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Home My WebLink About190-043Nolan 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: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187 END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' DATE 07/18/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL ENDICOTT MPI 2-18 (PTD 190-043); CD 1: Hiicorp_MPI2-18_PPROF_221un19_FINAL 7f'1+201911:20f h4 3 1 0 19 CD 2: Hilcorp_MPI_2-18_Processed-PPROF_22iun19 3 1 0 2 0 190043 RECEIVE® JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By; ' ! l f1t�/1V1 z-ts • • pr, tc2��3 Regg, James B (DOA) From: Larry McBride <Imcbride@hilcorp.com> Sent: Thursday, November 12, 2015 1:14 PM To: Regg, James B (DOA) 1\ell *`11(0 Subject: Deficiency Reports Attachments: CORRECTED DEFICIENCY REPORTS.pdf Mr. Regg, Guy Cook asked me to pass these directly to you. Thanks Larry McBride Hilcorp Endicott Pad Operator Office: 907-659-6530 Control Room: 907-659-6700 SCANtEO 5 i F: 1 0 • 1 I 1 State of Aiaska 1 i 00 a nri ei?s(iculcerkpit!on 1';nrnrn1F,Fin 1 1 T.,ii.--—- -- ,..-,7- — U.Liii-leilL1 eleptAlL I I I - Date: „.....:21A Operator: 1-11icolp La., Type Inspection: SVS ti 1 Operator Rep: Larry ivieBride inspector: Civ Cook I i ------- - 1 I pncitinn• I I or_ Phcr,e: ino7 an.„A-7rin (date): Follow Up Required: 1 t I Detailed Description of Deficienciesi I Date Corrected i 1 2-18 needs a OA valve handle. The valve cannot be open or shut. - 1 I I I /1- /0 /5 ' I 1 i I I I I I I I III 1 I I i 1 I I I 1 I I I I I I i 1 I I I I , I I I I I I I I I I I I I I I I I I I I 1 I 1 I 1 I I I I I i I I I -- d 414,4,„,.. Operator Operator Rep Signatures: / C-, 7.), e2.0 4._AOGCC Inspector *After signing,a c.., of this form is to be left with the operator. Follow-up instructions I Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the I "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must reauested and accompanied by justification(Attention:Inspection SupPrvisor). 1 I , e- -iiure to broci vie Ine required documen ration oi corrective actions consmui.es a vibration or 20 r:v:kr....2.. ...stio and is subject ti: oe..rnent nte2,2 55 entrct-ZiCelOrulr AM.2 .5,3 Revised 3/9/2015 • 191 E ` e , Post Office Box 244027 JUL 3 0 } Anchorage,AK 99524-4027 Hilcorp Alaska,LLC G 01,`3 3800 Centerpoint Drive Suite 100 GCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission I C'D o 3 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request iktltd° Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig i New API_WeIINo PermitNumber WeilName _ WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/I17 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/020 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/122 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 [1890340 DUCK IS UNIT MPI 2-22/114 2-22 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Iff 0 "OI1L~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other Complete COMMENTS: Scanned by:~ Bran Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. " Y Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r' ArAMED SEP20 0012 . May 22, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission _ O (4-3 333 West 7 Avenue � Anchorage, Alaska 99501 • Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, / ,l Mehreen Vazir BPXA, Well integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft _ bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2-06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / Q-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 _____.7 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIGi»JS CEIVED I G 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved ProgramD Repair WellŒ Pull TubingD Operation Shutdown 0 Plu!:l PerforationsD Perforate New PoolO Perforate 0 Stimulate 0 WaiverD OtherD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development IXI ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceD 9. Well Name and Number: 2-18/ L-16 10. Field/Pool(s): Endicott Field / Endicott Pool 6. API Number 50-029-22032-00-00 55.10 8. Property Designation: ADL-034633 11. Present Well Condition Summary: Total Depth measured 11465 feet true vertical 10504.0 feet Plugs (measured) Tagged TD @ 11081 (05/08/2006) Effective Depth measured 11081 feet Junk (measured) 4-1/2" BKR QUIKDRILL Plug, Milled & Pushed to true vertical 10174.0 feet 10206' (toD ofTBG stub (11/08/2006) Casing Length Size MD TVD Burst Collapse CONDUCTOR 93 30" Conductor 38 131 30.0 131.0 SURFACE 2459 13-3/8" 68# NT -80 37 - 2496 37.0 - 2496.0 5020 2260 INTERMEDIATE 8912 9-5/8" 47# NT80S 36 - 8948 36.0 - 8370.0 6870 4760 PRODUCTION 1598 9-5/8" 47# NT95HS 8948 - 10546 8370.0 - 9711.0 6870 4760 LINER 1183 7" 29# NT95HS 10279 - 11462 9481.0 - 10502.0 8160 7020 Perforation depth: Measured depth: 10851-10859,10863-10871,10952-10960, 10972-10980, 11032-11036, 11060-11065 True vertical depth: 9976-9982,9986-9993,10062-10069, 10080-10086, 10131-10135, 10155-10160 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# Cr80 4-1/2" 12.6# L-80 @ 35 @ 10200 @ 10141 @ 10232 @ 1515 10206 1031S Packers & SSSV (type & measured depth): 9-5/S" Baker Packer 9-5/S" Baker Packer 4-1/2" HES BBE SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: IA Cement Saueeze 8f!. 2 j 2006 Prior to well operation: Subsequent to operation: Oil-Bbl WellSI WellSI ReDresentative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 13 Copies of Logs and Surveys run _ Daily Report of Well Operations _ 2S. 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ ServiceD 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWay'ne R. Schnorr Signature h..?I~ ~~ Title Phone 564-5174 Date 11/15/06 Form 10-404 Revised 4/2004 AWGRS 09/10/2006 AWGRS 09/11/2006 AWGRS 09/12/2006 AWGRS 09/22/2006 AWGRS 1 % 1/2006 AWGRS 1 % 1 /2006 AWGRS 10/02/2006 AWGRS 1 0/02/2006 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY *** WELL SI ON ARRIVAL *** (PULL TTP) RIG UP WORK MASTER VALVE PUT HEATER ON VALVE. (PULL PX PLUG) PULLED PRONG FROM 10,150' SLM CHANGE FROM .108 TO .125 WIRE PULLED PX-PLUG FROM 10,150 SLM. RIG DOWN UNIT & CRANE *** TURN WELL OVER TO DSO *** TIO = 1180/180/140. Temp = SI. TBG & IA FL (for EL). TBG FL @ 2460' (38 bbls). IA FL @ surface. ***WELL SHUT IN UPON ARRIVAL*** T/I/0=240/100/200. ATTEMPT TO SET BAKER 4-1/2" CEMENT RETAINER. LRS FLUID PACKED WELL PRIOR TO RIH WITH CEMENT RETAINER. SWAB VALVE AND MASTER VALVE DO NOT OPEN COMPLETELY. UNABLE TO RIH WITH CEMENT RETAINER. WORKING ON VALVES. T/I/O =1200/200/120 temp=SI Assist E-Line (Prod CSG Sgueeze) Pumped 40 bbls sea water and 4 bbls 60/40 methanol down TBG. SEL unable to get through master valve. Pumped 6 bbls diesel for freeze protect. FWHP's=1100/200/120 ***WELL SHUT IN UPON ARRIVAL*** T/I/0=240/100/200. ATTEMPT TO SET BAKER 4-1/2" QUICK DRILL PLUG. LRS FLUID PACKED WELL PRIOR TO RIH WITH PLUG. SWAB VALVE AND MASTER VALVE DO NOT OPEN COMPLETELY. UNABLE TO RIH WITH Quikdrill. UNABLE TO GET VALVES TO OPEN FAR ENOUGH TO GET TOOL PAST. WELL LEFT SHUT IN. TURNED OVER TO DSO. JOB INCOMPLETE. AWGRS 10/07/2006 ***WELL S/I ON ARR.*** SPOT UNIT & CRANE WEATHER STAND BY ***WEATHER STAND BY *** AWGRS 10/10/2006 *** WELL SI ON ARRIVAL *** (WH Repair) RIH W/ 3.80 CENT. DOWN TO 20' POOH CHANGE TOOLS, RIH 1 7/8" TS, QC, 4.5" BL-BRUSH, 3.812" , 3.85" , 3.875" GAGE RING THROUGH TREE. SET 4.5 XX-PLUG @ 10,096' SLM BLEED OFF 600# SET 4.5 XX-PLUG @ 1,496' SLM BLEED WELL OFF TO 0 PSI GOOD TEST. AWGRS 10/11/2006 AWGRS 10/13/2006 AWGRS 10/14/2006 (WH repair) RIG DOWN UNIT & CRANE ***TURN WELL OVER TO DSO *** ***WELL S/I ON ARRIVAL*** (Post WH repair) PULLED 4.5 XX PLUG FROM 1496' SLM. PULLED 4.5 XX PLUG FROM 10104' SLM. (Post WH repair) BOTH 4.5 XX PLUGS OUT OF HOLE. ***WELL LEFT SHUT IN*** NOTE: DRIFT OK FOR E-LlNE TO SET COMPOSITE PLUG @ 9755' EMD. Page 1 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS AWGRS 10/17/2006 T/I/O=420/190/110 MITTBG 3000 psi PASSED(Master valve repair, production casing Sqz) (Shut in) Pumped 18.2 bbls of 55* 60/40 meth water down TBG to reach 3000 psi for MIT IA 1st test 1st 15 min lost 160 psi 2nd 15 min lost 70 psi for a total of 230 psi in 30 min bleed TBG psi down Final Whp's=10001 190/80 ***** SEVERAL IA HANGER STUDS NOT FULL NUT ****** AWGRS 10/17/2006 RUN BAKER QUICKDRILL. TOP OF PLUG SET AT 9755'. RIGGED DOWN BEFORE JOB COMPLEDED TO LEAVE FOR 9ES RIG JOB CALL IN. TUBING PUNCH, INJECTIVITY TEST, AND SET COMPOSITE SQUEEZE PACKER STILL REMAIN TO BE DONE. ***** JOB NOT COMPLETE***** AWGRS 10/18/2006 WELL SHUT IN ON ARRIVAL. SSV OPEN ON ARRIVAL. DID NOT RIG UP ON WELL. WELL SHUT IN ON DEPARTURE. SSV OPEN AWGRS 10/24/2006 PREPARE TO SHOOT TUBING PUNCHER 9734-9740 SPOT EQUIPMENT AND HELD PJSM. WAIT ON WELL SUPPORT TO RIG UP TO PUMPING SUB NOW ON TREE. WAITING ON DSM. AWGRS 1 0/25/2006 TIIIO = 40010/120 Assist E-line. Eline set BP, punched 6' of holes in tubing above it. LRS Established Injectivity of 4.1 bpm @ 1750 down lA, through holes, up tubing, down flowline. Established injectivity of 5.0bpm @ 1700psi down tubing, Up lA, to tiger tank. Freeze protected S-riser wI 2.5bbls 60/40. Pumped 25 bbls 60/40, starting at 2 bpm increasing to 5 bpm, down TBG taking returns up IA to tiger tank. AWGRS 1 0/25/2006 SHOT 6' TUBING PUNCHER FROM 9734' - 9740' LRS ESTABLISHED INJECTIVITY RATE SET HES 4-1/2" COMPOSITE PACKER AT 9670' LRS TESTED INJECTIVITY AGAIN DOWN TUBING THEY WERE ABLE TO PUMP AT 5 BPM, 1200 PSI. TESTED PACKER BY PUMPING DOWN IA AT 3000 PSI. NO INCREASE IN TUBING PRESSURE. FINAL TI 110 = 01 601 120. AWGRS 1 0/26/2006 Pressured up IA w/9.3 bbls 60/40 (total). Established LLR of .35 bpm @ 3000 psi with 5 bbls 60/40. Bled WPS's to tiger tank. Freeze protect hardline to tank w/2 bbls 60/40. FWP's = 200/60/60 AWGRS 1 0/26/2006 STANDBY WHILE LITTLE RED COMPLETES PUMPING FOR LLR. RIG DOWN JOB COMPLETE. WELL LEFT SHUT IN, TURNED OVER TO DSO. AWGRS 11/06/2006 Heat Upright tanks of fluid for Coil Job in progress AWGRS 11/06/2006 CTU #5. Production Casing Squeeze. MIRU CTU. AWGRS 11/07/2006 CTU #5. Production Casing Squeeze. RIH tag SQZ PKR and corrected depth to 9670' PUH 20' flagged pipe. Circ out tubing w. 120 bbls 160*1 % KCL Pumped 6 bbls 60/40 freeze protect down backside of CT, Circ down CT taking returns from IA w. 515 bbls of 160*1% KCI. Successfully performed no flow test on IA. Successfully pressure tested cement retainer to 400 psi. Pumped 20 bbls of diesel down CT. AWGRS 11/07/2006 Heat upright tanks for Coil Page 2 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS AWGRS 11/08/2006 CTU #5. Production Casing Squeeze. Put 162 bbls of 15.8 Class G Cement in IA through SQZ PKR est cement top in IA @ 6764', 5 bbls FW, 351 bbls 1 % KCI w. 0.21gal/bbl EC1124 inhibitor @ 114', Diesel to surface, Contaminated remaining cement in tubing to flag on CT @ 9650' POOH @ 60 % wasing jewelry on way out. Wait on compressive strength of cement in UCA until it reaches> 2000 psi. AWGRS 11/09/2006 CTU #5. Production Casing Squeeze. MIT-IA to 3500 psi (Passed) RIH w. 3.79 six bladed mill, tag and mill hard cement @ 9650' CTM. Mill to 9745' using XS 1 % KCI and biozan sweeps. Circulated bottoms up with biozan sweep to prepare to perform M IT - T. AWGRS 11/10/2006 CTU #5. Mill Cement. *** Continued from WSR 11/09/2006 *** MIT-T to 3500 psi. (Passed) Milled remaining cement and composite plug @ 9755' corrected CTM, continued down to 10180' POOH Freeze protect well. RD *** Job Complete*** FLUIDS PUMPED BBLS 6 Diesel --- PT Surface Equipment 387 60/40 Methanol Water 43 Diesel I 40 Sea Water I 10 Fresh Water 321 1 % XS KCL wI 0.6% Safe Lube 331 1 % KCL Water wI 0.21 Qal/bbl EC1124 Inhibited 660 1 % KCL Water 1240 1 % Extra Slick KCL Water 56 2# Biozan 167 15.6 PPG Class "G" Cement 3261 TOTAL Page 3 . TREE = 4-1/16" CNV (5000 PSO ~TES: 4_1/2" CHROMETBG WELLHEAD = 13-5/8" FMC (5000 PSI) ***S TOO DAMAGE@ TOP OF OLDTBG (10200' ,ACTUATOR= END2-18 SLM) (SEE OS/25/06 VIDEO LOG FOR DETAILS). KB. ELEV = 55.1' UNABLE TO GET ANY TOOLS THRU DAMAGBJ BF. ELEV = 16.2' SECTION KOP= Max Angle = 44 @ 10200' . 1 1516' H4-1/2" HES HXO SVLN, 10= 3.813" I Datum MD = GAS LIFT MANDRELS Datum TVD = 8800' SS ..A ST MO lVD DE\! lYÆ VLV LA TCH PORT DATE 13-3/8" CSG, 68#, NTSO CYHE, ID = 12.415" I - 5 3592 3591 5 MMG DMY RK 0 04/19/06 2496' r 4 5509 5503 12 MMG DMY RK 0 04/18/06 L 3 6917 6734 37 MMG DMY RK 0 04/18/06 2 8496 8003 37 MMG DMY RK 0 04/18/06 1 EST TOP OF IA CEMENT (11/0S/06) I 6764' 1 10030 9271 33 MMG OÆN* 06/03/06 ~ **GLM CEMelTBJ 11/8/06 DURING IA CMT SQZ 19-5/8" CSG, 47#, NT80S, 10 = S.681" I 8948' , , G 9385' - 9755' HCEMENT SHEATH, ID = 3.79" (11/0S/06) I ~ , ) 9790' HTOPOF IA CEMENT (LOGGED 06/20/06) I ~) ) . 10110' H4-1/2" HES X NIP, 10 = 3.813" I MINIMUM 10*** = 3.725" @ 10306' ~:} · í. ~ ~ I 10141' 1---19-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3.870" I 4-1/2" XN NIPPLE ~ 4-112" TBG, 12.6#, 13CR80 V AM 10196' I- ~ 10175' 1-14-1/2" HES X NIP, 10 = 3.813" I H 10200' 1-14-1/2" TBG STUB (DMS 04/13/06) I TOP, .0152 bpf, ID = 3.958" QUIKDRILLlFASDRILL PLUGS, MILLED & PUSHED 10206' Y 10206' H9-5/S" X 4-1/2" UNIQUE OVERSHOT I TO TOP OF TBG STUB 06/0S/06 & 11/08/06 I · 10224' 1-14-1/2" SWS PARKER X NIP, ID = 3.813" I · [ -~ 10231' HBKRLATCHASSYITBG ANCHOR,ID= ????? I ~ ~ 10232' 1-19-5/8" BKR PKR, 10 = 3.99" I TOPOF 7" LNR I 10279' lEI II I · 10285' H4-1/2" PARKER SWS NIP, 10 = 3.813" I 14-112" TBG, 12.6#. L-80, .0152 bpf, 10 = 3.958" I 10318' ~, I 10306' H4-1/2" XN NIP, 10 = 3.725" I 19-5/8" CSG, 47#, NT95HS,ID = 8.681" I 10546' I ÆRFORA TION SUMMARY \ ' I 10318' H4-1/2" WLEG, 10= 3.958" I REF LOG: DLL-GR ON 04/18/90 ~ I 10318' H ELMO TT LOGGED ON ??/??/?? I ANGLE AT TOP ÆRF: 31 @ 10851' H MARKER JOINT I Note: Refer to Production DB for historical perf data I 10728' SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10S51 - 10859 0 3-3/8" 6 10863 - 10871 0 I 3-3/8" 4 10920 - 10946 S 3-3/8" 4 10952 - 10960 0 3-3/8" 4 10960 - 10966 S 3-3/8" 4 10972 - 10980 0 3-3/8" 4 10980 - 10982 S 3-3/8" 4 11002 - 11032 S 2-7/8" 6 11032 - 11036 0 3-3/8" 4 11040 - 11060 S 3-3/8" 4 11060 - 11065 0 3-3/8" 4 11065 - 11066 S 3-3/8" 4 11070-11074 S 3-3/8" 4 11077 - 11090 S 11081' SLM HFU (?) (TAGGEDw/SL BAILER 05/08/06) I I UNKNOWN I FASDRILL REMNANTS MILLED & PUSHED I I PBTD I 11377' TO BTM 04/14/06 (TAGGED 05/08/06) 7" LNR, 29#, NT95HS TKC, .0371 bpf, 10 - 6.184" 11462' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNrr 04/21/90 ORIGINAL 10/25/06 JMF/PA G TBG PUNCH, FASDRILL SET WELL: 2-18/L-16 04120/06 D16 RWO 11/08/06 DMSITLH IA GMT SQZ & PLUGS MILLED ÆRMrr No: 1900430 OS/25/06 TMNlPJC TBG DAMAGE API No: 50-029-22032-00 06/03/06 /TLH GLV Cia SEC T N R E 06/08/06 SRB/PJC PKR SQZ / MU QUIKDRILL 06/20/06 JCIINTLH DRLG DRAFT CORRECTION BP Exploration (Alaska) 10/02/06 Schlumberger RECEIVED Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth OCT 0 4 2006 NO. 3980 --\Jaska Oil & Gas ConS. Ccmrrd$$icn Anchorage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI! J b# L 0 o BL CI CD e 0 09 escrlptlon ate o or L5-28A 11320994 STATIC PRESSURE LOG 07/30/06 1 P2-50B 11212876 LDL 07/17/06 1 H-26 11225990 LDL 07/09/06 1 K-02D 11209593 SCMT 07/20/06 1 J-09A 11321005 LDL 08/29/06 1 D.S.04-19A N/A INJECTION PROFILE 08/02/06 1 J-06 11321006 PRODUCTION PROFILE 08/29/06 1 G-24 N/A SCMT 08/08/06 1 2-18/L-16 11225986 LDL 07/04/06 1 F-05A 11216212 MCNL 09/03/06 1 1 . . Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .sr'l\. ·,.NNLiL} ::¡,p~., ~"' "0.; -..~~,.,~ r ';) 1.'''_:; /00-DLß ,. :... 1/J(hh STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 4 2006 REPORT OF SUNDRY WELL OPERA TIONe Oil & Gas Cons. Commission . q¿ RECEIVED A 1. Operations Performed: ~- Abandon 0 Repair Weill&! PluQ PerforationsD Stimulate 0 OtherD Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD 190-0430 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22032-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.10 2-18/ L-16 8. Property Designation: 10. Field/Pool(s): ADL-034633 Endicott Field 1 Endicott Pool 11. Present Well Condition Summary: Total Depth measured 11465 feet true vertical 10504.0 feet Plugs (measured) 4-1/2" PX Plug set@ 10160' SLM (06/17/06) Effective Depth measured 11377 feet Junk (measured) 4-1/2" BKR QUIKDRILL Plug, Milled & Pushed to true vertical 10429.0 feet 10206' (too of TBG stub (06/08/2006) Casing Length Size MD TVD Burst Collapse CONDUCTOR 93 30" Conductor 38 - 131 30.0 - 131.0 SURFACE 2459 13-3/8" 68# NT -80 37 - 2496 37.0 - 2496.0 5020 2260 INTERMEDIATE 8912 9-5/8" 47# NT80S 36 - 8948 36.0 - 8370.0 6870 4760 PRODUCTION 1598 9-5/8" 47# NT95HS 8948 - 10546 8370.0 - 9711.0 6870 4760 LINER 1183 7" 29# NT95HS 10279 - 11462 9481.0 - 10502.0 8160 7020 SCANNEll) SEP 2 0 200B Perforation depth: Measured depth: 10851-10859,10863-10871,10952-10960, 10972-10980, 11032-11036, 11060-11065 True vertical depth: 9976-9982,9986-9993,10062-10069, 10080-10086, 10131-10135, 10155-10160 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# Cr80 @ 35 - 10206 4-1/2" 12.6# L-80 @ 10200 - 10318 Packers & SSSV (type & measured depth): 9-5/8" Baker Packer @ 10141 9-5/8" Baker Packer @ 10232 4-1/2" HES BBE SSSV @ 1515 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: WellSI --- -- 290 2820 Subsequent to operation: WellSI -- - 170 250 14. Attachments: 15. Well Class after proposed work: Exploratory(] Development[! ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~~ ~ Y... 1/ Phone 564-5174 Date 9/7/06 Form 10-404 Revised 4/2004 fG'~IAf RBDMS BFL SEP 1 8 2006 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/07/2006 ***WELL S/I ON ARRIVAL*** (post rwo/pre packer sqz) PULLED 4.5" DSSSV @ 1492' SLM. PULLED B&R & RHC BODY @ 10170' SLM. 05/08/2006 PULLED 4.5" RHC BODY @ 10179' SLM. RAN 3.70" CENT WITH S. BAILER. TD @ 11081' SLM. S. BAILER EMPTY. ***WELL LEFT SHUT IN & PAD NOTIFIED*** 05/14/2006 T/I/O= 2820/290/100. Temp= SI. T,IA, & OA FL's (pre-Fas drill). Tubing FL @ 10195' (155 bbls) below sta# 1. IA FL @ surface. OA FL near surface. 05/15/2006 RIGGED UP FOR SETTING 4-1/2" BAKER QUIKDRILL COMPOSITE FRAC PLUG. LRS KILLING WELL. 05/15/2006 ATTEMPT TO SET PLUG, UNABLE TO WORK PLUG THROUGH OLD TUBING STUB @ 10208', PLUG HAD MARKS ON THE BOTTOM, MADE ANOTHER ATTEMPT W/ROUNDED BOTTOM W/SAME RESULTS. PAD OP NOTIFIED UPON DEPARTURE 05/16/2006 T/1I0=2500/300/120 Assist E-line (set plug) (Post PWO) Pumped 3 bbls Meth, 232 bbls 1% KCL Water and 20 bbls diesel for well kill. E-Line could not get TBG plug set. MIT IA Failed-- -Established IA LLR of 0.35 bpm @ 2980 psi for 10 min. Final WHP's=420/600/100 05/18/2006 RIH W/3.75 SWEDGE DOWN TO 2.875 CENT. TAG @ 10,190' SLM RIH W/3.74 LlB.NO DEFINITIVE MARKS ON LIB 05/19/2006 RAN 2" TAPPERED LIB-RETURNED W/ MARKS ON SIDE. RAN KJ ABOVE 3.70" SWEDGE & 1.25" SAMPLE BAILER TAG 10190' SLM, RETURNED W/ SAMPLE OF ASPHALTINE LIKE SUBSTANCE. RAN 10' x 2.25" DRIVE DOWN BAILER W/ FLAPPER MULE SHOE, RETURN W/ SMALL SAMPLE OF SAME, SMALL MARK ON EDGE OF MULE SHOE. RAN 2' x 1-7/8" STEM ABOVE 3.70" CENT & 1.25" S. BAILER TO 10190' SLM, SAMPLE OF SAME MATERIAL, NO MARKS ON CENT OR BAILER. ***WELL LEFT S/I*** OS/21/2006 CTU #4, Mill/ Dress Tbg Stub; MIRU unit. MU BKR 3.8" OD parabolic diamond speed mill and 3.8" OD string mill. Tag obstruction at 10205' CTM (down). Mill on obsturction for 17 minutes w/2.5K on bit 300-400 psi of motor work. Occasional 500# jerk on weight indicator, but no real progress. Appear to mill .3 feet. No sign of wear on mill. OS/25/2006 VIEW DAMAGED TBG -6 BELOW TOP OF OLD TBG STUB. DAMAGE AT 10,206'RKB. TOP OF TBG STUB AT 10,201 'RKB. OVERSHOT LOOKS TO BE PLANTED 3' OVER OLD TBG. HOLE TORN OUT OF TBG WALL. 05/30/2006 TII/0=2850/340/120 Well kill (packer squeeze) Pumped 20 bbls inhibited 60/40 methanol, 328 bbls sea water, followed by 52 bbls 60/40 inhibited methanol. FWHP's=200/280/0 Page 1 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/01/2006 T/I/O 2400/340/100.3.6" QUICKDRILL PLUG SET AT 10,080 FT. FINAL T/I/O after Tool OOH 2500/350/150 PE Bled Pressure down to 2000 psi and waited 30 minutes to test Composite Plug and no build-up (Passed). RDMO. Pad Operator and PE continue bleeding tubing down to 500 psi. No pressure build up. T/I/O after bleed to test Plug = 500/350/150 Leave well SI for Slickline. 06/02/2006 T/I/0=300/340/140 Load & Test / MIT tubing to 2800 psi., PASSED (Packer Squeeze) Pumped 5 bbls neat meth, 125 bbls 1 % KCL and 8 bbls DSL. to load. TBG . TBG.gained 20 psi in 15 min., and 40 psi in second 15 minutes. PASS Bleed TBG. to 500 psi. Final WHP's=500/350/130 06/03/2006 T/I/O= CMIT TXIA 2000 psi FAILED(Packer Squeeze) Spear in to TBG W/5 bbls meth followed by 15.4 bbls diesel to reach 2000 psi for CMIT TXIA Re-psi up w/9.4 bbls of meth 1 st test 1 st 15 min lost 520/500 start LLR test psi job in progress 06/03/2006 ***JOB CONTINUED FROM 6-2-06*** SET 4.5" X-LOCK CATCHER WITHOUT KEYS! 10065' SLM. PULLED 1.5" DGLV FROM STA #1. LEFT OPEN FOR CIRCULATION. PULLED CATCHER. RDMO ***WELL LEFT SHUT IN & WELL TECH NOTIFIED*** 06/04/2006 CMIT TXIA 2000 psi FAILED (Packer Squeeze) Attempted LLR test down TBG Pumped 6.5bbls of meth to reach 3025 psi pumped 3.5 bbls of meth and 6.5 bbls of diesel at .35 bpm for a total of 10 bbls at 3025 psi Attempted LLR test pumping down TBG at 2000 psi but to small for big pump bleed 7 bbls back TXIA psi down Final Whp's=500/260/100 06/05/2006 CTU #5, Pkr. Sqz; ... RIH with 2.5" BDN (.75" ball). Circulate Tbg x IA with 1%KCL. Attempt to fluid pack well, significant gas in returns. Met with plant personnel to discuss venting gas and other options for taking returns when attempting to fluid pack well. Cannot take returns to tanks at this time because of an unfavorable wind direction. Cannot take returns to system because of potential negative impact on production. Operations to fluid pack suspended until conditions change. POOH. Secure well. Pressure test flowline and lubricator..RIH with 2.5" BDN. 06/06/2006 CTU #5, Pkr Sqz.; RIH with 2.5" BDN. Circulate tubing and IA with 1 % KCL. Fluid pack IA with 292 bbls Inhibited KCL followed by 211 bbls 1 % KCL and 25 bbls diesel. Tag plug and correct depth to 10080'. PUH and flag pipe at 10070'. Pump and lay in 15.7 bbls cement. Pull to safe. Circulate 11.5 bbls cement into IA. WHP and lAP balanced. POOH filling void age. OOH, MU Wfd 27/8" motor and 3.70 junk mill.. RIH. 06/07/2006 CTU #5, Mill Cmt; RIH wlWFD 2 7/8" motor and 3.70" - 5 blade concave junk mill. Correct depth at 8800' flag. Wait for lab cement sample to reach adequate compressive strength. RIH milling. Hit a few hard stringers between 9535' and 9655'. First hard cement found at 9891' (138' above GLM #1). Milled hard cement to 10000' while pumping several Biozan sweeps. Sweeps had heavy solids loading. Made short trip to 5765' to clean hole. RBIH tagged shallow at 9839'. Milled debris field to 10000' with several more sweeps. Milled t010015', short tripped. Milled to 10031'. Page 2 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/08/2006 CTU #5; Mill; Mill CMT to 10070'. MIT tubing and IA to 2000 psi. Tubing passed. IA LLR = 0.14 bpm to 0.16 bpm. MITIA to 3000 psi. LLR = 0.19 bpm. Perform No-Flow test on IA- failed. IA flowed at 0.16 bpm to atmosphere. Town elected to keep Quick-Drill tubing plug in place. RBIH to clean bottoms up and sweep hole. Dry tagged fill at 10067'. Circulated to 10070' pumping Biozan sweep. PUH off bottom and lost circulation. Confirmed plug lost integrity. RBIH and tagged plug at same depth (10070'). Set weight down 14 k#, plug would not move. Appears coil had stretched 11' to 12' since original depth control flags were painted. Proceeded to mill push plug to 10199' ctmd. POOH. FP well with at least 500' of 50/50 methanol. Checked injectivity into well; 3.0 bpm at 950 psi WHP. RD CTU #5. *** Job Complete *** 06/15/2006 ***WELL SI ON ARRIVAL *** RIH W/3.80" CENT & 3.75" BLB. RIH W/4.5" PX PLUG BODY, UNABLE TO GET PAST 5400'. POOH. RIH W/3.80" CENT, 4.5" BLB, & 3.75' GR. 06/16/2006 TII/O= 1150/180/120 Assist S/L with brush and flush. Pumped 192 bbls of diesel. Final WHP=800/160/50. 06/16/2006 LRS PUMPED 192 BBL DIESEL. BRUSH TUBING. RIH TO SET 4.5 TTP @ 10,160' SLM 06/17/2006 SET TTP @ 10,160' SLM (GOOD CHECK SET TEST) SET PX-PRONG. ***TURN WELL OVER TO DSO*** 06/18/2006 T/I/0=40/180/100 MIT TBG PASSED @ 3000 psi. (Shut In)(Post RWO) TBG pressured up w/17.0 bbls Diesel pumped. TBG lost 0 psi in 15 min. w/ total loss of 0 psi in 30 min. Final WHP's=0/180/100 06/18/2006 ***CONTINUED FROM 06-17-2006*** SET 4.5 PX PLUG, RAN CHECK SET, GOOD SET INDICATED. RAN PX-PRONG. DRAW DOWN WELL FROM 100 PSI TO 10 PSI, WAIT 30 MIN. WELL PSI 10 PSI- GOOD TEST. ***TURN WELL OVER TO DSO *** 06/20/2006 RAN SCMT TO LOCATE TOP OF CEMENT FOUND TOP OF CEMENT AT 9790' HAD DIFFICULTIES RUNNING THROUGH TIGHT SPOT AT 8500'. 07/04/2006 T/I/O 270/180/100. LEAK DETECT TEMPERATURE PROFILE FROM SURFACE TO 10,175 FT. PRODUCTION CASING LEAK OBSERVED AT 7005 FT. *******JOB COMPLETE****** 07/04/2006 T/I/O = 250/200/100 Assist E-Line with Leak Detect Log (post packer squeeze) Pump 45 bbls of 60/40 methanol down IA @ .4 bpm while E-Line POOH. FWHP's=250/200/220 08/04/2006 T/I/O= 250/170/100. Temp= SI. Tubing & IA FL (pre EL). Tubing FL near surface. IA FL @ surface. Page 3 . . 2-18/ L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 5 Neat Methanol 52.4 Methanol 117 60/40 Inhibited Methanol 62 50/50 Methanol 1432 1 % KCL Water 990 1 % XS KCL wi Safe Lube 292 1 % KCL Water wi Inhibited 708 Sea Water 45 Fresh Water 161 Biozan 348 Diesel 11.5 15.8 PPG Class "G" Cement 4207.4 TOTAL Page 4 , ~OTES: 4-1/2" CHROMETBG TREE = 4-1/16" CWII (5000 PSI) WELLHEAD = 13-5/8" FMC (5000 PSQ ...·SEVERETBG DAMAGE@ TOP OF OLDTBG (10200' ACTUA TOR = END2-18 SLM) (SEE OS/25/06 VIDEO LOG FOR DETAILS). KB. ELEV = 55.1' UNABLE TO GET ANY TOOLS THRU DAMAGED BF. ELEV = 16.2' SECTION KOP= - Max Angle = 44 @ 10200' ~ 1516' H4-1/2" HES HXO SVLN, ID = 3.813" I Datum MD = GAS LIFT MANDRELS Datum TVD = 8800'SS ) ~ ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 5 3592 3591 5 MMG DMY RK 0 04/19/06 113-3/8" CSG, 68#, NTBO CYHE, ID = 12.415" I 2496' r L 4 5509 5503 12 MMG DMY RK 0 04/18/06 3 6917 6734 37 MMG DMY RK 0 04/18/06 ~ , 2 8496 8003 37 MMG DMY RK 0 04/18/06 19-5/8" CSG, 47#, NT80S, ID = 8.681" I 8948' 1 10030 9271 33 MMG OÆN· 06/03/06 ··GLM CEMENTED 6/20/06 DURING PKR CMT SQZ ~ 9790' 1-1 TOP OF IA CEMENT (LOGGED 06/20/06) I MINIMUM ID*** = 3.725" @ 10306' . I 10110' -14-1/2" HES X NIP, ID = 3.813" I 4-1/2" XN NIPPLE ~ C8: - 10141' -19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" I .2S. I 10175' H4-1/2" HES X NIP, ID = 3.813" I 4-1/2" TBG, 12_6#, 13CR80 V AM 10196' l- i"'---- 10160' SLM 1-14-1/2" PX PLUG (06/17/06) I TOP, .0152 bpf, ID = 3.958" -- r-, 10200' -14-112" TBG STUB (DIMS 04/13/06) I .......-1 I BKR QUIKDRILL PLUG, MILLED & PUSHED 10206' Y 10206' -19-5/8" X4-1/2" UNIQUE OVERSHOT I TO TOP OF TBG STUB 06/08/06 . 10224' -14-1/2" SWS PARKER X NIP, ID = 3.813" I :::: ~ 10231' -1 BKR LATCH ASSY /TBG ANCHOR, ID = ????? I lz~ .2S. 10232' -19-5/8" BKR PKR, ID = 3.99" I TOPOF7" LNR I 10279' 11IIII . I . 10285' -14-1/2" PARKER SWS NIP, ID = 3.813" I I I 10306' -14-1/2" XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6#. L-80, .0152 bpf, 10 = 3.958" H 10318' 9-5/8"CSG,47#, NT95HS.ID=8.681" I 10546' ~ 10318' -14-1/2" WLEG, 10 = 3.958" I ~ 1 10318' H ELMD TT LOGGED ON ??/??I?? I ÆRFORA TION SUMMARY REF LOG: DLL-GR ON 04/18/90 H MARKER JOINT I ANGLE AT TOP PERF: 31 @ 10851' 10728' Note: Refer to Production DB for historieal perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 6 10851 - 10859 0 I 3-3/8" 6 10863 - 10871 0 3-3/8" 4 10920 - 10946 S 3-3/8" 4 10952 - 10960 0 3-3/8" 4 1 0960 - 1 0966 S I 3-3/8" 4 10972 - 10980 0 3-3/8" 4 10980 - 10982 S 3-3/8" 4 11002 - 11032 S 2-7/8" 6 11032 - 11036 0 I 3-318" 4 11040 - 11060 S 3-3/8 " 4 11060 - 11065 0 0 3-3/8 " 4 11065 - 11066 S 3-3/8" 4 11070 - 11074 S ~ 11081' SLM I- FLL (?) (TAGGED w ISL BALER 05108106) I 3-3/8" 4 11077 - 11090 S 1 PBTD I 11377' I UNKNOWN I FASDRILL REMNANTS MILLED & PUSHED I TO BTM 04/14/06 (TAGGED 05/08/06) 7" LNR, 29#, NT95HS TKC, .0371 bpf, ID = 6.184" 11462' DATE REV BY COMMENTS DATE REV BY COMMENTS 8'JDICOTT UNIT 04/21/90 ORIGINAL 06/08/06 SRB/PJC PKR saz / MILL QUIKDRILL WELL: 2-18/L-16 04/20/06 D16 RWO 06/18/06 ITLH SET PX PLUG PERMIT No: '1900430 05/05/06 TWS/PJC PULLED DSSSV 06/20/06 JCMlTLH DRLG DRAFT CORRECTION API No: 50-029-22032-00 05/25/06 TMNlPJC TBG DAMAGE 06/21/06 JCMI1LH TOC LOG DEPTH SEC T N R E 06/01/06 RRD/PAG QUIKDRILL PLUG SET 06/03/06 /TLH GLV C/O BP Exploration (Alaska) ;'~;.\ ~ .~ :j~ ~ "W ,r-"j"¡"" 'I' " \" ¡ 1 ;,~ Ii ~I .I ,.., . I t jJ, "I' ,:>= "'..~"\ ¡ ¡ .I J \ ""Il¡ j? ?!'J 'i 1r-;\". I~ \~wUUU~ ¡;=;\ 17 Wllr .~ ~ ~ ¡f) n IX\ ~ rt< /M u1J Lb:~~1'{ ~-; J\~LI ~~ FRANK H. MURKOWSKJ, GOVERNOR A"~A.SIiA OILAlVD GAS CONSERVATION COMMISSION 333 W JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-66112 ~ÇANNED JUL 2 5 2006 Re: Endicott Field, Endicott Oil Pool, END 2-18jL-16 Sundry Number: 306-250 Dear Mr. McMullen: 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 fùe 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 this1!/day of July, 2006 Enc!. ,0,0 ~OL.13 Alter casing D Change approved program D 2. Operator Name: bp Exploration (Alaska) Inc. 3. Address: 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 1. Type of Request: 7. KB Elevation (ft): . Property Designation: 11. Total Depth MD (ft): 11465 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10851'-11065' / Packers and SSSV Type: 16. Verbal Approval: ." ,,~ -, "'''f;/ --b N <- /I:¿ Y /2..t:CG STATE OF ALASKA " --- ALA~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 "'41"1""" '-r~ I ",""''''''P JUl 2 4 2006 Abandon Alaska Oil & Gas Cons. Commission Anchora e Waiver Other Stimulate D Time Extension D ISOLATE. «J'it " Re-enter Suspended Well D CI4:StÑ6. l.E1II<.. Repair well 0 Pull Tubing D Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: / Exploratory D D 6. API Number: 50-029-22032-00-00 ,,/ 5. Permit to Drill Number: 190-043 / Development o D Service Stratigraphic P.O. Box 196612 9. Well Name and Number: 55.1 END 2-18/L-16 ./ 10. Field/Pools(s): ADL 034633 Endicott Field I Endicott Pool Total Depth TVD (ft): 10504 PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): NIA Plugs (measured): NIA 11377 10429 Length Size Collapse MD TVD Burst 131' 2496' 8990' 1556' 30" 13-3/8" 9-518" 9-5/8" 131' 131' 2496 2496 8990' 8405' 8990'-10546' 8405'-9711' 10279' -11462' 9481"-10502' 5020 2270 6870 4760 8150 5080 9690 7820 Tubing MD (ft): 10206' 10140' 10232' /' 1183' 7" Perforation Depth TVD (ft): 9976'-10160' Tubing Size: / Tubing Grade: 4-1/2", 12.6# 13Cr80x9Cr 4-1/2",12.6# L-80 9- Packers and SSSV MD (ft): 9-5/8" x 4-1/2" Packer 5/8" Baker Packer .j 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 0 Service D /' D Abandoned D D WDSPL D Date: Plugged WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name L ¡y1u~ Title Phone Sb 7 COMMISSION USE ONLY Gary Preble 564-4944 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: · &5D Plug Integrity D Other: Approved by: BOP Test D Mechanical Integrity Test D Location Clearance D RBDMS BFl JUl 2 5 2006 COMMISSIONER APPROVED BY THE COMMISSION Date: 'C,-, Endicott Production Well 2-18/L-16 Proposed Cement Job for Production Casing Leak Isolation July 21, 2006 Current Status: · Production well, currently SI because of 9-5/8" leak at 7000' (logged 7/4/06). · MIT-IA to 3000 psi: Failed - 0.4 BPM; 3000 psi into leak at 7000' (7/4/06). ./' · MIT-T to 3000 psi (w/ tubing tail plug set): Passed (6/18/06). / · MIT-OA to 3000 psi: Passed (1/12/06). / Proposed Procedure to Isolate PC leak: 1. Set millable composite bridge plug in tubing at ~9755'. Pressure test. 2. Punch holes in tubing at ~97 40'. Est circulation T -7 IA. 3. Set millable composite squeeze packer in tubing at ~9670'. Est circulation T -7 IA. Pressure test composite squeeze packer from below (via IA). 4. Coil tubing cement job: · RIH with cemeait ezzle to squeeze packer. · Mix and pump 165 bbls of Class G cement into inner annulus. Target TOC in IA ~67 00' above PC leak). · wac. · MIT-IA to 3500 psi. · Mill composite squeeze packer/cement down to composite bridge plug. · MIT-T to 3500 psi. · Mill composite bridge plug. / 5. Return well to production. ,,-/ WEllHEAD: 13·5/8" 1 5000 psi 1 FMC (CCl) R.T. ElEV = 55.1' S.F. ElEV = 16.2' MAX. DEV. = 44 ' 10,200' MD 13-3/8", 68#ifl. NT80 CYHE SUTT CSG TOP OF 7" LINER 9-5/8", 47#/ft, NT95HS, NSCC MARKER - KEY: 0 '" OPEN f C = CLOSED f PSTD 7", 29#/ft, NT95HS TKC WELLHEAD:· 13"5/8" 1 5000 psi 1 FMC (CCl) RT. ELEV = 55.1' B.F. ElEV = 16.2' MAX. DEV. = 44 ' 10,200' MD 13-3/8", 68#/ft, NT80 CYHE BUTT CSG TOP OF 7" LINER 9-5/8", 47#/ft, NT95HS, MARKER x X WELL: ?? WELLHEAD: 13-5/8" / 5000 psi / FMC RT. ELEV = 55.1' B.F. ELEV = 16.2' MAX DEV. = 44 ' 10,200' MD 13-3/8", 68#/ft, NT80CYHE 2496' > to 3500 psi. - MIT-IA to 3500 psi. TOP OF 7" 110279' MARKER 7", 29#1f!, NT95HS TKC TN R E Schlumberger NO. 3868 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 100 '-043 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 " " ',f" A., N," NE.Ü <:]><1'11 ' '~" r¡ n f\ ¡:, 'J~'~ t... u t.' '.- Field: Prudhoe Bay WII J b# L D D BL CI CD e 0 og escnption ate o or 01-17B 11209602 MCNL 04/27/06 1 1 D-25A """ ,"'..'" USIT 06/13/06 1 D-25A 11212869 USIT 06/18/06 1 D.S. 04-31 11243929 SCMT 06/14/06 1 L5-28 11212867 USIT 06/15/06 1 2-18/L-16 11212871 SCMT 06/20/06 1 L5-28 11212872 SCMT 06/25/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 06/26/06 e e STATE OF ALASKA ALAS.IL AND GAS CONSERVATION <eMISSION REPORT OF SUNDRY WELL OPERATIQ.NS 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 034633 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface I ntermed iate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): ~ Repair Well ~ Pull Tubing o Operation Shutdown 55.10 11465 10504 11377 10429 131' 2496' 8990' 1556' 1183' o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension ~ OthelReplace Tubing o Re-Enter Suspended Well 4. Well Class Before Work: o Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 190-043 6. API Number: 50-029-22032-00-00 9. Well Name and Number: END 2-18/L-16 10. Field I Pool(s): Endicott Field I Endicott Pool feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 30" 131' 131' 13-3/8" 2496' 2496' 5020 2270 9-518" 8990' 8405' 6870 4760 9-5/8" 8990' - 10546' 8405' - 9711' 8150 5080 7" 10279' - 11462' 9481' - 10502' 9690 7820 10851'-11065' 9976' - 10160' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2",12.6#, 4-1/2", 12.6# 9-5/8" x 4-1/2" Packer 9-5/8" Baker Packer 13Cr80 x 9Cr L-80 10206' 10200' - 10318' 10140' 10232' Treatment description including volumes used and final pressure: RBDMS 8Ft MAY 3 0 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Dail Gas-Mcf Water-Bbl Tubin Pressure correct to the 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my now edge. Sundry Number or N/A if C.O. Exempt o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram 17. I Printed Name Sondra Stewman 'I ~-- Title Technical Assistant Phone Oat _ ..'.'-;'Z' C' .. c'\ Prepared By Name/Number: ...) .......J l. ~ondra Stewman, 564-4750 Submit Original Only 564-4750 OR\Gif~AL TREE: 4-1/16"/5000 psi I.ron I END 2-18 ~TES: I WELLHEAD: 13-5/8" 1 50 1 FMC DRLG DRAFT R.T. ELEV = 55.1' B.F. ELEV = 16.2' 0 ..- HES SSE SSSV in HXO SVLN " MAX. DEV. = 44 ' 1,515' MD (control lines to surface) wi 2.62" ID dummy valve in place 10,200' MD 13-3/8", 68#/ft, NT80 CYHE BUTT CSG 1 2496' I >AIIIIII !II... ..- 4-1/2" 12.6#, 13Cr-80,VamTop Tbg "'" I - Five GLM's: " ST MO TVO VLV 5 3592 OCR 4 5508 OMY 3 6916 DMY 9-5/8", 4 7#/ft 2 8496 DMY NT80S XO to NT95HS 1 10029 DMY 1 8948' I > - 4·1/2" X-nipple (3.813' ID) 10,109' ~ , ~ ~ V < 9-5/8" x 4-112" Packer 10,140' ;.....:: .:;......:: 4-1/2" X-nipple (3.813" 10) 10,175' ~ , ~.TOP 4-1/2" tubing stub 10,200' (wi RHC-M plug) 4-1/2" 'SWS' NIPPLE 1 I ~ .¿. Y ./ PARKER (3.813" I.D.) 10224' Unique 9-5/8' x 4-1/2' O/S10,206'- - ~ 1 I ~ BAKER LATCH 10231' · I I~ ASSEMBLY g ~ 9-5/8" PACKER 1 10232' I TOP OF 7" LINER ~ BAKER (3.99" I.D.) 110279' I 1""'1I' 4-1/2", 12.6#/ft L-80, TAILPIPE > · I ---! 10285' 4-1/2" PARKER SWS NIP, ID = 3.813" ~ Ir- · I 10306' 4-1/2" XN NIP, 10 = 3.725" I 9-5/8", 47#/ft, NT95HS, NSCC r 10546' . to 10318' 4-1/2" WLEG I ÆRFORATION SUMMARY I H ELMO TT LOGGED ON ??i??!?? I REF LOG: DLL-GR ON 04/18/90 10318' ANGLE AT TOP ÆRF: XXX" @ 10851' i Note: Refer to Production DB for historical perf dat I SIZE SA=' INTERV AL ** DATE I I ~ 3-3/8" 6 10851 - 10859 0 """" MARKER 10728' 3-3/8" 6 10863 - 10871 0 3-3/8" 4 10920-10946 S 3-3/8" 4 10952-10960 0 3-3/8" 4 1 0960 - 10966 S 3-3/8" 4 10972 - 10980 0 3-3/8" 4 10980 - 10982 S 3-3/8" 4 11002 - 11032 S 2-7/8" 6 11032 - 11036 0 3-3/8" 4 11040 - 11060 S 3-3/8" 4 11060-11065 0 3-3/8" 4 11065 - 11066 S 3-3/8" 4 11070-11074 S 3-3/8" 4 11077 - 11090 S ** KEY: 0 = OPEN I C = CLOSED I SQZ=SQUEEZED PBTD 1 11377' I ...... , r "", "", 7", 29#/ft, NT95HS I 11462' I ...... XXX TKC , DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 03/23/95 JLH CTU SZQ & REPERF 09/26/05 MORITLr PXN A..UG SET 8/29/05 WELL: 2-18/ L-16 10/18/95 JTP ADÆRF 02/02/06 JGR 2006 RWO prop. compo PERMIT No: ?? 11/21/98 JOE ADÆRF 103/13/06 ALM prop. compo edit AA No: 50-029-2203200 02/20/03 SGS REA..ACED TREE SEC T N R E 08/20/05 KSBffiH GLV C/O BP Exploration (Alaska) . . 7 BP EXPLORATION Operations Summary Report Move Off Well 01-05, Move to Well Row 2. Rig Moved to Well Row #2. Waited on Removal of Well Head Equipment. Moved Rig Over END 2-18, Leveled, Shimmed and Set Down Rig. R I U Drilling Floor, Set #2 Pump Module and R I U Lines, Set Slop Tank, Prepare to Take on Seawater. Continued to R I U Floor. N I U Secondary Annulus Valve. Accepted Rig 0500 hrs 4 111 I 2006. R I U Circulating Manifold. R I U on Wellhead to Circulate, Spotted and R I U Vac Trucks. Held PJSM. R I U DSM, Latched and Pulled BPV, RID DSM. o psi on Tubing and Annulus. Held PJSM wI Rig Crew, Vac Truck Drivers, Tool Pusher and Drilling Supervisor. Finished R I U on Tree. Circulated Pumps and Lines, Pressure Tested Lines. Lined Up Valves, Pumped 50 bbls 140 deg Seawater Down 9-5/8" x 4-1/2" Annulus, Took Diesel Returns off OfTubing. Suction Line on #2 Mud Pump Came Apart Leaking 1 bbl Seawater into Pump Module Breezeway and onto Pad. Derrickman Immediately Shut Down #2 Pump. Shut Down Operations, Brought Vac Truck Around Rig from Slop Tank to Vac Up Seawater on Pad. Leak Cleaned Up. Notified Endicott ACS Rep Lance Douglas and ACT Drilling Superintendant Mike Miller. DECOMP Lined Up to Pump Down Tubing and Take Returns off of 9-5/8" x 4-112" Annulus. Pumped 20 bbl Hi-Vis Safe Surf Sweep followed by 700 bbls 140 deg Seawater. Pump Rate 9 bpm, 920 psi. Set TWC in Tubing Hanger Profile. Tested TWC from Below to 1,000 psi, OK. BID and RID Lines. Held PJSM. N I D Tree, Terminated Control Lines, N I D Adapter Flange. N I U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Blind Shear Rams, Mud Cross wI Kill Choke Lines, 13-5/8" Lower Pipe Rams with 3-112" x 6" Variable Rams. N I U Riser. M I U Test Joint wI XO. RIH and M I U to Tubing Hanger. R I U BOPE Test Equipment. Held PJSM. Tested BOPE. Tested Annular Preventer, Blind Rams, Pipe Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves and IBOPs to 250 psi I 3,500 psi. All Tests Held f/5 Min. All Pressure Tests Held wI No Leaks or Pressure Loss. AOGCC Rep. John Crisp Waived Witness of Test. Test Witnessed by Doyon Tool Pusher and BP Drilling Supervisor. Test #1- Annular, Dart Valve, Kill HCR, Choke Valves 12, 13, 14. Test #2- Annular, TIW Valve, Manual Kill, Choke Valves 9, 10. Test #3- Annular, Upper IBOP, Choke Valves 5, 8, 10. Test #4- Annular, Lower IBOP, Choke Valves 1,4,6, 7. Test #5- Annular, Choke Valve # 2. Test #6- Annular, Choke Valve #3. Test #7- Blind Rams, Choke HCR. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-18/L-16 2-18/L-16 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Date . From - To Hours Task Code NPT Phase . 4/10/2006 20:00 - 00:00 4.00 MOB P PRE 4/11/2006 00:00 - 03:00 3.00 MOB P PRE 03:00 - 04:00 1.00 MOB P PRE 04:00 - 05:00 1.00 MOB P PRE 05:00 - 06:00 1.00 WHSUR P DECOMP 06:00 - 09:00 3.00 WHSUR P DECOMP 09:00 - 10:00 1.00 WHSUR P DECOMP 10:00 - 11 :00 1.00 WHSUR P DECOMP 11 :00 - 12:00 1.00 WHSUR P DECOMP 12:00 - 12:30 0.50 WHSUR P DECOMP 12:30 - 13:00 0.50 WHSUR N SFAL DECOMP 13:00 - 14:30 1.50 WHSUR P 14:30 - 15:30 1.00 WHSUR P DECOMP 15:30 - 18:00 2.50 WHSUR P DECOMP 18:00 - 20:30 2.50 BOPSUF P DECOMP 20:30 - 21 :00 0.50 BOPSUF P DECOMP 21 :00 - 00:00 3.00 BOPSUF P DECOMP Start: 4/10/2006 Rig Release: 4/20/2006 Rig Number: Spud Date: 4/1/1990 End: Description of Operations Printed: 4/21/2006 11:56:41 AM BP EXPLORATION 0..... ,"""} 7 .",,~, OpèrCitions . Summary Report . Legal Well Name: 2-18/L-16 Common Well Name: 2-18/L-16 Spud Date: 4/1/1990 Event Name: REENTER+COMPLETE Start: 4/10/2006 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/20/2006 Rig Name: DOYON 16 Rig Number: Date From ~ To Hours Task Code NPT Phase Description of Operations 4/11/2006 21 :00 - 00:00 3.00 BOPSUF P DECOMP 4/12/2006 00:00 - 01 :00 1.00 BOPSUF P DECOMP Continued to Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Test #8- Blind Rams and Manual Choke Valve Test #9 Lower Pipe Rams. Perfom1 Accumulator Test. 2,950 psi Starting Pressure, Dropped to 1,750 psi After Actuating Valves, Built 200 psi in 15 Seconds, Back to 2,950 psi in 1 Minute 17 Seconds. 5 Nitrogen Bottles at 2,200 psi. 01 :00 - 01 :30 0.50 BOPSUF P DECOMP RID BOPE Test Equipment. 01 :30 - 02:30 1.00 WHSUR P DECOMP Waited on DSM. 02:30 - 03:00 0.50 WHSUR P DECOMP R I U DSM Lubricator and Pull TWC. RID Lubricator. 03:00 - 03:30 0.50 PULL P DECOMP M I U Spear Assy, M I U Spear Assy onto 4" DP. RIH wI Spear and Engaged Tubing. PI U wI 15,000# Overpull to Ensure Grapples Engaged. BOLDS, P I U on Hanger, Tubing Hanger Came Off Seat wI 225,000# Up Weight, Pulled Tubing Hanger to Rig Floor, String Weight Up 155,000#. 03:30 - 04:30 1.00 PULL P DECOMP Terminated Control Lines at Hanger. B I 0 and LID Spear Assy and DP, B I 0 and LID Tubing Hanger. 04:30 - 05:30 1.00 PULL P DECOMP R I U Circulating Head and Lines. Circulated Bottoms Up, 14 bpm, 2,300 psi. No Gas at Surface wI Bottoms Up. 05:30 - 06:30 1.00 PULL P DECOMP BID and RID Lines. 06:30 - 08:30 2.00 PULL P DECOMP POOH, LID 4-1/2" Tubing, Spooled Up Dual Encapsulated 1/4" Control Line. 08:30 - 09:00 0.50 PULL P DECOMP RID Control Line Spooling Equipment, B I 0 and LID SSSV Assy. Recovered 19 Rubber Clamps, 4 SS Bands. 100% Recovery of Clamps and Bands. 09:00 - 16:30 7.50 PULL P DECOMP POOH, B I 0 and LID 4-1/2" 12.6# L-80 TDS Tubing. Recovered 253 Joints 4-112" Tubing, 6 GLM Assy's, 1 SSSV Assy, Cut Joint - 1.5'. Note: Joint 250 Pin Hole Below Collar, Joint 251-2' Section Collapsed and Split 4' Above Pin End. Chemical Cut End Split on Both Sides of Cut. 16:30 - 17:30 1.00 PULL P DECOMP RID 4-1/2" Tubing Handling Equipment, Clear and Clean Rig Floor. R I U BHA and 4" DP Handling Equipment. 17:30 - 18:00 0.50 CLEAN P DECOMP Install Wear Bushing. 18:00 - 21 :00 3.00 CLEAN P DECOMP M I U BHA #1. 8.5" x 4.5" Dressing Mill Shoe, 2 x 8.125" TSWP Extensions, 6.25" x 3.875" Inner Dressing Mill, 8.125" Wash Over Boot Basket, Double Pin XO, 2 x Junk Baskets, 9.625" Casing Scraper, Bit Sub, XO, Lubricated Bumper Sub, Oil Jars, XO, 12 x 4.75" Drill Collars, 21 x 4" HWDP. BHA = 1071.24' 21 :00 - 22:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line. 22:00 - 23:30 1.50 CLEAN P DECOMP Stand Back BHA and Re-Configure BHA by Dropping 4' TSWP Extension. 23:30 - 00:00 0.50 CLEAN P DECOMP Handle BHA #1. 8.5" x 4.5" Dressing Mill Shoe, 8.125" TSWP Extension, 6.25" x 3.875" Inner Dressing Mill, 8.125" Wash Over Boot Basket, Double Pin XO, 2 x Junk Baskets, 9.625" Casing Scraper, Bit Sub, XO, Lubricated Bumper Sub, Oil Jars, XO, 12 x 4.75" Drill Collars, 21 x 4" HWDP. BHA = 1066.78' 4/13/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RIH wI BHA#1 to 1,066'. 00:30 - 10:30 10.00 CLEAN P DECOMP RIH wI Dressoff BHA on 4" DP to 10,185'. PI U 4" DP 1 x 1 from Pipe Shed. Rabbitted All DP Run in Hole. 10:30 -11:30 1.00 FISH P DECOMP M I U Top Drive, Engaged Pump, Established Parameters: wI . . Printed: 4/21/2006 11 :56:41 AM . . BP .EXPLORATION Page 3 of7 Qperation$ Summary Report Legal Well Name: 2-18/L-16 Common Well Name: 2-18/L-16 Spud Date: 4/1/1990 Event Name: REENTER+COMPLETE Start: 4/10/2006 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/20/2006 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2006 10:30 - 11:30 1.00 FISH P DECOMP out Pumps, String Weight Up 213,000#, String Weight Down 170,000#, wI Pumps String Weight Up 215,000#, String Weight Down 167,000#, String Weight Rotating 192,000#, 50 rpm, Torque 7,000 ft Ilbs, 5 bpm, 630 psi. Washed Down, Tagged Top of Tubing Stub at 10,200' DPM. Dressed Off 8" of Tubing Stub, WOM 1,000# - 5,000#, rpm 50, Torque 9,000 ft I Ibs, 5 bpm, 660 psi. PI U to 10,190', Shut Down Pump and Rotary, RIH and Tagged Top of Tubing Stub at 10,200'. Mill and Extensions Went Over Stub. 11 :30 - 13:00 1.50 FISH P DECOMP Pumped and Circulated Around 40 bbl Hi-Vis Detergent Sweep, 14.5 bpm, 4,050 psi. Blew Down Top Drive, Monitored Wellbore, Well Static. 13:00 - 15:30 2.50 FISH P DECOMP POOH wI 4" DP. 15:30 - 17:00 1.50 FISH P DECOMP POH wI Dress Off BHA, Stood Back 4" HWDP and 4-3/4" DCs, B I 0, LID Dress Off BHA. 17:00 - 18:00 1.00 FISH P DECOMP Clear and Clean Rig Floor, Removed Excess Milling Tools from Rig Floor. 18:00 - 18:30 0.50 FISH P DECOMP R I U 2-7/8" Handling Tools 18:30 - 20:00 1.50 FISH P DECOMP M I U BHA #2, 3.625" Bladed Junk Mill, Shear Pin Guide Mandril, 8.5" x 4.5" Dressing Shoe, Bushing, 5.75" Shear Through Guide, 6 x 2.875" Pac Drill Pipe, XO, Pump Out Sub, XO, Lubricated Bumper Sub, Oil Jar, XO, 12 x 4.75" Drill Collars, 21 x 4" HWDP. Total BHA Lenght = 1286.13' 20:00 - 23:00 3.00 FISH P DECOMP RIH with 4" DP from Derrick. Break Circulation at 2,436', 4,837',7,238' and 10,115' 23:00 - 00:00 1.00 FISH P DECOMP Establish Parameters, Up Weight 213,000#, Down Weight 170,000#, Rotating Weight 190,000#, Rotating Torque 4,000 ft Ilbs at 30 rpm. 800 psi Pump Pressure at 5 bpm. Tag FasDrill at 10,256'. Clean Out to 10,276'. 4/14/2006 00:00 - 00:30 0.50 FISH P DECOMP Pushed FasDrill from 10,276' Out of Tubing Tail at 10,318'. Well Went On Vacuum. 00:30 - 01 :30 1.00 FISH P DECOMP Pumped and Spotted High Vis Pill, 2.5 bpm at 1,250 psi. 01 :30 - 04:30 3.00 FISH P DECOMP Attempt to POOH to LID DP, Mill Hung Up in XN Nipple at 10,285'. Rotateed 40 rpm wI 7,000 ft Ilbs Torque and 2,500# Over Pull, Worked Through XN Nipple. 04:30 - 08:00 3.50 FISH P DECOMP POOH LID 4" DP. Pumped Double Pipe Displacement While POOH. POOH to 7,300'. 08:00 - 11 :00 3.00 FISH N DECOMP Observed Flow, Shut Down Hole Fill and Monitored Well, Flow Increased to 35%. Shut In Well, SICP 400 psi, SIDPP 20 psi. Notified AOGCC, BP Drilling Superintendent, Endicott Control Room. Circulated Well Using Drillers Method, Pump Rate 4.0 bpm, Held Constant DP Pressure 100 psi. Circulated Full Annular Volume. Circulated Out Gas from Annulus. Shut Down Pump, SICP 0 psi, SIDPP 0 psi, Monitored Well Through Choke No Flow. Opened Annular Preventer, Unable to See Fluid Level. 11 :00 - 13:00 2.00 FISH N DECOMP Pumped Down DP and Annulus, 9 bpm, Attempted to Fill Hole, without Success. Pumped and Spotted 20 bbl Hi-Vis 50# I bbl Safe Carb Pill Down DP. Continued to Pump Down Annulus Through Kill Line. Unable to Fill Hole. Ran Short of Seawater, Waited on Vac Trucks. Losses 480+ bbll hr. 13:00 - 15:00 2.00 FISH N DECOMP RIH wI DP from 7,300' to 10,115', Vac Trucks Arrived on . . Printed: 4/21/2006 11:56:41 AM · BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-18/L-16 2-18/L-16 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 4/10/2006 Rig Release: 4/20/2006 Rig Number: Spud Date: 4/1/1990 End: Date From - To Hours Task Code NPT Phase Descriptiooof Operations 4/14/2006 13:00 - 15:00 2.00 FISH N DECOMP Location, Filled Pits, Pumped Down Annulus While RIH, 7 bpm, Could Not Fill Hole. 15:00 - 22:00 7.00 FISH N DECOMP M I U Top Drive, Pumped and Spotted 40 bbl Hi-Vis 50# I bbl Safe Carb Pill Down DP. Continued to Pump Down Annulus Through Kill Line, 8 bpm. Unable to Fill Hole. Losses 480 bbls I hr. Drop Dart and Open Circulation Sub, Sub Sheared at 2,100 psi. Pump 40 bbls of 100# I bbl Safe Carb Pill Followed by 60 bbls of 40# I bbl Safe Carb Pill Down DP. Spot Safe Carb Pills with 109 bbls of Seawater. Line Up and Pump 150 bbls of 40# I bbl Safe Carb Pill Down Annulus. Switch to Seawater and Pump Down Annulus at 8 bpm. Returns to Surface. Establish Loss Rate, 120 bph Dropping to 40 bph 22:00 - 22:30 0.50 FISH N DECOMP Monitor Well, Loss Rate 60 - 40 bph. B I 0 and BID Top Drive. 22:30 - 00:00 1.50 FISH N DECOMP POOH from 10,115' to 9,251', Laying Down 4" DP. 4/15/2006 00:00 - 06:30 6.50 FISH P DECOMP POOH LID 4" DP. Losses 15 bph. 06:30 - 09:00 2.50 FISH P DECOMP POOH, LID BHA. Losses 15 - 12 bph. 09:00 - 10:00 1.00 FISH P DECOMP Cleared and Cleaned Rig Floor. 10:00 - 12:00 2.00 RUNCO RUNCMP Held PJSM wI Rig Crew, Baker Rep, Doyon Casing, Tool Pusher and Drilling Supervisor. R I U Compensator, Torque Turn Equipment and Handling Tools to Run 4-1/2" 13Cr80 Vam TOP Completion. 12:00 - 12:30 0.50 RUNCO RUNCMP M I U 4-1/2" Tail Pipe Assy: Unique Machine Overshot Assy, Lower X Nipple Assy wI RHC Sleeve, 9-5/8" x 4-1/2" Baker S-3 Packer Assy, Upper X Nipple Assy. PI U All Assy's wI Compensator, Torque Turned All Connections, M I U Torque 4,450 ft Ilbs. Bakerloc'd All Connections Below Packer, Applied Jet Lube Seal Guard Thread Compound to All Other Connections. 12:30 - 23:30 11.00 RUNCO RUNCMP Ran 201 Jts 4-1/2" 12.6# 13Cr80 Vam TOP Tubing. PI U All Joints wI Compensator, Torque Turned All Connections, M I U Torque 4,450 ft Ilbs. Applied Jet Lube Seal Guard Thread Compound to All Connections. 23:30 - 00:00 0.50 RUNCO RUNCMP R I U Control Line Spooler for SSSV. 4/16/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP R I U Control Line Spooler, M I U SSSV, M I U Control Lines to SSSV and Tested Same. 01 :00 - 04:00 RUNCMP Ran 35 Jts 4-1/2" 12.6# 13Cr80 Vam TOP Tubing wI 1/4" Dual Control Lines. PI U All Joints wI Compensator, Torque Turned All Connections, M I U Torque 4,450 ft Ilbs. Applied Jet Lube Seal Guard Thread Compound to All Connections. 04:00 - 06:00 RUNCMP M I U Circulating Head and Lines to Jt #237, M I U to Tubing String. Engaged Pump 3 bpm, 200 psi. RIH, Observed Pump Pressure Increase to 300 psi as 0 I S Swallowed Tubing Stub. Shut Down Pump and Continued to RIH, Stacked Out on Tubing Stub wI 0 I S Shear Pins, Pins Sheared wI 10,000# Down Weight, Continued to RIH, Stacked Out on Top of 4-1/2" Tubing Stub at 10,200', wI Bottom of 0 I Sat 10,208.5'. Stacked 10,000# on No-Go. P I U to 10,170' and Repeated Process x 2 to Ensure Proper Space Out. B I 0 Circulating Lines and Head, B I 0 and LID Jts #237 and #236. M I U 3.81' Space Out Pup. M I U Jt #236. 06:00 - 08:00 2.00 RUNCO RUNCMP M I U Tubing Hanger and Landing Joint. M I U Control Lines Through Hanger. RIH, Landed Tubing Hanger in Wellhead, Printed: 4/21/2006 11 :56:41 AM BPEXPLORATION PCige50f7 ()peration$ ·SummaryReport . . Legal Well Name: 2-18/L-16 Common Well Name: 2-18/L-16 Spud Date: 4/1/1990 Event Name: REENTER+COMPLETE Start: 4/10/2006 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/20/2006 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase DescriþtionofOperations . 4/16/2006 06:00 - 08:00 2.00 RUNCOI P RUNCMP RILDS. 08:00 - 09:30 1.50 EVAL P OTHCMP Held PJSM, R I U Slickline Equipment wI Pressure Control. 09:30 - 10:30 1.00 EVAL P OTHCMP M I U Retrieving Tool to Slickline, RIH wI Tool, Latched and Retrieved Dummy Valve from SSSVat 1,515'. POOH. 10:30 - 12:30 2.00 EVAL P OTHCMP M I U RHC Retrieving Tool to Slickline. RIH wI Tool, Latched and Retrieved RHC Sleeve from Lower X Nipple Assy at 10,176'. POOH. 12:30 - 13:30 1.00 EVAL P OTHCMP M I U PDS Memory CCL Tools to Slickline, RIH, Stacked Out in GLM at 3,600'. As Tool Stacked Out at 3,600', Slickline Lost Tension and Looped Off of Drum, Catching in Drum Drive Chain, Causing a Kink in Slickline. 13:30 - 16:00 2.50 EVAL N SFAL OTHCMP POOH wI PDS Memory CCL Tool, B I 0 and LID Tool. Schlumberger Slickline Crew Spooled Off 4,000' of Line to Remove Kink on Line. Recut Line, Restrung Line Through Equipment. Restrung Line Through Sheeves. M I U Rope Socket and Head. M I U PDS Memory Tool to Slickline and RIH. 16:00 - 19:00 3.00 EVAL N OTHCMP RIH wI PDS Memory CCL Tool on Slickline to 10,400'. Logged Up from 10,400' to 9,900'. 19:00 - 22:00 3.00 EVAL P OTHCMP M I U Running Tool and RIH with RHC Sleeve, Set Sleeve, POOH with Running Tool. 22:00 - 00:00 2.00 EVAL P OTHCMP M I U 0-16 Plug and RIH. 4/17/2006 00:00 - 01 :00 1.00 EVAL P OTHCMP Attempted to Set 0-16 Plug in X Nipple at 10,109' without Success. 01 :00 - 03:00 2.00 EVAL N DPRB OTHCMP POOH, C I 0 Pins on Setting Tool, Checked 0-16 Plug and M I U to Setting Tool. 03:00 - 05:00 2.00 EVAL N DPRB OTHCMP RIH wI 0-16 Plug on Slickline, Attempted to Set 0-16 Plug in X Nipple at 10,109' without Success, POOH. 05:00 - 07:00 2.00 EVAL N DPRB OTHCMP M I U Redressed 0-16 Plug on Setting Tool and RIH. Set 0-16 Plug in X Nipple at 10,109'. POOH. Set Back Slickline Tools. 07:00 - 08:00 1.00 EVAL N DPRB OTHCMP RID Slickline Packoff, Pump In Sub and XO. R I U XO, Circulating Head and Lines. Attempted to Pressure Test Tubing to 3,500 psi, Pressure Leaked by 0-16 Plug. 08:00 - 08:30 0.50 EVAL N DPRB OTHCMP Bled Down Pressure, RID Circulating Head, Lines and XO. R I U Slickline Packoff, Pump In Sub and XO. 08:30 - 11 :30 3.00 EVAL N DPRB OTHCMP M I U Retrieving Tool onto Slickline, RIH, Latched and Released 0-16 Plug from X Nipple at 10,109'. POOH. 11 :30 - 14:30 3.00 EVAL N DPRB OTHCMP M I U Running Tool and XX Plug onto Slickline, RIH and Set XX Plug in X Nipple at 10,109'. POOH. 14:30 - 16:30 2.00 EVAL P OTHCMP RID Slickline Packoff, Pump In Sub and XO. R I U XO, Circulating Head and Lines. Pressure Tested Tubing to 3,500 psi fl 30 Minutes. Bled Down Pressure, RID Circulating Head, Lines and XO. R I U Slickline Packoff, Pump In Sub and XO. 16:30 - 20:30 4.00 EVAL N DPRB OTHCMP M I U Retrieving Tool onto Slickline, RIH, Latched and Released XX Plug from X Nipple at 10,109'. POOH XX Nipple Hanging Up In GLM at 3,600'. Work XX Nipple at 3,600', Running Tool Sheared Off XX Nipple. POOH with Running Tools. 20:30 - 21 :00 0.50 EVAL N DPRB OTHCMP Redress Running Tool and Add Weight Bar. 21 :00 - 23:00 2.00 EVAL N DPRB OTHCMP RIH and Latch Onto XX Nipple ar 3,600', Knock XX Nipple Down Below GLM. Able to Pull Back Through Mandrel with Extra Drag. XX Nipple was Missing one Locking Dog. 23:00 - 00:00 1.00 EVAL N DPRB OTHCMP Discuss Options with Anchorage. M I U Brush Assembly. . . Printed: 4/21/2006 11:56:41 AM BPEXPLORATION Page 6 ()f7 Operations Summary Report . Legal Well Name: 2-18/L-16 Common Well Name: 2-18/L-16 Spud Date: 4/1/1990 Event Name: REENTER+COMPLETE Start: 4/10/2006 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/20/2006 Rig Name: DOYON 16 Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 4/18/2006 00:00 - 01 :30 1.50 EVAL N DPRB OTHCMP RIH with Brushes, Work Through GLM's to Ensure XX Nipple Locking Dog Is Not in Mandrel, RIH to RHC Sleeve at 10,176' POOH with Brushes. 01 :30 - 04:00 2.50 EVAL N DPRB OTHCMP M I U RHC- Sleeve Retrieval Tool and RIH to 10,176', Pull RHC- Sleeve Free and POOH with Same. Recovered XX Nipple Locking Dog in RHC-Sleeve. 04:00 - 07:00 3.00 EVAL N DPRB OTHCMP Redress RHC-Sleeve and RIH with Same, POOH with Slickline. 07:00 - 08:30 1.50 EVAL N DPRB OTHCMP M/U Dummy Valve Running Tool and RIH with Same. Set Dummy Valve in SSSV. POOH with Slickline 08:30 - 09:00 0.50 EVAL N DPRB OTHCMP RID Slickline Unit. 09:00 - 11 :00 2.00 EVAL N DPRB OTHCMP Attemp to Reverse Circulate, Pressured up to 500 psi, Unable to Circulate. R I U and Pump Down Tubing. Pumping Fluids Into Formation, 425 psi at 3 bpm. Call and Discuss Options with Anchorage. 11 :00 - 12:00 1.00 EVAL N DPRB OTHCMP Back Out Lock Down Screws. 12:00 - 13:00 1.00 EVAL N DPRB OTHCMP Attempt to Pull Overshot Off of Tubing Stub. Pull 225,000#. Unable to Pull Off Tubing Stub. Call and Discuss Options with Anchorage. 13:00 - 14:00 1.00 EVAL N DPRB OTHCMP Land Tubing Hanger and Run In Lock Down Screws. 14:00 - 21:00 7.00 EVAL N DPRB OTHCMP Establish Circulation Down the Annulus, Pressured Up to 1,800 psi and Broke Free, Reverse Circulate at 3 bpm with 180 psi. Pump Hi-Vis Sweep Around. Sweep Back At 250 bbls. Pump Dye Sweep Around and Confirm DCR Valve Sheared. Call and Discuss Options with Anchorage. 21 :00 - 22:30 1.50 EVAL N DPRB OTHCMP Spot and R I U Slickline Unit. 22:30 - 00:00 1.50 EVAL N DPRB OTHCMP RIH, Latch Onto SSSV Dummy Valve and POOH. 4/19/2006 00:00 - 02:00 2.00 EVAL N DPRB OTHCMP RIH and Retrieve DCR Valve from GLM at 3,601'. POOH with Same. 02:00 - 03:30 1.50 EVAL N DPRB OTHCMP RIH with Dummy Valve and Set in GLM at 3,601'. POOH 03:30 - 04:00 0.50 EVAL N DPRB OTHCMP Redress Running Tool. 04:00 - 05:00 1.00 EVAL N DPRB OTHCMP RIH with LIB to Verify Dummy Valve is Set. POOH 05:00 - 07:00 2.00 EVAL N DPRB OTHCMP RIH with Dummy Valve and Set in SSSV, POOH. RID Slcikline Sheaves. Remove Lubricator 07:00 - 07:30 0.50 EVAL N DPRB OTHCMP RlU to Reverse Circulate Down OA Taking Returns Up Tubing 07:30 - 09:00 1.50 EVAL N DPRB OTHCMP Held PJSM, Pressure Up OA in 800/1,000 psi Increments. Pressure 5 min Pressure Loss 1,000 psi o psi 2,000 psi o psi 2,800 psi 300 psi 2,800 psi 300 psi 2,800 psi 300 psi 3,100 psi Lost All Pressure After Total Pressure Loss at 3,100 psi. Established Circulating Rate of 3 bpm at 625 psi 09:00 - 13:00 4.00 EVAL N DPRB OTHCMP Reverse Circulate Down OA at 3 bpm at 625 psi. Pump 25 bbls Hi-Vis Sweep and Spot at 9,000'. 13:00 - 15:00 2.00 EVAL N DPRB OTHCMP BOLDS, Pull Tubing Hanger Loose with 175,000# Up Weight, SIO to 140,000#. Work Pipe by Increasing Pull by 10,000# Increments. Working String at Each 10,000# Weight Increase. Maximum Pull of 220,000#. Worked String at 220,000# Up Weight Making Steady Progress Until Overshot Came Free. Steady Pull of 220,000# for Additional -10' After String Broke . . Printed: 4/21/2006 11:56:41 AM \ . BP EXPLORATION Operations Summary Report Page 7 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-18/L-16 2-18/L-16 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 4/10/2006 Rig Release: 4/20/2006 Rig Number: Spud Date: 4/1/1990 End: Date From - To Hours Task Code NPT Phase De$críptiOf"lof OperatiOns 4/19/2006 13:00 - 15:00 2.00 EVAL N DPRB OTHCMP Free. Up Weight Decreased to 155,000# at -20' Off Bottom. 15:00 - 16:00 1.00 EVAL N DPRB OTHCMP Disconnect SSSV Control Lines. RID Circulating Equipment, B/O Landing Joint and Tubing Hanger and LID Same 16:00 - 17:00 1.00 EVAL N DPRB OTHCMP Held PJSM, MIU Circulating Head to 1 Joint 4.5" 12.6# Vam Top Tubing. M/U Tubing Joint to Completion String for Circulating and Space Out Measurements. Connect Circulating Hose to Circulating Head. 17:00 - 17:30 0.50 EVAL N DPRB OTHCMP Break Circulation at 3 bpm, 115 psi. SIO and Tag Tubing Stub at 10,200'. Observed Pressure Increase to 200 psi When Overshot Started to Swallow Tubing Stub. Tagged No-Go at 10,208'. P/U String and Broke Free at 160,000# Up Weight. Pulled Up to 10,207'. 17:30 - 19:00 1.50 EVAL N DPRB OTHCMP Close Annular and Reverse Circulate Hi-Vis Sweep Around. No Indication of Solids to Surface With Sweep. 19:00 - 19:30 0.50 EVAL N DPRB OTHCMP B I 0 and LID Landing Joint. M I U Hanger and Landing Joint. 19:30 - 21:00 1.50 EVAL N DPRB OTHCMP Terminate Control Lines and Land Hanger. No Drag and No Indications of Fill on Landing Out. RILDS 21 :00 - 00:00 3.00 EVAL N DPRB OTHCMP R I U Lines and Break Circulation. Unable to Circulate Initially. Work Pressure Up to 3,500 psi. Able to Establish Circulation to 3,450 psi at 1.5 bpm. 4/20/2006 00:00 - 00:30 0.50 EVAL P OTHCMP Reverse Seawater 3,740 psi at 1.75 bpm. 00:30 - 01 :30 1.00 EVAL P OTHCMP R I U Little Red and Pump 109 bbls of Diesel Freeze Protect Down Annulus. Pressure Dropping to 1,750 psi at 2.5 bpm with 100 bbls away. Pressure holding at 800 psi. 01 :30 - 03:00 1.50 EVAL P OTHCMP Drop Setting Ball Down Tubing and Pump 7 bbls of Diesel Freeze Protect Down Tubing. 03:00 - 07:30 4.50 EVAL P OTHCMP Pump Down Tubing and Set Packer. Pressure up to 3,500 psi. Good Test, Pressure up to 3,500 psi on Annulus. Pressure Bleeding Off. Call Anchorage and Discuss Options. Pressure Up to 4,000 psi on Tubing and Attempt to Set Packer, Pressure Up on the Annulus to 3,500 psi. Still Leaking. Call Anchorage and Discuss Options 07:30 - 09:00 1.50 EVAL N DPRB OTHCMP Pressure Test OA to 3,500 psi. Bled Down 750 psi in 5 min. Established Injection Rate Down OA at 1/2 bpm at 3,675 psi. 09:00 - 10:30 1.50 EVAL N DPRB OTHCMP Pressure Up on Tubing to 4,500 psi to Energize Packer Element, Held for 5 min. Bled Down Tubing Pressure to 500 psi Isolate. Pressure Up OA to 3,500 psi. 750 psi Drop in 5 min. Bled Down OA and IA to 0 psi. 10:30 - 11 :30 1.00 EVAL DPRB OTHCMP RID Circulating Equipment. B/O and LID Landing Joint. 11 :30 - 14:00 2.50 BOPSU SFAL OTHCMP Set TWC. Leaking by. Unable to Apply Pressure Underneath to Set Seal on Seat. Pull and Rebuild, Still Leaking. DSM Deliveried TWC. Installed Second TWC. Second TWC also Leaked. Install BPV. 14:00 - 16:00 2.00 BOPSU OTHCMP Nipple Down BOPE and Stand Back Stack. 16:00 - 18:00 2.00 BOPSU OTHCMP Remove Adapter Flange and Prepare Well Head for Tree. 18:00 - 20:30 2.50 BOPSU OTHCMP Nipple Up Tree and Adapter Flange, Test Adaptor Flange to 5,000 psi for 15 Minutes. 20:30 - 23:00 2.50 BOPSU OTHCMP R I U DSM Lubricator and Pull BPV, Install TWC and Test Tree to 5,000 psi. Pull TWC and Install BPV. RID Lubricator. 23:00 - 00:00 1.00 BOPSU OTHCMP Secure Well and Cellar. Rig Released at 24:00 Hours Printed: 4/21/2006 11 :56:41 AM Schlumbergel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth RECE'VEC; DEC 2 1 Z005 ~ ŒI & Gas eons. cowlr~kn Anchoïage Well Job # Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE W/DEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE WIDEFT 07/16/05 1 D.S 18-038 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08107/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-188 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 1'IO·tJ4ð 11087185 LDL 10/01/05 1 2-62/Q-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 "-'r-I: )"H~ibD ~" iJ.i n ~~g~~~~':]~,~; JkJ\J {,,¡ 5 2005 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Received bY~n I , ..... "" .... I 'Y ..... IJ 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P' Exploratory , :"",~ 3. Address: P.O. Box 196612 Stratigraphic 0 Service 6. API Number: Anchorage, AK 99519-6612 50-029-22032-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.1 KB 2-18/L-16 8. Property Designation: 10. Field/Pool(s): ADL-034633 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 11465 feet Plugs (measured) 10306 TT true vertical 10504.62 feet Junk (measured) None Effective Depth measured 11377 feet ~ÇANNEu DEG 1 62005 true vertical 10428.69 feet Casing Length Size MD TVD Burst Collapse Conductor 92 20" X 30" 39 - 131 39 - 131 Surface 2458 13-3/8" 68# NT -80 38 - 2496 38 - 2495.98 5020 2270 Production 8911 9-5/8" 47# NT80S 37 - 8948 37 - 8369.84 6870 4760 Production 1598 9-5/8" 47# NT95HS 8948 - 10546 8369.84 - 9711.46 -. 8150 5080 Liner 1183 7" 29# NT95HS 10279 - 11462 9481.44 - 10502.03 9690 7820 Perforation depth: Measured depth: 10851 - 10859 10863 - 10871 10952 - 10960 10972 - 10980 11032 - 11036 11060 - 11065 True Vertical depth: 9975.53 - 9982.41 9985.84 - 9992.71 10062.39 - 10069.28 10079.61 - 10086.5 10131.33 -10134.77 10155.45 - 10159.75 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 36 - 10318 Packers and SSSV (type and measured depth) 4-1/2" Baker SB3 Packer 10232 12. Stimulation or cement squeeze summary: Intervals treated (measured): RSDMS 8Ft NO V 2 :1 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf I Water-Bbl Casing Pressure I Tubing pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Developm ent P' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil P' Gas O! WAG 0 GINJ 0 WINJ O! WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal í Title Data Mgmt Engr Signat!o... ~A"___h:ð -7iA/;7/ Phone 564-4424 Date 11/17/2005 _ STATE OF ALASKA _ ALA" Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS NOV 2 ~ 20GS Alaska Oil & GI. Cons. Commission Form 10-404 Revised 04/2004 OR\G\~~AL Submit Original Only ~ C t: (' r:: I \ It: f""\ ... e e . 2-18/L-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Ik~$TIVITYDATE I SUMMARY 10/6/2005 ***WELL SI ON ARRIVAL *** PULLED PRONG FROM 10283' SLM. PULLED XN PLUG BODY FROM 10285' SLM PREMATURELY SET X PLUG BODY IN UPPER SWS NIPPLE. PULLED X PLUG BODY FROM 10,204' SLM. SET 41/2" PX PLUG BODY IN LOWER SWS NIPPLE @ 10,264' SLM. SET (2.125" X 101" LONG W/ 1.750" FN) EQUILlZING PRONG @ 10260' SLM LR CMIT IN PROGRESS ***CONT. ON 10-07-05*** 10/6/2005 T/I/O=2350/500/100 Assist Slick-line (secure well) 1st test-- CMIT T x IA (FAILED) Pumped 60 bbls diesel to pressure. TBG lost 40 psi in 15 min. Lost 80 psi 2nd 15 min. For a total of 120 psi in 30 min.IA lost 75 psi in 15 min. Lost 50 psi 2nd 15 min. For a total of 125 psi in 30 min.Bleed down pressure. SSL to reset TTP.***Continue AWGRS on 10-07-05*** 10/7/2005 ***CONT. FROM 10-06-05*** CMIT FAILED PULLED EQUILlZING PRONG FROM 10260' SLM PULLED X LOCK FROM 10267' SLM. SET 41/2" PX PLUG @10,197' SLM. SET 97" PRONG IN PX PLUG @10,194' SLM. (1.75" FN) STARTED MIT X lA, RAN OUT OF FLUIDS. LRS WILL CONTINUE ON WITH TEST. RDMO. ****LEFT WELL SHUT-IN DUE TO PX PLUG IN HOLE, NOTIFIED WELL TENDER OF STATUS**** 10/7/2005 ***Continued AWGRS from 10-06-05*** Assist Slick-line (secure well) CMIT Tx IA @ 3000 psi (PASSED) after Slickline re-set TTP. Pumped 25 bbls Diesel into TBG/ Pumped 24 bbls Diesel into IA. Monitored Pressures. Ordered more fluid and bled gas from TBG. TxlA Pressured up w/ an additional 61 bbls Diesel pumped into IA. 1 st test FAILED TBG lost 110 psi in 15 min. Lost 110 psi 2nd 15 min for a total of 220 psi in 30 min. IA lost 175 psi in 15 min. Lost 140 psi 2nd 15 min. For a total of 315 psi in 30 min. Pumped back up w/2 bbls diesel. 2 nd test PASSED TBG lost 40 psi in 15 min. Lost 10 psi 2 nd 15 min. For a total of 50 psi in 30 min. IA lost 40 psi in 15 min. Lost 10 psi 2nd 15 min. For a total of 50 psi in 30 min. Bled pressure down. Final WHP's=1790/1500/50 FLUIDS PUMPED BBLS I 172 Diesel 172 . TOTAL STATE OF ALASKA ALASI~:~""!L AND GAS CONSERVATION COMMISSI('~''''; REPORT SUNDRY WELL OPE,.ATIONS 1. Operations performed: Operation shutdown . Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.~le, Alaska 99519-6612 4. Location of well at surface 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E At top of productive interval 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L- 16 MPI 9. Permit number/approval number 90-43/Not Rec/uired 10. APl number 1 Encficott Off ~pol 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11465 feet 10505 BKB feet 11377 feet 10429 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131 131' 2457' 13-3/8' 3006 c.f. Permafrost 2496' 2496' 10507' 9-5/8" 2324 c.f. Class G 10546' 9711 1183' 7" 457c. f. Class G 10279'- 11462' 9481'- 10502' measured 10851'-10859'(open); 10863'-10871'(open); 10920'-10946'(squeezed); 10952'-10960'(open); 10960'-10966'(squeezed), 10972'-10980' (open); 10980% 10982' (squeezed); 11002'-111036' (squeezed); 11032'-11036'(open);1111040'-11060' (squeezed); 11060'-11065' (open); 1111065'-111066'(squeezed); 11070'-11074'(squeezed); 11077'-111090'(squeezed); 11106"-111113'(squeezed) true vertical (TVOSS) 9920'-9927' (open); 9931'- 9938' (open); 9980'-10002'(squeezed), 10007'-10014 (open), 10014'-10019' (squeezed), 10025'-10031' (open), 10031'-10033 (squeezed), 10050'-10080' (squeezed), 10076'-10079' (open), 10083'-10100' (squeezed), 10100'-10105' (open), 10105'-10106') squeezed, 10109'-10112'(squeezed), 10115'-10126' (squeezed), 10140'-10146' (squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSSV at 1552'. 13. Stimulation or cement squeeze summary Additional Perforations (11/21/98) Intervals treated (measured) 11032'-11036' Treatment description including volumes used and final pressure DUPLICATE 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1122 16696 10689 0 1014 14478 6905 0 Tubing Pressure 482 1100 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X, 16. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~~:~-~ Title.~enior T~chnica1,4~i.~tant IV .~.~-.~,.~,~ Form 10-404 Rev 06~5/88 Date 12/16/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department ADDITIONAL PERFORATIONS DATE: 11/21198 WELL N°: 2-181L-16 BP EXPLORATION REP: VARBLE / ECKSTEIN SERVICE COMPANY: SWS (C. YON) DATE/TIME OPERATIONS SUMMARY O8OO 0900 0910 092O 0935 1055 1102 1107 MIRU SWS FWHP=600 IAP=1150 OAP=150 Test fire SAFE package. Hold safety meeting Arm gun (4') Shut in well & RIH With 6' weight bar / Gun - GR / 4' 2-7/8" gun. Log tie m pass from 11100' - 10965' md. Tie into DLL dated 4/18/90."Add 4.5' Log confirmation pass. On depth. Lo.g into place & hang CCL @ 11024' md. (8' from CCL to top shot) SIWHP=2250 psg 1110 1115 1118 1330 1430 1530 1600 1630 Shoot gun from 11032'-11036' md. No indication gun fired. Slight increase ~n WHP - 100 psi. Log off. POOH. Gun did notfire. Removetoolsaverand setupto runinthe hole again. RIH with Gun #1 (again). Tie-in, shoot Gunfrom 11032'-11036' OOH POP well RDMO. PERFORATION SUMMARY: GUN INTERVAL(DLL) 1 11032'-11036' FEET SUBZONE 4 3A3 All intervals were shot using 2-7/8" 34J ultajet guns, 15.2 gram charge at 6 spf, 0 degree phasing and random orientation. STATE OF ALASKA ALAbr¢, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .__ Pull tubing__ Alter casing __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E At top of productive interval 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E Stimulate__ Plugging__ Perforate X Repair well __ Other__ 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L- 16 UPI 9. Permit number/approval number 90-43/Not Required 10. APl number 50- 029-22032 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 11465 feet 10505 BKB feet Plugs (measured) Effective depth: measured true vertical 11377 feet 10429 BKB feet Junk (measured) Casing Length Structural Conductor 92' Surface 2457' Intermediate 10507' Production Liner 1183' Perforation depth: Tubing (size, grade, and measured depth) Size 30" 13-3/8" 9-5/8" Cemented Measured depth True vertical depth BKB BKB Driven 131 131' 3006 c.f. Permafrost 2496' 2496' 2324 c.f. Class G 10546' 9711 7" 457c. f. Class G 10279'- 11462' 9481'- 10502' measured 10851'-10859' (open); 10863'-10871' (open); 10920'-10946' (squeezed); 10952'-10960' (open); 10960'-10966' (squeezed), 10972'-10980' (open); 10980'- 10982' (squeezed); 11002'-11036' (squeezed); 11040'-11060' (squeezed); 11060' -11065' (open); 11065'-11066'(squeezed); 11070'-11074' (squeezed); 11077'-11090' (squeezed); 11106'-11113' (squeezed) true vertical (TVDSS) 9920'-9927' (open); 9931' - 9938' (open); 9980'-10002'(squeezed), 10007°-10014 (open), 10014'-10019' (squeezed), 10025'-10031° (open), 10031'-10033 (squeezed), 10050'-10080' (squeezed), 10083'-10100' (squeezed), 10100'-10105' (open), 10105'-10106') squeezed, 10109'-10112' (squeezed), 10115'-10126' (squeezed), 4-1/2" 12.6# L-80 tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSS V at 1552'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1307 10703 3199 0 2348 14781 2988 0 Tubing Pressure 1281 1363 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~-~_.¢¢_.,/~ ~, /~'/~~,~ TitleSeniorTechnicalAssistantll Form 10-,~ Rev 06/15/88 SUBMIT IN DI~PLIfSATE , Endicott Production Engineering Department DATE' 10117~95 WELL N-°: 2-18/L-16 BP EXPLORATION REP' SERVICE COMPANY: Additional Perforations POWERS ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY ..... 0830 MIRU AWS. INSTALL SSV FUSIBLE CAP. SIWHP = 2600 PSI; lAP = 1140 PSI, OAP= 200 PSI, WHT=SI. WELL SI ON ARRIVAL. 9:30 PRESSURE TEST LUBRICATOR TO SIWHP. 9:35 RIH WITH GUN #1 (20 FT WITH A 4' BLANK IN THE MIDDLE). SIWHP = 2600 PSI 10:48 ON BOTTOM - OPEN WING VALVE AND SET CHOKE AT 20 BEANS FOR UNDERBALANCE. TROUBLESHOOT GREASE PROBLEMS. 11' 14 TIE INTO CBT DATED 5/6/90 AND MAKE A -5 FT CORRECTION. 11:29 HANG CCL AT 10849 (2' TO TOP SHOT). SHOOT GUN #1 FROM 10851-10859' (4'BLANK) 10863'-10871' MD. LOST350 LBS. LOG OFF. 11:42 SI WELL AND POOH. 12:30 AT SURFACE. BLEED LUBRICATOR & CONFIRM ALL SHOTS FIRED. 12:46 POP WELL AT 40 BEANS FROM SIP-1250. RDMO ATLAS PERFORATION SUMMARY' GUN DLL DEPTH FEET S U BZO N E I 10851' - 10859' 8 3B1 10863' - 10871' 8 3B1 All intervals were shot using 3-3/8" Alpha Jet guns at 6 spf, 21 gram charges, 60 degree phasing and random orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 23 October 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 4297.09 Run ~ 1 5869.06 Run # 1 6001.14 Run # 1 6146.03 Run # 1 6397.11 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 · ~ A:~chorage, AK__99518 F~ to (907.)563-7803 Received by :': ,L,<~ .<: /'" .,..?'~:,~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 1 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 2-18/L-16 ~0'~) 1 PLS FINAL BL+RF q 1 PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 4297.10 6001.15 6192.09 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~/r~FAX to (907)5~- Received by: . ./,- Date: R E C E IV ~: Lb Alaska Oil & Gas Cons. Co,rn, mis$/o~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 17 October 1994 Transmittal of Data ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as des~ed ~~: WELL ~ DESORIP%~F~ 1 PFC/PERF RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 4297.07 5756.02 PI ' 5600 B Street Suite 201 Anchorage, AK 99518 A~ttn. Rodney D. Paulson Or ~~7(907) 563-7803 Received by ~~---~Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 October 1994 RE: Transmittal'Of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PL/STP FINAL.BL 1 PL/STP FINL.RF SEPIA 1 PL/PROFILE FINAL BL 1 PL/PROFILE RF SEPIA 1 PLS FINAL BLUELINE 1 PLS FINAL RF SEPIA Run # 1 Run # 1 ECC No. 3235.04 Run # 1 4297.06 Run # 1 Run # 1 5765.05 Run # 1 Pl~ ~ and return to: Atlas 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or ~(907) 563-7803 Received by: ~ .... ~ "Date: STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMISS~JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1902' SNL, 2213' WEL, Sec. 36, TI~N, R16E At top of productive interval 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E 12. Present well condition summary 5. Type of Well: Development Exploratory Stratigraphic Service Gas Cor~s. Commission Anchorage 6. Datum elevation (DF or KB) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L- 16 MPI 9. Permit number/approval number 90-43/Not Required 10. APl number 50- 029-22032 11. Field/Pool Endicoft~Oil Pool Total depth: measured true vertical Effective depth: measured true vertical 11465 feet Plugs (measured) ' 10505 BKB feet 11377 feet Junk (measured)" 10429 BKB feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131 131' 2457' 13-3/8" 3006 c.f. Permafrost 2496' 2496' 10507' 9-5/8" 2324 c.f. Class G 10546' 9711 1183' 7" 457c. f. C/ass G 10279'- 11462' 9481'- 10502' measured 10920'-10946' (squeezed); 10952'-10960' (open); 10960'-10966' (squeezed), 10972'.10980' (open); 109a0'- 10982' (squeezed); 11002'~11036° (squeezed); 11040'.11060° (squeezed); 11060' .11065' (open); 11065'.11066'(squeezed); 11070'-11074' (squeezed); 11077'-11090' (squeezed); 11106'-11113' (squeezed) true vertical (TVDSS) 9980'-10002'(squeezed), 10007'-10014 (open), I0014'-I0019° (squeezed), 10025'.10031° (open), 10031'-10033 (squeezed), 10050'-10080' (squeezed), 10083'-10100' (squeezed), 10100°-10105' (open), 10105'-10106') squeezed, 10109'-10112' (squeezed), 10115'-10126' (squeezed), 10140'-10146' (squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12. 6# L-80 tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSSV at 1552'. 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment on 8/5/95 Intervals treated (measured) 10952'- 10960', 10972'- 10980', 11060'- 11065' Treatment description including volumes used and final pressure 13 Bbls seawater/mutual solvent mix, 73 Bbls seawater/scale inhibitor mix, 85 Bbls. seawater/2% surfactant mix and 181 Bbls seawater tubing volume. FSWHP = 1550 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1261 15367 2057 0 1540 1325 13445 2606 0 1377 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~1/2~,~.~' 2 ~_'~.~ . .~~.~ Title Senior Technical Assistant II Form 107,~ Rev 06/15/88 Date ~-/~ ~ SUBMIT IN DUPLIC'ATE~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage,' Alaska 99519-6612 4. Location of well at surface 5. Type of Well: Development .. Exploratory Stratigraphic Service RECEIVED 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E 6. Datum elevation (DF or KB) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L- 16 UPI At top of productive interval 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec.-25, T12N, R16E 12. Present well condition summary Total depth: measured true vertical MAR 29 1995 0il & Gas Cons. Commission chor 9. Permit number/approval number 90-43/Not Required 10. APl number 50- 029-22032 11. Field/Pool Endicott Oil Pool 11465 feet 10505 BKB feet Plugs (measured) Effective depth: measured true vertical 11377 feet 10429 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~l depth BKB 92' 30" Driven 131 131' 2457' 13-3/8" 3006 c.f. Permafrost 2496' 2496' 10507' 9-5/8" 2324 c.f. C/ass G 10546' 9711 1183' 7" 457 c.f. Class G 10279' - 11462' 9481' - 10502' measured 10920'-10946' (squeezed); 10952°-10960' (open); I0960'-10966' (squeezed), 10972°-10980° (open); 10980°- 10982' (squeezed); 11002'-11036' (squeezed); 11040'-11060' (squeezed); 11060' .11065' (open); 11065'.11066'(squeezed); 11070'-11074' (squeezed); 11077'-11090' (squeezed); 11106'-11113' (squeezed) true vertical (TVDSS) 9980510002'(squeezed), 10007510014 (open), 10014510019' (squeezed), 10025510031' (open), I0031'-10033 (squeezed), 10050'.I0080' (squeezed), 10083510100' (squeezed), 10100~10105' (open~ 10105~10106~ squeeze~ 10109510112' (squeezed), 10115'-10126' (squeezed), I0140'.I0146' (squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12. 6~ L-BO tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8"packer at 10232'; 4-1/2" SSSVat 1552'. 13. Stimulation or cement squeeze summary Gas shut off coiled tubing cement squeeze on 1/23/94 followed by adding perforations (1/27/95) Intervals treated (measured) 10974'-10982' 1705 Bbls. seawater, 31 Bbls. fresh water, 16 Bbls 15% HCL/IO% Treatment description including volumes used and final pressure Xylene, 15 Bbls 12/3 mud acid, 18 Bbls cement FWHP = 1100 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2246 22065 1377 0 2751 2O872 2643 0 Tubing Pressure I O34 7587 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-.~_~ ~ '~:~-"~ Title Senior Technical Assistant ll :orm 10-4~/Rev 06/15/88 SUBMIT IN DOPLI~ATE Endicott Production Engineering Department , DATE: 1/27195 WELL N~: 2-18/L-16 BP EXPLORATION REP: SERVICE COMPANY: Post Squeeze Perforations POWERS ATLAS/BARBA Ii;' 'DATE/TIME ,, ' '" oF'ERATI0'NS SUMMARY , , '' 123(~' RO. Post radio silence signs at th~" entrance to island and next to well site. ,, 1400 Establish radio silence and arm 9uns. ,, 1420 Install' sSV fusible cap. SIWHP = 1900 psig. WHT = SI F. lAP = 780 psig. CAP = 200 psicj. Choke = 0 Beans. Pressure test lubricator to wellhead pressure. 1430 ' RIH with Gun #1 (8' & 5' switched gun.~, CCL and GR. FlUid level at 410ff. 1545 POP well and bleed pressure to 450 psig. Tie 'in to DLL dated 4/18/90. All the depths listed below are referenced from the DLL. 1610 Shoot gun #lA from 11060' to 11065'. Icg off. Well pressure did not come up. POP well to bleed remaining pressure off. .... 1645, Tie-in and shoot gun # 1B from 10972 to 1098,0'. "iocj off~ si,well and PO'H. , 1 830 RIH with gun #2. Fluid level at 1250~i SIP= 250 psig.. 1910 POP well. ,, 1920 Tie-in and s..hoot (:jun # 2' from 10952 to 10960'. Icg off~ si well and POH. ' 2000 Confirm all shots fired. End radio silenCe. PoP well. Well died. Have operations line up well to 2nd, stage separ.ator to try and lower back pressure. 2105 RDMO Atlas. '1/~'8/95 0800 RU poorboy cjaslift to kick off well. .'.' PERFORATION SUMMARY: GUN DLL DEPTH lA · 110.60-11065 lB 10972-10980 2 10952-10960 FEET SUBZONE 5 3A4 8 3A4 8 3A3 Interval was shot using 3-3/8" guns at 4 spf, 60/120 degree phasing and random orientaion. ~t,s~,~ Oit & Gas Cons. Commiss'~on kncho~ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~,,.,,,.)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate × Pull tubing Alter casing Repair well .. Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 8. 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E At top of productive interval 9. 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E Datum elevation (DF or KB) KBF = 55.10 feet Unit or Property name Duck Island Unit/Endicott Well number 2-18/L-16 MPI 12. Present well condition summary Total depth: measured Permit number/approval number 90-43/Not Required 10. APl number 50- 029-22O32 11465 feet 10505 BKB f eat 11377 feet 10429 BKB feet Size Plugs (measured) Junk (measured) Cemented 11. Field/Pool Endicott Oil Pool RECEIVED 30" 13-3/8" 9 -5/8" JAN 0 3 1995 Alaska 0ii & Gas Cons. Commission Measured depth Anch0ra~ue ve~l depth BKB Driven 131 131' 3006 c.f. Permafrost 2496' 2496' 2324 c.f. Class G 10546' 9711 true vertical Effective depth: measured true vertical Casing Length Structural Conductor 92' Surface 2457' Intermediate 10507' Production Liner 1183' 7" 457c. f. Class G 10279'- 11462' 9481'- 10502' Perforation depth: measured 10920'-10946' (squeezed); 10954'-10966' (squeezed); 10974'-10982'; 11002'-11036' (squeezed); 11040'-11058' (squeezed); 11058' -11066' (squeezed); 11070'-11074' (squeezed); 11077'-11090' (squeezed); 11106'-11113' (squeezed); 10952'-10960'; 10972'-10980' true vertical (TVDSS) 9980'-10002' (squeezed); I0009'-10019' (squeezed); 10026'-10033'; 10050'-10079' (squeezed); 10083'-10099' (squeezed); 10099'-10105' (squeezed); 10109'-10112' (squeezed); 10115'-10126' (squeezed); 10140'-10146' (Squeezed); 10007'-10014'; 10025'-10031' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 tubing with a 4-1/2" taiipipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSSVat 1552'. 13. Stimulation or cement squeeze summary Gas shut off coiled tubing cement squeeze on 10/9/94 followed by adding perforations (10/12/94) Intervals treated (measured) 10974'-10982' Treatment description including volumes used and final pressure 1009 Bbls. seawater, 10 Bbls fresh water, 24 Bbls 15% HCL/IO% Xylene, 16 Bbls cement FSIWHP = 1600 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2344 17138 824 0 742 3488 152744 872 0 1273 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~O. ~'~~~., ~.~. ~-.'/~ ~'z~ T itleSenior Technical A ssistantll Form 10-404~rev 06/15/88 SUBMIT IN DU'PLI~A~.~ i Endicott .... ProduCtion Engineering Department DATE' 10/12/9~1 ~ WELL N~: 2-18/L-16 BP EXPLORATION REP' SERVICE COMPANY' Post Squeeze Perforations POWERS ATLAS/KOENN , , DATE/TIME OPERATIONS SUMMARY 10/12/94 0730 RU.' Post radio silence signs at the entranc~ to island and nexi to ~ell site. 0900 Establish radio silence and arm guns. 0930 Install SSV fusible cap. SIWHP = 1900 psig. WHT = SI F. lAP = 350 psig. OAP = 450 psig. Choke = 0 Beans. Pressure test lubricator to wellhead pressure. 0935 RIH with Gun #1 (5' & 8' switched gun). Saw fluid level at 4300'. 1040 Opened wing valve and bleed pressure to 800 psig. 1045 Sat down at about 11025' MD. Ran a tie in strip to correct depth then tried to work through tight spot. 1115 Could'nt work through. SI well and POOH to shOrten gun length. .. 1215 RIH with gun #1 (8') Saw FL at 2400' - squeeze inflowed. 1300 Sat down again. Pull short tie in strip to correct depth to DLL ~lated 4/18/90. Flow well at 20 beans. 1330 Shoot gun # 1 from 10972' to 10980".' "Log off, SI well (SIWHP'250 psig) and try to work through nodes. Couldn't work through. POOH. 1430 RIH with Gun #2 (8' gun). Saw fluid level at 1400' 1530 POP well at FOC FWHP=250 psig. Tie-in to DLL 1600 ShOot gun #2 from 10952' to 10960'. Log off, SI well and POOH. .. 1700 Confirm all shots fired. End radio silence. POP well. 1730 RDMO. 1830 Well is not flowing. Fluid level is at 1400'. RU hardline for porrbo¥ gaslift. 2100 Well still not flowing, lAP 1350 psig. Choke at 104 beans. Turn well over to operations~ 1....0../13/94 0730 Well kicked off at about 0300. WHP=1600 psig and climbing. PERFORATION SUMMARY' GUN DLL DEPTH FEET SUBZONE I 10972-10980 8 3A4 2 10952-10960 8 3A4 Intervals were shot using 3-3/8" guns at 4 spf, 60/120 degree phasing and random orientaion. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 SBT/GR FINAL BL+RF ECC No. Run # 1 4297.08 Run $ 1 6351.02 Please sign and return'to: Attn.~i~Rodney D. Paulson Atlas Wireline'Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received Date: ~,,.~ .-~..-~ s '~ ~n and return ,~.~t ~o.b,~chutCal ........ Data. ~Cente~ Feceived by FEB 08 1995 Anchora~ STATE OF ALASKA ALA~5~A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging. Perforate~ X Pull tubing Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development Exploraton/ Stratigraphic Service 6. Datum elevation (DF or KB) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L-16 MPI 9. Permit number/approval number 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E AUG "1 1994 0~'t & Gas Cons. commiSSiOn Anch0ra~e 90-43/Not Required 10. APl number 50- 029-22032 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11465 feet 10505 BKB feet 11377 feet 10429 BKB feet Plugs (measured) Junk (measured) ORIGINAL_ Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True verbal depth BKB 92' 30" Driven 131 131' 2457' 13-3/8" 3006 c.f. Permafrost 2496' 2496' 10507' 9-5/8" 2324 c.f. Class G 10546' 9711 1183' 7" 457 c.f. Class G 10279' - 11462' 9481' - 10502' measured 10920'-10946' (squeezed); 10954'-10966' (squeezed); 10974'-10982'; 11002'-11036' (squeezed); 11040'-11058' (squeezed); 11058' -11066' (squeezed); 11070'-11074' (squeezed); 11077'-11090' (squeezed); 11106'-11113' (squeezed) true vertical (TVDSS) 9980'-10002' (squeezed); 10009'-10019' (squeezed); 10026'-10033'; I0050'-10079' (squeezed); 10083'-10099' (squeezed); 10099'-10105' (squeezed); 10109'-10112' (squeezed); 10115'-10126' (squeezed); 10140'-10146' (Squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSS V at 1552'. 13. Stimulation or cement squeeze summary Gas shut off coiled tubing cement squeeze on 6/27/94 followed by adding perforations (6/28/93) Intervals treated (measured) 10920'. 10946; 10954'. 10966', 10974'- 10982', 11002'. 11036; 11040'- 11066; 11070'. 11074', 11077'- 11090; 11106'- 11113' see attachment for volumes used. FSIWHP = 1910 psig Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1869 16041 78 0 4499~'~ 2497 69 0 Tubing Pressure 1973 358 15. Attachments Copies of Logs and Surveys run . . Daily Report of Well Operations X 16. Status of well classification as: Oil ;X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~' ~ . Form 1~,4~06/.-$.5/,88~. ~ ~..~-.--/' Title Senior Technical Asslstantll SUBMIT IN DUPLI(~ATE .NDICOTT 2-18/L-16 GSO (. SQZ 6/27/94 PAGE 3 SUMMARY RU COIL, SQZ UNIT, MI SOLIDS CONTROL VAN AND BJ. PUMP 560 BBLS FSW DOWN BS TO LIQUID PAK WELL. TIH. PUMP 285 SW DOWN COIL TO COOL SUMP. ALL RETURNS ARE CLEAN WITH NO GAS. MIX CMT. FIELD FL 51 CC. LAY IN 17 BBLS CMTAT 400 TO 800 WHP. BUILD WHP TO 3400 PSI OVER NEXT 60 MINUTES. HOLD 3400 PSI FOR 35 MIN. 82 MINUTE LIVE CELL FLUILD LOSS IS 50 CC. SHUT DN PUMP ANDBLOCKED IN WELL. LOST 0 PSI IN 10 MIN. RIH REVERSING OUT CMT. REVERSED DN TO 11,200' CTMD AND PU TO 10640' CTMD. SHUT DN PUMP AND PT SQZ. LOST 60 PSI IN 10 MINS (1960-1900 PSI) JFT. RDMO BJ. SWITCHED TO JETTING AND JETTED SAME INTERVAL. SWITCHED TO REVERSING. RIH REVERSING TO 10,200' CTMD. REVERSED OUT JETTING & LINER VOL. PU TO 5000' CTMD AND UNDERBALANCED WELL (1500 PSI). POOH AND RDMO. LEFT 1900 PSI ON WELL. NOTE: APPROX 8 BBLS PLACED BEHIND PIPE. '" BBLS. 560 FILTERED SEA WATER (FSVV) TO LIQUID PAK WELL BORE[ , ,, 285 FSW DOWN COIL TO COOL DOWN SUMP 1 0 EFFL'0ENT WATER CMT PRE-FlUSH 1 7 CEMENT ..... '"1 6 ' EFFLUENT WATER CM~' POST-"FLUSH 51 FSW TO DISPI~ACE CMT FROM COIL AND BUILD SQUEEZE PRESSURE 295 FSW DOWN BS TO REV'ERSE OUT CMT 9 0 FSW USED FOR JEq-FING 200 "J~SW USED ON FINAL REVERSE OUT " BOTTOM HOLE ASSEMBLY [RUN # I (FT) (IN) (IN) NOWCAM TUBING CONNECTOR 0.90 1.52 2.45 ,,,BP CMT NZL (7/8" BALL) 0,.,50 0.75 3.50 TOTAL TOOL LENGTH 1.40' Gas Cons. Commission Anchor~e Endicott production Engineering Department DATE: 6/28/93 WELL N~: 2-18/L-16 BP EXPLORATION REP: SERVICE COMPANY: . ,A. dditiQnal Perforations POWERS ATLAS/RICHARDS DATE/TIME OPERATIONS SUMMARY , ,, 6/28/941200 'I~U. Post radio silence signs at the entrance to island and next to well site. 1320 Establish radio silence and arm guns. 1335 Install SSV fusible cap. SIWHP = 900 psig. WHT = SI F. lAP = 600 psig. CAP = 250 psig. Choke = 0 Beans. Pressure test lubricator to wellhead pressure. 1345 RIH with Gun #1 (8' gun). 1445 Sat down at 10925' MD. Ran a tie in strip to correct depth then tried to work through tight spot. 1515 Could'nt work through. POOH to remove decentralizer. 1600 CCH. Decided to remove CCL as well as the decentralizer to shorten the tool · , stdng. Tool looked like it was sitting down on the decntratizer. 1615 RIH with gun #1 (8') 1712 .Sat down again. Pull short tie in strip to correct del~th. Tn/to work through. 1733 Couldn't work through. POOH. 1810 CCH. Dissarmgun. RDFN. 6/29/940700 RU. Post radio silence signs at the entrance to island and next to well site. 0815 Establish radio silence and arm guns. 0830 Install SSV fusible cap. SIWHP = 900 psig. WriT = SI F. lAP = 600 psig. CAP = 250 psig. Choke = 0 Beans. Pressure test lubricator to wellhead,pressure. 0845 RIH with Gun #1 (8' gu.n). 0915 Sat down in GLM #5. Could'or work through - Assume it is the broach fish. POOH. 0945 [ CCH Dissarm gun and RDFN.' 6¢30/940730 RU. Post radio silence signs at the entrance to island and next to well site. 0815 Establish radio silence and arm guns. 0830 Install SSV fusible cap. SIWHP = 950 psig. WHT -- SI F. lAP = 600 psig. CAP = ... 250 psig. Choke = 0 Beans. Pressure test lubricator to wellhead pressure. ,., 0845 RIH with Gun #1 (8' gun). 0920 SIWHP 950 psi. POP well and bleed Pressure to 500 psig. 0925 Tie-in to CBL dated 5/6/90. The CBL is the perforation reference Io.q. 0955 Hang gun #1 Top Shot at'10974' MDBKB. 1000 Shoot gun #1 from 10974-10982' MDBKB. No pre.ssure response was seen. ..... 1005 FWHP 250 psi at 60 beans. Well died. SI well and Icg off while POOH. ..... 1050 SIWHP =650 psig fluid level was about 700'. 1100 Confirm all shots fired. End radio silence. POP well. Well died. Turn over to operations. 1105 RDMO. PERFORATION SUMMARY: GUN CBL DEPTH FEET suBzoNE I 10974-10982 8 3A4 Interval was shot using 3-3/8" guns at 4 spf, 60/120 degree phasing and random orientaion. Cons. 6omml~¢on ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 19 July 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 2-18/L-16 3-27/M-33 ~1 PFC/GR/CCL FINAL BL 1 PFC/GR/CCL RF SEPIA ~ PFC/GR/CCL FINAL BL~ 1 PFC/GR/CCL RF SEPIA 4-38/K-34 2-04/M-19 -~ SBT/GR/CCL FINAL BL PFC/GR/CC . FINAL 1 SBT/GR/CCL RF SEPIA ! PFC/GR/CCL RF SEPIA /1 PDK/GR/CCL FINAL BL 1 PDK/GR/CCL RF SEPIA ECC No. Run ~ 1 4297.05 Run # 1 Run # 1 6006.03 Run # 1 Run # 1 Run ~ 1 Run # 1 Run # 1 6235.00 Run ~ 1 5985.09 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Received by: Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by D~te RECEIVED MAY 1 7 1994 Alasl{a Oil & (~as Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. RE: ANCHORAGE AK, 99501. USA Date: 3 May 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 2-18/','.-16 1 PLS FINAL BL /~ PLS FINAL RF SEPIA Run # 1 Run # 1 2-62/Q-17 (MPI) 1PLS FINAL BL ' PLS FINAL RF SEPIA Run # 1 Run # 1 3-11/M-30 SDI /~1 SPINR/TEMP FINAL BL SPINR/TEMP RF SEPIA Run # 1 Run ~ 1 2-08/K-16 MPI 1 PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 Run # 1 1 PLS/SPNR FINAL BL i P~.S/SPNR ~ SEPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ECC No. 4297.04 6191.00 5723.03 6175.01 5764.03 Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,.,,,-)N REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging Perforate × /../~3i'''' ~,~~[ Pull tubing Alter casing Repair well Other X *~y~ ~'] 6. Datum elevation (DF or KB) 1. Operations performed: Operation shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1902' SNL, 2213' WEL, Sec. 36, T12N, R16E At top of productive interval 4440' SNL, 1516' WEL, Sec. 25, T12N, R16E At effective depth 4036' SNL, 1355' WEL, Sec. 25, T12N, R16E At total depth 3995' SNL, 1339' WEL, Sec. 25, T12N, R16E RECEIVED Gas Cons. Commission A~chor~ge 12. Present well condition summary Total depth: measured true vertical 11465 feet 10505 BKB feet Plugs (measured) KBF = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-18/L-16 MPi 9. Permit number/approval number 90-43/Not Required 10. APl number 50- 029-22032 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 11377 feet 10429 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True verbal depth BKB 92' 30" Driven 131 131' 2457' 13-3/8" 3006 c.f. Permafrost 2496' 2496' 10507' 9-5/8" 2324 c.f. Class G 10546' 9711 1183' 7" 457 c.f. Class G 10279' - 11462' 9481' - 10502' measured 10920'-10946' (squeezed); 10954'-10966' (squeezed); 10974'-10982' (squeezed); 11002'-11036' (squeezed); 11040'-11058' (squeezed); 11058' -11066'; 11070'-11074' (squeezed); 11077'-11090'; 11106'-11113'. true vertical (TVDSS) 9980'-10002' (squeezed); 10009'-10019' (squeezed); 10026'-10033' (squeezed); 10050'-10079' (squeezed); 10083'-10099' (squeezed); 10099'-10105'; 10109'-10112' (squeezed); 10115'-10126;' 10140'-10146: Tubing (size, grade, and measured depth) 4-1/2" 12.6~ L-80 tubing with a 4-1/2" tailpipe to 10318' Packers and SSSV (type and measured depth) 9-5/8" packer at 10232'; 4-1/2" SSSV at 1552'. 13. Stimulation or cement squeeze summary 8/29/93 cement squeeze; 9/2/93 cement squeeze #2 Intervals treated (measured) 10920'- 10946', 10954'- 10966; 10974'- 10982; 11002'- 11036', 11040'- 11064, 11070'- 11074', 11077'- 11090' Treatment description including volumes used and final pressure see attachments for volumes used. Cement Squeeze #1 FSIWHP = 2400 psig. Cement Squeeze #2 FSlWHP = 2760 psig 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4000 23125 65 0 2280 2663 ~20972 "~ 140 0 1909 16. St~us of wellclassific~ion as: Oil x Gas Suspended 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned L"~}~.F~{~/~.{__p' ~. ~'~~ TitleSenior Technical Assistant ll Form 10240'4~, Rev 06/15/88 Service SUBMIT IN DOPI.J~ATE r / J I !DEPTHI(BPM IPUMPED NOZZLE RETURN Page 4 COMMENTS ~UMMARY WELL FLOWING ON ARRIVAL. SI AND LIQUID PACK WELLBORE W/424 BBLS SW. RIH W/3.5" CMT NOZ AND TAG @ 11342' ELMD. COOL SUMP AND PERFS W/162 BBLS SW. INJECTIVITY WAS 1.5 BPM @ 50 PSI. PUMP CEMENT AS BELOW BEGINNING @ 400 PSI INITIAL AND INCREASING TO 3200 PSI OVER 80 MIN. LRO'D TO 11330' CTD. JETTED CLEAN TO 10500'. REV'D OUT AGAIN TO 11330'. REV IN N2 WHILE POOH AND LEFT 2400 PSI ON WELL. FLU 424 162 4 22 4 32 279 70 49 40 IDS BBLS SW (KILL) BBLS SW (LIQUID PACK, COOL SUMP AND PERFS) BBLS EW (PREFLUSH) BBLS CEMENT BBLS EW (SPACER) BBLS BBLS BBLS BBLS BBLS SW (DISPLACEMENT) SW (REVERSE OUT) SW (JET PASS) SW (FINAL REVERSE OUT) RECOVERED (N2 DISPLACEMENT) 410 15 WELL CLEANED OUT TO 11330" BBLS LOAD FLUID BEHIND PIPE TODAY BBLS CEMENT RECOVERED CEMENT (B.J. SERVICES) 15.8 PPG CLASS "G" CMT CONTAINING 0.52% FL-33 0.1% CD-32 0.34% R-11 1.0 GAL PER SK FP-6L THICK TIME = 8 HRS 5 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. -- 49.6 ML @ 170°F (REQUESTED RANGE 40 TO 60 ML) FIELD APl F.L. = 47 ML RECEIVED Anchorage Well: 2-18/L-16 DEPTH RATE CTP WHP Operation' GSO //2 ~ate: 9/2/93 OUT ] BBLSI NOZZLE[ RETURN REMARKS CE E.T SU UARY I I 15.8 ppg Class "G" cement including Lab thickening time: 8 hrs~ 5 min 0.52 % FL-33 Lab fluid loss: 49.6 CC 0.1 %CD-32 Test date' 8/26/93 0.34 % R-11 Field fluid loss: 44.7 CC I g HS FP-6L Live cell loss: 91 CC , Lab APl filter cake: 7/8" 21 BBL pumped Field APl filter cake: I" 18.5 BBL recovered Live cell cake: 3 1/4" 15 % HCI including: 10 % Xylene 0.7 % S-500 0.4 % ACI -274 25 ppt Ferrotrol 210 0.4 % NE-41 FLUIDS PUMPED BBLS. DESCRIPTION 226 Bullhead Sea Water 183 SW Circulate while RIH, partial rtns to surface. 207 SW circulate sump, rtns to surface. 12 15 % HCl with 10 % X~/lene 60 SW Overflush Acid and Displace Coil . 20 Effluent Water (Preflush) 21 Class "G" Cement ) 5 Effluent Water (Postflush) 66 Sea Water (Displacement) 540 Sea Water (Jetting and Reversing) 0 Biozan 0 Methanol BOTTOM-HOLE ASSEMBLY Tool String Descriptions I o.o. I I.D. I Length] Comments Coiled Tubing Connector 2.75" I 1.0' Nozzle 3.5"I 0.5' Combo Nozzle. TOTAL LENGTH 1.5' RECEIVED i Endicott Production Engineering Department DATE: 9/5/93 WELL N~: 2-18/L-16 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: RE-PERFORATE MARTIN ATLAS WlRELINE SERVICES DATE TIME OPERATIONS SUMMARY 9/5/93 0830 ATLAS ON LOCATION. RIG UP, ARM GUN AND PRESSURE TEST WHP = 300 PSI, lAP = OAP = 350 PSI. 0945 RIH. TIE IN TO CBT DATED 05/06/90. 1135 SHOOT 3-3/8" GUN AT 11,077' TO 11,090'. POH. 1140 WHP = 550 PSI. 1145 WHP = 750 PSI. 1 230 OOH. RIGGING DOWN. WHP = 1000 PSI. 1245 POP WELL AT 30/64" CHOKE. WELL DIES IN 10 MINUTES. LEAVE IN 3 PHASE HEADER TO SEE IF WELL WILL KICK OFF. 1900 WELL FINALLY FLOWING. 9/6/93 1 000 IN TEST SEPARATOR. ,, PERFORATING DATA: INTERVAL: 11,077" TO 11,090' GUN: 3-3/8" SPECTRA JET, 21 GRAM CHARGE, 60° - 120° PHASING RANDOM ORIENTATION RECEIVED I I Endicott Production Engineering Department DATE: 1/4/94 WELL N°: 2-18/L-16 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations KIMMET/POWERS ATLAS DATE/TIME OPERATIONS SUMMARY i 1030 RU. Post radio silence signs at the entrance to island and next to well site. ,, 1130 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 1220 Install SSV fusible cap. WHP = 1750 psig. WHT = 96 deg F. IAP = 300 psig. OAP = 275 0sig. Choke = 55 Beans. 1230 Pressure test lubricator to wellhead pressure. 1240 RIH with select fire guns. SIWHP = 2750 psig. .... 1545 Open wing valve and set production choke to 50 beans. 1610 Tie in to DLL dated 4/18/90. All of the depths listed below are from the open hole reference log. FWHP = 1925 psig @ 50/104 bean choke. 1620 Hang gun #1 Top Shot at 11106' MDBKB. 1620 Shoot gun #1 from 11106-11113 MDBKB and flow well for 15-20 minutes. FWHP = 1970 psig. 1640 HANG Gun #2 (11058 feet). 1640 Shoot gun # 2 from 11058-11064' MDBKB. FWHP = 1920 psig. 1800 SI well and POH. SIWHP =2950 psiR. Confirm all shots fired. 1840 End radio silence. 1900 RD. POP. PERFORATION SUMMARY: GUN .INTERVAL(DLL) CBL DEPTH FEET SUBZQNE 1 11106-11113 7 3A 2 11058-11066 6 3A All intervals were shot using 3-3/8" guns at 4 spf, 60/120 degree phasing and random orientation. RECEIVED ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 21 January 1994 RE: Transmittal of Data ECC #: 4297.03 Data: PL Dear Sir/Madam, Reference: . BP 2-18/5-16 ~D __~ ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL PFC/CCL FINAL BL PFC/CCL FINAL RF Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by:.. Date: WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME ~'7'-'81 .--1-09/J-18 ~57- ;5 2.-1-41/O-23 ~q---I lq--t -67/-r-20 ~'(o-~Z--.2-04/M-19 c~ o..- qB--2-18/L-16 ~o- z-q-2-36/O-14 ~ 2.-17_ i-3-03/J-33 9/17/93 9/20/93 9/25/93 9/21/93 9/21/93 9/22/93 9/24/93 11500'- 11951' 11050'-11875' 11300'-11800' 10300'-10750' 10800'-11150' 10550'-11350' 13425'-13725' Production Logging Services PDK-100 Production Logging Services Production Logging Services Production Logging Services PDK-100 Production Logging Services ATLAS WI RELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE t t ~70'--' I tq~O' BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 11, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, _~e/anne L. Haas Senior Technical Assistant II JLH Enclosures xc: File 06.10 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 16, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, Assistant II JLH Enclosures xc: File 06.10 SEp 2 0 1993 WELL NAME DATE ~?.-.~ I 1.09/J~18 8/22/93 INTERVALS LOG NAME RUN NO COMPANY NAME 11200'-11945' PDK-100 LOG I ATLAS WIRELINE 3-17/J-30 2-18/L-16 2-36/0-14 1-35/0-25 2-28/P-19 1-15/P-25 3-47/Q-35 1-51/V-20 7/27/93 9/5/93 8/20/93 8/25/93 8/28/93 9/4/93 9/6/93 8/21/93 13400'- 13950' 10900'-11200' 10800'-11250' 12700'-13261' 9800'-10320' 12400'-12860' 1 CO'-10450' 3600'-12700' PRODUCTION LOGGING SERVICES PFC/GR/CCL PRODUCTION LOGGING.SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES 1 ATLAS WIRELINE I ATLAS WIRELINE I ATLAS WIRELINE I ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE INTERVALS LOG NAME RUN NO COMPANY NAME WELL "AME/~DATE 1-15/P-25 L~/t~' ~, 6/5/93 1-27/P-20 %q 'e~. 6 / 26/9 3 2-04/M-19 ~'(e'~'~'6 / 25 / 9 3 2-18/1-16 ~I0'~'~ 7/1 7/93 2-50/U-08 ~1~-[,17 / 18/93 7/18/93 ,~,~ 7/20/93 3-21/L-34 6/19/93 3-25/M-27 ~b"1~"6/27/93 3-49/J-40~q 6/28/93 · ~0 7/9/93 12000'-12878' 10100'-10709' 10000'710695' 10700"11334' 13500'-15452' 13500'-15417' 14737'-14905' 12300'-12830' 13600'-13957' 14350'-14856' 14700'-14870' PFC Gamma Ray CNL/GR PDK-100 Production Logging Services Segmented Bond Log Compensated Neutron/GR/CCL GR/CCL PDB-100/GR/CCL Production Logging (PITS) PFC/GR/CCL PFC/CCL ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS June 13, 1991 Alaska Oil and Gas Conservation Commission Page 2 WELL 1-4 9/P-2/1 TEMPERATURE LOG 1 0770'-11272' WELL 1-69/V-19 / TEMPERATURE SURVEY 11200'-12885' WELL 2-02/P-18 VE nLOG 70'-6756' ATLAS WIRELINE WELL 2-14/O-16 PRODUCTION PROFILE SURVEy 7000'-10990' WELL 2-18/L-16 TEMP/CAP SURVEY V~ 11720'-11343' WELL 2-20/L-15 TEMPERATURE COLLAR LOG 10100'-11550' WELL 2-26/N-14 ~'~ STATIC TEMPERATURE SURVEyV/ 11 370'-1 2360' WELL 2-44/R-12 X// ~q~' ~ R~YI_O~ 10000'-12636' ATLAS WIRELINE 2013/JLH/clt 4/22/91 RUN ONE 5/1 8/91 RUNONE 5/3/91 RUNONE 5/26/91 RUNONE 5/23/91 RUN ONE 5/25/91 RUN ONE 5/16/91 RUNONE 4/24/91 RUNONE AlaSka 0ti & Gas cons. A~chO~a~e WELL 2-18/L-16. PRODUCTION PROFILE 10700'-11346' CAMCO 9/13-14/90 RUNONE WELL 2-68/S-17 STATIC TEMP SURVEY 10650'-11100' HRS "'--CAPACITANCE ~~95'-10895' PRODUCTION LOG 154' - 11125' SCHLUMBERGER 10/1/90 RUNONE 9/17/90 RUNONE WELL 3-47/Q-3~ PRODUCTION PROFILE 10000'-11263' CAMCO 9/10/90 RUNC~E · WELL 4-48/K-4:~ PRODUCTION PROFILE 15870'-16230' CAMCO Sincerely, ~.1-: Haas JLH/lms 9/1 0-11/90 RUNONE cc: File 06.10 ,, ~ 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 90-43 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22032 4.' Location of well at surface~~- '~"~[I 9. Unit or Lease Name 1902' SNL, 2213' WEL, SEC. 36, T12N, R16E ~!"i~i!~i~:i~'~.;;;';~'r Duck Island Unit/Endicott At Top Producing Interval ! ~,;..~.;~j;~j:~ [ 10. Well Number ,.. ~"~~~__~ 11. Field and Pool At Total Depth Endicott Field/Endicott Pool 3995' SNL, 1339' WEL, SEC. 25, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.10' J ADL 34633 i12. Date SptJdded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04-02-90 04-17-90 07-26-90I 6-12' 'MSL feet USE I ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11465'MD/10504'TVD 11377'MD/10429'TVD YES [] NO []I 1552'feet MD'1 1446' 22. Type Electric or Other Logs Run DLL/CHT/GR/PFC, RFT 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMi~I'rlNG RECORD AMOUNT PULLED 30" Cond. Surface 131' ,, 13-3/8" 68~ ~TBOCV,~ Surface 2496' 17-1/2" 3006 cufl Permafrost 9-5/8" 47# NT80S Surface 8990' 12-1/4" 9-5/8" 47# NTB$HS 8990' 10546' 12-1/4" 2324 cu ft Class G ...... 7" 29# NTgSHS 10279' 11462 8-1/2" 457 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Schlumberger 3-3/8" @ 4 spf 4-1/2" 12. 6# L-80 10318' 10232' MD TVSss 10920'- 10946' 9980'- 10002' ~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10954'-10966' 10009'-10019' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10974'-10982' 10026'-10033' 13'3/8"X 9-5/8" Downsqueeze annulus w/150 bbls 11002'-11036' 11050'-10079' 11040'-11066' 10083'-10105' Dry Crude 11070'-11074' 10109'- 10112' 11077'-11090' 10115'-10126' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) July26, 1990 IF/owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Fiow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ ~'~.' CORE DATA '~'~'ief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit corhc~)~i~ r,,, ~ j~l.~ ~1~' E~ E ! V E Ui AUG 2 ? 1990 ~/aska Oil & Gas Cons. Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS . .,-~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top HRZ 10206' 9419' Put River 10501' 96 72' Top Kekiktuk 10516' 9685' r~, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION O I G I tl L DAILY DRILLING REPORT: As of 0600 Hrs. Monday, April 2, 1990 WELL: 2-18/L-16 PRUDHOE BAY UNIT RIG: DOYON #15 Day: 1 Depth at 0600 Hrs. = 1,875 48 Hour Footage = 1,875 AP! No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' Drilling. Summary of Last 48 Hours: Move rig to slot 2-18 and rig up. Accept rig on Well 2-18/L-16 at 0330 on 4/1/90. Spud well at 0430 hrs on 4/1/90. Drill and survey 17-1/2" hole to 1875'. Wells Shut-in For Drill-By: MudType Mud Weight Viscosity PV Y_~_P Fluid Loss Solids Temp Spud Mud 9.4 lC/gal 250 Sec. 11 78 13.8 cc 3% 55 °F Survey Depth Angle .Direction TVD N-S E-W Dog Leg Section Coordinate Coordinate °/1,00', Reviewed By: AUG 2 7 BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday, April 3, 1990 WELL: 2-18/L-16 RIG: DOYON #15 Day: 2 Depth at 0600 Hrs. = 2,510 24 Hour Footage = 635 AP! No. AFE Number: AFE Amount = Current Field Costs = 50-029-22032 717578 Current Operation: Cementing 13-3/8" casing. Summary of Last 24 Hours: Drill and survey 17-1/2" hole to 2510'. Run 13-3/8" casing. Wells Shut-in For Drill-By: Condition hole for casing. POH. Mud Type Mud Weight Viscosity P ¥ Spud 9.6 Cf/gal 90 Sec. 6 YP Fluid Loss Solids Temp- 57 18.0 cc 3% 56 °F Survey ~ Angle J~.LEc..6.tJ.¢~ TVD N-S E-W DOg Leg Section Coordinate Coordinate °/100' Reviewed By:,,,~~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, April 4, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 3 Depth at 0600 Hrs. = 2,920 24 Hour Footage = 410 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation: Drilling. Summary of Last 24 Hours: Wells Shut-in For Drill-By: , Mud 'T'_vpe LSND Cement 13-3/8" casing. N/U split speedhead. RIH w/12-1/4" BHA. Test casing to 3000 psi- ok. Drill cement and shoe. Drill 12-1/4" hole to 2920'. , , ,, Mud Weight Viscosity P V .YP, Fluid Loss Solids Temp 9.3 CC/gal 42 Sec. 8 8 22.0 cc 4% 59 °F Survey Depth Anale -- N~S E-W Dog Leg Direction TVD Section Coordinate Coordinate °/100' Reviewed By: BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Thursday, April 5, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 4 Depth at 0600 Hrs. = 3,618 24 Hour Footage = 698 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' RIH with bit #5. Summary of Last 24 Hours: Drilled from 2920' to 3618'. Mud Type Mud Weight Viscosity LSND 9.3 Cf/gal 38 Sec. P V YP Fluid Loss Solids Temp 8 9 8.5 cc 6% 68 °F Survey .1~ Angle ~ TVD N-S. E-W Dog Leg Section Coordinate Coordinate °/100, Reviewed By:~-~-'~ BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Friday, April 6, 1990 WELL: 2-18/L-16 ENDICOTT UNIT RIG: DOYON #15 Day: 5 Depth at 0600 Hrs. = 5,098 24 Hour Footage = 1,480 APl No. AFE Number: AFE Amount = Current Field Costs = 5O-O29-22O32 717578 Current Operation' POH for mud motor'. Summary of Last 24 Hours: Drilled from 3618' to 5098'. Mud Tvoe Mud Weiaht Viscosity LSND 9.3 #/gal 37 Sec. PV YP Fluid Loss ~ 8 8 10.3 cc 6% Temp 79 °F Survey Deoth An(~le ~ TVD 4,863 0.40 N4W 4,861 5,052 0.40 N17.4E 5,050 N-S, E-W Section Coordinate Coordinate 70 N67 E17 71 N69 E17 Dog Leg o/100' 0.48 0.21 Reviewed By:1~- BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Monday, April 9, 1990 WELL: 2-18/L-16 ENDICOTT UNIT RIG: DOYON #15 Day: 8 Depth at 0600 Hrs. = 7,448 72 Hour Footage = 2,350 AP! No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation: RIH with Bit #9. Summary of Last 72 Hours: Drilled from 5098' to 7448'. Mud Type Mud Weight Viscosity LSND 9.7 #/gal 36 Sec. P¥ YP Fluid Loss Solids 9 8 6.9 cc 8% Temp 90 OF Survey Depth Angle Direction TV[;:) 35 5,640 15.80 N14E 5,630 43 6,427 34.40 N13.4E 6,340 51 7,174 36.50 N12.7E 6,939 N-S E-W Section Coordinate Coordinate N151 E38 486 N475 E107 932 N911 E206 Dog Leg o/100' 3.30 2.80 0.25 Reviewed By: BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Tuesday, April 10, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 9 Depth at 0600 Hrs. = 8,393 24 Hour Footage = 945 AP! No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' POH to change bit and BHA. Summary of Last 24 Hours: Drilled from 7448' to 8393' Mud Tv.De Mud Weight Viscosity LSND 9.8 Cf/gal 34 Sec. .P V. .YP. Fluid Loss Solids Temp 8 7 6.6 cc 9% 90 °F Survey ~ Angle ~ TVD 63 8,306 37.50 N14.1E 7,851 N-$ E-W Dog Leg Section Coordinate Coordinate °/100' 1,600 N1565 E353 0.34 Reviewed By' BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, April 11, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 10 Depth at 0600 Hrs. = 8,985 24 Hour Footage = 592 APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22032 717578 Current Operation' Drilling. Summary of Last 24 Hours' Drilled from 8393' to 8985'. Mud Type Mud Weight Viscosity FW/LIG 10.0 #/gal 34 Sec. P V YP Fluid Loss Solids Temp 9 9 6.7 cc 10% 92 °F Survey Depth Anale Direction TVD N-S E-W Dog Leg Section Coordinate Coordinate °/100' Reviewed By: ~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Thursday, April 12, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 11 Depth at 0600 Hrs. = 9,318 24 Hour Footage = 333 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation: Drilling. Summary of Last 24 Hours: Drilled from 8985' to 9318'. Mud TvDe Ligno Mud Weiaht Viscosity 10.0 CC/gal 35 Sec. P V yP Fluid Loss Solids Temp 1 0 1 0 6.4 cc 10% 92 °F Survey Anale -- D_JLe..C,J.[9~ TVD N-S E-W Do Lg_~ Section Coordinate .Coordinate °/100' Reviewed By~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Tuesday, April 17, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 1 6 Depth at 0600 Hrs. = 10,957 24 Hour Footage = 400 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' Drilling. Summary of Last 24 Hours: Drilled from 10557' to 10957'. ,Mud Type Ligno ~ud Weight Viscosity 9.7 #/gal 36 Sec. PV Y.P Flgid Loss Solids Temp 1 0 7 7.0 cc 8% 96 °F Survey Deoth Angle Direction TVD N-S E-W Dog Leg Coordinate Coordinate °/100! Reviewed By: BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Monday, April 16, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 15 Depth at 0600 Hrs. = 10,557 96 Hour Footage = 1,239 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation: RIH. Summary of Last 96 Hours: Drilled from 9318' to 10,557'. Ran and cemented 9-5/8" casing. Mud Tvae - . Ligno Mud Weight Vi~(;;osity 9.7 #/gal 38 Sec. pv YP Fluid Loss .Solids 1 0 1 0 6.8 cc 8% Temo oF Survey Death 81 9,996 Anale 33.00 ' r.D_i.Ee,.6.tL~E TVD N20E 9,243 N-S E-W Section ,Coordinate Coordinate 2,556 N2493 E585 Dog Leg °/100' 2.20 Reviewed By: ~-- BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, April 18, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 17 Depth at 0600 Hrs. = 11,465 24 Hour Footage = 508 APl No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' Circulate and clean hole. Summary of Last 24 Hours: Drilled from 10957' to 11465'. Performed "MAD" run with LWD tool. Mud Ty0e Mud Weight Viscosity Ligno 9.8 if/gal 38 Sec. P V Yp, Fluid Loss Solids Temo 15 10 6.0 cc 8% 98 °F Survey D_EEELO. Angle Direction N-S E-W Dog Leg Section Coordinate Coordinate °/100' Reviewed By: ~ RECEIVED BP EXPLORATION DAILY DRILLING REPORT:. ENDICOTT As of 0600 Hrs. Thursday, April 19, 1990 WELL: 2-18/L-16 UNIT RIG: DOYON #15 Day: 1 8 Depth at 0600 Hrs. = 11,465 24 Hour Footage = 0 AP! No. 50-029-22032 AFE Number: 717578 AFE Amount = Current Field Costs = Current Operation' Conditioning hole for 7" liner. Summary of Last 24 Hours: Ran open hole logs and RFT tool. Mud T.vpe Mud Weight Viscosity P V FW/LIG 9.8 CC/gal 38 Sec. 15 yp Fluid Loss Solids 11 6.3 cc 8% Temp oF Survey Deoth Anale Direction TVD N-$ E-W Section Coordinate Coordinate Dog Leg, °/100' Reviewed By: ~ BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Friday, April 20, 1990 WELL: 2-18/L-16 ENDICOTT UNIT RIG: DOYON #15 Day: 1 9 Depth at 0600 Hrs. = 11,465 24 Hour Footage = 0 AP! No. 50-029-22032 AFENumber: 717578 AFE Amount = Current Field Costs = Current Operation' RIH to clean out cement. Summary of Last 24 Hours' Ran and cemented 7" liner. Mud Tvoe Mud Weiaht Viscosity . . -- FW/LIG 9.8 #/gal 36 Sec. P V YP Fluid Loss Solids Temp 12 7 6.2 cc 8% 85 °F Survey Depth Angle Direction TVD N-S E-W Dog Leg Coordinate Coordinate °/100' Reviewed By: ~ GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY BP EXPLORATION COMPANY MPI 2-18/L16 WELL NAME ENDICOTT, ALASKA LOCATION AL 490 Dll MWD 4/19/90 JOB NUMBER KEVIN DESORMEAUX NAME TYPE SURVEY DIRECTIONAL SUPERVISOR TITLE DATE SIGNATURE 0 FT. 10577 FT DEPTH INTERVAL DATE SURVEY TAKEN FROM TO 4/01/90 4/14/90 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. RECEIVED, ,AUG 2 ? 19,90 Alaska, ,Ojl& ..Gas Cons. CQml~ss[{~l .. GREAT LA~D DIRECTIONAL DRILLING,INC Client .............. : BP EXPLORATION Well ................ : MPI 2-18/L-16 Vertical Section at.: N 16.71 E Magnetic Declination: 30 deg 36 min E Data file name ...... : B:ML16D.DAT RECORD OF SURVEY (Well assumed vertical to MD of 4/19/9 Computation: RADIUS OF CURVATURE Survey date: 4/2/90 Method ..... : MWD RKB Height.: 55.1 ft 0.0) MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD -- 0.00 N 0.00 E 0.00 N 0.00 E 0.46 S 86.00 E 0.15 S 2.08 E 1.12 N 76.00 E 0.01 N 3.86 E 1.95 N 58.00 E 0.52 N 5.05 E 3.20 N 25.00 E 1.55 N 5.97 E 0 0 0 0.00 -55.10 477 0 30 476.99 421.89 752 0 15 751.99 696.89 1050 0 15 1049.99 994.89 1371 0 15 1370.98 1315.88 CLOSURE DI STANCE DG MN S -- 0.00. N 0 0 0 E 2.08 S 86 0 0 E 3.86 N 89 50 10 E 5.08 N 84 9 32 E 6.17 N 75 25 46 E DOG LE deg/~ 0.00 0.10 0.09 0.00 0.00 1738 2116 2406 2630 3013 0 30 1737.97 1682.87 0 15 2115.97 2060.87 0 0 2405.96 2350.86 0 15 2629.96 2574.86 0 30' 3012.96 2957.86 5.59 N 7.00 E 5.90 S 45.00 W 5.95 N 0.00 W 6.09 N 57.00 W 8.01 N 23.00 E 3.85 N 6.63 E 4.68 N 4.93 E 4.87 N 4.47 E 5.13 N 4.06 E 7.34 N 3.39 E 7.67 N 59 50 39 E 6.80 N 46 30 36 E 6.61 N 42 34 45 E 6.55 N 38 21 32 E 8.09 N 24 46 39 E 0.06 0.06 0.08 0.11 0.06 3203 3312 3406 3500 3615 1 45 3202.91 3147.81 2 42 3311.83 3256.73 4 24 3405.65 3350.55 4 54 3499.34 3444.24 4 18 3613.97 3558.87 11.38 N 57.00 E 15.21 N 23.00 E 20.84 N 38.40 E 28.31 N 12.90 E 37.34 N 1.20 W 10.16 N 5.75 E 13.35 N 8.43 E 18.34 N 11.39 E 25.15 N 14.67 E 34.31 N 15.60 E 11.67 N 29 31 13 E 15.79 N 32 16 24 E 21.59 N 31 51 2 E 29.12 N 30 14 38 E 37.69 N 24 27 28 E 0.65 0.87 1.81 0, -~ ; 0.~. 3717 3810 3905 4000 4094 18 3715.74 3660.64 36' 3808.62 3753.52 12 3903.53 3848.43 48 3998.48 3943.38 54 4092.43 4037.33 43.87 N 4.70 E 48.55 N 3.80 E 52.44 N 5.70 E 55.71 N 10.00 E 58.74 N 21.30 E 41.06 N 15.81 E 45.83 N 16.16 E 49.80 N 16.49 E 53.08 N 16.95 E 56.00 N 17.76 E 44.00 N 21 3 33 E 48.60 N 19 25 38 E 52.46 N 18 19 35 E 55.72 N 17 42 24 E 58.75 N 17 36 2 E 0.98 0.75 0.42 0.42 0.10 4199 4291 4386 4481 4572 1 18 4197.39 4142.29 1 12 4289.36 4234.26 0 54 4384.35 4329.25 0 48 4479.34 4424.24 0 36 4570.33 4515.23 61.67 N 14.60 E 63.66 N 3.40 E 65.34 N 0.50 W 66.67 N 4.50 W 67.70 N 6.00 W 58.79 N 18.67 E 60.76 N 18.98 E 62.50 N 19.02 E 63.91 N 18.96 E 65.02 N 18.86 E 61.68 N 17 37 2 E 63.66 N 17 20 49 E 65.34 N 16 55 44-E 66.67 N 16 31 34 E 67.70 N 16 10 37 E 0.57 0.10 0.31 0.10 0.22 MPI 2-18/L-16 4/19/90 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM'WELL-HEAD CLOSURE DISTANCE DG MN S 4674 4768 4863 4958 5052 0 36 4672.32 4617.22 0 48 4766.32 4711.22 0 24 4861.31 4806.21 0 24 4956.31 4901.21 0 24 5050.31 4995.21 68.61 N 22.00 W 69.48 N 26.50 W 70.32 N 4.00 W 70.92 N 10.60 W 71.56 N 17.40 E 66.05 N 18.60 E 67.10 N 18.13 E 68.05 N 17.87 E 68.71 N 17.79 E 69.36 N 17.83 E 68.62 N 15 43 48 E 69.51 N 15 7 19 E 70.36 N 14 42 54 E 70.98 N 14 30 52 E 71.61 N 14 24 51 E 5167 3 54 5165.21 5110.11 5260 6 30 5257.82 5202.72 5355 8 48 5351.97 5296.87 5450 11 36 5445.46 5390.36 5545 12 48 5538.31 5483.21 75.84 N 27.80 E 84.19 N 20.90 E 96.83 N 14.70 E 113.60 N 10.80 E 133.55 N 9.60 E 73.34 N 19.48 E 81.01 N 22.96 E 93.04 N 26.82 E 109.45 N 30.53 E 129.21 N 34.09 E 75.88 N 14 52 39 E 84.20 N 15 49 15 E 96.83 N 16 4 45 E 113.63 N 15 35 12 E 133.63 N 14 46 43 E 5640 15 48 5630.35 5575.25 5735 18 30 5721.12 5666.02 5830 20 48 5810.58 5755.48 5940 22 30 5912.82 5857.72 6042 25 0 6006.17 5951.07 156.92 N 14.00 E 184.92 N 17.20 E 216.86 N 14.10 E 257.26 N 8.90 E 297.95 N 8.90 E 152.17 N 38.88 E 179.14 N 46.41 E 209.90 N 55.03 E 249.65 N 63.12 E 290.23 N 69.47 E 157.06 N 14 20 2 E 185.06 N.14 31 32 E 216.99 N 14 41 27 E 257.51 N 14 11. 19 E 298.43 N 13 27 42 E 6139 27 0 6093.35 6038.25 6231 29 24 6174.43 6119.33 6325 31 36 6255.41 6200.31 6427 34 24 6340.95 6285.85 6505 37 0 6404.29 6349.19 340.13 N 10.00 E 383.37 N 11.70 E 430.92 N 12.40 E 486.34 N 13.40 E 531.77 N 12.80 E 332.17 N 76.45 E 374.87 N 84.64 E 421.52 N 94.60 E 475.67 N 107.00 E 519.99 N 117.31 E 340.86 N 12 57 42 E 384.30 N 12 43 22 E 432.01 N 12 38 55 E 487.55 N 12 40 38 E 533.06 N 12 42 48 E 6600 37 6 6480.11 6425.01 6695 36 54 6555.98 6500.88 6789 36 54 6631.15 6576.05 6884 37 12 6706.97 6651.87 6977 36 48 6781.24 6726.14 588.87 N 12.70 E 645.90 N 12.80 E 702.20 N 12.30 E 759.29 N 13.10 E 815.16 N 13.30 E 575.82 N 129.94 E 631.58 N 142.56 E 686.67 N 154.83 E 742.51 N 167.41 E 797.00 N 180.19 E 590.30 N 12 43 1 E 647.47 N 12 43 11 E 703.91 N 12 42 22 E 761.15 N 12 42 20 E 817.12 N 12 44 22 E 7080 36 42 6863.77 6808.67 876.66 N 12.90 E 857.03 N 7174 36 30 6939.24 6884.14 932.58 N 12.70 E 911.68 N 7271 36 0 7017.46 6962.36 989.80 N 13.00 E 967.60 N 7354 35 36 7084.78 7029.68 1038.25 N 12.80 E 1014.92 N 7448 35 12 7161.40 7106.30 1092.57 N 12.60 E 1068.04 N 194.16 E 878.74 N 12 45 53 E 206.57 E 934.79 N 12 46 1 E 219.33 E 992.15 N 12 46 18 E 230.17 E 1040.70 N 12 46 40 E 242.14 E .1095.15 N 12 46 26 E .. DOG LE deg/10 0.00 0.21 0.~2 o, ') 0.00 3.04 2.79 2.42 2.95 1.26 3.17 2.86 2.45 1.69 2.45 2.07 2. 2,76 3.34 0.11 0.21 0.19 0.44 0.43 0.16 0.22 0.52 0.48 0.'.43 MPI 2-18/L-16 4/19/90 RECORD OF SURVEy MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 7542 35 6 7238.26 7183.16 1146.53 N 12.20 E 1120.90 N 253.76 E 7637 35 36 7315.74 7260.64 1201.32 N 12.20 E 1174.62 N 265.38 E 7732 35 48 7392.89 7337.79 1256.59 N 12.20 E 1228.81 N 277.09 E 7827 36 36 7469.55 7414.45 1312.50 N 11.60 E 1283.71 N 288.66 E 7927 36 48 7549.73 7494.63 1372.05 N 12.30 E 1342.17 N. 301.04 E 8022 37 0 7625.70 7570.60 1428.94 N 12.80 E 1397.85 N 8116 37 24 7700.57 7645.47 1485.67 N 13.60 E 1453.18 N 8211 37 36 7775.94 7720.84 1543.42 N 13.60 E 1509.39 N 8306 37 30 7851.26 7796.16 1601.24 N 14.10 E 1565.61 N 8394 37 18 7921.17 7866.07 1654.60 N 12.60 E 1617.61 N 313.43 E 326.41 E 340.01 E 353.87 E 366.21 E 8488 36 54 7996.14 7941.04 1711.16 N 12.80 E 1672.92 N 8583 36 54 8072.11 8017.01 1768.07 N 13.00 E 1728.52 N 8685 35 48 8154.26 8099.16 1828.40 N 13.00 E 1787.43 N 8780 35 12 8231.60 8176.50 1883.45 N 12.80 E 1841.21 N 8875 34 42 8309.47 8254.37 1937.75 N 13.10 E 1894.24 N 378.67 E 391.41 E 405.01 E 417.32 E 429.52 E 8970 34 6 8387.86 8332.76 1991.31 N 12.80 E 1946.55 N 9050 33 42 8454.26 8399.16 2035.84 N 13.50 E 1990.00 N 9149 33 42 8536.62 8481.52 2090.71 N 14.50 E 2043.30 N 9246 33 36 8617.37 8562.27 2144.40 N 13.80 E 2095.41 N 9341 33 36 8696.49 8641.39 2196.90 N 13.60 E 2146.49 N 441.55 E 451.70 E 464.99 E 478.13 E 490.58 E 9436 33 36 8775.62 8720.52 2249.40 N 13.70 E 2197.58 N 9531 33 42 8854.70 8799.60 2301.98 N 14.30 E 2248.66 N 9626 33 42 8933.74 8878.64 2354.67 N 15.60 E 2299.58 N 9714 33 18 9007.12 8952.02 2403.23 N 15.20 E 2346.41 N 9808 33 18 9085.69 9030.59 2454.83 N 16.40 E 2396.06 N 502.98 E 515.72 E 529.32 E 542.21E 556.27 E 9902 33 18 9164.25 9109.15 2506.43 N 16.20 E 2445.60 N 9996 33 0 9242.95 9187.85 2557.81 N 20.00 E 2494.45 N 10090 32 42 9321.92 9266.82 2608.75 N 18.20 E 2542.63 N 10184 32 12 9401.24 9346.14 2659.17 N 18.20 E 2590.54 N 10279 31 24 9481.98 9426.88 2709.19 N 19.80 E 2637.87 N 570.75 E 586.72 E 603.40 E 619.15 E 635.45 E CLOSURE DISTANCE DG MN S 1149.27 N 12 45 22 E 1204.23 N 12 43 51E 1259.66 N 12 42 27 E 1315.76 N 12 40 23 E 1375.52 N 12 38 30 E 1432.56 N 12 38 17 E 1489.39 N 12 39 34 E 1547.21 N 12 41 41 E 1605.10 N 12 44 11E 1658.55 N 12 45 22 E 1715.25 N 12 45 15 E 1772.29 N 12 45 32 E 1832.74 N 12 46 1 E 1887.91 N 12. 46 15 E 1942.33 N 12 46 33 E 1996.00 N 12 46 50 E 2040.62 N 12 47 19 E 2095.54 N 12 49 13 E 2149.27 N 12 51 13 E 2201.84 N 12 52 25 E 2254.41 N 12 53 31E 2307.04 N 12 55 2 E 2359.71 N 12 57 45 E 2408.24 N 13 0 42 E 2459.79 N 13 4 13 E 2511.32 N 13 8 11 E 2562.52 N 13 14 9 E 2613.25 N 13 21 0 E 2663.50 N 13 26 31E 2713.33 N 13 32 39 E DOG LE deg/10 0.17 0.52 0 0.32 0.28 0.52 0.21 0.22 0.66 0.43~ 0.07 1.07 0.63 0.53 0.63 o O. ~ 0.24 0.06 0.03 0.22 0.42 0.47 0.38 0.06 1.24 0.64 0.53 0.95 MPI 2-18/L-16 4/19/90 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD 10337 30 36 9531.70 9476.60 2739.00 N 21.00 E 2665.87 N 645.86 E 10464 30 0 9641.35 9586.25 2802.87 N 21.70 E 2725.55 N 669.19 E 10503 29 42 9675.18 9620.08 2822.21 N 21.40 E 2743.60 N 676.32 E 10577 29 18 9739.58 9684.48 2858.53 N 21.40 E 2777,53 N 689.62 E CLOSURE D~STANCE DG MN S 2742.99 N 13 37 7 E 2806.50 N 13 47 41 E 2825.73 N 13 50 52 E 2861.86 N 13 56 37 E DOG LE deg/10 1.48 0.49 0 MPI 2-18/L-16 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4/19/90 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 55 55 0 0 0 155 155 100 0 0 255 255 200 0 0 355 355 300 0 0 455 455 400 0 0 555 555 500 0 0 655 655 600 0 0 755 755 700 0 0 855 855 800 0 0 955 955 900 0 0 1055 1155 1255 1355 1455 1555 1655 1755 1855 1955 2055 2155 2255 2355 2455 2555 2655 2755 2855 2955 1055 1000 0 0 1155 1100 0 0 1255 1200 0 0 1355 1300 0 0 1455 1400 0 0 1555 1500 0 0 1655 1600 0 0 1755 1700 0 0 1855 1800 0 0 1955 1900 0 0 2055 2000 0 0 2155 2100 0 0 2255 2200 0 0 2355 2300 0 0 2455 2400 0 0 2555 2500 0 0 2655 2600 0 0 2755 2700 0 0 2855 2800 0 0 2955 2900 0 0 RELATIVE COORDINATES FROM WELL-HEAD m 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.10 S 2.58 E 0.04 S 3.23 E 0.02 N 3.87 E 0.19 N 4.27 E 0.36 N 4.67 E 0.53 N 5.07 E 0.86 N 5.35 E 1.18 N 5.64 E 1.50 N 5.92 E 2.08 N 6.12 E 2.71 N 6.30 E 3.33 N 6.48 E 3.89 N 6.55 E 4.11 N 6.10 E 4.33 N 5.65 E 4.55 N 5.21 E 4.70 N 4.87 E 4.77 N 4.71 E 4.84 N 4.55 E 4.93 N 4.38 E 5.05 N 4.20 E 5.28 N 4.02 E 5.86 N 3.84 E 6.43 N 3.67 E 7.01 N 3.49 E MPI 2-18/L-16 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4/19/90 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3055 3155 3255 3355 3456 3556 3656 3756 3857 3957 4057 4157 4257 4357 4457 4557 4657 4757 4857 4957 5057 5157 5257 5358 5460 5562 5666 5771 5878 5986 3055 3000 0 0 3155 3100 0 0 3255 3200 0 0 3355 3300 0 0 3455 3400 1 1 3555 3500 3655 3600 3755 3700 3855 3800 -'3955 3900 4055 4000 2 0 4155 4100 2 0 4255 4200 2 0 4355 4300 2 0 4455 4400 2 0 4555 4500 2 0 4655 4600 2 0 4755 4700 2 0 4855 4800 2 0 4955 4900 2 0 5055 5000 2 0 5155 5100 2 0 5255 5200 2 0 5355 5300 3 1 5455 5400 5 2 5555 5500 7 2 5655 5600 11 4 5755 5700 16 5 5855 5800 23 7 5955 5900 31 8 mmmmmmmm RELATIVE COORDINATES FROM WELL-HEAD 7.97 N 3.91 E 9.45 N 5.16 E 11.69 N 7.04 E 15.65 N 9.80 E 21.94 N 13.12 E 29.61 N 15.12 E 37.04 N 15.69 E 43.08 N 15.96 E 47.77 N 16.33 E 51.58 N 16.74 E 54.84 N 17.44 E 57.66 N 18.30 E 60.03 N 18.86 E 61.97 N 19.01 E 63.55 N 18.98 E 64.83 N 18.88 E 65.88 N 18.65 E 66.97 N 18.19 E 67.99 N 17.89 E 68~70 N 17.79 E 69.52 N 17.90 E 72.99 N 19.34 E 80.78 N 22.85 E 93.59 N 26.94 E 111.50 N 30.90 E 133.39 N 34.96 E 159.52 N 40.94 E 190.82 N 49.69 E 227.21 N 58.55 E 268.03 N 66.00 E MPI 2-18/L-16 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4/19/90 MEAS. DEPTH 6096 6209 6325 6444 6569 6694 6819 6944 7069 7194 7317 7440 7563 7685 7809 7934 8059 8185 8311 8437 8562 8686 8809 8930 9051 9171 9291 9411 9531 9652 TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT 6055 6000 41 10 6155 6100 54 13 6255 6200 70 16 6355 6300 89 19 6455 6400 114 25 6555 6500 139 25 6655 6600 164 25 6755 6700 189 25 6855 6800 214 25 6955 6900 239 25 7055 7000 262 23 7155 7100 285 23 7255 7200 308 23 7355 7300 330 22 7455 7400 354 24 .. 7555 7500 379 25 7655 7600 404 25 7755 7700 430 26 7855 7800 456 26 7955 7900 482 26 8055 8000 507 25 8155 8100 531 24 8255 8200 554 23 8355 8300 575 21 8455 8400 596 21 8555 8500 616 20 8655 8600 636 20 8755 8700 656 20 8855 8800 676 20 8955 8900 697 21 RELATIVE.COORDINATES FROM WELL-HEAD 313.77 N 73.39 E 364.69 N 82.69 E 421.34 N 94.56 E 485.57 N 109.30 E 557.41 N 125.78 E 630.94 N 704.31 N 777.82 N 850.72 N 923.02 N' 142.42 E 158.80 E 175.69 E 192.69 E 209.16 E 994.06 N 1063.68 N 1132.58 N 1202.26 N- 1273.36 N 225.39 E 241.16 E 256.29 E 271.35 E 286.48 E 1346.11 N 1419.58 N 1493.85 N 1568.46 N 1642.64 N 301.91 E 318.53 E 336.25 E 354.54 E 371.85 E 1716.07 N 1788.01 N 1857.21 N 1924.69 N 1990.54 N 388.56 E 405.14 E 421.00 E 436.52 E 451.83 E 2055.22 N 2119.77 N 2184'.33 N 2248.91 N .2313.21 N 467.99 E 484.06 E 499.77 E 515.79 E 533.07 E MPI 2-18/L-16 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4/19/90 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 9771 9891 10010 10129 10247 10364 10480 9055 9000 716 19 9155 9100 736 20 9255 9200 755 19 9355 9300 774 19 9455 9400 792 18 9555 9500 809 17 9655 9600 825 16 RELATIVE COORDINATES FROM WELL-HEAD '2376.73 N 2439.83 N 2501.86 N 2562.67 N 2622.11 N 550.80 E 569.06 E 589.28 E 609.99 E 630.02 E 2678.61 N 2732.89 N 650.84 E 672.09 E MPI 2-18/L-16 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 4/19/90 MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 6OOO 7000 8000 9000 10000 5968 5913 273.52 N 66.86 E 6800 6745 810.41 N 183.31 E 7608 7553 1384.96 N 310.56 E 8413 8358 1962.84 N 445.35 E 9246 9191 2496.50 N 587.43 E 1000 1000 945 0.43 N 4.85 E 2000 2000 1945 4.42 N 5.45 E 3000 3000 2945 7.27 N 3.41 E 4000 3998 3943 53.08 N 16.95 E 5000 4998 4943 69.00 N 17.81 E 550 1650 2200 8750 3300 3850 T 4400 V 4950 D 6050 6600 7150 7700 8250 8800 §350 9900 -550 VERTICAL SECTION BP EXPLORATION MFI 2-18/L-16 SECTION AT N 16.71E TVB SCALE: ~ ~nch = &~O0 feeb BEP SCALE: ~ inch = ~00 fee( BRA~N : 4/~9/90 Marker Identification MD TVD DEPRT A] KB 0 0 0 B] TVD i0577 9740 2859 0 55O :['tOO ~.650 2200 2750 3300 3850 4400 4950 5500 6050 Oepaptupe ~2~0 3000 2750 2500 2000 1750 ~500 1250 looo 75O 500 250 Marker Identlflcatlon MB TVD DEPRT AJ KB 0 0 0 8J TVB t0577 9740 2859 PLAN VZE~ EP EXPLORATZON CLOSURE: 2862 ft N t2.9 E DECLINATION: 30.60 deg E SCALE : t inch = 500 feet DRAWN' 4/19/90 250 0 250 500 750 1000 1250 1500 ~750 2000 2250 2500 2750 SUB. SURFACE DIRECTIONAL SURVEY ~---[UIDANCE [~] ONTINUOUS I-flooL Company BP EXPLORA, TION Well Name 2-18/L-16 MPI(1902' SNL,2213', WEL,SEC 36,T12N,R16E) FleidlLooatlonENDICOTT, NOR,,TH SLOPE~ AL, ASKA .... Job Reference No. Date 73827 21-APR-90 Logc3ed BT Computed By; FRITZKE KOHRING GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 2-18/L-16 MPI ENDICOTT NORTH SLOPE, ALASKA SURVEY DATE: Z1-APR-1990 ENGINEER: FRITZKE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVEATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 15 DEG 10 MIN EAST COMPUTATION DATE: 4-MAY-90 PAGE I BP EXPLORATION Z-]8/L-16 MPI ENDICOTT NORTH SLOPEr ALASKA DATE OF SURVEY: 21-APR-1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN lO0 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION A[IMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN 0.00 0.00 -55.10 0 0 N 0 0 E 100.00 100.00 44.90 0 I S 51 7 E ZO0.O0 200°00 144.90 0 8 S 55 36 E 300.00 300.00 244.90 0 13 S 78 43 E 400.00 400.00 344.90 0 13 N 75 44 E 500.00 500.00 444.90 0 16 S 80 26 E 600.00 599.99 544.89' 0 13 N 86 I E 700.00 699.99 644.89 0 12 N 70 12 E 800.00 799.99 744°89 0 13 N 83 49 E 900.00 899.99 844.89 0 12 S 87 51 E 1000.00 999.99 944.89 1100.00 1099.99 1044.89 1200.00 1199.99 1144.89 1300.00 1299.99 1244.89 1600.00 1399.99 1344.89 1500.00 1499.99 1444o89 1600.00 1599.99 1544.89 1700.00 1699.99 1644.89 1800.00 1799.98 1764.88 1900.00 1899.98 1844.88 012 N 86 5 E 0 15 N 63 3 E 0 14 N 43 12 E 0 13 N 12 5 E 016 N 24 8 E 016 N 27 7 E 0 16 N 19 39 E 014 N 4 25 bi 016 N 6 11W 0 12 N 3 26 E 2000.00 1999.98 1944.88 2100.00 Z099.98 2044.88 2200.00 2199.98 2144.88 2300.00 2299.98 2244.88 2400.00 2399.98 2344.88 2500.00 2499.98 2444.88 2600.00 2599.98 2544.88 2700.00 2699.98 2644.88 2800.00 2799.98 2744.88 2900.00 2899.98 2844.88 0 11 N 6 48 E 0 11 N 15 21 E 0 8 N 30 41E 0 9 N 33 33 E 0 8 N 39 54 E 013 N 22 9 E 0 15 N 12 46 E 0 16 N 6 53 E 0 20 N 5 29 E 0 22 N 20 25 E 3000.00 2999.98 2944.88 "- 3100.00 3099.97 3044.87 3200.00 3199.93 3144.83 3300.00 3299.87 3244.77 3400.00 3399.71 3344.61 3500.00 3499.40 3444.30 3600.00 3599.08 3543.98 3700.00 3698.84 3643.74 3800.00 3798.69 3743.59 3900.00 3898.59 3843.49 ENGINEER: FRITZKE 0 33 N 31 13 E I 5 N 51 34 E I 50 N 61 33 E 2 18 N 59 13 E 3 58 N 40 45 E 4 42 N 18 21 E 4 27 N 3 32 E 326 N 134 E 247 N 4 15 E 223 N 8 15 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.34 0.01 0.33 N 0.12 E 0.29 0.00 0.24 N 0.23 E 0.25 0.00 0.11 N 0.53 E 0.38 0.00 0.15 N 0.90 E 0.49 0.00 0.15 N 1.32 E 0.57 0.22 0.11 N 1.76 E 0.76 0.00 0.22 N 2.10 E 0.94 0o00 0.31 N 2.46 E 1.04 0.00 0.32 N 2.82 E 0.00 N 0 0 E 0.35 N 19 54 E 0.33 N 44 6 E 0.54 N 78 Z E 0.92 N 80 32 E 1.32 N 83 26 E 1.76 N 86 23 E 2.11 N 83 58 E 2.48 N 82 49 E 2.84 N 83 34 E 1.13 0.00 0.32 N 3.16 E 1.34 0.00 0.43 N 3.53 E 1.65 0.00 0.66 N 3.87 E 2.04 0.03 1.02 N 4.04 E 2.47 0.00 1.43 N 4.17 E 2.93 0.00 1.85 N 4.38 E 3.38 0.00 2.27 N 4.57 E 3.84 0.00 2.71 N 4.67 E 4.27 0.00 3.17 N 4.63 E 4.67 0.00 3.59 N 4.62 E 3.18 N 84 17 E 3.56 N 83 6 E 3.92 N 80 15 E 4.17 N 75 52 E 4.41 N 71 2 E 4.75 N 67 9 E 5.10 N 63 37 E 5.,60 N 59 53 E 5.6! N 55 38 E 5.85 N 52 11 E 5.00 0o00 . 3.92 N 4.65 E 5°35 0.00 4.27 N 4.72 E 5.60 0.00 4.50 N 4.82 E 5.84 0.00 4.71 N 4.96 E 6.08 0.00 4.91 N 5.10 E 6.31 0.21 5-12 N 5.24 E 6.71 0.00 5.50 N 5.36 E 7.12 0o00 5.91 N 5.42 E 7.62 0.23 6.41 N 5.47 E 8.21 0.15 7.00 N 5.55 E 6.08 N 49 52 E 6.36 N 4,7 54 E 6.59 N 46 59 E 6.84 N 46 27 E 7.08 N 46 4 E 7.32 N 45 39 E 7.68 N 44 18 E 8.02 N 42 33 E 8.43 N 40 29 E 8.93 N 38 26 E 8.93 0.25 7.65 N 5.90 E 10.11 0.92 8.63 N 6.80 E 12.09 0.14 10.05 N 9.13 E 14.51 2.09 11.73 N 12.18 E 19.04 1.91 15.29 N 16.38 E 26.56 2.09 22.03 N 20.27 E 34.56 1.25 29.98 N 21.51 E 41.24 0.52 36.82 N 21.81 E 46.52 0.37 42.23 N 22.02 E 50.99 1.02 46.72 N 22.53 E 9.66 N 37 39 E 10.99 N 38 16 E 13.58 N 4,2 15 E 16.91 N 46 4 E 22.41 N 46 58 E 29.94 N 42 37 E 36.90 N 35 40 E 42.80 N 30 38 E 47.63 N 27 32 E 51.87 N 25 45 E COMPUTATION DATE: 4-MAY-90 PAGE BP EXPLORATION Z-18/L-16 ENDICOTT NORTH SLOPE9 ALASKA. DATE OF SURVEY: Z1-APR=1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH OEPTH DEPTH DEG ENGINEER: FRITZKE I 52 N 12 12 E ! 44 N 13 54 E 1 22 N 15 46 E ! 8 N 14 25 E 049 N 738 E 0 43 N 0 58 I,I 0 43 N 723 W 0 40 N 11 57 W 0 32 N 14 31 W 0 26 hi 15 22 W N 9 32 W N 7 58 E N 25 41 E N Z! 28 E N 13 7 E N 9 27 E N 12 15 E N 16 19 E N 16 14 E N 11 12 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG NIN 4000.00 3998.53 3943.43 4100.00 4098.48 4043.38 4200.00 4198.44 4143.34 4300.00 4298.41 4243.31 4400.00 4398.40 4343.30 4500.00 4498.39 4443.29 4600.00 4598.38 4543.28 4700.00 4698.38 4643.28 4800.00 4798.37 4743.27 4900.00 4898.37 4843.27 5000.00 4998.36 4943.26 0 22 5100.00 5098.36 5043.26 0 55 5200.00 5198.24 5143.14 4 28 5300.00 5297.70 5242.60 7 18 5400.00 5396.61 5341.51 9 34 5500.00 5494.79 5439.69 11 56 5600.00 5592.23 5537.13 14 18 5700.00 5688.45 5633.35 17 5800.00 5783.14 5728.04 20 6 5900.00 5876.49 5821.39 21 44 54.54 0.21 50.ZZ N 23.17 E 57.67 0.38 53.28 N 23.88 E 60.38 0.05 55.89 N 24.59 E 62.66 1.35 58.09 N 25.19 E 64.28 0.24 59.70 N 25.49 E 65.54 0.00 60.98 N 25.57 E 66.74 0.21 62.24 N 25.47 E 67.82 0.00 63.41 N 25.27 E 68.74 0.37 64.43 N 25.04 E 69.46 0.00 65.24 N 24.81 E 6000.00 5968.63 5913.53 24 4 N 9 5 E 6100.00 6059.07 6003.97 26 25 N 9 57 E 6200.00 6147.77 6092.67 28 43 N 11 17 E 70.09 O.OB 65.94 N 70.91 1.46 66.78 N 75.22 2.89 70.78 N 85.40 2.04 80.23 N 100.08 1.61 94.32 N 118.96 1.02 112.89 N 141.35 3.23 134.95 N 168.52 3.14 161.24 N 200.65 2.47 192.03 N 236.46 2.22 2Z6.87 N 6300.00 6234.43 6179.33 31 3 6400.00 6318.99 6263.89 33 36 6500.00 6400.98 6345.88 36 14 6600.00 6481.00 6425.90 37 4 6700.00 6560.87 6505.77 36 54 6800.00 6640.77 6585.67 36 55 6900.00 6720.65 6665.55 37 7 275.11 317.56 363.57 N 1Z 1Z E 413.37 N 13 6 E 466.67 N 13 28 E 523.88 N 13 lB E 583.82 N 13 17 E 643.97 N 13 28 E 704.07 N 13 45 E 764.21 7000.00 6800.50 6745.40 36 56 7100.00 6880.59 6825.49 36 41 7200.00 6960.86 6905.76 36 26 7300.00 7041.56 6986.46 36 0 7400.00 7122.72 7067.62 35 26 7500.00 7204.45 7149.35 35 7 7600.00 7286.02 7230.92 35 27 7700.00 7367.44 7312.34 35 49 7800.00 7448.29 7393.19 36 19 7900.00 7528.65 7473.55 36 32 N 13 37 E 824.39 N 13 44 E 884.25 N 13 24 E 943.87 N 13 22 E 1002.90 N 13 lB E 1061.28 N 1Z 59 E lllB.8T N 12 45 E 1176.67 N 12 38 E 1234.68 N 12 29 E 1293.45 N 12 14 E 1352.91 55.31 N 24 46 E 58.38 N 24 9 E 61.06 N 23 45 E 63.32 N 23 26 E 64.91 N 23 7 E 66.12 N 22 45 E 67.25 N 22 15 E 68.26 N 21 44 E 69.12 N 21 14 E 69.80 N 20 50 E 24.65 E 70.40 N 20 30 E 24.66 E 71.19 N 20 16 E 26.39 E 75.54 N 20 27 E 30.44 E 85.81 N 20 46 E 34.58 E 100.46 N 20 8 E 38.23 E 119.19 N 18 43 E 42.42 E 141.46 N 17 27 E 49.28 E 168.61 N 17 0 E 58.4g E 200.75 N 16 56 E 66.86 E 236.51 N 16 25 E 2.51 2.15 2.77 2.21 Z.B8 2.05 0.02 0.19 0.51 0.35 265-14 N 73.40 E 275.12 N 15 28 E 307.22 N 80.42 E 317.57 N 14 40 E 352.59 N 88.90 E 363.62 N 14 9 E 401.43 N 99.09 E 413.48 N 13 52 E 453.49 N 110.78 E 466.82 N 13 44 E 509.18 N 123.99 E 524.06 N 13 41 E 567.52 N 137.89 E 584.03 N 13 39 E 626.07 N 151.74 E 644.20 N 13 37 E :t 684.58 N 165.64 E 704.34 N 13 36 E 743.04 N 179.85 E 764.50 N 13 36 E 0.44 0.27 0.49 0.25 0.24 0.38 0.26 1 °09 1.12 0.69 801.52 N 194.11 E 824.69 N 13 37 E 859.70 N 208.28 E 884.57 N 13 37 E 917.67 N 222.29 E 944.21 N 13 37 E 975.14 N 235.92 E 1003.27 N 13 36 E 1031.97 N 249.40 E 1061.68 N 13 35 E 1088.09 N 262.50 E 1119.31 N 13 34 E 1144.49 N 275.39 E 1177.15 N 13 32 E 1201.13 N 288.13 E 1235.21 N 13 29 E 1258.56 N 300.94 E 1294.04 N 13 27 E 1316.71 N 313.64 E 1353.55 N 13 24 E COMPUTATION DATE:'¢-NAY-90 PAG~ BP EXPLORATION 2-18/L-16 NPI ENDICOTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 21-APRL1990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: FRITZKE INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH OEG MZN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7608,71 7553o61 36 54 8100.00 7688.43 7633.33 37 14 8200.00 7767.89 7712.79 37 39 8300.00 7847.02 7791.92 37 37 8400.00 7926.30 7871.20 37 21 8500.00 8005.99 7950.89 36 55 8600.00 8086.19 8031.09 36 25 8700,00 8166,99 8111.89 35 46 8800.00 8248°38 8193.28 35 12 9900.00 8330.32 8275.22 34 45 N 12 23 E 1412o74 N 12 44* E 1473.06 N 13 0 E 1533.72 N 13 5 E 1594.82 N 12 58 E 1655.73 N 12 56 E 1716-09 N 12 58 E 1775.78 N 13 8 E 1834.66 N 13 19 E 1892.71 N 13 28 E 1950.01 0.00 0.18 0.37 0.34 0.43 0.60 0.51 0.53 0.72 0.21 1375.25 N 326.40 E 1413.46 N 13 2.1 E 1434.18 N 339.55 E 1473.82 N 13 19 E 1493.37 N 353.08 E 1534.54, N 13 18 E 1552.92 N 366.90 E 1595o67 N 13 18 E 1612.30 N 380.64 E 1656.63 N 13 17 E 1671.16 N 394.20 E 1717.03 N 13 16 E 1729.39 N 407.55 E 1776.77 N 1,3 16 E 1786.79 N 420.85 E 1835.69 N 13 15 E ~) 1843.35 N 434.12 E 1893.77 N 13 15 E · / 1899.12 N 447.35 E 1951.10 N 13 15 E 9000.00 8412.80 8357.70 34 7 9100.00 8495.84 8440.74 33 39 9200.00 8579.05 8523.95 33 44 9300,00 8662,24 8607,14 33 43 9400.00 874*5.49 8690.39 33 37 9500.00 8828.76 8773.66 33 37 9600.00 8911.95 8856.85 33 50 9700.00 8995.26 8940.16 33 20 9800.00 9078.79 9023.69 33 22 9900.00 9162.32 9107.22 33 21 N 13 45 E 2006.53 N 14 8 E 2062.23 N 14 23 E 2117.70 N 14 42 E 2173.19 N 15 3 E 2228.58 N 15 4* E 2283.96 N 15 11 E 2339.45 N 15 22 E 2394.76 N 15 44 E 2449.74 N 16 3 E 2504.72 0.55 0.25 0.18 0.38 0.19 0.33 0.13 0-27 0.23 0.39 1954.08 N 4*60.64 E Z007.64 N 13 16 E 2008.15 N 474.08 E 2063.35 N 13 17 E 2061.91 N 487.74 E 2118.82 N 13 19 E 2115.63 N 501.66 E 2174.30 N 13 2.0 E 2169.17 N 515.89 E 2229.67 N 13 23 E 2222.64 N 530.32 E 2285.03 N 13 25 E 2276.21 N 544.80 E 2340.50 N 13 28 E 2329.55 N 559.38 E 2395.77 N 13 30 E 2382.52 N 574.11 E 2450.72 N 13 33 E 2435.42 N 589.13 E 2505.66 N 13 36 E 10000.00 9245.96 9190.86 33 4 10100.00 9329.96 9274.86 32 43 10200.00 9414.32 9359.22 32 12 10300.00 9499.35 9444.25 31 26 10400.00 9585.09 9529.99 30 37 10500.00 9671.48 9616.38 29 66 10600.00 9758.44 9703.34 29 33 10700.00 9845.26 9790.16 29 56 10800.00 9931.64 9876.54 30 30 10900.00 10017.63 9962.53 30 44 N 16 57 E 2559.51 N 17 57 E 2613.72 N 19 0 E 2667.33 N 20 18 E 2719.81 N 21 41 E 2771.00 N 23 I E 2820.96 N 22 21 E 2869.89 N 21 57 f 2919.15 N 21 9 E 2969.23 N 20 53 E 3020.01 0.75 0.33 1.25 0.56 0.81 0.43 1.00 0.34 0.92 2487.97 N 604 69 E ~560 40 N 13 40 E 2539.73 N 620:94 E ,-614:53 N 13 44 E 2590.67 N 637.92 E 2668.05 N 13 50 E 2640°25 N 655.60 E 2720.43 N 13 57 E 2688.29 N 67¢.03 E 2771.50 N 14 5 E 2734.86 N 693.21 E 2821.35 N 14 13 E 2780.36 N 712.37 E 2870.17 N 14 22 E 2826.32 N 731.08 E 2919.35 N 14 30 E 2873.20 N 749.58 E 2969.37 N 14 37 E 2920.86 N 767.86 E 3020.10 N 14 44 E 11000.00 10103.74 10048.64 30 27 11100.00 10189.90 10134.80 30 33 11200.00 102T6.09 10220.99 30 3T 11300.00 10362.26 10307.16 30 21 11400.00 10448.54 10393.44 30 22 11465.00 10504.63 10449.53 30 22 N 20 53 E 3070.59 N 20 48 E 3121.11 N 21 53 E 3171.53 N 22 6 E 3221.89 N 21 59 E 3271.89 N 21 59 E 3304.51 0.66 0.90 0.81 0.39 0.00 0.00 2968.33 N 786.04 E 3070.64 N 14 50 E 3015.81 N 803.98 E 3121.14 N 14 56 E 3063.02 N 822.53 E 3171.5¢ N 15 2 E 3110.01 N 841.68 E 3221.89 N 15 9 E 3156.69 N 860.56 E 3271.89 N 15 15 E 3187.16 N 872.85 E 3304.52 N 15 19 E COMPUTATION DATE: 4-MAY-90 PAGE BP EXPLORATION 2-! 8/L-16 ENO]'COTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 21-APR:1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.10 0 0 1000o00 999.99 944.89 0 12 2000°00 1999.98 1944.88 0 11 3000.00 2999.98 2944.88 0 33 4000.00 3998.53 3943.43 I 52 5000.00 4998.36 4943°26. 0 22 6000.00 5968.63 5913.53 24 4 7000.00 6800.50 6745.40 36 56 8000.00 7608.71 7553.61 36 54 9000.00 8412.80 8357.70 34 7 ENGINEER: FRITZKE 10000.00 9245.96 9190.86 33 4 11000.00 10103.74 10048.64 30 2'7 11465.00 10504.63 10449.53 30 22 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG HZN N 0 0 E 0.00 0.00 N 86 5 E 1.13 0.00 N 6 48 E 5.00 0.00 N 31 13 E 8.93 0.25 N 12 12 E 54.54 0.21 N 9 32 W 70.09 0.08 N 9 5 E 275.11 2.51 N 13 37 E 824.39 0.44 N 12 23 E 1412.74 0.00 N 13 45 E 2006.53 0.55 N 16 57 E 2559.51 N 20 53 E 3070.59 N 21 59 E 3304.51 0.00 N 0.00 E 0.00 N 0 0 E 0.32 N 3.16 E 3.18 N 84 17 E 3.92 N 4.65 E 6.08 N 49 52 E 7.65 N 5.90 E 9.66 N 37 39 E 50.22 N 23.17 E 55.31 N 24 46 E 65.94 N 24.65 E 70.40 N 20 30 E 265.14 N 73.40 E 275.12 N 15 28 E 801.52 N 194.11 E 824.69 N 13 37 E 1375.25 N 326.40 E 1413.46 N 13 21 E 1954.08 N 460.64 E 2007.64 N 13 16 E 0.75 0.66 0.00 2487.97 N 604.69 E 2560.40 N 13 40 E 2968.33 N 786.04 E 3070.64 N 14 50 E 3187.16 N 872o85 E 3304° 52 N 1S 19 E COMPUTATION DATE: 4-NAY-90 PAGE BP EXPLORATION 2-18/L-16 ENDICOTT NORTH SLOPEr ALASKA DATE OF SURVEY: 21-APR*-1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0.00 0,00 -55.10 0 0 N 0 0 E 55.10 55.10 0.00 0 5 S 88 46 E 155o10 155.10 100,,00 0 5 S 48 45 E 255.10 255.10 200.00 : 0 12 S 66 50 E 355.10 355.10 300.00 0 13 N 79 32 E 455.10 455.10 400.00 0 14 S 87 58 E 555.10 555,10 500.00 0 16 S 85 23 E 655.11 655.10 600.00 0 12 N 67 36 E 755.11 755.10 700.00 0 13 N 75 25 E $55.11 855.10 800.00 0 12 N 89 31 E 955.11 955.10 900.00 1055.11 1055.10 1000.00 1155.11 1155.10 1100.00 1255.11 1255.10 1200.00 1355.11 1355.10 1300.00 1455.11 1455o10 1400.00 1555.11 1555,,10 1500.00 1655.11 1655.10 1600.00 1755.11 1755.10 1700.00 1855.12 1855.10 1800.00 0 12 S 88 23 E 0 1¢ N 71 50 E 0 13 N 55 55 E 0 13 N 21 0 E 0 15 N 15 59 E 0 16 N 28 4 E 0 16 N 23 28 E 0 16 N 15 31 E 0 16 N 5 47 W 0 15 N 2 40 E 1955.12 1955.10 1900.00 2055.12 Z055.10 2000.00 2155.12 2155.10 2100.00 2255.12 2255.10 2200.00 2355.12 2355.10 2300.00 2455.12 2455.10 2400.00 2555.12 2555.10 2500.00 2655.12 2655.10 2600.00 2755.12 2755.10 2700.00 2855.12 2855.10 2800.00 0 11 N 3 50 E 0 13 N 11 57 E 0 8 N 25 42 E 0 9 N 32 37 E 0 9 N 34 6 E 0 8 N 35 37 E 0 13 N 19 46 E 014. N 7 10 E 018 N 5536 020 N 6 2955.12 2955.10 2900.00 3055.13 3055.10 3000.00 3155.15 3155.10 3100.00 3255.20 3255.10 3200.00 3355.30 3355.10 3300.00 3455.55 3455.10 3400.00 3555.88 3555.10 3500.00 3656.17 3655.10 3600.00 3756.35 3755.10 3700.00 3856.47 3855.10 3800.00 ENGINEER: FRITZK,E 0 25 N 28 19 E 0 47 N 41 30 E I 42 N 59 25 E 2 0 N 61 16 E 3 15 N 50 4 E 4 39 N 29 20 E 4 38 N 7 29 E 352 N 2 10 E 3 2 N 2 0 E 236 N 7 4 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG HIM 0.00 0.00 0.00 N 0.00 E 0.34 0.23 0.33 N 0.09 E 0.32 0.00 0.29 N 0.16 E 0.25 0.00 0.16 N 0.37 0.30 0.00 0.11 N 0.74, E 0.46 0.00 0.17 N 1.12 E 0.52 0.00 0.12 N 1.57 E 0.67 0.00 0.16 N 1.95 E 0.87 0.00 0.28 N 2.30 E 1.01 0.00 0.32 N 2.66 E 0.00 N 0 0 E 0.3¢ N 14 28 E 0.33 N 28 49 E 0.40 N 66 13 E 0.75 N 81 41 E 1.13 N 81 10 E 1.57 N 85 46 E 1.96 N 85 19 [ 2.31 N 83 4 E ' 2.68 N 83 7 E 1.09 0.00 0.31 N 3.01 E 1.22 0.00 0.36 N 3.36 E 1.51 0.00 0.55 N 3.73 E 1.87 0.00 0.85 N 4,.00 E 2.27 0.00 1.24 N 4.10 E 2.72 0.00 1.66 N 4.28 E 3.18 0.00 2.08 N 4.49 E 3.64 0.00 2.51 N 4.65 E 4.07 0.00 2.96 N 4,,65 E 4,.50 0.25 3.41 N 4,.61 E 3.02 N 84, 4, E 3.38 N 83 58 E 3.77 N 81 38 E 4.08 N 77 58 E 4.29 N 73 9 E 4,.59 N 68 51 E 4.95 N 6511 E 5.28 N 61 36 E 5.51 N 57 31 E 5.73 N 53 30 E 4.85 0.00 3.77 N 4.63 E 5.20 0.00 4.12 N 4.68 E 5.50 0.00 4,.41 N 4.77 E 5.74 0.00 4.62 N 4.89 E 5.98 0.00 4.83 N 5.04 E 6.19 0.00 5.01 N 5.18 E 6.52 0.00 5.32 N 5.31 E 6.92 0.00 5.71 N 5-40 E 7.38 0.22 6.17 N 5.45 E 7.93 0.00 6.73 N 5.50 E 5.98 N 50 51 E 6.23 N 48 41 E 6.50 N 47 16 E 6.73 N 46 39 E 6.98 N 4,6 13 E 7.20 N 4,5 56 E 7.52 N 44 56 E 7,86 N 4,3 23 E ) 8.23 N 41 27 E 8.69 N 39 17 E 8.57 0.06 7.33 N 5.71 E 9.50 0.59 8.15 N 6.28 E 11.11 0.78 9.37 N 7.91 E 13~36 0.14, 10.93 N 10.T6 E 16.63 1.52 13.32 N 14.40 E 22.98 2.17 18.71 N 18.80 E 31.11 2.00 26.4,8 N 11.23 E 38.55 0.69 34.05 N 21.73 E 44.38 1.70 40.05 N 21.90 E 4,9.12 0.29 44,.85 N 22.28 E 9.29 N 37 57 E 10.28 N 37 36 E 12.26 N 40 11 E 15.33 N 44 33 E 19.62 N 4,7 13 E 26.52 N 45 8 E 33.94, N 38 4,3 E 40.39 N 32 32 E 45.65 N 28 4,0 E 50.08 N 26 25 E COMPUTATION DATE: 4-MAY-90 PAGE 6 ' BP EXPLORATION 2-18/L-16 END[COTT NORTH SLOPEp ALASKA DATE OF SURVEY: 21-APR-X990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: FRITZK~ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG NIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 3956.55 3955.10 3900.00 4056.60 4055.10 4000.00 4156.65 4155.10 4100.00 4256.68 4255.10 4200.00 4356.69 4355.10 4300.00 4456.70 4455.10 4400.00 4556.7I 4555.10 4500.00 4656.72 4655.10 4600.00 4756.73 4755.10 4700.00 4856.73 4.855.10 4800.00 2 0 N 10 49 E 148 N 13 0 E ! 32 N 15 32 E I 19 N 15 13 E 055 N 9 11E 042 N 3 25 E 0 44 N 5 24 W 040 N 9 29 W 035 N 13 0 28 N 15 29 53.06 0.06 48.78 N 22.88 E 56.34 0.39 51.98 N 23.57 E 59.29 0.42 54.84 N 24.29 E 61.71 0.23 57.18 N 24.95 E 63.63 0.20 59.04 N 25.39 E 65.02 0.00 60.44 N 25.56 E 66.23 0.07 61.70 N 25.53 E 67.36 0.06 62.92 N 25.37 E 68.37 0.14 64.02 N 25.14 E 69.16 0.03 64.91 N 24.91 E 53.87 N 25 8 E 57.08 N 24 23 E 59.98 N 23 54 E 62.38 N 23 34 E 64.27 N 23 16 E 65.62 N 22 55 E 66.77 N 22 29 E 68.78 N 21 26 E 69.52 N 21 0 E 4956.73 6955.10 6900.00 0 26 5056.76 5055.10 5000.00 0 25 5156.77 5155.10 5100.00 2 44 5257.09 5255.10 5200.00 6 8 5357.95 5355.10 5300.00 8 62 5659.67 5455.10 5600.00 11 23 5561.78 5555.10 5500.00 13 11 5665.18 5655.10 5600.00 16 11 5770.21 5755.10 5700.00 19 20 5877.00 5855.10 5800.00 21 26 N 12 69 W N I 15 W N 24 52 E N 22 44, E N 15 42 E N 11 3 E N 11 2 E N 15 31 E N 16 52 E N 12 I E 69.83 0.14 65.65 N 70.43 0.75 66.30 N 72.51 6.90 68.30 N 80.35 4.04 75.53 N 93.37 3.11 87.82 N 110.77 2.95 104.79 N 132.29 2.51 126.06 N 158.52 3.09 151.63 N 190.60 2.87 182.40 N 228.01 1.48 218.58 N 24.71 E 70.14 N 20 38 E 26.62 E 70.72 N 20 22 E 25.19 E 72.80 N 20 15 E 28.50 E 80.73 N 20 40 E 32.93 E 93.79 N 20 33 E 36.79 E 111.06 N 19 21 E · 0.59 E 132.43 N 17 51 E 46.52 E 158.61 N 17 3 E 55.62 E 190.69 N 16 57 E 65.15 E 228.08 N 16 36 E 5985.Z0 5955.10 5900.00 23 42 6095.56 6055.10 6000.00 26 20 6208.38 6155.10 6100.00 28 56 6326.20 6255.10 6200.00 31 34 6443.63 6355.10 6300.00 36 44 6567.56 6455.10 6400.00 37 4 6692.78 6555.10 6500.00 36 54 6817.92 6655.10 6600.00 36 53 6963.18 6755.10 6700.00 37 7068.22 6855.10 6800.00 36 41 N 9 5 E 269.15 2.64 N 9 54. E 315.59 2.23 N 11 23 E 367.62 2.68 N 12 25 E 425.93 2.24 N 13 22 E 491.15 2.56 N 13 23 E 56¢.27 0.51 N 13 17 E 639.63 0.21 N 13 33 E 714.83 O.a4 N 13 45 E 790.24 0.40 N 13 43 E 865.27 0.59 259.22 N 72.45 E 269.16 N 15 37 E 305.27 N 80.07 E 315.60 N 14 42 E 356.57 N 89.70 E 367.68 N 14 7 E 413.72 N 101.77 E 426.05 N 13 49 E 677.32 N 116.38 E 491o31 N 13 42 E 548.48 N 133.38 E 564.46 N 13 40 E 621.86 N 150.74 E 639.87 N 13 38 E 695.05 N 168.16 E 715.10 N 13 36 E ) 768.33 N 186.04 E 790.54 N 13 37 E 841.26 N 203.77 E 865.59 N 13 37 E 7192.8& 6955.10 6900.00 36 27 7316.74 7055.10 7000.00 35 58 7639.68 7155.10 7100.00 35 12 7562.04 7255.10 7200.00 35 27 7684.80 7355.10 7300.00 35 40 7808.46 7455.10 7400.00 36 24 7932.98 7555.10 7500.00 36 47 8058.13 7655.10 7600.00 37 14 8183.86 7755.10 7700.00 37 33 8310.20 7855.10 7800.00 37 38 N 13 25 E 939.62 N 13 22 E 1012.73 N 13 11 E 1084.20 N 12 52 E 1154.67 N 12 39 E 1225.80 N 12 26 E 1298.46 N 12 16 E 1372.58 N 12 38 E 1447.74 N 12 59 E 1523.88 N 13 5 E 1601.04 0.38 0.37 0.81 0.70 1.23 0.96 0.67 0.54 0.98 0.36 913.54 N 221.30 E 939.96 N 13 37 E 984.71 N 238.19 E 1013.11 N 13 36 E 1054.30 N 254.65 E 1084.62 N 13 35 E 1123.01 N 270.51 E 1155.13 N 13 33 E 1192.46 N 286.19 E 1226.32 N 13 30 E 1263.46 N 302.02 E 1299.05 N 13 27 E 1335.96 N 317.82 E 1373.25 N 13 23 E 1409.46 N 333.99 E 1468.49 N 13 20 E 1483.77 N 350.87 E 1526.69 N 13 18 E 1558.98 N 368.30 E 1601.90 N 13 18 E COHPUTATION DATE: 4-MAY-90 PAGE BP EXPLORATION Z-18/L-16 MPI ENDICOTT NORTH SLOPEr ALASKA DATE OF SURVEY: Z1-APR~1990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH OEPTH OEG COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH DEG MIN FEET OEG/ZO0 FEET FEET FEET OEG MIN 8,36.20 7955.10 7900°00 37 8561.31 8055.10 8000.00 36 38 8685.34 8155.10 8100.00 35 51 8808.21 8255.10 8200.00 35 10 8930.12 8355.10 8300.00 34 34 9051.00 8655.10 8400.00 33 50 9171-21 8555.10 8500.00 33 43 9291.,2 8655.10 8600.00 33 42 9,11.5, 8755.10 8700.00 33 38 9531.63 8855.10 8800.00 33 37 9651.88 8955.10 8900.00 33 33 9771o64 9055.10 9000.00 33 22 9891.36 9155.10 9100.00 33 21 10010.91 9255.10 9200.00 33 1 10129.85 9355.10 9300°00 32 35 10248.06 9455.10 9600.00 31 10365.12 9555.10 9500.00 30 68 10481.11 9655.10 9600.00 29 57 10596.16 9755.10 9700.00 29 33 10711.36 9855.10 9800.00 30 2 10827.26 9955.10 9900.00 30 36 10943.56 10055.10 10000.00 30 32 11059.59 10155.10 10100.00 30 31 11175.63 10255.10 10200.00 30 28 11291.71 10355.10 10300.00 30 21 11407.60 10455.10 10¢00.00 30 22 11465.00 10504.63 10649.53 30 22 N 13 0 E 1677.65 N 12 54 E 1752.77 N 13 6 E 1826.08 N 13 19 E 1897.44 N 13 31E 1967.12 N 13 58 E 2035.02 N 14 18 E 2101.71 N 14 40 E 2168-43 N 15 5 E 2234.97 N 15 6 E 2301.47 N 15 19 E 2368.25 N 15 39 E 243..1. N 16 0 E 2499.97 N 17 3 E 2565.46 N 18 11 E 2629.81 N 19 35 E 2692.70 N 21 12 E 2753.29 N 22 49 E 2811.64 N 22 23 E 2868.01 N 21 53 E 2924.79 N 21 4 E 2983.00 N 21 0 E 3042.07 N 20 35 E 3100.67 N 21 45 E 3159.23 N 22 10 E 3217.73 N 21 59 E 3275.70 N 21 59 E 3306.51 0.32 0.69 0.64 0.56 0.89 0.33 0.3, 0.3. 0 0 1633.68 N 385.56 E 1678.56 N 13 17 E 1706.95 N 402.40 E 1753.76 N 13 16 E 1778.43 N 418.90 E 1827.10 N 13 15 E 1847.95 N 435.21 5 1898.50 N 13 15 E 1915.77 N 451.35 E 1968.22 N 13 15 E 1981.75 N 467..46 E 2036.14 N 13 16 E 2046.42 N 483.78 E 2102.83 N 13 18 E 2111,,03 N 500.45 E 2169.54 N 13 20 E ~ 2175.34 N 517.55 5 2236.06 N 13 23 E * ? 2239.55 N 534.87 E 2302.53 N 13 26 E 0.58 0.36 0.32 0.73 0.94 1.22 1.18 1.33 0.47 0 0.76 0.11 0.2, 0.53 0.41 0.00 0o00 2303.99 N 552.37 E 2369.28 N 13 29 E 2367.51 N 569.89 E 2435.13 N 13 32 E 2430.85 N 587.82 E 2500.91 N 13 36 E 2493..66 N 606.43 E 2566.34 N 13 40 E 2555.04 N 625.96 E 2630.60 N 13 46 E 2614.68 N 646.33 E 2693.38 N 13 53 E 2671.71 N 667.53 E 2753.83 N 14 2 E 2726.19 N 689.54 E 2812.04 N 14 12 E 2778.61 N 711.65 E 2868.30 N 14 22 E 2831.59 N 733.20 E Z924.98 N 16 31 E 2886.11 N 754.56 E 2983.12 N 14 39 E 2941.56 N 775.78 E 3042.14 N 14 46 E 2996.60 N 796.73 E 3100.71 N 14 53 E 3051.52 N 817.93 E 3159.24 N 15 0 E 3106.13 N 840.10 E 3217.73 N 15 8 E 3160.25 N 861.99 E 3275.71 N 15 15 E 3187.16 N 872.85 E 3304.52 N 15 19 E BP EXPLORATTON 2-18/L-16 PEP]:: END]:COTT NORTH SLOPE, ALASKA MARKER GCT LAST READ]:NG PI~TO DR]:LLER* S DEPTH CONPUTAT]:ON DATE: 4-MAY-90 PAGE 8 DATE OF SURVEY: Z1-APR-1990 KELLY 8USH]:NG ELEVATTON: 55.10 FT ENG:[NEER: FR:[TZKE :I:NTERPOLATEO VALUES FOR CHOSEN HOR]:ZONS SURFACE LOCAT]:ON = 1902t SNL g 2213e tdEL~ SEC36 TZZN RZ6E MEASUREO DEPTH TVD RECTANGULAR COORDI'NATES 8ELOI4 KB FRON KB SUB-SEA NORTH/SOUTH EAST/tdEST 11323.00 10382.11 10327.01 3120.60 N 845°99 E 11377.00 104~28o70 10373.60 3145.91 N 856.21 E 11465.00 1050~.63 10449.53 3187.16 N 872.85 E COMPUTATION DATE: 4-MAY-g0 PAGE 9 BP EXPLORATION Z-18/L-16 MPI ENDICOTT NORTH SLOPEr ALASKA ~ARKER PBTD DRILLEReS DEPTH DATE OF SURVEY: II-APR-1990 KELLY BUSHING ELEVATION: 55o10 FT ENGINEER: FRITZKE · ~~*~ STRATIGRAPHIC SUMMARY ~*~*~*~~ SURFACE LOCATION = 1902e SNL & 2213' WELt SEC36 T12N R16E MEASUREO OEPTH TVO RECTANGULAR COORDINATES BELDB KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11377.00 10¢28o70 10373°60 3145o91 N 856o21 E 11465.00 10504.63 10449°53 3187o16 N 872°85 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL OEPTH DEPTH DEPTH 11465.00 10504o63 104~9.53 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 3304.52 N 15 19 ~ SCHLUMBERGER O I RECT I ONIqL SURVEY COMPANY BP EXPLORAT I ON WELL 2- 18/L- 18 MP I FIELD ENDICOTT COUNTRY USA RUN ONE DATE LOOOEO 21 - APR - 90 REFERENCE 73827 WELL 2-18/L-16 MPI (1902' SNL, 2213' WEL, SEC ;, T12N,R16E ) HORIZONTAL PROJECTION MIR'TH so0o 4000 2OOO 1000 REF 738~7 SCI~.E = 1/1000 IN/FT -~ ............................ , ......................................................... ~ .......... ~,~.~ .......................... +.~...~..~... ~-~-~- -+"+"{'"i ...... t'"!'"i'"i ..... ;--.;.4.-.v-. 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Ii [ [ ~ ~ ~ I ] I :iii fill ljii [ii![ · i t ! !...]. .... · i'll :' : ::.~:! :~4- :,~: ..~-~.z~.44-~.~-44...~...~ ...... ~...~.4...~....--:..~..4...~.-:..4..-~4-~-.-.i-$.4-4.-.-,+++- 4..4..4.-..¢..¢.4...~ ....... ~.4.-.L~ ...... ~..~.-4.-~ ...... +.-4-4-.-+..-~4-.''~ -..~,.~ ......... t...,..4 .......... ~.+.., ....... m'4-. -:: ---~-~ ........ ~'-'"'""-"'*'*""'~""-+-+- ~ '-H'+~ .... · --~--~-~-t'-~--~ ..... ~'~'-t-~--v-'~-??+'-t ....... t-~-~"'"~"'~-~-'~- -+'?"f'~ .... I ~ ! i ' i i i ~ ~ ~ ~ FT~--t:i:rF'i'':'l:''' ''" ,,,~i,,:, ,,:, '?'~'"" ":' "" ':'''-r-'!-' I'1'I '"t II C;) PROJECTION ON VERTICAL PLANE IS. - 19S, 81CAL£D IN VERTICAL DEP'fH~ HORIZ SCALE = 1/1000 IN/FT AOGCC GEOLOGICAL MATERIALS INVENTORY LIST cered intervals Lx/,~ _ ~ I [ check off or list data as it is received ] drillir~§', fiis~o~ -,:s'ur~e,,.yl ~ '~.11. te.~ts , ~/ - L,.~i ' ', _~',',, "o~ V 1~ I ~ ~,~ , , ,',' ~, ....... ' ......... ~ ......... '.: .... ','~ ~ I ~ . si ~] 11] 13] LOG TYPE ' ' .. RuN NO. ] NTERVAL"~ SCALE .... BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 15, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: /.~WELL 1-01/J-19 7/27/90 *PERFORATION RECORD 11 790'-1 2220' Run No. 1 SCHLUMBERGER WELL 1-27/P-20 *CNL-GR (2.5" TOOL) 9950'-1 0711' SCHLUMBERGER 7/21/90 Run No. 3 WELL 1-47/(~-21. ~.~PERFORATION RECORD 10882'- 11254' SCHLUMBERGER WELL 2-18/L-16 *PERFORATION RECORD 10280'-11210' SCHLUMBERGER 7/28/90 Run No. 1 7/25/90 Run No. 1 ,. Oil & Gas tuns. [,un]mission Anchorage *TMD 12750' - 14222' Halliburton Run No. 1 WELL 1-63/T-22 *TEMPERATURE SURVEY 12180' - 13093 Run No. 1 Camco WELL 1-67/T-20 *PRODUCTION PROFILE' 11275' - 11800' Camco Run No. 2 WELL 1-69/V-19 *DUAL LATEROLOG 11521' - 12994' Halliburton Run No. 1 *SPECTRAL DENSITY 11524' - 12994' Halliburton Run No. 1 *RFT Run No. 1 Halliburton *CET 3100' - 12898' Schlumberger Run No. 1 *CBT 3100' - 12872' Schlumberger Run No. 1 *PERFORATING RECORD 11125' - 12874 Schlumberger Run No. 1 WELL 2-04/M-19 *PRODUCTION PROFILE 10300' - 10685' Camco Run No. 1 WELL 2-14/O-16 *PRODUCTION PROFILE 10300' - 10998' Camco Run No. 1 WELL 2-18/L-16 *DUAL LATEROLOG 10100' - 11428' Atlas Run No. 1 *DGR/CNO/SFD 10557' - 11463' Sperry Sun Run No. 1 *FORMATION MULTI-TESTER 10636' - 11182' Run No. 1 Atlas *CBT 10160 - 11348 Schlumberger Run No. 1 *CET 10160' - 11370 Schlumberger Run No. 1 WELL 2-22/L-14 *TEMPERATURE LOG 11080' - 12235' Camco Run No. 2 WELL 2-36/O-14 *COLLAR LOG 10160' - 11260' Atlas Run No. 1 WELL3-01/N-29 STATIC TEMPERATURE SURVEY 12250' - 12953' Run No. 1 Camco WELL 3-07/N-28 *TEMPERATURE LOG 13000' - 13400' Camco Run No. 1 WELL :~-39/J-39 *TDT-P 14120'- 14636' Schlumberger Run No 1 WELL 3-49/J-40 *DUAL STATIC SURVEY 14922' - 14934' Schlumberger Run No. 1 WELL 4-04/T-26 *INJECTION PROFILE LOG 13575' - 13975' Run No. 1 Camco *TEMPERATURE LOG 13100' - 14037' Camco Run No. 1 0 Ft I I--I-- I I~1 13 SEFlVlCES WELL LOG TRANSMITT&L TO: AOGCC ATTN: John Boyle 3001 Porcupine Drive Anchorage, Alaska 99501 April 26, 1990 RE: MWD Formation Evaluation Logs - Endicott 2-18 / L-16 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 Mr. Erik A. Opstad. 2,, & 5,' Presentations: 1 Blueline Prints 1 Folded Sepia TVD 2" & 5" Presentations: None (Only 1 Survey Point Available) Digital Data: 1 Tape Verification Listings RECEIVE[) Received : :APR o 199n Alaska Oil .& Gas Cons. Commission Artchorag~ Alaska Oil & Gas Conservation Commission 8537 Corbin Drive (99507) · P.O. Box 231649 ° Anchorage, Alaska 99523 (907) 522-3256 ° Fax (907) 522-3432 A Baroid Company MEMORANDdM State of Alaska ALASKA OIL A~ND GAS CONSERVATION CO~ISSION TO: Lonnie C. Smi~%'-'.~ DATE: April 11, 1990 Commissioner ,~/ · mtENO: JT.HH. 411.2 THRU: TELEPHONE NO: SUBJEC'E BOP Test BPX DIU MPI 2-18/L16 Permit No 90-0043 Endicott Field FROM: w id R. Hawkins ~&rO Petroleum Inspector Tuesda A ril 3 .!9_90: I left Anchor,age at 7:15 a.m. via Alaska ~~ ~ay arriving at 8.45 a.m. I went to BP Exploration well A-16 to check on another job but MP was having problems. I left BP Exploration's Location to BPE Endicott to witness a BOP test on 2-18/L-16. There was one failure. I filled out an AOGCC field report which is attached. In summary, I witnessed the BOP Test on BP 2-18/L-16 MPI was satisfactorily performed by Doyon 15 crew. Attachment 02-001A (Rev. 8~85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Inspector Location: Sec ~ T/~.~by R/~4~' Representative Permit # ~(~ - './~.~ /~~j Casing set ~ Drlg contrctr Location (general) General housekeeping Reserve pit Well sign Rig Rig # /-~ Rep ,t~.f/wf~ ACCUMULATOR SYSTEM: Full charge pressure Press after closure ft psig psig MUD SYSTEMS: Vi Trip tank su~ Pit gauge Flow monitor Gas detectors BOPE STACK: Test Pressure Annul ar preventer ~ ~' ~ ~' Pipe rams ~ $~ Blind rams ~0 Choke line valves ~ ~ ~ HCR valve ~0~ Kill line valves ~ ~ Check valve .,~ ~' ~; TEST RESULTS: Audio min /9 min ~ Test time Pump incr clos press 200 psig '--' Full charge press attained J Controls: Master ~ ~' Remote ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: psig sec sec Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges Adjustable chokes Hydraulically operated choke Failures ~ hrs Repair or replacement of failed equipment to be made within Test pressure Test pressure Test pressure Test pressure Test pressure /? ~days and Inspector/Commission office notified. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 19, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn''Mr. C. V. Chatterton 2-18/L-16 MPI (Endicott) Enclosed, in triplicate, is form 10-401, our Application for Permit to Drill the above-named well. A spacing exception, Administrative No. 202.6, was approved for this well for the proposed bottomhole location falling within a distance of 700 feet from well 2-16/M-16 MPI. Also included are the attachments listed on the application form, and a check in the amount of $100 to cover the permit filing fee. Yours very truly, M. E. Miller Endicott Lead Engineer MEM/KTH CC Richard Loveland Well File March 27, 1990 Telecopy: (90?)276-7542 M. E. Miller Endicott Lead Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Duck Island Unit/Endicott ~-18/L-16 MPI BP Exploration (Alaska) Inc. Pemit No. 90-43 Sur. Loc. 1902'SNL, 2213'~>~L, Sec. 36, T12N, R16E, UM Btmhole Loc. 3919'SNL, !220'I,~EL, Sec. 25, T12M, R16E, ~ Dear Mr. Miller: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. To aid us in scheduling field work, please not~.fy this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly yo_~r,s ~ .~ / .' /, .,- . Chairman of Alaska Oil and Ga~ Conse~ation Co~ission BY ORDER OF TME CO~ISSION dlf Enclosure cc: D~partment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservatio'n w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilli-illb. Type of well. Exploratoryr3 Stratigraphic Testl-I DeveloPment Oill-xl Re-EntrY [] DeepenI-3! Service [] Development Gas [] Single Zone [~ Multiple Zone [] 2. Name of Operator i5. Datum Eieva~fion (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property;' Designation P. O. Box 196612,. Anchora.ge, A/aska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(8,,. 2o AAC 25.025) 1902' SNL, 2213' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 4277' SNL, 1340' WEL, SEC. 25, T12N, R16E 2-18/L- 16 MPI 2S 100302630-277 At total depth 9. Ajspr°xirriate"spud date Amount 3919' SNL, 1220' WEL, SEC. 25, T12N, R16E March 31, 1990 $200,000.00 i2. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandmvD) property line ....ADL 312828 @..1220' feet 2-16/M-16 @surface-lO'feet 2560 11530'MD/10481 'TVD..feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) Kickott depth 5000 feet .. Maximum hole angle 35.7,0 Maximum surface 3900 pslg At total depth (TVD)1000074890 18. Casing program Setting Depth s~ze Specifications TOp. '" BottOm Quantity of cement H~)le Casing weight Grade C~)upling Length MD TVD' "'MD TVD (include stage data) 30" Struct. Drive Pipe 75' Surface 131' 131' Drive 17-1/2" 13-3/8; 68// ,~oc,,,,~ Butt 2444' Surface 2500' 2500' 2700 cu fl Permafrost 12-1/4" 9-5/8" 47// NT80S NSCC 9035' Surface 9091' 8500' 12-1/4" 9-5/8" 47// NTgSHS NSCC 1454 9091 8500' 10545' 9681' 2318 cu fl Class G ,, , 8-1/2" 7" 29// NTgSH$ TKC 1236 10294 9477' 11530' 10481' 408 cu ft Class G ............. 1'9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical, feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .... ~... Surface Intermediate Production : Liner Perforation depth: measured ~ ~ . { :: ~: '-~ ~ ~1; ~; , true vertical ,~ '..,',-,--~,'~~ , 20. /~,ttachments Filing fee [] Property plat []" BOP Sketch I~1 Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed rep.ortl-I 20 AAC 25.050 requirements l-I 21. I hereby-certify that the foregoing is true and correct to the best of my knowledge / I Commission Use Only '"~ I P~rmit Number IAPi'number .... IApproval date 'lSee cover letter '~',:~ -/--/..:~ J50-~___~, --- 2_.;~_.o~'.~___ I 03/27/90 Jfor.other requirements C°nditio'ns of approval Samples required [] Yes ,,~_No Mud log required []Ye~/,~ No Hydrogen sulfide mea.~sures. [] Yes~,~ No Directional_ survey requ~recl ~'Yes [] Required working,,p'F~~~~~~;'~5M; r-Il OM; i-1151(/I; ' Other: Approved by ~,,-- ~, ,/~. ~~'-:~ . Commissioner the commission Date _ , Form 10-401 R( 12-1-85 Submit ~ :ate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-18/L-16 (MPI) Objective Well 2-18/L-16 will be drilled as an oil production well. Zone 3A is the primary objective. The completion will be mn at the time of drilling and will consist of a packer-tailpipe assembly. .Operation Execute a rig move to slot 2-18 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. Run and cement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 5000 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Complete with a packer-tailpipe completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9- 5/8" annulus of the well. Once the rig is released the 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet. Additionally, a CET/CBT/GR/CCL will be run in the 7" liner, a gyro will be run from TD to surface, and the well will be perforated with wireline conveyed guns. KRL 3/19/90 ENDICOTT DEVELOPMENT WELL 2-18/L-16 (MP.!). DEPARTURE TO TARGET: 3030 FT 10884 FT MD 9956 FT TVD BKB DEPARTURE TO BHL: 3408 FT 11530 FT MD 10481 FT TVD BKB TRUE NORTH GRID N 16° 42'E SLOT 2-18 SURFACE LOCATION X = 258,996 FT; Y = 5,982,514 FT 1902 FT SNL; 2213 FT WEL SEC 36, T12N , R16E NOTE: THE NEAREST WELL TO 2-18/L-16 IS 2-16/M-16 LOCATED 10 FT NORTHEAST AT SLOT 2-16. KRL/3-9-90 BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM STACK DRILLING I RISER I ANNULAR PREVENTER PI PE RAMS I I I BLIND RAMS I MANUAL GATE 2" KILL LINE HYDRAULIC GATE DRILLING SPOOL I I PIPE RAMS ,, ! 4" CHOKE LI,NE HYDRAULIC MANUAL GATE GATE ~o 22 0 ® 42400 0 44 0 62_0 I ?0 ii ~)0 1:3 0 17 I~) 0 ~1 0 2~ 0 2.r2b0 o k36 CERTIFICATE OF SURVEYOR i kearby certify thatl am properly registered end licensed to practice land surveying in the Slate of Alaska end that this plat represents on proposed location for the 'Well numbers shown above. All surveying was done byme or under my supervis~n, and that ell dimensions end details ere correct. DRW. 116-85 SHEET 2 of I0 REV. 0 iV O TES ' 0 Indicates well I Indicates Celc~Jleted Section Corner Position Indicates Perpendicular Offset Distance ilndicates I"~r~endiculer Offset Distance Per,~endiculQr ~istgnC~ v~r~es fgr ?ach will } PLAT OF MPi PROPOSED WELL LOCATIONS LOCATED IN SEC, 3S, T.I~N.,R. IS E. UMIAT M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY F.R. BELL ~ ASSOC.' PRUDHOE BAY OFFICE PRU~OE BAY, ~ASKA .! DATE ' IlOV. I$, IltS ICALE, I"" lO' DRAWN BY'. R~.T. CHECKED BY' I.E. ttkk MP IOl~ I U~' JNE 6 LiT ' i I Y-S912412,~7 N-710~324,5~ 7~21'10,0670" 14~17'10.4~4' l~'Zi.4l X- 2~9110,7~. E- 464137.36 .. 2 Y- ~982~79.BB N- 780~3~3.~2 70~2~'J0,98~4· ~47~57'2~"~6257· ~B3~.4~ Z'16S,94 X- 2~904J.49 E- 464094,4~ 3 Y- 5982474. lB N- 7805321 98 70~2i'09.'984'6' 247c57'20,625B" 1936.77 i 2032.21 464135'.65 4 Y= 5982571.69 ' N= 7805350.99 7002['10.~"~" ' [47~-57'24.7856' 1843.80: 2174.41 I X= 259035 76 E= 464092 74 5 Y= 5982465.99 N= 78053~9.46 70~l'09.902~" ~47c57'20.7857" X= 259169.27 E= 464~.95 6 Y= 5982563.50 N="7B05348.47 70°21'10,8168" 147°57'24',9454' IB~2.1~ 2t79.g8 X= 259030,02 E= 464091,04 7 Y=' ~9824~7,80 H= '7805316.94 70°21'09.8200" 147~7'20,945~- 19~3;~ 2043.06 X= 2~9163,~4 E= 464132,24 B ~y=' ~9a2~5,30 N= 780~345.94 70~21'10.~'344· 147o~7'25.10~3' 1860.~4 2XB~,3~ X= 2~9024.29 E= 464089. 9 Y= ~9B~449.6~ N= 7805314,41..... 7002'1'09,'7376· 1"47~7"21;1~S4~ 1961,19 204B.53 X= 2~9~57.~0 E- 464130,~3 ~-' lO ~Y= 5982~47, i]'" N= 7B05343;42' 70°21'10,6~21' i47~7'25;2651' 116~,91 2190',B3 X= 2~9018,5~ E- 464.087,62 t~ Y= ~98244i,42 N= 7805311."B9 70~2t'09.65~3" 147°57'21,2653, 1970'.26 .... 20~4.00 ..~X= 259152,07 E= 464128,83 ~2 Y= ~9BZ~3B.92 'N= 780~340.90 7o~2~'io,'~697' 1'47o57'25,4~'50' 1877;'21 2~96.3o X= 2~9012,82 E= 46408~,92 13 Y' ~982433,23 N='7805309.36 70~2'1'09,5730' 147°57'21,4251'~ 1978,63 ~0~9.47 X= 2~9146,33 E= 464127, 14 Y= 5982'~30.73 N= 780~338,37 7'0~2'I'10,4874· 147°57'25,~B49' IB85,66 220i.77 X- 2~9007,08 ~= 464084,2~ :, , t~ ~= 5982425.03 N= 780~306.84 70~21'09.4906· 147057'21,~B~0' 19'~'7,00 206~,94 X= 259~40,60 E= .46412~,42 ~6' Y= ~982522,54 N= 7805335.B5 70021'10,405l' 1'~7°57'25,7447~ 1194,03 2207,24 X= 259001,3~ E- 4640B2, 17 Y- 59B2416,B4 N= 7B0~304,31 70°2i'09,4083" 147°57~1,7449' 1995,3i 2070,41 X' 2~9134,16 E= 464123,71 lB Y= ~902~14,3~ N= 7B0~333.32 70°21'10,3227' 147o57'2~',904&· 1902,40 2212,71 X- 2~899~,61 E= 464080.80 19 Y' ~982408,6~ N= 7805301,79 70c21'09,3260' 147°~7'21,9047'' 2003,75 207~'~'B9 X= 2~9~29,13 E= 464122.00 20 Y= ~9'B2~06.16 N- 7805330,B0 70c2"~'10,2404' " 14'7~57'26"'0&44, 1910,77 22lB, lB X= 2~8989.87., E= 464079.09 2~ Y= ~9~2400.46 .- 780~299.~7 70~2'~'09.2436· 147~7 ~;'0,'~,~ 20~2;12 ~0~2.3~' x- 2~9t2~.~9 E= 464~20.30 ....... ii i i i i i ii i ii ii MPI PRO~SED WELL L~ATION LIST ~ OF,AC~t._ LOCATED IN SEC. ~6,T. IZN.,R.leE. UMIAT M. g"~--'~~"~ ~ SOHIO ALASKA PETROLEUM CO. fa~ t ~69194 .'.~ oew. NO- 11~-85 PREPARED BY DATE'NOV. 13, 1985 O~ESSI~k~ ~~ SHE ET 3 of i0 ' · SCALE: N/A ~~~ ~ p RU OHOE BAY OFFICE ~. REV. 0 PRUOHOE BAY, ALASKA OeAWN BY: RG.T CHECKED BY: I.[. i iii ii ii iii i ii i ii iiii i I~LL I~ iOl~ I U1 '01K i L TIT L~ "TUI~ X- 2SI914,14 E- 4&4077,31 23'' Y- 5902~92.27 N- 7B0529&.74 70~21'09,'1&13· 147~57'22.22~4' 2020.49 X- 2~9117.&~ E- .464118,~9 24 **Y- ~982489.77 N- 780~32~.7~ 70~21'10.07~7· 147~7 26,3842' 1927.~3~ 2229.13 'X- 25_8.~78~_~_E· .... 464075~6B ............. ~ .... iX- 2~9~11_ .92]E-. 464116..,Be ~_~ 26 ~Y- 59B24BI.~B ~N- 7B0~23.2~ '70~21'09.99~4' 147~7'26.5440·~. 19~.~0 ',22~4.60 ,X- 258972.67 i E' 464073.~7 i ............. 27 ~Y' ~e2~75.8~ N- 78052~1.6~':70~21'0e.9~66" I47c'~7'22.~442· 20~7.24~ 2097.77 X- 2~9106. I8 E- 464115,18 ., 2e y, ~8247~.~9 ~, 780~20.70 70o2~'09.9~1· ~47~7.~&.70~9, ~944.27"~2240.07 x- 2~e~6.9~ E, 4~4072.27 2~ Y- ~9e2~67.~0 N- 7eo~2eg.~7 ~0~21'0B,914~· 147~7'22,'7040· 2~4~,iI 21~'~'~"' .... .... X- 2~100,4~ E- 464111.47 ; 30 Y- ~98246~,20 N- 7IO~31I.ll 70o21'09,I287' 147o57'26,B637· 19~2,64 .... 224~.5'4 X- 2~B96~.20 E- 464070.~6 ~ 3~ Y- ~9823~9,~0 N, 7~0~2B6.,~ ~70~2~'08,1320' 147~7"22,B&3~" 20~3,~i 2~01,72 ~- 259094,71 E- 464~'76 32 Y- ~9B24~7,0~ N- 780~3~5:6~],~70~2~'09.74~4" 147°~7'27,0236" 19~,0'~ ~22~,0~ X- 2~B9~5,46 E- 46406B e~ I .l 3~ Y- ~9B23~1.3~ N- 780~284.~2 ~70~2~'0B.74~6" 147~57'23,0237· 2062.35] 2~14.~9 X- 2~90BB.9B E- 464ll0,06 ~ X= 258949,7~ E- 464067.15 35 Y- ~gB2~IB,~ N- 7B0~274.02 70°2~'0B,420~" 147~7'23.6632" ~ 209~.~4 2136,07 X- 2~9066,0~ E-' 464103,23 I 36Y' ge;4z6.0 ,-7e0 03.0 70 2z" 9. 347' 247 n7'27.,229' 2002.,7 227,.37 37Y- nge;3zo.s6 ,- 7eon27 'no 70 ; oe.3379· 47 n7' 3.,2 0' 2 4*.nn x- 2 9060.30 464 0z' 39 Y- 5982302.17 N- 710526B.gB 70021'0B.25~6" 147~57'23.tl29" 2112.~1 "2147.02 X- 2~90~4.~6 E- 464099,B2 40 Y- ~982399,67 N' 7B05297",98 ~70°21'09,1700' 1~7~S7'28.1'426' 20~9,&2 2289,3~ X' 2~891~.31 E- 4640~6.91 4~ Y- ~98229~,97 N- 7B0~266.4~ 70o21'-0B,1733' 147~7'24.2427' 2120.9~ 2152.49 X- 2~904B,8~ E- 464098.~1 -- . 42 Y- 5982~91.48 N- 7B0~29~.46 70o22'09.0B77' 147~7'28.3024' 2027.99 2294,79 X- 2~8909.~8 Em 4640~.20 ..... , ... i i i i ~~~_ MPI PR~SED WELL L~ATION LIST ~ O~ ~ ~t , ~~~...._~.~ t~ LOCATED ~, SEC. SS, ~.~Z.. ,.~S [. ua~a. ~~~~~~~.p SOHIO ALASKA PETROLEUM w~%~~~~ DRW. NO. 116-85 PREPARED BY DATE ' NOV.13 , 1985 · ~Z~SS~k~~ SHEET 4 of ~o ER. BELL E ASSOC. SCALE: N/A ~~~ " PRUOHOE BAY O~CE DRAWN BY: R.G.~ -',. REV. O PRUOHOE BAY, ~ASKA CHECKED BY: ii i iiii iiiii i i i ii iii · I..... Iqll IIELL AlP ZON~ 3 U~..ONE 43' y, S91221~,71 N,"7105263,~3'- 70~2~.0i,090t X- '259043,09 E- 464096,4~ 44 Y- ~982~8~,29 N- 780~292,9~ 70~2Z'09,00~4· Z470~7'28,4623' ' 203&,36 2300.26 X" 2~890~,84 E- 4640~,50 j X= 259037,36 q6. Y= 59B2~75,10 N= 7B05290.41 70' 21'08.~210' ~ 147~57'2B,6221* i 204~.7~ 2105,7~ I- 25BBgB, 11 E= q6~051,79 I 47 Y= 59B2269.~0 N= 7BO525B.BB : 70c21'07,926I" ; 1~7c57'24,6223' T 2146.07 216B.91 X- 25903t.62 E- 464092.99 ~ 48 Y= 5982~66.91 N= 7805287,89 ~70°21'08.8407" 147°57'2B,TB20~ 2053.10 23~.2~- X- 2~8892.37 E- 4640~0.08 49 Y= ~982261.21 N-'7805256,35 70o21'07.8439" 147°57'24.'712~ X- 2~9025.B9 E= 464091.29 ~0 Y= 5982358,71 N= 7B0~285.36 7002~'08.7584" 147°~7'28.941B" 206~.47 23~6.67 X= 258886.63 E= 464048.38 5~ Y= 5982253,02 N= 7805253.83 ~70~2t'07,7626" 147o57'24,9420" 2162.11 ~179,B6 X= 259020. ~5 52 Y= 5~82350,52 N= 7805282.84 70c2~'08,6760" 147o57 X= 258880.90 E= 464046,67 53 Y= 5982244.B3 N= 7805251.31 70o21'07.6793" ~47o57'25.~019 X= 2590~4.4~ E= 464087,88 ~4 Y= 5982342,33' N= 7805280,31 70o2~'08,5937· ~47o57'29,2&15" 2078,22~ 2327,&2 E= 464044.96 X= 258875. 55 Y= 5982236.64 N= 7805248.78 70c2~'07,5~6~" ~47o57'25,2627" 2279,56 2~90,80 X= 259008,68 E= 464086.~7 ~6 Y= 5~82334,24 N= 7805277,79 70~2~'08,51~" 247°57'29.4214= 2086,59~ 2333,09 X= 258869,43 E= 464043,26 57 Y- 5982228,44 N= 7805246,.2~ 70~21'07,5146" 147°57'25,4216" 2tB7,93 2t96.27 X= 259002,94 58 Y= 5~82325.95 N= 7805275.27 70~21'OB'.'~90· L ~470~7'29,~B~2' 20~4.96 2338'56 X= 258863"&9 59 Y' 5982220"25 N= 7805243,73 70~21'07,4323" '147057'25"5B~4" 2~&"30 220~'74- X" 2~8997"21 E" 464082'76 &0 Y' 5982317"76 N''7805272"74 700~i'0B,3467= ~'470~7'29,741~" 2103'33 2344'03 X' 258857'96 E= 464039'B5 61 Y' 5982212,06 N''7805241'21 70~21'07,3499" 147057'25'7413" 2204'&7 2207,21 X' 258991'47 E' 464081'05 62 Y= 5982309,57. N= 7805270.22 70C21'0B.2643" ~47057'29,'~0~9" 2~1~.7~ 2349,50 X= 258852.22 E= 4640~B.14 63 Y= 5982203.B7 N= 780523B.69 70°2~'07.2676' 147o57'25.90~l' 2213.05 2212.~9 X- 258985.74 E- .464079,34 ........ iii ii I i iiiH i i i rI -, MPI PRO S ED WELL L ATION LIST SO.I'O ALASKA PETROLEUM CO. (i~,~//.~~.~ DRW. NO. IIG- 85 PREP&RED BY DATE:NOV.13,1~B5. . qlZo~h'~~ ~-- ' F.R BELL & ASSOC ~A~uF;~S~~~ SHEET 5of IO ' ' ~CALE* N/A ~~~ PRUDHOE BAY OFFICE DRA~N BY : RG.T i i i i i I i ii iii i i I~ --~1 ..... i I I I LJ ~:~'~ 11 ~.I .Il IJ II I] I IIII fiLL ttI. P ZONE 3 UT )NE 6 LATITUIE Lt .TUll lilt lilt 64 Y-"S91230t,3! N-'7i05267,&~ 70~21'01,1120'".~47oS7'~0,0&01· ~lJ20,01" ~13~4,97 X- 25B846,41 E' 4&403&.43 6~ Y' 5982295.68 N' 7805236.16 70o21'07.2852, i47°57'26,0620' "2221.43, 221B.'~l& X' 258980.00 E' 464077.64 66 ': Y' 5982293.18 N" 7~!05265.17 ~ 70 21'08.0997" ' 147-57'30'.2206" ;'2228.45 :: 2360.45 X': 258840.75 E' 464034.73 , , ,, 69 :y- 5982179 30! N' 780523;1 11 70c21'07.0206' 147c57'2~,3;807" 2238, t7 2229.1 X- 2~,i8968153; E- 464074:25 ., 70 Y- 5982276.10 i N" 7805260.1.2 70o2~;07.93;50" : ~47o,"i7'$0.5403; X- 258829.28 E- 46403t.$! ] ..... I M PI PROPOSE D WELL LOCATION LIST 0~' ~4~. "~t LOCATED IN SEC. 36;T. 12N.,R. IE;E. UMIATM. · ---.-.._'4_a k ,, ~~,ru, q~-~%e~~ PREPARED FOR ,~'".~""~--~. ' SOHIO ALASKA PETROLEUM CO. ~ ~"'"l'~"~"'e -.., I,,,t,o. 6919.s ~,1':~,~",_I~ ~ DRW..... NO. IIG-8§ _ PREPARED BY · ,-~ -,--- ~- ,~, SHEET G of IO · SCALE; N/A ~k~,,~o~ss~o,~,~.d,"-,~ _ pR U DHOE BAY OF FlOE '"~:~qk,,~,~"~~ DRAWN BY: R.G.T. REV. 0 PRUDHOE CHECKED BY'* B.E II I I III II Il I Ill I I III II Search Radius= 200 For proposed well: Location = Top Bottom Closest Approach Analysis --- Date: 9-MAR-90 Time: 14:17:58 COURSE LINE 2-18/L-16 [34-25-12-16] W-E S-N TVD(SBS) 258996.00 5982514.00 -56.00 260079.98 5985744.58 10425.00 Ail depths in feet Below Kelly Bushing (BKB) Note: WELL IDENT A000-0000051 MI-1 A000-0000083 MI--33 A000--0000086 MI--36 A029--2051800 MI-SD7 A029--2063900 MI-SD9 A029-2064000 MISD10 A029-2156800 MI-P18 A029--2158500 MI-M19 A029--2160500 MI-O20 A029-2163900 MI-O16 A029--2166200 MI-P14 A029-2166900 MI--M25 A029-2167200 MI-O25 A029--2169300 MI--P20 A029-2169800 MI-J22 A029-2172200 MI-N22 A029-2174300 MI-J18 A029-2174800 MI-P24 A029-2175000 MI-S14 A029-2176700 MI-R12 A029-2177100 MI-K16 A029-2180100 MI-J19 A029-2181500 MI-N14 A029-2182700 Closest Approach /PROPOSED~ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE NO COORDINATE NO COORDINATE NO COORDINATE 2807.2 1707 5 4839 8 5646 2 1 1 5526 1 1400 9 POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW 0.0 2799.9 14.6 1513.8 0.0 1700.0 3.3 1562.7 0.0 4832.3 1052.5 1136.3 93.5 5644.2 41.9 58.2 0.0 0.0 0.0 70.5 61.7 5519.5 87.8 138.0 0.0 1400.0 4.7 15.3 4278.5 0.9 1.0 5000 0 0 8 1000 7 1339 6 2999 8 4600 7 400 9 120 6 379 .4 4860.7 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4278.5 0.0 0.0 4999.8 0.0 1000.0 1338.6 2999.3 4599.7 400.0 119.7 400.0 4859.8 67.6 0 0 0 0 13 9 0 0 1 8 31 6 33 3 34 5 0.7 0.3 1.1 25.7 32.2 180 .1 208 .1 173 .3 59.6 173 .0 165.3 186 .9 176.1 159 .7 49 .5 187.4 21.8 Vertical /PROPOSEDX TVD DEPART Intersection /NEARBY~ TVD DEPART 8016.1 1636.5 4220.0 534.2 -3788.8 7482.1 1252.9 4313.2 531.0 -3161.3 5275.0 17.0 6932.9 858.4 VERTICAL DISTANCE 5665.2 5.6 391.1 9465.3 839.8 2533.3 5534.4 63.7 6079.5 142.3 545.2 5034.8 59.4 5687.7 105.7 -652.0 /4I-P17 3593 . 0 0 . 0 3592 . 1 A0 29-2184700 lqI-P19 1600 . 8 0 . 0 1599 . 8 A0 29-2188500 MI-Mi6 0 . 9 0 . 0 0 . 0 A0 29-2189200 MI-P13 3900 . 2 0 . 0 3899 . 7 A0 29-2192100 MI-Q15 0 . 9 0 . 0 0 . 0 A029-2193100 MI-L14 3596 . 1 0 . 0 3595 o 6 76.5 18~0 0.0 29.4 0.0 14.8 177.6 38.7 9.4 129.3 170.1 9.4 5279.0 17.4 562.9 8.5 -4715.2 $ UMHAR Y The well which comes closest to the proposed well is: A029-2188500 MI-M16 Closest approach distance = KICK OFF for this run- = 9.4 feet 5000.0 feet --- Closest Approach Analysis --- Date: 9-MAR-90 Time:' 14:20:10 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 2-18/L-16 [34-25-12-16] Location = W-E S-N TVD(SBS) Top 258996.00 5982514.00 -56.00 Bottom 259678.19 5985852.60 10425.00 Note: Ail depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED~ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE AO00-0000051 'MI-1 A000-0000083 MI--33 A000-0000086 MI-36 A029-2051800 MI-SD7 A029-2063900 MI-SD9 A029-2064000 MISD10 A029--2156800 MI-P18 A029-2158500 MI-M19 A029-2160500 MI--O20 A029-2163900 MI-O16 A029-2166200 MI-P14 A029-2166900 MI--M25 A029-2167200 MI-O25 A029-2169300 MI--P20 A029-2169800 MI-J22 A029-2172200 MI-N22 A029-2174300 MI-J18 A029-2174800 MI-P24 A029-2175000 MI-S14 A029-2176700 MI--R12 A029--2177100 MI--K16 A029-2180100 MI-J19 A029-2181500 MI-N14 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 2807.2 0 . 0 2799 . 9 14 . 6 1513 . 8 1707.5 0.0 1700.0 3.3 1562.7 4839 . 8 0 . 0 4832 ..3 1052.5 1136 . 3 5614.2 84.2 5611.8 41.1 69.0 1.1 0.0 0.0 0.0 70.5 5501 . 8 55.7 5498 . 1 87 . 6 144 . 8 1400 .9 0.0 1400.0 4.7 15.3 4278.5 0.9 1.0 5000.0 0.8 1000.7 1339.6 2999.8 4600.7 400.9 120.6 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 4278 .5 67.6 32.2 0.0 0.0 180 .1 0.0 0 .0 208.1 4999.8 13.9 173.3 0.0 0.0 59 .6 1000.0 1.8 173.0 1338.6 31.6 165.3 2999.3 33 .3 186.9 4599.7 34.5 176.1 400.0 0.7 159.7 119.7 0.3 49.5 379 .4 4860 . 7 0.0 0.0 400.0 1.1 187.4 4859.8 25.7 21.8 Vertical Intersection /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART 7944.3 1584.9 3961.9 331.3 -3975.1 VERTICAL DISTANCE 7605.0 1341.2 4080.6 349.7 -3516.9. 5278.0 17.3 5704.0 7.6 6703.7 693.8 9215.5 676.0 426.9 2512.7 5737.3 122.4 5119.5 79.0 -616.9 6382.5 463.1 5971.5 417.7 -410.1 5557.3 69.3 6119.2 146.2 561.9 A~29-2182700 MI-P17 3593.0 0.0 3592.1 A~29-2184700 MI-P19 1600o8 0.0 1599.8 A~29-2188500 MI-M16 0.9 0.0 0.0 A~29-2189200 MI-P13 3900.2 0.0 3899.7 A029-2192100 MI-Q15 0.9 0.0 0.0 A029-2193100 MI-L14 3596.1 0.0 3595.6 SUMMARY The well which comes closest to the proposed well is: A029-2188500 MI-M16 Closest approach distance = KICK OFF for this run = 9.4 feet 5000.0 feet 76.5 18.0 0.0 29.4 0.0 14.8 177.6 38.7 9.4 129.3 170.1 9.4 5325.9 23.7 649.2 15.2 -4675.8 BT.. - ASKII ! C,I~ / ! ! c.,- c,' ¢ s ' · t': ' ' ,'2' ·: · I --~9 '-o VIE. lg - ! (4031 4.&8-~ 550 ...... 1 .... ~ '=" i .... i--' ~'~ ~ IF IN DOUBT. . - ASKtt 12 · I? 'C" JG-O ' / I1:,.0 ' 12 '-0 ' J /Z '~' DOYON DRILLING, IIgC.' RI G NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equ i pmen t Manufacturer ~Nominai Model Capacity Shak er Desander Mu dci ean er s Centri fuve Brandt Demco Tri Flow Dual Double 2-12" cones 1000 9pm 700 9pm (each) Double 400 gpm 8 each - 4" (each) cones Pioneer Mark II, 150 gpm Decantin9 Desasser Driico Avi tarots Brandt Hoppers Geosource Vacuum 1000 9pm 8 each - 25 h.p. Dual Sidewinders lO00 gpm The trip tank and mud 'tank sections have one vertical pit level float indicator which are connected to the driilin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. Interval ENDICOTT MUD PROGRAM .MAIN PRQDUCTION ISLAND WELL 2-15/L-16 Mud Weight Viscosity (_ppg) (sec/qt) Fluid Loss (ml/30min) _0__H_ 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 2,500- 10,545 10,545- 11,530 Set 13-3/8" casing 9.2-10.5 40-45 Mud Type/ Components Set 9-5/8" casing 9.6-10.5 40-45 Generic Mud #5 Hang 7" Liner Seawater Fresh water Gel Soda Ash 15-16 9.0-10.5 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill 6-8 9.0-11.0 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill ENDICOTT PROPOSED DIAGRAM WELL 2-1 8/L-1 6 (MPI) NON-FREEZING FLUID TVD (BKB) MD (BKB) 30" DRIVE PIPE 131 FT 131 FT BASE PERMAFROST 1466 FT 1466 FT , SSSV 1550 FT 1550 FT 13-3/8" 68~'/FT NT-8OCYHE BTC 2500 FT 2500 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3000 FT TOP OF 9-5/8" CEMENT (ESTIMATED) 3300 FT ~,KOP(DIR:N 16.7' E; ANGLE: 35.7DEG) 5000 FT 4-1/2", 12.6~/FT L-80 TD5 TUBING .W/ 4-1/2" TAILPIPE 9-5/8" 47=/FT NT80S NSCC 8500 FT 9091 FT 4-1/2" SLIDING SLEEVE 9-5/8" PACKER 7" LINER TOP 9437 FT 10244 FT 9477 FT 10294 FT 9-5/8" 47~/FT NT95HS NSCC 9681 FT 10545 FT 7" PACKER PLUG BACK TD 7" 29~/FT NT95HS TKC LINER I 1450 FT 10481 FT i1530FT KRL/3-9-90 TEST PLUG --PACKING PORT TEST eORT LOCKSCREW CASING HANGER SPLIT SPEEDHEAD 13-3/8 -- 9-5/8 13-5/8'' API-SO00~ 13-5/8" API-3000~ CONTROL LINE-- 13-3/8" CONTROL LINE --~-1/2:' WELLHEAD ASSEMBLY,ENDICOTT SKSI 13-3/8"x 9-5/8"× 4-l/2" SOHIO ALASKA PETROLEUM COMPANY F I611RE ! (3) Ii. 3. 9-5/8" CASING AND IdELLtlEAD EQUII'HENT 3.1 TESTING B.O.P. STACK 1. After B.O.P.'s are nippled up to split speedhead, make up 13" x !~-1/2 Internal Flush B.O.P. test plug, Accessories Item 7, Part No. 538116. 2. Lower plug into head (it will land on tower step). Tighten /~ lockscrews 90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plug. CAUTION': It is very important not to have the lockscrews protruding into the bore of the head ~htIe either running or pulling the B.O.P. test plug. Always check them if in doubt. (29) I SPL I T SPEEDHEAD TEST PLUG 13-3/8" 0.0. CASING (30) .. ACCESSORIES ITEN 6 ii t! L · /c-!./2:tF ~:'E.~ALE ]'HO II II II Ii II II II ( i ; i BOP TESt' PLUG FOR UPPER BOWL (538117} ~.98 ACCESSORIES ITEM 7 II ~1 II · :1 i II '1 I! - ~,2 - 'E_: ;' ~-tJ5 FOR LOWER P_,OWL (19) 210 ! I II. 6. 6-1/2 TUB[NC AND UELLHEAD EQUIPHENT 6.1 TESTING B.O.P.'s 1. After 9-5/8" has been set and tested, run in B.O.P. test plu~, Accessory Item 6, Part Number 538117, uhich lands in upper bowl of the split speedhead. Run in 6 lockscrews lightly, 90° apart to keep plug from moving. 2. After test, retract lockscrews and pull plt,R. 3. Run in short bowl protector, Accessory Item 8, Part Number 538116, usin~ the same running tool, Accessory Item 5, Part Number 5381{5, that was used for the long protector. 4. After bowl protector is in place, run in 4 lockscrews lightly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Admin /~p(. ~/~__/~)~ 9. (9 thru i'3)' '- 10. (10 and 13) 12. 13. (4) Cas~ · .~/_~,~ ~-~-~o (14 thru 22) (5) BOPE ~,~. J-~-e~ (23 thru 28) Company fg / YES Is the permit fee attached .......................................... ~-- Lease & Well No. ~ZP/_ 3~33 ' DJf-~ N 0 JREM3uRK S 2. Is well to' be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~. 4. Is well located proper distance from other wells .................... , , 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ......... i ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ,,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~7-- Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of ~m.~l~s~~ BOPE attached. Does BOPE have sufficient pressure rating - Test to 3000/_~-o~m psig .. Does the choke manifold comply w/API RP-53 (May 84) .... ~ ............ Is the presence of H2S gas probable ................................. (29 th (6) Add: Geology: Engineering: DWJ_a.~-----LCS ~"/~'BEW rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- Additional requirements ............................................. ~-w INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: g&oo'z~ /~-/G ~ .AI-~,~ ~ ¢~o 2 ~ ' / 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. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/04/24 ORIGIN OF DATA: RLL REEL NAME: BPX CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/04/24 ORIGIN OF DATA: L-16 TAPE NAME: ENDICOTT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** .APR 3 o 199n Oii& Gas Cons~ Commission Anchoraff~ ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: L16.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/24 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: BP EXPLORATION WELL: 2-18/L-16 API#: 50-029-22032 FIELD: ENDICOTT LOCATION: 1902' FNL & 2213' FEL, SEC. 36, TWP. 12N, RNG. 16E, ARCTIC NORTH SLOPE, ALASKA, U.S.A. RIG: DOYON #15 COMPANY REP. E. GOEBEL DATE: 04/18/90 RLL ENGINEERS: M. MOORE & D. WESLEY COMPANY PETROPHYSICIST: A. B. CUNNINGHAM COMMENTS: NEUTRON AND DENSITY LOGS ARE CALIPER COMPENSATED FOR BOREHOLE GAUGE CHANGES UP TO APPROXIMATELY 2 INCHES AND CORRECTED FOR TOOL WEAR USING POST- JOB SHOP CALIBRATIONS. NEUTRON ASSUMES FWS = 18,000 ppm C1 & SANDSTONE MATRIX. DENSITY PROCESSING ASSUMES A 2.65 G/C3 MATRIX & FLUID DENSITY = 1.0 G/C3. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT ROP MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD FXN MWD CAL MWD DRHO MWD NPSC MWD GRC MWD RHOB MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 APR ENTRY BLOCKS ,~%i,t{ska Oil & C~as Cons,, Commission ENTRY DESCRIPTION Anchora~ 255 LOG DIRECTION, DOWN TE~INATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 ROP NF0~ NFl NN0 NN1 FXN CAL DRHO NPSC GRC RHOB MWD ' MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD FT/H CTS CTS CTS CTS HOUR INCH G/C3 P.U. API G/C3 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) DEPT ROP NFO NFl CAL DRHO NPSC GRC NN0 RHOB NN1 10450.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10600.000 13.873 789.949 795.906 8.490 .002 31.935 92.966 3087.386 2.523 3064.726 10700.000 91.769 1109.581 1114.291 8.590 .009 15.765 62.054 3844.317 2.201 3790.920 10800.000 46.959 949.854 940.155 8.640 .013 20.229 63.213 3643.026 2.394 3611.550 10900.000 12.903 906.953 847.247 8.660 -.003 28.112 129.416 3219.963 2.486 3173.527 11000.000 67.947 988.136 987.741 8.680 -.022 17.843 48.861 3750.617 2.235 3601.481 11100.000 95.082 869.296 870.882 8.610 .005 19.819 26.044 3695.485 2.265 3651.225 11200.000 65.455 884.696 895.350 8.590 -.007 18.902 26.716 3735.654 2.209 3745.084 11300.000 104.866 795.740 840.757 8.580 -.003 21.536 21.784 3611.078 2.152 3595.272 11400.000 27.131 1046.579 1004.642 8.600 .008 21.388 40.755 3614.063 2.132 3562.088 11500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 101 DATA RECORDS ** FROM 10450.00 TO 11500.00 FT ** FILE TRAILER** FILE NAME: L16.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/24 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** FXN -999.250 -999.250 1.603 1.270 1.952 .985 .289 1.413 1.092 .814 .317 -999.250 ** FILE HEADER ** FILE SEQUENCE # 2 FILE NAME: L16.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/24 MAX. RECORD LENGTH: 1024 FILE TYPE: E2 PREVIOUS FILE NAME: ** COMMENTS ** ***** REPEAT (MAD) DATA ****** 1. DATA ARE CORRECTED FOR GAUGE CHANGES AND TOOL WEAR. 2. NO TEMPERATURE OR PRESSURE CORRECTIONS HAVE BEEN APPLIED TO EITHER THE MWD OR REPEAT DATA SETS. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT RATE REPEAT NF0 REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT FXN REPEAT CAL REPEAT DRHO REPEAT NPSC REPEAT GRC REPEAT RHOB REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 FT/H 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 HOUR 0 0 0 0 2 4 0 1 68 INCH 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 API 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY · 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 2 4 0 1 68 RATE REPEAT FT/H 0 0 0 0 2 4 0 1 68 NFO · NFl~ NN0 NN1 FXN CAL DRHO NPSC GRC RHOB REPEAT RE PEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT CTS CTS CTS CTS HOUR INCH G/C3 P.U. API G/C3 0 0 0 0 0 0 0 0 0 0 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every DEPT RATE NF0 CAL DRHO NPSC 10450.000 -999.250 -999.250 -999.250 -999.250 -999.250 10500.000 -999.250 -999.250 503.000 -999.250 72.653 10600.000 8.690 162.198 887.000 -.007 28.064 10700.000 8.730 153.101 1075.000 .012 16.719 10800.000 8.580 163.636 915.144 .005 23.367 10900.000 8.890 174.777 831.000 -.015 33.589 11000.000 8.840 170.028 935.000 -.004 18.660 11100.000 8.710 143.156 887.000 .009 21.248 11200.000 8.770 157.910 860.850 -.005 17.159 11300.000 8.750 143.115 847.000 -.013 19.846 11400.000 8.840 159.337 850.618 .017 24.423 11500.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** 101 DATA RECORDS ** ** FILE TRAILER** FILE NAME: L16.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/24 MAX. RECORD LENGTH: FILE TYPE: E2 NEXT FILE NAME: 1024 100 FT) ** NFl NN0 GRC RHOB -999.250 -999.250 -999.250 -999.250 535.000 2504.000 81.120 -999.250 823.000 3288.000 90.281 2.491 1043.000 3736.000 48.370 2.278 870.858 3623.147 57.839 2.256 799.000 3096.000 81.149 2.407 919.000 3608.000 46.172 2.203 863.000 3592.000 26.228 2.447 916.250 3787.100 24.705 2.247 831.000 3624.000 21.003 2.137 845.539 3586.158 42.033 2.108 -999.250 -999.250 -999.250 -999.250 FROM 10450.00 TO NN1 -999.250 2344.000 3160.000 3672.000 3667.433 3112.000 3576.000 3544.000 3652.900 3688.000 3440.763 -999.250 11500.00 FT FXN -999.250 -999.250 31.060 27.107 24.969 20.066 18.274 17.536 15.500 13.649 12.004 -999.250 ********** END OF FILE (EOF # 3) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/04/24 ORIGIN OF DATA: L-16 TAPE NAME: ENDICOTT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/04/24 ORIGIN OF DATA: RLL REEL NAME: BPX CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT * ALASKA COMPUTING CENTER * * * ****************************** * ............................ * * ....... SCHLUMBERGER ....... * ............................ * ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : 2-18/L-16 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292203200 REFERENCE NO : 98172 !, i C OFIL ED Date .... lo/a !._c,o _ LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 7 ORIGIN : FLIC REEL NAME : 98172 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, 2-18/L-16, ENDICOTT, 50-029-22032-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 7 ORIGIN : FLIC TAPE NAME : 98172 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, 2-18/L-16, ENDICOTT, 50-029-22032-00 TAPE HEADER Endicott CASED HOLE WIRELINE LOGS WELL NAME: 2-18/L-16 API NUMBER: 500292203200 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 6-APR-98 JOB NUMBER: 98172 LOGGING ENGINEER: E. Bartz OPERATOR WITNESS: A. Coleman SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: 1902 FSL: FEL: 2213 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 55.10 DERRICK FLOOR: GROUND LEVEL: 16.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7.000 11462.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 11110.0 11103.0 11095.5 11094.5 11077.5 11076.5 11075.5 11073.0 11072.5 11068.5 11068.0 11065.5 11057.5 11056.5 11055.5 11048.5 11042.0 11040.0 11038.5 11038.0 11029.5 11026.5 11025.0 11020.0 11018.0 11016.5 11015.0 11012.5 11011.5 11009.0 11003.0 11000.0 10998.0 10997.0 10996.0 10995.5 10989.5 10986.0 10984.0 10983.5 10980.5 10971.5 10964.5 10964.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.5 88886.0 11108.0 11102.5 11096.5 11095.5 11077.0 11075.0 11074.5 11072.0 11071.5 11068.0 11068.0 11064.5 11064.5 11056.0 11056.0 11054.0 11048.5 11041.5 11041.0 11037.5 11037.5 11030.0 11026.5 11024.0 11019.5 11017.0 11016.5 11014.0 11012.0 11012.0 11009.5 11003.5 10999.5 11000.0 10997.5 10997.5 10995.0 10995.0 10989.5 10987.0 10982.5 10983.0 10980.0 10980.0 10971.5 10965.0 10964.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10962.0 10955.0 10949.5 10945.0 10944.0 10942.0 10938.5 10937.5 10936.5 10930.5 10928.5 10927.0 10923.0 10920.0 10918.0 10917.5 10914.0 10907.5 10905.0 10904.5 10899.0 10896.5 10896.0 10887.0 10885.0 10884.5 10881.0 10878.5 10876.0 10873.0 10869.5 10867 5 10865 5 10862 0 10859 5 10859 0 10856 5 10855.5 10852.5 10848.5 10847.5 10844.5 10841.0 10835.5 10832.5 10825.5 10823.0 10816.5 10806.5 10805.0 10802.5 10801.5 10798.5 10798.0 10794.0 10793.5 10961.5 10954.5 10946.5 10942.0 10938.5 10937.0 10930.5 10926.5 10920.5 10918.0 10914.0 10905.0 10896.0 10884.5 10879.5 10873.5 10868.0 10865.5 10859.0 10855.0 10852.0 10845.5 10843.0 10840.5 10830.5 10822.0 10816.0 10803.5 10800.5 10797.5 10792.0 10954.5 10949.0 10944.0 10938.5 10926.5 10923.5 10918. 0 10914. 0 10908. 0 10904.5 10900. 0 10896. 0 10887.0 10884.5 10879.0 10873.5 10867.5 10862. 0 10859.0 10855.0 10845.5 10833.5 10822.0 10803.0 10800.0 10797.5 10792.0 7-APR-1998 09:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 10791.0 10790.5 10787.0 10783.5 10779.5 10777.5 10775.5 10770.5 10767.5 10765.0 10763.0 10759.5 10759.0 10756.0 10751.5 10749.0 10748.5 10745.0 10742.5 10738.0 10736.5 10734.0 10733.5 10728 5 10728 0 10721 5 10718 0 10717 5 10715 5 10713 0 10709 5 10707.5 10706.5 10705.0 10703.5 10702.5 10701.0 10692.5 10685.5 10684.5 10675.5 10673.5 10672.0 10668.0 100.0 $ REMARKS: 10791.0 10785.0 10782.5 10779.5 10775.0 10771.0 10768.0 10765.5 10764.0 10760.5 10756.5 10751.5 10749.5 10745.5 10743.5 10738.5 10736.5 10734.0 10728.5 10721.5 10718.0 10715.5 10709.5 10708.0 10706.0 10705.0 10703.0 10700.5 10692.0 10684.5 10673.0 10670.5 10665.5 97.5 10790.5 10783.0 10779.0 10768.0 10760.5 10756.0 10750.0 10743.5 10734.5 10729.0 10717.5 10715.5 10713.5 10709.5 10703.0 10692.5 10684.5 10673.0 99.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON BP'S 2-18/L-16 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS O~ RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAb94A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MA~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~E~RY LDWG TOOL CODE START DEPTH STOP DEPTH CRCH 11105.5 10657.5 TDTP 11114.0 10659.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 IArArDTDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11114. 000 SIGM. TDTP 38. 772 TPHI. TDTP 47. 704 SBHF. TDTP SBHN. TDTP 46. 739 SIGC. TDTP 1 . 355 SIBH. TDTP 52.217 TRAT. TDTP SDSI. TDTP 1 . 746 BACK. TDTP 23. 022 FBAC. TDTP 11 . 843 TCAN. TDTP TCAF. TDTP 1907. 460 TCND. TDTP 2539. 315 TCFD. TDTP 658. 067 TSCN. TDTP TSCF. TDTP 91. 467 INND. TDTP 281. 662 INFD. TDTP 53. 895 GRCH. TDTP TENS.TDTP 1652.000 CCL. TDTP 0.000 40.873 1.682 6668.751 310.910 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: DEPT. 10657.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 29.216 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE igIIMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11105.0 10632.5 TDTP 11112.5 10633.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: BASELINE DEPTH 88888.0 11112 0 11109 5 11105 0 11099 5 11096 5 11092 0 11090 5 11085 0 11081 5 11079.0 11077.5 11076.5 11070.0 11069.5 11066.5 11063.5 11063.0 11060.5 11056.0 11053.0 11049.5 11042.0 11040.0 11039.5 11037.0 11033.5 11030.5 11028.5 11027.0 11026.5 11024.0 11018.5 11013.5 11012.5 11009.0 11006.5 11003.0 11001.0 10999.0 10997.0 10995.0 10992.5 10985.5 10985.0 10981.5 10979.0 10978.5 10972.5 10970.5 10966.0 10963.0 10956.5 GRCH ....... 88887.0 11098.5 11097.0 11091.0 11089.0 11075.0 11068.0 11064.5 11061.5 11057.5 11050.0 11038.0 11035.0 11031.5 11026.5 11024.0 11016.5 11012.0 11006.0 11001.5 10999.5 10997.0 10995.0 10993.0 10991.0 10982.5 10979.5 10977.0 10971.5 10961.5 10955.0 TDTP 88884.5 11108.5 11106.0 11102.0 11095.5 11082.5 11080.5 11077.5 11074.5 11068.0 11061.5 11054.5 11048.5 11041.5 11038.0 11030.0 11025.5 11022.5 11011.5 11005.0 10999.5 10995.0 10984.0 10977.5 10967.5 10965.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 10953.5 10951.0 10948.5 10946.5 10946.0 10945.0 10942.5 10939.5 10939.0 10938.0 10934.0 10927.5 10921.5 10919.0 10915.5 10911.5 10909.5 10906.0 10901 5 10898 0 10897 5 10894 0 10886 5 10886 0 10884 5 10884.0 10882.5 1O880.0 10877.5 10874.5 10873.5 10870.0 10868.0 10861.0 10860.0 10857.5 10857.0 10855.5 10854.0 10850.0 10849.5 10845.5 10842.0 10839.0 10836.5 10834 0 10830 5 10829 0 10826 5 10825 0 10822 5 10821.0 10815.0 10810.5 10807.5 10952.0 10951.0 10949.0 10947.5 10946.0 10941.5 10938.5 10937.0 10930.5 10920.5 10918.0 10914.0 10909.5 10905.0 10900.0 10896.0 10891.0 10884.5 10882.0 10879.5 10873.5 10868.0 10858.5 10855.0 10853.0 10851.5 10845.5 10843.0 10840.5 10830.5 10827.0 10822.0 10818.5 10808.5 10949.0 10943.5 10938.5 10927.0 10918.5 10914.0 10908.5 10904.5 10896.0 10885.0 10882.5 10878.5 10873.5 10870.5 10867.5 10859.5 10854.5 10845.5 10842.0 10835.5 10833.5 10825.0 10821.5 10817.0 10809.5 10802.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 10 10803.0 10800.0 10799.0 10795.0 10792.0 10791.5 10786.0 10785.0 10781.0 10776.5 10773.5 10769.5 10768.0 10767.0 10764.5 10764.0 10760.5 10757.5 10754.0 10751.0 10750.5 10747.0 10744.0 10740.5 10740.0 10735.0 10732.5 10730.5 10729.0 10725.0 10722.0 10720.0 10717.0 10715 0 10711 5 10709 5 10708 0 10704 5 10704 0 10702.5 10700.0 10698.0 10697.0 10694.0 10692.0 10687.0 10685.5 10678.5 10677.5 10676.0 10671.0 10667.0 10663.5 100.0 $ 10800.0 10797.5 10792.0 10791.0 10782.5 10779.0 10775.0 10772.5 10768.5 10765.5 10764.0 10760.5 10756.5 10750.0 10745.0 10743.5 10739.0 10734.0 10731.5 10729.5 10721.5 10715.5 10713.0 10708.0 10706.0 10703.0 10701.0 10697.5 10694.5 10692.0 10689.0 10684.5 10673.0 10665.5 98.5 10800.0 10797.5 10792.0 10790.0 10783.0 10777.0 10768.0 10763.5 10760.5 10754.0 10750.0 10743.5 10740.0 10734.0 10729.0 10724.0 10720.5 10717.5 10715.5 10710.0 10708.0 10703.0 10696.0 10684.5 10676.0 10673.0 10668.0 10662.5 99.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 11 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS H2 AND GRCH BASE PASS Hi, ALSO SIGMA BASE PASS H2 AND SIGMA BASE PASS HI, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER H LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 12 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCND TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11112.500 SIGM. TDTP 31. 156 TPHI. TDTP 46. 681 SBHF. TDTP SBHN. TDTP 51. 010 SIGC. TDTP 3. 944 SIBH. TDTP 61. 906 TRAT. TDTP SDSI. TDTP 1. 485 BACK. TDTP 56. 513 FBAC. TDTP 16. 530 TCAN. TDTP TCAF. TDTP 3572. 642 TCND. TDTP 4701.177 TCFD. TDTP 1242. 354 TSCN. TDTP TSCF. TDTP 208. 114 INND. TDTP 352.202 INFD. TDTP 67. 070 GRCH. TDTP TENS. TDTP 1599. 000 CCL. TDTP -0. 006 DEPT. 10645. 000 SIGM. TDTP 15. 967 TPHI. TDTP 15. 098 SBHF. TDTP SBHN. TDTP 36. 893 SIGC. TDTP 2. 045 SIBH. TDTP 36. 893 TRAT. TDTP SDSI. TDTP O. 651 BACK. TDTP 67. 368 FBAC. TDTP 21. 358 TCAN. TDTP TCAF. TDTP 12723 . 467 TCND. TDTP 7998. 730 TCFD. TDTP 3390. 360 TSCN. TDTP TSCF. TDTP 1327.263 INND. TDTP 472. 503 INFD. TDTP 141 . 809 GRCH. TDTP TENS. TDTP 1550. 000 CCL. TDTP O. 000 41.194 1.700 11769.357 626.702 -999.250 24. 892 1 . 426 24462. 121 2551. 794 28. 046 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~gZ~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11106.0 10637.5 TDTP 11115.0 10638.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11113.5 11110.5 11108.0 11102.5 11098.5 11098.0 11090.5 11083.5 11082.5 11078.0 11076.0 11075.5 11073.5 11072.0 11068.5 11068.0 11065.0 11064.5 11062.5 11055.0 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88888.0 88887.0 11098.5 11091.0 11083.5 11075.0 11071.5 11068.0 11064.0 11061.5 11054.0 11112.5 11108.0 11106.0 11101.5 11095.5 11083.0 11077.5 11074.5 11072.0 11068.0 11064.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 14 11054.5 11049.5 11049.0 11042.0 11040.5 11039.0 11038.5 11035.5 11034.0 11033.0 11030.5 11030.0 11027.0 11025.5 11025.0 11022.5 11017.0 11011.5 11006.5 11002.5 11000.0 10999.5 10997.5 10995.5 10994.0 10992.5 10989.0 10985.5 10984.0 10980.5 10979.5 10977.0 10975.5 10971.5 10970.5 10967.5 10966.0 10962.0 10956.0 10955.0 10952.0 10950.0 10949.5 10947.0 10945.5 10941.5 10940.0 10938.5 10929.0 10927.5 10926.5 10923.5 10920.0 10919.5 10918.0 11048.0 11041.5 11038.0 11035.0 11031.0 11030.0 11026.5 11024.5 11054.0 11049.0 11041.5 11038.0 11034.0 11030.5 11024.5 11022.5 11017.0 11017.0 11012.0 11011.5 11005.0 11002.0 11000.0 11000.0 10997 5 10997.5 10995 10993 10991 10989 10984 5 10983 0 10979 5 10976.5 10975.0 10971.5 10967.5 10961.5 10955.0 10952.0 10951.0 10947.5 10942.0 10938.5 10927.0 10925.0 10923.0 10920.5 0 10995.0 0 5 5 10979.0 10970.5 10965.5 10955.0 10949.0 10947. 0 10941.0 10927. 0 10920.5 10918. 0 10918. 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 15 10914.0 10908.0 10907.5 10905.5 10905.0 10896.5 10896.0 10892.0 10889.5 10885.0 10884.5 10881.0 10879.0 10876.5 10873.5 10872.5 10869.5 10866.5 10863.5 10860.0 10859.0 10856.0 10853.0 10848.5 10848.0 10845.0 10844.5 10842.5 10838.5 10838.0 10834.5 10832.5 10829.5 10828.0 10824.5 10823.0 10817.0 10812.5 10809.0 10805 5 10802 0 10801 5 10799 5 10793 5 10791 0 10784.0 10778.0 10776.0 10770.5 10769.0 10768.0 10765.5 10763.5 10760.0 10759.5 10914.0 10908.0 10905.0 10896.5 10891.0 10884.5 10879.5 10875.5 10873.5 10869.0 10863.0 10858.5 10855.0 10851.5 10845.5 10843.0 10840.5 10836.5 10830.5 10827.0 10822.5 10816.0 10808.0 10803.5 10800.0 10797.5 10792.0 10791.0 10783.0 10775.5 10770.5 10768.5 10765.5 10760.5 10914.0 10908.5 10904.5 10896.0 10889.0 10884.5 10878.5 10873.5 10871. 0 10867.0 10859.0 10854.5 10845.5 10842.0 10836.0 10833.5 10825.0 10821.5 10809.5 10799.5 10792.0 10783.0 10778.5 10768.5 10764.0 10761.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 16 10756.0 10752 0 10745 5 10743 0 10737 5 10737 0 10734 0 10732.0 10729.0 10728.5 10721.0 10719.0 10718.5 10716.0 10714.0 10713.5 10708.5 10707.0 10703.5 10696.5 10693.5 10693.0 10688.5 10685.5 10685.0 10679.5 10677.5 10674.5 10668.5 100.0 $ 10756.0 10750.5 10743.5 10736.5 10734.0 10731.5 10729.0 10721.0 10718.0 10715.5 10713.0 10708.0 10706.0 10702.5 10694.5 10692.0 10687.0 10684.5 10677.5 10673.0 10666.0 97.5 10746.0 10743.5 10737.5 10734.0 10729.0 10720.5 10717.5 10715.5 10713.5 10708.0 10703.0 10696.0 10692.5 10684.5 10676.0 10673.0 98.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 17 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11115. 000 SIGM. TDTP 39.220 TPHI. TDTP 59. 312 SBHF. TDTP SBHN. TDTP 50. 753 SIGC. TDTP O. 000 SIBH. TDTP 61. 325 TRAT. TDTP SDSI. TDTP 2. 001 BACK. TDTP 69. 383 FBAC. TDTP 23 . 747 TCAN. TDTP TCAF. TDTP 3259. 607 TCND. TDTP 4550. 370 TCFD. TDTP 1161 . 367 TSCN. TDTP TSCF. TDTP 174. 647 INND. TDTP 360. 623 INFD. TDTP 77. 665 GRCH. TDTP TENS. TDTP 1583. 000 CCL. TDTP O. 000 46.166 1.787 11218.088 603.202 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 18 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~F~%RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11105.5 10834.5 TDTP 11115.0 10833.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88887.0 11114.0 11113.0 11110.0 11108.0 11102.5 11102.0 11099.0 11098.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 19 11094.5 11095.5 11090.5 11091.0 11080.0 11080.5 11078.0 11077.5 11076.0 11075.0 11075.5 11074.5 11073.0 11072.0 11072.0 11071.0 11068.5 11068.0 11068.0 11068.0 11065.5 11064.0 11065.0 11064.5 11062.5 11061.0 11061.5 11059.0 11057.0 11055.0 11054.0 11054.5 11054.5 11048.5 11049.0 11047.5 11048.0 11038.5 11038.0 11038.0 11038.0 11036.0 11034.5 11032.5 11031.5 11032.0 11032.0 11030.0 11030.0 11025.0 11024.0 11023.0 11023.0 11019.0 11017.0 11013.5 11012.0 11011.5 11012.0 11005.5 11004.5 11000.5 11000.0 10999.5 11000.0 10997.5 10997.5 10995.5 10995.0 10995.0 10993.5 10993.0 10987.5 10987.0 10986.0 10984.5 10980.5 10979.5 10980.0 10977.5 10976.5 10973.0 10972.5 10971.5 10971.0 10968.0 10968.0 10965.0 10964.5 10964.5 10964.0 10962.0 10961.5 10956.0 10955.0 10952.5 10951.0 10950.5 10951.0 10949.5 10949.0 10948.0 10946.5 10943.0 10941.5 10941.0 10941.5 10932.5 10930.5 10931.0 10928.5 10927.0 10921.0 10920.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 2O 10918.5 10918.0 10918.0 10915.0 10914.0 10914.0 10909.0 10908.0 10908.5 10906.0 10905.0 10905.5 10904.5 10901.5 10900.0 10900.0 10900.0 10897.5 10896.0 10897.0 10896.0 10893.5 10892.5 10891.0 10891.0 10890.0 10888.5 10886.0 10885.0 10885.5 10884.5 10883.5 10882.5 10882.0 10879.5 10879.5 10879.0 10877.0 10873.5 10873.0 10870.5 10868.5 10865.5 10867.0 10867.0 10860.0 10858.5 10857.5 10855.0 10856.5 10854.5 10855.5 10853.5 10853.0 10852.0 10851.5 10850.0 10849.0 10845.5 10848.0 10845.5 10844.5 10842.0 10842.0 10840.5 10840.5 10839.0 10839.5 10836.5 100.0 98.5 97.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 22 ** DATA ** DEPT. 11115, 000 SIGM. TDTP SBHN. TDTP 49,605 SIGC. TDTP SDSI. TDTP 1,577 BACK. TDTP TCAF. TDTP 3508 992 TCND. TDTP TSCF. TDTP 193,761 INND. TDTP TENS. TDTP 836,000 CCL. TDTP DEPT. 10833. 000 SIGM. TDTP SBHN. TDTP 39,818 SIGC. TDTP SDSI. TDTP O, 925 BACK. TDTP TCAF. TDTP 6978,589 TCND. TDTP TSCF. TDTP 721,380 INND. TDTP TENS. TDTP 781,000 CCL . TDTP 35. 907 TPHI. TDTP 54. 288 SBHF. TDTP 43. 812 2. 205 SIBH. TDTP 58. 720 TRAT. TDTP 1. 773 23. 753 FBAC. TDTP 11. 830 TCAN. TDTP 12268. 465 5111. 017 TCFD. TDTP 1311. 600 TSCN. TDTP 642. 319 411. 354 INFD. TDTP 83. 143 GRCH. TDTP -999. 250 0.000 21.521 TPHI.TDTP 22.561 SBHF. TDTP 31.263 3.444 SIBH. TDTP 39.818 TRAT. TDTP 1.554 46. 720 FBAC. TDTP 17. 385 TCAN. TDTP 16344. 553 7287. 050 TCFD. TDTP 2565. 356 TSCN. TDTP 1684. 968 441. 470 INFD. TDTP 109. 013 GRCH. TDTP -999. 250 O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 11106.5 TDTP 11115.0 STOP DEPTH 10827.5 10826.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE 23 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 11109 5 11107 0 11101 5 11098 5 11097 0 11094.0 11091.5 11090.0 11086.0 11085.5 11079.5 11079.0 11077.5 11075.0 11074.5 11072.5 11071.5 11067.5 11067.0 11064.0 11062.0 11061.5 11058.0 11054.5 11053.5 11052 5 11045 5 11043 5 11040 5 11038 0 11037 5 11034.5 11034.0 11031.5 11029.0 11024.5 11021.0 11012.0 11010.5 11004.5 10999.5 10997.5 10997.0 10995.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88888.5 88887.0 11099.0 11095.5 11091.0 11086.5 11079.0 11075.0 11071.0 11068.0 11064.0 11061.0 11057.5 11054.0 11052.0 11047.5 11045.0 11041.0 11038.0 11034.5 11031.0 11024.0 11012.5 10999.5 10997.5 11108.5 11106.5 11101.5 11095.0 11088.5 11083.5 11080.5 11077.5 11074.5 11072.0 11068.0 11064.0 11061.5 11054.5 11041.5 11037.5 11034.0 11029.5 11021.0 11011.5 11004.0 11000.0 10998.0 10995.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 24 10995.0 10992.0 10986.0 10984.5 10980.0 10979.5 10975.0 10972.5 10971.0 10969.0 10967.0 10965.5 10964.5 10961.5 10960.0 10956.5 10956.0 10953.0 10952.0 10950.0 10949.5 10947 5 10945 0 10942 5 10940 5 10938 5 10938 0 10937.0 10932.5 10931.0 10929.5 10927.0 10926.5 10923.5 10922.0 10920.5 10918.0 10914.5 10911.5 10908.5 10908.0 10905.5 10902.5 10900.5 10899.5 10897.5 10897.0 10895.5 10892.5 10889.5 10885.5 10885.0 10881.5 10879.0 10876.5 10995.0 10984.5 10979.5 10976.5 10972.5 10971.5 10970.0 10967.0 10964.0 10961.5 10956.0 10954.5 10951.0 10947.5 10942.0 10937.5 10935.5 10930.5 10929.0 10926.0 10923.0 10921.5 10920.5 10918.0 10914.0 10908.0 10905.0 10902.5 10900.0 10896.0 10894.5 10890.5 10884.5 10879.5 10877.0 10992.0 10986.0 10979.0 10971.0 10965.5 10960.0 10955.0 10952.0 10949.5 10943.5 10940.5 10938.5 10930.5 10927.0 10920.5 10918.0 10914.5 10911.0 10908.5 10905.0 10900.0 10896.0 10888.5 10884.5 10879.0 10873.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 25 10875.5 10873.5 10871.0 10869.5 10870.0 10867.5 10867.0 10865.5 10866.5 10867.0 10864.0 10861.5 10863.5 10862.5 10860.5 10858.5 10859.5 10856.5 10855.0 10856.0 10854.5 10853.0 10852.0 10848.5 10845.5 10845.5 10845.0 10844.0 10842.0 10841.5 10840.5 10838.5 10837.5 10836.0 10836.5 10836.0 10835.5 10833.5 100.0 99.5 98.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 26 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11115. 000 SIGM. TDTP 34. 690 TPHI. TDTP 50. 371 SBHF. TDTP SBHN. TDTP 47. 857 SIGC. TDTP 2. 822 SIBH. TDTP 54. 754 TRAT. TDTP SDSI. TDTP 1 . 614 BACK. TDTP 38. 693 FBAC. TDTP 14 . 3 67 TCAN. TDTP TCAF. TDTP 3302.147 TCND. TDTP 4708. 847 TCFD. TDTP 1203 . 071 TSCN. TDTP TSCF. TDTP 186. 551 INND. TDTP 368. 596 INFD. TDTP 75. 827 GRCH. TDTP TENS. TDTP 812. 000 CCL. TDTP O. 000 DEPT. 10826. 000 SIGM. TDTP 33 . 899 TPHI. TDTP 43 . 299 SBHF. TDTP SBHN. TDTP 37. 787 SIGC. TDTP O. 000 SIBH. TDTP 37. 787 TRAT. TDTP SDSI. TDTP 1.296 BACK. TDTP 55. 934 FBAC. TDTP 21 . 408 TCAN. TDTP TCAF. TDTP 5730. 377 TCND. TDTP 5980. 848 TCFD. TDTP 1762. 408 TSCN. TDTP TSCF. TDTP 351. 498 INND. TDTP 400. 811 INFD. TDTP 95. 572 GRCH. TDTP TENS. TDTP 753. 000 CCL. TDTP O. 000 49.563 1.759 11533.564 601.070 -999.250 33.460 1.814 18114.082 1095.182 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUA~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11106.0 10829.0 TDTP 11115.0 10828.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11109.5 11102.5 11102.0 11097.5 11090.0 11087.5 11079.5 11075.5 11075.0 11072.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88888.0 88887.0 11108.5 11102.5 11102.0 11095.5 11091.0 11088.5 11079.0 11080.5 11075.0 11074.5 11071.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 28 11072.0 11072.5 11068.0 11068.0 11067.5 11068.0 11064.5 11064.0 11061.5 11061.0 11057.0 11056.0 11054.0 11055.0 11051.5 11052.0 11049.0 11048.5 11046.0 11048.0 11041.5 11041.5 11041.0 11038.0 11038.0 11037.5 11038.0 11032.0 11031.5 11030.0 11030.0 11025.5 11025.5 11024.5 11025.5 11019.0 11019.0 11016.5 11017.5 11011.5 11012.0 11011.5 11005.0 11005.0 10999.5 10999.5 10999.5 10997.0 10997.0 10997.5 10995.5 10995.0 10995.0 10995.0 10992.0 10991.5 10980.0 10979.5 10979.0 10978.5 10972.5 10972.5 10967.0 10967.0 10964.5 10964.0 10965.0 10962.0 10961.5 10959.5 10960.0 10955.5 10956.0 10955.0 10952.0 10952.0 10950.0 10951.0 10948.0 10947.0 10947.5 10948.0 10945.0 10943.5 10942.5 10941.5 10939.5 10939.0 10938.5 10937.5 10937.5 10935.5 10932.5 10930.5 10929.5 10929.0 10928.0 10927.0 10926.5 10926.0 10924.0 10923.0 10920.5 10920.5 10918.5 10918.5 10918.0 10918.5 10914.5 10914.0 10914.0 10908.5 10908.0 10908.5 10905.5 10905.0 10905.0 10904.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 29 10900 0 10897 0 10894 5 10890 5 10889 0 10885 5 10885 0 10883 0 10881 5 10879 5 10879.0 10877.5 10876.0 10873.0 10872.5 10867.5 10867.0 10864.0 10860.0 10859.5 10856.5 10856.0 10853.5 10849.0 10848.5 10845.5 10844.5 10842.0 10839.0 10837.0 10835.0 100.0 $ 10896.0 10893.0 10890.5 10884.5 10879.5 10877.5 10873.5 10871.0 10865.5 10861.5 10858.0 10855.0 10852.0 10845.5 10843.5 10840.5 10836.0 99.0 10899.5 10896.0 10889.0 10884.5 10882.5 10879.0 10873.0 10870.5 10867.5 10859.0 10854.5 10845.5 10842.0 10836.0 10833.5 98.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 3O TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1022718 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11115. 000 SIGM. TDTP 35. 628 TPHI. TDTP 48. 803 SBHF. TDTP SBHN. TDTP 46. 481 SIGC. TDTP 2. 892 SIBH. TDTP 51 . 632 TRAT. TDTP SDSI. TDTP 2. 682 BACK. TDTP 45. 537 FBAC. TDTP 17. 058 TCAN. TDTP TCAF. TDTP 1762.563 TCND.TDTP 2494.630 TCFD.TDTP 604.174 TSCN. TDTP TSCF. TDTP 90.171 INND. TDTP 268. 421 INFD. TDTP 51. 946 GRCH. TDTP 37. 335 1. 749 6397.104 303. 938 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 31 TENS. TDTP 688. 000 CCL. TDTP O. 000 DEPT. 10828. 500 SIGM. TDTP 31 . 038 TPHI. TDTP 40. 792 SBHF. TDTP 29. 926 SBHN. TDTP 37. 753 SIGC. TDTP 1. 002 SIBH. TDTP 37. 753 TRAT. TDTP 1. 802 SDSI. TDTP 1. 763 BACK. TDTP 46. 267 FBAC. TDTP 15. 273 TCAN. TDTP 10389. 482 TCAF. TDTP 3339. 852 TCND. TDTP 3348. 488 TCFD. TDTP 1033. 468 TSCN. TDTP 668.259 TSCF. TDTP 220.916 IArND. TDTP 282.130 INFD. TDTP 65.311 GRCH. TDTP -999.250 TENS. TDTP 767. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 32 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 INND PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1022718 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 33 ** DATA ** DEPT. 11114.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 23. 022 FBAC. TDTP 11. 843 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10657.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 29.216 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NOWBER: 1 DEPTH INCREMENT: 0.5000 FILE SOW~VlARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11166.5 10646.0 LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 34 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) .. 23-FEB-98 8C0-069 1344 23-FEB~98 11377.0 11135.0 10634.0 11116.0 900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~94A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS -A TDTP BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11462.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids / Fi 9.00 20.0 211.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98:12339 GFR/WC 92~/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 35 Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 88 66 1 66 73 65 68 0.5 65 FT 66 11 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNPS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PSi CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 36 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TCAF PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 1022718 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11125 SBHN. PS1 48 SDSI.PS1 1 TCAF. PS1 1786 TSCF. PS1 84 GR.PS1 18 DEPT. 10646. SBHN. PS1 33. SDSI.PS1 1. TCAF. PS1 6635. TSCF. PS1 410. GR.PS1 22. 000 SIGM. PS1 37.026 TPHI.PS1 51.039 SBHF. PS1 452 $IGC. PS1 2.526 SIBH. PS1 56.105 TRAT. PS1 795 BACK. PSi 25.136 FBAC. PS1 10.117 TCAN. PS1 225 TCND.PS1 2449.024 TCFD. PS1 609.802 TSCN. PS1 244 INND. PS1 271.217 INFD. PS1 49.617 TENS.PSi 641 CCL.PS1 0.000 000 SIGM. PS1 32.679 TPHI.PS1 40.074 SBHF. PS1 512 SIGC. PS1 0.231 SIBH. PS1 33.512 TRAT. PS1 357 BACK. PSi 54.852 FBAC. PS1 19.120 TCAN. PS1 474 TCND.PS1 6099.323 TCFD.PS1 1916.898 TSCN. PS1 864 INND. PS1 479.949 INFD. PS1 129.786 TENS.PSI 155 CCL.PS1 -999.250 53.996 1.719 6549.399 292.230 1636.000 30.495 1.768 20219.508 1219.167 1546.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 37 **** FILE HEADER **** FILE NAME .. EDIT . 009 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11164.0 10622.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERIVAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 23-FEB-98 8C0-069 1344 23-FEB-98 11377.0 11135.0 10634.0 11116.0 900.0 TOOL NUMBER CGRS-A TDTP 8.500 11462.0 Produced Fluids / Fi 9.00 20.0 211.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 38 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98: 12339 GFR/WC 92%/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 39 TYPE REPR CODE VALUE 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 1022718 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11125.000 SIGM. PS2 35.851 TPHI.PS2 54.045 SBHF. PS2 SBHN. PS2 51.044 SIGC. PS2 2.408 SIBH. PS2 61.985 TRAT. PS2 SDSI.PS2 1.712 BACK. PS2 57.269 FBAC. PS2 15.876 TCAN. PS2 TCAF. PS2 2965.758 TCND.PS2 4251.573 TCFD. PS2 1071.676 TSCN. PS2 TSCF. PS2 165.412 INND.PS2 338.835 INFD.PS2 65.705 TENS.PS2 GR.PS2 21.024 CCL.PS2 0.000 DEPT. 10645.000 SIGM. PS2 14.845 TPHI.PS2 14.118 SBHF. PS2 SBHN. PS2 35.307 SIGC. PS2 2.033 SIBH. PS2 35.307 TRAT. PS2 SDSI.PS2 0.601 BACK. PS2 67.418 FBAC. PS2 20.981 TCAN. PS2 TCAF. PS2 13992.736 TCND.PS2 8210.656 TCFD.PS2 3592.294 TSCN. PS2 46.342 1.741 10342.697 533.273 1626.000 29.743 1.413 26313.789 2745.888 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 4O TSCF. PS2 1460 . 165 INND. PS2 GR. PS2 27.195 CCL. PS2 466.323 INFD.PS2 0.000 139.843 TENS.PS2 1557. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUM~LARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11151 . 0 10626.5 TDTP $ LOG HEADER DATA DATE LOGGED: 23-FEB-98 SOFTWARE VERSION: 8 CO - 069 TIME LOGGER ON BOTTOM: 1344 23-FEB-98 TD DRILLER (FT) : 11377.0 TD LOGGER (FT) : 11135.0 TOP LOG INTERVAL (FT) : 10634.0 BOTTOM LOG INTERVAL (FT) : 11116.0 LOGGING SPEED (FPHR): 900.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APRil998 09:04 PAGE: 41 VENDOR TOOL CODE TOOL TYPE GR G~ RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A TDTP BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11462.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids / Fi 9.00 20.0 211.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98: 12339 GFR/WC 92%/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 42 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS3 CPS 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 1022718 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 43 ** DATA ** DEPT. 11125.000 SIGM. PS3 SBHN. PS3 48.079 SIGC. PS3 SDSI.PS3 2.215 BACK. PS3 TCAF. PS3 2837.702 TCND. PS3 TSCF.PS3 146.869 INND.PS3 GR.PS3 135.606 CCL. PS3 40.489 TPHI.PS3 0.000 SIBH. PS3 73.565 FBAC. PS3 4353.018 TCFD.PS3 342.285 INFD.PS3 0.000 60.499 SBHF. PS3 55.258 TRAT. PS3 24.804 TCAN. PS3 1074.938 TSCN. PS3 60.965 TENS.PS3 39. 931 1. 857 10465.201 542. 604 1611. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MA3~REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MA~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUFkrlARY VENDOR TOOL CODE START DEPTH TDTP 11156.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 10813.0 23-FEB-98 8C0-069 1344 23-FEB-98 11377.0 11135.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 44 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY 10634.0 11116.0 900.0 TOOL NUMBER CGRS-A TDTP BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11462.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids / Fi 9.00 20.0 211.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98:12339 GFR/WC 92%/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 45 the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #1. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM FP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI FP1 PU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF FP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNFP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC FP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH FP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FP1 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI FP1 CU 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 BACK FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TCANFP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TCND FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 46 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 INFD FP1 CPS 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 TENS FP1 LB 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 GR FP1 GAPI 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 CCL FP1 V 1022718 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11125.000 SIGM. FP1 38.758 TPHI.FPl 56.709 SBHF. FP1 SBHN. FP1 48.274 SIGC.FP1 1.220 SIBH.FP1 55.700 TRAT. FP1 SDSI.FP1 1.603 BACK. FP1 21.104 FBAC.FP1 11.083 TCAN. FP1 TCAF. FP1 3239.773 TCND.FP1 4917.313 TCFD.FP1 1224.729 TSCN. FP1 TSCF. FP1 176.280 IArND.FP1 390.458 INFD.FP1 78.396 TENS.FP1 GR.FP1 0.000 CCL.FP1 0.000 DEPT. 10813.000 SIGM. FP1 31.168 TPHI.FPl 33.002 SBHF. FP1 SBHN. FP1 39.078 SIGC. FP1 1.642 SIBH. FPl 39.078 TRAT. FP1 SDSI.FP1 1.138 BACK. FP1 45.462 FBAC. FPl 16.354 TCAN. FP1 TCAF.FP1 6488.647 TCND.FP1 6382.543 TCFD.FP1 1985.907 TSCN. FP1 TSCF. FP1 403.087 INND.FP1 429.485 INFD.FPl 99.208 TENS.FP1 GR.FP1 52.041 CCL.FP1 -999.250 40.751 1.803 11679.920 602.615 838.000 29.785 1.651 19045.203 1127.030 761.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE · 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 47 FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH TDTP 11158.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) '. TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10813.5 23-FEB-98 8C0-069 1344 23-FEB-98 11377.0 11135.0 10634.0 11116.0 900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAB~IA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS -A TDTP BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11462.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : CAS~OIL RATIO: CHOKE (DEC): Produced Fluids / Fi 9.OO 20.0 211.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNTRATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 48 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98:12339 GFR/WC 92~/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 49 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM FP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI FP2 PU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF FP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNFP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC FP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH FP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT FP2 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI FP2 CU 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 BACK FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TCANFP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TCND FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 INND FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 INFD FP2 CPS 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 TENS FP2 LB 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 GR FP2 GAPI 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 CCL FP2 V 1022718 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 11125 SBHN. FP2 56 SDSI.FP2 3 TCAF.FP2 1599 TSCF.FP2 87 GR.FP2 16 000 SIGM. FP2 35.940 TPHI.FP2 59.905 SBHF.FP2 165 SIGC. FP2 2.064 SIBH. FP2 73.602 TRAT. FP2 059 BACK.FP2 39.246 FBAC.FP2 14.292 TCAN. FP2 515 TCND.FP2 2346.879 TCFD.FP2 590.581 TSCN. FP2 853 INND.FP2 247.658 INFD.FP2 49.492 TENS.FP2 499 CCL.FP2 0.000 DEPT. 10813.500 SBHN. FP2 41.654 SDSI.FP2 1.241 TCAF. FP2 6271.847 TSCF.FP2 425.432 GR.FP2 55.407 SIGM. FP2 SIGC.FP2 BACK. FP2 TCND.FP2 INND.FP2 CCL.FP2 31 007 0 683 57 420 6361 287 410 278 -999 250 55.880 1.777 5801.569 295.266 822.000 TPHI.FP2 34.163 SBHF. FP2 34.962 SIBH. FP2 41.654 TRAT. FP2 1.668 FBAC. FP2 20.679 TCAN. FP2 17899.031 TCFD.FP2 2023.769 TSCN. FP2 1183.265 INFD.FP2 106.547 TENS.FP2 749.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 5O **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: O . 5000 FILE SOWMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11148.0 10815.5 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~VZA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 23-FEB-98 8C0-069 1344 23-FEB-98 11377.0 11135.0 10634.0 11116.0 900.0 TOOL NUMBER CGRS-A TDTP 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 51 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11462.0 Produced Fluids / Fi 9.00 20.0 211.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Log tied into SWS CBT (06-MAY-1990). Well stats as of 1-8-98: 12339 GFR/WC 92%/ 10907 GOR Three flowing passes made at 900 FPH WFL stations done while well was flowing w~ choke of 176 b Water velocity too fast to accurately above 10990' w/o ATC GR. Experienced minitron problems while obtaining WFL data. Well shut in & three passes made at 900 FPH. Experienced some minitron problems during first of the shut in passes, so TPHI is spiky. THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 52 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI FP3 PU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SBHN FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FP3 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI FP3 CU 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 BACK FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TCANFP~ CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TCAF FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TCND FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF FPS CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 INND FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 INFD FP3 CPS 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 TENS FP3 LB 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 GR FP3 GAPI 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 CCL FP3 V 1022718 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-APR-1998 09:04 PAGE: 53 ** DATA ** DEPT. SBHN. FP3 SDSI.FP3 TCAF. FP3 TSCF.FP3 GR.FP3 11125 000 52 600 2 738 1721 333 87 032 0 000 SIGM. FP3 SIGC.FP3 BACK. FP3 TCND.FP3 INND.FP3 CCL.FP3 DEPT. 10815.500 SIGM. FP3 SBHN. FP3 35.681 SIGC. FP3 SDSI.FP3 2.075 BACK.FP3 TCAF. FP3 3535.775 TCND.FP3 TSCF. FP3 217.500 INND.FP3 GR.FP3 44.699 CCL.FP3 39.395 TPHI.FP3 1.745 SIBH. FP3 47.551 FBAC.FP3 2397.076 TCFD.FP3 256.909 INFD.FP3 0.000 33.551 TPHI.FP3 0.027 SIBH. FP3 48.281 FBAC.FP3 3258.259 TCFD.FP3 276.729 INFD.FP3 -999.250 52.415 SBHF. FP3 65.515 TR~T. FP3 15.424 TCAN. FP3 623.143 TSCN. FP3 49.314 TENS.FP3 38.240 SBHF. FP3 35.681 TRAT. FP3 16.580 TCAN. FP3 1025.369 TSCN. FP3 69.891 TENS.FP3 38.111 1.619 5942.743 283.375 684.000 42.702 1.725 10604.895 640.921 759.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/04/ 7 ORIGIN : FLIC TAPE NAME : 98172 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : BP EXPLORATION, 2-18/L-16, ENDICOTT, 50-029-22032-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/04/ 7 ORIGIN · FLIC REEL NAME : 98172 CONTINUATION # : PREVIOUS REEL : COf~4ENT : BP EXPLORATION, 2-18/L~16, ENDICOTT, 50-029-22032-00