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204-030
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-24A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-030 50-029-20744-01-00 11442 Conductor Surface Production Liner Liner 9032 79 2560 9660 315 2047 10185 20" 13-3/8" 9-5/8" 7" 3-1/2"x3-3/16"x2-7/8" 8856 34 - 113 33 - 2593 32 - 9692 9398 - 9714 9395 - 11442 34 - 113 33 - 2593 32 - 8461 8203 - 8479 8174 - 9032 10484 470 2670 4760 7020 13890 10185 1490 5380 8670 8160 13450 9906 - 11380 4-1/2" 12.6# x 5-1/2" 17# L-80 L-80 29 - 9447 8638 - 9021 Structural 4-1/2" Baker SAB Perm , 9347 , 8159 No SSSV 9361 8171 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 29 - 8246 262 1074 26032 51465 29 1 0 0 844 825 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 9361 , 8171 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:10 pm, Sep 18, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.18 13:01:05 - 08'00' Bo York (1248) DSR-9/27/24WCB 10-3-2024 RBDMS JSB 092724 ACTIVITYDATE SUMMARY 8/17/2024 ***WELL S/I ON ARRIVAL*** DRIFTED w/ 2.25'' CENT, 1' x 1-3/4'' STEM, 2.29'' SWAGE (cibp drift) DRIFT CLEAN TO DEVIATE OUT @ 10440' SLM w/ NO ISSUES ***WSR CONT ON 8-18-24*** 8/18/2024 ***WSR CONT FROM 8-17-24*** DRIFTED w/ 22' x 2'' DUMMY GUNS (max swell 2.29'' o.d) BOBBLE THRU ~9400' SLM, DEVIATE OUT @ 10,449' SLM ***JOB COMPLETE, WELL LEFT S/I*** 8/21/2024 *** WELL S/I ON ARRIVAL*** (PLUG SET / ADPERF) MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WLVS CORRELATE TO SLB BHCS DATED 05-JUN-82 SET NS EXTENDED RANGE CIBP AT 10,150'. CCL TO MID ELEMENT=15.8' CCL STOP DEPTH= 10134.2' PLUG TESTED TO 750PSI RIH WITH PERFORATING GUN AND TAGGED PLUG, FOUND IT HAD SLIPPED TO 10484', WILL RETURN TO SET ANOTHER PLUG POOH LAY DOWN FOR EVENING *** JOB CONTINUES ON 22-AUG-24 WSR*** 8/21/2024 ***Assist E-line*** (Testing plug and perfs) initial WHP T/IA/OA= 2100/1000/0 loaded TBG with 160 bbls Crude/ 3 bbls spear 60/40, tested plug to 750 psi took 8 bbls crude to reach pressure, Plug ended up moving further down hole, job put on hold till next day, Final WHP T/IA/OA= 150/1000/0 ***Well left in Yellow Jackets control*** 8/22/2024 TFS U4 (Assist Eline) Standby as pump contingency 8/22/2024 **** CONTINUE JOB FROM 21-AUG-24 **** (PLUG SET / ADPERF) PT PCE 300 PSI LOW./3000 PSI HIGH RIH WITH PLUG AND CORRELATE TO SLB BHCS DATED 05-JUN-82 SET NORTHERN SOLUTIONS EXTENDED RANGE CIBP AT 10,185' CCL TO MID ELEMENT=15.8' CCL STOP DEPTH= 10169.2'. TAG PLUG AFTER SET TEST PLUG TO 600PSI, RETAG AFTER TEST PERFORATE 9906' - 9926' WITH 2" 6SPF 60PHASE HSC WITH GEO RAZOR CHARGES CCL TO TOP SHOT: 8.4". CCL STOP DEPTH 9897.6'. CONFIRM SHOTS FIRED RDMO YJT E-LINE *** WELL S/I ON DEPARTURE *** JOB COMPLETE Daily Report of Well Operations PBU 02-24A PERFORATE 9906' - 9926' SET NORTHERN SOLUTIONS EXTENDED RANGE CIBP AT 10,185' CIBP and adperfs are correctly shown on WBS, below. -WCB Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/17/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU F-46 50029224500000 194027 4/13/2024 READ CaliperSurvey PBU 02-21B 50029207810200 211033 2/26/2024 BAKER MRPM PBU 02-24A 50029207440100 204030 2/25/2024 BAKER MRPM Please include current contact information if different from above T38715 T38716 T38717PBU 02-24A 50029207440100 204030 2/25/2024 BAKER MRPM Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.19 13:29:38 -08'00' 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Wednesday, November 22, 2023 11:27 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Bo York Subject:UNDER EVALUATION: Producer 02-24A (PTD #2040300) Sustained IA casing pressure over NOL Attachments:02-24.docx Mr. Regg, Producer 02‐24A (PTD # 2040300) IA pressure exceeded NOL to 2112 psi while the well was shut in during slickline intervention on 11/22. Subsequent IA bleed and monitoring shows 20 psi / hour re‐pressurization. The well is now classified as UNDER EVALUATION and is on a 28 day clock to be resolved. Plan Forward: 1.Fullbore / Slickline: Load & set TTP, MIT‐T & CMIT‐TxIA 2.Well Integrity: Further diagnostics as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 16, 2022 9:46 AM To: David Bjork <David.Bjork@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBE FS1 DS Operators <FS1DrillsiteOperators@hilcorp.com>; PBE FS1 Field Lead Operator <PBEFS1FieldLeadOperator@hilcorp.com>; PBE FS1 Foreman <PBEFS1Foreman@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Bo York <byork@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer 02‐24A (PTD #2040300) RWO complete All, Producer 02‐24A (PTD # 2040300) had a RWO completed on 08/16/22. A subsequent MIT‐T passed to 3240 psi and MIT‐ IA passed to 3300 psi. The passing MITs confirm two competent barriers and the well is now classified as OPERABLE. Slickline still has to pull the TTP, B&R and set a LGLV design before the well can be brought online. Please respond with any questions. 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. PBU 02-24APTD 2040300 2 Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: AK, GWO DHD Well Integrity Sent: Thursday, December 22, 2016 6:24 AM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS FS1 OSM <AKOPSFS1OSM@bp.com>; AK, OPS FS1 Facility OTL <AKOPSFS1FacilityOTL@bp.com>; AK, OPS FS1 Field OTL <AK_OPSFS1FieldOTL@bp.com>; AK, OPS FS1 DS Ops Lead <AKOPSFS1DSOpsLead@bp.com>; AK, OPS FS1 DS1 Operator <AKOPSFS1DS1Operator@bp.com>; G GPB FS1 Drillsites <ggpbfs1drillsites@BP.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS Prod Controllers <sewellcr21@bp.com>; Stone, Christopher <Christopher.Stone@bp.com> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Producer 02‐24A (PTD #2040300) Tubing x IA Communication All, Producer 02‐24A (PTD #2040300) was confirmed to have tubing x inner annulus communication. The well is reclassified as Not Operable and has been secured with a down hole plug. Work Completed: 1. Slickline: Set tubing tail plug – DONE 12/21/16 2. Fullbore: CMIT‐TxIA – PASSED 12/21/16 Please call with any questions or concerns. Ryan Moore Well Integrity / Down Hole Diagnostics (907) 659-5525 Office (805) 550-5342 Cell Harmony # 5415 Alternate: Josh Prowant 3 From: AK, GWO SUPT Well Integrity Sent: Wednesday, November 30, 2016 5:45 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS1 Operator; G GPB FS1 Drillsites; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; Stone, Christopher Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; 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 02-24A (PTD #2040300) Failed TIFL All, Producer 02‐24A (PTD #2040300) failed a TIFL on 11/27/16, indicating a lack of two competent well barriers. The well does not require gas lift to flow, but cannot be readily dummied off due to one of the live gas lift valves having a broken latch. The well is reclassified as Under Evaluation, and is on a 28 day clock for diagnostics and repair. Plan Forward: 1. Downhole Diagnostics: TIFL – Failed 11/27 2. Anchorage PE: Plan Forward 3. Well Integrity Engineer: Additional diagnostics as required As the IA Normal Operating Limit (formerly MOASP) was not exceeded, no notification to the AOGCC is required. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659‐5102 C: (907) 943‐0296 H: 2376 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. By Anne Prysunka at 9:58 am, Sep 02, 2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 02-24A JBR 08/30/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested with 4 1/2" and 5/1/2" Test joints, Tested all gas alarms and PVT's. Precharge Bottles 16 total, 7@900psi, 1@925psi, 1@940psi, 4@950psi, 1@960psi, 2@975psi Test Results TEST DATA Rig Rep:Brandon StifflerOperator:Hilcorp North Slope, LLC Operator Rep:Arvell Bass Rig Owner/Rig No.:Hilcorp Thunderbird 1 PTD#:2040300 DATE:8/13/2022 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB220815144208 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 2447 Sundry No: 321-204 CLOSURE TIME (sec) Time/Pressure P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 4 1/2"x7"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1550 200 PSI Attained P25 Full Pressure Attained P138 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P3@2167 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 9 9 9 999 9 9 9 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. From:Rixse, Melvin G (OGC) To:David Bjork Cc:DOA AOGCC Prudhoe Bay Subject:20220705 1001 APPROVAL BOPE Stack change Sundry 321-204 PBU 02-24A RWO PTD204-030 Date:Tuesday, July 5, 2022 10:04:47 AM David, Hilcorp is approved to change the BOPE stack as described below for well work on approved Sundry 321-204. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inpsectors From: David Bjork <David.Bjork@hilcorp.com> Sent: Tuesday, June 28, 2022 2:58 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 02-24A RWO PTD: 204030 Mel, 02-24A RWO sundry updates. We will be using the Cameron U Type BOP’s vs the Integrated Shaffer style as originally sundried. The Ram sizing will be 3-1/2” x 6” VBR’s. We will test with a 5-1/2” and 4-1/2” test joint. If a work string run is required we will swap and test accordingly. Regards, Dave Bjork FS1 OE 564-4672o 440-0331c 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. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:204-030 6.API Number:50-029-20744-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028308 Property Designation (Lease Number):10. 8. PBU 02-24A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11442 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9032 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9361 / 8171 No SSSV Installed Date: Liner 2047 3-1/2"x3-3/16"x2-7/8"9395 - 11442 8174 - 9032 13450 13890 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 33 - 2593 33 - 2593 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 113 Structural 8670 Proposal Summary 13. Well Class after proposed work: 5-1/2" Baker SAB 11230 - 11380 9011 - 9021 5-1/2" 17# L-80 29 - 9347 Liner 9383 8190 9384 none 34 - 113 470 13-3/8" 9-5/8" Contact Phone:(907)564 - 4672 Date: 4/21/2021 4760 79 149020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2560 5380 Production 9660 32 - 9692 32 - 8461 315 7"9398 - 9713 8203 - 8479 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2447 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 6-16-21 55 By Samantha Carlisle at 8:20 am, Apr 22, 2021 321-204 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.21 14:55:47 -08'00' Bo York BOPE test to 3000 psi. Annular to 2500 psi. SFD 4/22/2021 DSR-4/22/21 10-404 MGR22APR2021 2447 Yeption Required? Comm. 4/23/21 dts 4/22/2021 RBDMS HEW 4/23/2021 RWO 02-24A PTD: 2040300 Well Name:02-24A API Number:500292074401 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:06/16/2021 Estimated Duration:5 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:2040300 First Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer:Ryan Thompson 907-564-5280 907-301-1240 AFE Number:215-01272 IOR 120 Current Bottom Hole Pressure:3,327 psi @ 8,800’ TVD 7.3 PPGE | Offset producer 02-38a - 11/19 Max. Anticipated Surface Pressure:2,447psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:800 psi (Taken on 12/21/16) Min ID:2.313” ID liner top packer @ 9,384’ MD Max Angle:42 Deg @ 6,500’ Brief Well Summary: 02-24A is a Z2B slant producer that was originally drilled in ’82 and CTD sidetracked in 2004. It had two tubing patches installed in ’13 and stayed online until 2016. The original tubing is not worth patching again. We will pursue a RWO to replace the L-80 tubing. Objective: Pull the existing 5 ½” L80 tubing out of the well and replace with 4-1/2” 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work: SL - Pull 55KB patches Pull dmy valve from 9,278’ DHD – MIT OA – 1,200 psi CMIT-TxIA to 3,000-psi. Run Eline LDL if failing. Cycle LDS’s PPPOT-T PPPOT-IC EL – Cut tubing @ ~ 9,345’ Circ out well to 8.5ppg 1%KCl w/ diesel FP on T & IA. DHD - Bleed WHP’s to 0 Valve Shop – Set and test ISA BPV Nipple Down Tree and tubing head adapter. Inspect lift threads. Install ISA blanking plug. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO 02-24A PTD: 2040300 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 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 5 ½” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull Blanking Plug and ISA BPV 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~140K. Circulate bottoms up. 5. Pull 5 1/2” tubing 6. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on the proposed schematic. 7. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl. 8. Drop ball and rod and set packer with 3,500-psi pump pressure. 9. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 10. Shear valve in upper GLM. 11. Set TWC 12. Rig down Thunderbird #1. Post rig valve shop work 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. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer. Pull XX plug from 9,384’. 3. RDMO & pop well Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO 02-24A PTD: 2040300 Current Wellbore Schematic RWO 02-24A PTD: 2040300 Proposed Wellbore Schematic RWO 02-24A PTD: 2040300 RWO BOPs NOT OPERABLE: Producer 02 -24A it #2040300) Tubing Leak Found Page f'{ • iTY1,-- Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Saturday, September 10, 2011 8:58 AM f Re'el qii To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Russell, James Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Reynolds, Charles (Alaska) Subject: NOT OPERABLE: Producer 02 -24A (PTD #2040300) Tubing Leak Found All, Producer 02 -24A (PTD #2040300) was logged with a Tecwel LDL and a leak was confirmed at 6304' in the tubing. The well is currently secured with a plug and passed a CMIT -TxIA. The well is reclassified as Not Operable and should remain shut in until repaired. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells ' �y(;,+ / � ' ' Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, August 28, 2011 3:11 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS acility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Leaf AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East A -Ils Opt Engr; Russell, James Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer 02 -24A (PTD #2040300) TxIA Communication All, Producer 02 -24A (PTD #2040300) has confirmed sustained I casing pressure due to TxIA communication. The wellhead pressures were tubing /IA/O • -qual to 791/2240/100 on 8/26/2011. A TIFL failed on 8/27/2011. The well has been reclassified as U •er Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Proposed plan forward: 1. E -Line: Leak Detect Log (LDL) 2. WIE: Pending results of LDL, determine if •as lift valve change out or patch remediation is appropriate. A TIO plot and welibore schematic hav- been included for reference. « File: Producer 02 -24A (PTD # 040300) TIO Plot.doc» Please call if you have any que- ions or concerns. 9/12/2011 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r )50 0 D-)9 1 August 22, 2011 • Mr. Tom Maunder W Alaska Oil and d Gas Conservation Commission ��� ` 333 West 7 Avenue 4r0/� �� 6, Anchorage, Alaska 99501 4Jy l,' Subject: Corrosion Inhibitor Treatments of GPB DS -02 4h 81"&§19 Dear Mr. Maunder, vo Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top 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 02 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -068 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -088 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -178 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -188 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -228 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -328 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -338 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -348 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -358 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02-40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 I I UNDER EVALUATION: Producer 02,A (PTD #2040300) TxIA Communion Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, August 28, 2011 3:11 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Russell, James Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer 02 -24A (PTD #2040300) TxIA Communication Attachments: Producer 02 -24A (PTD #2040300) TIO Plot.doc; 02 -24A (PTD #2040300) wellbore schematic.pdf All, Producer 02 -24A (PTD #2040300) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/TA/OA equal to 791/2240/100 on 8/26/2011. A TIFL failed on 8/27/2011. The well has been reclassified as Under Evaluation. I he well may remain online while work is conducted to attempt to restore integrity. Proposed plan forward: 1. E -Line: Leak Detect Log (LDL) 2. WIE: Pending results of LDL, determine if gas lift valve change out or patch remediation is appropriate. — A TIO plot and wellbore schematic have been included for reference. «Producer 02 -24A (PTD #2040300) TIO Plot.doc» «02 -24A (PTD #2040300) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, sdP 3z.6 t off `t f Gerald Murphy (alt. Mehreen Vazir) 114,e- Well Integrity Coordinator Office (907) 659 -5102, rte ,.: Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/30/2011 PBU 02 -24A PTD #2040300 8/28/2011 TIO Pressures Plot Well: 02 -24 4,000 — i • 9 i 3,000 I I 1 9 a --.— T bg —E- IA 2,000 ____ 00 4 000A 1 I 1,000 .• 1 i .1. 06/04111 06/18/11 07/02/11 07/16/11 07/30111 08/13/11 08127/11 0 TREE = 5 FMC • OFEfY NOTES: WELLHEAD = FMC 02-24A ACTUATOR = AXELSON KB. ELEV = 64' _ BF. ELEV = KOP = 3100' I 1994' H5-1/2" CAM BA L-0 SSSV NIP, ID = 4.562" I Max Angle = 42° @ 6500' GAS LIFT MANDRELS Datum MD = 10197' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TV D = 8800' SS 1 2706 2706 2 CAMCO DOME RK 16 05/20/04 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" I 79' 2 4754 4568 39 CAMCO DOME RK 16 05/20/04 3 6438 5844 42 CAMCO DMY RK 0 113 -3/8" CSG, 72 #, L -80, ID = 12.347" . 1 — j 2593' 1-4 IL 4 7696 6791 39 CAMCO DOME RK 16 05/20/04 5 8375 7333 35 CAMCO DMY RK 0 Minimum ID = 2.440" @ 10485' 6 8453 7397 34 CAMCO DMY RK 0 3 -3/16" X 2 -7/8" X0 • • 7 8780 7670 32 CAMCO DMY RK 0 8 8857 7735 32 CAMCO SO RK 22 02/23/11 9 9200 8030 29 CAMCO DMY RK 0 125' HES DWP PATCH, ID = 2.987" (06/22/11) H 5782' - 5807' 10 9278 8098 29 CAMCO DMY RK 0 9347' H 5 -1/2" BAKER PBRASSY 1 1`, 1� 9361' J- 19 -5/8" X 5 -1/2" BKR SAB PKR ( 5-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 1-I 9373° 9373' _1- 15 -1/2" X 4 -1/2" XO, ID = 3.958" I (LTPASSEMPLY, ID= 2.31" (06/14/11) 1 1 9384' .:, ■ ►�- 9395' -{ TOP OF CEMENT I 9 -5/8" X 7 "" BKR LNR HGR w / TIEBACK H 1 9398' k � 9395' 1 -13.7" BKR DEPLOYMENT SLV, ID = 3.0" 1 1 IA - 9414' - 13 -1/2" HES X NIP, ID = 2.813" I 4 ►/ r 9435' '- 4 -1/2" CAM DB -5 LDG NIP, j ,j MILLED ID = 3.80" (BEHIND CT LNR) ■ ► 1 4 -1/2" TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" H 9447' ' j 9447' 1- 14 -1/2" BKR SHROUT SUB BEHIND CT LNR) 4 MI 9447' -- 14 -1/2" TUBING TAIL (BEHIND CT LNR) 1 13 -1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.990" I 9635' ir ∎ "?' ► • � • ■ • ►: � ►� 9418' I-{ ELMD -TT LOGGED 06/14/82 (BEHIND CT LNR) 1 V; •� 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1 9692' % % : %% 9635' 1--1 -112" X 3- 3/16" XO, ID = 2.786" 1 "SW = C, B Zoe : *40 ' �• ►i4 ■ i ♦• ♦•• 1TOPOF WHIPSTOCK 1 9710' # i ' ;' • + MILLOUT WINDOW (02 -24A) 9714' - 9720' • 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" 1 - 9720 , 7 fttri. ;Si ERFORATION SUMMARY . .. REF LOG: BHCS ON 06/05/82 10485' 1-13- 3/16" X 2 -7/8" XO, ID = 2.440" 1 ANGLE AT TOP PERF: 87° @ 11230' SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11230 - 11380 0 05/15/04 11406' -1 PBTD 1 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.800" H 10485' 1 IA 12 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.441" Fl 11442' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06114/82 RWN 35 ORIGINAL COMPLETION 06/20/11 MLM/ PJC SET X PLUG (6/14/11) WELL: 02 -24A 05/15/04 NORDIC 1 CTD SIDETRACK (02 - 24A) 06/26/11 JCM/ PJC SET HES PATCH (06/22/11) PERMIT No: '2040300 05/20/04 RMH/KAK GLV C/O 07/28/11 DAV/ PJC PULL X PLUG (06/30/11) API No: 50- 029- 20744 -01 03/05/11 MJC /PJC GLV C/O (02/23/11) SEC 36, T11 N, R14E, 1799' FNL & 36' FWL 03/09/11 BSEJPJC SET XX PLUG (03/07/11) 06/15/11 MLM/ PJC PULL XX/ SET LTP (6/14/11) BP Exploration (Alaska) OPERABLE: Producer 02 -24A (PTD #440300) Tubing Integrity Restored Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.comJ-7 Sent: Monday, August 01, 2011 2:32 PM � g /zf To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Russell, James Subject: OPERABLE: Producer 02 -24A (PTD# 2040300) Tubing Integrity Restored Attachments: 02 -24A TIO 07- 20- 11.doc; 02 -24A Schematic.pdf All, Producer 02 -24A (PTD #2040300) passed a TIFL on 7/30/2011 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 *MOW AUG 0 3 201' Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, July 20, 2011 7:02 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS 'S1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operatic) Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Townsend, S. Eliot; Reynolds, Charles (ALAS,,-); Rico Hernandez, Claudia; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 02 -24A (PTD# 2040300) Sustained casing '- -ssure on the IA All, Producer 02 -24A (PTD# 2040300) has been found to -ve sustained casing pressure on the IA during shutdown activity. On 07/19/11, the wellhead press. res were tubing /IA/OA equal to SSV /2270/0 psi. The well has been reclassified as Under Evaluation a d has been brought online for further diagnostics. The plan forward is as follows: 1. DHD: TIFL 2. Slickline: C/O GLV (if TIFL fails) 3. DHD: Re -TIFL A TIO plot and wellbore sche .tic have been included for reference. «02 -24A TIO 07- 20- 11.doc> «02 -24A Schematic.pdf» Thank you, 8/2/2011 PBU 02 -24A PTD 2040300 8/1/2011 TIO Pressures Plot Well: 02 - 24 4,000 — I I i 3,000 - • " Z rb9 It IA ■ I 2,000 &— OA 00A 1 OOOA —0 1 I I I 1 1,000 - _ ! 08/0'10 09/03/10 10/04/10 11/04/10 12/05/10 01/05/11 0 031051'11 04/08/11 05109)11 06/09/'91 07/'10/11 • TREE = ` 5 -1 /8" FMC • OETY NOTES: WELLHEAD = FMC 02-2 4 ACTUATOR = AXELSON KB. ELEV = 64' KOP = 3100' I 1994' H5-1/2" CAM BAL -O SSSV NIP, ID = 4.562" I Max Angle = 42° @ 6500' GAS LIFT MANDRELS Datum MD = 10197' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TV D = 8800' SS 1 2706 2706 2 CAMCO DOME RK 16 05/20/04 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" I 79' 2 4754 4568 39 CAMCO DOME RK 16 05/20/04 3 6438 5844 42 CAMCO DMY RK 0 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2593' 1--41 4 7696 6791 39 CAMCO DOME RK 16 05/20/04 5 8375 7333 35 CAMCO DMY RK 0 Minimum ID = 2.440" @ 10485' 6 8453 7397 34 CAMCO DMY RK 0 3-3/16" X 2-7/8" X0 11 I 7 8780 7670 32 CAMCO DMY RK 0 8 8857 7735 32 CAMCO SO RK 22 02/23/11 9 9200 8030 29 CAMCO DMY RK 0 125' HES DWP PATCH, ID= 2.987" (06/22/11) I--1 5782' - 5807' 10 9278 8098 29 CAMCO DMY RK 0 9347' - 15 -1/2" BAKERPBRASSY I 1331 ►Z 9361' J- 1 9-5/8" X 5 -1/2" BKR SAB PKR I 15 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 1-L 9373' I _, � , L 9373' H5-1/2" X 4 -1/2" XO, ID = 3.958" 1 LTPASSEMPLY, ID =2.31 „ (06/14/11) 9384 j � , 9395' -'1 TOP OF CEMENT ( 12 -7/8” X PLUG (06/14/11) I 9394' '1 g3g5 --I 3,7" BKR DEPLOYMENT SLV, ID = 3.0" 1 I9 -5/8" X 7" BKR LNR HGR w/ TIEBACK I 9398' 4 N 9414' --13 -1/2" HES X NIP, ID = 2.813" 1 ■ 4 ► 1 1 PI I 9435' I- 4 -1/2" CAM DB -5 LDG NIP, p MILLED ID = 3.80" (BEHIND CT LNR) 0, ► 1 Z ►� 1 4 -1/2" TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" H 9447' j 9447 I- 14 -1/2" BKR SHROUT SUB BEHIND CT LNR) 1 al ,� �� 9447' —14 -1/2" TUBING TAIL (BEHIND CT LNR) 1 • 13 -1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.990" H 9635' j, � • ■ j� I 9418' 1-1 ELMD TT LOGGED 06/14/82 (BEHIND CT LNR) 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I 9692' � :.: o o . ♦0 9635' --13 -1/2" X 3- 3/16" XO, ID = 2.786" 1 ■ ♦t "•♦ I TOP OF WHIPSTOCK I 9710' * • *0 MILLOUT WINDOW (02 -24A) 9714' - 9720' 1 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" I—L -9720 ° PERFORATION SUMMARY I REF LOG: BHCS ON 06/05/82 10485' H 3- 3/16" X 2 -7/8" XO, ID = 2.440" 1 ANGLE AT TOP PERF: 8T' @ 11230' SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11230 - 11380 0 05/15/04 11406' --I PBTD 1 It 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.800" I-i 10485' I [2 -7/8" LNR, 6.16 #, L -80, .0058 bpf. ID = 2.441" I-1 11442' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/14/82 RWN 35 ORIGINAL COMPLETION 06/20/11 MLM/ PJC SET X PLUG (6/14/11) WELL: 02 -24A 05/15/04 NORDIC 1 CTD SIDETRACK (02 -24A) 06/26/11 JCM/ PJC SET HES PATCH (06/22/11) PERMIT No: 1040300 05/20/04 RMH /KAK GLV C/O API No: 50- 029 - 20744 -01 03/05/11 MJC/PJC GLV C/O (02/23/11) SEC 36, T11 N, R14E, 1799' FNL & 36' FWL 03/09/11 BSE/PJC SET XX PLUG (03/07/11) 06/15/11 MLNI/ PJC PULL XX/ SET LTP (6/14/11) BP Exploration (Alaska) UNDER EVALUATION: Producer 02-24A (PTD# 2040300) Sustained casing pressure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 1 -7 Wednesday, 20, 2011 7:02 PM Sent: y, July To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Townsend, S. Eliot; Reynolds, Charles (ALASKA); Rico Hernandez, Claudia; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 02 -24A (PTD# 2040300) Sustained casing pressure on the IA Attachments: 02 -24A TIO 07- 20- 11.doc; 02 -24A Schematic.pdf All, Producer 02 -24A (PTD# 2040300) has been found to have sustai - • - . • • • - - • • e I: during shutdown activity. On 07/19/11, the wellhead pressures were tubing /IA/OA equal to SSV /2270/0 psi. The well has been reclassified as Under Evaluation and has been brought online for further diagnostics. The plan forward is as follows: 1. DHD: TIFL 2. Slickline: C/O GLV (if TIFL fails) 3. DHD: Re -TIFL `5cp ` 35% of A TIO plot and wellbore schematic have been included for reference. uph`ze o k- . - CD «02 -24A TIO 07- 20- 11.doc» «02 -24A Schematic.pdf» Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 AMAX) NY; 7/22/2011 PBU 02 -24A PTD 2040300 7/20/2011 TIO Pressures Plot Well: D2 -24 4.000 - - - ' 3.000 • w� �- Tb -- w 2.000 - - -OOA I t 000A I — On I . room • 1.000 " • • LI--6-1"..,.......11-- 'Ilhil"L L ■ ■ ratillpf l i • , 11111111111111111111 • ' 1 i MI. . Ai all _ - — . 08/03/10 09/03/10 10 /04 /10 71/04/10 12 /05/10 07/05/11 02/05/11 03105/71 04/08/11 05/80/11 06 /09117 07/10/17 • TREE = 5-1/8" FMC 0 02 ®� Ei'Y NOTES: WELLHEAD = FMC 4 ' ACTUATOR = AXELSON KB. ELEV = 64' ( I B OP ELEV 3100' I 1994' 1-15-1/2" CAM BA L-0 SSSV NIP, ID = 4.562" I Max Angle = 42° @ 6500' GAS LIFT MANDRELS Datum MD = 10197' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS 1 2706 2706 2 CAMCO DOME RK 16 05/20/04 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" I 79' 2 4754 4568 39 CAMCO DOME RK 16 05/20/04 3 6438 5844 42 CAMCO DMY RK 0 Pi 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2593° � a 4 7696 6791 39 CAMCO DOME RK 16 05/20/04 5 8375 7333 35 CAMCO DMY RK 0 Minimum ID = 2.440" @ 10485' 6 8453 7397 34 CAMCO DMY RK 0 3- 3/16 X 2 -7/8" XO . . 7 8780 7670 32 CAMCO DMY RK 0 -_. 8 8857 7735 32 CAMCO SO RK 22 02/23/11 9 9200 8030 29 CAMCO DMY RK 0 125' HES DWP PATCH, ID = 2.987" (06/22/11) H 5782' - 5807' 10 9278 8098 29 CAMCO DMY RK 0 • I 9347' H5 -1/2" BAKERPBRASSY I 0.0 ►� 9361' --19 -5/8" X 5 -1/2" BKR SAB PKR I 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 1-L 9373' I � I 9373" 1 X 4 -1/2" XO, ID = 3.958" I LTP ASSEMPLY, ID = 2.31 " (06/14/11) H 9384 ,- - '1 9395' --{TOP OF CEMENT I 12-7/8" X PLUG (06/14/11) FL 9394' j 9395' -- 13.7" BKR DEPLOYMENT SLV, ID = 3.0" I 19 -5/8" X 7" BKR LNR HGR w / TIEBACK H 9398' 4 1 9414' 1--13 -112" HES X NIP, ID = 2.813" I ■ 0 I 9435' I - I 4 -1/2" CAM DB -5 LDG NIP, MILLED ID = 3.80" (BEHIND CT LNR) 4 -1/2" TBG, 12.6 #, N-80, .0152 bpf, ID = 3.958" H 9447' j 9447' �1 14 - 1/2" BKR SHROUT SUB BEHIND CT LNR) I 13 -1/2" LNR, 8.81 4, L -80, .0087 bpf, ID = 2.990" H 9635' ir: k I 9447' H4 -1/2" TUBING TAIL (BEHIND CT LNR) I • 4 ►� .�j I 9418' 1 - 1 ELMD - LOGGED 06/14/82 (BEHIND CT LNR) I ‘ '.4: • .4'., 1 9 - 5/8" CSG, 47 #, L - 80, ID = 8.681" I 9692' i0 j•' •�* 4 • 9635'i X 3- 3/16" XO, ID = 2.786" I 4L( P = - ?o r5; ► p . 1 . . � • ► ♦. . 'TOP OF WHIPSTOCK 1 9710' �` X 40 0 MILLOUT WINDOW (02 - 24A) 9714' - 9720' 1 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" I - 9720 71,‘ 713 06 , A13 `‘*t PERFORATION SUMMARY REF LOG: BHCS ON 06/05/82 10485' 1 - I 3- 3/16" X 2 -7/8" XO, ID = 2.440" I ANGLE AT TOP PERF: 87° @ 11230' SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11230 - 11380 0 05/15/04 11406' - 1 PBTD I 3- 3/16" LNR, 6.24, L -80, .0076 bpf, ID = 2.800" H 10485' I +s 2 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.441" I--1 11442' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/14/82 RWN 35 ORIGINAL. COMPLETION 06/20/11 MLM/ PJC SET X PLUG (6/14/11) WELL: 02 -24A 05/15/04 NORDIC 1 CTD SIDETRACK (02 - 24A) 06/26/11 JCM/ PJC SET HES PATCH (06/22/11) PERMIT No: 2040300 05/20/04 RMH/KAK GLV C/O API No: 50- 029 - 20744 -01 03/05/11 MJC/PJC GLV C/O (02/23/11) SEC 36, T11 N, R14E, 1799' FNL & 36' FWL 03/09/11 BSE/PJC SET XX PLUG (03/07/11) 06/15/11 MLM/ PJC PULL XX/ SET LTP (6/14/11) BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other o TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ 5782' / 5807' Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IO Exploratory ❑ 1es 204 -030 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 •• 50- 029 - 20744 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028308 & 028311 PBU 02 -24A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11442 feet Plugs (measured) None feet true vertical 9032 feet Junk (measured) None feet Effective Depth measured 11407 feet Packer (measured) 9361 9384 feet true vertical 9025 feet (true vertical) 8171 8191 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 34 - 113 34 - 113 1490 470 Surface 2560' 13 -3/8" 33 - 2593 33 - 2593 5380 2670 Production 9660' 9 -5/8" 32 - 9692 32 - 8461 6870 4760 Liner 315' 7" 9398 - 9713 8203 - 8479 8160 7020 Liner 240' 3 -1/2" 9395 - 9635 8174 - 8411 Liner 850' 3- 3/16" 9635 - 10485 8411 - 8976 Liner 957' 2 -7/8" 10485 - 11442 8976 - 9032 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ A 1 L) JUL 3 201; True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 5 -1/2 ". 17# L -80 29 - 9373 29 - 8181 4 -1/2 ". 12.6# N -80 9373 - 9447 8181 - 8246 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" BKR SAB Packer 9361 8171 Liner To Packer 9384 8191 V : 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Mai) 0 . uM Coo Commission 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 801 39837 38 798 Subsequent to operation: 831 41525 38 805 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development el • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Elizabeth Barker I Printed Name Elizabeth Barker Title Data Manager Signature er: //: f 13 Phone (907) 564 -5674 Date 7/7/2011 Form 10-404 Revised 0 /2010 HBDMS JUL 11 Submit Origin 7 7 •H•li 04 02 -24A 204 -030 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02 -24A 5/14/04 PER 11,230. 11,380. 9,010.76 9,020.95 02 -24A 3/7/11 BPS 9,395. 11,380. 8,200.51 9,020.95 02 -24A 6/30/11 BPP 9,394. 11,380. 8,199.64 9,020.95 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED • MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 02 -24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Ate. 3/6/2011 T/I/0= 2250/2250/Vac Temp= S /I. Assist SSL as directed Load and Kill. (Eval high IAP) Pumped 5 bbls of neat followed by 273 bbls of crude down IA. ** *WSR Continued on 7Mar2011 * ** I i F � 1 t t 3/7/2011 * * * *CONT JOB FROM 3- 6- 11 * * * *(p /t integrity -eval well) LRS LOAD IA W/ 500 BBLS CRUDE & TUBING W/ 290 BBLS KCL -164 BBLS 'CRUDE. 'SET 3 1/2" XX -PLUG (c7 9405' SLM/9414' MD , FW H P= 500/500/0 ;****WELL LEFT TURNED OVER TO LRS ON DEPARTURE FOR MIT -T & CMIT -T IX IA - * * ** 3/7/2011; ** *WSR Continued from 6Mar2011 * ** Assist SSL L &K, MIT -T FAILED to 3000 psi, 'CMIT -TxIA INCONCLUSIVE to 3000 psi (Eval high IAP) Pumped a total of 500 t bbls Crude down IA to Toad. Swapped over to Tbg. Pumped 10 bbl Neat Meth spear followed by 297 bbls 1% KCL down Tubing. Pumped 165 bbls Crude tail ;down Tbg. SSL set plug. MIT -T failed 3 consecutive tests (see pump report). 'Swapped over to IA. Attempted CMIT -TxIA. CMIT -TxIA results inconclusive. } 'Pressure Toss past wing valve on ALL MIT's. PE notified. FWHP's= 500/500/60. DSO notified of well status. Well left shut in upon departure. E € 3/9/2011T/I/0 =290/290/vac. SI. MIT -T and CMIT -TxIA INCOMPLETE Wing not holding (eval TxIA comm). Integral installed on IA. Used 4 bbls to pressure TBG from 290 to 3000 psi. TBG pressure decreased 800 psi in 1st 15 min. Flow line pressure !increased 150 psi to 1850 psi, IAP increased 500 psi. Pump TBG back to 3000 psi, 'Flow line increased to 1900 psi. Tbg pressure decreased 700 psi in the 1st 15 l mins and Flow line increased to 2050 psi, call grease crew to service wing. Pump 1TBG to 3000 psi. In the 1st 15 mins TBG lost 700 psi and Flow line increased to 2100 psi. Wing not holding. During this time IAP increased 1430 psi. Bled TBG from 2280 psi to 250 psi, IAP tracking TBG pressure. Job incomplete. Final i W HPs= 250/270/vac ESV,WV= C,SSV,MV =O. IA,OA =OTG. NOVP • • 3/30/20111T/1/0 = 1200/1200/0. Temp = SI. MIT -T Failed /CMIT -IA Passed. (Eval TxIA !comm). Tubing fluid level near surface. IA FL @ surface. Bled Tubing pressure from 1200 psi to 760 in 9 min (FTS). During tubing bleed IAP decreased 400 psi to 800 psi. Used 6 bbls diesel to pressure tubing from 760 psi to 3000 psi, IAP increased 1140 psi to 1940 psi. Tubing lost 820 psi in 1st 15 min & IAP increased ! !240 psi to 2180 psi. Rig to perform CMIT -IA. Used 2 bbls diesel to pressure up j 'Tubing & IA to 3000 psi. During 1st 15 min tubing decreased 40 psi & IAP `decreased 20 psi, during 2nd 15 min tubing unchanged & IAP decreased 10 psi. Begin & maintain open bleed on IA & perform LLR -T. LLR of 0.19 bpm (8.3 gpm) 'established @ 3000 psi. Bled tubing from 3000 psi to 660 psi. Job complete. Final! ': W HPs = 660/580/0. SV, WV = C. SSV, MV = 0. IA & OA = OTG. NOVP. 4/2/2011 ***JOB CONTINUED FROM 1- APR - 2011 * ** :COMPLETE BASELINE PASS DOWN AT 100 FPM TO PLUG AT 9414'. H LEAK RATE AT APPROX • GA I ■ . • ITORING PLUG. , 'LOG 30 FPM UP PASS FROM 9412 TO SURFACE. LEAK FOUND AT 5794'. FINAL VALVES: WING CLOSED, MASTER OPEN, SSV CLOSED, SWAB CLOSED. I RDMO AND HANDOVER TO DSO. !FINAL T /I /0= 500/0/0. ** *JOB COMPLETE * ** 4/2/2011'T/I/O= 500/500/0 Assist E -line. Continued from 04 -01 -11 wsr. Pump 50 bbls crude down tbg taking returns up IA trying to maintain 3000 psi on tbg while E -line !makes LDL run. FWHP= 1100/0/0. IA & OA open. E -Line still on well upon LRS ! departure. 6/13/2011 ** *WELL S/I ON ARRIVAL ** *(pre patch) :EQUALIZED 3.5" XX PLUG @ 9408' SLM/ 9414' MD, LAY DOWN UNIT FOR THE KNIGHT * * *CONT ON WSR 6- 14 -11 * ** • • 6/14/20113 * * *CONT FROM WSR 6- 13 -11 ** *(pre patch) PULLED 3 1/2" XX PLUG FROM 9408' SLM/ 9414' MD DRIFTED TBG W/ 5 1/2" DMY PATCH, 4.55" MAX O.D., 26' OAL, DRIFTED 1CLEAN TO 5900' SLM, P/U WEIGHT 850# ,BRUSHED TBG FROM TOP OF DEP SLV @ 9395' MD TO X- NIPPLE @ 9408' ;SLM E RAN 3.75" LIB, TAGGEG TOP OF DEP SLV @ 9388' SLM/ 9395' MD, DID NOT ;GET CONCLUSIVE PICTURE 'SET BAKER LTP IN DEP SLV @ 9395' SLM (BOTTOM SEAL ASSY @ 9399' SLM) '. ** *WELL S/I ON DEPARTURE, LRS SPOTTING UP ON WELL ON DEPARTURE TO CMIT- TxIA * ** 6/15/2011 'T /I /0= 120/0/0 ( CMIT Tx IA Failed )WSR continued from 06- 14 -11. Pump 6 bbls ; meth followed by 28 bbls dead crude down IA to achieve a test press. of 3000 Psi. I (CMIT Tx IA to 3000 Psi was Inconclusive. See Log for details.) Bleed Tx IA press. to x psi. RDMO FWHP= 500/0/0. wing =shut / swab =shut / ssv =shut / master=open ;/ IA and OA open to gauges. Operator notified of departure. € j i t 6/16/2011'T/1/0=160/100/0 Temp= SI CMIT TxIA Passed to 3000 psi. (Eval high IA pressure) T/I pressured up to 3040/3060 psi with 18.3 bbls diesel. T/I lost 60/60 psi I in first 15 minutes and 20/20 psi in second 15 minutes. For a total of 80/80 psi in 30 :minutes. Bled pressure down. FWHP's= 60/60/0 (VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open- Well SI t i t E k I I i t 6/21/2011 ! * ** WELL SHUT IN ON ARRIVAL * ** (E -LINE: PATCH SETTING) INITIAL T/I/0 = 0/0/0 PSI INITIAL VALVES CONFIGURATION: SWAB, SSV, WING = CLOSED. MASTER = OPEN (ARRIVED TO LOCATION, HELD SAFETY MEETING, PERFORMED DUAL BARRIER TEST AND STABBED ON THE LUBRICATOR ** *JOB IN PROGRESS * ** TO BE CONTINUED 22- JUN -2011 E � � • 6/22/2011 * ** JOB IN PROGRESS FROM 21- JUN -2011 * ** 'PRESSURE TESTED, HOT CHECKED AND RIH WITH 5 -1/2" HALLIBURTON ;CHROME PATCH. CORRELATED TO PDS LEAK DETECTION LOG DATED IAPRIL-2011 FROM 5840 UP TO THE GLM AT 4754' COUNTING COLLARS IN !ORDER TO NOT PASS 5900' (SL DRIFT DEPTH). 28 COLLARS WERE ;OBSERVED FROM THE GLM TO THE 5840' AND THEN TIE -IN TO THE PDS LDL. PULL INTO SETTING POSITION AT 5786' AFTER CONFIRMING WITH PE CCL TO MID ELEMENT = 14', PATCELMID ELEMENT TO MID ELEMENTJNIERVAL = 5786'- 5806' AND CCL 'STOP DEPTH = 5772', TOP OF PATCH = 5782', BOTTOM OF PATCH =5808' I ID= 2.987 ". LOST 700 LBS AFTER SETTING FINAL VALVES CONFIGURATION: SWAB, SSV, WING = CLOSED. MASTER = OPEN FINAL T /I /O = 0/0/0 PSI ** *JOB COMPLETE ** * WELL LEFT SHUT IN ON DEPARTURE) 6/23/2011 jT /I /0= 20 /10Nac, Temp =S /I, MIT -T PASSED to 3000 psi, CMIT -TxIA PASSED to !3000 psi (Eval high IAP, Post Patch) Pressured up tubing with 6 bbls of diesel to reach 3000 psi. MIT -T lost 30 psi in the 1st 15 minutes and 10 psi in the 2nd 15 minutes for a total of 40 psi in a 30 minute test. Pressured up tubing and IA with 8 bbls of diesel to reach 3000/3010 psi. CMIT -TxIA lost 60/50 psi in 1st 15 minutPs_„ and 20/20 psi in 2nd 15 minutes for a total of 80/70 psi in a 30 minute test. Bled down Tbg and IAP. SV,WV,SSV =SHUT/ MV /IA/OA =OPEN. FWHP's= 100/50/0. I � f 3 f 6/30/2011 ! ** *WELL S/I ON ARRIVAL * ** (post patch) RUN EQ. PRONG, GET RING ON PRONG, SEE NO PRESSURE CHANGE PULL 2 7/8" X PLUG FROM 9394' MD ** *WELL LEFT S/I ON DEPARTURE * ** DSO NOTIFIED E i FLUIDS PUMPED BBLS 21 NEAT METH 297 1% KCL 32.3 DIESEL 1043 CRUDE 1393.3 TOTAL FREE =' ' 5 -1/8" FMC • UYNOTES: 02-24A ACTUATOR = AXELSON KB. ELEV = 64' ' KOP EV 3100' 1 1994' 1 CAM BAL -O SSSV NIP, ID = 4.562" I Max Angle ,= 42° @ 6500' GAS LIFT MANDRELS Datum MD = 10 ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum T V D = 8800' SS 1 2706 2706 2 CAMCO DOME RK 16 05/20/04 120" CONDUCTOR, 91.5 #, H-40, ID = 19.124" 1 79' 2 4754 4568 39 CAMCO DOME RK 16 05/20/04 3 6438 5844 42 CAMCO DMY RK 0 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2593' 1. ' 4 7696 6791 39 CAMCO DOME RK 16 05/20/04 5 8375 7333 35 CAMCO DMY RK 0 Minimum ID = 2.440" @ 10485' 6 8453 7397 34 CAMCO DMY RK 0 3- 3/16" X 2 -7/8" XD 7 8780 7670 32 CAMCO DMY RK 0 8 8857 7735 32 CAMCO SO RK 22 02/23/11 .---. N 9 9200 8030 29 CAMCO DMY RK 0 1 25' HES DWP PATCH, ID = 2.987" (06/22/11) H 5782' - 5807' 10 9278 8098 29 CAMCO DMY RK 0 9347' —15 -1/2" BAKER PBR ASSY 1 � �■ �� *-M, 9361 1 — i 9 -5/8" X 5 -1/2" BKR SAB PKR I 1 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 1-L 9373' 1 1 9373' 1 — I5 - 1/2" X 4 -1/2" XO, ID = 3.958" I LTPASSEMPLY, ID = 2.31" (06/14/11) H 9384' J g L 9395' H TOP OF CEMENT 1 ' '' �1 9395' H3.7" BKR DEPLOYMENT SLV, ID = 3.0" I G // I9 -518" X 7" BKR LNR HGR w /TIEBACK I—I 9398' $ j � 9414' J- -1/2" HES X NIP, ID = 2.813" 1 i ►i 0 0 0 D • t' 9435' 1 — 4 -1/2" CAM DB -5 LDG NIP, 1 j ► MILLED ID = 3.80" (BEHIND CT LNR) i ► 1 1 4 -1/2" TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" 1—L 9447' ■ j 9447' J - 14 - 1/2" BKR SHROUT SUB BEHIND CT LNR) I � 4 � 4 • 9447' H4 -1/2" TUBING TAIL (BEHIND CT LNR) 1 13 -1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.990" H 9635' / • •• I•��,4 ►∎•• — • I 9418' 1-I ELMD -TT LOGGED 06/14/82 (BEHIND CT LNR) I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9692' 141 ,y; ■•y;• • • •' •• • , H3-1/2" X 3- 3/16" XO, ID = 2.786" I • ► •• ■•• ■•• ■•••• ••••• ••, ••• ■•••• ■• ••••• I ■• •• 1 TOP OF WHIPSTOCK H • • � • MILLOUT WINDOW (02 -24A) 9714' - 9720' 1 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" 1--1 — 9720 • •� ' .* PERFORATION SUMMARY REF LOG: BHCS ON 06/05/82 10485' 1 - 13 - 3/16" X 2 -7/8" XO, ID = 2.440" I ANGLE AT TOP PERF: 87° @ 11230' SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11230 - 11380 0 05/15/04 11406' — 1 PBTD 1 13- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.800" 1 — I 10485' 1 ... 12 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.441" 1 - 1 11442' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/14/82 RWN 35 ORIGINAL COMPLETION 06/20/11 MLM/ PJC SET X PLUG (6/14/11) WELL: 02 -24A 05/15/04 NORDIC 1 CTD SIDETRACK (02 -24A) 06/26/11 JCM/ PJC SET HES PATCH (06/22/11) PERMIT No: "2040300 05/20/04 RMH/KAK GLV C/O API No: 50- 029 - 20744 -01 03/05/11 MJC/PJC GLV C/O (02/23/11) SEC 36, T11 N, R14E, 1799' FNL & 36' FWL 03/09/11 BSE/PJC SET XX PLUG (03/07/11) 06/15/11 MLM/ PJC PULL XX/ SET LTP (6/14/11) BP Exploration (Alaska) OPERABLE: Producer 02 -24A (PTD #20300) Tubing Patch Set • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] � Sent: Friday, June 24, 2011 1:25 PM el '7/4 '7/4 rt ' To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Rico Hernandez, Claudia Subject: OPERABLE: Producer 02 -24A (PTD #2040300) Tubing Patch Set All, Producer 02 -24A (PTD #2040300) passed an MIT -T and CMIT -TxIA to 3000 psi on 6/23/2011 after setting a tubing patch to repair TxIA communication. The passing tests verify two competent barriers and the well has been reclassified as Operable. The well will be ready to put back online once Slickline has pulled the TTP currently in the well. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells ,i1; 2 11 Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, March 07, 2011 2;01 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Rico Hernandez, Claudia Subject: NOT OPERABLE: Producer 02-24A (PTD #2040300) Secured w/ a L &K All, Producer 02 -24A (PTD #2040300) failed a TIFL on 03/02 after the IA pressure increased 740 psi on an overnight monitor. The well has been secured with a load a kill and will be reclassified as Not Operable until repaired. The plan forward is as follows: 1. Slickline: Set TTP for secure 2. Pumping: MIT -T & CMIT -TxIA to 3000 psi, LLR if fails 3. Eline: Leak detect log Please call with any questions. Thank you, 7/11/2011 OPERABLE: Producer 02 -24A (PTD #60300) Tubing Patch Set Page 2 of 2 • Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 12, 2011 8:46 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Rico Hernandez, Claudia Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: Producer 02 -24A (PTD #2040300) Sustained IA Casing Pressure Above MOASP All, Producer 02 -24A (PTD #2040300) has been found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA equal to 0/2200/300 on 02/09/11. The well has been reclassified as Under Evaluation and may continue to be produced while efforts to mitigate the communication are completed. The plan forward is: 1. DHD: TIFL 2. Slickline: Change out OGLV, caliper, dependent on result of initial TIFL 3. DHD: Re -TIFL A wellbore schematic and TIO plot have been included for reference. « File: Producer 02 - 24A (PTD #2040300) TIO Plot.doc » Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/11/2011 • WELL LOG TRANSMITTAL S 11. PROAcIivE Diagnos&ic SERVicES, INC. To: DNR Division of Oil & Gas Corazon Manaois 550 West 7th Avenue, Suite 800 Anchorage, Alaska 99501 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and 004 030 C9thc ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C "_ MAY 2 3 201 Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 01-Apr-11 02 -244 BL / EDE 50 -029- 20744 -01 2) Signed : Date : RECEIVED APR =1 ,9 2011 Print Name: Ca c.s..,:.Com PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL : pdsanchoraae(Wmemorvloo.com WEBSITE : WWW.memorvloq.com C:\Documents and Settings\Diane Williams \Desktop\BP Transmit.docx NOT OPERABLE: Producer 02 -24A ( #2040300) Secured w/ a L &K • Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] � 4151 (I Sent: Monday, March 07, 2011 2:01 PM / To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Rico Hernandez, Claudia Subject: NOT OPERABLE: Producer 02 -24A (PTD #2040300) Secured w/ a L &K All, Producer 02 -24A (PTD #2040300) failed a TIFL on 03/02 after the IA pressure increased 740 psi on an overnight monitor. The well has been secured with a load a kill and will be reclassified as Not Operable until repair - 'ee The plan forward is as follows: 1. Slickline: Set TTP for secure 2. Pumping: MIT -T & CMIT -TxIA to 3000 psi, LLR if fails 3. Eline: Leak detect log Please call with any questions. questions. AMAIED MAR 1 8 Z Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 12, 2011 8:46 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L •A)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 • erator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D: ' Wireline Operations Team Lead; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, RE ' 'B West Wells Opt Engr; Rico Hernandez, Claudia Cc: AK, D &C Well Integrity Coordinator; King, Whitney; - 'It, Ryan P (ASRC) Subject: UNDER EVALUATION: Producer 02 -24A (P • #2040300) Sustained IA Casing Pressure Above MOASP All, Producer 02 -24A (PTD #2040300) as been found to have sustained casing pressure on the IA above MOASP. The wellhead pressure: were tubing /IA/OA equal to 0/2200/300 on 02/09/11. The well has been 3/15/2011 UNDER EVALUATION: Producer 044A (PTD #2040300) Sustained IA Cass Pressure Abo... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] '" �� i4�1( Sent: Saturday, February 12, 2011 8:46 PM ,\ To: Maunder, Thomas E (DOA); Regg, James 8 (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Rico Hernandez, Claudia Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: Producer 02 -24A (PTD #2040300) Sustained IA Casing Pressure Above MOASP Attachments: Producer 02 -24A (PTD #2040300) TIO Plot.doc; Producer 02 -24A (PTD #2040300) wellbore schematic.pdf All, Producer 02 -24A (PTD #2040300) has been found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA equal to 0/2200/300 on 02/09/11. The well has been reclassified as Under Evaluation and may continue to be produced while efforts to mitigate the communication are completed. The plan forward is: 1. DHD: TIFL 2. Slickline: Change out OGLV, caliper, dependent on result of initial TIFL �l��� 3. DHD: Re -TIFL A wellbore schematic and TIO plot have been included for reference. «Producer 02 -24A (PTD #2040300) TIO Plot.doc» «Producer 02 -24A (PTD #2040300) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/14/2011 PBU 02 -24A PTD #2040300 2/12/2011 TIO Pressures Plot Well: 02 -24 4,000 • 3.000 - —4}— Tbg --E— IA 2,000 - 111\ OA OOA 0OOA On 1,000 - I 12/18/10 12/25/10 01/01/11 01/08/11 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 TREE = • • ACTUATOR = FMC 02-24A ACTUATOR = AXELSON SAFETY NOTES: MENZIMIIIIIIIIIMI BF. ELEV = KOP = 3100' I 1994' H5-1/2" CAM BAL -O SSSV NIP, ID = 4.562" Max An • le = 42 . 6500' Datum MD= 10147' GAS LIFT MANDRELS Datum TVD = 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2706 2706 2 CAMCO DOME RK 16 0520/04 2 4754 4568 39 CAMCO DOME RK 16 0520/04 3 6438 5844 42 CAMCO DMY RK 0 113 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2593' I--, 16, 4 7696 6791 39 CAMCO DOME RK 16 05/20/04 5 8375 7333 35 CAMCO DMY RK 0 6 8453 7397 34 CAMCO DMY RK 0 7 8780 7670 32 CAMCO DMY RK 0 8 8857 7735 32 CAMCO SO RK 22 05/20/04 9 9200 8030 29 CAMCO 0MY RK 0 10 9278 8098 29 CAMCO DMY RK 0 1 9347' 1 BAKER FBRASSY I - IN 1� -1 9361' H9 -5/8" X5 -1/2" BAKER SAB FKR I 1 5-1/2' TBG, 17 #, L -80, .0232 bpf, 10 = 4.892" H 9373' I I 9373' 1- -1/2" X 4 -1/2" XO I Minimum ID = 2.440" @ 10485' ■ ► 4 I 9395' I- -1TOP OF CEMENT I 3- 3/16" X 2 -7/8" XO '4 ► 9395' H3.7" BKR DEPLOY /VENT SLV, ID =3.0" I 4 9414' H3- 1 /2"HESXNIP,ID2.813 " 9435' 1 - 4 -1 /2" CAM DB -5 LOG NIP, MLLED ID= 3.80" (BEHINDCTLNR) 4 -1/7' TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" 9447' 9447' I I4 -1/7' BKR SHROUT SUB BEHIND CT LNR) I 13-1/2" LNR, 8.81 #, L -80, .0087 bpf, ID= 2.990" 9635' 44 ► �• 9447' 4 -1 /2' TUBING TAIL (BEHIND CT LNRJ ►. :•:•� I 9418' H ELMDTT LOGGED 06 /14/82 (BEHIND CT LNR) ►.� .. ( 9 - 5 /8" CSG, 47 #, L - 80, ID= 8.681" 1 - 1 6692' .1 ► � � �� • ►�:�' ••.�� 9635' 3 X 3 3/16" XO, ID= 2.786" ► •ii . • i ►O O ►.: •' TOP OF WHIPSTOCK —I 9710' , ��;` �.!�� MILLOUT WINDOW 9714' - 9720' P;fiv 800 I •1 *10 10485' I X 2 -7/8" XO, D= 2.440" I 17' LNR, 29 #, L -80, .0371 bpf, ID= 6.184" H 10512' 1. • • FERFORA TON SUMMARY REF LOG: BHCS ON 06/05/82 11406' PBTD ANGLE AT TOPPERF: 87 @ 11230' I3- 3/16" LNR 6.2 #, L -80, .0076 bpf, ID = 2.800" 10485' SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11230 - 11380 0 05/15/04 12-7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.441" H 11442' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/14/82 ORIGINAL COMPLETION WELL: 02 -24A 05/15/04 KAK CTD SIDETRACK (02 -24A) PERMIT No: 2040300 05/20/04 RMH/KAK GLV C/O API No 50- 029 - 20744 -02 SEC 36, T11 N, R14E, 2019.9' FE & 88.14' FNL BP Exploration (Alaska) r cu,-:~- MICROFILMED 03/01 /2008 DO NOT PLACE ~`: ;, <~,. _ ,~: ~_~ .F -: ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Ins~erts\Microfilm Marker.doc /çJwv-~~1.,. DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040300 MD 11442,r"" Well Name/No. PRUDHOE BAY UNIT 02-24A Operator BP EXPLORATION (ALASKA) INC TVD 9032 Completion Date 5/15/2004- Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Samples No Directional surve~............- Mud Log No DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL Well Log Information: Log/ Data Digital Typ~.Med/Frmt EO D Asc ..ßpt A C Tf .4 Tf ,.....ed. D ....Rpt "EO-""C Lis SP(.l¿ 9 ~ Áð-Ðc¡ API No. 50-029-20744-01-00 UIC N (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number Interval Start Stop Log Log Scale Media Run No OH/ CH Name Directional Survey Directional Survey 12734 Neutron Received 6/9/2004 6/9/2004 9/22/2004 25 9198 11330 12734 Neutron 25 Blu 9198 11330 9/22/2004 12766 Gamma Ray 12766 ~N""d ~y Û ~ S4~~""" L-? vt~"")-. 13598 Gamma Ray 9657 11412 9/14/2004 9657 11412 9/14/2004 9731 11442 Open 2/22/2006 Sample Set Sent Received Number Comments Well Cores/Samples Information: Name Interval Start Stop Well Cored? ADDITIONAL INFORMATION Y~ Daily History Received? ŒY ~N Chips Received? f / r~ Analysis Received? Comments: Formation Tops ~. . Comments IIFR IIFR COMPENSATED NEUTRON LOG/MEMORY GRlCCUCNU COMPENSATED NEUTRON LOG/MEMORY GRlCCUCNU GRlROP GR/ROP ROP NGP plus Graphics . DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040300 Well Name/No. PRUDHOE BAY UNIT 02-24A Operator BP EXPLORATION (ALASKA) INC MD 11442 TVD 9032 J:" 0", 5/15/2004 Completion Status 1-01L Current Status 1-01L Compliance Reviewed By: Date: API No. 50-029-20744-01-00 UIC N {q J~ ~þ . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ~D4 - ð 30 1~5gB RE: MWD Formation Evaluation Logs 02-24A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-24A: LAS Data & Digital Log Images: 50-029-20744-01 1 CD Rom ~~ Q- f ~Æ?c& . . ~o 1- {)3ô WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm, Attn,: Robin Deason 333 West 7ili Avenue, Suite 100 i\nchorage,Alaska 99501 September 14, 2004 RE: MWD Formation Evaluation Logs 02-24A, AK-MW-3062424 1 LDWG formatted Disc with verification listing. PùPI#: 50-029-20744-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. i\nchorage, Alaska 99518 BP Exploration (Alaska) Inc, Petro-Technical Data Center LR2-1 900 E. Benson Blvd. i\nchorage, Alaska 99508 Dme/¥~f RECE\\JED SEP "'\ ;; 2004 A\~!r,a 0" & Gas Cons. Comml5Sion .r'Jr.w' AnQhQØ9a _ STATE OF ALASKA I ALAS~L AND GAS CONSERVATION COM 'I~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 MGR / CCL / CNL CASING, liNER AND CEMENTING RECORD SmllílèDe:I>TH MD Sel'TIJ>.IGDeP'fHWD HOLE I OF> BOTTOM BOTTOM SIZE H-40 Surface 79' Surface 79' 36" 415 sx Arcticset II L-80 Surface 2593' Surface 2593' 17-1/2" 2700 sx Fondu, 400 sx Permafrost 'C' L-80/S00-95 Surface 9692' Surface 8461' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' L-80 9398' 9713' 8203' 8479' 8-1/2" 360 sx Class 'G' L-80 9395' 11442' 8200' 9032' 4-1/8" x 3-3/4" 140 sx Class 'G' o GINJ 0 WINJ 0 WDSPL No. of Completions 2, Operator Name: BP Exploration (Alaska) Inc. 3, Address: P,O, Box 196612, Anchorage, Alaska 99519-6612 4a, Location of Well (Governmental Section): Surface: 1799' SNL, 36' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 121' SNL, 1889' WEL, SEC. 02, T10N, R14E, UM Total Depth: 1238' SNL, 2109' WEL, SEC. 02, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 686809 y- 5949381 Zone- ASP4 TPI: x- 684976 y- 5945734 Zone- ASP4 Total Depth: x- 684785 y- 5944612 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: SGRC Combined GR & EWR, 22, FT. 91.5# 72# 47# 29# 8,81# /6.2# /6.16# 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 23, Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 11230' - 11380' 9011' - 9021' 26. Date First Production: May 31,2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press, 24-HoUR RATE One Other 5, Date Comp., Susp., or Aband, 5/15/2004 6, Date Spudded 5/9/2004 7. Date T.D. Reached 5/13/2004 8, KB Elevation (ft): 64' 9, Plug Back Depth (MD+ TVD) 11407 + 9025 10, Total Depth (MD+TVD) 11442 + 9032 11. Depth where SSSV set (Nipple) 1994' MD 19, Water depth, if offshore N/A MSL 1b, Well Cla!';s: IBI ~pH\erit [J Exploratory o Stratigraphic:rest OService 12, Permit to Drill Number 204-030 13. API Number 50- 029-20744-01-00 14, Well Name and Number: PBU 02·24A 15, Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028308 17, Land Use Permit: 20. Thickness of Permafrost 1900' (Approx,) 24. TUSING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2", 17#, L-80 9373' 9361' 4-1/2", 12,6#, N-80 9447' FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc,): Flowing Oll-BsL GAs-McF WATER-Bsl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary), Submit c~chipS.:.if n,£>ne, state "none". _ CCt/PLETi(JtJi None 0Vd¥', , ~' 'Eli , .... ..~,_...._~ Oll-Bsl 27. Form 10-407 Revised 12/2003 GAs-McF WATER-Bsl OR\G\NAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) ,~6fL. '" RÎI1!1' ì 1U~ i \.; f 28, e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik A 9744' 8505' None Shublik B 9774' 8530' Shublik C 9795' 854 7' Sadlerochit / Zone 4B 9836' 8581' CGL / Zone 3 10054' 8754' Base CGL / Zone 2C 10166' 8842' 238B I Zone 2B 10259' 8903' 30, List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31, I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed /1()^n LI 11/1 Æ.. T'tl T h· I A . t t D t 0/ 10 7--.u Terrie Hubble /'Q¡v,IO _ l~ Ie ec nlca 5815 an a e lO .. ."{.J 7 PBU 02-24A 204-030 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No, I Approval No. Drilling Engineer: Thomas McCarty, 564-4378 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval), ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval), ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain), ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/4/2004 11:00 -11:15 0,25 MOB P PRE Rig released from 02-29C @ 11 :OOHrs on 5/4/2004, Prep to move rig off well. 11:15-11:30 0.25 MOB P PRE PJSM for moving rig off well. 11 :30 - 11 :45 0.25 MOB P PRE Pull rig off well. Clean up location & conduct post operations pad inspection, 11 :45 - 12:00 0.25 MOB P PRE Held pre-move safety meeting. 12:00 - 12:30 0.50 MOB P PRE Move rig from 02-29C to 02-24, Conduct pre-operations pad inspection. 12:30 - 12:45 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 12:45 - 13:00 0.25 MOB P PRE Back rig over well & set down, ACCEPT RIG @ 13:00 HRS ON 05/04/2004. 13:00 - 18:30 5.50 RIGU P PRE PJSM with Peak crew on CT reel swap, P/U & lower reel to Peak double drop trailer. Replace reel drive plates. Meanwhile rebuild HCR valve. 18:30 - 22:00 3,50 RIGU P PRE Crew change & PJSM with Peak crew on CT reel swap. P/U replacement reel into reel house & align drive pins & bushing. R/U hardline to inner reel valve, Meanwhile changeout inside kill valve. 22:00 - 00:00 2.00 RIGU P PRE PJSM. N/U BOPE & C/O BOP inserts for 2-3/8" CT. Grease BOP valves, Spot trailers & tanks. 5/5/2004 00:00 - 07:00 7.00 BOPSUF P PRE Perform initial BOPE function/pressure test. AOGCC test witness waived by Jeff Jones. HeR failed PT. Rebuild HCR & retest OK. Meanwhile C/O hydraulic filters on injector & C/O injector gripper blocks. 07:00 - 12:30 5,50 RIGU P PRE C/O injecter head gripper blocks from 2" to 2-3/8". General rig maintenance 12:30 - 13:30 1.00 RIGU P PRE Grease injecter head, General rig maintenance, 13:30 - 15:30 2,00 RIGU P PRE Install 2-3/8" internal slips pull guide on CT, Pick up injecter head. Start to rig up guide arch, 15:30 - 19:30 4.00 RIGU N RREP PRE Found broken 1" bolt on center support beam swivel bushing of guide arch. One of three support beams. Had to remove both outer swivel bushings to access center one. Replace broken 1" bolt. M/U support beams & P/U guide arch, 19:30 - 20:00 0.50 RIGU P PRE M/U guide arch to injector & RIU to stab CT. 20:00 - 20: 15 0.25 RIGU P PRE Held PJSM & HAlHM for stabbing CT. 20:15 - 21:15 1.00 RIGU P PRE Slip grapple into CT & pull test. Pull CT over pipe shed with winch & stab into injector. 21: 15 - 21 :30 0.25 RIGU P PRE R/U hydraulic cutter for cutting CT. 21 :30 - 21 :45 0,25 RIGU P PRE Held PJSM & HAlHM for cutting CT, Review recent lessons learned from recordable injury during CT cutting operations @ Sajaa, 21 :45 - 00:00 2.25 RIGU P PRE Cut 2949' of 2-3/8" CT, Have 15630' of CT remaining on reel. 5/6/2004 00:00 - 00:45 0.75 PULL P DECOMP Install Baker dimple CTC. Pull test to 35k - OK, Install dart catcher. 00:45 - 01 :00 0,25 PULL P DECOMP Open up well & observe Opsi WHP (well on vac). lAP = 75psi, OAP = 2psi. 01 :00 - 02:00 1,00 PULL P DECOMP Pump 5bbls 1 % KCL water. Shut inner reel valve & P/test hardline in reel house to 4000psi - OK. Load wiper dart. Launch & chase with 1 % KCL. Dart hit @ 58.1 bbls. Pltest inner reel valve & CTC to 3500psi - OK. 02:00 - 02:15 0.25 PULL P DECOMP M/U liner retrieval BHA # 1 with Baker 3" GS spear, up only jar & MHA (OAL - 17.22'), Stab injector on well. Printed: 5/17/2004 8:26:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/6/2004 02: 15 - 02:35 0.33 PULL P DECOMP RIH with BHA #1 taking FP contaminant fluid to tigger tank. 02:35 - 04:25 1.83 PULL P DECOMP RIH BHA #1 to 8000', Up wt check = 32k, Down Wt = 19k, Continue RIH BHA#1 to 9000'. 04:25 - 05:50 1.42 PULL P DECOMP Circulate out FP contaminant fluid @ 2.0/1.6bpm & 2560psi. 05:50 - 07:00 1.17 PULL N WAIT DECOMP W.O Fluid, Truck delayed due to a spill @ loading plant. 07:00 - 07:45 0.75 PULL P DECOMP Circulate out FP contaminant fluid @ 1.9/1.5 bpm & 2400 psi. Take returns to tiger tank. 07:45 - 08: 15 0,50 PULL P DECOMP RIH to 9350 ft, Up wt = 39K, RIH circ 1.0 bpm, Tag fish at 9419 ft. Stop pump. Pick up to 46K, then up to 51 K, hold wt, fish not free, Pick up to 60 K, hold wt, fish not free. Pick up to 65K, hold steady wt, Set down wt to 25K and pick up to 60K. Not free. Set down to 25K and pick up to 60K. Up depth = 9408.7 ft. 08:15 - 11 :00 2,75 PULL P DECOMP Fish pulled free at 70K up wt. Did not jar. POH with fish. Fill well across the top, 46 K up wt with fish, 11:00-11:15 0,25 PULL P DECOMP SAFETY MEETING, Review procedure, hazards and mitigation for laying out 3-1/2" tubing. 11:15-12:15 1,00 PULL P DECOMP Layout fishing BHA and 11-2/3 jts, 10' pup and 2, 2 ft pups of 3-1/2", FL4S tubing 12:15 - 12:45 0,50 CLEAN P DECOMP M/U left hand thread 3.80" milling BHA to mill out 4-1/2" DB-5 LDC Nipple at 9435'. BHA = 18.9 ft. 12:45 - 14:15 1,50 CLEAN P DECOMP RIH with milling BHA. All connections up to CTC are left hand thread. Up wt at 9380 ft = 41 K, Tag 4-1/2" DB nipple at 9399 ft, 14:15 - 16:00 1.75 CLEAN P DECOMP Milling on 3,687" nipple with 3.80" diamond mill at 9399', 2.6/ 2.2 bpm, 2150 psi, 500# WOB. Milled out of nipple at 9340.5 ft, milled down to 9405 ft. Back ream. OK. Ream up and down 3 times, RIH dry OK. 16:00 - 16:50 0.83 CLEAN P DECOMP Mill down in 7" liner to cleanout to top of 3-1/2" liner top. 2.5/ 2,2 bpm, 2100 psi. Tag top of 3-1/2" liner at 9772' CTD. Pick up 20 ft off of fish and flag coil. Back ream to 9440 ft and ream to top of fish again to cleanout liner. 16:50 - 18:40 1.83 CLEAN P DECOMP POH while circ, at 2.6 bpm to chase any fill out of the hole, Still have a fluid loss of 0.3 bpm. 18:40 - 19:00 0.33 CLEAN P DECOMP OOH, PJSM, UD milling BHA #2, 19:00 - 19:15 0,25 CLEAN P DECOMP Held PJSM & HAlHM for reheading CT & M/U under-reaming BHA#3. 19:15 - 19:45 0.50 CLEAN P DECOMP Cut CT & install Baker slip CTC, Pull test to 35k - OK. 19:45 - 20:15 0.50 CLEAN P DECOMP M/U under-reaming BHA #3 with 3-5/8" DB under-reamer, Baker Xtreme motor, up only jar & MHA (OAL - 27.44'). Stab injector on well. 20: 15 - 22:00 1.75 CLEAN P DECOMP RIH with under-reaming BHA #3 without pumping, 22:00 - 22:15 0,25 CLEAN P DECOMP RIH BHA #3 to 9300'. Up wt check = 39,9k, Down Wt = 19k, Continue RIH BHA#3 to CT flag @ 9775', Correct CTD to 9762'. 22:15 - 22:20 0,08 CLEAN P DECOMP PUH to 9500'. Up wt = 42.4k. Bring on pumps to 1,Obpm/550psi. Creep in hole from 9500' to 9510' with 1.55/1.10bpm, 1030psi & 0.8fpm, Observe no motor work, Bring up pumps & establish freespin @ 2,90bpm/2500psi. 22:20 - 23:15 0.92 CLEAN P DECOMP Under-ream down from 9510' to 9762' with bio-KCL water @ 2.90/2.41 bpm, 2500psi & 3,5fpm. Observe no motor work. PUH to 9680', Printed: 5/17/2004 8:26:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 4/24/2004 5/15/2004 N1 Spud Date: 5/23/1982 End: 5/6/2004 23: 15 - 00:00 0.75 CLEAN P DECOMP Under-ream downlup 3x from 9680' to 9740' @ 2.85/2,53bpm, 2350psi & 7,5fpm. 5/7/2004 00:00 - 00:20 0,33 CLEAN P DECOMP Under-ream downlup 1x from 9680' to 9740' @ 2,85/2,53bpm, 2350psi & 7.5fpm, 00:20 - 00:40 0,33 CLEAN P DECOMP Under-ream up from 9740' to 9500' @ 2,85/2.53bpm, 2350psi & 12.5fpm. Bleed off OAP from 680psi to 70psi. 00:40 - 02:35 1.92 CLEAN P DECOMP POOH with under-reaming BHA #3 pumping across the wellhead. 02:35 - 03:00 0.42 CLEAN P DECOMP OOH. PJSM, LID under-reaming BHA #3, 03:00 - 03:15 0.25 EV AL P DECOMP PJSM for P/U & RIH GRlCCLlCaliper logging tools. 03: 15 - 03:30 0.25 EV AL P DECOMP P/U tool into rig floor. Initialize & test logging tools, Program logging tool caliper arms to open up by 06:45AM. 03:30 - 04:05 0.58 EVAL P DECOMP M/U logging BHA #4 with PDS MGR/CCLlCaliper logging tool, XOs & MHA. M/U injector. 04:05 - 05:50 1.75 EVAL P DECOMP RIH logging BHA #4 to CT flag @ 9783'. Correct CTD to 9763'. Continue RIH to 9770', 05:50 - 06:55 1.08 EVAL P DECOMP W.O. logging tool caliper arms to open up. 06:55 - 07:30 0.58 EVAL P DECOMP Log up with PDS Memory Caliper/GR from 9770 - 9250 ft at 40 fpm, 07:30 - 09:00 1,50 EVAL P DECOMP POH with Caliper BHA, 09:00 - 09:15 0,25 EVAL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out PDS caliper BHA. 09:15-10:00 0.75 EVAL P DECOMP LlO BHA. Download PDS Caliper Data. Good Data, 10:00 - 10:15 0.25 WHIP P WEXIT Install 2 SWS RA Tags in Baker Gen 2 Retrievable 3.625" Whipstock [10.0' top whipstock to RA tag], 10:15 -10:30 0.25 WHIP P WEXIT SAFETY MEETING, Review procedure, hazards and mitigation for M/U of Baker whipstock and Sperry MWD tools. 10:30 - 12:00 1.50 WHIP P WEXIT M/U Baker whipstock, setting tool, Sperry MWD, Orienter and MHA. OAL = 71,23', 12:00 - 13:30 1,50 WHIP P WEXIT RIH with BKR Whipstock BHA, SHT Sperry tools and orienter. Trouble getting a steady pulse signal from Sperry tools, Try different pump rates and switch pumps, Got good signal, Could not orient. 0 of 6 clicks, 13:30 - 14:30 1.00 WHIP N DFAL WEXIT POH for different orienter. 14:30 - 15:00 0.50 WHIP N DFAL WEXIT c/o orienter, test orienter at surface. OK, 2 of 2 clicks, 15:00 - 16:00 1.00 WHIP N DFAL WEXIT RIH with BKR Whipstock BHA to 4000 ft. SHT Sperry tools OK. 16:00 . 17:20 1.33 WHIP P WEXIT RIH at 70 fpm to 9710 ft. 17:20 - 18:00 0.67 WHIP P WEXIT Orient TF to 29L 18:00 . 19:00 1.00 WHIP P WEXIT Log down from 9710 ft top of whipstock depth. Tie-in with BHCS/GR of 6/05/1982 with GR. Correct -24 ft CTD, 19:00 - 21 :00 2,00 WHIP N DFAL WEXIT Pick up to 9700', RIH and position top of Whipstock at 9710 ft, TF = 29L. Circ. at 3,35 bpm, 4900 psi for 2 min, Drop pump to 0 bpm, Wait 2 min, Bring back pumps to O,75/0,35bpm & 500psi - still getting returns which indicates that pins have not sheared and/or setting mandrel has not retracted back. Repeat process 4x without luck. TF index from 29L to 33R. 21 :00 - 21 :20 0.33 WHIP N DFAL WEXIT Reorient TF to 29L Need about 1830psÎ pressure drop to shear pins. Mix/pump down 2ppb biozan pill to obtain enough pressure drop across shear pins. 21 :20 - 22:25 1,08 WHIP N DFAL WEXIT Pump biozan pill thru the BHA @ 3.40/3.05bpm & 4800psi. Surge pressure 3x from 2800psi to 4800psi. Drop pump & wait Printed: 5/17/2004 8:26:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/7/2004 21 :20 - 22:25 1.08 WHIP N DFAL WEXIT 22:25 - 00:00 1.58 WHIP N DFAL WEXIT 5/8/2004 00:00 - 01 :45 1.75 WHIP N DFAL WEXIT 01:45 - 02:00 0.25 WHIP N DFAL WEXIT 02:00 - 02:45 0.75 WHIP N DFAL WEXIT 02:45 - 04:15 1.50 WHIP N DFAL WEXIT 04:15 - 05:45 1.50 WHIP N DFAL WEXIT 05:45 - 06:00 0.25 WHIP N DFAL WEXIT 06:00 - 06:25 0.42 WHIP P WEXIT 06:25 - 07:30 1.08 WHIP P WEXIT 07:30 - 08:00 0.50 WHIP P WEXIT 08:00 - 08:15 0,25 ZONISO P WEXIT 08:15 - 08:40 0.42 ZONISO P WEXIT 08:40 - 10:10 1,50 ZONISO P WEXIT 10:10-10:20 0.17 ZONISO P WEXIT 10:20 - 10:55 0,58 ZONISO P WEXIT 10:55 - 11 :45 0.83 ZONISO P WEXIT 5 mins. Pump 5bbls @ 2bpm via the back side to fill hole & see if setting mandrel can be retracted. Bring on pumps to 0.75/0.35bpm & 400psi - still getting returns, Discuss with ANC & decide to set W/S by Eline. Call for SWS Eline unit. Paint EOP flag @ 9600' & POOH whipstock BHA#5 pumping across the wellhead. OOH, PJSM. UD W/S setting BHA. Observe that FAIV was not sheared, but shear pins were partially loaded due to not enough pressure drop across the two 1/4" orifices - suspect the additional MWD equalizer jet (5/32") could have reduced the pressure drop to 1540psi < the required 1830psi. Was able to shear pins @ BTT shop with 1600psi. Held PJSM with Baker & SWS logging crews on whipstock setting job. R/U SWS E-line unit. Calibrate E-line P~S tool to HS & arm. Align/orient wt bars to 15degs LOLS & M/U to whipstock. CCL to TOWS = 23.75'. RIH with P~S tool, weight bars, setting tool, & Baker Gen II 4-1/2" x 7" whipstock, Gently tag top of cut 3-1/2" 1m @ 9775' ELM. P/U wt @ 9380' = 3,7k. Log up hole to 9300' ELM, Tie-into SWS BCS/GR log of 6/8/82. Subtract 10' from ELMD. RBIH to 9750' ELM. Log back up to CCL depth of 9686,2' (TOWS @ 9710' ELM), Set W/S with good wt loss indication & tray orientation of 9 degs LOHS. Log off, tag W/S, log off again & confirmed W/S setting depth. POOH Eline & W/S setting tools, UO SWS Eline tools and rig down SWS. SAFETY MEETING. Review procedure, hazards and mitigation for MIU of Cementing BHA. M/U Cementing BHA. Big hole nozzle, 1 jt 2-3/8" PH6, Hyd Disc, XO and CTC, OAL = 36 RIH with Cementing BHA, R/U SWS cementing unit. Tag Whipstock pinch point at 9730 ft. Correct CTD to 9714 ft. Pick up 10ft and flag CT SAFETY MEETING. Review procedure, hazards and mitigation for pumping Cement Job, Batch mix 13.8 PPG cement with 8% Bentonite, Circ. 0,6 bpm, 0.4 bpm returns. Cement at weight at 1045 hrs, Stg 25,6 bbls, 13.8 ppg G Cement with 8% Bentonite, 2,3 bpm, 1700 psi, Stg 10 bbls water, 2.2 bpm, 1200 psi. Stop pump, close CT valve, Vac cement line clean, Displace with 30 bbl Biozan water, 2.6 I 2.2 bpm, 700 psi. 43K up wt with cement in coil. Close choke at 30 bbls displacement. 2 bpm, 700 psi, Nozzle at 9710 ft. 32 bbl displacement, Cement at nozzle, 2 bpm, 790 psi, 37 bbl displ, 2.0 bpm, 830 psi, Cement at top perf at 38 bbls. 41 bbl displ, 1.8 bpm, 950 psi, Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/8/2004 10:55 - 11 :45 11:45 - 12:30 12:30 - 12:45 12:45 - 15:00 15:00 - 15:45 15:45 - 16:00 16:00 -18:15 18:15-18:30 18:30 - 19:00 19:00 - 20:15 20:15 - 21:35 21:35 - 23:15 23: 15 - 00:00 5/9/2004 00:00 - 01 :20 01 :20 - 02:00 02:00 - 03:25 03:25 - 04:30 04:30 - 04:45 04:45 - 06:30 0.83 ZONISO P WEXIT 44 bbl displ, 1,1 bpm, 850 psi, switch to KCL water. 48 bbl displ, 1,0 bpm, 1270 psi, POH at 30 fpm, lay in at 1 :1, 35K up wt. 54 bbls, 1.0 bpm, 1300 psi, 9520 ft, 58,1 bbls, 1.0 bpm, last of cement out nozzle, TOC at 9400 ft. Drop pump to 0.3 bpm and Pull to safety at 9000 ft. WEXIT Circ. at 9000 ft at 0.2 bpm, 35K up wt. Squeeze cement to 1400 psi. WEXIT RIH. Found cement top at 9430 ft. Circ 2,7 bpm, 1700 psi, RIH at 30 fpm, Cleanout cement to Flag at 9704'. Top of whipstock at 9710 ft. WEXIT POH at 80%, Flag CT at 9500 ft EOP. POH at 80%, 3 bpm, 2000 psi, full returns, WEXIT UO Cementing BHA. P/U side jetting nozzle and jet stack to cleanout any cement or fill. WEXIT M/U 3.80" diamond HCC window milling BHA. OAL = 83,98 ft, WEXIT RIH with window milling BHA, Tag top of cement and correct -20 ft to 9704 ft. WEXIT Press test against firm cement. 2000 psi - bled down to 1910psi after 10mins, with no changes in lAP & OAP. P/U wt @ 9700' = 40,2k. WEXIT Ease in hole & stall @ 9702' - suspect we're @ WS/Lnr pinch pt. P/U with 5k O/pull. Ease in & stall again. P/U with 10k O/pull. Flag pipe & correct depth to 9714,6' (pinch pt ELMD). Establish freespin @ 2,65bpm/1350psi. WEXIT Mill from 9714.6' to 9717' with 2.65/2.65bpm, 1350/1680psi, 1-3k WOB & 1.9fph ave ROP. P/U clean @ 40.2k & ease back into milling. WEXIT Mill from 9717' to 9718.5' with 2.65/2,65bpm, 1350/1700psi, 3k WOB & 1,5fph ave ROP. P/U clean @ 40k & ease back into milling. WEXIT Mill from 9718.5' to 9720.5' with 2,65/2.65bpm, 1560/1750psi, 3-4k WOB & 1.5fph ave ROP. Stall 2x, P/U clean @ 40k & ease back into milling, WEXIT Control mill to 9721' with 2.65/2.65bpm, 1570/1650psi, <1k WOB & 1 fph ave ROP. Seems we're out. Pump down 12bbls of 2ppb bio hi-vis sweep, WEXIT Mill formation to 9731' with 2.65/2.65bpm, 1570/2050psi, 2k WOB & 8fph ave ROP. Pump down 8bbls of 2ppb bio hi-vis sweep & follow with Flopro mud. WEXIT Swap well bore to 8,6 ppg flopro mud, Meanwhile backream/dress window/rat hole 3x & drift 2x, Window looks clean, Tentative window depths are: TOWS = 9710', TOW = 9714,6', RA PIP Tag = 9720', BOW = 9720.5', BOWS = 9727.5'. WEXIT Paint EOP flag @ 9604' & POOH window milling BHA#7, WEXIT PJSM. UD BHA#7 & inspect mills. DWM gauge 3.80" go I 3.79" no-go & DSR gauge 3,80", Wear on window mill face indicates center crossed the liner wall. PROD1 Held pre-spud safety meeting, Reviewed well plan, potential hazards & drilling BHA M/U procedures. PROD1 Rehead & M/U DS CTC. Pull & pressure test. M/U build section 0,75 ZONISO P 0.25 ZONISO P 2.25 ZONISO P 0.75 ZONISO P 0,25 ZONISO P 2,25 STWHIP P 0,25 STWHIP P 0.50 STWHIP P 1.25 STWHIP P 1,33 STWHIP P 1.67 STWHIP P 0.75 STWHIP P 1,33 STWHIP P 0,67 STWHIP P 1.42 STWHIP P 1,08 STWHIP P 0.25 DRILL P 1.75 DRILL P Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/9/2004 04:45 - 06:30 1,75 DRILL P PROD1 BHA #8 with used HYC DS100 3-3/4" x 4-1/4" bicenter bit, 1.37deg bend motor, MWD & newly-improved orienter [has new actuating piston & 2 new external springs for better TF locking]. Check orienter at surface, Got 4 of 34 clicks, 06:30 - 08:30 2.00 DRILL P PROD1 RIH with MWD Build / Turn BHA #8 with 1,37 deg motor. SHT MWD and Orienter. OK, RIH. 08:30 - 08:45 0.25 DRILL P PROD1 Orient TF to 30L, 08:45 - 09: 10 0.42 DRILL P PROD1 RIH, sat down in window 2 times with 30L TF. RIH clean thru window on third try. Tag TD and correct depth to 9731 ft. 09: 10 - 11 :50 2.67 DRILL P PROD1 Attempt to Drill Build section in Sag river. many stalls on bottom, maybe 1 ft of progress. Checked GR tie-in, On depth with BHCS/GR at 9670'. Very light weight on bottom and motor stalls. Stalls with no weight on bit indicate we drilled into 7" centralizer and are catching the blade with the 4,25" Bi-center outer cutters. No progress. 11 :50 - 14:00 2,17 DRILL N DPRB PROD1 POH to check BHA. 14:00 - 14:30 0.50 DRILL N DPRB PROD1 Gauge on bit was beaten up, pilot cutters were fine, indicatiang no juck on bottom, but metal on side of 4-1/4"hole at 9731 ft. , Best guess is we drilled into a 7" centralizer. Replaced motor with 1.37 deg motor, Checked MWD Probe orientation - OK. M/U 3.76" Diamond D331 parabolic mill and diamond string reamer to clean up window area and drill ahead to tie-in with RA tag. 14:30 - 16:00 1,50 DRILL N DPRB PROD1 RIH with BHA #9, SHT MWD and Orienter. RIH. Stop at flag at 9500' EOP. -12 ft CTD correction. 16:00-16:15 0,25 DRILL N DPRB PROD1 Orient TF to 30L. 16:15-16:45 0.50 DRILL N DPRB PROD1 Ream down thru window, 2.7/2,7 bpm, 3200 psi, 46L, Stalled at 9721' at bottom of window, Ream down very slow at 9721' at 35L, Some motor work, no stalls. Ream down to 9732 ft, Stalled on bottom, Ream down again, no stall. 16:45 - 18:30 1.75 DRILL P PROD1 Drilling Build section with 3,76" D331 mill to get GR tie-in with RA tag in whipstock, 2,7/2,7 bpm, 3200-3900 psi, 18L, 5-10K WOB, 12 FPH. Drilled to 9752 ft. 18:30 - 19:30 1.00 STWHIP N DPRB WEXIT Backreamlream 3x from 9720' (BOW) to 9731' (end of rat hole) with HS TF, 2.8bpm/3500psi & 5fph ave ROP, Stalling @ 9720' while backreaming, 19:30 - 19:35 0,08 STWHIP N DPRB WEXIT Orient TF to 150R (180degs out from window). 19:35 - 19:45 0.17 STWHIP N DPRB WEXIT Backreamlream 2x from 9720' to 9731' with 150R TF, 2,8bpm/3550psi & 5fph ave ROP, Still stalling @ 9720' while backreaming. 19:45 - 19:50 0.08 STWHIP N DPRB WEXIT Orient TF to 50L 19:50 - 22:00 2.17 STWHIP N DPRB WEXIT Ease back to 9719' & park, Dress spot with 50L TF, 2,7bpm/3350psi. Slowly back ream to TOW. RBIH clean with pumps on, PUH clean thru window with pumps on. RBIH below window, Orient TF to 15R. Backream clean to TOW. RBIH below window. 22:00 - 22:35 0.58 STWHIP N DPRB WEXIT Log down GR & tie-in RA Pip tag into the Geology PDC log - Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/9/2004 22:00 - 22:35 0,58 STWHIP N DPRB WEXIT subtract 1,5' from PIP tag depth. Revised window depths are: TOWS = 9708,5', TOW = 9713', RA PIP Tag = 9718,5'. BOW = 9719', BOWS = 9726'. 22:35 - 23:30 0.92 STWHIP N DPRB WEXIT Orient to 55R & pull thru window. Attempt to go thru window @ 100R & 130R - won't go. Orient to 85L & enter window OK. Drift window with & without pumps - clean. 23:30 - 00:00 0,50 STWHIP N DPRB WEXIT Paint EOP flag @ 9605' & POOH window dressing BHA#9. 5/10/2004 00:00 - 01 :00 1,00 STWHIP N DPRB WEXIT Continue POOH window dressing BHA#9, 01 :00 - 01 :30 0.50 STWHIP N DPRB WEXIT PJSM. UD BHA#9 & inspect mills. D331 gauge 3,75" & DSR gauge 3.76". 01 :30 - 01 :45 0,25 DRILL P PROD1 Held PJSM & HAlHM for cutting CT, reheading CT & M/U drilling BHA#10, 01 :45 - 02:30 0,75 DRILL P PROD1 Cut 203' of CT. 02:30 - 03:30 1,00 DRILL P PROD1 Rehead & M/U DS CTC, Pull & pressure test. M/U build section BHA #10 with rebuilt HYC DS100 3-314" x 4-1/4" bicenter bit, same 1.37deg bend motor, MWD & orienter. MIU injector. 03:30 - 05: 10 1,67 DRILL P PROD1 RIH with drilling BHA #10. SHT MWD & orienter - OK. Continue RIH to 9600', Wt check: Up wt = 40k, Dwn wt = 20k. Run thru window with pumps down & tag btm @ 9775', Correct depth to 9752'. Check TF - @ 40R. 05: 1 0 - 05:30 0.33 DRILL P PROD1 Orient TF to 40L PVT = 329 bbls, 05:30 - 06:00 0.50 DRILL P PROD1 Drill to 9758' with 40L TF, 2.7/2.7bpm, 3350/3400psi, 2k WOB & 20fph ave ROP, 06:00 - 07:30 1,50 DRILL P PROD1 Drilling build section, 2.7/2.7 bpm, 3100 - 3900 psi, 10L, 20 fph, Drilled to 9770', 07:30 - 07:50 0.33 DRILL P PROD1 Orient TF to 90L, 07:50 - 09:30 1.67 DRILL P PROD1 Drilling build section, 2.7/2.7 bpm, 3100 - 3900 psi, 90L, 20 fph, Drilled to 9790 It, 09:30 - 11 :00 1.50 DRILL P PROD1 Drilling build section, 2.7 I 2.7 bpm, 3100 - 3900 psi, 80L, 15 fph, 36 deg incl. Drilled to 9810'. 11 :00 - 12:30 1,50 DRILL P PROD1 Drilling build section, 2,7/2.7 bpm, 3100 - 3900 psi, 90L, 15 fph, 35 deg incl. Drilled to 9823'. 12:30 - 14:00 1,50 DRILL P PROD1 Drilling build section, 2,7/2,7 bpm, 3100 - 3900 psi, 90L, 20 fph, 34 deg incl. Drilled to 9845'. 14:00 - 15:00 1,00 DRILL P PROD1 Drilling build section, 2,7 I 2,7 bpm, 3100 - 3900 psi, 70L, 20 fph, 34 deg incl. Drilled to 9867'. 15:00-15:15 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 15:15 - 16:30 1.25 DRILL P PROD1 Drilling build section, 2,7/2,7 bpm, 3100 - 3900 psi, 70L, 40 fph, 36 deg incl. Drilled to 9900', 16:30 - 17:30 1.00 DRILL P PROD1 Drilling build section, 2.7/2.7 bpm, 3100 - 3900 psi, 70L, 40 fph, 38 deg incl. Drilled to 9940', 17:30 - 17:45 0.25 DRILL P PROD1 Orient TF to 90R. 17:45-18:15 0.50 DRILL P PROD1 Drilling build section, 2.7/2.7 bpm, 3100 - 3900 psi, 80R, 40 fph, 39 deg incl. Drilled to 9955'. 18:15 - 18:30 0,25 DRILL P PROD1 Drilling build section, 2,7/2,7 bpm, 3100 - 3900 psi, 90R, 40 fph, 39 deg incl. Drilled to 9974', 18:30 - 21 :45 3.25 DRILL P PROD1 Drill to 10055' with 110R TF, 2.7/2.7bpm, 3100/3400psi, 3k WOB & 30fph ave ROP. 21 :45 - 22:05 0.33 DRILL P PROD1 Wiper trip clean to window. RBIH to btm, 22:05 - 22:35 0.50 DRILL P PROD1 Orient TF around to 80R. 22:35 - 00:00 1.42 DRILL P PROD1 Drill to 10073' with 80R TF, 2,7/2,7bpm, 3050/3500psi, 3k WOB & 30fph ave ROP, 5/11/2004 00:00 - 00:45 0.75 DRILL P PROD1 Drill to 10083' with 90R TF, 2.7/2.7bpm, 3150/3600psi, 3k Printed: 5/17/2004 8:26:17 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/11/2004 00:00 - 00:45 0,75 DRILL P PROD1 WOB & 15fph ave ROP. Penetrated zone-3 @ +/-10075' (8707ftvd) 00:45 - 00:55 0,17 DRILL P PROD1 Orient TF to 90R. 00:55 - 03:30 2.58 DRILL P PROD1 Drill to 10119' with 90-120R TF, 2,7/2,7bpm, 3200/3700psi, 3k WOB & 15fph ave ROP, 03:30 - 03:40 0.17 DRILL P PROD1 Orient TF to 25L, 03:40 - 04:30 0.83 DRILL P PROD1 Drill to 10126' with 30L TF, 2.7/2.7bpm, 3200/3600psi, 3k WOB & 1 Of ph ave ROP, 04:30 - 06:15 1.75 DRILL P PROD1 Paint EOP flag @ 9600' & POOH drilling BHA#10, 06:15 - 06:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA C/O. 06:30 - 07:00 0,50 DRILL P PROD1 C/O Bi-center Bit and Sperry MWD Probe. Motor and Orienter were OK. 07:00 - 09:00 2,00 DRILL P PROD1 RI H with BHA #11, 1,37 Deg motor, HC 3.75X4.13 BiCenter Bit #6, SHT tools. OK. RIH. Stop at Flag at 9600' EOP and correct -23 ft CTD, RIH, 09:00 - 09:15 0,25 DRILL P PROD1 Log tie-in with GR to RA tag. Added 1 ft CTD. 09:15 - 09:30 0.25 DRILL P PROD1 RIH, tag TD at 10128 ft. 09:30 - 10:00 0.50 DRILL P PROD1 Orient TF to 20L. 10:00-11:10 1.17 DRILL P PROD1 Drilling build section in Z3. 2,7 I 2.7 bpm, 3200- 3900 psi, 15L, 40 deg, 35 fph, Drilled to 10162', 11:10 -13:00 1,83 DRILL P PROD1 Drilling build section in Z3. 2,7 I 2,7 bpm, 3200- 3900 psi, 30L, 48 deg, 45 fph, Drilled to 10230'. 13:00-14:15 1.25 DRILL P PROD1 Drilling build section in Z2, 2,7/2.7 bpm, 3200- 3900 psi, 30R, 55 deg, 80 fph, Drilled to 10300', 14:15 - 14:52 0,62 DRILL P PROD1 Wiper trip to window. Wiper trip clean to bottom of window. 14:52 - 15:00 0.13 DRILL P PROD1 Orient TF 180 to 66R 15:00 - 16:00 1.00 DRILL P PROD1 Drilling TF at 30R, Q = 2.66/2.77bpm, Pp 3200/3900 psi. 16:00-16:19 0.32 DRILL P PROD1 PUH for Geologist an Orient TF to 20 L Geologist wants to land at 8912 ft. Need to put everything in build from here 16:19 - 16:30 0,18 DRILL P PROD1 Drilling TF at 4R, Zone II, Q = 2.66/2,77bpm, Pp 3200/3900 psi. Geologist changed landing TVD. Wants to land at 88 to 89 deg at a TVD of 8913 ft 16:30 - 17:26 0,93 DRILL N RREP PROD1 Wiper Trip while repairing MP#1 valve and seats and cir cutting into TT. Not drilling at 100fpm fpm with only 1 mud pump and need conformation on where to land. Gives Geologist time to confirm with town on the changes in landing TVD. 17:26 - 17:57 0,52 DRILL N RREP PROD1 Up in the 7" liner. Geologist confirmed with town on the landing TVD, Circulating hole up into the 4-1/2" TT. PUH to 9070 ft and RIH. Will stop above window to test drive MP#1 17:57 - 18:05 0.13 DRILL N RREP PROD1 Pump repaired, Test drive MP#1 before going in open hole 18:05 - 18:30 0.42 DRILL P PROD1 SD MP#1 RIH past WS. Bring on pumps & RIH to btm, lAP = 140psi, OAP = 285psi. PVT = 316bbls, Up wt = 39k. Run-in wt = 18k, 18:30 - 18:50 0,33 DRILL P PROD1 Orient TF to 15L, 18:50-19:15 0.42 DRILL P PROD1 Drill to 10465' with 20L TF, 2,7/2.7bpm, 3200/3400psi, 2k WOB & 75fph ave ROP. 19:15 -19:45 0,50 DRILL P PROD1 Drill to 10507' with 20L TF, 2,7/2,7bpm, 3200/3400psi, 2k WOB & 90fph ave ROP, Landed build section @ 8913'sstvd. 19:45 - 20:10 0.42 DRILL P PROD1 Orient TF to 80L. 20:10 - 20:15 0.08 DRILL P PROD1 Drill to 10512' with 80-90L TF, 2.7/2.7bpm, 3150/3400psi, 2k WOB & 45fph ave ROP. Printed: 5/17/2004 8:26:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 4/24/2004 5/15/2004 N1 Spud Date: 5/23/1982 End: 5/11/2004 20:15 - 20:45 0.50 DRILL P PROD1 Orient 1 click & drill to 10533' with 70L TF, 2.7/2,7bpm, 3150/3400psi, 2k WOB & 40fph ave ROP. 20:45 - 21 :45 1,00 DRILL P PROD1 Orient 1 click & drill to 10564' with 50-70L TF, 2.7/2.7bpm, 3150/3400psi, 2k WOB & 35fph ave ROP. Drill into shale from 10520' . 21:45 - 22:15 0.50 DRILL P PROD1 Orient 1 click & drill to 10600' with 75L TF, 2,7/2,7bpm, 3150/3550psi, 4k WOB & 80fph ave ROP. Stacking wt in shale. 22:15 - 23:00 0,75 DRILL P PROD1 Wiper trip clean to window. RBIH to btm, PVT = 308bbls, Up wt = 38k. Run-in wt = 19k. 23:00 - 23:05 0.08 DRILL P PROD1 Shoot off btm full survey, 23:05 - 00:00 0.92 DRILL P PROD1 Drill to 10655' with 90L TF, 2.7/2,7bpm, 3200/3560psi, 5k WOB & 25fph ave ROP. 5/12/2004 00:00 - 00:55 0,92 DRILL P PROD1 Orient 1 click & drill to 10672' with 75-90L TF, 2.7/2.7bpm, 3200/3560psi, 5k WOB & 30fph ave ROP, Drill into hard spot @ 10672'. Stacking wt & pulling heavy. 00:55 - 02:30 1.58 DRILL P PROD1 Grind-on to 10677' with 75L TF, 2,7/2,7bpm, 3150/3450psi, 10k WOB & 5fph ave ROP. Swap well to new 8.6ppg, 10# kla-gard, 3% lubex flo-pro mud, Still can't drill - decide to POOH to check bit & adjust motor. 02:30 - 04:00 1.50 DRILL P PROD1 Paint EOP flag @ 9600' & POOH drilling BHA#11. 04:00 - 04:15 0,25 DRILL P PROD1 PJSM for BHA changeout. 04:15 - 05:30 1,25 DRILL P PROD1 Check bit -3/4/1. Changeout bit & motor, M/U lateral drilling BHA #12 with new HYC DS49 bit, new 1.04deg bend motor, same MWD & orienter. M/U injector.! 05:30 - 07:10 1.67 DRILL P PROD1 RIH with lateral drilling BHA #12. SHT orienter & motor. Continue RIH, to 9753 ft Corrected + 1 ft to flag at 9600 ft. 07: 1 0 - 07:24 0,23 DRILL P PROD1 Tie-in at RA Marker at 9718,5 ft with bit at 9753 ft, Corrected 9739,6 ft to 9744,2 ft (+4,5ft) 07:24 - 07:55 0.52 DRILL P PROD1 RIH tagged bottom at 10680 ft 07:55 - 08:22 0.45 DRILL P PROD1 Orient TF around to 60 to 70 L 08:22 - 08:48 0.43 DRILL P PROD1 Drilled 60L TF and found TVD to low 08:48 - 08:53 0.08 DRILL P PROD1 Orient TF to HS 08:53 - 09:38 0.75 DRILL P PROD1 Drilling at 30L to 53L TF Q = 2,79/2.91 bpm Pp = 3000/3475 psi, Vp = 327 bbl. WOB = 2500 Ib, ROP 45 fph 09:38 - 10:05 0.45 DRILL P PROD1 Orient Around to 80 L 10:05 - 10:45 0,67 DRILL P PROD1 Drilling at 86L TF Q = 2.79/2,91 bpm Pp = 3000/3475 psi, Vp = 327 bbl. WOB = 3300 Ib, ROP 110 fph 10:45 - 11 :00 0.25 DRILL P PROD1 Orient TF 180 to 80 R IA = 144psi; OA = 336 psi 11:00 -11:14 0.23 DRILL P PROD1 Drilling at 94 TF Q = 2.79/2.91 bpm Pp = 3000/3475 psi, Vp = 327 bbl. WOB = 4500 Ib, ROP 150 fph Drilling 25API Sand (sweet spot) 11:14 -12:31 1,28 DRILL P PROD1 Wiper Trip after drilling 150 ft, Pulled tight and 300 psi motor work at 10,672 ft, worked through, Reamed 10,672 ft area on trip back in, Tagged again at 10,672', TF 180 Out 12:31 - 12:39 0.13 DRILL P PROD1 Orient TF to 90 L at 10,653 ft 12:39 - 12:45 0.10 DRILL P PROD1 RIH at 53L past shale area 12:45 - 12:58 0.22 DRILL P PROD1 Orient TF 12:58 - 14:00 1.03 DRILL P PROD1 Drilling at 94 TF Q = 2,79/2.91 bpm Pp = 3000/3358 psi, Vp = 321 bbl. WOB = 4,5k-3,5klb, ROP 75- 100 fph 14:00 - 14:05 0,08 DRILL P PROD1 Orient TF to stay on low side of 89 deg 14:05 - 15:00 0.92 DRILL P PROD1 Drilling, stacking in shale, having to work CT to get motor work, Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/12/2004 14:05 - 15:00 0,92 DRILL P PROD1 Drilling at 105 TF Q = 2.70/2.78 bpm Pp = 3100/3458 psi, Vp = 321 bbl. WOB = 4.5k-7.5klb, ROP 75- 130 fph Coming into good sand before wiper trip 15:00 - 16:05 1.08 DRILL P PROD1 Wiper trip to window area 16:05 - 17:00 0,92 DRILL P PROD1 Drilling at 90R TF Q = 2,79/2.91 bpm Pp = 303100/3358 psi, Vp = 316 bbl. Drilling in 30API sand. Got 1 click Orders from town have changed our objectives Vp=311 bbl 17:00 - 17:45 0,75 DRILL P PROD1 Orient TF around, they want to stay at 85 deg till end of pologon 17:45 - 17:55 0.17 DRILL P PROD1 Drilling w//26R TF @ 74 ftIhr. Q = 2.77/2,86bpm, P = 3100/3344psi. WOB = 2,6k 17:55 - 18:00 0,08 DRILL P PROD1 Orient TF 60 to 72 R 18:00 - 18:35 0.58 DRILL P PROD1 Drilling w//26R TF @ 74 ftIhr. Q = 2,81/2.91 bpm, P = 3100/3400psi. WOB = 3.6k Got one click. Drill to 11130'. 18:35 - 19:15 0,67 DRILL N DPRB PROD1 Wiper trip, Stall motor with 8k O/Pull @ 10948' (top of BHA @ 10883' shale). RBIH & set down with -8k. Work pipe free downwards & RBIH to 11000'. 19:15 - 20:15 1.00 DRILL P PROD1 Backream clean across shale section to 10800'. Continue wiper tripping up hole. Stall motor with 10k O/Pull @ 10741' (top of BHA @ 10676' shale), Backream clean to window. 20:15 - 20:40 0.42 DRILL P PROD1 Log up GR & tie into RA PIP tag. Add 7.5' to CTD. 20:40 - 21:15 0.58 DRILL P PROD1 RBIH clean to 11000', Meanwhile bring up Kla-Gard in mud system to 12ppb. 21 :15 - 21 :30 0.25 DRILL P PROD1 PUH clean to 10630'. 21 :30 - 21:40 0.17 DRILL P PROD1 RBIH clean to TD tagged @ 11133'. PVT = 313bbls, Up wt = 39k, Run-in wt = 17k, 21 :40 - 21 :55 0,25 DRILL P PROD1 Orient TF to 90R. 21 :55 - 22:30 0,58 DRILL P PROD1 Drill to 11165' with 75-90R TF, 2.65/2.65bpm, 2850/3150psi, 2k WOB & 80fph ave ROP. 22:30 - 22:45 0.25 DRILL P PROD1 Drill to 11202' with 90-1 OOR TF, 2,65/2.65bpm, 2850/3150psi, 2k WOB & 140fph ave ROP. 22:45 - 23:35 0.83 DRILL P PROD1 Circ off btm to allow Geo check forward plan with ANC. Decide to level off in good sand before dropping into the HOT. 23:35 - 23:45 0.17 DRILL P PROD1 Orient TF to 25L 23:45 - 00:00 0.25 DRILL P PROD1 Drill to original planned Vert Sect @ 11207' with 35L TF, 2,65/2.65bpm, 2850/3150psi, 3k WOB & 110fph ave ROP. 5/13/2004 00:00 - 00:15 0,25 DRILL C PROD1 Drill to 11236' with 30L TF, 2,65/2,65bpm, 2850/3150psi, 3k WOB & 120fph ave ROP. 00: 15 - 00:30 0,25 DRILL C PROD1 Orient TF to 90L. 00:30 - 00:50 0,33 DRILL C PROD1 Drill to 11258' with 90L TF, 2.65/2.65bpm, 2850/3000psi, 2k WOB & 65fph ave ROP. 00:50 - 01 :15 0.42 DRILL C PROD1 Orient & drill to 11300' with 60-75L TF, 2.65/2.65bpm, 2850/3100psi, 3k WOB & 11 Of ph ave ROP, 01:15 - 02:35 1.33 DRILL C PROD1 Wiper trip clean to window. RBIH to btm, PVT = 308bbls, Up wt = 39k. Run-in wt = 17k, 02:35 - 03:35 1,00 DRILL C PROD1 Orient & drill to 11363' with 45-75L TF, 2,65/2,65bpm, 2850/3100psi, 3k WOB & 70fph ave ROP. See GR creeping up from 11330' & Geo wants to turn it down. 03:35 - 03:55 0.33 DRILL C PROD1 Orient TF to LS. 03:55 - 05:20 1.42 DRILL C PROD1 Drill to TD @ 11440' with 160-180R TF, 2.65/2.65bpm, 2850/3100psi, 5k WOB & 25fph ave ROP, Cross polygon @ +/- 11380'. From ROP, we may have drilled into the 22N @ Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/13/2004 03:55 - 05:20 1.42 DRILL C PROD1 11430'. 05:20 - 06:10 0.83 DRILL P PROD1 Wiper trip to window. Saw little wt bobble @ 10930'. 06:10 - 06:20 0.17 DRILL P PROD1 Tie-in (+3 It) 9741' to 9744' 06:20 - 07:30 1,17 DRILL P PROD1 Pull above window and wait 2 hrs as per MOC dated 5-12-04 Q = 2,24/2.33bpm P = 2340psi. Cir bottom up. and then reduce Qp to 0.25 bpm. Circulated large globs of sand/shale across shaker then cleanup alter bottoms up. On Plan View, 71 It past polygon and on Vertical Section, 218 It past program VS 07:30 - 09:00 1.50 DRILL P PROD1 Reduce Qp to 0.25 bpm. This allows the stability of the shale to be determined. 09:00 - 09:38 0,63 DRILL P PROD1 RIH at correct TF to confirm TD and check shale integrity. Started Liner pill down CT 09:38 - 09:43 0.08 DRILL P PROD1 Tagged shale at 10672 ft TF at 180dge. PUH and orient TF to 81 L This area is the transition zone between 4-118 BC bit and 3-3/4" PDC. 09:43 - 10:20 0.62 DRILL P PROD1 RIH Q= 2.78/3.00 bpm at 3200 psi. Tagged at 11442 It 10:20 -13:10 2.83 DRILL P PROD1 POOH, Lay in liner pill. OH clean. POOH to 90 ft, RIH to 300 It to increase AV to clean up shaker. Painted flag at 9400 It EOP Have to remove one motor room panels to allow better air ventilation during the warmer season 600/480 volt transformer getting warm 13:10-14:10 1,00 DRILL P PROD1 LD BOT BHA 14:10 - 14:30 0.33 CASE P COMP PJSM on liner handling procedure and hazards associated with PU & RIH 14:30 - 17:40 3.17 CASE P COMP Running production liner and CTLRT 17:40 - 18:30 0.83 CASE P COMP Cut off 11' CT (15,416 It) and install CTC and pull test to 40k 18:30 - 19:30 1.00 CASE P COMP Install dart catcher. Load & launch wiper dart. Chase dart with mud & pig CT, Dart bumped on catcher @ 57,6bbls. MIU injector. 19:30 - 21:15 1.75 CASE P COMP RIH with liner on CT to 9600' circ @ O.28/0.68bpm & 920psi. Check up wt - 45k, down wt - 19k. RIH smoothly @ 50fpm thru window. RIH & set down @ 10584', P/U & bounce thru, Continue RIH with slight bobbles across shale sections. Tag TD @ 11462' CTD with EOP flag on depth, P/U @ 50k. RBIH @ retag TD @ same depth. Set down 10k down on CTLRT. 21 :15 - 21 :45 0,50 CASE P COMP Load & launch 5/8" steel ball & circ with mud @ 2,5/2,5bpm, 2370psi. Slow down to O,5bpm/1080psi @ 43bbls away, Ball on seat @ 45,2bbls. Pressure up to 4000psi & release CTLRT. P/U @ 34k & confirm release. 21:45 - 22:15 0.50 CASE N WAIT COMP Circ well @ 0.75/075bpm & 1180psi while W, 0, KCL trucks to arrive onsite. 22:15 - 00:00 1,75 CASE P COMP Displace well to 2% KCL at 2,8/2.8bpm & 1300psi. Send used FloPro to MI for reconditioning, Meanwhile R/U Dowell cementers. 5/14/2004 00:00 - 00:45 0.75 CASE P COMP Fill rig pits with 2% KCL, Mix 30bbls of 2ppb# biozan displacement fluid, Meanwhile continue displacing well to 2% KCL at 2,11/2,09bpm & 740psi. 00:45 - 01 :00 0.25 CEMT P COMP PJSM with all personnel concerning cementing operations. PVT = 247bbls, 01 :00 - 02:20 1.33 CEMT P COMP Batch mix 27bbls 15.8ppg 'G' latex cmt with additives. Cmt to Printed: 5/17/2004 8:26:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/14/2004 01 :00 - 02:20 1.33 CEMT P COMP wt @ 01 :20hrs, FlushlPT lines to 4k, Pump 27bbls cmt slurry @ 2,95/2.88bpm & 2770psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30bbls bio-KCL @ 2,87/2.50bpm & 2120psi. Losses start healing with cement @ the shoe. CTWP engage LWP @ 57.2bbls away, Shear plug with 3100psi. Continue displacing LWP @ 1.6/1.6bpm, 1140psi & bump @ 70.5bbls away with 1000psi over. Bleed off & check floats - held, Pressure up to 200psi & sting out of liner. 25,3bbls cmt pumped around shoe, CIP @ 02:20 hrs, PVT = 279bbls. 02:20 - 04:20 2,00 CEMT P COMP POOH @ 68fpm pumping @ 0.37bpm to replace CT voidage only. 04:20 - 05:00 0.67 CEMT P COMP OOH.PJSM, LID CTLRT, 05:00 - 05: 15 0.25 EVAL P COMP PJSM on P/U & RIH CNL tools & 1-1/4" CHS tbg. 05: 15 - 05:30 0.25 EVAL P COMP Initialize & test logging tools, P/U tool into rig floor. 05:30 - 08:15 2,75 EVAL P COMP P/U logginglcleanout BHA #14 with 2-1/4" D331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNLlCCLlGR logging tool carrier, XO, lower MHA, 66jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. 08:15 - 09:25 1.17 EVAL P COMP RIH w/ MCNLlGR/CCL 09:25 - 10:40 1.25 EVAL P COMP Cement at 800 psi compressives. RIH at 30 fpm at Q=1.5 bpm @ 1505 psi Tagged at 11428 ft -23 ft correction- wiper plug = 11405 ft (on the money) 10:40 - 10:49 0.15 EVAL P COMP POOH laying in Perf pill and logging at 60 fpm 600/480 volt transformer on MP # 1 is heating up again, switch pumps to MP#2 10:49 - 10:56 0,12 EVAL P COMP RIH to relog 10:56 - 11 :32 0.60 EVAL P COMP POOH logging at 60 fpm. Traction motor on MP#1 is fried Q= 1,00 bpm 11 :32 - 13:20 1.80 EVAL P COMP POOH at 1.50 bpm chasing contaminated fluid to surface, 13:20 - 16:20 3.00 EVAL P COMP Stand back injector head and POOH and stand CSH in derrick, Worked on inertia brake on drawworks, Cement at 2300 psi at 1500 hrs 16:20 - 16:58 0,63 EVAL P COMP PJSM on Source handling with Crew & SLB 16:58 -17:15 0,28 EVAL P COMP LD Logging tool and 2 jts CSH and MM. 17:15 - 18:30 1.25 CEMT P COMP Install jetting nozzle and jetted up BOP's Data collected from MCNL "good" Top Liner @ 9,394 ft PBTD at 11 ,406 ft Faxed logs to Cole Abel for conformation - He confirmed 1815 hrs 5-14-2004 18:30 - 20:00 1.50 CEMT P COMP Line up to test liner lap. Compressive strength of cement - >2000psi. Fill hole & PT liner lap to 2000psi for 30mins as follows: Time WHP lAP OAP Onset 15 100 0 0 2000 220 132 2 1981 220 132 4 1970 219 131 6 1963 219 131 10 1952 217 129 20 1941 216 128 30 1930 216 128 Printed: 5/17/2004 8:26:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-24 02-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/24/2004 Rig Release: 5/15/2004 Rig Number: N1 Spud Date: 5/23/1982 End: 5/14/2004 20:00 - 00:00 4,00 EV AL N RREP COMP Drawworks making some weird noise. Troubleshoot source of noise in drawwork clutch system, Found broken release-spring & stud in the jackshaft assembly of main high-drum clutch. Remove all 4 springs from jackshaft assembly. 5/15/2004 00:00 - 07:00 7.00 EVAL N RREP COMP Couple-back jackshaft assembly with only 2 springs & function test high-drum clutch - still making noise, Remove springs & parts from low-drum clutch to rebuild high-drum clutch. Will disengage air supply to low-drum clutch pending repairs when parts become available, As per Nordic, 95% of rig hoisting is done on the high-drum clutch - thus should be able to operate with only the high-drum clutch. 07:00 - 08:30 1.50 EVAL N COMP Tested Drawworks OK called for TCP supervisor. Off NPT time at 0700 hrs. Warm up Coiled tubing. Wait on SLB to PU guns 08:30 - 08:50 0,33 EVAL N COMP PJSM on TCP Perf Gun Handling and running 08:50 - 09:15 0.42 PERF N COMP PU Perf guns as per programme. 09:15-10:17 1,03 PERF N COMP RIH with 66 jts CSH Parts for the low drum clutch whill be here on Wednesday from Canada 10:17 - 10:30 0,22 PERF N COMP PU injector head and make up MHA BHA = 2223,20 ft 10:30 - 12:03 1.55 PERF N COMP RIH with Perf Gun Tagged at 11429 ft, confirmed 11429 ft Corrected to SLB MCNUCCUGR Dated 5-14-2004 12:03 - 12:24 0.35 PERF N COMP Pumped 15 bbl perf pill, drop 5/8" ball, zeroed counters 12:24 - 13:00 0.60 PERF N COMP Lanched ball, whitey valve leaked, replaced Pump 14 bbl Perf Pill and switch to KCL water. Vol = 54.4 ball on seats, Perforated 3750 psi, drive by at 11380.7ft VP = 281 bbl 13:00 - 15:00 2.00 PERF N COMP POOH to CSH 15:00 - 15:20 0,33 PERF N COMP PJSM on handling CSH and standing in derrick 15:20 - 16:45 1.42 PERF N COMP POOH standing CSH back in derrick 16:45 - 17:00 0.25 PERF N COMP PJSM on Perf Handling 17:00 - 17:17 0.28 PERF N COMP LD 2" perf guns. shots fired 17:17 - 17:52 0.58 PERF N COMP RU injector head and FB BHA 17:52 - 18:00 0.13 WHSUR N COMP RIH to FP, BHA = 12.03' Nozzle OD = 3" 18:00 - 19:15 1.25 WHSUR P COMP Start pumping MeOH, Lay in MeOH @ 60/40 from 2500' to 300'. Circulate 100% MeOH to surface. SI swab (29). 19:15 - 19:25 0.17 RIGD P POST PJSM for BD CT with N2. 19:25 - 19:45 0,33 RIGD P POST PfTest N2lines - OK, Blow down CT with N2 & bleed off. 19:45 - 20:00 0.25 RIGD P POST Set back injector. Meanwhile cleanout pits & tanks, 20:00 - 22:00 2.00 RIGD P POST PJSM. N/D BOP. N/U & PfTest tree cap. Release Rig @ 22:00 hrs on 05/15/2004. Printed: 5/17/2004 8:26:17 AM . . 20-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~ b4- - er-30 Re: Distribution of Survey Data for Well 2-24A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,700.00' MD 9,710.00' MD 11,442.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 11 Date c{ J~,,-.hI>"\ Signed '~J oiÁ¡ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) ')(:¡cI-\J3ð Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 02 02-24A Job No. AKMW3062424, Surveyed: 13 May, 2004 Survey Report 19 May, 2004 Your Ref: API 500292074401 Surface Coordinates: 5949381.34 N, 686809.29 E (70015' 59. 7627w N, 148029' 21.7654w W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 949381.34 N, 186809.29 E (Grid) Surface Coordinates relative to Structure Reference: 602.01 N, 816.26 W (True) Kelly Bushing Elevation: 64.00ft above Mean Sea Level Kelly Bushing Elevation: 64.00ft above Project V Reference Kelly Bushing Elevation: 64.00ft above Structure Reference SpE!ï'ï'Y-SUI'1 ORfL,LING seRVIc:eS A Halliburton Company DEFINITIVE e e Survey Ref: svy4266 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-24A Your Ref: API 500292074401 Job No. AKMW3062424, Surveyed: 13 May, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9700,00 28.700 217.600 8403.49 8467.49 3277,33 S 1832,11 W 5946059,55 N 685059.08 E 3746.21 Tie On Point 9710.00 28,640 217,630 8412.27 8476,27 3281,13 S 1835,03 W 5946055,68 N 685056,24 E 0.617 3750,90 Window Point 9731,26 32,610 216.700 8430,56 8494.56 3289,77 S 1841.57W 5946046.89 N 685049.92 E 18.806 3761.50 9760,65 35.250 212.000 8454,95 8518,95 3303,31 S 1850,80 W 5946033.12 N 685041,03 E 12,658 3777.69 9791.11 35,600 205.500 8479.78 8543,78 3318,77 S 1859,28 W 5946017.45 N 685032.94 E 12,418 3795.30 e 9829,18 33,550 197,830 8511.14 8575,14 3338,80 S 1867,27 W 5945997,23 N 685025.44 E 12.629 3816.82 9866,71 34,800 186,560 8542,22 8606,22 3359.34 S 1871.68 W 5945976,59 N 685021,55 E 17,173 3837.26 9899,68 37,530 180.400 8568,84 8632.84 3378,73 S 1872.82 W 5945957.17 N 685020.89 E 13.780 3855.28 9929.20 39.200 171.620 8592,00 8656,00 3396.97 S 1871.53 W 5945938.97 N 685022.64 E 19.293 3871.20 9963.52 39.200 169,860 8618,60 8682.60 3418.38 S 1868,04 W 5945917,66 N 685026,66 E 3.241 3889.05 9994,10 38.320 177.420 8642.46 8706.46 3437.37 S 1865.91 W 5945898.72 N 685029.26 E 15,735 3905,30 10022,82 37.700 184.100 8665,10 8729.10 3455.03 S 1866,13 W 5945881.06 N 685029.47 E 14.479 3921.36 10051.65 36.650 190.420 8688.08 8752,08 3472.30 S 1868.32 W 5945863,75 N 685027,71 E 13,733 3937,90 10082.89 36,830 200.090 8713,13 8777,13 3490,27 S 1873.23 W 5945845.66 N 685023.25 E 18,511 3956.24 10112.92 37.090 207,830 8737,14 8801.14 3506.74 S 1880.55 W 5945829.01 N 685016,34 E 15.514 3974,26 10139.87 39.990 205.190 8758,22 8822,22 3521.77 S 1888,03 W 5945813.80 N 685009.23 E 12,369 3991,05 10171,01 43.330 203.960 8781.48 8845.48 3540.60 S 1896,63 W 5945794.77 N 685001.10 E 11,042 4011.74 10204,12 47.640 200.620 8804.69 8868,69 3562.44 S 1905.56 W 5945772,71 N 684992,72 E 14.869 4035.30 10231,50 51.150 201,850 8822.51 8886,51 3581,81 S 1913.09 W 5945753,16 N 684985.67 E 13.265 4056,03 10271.74 56.860 205,010 8846,16 8910,16 3611,65 S 1926,06 W 5945723.01 N 684973.45 E 15.544 4088,55 10309,05 63.020 203.430 8864.84 8928.84 3641,09 S 1939.29 W 5945693.25 N 684960.95 E 16,911 4120,82 e 10346,60 67.760 208,180 8880.48 8944.48 3671.79 S 1954.16 W 5945662.19 N 684946.84 E 17.073 4154,93 10364.92 69.780 209,940 8887,11 8951,11 3686.72 S 1962.46 W 5945647,06 N 684938.92 E 14.204 4171.97 10409.88 75,850 213.980 8900,39 8964,39 3723.12 S 1985,20 W 5945610,10 N 684917,09 E 15.996 4214.61 10443.93 80,950 210.460 8907,24 8971,24 3751,33 S 2002,97 W 5945581.46 N 684900,03 E 18,078 4247,71 10488.56 85,870 200.970 8912,37 8976,37 3791,22 S 2022,16W 5945541 ,11 N 684881.83 E 23.821 4291,98 10526.12 87,010 201,670 8914,70 8978,70 3826,14 S 2035,79 W 5945505.86 N 684869.08 E 3,560 4329.37 10576.63 88.420 194.990 8916,72 8980,72 3874,02 S 2051,65 W 5945457.60 N 684854.41 E 13,506 4379.43 10621.60 88.510 188.310 8917.93 8981,93 3918,03 S 2060.72 W 5945413.38 N 684846.43 E 14,850 4423.08 10657,93 85,250 180,580 8919,91 8983.91 3954,16 S 2063,53 W 5945377.19 N 684844,51 E 23,060 4456.94 10685,93 84.810 175.660 8922.33 8986.33 3982.03 S 2062.62 W 5945349,35 N 684846.12 E 17,576 4481,73 10717,63 87.720 173.780 8924.40 8988.40 4013.53 S 2059,71 W 5945317,94 N 684849,81 E 10,922 4508.94 10764,32 90,000 168.980 8925.33 8989.33 4059.66 S 2052,71 W 5945271,99 N 684857.95 E 11.379 4547.64 10804,77 90.000 165.640 8925.33 8989.33 4099.12 S 2043,83 W 5945232,77 N 684867,81 E 8,257 4579,49 1 0835.55 89.210 171.440 8925.54 8989.54 4129.27 S 2037.72 W 5945202.77 N 684874,67 E 19,017 4604,11 19 May, 2004 - 15:31 Page 2 of4 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-24A Your Ref: API 500292074401 Job No. AKMW3062424, Surveyed: 13 May, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10864,73 88,940 176.710 8926.01 8990.01 4158,28 S 2034.71 W 5945173.85 N 684878.40 E 18,082 4629,04 10902,14 89.910 183.920 8926.39 8990.39 4195,66 S 2034,91 W 5945136.47 N 684879,12 E 19.445 4662.91 10939,17 88,770 186.560 8926,81 8990.81 4232,53 S 2038,29 W 5945099,53 N 684876,66 E 7.765 4697.67 10969.39 88,510 190,950 8927.53 8991,53 4262,38 S 2042.89 W 5945069.57 N 684872.80 E 14,548 4726,62 10995.51 87,690 190,130 8928.40 8992.40 4288,05 S 2047.66 W 5945043.80 N 684868.66 E 4.438 4751.85 e 11042,94 84.640 192.180 8931.57 8995.57 4334.47 S 2056.82 W 5944997,16 N 684860,67 E 7.742 4797.72 11075,74 84.110 192.180 8934.78 8998.78 4366.38 S 2063,70 W 5944965,09 N 684854,57 E 1.616 4829,50 11104,93 85.170 194,120 8937,51 9001,51 4394.68 S 2070,32 W 5944936,64 N 684848.67 E 7,548 4857.91 11139.76 85.600 199,920 8940,32 9004,32 4427.86 S 2080.47 W 5944903,22 N 684839.33 E 16,644 4892.24 11171.67 85.780 202,900 8942.71 9006,71 4457.48 S 2092.09 W 5944873.32 N 684828.46 E 9,329 4923,98 11197.35 85.600 201.320 8944.64 9008.64 4481,20 S 2101.73 W 5944849,36 N 684819.41 E 6.175 4949.55 11234,62 87.360 200.970 8946.93 9010.93 4515,90 S 2115,14 W 5944814.35 N 684806,86 E 4.814 4986.65 11277,05 86.570 194,120 8949,18 9013,18 4556,27 S 2127,91 W 5944773.67 N 684795.10 E 16.229 5028.60 11320,88 86.480 186,030 8951,84 9015.84 4599.31 S 2135.56 W 5944730.45 N 684788,52 E 18.425 5070.76 11352.55 85.430 181,280 8954.08 9018,08 4630,83 S 2137.57 W 5944698.89 N 684787,29 E 15.324 5100,11 11385,56 82.270 182.510 8957.61 9021,61 4663,62 S 2138.66 W 5944666,08 N 684787,02 E 10,265 5130.21 11418,38 78.050 181,110 8963,22 9027.22 4695.94 S 2139,68 W 5944633,75 N 684786.80 E 13.527 5159.85 11442.00 78.050 181,110 8968.11 9032.11 4719.04 S 2140.13 W 5944610,64 N 684786.93 E 0,000 5180.91 Projected Survey All data is in Feet (US Survey) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, e The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 205,360° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11442.0Oft., The Bottom Hole Displacement is 5181 ,65ft., in the Direction of 204.395° (True). 19 May, 2004 - 15:31 Page 3 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-24A Your Ref: API 500292074401 Job No. AKMW3062424, Surveyed: 13 May, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9700,00 9710,00 11442,00 8467.49 8476.27 9032.11 3277.33 S 3281,13 S 4719,04 S 1832,11 W 1835,03 W 2140,13 W Tie On Point Window Point Projected Survey e Survey tool program for 02-24A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 0.00 11442,00 9032,11 BP Conventional Gyro (02-24) e 19 May, 2004 - 15:31 Page 4 of4 Dril/Quest 3.03.06.002 TREE :: WELLHEAD :: ACTUATOR :: KB, ELEV :: BF. ELEV :: KOP= Max Angle = Datum MD = Datum TVD = ? FI'vC AXELSON 64' I SAFETY NOTES: . 1994' 3100' 42 @ 6500' 10147' 8800' SS 113-3/8" CSG, 72#, L-aO, 10=12,;347" 2593' ~ - l ~ GAS 5T \/[) TVD DEV TYPE VLV LATCH 1 2706 2706 2 CAI'vCO 2 4754 4568 39 CAI'vCO 3 6438 5844 42 CAI'vCO RK 4 7696 6791 39 CAI'vCO RK 5 8375 7333 35 CAI'vCO RK 6 8453 73'ð1 34 CAI'vCO RK 7 8780 7670 32 CAI'vCO RK 8 8857 7735 32 CAI'vCO RK 9 9200 8030 29 CAI'vCO RK 1 ° 9278 a098 29 CA 1'vC0 RK H5-112" BAKERPBRÀSSY 9361' H9--518" 9373' H5-112" X4-1/2"XO DATE 4 . 9435' 14-1/2" TBG-NR:;, 12,6#, N-80, H ,0152opf, I ' 9447' 9418' 19-518" CSG, 47#, L-80JSOO-95, I ¡ PERFORATION SUIv'illlARY REF LOG: Bf-CS ANGLEA TTOP deg SIZE SPF 2in 6 DATE 5/15/2004 10288' Hxo, C(9l1tralizer 10510' I T' LNR, 29#, L-aO, ,0371 opf, 6,184" H 10512' , REV BY COMIVENTS REV BY COMv1B\1TS DATE 06/14/82 121.27100 02/16101 051.2410 1 08/17103 05/15104 SIS-SL T CONVERTED TO CANVAS S8- \/[) FINAL RN/TP CMO/lLP DLH . . FRANK H. MURKOWSKI, GOVERNOR AI,A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 02-24A BP Exploration (Alaska) Inc. Permit No: 204-030 Surface Location: 1799' SNL, 36' EWL, SEC. 36, TIIN, RI4E, UM Bottomhole Location: 997' SNL, 2089' WEL, SEC. 02, TlON, RI4E, UM Dear Mr. ,McCarty: Enclosed is the,~pproved application for permit to redrill the above referenced service well. ,," This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom 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. P se provide at least twenty-four (24) hours notice for a representative of the Commission ess any required test. Contact the Commission's North Slope petroleum field' tor - 07 (pager). BY ORDER OF THE COMMISSION DATED tbis/Cì day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION CO MISSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: aD Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 11227 TVD 8979ss 7. Property Designation: ADL 028308 o Drill II Redrill 1 a, Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc, 3. Address: P.O, Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1799' SNL, 36' EWL, SEC, 36, T11N, R14E, UM Top of Productive Horizon: 5124' SNL, 1835' WEL, SEC, 35, T11N, R14E, UM Total Depth: 997' SNL, 2089' WEL, SEC. 02, T10N, R14E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: X-686809 Y-5949381 Zone-ASP4 16, Deviated Wells: Kickoff Depth 9840 ft Maximum Hole Angle 900 Top Hole Casinf,1 Weight Grade Coupling Length MD TVD MD TVD (includinf,1 staf,1e data) 3-3/4" 3·3/16' x 2·7/8" 6.2# / 6.5# L-80 TCII I STL 1837' 9390' 8132' 11227' 8979' 98 sx Class 'G' vJG A-LIt O/l.-OOtj RECEIVE, FEB 0 9 2004 / l\1:nbDI! &~' :1 C\Jn~. ('í'~rpve;'pon II Development Oil Multip~ Zone o Development Gas . (slßg~~ne 11. Well Name and Number: PBU 02-24A / 12. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Land Use Permit: 13, Approximate Spud Date: March 16, 2004 /' 14. Distance to Nearest Property: 28,000' 9. Acres in Property: 2560 10, KB Elevation 15, Distance to Nearest Well Within Pool (Height above GL): 64' feet 1,316' 17, Maximum Anticipated Pressures in psig (see 20 MC 253?5) Downhole: 3200 psig Surface: 2320 psig , 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): 10515 9195 None 10471 9155 10288 Structural Conductor 79' 20" 415sxASII 79' 79' Surface 2593' 13-3/8" 2700 sx Fondu, 400 sx PF 'C' 2593' 2593' Intermediate 9692' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 9692' 8461' Production Liner 1114' 7" 360 sx Class 'G' 9398' - 10512' 8203' - 9192' Perforation Depth MD (ft): 10269' - 10341' 20. Attachments aD Filing Fee aD BOP Sketch o Property Plat 0 Diverter Sketch IperfOration Depth TVD (ft): 8973' - 9038' aD Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report aD Drilling Fluid Program aD 20 MC 25,050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer Date: Contact Thomas McCarty, 564-4378 Permit To Drill Number: 209- 0.3"0 50- 029-20744-01-00 Conditions of Approval: Samples Hydro n S Phone 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 DYes ~No ~Yes DNo Permit Approval tJ Date: r Mud Log Required Directional Survey Required See cover letter for other requirements DYes ~No ~ Yes D No ORIGINAL BY ORDER OF THE COMMISSION Daæ ~L~I~t . . BP 02-24A Sidetrack Summary of Operations: / Well 02-24 is scheduled for a through tubing sidetrack with SLB/Nordic 1 in late March. In order for the sidetrack to take place a CIBP will be set at 9875' and the existing 3Y2" tubing tail will be cut (-9860') and pulled. The sidetrack, 02- 24A, will exit out of the existing 7" liner from a mechanical whipstock. The well targets Zone 2 reserves. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) 1) Slickline -Drift/Caliper tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. - already done 2) Eline -Set CIBP at approx. 9875' (8558'TVDss), cut 3-112" tubing at approx. 9860'. / CTD Sidetrack Summary (phase 2) 1) MIRU CTD rig. ,// 2) Pull 3-112" tubing tail, Run Thru tubing whipstock set in 7" liner at approx. 9840' (8527'TVDss) 3) Mill 3.8" window at 9840' md. / 4) Drill 3.75" openhole sidetrack to 11227' planned TD with MWD/gamma ray. 5) Run 3-3/16" x 2-7/8" liner completion. Top of liner will be at approx 9390' md (8132'TVDss) in 4 ¥2" tubiqg' tail. 6) Cement liner, Run MCNL, Perforate. 7) RDMO. Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2: 8.7 ppg used 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. Casing Program: · A 3-3/16" x 2-7~id cemented liner completion from 9390' to TD at 11227'. The liner cement volume is planned to be ~91s of 15.8 ppg class G. Perforate liner as per Asset instructions. Parent Well Casings Burst (psi) Collapse (psi) 9%" 47#, L-80 6870 4760 / 7" 29#, L-80 8160 7020 NA NA Sidetrack Casings 3-3/16" 6.2#, L-80, TCII- Prod LNR 2Ys" 6.5#, L-80, STL - Prod LNR 8520 10570 7660 11170 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. / Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. / · 2-24A will be approximately 1316' ctr-ctr away from well 6-02 at 9800'md · 2-24A will be approximately 28,000' from the unit boundary, (Prudhoe Bay Unit) . . Logging · MWD Gamma Ray log will be run over all of the open hole section. · A CNUGR/CCL cased hole log will be run after the liner has been cemented. Hazards /' · Drill site 2 is not considered an H2S pad. The closest BHL 06-01 had a reading of 4ppm in 2001, the neighboring wells at surface 2-4A and 2-7 A had readings of 3 and 4ppm respectively in 1994. No H2S measurements have been taken for well 02-24A. All H2S monitoring equipment will be operational. · Loss circulation is considered a low risk, no faults are prognosed in the polygon. Reservoir Pressure · Res. press. is estimated to be 3200 psi at 8800'ss (7.0 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) ,/ to surface is 2320 psi. TREE = ' WELLHEAD ? FMC AXELSON 64' 3100' 42 @ 6500' 10147' 8800' SS Max Angle = Datum MD = TVO ! 13-3/8" CSG, 72#, L-80, 10 = 12.347" 2593' -- ¡ 5-1/2" 17#, L-80, .0232 bpf, 4.892" 14-1/2" TBG-NPC,12.6#, N-80, 0152 bpf, 10 = 3,958" 19-5/8" CSG, 47#, L-80/S00-95, 10 = 8.681" ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLE AT TOP ÆRF: 26 @ 10211' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL DATE SEE PAGE 2 FOR ÆRF BREAKDOWN 9692' .1& 13-1/2" LNR-CT, 9.3#, L-80, .0087 bpf, ID 2.992" I 7" LNR, 29#, L-80, .0371 DATE 06/14/02 12/27/00 02/16/01 05/24/01 08/17103 REV BY COMMENTS ORiGINAL SIS~SLT CONVERTED TO CANVAS SIS-MD FINAL RNlTP CORRECTIONS CMO/TLP ÆRF ANGLE CORRECTION DATE REV BY COMMENTS 1994' .. MD TVD DEV 1 2706 2706 2 2 4754 4568 39 3 6438 5844 42 4 7696 6791 39 5 8375 7333 35 6 8453 7397 34 7 8780 7670 32 8 8857 32 9 9200 8030 29 10 9278 8098 29 CAMCO CAMCO CAMeO CAMCO CAMCO CAMCO CAMCO CAMeO CAMCO CAMCO RK RK RK RK RK RK 9347' 9373' 9447' PRUDHOE BAY UNIT Sf> . . / I SAFETY NOTES: TREE = WB..LHEAD = ACTUATOR = KB. B..EV = BF, B..EV = KOP= .~x Angle = Datum MD = . .. Datum lVD = ? FMC AXB..SON 64' 02-24 H5-1/2" CAM BAL-O SSSV NIP,ID = 4.562" I GAS LIFT MANDRB..8 DEV TYÆ VLV LATCH 2 CAMeO DMY RK 39 CAMeO DMY RK 42 CAMeO DMY RK 39 CAMeO DMY RK 35 CAMeO DMY RK 34 CAMeO DMY RK 32 CAMeO DMY RK 32 CAMeO DMY RK 29 CAMeO DMY RK 29 CAMCO DMY RK 1994' 3100' 42 @ 6500' 10147' 8800'88 . PORT DA TE o 01/21/04 o o o 01/21/04 o o o o o o 01/21/04 ST MD lVD 1 2706 2706 2 4754 4568 3 6438 5844 4 7696 6791 5 8375 7333 6 8453 7397 7 8780 7670 8 8857 7735 9 9200 8030 10 9278 8098 ~ ~ 113-3/8" CSG, 72#, L-80, ID = 12,347" 1-1 2593' L I Minimum ID = 2.992" @ 9407' I NO GO SUB ~ f~ 9347' H5-1/2" BAKERPBRASSY 9361' 1- 9-5/8" x 5-1/2" BAKERSAB PKR 9373' H5-1/2" x 4-1/2" XO I 5-1/2"1BG, 17#, L-80, ,0232 bpf, ID = 4.892" H I TOP OF 4-1/2" TBG-NPC H 9373' 9373' TOP OF 7" LNR H 9398' ~ I - I 9407' I- NOGOSUB,ID=2,992" n I 9435' 114-1/2" CAM DB-5 LOG NIP, ID = 3.687" (BEHIND CT LNR) i 9447' H4-1/2" BKR SHROUT SUB I I 9447' H4-1/2" TUBING TAIL (BEHIND CT LNR) I 9418' I- B..MD- TT LOGGED 06/14/82 I ... 13-1/2" LNR LANDED IN DB-5 NIP H 9435' 4-1/2"TBG-NPC,12.6#, N-80, 1-1 ,0152 bpf, ID = 3,958" 19-5/8" CSG, 47#, L-80/S00-95, ID = 8.681" 1-1 9447' I-- 9692' 13-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" H 10261' I ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLEATTOPÆRF: 26 @ 10211' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE SEEPAGE 2 FOR ÆRF BREAKDOWN 10288' HFISH (XO & CENTRALIZER ON 11/07103) 10510' H ÆRF GUN (LOST 06/22/97) I 17" LNR, 29#, L-80, .0371 bpf, ID = 6,184" H 10512' ~-I 10515' ~ DATE 06/14/82 02/16/01 OS/24/01 08/17/03 02/14/00 12/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIS-MD FINAL RNffP CORRECTIONS CMOffiP ÆRF ANGLE CORRECTION JADffiP NO GO SUB/REMOVE PBR MHffiH FISH (XO & CENRALIZER) DA TE REV BY COMMENTS 01/21/04 KSBffiH GLV ClO PRUDHOE BAY UNIT WELL: 02-24 PERMIT No: 1820710 API No: 50-029-20744-00 SEC 36, T11N, R14E, 2019.9' FB.. & 88,14' FNL BP Exploration (Alaska) . PERFORATION SUMMARY REF LOG: BHCS ON 06/05/82 ANGLE AT TOP PERF: 26 @ 10211' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10211 - 10231 S 10/24/86 3-1/8" 4 10231 - 10251 S 10/24/86 3-1/8" 4 10256 - 10261 S 10/24/86 3-1/8" 4 10261 - 10266 S 10/24/86 3-1/8" 4 10269 - 10287 S 10/24/86 3-3/8" 4 10269 - 10289 0 09/18/89 3-3/8" 4 10270 - 10290 S 05/07/89 3-3/8" 4 10291 - 10295 0 09/18/89 3-3/8" 4 10292 - 10296 S 05/07/89 3-3/8" 6 10323-10331 0 06/22/97 3-3/8" 4 10325 - 10333 S 10/15/88 3-3/8" 4 10326 - 10334 0 OS/20/89 3-3/8" 4 10326 - 10334 S 05/07/89 3-3/8" 6 10334 - 10341 0 06/22/97 DATE 06/14/82 02/16/01 OS/24/01 08/17/03 02/14/00 12/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIS-MD FINAL RNrrP CORRECTIONS CMOfTLP PERF ANGLE CORRECTION JADfTLP NO GO SUB/REMOVE PBR MH/TLH FISH (XO & CENRALIZER) 02-24 PERFS . ~ L ~ ~ I - == . .. -.. -.. ~ DA TE REV BY COMMENTS 01/21/04 KSBfTLH GLV C/O I ~ . ~ PRUDHOE BA Y UNIT WB.L: 02-24 ÆRMIT No: 1820710 API No: 50-029-20744-00 SEC 36, T11 N, R14E, 2019.9' FB. & 88.14' FNL BP Exploration (Alaska) Plan: Plan #1 (02-24/Plan#1 02-24A) Created By: Brii Patnis Date: 1/15/2004 (907) 267-6613 ¡9~1)J6j:~~3~q,(~m Cnnlacl infom)ation: Dîf'f,!Gl: r:>rna¡¡: INTEQ' Azimuths to True North Magnetic North: 25,50' Magnetic Field Strenth: 57590nT D~at;gj7i gg.g8.; Model: bggm2003 T ^M ¿ ~~~:1(~~-~~A P1an#1 - . Huuhes Bak&r .... c- ~- o "I"" -371 .... ..... t,.-381 .c 1:: -3900-::- o - !!!!: -41 ..... . :E-4 .. ::I o -4, CI)' BP Amoco WIiLLPATH DETAILS PI....1 02-24A 500212074401 Pa,.II' We'''''''' ..-24 THo 011 MO, 1100.00 RI" 11 124 Sl23f1182 00:00 R.... DatunII V.secUoa ~~ti C:~= ::::~ ..... 20S.3'· 0.00 .... ..... REFERENCE INFORMATION eo.yre~rc':rA~'6~ ~:~:~~~~ ~el:e~~:~~2S;i ~e~:1 North Section (VS) Reference: sbi - 24 (D.DON,O.OOE) Measured Depth Reference: 51: 24 5/23/1982 00:00 64.00 Calculation Method: MinImum CUlVature SECTION DETAILS .. ... ... "'" ..... ..... DLe. Wace vSec T..... 1 "00.00 28.01 217.8. ....,.41 -3314." -IHI.22 0.00 0.00 URea ~ ::::::: :::~ ~~~:~ ::::: ::~;:: ~:~~: :::: =::~ ::::: i ~:r~5 =:: =:!¡ !æ!i ::;~¡! ~=:~ :~: =:gg E::: : ~g¡;::: :::::::: :=~ ::~::: :=::: ~::gg z::: :::t: . 106011.52 88.21 11t1.82 81134.111 -3884.20 -205IÞ.58 t2.00 210.00 43e2.03 to 10743.0IiI eo.OO 201." 8113II.80 -4010.35 -2105.10 12.00 84.00 4ð2$,U 11 11088.00 11.11 lea.", .114&15 -4325.58 -2151.82 12.00 28&.50 4830.38 12 11220.85 88.11 lea.'" ."1a.OO .....11.1. _2122-25 12.00 lao.OO 4854.ea ANNOTATIONS TARGETOETM.S TVD MD "110...10. ,.~ "'" +HI.$ ~Shop" 02-24AP~U 0,00-3971.04-2281.61= M'1A7 1100.00 TIP ~r~n:i 1 :~ti I:H ift 5S 1528.78 "40.00 KOP 8544.32 "'0.00 3 1S1S..8 1110.00 4 116'.18 10010.00 , 87H.o. 10100.00 . '''9.11 10110.00 7 8930.72 10471.12 . 1934.71 10601.13 . ..3...0 1014).01 10 8&45.15 110U.0' 11 "78.00112H.OS TD e 8:50 AM 1/16/200'1 r!·T·t'Tr r'" TiTT í'" -3~00-3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400-2300 -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 , ,,',' I", , ' , ," I"" r ' 40'5041004150420042504300435044004450450045504600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 Vertical Section at 205.36° [50ft/in] 83 ....845(}' C ~851 !2.85' .c b,861 GI Cl86' ¡¡ U871 :e Gl87' > Gl881 ë ... 88' 90 89' · BP-GDB Baker Hughes INTEQ Planning Report e Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0,00 ft 5948800,37 ft 687638.44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: 53.847 N 58.060 W True 1.43 deg Well: 02-24 Slot Name: 24 02-24 Well Position: +N/-S 601.49 ft Northing: 5949381.34 ft Latitude: 70 15 59.763 N +E/-W -814.46 ft Easting : 686809.29 ft Longitude: 148 29 21.765 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 02-24A 500292074401 Current Datum: 51 : 24 5/23/1982 00:00 Magnetic Data: 1/15/2004 Field Strength: 57590 nT Vertical Section: Depth From (TVD) ft 34,00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 02-24 9800.00 ft Mean Sea Level 25.50 deg 80,86 deg Direction deg 205,36 Height 64.00 ft Targets 02-24A Polygon 1 ,1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 02-24A Fault 1 -Polygon 1 -Polygon 2 02-24A T1,1 02-24A T1,2 0.00 -3971,04 -2287.67 5945355.00 684621,00 70 15 20,704 N 148 30 28,314 W 0.00 -3971,04 -2287.67 5945355.00 684621.00 70 15 20.704 N 148 30 28.314 W 0.00 -4629.30 -2287.00 5944697.00 684638,00 70 15 14.230 N 148 30 28,289 W 0.00 -4671,03 -1975.92 5944663,00 684950,00 70 15 13.821 N 148 30 19.240 W 0,00 -4037.76 -1937.19 5945297.00 684973.00 70 15 20.049 N 148 3018,118 W 0,00 -3413,63 -1731.63 5945926,00 685163.00 70 15 26.188 N 148 3012,143 W 0.00 -3382.67 -1648.83 5945959.00 685245.00 70 15 26.492 N 148 30 9.734 W 0.00 -3382.67 -1648.83 5945959.00 685245,00 70 15 26.492 N 148 30 9.734 W 0.00 -3793.98 -1319.92 5945556.00 685584,00 70 15 22,448 N 148 30 0.163 W 8937,00 -3987.12 -2082.99 5945344.00 684826.00 70 15 20,547 N 148 30 22.360 W 8945,00 -4320.14 -2127.27 5945010.00 684790.00 70 15 17,271 N 148 30 23,645 W 8979,00 -44 77.33 -2122.17 5944853.00 684799.00 70 15 15.725 N 148 30 23.496 W 02-24A T1.3 -Plan hit target Annotation 9800,00 9840,00 9860,00 9910.00 10010,00 10100,00 10180.00 10478,52 10608.53 10743.09 8491.47 8526.79 8544,32 8585,88 8665,16 8736.09 8799,11 8930,72 8934,75 8936,80 TIP KOP 3 4 5 6 7 8 9 10 · BP-GDB Baker Hughes INTEQ Planning Report e Annotation 11068,09 8945.15 11 11226.95 8979.00 TD Plan: Plan #1 Date Composed: 1/15/2004 Identical to Lamar's Plan #1 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9800,00 28,07 217.89 8491.47 -3314.92 -1861.22 0,00 0.00 0.00 0.00 9840.00 27.93 217.77 8526.79 -3329.75 -1872.73 0.38 -0,35 -0,30 201.87 9860,00 29.57 216.23 8544.32 -3337.44 -1878.52 9.00 8.20 -7,71 335,00 9910,00 37.90 210.05 8585.88 -3360,73 -1893.53 18.00 16.66 -12,36 335,00 10010.00 38.43 180.73 8665.16 -3418,87 -1909.44 18.00 0,52 -29,32 260,00 10100.00 38.52 206.91 8736.09 -3472,18 -1922.57 18.00 0,10 29,09 100,00 10180.00 38,30 183.64 8799.11 -3519.38 -1935.49 18.00 -0.27 -29.09 260,00 10478.52 88.20 207.42 8930.72 -3762,19 -2016.06 18.00 16.71 7.97 30.00 10608,52 88.27 191,82 8934.75 -3884.20 -2059.56 12,00 0.05 -12.01 270.00 10743.09 90.00 207.88 8936.80 -4010,35 -2105.10 12,00 1,29 11,93 84,00 11068.09 87,17 168.96 8945.15 -4325,56 -2151.82 12.00 -0,87 -11.97 265.50 11226.95 68.11 168.96 8979.00 -4477,16 -2122.25 12.00 -12,00 0.00 180.00 Survey 9800,00 28,07 217,89 8491.47 -3314,92 -1861.22 5946021.46 685031.02 3792,65 0,00 0.00 TIP 9825,00 27,98 217.82 8513.54 -3324.19 -1868.42 5946012.01 685024.04 3804.12 0,38 201.87 MWD 9840,00 27,93 217.77 8526,79 -3329.75 -1872.73 5946006.34 685019.87 3810.99 0.38 201.93 KOP 9850.00 28,75 216.98 8535,59 -3333.52 -1875.61 5946002.50 685017.08 3815.63 9.00 335.00 MWD 9860.00 29.57 216.23 8544,32 -3337.44 -1878.52 5945998.52 685014,28 3820.41 9.00 335.70 3 9875.00 32,04 214.08 8557.21 -3343.72 -1882.94 5945992.13 685010.02 3827.98 18.00 335,00 MWD 9900.00 36,21 211,08 8577.90 -3355.54 -1890.47 5945980.13 685002,78 3841.89 18,00 336.85 MWD 9910,00 37,90 210,05 8585.88 -3360,73 -1893.53 5945974.86 684999,85 3847.89 18.00 339,33 4 9925.00 37,51 205,68 8597,75 -3368.83 -1897.82 5945966.65 684995,76 3857,05 18.00 260,00 MWD 9950.00 37,23 198,28 8617.63 -3382.88 -1903.49 5945952.47 684990,44 3872.17 18,00 263.46 MWD 9975,00 37.41 190,86 8637,52 -3397,53 -1907.30 5945937.73 684987.00 3887.04 18,00 269.34 MWD 10000,00 38,05 183,58 8657,30 -3412.68 -1909.21 5945922,54 684985.47 3901.55 18,00 275.25 MWD 10010,00 38.43 180,73 8665,16 -3418.87 -1909.44 5945916,35 684985,39 3907.24 18,00 281.01 5 10025,00 38,04 185,05 8676,94 -3428,13 -1909.91 5945907,08 684985.15 3915.81 18,00 100.00 MWD 10050.00 37,74 192,36 8696,68 -3443.29 -1912.23 5945891,87 684983,21 3930.49 18.00 96.61 MWD 10075.00 37,91 199.70 8716,44 -3458,00 -1916.45 5945877.06 684979,35 3945.60 18.00 90.83 MWD 10100,00 38,52 206,91 8736,09 -3472.18 -1922.57 5945862,74 684973,59 3961.03 18.00 85,03 6 10125.00 37.95 199,69 8755.74 -3486.36 -1928,69 5945848.40 684967.82 3976.47 18.00 260.00 MWD 10150.00 37.84 192.37 8775.48 -3501.1 0 -1932.92 5945833,57 684963.95 3991.60 18.00 265,67 MWD 10175.00 38,18 185,08 8795,19 -3516.29 -1935,25 5945818.32 684962.01 4006.33 18,00 271.46 MWD 10180,00 38,30 183,64 8799,11 -3519.38 -1935.49 5945815.23 684961.85 4009,22 18.00 277,20 7 10200.00 41.45 186.36 8814.46 -3532.15 -1936,61 5945802.44 684961.04 4021,24 18,00 30,00 MWD 10225.00 45.47 189.31 8832,60 -3549.18 -1938,97 5945785.36 684959,10 4037,64 18,00 27.91 MWD 10250.00 49.55 191.88 8849.49 -3567.29 -1942,37 5945767.17 684956.15 4055.46 18,00 25,77 MWD 10275.00 53.69 194,15 8865,01 -3586.37 -1946,80 5945747.98 684952,20 4074,60 18,00 24.03 MWD 10300.00 57.86 196.19 8879,07 -3606.32 -1952.21 5945727.91 684947,28 4094,94 18,00 22.62 MWD 10325.00 62.06 198.06 8891,58 -3626.99 -1958,59 5945707.09 684941.42 4116,35 18,00 21.47 MWD 10350.00 66.28 199.78 8902.47 -3648.27 -1965,89 5945685.63 684934.65 4138,71 18.00 20.54 MWD 10375.00 70.53 201.39 8911.67 -3670.02 -1974.07 5945663,68 684927,02 4161.87 18,00 19,79 MWD 10400.00 74.78 202.92 8919.12 -3692.12 -1983.07 5945641,38 684918.57 4185.69 18.00 19,19 MWD · BP-GDB Baker Hughes INTEQ Planning Report e Survey 10425,00 79.05 204.40 8924,78 -3714.41 -1992,84 5945618,84 684909,35 4210,02 18,00 18,73 MWD 10450,00 83.32 205.82 8928,61 -3736.78 -2003,32 5945596,23 684899.43 4234,72 18,00 18.40 MWD 10475,00 87,60 207.23 8930,59 -3759.07 -2014.45 5945573,67 684888.86 4259.63 18,00 18,18 MWD 10478.52 88,20 207.42 8930.72 -3762.19 -2016.06 5945570.51 684887.32 4263,14 18,00 18,07 8 10500.00 88.20 204.85 8931,39 -3781.47 -2025,52 5945551,01 684878.35 4284,61 12,00 270.00 MWD 10525.00 88.21 201.84 8932,18 -3804.41 -2035.42 5945527,83 684869.02 4309,58 12,00 270.08 MWD 10550.00 88.22 198.84 8932,96 -3827,83 -2044.11 5945504.20 684860.92 4334.47 12,00 270,18 MWD 10575.00 88.24 195.84 8933,73 -3851.68 -2051,55 5945480.17 684854,07 4359,21 12.00 270,27 MWD 10600.00 88.26 192.84 8934.49 -3875,89 -2057,74 5945455.82 684848.48 4383.73 12.00 270,36 MWD 10608.52 88.27 191.82 8934,75 -3884.20 -2059,56 5945447.46 684846.87 4392.03 12.00 270.45 MWD 10608.53 88.27 191,82 8934,75 -3884,22 -2059.56 5945447.45 684846.87 4392,04 0,00 0.00 9 10625.00 88.47 193.79 8935,22 -3900,27 -2063.21 5945431.31 684843.62 4408.11 12.01 84.00 MWD 10650.00 88.79 196.77 8935,82 -3924.38 -2069.80 5945407.05 684837.64 4432.71 12.00 83.94 MWD 10675.00 89,11 199.75 8936,27 -3948,11 -2077.63 5945383.13 684830.40 4457.51 12.00 83,87 MWD 10700,00 89.44 202,74 8936,59 -3971.41 -2086,68 5945359.61 684821.92 4482.44 12.00 83,82 MWD 10725,00 89.76 205.72 8936,76 -3994,20 -2096.94 5945336.57 684812.23 4507.43 12,00 83,78 MWD 10743,09 90.00 207.88 8936,80 -4010.35 -2105.10 5945320.23 684804.48 4525.52 12,00 83,76 10 10750.00 89.93 207.05 8936,80 -4016.48 -2108.28 5945314.02 684801.45 4532.42 12.00 265,50 MWD 10775,00 89.70 204.06 8936,88 -4039,03 -2119.07 5945291.21 684791.23 4557.42 12,00 265,50 MWD 10800,00 89.47 201.07 8937,07 -4062,12 -2128.66 5945267,90 684782.21 4582.39 12.00 265,51 MWD 10825.00 89,23 198,08 8937,35 -4085.67 -2137.03 5945244,15 684774.43 4607,25 12.00 265.53 MWD 10850,00 89,00 195.08 8937,74 -4109.62 -2144.16 5945220,03 684767,89 4631,96 12.00 265.57 MWD 10875.00 88,77 192,09 8938,22 -4133.92 -2150.03 5945195,60 684762.63 4656.42 12.00 265,61 MWD 10900,00 88,55 189.10 8938.81 -4158.48 -2154.63 5945170.93 684758.64 4680,59 12.00 265,67 MWD 10925,00 88,33 186,11 8939.49 -4183,25 -2157.94 5945146,09 684755,95 4704.39 12.00 265,74 MWD 10950,00 88.11 183,11 8940.26 -4208,15 -2159,95 5945121,14 684754.56 4727.75 12,00 265.82 MWD 10975.00 87,90 180.12 8941,13 -4233.12 -2160.65 5945096.16 684754.48 4750.62 12.00 265,91 MWD 11000.00 87,70 177.12 8942,09 -4258.10 -2160,05 5945071.21 684755,70 4772.92 12,00 266.02 MWD 11025,00 87.50 174.13 8943.14 -4283.00 -2158,15 5945046.37 684758,22 4794,61 12,00 266.13 MWD 11050.00 87.30 171.13 8944.28 -4307.76 -2154.94 5945021.69 684762.03 4815,62 12,00 266.26 MWD 11068,09 87.17 168.96 8945.15 -4325.56 -2151.82 5945003.98 684765,60 4830,36 12,00 266.40 11 11075.00 86.34 168.96 8945.54 -4332.33 -2150.50 5944997.24 684767.09 4835,91 12.00 180,00 MWD 11100.00 83,34 168.96 8947,79 -4356,77 -2145,73 5944972,93 684772.46 4855.95 12.00 180.00 MWD 11125.00 80,34 168.96 8951,34 -4381.05 -2140,99 5944948,77 684777.80 4875,87 12,00 180,00 MWD 11150,00 77,34 168.96 8956,17 -4405.12 -2136.30 5944924,83 684783,09 4895.61 12,00 180,00 MWD 11175,00 74,34 168.96 8962.29 -4428,91 -2131.66 5944901,16 684788.32 4915.12 12,00 180.00 MWD 11200.00 71,34 168,96 8969,66 -4452,35 -2127.09 5944877 .84 684793.47 4934,34 12,00 180.00 MWD 11225,00 68,34 168,96 8978,28 -4475.39 -2122.59 5944854.93 684798,53 4953.23 12.00 180.00 MWD 11226.95 68,11 168.96 8979,00 -4477,16 -2122.25 5944853.17 684798,92 4954,68 12.00 180,00 02-24A T All Measurements are from top of Riser 2/5/2004 ~ CD (/) .- cr: top of bag ~ ~: I;t .> ; i',f¡-;f,:,:1 .. -"F~ BAG ~, !In, ''''1_;,,:",~ bttm of bag middle of slips Blind/Shears .......................... middle of pipes 2-3/8" combi ram/slips TOTs 1 ...... ..."" .............................. -- ,.....-.. middle of flow cross Mud Cross Mud Cross ............. "---" middle of blind/shears I 2-3/8" x 3-1/2" VBR pipe rams I 2-3/8" combi ram/slips r·· ........................ TOTs I ..' ....................... middle of pipe/slips i~f,"J I I , L ~ ::! Sf< >-,'" \ q¡;; æ, " Flow Tee p 055219 DATE 1/6/2004 PR010504C INVOICE I CREDIT MEMO DESCRIPTION PERMIT TO DRILL TilE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLOFtATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX '196612 ANCHORAGE, j\K 99519-6612 PAY: TO THE ORDER OF: B fD r.;".~ "'''. .' . .~ .dJ.. STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 GROSS O~'Âl.fA- NATIONAL CITY BANK Ashland, Ohio f'''; ( t~" ¡ uuu ,., . DATE I 1/6/2004 C;~~~ ~~ __I l VENDOR DISCOUNT NET 56-389 412 No. P 0 5 5 219 CONSOLIDATED COMMERCIAL ACCOUNT DATE January 6, 20041 NOT II- 0 5 5 2 ~ g II- !: 0 ~ . 2 0 :¡ 8 g 5 I: O. 2 78 g b II- AMOUNT *******$1 OO~-ÕO:::] H . e . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERfPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pll..OT (PH) "CLUE" The permit is for a new wellbore segment of existing weD Permit No, API No. Production should continue to be reported as a function· of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(1), aJI records, data and logs aéquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing e:xception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals througb target zones. . . Well bore seg D Annular Disposal D Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 02-24A Program DEV PTD#: 2040300 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Administration 1 PJ¡uYjitfee ~ttached. . . . . . - - - - - - - -- Xes. - - - - - 2 .Le~s~number .appropriate. . . YJ¡s 3 .U.nique wellname.and o~mb.er . - - - - - - - - - - - - - - - - - - - ........ Y~s.. - - - - - - - - - - - - - -- 4 Well Jocated ina qefined .pool Xes 5 WeJlJocated prpper .distance from driJling unilb9und.ary . Xes. 6 WellJQcated proper .distance. from Qther welJs. YJ¡s. - - - - - 7 .S.ufficient .acre~~eay~ilable in drilliog unit. . . . . . YJ¡s. 8 JtdJ¡viated, js weJlbore plaUncJuded . Xes 9 Operator ()nl~ ~ffected PClrty. - - - - - - - - - - - YJ¡s - - - - - - 10 .Opecator has.apprppriate. bond inJorce . . . . . . . . . . . . . . . . . .. .. . . . . .Y~s.. - - ~ - - - - - - - - - - - - 11 PJ¡rmit c.ao be iss~ed withQut cOMervaJion order. . . Xes. Appr Date 12 Permit cao be iss~ed without ~dministrati\(e.approval . . . Xes. - - - -- RPC 2/9/2004 13 Can permit be approved before 15-day wait Yes 14 Well JQcatJ¡d within area and strata .aut\1orized by.lojectipo Order # (put 10# in c.omm~ots) (For. NA - - - - - 15 .AJI we IJs. with in Jl4JlJile.area.of reyiew id.eot[fied (FprservjCce-"v.ell onl~L . . . . . . . . . . . . . . NA - - - - - ~ - - - - - - - - - 16 PJE~-produced injector; .duration.of pre-production less than 3 months. (for.service well onJy) . . NA - - - - - 17 ACMP Finding .of Con.sisteocy has been Jssued. for this pr9iect NA Engineering 18 .C90ductor string.prQvided . . . - - - - - - NA 19 S.urface.casing.protec.ts all.known. USDWs . - - - - - - - - - - - - - NA 20 .CMT v.ol adequ.ate to circJJlate o.ncond.uçtot 8. surt ~g . . NA - - - - - 21 .CMT vol adequ.ateJo tie-inJQng .string to surf csg. . . . . . . NA - - - - - - - - - - 22 CMTwill coyer all knownpro.dUGtiye hQri~ons. . . . - - - -- Xes 23 .C.asiog des[gos ad.eQua.te fpr C,r, B.& p.ermafrpst - - -- . . . YJ¡s 24 .Adequatetan.kage.or reserve pit. - - -- - - - - - - - - - - Xes CTDU. - - - - - 25 JtaJe-prilt \'1é¡s.a l0:403 fQr abandonment beJ¡O apprQved . YJ¡s * 26 .A.dequatewellboresep~ratio.n-Pfoposed. . . . . . . . . . . . . . . . . . . . . . . . . . Yes - - - - - - - - - - - - - -- 27 Jtdjvecter required, dQes it meet reguJations. NA Sidetraçk. Appr Date 28 Drilliog fluid program schematic & e<l-uip Jistadequate. - - - - Xes Max MW8, 7. ppg.. WGA 2/10/2004 29 .B OPE s , do Jhey meetreguJation . Y~s 30 BOPEpress ratiJlg appropriate; .test to (puJ psig in .comments) YJ¡s Test to 3500 psi. . 131 .C.hoke.manifold compJies w/APl RP-53 (May 84). . YJ¡s - - - - 32 WQrk willoGc.ur withoutoperatjon.shutdQwn. . YJ¡s - - - - - 33 Js presence of H2S gas prob.able . ~ - - - - N.o l\JoLdesignated .H2S pad. 34 Meçbanicalcondjt[oo pf wells within AOß verified (For_s_ervjce w~1J only). NA ~ Geology 35 PJ¡rmit C.an be issu.ed wlo hydrogen sulfide meCls_ures. . . - - ~ - - N.o. 36 .D.ata.presented Qn. pote.ntial ove.rpTeSS\.lr~ .zones. . _ . . . . NA Appr Date 37 SJ¡isrnic.analysjs Qf shaJlow gaszPJles. . . . NA ~ - - - - ~ - - ~ - - - RPC 2/9/2004 38 _S~abed .conditioo survey (if off-sh.ore) . . NA 39 . CQnta.ctnam.elpÞoneJor.weels.ly progress.report$ [exploratoryooly]. . .NA Geologic Engineering Date Public Date Commissioner: Date: Commissioner: Commissioner DT~ ~ 011- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e e c:2ocf /o~ $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 13 14:21:09 2004 :1/~l~fe Sperry-Sun Drilling Services LIS Scan utility Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 041 09/13 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/09/l3 Origin..... ..............STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-24A 500292074401 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 13-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003062424 S. LATZ WHITLOW/EGBE MWD RUN 4 MW0003062424 S. LATZ WHITLOW/EGBE MWD RUN 5 MW0003062424 S. LATZ WHITLOW/EGBE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0003062424 S. LATZ WHITLOW/EGBE MWD RUN 7 MW0003062424 S. LATZ HILDRETH/EGB # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 UN l4E 1799 36 64.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.625 7.000 9710.0 ~=<ECEtVED # REMARKS: r"I'\ II .- LV J.~:~ f~\çì$;~11 Oi! & Gas Cons. COffiinisskm /,~èi1Qrag~ e e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 2-24 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9710'MD AND THE BOTTOM WAS AT 9728'MD. 4. MWD RUNS 2 - 7 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO PROGRESS WAS MADE ON MWD RUN 1. THE WHIPSTOCK WAS POSITIONED ON MWD RUN 2 AND THE WINDOW WAS MILLED. ONLY l' WAS MADE ON MWD RUN 3. 5. DUE TO A TOOL PROBLEM, REAL-TIME SGRD DATA ARE PRESENTED FROM 11102'MD TO TD (11442'MD). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-24A WELLBORE ON 14 MAY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 8 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 2 - 7 REPRESENT WELL 2-24A WITH API#: 50-029-20744-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11442'MD/8968'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9657.0 9731. 0 STOP DEPTH 11412.5 11443.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9657.0 9660.0 9667.5 9672.0 9680.0 9681.5 9685.5 9691. 0 GR 9657.0 9660.0 9667.0 9671.0 9679.0 9680.5 9684.5 9690.0 e e 9699.5 9706.0 9708.5 9710.5 9713.0 9715.5 9717.5 9719.0 9721.0 9726.5 9736.0 9739.5 9743.0 9746.0 9753.0 9757.5 9767.0 9768.0 977 2.0 977 3.5 977 6.5 9778.5 9780.0 9783.5 9786.5 9795.5 9800.0 9802.0 9805.0 9808.5 9813.5 9816.0 9821.0 9824.5 9829.0 9832.5 9835.0 9842.5 9848.5 9855.0 9860.0 9866.0 9869.5 9873.0 9876.0 9884.0 9888.0 9893.5 9895.5 9898.0 9903.5 9906.0 9909.5 9915.0 9918.0 9922.5 9928.0 9930.0 9933.5 9938.0 9939.5 9953.0 9956.5 9959.0 9961. 5 9964.0 9968.5 9970.0 9972.5 9976.5 9979.5 9984.5 9987.0 9991. 0 9992.0 9699.0 9705.5 9708.0 9710.0 9712.5 9714.0 971 7 . 0 9718.5 9720.0 9726.5 9736.0 9738.5 9742.0 9745.0 9752.0 9757.0 9765.5 9766.5 9771. 0 9772.0 9775.5 9777.5 9779.0 9782.0 9785.5 9794.5 9799.0 9801. 0 9803.5 9807.5 9812.5 9815.0 9820.0 9823.5 9827.5 9831. 0 9834.0 9841. 5 9847.5 9856.0 9858.5 9865.0 9868.5 9872.5 9875.5 9883.0 9888.0 9893.0 9895.0 9898.0 9902.5 9905.5 9908.5 9914.0 9917.0 9922.5 9927.0 9929.5 9934.0 9939.0 9940.5 9953.0 9956.0 9959.0 9962.0 9963.5 9968.0 9969.0 9972.5 9976.0 9978.5 9984.0 9987.0 9990.5 9992.0 e e 9994.0 9998.0 10001.5 10004.0 10006.5 10012.0 10014.0 10026.0 10036.5 10046.5 10048.0 10050.5 10055.0 10073.0 10076.5 10078.5 10081. 5 10086.5 10091. 0 10093.5 10097.5 10100.0 10102.5 10105.0 10115.0 10119.0 10130.0 10144.0 10158.5 10170.0 10173.0 10176.0 10184.5 10197.0 10201. 5 10212.5 1021 7.5 10223.0 10225.0 10232.0 10236.5 10248.5 10255.5 10260.5 10266.5 10269.0 10273.0 10275.0 10285.5 10303.5 10305.5 10315.5 10324.5 10336.0 10340.0 10343.0 10347.0 10367.5 10378.5 10383.5 10407.5 10414.0 10419.0 10422.5 10426.5 10443.0 10449.0 10452.5 10456.0 10458.0 10463.0 10469.0 10476.5 10481.5 10487.5 9994.0 9997 .5 10002.0 10004.0 10007.0 10012.0 10013.5 10026.0 10036.0 10045.5 10047.5 10050.5 10054.5 10072.0 10076.5 10078.5 10081.0 10086.5 10090.5 10092.5 10097.5 10099.5 10102.5 10104.5 10114.5 10116.5 10129.5 10143.5 10156.5 10169.5 10173.0 10174.5 10183.5 10196.5 10202.0 10211. 5 10217.0 10222.5 10225.0 10231. 0 10237.0 10248.5 10258.0 10261. 5 10267.0 10269.5 10272.0 10273.5 10282.0 10302.5 10305.0 10315.0 10324.5 10337.5 10340.5 10344.0 10348.0 10367.0 10378.5 10383.5 10407.0 10413.5 10418.0 10421. 5 10426.5 10441.5 10446.5 10451.5 10454.0 10457.5 10462.0 10468.0 10476.0 10481. 5 10486.5 e e 10517 .0 10527.5 10533.5 10539.0 10544.5 10546.5 10549.0 10551. 5 10553.5 10562.0 10568.0 10575.5 10581. 5 10586.5 10592.0 10599.0 10618.0 10632.5 10640.5 10647.5 10653.0 10658.0 10661.5 10668.5 10680.5 10682.5 10690.0 10695.0 10696.5 10725.0 10735.0 10738.5 10741. 0 10745.5 10751.0 10754.5 10761.5 10766.5 10782.0 10795.5 10803.5 10809.5 10814.5 10819.0 10824.5 10832.0 10835.5 10840.5 10843.5 10851.5 10864.0 10872.5 10880.0 10892.5 10899.5 10917.5 10930.5 10944.5 10961. 0 10967.0 10974.5 10979.0 10990.5 11000.0 11009.0 11017.0 11029.0 11035.0 11053.0 11064.0 11071. 5 11073.5 11075.5 11078.0 11080.5 10517.0 10527.0 10532.5 10538.5 10543.5 10546.0 10548.0 10550.0 10552.5 10562.5 10567.0 10574.0 10581. 0 10586.0 10592.5 10598.0 10617.5 10632.0 10643.0 10649.5 10655.5 10659.0 10663.0 10670.5 10681.0 10683.5 10691.5 10696.0 10698.5 10726.0 10736.5 10739.5 10743.0 10745.5 10751.5 10756.5 10763.5 10769.5 10782.5 10794.5 10802.0 10809.5 10815.0 10822.5 10826.5 10832.0 10840.0 10844.0 10846.5 10853.5 10864.5 10874.5 10882.5 10895.0 10901.5 10920.0 10932.5 10947.0 10963.0 10969.5 10977.0 10981.5 10992.5 11002.0 11010.5 11019.5 11031.0 11039.0 11058.5 11066.0 11072.5 11075.0 11078.0 11080.0 11 081. 5 e e 11096.5 11098.5 11116.5 11124.0 11135.0 11144.5 11159.0 11169.0 11189.5 11202.0 11224.0 11240.5 11244.5 11248.0 11250.5 11266.0 11268.0 11274.0 11277.0 11279.5 11286.0 11294.0 11296.5 11302.5 11305.5 11443.0 $ 11098.5 11100.0 11117.0 11125.5 11135.0 11143.0 11160.0 11170.0 11190.0 11201. 0 11222.5 11239.0 11243.0 11248.5 11251.0 11265.5 11268.5 11275.0 11277.0 11280.0 11284.5 11292.5 11297.5 11303.0 11304.5 11442.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 2 4 5 6 7 MERGE TOP 9657.0 9690.0 9752. 0 10128.0 10680.0 MERGE BASE 9689.5 9752.0 10128,0 10680.0 11442.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code Offset o 4 8 Channel 1 2 3 MWD MWD First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9657 11443 10550 3573 9657 11443 ROP MWD FT/H 0.05 1219.16 87.493 3425 9731 11443 GR MWD API 15.14 957.75 49.2171 3512 9657 11412.5 First Reading For Entire File..........9657 Last Reading For Entire File...........11443 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 e Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/l3 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR $ 2 e header data for each bit run in separate files. 2 .5000 START DEPTH 9657.0 STOP DEPTH 9689.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: 07-MAY-04 Insite Memory 9732.0 9710.0 9732.0 .0 .0 TOOL NUMBER TLG002 3.625 9710.0 Bio 8.30 60.0 .0 o .0 .000 .000 .000 .000 .0 141.7 .0 .0 e $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type. ....0 Logging Direction................. Down Optical log depth units...... .... . Feet Data Reference Point....... .... ...Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 Name Service Unit DE PT FT GR MWD020 API Min 9657 42.34 Max 9689.5 77.54 Mean 9673.25 61. 4703 Nsam 66 66 First Reading For Entire File..........9657 Last Reading For Entire File...........9689.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 9690.0 9731. 0 STOP DEPTH 9721.5 9752.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 09-MAY-04 Insite Memory 9752.0 9732.0 9752.0 e First Reading 9657 9657 Last Reading 9689.5 9689.5 e BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.............,....... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 .0 .0 TOOL NUMBER TLG002 3.800 9710.0 Flo Pro 8.60 65.0 9.5 25000 5.5 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 129.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9690 9752 9721 125 9690 9752 ROP MWD040 FT/H 0.05 23.33 13.1891 43 9731 9752 GR MWD040 API 48.69 876.07 108.907 64 9690 9721.5 First Reading For Entire File..........9690 Last Reading For Entire File...........9752 File Trailer Service name... ..........STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 Fi 1 e Type................ LO e Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/l3 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 5 .5000 START DEPTH 9722.0 9752.5 STOP DEPTH 10098.0 10128.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: ll-MAY-04 Insite Memory 10126,0 9752.0 10126.0 28.6 39.2 TOOL NUMBER TLG002 4.125 9710.0 Flo Pro 8.60 65.0 9.3 24000 5.8 .000 .000 .000 .000 .0 137.5 .0 .0 e e # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.. ...................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD050 MWD050 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9722 10128 9925 813 9722 10128 ROP MWD050 FT!H 0.06 87.14 24.1137 752 9752.5 10128 GR MWD050 API 19.99 957.75 81. 6803 753 9722 10098 First Reading For Entire File..........9722 Last Reading For Entire File...........l0128 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 6 .5000 START DEPTH 10098.5 10128.5 STOP DEPTH 10650.0 10680.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): 12-MAY-04 Insite Memory 10677.0 10126.0 e BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units. ..........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 MWD060 MWD060 Nsam Rep 1 68 1 68 1 68 Code 10677.0 37.1 88.7 TOOL NUMBER TLG016 4.125 9710.0 Fl0 Pro 8.80 65.0 9.1 24600 5.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 141.7 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10098.5 10680 10389.3 1164 10098.5 10680 ROP MWD060 FT/H 1. 78 1219.16 107.758 1104 10128.5 10680 GR MWD060 API 19.13 104.54 35.5586 1104 10098.5 10650 First Reading For Entire File..........10098.5 Last Reading For Entire File...........l0680 File Trailer Service name............. STSLIB. 005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ . . e File Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/13 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.005 6 7 .5000 START DEPTH 10650.5 10680.5 STOP DEPTH 11411. 5 11442.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL 1FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION IDEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES IPPM): FLUID LOSS IC3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: e 13-MAY-04 Insite Memory 11442.0 10677.0 11442.0 84.8 90.0 TOOL NUMBER TLG002 3.750 9710.0 Flo Pro 8.70 65.0 9.1 25000 6.2 .000 .000 .000 .000 .0 154.3 .0 .0 e e $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point..............Undefined Frame Spacing......... ............60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD070 MWD070 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10650.5 11442 11046.3 1584 10650.5 11442 ROP MWD070 FT/H 1. 78 1079.63 105.023 1524 10680.5 11442 GR MWD070 API 15.14 160.33 39.8396 1523 10650.5 11411. 5 First Reading For Entire File..........l0650.5 Last Reading For Entire File...........11442 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/13 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/09/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. ....................04/09/13 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
