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Home My WebLink About199-0857. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-09A Pull WRP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-085 50-029-20381-01-00 11591 Conductor Surface Intermediate Liner Liner 9054 90 2653 9582 739 2479 11524 20" 13-3/8" 9-5/8" 7" 2-7/8" 28 - 118 27 - 2680 26 - 9608 9107 - 9846 9112 - 11591 28 - 118 27 - 2680 26 - 8426 8016 - 8621 8020 - 9054 None 2670 4760 7020 13890 None 4930 6870 8160 13450 11430 - 11480 4-1/2" 12.6# 13cr80, L80 23 - 9139 8993 - 9010 Structural 4-1/2" Baker S3 Packer 9013, 7939 8827, 9013 7788, 7939 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028286 23 - 8042 N/A N/A 668 Well Not Online 53755 824 600 550 1200 200 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Otis Perm Packer 8827, 7788 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 9026 No SSSV Installed By Grace Christianson at 2:42 pm, Nov 08, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.11.06 11:20:46 - 09'00' Torin Roschinger (4662) DSR-11/20/24 RBDMS JSB 111824 WCB 2-7-2025 ACTIVITYDATE SUMMARY 10/28/2024 ***WELL FLOWING ON ARRIVAL*** (rst/ cnl/ pnl) RIG UP POLLARD #60 ***CONTINUE ON 10/29/24 WSR*** 10/29/2024 ***CONTINUED FROM 10/28/24 WSR*** (rst/ cnl/ pnl) PULLED 4-1/2" FLOW THRU STOP AT 8,933' MD RAN 2.342" CENT & 1.75" SAMPLE BAILER TO WRP AT 9,300' MD (no issues - bailer empty) PULLED 2-7/8" WRP FROM 9300' MD ( partial element missing ) RAN 2-7/8" BLB, 2.25 WIREGRAB TO DEVIATION @ 10121' MD RAN 30' x 2.15 DUMMY GUNS, 2.30 CENT TO 10124' MD *** WELL LEFT S/I ON DEPARTURE *** Daily Report of Well Operations PBU D-09A y) PULLED 2-7/8" WRP FROM 9300' MD 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-09A Set WRP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-085 50-029-20381-01-00 11591 Conductor Surface Intermediate Liner Liner 9054 90 2653 9582 739 2479 9300 20" 13-3/8" 9-5/8" 7" 2-7/8" 8173 28 - 118 27 - 2680 26 - 9608 9107 - 9846 9112 - 11591 28 - 118 27 - 2680 26 - 8426 8016 - 8621 8020 - 9054 None 2670 4760 7020 13890 9300 4930 6870 8160 13450 11430 - 11480 4-1/2" 12.6# 13cr80, L80 23 - 9139 8993 - 9010 Structural 4-1/2" Baker S3 Packer 9013, 7939 8827, 9013 7788, 7939 Aras Worthington for Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028286 23 - 8042 N/A N/A 592 632 56149 54459 840 1440 700 700 1099 1117 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Otis Perm Packer 8827, 7788 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 2:17 pm, Jun 12, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.12 13:11:28 - 08'00' Torin Roschinger (4662) WCB 8-30-2024 RBDMS JSB 061924 DSR-6/12/24 ACTIVITYDATE SUMMARY 5/17/2024 ***WELL S/I UPON ARRIVAL*** (cbl) PULLED 4 1/2" FLOW-THRU SUB FROM 8,836' SLM / 8,839' MD (f.neck partially flow cut) ***CONT WSR ON 5/18/24*** 5/18/2024 T/I/O= 2500/500/0 TFS Unit 4 Assist Slick Line (Pump Down) Pumped 3 BBLS of 50/50 and 167 BBLS of Crude to Load the TBG. Pumped 87 BBLS Crude to assist SL with deviation. Further pumped 55 bbls Crude to attempt pressure test on plug in hole. Test = failed. Halliburton SL in control of well upon TFS departure FWHPS = 140/500/0 5/18/2024 ***CONT WSR FROM 5/17/24*** (cbl) LRS LOAD TUBING W/ 170bbls CRUDE RAN 2.25" CENT, 20' x 1.75" DD BAILER TO DEVITATION @ 10,126' SLM. RIH TO 11,442' SLM W/ T-BIRD ASSIST (4bpm) RAN HES CBL FROM 11,435' SLM TO 8,600' SLM.(good data) THUNDERBIRD ASSISTED W/ PUMPING DOWN CBL TOOLS, PUMPED 44 BBLS OF CRUDE DOWN TBG. SET 2-7/8" WFD WRP IN LINER @ 9,300' MD. SET 4 1/2" FLOW-THRU SUB IN XN-NIPPLE @ 8,933' MD (verified w/ checkset) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU D-09A WRP shown correctly on WBS, below. -WCB SET 2-7/8" WFD WRP IN LINER @ 9,300' MD. 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: 6/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240612 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPI-06 50029228220000 197195 5/2/2024 READ Caliper Survey MPI-09 50029229640000 200103 5/2/2024 READ Caliper Survey PBU B-04A 50029200720100 210095 5/20/2024 HALLIBURTON RBT PBU B-29B 50029215230200 217114 5/20/2024 HALLIBURTON RBT PBU C-26A 50029208340100 198145 5/24/2024 HALLIBURTON RBT PBU D-09A 50029203810100 199085 5/18/2024 HALLIBURTON RBT PBU D-23A 50029207380100 196188 5/18/2024 HALLIBURTON RBT PBU L-295 50029237740000 223115 5/25/2024 HALLIBURTON PPROF Please include current contact information if different from above. T38893 T38894 T38895 T38896 T38897 T38898 T38899 T38900 PBU D-09A 50029203810100 199085 5/18/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:38:22 -08'00' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 ',-:„,./.4;015) Mr* .1 6 ZOlt 199 --°35— Mr. Tom Maunder °6119 - Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB D Pad 14,11cka Cons,. CU '' SIOP Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion 0 Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 0-07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 0........4 D -08A 2021230 50029203720100 _ NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 , NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -198 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000_ .. NA 0.2 NA 3.40 2/10/2011 0 -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA _ 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 fik, 6/.2.-?hf; RECEIVED .. STATE OF ALASKA .. ALAS~IL AND GAS CONSERVATION CW'IMISSION JUN 272006 REPORT OF SUNDRY WELL OPERATAQ~ Gas Cons. Commission Anchorage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028286 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 181 Pull Tubing o Operation Shutdown 72.21' 11591 9055 11524 9026 110' 2680' 9608' 739' 2479' o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 4. Well Class Before Work: 181 Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 199-085 6. API Number: 50-029-20381-01-00 9. Well Name and Number: PBU D-09A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" x 30" 110' 110' 13-3/8" 2680' 2680' 4930 2670 9-5/8" 9608' 8426' 6870 4760 7" 9107' - 9846' 8016' - 8621' 8160 7020 2-7/8" 9112'-11591' 8020' - 9055' 13450 13890 11430' - 11480' 8993' - 9010' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Signature Form 10-404 Revised 04/2006 4-1/2", 12.6# 13Cr80 / L-80 9139' Tubing Size (size, grade, and measured depth): 9013' 8827' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Otis Perm Packer; 9-5/8" x 4-1/2" Baker 'S-3' Packer RBDMS 8Ft ,IlJN 2 8 2DD6 Treatment description including volumes used and final pressure: Cut and pull tubing from about 8954'. Cut and pull about 1630' of 9-5/8" casing. Run new 9-5/8" casing and cement with 106 Bbls (59 cu ft / 509 sx). Run new completion string. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Representative Dail Gas-Mef Water-Bbl Tubin Pressure Contact correct to the 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my knowe ge. Sundry Number or N/A if C.O. Exempt 306-172 o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Terrie Hubble Title Technical Assistant Phone Date Ci.u f, IV Prepared By Name/Number: 1ÁØ Terrie Hubble, 564-4628 Submit Original Only 564-4628 nRlh1t\1AI TREE"; 4-1/16" CrN? ~NOTES: ***4-1/2" CHROMETBG*** WB...LHEAo = MCEVOY D-09A ACTUATOR = BAKER 70° @ 10052' KB. ELEV = 72.21' BF. B...EV = 47.73' ~ ~ KOP= 3300' Max Angle = 86 @ 10940' I 2132' 1-14-1/2" HES X NIP, ID = 3.813" I Datum MD = 10787' · Datum TVo = 8800' SS I ~ - 2614' H 9-5/8" OV PKR I 19-5/8" SCAB CSG, 47#, L-80 TCII, 10 = 8.681" I 1631' GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 2680' W ~ ST MD TVD DEV lYÆ VLV LA TCH PORT DATE l 4 3197 3195 9 MMG OCR RKP 06/05/06 3 5860 5496 36 MMG DMY RK 0 06/05/06 2 7683 6883 39 MMG DMY RK 0 06/05/06 1 8716 7699 37 MMG DMY RK 0 06/05/06 Minimum 10 = 2.34" @ 9118' TOP OF 2-7/8" LINER I · I 8796' H4-1/2" HES X NIP, 10 = 3.813" I :8 ...,...." 8827' -19-5/8" X 4-1/2" BKRS-3 PKR, 10= 3.85" I ..::.:::. ~ · 8861' '-{4-112" HES x NIP, 10 = 3.813" I · 8933' -f 4-112" HES XN NIP, 10 = 3.725" I 14-112" TBG, 12.6#, 13CRSO VAM TOP 8964' I I 8960' -14-112" TBG STUB (DIMS 06/04/06) I .0152 bpf, 10 = 3.958" 8964' -19-5/8" x 4-1/2" UNIQUE OVERSHOT I I · 9000' -14-1/2" PKR SWS NIP, 10 = 3.813" I I 9011' H RT HAND RELEASE SAP LA TCH I ~ oc:::::;;> 9013' -19-5/8" x 4-1/2" OTIS ÆRM PKR, 10 = 3.85" I "'""'" I 9106' 1-14-112" PKR SWS NIP, 10 = 3.813" I TOPOF 7" LNR TIE-BACK SLV I 9107' 1 I ~ . I r 9112' H 3.0" DEPLOYMENT SUB, 10 = 3.00" I I~ I-- 9117' -i 7" BOT LNR HGR I I I 9127' 1-14-112" PKR SWN NIP, 10 = 3.80" (BB-IIND PIPE) I Î 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9139' I 9139' -14-1/2" WLEG, 10 = 3.854" (BB-IIND PIPE) I I 9124' H ELMO TT LOGGED 10/06/91 I I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 9608' I ~ L~ I BKR RETRIEVABLE WHIPSTOCK I 9842' I IRA TAG 9852' I I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I 10674' PERFORA TION SUMMARY REF LOG: POS MEMORY INDUCTION ON 09/19/99 I PBTD , 11524' ý~¡ ANGLEATTOPPERF: 71 @ 11430' / Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 11430 - 11480 0 09/25/99 I 2- 78" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 11591' I DATE REV BY COMMENTS DATE REV Bjý COMMENTS PRUDHOE BA Y UNIT 12/12/79 ORIGINAL COM PLETION WELL: D-09A 09/01/99 SIDETRACK (D-09A) PERMIT No: '1990850 06/05/06 D16 RWO API No: 50-029-20381-01 06/18/06 DAC/TLH DRLG DRAFT CORRECTIONS SEC 23, T11 N, R13E, 2020' NSL & 1067' WB... BP Exploration (Alaska) e e D-09A Prudhoe Bay Unit 50-029-20381-01 199-085 Accept: Spud: Release: Ri: PRE-RIG WORK 05/02/06 PULLED 41/2" PXX PLUG BODY AND PRONG FROM X-NIP AT 8992' SLM. RDMO. 05/06/06 T/I/O = 2320/360/100. TEMP = SI. T, IA AND OA FL'S FOR EL (PRE FASDRILL). TBG FL AT 8575' (STA #1) (131 BBLS). IA FL AT 115' (7 BBLS). OA FL AT 40' (3 BBLS). 05/18/06 SET 4-1/2" BAKER QUICKDRILL PLUG AT 8945' ELMD. BLED TUBING DOWN FROM 2300 PSI TO 100 PSI. LRS PUMPED DOWN TBG FOR CMIT-TXIA AND SAW TBG PRESSURE BREAK OVER AT 3400 PSI TO FAIL THE CMIT. T/I/O=2300/0/240 ASSIST E-LlNE. PUMPED 150 BBLS OF CRUDE DOWN THE TUBING. ATTEMPTED CMIT TXIA, AT 3400 PSI, TUBING AND IA LOST OVER 3000 PSI IN LESS THAN A MINUTE. 05/19/06 T/I/O = 250/350/100. SI. BLEED WHPS TO 0 PSI (PRE-RIG). TBG FL AT SURFACE, IA FL AT 120', OA FL AT 36'. AL LINE SHUT-IN AT TREE, (2100 PSI). BLEED WHPS TO BLEED TRAILER 68-625 (1 HR), 11.8 BBLS. NO CHANGE IN TBGP OR lAP, OAP INCREASED 150 PSI TO 250 PSI. TBG, IA AND OA FL AT SURFACE. FINAL WHPS = 250/350/250. TAGGED QUICKDRILL AT 8945' ELMD TO CONFIRM NO MOVEMENT DURING FAILED CMIT-TXIA. OS/20/06 JET CUT TUBING AT 8940' WITH 3.65" SCHLUMBERGER POWER CUTTER. CCL TO CUTTER = 14.4' CCL STOP DEPTH = 8925.6'. OS/22/06 DOUBLE TRUCK WELL KILL (PRE-RWO) MIT OA TO 2000 PSI. (PASSED) TRUCK #1 - LRS UNIT #42 PUMPED 5 SBLS NEAT METHANOL SPEAR, 685 BBLS 2% KCL AND 38 BBLS DIESEL (FREEZE PROTECT) DOWN TSG. TRUCK #2 - LRS UNIT #62 PUMPED 5 BBLS NEAT METHANOL SPEAR, 248 BBLS 2% KCL AND 134 BBLS DIESEL (FREEZE PROTECT) DOWN IA. TRUCK #1 PUMPED ENTIRE FLUID AT 1.5 BPM. TRUCK #2 PUMPED ENTIRE FLUID AT 5 BPM. BOTH TRUCKS PUMPED AT SAME TIME. MIT OA PRESSURED UP TO 2000 PSI WITH 1 BBL DIESEL. MIT OA LOST 140 PSI IN 1ST 15 MINUTES AND 40 PSI 2ND 15 MINUTES FOR A TOTAL OF 180 PSI IN 30 MINUTES. FREEZE PROTECTED FLOW LINE WITH 124 BBLS DIESEL. FINAL WHP'S=O/O/O. SET BPV. T/I/O/= 0/0/0 MCEVOY SSH 13' 5M WELLHEAD, 13" X 4.5" 5-SEAL ADAPTER, 4.5 UPPER TREE PPPOT-T: BLED TUBING HANGER VOID TO 0 PSI. INSTALL TEST PUMP AND TEST VOID TO 5,000 PSI FOR 30 MINUTES. TEST PASS. NOTE: FUNCTIONED ALL LOCK DOWN PINS. ALL FUNCTIONED WELL WITH NO SIGN OF ANY BENT OR BROKEN PINS. PPPOT-IC: ATTEMPT TO BLED 9 518" CASING VOID TO 0 PSI. FUNCTION ALL LOCKSCREWS. ALL FUNCTION GOOD. BLED VOID TO "0". INSTALL TEST PUMP ON TEST PORT. ATTEMPT TO TEST VOID TO 3,500 PSI. PRESSURE WOULD NOT INCREASE BEYOND 1500 PSI AND BLED IMMEDIATELY TO 500 PSI. TEST FAILED. NOTE: FUNCTIONED ALL LDS ON CASING HANGER VOID. ALL FUNCTIOND WELL WITH NO SIGN OF ANY BENT OR BROKEN LOCKSCREWS. e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/23/2006 08:30 - 12:00 3.50 MOB N WAIT PRE 12:00 - 14:00 2.00 MOB P PRE 14:00 - 15:00 1.00 MOB P PRE 15:00 - 17:00 2.00 MOB P PRE 17:00 - 18:00 1.00 WHSUR P WHDTRE 18:00 - 21 :30 3.50 WHSUR N WAIT WHDTRE 21 :30 - 00:00 2.50 WHSUR P WHDTRE 5/24/2006 00:00 - 01 :00 1.00 WHSUR P WHDTRE 01 :00 - 01 :30 0.50 WHSUR P WHDTRE 01 :30 - 02:00 0.50 WHSUR P DECOMP 02:00 - 03:30 1.50 WHSUR P DECOMP 03:30 - 07:00 3.50 BOPSU P DECOMP 07:00 - 07:30 0.50 BOPSU WAIT DECOMP 07:30 - 12:00 4.50 BOPSU DECOMP 12:00 - 13:00 13:00 - 14:00 14:00 - 15:00 DECOMP P/U Lubricator Extension and DSM Lubricator. Pull TWC, Tubing on Vac. UD Lubricator and Extension. DECOMP P/U Baker 4-1/2" Tbg Spear wI Double Grapple. M/U Spear to Jt of DP. Engage Tbg, Check Pressure on IA and OA both = zero. Pull Hanger off Seat wI 125,000 Ibs. Once Hanger Off Seat, Gas coming past Hanger. Shut-in Well, 50 psi on Tbg and IA. DECOMP Circulate through Choke, Pump Down Tbg at 3.0 bpm and 200 psi. No Returns at surface, bleed gas through gas buster. After Pumping 80 bbls pressure on IA = zero. Continue pumping, bring rate up to 5 bpm and 450 psi. Still not returns to surface. Pump full tubing volume = 140 bbls.Pump 50 bbls down IA at 5.0 bbls/min. Check Pressures, all Zero, Open Well and 1.00 WHSUR P 1.00 PULL P 1.00 PULL P Ready Rig to Move. Back Rig off Well D-10. Wait on Pad Prep of Well D-09. Lay Rig Mats and Herculite around D-09. Move Rig from D-10 to D-09. Spot Rig Over Well. R/U Double Annulus, Circulation Manifold and Hoses, Burm and Spot Slop Tank. Spot Number 2 Pump and R/U. Wait on BPV Lubricator and Seawater to arrive. P/U BPV Lubricator and Pull BPV. UD BPV Lubricator. Tubing on Vac. IA initally had 1000 psi, bleed to zero quickly. OA had 200 psi, bleed to zero quickly. Wait on Seawater Trucks. 870 bbls on location Wait on another 590 bbls. Bull Head Tubing Volume 185 bbls @ 8 bpm, 800 psi. Bull Head Annulus Volume 690 bbls @ 8 bpm, 1,450 psi. Lined Back Up On Tubing Side and Bull Head an Additional 175 bbls at 6.5 bbls, 1410 psi. Continue Bull Heading Operations. At 6.5 bpm with 1,450 psi. Monitor Well, 0 psi on Tubing, 0 psi on Casing Annulus. Set and Test TWC, Tested to 1,000 psi. BID Surface Lines. NID Tree and Adapter Flange, Inspect Hanger. N/U BOPE, Change Out API Ring Between Spacer Spool and Bottom of BOP Stack. 4-1/2" Test Joint not on location. Locate and Confirm Transportation before Starting BOPE Test. Test BOPE - 250psi low and 3500 high for 5 mins each. Witness of Test Waived by John Crisp wI AOGCC. Test Witnessed by BP WSL and Doyon ToolPusher. All Equipment Tested Passed Test #1 Hydril, Chk Valve #1,12,13,14, Upper IBOP & Kill HCR Test #2 Chk Valve #9,11, Lower IBOP, Manual Kill. Test #3 Chk Valve #5,8,10, Dart Valve Test #4 Chk Valve #4,6,7, TIW Valve Test #5 Chk Valve #2 Test #6 Choke HCR Valve Test #7 Manual Kill Valve Test #8 Blind Rams & Chk Valve #3 Test #9 4-1/2" Test Joint and Variable Pipe Rams Test #10 4" Test Joint and Variable Pipe Rams Test #11 Koomey Printed: 6/12/2006 9:40:27 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-09 0-09 WORKOVER DOVON DRILLING INC. DOVON16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/24/2006 14:00 - 15:00 1.00 PULL P DECOMP Monitor. 15:00 - 15:30 0.50 PULL P DECOMP POOH wI Spear and Tbg Hanger. Release Spear. Terminate Control Lines. UD Spear and Tbg Hanger. 15:30 - 16:30 1.00 PULL N WAIT DECOMP M/U TIW. Pump 5 bbls /15 mins down IA while Waiting on more Seawater. 16:30 - 17:00 0.50 PULL P DECOMP Pump Down IA at 6 bpm. Catch Up to Fluid Level after 80 bbls. 17:00 - 18:00 1.00 PULL P DECOMP Circulate Bottoms Up down Tbg at 5 bpm at 130 psi. See Returns after 40 bbls pumped. Returns around 50%. 18:00 - 20:00 2.00 PULL N WAIT DECOMP Waiting On Trucks, pumped 5 bbls every 15 min wlHole Fill Pump. 20:00 - 22:30 2.50 PULL P DECOMP Pumped 638 bbls at 7bpm 590 psi. Increased Rate to 11 bpm and 1450 psi. Returns Approx 50%. 22:30 - 23:00 0.50 PULL P DECOMP Monitor Well, RID BID Circulating Lines. 23:00 - 00:00 1.00 PULL P DECOMP Pull Tubing 4.5" Tubing f/8,940' to 7,780' with Control lines. 5/25/2006 00:00 - 05:30 5.50 PULL P DECOMP POOH and UD 4.5" Tubing. 05:30 - 06:30 1.00 PULL P DECOMP M/U Head Pin and Circualte 160 bbls. Returns Seen at surface, 50% returns while pumping. 06:30 - 08:30 2.00 PULL P DECOMP Continue to POOH and UD 4.5" Tbg. 221 Jts of 4-1/2" Tbg, 5 GLM's, 1 SSSV, 26 Clamps, 4 Stainless Steel Bands, and 1 Cut Jt measuring 29.21'. Cut was clean but did have large flare to it. 08:30 - 09:30 1.00 BOPSU P DECOMP Rig Up Test Equipment. MIU Test Joint and Test Plug. Land Test Plug in Wellhead. 09:30 - 12:30 3.00 BOPSU N HMAN DECOMP Not able to get test plug to hold. Back Out and Re-Seat Several Times. Run In All LOS, Still Unable to Hold Fluid in Stack. Consult Cameron on Problem. Try New Test Plug, Still Same Problem, Unable to Hold Fluid. Examine Test Plugs against Tubing Hanger. Evident using wrong plug. Correct Test Plug Brought Out to Location by Cameron. 12:30 - 13:00 0.50 BOPSU P DECOMP Test BOPE. Test Hydril 250 psi Low and 3500 psi High for 5 mins each. Good Test. Witnessed by BP WSL and Doyon Tool Pusher. 13:00 - 13:30 0.50 BOPSU DECOMP RID Test Equipment and Pull Test Plug. Install Wear Bushing. 13:30 - 15:00 1.50 CLEAN DECOMP PIU BHA #2; 8-1/2" Bit, Csg Scraper, 2 Boot Baskets, Bumper Sub, Jars, 9 6-1/4" DC's. Total Length = 316.9 ft 15:00 - 21 :30 6.50 CLEAN P DECOMP PIU DP from Pipe Shed and RIH 1 x1. Continue to Fill Hole wI 5 bbls per 15 mins. 21 :30 - 22:30 1.00 CLEAN P DECOMP Obtain Parameters Pumps On Up Weight = 185,000#, Down Weight = 155,000#, Rotating Weight = 175,000#. Tag Tubing Stump At 8,942'. Pumped BIU At 10 bpm with 2,290 psi. Scraper Depth 8,939'. 22:30 - 23:00 0.50 CLEAN P DECOMP UD Single BID T/D, RlU to Reverse Circulate. 23:00 - 00:00 1.00 CLEAN P DECOMP Reverse Circ 91 bbls at 10 bpm and 680 psi. 5/26/2006 00:00 - 00:30 0.50 CLEAN P DECOMP POOH wlScraper BHA. 00:30 - 01 :30 1.00 CLEAN P DECOMP Cut and Slip 123' of Drilling Line. 01 :30 - 04:00 2.50 CLEAN P DECOMP Continue to POOH. 04:00 - 05:00 1.00 CLEAN P DECOMP UD Scraper BHA. 05:00 - 05:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 05:30 - 08:00 2.50 CLEAN P DECOMP Make Up 9-5/8" Model 3L RBP on 6-1/4" Drill Collars. Difficult Time getting through wear bushing. Pull Back Out with RBP and inspect. Pull Wear Bushing and Inspect. P/U Different RBP and RIH. Printed: 6/12/2006 9:40:27 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/26/2006 08:00 - 12:30 4.50 CLEAN P DECOMP RIH wI RBP on DP to 8930'. 12:30 - 14:00 1.50 DHB P DECOMP Set RBP at 8930'. Made multiple attempts to set from 8930- 8900'. Could not get Plug Set. Run in hole to top of plug and tag. PUH to 8930' again and set RBP. 14:00 - 16:30 2.50 DHB P DECOMP Circulate Surface to Surface with Seawater. Took 53 bbls to fill pipe. Circulate at 10 bpm and 1700 psi. Full Returns. Pressure Test 9-5/8" Casing for 30 mins at 3500 psi. - Good Test 16:30 - 20:00 3.50 CLEAN P DECOMP POOH wI DP and DC's, Stand Back in Derrick. 20:00 - 20:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 20:30 - 21 :30 1.00 EVAL P DECOMP PJSM RlU SWS Tools For USIT and Corrosion Logs. 21 :30 - 00:00 2.50 EV AL P DECOMP Begin Logging Program, RIH to 8,880' and Log Up Hole. 5/27/2006 00:00 - 06:00 6.00 EV AL P DECOMP Continue US IT and Corrosion Logs, After initial Evaluation Decision Made to Re-Log Section at 7,500' In Hi-Res Mode. 06:00 - 07:00 1.00 EVAL P DECOMP RID SWL Equipment. 07:00 - 07:30 0.50 EVAL P DECOMP M/U HES RBP#2 BHA. 07:30 - 10:30 3.00 EVAL P DECOMP Review Results from USIT Log for Corrosion and Cement. Consult Town and SLB E-Line on Cement for Best Cut Depth. Decision Made to Cut Above 1650'. 10:30 - 12:30 2.00 DHB P DECOMP RIH W/RBP BHA to 2525', Drilling Parameters Up Weight = 88,000#, Down Weight = 92,000#, 12:30 - 13:00 0.50 DHB P DECOMP Set RBP @2525' and Test to 1000 psi. 13:00 - 13:30 0.50 CLEAN P DECOMP Pump 20 bbl Hi-Vis sweep, Circ Btms Up at 10 bpm and 650 psi. 13:30 - 14:30 1.00 CLEAN P DECOMP B/O BID Top Drive and POOH. Stand Back DP and Stand Back DC, Lay Down Running Tool. 14:30 - 16:30 2.00 DHB P DECOMP P/U 7" Lubricator Ext. and Set in Rotary. Dump 2,200# 20/40 Mesh Sand in on RBP. Pull Lubricator Extendsion. 16:30 - 17:30 1.00 FISH P DECOMP MIU 8-1/4" Multi String Cutter Assembly. BHA Consists of Multi String Cutter, XO, Stabilizer, XO. BHA = 14.13'. RIH to 1 ,580'. Locate Collars at 1627' and 1588'. 17:30 - 18:00 0.50 FISH P DECOMP M/U TID Establish Parameters, Up Weight=65,000#, Down Weight= 65,000#, 60 rpm 2,000 ft-Ibl Torque. Spot Cutter at 1,612'. 18:00 - 18:30 0.50 FISH P DECOMP Line Up and Test Annular Return Line to 1,000 psi. 18:30 - 20:00 1.50 FISH N WAIT DECOMP Wait on Clean Brine Truck, Dirty Trucks and Hot Oil. 20:00 - 00:00 4.00 FISH N DECOMP Make Cut at 1,612'. Pump Pressure at 960 psi w/5,000 ft-Ibs Torque, Clean Cut. Shut Annular Preventer Circulate at 1bpm1,280 psi, Increased pump Rate to 2 bpm with 1,600 psi, Pumped 96 bbl 9.8 ppg brine at 5.5 bpm wI 1,420 psi FCP. Pumped 96 bbls Hot Diesel at 2 bpm at 600 psi. Shut In For 30 min, Circ Out Diesel w/130 bbls Brine @ 7 bpm and 2020 psi FCP. Pumped 20 bbl Sweep and 120 bbl 9.8 brine at 7 bpm and 2,020 psi. Pumped 60 bbl Hot Diesel and Shut in for 1 hr. 5/28/2006 00:00 - 01 :00 1.00 FISH P DECOMP Continue.. Let Hot Diesel Soak for 1 hr. 01 :00 - 02:00 1.00 FISH P DECOMP Circulate Safe-Surf-O Pill and Chase with 120 bbls 9.8 ppg Hot Brine at 9 bpm. Returns Clean. 02:00 - 03:00 1.00 FISH P DECOMP POOH wI DP fl 1,612' . UD Casing Cutter. Clear and Cllean Rig Floor. 03:00 - 04:00 1.00 BOPSU P DECOMP Change Out Pipe Rams to 9 5/8". 04:00 - 05:00 1.00 BOPSU P DECOMP PIU Test Joint and Set in Wellhead. Test 9 5/8" Rams 250 psi Low Test and 3,500 psi High Test. 05:00 - 07:00 2.00 BOPSU P DECOMP Split BOP Stack, NID 15" Spacer Spool. NID Tubing Spool. Printed: 6/12/2006 9:40:27 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: Pull PackOff and Install Handles on Slips. N/U Drilling Spool and BOP Stack. 08:30 - 09:00 0.50 DECOMP Test Drilling Spool and BOP Stack Connection to 2000 psi f/15 mins. 09:00 - 09:30 0.50 FISH P DECOMP M/U Casing Spear. 09:30 - 10:30 1.00 FISH P DECOMP Spear 9 5/8" CSG, Back Out LDS and Pull Casing to Rig Floor. Casing Pull Free at 145,000 Ibs. Pull to the Floor wi 110,000 Ibs. 10:30 - 11 :30 1.00 FISH P DECOMP Break Out and UD Casing Spear. Break Out and UD First Joint and Slips. Required Full Torque on Power Tongs to break free. 11 :30 - 12:00 0.50 CLEAN P DECOMP M/U Circulating Head. 12:00 - 13:00 1.00 CLEAN N WAIT DECOMP Wait on Little Red Hot Oil to arrive on location wI Diesel 13:00 - 14:30 1.50 CLEAN P DECOMP RlU Little Red Hot Oil. Pressure Test Lines to 2,500 psi and Pump 102 bbls Hot Diesel, 2 bpm at 325 psi. RID Little Red and Line Up and Pump 40 bbl HI-VIS Sweep and 80 bbl Brine, 7bpm and 600 psi. Reciprocate Pipe while pumping. 14:30 - 15:30 1.00 CLEAN P DECOMP Shut-In for 1 hr and let diesel soak, continue to Reciprocate Pipe. 15:30 - 16:00 0.50 CLEAN P DECOMP Pump 170 bbls Brine at 9bpm and 1200 psi. 16:00 - 17:00 1.00 CLEAN P DECOMP RID Circulating Hoses, RID Circ Head. RlU to UD 9-5/8 Casing. 17:00 - 23:00 6.00 CASE P DECOMP POOH and UD 9-5/8" 47#, L-80 BTC CSG. 41Jts and 1 Cut Jt 24.29'. Connections a Little Snug, Average Break Out Torque 35,000 I 40,000 ft-Ibs, Max 60,000 ft/lbs. 23:00 - 00:00 1.00 CASE P DECOMP Clear and Clean Rig Floor. 5/29/2006 00:00 - 01 :30 1.50 BOPSU P DECOMP CLean and Clear Rig Floor. Change Pipe Rams from 9-5/8" to 3-1/2'" x 6" Variables. 01 :30 - 02:30 1.00 BOPSU P DECOMP M/U Test Jt and Pressure Test Rams, 250 psi Low Test and 3,500 psi High Test Held For 5 Minutes. 02:30 - 04:00 1.50 CLEAN P DECOMP M/U Wash Pipe Assembly, BHA consists of Wash Pipe Shoe, Wash Pipe, Wash Over Boot Basket, XO, Scraper, Bit Sub, LBS, Oil Jar, XO, 9 DC, XO. BHA= 345.89' 04:00 - 05:00 1.00 CLEAN P DECOMP RIH wI Wash Pipe Assembly on DP. RIH Slowly due to large diameter BHA to keep fluid from coming over top of DP. 05:00 - 06:00 1.00 CLEAN P DECOMP Reverse Circ 60 bbls at 7.0 bpm and 440 psi. Large Volume of Arctic Pack in Returns. 06:00 - 06:30 0.50 CLEAN P DECOMP RIH wI DP to 1114'. 06:30 - 07:30 1.00 CLEAN P DECOMP Reverse Circ 150 bbls at 7.0 bpm and 500 psi. Large Volume of Arctic Pack in Returns. 07:30 - 08:00 0.50 CLEAN P DECOMP RIH wI DP to 1595'. M/U Top Drive. Establish Parameters; P/U Wt = 86,000 Ibs, S/O Wt= 82,000 Ibs, Rt Wt= 82,000 Ibs at 50 rpm's and 2,000 ft-Ibs torque. Pump Rate = 3.0 bpm at 60 psi. 08:00 . 09:30 1.50 CLEAN P DECOMP Tag Up on Casing Stub at 1612'. Wash Down Over Casing. Mill and Wash Through Cement at 1622' - 1642'. Hard Cement Found 1626' - 1642'. 10,000 Wt on Mill, 10-14,000 ft-Ibs torque and 60 rpm's. 09:30 - 10:00 0.50 CLEAN P DECOMP P/U Shoe to Just Above Casing Collar. Reverse Circ 20 bbl High Visc Sweep Surface to Surface wI 280 bbls. 9 bpm at 880 psi. A Large Volume of Cement and Arctic Pack seen in Returns. 10:00 - 11 :30 1.50 CLEAN P DECOMP POOH and Stand Back DP and DC's. 11 :30 - 13:30 2.00 CLEAN P DECOMP UD Wash Pipe BHA, Boot Baskets, and Jars. Printed: 6/12/2006 9:40:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/29/2006 13:30 - 15:30 2.00 CLEAN P DECOMP PJSM wI SWS E-Line. PIU Lubricator Extension. RlU E-line Sheeves, E-Line, Pump-In Sub and Packoff I Line Wiper. 15:30 - 16:00 0.50 CLEAN P DECOMP RIH wI E-Line. CCL, 12ft 3 Strand String Shot and Bottom Nose. Tie into Cut 9-5/8" Joint at 1612'. Fire String Shot from 1620.5' to 1632.5'. 16:00 - 17:00 1.00 CLEAN P DECOMP POOH and RID E-Line. 17:00 - 18:00 1.00 CLEAN P DECOMP M/U Csg Back Off BHA. Bullnose, 9-DC's, Blank Sub, Lower Anchor, Power Section, Upper Anchor. Total Lenght = 323.11 ft. 18:00 - 19:30 1.50 CLEAN P DECOMP RIH Fill Pipe Every 5 stds to 1,932'. 19:30 - 20:30 1.00 CLEAN P DECOMP Spot Backoff Tool Across Csg Collar at 1,627'. Set bottom Anchor 1,500 psi, Hang 20,000# Collars. Set top Anchor 5,000 psi, Set Down 20,000# Drill Pipe Weight.Cycle Tool 13 Times, Made 5.5 Rotations to Left. Released Anchor. 20:30 - 21 :30 1.00 CLEAN P DECOMP POOH 21 :30 - 23:00 1.50 CLEAN P DECOMP UD Back Off Assembly. 23:00 - 23:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 23:30 - 00:00 0.50 CLEAN P DECOMP M/U Casing Spear Assembly, BHA Consists of Bull Nose, Packoff, Spear, Spear Extendsion, Stop Sub, LBS, XO. BHA = 24.49'. 5/30/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RIH to top of Fish 1,627'. 00:30 - 01 :00 0.50 CLEAN P DECOMP Parameters: 65,000# Up Weight, 62,000# Down Weight. Pumping at 3 bpm #2 pump at 60 psi. Stabbed Into 9 5/8" Casing Stub at 1,612'. 01 :00 - 01 :30 0.50 CLEAN P DECOMP Pumped 20 bbl HI-VIS Sweep. 01 :30 - 02:30 1.00 CLEAN P DECOMP POOH w/Fish. UD Same. 02:30 - 07:00 4.50 CLEAN P DECOMP Change Ram to 9 5/8" CSG. Rig Up Test Equipment. Test 9 5/8" Rams. Test Plug Would Not Hold. Set New Test Plug Good Test. 07:00 - 09:00 2.00 CASE P TIEB1 RlU to Run 9 5/8" CSG. 09:00 - 14:00 5.00 CASE P TIEB1 PJSM PIU and Run 95/8" 47# L-80 TCII Casing. Torque Turning All Connections Using Jet Lube Seal Guard Thread Compound. Average Torque = 17,000 ft-Ibs. 14:00 - 14:30 0.50 CASE P TIEB1 RID Casing Equipment Clear Floor. 14:30 - 15:30 1.00 CASE P TIEB1 Obtain Drilling Parameters: 100,000# Up Weight, 102,000# Down Weight. Screw Into Casing Stub 12.5 Rotations, 11,000 ft-Ibs Torque. 15:30 - 16:00 0.50 CASE P TIEB1 Pressure Tested Casing to 2,000 psi for 30 minutes, Good Test. 16:00 - 16:30 0.50 CASE P TIEB1 Nipple Down BOPs, Nipple Down Drilling Spool. 16:30 - 17:30 1.00 CASE P TIEB1 Set Emergency Slips With 50,000#. 17:30 - 18:00 0.50 CASE P TIEB1 Nipple Up BOPs. 18:00 - 18:30 0.50 CASE P TIEB1 Body Test BOPs, 250 psi Low 3,500 psi High. 18:30 - 19:30 1.00 CASE P TIEB1 RID XOs and BID Top Drive, RlU Cement Head and Lines. 19:30 - 20:30 1.00 CEMT P TIEB1 PJSM With Rig Crew, Cement Crew, Truck Drivers, Discussed Safety Issues and Plan Forward for Cement Job. Pressured Up To Open ES Cementer. Shifted to Open Position at 2,650 psi. Batch Mixed Cement. 20:30 - 22:00 1.50 CEMT P TIEB1 Pumped 5 bbls Water, Tested Lines to 4,500 psi, Pumped 50 bbls 9.8 brine, 108 bbls Class G 15.8 CMT. Additives 0047 Anti Foam 0.200 gallsk, 0065 Dispersant 0.300% BWOC, D600G GAS BLOCK 2.000 gal/sk, D11 0 Retarder 0.0010 Printed: 6/12/2006 9:40:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/30/2006 20:30 - 22:00 1.50 CEMT P TIEB1 gal/sk. Pumping Schedule as Pumped Rate Psi 20 bbls 7.4 bpm 809 40 bbls 7.7 bpm 750 60 bbls 7.8 bpm 650 80 bbls 8.0 bpm 612 100 bbls 8.0 bpm 612 108 bbls 8.0 bpm 562 Kicked Out Closing Plug with 5 bbls Water, and Displaced with 113 bbls 9.8 Brine. Bumped Plug, Cement In Place at 21 :35. Cement Back to Surface 18 bbls. Pumped Rate Psi 25 bbls 6bpm 278 50 bbls 6bpm 516 75 bbls 6bpm 759 100 bbls 6bpm 1116 113 bbls 6bpm 1118 22:00 - 22:30 0.50 CASE P 22:30 - 00:00 1.50 CASE P 5/31/2006 00:00 - 01 :00 1.00 CASE P 01 :00 - 02:00 1.00 CASE P 02:00 - 04:00 2.00 CASE P 04:00 - 06:00 2.00 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 08:00 1.50 CASE P 08:00 - 14:30 6.50 CASE P 14:30 - 15:00 0.50 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 22:30 7.00 CASE P TIEB1 Pumped Out Stack and Casing to the Casing Spool. Nipple Down BOPs. TIEB1 R/U Wachs Cutter, Cut 9 5/8" Casing TIEB1 NID Drilling Spool, Set Back BOP Stack. TIEB1 NIU 135/8",5,000 psi Tubing Spool TIEB1 Fill Tubing Spool Void with Plastic Sealant and Test to 3,800 psi, For 30 minutes. TIEB1 Nipple Up BOPE TIEB1 R/U to Test BOPE TIEB1 Test BOPE 250 Psi Low Test, 3,500 psi High Test. Annular Preventer Failed. TIEB1 PJSM, Change Out Annular Preventer. TIEB1 Nipple Up Riser. TIEB1 R/U to Test BOPE. TIEB1 Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Jeff Jones. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, Choke Valves 12,13,14,1, and Dart Valve and HCR Kill. Test #2- Manual Kill, Floor Valve, Choke Valves 9, 11. Test #3- Choke HCR, Upper Kelly. Test #4- Manual Choke, Lower Kelly. Test #5- 4" Pipe Rams. Test #6- Blind Rams, Choke Valves #5, 8, 10. Test #7- Choke Valve # 6 Test #8-Choke Valve # 7 Test #9- Choke Valve # 2 Test #lO-Choke Valve # 3 Printed: 6/1212006 9:40:27 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-09 0-09 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 5/31/2006 15:30·22:30 7.00 CASE P TIEB1 Test #11- 4.5" Pipe Rams. Test #12 - Choke Valve # 4 Accumulater Test- 3,000 psi Starting Pressure, 1,800 psi After Actuation, First 200 psi in 28 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,200 psi. Rebuilt Choke Valve #4 On Choke Manifold. 22:30 - 23:00 0.50 CASE P TIEB1 RID Test Equipment, Pull Test Plug, Install Wear Ring. 23:00 - 00:00 1.00 CASE P TIEB1 MIU Drill Out Assembly. BHA Consists Of Bit, 2 Boot Baskets, Scraper, XO, Bit Sub, LBS, Oil Jar, XO, 9 Drill Collars, XO. BHA=315.72'. 6/1/2006 00:00 - 00:30 0.50 CASE P TIEB1 Continue to MIU Drill Out Assembly. BHA Consists Of Bit, 2 Boot Baskets, Scraper, XO, Bit Sub, LBS, Oil Jar, XO, 9 Drill Collars, XO. BHA=315.72'. 00:30 - 02:00 1.50 CASE P TIEB1 RIH with 4" DIP to 1,565' Obtain Drilling Parameters, 75,000# Up Weight, 80,000# Down Weight, 80,000# Rotating Weight, Pumping 10 bpm with 810 psi. Tagged Cement at 1,593' Drilled Out CMT to Top ES- Cementer Closing Plug at 1,616'. 02:00 - 04:30 2.50 DRILL P TIEB1 Drilling ES- Cementer 5,000 110,000 # wob, 10 bpm, 810 psi, 70 rpm. Circulate B/U 13 bpm with 1,360 psi. 04:30 - 05:30 1.00 DRILL P TIEB1 RIH Tagged Top Of Sand At 2,461, Pumped Hi - Vis Sweep at 18 bpm with 3040 psi. 05:30 - 07:00 1.50 CASE P TIEB1 RlU to Test 9 5/8" CSG to 3,500 psi f/30 minutes and RID 07:00 . 07:30 0.50 DRILL P TIEB1 POOH wI Drill Out BHA. 07:30 . 08:00 0.50 CASE P TIEB1 UD BHA. 08:00 . 08:30 0.50 CASE P TIEB1 Clear and Clean Rig Floor. 08:30 - 09:00 0.50 CASE P TIEB1 MIU Reverse Basket Assembly, BHA Consists of Reverse Basket, XO, Bit Sub, LBS, Jar, XO, 9 Drill Collars, XO, BHA=317.02. 09:00 - 09:30 0.50 CASE P TIEB1 RIH wI 4" Drill Pipe to 2,479'. 09:30 - 10:30 1.00 CASE P TIEB1 Obtain Parameters: Up Weight = 88,000#, Down Weight = 93,000#, Rotating Weight = 94,000#,40 rpm, 1-2,000 ft-Ibs Torque, 2 bpm, 2770 psi. Washto 2,469'. 10:30 . 12:30 2.00 CASE P TIEB1 POOH From 2,469', Clean Reverse Basket of Cement. 12:30 - 14:00 1.50 CASE P TIEB1 MIU Reverse Circulating BHA, RIH to 2,429'. 14:00 - 15:30 1.50 CASE P TIEB1 Wash Down fl 2,461', T/2,510' at 7 bpm with2,950 psi, 30 rpm, 2,500 ft·lbs Torque. 15:30 - 17:00 1.50 CASE P TIEB1 Fill Pits wI Clean Sea Water, Pumped 20 bbl Hi-Vis Sweep, Chased wI Clean Sea Water at 7 bpm and 2900 psi. 17:00 - 19:00 2.00 CASE P TIEB1 BID Top Drive, POOH fl 2,510', Cleaned Reverse Circulating Basket. 19:00 - 20:00 1.00 CASE P TIEB1 MIU Reverse Circ Basket and RIH to 2,510'. 20:00 - 20:30 0.50 CASE P TIEB1 Worked Reverse Circ Basket, fl 2,510' to 2,513'. Parameters Up Weight = 88,000#, Down Weight = 93,000#, Rotating Weight = 95,000#, 35 rpm, 2,500 ft-Ibs Torque. 20:30 . 21 :00 0.50 CASE P TIEB1 Pump 40 bbl Sweep at 6 bpm, 2,900 psi. 21 :00 - 22:00 1.00 CASE P TIEB1 BID Top Drive, POOH f/2,513'. 22:00 - 00:00 2.00 CASE P TIEB1 MIU RBP Retreving Assembly RIH. 6/2/2006 00:00 - 00:30 0.50 DHB P TIEB1 Continue to RIH to 2,510', Obtain Parameters: 92,000# Down Weight, Up Weight 85,000#, SIO to 2,513' Latch up RBP Set down 15,000# to confirm PIU with Right Hand Rotation, Unseat Printed: 6/12/2006 9:40:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-09 0-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: 6/2/2006 00:00 - 00:30 0.50 DHB P TIEB1 RBP. 00:30 - 01 :00 0.50 DRILL P TIEB1 CBU at 12 bpm, with 630 psi, BID T/D. 01 :00 - 02:00 1.00 DRILL P TIEB1 POOH wI RBP f/2,525'. 02:00 - 02:30 0.50 DRILL P TIEB1 UD RBP. 02:30 - 03:30 1.00 CASE P TIEB1 Clear and Clean Rig Floor, RlU and Test CSG to 3,500 psi on Chart For 30 minutes RID Test Equipment. 03:30 - 04:00 0.50 DRILL P TIEB1 Service Rig. 04:00 - 07:30 3.50 DRILL P TIEB1 RIH with RBP retreval assembly to 8930'. 07:30 - 08:00 0.50 DRILL P TIEB1 Obtain parameters. UWT = 185K, DWT = 145K. Pump @ 12 bpm @ 2900 psi. 08:00 - 08:30 0.50 DRILL P TIEB1 Latch RBP @ 8930'. Set down 15K, P/U to 210K to release. Well on a vacuum & taking +-390 bph. Pump @ 12 bpm & attempt to release RBP. 08:30 - 09:30 1.00 DRILL P TIEB1 Shut down pumps. Allow fluid level in well to fall & lower hydrostatic pressure on plug. Release plug. 09:30 - 14:00 4.50 DRILL P TIEB1 POH with RBP from 8930'. Lost 20K string weight @ 7250'. Filling well with triple calculated metal displacement while POH. 14:00 - 14:30 0.50 DRILL P TIEB1 UD RBP. Lost 1 1/2 rubbers (packer element) from plug. Rubbers are approx 5 Ibs each in weight. 14:30 - 15:00 0.50 DRILL P TIEB1 Clear & clean rig floor. Filling well with 100 bph while out of the hole. 15:00 - 16:30 1.50 DRILL P TIEB1 PIU Reverse circ junk basket assy with 10' wash pipe extension. 16:30 - 19:00 2.50 DRILL P TIEB1 RIH with RCJB assy to recover rubbers from RBP. To 8,874'. 19:00 - 19:30 0.50 DRILL P TIEB1 Obtain Parameters: 190,000# Up Weight, 150,000# Down Weight, 168,000# Rotating Weight, 30 rpm, 6,000 ft-Ibs, 7 bpm, 2,950 psi, 8,942 TOF. 19:30 - 21 :00 1.50 DRILL P TIEB1 CBU at 7 bpm with 2,950 psi. Pumped Additional 90 bbls to Circulate Gas Out. 21 :00 - 00:00 3.00 DRILL P TIEB1 POOH From 8,942' to 1,769'. 6/3/2006 00:00 - 01 :00 1.00 DRILL P TIEB1 POOH w/4" Drill Pipe. Filling Well with Double Metal Displacement. 01 :00 - 02:00 1.00 DRILL P TIEB1 Stand Back Drill Collars, UD Reverse Circulating Junk Basket BHA. Several pieces of Rubber in Junk Basket, 2-3" Long 1" Wide. 02:00 - 03:00 1.00 DRILL P TIEB1 MIU Outside Cutter Assembly, BHA Consists of Shoe, Outside Cutter, 1Joint of Washpipe, Boot Basket, XO, 9 Drill Collars, XO. BHA = 323.8' 03:00 - 04:00 1.00 DRILL P TIEB1 RIH w/4:' DP to 2,245'. 04:00 - 05:30 1.50 DRILL P TIEB1 Cut and Slip 94' Drilling Line. 05:30 - 07:00 1.50 DRILL P TIEB1 Continue to RIH to 8,942. 07:00 - 07:30 0.50 DRILL P TIEB1 Obtain Parameters: Up Weight=185,000#, Down Weight=148,000#, Rotating Weight=165,000#, 40 rpm, 5,000 ft-Ibs Torque. 07:30 - 08:30 1.00 FISH P RUNCMP Tag Tubing at 8,943', Began Cutting Operation at 8,954', Pumping at 2 bpm, With 0 psi, 30 rpm, 7,500 ft-Ibs Torque Maximum, Neutral WOB. 08:30 - 16:00 7.50 FISH P RUNCMP BID TID, POOH fl 8,954' Laying Down Drill Pipe. Filling Well with Double Metal Displacement. 16:00 - 17:30 1.50 FISH P RUNCMP UD Drill Collars and Outside Cutter Assembly, Retrived Fish with Tubing Plug. 17:30 - 18:00 0.50 FISH P RUNCMP Clear and Clean Rig Floor. Filling Well with 60 bph While out of Hole. Printed: 6/12/2006 9:40:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-09 D-09 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/23/2006 Rig Release: 6/5/2006 Rig Number: Spud Date: 11/14/1979 End: Service Rig. Pull Wear Ring. Rig Up to Run 4.5' Completion. P/U and Run Completion: 4.5",12.6#, 13Cr80 Vam Top Tubing. Using Jet Lube Seal Guard Pipe Dope. Average M/U Torque 4,400 ft/lbs. Torque Turning Connections Using Compensator. 6/4/2006 00:00 - 09:00 RUNCMP PIU and Run Completion: 4.5",12.6#, 13Cr80 Vam Top Tubing. Using Jet Lube Seal Guard Pipe Dope. Average M/U Torque 4,400 ft/lbs. Torque Turning Connections Using Compensator. Filling Hole wI 60 bph. 09:00 - 09:30 0.50 RUNCMP RlU Circulating Head On Joint # 208. 09:30 - 10:00 0.50 RUNCMP Parameters Up Weight=140,OOO#, Down Weight= 120,000#. Wash Down to TBG Stump At 8,960" Wash to 8,968 at No-GO Twice. Pumping at 3 bpm with 100 psi. Indicator Shear Pins at 4,000 # 10:00 - 10:30 0.50 RUNCMP RID Circulating Equipment, UD Jt # 208. 10:30 - 11 :30 1.00 RUNCMP PI U Landing jt, RlU Circulating Head, M/U Hanger, Land Tubing, RILDS. 11 :30 - 12:00 0.50 RUNCMP RlU To Circulate. 12:00 - 16:30 4.50 RUNCMP Pumped 290 bbls 140 deg, 2 % KCL Followed By 450 bbls of 2% KCL wlCorrosion Inhibitor at 3 bpm and 60 psi. 16:30 - 18:30 2.00 RUNCMP RID Circulating Equipment, Drop Ball and Rod Pressure up to 2,500 psi Set Packer. Pressure up To 3,500 psi Test Tubing On Chart For 30 minutes. Bled TBG Pressure to 2,000 psi, Pressured Up On Casing Annulus to 3,500 psi on Chart For 30 Minutes. Bled Off TBG Pressure and Sheared OCR Valve, Circulated Both Ways Though OCR Valve to Confirm Communication. Set Two Way Check. 18:30 - 19:00 0.50 RUNCO RUNCMP RID and BID Lines and UD Landing Joint. 19:00 - 20:00 1.00 RUNCO RUNCMP NID BOP Equipment. 20:00 - 22:00 2.00 RUNCO RUNCMP Prepare Hanger Nipple Up Adapter Flange And Test to 5,000 psi for 30 minutes. 22:00 - 23:30 1.50 RUNCO RUNCMP N/U Tree and Test II 5,000 psi for 30 minutes. 23:30 - 00:00 0.50 RUNCO RUNCMP RlU Drill Site Maintenance to Pull TWC, NID DSM. 6/5/2006 00:00 - 01 :30 1.50 RUNCO RUNCMP PJSM with Little Red, Rig Crew On Pumping Freeze Protection. Pressure Test Lines to 1,000 psi. Pumped 140 bbls of Diesel Down II A. 01 :30 - 02:30 1.00 RUNCO RUNCMP RlU and U-Tubed Freeze Protection. 02:30 - 03:30 1.00 RUNCO RUNCMP BID RID Manifold and Lines. Set BPV Tested to 1,000 psi wI Little Red. Test OK, RID Little Red. 03:30 - 04:00 0.50 RUNCO RUNCMP Secured Well Prep for Move. 04:00 - 0.00 RUNCO RUNCMP Rig Released 04:00. Printed: 6/12/2006 9:40:27 AM RECE\VEO 06/01/06 Schlumberger JUN 0 8 7.006 NO. 3828 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth \~ C1I.31 Gas Cc!ìS. ccmmiiSiOO A~e '~, ;~" Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 5 Field: Prudhoe Bay t q <1'" 0 g WII J b# L D D t BL CI CD e 0 og escrrptlon ae o or >2-22 I "Y?· - (j"-A 11136744 GLS 11/13/05 1 P2-16 I~~ - I;::¡'~ 11058238 wFL 08/18/05 1 P2-36 j Cj.? - 1(,,[' N/A LDL 07/13/05 1 P2·50B i (..7,-'\- - n.q(~ N/A LDL 07/16/05 1 16-03 1~I-Cìl 11076454 INJECTION PROFILE 07/28/05 1 P2-36 ¡ C¡ 1- - /("b 11051061 GLS/LDL 06/15/05 1 4-18/5-30 ¡-9¡'Í<;"-liè, 10564459 PSP GLS 04/18/03 1 1·33B/L-24 I q '?r - ,;)5:) 10889175 SCMT 10/12/04 1 04-41A ICi'1- - Òç-<)" N/A LDL 07/18/05 1 15-09A j C, -3 - L~~ N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09·17 t -:r~ -r-;~:z,'i< 11076460 INJECTION PROFILE 08/18/05 1 16-09A 1'1/ - (')~~ 11051089 PRODUCTION LOG WIDEFT 08/18/05 1 16-11 j -<i<.-' - II '7( 11058249 LDL 09/14/05 1 17-02 I~{) - Oro N/A SENSA MEMORY LDL 10/17/05 1 NK-38A .o(~4 -::::)"-1/ 10687734 MDT 02/27/05 1 R-35 ¡ Co¡ 'z- I fî I 11212863 USIT OS/26/06 1 D-09A I o,~ - í~<:"- 11221576 USIT OS/27/06 1 L5-16 ¡"X '1- - n 10, 11212864 USIT OS/28/06 1 K-08A ") .....>~.. ¡'-II) 11054182 MCNL ~ ì~ <.¡C¡;l 06/06/05 1 1 H-04A .)(....-=\ -If, I 10715365 MCNL # I?'i <'/C? ~ 11/27/03 1 1 e e Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 í1 /~; 1// ! i r~ f f ¡¡ i I G. /./ j / ! . 1 1/ ~ V\.// Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth e e FRANK H. MURKOWSKI, GOVERNOR A.,ASIiA. OILAlft) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 CfJ5 \~q-o Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-09A Sundry Number: 306-172 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisl1aay of May, 2006 Enc!. ~\~\p(1 ~ 5-n-Ð(¡ ft¿ sJ;~ .'~ STATE OF ALASKA .-v- I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~" 20 AAC 25.280 :ìr;:frlt~oG. ~f ~:'f >,,,,~....,,,,,di 1. Type of Request: 0 Abandon IBI Repair Well o Plug Perforations o Stimulate o Other o Alter Casing IBI Pull Tubing o Perforate New Pool o Waiver o Re-Enter Suspended W o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Befo~ork: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development 0 Exploratory 199-085 ,.-/ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20381-01-00 ./ 7. KB Elevation (ft): 72.21' 9. Well Name and Number: PBU D-09A /' 8. Property Designation: 10. Field / Pool(s): ADL 028286 Prudhoe Bay Field / Prudhoe Bay Pool t'<cL;''',,; '; ;;;' .'tx/ii;,;t;'t;"i " ,cL, i,<,,;t;,!;;;""""""'" !, Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 11591 9055 11524 / 9026 None None Casinc¡ Lenc¡th Size MD / TVD Burst COllapse Struch I r::¡ I Conductor 110' 20" x 30" 110' 110' Surface 2680' 13-3/8" 2680' 2680' 4930 2670 Intermediate 9608' 9-5/8" 9608' 8426' 6870 4760 Prodlldion Liner 739' 7" 9107' - 9846' 8016' - 8621' 8160 7020 Liner 2479' 2-7/8" 9112' - 11591' 8020' - 9055' 13450 13890 Perforation Depth MD (, I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11430' - 11480' 8993' - 9010' 4-1/2", 12.6# ../ L-80 9139' Packers and SSSV Type: 9-5/8" x 4-1/2" Otis Perm Packer I Packers and SSSV MD (ft): 9013' / 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal 0 BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 14. Estimated Date for /\ 15. Well Status after proposed work: Commencing Operations: Ma(25, ~06 181 Oil o Gas o Plugged o Abandoned 16. Verbal Approval: ~ o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer ~~~- Prepared By Name/Number: Sianature Phone 564-4303 Date S/II / (Jt. Terrie Hubble, 564-4628 t7 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:(~( 0 ~ 11 & o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: \ e,£, t- ßOP6 f-o 3Çoo y?U. Subsequent Form Required: 1" - rJ A..'ØfcOMMISSIONER RBDMS 8Fl MAY 1 8 2006 APPROVED BY Ó'" /1- ... () 6 Approved By: THE COMMISSION Date Form 10-403 Revised 07/2005 oRfGfN) '" l Submit In Duplicate AL e e Obp GL~JIiT D-09A Rig Workover Scope of Work: Pull 4-W' completion, replace 9-5/8" casing above TOC, run 4-Yz" 13Cr80 stacker packer completion. MASP: 2370 psi Well Type: Producer Estimated Start Date: May 25, 2006 Pre-ri 0 1 S 2 E 3 F 4 0 5 0 6 re work: Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time. PPPOT-T & IC. Drift 4-W' tubin for FasDrill and Power 'et cut down to the 4-Yz" WLEG. Set 4-W' HES FasDrill at 8945' MD, 5' above the bottom of the 2" full joint above the packer. Power 'et tubin at 8940' MD. Reference tubin tall dated 09/24/91. Circulate well with seawater and diesel thru the cut. CMIT TxlA to 3500 psi (note, this step can also be done in ste #2. Set a BPV in the tubin han er. Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circula¥ well to clean seawater through the cut. é 2. Pull and LD 4-1/2" tubing string to the cut. / 3. Determine top of cement in the 9-5/8" x 13-3/8" annulus with cement bond log. 4. Cut and pull 9-5/8" casing above TOC. 5. Tie back 9-5/8" casing with ES cementer. 6. Cement 9-5/8" x 13-3/8" annulus to surface. / 7. Run 4-1/2" 13Cr80 stacker packer completion. Position packer at -8900' MD. / 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. / 10. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = . WB...LHEAD = ACTUA TOR = KB. B...EV = BF. B...EV = KOP= Max Angle = Datum MD = DatumTVD= 4" CrN MCEVOY BAKER 72.21' 47.73' 3300' 86 @ 10940' 10787' 8800'SS 113-3/8" CSG, 72#, L-80, ID = 12.347" e D-09A Minimum ID = 3.80" @ 9127' 4-1/2" PKR SWN NIPPLE ITOPOF?" LNRTIE-BACKSLV I TOPOF2-7/8"LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" , 9107' 9112' 9139' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 9608' IBKR RETRIEVABLE WHIPSTOCK I 9842' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ÆRFORA TION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/19/99 ANGLEAT TOP ÆRF: 71 @ 11430' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 11430 - 11480 0 09/25/99 DATE 12/12/79 09/01/99 09/04/03 09/17/03 09/09/04 10/28/04 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (D-09A) KC/TLH WAIVER SAFE1Y NOTE CMOITLP ÆRF ANGLE, LOCATION WRRlTL GL V C/O WRRlTLP GL V C/O DATE 08/04/05 09/24/05 05/02/06 05/03/06 . ~NOTES: 70o@10052' 2128' -14-1/2" CAM SSSV NIP, ID = 3.813" I 2614' -19-5/8" DV PKRI GAS LIFT MANDRELS ST MD TVD DEV 1YPE VLV LATCH 5 2987 2914 5 MERLA DMY RM 4 5102 4809 35 MERLA DMY RM 3 7019 6297 41 MERLA DMY RA 2 8230 7239 38 MERLA DMY RM 1 8575 7513 36 MERLA DMY RA FORT DATE o 08/04/05 o 08/04/05 o o 09/09/04 o 9000' -14-1/2" PKR SWS NIP, ID = 3.813" I 9011' 9013' H RT HAND RB...EASE SAP LA TCH I -19-5/8" X 4-1/2" OTIS PERM PKR, ID = 3.85" -14-1/2"PKRSWSNIP,ID=3.813" , -?" BOT LNR HGR , -1 DEPLOYMENT SUB 9127' -14-1/2" PKR SWN NIP, ID = 3.80" (BEHIND PIPE) -14-1/2" WLEG, ID = 3.854" (BEHIND PIPE) HB...MDTILOGGED10/06/91 I 9139' 9124' 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I REV BY COMMENTS DA V /PJC GL V C/O MORlTLH PX TIP SET (08/09/05) JLJ/PJC PULL TIP @ 9000" COIINPJC WAIVER SFTY NOTE DB...ETED PRUDHOE BA Y UNIT WB...L: D-09A PERMIT No: 1990850 API No: 50-029-20381-01 SEC 23, T11 N, R13E, 2020' NSL & 1067' WB... BP Exploration (Alaska) 4" CrN MCEVOY BAKER 72.21' 47.73' 3300' 86 @ 10940' 10787' 8800' SS HES ES CEMENTER 113-3/8" CSG, 72#, L-80, ID = 12.347" 1 TREE = WELLHEAD = ACTUATOR = KB. ELEV - BF. ELEV - KOP= Max Angle = Datum MD = Datum1VD= D-O~ Proposed Compltion -2100 -14-1/2" HESXNIP, ID=3.813" 2614' -19-5/8" DV PKRI GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE 5 4 3 2 1 TOPOF7" LNRTIE-BACKSLV I 1 TOP OF 2-7/8" LNR 1 -8900 1-14-1/2" HES X NIP, ID = 3.813" -19-5/8" X 4-1/2" BAKER S-3 PKR, ID =" -14-1/2" HES X NIP, ID = 3.813" -1 UNIQUE MACHINE OVERSHOT -14-1/2"PKRSWSNIP, ID=3.813" I H RT HAND RELEASE SAP LA TCH 1 -i 9-5/8" X 4-1/2" OTIS PERM PKR. ID = 3.85" -i4-1/2" PKRSWS NIP, ID = 3.813" 1 -i 7" BOT LNR HGR I -i DEA...OY MENT SUB 9000' 9011' 9013' 9107' 9112' 9127' -14-1/2" PKR SWN NIP, ID = 3.80" (BEHIND PIPE) -4-1/2" WLEG, ID - 3.854" (BEHIND PIPE) H ELMD TT LOGGED 10/06/91 I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9139' 9139' 9124' 19-518" CSG, 47#, L-80, ID = 8.681" I 9608' I BKR RETRIEVABLE WHIPSTOCK I 9842' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I PERFORA TION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/19/99 ANGLE AT TOP PERF: 71 @ 11430' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 11430 - 11480 C 09/25/99 DATE 12/12/79 09/01/99 03/03/02 09/04/03 09/17/03 09/09/04 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (D-09A) RNlTP CORRECTIONS KClTLH WAIVER SAFETY NOTE CMOITLP PERF ANGLE, LOCATION WRRlTL GL V C/O DATE 10/28/04 08/04/05 09/24/05 REV BY COMMENTS WRRITL GL V C/O DAV/PJC GLV C/O MORlTLH PX TIP SET (08/09/05) PRUDHOE BAY UNIT WELL: D-09A PERMIT No: 1"1990850 API No: 50-029-20381-01 SEC 23, T11 N, R13E, 2020' NSL & 1067' WEL BP Exploration (Alaska) D-09A (PTD #1990850) Classified as Problem Well ) ) Subject: D-09A (PTD #1990850) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 31 Ju12005 18:15:41 -0800 T~: "Younger, Robert 0" <Younger2@BP.com>, "GPB,GCl AreaMgr" <GPBGClTL@BP.com>, "GPB, GCl Wellpad Lead" <GPBGCl WellpadLead@BP.com>,"Rossberg, R Steven" <RossbeRS@BP.com>, "N8U, ADW Well Operations Supervisor" _ <NSUADWWellOpe~ationsSupervisor@BP.com>,"GPB, Wells Opt Eng" _ _ _ _ __ , _ <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (F>mailY' <jim_regg@adniin~state.ak~us>, "AOGCC Winton Aubert (E-mail)..><winton_aubert@admin.state.ak.us>. "NSU,ADW-WL & ' Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>,· "GPB, ~W ell 'Pads DFG" <GPBWellPadsDFG@BP.com>, "NSU, ADWWell IntegrityEngin~er'" <NSUADWVV~l1IntegrityEngil1eêr@BP.~om> ,"',", ," " -. ,"',' .', , : cc: "NSU, ADW Well Integrity :Engineer" - <NSUADWW ellIntegrit~'Engine~@BP.com>, tlH1.Ígl1es, Aridrea (VECO)" <hugha4@BP . com> All, Well D-09A (prD #1990850) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 07/25/05 were 1100/2150/175. The well is currently waivered for IAxOA communication and failed a TIFL on 7/26/05. Ix:rA The plan forward for this well is as follows: 1. SL: Run DGL V's ¡// 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «D-09A. pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-51 02 907 -659-5100 #1923 pgr SCANNED AUG 0 B 200~ï Content-Description: D-09A.pdf D-09A.pdf Content-Type: application/octet-stream Content-Encoding: base64 ~çsv~_ Jvçr^"( P ¿o tJ.:ü¡ p ....-::- - ( p\lL¡-l^~~ ~ { (,L~I\ ~ lloo P :"1 ~fl~15 ]A 21~O ps; (, c£510p-s', "3L 3(1¿o p~'<;SV\}L s C0 Iv\. al~eç "- CO LIe¡ L O.t\ (,V\ \ 75 fS ~ S"3bOf?; 3 -,v~ J'K'~î ~2(OÇ .:::> L> N~: ZðOOp";, 1W\.~l CBP) 1 of 1 tAkll ~ V teS6 w"e- W!(Á.,QJ be.- '37 CZo of /v'J<-t? 8/2/2005 1 :43 PM TREE = WELLHEAD ::= ACTUATOR == KB. REV = BF."Bj~V'''~< . KOP= Max Angle = 'Öatun1MO = ÖaiUmTV b; 4"CIW MCEVOY BAKER 72.21' 47.73' " T"';" , ,I', -~ T\ ,!T )I, ;'11111 i~;1I11!11T 3300' 86 @ 10940' . ..............."............. 1 0787' 8800'SS ) D-09A .k NOTES: ***IAxOA COMM. OPERATING LIMITS: MAX lAP:::: 2000 PSI, MAX OAP :::: 2000 PSI (08/30/03 WAIVER)*** 70° @ 10052' - 2128' 1---14-1/2" CAM SSSV NIP, 10 = 3,813" 1 2614' 1---1 9~5/8" DV ~R I 113-3/8" CSG, 72#, L~80, ID = 12,347" 1-1 2680' ~ ~ GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH 5 2987 2914 5 MERLA DOME RM 4 5102 4809 35 MERLA SIO RM 3 7019 6297 41 MERLA DMY RA 2 8230 7239 38 MERLA DMY RM 1 8575 7513 36 MERLA DMY RA PORT DATE 16 10/28/04 20 10/28/04 L 09/09/04 Minimum ID = 3.80" @ 912T 4..1/211 PKR SWN NIPPLE I . I I Z I I I L--¡ 9000' 9011' 9013' 9106' 9117' 9112' 1---14-1/2" PKR SWS NIP, ID = 3.813" 1 1---1 RT HAND RELEASE SAP LA TCH 1 1-I9~5/8" X 4~ 1 /2" OTIS PERM PKR, ID :: 3.85" J---14-1/2" PKR ~WS NIP, ID ~ 3.813".1 1---17" B<?T LNR HGRI 1---1 DEPLOYMENT SUB Z I ITOP OF 7" LNR TIE-BACK SLV 1---1 9101' I l TOP OF 2- 7/8" LNR I-i. 9112'. . I . j I I . I 9127' 1---14-1/2" PKR SWN NIP, ID = 3.80" 9139' 1-14-1/2" WLEG, ID:: 3.854" 1 9124' l-f ELMO n' LOGGED 10/06/91 [4-1/2" TBG, 12.6#, L-BO, .0152 bpf, ID:: 3,958" 1---1 9139' 19-5/8" CSG, 47#, L-BO, ID:: 8.681" 1-1 9608' ~ 1 BKR RErRlEV ABLE WHIPSTOCK 1-1 9842' I I.. PERFORA TION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/19/99 ANGLEATTOPÆRF: 71 @ 11430' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11430 - 11480 0 09/25/99 9852' 1-1 RA TA G 1 I 7" LNR, 29#, L-80, ,0371 bpf, 10 = 6.184" 1-1 [ PBTD 1-1 11524' 12-7/8" LNR. 6.16#. L-80, ,0058 bpf, 10 = 2.441" 1-1 11591' I DATE 12/12/79 09/01/99 03/03/02 09/04/03 09/17/03 09/09/04 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (D-09A) RNlTP CORRECTIONS KClTLH WANER SAFETY NOTE CMOfTLP PERF ANGLE, LOCATION WRRlTLP GL V C/O OA TE REV BY COMMENTS 10/28/04 WRR/TLP GL V CiO PRUDHOE BA Y UNIT WB..L: D-09A PERMIT No: 1990850 API No: 50-029-20381-01 SEC 23, T11 N, R13E. 2020' NSL & 1067' WEL BP Exploration (Alaska) Problem Well Notification: D-09A (PTD #1990850) ') Subject: Problem Well Notification: D-09A (PTD #199085-0) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 29 Aug 2004 14:56:56 -0800 ,. To:: "Ingalls, l)aveC'~ <IngaI1DC@BP.éom>,."GPB, WellPadsDFG" . . . , .'. <qPBW el[padsDFG@BP ~COrh>, .nGP~~ Fld ,TL" <GPBFldTL@BP.com>,'''GPB',Wells Opt, Engff.' <CìPBWellsOptEng@BP~coJ;l1>, "Rossber&, R Steven!' <Ros$beRS@BP.com>, ~'NSU~ ADWW ell Operations Supervisor" <NSUADWWellOpÿrationsSupen1sor@B¡>.com>;"AOGCC Jim Regg" (E~inail)n'<jim~~êgg@adIDill¡state~åk:iis>~ ;tAOGCC'Wmt{)n"Au~ert '(E~mail)". .." '...' ::.: ~.:......., ::;.:, . <winton_aubert@ådmin~state.ak.us>,'':NSU,.ADW:WL.&Completíon-SuperVisor":, : .", ::. '., '.' <N~UADWWL&CompletiQnSupervis()r@I3P ~com>,:"Yotiriger,':Robert ~",<Yoiu1ger2@B~P~~om>,. . , "G;PB, Ops JY1gr". <GPBOpsMgr@BP.coD.1>, "GPB,:.Opti~ization :Engr".: :-.' . . : ,,'.. . ,:. , . .;. ;,"" , <QPBOptimizat1onEngr@BP.cqm>, "GPB,:Fld Ops Lead" ,<GPJ3FldopsLead@BP.èom~:;' ,. " ',: , . Cç,: nNSU:, .ADWW~ll Iiitegnt)' Engineer'~ <::NS1JADWWelllntegrityEngìneër@BP~com>;:~'OIsen, " Cl~k An <OlsenÇA@BP.~öh1~,"MiéIke, Robert L~"':<röb~rt'ri1ieß(e@I3P.c~ni>:.' " '., '. '.' " All, Well D-09A (PTD #1990850) has sustained casing pressure on the IA and the well has been classified as a Problem well. The TIO's on 08/27/04 were 1900/1920/180. The plan forward for this well is as follows: Obj: Fix TxIA Comm 1. DHD: TIFL - FAILED 2. SL: DGLV's stations 5, 4, 2, Caliper 3. DHD: ReTIFL 4. SL: If ReTIFL fails set TTP Attached is a wellbore schematic. Please call if you have any questions. «D-09A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: D-09A.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NO\} () 2 '2004 1 of 1 9/22/2004 1 :07 PM ) 4"CMI tvCEVOY """"'BÄ"kËk 72.21; 47.7~ 33ÕÕi" . , ~...~...~.g940' 10787' 8800' SS TREE = WElLHEAD = KCfUA;foR";'" KB. ELEV ;-- SF.ElEV =' KOF>= .. .... .NI~. ~ng~= Datum MD = OatumTVO = D-09A fit - - 113-318" CSG, 72#, L-80, 10 = 12.347" 1-1 2680' ~ L Minimum ID = 3.80" @ 9127' 4-1/2" PKR SWN NIPPLE I I 1 I I L--¡ :g :& I ITOPOF7" LNRTIE-BACKSLV H 9107' ITOP OF 2-7/8" LNR l-i 9112' ~ 14-1/2"TBG, 12.6#, L-80,.0152bpf,10=3.958" H 9139' , I 19-518" CSG, 47#, L-80, 10= 8.681" H 9608' ... 9842' I-1BKR REfRlEVABLEWHIPSTOCK 1 17' LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 PERFORATION SUIVMARY REF LOG: PDS MEMORY INIJJCTION ON 09/19/99 ANGLE AT TOP ÆRF: 71 @ 11430' Note: Refer to Production DB for historcal perf data SIZ E SPF IN1£RV A L OpnlSqz [)6. TE 2" 4 11430-11480 0 09/25/99 ) SAFETY NOTES: ***IAxOA COMM. 0 PERAT1NG LIMITS: MAX lAP = 2000 PSI, MAX OAP = 2000 PSI (08/30/03 WAIVER)*** 70° @ 10052' 2128' 1-I4-1/2"CAM SSSV NIP, D =3.813" 1 2614' 1-19-5/8" OV PKR 1 ~ GAS LIFT MANDRELS ST MO lV 0 OBI TYPE VL V LATCH 5 2987 2914 5 MERLA RA 4 5102 4809 35 MERLA RA 3 7019 6297 41 MERLA RA 2 8230 7239 38 MERLA RA 1 8575 7513 36 MERLA RA FORf DATE 9000' 9011' 1--14-1/2" PKR SWS NIp, 10= 3.813" 1 1-1 RT HAND RElEASE SAP LATCH 1 1-19-5/8" X 4-1/2" OTIS PERM PKR, 10 = 3.85" 1 9013' 9106' 1-14-1/2"PKRSWSNIP,10=3.813" 1 911T H7"BOT LNRHGRI 911 X 1-1 OEPLOYrvENT SUB 1 912T 9139' 1-14-1/2" PKR SWN NIp, 10= 3.80" I 1-14-1/2"WLEG, ID= 3.854" I 1-1 ELMO IT LOGGED 10/06/91 1 9124' .. 9852' H RA TAG I I PBTO H 11524' 12-7/8"LNR,6.16#,L-80,.OO58bPf,ID=2.441" H 11591' 1 [)6. TE RBI BY OOIVMENTS 12/12/79 ORIGINAL COMPLETION 09101/99 SIDETRACK (D-09A) 03103/02 RWTP CORRECTIONS 09/04/03 KOTLH WANER SA.FEfY NOTE 09/17/03 CMOfTLP PERF ANGLE, LOC'A 1l0N [)6. 1£ REV BY COMrvENTS PRLDI-OE BA Y UNIT VVELL: D-09A PERMrr No: 1990850 AA No: 50-029-20381-01 SEC 23, T11N, R13E, 2020' NSL & 1067' WEl BP Exploration (Alaska) 199-085-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 11591 ~'TvD 09054 ,-Completion Date: D-09A 50- 029-20381-01 Start Stop L9/~1/99' Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: T Name Interval D 9332~'~'~' FINAL PDS IL D 9519 ~'- 1-10 SPERRY GR L IL ~ FINAL 9625-11580 L NGP-MD ~ FINAL 9827-11591 L NGP-TVD ~ FINAL 8548-8982 R SRVYLSTNG ~ BHI 9800-11591. R SRVYRPT (--'/'"/ SPERRY 9800-11591. OH 9/23/99 9/23/99 OH 3/23/00 3/28/00 OH 9/23/99 9/23/99 OH 2/5 3/28/00 3/28/00 OH 2/5 3/28/00 3/28/00 OH 10/22/99 10/22/99 OH 10/22/99 10/22/99 Sent Received T/C/D Wednesday, June 20, 2001 Page 1 of 1 STATE OF ALASKA ALASK~-dlL AND GAS CONSERVATION C't.~MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Acid 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3260' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 884' SNL, 1519' EWL, SEC. 25, T11N, R13E, UM At effective depth (n/a) At total depth 140' SNL, 1507' EWL, SEC. 25, T11N, R13E, UM 12. Present well condition summary Total depth: measured 11591 feet true vertical 9054 feet Effective depth: measured 11524 feet true vertical 9026 feet 5. Type ~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 72.21' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-09A 9. Permit Number / Approval No. 199-085 10. APl Number 50- 029-20381-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) Junk (measured) KOP (window) @ 9846' - 9853'. 7" abandoned from 9846' to 10674'. Casing Length Size Structural Conductor 110" 20"x 30" Surface 2656' 13-3/8" Intermediate 9584' 9-5/8" Production Liner 739' 7" Sidetrack Liner 2479 2-7/8" Cemented MD TVD 126 c.f. Arcticset Concrete 4325 c.f. Permafrost 1346 c.f. Class 'G', 130 cu ft PF 450 c.f. Class 'G' 112 c.f. Class 'G' 134' 134' 2680' 2680' 9608' 8426' 9107'-9846' 8016'-8621' 9112'-11591' 8020'-9055' Perforation depth: measured Open Perfs 11430' - 11480' true vertical Open Perfs 8993'- 9010' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, Lo80 tubing to 9013' with 4-1/2" tailpipe to 9139'. Packers and SSSV (type and measured depth) 9-5/8" Otis Perm. Packer (MHR) @ 9013'. 4-1/2" Camco SSSVLN @ 2128'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedScott LaVoie ~' Title TechnicalAssistant Date Prepared By Name/Number: DeWayne Sch" nort/564-5174 Form 10-404 Rev. 06/15/88 UR } r'"' i Submit In Duplicate"~ D-09A ..... DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/06/2001 03/07/2001 03/08/2001 04/15/2001 ACID: DRIFT (PRE ACID STIM) ACID: ACID PERF WASH ACID: ACID WASH PERFS ACID: SCALE INHIBITOR TREAT SUMMARY 03/06/01 DRIFTED W/2.12" CENTRALIZER TO 9800' WLM (STOPPED TO AVOID GOING OUT SIDETRACK WINDOW). RDMO. RETURNED WELL TO PRODUCTION. NOTIFIED OPER OF WELL STATUS. 03/07/01 WEEKLY BOP TEST. RIH. 03/08/01 RIH TO 11480'. ATTEMPT TO JET DEEPER. HARD BOTTOM. JET PERFS WITH 60 BBLS 12% DAD ACID. PRE-ACID INJECTIVlTY- 1 B/M WITH WHP-137 CTP-1306. NO BREAK DOWN SEEN DURING JETTING. POST ACID INJECTIVITY: 1.6 B/M WHP-164 CTP-1338. POH. RDMO. WELL TURNED OVER FOR POP. 04/15/01 PUMPED L47 SCALE INHIBITOR TREATMENT PER PROCEDURE. AVG TREATING PRESS= 1000 PSI. LEFT WELL SHUT IN FOR 24 HR SOAK. SWAPPED TBG TO CRUDE TO TT. Fluids Pumped BBLS. Description 1 DIESEL 25 MEOH 53 60/40 METHANOL 400 2% KCL WATER 60 ACID (12% HCL + 10% XYLENE) 539 TOTAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~_- Commissioner Tom Maunder, P. I. Supervisor ~,(>~"~ ~'' DATE: April 20, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday, April 20, 200.,! ;i I traveled to BPXs D Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on well D-06 had a slow leak when pressure tested. This valve was serviced and the retest witnessed on this date. Merv Liddlow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in fair conditions. Su..mmary: I witnessed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20 wells, 40 components, -1 failure 2.5% failure rate 25 wellhouse inspections Attachment: SVS PBU D Pad 4-20-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4/20 HPS 660 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Tdp Code Code Code Passed GAS or CYCLe D-01A 1970780 154 " 125 125 P P ' OIL , , D-03A 2001340 154 125 125 e e OIL b-04^ 1871250 ' D-05 1700060 660 550 450 P ' e '0IL , D-06A 1970430 660 5501 600 P 4 OIL , D-07A 1931570 660 550: 525 P P 4/20/01 OIL D-08 1790360 D-09A 1990850 660 550 525 P P OIL D-10 1790530 660 5501 525 P e ' OIL ,, D-11A 1951830 660 5501 525 P P OIL :b-12 1800150 660 550 530 P P oIL 'D-13A 2000810 D-14A i961530' ' ' i~-15A 1972120 ' b-16 1811710 660 550 '500 P P OIL ..... D-17A 1960460 n , D-18 1811880 D-20 18204401 154 125 120 P P OIL :D-21 1820520! 154 1251 125 P P oiL . D-22A 1972040 D-23A 1961880 660 550 525 P P oIL , D-24 1852990' , D-25A 2000240 154 125 100 P P OIL D-26A 1970870! 660 550 525 P P OIL D-27 1860330 660 550i 550 P P oIL D-28A 1952130! 660 550 550 P P OIL , D-29 1852530 154 125 110 P P OIL ,, D-30 1960260 D-~iA 1960950! 660 550 550 P P OIL D-33 1960360' 660 550! 550 P P OIL ,, ,, RJF 1/16/01 Page 1 of 2 SVS PBU D Pad 4-20-01 CS Well [ Permit [ Separ ] Set I L/~ ] Te~t ]Test I T~t ! Date [Oil, wAG, GINJ, Number I Number I PSI I PS! I Trip ! Code I Code I Code ! Passed I GASorCVCLE Wells: 20 Components: ..... ,40, Failures: __ .. 1 Failure Rate: 2.§0% Ufo0 Day Remarks: The surface, safety valve on well D-6 had slow leak when pressure tested. Valve was ~rv~,ced ,and ret, ested, same day, ...... ,1 , i I I I Il . .I I I 1, I I I ~ I .[ .. I I I I I I I I I I _ RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS DRILLING C;ERL/ICE~=; To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' March 28, 2000 D-09A, AK-MW-90154 D-09A: 2"x 5"MD Gamma Ray Logs' 50-029-20381-01 2" x 5" TVD Gamma Ray Logs' 50-029-20381-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TltE TRANSMITTAL LETTER TO TltE ATTENTION OF: Sperry-Sun Drilling Services Attn: Yum Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED mtn:28 Alaska 0il & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company nRILL. I EIB c=;ER~./ICE~=; WELL LOG TRANSMITTAL To: State of Alaska March 23, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs D-09A, AK-MW-90154 1 LDWG formatted Disc with verification listing. API#: 50-029-20381-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 R£CEIVrr. D Date: Mtt~} o Alaska Oil a Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [-] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 99-085 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ..............~_: ....... ...-;.~ , 50-029-20381-01 4. Location of well at surface ~ ..... ~";'-"'~: ..... ~- 9. Unit or Lease Name 3260'SNL, 1067'WEL, SEC. 23, T11N, R13E, UM !}..~.~ ~i~, ~~, Prudhoe Bay Unit At top of productive interval .............. ~-' ~ 10. Well Number 884' SNL,At total depth1519' EWE, SEC. 25, T11N, R13E, U M i~ ~].~.: }.... ~'_~'~.~~'~.~ii~7~ '.[ D-09A '~'"--~-"'~'-- ........... "~ f 11. Field and Pool 140' SNL, 1507' EWL, SEC. 25, T11 N, R13E, UM~! Prudhoe Bay Field/Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 72.21' AMSLI ADL 028286 12. Date Spudded9/12/99 113' Date T' D' Roached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °f c°mploti°ns9/10/99 9/21/99 N/A MSLI One 17. Total Depth (MD+TVD)[18. Plug Back Depth (MD+TVD)[19. Directional Survey 120. Depth where SSSV set [21. Thickness of Permafrost 11591 9054 FTI 11524 9026 FTI [] Yes [] No (Nipple) 2128' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ReP Memory Induction, Memory CNL 23. CASING~ LINER AND CEMENTING RECORD CASING S E'I-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE ToP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20"x 30" Insulated Conductor Surface 110' 36" 14 cu yds Arcticset Concrete 13-3/8" 72# L-80 Surface 2680' 17-1/2" 4325 cuft Permafrost 9-5/8" 47# L-80 Surface 9608' 12-1/4" 1346 cu ft Class 'G', 130 cu fi Permafrost 7" 29# L-80 9107' 9846' 8-1/2" 450 cu fi Class 'G' 2-7/8" 6.16# L-80 9112' 11591' 3-3/4" 1112 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9139' 9013' MD TVD MD TVD 11430' - 11480' 8993' - 9010' :26. ACID, FRACTURE, CEMENT SQUEEZE, Erc. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with MeOH 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) September 26, 1999 ! Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Casing Pressure =CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE) Tubing iD 24-HOUR I~.SS. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED .... ORIGINAL Alas~ 0il & Gas Co~, Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. ' ' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Zone 3 10444' 8808' Zone 2C 10803' 8876' 25N 11312' 8956' 24N 11389' 8980' 22N 11510' 9021' HOT 11575' 9046' ~31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble "~,~), ~ Title Technical Assistant III Date D-09A 99-085 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: D-09A Accept: 09/12/99 Field: Prudhoe Bay Spud: 09/12/99 APl: 50-029-20381-01 Release: 09/21/99 Permit: 99-085 CTD Unit: Nordic #1 09/11/99 1 Finish RU after derrick down move from B-13ai. Remove tree cap. Spot DS/N #1 over tree. Accept for operation at 1200 hrs 9/10/99. NU BOPE. Spot green tank. RU hardline. Test BOPE. Install Baker CTC. Fill CT with SW and pump wiper dart. Open well, WHP-350 psi. Pump 1.5 tubing volumes to kill well. Well went on vacuum. PU Cement BHA, TIH. Tag up on whipstock, correct depth (-23'). Attempt to fill hole down backside, could not fill hole. Pump 33 bbl cement (5 bbl neat, 20 bbl w/15 ppb aggregate, 8 bbl neat), did not see any pressure increase. Stop pumping when tail of cement 10 bbl (260') above perforations. Pull to safety, WOC. Fill hole on backside. Circulate, began getting oil and gas. Circulate thru choke. 09/12/99 2 9846' Circulate out gas and crude while WOC. Bleed IA from 440 to 100 psi. PT cement plug to 1500 psi for 30 minutes and lost 120 psi while IA rose 45 psi (assume leak is by a DGLV). POOH~",., LD cementing BHA. MU milling BHA. RIH with milling BHA #1 (3.80" dimple mill/motor). Mill ""\ XN nipple at 9112'. Drill 5' cement above whipstock. Mill window from 9845.7-9853'. POOH, ~ change out mill. TIH, mill window. Stalling with string reamer at top and bottom of window. Lost 800 psi while milling. POOH to check tool string. 09/13/99 3 10453' Found Baker hydraulic disconnect had disconnected (set screws had backed out). MU fishing BHA. RIH with Baker GS spear on 2 jts tubing. Latch fish and POOH. LD fishing BHA and fish. MU drilling assy. RIH with drilling BHA #1 (2.43° motor). Tie-in to BHCS in 7" liner at 9720', corr -15'. RIH thru window and tag at 9856'. Drill ahead building angle and turning left from 9856-10453'. Having trouble getting clicks on Orienter. Backream to window to get clicks. Bit quit drilling. POOH for bit 09/14/99 4 10540' Finish POOH for bit. Change bit, motor. RIH with BHA #2 (STR20D bit, 1.2° motor). Drill Zone 3 from 10453-10490' in 2.5 hrs. POOH for bit. Change bit, orienter. RIH with BHA #3 (STR20D bit, 1.2° motor). Drill 10490'- 10527'. POOH, change bit and MWD probe, LD shock sub. TIH, ream under-gauge hole. Orient toolface and drill ahead. 09/15/99 5 10581' Drill in Zone 3 from 10540-547' and bit dulled. POOH for bit. Change bit. Change out leaking reel swivel. RIH with BHA #5. Drill in Zone 3 from 10547-576' and bit dulled. POOH for bit. Change bit. RIH with BHA #6. Drilled to 10581'. PR very Iow. POH. Changed Bit & motor. PT'D coil connector. RIH with BHA #7. 8400 8500 8600 8700 88oo 8900 9O0O B.P. Exploration (True) Structure : Pod D Field : Prudhoe Bay Brij Potnis Dote plottod : ~O-$ep-lggg Well : D-O9A, 50-029-20381-01 Coordinates ore in feet reference D-og. Location : Northc,_olope. Alaska Tr.o vc.~:o, ~pth ...... , ...... ~. - MSL: 7~.2 ,t. --- Bake" Hughes INTEO --- East (feet) -> 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 `3200 .3400 .3600 I I I f I I I I I I I II I I I I I I II I 1800 Projected to TD -- C05e401o Plan .-. · ORIGINAL e4018 Ptan ] Projected to TD I I I I I I I I i I I I I I I I i I I I I I I I I I I II I I I I I I I I I I I I I I I 500 400 300 200 100 0 1 O0 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 Vertical Section (feet) -> Azimuth 31.18 with reference 3108.25 S, 2044.34 E from D-09 2000 2200 2400 2600 2800 3000 3200 3600 3800 B.P. Exploration (True) Pad D D-09A D-09 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : D-09A Our ref : svy228 License : 50-029-20381-01 Date printed : 30-Sep-1999 Date created : 30-Sep-1999 Last revised : 30-Sep-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 655230.717,5955744.049,999.00000,N Slot location is n70 17 29.249,w148 45 8.058 Slot Grid coordinates are N 5957741.000, E 654121.000 Slot local coordinates are 2019.58 N 1068.34 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad D, D-09A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 1 Your ref : D-09A Last revised : 30-Sep-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing. 9800.00 35.40 163.90 8511.04 3108.25S 2044.34E 0.67 0.00 656228.91 5954675.83 9845.00 35.46 164.04 8547.70 3133.32S 2051.54E 0.22 -17.72 656236.63 5954650.92 9873.00 43.80 157.89 8569.26 3150.15S 2057.43E 32.89 -29.06 656242.87 5954634.22 9910.78 49.13 149.60 8595.30 3174.62S 2069.60E 21.24 -43.70 656255.54 5954610.00 9938.73 53.26 143.45 8612.82 3192.75S 2081.63E 22.62 -52.98 656267.94 5954592.13 9960.91 57.29 138.58 8625.45 3206.90S 2093.11E 25.60 -59.15 656279.70 5954578.22 9980.33 60.38 135.06 8635.51 3219.01S 2104.48E 22.22 -63.62 656291.32 5954566.35 10011.98 65.57 129.09 8649.89 3237.86S 2125.41E 23.47 -68.91 656312.63 5954547.94 10051.98 72.33 123.46 8664.26 3259.89S 2155.50E 21.40 -72.18 656343.17 5954526.54 10079.41 76.29 119.95 8671.68 3273.75S 2177.96E 18.98 -72.41 656365.91 5954513.14 10117.28 80.51 112.74 8679.30 3290.18S 2211.18E 21.72 -69.27 656399.46 5954497.40 10148.78 82.18 106.59 8684.05 3300.65S 2240.49E 20.02 -63.05 656428.98 5954487.53 10192.11 83.76 99.91 8689.36 3310.50S 2282.33E 15.73 -49.82 656471.00 5954478.55 10217.36 82.99 91.53 8692.27 3313.00S 2307.26E 33.11 -39.05 656495.98 5954476.57 10248.78 81.46 85.10 8696.53 3312.09S 2338.36E 20.85 -22.17 656527.05 5954478.12 10279.91 79.43 79.17 8701.70 3307.89S 2368.75E 19.88 -2.84 656557.35 5954482.94 10310.58 78.66 72.84 8707.53 3300.62S 2397.95E 20.42 18.50 656586.40 5954490.82 10351.88 77.34 62.47 8716.14 3285.29S 2435.27E 24.77 50.93 656623.38 5954506.91 10385.88 76.92 56.30 8723.72 3268.42S 2463.78E 17.73 80.12 656651.54 5954524.37 10407.43 78.13 50.34 8728.38 3255.86S 2480.64E 27.58 99.61 656668.14 5954537.28 10458.79 79.54 40.85 8738.35 3220.64S 2516.59E 18.33 148.35 656703.34 5954573.23 10491.25 80.51 33.99 8743.98 3195.26S 2536.00E 21.03 180.11 656722.23 5954599.00 10534.33 81.07 26.09 8750.88 3158.48S 2557.27E 18.15 222.59 656742.73 5954636.21 10577.77 80.68 21.33 8757.78 3119.22S 2574.51E 10.86 265.10 656759.16 5954675.81 10616.03 -77.61 14.30 8764.99 3083.48S 2586.01E 19.75 301.63 656769.91 5954711.78 10646.90 77.26 12.54 8771.71 3054.17S 2593.00E 5.68 330.33 656776.30 5954741.22 10674.23 78.25 10.20 8777.50 3027.99S 2598.26E 9.12 355.45 656781.02 5954767.51 10698.23 79.28 4.63 8782.18 3004.66S 2601.30E 23.16 376.99 656783.57 5954790.89 10737.25 78.84 353.38 8789.61 2966.42S 2600.64E 28.33 409.36 656782.12 5954829.11 10780.45 76.90 346.88 8798.70 2924.83S 2593.41E 15.38 441.20 656774.04 5954870.53 10828.32 79.33 337.49 8808.58 2880.30S 2579.08E 19.85 471.88 656758.80 5954914.76 10862.40 81.74 334.58 8814.18 2849.59S 2565.43E 11.00 491.08 656744.51 5954945.18 10909.77 84.90 340.02 8819.70 2806.20S 2547.29E 13.21 518.81 656725.48 5954988.18 10940.37 85.78 344.77 8822.18 2777.14S 2538.07E 15.74 538.90 656715.66 5955017.04 10977.50 84.99 350.40 8825.17 2741.01S 2530.11E 15.26 565.69 656706.96 5955053.00 11010.00 84.37 353.56 8828.19 2708.97S 2525.60E 9.87 590.77 656701.79 5955084.93 11059.62 83.98 2.24 8833.23 2659.69S 2523.79E 17.42 631.99 656698.96 5955134.16 11094.40 85.17 5.34 8836.52 2625.14S 2526.08E 9.51 662.73 656700.54 5955168.74 11125.50 83.50 9.20 8839.59 2594.45S 2529.99E 13.47 691.02 656703.82 5955199.51 11158.37 81.65 13.25 8843.84 2562.49S 2536.33E 13.45 721.64 656709.50 5955231.59 11189.37 77.96 14.13 8849.33 2532.85S 2543.55E 12.23 750.74 656716.10 5955261.37 11246.01 73.04 10.26 8863.51 2479.28S 2555.15E 10.92 802.57 656726.59 5955315.16 11282.46 72.07 10.26 8874.44 2445.07S 2561.34E 2.66 835.05 656732.08 5955349.50 11342.58 71.54 347.06 8893.44 2388.44S 2560.03E 36.65 882.83 656729.60 5955406.09 11384.33 72.16 359.01 8906.49 2349.14S 2555.24E 27.23 913.96 656724.00 5955445.27 11416.18 70.93 6.92 8916.59 2319.00S 2556.80E 23.87 940.56 656724.93 5955475.44 11447.91 70.49 5.69 8927.07 2289.23S 2560.08E 3.91 967.73 656727.60 5955505.26 11485.81 69.52 8.50 8940.03 2253.89S 2564.48E 7.42 1000.24 656731.27 5955540.68 11518.98 67.76 12.54 8952.12 2223.53S 2570.11E 12.52 1029.13 656736.27 5955571.16 11545.01 65.13 16.06 8962.52 2200.41S 2576.00E 15.99 1051.95 656741.68 5955594.39 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from D-09 and SSTVD from RKB - MSL = 72.2 ft. Bottom hole distance is 3369.03 on azimuth 129.88 degrees from wellhead. Vertical section is from tie at S 3108.25 E 2044.34 on azimuth 31.18 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad D,D-09A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : D-09A Last revised : 30-Sep-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing. 11571.58 64.16 12.02 8973.90 2177.13S 2581.82E 14.22 1074.89 656747.02 5955617.79 11591.00 64.16 12.02 8982.37 2160.03S 2585.46E 0.00 1091.40 656750.31 5955634.95 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from D-09 and SSTVD from RKB - MSL = 72.2 ft. Bottom hole distance is 3369.03 on azimuth 129.88 degrees from wellhead. Vertical section is from tie at S 3108.25 E 2044.34 on azimuth 31.18 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad D,D-09A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 3 Your ref : D-09A Last revised : 30-Sep-1999 MD SSTVD 9800.00 8511.04 3108.25S 11591.00 8982.37 2160.03S Rectangular Coords. Comments in wellpath Comment 2044.34E Tie-in Point 2585.46E Projected to TD NO Targets associated with this wellpath Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOAD Pad, Slot D-09 D-O9A Job No. AKMW90154, SURVEY REPORT 6 October, 1999 ORIGINAL Your Reft AP1-500292038101 Surface Coordinates: 5957740.72 N, 654120.11 E (70° 17'29.2465" N, 148° 45' 08.0837" W) Kelly Bushing: 72.20ft above Mean Sea Level sper~r',~j-s[.Jn Survey Reh svy9340 Sperry-Sun Drilling Services Survey Report for D-OgA Your Ref: API-500292038101 Job No. AKMW90154, Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9800.00 35.400 163.915 8511.04 8583.24 9845.00 35.460 164.040 8547.70 8619.90 9873.00 43.800 157.890 8569.26 8641.46 9910.78 49.130 149.600 8595.30 8667.50 9938.73 53.260 143.450 8612.82 8685.02 9960.91 57.290 138.580 8625.45 8697.65 9980.33 60,380 135.060 8635.51 8707.71 10011.98 65.570 129.090 8649.89 8722.09 10051.98 72.330 123.460 8664.26 8736.46 10079.41 76.290 119.950 8671.68 8743.88 10117.28 80.510 112.740 8679.30 8751.50 10148.78 82.180 106.590 8684.05 8756.25 10192.11 83.760 99.910 8689.36 8761.56 10217.36 82.990 91.530 8692.27 8764.47 10248.78 81.460 85.100 8696.53 8768.73 10279.91 79.430 79.170 8701.70 8773.90 10310.58 78.660 72.840 8707.53 8779.73 10351.88 77.340 62.470 8716.14 8788.34 10385.88 76.920 56.300 8723.72 8795.92 10407.43 78.130 50.340 8728.38 8800.58 10458.79 79.540 40.850 8738.35 8810.55 10491.25 80.510 33.990 8743.98 8816.18 10534.33 81.070 26.090 8750.88 8823.08 10577.77 80.680 21.330 8757.78 8829.98 10616.03 77.610 14.300 8764.99 8837.19 Local Coordinates Northings Eastings (ft) (ft) 3108.80 S 2043.51E 3133.87 S 2050.71 E 3150.69 S 2056.60 E 3175.17 S 2068.77 E 3193.30 S 2080.80 E 3207.44 S 2092.28 E 3219.55 S 2103.65 E 3238.40 S 2124.58 E 3260.43 S 2154.67 E 3274.30 S 2177.13 E 3290.73 S 2210.35 E 3301.20 S 2239.66 E 3311.05 S 2281.49 E 3313.54 S 2306.43 E 3312.63 S ,2337.53 E 3308.44 S 2367.92 E 3301.16 S 2397.12 E 3285.84 S 2434.43 E 3268.97 S 2462.95 E 3256.40 S 2479.81E 3221.18 S 2515.76 E 3195.81S 2535.17 E 3159.02 S 2556.43 E 3119.77 S 2573.68 E 3084.02 S 2585.18 E Global Coordinates Northings Eastings (ft) (ft) 5954674.47 N 656226.92 E 5954649.55 N 656234.64 E 5954632.85 N 656240.87 E 5954608.63 N 656253.54 E 5954590.75 N 656265.94 E 5954576.84 N 656277.70 E 5954564.97 N 656289.32 E 5954546.55 N 656310.63 E 5954525.15 N 656341.17 E 5954511.74 N 656363.91 E 5954496.00 N 656397.46 E 5954486.13 N 656426.98 E 5954477.14 N 656469.01E 5954475.15 N 656493.99 E 5954476.70 N 656525.06 E 5954481.52 N 656555.36 E 5954489.39 N 656584.41E 5954505.48 N 656621.40 E 5954522.93 N 656649.56 E 5954535.84 N 656666.16 E 5954571.79 N 656701.38 E 5954597.56 N 656720.26 E 5954634.77 N 656740.77 E 5954674.37 N 656757.21 E 5954710.34 N 656767.97 E Alaska State Plane Zone 4 PBU_WOA D Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.209 ~2.886 21.241 22.625 25.601 22.217 23.470 21.397 18.977 21.721 20.015 15.729 33.107 20.852 19.883 20.417 24.765 17.734 27.580 18.333 21.027 18.148 10.856 19.747 3563.87 3585.51 36OO.84 3625.89 3646.76 3664.65 3681.14 3709.29 3746.50 3772,62 3808.63 3837.81 3876.18 3896.89 3920.12 3940.71 3958.40 3977.12 3988.11 3992.95 3997.84 3996.40 3989.04 3977.01' 3962.84 Tie on Window Point Continued... 6 October, 1999 - 10:06 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for D-O9A Your Ref: API-500292038101 Job No. AKMW90154, Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10646.90 77.260 12.540 8771.71 8843.91 10674.23 78.250 10.200 8777.50 8849.70 10698.23 79.280 4.630 8782.18 8854.38 10737.25 78.840 353.380 8789.61 8861.81 10780.45 76.900 346.880 8798.70 8870.90 10828.32 79.330 337.490 8808.58 8880.78 10862.40 81.740 334.580 8814.18 8886.38 10909.77 84.900 340.020 8819.70 8891.90 10940.37 85.780 344.770 8822.18 8894.38 10977.50 84.990 350.400 8825.17 8897.37 11010.00 84.370 353.560 8828.19 8900.39 11059,62 83.980 2.240 8833.23 8905.43 11094.40 85.170 5.340 8836.52 8908.72 11125.50 83.500 9.200 8839.59 8911.79 11158.37 81.650 13.250 8843.84 8916.04 11189.37 77.960 14.130 8849.33 8921.53 11246.01 73.040 10.260 8863.51 8935.71 11282.46 72.070 356.720 8874.48 8946.68 11342.58 71.540 347.060 8893.30 8965.50 11384.33 72.160 359.010 8906.34 8978.54 11416.18 70.930 6.920 8916.44 8988.64 11447.91 70.490 5.690 8926.92 8999.12 11485.81 69.520 8.500 8939.89 9012.09 11518,98 67.760 12.540 8951.97 9024.17 11545.01 65.130 16.060 8962.37 9034.57 Local Coordinates Northings Eastings (ft) (ft) 3054.72 S 2592.17 E 3028.54 S 2597.43 E 3005.20 S 2600.47 E 2966.96 S 2599.81 E 2925.38 S 2592.58 E 2880.84 S 2578.25 E 2850.13 S 2564.59 E 2806.75 S 2546.45 E 2777.68 S 2537.23 E 2741.56 S 2529.28 E 2709.52 $ 2524.76 E 2660.23 S 2522.96 E 2625.69 S 2525.25 E 2595.00 S 2529.16 E 2563.04 S 2535.50 E 2533.40 S 2542.72 E 2479.83 S 2554.32 E 2445.22 S 2556.44 E 2388.75 S 2548.40 E 2349.46 S 2543.61 E 2319.32 S 2545.16 E 2289.55 S 2548.45 E 2254.21 S 2552.85 E 2223.85 S 2558.48 E 2200.73 S 2564.36 E Global Coordinates Northings Eastings (ft) (ft) 5954739.79 N 656774.36 E 5954766.07 N 656779.09 E 5954789.46 N 656781.64 E 5954827.68 N 656780.20 E 5954869.11 N 656772.12 E 5954913.34 N 656756.88 E 5954943.76 N 656742.60 E 5954986.77 N 656723.57 E 5955015.63 N 656713.76 E 5955051.59 N 656705.06 E 5955083.53 N 656699.89 E 5955132.77 N 656697.08 E 5955167.35 N 656698.66 E 5955198.12 N 656701.94 E 5955230.20 N 656707.62 E 5955259.98 N 656714.23 E 5955313.78 N 656724.73 E 5955348.42 N 656726.14 E 5955404.71N 656716.95 E 5955443.90 N 656711.35 E 5955474.07 N 656712.29 E 5955503.90 N 656714.96 E 5955539.32 N 656718.63 E 5955569.79 N 656723.64 E 5955593.02 N 656729.05 E Alaska State Plane Zone 4 PBU_WOA D Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 5.679 9.118 23.164 28.328 15.379 19.853 10.997 13.212 15.736 15.263 9.867 17.420 9.510 13.467 13.451 12.227 10.917 35.530 15.288 27.234 23.870 3.913 7.422 12.522 15.991 3949.35 3936.55 3923.87 3898.78 3866.51 3826.90 3796.70 3754.92 3729.17 3699.85 3675.79 3642.72 3622.27 3605.53 3589.84 3576.32 3550.76 3530.13 3487.68 3458.74 3440.55 3423.94 3404.58 3389.38 3379.02 Continued... 6 October, 1999 - 10:06 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for D-O9A Your Ref: API-500292038101 Job No. AKMW90154, Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11571.58 64.160 12.020 8973.76 9045.96 2177.44 S 2570.19 E 11591.00 64.160 12.020 8982.22 9054.42 2160.35 S 2573.83 E 5955616.42 N 656734.40 E 5955633.59 N 656737.69 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. Alaska State Plane Zone 4 PBU_WOA D Pad Dogleg Rate (°/100fi) Vertical Section (ft) Comment 14.216 0.000 3368.52 3360.31 Projected Point The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 130.009° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11591.00ft., The Bottom Hole Displacement is 3360.31ft., in the Direction of 130.009° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9800.00 8583.24 3108.80 S 2043.51 E Tie on 9845.00 8619.90 3133.87 S 2050.71 E Window Point 11591.00 9054.42 2160.35 S 2573.83 E Projected Point 6 October, 1999 - 10:06 - 4 - DrillQuest IA LL LOG TFIAN$_MITTAL ~_oActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RI= ' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technicai Oata Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL . MYLAR / BLUE LINE WELL DATE TYPE DATA ! SEPIA FILM PRINT[S} Open Hole I L I 1 . . ~ Res. Eval. CH I '~ I 1 i 1 I Signed · Print Name: Date' '~ 'P 23 i999 ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax: (907)659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C:LMy Documents\Excel_Word_DocumentsXDistribution_FormsXBp_pb_form-doc MEMORANDUM State of Alaska TO: Robert Christenso¢1~ Chairman Alaska Oil and Gas Conservation Commission DATE: September 18, 1999 THRU: FROM: Blair Wondzell, ~ FILE NO' P. I. Supervisor Lou G rimald i,~r,~..~ SUBJECT: Petroleum In~'pector BOP NORD1 LG 9-17-99.DOC BOPE Test, Nordic rig #1 PBU #D-09A PTD #99-0085 Friday, September 17, 1999: I witnessed the weekly BOPE test on Nordic rig #1 which was sidetracking BPX well #D-09A in the WOA of the Prudhoe Bay field. The rig was ready to test when I arrived and we began immediately. All BOPE equipment was tested and passed with the exception of the #2 valve upstream of the manual choke on the choke manifold. This valve was greased and retested but still had a slight leak. This valve will be repaired after completion of this well during the rig move or before the next BOP test, whichever comes first. The test spanned approximately 5 ½ hours (4 ½ test hours) with much time being wasted chasing leaks that were eventually tracked down to a leaky master valve. This is normal (but unacceptable) for these Workover/Coil Tubing rigs. It seems every time I test one, we fight this problem. I feel this might lead to a complacent attitude in testing that would result in passing a component that showed a decline and erroneously attributing this to a leaking swab or master valve instead of the leaking BOP component. During the time we were waiting on the grease crew to come and grease-lock the swab valve we tested the choke manifold. We then stood-by for approximately ½ hour. During this time i noticed approximately 60 joints of 2 7/8 tubing on the pipe rack. As there were only 2 3/8 rams in the stack I asked Zane Montague (Nordic Toolpusher) if they planned to put 2 7/8 rams in before runnin.q~..,.~ it. It was indicated that they were not. I informed Zane that the proper~,wou"l-d"b e required~'¢''~ and I would check to make sure but to be ready to install them. I spoke with one of the other inspectors and the P.I supervisor who both indicated that the proper sized rams would be required for the tubing being run. I went back to the rig and spoke with Zane and Charlie Parker (BPX rep.) and confirmed what I had told Zane earlier. BOP NORD1 LG 9-17-99.DOC page I of 2 BOP NORD1 LG 9-17-99.DOC page 2 of 2 I spoke with John McMullen who is the BPX engineer for Nordic rig I and we looked over BPX guidelines for BOP configuration. Their guidelines require that there be properly sized rams for the liner being run if the liner is a significant portion of the string. This verbage seemed vague to me and I suggested to John if they wanted a exemption from the rams, they should apply to the Commission for a variance. SUMMARY: I witnessed the weekly test of the BOPE on Nordic rig #1 side tracking BPX well #D-09A in the WOA of the Prudhoe Bay field. There was one failure observed. Test time 4 1/2 hours. Attachments: BOP NORD1 LG 9-17-99.XLS CC: Ted Stagg (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA ..... - , ,_ OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DS/Nordic Rig No. 1 PTD # 99-0085 BP Exploration Rep.: D-O9A Rig Rep.: Set @ Location: Sec. Weekly X Other TEST DATA DATE: 9/17/99 Rig Ph.# 659-4433/4434 Charlie Parker Zane Montague 23 T. 11N R. 13E Meridian Umiat BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 250/4000 n/a 1 250/4000 P 1 250/4000 P 1 250/2500 P n/a 1 25O/4OOO P n/a CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 1 250/4OOO P 2 250/4000 P 1 250/4000 P MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank ok ok Location Gen.: ok Pit Level Indicators ok ok Housekeeping: ok Meth Gas Detector ok ok Permit to drill: yes H2S Gas Detector ok ok Standing Order Posted Test Quart. Pressure P/F '15 250/4000 '1 32 250/4000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3 @ 2'1oo 3,050 p 2,050 p minutes 29 sec. minutes '10 sec. X' Remote: X Psig. yes Well Sign yes Drl. Rig ok Hazard Sec. yes TEST RESULTS Number of Failures: 1' ,Test Time: 4.5 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: #2 inside manual choke valve leaked slightly. Greased, cycled and retested. Valve still leaks, will be repaired during next rig move (3-4 days), Test would be shorter if tree swab valve had held from beginning or back pressure valve set. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Lou Grimaldi Form Revised 2/20/97 L.G. BOP NORD1 LG 9-17-99.xls 9~23~99 TONY KNOWLE$, (30VEFINOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 3; 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit D-09A BP Exploration (Alaska) Inc. Permit No: 99-085 Sur Loc: 3260'SNL. 1067~WEL, Sec. 23, T11N; R13E, UM 5 ' Btmhole Loc. 18 I'SNL. 1_ 24 EWL. Sec. 25. T11N, R13E? UM Dear Mr. Stagg' Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. , STATE OF ALASKA ALASKA .~-,-LAND GAS CONSERVATION CON .... ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of w'ork [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 72.21' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028286 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3260' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number _~ Number 2S100302630-277 1100' SNL, 1091' EWL, SEC. 25, T11 N, R13E, UM D-09A At total depth 9. Approximate spud date Amount $200,000.00 181' SNL, 1524' EWL, SEC. 25, T11 N, R13E, UM 09/08/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028285, 181' MDI No Close Approach 2560 11561' MD / 8960' TVD 16. To be completed for deviated wells i17. Anticipated pressure [see 20 AAC 25.035 (e) (2)} Kick Off Depth 9850' MD Maximum Hole Angle 81° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2471' 9090' 7930' 11561' 8960' 112 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen OperationS.Present well condition summary 0 R I NAL Total depth: measured 10684 feet Plugs (measured) true vertical 9291 feet Effective depth: measured 10600 feet Junk (measured) Fish in hole, 3-1/8" OD x 20' Fired Peri gun and CCL. TOF at 10600' (06/17/80). true vertical 9225 feet Casing Length Size Cemented MD TVD Structural Conductor 110" 20"x 30" 14 cu yds Arcticset Concrete 134' 134' Surface 2656' 13-3/8" 4325 cu ft Permafrost 2680' 2680' Intermediate 9584' 9-5/8" 1346 cuft Class 'G', 130 cuft PF 9608' 8426' Production Liner 1567' 7" 450 cu ft Class 'G' 9107' - 10674' 8016' - 9283' Perforation depth: measured 10218' - 10230', 10255' - 10278', 10278' - 10288', 10294' - 10300', 10308' - 10318', 10328' - 10346' true vertical 8922' - 9025' (six intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] D'rilllft~Pr'~5~r~.S [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.05¢.Re~gi~nts Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoigg is true and correct to the best of my knowledge Signed ~~.~ Ted Stagg Title CT Drilling Engineer Date Commission Use Only I I A~pro_.val D,¢~ See cover letter Permit Number APl Number ~ ~ 0 ~.~-' 50-029-20381-01 .~- "~',~' for other requirements Conditions of Approval' Samples Required []Yes [~No Mud Log Required I--lYes ~No Hydrogen Sulfide Measures []Yes []No Directional Survey Required [~,Yes[]No Required Working Pressure for DOPE 1--12K; ~3K; 1--14K; []5K; I--I10K; I--I15K Other: by order of Approved By ORIGINAL SIGNED'BY Commissioner the commission Date~ -.- Form 10-401 Rev. 12-01-85 Robert N. Ohristenson Submit In Triplicate BPX D-09a Sidetrack Summary of Operations: D-09 has been shut in since July 1997 due to high GOR, high water cut and Iow oil rate. The sidetrack, D-09a, will be a high angle sidetrack targeting the mid-zone 2, (25P & 24P). This sidetrack will be conducted in two phases. Phase 1: Set whipstock: Planned for Sept. 3, 1999. · A Tubing Integrity Test will be performed. · A casing caliper will be run over the tubing and liner. · A permanent whipstock will be set on E-Line at approximately 9,850' MD. Phase 2: Squeeze Perfs, Mill Window & Drill Directional Hole: Planned for Sept. 8, 1999. Directional drilling coiled tubing equipment will be rigged up and utilized to squeeze perfs, mill the window and drill the directional hole as per attached plan to planned TD of 11,561' MD (8,960' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and all other Class II wastes will go to Grind & Inject for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,090' MD and cemented with approx. 20 bbls. cement to bring cement 200 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,850' MD (8,552' TVD ss) - TD: 11,561' MD (8,960' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction log and Memory CNL will be run in open hole. TREE: 4" CIW KB. ELEV - 72.21' WELLHEAD: McEVOY 2-step D-09a Pro :d Completi( 9 5/8" DV I 2614'1 13 3/8", 72 #/ft, I 2680'1 KOP: 2800' MAX ANGLE: 44° @ 6500' 4 1/2", 12.6#/ft, L-80, TDS TUBING TUBING ID:: 3.958" CAPACITY: .0152 BBL/FT SSSV LANDING NIPPLE I 2128'1 GAS LIFT MANDRELS N° MD(EKE) TVD(SS) 5 2987' 2914' 4 5102' 4809' 3 7019' 6297' TOP OF 7" LINER I 9107'I TIE-BACK SLEEVE 7" EOT LINER HANGER I 9117'I 9 5/8", 47#/ft, I 9608' I~ L-80, BTRS Whipstock approx. 9850' MD 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) Rt. Hand Release "SAP" Latch 9 5/8" OTIS PERM. PACKER (MHR) (3.85" ID) 19000' I 9011' I 9013' 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 ....SWN" NIPPLE (PARKER) (3.725" ID) 4 1/2" WLEG (5.50" OD, 3.854" ID) ELMD 9106' 9127' 9139' 9124' 2 7/8" liner cemented to approx. 200 ft above window REF LOG: SWS-BHCS- 12-3-79 TIE-IN LOG: SWS - CBL 12-8-79 SIZE SPF INTERVAL )PEN/SQZ'D 2-1/8" 6 10,218-10,230 OPEN 7/15/96 3 1/8" 4 10,218-10,248' SQZD 9-12-91 3 3/8" 4 10,255'-10,278' OPEN 1-6-96 3 3/8" 6 10278 - 10288' SZ/RPF 3-16-94 3 1/8" 4 10,291-10,294 SQZD/9-12-91 3 3/8" 6 10,294-10,300 S:~Z/RPF 9-16-93 3 1/8" 4 10,300-10,308 .~QZD/9-12-91 3 3/8 6 0,308-10318 5Z/RPF/9-16-93 3 3/8" 4 10,328-10,346 .~Z/RPF/10-6-91 2 9/16 6 10278-10288 (:~PEN 7/21/95 2 9/16 6 10294-10300 £~PEN 7/21/95 PBTD I~o,e2~'l 7" , 29 #/ft, L-80, BTRS [10,674'[ Abandonment cement to be downsqueezed past whipstock Section 500 TSAB Path Distance (Feet) 1,000 1,500 2,000 I ~ I 2,500 3,000 I I Angle @ K.O.= 35 deg MD:9850 8,870 Tot Drld:1711 ft Marker Depths ~:3rig Wellbore Base Z3 1'Z3 TSAD 8,960I I 8,9601ft TVD 8,797 Irt TVD I I 8,5271. Kick Off I 8,5521ft TVD 9,850lft MD IDeprtr @KO 3,763 ft I MD KO Pt 9,850 MD New Hole 1711 Total MD 11,561 TVD TD 8,960 DLS deg/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 30 -45 200 Curve 3 18 -90 399 Curve 4 14 -90 499 Curve 5 10 100 499 Curve 6 10 128 84 1,71 i Drawn: 8/27/1999 9:32 Plan Name: Case 401a 1,500 D-09 I 2,000 2,500 8,870 X distance from Sfc Loc 3,000 -2,000 -2,500 -3,000 -3,500 -4,000 IWell Name D-09 J CLOSURE I Distance 3,401 ft Az 129 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 2,116 -3,093 TD 2,638 -2,146 State Plane 656,759 5,955,595 Surface Loc 654,121 5,957,74 DLS de~l/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 30 -45 200 Curve 3 18 -90 399 Curve 4 14 -90 499 Curve 5 10 100 499 Curve 6 10 128 84 1,711 Drawn: 8/27/1999 9:32 Plan Name: Case 401a D~9a CT Drilling & Completion BOP LU 22.5" 18" 38" 2 3/8" CT ---~ J I 10,000 psi Pack-Off Lubricator~ ! Annular ...... I I I I Blind/Shear 7 1/16" Pipe/Slip -'- 2 3/8" 7 1/16" Pipe 2 7/8" SWAB OR MASTER VALVE 2 3/8" STATE OF ALASKA ALAS~~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: i~ Abandon [] Suspend [] Plugging [] Time Extension [] Perforate ~ Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [~ Development [] Exploratory [] Stratigraphic [--I Service 4. Location of well at surface 3260' SNL, 1067' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 1100' SNL, 1091' EWL, SEC. 25, T11 N, R13E, UM At effective depth 1551' SNL, 1097' EWL, SEC. 25, T11 N, R13E, UM At total depth 1602' SNL, 1109' EWL, SEC. 25, T11 N, R13E, UM Datum Elevation (DF or KB) KBE = 72.21' AMSL 7. Unit or Property Name Prudhoe Bay Unit - 8. Well NUmber D-09 9. Permit Number 79-45 10. APl Number 50-029-20381 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 112. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 10684 feet 9291 feet 10600 feet 9225 feet Plug§ (r~'e'~.~u r~:: :-_-.'_: !; Junk (measured) Fish in hole, 3-1/8" OD x 20' Fired Perf gun and CCL. TOF at 10600' (06/17/80). Length Size Cemented MD TVD 110" 20"x 30" 14 cu yds Arcticset Concrete 134' 134' 2656' 13-3/8" 4325 cuft Permafrost 2680' 2680' 9584' 9-5/8" 1346 cuft Class 'G', 130 cuft PF 9608' 8426' 1567' 7" 450 cu ft Class 'G' 9107' - 10674' 8016' - 9283' 10218' - 10230', 10255' - 10278', 10278' - 10288', 10294' - 10300', 10308' - 10318', ;90;22'8: ;~0~'4(~'six intervals) 0 R I GiN A L 4-1/2", 12.6#, L-80 TDS tubing to 9139' Packers and SSSV (type and measured depth) 9-5/8" Otis 'MHR' Permanent Packer at 9013'; 4-1/2" Camco SSSV Nipple at 2128' 13. Attachments ~ Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation September 3, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved 15. Status of well classifications as: [] Oil ~ Gas E~ Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fore.~o~ue and correct to the best of my knowledge Signed TedStagg (;~-.,~,,./,'~..~'¢ Title CT Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test__ Subsequent form required 10- I Approval No. '~le~l..., / ~9 / Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE 072099 HANDL INVOICE / CREDIT MEMO CKO72099A [NO INST: S/l- THE ATrACHED CHECK IS IN PAYMENT FOR ITEM~ DESCRIBED ABOVE. DESCRIPTION TERR I HUBBLE GROSS ,---_..._._.______ oo. 06 X4~28 VENDOR DISCOUNT --.-.-.___.____. I 001544~50] H :.:.::. .I!BP EXPLORATION (ALASKA),. INC, ~:, j :i.: ,' 'ANCHORAG E':i ALASKA ":?'~':::; ~:'J"' ::'"~,; ,:?;i.'J .... 99519-6612 : ,.:: ':: i'. PAY' == :,,..? ,, ONE 'FIRST' NATIoNAL,BANK ~3F ASHLAND i:: ii;. ": ;"i ;,ANI:~,i~FIii. iATE O~ ;:! .: . :.,": ...... . NAi'ON;~:C ~ ~K :}; ' ~: ' ,' . ;.:: · ;~;:: .... :,~: ,.: :. :, :~ :.,, ~ '.'j,,:,.:~:::,; :S6:3se ~;~", :.:.. . :::"ALASKA STATE DEPT': ;OF REVENUE :i"'::,3001:i:!iilPORcUP INE ~;;:D~~',' ',:~:.,? ANCHORAGE AK 99501-31~0 "' l, 5 IL, h r-., O,' WELL PERMIT CHECKLIST COMPANY ~ J3 WELL NAME ~ 5 ~ [~)':-0ffJ~ PROGRAM: exp dev X redrll //~ serv wellbore seg ann. disposal para req FIELD & POOL ~ ~ ~) I ~ 0 INIT CLASS g ~ v J - 0 1/,.. GEOL AREA ~' ~ C) UNIT# J ) ~ ~° ~ ON/OFF SHORE O ~ ADMINISTRATION rR 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 ........... ENGINEERING DT 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~N ~N Y N N GEOLOGY A~R DATE ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure z0~ ..... Y 32. Seismic analysis of shallo,.w. ~ ........ Y 33. Seabed condit~shore) ..... ..._........ Y 34. Con phone for weekly progress reports [exploratory only] Y 35. With proper ceme~0flng records, this plan (A) will contain~,'Aste in a suitable receiving zone; ....... Y N (B) will not co~aminate f?fr. eshwa'te~; or cause d~jlli.~a~ste... Y N to surfa/c'e; / ~/ / ,,,/ (C) will n~ im_,l:~l'r mechanical/idte~Jty'of the well/u~ed for disposal; Y N (D) will ~ot-d'amage produ ' .~mation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or20 AAC 25.412. Y N GE.~O~_: ENGINEERING: U IC/~.].~ COMMISSION: JDH ' ~ RNC ~ - co Comments/Instructions: c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun ~=zlling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Mar 22 13:20:50 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/22 Origin ................... STS Reel Name ................ I/NKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/03/22 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: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 90154 B. JAHN PARKER/SEVCI RECEIVED MArl 2 8 000 AJaska Oil & Gas Cons. Commission Anchorage D-09A 500292038101 BP Exploration (Alaska) Inc. Sperry Sun 22 -MAR- 00 MWD RUN 2 AK-MW- 90154 B JAHN PARKER/SEVCI MWD RUN 3 AK-MW- 90154 B JAHN PARKER/SEVCI JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW- 90154 B. JAHN PARKER/SEVCI MWD RUN 5 AK-MW-90154 B. JAHN PARKER/SEVCI MWD RUN 6 A/~-MW- 90154 S. LATZ PARKER/HUPP JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-90154 S. LATZ PARKER/HUPP MWD RUN 8 AK-MW-90154 S. LATZ PARKER/HUPP MWD RUN 9 AK-MW- 90154 S. LATZ PARKER/HUPP JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: MWD RUN 10 AK-MW-90154 S LATZ PARKER/HUPP 23 liN RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 13E 3260 1067 72.21 .00 45.31 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9845.0 3.750 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1 - 10 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 09/19/99 (DDS MRIL GR) WITH A KBE OF 72.21' AMSL. LOG DATA RETAINS THE ORIGINAL DRILLERS'S DEPTH REFERENCES. THIS WELL KICKS OFF FROM D-09A AT 9845'MD, 8548'SSTVD (TOP OF WHIPSTOCK). 5. MWD RUNS 1 - 10 REPRESENT WELL D-09A WITH API # 50-029-20281-01. THIS WELL REACHED A TOTAL DEPTH OF 11,591' MD, 8,982' SSTVD. SROP = Smoothed Rate of Penetration SGRD = Smoothed Gamma Ray $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9828.0 11552.0 SROP 9857.5 11578.5 $ BASELINE CURVE FOR SHIFTi _ CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 9830 0 9839 9844 9851 9857 9869 9871 9874 9877 9879 9883 9887 9912 9929 9945 9956 9958 9963 9966 9978 9982 9991 9993 9996 10000 10004 10026 10030 10039 10054 10058 10064 10066 10070 10077 10091 10098 10144 10155 10170 10246 10261 10267 10276 10281 10284 10292 10295 10305 10334 10372 10398 10405 10419 10444 10454 10479 10537 10543 10557 10565 10578 10587 10598 5 0 5 5 0 5 5 0 0 0 5 0 0 0 .0 .5 .0 .0 5 5 5 5 0 5 5 5 0 5 0 0 0 0 5 0 5 5 .0 0 5 0 0 5 0 0 0 0 0 5 0 5 5 0 0 0 5 0 5 0 5 5 0 5 0 GR 9829 5 9840 0 9845 5 9851 0 9858 0 9868 5 9872 5 9874 0 9876 0 9878.5 9880.5 9887.0 9910.5 9925 0 9944 0 9956 0 9957 5 9961 0 9965 0 9978 5 9981 5 9989 0 9992 0 9995 0 9998 0 10004 0 10026 0 10029 5 10037 0 10053 5 10058 0 10063 0 10064 5 10068 5 10076 5 10094 0 10097 5 10142 5 10154 0 10170 0 10245 5 10258 5 10265 5 10271 5 10277 5 10283 5 10289 5 10292 0 10303 5 10331 5 10370 5 10400 0 10405 5 10417 0 10444 5 10455 5 10475 0 10536 0 10542 0 10560 0 10565 5 10578 5 10588 0 10598 5 10603 10621 10634 10648 10697 10707 10755 10767 10774 10780 10786 10790 10798 10800 10810 10822 10839 10859 10875 10881 10915 10918 10920 10928 10931 10936 10949 10971 10974 10981 11000 11006 11012 11018 11034 11040 11050 11059 11075 11079 11085 11102 11129 11142 11146 11164 11180 11193 11202 11210 11216 11225 11231 11237 11240 11268 11282 11288 11295 11300 11303 11307 11314 11318 11322 11328 11334 11345 1066 .... J 10621.5 10635.5 10648.5 10697.0 10707 0 10756 5 10768 5 10775 5 10781 0 10788 5 10792 5 10797 5 10799 5 10810 5 10819 5 10838 0 10857.5 10872.0 10877.0 10913.5 10915 0 10917 0 10926 0 10931 0 10934 0 10946 5 10968 0 10972 5 10979 5 11000 0 11008 0 11015 5 11023 0 11038 5 11045.0 11058.0 11065.5 11086.0 11090.0 11096.5 11106.5 11132.5 11147.5 11153.0 11168.0 11187.5 11200 0 11210 5 11219 5 11224 0 11231 0 11238 0 11243 5 11246 5 11274 5 11291 0 11297 0 11304 5 11308 5 11311 0 11314 0 11322 5 11325 5 11329 0 11336 0 11343 0 11353 0 11350 0 11354 5 11362 5 11367 5 11372 5 11379 0 11386 0 11388 0 11392 0 11395 5 11402 5 11406 5 11414 5 11416 5 11418 5 11443 5 11452 0 11455 5 11474 5 11478 0 11482 5 11486 0 11488 5 11494 5 11499 5 11501 0 11507 5 11513 0 11517 5 11521 5 11532 5 11537 0 11542 5 11545 5 11550 0 11552 0 11578 5 $ MERGED DATA PBU TOOL MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: Data Format 1135~ 11359 11371 11380 11385 11386 11393 11397 11399 11402 11406 11411 11418 11421 11424 11447 11456 11461 11476 11482 11491 11496 11498 11506 11510 11512 11520 11525 11535 11542 11546 11550 11553 11556 11562 11564 11591 5 0 0 0 5 0 0 5 5 0 0 5 0 0 5 5 0 5 0 5 5 5 5 0 5 0 5 0 5 0 0 5 0 .0 .5 .0 SOURCE CODE BIT RUN NO 1 2 3 4 5 6 7 8 9 10 MERGED MAIN PASS. $ Specification Record MERGE TOP 9827.5 10425 5 10460 0 10497 5 10522 0 10551 0 10556 0 10605 5 10690 0 11219 5 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 MERGE BASE 10454.5 10490 0 10527 0 10547 0 10577 0 10581 0 10631 0 10719 5 11249 5 11591 0 Name Service Order Unit~ ,~ize Nsam Rep Code Offset Chann~j DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9828 11578.5 10703.3 3502 ROP MWD FT/H 3.2 765.1 86.5613 3443 GR MWD API 16.95 416.48 34.8477 3449 First Readin9 9828 9857.5 9828 Last Readin9 11578.5 11578.5 11552 First Reading For Entire File .......... 9828 Last Reading For Entire File ........... 11578.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 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 ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9827.5 10424.0 ROP 9858.0 10454.5 $ LOG HEADER DATA DATE LOGGED: 13-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10455.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 35.5 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BO~_.~OM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3kTURE (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 TOOL NUMBER TLG 002 3.750 9845.0 FLOPRO 8.60 65.0 9.2 22000 6.8 · 000 .000 .000 .000 .0 142.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9827.5 10454.5 10141 1255 ROP MWD010 FT/H 23 690.3 94.8652 1194 GR MWD010 API 17.71 416.48 36.807 1194 First Reading 9827.5 9858 9827.5 Last Reading 10454.5 10454.5 10424 First Reading For Entire File .......... 9827.5 Last Reading For Entire File ........... 10454.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Recora.~.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 ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NLTMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10425.5 ROP 10455.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 10459.5 10490.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPER3tTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 13-SEP-99 Insite 0 Memory 10490.0 79.5 79.5 TOOL NUMBER TLG 003 3.750 9845.0 FLOPRO 8.60 65.0 9.2 22000 6.8 .000 .000 .000 .000 .0 150.0 .0 .0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STA/~DOFF (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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10425.5 10490 10457.8 130 ROP MWD020 FT/H 7.8 41.7 17.7042 71 GR MWD020 API 19.51 47.42 27.6765 69 First Reading 10425.5 10455 10425.5 Last Reading 10490 10490 10459.5 First Reading For Entire File .......... 10425.5 Last Reading For Entire File ........... 10490 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 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 ....... 00/03/22 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: .5 ~ _ ~ FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10460.0 ROP 10490.5 $ 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 10497.0 10527.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AATD 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 TEMPER3kTURE (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 13-SEP-99 Insite 0 Memory 10527.0 79.5 80.5 TOOL NI/MBER TLG 003 3.750 9845.0 FLOPRO 8.65 65.0 9.5 22000 6.'6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel .0 272.5 .0 .0 DEPT FT .. 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 Name Service Unit Min Max DEPT FT 10460 10527 ROP MWD030 FT/H 4.7 50.9 GR MWD030 API 18.81 46.8 Mean Nsam 10493.5 135 16.8365 74 24.8712 75 First Reading 10460 10490.5 10460 Last Reading 10527 10527 10497 First Reading For Entire File .......... 10460 Last Reading For Entire File ........... 10527 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 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 ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW 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 STAd~T DEPTH STOP DEPTH GR 10497.5 10521.5 ROP 10527.5 10547.0 $ LOG HEADER DATA DATE LOGGED: 14-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10547.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 80.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE %~L TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MLrD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OFIMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3tTURE: 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 TOOL NUME .... TLG 002 3.750 9845.0 FLOPRO 8.60 65.0 9.2 22000 6.8 .000 .000 .000 .000 .0 154.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10497.5 10547 10522.3 100 ROP MWD040 FT/H 4.6 174.8 48.48 40 GR MWD040 API 18.79 25.3 21.6667 49 First Reading 10497.5 10527.5 10497.5 Last Reading 10547 10547 10521.5 First Reading For Entire File .......... 10497.5 Last Reading For Entire File ........... 10547 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ............. -.J..LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10522.0 ROP 10547.5 $ 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 10550.5 10577.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 14-SEP-99 Insite 0 Memory 10577.0 81.0 81.0 TOOL NUMBER TLG 002 3.750 9845.0 FLOPRO 8.60 65.0 9.2 22000 6.8 .000 .000 .000 .000 .0 146.0 .0 .0 MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STAi~-DOFF (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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10522 °10577 10549.5 111 ROP MWD050 FT/H 3.2 31.2 10.11 60 GR MWD050 API 16.95 24.12 21.1597 58 First Reading 10522 10547.5 10522 Last Reading 10577 10577 10550.5 First Reading For Entire File .......... 10522 Last Reading For Entire File ........... 10577 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE N-UMBER: 7 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10551.0 ROP 10577.5 $ 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 10555.5 10581.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TURE (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 15-SEP-99 Insite 0 Memory 10581.0 81.0 81.0 TOOL NUMBER TLG 002 3.750 9845.0 FLOPRO 8.65 65.0 9.2 22000 6.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 .0 146.0 .0 .0 ROP MWD060 FT/~. , 4 GR MWD060 API 4 1 68 1 68 Name Service Unit Min Max DEPT FT 10551 10581 ROP MWD060 FT/H 11 25.6 GR MWD060 API 19.07 19.46 Mean Nsam 10566 61 20.6375 8 19.283 10 First Reading 10551 10577.5 10551 Last Reading 10581 10581 10555.5 First Reading For Entire File .......... 10551 Last Reading For Entire File ........... 10581 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10556 . 0 10605 . 0 ROP 10581.5 10631.0 $ LOG HEADER DATA DATE LOGGED: 15-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10631.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 80.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP $ .... .~£URAL GAMMA PROBE BOREMOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MI/D VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 TLG 002 -- 3.750 9845.0 FLOPRO 8.60 65.0 9.0 22000 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 .0 142.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10556 10631 10593.5 151 ROP MWD070 FT/H 9.1 36.6 22.914 100 GR MWD070 API 19.75 36.18 25.0677 99 First Reading 10556 10581.5 10556 Last Reading 10631 10631 10605 First Reading For Entire File .......... 10556 Last Reading For Entire File ........... 10631 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ....... · .... STSLIB.009 .. - Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10605.5 ROP 10631.5 $ 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 10689.5 10719.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MI/D DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASLrRED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 15-SEP-99 Insite 0 Memory 10720.0 77.3 79.3 TOOL NUMBER TLG 002 3.750 9845.0 FLOPRO 8.70 65.0 9.2 22000 5.8 .000 .000 .000 .000 .0 146.0 .0 .0 HOLE CORRECTION (1. : 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 MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10605.5 10719.5 10662.5 229 ROP MWD080 FT/H 6.9 67.6 32.0136 177 GR MWD080 API 20.34 40.08 27.534 169 First Reading 10605.5 10631.5 10605.5 Last Reading 10719.5 10719.5 10689.5 First Reading For Entire File .......... 10605.5 Last Reading For Entire File ........... 10719.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY ..... VENDOR TOOL CODE START DEPTH GR 10690.0 ROP 10720.5 $ 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 11219.0 11249.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MIlD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 17-SEP-99 Insite 0 Memory 11250.0 76.9 85.8 TOOL NUMBER TLG 003 3.750 9845.0 FLOPRO 8.65 65.0 9.3 22000 6.2 .O0O .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 .0 150.0 .0 .0 GR MWD090 AP~ . ~ 4 1 68 Name Service Unit Min Max DEPT FT 10690 11249.5 ROP MWD090 FT/H 23.3 197.4 GR MWD090 API 17.72 82.31 Mean Nsam 10969.8 1120 97.4669 1059 26.1932 1059 First Reading 10690 10720.5 10690 Last Reading 11249.5 11249.5 11219 First Reading For Entire File .......... 10690 Last Reading For Entire File ........... 11249.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11219.5 11564.5 ROP 11250.0 11591.0 $ LOG HEADER DATA DATE LOGGED: 18-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWN-HOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11591.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 64.2 MAXIMUM ANGLE: 72.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE TOOL NUMBER TLG 002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 3.750 9845.0 FLOPRO 8.63 65.0 9.2 22000 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 .0 159.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11219.5 11591 11405.3 744 ROP MWD100 FT/H 16.7 765.1 105.282 683 GR MWD100 API 19.01 167.3 50.319 691 First Reading 11219.5 11250 11219.5 Last Reading 11591 11591 11564.5 First Reading For Entire File .......... 11219.5 Last Reading For Entire File ........... 11591 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 00/03/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File