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199-078
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC X-11A PRUDHOE BAY UNIT X-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 X-11A 50-029-20471-01-00 199-078-0 W SPT 8147 1990780 2037 1095 1095 1095 1095 10 23 24 24 4YRTST P Josh Hunt 7/20/2024 Good test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT X-11A Inspection Date: Tubing OA Packer Depth 349 2279 2234 2219IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240720110321 BBL Pumped:3.9 BBL Returned:4.3 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 11:53:22 -08'00' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWelIIntegrity@hilcorp.com> Sent: Wednesday, July 8, 2020 9:33 AM To: Stan Golis; Bo York; Erik Painter; Kenny Wingard; Edward Apodaca; David VanDenburgh; Alaska NS - PB W - GC1 - Field Lead Operator; Alaska NS - PB - EOC Specialists; John Menke; Wallace, Chris D (CED) Cc: Sternicki, Oliver R; Aras Worthington; Wyatt Rivard; Regg, James B (CED) Subject: OPERABLE: Injector X-1 1A (PTD #1990780) MIT -IA Passed All, Injector X -11A (PTD #1990780) was made Under Evaluation on 06/14/20 for IA re -pressurization observed while shut in post MI injection. On 6/15/20 the IA pressure was bled from 1110 psi to 540 psi and subsequent monitoring determined 10 psi / day re -pressurization. The well was put on water injection on 06/30/20 and subsequent MIT -IA passed to 2671 psi on 07/01/20 verifying two competent well barriers. The IA pressure has remained stable at 160 psi post MIT -IA bleed down. The well currently has no utility for further MI injection and sundry application for PWI only conversion is forthcoming. The well is now classified as Operable for continued PWI injection. Please respond with any questions. Ryan Holt Hilcorp Well Integrity / Compliance 907-659-5102 Frbm,: AK, GWO SUPT Well Integrity Sent: Sunday, June 14, 2020 7:26 AM To: Ak, OPS GC1 Field PTL <AkOPSGC1Field PTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1Wellp Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontroller bp.com>; AK, OPS Well Pad CX <AKOPSWeliPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.c >; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESG BW' estWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpeciali @bp.com>; Semmens, Travis <travis.semmens@bp.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>;'ch ris. aIlace@alaska.gov'<chris.waIlace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDH elllntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS 'pp User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@6p-.,q'om>; Dempsey, David G <David.Dem pseyl@bp.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Sternicki, Oliver R <Olive`.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Mcmullen, John C <John.McM`ullen@bp.com>; Lau, Jack <Jack.Lau@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; egg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector X -11A (PTD #1990780) TxIA communnkotion All, Injector X -11A (PTD #1990780) was made Operable on 06/11/19, after a tubing leak was repaired with a patch. The well has again begun to exhibit TxIA communication. It is currently shut in. The well is now classified UNDER EVALUATION for diagnostics and repair. By Jody Colombie at 3:22 pm, Jul 08, 2020 SFD 7/9/2020DSR-7/8/2020 RBDMS HEW 7/9/2020 MGR09JUL2020 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, June 11, 2019 8:30 AM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J; Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector X -11A (PTD #1990780) TxIA communication mitigated with tubing patch 23 Injector X -11A (PTD #1990780) was made under evaluation on 5/15/2019 in order to monitor for IA repressurization post tubing patch repair. The well was brought on MI injection on 5/16/2019 and has shown no signs of TAA communication during the 28 day UE period indicating a successful repair. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GNCL.WE ll Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, M&IL 5, 2019 8:25 AM To: AK, OPS EOC Specialists SEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1Field PTL@bp.com>; AK, OPS GCI Wellpad Lead <AKOPSGCI dLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl Com>; AK, OPS Well Pad CX <AKOPSWeliPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RE East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt .com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@b >; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com>;'chris.wallace@alaska.gov'<chris.wallace ka.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; A , O DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsl e' In rityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrit ell Information MEMORANDUM Packer State of Alaska Initial 15 Min 30 Min 45 Min 60 Min Alaska Oil and Gas Conservation Commission TO: Jim Regg �yDATE: P.I. Supervisor �E7/ �(3`rl� Thursday, May 30, 2019 SUBJECT: Mechanical Integrity Tests / 2374 2334 . BP EXPLORATION (ALASKA) INC. — - 2332 " PT X-1IA FROM: Bob Noble 2500 PRUDHOE BAY UNIT X-1 IA Petroleum Inspector 2972 2958 2945 2935 " BBL Pumped: 5.4 "BBL Returned: Ste: Inspector OA 153 430 Reviewed By: 475 477 - Intervall P.I. Suprvj--73p— OTHER LPIF ` P NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X -I IA IInsp Num: mitRCN190527091940 Rel Insp Num: API Well Number 50-029-20471-01-00 Inspector Name: Bob Noble Permit Number: 199-078-0 Inspection Date: 5/26/2019 Thursday, May 30, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min X-1 IA Type In' i -^47 yp 1 a TVD TD 81- -- _ - Tg 2329 � Tubing - 233> � 2374 2334 . L 2332 — - 2332 " PT 1990780 'type 'rest SPT Test psi 2500 r IA 251 3000-': 2972 2958 2945 2935 " BBL Pumped: 5.4 "BBL Returned: 5 9 OA 153 430 450 469 475 477 - Intervall OTHER LPIF ` P - - - Notes: MIT -IA post tubing patch, Sundry 319-022, tested to 3000 psi Thursday, May 30, 2019 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, May 15, 2019 8:25 AM To: AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector X-1 1A (PTD #1990780) TAA communication mitigated with tubing patch, MIT -IA passed All, Injector X -11A (PTD #1990780) was made not operable on 11/8/2018 for having a confirmed tubing leak at 261'. On 2/22/2019 E -line completed setting a tubing patch over 253'-268' MD and the well passed a subsequent MIT -IA to 3,382' on 3/5/2019. The well is now ready to be put on injection and monitored for IA repressurization. At this time the well is reclassified as Under Evaluation. An AOGCC MIT -IA will be performed once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 FroffrA GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Mond -al, ember 3, 2018 12:47 PM To:'chris.wallace@alaska. .wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AKOPSGC1FieldO com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WelIpad Lead @bp.com>; AK, OPS PC Ops Beads KOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad AB <AKOPS1WAe-tl B@bp.com>; AK, OPS Well Pad CX <AKOPSWeliPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp. AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AK, OPS Pipeline Compl Specialist<AKOPSPipelineComplSpecialist@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Boman, Wade <Wade.Boman@bp.com>; Igbokwe, Chidiebere` rsc�,cIvcv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 2 8 2019 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shu�t{n1 CC Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Tubing Patch 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 199-078 3. Address. P.O. Bax 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service 0 1 6. API Number: 50-029-20471-01-00 7. Property Designation (Lease Number). ADL 028313 8. Well Name and Number: PBU X -11A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9768 feet Plugs measured None feet true vertical 8972 feet Junk measured 9640 feet Effective Depth: measured 9737 feet Packer measured 8266, 8417 feet true vertical 8983 feet Packer true vertical 8001, 8149 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2626 13-3/8" 37-2663 37-2663 5380 2670 Intermediate 8987 9-5/8" 35-9022 35-8741 6870 4760 Liner 692 7" 8491-9183 8221-8899 8160 7020 Liner 1299 2-7/8" 8469-9768 8199-8972 13450 13890 Perforation Depth: Measured depth: 9595-9685 feet True vertical depth: 9034-9003 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 32-8524 32-8253 4-1/2" HES TNT Perth Packer 8266 8001 Packers and SSSV (type, measured and 4-1/2" Baker SAB -3 Packer 8417 8149 true vertical depth) 2-7/8" HES MCX SSSV 2199 2199 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 15719 0 400 2000 Subsequent to operation: 0 0 0 0 190 14. Attachments: (2ywred per2o MC 25ms25. W1, &25,20) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-022 Authorized Name: Glasheen, Brian P Contact Name: Glasheen, Brian P Authorized Title: Production Engine 04 4 Contact Email: Brian.Glasheen@bp.com Authorized Signature: - Date: .i—g Contact Phone: +1 907 584 5905 Forth 10-404 Revised 04/2017 11 1 /t Y11q RBDMSG6 MAR 2 9 2019 SubmitO Original Only Daily Report of Well Operations PBU X -11A ACTIVITYDATF SI IMMARY '**WELL FOUND S/I ON ARRIVAL*** SET 4-1/2'x2-7/8" NIPPLE REDUCER IN X NIP @ 2199' MD (confirm set w/ checkset) SET 2-7/8" XX PLUG IN NIPPLE REDUCER @ 2199' MD. MIT -T TO 2250 PSL(SEE LOG FOR DETAILS) EQUALIZE & PULL 2-7/8" XX- PLUG FROM 2199' MD. EQUALIZE 2-7/8" XX -PLUG @ 8292' SLM 2/18/2019 **'*CONT WSR ON 2-19-19"" "**CONT WSR FROM 2-18-19***(patch/liner) PULL 2-7/8" XX -PLUG FROM 8292' MD. 2/19/2019 *'*'WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*'*' *"WELL S/I ON ARRIVAL*** (patch) RIG UP HES ELINE UNIT 4863 2/21/2019 *"CONT. ON 02/22/2019 WSR"* ***CONT. FROM 02/21/2019 WSR*'* (patch) LRS LOADED WELL WITH 180* 1% kcl AND 180* FP DIESEL. RIH W/ 4.5" BAKER 45 KB PATCH SET BAKER 45 KB ONE TRIP PATCH FROM 253'- 268' ELMD. TOP OF PATCH= 251'. BOTTOM OF PATCH= 273' CCL TO TOP OF MID ELEMENT = 8.8', CCL STOP AT 244.1' ELMD... see log for patch details 2/22/2019 ***JOB COMPLETE, READY FOR SLICKLINE*** "*WELL S/I UPON ARRIVAL**' (patch tubing / liner) DRIFTED W/ 2.25" CENT, 1.5" SAMPLE BAILER TO 2,300' SLIM (no issues) SET 2 7/8" MCX (.75" bean, BPX-205) IN NIPPLE REDUCER @ 2,199' MD (verified w/ check set) 3/2/2019 '*"WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** TRU= 4-11W CMNFLS VVELLFEAD= GRAY ACTUATOR= BAKERC KB. 9F/ = 74.0.5' BF. BEV =39.95' OF 2-7/8" LNR 8489' KOP= 3100' Affix Angle = 1120 @ 9718' Datum MD 915T DetumTVD= 8800 -SS, X 11 A SAFETY NOTES: 1-12S READINGS AVERAGE 125 ppm WHEN ON Mi. WELL REQUIRES A SSSV WHEN ON ML WELL ANGLE > 700 @ 9400'. —4-12- GS FISH NErK SET @ TOP OF 2-718" LNR"00 4-112" BKR PATCH 251' - 273' D= 2.45, 2189' 4-12" HES X NP, D = 3.813" (02122119) 2199' 4-12" X 2-7/8" NP Fes, D=2.313" 2686' 9-518" DV PKRCOLLAR 13-318" CSG, 72#, L-80, D=12.34T 2662' Minimum ID = 2.313"@ 2199' 41/2" X 2-7/8" NIP RED 12.9#, L-80 VT, .0152 6pf, D = 3.958" 8360' TBG STUB (01/12/18) 8366' TBG, 12.80, 1 8230' 1 8266' 1--19-5/8" X 4-1/2" HES TNT RRZ D = 3.903" 8292' 4-12" HES X NP, D = 3.813' 829T 4-1/2- X 2-7/8" NIP REDl1CHR, ID = 2.313' 8396' 1 14-12'BAKBi SBRSEALASSY 19-5/8" CSC. 47#. L-80. D = 8.681" 1 PEF FORATDN SIAMMRY REF LOG: MVID GR ON 10/15199 ANGLEAT TOP PERF. 106" @ 959T Note: Refer to Production DB for historical pert data 8416' s-5/8" x a-12" Bq2 SAB -3 R(R D = SPF 8459' 4-12" 0715 X NP, D = 3.013" OF 2-7/8" LNR 8489' DATE 2' 4 8469' 3" OffLOY SLV, ID=2.37" r—�I. 10/17199 03/27/19 BTN'JM) SET BKR PATCH (0222/19) 01/18118 8490' 4-12' OTIS XN NP. D = 3.725" 19-5/8" CSC. 47#. L-80. D = 8.681" 1 PEF FORATDN SIAMMRY REF LOG: MVID GR ON 10/15199 ANGLEAT TOP PERF. 106" @ 959T Note: Refer to Production DB for historical pert data SIZE SPF I MH2VAL I Opn1Sgz DATE 2' 4 9595- 9685 O 10/17199 7- 8622' H 4-12" TBG TAIL, D = 3.958" 8525' HELmOTT LOGGED 1027/99 MLLOUT WINDOW (X -11A) 9183'-9190' 9640' CTM FISH: 2 PECES OF PACKING FROM 2-7/8" XX RUG (02/05/18) DATE fa=ll BY COMMENTS DATE REV BY COMMENTS 01/30181 ORIGINAL COMPLETION 02/07/18 JL/JMJ PLUG RJLLEDLffT RICES DH 10117199 SIS- SIDETRACKCOMPLEFION 01/09/19 ZV/JM) SET NPFED1XEt&xX PLUG 01113118 P-272 RNO 03/27/19 JMGIJM) SET NP FEE) &RLL PLUG 01/16118 JM) DRLG HO 0OR7ECTKM 03/27/19 BTN'JM) SET BKR PATCH (0222/19) 01/18118 Z61JMD FMN-ODEAPPROVAL 02/05/18 GJB/JM RLLID Px PLUG (02/02118) PBTD H 973T PRIDHOE BAY LIIf WILL X -11A P$iMT No: F1990780 AR No: 50-029-20471-01 SEC 7, T10N, R14L 498' Ft,L & 588' FB BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Wade Boman Production Engineer, B&X Pads BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X-11 A Permit to Drill Number: 199-078 Sundry Number: 319-022 Dear Mr. Boman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 40e Daniel T. Seamount, Jr. Commissioner DATED this Z qday of January, 2019. MMS%Ul STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ]AN 9 2 MIQ 1. Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change G arc C Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Tubing Patch 0 2. Operalor Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 199-078 al, 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-20471-01-00 . 99519-6612 Stratigraphic ❑ Service D 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? t Will planned perforations require a spacing exception? Yes ❑ No 0 PBU X -11A 9. Property Designation (Lease Number): I 10. Field/Pools: ADL 028313 i PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD In): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9768 8972 8292 8027 8292 9640 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2626 13-3/8" 37-2663 37-2663 5380 2670 Intermediate 8987 9-5/8" 35-9022 35-8741 8870 4760 Liner 692 7" 8491-9183 8221 - 8899 8160 7020 Liner 1299 2-7/8" 8469-9768 8199 - 8972 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft)' 9595 - 9885 9034-9003 4-1l2" 12.8# L-80 32-8523 Packers and SSSV Type: 4-1/2" HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (ft): 8266, 8001 4-1/2" Baker SAB -3 Packer 8417, 8149 No SSSV Installed 12. Attachments: Proposal Summary RI Wellbore Schematic IZ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service El 14. Estimated Date for Commencing Operations: 2/4/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 8 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 11 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Boman, Wade be deviated from without prior written approval. Contact Email: Wade.Boman(a)bp.00m Authorized Name: Boman, Wade Contact Phone: +1 9075644674 Authorized Title: Production Engineer, B&X pads Authorized Signature: J ;y(„ Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 7� �I G -oil - / Plug Integrity ❑ SOP Test13 Mechanical Integrity Test Location Clearance ❑ Other: K I`T'— � to 06'0cc 1i5/ Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required I� — Ll 4 APPROVED BYTHE p Approved by: COMMISSIONER COMMISSION Date 44 O it, ORIGINAL RBDMS� ®N i �01� A&P22rK0F1 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Zr. t.S I&4C1 10-403 Sundry Application for Well PBU X -11A PTD# 199-078 Expected Start Date: February 4, 2019 Current condition of well: WAG Injection Well, Not Operable, Offline: Water Injection Rate: 0 bw d Injection Pressure: 171 psi Shut-in Wellhead Pressure: 2400 psi Reservoirpressure: 3344 psi Well objective(s): Setting a tubing patch across the leaking connection at 261' MD, addressing the TAA so the well can go back on MI injection. Proposed program: 1. RIH and pull 2-7/8" XX plug from nipple reducer at 8292' MD. POOH. 2. RIH, and set a 2-7/8" nipple reducer in the SSSV nipple at 2199' MD. The nipple reducer will consist of a 3.813" X -lock, 2.313" profile landing nipple, and a muleshoe guide. This will be for holding a reduced size MCX valve in the future, after EL sets the patch. 3. Pump a tubing volume (130 bbls) of 180 -deg F 1% KCL @4 bbl/min into the tubing, to heat tubing in preparation for EL patch set. Follow with 40 bbls of 180 - deg diesel, then have EL set the patch. The tubing will be warmed up for the patch set, any water that could freeze behind the patch will have been displaced, and the tubing will be freeze protected for when EL and FB rig down. 4. At Baker shop, pass a 2-7/8" lock through the patch by hand, ensuring 2-7/8" plugs can pass through it, so SL can set a 2-7/8" MCX valve and for future well secure operations. 5. Install cold temperature 70 durometer seals on the patch, as it will be placed within the permafrost zone. 6. RIH, and set a one-piece 15 -foot element -to -element Baker 45 Flo Guard one trip patch across the tubing connection at 261' MD (according to the attached LDL). The connection across which to place the patch is the one at the bottom of the 5th full length joint in the well, counting from the surface. See the attached LDL screenshot and Tubing Tally for reference. The depths seen on the LDL are 6' less numerically than the depths on the Tubing Tally, so just be aware of this. Place the middle of the patch's bottom element at 268' MD, according to the LDL depths. r BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU X -11A PTD# 199-078 7. RIH, and set a 2-7/8" MCX valve with a 0.75" bean in the reducing nipple @2199' MD. The Wireline Bldg has three of these small 2-7/8" MCX valves on the shelf. POOH. 8. Contact Well Integrity, and inform them that the MI injector has been patched and will need to go on MI injection "Under Eval" to make sure the TAA has been repaired by the patch. Turn well over to Ops for MI injection. A-® C -GL -i o ua lT v, m-5 5 C L, -J wL IL Annotated LDL Log for Patch Placement: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 —` Company BP EXPLORATION (ALASKA), INC. N Well X -11A N a a Field PRUDHOE BAY -2 C Borough NORTH SLOPE state ALASKA o K o �x O m O Surface Location om Br SBNKes ) j ¢ V N 497.95' FNL 8 588.04' FEL Nie o on QT C13 X a` Z Q SEC: 7 INP: 10N RGE: 14E Elerx pn o nm Permanent Datum MSL Ekvavon 0.0' K.8. 7405' r E m a o 21 Log Nieaapred Fran RKB 76 05 FT. Above Peml. Datum OF NA V'u 0 a 1 Seal Numcer 50.029.20471-01 GL NIA _N m L Cd1 Dal, 4-%V- 08 N Run Number One N PB DOrier 9,7 T cg PBTGtogg. _ N d Ta9W Bdtan L M InMNd 8.295 op L Interval S 3 o Open Hue bee NA o 3 0 C j Type RUM l G Ni Gas rp N ij Mat RecoNeC Temp. (deg. F.) 139" w FINAL PRINT 3 iZ Timet/ 11 Ready 2340 m v. � Time L er. Babdn 05:31 L C 3 a d E9apmenl Number SNCP x4519 Lpra Npe am Sk 3 Semce,nMw Nb - 15658 D c Cel B. Suhenek O YMfieebMk3y 2 V2k L Gmy BaendeRecaa TubNg RNCN Run Numb. 0e From Tp Sae Wl From Tc a lar 1260 5u, a . 8.527 Cann RecaC sae Surface t33R' 00m S0 Su rR 2.667 Prot. StM 95!8' a Surtaze 9027 Liner 7- 29.009,180' Laer 27V 61E 8,469' 9.768' BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 N N a a a m -2 C LL o K o �x 8 o QT N c o- o c rnp� r N g _N m L Cd1 l N Z N cg i v 3 o a� H $ m y Zo o 3 0 C j rp N ij w 3 iZ m v. � L C 3 a d � LL C g' 3 J D c O N BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU X -11A PTD# 199-078 First full joint 2 pups 4 full joints Place middle of patch �y across this / connection Set lower / element of patch at 268' 0 Tree 100 11 Leak Signature i 300 1111111071 0 Pressure Temperature - \Temperature (Well Injecting. No IA Bleed) r. Temperature (Well Injecting, Open IA Bleed) �,r = i r y - emperature (Plug in X -Nip. Open IA Bleed) ---0- I Temperature (Plug in41� X-Nip, No IA Bleed) Differential Temperature r � — LeakPomt`" - A (Upper Tool - Leak Active) BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TfaR==. 4-1/8.OW FLS N9IREAD= GRAY ACn1ATOR- BAKER KB. ELEV = 74.05' BF. ELEV = 39.9.5' KOP= 3100' Max Angle = 112° @ 9718' Datum MD= 9157 Datum TVD= 88W SS 133!6' CSG, 720, L-80, D =12.347' Minimum ID = 2.313"@ 8292' 4-112" X 2-718" NIP RED IG. 12.6#, L-80 VT, .0152 bpf, D= 3.958' 14 8360' TOP OF 7- LNR I --i 8491' .0152 bpf, D - 3.958• H 8622' 9-5/8^ CSG 4711, L-80. D - PH2FOR4T10N SUKMRY REF LOG: ANMD GR ON 10/15!99 ANGLE AT TOP F732F: 106` @ 9595' Note: Refer to Production DB for historical pert data SIZE SPF NTETWAL Opn/Sqz DATE T 4 9595-9685 O 10/17199 1 —9180' 1 X 11 A SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ML WBL ANGLE>70°@9400'.-4-12'GS RSH NECK SET @ TOP OF 2-718- LNR"' 9-199- 4-1/2^ FES X NP D = 3.813' 8230' H 4-12^ HES X NP, D = 3.813^ 8292' H 4-1/2• HES X NP, D = 3.813^ 8292' 4-12'X2-7/8'NPRmwER 1)=2.313"(1 8292' 2-718' XX RUG (11128/18) 8376' 9-518^ X 4-1/2^ UNDUE OV ERSFIOT 8398' 4-12' BAKER SBR SEALASSY 9416' H 9-518^ X 4-12' BKR SAB -3 FKR. D = 3.813' 4-12.0718 X NP, D=3.813' 13' DEPLOY SLV, D= 2.37^ 1 8622' �14-10 TBG TAI, D= 3.958' 8525'�j RAID TT LOGGED 1027M MLLCUTVWMW(X-11A) 9183'-9190' 047E REV BY COMFS4TS DATE REV BY COMENTS 01130181 ORIGINAL COMPLETION 02/07/18 JUJMD R -UG PLLLEO'LEFT PIECES DH 10117/99 SIS SIDEfRACKCOMPLE7TON 01/09/19 ZV/JAD SET NP RfDLKIR B XX TLLIG 01113118 P-272 RING 01116118 JAM ORLG HO CORRECMNIS 01/18118 ZRYJAM FINAL ODEAPPROVAL 02/05118 GJBIJAD PU1® PX FLM (02102118) 2-718' XX PLUG 9768' PRUDHDEBAY UNIT WELL: X -11A P94W ND: 1990780 AR No: 50-02320471-01 SEC 7, TION, RME, 498' FTL 8 588' FEL BP Blplolatbn (Alaska) ACI TOR• BI K3 t3EY = 01130M Ur. ES✓ _ 02WIl Kd'= SIS- BOX-FRACICCOMR-ETION 6pr Angle - 112° 1 Datum W= Batu wo= O Bottom patch element at 268'. Patch id is large enough to pass 2-7/8" plug bodies F 4-1/2" x 2-7/8" nip reducer to be installed This will house the new, smaller MCX body Mlnlmum N) : 2-313"C82920 4-112" X 2-7/8" NIP RED Olug will removed 9 -SAP CSG.47a. 480. lD--& "V 9022- FIEFLOG IAMM ON IMIS A ANGLE AT TOPPEW: 106• Q 9596' Nnl Refer b Roducd n 081« hwbncM pert Oala T1.Ni,2'l X-11 A 9AFMNDTB:HIS INE DINGSAVMGE123"m 9M EN ON Ml, W&A RMLOWS A SSSV WHEN ON a..a� Kh WELL ANGLE - 7V ! 9400'. -•4-VC 04 RSH • .. 1 9 NECK SET TOP OF 2-T9-LNR-• 8230'4-/@•1ES XFP.O-381Y 8266 I-10.306•% f112• rM 77R WK 91-3903' 8792• ;--4-tf1•t0�XFP.D-!.0613- 8292' 4.1/IX2-718•Nv(�ll®`l)s2.31T111/tV19)I 8292' h2 -Hr XXILUDtPRED y 6376' 03M'zs-11 UNQUEOVWIS11DT { 1W22' F'14-12 TW TAIL. 0= 3.95r 1 8626' H.Ir67L00O®104799 IAL/OIR NAM1OWV(X-11A1 910.1'-0100' GATE Rey BY COA9BN5 MlE REV BY COMANTS 01130M ORIGNIAL GOMPLENON 02WIl 10'1799 SIS- BOX-FRACICCOMR-ETION 819919 ZVIAO SET MPF43JLK7:RBXXFLLG 01119119 P-272 NMR) 01/1610 JW OILG NO OONFMOTIOFS OV1a19 ZFLJLO RMLOBEAPPROVAL QT/8511H fi9TJJ1A RUED PX PLIC (02XW18) 2-7/8- xx MUG PRA:k"BAY UW NHL X -11A PuturT No. 9990780 AR7b: 90.029.20171-0/ T10H R14E 499' FHL 6 989.1 BP EepbrMWn (Abaka) Norfhurtl SUllli If1tlSua Well No.: X-11 Requested By: Wade Boman l0' Baker 4S Flo Guard One Trip FOR INFORMATION ONLY Description Upper Straddle Packer 4" GS Fishing Neck Up x 3-14" STL Pin Dn 3 Vz" 9.311 STL Pup Joint Lower Straddle Packer 3'" Box Up x WLEG Down Local Knowledge for a Global industry NSAK Ref: 15465-00W Vendor: Drawn By: CWI BHGE 01-08-2019 Length 3.70" 1 2.45" 1 5.51' 3.500" 1 2.910" 1 –10.00' 3.70" I 2.4S" 1 5.80' !—/ 1 I Total Length TW: I The enclosed is conceptual for information only. Ali feasibility and dimensional data should be verified with the c.phs:':m M" From 2018 RWO to present 0.+ Rw'9 SFO umsR Wade Boman Petroleum Engineer, Prudhoe A,B, & X pads BP Exploration Alaska, Anchorage Office 855B vvade.boman@_bp.co Office: 907-564-4674 Cell: 907-687-4468 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, January 22, 2019 3:37 PM To: Boman, Wade <Wade.Boman@bp.com> Cc: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: PTD 199-078 Sundry 319-022, PBU X -11A Wade, What fluids are in the IA? Will it be fluid packed? 1 need a state witnessed and charted MIT -IA. When in your procedure do you want to perform that? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 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. Rixse0alaska.govI. 2 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 30,2018 TO: Jim Regg ff P.I.Supervisor I`e.CG i 18 SUBJECT: Mechanical Integrity Tests C 1 BP EXPLORATION(ALASKA)INC. X-11A FROM: Brian Bixby PRUDHOE BAY UNIT X-11A Petroleum Inspector • Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-11A API Well Number 50-029-20471-01-00 Inspector Name: Brian Bixby Permit Number: 199-078-0 Inspection Date: 4/27/2018 ' Insp Num: mitBDB180427151643 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X-1 IA _Type Inj G 'TVD 8147 - Tubing 2159 -1 2167 - 2168 - 2166 " PTD ' 1990780 _,Type Test SPT Test psi j 2037 IA 305 2800 - 2775 ' 2765 BBL Pumped: Si - ,BBL Returned: 5.8 - OA 85 352 - 368 - 385 - Intervall INITAL 1P/F P Notes: Sundry 317-060 Post tubing swap with rig. SCANNEV Monday,April 30,2018 Page 1 of 1 • . Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, March 12, 2018 2:11 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL; AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Boman,Wade;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg, James B (DOA);AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector X-11A(PTD#1990780)Will not be brought online due to surface kit issues All, Recently worked over injector X-11A(PTD#1990780)cannot be brought online due to surface kit issues. The well is now reclassified as Not Operable for tracking purposes. Once surface kit issues are resolved the well will be made operable and an AOGCC witnessed MIT-IA will be performed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED WO From: A , GWO Well Integrity Engineer Sent: Wedn- ,- , January 24, 2018 2:18 PM To: AK, OPS EOC :> ialists; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, O• ell Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Boman, Was-, 'chris.wallace@alaska.gov' Cc: AK, GWO Completions Well In - ; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity We - • • ation; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Mic -- , - •a , ki Carrie; Montgomery, Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver •, -•• eel, Joshua; Worthington, Aras J; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: OPERABLE: Injector X-11A(PTD #1990780)Tubing integrity restored with rig workOver-- 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg ZfZ7 P.I.Supervisor ISUBJECT: Mechanical Integrity Tests G 'l� ( BP EXPLORATION(ALASKA)INC. X-IIA FROM: Brian Bixby PRUDHOE BAY UNIT X-1 IA Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�i� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-1IA API Well Number 50-029-20471-01-00 Inspector Name: Brian Bixby Permit Number: 199-078-0 Inspection Date: 2/18/2018 Insp Num: mitBDB180219112102 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X-11A Type Inj N 1TVD 8147 ' Tubing 31 31 31 31 PTD1990780 Type Test SPT Test psi 2100 - IA 0 2500 2476 - 2467 - BBL Pumped: 5.8 _ BBL Returned: 4A OA 0 0 0 0 Interval OTHER - P/F P Notes: Witnessed as per Sundry#317-060 to 2100 psi minimum.This is a post rig MIT.They will submit another notificatuon to witness again after the v well is on injection. SCANNED b = Tuesday,February 20,2018 Page 1 of 1 • VCU STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI N • REPORT OF SUNDRY WELL OPERATIONS FEB U 9 ?018 • 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations sl GGCC Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 199-078 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20471-01-00 7. Property Designation(Lease Number): ADL 028313 8. Well Name and Number: PBU X-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9768 feet Plugs measured None feet true vertical 8972 feet Junk measured 9640 feet Effective Depth: measured 9737 feet Packer measured 8266,8417 feet true vertical 8983 feet Packer true vertical 8001.8149 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2626 13-3/8" 37-2663 37-2663 5380 2670 Intermediate 8987 9-5/8" 35-9022 35-8741 6870 4760 Liner 692 7" 8491-9183 8221-8899 8160 7020 Liner 1299 2-7/8" 8469-9768 8199-8972 13450 13890 Perforation Depth: Measured depth: 9595-9685 feet feet True vertical depth: 9034-9003 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-8524 32-8253 Packers and SSSV(type,measured and 4-1/2"HES TNT Packer 8266 8001 true vertical depth) 4-1/2"Baker SAB-3 Packer 8417 8149 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Treatment descriptions including volumes used and final pressure: a1;.1 , 0 5 ; 6 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 17000 1523 2350 Subsequent to operation: 0 250 197 14.Attachments:(required per 20 MMC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-060 Authorized Name: Lastufka,Joseph N Contact Name: Browning,Zachary H Authorized Title: Inf' -,.n and Dal nn r Contact Email: Zachary.Browningt bp.com Authorized Signature: Date:U I/15 Contact Phone: +1 907 564 5220 Form 10-404 Revised 04/2017 ��/ D RODMS Lt. FEB� r� r.1 2'{,18 Submit Original Only • s Daily Report of Well Operations X-11 A ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(pre rwo) PULL PLUG FROM NIPPLE REDUCER AT 8459' MD. DROPPED PLUG UNDER REDUCER 9/6/2017 ***CONT ON 9-7-17 WSR*** T/I/0=300/130/0 Temp=S/I (LRS unit 76-Assist Slickline: Load and Test/RWO Expense) 9/7/2017 Rig up and pressure test. ***Continued on 09-08-17 WSR*** ***CONT FROM 9-7-17 WSR***(Pre RWO) PULLED 4 1/2"x 2 7/8" NIPPLE REDUCER FROM 8459' MD RAN SBHPS PER PROGRAM.(good data) MADE TWO ATTEMPTS TO RECOVER 2-7/8"XX PLUG FROM LINER.(no recovery) MADE TWO ATTEMPTS TO SET 4-1/2" PX PLUG BODY, TOOLS S/D @ 1155'-1175' SLM. DRIFTED TBG TO DEPLOYMENT SLV @ 8459' MD W/3.80"GAUGE RING & S.BAILER.(no sample) SET 4-1/2" PX PLUG BODY(oal-26", 4 x 7/16" ports) IN X-NIPPLE AT 8459' MD RAN 4 1/2" CHECK SET TO PLUG BODY AT 8459' MD - (Good Set) SET PRONG(oal-96", 1.75" f/n) IN PLUG BODY AT 8459' MD ***CONT ON 9-8-17 WSR*** 9/7/2017 ****FISH LEFT IN HOLE -2-7/8"XX PLUG - DEPTH UNKNOWN**** ***Continued from 09-07-17 WSR*** (LRS unit 76-Assist Slickline: Load and Test/ RWO Expense) CMIT-TxIA PASSED to 4118/4025 psi. Max applied pressure 4200 psi. Target pressure 4000 psi. Pumped 60 bbls crude down T/IA to reload, pressured up Tubing to 4200 psi and couldn't get IA pressure past 4000 psi w/ 10.3 bbls crude. Bled T/IA to 400/300 psi. Bled back— 15 bbls. 2nd test- Pressured up T/IA to 4182/4066 psi with 13.7 bbls crude. 15 min T/IA lost 25/18 psi. 30 min T/IA lost 21/14 psi. 45 min T/IA lost 18/9 psi for a total loss of 64/41 psi in 45 min. Bled T/IA to 300/250 psi. Bled back — 13 bbls. Tags hung, AFE sign hung on well. SL in control of well upon departure. IA OA= OTG. 9/8/2017 FWHPS=300/250/5 ***CONT FROM 9-7-17 WSR***(pre rwo) LRS PERFORMED PASSING CMIT-TxIA TO 4000#. 9/8/2017 ***WELL LEFT S/1 ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** ***WELL SHUT-IN ON ARRIVAL*** (SLB E-LINE TUBING PUNCH /CUT) INITIAL T/I/O =280/250/0. MIRU, LPT/HPT= PASS. RIH W/ 1.56"X 1' TBG PUNCH, 4 SPF (4 SMALL CHARGES AND 1 MEDIUM CHARGE), 0 DEG PHASE. OAL= 28', OAW= 225 LBS. MAX OD = 1.69". PUNCH TUBING 8353'-8354'. CCL TO TOP SHOT= 9.7'. CCL STOP DEPTH = 8343.3'. RIH W/ POLLARD 2.5" RCT TOOLSTRING. OAL = 30', OAW= 230 LBS, MAX OD = 2.5" CUT TUBING @ 8361', CCL TO CUTTER = 13.4', CCL STOP DEPTH = 8347.6'. ALL LOGS TIED INTO TUBING TALLY DATED 30-JAN-1981 1/2/2018 ***JOB CONTINUED ON 03-JAN-2018*** S • Daily Report of Well Operations X-11 A T/I/O= 198/190/3. Circ Out Wellbore (prep well for RWO) CMIT-TxIA*PASSED*at 2574 psi. 2500 psi target (2700 psi max applied) TBG lost 23 psi and the IA lost 25 psi during the first 15 minutes. TBG lost 10 psi and IA lost 12 psi during the second 15 minutes. TBG lost 33 psi and IA lost 37 psi during the 30 minute test. Pumped 9.8 bbis of 26* F diesel to achieve test pressure. Bled back 6.9 bbls to T/1/0= 502/641/2. Pumped 5 bbls of 60/40 methanol and 593 bbls of 110* F. 1% KCI into the TBG. IA returns through choke skid to X-35 F/L. Waited one hour for IA gas to migrate past the TBG leak. Pumped another 586 bbls of 110* F. 1% KCI into the TBG with IA returns to X-35 F/L. Pumped 172 bbls of 120* F. diesel into the IA while TBG returns to X-35. Freeze protect surface line and X-35 F/L with 5 bbls of 60/40 (twinned with X-10 online) Pressured up to 1000 psi, tag hung. U-Tube TxIA. 1/3/2018 ***Job continued to 1/4/2018*** ***JOB CONTINUED FROM 02-JAN-2018*** (SLB ELINE TBG PUNCH-CUT) FINISH RIGGING DOWN. PAD OP NOTIFIED ON DEPARTURE. FINAL T/I/O = 230/235/0. 1/3/2018 ***WELL LEFT S/I ON DEPARTURE*** ***WSR continued from 1/3/2018. (LRS Unit 72 - Pre-Rig Testing/Circ Out) U-Tube Freeze Protect acrosss Tubing x IA after Circ Out. MIT-OA***FAILED***to 1194 psi, target 1080 psi. Pumped 2.9 bbls of dsl for 3 MIT-OA attempts, all with failing results. On final attempt pumped .04 bbls of crude to reach a test presure 1194 psi. 1st 15 min OA lost 29 psi, 2nd 15 min OA lost 30 psi. Bled back—1 bbls diesel. LRS unit pulled from job. Tags hung. DSO notified of well status. Well support notofied LRS done on well. Vavles= swab, wing, ssv= closed IA to hardline= closed IA to gauge= open OA= open 1/4/2018 FWHP= vac/vac/8 T/I/O= TWC/0/0 ***Cont from night shift*** PT'd DH tree to TWC to 5000 psi =PASS , RU 3- 1/8" HWO PB OA Temp Valve#67 to OA-Torqued to API Specs and PT'd to OA gate to 3500 psi =PASS , RU 3-1/8" HWO PB IA Temp Valve#58 to IA-Torqued to API specs and 1/5/2018 PT'd to 3500 psi (Charted and Retained all Tests) ***Job Complete*** FWP=TWC/0/0 T/I/O=0/0/0 Set 6" CIW"J"TWC#423 Pre- Parker 272. FWP's TWC/0/0 see log for 1/5/2018 details. T/I/O=TWC/0/0 R/D production tree, R/U dryhole tree Temp. #27. torqued to specs. FWP's 1/5/2018 TWC/0/0 see log for details. T/I/O = TWCNAC/0+. Temp = SI. WHPs (pre RWO). Dryhole & double CVs on IA& OA installed. Wellhouse, scaffold, and grating removed. 1/6/2018 IA, OA= OTG. 03:00 • • North America-ALASKA-BP Pape 1 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) Start Date:1/7/2018 1 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855. Active datum:13:11 7/29/1980 00:00 @74.10usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT I Total Depth ' Phase j Description of Operations (hr) I i (usft) I 1/7/2018 00:00 08:00 8.00 MOB P PRE I BEGING X-11A RWO(TUBING SWAP)EVENT . AT 00:00 WITH PARKER RIG 272 l I MOVE THREE RIG MODULES FROM PRICE PAD STAGING AREA TO X-PAD -RIG HAD BEEN STAGED ON PRICE PAD DURING RIG MOVE FROM V PAD WHILE WAITING ON X WELL/PAD PREPARATION DUE TO LAST MINUTE RIG SCHEDULE CHANGE. I BEGIN EVENT&RESUME MOVE AT 00:00 I I UPON NOTICE THAT X PAD PREP IS NEARLY I COMPLETE AND READY FOR RIG ARRIVAL. 08:00 - 12:00 4.00 MOB N PRE 1 STAGE RIG MODULES ON X-PAD 1-WAIT ON COMPLETION OF PAD PREP -SPOT RIG MATS AROUND WELL FOR RIG I PLACEMENT. 1 j ,-PLACE DUMMY WELL HOUSE,INSTALL 1 FLOORING AROUND WELLHEAD. -INSTALL PRESSURE GAUGE TO SWAB AND 1 OPEN TREE TO MONITOR PRESSURE BUILD UP.BLEED AS NECESSARY,MAX PRESSURE 500 PSI. -CAMERON WELLHEAD REP VERIFIED NO PRESSUE ON CONTROL LINES.WILL RE-VERIFY AND BLEED IF NECESSARY PRIOR TO ND OF THE TREE. **SIMOPS:MOVE RIG CAMP FROM MOBILE PAD TO TARMAC RUNWAY. 12:00 - 15:00 3.00 MOB P PRE SPOT DRILL MODULE OVER WELL.MATE UP MUD MODULE AND UTILITY MODULES. 15:00 - 16:30 1.50 MOB P I PRE RIG UP INTERCONNECTS 16:30 - 17:00 0.50 MOB P PRE RAISE MAST I '-HOOKLOAD=565 KLBS OFF RACK 17:00 - 18:00 1.00 MOB P PRE SKID RIG FLOOR AND CATTLE CHUTE.RAISE PIPE CAT. 18:00 - 21:30 3.50 MOB P ' PRE GENERAL RIG UP OPERATIONS: -BRIDAL DOWN,UNTIE SERVICE LOOPS AND INSTALL MOUSEHOLES. -RIG UP RIG FLOOR EQUIPMENT. I -CALIBRATE BLOCKS AND AMPHION SYSTEM. **ACCEPT RIG AT 21:30 HRS 01/07/2018** 21:30 - 00:00 2.50 MOB P 1 PRE CONTINUE GENERAL RIG UP OPERATIONS. -TAKE ON FRESH WATER FOR PIT CALIBRATION.QUADCO REP ON LOCATION TO CALIBRATE PVT SYSTEM 1 -PRESSURE TEST SURFACE LINES TO4000 PSI. -RIG UP WELLHOUSE FOR WELL WORK, INSTALL SECONDARY KILL TO IA. I -HOLD PRE-SPUD MEETING WITH BUCKLER CREW. 1/8/2018 00:00 - 01:00 1.00 RIGU P PRE RIG EVACUATION DRILL WITH H2S COMPONENT-HELD MR:REVIEWED PARKER PROCEDURE FOR H2S AND EVACUATION PROCEDURE. Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • oo ,,' � ,!..F/4/;;.,-;;;,-/,' S � �. �AI i9 ♦ / Common Well Name:X-11 I AFE No Event Type:WORKOVER(WO) Start Date:1/7/2018 End Date: ,,X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. I BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date I From-To I Hrs I Task Code NPT Total Depth I Phase Description of Operations (hr) (usft) -+ — — 01:00 - 03:00 2.00 WHSUR P PRE PRESSURE TEST 6"J STYLE TWC FROM BELOW TO CONFIRM BARRIER FOR ND -PRESSURE TEST WITH DIESEL FROM II 1 BELOW TO 2500 PSI FOR 5 CHARTED MIN (PASS) REVIEW BP PRESSURE CROSS CHECK LIST PRIOR TO TESTING. 03:00 - 10:00 I 7.00 WHSUR N PRE IATTEMPT TO NIPPLE DOWN DRYHOLE TREE AND TUBING HEAD ADAPTER I-SIGNIFICANT DIFFICULTY PULLING 1981 TUBING HEAD ADAPTER OFF TUBING SPOOL. USE STEAM,DUAL FLANGE SPLITTERS AND j EXTRA PULLING DEVICES(TUGGERS,ETC.). CONFIRM RATINGS OF ALL PULLING EQUIPMENT PRIOR TO EXTRA PULLS. VERY DIFFICULT TO BREAK SEVERAL FLANGE NUTS AND TO REMOVE SEVERAL IRUSTED STUDS. 110:00 - 13:00 1 3.00 WHSUR P PRE I NIPPLE DOWN DOUBLE MASTER DRY HOLE TREE AND 13-5/8"5K ADAPTER FLANGE -BLEED OFF CONTROL LINES(VERY QUICK). 'REVIEW CAMERON JSA PRIOR TO CONTROL LINE TERMINATION. FUNCTION AND RE-TORQUE ALL LOCK DOWN SCRWS.REPLACE ONE LDS AND GLAND NUT ON TBG SPOOL PER CAMERON RECOMMENDATION. I-INSTALL 7"TC4S CROSSOVER IN HANGER- 6 TURNS TO MAKE UP.HGR THREADS , I 'APPEAR TO BE IN GOOD CONDITION. -INSTALL BLANKING PLUG WITH 9 TURNS 113:00 - 17:30 4.50 BOPSUR P 1 PRE [NIPPLE UP HIGH PRESSURE RISERS AND I I 13-5/8"5K SHAFER BOPE STACK I -INSTALL TURNBUCKLES AND INSERT BELL NIPPLE -AIR UP ALL AIR BOOTS -MEASURE AND RECORD RKBS I-INSTALL MOUSEHOLE -ENERGIZE ACCUMULATOR 17:30 - 18:30 1.00 BOPSUR P 1 PRE 1 RIG UP EQUIPMENT TO TEST BOPE -FILL STACK,PERFORM BODY TEST ON BOPE AND RE-TORQUE ALL STUDS AFTER (TESTING. — — 18:30 - 23:30 5.00 BOPSUR P PRE [TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH PER BP STANDARD (100218)AND AOGCC REGULATIONS -TEST WITNESS WAIVED BY AOGCC REPRESENTATIVE BRIAN BIXBY I -TEST ANNULAR PREVENTER WITH 4-1/2"& 5"TEST JOINTS(LARGEST AND SMALLEST DP) -TEST(4-1/2'X 7")UPPER VBRS WITH 4-1/2" AND 5"TEST JOINTS -TEST(2-7/8"X 5") LOWER VBRS WITH 4-1/2" AND 5"TEST JOINTS -TEST RAM LOCKS ON INITIAL TEST AND BACKSIDE OF DUAL-DIRECTION CHOKE MANIFOLD VALVES ,-COMPLETE BLACKOUT TEST I -NO FAILURES,SEE ATTACHED DOCUMENTATION Printed 1/22/2018 11.03:36AM *All depths reported in Drillers Depths* 41) North America-ALASKA-BP • Page 3 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) j Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay I Site:PB X Pad Rig Name/No.:PARKER 272 1 Spud Date/Time:1/30/1981 12:00:OOAM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT 1 Total Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 WHSUR P DECOMP RIG UP DUTCH RISER AND LUBRICATOR FOR PULLING TWC -INSTALL DUTCH RISER AND FILL WITH FRESH WATER 1/9/2018 00:00 - 04:00 4.00 WHSUR P DECOMP 1PULL BACK PRESSURE VALVE WITH LUBRICATOR AS FOLLOWS: -PRESSURE TEST LUBRICATOR TO 250/3500 PSI PER LEAKTIGHT CRITERIA(PASS) 1-BREAK OFF LUBRICATOR AT QUICK TEST .SUB -RUN STAND OF 4"DRILLPIPE WITH I LEFT-HANDED RUNNING TOOL DOWN THROUGH DUTCH RISER. MAKEUP TO I BLANKING PLUG IN TUBING HANGER WITH 9 TURNS TO LEFT. ROTATE ADDITIONAL 7.5 TURNS TO BACKOUT 7"TC-II XO. RETRIEVE � I BLANKING PLUG AND XO TO SURFACE THROUGH DUTCH RISER. -MAKEUP LUBRICATOR AND TEST QUICK TEST SUB -PULL 6"J STYLE TWC.(NO TRAPPED PRESSURE FOUND BELOW TWC) -RDMO VALVE SHOP LUBRICATOR CREW. RIG DOWN LUBRICATOR AND DUTCH RISER .-REVIEW PRESSURE CROSS CHECK PRRIOR TO ALL PRESSURE TESTS. 04:00 - 06:00 1 2.00 WHSUR P DECOMP DISPLACE DIESEL FREEZE PROTECT OUT OF • WELL AS FOLLOWS: -LINE UP TO CIRCULATE DOWN THE IA THROUGH TUBING HOLE AT 7716'MD AND THE JET CUT AT 8361'MD. TAKE RETURNS UP THE TUBING TO THE FLOWLINE AND OUT TO THE CUTTINGS TANK -REVERSE 50 BBLS OF 120°F 8.45 PPG SEAWATER WITH SOURSCAV H2S SCAVENGER;225 GPM,978 PSI PUMP PRESSURE -LINE UP TO PUMP DOWN THE TUBING TAKING RETURNS OUT THE IA TO THE FLOW 1 ( BACK TANK THROUGH THE CHOKE SKID TRAILER. -PUMP-240 BBLS THROUGH THE TUBING CUT AND TBG HOLE AT;440 GPM,FCP= 1-1900 PSI,<150 PSI PRESSURE 1 DOWNSTREAM OF CHOKE -MONITOR BBL FOR BBL AT THE FLOW BACK TANK BY VISUAL CONFIRMATION AND LEVEL SENSOR. 1-DUMP ALL FLUID DURING CIRCULATING AND SEND TO HYDROCARBON RECYCLE •-TOTAL OF-172 BBLS OF DIESEL SENT OUT. -SIMOPS: RIG UP DOYON CASING TUBING HANDLING EQUIPMENT,PICKUP 06:00 - 07:00 1.00 WHSUR P DECOMP MAKE UP THE SLB 4-1/2"SPEAR ASSEMBLY. -MAKE UP SPEAR ASSEMBLY WITH 1 GRAPPLE,EXTENSIONS,STOP SUB XO AND 5"DP -OAL OF SPEAR=14.02 -RIH WITH ASSEMBLY TO TOP OF THE TUBING HANGER AND ENGAGE THE SPEAR. -UNABLE TO ENGAGE THE SPEAR PAST THE 7"X 4-1/2"XO BELOW THE HANGER. Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page a of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) I Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay i Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:OOAM 1Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00 @74.10usft(above Mean Sea Level) Date From-To 1 Hrs Task 1 Code NPT Total Depth 1 Phase Description of Operations (hr) (usft) 07:00 17:00 10.00 WHSUR N DECOMP ATTEMPT TO ENGAGE THE SPEAR PAST THE CROSS OVER BELOW THE TUBING HANGER -SEVERAL ATTEMPTS MADE FROM THE DIRECTION OF THE SLB FISHING HAND. 1-SPEAR WENT TO NO GO, NOT ON CORRECT DEPTH FOR ENGAGEMENT. ATTEMPT TO PULL OUT&RE-ENGAGE. -ABLE TO GET SPEAR DISENGAGED. -MAKE SECOND ATTEMPT TO ENGAGE I SPEAR AT CORRECT DEPTH.STILL NOT ABLE TO GET SPEAR TO CORRECT ENGAGEMENT 1 DEPTH IN 4-1/2"TUBING. -ATTEMPT TO DISENGAGE WITH 40K OVER WITH NO SUCCESS,IN THE PROCESS OF WORKING THE SPEAR WAS ABLE TO WORK I THE SPEAR DOWN AN ADDITIONAL 6"PAST ORIGINAL NO GO. -CONTACT ODE AND WSUP FOR PLAN FORWARD. 17:00 - 19:30 2.50 WHSUR P DECOMP 1CIRCULATE SOAP PILL SURFACE TO SURFACE WHILE PLAN FORWARD IS (DEVELOPED. -PJSM AND FOR CIRCULATING SOAP SWEEP. VERIFY CORRECT LINE UP FOR CIRCULATING DOWN THE TBG TAKING RETURNS UP THE IA TO THE RIG. -PUMP AT 7 BPM WITH 1790 PSI. -SHUT DOWN,FLOW CHECK THE WELL 10 MIN-WELL STATIC. BLOW DOWN CIRCULATING LINES. -8.45 PPG SEAWATER IN/OUT 19:30 - 00:00 4.50 WHSUR N DECOMP I PLAN FORWARD FOR PULLING TUBING HANGER WITH SPEAR ASSEMBLY. -RECEIVE AND AGREE PER THE RAPID FOR OCN#2.REVIEW ASSOCIATED RISKS AND MITIGATION'S WITH THE RIG CREW. '-MAKE UP APPROVED JARRING ASSEMBLY ABOVE THE SPEAR ASSEMBLY. -MAKE UP XO TO 5'DP,OIL JARS,4-3/4" DRILL COLLAR,ACCELERATOR. -PER OCN#2,ATTEMPT TO JAR THE SPEAR FREE FROM THE TBG HANGER WITH MAX 30K OVER BLOCK WT TO FIRE JARS X 4.- UNSUCCESSFUL -CONTACT ODE PER THE PLAN.DISCUSS THE RESULTS OF THE JARRING ATTEMPT TO GET THE SPEAR OUT. -PER OCN#2,ATTEMPT TO FREE TUBING HANGER WITH COMBINATION OF JARRING AND STRAIGHT PULL. -WORK UP TO MAX PULL 130K PER SLB JAR LIMITATIONS, 95K OVER BLOCK WT OF 35K. -ATTEMPT STRAIGHT PULLS IN BETWEEN JARRING INTERVALS,MAX OVERPULL OF l 177K HOOK LOAD,50K OVER BUOYED 1 1STRING WT. -ENSURE SLB PROVIDES IMPACT FORCE REPORT PRIOR TO JARRING. -ENSURE ANNULAR PREVENTER IS CLOSED WITH MINIMAL CLOSING PRESSURE. Printed 1/22/2018 11:03:36AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 5 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00 @74.10usft(above Mean Sea Level) Date From-To Hrs i Task Code j NPT Total Depth Phase Description of Operations (hr) (usft) 1/10/2018 00:00 - 02:00 2.00 WHSUR N DECOMP CONTINUE OCN#2 FOR JARRING HANGER i FREE. -PER OCN#2,ATTEMPT TO FREE TUBING HANGER WITH COMBINATION OF JARRING AND STRAIGHT PULL. -WORK UP TO MAX PULL 130K PER SLB JAR LIMITATIONS, 95K OVER BLOCK WT OF 35K. -ATTEMPT STRAIGHT PULLS IN BETWEEN JARRING INTERVALS,MAX OVERPULL OF 177K HOOK LOAD,50K OVER BUOYED STRING WT. -MADE 5 HITS AT 130K OVER,OBSERVED JAR INTENSITY DECLINING. SHUTDOWN OPERATIONS TO PERFORM DERRICK INSPECTION.DURING INSPECTION THE JARS WERE FOUND TO BE LEAKING. -ENSURE ANNULAR PREVENTER IS CLOSED WITH MINIMAL CLOSING PRESSURE DURING JARRING OPERATIONS. 02:00 - 03:00 1.00 WHSUR N DECOMP RIG DOWN JARS AND ACCELERATOR AND LAY DOWN. 03:00 - 04:00 1.00 WHSUR N DECOMP WAIT FOR 4-3/4"JARS FROM SLB. -BACKUP JARS WERE 6-1/4"AND NOT PART OF THE APPROVED OCN#2 BHA. 04:00 - 09:00 5.00 WHSUR N DECOMP RIG UP NEW JARS AND ACCELERATOR CONTINUE OCN#2 FOR JARRING HANGER FREE. -JARRING ATTEMPTS STAGE UP TO 95K OVER,BLOCK WT-130K MAX HOOK LOAD- JAR LIMITATIONS. -INTERMITTENT STRAIGHT PULL WITH A MAX OF 250 K PER THE WELL PROGRAM. 09:00 - 09:30 0.50 WHSUR N DECOMP POST JARRING. DERRICK AND TOP DRIVE INSPECTION 09:30 - 18:00 8.50 WHSUR N DECOMP CHANGE NOTICE,OCN#2: TO INSPECT LOCK DOWN SCREWS AND PU 6-1/4"JARS -PUMP OUT THE STACK -RIG DOWN THE 4-3/4"JARS AND BUMPER SUB 1-CAMERON REP TO REMOVE AND INSPECT ALL THE LOCK DOWN SCREWS AND GLAND i NUTS FOR INSPECTION. 1-PU&MU 6-1/4" JAR BHA WHILE LOCK DOWNS ARE BEING INSPECTED. 18:00 - 18:30 0.50 WHSUR P DECOMP OCN#2: TO INSPECT LOCK DOWN SCREWS AND PU 6-1/4"JARS TO FREE TUBING HANGER -CONTINUE ATTEMPTS TO FREE HANGER FROM TUBING SPOOL WITH JARRING AND STRAIGHT PULL ACTIONS. -JARRING ATTEMPTS STAGING UP FROM 130K TO MAX 180 K HOOK LOAD(145 K OVER BLOCK WEIGHT)PER OCN -STRAIGHT PULL ATTEMPTS IN BETWEEN EACH JAR ATTEMPT.MAX 250 K -HANGER CAME FREE ON THIRD HIT OF THE JARS WITH 180K -PU TO 160K,30K OVER STRING WEIGHT WITH 4'OF PIPE STRETCH. -CONTACT ODE PER OCN: Printed 1/22/2018 11.03:36AM `AII depths reported in Drillers Depths* • , • North America-ALASKA-BP Page 6 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) I Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay i Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. •BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date From-To : Hrs Task Code NPT Total Depth Phase Description of Operations (hr) --- (usft) 18:30 - 21:00 2.50 WHSUR P • DECOMP OCN#2:JAR TUBING SPOOL FREE. -WORK PIPE WITH 160K HOOK LOAD,30K ' i OVER IN ATTEMPT TO BREAK TUBING FREE • ' AT THE CUT. -SLOWLY STAGE UP MAX PULL UP TO 180K, • 50K OVER STRING WT. I-WORK STRING WITH NO PUMPS FOR 2 I; HOURS ,STAGE PUMPS UP CIRCULATING DOWN THE TBG TAKING RETURNS UP THE IA II I BACK TO THE GAS BUSTER.ENSURE I HANGER IS NOT PLACE BACK ON SEAT AND MONITOR PRESSURE CLOSELY WHILE I SIMULTANEOUSLY WORKING PIPE STRETCH I UP TO 160K. -5 BPM WITH 600 PSI,NO SOLIDS OBSERVED I DURING CIRCULATION. -TUBING BROKE FREE AT 185K,-50K OVER II STRING. -PU-145K,SO-120K 121:00 - 22:00 I 1.00 WHSUR P1 DECOMP LAY DOWN BHA -PJSM WITH SLB AND CREW FOR BEST WAY 'TO BREAK OUT BHA. 22:00 - 23:00 1.00 WHSUR P DECOMP •OCN#2:ENSURE PROPER ENGAGEMENT& I PRESSURE TEST LOCK DOWN SCREWS AND I I I GLAND NUTS I I -PRESSURE TEST TO 2500 PSI PER THE i OCN. I -TEST MEETS CRITERIA FROM BP PRACTICE 100218 TABLE 2,26.LOST 10 PSI FOR TEST.- • I GOOD TEST 23:00 - 00:00 1.00 WHSUR P DECOMP I POST JARRING. DERRICK AND TOP DRIVE I I INSPECTION -FOUND KEEPER PIN IN DERRICK TO BE UN-CLIPPED,HOWEVER STILL IN PLACE. DERRICK MAN RE-CLIPPED THE KEEPER. -VERIFY CORRECT CASING TONG AND I SPOOLER MAKE UP WITH DDI CASING REP AND SLB SPOOLER HAND. 1/11/2018 00:00 - 01:00 1.00 PULL P , DECOMP I PULL HANGER TO THE RIG FLOOR -BREAK OUT HANGER IN MOUSE HOLE AND ' I LAY DOWN. I INSPECT HANGER FOR UNUSUAL DAMAGE, NONE FOUND. -FLOW CHECK THE WELL 10 MIN-WELL STATIC 01:00 - 01:30 0.50 PULL P ' DECOMP D1 WELL CONTROL DRILL WITH CONTROL I •LINES IN BOP. -AAR I -DISCUSS STANDING ORDERS WITH CONTROL LINES ACROSS THE STACK -ENSURE THIRD PARTY UNDERSTAND ROLES. I 01:30 - 02:30 1.00 PULL P 1DECOMP I CIRCULATE BOTTOMS UP PER OCN#2 I-CIRCULATE MAX RATE.585 GPM WITH 975 PSI. -8.45 PPG SEAWATER IN/OUT. I-SMALLAMOUNT OF CONTROL LINE SHEATH I RUBBER MATERIAL COMING OVER THE I ISHAKER. Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* 0 ikiarth America-ALASKA-BP Page 7 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) i Start Date:1/7/2018 End Date X4-01456-E:(2,015,410.00) Project:Prudhoe Bay I Site:PB X Pad Rig Name/No.:PARKER 272 I Spud Date/Time:1/30/1981 12.00.00AM I Rig Release:1/13/2018 Rig Contractor.PARKER DRILLING CO. I BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date I From-To Hrs I Task I Code I NPT I Total Depth Phase Description of Operations (hr) i (usft) 02 30 - 05:00 2.50 PULL 1 P ', DECOMP I PULL AND LAY DOWN 4-1/2"12.6#L-80 BTC TUBING TO THE SSSV AT-2140' I -LAY DOWN TUBING WITH CONTROL LINES j AND CENTRALIZER S CLAMPS 1-PU 140K;SO 120K -LAY DOWN THE OTIS SSSV AND HANDLING PUPS. IRECOVERED 50 JOINTS OF 4-1/2"TUBING,3 I BANDS AND 26 CLAMPS. -MONITOR HOLE FILL WITH TRIP TANK.- CORRECT DISPLACEMENT. 05:00 - 06:00 1.00 PULL P 1 DECOMP I CLEAN AND CLEAR RIG FLOOR -CLEAR CONTROL LINE SPOOLER. I , -PREPARE TOOLS FOR STORM PACKER RUN. 06:00 - 07:00 1.00 DHB P DECOMP I MAKEUP MODIFIED RTT'S,STORM PACKER -MAKE BTC XO TO PORTED SUB AND DRILL , I PIPE SCREEN TOA STAND OF 5"DP. -RIHANDSETAT--95', 50'BELOWTHE WELLHEAD. -SET PER HES PROCEDURE. 107:00 - 10:30 3.50 BOPSUR P DECOMP NIPPLE DOWN BOPE FOR WELL HEAD WORK PULL FLOW RISER,UNSEAT TUBING SPOOL WITH BOP CRANES. ND STACKAND SET BACK,PULL HIGH PRESSURE RISERS AND LAY DOWN. -REMOVE OLD TUBING SPOOL AND PULL TO THE BOP DECK. -CLEAN AND DRESS OFF WELL HEAD AND HANGER NECK. W 10:30 - 14:30 4.00 HSUR P I DECOMP CHANGE OUT OLD GRAY BIG BORE TUBING SPOOL AND 9-5/8"MANDREL HANGER NECK I i ISEALS !-INSTALL NEW POLY BI PAK MANDREL HANGER NECK SEALS ON THE 9-5/8" HANGER PER CAMERON PROCEDURE. -NIPPLE UP NEW TUBING SPOOL.13-5/8"X 13-5/8",5000#GRAY NEW STANDARD -PRESSURE TEST INNER CASING PACK OFF TO 3500 PSI FOR 15 CHARTED MIN.GOOD I , TEST.MEETS BP PRACTICE(100218) CRITERIA TABLE 2,3A. 14:30 - 16:00 1.50 BOPSUR I P , DECOMP NIPPLE UP BOPE AFTER TBG SPOOL I CHANGE OUT. -NU BOPE HIGH PRESSURE RISERS,BOP STACK&FLOW RISER. -INSTALL MOUSE HOLE AND FILL LINES. _ -- --...-_--.-_--- 16:00 - 17:00 1.00 BOPSUR P I DECOMP PRESSURE TEST BREAKS IN BOPE FLANGES. I -INSTALL TEST PLUG IN TUBING SPOOL. -PRESSURE TEST BOP BREAKS TO 250 LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN.- GOOD TEST 17:00 - 18:00 1.00 PULL P DECOMP PULL AND LAY DOWN MODIFIED STORM 1 PACKER. -RIH WITH RUNNING TOOL AND ENGAGE RTTS.VERIFY NO PRESSURE -PULL TO THE FLOOR AND LAY DOWN. -LAY DOWN STAND AND RTTS RUNNING TOOL.CLEAR RIG FLOOR. Printed 1/22/2018 11.03.36AM *All depths reported in Drillers Depths* . North America-ALASKA-BP Page 8 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) I Start Date:1/7/2018 End Date X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 I Rig Contractor PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date I From-To tHrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) - — 18:00 - 21:30 I 3.50 PULL P ' DECOMP CIRCULATE HIGH VIS SEEP -505 GPM,WITH 525 PSI. -8.45 PPG SEAWATER IN/OUT. I -SMALL AMOUNT OF ENCAPSULATION MATERIAL ACROSS THE SCREENS. 21:30 00:00 2.50 DHB P I DECOMP PULL AND LAY DOWN REMAINING 4-1/2"12.6# j i L-80 BTC TUBING -PU 60K;SO 60K -MONITOR HOLE FILL WITH TRIP TANK.- ' CORRECT DISPLACEMENT. 1/12/2018 100:00 - 02:00 2.00 PULL P DECOMP CONTINUE:PULLAND LAY DOWN REMAINING 4-1/2"12.6#L-80 BTC TUBING -RECOVER TOTAL OF 197 JOINTS PLUS CUT JOINT,(5)GLM'S,(1)SLIDING SLEEVE,(1) SSSV I -CUT JOINT=5.91'WITH NO FLARE -MONITOR TRIP ON TRIP TANK:CORRECT DISPLACEMENT 02:00 - 02:30 0.50 PULL P I DECOMP CLEAN AND CLEAR RIG FLOOR. -VERIFY DECOMPLETE COUNT IN THE PIPE SHED -DRIFT NEW PX PLUG IN CUT JOINT.NO I ISSUES. i ',-VERIFY PLAN FORWARD FOR NO CLEAN OUT RUN WITH ODE 02:30 - 04:30 1 2.00 RIGU P RUNCMP PREPARE FOR TUBING RUN -CHANGE CASING TONGS.RU TORQUE I TURN EQUIPMENT AND FUNCTION TEST. I -REMOVE OLD TUBING FROM PIPE SHED FOR 4-1/2"TUBING RUN VERIFY PIPE COUNT AND JEWELRY LINE UP IN PIPE SHED FOR UPPER COMPLETION RUN -PJSM FOR PICKING UP COMPLETION 04:30 14:00 9.50 RUNCOM P 1 1 RUNCMP RUN 4-1/2",12.6 LB/FT,L-80,VAMTOP COMPLETION WITH UNIQUE MACHINE I OVER-SHOT PER THE APPROVED RUN TALLY TO-8,310'MD -MONITOR WELL 10 MIN BEFORE RIH:STATIC I-BAKERLOK ALL CONNECTIONS BELOW THE PACKER -USE JET LUBE SEAL GUARD PIPE DOPE ON I ALL VAMTOP CONNECTIONS -TORQUE TURN ALL VAMTOP CONNECTIONS TO 4440 FT-LBS(VAM REP WITNESS) -RUNNING SPEED=90 FT/MIN,LIMITED BY ,PACKER -MONITOR WELL ON TRIP TANK:CORRECT DISPLACEMENT 14:00 16:00 2.00 RUNCOM P RUNCMP I CIRCULATE BOTTOMS UP WITH CLEAN I I I SEAWATER -7 BPM,375 PSI I -MW IN/OUT=8.45 PPG Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 9 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00 @74.10usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT I Total Depth Phase Description of Operations (hr) - (usft) 16:00 18:00 2.00 RUNCOM ' P F RUNCMP SPACE OUT AND LAND COMPLETION TO POSITION UNIQUE OVERSHOT OVER 4-1/2" I TUBING STUB RIH&TAG TOP OF TUBING STUB AT 8,382' MD -CONTINUE DOWN,STRING TAKING WEIGHT. PU TO ENSURE FREE,SLIGHT OVERPULL I OBSERVED.INDICATIONS OF DEBRIS. -PUMPS ON AT 3 BPM TO WASH OVER THE !STUB 1-FIRST SHEAR: 8,385'MD, SHEAR OBSERVED.5 KLB BOBBLE,OBSERVE IPRESSUREINCREASE. -SECOND SHEAR:8,393'MD(12'BELOW STUB).5 KLB BOBBLE. -BOTTOM OUT ON SHOULDER OF OVERSHOT:8,395'MD(16'BELOW STUB) -PICK UP AND BRING ON PUMPS AT 3 BPM, 450 PSI TO ESTABLISH BASELINE PRESSURE 1*CALCULATE SPACE OUT PUPS NEEDED j !!BASED ON TAG UP AND NO GO ON THE 4-1/2" TUBING STUMP. -SPACE OUT PLACES OVERSHOT AT 8,388' MD(-6'OVER STUMP) 18:00 - 19:00 1.00 RUNCOM P RUNCMP CIRCULATE BOTTOMS UP FOR SUSPECTED DEBRIS AT TUBING STUB -PICK UP ABOVE THE STUMP AND CIRCULATE DEBRIS OUT OF THE HOLE 7 BPM,340 PSI -MW IN/OUT=8.45 PPG 19:00 - 21:00 2.00 RUNCOM P RUNCMP LAND TUBING HANGER(GRAY NEW STANDARD 13"X 4.5"TC2 BOTTOM) -LAY DOWN SPACE OUT JOINTS USED FOR I SPACE OUT -MAKE UP SPACE OUT PUPS AND PLACE UNDER ONE FULL JOINT OF TUBING -MAKE UP HANGER AND LANDING JOINT. LANDING JOINT IS TC2 CROSS OVER TO 4-1/2"IF AND TWO JOINTS OF 5"DP. -RIH AND LAND TUBING HANGER 21:00 - 00:00 3.00 RUNCOM P RUNCMP ,CIRCULATE COMPLETION FLUID -RIG UP TO REVERSE CIRCULATE DOWN IA WITH CORROSION INHIBITED SEAWATER& DIESEL FREEZE PROTECT 1-OBSERVE HIGH CASING PRESSURE(800 PSI AT 1 BPM) -CONTINUE PUMPING AT 1 BPM FOR 5 MIN BEFORE PRESSURE STARTED FALLING OFF -FINAL CIRCULATION RATE OF 3 BPM WITH 800 PSI 'REVERSE CIRCULATE CORROSION INHIBITED 8.45 PPG SEAWATER AS FOLLOWS: ! !-150 BBLS OF CLEAN 8.45 PPG BRINE AT 3 BPM,700-800 PSI -430 BBLS OF CORROSION INHIBITED 8.45 i PPG SEAWATER AT 3 BPM,850 PSI Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • North America •ALASKA-BP Page 10 of 11 Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AM Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00 @74.10usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 1/13/2018 00:00 04:30 4.50 RUNCOM P RUNCMP CONTINUE REVERSE CIRCULATING COMPLETION FLUIDS AND FREEZE PROTECT -FINISH PUMPING CORROSION INHIBITED 8.45 PPG SEAWATER PUMP 6.8 PPG DIESEL FREEZE PROTECT AS FOLLOWS: REVERSE 152 BBLS OF DIESEL DOWN THE IA TAKING RETURNS UP THE TUBING. -2.5 BPM,ICP-400 PSI,FCP-600 PSI. -SHUT DOWN AND ALLOW 1-HOUR FOR U-TUBE. "SIMOPS:RIGCREWCOMPLETEDDRILL I LINE SLIP AND CUT.SLIP AND CUT ENTIRE DRUM. 04:30 08:00 3.50 RUNCOM P RUNCMP SET HES 9-5/8"X 4-1/2"TNT PACKER I-VERIFY NO PRESSURE UNDER RAMS.OPEN BLIND SHEAR RAMS. -INSTALL TEST JOINT -DROP STANDARD BALL AND ROD.ALLOW TO FALL ON SEAT AT 8,294'MD. -PULL LANDING JOINT AND CLOSE THE BSR'S SET PACKER AS FOLLOWS: -PRESSURE UP THE TUBING,DOWN THE KILL LINE -PRESSURE UP&SET TNT PACKER IMIT-IA&T -PRESSURE TEST TUBING,IA AND PACKER TO 3500 PSI.FOR 30 CHARTED MIN. -ALL TESTS PASSED BP PRACTICE 100218 PRESSURE TESTING CRITERIA,TABLE 1,3B. -TEST RESULTS SENT TO WSUP FOR APPROVAL. 08:00 - 09:00 1.00 WHSUR P RUNCMP DRY ROD TWC -CAMERON REP DRY ROD IN 4"H STYLE 1 TWC. -PRESSURE TEST FROM ABOVE PER THE I WELL PROGRAM. -TEST MEETS BP PRACTICE 100218 PRESSURE TESTING CRITERIA,TABLE 1,2B. 09:00 - 12:00 3.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE AND HIGH PRESSURE RISER -PUMP OUT STACK AND CLEAN DRIP PANS -DE-ENERGIZE ACCUMULATOR -LET AIR OUT OF AIR BOOTS AND PULL BELL I NIPPLE -BREAK STACK AND RACK BACK ON STUMP -NIPPLE DOWN HIGH PRESSURE RISERS j AND LAY DOWN TO PIPE SHED SIMOPS: -BLOW DOWN ALL SURFACE LINES AND EQUIPMENT -BREAK DOWN RIG FLOOR INTERCONNECTS -CONTINUE TO PREP MUD MODULE FOR RIG IMOVE Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • North America ALASKA-BP •• Page 11 of 11 • Operation Summary Report Common Well Name:X-11 AFE No Event Type:WORKOVER(WO) , Start Date:1/7/2018 End Date: X4-01456-E:(2,015,410.00) Project:Prudhoe Bay Site:PB X Pad Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1981 12:00:00AMI Rig Release:1/13/2018 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00000855 Active datum:13:11 7/29/1980 00:00©74.10usft(above Mean Sea Level) Date I From-To I Hrs Task I Code NPT Total Depth Phase I Description of Operations 12:00W - 15:00 3.00usft) - HSUR P j RUNCMP 'INSTALL AND TEST ADAPTER FLANGE AND TREE -TORQUE ALL FLANGES TO SPEC PRESSURE TEST HANGER VOID;250 PSI LOW,4500 PSI HIGH FOR 5/15 MIN -PRESSURE TEST TREE;250 PSI LOW,4500 I PSI HIGH FOR 5 MIN VISUAL LEAK-TIGHT 1-GOOD TESTS,NOTIFY WSUP AND RECEIVE ATP I SIMOPS: I-SECURE TOP DRIVE AND UNPIN BLOCKS -PIN BRIDAL LINES -CONTINUE TO PREP MUD MODULE AND DRILL MODULE FOR RIG MOVE 115:00 - 16:00 1.00 WHSUR P i RUNCMP !SECURE TREE AND CELLAR AND PREP DUMMY WELL HOUSE FOR RIG MOVE -RDMO OPERATIONS � I ' • **RIG RELEASE FROM X-11AAT 16:00 HRS ON 01/13/2018** !NEXT EVENT=RON EVENT ON 09-51A Printed 1/22/2018 11:03:36AM *All depths reported in Drillers Depths* • • Daily Report of Well Operations X-11 A ACTIVITYDATE SUMMARY T/1/O=TWC/0/0. R/U Gray Lubricator W/40' of EXT, &J-Plug pulling tool. Pulled 6" J-plug 1/9/2018 #423@ 90". ***Job Complete*** FWHP=0/0/0. T/I/O = TWC/0/0. (Post Parker 272). RD Temp Valve#97, RU Upper tree, Torqued MVxSSV to 890 FT LBS, PT'd against TWC 350/5000 PSI (Pass) Charted and retained. RD Piggyback IA, RU Blind flange, Torqued to 300 FT LBS, PT'd against IA 2500 PSI (Pass). RD Piggyback OA, RU Blind flange, Torqued to 640 FT LBS, PT'd agaist OA 2500 1/15/2018 PSI (Pass). RDMO. ***Job Complete*** T/I/O=TWC/0/0. Post Parker 272. Pulled 4" CIW"H"TWC#430 through tree. Tagged @ 1/26/2018 135" FWP's 0/0/0 see log for details. ***WELL SHUT IN ON ARRIVAL***(Post RWO) PULLED BALL& ROD @ 8270' SLM PULLED RHC @ 8292' MD BAIL FILL ON PX-PLUG FROM 8,426' -8434' SLM 1/31/2018 ***CONT. ON 02/01/2018 WSR*** ***CONT. FROM 01/31/2018 WSR*** (Post RWO) BAIL FILL TO TOP OF P-PRONG @ 8435' SLM PULLED P-PRONG @ 8435' SLM (PLUG DID NOT APPEAR TO EQUALIZE) RAN 2.5" BAILER TO 8439' SLM ***TOOLS HUNG UP FOR 45 MIN*** RECOVERED —2 GALLONS FILL. 2/1/2018 ***JOB IN PROGRESS/ NOTIFY DSO*** ***WELL S/I ON ARRIVAL***(Post RWO) BAIL A FEW SMALL PIECES OF METAL/RUBBER OUT OF 4-1/2" PX PLUG BODY. PULL 4-1/2" PX PLUG BODY FROM 8,451' SLM /8,459' MD. 2/2/2018 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** CTU#8 1.75" CT. Job Scope: Push plug to TD Schedule stand by, RAP goes live at midnite 2/4/2018 ***continued on 2/5/18*** CTU#8 1.75" CT. Job Scope: Push plug to TD Rig up. MU RIH w/BKR ctc 1.75", DBPV 1.69", KJ 1.69", pup joint 1.56", disco (1/2" ball), 1.69", x-over 2.11", prong/blind box 2.0", OAL=14.13' (MAX OD=2.11") ***Job in progress*** 2/5/2018 CTU#8 1.75" CT. Job Scope: Push plug to TD MIRU CTU. MU Baker MHA w/2.0" blind box bha. Tag at 9641' down/9638' up. Hard bottom. Try jetting. No hole made. Pooh. MU BOT fishing bha with 2-7/8" GS spear& Rih. Set down at 9640' ctm. Hit four Jar licks. Pooh. Recovered 2-7/8" plug body. Missing 2 pieces of packing. 2/5/2018 ***Continued on 02/06/18*** CTU#8 1.75" CT. Job Scope: Push plug to TD Rig down CTU 2/6/2018 ***Job complete*** TREE= 4-1/8"aW FLS // SApL�fY NOTES:H2S READINGS AVERAGE 125 ppm LHEAQ Y • X—1 1 A WHEN ON NIL WELL REQUIRES SSSV WHEN ON ACTUATOR= BAKER C M L WELL ANGLE >70°@ 9400'."*"4-1/2"GS FISH KB.ELEV= 74.05' NECK SET @ TOP OF 2-7/8"LNR""" BE ELEV= 39.95' KOP_ -- 3100' Max Angle=-v_ 112°@ 971_8' I I 2199° I—4-1/2"HES X NP,D=3.813" Datum MD= 9157' Datum ND= 8800'SS 2586° H 9-5/8"DV PKR COLLAR 13-3/8"CSG,72#,L-80,ID=12.347" H 2662' 1—r ' 8230' }—4-1/2"HES X NP,D=3.813" Minimum ID = 2.37" @ 8469' TOP OF 2-7/8" LINER 8266' 1—9-5/8"X 4-1/2"HES TNT PKR,D=3.903" I 8292' I—4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12-6#,L-80 VT,.0152 bpf,ID=3.958" H 8360' -- TBG STUB(01/12/18) — 8368' I 8375' H 9-5/8"X 4-1/2"UNIQUE OVERSHOT I` 8396' _14-1/2"BAKER SBR SEAL ASSY 8415' —9-5/8"X 4-1/2"BKR SAB-3 PKR,ID=3.813" ' ' 8459' —4-1/2"OTIS X NP,ID=3.813" TOP OF 2-7/8"LNR — 8469° • 8469' }—3"DEPLOY SLV,D=2.37" — TOP OF 7"LNR —) 8491' ' 8490° —4-1/2"OTIS XN NP,D=3.725" L 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" H 8522' / 85522' H 4-1/2"TBG TA L,D=3.958" 8525' I—ELMD TT LOGGED 10/27/99 9-5/8"CSG,47#,L-80,D=8_681" —I 9022' _I , PERFORATION SUMMARY REF LOG:MWD GR ON 10/15/99 ANGLE AT TOP PERF:106°@ 9595' MILLOUT WINDOW(X-11A) 9183'-9190' Note:Refer to R-oduction DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 2" 4 9595-9685 0 10/17/99 9640'CTM 1—FISH:2 PECES OF PACKING FROM 2-7/8"XX PLUG(02/05/18) V0*�*.*�*. 4 TOP OF WHIPSTOCK H 9180' ,;,;,�,;,�,�,;, PBTD H 9737' 7"LNR,29#,L-80,-0371 bpf,D=6.184" --I —9180' �4,11,� *4, 4*1*****.. 4 8 2-7/8"TBG,6.16#,L-80,.0058 bpf,ID=2.441" H 9768' DATE REV BY COMMENTS —ME TS _ DATE REV BY COM M NrS — PRLDHOE BAY MIT 01/30/81 ORIGINAL COMPLETION _ 02/07/18 JUJMD PLUG FILLED/LEFT FECES DH — WELL: X-11A 10/17/99 SIS- SIDETRACK COMPLETION PERMIT No:71990780 01/13118 P-272 RWO AR No: 50-029-20471-01 01/16/18 JMD DRLG HO CORRECTIONS SEC 7,T1 ON,R14E,498'FNL&588'FEL 01/18/18 ZB/JMD FINAL ODE APPROVAL - 0:/05/18 GJB/JMD FILLED FX PLUG(02/02/18) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,January 24, 2018 2:18 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Boman,Wade; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A;Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: OPERABLE: Injector X-11A(PTD#1990780)Tubing integrity restored with rig workover Attachments: X-11A.pdf All, Injector X-11A(PTD#1990780)was made not operable 11/16/15 for having TxIA communication while on MI. On 01/13/18 parker 272 completed performing a rig workover to replace the production tubing. The well passed an MIT-T to 3,500psi and CMIT-TxIA to 3,500psi. The passing pressure test confirms well integrity has successfully been restored. At this time the well is reclassified as Operable. Please note the remaining post rig work needed before the well can be brought online. Once the well is returned to stable injection an AOGCC witnessed MIT-IA will be performed. Post Rig Steps Remaining: 1. Slickline—Pull B&R, Pull RHC Sleeve, Pull Plug 2. Coil Tubing—Fish 2-7/8" plug body/push to bottom 3. Slickline—Set MCX Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068SCANS . WO gi.ar w.a..q..w«w From: AK, D&C We - -•rity Coordinator Sent: Monday, November 1., a 5 4:52 PM 1 flu. r(a- Pi qq6760 Regg, James B (DOA) From: AK, GWO Rig 272 Well Site Leader <AKDCRig272WellSiteLeader@bp.com> �' G Sent: Tuesday,January 16, 2018 4:15 PM To: Brooks, Phoebe L(DOA) I /(o(i Cc: Regg, James B (DOA);AK, GWO Projects Well Integrity; Browning,Zachary H Subject: RE: BOPE Test Report Attachments: X-11A RedLine Drawing.pdf Phoebe, The schematic that we use (attached)only has measured depth but using the MD of 8279' the TVD is 8013.85' Anything else please let us know Regards Blair Neufeld From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Tuesday, January 16, 2018 3:49 PM To: Neufeld, Blair (Fircroft) Cc: Regg, James B (DOA); AK, GWO Projects Well Integrity Subject: RE: BOPE Test Report Blair, Will you send me the well schematic for X-11A so I can verify the Packer TVD? Thank you, Phoebe Phoebe Brooks Statistical Technician II SCANNED ,;;',A R. I Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Neufeld, Blair(Fircroft) [mailto:Blair.Neufeld@bp.comj Sent:Saturday,January 13, 2018 10:37 AM To: Regg,James B (DOA) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; Wall , Chris D (DOA) <chris.wallace@alaska.gov> Cc: Browning, Zachary H <Zachary.Browning@bp.com> Subject: BOPE Test Report Attached is the test results for X-11A Any questions or additional informati7451ease let us know. Regards J 1 TRFF= 4-1/8"CIWFLS • 1/14 11. D= GRAY SAFETY NOTE:Ii2S BEADINGS AVERAGE 125 ppm ACTUATOR= BAKER C e '; W165M0NMI.WELLREQU/RESA.SSSVWH,ENON Q 811.1 Ell A E>70' 8400', 4-1 :s KB.H..EV= 74.05' `�� ,. .a es, `T•T" 7 L:P �� BF.EL EV= 39,95' j KCX" 3100' 1 - iVrax Angk - 112` 10971#3' _,v 1/2'HES X NP,V=3.913" Datum M)-= 9157' Datum TVD= 8600'99 = .=.- 1 2688' 9-5/8"DV FK COLLAR] 13-3/8"CSG,72#,L-80,D=12.347' 4 2662* ., A ii r,, 4- X ",D,.3.813" Minimum ID = 2.37" @ 8469' TOP OF 2-7/8" LINER r� I oqf x.+.r"x4 112 t 3,465:-71, I fe3o6 4-1frIAM Xtom?D=3.8139 +1e..-+ . 4-112'TITO,12. ,L VT,.01 2 bpf,V=3.9581---1. $1'b' ,'.I l 8396 1,_W1/2-BAKER SBR SEAL ASSY 1 1 8416' 9 5/8'X 4-1/2'BKR SA B-3 PKR,13=3.813' 9* 4-1/2"OTIS X NP,D=3.813' ' SCUM 4-1/2"PX PLUG(09/08117) TOP OF 2-7/8'LNRi- 8469' I - I 4 I 8489' }DEFt..OY SLV,D-2.37" i �+I $490' *4-1/2'OTIS XN NP,D=3.725"j tTCW OF 7'LNR —1-8::719 4-1/2"TBG,12.6#,L-80,.0152 bpi,ID=3.1-51=1-1 8622' i .� 8627' 4-1/2'TBG TAL,D=3.958 „ -ii-v EI D TT LOGGED 10/27/99 19-5/8"CSG,47#.L-60,D=8.681" 1 'i a 34 PERFORATION SUM,VIRY REF LOG:MN()GR ON 10115/99 ANGLE AT TOP PERE:106'@ 9595' NLLOUT WINDOW(X-11A) 9183'-9190' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE ? —FISH 2-7/8'XX FI_UG-DEPTH UNKNOWN 2" 4 9595-9685 0 10/17/99 (09/08/17) * [TOP of wt�sTOCK - 8i 90' 1**1�1 P9Tt7 —1 9737' 7'L811.,29# 1-80..0371 bpf =6.184" J-[ -9180' .#9.9 9 99 wir 2-7/8"TBG,6.16#,L-80,.0058 bpf,D=2.441" -I 9768' J DATE REV BY COMBOS DATE REV BY CD T'S P'il DHOE BAY UNI 01/30/81 ORIGINAL COMPLETION WELL: X-11A 10/17/99 SCIS- SIDETRACK COMPLETION PERIAT No:'1990780 AF1 No: 50-029-20471-01 '11107/17. 111X.1.1" °*:::s SEC 7,T10N,R14E,498'F14.. a. 8 588'F BP Brploration(Alaska) • • P5u. PrD rqlO7o Regg, James B (DOA) From: Neufeld, Blair(Fircroft) <Blair.Neufeld@bp.com> 1Seit� Sent: Saturday, January 13, 2018 10:37 AMS To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);Wallace, Chris D (DOA) Cc: Browning, Zachary H Subject: BOPE Test Report Attachments: X-11A State test form 10-426.xlsx Attached is the test results for X-11A Any questions or additional information please let us know. Regards Blair Neufeld Parker 272 WSL 685-4802 Harmony#7316 1 f ,,,,. I • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rea t6alaska.aov AOGCC.Insoectors(Walaska.gov phoebe.brooks(c@alaska.clov chris.wallace(6talaska.aov OPERATOR: BP "_( t (/J(o1lQ? FIELD I UNIT I PAD: Prudoe Bay/West/X-11A DATE: 01/13/18 OPERATOR REP: Blair Neufeld •AOGCC REP: Jeff Jones waived witness(via email.on 1/12/18) , Well X-11A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. • 60 Min. PTD 199-078, Type In) G Tubing 0 3720 - 3590' 3530 ' Type Test P Packer TVD 7926 • BBL Pump 2.5 . IA 0 20 20 20 Interval I Test psi 3500 BBL Return 2.5 OA Result P v"' Notes: MIT-T Well X-11A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 199-078. Type In) G Tubing 2000 2500 ' 2500 2490 " Type Test P - Packer TVD 7926 - BBL Pump 3.5 " IA 0 3790 - 3720 - 3700 Interval •I Test psi 3500 - BBL Return 3.5 OA 266 691 691 670 Result P Notes: MIT-IA Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer ND BBL Pump IA - Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test - P=Pass G=Gas • 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) x-11A State test form 10-426 • • prD 191- © -g Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday,January 02, 2018 9:49 AM To: Loepp,Victoria T(DOA) Cc: Browning,Zachary H Subject: RE: New Parker NOV 6012 BOP Stack sundry#317-060 X-11A (PTD#199-078). Attachments: 6012 BOP STACK.PDF Follow Up Flag: Follow up Flag Status: Flagged Victoria, Just to clarify,the attached BOP Schematic submitted for the X-11A sundry is correct.We did not mean to insinuate that the ram sizes listed below for P1-04 would be used for this workover.The planned sizes are as follows: • Annular • 4-1/2"x 7"VBRs • Blind/Shear • 2-7/8"x 5"VBRs If you have any questions or need additional information, please don't hesitate to let me know. Thank you, SCANNED MAR it, 9 2018 Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 ,..,,, P BP Exploration AlaskaI900 E. Benson Blvd.JRoom: 788D1Anchorage, AK From: Lastufka,Joseph N Sent:Thursday,August 3,2017 3:00 PM To:Victoria.Loepp@alaska.gov Cc: Browning, Zachary H<Zachary.Browning@bp.com> Subject: RE: New Parker NOV 6012 BOP Stack Victoria, This also includes sundry#317-060 X-11A(PTD#199-078). Please let me know if you need any additional information. Thank you, 1 • . �..., • 1 u 6, X IS "W 416U 41 '55 iii �� .. � ; :i .. hn jt gym g 2mm'. .tm- tm: �j 1J K�j 0.1 -.6J ANN NNNM \\N *.u. . late.p���\ ��.Nj O �^H'-�vv � �.H-� FFHHH3 ���3 NNM1� I-HHH '�.-/(��' I I I .+ L i I I yl I I I CY i , a gCl:= =- i bv: = = ' g" g" 'i 2221 872:2 i ,_ i 3 11111 lam., i..,.., I I Q 1I e I i -`—+- it '"-s GO . ,_ __,_,..,.._., , , n .)----r- 1 . p cwt I I\-_\ 1 1. vII 1 IU ; Li $$��jj ito CO A-.6 too \�€ WED 501 6111.M1 .9 M N- -.Nt s-9 JI-.It Z/I OI .0 �' O D8 r .zit 9-.x9 $ CLIA Beaus) .9999 • • PTO 199-o�g Loepp, Victoria T (DOA) Lastufka,Joseph N <Jose h.Lastufka .com>b From: p p @ p 2017 3:00 PM Sent: Thursday,August 03, 9 To: Loepp,Victoria T(DOA) Cc: Browning,Zachary H Subject: RE: New Parker NOV 6012 BOP Stack Follow Up Flag: Follow up Flag Flagged Fla ed Victoria, This also includes sundry#317-060 X-11A(PTD#199-078). Please let me know if you need any additional information. SCANNED Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 w leafv. A } BP Exploration AlaskaI900 E. Benson Blvd.lRoom: 788DlAnchorage, AK From: Lastufka,Joseph N Sent:Thursday,August 3,2017 1:26 PM To:Victoria.Loepp@alaska.gov Cc: Leemhuis,Jacob<Jacob.Leemhuis@bp.com> Subject: FW: New Parker NOV 6012 BOP Stack Victoria, Please update the sundry#317-239 for P1-04(PTD#196-063)and replace the previous BOP sketch to this one. The rams sizes are also different then what we had listed. • Annular • 3-1/2"x 5-1/2"VBRs • Blind/Shear • 2-7/8"x 5"VBRs I'll be sending you a list of approved sidetracks which will have a configuration change at some point as well. Thank you, 1. • • Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 4.:„Ariid BP Exploration Alaskaf900 E. Benson Blvd.IRoom: 788D1Anchorage, AK 2 • • SHEAR CHART FOR NOV 6012 3-1/2" MANUAL LOCK W/ 11" BOOSTER Hydraulic Pressure Required Pipe Data for Shearing(psi) Pipe OD Weight ID Wellbore Pressure Grade Description in lb/ft in 0 psi 5000 psi Drill Pipe 2 7/8 10.4 S-135 2.151 1311 1592 Drill Pipe 4 14.0 S-135 3.34 1915 2196 Drill Pipe 5 19.5 S-135 4.276 2264 2545 Tubing 2 3/8 4.7 L80 1.995 367 648 Tubing 2 7/8 6.5 L80 2.441 510 791 Tubing 31/2 9.3 L80 2.992 729 1009 Tubing 41/2 12.6 L80 3.958 1013 1294 Tubing 51/2 17.0 L80 4.892 1396 1677 1 Casing 51/2 17.0 N-80 4.892 1469 1750 IN THE EVENT THAT YOU ARE SHEARING, MOVE THE HIGH LOW BY PASS INTO HIGH POSITION FOR ALL PIPE SIZES SHOWN. ALL OTHER PIPE NOT LISTED IS NON-SHEARABLE • • NOV 6012 Stack-13-5/8"x 5 K Ram Type Size Blind/Shear Upper Blind/Shear Lower VBR 2-7/8"x 5" VBR 3-1/2"x 5-1/2" Pipe 2-3/8" Pipe 5" Pipe 7" Pipe 7-5/8" Pipe 9-5/8" • �-----, • U C g i w wg 8 1' 51 o "I $1' v— ill ;111 Y gas .. mxn y __ g• .101,- ro•m. ma9m rk,tig.›,71 3` m �' mmio romm� meo � ->,.>�S . n r 3 C.'2.72 4NN i I I t I 1__L. ii g i o CY / II –4V2 p_.-5 ri >. a ,. , li 11 1 / 5 1 C::.............., — — — ' ax gaa gal g / INNI j I —rate- 1 �� ;; §�� 8� 8� 1 1f _ — i.16 s - _=:;1 ��I�I�K;� ------------ ,1 U .• L '�!lI 1111 I ( 9 Q 1 ___,.... r.0-., mil ______i (Jr)■ y i II I ww —+ rm O I I i N I � wal� m 02 ' gig 1 .11-.8-% g ma vt � 1 UIfOO TOY 9 IMI n A V- - —.f/9 9,9 .R-,tt� - O p .Z/l Ol-AZ (3dV1=MOO) OF T�y� • • k.), THE STATE Alaska Oil and Gas f AT . A ,C) Conservation Commission o 1 iLl 1 V Kl 1 � 2___�_ !, 333 West Seventh Avenue ,., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 C4'11.LASlP Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor App,, ' 4 Zr2,i';', BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU X-11A Permit to Drill Number: 199-078 Sundry Number: 317-060 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ag Cathy P.y oerster Chair DATED thisZlda of March, 2017. RBDNIS 1V w, ' L 3 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM N • APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well gdP Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing ® . Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 199-078 • 1 Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 99519-6612 Stratigraphic 0 Service 0. 6. API Number: 50-029-20471-01-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU X-11A RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028313 . PRUDHOE BAY,PRUDHOE OIL • FEB 0 1 2017 11. PRESENT WELL CONDITION SUMMARY Ilia !_3 z ` J,� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Ajy7 k tMpL CL; 9768 ' 8972 • 8459 8190 2500 8459 �� None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2626 13-3/8" 37-2663 37-2663 4930 2670 Intermediate 8987 9-5/8" 35-9022 35-8741 6870 4760 Liner 692 7" 8491-9183 8221 -8899 8160 7020 Liner 1299 2-7/8" 8469-9768 8199-8972 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9595-9685 9034-9003 4-1/2"12.6#L-80 L-80 33-8524 Packers and SSSV Type: 4-1/2"Baker SAB-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8417/8149 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic RI 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development 0 Service I3 14.Estimated Date for Commencing Operations: July 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ® ` GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hyatt,Trevor be deviated from without prior written approval. Email Trevor.Hyatt@bp.com Printed Name John Egbejimba Title Drilling Supervisor Signature17.X. 6///0•V"tenit4.14Phone +1 907 564 4139 Date 1 1 2 al 1 i?' COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test L� Mechanical Integrity Test / Location Clearancele ❑ �� a �c o Other: ' • 3 P kV r ► ZCt� i"(...., p i ,, \ecNieN-T"-Tc'2 �ES� c- 3;i�2. ��'� 4 M3 1 ltp ��Mr o0 i 1-Al wn l\PI" CV vaetacw1I "to r 10 APIC. 2S,A' 2.6) Post Initial Injection MIT Req'd? Yes No ❑/ rOfL �'��- � ' Spacing Exception Required? Yes 0 No I�7 Subsequent Form Required: \O- AO-1 Approved by /90,t4.44/...._ae47 APPROVED BYTHE COMMISSIONER COMMISSION Date: 3._--( ORIGINAL RBDMIIS tit._ MAL. 2 3 2017 l(iO t n Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • • To: Alaska Oil &Gas Conservation Commission From: Trevor Hyattby RWO/CTD Engineer �/r�+ Date: January 31, 2017 Re: X-11Ai Sundry Approval Sundry approval is requested to perform a tubing swap on X-11 Ai to restore integrity to the well. History and current status: X-11 was originally drilled 1/30/1981. It was sidetracked to its current placement on 10/17/1999. X-11 A is a WAG injection well that developed TxIA communication during 2015, when it was swapped to MI injection. It would pass MIT-lAs to liquid, but on MI injection it pressured up its IA. It was SI 11- 17-15. Since the tubing only leaked to gas, an acoustic LDL was run with the tubing pressured up on MI. The only leak found was at 3,038' MD, at the uppermost, STA#5 GLM. A DGLV with extended packing was installed, but with the well on MI injection it still pressured up its IA,the BUR being the same as before. Since the extended packing dummy didn't fix the leak, the plan was to set a patch across the GLM#5. This was deemed prudent because the acoustic LDL had only seen the one leak, and the well passed a PPPOT-T. The first step in the patch program was to get a high pressure test on the tubing.When this was attempted with DHD, pressure was not held against the IA-as was specified in the SOR due to de-rated tubing - and the tubing gave way under an applied pressure of 3589 psi, dropping quickly to 837 psi. Before this the tubing leaked only to gas, but during this operation the IA tracked with the tubing (1 bbl diesel pumped,tubing increased 383 psi, IAP increased 370 psi, in 6 min (see 2-24-16 WSR)).To go look for the large leak, SL went in 5-17-16, but tagged very shallow, at 4' SLM, getting a crescent moon shaped impression on a LIB. SL believed they had found separated tubing and pulled out. EL then ran a downhole video camera. They also tagged 4', getting the same crescent moon shape on a LIB, but were able to get the camera through it, running down to 200', No tubing separation was seen. It was determined that SL's LIB had tagged the 7-1/2"x4-1/2"crossover that is in this wellhead. With the crossover tag/problem understood, the LDL program was reinitiated. On 9-17-16 FB filled up the tubing and IA with diesel, establishing significant LLR's of 1 bpm w/275 psi differential, 3 bpm w/412 psi differential, and 5 bpm w/640psi differential. SL next pulled a caliper two days later,finding the tubing split/burst at 7716' MD. The well is currently offline, classified as"Non-Operable,"due to TxIA communication. The tubing and IA are filled with diesel, and there is a TTP installed at 8,459' MD. The tubing is in "good to poor"condition, with many wall penetrations up to 30%, and a few up to 40%. There is a known tubing split at 7,716' MD. There is also potentially a tubing leak only to gas at 3,038' MD, in the STA#5 GLM. Proposed plan: Parker 272 rig will perform a tubing swap on or around July 1st, 2017. The MASP is 2500 psi. This Sundry covers a waiver request for setting the new production packer 1,345' MD from the existing X-11 Ai perforations (waiver request for 20 AAC 25.412(b) "packer must be placed within 200' MD above the top perforation").—We are unable to set the packer lower because the existing production packer is at 8,414' MD (1,180' MD from the top of the perforations). Perforations are isolated by a fully cemented 7"liner. The 9-5/8"$- — CBL has poor data uality. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. • • Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable • status. Pre Rig Prep Work: S 1 Pull XX plug and Nipple reducer. SBHPS. Set 4-1/2" PX plug. F 2 CMIT-TxIA to 4,000 psi, MIT-OA to 1200 psi. E 3 RCT cut the 4-1/2"tubing. F 4 L&K well with seawater and Diesel F/P to 2500'. Bleed TBG to-200 psi. ✓ 5 LDS. PPPOT-T& IC. ✓ 6 Set TWC and test to 1000 psi, ND Tree, NU Dry Hole Tree, PB I/A& upper 0/A valves O 7 Bleed WHP(s) to zero. Remove the well house &flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE. 2. Pull 4-1/2"L-80 tubing from jet cut. 3. Set a storm packer and swap tubing spool and IC packoff during tubing decomplete 4. Run 4-1/2", 12.6#, L-80 VamTop tubing with packer and Unique Overshot. 5. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work ✓ 1 Pull dryhole tree,put on the production tree. Pull TWC. S 2 Pull B&R, Pull RHC sleeve, Fish PX plug F 3 Pre-injection State witnessed MIT-IA test 2_t , Vit,. Trevor Hyatt 1 OS ,w tirp�` 1� ,� t , , t ROW/CTD Engineer 564-4627 i2-03t`mie t-KJCL '426n CC: Well File Joe Lastufka TREE= 4-1/8"CNV FLS • NOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD= GRAY X-11 A 10N ML WELL REQUIRES A SSSV WHEN ON ACTUATOR= BAKER C MI. WELL ANGLE >70°@ 9400" ***4-1/2"GS FISH KB.ELEV= 74.05' NECK SET @ TOP OF 2-7/8"LW*** BF.ELEV= 39.95" L KOP= 3100' Max Angle- 112°@ 9718' 4' }—7 X 4-1/2"XO,D=3.895" Datum M)= 9157' Datum TVD= 8800'SS 2140' —4-1/2"OTIS DBE SSSV N,ID=3.813" I 13-3/8"CSG,72#,L-80,D=12.347" H 2662' I I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH TORT DATE 5 3032 2957 7 OTIS "DMY RM 0 09/25/15 4 5113 4944 18 OTIS DMY RM 0 09/26/08 3 7235 6932 18 OTIS DMY RM 0 09/26/08 2 8005 7671 14 OTIS DMY RM 0 09/26/08 Minimum ID = 2.313" @ 8459' 1 8231 7893 12 0115 DMY RM 0 09/26/08 4-1/2" X 2-7/8" X NIPPLE REDUCER 'STA#5=EXTENDED PACKtJG II 8340' --14-1/2"OTIS SLD SLV,D=3.813 8396' _44-1/2"BAKER SBR SEAL ASSY 8415' --19-518"X 4-1/2"BKR SAB-3 FKR D"3.813" 8459' —4-1/2"OTIS X NP,D=3.813" 8459' —4-1/2"X 2-7/8"X MP REDUCER,D=2.313" (01/25/16) TOP OF 2-7/8"LNRI—� 8459' 8459' --I2-7/8"XX PLUG(01/25/16) 8469' —3"DEPLOY SLV,ID=? TOP OF 7"LNR — 8491' 8490' —14-1/2"OTS XN NP,ID=3.725" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" 8522' / V 8522' 4-1/2"TBG TAS,D=3.958" 8525' H ELMD TT LOGGED 10/27/99 14-5/8-CSG,47#,L-80,15;8.681" --r PERFORATION SUMMARY REF LOG:MVVD GR ON 10/15/99 ANGLEAT TOP PERF: 106°@ 9595' MILLOUT WINDOW(X-11A) 9183'-9190' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9595-9685 0 10/17/99 1.40001747 TOP OF WHIPSTOCK 9180' /....... PBTD I— 9737' .i.i.i«iii 7"LNR,29#,L-80,0.0371 bpf,D=6.184" --� 9971" MAttoAtt kft.N 2-7/8" 1BG,6.16#,L-80,.0058 bpf,D=2.441" — 9768' DATE REV BY COMMENTS DATE REV BY COMMENTS RJJH)E BAY UNIT 01/30/81 ORIGINAL COMPLETION 05/25/16 RCT/JM) PARIWTBG(05/17/16) WELL: X-11A 10/17/99 SIS- SIDETRACK COMPLETION 07/05/16 KS/JM) CORRECTED PARTED TBG TO XO FERMI No:'1990780 03/29/02 RN/TP CORRECTIONS AR No: 50-029-20471-01 10/02/15 TBD/JMD GLV C!O(09/26/15) SEC 7,T1ON,R14E,498'FM_&588'FEL 01/27/16 DJS/JM) SET NP RED/PLUG(01/25/16) 02124/16 DU/JM) TREE C/O(02/06/16) BP Exploration(Alaska) TREE= " 4-118"CAN FLS • ON MI.W READINGS A AVERAGE 125 ppm WHEN ON AV1�LFEAD= GRAY X-1 1 A _CTUATOR=__ B BAKER C Proposed ML WELL ANGLE >70°@ 9400'.`A"4-1I2"GS FISH KB.ELEV= 74.05' NECK SET @ TOP OF 2-7/8"LW'"* BF.ELEV ---39-95' J _KOP_---- 31-0737 3100' NfaxAngle= 112°09718' 11 _ —4-1/2" X NIP - 3.813" (for MCX SSSV) _Datu_m_MD= __- 57 91 ' DatumTVD= — 8800'SS 13-3/8"CSG,72#,L-80,D=12-347" H 2662' 4-1/2" L-80 VamTop Minimum ID = 2.313" @ 8469' I 14-1/2" XNIP - 3.813" 4-1/2" X 2-7/8" X NIPPLE REDUCER 23 — I I �- HES 4-1/2" x 9-5/8" TNT PKR @ 8250' 4-1/2" X NIP - 3.813" — _ Unique Machine Overshot � 1 Pre rig RCT cut @ 8360' 8396' _14-1/2"BAKER SBR SEAL ASSY x 8415' 1-19-5/8"X 4-1/2"BKR SAB-3 R(R,ID=3.813" - 8t8459' H4-1/2"OTIS X NP,D=3-813" 84.59' —4-1/2"PX plug TOP OF 2-7/8"LNR —I 8469' TOP OF 7"LNRH 8491' —� 8469' H3"DEPLOY SLV,ID=? 8490' H 4-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" —I 8522' - / \ 8522' —4-1/2"TBG TAL,ID=3.958" 8525' H B-MD TT LOGGED 10/27/99 9-5/8"CSG,47#,L-80,D=8.681" H 9022' I L PERFORATION SUNSMIRY REF LOG:NMID GR ON 10/15/99 ANGLE AT TOP PEW: 106°@ 9595' MLLOUT WINDOW(X-11A) 9183'-9190' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DOTE 2" 4 9595-9685 0 10/17/99 •i1v1c1� � •�•�•• 4...4.. PBTD 9737' TOP OF wFiPSTocK 9180' ►010101/11 0 1111111/111111 4..4.1.......1. 7"LNR,29#,L-80,0.0371 bpf,ID=6.184" — 9971' ��1 A.A.A.At� atiV 2-7/8"TBG,6.16#,L-80,.0058 bpf,ID=2.441" —I 9768' DATE REV BY CONSENTS DATE REV BY CONSENTS PRLDHOE BAY UNIT 01/30/81 ORIGINAL COMPLETION 05/25/16 RCT/JND PARTED TBG(05/17/16) WELL: X 11A 10/17/99 SIS- SIDETRACK COMPLETION 07/05/16 KS/JND CORRECTED PARTED TBG TO XO PBRMT No:`1990780 03/29/02 RN/TP CORRECTIONS API Nb: 50-029-20471-01 10/02/15 TBD/JND GLV CO(09/26/15) SEC 7,T1ON,R14E,498'FNL&588'FEL 01/27/16 DJS/JND SET NP RED/PLUG(01/25/16) 02/24/16 DUYJND TREE CIO(02/06/16) BP Exploration(Alaska) • 0 PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M A 13 5/8"-5M STUDDED TOP w, 13 5/8"-5M FLANGED BOTTOM o ANNULAR BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY AND (2) 14" PSLK W/BSTR OPERATOR, nn�i Oo7a SHAFFER LXT 13 5/8"-5M LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 1 I DRILLING CROSS: 13 5/8"-5M FLANGED TOP I I0 I 1 13 5/8"-5M FLANGED BOTTOM 0.31 °°°°•0 E- w (2) 3 1/8"-5M SIDE OUTLETS ° ° - II ° e E ���°°(((yyyyyy II II II 1DI •• °°°° "' •• 1 II I I - - KILL LINE: y �� � .� �n�I , �� _v 2-1/16" 5M FLEX HOSE XX �;VA FF �� . is * �-.- 5C 2-1/16" 5M X 3 1/8" 5M D.S.A. �/ SII 3-1/8" 5M FLANGED MANUAL GATE VALVE MIIIMIIIIII E �� O 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 11LL • • ° O Or •• P I 1 I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 3-1/8" 5M FLEX HOSE 13 5/8"- 5M FLANGED BOTTOM W/(2) 14" UL2 OPERATOR OF T • • \N I/7,�s� THE STATE Alaska Oil and Gas 1,0 • 9� OfALAS Conservation VatiOYl CommissionS1®ri — '#-t2 333 West Seventh Avenue " GOVERNOR BILL WALKER Anchorage,e, Alaska 99501-3572 110TMain: 907.279.1433 4LAS' Fax: 907.276.7542 www.aogcc.alaska.gov Wade Boman Production Engineer S'. 'YNEU rE6 2`E6 2 4 235 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-11A Permit to Drill Number: 199-078 Sundry Number: 316-012 Dear Mr. Boman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this l4 day of January, 2016. RBDMS JAN 15 2011 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPRO S • 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate D Repair Well EI • Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other it-.!?i n q 4 tC n L c/ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 199-078 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service H• 6. API Number: 50-029-20471-01-00 • 7, If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? p..' �w Will planned perforations require a spacing exception? Yes 0 No RI PBU X-11A :, C C 9. Property Designation(Lease Number): 10. Field/Pools: JAN 0 6 20,6 ADL 0028313 • PRUDHOE BAY,PRUDHOE OIL • i �/ 11. PRESENT WELL CONDITION SUMMARY 0 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9768 8972 • 9737 8983 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 37-117 37-117 Surface 2626 13-3/8"72#L-80 36-2662 36-2662 4930 2670 Intermediate 8987 9-5/8"47#L-80 35-9021 35-8740 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9595-9685 9034-9003 4-1/2"12.6#L-80 L-80 32-8523 Packers and SSSV Type: 4-1/2"Baker SAB-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8416, 8147.05 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: - Detailed Operations Program Q BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development 0 Service RI 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG Q • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Boman,Wade be deviated from without prior written approval. Email Wade.Boman@bp.com Printed Name Boman,Wade Title Production Engineer,B&X pads Signature a n � Phone +1 9075644674 Date (—6-(6- vs,,,„ _ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Inte ri3 I�j/ • Q ( D_ Plug 9 ty 0 BOP Test 0 Mechanical Integrity Test It Location Clearance 0 Other: 0_1_ 4 fic, w,-f-,..,r.svzd , sT—/A- rt1vf✓�4 a ¢j-tr ska6.j /15-r‘ ei linj.Ceh > ll Post Initial Injection MIT Req'd? Yes IA' No 0 Spacing Exception Required? Yes❑ No !$I Subsequent Form Required: /I' — 4t'' 4 APPROVED BYTHE Approved by: /, COMMISSIONER COMMISSION Date: /_ /1 `/6 (TTL 1/y2/y(o TJ ORIGINAL RBDMS'JAN 15 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • m a O DQ co N- O O N O O ti , O p N d U MO NCO co COc co co CO - co OO N_ N O N O) N CO d' N. O) UD O ti O co N NCOCOCOCO i i I i I i O) N I- co Lo O) N N 000100 ,— N0) CO CO N r CO M C) CO N CO CO N CO O ti r LO N (5) O) O) 00 V 0 M C I I oo co c N M CO M dCO CO O' .Q c• O O O Q O _ CO Cb O CO ;-11 � Ooo - ON V N `o N 01) N r +' CO N- C) C CO CO O) N O) d- J N CO r- c0 co W CC Q C 0w 0 ' U W U 0 LLE CtQ Z O J I Z Z D U) Z J J ALASKA WELL AC•Y STATEMENT OF REQUIREMENTS (V2.0,D•LHD,EAZ,BPG 10/12/15) General Information Well Name: X-11A Well Type: WAG Injection Well API Number: 50-029-20471-01 Well Activity Conventional 4 Classification: Activity Description: Tubing Patch Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 150 bopd: Job Type: Mech-Patch Estimated Cost, $325 $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Wade Boman Contact numbers: (907) 564-4674 (907)687-446E Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 (907)301-124C Lead Engineer: Brian Glasheen Contact numbers: (907) 564-5905 (907) 545-1144 Date Created: December 8, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectior Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut (%) (Mscf/Day) (psi) 11/23/2015 0 0 3,230 Current Status: Not Operable Shut In Inclination>70°at Depth (ft) 9,429' MD RecentMaximum Deviation(Angle and H2S (date,ppm) NA 0 ppm Depth) l 9,695' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 43° 9,429' MD Reservoir pressure(date, psig) 7/2/2013 3281 psi Minimum ID and Depth 2.37" 8469' MD Reservoir Temp,F 226° F Shut-in Wellhead Pressure Known mech. integrity problems(specifics) IA pressures up while on MI. Leaking DGLV replaced with extended packing and IA still pressures. Last downhole operation (date, operation) 9/26/2015 Pull 4-1/2" PX plug from 8459' MD. Set 4-1/2" MCX in SVLN @2140' MD. Most recent TD tag (date,depth, toolstring OD) 9/23/2015 8469" MD SL tagged deployment sleeve w/3.6"CENT, 3.5" LIB If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? Surface Equipment Checklist. Comments,well history, X-11A has historically been on PWI. Recently, while on PWI, it passed an MIT-IA to 2500 psi on 7-20-15. background information, Then on 8-16-15 the well was swapped to MI injection. At first no anomalies were seen, but after about 10 / etc: days of the MI swap the IA pressure started climbing, making bleeds necessary as the IA got up around 1500 psi, close to the MOASP of 2000. The WIC classified the well as "Under Eval" on 8-30-15, allowing • me wei main onnne so as to make possioie ringing mese or mis IR pressure ciimo.Hoout a week • later an NITf-IA was performed with diesel to 2500 psi, the well barely failing the test(s). Three tests were performed in all,the total pressure losses being only 75 psi, 56 psi,and 48 psi, respectively. On 9-11-15 it was determined that the secondary tubing hanger seal was holding. Since the TxIA communication was seen only while the well was on gas(MI)injection, on 9-25-15 SL set a plug and ran a Press/Temp/CCL and tandem Archer acoustic memory log with the tubing pressured-up on MI at 3000 psi WHP,to find the source of the TxIA communication.To ensure a low dP between the tubing and IA returns were taken up the IA and to a bleed trailer. During the log a single leak was found at the STA#5 GLM, at 3038' MD.A DGLV with extended packing was installed and the well passed an MIT-IA to 2500 psi with 60/40 methanol. SL pulled the plug and reset the MCX. On 9-26-15 the well was POI with MI and a PPPOT- T passed,with the IAP increasing to only 380 psi.The well was then SI. The well was put on continuous MI injection on 10-29-15. IA BUR's were seen just barely better than before. The well was then classified as "Not Operable"and SI 11-17-15. Due to the single leak seen with i the LDL and the passing PPPOT-T it is believed that the same mandrel(#5) is still leaking, with the extended packing DGLV not stopping the leak.This goal of this program is to place a straddle packer patch across the#5 GLM,thereby stopping the TxIA communication. • Well Intervention Details • Suspected Well Problem: Specific Intervention or Well Objectives: 1 Set patch over GLM#5 to seal TxIA leak to gas 2 3 Key risks,critical issues: Mitigation plan: 1 De-rated tubing. Use 1.1x max injection press for MIT-T(1.1x3200=--3500 psi) 2 Operations on MI injection well Follow RP for working on gas/MI injection wells. 3 Summary Ste # Service Line Activity P 1 FB Assist SL. Load tubing. CMIT-TxIA to test nipple reducer. MIT-T to test tubing. 2 SL Set reducing nipple and plug. 3 FB Assist EL. Pump hot diesel to warm-up tubing for patch set. 4 EL Set patch across GLM #5. 5 SL Set plug. 6 FB Assist SL. Load tubing. MIT-T to 3500 psi Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1) Load tubing with 1.5 tubing volumes diesel, max press 2500 psi (see pump schedule). 2) SL RIH, pull MCX, POOH. 3) SL RIH, drift with 25' KB packer dummy to 4-1/2"X-nipple @8459' MD. POOH. 4) SL RIH, set 2-7/8" reducing nipple in 4-1/2" X-nipple @8459' MD. POOH. 5) SL RIH, set plug in nipple reducer. POOH. 1 SL/FB 6) FB test nipple reducer with 2500 psi CMIT-TxlA(see pump schedule). 7) FB test tubing integrity with 3500 psi MIT-T with 1500 psi held against the IA(see pump schedule). If this passes or fails move on to Step 8. 8) SL RIH, pull plug, POOH. 9) RDMO for E-line. 1) FB pump 60 bbls 180-deg diesel down tubing to heat tubing in preparation for E-line patch set. Coordinate with EL. It is imperative that the patch location is heated-up well just before EL sets the patch. 2) EL RIH, tie into 9-24-15 PDS LDL(log is referenced/tied-in to tubing tally). 2 EL/FB3) EL set 20'element-to-element Baker 45 Flo-Guard Straddle Packer across GLM #5, with bottom element set @3047' MD in lower 10'pup joint(**see "patch location diagram" tab, below**). POOH. CONTINGENCY STEP If 3500 psi MIT-T failed after SL set nipple reducer: 1) SL RIH, set plug in reducing nipple @8459' MD. 3 SL/FB 2) FB load tubing and hold 1500 psi on IA and perform 3500 psi MIT-T(see pump schedule). 3) SL pull plug, POOH. 4) RDMO. Performance Ectations (may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Put on MI injection, after WIC approval Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • 1) VIS,INN ,3 1" C:S,7,40,r '":"'S 7::'...),4 Gu'.; A 11 col,t(Ais act -c-,....e. 71/4141 Tftl 7. 3011.i 1— -- 4 J -S , a . —- 30iX-, — t.. .› 1 # i.s. . 4 '4. i ,•,.. —..„ .4„icePC4J A,1 WI , . . ,. !... , ,.... 3(.141- • g. 305). ,3 -- I • • • '. rthern Soluttonc, Baker 45 Flo Guard One Trip °Kr+s�Kr+edge for " � ai..k." "�' "` Straddle Packer—Eli Mechanical Set '�Ind:�siry 465 000xx I Well No.: ! X-11A Vendor: Drawn By:CWD Requested By: Wade Boman i:O i N FO t P ATI O `l O N=: BOT 12-03-15 Description , OD ID Length MN A A 1 _ 1.18' V V . __ .40, n A Upper Straddle Packer 3.70" 2.45" 5.51' III 4"GS Fishing Neck Up 5.51" 3-':"STL Pin Down ® 3.93' 20.00' III ■ Iv • 26.15' 15.24' 33i"9.34 STL Pup Joint 3.500" 2.910" ! 15.24' III .83' .40' 11111 Lower Straddle Packer Iir, 5.40' 3 ."STI.Box Up 3.70" 2.45" 1 5.40' � 3-'2"WLEG Down I ® 4.17' II. i , 111 T T 1 i_ Total Length TW: I I he enclosed is conceptual for 1-'1- ;inn only All feasibility and dimensional data shooid tarr verified with th. w I ���_ , plying vendor prior to installatIon. TREE= GW NOTES:li2S HEADINGS AV67AGI:125 ppm VbQL HEAD= GRAY • X-11 N lYiI.WELL REG?tlIRES A SSS/WNEN ON ACTUATOR= BAKER C 1 MI. WELL ANGLE >70'@ 9400'."*41/2"GS FISH KB.ELEV= 74.05' NECK SET @ TOP OF 2-7/8"LNR"* BF.B_EV= 39 95' KOP= 3100' —.------_ __— 2140' -44-1/2"OTIS SSS/Imo,D=3.813" Max Angle= 112"Q 9718' Datum MD= 915T Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" --F 2662' -Al 11 GAS LIFT MANDRas 1ST MD ND DEV TYPE VLV LATCH PORT DATE li 5 3032 2957 7 OTIS *DMY FM 0 09/25/15 L_j1 4 5113 4944 18 OTIS DMY RM 0 09/26/08 3 7235 6932 18 OTIS DMY RM 0 09/26/08 2 8005 7671 14 OTIS DMY RM 0 09/26/08 1 8231 7893 12 OTIS DMY RM 0 09/26/08 Minimum ID = 2.37" @ 8469' .STA#5=EXTENDED PACKIVG TOP OF 2-3/8" LINER I TT 8340' -441/2"Oils SLDSLV,D=3.813=1 839€' 4-112'BAKER SBR SEAL ASSY R 8415' --9-5/8'X 4-1/2'BKR SAB-3 FKR,D=3.813' I I } 8459' --141/2"OTIS X tom,D=3.813" [TOP OF 2-7/8"Lt+R H 8469--j a ■ j— :46 ---1 3"DEFLOY SLV,D=? 1 I I[TOP OF 7"LNR H 8491' I--1-. ,,., [ 84 -�4 90` - 1J2"OTIS XN Fes,D=3.725" 4-1/2"TBG, 12.6#,L-80,.0152 bpf, =3.958" H — 8522 8522' J / \- ^ ' r-41/2'TBD G TAL, =3.9581 D - 1 8526' H B-MD TT LOGGED 10/27/99 1 97518*CSG,47#,L-80,D=8.681" IH 9022' PERFORATION SUIMMRY REF LOG:MWD GR ON 10/15/99 ANGLE AT TOP PERF:106"Cs 9595' MLLOUT WINDOW(X-11A) 9183'-9190' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DOTE 2' 4 9595-9685 O 10/17/99 TOP OF Wt*STOCK 9180' •'•'•'•�•�•�•#• •�•••�•�•••• F'BTD — 9737 1•••••••••••••• •.••••••••••••• •••••••• - 7"LPN2 29#,L-80,0.0371 bpf,D=6.184" H 9971' MAJAVA 400b 2-7/8"TBG,6.16#,L-80, .0058 bpf,I)=2.441' —{ 9768' j DATE REV BY COMfUYTS DATE REV BY COMMENTS PRUOFiOEBAY UNIT 01/30/81 ORIGINAL COMPLETION 02/16/11 MB/AIDADDED SSSV SAFETY NOTE V L X-11A 10/17/99 SIS- SIDETRACK COMPLETION 01/20/12 TM/MD ADDED H2S SAFETY NOTE PERMIT No:'1990780 03/29/02 RN/TP CORRECTTORIS 10/02/15 TBD/JMD GLV C1O(09/26/15) AR No: 50-029-20471-01 12/04/06 RAC/ThH C)OMNB�T BOX COf TION SEC 7,T10N,R14E,498'FNL&588'FH 01/08/08_ALS/SV CORRECTIO S 10/17/08 SEW/PJC GLV C/O(09/26/08) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, October 20, 2015 2:23 PM To: 'AK, D&C Well Integrity Coordinator' Cc: Regg, James B (DOA) Subject: RE: X-11A (PTD #1990780) Extended Monitoring Inner Annulus Pressure post LDL Kevin, Approved for an additional 28 days injection as proposed below. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) 8 (907)276-7542 (fax) SCAEV APR 0 2016 chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Tuesday, October 20, 2015 2:21 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: X-11A (PTD #1990780) Extended Monitoring Inner Annulus Pressure post LDL Chris, Injector X-11A(PTD#1990780) was showing signs of anomalous inner annulus pressure on miscible injection.A leak detection log was performed on September 25, 2015 and found gas lift valve @ stn#5 leaking.The valve was changed out and a subsequent MIT-IA passed to 2500 psi on September 26, 2015. The well was put back on injection on October 08, 2015. The MI injection rate has shown not to be stable enough to get an accurate build up rate. BP would like to monitor the pressures for an additional 28 days to determine if there is any communication. Enclosed is a copy of the TIO and Injection Plots for reference. Thank you, Kevin Parks BP Alaska-Well Integrity Coordinator GNGlobal Wells 'f Y Organization 1 • • • Injecetor X-11A(PTD#1990780) Injection Plot Wei,N-,I 305- IDS :A all kW 2,46 SOX S'Sk —k _t67F nit"i —M t4G �� £:SLS _p.. RNt la ^7x u CS tiZ 4. 1 p� h ena \ /"... 2sa 0,2015 F]?t5 'kt<l+ d44% 14.1'1! MCI ait"5 '94^5 b'.rc 5P8 3331 1001 N'2"'. W141 Injector X-11A(PTD#1990780)TIO Plot +A. tr zcd �a as -4-Ir. a zam VAI V \//1/41.* 0`®'15 SMIS IGOE 76'x15 7617,15 012415 tori WC'S Tilt/ 141.15 CS.2 INV! xu'!. A'S-`. • 2Co330) WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. VO/I4i/2015 M.K.`BENDER To: AOGCC -4 Makana Bender 333 W. 7th Ave L I C 9 2.015 Suite 100 SCANNED SEP 1 5 2016: (907)Anchorage,793-1225 Alaska 99501 AOGCC 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 attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2—1 900 Benson Blvd. Anchorage, AK 99508 uancodc@bb.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 24-Sep-15 X-11A BL/CD 50-029-20471-01 2) Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE@p MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, September 28, 2015 12:30 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION: X-11A (PTD #1990780) Monitor Inner Annulus Pressure post LDL Attachments: Injector X-11A (PTD #1990780) TIO Plot 09-28-15.docx;X-11A WBS.pdf Chris, As per our conversation earlier. WAG injector X-11A (PTD#1990780)was showing signs of anomalous inner annulus pressure on miscible injection. A leak detection log was performed on September 25, 2015 and found gas lift valve @ stn#5 leaking. The valve was changed out and a subsequent MIT-IA passed to 2500 psi on September 26, 2015.The well is still classified as Under evaluation for additional diagnostics.The plan forward will be to monitor inner annulus pressure for 14 days and obtain an Inner annulus pressure build up rate. If we don't see any communication the diagnostic work will be completed. If there is still inner annulus repressurization more diagnostic work will continue. We will use the AOGCC witnessed test that was performed on 07/20/15 for our anniversary date if there is not any additional work to be done. A copy of the wellbore schematic and TIO plot are included for reference. Thank you, Kevin Parks (Alternate. Whitney Pettus BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 SCANNED AUG i i 2016 WIC Email:AKDCWeIllntegrityCoordinator@bp.com 1 _ • • Injector X-11A(PTD#1990780)TIO Plot 09-28-15 2. 1. � i • ' TREE= OW • SY NOTES:H2S READINGS AVERAGE 125 ppm WEACTUATAD R= GRAYRX-11 A Mi.WHEWELL ANGLE >0N ON MI.WELL °@/RES9400'.S4-1V WHEN ON 1/2"GS ISH ACTUATOR= BAKER C KB. ELEV= 74 05' NECK SET @ TOP OF 2-7/8"LNR""" BF. ELEV= 39 95' KOP= 3100' 2140' —14-1/T OTIS SSSV NIP,ID=3.813" l Max Angle= 112°@ 9718' O Cetum MD= 9157' Datum TVD= 8800'SS 13-3/8"CSG,72#, L-80,ID=12.347" —I 2662' , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Li1 5 3032 2957 7 OTIS DMY RM 0 09/26/08 'LII 4 5113 4944 18 OTIS DMY RM 0 09/26/08 3 7235 6932 18 OTIS DMY RM 0 09/26/08 2 8005 7671 14 OTIS DMY RM 0 09/26/08 1 8231 7893 12 OTIS DMY RM 0 09/26/08 Minimum ID = 2.37" @ 8469' TOP OF 2-3/8" LINER - [ 8340' —(41/2"OT1SSLD SLV, ID=3813"j I I 8396' _14-1/2"BAKER SBR SEAL ASSY Z 8415' --19-5/8"X 4-1/2"BKR SAB-3 PKR, ID=3 813" 1 ' ' [ 8459' 1-14-1/2"OTIS X NIP, ID=3 813" 1 TOP OF 2-7/8"LNR l—{ 8469' l I P { 8469' —3" DEPLOY SLV,ID=? I TOP OF 7"LNR — 8491' I I _ 8490' —14-112"OTIS XN NIP,ID=3.725" 14-1/2"TBG, 12 6#,1-80, .0152 bpi,ID=3.958" H 8522' / \ I 8522' H4-1/2"TBG TAIL,ID=3.958" 1 8525' i—ELMD TT LOGGED 10/27/99 9-5/8' CSG.47#,L-80. ID=8.681" H 9022' HA , PERFORATION SUMMARY REF LOG MWD GR ON 10/15/99 ANGLE AT TOP PERF 106°@ 9595' MILLOUT WINDOW(X-11A) 9183'-9190' Note Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9595-9685 0 10/17/99 111111111111111 1111111 TOP OF WHIPSTOCK 9180' 11111111111111 PBTD —( 9737' 11111111 111111111111111 1111111 1111111 1111111111111 7"LNR,29#, L-80,0 0371 bpf, ID=6 184" —1 9971' 1�1�•1A1•1•1•1/ akNliT 2-7/8"TBG,6 16# L-80. 0058 bpf, ID=2 441" 9768' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/30/81 ORIGINAL COMPLETION 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE WELL X-11A 10117/99 SIS- SIDETRACK COMPLETION 01/20/12 TMN/JMD ADDED H2S SAFETY NOTE PERMIT No '1990780 03/29/02 RN/TP CORRECTIONS API No 50-029-20471-01 12/04/06 RAC/TLH COMMENT BOX CORRECTION SEC 7,T1ON, R14E 498'FNL&588'FE- 01/08/08 ALS/SV CORRECTIONS 10/17/08 SEW/PJC'GLV C/O(09/26/08) BP Exploration (Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, August 30, 2015 8:57 AM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL;AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Glasheen, Brian P; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector X-11A (PTD #1990780)Inner annulus Pressurization Attachments: Injector X-11A (PTD #1990780) TIO Plot.docx All, WAG Injector X-11A(PTD#1990780) has shown signs of anomalous inner annulus pressure trends while on miscible injection.The well has been reclassified as Under Evaluation and is placed on a 28 day clock for additional diagnostics. Plan Forward: 1. DHD: Bleed down IA and obtain a BUR 2. DHD: Perform MIT-IA to 2,500 3. WIE: Additional diagnostics as needed A copy of the TIO plot has been included for reference. %WED SEP 0 32015, Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 A. Injector X-11A(PTD#1990780)TIO Plot CV\ ''may :M I Cos p i5 la lippp...140v :... 00101 ann 0w15 a. 012,1 0:115 I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,July 23,2015 TO: Jim Regg ?°-em 51 13115 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC X-11A FROM: Bob Noble PRUDHOE BAY UNIT X-11A Petroleum Inspector Src: Inspector Reviewed By,, P.I.Supry J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-11A API Well Number 50-029-20471-01-00 Inspector Name: Bob Noble Permit Number: 199-078-0 Inspection Date: 7/20/2015 Insp Num: mitRCN150723115340 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type Iu g 1 -_ - 1990780 Type SPIT-Test --...- 8147037 199 2511 ' 2444 - 2411 Well 1 T e In' TVDTubing 2 PTD 4YRTST T e TCSt TCSt S P ✓ IA 93 177 206 244 - Interval ; P/F 1 OA Notes: SCANNED , / ; r Thursday,July 23,2015 Page 1 of 1 • s MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 14,2015 P.I.Supervisor 'Ver b'it(is- SUBJECT: Mechanical Integrity Tests (( I BP EXPLORATION(ALASKA)INC X-1IA FROM: Chuck Scheve PRUDHOE BAY UNIT X-I IA Petroleum Inspector SCOWL, JUL v e) ,/4� r°, Src: Inspector Reviewed By: P.I.Supry,1-04— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-1 IA API Well Number 50-029-20471-01-00 Inspector Name: Chuck Scheve Permit Number: 199-078-0 Inspection Date: 7/11/2015 Insp Num: mitCS150712061241 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X-11A - Type Inj W -TVD 8147 ' Tubing 859 j 860 - 860 - 860 -T 858 - PTD� 1990780 - Type Test,SPT Test psi 2037 IA 226 2502 - 2400 - 2326 2273 - Interval I4YRTST P/F I ✓ OA 107 186 186 197 202 J Notes: First attempted test .i Tuesday,July 14,2015 Page 1 of I . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 14,2015 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC X-11A FROM: Chuck Scheve PRUDHOE BAY UNIT X-11A Petroleum Inspector SG�►NNE� JULi1 i Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-11A API Well Number 50-029-20471-01-00 Inspector Name: Chuck Scheve Permit Number: 199-078-0 Inspection Date: 7/11/2015 Insp Num: mitCS150712061530 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X-11A . 1Type Inj w'TVD 8147 ' [Tubing 860 " 859 • 860 • 860 - 860 - 1990780 - Type Test SPT Test psi 2037 IA 2251 2501 • 1 2455 - 2417 - 2387 -1 Interval - - I Val 4YRTST P/F I I ✓ OA 202 209 • 207 212 213 " Notes: Second test attempt ✓ Tuesday,July 14,2015 Page 1 of 1 . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: p DATE: Tuesday,July 14,2015 P.!.SuSupervisor t u( (1 SUBJECT: Mechanical Integrity Tests l ` BP EXPLORATION(ALASKA)INC X-11A FROM: Chuck Scheve PRUDHOE BAY UNIT X-11A Petroleum Inspector Sr AKU " Src: Inspector �'i�� Reviewed By: P.I.Supry i NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-11A API Well Number 50-029-20471-01-00 Inspector Name: Chuck Scheve Permit Number: 199-078-0 Inspection Date: 7/11/2015 Insp Num: mitCS150712061829 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X-IIA `!Type Inj w- TVD 8147 - Tubing', 859 • 860 • 860 858 859 - PTD 1990780 Type Test SPT Test psi 2037 - IA 185 2502 - 2469 - 2448 i 2431 - Inter 4YRTST 1 106 184 185 • 195 . 200 _ Interval P/F OA 1 Notes: Third attempt Tuesday,July 14,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, July 13, 2015 3:59 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Wallace, Chris D (DOA); Glasheen, Brian P Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION:Injector X-11A (PTD #1990780) AOGCC MIT-IA Inconclusive Attachments: image001.png All, Injector X-11A(PTD#1990780)was due for regulatory compliance testing by the end of September. An inconclusive AOGCC MIT-IA was performed on July 11, 2015.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform another AOGCC MIT-IA 2. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED JUL 1 6 2015 (Alternate: Kevin Parks) BP Alaska -Well Integrity Coordinator a WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~c[.[}'7,~" File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA ~ Diskettes, No. ~X [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverl~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 BRIGHTWATER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ TREATMENT 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 ❑ Exploratory ❑ "199-0780 3. Address: P.O. Box 196612 Stratigraphic Service 111 6. API Number: Anchorage, AK 99519 -6612 a 50- 029 - 20471 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: . ADLO- 028313 PBU X -11A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9768 feet Plugs (measured) None feet true vertical 8971.9 feet Junk (measured) None feet Effective Depth measured 9737 feet Packer (measured) 8415 feet true vertical 8983.41 feet (true vertical) 8147 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 34 - 114 34 - 114 Surface 2629' 13- 3/8 "72# L -80 33 - 2662 33 - 2662 4930 2670 Production 8990' 9- 5/8 "47# L -80 32 - 9022 32 - 8741 6870 4760 Liner 699' 7" 29# L -80 8491 - 9190 8221 - 8906 8160 7020 Liner 1299' 2 -7/8" 6.16# L -80 8469 - 9768 8199 - 8972 13450 13890 Liner Perforation depth: Measured depth: 0 9595 - 9685 _ _ - True Vertical depth: 0 9033.76 - 9002.68 _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 31 - 8522 31 - 8251 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SAB -3 Packer 8415 8147 RECEvED 12. Stimulation or cement squeeze summary: OCT 0 4 ? Intervals treated (measured): Alaska Oil & Gas Cons. Commission Treatment descriptions including volumes used and final pressure: Ancnort,tgo 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 5,978 1,265 Subsequent to operation: 5,570 1,013 14. Attachments: 15. Well Class after work: , Copies of Logs and Surveys Run Exploratory Development ❑ Service eg Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP0 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best gfr�edge. t', .os 0 '0%1 Sundry Number or N/A if C.O. Exempt: °' ri i � NA Contact Joe Lastufka Printed Nam- Joe Last- - Title Petrotechnical Data Technologist Signatu - k 'I, Phone 564 -4091 Date 10/4/2011 R iDMS OCT 17 2011 Iff 7 � 0 ' ' `� Form 10 -404 Revised 10/2010 l � Subm' Origp al Only • • X -11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ".' x �. t, r .o '§''`.,�. 'i +'�"� '� d�5a�'. . �, �.•, ,,..xy. .,u i, «'�°' %. .,e ',,tk �r..r,�^ � +. �F. s� v, ;w �: a' 7. -:« .:.d'��.�`m: � . 4°: �.�:.: ".!k'. " > ; . .. °#"�`�, 8/20/2011i T/I/0=1100/510/200 Temp= Injecting (Brightwater Reservoir Sweep Mod) Prep unit ** Continued on 8 -21 -11 WSR ** , E 8/21/2011': Continued from 08 -20 -2011 T /I /0= 1200/460/75 Temp =Hot ( Brightwater Reservoir` ;Sweep Mod) 'Start pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped xxx gal. EC9360A (Surfactant) Average of xxxx gph for 24 hrs. Pumped a total of xxxx gal. since start of project. Pumped xxxx gal. EC9378A ( Polymer) Average of xxxx gph for 24 hrs. Pumped a total of xxxx gal. since start of project 8/21/2011;T/I/0= 1260/480/220. Temp= 150 °. IA FL. (Pre MIT -IA). IA FL @ 426' (23 bbls). No integral installed on IA. LRS on well at time of departure. 8/21 /20111* *Continued from 08 -20 -2011 WSR ** T /I /0= 1200/460/75 Temp =Hot (Brightwater 'Reservoir Sweep Mod) :Start pumping brightwater chemicals down TBG while on water injection @ 5500 'bwpd. Pumped 146 gal. EC9360A (Surfactant) Average of 24 gph for 6 hrs. Pumped a total of 146 gal. since start of project. Pumped 627 gal. EC9378A ( Polymer) Average of 109 gph for 5.75 hrs. Pumped a total of 627 gal. since start of project ** Continued on 8 -22 -11 WSR ** _ V 8/22/2011, Continued from 08 -21 -2011 T /I /0= 1330/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) =Start pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. !Pumped 537 gal. EC9360A (Surfactant) Average of 22 gph for 24 hrs. Pumped a total of 683 gal. since start of project. :Pumped 2,542 gal. EC9378A ( Polymer) Average of 106 gph for 24 hrs. Pumped a total of 3,169 gal. since start of project {* *Continued on 8 -23 -11 WSR ** 8/23 /2011 =Continued from 08 -22 -2011 T /I /0= 1300/500/200 Temp =Hot ( Brightwater Reservoir Sweep Mod) !Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 596 gal. EC9360A (Surfactant) Average of 24.8 gph for 24 hrs. Pumped a total of 1279 gal. since start of project. Pumped 2563 gal. EC9378A ( Polymer) Average of 106.8 gph for 24 hrs. Pumped a total of 5732 gal. since start of project • • 8/24/2011 Continued from 08 -23 -2011 T /1 /0= 1275/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ :5500 bwpd. ;Pumped 529 gal. EC9360A (Surfactant) Average of 22 gph for 24 hrs. Pumped a ;total of 1808 gal. since start of project. Pumped 2514 gal. EC9378A ( Polymer) Average of 104.75 gph for 24 hrs. Pumped a total of 8246 gal. since start of project 8/25/2011 `.Continued from 08 -23 -2011 T /I /0= 1296/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continued pumping brightwater chemicals down TBG while on water injection @ '5500 bwpd. Pumped 458 gal. EC9360A (Surfactant) Average of 20.8 gph for 22 hrs. Pumped a total of 2266 gal. since start of project. Pumped 2356 gal. EC9378A ( Polymer) Average of 107 gph for 22 hrs. Pumped a total of 10602 gal. since start of project 8/26/2011 Continued from 08 -25 -2011 T /I /0= 1302/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continued pumping brightwater chemicals down TBG while on water injection @ ;5500 bwpd. Pumped 548 gal. EC9360A (Surfactant) Average of 22.8 gph for 24 hrs. Pumped !a total of 2814 gal. since start of project. Pumped 2562 gal. EC9378A ( Polymer) Average of 106.75 gph for 24 hrs. ;Pumped a total of 13164 gal. since start of project 8/27/2011 Continued from 08 -26 -2011 T /I /0= 1302/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continued pumping brightwater chemicals down TBG while on water injection @ ,5500 bwpd. Pumped 506 gal. EC9360A (Surfactant) Average of 21 gph for 24 hrs. Pumped a total of 3320 gal. since start of project. Pumped 2553 gal. EC9378A ( Polymer) Average of 106.4 gph for 24 hrs. Pumped a total of 15717 gal. since start of project 8/27/2011; Continued from 08 -26 -2011 T /I /0= 1302/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 506 gal. EC9360A (Surfactant) Average of 21 gph for 24 hrs. Pumped a ;total of 3296 gal. since start of project. Pumped 2553 gal. EC9378A ( Polymer) Average of 106.4 gph for 24 hrs. Pumped a total of 15717 gal. since start of project 8/28/2011, Continued from 08 -27 -2011 T /I /0= 1322/500/200 Temp =Hot ( Brightwater Reservoir Sweep Mod) !Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. :Pumped 534 gal. EC9360A (Surfactant) Average of 22.25 gph for 24 hrs. Pumped a total of 3830 gal. since start of project. Pumped 2546 gal. EC9378A ( Polymer) Average of 106.1 gph for 24 hrs. Pumped a total of 18263 gal. since start of project III 1 8/29/2011; Continued from 08 -28 -2011 T /I /0= 1299/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) :Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 476 gal. EC9360A (Surfactant) Average of 19.9 gph for 24 hrs. Pumped 'a total of 4330 gal. since start of project. ! Pumped 2495 gal. EC9378A ( Polymer) Average of 104 gph for 24 hrs. Pumped a total of 20758 gal. since start of project 8/30/2011 Continued from 08 -29 -2011 T /I /0= 1321/500/200 Temp =Hot (Brightwater . Reservoir Sweep Mod) `Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. . Pumped 513 gal. EC9360A (Surfactant) Average of 21.375 gph for 24 hrs. Pumped a total of 4843 gal. since start of project. Pumped 2538 gal. EC9378A ( Polymer) Average of 105.75 gph for 24 hrs. i Pumped a total of 23296 gal. since start of project 8/31/2011, Continued from 08 -30 -2011 T /I /0= 1303/500/200 Temp =Hot (Brightwater 1 Reservoir Sweep Mod) ;Continued pumping brightwater chemicals down TBG while on water injection @ `5500 bwpd. Pumped 384 gal. EC9360A (Surfactant) Average of 20.2 gph for 19 hrs. Pumped , a total of 5227 gal. since start of project. Pumped 2013 gal. EC9378A ( Polymer) Average of 105.9 gph for 19 hrs. Pumped a total of 25309 gal. since start of project 9/1/2011 ; Continued from 08 -31 -2011 T /I /0= 1282/500/200 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ 15500 bwpd. Pumped 30 gal. EC9360A (Surfactant) Average of 15 gph for 24 hrs. Pumped a ;total of 5233 gal. since start of project. Pumped 229 gal. EC9378A ( Polymer) Average of 109 gph for 24 hrs. Pumped a ! total of 25538 gal. since start of project 9/2/2011 ,Continued from 09 -01 -2011 T /I /0= 1245/500/100 Temp =Hot (Brightwater Reservoir Sweep Mod) 'Continued pumping brightwater chemicals down TBG while on water injection @ '5500 bwpd. Pumped 544 gal. EC9360A (Surfactant) Average of 22.7 gph for 24 hrs. Pumped a total of 5777 gal. since start of project. Pumped 2532 gal. EC9378A ( Polymer) Average of 105.5 gph for 24 hrs. 1 Pumped a total of 28070 gal. since start of project 9/3 /2011 ;Continued from 09 -02 -2011 T /I /0= 1245/500/100 Temp =Hot (Brightwater • Reservoir Sweep Mod) ' Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 334 gal. EC9360A (Surfactant) Average of 20.9 gph for 16 hrs. Pumped a total of 6135 gal. since start of project. Pumped 1648 gal. EC9378A ( Polymer) Average of 103 gph for 16 hrs. Pumped a total of 29718 gal. since start of project • • 9/4/2011 Continued from 09 -03 -2011 T /I /0= 1155/500/100 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. `Pumped 0 gal. EC9360A (Surfactant) Average of 0 gph for 0 hrs. Pumped a total of 6135 gal. since start of project. Pumped 0 gal. EC9378A ( Polymer) Average of 0 gph for 0 hrs. Pumped a total of 29718 gal. since start of project 9/5/2011 !Continued from 09 -04 -2011 T /I /0= 1200/440/100 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. ;Pumped 472 gal. EC9360A (Surfactant) Average of 21.4 gph for 24 hrs. Pumped s a total of 6607 gal. since start of project. Pumped 2415 gal. EC9378A ( Polymer) Average of 109.8 gph for 24 hrs. Pumped a total of 32133 gal. since start of project 9/6/2011 `Continued from 09 -05 -2011 T /I /0= 1244/500/150 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ :5500 bwpd. Pumped 600 gal. EC9660A (Low Temp Surfactant) Average of 25 gph for 24 hrs. Pumped a total of 7207 gal. since start of project. 'Pumped 2567 gal. EC9378A ( Polymer) Average of 106.95 gph for 24 hrs. Pumped a total of 34700 gal. since start of project 9/7/2011 Continued from 09 -06 -2011 T /I /0= 1244/480/150 Temp =Hot (Brightwater Reservoir Sweep Mod) 'Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 539 gal. EC9660A (Low Temp Surfactant) Average of 22.45 gph for 24 ;hrs. Pumped a total of 7746 gal. since start of project. =Pumped 2414 gal. EC9378A ( Polymer) Average of 104.75 gph for 24 hrs. Pumped a total of 37214 gal. since start of project 9/8 /2011: Continued from 09 -07 -2011 T /I /0= 1250/500/150 Temp =Hot (Brightwater Reservoir Sweep Mod) :Continued pumping brightwater chemicals down TBG while on water injection @ {5500 bwpd. Pumped 605 gal. EC9660A (Low Temp Surfactant) Average of 25.2 gph for 24 hrs. Pumped a total of 8,351 gal. since start of project. Pumped 2,564 gal. EC9378A ( Polymer) Average of 106.83 gph for 24 hrs. Pumped a total of 39,778 gal. since start of project • • 9/9/2011' Continued from 09 -08 -2011 T /I /0= 1244/480/150 Temp =Hot (Brightwater Reservoir Sweep Mod) Continued pumping brightwater chemicals down TBG while on water injection @ 5500 bwpd. Pumped 40 gal. EC9660A (Low Temp Surfactant) Average of 26.66 gph for 1.5 hrs. Pumped a total of 8391 gal. since start of project. Pumped 106 gal. EC9378A ( Polymer) Average of 106 gph for 1 hr. Pumped a .':total of 39884 gal. since start of project 9/10/2011 1050/500/194 Temp =Inj MIT -IA PASSED to 2500 psi (Pre AOGCC) * *No Integral Installed ** Pumped 22 bbls neat meth down IA to load and reach test pressure. MIT -IA passed 1st attempt, lost 21 psi in the 1st 15 min and 7 psi in the '2nd 15 min for a total pressure loss of 28 psi in 30 min. Bled back 5.4 bbls fluid. FWHP's= 1050/494/350. SV =C. WV, SSV, MV =O. IA, OA =OTG. Pad Op notified, ; ;tags hung. 9/12/2011T/I/0= Temp= In] AOGCC MIT -IA PASSED to 2500 psi (Witnessed by B. Noble) Pressured up IA with 4.1 bbls meth. IA lost 40 psi in 1st 15 mins and 30 psi in 2nd 15 mins. Monitored pressures for an additional 15 mins and IA lost 15 psi for a total loss of 85 psi in 45 min test. Bled pressure back. Final WHPs 100/500/350 W \SV= Shut WV,SSV,MI,OA= Open FLUIDS PUMPED GALS 8391 EC9660A (LOW TEMP SURFACTANT) 39884 EC9378A (POLYMER) 48275 TOTAL KB. ELEV =' 74.05' • SAFETY N. WELL REQUIRES A SSSV WHEN ON BF. ELEV = 39.95' X - 1 1 A NECK SET @ TOP OF 2-78" LNR.**** 4 -1/2" GS FISH KOP = 3100' Max Angle= 112 @9718' Datum MD = 9157' ' - Datum TV D = 8800' SS I 2140' H4-1/2" OTIS SSSV NIP, ID = 3.813" 1 • 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 1-1 2662' 1-.. -411 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE L 5 3032 2957 7 OTIS DMY RM 0 09/26/08 4 5113 4944 18 OTIS DMY RM 0 09/26/08 3 7235 6932 18 OTIS DMY RM 0 09/26/08 2 8005 7671 14 OTIS DMY RM 0 09/26/08 1 - 8231 12 - OTIS DMY RM 0 - 09/26/08 Minimum ID = 2.37" @ 8469' I 8340' 1 -- I4 -1/2" OTIS SLD SLV, ID = 3.813" I TOP OF 2-3/8" LINER I I 1 8396' I- 14 -1/2" BAKER SBR SEAL ASSY 1 8415' 9 -5/8" X 4 -1/2" BKR SAB -3 PKR, ID = 3.813" 8459' H4 -1/2" OTIS X NIP, ID = 3.813" I TOP OF 2 -7/8" LNR I--I 8469' I 1 8469' H 3" DEPLOY SLV, ID = ? I ITOP OF 7" LNR H 8491' I 1 I 8490' H4 -1/2" OTIS XN NIP, ID = 3.725" I I4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1-1 8522' , ( 8522' H4-1/2" TBG TAIL, ID = 3.958" 8525' H ELMD TT LOGGED 10/27/99 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9022' PERFORATION SUMMARY REF LOG: MWD GR ON 10/15/99 ANGLE AT TOP PERF: 106 @ 9595' MILLOUT WINDOW (X -11 A) 9183' - 9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 9595 - 9685 0 10/17/99 ITOPOF WHIPSTOCK I-I 9180' ��������� PBTD H 9737' I 1 7" LNR, 29 #, L -80, 0.0371 bpf, ID = 6.184" I—I 9971' 12 -7/8" TBG, 6.16 #, L -80, .0058 bpf, ID = 2.441" I--1 9768' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/30/81 ORIGINAL COMPLETION 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: X -11A 10/17/99 SIS- SIDETRACK COMPLETION PERMIT No: '1990780 03/29/02 RN/TP CORRECTIONS API No: 50- 029 - 20471 -01 12/04/06 RAC/TLH COMMENT BOX CORRECTION SEC 7, T1 ON, R14E, 498' FNL & 588' FEL 01/08/08 ALS /SV CORRECTIONS 10/17/08 SEW /PJC GLV C/O (09/26/08) BP Exploration (Alaska) MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, September 15, 2011 TO: Jim Regg t 7 ! P.I. Supervisor , ` ? i SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC X -11A FROM: Bob Noble PRUDHOE BAY UNIT X -1IA Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 5 1- ' 4-- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT X - 11A API Well Number: 50 029 - 20471 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110912141440 Permit Number: 199 - 078 - Inspection Date: 9/12/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well X-1 1A . Type Inj. W .) TVD I 8147 '' IA 610 2500 2460 2430 , 2415 ' P.T.D 1990780 ' TypeTest SPT Test psi I 2036 - OA 380 500 490 510 - 530 Interval 4YRTST P/F P Tubing 930 940 950 950 950 Notes: OA psi increased. * ' Q4) (') 1 ti ? l) [ i Thursday, September 15, 2011 Page 1 of 1 OPERABLE: X-11A (PTD #1990780} Confirmed no TxIA on MI injection Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] , Sent: Saturday, November 22, 2008 9:35 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Wood, Alecia; NSU, ADW Well Integrity Engineer Subject: OPERABLE: X-11A (PTD #1990780) Confirmed no TxIA on MI injection Hi all, Well X-11A (PTD #1990780} has been confirmed to have no TxIA communication on MI injection. The well has been on MI injection since 10/26108 with stable wellhead pressures. The well has been reclassified as Operable. Please let me knave if you have any questions. Thank you, Anna Dube From: NSU, ADW Well Integrity Engineer Sent: Wednesday, November 19, 2008 10:35 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCS/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Kimmet, Megan; GPB, Gas Lift Engr Subject: UNDER EVALUATION: X-11A (PTD #1990780) Eval for possible TxIA on MI injection Hi all, Well X-11A (PTD #1990780) had high IA pressure noted in 2002 when the well was on MI injection. New dummy GLVs were recently set and a MITIA passed to 4000 psi. The well has been reclassified as Under Evaluation to monitor for IA repressurization while on MI injection. The well has been on Mt injection since 10/26/2008 with stable wellhead pressures. The plan forward for the well is as follows: 1. Operations: Place well on MI injection -DONE 2. Downhole Diagnostics: Monitor IAP A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, ~tnna ~u6e, ~'. E. Wets Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 11 /24!2008 ~ 800ZJb/Z 6 $OOZi6 lJ 6 L $OOZI~'J L 6 80QZ16 WO 4 800ZJtr1Q 4 800U8 416 800Z1~'i6 80Q~J6 W8 KB. ELEV = 74.05' BF. ELEV = 39,95' KOP = 3100' Max Angle= 112 @ 9718` Datum MD = 9157 Datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" SAFETY NOTES: WELL ANGLE > 70° @ 9400'. *** ~ ~ 4-1/FISH NECK SET @ TOP OF 2-718" LNR.* ~7 Minimum ID = 2.37" ~ 8469' TOP OF 2-318" LAVER TOP OF 2-7/8" LNR TOP OF 7" LNR 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-518" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: MWD GR ON 10(15/99 ANGLE AT TOP PERF: 106 @ 9595' Note: Refer to Praduction DB far historical perf data SIZE SPF INTERVAL Opn(Sgz DATE 2" 4 9595 - 9685 O 10!17199 TOP OF WHIPSTOCK 9180® 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1 PBTD I 2-718" TBG, 6.16#, L-80, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 01130P81 ORIGINAL COMPLETIQN 10117/99 SiS- SIDEfRACKCOMPLETI4N 03129102 RN/TP CORRECTIONS 12(04f06 RAC/TLH COMMENT BOX CORRECTION PRUDHOE BAY UNIT WELL: X-11A PERMIT No: 1990780 API Na: 50-029-20471-01 SEC 7, T10N, R14E, 498' FNL & 588` FEL BP Exploration (Alaska] 2140' F-I4-112" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3032 2957 7 OTIS DMY RM fl 09!26/08 4 5113 4944 18 OTIS DMY RM 0 09126(08 3 7235 6932 18 OTIS DMY RM 0 09/26/08 2 8005 7671 14 OTIS DMY RM 0 09!26108 1 8231 7893 12 OTIS DMY RM 0 09/26108 4-1d2" OTIS SLD SLV, ID = 3.813" $398' ~4-1/2"BAKERSBRSEALASSY' $415' 9-518" X 4-1/2" BKR SAB-3 PKR, ID = 3.813" $459' 4-112" OTIS X NIP, ID = 3.813" $489' 3" DEPLOY SLV, ID = ? 8490' 4-1;2" OTIS XN NIP, ID = 3.725" $522' F-~4-1?2" TBG TAIL, ID = 3.958" $525' ELMD TT LOGG® 10127!99 MILLOUT WINDOW (X-11A) 9183' - 9190° STATE OF ALASKA ALASKA ~ND GAS CONSERVATION COMMISSION. Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us ,-~ l ~ ( i OPERATOR: BP Exploration (Alaska), Inc. i<~~c i7 FIELD /UNIT (PAD: Prudhoe Bay I PBU / X pad ( f DATE: 09115!07 OPERATOR REP: Andrea Hughes AOGCC REP: ly9"o~3 Packer Depi Pretest Initial 15 Min. 30 Min. Well X-11A Type Inj. W TVD /8147 Tubing 320 220 220 220 Interval 4 P.T.D: 1990780 Type test P' Test psi t'2037 Casing 400 2280 2170 2130 P/F P Notes: MIT-IA for UIC compliance. Plant decreased rate OA 50 100 100 100 during the start of the test. 45 minute pressures: 220 1 2120 / 100. Well Type Inj. TVD Tubing Interval P.T.D. Type test lest psi Casing P/F Notes: OA Weli Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: oA Well Type Inj. TW Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1105 MIT PBU X-11A 09-15-07.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~S~;:~isor ~fr 9(5(07 DATE: Wednesday, September 05, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC X-II A PRUDHOE BAY UNIT X-IIA FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:ïÞ..e.- Corom NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT X-IIA API Well Number: 50-029-20471-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ070904202933 Permit Number: 199-078-0 Inspection Date: 9/3/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well X-IIA Type Inj. w TVD 8147 / IA 240 2350 2340 2380 2430 P.T. I'J',IU/~O TypeTest SPT Test psi 2036.75 OA 200 300 330 350 360 Interval 4YRTST P/F I ,/ Tubing 200 220 240 240 240 Notes: Tubing spoollockdown leaking, shut down injection & repaired leak. Injection resumed but well needs time to stabilize pressure and temperature. SCANNED SEP 1 0 2007 Wednesday, September 05,2007 Page I of I X-1 IA (PTD #1990780) Passing MITIA Subject: X-1 lA (PTD #1990780) Passing MITIA Date: Fri, 19 Sep 2003 14:46:19 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> Hi Bob, Please see the attached MITIA form for your records on X-11A. If you have any questions, please don't hesisitate to call. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 <<MIT PBU X-11 09-18-03.xls>> [->IMIT PBU X-11 09-18-03.xlsi Type: Microsoft Excel Worksheet (application/vnd.ms-excel) 1 Encod~n,' base64 9/19/2003 12:38 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@adrnin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jirn_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / X 09/18/03 Jim Moore Packer Depth Pretest Initial 15 Min. 30 Min. vv~,l×-~^ I~,ni.I ~ TV~ [ ~'~4~' ~,,~,,~l °1 ~°°1 ~ol ~ool ,~t~I ~ P.T.D.11990780 Type test P Test psi 2036.75 CasingI 1,800 4,0001 3,8201 3,7601 P/FI P Notes: WellI Ini. TVD P'T'D'I [Type test Test P/FI Notes: w~,,I Type Inj.I TVD Tubin~l Type tesli Test P/FI Notes: WellI Type Injt TVD I Tubingl Type tesl~ Test psiI P/FI Notes: TVD P.T.D. Test P/FI Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0918_MIT_PBU_X-11 .xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ FCO / MUD ACID Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 498' FNL, 588' FEL, Sec. 07, T10N, R14E, UM At top of productive interval 2305' FNL, 338' FEL, Sec. 07, T10N, R14E, UM At effective depth 2697' FNL, 425' FEL, Sec. 07, T10N, R14E, UM At total depth 2721' FNL, 409' FEL, Sec. 07, T10N, R14E, UM 5. Type of Well: Development __ Explorato~ Strat~graphic__ Service~X (asp's 665308, 5939619) (asp's 665604, 5937818) (asp's 665528, 5937424) (asp's 665544, 5937400) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-11A 9. Permitnumber/approvalnumber 199-078 10. APInumber 50-029-20471-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical 9768 feet Plugs (measured) 8972 feet Tagged TD @ 9661' (11/24/2002) Effective depth: measured true vertical 9737 feet Junk (measured) 8983 feet Casing Length Conductor 110' Surface 2628' Intermediate 8988' Liner 691' 1199' Size Cemented Measured Depth True Vertical Depth 20" 8.6 cu yds Concrete 144' 144' 13-3/8" 3813 c.f. Permafrost II 2662' 2662' 9-5/8" 1254 c.f. Class 'G', 130 9022' 8741' c.f. Permafrost 7" 491 c.f. Class 'G' 8491' - 9183' 8221' - 8899' 2-7/8" 62 c.f. Class 'G' 8469'- 9768' 8199' - 8972' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 9595'-9685' RECEIVED true vertical Open Perfs 9034'-9003' DEC 1 9 2002 L/~,ka 0il & Ga~. Cons. Commission 4-1/2", 12.6#, L-80, TBG @ 8415' MD; 4-1/2", 12.6#, '_~T,--~ue~ng~-11~l~.~?.2' MD. 9-5/8" x 4-1/2" Baker 'SAB-3' Packer @ 8415'. 4-1/2" Otis SSSV Nipple @ 2140' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/29/2002 Subsequent to operation 12/10/2002 OiI-Bbl Representative Daily Averaoe Production or Iniection Data Gas-Mcf Water-Bbl 0 329 Casing Pressure Tubing Pressure 0 1336 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas _ Suspended _ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~.~J~ Title: Technical Assistant Date December 11, 2002 Prepared b~/DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT tN DUPLICATE 10/29/2002 10/29/2OO2 11/19/2002 11/21/2002 11/21/2002 11/22/2002 11/22/2002 11/23/2002 11/24/2002 11/25/2002 TESTEVENT FILL CLEAN FILL CLEAN FILL CLEAN FILL CLEAN FILL CLEAN PLUG FILL CLEAN FILL CLEAN PLUG FILL CLEAN PLUG TESTEVENT X-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS --- INJECTION PRESSURE, PSI: 0 TYPE: PW, VOL: 0 BPD. OUT: DRIFT/TAG OUT: AC-EVAL; AC-FLUID LEVEL OUT: AC-BLEED O UT: AC- M ITIA OUT: ACID TREATMENT; FILL CLEAN OUT; HYDRATE / ICE OUT: GAS LIFT--TO DUMMY VALVES; SSSV C/O OR STROKE OUT: ACID TREATMENT; FILL CLEAN OUT; HYDRATE / ICE OUT: ACID TREATMENT; FILL CLEAN OUT; HYDRATE / ICE --- Inj Press, psi: 1,404 Type: PW Vol: 318 10/29/02 10/29/02 11/19/O2 11/21/02 11/22/02 11/22/02 EVENT SUMMARY TESTEVENT --- INJECTION PRESSURE, PSI: 0, TYPE: PW VOL: 0 BPD. DRIFTED TBG W/2.70." CENT,SAMPLE BAILER TAGGED ICE PLUG @ 1528' WLM,. NOTIFIED DSO WELL LEFT SHUT IN. TIO= SI 400/800/0 IA FL @ 160' (9 bbls). T/I/O=460/840/0 PREP FOR PRE ACID MITIA. IA FL WAS AT 160' (8.6 BBLS). BLED IA FROM 840 PSI TO 560 PSI IN 5 HOURS. IA FL WAS AT 240' (13 BBLS) POST BLEED. T/I/O = SI/650/0. MIT - IA TO 3000 PSI PASSED. (PRE ACID STIM). IA FL @ 1000' (53 bbls). PRESSURED IA TO 3000 PSI WITH 51 BBLS OF METHANOL. STARTED 30 MINUTE TEST. IA LOST 200 PSI IN 15 MINUTES. RE-PRESSURED IA TO 3000 PSI. IA LOST 60 PSI IN 15 MINUTES AND A TOTAL OF 80 PSI IN 30 MINUTES. BLED IA TO 650 PSI. FINAL WHP's - SI/650/0. RIH W/3" DJ NOZZLE, JETTING FROM SURFACE W/HEATED 2% KCL. SWITCH TO NEAT METH AT 1650' AND CONTINUE JETTING TO SSSV. POH, STAND BACK FOR S/L TO PULL VALVE. RIG UP NEXT TO COIL UNIT. PULL MCX SERIAL # M-47B ON 4 1/2" LOCK. MCX FULL OF ICE & PLASTIC COATING. RDMO. CTU TO RIG BACK UP ON WELL. WELL LEFT SHUT IN. Page I X-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/23/02 RIH W/3" DJ NOZZLE. JET FROM 2100' TO 4000' W METH/WTR. POOH, CHANGE TO JS NOZZLE, RIH JETTING TUBING TO LINER TOP. FLAG COIL. JET OUT @ 80%. CHANGE TO 1.75" JSN AND BHA. RIH. TAG AT 26'. COULD NOT GET PAST. POH, PU SECOND STINGER, STRAIGHTEN PIPE. RIH. TAGGING AT SAME SPOT IN TREE. POH, DROP 2ND STINGER. REBEND PIPE. SAME TAG. POH. REBEND S. RIH W/1 STINGER AND 1.75" JSN. NO PROBLEM @ TREE. <<< NOTE: COIL TAGGED EVERY RUN (SEVERAL DIFFERENT BHA'S) AT THE TUBING HANGER. >>> 11/24/02 JET LINER FROM 8469' TO TAG @ 9661' (UP). JET ON FILL, NO HOLE MADE. PUMP FLOPRO PILL, CHASE UP/CIRC BOTTOMS UP. PERFORM PRE INJECTIVITY TEST DOWN CT/BACKSIDE W/NON-SLICK 2%. PERFORM ACID TREATMENT. JET ON FILL WITH 6 BBLS HCL, NO PROGRESS. JET STAGE 1: 25 BBL 3% NH4CL, STAGE 2:100 BBL 7.5% HCL, STAGE 3:50 BBL 9-1% HCL-HF, STAGE 4:150 BBL 3% NH4CL ACROSS PERFS FROM 9560' TO 9661'. POH. PERFORM INJECTIVITY TEST AS FOLLOWS: 0.5 BPM @ 140 PSI, 0.75 BPM @ 360 PSI, 1.0 BPM @ 600 PSI, 1.5 BPM @ 600 PSI, 2 BPM @ 1117 PSI, 3 BPM @ 1362 PSI, 4 BPM @ 1510 PSI, 5 BPM @ 1575 PSI, 5.5 BPM @ 1550 PSI. FREEZE PROTECT WELL WITH 60/40 MEOH. RU N2. BLOWN DOWN REEL FOR PIPE SWAP. RDMO <<< NOTIFY PAD OPERATOR OF CONDITION AND WELL IS READY TO BOL. >>> 12/10/02 TESTEVENT--- IN]ECTION PRESSURE, PSI: 1,336 TYPE: PW VOLUME: 329 BWPD. Fluids Pumped BBLS 5 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 4 TEST) 234 NEAT METHANOL 280 METHANOL WATER 402 2% KCL WATER 640 2% KCL WATER, EXTRA SLICK 19 FLOPRO --- 140,000 LSRV 183 3% NH4CL 99 7.5% HCL: TITRATION IS 7.8%, IRON < 50 PPM 50 9/1 HCL-HF: TITRATION IS 9°/o/1.2%, IRON < 50 PPM 1912 TOTAL Page 2 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990780 Well Name/No. PRUDHOE BAY UNIT X-I lA Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20471~01-00 /7 MD 9768 TVD 8972 Completion Date 10/17/1999 Completion Status WAGIN Current Status WAGIN UIC Y 221-~ --~-~ ~-] ~ ...... ~7__~___.~' .-~ 5_ ~"~ ]'--__-~ ~- " ~7_--~7_~-'__-~2~2. -- i- ~ ~"-~--- ............................................. L~-_£__--'~ ~_'2_£~_~7~-~_~i~ ............ 22__' REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- ......................................................................................... -'- ~."'~-~_--.' 2-E~L~'£ ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments D ~ IL FINAL 9060 9762 OH 10/19/1999 ~ INJP-SPIN/TEM 5 FINAL 9000 9670 CH 12/8/1999 PRES 11/28/99 '"'~" NGP-'TVD 25 FINAL 8822 8898 OH 5/4/2000 ~'~[~' NGP-MD 25 FINAL 9180 9768 OH 5/4/2000 Well Cores/Samples Information: O 10/19/1999 09058 9060-9762 O 5/2/2000 09526 9157-9735 Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/'~} .C~~ved? Y / N A,~j~ ~s..i~.~d?._.W7~7 ...... Daily History Received? ~)/N Formation Tops Receuived? ~ N Comments: Compliance Reviewed By: :~ ........ Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' FROM: Julie Heusser, ~ Commissioner Tom Maunder, P. I. SUpervisor Jeff JOneS; Petroleum Inspector DATE: SUBJECT: December 9, 2000 Safety Valve Tests Prudhoe Bay Field BPX / X-Pad Saturday~ December 97 2000: I traveled to BPX's X Pad in the Prudhoe Bay Field to witness-Safety Valve System tests. Merv Liddelow, BPX representative in charge of the testing, performed the tests in a safe and proficient manner. Of the 26 wells tested, 3 fa[lures were witnessed. Well X-14A's SSV failed to close and well X, 19B's pilot was frozen and the SSV failed to close. Mr. Liddelow indicated to me on 12/10/00 that these items have been corrected and successfully re-tested. The AOGCC test reports are attached for reference. I conducted 26 well hOuse inspections concurrent with the SVS tests. A slight crude oil leak was noted on a wellhead flange of well X-19B. Mr. Liddelow indicated he would have this item addressed. No other exceptions were noted. SUMMARY: I witnessed SVS tests and conducted well house inspections on BPX's X Pad. 26 wells, 53 components tested, 3 failures. 26 well houses inspected. Attachments: SVS PBU X Pad 12-9-00 JJ NON-CONFIDENTIAL SVS PBU X Pad 12-9-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/X Pad Separator psi: LPS 174 Date: 12/9/00 HPS 723 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI T~p Code Code Code Passed CAS or CYCLE X-01 1790540 174 125 125 P P OIL X-02 1790690 174 125! 125 P P OIL X-03A 1980860 723 550 400 P P OIL X-04 1790890 174 125 125 P P OIL X-05 1791040 174 125 115 P P OIL X-06 1800090 X-07 1800130' 174 125 110 P P OIL X-08 1800360 174 125 115 P P OIL X-09 1800280 X-10 1800430 174 125 120 -P P OIL X~ 1 lA 1990780 2000 1950 p p P WAG X-12 1800440 174 125 110 P P OIL X-13A 1930650 174 125 100 P P OIL ×-14A 1921430 174 125 120 P 5 OIL X-15 1800740 174 125 125 P P OIL I iX-16 1811720 174 125 125 p p OIL X-17 1811690 723 55.6' 520 ' P P OIL X-18 1811620~ 174 125 120 P P OIL X-19B 1961300 174 125 0 2 5 OIL X-20 1940670 X-21A 1991080 174! 125 110 P P OiLI X-22 1931300 174 125 1-10 P P OIL X-23 1840610 ,, X-24A 1991250 X-~5 1840340 174 125 '120! P' 'P OIL X-26 1840300 X-27 1840690 174 125 120 P P OIL 1X-28 1931140 X-29 1951390 .I X-30 1950410 174 125~ 115 P P OIL X-31 1931980! 174 125 120 P P OIL X-32 1931620 1741 125 125 P P OIL X-34 1931720 174 125 115 P P OIL X-35 1931990 174 125 90 P P OIL Page 1 of 2 SVS PBU X Pad 12-9-00 JJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLr. i X-36 1961'670 Wells: 26 Components: 53 Failures: 3 Failure Rate: 5.6% Remarks: 12/13/00 Page 2 of 2 SVS PBU X Pad 12-9-00 JJ.xls To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' 7q q-oT' . X-1 lA, AK-MW-90166 May 04, 2000 X-11A: 2" x 5" MD Cramma Ray Logs' 50-029-20471-01 2" x 5" TVD Gamma Ray Logs' 50-029-20471-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Tan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED rote: MAY 04 2000 Alaska Oil & Gas COns. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company ORI LI_I IM [~ c; IE R~/I C E c:; WELL LOG TRANSMITTAL To: State of Alaska May 2, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs X- 1 lA, AK-MM-90166 1 LDWG formatted Disc with verification listing. API~: 50-029-2047 l-01 PLEASE ACKNOWLEDGE RECEIFF BY SIGNINGAND RETURNtNGA COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silveraclo Way, Suite G. Anchorage, Alaska 99518 Date:}~ti/[¥ 02--. ~[000 Alaska 0il 8, Cas Cons. C0mmiasi0n Anchorage BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company GeoQuest 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATt'N: Sherrie NO. 12996 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 12/7/99 Well Job # Log Description Date Blueline Sepia Color CD Prints B-36 PROD PROFILE/DEFT/GHOST 991125 1 i X-11A blt C_.- INJECTION PROFILE 991128 1 1 F-21 99433 CNTD t~ ~ot 991110 1 ! 1 F-29 99432 CNTD 1::~. ~'~ ~ © '-~' 991107 1 I 1 F-38 99435 CNTD ~ (--~c~(L)"2__ 991112 1 1 1 J-13 99437 CNTD ~ C:[~O~ 991020 1 1 1 J-17A 99438 MCNL ~ C~':~-'~'~ 991024 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotectnical Data Center MB3-3 3940 Arctic BIvd, Suite 300 900 E, Benson BlVd.Anchorage, Alaska 99519-6612I ~1,=. U11~--" M I,-~ I~'~ ~11~,i~% ~ ~ % ~ ~n Al-rN:Anch°rage'AKsherrie 99..~50_3-57 ] 1 /z ~T' ~., .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector !2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-078 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20471-01 4. Location of well at surface ~ 9. Unit or Lease Name ~ ,~..:~:ii: :-',':ii'i' .::~'. 'i Prudhoe Bay Unit 498' SNL, 588' WEL, SEC. 07, T10N, R14E, UM~.~.. / ~ i[ ~ At top of productive interval ~ z/~..~.~,~. ~=~~~ 10. Well Number 2305' SNL, 338' WEL, SEC. 07, T10N, R14E, UM X-11Ai ~i ...... i" 11. Field and At total depth Pool 2721' SNL, 401' WEL, SEC. 07, T10N, R14E, UM ............. .,~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 74.05' AMSLI ADL 028313 12. Date Spudded10/13/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband115' water depth' if °fIsh°re 16' N°' °f c°mpleti°nsl 0/15/99 10/17/99 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey I0. Depth where SSSV set 121 · Thickness of Permafrost 9768 8972 FTI 9737 8983 FTI [~Yes [] No (Nipple) 2140' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, Memory GR Induction 23. CASING~ LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP DO'I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X30" Insulated Conductor Surface 110' 36" 18.6 cu yds Concrete 13-3/8" 72# L-80 Surface 2662' 17-1/2" 3813 cu ft Permafrost II 9-5/8" 47# L-80 Surface 9022' 12-1/4" 1254 cu ft Class 'G', 130 cuft Permafrost 7" 29# L-80 8491' 9183' 8-1/2" 491 cuft Class 'G' 2-7/8" 6.16# L-80 8469' 9768' 3-3/4" 82 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8522' 8415' MD TVD MD TVD 9595'- 9685' 9034' - 9003' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 21 Bbls MeOH 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) November 2, 1999I Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE !OIL-BBL GAS-MCF WATER-BBL O~b GRAVITY-APl (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL . : · i Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers :30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Shublik 'A' 9180' 8896' Shublik 'B' 9207' 8923' Shublik 'C' 9230' 8944' Sadlerochit / Zone 4B 9265' 8974' HOT 9386' 9049' Sadlerochit / Zone 4B 9736' 8984' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing istrue and correct to the best of myknowledgesigned ~'""'~_ ~,,~ I I/(~'/~ Terrie Nubble J , v Title Technical Assistant III Date X-11Ai 99-078 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: X-1 lA Accept: 10/11/99 Field: Prudhoe Bay Spud: 10/13/99 APl' 50-029-20471-01 Re lease: 10/17/99 Permit: 99-078 CTD Unit: Nordic #1 .......................................... ......... i :: .. ......... 10/11/99 1 Move DS/N #1 from E to X Pad. Raise derrick, windwalls. Move rig over tree. Swap CT reels. Haul gravel and level back end of rig. Pull CT to rig floor and stab into injector. NU BOP. Clear floor, prep to test BOP. Accept rig at 02:00 10/11/99 10/12/99 2 Begin initial BOPE test and choke manifold leaked. Tear down manifold to remove debris. Replace choke line (leak). Downtime 0700-1600 hrs. Install new packoff, CTC. Pull test connector. Fill CT w/seawater and pump dart. Pressure test CT connector. PU Cement BHA, TIH. Pump down backside to liquid pack well. Pump 31 bbl. Cement (5 bbl, 20 bbl w/18 ppb aggregate, 6 bbl neat). No squeeze pressure after 20 bbl cement out nozzle. Pull uphole while laying in cement at 1:1. WOC at safety 10/13/99 3 9186' WOC. Test cement plug at 500 psi for 5 min and lost 50 psi. POOH. LD cementing BHA. MU milling BHA. RIH with milling BHA #1 (3.80" dimple mill/motor). Mill XN. RIH to whipstock at 9180' finding no cement. Attempt to PT to 1500 psi and broke at 650 psi. Mill window in Sag perf interval while discuss with AOGCC to determin .e~another plug is necessary. Full returns, no more cement required. Mill window w/Dimple mill to 9191 '. POOH, LD Window Milling BHA, PU Cement BHA, TIH. Tagged @ 9184'. Held PJSM:rPumped 5 bbls 13.8 ppg (8% gel) cmt, 11 bbls 13.8 ppg slurry w/18#/bbls aggregate & 5 bbls 13.8 ppg cmt. Displaced to end of coil. Spotted cmt f/9180-8614'. POH to 8300'. Took 1.5 bbls to get 500 psi sqz. Held for 15 min. Bled off and cleaned out cmt to 9184'. POH while pumping. Jetted stack. PU & RIH w/ formation mill & string mill. Tagged @ 9180.9'. Milled f/9180.9-86'. Milling @ 9186'. 10/14/99 4 9400' Milled f/9186-9198. Tripped for drlg assy. Drilled to 9358'. Lost returns. PU to window. RIH. Drilled to 9400' w/50% returns. POH to PU cmt'g assy. LD drlg assy. PU Cmt'g assy. RIH. Circulate to check losses. Circ @ 2 bpm losing 0.8 bpm. Prepare to pump 13.8 ppg gel cement. 10/15/99 5 9454' Spotted 24 bbls gel cmt @ 13.8 ppg (3 bbls neat, 18 bbls w/20#/bbl aggregate, 3 bbls neat). Ramped up sqz pressure to 450 psi. Washed dn to 9170' (10' above ws) began losing 0.2 bpm. POH. LD cmt stinger. PU drilling BHA ( (2.5° motor & used PDC bit). RIH. Washed cmt to 9358' (fault area). Worked through fault area & washed to 9400'. POH. LD Clean out assy (2.5° motor assy). MU 3.3° angle build assy. RIH. Drilled f/9400-9454'. Could not orient TF to left side. POH to change to less aggressive bend motor. Changed bend to 2.29° f/3.3 °. RIH w/drlg assy X-1 lA, Coil Tubing Drilling Page 2 10/16/99 6 9768' RIH. Drilled f/9454-9768', GR log for correlation at window. POOH. MU and RIH w/PDS memory Induction Logging Tools. Logged f/9768-9080'. POH w/PDS memory Induction Tools. LD logging tools. Held safety meeting. MU & RIH wi 2-7/8" STL liner assy (1308.12'). Held kick drill while PU liner. Tagged btm @ 9768'. Broke circulation. Launched 5/8" ball. Sheared @ 3900 psi. Released from liner. 10/17/99 7 9768' Displace FIo-Pro from well w/2% KCI. Pump 11 bbl cement, drop dart and displace to Liner Wiper Plug. LWP sheared at 3300 psi, displace to Latch Collar. Bump LWP w/2500 psi. Bleed pressure, check floats--held OK. Pressure to 400 psi, pull out of liner. Wash top of liner and POOH. LD liner running tool. PU 46 jts 1-1/4" CSH. RIH to LC @ 9737'. Filled liner w/150 LSRV FIo-Pro. POH to 2100'. Tested liner to 2200 psi. POH. Stood back 1-1/4" CSH. PU SWS perf gun assy. RIH w/perf gun assy on 1-1/4" CSH. Tagged LC @ 9737'. PU & spaced out 2" perf guns. Dropped ball. Fired guns w/3150 psi. Monitored well. No fluid loss. POH wi perf guns. LD 1-1/4" CSH. LD perf guns. Perforated 9595-9686' w/2" PJ guns @ 4spf 60 deg phasing 10/18/99 8 9768' RIH to 2000' & freeze protect tbg. Purge CT w/N2. Unstab CT, pull gooseneck, set back injector. ND BOP. Release Rig 10/17/99 10:00 hrs. Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA X Pad, Slot X-11 X-11A Job No. AKMW90166, Surveyed: 15 October, 1999 SURVEY REPORT 20 October, 1999 Your Reft 500292047101 Surface Coordinates: 593618.74 N, 665308.58 E (55° 37' 22.4370" N, 149° 12' 00.5249" W) Kelly Bushing: 74.05ft above Mean Sea Level D R,I L L,! N I~ $ E RV I r" E, 5 A HALLIBtJRT~N COM]PANY Survey Ref: svy9410 Sperry-Sun Drilling Services Survey Report for X- 1 lA Your Ref: 500292047101 Job No. AKMW90166, Surveyed: 15 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9100.00 10.470 207.195 8743.68 8817.73 9180.00 10.190 210.220 8822.38 8896.43 9212.87 18.720 210.060 8854.18 8928.23 9233.17 26.810 210.030 8872.89 8946.94 9262.34 36.470 210.010 8897.69 8971.74 9290.21 44.820 210.000 8918.82 8992.87 9312.13 49.480 209.990 8933.72 9007.77 9347.91 54.320 209.980 8955.79 9029.84 9374.76 59.900 209.970 8970.37 9044.42 9400.26 69.350 209.750 8981.28 9055.33 9428.68 81.470 209.580 8988.43 9062.48 9456.94 92.900 211.860 8989.82 9063.87 9483.89 100.020 205.710 8986.78 9060.83 9509.44 104.760 200.790 8981.30 9055.35 9541.14 104.330 196.570 8973.33 9047.38 9576.71 104.150 183.560 8964.55 9038.60 9602.81 107.400 174.120 8957.44 9031.49 9633.37 111.360 171.080 8947.30 9021.35 9662.24 110.920 162.110 8936.87 9010.92 9695.39 111.710 154.730 8924.80 8998.85 9718.17 111.800 147.700 8916.35 8990.40 9768.00 111.800 147.700 8897.85 8971.90 Alaska State Plane Zone 4 PBU_WOA X Pad Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (fi) (fi) (fi) (fi) (°/100ft) 1766.23 S 273.16 E 591855.78 N 665602,07 E 1778.81S 266.28 E 591843.12 N 665595.33 E 0.763 1785.90 S 262.16 E 591835.98 N 665591,30 E 25.951 1792.69 S 258.23 E 591829.14 N 665587.45 E 39.852 1805.92 S 250.59 E 591815.82 N 665579.96 E 33.116 1821.63 S 241.52 E 591800.01N 665571.07 E 29.961 1835.55 S 233.48 E 591786.01 N 665563.20 E 21.259 1859.93 S 219.42 E 591761.46 N 665549.41E 13.527 1879.45 S 208.16 E 591741.81 N 665538.38 E 20.782 1899,41 S 196.70 E 591721,72 N 665527.15 E 37.067 1923.26 S 183.11E 591697.71N 665513.84 E 42.650 1947.49 S 168.72 E 591673.33 N 665499.73 E 41.238 1970.92 S 155.83 E 591649.74 N 665487.11 E 34.806 1993.83 S 145.98 E 591626.72 N 665477.52 E 26,413 2022.89 S 136.15 E 591597.55 N 665468.03 E 12.957 2056.76 S 130.14 E 591563.62 N 665462.41 E 35.451 2081.84 S 130.63 E 591538.55 N 665463.19 E 36.959 2110.42 S 134,34 E 591510.01N 665467.22 E 15.998 2136.57 S 140.57 E 591483.93 N 665473.76 E 29.015 2165.27 S 151.92 E 591455.37 N 665485.43 E 20.874 2183.80 S 162.10 E 591436.96 N 665495.83 E 28.663 2222.90 S 186.82 E 591398.14 N 665521.00 E 0.000 Vertical Section (ft) Comment 1782.90 1794,86 1801,58 1808.02 1820.57 1835.46 1848.65 1871.77 1890.28 1909.21 1931.84 1954.77 1977.05 1999.05 2027,19 2060.43 2085.46 2114.25 2140.84 2170.39 2189.70 2230.74 Tie On Survey Window Point Projection Cont/nued... 20 October, 1999 - 16:18 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for X- 1 lA Your Ref: 500292047101 Job No. AKMW90166, Surveyed: 15 October, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA X Pad All data is in feet 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. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 175.196° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9768.00ft., The Bottom Hole Displacement is 2230.74ft., in the Direction of 175.196° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9100.00 8817.73 1766.23 S 273.16 E Tie On Survey 9180.00 8896.43 1778.81 S 266.28 E Window Point 9768.00 8971.90 2222.90 S 186.82 E Projection 20 October, 1999 - 16:18 - 3 - DrillQuest 8720 · +- 8760 %,._ 8800 -4-- ¢-~ 8840 · -- _f] 8880 >. 8920 8960 I V 9000 B.P. Exploration (True) Structure : Pad X Field : Prudhoe Bay Well : X-11AI, 50-029-20471-01 Location : North Slope, Alaska Brij Potnis 267-661.5 Date plotted: 22-Oc~-lggg Plat Reference is X-11AI. Coardinotea are in feet reference X-11. True VerUcal Oepthe are reference RKB - MSL = 74.1 ft. --- Baker Hughes INTEQ --- East (feet) -> 0 40 80 120 160 200 240 280 320 360 400 I I I I I I I I I I I I I Point ' 4~0 Tie-in Point : .-, .. , Projected to TD i 0 40 Projected to TO i i i I i i i i i i i i i i i i i 80 120 160 200 240 280 .320 ,360 400 440 480 520 560 600 640 Vertical Section (feet) -> Azimuth 175.26 with reference 1766.20 S, 275.52 E from X-11 X-11AJ Cozeg01 Pt~n I 1720 1760 1800 1840 1880 1920 1960 2OOO 2040 2080 2120 2160 22OO 2240 B.P. Exploration (True) Pad X X-11AI X-II Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : X-11AI Our ref : svy236 License : 50-029-20471-01 Date printed : 22-0ct-1999 Date created : 22-0ct-1999 Last revised : 22-Oct-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665883.554,5940129.199,999.00000,N Slot location is n70 14 28.703,w148 39 53.668 Slot Grid coordinates are N 5939618.000, E 665309.001 Slot local coordinates are 498.47 S 585.70 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad X,X-11AI Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth SURVEY LISTING Page 1 Your ref : X-11AI Last revised : 22-Oct-1999 R E C T A N G U L A R Dogleg Vert G R I D C O O R D S C O 0 R D I N A T E S Deg/100ft Sect Easting Northing' 9100.00 10.47 207.19 8743.63 1766.20S 273.32E 0.72 0.00 665621.10 5937858.36 9180.00 10.19 210.22 8822.33 1778.78S 266.44E 0.76 11.97 665614.50 5937845.63 9212.87 18.72 210.06 8854.13 1785.87S 262.33E 25.95 18.70 665610.54 5937838.46 9233.17 26.81 210.03 8872.84 1792.67S 258.40E 39.85 25.14 665606.76 5937831.58 9262.34 36.47 210.01 8897.64 1805.90S 250.75E 33.12 37.70 665599.41 5937818.18 9290.21 44.82 210.00 8918.77 1821.61S 241.68E 29.96 52.60 665590.69 5937802.28 9312.13 49.48 209.99 8933.67 1835.52S 233.65E 21.26 65.80 665582.97 5937788.19 9347.91 54.32 209.98 8955.74 1859.90S 219.58E 13.53 88.94 665569.44 5937763.51 9374.76 59.90 209.97 8970.32 1879.42S 208.32E 20.78 107.47 665558.61 5937743.74 9400.26 69.35 209.75 8981.23 1899.38S 196.86E 37.07 126.41 665547.60 5937723.54 9428.68 81.47 209.58 8988.38 1923.24S 183.28E 42.65 149.06 665534.54 5937699.39 9456.94 92.90 211.86 8989.77 1947.46S 168.88E 41.24 172.01 665520.68 5937674.86 9483.89 100.02 205.71 8986.73 1970.90S 155.99E 34.81 194.30 665508.31 5937651.15 9509.44 104.76 200.79 8981.25 1993.81S 146.14E 26.41 216.32 665498.97 5937628.03 9541.14 104.33 196.57 8973.28 2022.87S 136.31E 12.96 244.47 665489.79 5937598.76 9576.71 104.15 183.56 8964.50 2056.73S 130.31E 35.45 277.72 665484.52 5937564.77 9602.81 107.40 174.12 8957.39 2081.81S 130.80E 36.96 302.75 665485.57 5937539.71 9633.37 111.36 171.08 8947.25 2110.39S 134.50E 16.00 331.54 665489.90 5937511.22 9662.24 110.92 162.11 8936.82 2136.55S 140.74E 29.02 358.13 665496.71 5937485.21 9695.39 111.71 154.73 8924.75 2165.24S 152.08E 20.87 387.66 665508.68 5937456.78 9718.17 111.80 147.70 8916.30 2183.77S 162.26E 28.66 406.97 665519.26 5937438.48 9768.00 111.80 147.70 8897.80 2222.88S 186.98E 0.00 447.98 665544.84 5937399.93 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from X-11 and SSTVD from RKB - MSL = 74.1 ft. Bottom hole distance is 2230.73 on azimuth 175.19 degrees from wellhead. Vertical section is from tie at S 1766.20 E 273.32 on azimuth 175.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad X,X-llAI Prudhoe Bay,North Slope, Alaska MD SSTVD 9100.00 8743.63 9768.00 8897.80 Comments in wellpath Rectangular Coords. Comment 1766.20S 273.32E Tie-in Point 2222.88S 186.98E Projected to TD SURVEY LISTING Page 2 Your ref : X-llAI Last revised : 22-0ct-1999 NO Targets associated with this wellpath WELL LOG TRANSMITTAL. - ~Active Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technical Oata Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT(S] X-1 1 ai / o - / ~- -~ Open Hole I I 1 Res. Eval. CH I I 1 _.-- 'RF_C NED Signed · Print Name: Date' 'L%~- 1 9 ~999 .~a~a Oil & Gas Cans. ~mi~$on ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone: (907)659-2307 Fax: (907)659-2314 E-mail: pdspruclhoe@NA800.net Website: www.memorylog.com C:WIy Documents\Excel_Word_Documents\Distribution_Forms\Bp_pb_form.doc TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 12. 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit X-11Ai BP Exploration (Alaska) Inc. Permit No: 99-78 Sur Loc: 498'SNL. 588~/EL. Sec. 07. T10N, R14E. UM Btmhole Loc. 2710'SNL. 290"WEL. Sec. 07. T10N. R14E. UM Dear Mr. Stagg' Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated August 9. 1999. are in effect for this revision. Robert . Christenson, P.. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC~ Department of Fish & Game. Habitat Section W/o cncl Department of Environmental Conservation w/o encl STATE OF ALASKA ~ ALASKA ,~ .-AND GAS CONSERVATION CON. ,ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work F-IDrill [] Redrill Ilb. Type of well [] Exploratory []Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 74.05' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028313 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 498' SNL, 588' WEL, SEC. 07, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 N/A - Water Injection Well X-11Ai At total depth 9. Approximate spud date Amount $200,000.00 2710' SNL, 290' WEL, SEC. 07, T10N, R14E, UM 10/05/99 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047475, 2568' I ~. No Close Approach 2560 9740' MD / 8904' TVDss 16. To be completed for deviatgd well~-' 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8832' ~D'-?'YZ~ M'a,~i~um Hole Angle 105° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program ~//~/(~°~'//?Z) Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1265' 8475' 8131' 9740' 8904' 95 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ' ORIGINAL , Present well condition summary Total depth: measured 9971 feet Plugs (measured) ~..';L~ ",.';' true vertical 9679 feet Effective depth: measured 9582 feet Junk (measured) Fill at 9882' (09/89) /~laS[(~t 0ii & Gas Cons, i~;0~ true vertical 9293 feet A.qc[10fag8 Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8.6 cu yds Concrete 110' 110' Surface 2618' 13-3/8" 3813 cu ft Permafrost II 2662' 2662' Intermediate 8978' 9-5/8" 1254 cu ft Class 'G', 130 cu ft PF 9022' 8741' Production Liner 1493' 7" 491 cu ft Class 'G' 8491' - 9971' 8208' - 9679' Perforation depth: measured 9158' - 9190', 9261' - 9266', 9276' - 9284', 9288' - 9298', 9304' - 9321', 9326' - 9338' true vertical subsea 8801' - 8978' (six intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the for/Fg,oing is true and correct to the best of my knowledge Signed ~~,/,~/</'//~/~- Ted Stagg Title CT Drilling Engineer Date / Commission Use Only Permit Numbe~ APl Number I Approval Date I See cover letter ~-" ~7S 50-029-20471-01 ~.-. ¢- /47',¢ for other requirements Conditions of Approval: Samples Required []Yes J~o Mud Log Required D_.,,Yes .~'~1o Hydrogen Sulfide Measures .~'¢esI--~No Directional Survey Required Jl~t,Yes [] No Required Working Pressure for BOPE [] 2K; I--]3K; '[~4K; [-15K; [-I 10K; [-I 15K Other: by order of e/~-/~ Approved By ORIGINAL SIGNED BY Commissioner the commission Dar "-~¢ ~ . Form 10-401 Rev. 12-01-85 Rouert N. Christenson Submit In Triplicate t _ hared ervices a rilling Date: Oct. 4,1999 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re: Well X-1 Iai Change in Bottom Hole Location A coil sidetrack of X-11 has been permitted, 99-78, as is scheduled to begin abandonment and milling operations as early as late tomorrow, 10/5/99. Drilling will not begin until approximately 10/8/99. However, a change in BHL for this sidetrack has been requested. The revised directional plan and revised Form 10-401 are attached. Please advise if further information is needed. Ted Stagg Y CT Drilling Engineer cc: Well File Petrotechnical Data Center Section 500 Path Distance (Feet) 1,000 1,500 2,000 Angle @ K.O.= 10 deg MD:9190 Tot Drld:550 ft 9740 TD Marker Depths ~:)ri~l Wellbore ~,~o~1 8,~031~TVD I 8,8221 t HOT 8978 I 8,978 Irt TVD ol ol. vo IKick Off I 8,8321ft TVD 9,1901ft MD IDeprtr @KO 1,815 ft MD KO Pt 9,190I MD New Hole 550[ I Total MD 9,740I TVD TD 8,9041 DLS deg/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 36 - 10 266 Curve 3 18 -90 264 550 Drawn: 10/4/1999 10:22 Plan Name: Case 901 X-11 ' 5O0 665661 5937442 X distance from Sfc Loc -2,000 -2,500 -3,000 JWell Name X-11 J CLOSURE JDistance 2,233 ft Az 171 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 304 - 1,774 TD 353 -2,205 State Plane 665,662 5,937,413 Surface Loc 665,309 5,939,618 DLS de~l/100 Tool Face Length Curve 1 ' 6 0 ~0 Curve 2 36 - 10 266 Curve 3 18 -90 264 550 Drawn: 10/4/1999 10:22 Plan Name: Case 901 , , WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION DATE, COMPANY INIT CLASS //' /~J/~l(: ENGINEERING DATE WELL NAME ~.'.]r~/_~'_ ~'~:;////~L' PROGRAM: exp GEOLOGY 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. dev redrll serv ..~'" wellbore seg ann. disposal para req ~,¢~_~) UNIT# .,~,'&/~'<~.~-~_~") ON/OFF SHORE GEOL AREA N '~r N Y N /V/"~ DATE~ -, ANNULAR DISPOSAL.- APPR DATE 33. Seabed condition survey (if off-shore) ............. Y N 34. Contact name/phone for weekly progre,s,~eports [exploratory only] Y N With proper cementing records: thi~.n (A) will contain waste in a~e receiving zone; >,..- . ': . . Y N (B) will not contaminate/freshwater; or cause~ waste... Y N tO surface; /" . ~ .. (C) will notim~., i.nte~fth.ewel!usedfordisposal; Y N (D) will not dam/zfge producing formation or impair recovery from a Y N pool; and ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N 35. _G_E OI:._C)_/~/, ENGINEERING: UIC/An~ ~. RPC/~.'~(---- BEW Z~ W----~~- '/ S F ___D'~'~ JDH ---'~ c:\msoffice\wordian\diana\checklist (rev. 09/27/99) COMMISSION: Comments/Instructions: m z TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 9, 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Rez Prudhoe Bay Unit X-1 IAi BP Exploration (Alaska). Inc. Permit No: 99-078 Sur. Loc. 498'SNL. 588'WEL. SEC. 07. T10N. R14E. UM Btmhole Loc. 3477'SNL. I'WEL. SEC. 07, T10N. R14E. UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integriv,.' (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be givcn so that a representative of the Commission max' witness the tests. Notice max' be given bx' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC; Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation xv/o encl. · -- STATE OF ALASKA _ ~ ALASKA U,~_ AND GAS CONSERVATION CON, ,SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Developmen. t Oil [] Re-Entry [] DeepenI []Service [] Bevelopment Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 74.05' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028313 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 498' SNL, 588' WEL, SEC. 07, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 N/A - Water Injection Well X-11Ai At total depth 9. Approximate spud date Amount $200,000.00 3477' SNL, 1' WEL, SEC. 07, T10N, R14E, UM 08/15/99 ....... 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047475, 1802'I No Close Approach 2560 10574' MD / 8977' TVDss ...... 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9175' MD Maximum Hole Angle 95° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2139' 8435' 8092' 10574' 8977' 95 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9971 feet Plugs (measured) true vertical 9679 feet Effective depth: measured 9582 feet Junk (measured) Fill at 9882' (09/89) true vertical 9293 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" x 30" 8.6 cu yds Concrete 110' 110' Surface 2618' 13-3/8" 3813 cuft Permafrost II 2662' 2662' Intermediate 8978' 9-5/8" 1254 cuft Class 'G', 130 cuft PF 9022' 8741' Production Liner 1493' 7" 491 cuft Class 'G' 8491' - 9971' 8208' - 9679' Perforation depth: measured 9158' - 9190', 9261' - 9266', 9276' - 9284', 9288' - 9298', 9304' - 9321', 9326' - 9338' true vertical subsea 8801' - 8978' (six intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terde Hubble, 564-4628 21. I hereby certify that t¢b~ foible and correct to the best of my knowledge Signed ..... Ted Stagg ~---~,'f~., Title CT Drilling Engineer Date ' ¢/~ Commission Use Only Permit Number APl Number I Al~pro. val Date See cover letter 4:~,_.~,,~ 50-029-20471-01I < 1'1 Ic~ for other requirements Conditions of Approval: Samples Required []Yes I~ No Mud Log Required I-lYes J~ No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required l~Yes'[] No Required Working Pressure for BOPE 1--12K; [-13K; ~4K; [-15K; I--I 10K; [-I 15K Other: ORIGINAL SIGNED'BY by order of lo~ Fr~)i~hc Approved By Robert N. Chdsten$0n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit[ In ate BPX X-11 ai Sidetrack Summary of Operations: x-114 has been a water injector since 1985. The sidetrack, X-1 lai, will isolate injection to better flood Zone 4B. This sidetrack will be conducted in two phases. Phase 1: Set whipstock: Planned for August 13, 1999. · A Mechanical Integrity Test has been performed. A Kinley caliper has been run over the tubing and liner. · A permanent whipstock will be set on ELine at approximately 9,165' MD. Phase 2: Squeeze Cement, Mill Window and Drill Directional Hole: Planned for August 15, 1999. Coiled tubing drilling equipment will be rigged up and utilized to squeeze cement, mill the window and drill the directional hole as per attached plan to planned TD of 10,574' MD (8,977' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: - No annular injection on this well. - All drilling and comp. fluids and all other Class II wastes will go to Grind & Inject for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,435' MD and cemented with approx. 17 bbls. cement to bring cement at least 200 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be preSsure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,165' MD (8,817' TVD ss) - TD: 10,574' MD (8,977' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction Log will be run at TD. TREE: 6" CIW WELLHEAD: GRAY ACTUATOR: OTIS 9 5/8" DV PACKER 13-3/8", 72 #/ft, L-80, BTRS I2662'I KOP: 2800' MAX ANGLE: 21 X-11ai Proposed Completion KB. ELEV: 74.05' BF. ELEV: 39.95' SSSVLANDING NIPPLE I 2140' J (OTIS)( 3.813" ID) GAS LIFT MANDRELS ( OTIS W/RA LATCH) N°. MD(BKB) TVDss 5 3032' 2957 4 5113' 4944 3 7235' 6932 2 8005' 7671 1 8231' 7893 4-1/2", 12.6#/ft, L-80, NB MOD BTRS IPC TUBING TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT SLIDING SLEEVE OTIS (3.813" MIN. ID) TUBING SEAL ASSY. 20' BAKER SBR 9-5/8" PACKER (BAKER SAB)(3.813"ID) TOP OF I 8491'1 7" LINER 9-5/8", 47#/ft, ] 9022' L-80, BTRS I 2 7/8" liner cemented to approx. 200 ft above window I8340' 8396' 8415' 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 ....X" NIPPLE 8459' (OTIS) ( 3.813" ID) 4-1/2" "XN" NIPPLE 8490' (OTIS) (3.725" ID) 4-1/2" TBG TAIL (BAKER SOS)(3.958"1D) (ELMD) 8522' 8525' Whipstock PERFORATION SUMMARY REF: LOG: BHCS 08-11-80 SIZE SPF INTERVAL ()PEN/SQZ'D 3-3/8 4 9158-9190' OPEN 3-3/8 4 9261-9266' OPEN 3-3/8 4 9276-9284' OPEN 3-3/8 4 9288-9298' OPEN 3-3/8 4 9304-9321' OPEN 3-3/8 4 9326-9338' OPEN Abandonment cement to be squeezed past whipstock PBTD I 9916' 7", 29 #/ft, L-80, BTRS I 9970' X-ll 5OO 978 HOT 8978 X distance from Sfc Loc 1,000 JWell Name X-! 1 J CLOSURE J Distance 3,038 ft J Az 167 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 306 - 1,772 TD 663 -2,965 State Plane 665,972 5,936,653 Surface Loc 665,309 5,939,618 DLS dec)/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 36 - 10 234 Curve 3 9 -90 549 Curve 4 9 150 147 Curve 5 9 90 439 1,399 Drawn: 8/2/99 16:00 Plan Name: Case 201a Section HOT 8978 500 Path Distance (Feet) 1,000 1,500 2,000 I I I 2,500 3,000 Angle @ K.O.= 10 deg MD:9175 Tot Drld: 1399 ft 10574 TD Marker Depths ~)ri~l Wellbore TSHU 8,9231 8,923J~ TVD I 8,822]~TV~ 8,9101 8,9101ft TVD Kick Off I 8,817 ft TVD I 9,175 fl' MD Deprtr @KO 1,813 fi' I MD KO Pt 9,175 MD New Hole 1399 Total MD 10,574 TVD TD 8,977 DLS decj/100 Tool Face Len~lth Curve 1 6 0 ~30 Curve 2 36 - 10 234 Curve 3 9 -90 549 Curve 4 9 150 147 Curve 5 9 90 439 1,399 Drawn: 8/2/99 16:00 Plan Name: Case 201a X-11ai CT Drilling & Completion BOP u.! 22.5" ~$" 2 3/8" CT ~ I i i I 7 1/16" Annular 7 1/16' 5000 psi Blind/Shear 7 1/16" Pipe/Slip --~ 2 3/8" 17 ~/~e'xs,°°° Psi / / Slips ~ ~ 2 7/8" 7 1/16" SWAB OR MASTER VALVE I ;--.. STATE OF ALASKA · . ALASKA O1_ AND GAS CONSERVATION COMrv,.._,SlON APPLICATION FOR :SUNDRY APPROVAL 1. Type of Request: ~;;~]Abandon [] Suspend [] Plugging E]Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~ Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 498' SNL, 588' WEL, SEC. 07, T10N, R14E, UM At top of productive interval N/A - Water Injection Well At effective depth 2332' SNL, 355' WEL, SEC. 07, T10N, R14E, UM At total depth 2371' SNL, 381' WEL, SEC. 07, T10N, R14E, UM Type of well: [--] Development [~ Exploratory [-~ Stratigraphic [~ Service Datum Elevation (DF or KB) KBE = 74.05' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number X-11i 9. Permit Number 80-49 10. APl Number 50-029-20471 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary 13. Total depth: measured 9971 feet Plugs (measured) -.-- true vertical 9679 feet Effective depth: measured 9582 feet Junk (measured) Fill at9~ true vertical 9293 feet Casing Length Size ,, Cer~nted M D TVD Structural Conductor 110' 20" x 30" 8.6 c/u yds ~crete 110' 110' Surface 2618' 13-3/8" ' 381__3 cu ft i~efmafrost II 2662' 2662 Intermediate 8978' 9-5/8~" 12t~5.~ Class 'G', 130 cuft PF 9022' 8741' / v · Production 9 o4'- Peroration depth: measured 915 ~al ~~8~1' - 8978' (six inte~als) Tubing (size, gr~e, and meas~ed depth) 4-1/2", 12.6¢, L-80 to 8522' Packers and ~~~ ;e~sured depth) 9-5/8" Baker packer at 8415" 4-1/2" SSSVLanding Nipple at ~24, ,/ Attachments ~ Descrip~n summaw of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation August 13, 1999 16. If proposal was verbally approved Name of approver contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved 15. Status of well classifications as: [~] Oil i~ Gas [~ Suspended Service Water Injection Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fo~~s true and correct to the best of my knowledge . Signed Ted Stagg ~_____~~'~ Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test~ Subsequent form required 10- Approval Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate H 153102 DATE o67-[B/99 CHECK NO. O01531021 VEN~R ALASKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 061499 CK061499D 100. O0 100. O0 HANDLING INST: s/H TERRI HUBBLE X4&28 A~ACHEO CHECK ~ IN PAY~ ~ ~ DE~RIB~ A~. ~e]~!l~ ~ 1 OO. O0 1 OO. OO :.:BP EXPLORATION (ALASKA).,::INC~ . .. P.O:;BOX 196.612 :~::i:" ' ANCHORAGE;:ALASKA 99519-6612 i..i ..:: .::. FIRST NATIONAi~..BANK OF ASHLAND -' ;AN AFFILIATE OF .... NATIONAL: CITY.BANK CLEVELAND. OHIO .... :'56-389 412 No. H 153102 CONSOLIDATED COMMERCIAL ACCOUNT 00153102 PAY '..T°': The ::::'"ALASKA STATE-.:,.:DEPT. OF REVENUE ORDER '::: :¥3OO1: PORCUPTNE?DR -. :;:::?'i- .':~ .... ::; :':O'F: i': :: . ;:':' ::::i-::'~ :-::- i'- .:'- :::!" -.!: :: -.*!i:!:: ..'::i- :: · i' '" :' i:: -'7i :. ::.:: : .' ::;i'Z"i"'i,::i:'::': AMOUNT $100. O01 : :: i::. ' :: NOT:VALID AFTER 120 DAYS .::;i ' ' ::': '' '"~".'~"~;~' ':':":":''.'"' o "--'"" ANCHORAGE AK 99501-3120 WELL PERMIT CHECKLIST FIELD & POOL COMPANY ,~ ADMINISTRATION WELL ENGINEERING ,~R~ DATE INIT CLASS GEOLOGY PROGRAM: exp_ dev__ ANNULAR DISPOSAL 35. APPR DATE GEOL AREA ~'~'<:::) N 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~:::~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y N/' 32. Seismic analysis of shallow gas zones ............. Y/N Seabed condition survey (if off-shore) ............. /,Y N 34.33' Contact name/phone for weekly progress reports [exploratory only]' Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshw_aterpo~ cause drilling waste... Y N to surface; (C) will not imp....aJrdfi'echanica],.integdty of the well used f_or-disp'b~al; Y N (D) will not/~. ~age producing formation_..or.-impair-Y~'~)very from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N redrll ?~'_ serv .,~. wellbore seg __ u.n-# ann. disposal para req_ ON/OFF SHORE <:~,,'~) ENGIN EF__.RIN~G: UIC/Annular JDH ~. COMMISSION: DWJ ~ RNC - co Comments/instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not padiculady 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mort May 01 09:46:08 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/05/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD nOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 1 AK-MM-90166 B. JAHN SEVCIK / PAR X-11A 500292047101 BP Exploration (Alaska) Inc. Sperry Sun 01-MAY-00 MWD RUN 3 AK-MM-90166 B. JAHN SEVCIK / PAR 7 I0N 14E 498 588 74 . 05 .00 38.77 MWD RUN 4 AK-MM-90166 B. JAHN SEVCIK / PAR OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9180.0 RECEIVED 0 2_ 2000 Alaska Oil & Gas Cons. Commission Anchorage R~MARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 - 4 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUN 2 WAS A CLEAN OUT RUN WITH NO FOOTAGE DRILLED AND IS NOT PRESENTED. 4. DIGITAL DATA ONLY IS DEPTH CORRECTECD TO THE PUC LOG OF 10/15/99 (PUS GR) WITH A ABE OF 74.05' AMSL. THIS WELL KICKS OFF FROM X-Il AT 9180' MD, 8822' SSTVD (TOP OF WHIPSTOCK). 5. MWD RUNS 1 - 4 REPRESENT WELL X-11A WITH API # 50-029-20471-01. THIS WELL REACHED A TOTAL DEPTH OF 9768' MD, 8898' SSTVD. SROP = SMOOTHED P~ATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9157.0 9735.0 ROP 9209.5 9766.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9157.0 9159.0 9161 0 9162 9171 9175 9179 9189 9192 9203 9206 9219 9234 9235 9242 9244 GR 9166 5 9168 5 9170 0 9172 5 9177 0 9180 0 9182 0 9189 0 9193 0 9203 5 9206 0 9219 0 9234 0 9235 5 9241 0 9243 5 EQUIVALENT UNSHIFTED DEPTH 9248 9253 9258 9261 9274 9278 9295 9304 9313 9321 9324 9328 9331 9344 9356 9365 9368 9373 9386 9402 9404 9408 9412 9417 9422 9432 9458 9473 9478 9481 9489 9492 9503 9534 9545 9551 9557 9564 9567 9576 9585 9620 9624 9632 9640 9666 9668 9692 9697 9703 9705 9710 9726 9729 9733 9766 $ 0 5 5 5 5 5 5 0 5 5 5 5 5 5 5 0 0 0 0 0 0 5 5 0 5 5 0 5 5 5 5 0 5 0 0 5 0 0 0 5 0 5 5 5 5 0 5 5 5 0 5 5 0 0 5 0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REM2kRKS: 9247 5 9252 5 9257 5 9260 0 9273 0 9277 5 9294 5 9302 5 9312 0 9320 0 9323 0 9328 0 9331 0 9343 5 9355 5 9364 5 9368 5 9372 5 9383 0 9397 5 9400 5 9406 0 9409 5 9415 5 9420 5 9431 5 9457 5 9471 0 9477 0 9481 0 9487 5 9490 0 9502 0 9533 0 9542 5 9550 0 9556 5 9563.0 9567 0 9575 5 9584 0 9620 5 9624 0 9630 5 9639 0 9665 5 9669 5 9691 5 9695 0 9702 0 9705 5 9711 5 9727 0 9729 0 9735 5 9768 0 BIT RUN NO 1 3 4 MERGED MAIN PASS. $ MERGE TOP 9166.5 9400.0 9454.5 MERGE BASE 9399.5 9454.0 9768.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9157 9766 9461.5 1219 ROP MWD FT/H 3.53 863.27 75.7538 1114 GR MWD API 23.82 848.9 74.636 1157 First Reading 9157 9209.5 9157 Last Reading 9766 9766 9735 First Reading For Entire File .......... 9157 Last Reading For Entire File ........... 9766 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: .5000 START DEPTH STOP DEPTH 9166.5 9373.0 9209.5 9399.5 28-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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) MtTD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 7.74 Memory 9400.0 18.7 59.9 TOOL NLTMBER 003 3.750 FLOPRO 8.70 65.0 9.0 22000 6.8 .000 .000 .000 .000 .0 125.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD010 FT/H Min Max Mean Nsam 9166.5 9399.5 9283 467 4.38 108.6 52.8556 381 First Reading 9166.5 9209.5 Last Reading 9399.5 9399.5 GR MWD010 API 24.13 621.78 104.286 414 9166.5 9373 First Reading For Entire File .......... 9166.5 Last Reading For Entire File ........... 9399.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9373.5 9423.5 ROP 9400.0 9454.0 $ LOG HEADER DATA DATE LOGGED: 28-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWN-HOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9454.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 69.3 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER 002 3.750 FLOPRO MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TErRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M_AX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAlXIDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.65 65.0 11.0 21000 6.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 133 .3 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9373.5 9454 9413.75 162 ROP MWD030 FT/H 19.58 134.56 85.3811 109 GR MWD030 API 27.39 153.74 49.0053 101 First Reading 9373.5 9400 9373.5 Last Reading 9454 9454 9423.5 First Reading For Entire File .......... 9373.5 Last Reading For Entire File ........... 9454 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9424.0 9737.0 ROP 9454 . 5 9768 . 0 $ LOG HEADER DATA DATE LOGGED: 28-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWN-HOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9768.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 92.9 MAXIMUM ANGLE: 111.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURA3~ GAMMA PROBE $ 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 TEMPEP_ATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER 002 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 3 .75O REMARKS: $ Data Format Specification Record FLOPRO 8.65 65.0 11.0 21000 6.8 .000 .000 .000 .000 .0 133.3 .0 .0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9424 9768 9596 689 ROP MWD040 FT/H 3.53 863.27 89.4678 628 GR MWD040 API 23.82 848.9 60.8591 627 First Last Reading Reading 9424 9768 9454.5 9768 9424 9737 First Reading For Entire File .......... 9424 Last Reading For Entire File ........... 9768 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
