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Home My WebLink About207-1337. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: Tubing Swap Conductor Surface Intermediate Liner Liner 2670 4760 7020 10530 Structural Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: 13b. Pools active after work: Sr Pet Eng:Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations DSR-4/6/23 RBDMS JSB 040623 WCB 11-29-2023 MIT-T passed. -WCB MIT-IA passed. -WCB 1 Regg, James B (OGC) From:PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Sent:Wednesday, March 22, 2023 1:23 PM To:Regg, James B (OGC); PB Wells RWO WSS Cc:Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; John Menke Subject:RE: [EXTERNAL] RE: Nordic 3 BOP Test 3/5/23 Attachments:Hilcorp Nordic 3 3-5-23 BOPE Test Report Revised.xlsx; Nordic 3 BOP Test Report 03-14-2023 Revised.xlsx; Nordic 3 03-19-2023 BOP Test Revised.xlsx Follow Up Flag:Follow up Flag Status:Flagged Jim, Reference the attached/updated BOPE Test Report for 3/5/23. We noticed the test reports on 3/14/23 and 3/19/23 also needed the same revision. Also attached. Thanks, Hilcorp RWO Team From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, March 22, 2023 8:50 AM To: PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Subject: [EXTERNAL] RE: Nordic 3 BOP Test 3/5/23 Missing valve sized for choke and kill lines; update and resubmit Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Sent: Tuesday, March 7, 2023 8:09 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. PBU H-24APTD 2071330 2 Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Subject: Nordic 3 BOP Test 3/5/23 Please find attached, Hilcorp RWO Team The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:3 DATE:3/19/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2071330 Sundry #322-309 Operation:Drilling:Workover:xxx Explor.: Test:Initial:xxx Weekly:Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2335 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 GK13 5/8" FP Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 1/2 VBR P Flow Indicator P P #2 Rams 1 BLIND P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1800 P Check Valve 0 NA 200 psi Attained (sec)23 P BOP Misc 1 3"P Full Pressure Attained (sec)124 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@2100psi P No. Valves 13 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 17 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/16/23 / 14:09 Waived By Test Start Date/Time:3/19/2023 /14:00 (date)(time)Witness Test Finish Date/Time:3/19/2023 /21:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nordic Test BOPE & Annular With 4 1/2" test JT. Annular fail. Function bag and retest - pass Hansen / Bondietti Hilcorp Ross / Bass PBU H-24A Test Pressure (psi): al.hansen@nordic-calista.com pbwellsrwowss@hilcorp.com Form 10-424 (Revised 08/2022)2023-0319_BOP_Nordic3_PBU_H-24A         J. Regg; 6/13/2023 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-24A Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-133 50-029-21512-01-00 341J ADL 0028284 11375 Conductor Surface Intermediate Liner Liner 8927 81 2646 9498 399 2138 9265 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8433 29 - 110 28 - 2674 27 - 9525 9231 - 9630 9237 - 11375 2335 29 - 110 28 - 2673 27 - 8654 8405 - 8744 8410 - 8927 None 2670 4760 7020 10530 9265 4930 6870 8160 10160 10000 - 11300 4-1/2" 12.6# L80 26 - 92828843 - 8877 Structural 4-1/2" TIW HBBP Packer No SSSV Installed 9174, 8357 Date: Stan Golis Sr. Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 970.779.1200 PRUDHOE BAY 2/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 4:19 pm, Jan 31, 2023 323-060 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.01.31 16:01:33 -09'00' Stan Golis (880) SFD 2/1/2023 DSR-2/1/23 10-404 * BOPE test to 3000 psi. Annular to 2500 psi. MGR03FEB23GCW 02/06/23JLC 2/6/2023 2/6/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.06 09:34:27 -09'00' RBDMS JSB 020723 REV. 1 Well Name:H-24A Date:1/31/23 Current Status:Not Operable Ivishak Producer API Number:50-029-21512-01 First Call Engineer:Josh Stephens Second Call Engineer:David “Brodie” Wages 713.380.9836 (M) PTD:207-133 Current Bottom Hole Pressure:3205 psi @ 8700’ TVD SBHPS 5-11-2021 Max. Anticipated Surface Pressure: 2335 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:265 psi 5-11-2022 Min ID:3.813” SSSV @ 2029’ CMIT: 10/21 to 2450 psi PPPOT-T/IC:5000 psi/3500 psi on 4/30/22 70 deg Dev:9800’ Last TT tag:11/21 - Drift to 8800’ SLM w/ 3.7” x 30’ 45KB patch drift Brief Well Summary and discussion Relatively uneventful drill well. The production casing cement job packed off early leaving ~50% of pumped cement volume (124 bbls of 263 bbls) in 9-5/8 casing. The rig pumped an OA downsqueeze after liner was set. H-24 has had a long history of integrity evaluations with suspected wellhead leaks, IA x OA communication and T x IA communication but has always managed to pass either a TIFL or MIT, until October 2021 where a TIFL failed and a subsequent LDL found Stations #7 and 3 leaking. We’ve tried Freudenberg, extended Freudenberg and swell dummy GLVs to no avail. Dual patches over 7 and 3 didn’t work either. The 2015 caliper has the tubing in fair condition so expect the integrity issue to be isolated with the patches. The 2021 LDL showed clear leak at 7 with possible leak at 3. With Station #7 dominating the IA x T inflow, it is difficult to say that the Station #3 leak is not bigger than it appears. Notes Regarding Wellbore Condition: 7” production casing passed a CMIT-TxIA on 10/2021 to 2450 psi The Ivishak perfs will remain isolated during the RWO via plug set in the 3-1/2” coil liner PPPOT-T to 5000 psi passed 4/30/2022 PPPOT-IC to 5000 psi passed 4/30/2022 Objective: RWO to replace 4-1/2” tubing with new 13Cr tubing Variance Request: 20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs. New tubing packer is at ~9000’MD which is 1000’ MD above the uppermost open perforations at 10,000’. Procedure Work Completed as of 8/16/22 Pre Sundry Work: DHD 1. CMIT-TxIA to 3,000-psi 2. Cycle LDS’s 3. PPPOT-T to 5000 psi 4. PPPOT-IC to 5000 psi The Ivishak perfs will remain isolated during the RWO via plug set in the 3-1/2” coil liner REV. 1 Sundry Procedure (Approval required to proceed): Eline 5. Cut tubing @ ~ 9,115’ ~5’ below first full joint collar above packer 6. Circulate well to 8.4 ppg 1% KCL or equivalent w/ diesel FP on T & IA Work Remaining as of 1/25/23 Valve Shop/Ops 7. Bleed WHP’s to 0 psi 8. Set and test TWC to 3000 psi 9. Nipple Down Tree and tubing head adapter. Inspect lift threads. Cap SSSV control lines 10. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO 11. MIRU Nordic 3 Rig. 12. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Nordic 3 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-½” and 4” test joints. Test the Annular preventer with a 4” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Pull TWC.Risk analysis to assure no pressure under BPV. May require lubricator to assure no pressure relase 14. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~95K 15. Pull 4 ½” tubing to floor, circulate bottoms up. a. Cut and cap control lines 16. LD Tubing to cut. Confirm and Strap cut joint length, and eccentricity of pipe to latch with overshot. a. Count control line protectors, original program had a band every other joint, no mention in drilling reports b. if any overpulls or indication of cement sheath is seen during POOH of original completion, discuss mill/scraper run with OE 17. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on proposed schematic. a. Ensure shear valve set at 2500# shear is installed in top GLM 18. Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 19. Drop ball and rod and set packer with 3,500psi pump pressure. 20. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 21. Shear valve in upper GLM. 22. Set TWC 23. Rig down Nordic 3. Valve Shop/Ops 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. REV. 1 Slickline 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. RDMO & pop well. Obtain AOGCC witnessed SVS test within 5 days of putting well online (all wells except water injectors) Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Change Form REV. 1 Current WBD: REV. 1 Proposed WBD: REV. 1 Nordic 3 BOP Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 31, 2022Subject: Changes to Approved Sundry Procedure for Well H-24ASundry #: 322-309 & TBDAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date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73,$3ORVWSVLLQVWPLQORVWSVLLQQGPLQIRUDPLQWRWDORI SVLIRUD3$66%OHGSUHVVXUHVEDFNWRVWDUWLQJSUHVVXUHEEOV7DJKXQJ )LQDO:+3V 69:9669 &09 2,$2$ 27* Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govOctober 4, 2021 Mr. Stan Golis Senior Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-21-037 Defeated Safety Valve System PBU H-24A (PTD 2071330) Dear Mr. Golis: On September 27, 2021 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed safety valve system tests performed by Hilcorp North Slope LLC (Hilcorp) at the Prudhoe Bay Unit H-pad. The low-pressure pilot on Prudhoe Bay Unit H-24A was found defeated at the time of performance testing. A copy of the inspection report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system, which would be a violation of State regulations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with an explanation of how this event happened and what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields. Inspection revealed Prudhoe Bay Unit H-24A was producing prior to the performance test but the low-pressure pilot was rendered inoperable; the pilot was placed back in service during the inspection. You are reminded that 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. Paragraph (m) establishes tagging procedures for a well safety valve system component that is inoperable, removed or blocked. There was no tag observed on Prudhoe Bay Unit H-24A that would indicate an inoperable low-pressure pilot. Sincerely, Jeremy M. Price Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.04 13:16:15 -08'00' Safety Valve & Well Pressures Test Report Reviewed By:P.I. Suprv ________Comm ________Well NumberPermit NumberInner PSIOuter PSITubing PSITest Code Date SISepar PSISet PSIL/P TripTest Code Test Code Oil,WAG,GINJ, GAS,CYCLE, SIYes/NoYes/NoWell DataPilotsSSVSSSVShutIn DtWell TypeWell PressuresGas LiftWaiverCommentsPBU_HMatt Herrera9/27/2021Pad:IntervalInspected by InspDt:InspNosvsMFH210928125210OperatorHilcorp North Slope, LLCOperator RepDavid Kindred180-DayReasonField NamePRUDHOE BAYInspectorSrc:Related Insp:H-01A1951100980550505P41-OIL05501338YesNo SSV Failed to hold Dp; will service and retest.NAH-061770020153125126PP1-OIL600500222NoNoNAH-081770230680550502PP1-OIL2751801838NoNoNAH-111800680153125110PP1-OIL65050285YesNoNAH-14B2071160680550536PP1-OIL001200NoNoNAH-16B2000650680550535PP1-OIL58001134YesNoNAH-17A1971520680550544PP1-OIL6403001779YesNoNAH-181822100680550521PP1-OIL175251400NoNoNAH-19C2140550203125117PP1-OIL1200150214YesNoNAH-201830070680550510PP1-OIL132501790NoNoNAH-211860710980550530PP1-OIL12005501099YesNoNAH-23A1950850980550512PP1-OIL8602001365YesNoNAH-24A207133068055053643P1-OIL13502001050YesNo LPP was in defeated position and could not trip on low pressure. LPP was reset and well tested.NAH-28A2140040203125114PP1-OIL3400200NoNoNAH-29A1980380680550535PP1-OIL7502001758YesNoNAH-301880350980550525PP1-OIL5001501232NoNoNAH-32194025015312595PP1-OIL16250325YesNoNAH-331940380680550530PP1-OIL3801501291YesNoNAH-382081670980550523PP1-OIL350751080YesNoNAH-4021505606805501P1-OIL150501309YesNo LPP failed to trip intially and every susbsequent attempt unless bled to 0 PSI. SSV tested good. Well was left shut in pending repairs.NA204037.5%CommentsWellsComponentsFailuresFailure RatePerformanceTuesday, September 28, 2021Page 1 of 1-%5James B. ReggDigitally signed by James B. Regg Date: 2021.09.30 12:54:57 -08'00' • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday,June 03, 2016 1:13 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; AK, OPS GC2 Facility OTL; Morrison, Spencer; Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy;Worthington, Aras J; Wellman, Julie Subject: OPERABLE: Producer H-24A (PTD #2071330) TIFL Passed All, Producer H-24A (PTD#2071330) was reported to have sustained IA casing pressure above MOASP on 05/22/16. The well was reclassified as Under Evaluation for further diagnostics on 05/24/16. A warm TIFL passed on 06/03/16 confirming two competent barriers in the wellbore. The well has been reclassified as Operable. Thanks! Jack Lau (Alternate:Adrienne McVey) LpNN�� OQ1 BP Alaska -Well Integrity Superintendent 5 W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Tuesda May 24, 2016 11:25 AM To: AK, D&C We • egrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; A', .• PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Se - O•erations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; A , •' GC2 Facility OTL; Morrison, Spencer; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects -Il Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; 'chris.walla 'alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitnernicki, Oliver R; Tempel, Troy; Worthington, Aras J ., Subject: UNDER EVALUATION: Producer H-24A (PTD #2071330) Sustained IA Casing Pressure Above MOASP All, Producer H-24A (PTD#2071330) was reported to have sustained IA casing pressure above MOASP on 05/2 .The pressures were confirmed to be TBG/IA/OA=SSV/2350/150.The well is reclassified as Under Evaluation for furthe diagnostics. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, May 24, 2016 11:25 AM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; AK, OPS GC2 Facility OTL; Morrison, Spencer; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer H-24A (PTD #2071330) Sustained IA Casing Pressure Above MOASP All, Producer H-24A (PTD#2071330) was reported to have sustained IA casing pressure above MOASP on 05/22/16.The pressures were confirmed to be TBG/IA/OA=SSV/2350/150.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Downhole Diagnostics:TIFL 2. Well Integrity Engineer/Anchorage PE:Additional diagnostics as needed Please reply if in conflict with proposed plan. Thanks, SCANNED JUL 1 12016 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWellIntegrityCoordinator@BP.com 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 5 *ANNEDAUG 8 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission a07- t 33 333 West 7 Avenue Anchorage, Alaska 99501 H Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 1403 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 1-1-06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 11-09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 11-11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 1-1-20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 -- H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 11-33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 11-34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 11-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H-36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071330 Well Name/No. PRUDHOE BAY UNIT H-24A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21512-01-00 MD 11375 TVD 8927 Completion Date 12/1/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES, MCNL / GR /CCL Well Log Information: Log/ Electr Data Digital Dataset T e Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments WED D Asc Directional Survey ~; Rpt Directional Survey Cement Evaluation D C L 15919 ~d /R i ti it i as uct on s v y es G~L~og Neutron C Lis 15924~eutron pt LIS Verification ,.ED C Lis 16574 ~ duction/Resistivity ~Je6g Gamma Ray wog Induction/Resistivity ~og Induction/Resistivity I og See Notes 9602 11375 Open 1/10/2008 9602 11375 Open 1/10/2008 5 Col 1 9152 11282 Case 1/22/2008 Mem CBL, GR, CCL, VDL 30-Nov-2007 9568 11374 Open 2/8/2008 LAS ATR, RPM, GR, Ram, ROP, RPD in PDF graphics Cam 25 Blu 9000 11253 Arycn 2/13/2008 MCNL, GR, CCL in Carrier 29-Nov-2007 8919 11260 Open 2/13/2008 LIS Veri, GR, CNT 9560 11366 Open 7/10/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 9560 11366 Open 7/10/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 5 Col 9625 11375 Open 7/10/2008 MD GR 5 Col 9625 11375 Open 7/10/2008 MD MPR, GR 5 Col 9625 11375 Open 7/10/2008 TVD MPR, GR 2 Col 9480 11330 Open 7/10/2008 Depth Shift Monitor Plot Well Cores/Samples Information: • Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071330 Well Name/No. PRUDHOE BAY UNIT H-24A MD 11375 TVD 8927 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~~-P~1~ Analysis 4"Tl~ Received? Comments: Completion Date 12/1/2007 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21512-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? / N Formation Tops / N Compliance Reviewed By: Date: ~ ~ INTEQ Log & Data Transmittal. Form To: State of Alaska -AOGCC 333 W. 7~h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: H-24A ~ Contains the following. c 1 LDWG Compact Disc (Includes Graphic Image files) ,~ 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - GR Directional MAD MD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) 1 color print - MPR/Directional MAD MD Log (to follow) LAC Job#: 1681896 Sent by: Catrina Guidry Date: 07/10/08. -. Received by: ~ ~ ~ ~~ .~ Date: ,, .. PLEASE ACKNOWLEDGE RECEIPT BY' SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ ~~~ BAK LIYTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ®/-® BAKER NV~sHES Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y BY EXYLURA'1'lUN (ALASKA) 1NC CUUNIY NUK'1'H SLUYE BURUUGH WELL NAME H-24A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 7/10/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 168 i 896 Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 - This Distribution List Completed Bv: Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-] Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 I Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address ~~~ - ;~~ Page 1 of 1 07/03/08 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth U/nll _Inh ~ N0.4768 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... n,. MPB-50 11999019 RST WFL a 06/13/08 1 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 Pi-24 12066527 MEM LDL (p~° f 06/18/08 1 1 04-11A 11975778 LDL ~~, - / 06/24/08 1 1 M-04 11962601 PRODUCTION PROFILE s 06/21/08 1 1 12-03 12071857 USIT j ~ . ~(~ ~ 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG '3.~ ~ 06/20/08 1 1 E-10B 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v-~-_ (0 12/07/07 1 1 18-13B 12021159 MCNL V _ 05/18/08 1 1 vv r.v.~..v •.r~v Ma. ..~v ~.. . Y ~ VI~.I~Y~I~~.i I1~~IJ f1G1 VIlIY11YV VIYG liVr ~ CNVfI 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~a ~s ;t% Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 /' ATTN: Beth ~ / /~ Received by: ~~ 1 02!04/08 • c~~~mb~rrer NO. 4572 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt, Polaris,Lisburne Wnll _Inh 8 1 nn r]ocr_rintinn Dafa RI Cnlnr CD LGI-04 11970706 SBHP SURVEY , 6" 01/01/08 MPH-12 11978435 MEM DDL 01/31/08 1 W-216 12031441 USIT ~-.- . 01/11/08 1 W-214 11855826 CH EDIT PDC GR (USIT) ~, 11/19/07 1 GNI-04 11846828 CH EDIT PDC GR (USIT) 11/11/07 1 15-36B 11216209 MCNL (0 08105/06 1 1 H-24A 11767145 MCNL 'a- I'J`'9~t 11/29107 1 1 C-04B 11216198 MCNL ~ - (~".; ~) 3 06102/06 1 1 L3-11 11962776 MCNL ~ ~ q 12/12/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 r ~" '~ I ~, - 900 E. Benson Blvd. Anchorage, Alaska 99508 s ryry rf Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ ~~ by • BPXA WELL DATA TRANSMITTA Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have Date 02-08-2008 Transmittal Number:92927 ,. ~~-~ ~,;,~ a,:; L ~ ., .,~:, ~ ,, . to .~, contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 18-13BPB1 i~'$-IoV tS q ~ 5~ 18-136P62 l$'~--r6° lS9l~ 18-13BPB3 (~S~ -« ! S9 t ~- H-14B c~V~-- ~r co t~ °- ~ 3l -14A ~~-_ l p2 159ao I-214 ul~ao`~- a~la lssar G/,~~~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • Saltmarsh, Arthur C (DOA) • Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, January 28, 2008 11:51 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU H-24A / PTD # 207-133 Hi Art, Please reference the following well: Well Name: PBU H-24A Permit #: 207-133 API 50-029-21512-01-00 Top Perf MD: 10,000' Bottom Perf MD: 11,300' This welP began Production on January 22, 2008 Method of Operations is: Flowing Date of Test: 01!22/08 Hours Tested: 8 24-Hour. Rate /Oil-Bbl: 4,797 24-Hour Rate 1 Gas-cf: 19,905 24-Hour Rate 1 Water-Bbl: -0- Test Rate /Oil-Bbl: 1,599 Test Rate /Gas-Mcf: 6,635 Test Rate fWater-Bbl: -0- Choke Size: 80 Gas-Oil Ration: 4,150 Flow Tubing Pressure: 1,120 Casing Pressure: 1,560 Oil Gravity-API: Unavailable 1/28/2008 01/11/08 NO. 4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Seth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. Wall .Inh $ Inn Ilaccrin4inn rla4a RI Cnlnr Rr1 Z-06 11594523 STATIC TEMP LOG 09/09/07 1 14-188 11975743 SBHP SURVEY 12108/07 1 14-02C 11767144 SBHP LOG - 11102107 1 H-24A 11963073 MEM CBL - ~ 11/30107 1 C-35A 11624351 CEMENT BOND & GRAVEL PACK --a 11/03/07 1 MPH-19 11982423 USIT - (p ~ 12110/07 1 1 E-03A 11628773 MEM PROD PROFILE - j 05/09107 1 E-11B 11434760 OH LDWG EDIT (DSI) - G ~ 10/29/06 1 1 G-06A 11209587 MCNL - (~ ~-~ 02/25/06 1 1 D-07B 11162822 MCNL ~- ~ 12/04/05 1 1 G-10C 11209607 MCNL ~(p- a 06/15/06 1 1 G-09B 11649989 MCNL ~ ~. - j j () j ~j$ f' 09/11/07 1 1 K-086 11745243 MCNL 9 '~ ~S 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12/06107 1 V-07 11978425 USIT - ( 12/06/07 1 L2-33 11970801 RST j - d ~ 07107!07 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ I 04/23106 2 1 ~~ YLtASt AI:RNVWLtU(9t KtlalYl liY JItiNIN(i ANU ha1UKNING VNE GVPY EAGN tU: BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LR2-1 ' 900 E. Benson Blvd. ~~- Anchorage,Alaska 99508 Date Delivered: fl,.9~ ~ ~~ '~ r'~l~~rS Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~' ,-- /~ Received by: ~"' / ®~ STATE OF ALASKA / -O~ j ; ~ ~ ALASKA~L AND GAS CONSERVATION COM~SION / WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~c~ ~ s ~oa~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended `' i'"'' ~fl•1l~ImSiO 20AAC25.105 2oAAC2s.~,o ®Devel a Exploratory ° +' ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One .. . ^ Service ~ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 12/1/2007 207-133 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/22/2007 50-029-21512-01-00 ~ 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 11/27/2007 PBU H-24A 755 FNL, 1735 FEL, SEC. 21, T11N, R13E, UM ' Top of Productive Horizon: 8. KB (ft above MSL): 71.8' 15. Field /Pool(s): 469' FNL, 4826' FEL, SEC. 21, T11 N, R13E, UM Ground (ft MSL): 42.86' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 310' FNL, 3567' FEL, SEC. 21, T11N, R13E, UM 11340 8903 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 642842 y- 5960025 Zone- ASP4 11375 8927 ADL 028284 ~ TPI: x- 639746 y- 5960251 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 641001 y- 5960435 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed informatio per 20 AAC 5.071): MWD DIR / GR / RES, MCNL / GR / CCL /~/%Ndo/~/ 96,E j/l ~ ~ ~TY4~ 22. CASING, LINER AND CEMENTING ECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HDLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated C nductor Surface 110' Surface 110' 36" 8 c ds Con re e 13-3l8" 72# L-80 Surface 2674' Surface 2673' 17-1/2" 3271 cu ft Coldset III 465 cu ft CS II 9-5/8" 47# L-80 Surface 9525' Surface 8654' 12-1 /4" 1984 cu ft Class 'G', 230 cu ft Class 'G' 7" 26# L-80 231' 8405' 8744' 8-1/ " u ft lass'G' 3-1 /2" x 3-3116" 8.8# / 6.2# / L-80 9237' 11375' 8410' 8927' 4-1 /8" 174 cu ft Class 'G' 116 cu ft Class 'G x 2-7/8" / 6.16# 23. Open to production or inject ion? ®Yes ^ No 24. TueING RecoRD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9282' 9174' MD TVD MD TVD 10000' - 10230' 8843' - 8808' CEMENT SQUEEZE ETC. 25 ACID FRACTURE 10500' - 10590' 8806' - 8798' , . , , 10620' - 10990' $794' - 8769' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11020' -11300' 8774' - 8877' 2100' Freeze Protect w/ 18 Bbls of McOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PfeSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. § .~G~Eh~~ti70i4~ None ~ ~,.. Form 10-407 ReVlSed 02/2007 CONTINUED ON REVERSE SIDE ¢ ~ ~ ~ / 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit /Zone 4B 9725' 8817' None Formation at Total Depth (Name): Sadlerochit /Zone 46 9725' 8817' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego g is true and correct to the best of my knowledge. Si d ~~/~~~ ~ ~ gne Title Drilling Technologist Date ( Terrie Hubble PBU H-24A 207-133 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: .Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 jRig Name: NORDIC 1 Rig Number: N1 Date From - To Hours. Task Code NPT - -Phase Description of Operations 11/17/2007 09:00 - 11:00 2.00 RIGD N RREP PRE Satellite camp would not run on its on power, unloaded sewage 11:00 - 12:00 1.00 MOB P 12:00 - 13:00 1.00 MOB N 13:00 - 19:00 6.00 MOB P 19:00 - 19:15 0.25 MOB P 19:15 - 20:30 I 1.25) MOB ~ P 20:30 - 00:00 3.50 BOPSU P 111/18/2007 100:00 - 07:00 I 7.001 BOPSUFiP 07:00 - 07:50 I 0.831 RIGU I P 07:50 - 08:20 0.50 RIGU P 08:20 - 09:30 I 1.171 CLEAN I P 09:30 - 10:15 I 0.751 CLEAN I P 10:15 - 11:30 1 1.251 BOPSURP 11:30 - 12:15 I 0.751 CLEAN I P 13:00 - 14:105 I 10.251 CLEAN I P 14:15 - 14:50 i 0.581 CLEAN I P 14:50 - 17:30 I 2.671 CLEAN I P 17:30 - 17:50 i 0.331 CLEAN I P 17:50 - 19:45 I 1.92 CLEAN I P 19:45 - 20:30 0.75 CLEAN P 20:30 - 20:45 I 0.25 WHIP I P 20:45 - 23:30 2.75 WHIP P and water tanks to sewage truck, freeze protect camp with RV anti-freeze PRE PJSM on rig move and weather conditions, Jack do and attempt to moved rig off well, would not move, Jack up not able to turn wheels in low gear but was able turn wheels in high gear, troubleshoot problem, not able to solve, jack do rig, moved off well in high gear and to front side of pad WAIT PRE Roads and pads clearing snow drifts in front of pad for rig move - PRE Move rig and satellite camp from K-pad to H-24 in high gear PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation for backing rig over well H-24A. PRE Back rig over well and set rig down. PRE RIG ACCEPT 20:30 HRS, 11/17/07 N/U BOPE R/U tiger tank and hardline. PT hardline. Fill pits w/ 2% double slick KCL PRE BOPE test, 250 si Low - 3500 si Hi h - AOGCC notified - witness test waived by Bob Noble Bottom of lubricator leaking, change out o-ring, serviced and retested kill tine valve and #12 manifold valve . Re-grease all valves on choke manifold. PRE PU injector, RU to pull CT across pipeshed, leveled satellite camp PRE PJSM on pulling CT across, pull tested internal grapple, Pull CT across pipeshed, stab injector WEXIT Pump 5 bbls of KCL water, test surface lines to inner reel valve, 4000psi, repaired leak in chicsan line, circ CT vol at 2.86bpm, 400psi WEXIT Slack management, pumped 35 bbls, cable move a couple times on first pump up at 4.1 and 4.6 bpm, 2150 and 2600psi , Std Back Injector over circ hole, circ thru CT WEXIT PJSM, reviewed RP for pulling BPV, PU lubricator, extensions and tools to rig floor, RU and test lubricator to 1000 psi, Pull L, offload lubricator, extensions and tools. WEXIT PU injector, install Hydraulic CT cutter, Cut 100' of coil, 10' of E line, RD Hydraulic cutter WEXIT Install coil connector and pull test CTC WEXIT MU a-line anchor sub, Pressure test CTC and inner reel valve, change out leaking fitting on first attempt WEXIT MU LH Nipple milling BHA #1, Bakerloc all RH connections above X-O made up to LH motor and mill, stab injector WEXIT RIH with BHA #1, .44bpm, 300psi, RIH to 9100', Up wt 39.5k, Dn wt 26.6k, RIH dry tag at 9259', WEXIT PU, tagged XN nipple, stalled mtr at 9259', 2x, milled thru XN nipple, worked thru several times, RIH to 9360', dry drift XN, OK WEXIT POH to BHA #1. WEXIT P/U injector. L!D LH XN nipple milling BHA #1. S/B injector. Circ through kill line to keen hole full. Loosino 0.6 born. WEXIT P/U whipstock through beaver slide and layout on catwalk. WEXIT M/U SLB Dipple CTC, Re-head eline. meg test eline -okay. PT to 4000 psi. Printed: 12/19!2007 2:23:07 PM BP EXPLORATION Operations Summary Report Page 2 of 14 ~ Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT I Phase I Description of Operations 11/18/2007 23:30 - 00:00 0.50 WHIP P WEXIT M/U BOT 4-1/2" x 7" whipstock setting BHA #1. WS #10 11/19/2007 00:00 - 00:45 I 0.75 WHIP I P 00:45 - 03:00 2.25 WHIP P 03:00 - 04:00 I 1.001 WHIP I P 04:00 - 04:10 0.17 WHIP P 04:10 - 06:40 2.50 WHIP P 06:40 - 07:00 0.33 WHIP P 07:00 - 08:30 1.50 REMCM P 08:30 - 10:30 I 2.001 RE 10:30 - 12:30 I 2.00 12:30 - 13:30 1.00 13:30 - 14:50 1.33 14:50 - 17:35 2:75 17:35 - 17:40 0.08 17:40 - 17:50 0.17 17:50 - 18:30 0.67 18:30 - 19:45 1.25 WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT SFAL WEXIT J-Hydraulic setting tool, BHI CoilTrak. Overall BHA length 81.36' Continue M/U WS setting BHA #2. Stab injector. Open EDC. RIH w/ whipstock BHA #2. RIH at 100 fpm, 1.0/1.0 bpm. Up wt 40k. Dn wt 26K. Log GR tie-in to PDC log from 9600'-9675'. -10' correction. PUH to 9,625' top of whipstock. Orient TF to 10 deg ROHS. Top of Whipstock at 9,625'. Close EDC. Began pumping at 0.3 bpm. Bring up pump to 3000 psi, pressure dropped to 300 psi. Clear indication of release. Shut off pumps, RIH slow, set down 3K. P/U clean. POOH to whipstock setting BHA, stand back injector POH, LD WS setting tool BHA #2 MU Cementing BHA #3 with SLB Dipple Connector, X-O, UOC, LQ Blind, 2 X-O's, 2 3/8" PH6 Pup Jt, Nozzle with 1" center hole - OAL 13.71', stab injector RIH with Cmtg BHA #3, Tag WS at 9642', correct depth to 9625', PU 10' to 9615', Flagged pipe, EOP at 9601.3', POH to 9300' PJSM for cement job, Shut in well, Est Inj Rates at 1.0 bpm 165psi 1.5 bpm 780psi 2.0 bpm 1190psi 2.5 bpm 1630psi Open well, Circulate .6 BPM at 35 psi, Pump 5 bbl H2O, PT cementers to 6500 psi, 23 bbl of 15.8ppp cmt slum at 1.62-1.45/1.02-.86bpm with 1100-1300psi, 5 H2O at 1.6/1.02bpm, 1523psi, Swap to Bio, Displace cmt with rig pump, 25bbls of biozan at 2.1 -2.38/1.28-1.70 bpm at 1875-1350 psi, Shut in backside, Bullhead at 2.1 bom at 1700 psi, 11 bbl away WH Presssure increase to 1700-1935psi, 16bbls away at 2200psi, 31.5 bbl away Rressure increased to 3800psi, shut down pumping while POH tp 9000`, pressure fell off to 1400psi, monitor well for 30 minutes with 1400 -985 psi bbls in 7" csg above whipstock at 9625', top set of perfs at 9590' - 9610' RIH, wash do tagged top of WS at 9625', maintain 500 psi back pressure while pumping 2.35/2.52bpm, 2200psi Circ Btms up with 35bb1 biozan sweep at 2.66/2.66bpm with 1840 - 1115psi, cmt returns to surface, strung out over 50bbls at 8.53 -11.Oppg, washed back thru 7" 3x's POH to Cmtg BHA #3, circ at 2.78/2.60bpm, 1285psi, wash thru all jewelry in 4 1/2" production tbg POH, LD cmt nozzle BHA #3 MU swizzle stick, Stab Injector Flush stack, circ thru surface lines, cycling choke and reel manifold valves Manifold lines in reel house frozen. Heat up and thawed out. Printed: 12/19!2007 2:23:07 PM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2007 18:30 - 19:45 1.25 REMCM N SFAL WEXIT Change out CT packoffs. 19:45 - 21:15 I 1.501 BOPSUF4 P I I WEXIT 21:15 - 22:30 I 1.251 BOPSUFI P I I WEXIT 22:30 - 22:45 I 0.251 STWHIPI P I I WEXIT 22:45 - 23:45 I 1.00 I STWHIPI P I I WEXIT 11/20/2007 100:00 - 01:30 I 0.501 STWHIPI P I 1 WEXIT 01:30 - 02:00 0.501 STWHIPI P WEXIT 02:00 - 02:10 0.17 STWHIP P WEXIT 02:10 - 03:45 I 1.581 STWHIPI P I I WEXIT 03:45 - 04:45 I 1.001 STWHIPI P I I WEXIT 04:45 - 07:00 I 2.251 STWHIPI P I I WEXIT 07:00 - 07:30 0.50 STWHIP N RREP WEXIT 07:30 - 07:50 0.33 STWHIP P WEXIT 07:50 - 11:40 I 3.831 STWHIPI N I RREP I WEXIT 11:40 - 11:45 0.08 STWHIP N RREP WEXIT 11:45 - 00:00 12.25 STWHIP N RREP WEXIT 111/21/2007 100:00 - 06:00 I 6.001 STWHIP) N I RREP I WEXIT PT lines in reelhouse and CT packoff to 4000 psi. PJSM. P/U injector. L/D swizzle stick. Drain stack. Open bottom door on BOP stack, inspect for cement -okay. Meanwhile R/U to test eline. Eline tested okay. R/U to PT stack. Pressure test BOP stack body to 250 psi low, 3500 psi high. SAFETY MEETING. Reviewed procedure, hazards and mitigation for M/U window milling BHA. M/U window milling BHA #4. M/U 3.8" mill, string reamer, 2 jts 2-3/8" PH6, BHI CoilTrak including DGS. Overall BHA length 122.20'. Stab injector. RIH w/ window milling BHA #4. RIH w/ whipstock milling BHA #4. Pump at min rate. Full returns. RIH to 9585'. Tie in with GR from 9585'- 9625'. -9' correction. Bring up pumps to 2.5 bpm, 2100 psi. RIH at 2.5 fpm. Tag pinch point at 9629.8'. Flag pipe. Did not see any cement i,/i above whipstock. Mill 3.80" window thru 7" Liner. 2.6 bpm, 2500 psi, 0.5K wob, 1 fph. Stalled multiple times getting window started. Motor would stall w/ 200 Ibs WOB. Milled to 9630.3'. Mill 3.80" window thru 7" Liner. 2.5 bpm, 2600 psi, 1-1.5K wob, 1 fph. Milled to 9631.0'. Mill 3.80" window. 2.5 bpm, 2600 psi, 3-4.2K wob, 1 fph. Milled to 9633.1'. POH to 9350', Troubleshoot Gen #2, generator not producing proper voltage and cycles, creating loud noise and vibration, RIH to Btm at 9633.1' Mill 3.80" window, 2.5 bpm, 2600 psi, 3-4.2K wob, 1 fph, Milled to 9633.4' Temporarily lost rig power, PU off btm to 9566', circ at .20bpm, 700psi, troubleshoot generator #2 and SCR #1 problem, changed out mother board on SCR #2 RIH to btm. attempt to mill window with 2.5 bpm, 2600 psi, SCR tripped at 9632', lost power pack and pump, trouble assigning SCR assignments, SCR #1 back online at 12 noon, POH to 9600', circ 5bbls Troubleshoot SCR#1, Caterpillar mechanic Steve(sick with Flu) arrived at rig from 1300 - 2100 hrs, RU computer, reprogram generator, found fusible link on fuel line tripped, still investigating problem with SCR #1 and or generator, troubleshooting voltage irregularities with gen #2 Change out electronic control modulator (ECM) on gen #2, stilt troubleshooting problem. Still troubleshooting problem with SCR #1 and or generator. NC mechanic, Josh, onsite from 0100 - 0400hrs. Coil parked 9589.6', circ at 0.4 bpm thru open EDC. Nordic electrician houred out until 0600 hrs. Printed: 12/19/2007 2:23:07 PM BP EXPLORATION Page 4 of 14 Operations Summary Report ~'~ Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/21/2007 06:00 - 16:00 10.00 STWHIP N RREP WEXIT Troubleshoot problems with SCR and or Gen #2. Nordic 2 16:00 - 17:00 1 1.00 i STWHtPI P I I WEXIT 18:00 - 20:30 I 2.501 STWHIP P I I WEXIT 22:00 - 23:45 I 1.751 STWHIPI P I ~ WEXIT 23:45 - 00:00 0.25 STWHIP P WEXIT 11/22/2007 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 02:45 0.25 STWHIP N SFAL WEXIT 02:45 - 04:45 2.00 STWHIP P WEXIT 04:45 - 06:00 ( 1.251 STWHIPI P 06:00 - 06:45 I 0.75 DRILL P 06:45 - 08:30 I 1.751 DRILL I P 08:30 - 08:45 0.25 DRILL P Utf:45 - 13:00 - 13:10 0.17 DRILL P 13:10 - 14:15 1.08 DRILL P 14:15 - 14:30 I 0.251 DRILL I P 14:30 - 15:10 I 0.671 DRILL I P WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 electrician, Mike Schick arrived on slope at rig for 1400hrs, PJSM reviewed operational proceedures, proceeded to investigate SCR and Gen #2 problems, found negative reference for trottle signal missing, ran a new negative reference wire for trottle signal, load test Gen #2, ok Mill 3.80" window, 2.68 bpm, 2574 psi, 1.0-2K wob, 1 fph, ECD 9.39ppg, Milled to 9634.2', PVT 304bb1s Mill 3.80" window, 2.68 bpm, 2640 psi, 2K wob, 1 fph, ECD 9.36ppg, Milled to 9635.2' Mill 3.80" window thru 7" Liner. 2.65 bpm, 2600-2700 psi, 2-2.5K wob, 1 fph. Milled to 9637'. Exit liner at 9,637'. 7.2' long window. Mill to 9639.4'. 2.65 bpm, 2600 psi, 0.7-1K WOB, 1 fph. Mill 10' rat hole. 2.67/2.67 bpm @ 2650 psi, 5 fph. Drill to 9647'. P/U and backream window. Continue to backream window to 9624.5'. Ream and backream window multiple times at 0.5 ft/min. Shut down pumps, drift window -okay. Swap wellbore over to Flo-Pro. Temporarily lost rig power. Breaker for Gen #2 tripped, causing Gen #1 breaker to trip. Circulating fan in SCR room had not been turned on. P/U to 9616', open EDC. Called out Nordic electrician to check everything. No issues were found. POOH w/ window milling BHA #4. KICK WHILE TRIP DRILL 04:00 HRS PJSM. S/B injector. LD window milling BHA #4. M/U drilling build BHA #5 with 3.75 x 4.125 BC bit, x-treme 3.0 degree motor, HOT USR, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LOC, UOC, X-O, SLB CTC, stabbed Injector Open EDC, RIH with Drlg BHA #5 to 9600', closed EDC Tie-in pass from 9615' to 9644', TF 7R, correct -10' SLB, -9' Baker RIH to btm at 9647, Drld Dir to 9809', 2.48/,2.48bpm, 3400psi, FS at 2.60bpm, 3250psi, WOB 1.5k, Dn wt 21.5k,Up wt 39k, PVT 299bb1s, ECD 9.83ppg, ROP 25-110fph, BP 4890psi, AP 4431 psi, IA 33psi, OA 118psi Wiper trip to window Drld Dir to 9910', TF 90R, 2.62/,2.62bpm, 3600psi, WOB 2.3k, PVT 299bb1s, ECD 9.93ppg, ROP 124fph, BP 5222psi, AP 4529psi, IA 56psi, OA 242psi, Lost all returns, pump pressure drop to 2600psi at 2.62bpm POH to 9800', no problem coming off btm, unable to est returns, RIH Drld Dir to 9950', TF97R, 2.5/O.Obpm, 3127psi, FS at 2.45bpm, 2700psi, WOB .5 - 1.5k, PVT 238bb1s, ECD 9.12ppg, ROP 105fph, BP 4925psi, AP 4163psi, IA 52psi, OA 300psi, partial returns at 9950', 2.51/.51 bpm, 3157psi, PU off btm clean at 9930', 9950' with Up wt 39.5k Printed: 12/19/2007 2:23:07 PM BP EXPLORATION Operations Summary Report Page 5 of 14 Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date (From - To (Hours I Task Code ~ NPT ~ Phase ~ Description of Operations 11/22/2007 14:30 - 15:10 0.67 DRILL P PROD1 Offloading Vac Trk of Flo-Pro to active system to keep up with loses 15:10 - 15:35 0.42 DRILL P PROD1 Drld Dir to 9994', TF 90R, 2.5/.51 bpm, 3127psi, FS 3150psi, WOB .5 - 1.5k, PVT 275bb1s, ECD 9.74ppg, ROP 80fph, BP 4825psi, AP 4429psi, IA 22psi, OA 260psi, PU off btm clean at 9994' with Up wt 39.5k 15:35 - 15:45 0.17 DRILL P PROD1 Short BHA wiper, PU off btm clean at 9994' with Up wt 39.5k 15:45 - 16:00 0.25 DRILL P PROD1 Drld Dir to 10011', TF 100R, 2.5/.80bpm, 3340psi, FS 2800psi, WOB 3.75k, PVT 275bb1s, ECD 9.70ppg, ROP 65fph, BP 5111 psi, AP 4413psi, IA 22psi, OA 255psi, 16:00 - 16:30 0.50 DRILL P PROD1 Drid Dir to 10050', TF 94R, 2.5/1.1 bpm, 3340psi, WOB 2.35k, PVT 279bb1s, ECD 9.67ppg, ROP 99fph, BP 5210psi, AP 4428psi, IA 15psi, OA 225psi, 16:30 - 17:00 0.50 DRILL P PROD1 Wiper trip to 9700' 17:00 - 18:00 1.00 DRILL P PROD1 Drld Dir to 10153', TF 80R, 2.45/1.45bpm, 3300psi, WOB 2.47k, PVT 278 -238bb1s, ECD 9.69ppg, ROP 82fph, BP 5152psi, AP 4393psi, IA 9psi, OA 118psi, 18:00 - 18:30 0.50 DRILL P PROD1 Wiper trip to 9900' 18:30 - 19:00 0.50 DRILL P PROD1 Directionally drill build to 10200', 2.45/1.12 bpm, 3300 psi, TF 150R, 1.5-2k DHWOB, 90fph, 9.8ppg ECD, PVT 170 bbls, IA 10psi, OA 117psi 19:00 - 20:00 1.00 DRILL P PROD1 MAD pass build section. 20:00 - 20:45 0.75 DRILL P PROD1 P/U to 9537', open EDC. Circulate at 2.71/1.37 bpm at 2800 psi. Finish mixing Form-A-Squeeze pill. 20:45 - 21:15 0.50 LCR P PROD1 RIH to 10200' while circulating 22 bbl 9.5 ppb Form-A-Squeeze pill to bit. Displace FASO w/ 50 bbls viscosified Flo-Pro. 21:15 - 23:15 2.00 LCR P PROD1 Pump pressure dropped from 3300 psi to 3100 psi at 57 bbls (pill exiting bit) at 2.6 bpm. After calculated 2 bbls out, POH laying pill up to 7200', 0.44/0.15 bpm, 800 psi, P/U at 42 fpm. At 7200', increase rate to 1.50 bpm, losses seemed to nearly stop, POOH. Stop at 550', pump at 0.27/0.23 bpm, 900 psi. Loosing 0.05 bpm. POOH to surface. 23:15 - 00:00 0.75 DRILL P PROD1 PJSM. S/B injector. L/D drilling build BHA #5. 11/23/2007 00:00 - 00:15 0.25 DRILL P PROD1 Continue L/D drilling build BHA #5. Bit graded 1/1/i. 00:15 - 00:30 0.25 WHSUR C PROD1 SAFETY MEETING. Reviewed procedure, hazards and mitigation with Little Red for FP wellbore w/diesel. 00:30 - 01:15 0.75 WHSUR C PROD1 Little Red PT lines to 2500 psi, Little Red began pumping down kill line to bullhead diesel into wellbore. Begin pumping at 1 bpm, 100 psi shut in pressure 5 bbls away, pressure built to 700 psi, then dropped to 0 psi. 10 bbls away, pressure started slowly building again to 150 psi. 15 bbls away, 345 psi 20 bbls away, 520 psi 25 bbls away, 640 psi 30 bbls away, 725 psi 35 bbls away, 800 psi Little Red shut down pumps at 35 bbls away, pressure slowly started dropping off to 0 psi. Well seems to have gone slightly back on a vac. 01:15 - 01:45 0.50 WHSUR C PROD1 PJSM. Set BPV using T-bar. 01:45 - 03:00 1.25 RIGD C PROD1 P/U injector. R/U to reverse circulate thru coil to freeze protect. Pump 5 bbl water spacer, followed by 5 bbls McOH. Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date.. From - To Hours Task Code NPT Phase Description of Operations 11/23/2007 03:00 - 06:00 3.00 RIGD C PROD1 S/B injector. N/D BOP stack. N/U tree cap. PT tree cap to 3500 psi. Secure stack in cellar. Empty and clean rig pits. 06:00 - 00:00 18.00 MOB C PROD1 Suspended operations and preparing to move off well to allow Doyon 14 to move off pad which is expected to occur within next 24 hrs, Performing maintenance on pumps, injector, and boiler. Performing general housekeeping and painting. WOW unable to open cellar doors do to high winds 07:00 -Weather conditions Phase 2 on all roads and Pads in GPB FIRE DRILL 2200 HRS SPILL DRILL 2330 HRS 11/24/2007 00:00 - 06:00 6.00 MOB C PROD1 Continue to suspended operations and preparing to move off well to allow Doyon 14 to move off pad which is expected to occur within next 24 hrs. Performing maintenance on pumps and boiler. Performing general housekeeping and painting. WOW unable to open cellar doors do to high winds Phase 1 weather conditions with 37 MPH winds gusting to 45 MPH H2S DRILL 0300 HRS 06:00 -13:00 7.00 MOB C PROD1 Continue to suspended operations and preparing to move off well to allow Doyon 14 to move off pad which is expected to - occur within next 24 hrs. Performing maintenance on pumps and boiler. Performing general housekeeping and painting. WOW, unable to open cellar doors do to high winds Phase 1, Level 11 weather conditions with 32 MPH winds gusting to 45 MPH Fire Drill in Motor Room at 0815 hrs 13:00 - 15:30 2.50 MOB C PROD1 PJSM on rig move operations, Continue to suspended operations, moved off well, spot rig in SW comer of pad along with satellite camp to allow Doyon 14 to move off pad, Performing general housekeeping and painting 15:30 - 00:00 8.50 MOB C PROD1 Continue to suspended operations, rig spotted in SW corner of pad along with satellite camp to allow Doyon 14 to move off pad, Performing general housekeeping and painting 11/25/2007 00:00 - 01:00 1.00 MOB C PROD1 Continue to suspended operations, rig spotted in SW corner of pad along with satellite camp to allow Doyon 14 to move off pad, Performing general housekeeping and painting 01:00 - 01:30 0.50 MOB C PROD1 Doyon 14 began moving from H-14. Started warming up moving system and getting ready for Doyon 14 to pass. Doyon 14 passed Nordic 1 at 0130 HRS. 01:30 - 01:45 0.25 MOB C PROD1 SAFETY MEETING. Reviewed procedure, hazards and mitigation for backing rig over well. 01:45 - 02:45 1.00 MOB C PROD1 Back rig over H-24A and set rig down. 02:45 - 05:30 2.75 BOPSU C PROD1 N/U BOPE R/U tiger tank hardline Fill pits w/ Flo-Pro Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Page 7 of 14 Operations.. Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date: From - To Hours Task Code NPT Phase Description of Operations 11/25/2007 05:30 - 06:30 1.00 BOPSU C PROD1 Funtion test BOPE, Body test BOPS, AOGCC notified -test witnessed waived by Jeff Jones 06:30 - 08:00 1.50 BOPSU C PROD1 PT hardline to tiger tank, replaced leaky 1" block valve on manifold line, test hardline to 300 - 3000psi 08:00 - 09:45 1.75 BOPSU C PROD1 PJSM on retrieving BPV, PU DSM lubricator, Pressure test to 1500psi, retrieve BPV, LD, offload lubricator 09:45 - 10:35 0.83 DRILL C PROD1 MU nozzle assy #6 with 1" big hole nozzle, 2 3/8" PH6 pup jt, X-o's, LO blind, install check valves in UOC, X-O, SLB CTC, Stab injector, BHA OAL - 13.71' 10:35 - 11:00 0.42 DRILL C PROD1 Circ 8 bbls of McOH and FW from CT to tiger tank, PVT 286bb1s 11:00 - 12:30 1.50 DRILL C PROD1 Open well, on slight vacuum, RIH with Nozzle assy #6 to 9300', started getting returns while RIH at 3500' 12:30 - 13:00 0.50 DRILL C PROD1 Circ well clean at 3.0/2.4bpm, 3040psi, MW in 8.45 ppg, MW out 8.64ppg 13:00 - 15:00 2.00 DRILL C PROD1 POH to nozzle, pumping at 1.37/.83bpm, 1362 psi 15:00 - 15:30 0.50 DRILL C PROD1 PJSM. L/D Nozzle BHA 15:30 - 16:30 1.00 DRILL P PROD1 PJSM. M/U lateral drilling BHA #7 with 3.75 x 4.125 HC BC bit, x-treme 1.3 degree motor, HOT USR, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LQC, UOC, X-O, SLB CTC. Overall BHA length 78.96' Stabbed Injector 16:30 - 17:00 0.50 DRILL N SFAL PROD1 Work on packoffs on injector, replace some broken cotter keys on injector chain. 17:00 - 18:45 1.75 DRILL P PROD1 RIH w/ lateral drilling BHA #7 18:45 - 19:15 0.50 DRILL P PROD1 Tie in at 9635'. -9.5' BHI, -12' SLB correction. 19:15 - 20:00 0.75 DRILL P PROD1 RIH to 10200'. 2.6/1.9 bpm, 2800-3000 psi, 25 fpm. Tagged up on shale at 10000', P/U and ream shale section. 2.4/1.7 bpm, 2900 psi. 20:00 - 21:30 1.50 DRILL P PROD1 Drill Zone 4 lateral to 10350', 2.6/1.7 bpm, 3200-3400 psi, TF 90R, 1-1.5k DHWOB, 60-100fph, 9.6ppg ECD, PVT 260 bbls, IA 11psi, OA 15psi KICK WHILE DRILLING DRILL 20:00 HRS 21:30 - 22:15 0.75 DRILL P PROD1 Wiper trip to window, 35% losses. Slight overpulls around 10,000', but rest of hole clean. 22:15 - 00:00 1.75 DRILL P PROD1 Drill Zone 4 lateral to 10460', 2.61/1.85 bpm, 3400-3800 psi, TF 120L, 2-3k DHWOB, 70fph, 9.7ppg ECD, PVT 220 bbls, IA 11 psi, OA 26psi 11/26/2007 00:00 - 00:30 0.50 DRILL P PROD1 Drill Zone 4 lateral to 10500', 2.6/1.9 bpm, 3300-3600 psi, TF 90R, 1.5k DHWOB, 90fph, 9.7ppg ECD, PVT 330 bbls, IA 10psi, OA 30psi 00:30 - 01:45 1,25 DRILL P PROD1 Wiper trip to 9200' (in 4-1/2" tubing tail). Hole clean. 01:45 - 03:30 1.75 DRILL P PROD1 Drill Zone 4 lateral to 10650', 2.5/1.8 bpm, 3300-3400 psi, TF 35R, 1-2k DHWOB, 100fph, 9.7ppg ECD, PVT 242 bbls, IA 13psi, OA 37psi. Did not see expected fault at 10400', start building inclinatiori. 03:30 - 04:00 0.50 DRILL P PROD1 Wiper to window. 04:00 - 04:10 0.17 DRILL P PROD1 Tie in from 9640' to 9665'. No correction. 04:10 - 04:45 0.58 DRILL P PROD1 R1H clean to bottom. Printed: 12/t9/2007 2:23:07 PM BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date. From - To Hours Task Code - NPT Phase Description of Operations 11/26/2007 04:45 - 06:00 1.25 DRILL P PROD1 Drill Z4 lateral to 10740', 2.75/2.10 bpm, 3500-3800 psi, TF 06:00 - 06:45 I 0.751 DRILL I P 06:45 - 08:15 I 1.501 DRILL I P 08:15 - 09:30 I 1.251 DRILL I P 09:30 - 10:00 0.50 DRILL P 10:00 - 11:00 1.00 DRILL P 11:00 - 14:00 3.00 DRILL N 14:00 - 14:15 0.25 DRILL N 14:15 - 18:00 3.75 DRILL N 18:00 - 19:15 1.25 DRILL N 19:15 - 19:30 0.25 DRILL N 19:30 - 20:15 0.75 DRILL N 20:15 - 22:00 1.75 DRILL N 22:00 - 22:15 0.25 DRILL P 22:15 - 23:00 0.75 DRILL P 23:00 - 00:00 1.00 DRILL P 11/27/2007 00:00 - 00:45 0.75 DRILL P 00:45 - 02:00 1.25 DRILL P 02:00 - 03:15 1.25 DRILL P 03:15 - 05:15 2.00 DRILL P 05:15 - 06:00 I 0.751 DRILL I P 90L, 1.5-2k DHWOB, 100fph, 9.8ppg ECD, PVT 225 bbls, IA 16psi, OA 46psi. Returns have increased to -25%. PROD1 Drill Z4 lateral to 10800', 2.6/2.0 bpm, 3400 psi, TF 90R, 1.5-2k DHWOB, 125fph, 9.8ppg ECD, PVT 321 bbls, IA 15psi, OA 49psi. PROD1 Wiper trip to 9200'. Pulled into shale section at 10480'. Could not go up or down, shut down pumps, work pipe. Let loose, pulled free. PROD1 RIH, set do on bit at 10440' and 10480'. RIH to 10540'. P/U thru shale section, saw many 5-10K overpulls, but no hang ups. RIH to bottom. PROD1 Drill Z4 lateral, 2.6 bpm, 2.0 bpm returns, 3400-3800 psi, 110 fph, Drilled to 10875'. PROD1 Wiper trip to window. Overpulls in shales at 10480'. SFAL PROD1 POH to surface to align gripper blocks, replace chains keeper pins and c/o pack-off. SFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for Laying out BHA and working on injecter. SFAL PROD1 L/O BHA. Replaced packoff, Align gripper blocks with packoff, replaced keeper pins on chain links. SFAL PROD1 Change out traction cylinders on injector. SFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U lateral drilling BHA SFAL PROD1 S/B injector. M/U lateral drilling BHA #8 with 3.75 x 4.125 HC BC bit, x-treme 1.3 degree motor, HOT USR, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LOC, UOC, X-O, SLB CTC. Overall BHA length 78.96' Stabbed Injector SFAL PROD1 RIH w/ lateral drilling assembly to window. Circ at 0.4 bpm w/ 35% losses. PROD1 Tie in at 9635'. -7.5' BHI correction PROD1 RIH, set wt do at 10000', 10456'-10480'. P/U to 10400' and ream shale section. RIH to bottom. PROD1 Drill Z4 lateral to 10960', 2.55/2.20 bpm, 3400 psi, TF 120R, 2-3k WOB, 125fph, 9.8ppg ECD, PVT 255 bbls, IA 10psi, OA 26psi. PROD1 Drill Z4 lateral to 11000', 2.55/2.15 bpm, 3400 psi, TF 120R, 1-2k WOB, 115fph, 9.8ppg ECD, PVT 249 bbls, IA 12psi, OA 28psi. PROD1 Wiper to window. 15K-20K overpulls at .10470', 10370', 10310', 10286'. RIH clean to bottom PROD1 Drill Z4 lateral to 11150', 2.7/2.3 bpm, 3600-3700 psi, TF 120L, 2-3k WOB, 120fph, 9.8ppg ECD, PVT 200 bbls, IA 20psi, OA 48psi. PROD1 Wiper trip to 9200'. 10K-25K overpulls from 10550'-10430', 18K overpull at 10290'. RIH, tag window 2x, P/U and run thru. Tag at 10250', P/U and run thru, set do wt at 10300'. RIH to bottom. PROD1 Drill Z4 lateral to 11250', 2.70/2.25 bpm, 3400-3600 psi, TF 130L, 2-3k WOB, 130fph, 9.8ppg ECD, PVT 280 bbls, IA 27psi, Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Operations Summary Report Page9of14~ Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2007 05:15 - 06:00 0.75 DRILL P PROD1 OA 82psi. 06:00 - 06:45 0.75 DRILL P PROD1 Drill Z4 Lateral, 2.6 / 2.2 bpm, 15% loss, 3200-3600 psi, 170E TF, 60 deg incl, 9.8 ecd, 100 fph, 2.5K wob, Drilled to 11307'. 06:45 - 08:00 1.25 DRILL P PROD1 Wiper trip to window. 42K up wt, 20-30K overpull in shale at 10,430'. Ream shale. Back ream at 10 fpm and pulled thru shales OK. Wiper up to window clean. 08:00 - 08:50 0.83 DRILL P PROD1 RIH. Set down and fell thru shales at 10,250' and 10,430'. Clean trip to bottom. 08:50 - 09:30 0.67 DRILL P PROD1 Drill Z4 sand, 2.7/2.3 bpm, 3200-3800 psi, 170E TF, 120 fph, 50 deg incl. Drilled to 11370'. 09:30 - 11:30 2.00 DRILL P PROD1 Wiper trip up to tailpipe. 10-20K Overpull at 10470, 10430 and 10250'. Rest of hole was clean. 11:30 - 12:00 0.50 DRILL P PROD1 Log down GR tie-in at RA tag. added 8' to CTD. 12:00 - 12:45 0.75 DRILL P PROD1 RIH to TD. Sat down in shales at 10,430 and 10,470'. RIH clean to TD. Tagged final TD at 11,375'. 12:45 - 14:00 1.25 DRILL P PROD1 Wiper trip up to 10100'. Shales were clean on way out of hole. Log MAD pass from 10100-9950'. Circ at 2.55 bpm in with 2.11 bpm returns. 17% fluid loss. Wiper up to window clean. 14:00 - 15:45 1.75 DRILL P PROD1 POH. 15:45 - 16:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out BHA. 16:00 - 16:45 0.75 DRILL P PROD1 Lay out BHI drilling BHA #8. Recovered 100%. Bit #5 graded at 16:45 - 17:00 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping Pickle procedure. 17:00 - 18:15 1.25 CASE P RUNPRD Pump Pickle procedure, 15 bbl Surf Save, 45 bbl rig water, 15 bbl A266 Inhibitor and 10 bbl MEOH. Rig up N2 unit. 18:15 - 18:30 0.25 CASE P RUNPRD PJSM for N2 blowdown. 18:30 - 19:00 0.50 CASE P RUNPRD Pump 1500 mcf of N2. 19:00 - 20:00 1.00 CASE P RUNPRD Slowdown with N2. 20:00 - 20:45 0.75 CASE P RUNPRD PJSM unstab from well and prep coil for pull back. 20:45 - 22:15 1.50 CASE P RUNPRD Pull back coil and secure reel. 22:15 - 23:00 0.75 CASE P RUNPRD Well on vac. Fill well with 33 bbls. Static loss rate 6 bph. 23:00 - 00:00 1.00 CASE P RUNPRD Continnue to lower reel and load out. 11/28/2007 00:00 - 02:20 2.33 CASE P RUNPRD Install grapple and pull CT to rig floor. 02:20 - 03:40 1.33 CASE P RUNPRD Install coil connector, Pull test CTC. 03:40 - 05:00 1.33 CASE P RUNPRD Circulate ct with 10 bbl MEOH and Flo Pro. PT to 4000 psi OK. Pump volume dart. Dart landed at 59.5 bbls 05:00 - 06:00 1.00 CASE P RUNPRD Clear floor. Standback injector. 06:00 - 06:30 0.50 CASE P RUNPRD Crew change. SAFETY MEETING. Review procedure, hazards and mitigation for running liner. 06:30 - 10:30 4.00 CASE P RUNPRD M/U Indexing guide shoe, Flt Cllr, 1 jt 2-7/8" STL, Flt Cllr, Landing Cllr, XO and 60 jts of 3-3/16" TCII liner. Filled liner at 30 jts in. 10:30 - 12:00 1.50 CASE P RUNPRD M/U XO, M/U 9 jts of 3-1/2" STL Liner, Howco "X" Nipple, two 10' pups, one 4' pup and BTT Deployment sleeve with CTLRT. Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To I Hours I Task I Code ~ NPT (Phase I Description of Operations 11/28/2007 110:30 - 12:00 I 1.501 CASE I P RUNPRD OAL of liner = 2,137.60'. 12:00 - 14:00 2.00 CASE P 14:00 - 14:50 0.83 CASE P 14:50 - 15:30 0.67 CEMT P 15:30 - 19:00 3.50 CEMT P 19:00 - 19:20 19:20 - 20:28 20:28 - 21:45 OAL of Liner with CTLRT BHA = 2,146.81'. RUNPRD RIH with Liner on CT. Circ at 0.4 bpm. Up wt above window = 40K. Went thru window clean. RUNPRD Run in open hole at 60 fph, circ at 0.3 bpm. 23K dwn wt at 10200'. Sat down at 10320, 10400, 10450, 10870 and 11080'. 15K down wt at 11,300'. Landed liner on bottom at 11,382' CTD. Sat down wt 3 times at same depth. Corrected TD is 11,375'. PBTD is 11,338'. RUNPRD Insert 5/8" steel ball and displace with FloPro. Ball on seat at 49.5 bbl. Sheared at 4000 psi, Pick up free from liner at 34K. Stack 10K back down on liner. RUNPRD Swap well to 2% KCL water, double slick for lower cementing circ pressure. Circ at 2.5 bpm, 2.0 bpm returns, 20% loss with FloPro on formation. After circ. 200 bbl, KCL water, the fluid loss rate fell to 12%. Circ at 2.60 bpm with 2.30 bpm returns. 0.33 CEMT P RUNPRD PJSM for cementing liner. Discussed communicationissues. Clean ou procedure, DS to stay RU until) completion of displacement. 1.13 CEMT P RUNPRD RU to dirty vac and to Rig water supply. Batch mix cement. Flood lines and PT to 3500 psi. 1.28 CEMT P RUNPRD PT 270 bbls. Pump cement. Zero in MM on density. Pump 31 bbl cement 2/1.6 bpm @1500-2000 psi. @ 27bb1 cement over Goose Neck. Close back side. Launch dart Displace with 30 bbl Bio &KCL. Displacement In rate Out rate PSI 31 cement 40 1.96 1.39 1282 50 1,95 1.78 920 60 1.95 1.77 750 70 1.93 1.31 500 75.8 1.90 1.19 Cement at shoe zero out MM 78.2 1.53 .80 240 Cement at shalve 10400 assume gage hole 85.5 1.63 1.28 1100 Cement at fault 9910 assuime gage hole 90.5 1.6 1.18 91.5 Shear LWP with 4000 psi. 91.5+16.3 = 107.8 to bump plug. 100 1.05 .68 1146 107 1.05 .56 1230 107.6 Bump PLug with 1200 psi Floats held. Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Page 11 of 141 Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2007 20:28 - 21:45 1.28 CEMT P RUNPRD 10.7 bbl lost to fault of which 2/3 was cement. Pressure to 500 psi unsting pump 3 bbl 1.2 bpm @ 500 psi 21:45 - 23:15 1.50 CEMT P RUNPRD POH to surface 23:15 - 00:00 0.75 CEMT P RUNPRD LD liner running tools. 11/29/2007 00:00 - 00:15 0.25 CEMT P RUNPRD LD liner running tools. evidence of cement obove liner top. Clear floor. 00:15 - 00:30 0.25 EVAL P LOWER1 PJSM for logging BHA 00:30 - 02:45 2.25 EVAL P LOWER1 MU BHA and 34 stands of 1-1/4 CSH tubing. 02:45 - 04:30 1.75 EVAL P LOWER1 RIH to 9000'. Up Wt 33K. 04:30 - 06:30 2.00 EVAL P LOWER1 Log down at 30 fpm. tag TD at 11345'. Log up at 60 fpm to 9000'. 06:30 - 07:45 1.25 EVAL N WAIT LOWER1 Wait for pert pill to arrive. Vac truck not available when needed. RIH to PBTD while circ pert pill to bottom. 07:45 - 08:30 0.75 EVAL P LOWER1 Lay in 30 bbl FloPro high vis pert pill inside 3-3/16" Liner, 08:30 - 10:00 1.50 EVAL P LOWERI POH with MCNUGR /mill and motor BHA. 10:00 - 10:10 0.17 EVAL P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. 10:10 - 11:00 0.83 EVAL P LOWER1 Stand back 17 stds of 1-1/4" CSH. 11:00 - 11:15 0.25 EVAL P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for Laying out MCNL BHA 11:15 - 13:30 2.25 EVAL P LOWER1 Lay out BHA. Download Memory CNL/GR/CCL. Fax log to Anc. Geo. No gas seen with memory CNL. M/U Swizzle stick and jet stack. SAS cement UCA was at 2000 psi at 12.00 hrs. 13:30 - 14:30 1.00 CEMT P RUNPRD Perform infectivity test on liner lap. Pump 1.0 bpm at 730 psi SIWHP. Pump 2.0 bpm at 1,150 psi SIWHP. 14:30 - 16:00 1.50 CEMT P RUNPRD Weld on 2.50" SWS CTC. Pull test with 35K. Press test with 4000 psi. Good weld. 16:00 - 17:00 1.00 CEMT P RUNPRD PJSM for M/U BHA. M/U Cementing BHA #11 with 2.25" cementing nozzle, 2 jts 1-1/4" CSH, XO, BTT circ sub, BTT Hyd Disc and CTC. OAL = 66.51'. 17:00 - 22:00 5.00 CEMT P RUNPRD RIH with Cementing BHA #11. UP Wt at liner top 35K.RIH to TD .Circulate in 10 bbl Hi vis pill. 1.4 bpm @ 1150 psi.PU to 10500 and lay in pill. PU to 9210 22:00 - 22:30 0.50 CEMT P RUNPRD Shut in well bullhead. Injection rate and pressure 1 bpm @ 1170 psi WH 7901.1.6bpm 1600psi 916psi WH .2bpm 1820 psi 1000 wh 22:30 - 23:00 0.50 CEMT P RUNPRD Circulate at min rate .65 / .43 bpm @ 170 psi. Cementer on location spot cementing equipment. 23:00 - 00:00 1.00 CEMT P RUNPRD Wait on Vac truck with contaminent pill. 11/30/2007 00:00 - 00:30 0.50 CEMT P RUNPRD Circulate 00:30 - 00:50 0.33 CEMT P RUNPRD PJSM for cement job. Discussed corcdinated operations between Little Red and SLB cementers. 00:50 - 01:30 0.67 CEMT P RUNPRD Little Red flood line to 2"drain line and PT to 4000 psi. Shut-in well. Bullhead 52 diesel down CT X tubing annulus. Periodically bullhead CT to pervent freezing. Bullhead diesel 10 bbl 1.8 bpm 1800 psi 1200 psi CT, IA 21 psi , OA 34 psi 20 1.8 1900 1238 22 35 Printed: 12/19/2007 2:23:07 PM • • BP EXPLORATION Page 12 of 14 ~ Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours .Task Code N'PT Phase Description of Operations 11/30/2007 00:50 - 01:30 0.67 CEMT P RUNPRD 30 1.8 1950 1183 21 33 40 1.8 2250 1542 21 37 52 1.8 1180 20 38 01:30 - 02:15 0.75 CEMT P RUNPRD Batch up cementers. Relocate Little Red's tie-in to cementers. PT SLB to 4100 psi and PT Little Red to 4000 psi. 02:20 - 03:40 1.33 CEMT P RUNPRD Pump 20.7 bbl Cement Vol Rate Pressure Well head IA OA 10 1.95 1652 20 45 16 1.9 2142 1333 20 45 20.7 Shut down 150 380 29 311 18 223 Displace with diesel 26 1.93 2655 1256 17 45 30 1.93 2500 1501 17 45 35 1.93 2050 1550 17 45 40 1.98 1710 1622 17 44 45 1.98 1326 1644 17 44 50 1.98 1490 1677 17 45 55 1.98 1590 1685 17 45 60 1.98 1870 1692 16 44 Cement to liner top 65 1.93 2494 1765 66 1.0 1476 1549 67 1.0 1198 1340 15 68 1.0 1135 1296 69 1.0 1250 1350 15 45 70 1.0 1380 1392 71 1.0 1516 1395 cement to fault 72 1.0 1600 1366 73 1.0 1663 1344 76 1.0 1890 1337 77 1.0 1996 1351 78 1.0 2058 1360 79 Shut down Lay last bbl in 1:1hold 240 psi PU to 8500 to safety 03:40 - 06:00 2.33 CEMT P RUNPRD Wait on cement holding 240 psi. The press slowly bleed off. repressure with 0.2 bbl. SIWHP = 40 psi at 0600. 06:00 - 07:30 1.50 CEMT P RUNPRD WOC. Pumped 0.5 bbl at 0700hrs. SIWHP increased from 40 to 330 psi. 0720 hrs. pumped 0.2 more bbls and SIWHP increased from 330-490 psi. Cement is holding press. Cement in place for 4 hrs at 0730 hrs. 07:30 - 08:30 1.00 CEMT P RUNPRD RIH into 3-1/2" x 3-3/16" liner to 10400' to ensure no hard cement inside lines Printed: 12/19/2007 2:23:07 PM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: H-24 Common Well Name:. H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/30/2007 07:30 - 08:30 1.00 CEMT P RUNPRD Sat down wt at top of liner and jetted thru easily, RIH to 10400', circ at 0.5 bpm POH to 9000' and WOC while circ at min. rate to keep 60 bbl of diesel on backside of coil. 08:30 - 10:00 1.50 CEMT P RUNPRD Wait on Cement. circ at 0.3 bpm, diesel in returns. 10:00 - 10:40 0.67 CEMT P RUNPRD Cement UCA at 600 psi, start cleanout, RIH to PBTD while circ at 2.6 bpm, 3.0 bpm returns. sent retums to tiger tank. full returns. RIH at 50 fpm. Tag PBTD at 11,348' CTD. 10:40 - 13:15 2.58 CEMT P RUNPRD POH while circ at 3.1 bpm. L/O Nozzle BHA. M!U Swizzle stick 13:15 - 13:45 0.50 CEMT P RUNPRD Jet stack with swizzle stick at 3 bpm. 13:45 - 14:30 0.75 EVAL P RUNPRD M/U SWS Memory CBUGR/CCL logging BHA #12. BHA OAL = 70.0'. 14:30 - 16:45 2.25 EVAL P RUNPRD RIH w/ MCBL BHA. circ at 1.7 bpm, full returns. SWS Cement UCA was at 2500 psi at 10 hrs. 16:45 - 18:30 1.75 EVAL P RUNPRD Log down from 9100' at 30 fpm with memory cement bond log. No wt loss going into top of 3-1/2" liner. RIH clean. Circ new FloPro pert pill to bottom. 18:30 - 17:50 23.33 EVAL P RUNPRD Log up at 30 fpm while laying in 30 bbl new FloPro pert pill. 17:50 - 21:30 3.67 EVAL P RUNPRD POH 21:30 - 22:00 0.50 EVAL P RUNPRD LD bond log BHA. 22:00 - 22:30 0.50 EVAL P RUNPRD Swizzel BOP stack. 22:30 - 23:00 0.50 PERFO P LOWER1 Finish loading pipe shed & Prep floor for perorating well. 23:00 - 23:30 0.50 PERFO P LOWER1 PJSM for perforating. Need to PU 62 guns and 15 stands of 1-1/4 CSH tubing. 23:30 - 00:00 0.50 PERFO P LOWER1 Completing floor prep and wait on cement bond log results 12/1/2007 00:00 - 01:30 1.50 PERFO P LOWER1 Continue to wait on processing log data. 01:30 - 02:00 0.50 PERFO N HMAN LOWER1 Start PU gun OOPS and LD same for liner lap test. 02:00 - 02:45 0.75 PERFO P LOWER1 Test liner lap to 2000 psi .Jug tight Passed test. 02:45 - 05:30 2.75 PERFO P LOWER1 PU 62 guns. SWS, 2", PJ, 6 SPF. Loaded as per perforating ~ program. 970' of loaded guns. 4 intervals. 05:30 - 06:00 0.50 PERFO P LOWER1 PU 15 stands of CSH. 06:00 - 08:50 2.83 PERFO P LOWER1 RIH with perforating BHA #13. OAL = 2250.5'. Circ at min. rate. Up wt at 9200' = 39K. Entered top of liner with nowt loss. RIH to PBTD. Tagged bottom at 11345' up depth. Corrected to PBTD of 11,341'. corrected depth from memory CNL/GR log. [-4']. 08:50 - 09:45 0.92 PERFO P LOWER1 Pump 7 bbl FloPro perf pill. Insert 1/2" AL ball and displace with 8 bbl FloPro. Displace with KCL water. Position bottom shot at 11,303'. Ball on seat at 60 bbls. Fire guns on the fly on depth with bottom shot at 11,300'. Firing head sheared at 2800 psi. Good shot detection. 09:45 - 12:15 2.50 PERFO P LOWER1 POH with fired perf guns. Flow check at top of liner. No flow. POH. Flow check at surface, no flow. 12:15 - 12:30 0.25 PERFO P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. 12:30 - 13:15 0.75 PERFO P LOWER1 Stand back 15 stds of CSH workstring. 13:15 - 13:30 0.25 PERFO P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired pert guns. Printed: 12/t9/2007 2:23:07 PM ! • BP EXPLORATION Page 14 of 14 ~ Operations Summary Report Legal Well Name: H-24 Common Well Name: H-24 Spud Date: 12/27/1985 Event Name: REENTER+COMPLETE Start: 11/17/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 12/2/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2007 13:30 - 17:30 4.00 PERFO P LOWER1 Lay out fired 2" pert guns and blanks, 62 guns total. Al~h~ots PERFORATED INTERVALS: 10,000-10,230' 10,500-10,590' 10,620-10,990' 11,020-11,300', TOTAL PERFS = 970' Clear rig floor and pipe shed of perforating equipment. 17:30 - 17:45 0.25 WHSUR P POST RIH with nozzle and freeze protect 4-1/2" tubing to 2100' with MEOH. 17:45 - 19:00 1.25 WHSUR P POST SWS hyd controls locked up, no level wind, no injecter drive. Stop coil at 1664'. 18 bbls of MEOH pumped into coil. 2 Fuses in OPS cab failed. Found loose connector on joy stick. Completed Freeze protection. 19:00 - 20:45 1.75 WHSUR P POST Blow down reel with N2. 20:45 - 21:15 0.50 WHSUR P POST Set back injector. Install well cap and check well for presure. Well on slight vac then dead. PJSM with BPV crew. Set BPV with dry rod. 21:15 - 21:30 0.25 WHSUR P POST PJSM for simultaneous ND of BOP and pit cleaning. 21:30 - 00:00 2.50 WHSUR P POST ND BOP. Clean pits. NU tree cap and test. Release Rig Printed: 12/19/2007 2:23:07 PM ~ i by BP Alaska ~~$ Baker Hughes INTEQ Survey Report INTE Q Company: BP Amoco Date: 11/28/2007 Time: 09:03:01 Page: 1 Field: Prudhoe Bay Co-erdioate(NE) Reference: Well: H-24, True North Site: PB H Pad Vertical (TVD) Reference: 33:24 12/27/1985 00:00 71.8 Well: H-24 Secdoe (VS) Reference: WeU (O.OON,O.OOE,283.62Azi) Wcllpat6: H-24A Survey Cakalation Method: Minimum Curvature Db: OraGe Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zoue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB H Pad TR-11-13 UNITED STATES :North Slope Site Positioe: Nortbiog: 5957572.25 ft Latitude: 70 17 30.055 N From: Map Easting: 641366.07 ft Longitude: 148 51 19.802 W Positau Uncertainty: 0.00 ft Nortb Retenece: True Ground Level: 0.00 ft Grid Couvergeece: 1.08 deg Well: H-24 Sbt Name: 24 H-24 Well Position: +N/-S 2424.74 ft Nortbiug: 5960024.99 ft Latitude: 70 17 53.901 N +E/-W 1521.91 ft Easting : 642842.00 ft Longitude: 148 50 35.438 W Position Uncertainty: 0.00 ft Wellpatb: H-24A Drilled From: H-24 500292151201 Tie-ou Deptb: 9602.45 ft Current Datum: 33:24 12/27/1985 00:00 Height 71.80 ft Above System Datum: Mean Sea Level Magnetic Data: 8/14/2007 Declination: 23.57 deg Field Strength: 57647 nT Mag Dip Angle: 80.89 deg Vertical Sectioe: Depth From (TVD) +N/-S +E/-W DireMioo ft ft ft deg 28.80 0.00 0.00 283.62 Survey Program for Definitive Wellpatb Date: 8/14/2007 Validated: Yes Version: 1 Actual From To Survey Tookode Tool Name ft ft 106.15 9602.45 1 : Schlumberger GCT mulfishot GCT-MS Schlumberger GCT mulGshot 9625.00 11375.00 MWD (9625.00-11375.00) MWD MWD -Standard Annotation MD TVD ft R 9602.45 8720.46 TIP 9625.00 8739.86 KOP 11375.00 8926.66 TD Survey: MWD Start Date: 11/26/2007 Company: Baker Hughes INTEQ Eugieeer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Ioei Aaim TVD SysTVB N/S E/W MapN MapE VS DLS Tool $ deg ?:deg ft ft ft ft ft ft ft deg/100ft 9602.45 30.72 288.61 8720.46 8648.66 242.54 -3032.61 5960209.84 639805.56 3004.48 0.00 MWD 9625.00 30.51 288.71 8739.86 8668.06 246.22 -3043.49 5960213.30 639794.61 3015.92 0.96 MWD 9655.01 34.48 301.67 8765.20 8693.40 253.13 -3057.96 5960219.94 639780.02 3031.61 26.64 MWD 9686.45 41.34 312.02 8790.02 8718.22 264.78 -3073.28 5960231.30 639764.48 3049.25 29.69 MWD 9716.76 47.14 319.73 8811.74 8739.94 279.98 -3087.92 5960246.21 639749.55 3067.05 26.07 MWD 9747.35 55.52 326.00 8830.85 8759.05 299.04 -3102.25 5960264.99 639734.86 3085.47 31.70 MWD 9778.06 62.74 335.14 8846.62 8774.82 321.98 -3115.11 5960287.68 639721.58 3103.36 34.69 MWD 9808.80 73.66 343.11 8858.03 8786.23 348.61 -3125.18 5960314.11 639711.00 3118.42 42.88 MWD 9840.02 83.17 348.25 8864.30 8792.50 378.20 -3132.71 5960343.56 639702.91 3133.71 34.46 MWD 9879.24 94.24 355.26 8865.18 8793.38 416.92 -3138.32 5960382.16 839696.57 3148.27 33.39 MWO 9912.66 100.25 4.61 8860.96 8789.16 450.02 -3138.37 5960415.25 639695.88 3156.12 33.08 MWD • r by BP Alaska $ Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 11/28!2007 Tim e: 09:03:01 Page: 2 Field: Prudhoe Bay Co-ordinxte(NE) Reference: Well: H-24, True North Site: PB H Pad Yertieni (TW) Refercnce: 33:24 12/27/1985 00:00 71.8 Well: H-24 Sectiea(VS) Reference: Well (O.OON,O.OOE,283.62Az) Wellpath: H-24A Sr,rvcy Calculutiioe Method: Minimum Curvature Db: OraGe Survey MD lac! Azim TVD Sys TYD N/S E/W ft deg deg ft ft ft ft 9943.02 101.36 14.74 8855.26 8783.46 479.38 -3133.37 9973.22 102.76 25.13 8848.93 8777.13 507.10 -3123.33 10005.08 101.75 36.53 8842.15 8770.35 533.79 -3107.39 10035.60 100.47 47.09 8836.25 8764.45 556.07 -3087.45 10065.84 101.42 57.53 8830.49 8758.69 574.20 -3064.00 10095.76 101.80 68.97 8824.45 8752.65 587.37 -3037.87 10125.24 102.99 79.08 8818.11 8746.31 595.29 -3010.23 10155.70 101.79 89.76 8811.56 8739.76 598.17 -2980.67 10186.26 92.55 96.62 8807.74 8735.94 596.47 -2950.45 10227.70 88.30 103.28 8807.43 8735.63 589.31 -2909.87 10255.04 90.46 103.55 8807.73 8735.93 582.97 -2883.08 10282.06 91.35 99.95 8807.30 8735.50 577.47 -2856.63 10312.12 91.07 95.36 8806.67 8734.87 573.47 -2826.85 10339.70 91.47 91.90 8806.06 8734.26 571.72 -2799.34 10366.16 90.95 87.51 8805.50 8733.70 571.86 -2772.89 10398.72 90.25 84.42 8805.16 8733.36 574.15 -2740.42 10431.46 89.51 82.81 8805.22 8733.42 577.79 -2707.88 10464.86 89.32 86.23 8805.56 8733.76 580.98 -2674.64 10494.61 90.06 91.77 8805.73 8733.93 581.50 -2644.91 10521.09 91.90 95.50 8805.27 8733.47 579.82 -2618.49 10549.74 95.02 98.45 8803.54 8731.74 576.35 -2590.11 10582.25 98.87 101.06 8799.61 8727.81 570.88 -2558.32 10612.17 99.46 97.06 8794.85 8723.05 566.23 -2529.15 10641.17 99.94 93.28 8789.96 8718.16 563.66 -2500.69 10674.05 100.74 88.68 8784.05 8712.25 563.10 -2468.36 10700.79 99.83 85.23 8779.28 8707.48 564.50 -2442.09 10730.66 97.59 82.60 8774.75 8702.95 567.63 -2412.73 10772.06 93.88 88.82 8770.61 8698.81 570.70 -2371.68 10805.14 93.07 92.75 8768.61 8696.81 570.25 -2338.68 10838.78 92.52 99.64 8766.96 8695.16 566.63 -2305.29 10864.74 92.00 104.34 8765.94 8694.14 561.24 -2279.93 10893.76 91.41 107.46 8765.08 8693.28 553.29 -2252.03 10925.76 89.35 t 10.74 8764.86 8693.06 542.83 -2221.80 10953.46 86.75 115.52 8765.81 8694.01 531.96 -2196.35 10982.80 83.53 119.85 8768.29 8696.49 518.38 -2170.47 11012.42 80.24 117.44 8772.48 8700.68 504.32 -2144.74 11043.52 78.31 113.83 8778.26 8706.46 491.10 -2117.20 11072.74 76.89 110.14 8784.54 8712.74 480.42 -2090.75 11101.74 75.34 106.64 8791.50 8719.70 471.54 -2064.04 11131.04 72.61 103.28 8799.59 8727.79 464.26 -2036.84 11161.30 69.51 101.08 8809.41 8737.61 458.22 -2008.87 11192.20 65.20 89.04 8821.31 8749.51 453.23 -1980.80 11222.50 62.16 96.15 8834.74 8762.94 449.64 -1953.89 11253.04 58.43 93.35 8849.88 8778.08 447.43 -1927.46 11283.58 53.90 91.75 8866.88 8795.08 446.29 -1902.13 11322.48 47.85 91.96 8891.41 8819.61 445.32 -1871.98 11375.00 47.85 91.96 8926.66 8854.86 443.99 -1833.06 MapN 141apE ft ft 5960444.70 639700.32 5960472.60 639709.84 5960499.58 639725.26 5960522.24 639744.77 5960540.81 639767.88 5960554.47 639793.75 5960562.91 639821.23 5960566.36 639850.73 5960565.23 639880.98 5960558.85 639921.88 5960553.02 639948.59 5960548.02 639975.13 5960544.58 640004.98 5960543.36 640032.52 5960544.00 640058.96 5960546.91 640091.38 5960551.17 640123.84 5960554.99 640157.01 5960556.07 640186.72 5960554.89 640213.16 5960551.96 640241.60 5960547.11 640273.50 5960543.01 640302.74 5960540.98 640331.24 5960541.04 640363.58 5960542.93 640389.81 5960546.62 640419.10 5960550.47 640460.08 5960550.65 640493.09 5960547.68 640526.53 5960542.76 640552.00 5960535.34 640580.04 5960525.45 640610.46 5960515.07 640636.11 5960501.99 640662.24 5960488.42 640688.23 5960475.73 640716.01 5960465.55 640742.66 5960457.18 640769.54 5960450.43 640796.88 5960444.92 640824.94 5960440.46 640853.10 5960437.38 640880.07 5960435.67 640906.54 5960435.02 640931.88 5960434.62 640962.04 5960434.02 641000.97 VS D[S Tool ft degl100ft 3158.17 32.98 MWD 3154.93 33.96 MWD 3145.72 35.11 MWD 3131.59 34.21 MWD 3113.06 34.04 MWD 3090.77 37.47 MWD 3065.77 33.73 MWD 3037.72 34.47 MWD 3007.95 37.54 MWD 2966.63 19.06 MWD 2939.29 7.96 MWD 2912.29 13.72 MWD 2882.41 15.29 MWD 2855.26 12.63 MWD 2829.58 16.70 MWD 2798.56 9.73 MWD 2767.80 5.41 MWD 2736.24 10.25 MWD 2707.47 18.79 MWD 2681.40 15.70 MWD 2653.00 14.97 MWD 2620.81 14.27 MWD 2591.37 13.34 MWD 2563.10 12.95 MWD 2531.55 13.98 MWD 2506.35 13.14 MWD 2478.55 11.49 MWD 2439.38 17.43 MWD 2407.19 12.11 MWD 2373.89 20.52 MWD 2347.97 18.20 MWD 2318.99 10.94 MWD 2287.15 12.10 MWD 2259.85 19.63 MWD 2231.50 18.35 MWD 2203.19 13.72 MWD 2173.31 12.98 MWD 2145.08 13.26 MWD 2117.03 12.88 MWD 2088.89 14.43 MWD 2060.28 12.34 MWD 2031.83 15.22 MWD 2004.82 13.18 MWD 1978.62 14.58 MWD 1953.73 15.46 MWD 1924.20 15.56 MWD 1886.07 0.00 MWD T~tEE = 4" CM/ WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 71.8' BF. ELEV = 44.4' KOP = 3660' Max Angle = 103 @ 10125' Datum MD = 11292' Datum TV D = 8800' SS DRLG DRAFT H -24A I • I 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.80" @ 9548' XO to 3-3/16" TCII liner TOP OF 7" LNR ~-I 9231' ~ TOP OF 3 1/2" x 2 718" LNR 8237' TOC lap sqz ~ g237' 3.5" X Nip 2.813" ID 9265' NOTES: 202--~4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3085 3084 0 OTIS DOME RM 16 12/16/07 6 5050 4923 30 OTIS SO RM 20 12/16/07 5 6472 6088 38 OTIS DMY RM 0 06/23/07 4 7625 7044 30 OTIS DMY RA 0 01/14/86 3 8272 7608 31 OTIS DMY RA 0 01/14/86 2 8877 8110 35 OTIS DMY RM 0 06/23/07 1 9029 8236 34 OTIS DMY RM 0 08/08/06 9099' --~4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9159' TM/ SBR SEAL ASSY 9174' 9-5/8" X 4-1 /2" TM/ HBBP PKR, ID = 4.75" 9217' 4-1 /2" OTIS X NIP, ID = 3.813" I 9249' I I I 92$2' 4-1/2" TM! TBG TAIL, ID = 3 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9282' 9281' ELMD TT LOGGED 02/06/86 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9525' 3.5" X 3.188" xover 9547' PERFORATION SUM MARY REF LOG: SWS-MCNUGR/CCL OF 11/29/07 A NGLE AT TOP PERF: 102° Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2.00 6 10,000'-10,230' O 12/01/07 2.00 6 10,500'-10,590' O 12/01/07 2.00 6 10.620'-10,990' 0 12101/07 2.00 6 11,020'-11,300' O 12'01/07 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9625' ~~ Mechanical Whipstock top 11341' PBTD 3 1/2" x 3 3116" crM'ed and perfed 11375' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/16186 ORIGINAL COMPLETION 12/17/07 TFA/SV GLV GO & CORRECTIONS 07/15/03 CMO/TLP KB ELEVATION CORRECTION 06!04/06 KSB/PAG GLV C/O (06101/06) 08/08/06 RCT/PJC GLV GO 12/01/07 NORDICI CTD SIDETRACK (H-24A) 12/03/07 /TLH CORRECTIONS PRUDHOE BAY UNIT WELL: H-24A PERMfT No: 2071330 API No: 50-029-21512-01 SEC 21, T11 N, R13E, 754' FNL 8~ 1735' FEL BP Exploration (Alaska) • INTEQ BAKER HYGNES 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 To Whom It May Concern: January 18, 2008 Please find enclosed directional survey data for the following wells: 18-13BPB1 18-13BPB2 18-13BPB3 18-13B K-14A H-24A 15-04BPB 1 15-04B Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY:~~_ ,State of Alaska AOGCC DATE: ~ ~ J ~.,. ~~'z Cc: State of Alaska, AOGCC ~ (~.7.~ 133 d 0 ~ ~ SARAH PALIN, GOVERNOR 4i~Af7~ O~ ~ ~S 333 W. 7th AVENUE, SUITE 100 COIQSER`rA'1`I011T COMMISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-24A BP Exploration Alaska, Inc. Permit No: 207-133 Surface Location: 755' FNL, 1735' FEL, SEC. 21, T11N, R13E, UM Bottomhole Location: 267' FNL, 3734' FEL, SEC. 21, Tl 1N, R13E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9059-3607 (pager). N DATED this day of October, 2007 cc: Department of Fish 8b Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA 9~ ~_::.~V~ ALASI~IL AND GAS CONSERVATION COMMI~N ~ o~ PERMIT TO DRILL /,~~. ~~~_~~~` ~ 9 %~~~ 20 AAC 25.005 (/" ~~ \~ ~_ ~_ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas D Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify'if `W`elt i~ j5r p` or: ' ^ Coalbed Methane ~'f'i~6rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU H-24A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11170 TVD 8790ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 755' FNL 1735' FEL 21 T11N R13E UM SEC 7. Property Designation: ADL 028284 Pool , , , , , . Top of Productive Horizon: 516' FNL, 4755' FEL, SEC. 21, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2007 Total Depth: 267' FNL, 3734' FEL, SEC. 21, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,850' 4b. Location of Well (State Base Plane Coordinates): Surface: x-642842 y-5960025 Zone-ASP4 10. KB Elevation (Height above GL): 71.8' feet 15. Distance to Nearest Well Within Pool: 1,230' 16. Deviated Wells: Kickoff Depth: 9625 feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3220 Surface: 2340 18. Casih Pr ram: S 'ficatio ns To - Settin De th -Bo ttom uanti of Cement c.f. or sa s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" s-,+z° x za/e° 9.3# / 6.16# 13Cr STL 1940' 9230' 8332' 11170' 8790' 152 cu ft Class 'G' 19. .PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10200 Total Depth TVD (ft): 9241 Plugs (measured): None Effective Depth MD (ft): 10158 Effective Depth TVD (ft): 9204 Junk (measured): 9945 :Casing; Length ize ement Volume MD D Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2674' 13-3/8" 3271 cu ft Coldset III 465 cu ft CS II 2674' 2673' Intermediate 9525' 9-518" 1984 cu ft Class'G' 230 cu ft Class'G' 9525' 8654' Produ ion Liner 967' 7" 305 cu ft Class 'G' 9231' - 10198' 8405' - 9239' Perforation Depth MD (ft): 9590' - 9900' Perforation Depth TVD (ft): 8710' - 8979' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature ~-^ / v ~-~'l Phone 564-4387 Date 9 2S o Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: 0,7 O API Number: 50-029-21512-01-00 Permit Approval See cover letter for Date: ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ^ No ud Log Req'd: ^ Yes ^ No ;~ HZS Measures: ^ Yes Di ction Survey Req'd: ^ Yes ^ No Other: ~50~ PSG -J~~ ~'S~h Date ~D-' ~6'" 0~-- PROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate ORIGINAL BP Prudhoe Bay H-24A CTD Sidetrack CTD Sidetrack Summary P re-Rig Work: (scheduled to begin October 15, 2007) 1. S Caliper tubing from 9792' done 4/10/07 2. S Dummy WS drift to 9811' done 6/1/07 3. O MIT-OA (passed) done 6/2/07 4. S Dummy GLV's done 6/23/07 5. O MIT-IA (passed) done 6/23/07 6. C Mill XN nipple at 9249' with LH motor 7. C Underream 7" 29# liner from 9575'-9675 8. S Caliper tubing from 9675' ' 30~- ~~~ 9. E Set Whipstock at 9625 10. C Down squeeze cement for P&A -17 bbls of 15.8 unislurry 11. O AC-LDS; AC-PPPOT-IC, T 12. O PT MV, SV, WV 13. O Bleed gas lift and production flowlines down to zero and blind flange 14. O Remove wellhouse, level pad Rig Work: (scheduled to begin on November I, 2007} L MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mi113.8" window at 9625' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 650' (35 deg/100 planned) with resistivity 4. Drill Lateral: 4.125" OH, 895' (15 deg/100 planned) with resistivity Th~S 5. Run 3-U2" x 2-7/8" solid chrome liner leaving TOL at 9230' ~ 6. Pump primary cement leaving TOC at 9230', 27 bbls of 15.8 ppg liner cmt planned ~~~~~~~ 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions 0300') 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Mud Program: • Well kill: 8.6 ppg brine ~ Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-1/2", 13-CR 9.3# STL 9230' and - 9600' and • 2-7/8", 13-CR 6.16# STL 9600'md - ll170'md • A minimum of 27 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9230' Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional pl~ Max. planned hole angle is 102 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 25850 ft. • Distance to nearest well within pool - 1230 ft. Anti-Collision • No close approches Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on H Pad is 180 ppm. • Lost circulation risk is high potential for losses. A major fault crossing at 10400' is likely to produce a loss circulation event. Reservoir Pressure • The max res. press. is estimated to be 3220 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. TREE = 4" CIW WELLHEAD= FMC ACTUATOR = OTIS KB. ELEV = 71.8' BF. ELEV = 44.4' KOP = 3660' Max Angle = 38 ®8013' Datum MD = 9777' Datum TVD = 8800' SS H-24 2029' H4-1 /2" OTIS SSSV NP, D = 3.813" CHAS I FT MANCIREI S 13-3/8" CSG, 72#, L-80, D = 12.347" Minimum ID = 3.725" ~ 9249' 4-1/2" OTIS XN NIPPLE ITOP OF 7" LNR 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3085 3084 0 OTC DOME RM 16 06/01/06 6 5050 4923 30 OTIS DMY RA 0 5 6472 6007 37 OTIS DOME RM 16 06/01/06 4 7625 7043 30 OTIS DMY RA 0 3 8272 7607 31 OTIS DMY RA 0 2 8877 8108 34 OTIS SO RA 20 08/08/06 1 9029 8234 34 OTIS DMY RM 0 08/08/06 9099' 4-1/2" OTIS XA SLDNJG SLV, D = 3.813" 9159' TNV SBR SEAL ASSY 9174' 9-5/8" X 4-1/2" TNV HBBP PKR, D = 4.75" 921T a-1/2° OTIS X NP, D = 3.813" 92$9` 4-112" OTIS XN NP, D = 3.725" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 9282' 9282 4-1/2" TNV TBG TAIL, D = 3.958" 9281' ELMD TT LOGGED 02/06/86 9-518" CSG, 47#, L-80, D = 8.881" ~~ 9525' PERFORATION SUMMARY REF LOG: SWS-BHCS 01/11/86 ANGLE AT TOP PERF: 31 (~ 9590' Note: Refer to Production DB for h~torical pert data SQE SPF fNTERVAL Opn/Sgz DATE 3-3/8" 6 9590 - 9610 O 03/23/96 3-3/8" 4 9718 - 9748 O 08/14/92 3-3/8" 6 9764 - 9782 O 01/02/91 3-3/8" 6 9792 - 9810 O 12/21/90 3-3/8" 6 9810 - 9824 O 11/04/90 3-3/8" 4 9835 - 9840 S 10/27/90 3-3/8" 4 9852 - 9857 S 10/27/90 3-3/8" 4 9880 - 9900 O ~ PBTD ~ 10158' 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" 10200' MARKER JONT 994$' ~-~ FISH - DOVIIELL STRADLE PKR DATE REV BY COMMENTS DATE REV BY COMMENTS 01/16136 ORIGINAL COMPLETION 07/15/03 CMO/TLP KB ELEVATION CORRECTDN O6/04!06 KSB/PAG GLV GO (06/01/08) 08/08/ RCT/PJC GLV GO PRUDHOE BAY UNff WELL: H-24 PERMIT No: 1853050 API No: 50-029-21512-00 SEC T1, T11 N, R13E, 754' FNL & 1735' FEL ~ Expbratbn (Alaska) TREE = 4" CNV WELLHEAD= FMC ACTUATOR = OTIS KB. ELEV = 71.8' BF. ELEV = 44.4' KOP = 3660' Max Angle = 38 ~ 6013' Datum MD = 9777' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I--I 2674' Minimum ID = 3.725" @ 9249' 4-1 /2" OTIS XN NIPPLE TOP OF 3 1/2" x 2 7; S" 13Cr LNR 9230' TOC lap sGz 9230' TOP OF 7" LNR 9231' 3-5" X Nip 2.813" ID 9260' 12.6#, L-80, .0152 bpf, ID = 3.958" 92$2' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9525' 3.5" X 2.875" xover 9600' PERFORATION SUMMARY REF LOG: SWS-BRCS 01/11/86 ANGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OpnlSgz DATE 3-3/8" 6 9590 - 9610 S proposd 3-3/8" 4 9718 - 9748 s proposd 3-3/8" 6 9764 - 9782 s proposd 3-3/8" 6 9792 - 9810 s proposd 3-3/8" 6 9810 - 9824 s proposd 3-3/8" 4 9835 - 9840 S 10/27/90 3-3/8" 4 9852 - 9857 S 10/27/90 3-3/8" 4 9880 - 9900 s proposd 29#, L-80, .0371 bpf, ID = 6.184" 10200' H -2 4 A SAFETY NOTES: used CTD sidetrack 1 /2" OTIS SSSV NIP, D = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3085 3084 0 OTIS DOME RM 16 06!01/06 6 5050 4923 30 OTIS DMY RA 0 5 6472 6007 37 OTIS DOME RM 16 06/01/06 4 7625 7043 30 OTIS DMY RA 0 3 8272 7607 31 OTIS DMY RA 0 2 8877 8108 34 OTIS SO RA 20 08/08/06 1 9029 8234 34 OTIS DMY RM 0 08/08/06 9099' 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9159' TNV SBR SEAL ASSY 9174' 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 4.75" ~ 4-1 /2" OTIS X NIP, ID = 3.813" ~ yL48- I ~ 4- i is v i W ~rv rvir, iu mmea [o = 9282' 4-1/2" TNV TBG TAIL, ID = 3.958" 9281 ~ ELMD TT LOGGED 02/06/86 9625' 3 112" x 2-7/8" 13Cr anted and perfed 11170' DATE REV BY COMMENTS DATE REV BY COMMENTS 01116/86 ORIGINAL COMPLETION 07/15/03 CMO/TLP KB ELEVATION CORRECTION 06/04/06 KSB/PAG GLV GO (06/01/06) 08/08/06 RCT/PJC GLV GO PRUDHOE BAY UNIT WELL: 1+24 PERMIT No: 1853050 API No: 50-029-21512-00 SEC 21, T11N, R13E, 754' FNL 8 1735' FEL BP Exploration (Alaska) • by BP Alaska Baker Hughes INTEQ Planning Report ~t~ ~s INTEQ Company: BP Amoco Date: 8/31/2007 Time: 13:49:08 Page: l Field:. Pnuihoe Bay Co~ordinate(NE) Reference: WeN: H-24, True North Site: PB H Pad. Vertical (TVD}Refereece: 33 :24 :12/27/1985 00:0 0 71.8 Well: H-24 Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Welipat6i Plan 6, H-24A 8nrveyCakulation Method: Minimum Ctavatare Db: Grade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB H Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5957572 .25 ft Latitude: 70 17 30.055 N From: Map Easting: 641366 .07 ft Longitnde: 148 51 19.802 W Position Uncertainty: 0.00 ft North Reference: True Gronnd Level: 0.00 ft Grid Convergeece: 1.08 deg Well: H-24 Slot Name: 24 H-24 Well Position: +N/-S 2424.74 ft Northing: 5960024 .99 ft Latitude: 70 17 53.901 N +E/-W 1521.91 ft Easting : 642842 .00 ft Longitude: 148 50 35.438 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, H-24A Drilled From: H-24 Tie-on Depth: 9602.45 ft Carreat Datum: 33:24 12/27/1985 00:00 Height 71 .80 ft Above System Datum: Mean Sea Level Magnetic Data: 8/14/2007 DecGnatioo: 23.57 deg Field Strength: 57647 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.80 0.00 0.00 90.00 Plan: Plan #6 Date Composed: 8/14/2007 use 15 Deg/100 /all 4.125" hole Version: 19 Principal: Yes Tied-to: From: Definitive Path Targets Map Map. <-- Latitude ---> <--- Longitude ---~ Name Description TVD +N/S +E/-W Northing Easting Deg Min Sec Deg Mie Sec Dip. Dir. ft ft ft ft it H-24A Polygon 71.80 618.86 -3351.11 5960580.00 639480.00 70 17 59.980 N 148 52 13.132 W -Polygon 1 71.80 618.86 -3351.11 5960580.00 639480.00 70 17 59.980 N 148 52 13.132 W -Polygon 2 71.80 715.07 -2624.09 5960690.00 640205.00 70 18 0.929 N 148 51 51.939 W -Polygon 3 71.80 760.40 -2378.16 5960740.00 640450.00 70 18 1.376 N 148 51 44.770 W -Polygon 4 71.80 572.69 -1711.56 5960565.00 641120.00 70 17 59.531 N 148 51 25.334 W -Polygon 5 71.80 387.04 -1680.08 5960380.00 641155.00 70 17 57.705 N 148 51 24.415 W -Polygon 6 71.80 445.63 -2394.15 5960425.00 640440.00 70 17 58.280 N 148 51 45.233 W -Polygon 7 71.80 105.21 -3165.82 5960070.00 639675.00 70 17 54.929 N 148 52 7.724 W H-24A Fault 1 71.80 978.36 -2899.16 5960948.00 639925.00 70 18 3.517 N 148 51 59.961 W -Poygon 1 71.80 978.36 -2899.16 5960948.00 639925.00 70 18 3.517 N 148 51 59.961 W -Polygon 2 71.80 374.07 -2681.58 5960348.00 640154.00 70 17 57.575 N 148 51 53.611 W -Poygon 3 71.80 224.28 -2431.37 5960203.00 640407.00 70 17 56.103 N 148 51 46.316 W -Polygon 4 71.80 189.54 -1866.88 5960179.00 640972.00 70 17 55.763 N 148 51 29.860 W -Polygon 5 71.80 293.61 -1500.81 5960290.00 641336.00 70 17 56.787 N 148 51 19.189 W -Polygon 6 71.80 189.54 -1866.88 5960179.00 640972.00 70 17 55.763 N 148 51 29.860 W -Polygon 7 71.80 224.28 -2431.37 5960203.00 640407.00 70 17 56.103 N 148 51 46.316 W -Polygon 8 71.80 374.07 -2681.58 5960348.00 640154.00 70 17 57.575 N 148 51 53.611 W H-24A Faun 2 71.80 990.54 -3329.04 5960952.00 639495.00 70 18 3.635 N 148 52 12.494 W -Polygon 1 71.80 990.54 -3329.04 5960952.00 639495.00 70 18 3.635 N 148 52 12.494 W -Polygon 2 71.80 986.23 -2892.00 5960956.00 639932.00 70 18 3.595 N 148 51 59.752 W -Polygon 3 71.80 1199.59 -2644.89 5961174.00 640175.00 70 18 5.694 N 148 51 52.550 W -Polygon 4 71.80 1142.55 -2222.86 5961125.00 640598.00 70 18 5.135 N 148 51 40.245 W -Polygon 5 71.80 820.00 -1303.75 5960820.00 641523.00 70 18 1.964 N 148 51 13.447 W -Polygon 6 71.80 1142.55 -2222.86 5961125.00 640598.00 70 18 5.135 N 148 51 40.245 W -Polygon 7 71.80 1199.59 -2644.89 5961174.00 640175.00 70 18 5.694 N 148 51 52.550 W -Polygon 8 71.80 986.23 -2892.00 5960956.00 639932.00 70 18 3.595 N 148 51 59.752 W by BP Alaska B~ Baker Hughes INTEQ Planning Report nvTE Q Comps®y: BP Amoco Date: 8/31/2007 Time: 13:49:08 Page: 2 Field: PRtdhoe Bay Co-ordmate(NE) Reference: WeN: H-24, True North Site: Pl3 H Pad Vertical (TVD) Reference: 33:24 12/27!1985 00:00 71.8 We1L H-24 Sectioa (VS) Reference: WeN (O.OON,O.OOE;90.OOAzi) Wellpat6: Plan 6, H-24A Survey CakalaHoo Method: Minimum Curvature Db: Oracle Targets Map Map ~-- Latitude -> ~ Longitude --> Name Description TVD +N/-$ +E!-W No'thing Eastiug Deg Mln Sec Deg Min Sec .Dip. Dir. ft ft ft ft ft H-24A Fauft 3 71.80 785.94 -1301.40 5960786.00 641526.00 70 18 1.629 N 148 51 13.378 W -Polygon 1 71.80 785.94 -1301.40 5960786.00 641526.00 70 18 1.629 N 148 51 13.378 W -Polygon 2 71.80 438.41 -1436.04 5960436.00 641398.00 70 17 58.211 N 148 51 17.301 W -Polygon 3 71.80 297.50 -1389.71 5960296.00 641447.00 70 17 56.825 N 148 51 15.950 W -Polygon 4 71.80 .438.41 -1436.04 5960436.00 641398.00 70 17 58.211 N 148 51 17.301 W H-24A Target 4 8766.80 543.90 -2302.26 5960525.00 640530.00 70 17 59.247 N 148 51 42.555 W H-24A Target 2 8801.80 594.93 -2881.44 5960565.00 639950.00 70 17 59.746 N 148 51 59.440 W H-24A Target 3 8801.80 584.64 -2866.63 5960555.00 639965.00 70 17 59.645 N 148 51 59.008 W H-24A Target 1 8861.80 430.36 -3169.64 5960395.00 639665.00 70 17 58.127 N 148 52 7.840 W H-24A Target 5 8861.80 478.11 -1998.43 5960465.00 640835.00 70 17 58.600 N 148 51 33.697 W Annotation MD TVD ft ft 9602.45 8720.46 TIP 9625.00 8739.86 KOP 9645.00 8756.94 End of 9 Deg/100' DLS 9857.14 8861.79 4 9897.76 8858.25 5 9997.76 8839.86 6 10156.98 8809.02 7 10206.98 8803.03 8 10250.00 8801.74 End of 35 Deg/100' DLS 10330.00 8800.26 10 10480.00 8792.62 11 10630.00 8782.51 12 10780.00 8770.14 13 10845.70 8767.23 14 10951.00 8778.28 15 11061.00 8811.39 16 11169.99 8861.41 TD Plan Section Information MD Intl Azim TVD +N/S +E/ W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft degl100ft deg/100ft deg _ 9602.45 30.72 288.61 8720.46 242.54 -3032.61 0.00 0.00 0.00 0.00 9625.00 30.51 288.71 8739.86 246.22 -3043.49 0.96 -0.93 0.44 166.41 9645.00 32.21 289.86 8756.94 249.66 -3053.31 9.00 8.48 5.77 20.00 9857.14 90.00 349.25 8861.79 393.84 -3138.55 35.00 27.24 27.99 63.40 9897.76 100.00 359.40 8858.25 434.00 -3142.57 35.00 24.62 25.00 45.00 9997.76 100.52 34.99 8839.86 526.40 -3114.00 35.00 0.52 35.58 85.90 10156.98 100.00 91.70 8809.02 593.59 -2980.02 35.00 -0.33 35.62 85.00 10206.98 93.69 108.15 8803.03 585.02 -2931.32 35.00 -12.62 32.90 110.00 10250.00 89.71 93.62 8801.74 576.93 -2889.22 35.00 -9.24 -33.78 255.00 10330.00 92.40 81.92 8800.26 580.04 -2809.44 15.00 3.36 -14.62 283.00 10480.00 93.37 104.43 8792.62 571.82 -2660.82 15.00 0.64 15.01 87.00 10630.00 94.26 81.89 8782.51 563.60 -2512.35 15.00 0.59 -15.02 273.00 10780.00 95.08 104.45 8770.14 555.40 -2364.06 15.00 0.55 15.04 87.00 10845.70 90.00 96.00 8767.23 543.77 -2299.55 15.00 -7.73 -12.87 239.21 10951.00 77.96 106.31 8778.28 523.68 -2197.12 15.00 -11.43 9.79 140.00 11061.00 67.08 93.27 8811.39 505.56 -2094.20 15.00 -9.89 -11.85 227.00 11170.00 58.51 108.96 8861.42 487.47 -1999.49 15.00 -7.87 14.39 125.00 • by BP Alaska sAg Baker Hughes INTEQ Planning Report INTEQ Compaay: BP AmOCO Date: 8/31/2007 Tine: 13:49:08 Page: 3 Field:. Prudhoe Bay Co-ordiaate(NE) Reference: Well: H-24, True -North Site: PB H Pad Vertical (TVD) Reference: 33:24 12!27/1985 00:00 71.8 Well: H-24 . Section (VS) Reference: Well (O:OON,O: OOE;90.OOAzi) Wellpath:i Pian 6, H-24A Survey Calculation Metbod: Minimum Curvature Db: Qracle Survey M~ Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg R ft ft tt tt deg/100ft fl deg 9602.45 30.72 288.61 8648.66 242.54 -3032.61 5960209.84 639805.56 0.00 -3032.61 0.00 MWD 9625.00 30.51 288.71 8668.06 246.22 -3043.49 5960213.30 639794.61 0.96 -3043.49 166.41 MWD 9645.00 32.21 288.86 8685.14 249.66 -3053.31 5960216.56 639784.73 9.00 -3053.31 20.00 MWD 9650.00 33.02 292.74 8689.35 250.64 -3055.82 5960217.49 639782.20 35.00 -3055.82 63.40 MWD 9656.78 34.23 296.43 8695.00 252.20 -3059.24 5960218.98 639778.76 35.00 -3059.24 60.98 H-24A 9675.00 37.96 305.23 8709.73 257,72 -3068.41 5960224.33 639769.48 35.00 -3068.41 57.91 MWD 9700.00 43.93 315.01 8728.62 268.31 -3080.85 5960234.68 639756.85 35.00. -3080.85 50.79 MWD 9701.92 44.42 315.67 8730.00 269.26 -3081.79 5960235.61 639755.89 35.00 -3081.79 43.38 H-24A 9725.00 50.58 322.78 8745.60 282.16 -3092.84 5960248.30 639744.59 35.00 -3092.84 42.91 MWD 9750.00 57,64 329.16 8760.25 298,95 -3104.12 5960264.86 639733.00 35.00 -3104.12 38.09 MWD 9775.00 64.99 334.60 8772.25 318.28 -3114.41 5960284.00 639722.34 35.00 -3114.41 34.34 MWD 9800.00 72.50 339.41 8781.31 339.72 -3123.48 5960305.26 639712.87 35.00 -3123.48 31.73 MWD 9825.00 80.12 343.83 8787.23 362.75 -3131.12 5960328.14 639704.80 35.00 -3131.12 29.98 MWD 9850.00 87.80 348.06 8789.86 386.84 -3137.15 5960352.11 639698.31 35.00 -3137.15 28.93 MWD 9857.14 90.00 349.25 8789.99 393.84 -3138.55 5960359.08 639696.78 35.00 -3138.55 28.48 MWD 9875.00 94.42 353.68 8789.30 411.48 -3141.20 5960376.67 639693.79 35.00 -3141.20 45.00 MWD 9897.76 100.00 359.40 8786.45 434.00 -3142.57 5960399.15' 639692.00 35.00 -3142.57 45.17 MWD 9900.00 100.06 0.20 8786.06 436.21 -3142.58 5960401.36 639691.95 35.00 -3142.58 85.90 MWD 9925.00 100.54 9.08 8781.58 460.70 -3140.59 5960425.88 639693.46 35.00 -3140.59 86.04 MWD 9950.00 100.78 17.98 8776.95 484.56 -3134.85 5960449.85 639698.75 35.00 -3134.85 87.63 MWD 9975.00 100.76 26.89 8772.27 507.24 -3125.49 5960472.70 639707.68 35.00 -3125.49 89.28 MWD 9997.76 100.52 34.99 8768.06 526.40 -3114.00 5960492.08 639718.80 35.00 -3114.00 90.95 MWD 10000.00 100.59 35.78 8767.65 528.20 -3112.72 5960493.90 639720.04 35.00 -3112.72 85.00 MWD 10025.00 101.20 44.67 8762.91 546.93 -3096.89 5960512.92 639735.52 35.00 -3096.89 85.15 MWD 10050.00 101.55 53.59 8757.97 562.95 -3078.38 5960529.29 639753.72 35.00 -3078.38 86.83 MWD 10075.00 101.63 62.52 8752.94 575.89 -3057.62 5960542.62 639774.23 35.00 -3057.62 88.59 MWD 10100.00 101.43 71.45 8747.93 585.45 -3035.10 5960552.61 639796.56 35.00 -3035.10 90.39 MWD 10125.00 100.97 80.36 8743.06 591.42 -3011.34 5960559.03 639820.20 35.00 -3011.34 92.18 MWD 10150.00 100.25 89.23 8738.45 593.64 -2986.89 5960561.71 639844.60 35.00 -2986.89 93.91 MWD 10156.98 100.00 91.70 8737.22 593.59 -2980.02 5960561.79 639851.47 35.00 -2980.02 95.55 MWD 10175.00 97.79 97.68 8734.43 592.13 -2962.29 5960560.67 639869.22 35.00 -2962.29 110.00 MWD 10200.00 94.60 105.88 8731.73 587.06 -2937.98 5960556.06 639893.62 35.00 -2937.98 110.93 MWD 10206.98 93.69 108.15 8731.23 585.02 -2931.32 5960554.15 639900.32 35.00 -2931.32 111.81 MWD 10225.00 92.04 102.05 8730.33 580.34 -2913.96 5960549.80 639917.77 35.00 -2913.96 255.00 MWD 10250.00 89.71 93.62 8729.94 576.93 -2889.22 5960546.86 639942.56 35.00 -2889.22 254.70 MWD 10275.00 90.56 89.96 8729.88 576.15 -2864.23 5960546.56 639967.56 15.00 -2864.23 282.99 MWD 10300.00 91.40 86.31 8729.46 576.96 -2839.26 5960547.84 639992.51 15.00 -2839.26 282.99 MWD 10325.00 92.24 82.65 8728.66 579.37 -2814.39 5960550.72 640017.33 15.00 -2814.39 282.93 MWD 10330.00 92.40 81.92 8728.46 580.04 -2809.44 5960551.49 640022.27 15.00 -2809.44 282.81 MWD 10350.00 92.55 84.92 8727.60 582.33 -2789.59 5960554.15 640042.06 15.00 -2789.59 87.00 MWD 10375.00 92.74 88.67 8726.44 583.73 -2764.66 5960556.02 640066.96 15.00 -2764.66 87.13 MWD 10400.00 92.91 92.42 8725.21 583.49 -2739.70 5960556.26 640091.92 15.00 -2739.70 87.30 MWD 10425.00 93.07 96.17 8723.91 581.62 -2714.81 5960554.87 640116.84 15.00 -2714.81 87.49 MWD 10450.00 93.21 99.92 8722.54 578.13 -2690:09 5960551.85 640141.61 15.00 -2690.09 87.68 MWD 10475.00 93.34 103.67 8721.11 573.03 -2665.67 5960547.21 640166.13 15.00 -2665.67 87.89 MWD 10480.00 93.37 104.43 8720.82 571.82 -2660.82 5960546.09 640171.00 15.00 -2660.82 88.10 MWD 10500.00 93.52 101.42 8719.62 567.35 -2641.37 5960542.00 640190.53 15.00 -2641.37 273.00 MWD 10525.00 93.70 97.67 8718.04 563.21 -2616.77 5960538.33 640215.20 15.00 -2616.77 272.82 MWD 10550.00 93.86 93.92 8716.39 560.69 -2591.95 5960536.28 640240.06 15.00 -2591.95 272.58 MWD 10575.00 94.00 90.16 8714.68 559.81 -2567.03 5960535.87 640264.99 15.00 -2567.03 272.34 MWD 10600.00 94.13 86.40 8712.91 560.55 -2542.11 5960537.09 640289.89 15.00 -2542.11 272.08 MWD 10625.00 94.24 82.65 8711.08 562.93 -2517.30 5960539.94 640314.66 15.00 -2517.30 271.81 MWD 10630.00 94.26 81.89 8710.71 563.60 -2512.35 5960540.70 640319.58 15.00 -2512.35 271.54 MWD by BP Alaska ~~~ Baker Hughes INTEQ Planning Report 1NTE Q Survey MD Iacl Azim SS TVD NJS E/W ft . ....deg deg ft ft ft 10650.00 94.41 84.90 8709.20 565.90 -2492.55 10675.00 94.58 88.66 8707.24 567.30 -2467.67 10700.00 94.73 92.41 8705.21 567.07 -2442.76 10725.00 94.86 96.18 8703.12 565.20 -2417.92 10750.00 94.98 99.94 8700.97 561.71 -2393.26 10775.00 95.07 103.70 8698.79 556.61 -2368.89 10780.00 95.08 104.45 8698.34 555.40 -2364.06 10800.00 93.54 101.87 8696.84 550.86 -2344.64 10825.00 91.61 98.66 8695.72 546.41 -2320.07 10845.70 90.00 96.00 8695.43 543.77 -2299.55 10850.00 89.51 96.42 8695.45 543.31 -2295.27 10875.00 86.63 98.83 8696.29 539.99 -2270.51 10900.00 83.77 101.26 8698.38 535.65 -2245.98 10925.00 80.91 103.71 8701.71 530.30 -2221.79 10950.00 78.08 106.21 8706.27 523.96 -2198.05 10975.00 75.52 103.59 8711.98 517.66 -2174.55 11000.00 73.01 100.69 8718.76 512.59 -2151.03 11025.00 70.55 97.72 8726.58 508.79 -2127.59 11050.00 68.13 94.65 8735.40 506.27 -2104.34 11061.00 67.08 93.27 8739.59 505.56 -2094.20 11075.00 65.89 95.16 8745.18 504.62 -2081.39 11100.00 63.82 98.61 8755.80 501.91 -2058.93 11125.00 61.83 102.19 8767.22 497.91 -2037.06 11150.00 59.94 105.90 8779.39 492.62 -2015.88 11170.00 58.51 108.96 8789.62 487.47 -1999.49 MapN MapE DLS ft ft deg/1 5960543.37 640339.34 15.00 5960545.24 640364.19 15.00 5960545.49 640389.10 15.00 5960544.09 640413.96 15.00 5960541.07 640438.68 15.00 5960536.44 640463.14 15.00 5960535.32 640468.00 15.00 5960531.15 640487.50 15.00 5960527.17 640512.14 15.00 5960524.92 640532.71 15.00 5960524.53 640537.00 15.00 5960521.69 640561.82 15.00 5960517.82 640586.42 15.00 5960512.93 640610.70 15.00 5960507.04 640634.56 15.00 5960501.19 640658.18 14.44 5960496.57 640681.79 15.00 5960493.22 640705.29 15.00 5960491.13 640728.58 15.00 5960490.62 640738.73 15.00 5960489.92 640751.56 15.00 5960487.65 640774.06 15.00 5960484.05 640796.00 15.00 5960479.17 640817.28 15.00 5960474.34 640833.77 15.00 VS TFO Tool Oft ft deg.... .. -2492.55 87.00 MWD -2467.67 87.23 MWD -2442.76 87.52 MWD -2417.92 87.83 MWD -2393.26 88.14 MWD -2368.89 88.46 MWD -2364.06 88.79 MWD -2344.64 239.21 MWD -2320.07 239.02 MWD -2299.55 238.87 MWD -2295.27 140.00 MWD -2270.51 140.00 MWD -2245.98 139.92 MWD -2221.79 139.71 MWD -2198.05 139.39 MWD -2174.55 224.65 MWD -2151.03 227.62 MWD -2127.59 228.41 MWD -2104.34 229.34 MWD -2094.20 230.42 MWD -2081.39 125.00 MWD -2058.93 124.25 MWD -2037.06 122.78 MWD -2015.88 121.15 MWD -1999.49 119.34 O 3 3/16" • i by BP Alaska Anticollision Report. ~,.r s INTEQ Company: BP AmoCO Date: 8/31/2007 Time: 13;51:31 Page: 1 Fiehl: Prudhoe Bay , Reference Site: PB Fi Pad !^o-ordinate(NE) Reference: ` Weil; H-24, True North Reference We1L• H-24 Vertical (TVD) Refereae: 33:24.12/27/1985 00:00 71.8 Reference Wellpath: Plan 6, H-24A Db: Orecle GLOBAL SCAN APPLIED: Ali welipaths withie 200'+ 100/1000 of rcfercoce -There arc aerlls in this Aldhttipal Plan 8 PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9602.45 to 11170.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Det-initive Wellpath Date: 8/1 4/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 106.15 9602.45 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT mukishot 9602.45 11170.00 Planned: Plan #6 V19 MWD MWD - Standard Casing Points MI) TYI) Diameter $ole Size Name ft ft in in 11170.00 8861.42 3.188 4.125 3 3/16" Casing Summary Onset Wellpath ~ Refercuce ,Oftsef Ctr-Ctr No-Ga Allowable Site Well Wellpath MD MI) Distance Area Deviation Warning ft ft ft ft ft PB H Pad H-11 H-11 V1 Out of range PB H Pad H-15 H-15 V5 9998.29 9900.00 1580.30 176.78 1403.52 Pass: Major Risk PB H Pad H-16 H-16 V3 10939.21 9300.00 956.58 478.24 478.34 Pass: Major Risk PB H Pad H-16 H-16A V2 11067.17 9000.00 1015.65 363.57 652.07 Pass: Major Risk PB H Pad H-16 H-16AP61 V1 11067.17 9000.00 1015.65 363.57 652.07 Pass: Major Risk PB H Pad H-16 H-16B V2 11067.17 9000.00 1015.65 363.57 652.07 Pass: Major Risk PB H Pad H-24 H-24 V2 9697.55 9700.00 10.62 156.93 -146.31 FAIL: Major Risk PB H Pad H-25 H-25 V3 10140.00 9500.00 1628.62 502.32 1126.30 Pass: Major Risk Site: PB H Pad Well: H-15 Rule Assigned: Major Risk Wellpath: H-15 V5 Inter-Site Error: 0.00 ft Reference Offset .Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVl) MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistabee Area Deviatioe Warning ft ft ft ft ft ft deg deg in ft ft ft 10015.03 8836.63 9200.00 7387.82 18.35 95.94 14.65 333.53 9.625 1648.76 138.80 1509.96 Pass 10010.00 8837.58 9300.00 7455.65 18.10 90.55 9.19 329.85 9.625 1625.99 142.80 1483.19 Pass 10010.00 8837.58 9400.00 7524.46 18.10 91.31 5.76 326.43 9.625 1607.66 148.95 1458.71 Pass 10005.21 8838.48 9500.00 7594.44 17.87 85.79 0.24 322.61 9.625 1593.67 153.10 1440.57 Pass 10002.99 8838.90 9600.00 7665.59 17.77 83.43 355.76 318.91 9.625 1584.15 158.75 1425.40 Pass 10000.00 8839.45 9700.00 7738.14 17.63 79.94 350.91 315.13 9.625 1578.74 163.06 1415.68 Pass 9999.62 8839.52 9800.00 7812.26 17.62 79.78 347.14 311.50 9.625 1577.22 170.74 1406.49 Pass 9998.29 8839.76 9900.00 7887.49 17.56 78.31 342.98 307.80 9.625 1580.30 176.78 1403.52 Pass 9997.76 8839.86 10000.00 7961.56 17.54 77.91 339.18 304.19 9.625 1591.40 184.18 1407.22 Pass 9997.76 8839.86 10100.00 8032.66 17.54 78.27 335.70 300.72 9.625 1612.85 193.37 1419.48 Pass 9997.76 8839.86 10200.00 8100.58 17.54 78.64 332.37 297.39 9.625 1644.17 202.30 1441.86 Pass 9995.03 8840.36 10300.00 8165.10 17.42 75.67 328.08 294.06 9.625 1684.68 200.08 1484.60 Pass 9994.85 8840.39 10400.00 8225.76 17.42 75.73 325.09 291.14 9.625 1734.01 205.48 1528.53 Pass 9994.75 8840.41 10500.00 8285.26 17.41 75.90 322.32 288.40 9.625 1788.69 210.18 1578.51 Pass 9994.64 8840.43 10600.00 8346.39 17.41 76.08 319.68 285.80 9.625 1845.49 214.42 1631.07 Pass 9994.55 8840.45 10700.00 8409.55 17.40 76.25 317.16 283.31 9.625 1903.74 218.41 1685.34 Pass 9994.49 8840.46 10800.00 8474.43 17.40 76.44 314.76 280.93 9.625 1963.47 222.16 1741.31 Pass 9994.59 8840.44 10900.00 8540.77 17.41 76.70 312.52 278.66 7.000 2024.45 225.98 1798.47 Pass 9994.83 8840.39 11000.00 8608.10 17.42 77.04 310.45 276.50 7.000 2086.94 229.98 1856.96 Pass 9997.76 8839.86 11100.00 8676.67 17.54 80.50 309.60 274.61 7.000 2150.86 248.40 1902.46 Pass 9997.76 8839.86 11200.00 8746.10 17.54 80.50 307.62 272.64 7.000 2216.43 250.75 1965.68 Pass 9997.76 8839.86 11300.00 8816.46 17.54 80.49 305.73 270.75 7.000 2283.35 252.70 2030.65 Pass 9997.76 8839.86 11400.00 8887.63 17.54 80.47 303.93 268.94 7.000 2351.66 254.25 2097.40 Pass 9997.76 8839.86 11500.00 8959.09 17.54 80.44 302.22 267.23 7.000 2421.57 255.39 2166.18 Pass C~' J are L NN_~ I..L~ Dowell bag of slips Blind/Shears middle of oioes 2 3/8" combi ram/slips BAG TOTs H-24A ~ ~ Mud Cross I I Mud Cross of flow cross of blind/shears variable bore pipe 3 1/2"-2 7/8" 2 3/8" combi ram/slips ~/a~V TOTs Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of '~ ~. . :,;:.~`"`°~5ha~Go°t~,~;~p ,.3^d 2ecordstStatt,s Plats I~F;~°~rder's Se~,rCh-State Cabins ~~uf~~ 3~D41PC~S Alaska DNR Case Summary File Type ADL,...,,,~„___ Fr<le Number: 2$2$4 ~ Printable Case Fife_Summary See Township, Range, Section and Acreage? ~'' Yes No New Search ~+~__~ ~ Case Abstract ~ Case Detail t Land Abstract I'tlc: al)[. 2R?N-l ~ Se;~r:.h ~,a~ } ~*i;, 3-::~~ pd~~~rs Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99~ 196612 C'u.selt-pe: 7~=~ OiL & GAS LEASE COMP File Location: llOG DIV OIL AND CAS Case,Stat2lS: 35 ISS/APPRV/ACTV/ AUTH Total Acres: 2560.000 Office of Prr~nury Responsibility: DOG L Last Transaction Date: 12/04/2006 DNR Unit: 780 OIL AND GAS Status Dote: 08/19/1965 Date Initiated: 05/28/1965 >CV OIL AND GAS Case Subtype: h1~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U P9ats lrnrn~liip: U I IN Range: 013E .S~ectiorz.~ ~ ~ :~'c~c~inn Acres: 6~0 ~lleridiart: I~ fo~rr~shij~: O11N Rcan~c~.~ U131: .ti'cx°li~,j~.~ I(~ ~"~~c/iurl.l~~j~t~~': 6~1U Meridian: l_' 7ulrnt{~i/~- 0l I N Range: U I ~ I ~: Seeti~~ul.~ ~ I ,~'~c~~ion : [c~i~r~~: (;-~0 Meridian: l 7nwnship: Ol1N Rcr~t~e: Ol 3I~ Section: ~? Section,lc~res~: f~-t0 Leal UescriptiorEi 0~-2~4-19fi~ * * SALE NOTICE LEGAL DESCRIPTION C1~t-95 TIIN-RI3E-UM15,16,21,22 260.00 End ~f Case Summary Sear :<~ Last updated on 09/27/2007. http://www.dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28284&....9/27/2007 i • TRANSMITTAL LETTER CHECKLIST WELL NAME ~,(~~ ~~ v~~~ PTD# ~D~`331~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No, ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), ail records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit; Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after ~Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ~ • ^^ m ~ N O j ~ Q ; ~ ~ ~ ~ ~ ~ N. ~ ~ ~ i, O 3 01 a~ ~. , > m' ~ ; 1°' o `o m' O py ~ ~ L, ~ ~ ~ ~ C. W v: a ,~: c, ~ N ~ ~ ~ Q ~ N Q ~ ~ y~ i ' c ~ ~ N "_ p, ~ °' ~ , i 3. a I ~ ~ o> ~ , u > ~ a ~ r Q ~, m c. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ a, ~ a, a. ~ ~ ~ N~ N ~ ~ ~ ~ 2 ~ ~ ~ ~ ~ ~ ~ ~ ~ o ~ oi, n m ~ ~ 4 o~ N o ~ a O ~ Ll1 N. ~a ~, ~ c9 O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ ~ ~ i N• 'a~ C' ~~ ~ ~~ TC O, ~ N~ ~ ~ ~, S ~ Q ~~ ~ ~•~ N ~ ~ 3k, ~ C a~, ~ N. ~ 3~ .p U N v ~ ~T N. ~ ~ a ~ ~, ~ ~ C _ L. ~ ~ ~ ~ ~ ~ ~ O ~ ~ ~ ~ ~ i ~ ~~ ' ~ Q . ~ N, ~ • ~ • ~ ~ ~ ~ ~ f6 N ~ m• ~i p: C L N' U• O• ~ a ~ U N ~ ~ _ ~~ ~ O, ~ Q ~ N' x ~p~ ~ ~ J. U ~, > o Z ~ ~ ~ ~ ~ ~ f9, ~ ~ ~ ~ ~ ~: O. ~ ,~ v. _~ 7• O: ~ ~ m X, a.. x ~ ~~ O. ~. gyp, ~ Q. ~ ~ N• ~ ~ Q ~ ~ ~ ~ O, ~ ~ ~ O Q. y~ N, y~ N. N~ N, N N N. N N~ N N: N, N. ~ N~ N O N ' N~ N ' N N Q, Q, Q, O ' QQ Q, Q, O N~ N, f/D N~ N N t/b N~ N, N, N, N, N N, Q N N, N N ' ' ' ' N, N~ N N ' Q ' ~ O ' Q, Q Q, ' N, N, a Z, ~, >', ~, ~, ~, ~, >', ~, Z; } } } z Z, z, z Z; z Z Z; >' ~ ~ Z ~ >' ~ ~ ~ ~ ~ r z z Z Z Z ~ ' T N o , I ~' b O' , , , ~ O. 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L~ o ar M, m N `m~ ~ a~ ~ . o o a ,~~ 3 o 0 3 •~ ~~ 0 ~, ~- o 3, ~ c E uJ o ° z O Q o, -o, ~ c, +~ `o ~ m > o -o , ~~ a m . a a> o ~ ~: '~ .. o: a :a, v. ~ o o . ~ ~ a fl. ~ ° ~ N ~ ~ °. a~ 3 ~, o rn . ~ , v n ~ ~ 3 a~ U o d _ ~ ~ . N N p o' . . N U , N ~ , o, O ~ `: . Y o' N , : , v ~ N ~ O , ~ p . N , O ~ ~ ~ ~ a~ L• a a' a~' O, a ~ m' a , o ~ ,p. _ N' ~, o ~ a tq~ t~' ~ N~ a a c' v ~~ , U ,N. ~ °' ~ ai ~ : a . _ ~ . 'a o ~p~ ~ ~ -o m ~ o' o C. U p ~ ~ N. ~~ . ~' N. c O' U: o' G o' t~ U. N. O ~, O ~ 3' pr .~~ m ~, (9 ~ ~, C. N. m ~ ~ f6- f o' o' N f6. ' , O ~~ T ~ 'O. m' B • ~' , 2. p ~~ v~ ~ Q •`~~ . _a ~ i O ~~ ~. ~, .S. a fl. ~ , '~ ~ 0~ o o, a~ ~ 3. S '~ ~ ~ ~ a o ~ aai a~i >~ ~ Y ~ ~~ o ~ a~ ~ ~ n ~~ t o ~ ~ U °~ o. U ~ ~~ o, _ >' ~. a~~ i a , ~, - ~, ~ a; ~ m, ~, O. L, C. C ...~ N. ' . U, c -o a . N. ' ~ . N ' , ~ ~ ~ _, 3 ° ~ ~ ~ O. ~ f6. C. N. C. rl' X o 3 = N O f6 N _ 3 i fA W ~ C U U ar a a U o' ~. ~~ O O U ~ ~ U ~ U N a ~ o. o ~: ~~ ~~ o, 3 ~ ~~ N~ '~~ d ~' v;. ~ , v. ~~ r~ N 3, , C ~ U' ~' U ~, ~i~ '~~ J m r ~ N, ~ _, _, - U, '> ~, ~, '~, '~. a _, a~ 3 , Q U ~ a m 1- H 1= c °' o ~ ~, °' > , 'r d nW ~ Y ~, ~ L. ~E' a c~ N ~. ~o ai Y a~, aoi~ ~c, °~~ a~' a~' ' ~' a o_ n ai ui m . a~' ' ~~ o o; ~~, ~', ~' ~', a ~, - . f0 ~~ -° = O~, O, s°; o' °~ °i ' aoi' ' a~, m; ~a>, a~i, moo; ~ '~ U c a, -', ~, ~; ~; ~ , cn; w _, O; O; a; a; U ~; ¢ , a; z; ~ U, tn, U, U; U, U; Q, w , m, m, U, ~; Q, -, ~; ~ : ~ a, 4, cn, cn, U •-~ w _ n ~ O ~- N M V ~ (D ~ ~ O _ ~ N N N N N N N N N N OM M M M M M M M M M F- U ti ro ti .. C ~'' N ~ ''' ~ "'.' ~ U C w M M . ~ O r' N i 01 ~ r ~ ~ n N_ m y O U 1 ^ Q L ~ L Q ~ J N Vl d C1 ,, ^^ CC V C ~~~ W ~ 0 ~ Q Q ~ Q H i. ' d R Q a Q w (9 • s Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part ofi the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this calegory of information. • **** REEL HEADER **** MWD 08/06/10 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 07/11/27 1681896 01 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9560.0000: Starting Depth STOP.FT 11366.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: H-24A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 53.901"N 148 deg 50' 35.438"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 27 Nov 2007 API API NUMBER: 500292151201 Parameter Information Block #MNEM.UNIT Value Description SECT. 21 Section TOWN.N T11N Township RANG. R13E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 71.8 Feet Above Perm. Datum DMF DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 71.8 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. ao~ X33 ~ ~~ ~~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to PDCL (Primary Depth Control Log) provided by Schlumberger GR CNL dated 27 Nov 2007 per Roger Sels with BP Exploration (Alaska), Inc. (8) Tied to H-24 at 9615 feet MD (8659 ft. TVDSS) (9) The sidetrack was drilled from H-24 through a milled window in 7 inch liner. Top of window 9864 ft.MD (8672 ft.TVDSS) Bottom of window 9637 ft.MD (8678 ft.TVDSS) (10) The interval from 11345 feet to 11375 feet MD (8835 feet to 8855 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Compensated Attenuation Resistivity Borehole Corrected (LS) [MWD](400kHz),Ohm-m RACHX -> Compensated Attenuation Resistivity Borehole Corrected (LS) [MWD](2MHz),Ohm-m RPCLX -> Compensated Phase Difference Resistivity Borehole Corrected (LS)[MWD](400kHz),Ohm-m RPCHX -> Compensated Phase Difference Resistivity Borehole Corrected (LS)[MWD](2MHz),Ohm-m TVD -> Subsea True Vertical Depth CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9574.67, 9572.81, ! -1.86523 9577.37, 9575.92, ! -1.45117 9579.24, 9577.99, ! -1.24414 9580.27, 9578.82, ! -1.4502 9582.97, 9581.1, ! -1.86523 9585.87, 9584.21, ! -1.6582 9588.36, 9587.53, ! -0.829102 9591.05, 9589.6, ! -1.45117 9611.57, 9610.12, ! -1.4502 9614.89, 9613.65, ! -1.24414 9618, 9616.13, ! -1.86621 9621.52, 9619.24, ! -2.28027 9623.6, 9620.9, ! -2.69434 9626.08, 9622.97, ! -3.10938 9628.16, 9625.05, ! -3.10938 9634.16, 9630.64, ! -3.52441 9639.76, 9635.4, ! -4.35352 9648.67, 9645.35, ! -3.31738 9654.06, 9649.92, ! -4.14648 9656.55, 9652.61, ! -3.93848 9659.04, 9655.1, ! -3.93848 9660.07, 9656.96, ! -3.11035 9663.6, 9660.28, ! -3.31641 9675.62, 9670.85, ! -4.76758 9681.63, 9677.49, ! -4.14648 9684.12, 9679.35, ! -4.76758 9687.32, 9683.59, ! -3.73145 9694.58, 9689.6, ! -4.97461 9696.65, 9692.09, ! -4.56055 9704.53, 9699.14, ! -5.38965 9705.98, 9701.42, ! -4.56055 9711.99, 9705.98, ! -6.01172 9715.1, 9709.92, ! -5.18262 9716.55, 9711.57, ! -4.97559 9718.21, 9713.44, ! -4.76758 9720.07, 9715.3, ! -4.76855 9727.95, 9722.56, ! -5.38965 9731.47, 9727.54, ! -3.93848 9739.29, 9733.49, ! -5.80371 9740.95, 9735.15, ! -5.80469 9743.23, 9737.43, ! -5.80469 9752.5, 9747.53, ! -4.97461 9756.65, 9750.84, ! -5.80469 9760.17, 9754.78, ! -5.38965 9764.73, 9758.1, ! -6.63281 9771.99, 9765.15, ! -6.84082 9774.06, 9767.22, ! -6.84082 9777, 97 70.16, ! -6.84082 9781.57, 9774.1, ! -7.46289 9785.5, 9781.36, ! -4.14551 9794.21, 9787.16, ! -7.09883 9808.1, 9804.16, ! -3.93848 9841.68, 9840.02, ! -1.6582 9899.19, 9896.28, ! -2.90234 9916.6, 9913.28, ! -3.31641 9920.12, 9918.05, ! -2.07324 9923.23, 9922.2, ! -1.03711 9926.13, 9925.3, ! -0.829102 9937.12, 9932.97, ! -4.14648 9939.61, 9935.67, ! -3.93848 9940.85, 9937.54, ! -3.31738 9947.84, 9944.32, ! -3.52441 9989.34, 9984.58, ! -4.76758 9994.53, 9989.55, ! -4.97461 9998.46, 9994.32, ! -4.14551 10000.7, 9996.39, ! -4.35254 10003.6, 9999.09, ! -4.56055 10009.1, 10004.2, ! -4.97461 10011.6, 10007.3, ! -4.35254 10031.1, 10026.5, ! -4.56055 10034.2, 10029.7, ! -4.56055 10036.5, 10031.9, ! -4.56055 10039.2, 10035.2, ! -3.93848 10110.7, 10105.1, ! -5.59668 10190.1, 10134.3, ! -5.80469 10184.9, 10181.2, ! -3.73145 10193, 1 0193, ! 0 10195.9, 10195.1, ! -0.829102 10234.8, 10228.8, ! -6.01074 10242.2, 10236.9, ! -5.38965 10246.2, 10241.4, ! -4.76758 10258.8, 10253, ! -5.80469 10272.5, 10266.1, ! -6.42578 10301.9, 10296.7, ! -5.18262 10306.4, 10301.3, ! -5.18262 10312.5, 10308.3, ! -4.14551 10356.7, 10349, ! -7.66992 10366.6, 10357.3, ! -9.32812 10370, 1 0360.6, ! -9.32812 10379.3, 10373.9, ! -5.38965 10388.4, 10382.3, ! -6.01172 10398.9, 10391.5, ! -7.46289 10404.1, 10395.8, ! -8.29199 10407.6, 10400, ! -7.66992 10418.2, 10411.6, ! -6.63379 10427.3, 10422.1, ! -5.18262 i n LJ 10438.5, 10428.8, ! -9.74219 10442.7, 10432.1, ! -10.5723 10451.6, 10445.1, ! -6.42578 10473.7, 10470.6, ! -3.10938 10484.1, 10479.9, ! -4.14648 10499.6, 10495.6, ! -3.93848 10591.9, 10584.7, ! -7.25586 10596.9, 10588.8, ! -8.08398 10602.1, 10592.6, ! -9.53613 10606.2, 10597.7, ! -8.49902 10609.8, 10602.9, ! -6.84082 10673.7, 10667.1, ! -6.63379 10702, 10696, ! -6.01172 10821.2, 10815.6, ! -5.59668 10996.4, 10990.6, ! -5.80469 11006.2, 11001.4, ! -4.76758 11010.7, 11004.7, ! -6.01172 11019.5, 11013.9, ! -5.59766 11022.5, 11017.3, ! -5.18164 11101.9, 11099.2, ! -2.69531 11174.3, 11168.5, ! -5.80469 11178, 11173.3, ! -4.76758 11182, 11174.9, ! -7.04785 11209.4, 11201.5, ! -7.87695 11221.8, 11214.8, ! -7.04883 11227.2, 11219.6, ! -7.66992 11229.7, 11222.5, ! -7.25586 11252.9, 11245.2, ! -7.66992 11255.6, 11247.3, ! -8.29199 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 199 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN H_24A_Madpass_5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN H-24A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 27 Nov"2007 per Roger Sels with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 98 Tape File Start Depth = 9486.000000 Tape File End Depth = 11242.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 111 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 I~ 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN H-24A 5.xtf LCC 150 CN BP Exploration (Alaska) WN H-24A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!~~! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 27 Nov 2007 per Roger Sels with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM ----- CHAN DIMT ------------------ CNAM ---------- ODEP GR GR -- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ) Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 101 Tape File Start Depth = 9566.000000 Tape File End Depth = 11366.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 114 records... Minimum record length: 34 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .003 1024 f~ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN H_24A.xtf LCC 150 CN BP Exploration (Alaska) WN H-24A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT ------------ CNAM ODEP ----------- GR GR ----------------- GRAX ------------ 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is do wn (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0. 250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0. 250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Sam ples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 201 Tape File Start Depth = 9568.000000 Tape File End Depth = 11375.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 214 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .004 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN H_24A_Madpass.xtf LCC 150 CN BP Exploration (Alaska) WN H-24A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MadPass data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------ CNAM ODEP GR ------------ GR ----------- GRAX ------------------ 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 48 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 2 OHMM 4 RAS MWD 68 2 OHMM 5 RPD MWD 68 2 OHMM 6 RPS MWD 68 2 OHMM 1 Size Length • 4 8 *F 4 4 4 8 *F 4 8 *F 4 8 *F 4 8 *F 44 *F denotes fast channel curve Total Data Records: 167 Tape File Start Depth = 9487.000000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 Minimum record length Maximum record length 180 records... 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 07/11/27 1681896 O1 **** REEL TRAILER **** MWD 08/06/10 BHI O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS ~ ~ Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9486.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9486.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 62.7832 -999.2500 0.3081 1.5988 0.0837 0.0831 9600.0000 54.2620 -999.2500 2000.0000 2000.0000 0.2995 12.2422 9700.0000 114.0402 23.2566 23.7650 2000.0000 128.5268 120.9823 9800.0000 32.8463 97.1988 10.9803 12.8084 11.1308 10.3077 9900.0000 30.3461 61.5966 5.5447 5.8193 5.3650 5.0861 10000.0000 33.1689 48.8425 16.5507 27.5661 21.5191 21.0488 10100.0000 28.3097 82.6291 29.0285 64.4564 39.1436 31.0242 10200.0000 39.1608 183.5495 23.0325 31.8168 21.6564 18.5273 10300.0000 121.5748 120.2561 29.4449 41.4364 44.9797 34.3891 10400.0000 99.2388 48.7320 28.9876 40.9261 27.3496 21.9218 10500.0000 29.5161 107.1103 28.1284 59.8038 31.9950 26.5498 10600.0000 -999.2500 64.7775 22.6551 48.2166 36.9905 37.0829 10700.0000 29.8547 114.4427 30.8084 66.6615 43.6336 40.2110 10800.0000 25.5885 163.3305 23.8130 54.6959 37.5283 36.1297 10900.0000 40.3201 150.5874 26.2813 74.8871 45.8872 43.1967 11000.0000 89.0389 139.1339 27.0093 56.0419 40.7467 35.2692 11100.0000 33.6425 138.8528 29.2612 57.3969 44.1555 40.8410 11200.0000 29.4998 102.7209 28.6125 66.7390 49.7869 45.8926 11242.0000 -999.2500 72.9703 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9486.000000 Tape File End Depth = 11242.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9566.0000 11.2000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9566.5000 107.1902 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 49.5709 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 87.8456 23.2566 42.5100 326.5988 128.9982 103.2849 9800.0000 28.5946 97.1988 10.6988 12.3420 10.8264 9.8617 9900.0000 31.8974 61.5966 5.5759 5.2157 4.8568 4.2958 10000.0000 38.6034 48.8425 16.8690 29.5664 25.1260 27.0012 10100.0000 22.9385 82.6291 29.8125 67.0780 47.8420 41.4290 10200.0000 37.2977 183.5495 24.3782 35.1194 32.2894 29.9323 10300.0000 136.8120 120.2561 27.5744 54.6409 49.1911 49.8576 10400.0000 111.1484 48.7320 25.9914 34.4413 44.9473 45.1109 10500.0000 32.2580 107.1103 27.8695 51.3553 40.1842 36.2222 10600.0000 73.1820 64.7775 25.4228 51.4549 41.7700 41.2822 10700.0000 26.7668 114.4427 30.7372 65.6414 50.7799 45.8873 10800.0000 24.8359 163.3305 25.8084 58.9713 44.0590 40.6295 10900.0000 35.7577 150.5874 26.9977 66.7926 47.6249 43.3531 11000.0000 117.1819 139.1339 27.3980 43.8846 28.4928 23.4689 11100.0000 54.4492 138.8528 28.9476 60.1075 44.5265 39.8983 11200.0000 31.0131 102.7209 28.0408 61.4275 43.8862 40.5755 11300.0000 36.4412 107.1600 5.7902 5.0152 4.9646 4.6982 11366.0000 -999.2500 126.5396 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9566.000000 Tape File End Depth = 11366.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet n • w Tape Subfile 4 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9568.0000 11.2000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9568.2500 104.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 44.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 100.1000 21.8000 45.6360 6064.5400 220.1330 171.0280 9800.0000 26,7000 88.1000 11.2150 12.8230 10.8840 9.5460 9900.0000 24.6000 87.1000 4.5550 3.0630 3.1060 2.5710 10000.0000 140.9000 40.2000 14.8090 24.3300 21.4220 23.2240 10100.0000 23.7000 83.8000 29.5470 65.5010 47.8420 42.2860 10200.0000 45.7000 89.9000 24.1240 33.8870 29.0280 25.8990 10300.0000 137.2000 120.2000 28.7920 46.1650 37.8070 34.3910 10400.0000 154.9000 56.8000 32.0610 42.9720 24.3330 18.2610 10500.0000 39.4000 117.6000 28.2780 54.6890 42.0680 38.3290 10600.0000 45.2000 82.0000 23.0870 47.8560 41.5120 44.1870 10700.0000 40.5000 123.1000 31.1740 65.8620 44.9300 39.0610 10800.0000 27.1000 118.6000 25.6450 55.1970 42.3570 39.8150 10900.0000 33.4000 137.0000 26.4180 70.4600 50.8480 47.6550 11000.0000 44.8000 108.0000 26.1610 53.5110 46.1840 43.8680 11100.0000 33.5000 138.2000 28.1250 56.8550 45.0460 41.3400 11200.0000 27.6000 144.0000 29.0490 70.0370 49.9020 46.8440 11300.0000 70.1000 101.3000 10.8090 13.7200 12.9010 12.8180 11375.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9568.000000 Tape File End Depth = 11375.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * ~ Tape Subfile 5 is type: LIS DEPTH GR (0001) GR (0002) ROP RAD (0001) RAD (0002) RAS (0001) RAS (0002) RPD (0001) RPD (0002) RPS (0001) RPS (0002) 9487.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9487.5000 68.9410 68.8334 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 62.9243 62.7832 -999.2500 0.3037 0.3081 1.4761 1.5988 0.0839 0.0837 0.0811 0.0831 9600.0000 49.8881 50.1026 -999.2500 2104.2510 2029.1018 5855.4541 5646.3682 0.1001 0.1152 15.5239 15.0556 9700.0000 106.0773 107.3562 23.2566 26.7828 26.2981 4217.3574 3953.4746 147.9511 144.8314 132.2086 130.4056 9800.0000 36.5288 36.9346 97.1988 10.7993 10.7793 12.6520 12.6347 10.8726 10.8442 10.2169 10.2069 9900.0000 30.2270 30.1673 61.5966 5.1729 5.0568 4.9730 4.7086 4.5641 4.3139 4.0790 3.7643 10000.0000 43.4982 38.4344 48.8425 16.1898 16.3011 26.9916 27.1523 22.3392 22.1124 22.6699 22.2147 10100.0000 28.0990 28.1495 82.6291 29.0677 29.0484 64.0114 64.1056 38.0367 38.3224 30.2920 30.4767 10200.0000 36.9411 36.8063 183.5495 24.0118 24.1225 35.1593 35.4149 25.9868 26.4760 22.1947 22.6955 10300.0000 126.7430 127.7620 120.2561 28.4887 28.2958 43.8719 44.3601 41.8819 41.2491 34.5017 34.5148 10400.0000 73.9431 68.4315 48.7320 28.5882 28.5021 38.1706 37.5764 28.0079 28.1498 23.5063 23.8480 10500.0000 28.1831 28.2971 107.1103 28.4151 28.5197 59.6872 59.6467 32.2064 32.2799 26.7365 26.8013 10600.0000 -999.2500 -999.2500 64.7775 22.8086 22.8357 50.0670 50.3627 36.9278 36.9059 36.8425 36.7766 10700.0000 31.7958 31.2585 114.4427 31.0468 30.9808 65.8622 66.0834 42.9811 43.1617 39.1756 39.4622 10800.0000 25.6731 25.792E 23.9185 54.7867 54.9148 36.1427 36.1610 10900..0000 41.0986 40.9928 26.7683 72.0345 71.5984 42.0721 41.8991 11000.0000 73.9430 70.7751 26.7007 53.5360 53.3637 35.4552 34.7194 11100.0000 33.4446 33.3705 29.3646 58.1970 58.4965 40.7828 40.7610 11200.0000 30.1416 30.5651 28.5177 66.9254 67.0484 45.8111 45.7573 11240.0000 -999.2500 -999.2500 -999.2500 42.8339 -999.2500 28.7508 -999.2500 Tape File Start Depth = 9487.000000 Tape File End Depth = 11240.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 163.3305 37.7004 150.5874 45.5503 139.1339 40.5578 138.8528 44.2867 102.7209 49.6254 109.8323 32.2829 23.8567 37.9433 26.7100 45.4928 26.7448 39.6791 29.3365 44.3358 28.5554 49.5189 24.0825 -999.2500 • Tape Subfile 6 is type: LIS