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Home My WebLink About200-1377. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-34A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-137 50-029-22474-01-00 12045 Conductor Surface Intermediate Liner Liner 8875 80 3777 10542 907 1370 10660 20" 10-3/4" 7-5/8" 5-1/2" 2-7/8" 8433 34 - 114 33 - 3810 30 - 10572 10403 - 11310 10651 - 12021 34 - 114 33 - 3517 30 - 8351 8207 - 8608 8167 - 8871 11989 470 2480 5120 6280 13890 10660 1490 5210 8180 7740 13450 11430 - 11990 4-1/2" 12.6# L-80 27 - 10415 8812 - 8867 Structural 4-1/2" Baker SABL-3 2198 / 2166 10351 8153 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907.564.5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028307 27 - 8210 371 0 35425 0 27 0 0 0 1015 0 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Camco TRDP-4A 10351 / 8153 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:31 am, May 30, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.05.30 09:26:26 - 08'00' Bo York (1248) DSR-5/30/24 RBDMS JSB 053024 WCB 7-16-2024 ACTIVITYDATE SUMMARY 4/7/2024 T/I/O=2480/515/vac MIT-IA to1800 psi (PRESSURE TEST (INTEGRITY)) Attempted MIT-IA 3 times, all attempts Failed. DSO notified upon LRS departure. Valve Positions: SV/WV/SSV = Closed, MV = Open, IA/OA = OTG Final WHPs = 2477/513/vac 4/24/2024 T/I/O = 2360/470/VAC. Temp = SI. T & IA FL (FB). No AL. T FL @ 10350' (158 bbls). IA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 4/27/2024 ***WELL S/I ON ARRIVAL*** DRIFTED w/ 2.20" D-CENT, 2.00" S. BLR (msfb) S/D ON DEPLOY SLV @ 10,654' SLM, DRIFT TO 10,800' SLM ***JOB COMPLETE, WELL LEFT S/I*** 4/30/2024 T/I/O=2330/422/0 Assist E-Line / CMIT TxIA 1800 psi PASSED ( Secure Well ) Pump 215 bbls crude down tbg to load. E-Line set plug. Pump 5.5 bbls crude down Tbg & IA to test. 1st test failed ( Jumper from tbg to IA was shut during test ) Repressured with 0.75 bbls crude to 1998/2007 psi ( Left jumper open per Ogg ) T/IA lost 19/19 psi 1st 15 min & 8/8 psi 2nd 15 min PASS. Bled back ~4.3 bbls FWHPs=205/215/0 4/30/2024 *** WELL SI ON ARRIVAL*** PT TO 250 LOW AND 3000PSI HIGH LRS FLUID PACK WELL. LOG CORRELATED TO LINER SUMMARY DATED 9/23/2000 SET NS 2 7/8 CIBP CCL - MID ELEMENT: 8.8FT / CCL STOP DEPTH 10651.2FT / MID ELEMENT DEPTH SET: 10660FT *** JOB COMPLETED*** Daily Report of Well Operations PBU 15-34A CIBP is correctly shown on the new WBS, below. -WCB SET NS 2 7/8 CIBP CCL - MID ELEMENT: 8.8FT / CCL STOP DEPTH 10651.2FT / MID ELEMENT DEPTH SET: 10660FT C C C 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Tuesday, December 26, 2023 8:37 AM To:Regg, James B (OGC) Cc:Bo York; Wallace, Chris D (OGC); Oliver Sternicki; PB Wells Integrity Subject:OPERABLE: Producer 15-34A (PTD #2001370) MIT-T, CMIT-TxIA Passed Mr. Regg, Producer 15‐34A (PTD #2001370) passed a MIT‐T and CMIT‐TxIA on 12/25/2023, verifying two competent well barriers. The well is now classified as OPERABLE. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Saturday, December 23, 2023 7:53 PM To: jim.regg@alaska.gov Cc: Bo York <byork@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UNDER EVALUATION: Producer 15‐34A (PTD #2001370) Sustained casing pressure IA Mr. Regg, Slickline is currently on producer 15‐34A (PTD #2001370) working to set a plug and MIT‐T, CMIT‐TxIA. The well will remain UNDER EVALUATION until the current slickline work is concluded to determine barrier integrity status. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe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y Anne Prysunka at 8:43 am, Sep 21, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNRX 8VHUV 'DWH MGR24SEP2022 DSR-9/21/22 RBDMS JSB 093022 $&7,9,7<'$7(6800$5< :(//6,21$55,9$/ (48$/,=( 38//0(3/8*)520 0' 6/0 -2%&203/(7(:(///()76,785129(572'62 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8$ 38//0(3/8*)520 0' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scahnable) [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation I x30: '""~0 BY: BEVERLY ROBIN VINCENT SHER~INDY r~ Other Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .._~ YES NO IF NO IN STAGE 1, PAGE(S) DISCREPA,~WERE BEVERLY ROBIN VINCENT SHERYL MARI~.~ FOUND: YES NO III IIIIIlllill II III RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked 12/10/02Rev3NOTScanned.wpd I STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li Plug Perforations LJ Perforate U Other Li Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat.ShutdownD Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc • Name: Development le' Exploratory ❑ 200-137-0 ' 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22474-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028307 PBU 15-34A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL ' 11.Present Well Condition Summary: Total Depth measured 12045 feet' Plugs measured None feet true vertical 8875.42 feet Junk measured None feet Effective Depth measured 11989 feet Packer measured 10354 feet true vertical 8866.76 feet true vertical 8156.03 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface • 3777 10-3/4"45.5#NT-80 36-3813 36-3519.28 5210 2480 Intermediate None None None None None None Production 10540 7-5/8"29.7#NT-95HS 32-10572 32-8352.78 8180 5120 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11430-11460 feet 11510-11540 feet 11825-11950 feet 11960-11990 feet True Vertical depth 8812.04-8812.71 feet 8815.1-8817.22 feet 8841.29-8860.79 feet 8862.26-8866.92 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-10417 28-8212.46 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker S-3 Perm Packer 10354 8156.03 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCpNNEt) NOV 0 8 2.013 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: 400 18638 0 0 443 Subsequent to operation: 1523 35547 15 0 757 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development g Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑• Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays�BP.com Printed Name Nita Summerhays f Title Petrotechnical Data Technician �i��• ,. Signatur "%r,/../ _ // �/ Phone 564-4035 Date 7/2/2013 T vi-i V//113 RBDMS JUL - 3 20133\ ./ gfrp Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028307 CTU#9 w/ 1.75" CT/Job Objective: RPM Log, Contingent CIBP + Perfs <<< Conitnue WSR from 6/5/13 >> RIH w/Baker RPM logging tools 1.72"x 36.92'. Make two up passes at 20 fpm from flag @ 11930'to 10950'with well full of gas. Make two subsequent up passes loaded w/ 1% KCL while pumping at 1.8 bpm. POOH. At surface. Good data. APE decides to shoot upper two sets of perfs, foregoing CIBP and lower set of Perfs. RIH w/2"x 6/6/2013 30' 2006 PJ HMX 6 SPF 60* (AdPerf run 1 of 2).. <<<In Progress>>> CTU#9 w/ 1./b" C I /Job Objective: RPM Log, Contingent CIBP + Perfs <<< Conitnue WSR from 6/6/13 >> RIH to flag. Correct top shot to Ref Log SLB CNL/CCL/GR dated 20-April-09. RIH 50', PU to shot depth, and launch 1/2" aluminum ball. Perforate 11,510-11,540'ELM w/2"2006 PJ HMX (6 SPF, 60*). Good indication of firing. POOH. Confirm guns fired. Recover 1/2" aluminum ball. RIH w/2"x 30' 2006 PJ HMX 6 SPF 60* (AdPerf run 2 of 2). Perforate 11430'-11,460' ELM w/2"2006 PJ HMX (6 SPF, 60*). Good indication of firing. POOH. Confirm guns fired. Recovered 1/2" aluminum ball. 6/7/2013 RDMO <<< Job Complete >>> FLUIDS PUMPED BBLS _ 39 METH 436 1% KCL 475 TOTAL Casing / Tubing Attachment ADL0028307 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 _ 20" 91.5#H-40 30 - 110 30 - 110 1490 470 LINER 1654 2-7/8"6.16# L-80 10367 - 12021 8167.66 - 8871.72 13450 13890 LINER 437 5-1/2" 17# 13Cr80 10414 - 10851 8209.76 - 8608.81 7740 6280 PRODUCTION 10540 7-5/8"29.7# NT-95HS 32 - 10572 32 - 8352.78 8180 5120 TUBING 10389 4-1/2" 12.6# L-80 28 - 10417 28 - 8212.46 8430 7500 SURFACE 3777 10-3/4"45.5# NT-80 36 - 3813 36 - 3519.28 5210 2480 • • O TREE= FAC • ..�. '15-34A SA NOTES: WELL ANGLE>70°@ 11108'. ,WELLHEAD (2V S/ "'5-1/2"CHROME LNR***SSSV FLAPPER ACTUATOR BAKER C BROKEN(05/12/09) NTWL KB.ELE 65.45' N BF.Hla/= KOP'= 1252 -Max Angle= 91°@ 11340' 2201' I—4-1/2"CAMCO TRSV SSSV NIP,D=3.855' Datum M)= 11981' 0 LOCKED OUT(09/29/95) Datum TVD= 8800'SS 2201' —4-1/2'HOLD OPEN SLV w/DB LOCK, D=2.25'(08/10/12) 10-3/4'CSG,45.5#,NT-80,D=9.953' H 3813' I. GAS LIFT MASS ST MD 1VD DEV TYPE VLV LATCH PORT GATE 1 3268 3114 37 KBMG DOME BK 16 03/24/13 J 2 6110 5115 46 KBMG DONE BK 16 03/24/13 Minimum ID =2.25" @ 2201' 3 8583 6819 45 KBMG OMY BK 0 09/05/04 4-1/2" HOLD OPEN SLEEVE 4_10223 8040 29 KBMG DMY BK 0 09/05/04 I I 10333' H4-1/2"OTIS X NP,D=3.81" I E g 10354' H7•X 4-1/2"BKR S-3 PKR,D=3.89" I I I 10388' —14-1/2"OTIS X IM',D=3,725" TOP OF 5-1/2'LNR H 10403' I I 10406' --H4-1/2"OTIS XN MP ID=3.725" 4-1/2 TBG,126#,L-80 NSCT, —{ 10418` i a 1 10418' H4-1/2"WLEG,D=3.81" .0152 bpf,ID=3.958" --{FEND TT NOT LOGGED 17-5/8'CSG,29.7#,NT-95 HS,D=6.875" H 10572' I 10643' H3-112"FL4S BKR DEPLOY SLV,D°3.00" (TOP OF 2-7/8"LNR —1 10651' 10649 H3-112"X 2-7/8'XO PIN,D=2.44" MLLOUT WNOOW(15-34A)10851'-10857' TOP OF WHIPSTOCK --I 10850' RA TAG — 10859' 15-1/2"LP,17#,13CR-80,.0232 bpf,D=4.892" I—I 11310' , ` PEFFORATION SUMMARY ` REF LOG: SFEJ Y AMVDIGR ON 09/24/00 ANGLE AT TOP F RE: 89°@ 11430' ;` Note:Refer to Production 0B for historical perf data ��`: SIZE SFF INTERNAL Opn/Sgz SHOT SQZ PBTO H 11989' I ��, 2" 6 11430-11460 0 06/07/13 2" 6 11510-11540 0 06/07/13 2" 4 11825-11950 0 09/27/00 I2-7/8'LNR,6.16#,STL,L-80,.0579 bpf,D=2.37" H 12021' I 2" 4 11960-11990 0 09127/00 GATE REV BY COMMENTS DATE REV BY COM0.134TS PREDHOE BAY UNIT 05/20/94 ORIGINAL COMPLETION 08/15/12 SET/JM) SET BP(08/13/12) MLL: 15-34A 09/29/00 LAST WORKOVER 04/03/13 TM/JND PULLED BP&GLV C/O(03/23-24/ PERMT No: 2001370 08/24/05 TEUTLH GLV GO 06/13/13 JJUJMD ADFERFS(06/07/13) API No: 50-029-22474-01 10/17/08 BSE/PJC SSSV LOCKED OUT(09/29/95) SEC 22,T11 N,R14E,1428'FNL&945'FWL 06/03/09 GJF/TLH SET HO SLEEVE(05/12/09) II 08/11/12 RCT/PJC C/O HOLD OPEN SLV(8/10112) BP Exploration(Alaska) 1 � 1 S— 3g A zoo ► 370 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator ( AKDCWeIIIntegrityCoordinator @bp.comj Sent: Saturday, March 09, 2013 7:32 PM ' <-? . 1 ' 3 To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists; Lee, Timothy Cc: AKD &CDHDWelllntegri @bp.com; Ryan.Holt @bp.com; Arend, Jon Subject: OPERABLE: Producer 15 -34A (PTD #2001370) Tubing Integrity Restored All, Producer 15 -34A (PTD #2001370) passed an MIT -IA to 2500 psi on 03/09/2013 after resetting a leaking dummy gas lift valve. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Co G W 1°ol ' raa�aati zat 11 €�:' SCANNED JUL 2 2 2013 Office: 907.659.5738 WIC Email: AKDCWeIIIntegrityCoordinator Pbp.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, August 15, 2012 7:38 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producer 15 -34A (PTD #2001370) Failed Mechanical tegrity Testing All, Producer 15 -34A (PTD #2001370) failed an MIT -T and a CMI xIA after an IBP was set in the hole indicating a lack of competent barriers. At this time, the well has been load-: with kill weight fluid on top of the IBP and is reclassified as Not Operable until integrity is confirmed. Plan forward: 1. APE: Evaluate for Leak Detection og Thank you, Mehreen Vazir BPXA Well Integrity Coordinat.r 1 VI 414 2-co-vs7 s_. WELL LOG TRANSMITTAL I I, PROACTIVE DiAgNOSTic SERVICES, INC. To: AOGCC Christine Shartzer 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793 -1225 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 Benson Blvd. SCANNED JUL 01 900 Anchorage, AK 99508 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 21- Aug -12 15 -34A BL/ CD 50 -029 *- 22474-01 2) Signed . i,' _Af, :, �, �( ) _ ) ; _ t -t Date : -, / j t ' i. Print Name: ,ki.,,..L-a =�.._ `<-- 6 ==.- ,� `Z �-. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGEAMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittatSheets\BP Transmit docx 2e7c7--\ 7 DATE: 28- Sep -12 Stephanie Pacillo TRANS#: 6067 Data Delivery Services Technician . 1$ 7Makana K Bender SChlumberger Oilfield Services -� '' Natural Resource: Technician II WIRELUNE ria.ska Oil& Gas Conservation C:'on 2525 Gambell St, Ste, 400 - 7 . _ f- «, S u i Ft 1 ,. r} 1 " - . ":<;. a r. ; 1 - _i' , Anchorage, Al( 99503 - N: Office: (907) 273 -1770 t_:�,.:�, ` ^�� , ��> T it u -4 �r „•( �- N 3 LPG 'F� �SDRIP'T�O�! <DI'�'i'E .8, 'COLOR: `,,, x.. S H s. +r.. . '. F.. ��1u t c� � �.. � ��CH f- . :!:B/W” Tf�4�7.� 4 NAME .ORDER # DIST DIST DIST DIST LAGGED PRINTS PRINTS R -01 BCRC -00203 _ X MEMORY LEAK DETECTION 9- Aug -12 1 1 CD V -122 BINC -00101 X DRIFT SURVEY 25- May -12 1 1 CD ili MPB -05A C600 -00037 X MEMORY IPROF 11- Aug -12 1 1 CD G -10C C600-00029 X PPROF /IPROF w CNL -BORAX 17-Jul-12 1 1 CD r K -10C BAUJ -00138 X MEMORY PPROF w GHOST 29- Jun -12 1 1 CD S -102 COT4-00047 X MEMORY TEMPERATURE LOG 4- Aug -12 1 1 CD 1- 35/0.25 BG4H -00114 X X FLOW CHECK 20- Feb -12 1 1 CD 15 -053 C600-00038 X MEMORY PPROF 16- Aug -12 1 1 CD 15-34A BG4H -00129 X XFLOW CHECK w IBP RECORD 13- Aug -12 1 1 CD B -050 C5XI.00023 X MEMORY CEMENT BOND LOG 09 -AUG -212 1 1 CD 1 CD M -23 BBSK -00133 X CROSSFLOW LOG 17- Aug -12 1 A -28 C4W7-00011 X PPROF 4- May -12 1 1 CD C-42A C1UB -00024 X SLIM CEMENT MAPPING TOOL 4- Aug -12 1 1 CD . H -38A CSXI -00024 X MEMORY PPROF GHOST 9- Aug -12 1 1 CD 2.58/S.09 3281 -00034 X LEAK DETECTION LOG 15- Aug -12 1 1 CD W -211 3281.00032 X PPROF W GHOST DEFT 12- Aug -12 1 1 CD 11 _ _ _ _ _ _ X _ _ ._ _ x Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 SCANNED JUL 0 1 2013 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 P3tL 15 Pr Z j Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] � � � Sent: Wednesday, August 15, 2012 7:38 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 bs Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producer 15 -34A (PTD #2001370) Failed Mechanical Integrity Testing All Producer 15 -34A (PTD #2001370) failed an MIT -T and a CMIT -TxIA after an IBP was set in the hole indicating a lack of competent barriers. At this time, the well has been loaded with kill weight fluid on top of the IBP and is reclassified as Not Operable until integrity is confirmed. Plan forward: 1. APE: Evaluate for Leak Detection Log Thank you, SCANNED APR 2 4 Mehreen Vazir 2.013 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 21, 2012 9:38 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops -ad; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Tea ► ead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producer 15 -34A (PTD #2001370) Sustained IA Casi Pressure Above MOASP All, Natural Flow Producer 15 -34A (PTD #2001370) has confirmed sustained I asing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV /2050/20 on 07/18/20 . A TIFL was performed with inconclusive results. The well has been reclassified as Under Evaluation while diagn ,stics are performed to evaluate integrity. Plan forward: 1. Operations: Place well on production 2. Downhole Diagnostics: Warm TIFL 3. WIE: Pending TIFL results, evaluate gas lift valve • ange out A TIO plot and wellbore schematic have been includ d for reference. « File: 15 - 34A TIO Plot 07- 21- 12.docx » <- File: 15- 34A.pdf » OPERABLE: Producer 15 -34A (PTD 601370) Tubing Integrity Restored Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, August 28, 2011 7:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Producer 15 -34A (PTD #2001370) Tubing Integrity Restored Attachments: Producer 15 -34A (PTD #2001370) TIO Plot.doc All, Producer 15 -34A (PTD #2001370) passed a TIFL performed On 08/27/2011. The passing test confirms that tubing integrity has been restored. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 ' #a , 't t- SEP t` !'`1 L C 1 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, August 26, 2011 7:44 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 15 -34A (PTD #2001370) Sustained IA Casing Pressure Above MOASP All, Producer 15 -34A (PTD #2001370) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA /OA equal to SSV /2130/0 on 08/25/2011. The well has been reclassified as Under Evaluation. The well is currently shut in for pro- ration. Plan forward: 1. DHD: TIFL when brought online 2. WIE: Pending TIFL result, evaluate gas lift valve change out A TIO plot and wellbore schematic have been included for reference. «Producer 15 -34A (PTD #2001370) TIO Plot.doc» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/30/2011 UNDER EVALUATION: Producer 154A (PTD #2001370) Sustained IA Cast Pressure Abo... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, August 26, 2011 7:44 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 15 -34A (PTD #2001370) Sustained IA Casing Pressure Above MOASP Attachments: Producer 15 -34A (PTD #2001370) TIO Plot.doc; Producer 15 -34A (PTD #2001370) wellbore schematic.pdf All, Producer 15 -34A (PTD #2001370) has confirmed sustained IA casing reassure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV /2130/0 on 08/25/2011. The well has been reclassified as Under Evaluation. The well is currently shut in for pro- ration. Plan forward: 1. DHD: TIFL when brought online 2. WIE: Pending TIFL result, evaluate gas lift valve change out A TIO plot and wellbore schematic have been included for reference. «Producer 15 -34A (PTD #2001370) TIO Plot.doc» «Producer 15 -34A (PTD #2001370) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Sc.f to S 7 6 /5 4 , Z`I 7ftf Ni 96 Gerald Murphy (alt. Mehreen Vazir) P= 61 70P5, Well Integrity Coordinator Office (907) 659 -5102 5CP = Z136 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 % p _ 2_4,1 ?1 (e a lc_ 8/30/2011 PBU 15 -34A PTD #2001370 8/26/2011 TIO Pressures Plot Well: 15 -34 4,000 — 3.000 - • I I /rift - +- Tbg --U-- IA 2A00 --A-- 0°A 0A M� 00A J �r" -4- OOOA 1' On I I 1,000 - I I I I I an� 1 I 05/28/11 06104/11 06/11/11 06/18/11 06/25/11 07/02/11 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 TREE = FMC 410 WELLHEAD = CM/ SAFETY S: WELL ANGLE > 70° @ 11108'. _ACTUATOR = BAKER C * * *5 - 1/2" CHROME LINER * ** - KB. ELEV = 65.5' ® SSSV FLAPPER BROKEN (05/12/09) BF. ELEV = ? Max Angle = 91 @ 11340' OP = 1252' I 2201' I— 4 -1/2" CAMCO TRSV SSSV NIP, ID = 3.855" Datum MD = 11981' 7—'6.(1 LOCKED OUT (09/29/95) Datum TVD = 8800' SS 2201' I-14 -1/2" HO SLEEVE w /DB LOCK (05/12/09), ID = 2.99" 10 -3/4" CSG, 45.5 #, NT -80, ID = 9.953" H 3813° ■ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3268 3114 37 KBMGMSPM DOME BK 16 06/06/05 Minimum ®= 2.317" @ 10643 2 6110 5115 46 KBMGMSPM SO BK 20 08/24/05 3 8583 6819 45 KBMGMSPM DMY BK 0 09/05/04 2 -7/8" LINER TOP 4 10223 8040 29 KBMGMSPM DMY BK 0 09/05/04 I I I 10333' I- -14 -1/2" OTIS X NIP, ID = 3.81" I S Z I 10354' I—17" X 4 -1/2" BKR S -3 PKR, ID = 3.89" I I I 10388' I- 14 -1/2" OTIS X NIP, ID = 3.725" I I TOP OF 5-1/2" LNR I-{ 10403' j—, I , F I 10405' 1-14-1 /2" OTIS XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, L -80 NSCT, --I 10418' I . 10418' I- 14 -1/2" WLEG, ID = 3.81" .0152 bpf, ID = 3.958" I 17 -5/8" CSG, 29.7 #, NT -95 HS, ID = 6.875" H 10572' I J ® I I"'{ d MD TT NOT LOGGED 1 US4 P-- SI'7C p I ! / I TOP OF 2 -7/8" LNR H 10651' ( 10543' I—i 3-1/2" FL4S BKR DEPLOY SLV, ID = 3.00" 10649 I-13 -1 /2" X 2 -7/8" XO PIN, ID = 2.44" I MILLOUT WINDOW (15 -34A) 10851' - 10857' I TOP OF WHIPSTOCK 1 10850' RA TAG I I 10859' I c ` 5-1/2" LNR, 17 #, 13- CR -80, .0232 bpf, ID = 4.892" H 11310' I PERFORATION SUMMARY REF LOG: SPERRY MWD /GR ON 09/24/00 ANGLE AT TOP PERF: 80 @ 11825' #� Note: Refer to Production DB for historical perf data Tw=o. SIZE SPF INTERVAL Opn /Sqz DATE IPBTD 1.--1 11989' 2" -. 4 11825 - 11950 0 09/27/00 2" 4 11960 - 11990 0 09/27/00 12-7/8" LNR, 6.16 #, STL, L -80, .0579 bpf, ID = 2.37" I-1 12021' J DATE REV BY COMMENTS i DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/20/94 ORIGINAL COMPLETION 1 06/03/09 GJF/TLH SET HO SLEEVE (05 /12/09) WELL: 15 -34A 09/29/00 LAST WORKOVER PERMIT No: 2001370 02/27/02 RN/TP CORRECTIONS API No: 50 -029- 22474 -01 08/24/05 TEL /TLH GLV C/O SEC 22, T11 N, R14E, 1428' FNL & 945' FWL 08/19/07 CJNIPJC TRSV LOCKED OUT (09/29/05) 10/17/08 BSEJPJC SSSV LOCKED OUT (09/29/95) ( BP Exploration (Alaska) ~~ BP Exploration (Alaska) Inc. Attn: well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~'.~: ,~~,I` `SCI`s Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue ~~~,,,,~~ 3 Anchorage, Alaska 99501 ,~ Subject: Corrosion Inhibitor Treatments of GPB DS 15 ~ ~ 3 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 nata~ (11/OS/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 500292072fi0200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7!2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 Sehb~rgP.r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WeII Job # 1 {' JUN 1 ~ 2009 ~! . ail ~ ~~ C®ns. CArntnissi®tt Anohorage Log Description NO.5279 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD osn sros 14-23A AYKP-00016 USIT 04/10/09 1 1 A-44 AP3O-00036 SCMT 04/26/09 1 1 14-23A AYKP-00016 USIT 04/10/09 1 1 07-10A B1JJ-00022 MEM CN STP 05/26/09 1 1 07-14B AYOO-00029 LDL - L ~ 05/26/09 1 1 12-09 AYTU-00038 PRODUCTION PROFILE .® 05/31/09 1 1 V-218 AVYS-00048 INJECTION PROFILE/WFL G)^ p 05/29/09 1 1 15-34A AWJI-00020 MCNL 04/20/09 1 1 A-44 AWL8-00017 CH EDIT PDCL-GR (SCMT) - 05/25/09 1 YLtASt AGKNUWLtUGt HtGt1Y 1 t3Y'1(9NING ANU Ht I UHNING UNt (:UI'Y tAGH 1 U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • 15-34 (PTD #2001370) Classified as Problem Well ) ) /<. ,If):.,:3LI--A. < ',",,'.. ,'.'.' ,'" ,,' ',,'. ','. ..,",. ,".." ,,'" .' ','.." ,',«,', ,,'. .. ..,'.<' ;JRq;fj<ß1 ZZ!ð'5" Sw~j~C~:.....~..(B1:p~~9q·~,·3?Q).$1ªssi~7d.'asProÞ~~rpVfe~l.·.·.i..'··'.,.,·.......·'i.·.,·..',..'. ....,"., '. ," '.'" ...' ..,'.'.,.....'....'.,.,. ,....,"...'.'.'...'.,........,.......'.",.......,.,.'..".,"....'...,.'..'.'.'., !f~øm::"~$"(.h~WWenllit~grityEngit)ø¢:t:"$NSUA.1LJWW¢nIiitøgI"ity:epgi1'l¢ør@BP;cQWr' ' ¡j::~:iTµ¢,16:Âilig~QQ.5i:i:i7:46~080Ò> "", " ' ',' '," ,'" "" ',,', '"''''',''''' ,.'""'""."',,,,. ".' "'," "'" .,' '. ',', '"",, "'. " ',',',' All , 15-34 A Well 1..5...a4 (PTD #2001370) has sustained casing pressure on the inner annulus and is classified as a Problem well. The TIO pressures on 08/13/05 were 2300/2180Ivac. The plan forward for this well is as follows: 1. SL: Pull OGL V from sta #2 (6110' MD). Set DGL V in same. 2. DHD: ReTIFL Attachecd is a wellbore schematic. Please call if you have any questions. «15-34A.pdf» Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: robert.mielke@bp.eom '~"f"f' ¡,\1Ìf\ijI1'-'I"-,,¡ (['ED ¡;"~ ',' ?nr¡'~~,¡ ~~.'¡""4('t..~~ "~:;;;r:,,. .) - f G,' )i. ,--" '.'. ~f Mk{p '-'to ,1.-l,J:: Y P J:A- 2 (<OC>~'I 'B I bLf~ lie . 7 G2c ù~ (12-r-- Cð 4-'1 z- ù^ 0 ~~ì JRe1c( 1(1(0)' G:>z,o 1 of 1 8/22/2005 4: 19 PM ) TREE = FMC WELLHEAD::: CIW ACTUATOr~:::: BAKEH C ~'Ki3·:"Êl~'Ë\/~';4'1I¡~,m..,,,,,~.,.., -, n- "e""6'5~'5~J BF:" ECBï';' '" ,,,.,,,,,,,,.,,,, ";? .I>I"lllr.T"."";;",""T.,'",,,I..,')o,,':';;,,,·,·,,II'i KOP::: 12S2' Max Angle::: 91 @ 11340' "t5â'iuáï M'O''';;'' . '1"1"sà'1ï' ÖaÚÚrïi\/b ::: ..... 8800' 88 ) 15-34 SAFElY NOTES: HORIZONTAL WELL ~ 70° @ 11108' AND 90° @ 11340' - 5-1/2" CHROME LINER I 2201' 1-1 4-1/2" CAMCO TRSV SSSV NIP, ID = 3.855" 1 [10-314" CSG, 45.5#, NT-80, ID = 9,H5:'¡" 1-1 3813' .~ Minimum ID = 2.31" @ 10643' 2..7/8" liNER TOP ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3268 3114 37 KBMGMSPM DOME BK 16 06/06/05 L-- 2 6110 5115 4ß KBMGMSPM SO BK 20 06/06/05 3 8583 681EJ 45 KBMGMSPM DMY BK 0 09/05/04 4 10223 8040 29 KBMGMSPM OMY BK 0 09/05/04 I I 10333' 1-1 4-1/2" OTIS X NIP, ID::: 3,81" I ~ Z---1 10354' 1-1 .7" X 4-1/2" BAKER SABL-3 PKR I I I I 10388' 1-1 4-1/2" OTIS XN NIP, ID ::: 3.725" 1 I TOP OF 5-1/2" LNR 1-1 10403' I . II II I I .. 10405' .1-14-1/2" OTIS XN,NIP: ID::: 3.1.25" (BEH. LNR). I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10:::: 3.958" 1-1 10418' I .- '-. I 7-5/8" CSG, 2H,7#, NT-95 HS, ID::: 6.875". .Ii... 10572' µ 10418' 1-14-1/2" TUBING TAIL WLEG (BEH. LNR) I ~1-1 ELMD IT NOT LOGGED 1 I TOP OF 2-7/8" LNR --f 10651'1 ~ , I 1.0..643'. J- 3.5" FL~S BAKER DEPLOYMENT SLEEVE I I WINDOW 10851' -10857' r TOP OF WHIPSTOCKI-r 10850' I RA TAG 1-1 10859' 15-1/2" LNR, 17#, 13·CR·80, ,0232 bpf, ID = 4.892" 1-1 11310' I PBTD 1-1 11989' ÆRFORA TION SUMMARY REF LOG: SÆRRY MWD/GR ON 09/24/00 ANGLE AT TOP PERF: 80 @ 11825' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11825 - 11950 0 09/27/00 2" 4 11960 - 11990 0 09/27/00 12-7/8" LNR, 6.16#, STL, L-80, .00579 bpf, ID = 2.37" l-i 12021' 1 DATE OS/20/94 09/29/00 02/27/02 06/13/03 07/28/04 09/05/04 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNrTP CORRECTIONS CMOfTLP KB ELEVATION CORRECTION JLJrrLP GL V C/O WRRlTLP GL V C/O DATE REV BY COMMENTS 06/07/05 KDClTLH GL V C/O PRUDHOE BA Y UNIT WELL: 15-34A ÆRMIT No: "2001370 API No: 50-029-22474-01 SEC 22, T11 N. R14E, 1428' FNL & 945' FWL BP Exploration (Alaska) F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~;,,~-'" , .:,..~i!': o.M_ .~~. -';'j"'..=.oI!.:.":~~~".' .,,\ . ' -,' .' II ':. ' , ','~'f '1': II ',.... ' . II' .' ...... ;;;J:: Y ,"~ "r';'<'~ ~~, ' ,~' l¡.~~rr~'" ) ) 15-34:\ (PTD #~OO 13 70) Classified as Problem Well Subject: 15-34A (pTD #2001370) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.coßl> Date: Sun, 18 Jul 2004 09:05:34 -0800 To: "Jenkins, Christopher N" <Christopher.Jenkins@BP.com>, "GPB, FS3 TL" <GPBFS3TL@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng". <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GP8, FS3 DS Operators" <GPBFS3DSOperators@BP.com> cc: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.coßl>, "Reeves, Donald F" <ReevesDf@BP .com> ~t'l 1/Z>bl U4 All, Well 15-34A (PTD #2001370) has been found to have sustained casing pressure on che IA. The WHPs on 07/16/04 were 2330/2320/0. A TIFL Failed on 07/17//04. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GLV c/o 3. DHD: Re-TIFL A wellbore schematic has been included for reference. «15-34A.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659- 5102 Pager: (907) 659-5100 xl154 call if you have any Content-Description: 15-34A.pdf , 15-34A.pdf Content-Type: application/octet-stream i Content-Encoding: base64 ! C'LI {~(( c.. rrt's~", ~ L~:~ ( 4çi~ J.ü~t\) -r~. -:> 233Dp";)'. :J .:::cA -"'> -2."3£0 f~J: 6l0t r~~ () l¿..- O~ "') '34 - -'> 0 L, 5 r-::.. 1 of 1 7/28/200-t 9:32 AM TREE -= WB.LHEAD = A CTl.LA. TOR = KB ELEV = BF ELEV = KOP= Max Ange = Datum MD = Datum TVD = FMC crvv BAKER C 655' ? 1252' 91 @ 11340' 1198" 8800' SS 110.314" CSG. 45 5#. NT-80. 10 = 9953" 1-1 3813' ~ Minimum ID = 2.37" @ 106431 2-7/8" LINER TOP ITOP OF 5-112" LNR 1-1 10403' I I 4-1/2" TBG. 12.6#, L-80, 0152 bpf, 10 = 3.958" 1-1 10418' 1 17-5/8" CSG, 29.7#, NT-95 HS. 10 = 6.875" 1-1 10572' I ITOP OF 2-7/8" LNR 1-1 10651' I ITOPOFWHIPSTOCK 1-1 10850' 1 1 RA TAG 1-1 10859' 1 I 5-1/2" LNR, 17#, 13-CR-80, .0232 bpf, 10 = 4.892" 1-1 11310' ÆRFORA 110N SUMMA. RY REF LOG: SPERRY MNDiG RON 09/24/00 ANGLEATTOP PERF 80 @ 11825' Note: Refer to Production DB for historical perf data SIZE SFf NTERVAL Opn/Sqz DATE 2" 4 11825-11950 0 09/27/00 2" 4 11960-11990 0 09/27/00 Dð. TE 05120194 09129Æ>0 01/23101 02/27102 06/13103 CO~8'JTS ORIGINAL COM PLETION LAST WORKOVER SIS-MD FINA L RN/W CORRECTONS CMO/11P KB ELEVATION CORRECfION REV BY DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL' 15-34A PERMrr No: 2001370 A R No 50-029-224ì 4-01 SEC 22, T11 N, R 14E, 1428' FNL & 945' FWL 15-34A SAFETY NOTES: HORIZONTAL WELL - 70° @ 11108' AND 900@ 11340' - CHROME UNER e 2201' H 4-112" C6.fvCO TRSV SSSV NIP,ID = 3 855" I ~ GA S LIFT MA. NDRB.S DEV TYÆ VLV LATCH 37 KBfvJ3MSFM BK-2 46 KBfvJ3MSFM BK-2 45 KBfvJ3MSFM BK-2 29 KBfvJ3MSFM BK-2 PORT Dð. TE L ST M) 1VD 1 3268 3114 2 6110 5115 3 8583 6819 4 10223 8040 I I 10333' 1--1 4-1/2" OTIS X NIP. 10 = 3 81" I g Z--l 10354' 1--1 7" X 4-1/2" BAKER SA BL-3 PKR I I I I 10388' 1-1 4-1/2" OTIS XN NIP. D = 3.725" 1 - ' I 1 10405' 1--14-1/2" 011S XN NIP,ID = 3725" (BEH LNR) I I ,I I 10418' 1--14-1/2" TUBING TAIL WLEG (B8-I. LNR) I .. I 1--1 ELMO TT NOT LOGGED I ... ~ I 10643' 1--1 35" FL4S BAKER DEPLOYMENT SLEEVE I , I WINDOW 10851' - 10857' ~ 11989' \2-7/8" LNR 6 16#, Sl1, L-80, .00579 bpf, D = 2 37" l-i 12021' I BP Exploration (Alas ka) To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 04, 2002 MWD Formation Evaluation Logs' 15-34A, AK-MW-00196 15-34A: Digital Log Images 50-029-22474-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED DEC 0 6 002 Ala~ Oit & Gas Cons. C~mmi~ion ~ z o, c~z §o ~o o ~< ~' _~a~- WELL LOG TRANSMITrAL To: State of Alaska April 29, 2002 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 15-34A, AK-MW-00196 1 LDWG formatted Disc with verification listing. API#: 50-029-22474-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TItE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. ' Anchorage, Alaska 99508 Date: RECEIVED r,i, Y o 9 2002 Almk~ Oil & Gas Corn, Cmnm~r, .I ID' 0 C ,-- 0 ~ o o 0 o o o CI ~° STATE OF ALASKA '" ALASK,~' ,L AND GAS CONSERVATION COMI{i _,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-137 RECEIVED ...... 3. Address 18. APl Number .:: '..~ ': P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22474-01 . ,~, ~,o~.' 4. Location of well at surface 9. Unit or Lease Name ......... 1428' SNL, 945' EWL, SEC. 22, T11N, R14E, UM ~J0V 0 (:) ~0~ Prudhoe Bay Unit ' ~ :'~ ': At top of productive interval "" ....... 277' NSL, 1331' EWL, SEC. 14, T11N, R14E, UM Alae~0il&GasCoas. C0mm~ 10. Well Number At total depth 346' NSL, 558' EWL, SEC. 14, T11N, R14E, UM AllChOl'alge 15-34A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 65.45' ADL 028307 12. Date SpuddedD/19/2000 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'9/22/2000 0/28/2000 115' water depth' if °ffsh°reN/A MSL 116' N°' of c°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 12045 8875 FTI 11988 8867 FTI [] Yes [] NoI (Nipple) 2201' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD / GR, GR / CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" _>60 sx Arctic Set (Approx.) 10-3/4" 45.5# NT-80 36' 3813' 13-1/2" 1100 sx PF 'E', 375 sx Class 'G' 7-5/8" 29.7# NT95HS 32' 10572' 9-7/8" 532 sx Class 'G' 5-1/2" 17# 13Cr80 10414' 10851' 6-3/4" 130 sx Class 'G' 2-7/8" 6.16# L-80 10367' 12021' 3-3/4" B8 sx Class 'G', 74 sx Class 'G' 24. Perforations pp. en to. P.roducti.on (M.D+,TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s~ze ana number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10417' 10354' MD TVD MD TVD 11825' - 11950' 8841' - 8861' 11960' - 11990' 8862' - 8867' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 30 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 2, 2000 Gas Lift 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 CALCULATED OIL'BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,. Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate (' '29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Zone 1 11200' 8805' Base of Sadlerochit 12000' 8868' RECEIVED NOV 09 000 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~"/~ ~ Title TechnicalAssistant Date 15-34A 200-137 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 BP EXPLORATION Page 1 of 8 Operations Summary Report .. Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/28/2000 Contractor Name: NORDIC CALISTA Rig Release: 9/29/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Sub .. · : Phase : Description of Operations Date From-To Hours Task Code 9/18/2000 15:30 - 17:00 1.50 MOB PROD1 Rig off standby at 15:30 hrs. Move over to well 15-34a. Back rig over well and set down same. ACCEPT RIG ON DS15-34A AT 17:00 HRS ON 09/18/2000. 17:00 - 20:50 3.83 RIGU PROD1 Set cuttings tank. Rig up floor. Prepare to test BOPE. Waiting on AOGCC Rep to start BOP test. 20:50 - 23:30 2.67 RIGU PROD1 Started BOP test. Test witnessed by AOGCC Rep J. Jones. 23:30 - 00:00 0.50 BOPSUI~ PROD1 Continue testing BOP's. 9119/2000 00:00 - 02:00 2.00 BOPSUI~ PROD1 Finish BOP test. Tested @300/3500 psi. OK 02:00 - 04:00 2.00 RIGU PROD1 Testing coil. OK. 05:00 - 06:45 1.75 STWHIP PROD1 RIH. Pumping at minimum rate 0.6BPM @330 psi. Tag 4 1/2" XN : nipple at 10403' and correct to ELMD of 10397' (-6'). 06:45 - 07:00 0.25 STWHIP PROD1 Mill thru XN nipple profile 2.5 bpm 1400 psi. 07:00 - 07:15 0.25 STWHIP PROD1 RIH. Tag pinch point on whipstock face and correct depth to 10851' (+0.5'). 07:15 - 11:00 3.75 STWHIP PROD1 Start milling window at 10851'. Got some gas up from btms up and "',,,j divert returns thru buster. Pump 15 bbl visc sweep at 08:45 hrs with 3' ! ~,~ of window milled. Take returns back thru MM. 11:00 - 11:45 0.75 STWHIP PROD1 Got a stall - probably at bottom of window. Dress off bottom of window. Bottom of window at 10857.2'. Start milling formation. 11:45 - 12:30 0.75 STWHIP PROD1 Pump 20 bbl viscosified sweep. Mill formation to 10867' 2200 psi ~ 2.5 bpm. ~ ~. 12:30 - 15:00 2.50 STWHIP PROD1 Work string mill across window to clean up burrs and rough edges. _ 15:00 - 16:00 1.00 STWHIP PROD1 Switch to FIo-Pro for mud displacement. i;~ 16:00 - 18:00 2.00 STWHIP PROD1 Displace mud into annulus and POH for drilling assembly. Flag pipe at 10700' EOP. 18:00 - 18:30 0.50 STWHIP PROD1 LD milling BHA. 18:30 - 19:15 0.75 DRILL PROD1 M/U MWD BHA #2 with 2.57 deg short rad motor and M09 Bit #1 19:15 - 21:15 2.00 DRILL PROD1 RIH with drilling BHA. Shallow test Sperry tools. Cont. RIH. 21:15 -22:00 0.75 DRILL PROD1 Pre-Spud meeting with all personnel. Review well plan. 22:00 - 22:30 0.50 DRILL PROD1 Orient TF to 90R. 22:30 - 00:00 1.50 DRILL PROD1 Drill build / turn interval at 90R TF to 10,895 ft. 30 FPH, 9/20/2000 00:00 - 01:30 1.50 DRILL PROD1 Drilled to 10928 fi, 75R TF, 01:30 - 02:30 1.00 DRILL PROD1 Drilled to 10942 ft, 90R TF. 02:30 - 04:20 1.83 DRILL : PROD1 Orient TF to 80R. Unable to orient on bottom. Pull to window and orient. RIH. Orientor rolled 90 deg. Pull to window, Orient. RIH. 04:20 - 04:40 0.33 DRILL PROD1 Drilling, 80R, 2.5 BPM, 3200 psi, TF rolling to right. 04:40 - 06:00 1.33 DRILL PROD1 Pull to window and orient. RIH. TF wrong. 06:00 - 06:30 0.50 DRILL PROD1 ~ Drilling. Started losing returns at 10970' +/- 0.5 bpm. 06:30 - 07:45 1.25 DRILL PROD1 Cont drilling - losses increased to 1 bpm but slowly came down to 0.3-0.5 bpm. 2.4/2.2 bpm @ 3450 psi. TF 45L. ROP 70 fph. 07:45 - 09:30 1.75 DRILL PROD1 Continue drilling ahead monitoring mud losses - increased up to 0.7 bpm at 11017' and ROP decr to 14 fph. 09:30 - 10:15 0.75 DRILL PROD1 Cont drilling - 2.5/1.8 bpm 3700 psi. 58R. ROP -- 10 fph. Received 250 bbl new FIo-Pro. 10:15 - 10:30 0.25 DRILL PROD1 Circ pressures increasing to 4000 psi on bottom drilling and losses still at about 1 bpm. Wiper trip to window - circ pressures not coming down and hole looks clean. 10:30 - 11:15 0.75 DRILL PROD1 Cont drilling ahead - 2.5/1.5 bpm. 3850 psi. 53R. ROP = 12 fph. MI mixing 400 bbl Aphron system at plant. 11:15 - 11:45 0.50 DRILL PROD1 Pull up to window and get 2 clicks - not getting response.Try 1 more click - OK 11:45 - 12:15 0.50 DRILL PROD1 Drill to 11055'. 2.5/1.3 bpm. 3750 psi. 42R. Printed: 111312000 2:14:53 PM BP EXPLORATION Page 2 of 8 Operations Summar Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/28/2000 Contractor Name: NORDIC CALIST^ Rig Release: 9/29~2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task. SUb' Phase. .' · Description of Operations · . . Code · 9~20~2000 12:15 - 13:30 1.25 DRILL PROD1 Pull up to window and get 1 click. RIH and drill ahead to 11060'. Having trouble getting and/or holding orientation. Now running Iow on FIo-Pro with losses at 1.5 bpm. Pull up into 5 1/2" liner for 3 clicks - got 2. 13:30 - 15:15 1.75. DRILL PROD1 POH to check BHA/bit while aphron mud system is mixed and delivered. 15:15 - 16:00 0.75 DRILL PROD1 OOH. Stand back injector. Change out MWD probe and orienter. Reduce motor bend to 2 deg. Bit OK. 16:00 - 16:45 0.75 DRILL PROD1 MU BHA #3 - Smith M09RR, 2 deg short radius motor, MWD/GR. 16:45 - 18:30 1.75 DRILL ' PROD1 RIH. Shallow test MWD - OK. RIH thru window at 10850' i 18:30 - 19:30 1.00 DRILL PROD1 Circulate in MI Aphron FIoPro system to reduce losses. Circulate at 2.1 BPM wi 1.1 returns. Circ at 2.5 BPM wi 1.25 returns. Pump = 3150 psi, No reduction in losses seen. 19:30 - 19:40 0.17 DRILL PROD1 Orient TF to 60R. 19:40 - 20:10 0.50 DRILL PROD1 Drilling, 2.5/1.0 BPM, 3200 psi. 60R. 1.5 BPM Aphron mud loss. No C initial reduction in mud loss with Aphron mud. Stop drilling, lower pump O(~ rate to reduce losses while trying to generate more aphrons with rig pit system. ~. 20:10 - 22:00 1.83 DRILL PROD1 Circulate at 0.810.5 BPM while shearing Aphron FIoPro at surface. ,..'3 POOH slow while shearing Aphrons. inc. circ rate to 1.510.6 BPM. ~ pump press = 2120 psi. pump 1.0 / 0.6 BPM at 1800 psi. Surface sample of Aphron FIoPro = 8.3 PPG at 0 psi, Density = 8.73 ppg at 1800 psi. Shearing mud at surface Pump 1.610.7 BPM at 2150 psi. Pump 2.510.9 BPM at 3150 psi. 22:00 - 22:30 0.50 DRILL PROD1 Circ. at 1.0/0.6 BPM at 1800 psi. Cont. to shear Aphron mud with pit jet pumps and centrifuge. Pull up into liner at 10600 f. 22:30 - 00:00 1.50 DRILL PROD1 Stop circulation down hole to reduce losses. Shear Aphron mud with centrifuge and jet pumps in rig pits. 9/21/2000 00:00 - 01:00 1.00 DRILL PROD1 Shear mud in rig pits. Load additional 220 bbl Aphron FIoPro. No downhole circ. for 2 hrs. 01:00 - 02:00 1.00 DRILL PROD1 RIH to 10800 ft. Pump 1.0 BPM ! 0.7 returns, 50 ft above window. pump 1.5 BPM 10.9 returns, pump = 2200#, Mud wt = 8.2 - 8.3 ppg at 0 psi, 8.7 ppg at 30 psi. Circ. at 2.0 / 1.1 returns, 2820 pump press at 10800 ft. 02:00 - 02:20 0.33 DRILL PROD1 RIH to TD. Start mixing Form-A-Set pill. 02:20 - 02:30 0.17 DRILL PROD1 Orient to 66R. 02:30 - 03:00 0.50 DRILL PROD1 Drilling, 66R, 2.3~0.9 BPM, 3000 psi, Stop drilling at 11,099 ft. 03:00 - 03:50 0.83 DRILL PROD1 Circ. at 0.7 / 0.5 BPM while wait on Form-A-Set pill. 03:50 - 04:26 0.60 DRILL . PROD1 Pump 25 bbl Form-A-Set pill. 1.9 / 0.7 BPM. 2940- 3800 psi, Displace with Aphron FIoPro. 1.9 / 0.8 BPM, 3550 psi. 04:26 - 05:00 0.57 DRILL PROD1 Lay in FAS pill at 1.0 BPM, 0.7 returns, pull at 40 FPM. lay in 6 bbls. from 11040 - 10840 ft. close choke. Bit at 10840 ft. Sqz in Formaset 3ill at 1 BPM up to 700# SIWHP, slow pump to 0.5 BPM [680 psi SIWHP], and sqz total of 12 bbls to formation. FSIWHP=660 psi. Open choke slowly and hold 100 psi WHP with choke. Lay in 5 bbls pill at 50 FPM. Top of pill at 10590 ft. Pull up to 10,400 ft. Stop pump. Shut in well. 05:00 - 08:30 3.50 DRILL PROD1 Wait on Form-A-Set pill to set up. 08:30 - 09:30 1.00 DRILL PROD1 RIH to clean out Form-a-Set pill and check losses. Orient to get thru window. Clean out past initial loss zone at 10940'. Started losing immediately - 0.5 bpm loss rate: 2.3/1.8 bpm. 09:30 - 10:00 0.50 DRILL PROD1 'RIH to bottom. Losses have increased to 1.5 bpm. 2.6/1.1 bpm. 3550 psi. Orient for 60R. Printed: 11/3/2000 2:14:53 PM LU BP EXPLORATION Page 3 of 8 Operations Summa Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/28/2000 Contractor Name: NORDIC CALISTA Rig Release: 9~29~2000 Group: COIL Rig Name: NORDIC 1 Rig Number: "SUb Phase DesCription of Operations . Date From-To Hours Task Code .' . . . 9/21/2000 10:00 - 10:15 0.25 DRILL PROD1 Drill ahead with sustained losses of 1.5 bpm. ROP = 140 fph. 10:15 - 10:45 0.50 DRILL PROD1 Orient around for 40-50R. 10:45 - 11:45 1.00 DRILL PROD1 Drill ahead. ROP 100-150 fph. Losses are coming down slightly to 1.25 bpm - drill cuttings from fast ROP healing loss zone? 11:45 - 12:15 0.50 DRILL PROD1 Continue drilling ahead. Losses have healed to 0.4 bpm. 2.5/2.1 bpm. 3750 psi. 70R. ROP = 150 fph. 12:15 - 12:45 0.50 DRILL PROD1 Short trip up to window - started stacking weight when drilling. 12:45 - 14:15 1.50 DRILL PROD1 Drill ahead. Poor ROP - still stacking wt. Start new FIo-Pro with 6% LubeTex downhole to help sliding. ROP improved once new mud ~1~ reached open hole. 2.5/2.1 bpm. 4000 psi. ROP = 100 fph. TF -- 66R. Get 1 click. 14:15 - 14:30 0.25 DRILL PROD1 Orient around. 14:30 - 15:15 0.75 DRILL PROD1 Drill ahead. 2.512.0 bpm. 3500 psi. 77R. Build and turn OK. C,~ 15:15- 17:15 2.00 DRILL PROD1 POH for new bit and motor. 17:15 - 19:00 1.75 DRILL PROD1 Lay out drilling BHA. Cut off 200 ff of CT for fatigue life management. .'3 ~ 19:00 - 19:45 0.75 DRILL PROD1 M/U CTC, pull/press test. M/U MWD BHA #4 with 1.1 deg motor with :~=" ~ DS49HGJU Bit #2. 19:45 -21:30 1.75 DRILL ~PROD1 RIH with MWD BHA#.4. Shallow test Sperry tools. Cont. RIH. 21:30 - 22:00 0.50 DRILL PROD1 Log tie-in pass across RA tag at 10859 ft. No correction, on depth. 22:00 - 22:30 0.50 DRILL PROD1 RIH to TD. Hole in good condition. 22:30 - 00:00 1.50 DRILL PROD1 Drilling, TF=95R, 2.5~2.2 BPM, 3200 psi, 100 FPH, 90 deg incl. Depth = 11,435 ft. 9~22/2000 00:00 - 00:30 0.50 DRILL PROD1 Drilling, TF--100R, 2.5/2.3 BPM, 3200 psi, 110 FPH. 89 deg incl. Depth = 11,475' 00:30 - 01:10 0.67 DRILL PROD1 Short trip to window. RIH to TD. Hole in .good condition. 01:10 - 01:40 0.50 DRILL PROD1 Drilling, 105R, 2.5/2.3 BPM, 3200 psi, 120 FPH, 87 deg incl. Depth = 111,535 ft. Good clean sand. 01:40 - 02:00 0.33 DRILL PROD1 I Orient TF to 85R. 02:00 - 03:45 1.75 DRILL PROD1 Drilling, 85R, 2.5/2.2 BPM, 3200 psi, 80 FPH, 87 deg incl. Depth = 11630 ft. 03:45 - 04:50 1.08 DRILL PROD1 Short trip to window. RIH to TD. Hole in good condition. 04:50 - 06:00 1.17 DRILL PROD1 Drilling, 90R, 2.5~2.2 BPM, 3100 psi, 88 Deg. Incl. 120 FPH. Depth -- 11700 ft. 06:00 - 06:30 0.50 DRILL PROD1 Drilling, 154R, 2.5~2.0 BPM, 3100 psi, 88 Deg. Incl. 120 FPH. Depth--11,750 ft. 06:30 - 07:15 0.75 DRILL PROD1 Short trip to window. Hole in good condition. 07:15 - 07:30 0.25 DRILL PROD1 Make tie-in pass to RA tag. No correction. 07:30 - 07:45 0.25 DRILL PROD1 RIH to bottom. Hole condition good. 07:45 - 09:15 1.50 DRILL PROD1 Drill to 11770'. Hole angle should now be +/- 80 deg proj. Get clicks for 90L. Drill ahead to 11864'. 2.6/2.0 bpm. 3500 psi. 82L. ROP -- 150 fph. 09:15 - 10:15 1.00 DRILL PROD1 Drill to 11900'. 2.511.8 bpm 3600 psi. 77L. ROP = 80-120 fph. Losses have increased to 0.7 bpm. 10:15 - 11:15 1.00 DRILL PROD1 Wiper trip up to window. Hole condition good. RIH to bottom. Start taking on new FIo-Pro to build pit vol. 11:15 - 11:30 0.25 DRILL PROD1 Orient around for 90R. 11:30 - 14:00 2.50 DRILL PROD1 Drill to 12038' - rathole below 12000'. Losses increased rapidly to over 1.7 bpm. Attempt to drill ahead but losses are too high. Suspect we have drilled in to another fault at 12038'. 14:00 - 14:45 0.75 DRILL PROD1 POH into window and wait on mud and forward plan. 14:45 - 15:30 0.75 DRILL PROD1 Wait on plan forward. Circ across top of hole. Static loss filling across top of hole is 12 bph. 15:30 - 16:00 0.50~ DRILL PROD1 Tie in to RA tag on whipstock at 10859'. Corr'n (+4'). Printed: 11/3/2000 2:14:53 PM BP EXPLORATION Page 4 of 8 Operations Summa Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/28/2000 Contractor Name: NORDIC CALISTA Rig Release: 9/29/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To' HoUrs .Task Sub ' ' Code Phase .... ' . . .. Description of O'perations . .. .. · . 9/22/2000 16:00 - 16:45 0.75 DRILL PROD1 RIH to bottom to check loss rate. No change when going past upper loss zone at 10940'. On bottom - 2.5 in 1.5 out. Drill to 12,045' with losses 2.5 in 1.4 out. Still believe most recent losses are on bottom but ,?~ have partially healed. Final TD=12,045 ft BKB. ~ ~' 16:45 - 19:00 2.25 DRILL PROD1 POH to PU inflatable bridge plug. 19:00 - 19:30 0.50 DRILL PROD1 Lay out drilling BHA. 19:30 - 20:00 0.50 CASE PROD1 Safety Meeting with all personnel. 20:00 - 20:30 0.50 CASE PROD1 M/U Baker 2.5" Open Hole IBP with 15 ft' of 2 3~8" EUE spacer pup jts below. MlU Baker running tools. BHA total length = 33.32 ff. . 20:30 - 22:30. 2.00 CASE PROD1 RIH with Baker open hole IBP to stop fluid loss at TD. ~ ' 22:30 - 00:00 1.50 CASE PROD1 Sat down wt. on profile in Baker 7"x4.5" production Packer / anchor ;~ ~ while RIH at 10,358 ft. Work up and down. Free to slide 1 ft up and down. _~ 2 3~8" EUE collar [3.1" OD with square shoulders] on pup jt below 2.5" IBP catching on ID profiles inside.production packer I anchor. Work free going down. Unable to pull up past 10,358 ft. RIH into 5 1/2" liner.. 9~23~2000 00:00 - 02:00 2.00 CASE PROD1 Wait on mud prior to run in open hole with Baker 2.5" IBP. 02:00 - 03:00 1.00 CASE PROD1 RIH with IBP. No wt. loss going thru window. RIH and tag TD at 12,046 ft CTD. Circ. 1.6 BPM with 0.4 BPM returns. 03:00 - 05:10 2.17 CASE PROD1 Press test HB&R line. Pump 30 bbls 2% KCL water at 185 F. at 1.6 BPM / 0.4 returns. Drop 0.5" steel ball. Pump 15 BBL hot 2 % KCL water. Displace with FIoPro. Ball on seat at 63 bbls. Inflate IBP to 2000 psi. wait 10min. Pull up to 46K. Element set. Set down. Inflate to 2300 psi. wait 10 min. inflate to 2600 psi. / 5 min. 3100~/5min. Press up and release from IBP 05:10 - 05:30 0.33 CASE PROD1 Circ. 1.6 BPM / 1.1 BPM returns. Circ. 2.01 1.5 BPM returns. 05:30 - 07:45 2.25 CASE PROD1 POOH with Baker running tools. Lower lost circulation zone at TD is corrected, still have losses at top zone at 10,970 ft. PBTD [top of IBP] = 12,021 ft BKB. 07:45 - 08:00 0.25 CASE PROD1 OOH. Stand back injector. LD IBP running tools. 08:00 - 08:15 0.25 CASE PROD1 RU to run 2 7/8" liner. 08:15 - 08:30 0.25 CASE PROD1 Safety meeting and hazard identification prior to running liner. 08:30 - 10:30 2.00 CASE PROD1 Run 45 jts 2 7~8" 6.16# L-80 STL liner. 10:30 - 11:30 1.00 CASE PROD1 MU deployment sleeve and CTLRT. Install Baker coil connector. Pull & pressure test same. MU injector. 11:30 - 13:45 2.25 CASE PROD1 RIH with liner. Getting returns but hole calculated to be taking +/- 0.25 bpm while RIH. Tag bottom at 12028' and correct to 12021' (-7'). 13:45 - 15:15 1.50 CASE PROD1 Load 5/8" ball in reel manifold and pump to coil. Circ and displace ball downhole with mud. 2.0/1.5 bpm. 2150 psi. Ball did not go over gooseneck initially. Keep displacing. Ball on seat. Shear at 3900 psi. PU and confirm released from liner- OK. 15:15 - 18:15 3.00 CASE PROD1 Displace well to 2% KCI using HB&R to heat fluid to 140 deg F to keep IBP inflated. 2.9/2.3 bpm. 2600 psi. Pumped 450 bbl total. 18:15 - 20:00 1.75 CASE PROD1 Circulate while transferring cool fluid to pits to pump ahead of cement. 1.0/0.6 bpm. Rig up DS cement van / lines. 20:00 - 20:30 0.50 CEMT PROD1 Safety Meeting with all personnel. 20:30 - 21:05 0.58 CEMT PROD1 Batch up 15.8 PPG, G Cement with Latex. At wt at 20:50 hrs. Press test cement line. 21:05-22:15 1.17 CEMT PROD1 Stg 18.0 bbl, 15.8 ppg cement. Insert dart. Flush lines. Displace dart with 2% KCL water using rig pumps. 2.9 BPM / 2.4 BPM returns, 2700psi. Land on LWP at 58.1 bbl, sheared at 3500 psi. Displace Printed: 11/3/2000 2:14:53 PM BP EXPLORATION Page 5 of 8 Operations Summa Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9~28/2000 Contractor Name: NORDIC CALISTA Rig Release: 9~29~2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Phase Description of Operations. Date From-To Hours Task Code 9~23/2000 21:05 - 22:15 1.17 CEMT PROD1 CMT at 3.0 BPM. 12.6 BPM returns. Bumped plug at 65.9 bbls with 1800 psi. Hold press OK. Test floats. OK. Press up to 1800 psi. Sting out. Jet top of liner. 22:15 - 23:00 0.75 CEMT , PROD1 Circ. cement returns to surface. Did see cement returns. 23:00 - 00:00 1.00 CEMT PROD1 'POOH with Baker CTLRT BHA. 9/24/2000 00:00 - 01:00 1.00 CEMT PROD1 POOH with Baker CTLRT. Lay out tools. 01:00 - 01:30 0.50 CEMT PROD1 Safety Meeting with all personnel. 01:30 - 03:15 1.75 CEMT PROD1 P/U SWS 2.20" carrier with nozzle, 46 jts of CSH workstring, DS package. Total BHA length = 1,488.5 ft. 03:15 - 06:00 2.75 CEMT PROD1 RIH with nozzle BHA on CT to clean out liner. Tagged PBTD of 11,988 ft BKB at 12,007 ft CTD. No cement seen in liner. 06:00 - 07:45 1.75 CEMT PROD1 POOH with cleanout BHA. Circ. 1.5 / 1.3 BPM with KCL water with coil stationary. 07:45 - 09:00 1.25 CEMT PROD1 Stand back injector. PJSM. Rack back 23 stds 1 1/4" CSH workstring. 09:00 - 09:30 0.50 EVAL PROD1 PJSM and hazard ID prior to PU memory CNL and loading RA source. 09:30 - 10:15 0.75 EVAL PROD1 RU memory CNL/GR in running sleeve and load source. 10:15 - 11:00 0.75 EVAL PROD1 RIH with 23 stands of 1 1/4" CSH workstring. 11:00 - 13:00 2.00 EVAL PROD1 MU coil conn& stab injector. RIH with CNL. 13:00 - 14:00 1.00 EVAL PROD1 Log down from 10550' to PBTD at 11988' at 30 fpm. Tag at 12008' and correct to 11988'. 14:00 - 14:45 0.75 EVAL PROD1 POH logging up at 30 fpm laying in 12 bb1120k LSRV perf pill in liner. 14:45 - 15:00 0.25 EVAL PROD1 Attempt to pressure test liner and lap to 2000 psi - no go. Pressure dropped off to 200 psi in 5 min. 15:00- 16:45 1.75 EVAL PROD1 POH. .~...~:1~ 16:45 - 18:00 1.25 EVAL . PROD1 OOH. Stand back injector. Rack back 1 1/4" CSH. PJSM. Remove RA source & LD CNL tool. ~ 'ES New PBTD based on CNL/GR Memory log is 11,993 it BKB. Top of 2 7/8" liner deployment sleeve is correct at 10,643 ft BKB. 18:00 18:30 0.50 CASE LSTR PROD1 Crewchange and PJSM for running LTP. ~ 18:30 - 20:30 2.00 CASE LSTR PROD1 M/U Baker seal assembly, Iocator sub, XO's, 9 jts-2 7/8" STL tubing, 2 XO's, Baker 4 1/2" KB Packer and running tools. I BHA total length = 354.0 ft. 20:30 - 22:30 2.00 CASE PROD1 RIH with liner top packer, 2 7~8" tubing and seal assembly to repair liner lap leak. Circ. at 0.5 BPM, 120 psi. 22:30-00:00 1.50 CASE PROD1 Upwtat10550ft=41K. Dwnwt=18K. RIH slowly with 0.5 BPM pump. Sting into liner deployment sleeve at 10651.5 ft. RIH and set down 10K at 10659'. Pull to 1.5 ft above pickup at 10650ft. Flag pipe. Pull out and re-sting into sleeve to confirm depths. OK. Sting out. Drop 5~8" steel ball. Displace over guide arch [30 bbls].. Let ball fall on seat. Sting in. Stack wt, Pick up to 1 ft off sleeve. Set packer slips with 2800 psi. Stack 10k down wt to energize element. 9/25/2000 . 00'.00 - 02:00 2.00 CASE PROD1 Test packer seal with 1000 psi down back side. Leaking. Repressure and set down 15K to energize packer element. Still leaking, Pull 10 K over. Slips still set. Set down 15 K and pressure up to 2800 psi. Still leaking. Unable to get packer element to seal. 02:00 - 02:45 0.75 CASE PROD1 Pull release packer with 88,000 lbs up wt [42 K normal up wt] 02:45 - 06:00 3.25 CASE PROD1 POOH to inspect Baker KB Packer. Fill across top with KCL water, 06:00 - 07:30 1.50 CASE PROD1 Lay out packer, lay out 9 its tbg and seal assembly. All 4 slip segments and 1 1/2 rubber elements are missing. 07:30 - 09:30 2.00 REMCM'~ PROD1 Wait on delivery of motor & mill from Baker. 09:30 - 11:00 1.50 REMCM'~'PACK PROD1 MU 2.26" mill & 1 11/16" motor, disconn, 1 1/4" CSH. RIH 11:00 - 12:30 1.50 REMCM'~'PACK PROD1 RIH with mill and motor. 12:30 - 12:45 0.25 REMCM;'PACK PROD1 Wash down to 10538'. Do injectivity test into lap. PU wt 39500~. 1.1 Printed: 11/3/2000 2:14:53 PM BP EXPLORATION ' Page 6 of 8 Operations Summa Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/2812000 Contractor Name: NORDIC CALISTA Rig Release: 9/29/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Sub. · Date From-To Hours Task Phase Description of Operations COde · · . 9/25/2000 12:30 - 12:45 0.25 REMCM'I'PACK PROD1 bpm {~ 750 psi. 1.5 bpm ~ 775 psi. 12:45 - 14:00 1.25 REMCM'~'PACK PROD1 Wash across liner top 4 passes. Saw TeL at 10665' uncorr but no evidence of debris at TeL. Continue washing in hole 1.9 bpm @ 3150 psi. Took slight wt at 11445'. Cent to btm - no problems. 14:00 - 16:30 2.50 REMCM~'PACK PROD1 POH. Did not see any overpulls or drag. Wash across TeL and go back inside. No overpulls or drag. POH for cementing nozzle and BHA. 16:30 - 18:30 2.00 REMCM~'PACK PROD1 OOH. Stand back injector. PJSM. Rack back 1 114" CSH. LD motor and mill. · ~1~ 18:30 - 19:15 0.75 REMCM"PACK PROD1 MU cementing nozzle, 2jts 2 3/8" PH6, Dowell package. I', _~~ 19:15 21:00 1.75 REMCM"PACK PROD1 RIH and Tag top of liner at10647 ff. Correct to10643 ff. ::::)~ 21:00 21:15 0.25 REMCM"PACK PROD1 Safety Meeting with all personnel. ~. 21:15 - 22:05 0.83 REMCM"PACK PROD1 Batch 15 BBLS, 15.8 PPG G CMT with latex and 15 PPB aggregate in ~ last 10 bbls. CMT at wt at 21:55 hrs. "-'- ~:~ 22:05 - 22:40 0.58 REMCM"PACK PROD1 Stg 15 BBL CMT. 15.9 ppg on densiometer. Add 15 PPB agg. to last 10 bbl slurry. 1.0 / 1.0, 600 psi. Zero in totalizer. Pump 5 bbl water. Displace with rig pumps using 2 % KCL water. 22:40 - 00:00 1.33 REMCM' 'PACK PROD1 CMT at nozzle. Sqz away 10 bbls at 1.0 - 0.5 BPM. SIWHP--800, Open choke slowly and lay in last 5 BBL CMT at 1 BPM. Pull to safety. Wait 20 min. Close choke and SQZ 1 bbl cmt away. SIWHP=880, Sqz 1 bbl, SIWHP--1100. Press holding steady. 9~26~2000 00:00 - 00:40 0.67 REMCM' 'PACK PROD1 SQZ 1/2 bbl and hole 1260 psi WHP for 20 min.: Good test. RIH and jet out cmt down to 10630 ff [10 ft above liner top]. 00:40 - 03:00 2.33 REMCM' 'PACK PROD1 POOH while chasing cement contaminate to surface. LD cementing BHA. 03:00 - 03:15 0.25 REMCM'I'PACK PROD1 M/U 2.25" mill and motor. 03:15 - 05:45 2.50 REMCM'I*PACK PROD1 RIH with 23 stands of CSH workstring. RIH with BHA on CT. 05:45 - 08:00 2.25 REMCM'I'PACK PROD1 Tag firm cement at 10656 ft CTD. Drill cement. Multiple stalls at 10661' - TeL. Finally made progress inside deployment sleeve. 08:00 - 09:15 1.25 REMCM'I'PACK PROD1 ~ Continue washing down inside liner. Tag bottom at 12000' uncorrected. 09:15 - 10:00 0.75 REMCM'I'PACK PROD1 ' POH to liner top 10:00 - 12:00 2.00 REMCM'I'PACK PROD1 Wash up and down across liner top and make dry passes to check if clean - OK. 12:00 - 13:00 1.00 REMCM']'PACK PROD1 RIH to PBTD while displacing 15 bbl perf pill into CT and chase to motor. 13:00 - 14:00 1.00 REMCM'I'PACK PROD1 POH above TeL laying perf pill in liner. 14:00 - 14:45 0.75 REMCM'~'PACK PROD1 Pressure test liner and lap to 2000 psi for 30 min - good test. 14:45 - 18:30 3.75 REMCM']'PACK PROD1 POOH with motor I mill. Stand back CSH workstring. Lay out motor I mill. 18:30 - 21:00 2.50 BOPSUI;.PERS PROD1 Perform weekly BOPE press I Function test and swab leaked, we DSM to service 21:00 - 23:59 2.98 BOPSUI; PROD1 Resume BOPE test 9~27~2000 00:00 - 02:30 2.50 PERF PROD1 Finish weekly BOPE test. Witness waived by AOGCC 02:30 - 02:45 0.25 PERF PROD1 Safety mtg re: perf 02:45 - 03:20 0.58 PERF PROD1 RU tools. MU 8 2" SWS perf guns and blanks 03:20 - 04:00 0.67 PERF PROD1 MU 23 stands CSH workstring 04:00 - 05:40 1.67 PERF PROD1 RIH w/CT, 40.5k @ TeL. RIH in liner and had several set downs from 11130- 11218'. Tite @ 11224' 05:40 - 08:45 3.08 PERF PROD1 POOH filling from BS. Stand back 23 STDS, CSH workstring 08:45 - 09:00 0.25 PERF PROD1 Safety Meeting. 09:00 - 09:45 0.75 PERF PROD1 Lay out SWS 2" perf guns. 09:45 - 10:00 0.25 PERF FILL PROD1 M/U 2.13" motor, 2.30 mill, circ sub and hyd disc. to CIO fill. 10:00 - 11:15 1.25 PERF FILL PROD1 RIH with 23 stds CSH workstring. M/U DS BHA. BHA total length = Printed: 1113/2000 2:14:53 PM BP EXPLORATION Page 7 of 8 Operations Summa Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17/2000 End: 9/28/2000 Contractor Name: NORDIC CALISTA Rig Release: 9/29/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: . Sub' Phase , DeScription of Operations , · Date FrOm-To HoUrs Task Code 9/27/2000 10:00- 11:15 1.25 PERF FILL PROD1 1479.6 ft. 11:15 - 13:15 2.00 PERF FILL PROD1 RIH with CT. Tag top of liner. 13:15 - 14:45 1.50 PERF FILL PROD1 Stall at liner top 3 times, ream 30 ft interval. RIH at 20 FPM with 1.7 BPM pump. Circ. 60 BBL, very high visc. [150,000 cp] Flopro pill to clean liner. Saw some wt loss at 11,220-11,300 ft. Did not appear to be junk, no overpull or sticking. Most likely cement cuttings in liner from liner top cement squeeze. 14:45 - 15:30 0.75 PERF FILL PROD1 Tag PBTD at 11990 ft CTD. POOH chasing high vis FIoPro to surface. Pull to 30 ft above liner top. Ream top of liner area. Enter top of liner with no wt loss or motor work. 15:30 - 17:00 1.50 PERF FILL PROD1 RIH to PBTD. Lay in 30 BBL very high visc. FIoPro pill from 11,993' to 200 ft above top of 2 7/8" liner. 17:00 - 19:00 2.00 PERF FILL PROD1 POOH with motor / mill. 19:00 - 19:30 0.50 PERF PROD1 Standback CSH workstring 19:30 - 19:40 0.17 PERF PROD1 Safety mtg re: perf 19:40 - 20:00 0.33 PERF PROD1 RU tools. MU 8 2" SWS perf guns and blanks 20:00 - 20:45 0.75 PERF PROD1 MU 23 stds CSH workstring 20:45 - 22:35 1.83 PERF PROD1 ~RIH w/CT to PBD at 11993', confirm 42K. Position to shoot 22:35 - 23:25 0.83 PERF PROD1 Load CT wi 15 bbls fresh FIo Pro, 5/8" steel ball. Displace w/2% KCl 23:25 - 23:59 0.57 PERF PROD1 Guns fired at 3600 psi, 2 bbl loss. POOH 42K filling from BS 9/28/2000 00:00 - 01:15 1.25 PERF PROD1 Finish POOH after perforating 01:15 - 03:45 2.50 PERF PROD1 LD CSH workstring 03:45 - 04:00 0.25 PERF .PROD1 Safety mtg re: perf 04:00 - 06:00 2.00 PERF PROD1 LD perf guns, all shots fired. Load out guns 06:00 - 08:00 2.00 RIGD PROD1 FRZ protect CT. 08:00 - 10:00 2.00 RIGD PROD1 Grease/inspect injector chains. 10:00 - 12:00 2.00 RIGD PROD1 Change out CT pack-off and press test. 12:00 - 18:00 6.00 RIGD PROD1 General rig maintenance. 18:00 - 18:30 0.50 RIGD PROD1 Safety Meeting. 18:30 - 20:00 1.50 RIGD PROD1 General rig maintenance 20:00 - 21:00 1.00 RIGD PROD1 RIH w/CT pumping MeOH. POOH leaving top 2000' freeze protected with MeOH 21:00 - 23:59 2.98 RIGD PROD1 Secure tree valves. ND BOPE. Install tree cap and test. Rig released at 0000 hrs 9~29~00 Printed: 11/3/2000 2:14:53 PM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: 15-34 Common Well Name: 15-34 Spud Date: 4/28/1994 Event Name: REENTER+COMPLETE Start: 9/17~2000 End: 9~28~2000 Contractor Name: NORDIC CALISTA Rig Release: 9/29~2000 Group: Rig Name: NORDIC 1 Rig Number: SUb :.. Date. From'- To Hours Task. Code Phase Description of Operations 9/19/2000 04:00 - 05:00 1.00 PROD1 MU window milling BHA. Printed: 11/3/2000 2:14:53 PM 04-Oct-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-34A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,817.37' MD 10,850.00' MD 12,045.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED OCT Alisa git& gas I~ms. ~mmi~km Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount ~ Commissioner THRU: Blair Wondzell ~ P.I. Supervisor q{~¢~O~ FROM: JeffJones-'~ ~e_~ ~.. Petroleum Inspector NON- CONFIDENTIAL DATE: September 18, 2000 SUBJECT: Blowout Preventer Test Nordic Rig #1 BPX/DS-15 15-34A 200-137 PBFIPBU Operator Rep.: Dick Maskel_l Contractor Rep.: Shawn McKiernan Op. phone: 659-4433 Rig phone: 659-4434 Test Pressures Rams: 250/350q. .Annular: 250/2500 PIF PIF Location Gen.: P Well Sign P Housekeeping: P ,, Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size/Type PIF Stripper NIA P Annular Preventer 1 7 1116 P #1 Rams 1 Blind/Shear P #2 Rams 1 2 318 PIS P #3 Rams 1 2 7/8 PiS P #4 Rams 1 2 318 Pipe P #5 Rams NIA Choke La. Valves 1 3 '1/8 P HCR Valves 1 3 118 P Kill Line Valves 2 2 1116 P Check Valve 1 2 1116 P CHOKE MANIFOLD: Quantity P/F No. Valves 13 F Manual Chokes 1 P Hydraulic Chokes 1 P Op. e-mail: pbuctdsupervisor~bp.com Rig e-mail: Quantity PIF NIA NIA NIA 1 P Visual Alarm P P P P P P P P P P Choke: 250/3500 Upper Kelly Lower Kelly Ball Type Inside BOP MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Inside Reel valves Quantity PIF 1 P ACCUMULATOR SYSTEM: Time/Pressure PIF System Pressure 3050 P Pressure After Closure 2000 P 200 psi Attained 20 sec. P Full Pressure Attained 2 mia P Blind Switch Covers: All P Nitgn. Bottles (avg.): 3{~2000 P Monda% September18~ 2000,'., I traveled to BPX's PBU DS-15 to witness the initial BOPE test on Dowell Schlumberger/Nordic Pig #1, prepare§ to drill well 15-34A. The test lasted ? hours and I observed one failure. Problems with the test pump bleed valve, a leak at a pressure sending unit on the choke manifold and rigging up to test the inside reel valve on the coiled tubing contributed to the length of the test time. The leaks on the choke manifold sonding unit and test pump were repaired while ! was on location. Fluid was also found to be leaking from the bottom of the mud pits while I was on location. A tank placed under the leak was able to contain the leaking fluid. BPX representative Dick Maskell indicated to me that he is working on this problem, and will have it corrected. Summary: I witnessed the initial BOPE test on DS/Nordic Pig #1 drilling BPX's welllS-34A. Forty-one components were tested; one failure witnessed. Total Test Time: 7 hrs., cc: PBU Drla. Ency. Number of failures: 1_ Attachments: none BOP Nordic1 9-18-00 JJ1 .xls 9~20/00 ALASKA OIL A~D GAS CONSERYA~ION CO~ISSION' TONY KNOWLE$, (~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Pmdhoe ay Unit 15-34A BP Exploration (Alaska) Inc. Permit No: 200-137 Sur Loc: 1428'SNL, 945'EWL, Sec. 22, T1 IN, R14E, UM Btmhole Loc. 99'NSL, 1132'EWL, Sec. 14, T1 IN, 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 by law from other governmental agencies, and does not authorize condUcting drilling operations until all other required permitting determinations are made. ,. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hourS) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given' by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerelyl Commissioner BY ORDER OF THE COMMISSION DATED this ! q_.-4~, day of September, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. j. ('" ALAS .)IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Reddll 1 lb. Type of well Re-Entry I-I Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas [][] SingleStratigraphiCzone Test [][] MultipleDevel°pmentzone Oil I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65.45' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ~,~..~,~ ~ ADL 028307/~t~ .4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1428' SNL, 945' EWL, SEC. 22, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 485' NSL, 1189' EWL, SEC. 14, T11N, R14E, UM 15-34A Number 2S100302630-277 At total depth 9. Approximate spud date 99' NSL, 1132' EWL, SEC. 14, T11N, R14E, UM 09/17/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028306, 1132' MDI No Close Approach 2560 11694' M D / 8821' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10870' Maximum Hole Angle 86 o Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig! 18. Casing Program "- Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin.cl Weiaht Grade Couplin.q Len,qth MD TVD MD TVD (include sta.qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 3519' 8175' 6471' 11694' 8821' 59 sx Class 'G' I~ ~:[.~.~! 19. To be completed for Redrill, Re-entry, and Deepen Operations. ' Present well condition summary Total depth: measured 11310 feet Plugs (measured)S,[P1 ~2000 true vertical 9035 feet Effective depth: measured 11232 feet Junk (measured) ~ka 1~ & Gas Co,is4 true vertical 8962 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3777' 10-3/4" 1100 sx PF 'E', 375 sx Class 'G' 3813' 3519' Intermediate Production 10540' 7-5/8" 532 sx Class 'G' 10572' 8353' Liner 896' 5-1/2" 130 sx Class 'G' 10414' - 11310' 8210' - 9035' Perforation depth: measured 11080'-11110', 11118'-11124', 11132'-11142' 0 ~ I ~ I ?\li~.~ L. true vertical 8821' - 8849', 8856' - 8862', 8869' - 8878' 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: Terrie Hubble, 564-4628 21. I hereby certify that the foregoir~ is true and correct to the best of my knowledge . Signed TedStagg ~~ Title CT Drilling Engineer Date i~i~t~'lir¥t.~ li~'~'~ ?"!!~1,' ~"" ~, ', ~ '~'"-'" ..................... I ............... ' ~'.. '"' I' '" '~ ' ..... i,~!, ~.',' ,.~. ~! ,! Permit Number APl Number Approval Date See cover letter ~ -/' ~ 50- 029-22474-01 ~./~, {pr..) for other requirements Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures I~Yes [] No Directional Survey Required l~Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,~ 3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of Approved By D Taylor Sea~'~"~(:.)~.m~ Commissioner the commission Date ~.. Form 10-401 Rev. 12-01-85 Submit In Triplicate .(" BPX 15-34a Sidetrack Summaw of Operations: 15-34 is a poor cycle producer with Iow oil rate and high GOR. The sidetrack, 15-34a, will target lower Zone I at a departure from the original well sufficient to avoid any gas cone associated with the original completion. This sidetrack will be conducted in two phases. Phase 1: Set Whipstock, Downsqueeze cement. Planned for Sept. 14, 2000. · E-Line will set the whipstock at approx. 10,850'. · Service coil will downsqueeze approx. 20 bbls cement to shut off existing perfs. Phase 2: Mill window, Drill and Complete sidetrack: Planned for Sept. 17, 2000. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented liner. Top of 2 7/8" to be approx. 8175' MD with top of liner cement approx. 10,600'MD. This will leave top of liner cement approx. 250 ft above the window. Approx. 12 bbls cement will be used for this liner cement job. 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 completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L cemented liner will be run from TD to approx. 8175' MD. Top of liner cement will be at approx. 10,600' MD. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity Log will be run in open hole. Hazards Production from DS 15 is averaging less than 20 ppm H2S. Lost circulation risk is Iow. Reservoir Pressure Res. press, is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. RECEIVED ARCO ALASKA, INC, TRSV Tubing" NIP Casing PKR [":iJiBiiii""~iii"iJ~":-'"'~':f~'J;~'~'''''''I ...,(4.,-..!..~. Otis XN.Nip.) ..................... j NIP NOGO Liner " Prudhoe Bay 15-34 APl: 500292247400 Well Type: PROD Angle ~ TS: 24 deg ~ 10629 SSSVType: Orig Compltn: 5/20/94 Angle ~ TD: 21 deg ~ 11310 Annular Fluid: Diesel 6.8/8.5 SW Last W/O: 5/20/94 Rev Reason: Picture Reference Log: Ref Log Date: 111/60 Last Update: 4/22/99 LastTag: 11158 TD: 11310ttKB Last Tag Date: 3/28198 Max Hole 48 deg ~16646 · -,, .~ Angle: ....... i~i!~i!~'.,.'.~.~ !~ii:i:i~ i~!ii?:iii:: ::!i ii: i:::~i ~i:i!:i!i:::~';~iiii~!~iiii~ i~: ii,ii': i:i; ::~:!~ ."",; :~i:ii~i:~?~ iii~!~ !i~!:~iiii~;:i!~;!~::~ :i:: ~;~il; Depth Comment 10388 10388' MIN ID = 3.725" (4-1/2 Otis. XN N!p.). ....................................... : ~_".~'~:'~'.~ir~i~-?.~ ~ ~.: i'~ ~:~:: ~ i::~ :L*.~ ~:.". ! $~!:[!:: ;.'~:~-,"..~;::~ :i.?.: :!::::": ::.'..:,':!::.:; 'i:i,: :!~,S!:!':i~.:~:'::::i:i !:~'.":: ::.: ~:~:!::::.q,:.-.:: :}::: :~.'::;::.::.". :' :~}::. ::: '?' :.T.:~ :.~,: .~:: .,.:' ..~ ':~!,~~::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ;~: :~.:.: .:. ;: .: :':: &~.; :.';.:; :::~;: :. :::: ::: ..:.;..:,¢..::..-..:: ...:.:.:~>.~.:...~:.: :.'..:.:.: .:.:.:. :::.: :..:... ". :.: :.;.:.:.'. :-:- ,:+:c. :. · · Date Note 5/20/94 lTL ELM I~ 0: ELM Tubing Tail .(,Not Logged) .............. .... ,~' .~.,~.~:¢.. ~'~ *~,~:~'c.~'e~;, i,>:.:~;~¢.;, r~...*: ~.~*.~:~ ......... .,:.:'~:,:~.>,.'/;'.'.:;' ~,, ,' ,' ':' ,. :' ~';': "':: $: ~'" ::' .'.:::~':~:';'.'::' :::.~:. :'.." ,.. ".. ':..:. :. :.:.:..':,:~ i~:~(~g ~#~:::~et,e.::.):~.~~!i~! i!: ~!:~::.:,!~:~:~!~:~..':'i~!~i:!~,.~!::, i~ ~:::~ :~;~ ::::::~ i~.::~:~:i:i: :~:~: ~:i~i:~::::~::. Depth TVD Type Description ID 2201 2169 TRSV 4-1/2" Camco TRDP SSSV Nipple. Locked out 9122/95. 3.855 10333 8137 NIP 4-1/2" Otis X Nipple 3.810 10354 8156 PKR 7" x 4-1/2" Baker S,*~BL-3 Packer 0.000 10388 8186 NIP 4-1/2" Otis XN Nipple 3.725 10405 8202 NOGO 4-1/2" Otis XN Nipple 3.725 10416 8212 SOSUB 4-1/2" Shearout Sub 0.000 10418 8213 TTL 4-1/2"Tub_.!ni!TailW/LRe-en.,.t~.Guide .~ ,, ~ ~ .,., · . ........ .,,¢ . ~,..~. ~..<~',~..~, ,~ . . ~.~,.~¥:.~; ,~ .., .~.. v. ~.,.~.,. ~ .... ,~,....,~,~ ..~,, .. ...... ~...,,% ~. ...... ~.~.. ~ ........ ~.~...,~ ..,~. ,~..~ ..~....~m~[.~j~.~J..::;,T.-jA~:.:~:~:~'~,.>~...~g~.~:~':,[~,;~.~ ,., >: '.d~.:.>.c ~>~;~:.:~;~`~;~!~`~¢~;~:~:~:;~,~¢~~"~'- ~......,.,..,,..,,,.,..,...... Depth Description Comment 11305 FISH FISH' (2) CA-E-BK-2 (Lost 06/23/95) ~ Size Weight Grade Top Btm Feet Description 10.750 45.50 NT-80 0 3813 3813 Casing 5.500 17.00 13CR-80 10403 11310 907 Liner 7 625 29 70 NT-95 HS 0 10572 10572 Casing Size Weight Grade Top Btm Feet Description 4500 12.60 L-80 ,.0~. ~104~ 8~ 1041~ ,,,.T~bin~ Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Commenl 1 3268 3114 CAMCO (BMGMSPI~ CAMCO DMY 1.0 BK-2 0.000 0 6/24/95 E 2 6110 5116 CAMCO (BMGMSPI~ CAMCO DMY 1.0 BK-2 0.000 0 5/20/94 E 3 8583 6819 CAMCO (BMGMSPI~ CAMCO DMY 1.0 BK-2 0.000 0 5/20/94 E 4 10223 8040 CAMCO (BMGMSPI~ CAMCO DMY 1.0 BK-2 0.000 0 5/20/94 E ; ~ ~,, ~ ~.4 ~,~ ~ :~.'~ ~ ~.~p,~'~' ~:~ ~: '~e~..~ .'~ ..~e~'~.,~.~,,~ e ~ ~ .~:~t ~ ~$ ~:..~:-:~'~"~. ~ ~.~.:':~:~':~.:'~:~, ~%~`~"~:e~.`~`;`~`.~F~.~`>!``~;~:~:~.~:~:~.~>~:C~`~;%~::~":~:~:[:~:~ ;~''~ Interval TVD Zone StatusFeetSPF Date Type Comment 11080 - 8821 - 8649 ZONE O 30 6 7/30/94 IPERF 11110 lB 11118 - 8856 - 8862 ZONE 6 0 3/29/98 APERF 11124 lB 11132 - 8869 - 8878 ZONE O 10 6 7/30/94 IPERF 11142 lB SOSUB ............... E 3 o o :)Ol o~S LUOJ~ eou~s!p A 8 ~ 2 3/8" CT i i I 10,000 psi Pack-Off Lubricator ~ 15-34a CT Drilling & Completion BOP LU 12" 36" 22.5" 1 a" 7 1116" Annular 7 1/16' 5000 psi Blind/Shear 71/16" Pipe/Slip 7 1/16' x 5,000 psi 7 1/16' x 5,000 psi Slips 71/16" Pipe RECEIVED SEP 1 i 2000 Gas Cmos.¢o'" ~,~m.s.~on 2 3/8" 2 7/8" 2 3/8" SWAB OR MASTER VALVE STATE OF ALASKA ALASI~' )IL AND GAS CONSERVATION COl~ 3SION APPLICATION FOR SUNDRY APPROVAL' 1. Type of Request: Ba Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back ~or 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 1428' SNL, 945' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 485' NSL, 1189' EWL, SEC. 14, T11N, R14E, UM At effective depth 518' NSL, 1417' EWL, SEC. 14, T11N, R14E, UM At total depth 521' NSL, 1445' EWL, SEC. 14, T11N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ORIGINAL 6. Datum Elevation (DF or K~B) KBE = 65.45' ,, 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ' 15-34 9. Permit Number 194-063 10. APl Number 50- 029-22474-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary. Total depth: measured true vertical Effective depth: measured true vertical Casing 11310 feet.· Plugs (measured) 9035 feet 11232 feet Junk (measured) 8962 feet Length Size Cemented Structural Conductor 80' 20" 260 sx Arcticset (Approx.). Surface 3777' 10-3/4" 1100 sx PF 'E',. 375 sx Class 'G' Intermediate Production 10540' 7-5/8" 532 sx Class 'G' Liner 896' 5-1/2" 130 sx Class 'G' MD 'rVD 110' 110' 3813' 3519' 10572' 8353' 10414' - 11310' 8210' -' 9035' Perforation depth: measured 11080'- 11110', 11118'- 1.1124', 11132'- 11142' true vertical 8821' - 8849', 8856' - 8862', 8869' - 8878' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10417' RECEIVED SEP 1 1 000 ,Alaska C :'a & Gas Cons. Commiss Packers and SSSV (type and measured depth) 4-1/2" Camco SSSV Nipple at 2201'; 4-1/2" Baker 'SABL-3' packer at 10354' ' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation ~ 15. September 15, 2000 16. If proposal was verbally approved Name of approver Date Approved [] Detailed Operations Program' Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fore~o~g~ is true and correct to the best of my knowledge Sign~ed ,red Stagg~ ~' , Title CT Drilling Engineer. ~ , Date ',',.~:..: ~,¢..,,,.~,~.,~ ,,t~i'~'.'~'.' ~,,~' "¢~" ' ~,'.~ ~ ' .'~'~' ,' ~.'~".~' ~ ''>;~',~.~ ' ' ' ' .... ~ ~.t' :~"'~ ' ~ ' ,~"~ '~!" ~-R' ~'~,~';"~ '~ ~nditions of Approval: NoUN ~mmission ~ mpm~ntative may w~ess Approval No. ~Oo, ' Plug i~egd~ __ BOP Te~'.__ L~fion cleaance ~ Mechani~l IntegrEy Te~ ~ Su~eque~ ~ required 10- Approved by o~er of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate I DATE / CHECK NO' · ~01~33&8 H 173368 ( (,, I VENDOR ALASKASTAT 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GRO,~ DISCOUNT NET )82200 :K082200 100. O0 100. O0 HANDLI CG INST: TERR [E HUBBL£ X46 ~_8 ,, lie A'rrACHE. CHECK IS I# PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 100- OO I OO_ OO ':. ::::.! ::'.:;:':" N~.~ONA.',.L.'.:~ITY:.B.,~K ':.' .]i!. !."7: !. ,;:,::,'::, .,:,.::. ;}' ' .~L."'EVELAN'D, OHIO . '.,: :: ,:,. '::.";: .' '.':::"'. ':.'::':: ':"':::::.' ':.,'"".' .:::i::':.: ~':.',::'.:: ~'::.;:~:i:.' ' . ::::::::::::::::::::: 'L:::i.:i;:,~g3,./.:.? . ::::::::::::::::::::::::::::: ...... ':.i~i7~8: l:'ii'i:''' .:. 412 ." . . ...~ ,"&?:~=.~.8," ,:0i, I, 8038ci5~: OO.°.hh&q"" WELL PERMIT CHECKLI_S./T COMPANY FIELD & POOL ~,~ ~(~_/~-,-~_~ INIT CLASS ADMINISTRATION 1. Permit fee attached. 2. Lease number approl:;ri~t~.~. 3. Unique well name and number .................. 4. Well located in a defined pool .................. DATE, ,~./I.,~z~ 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 ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. " :)3. 24. 25. DATE 26. · ,.(.1, ,'~o~ 27. 28. 29. GEOLOGY WELL NAME IS"-~ ~/~ PROGRAM: exp dev. ~,'/redrll v" serv wellbore sag ann. disposal para req /~//~ . GEOLAREA ~,~C:~/,--~ UNIT# ~,~/~._~._~-~_~) ON/OFFSHORE ~,,?~/ DATE ~.,/t.~ 30. 31. 32. 33. 34. ANNULAR DISPOSAL35. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... (~ N BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~5'~30 psig. N Choke manifold .complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued wlo hydrogen sulfide measures ..... ~_,~/~.~ ~.~ Data presented on potential overpressure zones ........ Seismic analysis of shallow gas zones ........... /;/,~ ~'~ Y N Seabed condition survey (if off-shore) ...... ~/.~.' Y N ' Contact name/phone for weekly progress re--exploratory only] Y N ' With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receivin~g.~ (B) will not contaminate freshwater; o~,,~use drilling waste...~ Y N to surface; ~ ~ (C) will not impair mechanical'~rt~egrit~ll used~e~disposal; Y N (D) will not damage produ~rf~g formation or impair~j~.~overy from a Y N pool; and /~ ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y'"- N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: Z -4 c:\msoffice\wordian~iana\checklist (rev. 02/17/00) ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify 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 ils Scan Usili~y SRevzsion: 3 $ LisLib SRevision: 4 $ Thu Apr 18 2C.:13:14 2302 Reel Header Service name ............. LISTPE Date ..................... 02/04/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library, Tape Header Service name ............. LISTPE Date ..................... 02/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Coments ................. STS LIS Writing Library, Scientific Technical Services Scientific Technical Services Physical EOF Co~ent Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS 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 15-34A 500292247401 BP Exploration (Alaska), Inc. Sperry Sun 18-APR-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-00196 AK-MW-00196 AK-MW-00196 B. JAHN B. JAHN B. JAHN D.MASKELL /R D.MASKELL /R D.MASKELL/R. 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: i. 22 11N 14E 1428 945 65,45 ,00 ,00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4,500 10850,0 ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR, 3. GT=M~I RAY (SGRD} LOGGEE BEHIND CASING FROM !0835' :,'~, 5529' c ~'~ TC i0~5C' MD, 6542' SSTVi. 21=iTAL DATA ONLY IS ~=~'= CORRECTED TC THE PDC LOG ',MCNL GR) WITH A KBE OF 6.5.45' AMSL. THiS WELL KICKS OFF FRO,~: 15-34 AT 10850' MD, 8542' SSTVE (TOP OF WHIPSTOCK ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 3 REPRESENT WELL 15-34A WITH API % 50-029-22474-01. THIS WELL REACHED A TOTAL DEPTH OF 12045' MD, 8810' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 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 10835.5 12011.0 ROP 10866.5 12042.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10835.5 10838.0 10851.5 10858.0 10867.0 10875 0 10886 0 10894 5 10899 0 10901 5 10906 5 10911 5 10914 5 10918 0 10928 5 10936 0 10945.5 10947.0 10952.5 10959.0 10963.5 10974.5 10977.5 10981.0 10985.0 11000.5 11016.5 11038.5 11042.5 11052.5 GR 10835.0 10837.5 10852.0 10858.5 10867.5 10876.5 10888.0 10894.5 10899.5 10903.5 10907.0 10912.0 10914.5 10918.0 10928.5 10937.5 10945.0 10947 0 10951 0 10957 0 10963 0 10975 0 10978 5 10983 0 10987 0 11001 5 11018.5 11045.0 11048.5 11057.5 - EQUIVALENT UNSHIFTED DEPTH ilO6!.f 11093.C 11112 f 11124 { 11175 5 1'191 5 11242 O 11246 5 11252 0 11267 O i1=6. 5 11276 0 11279 0 11294 0 11305 5 11308 0 11311 0 11320 5 11335 5 11340.5 11351.0 11360.0 11366.0 11373.0 11404.0 11416.0 11419.0 11423.5 11425.5 11439.0 11442.5 11450.5 11464.0 11471.0 11472.5 11491.5 11495.5 11506.5 11518.0 11521.5 11529.0 11538.5 11549.0 11576.5 11587.5 11590.0 11613.5 11637.5 11643.5 11645.0 11648.0 11675.0 11686.5 11690.5 11721.0 11730.5 11737.0 11739.0 11757.0 11759.5 11762.0 11777.0 11786.5 11790.0 11791.0 11794.0 11838.0 11850.0 11856.0 11875.0 11876.5 11879.0 11881.0 11067.5 i!09r.5 11101.~ l!!08.C 11119.5 11129.0 '1154.0 11179.5 11195.0 11244.5 ~1250.~ 11256.0 11269.0 11272.5 11277.5 11283.0 11300.0 11311.0 11314.5 11317.0 11327.0 11342.5 11347.5 11360.0 11367.0 11372.0 11380.0 11410.0 11422.0 11424.0 11429.5 11431.5 11444.5 11447.5 11457.5 11470.0 11476 5 11478 5 11497 0 11500 5 11509 0 11521 0 11523 5 11532 5 11542 0 11554 0 11580 0 11591 0 11594 5 11617 5 11640 0 11646 0 11648 5 11650 5 11675 0 11688 0 11692 0 11724 0 11733 5 11739 5 11742 5 11760.5 11762.5 11766.5 11780.5 11789.5 11793.5 11796.0 11798.5 11843.0 11854.5 11860.5 11878.0 11879.0 11881.5 11884.0 11935 5 -196! C 12042~. ~ $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD REMARKS: 11886 11892 11894 11903 11907 11910 11938 11964 12045 BiT RUN NO MERGE TOP MERGE BASE I 10835.0 11060.0 2 11060,5 11325.0 3 11325.5 12045.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point ............. '.Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 1 BOP MWD FT/H 4 I 68 4 2 GR MWD API 4 I 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10835.5 12042 11438.8 2414 ROP MWD FT/H 2.82 2008.66 98.0152 2352 GR MWD APi 16.52 300.39 49.3618 2352 First Reading For Entire File .......... 10835.5 Last Reading For Entire File ........... 12042 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 10835.5 10866.5 10835.5 Last Reading 12042 12042 12011 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER F~.LE NUMBER: 2 Curves -nd l:~ ?.eader data fer ea:k bit run in separate files · ~iT RUN NUMBER: DEPTH iNCREMEKT: .50OC FiLE SUB~,~,RY VENDOR TOSL 2SDE START DEPTH GK 10835.0 ROP 10867.0 LOG HEADER DATA DATE LOGGEE: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (PT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (PT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 11029.5 i1060.C 20-SEP-00 Insite 4.05.2 3.3 Memory 11060.0 MINIMUM ANGLE: 22.4 MAXIMUM ANGLE: 60.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE.CONDITIONS MUD TYPE:' Water Based MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: 9.5 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 141.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Servlse Un~5 Min Max DEFT FT !~S35 !i06C ROF MWDCiC F?:'H 2.62 156.58 SF. MWD21C ;Fi~ '~.64 233.-- First Reading For Entire File .......... 10835 Last Reading Fc~ Entlre File ........... ii06C File Trailer Service name ............. STSLiB,002 Service Sub Level Name,.. Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,003 First Mean Nsam Reading '0947.5 451 10635 37.3023 367 i06~' '6 8218 ~9C 10835 Reading ii06C iI06C Physical EOF File Header Service name ............. STSLIB,003 Service Sub Level Name,,, Version Number ........... 1,0.0 Date of Generation ....... 02/04/18 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: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11030.0 ROP 11060.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING ,TOP TO BOTTOM) VENDOR TOQL CODE TOOL TYPE NGP NATURAL GAM~ PROBE $ BOREHOLE ANE CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CON2ITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): STOP DEPTH 11294.5 11325.0 21-SEP-00 Insite 4,05,2 3,3 Memory 11325,0 67,1 88.0 TOOL NUMBER 034 3.750 AphronICS 8.40 ,0 MUD PH: MUD CHLSP. iDES :PP.~:' : RESISTiViTY ~OHMR.~ AT TEMPERATURE .,DEGF MUi AT !~.EASURED TEMPERATURE {MT': MU.- AU .u~3: CIRCULATING TERMPERATURE: MU-' FILTRATE AT MT: MU2 CAKE AT MT: NEUTRON TOOL F~.TRiX: MATRIX DENSITY: HOLE COP3.ETTION (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 iC.5 23000 6.8 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 1 ROP MWD020 FT/H 4 i 68 4 2 GR MWD020 API 4 I 68 8 3 .C 162.E · 0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11030 11325 11177.5 591 ROP MWD020 FT/H 5.88 248.92 109.626 530 GR MWD020 API 16.52 162.65 43.7376 530 First Reading For Entire File .......... 11030 Last Reading For Entire File ........... 11325 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record..65535 File Type ................ LO Next File N~e ........... STSLIB.004 Firs~ Reading 11030 11060.5 11030 Last Reading 11325 11325 11294.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and ic,~ header d-~~ for each bi~ run ~n separate files BiT RUN N'J!~BEF.: DEPTH =N~,u.,.~N.: Fi LE VE!~DCF. -~" ZZ. DE STAK? DEPTH STOP DEPTH GR '1295.C 12C14.0 ROP '1325.5 12045.0 $ LOG HEADER EATA DATE LOGGED: 22-SEP-00 SOFTWARE SURFACE SCFTWAKE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12045.0 TOP LOG iNTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.1 MAXIMUM ANGLE: 91.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3,750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: AphronICS MUD DENSITY (LB/G): 8.67 MUD VISCOSITY (S): .0 MUD PH: 10.8 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 142.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD03C API 4 1 68 8 3 Name Service Unit Min Max DEFT FT 11295 '2045 ROF MWD03C FT/H ''.$~ GR .~D030 APl ^3.~' 3C0.39 Firs= Reading =^~ Entire File "~95 Lasl Reading For Entire File ........... 12045 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Las~ Mean Nsam Keadin= Reading 11670 1501 11295 12045 i09.16~ i44~ 11325.5 12C4~ 53.0311 1439 11295 12514 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS. LIS Writing Library. Reel Trailer Service name ........... ,.LISTPE Date ...................... 02/04/18 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