Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-064
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250515 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-23 50283201910000 223061 4/24/2025 AK E-LINE Plug/Perf T40412 END 2-72 50029237810000 224016 4/4/2025 READ CoilFlag T40413 IRU 241-01 50283201840000 221076 4/30/2025 AK E-LINE Perf T40414 IRU 241-01 50283201840000 221076 4/23/2025 AK E-LINE Plug/Perf T40414 KU 33-08 50133207180000 224008 4/22/2025 AK E-LINE PPROF T40415 MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf T40416 NSU NS-06 50029230880000 202101 4/21/2025 AK E-LINE PPROF T40417 NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf T40418 NSU NS-20 50029231180000 202188 4/24/2025 AK E-LINE Perf T40419 NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer T40420 PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN T40421 PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax T40422 PBU S-100A 50029229620100 224083 2/28/2025 BAKER MRPM Borax T40423 PBU Z-235 (Revised)50029237600000 223055 4/1/2025 READ InectionProfile T40424 SRU 231-33 50133101630100 223008 5/1/2025 AK E-LINE Plug/Perf T40425 Revision Explanation: Processing report added Please include current contact information if different from above. T40421PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 08:15:21 -08'00' STATE OF ALASKA MAY 1. 5 2013 AIL OIL AND GAS CONSERVATION COMMWON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other[✓ Mill CIBP • Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat. Shutdown[1] Stimulate - Other ❑ Re -enter Suspended Well[1] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc . Development El . Exploratory ❑ 200 -064 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20163 -02 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028308 • PBU 02 -10B ' 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 11640 feet Plugs measured None feet true vertical 8972 feet Junk measured None feet Effective Depth measured 11553 feet Packer measured See Attachment feet true vertical 8971.09 feet true vertical See Attachment feet I Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 100 20" 94# H -40 25 - 125 25 - 125 1530 520 Surface 2691 13 -3/8" 72# MN -80 24 - 2715 24 - 2714.94 5380 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9130 - 9140 feet 9280 - 10540 feet 10650 - 11550 feet True Vertical depth 8966.67 - 8968 feet 8980.22 - 8991.45 feet 8976.48 - 8971.08 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: g Intervals treated (measured): SCANNED JUL c' 2013 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: 703 38396 27 0 1621 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development El • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 12 . Gas U WDSPIU 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.Summe Printed Name Nita Summerhays Title Petrotechnical Data Technician Iis���I.I Signatur- / / /7/� %: Phone 564 -4035 Date 5/15/2013 RBDMS MAY 17 201A 3/3/3 Form 10 -404 Revised 10/2012 t41.I Submit Original Only • • Daily Report of Well Operations ADL0028308 Continued from WSR 04 -21 -13 CTU 8 w/ 1.75" CT. Scope; Mill / Push CIBP to bottom. Finish rig up. Function test BOPs. RIH w/ BHA; 2.875" ctc,dfcv, 3.18" dual jars, 2.875" disco, 3.125" x -o, 3.125" x -o, venturi w/ extension (oal= 20.66') Make double pass thru GLM #2 @ 3375' and GLM #1 @ 5910. Cont RIH .Sat down on tubing stub 8129'ctm, work thru and venturi thru liner top 8200' - 8230'ctm, sat down in middle of second pert interval 10,250'ctm unable to work thru pooh. RIH w/ 2.875 ctc, dfcv, 3.125" jars, 2.875 disco, 3.125" motor, venturi w/ extension, 3.61" cut lip shoe (oal= 30.05') to 10,254'. attempt to work pass obstruction to no avail. Pooh. * *job continued on WSR 04- 23 -13 ** 4/22/2013 Continued from WSR 04 -22 -13 CTU 8 w/ 1.75" CT. Scope; Mill / Push CIBP to bottom. Finish pooh w/ 2.875 ctc, dfcv, 3.125" jars, 2.875 disco, 3.125" motor, venturi w/ extension, 3.61" cut lip shoe (oal= 30.05'). Recovered 1/2 cup of parts from CIBP ? RIH w/ same to 10254'. Work up / down several times while pumping various pump rates. POOH. LD Venturi, empty. Cut 150' of coil. MU 3.80" Mill and Motor BHA, RIH, initial tag plug @ 10265. Mill/ push to 11452'. Could not get motor to stall. possibly spinning on fill. Phone APE; Decision made to run venturi with burn shoe attempt to recover any 4/23/2013 possible plug parts remaining. Pooh ** *job continued on WSR 04- 24 -13 * ** Continued from WSR 04 -23 -13 CTU 8 w/ 1.75" CT. Scope; Mill / Push CIBP to bottom. MU Venturi, RIH w/ BHA; 2.875" ctc,dfcv, 2.875" dual jars, 3.125" disco, 2.875 ", circ. sub 2.875 ", ctd motor 3.125 ", venturi w/ extension 3.125 ", cage housing 3.125 ", Burn over shoe, 3.73 ", (oal= 30.87'). Worked venturi down to 10463, POOH. LD venturi, Recovered scale, formation rocks, piece of slip retainer, core, and nose cone from CIBP. MU 3.75" mill assembly and RIH. Tag at 11,465', Wash down from 11,465' to 11,550' with wiper trips. PU and tag bottom at 11,550', POOH. At surface freeze protect tubing 38 bbls. 4/24/2013 ** *Job Complete * * ** FLUIDS PUMPED BBLS 230 1% KCL, w /.06% SAFELUBE 396 1% SKCL 368 60/40 METH 806 2% SL KCL 496 2% SL KCL W /SAFELUBE 2296 TOTAL Casing / Tubing Attachment ADL0028308 Casing Length Size MD TVD Burst Collapse CONDUCTOR 100 20" 94# H -40 25 - 125 25 - 125 1530 520 LINER 745 7" 26# L -80 7640 - 8385 7639.66 - 8370.68 7240 5410 LINER 3429 4 -1/2" 12.6# L -80 8211 - 11640 8201.79 - 8972.08 8430 7500 PRODUCTION 2313 9 -5/8" 47# S00-95 23 - 2336 23 - 2335.98 8150 5080 PRODUCTION 4820 9 -5/8" 47# MN -80 2336 - 7156 2335.98 - 7155.66 6870 4760 PRODUCTION 1939 9 -5/8" 47# S00-95 7156 - 9095 7155.66 - 8959.47 8150 5080 SURFACE 2691 13 -3/8" 72# MN -80 24 - 2715 24 - 2714.94 5380 2670 • TUBING 8131 4 -1/2" 12.6# 13Cr80 22 - 8153 22 - 8145.56 8430 7500 TUBING 75 4 -1/2" 12.6# L -80 8140 - 8215 8132.95 - 8205.67 8430 7500 • . • • Packers and SSV's Attachment ADL0028308 SW Name Type MD TVD Depscription 02 -10B PACKER 8051 7988.27 4 -1/2" Baker S -3 Perm Packer 02 -10B PACKER 8160 8094.02 4 -1/2" Baker S -3 Perm Packer 02 -10B PACKER 8211 8143.47 4 -1/2" Baker ZXP Packer IRE_= ON • ' VVB_LFEAD= FMC 7ES:WEL ANGLE >70 9076' ACTU4IOR = BAKER C 02-10B , "'4 -112' CRONE TUBING ' I MML KB. B.EV = 58 BF. EP/ = KOP= 7915 1 I 2101' H4-1/7 HES X FQ D= 3.817 I OAK Angle = 99' 10634' Datum KO = 8905' 1\1./1— 2,108' HLPF13t 9-518 FOC I Datum ND = 8800' SS i / i ff 9.5/8' CSC 471, 50095 BTRS I 2336' _' 2642' HLO 1134 -518' FCC J XO TO M 1-80 MRS ■ GAS LFT MAN7R13.S ST MD ND DEV vLV TYPE LATCH PORT OM1E 1 13-3!8' CSG, 728, N-99 BTRs, D =12.34r H 2716' in 2 3375 3375 1 LNG RK 16 2/22006 1 5910 5909 1 SO WAG RC 20 222006 9-518' CSG, 478, M- 8013MS H 7158' I X X XO TO S0095 BTRS I r -------1 7640' I — 9 X T ZXP LTPw /FLEXLOCK F&C FM, /TOP OF r LPR 7640' 13= 6.313' I $020' H4-1? MS X PP, D = 3.813' I MinMum ID 3.813" Q 2101' 4-112" HES X NIPPLE g I 8061' Hr x4- 12' BKRS3RKR,D =3.875' I ril 1 I 8076' H4- 12' HESx NP, D =3.813' I 14-1/7 TBG STIR (01/09/06) 8140' , J 4-1? TOG,12.8/,13CR -80 VAM TOP, —I 8138' I� I 8153' HT X 4-1? I.M .EONHiSHOT, D =4.625' I 0152 bpf, D = 3.958' 8160' Hr x 4-12' BKR S3 RCR, 13= 3.875' I Il III 8193' H4- 1 ?HESXPP,13= I TOP OF 4-1? LPR 8211' 8211' I— T X 4-117 BKR ZXP LTP .0 4-12' 1BG,12.88, L-80 BT-IN, I 8215' & ` w /TT®ACK SLV, D = ?' 152 bpf, D = 3.958' 8216' H4 WLEG► D = 3.958' I I H mien NOT LOGGED 1 I 8225' I— T X 4-1? FLDO-OCK FW D IN F( FIDE r LNZ 281, L-80 ETC -U, .0383 bpi, H 8385' I D= 4.375' D =627r I . • I 8770' H4- 1 ? MARKERJONT I 1 9-518' CSG, 471, 50095 BIBS, D = 8.881' H 9096' I-- (TOP OF 9-5/7 w1 Ps1OGK H 7789' I 9-5/8' FALLOUT IMCtW (02.108) 7798' - 7814' I 9-5/8' EZSV 7821' PERFORATION SLMwARY R8= LOG: INWD,GR ANGLE AT TOP PERF: 83' Q 913U _` Note: Refer to production DB for historical pert data SIZE SW INTERVAL OpnlSgz DATE SCQZ 2 -718` 6 9130 - 9140 0 09126103 OPC 4 9280 -10540 0 06/13100 DPC 4 10650 -11550 0 06/13100 �� • i,�%. - - MID 11663' I ` X 11: ' 14-1? LPR, 12.66, L-80 BT-M, .0152 bpi, D = 3.958' H 11 640' DATE REV BY COMMENTS DATE REV BY COLME4TS FRICHOE BAY 1KT 0610/16 ORIGINAL COMPLETION 01/28/13 CJPI'JMD FISH CORRECTION (04/22/10) WE-L' 02 -108 06116100 SIDETRACK (02.108) 03/01/13 TBHJMD RUED FISH (02/13/13) FERMI No: 2000640 01/11/08 D14 IaNO 05106/13 RlWJMD FU13) CBP(04/24/13) AR No: 50-029- 20163-02 02/201619 F WJMD DRLG DRAFT CORRECTIONS SE;, 36, 71114, R14E, 1039' A L & 938' FW. 03/25/09 9/JM) DRLG DRAFT CORRECTIONS 04/29/10 CJNRIC FULL R( PLUG 1 FBH (04/22/10)_ BP Brplontlon (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 ! * Mr. Tom Maunder r Alaska Oil and Gas Conservation Commission 4U& ? c 333 West 7 Avenue 4 ?Of; Anchorage, Alaska 99501 ees Subject: Corrosion Inhibitor Treatments of GPB DS 02 e n 1 bo -0 Dear Mr. Maunder, �� Q Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA C 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -226 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 1 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 o7n 3/10 • 5chtwnb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2939 ATTN: Beth Well Job # N0.5561 Company: State of Alaska Alaska Oi18 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 log Description Date BL Color CD N-09 3-27/M-33 GNI-03 BCZ2-00013 BB6M-00024 AY1M-00049 PRODUCTION PROFILE PRODUCTION PROFILE STATIC PRESSURE SURVEY - 7/09/10 07/08/10 07/10/10 1 1 i / 1 1 1 C-20C 02-108 F-28A BAUJ-00009 BCRJ-00013 BD88-00002 MCNL RST .- MCNL 4 03/07/10 05/07/10 03/20/10 1 1 1 1 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2.1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambali Street, Sutle 400 Anchorage, AK 99503-2838 ~~~ 1RR _ e STATE OF ALASKA a?-/~G~~ ALA OIL AND GAS CONSERVATION COSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ~~ ~u'~tsh"„ ~0~(f1~5:. ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate (] Re Ent~r~~~~ted Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-064 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20163-02-00 - 7. KB Elevation (ft): 58 32' 9. Well Name and Number: PBU 02-10B ' 8. Property Designation: 10. Field /Pool(s): ADL 028308 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11640 - feet true vertical 8972 - feet Plugs (measured) 10600 Effective depth: measured 11554 feet Junk (measured) Yes, Unknown Depth true vertical 8971 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2715' 13-3/8" 2715' 2715' 5380 2670 Intermediate 7798' 9-5/8" 7798' 7798' 6870 4760 Production Liner 745' 7" 7640' - 8385' 7640' - 8371' 7240 5410 Liner 3429' 4-1/2" 8211' - 11640' 8202' - 8972' 8430 7500 ~c~,:1~NE FFB ~ 3 ZOD~ Perforation Depth MD (ft): 9130' - 11550' Perforation Depth TVD (ft): 8967' - 8971' 4-112", 12.6# 13Cr80 / L-80 8215' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packers (2) 8051' & 8160' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 877 45,574 5 420 215 Subsequent to operation: 115 5,912 1 1,700 193 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Explorato ry ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Frank Roach, 564-4373 N/A Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: o Signatur Phone 564-4628 Date Q7 ~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~~. r ~_Es ~ ~ 2008 Submit Original Only ~li~ ~I.~l ~~i~ . Page 1 of 1 • Well History Well Date Summary 02-10B 12/15/2007 "** WELL SHUT IN ***' (pre rwo) PULLED STANDARD (96") "P" PRONG FROM PLUG BODY_~ 8,176' SLM ~~r H RT MODI IED "P" PRONG IN PX PLUG BODY ~ 8182' SLM (PRONG: 1 3/8" F/N, 16" OAL) RAN GUTTED & PINNED GS W/CHINA CAP TO PX PLUG BODY ~ 8181' SLM (GS SHEARED, NO F/N MARKS FROM PRONG) CURRENTLY ATTEMPTING CMIT W/TRIPLEX "*CONTINUE R N 12-16-07"* 02-10B 12/16/2007 *'*CONTINUED FROM 12-15-07*** (pre rwo) PERFORMED CMIT T x IA TO 3000# (PASSED -SEE LOCI ~`~ LL S/I ON DEPARTURE, DSO NOTIFIED OF CONDITIONS, TAGS INSTALLED ON TREE"' 02-10B 12/16/2007 **'*WELL SHUT IN UPON ARRIVAL***' INITIAL WHP: lA(OA(T = 500/ 575( 75 PSI. JET CUT TUBING AT 8130' MD SING 3.65" SLB POWER CUTTER. FIRST ATTEMPT UCCESSFUL DUE TO SHORT IN SHOCK SUB. SECOND ATTEMPT SUCCESSFUL, POSITIVE INDICATION OF CUT. "*JOB INCOMPLETE. CONTINUED ON 17-DEC-2007*" 02-10B 12/17(2007 *""WELL SHUT W UPON ARRIVAL**** INITIAL WHP: IA/OAlT = 500/ 575/ 75 PSI. POOH AFTER JET CUTTING TUBING AT 8130' MD. CONFIRMED JET CUT DETONATED NORMALLY. WELL LEFT SHUT IN. FINAL T/ I/ O = 500/ 575/ 75 PSI. TURNED OVER TO DSO. "'JOB COMPLETE*"' 02-106 12/25/2007 T/I/0= 475/340/0 Temp= S/I Circ-out (RWO prep) Pumped 10 bbls. meth down flow line, Pumped 10 bbls. meth down TBG, Started pumping 1 %KCL down TBG taking returns up IA through jumper loop and casasco to flow line, -----job In Progress----- *'*WSR Continued to 12-26-07**` 02-10B 12/26/2007 '**WSR Continued froml2-25-07*** Circ-out, CMIT TxIA to 3500 psi PASSED (RWO prep) Pumped a total of 882 bbls. 1%KCL down TBG taking re urns up roug fumper oop an casasco to flow line, Pumped 160 bbls. 110' diesel down IA taking returns up TBG to flow line, U-tube TxIA for 1 hr. to put freeze protect in place. Freeze protect the flow line with 45 bbls of diesel. CMIT TxIA to 3500 psi with 8 bbls of diesel. TxIA lost 20/20 psi in the 1st 15 min and 10/10 psi in the 2nd 15 min for a total loss of 30/30 psi in the 30 min test. Bleed TxIAP back down to 0 psi. Final WHP's = 0/0/0 Annulus valves tagged and left open to the gauges at the time of departure. 02-106 12/27/2007 T=VAC. Set 5-1/8" FMC IS-A BPV. (Pre Doyon 14). Set 5-1/8" FMC IS-A BPV thru tree with 1 - 2' ext C~ 90". No problems. 02-106 12/29/2007 T/I/O=SSV/0/0, Temp=Sl. Attempt to function LDS on casing head upper flange. All but three pins functioned normally. Left one pin backed out, it was moving but felt tight on the way out. Two have gland nuts corroded to the LDS. Pin and gland nut functioned together freely, sprayed with penetrating oil and flagged. This should not pose a problem, these pins will be replaced. Print Date: 2/7/2008 Page 1 of 1 http:/ldigitalwellfile.bpweb.bp.com/Wl Info/Reports/ReportViewer.aspx 2/7/2008 Start: 1 /2/2008 Rig Release: 1 /11 /2008 Rig Number: BP AMOCO Operations Summary Report Legal Well Name: 02-10 'Common Well Name: 02-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. ~ Rig Name: DOYON 14 Date From - To Hours Task Code NPT I Phase 1/2/2008 03:00 - 11:00 800 RIGD P 11:00 - 00:00 13.001 MOB P 1/3/2008 00:00 - 09:00 9.00 MOB P 09:00 - 11:00 2.00 MOB P 11:00 - 12:00 1.00 RIGU 12:00 - 15:00 3.00 RIGD P 15:00 - 18:00 I 3.001 DHB I P 18:00 - 21:30 3.50 WHSUR P 21:30 - 00:00 2.50 WHSUR P 1/4/2008 100:00 - 02:30 2.501 WHSUR P 02:30 - 04:00 I 1.501 WHSUR I P 04:00 - 05:30 1.50 WHSUR P 05:30 - 10:00 4.50 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 16:30 5.50 WHSUR P 16:30 - 17:00 0.50 WHSUR P 17:00 - 18:00 1.00 WHSUR P 18:00-19:00 i 1.00WHSURP 19:00 - 22:30 I 3.501 WHSUR I P 22:30 - 00:00 1.501 WHSUR P • Page 1 of 6 Spud Date: 5/26/2000 End: 1 /11 /2008 Description of Operations PRE Rig down. Prepare for Rig move. PRE Mobilize Rig for move to DS #2 -10. -Depart S-pad. PRE Move rig from BOC to DS # 2. PRE Drop rear Boosters. Set rig mats. -Spot Rig over well. Shim Rig level into place. DECOMP PJSM. -Skid Rig floor. DECOMP Install conveyor. Spot and berm Rock washer. -R/U Rig floor. DECOMP Accept Rig C~ 15:00 hrs, 01/03/2008. -ruu i vv~.. -R/U 500 bbl open top tank, choke skid & hard line. DECOMP R/U Tree for displacement. DECOMP Test lines - OK. Displace out diesel freeze protection. -Reverse in 50 bbls Seawater (~ 120 degrees F). Swap hoses. -Pump 200 bbls Seawater down Tbg. -Take returns outside to open top tank. -105 gpm / 2500 psi. DECOMP Finish displacement of diesel out of well. -Wait 30 minutes for any diesel migration. -Pump an additional 40 bbls of Seawater. -105 gpm / 2500 psi. DECOMP Confirm well dead. -R/D lines. FMC- install - ISA BPV. -Test from bottom to 1.000 psi l 30 minutes-chart. -R/D lines. DECOMP Nipple down Tree. -FMC install blanking plug. DECOMP N/U BOPE. -Riser, flowline. -Change out choke line spacer spool. DECOMP R/U to test BOPE. DECOMP Test BOP and related equipment per BP / AOGCC procedures - est to 250 psi low - 3,500 psi high. 5 minutes each on chart. -Test top rams and all components w/ 4" test joint. -Test bottom rams w/ 5" test jt. -Perform koomey test. Test witnessed by WSL and Toolpusher. -Lou Grimaldi w/AOGCC waived witness of test. DECOMP R/U XO and pull blanking plug per FMC Rep- LD same. DECOMP R/U DSM lubricator -Test to 500 psi. -Pull BPV per FMC and DSM - R/D lubricator. DECOMP P/U BHA t/ Rig floor. -FMC to Back out LDS. DECOMP Spear into hanger, attempt to pull per Baker rep. -Pull up to 250K while circulating @ 3,600 psi. -Tbg cut appears problematic -Decision made to attempt recut ~ 8,133' and -(Old cut f~ 8,130' md). -CBU ~ 145 gpm / 3,600 psi. DECOMP Break circulation. CBU @ 147 gpm / 3600 psi. Printed: 2/7/2008 1:44:59 PM • BP AMOCO Page 2 of 6 ~ Operations Summary Report Legal Well Name: 02-10 Common Well Name: 02-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 ..Date From - To Hours Task I Code NPT - ~- 1/5/2008 00:00 - 01:001.00 PULL P 01:00 - 02:00 I 1.00 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 06:30 3.50 PULL P 06:30 - 09:00 I 2.501 PULL I P 09:00 - 10:00 1.00 PULL P 10:00 - 11:00 1.00 PULL P 11:00 - 12:00 1.00 PULL P 12:00 - 13:00 1.00 PULL P 13:00 - 15:30 2.50 PULL 15:30 - 20:30 5.001 PULL I P Spud Date: 5/26/2000 Start: 1 /2/2008 End: 1 /11 /2008 Rig Release: 1/11/2008 Rig Number: Phase ~ Description of Operations - -- __ DECOMP Continue to CBU 3,570 psi / 147 gpm. DECOMP Land hanger. RILDS. -4 LDS were able to screw in past setting depth. -Back off same to correct depth. -5 LDS set correctly. -Drain stack. Observe from Rig floor. -2 LDS visibly pushed above top of hanger. -1/3 circumference of Hanger top above snap ring appears to have been peeled off. -Back off 4 Bad LDS to prevent thread damage. -Release spear. UD same. DECOMP N/D riser & flow line. N/U shooting flange. DECOMP R/U SLB lubricator & tools. -Test lubricator & tools to 500 psi. DECOMP SLB -RIH w/ Guage ring / CCL to 8,180' md. -Log shows indication of cut C~ 8,130' md. -POH. DECOMP R/D SLB E-line svs. DECOMP N/D shooting flange. N/U Picture nipple. -N/U Riser & Flow line. DECOMP R/U for SLB Free point. DECOMP P/U SLB Free point tools. DECOMP PJSM. R/U SLB. P/U 1 Jt 5" DP, 1 Pup jt. -P!U XO to Tbg hanger. -Screw into Hanger. Back out Lock down screws. -Perform pull test on Tbg. DECOMP PJSM. Hang sheave in derrick. -RIH w/ E-line t/ 4,450' md. -Pull 10K over string wt (150K). -Pulled 210K -Slack off to 150K. -C~ 4,450' and -Tbg string is 100% Free. -C~ 7,630 and -Tbg string is 100 °I° Free. -@ 8,120' and -Tbg string is 100 % Free -C~? 8,143' and -Tbg string is 100 % Free. -C~3 8.170' and - No Tbg string movement. 20:30 - 22:30 2.001 PULL i P 22:30 - 23:00 0.50 PULL P 23:00 - 00:00 1.00 PULL P 1/6/2008 00:00 - 00:30 0.50 PULL P 00:30 - 03:00 2.50 PULL P 03:00 - 04:30 1.50 PULL P 04:30 - 05:00 0.50 PULL P 05:00 - 07:30 I 2.501 PULL I P -POH w/SLB E-line. R/D SLB. DECOMP R/D Riser, Picture nipple, Flow line. -R/U Shooting flange, extension, Pump-in flange. -R/U Well control equipment & attach Firing head. DECOMP PJSM on explosives. -Test SLB pressure control to 500 psi. DECOMP P/U Jet cutter. DECOMP Continue PU Jet cutter DECOMP RIH w/ Jet cutter. -Cut 4 1/2" Tbg ~ 8,133' md. DECOMP R/D SLB. DECOMP N/D Shooting flange. -N/U Picture nipple, Riser & Flow line. DECOMP P/U Baker spear. -Spear into Tbg hanger. -Work hanger through BOP's - PUW 140K. Printed: 2!7/2008 1:44:59 PM • BP AMOCO Operations Summary Report Page 3 of 6 Legal Well Name: 02-10 ,Common Well Name: 02-10 Spud Date: 5/26/2000 'Event Name: W ORKOVER Start: 1 /2/2008 End: 1 /11 /2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2008 Rig Name: DOYON 14 Rig Number: Date ;From - To Hours Task Code NPT Phase Description of Operations 1/6/2008 07:30 - 08:00 0.50 P DECOMP UD spear, hanger and XO's. 08:00 - 10:00 2.00 PULL P DECOMP Pump "Safe Kleen" and "Safe Scav" pills surface to surface. -Pump ~ 8 bpm / 330 psi. -PJSM on L/D Tubing. 10:00 - 12:00 2.00 PULL P DECOMP Pump Dry job. -POH L/D 4 1/2" 12.6# L80 IBT-M tubing. -Seawater wt 8.5 ppg in & out. 12:00 - 18:30 6.50 PULL P DECOMP Continue to L/D 4 1/2" Tbg. (196 jts + 1 cut jt). -Cut jt length was 22.06' w/ 5 1 /8" flare -Recovered 3 GLMs & 1 X- nipple. 18:30 - 19:30 1.00 PULL P DECOMP Clear Rig floor of Csg equipment. -Clean Rig mats. 19:30 - 20:30 1.00 PULL P DECOMP R/U 4" test jt & test equipment. -Test lower Rams to 250 psi low/ 3,500 psi high. -Chart test -Pass. -R/D test equipment & 4" test jt. 20:30 - 21:30 1.00 PULL P DECOMP P/U 4" jt of DP, XO and running tool. -J-into packoff. Screw in Top Drive. -Back out Lock down screws. 21:30 - 23:00 1.50 PULL P DECOMP Re-J in running tool. -Attempt to rotate 2 turns left to loosen -No Go. -Run new Packoff. -Energize Lock down screws. -Test LDS to 3,800 psi f/ 15 minutes - OK. 23:00 - 23:30 0.50 PULL P DECOMP R/D 4" jt, XO and running tool. 23:30 - 00:00 0.50 PULL P DECOMP P/U Baker BHA t/ Rig floor. 1/7/2008 00:00 - 00:30 0.50 PULL P DECOMP Install Wear ring. 00:30 - 04:00 3.50 CLEAN P DECOMP P/U & M/U Baker Washover /Dressing Mill -BHA. 04:00 - 10:30 6.50 CLEAN P DECOMP P/U 4" DP- Single in hole w/ Baker BHA to 8,120' md. 10:30 - 11:30 1.00 CLEAN P DECOMP Obtain parameters -PUW= 165K -SOW= 170K -ROT wt= 170K. -Ta Tb stub at 8 140' md. -Break circulation C~ 4 bpm / 350 psi. -Wash down and tag w/ 60 rpm / 1 K tq. -Taking weight at 8,140' and -Observe torque increase. -Clean out to 8,154' and shoe depth. -Tag Tbg w/ internal mill at 8,140' md. -Dress off same w/ 2K WOB / 100 rpm. -PUW= 165K -SOW= 170K -ROT wt= 170K. -Work over stub several times. 11:30 - 13:00 1.50 CLEAN P DECOMP Pump H.V. Sweep w! W.O. assembly over Tbg stump. -334 gpm / 1,400 psi. -Monitor well -Static. 13:00 - 13:30 0.50 CLEAN P DECOMP R/U to reverse circulate H.V. Sweep. 13:30 - 15:00 1.50 CLEAN P DECOMP -Reverse H.V. Sweep around w/ W.O. assembly over Tbg stump. -275 gpm / 1,010 psi. 15:00 - 15:30 0.50 CLEAN P DECOMP R/D Reverse circulation equipment. -Blow down Kill line. -Monitor well -Static. 15:30 - 19:00 3.50 CLEAN P DECOMP Pump Dry job. Printed: 2/7/2008 1:44:59 PM ., • BP AMOCO Page 4 of 6 Operations Summary Report Legal Well Name: 02-10 Common Well Name: 02-10 Spud Date: 5/2612000 Event Name: WORKOVER Start: 1/2/2008 End: 1/11/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2008 Rig Name: DOYON 14 Rig Number: Date. From - To Hours Task ~ Code NPT Phase 'I Description of Operations 1/7/2008 15:30 - 19:00 3.50 CLEAN P DECOMP -POH w/ 4" DP f/ 8,140' - 591' md. Seawater wt in & out= 8.5 ppg. 19:00 - 20:00 1.00 CLEAN P DECOMP P/U 1 jt of 4" DP to UD Baker BHA. -Rack back remaining 4" DP. -Good tattletale marks [+1J8" groove] on Dressing Mill. 20:00 - 21:30 1.50 CLEAN P DECOMP Clear Rig Floor of all Baker Tools. -P/U Muleshoe BHA and 2 7/8" csg slips & tongs. 21:30 - 22:30 1.00 CLEAN P DECOMP M/U Muleshoe BHA. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH w/ Muleshoe BHA f/ 301' to 3,900' md. 1/8/2008 00:00 - 02:00 2.00 CLEAN P DECOMP RIH f/ 3,900' to 8,175' md. -Wash down and tag PXX plug ~ 8,200' md. -P/U= 165K, SOW= 167k. -168 gpm / 270 psi. 02:00 - 04:00 2.00 CLEAN P DECOMP -Close Annular Preventer & Reverse Circulate S/S. - Pump 40 bbl H. V. Sweep while reversing. - 336 gpm / 1080 psi. 04:00 - 04:30 0.50 CLEAN P DECOMP Flow Check Well (10 minutes) -Static. -POH f/ 8,200' to 7,200' md. -Seawater wt= 8.5 ppg in & out. 04:30 - 06:30 2.00 CLEAN P DECOMP Cut & slip Drlg line. Service Top drive. 06:30 - 09:00 2.50 CLEAN P DECOMP Pump Dry job. POH f/ 7,200' to 300' md. -Seawater wt= 8.5 ppg in & out. 09:00 - 09:30 0.50 CLEAN P DECOMP Stand back DCs. -UD Oil jars, Bumper jars & Mule shoe. 09:30 - 10:00 0.50 CLEAN P DECOMP M/U "GH" Spear BHA. 10:00 - 12:30 2.50 CLEAN P DECOMP RIH w! "GH" Spear & 4" DP fl 300' to 8,182' md. 12:30 - 14:00 1.50 CLEAN P DECOMP P/U single from pipe shed to 8,200' md. -Obtain parameters: GPM= 250, PSI= 790. -PUW= 162K, SOW= 168K. -Pull PXX plug. Set Latch. P/U 7K overpull - No Latch. -Set 20K down wt. Observe 500 psi increase. -Induce 7K overpull - No Latch. Set 25K down wt. -Observe Latch and pressure increase. P/U 15K overpull and bleed jars. -Observe fluid drop. PfU 30K. Over wt fell ofif. 14:00 - 15:00 1.00 CLEAN P DECOMP UD 2 jts to clear Tbg. -Fill hole to calculate fluid loss rate. -Loss rate= 68 b h. 15:00 - 16:00 1.00 CLEAN P DECOMP UD DP f/ 8,130' to 6,750' md. 16:00 - 17:00 1.00 CLEAN P DECOMP DHD to shoot fluid levels: -#1= 810 ft. #2= 852 ft. #3= 888 ft. 17:00 - 21:30 4.50 CLEAN P DECOMP POH, UD DP f/ 6,750' to 304' md. -Fill hole w/double hole displacement method. 21:30 - 23:00 1.50 CLEAN P DECOMP UD BHA, six 4 3/4" DCs, Pumpout sub. -UD XO, Oil jar, XO, 3 jts of 2 7/8" DP. -UD XO & 4" "GH" Spear. 23:00 - 00:00 1.00 CLEAN P DECOMP Wait on new Spear. -Fill & monitor hole. -Loss rate= 22.5 b h. -Load pipe shed w/ 4" DP & 4 314" DCs. -Decision made to Fish PXX plug with S_ lickline. 1/9/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Clear Rig floor of Baker tools. -Remove DP from pipe shed. Printed: 2/712008 1:44:59 PM • BP AMOCO Operations Summary Report Page 5 of 6 Legal Well Name: 02-10 Common Well Name: 02-10 Spud Date: 5/26/2000 Event Name: WORKOVER Start: 1/2/2008 End: 1!11/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2008 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours j Task Code NPT Phase Description of Operations 119/2008 101:30 - 02:30 1 1.00 ~ CLEAN I P 02:30 - 06:00 I 3.501 CLEAN I P 06:00 - 08:00 I 2.001 CLEAN I P 08:00 - 09:00 1.00 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 12:00 1.50 BUNCO P 12:00 - 14:00 2.00 BUNCO P 14:00 - 00:00 I 10.001 RU 1/10/2008 100:00 - 03:30 ~ 3.50 03:30 - 04:30 I 1.001 RU 04:30 - 08:00 3.50 RU 08:00 - 09:30 1.50 RU 09:30 - 13:00 3.50 RU 13:00 - 14:00 1.00 RU 14:00 - 16:00 2.00 RU DECOMP N/D Flow line, Riser & Picture nipple. -N/U Shooting flange. DECOMP Spot SLB wireline unit. -R/U extensions & Lubricator. -Hang sheaves. M/U Tools. -Test Lubricator to 500 psi & chart - OK. DECOMP RIH w/ Slickline retrieval tool. -Slickline Operator reported a maximum depth of -No issues on final "X" ni le depth 8,193' md) -POH w/ Wireline tools. DECOMP RD Slickline extensions, Lubricator & sheaves. DECOMP ND shooting flange. -NU Pitcher nipple, Riser & Flow line. DECOMP Pull Wear ring. RUNCMP PJSM - R/U to run 4 1/2" 13Cr-80, VAM TOP tubing. RUNCMP -R/U Stack tongs, compensator & single joint elevators. -R/U Long bales & Torque turn equipment. -R/U Airlines & thread protector bag. RUNCMP Run 4 1/2" 13Cr-80 Tb . -Utilize "Jet Lube Seal Guard" pipe dope. -Optimum Tq= 4,440 ft-Ibs -Maximum Tq- 4,880 ft-Ibs. -Run Unique Overshot &Tbg per program. RUNCMP Continue to run 4 1/2" 13Cr-80 Tbg per program to 8,137' md. -No Tbg jts rejected. -Wash over Tbg stub to 8,140' md. -PUW=135K, SOW= 135K. 100 psi / 126 gpm. -Noted pressure increase to 170 psi /Pumps turned off. -Shear ~ 8,144' and w/ 12K down wt. -Shear ~ 8,152' and w/ 16K down wt. -Spaceout= 3.5 ft. RUNCMP UD 1 jt (#191) -M/U Tbg hanger: -While making up XO for Tbg hanger w/ L.H. Acme threads in top. -Noticed bottom of hanger was not torqued up. RUNCMP -UD Tbg hanger and send to Baker machine for re-torque. -Then send to Schlumberger for pressure re-test. RUNCMP M/U hanger and landing joint. -R/U to revese circulate. RUNCMP Reverse circulate: -Pump- 310 bbls clean Seawater w/ corrosion inhibitor. -Pump- 180 bbls clean Seawater. -126 gpm / 250 psi. RUNCMP Change seal on landing joint. -Land hanger. -RILDS. RUNCMP Drop Ball & Rod -Set Packer. -Increase pressure to 3.500 osi f/ 30 minutes. -Bleed pressure to 1,500 psi. -Test IA to 3,500 psi f/ 30 minutes - OK, -Bleed pressure from Tbg to 1,000 psi. -DCK valve sheared at 2,500 psi. Printed: 2(7(2008 1:44:59 PM • • BP AMOCO Operations Summary Report Legal Well Name: 02-10 Common Well Name: 02-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Mours Task Code ~ NPT 1/10/2008 ~ 16:00 - 16:30 ~ 0.50 ~ RU 16:30 - 18:00 I 1.50 18:00 - 23:30 I 5.50 23:30 - 00:00 I 0.50 1/11/2008 X00:00-02:30 ~ 2.50~WHSUR~P 03:00 - 04:30 0.501 WHSUR P 04:30 - 06:00 1.50 WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 10:00 3.00 WHSUR P 10:00 - 12:00 2.001 WHSUR ~ P Page6of6~ Spud Date: 5/26/2000 Start: 1 /2/2008 End: 1 /11 /2008 Rig Release: 1/11/2008 Rig Number: Phase Description of Operations RUNCMP Back out landing jt. Break off XOs. -UD landing jt. -Blow down hose, swing & T-sensor. RUNCMP Suck out stack. Dry rod in BPV. -Test from below to 1,000 psi f/ 30 minutes. -Blow down Choke, Kill & Fill line. -Blow down Injection line. RUNCMP PJSM. Remove Flow line. Pull mouse hole. -Pull Riser. Remove turn buckles & Choke line. -Set stack back. Install Tree. -UD Csg equipment. -C/O Bails and Elevators. -Load pipe shed w/ 120 jts of 4" DP. -R/D Geronimo line. P/U Rig mats. -FMC test Adaptor flange to 5,000 psi f/ 10 minutes - OK. RUNCMP R/U DSM Lubricator. Test Lubricator to 500 psi f/ 5 minutes - OK. WHDTRE Test Lubricator to 500 psi f/ 5 minutes - OK. -DSM- pull BPV. -FMC- set Tree test plug. -Test tree to 5,000 psi f/ 5 minutes - OK. -M/U DSM Lubricator & test to 500 psi f/ 5 minutes - OK. -Pull Tree test plug. R/D DSM. WHDTRE R/U Hot Oil Svs & test to 3,000 psi - OK. WHDTRE -Pump 160 bbls of diesel (80-F) to freeze protect. -84 gpm / 450 psi. WHDTRE U-tube diesel. WHDTRE Suck back fluid & R/D lines. WHDTRE R/U DSM Lubricator & test to 500 psi / 5 minutes - OK. -Install blank flange. -Hot oil test BPV from below to 1,000 psi / 10 minutes - OK. WHDTRE Suck back fluids. R/D lines. -Install guages, Secure well. -Obtain pressure readings. -R/D test equipment. -OA psi= 0, IA psi= 0, Tbg psi= 0. -Rig released ~ 12:00 hrs 01/11/2008. Printed: 2/7/2008 1:44:59 PM TREE = FMC GEN 1 WELLHEAD = FMC ACTUATOR = BAKER C KB. l1EV = 58' BF. ELEV = KOP = 7916' Max Angle = 99 @ 10634' Datum MD = 8905' Datum N D = 8800' SS DRLG DRAFT 13-318" CSG, 72#, MN-80, ID = 12.347" ~~ 2715' TOP OF 7" LNR 7640 Minimum ID = 3.813" @ 2100' 4-1 /2" HES X NIPPLE 4-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" 8128 TOP OF4-1/2" LNR I~ 8210' ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 8385' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9095 TOP OF 9-5/8" WHIPSTOCK -~ 7799' 02-10B 2100' ~--{4-1/2" HES X NIP, ID= 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3375 5910 3375 5909 1 1 MMG MMG ~'~CR R!<P 0 0 01!08/OS 01(08/08 803~~ 4-1 /2" HES X NIP, ID = 3.813" I 8051 7" X 4-1/2" BAKER S3 PKR, ID = 3.875" 8075' 4-1 /2" HES X NIP. ID = 3.813" 8153' UNIQUE MACHINE OVERSHOT 8160 7" X 4-1 J2" BAKER S3 PKR ID = 3.875" 8193 4-1 /2" HES X NIP, ID = 3.813" 8211 ~ 7" X 4-1 /2" BAKER ZXP LINER TOP PKR 8215 4-1/2" WLEG ELMD TT NOT LOGGED 9-5/8" WINDOW (02-10B) 7798' - 7814' FISH- PX PLUG (12/15/07) NOTE BELOW 9122' SLM (DRIFTED 01/09/08) 9-5/8" EZSV PERFORATION SUMMARY REF LOG: MWD,GR ANGLEATTOPPERF: 83 @ 9130' Note: Refer to Roduction DB for historical perf da?a SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9130 - 9140 O 09/26.0 DPC 4 9280 - 10540 O 06113r(`~~,' DPC 4 10650 - 11550 C 06/13;0; PBTD 10600' ~~4-1/2"WFCIBP (05/17/03) 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" ~-{ 11640' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/06/76 ORIGINAL COMPLETION 06/16/00 SIDETRACK (02-106) 01/11/08 D14 RWO 01/15/08 GJF/PJC FISH (12!15/07) 01/20/08 /TLH GLV CORRECTIONS PRUDHOE BAY UNIT WELL: 02-10B PERMIT No: 2000640 API No: 50-029-20163-02 SEC 36, T11 N, R14E, 1765.36 FEL, 300.6 FNL BP Exploration (Alaska) . . WELL LOG TRANSMITTAL _. . ____. _ _ ",_"__' ___.. n_ ..·..W·__, ,~~--~----~". ProActive Diagnostic Services, Inc. To: ACX:;CC Christine ~ahnken 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 : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) EDE Disk 2) 3) 4J 5J 6J 7) D.S.02 - 108 Leak Detect - WLD 04-May-07 sCANNED JUN, 2 02007 6b0 -00« +f I~-'c}~ .... . . . ..... _..~,..... Signed: ~fl~ 1 1 Date : Alaska Oil 8tGdS jCC1~~. C:ùnjm~~ton Print Name: Œ1("'~+'IIA¡?- (\I\i'\.III A\{~1J\ PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?DS)_;;gCEOR1:.0iE@r/f:=~::1GR.~.f":...CG.G08j WEBSITE : :¡\j1PjlN.:¡JjEr~10RY~·D;3.,:·Ç;~!Jl D:lMaster _Copy _00 ]DSANC·2OxxIZ _ W ord\Distribution\Transmittal_ Sheets\1iansmit _ Original.doc ~fG r//(/o.Ç . STATE OF ALASKA . RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSI<2~~ 1.L2006 REPORT OF SUNDRY WELL OPERATION:) AI. "I. n" 0 I" 1". - 1. Operations Performed: n.....".. ..... Y< ....... .......... Abandon 0 Repair WellD Plug PerforationsD Stimulate 0 Anchorage OtherOOSecure Well Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ]] ExploratoryD 200-06A0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20163-02-00 7. KB Elevation (ft): 9. Well Name and Number: 58.32 02-108 8. Property Designation: 10. Field/Pool(s): ADL-028308 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11640 feet true vertical 8972.0 feet Plugs (measured) Secured Well--- 4-1/2" TTP @ 8193' (06/28/2006) Effective Depth measured 11554 feet 4-1/2" WF CIBP set @ 10600' (05/17/03) true vertical 8971.0 feet Junk (measured) Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 20" 94# H-40 30 - 100 30.0 - 100.0 1490 470 SURFACE 2686 13-3/8" 72# MN-80 29 - 2715 29.0 - 2715.0 4930 2670 PRODUCTION 7770 9-5/8" 47# MN-80 28 - 28.0 - 6870 4760 9-5/8" 47# SOO-95 - 7798 7798.0 8150 5090 LINER 745 7" 26# L-80 7640 - 8385 7640.0 - 8371.0 7240 5410 LINER 3429 4-1/2" 12.6# L-80 8211 - 11640 8202.0 - 8972.0 8430 7500 Perforation depth: t)CANNED SEP 2 0 200B Measured depth: 9130-9140,9280-10540,10650-11550 True vertical depth: 8967-8968,8980-8991,8976-8971 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 26 - 8215 Packers & SSSV (type & measured depth): 7" Baker S3 Packer @ 8160 7" Baker ZXP Liner Top PKR @ 8211 4-1/2" HE5 X Nipple @ 2191 12. Stimulation or cement squeeze summary: RBDMS 8Ft SEP 1 8 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 923 50008 0 --- 1307 Subsequent to operation: 51 0 0 350 250 14. Attachments: 15. Well Class after proposed work: ExploratoryD Developmentl!! ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasO WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWay.ne R. Schnorr Title Petroleum Engineer Signature A~.-~~ À. /! I>.. Phone 564-5174 Date 9/13/06 "", Form 1 0-404 Revised 4/2004 0/1 ILJII\J!-\L . . 02-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/05/2006 T/I/O/OO=250/350/40/0+. Temp=SI. WHPs (for secure). TBGP increased 30 psi from 220 psi to 250 psi. lAP decreased 30 psi from 380 psi to 350 psi. OAP decreased 10 psi. No change in OOA. 07/04/2006 TIO = 760/760/50/0+. Temp = SI. Bleed WHP's < 500 psi (for secure). Continued bleed from 7/3. No AL. TBGP & lAP equalized overnight. Bled TBGP & OAP simultaneously to production for 1 hr. Bled TBGP from 760 psi to 220 psi. Bled lAP from 760 psi to 380 psi. FWHPs = 220/380/50/0+. 07/03/2006 TIO = 1940/1940/50/0+. Temp = SI. Bleed WHPs < 500 psi (for secure). No AL. TBG FL @ 8060'. IA FL @ 7350'. Bled IA & TBG simultaneously to production for 2 hrs. Bled TBG from 1940 psi to 850 psi. Bled IA from 1940 psi to 720 psi. F-5 valve at FS1 was SI; bleed source was lost for the day. FWHP's = 850/720/50/0+. 06/28/2006 SET 4.5 PX PLUG (4 - 1/4" EQ. PORTS) IN LOWER X NIPPLE @ 8179' SLM. SET PRONG (96" LNG W/1. 75" FN & BODY) @ SAME. BLEED IA AND TBG DOWN - GOOD TEST. ***WELL LEFT SHUT IN*** 06/27/2006 ***WELL SHUT IN ON ARRIVAL*** RIH W/4.5 XX PLUG TO X NIPPLE @ 8193' MD 06/25/2006 T/IIO=2360/2340/50. SI. WHPs post TIFL. (post DGL V) problem well day 13. TGBP unchanged, lAP increased 1370 psi, OAP increased 20 psi overnight. 06/24/2006 T/I/O=2360/2360/30. SI. TIFL (FAILED) (post-DGL V). Problem well day 11. IA FL @ 7603" sta# 3. Bled lAP from 2360 psi to 850 psi in 2.5 hours. Monitored 1 hour. IA FL unchanged. lAP increased 120 psi. Final WHP's=2360/970/30 FLUIDS PUMPED BBLS I 1 PT Surface Egui~ment 1 TOTAL Page 1 TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= FMC GEN 1 FMC BAKERC 58' 7916' 99 @ 10634' 8905' 8800' SS 02-108 S Y NOTES: HORIZONTAL W8.L . 70· @ 9075' AND 90· @ 9670'. . 2191' -14-1/2"HESXNIP,ID=3.813" I 113-3/8" CSG, 72#, MN-80, ID= 12.347" Minimum ID = 3.813" @ 2191' 4-1/2" HES X NIPPLE I TOP OF 7" LNR I 7640' ST MD 1VD 1 3720 3720 2 6395 6395 3 7603 7603 GAS LIFT MANDRELS DEV VLV ìYÆ LATCH PORT DATE 1 MMG RK o MMG RK 1 MMG RK I TOP OF 4-1/2" LNR I 8210' 14-1/2" TBG, 12.6#, L-80, "0152 bpf, ID = 3.958" 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1 I 9-5/8" CSG, 47#, L-80, ID = 8"681" I TOP OF 9-5/8" WHIPSTOCK I 8385' 9095' 7799' 19-5/8" EZSV I PERFORA TION SUMMARY REF LOG: MWD,GR ANGLEATTOPPERF: 83@9130' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9130 - 9140 C 09/26/03 DPC 4 9280 - 10540 C 06/13/00 DPC 4 10650 - 11550 C 06/13/00 DATE 08/06/76 06/16/00 10/12/02 11/12/02 05/17103 09/30103 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (02-108) JAUKK WAIVER SAFETY NOTE ITLH DELETE WAIVER SAFETY NOT TMNlTLH CIBP SET JGMlTLH ADPERF -- 7" X 4-1/2" BAKER S3 PKR, ID = 3.875" I 4-112" HES X NIP, ID= 3.813" 4-1/2" PX PLUG SET (06/28/06) -- 7" X 4-1/2" BAKER ZXP LINER TOP PKR -- 4-1/2" WLEG I H ELMD TT NOT LOGGED I 9-5/8" WINDOW 7798' - 7814' 10600' -14-1/2"WFCIBP(05/17/03) I \PBTD I 11553' 14-112" LNR, 12"6#, L-80, "0152 bpf, ID = 3"958"' DA TE REV BY COMMENTS 06/28/06 TWS/PAG SET PX PLUG PRUDHOE BA Y UNrT WELL: 02-10B ÆRMrT No: '2000640 API No: 50-029-20163-02 SEC 36, T11 N, R14E. 1765"36 FEL, 300.6 FNL BP Exploration (Alaska) Kt: UL-IUö~.t' lU ffLUUUOLfUj Lla~Slllt:u as nULJlt:lll VVt:ll --- ~'-'" Subject: RE: 02-10B (PTD #2000640) Classified as Problen1 Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWeIlIntegrityEngineer@BP.com> Date: Sat, 17 Jun 2006 14:06:26 -0800 To: "Dean, James A" <James.Dean@BP.com>, "GPB, FS1/S1P/STP Area Mgr" -<GPBFS1 TL@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisoi@BP.com>, "GPB, Wells Opt Eng" ¡<GPBW ellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admîn.state~ak.us>. ~'AOGCC Winton Aubert (E-mail)..<wmton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSlWervisor@BP.com>, "GPB,FS IDS Ops ~ead" <GPBFSIDSOpsLead@BP.com>. . ~C: "MCCOLLUM;CODY 0 (VECO)" <Cody.McCollum@BP.com>, "Winslow, Jack L." ~Lyonsw@BP.com> All, Well 02-10B (PTO #2000640) has been found to have sustained casing pressure on the IA. The TIO pressures were 2400/2390/60/0 on 06/15/06. A TIFL Failed on IA repressurization on 06/14/06. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Evaluate for dummy GL valves 3. SL: DGL Vs 4. DHD: Re-TIFL ]:A Z:R o¡>-;. ¡ 6c¿10fl"\ ÌJ~ 34 {1 '2 , .D C 'SC~ A/CU¡ P '1 2.n no SCANNED JUN 2 s uuQ ðk:- p-er- éù4QZ- vtc,--h \.( 'cCL..hG~\. r ~s ,-3R ~11 6 {2t ( ~ A wellbore schematic has been included for reference. «02-10B.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, .Jfnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 02-10B.pdf 02-10B.pdf Content-Type: application/octet-stream ~ Content-Encoding: base64 1 of 1 6/21/2006 3: 11 PM .~"'- '-- FMC GEN 1 FMC BAKER C 58' TREE = WELLHEA 0 = 'ACTuA TOR = KB. ELEV = SF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = SAFETY NOTES: HORIZONTAL WB..L - 70° @ 9075' AND 90° @ 9670'. 02-10B 7916' 99 @ 10634' 8905' 8800' SS 2191' 1--14-112" HES X NIP, 10 = 3.813" 1 e 113-3/8" CSG, 72#, MN-80, 10 = 12.347" 1-1 2715' ~ ~ GAS LIFT MANDRELS DEV VL V TV PE LATCH PORT DATE 1 MMG RK o MMG RK 1 MMG RK ST MD lVD 1 3720 3720 2 6395 6395 3 7603 7603 Minimum ID = 3.813" @ 2191' 4-1/2" HES X NIPPLE L ITOP OF 7" LNR 1-1 7640' ¡ '"¡¡¡ :8: :8---1 8160' 1-17"X4-1/2"BAKERS3PKR,ID=3.875" 1 ~~ I 8193' 1-14-1/2" HES X NIP, 10 = 3.813" 1 TOPOF 4-1/2" LNR 1-1 8210' 8211' 1--17" X 4-1/2" BA KER ZXP LINER TOP PKR 8215' 1-14-1/2" WLEG 1 1--1 B..MD TT NOT LOGGED 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" 1-1 8215' 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 8385' 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9095' I TOP OF 9-5/8" WHIPSTOCK 1-1 7799' 9-5/8" WlNOOW 7798' - 7814' I 10600' 1-14-1/2" WF CIBP(05/17/03) 1 19-5/8" EZSV 1-1 7821' PERFORA TlON SUMMARY REF LOG: MWD,GR ANGLEATTOPPERF: 83@9130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9130 - 9140 0 09/26/03 DPC 4 9280 - 10540 0 06/13/00 DPC 4 10650 - 11550 C 06/13/00 IPBID 1-1 11553' 1 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 11640' 1 DA TE REV BY COtvWlENTS 11/12/02 ffiH DB..ETEWAIVERSAFETY NOTE 05/17/03 lMNlTLH CIBP SET 09/30/03 JGMlTLH ADÆRF REV BY COrv1MENTS ORIGINA L COMPLETION SIDETRACK (02-10B) SIS-SLT CONVERTED TO CANVAS SIS-LG REVISION RNnP CORRECTIONS JAUKK WAIVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 02-10B PERMIT No: 2000640 API No: 50-029-20163-02 SEC 36, T11 N, R14E, 1765.36 FB.., 300.6 FNL DATE 08/06/76 06/16/00 12/29/00 02/21/01 01/31/02 10/12/02 BP Exploration (Alas ka) Schlum~epgep RECEIVED , Ii 11\! 0 Q ?no~ y-j v LU it..; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~!..,,<:".:; (',il :<. ¡~"''' '...."n" <ÃrnmissiOll:,..~ '''¡',i;o.!\'-..IF'j'\ Anchorage, AK 99503.2838 . .1......"'_... ... "".... ,,"""", ' ",/ì.."r., .... ......- A TTN: Beth ,~!!dIOïcge Well 17-13A f::!t,.c:::; - n.;::J(\ NK-65A At')") -r..,r:-~ 02~10S ,~, - (; (" '- 01-11 r-,..-.¡ -/"-,< 01-09A Ie¡<- - ñ;:n 01-11 !:;.+ _,,,~-~ 11-34 ¡ qi../ - I::Z';<' A-fJ7 1 -::2 ~ _ Q'4 ( B-36 I q (~ - ()0~ 01 :20 i"7í:.1- ) 4/ /_ K-01 ì "Ír"'2, - I ~ I H-3'O l ~7f - (...,~.:.; D.S:09-06 ¡.,+(~ - ;-.iJ4t-' Job# 11001218 11084270 10964140 11051039 10559825 10662950 10687720 9153241 10563182 10687694 11211415 11217253 11258699 "1 9) ....., ~,'J Log Description USIT SCMT LDL INJECTION PROFILE &~ :)'1 - roc. ., ,) !~-J C, /eV>.I.<7. INJECTION PROFILE I INJECTIO~ PROFILE (l0P~1 - r.¿c..e\V~ ::> /;}3/C."'> LDL PRODUCTION'PROFILE Œ.- Q, i - r <'<' .",.;) -ill-:'/-, LDL ('","\ i -rot.'.,.:,::'''':' IJ;:J~/(\-:<!' PRODUCTIÖN 'PROFILE SCMT US IT US IT , Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , AAohorn", A'.." 99508 G «~ Date 04/04/05 07/05/05 04/06/05 04/29/05 07/31/03 09/16/03 12/31/04 02/04/03 07/09/03 07/16/04 06/01/06 06/01/06 04/13/06 06/05-06/06 NO. 3835 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ¡~~~::~:~~v~9~~~te 100 .. a ~~'é Field: Prudhoe Bay a.DÖ-o BL Color 1 1 e CD 1 1 1 1 1 1 1 1 1 1 1 e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ."..' . ;',,"," {f"l-~. \"It::1',,,, ~ ~. . . -'" -....-\;-\~ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To~ State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joe¥ Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13S9 Stafford, TX 77497 BP Exploration [Alaska}, Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole I I 1 Res. Eval. CH I 1 1 ~so~-~o~ ~-~-o~ Mec~.O~ ~ i C1~ ,~ Caliper Survey Signed' Print Name: Date · ProActive Diagnostic Services, Inc., Po Box 1369 Stafford Tx 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Website: www.memorylog.com WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 3:33 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / deni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole I I 1 DS 02-10 5-16-03 Mech. CH 1 Caliper Survey ,Signed' Print Name: Date · ,JUN 2 0 ~ut~o ProActive Diagnostic Services, Inc., 3 IO K Street Suite 2~, Ancho~qe, AK 9v~ho~;~ ~o~c:(~0?) ~45-8~5 ] ~a~:(~0?) ~45-8~52 ~-maQ: pdsa~choTa~c~mcmo~]o~.co~ Webs jrt: ~.mcmo~]o~.co~ " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Alter Casing D Change Approved Program D Suspendr~ Repair Well Pull Tubing F'-' Operation Shutdown D Plug Perforations[~] Perforate New Pool D PerforateE~ Variance StimulateD Time Extension r- Re-enter Suspended Well Annular Disposal E] OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 4. Current Well Class: 15. Permit to Drill Number: Development [~] ExploratoryD16 200-0640 · APl Number StratigraphicD Servicer'"'] 50-029-20163-02-00 7. KB Elevation (ft): 58.32 9. Well Name and Number: 02-1 OB 10. Field/Pool(s): Prudhoe I Prudhoe Oil Pool 8. Property Designation: ADL-0028308 11. Present Well Condition Summary: Total Depth measured 11640 feet true vertical 8972 feet Effective Depth measured 10600 feet true vertical 8867 feet Plugs (measured) Junk (measured) 4-1/2" CIBP @ 10600' MD Casing Structural Length Size MD TVD Burst Collapse 100 20" 94# H-40 25 125 25 - 125 1530 520 2690 13-3/8" 72# N-80 25 2715 25 - 2714.94 4930 2670 2311 9-5/8" 47# SOO-95 25 - 2336 25 ., 2335.98 8150 5080 4820 9-5/8" 47# N-80 2336 7156 2335.98 - 7155.66 6870 4760 1939 9-5/8" 47# SOO-95 7156 9095 7155.66 - 8959,47 8150 5080 3430 4-1/2" 12.6# L-80 8210 11640 8200.82 - 8972.08 8430 7500 745 7" 32# L-80 7640 8385 7639.66 - 8370.68 9060 8600 Conductor Surface Intermediate Intermediate Intermediate Production Liner Perforation depth: Measured depth: 9280' - 10540' True vertical depth: 18980.22' - 8991.45' Tubing: ( size, grade, and measured depth) Packers & SSSV (type & measured depth) 12. Stimulation or cement squeeze summary: 5-1/2" 17# 13Cr80 @ 24' - 28' MD/4-1/2" 12.6# L-80 @ 28' - 8215' MD 7" Liner Top Packer @ 7640' MD/Baker S-3 Packer @ 8160~1~'~'. ~ ~\/~' 4-1/2" Baker ZXP Packer @ 8211' MD / NO SSV i 4 2003 13 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Avera,qe Production or Iniection Data Alaska 0il & Gas Cons. Anchorage Prior to well operation: Subsequent to operation: OiI-Bbl Gas-Mcf 1207 45.5 875 31.9 14. Attachments: Copies of Logs and Surveys run __ Daily Report of Well Operations __ X Water-Bbl Casing Pressure Tubing Pressure 7 542 6 888 5. Well Class after proposed work: ExploratoryE] Development[-~ Service 6. Well Status after proposed work: Operational Shutdown Oil[] GasF-I WAG r-I G~NJFI W~NJFI Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name ¢iprryCatron Signature D WDSPLD ISundry Number or N/A if C.C. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 10/9/03 Form 10-404 Revised 4/2003 ORIGINAL 02-10B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/16/03 MIRU CTU # 5 TO SET CIBP: KNOCK WHP W/75 BBLS 1% KCL/10 M/W. MU/RIH W/ MEM CCL/GR IN CARRIER W/3.65" DRIFT. LOG INTERVAL 10900' - 9850' W/COIL FLAG @ 10550'. POOH IN PROGRESS. 05/17/03 POOH W/MEM TOOLS. MAKE TIE-IN CORRECTION OF +9'. MU & RIH W/ WEATHERFORD 4.5" CIBP. SET DOWN @ 9480' AND 10386'. PUMPED THROUGH W/ CRUDE DOWN BACKSIDE. TIE-IN TO FLAG. SET WEATHERFORD CIBP (3.594 RUNNING OD, 1.01' LONG) W/CENTER OF ELEMENT @ 10600'. RE-TAG TO CONFIRM GOOD SET. WHP DROPPED FROM 820 PSI TO 320 PSI WHILE POOH. - WELL READY TO POP & TEST. FLUIDS PUMPED BBLS 10 Methonal 75 1% KCL Sea Water Diesel 85 TOTAL Page 1 TREE = FMC GEN 1 WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 58' BF. ELEV = KOP = 7916' Max Angle = 99 @ 10634' Datum MD = 8905' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, MN-80, ID= 12.347" Id 2715' IMinimum ID = 3.813" @ 2191' I 4-1/2" HES X NIPPLE 02-10B SAFETY NOTES: HORIZONTAL WB_L - 70° @ 9075' AND 90° @ 9670'. 2191' Id4-1/2" HES X NIP, ID= 3.813" GAS LIFT MANDRELS 1 13720137201 1 I I MMGI RE I I I I 3 176o3176o31 1 I I MMGI RE I I I ITOP OF 7" LNR Id 7640' I TOP OF 4-1/2" LNR Id 8210' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" Id 8215' I 7" LNR, 26#, L-80, .0383 bpf, ID= 6.276" Id 8385' I 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 9095' ITOP OF 9-5/8" WHIPSTOCK Id 7799' 8160' 8193' 8211' 8215' Id7" X 4-1/2" BAKER 53 PKR, ID= 3.875" Id4-1/2" HES X NIP, ID= 3.813"I 4-1/2" BAKER ZXP LINER TOP PKR I Id4'1/2'' WLEG J Id ELMD TI' NOT LOGGED 9-5/8" WINDOW 7798'- 7814' 19-5/8" EZSV Id 7821' '1 10600' H4-1/2,, WF CIBP (05/17/03) PERFORATION SUMMARY REF LOG: MVVD, GR ANGLEAT TOP PERF: 83 @ 9130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9130- 9140 O 09/26/03 DPC 4 9280 - 10540 O 06/13/00 DPC 4 10650 - 11550 C 06/13/00 I-&-~-H 11553'I I4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11640' I DATE REV BY COMMENTS DATE REV BY COMMENTS 08/06/76 ORIGINAL COMPLETION 11/12/02 /TLH DELETE WAIVER SAFETY NOTE 06/16/00 SIDETRACK (02-10B) 05/17/03 TMN/TLH ClBP SET 12/29/00 SlS-SLT CONVERTED TO CANVAS 09/30/03 JGM/TLH ADPERF 02/21/01 SlS-LG REVISION 01/31/02 RN/TP CORRECTIONS 10/12/02 JAL/KK WAIVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 02-10B PERMIT No: 2000640 APl No: 50-029-20163-02 SEC 36, T11N, R14E, 1765.36 FEL, 300.6 FNL BP Exploration (Alaska) f,. STATE OF ALASKA ,¢~' ALA§KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS -1. Operations Pedormed: AbandonF-~ Suspend~ Operation Shutdown[--~ PerforaterX"~ Variance[~ Annular DisposalF"~ Alter Casing['~ Repair Wellr-'"~ Plug PerforationsD stimulateD Time Extensionr--~ OtherB Change Approved ProgramF-~ Pull Tubing~ Perforate New Pool['-] Re-enter Suspended Well[--] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r~] Exploratory[--] 200-0640 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic BI Service [~] 50-029-20163-02-00 7. KB Elevation (ft): 9. Well Name and Number: 58.32 02-10B 8. Property Designation: 10. Field/Pool(s): ADL-0028308 Prudhoe / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11640 feet true vertical 8972 feet Plugs (measured) 4-1/2" ClBP @ 10600' MD Effective Depth measured 10600 feet Junk (measured) true vertical 8867 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100 20" 94# H-40 25 - 125 25 - 125 1530 520 Surface 2690 13-3/8" 72# N-80 ; 25 - 2715 25 - 2714.94 4930 2670 Intermediate 2311 9-5/8" 47# SOO-95 25 2336 25 - 2335.98 8150 5080 Intermediate 4820 9-5/8" 47# N-80 2336 - 7156 ' 2335.98 - 7155.66 6870 4760 Intermediate 1939 9-5/8" 47# SOO-95 7156 - 9095 ! 7155.66 - 8959.47 8150 5080 Production 3430 4-1/2" 12.6# L-80 8210 - 11640 ! 8200.82 - 8972.08 8430 7500 Liner 745 7" 32# L-80 7640 - 8385 ~ 7639.66 - 8370.68 9060 8600 Perforation depth: Measured depth: 9130' - 9140', 9280' - 10540' True vertical depth: 8966.67' - 8968', 8980.22' - 8991.45' Tubing: ( size, grade, and measured depth) 5-1/2" 17# 13Cr80 @ 24' - 28' MD/4-1/2" 12.6# L-80 @ 28' - 8215' MD Packers & SSSV (type & measured depth) 7" Liner Top Packer @ 7640' MD/Baker S-3 Packer @ 4-1/2" Baker ZXP Packer @ 8211' MD / NO SSV 12. Stimulation or cement squeeze summary: U~ I t z~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska 0il & Gas Cons. Commission 13 Representative Daily Averaqe Production or Iniection Data r~m,,,u~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 484 22.0 0 548 Subsequent to operation: 1369 29.5 13 527 14. Attachments: 15. Well Class after proposed work: Exploratory[~] Development[~] Service Copies of Logs and Surveys run __ 16. Well Status after proposed work: Operational Shutdown r-~ Oil[~-] GasE] WAG [~ GINJE] WINJE] WDSPL[-"~ Daily Report of Well Operations _ X Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact Garry CatronI N/A Printed Name Ge, rrv Catron Title Production Technical Assistant Signature ./"'-.J~l~l--~;b'i.,,4,~/-' { Phone 564-4657 Date 10/9/03 --, , 100 20" 94# H-40 25 - 125 25 - 125 1530 520 2690 13-3/8" 72# N-80 25 - 2715 25 - 2714.94 4930 2670 2311 9-5/8" 47# SOO-95 25 2336 25 - 2335.98 8150 5080 4820 9-5/8" 47# N-80 2336 - 7156 2335.98 - 7155.66 6870 4760 1939 9-5/8" 47# SOO-95 7156 - 9095 7155.66 - 8959.47 8150 5080 3430 4-1/2" 12.6# L-80 8210 - 11640 8200.82 - 8972.08 8430 7500 745 7" 32# L-80 7640 - 8385 7639.66 - 8370.68 9060 8600 Form 10-404 Revised 4/2003 ORIGINAL 6CT 1_ 2003 02-1 OB DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/25/03 MIRU CTU # 9. Run PDS tie-in log in carrier with 3" nozzle. Log 9300 to 8900. Flag pipe at 8900. POH. Recover data but depths are suspect. 09/26/03 Rerun tie in log. Log from 9300 to 8900 at 40 fpm. Flag pipe at 8900. POH and verify data. Good data. MU gun #1. (2 7/8" 10' long with 6 SPF, 60 deg phasing and random orientation.). Knock down WHP. RIH with gun#1 and Perf interval 9130' - 9140' - 2 7/8 gun - 6 SPF - Random Orient - 60 Phase. POH all shots fired. RDMO **** Notify DSO of well status. Well shut in. Ready to POP FLUIDS PUMPED BBLS Methonal 1% KCL Sea Water Diesel 0 TOTAL Page 1 TREE FMC GEN 1 WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 58' BF. ELEV = KOP = 791 Max Angle = 99 @ 10634~ Datum MD = 8905' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, MN-80, ID= 12.347" I-'~ 2715' IMinimum ID = 3.813" @ 2191' I 4-1/2" HES X NIPPLE 02-10B SAFETY NOTES: HORIZONTAL WELL - 70° @ 9075' AND 90° @ 9670'. 2191' I--~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ISTI MD I TVDIDEvlvLvlTYPEILATcHIPoRTIDATEI 1216395163951° I IMMGI .X I I I 131760317603111 IMMGI RKI I I ITOP OF 7" LNR I"~ 7640' I TOP OF 4-1/2" LNR I--~ 8210' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I'"{ 8215' I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I'"'~ 8385' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I--~ 9095' I TOP OF 9-5/8" WHIPSTOCK I"~ 7799' 8160' 8193' 8211' 8215' I--~7" X 4-1/2" BAKER S3 PKR, ID= 3.875" I--~4-1/2" HES X NIP, ID= 3.813"I I--~7" X 4-1/2" BAKER ZXP LINER TOP PKR I I--~4'1/2'' WLEG I I""~ FIMD 'CF NOT LOGGED 9-5/8" WINDOW 7798' - 7814' 19-5/8" EZSV I--~ 7821' I 10600' I--~4-1/2"WFCIBP(05/17/03)I PERFORATION SUMMARY REF LOG: MVVD, GR ANGLEAT TOP PERF: 83 @ 9130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7~8" 6 9130 - 9140 O 09/26/03 DPC 4 9280 - 10540 O 06/13/00 DPC 4 10650 - 11550 C 06/13/00 r-~-F~-i~ 11553,I I4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11640' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/06/76 ORIGINAL COMPLETION 11/12/02 /TLH DELETE WAIVER SAFETY NOTE 06/16/00 SIDETRACK (02-10B) 05/17/03 TMN/TLH CIBP SET 12/29/00 SIS-SLT CONVERTED TO CANVAS 09/30/03 JGM/TLH ADPERF 02/21/01 SIS-LG REVISION 01/31/02 RN/TP CORRECTIONS 10/12/02 JAL/KK WAIVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 02-10B PERMIT No: 2000640 APl No: 50-029-20163-02 SEC 36, T11N, R14E, 1765.36 FEL, 300.6 FNL BP Exploration (Alaska) Permit to Drill 2000640 MD 1164O TVD DATA SUBMITTAL COMPLIANCE REPORT 9~6~2O02 Well Name/No. PRUDHOE BAY UNIT 02-10B Operator BP EXPLORATION (ALASKA) INC 8972 Completion Dat 6/15/2000 ~" Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20163-02-00 UIC N REQUIRED INFORMATION Mud Log N__~o Sample Nc) Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fit Log Log Run Name Scale Media No (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH / Dataset CH Received Number Comments 2/22/2001 09902/---7-7~4-11596 7774 11596 Case R ~f MWD Survey Report 9902 LIS Verification SRVY RPT DGR/EWR-MD DGR/EWR-TVD- DGR/SLD/CTN-MD DGR/SLD/CTN-TVD MWD Formation Eval MWD LIS 2/5 2/5 2/5 2/5 FINAL FINAL FINAL FINAL FINAL FINAL FINAL 9100 10078 7739 11640 OH 7798 11640 OH 7798 8997 OH 8385 11640 OH 8385 8997 OH 7774 11569 2/2/2001 2/22/2001 2/22/2001 6/21/2000 10~24~2000 10/24/2000 10/24/2000 10/24/2000 1/9/2001 1/9/2001 9100-10078 Paper Copy 9902 ~"l~erification Digital Data LIS Verification Paper Copy SPERRY 7739.32-11640. 7798-11'640 5/25/00 THRU 7798-8997 5/25/00 THRU 8385-11640 5/25/00 THRU 8385-8997 5/25/00 TRHU 7774-11569 Digital Data Verification Listing Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/N~ Chips Received? Analysis R ~.c.~.iv~.d? Daily History Received? ~__~/N Formation Tops ~/N Comments: Permit to Drill 2000640 MD 11640 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. PRUDHOE BAY UNIT 02-10B Operator BP EXPLORATION (ALASKA) INC 8972 Completion Dat 6/15/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20163-02-00 UIC N Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 26, 2000 RE: MWD Formation Evaluation Logs - D.S. 02-10B, AK-MM-00050 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: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. AP1//: 50-029-20163-02. WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. At~.: Lofi-~[aylor 3001 Porcupine Dr. MWD Formation Evaluation Logs · D.S. 02-10B, Oetobee24~ 2000 AK-MM-00050 ,,u,,. ,oo cems to the attention of.' ~10B: 2"-x 5?lg~K~~ ~:'~ltaiy · 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-0~63-0-2- · 2" x 5" MD Neutron & Density Logs: 504O__QD,_t~2 th,'} _. 2" x 5" TVD Neutron & Density Logs: I"~ueline 1. Eolde4 Sepia 1 Blueline t-FoWed~Sepia 1 Blueline ~U',~1,4 ,-.,4 ' 1- .-,,x,,,~ Sepia 1 Blueline OCT 24 000 alaska 0il.& aaa Cons. Commissio~ Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company STATE OF ALASKA .... ALASK~ ,L AND GAS CONSERVATION COM~ 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. 'T~'~~ t, 200-064 3. Address , 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 . .,4.~,-'r~K; 50-029-20163-02 4. Location of well at surface '!~' ~i!~:i:~?~;Fi'~i,~'' ~,.9. Unit or Lease Name 1038' S~L, 4341' WEL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 677' SNL, 4519' WEL, SEC. 36, T11N, R14E, UM At total depth .-- i 10. Well Number 02-108 302' SNL, 1766' WEL, SEC. 35, T11 N, R14E, UM ~' ~.,,.,~,'/~._ I 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Desighattoh~and~tial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE -- 58.32' ADL 028308 12. Date Spudded 5/31,2000 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'6,10,2000 6,15,2000 115' Water depth' if °fish°re N/A MSL J 16. No. of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV setI 21. Thickness of Permafrost 11640 8972 FTI 11554 8971 FTI []Yes [] NoI (Nipple) 2191' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 SUrface 100' 32" 500 sx (Approx.) 13-3/8" 72# MN-80 Surface 2715' 17-1/2" ~500 sx Permafrost II 9-5/8" 47# S00~95/MN-80 Surface 7798' 12-1/4" 1500 sx Class 'G'~ 150 sx PF II 7" 26# L-80 7640' 8385' 8-1/2" 171 sx Class 'G' 4-1/2" 12.6# L-80 8211' 11640' 6-1/8" ¢17 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8215' 8160' 9280' - 10540' 8980'-8991' 10650' - 11550' 8976'- 8971' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. ;~ ~, ~' ,, ~,',n:h DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED d'..~L_ © { .E'.~b'J Freeze Protect with 154 Bbls of Diesel Anchera~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 22, 2000 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (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. ORIGINAL Form 10-407 Rev. 07-01-80 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. Sag River .8389' 8374' Sh ublik ., 8426' 8410' Sadlerochit ~8490' 8473' Zone 1 B .9065' 8950' Zone lA 9140' 8968' ',~L. © i ~..:.:i,i~.~ 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 02-1 OB 200-064 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. ~NSTRUCTIONS 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 _ eGO Page I of 5 'O i SSUmma RePort Legal Well Name: 02-10B Common Well Name: 02-1 OB Spud Date: 5/26/2000 Event Name: REENTER+COMPLETE Start: 5/25/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es · Date ~ From_- To H°U~ '~ivity C°de :'Phase , Description of Operations , , 5/25/2000 10:31 - 12:00 1.48 RIGD PRE PJSM. RD f/DS 11-28. LD derrick. RD berms & cuttings tank. Pull pits, shop, & camp away f/subbase. 12:00 - 00:00 12.00 MOVE PRE Move rig to DS 2-10B. Spot modules on well. 5/26/2000 00:00 - 06:00 6.00 RIGU PRE Set cuttings tank. Berm up & trim herculite. Raise & pin derrick. RU floor. Raise chute. Accept rig @ 0600 hrs on 5/26/00. 06:00 - 07:00 1.00 KILL DECOMP Finish taking on seawater. 07:00 - 08:00 1.00 WHSUR DECOMP RU DSM. Pull BPV. RD DSM. 08:00 - 15:00 7.00 KILL DECOMP Displace well to clean seawater. Well cleaned up slow. Monitor well-ok. 15:00 - 16:00 1.00 WHSUR DECOMP Set BPV. Test to 1000 psi from below. 16:00 - 17:30 1.50 WHSUR DECOMP ND tree & adapter. Set TTP. Function LDS. 17:30 - 19:00 1.50' WHSUR DECOMP NU DOPE. 19:00 - 22:00 3.00 WHSUR DECOMP Test DOPE to 250 / 3500 psi. Witnessing waived by Leu Grimaldi-AOGCC Field Inspector. 22:00 - 23:00 1.00 WHSUR DECOMP RU DSM. Pull TTP & BPV. RD DSM. 23:00 - 00:00 1.00 PULL DECOMP PU & MU landing jt. BOLDS. PJSM. 5/27/2000 00:00 - 02:30 2.50 PULL DECOMP Pull hanger loose w/175k max pull. Pull to floor. LD landing jt & hanger. 02:30- 03:30 1.00 PULL DECOMP CBU. 03:30 - 14:30 11.00 PULL DECOMP LD tbg to SSSV. LD SSSV & RD HES. LD tbg. LD total of 252 its 5.5" tbg + stub. Recovered 56 SS bands. 14:30 - 16:45 2.25 PULL DECOMP Test pipe rams, TIW, dart, & Hydril to 250 / 3500 psi. 16:45 - 18:00 1.25 STWHIP WEXIT Set wear ring. MU window milling assembly f/dummy run. 18:00 - 19:30 1.50 STWHIP WEXIT Cut 90' drlg line. Service TD. 19:30 - 23:30 4.00 STWHIP WEXIT Single in 4" DP to 5575'. 23:30 - 00:00 0.50 STWHIP WEXIT Held D2 Drill, followed w/Well Kill Drill. Rotated choke operators. 5/28/2000 00:00 - 03:00 3.00 STWHIP WEXIT Single in DP to 7971' (top of tubing stub). 03:00 - 04:30 1.50 STWHIP WEXlT POH to 7500'. 04:30 - 06:00 1.50 S'I'WHIP WEXIT Held D2 Drill followed by Stripping Drill. Rotate choke operators. 06:00 - 09:00 3.00 S'I'WHIP WEXIT POH to BHA @ 908'. 09:00 - 09:45 0.75 STWHIP WEXIT PU 24 jts 4" DP. 09:45 - 10:00 0.25 STWHIP WEXlT POH to BHA. 10:00 - 12:00 2.00 S'I'WHIP WEXIT LD mills. Stand back BHA. 12:00 - 16:30 4.50 STWHIP WEXIT RU SWS. RIH w/EZSV. Tie in to SWS CNL/GR dated 4/20/75. Set EZSV @ 7821 '. Tool did not shear off. Attempt to shear off w/no success. Pulled off head w/5200#. Top of set tool @ 7799'. POH & RD SWS. 16:30 - 17:30 1.00 FISH OTHR WEXlT MU BHA #2 to fish setting tool from EZSV. 17:30 - 20:00 2.50 FISH OTHR WEXIT RIH to TOF @ 7799'. 20:00 - 20:30 0.50i FISH OTHR WEXIT Latch fish. Pulled free w/30k over. Pressure DP-fish on. Set down on depth w/10k to check EZSV-OK. 20:30 - 21:00 0.50 FISH OTHR WEXIT Drop bar to open circ sub. Pump dry job. 21:00 - 23:00 2.00 FISH OTHR WEXIT POH w/fish to 575'. 23:00 - 00:00 1.00 FISH OTHR WEXlT Stand back BHA. LD fish & overshot. 5/29/2000 00:00 - 00:15 0.25 FISH OTHR WEXIT Pressure casing to 3000 psi to help ensure EZSV is set. 00:15 - 03:00 2.75 STWHIP WEXIT MU Baker whipstock / milling assembly. 03:00 - 06:00 3.00 STWHIP WEXIT RIH w/whipstock to setting depth @ 7821'. 06:00 - 06:45 0.75 STWHIP WEXIT PJSM w/Baker, Gyrodata, & SWS. 06:45 - 12:00 5.25 STWHIP WEXlT RU SWS. RIH w/gyro. Orient whipstock @ 345 deg & verify. POH. RD SWS. 12:00 - 13:00 1.00 STWHIP WEXIT Set whipstock w/15k down. verify. Shear off w/45k down. 13:00 - 14:00 1.00 STWHIP WEXIT Displace well to 10 ppg milling fluid. 14:00 - 23:30 9.50 STWHIP WEXIT Milled window f/7798'-7814'. Milled outide window to 7828'. Appeared to be good cement outside pipe. Recovered ~350# steel. D2 Drill: OS-1 min. Printed: 7/24/2000 6:24:12 PM samma RePort Legal Well Name: 02-10B Common Well Name: 02-10B Spud Date: 5/26/2000 Event Name: REENTER+COMPLETE Sta~ 5/25/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Free,To ~cti~ ~0~ phase Description of Operations 5/29/2000 23:30 - 00:00 0.50 STWHIP WEXlT Pump fiber sweep while rotating & reciprocating through window. 5/30/2000 00:00 - 01:15 1.25 STWHIP WEXIT Finish circ fiber sweep while rotating & reciprocating through window. Pump dry job. Monitor well-OK. 01:15 - 03:30 2.25 STWHIP WEXlT POH to BHA. 03:30 - 05:30 2.00 STWHIP WEXIT Stand back BHA. LD mills. 05:30 - 07:45 2.25 S'I'WHIP WEXlT Pull wear ring. Flush stack. Set wear ring. 07:45 - 11:00 3.25 STWHIP WEXIT MU BHA #4 & RIH. 11:00 - 14:30 3.50 STWHIP WEXIT RIH to top of window @ 7798'. 14:30 - 15:30 1.00 STWHIP WEXlT Service top drive. 15:30 - 15:45 0.25 S'I'WHIP WEXIT PJSM w/SWS, Sperry Sun, & Gyrodata. 15:45 - 00:00 8.25 STWHIP WEXIT RU SWS w/side door entry sub. Test, change out, repair & test gyro tools. RIH. Orient tool face to 345 deg. POH w/gyro & stand back SWS. 5/31/2000 00:00 - 00:15 0.25 DRILL WEXIT Finish POH w/o & Stand back SWS. 00:15 - 01:00 0.75 DRILL WEXIT Cycled pumps & calibrated MWD tools. Obtain magnetic toolface @ 182 deg. 01:00 - 12:30 11.50 DRILL LNR1 Ream hole to 7828'. Trying to get a handle on reactive torque in the string. Having trouble holding toolface. Drld to 7835'. Fire Drill: OS-1:30 min. 12:30 - 14:30 2.00 DRILL LNR1 PU constant readout gyro & RIH thru side entry sub to 7735'. Orient motor. 14:30 - 00:00 9.50 DRILL LNR1 Drill w/constant readout gyro 6/1/2000 !00:00 - 02:00 2.00 DRILL LNR1 Slide f/7931'-7945'. 02:00 - 04:00 2.00 DRILL LNR1 Pull 2 stds. POH w/wireline. LD gyro & side entry sub. RD SWS. RIH 2 stds. 04:00 - 00:00 20.00 DRILL LNR1 Drld to 8363'. D2 Drill: OS-1 min. 6/2/2000 00:00 - 01:00 1.00 DRILL LNR1 Drld to 8385'. 01:00 - 02:30 1.50 DRILL LNR1 Rotate & reciprocate while circ samples up. Pump sweep. 02:30 - 03:30 1.00 DRILL LNR1 Orient motor. POH above window. No problems. ,03:30 - 04:00 0.50 DRILL LNR1 Run back to bottom. No problems. 04:00 - 06:00 2.00 DRILL LNR1 Pump sweep while rotate & reciprocate. 06:00 - 09:30 3.50 DRILL LNR1 Drop rabbit & single shot. Pump dry job. POH to 2000'. SLM. 09:30 - 11:30 2.00 DRILL LNR1 Slip & cut drlg line. Service TD. 11:30 - 12:00 0.50 DRILL LNR1 POH to BHA. SLM-No correction. 12:00 - 15:00 3.00 DRILL LNR1 LD BHA #4. 15:00 - 16:30 1.50 CASE LNR1 Fix hydraulic leak under drawworks. 16:30 - 17:30 1.00 CASE LNR1 RU casing tools. 17:30 - 18:00 0.50 CASE LNR1 PJSM. 18:00 - 20:00 2.00 CASE LNR1 PU & Run 18 jts 7", 26#, L-80 BTC-Mod. 20:00 - 20:30 0.50 CASE LNR1 MU 9 5/8" x 7" Baker liner top packer & hanger assembly. Circ liner volume. 20:30 - 00:00 3.50 CASE LNR1 RIH w/liner. Fill pipe every 10 stds. 6/3/2000 00:00 - 02:30 2.50 CASE LNR1 Continue RIH w/liner to window. 02:30 - 03:00 0.50 CASE LNR1 CBU & MU cement head. 03:00 - 03:30 0.50 CASE LNR1 Run liner to bottom @ 8385'. 03:30 - 06:00 2.50 CEMT LNR1 Circ &cond mud for cement. Held PJSM while circulating. D2 Drill: OS-1:15 min. 06:00 - 07:15 1.25 CEMT LNR1 Cement 7" liner as per procedure w/171 sxs (36 bbls) batch mixed Premium 'G'. Displace w/rig. Bumped plug w/calculated strokes to 3300 psi to set hanger & liner top packer. Floats held-OK. Unsting w/ pressure on DP. Set down 60k to set liner top packer. 07:15 - 08:30 1.25 CEMT LNR1 Circ 17 bbls cement from top of liner while reciprocating. 08:30 - 12:00 3.50 CEMT LNR1 POH. LD liner setting tool. Printed: 7/24/2000 6:24:12 PM summa RePort Legal Well Name: 02-10B Common Well Name: 02-10B Spud Date: 5/26/2000 Event Name: REENTER+COMPLETE Start: 5/25/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es ActMty ~ode; ;: ;:;~has~ Description of Operations 6/3/2000 12:00 - 12:15 0.25 BOPSUF LNR1 Pull wear ring. 12:15 - 16:15 4.00 BOPSUF LNR1 Set test plug. Test DOPE to 250 / 3500 psi. Witnessing waived by John Spaulding-AOGCC Field Inspector. Pull Test plug. 16:15 - 16:30 0.25 BOPSUF LNR1 Set wear ring. 16:30 - 23:00 6.50 DRILL LNR1 MU BHA. Set PDM kick sub. Calibrated MWD/LWD tools. Oriented MWD. PJSM. Loaded LWD nuclear sources. Function tested tools. 23:00 - 00:00 1.00 DRILL LNR1 PU extra DP. 6/4/2000 00:00 - 03:00 3.00 DRILL LNR1 Finish picking up total of 126 jts 4" DP. 03:00 - 04:00 1.00 DRILL LNR1 RIH by stands from derrick to 6496 ft. 04:00 - 04:30 0.50 DRILL LNR1 Held pipe stripping drill. 04:30 - 05:00 0.50 DRILL LNR1 Held well kill drill - D5. 05:00 - 06:00 1.00 DRILL LNR1 RIH by stands from derrick to cement bridge at 8235 ft. 06:00 - 07:00 1.00 DRILL LNR1 Wash cement stringers from liner 8225-8301 ft. 07:00 - 09:00 2.00 DRILL LNR1 Circulate bottoms up and conditon mud. 09:00 - 09:30 0.50 DRILL LNR1 Tested 9 5/8" casing and 7" liner to 3000 psi for 30 rains. - OK. 09:30 - 12:30 3.00 DRILL LNR1 Drilled cement from float collar and casing shoe interval 8301-8378 ft. 12:30 - 15:30 3.00 DRILL LNR1 Pumped 50 bbl. N-Vis spacer and displaced 10.3 ppg mud from hole with 8.3 ppg Baroid QuikDriI-N mud. 15:30 - 16:30 1.00 DRILL LNR1 Drilled cement and float shoe and 20 ft. of new hole to 8410 ft. 16:30 - 17:00 0.50 DRILL LNR1 Circulate and condition mud for FIT test. 17:00 - 17:30 0.50 DRILL LNR1 Performed FIT test to 530 psi (9.5 ppg EMW) - OK 17:30 - 00:00 6.50 DRILL PROD1 Drilled by rotating to 8538 ft. 6/5/2000 00:00 - 06:00 6.00 DRILL PROD1 Drilled from 8538 ft. to 8720 ft. 06:00 - 12:00 6.00 DRILL PROD1 Drilled from 8720 ft. to 8874 ft. 12:00 - 00:00 12.00 DRILL PROD1 Drilled from 8874 ft. to 9116 ft. 6/6/2000 00:00 - 18:30 18.50 DRILL PROD1 Drlg 6.125" Hole to 9369; ART 14 AST 1.5 hrs 18:30 - 20:30 2.00 DRILL PROD1 Pump Hi Vis Sweep 20:30 - 21:30 1.00 DRILL PROD1 Drop ESS Tool & POH to Chk Point @ 8907 Bit Depth, Continue POH into 7" Liner (No Problems) 21:30 - 22:00 0.50 DRILL PROD1 Pump Dry Job, Install Stripping Rubbers & Air Slips 22:00 - 00:00 2.00 DRILL PROD1 Continue POH for Bit 6/7/2000 00:00 - 01:30 1.50 DRILL PROD1 POH W/BHA 01:30 - 03:00 1.50 DRILL PROD1 Remove ESS, Sources, DWN Load MWD 03:00 - 03:30 0.50 DRILL PROD1 Handle BHA 03:30 - 05:30 2.00 DRILL PROD1 Surf CHK MWD 05:30 - 06:00 0.50 DRILL PROD1 Service Top Drive 06:00 - 09:30 3.50 DRILL PROD1 RIH 09:30 - 10:30 1.00 DRILL PROD1 CBU 10:30 - 12:00 1.50 DRILL PROD1 Drlg f/9369 to 9370, Motor Failed 12:00 - 13:00 1.00 DRILL MOTR PROD1 POH Into Liner, Flow Check 13:00 - 13:30 0.50 DRILL MOTR PROD1 Pump Dry Job, Install Rubbers, Air Slips 13:30- 16:00 2.50 DRILL MOTR PROD1 Continue POH 16:00 - 17:30 1.50 DRILL MOTR PROD1 Handle BHA 17:30 - 18:30 1.00 DRILL MOTR PROD1 DownLoad & ReProgram MWD 18:30-21:30 3.00 DRILL MOTR PROD1 RIHto6000' 21:30 - 22:30 1.00 DRILL MOTR PROD1 Cut & Slip Drlg Line 22:30 - 00:00 1.50 DRILL MOTR PROD1 Contkinue RIH, Take Check Shot 6/8/2000 00:00 - 00:30 0.50 DRILL MOTR PROD1 Continue RIH to 9355 00:30 - 01:00 0.50 DRILL MOTR PROD1 Overlap MWD f/9355-9370 01:00 - 00:00 23.00 DRILL PROD1 DRLG & Slide to 10293, AST 1.5, ART 11.5 6/9/2000 00:00 - 00:00 24.00 DRILL PROD1 DRLG & SLIDE to PD. AST:6 ART:13 6/10/2000 00:00 - 16:00 16.00 DRILL PROD1 DRLG to TD, ART 8.25, AST 2.75 Hm 16:00 - 18:00 2.00 DRILL PROD1 Circ Sweep Around, Flow Check, Well Static Printed: 7/24/2000 6:24:12 PM -. Bp AMOCO Page 4 of 5 - i ti°ns SUmmary Report Legal Well Name: 02-1 OB Common Well Name: 02-1 OB Spud Date: 5/26/2000 Event Name: REENTER+COMPLETE Start: 5/25/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Date From-To HoUrs Activity Code PhaSe ,, Description of Operations 6/10/2000 18:00 - 20:00 2.00 DRILL PROD1 POH F/11640-8385, Flow Check @ Shoe; Loss Rate 4 BPH, Minor Overpulls BTM 9 STDS 20:00 - 22:00 2.00 DRILL PROD1 RIH Slow, Loss Rate 4 BPH, Hole Clean, Took CHK Shot @ 8849, OK 22:00 - 00:00 2.00 DRILL PROD1 ClRC Sweep Around, Spot Liner PIll 6/11/2000 00:00 - 01:30 1.50 DRILL PROD1 Finish Circ Sweep Around, Spot 125 BBL Liner Running Pill 01:30 - 03:00 1.50 DRILL PROD1 POH f/11640-8385, OK, DROP DRIFT, SLM 03:00 - 06:30 3.50 DRILL PROD1 Pump Slug, POH, SLM 06:30 - 08:30 2.00 DRILL PROD1 L/D BHA, Down Load Sperry Data 08:30 - 09:00 0.50 DRILL PROD1 Clean Drill Floor, Prep to Run LNRa 09:00 - 09:30 0.50 DRILL PROD1 RIG UP CSG Tools 09:30 - 14:30 5.00 DRILL PROD1 P/U 83 Jts, 4.5" 12.6# L80,1Bt-MOD R3 Liner & Baker HGR/Liner Top PKR, Circ Liner Cap, Liner Wt 27K 14:30 - 17:30 3.00 DRILL PROD1 RIH w/Liner on 4" DP to 7" Shoe 17:30 - 19:00 1.50 DRILL PROD1 Break Circ, Displace Liner & DP Content 19:00 - 20:30 1.50 DRILL PROD1 Run Liner to TD @ 11640, Worked Thru Bridges, 8 bbl short on Displacement RIH 20:30 - 22:00 1.50 DRILL PROD1 Circ & Reciprocate (12' Stroke), Full Returns 22:00 - 23:30 1.50 DRILL PROD1 PJSM, Pump 5 BBL B45 Spacer @ 9.5 ppg, PT Lines to 4400, pump 25 more Spacer, 87 bbl (417 sx) Class G @ 15.8 #/gal, Launch Dart Chased with 85 bbl Perf Pill, Displace W/Mud, Observe Dart Latch Liner ~ Plug, Bump Plug to 2500, Reciprocated Through out,Continue Pressure ~ '~ ~'~ ~>~'~' Up to 4200 to Hang Liner, Bled Off Floats Held, Set Down 60 K Confirm Liner Hung, Rotate & Release From Liner, P/U & Note Loss of Liner 23:30 - 00:00 0.50 DRILL PROD1 Cim & Max Rate 6/12/2000 00:00 - 00:30 0.50 DRILL LNR2 Finish Circ CMT Contaminated Mud 00:30 - 04:30 4.00 DRILL LNR2 PJSM; Displace Mud to Seawater Until Clean Returns 04:30 - 05:00 0.50 DRILL LNR2 L/D CMT Head & Hoses, Clean Out under Shakers & Mix Dry Job 05:00 - 08:00 3.00 DRILL LNR2 Pump Dry Job & POH W/Liner Set Tool 08:00 - 08:30 0.50 DRILL LNR2 Break & L/D Set Tool 08:30 - 09:00 0.50 DRILL LNR2 Clean Rig Floor 09:00 - 10:30 1.50 BOPSUF LNR2 Pull Wear Bushing, Set Test Plug, Test Top Rams, IBOP, HCR, Floor Valves,Man Chore & Kil, Hydril to 250 Iow, 3500 high 10:30 - 20:30 10.00 BOPSUF LNR2 Remove Door On Off Driller Side, Bottom Ram, replace same, Test 250/3500 OK. Attempt to Test Blind/Shear Rams, Failed, Change to Blind Rams, Test Same, OK 20:30 - 21:00 0.50 BOPSUI; LNR2 Pull Test Plug, Set Wear Ring 21:00 - 22:00 1.00 CASE LNR2 R/U Test CSG to 3000 psi, 30 Min, OK, R/D 22:00 - 00:00 2.00 PERF LNR2 PJSM, P/U & Run DP Con Perf Guns 6/13/2000 00:00 - 01:30 1.50 PERF LNR2 . PJSM FOR Crew Change, Continue P/U Guns 01:30 - 03:00 1.50 PERF LNR2 P/U & Run 35 Jts 2 7/8 PAC DP 03:00 - 06:30 3.50 PERF LNR2 RIH w/4" DP, No Problems Getting Into Liner Tops 06:30 - 08:00 1.50i PERF LNR2 Locate On LC, Position Guns, PJSM, R/U Sound Recorder, Pressure Up & Bleed Off, Initiate Firing Sequence, Positive Indication Of Fire 08:00 - 09:00 1.00 PERF LNR2 Well On Trip Tank, POH, F/11551-9300, Hole Taking Fluid @ 9 BPH Seawater 09:00 - 10:30 1.50 PERF LNR2 Circ Clean Seawater, Loss Rate 15 BPH Printed: 7/24/2000 6:24:12 PM Legal Well Name: 02-1 OB Common Well Name: 02-10B Spud Date: 5/26/2000 Event Name: REENTER+COMPLETE Start: 5/25/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Fr~ iTo ActiVitY' C~ :~hase Description of Operations 6/13/2000 10:30 - 15:30 5.00 PERF LNR2 POH, L/D DP (192its) 15:30 - 16:00 0.50 PERF LNR2 ! R/U Floor 16:00 - 17:00 1.00 PERF LNR2 POH & L/D 35 Jts 2 7/8 DP 17:00 - 22:00 5.00 PERF LNR2 PJSM Prior to Gun Recovery, Recovered Guns, All Shots Fired 22:00 - 22:30 0.50 PERF LNR2 Clean Floor of Gun Debris 22:30 - 00:00 1.50 PERF LNR2 RIH W/Excess 4" DP f/derrick, Hole Taking 4-9 BPH 6/14/2000 00:00 - 00:30 0.50 PERF LNR2 RIH w/Excess 4" DP f/derrick 00:30 - 04:30 4.00 PERF LNR2 POH L/D 189 Jts 04:30 - 05:30 1.00 PERF LNR2 Slip & Cut Drlg Line 05:30 - 06:00 0.50 RUNCO~ COMP Service Top Drive 06:00 - 06:30 0.50 RUNCOI~ COMP Pull Wear Bushing 06:30 - 07:00 0.50 RUNCOI~ COMP PJSM 07:00 - 07:30 0.50 RUNCOI~I COMP R/U to Run TBG 07:30 - 14:00 6.50 RUNCOI~I COMP Run Completion 14:00 - 15:00 1.00 RUNCOI~ COMP Tag Up, Space Out 15:00 - 16:00 1.00 RUNCOI~ COMP M/U HGR & Land in Wellhead, RILDS 16:00 - 19:00 3.00 RUNCOI~I COMP Reverse Circ Clean Seawater @ 3 bbl/min, Spot inhibitor, drop ball 19:00 - 23:30 4.50 RUNCOI~I COMP Pressure TBG to 3500 for 30 min.OK Set PKR, Bled TBG to 1500. PT Annulus to 3000, TBG Started Tracking Annulus @ 1900 psi. Test Annulus 3000K for 30 Min. Bled Off TBG to Shear RP, did not Shear. Repressure Annulus, Would Circ, Annulus to TBG, Pressure & Bleed off Cycle Tbg & Annulus, Able to Shear RP & Circ 23:30 - 00:00 0.50 RUNCOI~ COMP Blow Down Lines, Prep to Set BPV & N/D N/U 6/15/2000 00:00 - 00:30 0.50 RUNCOI~ COMP Blow Down & Rig Down Lines, Install BPV 00:30 - 01:30 1.00 RUNCOI~ COMP N/D BOP 01:30 - 03:00 1.50 RUNCOI~ COMP N/U TBG SPL Adapter Flange Test to %000 10 Min 03:00 - 04:00 1.00 WHSUR COMP R/U DSM, Pull BPV, Set Test Plug 04:00 - 05:00 1.00 WHSUR COMP Test Tree to 5000,OK 05:00 - 06:30 1.50 RUNCOk COMP R/U HB&R, Pump 154 bbl freeze protection 06:30 - 08:00 1.50 RUNCO~ COMP Hook Up Line, "U" Tube Freeze Protection 08:00 - 08:30 0.50 RUNCO~ COMP Set BPV 08:30 - 09:00 0.50 RUNCO~ COMP !Blow Down & Rig Down Lines, Secure Tree & Cellar, RIG Released from DS 2-10B S.T. 0900 Hrs 15 Jun 00 . ..,. ~ ~, .~.~.~ Printed: 7/24/2000 6:24:12 PM North Slope Alaska Alaska State Plane 4 PBU_EOA DS O2 02-10 - 2-10B Surveyed: 10 June, 2000 SURVEY REPORT 19 June, 2000 Your Ref: AP1-500292016302 Surface Coordinates: 5950164.00 N, 687691.01 E (70° 16' 07.2425" N, 148° 28' 55.5408" W) Kelly Bushing: 58.32ft above Mean Sea Level DRILLINI~ SIEi RV I I~ E S Survey Ref: s vy9821 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 02-10 - 2-10B Your Ref: API-500292016302 Surveyed: 10 June, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 7739.32 0.500 249.001 7680.56 7738.88 7798.00 0.550 243,710 7739.24 7797.56 7823.00 2.100 348.100 7764.24 7822.56 7858.00 5.000 3.900 7799.17 7857.49 7893.23 8.530 0.460 7834.15 7892.47 7915.57 10.430 358.870 7856.18 7914.50 7944.68 11,870 357.580 7884.74 7943.06 7976.49 13.550 356.640 7915.77 7974.09 8006.76 13.710 355.860 7945.19 8003.51 8037.61 13.570 355.250 7975.17 8033.49 8069.13 14.010 348.450 8005.78 8064.10 8100.41 14.050 348.750 8036.13 8094.45 8131.25 13.980 344.350 8066,05 8124.37 8163.34 14.250 339.620 8097.17 8155.49 8194.04 14.140 339.900 8126.93 8185.25 8225.35 13.920 340.790 8157.31 8215.63 8256.83 13.870 340,010 8187,87 8246.19 8349.66 13.940 338.850 8277.98 8336.30 8396.00 14.160 339.350 8322.93 8381.25 8484.87 13.310 340.330 8409.26 8467.58 8579.54 17.100 329.970 8500,62 8558.94 8669.12 17.700 329.020 8586.10 8644.42 8703.90 17.390 327.380 8619.26 8677.58 8734.56 17.200 327.300 8648.53 8706.85 8764.20 18.760 319.560 8676.73 8735.05 17,50 N 38.19 E 17.28 N 37.70 E 17,68 N 37.50 E 19.83 N 37.47 E 23,97 N 37.60 E 27.65 N 37.57 E 33.28 N 37.39 E 40.27 N 37.03 E 47.38 N 36.57 E 54.64 N 36.00 E 62.06 N 34.93 E 69.49 N 33.43 E 76.75 N 31.70 E 84.19 N 29.28 E 91.25 N 26.67 E 98.40 N 24.12 E 105.52 N 21.58 E 126.41N 13.75 E 136.92 N 9.73 E 156.72 N 2.46 E 179.05 N 8.18W 202.12 N 21.78W 211.03 N 27.31W 218.71 N 32.23W 226.02 N 37.69W Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100ft) 5950182.45 N 687728.75 E 5950182.22 N 687728.27 E 0.119 5950182.61 N 687728.06 E 9.197 5950184.76 N 687727.97 E 8.667 5950188.90 N 687728.00 E 10.081 5950192.58 N 687727.88 E 8.585 5950198.20 N 687727.56 E 5.020 5950205.18 N 687727.03 E 5.321 5950212.28 N 687726.38 E 0.805 5950219.52 N 687725.64 E 0.651 5950226.91 N 687724.39 E 5.325 5950234.31N 687722,70 E 0.265 5950241.52 N 687720.79 E 3.462 5950248.89 N 687718.18 E 3.691 5950255.89 N 687715.40 E 0.422 5950262.97 N 687712.67 E 0.984 5950270,03 N 687709.96 E 0.616 5950290.71N 687701.60 E 0.310 5950301,12 N 687697.33 E 0.542 5950320.73 N 687689.56 E 0.992 5950342.79 N 687678.37 E 4.911 5950365.52 N 687664.19 E 0.741 5950374.29 N 687658.45 E 1.678 5950381.84 N 687653.34 E 0.625 5950389.01 N 687647.70 E 9.616 Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) Comment -33.68 -33.24 -32.96 -32.48 -31.74 -30.94 -29.58 -27.77 -25.82 -23.75 -21.15 -18.12 -14.91 -10.98 -6,95 -2.96 1.01 13.06 19.18 30.45 45.53 63.67 70.94 77.35 84.23 Tie-on Survey Window Point Continued... 19 June, 2000- 9:59 -2- DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 02-10 - 2-10B Your Ref: API-500292016302 Surveyed: 10 June, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8795.14 18.940 319.540 8706.01 8764.33 8825.36 22.910 319.190 8734.23 8792.55 8855.45 31.390 317.760 8760.98 8819.30 8887.32 39.300 317.600 8786.96 8845.28 8921.65 47.620 316.740 8811.85 8870.17 8950.02 52.730 313.540 8830.02 8888.34 8983.75 54.100 313.370 8850.12 8908.44 9013.74 56.040 310.200 8867.30 8925.62 9042.88 63.310 306.740 8882.00 8940.32 9075.24 69.600 302.270 8894.93 8953.25 9108.82 77.620 298.390 8904.40 8962.72 9t36.20 82.610 291.670 8909.10 8967.42 9165.04 84.950 290.570 8912.23 8970.55 9198.20 85.200 291.820 8915.08 8973.40 9229.95 85.450 291.820 8917.66 8975.98 9259.31 85.080 291.910 8920.09 8978.41 9289.51 85.550 288.700 8922.55 8980.87 9297.85 86.680 286.970 8923.12 8981.44 9332.15 88.110 278.310 8924.68 8983.00 9363.50 85.990 277.780 8926.29 8984.61 9391.79 85.140 275.910 8928.48 8986.80 9426.00 85.900 274.960 8931.15 8989.47 9456.94 88.020 273.900 8932.80 8991.12 9484.67 88.650 274.360 8933.60 8991.92 9518.11 88.990 274.080 8934.29 8992.61 233.63 N 44.17W 241.82 N 51.20W 252.07 N 60.31W 265.69 N 72.72W 282.98 N 88.77W 298.40 N 104.14W 317.03 N 123.80W 333.40 N 142.14W 349.02 N 161.83W 365.78 N 186.27W 382.02 N 214.06W 393.41N 238.48W 403.74 N 265.23W 415.68 N 296.03W 427.44 N 325.41W 438.34 N 352.56W 448.78 N 380.79W 451.33 N 388.71W 458.82 N 422.11W 463.20 N 453.11W 466.56 N 481.11W 469.79 N 515.06W 472.18 N 545.86W 474.17 N 573.51W 476.63 N 606.85W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5950396.46 N 687641.03 E 5950404.47 N 687633.80 E 5950414.49 N 687624.43 E 5950427.79 N 687611.69 E 5950444.68 N 687595.21 E 5950459.71 N 687579.46 E 5950477.84 N 687559.34 E 5950493.76 N 687540.60 E 5950508.87 N 687520.53 E 5950525.02 N 687495.67 E 5950540.56 N 687467.49 E 5950551.34 N 687442.79 E 5950561.00 N 687415.80 E 5950572.17 N 687384.71 E 5950583.19 N 687355.05 E 5950593.41N 687327.63 E 5950603.15 N 687299.15 E 5950605.50 N 687291.17 E 5950612.15 N 687257.59 E 5950615.76 N 687226.49 E 5950618.42 N 687198.42 E 5950620.80 N 687164.39 E 5950622.42 N 687133.54 E 5950623.73 N 687105.86 E 5950625.35 N 687072.46 E 0.582 13.143 28.264 24.821 24.296 19.983 4.082 10.813 26.966 23.193 26.325 30.271 8.956 3.831 0.787 1.297 10.707 24.736 25.563 6.970 7.243 3.550 7.658 2.813 1.317 Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) Comment 92.16 100.75 111.81 126.80 146.11 164.38 187.51 208.87 231.40 258.81 289.38 315.65 343.97 376.59 407.78 436.61 466.40 474.68 508.91 540.14 568.22 602.10 632.71 660.16 693.28 Continued... 19 June, 2000 - 9:59 - 3 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 02-10 - 2-10B Your Ref: API-500292016302 Surveyed: 10 June, 2000 9548.65 89.250 273.550 8934.76 9576.34 87.780 273.170 8935.48 9611.00 87.310 273.550 8936.96 9641.84 88.900 271.430 8937.98 9669.83 90.430 272.250 8938.14 9700.92 90.660 271.960 8937.85 9735.31 90.130 272.320 8937.61 9763.35 88.830 272.510 8937.87 9795.50 88.720 272.490 8938.55 9827.00 88.900 273.550 8939.21 9852.20 89.080 273.250 8939.65 9889.58 89.340 273.550 8940.17 9920.47 88.900 273.900 8940.64 9951.91 88.830 275.110 8941.26 9982.59 88.990 274.960 8941.85 10014.20 88.990 275.310 8942.41 10045.50 88.650 275.080 8943.05 10075.40 88.630 275.310 8943.76 10109.20 88.460 275.490 8944.62 10138.30 88.650 276.840 8945.35 10170.20 88.630 276.370 8946.11 10201.70 88.720 277.070 8946.84 10231.70 87.660 276.880 8947.78 10263.30 87.050 276.370 8949.24 10297.50 88.280 275.840 8950.64 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8993.08 478.67 N 637.32W 8993.80 480.29 N 664.95W 8995.28 482.32 N 699.52W 8996.30 483.66 N 730.31W 8996.46 484.56 N 758.29W 8996.17 485.70 N 789.35W 8995.93 486.98 N 823.72W 8996.19 488.16 N 851.73W 8996.87 489.57 N 883.84W 8997.53 491.22 N 915.29W 8997.97 492.72 N 940.44W 8998.49 494.94 N 977.76W 8998.96 496.94 N 1008.58W 8999.58 499.41N 1039.91W 9000.17 502.10 N 1070.47W 9000.73 504.93 N 1101.95W 9001.37 507.77 N 1133.11W 9002.08 510.47 N 1162.88W 9002.94 513.65 N 1196.52W 9003.67 516.78 N 1225.44W 9004.43 520.44 N 1257.12W 9005.16 524.13 N 1288.40W 9006.10 527.77 N 1318.16W 9007.56 531.41N 1349.51W 9008.96 535.05 N 1383.49W 5950626.63 N 687041.95 E 5950627.56 N 687014.29 E 5950628.73 N 686979.68 E 5950629.30 N 686948.86 E 5950629.50 N 686920.88 E 5950629.86 N 686889.79 E 5950630.29 N 686855.40 E 5950630.77 N 686827.37 E 5950631.37 N 686795.23 E 5950632.25 N 686763.75 E 5950633.12 N 686738.57 E 5950634.40 N 686701.22 E 5950635.64 N 686670.36 E 5950637.33 N 686638.97 E 5950639,25 N 686608,35 E 5950641.30 N 686576.82 E 5950643.35 N 686545.59 E 5950645.32 N 686515.76 E 5950647.66 N 686482.05 E 5950650.06 N 686453.06 E 5950652.94 N 686421.30 E 5950655.84 N 686389.95 E 5950658.74 N 686360.10 E 5950661.60 N 686328.67 E 5950664.38 N 686294.61E Dogleg Rate (°/100fi) 1.933 5.483 1.743 8.59O 6.202 1.190 1.863 4.685 0.348 3.413 1.388 1.062 1.820 3.854 0.715 1.107 1.311 0.772 0.732 4.683 1.474 2.240 3.590 2.515 3.916 Alaska State Plane 4 PBU_EOA DS O2 Vertical Section (ft) Comment 723.50 750.86 785.08 815.47 843.01 873.63 907.50 935.14 966.83 997.93 1022.83 1059.78 1090.34 1121.49 1151.94 1183.31 1214.37 1244.05 1277.61 1306.54 1338.29 1369.64 1399.50 1430.93 1464.91 Continued... 19 June, 2000 - 9:59 -4 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 02-10 - 2-10B Your Ref: API-500292016302 Surveyed: 10 June, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10325.70 91,290 274.700 8950.74 9009.06 10359.90 92.250 274.080 8949.69 9008.01 10391.40 92.780 274.080 8948.30 9006.62 10419.10 94.060 273.570 8946.65 9004.97 10453.00 96.560 272.490 8943.51 9001.83 10481.60 96,830 273.200 8940.18 8998.50 10512.10 97,150 273.430 8936.47 8994.79 10543.70 96,920 274.080 8932.60 8990.92 10575.10 97.090 274.430 8928.77 8987.09 10603.00 98,020 273.790 8925.10 8983.42 10634.40 99.030 273.720 8920.45 8978.77 10668.90 97.710 275.310 8915.42 8973.74 10697.10 94.370 276.810 8912.46 8970.78 10731.60 93.660 276.190 8910.04 8968.36 10763.00 93.830 276.540 8907.99 8966.31 10789.20 93,140 278.150 8906.40 8964,72 10824.10 91.370 277,950 8905.02 8963.34 10855.00 89.430 279.010 8904.81 8963.13 10883.40 89.570 278.610 8905.06 8963.38 10917,60 91.100 279.190 8904.86 8963.18 10947.80 91.630 280,240 8904.14 8962.46 '10976.00 91.840 281.700 8903.28 8961.60 11007.00 90.840 281.650 8902.56 8960.88 11043.30 90.480 281.130 8902.14 8960.46 11070.10 89,080 282.120 8902.24 8960.56 537.64 N 1411.57W 540.25 N ~1445.65W 542.49 N 1477.04W 544.34 N 1504.63W 546.12 N 1538.33W 547.53 N 1566.70W 549.28 N 1596.92W 551.34 N 1628.22W 553.65 N 1659.30W 555.63 N 1686.89W 557.66 N 1717.87W 560.35 N 1751.90W 563.31 N 1779.78W 567.21N 1813.97W 570.68 N 1845.11W 574.02 N 1871.05W 578.91N 1905.58W 583.46 N 1936.13W 587.81 N 1964.20W 593.10 N 1997.99W 598.20 N 2027.74W 603.56 N 2055.41W 609.83 N 2085.76W 617.00 N 2121.35W 622.40 N 2147.60W 5950666.27 N 686266.48 E 5950668.04 N 686232.34 E 5950669.49 N 686200.90 E 5950670.65 N 686173.28 E 5950671.59 N 686139.54 E 5950672.29 N 686111.14 E 5950673.29 N 686080.89 E 5950674.56 N 686049.55 E 5950676.10 N 686018.42 E 5950677.39 N 685990.79 E 5950678,65 N 685959.77 E 5950680.49 N 685925.69 E 5950682.76 N 685897.74 E 5950685.80 N 685863.46 E 5950688,50 N 685832.24 E 5950691.19 N 685806.23 E 5950695.21N 685771.59 E 5950699.01 N 685740.93 E 5950702.65 N 685712.76 E 5950707.10 N 685678.86 E 5950711.45 N 685648.98 E 5950716.12 N 685621.18 E 5950721.64 N 685590.69 E 5950727.92 N 685554.94 E 5950732.66 N 685528.56 E Dogleg Rate (°/100fl) 11.413 3.341 1,683 4.973 8.028 2.640 1.289 2.167 1.232 4.035 3.224 5.952 12.971 2.729 1.237 6.675 5.104 7.154 1.492 4.784 3.894 5.228 3.230 1.742 6.398 Alaska State Plane 4 PBU_EOA DS O2 Vertical Section (ft) Comment 1492.91 1526.78 1557.94 1585.30 1618.63 1646.67 1676.59 1707.62 1738,49 1765.88 1796.60 1830.43 1858.32 1892.57 1923.74 1949.81 1984.59 2015.43 2043.78 2077.92 2108.09 2136.27 2167.26 2203.55 2230.35 Cont~ued... 19 June, 2000 - 9:59 - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 02-10 - 2-10B Your Ref: API-500292016302 Surveyed: 10 June, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (fi) (ft) (fi) (fi) Global Coordinates Northings Eastings (ft) (ft) 11098.80 85.930 281.180 8903.49 8961.81 628.19 N 2175.67W 11130.50 86.520 281.830 8905.58 8963.90 634.50 N 2206.67W 11162.30 87.290 280.760 8907.30 8965.62 640.72 N 2237.81W 11195.40 88.900 280.600 8908.40 8966.72 646.85 N 2270.32W 11225.10 88.720 281.830 8909.01 8967.33 652.63 N 2299.44W 11255.30 89.200 282.360 8909.56 8967.88 658.95 N 2328.97W 11288.90 89.250 281.130 8910.02 8968.34 665.79 N 2361.86W 11320.70 89.250 281.650 8910.43 8968.75 672.07 N 2393.03W 11349.80 89.260 282.640 8910.81 8969.13 678.19 N 2421.48W 11382.60 89.160 281.480 8911.26 8969.58 685.04 N 2453.55W 11412.50 89.160 280.770 8911.70 8970.02 690.81 N 2482.88W 11443.40 89.630 281.630 8912.03 8970.35 696.81 N 2513.19W 11477.50 89.600 281.130 8912.26 8970.58 703.54 N 2546.62W 11508.60 89.340 281.480 8912.54 8970.86 709.64 N 2577.12W 11537.10 90.180 281.830 8912.66 8970.98 715.40 N 2605.03W 11581.30 89.250 281.830 8912.88 8971.20 724.46 N 2648.29W 11640.00 89.250 281.830 8913.65 8971.97 736.49 N 2705.74W 5950737.75 N 685500.35 E 5950743.28 N 685469.21 E 5950748.72 N 685437.92 E 5950754.04 N 685405.27 E 5950759.09 N 685376.01 E 5950764.67 N 685346.34 E 5950770.69 N 685313.28 E 5950776.19 N 685281.97 E 5950781.60 N 685253.38 E 5950787.65 N 685221.14 E 5950792.69 N 685191.67 E 5950797.93 N 685161.22 E 5950803.82 N 685127.64 E 5950809.16 N 685097.00 E 5950814.22 N 685068.95 E 5950822.20 N 685025.48 E 5950832.79 N 684967.75 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.206° (27-May-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 282.100° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11640.00ft., The Bottom Hole Displacement is 2804.18ft., in the Direction of 285.227° (True). Dogleg Rate (°/100ft) 11.453 2.766 4.141 4.888 4.185 2.368 3.663 1.635 3.402 3.549 2.374 3.172 1.469 1.402 3.193 2.104 0.000 Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) Comment 2259.02 2290.65 2322.40 2355.47 2385.16 2415.35 2448.95 2480.74 2509.84 2542.64 2572.53 2603.42 2637.52 2668.61 2697.11 2741.31 2800.01 Projected Survey Cont~ued... 19 June, 2000 - 9:59 - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 02-10 - 2- lOB Your Ref: API-500292016302 Surveyed: 10 June, 2000 North Slope Alaska Alaska State Plane 4 PBU_EOA DS O2 Comments Measured Depth (ft) 7739.32 7798.00 11640.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7738.88 17.50 N 38.19 E 7797.56 17.28 N 37.70 E 8971.97 736.49 N 2705.74 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 11640.00 8971.97 Survey Tool Description MWD Magnetic 19 June, 2000- 9:59 - 7- DrillQuest 1.05.05 19-Jun-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2-10B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 7,739.32' MD 7,798.00' MD 11,640.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) JUN 2 1 2000, Alaska Oil & Gas Cons. Commission Anchorage ALASILA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer ARCO Alaska, Inc. - P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit 02-1 OB ARCO Alaska, Inc. Permit No: 200-64 Sur Loc: 1038'SNL, 4341'WEL, Sec. 36, T11N, R14E, UM Btmhole Loc. 436'SNL, 1738'WEL, Sec. 35, T11N, R14E, UM Dear Mr. Stone: 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. Robert N. Christenson, P.E. Chair BY ORDER OF T~ COMMISSION DATED this o) ..- day of May, 2000 dlfA~nclosures cc~ Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA - ALASKA ,., .,_ AND GAS CONSERVATION COMM, .~ION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 59.5' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 1038' SNL, 4341' WEL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 597' SNL, 4561' WEL, SEC. 36, T11N, R14E, UM 02-10B Number U-630610 At total depth 9. Approximate spud date 436' SNL, 1738' WEL, SEC. 35, T11N, R14E, UM 05/10/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 114. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028309, 3540' MDI No Close Approach 2560 11640' MD / 9010' TVD 16. To be completed for deviated wells !17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7800' MD Maximum Hole Angle 89.7 o Maximum surface 2420 psig, At total depth (TVD) 8800'/3330 psig 18. Casing Program Setting Depth Size Specifications Top B0t':~)m Quantitv of Cement Hole Casino Weiqht Grade Couplinq Lenqth MD TVD MD TVD (inqlude staoe data) 8-1/2" 7" 26# L-80 BTC-M 7197' 7650' 7650' 8384' 8369' 179 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3406' 8234' 8224' 11640' 9010' 435 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary , .~: 0 4 2000 Total depth: measured 10375 feet Plugs (measured) IBP pushed to 9138' (10/99) true vertical 8903 feet CIBP set at 9298' (04/97) j~a~ 0J~ & Gas Cons, C0mmi~ Effective depth: measured 9138 feet Junk (measured) AR~01'~j~ true vertical 8998 feet Casing Length Size Cemented MD TVD Structural Conductor 100' 20" 500 sx (Approx.) 100' 100' Surface 2657' 13-3/8" 6500 sx Permafrost II 2715' 2715' Intermediate Production 8666' 9-5/8" 1500 sx Class 'G', 150 sx PF II 8724' 8724' Liner 2165'_ __ 2-7/8" 147 sx Class 'G' 8195' - 10360' 8195' - 8964' ORIGi NA L Perforation depth: measured 8922' - 8927', 8931' - 8936', 8944' - 8949', 8957' - 8962', 8990' - 9010', 9133' - 9138' Below IBP & CIBP: 9138'- 9960' (eight intervals) true vertical 8912' - 8916', 8920' - 8924', 8930' - 8934', 8940' - 8944', 8904' - 8914', 8939' - 8998' Below IBP & CIBP: 8998'- 8919' (eight intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed DanStone ~.~'~~,~~:~ Title Senior Drilling Engineer Date Permit Number J AP, Number J Approval Date J See cover',etter -,~..o,o -" ~',/-./' 50- 029-20163-02 ,.~'-~ ~ ~.-. O~ for other requirements Conditions of Approval: Samples Required I'"1 Yes J~ No Mud Log Required I-I Yes J~ No Hydrogen Sulfide Measures D Yes ,,~No Directional Survey Required DYes [] No Required Working Pressure for BOPE [] 2K; [] 3K; [] 4K; ~5K; [] 10K; [] 15K Other: ORIGINAL SIGNED, BY by order of Approved By gnh,=,.~ ~u r,l.,.-; ....... Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 2-10B Permit to Drill I Well Name: 12-10B Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer ISurface Location' Target Location: Bottom Hole Location: 1038' SNL4341' WEL S36 T11N R14E Umiat 597' SNL4561'WEL S36T11N R14E Umiat 436' SNL 1738' WEL S35 T11N R14E Umiat I AFE Number: 1 4J0412 I I Estimated Start Date: 1 5/10/00 IMD=111,640'1 I TVD=19010' I I Rig: I Nabors 7ES I Operating days to complete: 119.9 I BF/MSL= 130.2' I IRKS= J 59.5' I Well Design (conventional, slimhole, etc.): I Conventional Horizontal Sidetrack Objective: I Development producer targeting distributary and mouth bar sands in Zone 1. Mud Program: Milling/Cutting Casing Mud Properties: LSND DensitY10.2(ppg) IFunnel45 - 55Vis I Yield25 - 35Point Whipstock Window in 9-5/8" I pH I HTHP FL 9 - 9.5 <10 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to 8384' MD (8369' TVD). TD Top of Sag River. Density(ppg) I Funnel Vis I Yield PointI PV tau0 10.2 to 10.5 45 - 55 23 - 28 10 - 17 3 - 7 IpH 9 - 9.5 APl FL <10 to 6 Production Mud Properties: Low Density QUICKDRILn Density (ppg) lFunnel vis I LSRV PV 8.3 - 8.5 40 - 50 < 12,000 cP 5 - 8 6 1/8" hole section YP Ca++ 17 - 22 <100 APl FI I pH <10 9.0-9.5 Directional: KOP: I 7800' MD - 8 Y2" I hole. Maximum Hole Angle: Close Approach Well: 89.7° @ 9378' (8962' TVD) None MAY 04 2000 2-10B Permit to Drill Logging Program: Intermediate Section Production Hole IDrilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD / GR / Resistivity None None MWD / GR / Resistivity / Neutron / Density None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost Not Penetrated SV3 / T5 Not Penetrated SV1 / T3 Not Penetrated UG4 / K15-C1 Not Penetrated UG1 / UgS Not Penetrated WS2 Not Penetrated WS1 / West Sak Not Penetrated CM3 / K-12 6894' 6834' Not Penetrated Kick-Off Point 7800' 7740' Kick-off with-in CM3 CM-1 / K5 8827' 7439' LCU 8238' 8167' Kingak Not Present Sag River 8384' 8309' Shublik 8420' 8344' Top Sadlerochit / Z4B 8494' 8415' Est. pore pressure 3300 psi (7.2ppg EMW) TZ3 8660' 8576' TZ2 8746' 8660' TZ1 9029' 8872' BSAD 10,290' 8945' HOT 10,290' 8945' Not Penetrated Maximum TVDss 11,640' 8950' TD Casinq/Tubing Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC-M 7197' 7650'/7650' 8384'/8369' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3406' 8234'/8224' 11,640'/9010' Tubing 4-1/2" 12.6# L-80 IBT-Mod 8084' Surface 8084'/8077' RECEIVED MAY 04 2000 Alaska Oi~ & Gas Cons. Cerr~mission Anchof~e 2-10B Permit to Drill Cement Calculations: Liner Size 17" Intermediate I Basis: I Lead: None I Lead TOC: N/A Tail TOC: At -7,650' MD (7,650' TVD). Tail: Based on 80' shoe track volume and 584' of open hole with 30% excess. Total Cement Volume: ILead I None Tail 1 37 bbl / 209 f¢ / 179 sks of Dowell Class 'G' at 15.8 ppg and 1.17 I cf/sk. Liner Size 1 4 ~" Production I Basis: Tail: Based on 3256' of open hole with 50% excess, 150' of 7"x 4.5" liner lap, 200' of 7" x 4" drill pipe annulus volume, and 80' of 4-1/2" shoe joint. Tail TOC: At top of liner -8,234' MD (8225' TVD). Total Cement Volume: J Tail I 91 bbl/509 f¢ / 435 sks of Dowell Class 'G' at 15.8 ppg and 1.17 I I cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, ROPE and drilling fluid system schematics on file with the AOGCC. Maximum anticipated BHP: 3330 psi @ 8800' TVDss - Zone 1 Maximum surface pressure: 2420 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.6 ppg Seawater / 6.8 ppg Diesel RECEIVED Drilling Hazards/Contingencies: o4 2000 A~a~k~ Oii & Gas Cor~s. Co!~'~mission HYDROGEN SULFIDE- H2S Anch0 a<je · DS 2 is not designated as an H2S drill site and has no wells with over 10 ppm, (9/28/99). Standard Operating Procedures for H2S precautions should be followed at all times. DRILLING CLOSE APPROACH: · All wells pass close approach guidelines. INTERMEDIATE SECTION: · Gas cut mud was encountered while drilling 2-10 in the K-1/LCU transition (8235' MD/TVD). Gas cut mud will be controlled with appropriate mud weights. · The 2-10B well path will drill approximately 95' of Kingak shale (Jurassic A.) · Tight hole conditions and stuck pipe have not been encountered on DS 2 in the intervals below the 2-10B KOP, -7800' MD/TVD. · The kick tolerance for the 8-1/2" open hole section would be 194 bbls assuming an influx from the Sag River interval at -8,384' MD. This is a worst case scenario based on a 7.5 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.5 ppg mud in the hole. 2-10B Permit to Drill PRODUCTION SECTION: There are no planned fault crossings in the reservoir section. Lost circulation has been minor on DS 2 on past wells in the production interval, with a maximum loss of 380 bbls on well 2-31 in 1991. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 11,640' MD. This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.3 ppg mud in the hole. Disposal-. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1.. RU slickline and drift as required to verify ID of tubing for upcoming cement P&A. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 2 7/8" liner from top of IBP @ 9,138' MD to a minimum of 100' above the top perforation at 8,922' MD, plus squeeze 5 bbls to the perforations. Estimated minimum cement volume needed is 2 barrels and aggregate can be used as required to aid in plugging perfs. NOTE: Top of cement must be at a minimum of 8,822' for AOGCC compliance. Top of cement may extend up and into the tubing tail as long as it does not interfere with the upcoming tubing cutting operations. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 4. Liquid pack the 9-5/8" x 5-1/2" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3000 psi for 30 minutes (tubing has a POGLM stuck at 8020' MD). Increase tubing pressure prior to the 9-5/8" annulus to avoid possibility of tubing collapse. NOTE: This step should be done prior to the tubing cut to allow additional trouble-shooting if either the cement plug or 9-5/8" casing is leaking. 5. RU E-line. Cut the 4 Y2" L-80 tubing at approximately 7,900' MD. NOTE: The type of cutter to be used is at the discretion of the Wells Group. This cut will not be fished, however avoid cutting a tubing collar. 6. Displace the well to clean sea water by circulating down tubing through the tubing cut. Continue to circulate until clean sea water returns to surface. Freeze protect top 2200' MD with diesel. 7. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. On both the tubing hanger and 9 5/8" casing head, completely back out and check each lock down screw for breakage (check one at a time). Notify the ODE, Allen Sherritt, immediately concerning any problems with backing out the lock down screws or other potential well head problems. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 9. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. MAY 04 2000' 2-10B Permit to Drill Ri~ 1. 2. $. 4. Operations: MIRU Nabors 7ES. Circulate out freeze protection and displace well to sea water. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull and lay down 5-1/2" tubing from E-line cut at -7,900' MD. Replace 9-5/8" pack off as required by hanging tubing off below storm packer after pulling the SSSV. 5. RU E-line and make GR/JB run to top of tubing cut. Set BP on E-line at -7,820' MD (set as needed to avoid cutting casing collar). Pressure test the 9 5/8" casing to 3000 psi. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, with gyro (vertical hole) as desired and set on BP. Mill window in 9-5/8" casing at -7,800' MD. POOH. 7. Kick-off and drill 8 ½" hole from 7,800' to 8,384' at the top of the Sag River formation. Run MWD/GR LWD. No other logs are planned for this interval. 8. Run and cement a 7" 26# L-80 intermediate drilling liner. 9. Make up and RIH with a 6-1/8" directional assembly to the landing collar. 10. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 11. Drill out 6 1/8" hole from 8,384' to TD of 11,640' in Zone 1. Run MWD/GR/Res/DEN/NEU real time LWD. 12. Run and cement a 4 %", 12.6# L-80 IBT-Mod solid production liner throughout the 6-1/8" well bore. 13. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. Displace well to clean sea water above liner top. POOH LD DP. 14. The well will be perforated using DPC guns with 200 psi of under balance to formation pressure. Perforation intervals will be determined after logs are reviewed, (est. -1200 Z1A and -800' Z1B.) POOH and lay down all DP and perf guns. 15. Run 4-1/2", 12.6# L-80 IBT-Mod completion tying into the 4-1/2" liner top. 16. Set packer @ -8480' MD and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 17. Set BPV, nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure well. 19. Rig down and move off. Estimated Pre-rig Start Date: Estimated Spud Date: Allen Sherritt Operations Drilling Engineer 564-5204 RECE!VED MAY 0,5 2000 Alaska Oii & Gas ~r~s. ~mm 05/5/00 05/10/00 ARCO ALASKA INC, SSSVNIP Tubing-NPC FO @ 2408' Casing FO @ 2642' 8020' 234 MIN ID = 5-1/2" AVA POGLM POGLM SLS NOGO PBR PKR XO OTHER Tubing-NPC Liner-CT XO XO SOSUB 8729'-8735' 9-5/8 Window (milled 12/26/96) Pod Ped FraC Zone iBP CIBP LC Float A Pru lhoe Bay 02-10A APl: 500292016301 Cdc Compttn: 1/13/97 SSSV Type: Last W/O: 1/17/97 Angle @ TD: 96 dec @ 10375 Rev Reason: Depth Note re: POGLM holes (kak) Last Update: 2/29/00 Annular Fluid: Diesel/10 6 Ref Log Date: 7/20/75 CAC12 Reference Log: BHCS RK8:58 8 Last Tag: 9138' CTM TD: 10375 flKB Last Tag Date: 10/10/99 Max Hole 98 dec @ 9382 Angle: Well yype: PROD Ar~gle @ TS: dec ~ Depth Annotations Depth Comment 2408 FO ~_~ 2408' 2642 FO @ 2642' 4311 4311-4312 5' POGLM Holes 5-22-97 POGLM pulled 8020 8020' 234 MIN ID = 5-1/2" AVA POGLM 8729 8729'-8735' 9~5/8 Window (milled 12/26/96) Safety Notes Date Note 2/24/00 TROUBLE WELL - FTS, T x IA communication, POGLM #2 stuck in tubing Holes at 8020', ? IA x CA Communication to 9as. CA x Form Communication, water and smal~ amounts of gas bubblin9 in Cellar General Notes Date Note 3/24/77 TTL ELM @ 8278: ELM TT (Behind CT Liner) FRAC ZN1/DATA FRAC 04/29/97; 05/06/97 Other (plugs, equip.; etc.): JEWELRY Depth TVD Type Description ID 2219 2219 SSSVNIP 5-1/2" otis RQ SSSV Nipple 4562 8020 8020 POGLM 5-1/2" AVA*DWP POGLM (Set 03/10/97) 2340 8078 8078 SLS 5-1/2" Otis XA S~iding Sleeve 4562 8106 8106 NOGO 5-1/2" Otis XN Nipple 4455 8145 8145 PBR 5-1/2" 8CT PBR Assembly 0 000 8170 8170 PKR 9-5/8" x 5-1/2" Baker SAD Packer 0000 8195 8195 XO Crossover 5-1/2" x 4-1/2" (Behind CT Liner) 0000 8195 8195 OTHER 4-1/2"G Seal Sub 3000 8199 8199 XO Crossover 4-1/2" x 3-1/2" 2441 8200 8200 XO Otossover 3-1/2" x 2-7/8' 2441 8232 8232 NIP 4-1/2" Otis X Nipple (Behind CT Liner) 3813 8293 8293 SOSUB 4-1/2" DOT Shearou~ Sub (Behied CT Liner) 0000 8296 8296 TTL 4-1/2" Tubing Tail (Behind CT Liner) 0000 9138 9000 IBP 4-1/2" iBP pushed to 9138' CTM 10/10/99 0000 9298 8997 CIBP CIBP (Set 04/27/97) AC'd Mill 02/15/98 0001 10293 8971 LC 2-7/8" Baker Landin9 Collar 2 441 10358 8966 FIgat 2~7/8" Davis Lynch Float Shoe 0,000 Casing Strings - All Size Weight Grade Top Btm Feet Description 9625 47,00 MN-80/SOO-95 0 8729 8729 Casing 2875 640 L-80 8195 10360 2165 Liner-CT 13.375 72,00 MN~0 0 2715 2715 Casin9 Tubing Strings: All Size Weight Grade Top Btm Feet Description 5500 1700 N-80 0 8i95 8195 Tubing-NPC 4.500 12,60 N-80 8195 8296 101 Tubi0g-NpC Gas Lift MandrelsNalves Stn MD TVD Man Man V Mfr V Type V OD Latch Port TRO Mfr Type Date Vlv 6/29197 (1) 2 8020 8020 AVA DWP CA SBK0-DF 10 6K 0440 1. ScaleO#/24/97 Perforations Interval TVD Zone Status FeetSPF Date Type 8922-8927 8912-8916 O 5 4 4/11/98 APERF 8931 -8936 8920- 8924 0 5 4 4/11/98 APERF 8944 - 8949 8930 - 8934 O 5 4 4/11/98 APERF 8957 8962 8940-8944 O 5 4 4/11/98 APERF 6990-9000 8961 -8967 O 10 4 10/31/97 APERF 9000 - 9010 8967 - 8972 O 10 4 10/31/97 APERF 9133-9153 9000-9002 O 20 4 5/5/97 APERF 9165-9180 9003-9003 O 15 4 1/15/97 IPERF 9193-9213 9003-9002 O 20 4 5/5/97 APERF 9198-9214 9003-9002 0 16 4 1/15/97 APERF 9258-9266 8999-8998 O 8 4 1/15/97 ~PERF 9330-9520 8994-8976 O 190 4 1/15/97 APERF 9658-9690 8979-8981 O 32 4 1/15/97 IPERF 9704 - 9908 8982 - 8980 0 204 4 1/15/97 ~PERF 9932 - 9960 8980 ~ 8981 O 28 4 Stimulations & Treatments Interval Date Type Comment 9133- 9960 5/6/97 FracZone 1 TREE: FMC Gen 1 - 5M L-80 WELLHEAD: FMC - 5M 2-10B Proposed Completion GL Elevation = 30.2' Nabors 7ES RKB = 59.5' 4-1/2" 'X' Landing Nipple with 73.813" seal bore. I 2200' 13 3/8", 72 #/ft, MN-80 2715' 4-1/2" x 1-1/2" Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. GAS LIFT MANDRELS IVD Size Valve Type 1-1/2" RP Shear 1-1/2" DV ' 1-1/2" DV (or lit above packer) 4-1/2" 12.6# L-80, IBT Mod Tubing Liner Top at I +/-7650' BAKER 9 5/8" x 7" ZXP Liner Top Packer 'Hydraulic Liner Hanger MAY 0 4 200~: Window Milled from Whipstock Top of Window at +/- 7800' MD Bridge Plug set at +/-7820' MD 7" x 4 1/2" Baker'S' Production Packer ". @ -8084' MD 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" WireLine Entry Guide spaced-out into liner top. 4-1/2" 12.6 #/ft, L-80, BTCM I +/-11,640' Horizontal Sidetrack into Zone 1 Sands 9-5/8", 47 #/fi, L80, BTC I6724' I TOC at +/-8822' MD Top Perforation at +/-8922' MD Date 5/1/00 PRUDHOE BAY UNIT WELL: 2-10B APl #: 50-029-20163-02 Revised by_.p JAS Comments Proposed completion. OI:llLLING SERVICES Shared Services Drilling 32-10R Wp04 774.10 N 3122.68 W 5950860.00 N 960.99 N 1992.67 W 5951075.00 N 623.45 N 90.49 W 5950785.00 N 187.83 N 271.41 W 5950345.00 N 435.03 N 1960.77 W 5950550.00 N 379.24 N 2932.47 W 5950470.00 N Single Well Target Data for 02-10B Measurement Units: ft Coordinate Target Point TVDrkbTVDss Northings Eastings ASP Y ASP X Target Name Type Shape 02-10B Polygon Entry Point 774.10 N 3122.68 W 5950860.00 N 684550.00 E Polygon Boundary Point A 684550.00 E B 685675.00 E C 687585.00 E D 687415.00 E E 685720.00 E F 684750.00 E 02-10B TI Entry Point 8960.00 8900.00 441.62 N 220.07 W 5950600.00 N 687460.00 E Point 02-10B T2 Entry Point 8970.00 8910.00 537.30 N 1047.94 W 5950675.00 N 686630.00 E Point 02-10B T3 Entry Point 9005.00 8945.00 574.27 N 1327.10 W 5950705.00 N 686350.00 E Point 02-10B T4 Entry Point 9010.00 8950.00 602.93 N 2676.81 W 5950700.00 N 685000.00 E Point 780O Exit @ 12.000°/100ft, 40.000° TF: 7800.00ft MD, 7799.56ft TVD in Dir @ 10.850°/100ft: 7832.00ft MD, 7831.53ff TVD Dir- 7951.79ff .M..D,..7..9~}.9...8.2.ft...T~/..D. ............... K2ffHRZ - 7950.00 TVD BHRZ- 8149.00 TVD LCU - 822Z00 TVD I DriliQuesF 8125 Proposal Data for 02-10B Wp04 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ff North Reference: True North Dogleg severity: Degrees per 100ff Vertical Section Azimuth: 282.100° Vertical Section Description:Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northlngs Eaetlngs Vertical Dogleg Depth Depth Section Rate 7800.00 0.549 243.699 7799.56 7832.00 4.275 ~,278.971 7831.53 7951.79 14.253 143.621 7949.82 8750.84 14.~1~i~ 8724.27 9377.97 31 8962.01 9926.81 89~ 2~31 896~.92 10005.64 ~ 8970.00 ~ 27~!144 10021.46~ ~l~t4TM 278.849 8972.14 ~l~ 278.849 8997.91 O 7~.'Ir88 271.217 9005.00 9.788 27t.217 9010.00 17.28 N 37.70 E -33.24 17.40 N 36.38 E -31.93 12.000 32.31 N 27.78 E -20.39 10.850 221.05 N 27.70 W 73.42 0.000 441.62 N 220.07 W 307.75 19.000 522.59 N 420.82 W 521.02 19.000 531.51 N 969.58 W 1059.45 0.000 537.30 N 1047.94 W 1137.28 12,000 539.53 N 1063.46 W 1152.93 12.000 566.13 N 1234.30 W 1325.55 0.000 574.27 N 1327.10 W 1418.00 12.000 602.93 N 2676.81 W 2743.72 0.000 MAY 04 2000, 7" Liner _ ~ 8369.00 TVD ~~ ~ {~t0 ~' ~ ~ ............ ...................................... ~a~s-.-~.~-~- ~w~ ~ ~O .............................................................................. ~-~ ~.~ ~.~ ~ _.~ .... ~.~ ........ ~ .... .?~:.~.~ O~IOB T! 02-10B ~ 02-10B T3 ~' ~ --~ ~tnR ~d ~ a ~, ~ I I I I I I I I I 325 650 975 1300 1625 1950 2275 2600 2925 8450 8775 II o_ ~ 9100 Scale: linch = 325ft Vertical Section Fm~red: Section Azimuth: ~Approved: Cm, c~: 282.100° (True North) DRILLING SERVICES Shared Services Drilling 02-10B Wo04 Current Well Properties Well · 02-10B Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: I DrillQ. uesf 5950164.00 N, 687691.01 E 1362.54 N, 84.77 E 70° 16' 07.2425" N, 148° 28' 55.5408' W 60.00ff above Mean Sea Level 60.00ft above Structure Reference 1000 500 North Reference: True North Units: Feet Scale: linch = 500ft Eastings ~ ~ -3000 -2500 -2000 -1500 -1000 0 500 -- 1000 -3000 -2500 -2000 -1500 -1000 -500 0 500 Scale: linch = 500ft Eastings Reference is True North 2000. 500 602.93 2676.81 23 March, 2000 - 18:11 .1 ~ DrlllQuest North Slope Alaska Alaska State Plane 4 o~r, oa ~o4~~' PROPOSAlS. PORT ,~oo n FI I L. L I N I:~ ~EFIVIC:ES Proposal Ref: pro9700 04 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 7800.00 0.549 243.699 7739.56 7832.00 4.275 278.971 7771.53 7900.00 9.046 332.869 7839.11 7951.79 14.253 343.621 7889.82 7951.98 14.253 343.621 7890.00 8000.00 14.253 343.621 7936.54 8100.00 14.253 343.621 8033.46 8157.30 14.253 343.621 8089.00 8200.00 14.253 343.621 8130.39 8237.78 14.253 343.621 8167.00 8300.00 14.253 343.621 8227.31 8384.29 14.253 343.621 8309.00 8400.00 14.253 343.621 8324.23 8420.40 14.253 343.621 8344.00 8493.65 14.253 343.621 8415.00 85(X).00 14.253 343.621 8421.15 8600.00 14.253 343.621 8518.07 8659.76 14.253 343.621 8576.00 8700.00 14.253 343.621 8615.00 8746.43 14.253 343.621 8660.00 8750.84 14.253 343.621 8664.27 8800.00 22.735 330.945 8710.87 8824.41 27.151 327.563 8733.00 8865.23 34.655 323.727 8768.00 8900.00 41.114 321.458 8795.43 Sperry-Sun Drilling Services Proposal Report for 02-10B Wp04 Vertical Local Coordinates Global Depth Northings Eastings (~t) (~t) (~t) (~t) 7799.56 17.28 N 37.70 E 7831.53 17.40 N 7899.11 22.56 N 7949.82 32.31 N 7950.00 32.35 N 7996.54 43.69 N 8093.46 67.32 N 8149.00 8190.39 8227.00 8287.31 } N 8369.00 } N 8384.23 18 N 8720.00 8724.27 8770.87 8793.00 8828.00 8855.43 lates 161.8o N 185.42 N 199.53 N 209.04 N 220.01 N 221.05 N 235.19 N 244.02 N 261.26 N 278.19 N 36.38 E 687726.95 E 31.43 E N 687721.87 E 27.78 E 5950196.99 N 687717.97 E 3 N 687717.96 E 687714.34 E 5950231.73 N 687706.81 E 5950245.16 N 687702.50 E E 5950255.17 N 687699.28 E 7.92 E 5950264.03 N 687696.44 E 3.60 E 5950278.61 N 687691.75 E 2.25 W 5950298.37 N 687685.41 E 3.34 W 5950302.05 N 687684.22 E 4.76 W 5950306.83 N 687682.69 E 9.84 W 5950324.00 N 687677.17 E 10.28 W 5950325.49 N 687676.69 E 17.23 W 5950348.93 N 687669.17 E 21o38 W 5950362.94 N 687664.67 E 24.17 W 5950372.37 N 687681.64 E 27.39 W 5950383.25 N 687658.14 E 27.70 W 5950384.29 N 687657.81 E 34.03 W 5950398.27 N 687651.12 E 39.31 W 5950406.96 N 687645.62 E 51.19 W 5950423.90 N 687633.32 E 64.18 W 5950440.50 N 687619.91 E Dogleg Rate (°/100fi) 12.000 10.850 10.850 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 19.000 19.000 19.000 19.000 Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) -33.24 -31.93 -26.01 ~0.39 -20.36 -14.73 -2.99 3.74 8.75 13.19 20.49 30.39 32.23 43.23 43.97 55.71 62.73 67.45 72.90 73.42 82.58 89.59 104.82 121.07 Comment ST Exit @ 12.000°/100ft. 40.000° TF: 7800.00ff MD, 7799.56ff TVD 78B8B8~2in Dir @ 10.850°/100ft: .00ff MD, 7831.53ft TVD End Dir: 7951.79ft MD, 7949.82ft TVD K2/THRZ BHRZ LCU 7" Liner TSGR TSHU TSAD/TZ4B TZ3 TZ2C Beain Dir @ 19.000°/100ft: 8750.84ft MD, 8724.27ft TVD 23SB 22TS Continued... 23 March, 2000- 18:12 - 2 o DrillQuest 1.05.04c ~,~-~Y 04 2000 Sperry-Sun Drilling Services Proposal Report for 02-1DB Wp04 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 8931.41 46.979 319.864 8818.00 9000.00 59.840 317.234 8858.80 9028.62 65.220 316.344 8872.00 9100.00 78.657 314.402 8894.08 9156.56 89.313 313.000 8900.00 9200.00 89.364 304.746 8900.50 9300.00 89.530 285.745 8901.48 9377.97 89.696 270.931 8902.01 9400.00 89.696 270.931 8902.12 9500.00 89.696 270.931 8902.65 9600.00 89.696 270.931 8903.18 9700.00 89.696 270.931 8903.71 9800.00 89.696 270.931 8904.25 9900.00 89.696 270.931 8904.78 9926.81 89.696 270.931 8904.92 9934.31 89.050 271.557 8905.00 10000.00 83.398 277.067 8909.33 10005.64 82.915 277.544 8910.00 10021.46 81.524 278.849 8912.14 10100.00 81.524 278.849 8923.72 10196.27 81.524 278.849 8937.91 10200.00 81.852 278.541 8938.45 10289.85 89.788 271.217 8945.00 10300.00 89.788 271.217 8945.04 10400.00 89.788 271.217 8945.41 Alaska State Plane 4 PBU_EOA DS 02 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8878.00 295.06 N 78.03 W 8918.80 336.18 N 114.48 W 8932.00 354.67 N 131.87 W 8954.08 402.83 N 179.46 W 8960.00 441.62 N 220.07 W 8960.50 468.86 N 253.86 ~b~, 5950626.39 N 8961.48 511.32 N 343.~950666.58 N 8962.01 522.59 N 4~'2~ ~950675.94 N 8962.12 522.95 N ~I1~1~ 5950675.74 N 8962.65 524.57~ .~B3 ~ 5950674.88 N 8963.18 526.2(~L ~ 642.81 w 5950674.01 N 8963.71 527.82~ 742.80 W 5950673.14 N 8964.25 ~, ~,45 N N ~ 842.79 W 5950672.27 N 8964.78 ~ 942.77 W 5950671.40 N 8964.92 ~l~li~l.]J~l~l 969.58 W 5950671.17 N 89~5.oo,.~'~1.67, ~ '~' 536.59 N ~0_...0~,~ 537.30 N V 539.53 N 8983~2 551.48 N 977.07 W 5950671.14 N 1042.38 W 5950674.43 N 1047.94 W 5950675.00 N 1063.46 W 5950676.85 N 1140.21W 5950686.88 N Global Coord~ates Dogleg Vertical NorthingsA ~]~Lstings Rate Section Comment (ft) ~~ft) (o/'t ooft)(ft) ~ '~' 687568.18 E 19.000 182.41 ~1505'1~7~1t 687550.34 E 19.000 203.28 TZ1B ~r~56~3 N 687501.56 E 19.000 259.91 5gl~.00 N 687460.00 E 19.000 307.75 Target - 02-10B T1, Geological 687425.54 E 19.000 346.50 687334.48 E 19.000 443.43 687257.29 E 19.000 521.02 687235.26 E 0.000 542.62 687135.27 E 0.000 640.73 687035.27 E 0.000 738.83 686935.28 E 0.000 838.94 686835.29 E 0.000 935.04 686735.29 E 0.000 1033.15 686708.48 E 0.000 1059.45 686700.99 E 12.000 1066.81 686635.57 E 12.000 1131.70 686630.00E 12.000 1137.28 686614.43 E 12.0(X) 1152.93 686537.40E 0.000 1230.48 End Dir: 9377.97ft MD 8962.01ft TVD ' 99B9B9~6in Dir @ 12.000°/100ft· .81ft MD, 8964.92ft =I~/D TZIA Target - 02-10B T2, Geological End Dir: 10021 46ft MD, 8972.14ft TVD ' 8997.91 566.13 N 1234.30W 5950699.18 N 8998.45 566.69 N 1237.94W 5950699.64N 9005.00 574.27 N 1327.10W 5950705.00N 9005.04 574.49 N 1337.25W 5950704.96N 9005.41 576.61N 1437.22W 5950704.59 N 686442.98 E O.O(X) 1325.55 686439.32 E 12.000 1329.23 686350.00 E 12.000 1418.00 686339.85 E 0.0(X) 1427.96 686239.85 E 0.000 1526.16 10EoE0~96in Dir @ 12.000°/100ff. .27ftMD, 8997.9~'=1'~D End Dir- 10289.85ft MD, 9005.00ff 'I'VD BSAD Target - 02-10B T3, Geological Continued... 23 March, 2000- 18:12 - 3 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 02- lOB Wp04 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 10500.00 89.788 271.217 8945.78 10600.00 89.788 271.217 8946.15 10700.00 89.788 271.217 8946.52 10800.00 89.788 271.217 8946.89 10900.00 89.788 271.217 8947.26 11000.00 89.788 271.217 8947.63 11100.00 89.788 271.217 8946.00 11200.00 89.788 271.217 8946.37 11300.00 89.788 271.217 8948.74 11400.00 89.788 271.217 8949.11 11500.00 89.788 271.217 8949.48 11600.00 89.788 271.217 8949.85 11639.87 89.788 271.217 8950.00 Vertical Depth Northings (~) (~) 9005.78 578.73 N 9006.15 580.86 N 9006.52 582.98 N 9006.89 585.10 N 9007.26 587.22 N 9007.63 589.35 N 9008.00 591.47 N 9008.37 593.59 N 9008.74 595.72 N 9009.11 597.84 N 9009.48 9009.85 9010.00 .93 Local Coordinates Eastings (ft) 1537.20 W 1637.18 W 1737.15 W 1837.13 W 1937.11 W 2037.08' )7 W 2636.95 W 2676.81 W Global Coord~ates Dogleg Northings stings Rate 5950704A'~686~39.86 E 0.000 5,~~ '~ 686039.86 E 0.~ ~~~ 6~939.86 E 0.~ ~7~ ~ ~56~.~ ~ 0.~ s~~ ~ 6857~9.~ ~ 0.~ 5950702.37 N 685639.86 E 0.000 N 685539.86 E 0.000 N 685439.87 E 0.000 5950701.26 N 685339.87 E 0.000 5950700.89 N 685239.87 E 0.000 5950700.52 N 685139.87 E 0.000 5950700.15 N 685039.87 E 0.000 5950700.00 N 685000.00 E 0.000 All data is in feet unless otherwise stated. Directions and Vertical depths are relative to Well. Northings and are relative to True North. lative to Well. Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) 1624.36 1722.56 1820.76 1918.96 2017.17 2115.37 2213.57 2311.77 2409.97 2508.17 2606.37 2704.57 2743.72 Comment Total Depth: 11639.87ft MD, 9010.00ft TVD 4 1/2" Liner Target - 02-10B T4, Geological The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 282.100° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11639.87ft., The Bottom Hole Displacement is 2743.87ft., in the Direction of 282.694° (True). 23 March, 2000 - 18:12 - 4 - DrillQuest 1.05.04c H 16'7633 I VENOO~ ALASI4,AST40 0 DATE INVOIC'E i CREDrT MEMO DESCRIPTION GROSS DISCOUN~ ........ NET' 04:1700 C1~04:1700B :100. O0 :100. O' HANDLI,NO INST: s/h teerie x 4&2EI 02... I0 REC[ IVED , , ,' o 4 2000 .Ata~,ka Oil & Gas ( o~s. ~mmis~ion , A~ch~ rage BP EXPLORATION (ALASKA),:.INC.:.:, ...:. . ....... ... : ..... No..H1 ..7 ,... ...... ...... · .... . .... '.:. .... :: .... .':': ':.:: ::::::' ..:..':: ':' : .... ~',;..:,, ""'. :":':":" ':'?.. ':',:.' ..... . ... :': 6',. '~ ~ .. . ....., :c,.: ':,~.~.... ..... .,'. .:&:~F:.' '"::'~ ' .":' '"' '.:::... :~: :."':',~...', ."~ ~JA~ILtATE:~ ':~:~:'. :' :":' . '."::.::: .,..' :~ .:" :::.: ',~::~:,~' ' 'h~ ' '"'* ~ . P.O. BOX 196612 ::::' ,.:::::., ..~::'.',~:. ">...~:>.: .... .'. ....,,::,, , ~.::.:.. "::::..~:. ..... t~'~ :.:::::~ ::.,.:." NA~[ONA[.~BA~K :':: '::. ~'.':: CONSOLID~EDCOMME 'AN A EA ' ~:'~ .::.:.':~..:.: ...... :~.~ :~:..::~: .... . .... ".: ."'::t.:', '";~ .":"::: : :: 'CEEVE~D ONio '"'" ''. t.'..: .' ": :' , 't ....... ~ ".:,?' :'..'-' CHOR G .:,:' LAS~' 99519-6612 ':::.::...: :'::::'.: ."~:..':.::.~. '.~:.:::.:: '...,:..':.c.;;::. ,,~' :.:'.:::.."::.::':' ...~ ...... ... ' ::.:.. :::'::: .~:'.~ :r~:'.::..' :':'~:::. .... '...:. ,:~;:~ .. :~/::':~ .' "".: :::': ~" .'.":' '.:.' '?: :~': :~:' .J '~':;:~ ~:? ~',:"' ' ~" , '~: J;.::" ';":~:.:"56:389 :;~ :." ?: '~ '::~:::'" ':'~::"" : ':. .... ::~'J::::' ;')~; ~ "' ....... · .......... "':". "" :" ~"' ' ':' ":'::' ~2~' ':: ' 'OO1~7'~3~:~ ;; ..... · : .~::'. :::.~:':.~..: .'f.:k: { :...~...~ ......... .: ./.:: :::?: ..:.. ' :~::;....: ..:.::.:..:.:.::.::... ..~ :~.. : ': :.:~.[ .:.::... , ~ .... 4 PAY ONE .HUNDR/D:'.:~& 0.~1100~~"~~~~~~~~'~ US.'.::DOLE~ : ,~ ' : .... '.~::.: ~:::"~;:; '~.~::::. ~':::::~:':~ :'::L':. ========================= :¥.~: "'~':.:'~ ?.{ ::':.:::.~ .~?"::. ,.:.-.~f' :.~. ?' '-: ::: ':::.:~ :::'?':.?..:~'~'~:.:.:: '~, ~['tz~" :': :~:~:': ?~"'? ';:~{..-.' ~:~' ':: ...... :::~' .?"~:' DATE ?~-:::~:' ':~ :. ' ":': ~OUNT '~?". ~ I ~':~' " To The STATE OF ALAF:~AAI:Aoocc .... ..' . .., · )::~ :.:':: ': :~i:.::::: '~::":.' ::: ':"' ORDER 3001 'PDRCUP INE ~DR~:VE.:....:.!: ..... ., ...-. ,:~.:::/:.:. ::.: ANCHORAGE WELL PERMIT CHECKLIST FIELD & POOL ~,,~ y~ COMPANY ~,..~,~ WELL NAME~22_-/,--)~ PROGRAM: exp dev ~ redrll ~, serv wellbore seg ann. disposal para req ADMINISTRATION INIT CLASS ?~__~ /.~,~" ENGINEERING DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ........... . ...... 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,_~O__,t,~3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of U2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... AP,,P~R D,~/1'F~ 31. Data presented on potential overpressure zones ........, ~I~N ' ~ 32. Seismic analysis of shallow gas zones ............. . 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory o~ry] Y N Y N Y N Y N Y N Y N / ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX~ No Special'effort has been made to chronologically organize this category of information. -: · .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mort Oct 16 20:47:28 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/10/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPER3XTOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 2-10B 500292016302 PHILLIPS Alaska, Inc. Sperry Sun 15-OCT-00 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00050 AK-MM-00050 AK-MM-00050 R. KRELL R. KRELL M. HANIK T. ANGLEN T. ANGLEN J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: R3~NGE: MWD RUN 4 AK-MM-00050 M. HANIK J. RALL 36 liN 14E FNL: 1038 FSL: FEL: 4341 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 58.32 GROUND LEVEL: 30.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.630 7798.0 8.500 7.000 8385.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABILIZED LITH-DENSITY (SLD) . 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 5. GAMMA RAY (DGR) LOGGED BEHIND CASING FROM 8363' MD, 8349' TVD TO 8385' MD, 8371' TVD. 6. DIGITAL AND LOG DATA ARE TIED INTO THE PDC GR (BCS GR) LOG OF 7/20/75 FOR 2-10 WITH KBE = 58.0' A.M.S.L.. THIS WELL KICKS OFF FROM 2-10 AT 7798' MD 7798' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL 2-10B WITH API # 50-029-20163-02. THIS WELL REACHED A TOTAL DEPTH OF 11640' MD, 8972' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 8.3 - 8.4 PPG MUD FILTRATE SALINITY: 800 - 900 PPM CHLORIDES FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.00 G/cc MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 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 GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT DRHO RHOB PEF $ START DEPTH 7774.5 7798.0 8375 0 8375 0 8375 0 8375 0 8375 0 8375 0 8375 0 8375 0 8383 0 8383 0 8383 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 7774 5 7777 0 7782 0 7791 5 7796 5 11639 0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: GR 7776 5 7779 0 7784 0 7792 5 7797 0 11639 5 STOP DEPTH 11596 5 11639 0 11603 5 11603 5 11603 5 11603 5 11603 5 9267 5 9267 5 9267 5 9283 5 9283 5 9283 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 7776.5 8390.0 2 8390.5 9369.0 3 9369.5 9372.0 4 9372.5 11639.5 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 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CP30 4 1 68 NCNT MWD CP30 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD B/E 4 1 68 20 24 28 32 36 40 44 48 52 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 7774.5 11639 ROP MWD FT/H 1.1 872.76 GR MWD API 13.79 531.62 RPX MWD OHMM 2.08 793.35 RPS MWD OHMM 2.26 363 RPM MWD OHMM 1.62 1947.66 RPD MWD OHMM 1.36 1280.31 FET MWD HR 0.55 66.47 NPHI MWD PU-S 8.45 59.06 FCNT MWD CP30 120 2026 NCNT MWD CP30 14583 42258 RHOB MWD G/CM 1.86 3.34 DRHO MWD G/CM -0.66 0.87 PEF MWD B/E 1.42 11.57 Mean 9706.75 50.0223 71.2585 25.6374 30.3529 38.4708 39.824 2.15217 23.3365 635.928 27317.8 2.35909 0.0791731 2.23998 Nsam 7730 7683 7645 6458 6458 6458 6458 6458 1786 1786 1786 1802 1802 1802 First Reading 7774.5 7798 7774.5 8375 8375 8375 8375 8375 8375 8375 8375 8383 8383 8383 Last Reading 11639 11639 11596 5 11603 5 11603 5 11603 5 11603 5 11603 5 9267 5 9267 5 9267 5 9283 5 9283 5 9283 5 First Reading For Entire File .......... 7774.5 Last Reading For Entire File ........... 11639 File Trailer Service name ............. STSLIB.001· Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7776.5 ROP 7798.5 $ 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: STOP DEPTH 8363.5 8390.0 02 -JUN- 00 Insite 4.05.2 65.41 Memory 8390.0 .4 14.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER PB01526HGV6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8385.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND-HT 10.30 38.0 9.2 8OO 3.0 .000 .000 .000 .000 .0 138.0 .0 .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 Service Unit Min Max Mean Nsam DEPT FT 7776.5 8390 8083.25 1228 ROP MWD010 FT/H 1.1 872.76 50.7696 1184 GR MWD010 API 70.08 404.81 175.496 1175 First Reading 7776.5 7798.5 7776.5 Last Reading 8390 8390 8363.5 First Reading For Entire File .......... 7776.5 Last Reading For Entire File ........... 8390 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW 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 STOP DEPTH GR 8364 0 9316 0 RPM 8375 5 9323 0 NCNT 8375 5 9268 0 FCNT 8375 5 9268 0 NPHI 8375 5 9268 0 RPS 8375 5 9323 0 RPX 8375 5 9323 0 RPD 8375 5 9323 0 FET 8375 5 9323 0 PEF 8383 5 9284 0 DRHO 8383 5 9284 0 RHOB 8383 5 9284 0 ROP 8390 5 9369 0 $ LOG HEADER DATA DATE LOGGED: 06-JUN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9369.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 13.3 MAXIMUM ANGLE: 85.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01533GRV4 EWR4 ELECTROMAG. RESIS. 4 PB01533GRV4 SLD STABILIZED LITHO DEN PB01521NL4 CTN COMP THERMAL NEUTRON PB01521NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S cASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: LSND-HT MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S) : 40.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 3.200 2.017 3.600 3.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 NPHI MWD020 FCNT MWD020 NCNT MWD020 RHOB MWD020 DRHO MWD020 PEF MWD020 FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HR 4 1 68 28 8 PU-S 4 1 68 32 9 CP30 4 1 68 36 10 CP30 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 B/E 4 1 68 52 14 70.0 115.0 70.0 70.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 0HMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HR NPHI MWD020 PU-S Min 8364 2.62 13 79 2 08 2 26 1 62 1 36 0 97 8 45 Max 9369 137.63 531.62 793.35 363 1947.66 1280.31 66.47 59.06 Mean Nsam 8866.5 2011 35 6451 1958 59 5757 1905 31 2264 1896 41 8395 1896 66 2671 1896 67 2437 1896 3.47749 1896 23.3365 1786 First Reading 8364 8390.5 8364 8375.5 8375.5 8375.5 8375.5 8375.5 8375.5 Last Reading 9369 9369 9316 9323 9323 9323 9323 9323 9268 FCNT MWD020 CP30 NCNT MWD020 CP30 RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 B/E 120 2026 14583 42258 1.86 3.34 -0.66 0.87 1.42 11.57 635.928 27317.8 2.35909 0.0791731 2.23998 1786 1786 1802 1802 1802 8375.5 8375.5 8383.5 8383.5 8383.5 9268 9268 9284 9284 9284 First Reading For Entire File .......... 8364 Last Reading For Entire File ........... 9369 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9316 5 9321.0 RPD 9323 5 9328.0 RPX 9323 5 9328.0 RPM 9323 5 9328.0 FET 9323 5 9328.0 RPS 9323 5 9328.0 ROP 9369 5 9372.0 $ LOG HEADER DATA DATE LOGGED: 07-JUN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3kTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 Memory 9372.0 85.6 85.6 TOOL NUMBER PB01533GRV4 PB01533GRV4 6.125 LSND-HT 8.40 40.0 9.4 80O 9.0 3.400 1.744 3.600 3.600 68.0 139.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 RPD MWD030 FET MWD030 FT/H API OHMM OHMM OHMM OHMM HR 1 68 1 68 1 68 1 68 1 68 1 68 1 68 4 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HR Min 9316.5 9.07 45 38 20 72 20 59 20 46 20 51 2 86 Max 9372 32.62 51 28 23 49 21 87 21 51 21 96 19 11 Mean Nsam 9344.25 112 22.1717 6 49.198 10 22.599 10 21.402 10 20.811 10 20.996 10 14.19 10 First Reading 9316 5 9369 5 9316 5 9323 5 9323 5 9323 5 9323 5 9323 5 Last Reading 9372 9372 9321 9328 9328 9328 9328 9328 First Reading For Entire File 9316.5 Last Reading For Entire File ........... 9372 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9321.5 FET 9328.5 RPD 9328.5 RPM 9328.5 RPS 9328.5 RPX 9328.5 ROP 9372.5 $ 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: STOP DEPTH 11597 0 11604 0 11604 0 11604 0 11604 0 11604 0 11639 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA tLAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 10-JUN-00 Insite 4.05.2 65.44 Memory 11640.0 85.9 99.0 TOOL NUMBER PB01533GRV4 PB01533GRV4 6.125 QUIKDRIL-N 8.60 39.0 9.1 600 9.4 3.400 1. 965 4.000 2.400 74.0 133 .0 74.0 69.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 0HMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 0HMM RPD MWD040 OHMM FET MWD040 HR Min 9321.5 4.99 23.98 8.75 8.65 9.04 9.55 0.55 Max 11639.5 187.03 139 22 45 04 47 73 48 52 47 45 32 98 Mean Nsam 10480.5 4637 56 0714 4535 49 23 25 26 28 1 2747 4552 3161 4552 5881 4552 9318 4552 4445 4552 5737 4552 First Reading 9321 5 9372 5 9321 5 9328 5 9328 5 9328 5 9328 5 9328 5 Last Reading 11639.5 11639.5 11597 11604 11604 11604 11604 11604 First Reading For Entire File .......... 9321.5 Last Reading For Entire File ........... 11639.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/10/16 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
