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Home My WebLink About198-255 • • RECEIVED Post Office Box 244027 JUL0 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U 3 20111 3800 Centerpoint Drive Suite 100 A®GCh Anchorage,AK 99503 `1V" Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 calliKEa AUG 2 9 ZU b Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 I �� ES- Re: '5Re: Duck Island Unit Well Renaming Request I — 3 3)3 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 "I" 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 • New API_WeliNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 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/J18 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 1-17/5N2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 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/Q21 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/Q20 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/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 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 2-20/115 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~"- ~ ~'_..~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA ~ Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by: Bevedy Mildred Daretha ~owell Date: ~/,/// ~si ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg 61 -3 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 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, - 127 — 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 1 Date: 09/24/2010 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 END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 1P-20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 __-47END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0 -25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1-47A / M-20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0 -20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0-24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0 -20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 _ 9/2/2010 0.85 9/24/2010 RECE\VED Schlumberger JUN 0 8 7006 NO. 3828 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ccmmi&SìCn .~Jæ:<,a C1I & Gas Cv41S· Ancncr.age Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 . 5 Anchorage, AK 99501 ~ Field: Prudhoe Bay \ q tQ .; :;).. SCANì'JED JUN 1 2 20D6 WII # e Job Log Description Date BL Color CD P2-22 I'"; 1- - d¿t"i 1113ti744 uL::; 11113/05 1 P2-16 /c::l, - I;.::J'~ 11058238 WFL 08/18/05 1 P2-36 í 0'+ - 1(,'/) N/A LDL 07/13/05 1 P2-50B 10,-\' - o4~ N/A LDL 07/16/05 1 16-03 I~I-C' I 11076454 INJECTION PROFILE 07/28/05 1 P2-36 1';1- -I, ~b 11051061 GLS/LDL 06/15/05 1 4-18/S-30 ì-',)"Ïí -116 10564459 PSP GLS 04/18/03 1 1-33B/L-24 I G 'it- - ;::):50 10889175 SCMT 10/12/04 1 04-41 A ¡Ci't- - ~~-~ N/A LDL 07/18/05 1 15-09A ì C¡ _~ - L~"K N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09-17 1-'1- -(',;::z,<{ 11076460 INJECTION PROFILE 08/18/05 1 16-09A 1<11 - (,-;:¡ :~ 11051089 PRODUCTION LOG W/DEFT 08/18/05 1 16-11 '~,'ì -I j<; 11058249 LDL 09/14/05 1 17-02 1-'1'.'(' - 0 "TO N/A SENSA MEMORY LDL 10/17/05 1 NK-38A Dh4 -fJ.j J 10687734 MDT 02/27/05 1 R-35 ¡'i'~-ltf 11212863 USIT OS/26/06 1 D-09A I CJ'4 - 0::: '7<,- 11221576 USIT OS/27/06 1 L5-16 ì"?{'t-r'il(;)¡ 11212864 USIT OS/28/06 1 K-08A "ì.".:~.. ¡'-It....., 11054182 MCNL ~ ì';::;«'¡S~ 06/06/05 1 1 H-04A _'ì{]:) .- /r,. I 10715365 MCNL ;:t. ¡:"\ <./'7 ~ 11/27/03 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /1 li (~ IJ í i !í i / ~ Ii { / V v(j/ 06/01/06 e e STATE OF ALASKA -, ALASKÅ~L AND GAS CONSERVATION C<J.w.MISSION RECEIVED REPORT OF SUNDRY WELL OPERATION~~PR ···1 2005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program AlaSK& m~ & Gas lAns.. Commiss·oß d'eHRßfag8 IBI Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 55.5' 8. Property Designation: ADL 312828 11. Present well condition summary Total depth: measured 12585 feet true vertical 1 0077 feet Effective depth: measured 12542 feet true vertical 10075 feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 90' 4971' 11685' 30" 10-3/4" 7-5/8" 1438' 2-7/8" Perforation Depth MD (ft): Perforation Depth TVD (ft): 12500' - 12540' 10072' - 10075' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4. Current Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 198-255 6. API Number: 50-029-22577-02-00 9. Well Name and Number: END 1-33B/L-24 10. Field / Pool(s): Endicott Field / Endicott Pool Plugs (measured) None Junk (measured) None MD TVD Burst 130' 130' 5013' 4406' 5210 11724' 9794' 8180 Collapse 2480 5120 11147' - 12585' 9322' - 10077' 10570 SC,ANNEl) l~PR .1 4 2005 11160 4-1/2",12.6# & Tubing Patch: 2", 6.16# 7-5/8" TIW 'HB-BP-T' packer; 4-1/2" HES 'HXO' SVLN 13Cr80 16Cr 11198' 11001' - 12430' 1111 0' 1581' Treatment description including volumes used and final pressure: RBDMS BFl APR 0 4 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 3 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations o Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure 3 2,910 15. Well Class after proposed work: o Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mark O. Johnson, 564-5666 NIA Printed Name Terrie Hubble Signature --1O;VlÙ. ~ Form 10-404 Revised 04/2004 1,350 Title Technical Assistant Phone Date 04/01/ 05 Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 '.....; \ ~ \......,i ~ ii.J ;¡ !_. ) ) Well: Field: API: Permit: 1-338/L-24 Rig Workover Duck Island Unit / Endicott 50-029-22577 -02-00 198-255 Accept: Spud: Release: Rig: 03/05/05 N/A 03/08/05 Nordic #2 "~- ~- - -..... -----..... - - .... -- - .-..... .' ~. ... . . ~ - -. ~ . ..--~- -' .'" . '. - ~-' .'" -' -. ,.- -~ . . _......... L__' ~__~. ',' ~_ _. _ PRE-RIG WORK 09/29/04 RAN 3.70" DRIFT W/4-PRONG GRAB TO 7700' SLM AND COULD NOT GRAB RUBBER. RAN 3.5" LIB TO 8165' SLM, NO MARKS, RAN 3.70" DRIFT W/3-PRONG GRAB AND SPEAR DOWN TO 9,854' SLM. LOOKS LIKE PUSHING RUBBER DOWN HOLE. 1 0/01/04 TAG W/2.125" GR AT 11140' SLM, POOH HAD MARK'S ON GR. TAG WI 2.5" GR AT 11140' SLM, POOH HAD MARK ON LIB. DRIFT WI 1.90" SWEDGE AT 11250' SLM. WILL PUMP FLUIDS AND COME BACK TO RE- DRIFT. 1 0/07/04 DRIFTED WI 1.90" SWAGE TAG TOC AT 12257' SLM. 1 0/12/04 RAN SCMT TO 12150', STOPPED DUE TO DEVIATION. LOGGED UP TO 11000' AS PER PROGRAM. FOUND LINER TOP AT 11155' AND TOC AT 11410'. TIED INTO SLB DUAL LATEROLOG DATED 4-FEB-99. 11/12/04 RIH WI DUMMY PACKER DRIFT (2.25" X 4'). DRIFT TO 12,510' CTMD, POOH. RIH WITH PDS MEMORY CALIPER. 11/13/04 RIH WITH PDS MEMORY CALIPER. LOG FROM 12500' UP TO 10600' CTMD. POOH. FREEZE PROTECTED WELL TO 2000' WITH 60/40 METHANOL. GOOD CALIPER DATA. RIG DOWN. JOB COMPLETE. 01/29/05 DRIFTED TBG TO 11,123' SLM WI 3.80" CENT. RAN 20' WHIP STOCK DUMMY TO 11124' SLM. 01/30/05 RAN 2.25 CENT WISB TO 11500' SLM. SB EMPTY. WELL LEFT SHUT IN. 02/19/05 SET FA PACKER: STANDBY FOR SL & VECO. 02/20/05 BOPE TEST COMPLETE, GOOD TEST. ATTEMPT TO KILL WELL BY LUBE & BLEED METHOD, UNSUCCESSFUL. MU MEM GRICCL IN 2.2" CARRIER WI 2.25" JSN. SNUB INTO WELL. LOG FROM 12510 TO 11000, PAINT FLAG AT 12345. PARK AT 1100 CIRC KILL WELL -IN PROGRESS. 02/21/05 CIRC KILL WELL, MONITOR WELL. WELL DEAD WITH 312 PSI. POH KEEPING HOLE FULL. MONITOR WELL 20 MIN. WELL DEAD AT 340 WHP. LD I PDS LOG TOOL, VERIFY DATA. MU/RIH WI BAKER 2-7/8" FA PACKER. TIE INTO FLAG. SET PACKER AT 12430', COE. POOH, KEEPING HOLE FULL WITH 10.1 PPG NACUNABR BRINE. PERFORM INJECTIVITY TEST WI BRINE. FP FLOWLINE & TBG. RDMO. ") ) Legal Well Name: 1-338/L -24 Common Well Name: 1-338/L-24 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 p7rofn'- To Houts Task Code· ·NPT 3/5/2005 09:30 - 09:45 0.25 MOB P PRE 09:45 - 10:15 0.50 MOB P PRE 10:15 - 13:30 3.25 MOB P PRE 13:30 - 16:30 3.00 MOB P PRE 16:30 - 18:00 1.50 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 19:30 1.00 RIGU P PRE Start: 3/5/2005 Rig Release: 3/8/2005 Rig Number: 2 Spud Date: 9/2/1995 End: 3/8/2005 . ... ... . . . ; p~scription;()f Qpetøtions 19:30 - 23:30 4.00 RIGU P PRE 23:30 - 00:00 0.50 BOPSUP P PRE 3/6/2005 2.00 BOPSUR P PRE 00:00 - 02:00 02:00 - 02:30 0.50 BOPSUR P PRE 02:30 - 03:00 0.50 BOPSUP P PRE 03:00 - 04:00 1.00 BOPSUR P PRE 04:00 - 05:00 1.00 BOPSUP P PRE 05:00 - 05:30 0.50 BOPSUP P PRE 05:30 - 06:00 0.50 BOPSUP. P PRE 06:00 - 06:15 0.25 BOPSUR P PRE 06:15 - 12:30 6.25 BOPSUP P PRE Safety meeting prior to moving off well 1-55. Attended by rig crew, Pad Operator, Toolpusher, Teamleader, Co Rep. Discuss procedure, hazards, and mitigations. Move Nordic 2 rig off of well 1-55, and stage in front of 1-33. Standby on pad in front of well 1-33 waiting for load and kill to be completed. Well kill is completed. WHP=O psi. IAP=2500 psi with some gas. LRS bleed IA to 0 psi. Begin rigging up on well 1-33. Set herculite around wellhead. Spot rig mats. Move rig onto mats. Check WHP with DSO: 1 00 psi. Hold PJSM to discuss spotting rig over well. Discuss comms, responsibilities, procedures. Put XO spool on bottom of BOPS using loader. Move rig over well. Center up rig. Accept rig at 1930 hrs. Secure and seal cellar area with berm material and snow. NU BOPS. Rig up kill & choke lines. Hook up and test BOP hydraulics. Continue to RU location. Call for DSM to run hardline to flow back tank. Body test BOPS to 400 and 3500 psi. Rig up SLB pressure transducer to record BOP test. Begin BOP test. Record all data on SLB system and chart. Test lower 2" combis to 400 psi, 3500 psi. Not able to hold more than 2750 psi. Call for TWC and grease crew Grease all BOP and tree valves. Body test BOPS again to 3500 psi. Held solid. Body test to 400 psi. Continues to bleed off. Set two way check. Found 435 psi on well. Master valve not holding very well. Take on 290 bbls 10.1 ppg hi-vis flopro mud into pits. TWC not holding pressure. Pull and re-dress same. BOP's still not holding low pressure test, but no surface leaks can be detected. Re-set TWC. Holding pressure. RD lubricator. Body test BOPs. Shut down BOP testing for crew change. Continue BOP testing of 7-1/16" stack. Witness by the AOGCC waived by John Crisp. Bop test since 06:00 witnessed by BP Co Rep, Greg Sarber. BOP test was completed Choke side manual valve, and a 2nd manual valve in the choke failed. They were greased and then passed ok. PRE Pick coil tubing injector up, attached legs and packoff. PRE Safety meeting re: stabbing pipe. PRE Pull pipe from reel to injector and stab. PRE Circulate viscosified 10 ppg brine to clean the coil at minimum rate. PRE PJSM prior to pulling TWC. PRE Pull TWC. 289 psi on wellhead. 12:30 - 14:30 2.00 RIGU P 14:30 - 14:45 0.25 RIGU P 14:45 - 16:00 1.25 RIGU P 16:00 - 16:30 0.50 RIGU P 16:30 - 16:50 0.33 RIGU P 16:50 - 18:00 1.17 RIGU P Printed: 3/14/2005 1 :44:20 PM ) ) SPEXRLORATION . .. ........ . . . Øpêr¡Jti()I1$)SUfr1nl~rY R¡!þþrf. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-338/L-24 1-338/L -24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/5/2005 Rig Release: 3/8/2005 Rig Number: 2 Spud Date: 9/2/1995 End: 3/8/2005 Hours T a.sk Code NPT .. Pha.se .·O~sCriþtion9fOperati()hs . 3/6/2005 18:00 - 20:00 2.00 ZONISO P RUNPRD Circulate 2 coil volumes at 1.9 bpm @ 3250 psi to clear coil. Spoolable connector holding fluid ok, estimate 300-400 psi. Round up and spot diesel pup, triplex, bleed trailer to pressure IA for next tubing kill. Bring Baker tools to rig floor. Pressure IA to 1000 psi. 20:00 - 20:45 0.75 ZONISO P RUNPRD Hold PJSM in ops cab with Baker, Nordic, SLB. Discuss well kill, coil patch hardware and make up procedure, pressure control contingencies if well comes on during patch make up. 20:45 - 22:45 2.00 ZONISO P RUNPRD Pressure fA to 2400 psi. MU K-anchor assy. Install cold roll connector. Pressure test connector to 2500 psi. Held solid. Circulate to warm up coil. 22:45 - 23:30 0.75 ZONISO P RUNPRD Bull head 10.0 ppg hi vis flopro at 8.5 bpm w/ 2410 psi initial circ pressure. WHP increased to 3000 psi with 172 bbls pumped. Slow rate to 7.3 bpm @ 2900 psi WHP. PRessure dropping with 185 bbbls away. Increase rate again to 8.0 bpm @ 2400 psi. 23:30 - 00:00 0.50 ZONISO P RUNPRD Monitor well for pressure and or flow. No whp or flow. 3/7/2005 00:00 - 00:30 0.50 ZONISO P RUNPRD Continue to monitor well. No pressure or flow. Bleed IA down to 1750 psi. 00:30 - 01 :30 1.00 ZONISO P RUNPRD MU K-anchor. RIH with1410' of chrome coil. Close upper 2" combi rams. Pull 1 Ok#, push 5k#. Run in manual lock downs on slips. 01 :30 - 02:30 1.00 ZONISO P RUNPRD Strip injector up off lubricator. Hot tap coil. Cut and dress coil. Install slip type connector. Install safety valve. 02:30 - 03:15 0.75 ZONISO P RUNPRD Cut 300' of extra chrome coil off reel. Recover spoolable connector. This Kendal style worked very well. Held 2000 psi pressure and passed through injector with no problems, with no deformation of coil ends. 03:15 - 03:45 0.50 ZONISO P RUNPRD MU Baker connector. Leaked at 700 psi. Cut off. Install SLB Kendal style connector. Pressure test to 2000 psi. Pull test to 20k#. Good test. 03:45 - 04:30 0.75 ZONISO P RUNPRD MU GS coil assembly below injector with deployment sleeve. Pull test assembly. Hold 9k# up wt. Release manual ram locks. Open combi slips. Slack off blocks with patch assembly and stab on to lubricator. Total BHA length including patch and GS running tools: 1428.96'. 04:30 - 06:00 1.50 ZONISO P RUNPRD Run in hole with coil patch assembly at 90 fpm. Bleed IA to 250 psi. 06:00 - 06:40 0.67 ZONISO P RUNPRD Continue to RIH with pumps down. RIH thru the liner top at 11147', with no bobbles. Kick on pumps to minimum rate, and continue RIH. 0.5/0.57/1730 psi. RIH @ 11500', weight is 12200 psi. Weight check at 12200', 37000 # up, 11000 # RIH. 06:40 - 07:05 0.42 ZONISO P RUNPRD Weight check at 12355'. 37,800 # up, RIH at 10000#. RIH at 30 fpm to 12380', pumping at 0.5 bpm. 0.47/0.47/1830 psi. Weight check at 12380'. 37300# up, RIH at 9800 # down weight. RIH at 20 fpm, pumping at 0.5 bpm. 0.48/0.44/1820 psi. Tag up at 12443' CTM, see pressure increase and drop in out rate to O. Set down 5000 Ibs weight. PU to 32 klbs. Got out rate back, pulled out of latch. Shut down pumps, and get up weight with pumps down at 37000 Ibs. RIH at 11000 Ibs. Set down at 12445' CTM. Stack 5000 Ibs on latch, and wait 5 Printed: 3/14/2005 1 :44:20 PM -) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-338/L -24 1-338/L-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/5/2005 Rig Release: 3/8/2005 Rig Number: 2 Spud Date: 9/2/1995 End: 3/8/2005 Date' Frorrf~To HoÜrsía$kCode NPT Phase · . Dè~criþtiön ofQperatiönS 3/7/2005 06:40 - 07:05 0.42 ZONISO P 12:45 - 13:15 0.50 ZONISO P RUNPRD minutes. PU at 42000 Ibs. Good indication from overpull that we are latched. Position pipe with 2000# stacked. Bring pumps up to 1.2 bpm, injecting at 2710 psi, no returns. Confirmed good hydraulic seal on lower anchor. GS should be released. PU at 31 klbs, pump pressure dropped to 2240 psi, started getting out rate. Confirmed free of coil patch. Good set. Bottom of coil patch is at 12443' CTM, 12430' ELM. POH pumping at 1.25 bpm, and taking returns. PSJM re: changing BHA's, and picking up L TP. Tag up at surface with BHA #1, coil deployment BHA. Lay down BHA. Pick up BHA #2 to deploy L TP. RIH with BHA #2 to set L TP. RIH at 100 fpm. Pumping 0.5 bpm in, 0.83 bpm out. Stop at 10920', Check wt up = 35000 Ibs, (pumps at 0.3 bpm) RIH, pumps at 0.3/0.38 bpm, 1280 psi. Saw weight drop, and pressure bump at 11028' while RIH, and returns went to 0, confirming seal on stinger in deployment sleeve. Set down at 11038'. Stinger is 10.28' long. This is all consistent with what is expected. SD pumps, paint flag on coil at 11038'. Line up to pump down the backside. Pump at 0.3 bpm, 1800 psi. Confirm we have injectivity into the leaks in the liner. Bleed backside pressure to O. PU out of seal assembly, drop 5/8" steel ball to set L TP. Coil volume to gooseneck is 10 bbls. Pump 15 bbls of mud @ 1.5 bpm, 2400 psi. Heard ball rolling. At 15 bbls away, drop rate to 0.5 bpm, 1400 psi. Circulate ball on seat, landed at 27.8 bbls away, with a 200 psi pressure bump. Bleed oft coil pressure. RUNPRD RIH dry, Set down with seal assembly at top of deployment sleeve, 11028'. PU, set down again, same place. Stack 5klbs, not able to get into deployment sleeve with seal assembly. Can't pump down coil, as ball is on seat. Line up to pump down the backside. PU above liner top, pump down the backside at 0.4 bpm, 800 psi, and RIH. Tag up at 11028'. PU, and RIH faster, still set down at 11028'. PU 100', and RIH at 50-70 fpm. RIH, set down at 11029'. PU 100' again, RIH and set down at 11003'. PU 45 klbs. Slips may be setting. Work pipe up and down. 07:05 - 08:45 1.67 ZONISO P RUNPRD 08:45 - 09:00 0.25 ZONISO P RUNPRD 09:00 - 09:30 0.50 ZONISO P RUNPRD 09:30 - 11 :30 2.00 ZONISO P RUNPRD 11 :30 - 12:45 1.25 ZONISO P RUNPRD 13:15 - 13:45 0.50 ZONISO P 13:45 - 15:40 1.92 ZONISO N RUNPRD Work pipe. Can't get free. Slips on L TP hung up and began to set above required set depth. Bottom of L TP seal assembly is 11 003'. Top of L TP is 10981'. Can't get free. Pressure up to set L TP. CTP=4200 Ibs. PU to 45 klbs. Not free. Work pipe, trying to get free of L TP. Drop CTP to 0, and ramp it up to 5000 psi as fast as possible a few times trying to set packer and release. Finally got free after cycling pressure 6 times. STUC RUNPRD POOH with L TP setting tool pumping at 1.2 bpm. Call Baker TT shop for fishing equipment to retrieve L TP. Getting rust/scale accross shaker while POOH. STUC RUNPRD Hold PJSM prior to bumping up with L TP setting BHA. STUC RUNPRD Tag up with BHA #2, L TP setting BHA. Confirmed L TP left in the hole. 5/8" ball on seat, and recovered in the setting tool. Send setting tool back to Baker shop to be redressed. MU BHA #3, fishing BHA. 15:40 - 16:00 16:00 - 16:50 0.33 ZONISO N 0.83 ZONISO N Printed: 3/14/2005 1 :44:20 PM ) ) BPiEXPLORATION . . .··øperªt¡:QlÎs$qrnI11CJry· .RE!P()r~· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-338/L -24 1-338/L-24 WORKOVER NORDIC CALISTA NORDIC 2 · . pagé4of5 Start: 3/5/2005 Rig Release: 3/8/2005 Rig Number: 2 Spud Date: 9/2/1995 End: 3/8/2005 .. Datè FrÖI11~To Hours Task Code NPT .·pescri ption ofOperatiQns . STUC RUNPRD RIH with fishing BHA. 37k# up, 11 k# dn wt. Pump min rate while engaging fish. 1370 psi @ 0.48 bpm. STUC RUNPRD Tag fish at 10991'. Note pressure increase. Shut in pump, bleed coil. Pull 46k# up. Jars no fire. Re-cock jars. Pull 50k# (14k# over). Repeat several attempts with up and down weights. Unable to get jars to fire. Pump at 1.5 bpm @ 3100 psi. Release GS from fish. Circulate OOH to replace jars. Losing a few bbls per hr to formation. At surface get of well. Unstab coil. Replace jars in BHA. Stab coil. Get on well. RIH with packer fishing BHA. Continue to RIH with packer retrieving assembly. 35k# up, 11.5k# dn wt at 10900'. 1350 psi @ 0.49 bpm. Engage packer at 10992'. PU to 46k#. Jars fired ok. Set dn. PU to 49k#. Packer came free on second jar stroke. POOH slowly with packer dragging 2-3k# over initial up wt. Fill hole across top. Monitor hole fill closely due to concerns about swabbing. 241 bbls initial pit volume, 200 bbls final. At surface. STUC RUNPRD Get off well. Unstab coil. LD fishing assembly and L T packer fish. MU replacement L T packer with running tool on 1 jt 2-3/8" PH6 dp. Stab coil. Get on well. STUC RUNPRD RIH with KB L T packer. STUC RUNPRD Circulate at 1400 psi @ 0.37 bpm. 37k# up, 10.6k# dn wt. Stab into seal assembly. Note pressure increase. Bottom out at 11026'. PU to get into reel ball drop position. Drop delrin ball. Circulate at 1.05 bpm @ 1900 psi, unstung from seal assembly. RUNPRD Circulate ball over gooseneck. At 19 bbls away, sting into deployment sleeve with stinger, and nogo at 11035'. Pickup 5' for spaceout. Pressure increased on circ pressure, returns went to 0, confirming seals are engaged. Bullheading fluid to get ball on seat. Pumping at 0.5 bpm, 2300 psi. Ball on seat at 36.6 bbls away. Immediately ramp pressure up to do complete set cycle on L TP. Trips on pump went at 4600 psi, then got set from L TP. Stack out at 11030' CTM. Looks like L TP is set. Pump down the backside. Held 2000 psi for 5 minutes. Held like a rock. We have good set of L TP. Bleed lAP to 0, PU, pulled 40 klbs. Set down again at 11030'. Pressure up to pump down the coil PU at 34 klbs. 3/7/2005 16:50 - 19:15 2.42 ZONISO N 19:15-20:00 0.75 ZONISO N 20:00 - 21 :45 1.75 ZONISO N STUC RUNPRD 21 :45 - 22:15 0.50 ZONISO N STUC RUNPRD 22: 15 - 00:00 1.75 ZONISO N STUC RUNPRD 3/8/2005 00:00 - 00:15 0.25 ZONISO N STUC RUNPRD 00: 15 - 00:30 0.25 ZONISO N STUC RUNPRD 00:30 - 03:00 2.50 ZONISO N STUC RUNPRD 03:00 - 03:45 0.75 ZONISO N 03:45 - 05:15 05: 15 - 06:00 1.50 ZONISO N 0.75 ZONISO N 06:00 - 06:50 0.83 ZONISO P 06:50 - 08:45 1.92 ZONISO P RUNPRD 08:45 - 09:00 0.25 ZONISO P RUNPRD 09:00 - 09:30 0.50 ZONISO P RUNPRD 09:30 - 11 :45 2.25 ZONISO P RUNPRD ELM depth of bottom of stinger on packer is 11017', ELM depth of top of packer is 11000.5'. POOH pumping 0.88/0.74/1770 psi. PJSM re: open hole undeployment of BHA. Lay down Baker eq, BHA #5. All recovered ok. PU SWS stinger and 3" JSN, BHA #6. RIH with 3" JSN. Swap to KCL at 2700', pumping at minimum rate to have KCL at the nozzle when we get to the top of the liner. Printed: 3/14/2005 1 :44:20 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: · Date 1-338/L-24 1-338/L -24 WORKOVER NORDIC CALISTA NORDIC 2 . HoUrs Task. Code N PT Start: 3/5/2005 Rig Release: 3/8/2005 Rig Number: 2 Spud Date: 9/2/1995 End: 3/8/2005 Description dfOperatiöl1s 3/8/2005 11 :45 - 13:30 1.75 ZONISO P RUNPRD 10950', KCL to the nozzle. POOH pumping KCL, and saving mud returns. Pulling at 70 fpm, pumping at 2.14/1.90/3200 psi. 13:30 - 14:30 1.00 ZONISO P Parted CT drill RUNPRD At surface. Perform injectivity test with KCL from surface, pumping through kill line. 14:30 - 15:00 0.50 ZONISO P RUN PRO 15:00 - 15:15 0.25 RIGD P POST 15:15 -15:30 0.25 RIGD P POST 15:30 - 16:30 1.00 RIGD P POST 16:30 - 18:00 1.50 RIGD P POST 18:00 - 20:30 2.50 RIGD P POST 20:30 - 00:00 3.50 RIGD P POST Time Rate Bbls Pressure 1330 0.52 0.5 1490 1350 0.50 10.0 1685 1400 0.75 20.5 1622 1415 1.01 25.0 1637 Open well to check for flow back and/or pressure. WHP bled to zero with no flow. RU diesel to freeze protect tbg. Bullhead 3 bbls: FP to 200'. Shut in well. Flush pump & BOPs with KCL water. RU SLB N2 pump truck. Open hard line to tiger tank. Get off well. Remove BHA. Get back on well. Hold PJSM with crews in ops cab to discuss blow down procedure. Discuss hazards, contingencies, safe area and more. Pressure test hardline to 4000 psi. Begin pumping N2. Blow down to outside tiger tank. Purge all rig lines as well. RD N2 equipment. Phz 2 (30 mph wind w/ blowing snow) Unstab coil and pull to reel. Secure CT on reel. Set injector for RWO ops, remove stuffing box Wash pits, but too low on rig water to finish w/ weather conditions (need water for boilers first). WO loader to convoy rig water truck from Deadhorse. Endicott opened road at first bridge w/ blade at 2000 hrs NO BOPE. NU tree cap and PT @ 5000 psi. Prep cellar for move Fin vac pits Phz 3 @ 2200 hrs RREL @ 2400 hrs 3/8/05 Future reports and charges will be found on 4-02/0-28 Printed: 3/14/2005 1 :44:20 PM RT. ELEV = 56.0' BF. ELEV = 18.7' MAX DEV = 88 @ 12541' ) E N D 1 33 B TREE: 4-1/2" .CAMERON W 5000 psi _ WELLHEAD: )t8" 5000 psi FMC 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 5013' I ~ A . HES 'HXO' SVLN .- (3.813" MIN. ID) .. W/SSSV MIN I.D. is 2.0" 1581' 4-1/2", 12.6#/ft, 13CR NSCT tubing ... Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors GAS LIFT MANDR8..S (HES-KBMGM) ST MD NO VLV LATC!- PORT DATE 7 3946 3490 BK 6 6122 5238 BK 5 7447 6302 BK 4 8323 7001 BK 3 9185 7705 BK 2 10051 8391 BK 1 10956 9099 BK Minimum ID = 1.25" @ 12,430' BAKER FA PACKER 111147 Z' ZI .-- 4-1/2" KB PACKER 4-1/2" 'X' NIPPLE ~ ~.- 7~;8~ :::~~: Z ~~ (TIW HB-BP-T ) I þ ~ ~ 4-1/2", 12.6#/ft, L-80 TAILPIPE I~ ! \ 11001' Note: Tie back sleeve is not Anchored 11099' Baker CHP Tie back sleeve 3.125" 10 11110' XO to 2-7/8 Liner 2.375" ID I 11155 7-5/8" CSG-BTC, 29.7# -.... Top of window @ 11724 PERFORA TION SUMMARY REF LOG: DLL-GR ON 02/04/99 ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL DATE 1-11/16" 4 12499 - 12539 0 2", 6.16#, 16Cr Tubing Patch (11001' to 12430') :8 ~ 12430'1-i BAKER FA PACKER, 10=1.25" ... o ...... 2-7/8" ST -L Liner 2.441" 10 Min. 10 @ XO = 2.375" ** KEY: 0 = OPEN / C = CLOSED / SQZ=SQUEEZED PBTD 2-7/8" Float Collar 12548' I ,--. - .... .... TD TAG TD I 12542' t.. .12585' 12549' DATE 02/12/99 02/20/99 10/10/04 12/31/04 02/21/05 REV BY COMMENTS DA V INITIAL COMPLETION DB INITIA L PERF / TLH FORMA T CORRECTION / TLP 7 -5/8" CSG CORRECTION BMcNlPJC BK FA PACKER ENDICOTT UNIT W8...L: 1-33B / L-24 PERMIT No: XXXXXXX API No: 50-029-22577-02 SEC T N R E BP Exploration (Alaska) Re: 10-403 Sundry for 1-33B/L-24 ) ) Subject:Re: 10-403 Sundry for 1-33BIL-24 From:.. Jody Colombie <jody_colombie@admin.state..ak.us> Date: Fri,04 Feb 2005 15:01:07 -0900 To: .I'Hubble, .TèrfiêL" . <HubbleTL@l1P.cøm> B€C:Jody Colombie <jody_Colombie@admin.state.ak.us> \C~,ß..;¡.ø . Terrie, The AOGCC has cancelled Sundry Number 305..021 with approval date of February 2, 2005. I apologize for the confusion! Jody Colombie Special Staff Assistant Hubble, Terrie L wrote: ¡ Hi Jody, I called a little while ago and left a message for you to call. Then 1 decided that 1 should write you an explanatory note. Yesterday 1 received an approved 10-403 for this well, Sundry # 305-021. At first 1 didn't think anything of it, but when 1 filed it 1 discovered that we had already received an approval on it a few weeks back. That Sundry # is 305-003. What should we do? AP I: 50-029-22577-02-00 Thanks! Terrie SCANNED FES 0 4 2005 1 of 1 2/4/2005 3:01 PM ~,'.~,1 C'I',;, 11~,:j/.'f¡A\\\. J! j' I;...,I[;,~,~,. [';1'J'! L) ;1[.',\,' \\ ! lí.:~.\.,ì\ ~~ r t¡ II;í.1 \\ \..:lJ ." - ---.. ..::::. LJ ~J t ..~:::¡ Lr t. Q)) .J \\ d -U ) FRANK H. MURKOWSK/, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ."!P \OxCt{r Re: Endicott 1-33B/L-24 Sundry Number: 305-021 Dear Mr. Johnson: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a . ay or weekend. A person may not appeal a Commission decision to Superior ourt unless rehearing has been requested. ( / # ;¡.e~(~ DATED this£ day of~, 20l,5 Encl. 1 . Type of Request: II Abandon I 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well W4A- Z./t/Z.OOS ) STATE OF ALASKA ) tØ" 2(1 ß ALASKA Oil AND GAS CONSERVATION COMMISSION E1VED APPLICATION FOR SUNDRY APPROVAL Jp,N 1. 0 2005 20 AAC 25.280 , C, Commission &. oos. (~fithcrage 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Curr"t Well Class: aa Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number 198-255 / 6. API Number: / 50- 029-22577-02-00 9. Well Name and Number: . END 1-33B/L-24 '/ 99519-6612 55.5' 8. Property Designation: 10. Field / Pool(s): ADL 312828 Endicott Field / Endicott Pool PRESENT WELL,CONQITIONSUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12542 10075 None MD TVD ' Burst Junk (measured): None Collapse 11. Total Depth MD (ft): 12585 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 10077 Length Size 90' 30" 130' 130' 4971' 10-3/4" 5013' 4406' 5210 2480 11685' 7-5/8" 11724' 9794' 8180 5120 1438' 2-7/8" 11147' - 12585' 9322' - 1 0077' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12500' - 12540' 10072' - 10075' Packers and SSSV Type: 7-5/8" TIW 'HB-BP-T' packer; 4-1/2" HES 'HXO' SVLN Tubing Size: 4-1/2", 12.6# Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 11110' 1581' Tubing MD (ft): 11198' 12. Attachments: aa Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mark O. Johnson Title CT Drilling Engineer Signature. ~ O~.~¡~~~r.)n'ø$!¡~~666 0 BOP Sketch 13. Well Class after proposed work: / 0 Exploratory aa Development 0 Service 15. Well Status after proposed work: 0 Oil 0 Gas 0 WAG DGINJ /.' 0 Plugged aa Abandoned 0 WINJ 0 WDSPL January 14,2005 Date: Contact Mark O. Johnson, 564-5666 Prepared By Name/Number: Date I/Ið/o S" Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3 D S-- Od}-! 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: /tp p 1/IU e.d Fo V V1Å ló - 4-0 l V"r,{~J j)~ ç;J¡t~K- IM-l/{ J - š ~ [/ ¡.II. lðr . RBDMS BFL FEB 0 3 20ð5 Subsequent F COMMISSIONER APPROVED BY THE COMMISSION Date ~-:) -,oS Submit In Duplicate ORIGINAL ) ) j~ b~ r) Ø~.tb%ili~ " i, ~ ~~- r To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mark O. Johnson CTD Engineer Date: January 7, 2005 Re: P&A operations for Endicott 1-33B/L-24 in prep for a CTD sidetrack We1l1-33B/L-24 is scheduled for a through tubing sidetrack with th~SLB/Nordic 2 Coiled Tubing Drilling rig./ The sidetrack, 1-33C/M-24, will exit out of the existing 7 5/8" liner from a mechanical whipstock and target Kekituk S2A1 reserves. The existing 2 7/8" liner perfs will be abandoned with a CIBP set in the 2 7/8" at 11430'md. The following describes work planned for the P&A and is submitted as an attachment to Form 10- 403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) Slickline - Drift tubing for whipstock. Dummy gas lift valves. Pressure test IA to 2500 psi. Drift 2 7/8" liner for CIBP. / 2) E-líne - Set 2 7/8" CIBP at 11430' md. Pressure test wellbore to 1000 psi. P&A is complete. Regardless of pressure test results continue with planned operation? The old wellbore will be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line - Chemical cut 2 7/8" liner above top of liner cement at 11380' md. 4) Service coil- Grab CPH liner top with releasable spear at 11147' md and pull check liner to confirm free. Set back down. 5) Remove wellhouses and flowlines. Prep pad for Nordic 2 rig. ^ CTD Sidetrack Summary 1) MIRUNordic 2. 2) Pull 2 7/8" liner from chemical cut.T k 4, 1 0 ,~ 4 o'~ tfP yO \it.\., ( . 3) Underream 7 5/8" liner from 11200-11380' md. 4) SL - Log PDS caliper survey of 7 5/8" liner to confirm all cement is gone. 5) Set 4 ~"x 7 5/8" whipstock in 7 5/8" liner at 11350'md. 6) Mill 3.8" OD window at 11350' md. 7) Drill HRZ shale to ~ 1165 0' to ~top of Kekituk. 8) Run and cement 3 3/16" L-80 protective casing string. 9) Drill 2.7" x 3" bicenter hole from 11650' to TD at 12877' md with MWD/GR. 10) Log resistivity. 11) Run 2 3/8" 13Cr solid liner completion and cement. 12) Log memory CNL during liner cleanout run. 13) Perforate. 14) RDMO. The pre CTD work is sla to begin on January 14,2005. '~o. Mark O. Johnson CTD Drilling Engi 564-5666,240-8034 ? CC: Well File Sandra StewmanfTerrie Hubble RT. ELEV = 56.0' ), SF. ELEV = 18.7' MAX DEV = 88 @ 12541' TREE: 4-1/2" ,CAMERON W 5000 psi END1-33B WELLHEAD: )8" 5000 psi FMC Note: Tie back sleeve is not - - ~ Anchored L, J :1:~~eCH;1~.~~Ck 111147' 1 ~., z:- 1 11155' 1'-------" ! ~ 10-3/4", 45.5#/ft, L~80, BTC. CSG. I 5013' I ~ A . 4-1/2", 12.6#/ft, 13CR NSCT tubing ~ Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors XO to 2-718 liner 2.375" ID 7 -5/8" CSG-STC, 29.7# PERFOR!\ TiON SUMMt, RY REF LOG' OLL-GR ON 02/04/99 , ft,NGLE AT TOP r-ffiF: ! , Note: Refer to Production œ for historical perf data J - -- 'I ~ SIZE: SPF: INTEf,-",v' ,4, L ! ** DÞ. TE ! -1-11/16"1 4 '12499-1253910 î j ! ¡ : ¡ I ! ¡ ! ¡ ! i ! : I - KEY: 0 = OPEN I C = CLOSED I SOZ=SQUEEZED PSTD I 12548' I 2-7/8" Float I 12549' I ~ Collar -~ CIA TE r£l BY COMM8.JTS : : 02/12/99 DAV, :Nfr;;\L CO~H.E:TiON : ¡ 02tlO/99 œ ~ :NITLl\L PERF ~ ! 10/10/04 1 TLH ¡ FORfM T CORRB:;TION 12131 104 , ITLP f7-518" CSG CORFr::CTION ,-- HES 'HXO' SVLN ....-- (3.813" MIN. 10) . W/SSSV MIN 1.0. is 2.0" 1581' 1 - G~S LIFT MANORB_S (HES~KBMGM) - JST~ ~~_-L-;:VD.,.. ~.LV-- ',~,~..!CHL PORT ,i. Dft.TE : -r ¡ 3945 ¡ 3490 ' BK ¡ ¡ 6 I 6122 ¡ 5238 ' 8K ~ ! 5 ¡ ì 447 ¡ 6302 : i BK ¡ :,: I : 4 ! 8323 ¡ 7001 8K i 3 i 9'185 ¡ 7705 ' 8f< ¡ ~ !. c J .....,,. ). ¡ .:. i 100,-,1! 8",91 ' . 8K i 1 J 1 ~956 J 9D~~ , Sf';, -.- J 11 099' I 11110' I 4-1/2" 'X' NIPPLE (HES 3.813" 10) 7-5/8" PACKER ( TlW HS-BP- T ) 4-1/2", 12.6#/ft, L-80 TAILPIPE -~ Top of window @ 11724 ~ 2-7/8" ST-L liner 2.441" 10 Min. 10 @ XO = 2.375" TO TAG 12542' 8.JDCOTT UNIT ìNB-L: 1-338 i L-24 PE.~~.m- r.,¡o: XXXXXXX AP¡Nc: 50-029-22577-02 SEe TNR E 8P ExplcratiÖn (AÌaSKa)'- .. c~, RT. ELEV = 56.0' SF. ELEV = 18.7' MAX OEV = 88 @ 12541' 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 5013' I 4-1/2", 12.6#/ft, 13CR NSCT tubing Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors 4-1/2" 'X' NI PPLE (HES 3.813" 10) 7-5/8" PACKER ( TIW HB-BP- T ) 4-112" 'XN' NIPPLE ( 3.80" 10 milled out) 4-1/2", 12.6#/ft, 11198' OPM TAILPIPE 11188' ELM 7-5/8" CSG-BTC, 29.7#- EN D1 33C TREE: 4::-"".1'2" ,CAMERON W 5000 psi ) - WELL- »: 13 5/8" 5000 psi FMC ~ A . ~ L L 11099'~ 11110', ... ~ HES 'HXQ' SVLN (3.813" MIN. 10) W/SSSV MIN 1.0. is 2.0" 1581 ' GAS LIFT MANDRELS (HES-KBMGM) ST MD TVD VLV LATCH PORT DATE 7 3946 3490 BK 6 6122 5238 BK 5 7447 6302 BK 4 8323 7001 BK 3 9185 7705 BK 2 10051 8391 BK 1 10956 9099 BK I 1-33C Proposed Sidetrack / z r TOl 2 318" at 11140' md ~ TOL 3 3/16" at 11170' md \ l Whipstock 11350' md-------... Chemical cut 2 7/8" 11380' MD ./ Top ofTTRD window @ 11724' DATE 02/12/99 02120/99 10/10104 12/31/04 01/07/05 REV BY DAV DB ITLH /TLP MOJ COMMENTS INITIAL COMPLETION INITIAL ÆRF FORMAT CORRECTION 7-5/8" CSG CORRECTION proposed sidetrack 1-33C 3 3/16" TC II L-80 drilling liner 11650' md or ENDICOTT UNIT WELL: 1-33B / L-24 ÆRMIT No: XXXXXXX API No: 50-029-22577-02 SEC T N R E BP Exploration (Alaska) ) ) ~1J/Æ1fŒ (ill~ , n [Æð' ~'I" . ¡ \ ¡ i g\ ru~ í ~ ¡ / / I FRANK H. MURKOWSK/J GOVERNOR AI,A~&A. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~, .~ Re: Endicott 1-33 B/L-24 Sundry Number: 305-003 Dear Mr. Johnson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior C unless rehearing has been requested. DATED thisßday of January, 2005 Encl. SCANNED JAN 2 0 2005 ) STATE OF ALASKA) ;:' E ALASKA OIL AND GAS CONSERVATION COMMISSION. f\{"; Ja--- 2005 APPLICATION FOR SUNDRY APPROVAr,:'~.r. '. 20 MC 25.280 A\aska On & ~Ja;) ,Amó» , A\1ch;J{ag~ 1. Type of Request: 181 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate [J Re-Enter Suspended Well --- 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number 198-255 6. API Number: 50- 029-22577-02-00 99519-6612 55.5' 9. Well Name and Number: END 1-33B/L-24 8. Property Designation: 10. Field / Pool(s): ADL 312828 Endicott Field / Endicott Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12542 10075 None MD TVD Burst Junk (measured): None Collapse 11. Total Depth MD (ft): 12585 Casing Structural Conductor Surface Intermediate , Production Liner ' Total Depth TVD (ft): 10077 Length Size 90' 30" 130' 130' 4971' 10-3/4" 5013' 4406' 5210 2480 11685' 7-5/8" 11724' 9794' 8180 5120 1438' 2-7/8" 11147' - 12585' 9322' - 10077' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12500' - 12540' 10072' - 10075' Packers and SSSV Type: 7-5/8" TIW 'HB-BP- T' packer; 4-1/2" HES 'HXO' SVLN Tubing Size: 4-1/2", 12.6# Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 11110' 1581' Tubing MD (ft): 11198' 12. Attachments: rm Description Summary of Proposal 0 Deta iled Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the .foregoing is true and correct to the best of my knowledge. Printed Name Mark O. Johnson Title CT Drilling Engineer Signature ~ O. ~, , phon,e 564, -5666 tl' - - - Commission Use Only 0 BOP Sketch 13. Well Class after proposed work: 0 Exploratory 1m Development 0 Service 15. Well Status after proposed work: 0 Oil 0 Gas 0 WAG OGINJ 0 Plugged OWINJ 1m Abandoned 0 WDSPL January 14. 2005 Date: Contact Mark O. Johnson, 564-5666 Prepared By Name/Number. Date ///0 /c "5 Terrie Hubble, 5644628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: .3 0 S-- 00-3 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: ¡~)V VVV ~d (:.& 'y 10 .- 40 l r<' #' l/uA I>€' J Lk f Ç~J.Aý"-<L ~il 1- ~ z, c) leA.. 2-4 . RBDMS 8Fl JAN 1 8 2005 COMMISSIONER APPROVED BY THE COMMISSION Daœ íi~~ '-- DUPLfCAT:: ) . " Obp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mark O. Johnson CTD Engineer Date: January 7, 2005 Re: P&A operations for Endicott 1-33B/L-24 in prep for a CTD sidetrack Welll-33B/L-24 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig. The sidetrack, 1-33C/M-24, will exit out of the existing 7 5/8" liner from a mechanical whipstock and target Kekituk S2Al reserves. The existing 2 7/8" liner perfs will be abandoned with a CIBP set in the 2 7/8" at 1 1430'md. The following describes work planned for the P&A and is submitted as an attachment to Form 10- 403. A schematic diagram of the proposed sidetrack is attached for reference. ,f' Pre CTD Summary 1) Slickline - Drift tubing for whipstock. Dummy gas lift valves. Pressure test IA to 2500 psi. Drift 2 7/8" liner for CIBP. 2) E-line - Set 2 7/8" CIBP at 11430' md. Pressure test wellbore to 1000 psi. P&A is complete. Regardless of pressure test results continue with planned operations. The old wellbore will be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line - Chemical cut 2 7/8" liner above top of liner cement at 11380' md. 4) Service coil - Grab CPH liner top with releasable spear at 11147' md and pull check liner to confirm free. Set back down. 5) Remove ';Yellhouses and flowlines. Prep pad for Nordic 2 rig. _."".,,,-" 'l~'Vt ~~ i 0 - 40 5 tLf P ¡ () <./ ~ l I CTD Sidetrack Summary 1) MIRU Nordic 2. 2) Pull 2 7/8" liner from chemical cut. 3) Underream 7 5/8" liner from 11200-11380' md. 4) SL - Log PDS caliper survey of 7 5/8" liner to confirm all cement is gone. 5) Set 4 ~"x 7 5/8" whipstock in 7 5/8" liner at 11350'md. 6) Mill 3.8" OD window at 11350' md. 7) Drill HRZ shale to -11650' to -top of Kekituk. 8) Run and cement 3 3/16" L-80 protective casing string. 9) Drill 2.7" x 3" bicenter hole from 11650' to TD at 12877' md with MWD/GR. 10) Log resistivity. 11) Run 2 3/8" 13Cr solid liner completion and cement. 12) Log memory CNL during liner cleanout run. 13) Perforate. 14) RDMO. The pre CTD work is sla to begin on January 14, 2005. .., .~~ O. Mark O. Johnson CTD Drilling Engi 564-5666,240-8034 CC: Well File Sondra Stewmanff errie Hubble RT. ElEV = 56r ",), BF. ElEV = 18. MAX OEV = 88 @ 12541' EN D1 338 IKI:.I:.: 4-1l;~C ,l;AMI:.KUN VV:>WUpSI - WEllHE )135/8" 5000 psi FMC 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 5013' J ... A . HES 'HXO' SVlN ~ (3.813" MIN. 10) ~ W/SSSV MIN 1.0. is 2.0" 1581' 4-1/2", 12.6#/ft, 13CR NSCT tubing ~ Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors I GAS LFT MANæB..S (HES--KBMGM) :ST MD! ND VlV L.A.T~ PORT DATE , -r' 3945 r 349(): BK ! ! 6 6122; 5238 B;{ : i 5 : ì 447 6302 BK ! : 4 : 8323 : 7001 8K ! 3 9185: nQS BK , : 2 : 10051: 8391 BK : ¡ 1 1 09SE;: 9{J88 Œ' : Note: Tie back sleeve is not ~ Anchored ~ Baker CHP Tie back zr sleeve 3.125" 10 111147' I ~~ 111155' I~ ! ~ ,----- ~ 4-1/2" 'X' NIPPLE (HES 3.813" 10) 7-5/8" PACKER (TIW HB-BP-T) 4-1/2", 12.6#/ft, L-80 TAILPIPE 11 099' I 11110' I XOto 2-7/8 liner 2.375" 10 7-518" CSG-BTC, 29.7# -. Top of window @ 11724' PERFORA TiON SUMMt. RY REF LOG' CLl.-GR ON 02/04/99 .A.NGLE A ì ìOP PERF: Note: Refer to Production œ for historical perf data: SIZE i SPF t-HEfN.4.L ,"" DÞ,TE' 1-11;15") 4 12499 - 125:~91 0 ~ . '2-7/8" ST-lliner 2.441" 10 Min. 10 @ XO = 2.375" - KEY: 0 = OPEN I C = CLOSED I SQZ=SQUEEZB> PBTD I 12548' I 2-718" Float I 12549' 1-' Collar .. TO TAG I 12542' ~TE 02112,'99 02,'20199 10l10Æ}4 12ß1Æ}4 RÐI BY COMMB'-4TS DA V ' iNiTIAL CCÞ.PLEJiON œ !N:TIAL PffiF ; TLH r-QRMA T OORRE<;TON I TlP .7-518" CSG CORRECTION BÐa..ì rr uNIT v\Rl: 1-338/l-24 PERllAIT Nc: XXX)(XXY. APi Nc: 50-029-22577-02 SEe TNR E BP 8cpkmltion (Alasica) RT. ELEV = 56.0' 8F. ELEV = 18.7' MAX DEV = 88 @ 12541' 1 0-3/4", 45.5#/ft, L-80, BTC. CSG. f 5013' I 4-112", 12.6#/ft, 13CR NSCT tubing Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors 4-112" 'X' NI PPLE (HES 3.813" ID) 7-5/8" PACKER ( TIW HB-BP- T ) 4-112" 'XN' NIPPLE ( 3.80" ID milled out) 4-1/2" t 12.6#/ft, 11198' DPM TAILPIPE 11188' ELM 7-5/8" CSG-BTC, 29.7#- ) E N D 1 33C TR~ç:"",~ 4-1/2" ,CAMERON W 5000 psi - WE.. 1tEAD: 13 5/8" 5000 psi FMC ..... A . ~ 11099'~ 11110'~ Whipstock 11350' md-----... Chemical cut 2 7/8" 11380' MD Top of TTRD window @ 11724' DATE 02112/99 02120/99 10/10104 12/31104 01107105 REV BY DAV DB ITLH ITLP MOJ COMMENTS INITIAL COMPLETION INITIAL ÆRF FORMAT CORRECTION 7-518" CSG CORRECTION proposed sidetrack 1-33C ... ~ HES 'HXQ' SVLN (3.813" MIN. ID) W/SSSV MIN I.D. is 2.0" 1581' L L GAS LIFT MANDRELS (HES-KBMGM) ST MO TVO VL V LA TCt- PORT OA TE 7 3946 3490 BK 6 6122 5238 BK 5 7447 6302 BK 4 8323 7001 BK 3 9185 7705 BK 2 10051 8391 BK 1 10956 9099 BK I 1-33C Proposed Sidetrack z ¡---- TOl2 3/8" at 11140' md J::: ~ TOL 3 3/16" at 11170' md ;\ 3 3/16" TCII L-80 drilling liner 11650' md ENDICOTT UNIT WELL: 1-33B I L-24 ÆRMIT No: XXXXXXX API No: 50-029-22577-02 SEe T N R E BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571'1 ATTN: Beth NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Corem At'tn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/13/03 Well Job # Log Description Date Blueline Color Prints CD NK-14 ~ C:{ j~, O(~ SBHP SURVEY 04/20/03 NK-08A ~.-O ~ .O?.-cj SBHp SURVEY 04119/03 NK-20 I~'CJ'~ ~ i c7 I SBHP SURVEY 04/20/03 NE-21 [c[~,~-~G'/~,~ SeEP SURVEY 04119/03 NK-07A ~ {. (~(,, ~.,~ SBHP SURVEY 04121103 4-18/S-30 i~. i ~ ~ PSP GLS 04118103 1-33B/L-24 .~dJ~5. ~,~' LDL 04119103 3-451M-29 ~ ~'~ -O,~ i INJECTION PROFILE .. 03~27~03 D.S. 15-47 jcl~.~ ~i-J ~j- LDL 03/2~/03 D.S. 17-11 I ~J' - ~q.~['~{' GLS 04/27/03 D.S. 18-~4A iq~-~, OO"J LDL 04/03/03 D.S. 13-29L1 ~..O'~-, C~cj PRODUCTION PROFILE 04/06/03 ;D.S. 18-03A J.~.j -- [(~ LDL 03/27103 D-05 t"~O, ~(::)/,, PRODUCTION PROFILE 04/13/03 D.S. 9-20 %-J-J. ~ q- J INJECTION PROFILE 04115103 E-13A j cl"~, ~ '7.- SBHP SURVEY 04124/03 D.S. 1-28 J~(E ' O~J.~ CHFR 0313~/03 D.S. 4-18 i ~ ;(-~: ~ j,~-~ FLOWING BHP & TEMP 04/13103 J-23 I ~l~ ~J · O '~ ~ LDL 04/25/03 N-20A [q~ -- I~ ~- CHFR 04110103 D.S. 1-34 J ~)(I? --J t ~-J CHFR 03~29~03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T,O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'r-I'N: Beth 198-255-0 DUCK IS UNIT MPI 1-33B/L24 50- 029-22577-02 Roll #1: Start: Stop Roll #2: Start Stop MD 12585 "~TVD 10077- Completion Date: __/~/18/99.Completed Status: 1-OIL BP EXPLORATION (AI.ASKA) INC ~-Current: T Name Interval D 9102 ~ 1-5 SPERRY GR . L DGR-MD t"~' FINAL 11719-12585 L DGR-TVD ~ FINAL 9790-10070 L MEM-PDC/GR/CCL t,--"~INAL 10860-12536 L SLIM-CN/GR ~ FINAL 11720-12557 L SLIM-CN/LDT/GR ,~'~'"- FINAL 11720-12557 L SLIM-DLL/DT/NT t-'"'~INAL 11720-12557 R SRVY RPT / T 9029 t.,,'~ 1 SPERRY 11699.50-12585. SCHLUM SLDT/MDLT/SCNT Sent Received T/C/D OH 3/18/99 3/18/99 OH 3/23/99 3/23/99 OH 3/23/99 3/23/99 CH 2 3/11/99 3/18/99 OH 3/11/99 3/18/99 OH 3/11/99 3/18/99 OH 3/11/99 3/18/99 OH 3/17/99 3/17/99 OH 3/11/99 3/18/99 Thursday, February 01,2001 Page 1 of 1 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I. SupervisoK FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MP! 1 & 2 MaY 20,2001,: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. I inspected 25 well houses on MP! Row 1 & 2 wi no problems witnessed. SUMMARY: I witnessed SVS testing in BP's. Endicott Field. 17 wells, 51 components tested. I failure witnessed. 1.96% failure rate. 25 well houses inspected. A...ttachmen.ts: SVS DIU 5-20-01jc cc; NON-CO.N .FIOENTIAL SVS DIU 5-20-01jc Aia~aa Oil and Gas Conservation CommL._.Jn Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Crisp Submitted By: John Crisp, Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: LPS 235 Date: 5/20/01 HPS i i i i ~ ii i Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Pass, ed ,, GAS or CYCLE 1-01/J19 1880370 235 150 125 P P P OIL 1-03/P16 1951500 235 150 135 P P P OIL 1-65/0'2o '186i066 .......... 1-09A/L2 1970290 235 150 130 P P P OIL 1-15~25 i93i~560 ....... 1-17A/Il 1961990 1-19/I18 1950930 2'35 150 125 P"' P 9' OiL 1-21/K25 1900020 1-25MK2' 1970756 235 150 "' 150 P '" P "P OIL 1-27/~20' 18~b066 235 150 135 V'" V "V OIL 1-29/M25 1861810 1-31/M21 1950720 235 150 125 P " P ' P" OIL 1-33B/L2 1982550 235 i50 1~,5 P V v .... 0IL 1-'3~/O25 18618'40 ' '235 150 135' V V 'V' ' oiL 1-39/P 17 1880630 i'-'45/Q26 18912.4..0 ...... ' . 1-47A/M2 1972030 1-49/P21 188078'0 235" 150' 130 P ' P P oIL 1-~5/R25 18802101 235 150 145 P P P OIL 1-57/R23 18811401 235 150 140 P P P oIL 17,61/Q20 1941420 235 150 135 p'" P P ....... 0IL 1-63/T22 18~0060: 235 150 145 P P 1~ OIL 1-65/N25 1951880! 235 150 150 P P P ......... OIL .... , , . 2-04/M19 18.6982o , , [ .... 2-06/J22 1870180 2-08/K16 1880040 2-!2/Q16 '1921170 ..... 2-14/016 '1861 ~'0 ...... 2-18/L16 1900430 :2-20/Li5 i'900600 ' ' ' 2-56/N14 1880550 " , 2-28/P19 1880860 !2'30A/Ei' 1981880 ......... 12-32/SN3 1901190 2-36/O14 1900240 2-38/sN1 1901290 2,fiq/~S¢Tn~/,~ 1941520 P2e,,~ of 2 ~xzq r ;~ ~_on_n~;,. Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J,: Number Number psI ,P. SI T~.'p Code Co,de Code, ..P.asse,d GAS orC~.CLE 2~42/P13 1881450 "~:44A/Q1,' 19~.07'10...... . ,'i', .... ,, , 2-46B/S1 1971370 2-48/013 1951660 2-50/U08'' 1930~'70 '235. ~' 150' 145 P P .... P '' OIL 2-52/S14 1870920 :- aAmI 980 80 2.58/809 "1900520 ................ 2-60/U13 1930830 235 150 130 P P P OIL 2-62/Q17 1861580 2-68/S 17 1880970 , , , , ..... , , 5-01/SD7 1801200 Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.96% Fl ~O var · .. Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc WELL LOG TRANSMITFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine St. Anchorage, Alaska 99501 q March 23, 1999 MWD Formation Evaluation Logs 1-33B / L-24, AK-MW-90066 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1-33B / L-24: 2"x 5"MD Gamma Ray Logs: 50-029-22577-02 2" x 5" TVD Gamma Ray Logs: 50-029-22577-02 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company March 11, 1999 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the SLDT/MDLT/SCNT for well 1-33B/L-24. Job # 99087. & MEM PERF D BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS 2 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 Sepia each ARCO Alaska, Inc. Dede Schwar17_~ ATO-1336 Anchorage, AK 99510-0360 E-TRANS 1 Sepia each Exxon ComDany U.S.A. Alaska Interest Organization Attn: Susan Nisbet 800 Bell Street, EB3083 Houston, D( 77002-7420 1 OH LIS Tape 1 Blueline each 1 Sepia each UNOCAL Attn: Debra Childers 909 W.9th Ave. Anchorage, AK 99519-0247 1 OH LIS Tape 1 Blueline each 1 Sepia each PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Explorafior~f~l~k~ .r~. ~ 1F ~ Petrotectnic~~l~ ~i~~ 9~ E. Benson Blvd. Anchorage, Alaska,~5~9~~ Date De~.~ & Gas Co~s. Commission Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Rece~vedLb¢l// -"'- ~[~ " [ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .--- WELL COMPLETION OR RECOMPLETION REPORT AND.LOG ~ ~::~':~:? 1. Status of Well Classification of Service wel!.i.;'~?.,i;~i'..'.;/~¢ ...... [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator ~~;~; 7. Permit Number BP Exploration (Alaska)Inc.~~ 98-255 399-007 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 · 50-029-22577-02 4. Location of well at surface ~ '.r,3';'!< * '~~? 9. Unit or Lease Name 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM:' ; ~~,~,~..~ ! Duck Island Unit/Endicott At top of productive interval . 10. Well Number 1967' NSL, 3983' EWL, SEC. 31, T12N, R17E, UPM (Planned)! ............. ; 1-3aB/L-24 At totaldepth4 :~. ~/: ....:.. 11. Field and Pool 2394' NSL, 3940' EWL, SEC. 31, T12N, R17E, UPM (Planned) ....................... Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADL 312828 12. Date Spudded 113. Date T.D. Reached ] 14. Date Comp., Susp., or Aband.115. Water depth,if offshore 116. No. of Completions 1/27/99I 2/3/99I 2/18/99I 6'- 12' MSLI One 17. Total Depth (MD+TVD)118. ,lu~ ,ac, Depth (~D+TVD)I19. Directiona, Survey 120. Depth where SSSV set 121. Thickness o' Permafrost 12585 10077 FTI 12549 10075 FTI [~Yes []No (Nipple) 1581' MD 1650' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES ~--~ 23. CASING, LINER AND CEMENTING RECORD ~ ~ ~ r~ L CASING SE-I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' Driven 10-3/4" 45.5# L-80 42' 5013' 13-1/2" 795 sx Permafrost 'E', 600 sx Class 'G' 7-5/8" 29.7# USS-95 39' 11724' 9-7/8" 500 sx Class 'G' 2-7/8" 6.4# L-80 11147' 12585' 3-3/4" 100 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 11198' 11110' MD TVD MD TVD 12500' -12520' 10072' - 10074' 12520' - 12540' 10074' - 10075' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 7 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 20, 1999I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO iTEST PERIOD ! Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAwrY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. K2B 11785' 9837' K2M 12013' 9954' K2A 12130' 9995' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32' I hereby certify that,~A treg°ing is true and c°rrect t° the best °f mY kn°wledgeSigned '"' I.(~,,~-~- ~ merrie Rubble Title Technical Assistant III Date ' 1-33B/L-24 98-255 399-007 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility End MPI Well 1-33B/L-24 Rig Doyon 15 Page 1 Date 10 February 99 Date/Time 19 Jan 99 20 Jan 99 21 Jan 99 22 Jan 99 23 Jan 99 16:30-18:00 18:00-19:00 19:00-19:30 19:30-04:30 04:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-11:30 11:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-00:00 00:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-13:00 13:00-14:00 14:00-15:30 15:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:15 19:15-19:30 Duration 1-1/2 hr lhr 1/2 hr 9hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 6-1/2 hr 1/2 hr 2hr 1-1/2 hr 2hr 3-1/2 hr lhr 1-1/2 hr 1/2 hr llhr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 7-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr lhr 1-1/2 hr lhr 1/2hr 1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr Activity Skid rig Held safety meeting Held safety meeting Rig moved 100.00 % Skid rig Held safety meeting Serviced Main engine Rigged up Lubricator Removed Hanger plug Installed Hanger plug Removed Xmas tree Rigged up All functions Held safety meeting Rigged up High pressure lines Rigged down Iron roughneck Serviced Top drive Rigged up Drillfloor / Derrick Tested Adapter spool Installed BOP test plug assembly Held safety meeting Tested All functions Rigged up Lubricator Held safety meeting Retrieved Hanger plug Rigged down Lubricator Installed Wear bushing Rigged up Flowline Made up BHA no. 1 R.I.H. to 530.0 ft Circulated at 530.0 ft Singled in drill pipe to 4360.0 ft Held safety meeting Singled in drill pipe to 11700.0 ft Washed to 11754.0 ft Milled Casing at 11756.0 ft Held safety meeting Milled Casing at 11757.0 ft Flow check Pulled out of hole to 86.0 ft Pulled BHA Rig waited: Equipment Held safety meeting Rig waited: Equipment Made up BHA no. 2 R.I.H. to 8636.0 ft Serviced Block line R.I.H. to 11674.0 ft Laid down 93.0 ft of 2-3/8in OD drill pipe Singled in drill pipe to 93.0 ft Serviced Top drive Circulated at 11745.0 ft Held safety meeting Circulated at 11745.0 ft Flow check Progress Report Facility End MPI Well 1-33B/L-24 Rig Doyon 15 Page 2 Date 10 February 99 Date/Time 24 Jan 99 25 Jan 99 26 Jan 99 27 Jan 99 19:30-21:00 21:00-21:15 21:15-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-13:00 13:00-14:30 14:30-16:30 16:30-19:30 19:30-21:00 21:00-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-23:30 23:30-00:00 00:00-00:30 00:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-15:30 15:30-15:45 15:45-17:30 17:30-19:00 19:00-19:15 19:15-23:30 23:30-00:30 00:30-02:00 02:00-02:30 02:30-03:15 03:15-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-10:30 10:30-11:00 11:00-13:30 13:30-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-21:30 21:30-06:00 Duration 1-1/2 hr 1/4 hr 5-3/4 hr lhr 2hr 1/2hr 6-1/2 hr 1-1/2 hr 2hr 3hr 1-1/2 hr 5-1/2 hr lhr 1/2 hr 2hr 1/2 hr 2-1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 5hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 9hr 1/4 hr 1-3/4 hr 1-1/2 hr 1/4hr 4-1/4 hr lhr 1-1/2 hr 1/2 hr 3/4 hr 1/4 hr 2-1/2 hr 1/2hr lhr 2-1/2 hr 1/2hr 1/2hr 2-1/2 hr 2hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 8-1/2 hr Activity Fished at 11753.0 ft Flow check Pulled out of hole to 86.0 ft Pulled BHA Rig waited · Equipment Held safety meeting Rig waited · Equipment Rigged up Lubricator Serviced Other sub-surface equipment Rig waited · Equipment Serviced Other sub-surface equipment Set downhole equipment (wireline) Rigged down Rigging equipment Made up BHA no. 3 R.I.H. to 5800.0 ft Held safety meeting R.I.H. to 11724.0 ft Circulated at 11710.0 ft '"-"-*Milled Casing at 11729.0 ft Circulated at 11729.0 ft Flow check Held safety meeting Pulled out of hole to 86.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 11715.0 ft Washed to 11724.0 ft Reamed to 11729.0 ft Held safety meeting Milled Casing at 11734.0 ft Flow check Pulled out of hole to 9296.0 ft Rig waited · Production facilities Flow check Pulled out of hole to 86.0 ft Pulled BHA Racked back drill pipe Serviced Top drive Made up BHA no. 5 Tested MWD - Via string R.I.H. to 7250.0 ft Held safety meeting Serviced Block line R.I.H. to 11700.0 ft Circulated at 11700.0 ft Set tool face Drilled to 11752.0 ft Repaired Top drive Set tool face Drilled to 11769.0 ft Held safety meeting Drilled to 11794.0 ft Serviced Fuel oil supply Drilled to 11860.0 ft Progress Report Facility End MPI Well 1-33B/L-24 Rig Doyon 15 Page 3 Date 10 February 99 Date/Time 28 Jan 99 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 29 Jan 99 06:00-06:30 06:30-15:30 15:30-15:45 15:45-16:00 16:00-18:00 18:00-18:30 18:30-22:30 22:30-23:30 23:30-23:45 23:45-00:00 30 Jan 99 00:00-03:00 03:00-03:15 03:15-03:30 03:30-04:45 04:45-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-18:00 18:00-18:30 18:30-06:00 31 Jan99 06:00-06:30 06:30-09:30 09:30-10:00 10:00-10:30 10:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-23:30 23:30-06:00 01 Feb 99 06:00-06:30 06:30-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-01:00 02 Feb 99 01:00-01:30 01:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-18:00 18:00-18:30 18:30-01:00 03 Feb 99 01:00-02:30 02:30-06:00 06:00-06:30 06:30-08:00 Duration 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 9hr 1/4 hr 1/4 hr 2hr 1/2 hr 4hr lhr 1/4 hr 1/4 hr 3hr 1/4 hr 1/4 hr 1-1/4 hr 1/4hr lhr 1/2hr 4-1/2 hr 7hr 1/2 hr 11-1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 6hr lhr 1/2 hr 1/2 hr 5hr 6-1/2 hr 1/2 hr 8hr 3hr 1/2hr 1/2hr 6-1/2 hr 1/2hr 1/2 hr 3-1/2 hr 1/2hr 1/2 hr lhr 10-1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr Activity Held safety meeting Drilled to 11942.0 ft Held safety meeting Drilled to 12020.0 ft Held safety meeting Drilled to 12051.0 ft Held safety meeting Flow check Pulled out of hole to 8000.0 ft Held safety meeting Pulled out of hole to 115.0 ft Pulled BHA Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 6 Tested MWD - Via string R.I.H. to 2963.0 ft Held safety meeting R.I.H. to 12051.0 ft Drilled to 12100.0 ft Held safety meeting Drilled to 12205.0 ft Held safety meeting Drilled to 12222.0 ft Serviced Top drive Flow check Pulled out of hole to 115.0 ft Pulled BHA Made up BHA no. 7 Held safety meeting R.I.H. to 12222.0 ft Drilled to 12266.0 ft Held safety meeting Drilled to 12326.0 ft Circulated at 12326.0 ft Drilled to 12329.0 ft Held safety meeting Pulled out of hole to 114.9 ft Pulled BHA Made up BHA no. 8 R.I.H. to 11700.0 ft Serviced Block line Held safety meeting R.I.H. to 12326.0 ft Drilled to 12418.0 ft Held safety meeting Drilled to 12495.0 ft Circulated at 12495.0 ft Pulled out of hole to 5300.0 ft Held safety meeting Pulled out of hole to 115.0 ft Progress Report Facility End MPI Well 1-33B/L-24 Rig Doyon 15 Page 4 Date 10 February 99 Date/Time 08:00-09:00 09:00-09:30 09:30-14:00 14:00-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-22:30 22:30-00:30 04 Feb 99 00:30-01:00 01:00-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-16:00 16:00-18:00 18:00-18:30 18:30-23:00 23:00-01:30 05 Feb 99 01:30-06:00 06:00-06:30 06:30-08:00 08:00-13:30 13:30-14:00 14:00-14:30 14:30-19:30 19:30-20:30 20:30-21:00 21:00-00:00 06 Feb 99 00:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:30 08:30-11:00 11:00-11:30 11:30-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-22:00 22:00-01:00 07 Feb 99 01:00-01:30 01:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-09:00 09:00-14:30 14:30-15:00 Duration lhr 1/2 hr 4-1/2 hr 1/2 hr lhr 1/2hr 2hr 1/2 hr 4hr 2hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 1/2 hr 5-1/2 hr lhr 3hr 2hr 1/2 hr 4-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2hr 5hr lhr 1/2hr 3hr 6hr 1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr 1/2hr 4hr 1-1/2 hr lhr 1/2 hr 3-1/2 hr 3hr 1/2 hr lhr 1/2hr 3hr 1/2 hr 2-1/2 hr 5-1/2 hr 1/2hr Activity Pulled BHA Made up BHA no. 9 R.I.H. to 11700.0 ft Circulated at 11700.0 ft R.I.H. to 12475.0 ft Washed to 12495.0 ft Drilled to 12528.0 ft Held safety meeting Drilled to 12585.0 ft Circulated at 12585.0 ft Pulled out of hole to 11700.0 ft Reamed to 11220.0 ft Circulated at 11220.0 ft R.I.H. to 12585.0 ft Circulated at 12585.0 ft Held safety meeting Pulled out of hole to 115.0 ft Pulled BHA Rigged up sub-surface equipment - Formation logs R.I.H. to 3500.0 ft Held safety meeting R.I.H. to 11420.0 ft Rigged up sub-surface equipment - Formation logs Ran logs on tubulars Held safety meeting Ran logs on tubulars Circulated at 11272.0 ft Pulled out of hole to 11090.0 ft R.I.H. to 11565.0 ft Circulated at 11565.0 ft Pulled out of hole to 10615.0 ft R.I.H. to 11565.0 ft Circulated at 11565.0 ft Pulled out of hole to 1900.0 ft Held safety meeting Pulled out of hole to 154.0 ft Rigged down sub-surface equipment - Formation logs Made up BHA no. 10 R.I.H. to 6000.0 ft Circulated at 6000.0 ft R.I.H. to 11652.0 ft Circulated at 11652.0 ft R.I.H. to 11969.0 ft Held safety meeting R.I.H. to 12585.0 ft Circulated at 12585.0 ft Pulled out of hole to 11650.0 ft Serviced Block line R.I.H. to 12585.0 ft Circulated at 12585.0 ft Held safety meeting Pumped out of hole to 11700.0 ft Pulled out of hole to 67.0 ft Pulled BHA Progress Report Facility End MPI Well 1-33B/L-24 Rig Doyon 15 Page 5 Date 10 February 99 Date/Time 08 Feb 99 09 Feb 99 15:00-16:30 16:30-17:30 17:30-18:00 18:00-22:00 22:00-22:30 22:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-10:00 10:00-10:30 10:30-11:30 11:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-03:00 03:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-12:00 12:00-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:00 21:00-04:00 Duration 1-1/2 hr 1 hr 1/2 hr 4hr 1/2 hr 5-1/2 hr lhr lhr 1/2 hr 1/2 hr 3hr 1/2 hr lhr 1-1/2 hr lhr 4hr 1/2 hr 8-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 5-1/2 hr 4hr 2hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 7hr Activity Installed BOP stack Rigged up Casing handling equipment Held safety meeting Ran Liner to 1445.0 ft (2-7/8in OD) Circulated at 1445.0 ft Ran Drillpipe on landing string to 11700.0 ft Circulated at 11700.0 ft Ran Drillpipe on landing string to 12585.0 ft Held safety meeting Ran Drillpipe in stands to 12585.0 ft Circulated at 12585.0 ft Held safety meeting Mixed and pumped slurry - 20.000 bbl Circulated at 11147.0 ft Rigged down Cement head Laid down 4293.0 ft of 2-3/8in OD drill pipe Held safety meeting Laid down 8564.0 ft of 2-3/8in OD drill pipe Freeze protect well - 6.500 bbl of Diesel Installed Hanger plug Installed BOP stack Held safety meeting Rigged down Drillfloor / Derrick Removed BOP stack Installed Xmas tree Held safety meeting Retrieved Hanger plug Tested Liner Installed Hanger plug Cleared Mud shakers Endicott, AK Camco Coiled Tubing Well: Endicott 1-33b/L-24 Engineer: Kirby Walker AFE #: 727027.2 Gen/Sub/Elem: Sidetrack / Comp / CTU Summary: Mill Run - Jewelry/GR log - Perforate 2/18/99 - MIRU Camco CTU (16,924', 38.5 bbl). MU BHA #1 and pull/pressure test. RIH pumping seawater at minimum rate to clear methanol from coil. Tag liner lap at 11,135' (-20' shallow). Continue in hole and see weight loss at 12,500'. No hard tag, presumed to be cement contaminant. Wash to 12,527'; see sign of milling. Appears to be bottom. Pump 30 bbls while on bottom and begin POOH swapping well over to seawater freeze protecting top 500' with methanol. MU BHA #2 and RIH to 10,850' (-100' above bottom GLM). Begin logging to TD. Tag bottom at 12,526' and flag pipe. POOH logging 200' repeat. Return to TD and POOH logging to 10,850'. POOH. Data looks good. 2/19/99 - MU first gun assembly with 20' of SWS 1-11/16" guns. RIH to TD, tag, adjust depth and pull into position. Drop ball and fire guns perforating 12,519' - 12,539'. POOH 100' and flag pipe for next run. POOH. MU BHA #4 and RIH to flag. Adjust depth and drop ball. Position coil and perforate next interval from 12,499' - 12,519'. POOH. RDMO Camco CTU. Initial Well Conditions: SITP220 I FWHPo I lAP OAP I TEMP 0 7O 10:00 38 Load coil and pressure test to 4000 psi. 11:15 0.3 400 265 Start RIH w/BHA #1 displacing methanol down FL. 11:35 3000 0.5 1100 265 Pick up - 5,200# 12:00 6050 0.5 1200 265 Pick up - 9,700# 12:39 11135 - 730 265 Set down on liner lap. Pick up - 21,500# 12:40 11110 0.4 890 260 Restart pump and attempt to get through liner. Made it. 12:55 12000 0.45 900 262 Pick up - 22,500#. 13:05 12500 0.45 985 265 Tag. S/D pump retag. Seems to be soft. 13:08 12500 1.5 2670 265 52.5 Start mill. Ease into it. 13:14 12525 1.5 2520 265 Pick up - 26,300#. 13:16 12495 1.5 2650 265 Start back in hole milling. 13:18 12527 1.5 2845 265 See sign of milling...bottom. Pick up - 27,000#. 13:32 12527 1.5 2557 265 210 POOH. Swapping well over to seawater. 15:00 4355 1.5 2834 270 Swap to methanol. POOH FP top 500'. 15:26 500 1.5 3420 262 38 Methanol at end of coil. 15:30 0 290 260 48 On surface with coil. SI swab. Rig off BHA #1. 17:15 Pull/pressure test BHA #2. Hold safety meeting with SWS. 17:05 0 0 315 254 RIH w/BHA #2. 17:43 5000 0 483 264 Park coil. Calibrate SWS depth counter. Pick up - 8,000# 18:30 10850 0 830 254 Start logging. 18:45 11900 0 875 250 Pick up - 20,000# 18:53 12526 0 789 260 On bottom with coil. Park coil, flag pipe. SWS depth is on. 18:57 12526 0 791 250 POOH logging repeat pass. 19:00 12323 0 725 250 RIH to bottom. 19:05 12526 0 760 250 Tag bottom. POOH logging. 19:34 10850 0 40 250 35 Park coil. Stop logging. POOH. FP coil and well to 500'. 20:45 0 0 100 100 On surface with coil. Rig off for the night. Data looks good. 2/19 06:00 On location. MU BHA #3. Pull/pressure test. Hold pre job safety meeting with crew. 07:30 0 0 50 122 RIH with BHA #3. 08:53 11000 0 720 240 Pick up - 18,600' 09:00 11500 0 735 250 Pick up - 19,800' 09:10 12540 0 700 250 Tag TD (adjust depth) 09:21 12539 1.5 3275 250 Drop ball and begin pumping. 09:40 12539 0.65 1225 245 Slow rate. 09:42 12539 0 1250 250 31.4 Seat ball. S/D. Shut in wing. 10:00 12539 0.75 725 276 38 Fire guns at 4,400 psi perforating from 12,520' - 12,540'. S/D pump. Close wing. POOH. 10:05 12439 0 520 150 Flag pipe for next run. 11:36 0 0 32 5 On surface with coil. Verify guns fired. RO BHA #3. Re- pressure test connector. 13:05 0 0 0 0 Radius here with new connection. 13:40 0 0 0 0 MU BHA #4; pull and pressure test. 13:53 0 0 98 250 RIH w/BHA #4. 15:20 12020 0 427 257 Pick up - 22,100#. 15:27 12439 0 557 257 Tie into depth of flag. 15:33 12483 1.5 2970 257 Drop ball. Start pumping and pull into position. 16:00 12519 0.7 1135 264 Slow rate. 16:07 12519 0.7 3600 270 30 Ball on seat (28.5 bbl). Fire guns. Close wing. POOH. 17:52 0 60 285 On surface with coil. RDMO Camco. Initial Well Conditions: SITP350 FWHPN/A I lAP0 OAP0 TEMP60 I Fluids: I Seawater (slicked) 210 bbls I Methanol 189 bbls BHA #1 Cement Mill Tool OD ID Length CT Connector 2.20 1.0 Dual Checks 2.20 1.0 Disconnect 2.20 0.75 Circ Sub 2.20 2 1/8" Motor 2.125 N/A X-O 2.20 N/A Bit (3 holes / blades) 2.25 0.86 1.65 6.77 0.275 0.41 Total 9.965' BHA#2 Logging Tool String Tool OD ID Length CT Connector 1.9 1.0 Dual Checks 1.75 1.0 Disconnect - 5/8" ball 1.75 9/16 Circ Sub - Y2" ball 1.75 7/16 1.866 X-O 1.75 N/A 0.46 Knuckle Joint 1.73 N/A 0.94 Battery Pack 1.375 N/A 3.04 MPL Adapter 1.375 N/A 4.10 CCL 1.375 N/A 2.07 Gamma Ray 1.375 N/A 2.95 Total 15.426' BHA #3 and #4 Perforating Tool String Tool OD ID Length CT Connector 1.9 1.0 0.22 Dual Checks 1.75 1.0 Disconnect - 5/8" ball 1.75 1.71 X-O and Firing Head (1" MT Box facing up) 1.69 3.42 I 11/16, 4 spf 20J UJ HMX (1/2" ball) 1.56 N/A 20.70 Bottom Nose 2.20 N/A 1.15 Total 27.20' Perforating Data Top Bottom Gun SPF EHD Penetration 12,520' 12,540' 1-11/16" 20J UJ HMX 4 0.22" 9.2" 12,500' 12,520' 1-11/16" 20J UJ HMX 4 0.22" 9.2" North Slope Alaska Alaska State Plane Zone 3 Endicott DI-MPI, Slot 1-33B/L-24 1-33B/L-24 Job No. AKMW90066, Surveyed: 3 February, 1999 ORI'GINAL SURVEY REPORT 23 February, 1999 Your Reft API-500292257702 KBE-55.50 Surface Coordinates: 5982350.76 N, 259089.08 E (70° 21' 08.7442" N, 147° 57' 23.0202" W) DRI I..~LI N G SEll;VICES A HALL~TON COh~PA~'~ Survey Reft svy903 Sperry-Sun Drilling Services Survey Report for 1-33B/L-24 Your Ref: API-500292257702 Job No, AKMW90066, Surveyed: 3 February, 1999 North Slope Alaska Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) Vertical Depth (ft) 11699.50 36.200 110.510 9718.34 9773.84 11719.00 36.340 110.640 9734.06 9789.56 11752.06 44.690 103.000 9759.19 9814.69 11786.20 49.920 96.430 9782.34 9837.84 11819.55 52.920 91.000 9803.15 9858.65 11848.11 54.600 86.960 9820.04 9875.54 11882.16 57.400 82.480 9839.08 9894.58 11910.37 61.400 76.520 9853.45 9908.95 11940.78 63.050 68.670 9867.64 9923.14 11974.94 66.150 58.280 9882.32 9937.82 12006.19 67.930 49.410 9894.53 9950.03 12038.61 68.870 39.440 9906.49 9961.99 12070.75 69.540 33.470 9917.91 9973.41 12101.41 67.690 26.190 9929.10 9984.60 12132.73 68.590 18.040 9940.78 9996.28 12165.30 70.620 13.510 9952.14 10007.64 12196.14 72.060 10.710 9962.00 10017.50 12225.86 75.060 7.440 9970.42 10025.92 12260.64 75.860 5.370 9979.15 10034.65 12287.54 76.720 5.170 9985.53 10041.03 12322.27 77.820 5.300 9993.18 10048.68 12354.86 83.240 358.310 9998.54 10054.04 12386.32 83.310 354.200 10002.23 10057.73 12415.20 82.230 350.950 10005.87' 10061.37 12448.07 83.120 341.650 10010.07 10065.57 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1375.61S 5800.40 E 5980789.36 N 264842.25 E 1379.66 S 5811.20 E 5980784.96 N 264852.91 E 1385.75 S 5831.74 E 5980778.22 N 264873.25 E 1389.92 S 5856.45 E 5980773.26 N 264897.81 E 1391.58 S 5882.45 E 5980770.76 N 264923.74 E 1391.16 S 5905.47 E 5980770.44 N 264946.77 E 1388.54 S 5933.56 E 5980772.15 N 264974.93 E 1384.10 S 5957.41 E 5980775.83 N 264998.91 E 1376.05 S 5983.05 E 5980783.05 N 265024.79 E 1362.26 S 6010.59 E 5980795.94 N 265052.76 E 1345.29 S 6033.78 E 5980812.15 N 265076.49 E 1323.80 S 6054,84 E 5980832.96 N 265098.23 E 1299.64 S 6072.68 E 5980856.53 N 265116.84 E 1274.90 S 6086.88 E 5980880.80 N 265131.82 E 1248.00 S 6097.81 E 5980907.34 N 265143.61 E 1218.63 S 6106.10 E 5980936.43 N 265152.84 E 1190.06 S 6112.22 E 5980964.78 N 265159.88 E 1161.92 S 6116.71 E 5980992.76 N 265165.27 E 1128.47 S 6120.47 E 5981026.08 N 265170.10 E 1102.45 S 6122.87 E 5981052.01N 265173.33 E 1068.71S 6125.96 E 5981085.63 N 265177.51 E 1036.61S 6126.95 E 5981117.68 N 265179.53 E 1005.44 S 6124.9'1E 5981148.90 N 265178.50 E 977.04 S 6121.21 E 5981177.41 N 265175.71 E 945.40 S 6113.50 E 5981209.28 N 265169.02 E Alaska State Plane Zone 3 Endicott DI-MPI Dogleg Rate (°/lOOff) Vertical Section (ft) Comment 0.819 29.344 20.836 15.581 12.835 13.657 23.052 23.470 28.924 26.743 28.734 17.489 22.915 24.319 14.448 9.787 14.602 6.203 3.278 3.188 26.903 12.976 11.773 28.193 -578.68 -581.24 -584.49 -585.28 -583.41 -579.88 -573.49 -565.86 -554.42 -537.03 -517.09 -492.94 -466.59 -440.16 -412.03 -381.81 -352.68 -324.19 -290.53 -264.42 -230.58 -198.64 -168.04 -140.39 -110.09 Tie-On Point Window Point Continued... 23 February, 1999 - 11:09 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 1-33B/L-24 Your Ref: API-500292257702 Job No. AKMW90066, Surveyed: 3 February, 1999 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12481.37 82.430 336.350 10014.26 10069.76 914.57 S 6101.66 E 5981240.47 N 265158.18 E 12510.02 84.540 333.490 10017.51 10073.01 888.80 S 6089.60 E 5981266.62 N 265146.95 E 12541.76 87.940 331.370 10019.59 10075.09 860.73 S 6074.94 E 5981295.15 N 265133.20 E 12585.00 87.940 331.370 10021.14 10076.64 822.80 S 6054.24 E 5981333.72 N 265113.73 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 28.245° (03-Feb-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 7.771° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12585.00ft., The Bottom Hole Displacement is 6109.89ft., in the Direction of 97.739° (True). Alaska State Plane Zone 3 Endicott DI-MPI Dogleg Rate (°/100ft) Vertical Section (ft) Comment 15.924 12,353 12,616 0.000 -81.14 -57.23 -31.40 3.38 Projected Survey Continued... 23 February, 1999 - 11:09 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1-33B/L-24 Your Ref: API-500292257702 Job No. AKMW90066, Surveyed: 3 February, 1999 North Slope Alaska Alaska State Plane Zone 3 Endicott DI-MPI Comments Measured Depth (ft) 11699.50 11719.00 12585.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9773.84 1375.61 S 5800.40 E 9789.56 1379.66 S 5811.20 E 10076.64 822.80 S 6054.24 E Comment Tie-On Point Window Point Projected Survey 23 February, 1999 - 11:09 - 4 - DrlllQuest ri F:t I LI_I IM G WELL LOG TRANSMITTAL To: State of Alaska March 18, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 q"~' ~ ~ ~'-'~ q ~ O~ MWD Formation Evaluation Logs - 1-33B / L-24, AK-MW-90066 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG tbrmatted Disc with verification listing. API#: 50-029-22577-02 :~ar~a C~J & Gas Cons. Commission ~,~0rage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson(~ DATE: January 29, 1999 Chairman THRU: Blair Wondzell, ~ P. I. Supervisor FROM: Lou Grimaldit~,,.~ SUBJECT: Petroleum Ins~)ector FILE NO: AKHJG 1FE.DOC BOPE Test Doyon 15 BPX well #1-33B/L-24 Endicott Field PTD #98-255 Friday, January 29, 1999: I witnessed the weekly BOPE test on Doyon rig 15 which was performing a T.T.R.D. (through tubing redrill) on BPX well #1- 33B/L-24 in the Endicott field. The rig was not ready to test when I arrived but was breaking down the bottom hole assembly and started within two hours. All BOPE equipment was tested with no failures observed. The Gas detectors were calibrated and checked the following morning with the results faxed to our North Slope office. The test time of 4 hours is average for this rig. The rig was in good shape and I saw cleaning being performed throughout the rig. The area surrounding the rig was clear and kept neat and clean. SUMMARY: I witnessed the weekly test of the BOPE on Doyon rig #15 which is redrilling BPX well #1-33B/L-24 in the Endicott Field. There were no failures observed. Test time 4 hours. Attachments' AKHJA3GF.XLS CC: John Rail (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: BPX Well Name: 1-33B/L-24 Casing Size: Set @ Test: Initial Weekly Rig No. 15 PTD # 98-087 Rep.: Rig Rep.: Location: Sec. X Other DATE: Rig Ph.# James Carlisle 1/29/99 659-6770 Jim Willingham 36 T. 12N R. 16E Meridian Umiat MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: P Well Sign P Upper Kelly/IBOP Housekeeping: P (Gen) Drl. Rig P Lower Kelly/IBOP PTD On Location P Hazard Sec. P Ball Type Standing Order Posted P Inside BOP Test Quan. Pressure 1 250/5,000 250/5,000 250/5,000 250/5,000 P/F BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F ./ 250/2500 P 1 250/5,000 P 1 250/5, 000 P 1 250/5,000 P 3 250/5, 000 P 2 250/5,000 P 1 250/5, 000 P N/A 250/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P 3it Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves '/7 No. Flanges 42 Manual Chokes 2 Hydraulic Chokes '/ Test Pressure P/F 250/5,000 P 250/5,000 P Functioned Functioned P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,900 P 1,900 P minutes 27 sec. minutes 42 sec. P Remote: P Four Bottles 2600 avg Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659..3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test. Gas detectors tested following day and results faxed to N.S. office. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X' NO Waived By: Witnessed By: AKHJA3GF.xls Louis R. Grimaldi FI-021L (Rev.12/94) ._ STATE OF ALASKA ALASKA ~'~ AND GAS CONSERVATION COMT~TiSSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM 5. Type of well: [~ Development [] Exploratory [] Stratigraphic E~]Service 6. Datum Elevation (DF or KB) Plan KBE = 56.0' At top of productive interval 2155' NSL, 912' WEL, SEC. 31, T12N, R17E, UPM (Planned) At effective depth At total depth 2654' NSL, 1054' WEL, SEC. 31, T12N, R17E, UPM (Planned) 12. Present well condition summary Total depth: measured 12165 feet true vertical 9962 feet Effective depth: measured 11760 feet true vertical 9823 feet Plugs (measured) Junk (measured) 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 1-33B/L-24 9. Permit Number 98-255 10. APl Number 50-029-22577-02 11. Field and Pool Endicott Field / Endicott Pool Fish (Jars) at 12112' Casing Length Size Structural Conductor 91' 30" Surface 4974' 10-3/4" Intermediate Production 12365' 7-5/8" Liner Cemented MD TVD BKB BKB Driven 130' 130' 1725 c.f. PF, 690 c.f. Class 'G' 5013' 4390' 559 c.f. Class 'G' 12404' 10329' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) RECEIVED JAN 1,5 1999 Alaska 0il & Gas eons. Commission Anol~r~ge 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: January 14, 1999 16. If proposal was verbally approved [~ Oil [] Gas [] Suspended · ..- i /~ I(1'~/~ Service Name of approver ~ ~ate approved Contact Engineer Name/Number: Jeff Hupp, 564-56~.~ Bryan McLellan, 564-5516 Prepared By Name/Number: Carol Withey, 564-4114 17. I hereby certify that the foregoin, g is true and correct to the best of my knowledge Signed UaveCookin~'~~~~ '~/~'¢ Title Drilling Superintendent Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date Plug integrity__ BOP Test ~ Location clearance__ Mechanical Integrity Test __ Subsequent form requir 10- j,/.~Commissioner ORIGINAL SIGNED' BY r~, .................... ~.O. ¥.., Approved by order of the Commission ,-,_,.,.~ kl phHet,~n~nn / Form 10-403 Rev. 06/15/88 Submit In Triplicate l Well Name: J1-33B/N-24 REVISED SUMMARY PROCEDURE The procedure was revised to reflect milling the window with a service coil unit prior to Doyon Rig #15 moving on the well. COMMENTS 1. The 7-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. 2. The existing perforations and previous sidetrack windows are plugged with cement. 3. This well will be sidetracked at app. 11,750 md. PRE-RIG OPERATIONS 1. Test 4-1/2" tbg hanger void area to 3500 psi. Test 7-5/8" packoff to 3500 psi. 2. Pressure test IA and wellhead packoff (tubing and annulus) to 3,500psi. 3. RU slickline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 4. RU a coil tubing unit and underream cement from 11511-11765' MD (Planned whipstock depth). 5. RU Slickline. Tag cement top and correct top tbg tail depth. RU e-line and set bottom of mechanical TTRD whipstock at 11750' ELM. 6. RU a coil tubing unit and test BOP equipment. Rig up to take returns through a well flow line. 7. Pick up 3.80" Window mill assembly on CT. Tag whipstock top. Mill window at 11760' MD with the CT unit using seawater. 8. Displace well with kill weight mud prior to POH with the window milling assembly. 9. After monitoring well for no pressure, set BPV. Remove flowline, level pad, dig out cellar. RIG OPERATIONS (SUMMARY) MPI 1-33B/L-24 4 01/13/99 1. . . . 7. . . 10. 11. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. Pull BPV. If not dead, attempt to bleed off. If pressure will not bleed off, RU slickline & pull btm GLV Circulate well w/KW brine until dead. Reset GLV. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. Pick up directional BHA 2-3/8" SLH-90 Drill pipe. RIH to just above window. Condition mud to 9.5 ppg Quikdril while starting kickoff. Orient BHA to build and turn @ 24°/100 feet to 99° at appx 12200' MD. Drop and turn well @ 12°/100 feet to 70° at TD (12899' MD/10156' TVD). Drill ahead as specified by the rig supervisor to TD. POOH. If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. Pick up and run Slim-Access DPC logging tools if the well condition allow. Run a 2.875" solid liner from 11,150' to TD, cement as per plan with 21+/- BBL of cement. Pump plug w/KW brine. POOH and WOC. The 2-7/8" liner may be perforated with rig depending on the interval to be perforated. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. MPI 1-33B/L-24 5 01/13/99 BP Exploration / Arco Alaska Date: To: Attn: Reference: From: January 13, 1998 Alaska Oil & Gas Conservation Commission Blair Wondzell Endicott Well, 1-33B/L-24, Permit #98-255 APl 50-029-22577-02 Jeff Hupp Senior Drilling Operations Engineer Blair: The attached Application for Sundry Approval identifies a change to our approved drilling program. We have not yet moved to this well location but anticipate doing so this evening. A summary of the revised operations is attached for your review and approval. Thank you. Atta~c~e~f/ Cc: Well File TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 21, 19898 Dave Cocking Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Duck Island 1-33B/L-24 BP Exploration (Alaska) Inc. Permit No: 98-255 Sur Loc: 32177qSL, 2114'vVEL, Sec. 36, T12N, R16E, UM Btmholc Loc. 2654~SL, 1054'WEL, Sec. 31, T12N, R17E, UM Dear Mr. Cocking: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissione BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ hared 8~. hervices ~,~,1~.~¢_~ *~m¢~ rill in a Exploration / Arco Alaska Date: December 15, 1998 To: Attn: Alaska Oil & Gas Conservation Commission Mr. Blair Wondzell / Mr. David W. Johnston Reference: Rush Permit Fro m: Jeff Hupp Senior Drilling Operations Engineer Mr. Wondzell and Mr. Johnston: The Endicott Asset Group is requesting your review and approval of the attached permit, 1-33B/L-24 by December 23, 1998. Although we will not spud the well until December 29, the approaching holiday season has required us to move our pre- spud meeting to December 24, 1998. The meeting is designed to review the drilling plan and discuss the approved permit with management and drilling personnel. Thank you for accommodating us on such short notice. Please contact me if you have questions at 564-5606. '~c: W ellF~il '~ STATE OF ALASKA ALASKA ~-,,.,_ AND GAS CONSERVATION corv-.~..¢lSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56.0' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL312828 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 2155' NSL, 912' WEL, SEC. 31, T12N, R17E, UPM 1-33B/L-24 At total depth 9. Approximate spud date Amount $200,000.00 2654' NSL, 1054' WEL, SEC. 31, T12N, R17E, UPM 12/29/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL047502I 1-65/N-25, 1044' at 11760' MD aprox. 4300 12846' MD / 10050' TVDSS 16. To be completed for deviated wells 17. Anticipated pressure [see 20 AAC 25.035 (e) (2)} Kick Off Depth 11735' MD Maximum Hole Angle 83° Maximum surface 3599 ps/g, At total depth (TVD) 9781' / 4577 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 1798' 11048' 9300' 12846' 10050' 119 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12165 feet Plugs (measured) true vertical 9962 feet Effective depth: measured 11760 feet Junk (measured) Fish (Jars) at 12112' true vertical 9823 feet Casing Length Size Cemented MD TVD Structural BKB BKB Conductor 91' 30" Driven 130' 130' Surface 4974' 10-3/4" 1725 c.f. PF, 690 c.f. Class 'G' 5013' 4390' Intermediate Production 12365' 7-5/8" 559 c.f. Class 'G' R~c~VED 12404' 10329' Liner 0 - 'j998 Perforation depth: measured N/A Aiaska 0il & Gas Cons. 60mmissi0r~ true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , Contact Engineer Name/Number: Jeff Hupp, 564-5606- ~'~~J Bryan McLellan, 564-5516 Prepared By Name/Number: Carol W/they, 564-4114 211 hi,e~y /,,~7'/~~ F~ certify that the fore oing is true and coFrect to the best of my knowledge · S"g DaveCook~.g ~ Title Drilling Superintendent Date Commission Use Only Permit Number I APl Number Approval Date/. ,,,, I See cover letter /~'~"~ --~'-~'I 50- ~,.2., ~-' 2.. ~ .5"~.~-- <::~.2~ /,¢~---¢~/-' ~', for other requirements Conditions of Approval: Samples Required []Yes I~ No Mud Log Required []Yes [] No Hydrogen Sulfide Measures []Yes J~ No Directional Survey Required []Yes [] No Required Working Pressure for BOPE []2K; []3K; []4K; J~5K; [] 1OK; [] 15K Other: by order of Original Signed 67 Commissioner the commission Date Approved By _~f!d w .!~hn~t~n Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: ! 1-33B/L-24 Well Plan Summary Type of Well (Producer or injector): ITl'RD SIDETRACK Producer I Well Design (Conventional, slimhole, etc.): FSL FEL SEC TWP RNG Surface Location: 3217 2114 36 12N 16E Top of Kekiktuk is above KOP: Target 1 Location: 2155 912 31 12N 17E Target 2 - Bottom Hole Location: 2654 1054 31 12N 17E I~F~ Number: 1727027.2 I I Rig:I ~O¥O~ ~S I Estimated Start Date:~e~m~r 24' ~S I I OP~t~g a~Y~ t° a~m a~dcomplete: [~+a Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =3599 psi TOP WEST SAK Above KOP TOP SEABEE/AYLYAK Above KOP TOP SHALE WALL/TUFFS Above KOP TOP HRZ Above KOP BASE HRZ Above KOP PUT RIVER Above KOP LCU Above KOP KEKIKTUK- Top 3A2S 9.3 ppg Above KOP 3Al (KOP) 11,735 9,747 KOP K2B(2900F) 11,779 9,781 9.0 ppg 4577 psi @ 9781' TVDss K2M (2400SB) 11,994 9,895 K2A (2300F) 12,146 9,950 8.7 ppg 4519psi @ 9990' TVDss Target CGOC 12,146 9,950 TD 12,846.35 10,050 Logging Program: Logs: MWD-GR 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: GR/Res NA Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 1,798 11,048/9,300 12,846/10,050 TBG* 4.5" 12.6 13CR NSCT 11,160 38 11,198/9,439 Note: The existing tubing will be left in place and re-used. The 3.5" tubing tail will have to be milled off, and the 2.875" liner hung 150 feet above the existing packer. Cementing Program (No inner String): Hole Section Liner Size Depth · Volume Cement Production 2.875" Liner from Cement from _+ 18 BBL Class 'G' 11,048' to 12,846' with 11,435' to Actual volume 0.45% Halad-344 2.875" x 4.5" tie back 12,846' based on final 0.2% CFR-3 sleeve in 4.5" tubing. TD 0.25#/sk Super CBL 119 sacks HR-5 as required Yield 1.15 CF/SK Mud Program: Production Mud Properties: [ 3.75" hole section: Quik-Dril-n Depth Density Plastic Yield Tau 0 ph Fluid Flow Rate (PPG) Viscosity Point Loss Res ervoir 10.0 < 10 16 - 25 5 - 6 9.0-9.3 <4 100 Hazards/Concerns WELLHEAD EQUIPMENT Pore pressure (+9.3 ppg EMW) based on offset max SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. High circulating pressures of up to 4500 psig. Close annular clearance causing swab and surge pressures. Excessive Torque to be combated with lubricant additions after testing. Maintain minimum YP of 25 4//100 sq ft Casing Head: Casing Hanger: Tubinghead: X-mas Tree: FMC 10-3/4" X 13 5/8", 5M Flange SSH FMC 7-5/8" Mandrel Hanger FMC 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8" ,5M DIRECTIONAL STATS FOR 7-5/8" CASING ON 1-33B/L-24 Average Angle: Maximum Angle Maximum Dogleg Top of Cement 37° 53° 37" @ 9570' 4.38°/1 O0 @ 4057' 3.41 °/100' @ 4157' 11,500' (Review of bond Io~1) COMMENTS The 7-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. , The existing perforations and previous sidetrack windows are plugged with cement. 3. This well will be sidetracked at app. 11,750 MD . 10. 11. 12. PRE-RIG OPERATIONS 1. The tbg hanger void area and 7-5/8" pack have been tested to 3500 psi. 2. RU slickline, and drift tbg to w/3.80" od drift to top of cement @ 11511' MD. 3. RU Coil tubing unit. RIH w/7-5/8" underreamer on a 2.875" straight motor assembly. Tag cement at 11511' md. Undeream cement down to 11760' md (7- 5/8" whipstock setting depth). 4. PU and tag cement to ensure cement has been underreamed to 11760' md. 5. Freeze protect top 1500' of well with diesel. 6. POH. LD motor assy. Gauge underreamer to ensure cement has milled out of the casing. RD & MO CT unit. 7. RU slickline and run Kinley caliper from 11400 to 11760'. Review log with Kinley representative to ensure Baker whipstock can be set at 11750'. 8. RU SWS e-line unit. MU Baker 7-5/8" through Tubing Mechanical Whipstock. (See attached whipstock procedure for setting details. RIH w/WS assy on e-line. Set whipstock at 11750' md with 15° L orientation. POH and RD SWS e-line unit. Set BPV after observing well for 2 days to ensure well is dead. Remove flowline. Level pad and prep for rig move. RIG OPERATIONS (SUMMARY) . Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. Pull BPV. If not dead, attempt to bleed off. . If pressure will not bleed off, RU slickline & pull btm GLV Circulate well w/brine until dead. Reset GLV. . Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. (1/2 day). . . . . . 10. 11. 12. Pick up 3.80" Window mill assembly and 2-3~8" SLH-90 Drill pipe. Tag whipstock top. Correlate whipstock top to collar log. PU above WS top, open PBL sub and displace seawater to 10.0 ppg Quikdril. Mill window and 5 feet of formation using 10 ppg mud. Pick up directional BHA and RIH to lust above window. Orient BHA to build and turn @ 24.5°/100 feet to 76° at appx 12,224' MD. Continue to build angle @ 12.4°/100 feet to 83.4° at appx 12,324' MD. Drill ahead as specified by the rig supervisor to TD (12,846' MD/10,050' TVD). POOH. If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. Pick up and run Slim-Access DPC logging tools if the well condition allow. Run a 2.875" solid liner from 11,048 MD to TD, cement as per plan with 18+/- BBL of cement. Pump plug w/KW brine. POOH and WOC. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Bryan McLellan Drilling Engineer Senior Drilling Engineer Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS The closest well bore is the original well 1-33a/L-24/M-23 which quickly diverges from the sidetrack. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. PORE PRESSURE / LOST CIRCULATION Production Interval (3.75"): The Kekiktuk Sands (3A) reservoir pressure could be higher than normal at 9.3 ppg (based on well 1-39/P-17 SBHP). The formation also has the potential for lost circulation due to faulting in the area. TTRD wells to date have not experienced lost circulation. Liquid casing and OM seal should be on location to help combat severe lost circulation. Lubricant additions should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. BOPE, and drilling fluid system schematics on file with AOGCC. Waste Disposal Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. Contacts Office Home Drilling Superintendent Dave Cocking 564-4896 Operations Drilling Engineer: Jeff Hupp 564-5606 345-4501 TTRD Team Leader Jeff Hupp 564-5606 345-4501 Production Engineer Scott McEntyre 564-5952 Reservoir Engineer Susan Brown 564-4375 564-5308 Geologist: Brent Voorhees 564-4448 276-1045 Geologist Tina Wells 564-5813 243-4453 Geophysicist: Steve Roberts 564-5911 348~0358 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Carl Thomesen 248-3511 Pager 275-9869 275-9869 275-1337 275-1337 TREE: 4 .o.,, ,CAMERON W 5000 psi WELLHE/. 13 5/8" 5000 psi FMC RT. ELEV = 56.0' ..._~. . ..... BF. ELEV = 18.7' ~ MAX DEV = 40° AT 3742' , 4-1/2", 12.6#/ft, L-80 tbg ~ ~14-- 4-1/2" 'X' NIPPLE/~)fS) __ (3.813" MIN. 11099' ~ ~ 7-5/8" PACKER ~ I 11110' ( TIW HB-BP-T ) 4-1/2" 'X' NIPPLE (HES) (3.813" ID) I 11175' il I <~r~ 4-1/2,, 'XN'NIPPLE -"~ (HES) Milled to 3.80" ID) 11186' --"' 4-1/2" WLE G 1 1 1 98' New Style I ELMD [ 11188' Baker 7-5/8" x 4-1/2" Thru Tbg W$ ~ To be set @ 11750' MD Cement to underreamed down to 11760' md ~ **, . ~~~' 2nd W, ndow f/11780-11786 :-- -'_-' :: .. TD of 2nd attempt ~ ,,--- ........... TOF @ 12112 tag) to 11780' md (22 bbls cmt) ~ ~-"-"* = :-~-'--- ~ TRACKED ALONG CSG TO 11886' 7-5/8", 29.7#/,, I 12404' I ..L-80 NSCC DATE REV. BY (;OMMENTS ENDICOTT WELL 1-33A/N-24 11/24198 JLH Proposed Pre-Rig Schematic APl NO: 50-029-22577-01 11/20/98 J LH Actual P&A Wi now~)iacl ram 8/18/98 JLH Cmt Window Schematic BP EXPLORATION, INC. CURRENT WELL INFORMATION Well Name: 1-33A/N-24 API Number: 50-029-22577 Well Type: Current Status: Producer Shut-in/Sidetrack attempt was aborted. Lost window while drilling. Last H2S Sample: TD / PBTD: Last Tag: BHP: BHT: Kekiktuk: Open Perfs: Yes No X H2S__PPM 12,165'/11,760' 11,760' SLM 4330 psi (ppg EMW) @ '10,000 TVDss (measured) 212°F @ 10,000' ss Perforated? No No Original KB - MSL: Casing Test: Tubing Test: Casing Hanger: Tubing Hanger: BPV Information: Adapter: Tree: Shut In Pressure: 56' (Doyon 15) 3,500 psi MIT on 4/98 2,500 psi on 8/98 FMC 7-5/8" Mandrel hanger FMC 15-5/8" x 4-1/16" Alloy Cameron BPV Type "G" FMC 13-5/8" x 4-1/16", 5M Cameron 4-1/16", 5M (4-1/8" bore) Alloy Tree Surface Casing ) See P.E. "post-perf- Production Casing ) abandonment" handover Tubing ) notes & diagram for info. Tubing Fluid: Annulus Fluid: Freeze protected with diesel to +_ 1500' MD Inner: Diesel freeze protection, 8.6 ppg Seawater packer fluid KOP: Maximum angle: Maximum dogleg: 1,050' MD 40.4° @ 3,742' MD 4.2°/100' @ 1,234' MD MECHANICAL CONDITION Tubing: Casing: OA 4-1/2"12.6/4 CR-13 w/4-1/2" tailpipe. Currently drifted to 3.80" thru tbg. tail. 7-5/8" 29.7#/ft. L-80 NSCC on mandrel hanger 7-5/8" x 4-1/2". No problems; passed MIT @ 3500 psi. 13-3/8" x 7-5/8". Down squeezed with cement. Tested to 2000 psi. Proposed TTRD Sidetrack Information Kickoff Point: BUR/DLS: Target # 1' Target #2: Total Depth: 11,735 MD (see directional profile attached) 24.54°/100' is planned DLS during build Drop @ 7.3°/100, is planned DLS during drop 9,990' TVDss 10,050' TVDss 12,846' MD/10,050' TVDss Anti-Collision Scan Results Operator: BP Exploration Field: Endicott Well: 1-33B/L-24 Rig: Doyon 15 Date : 18:16, 14 Dec 98 Scan of existing interference data set Search Parameters :- Minimum Search Depth(MD): Maximum Search Depth(MD): Search Radius at minimum search depth: Rate of Search Radius increase: 11700.00 ft 12846.35 ft 1200.00 ft 100.00 ft/1000ft Subject Well Plan Description : 1-33B/L-24 Wp6 Subject Well Plan Data Points MD Inc Azm North (ft) (deg) (deg) (ft) 11700.00 36.200 110.490 -1373.78 11735.00 36.445 110.720 -1381.08 11765.00 39.597 107.897 -1387.17 11800 . 00 43 . 950 96 . 758 -1392 . 04 11900.00 60 . 546 73 . 602 -1383 . 70 11944 . 86 69 . 064 65 . 881 -1369 . 58 11945.20 69.064 65.881 -1369.45 12000 . 00 67 . 968 51. 470 -1343 . 05 12100 . 00 69 . 228 25 . 112 -1270 . 74 12200.00 74.330 359.808 -1178.86 12223.86 76.000 354.000 -1155.84 12300.00 81.612 346.255 -1082.35 12323.86 83.406 343.880 -1059.49 12400.00 83.406 343.880 -986.84 12500.00 83.406 343.880 -891.40 12600.00 83.406 343.880 -795.97 12700.00 83.406 343.880 -700.54 12800.00 83.406 343.880 -605.11 12846.35 83.406 343.880 -560.87 East TVD (ft) (ft) 5800.79 9774.32 5820.20 9802.52 5837.64 9826.15 5860.36 9852.28 5937.77 9913.81 5975.74 9932.91 5976.03 9933.03 6019.46 9953.20 6076.43 9990.25 6096.42 10021.98 6095.17 10028.09 6082.33 10042.89 6076.23 10046.00 6055.23 10054.74 6027.65 10066.22 6000.07 10077.71 5972.49 10089.19 5944.91 10100.67 5932.12 10106.00 DLS (deg/100ft) 0.801 11.997 24.544 24.542 24.542 0.000 24.543 24.543 24.541 24.543 12.403 12.404 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Subject Well Survey Programme Details: No Instrument Run Type 1 Gyrodata multishot - gyrocompassing 2 MWD - Standard (declination corrected) Planned Depths Start End (ft) (ft) 100.00 11700.00 11735.00 13500.00 Well : 1-33A/N-24 Survey : Definitive WDF - Survey Description : Final Composite Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty Object Well WDF Composition Details: No Instrument Run Type 1 Gyrodata multishot - gyrocompassing 2 MWD - Standard (input as multishot) Wellbore : 1-33A/N-24 0.00 (ft) Actual Depths Start End (ft) (ft) lOO.OO 117oo.oo 11781.00 12092.23 Interference Detected: MINOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 11700.00 48.92 11700.00 48.90 0.00 0.00 0.0 110.5 279.73 -104.64 11800.00 48.97 11799.29 49.01 0.00 4.78 122.3 219.2 281.00 -249.68 11900.00 49.24 11880.22 49.42 0.00 50.12 101.3 178.7 266.51 -215.88 12000.00 49.83 11926.72 49.70 0.00 128.96 97.9 166.8 250.19 -119.80 12100.00 50.50 11939.80 49.78 0.00 225.95 96.0 162.7 245.02 -16.86 12165.00 50.64 11941.11 49.79 0.00 290.89 96.4 162.9 244.53 48.43 Well : 1-33A/PB1 Survey : Definitive WDF - Survey Description : Final Composite Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty Object Well WDF Composition Details: No Instrument Run Type 1 Gyrodata multishot - gyroco~npassing 2 MWD - Standard (input as mu, ltishot) Wellbore : 1-33A/PB1 0.00 (ft) Actual Depths Start End (ft) (ft) lOO.OO ~8oo.oo 11815.00 12218.84 Interference Detected: MINOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd.) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 11700.00 48.91 11700.00 48.90 0.00 0.00 0.0 110.5 279.70 -104.40 11800.00 49.43 11799.27 49.01 0.58 5.36 141.2 238.2 283.04 -205.69 11900.00 49.53 11881.45 49.43 0.60 46.16 120.4 197.5 267.38 -212.56 12000.00 49.97 11931.45 49.73 0.22 119.15 112.4 180.5 248.87 -127.62 12100.00 50.44 11948.08 49.84 0.56 211.91 105.5 170.6 241.86 -29.88 12200.00 50.71 11940.41 49.79 0.63 309.71 101.9 168.5 245.29 64.46 12282.00 50.78 11936.89 49.77 0.64 391.32 101.4 168.6 246.80 144.62 Well : 1-33/M-23 Wellbore : 1-33/M-23seql Survey : Definitive WDF - Composite Survey Description : Created by procedure WDFGEN2.2 Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty Object Well WDF Composition Details: No Instrument Run Type 1 Gyrodata multishot - gyrocompassing : 0.00 (ft) Actual Depths Start End (ft) (ft) 100.00 12425.00 Interference Detected: MINOR Risk Output Object Well Subject Well. Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 11700.00 48.91 11700.00 48.90 0.00 0.00 0.0 110.5 279.70 -104.40 11800.00 49.39 11799.27 49.01 0.58 5.36 141.2 238.2 282.94 -205.68 11900.00 49.88 11884.20 49.45 1.23 42.46 142.0 218.6 268.30 -180.97 12000.00 50.38 11943.67 49.81 1.45 105.41 144.3 210.4 246.69 -94.51 12100.00 50.88 11993.59 50.14 1.64 180.98 146.4 199.5 217.64 -8.58 12200.00 51.37 12030.70 50.28 1.64 263.00 147.0 190.3 193.32 84.29 12300.00 51.85 12057.87 50.37 1.59 349.96 147.3 183.4 174.37 181.99 12400.00 52.34 12078.19 50.44 1.54 440.19 147.4 178.2 160.27 281.80 12425.00 52.34 12082.47 50.46 1.52 463.12 147.4 177.1 157.39 307.03 Well : 1-65/N-25 Wellbore : 1-65/N-25seql Survey : Definitive WDF - Composite Survey Description : Created by procedure WDFGEN2.2 Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty Object Well WDF Composition Details: No Instrument Run Type 1 Gyrodata multishot - gyrocompassing 2 MWD - Standard (input as multishot) : 0.00 (ft) Actual Depths Start End (ft) (ft) loo.0o 98oo.oo 9858.50 13286.00 Interference Detected: MAJOR Risk Output Object Well Subject Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 11700.00 46.85 11760.13 48.97 0.00 1044.33 73.1 181.4 306.24 756.44 11800.00 47.55 11785.08 49.00 0.00 1078.01 78.2 179.5 307.87 789.29 11900.00 48.37 11805.53 49.04 0.00 1119.72 82.4 177.5 308.05 831.38 12000.00 49.24 11825.01 49.14 0.00 1165.54 85.9 175.8 307.80 878.30 12100.00 50.17 11843.68 49.24 0.00 1212.91 89.1 174.4 306.01 927.25 Wellbore Name 1-33/M-23seql 1-33A/N-24 1-33A/PB1 1-65/N-25seql Summary of Contents Survey Type Definitive WDF - Composite Definitive WDF - Composite Definitive WDF - Composite Definitive WDF - Composite End of Summary ** Interference Yes Yes Yes Yes SHARED SERVICES DRILLING Proposal Data for 1-33B/L-24 Wp6 vedicel Origin: Well Horizontal Origin: Well Measurernenl Units; II Norlh Reterence: True North Dogleg sevenly: Degrees per 10Oft Vertical Section Azlmulh: 7.771° Vertical Section Deecdptlon: Well Vertical Section Odgln: 0.00 N,0.00 E Meelur~d Inol. Azlm. Vertical Northlngl Eaetlnge Vertical Dogleg Depth Depth Rate I 1735.00 36,445 110.720 9802,.52 1381.07 $ 5820.20 E -58t.41 11765.0039.597 107.89'/9826.1.5 1387.16 $ .5837.63 E .585.00 12.0(}O 11944.~66~.064 65.881 ~932,91 1369,58 $ 597.5.74 E -548,~ 24.542 11945.2069.064 6.5.881 9933.03 1369.45 $ .5976.03 E -545.$3 0.000 12223.8776.000354.0~0 10028.09 t 155.83 $ 60g$. 16 E-321,06 24.542 12323.8783,40~343.8g0 10046.00 1059.49 S ~76.23 E -228.16 12.403 12846.35$3,406343.880 10106.00 5{50.86 $ 5932.12 E 246.40 0.000 WELL · 1-33B/L-24 Wp6 I DrillQuesf DAT -DEC-98 Cr~4tl~,d By: . ,a4:~roved By: Proposal Target Summary T~'8~ N~; TVD~J:TVDr'~ W¢l~ad Off~l~: (;1~ C~r~: 1-33~-24 W~ TI ~.~ I~.~ 10~.49 S. ~76.2~ E ~9~1~7.~ N. 26512S ~ E 1-33~24 W~ I~.0 101~.~ ~.~ S. 5932 12 E 5981~ ~ N. 26~ ~ E -600 - -750 - -900 - o-1050 - Z Scale: linch = 15Oft 5700 5850 I I 2 7~8" Liner 12846,35 MD 1O106,0O 'I'VD Eastings 6000 6150 6300 I I I 1-35BIL-24 Wp6 T2 TVD 560.86 S~ 5932.22 E End DIr: 12323.87ft MD, 10046.00ft TVD Lse@ 12.403°/100fl · 12223.87ft MD, 10028.09ft DIr Rate Decm -1200 - · 7 =-1350 -~ ~ o _ ~.oo 9~o0.oo_~ to O ' 5~ 5700 5850 6000 6150 Scale: linch = 150ft 1-33B/L.24 Wp6 T1 10046.00 TVD 1059.49 S, 6076.23 E Eastings I 6300 Reference is True North - -600 - -750 - -900 ---1050 ~ -- -1200 - -1350 - -15OO Proposal Data for 1-33B/L-24 Wp6 vert~caJ Origin: Well Hodzontal Origin: Well h~m..~.'eme~i Units: ft Ncxl~ Relef'e~ce: True Nort~ Vmlk::~l Secbon Az. kno~: 7.771' Vertical ~ Veflic~ Secihm Or~: 0.00 N.0.0O E Measured In~. Azim. Vm'Ucal Northlngs EasUngs VerUcal Dogie9 Oe~h Depm S<~ct~o~ Rate 11735.00 36.44~ 110.720 9802.52 1381.07 $ 5820.20 E -581.41 11765.0O 39.59q 107,897 9826.15 1387.16 S 5837.63 E -585.09 12.000 11944.8~ 69.064 65.881 9932.91 1369.58 S 5975.74 £ -548.99 24.542 · 11945.20 69.064 65.881 9933.03 1369.45 S 5976.03 E -548.83 0.000 122.23.K7 76.(X~ 354.000 10028.09 1155.g3 S 6095.16 E -321.06 24.542 12323.8'/ 83.406 343.880 10046.00 1059.49 S 6076.23 E -22g.16 12.403 12846.35 83.406 343.880 10106.00 560.86 S 5932.12 E 246.40 0.00O vvr-I_l_ ' I-,.1,.1DIL-Z/~ wpo SURFACE LOCATION Horizontal Coordinates: 59~2351.31 N, 259088.98 E RKB Elevation: 41.50 Il R~ (EST) 14.50ft WelI(CBL=) 56.00 ft RKB - AMSL NAD27 Alaska State Planes, Zone 3, US Foot Coordinate System: [l~rttt~.Utf~'t PLOT DAT~0-DEC-98. Created By: Approved By: Proposal Target Summary Target Name: 1-33B/L-24 Wp6 TI 1-33B/L-24 Wp6 T'2 TVDss: TVDrkb Wellhead Offsets: 9990.00 10046.00 1059.49 S, 6076.23 E 10050.0 10106.00 560.86 $, 5932.12 E Global Coordinates: 598 I097.00 N, 265128.00 E 5981600.00 N, 265000.00 E 985O ~_9950 > 10050 10150 11800.00 19O0.0O 1210O.00 1250O.0O 1-33B/L-24 Wp6 TI 10046.00 TVD ................................. 1..0..5.9.:.4.9...S.,..6.0..76.23 13 -600 I -500 I -400 I -300 I I -200 - 1 O0 Vertical Section 3Al - 9803.00 TVD K2B (2900F) - 983Z00 TVD .................................... k'~'(iJbbY~;56'6~ :'ia~lbb'~b' 406° [¢c~°tx°~ o~ ~3'~Bo 212846.357/8" Liner 10106.~ 127~.~ I 100 K I (2000)- 1-33B/L-24 Wp6 T2 10106.00 TVD I 560.86 S, 5932.12 E 200 Section Azimuth: 7.771 o (True North) 'perry-$un Drilling Services Propo~J Data- 1-33B/L-24- 1-33B/L-24 1735.00 36.4~5 · 9802.52 ~381.07 S~5820.20 E -581 41 m~7~5.00 ]0.003~.s9~ 10~.~7 982~.~s 2~.~3~8~:~ ssS~'.~a' ~i ~2.00b 336 000 -58g 09 11944.86 179.86 69.064 65.881 9932.91 106.761369.58 S5975.74 E; 24.542 296.149 -548.99 ~11945 20 0.34i69.064! 65.8811 9933 03i 0.12!1369.45 S5976.03 Ei 0.000~. 0 000 -548 83 ..~: 12223 87i 278.67': 5/6. 0001'"~'~"~"i'~6'i"i'0"~-§'""09'i ......... ~'~'~"~"~Ji~"~'~*'i'~"~'""S~'~5"i ~'~' '~ '24 ~542~ 262 701 -321 06 ~:8,~ ~l ~::.,~.,o~i~,~.~ol~o~o~ ool ~o.ool ~o.~ ~l~:-~: ~ o.oool o ooo~ :~ 4oI ;)ecember, 1998- 17:38 - I- DrillOuest Sperry-Sun Drilling Services Proposal Report for 1-33B/L-24 Wp6 Revised: 9 December, 1998 Endicott Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (fi) (ft) 11735.00 36.445 110.720 9746.52 9802.52 11735.60 36.507 110.659 9747.00 9803.00 11765.00 39.597 107.897 9770.15 9826.15 11779.25 41.239 103.132 9781.00 9837.00 11800.00 43.950 96.758 9796.28 9852.28 11900.00 60.546 73.602 9857.81 9913.81 11944.86 69.064 65.881 9876.91 9932.91 11945.20 69.064 65.881 9877.03 9933.03 11994.14 68.025 53.019 9895.00 9951.00 12000.00 67.968 51.470 9897.19 9953.19 12100.00 69.228 25.112 9934.25 9990.25 12146.34 71.170 13.200 9950.00 10006.00 12200.00 74.330 359.808 9965.98 10021.98 12223.87 76.000 354.000 9972.09 10028.09 12300.00 81.612 346.255 9986.89 10042.89 12323.87 83.406 343.880 9990.00 10046.00 12400.00 83.406 343.880 9998.74 10054.74 12500.00 83.406 343.880 10010.23 10066.23 12585.11 83.406 343.880 10020.00 10076.00 12600.00 83.406 343.880 10021.71 10077.71 12700.00 83.406 343.880 10033.19 10089.19 12800.00 83.406 343.880 10044.68 10100.68 12846.35 83.406 343.880 10050.00 10106.00 1381.07 S 5820.20 E 1381.20 S 5820.53 E 1387.16 S 5837.63 E 1389.63 S 5846.53 E 1392.03 S 5860.35 E 1383.69 S 5937.77 E 1369.58 S 5975.74 E 1369.45 S 5976.03 E 1346.37 S 6015.16 E 1343.05 S 6019.46 E 1270.73 S 6076.43 E 1229.63 S 6090.68 E 1178.85 S 6096.41 E 1155.83 S 6095.16 E 1082.35 S 6082.33 E 1059.49 S 6076.23 E 986.83 S 6055.23 E 891.40 S 6027.65 E 810.17 S 6004.17 E 795.96 S 6000.07 E 700.53 S 5972.49 E 605.10 S 5944.91 E 560.86 S 5932.12 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOft) (fi) 5980783.82 N 264861.76 E -581.41 5980783.68 N 264862.09 E 12.000 -581.49 5980777.16 N 264878.99 E 12.000 -585.09 5980774.42 N 264887.81 E 24.542 -586.33 5980771.57 N 264901.54 E 24.542 -586.84 5980777.41 N 264979.19 E 24.542 -568.12 5980790.30 N 265017.59 E 24.542 -548.99 5980790.42 N 265017.89 E 0.000 -548.83 5980812.23 N 265057.74 E 24.542 -520.67 5980815.41 N 265062.14 E 24.542 -516.80 5980885.86 N 265121.41E 24.542 -437.44 5980926.48 N 265136.97 E 24.542 -394.79 5980977.05 N 265144.34 E 24.542 -343.70 5981000.10 N 265143.83 E 24.542 -321.06 5981073.96 N 265133.36 E 12.403 -249.99 5981097.00 N 265128.00 E 12.403 -228.16 5981170.30 N 265109.35 E 0.000 -159.01 5981266.57 N 265084.85 E 0.000 -68.19 5981348.50 N 265064.00 E 0.000 9.12 5981362.84 N 265060.35 E 0.000 22.64 5981459.11N 265035.85 E 0.000 113.47 5981555.38 N 265011.36 E 0.000 204.29 5981600.00 N 265000.00 E 0.000 246.40 Alaska State Plane Zone 3 Endicott MPI Comment KOP- Start Dir @ 12.000o/100ft - 11735.00ft MD, 9802.52ft TVD 3A1 Start Dir @ 24.542o/100ft· 11765.00ft MD, 9826.15ft TVD K2B (2900F) End Dir- 11944.86ft MD, 9932.91ft TVD Start Dir @ 24.542o/100ft · 11945.20ft MD, 9933.03ft TVD K2M (2400SB) K2A (2300F)/CGOC Dir Rate Decrease @ 12.403°/100ft · 12223.87ft MD, 10028.09ft TVD End Dir: 12323.87ft MD 10046 00ft 'I'VD Target: 1-33B/L~24 Wp6'T1, GeOlogical Sail @ 83.406° Inclination on 343.880° Azimuth Total Depth - 12846.35ft MD, 10106.00ft TVD 2 7/8" Liher Target: 1-33B/L-24 Wp6 T2, Geological 10 December, 1998 - 17:33 -1- Continued... Dr~Quest Endicott Sperry-Sun Drilling Services Proposal Report for 1-33B/L-24 Wp6 Revised: 9 December, 1998 Alaska State Plane Zone 3 Endicott MPI All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 7.771° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12846.35ft., The Bottom Hole Displacement is 5958.58ft., in the Direction of 95.401 ° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11735.00 9802.52 1381.07 S 5820.20 E 11765.00 9826.15 1387.16 S 5837.63 E 11944.86 9932.91 1369.58 S 5975.74 E 11945.20 9933.03 1369.45 S 5976.03 E 12223.87 10028.09 1155.83 S 6095.16 E 12323.87 10046.00 1059.49 S 6076.23 E 12585.11 10076.00 810.17 S 6004.17 E 12846.35 10106.00 560.86 S 5932.12 E Comment KOP: Start Dir @ 12.000°/100ft: 11735.00ft MD, 9802.52ft TVD Start Dir @ 24.542°/100ft: 11765.00ft MD, 9826.15ft TVD End Dir: 11944.86ft MD, 9932.91ft TVD Start Dir @ 24.542°/100ft: 11945.20ft MD, 9933.03ft TVD Dir Rate Decrease @ 12.403°/100ft: 12223.87ft MD, 10028.09ft 'I'VD End Dir- 12323.87ft MD, 10046.00ft TVD Sail @ 83.406° Inclination on 343.880° Azimuth Total Depth · 12846.35ft MD, 10106.00ft TVD Continued... 10 December, 1998 - 17:33 - 2- DrillQuest Endicott Sperry-Sun Drilling Services Proposal Report for 1-33B/L-24 Wp6 Revised: 9 December, 1998 Alaska State Plane Zone 3 Endicott MPI Formation Tops Measured Depth (ft) 11735.60 11779.25 11994.14 12146.34 Vertical Sub-Sea Depth Depth Northings Eastings (~) (~) (~) (~) 9803.00 9747.00 1381.20 S 5820.53 E 9837.00 9781.00 1389.63 S 5846.53 E 9951.00 9895.00 1346.37 S 6015.16 E 10006.00 9950.00 1229.63 S 6090.68 E Formation Name 3A1 K2B (2900F) K2M (24005B) K2A (2300F)/CGOC Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) <Run-TD> <Run-TD> Targets associated with this wellpath Target Name 1-33B/L-24 Polygon Casing Detail 2 7/8' Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 66.00 1062.70 S 5976.28 E 10.00 5981097.00 N 265028.00 E 70° 20'58.2742' N 147°54'28.3697"W 66.00 1062.70 S 5976.28 E 66.00 564.08 S 5832.17 E 66.00 557.65 S 6032.07 E 66.00 1056.27 S 6176.18 E Target Target Shape Type Polygon Geological Continued... 10 December, 1998 - 17:33 - 3 - DrillQuest Endicott Target Name Targets associated with this wellpath (Continued) 1-33B/L-24 Wp6 T1 1-33B/L-24 Wp6 T2 Sperry-Sun Drilling Services Proposal Report for 1-33B/L-24 Wp6 Revised: 9 December, 1998 Alaska State Plane Zone 3 Endicott MPI Target Entry Coordinates TVD Northings Eastings (fi) (ft) (ft) Target Target Shape Type Mean Sea Level/Global Coordinates #1 #2 #3 #4 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: 10.00 10.00 10.00 10.00 10046.00 9990.00 10106.00 10050.00 5981097.00 N 265028.00 E 5981600.00 N 264900.00 E 5981600.00 N 265100.00 E 5981097.00 N 265228.00 E 70° 20'58.2742' N 147°54'28.3697'W 70° 21'03.1794' N 147°54'32.5698'W 70°21'03.2411'N 147°54'26.7274'W 70° 20'58.3359' N 147°54'22.5276'W 1059.49 S 6076.23 E 5981097.00 N 265128.00 E 70° 20'58.3051' N 147°54'25.4486"W 560.86 S 5932.12 E 5981600.00 N 265000.00 E 70° 21'03.2103' N 147°54'29.6486"W Point Geological Point Geological 10 December, 1998 - 17:33 - 4 - DrillQuest 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Drilling Jeff Hupp Jeff, The above mentioned well has been scanned using standard anti-collision methods via DEAP. Endicott 1-33B/L-24 Wp6 The scan was performed with the following parameters: Start Scau Inspection Zone End Scan Inspection Zone Stm~ing S~an Radius Rate of Radius Increase (per 1000') 11,700.00 ' 12,846.35 ' 1,200.00 ' 100.00 ' Anti-Collision Scan summary: At the planned KOP the StaRing Scan Radins is 515' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50 ' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 685' at the Start Scan Inspection Zone as stated above. These numbers are used to produce a f'mal scan radius of 1314.635' which is 572.3175' larger than DEAP's default value of 742.3175' Scan Parameters Comments: At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation from Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Comparison Sublect Well Planned Well Well: Depth Seperatton f'= Existin~ Survey} ('= Well Plan MD} (Point to Point} 1-33/M-23 11700.00 'MD 0.00 ' 11884.20 'MD 42.46 ' 11993.59 'MD 180.98 ' 1-33A/N-24 11700.00 'lVlD 0.00 ' 11880.22 'MD 50.12 ' 11939.80 'MD 225.95 ' 11941.11 'MD 290.89 ' 1-33AJPB1 11700.00 'MD 0.00 ' 11881.45 'MD 46.16 ' 11948.08 'MD 211.91 ' 11936.89 'MD 391.32 ' Relative Allowable Aztmuth Deviation CFC Dir~tion) (Awrox. TL 110.50 ° -104.40 ' 218.60 ° -180.97' 199.50 o -8.58 ' Shut-in Required? (Seperation notes3 No; Orisinal Well 110.50 o -104.64 ' 178.70 o -215.88 ' 162.70 o -16.86 ' 162.90 ° 48.43 ' No; PNA original wellbore No; PNA original wellbore 110.50 o -104.40' 197.50 o -212.56 170.60 o -29.88 168.60 ° 144.62 Status Minor Minor Minor Tolerance Plot required: No Close Approach Comments: Ch,sc A l)l),'oac.91~ca n Che;kedd,~, ~~.z...,~./_~.,.~.~.___..~' ~.c.-_ ................. Z:',¢ "'% Approved by: Date: Date: Date: Shared Services Approval: Date: 133b124wp6prox.xls _ AWD Proximity Review 12/14/98 I VENDOR ~..AS½AST 14 OO INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~c~8 CKllO&C~8B 100. O0 100. O0 ~DLING INST' S/H KATHY CAMPOAMOR X5122 ~ I l ~,,.-~' . ,_5::..~. l-_d~~, 1 00. O0 ~V ~ EXPLORATION (ALASKA)~: INC, {.:.:.::: '.':': . :.: :i:-}' ~: . ,. BOX:196612 :i::-'"!::.~ :~.. CHORAGE;' ALAS~~'' ....99519-6612' -.. '. ' I~i14 ST'~ATI~,..BAN K :i~3F ASHEAND i ::;ii :Ci. LEVELAND 6HIO .:: .. :. '- 'i T:' ': ::::. · - . '.::: . !': :.: '::..'::i. 412 The eT' ALASKA STATE..:'-DEPT::'i."OF REVENUE :300 i:.?.PORCUP INE': DR" : ' - t~i:. · ONE :.::HUNDRED: &:::OO! 100~'~"~"~-~"~"~"~'~"i~"*'~'~'*'~'~'*~'-~~*i~-{i US:: DOLOR .... ': -:~"-': · ~ :: ~::~;~':: .~ ~:: '::~'~':~:'~'~? ~' DATE :?~:~? ":}~::' -'~'- :~':~"~' ~":::~:.:-~:~::~:~MouNT ! 11/0&''8 ! ' $100'001 :h::.:.: ;'~';;;~ :- ':' .:~-~-:'i NO~:.::VALID A~R 1~ D~YS:F' .... - '::'-':~'~: . :;:;. ':::' ...: ?~::~:. ~:~.~:.:" -::: ' ~::::. --~..~: ?: .':7% :~' .: .:::-.- ..:.:~'. :: .' :: : ::::~:] :.:::-. ~:?..~:. ,. ~.1~ 50 5 2,' ~:C)L, ;I. 20 -3P, c~ Sm: OORm.,L, &cf,' · WELL PERMIT CHECKLIST FIELD & POOL .2- ~-0/0 ~ ADMINISTRATION 1, . 3. 4. 5. 6. 7. 8. 9. 10. 11. ABDR DA,;r E 12. INIT CLASS ENGINEERING APPR DATE WELL NAME:Z~.Z'"~-'Z'/'-,.~...~-.2/-72 PROGRAM, exp [] dev.~redr~serv [-_1 wellbore segll ann. disposal para reqll (::3'/°.// GEOL AREA .. ~"7~::~ uNiT# //(::~ ~_~O'"<::3 ON/OFF SHORE ('~._ _,~.. .... Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well Iocaled in a defined pool .................. Well Iocaled proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficienl acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conduclor string provided ................... 15. Surface casing protects all known USDWs ........... 16. cMr vol adequate to circulate on conductor & surf csg ..... 17. CM r vol adequate to tie-in long string to surf csg ........ 18. CMI will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B 8, perrnafrosl ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to :5'O~O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y Y Y Y Y N N N N ~N ~N (~ N C~N (~N (~U GEOLOGY ANNULA~R DISPOSAL 35. With proper cemen-'ti~g records, this plan (A) will contain waste~ a suitable receiving zone; ....... APPR DATE (B) will not contaminale~shw~er; ~illing waste... Io surface; ~ (C) will not impair me~~rity of the well used for disposal; (I)) will not d~~tion or impair recovery from a pool; ~ ~ (E) will n~umvent 20 AAC 25.252 ~AAC 25.412. Y N ..................................... ~~: ..... ENGINEERING: UI~~' COMMISSION: JDH ' ~- [ ~ RNC .... ~~ ~ co ...~,~'~~ 31.30' Data Permit presented can be issued on potentialW/° hydrogen overpressure sulfidezones measures ....... ..... ~ YY N ~~,~/~ ...~ ............................................................................................................................. 32. Seismic analysis of shallow gas zones. ' ............................................................................................ 33. Seabed condition survey (if off-shore) ............. Y N 34. Contact name/phon.e_for weekly progress reports / Y N [exploratory only] ....... ~' ............................................................................................................................ Y N Y N Comments/Instructions: Mchekhsl u:w 05/29/9(I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Mar 17 10:12:46 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/03/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ENDICOTT ~/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 90066 E. CRIBBS J. CARLILE RECEIVED :'.,',^~, 'I 8 1999 ~m ~1 & C-~ Cons. ComPri An~or~Je 1-33B/L-24 500292257702 BP EXPLORATION (ALASKA), INC. SPERRY-SUNDRILLING SERVICES 17-MAR-99 MWD RUN 2 AK-MW-90066 E. CRIBBS J. CARLILE MWD RUN 3 AK-MW- 90066 E. CRIBBS J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RIIN 4 AK-MW-90066 E. CRIBBS E. VAUGHN MWD RUN 5 AK-MW-90066 E. CRIBBS E. VAUGHN 36 12N 16E FNL: FSL: 3217 FEL: 2114 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 55.50 GROI/ND LEVEL: 14 . 50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 10.750 5013.0 3RD STRING 7.825 11726.0 PRODUCTION STRING 3.750 12585.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS (SOLAR 175 TOOL). 3. MWD DATA IS DEPTH SHIFTED TO THE SCHLUMBERGER DLL GAMMA RAY OF 02/04/99. 4. MWD RUNS 1-5 REPRESENT WELL 1-33B/L-24 WITH API#: 50-029-22577-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12585'MD, 10077'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI3MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 11691.5 12576.5 GR 11693.5 12547.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 11691.5 11700 11704 11719 11751 11755 11760 11770 11777 11779 11785 11801 11819 11829 11831 11845 11850 11852 11883 11896 11902 11920 11924 11999 12001 12016 12021 12027 12037 12040 12067 12068 12072 12075 12083 12084 12087 12092 12100 12105 12150 12151 12184 12187 12204 12212 12259 12278 12288 12294 12302 12306 12320 12323 12326 12330 .0 .5 .0 .0 .0 .5 .0 .0 .0 .0 .5 .0 .5 .5 .0 .0 .0 .5 .0 .5 5 5 0 0 0 0 .5 .5 .0 .0 .5 .5 .0 .0 .5 .5 .0 .5 .0 .0 .0 .5 0 0 0 5 0 5 0 0 5 0 5 0 0 GR 11701.5 11710.0 11714.0 11729.0 11760.0 11764.5 11770.5 11780.0 11785.5 11788.0 11794.5 11811.0 11827.0 11837.5 11840.0 11853.5 11857.5 11861.0 11892.5 11905.0 11910 5 11928 5 11933 0 12007 5 12009 5 12024 5 12029.5 12036.0 12046.5 12049.0 12076.0 12077.5 12082.0 12084.0 12092.0 12093.5 12096.5 12100.5 12109.0 12113.0 12158.0 12159.0 12192.5 12196.0 12213.0 12221.0 12267.5 12286.0 12293.0 12298.5 12309.5 12315.0 12328.5 12333.0 12336.5 12341.0 12337.0 12346 12381.0 12390 12404.0 12413 12412.5 12422 12415.5 12425 12417.5 12426 12423.0 12431 12429.0 12438 12434.0 12441 12437.0 12444 12443.0 12451 12450.0 12459 12454.5 12464 12483.0 12491 12576.5 12585 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: .5 .5 .5 .0 .5 .5 .5 .0 .0 5 5 5 0 5 0 BIT RUN NO MERGE TOP MERGE BASE 1 11719.0 12051.0 2 12051.0 12222.0 3 12222.0 12329.0 4 12329.0 12495.0 5 12495.0 12585.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11691.5 12576.5 12134 1771 11691.5 ROP 0.36 1679.16 42.2452 1771 11691.5 GR 6.77 197.81 38.2366 1708 11693.5 First Reading For Entire File .......... 11691.5 Last Reading For Entire File ........... 12576.5 Last Reading 12576.5 12576.5 12547 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11701.5 12051.0 GR 11703.5 12020.5 $ LOG HEADER DATA DATE LOGGED: 29-JAN-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12051.0 TOP LOG INTERVAL (FT) : 11719.0 BOTTOM LOG INTERVAL (FT) : 12051.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 36.3 MAXIMUM ANGLE: 67.9 TO. QL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ INSITE 3.2 TM4.15/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type.' ...0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point ............ -..Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 QUICKDRILL 9.80 53.0 9.3 2.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 67.2 First Name Min Max Mean Nsam Reading DEPT 11701.5 12051 11876.2 700 11701.5 GR 7.31 180.33 34.8239 635 11703.5 ROP 0.67 1679.16 78.5235 700 11701.5 First Reading For Entire File .......... 11701.5 Last Reading For Entire File ........... 12051 Last Reading 12051 12020.5 12051 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUI~ NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMSULRY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12021.0 12191.5 ROP 12051.5 12221.5 $ LOG HEADER DATA DATE LOGGED: 31-JAN- 99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12222.0 TOP LOG INTERVAL (FT) : 12051.0 BOTTOM LOG INTERVAL (FT) : 12222.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.7 MAXIMUM ANGLE: 70.6 TO~L STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ INSITE 3.2 TM4.15/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 74165 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 QUICKDRILL 9.80 53.0 8.7 3.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 86.3 First Name Min Max Mean Nsam Reading DEPT 12021 12221.5 12121.2 402 12021 GR 6.77 182.13 58.7982 342 12021 ROP 0.43 50 12.3222 341 12051.5 First Reading For Entire File .......... 12021 Last Reading For Entire File ........... 12221.5 Last Reading 12221.5 12191.5 12221.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in- separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12192.5 12301.0 ROP 12222.5 12328.5 $ LOG HEADER DATA DATE LOGGED: 01-FEB-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12329.0 TOP LOG INTERVAL (FT) : 12222.0 BOTTOM LOG INTERVAL (FT): 12329.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 75.1 MAXIMUM ANGLE: 76.7 TQOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ INSITE 3.2 TM4.15/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MLTD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Loggin9 Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 QUICKDRILL 9.80 52.0 9.4 2.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 86.6 First Name Min Max Mean Nsam Reading DEPT 12192.5 12328.5 12260.5 273 12192.5 GR 7.16 64.92 16.9244 218 12192.5 ROP 0.7 154.36 16.4355 213 12222.5 First Reading For Entire File .......... 12192.5 Last Reading For Entire File ........... 12328.5 Last Reading 12328.5 12301 12328.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12300.0 12464.5 ROP 12330.0 12495.0 $ LOG HEADER DATA DATE LOGGED: 03-FEB-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12495.0 TOP LOG INTERVAL (FT) : 12329.0 BOTTOM LOG INTERVAL (FT) : 12495.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMIIMA/~GLE: 77.8 MAXIMUM AI~GLE: 83.1 TOQL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ INSITE 3.2 TM4.15/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 78653 BOREHOLE A1W-D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): M~JD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM)-AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 QUICKDRILL 9.80 52.0 9.0 3.5 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 74.5 First Name Min Max Mean Nsam Reading DEPT 12300 12495 12397.5 391 12300 GR 7.1 197.81 43.8655 330 12300 ROP 0.37 383.11 21.7529 331 12330 First Reading For Entire File .......... 12300 Last Reading For Entire File ........... 12495 Last Reading 12495 12464.5 12495 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12465 . 5 12555 . 5 ROP 12495 . 5 12585 . 0 $ LOG HEADER DATA DATE LOGGED: 03 - FEB- 99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: GM 1.22 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12585.0 TOP LOG INTERVAL (FT) : 12495.0 BOTTOM LOG INTERVAL (FT) : 12585.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82.4 MAXIMUM ANGLE: 87.9 TO~L STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ INSITE 3.2 TM4.15/.41 DM3.07/.13 TOOL NUMBER SOLAR GM 78893 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 QUICKDRILL-N 9.80 58.0 8.9 2.0 .000 .000 .000 .000 90.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 OR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12465.5 12585 12525.2 240 12465.5 GR 11.17 52.4 22.5993 181 12465.5 ROP 0.36 177.26 25.9516 180 12495.5 First Reading For Entire File .......... 12465.5 Last Reading For Entire File ........... 12585 Last Reading 12585 12555.5 12585 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... . ............................ . COMPANY NAIV~E : BP EXPLORATION (ALASKA), INC. WELL NAME : 1-33B/L-24 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 500292257702 REFERENCE NO : 99087 RECEIVED 1999 ~Oil&GasCo~.Com~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC REEL NA~E : 99087 CONTINUATION # : PREVIOUS REEL : CO~94ENT : BP EXPLORATION, 1-33B/L-24, ENDICOTT, API #50-029-22577-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC TAPE NA~E : 99087 CONTINUATION # '. 1 PREVIOUS TAPE : CO[~4~NT : BP EXPLORATION, 1-33B/L-24, ENDICOTT, API #50-029-22577-02 TAPE HEADER ENDICOTT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER .. OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE.. FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 1-33B/L-24 500292257702 BP EXPLORATION (ALASKA), INC. SCHLUMBERGER WELL SERVICES 3-MAR-99 RUN1 99087 CYCA/MORRISO ZARNDT RUN 2 RUN 3 36 12N 16E 3217 2114 56. O0 54. O0 15. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 11188.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED SLIM ACCSESS SDN, CNT, AND DLL OPEN HOLE DATA AQUIRED ON BP EXPLORATION'S 1-33B/L-24 WELL. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJT~BER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUb~4ARY LDWG TOOL CODE START DEPTH MWD 12510.0 MWD 12492.0 MWD 12557.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 11716.5 11710.0 11705.0 11701.0 11691.0 11685.5 11679.0 11672.0 11668.0 11657.0 11644.5 11641.0 11635.5 11634.0 11630.0 STOP DEPTH 11380.0 11380.0 11380.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... MWD MWD MWD 88888.5 11717.0 11711.5 11704.0 11701.5 11692.5 11687.0 11680.0 11673.5 11669.5 11658.0 11645.5 11641.0 11637.0 11635.0 11630.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: 11618.5 11612.0 11600.0 11592.0 11589.5 11577.0 11570.0 11566.0 11563.0 11558.0 11552.0 11544.0 11536.0 11534.0 11529.0 11525.0 11515.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 11619.5 11612.0 11598.5 11594.0 11591.0 11578.0 11573.5 11567.0 11564.0 11558.5 11552.0 11544.5 11537.0 11535.0 11528.0 11525.0 11515.5 100.5 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE EDITED DATA. THE GR IS TIED INTO THE PARENT 1-33/M23 WELL DOWN TO 11724'. THE PARENT LOG IS A WESTERN ATLAS DIL LOG AQUIRED 20-SEP-95. THE GR SHIFTS ARE CARRIED TO THE CNT, SDN, AND DLL TOOLS. THE CURVES ARE CLIPPED AT FIRST AND LAST VALID READINGS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUIZiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 SP SDN MV 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1291423 O0 000 O0 0 1 1 1 4 68 0000000000 LLD DLL OH~M1291423 O0 000 O0 0 1 1 1 4 68 0000000000 LLS DLL 0H~1291423 O0 000 O0 0 1 1 1 4 68 0000000000 * * DA TA * * DEPT. 12572.000 GR.SDN -999.250 SP. SDN -999.250 TENS.SDN CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT -999.250 FCNT. CNT NCNT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT -999.250 CAL1.SDN DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN -999.250 LLD.DLL LLS.DLL -999.250 DEPT. 11380.000 GR.SDN 108.371 SP. SDN 12.000 TENS.SDN CNTC. CNT 1646.636 CFTC. CNT 235.095 CRAT. CNT 6.238 FCNT. CNT NCNT. CNT 1517.241 NRAT. CNT 5.867 NPHI.CNT 45.041 CAL1.SDN DRHO.SDN -0.053 PEF. SDN 7.999 RHOB.SDN 2.396 LLD.DLL LLS.DLL 0.578 1477.000 -999.250 -999.250 -999.250 1216.000 258.621 5.195 1.449 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUFk4ARY FILE HEADER FILE NUMBER 2 RAW MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH SLDT 12573.5 11237.0 MDLT 12573.5 11237.0 SCNT 12573.5 11237.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 04-FEB-99 8Cl-205 600 04-FEB-99 12585.0 12572.0 11380.0 12572.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: GR G~RAY SLDT SLIM DENSITY SCNT SLIM NEUTRON MDLT SLIM LATROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : STGC-B SLDT-A CNT-S ~DLT-A 3. 750 11188.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL N MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S) : 52.0 MUD PH: 8.9 FLUID LOSS (C3): 3.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 074 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 068 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 081 MUD CAKE AT (BHT) : 64.0 64.0 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: Tied-in to original well bore of 1-33/m-23 using W.A. CNL-GR of 20-SEP-1995. First well logged with Thru-tubing Slim DPC Logged SLIM TLC. 2.5" density-gamma ray with 2.75" NDLTand SCNT Density/PEF log affected by tool orientation. No Swivel available for Slim DPC system. Pipe rotation not possible. Tools Ran SLick to pass high dog-legs (28 deg/lO0') Clearence of cable in tubing was 0.2" at side door sub (with 0.39 line). Slim TLC system used with ultra slim side-door entry sub. No temperature recorded. TVD log presented as Sub Sea TVD. THIS FILE CONTAINS THE RAW DATA FOR THE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: . ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 ND?4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S~P ELEM CODE (HEX) DEPT FT 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 TENS LOG LB 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 LLD LOG OH~gf 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 LLS LOG 0Pff4~1291423 O0 000 O0 0 2 1 1 4 68 0000000000 CALI LOG IN 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 SP LOG MV 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 RTi~R LOG 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT LOG CPS 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT LOG CPS 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC LOG CPS 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 TNRALOG 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC LOG CPS 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LOG G/C3 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LOG 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LOG G/C3 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI LOG PU 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LOG PU 1291423 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: DEPT. 12574.000 TENS.LOG CALI.LOG 3.470 GR.LOG RCNT.LOG 6500.000 RCFT. LOG CFTC.LOG 1590.808 DRHO.LOG NPHI.LOG 26.258 DPHI.LOG DEPT: 11237.500 TENS.LOG CALI.LOG 5.215 GR.LOG RCNT.LOG 1482.759 RCFT. LOG CFTC.LOG 203.749 DRHO.LOG NPHI.LOG 49.115 DPHI.LOG 1282. 31. 1750. O. 32. 1216. 104. 224. -0. 19. 000 LLD.LOG 781 SP.LOG 000 CNTC.LOG 211 PEF. LOG 718 000 LLD.LOG 766 SP.LOG 138 CNTC.LOG 093 PEF. LOG 388 341.339 LLS.LOG 0.000 RTNR.LOG 6978.151 TNRA.LOG 2.050 RHOB.LOG 1. 449 LLS. LOG O. 750 RTNR. LOG 1684. 017 TN-RA.LOG 8. 412 RHOB. LOG 85.680 3.714 4.061 2.110 0.578 5.931 6.704 2.330 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW REPEAT PASS Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUN242LRY VENDOR TOOL CODE START DEPTH SLDT 12572.0 ~iDLT 12572.0 SCNT 12572.0 STOP DEPTH 11932.0 11932.0 11932.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: $ LOG HEADER DATA DATE LOGGED '. SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 04-FEB-99 8Cl-205 600 04-FEB-99 12585.0 12572.0 11380.0 12572.0 TOOL STRING (TOP TO BOTTOM) VEA~OR TOOL CODE TOOL TYPE GR GAM~A RAY SLDT SLIM DENSITY SCNT SLIM NEUTRON MDLT SLIM LATROLOG $ TOOL NUMBER ........... STGC-B SLDT- A MDLT-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 3. 750 11188.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL N MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S) : 52.0 MUD PH: 8.9 FLUID LOSS (C3): 3.3 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 074 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 068 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 081 MUD CAKE AT (BHT) : 64.0 64.0 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: Tied-in to original well bore of 1-33/m-23 using W.A. CNL- First well logged with Thru-tubing Slim DPC Logged SLIM TLC. 2.5" density-gamma ray with 2.75" MDLT and SCNT Density/PEF log affected by tool orientation. LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: 10 No Swivel available for Slim DPC system. Pipe rotation not possible. Tools Ran SLick to pass high dog-legs (28 deg/lO0') Clearence of cable in tubing was 0.2" at side door sub (with 0.39 line). Slim TLC system used with ultra slim side-door entry sub. No temperature recorded. TVD log presented as Sub Sea TVD. THIS FILE CONTAINS THE RAW REPEAT DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RPT LB 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 LLD RPT OHMM1291423 O0 000 O0 0 3 1 1 4 68 0000000000 LLS RPT OH~M1291423 O0 000 O0 0 3 ! 1 4 68 0000000000 CALI RPT IN 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 GR RPT GAPI 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 SP RPT MV 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR RPT 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT RPT CPS 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: 11 NAME SERVUNIT SERVICE API API API API FILE NTgM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) RCFT RPT CPS 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC RPT CPS 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 TNRARPT 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC RPT CPS 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO RPT G/C3 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 PEF RPT 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB RPT G/C3 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI RPT PU 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI RPT PU 1291423 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12572.000 TENS.RPT 787.000 LLD.RPT 500.023 LLS.RPT CALI.RPT 3.469 GR.RPT 23.656 SP.RPT 0.000 RTNR.RPT RCNT.RPT 7000.000 RCFT. RPT 2000.000 CNTC.RPT 7514.932 TNRA.RPT CFTC.RPT 1818.066 DRHO.RPT 0.329 PEF.RPT 1.767 RHOB.RPT NPHI.RPT 24.438 DPHI.RPT 24.535 DEPT. 11932.000 TENS.RPT 1393.000 LLD.RPT 639.765 LLS.RPT CALI.RPT 3.415 GR.RPT 93.930 SP.RPT 91.375 RTNR.RPT RCNT.RPT 7883.334 RCFT. RPT 2891.667 CNTC.RPT 7931.655 TNP~.RPT CFTC.RPT 2628.621 DRHO.RPT 0.268 PEF. RPT 1.763 RHOB.RPT NPHI.RPT 18.581 DPHI.RPT 26.771 222.367 3.500 3.827 2.245 603.501 2.708 3.043 2.208 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION ' O01CO1 DATE : 99/03/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC TAPE NAME : 99087 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, 1-33B/L-24, ENDICOTT, API #50-029-22577-02 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1999 10:37 PAGE: 12 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/ 3 ORIGIN : FLIC REEL NAM~ : 99087 CONTINUATION # : PREVIOUS REEL : COMFIEITT : BP EXPLORATION, 1-33B/L-24, ENDICOTT, API #50-029-22577-02