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Home My WebLink About202-247 S Post Office Box 244027 Anchorage,AK 99524-4027 JUi Hilcorp Alaska,LLC , U L 3 V 201'.1 3800 Centerpoint Drive Suite 100 A CC Anchorage,AK 99503 1d er Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 rblita G292Qi6 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission — — D, 4 7 333 West 7th Avenue, Suite 100 a Anchorage, AK 99501 r '/ Re: Duck Island Unit Well Renaming Request 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 • OrigNew API_WeilNo PermitNumber WenName WellNumber I WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/5D9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/128 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E · .' #~;;;"; ~ ", ;~c,· WELL LOG'TRANSMITT AL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 02-28B_0-19, 03-17E_K-30, 03-25B_L-27. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 02-28B 0-19: c903-00(o ~ 14490 Digital Log Images: 50-029- 2184 7 -02 1 CD Rom 03-17E _ K-30: QOd -';)<r¡ t:t (~'-I?d. Digital Log Images: 50-029-21946-05 1 CD Rom 03-25B_L-27: d03 -()é) / 1t /4l..f?1 Digital Log Images: 50-029-22125-02 1 CD Rom SCANNED FEB 0 1 2007 £.{ I . /354tp WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 18, 2003 RE: MWD Formation Evaluation Logs: 03-17E1K-30, AK-MW-2298594 03-17EIK-30: Digital Log Images 50-029-21946-05 2bD- /)LFl 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATI'ENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:-.2:J r;\r;:f I ()~) ¡'lll~ S¡gnedfè]JOIJI ~Cf) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ~)~ A.tp )~(j (j r DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022470 Well Name/No. DUCK IS UNIT SDI 3-17E1K30 Operator BP EXPLORATION (ALASKA) INC MD .~ 10403 /' Completion Date 3/22/2003 V'comPletion Status 14048 TVD - -~-- REQUIRED INFORMATION Mud Log No Samples No ---~-- ------- DATA INFORMATION Types Electric or Other Logs Run: MWD, PWD, RES, GR, NEU, DEN Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Scale Media Rpt ~/ I ~ No M"~·~v~~~ <.:)-II.. ~' Rpt LIS Verification ED D LIS Verification ED 0 LIS Verification Rpt ~9 /' c·/: ! ED C Asc Directional Survey ')2017 LIS Verification C Pds V12017 Casing collar locator 5 [ -t Rpt /-J 20 17 Casing collar locator 5 Blu -- ----- -- 1-01L Current Status P&A 5tÎ~ LI I'llV'\. M"ùJ API No. 50-029-21946-05-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Run No Interval OH / Start Stop CH .-- Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, SLD,ROP-REPLACES ALL PREVIOUS DATA 4 9239 14020 Open 6/25/2003 9239 14020 Open 6/25/2003 9243 14000 Open 7/24/2003 9946 14048 Open 4/22/2003 7800 10232 Case 6/10/2003 4 4 Final Final 7800 10232 Case 6/10/2003 Final 7800 10232 Case 6/10/2003 A Directional Survey Log is required to be su 'itted. This recor matically create om Permit to Drill ule on: 1/28/2003. REPLACED BY DATA RECEIVED 12/22/03 REPLACED BY DATA RECEIVED 12/22/03 REPLACED BY NEW DATA RCVD 06/25/2003 ----; Wireline for Prinary Depth Control, GR, CCL LOG WITH JUNK BASKET PRIMARY DEPTH CONTROL,GR,CCLLOG WITH JUNK BASKET PRIMARY DEPTH CONTROL,GR,CCLLOG WITH JUNK BASKET DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022470 Well Name/No. DUCK IS UNIT SOl 3-17E/K30 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21946-05-00 MD 14048 1VD 10403 Completion Date 3/22/2003 Completion Status 1-01L Current Status P&A UIC N .----- ._---- : Rpt Induction/Resistivity 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, SLD, ROP-REPLACES ALL PREVIOUS DATA Rpt Neutron 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, SLD, ROP-REPLACES ALL PREVIOUS DATA Rpt Density 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, SLD, ROP-REPLACES ALL PREVIOUS DATA I Rpt I Rate of Penetration 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, -. I SLD,ROP-REPLACES ¡ I ALL PREVIOUS DATA i_ED D "':11809 ~ ~~ r'^~\ ~ 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, (: ( SLD,ROP-REPLACES ALL PREVIOUS DATA I I lED D 11809 I nd uction/Resistivity 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, I SLD, ROP-REPLACES I \ j ED ALL PREVIOUS DATA D 11809 Neutron 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, (./ I L/ SLD,ROP-REPLACES I ALL PREVIOUS DATA I I ¡ ED D 11809 Density 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, ! I SLD,ROP-REPLACES i I ¡ I ALL PREVIOUS DATA [ ED D 11809 Rate of Penetration 9239 14020 Open 12/22/2003 MPT, GR, EWR4, CNP, v SLD, ROP-REPLACES ALL PREVIOUS DATA --- Well Cores/Samples Information: ~ Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y è Chips Received? ~ Daily History Received? 6/N l,/N Formation Tops Analysis Received? ~ --~--- --- Permit to Drill 2022470 MD 14048 TVD 10403 Comments: - "-.. - - .-------- - ------ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No. DUCK IS UNIT SDI 3-17E1K30 Operator BP EXPLORATION (ALASKA) INC Completion Date 3/22/2003 Completion Status 1-01L Current Status P&A ~ Date: API No. 50-029-21946-05-00 UIC N ;{ ~ !l,)JH:.- --~/ "- ) STATE OF ALASKA ) ALASKA UIL AND GAS CONSERVATION COMMISSION I:)ECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND Lod' APR 1 5 2004 1a. Well Status: 0 Oil 0 Gas 0 Plugged liD Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM Top of Productive Horizon: 5254' NSL, 1178' WEL, SEC. 05, T11N, R17E, UM Total Depth: 160' NSL, 1229' WEL, SEC. 32, T12N, R17E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 270243 y- 5970974 Zone- ASP3 TPI: x- 270080 y- 5978761 Zone- ASP3 Total Depth: x- 270034 y- 5978948 Zone- ASP3 18. Directional Survey 0 Yes liD No 21. Logs Run: MWD, GR, PWD, RES, NEU, DEN 22. Zero Other 5. Date Comp., Susp., or Aband. 2/22/2004 6. Date Spudded 3/412003 7. Date T. D. Reached 3/12/2003 8. KB Elevation (ft): KBE = 52.6' 9. Plug Back Depth (MD+TVD) 13957 + 10325 10. Total Depth (MD+TVD) 14048 + 10403 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL '\t\taMi.IOOI&ias (;ons. Commission liD Develop~~l1oragØJ Exploratory o Stratigrapnlc Test 0 Service 12. Permit to Drill Number 202-247 303-369 13. API Number 50- 029-21946-05-00 14. Well Name and Number: END 3-17E/K-30 15. Field I Pool(s): Endicott Field I Endicott Pool Ft Ft 16. Property Designation: ADL 312828 17. Land Use Permit: 20. Thickness of Permafrost 1465' (Approx.) ¡ ...........'............. .......... ...i·..,'·, Wr.' :~~~.¡:;:T. Structural 68# 47# 12.6# I,', '"I,.,' GRÁl:)~:" Drive Pipe NT80CYHE NT80S 13Cr CASING, LINER AND CEMENTING RECORD $ISTTING ÐEPrHMQ:.Sr:iJl'nN~PE~TH'1YQ ¡Hol.:ii.', ' . ,.. ..'.., ¡,. ............. ..,,'.": ....,,{¡, ;>¡.: :lr.·.·¡/I",·,tXry1oy~,:.¡ ¡ 'lOP BOTTOM Top' BOTTOM SIZE: CEMEN11NGR@~ORD': 11'1 .I,'IPULI.lE:D' Surface 142' Surface 142' Driven Surface 2498' Surface 2496' 17-1/2" 4185 cu ft Permafrost Surface 9976' Surface 7734' 12-1/4" 575 cu ft Class 'G' 9827' 14048' 7633' 10403' 8-1/2" 1038 cu ft Class 'G' 25. .. ACIÒ,FR.iXGTURE,CE~ENT$QUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13719' - 13729' Perfd for Squeeze Perf ops, P&A w/1 0 Bbls Class 13738' Set WS-R-BB Packer (Bridge Plug) 13720' Set Whipstock 13698' Set 2nd Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BsL 30" 13-3/8" 9-518" 4-1/2" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED -iii... OIL-BsL Press. 24-HoUR RATE"" 24. .'TuålNGRecORD ··1' DEPTH SET (MD) 9857' PACKER SET (MD) 9799' SIZE 4-1/2", 12.6#, 13Cr I L-80 TVD GAs-McF W A TER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF W A TER-BsL OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 l; ¡\ ~ 0'1 ,1~¡~\ L CONTINUED ON REVERSE SIDE _aFl ~~F R 2 2? l1M~' 28. ") GEOLOGIC MARKERS NAME MD TVD K3A 13413' 9871' Kekituk 13413' 9871' K2B 13516' 9957' K2A 13693' 10104' S2A3 13693' 10104' S2A2 13830' 10219' S2A1 13851' 10236' K1 13897' 10275' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 29. ) FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED APR 1 5 2004 Alaska on & Gas Cons. Commission Anchorage 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~, ~ Title Teehniæl Assistant Date D-J -{ '-{ .0(. EN 0 3-17E/K-30 202-247 303-369 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Johnson, 564-5666 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OS;, G , ì\! lj , ) ') Well: Field: API: Permit: 3-17F/K-30 Duck Island Unit 50-029-21946-06-00 203-216 Accept: Spud: Release: Ri~r 02/21/04 02/26/04 03/13/04 Nordic #2 PRE-RIG WORK 12/20/03 RIH WITH WEATHERFORD 4.5" WRP PLUG. NO PROBLEM GOING THROUGH BVN, GLM'S, X NIPPLES. SAT DOWN IN XN-NIPPLE (I.D.= 3.725", WRP O.D.= 3.69"). WORKED WIRE, BLED WHP DOWN 40 PSI FROM 2550 TO 2510 PSI .PRESSURE EQUALIZED WELL FLOWING, CHOKE SETTING 20 BEANS, NO MOVEMENT. WRP IN XN-NIPPLE @ 9844'. TOP OF WRP @ 9842'. DECIDED TO SET WRP VS PULLING OUT OF WEAKPOINT TO MAKE FISH SHORTER AND TO KEEP WIRE FROM BLOWING OUT OF HOLE. 12/21/03 PULL 3.725" WRP FROM 9803' SLM. DRIFT TO TD @ 13832' SLM. 12/31/03 SET WRP PLUG. TOOL = 33.6 FT X 3.65" MAX OD. 01/01104 1ST RIH = ATTEMPT TO SET WRP PLUG. TOOL = 33.6 FT X 3.65" MAX OD. UNABLE TO DESCEND BELOW XN AT 9844 FT. 2ND RIH - ATTEMPTED SET CENTER ELEMENT OF BAKER 3 3/8" IBP AT 13794 FT MD.TOOL = 37.6 FT X 3.375" MAX OD. IBP DID NOT SET PROPERLY. DEPTH CORRELATED TO SWS PRIMARY DEPTH CONTROL LOG DATED 22-MARCH-2003. UPPER WIRELlNE RAM LEAKING, CLOSED LOWER RAM & PUMPED FLUIDS ATTEMPTED TO KILL WELL AND UNABLE DUE TO HIGH PRESSURE, CUT WIRELlNE WITH SWAB. WELL SHUT IN. 01/02/04 LATCHED FISHING SPEAR, E-LlNE CAME FREE. RECOVERY IN PROGRESS. 01/03/04 RECOVERED E-LlNE FOR SWS TO BACKSPOOL. ATTEMPT TO FISH E-LlNE TOOLS WI 3.7 O-SHOT. UNABLE TO GET PAST WINDOW @ 10,000' BLM. RIH WI 3.55 BAITED O-SHOT, LATCH FISH @ 13,792' BLM. CAME FREE, POH WI FISH @ TIME OF REPORT. 01/04/04 RAN 3.5 O-SHOT, RECOVERED TOOL STRING & SETTING TOOL. RAN 3.7 BELL GUIDE & 2 1/2 SB, RECOVERED IBP (MISSING 2 RUBBER ELEMENTS). RIG DOWN BRAIDED LINE, RIG UP SLICK LINE. TAGGED SOFT / STICKY BOTTOM @ 13,821' WLM, (13,858' MD USING 37' BFIKB MEASURMENT) WI 41/2" WIRE GRAB (RECOVERED ONE 6" ELEMENT AND ONE SPACER RING). APROX. 21' OF PERFS ARE COVERED. 01/05/04 MADE 2 ATTEMPTS TO FISH LAST RUBBER ELEMENT OUT OF WELL 01/06/04 ATTEMPTED TO FISH OUT IBP ELEMENT, DRIFTED TO SOFT BOTTOM @ 13,858' MD WI 4 PRONG / CENTER SPEAR WIRE GRAB, NO RECOVERY. DRIFTED TO 10,605' WLM WI 12 X 3 3/8" DUMMY GUN, SMOOTH IN & OUT. RAN 4 1/2 C-SUB BELOW STA# 4. RUNNING 4 1/2 OM-1, 7" EXT, 1 5/8 JDC @ TIME OF REPORT. 01/07/04 PULL DGLV FROM STA'S 4 & 5. SET STA #5 (1/4" PORT 1500# TRO). SET STA #4 (20/64" S/O). PULL EMPTY C-SUB. DRIFTED WI 3.69 CENT, 5' 1 7/8" STEM, 3.62 CENT & SAMPLE BAILER TAG @ 13,790' SLM CORRECTED TO 13,827' MD USING BF/KB MEASUREMENT. 01/08/04 SET BAKER IBP MID ELEMENT 13797' WITH 1.75" JDC @13790.5'. OVERALL LENGTH 11.59', WITH 3 ELEMENTS 2 @ 5.5" & 1 @ 1". SERIAL #10069560. 3-17F/K-30, Coil Tubing Drilling, . )e-Rig Work Page 2 ) 01/18/04 TIIIO = 158011100/210. LDSIPOT = BOTH SETS GOOD AT 450 FT-LBS. PPPOT-IC = PASSED AT 3000 PSI. PPPOT-T = PASSED AT 5200 PSI. 01/21/04 DRIFT 3.70" BARBELL ASSEMBLY AND 3.5" IMPRESSION BLOCK TO IBP @ 13732' SLM - GOOD IMPRESSION OF FISH NECK. PULL IBP FROM 13732' SLM AFTER SEVERAL ATTEMPTS - FISHED TWO RUBBER ELEMENTS (5-1/2" AND 1"). SET SLIP STOP CATCHER SUB @ 7420' SLM. 01/22/04 PULL 1-1/2" OGLV (20164, RK) FROM STA-4 @ 5939' SLM. PULL 1-1/2" LGLV (16164,1500# TRO, RK) FROM STA-5 @ 3774' SLM. SET DGLV'S (RK) IN STA'S 4 AND 5. PULL SLIP STOP CATCHER (EMPTY). 01/24/04 FLANGE UP BOP'S. MU BAKER LEFT HAND 3 118" MOTOR AND 3.80" HSD MILL. TROUBLE WITH PRESSURE TEST. LOADED WELL WITH 1 % KCL. THAW ICE PLUG IN RETURN LINE. 01/25/04 BLED WHP DOWN. RIH WITH BAKER LEFT HAND 3 1/8" MOTOR AND 3.80" HSD MILL. MILL THROUGH 'XN' NIPPLE AT 9844'. DRY RUN THROUGH NIPPLE - GOOD. CONTINUE RIH MILLING AT MIN. RATE. CLEAN OUT TO 13800'. PUMP 23 BBL FLOPRO SWEEP. POOH AT 80%. SURFACE. MU RIH WITH WEATHERFORD DUMMY WS (3.70" DIA X 17' LONG) TO 6500'. PULL BACK TO SURFACE. SUSPEND OPERATIONS. 01/26/04 PT SURFACE EQUIPMENT. RIH WITH WEATHERFORD DUMMY WS (3.70" DIA X 17' LONG). SAW BOBBLE AT 6592' CTMD. WASHED THROUGH - OK. RIH AND TAGGED AT 13856' CTMD. POOH. FP WELL WITH METH TO 2500'. WELL LEFT SHUT IN FOR E-LlNE WORK TO FOLLOW. JOB COMPLETE. ATTEMPTED TO PERF 13719'-13729' WITH 10' X 3 3/8" 6 SPF POWERJET GUN AND THEN SET WFD WHIPSTOCK BUT COULD NOT GET DOWN PAST 10630'. PLAN TO RETURN ON 1/27 TO ATTEMPT TO GET DOWN WITH 2 7/8" GUN. 01/27/04 PERFORATE INTERVAL: 13719'-13729', DEPTH REFERENCED TO SLB PDC LOG DATED 22-MARCH-2003. 2- 7/8" 2906 PJ HSD GUN 6SPF- 60 DEG RANDOM (GUN APliN 4.5": PEN= 27.7", EHD= 0.36"). DID NOT TAG TD. ATTEMPT TO SET 4-1/2 LSX-N WEATHERFORD WHIPSTOCK, UNABLE TO GET BELOW 10655'. PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 02104/04 TIO= 7601400/20. OA FL FOR CTD. OA FL @ SURFACE. T10=1000/400/80 (PRE CTD). PUMPED 12 BBLS SEAWATER AND 16 BBLS DIESEL. INJECTION RATE OF >0.25 BPM @ 1800 PSI AFTER. FINAL WHP'S=1 000/400180. 02107/04 WHP=XXXl300/150. LOAD IA WI 273 BBLS DIESEL. MIT IA TO 3000 PSI. PASSED. LOST 100 PSI IN FIRST 15 MINUTES & 0 PSI IN SECOND 15 MINUTES. BLEED IA DOWN TO 650 PSI. FWP=250165010. ') ) BP Oper.é1ti()(I~SUnlmªryFl~p,ºrt paget_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 . Hours Tåsk Code NPT Phase 2/2112004 05:00 - 06:00 1.00 MOB P PRE Released from END 3-33 at 0500 hrs Warm moving system. General preparations for moving 06:00 - 06:15 0.25 MOB P PRE Safety mtg re: move off well 06:15 - 07:15 1.00 MOB P PRE Move off 3-33 and move to center of pad directly in front of 3-17 Phz 1 -24F, -74 CF 07:15 - 09:00 1.75 MOB P PRE Move cellar liner and pickuplreset matting boards 09:00 - 09: 15 0.25 MOB P PRE Safety mtg re: move over well 09:15 - 10:00 0.75 MOB P PRE Move over 3-17 and set down. Had trouble climbing onto mats wI front of rig 10:00 -11:00 1.00 BOPSUP P PRE Accept for operations at 1000 hrs Note: Revised accept time back to 0800 hrs on 2/23/04 because Nordic whinned about the time it took to move the matting boards and liner NU BOPE 11 :00 - 11 :30 0.50 MOB N PRE Jack up and relevel rig 11:30 -15:00 3.50 BOPSUR P PRE Fin NU BOPE and lub 15:00 - 20:45 5.75 BOPSURP PRE Test BOPE. 500psi/3500psi Check Koomey bottle pressures and perform accumulator test. Witness waived by AOGCC 20:45 - 22:15 1.50 BOPSUF P PRE RlU lubricator and pull TWC. WHP = 340 psi close MV SV bleed down stack RID lubricator. Phase II driving conditons. 25-30 mph winds -25* 22:15 - 22:30 0.25 KILL P DECaMP PJSM. Review plan forward - cut 100' coil rehead and test. BHA and well kill procedures. 22:30 - 00:00 1.50 KILL P DECOMP RlU hydraulic cutter. Cut 118' of coil. Rehead pull test to 35K. 2/22/2004 00:00 - 00: 15 0.25 KILL P DECaMP PT coil connector to 3500 psi. Phz 1/2 00: 15 - 00:45 0.50 KILL P DECOMP M/U nozzle BHA. 00:45 - 01 :30 0.75 KILL P DECOMP Stab on well. Chase down frozen lines - choke I return line in cellar. Setback injector. 01 :30 - 03:00 1.50 KILL N DECaMP Circulate through bung hole. Unthaw lines in cellar. 03:00 - 03:10 0.17 KILL P DECOMP PJSM. Discuss strategy for taking returns to Tiger Tank. (without freezing everything up) 03:10 - 06:15 3.08 KILL P DECaMP Stab on well. Line-up through Swaco choke to Tiger Tank. Open MV SV 340 psi. RIH maintaining 450psi on well. RIH to 13800' 06:15 - 09:15 3.00 KILL P DECOMP POOH jetting wI 3.5" sidejet nozzle 3.5/1950 52.8k holding 400 psi BP to 13000'. POOH 2.5/1200 holding 200-400 psi BP to bottoms up+ at 9500'. Chk for flow and none. Start keeping returns. FP hardline wI MeOH. POOH 1.67/450,2.31800 circ'ing fromlto pits 09:15 - 09:30 0.25 KILL P DECOMP Chk well for flow-none. LD nozzle assy. Recovered 1/3 of an IBP rubber on BHA 09:30 - 10:05 0.58 STWHIP P WEXIT MU WII dummy drift onto SWS GRlCCL flow thru carrier 10:05 - 11 :35 1.50 STWHIP P WEXIT RIH wI BHA #2 to 9300' 0.4/60 11 :35 - 12:20 0.75 STWHIP N SFAL WEXIT Gus found a dripping a-ring on lubricator below drip pan. PJSM. Lift injector and replace O-ring. Will replace and PT all a-rings on lub when OOH 12:20 - 13:00 0.67 STWHIP P WEXIT Resume RI H 13:00 - 13:20 0.33 STWHIP P WEXIT Log down from 13000' to 13810' at 60'/min 0.4140 13:20 - 13:45 0.42 STWHIP P WEXIT Log up from 13810' 49k 0.44/30 at 30'/min. PVT 331 Paint flags at 13650' and 13000' EOP's Printed: 311512004 10:17:02 AM ) ) BP Qpe.ratiol1§··.Syn1måry..·.Repørt POOH wI drift assy LD WS drift and GR/CCI carrier. Download data. -4.25' correction to SLB PDC log. Replace O-rings on lub and PT MU WI! 4-1/2 WS-R-BB Packer (anchor) assy wI setting adaptor and fury tool. MU SS ESS tool. WO SWS to put GRlCCI tool back together. MU GRlCCL carrier, WI! MHA wI divert sub WEXIT RIH wI BHA #3 (46.59') to first EOP flag at 13000' correct depth -8.6'. RIH to second flag no correction. RIH placing bottom of packer at 13738'. WEXIT Load and launch .625" Delron ball. Pump first 40bbls at 2.0 bpm reduce rate to .6bpm 115psi ball on seat after 53.5 bbls. wt 21 k Pressure up to 2325 and set packer continue pumping at .15bpm holding 2200-2300psi for 3 minutes bring pressure up to 3000psi hold while pumping .19bpm increase to 3500psi and hold increase to 4000psi and hold increase toward 4500psi and sheared at 4350psi. Setdown to 16k. Log CLUGr up 30'/min to 13000' then back down to 13650'. TOH Finish TOH UD SWS MCCUgr and Sperry ESS tools. Wait on CCUgr log & survey processing. CLUgr correction +6' on up pass, -2' on down pass. Sperry ESS showing packer face of the mule shoe slot is 319.5* Call into Weatherford to dress WS without 3' spacer and setup latch lug 320* for a HS-WS TF. Once run and latched into packer this will make the distance from the bottom of the packer to the top of the WS 16.42' Based on log correction results best to err on the lower depth interval called out in the procedure to avoid csg collar at +1- 13718'. Top of the WS with the down pass correction will be +1-13720', with up pass correction it is 13728'. Make up BHA #4 ( 29.16' ) Weatherford equipment. Install 3 SWS ·pip· tags on backside of WS tray 7.84' below top of WS. RIH to 13693.8' and corr -13' to flag at 13650' EOP by GRlCCI. Chk wt 49.2k, 21.3k 0.35/30 RIH Tag at 13727' and stack 5k, PUH and engaged. PUH to 62k and sheared off leaving WS in hole POOH wI setting tool LD setting BHA RU cutter and cut 100' CT. Install DS connector. PT 45k, 3500 psi MU cement nozzle BHA MIRU DS cementers. Safety mtg re: cementing. Batch up cement RIH wI BHA #5 0.4/60 Cement to wt at 1400 hrs TT 5:58 13600' 48.5k, 19.2k RIH and tag at 13740' CTD. PUH and park at 13715' Injectivity test-pressure well bore to 2150 psi. Bled to 1750 psi in 5 min. Bleed off pressure Cementers load CT wI 5 bbl FW. PT at 4000 psi. Load 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From .~ To HoLirs Task Code NPT Phase 2/22/2004 13:45 - 16:20 2.58 STWHIP P WEXIT 16:20 - 16:45 0.42 STWHIP P WEXIT 16:45 - 17:50 1.08 STWHIP P WEXIT 17:50 - 20:40 2.83 STWHIP P 20:40 - 21 :45 1.08 STWHIP P 21 :45 - 22:35 0.83 STWHIP P WEXIT 22:35 - 00:00 1.42 STWHIP P WEXIT 2/23/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 01 :45 0.25 STWHIP P WEXIT 01 :45 - 04:20 2.58 STWHIP P WEXIT 04:20 - 05:20 1.00 STWHIP P WEXIT 05:20 - 08:05 2.75 STWHIP P WEXIT 08:05 - 08:15 0.17 STWHIP P WEXIT 08:15 - 10:40 2.42 STWHIP P WEXIT 10:40 - 11 :00 0.33 STWHIP P WEXIT 11 :00 - 12: 1 0 1.17 STWHIP P WEXIT 12:10 - 14:15 2.08 STWHIP P WEXIT 14:15 - 14:30 0.25 STWHIP P WEXIT 14:30 - 14:45 0.25 STWHIP P WEXIT 14:45 - 15:30 0.75 STWHIP P WEXIT Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 Description ot(jpèrations· Printed: 311512004 10:17:02 AM ) BP ·0. .. þe. ..·râti()I1.~.·..S·uroI'TlCl".Y..... R... ..~P. 0.. ·..·....rt "',, , .. " " . ,,,,.' .." Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 . [)åte Frorn- To Hours· . Task . Code NPT 2/23/2004 14:45 - 15:30 0.75 STWHIP P 15:30 - 15:42 0.20 STWHIP P 15:42 - 15:50 0.13 STWHIP P 15:50 - 16:30 0.67 STWHIP P 16:30 - 17:00 0.50 STWHIP P 17:00 - 17:40 0.67 STWHIP P 17:40 - 20:20 2.67 STWHIP P 20:20 - 20:50 0.50 STWHIP P 20:50 - 21 :20 0.50 STWHIP P 21:20 - 22:15 0.92 STWHIP P 22: 15 - 22:30 0.25 STWHIP P 22:30 - 23:30 1.00 STWHIP P 23:30 - 00:00 0.50 STWHIP P 2/24/2004 00:00 - 07:50 7.83 STWHIP P 07:50 - 08:05 0.25 STWHIP P 08:05 - 11 :45 3.67 STWHIP P 11 :45 - 13:30 1.75 STWHIP P Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 13:30 - 14:15 0.75 STWHIP P WEXIT 14:15 - 18:30 4.25 STWHIP P WEXIT 18:30 - 20:00 1.50 STWHIP P WEXIT 20:00 - 20:45 0.75 STWHIP P WEXIT 20:45 - 00:00 3.25 STWHIP P WEXIT 2/25/2004 1.50 STWHIP P WEXIT 00:00 - 01 :30 01 :30 - 06:00 4.50 STWHIP P WEXIT ') Page 3" Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 · Description of Operations bbls 15.8 ppg G cement wI latex 2.6/1300 followed by 10 bbls FW. Displace wI rig 2% KCI at 2.3/1300 Red rate to 1.0 bpm when cement at nozzle. Let 2 bbls come out then POOH 65'/min 53k Last bbl out at 13077'. PUH to safety 0.6/100 at 65'/min 56k Circ 0.5170,1.1/300 while circ biozan to CT and let cement settle Pressure well bore to 2500 psi and hold for 25 min w/ 150 psi loss (thru pump). IA gained 10 psi to 134 psi RIH while fin circ biozan to nozzle at 2.1/900. JeVdilute cement 2.0/900 @ 44'/min while RIH to 13725' POOH jetting 3.0/2500 and recip over GLM's P/U swizzle stick and jet BOP stack clean. Wait on N2. R/U SLB N2 equipment. Install pig catcher on coil. PJSM review plan foward for coil N2 blowdown. Test N2 lines to 3k. Pump 10 bbl methanol ahead followed by N2 and coil pig. Start swap to EL coil. Prep coil reel for removal. Lower coil to flatbed. Change reel bushings. Lift and secure E-line coil. Install internal grapple and PT Safety mtg re: THA on pull CT to floor Pull 2-3/8" E-CT to floor and stab. Cut off 50' CT. Install CTC and PT 35k. Install wet connect and test Fill CT w/1 0 bbls MeOH followed by 2% KCI. Pump at reduced rate to avoid moving slack. Coil pressured up after pumping 14 bbls. Ice plugged. Maintain 50psi on coil and 100+ degree heat inside reel house. Decide better to P/U BHA and RIH to help thaw reel. P/U milling BHA #6 (43.78') RIH maintaining 150 psi on frozen coil. Thawed at 8000'. Slowly increase circ rate. Begin displacement to flo pro through EDC. Continue to RIH. Record casing collar log from 13500' to 13600'. Add 1.5' correction, although tie in with marker joints on casing collar log was not clear. Tag cement at 13714'. Mill ahead at 0.4 fpm. 3400 psi fs @ 2.33 bpm. 3.5-4.0K# DH WOB. Cement very firm. Stall at 13725'. Appear to be on whipstock. 60K# pick up wt Mill ahead as per RP & well plan. Follow conservative time mill sequence as per Weatherford recommendation. 2.4 bpm@ 3400 psi FS. 3.0k# WOB. Mill to 13729'. Replace leaking hardline seal in side reel. Check magnets for metal, some found, cleaned off. Continue milling ahead. PU off btm to switch pumps, repair washed out pot bladder. Metal on magnets. Continue milling ahead at 13735'. 3450 psi@2.5 bpm fs. Checking shakers for sand. Calling bottom of window at 13733'. There is some type of surface electrical problem affecting BHi surface computers that in turn affects communications with downhole tools. Have turned off BHi surface equipment. Printed: 311512004 10:17:02 AM ) ) Page4_ BP ···QperatlonsSun'1111aryR~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From... To Hou rs Task Code NPT Phase 2/25/2004 01 :30 - 06:00 4.50 STWHIP P WEXIT 06:00 - 06:50 0.83 STWHIP P WEXIT 06:50 - 07:50 1.00 STWHI P P WEXIT 07:50 - 10:45 2.92 STWHIP P WEXIT 10:45 - 11: 15 0.50 STWHIP N SFAL WEXIT 11:15 -11:45 11:45 -12:15 0.50 STWHIP P 0.50 DRILL N WEXIT SFAL PROD1 12:15 - 14:45 2.50 DRILL N SFAL PROD1 14:45 - 15:15 15:15 - 15:40 15:40 - 16:10 16:10 - 20:00 0.50 DRILL P 0.42 DRILL N 0.50 DRILL N 3.83 DRILL N PROD1 SFAL PROD1 SFAL PROD1 SFAL PROD1 20:00 - 23: 15 3.25 DRILL P PROD1 23:15 - 00:00 0.75 DRILL N DFAL PROD1 2/26/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 03:30 3.00 DRILL N DFAL PROD1 03:30 - 05:00 1.50 DRILL N DFAL PROD1 05:00 - 08:00 08:00 - 08:30 3.00 DRILL N 0.50 DRILL P DFAL PROD1 PROD1 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 Description of Operations· Drill formation from 13733' to 13744'. Nordic electrican has determined that BHi's surface transfomer is shot. Mostly likely cause do to having 2 - single pole/single throw circuit breakers (verses double pole/single throw). Throwing these breakers individually over time has damaged the transformer. Ream up - down - up from 13744' to 13725' Down pass wlo pump. Window looks great. TOH. Flag EOP at 13400'. Locating another 11 0/240v generator that can be used until BHi can replace the faulty transformer used to convert rig power back to 11 0/240v Rebuilding mud pump #1 Surface test communication with BHi tools while still in the hole at surface. Using a separate small BHi transformer. If this works we can plu the next BHA while waiting for the located 110/240v generator. To make good use of downtime we also plan to replace 1 drive bushing on the coil reel after lId of window milling BHA. Small transformer doesn't work. UD BHA #6. Mill 3.80" SR 3.78+ Change out off drillers side coil reel bushing. Waiting on generator for BHi. Continue waiting on generator. Checking BHi data cable at reel for possilbe bad connection. Found waterproof junction box flooded from las tnights o-ring seal failure on 2" hardline. All connections fried. Repair wire connections. We now have comms while using surface test cables. Making necessary connections to make generator useable. SLB J box failure down time: previous 3.5 hrs. P/U BHA #7 (65.70') build assembly. RIH to 1000' seems to a short within the tools. TOH with BHA. Setback injector. Trouble shoot & test tools. Surface equipment, e-line, tools all test ok separately, but not in combination. BHI found crossed wires in MWD cabin. previous 4.0 hrs down time due to BHI. Get on well. RIH at 75 fpm due to high angle motor. Log initial GR tie in log. Unable to communicate with lower half of MWD tool. Trouble shoot same. Check surface equipment & reel components. Apparently a down hole problem. Continue to trouble shoot MWD tools. Determine fault is downhole. POOH to repair mwd tools. At surface. Get off well. Unstab from coil. LD tools. Test replacement tools on catwalk. OK. PU tools. Stab coil. Communication to tool lost once coil was stabbed. Unstab. Clean connections and try again. Test ok. Problem with previous tools was a short in the orienter. RIH to 13400. Correct to flag -18'. Log Gr tie-in -2' correction. Printed: 311512004 10: 17:02 AM "- , ) pageS_ BP OperationsSu I11l11ary .Fleport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From-To . Hours Task Code NPT Phasè 2/26/2004 08:30 - 08:45 0.25 DRILL P PROD1 Uö:4::> - 1;¿:4::> 4.UU UHILL P PHOD1 12:45 - 13:35 0.83 DRILL P PROD1 13:35 - 16:00 2.42 DRILL P PROD1 16:00 - 16:30 16:30 - 17:15 17:15 - 18:30 18:30 - 19:00 0.50 DRILL P 0.75 DRILL P 1.25 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 19:00 - 20:45 1.75 DRILL P 20:45 - 21 :45 1.00 DRILL P 21 :45 - 23:00 1.25 DRILL N 23:00 - 00:00 1.00 DRILL PROD1 2/27/2004 00:00 - 03:45 3.75 DRILL PROD1 03:45 - 04:45 PROD1 04:45 - 06:30 P PROD1 06:30 - 09:25 09:25 - 10:20 2.92 DRILL N 0.92 DRILL N PROD1 PROD1 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 . DescHpfionofGþerations RIH tag bottom 13738'. No problems through window. Directionally drill fn 3f38' 2.4bpm 3380 'Hs 10.95 t::GU 2K wOt) slow start on drilling ahead, frequent stalls with high bend motor. Avg 10-20'/hr picked up RA marker at 13727' 6' hig than previously antcipated. This puts top of window at 13 0', bottom at 13727'. Drilled to 13790 Continue drilling ahead fl 13790' 2.5bpm 3450 free- in, 10.95ppg ECD 2-300psi motor work 2-3k wob. C tinues to be very touchy about motor stalls, motor's stron . st maybe the high angle short radius motor combo. 10-2 r rop's. Drilled to 13796'. First good survey at 13755' sho . g only a 31* DLS, NBI angles dont show the DLS gettin ny higher. Open EDC. TOH up wt 44.7k down wt 14k Int EOP flag at 13300'. Discuss with town next optio . Need +1-53* DL to reach landing at 13874'md 1014 vd. Setting motor to 3.96* and plu "old" style M09 bit. Sta tree clearance will determine maximum setting. TOH inspecting t ast 150' for wear. Standback BH . Change AKO 3.98* Prep to cut of coil. Hold falle object incident review in ops cab. A 2 Ib round teflon r er fell from goose neck to rig floor, approximately 15', whil oving injector. Retaining ring had come loose allowing r er to part. Stopped job to discuss plan forward and inspect oose neck. MU e-line connector. Pull & pressure test same. Test continuity. MU build assembly (3.9 deg mtr wlold style M-09 bit). Work through well head & BOPS (no significant hang ups, but had to turn BHA by hand). Stab coil. Get on well. Inspect goose neck. Remove teflon coil guide assemblies. Check for other dropped object potential from injector assembly. RIH, slowly, to protect bit. Watch for jewelry in tbg. Continue to RIH with 3.9 mtr & M09 bit. No hang ups on jewelry, slowing down for GLM's etc. Log gr tie in from 13500'. Extra long section to verify previous tie in correlation. Add 5' correction from tie in on previous run. Found corrected RA tag at 13732'. Corrected top of WS and window is 13724.16' (13724') bottom of window 8' lower than top of window. Drill ahead from 13801'. Through window no problem. 3800 psi@ 2.67 bpm fs. 200-300 dpsi. 3K# WOB. 10.69 ECD Drilled to 13815'. Orienter showing signs of not being able to maintain highside TF's. PUH into csg. Comms with tool is good but appears the hydraulic motor is not functioning to turn orienter to assigned TF. No surveys taken to confirm motor setting is giving desired DL's. NBI confirms previous 3.1 * motor setting was only giving low 30's. Open EDC TOH for orienter. Paint EOP flag at 13200'. UD BHA #8 and plu BHA #9 (65.58') Surface continuity test Printed: 3/1512004 10:17:02 AM ) STATE OF ALASKA ., ALASKJ-\ 61L AND GAS CONSERVATION cot\,~.".J:SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: . Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing D Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Perforate ŒJ WaiverD Stimulate OTime ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2470 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development Œ] Exploratory 0 52.60 8. Property Designation: ADL-312828 11. Present Well Condition Summary: Stratigraphic 0 9. Well Name and Number: 3-17E1K-30 10. Field/Pool(s): Endicott Field I Endicott Oil Pool, Duck Island Unit Service 0 6. API Number 50-029-21946-05-00 Total Depth measured 14048 feet true vertical 10403.0 feet Effective Depth measured 13957 feet true vertical 10325.3 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Intermediate 9989 9-5/8" 47# L-80 37 - 10026 37.0 - 7767.7 6870 4760 Production 4221 4-1/2" 12.6# 13Cr80 9827 - 14048 7632.8 - 10403.0 8430 7500 Surface 3956 10-3/4" 45.5# L-80 37 - 3993 37.0 - 3864.7 5210 2480 Perforation decth: Measured depth: 13772 -13777, 13816 -13826,13854 -13874, 13874 -13879 True vertical depth: 10170.19 -10174.36,10206.9 -10215.24,10238.63 -10255.34,10255.34 -10259.52 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 37 9857 ;~~",,{ 'L,t 14.",.", .....,,,1 ~.,... ~ \I1AR 1 0 200~ Packers & SSSV (type & measured depth): 4-1/2" Baker ZXP Packer 4-1/2" HES HXO SSV Baker S-3 Packer @ 9838 @ 1521 @ 9799 A¡~I.'~(~ iI', Cpn5í (;(1; ':1C:W, ~di)n /\,rJrt"nr,¡g' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Prior to well operation: 417 13.5 16 1800 Subsequent to operation: 428 7 18 2100 Tubing Pressure 2467 2371 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ] Service D Copies of Logs and Surveys run_ 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasO WAG 0 GINJD WINJO WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations _ ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron }JÚJc,ot rá.Á-4.~ Title Production Technical Assistant Signature Phone 564-4657 Date 3/10/04 Form 1 0-404 Revised 12/2003 OR\G\NAL ~'~~ìW~~ B\.fL \~ MAil - ) ) 3-17E1K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/25/03 Change out Station 3,5 11/26/03 RAN 101 OF 3.68511 DUMMY WHIPSTOCK, SAT DOWN AT 99321 WLM BEAT LOOSE AND POOH WITH DUMMY WHIPSTOCK. RAN 3.62511 X 51 LONG ASSEMBLY WITH SAMPLE BAILER, SAT DOWN AT 10,8901 WLM, WORKED TOOLS COULD NOT GET DEEPER, POOH. RAN 2.75 II X 51 LONG ASSEMBLY WITH SAMPLE BAILER, SAT DOWN AT 10,6801 WLM WORKED THROUGH, SAT DOWN AT 11,2201 WLM COULD NOT WORK THROUGH, POOH. FLOWED WELL FOR 2 HOURS. RAN 10' X 2.8011 DUMMY GUN SAT DOWN AT 11,1901 WLM BEAT AND CHASED OBSTRUCTION TO 11,4561 WLM, BROKE OUT AND WENT TO 13,82511 WLM + 441 CORRECTION = 13,869 RKB 11/29/03 PERFORATE INTERVAL: 137721-13777' DEPTH CORRECTED TO SWS PDC LOG DATED 22-MARCH-2003. 2-1/211 PJ 2506 HSD GUN, 6 SPF- 60 DEG RANDOM. API DATA: PEN= 25.211, EHD= 0.3211. WELL SHUT IN WHILE IN HOLE. FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 RT. ELEV = 52.60' BF. ELEV = 15.75' ) 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 3,993' I 228 JTS 4-1/2" 12.6#/ft, 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 sidetrack info SECTION MILL 50' WINDOW 9,976' - 10,026' 9-5/8" BRIDGE PLUG AT 10,180' 8-1/2" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TD 14,048' MD, 10,403' TVD PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 CO SIZE SPF INTERVAL SWS 2-1/2" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 13,772 - 13,777 13,816 - 13,826 13,854 - 13,874 13,854 - 13,879 END3-17E/K-30 'ì TREE: 4-'1 þoo psi Chrome CIW WELLHEAD: 135/8" 5,000 psi FMC NS .04 . HES 'HXO' SVLN .....-- 3.813" MIN. 10 . 1,520" I · "4-1/2" MMGM GAS LIFT MANDRELS . I · 9,778' 4-1/2" 'X' NIPPLE 3.813" 10 8 Z ..-9-5/8" x 4-1/2" BAKER S-3 PACKER 9,799' ./4-1/2" 'X' NIPPLE 3.81310 9,823' ~4_1/2" 'XN' NIPPLE 3.725" 10 9,844' 4-1/2" x 5-1/2" WLEG 9,856' --1 1:::!-8.25" 00 x 7.5" 10 TIE BACK SLEEVE 9,826' 2$J. QS: ....9-5/8" x 4-1/2" ZXP LINER PACKER 9,837' "'9-5/8" x 4-1/2" LINER HANGER 9,848' MARKER JOINTS 13,537-13,577 RTD I 14,048' I :8: Z : X X : X X : X X ~2-7/8" 6.4# ST-Liner I I -..... : X X ~ 9-5/8", 4 7#/ft, 10,500' --....--... : X X PBTD I 12,940' I ~: X X DATE 3/17/03 REV. BY COMMENTS Rochin sidetrack completion 3/22/03 Warner Add Perfs EN DICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM BP EXPLORATION, INC. Amendment to Sundry 303-369 (Endicott 3-17E P&A) ~,02-7..'-Î7 .,$,U,t>j.~·~J~..~ro.e~.dim~¡6.t...itb,.'$,µ¡6¡~,.riJ..·..ªØ3'~'3$$.',·',(.I$,rjdi:Øp~t,.·~~,.·1.'7.EËi.·¡~&~}.·. ' ~~'Î~~¡~~ê~~~'~'~'~i~~~rai~~A:~r:n~Un\" .. ..... ) ) ,', Winton, RE: Sundry 303-369 We plan to change the way Endicott 3-17E is P&A'd. A whipstock will be set at 13719' md and 12 Bbls of cement will be laid in for squeeze past the whipstock to abandon all existing perforations in the well. The cement will also help hold the whipstock in place for milling the sidetrack window. Cement will be cleaned out to the top of the whipstock. After WOC we will pressure test the squeeze to 1000 psi. However; if it does not pressure test no further work is necessary. The new cemented sidetrack liner will provide complete isolation from the abandoned perforations. This is a change from the approved sundry 303-369 which placed a CIBP at 13732' for the P&A and a whipstock at 13715' md. Thx much, MOJ 564-5666 240-8034 1 of 1 1/27/20049:38 AM t)Oé)-d47- ) ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 18, 2003 RE: MWDFormationEvaluationLogs: 3-17E/K-30, AK-MW-2298594 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK.99518 ~~\9.-~'-... ^" ~ \.0 O"LJ........~ 1 illWG formatted Disc with verification listing:::tt:- J /3éJ" API#: 50-029-21946-05 Note: This Data Replaces Any Previous Data For We1l3-17E I K-30. '\ \'-Ä '^->--~~'-". c\..~ ~<c:JLL~\ lo - ()5'-{)3 ~ ""={ -<91-1.... 0 3, . f'''\ ¡r"".... (~ ~.-.õ ¡:: \, If ir-' r'"\ rF:,/1 "'"-. [.,'.mI" ~.; !\,,:.~,. 1.: ~ '" L_ .' ,,F Ii,.."" ~ ,~. l,,-,.~~ I.,...,,,,. DEC 22 2003 ,ê~a8ka Oil & 0åS lXms. wrnfni$~on Anchorage ~~~ì\\\b ) STATE OF ALASKA) ALASKA OIL. AND GAS CONSERVATION COMt\..~SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 jN41\ 12-/ fl.l 2.DO .~ D:T:J ¡2/I-¿( 3 7/f r?j /1Z- 1. Type of Request: 181 Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory o Stratigraphic 0 Service o Variance o Time Extension Plug Back for Sidetrack o Annular Disposal 5. Permit To Drill Number 202-247 /' 6. API Number: / 50- 029-21946-05-00 181 Other 99519-6612 KBE = 52.6' 9. Well Name and Number: END 3-17E/K-30 / 8. Property Designation: 10. Field I Pool(s): ADL 312828 Endicott Field I Endicott Pool Total Depth MD (ft): 14048' Q~sirïg< , Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10403' 13957' 10325' N/A .L.engt~ '~iže··.MP" "':IJ\lO . Burst Junk (measured): NIA 'CþUaþse' 142' 30" 142' 142' 2498' 2495' 5380 9976' 7734' 6870 9827' - 14048' 7633' - 10403' 2670 4760 2498' 13-3/8" 9976' 9-5/8" 4221' 4-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): 13772' - 13963' 10170' - 10330' P k d SSSV T HES 'HXO' SVLN NIPPLE ac ers an ype: 9-5/8" x 4-1/2" Baker S-3 Packer, 9-5/8" x 4-1/2" ZXP Packer Tubing Size: 4-1/2", 12.6# Tubing Grade: 13Cr80 / Packers and SSSV MD (ft): 1522' 9799', 9837' Tubing MD (ft): 9857' 12. Attachments: II Description Summary of Proposal II BOP Sketch o 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 Johnson!l Title CT Drilling Engineer Signature "7~ Û. '>rf~ /./ 1/' 13. Well Class after proposed work: o Exploratory II Development 0 Service December 17 2003 ,.-/ Date: 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ IBI Plugged DWINJ IBI Abandoned o WDSPL Contact Phone 564-5666 Commission Use Only Date Î ¿III þ:J I Sundry Number: 303 -.~ b f Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance RECEIVED DEC 11 2003 Alaska Oil & Gas Cons. Commission Anchorage Other: Subsequent form required 10- '-/ 0 1 Approved By: Original Signed By Form 10-403 Revised 2/2003 3a,.1h 1"oJtf\ RBl)YS Brl OE(~ 1 5. COMMISSIONER ~~~~g~~~~ION Date / J" 1?/ó'3 suX'¿ln Duplicate ORIGINAL \ ) ') A .I~, ~,:D" ; ~..,." "'?i~ ~~ ~"~' $@ij~ To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation C0111mission From: Mark O. Johnson CTD Engineer Date: Decelllber 9, 2003 Re: P&A operations for Endicott we1l3-17E/K-30 as part of the CTD sidetrack Endicott we1l3-17E/K-30 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on 1/21/04. The sidetrack, 3-17F/K-30, will exit..et:tt-'efthe existing 4 I¡i" liner from a whipstock at 13715' md. All existing perforations in 3-17E/K-30 will be abandoned by a CIBP set at 13732' 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. 4 Pre CTD Summary (phase 1) /' . 1) Slickline -Drift tubing. Dummy GL Vs, Pressure test IA to 3000 psi. 2) CT -mill XN nipple to 3.pO" ID, cleanout liner, drift for whipstock. 3) EL - Set CIBP at 13732' md ~ pressure test wellbore to 1000 psi (P&A of 3-17EIK-30 is complete), set 4 I¡i" whips!ock at 13715, ' ~d , I . TM c;. f 0 '- L{ 0 Š of' p VlJ 'if Ci., · CTD Sidetrack Summary (phase 2) 1) MIRV CTD rig. 2) Mill window with 3.80" OD diamond speed mill. 3) Drill 3.75" openhole sidetrack to ~15390' TD with MWD/gamma ray/resistivity. 4) Run 3 1/2" x 2 7/8" solid liner completion and cement with 16 Bbls of 15.8 ppg class G cement. Bottom of liner at TD, top of liner at ~ 13645' md. wac. Pressure test liner and lap to 2000 psi. Run liner top packer if needed. 5) Perforate 3-17F/K-30 liner. 6) RDMO. The pre CTD work is slated to begin on 12/17/03. :;J ft~o. Mark O. Johnson CTD Drilling Engi 564-5666, 240-80 CC: Well File Somira Stewman!Terrie Hubble \RT. ELEV = 52.60' BF. ELEV = 15.75' 133/8", 72#/ft, L-80, BTC. CSG. I 2498' 228 JTS 4-1/2" 12.6#/ft, 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 sidetrack info SECTION MILL 50' WINDOW 9,976' -10,026' 9-5/8" BRIDGE PLUG AT 10,180' 8-1/2" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TO 14,048' MD, 10,403' TVD PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 CO SIZE SPF SWS 2-7/8" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 INTERVAL 13,772-13,777 13,805-13,815 13,854-13,879 13,943-13,963 r '13-17E/K-30 /TREE: 4-1/2" 5,000 psi Chrome CIW WELLHEAD: 13 5/8" 5,000 pr 'rc NS ~A . HES 'HXO' SVLN 1,520" ......-- 3.813" MIN. ID ~ et,S1/Pfr l · -4-1/2" MMGM GAS LIFT MANDRELS I 1____4-1/2" 'X' NIPPLE 3.813" ID 9,778' Z z: ...-9-5/8" x 4-1/2" BAKER S-3 PACKER 9,799' /4-1/2" 'X' NIPPLE 3.81310 9,823' l/4_1/2" 'XN' NIPPLE 3.725" 10 9,844' 4-1/2" x 5-1/2" WLEG 9,856' -.I' ~.25" OD x 7.5" ID TIE BACK SLEEVE 9,826' 2$l JZs:: .....9-5/8" x 4-112" ZXP LINER PACKER 9,837' ~ 9-5/8" x 4-1/2" LINER HANGER 9,848' MARKER JOINTS 13,537' RTD I 14,048' ~ Z : X X : X X : X X ~2-7/8" 6.4# ST-Liner \__L :XX ~ 9-5/8", 47#/ft, I 10,500' -. : X X PBTD I 12,940' I ~: X X DATE 3/17/03 REV. BY COMMENTS Rochin sidetrack completion 3122103 Warner Add Perfs ENDICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM BP EXPLORATION, INC. RT. ELEV = 52.60' BF. ELEV = 15.75' ') . END 3-17F Proposed TRl ·~-1/2" 5,000 psi Chrome CIW WELLHEAD: 13 5/8" 5,000 psi FMC NS 13 3/8" 72#/ft, L-80, BTC. CSG. I 2498' ......A ...- .. HES 'HXO' SVLN 1,520" 3.813" MIN. 10 228 JTS 4-1/2" 12.6#/ft, 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 L · -4-1/2" MMGM GAS LIFT MANDRELS I I- -4-1/2" 'X' NIPPLE 3.813" 10 9,778' ~ Z ........-9-5/8" x 4-1/2" BAKER S-3 PACKER 9,799' 9,823' sidetrack info 8-1/2" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TD 14,048' MD, 10,403' TVD i/4_1/2" 'X' NIPPLE 3.81310 ~ 4-1/2" 'XN' NIPPLE 3.725" 10 I ./ 4-112" x 5-1/2" WLEG i. ~.25" 00 x 7.5" 10 TIE BACK SLEEVE 6---t~ ......9-5/8" x 4-1/2" ZXP LINER PACKER .... 9-5/8" x 4-1/2" LINER HANGER 9,844' PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 CO SIZE SPF INTERVAL SWS 2-7/8" 6 13,772-13,777 SWS 2-7/8" 6 13,805-13,815 SWS 2-7/8" 6 13,854-13,879 SWS 2-7/8" 6 13,943-13,963 9,856' 9,826' 9,837' 9,848' Potential adperfs in K.2B with ~ straddle shutoff capability (post CTO) 'Shorty lap with L TP 13645' Proposed 3-17F/K-30 CTD Sidetrack 0000 2 7/8" 13Cr liner 15390' TO DATE REV. BY COMMENTS ENDICOTT WELL 3-17E/K-30 3/17/03 Rochin sidetrack completion API NO: 50-029-21946-05 3/22/03 Warner Add Perfs COMPLETION DIAGRAM 12/9/03 MOJ Proposed CTO sidegtrack BP EXPLORATION, INC. ) Nordic 2 CTD BOP Detail JUI r I I XO Spool as necessary \ / I I ® , I ® I I 'r THA I L ~_ __~ Tubing @ r Spool -, I I -@-~ ? Methanol Injection bH..ð I Otis 7" WLA Quick I Connect - I 7-1/16" 10, 5000 psi working pressure ),- Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I (I f=C t==e= HCR I C@Itffi I TOT 7-1/16"ID, 5000 psi working pressure ~ Ram Type Dual Gate BOPE I TOT I =~ Manual over Hydraulic = Full production christmas tree MOJ 9/15/02 \... I ) o~ ---CT Injector Head I I -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ...."". 7" Riser I """'\ Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure .J I I , C:J=t I Blind/Shear I 12 3/8 II Combi Pipe/Sli~ Kill line check valve or HCR --¥AC)-I Fire resistant Kelly Hose to Flange by Hammer up 1/4 Tun Valve on DS Hardline to Standpi manifold I )l0rrJffiJ II F= I ~I / 2 3/8" X 3 1/2" VBRs 2 3/8" Combi Pipe/Slip I I 2" Side outlets 2 flanged gate valves Inner Annulus Outer Annulus ) STATE OF ALASKA ) ALAS, ,.~ OIL AND GAS CONSERVATION COM~, .{SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D Suspendc=J RepairWellC] Pull Tubingc=:=J Operation Shutdown D Plug PerforationsD Perforate New Pool D PerforateD VarianceD Stimulate[29 Time ExtensionD Re-enter Suspended Well 0 Annular Disposal D OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development 00 ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD ServiceD 9. Well Name and Number: 3-17E1K-30 10. Field/Pool(s): Endicott 5. Permit to Drill Number: 202-2470 6. API Number 50-029-21946-05-00 7. KB Elevation (ft): 52.6 8. Property Designation: ADL-312828 11. Present Well Condition Summary: / Duck Island Unit Total Depth Effective Depth measured 14048 feet true vertical 1 0403 feet measured 13957 feet true vertical 1 0220 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 3956 9989 4221 10-3/4" 45.5# L-80 9-5/8" 47# L-80 4-1/2" 12.6# 13Cr80 37 37 9827 3993 10026 14048 37 37 7632.76 - 3864.71 7767.66 10403 5210 6870 8430 2480 4760 7500 Perforation depth: Measured depth: 13816' -13826', 13854' -13874', 13874' -13879' True vertical depth: 10206.9' -10215.24' , 10238.63' -10255.34' , 10255.34' -10259.52' Packers & SSSV (type & measured depth) 4-1/2" 12.6# 13Cr80 @ 37' - 9857' MD Baker S-3 Packer @ 9799' MD /4-1/2" Baker ZXP Packer RmGE IVE D 4-1/2" HES HXO SSV @ 1521' MD OCT 1 4 2003 Tubing: ( size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: A\aska Oil & Gas Cons. Commission t\nchoraae Prior to well operation: Subsequent to operation: 14. Attachments: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut-In 605 5244 9806 Tubing Pressure 13 357 15. Well Class after proposed work: ExploratoryD Development[X Service D Signature Garry Catron ~rrry Catron ~ / _____ J.! I'~. (c.iAl ~ 16. Well Status after proposed work: Operational Shutdown Oil 00 GasO WAG 0 GINJD WINJD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant D WDSPLD Copies of Logs and Surveys run_ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Phone 564-4657 Date 1 0/9/03 ORIGINAL lfØ)MS BFl OCT1A. Form 10-404 Revised 4/2003 ) ) 3-17E/K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/26/2003 RWO CAPITAL: DRIFT/TAG 07/20/2003 ACID: ACID TREATMENT 07/21/2003 ACID: ACID TREATMENT; FILL CLEAN OUT; JEWELRY LOG--DEPTH CONTROL 07/22/2003 ACID: ACID TREATMENT 08/02/2003 ACID: GAS LIFT--TO DUMMY VALVES 08/16/2003 ACID: SSSV C/O OR STROKE EVENT SUMMARY 06/26/03 PULLED 3.813 BBEX SCSSSV FROM 14841WLM RIH WI 2.70 CENT. & BAILER & TEL & TAGGED BOTTOM AT 138221 WLM TEL DID NOT FIND EOT GOT SAMPLE OF BLACK SCHMOO RIH WI 3.710 CENTRILlZER ON 51 2-1/8 STEM & FOUND XN NIPPLE AT 98181 WLM THE XN IS AT 9844' RKB = 261 CORRECTION TAGGED BOTTOM WI SAME TOOL AT 138211 WLM + 261 CORRECTION = 138471 RKB. NOTE: TUBING TAIL IS STUNG INTO TOP OF LINER. NO JEWELRY LOG HAS BEEN RUN ON THIS SIDETRACK. 07/20/03 TIO=2350/1350/300 LOAD IA FOR ACID STIMULATION. PUMPED 5 BBLS 50/50 METHANOL, 267 BBLS SEAWATER, 369 INHIBITED SEAWATER, 110 BBLS INHIBITED METHANOL. COIL TUBING UNIT MOVING ON WELL. TIO=350/400/0. ~R.,%:,:.¡:ç.,"'-:.~OO,~*~t~:~r~,;~, ,..""'-._>r""'~_~~~!o.~~If«'!'_>r"'",""", ~~~,,'>':>~-~~ 07/21/03 CTU #5 FCO/COIL FLAG/DIESEUXYLENE TREATMENT. RIH WITH 2.5" JSN. TAGGED FILL AT 13,876' CTMD,CLEANED OUT TO HARD TAG @ 13942' CTMD. JET OOH AT 80%. RIH WITH 3.36" OD TEL AND LOCATE "XN" @ 9850' AND POOH. RIH WITH JET PACK PACKER ASSY @ 13840' (TIE INTO 22-MAR-03 SWS GR/CCL). INJECTION RATE WITH FILTERED SEA WATER 0.3 BPM, 2900 CT PSI. UNSET PACKER, CIRCULATED DIESEUXYLENE DOWN CT AND RE-SET PACKER. INJECTION RATE WAS 0.3 BPM AT 3980 PSI WITH FILTERED SEAWATER. TREATED FORMATION WITH 10 BPD DIESEUXYLENE AT 0.4 BPM AND CT PRESSURE 4000 PSI. SOAKED FOR 30 MINUTES, CONTINUED JOB AT 0.5 BPM. 59 bbl's diesel/xylene pumped Still tight. Pumped 36 bbl's 7.5% HCL DAD acid, let soak for 30 miunutes, followed by remaining 82 bbl's diesel/xylene. No significate change in injection pressures through out treatment. FINAL INJ PRESSURE=4000 psi at 0.6 bpm W Ifiltered seawaer in coil. ÞJL-_-Kf:w,-.-.........V(I-Xtfm"m.vf)JfiP:'~~"-#:;:..ll. :~.-.;..\;..m-:.... ;AA.!J.W,'W.H ,W:i-:~-...;..'f.-,,-.¡'~.-.I-- :~.-.--.-:-I-;f-r---: w¡---,-- -or Att..---"'._\,--'---'.-.-:¡;lî-¡ffJ1t -.I-U1 -,---,-fU<:x,f',--,-.-....-.;.:u.."Ko.,·-...ÞlX!!I 07/22/03 CTU #5. Diesel/xylene & acid treatment. Continued from 7/21103 WSR. Finished pumping treatment, final pressure fall off 3350 psi in 15 minutes, (3950 to 600 psi). Slack off and pkr released as per design but had trouble coming up hole. Had to alternate pumping down coil and backside and work back and forth then pump down the coil while taking returns to flow back tank to POOH. Sub above the element was packed off with cement not allowing the element to fully relax. Rubber element missing a couple small chunks. Pump 10 bbl's corrosion inhibited 2% KCL water down the flow line. --Return well to DSO to POP-- Titration=7.7% HCL. Iron < 50 ppm Page 1 ') ) 3-17E/K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/02/03 ***WELL FLOWING UPON ARRIVAL*** SET 4-1/2" CS @ 98041 WLM. PULL OGLV FROM STA # 1 @ 97141 WLM. ( HARD TO TELL IF THE CHECK WAS LEAKING). SET DGLV IN STA # 1 @ 9714' WLM. PULL CS. TURN BACK TO OPERATOR TO POP. 08/16/03 *** WELL FLOWING *** (POST ACID STIM / SET "BBE") SET & TEST "BBE" # NBB-60. POP, NOTIFY WELL TENDER OF WELL STATUS. FLUIDS PUMPED BBLS 11 0 Methonal 36 7.5% DAD Acid 868 Sea Water 141 Diesel 250 2% KCL 5 Flo Pro 1410 TOTAL Page 2 RT. ELEV = 52.60' BF. ELEV = 15.75' ) 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 3,993' I 228 JTS 4-112" 12.6#/fl:, 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 :~806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 sidetrack info SECTION MILL 50' WINDOW 9,976' - 10,026' 9-5/8" BRIDGE PLUG AT 10,180' 8-1/2" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TO 14,048' MD, 10,403'TVD PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 CO SIZE SPF INTERVAL SWS 2-7/8" 6 13,854-13,879 END3-17E/K-30 TREE: 4-, )000 psi Chrome CIW WELLHEAD: 13'518" 5,000 psi FMC NS ....~ . HES 'HXO' SVLN ~ 3.813"MIN.ID .. 1,520' I · 4-1/2"MMGM GAS LIFT MANDRELS I I . 9,778' 4-1/2" 'X' NIPPLE 3.813" 10 :8 z: ~-5/8" x 4-1/2" BAKERS-3 PACKER 9,799' 9,823' _ ./4-1/2" 'X' NIPPLE 3.813 10 ~_1/2" 'XN'NIPPLE 3.725"10 4-1/2" x 5-1/2" WLEG __. 1::!-8.25" 00 x 7.5" 10 TIE BACK SLEEVE & ~ ....9-5/8" x 4-1/2" ZXP LINER PACKER "'9-5/8" x4-1/2" LINER HANGER 9,844' 9,856' 9,826' 9,837' 9,848' MARKER JOINTS 13,537' RTD I 14,048' I :8: z : XX : XX : XX 1____ ..L. : X X 9-5/8", 47#/ft, I 10,500' ---.. : XX PBTD 1 12,940' 1 ~: X X DATE 3/17/03 REV. BY Roch in COMMENTS sidetrack completion ENDICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM 3/22/03 Add Perfs Warner ~ -2-7/8" 6.4# ST-Li ner ~ BP EXPLORATION, INC. ) ) ;to d. -al{--' II gDq WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 04,2003 RE: MWD Formation Evaluation Logs - 3-17£ / K-30, AK~MW-2298594 The technical data listed below is being subnñtted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21946-05 RECEIVED JUL 24 2003 Alaak! atJ &~~S."CW~ 'i~~or~ v 0 (V ') "\ ,,' 6(Od. -a'1-- l l \ ~Oc\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West ill Avenue, Suite 100 Anchorage, Alaska June 20,2003 RE: MWDFonnation Evaluation Logs - 3-17E / K-30, AK-MW-2298594 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21946-05 Note: This Data Replaces Any Previous Data For We1l3-17.E / K-30. r~ ~'\~ ç r ':~n'~J ~"AJO .,;I1-'l··J /-)<.) (I~.IU ujL/ ~(. '.. ..,' . ~~' ".' -.~~ ~'~ ~- .\ '\ .;~ rl(~~J-Ø\ Ð3 ~" ~ -f)(} )tj Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well 2-28B/0-19 ~Ö3-cr;¡ 0 2-28B/0-19 r9..0"=3 -(x:)lð 3-17E/K-30~' ~-~L1r 3-25B/L-27 u 0 3 ~ 4-1 OA/L-28 )~- [ì.. ~ ~ Job# 23205 23204 23292 23256 23321 Log Description PDC GRlCCL RST SIGMA PDC GRlCCL PDC GRlCCL PDC GRlCCL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~t<\ ~ fa /' (d - 03 06/03/03 NO. 2872 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott Color Date Blueline Prints CD 04/12103 1 Jd(){~ 04/12/03 1 02125/03 1 111 04/29/03 1 02/28/03 1 ) --n '- -' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth F;:J: (:~ E t'VE 0 ~~ Received by: ^ t\r·..., JUN 1 0 Lvv) ~t;.12BKa (;~-~ i~~ {;2~, C(jn3~ t~crnrrH55K)n /}~n(~;10raqe 06/03/03 Schlumbepger NO. 2872 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott Well Job# Log Description Color Date Blueline Prints CD 04/12/03 1 1 04/12/03 1 1 02/25/03 1 1 04/29103 1 1 02/28/03 1 1 --' };:)r;? ().:)j/ 2-28B/O-1N 2-28B/O-19'J ~ ~L/ '7 3-17E/K-3b----J 'Çj~3 ,- 0 ~, 3-25BJL-2N 9 'I~ Q..5:J 4-10AJL-2fhj 23205 PDC GRlCCL 23204 RST SIGMA 23292 PDC GRlCCL 23256 PDC GRlCCL 23321 PDC GRlCCL .~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: (ç -I 0' ---0 ? Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AlTN: ~ . .). / . ¡ ) Receive~'-e_ ilL! I ~4(~~ ~ ' \-J ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ISI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM At top of productive interval 5254' NSL, 1178' WEL, SEC. 05, T11 N, R17E, UM At total depth 160' NSL, 1229' WEL, SEC. 32, T12N, R17E, UM X = 270034, Y = 5978948 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Endicott Field / Endicott Pool KBE = 52.6' ADL 312828 Classification of Service Well 7. Permit Number 202-247 8. API Number 50- 029-21946-05 9. Unit or Lease Name X = 270243, Y = 5970974 Duck Island Unit/Endicott X = 270080, Y = 5978761 10. Well Number 3-17E/K-30 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/4/2003 3/12/2003 3/22/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 14048 10403 FT 13957 10325 FT ISI Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,PWD,RES,NEU,DEN 15. Water depth, if offshore 16. No. of Completions 6' - 12' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost Nipple 1522' MD 1465' (Approx.) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 142' Driven 13-3/8" 68# NT80CYHE Surface 2498' 17-1/2" 4185 cu ft Permafrost 9-5/8" 47# NT80S Surface 9976' 12-1/4" 575 cu ft Class 'G' 4-1/2" 12.6# 13Cr 9827' 14048' 8-1/2" 1038 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 spf MD TVD SIZE 4-1/2", 12.6#, 13Cr/L-80 TUBING RECORD DEPTH SET (MD) 9857' PACKER SET (MD) 9799' 25. MD TVD 13805' - 13815' 10198' - 10206' 13843' - 13868' 10229' - 10250' 13943' - 13963' 10314' - 10331' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 110 bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 27, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 4/7/2003 4 TEST PERIOD 2757 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF 1857 GAs-McF WATER-BBL 56 WATER-BBL CHOKE SIZE GAS-OIL RATIO 55 674 OIL GRAVITY-API (CORR) 23 CORE DATA Brief description of I~hology, porosity. fractures. apparent dips and P:ñ~~s or water. R'EC e.N t:. u No core samples were taken. ',-' ".-, 1'..';1 APR 2 4 2003 , MOMs 8Fl APR 3 0 20Qf1~~) l~~. <;:1 Alaska Oil & ;::h~~::~ CommissIon .~_..: . " , , ,., .~.'".", c' [' .. ~8. Form 10-407 Rev. 07-01-80 ORIGiNAL Submit In Duplicate ) \, ) Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. K3A 13413' 98711 TKEK 13413' 9871' K2B 13516' 9957' K2A 13693' 10104' S2A3 13693' 10104' S2A2 13830' 10219' S2A1 13851' 10236' K1 13897' 10275' RECE\VED APR 2 4: 2003 Commission O·~ & Gas Cons. A\aska I Ancnof3ge 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post-Rig Summary and a Leak-Off Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title. Technical Assistant Date ~/" ~&4'()~ 3-17E/K-30 Well Number 202-247 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 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. IrEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, i~jection for in-situ combustion. IreM 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. IrEM 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 ¡ntelVa!. IrEM 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 Lìft, 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 ORIGINA~ ) ) BP Operations Summary R.eport Page 1 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From ~To Hours Task Code NPT Phase Description of Operations 2/22/2003 13:00 - 15:30 2.50 MOB P PRE PREPARE RIG TO SKID RIG FLOOR 15:30 -16:30 1.00 MOB P PRE SKID RIG FLOOR 16:30 - 18:00 1.50 MOB P PRE MOVE PIT MODULE AROUND WELL ROW 4 18:00 - 19:00 1.00 MOB P PRE JACK UP CANTILEVER LEGS 19:00 - 20:00 1.00 MOB P PRE MOVE SUB BASE OFF WELL 4-10 - MOVE SUB AROUND CORNER OF WELL ROW 4 20:00 - 21 :00 1.00 MOB P PRE PICK UP TREE WITH CELLAR BRIDGE CRANE - SET ON STUMP ON BOP DECK - SET OPEN TOP TANK 21 :00 - 00:00 3.00 MOB P PRE INSTALL AUGAR END FOR OPEN TOP TANK - WELD FRAME WORK ON HOLE IN SUB BASE WALL AND PIT MODULE WALL FOR FILL UP LINE - INSTALL COUNTER BALANCE ON TOP DRIVE - SET MATS TO MOVE ON 3-17 2/23/2003 00:00 - 02:30 2.50 MOB P PRE FINISH INSTALLING COUNTER BALANCE ON TOP DRIVE - FINISH WELDING PROJECTS IN PITS / ON RIG - FINISH INSTALLING AUGAR DUMP ON PITS 02:30 - 04:00 1.50 MOB P PRE MOVE SUB OVER WELL 3-17 / K-30 - CENTER SUB TO WELL 04:00 - 05:00 1.00 MOB P PRE MOVE AND SET PIT MODULE 05:00 - 06:30 1.50 RIGU P PRE HOOK UP ALL SERVICE LINES - PRESSURE TEST GAS LINE WITH WELL TENDER 06:30 - 07:00 0.50 RIGU P PRE LOWER BACK SUPPORT LEGS ON SUB 07:00 - 08:00 1.00 RIGU P PRE SKID RIG FLOOR OVER WELL 3-17E 08:00 - 11 :00 3.00 RIGU P PRE CLOSE CELLAR DOORS - INSULATE CELLAR AROUND WELL HOUSES - FOLD IN BEAVER SLIDE - SET STEPS AROUND RIG - INSTALL GERONIMO LINE - TAKE ON 100 BBLS SEAWATER 11:00 -12:30 1.50 RIGU P PRE HOOK UP SECONDARY VALVE ON ANNULUS VALVE 12:30 - 13:30 1.00 WHSUR P DECOMP ACCEPT RIG 12:30 HRS ON 2/23/2003 - RIG UP LUBICATOR AND PULL BPV - RIG DOWN LUBICATOR 13:30 - 15:30 2.00 RIGU P DECOMP RIG UP TP DISPLACE WITH SEAWATER - TEST ALL SURFACE LINES TO 3000 PSI 15:30 - 20:30 5.00 CLEAN P DECOMP DISPLACE FREEZE PROTECTION WITH SEAWATER- PUMP 300 BBLS - STAGE UP TO 2 BPM THEN 5 BPM 2 BPM - 500 PSI - 5 BPM 1050 PSI - WAIT 30 MINS - PUMP 300 BBLS - STAGE UP TO 2 BPM THEN 5 BPM 2 BPM - 375 PSI - 5 BPM 1025 PSI - WAIT 30 MINS - PUMP 300 BBLS - STAGE UP TO 2 BPM - THEN 5 BPM 2 BPM - 400 PSI - 5 BPM 1050 PSI - MONITOR WELL FOR 30 MINS - WELL STABLE 20:30 - 21 :00 0.50 WHSUR P DECOMP SET TWC - BLOW DOWN LINES 21 :00 - 21 :30 0.50 WHSUR P DECOMP TEST TWC TO 1000 PSI FOR 15 MINS 21 :30 - 22:00 0.50 REST P DECOMP BLOW DOWN ALL SURFACE LINES - PICK UP AND CLEAR AREA FOR NIPPLE DOWN TREE - NU BOP 22:00 - 00:00 2.00 WHSUR P DECOMP NIPPLE DOWN 41/16" TREE - ADAPTER FLANGE - SEPERATE ADAPTER FLANGE FROM TREE - PLUG CONTROL LINE PORTS ON HANGER - SCREW XO SUB INTO HANGER TO ENSURE THREAD INTERGRITY OF HANGER - THREADS TDS - NOSE SEAL BAD - STRENGTH INTERGRITY IS GOOD 2/24/2003 00:00 - 09:30 9.50 BOPSUR P DECOMP NIPPLE UP - SPACER SPOOL - RISER - BOP'S - CHANGE BOTTOM RAMS TO 4 1/2" X 7" VARIABLES - (LOAD PIPE SHED WITH 5" DP) 09:30 - 10:30 1.00 BOPSURP DECOMP HOOK UP CHOKE LINE - KILL LINE Printed: 3/2412003 9:13:41 AM ) ~) BP Operations Summary Report Page 2 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2003 10:30 - 12:00 1.50 BOPSUR P DECOMP HELD PJSM. M I U TEST JOINT, R I U TO TEST BOPE 12:00 - 19:00 7.00 BOPSURP DECOMP TESTED BOPE - ANNULAR 250 LOW I 3,000 HIGH - 5 MINS EA TEST - PIPE RAMS - BLIND RAMS - CHOKE MANIFOLD - CHOKE LINE MANUAL VALVE I CHOKE HYDRAULIC VALVE - KILL LINE MANUAL VALVE I KILL LINE HYDRAULIC VALVE - FLOOR SAFETY VALVES - UPPER I LOWER IBOP VALVES - 250 LOW 14,500 HIGH - 5 MINS EA TEST 19:00 - 20:00 1.00 BOPSU¡:;. P DECOMP RID BOPE TEST EQUIPMENT 20:00 - 22:30 2.50 EVAL P DECOMP PJSM - DERRICK INSPECTION 22:30 - 23:00 0.50 RIGU P DECOMP INSTALL BAILS - ELEVATORS ON TOP DRIVE 23:00 - 00:00 1.00 WHSUR P DECOMP SET SHOOTING FLANGE - RIG UP LUBRICATOR 2/25/2003 00:00 - 00:30 0.50 WHSUR P DECOMP HELD PJSM. PULLED 1WC WITH DSM - RIGGED DOWN LUBRICATOR - LAID DOWN SHOOTING FLANGE. 00:30 - 01 :00 0.50 PULL P DECOMP PICKED UP 1W0 JOINTS 5" DP MADE UP XO - RIH - SCREWED INTO HANGER - 11 TURNS MADE UP TDS THREADS. 01 :00 - 01 :30 0.50 PULL P DECOMP CHECKED ANNULUS, NO PRESSURE - WELL STABLE - BACKED OUT LOCK DOWN SCREWS - PULLED HANGER AND TUBING STRING UP 12' - PICK UP WEIGHT 155,000#. 01 :30 - 03:30 2.00 PULL P DECOMP BROKE CIRCULATION - CHECKED SURFACE EQUIPMENT FOR LEAKS - CIRCULATED 2 x BOTTOMS -11,000 STROKES - PUMP RATE 424 GPM, SPP 475 PSI. 03:30 - 04:00 0.50 PULL P DECOMP BROKE OUT AND BLEW DOWN TOP DRIVE. 04:00 - 05:00 1.00 PULL P DECOMP HELD PJSM. PULLED TUBING HANGER TO FLOOR, TERMINATED CONTROL LINES. BROKE OUT AND LI 0 HANGER. LI 0 5" DP AND XO. R I U CAMCO CONTROL LINE SPOOLING EQUIPMENT. 05:00 - 05:30 0.50 PULL P DECOMP CHANGE ELEVATORS - POOH, LID 4-1/2" IBT TUBING 05:30 - 06:00 0.50 PULL P DECOMP RIG SERVICE 06:00 - 08:00 2.00 PULL P DECOMP LAY DOWN 4 1/2" TUBING 35 JOINTS - RECOVERED 40 STEEL BANDS - RIG DOWN - LAY DOWN CAMCO SPOOLING SYSTEM 08:00 - 12:00 4.00 PULL P DECOMP CONTINUE LAYING DOWN 41/2" TUBING - TOTAL DOWN 164 JTS 12:00 - 12:30 0.50 PULL P DECOMP PJSM - LAYING DOWN TUBING 12:30 - 13:00 0.50 PULL P DECOMP RIG SERVICE - TOP DRIVE 13:00 - 14:30 1.50 PULL N RREP DECOMP REPAIR HYDRAULIC LEAK ON HYDRAULIC UNIT ON RIG FLOOR 14:30 - 18:00 3.50 PULL P DECOMP CONTINUE LAY DOWN 41/2" TUBING - TOTAL JOINTS LAID DOWN 239 JTS - CUT OFF 33.33' - 6 GLM - 1 SSSV - 2 PUPS 18:00 - 19:00 1.00 PULL P DECOMP PJSM - RIG UP SCHLUMBERGER WIRELlNE TOOLS 19:00 - 22:00 3.00 PULL P DECOMP RIH WITH CCL - GR - JB - GR 8.0" - TAG UP ON TUBING CUT 10241' WLM - LOG UP FROM 10241' TO 7800' - POH - NOTHING IN JUNK BASKET 22:00 - 23:00 1.00 PULL P DECOMP CHANGE TOOLS - MAKE UP 9 5/8" EZSV PLUG TO SCHLUMBERGER TOOLS 23:00 - 00:00 1.00 PULL P DECOMP RIH WITH 9 5/8" EZSV PLUG 2/26/2003 00:00 - 01 :30 1.50 PULL P DECOMP RIH WITH 9 5/8" EZSV PLUG - SET ON DEPTH @ 10180' - FIRED SETTING TOOL 3 TIMES - NO INDICATION OF RELEASING SLEEVE - LINE WEIGHT 3800 - PU TO 4500 LINE WEIGHT - NOT RELEASED - SLACK OFF TO 1900 LINE WEIGHT - PLUG SET NO MOVEMENT DOWN - PU TO Printed: 3/24/2003 9:13:41 AM ) ) BP Operations Summary Report Page 3 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2003 00:00 - 01 :30 1.50 PULL P DECOMP 7000 LINE WEIGHT 75% OF LINE PULL - NOT RELEASED TOP OF FISH 10156.6' - FISH LENGTH 23.4" - ROPE SOCKET CONNECT 00 2 1/4" 113" LONG - XO TO ROLLER HOUSING - FISHING NECK 3 3/8" 00 - FISHING LENGTH 16" - ROLLERS 51/2" 00 - ROLLER HOUSING 4" - 3 SETS OF ROLLERS ON TOOL 01 :30 - 02:30 1.00 PULL N DFAL DECOMP PJSM - RIG UP T-BAR TO BLOCKS - PULL LINE FROM ROPE SOCKET WITH BLOCKS - RIG DOWN T-BAR 02:30 - 03:00 0.50 PULL P DECOMP POH WITH WIRE LINE - DISCONNECT FROM ROPE SOCKET ON LINE 03:00 - 03:30 0.50 PULL P DECOMP RIG DOWN SCHLUMBERGER TOOLS 03:30 - 04:30 1.00 PULL P DECOMP CLEAR RIG FLOOR OF TOOLS (POWER TONGS - HANGER - 2 PUPS - ELEVATORS - SLIPS) PICK UP WEAR RING- RUNNING TOOL 04:30 - 05:00 0.50 PULL P DECOMP INSTALL WEAR RING 05:00 - 08:00 3.00 PULL P DECOMP PREPARE TO PU 5" HWDP - LOAD 61/4" DC'S IN PIPE SHED - STRAP I 00 liD'S - 08:00 - 09:00 1.00 PULL P DECOMP MAKE UP BAKER OVERSHOT WITH 3 3/8" GRAPPLE 09:00 - 12:00 3.00 PULL P DECOMP PICK UP BHA - RIH TO 761' 12:00 - 17:30 5.50 PULL P DECOMP RIH WITH 5" DP FROM SHED - 5" DP PACKED WITH ICE I SNOW - STEAM OUT EACH JOINT TO ENSURE OPEN - RIH TO 3900' 17:30 - 18:00 0.50 PULL P DECOMP CIRCULATE DRILL PIPE VOLUME - 90 SPM - 350 PSI - UP WT 150K - SO 150K - BLOW DOWN TOP DRIVE 18:00 - 21 :00 3.00 PULL P DECOMP CONTINUE PICKING UP 5" DRILL PIPE - STEAMING OUT SNOW liCE PACKED JOINTS - RIH TO 7100' 21 :00 - 22:00 1.00 PULL P DECOMP CIRCULATE DRILL PIPE VOLUME - 90 STKS - 500 PSI - UP WT 190K - SO 170K - BLOW DOWN TOP DRIVE 22:00 - 00:00 2.00 PULL P DECOMP CONTINUE PICKING UP 5" DRILL PIPE - STEAMING SNOW liCE PACKED JOINTS - RIH TO 9300' - TOTAL JOINTS 5" DRILL PIPE PICKED UP 269 2/27/2003 00:00 - 00:30 0.50 PULL P DECOMP RIG SERVICE - INSPECT TOP DRIVE 00:30 - 01 :30 1.00 PULL P DECOMP CONTINUE PICK UP 5" DRILL PIPE - FROM 9300' TO 10120' - TOTAL PICKED UP 295 JOINTS 01 :30 - 02:00 0.50 PULL P DECOMP BREAK CIRCULATION @ 7 BPM - PSI 400 - PU 245K - SO 200K - TEST HARD LINE FROM 3-17 TO 3-19 TO 1800 PSI- OK 02:00 - 05:30 3.50 PULL P DECOMP PJSM - PAD OPERATOR OPENED FLOW VALVE ON 3-19- START DISPLACING SEAWATER WITH MILLING FLUID FROM 3-17- TAKING RETURNS TO 3-19 - STAGING UP RATE'S - (100 BBLS SEAWATER OUT OF PITS - 50 BBLS FRESH WATER - 670 BBLS MUD) 2BPM 350 PSI 4BPM 450 PSI 5BPM 700 PSI 5 BPM MAX RATE PRODUCTION CAN HANDLE - CUT DISPLACEMENT 100 BBLS SHORT - TOOK RETURNS INTO PITS FOR FINAL 100 BBLS - TO ENSURE NO MUD INTO PRODUCTION FLOW LINE - FINAL RATE 10 BPM -1600 PSI 05:30 - 06:00 0.50 PULL N DFAL DECOMP RIH TAG FISH @ 10156' - PUMP 23 STKS 800 PSI- Printed: 312412003 9:13:41 AM ) ) BP Operations Summary Report Page 4 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase . Description of Operations 2/27/2003 05:30 - 06:00 0.50 PULL N DFAL DECOMP INCREASE TO 950 PSI - PU 245 - SO 195 - ROT 225 - 80 RPM 1 OK TO - 90 RPM - 11 K TO - 100 RPM 11 K TO - PULL 35K OVER STRING WT TO 280K - SHEAR OFF PLUG - SHEAR OUT CIRCULATING SUB @ 3200 PSI - 06:00 - 06:30 0.50 PULL P DECOMP PUMP DRY JOB - BLOW DOWN TOP DRIVE 06:30 - 13:30 7.00 PULL P DECOMP POH WITH FISH - DRAG NORMAL - RECOVERED 100% OF ALL FISH 13:30 - 14:30 1.00 PULL N DFAL DECOMP LAY DOWN FISH - FISHING TOOLS - CLEAR FLOOR 14:30 - 16:00 1.50 STMILL P WEXIT TEST CASING TO 3000 PSI FOR 30 MINS - TEST ON CHART - UNPLUG DRIP PAN UNDER RIG FLOOR 16:00 - 17:00 1.00 STMILL P WEXIT MAKE UP 9 5/8" SECTION MILLING ASSEMBL Y 17:00 - 19:30 2.50 STMILL P WEXIT RIH WITH MILLING ASSEMBLY to 3130' 19:30 - 21 :00 1.50 STMILL P WEXIT CUT DRLG LINE - BREAK CIRCULATION - 45 SPM 500 PSI (TOOK 6 BBLS TO FILL PIPE) 21 :00 - 22:30 1.50 STMILL P WEXIT CONTINUE RIH FROM 3130' TO 4750' 22:30 - 23:00 0.50 STMILL P WEXIT BREAK CIRCULATION -100 SPM 1500 PSI- (TOOK 8 BBLS TO FILL PIPE) 23:00 - 00:00 1.00 STMILL P WEXIT CONTINUE RIH FROM 4750' TO 7409' (TOOK WEIGHT @ 7380' 10 TO 15K IMEDIA TEL Y DROPPED OFF - PULLED BACK THROUGH - NO DRAG SEEN - RIH - DID NOT SEE ANY THING) 2/28/2003 00:00 - 02:00 2.00 STMILL P WEXIT CONTINUE RIH FROM 7409' TO 7889' - FILL PIPE - CONTINUE RIH FROM 7889' TO 10176' TAG UP ON EZSV PLUG 02:00 - 03:00 1.00 STMILL P WEXIT PICK UP 5' - SPOT 20 BBL 18 PPG PILL ON TOP OF EZSV PLUG 03:00 - 03:30 0.50 STMILL P WEXIT POH TO 9976' MILLING DEPTH 03:30 - 00:00 20.50 STMILL P WEXIT START MILLING SECTION @ 9976' - 10004' - 28' CUT IN 20.5 HRS - AVG 1.4 FT/HR - 28' = 1316 LBS METAL- RECOVERED 1025 LBS = 77 % - WT ON CUTTING BLADES 8K TO 16K - GPM 650 - PP 3500 - RPM 85 - TO 18K TO 21K- ROT WT 208K - PUMPED 8 SWEEPS - 1 LOW - 1 HIGH - 6 BAROLlFT 3/1/2003 00:00 - 09:30 9.50 STMILL P WEXIT MILLING 9 5/8" SECTION FROM 10004' TO 10026' - WEIGHT ON BLADES 8K TO 16K - RPM 85/110 - TO ON 20K OFF 14K - GPM 600/650 - PP 3000 /3500 - PU 285 - SO 195- ROT 225 - CUT 50 FEET = 2350 # METAL - RECOVERED - 3000 # METAL / BAROLlFT / CUTTINGS = 130%- (BAROLlFT MIXED WITH MUD IS PROBABL Y THE DIFFERENCE IN WEIGHT) 09:30 - 14:00 4.50 STMILL P WEXIT CIRCULATE CLEAN HOLE OF METAL CUTTINGS- RECIPROCATE AND ROTATE PIPE THROUGH WINDOW- WORK MILL ON TOP STUMP TO CLEAR ANY CUTTINGS NEST OFF MILL - 150 RPM - TO 14K - GPM 670 - PP 3750 - PUMPED 5 HI-VIS SWEEPS - 2 WEIGHTED - 1 WEIGHTED HI-VIS - PULL INTO CASING - PUMP DRY JOB - BLOW DOWN TOP DRIVE 14:00 - 16:30 2.50 STMILL P WEXIT POH TO 5400' - NOTICED METAL BIRDS NEST IN BOP'S 16:30 - 17:30 1.00 STMILL P WEXIT KNOCK BIRDS NEST APART - CIRC IT OUT - PUMPING THROUGH KILL LINE 17:30 - 18:00 0.50 STMILL P WEXIT POOH TO 5000' - (CIRCULATE THROUGH KILL LINE VERY LITTLE CUTTINGS BACK) 18:00 -19:00 1.00 STMILL P WEXIT RIG SERVICE TOP DRIVE - DRAWWORKS - TROUBLE Printed: 3/24/2003 9:13:41 AM " ") BP Operations Summary Report Page 5 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2003 18:00 - 19:00 1.00 STMILL P WEXIT SHOOT CROWN-O-MA TIC 19:00 - 21 :00 2.00 STMILL P WEXIT POOH - SPORADIC OVERPULL FROM 1970 TO 1750' - 21 :00 - 22:00 1.00 STMILL P WEXIT CIRCULATE HOLE @ 1750' - GPM 630 - PP 1450 - SLOWL Y WORK PIPE UP WHILE CIRCULATING - WORK PIPE TWICE - RECOVERED 4 BUCKETS OF METAL - 22:00 - 23:00 1.00 STMILL P WEXIT CONTINUE POH FROM 1750' TO BHA - NO DRAG 23:00 - 00:00 1.00 STMILL P WEXIT LAYING DOWN 61/4" DC'S 3/2/2003 00:00 - 01 :30 1.50 STMILL P WEXIT LAYING DOWN 61/4" DC'S - LAST TWO DC'S WITH CUTTER - CIRCULATE 600 GPM PULLING THE TOOL OUT TO FLUSH STACK - LAY DOWN MILL - XO 01 :30 - 03:00 1.50 STMILL P WEXIT MAKE UP STACK WASHER WITH STRING MAGNET - RIH WASH STACK - 400 GPM -100 RPM ROTATING - WASH / FLUSH STACK 4 X - LOTS OF METAL BACK ON MAGNET AND AT SHAKER'S 03:00 - 03:30 0.50 STMILL P WEXIT LAY DOWN STACK WASHER - STRING MAGNET - 2 DC'S- BLOW DOWN TOP DRIVE 03:30 - 04:00 0.50 REMCM-P WEXIT RIG SERVICE - ADJUST TOP DRIVE 04:00 - 09:30 5.50 REMCM-P WEXIT MAKE UP MULES HOE - RIH TO 9520 - BREAK CIRCULATION @ 2376' - 4750 -7133 - 9520' 09:30 - 11 :00 1.50 REMCM-P WEXIT PICK UP SINGLES FROM PIPE SHED 21 JOINTS - CONTINUE RIH TO 9970' - WASH FROM 9970 TO 10076' 11 :00 - 13:00 2.00 REMCM-P WEXIT CIRCULATE / CONDITION MUD FOR KICK OFF PLUG - RPM 90 - TQ 12K - GPM 423 - PP 1100 - PU 230K - SO 185K- ROT 200K 13:00 - 14:30 1.50 REMCM-P WEXIT PJSM - BATCH MIX 34 BBLS CEMENT 17 PPG - PUMP 10 BBLS WATER - 4 BPM - 680 PSI - TEST LINES TO 3500 PSI - PUMP 10 BBLS WATER - PUMP 34 BBLS CEMENT - 5 BPM - 1300 PSI - PUMP 7 BBLS WATER - DISPLACE WITH RIG - 153 BBLS MUD - CUT DISPLACEMENT SHORT 5 BBLS - 10 BPM - 800 PSI 14:30 - 15:00 0.50 REMCM-P WEXIT POH 8 STANDS SLOWLY TO 9295' 15:00 - 16:00 1.00 REMCM-P WEXIT PUMP 30 BBL NUT PLUG SWEEP AROUND - PUMP WIPER BALL OUT DP - 423 GPM -1600 PSI- CLEAR PIPE 16:00 - 18:00 2.00 REMCM-P WEXIT PERFORM HESITATION SQUEEZE 16 STKS 350 PSI- 310PSI 27 STKS 650 PSI - 625 PSI 42 STKS 1000 PSI - 925 PSI 63 STKS 1350 PSI - 1250 PSI 86 STKS 1700 PSI - 1500 PSI 100 STKS 1800 PSI- 1675 PSI 117 STKS 2000 PSI-1800 PSI FINAL PRESSURE AFTER 1 HR PUMPED 11.78 BBLS - BACK 8 BBLS 18:00 - 18:30 0.50 REMCM-P WEXIT BREAK OUT TEST EQUIPMENT - PUMP DRY JOB - BLOW DOWN SURFACE EQUIPMENT 18:30 - 22:30 4.00 REMCM-P WEXIT POOH FROM 9295' TO SURFACE BREAK OFF MULESHOE 22:30 - 00:00 1.50 BOPSUR P PROD1 DRAIN STACK - RIG UP TO PULL WEAR RING - METAL ON TOP OF WEAR RING - PICK UP STAND 5" - USE TOOL JOINT AS MAGNET - RETRIEVE METAL STRINGERS FROM TOP OF WEAR RING - SEVERAL RUNS MADE CLEANING OUT METAL 3/312003 00:00 - 00:30 0.50 BOPSUR P PROD1 RUN IN WITH RUNNING TOOL - RETRIEVE WEAR RING 00:30 - 01 :30 1.00 BOPSUR P PROD1 MAKE UP TEST ASSEMBLY - FILL STACK / MANIFOLD Printed: 312412003 9: 13:41 AM ) ) BP Operations Summary Report Page 6 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From- To Hours Task Code NPT Phase Description of Operations 3/3/2003 00:30 - 01 :30 1.00 BOPSUR P PROD1 WITH WATER 01 :30 - 04:30 3.00 BOPSUR N SFAL PROD1 TESTING LOWER PIPE RAMS - NO VISABLE LEAKS - RAMS HOLDING - NO LEAK FROM ANNULUS - GRADUAL PRESSURE LEAK FROM 4500 TO 4200 PSI IN 3 TO 4 MINS - TROUBLE SHOOTING LOSS OF PRESSURE - FOUND PROBLEM IN PRESSURE MANIFOLD - BY-PASS MANIFOLD - CONTINUE TESTING 04:30 - 09:00 4.50 BOPSURP PROD1 TEST BOP'S - ANNLUAR 250 LOW 3000 HIGH - 5 MINS EACH TEST - RAMS UPPER 1 LOWER - BLIND - CHOKE MANIFOLD - HYD CHOKE VALVE - MANUAL CHOKE VALVE - KILL HYD VALVE - KILL MANUAL VALVE - UPPER 1 LOWER IBOP - FLOOR SAFETY VALVES - SPACER SPOOL ANNULUS VALVES - 250 LOW 4500 HIGH - 5 MINS EACH TEST - TEST GOOD - JOHN CRISP WITH AOGCC WAIVED THE WITNESS OF THE TEST 09:00 - 09:30 0.50 BOPSUR P PROD1 INSTALL WEAR RING - SHUT ANNULUS VALVES 09:30 - 13:30 4.00 DRILL P PROD1 PU 5" DRILL PIPE FROM SHED TO COMPLETE STRING FOR TD OF 3-17 - PU 99 JTS S-135- 13:30 - 14:00 0.50 DRILL P PROD1 CIRC 30 BBL WLLNUT SWEEP THROUGH DP TO CLEAN RUST 1 SCALE OUT OF PIPE - 600 GPM - 750 PSI 14:00 - 15:30 1.50 DRILL N RREP PROD1 WORK ON PASON EQUIPMENT ON CROWN - TRACKING UNIT FOR FOOTAGE 1 DEPTH AT BIT 15:30 - 17:00 1.50 DRILL P PROD1 BLOW DOWN TOP DRIVE - POH 5" DP - UD MULESHOE - CLEAR FLOOR 17:00 - 20:00 3.00 DRILL P PROD1 PU MOTOR 1 MWD - ORIENT SAME - PROGRAM MWD - FLEX DC'S - JARS - 5 JTS HWDP - SHALLOW TEST @ 350' 20:00 - 00:00 4.00 DRILL P PROD1 RIH - FILL PIPE @ 3190' 90 STKS 1800 PSI- 5560' 90 STKS 1800 PSI - 7946' 90 STKS 3200 PSI - JET PLUGGED - WORK PIPE - DUMP PRESSURE - UNPLUG JET - 90 STKS 1800 PSI - CIRCULATE FOR 20 MINS CLEAR PIPE - BLOW DOWN TOP DRIVE 3/4/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held Pre-Job Safety Meeting And Continue To RIH w/8 1/2" Directional BHA On 5" DP From 7,946' To 9,300' 01 :00 - 01 :30 0.50 DRILL P PROD1 Connect Tesco Top Drive And Break Circulation - Record Pump Pressure At The Following Rates: Rate GPM Pressure 90 381 1700 PSI 100 423 2100 PSI 136 575 3500 PSI Wash From 9,300' TO 9,830' - Tag Good Hard Cement 01 :30 - 02:30 1.00 DRILL P PROD1 Drilled Good Cement By Rotating From 9,830' to 9,929' WOB Rotating 20,000# - 30,000#, RPM 60, Motor RPM 145, Torque Off Bottom 18,000 ft Ilbs - On Bottom 15,000 ft Ilbs, Pump Rate 450 To 500 gpm, SPP Off Bottom 3,000 psi, On Bottom 3,200 psi. String Weight Up 235,000#, String Weight Down 185,000#, String Weight Rotating 215,000# 02:30 - 03:00 0.50 DRILL P PROD1 Circulate Out Clabbered Mud While Reciprocating And Rotating Drill String 03:00 - 04:00 1.00 DRILL P PROD1 Continue To Drill Hard Cement From 9,929' To 9,979' - WOB Rotating 25,000# - RPM 60, Motor RPM 145 Printed: 3/2412003 913:41 AM ) ) BP Operations Summary Report Page 7 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From- To Hours Task Code NPT Phase Description of Operations 3/4/2003 04:00 - 08:00 4.00 DRILL P PROD1 Per Well Program Orient Motor Tool Face To 90 Degrees Left Of High Side For Kick Off And Directional Drill Ahead From 9,979' To 10,046' (20 Feet Below Bottom Of Window) 08:00 - 09:00 1.00 DRILL P PROD1 Pull Bit Into Casing - Circulate And Condition Mud For Formation Integrity Test 09:00 - 09:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 12.0 PPG EMW Closed Annular Element And Performed FIT. Strokes Pmp'd Pressure 4 125 psi 8 235 psi 12 375 psi 16 500 psi 20 625 psi 24 750 psi 28 875 psi 32 950 psi Held Test F/10 minutes wI 50 Psi. Pressure Loss. MW 9.7 ppg, Csg Shoe TVD 7,734' Pressure 950 psi = 12.06 PPG. EMW. Bleed Pressure To 0 Psi. - Open Annular 09:30 - 12:00 2.50 DRILL P PROD1 Blow Down Kill Line - Hold Pre-Job Safety Meeting With All Personal - Pump Hi-Vis Sweep And Displace Hole To Baroid GEM Enhanced Mud At 7 BPM And 80 RPM - Clean Mud Trough And Shaker Possom Belly - Record Slow Pump Rates - Wash Back To Bottom At 10,046' 12:00 - 13:00 1.00 DRILL P PROD1 Directional Drill Ahead Sliding From 10,046' To 10,068' 13:00 - 14:00 1.00 DRILL N RREP PROD1 Held Pre-Job Safety Meeting - POH To Window And Repair Cooling System On Turbine 14:00 - 00:00 10.00 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,068' to 10,360'. WOB Sliding 20,000# - 30,000#, WOB Rotating 25,000# - 28,000#, RPM 60 To 85, Motor RPM 148, Torque Off Bottom 19,000 ft /Ibs To 22,000 ft /Ibs. - On Bottom 18,500 ft /Ibs, Pump Rate 508 gpm, SPP Off Bottom 2,400 psi, On Bottom 2,580 psi. String Weight Up 295,000#, String Weight Down 175,000#, String Weight Rotating 215,000#. ART = 6.11 hrs, AST = 6.01 hrs. *NOTE* Excessive Torque (27K) On Connection At 10,326' While Back Reaming Stand Up - Lost Power To Top Drive Had To Reset Breakers 3/5/2003 00:00 - 07:30 7.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,360' to 10,614' - Record Slow Pump Rates - WOB Sliding 20,000# - 30,000#, WOB Rotating 25,000# - 28,000#, RPM 60 To 85, Motor RPM 148, Torque Off Bottom 19,000 ft /Ibs To 22,000 ft /Ibs. - On Bottom 18,500 ft /Ibs, Pump Rate 508 To 550 gpm, SPP Off Bottom 2,680 psi, On Bottom 2,950 psi. String Weight Up 295,000#, String Weight Down 175,000#, String Weight Rotating 215,000# - ART = 4.06 hrs, AST = 1.05 hrs. 07:30 - 09:00 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep At 546 GPM With 2950 Psi While Rotating And Reciprocating Drill String Printed: 3/2412003 9:13:41 AM ) ) BP Operations Summary Report Page 8 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/512003 09:00 - 09:30 0.50 DRILL P PROD1 Held PJSM - Monitor Well Bore (Static) - POH Wet With 8 1/2" Directional Drilling Assembly Standing Back 5" Drill Pipe In Mast From 10,614' To Window At 9,969' With No Problems 09:30 - 10:30 1.00 DRILL P PROD1 Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 10:30 - 14:00 3.50 DRILL P PROD1 POH With 8 1/2" Directional Drilling Assembly From 9,969' To 9,342' - Mad Pass Log At 150 FPH From 9,342' To 9,279' - Continue To POH Standing Back 5" Drill Pipe In Mast From 9,279' To 3,940' 14:00 - 15:00 1.00 DRILL N RREP PROD1 Held PJSM - Replace Hydraulic Hose On Varco Iron Ruffneck 15:00 - 16:00 1.00 DRILL P PROD1 POH With 8 1/2" Directional Drilling Assembly Standing Back 5" Drill Pipe In Mast From 3,940' To BHA At 813' 16:00 - 17:00 1.00 DRILL P PROD1 Held PJSM - POH Standing Back BHA No.3 - Remove Bit And Down Load MWD Data 17:00 - 19:30 2.50 DRILL P PROD1 Held PJSM - Pick Up Adjustable Gage Stablizer - Adjust AKO On Motor To 1.22 Degrees And Orient To MWD - Surface Test AGS And MWD Tools - Make Up Smith PDC Bit - Initalize MWD Tool And RIH With Directional Drilling BHA No.4 19:30 - 23:30 4.00 DRILL P PROD1 Held PJSM - RIH wI 81/2" Directional BHA On 5" DP To 9,957' - Fill Pipe Every 25 Stands 23:30 - 00:00 0.50 DRILL P PROD1 Held PJSM - Service Tesco Top Drive, Traveling Blocks, Swivel, And Drawworks 3/6/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM - Fill Drill String At 9,957' - RIH w/8 1/2" Directional BHA On 5" DP From 9,957' To 10,532' With No Problems 01 :00 - 01 :30 0.50 DRILL P PROD1 M/U Top Drive - Wash And Ream As Precaution From 10,532' To 10,614' No Fill- RPM 80, Motor RPM 154, Torque 10,000 FtlLbs, Pump Rate 533 GPM, SPP Off Bottom 2,480 Psi. String Weight Up 295,000# String Weight Down 175,000# String Weight Rotating 220,000# - Take Directional Survey At 10,612' Establish Differential Pressure For AGS Open At 2800 Psi. & Closed 2600 Psi. 01 :30 - 00:00 22.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,614' to 11,969'. WOB Rotating 15,000# - 18,000#, WOB Sliding 13,000#, RPM 80, Motor RPM 157, Torque Off Bottom 10,000 ft I Ibs - On Bottom 14,000 ft I Ibs, Pump Rate 541 gpm, SPP Off Bottom 2,650 psi, On Bottom 3,300 psi. String Weight Up 260,000#, String Weight Down 205,000#, String Weight Rotating 230,000# ART = 11.07 hrs, AST = 4.04 hrs. 3/7/2003 00:00 - 03:30 3.50 DRILL P PROD1 Held PJSM - Drilled 8 1/2" Directional Hole By Rotating And Sliding From 11,969' to 12,072'. WOB Rotating 15,000# To 18,000#, WOB Sliding 2,000# To 5,000# *NOTE* While Rotary Drilling ROP 90 To 160 FPH While Slide Drilling ROP At 20 To 30 FPH Unable To Get Enough Drop Rate In Angle Prior To Getting Into Tuffs With Out Stalling Out Motor With PDC Bit Very Hard To Steer And Stay On Bottom 03:30 - 05:00 1.50 DRILL P PROD1 Consult With Anchorage Drilling Engineer Regarding Directional Issue - Stand Back Stand And Circulate 2 Bottoms Up While Rotating And Reciprocating Drill String Printed: 3/24/2003 913:41 AM ) ') BP Operations Summary Report Page 9 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/7/2003 05:00 - 07:00 2.00 DRILL P PROD1 Held PJSM - POH Wet With 8 1/2" Directional Drilling Assembly Standing Back 5" Drill Pipe In Mast From 12,072' To Window At 9,957' 07:00 - 07:30 0.50 DRILL P PROD1 Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 07:30 - 11 :30 4.00 DRILL P PROD1 Held PJSM - POH With 8 1/2" Directional Drilling Assembly Standing Back 5" Drill Pipe In Mast From 9,957' To BHA At 823' 11:30-13:00 1.50 DRILL P PROD1 Held PJSM - POH Standing Back BHA No.3 - Remove Bit And Lay Down Ajustable Gage Stabilizer Down Load MWD Data 13:00 - 15:00 2.00 DRILL P PROD1 Held PJSM - Pick Up String Stablizer - Adjust AKO On Motor To 1.50 Degrees And Orient To MWD - Surface Test MWD Tools - Make Up Hughes 81/2" MX-R20HDX2 Bit - Initalize MWD Tool And RIH With Directional Drilling BHA No.5 15:00 - 15:30 0.50 DRILL N RREP PROD1 Held PJSM - Repair Iron Ruffneck 15:30 - 21 :30 6.00 DRILL P PROD1 Held PJSM - RIH w/ 81/2" Directional BHA On 5" DP To 9,951' - Fill Pipe Every 25 Stands 21 :30 - 22:00 0.50 DRILL P PROD1 Held PJSM - Service Tesco Top Drive, Traveling Blocks, Swivel, And Drawworks 22:00 - 23:30 1.50 DRILL P PROD1 Held PJSM - Slip And Cut 85 Feet Of 1 3/8" Drill Line - Circulate Drill Pipe Volume 23:30 - 00:00 0.50 DRILL P PROD1 Held PJSM - Continue To RIH w/ 81/2" Directional BHA On 5" DP To 10,600' With No Problems - Connect Top Drive - Break Circulation And Take Check Shot Survey 3/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM - RIH w/ 81/2" Directional BHA On 5" DP From 10,600' To 11,971' With No Problems 01 :00 - 01 :30 0.50 DRILL P PROD1 Held PJSM - Connect Top Drive And Break Circulation - Wash And Ream As Precaution From 11,971' To 12,072' - RPM 80, Motor RPM 154, Torque 10,000 FULbs, Pump Rate 533 GPM, SPP Off Bottom 2,800 Psi. String Weight Up 265,000# String Weight Down 200,000# String Weight Rotating 225,000# 01 :30 - 02:00 0.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,072' to 12,078'. WOB Rotating 25,000# To 35,000#, WOB Sliding 35,000# *NOTE* Very Slow ROP (9 To 12 FPH) 02:00 - 02:30 0.50 DRILL P PROD1 Pump Nut Plug Sweep, Condent, And SAP Make Sure Bit Not Balled Up 02:30 - 00:00 21.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,078' to 12,418' WOB Rotating 35,000# - 40000#, WOB Sliding 35,000# To 42,000#, RPM 80-100, Motor RPM 154, Torque Off Bottom 9,000 ft / Ibs - On Bottom 10,000 ft / Ibs, Pump Rate 533 gpm, SPP Off Bottom 2,850 psi, On Bottom 2,950 psi. String Weight Up 260,000#, String Weight Down 215,000#, String Weight Rotating 235,000# - ART = 6.96 hrs, AST = 9.38 hrs. 3/9/2003 00:00 - 19:30 19.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,418' to 12,922' WOB Rotating 35,000# - 45000#, WOB Sliding 35,000# To 45,000#, RPM 55, Motor RPM 154, Torque Off Bottom 9,000 ft / Ibs - On Bottom 11,000 ft / Ibs, Pump Rate 508 gpm, SPP Off Bottom 2,980 psi, On Bottom 3,150 psi. String Weight Up 285,000#, String Weight Down 210,000#, String Weight Rotating 245,000# - ART = 10.55 hrs, AST = Printed: 3/24/2003 9:13:41 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Description of Operations 3/912003 00:00 - 19:30 From -To Hours Task Code NPT Phase PROD1 4.68 hrs. Date 19:30 - 22:00 22:00 - 00:00 3/10/2003 00:00 - 00:45 00:45 - 04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 08:30 08:30 - 09:00 09:00 - 18:30 18:30 - 20:30 19.50 DRILL P 2.50 DRILL P 2.00 DRILL P 0.75 DRILL P 3.25 DRILL P 0.50 DRILL N 2.50 DRILL P 1.50 DRILL P 0.50 DRILL P 9.50 BOPSUR P 2.00 DRILL P Formation Tops: MD TVD Tuffs 12,446' 9,062' PROD1 Rotate And Reciprocate Drill String While Circulating Hole Clean At 12,922' - RPM 55, Motor RPM 147, Torque Off Bottom 9,000 ft I Ibs, Pump Rate 508 gpm, SPP Off Bottom 2,980 psi, String Weight Up 285,000#, String Weight Down 210,000#, String Weight Rotating 245,000# - Stand Back 4 Stands While Circulating From 12,922' To 12,538' PROD1 Held PJSM Blow Down Tesco Top Drive - POH w/8 1/2" Directional BHA On 5" DP From 12,538' To 10,601' With No Hole Problems Over Pull Maximum At 20,000# Average Drag 10,000# - Connect Tesco Top Drive And Break Circulation - Take Benchmark Survey At 10,601' For JORPS Compliance - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Tesco Top Drive PROD1 Held PJSM Continue To POH wI 81/2" Directional BHA On 5" DP From 10,601' To 9,929' Inside Window With No Hole Problems Maximum Over Pull 25,000# Average Drag 10,000# - Flow Check Well (OK) PROD1 Held PJSM POH wI 81/2" Directional BHA On 5" DP From 9,929' To 4,498' Pipe Came Wet Mix Second Dry Job FLUD PROD1 Continue To POH With 5" Drill Pipe - While Filling Trip Tank With Mud Mix Gun Line The Valve On The Hopper Wasn't Closed Completly Causing Mud To Come Out Of Mixing Hopper - Mud Spilled To Floor And Traveled Outside Spilling 10 Gallon Of Drilling Mud Into Secondary Containment Outside Below Pallet Lift - See LCIR No. 2003-IR-455475 - Secure Well With Safety Valve And Clean Up Area - Notify ACS And Anchorage Drilling Superintendent Of Spill PROD1 Held PJSM POH wI 81/2" Directional BHA On 5" DP From 4,498' To 817' PROD1 Held PJSM POH Standing Back 7 Stands 5" HWDP, Daily Hyd. Drilling Jars And 1 Stand Flex Drill Collars In Mast - Flush BHA With Fresh Water- Down Load MWDILWD Tools -UD Remainder Of BHA NO.5 UD FEMWD wI TM-DM-RLL-DGR -EWR, String Stab, Float Sub, Break 81/2" Smith Bit And Lay Down Sperry Sun Mud Motor - Monitor Well Bore Static - Calculated Fluid Displacement 114 bbls. Actual 129 bbls. PROD1 Clear Rig Floor And Wash Off Mud PROD1 Hold Pre-Job Safety Meeting - Remove Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Spaulding - Test Annular At 250 Psi. Low And 3,000 Psi. High, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 4,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment - Pull Test Plug And Install Wear Bushing - Blow Down Choke Manifold And Kill Lines. PROD1 Monitor Well Bore (Static) - Held PJSM P/U Adjustable Gauge Printed: 3/24/2003 9;13:41 AM ) ') Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2003 18:30 - 20:30 2.00 DRILL P PROD1 Stabilizer, Float Sub, And 7" Sperry Drill Mud Motor With 1.22 Deg. Bent Housing - M/U 8 1/2" Smith PDC Bit - P/U FEMWD w/ RLL-GR-RES-DM-CTN-SLD And TM -Initalize MWD/LWD Tools - M / U Top Drive And Tested MWD/LWD Tools At 444 GPM 1,200 Psi. (OK) - Blow Down Top Drive 20:30 - 21 :45 1.25 DRILL P PROD1 Held PJSM For Radioactive Sources - Load Sources In BHA No.6 - RIH w/ Remainder Of BHA 3 x Flex Drill Collars, Daily Hyd. Drilling Jars And 20 x 5" HWDP 21:45 - 00:00 2.25 DRILL P PROD1 Held PJSM - RIH w/8 1/2" Directional BHA On 5" DP From Mast From 852' To 4,653' - Fill Pipe Every 25 Stands 3/11/2003 00:00 - 02:30 2.50 DRILL P PROD1 Held PJSM - RIH w/8 1/2" Directional BHA On 5" DP From Mast From 4,653 To 9,890' - Filled Pipe Every 25 Stands 02:30 - 03:00 0.50 DRILL P PROD1 Held PJSM - Serviced Tesco Top Drive, Traveling Blocks, Swivel, And Drawworks 03:00 - 03:30 0.50 DRILL P PROD1 Connected Top Drive And Broke Circulation Oriented 90 Degree's Left Of High Side Through Window From 9,890' To 9,985' 03:30 - 04:30 1.00 DRILL P PROD1 Circulated Bottoms Up - Recorded ECD Base Line At 11.19 PPG With 10.4 PPG Clean Mud At 9,985' 04:30 - 06:00 1.50 DRILL P PROD1 Held PJSM - RIH w/8 1/2" Directional BHA On 5" DP From 9,985' To 10,607' Connected Top Drive And Took Benchmark Survey For JORPS Compliance - Continued To RIH From 10,607' To 12,863' With No Problems. Broke Circulation every 15 stands - Calculated Fluid Gain 143 bbls. Actual 131 bbls. 06:00 - 06:30 0.50 DRILL P PROD1 Held PJSM - Connected Top Drive And Broke Circulation - Washed And Reamed As Precaution From 12,863' To 12,922'- RPM 55, Motor RPM 154, Torque Off Bottom 9,000 ft /Ibs - Pump Rate 508 gpm, SPP Off Bottom 2,980 psi, String Weight Up 285,000#, String Weight Down 210,000#, String Weight Rotating 245,000# 06:30 - 00:00 17.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,922' to 13,665' WOB Rotating 15,000# - 22,000#, WOB Sliding 10,000# To 15,000#, RPM 70, Motor RPM 139, Torque Off Bottom 14,000 ft /Ibs - On Bottom 17,000 ft /Ibs, Pump Rate 478 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,150 psi. String Weight Up 325,000#, String Weight Down 230,000#, String Weight Rotating 268,000# - ART = 9.60 hrs, AST = 2.68 hrs. Preliminary Formation Tops: MD TVD TUFFS 12,446' 9,062' HRZ 13,083' 9,593' LCU 13,408' 9,867' K3A 13,408' 9,867' K2B 13,508' 9,950' K2A 13,683' 10,097' 3/12/2003 00:00 - 06:00 6.00 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 13,665' to 14,048' TD. WOB Rotating 15,000# - 22,000#, WOB Sliding 10,000# To 15,000#, RPM 70, Motor RPM 139, Torque Off Bottom 12,000 ft /Ibs - On Bottom 14,000 ft /Ibs, Pump Rate 478 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,150 psi. String Weight Up 320,000#, String Weight Down 230,000#, String Weight Rotating 268,000# Printed: 312412003 9: 13:41 AM ) BP Operations Summary Report Page 12 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From'" To Hours Task Code NPT Phase Description of Operations 3/12/2003 06:00 - 10:30 4.50 DRILL P PROD1 Pumped and Circulated Hi-Vis Sweep, Pump Rate 500 gpm, 2,850 psi. Circulated 4 x Bottoms Up, Rotated and Reciprocated while Circulating. RPM 100, String Weight Up 320,000#, String Weight Down 230,000#, String Weight Rotating 268,000#. Flow Checked Well, Static. 10:30 - 14:30 4.00 DRILL P PROD1 Made Wiper Trip from 14,048' to Window at 9,976'. Maximum Overpull 30,000#, Average Drag 15,000#. Calculated Fill = 32.5 bbls, Actual Fill = 50 bbls. 14:30 - 15:00 0.50 DRILL P PROD1 Serviced Rig, Flow Checked Well, Static. 15:00 - 17:30 2.50 DRILL P PROD1 RIH after Wiper Trip From 9,976' - Connect Top Drive And Wash Last Stand To Bottom At 14,048' - No Problems On Trip 17:30 - 22:30 5.00 DRILL P PROD1 Pumped and Circulated Hi-Vis Sweep, Pump Rate 500 gpm, 2,850 psi. Circulated 4 x Bottoms Up, Rotated and Reciprocated while Circulating. RPM 100, String Weight Up 320,000#, String Weight Down 230,000#, String Weight Rotating 268,000#. Flow Checked Well, Static - Spot 300 bbl. Liner Running Pill - Flow Checked Well, Static 22:30 - 00:00 1.50 DRILL P PROD1 Held PJSM - POH (Wet) w/ 8 1/2" Directional BHA On 5" DP From 14,048' To 12,895' (SLM) - Blow Down Tesco Top Drive- Continue To POH To 12,511' With No Hole Problems Over Pull Maximum At 35,000# Average Drag 15,000# 3/13/2003 00:00 - 02:30 2.50 DRILL P PROD1 Continue To POH (SLM) From 12,511' To 10,607' With No Hole Problems Over Pull Maximum At 35,000# Average Drag 15,000# - Connect Tesco Top Drive And Break Circulation - Take Benchmark Survey At 10,607' For JORPS Compliance - Drop Rabbit With Tail And Continue To POH From 10,607' To 9,918' - Calculated Fill = 32.5 bbls, Actual Fill = 57 bbls. 02:30 - 03:00 0.50 DRILL P PROD1 Monitor Well Bore (Static) - Pump Dry Job - Blow Down Tesco Top Drive - Wash And Clean Rig Floor 03:00 - 08:00 5.00 DRILL P PROD1 Held PJSM - POH w/ 81/2" Directional BHA On 5" DP From 9,918' (SLM) To 852' 08:00 - 08:30 0.50 DRILL P PROD1 Held PJSM - Stood Back 1 Joint 5" Drill Pipe And 20 Joints Of 5" HWDP 08:30 - 09:00 0.50 DRILL P PROD1 Held PJSM - Laid Down Daily Hyd. Drilling Jars, 2 x Non Mag Flex Drill Collars 09:00 - 11 :00 2.00 DRILL P PROD1 Held PJSM For Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - POOH And Laid Down Remainder Of BHA 1 Flex Drill Collar, FEMWD CTN-SLD-RLL-DGR-EWR, Adjustable Gauge Stab, And Float Sub - Removed Smith PDC Bit And Laid Down Sperry Mud Motor 11 :00 - 11 :30 0.50 DRILL P PROD1 Held PJSM - Cleared Rig Floor Of 81/2" Drilling Tools 11 :30 - 14:00 2.50 CASE P CaMP Held PJSM - Rigged Up Casing Tools And Equipment 14:00 - 14:30 0.50 CASE P CaMP Held Safety Meeting With All Personal Regarding 4 1/2" Liner Running Operation 14:30 - 22:30 8.00 CASE P CaMP P / U And Made Up 98 Jts, 4 1/2" 12.6# L-80 13 Cr Liner. P / U Shoe Track And Bakerlocked, Make Up Torque At 8,560 ft/lbs- Verified Floats Working, RIH With 11 Joints 4 1/2" Liner, P / U 2 Marker Joints, Continue To RIH w/ 98 Total Jts. 22:30 - 23:30 1.00 CASE P CaMP Held PJSM - Changed out to 5" DP Elevators - M / U Baker Flex Lock Liner Hanger, ZXP Packer w/ HRD Setting Tool, Liner Tie Back Sleeve, And Running Tool - P / U (1) 5" Drill Pipe Pup Joint, RIH w/ 1 Stand 5" Drill Pipe From Mast 23:30 - 00:00 0.50 CASE P CaMP Circulated 41/2" Liner Volume At 182 GPM With 475 Psi. - Printed: 3/24/2003 9: 13:41 AM '.) ') BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2003 23:30 - 00:00 0.50 CASE P CaMP Recorded Liner Weights- String Weight Up 100,000#, String Weight Down 98,000#, Block Weight 52,000# 3/14/2003 00:00 - 01 :00 1.00 CASE P CaMP Continued To Circulate 4 1/2" Liner Volume - Changed Out Bales And Pick Up 5" Elevators - Picked Up Rig Floor Area 01 :00 - 04:00 3.00 CASE P CaMP Held PJSM RIH w/ 98 Jts, 4 1/2" 12.6# 13 Cr Liner On 5" Drill Pipe From 4,239' To 9,943' - Recorded Pick Up Slack Off Weights And Filled 5" Drill Pipe Every 10 Stands 04:00 - 06:00 2.00 CASE P CaMP 06:00 - 07:00 CaMP 1.00 CASE P 07:00 - 09:00 2.00 CASE P CaMP 09:00 - 09:30 0.50 CASE P CaMP 09:30 - 12:30 3.00 CASE CaMP P Stand Depth Up Weight Down Weight 1 4,239' 100K 98K 10 5,187' 120K 115K 20 6,138' 130K 125K 30 7,090' 140K 135K 40 8,042' 160K 150K 50 8,994' 175K 160K 60 9,943' 185K 160K Held PJSM M/U Top Drive Circulate Liner Volume And Annular Volume - Pump Rate 800 GPM With 800 Psi. String Weight Up 185,000#, String Weight Down 160,000#, Rotating Weight 182,000# - RPM 15 Torque 4,000 ftllbs Held PJSM - M/U Cement Head With 5" DP Pup Joint (10') Safety Valve, And 5" DP Pup Joint (15') Place On Pipe Lay Down Machine - Rig Up Line To Fill 5" Drill Pipe On The Fly In Open Hole Section - Blow Thru Cement Lines And Stand Pipe Manifold - Rig Up Cement Head Manifold And Wash Up Line Held PJSM RIH w/ 98 Jts, 41/2" 12.6 lb. 13 Chrome Liner On 5" Drill Pipe From 9,943' To 14,043' With No Problems - Fill 5" Drill Pipe On The Fly Pick Up Cementing Head And Make Up To Tesco Top Drive- Install Manifold And Circulating Lines - Secure With Safety Lines - Work Casing String And Establish Circulation - Tag Bottom At 14,048' With No Problems. 4-1/2" Liner Set As Follows: Item Reamer Shoe 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr Float Collar 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr Latch Collar 9 Jts 4-1/2" 12.6# L-80 Hydril563 Lnr 4-1/2" 12.6# L-80 Hydril563 Mkr Jt 4-1/2" 12.6# L-80 Hydril 563 Mkr Jt Length 2.92' 42.38' 1.50' 42.38' 1.69' 379.91 ' 19.83' 19.84' 87 Jts 4-1/2" 12.6# L-80 Hydril 563 Lnr 3,674.59' Cross Over Bushing 5.24' Liner Hanger 9.38' RS Nipple 2.83' ZXP Packer 7.64' Tie Back Sleeve 10.97' Stage Up Pump Rates as Follows: Rate Pressure 5.0 BPM 800 psi 7.5 BPM 1,400 psi Top At 14,045.08' 14,002.70' 14,001.20' 13,958.82' 13,957.13' 13,577.22' 13,557.39' 13,537.55' 9,862.96' 9,857.72' 9,848.34' 9,845.51' 9,837.87' 9,826.90' Printed: 3/24/2003 9:13:41 AM ) ') Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Date From - To Hours Task Code NPT Phase 3/14/2003 09:30 - 12:30 COMP 3.00 CASE P 12:30 - 13:30 1.00 CASE N SFAL COMP 13:30 - 14:00 0.50 CASE N RREP COMP 14:00 - 15:45 1.75 CEMT P COMP 15:45 - 18:00 2.25 CEMT P COMP Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Description of Operations 9.5 BPM 2,000 psi String Weight Up 270,000#, String Weight Down 200,000# Continue To Circulate to Cool and Condition the Hole While Reciprocating Casing String Continuously. Continue To Circulate Well At 9.5 BPM With 2,000 Psi. - Dowell Batch Mixer Valve Froze - Ordered Out Heater To Thaw While Circulating At 7 BPM With 1,050 Psi. Cementing Line Tee Washed Out - Repaired Pin Hole And Tested Line To 4,000 Psi. (Test Good) Held PJSM wi Dowell, Peak Truck Driver and Rig Crew - Batch Mix Cement And Continue To Reciprocate And Circulate At 7 BPM With 1,050 Psi. - String Weight Up 270,000#, String Weight Down 200,000# Switched Over To Dowell. Pumped 5 bbls Of Seawater To Flush The Lines And To Establish Circulation. Shut In Cement Manifold And Tested Lines To 4,500 psi, OK. Pumped 75 bbls Of Mud Push At 5.0 bpm, 700 psi. Pumped 185 bbls (866 sx) 15.8 ppg Latex Cement wi 0.40% SWOC Dispersant, 0.30% BWOC Retarder, 3.00 gallsk Expanding Agent, 0.20 gallsk Antifoam, 2.00 gallsk GASBLOK. Pumped Cement At The Following Rates: Pumped Rate Pressure 5.0 bbls 5.25 bpm 1,000 psi 25.0 bbls 7.00 bpm 1,525 psi 50.0 bbls 6.75 bpm 1,275 psi Slowed Rate Due To Vibration In Cement Line 75.0 bbls 5.00 bpm 700 psi 100.0 bbls 5.00 bpm 775 psi 125.0 bbls 5.00 bpm 760 psi 150.0 bbls 4.00 bpm 563 psi 185.0 bbls 4.00 bpm 522 psi Cleaned Up Behind Plug, Dropped Drill Pipe Dart And Pumped Out Of Manifold wi 5 bbls Of Water At 3.00 bpm, 125 psi. Displaced wi 224 bbls Of Mud At The Following Rates: Pumped Rate Pressure 50.0 bbls 14.0 bpm 1,200 psi 100.0 bbls 14.0 bpm 3,200 psi 150.0 bbls 14.0 bpm 3,350 psi slw'd Pmps to 3.5 bpm 850 psi Drill Pipe Dart Hit wi 175.4 bbls Pumped, Pressure Increased To 1,100 psi, Wiper Plug Sheared, Pressure Dropped to 850 psi, Increased Rate 180.0 bbls 12.0 bpm 3,000 psi 190.0 bbls 12.0 bpm 3,000 psi 200.0 bbls 12.0 bpm 3,000 psi 210.0 bbls 6.0 bpm 1,500 psi 220.0 bbls 4.0 bpm 1,250 psi Wiper Plug Bumped wi 224 bbls Pumped. Cement in Place @ 1800 Hrs. *NOTE* During Cementing Operation 5 Gallon Of Cement Was Spilled Onto Secondary Containment In Cellar Area Due To A Printed: 3/24/2003 9: 13:41 AM ) \ l BP Page 15 of 18 Operations Summary Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: From - To Hours Task Code NPT Phase Description of Operations 3/14/2003 15:45 - 18:00 2.25 CEMT P CaMP Union Backing Off On Cement Line. 18:00-18:15 0.25 CASE P CaMP Increased Pressure To 2,500 psi To Set Liner Hanger, Bled Off Pressure To 500 Psi. Slacked Off On Liner To Confirm Hanger Set - Bled Pressure Off And Check Floats (Floats Held). Pressured Up To 4,000 psi To Release Running Tool From Liner, Bled Off Pressure To 1,000 Psi. PI U On DP (215K) Confirm Running Tool Released - Continue To PI U to Expose Setting Dogs. Rotate And Set Down On Liner Top wI 50,000# and Observed ZXP Packer Set. Pressure Up On Liner To 1,000 psi, PI U On Drill Pipe 10', Observed Pressure Drop To 0 psi To Reconfirm Liner Running Tool Released from Liner. 18:15 - 19:15 1.00 CASE P CaMP Circulated Bottoms Up To Clean Possible Cement Out Of Hole. Pump Rate 14 bpm, 2,800 psi. Circulated Back 24 bbls Of Contaminated Mud Push Spacer. 19:15 -19:45 0.50 CASE P CaMP Held PJSM. Closed Top Pipe Rams and Pressure Tested Liner Top And Casing To 2,000 psi fl 5 minutes. OK. Bled Down Pressure And Opened Top Pipe Rams - Blow Down Kill Line 19:45 - 21 :45 2.00 CASE P CaMP Held PJSM wI Peak Truck Drivers And Rig Crew - Displaced The Well wI Clean Seawater. Pump Rate 15 bpm, 2,900 psi. - Pump 100 bbls Dirt Magnet - 50 bbls Hi-Vis Pill - Displace With 685 bbls. Sea Water 21:45 - 23:00 1.25 CASE P CaMP Held PJSM - Break And Lay Down Baker Plug Dropping Head And Circulating Lines - Clear Rig Floor - Blow Down Cement Line - Mix Additional 120 bbls Fluid For Hole Cleaning And Pipe Displacement 23:00 - 23:30 0.50 CASE P CaMP Held PJSM - Make Up Head Pin And Circulate 60 bbls Additional Volume For Hole Cleaning - Pump Rate 10 bpm, 1,500 psi. 23:30 - 00:00 0.50 CASE P CaMP Held PJSM - POH wI Baker Liner Running Tool Laying Down 5" Drill Pipe From 9,826' To 9,550' 3/15/2003 00:00 - 08:00 8.00 CASE P CaMP Held PJSM - POH Laying Down 5" Drill Pipe From 9,550' To Baker Running Tool - Break And Lay Down Same 08:00 - 09:30 1.50 CASE P CaMP Held PJSM - RIH w/7 Stands Of 5" Heavy Weight Drill Pipe And 37 Stands Of 5" Drill Pipe From Mast 09:30 - 13:00 3.50 CASE P CaMP Held PJSM - POH Laying Down 5" Drill Pipe From 3,999' - Clear Rig Floor 13:00 - 13:30 0.50 BOPSURP CaMP Held PJSM - Rig Up Retrieving Tool And Pull Wear Bushing 13:30 - 15:00 1.50 RIGU P CaMP Held PJSM - Rig Up Tubing Tongs, Compensator, And Other Completion Running Equipment 15:00 - 16:00 1.00 EVAL P CaMP Held PJSM - Close Blind Rams - Test 9 5/8" Casing And 41/2" Liner To 3,500 Psi - Hold For 30 Minutes And Record On Circle Chart - Hold Pre-Job Safety Meeting With Rig Crews, Service Hands Regarding 4 1/2" Completion Running Operation 16:00 - 17:00 1.00 RUNCOrvP CaMP Pick Up And RIH With 4 1/2" Completion Per Well Program - Make Up Tail Pipe Assembly - Baker Lock And Torque TC II Connections Below Baker S-3 Packer To 2,900 fUlbs - Pick Up "X" Nipple Assembly Verify D-16 Plug Installed 17:00 - 00:00 7.00 RUNCOrvP CaMP Pick Up And RIH With 41/2" 12.61b 13 Chrome Vam Ace Tubing Joints 1 To 100 - Make Up Torque At 3,650 Nibs - Test Completion String Every 50 Joints To 3,500 Psi For 10 Minutes (Test Good) 3/16/2003 00:00 - 07:30 7.50 RUNCOrvP CaMP Held PJSM - M I U and RIH With 4-1/2" 12.6# 13Cr Vam Ace Tubing Joints 100 To 193 - Make Up Torque 3,650 ft I Ibs - Printed: 3/24/2003 9: 13:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/16/2003 ) ) BP Page 16 of 18 Operations Summary Report 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 00:00 - 07:30 From - To Hours Task Code NPT Phase 07:30 - 08:00 08:00 - 09:00 09:00 - 12:00 12:00 - 13:30 13:30 - 14:30 14:30 -15:00 7.50 RUNCOIVP COMP 0.50 RUNCOIVP COMP 1.00 RUNCOIVP COMP 3.00 RUNCOIVP COMP 1.50 RUNCOIVP COMP 1.00 RUNCOIVP COMP 0.50 RUNCOIVP COMP 15:00 - 16:00 1.00 RUNCOIVP COMP 16:00 - 17:00 1.00 RUNCOIVP COMP 17:00 - 18:00 1.00 RUNCOIVP COMP 18:00 - 19:30 1.50 RUNCOIVP COMP 19:30 - 22:30 3.00 RUNCOIVP COMP 22:30 - 23:00 0.50 RUNCOIVP COMP 23:00 - 00:00 1.00 RUNCOIVP COMP Descri ptionof· Operations Tested Tubing Every 50 Joints To 3,500 Psi For 10 Minutes (All Tests Good) Held PJSM wi Halliburton and Drilling Crew on Rigging Up and Running Control Line. R I U Control Line Equipment. M I U SSSV Assembly, M I U Control Lines and Tested Same to 5,000 psi fl 15 minutes, OK. Ran 4-1/2" 12.6# 13Cr Vam ACE Tubing Total Joints Run 228. String Weight Up 150,000#, String Weight Down 130,000#. M I U Jts 229 & 230, Tagged Up at 9,861' wi 13.1' of Jt 230. Held PJSM. Broke out and LID Jts 230, 229 & 228. M I U Pup Jt - Length 8.13', M I U Jt 228, M I U Tubing Hanger and Landing Jt. M I U Control Lines to Tubing Hanger. Tested Same to 5,000 psi fl 15 minutes, OK. Drained BOP Stack, RIH and Landed Tubing Hanger. M I U Circulating Head and Tested Tubing and Hanger to 3,500 psi fl 10 minutes, OK. Completion Equipment Set At The Following Depths: Item Length Depth XN Nipple Assembly 22.21' 9,856.60' X Nipple Assembly 20.81' 9,813.58' S-3 Packer Assembly 24.4 7' 9,789.11' X Nipple Assembly 20.75' 9,768.36' #1 GLM Assembly 28.29' 9,740.07' 20 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 839.47' 8,960.00' #2 GLM Assembly 28.36' 8,872.24' 32 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 1,343.40' 7,528.84' #3 GLM Assembly 28.33' 7,500.51' 36 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 1,511.42' 5,989.09' #4 GLM Assembly 28.44' 5,960.65' 51 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 2,135.64' 3,825.01' #5 GLM Assembly wi DCK Valve 28.41' 3,796.60' 54 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 2,263.30' 1,533.30' SSSV Assembly 22.39' 1,510.91' 34 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 1,422.07' 88.84' 4-1/2" 12.6# 13CrVam Ace Pup Jt 8.13' 80.71' 1 Jt 4-1/2" 12.6# 13Cr Vam Ace Tbg 38.86' 41.85' Tubing Hanger 4.99' 36.86' RID Completion Handling Equipment. Held PJSM - Rig Up Haliburton Slick Line Unit And Pulling Tools Slick Line Run NO.1 - RIH With Tools And Pull Dummy Valve In SVLN - POH And Break Down Dummy Valve Retrieving Tools Slick Line Run No.2 - Make Up Equalizer Tools - RIH To 0-16 Test Plug And Equalize - POH - Break And Lay Down Tools Slick Line Run NO.3 - Make Up Pulling Tools For 0-16 Plug - RIH And Latch Up - POH With 0-16 Plug - Lay Down Plug And Break Down Tools Slick Line Run No.4 - Make Up 3.625 Drift And Sample Bailer - RIH To 9,950' - POH - Break And Lay Down Tools Slick Line Run NO.5 - Make Up RHC-M Plug And Running Tools - RIH With RHC-M Plug And Set In "XN" Nipple Printed: 3/24/2003 9: 13:41 AM ) ') BP Operations Summary Report Page 17 of 18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date From- To Hours Task Code NPT Phase Description of Operations 3/17/2003 00:00 - 02:00 2.00 RUNCOrvP CaMP Slick Line Run NO.5 - RIH With RHC-M Plug And Set In "XN" Nipple - Shear Off RHC Sleeve - POH - Break And Lay Down Tools 02:00 - 04:00 2.00 RUNCOrvP CaMP Slick Line Run NO.6 - Make Up Check Set Tool - RIH And Verify That RHC-M Plug Set In "XN" Nipple At 9,844' - POH - Break And Lay Down Tools 04:00 - 05:00 1.00 RUNCOrvP CaMP Slick Line Run NO.7 - Make Up Setting Tool And Dummy Sleeve - RIH And Set Dummy Sleeve In SVLN Valve At 1,520' - Test Control Lines And Dummy Sleeve - Shear Off Of Sleeve And POH - Break And Lay Down Tools 05:00 - 05:30 0.50 RUNCOrvP CaMP Held PJSM - Rig Down Haliburton Slick Line Unit - Clear Rig Floor 05:30 - 09:30 4.00 RUNCOrvP CaMP Held PJSM - Rig Up Circulating Hoses And Equipment - Energize Lock Down Studs - Reverse Circulate 600 BBLS. Corrosion Inhibitor At 3 BPM with 300 Psi. 09:30 - 11 :30 2.00 RUNCOrvP CaMP Held PJSM - Drop Ball And Rod & Allow To Seat - Pressure Up On Tubing String To 2,500 Psi. To Set Packer - Continue To Pressure Up Down Tubing To 3,500 Psi. And Test For 30 Minutes Record On Circle Chart - Bleed Back Tubing Pressure To 1,500 Psi. And Test Annulus To 3,000 Psi. For 30 Minutes - Bleed Off Tubing Pressure Quickly And Shear DCK Valve - Pump Down The Tubing And Annulus To Verify That DCK Valve Sheared (OK) 11 :30 - 12:00 0.50 RUNCOrvP COMP Held PJSM - Blow Down All Circulating Lines - Back Out 4 1/2" Landing Joint And Lay Down 12:00-13:00 1.00 RUNCOrvP CaMP Held PJSM - Set Two Way Check Valve And Test From Below To 1,000 Psi. (Test Good) - Blow Down Stand Pipe, Choke Manifold, Choke And Kill Lines 13:00 - 17:30 4.50 BOPSUR P CaMP Held PJSM - Nipple Down BOP And Related Equipment 17:30 - 18:30 1.00 WHSUR P CaMP Held PJSM - Clean Off Tubing Hanger - Terminate DHCV Ports And Test Control Line's To 5,000 Psi. (Test Good) 18:30 - 20:30 2.00 WHSUR P CaMP Held PJSM - Orient And Nipple Up FMC Adaptor Flange And Production Tree - Test Adaptor Flange Void To 5,000 Psi. (Test Good) 20:30 - 21 :30 1.00 WHSUR P CaMP Held PJSM - Test Production Tree And Record On Circle Chart To 5,000 Psi. For 15 Minutes (Test Good) 21 :30 - 22:30 1.00 WHSUR P CaMP Held PJSM - Rig Up DSM Lubricator And Pull Two Way Check Valve - Rig Down Lubricator And Clear Rig Floor 22:30 - 23:00 0.50 WHSUR P CaMP Held PJSM - Rig Up Circulating Lines And Equipment 23:00 - 23:30 0.50 WHSUR P CaMP Held PJSM - Test Little Red Services Surface Lines And Equipment At 1,000 Psi. (Test Good) - Pump 110 Barrels Of Diesel At 4 BPM With 850 Psi. 23:30 - 00:00 0.50 WHSUR P CaMP Held PJSM - U-Tube Diesel From Annulus To Tubing 3/18/2003 00:00 - 00:30 0.50 WHSUR P CaMP Held PJSM - U-Tube Diesel From Annulus To Tubing 00:30 - 01 :30 1.00 WHSUR P CaMP Held PJSM - Suck Back Diesel In U-Tube Lines - Drain And Rig Down Same 01 :30 - 02:00 0.50 WHSUR P CaMP Held PJSM - Pick Up T-Bar And Install Back Pressure Valve - Install Tree Cap And Test Back Pressure Valve From Below At 1,000 Psi. For 5 Minutes 02:00 - 03:00 1.00 WHSUR P CaMP Held PJSM - Remove Secondary Annulus Valve And Install Flange - Install Tree And Annulus Gauges - Secure Well - Clean Up Well House And Cellar Area Printed: 312412003 9: 13:41 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 18 of 18 BP O.perations Summary Report 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE DOYON DOYON 15 Start: 2/23/2003 Rig Release: 3/18/2003 Rig Number: Spud Date: 2/23/2003 End: 3/18/2003 Date Description öf Operations From - To Hours Task Code NPT Phase 3/18/2003 02:00 - 03:00 1.00 WHSUR P CaMP *NOTE* - Rig Released From Well Work On 3-17E / K-30 At 03:00 Hours On 3-18-2003 Printed: 3/24/2003 9: 13:41 AM ') Well: Field: API: Permit: 3-17E/K-30 Endicott Field I Endicott Pool 50-029-21946-05 202-247 Accept: Spud: Release: Ri~r 02-23-03 03-04-03 03-18-03 Doyon 15 POST-RIG WORK 03/19/03 WELL SHUT IN UPON ARRIVAL. ASSIST VALVE CREW PULL BPV. PULL DSSSV. PULL BALL & ROD. PULL RP SHEAR VALVE FROM STA #5. PULL DGLV FROM STA #4. SET GENERIC DESIGN. LGLV(1/4" TRO 1500#) @ STA #5,5/16" OGLV @ STA #4. PULL RHC PLUG BODY. 03/20/03 . MIRU CT #9. PU 2.5" JSN. RIH. BEGIN CIRCULATING OUT MUD AT 98001. CIRC OUT TO A HARD TAG OF 13832. POH AT 80%. PICK UP MOTOR AND MILL. DRIFT WI 2-7/8" DUMMY GUN. SAT DOWN @ 137581 SLM 03/21/03 RIH WITH 3.25" THREE BLADED CEMENT MILL. MILL TO 13940 (UP). SPORADIC MOTOR WORK SEEN FROM INITIAL TAG OF 13842 TO TD. PUMP FLO-PRO SWEEPS OFF BTM, OPEN CIRC SUB, & CIRC TO SURFACE @ 1.8 BPM. LAY IN DIESEL (FOR UNDERBALNCE) 1:1 FROM 128501 TO 25001, SLOWED TO 90% FROM 2500 TO SURFACE (2% KCL FROM 12850 - 139401). 03/22/03 MADE 3 RUNS. 1 ST RIH (GR-CCL-PRESS-TEMP)- LOGGED PRIMARY DEPTH CONTROL LOG FROM TD TO 78001 MD. TAGGED TD @ 139561 MD AS CORRELATED TO PREVIOUS PDC LOG RUN IN CASING ABOVE SIDETRACK. 2ND RIH (GR-CCL-25IGUN)- TIED INTO GAMMA RAY FROM SPERRY SUN MWD LOG AND SHOT 2-7/811 X 251 X 6-SPF PJ-2906 GUN FROM 138431-138681 MD. NO PROBLEMS RIH OR POOH. TAGGED TD @ 139411 MD AS CORRELATED TO MWD LOG. RIH 3 (GR-CCL-10'GUN-PETRODET _MEMORY _PRESSUREGUAGE)- TIED IN TO MWD GR AND LOGGED 30 MIN PRESSURE STOPS @ 136581 MD. OPENED CHOKE SLIGHTLY. RIH AND ON ATTEMPTING TO TIE IN JUST OFF BOTTOM, PULLED TIGHT IN PREVIOUS PERF ZONE. WORKED TOOLS UP AND DOWN UNTIL TOOLSTRING CAME FREE. ABORTED PERFORATING ATTEMPT (SEE TIME LOG FOR DETAILS). TOOK 30 MINUTE PRESSURE STOPS @ 107531 AND 106581 MD. POOH. 03/24/03 RIH WI PRESS-TEMP-GR-CCL-GRADIO-DEFT-SPINNERS TO DETERMINE NATURE OF DOWNHOLE FLUID. FOUND FLUID LEVEL (HYDROCARBON WI DENSITY = 0.95 G/CC) @ 31751 MD. CONTINUE RIH AND FOUND OIL-WATER TRANSITION NEAR 94001 MD (DENSITY INDICATION & STRONG DEFT INDICATION). CONTINUE RIH AND ENCOUNTERED TOOL PROBLEMS NEAR 10,1001 MD. BEGIN POOH TO INSPECT TOOL. TOOL PROBLEM CORRECTED NEAR 70001 MD. CONTINUE RIH. UPON REVIEW OF DATA ALREADY ACQUIRED, ADDITIONAL PASSES ABORTED AND GUN ORDERED. GUN CANCELLED LATER. 03/25/03 ATTEMPT TO HOT OIL TBG. PUMP 85 BBLS OF 180* F DIESEL DOWN TBG. NEEDED 170 BBLS TO REACH PERFS. TBG PRESSURED UP TO 3000 PSI @ 0.2 BPM. 3-17E/K-30 Page 2 ') 03/26/03 PULL LGL V AND S/O GL V FROM STS # 5 AND 4 RESPECTIVELY & DGL VIS FROM STS # 3 AND 1. SET LGLV IN ST # 5 (16//64, TRO 1766#.), SET DGLV IN ST # 4., SET LGLV IN ST # 3 (16/64, TRO 1766#) 03/27/03 SET SOGLV IN STA# 1 22/64. PULL C/S. DRIFT W/ 2.5 PUMP BLR MADE IT THRU TIGHT SPOT (13,824- 13,8431 SLM) TAG @ 13,877' SLM, 13,914' CORRECTED DEPTH. 03/29/03 DRIFT W/ 3.625 CENT SIT DOWN@ 38621 CORRECTED. -- RUN 27/8 X101 DUMMY GUN SIT DOWN @ 138711 CORRECTED. -- RUN 21/2 X 101 DUMMY GUN TO 13,8701 CORRECTED. END3-17: 27/811 201 PERFORATING GUN RAN. 6 SPF, 60 DEGREE PHASING, POWERJET CHARGES. SHOOTING DEPTH WAS 139431-139631. WELL WAS NOT FLOWED DURING PERFORATING DUE TO THE KNOWN RESTRICTION WITHIN THE PERFORATED INTERVAL. TD @ 138661. 1ST RUN MISRUN, 2ND RUN ALL SHOTS FIRED. 04/01/03 PERFORATE 13805-13815 FT MD WITH 2 7/811 HSD @ 6 SPF, 2906 POWERJET CHARGES. SPECIFICATIONS IN 3.511 CASING: LOAD = 15 G / ENTRANCE HOLE = .3611 / PENETRATION = 27.7'1 RAN GUN GAMMA RAY FOR TIE INTO MWD LOG. PULLED TIGHT WITH CCL AT 13821 FT, BOTTOM NOSE AT 13836 FT. WHP BLED FROM 1900 TO 1650 PSI JUST BEFORE SHOOTING. SHOT WITH WELL STILL BLEEDING DOWN, BUT WHP CLIMBED QUICKLY TO 2000 PSI. WHP AT RD = 2050 PSI. Legal Name: Common Name: Test Date 3/4/2003 FIT 3-17E/K-30 3-17E/K-30 Test Type Test Depth (TMD) 9,976.0 (ft) BP L.eak-OffTestSurnmary Test Depth{TVD) 7,734.0 (ft) AMW 9.70 (ppg) SÜrfacePressure Leak Off Pressure (BHP) 950 (psi) 4,847 (psi) 12.06 (ppg) - - Printed: 3/24/2003 9:13:33 AM ) ) ~ oa-¿:)L/7 20-Apr-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3-17E/K-30 Dear: Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,946.10' MD 9976' MD 14,048.00' MD (if Applicalble) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager attachments RECE\VED APR 2 2 2003 Ala*! on & Gas Cons. CommiseiOn Anchorage " Sperry-Sun Drilling Services Alaska State Plane 3 BPXA Endicott DI-SDI, Slot 3-17/J-30A 3-17/J-30 - 3-17E/K-30 Job No. AKMW2298594, Surveyed: 12 March, 2003 Survey Report 17 April, 2003 Your Ref: APlS00292194605 Surface Coordinates: 5970973.83 N, 270243.36 E (700 19' 20.3471" N, 1470 51' 46.9665" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Surface Coordinates relative to Project Coordinates: 970973.83 N, 229756.64 W (Grid) Surface Coordinates relative to Structure Reference: 1590.05 N, 2038.60 W (True) Kelly Bushing: 52.6Oft above Mean Sea Level Elevation relative to Project Elevation: 52.60ft Elevation relative to Structure Reference: 52. 60ft spe'-''-'Y-!5LJr1 DRILLING SeRVices A Halliburton Company )=;:: \I --- V= -, ~ .... ~ ~ Survey Ref: svy744 Sperry-Sun Drilling Services Survey Report for Endicott DI-SDI- 3-17/J-30 - 3-17E/K-30 Your Ref: API 500292194605 Job No. AKMW2298594, Surveyed: 12 March, 2003 .-. BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/1 OOft) 9946.10 47.420 3.570 7660.42 7713.02 5133.72 N 370.75 E 5976093.80 N 270771.10E 5102.92 Tie On Point MWD Magnetic 9976.00 47.420 3.790 7680.65 7733.25 5155.69 N 372.16 E 5976115.71 N 270773.18 E 0.542 5124.77 Window Point 10072.40 49.280 348.830 7744.91 7797.51 5227.18 N 367.41 E 5976187.31 N 270770.63 E 11.739 5196.41 10168.80 53.4 70 349.270 7805.07 7857.67 5301.11 N 353.12 E 5976261.64 N 270758.60 E 4.361 5271.05 10263.89 53.000 346.520 7862.00 7914.60 5375.58 N 337.15 E 5976336.57 N 270744.92 E 2.369 5346.34 10360.97 56.590 351.110 7917.97 7970.57 5453.36 N 321.85 E 5976414.78 N 270732.00 E 5.347 5424.89 -~- 10456.86 57.960 349.240 7969.81 8022.41 5532.84 N 308.07 E 5976494.64 N 270720.67 E 2.175 5505.04 10535.84 60.71 0 346.250 8010.10 8062.70 5599.20 N 293.63 E 5976561.42 N 270708.27 E 4.767 5572.14 10648.49 64.090 345.210 8062.28 8114.88 5695.93 N 269.01 E 5976658.86 N 270686.62 E 3.110 5670.15 10745.37 64.150 345.150 8104.57 8157.17 5780.20 N 246.72 E 5976743.77 N 270666.92 E 0.083 5755.59 10840.78 63.810 343.390 8146.43 8199.03 5862.72 N 223.48 E 5976826.96 N 270646.21 E 1.696 5839.34 10935.4 7 63.460 343.360 8188.48 8241.08 5944.02 N 199.20 E 5976908.96 N 270624.44 E 0.371 5921.92 11030.88 62.900 342.770 8231.53 8284.13 6025.47 N 174.40 E 5976991.14 N 270602.14 E 0.806 6004.70 11126.43 62.430 342.460 8275.40 8328.00 6106.47 N 149.04 E 5977072.88 N 270579.27 E 0.570 6087.05 11225.53 64.040 343.850 8320.03 8372.63 6191.15 N 123.41 E 5977158.30 N 270556.25 E 2.051 6173.10 11320.51 63.820 342.140 8361.77 8414.37 6272.74 N 98.46 E 5977240.61 N 270533.81 E 1.634 6256.01 11417.67 63.310 341.870 8405.03 8457.63 6355.48 N 71.58 E 5977324.14 N 270509.48 E 0.581 6340.20 11512.67 62.950 340.650 8447.96 8500.56 6435.73 N 44.36 E 5977405.19 N 270484.72 E 1.207 6421.91 11609.71 62.710 340.670 8492.28 8544.88 6517.19 N 15.77 E 5977487.48 N 270458.64 E 0.248 6504.92 11706.01 61.050 341.030 8537.66 8590.26 6597.42 N 12.09 W 5977568.53 N 270433.25 E 1.755 6586.65 11801. 12 59.320 339.180 8584.95 8637.55 6675.01 N 40.16 W 5977646.94 N 270407.57 E 2.481 6665.76 11896.65 56.330 338.630 8635.82 8688.42 6750.45 N 69.25 W 5977723.23 N 270380.80 E 3.168 6742.78 11992.66 53.730 339.410 8690.84 8743.44 6823.90 N 97.43 W 5977797.51 N 270354.88 E 2.789 6817.76 12060.02 52.540 337.790 8731.25 8783.85 6874.07 N 117.08W 5977848.26 N 270336.77 E 2.612 6869.01 ---- 12087.87 51.330 337.740 8748.42 8801.02 6894.37 N 125.38 W 5977868.80 N 270329.10 E 4.347 6889.76 12120.71 49.140 338.750 8769.43 8822.03 6917.81 N 134.74 W 5977892.52 N 270320.46 E 7.075 6913.71 12154.79 47.480 338.600 8792.10 8844.70 6941.51 N 143.99 W 5977916.50 N 270311.94 E 4.882 6937.92 12182.81 46.280 337.710 8811.25 8863.85 6960.50 N 151.60 W 5977935.71 N 270304.92 E 4.870 6957.32 12215.89 45.140 337.060 8834_35 8886.95 6982.36 N 160.71 W 5977957.83 N 270296.49 E 3.722 6979.68 12250.99 43.900 336.970 8859.37 8911.97 7005.01 N 170.32 W 5977980.77 N 270287.57 E 3.537 7002.86 17 April, 2003 - 14:33 Page 2 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Endicott D/-SD/- 3-17/J-30 - 3-17E/K-30 Your Ref: AP/500292194605 Job No. AKMW2298594, Surveyed: 12 March, 2003 -~ BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 12283.10 42.670 337.100 8882.75 8935.35 7025.28 N 178.91 W 5978001.30 N 270279.61 E 3.841 7023.61 12312.36 41.480 337.010 8904.47 8957.07 7043.34 N 186.55 W 5978019.58 N 270272.52 E 4.072 7042.08 12344.60 40.410 337.110 8928.82 8981.42 7062.80 N 194.79 W 5978039.28 N 270264.89 E 3.325 7061.99 12375.73 38.770 337.220 8952.81 9005.41 7081.08 N 202.48 W 5978057.79 N 270257.75 E 5.273 7080.69 12408.97 36.970 338.970 8979.05 9031.65 7100.01 N 210.10W 5978076.94 N 270250.72 E 6.306 7100.04 12441.35 35.680 341 .960 9005.13 9057.73 7118.07 N 216.52 W 5978095.20 N 270244.85 E 6.766 7118.45 12471.06 34.620 346.000 9029.43 9082.03 7134.50 N 221.25 W 5978111.76 N 270240.63 E 8.602 7135.13 '_c. 12504.21 33.900 348.560 9056.83 9109.43 7152.70 N 225.36 W 5978130.08 N 270237.08 E 4.859 7153.54 12567.04 32.140 347.580 9109.51 9162.11 7186.20 N 232.43 W 5978163.78 N 270231.04 E 2.927 7187.40 12664.13 32.760 346.630 9191.44 9244.04 7236.98 N 244.06 W 5978214.89 N 270220.97 E 0.827 7238.78 12760.03 33.330 343.160 9271.83 9324.43 7287.45 N 257.69 W 5978265.75 N 270208.89 E 2.060 7289.96 12853.60 31.780 341 .500 9350.70 9403.30 7335.42 N 272.96 W 5978314.17 N 270195.10 E 1.912 7338.75 12885.55 33.940 341.920 9377.54 9430.14 7351.88 N 278.40 W 5978330.79 N 270190.16 E 6.798 7355.50 12981.62 34.880 343.690 9456.80 9509.40 7403.74 N 294.43 W 5978383.11 N 270175.72 E 1.429 7408.22 13076.28 33.410 342.840 9535.14 9587.74 7454.62 N 309.73 W 5978434.44 N 270161.99 E 1.633 7459.91 13172.20 32.370 342.380 9615.68 9668.28 7504.33 N 325.29 W 5978484.60 N 270147.96 E 1.115 7510.45 13268.29 33.270 344.130 9696.44 9749.04 7554.20 N 340.28 W 5978534.90 N 270134.50 E 1.361 7561.12 13363.31 32.850 344.260 9776.07 9828.67 7604.07 N 354.40 W 5978585.19 N 270121.91 E 0.448 7611.74 13459.35 33.740 345.360 9856.35 9908.95 7654.95 N 368.21 W 5978636.4 7 N 270109.67 E 1.120 7663.34 13557.57 33.600 344.980 9938.09 9990.69 7707.59 N 382.15 W 5978689.51 N 270097.35 E 0.258 7716.71 13652.51 33.660 344.420 10017.14 10069.74 7758.31 N 396.02 W 5978740.63 N 270085.03 E 0.333 7768.16 13705.48 33.400 344.300 10061.30 10113.90 7786.48 N 403.91 W 5978769.03 N 270078.01 E 0.507 7796.75 13781.48 33.490 343.950 10124.71 10177.31 7826.77 N 415.37 W 5978809.65 N 270067.79 E 0.280 7837.65 13878.30 33.280 344.300 10205.56 10258.16 7878.02 N 429.94 W 5978861.32 N 270054.80 E 0.294 7889.66 13973.07 31.330 345.060 10285.65 10338.25 7926.86 N 443.33 W 5978910.55 N 270042.91 E 2.102 7939.21 ~ 14048.00 31.330 345.060 10349.66 10402.26 7964.50 N 453.38 W 5978948.48 N 270034.02 E 0.000 7977.38 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 356.619° (True). Magnetic Declination at Surface is 26.386°(25-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14048.00ft., 17 April, 2003 - 14:33 Page 3 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Endicott DI-SDI- 3-17/J-30 - 3-17E/K-30 Your Ref: API 500292194605 Job No. AKMW2298594, Surveyed: 12 March, 2003 BPXA Alaska State Plane 3 The Bottom Hole Displacement is 7977.40ft., in the Direction of 356.742° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9946.10 9976.00 14048.00 7713.02 7733.25 10402.26 5133.72 N 5155.69 N 7964.50 N 370.75 E 372.16 E 453.38 W Tie On Point Window Point Projected Survey '-' Survey tool program for 3-17/J-30 - 3-17E/K-30 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9946.10 0.00 9946.10 7713.02 BP High Accuracy Gyro (3-17) 7713.02 14048.00 10402.26 MWD Magnetic (3-17E/K-30) '-" 17 April, 2003 - 14:33 Page 4 of4 DrillQuest 3.03.02.005 @ìì®rre æ):jWuLb ) :'f !Æ~!Æ~~~!Æ ) AIfA~1iA. OIL A5D GAS CONSERVATION COMMISSION FRANK H. MURKOWSK'. GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 3-17E/K-30 BP Exploration (Alaska) Inc. Permit No: 202-247 (revised) Surface Location: 2524' SNL, 799' WEL, SEC. 08, TI1N, RI7E, UM Bottomhole Location: 158' NSL, 1246' WEL, SEC. 32, TI2N, RI7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required· test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, . / Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this~ day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA 2 AND GAS CONSERVATION COMM. )ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test /I Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 55' Endicott Field I Endicott Pool 6. Property Designation Þ'/1,o2-8( ADL 312828 ßþ 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-17E/K-30 9. Approximate spud date 02/21103 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14015' MD Î 103711 TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 63 0 Maximum surface 3942 (psig, At total depth (TV D) 10276' I 4970 psig Setting Depth y.¥:Jt- Top Bottom - Quantity of Cement Lenath MD TVD MD TVD oS i< (include staae data) 4165' 9850' 7643' 14015' 10371' 750~Class 'G' ALASKA \., WCtA- 'z.1 f1/tJ's ¿¿Æ> z/¿I(O '1 Revised 02/19/03 Change BHL 1 a. Type of work 0 Drill /I Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 270243, Y = 5970974 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM At top of productive interval x = 270109, Y = 5978632 154' SNL, 1145' WEL, SEC. 05, T11 N, R17E, UM I At total depth x = 270017, Y = 5978947 158' NSL, 1246' WEL, SEC. 32, T12N, R17E, UM "' o Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch /I Drilling Program /I Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report /I 20 AAC 25.050 Requirements Contact Engineer Name/Number: Walter Quay, 564-4178 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the for,poin~i~tr e nd correct to the best of my ~nowl~~ge . Signed Fred JOhnson(j /l£e"Í ' Title Semor Dnlhng Engineer . '. " ",';;':.,' .'>.': ,....", .·.··.,.·.::::;çqmijî~~qg;iQ~;PnJy'.''''-:':,:,:;;:,,:,'i.:, ",/i'l: Permit Number API Number ~., proy~1 B?~ See cover letter 202-247 50- 029-21946-05 '~ i <"' I/(j ~ for other reauirements Conditions of Approval: Samples Required 0 Yes IiJ No Mud Log~eqUlred 0 Yes IZ?l- No . Hydrogen Sulfide Measures ,II Yes 0 No Directional Survey Required JZ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T"e_~1- "t~PF tc 45 t) c p' ¡,r . ORIGINAL SIGNED BY Approved By Form 10-401 Rev. 12-&1-ég\Y1or S!~moun! 12. Distance to nearest property line 13. Distance to nearest well ADL 047502,158' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10000' MD' Maximum Hole Angle 18. Casing ~rogram Specifications Size Casinq Weiaht Grade CouDlina 4-1/2" 12.6# 13Cr Hydril Hole 8-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13010 feet 10146 feet 12878 feet 10018 feet Length Size 142' 30" 24981 13-3/8" 10500' 9-5/8" 3861 7"x4-1/2" 2706' 2-7/8" Perforation depth: measured 12897' - 12902' true vertical 10037' - 10041' 20. Attachments 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Plugs (measured) Junk (measured) Cemented MD TVD Driven 142' 142' 4185 cu ft Permafrost 2498 2496' 575 cu ft Class 'G' 10500' 8082' 218 cu ft Class 'G' 10312' - 106981 7959' - 8225' 127 cu ft Class 'G' 103041 - 130101 7954' - 10146' Commissioner by order of the commission ;;L; ,'j (r ~ ~ Date; , (71' I~/ ~ bmit In Triplicate l.z ¿ì ~2/~-1 i.¡ß , 1 ."\ I I , \ ; ~ ) ) Endicott 3-17E1K30 Well Program I Well Name: 13-17E/K-30 Drill and Complete Plan Summary I Type of Well (service I producer I injector): Surface Location: Target Location: K-30 K2B Target Location: K-30 K1 Target Location: BHL Well TD I AFE Number: I Estimated Start Date: I Producer 2524'FNL, 7991 FEL, SEC. 8, T11N,R17E X=270,243.36 Y=5,970,973.83 1541 FNL, 1145' FEL, SEC. 5, T11 N, R17E X=270,109 Y=5,978,632 Z=9867' TVD 801 FSL, 1221' FEL, SEC. 32, T12N, R17E X=270,040 Y=5,978,868 Z=10,245' TVD 1581 FSL, 1246'FEL,SEC.32, T12N, R17E X=270,017 Y=5,978,947 Z=1 0,371' TVD / / /' I END 727111 I I Rig: I Doyon 15 I Operating days to complete: 24 I Feb. 21,2003 I MD: 114,015' I I rVD: 110,371' I I Max Inc: 163 @ 11,000' I I KOP: 110,000' I I KBE: 155.0 I Conventional Sidetrack I Objective: I Well Design (conventional, slimhole, etc.): Kekiktuk S2A3 & S2A1 Sands Overview: Mill Window in 9-5/8" at -10,000' in Seabee shale. Directionally drill to TD @ 150' MD r' below the K1 Zone in the Kekiktuk. Run and cement a 4-1/2" liner in this 8-1/2" hole, followed by a 4-1/2" completion. Version 2.0 19 Feb 2003 ) ) Endicott 3-17E1K-30 Well Program Mud Program: 9-5/8" Milling Fluid Properties: Density Viscosity Yield Point (ppg) (seconds) (lb/100ft2) 9.7 200 - 300 > 70 I Bentonite Milling Fluid tauO Gel Strengths (lb/100ft2) 1 Osec/1 Omin > 15 25-40/30-60 API FL (mls/30min) <8 pH 8.5- 9.5 8.5-in Intermediate Hole Mud Properties: Density Plastic Viscosit Yield Poi (ppg) (cp) (lb/1 OOft~ 9.7 10 - 15 27 - 32 Drill out of Surf Casing To Top HRZ 10.4 / 10 -15 I GEM Freshwater Mud TauO 10' G, API/ HTH pH LGS (lb/1 OOft~ (mls/30mi %vo 4-7 10 6-10 8.5-9.5 <5 3-7 10 < 4/ < 10.0 8.5-9.5 <5 Top HRZ to TD 20 - 25 LCM Restrictions: Minimize use of organic LCM products in the Kekiktuk Waste Disposal:NO ANNULAR INJECTION. Waste mud and drill cuttings taken to DS-4 disposal site Notify Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Cement Program: Casins Size I 4.5" 12.6-lb/ft 13Cr Hydril 563 Production Liner Basis50O/o excess over gauge hole. Planned TOC - 11,900' MD. 1500' above top of Kekiktuk, but keep> 1000' from window if possible. Spacer 75 bbI11.5-lb/gal MudPush XL Spacer Lead NA Tal' 750-6.~}160-bbl) 15.8 Ib/gal Prem G - 1.2 cuft/sx (top of tail - 11 ,900-ft MOt Temp r BHST:::: 2180 F estimated by Dowell Evaluation Program: 8-1/2" Hole Section: Open Hole: MWD/GR PWD for the entire section RES/NEU/DEN through Kekiktuk Cased Hole: WL USIT Log and Static Pressure Log after the rig leaves this well. Version 2.0 2 of 6 19 Feb 2003 ) Formation Markers: MDrkb TVDrkb Formation Tops (ft) (ft) KOP in Seabee 10,000 7750 Tuffs 12,390 9052 THRZ 13,075 9591 LCU/P3 Coals 13,414 9867 K3A 13,414 9867 K2B 13,506 9944 K2M 13,625 10,044 K2A 13,865 10,094 S2A2 13,775 10,169 S2A 1 13,798 1 0, 189 K1 13,865 10,245 *Based on sub-surface depths. ) Endicott 3-17E1K-30 Well Program Pore Pressure Estimated EMW (psi) (Ib/Qal)* \0' ~ 4819 4484 4545 4267 4299 4308 4910 9.44 8.76 8.75 8.17 8.17 8.18 9.31 CasingITubing Proaram: Hole Csg I WtlFt Grade Conn Length Size Tbg O.D. 8.5-in 4.5" 12.6 # 13Cr Hydril 563 4165 ft Tubing 4.5" 12.6# 13 Cr Vam ACE 9850 Well Control: Production Intervals BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure Casing Test Pressure (9-5/8" x 4-1/2") Planned completion fluids Top MD I TVDrkb 9850'/7643' 0/0 Bottom M D I TVDrkb 14,015'/10,371 ' 9850'/7643' 13-3/8", 5M, Double ram with annular (Hydril - GK) 4970-psi (9.3-lb/gal @ 10276-ft TV D) 3942-psi (0.1-psi/ft gas gradient to surface) Infinite with 12.0 ppg emw FIT Rams test to 4500-psi/250-psi. /' Annular test to 3,500-psi/250-psi 3,000-psi 8.5 Seawater & Diesel packer fluid 3-17E/K-30 is being drilled as a K2A producer. The 10.3 Ib/gal recommended mud weight for the HRZ is the controlling mud weight requirement. All of the anticipated Kekiktuk intervals should be overbalanced with this mud weight. Version 2.0 3 of 6 19 Feb 2003 I) .) Endicott 3-17E1K-30 Well Program Sidetrack and Complete Procedure Summary Pre-RiQ Work: 1. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. COMPLETE (10/10/01): Packoff passed test to 3000 psi, Tubing hanger passed test to 5000 psi. All lock-down screws functioned. Some lockscrews are hard to operate. 2. RU slickline, drift tubing and tag PBTD. Well drifted on 11/11/02 w/2.25" OD to 12,839' and w/3.625" OD to 10,266'. Dummy off all GLM's. Test the integrity of the dummied off tubing string by applying -3000 psi on the annulus. GLMs dummied off and IA x tubing annulus tested to 3000 psi on 10/27/02 3. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement. Use adequate cement volume to fill the 2-7/8" casing from PBTD (12,878') and extend the cement plug up to the 4-1/2" tubing @ - 10,290'. approximately 15' above the 2-7/8" X 4-1/2" liner hanger, plus squeeze 2 bbls to the perforations. Circulate to clean any residual cement above this depth as the casing cut is planned for just 40' above this depth, at -10,250' . 4. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut @ -10,250'. 5. Test the integrity of the cement plug and 2-7/8" casing by pressure testing the tubing to 3000 psi for 30 minutes. 6. Pull one of the lower DGLMs. Displace the well to clean seawater by circulating down the tubing via the lower GLM. Freeze protect top 1500' MD with diesel. 7. RU E-line. Cut the 4 Y2" L-80 tubing at approximately 10,250' MD using either a jet or chemical cutter. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. If necessary, level the pad. Ri~ Operations: 1. MIRU Doyon 15. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree. Aliqnment marks should be made before remov~ the old tree. Nipple up (Redress Rams . as needed for 5" DP) and test BOPE to 250/4500 psi. Pull TWC. 4. Pull and lay down 4-1/2" tubing from E-line cut and above. /' 5. MU 9-5/8" window section milling assembly and RIH with 5" DP to top of tubing stub. Displace well to milling fluid. '_.~ /' 6. Spot.-etbala ced 18.0 ppg mud pill from -10,250' to 9,9~ 7. ~tio~~J,F1'iï.window from 10,000' to 10,050'. PO~H. . . 8. M.U.,~eementlng mule-shoe and TIH to 10,050'. Circulate and condition. 9. Mix and pump cement kickoff plug. POOH. ,./ , 10. MU 8-1/2" PDC drilling assembly including MWD/GR RIH to top of cement. Clean out cement to kick-off /' point. /' 11. Kick-off and drill the 8-1/2" hole section as per directional plan to TD. Condition hole for running liner, spot liner running pill, and POOH. /" 12. Run and cement a 4 Y2", 12.6# 13 Cr80 production liner. Release from liner and set liner top packer. Test backside to 1000 psi to verify liner top packer is set. / 13. Run 4-1/2", 12.6# 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie- back sleeve. 14. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulys to 3000 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. /' 16. Freeze protect and secure the well. 17. Rig down and move off. Post-RiQ Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. 2. RU CTU to clean much from 4-1/2" liner. 3. Install gas lift valves. 4. RU e-line. Perforate -50' of Kekituk interval with 2-7/8" guns. Version 2.0 4 of 6 19 Feb 2003 ) ) Endicott 3-17E1K-30 Well Program Job 1: MIRU Hazards and Contingencies » Three wells, 3-21, 3-19 and 3-15 will require shut-in before the 3-17 rig move. The well is located -10' from 3-15 & 3-19 and 20' from 3-21. These wells will need to be shut-in at the both at the surface and the SSSV. All surface flowlines and gas lift lines will be de-pressured to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. » SDI is designated as an H2S site. Follow Standard Operating Procedures for H2S at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: 3-11 Max: 800 ppm (10/1/00), Last: 380 ppm (2/28/02) 3-15 Max: 128 ppm (7/1/01), Last: 52 ppm (2/22/02) 3-19 Max: 1600 ppm (3/2/99), Last: 160 ppm (12/10/00) 3-21 Max: 167 ppm (3/1/02), Last: 47 ppm (3/07/02) The maximum recorded level of H2S on the pad was 2000+ ppm from 3-43 on June 19,1999. >¡',""';'¡/f¡o.M¡';';';';'iI/.;.¡';;"';;';~~,i¡.,¡"'~~;~if.'>'/."!f«ôM>N,WW"MI,~A' ,._,--,.,--,' .\.,'-.:,.\,"",I¡~~;.w;;..,;;...:;,I,:I.>1,~;þ>.w;.'¡;';'¡"~A~A¡';;.",,'-;;':;'¡';';,.w.¡);..¡¡.;¡.¡w;¡.,,\,'(\--¡....,..--_.,I":._\ -' --, :.. -,. - --, -'-."IW,"',~W'lf/llf'ff·:-I'i~t:_''t:O·T~''''U.·~''~'''>tt:_'I'',~(_¡r.,;;¡'''A'W.,r.;.,'-~H/4ii¡'¡')¡'¡';"'¡')i#mff1r~':ffI¡'( _f-"m'W1'1--;':""""U""I."'''''''',¡'--;';~'*';'''-:,.,'.'of\.;';'';;;:+;'#: Job 2: Decomplete Well Hazards and Contingencies » The existing perforations should be isolated by the pre-rig cement plug. The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. Seawater will be underbalanced to the Kekiktuk reservoir pressures. » NORM test all retrieved well head and completion equipment. "1IIn_ICI111. .11.111111_U.II- .a;l- -,::-m: -¡:I:IIII!- :l11:III:mlll :IIII:IIII:ml:m:lmm:m~;;¡,'(.4m~I::~IIII_II_':la_III__ILI111111. _II 111'_ --:a:rr:I-:a!IIIII;:Da:llllmlllllnlmm:m:lalm~1111111~llllm1:__11_111111_1__ ~I. :1111:11:-1:1:11_ _:~I::--:!II:I---IIIIIICnm!l'llmII111~II:I_II_1:~ _1:_ _I . Job 4: Section Mill Hazards and Contingencies » Ensure that the Baker section mill is dressed with the older style 3-arm cutters. » Ensure that the milled cuttings are being cleaned from the hole. Adjust mud and milling parameters as required to provide for good hole cleaning. ~ Once section milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Inl-I-'\I;llmml\_I__I_~_I__II_ _I Job 7: DrillinQ Intermediate/Production Hole Hazards and Contingencies » The well will kick off in the Seabee with a 9.7 Ib/gal mud. The mud weight will be increased to 10.4 Ib/gal prior to drilling the HRl. The 10.4 mud weight requirement for the HRl should result in being overbalanced to all of the Kekiktuk reservoirs. Follow all shale drilling practices to minimize potential problems. » The well path will drill full sections of the Tuffs and HRl shales, and both formations have been troublesome in the Endicott area. The Tuffs is typically slow and erratic drilling, which can wipe out a PDC bit if proper drilling parameters are not maintained. The HRl on the other hand has shown severe hole instability problems if insufficient mud weight is used. Follow all (1) shale drilling practices, (2)ECD management to limit high ECD's, and (3) maintain proper mud weights and shale stabilizers in the drilling fluid. » The P-3 coal sections should be encountered at the top of the Kekiktuk interval in this well. These coals have caused packoff and stuck pipe problems in the past. Follow good coal drilling practices. Version 2.0 5 of 6 19 Feb 2003 ) ) Endicott 3-17E1K-30 Well Program } Differential sticking is the largest operational risk in this well. Differential sticking will be a problem if the drill string or liner is left stationary for any period of time across the high permeability Kekiktuk Sands. The GEM enhanced LSND drilling mud must be kept in excellent shape when drilling the Kekiktuk to provide good filter cake properties. The Kekiktuk K2A reservoir pressure is expected to be 4300 psi (8.2 ppg EMW) at the bottom hole location. The 10.3 Ib/gal mud required for HRZ stability will be 2 Ib/gal over balanced to the Kekiktuk. This 1200 psi pressure differential creates a severe differential sticking risk. } No major fault crossings are planned in the drilling of this well. The well path will cross over the major Midfield Fault but this fault does not extend upwards into the wellbore path. The directional plan will need to followed closely in the target interval to prevent hitting the smaller faults to the south and north of the target. Job 9: Install 4Y2" Production Liner Hazards and Contingencies } Long shale intervals will be exposed while running the liner. Rotation of the liner may be necessary if downward progress is not possible. To minimize ECD spikes and associated shale stability problems, bring pumps on slow and minimize downward surges with pipe. The limits for working the liner to bottom are: Workina Ranaes Basis o Torque in liner: < 5000 ft-Ibs Max: Connections MU to 7000 ft-Ibs o RPM in liner < 35 rpm o Pressure in liner < 2000 psi Max: 2625 psi sets Flexlock LH o Compression in liner < 50K Ibs Max: 200K (HRD Setting Tool) o Tension in liner < 100 K Max: 288K (pipe) } Differential sticking is a significant potential problem in the Kekiktuk. Minimize the time the pipe is left stationary while running the liner through this interval. } Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. m!IIUllml':fIUIHI1II1:llIImr-IIWlm'lIa::nmlllllmmIlIUIIUllllimlll.IIILILLIIImUII__'-.IL.m. .1. .1 L -Tlnll;1II;rumn:mmOllIlIllLIiIILTaLlIII. -T- -:IrWUIIUTmlll!,m,:mmmlm'IIIII:,.:mIlLIILIL.IL _II : 1t11.1:TlUIHammIlIUIIUmUlil:,m:mWIW-.IUI.III. _1__1. .L--'---::WTmU:lI;nmlllllalIlIOllnllnl!lImnm :l:1:I1I1':¡--'II:IIIIW Job 12: Run Completion Hazards and Contingencies } Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. "'YII'1'1'1I . .... ·~·"~L..m~ . '1110-'" .11 1_ \·'\fl. .1__1._1..1 III. T If· .....I'I·'·'+'·¡ I ;'11 I. ^ Job 13: ND/NU/Release Rig Hazards and Contingencies } See Job 1 for adjacent well spacing. These are close well centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Version 2.0 6 of 6 19 Feb 2003 ) ) SI:JE!r".....y-sLJr1 BPXA C'An:::L.IN.è:i ,sf,iFf$IC',ª:'~ A",llIbrJ"M<:I\.\~ Alaska State Plane 3 Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordinates: RKB Elevation: 5970973.83 N, 270243.36 E 1590.05 N, 2038.60 W 70019' 20.3471" N, 147051' 46.9665· W Endicott DI-SDI 3-17E/K-30 Wp 11 Eastings(Well) Scale: 1 inch = 750ft -750 0 750 "'''''''' '" I ':':'~~D ,..~=~j-----,---,,--____,_'_, _ 8250 10245.00 TVD. 10370.81ftTVD t4015.23ftMD,! :/f7~~~~~'l~4Ør¡ßc~~ 1 0370.81ftTVD I .~ 95 % WI Mwv,~n..-,-_n~ne Hardlln~2 'ì<,"'i ~\ \ 3.17f.IK3() Ti . $ I . 9867.00 rVD, ' ,.." "", ¡ 7651.4'1 N, 368.39 W. v,.. ..<,,-6\, Hnrdlil'lfJ3 :/..1 'lflJK·:)O T"1 Drillers nnn...,.......{... \ \ ¡ @ 95 % WI MWD \ '- 13734..\0 I End Dir, Start Sail @ 32.993°: 13415.10ftMD,9867.46ftTVD '" / ~~I:2.~'~~'-_ '--~-'. Begin Dir @ 1.5000/100ft: 13075.22ft MD, 9591.00ft TvA 1(:;~::~~+·-"-··_..·n..n....nn_.._.._.._.EI.II.I/1..1.. ~ I ~ I DrillQuesl~ Well: Current Well Properties 3·17E/K·30 55.001t above Mean Sea Level North Reference: Units: True North Feet (US) - 7500 ,,';..,~.;.I.,...::if.'~!'·' ,;~ tiff ,p~~ ,~~~{~~ ,..~:t~~ .: ~~:t'~' .:\..\"!\)!M·:\\ '~:,u(.,'n .1 End Dir, Start Sail @ 62.955° : 10492.44ftMD,8037.34ftT~ Q; ~ Cñ - 6750 g> :E t o Z End Dir, Start Sail @ 38.092° : 12263.30ftMD,8952.00ftTVD ~:1~" ~~~!~7~.. ~1'jJj~;1'''i ~~~ Begin Dir @ 4.0000/100ft: 11641.72ft MD, 8559.91ft TVD - 6000 8000 - ! ! I Increase Dir Rate @ 5.0000/100ft: 10050.00ftMD,7784.08ft~VD~t , 10073.73 Sidetrack Point TF 90° Left 4.0000/100ft: 10000.00ft MD, 7750.27ft TV~ i ~(\f ' i (~,\,',~¡~, ',i:, .:¡:: o LO r-.. 11 .s::. o .£ - 5250 ~ ~ (/) 7000 - Sidetrack Point TF 90° Left 4.0000/100ft: 10000.00ft MD.1, 7750.27ft TVD 00.0 Increase Dir Rate @ 5.0000/lOOft : 10050.00ftMD,7184.08ftTVD End Dir, Start Sail @ 62.955° : 10492.44ftMD,8037.34ftTVD .' . 1~SOO.00 ëõ ~ Dir @ 4.0000/100ft : 11641.72ft MD, 8559.91ft TVD L: ã.. (.J o ëU 9000- (.) t (.J > 10000 - I I ~..m.",. ." ." '.,,) ,,,) ',' 1':''''\''',' ,,- j ¡ End Dir, Start Sail @ 38.092° : 12263.30ftMD,8952.00ftTVD ,.,'!;¡""'~\ Begin Oir @ 1 ,5000/1 00ft : 13075,22ft MO, 9591.0011 TVO 765~:;~()3r:ei91;~~OO "'1;';~~'~~['}¡Z'~~rS,-,,~nd Dir, Start Sail@32.993°:13415.10ftMD,9867.46ftTVD , " __ 3· 17£/K30 T2 Hardlme1 0 ....., " /IJ245.()() rVD, \psoo.oo .' .,,/" ìÐ(J·:.5'l N. ·/.1.:.96 W \ ..' 3-17E!K..JO 'T2 DtiJ!IH$ \ ",/ Hardline2 or. 9S 0:; Wi MWD Hardline3 0 ~ 1:O~~2;~':D ~ Total Depth: 14015.23ftMD,10370.81ftTVD 10370.81ftTVD .::: o o o 11 ..s::. o -£ '* 11 000 - o (f) I 4500 Scale: 1 inch = 1000ft I 5500 I 6500 Vertical Section (Well) I 7500 I 8500 Section Azimuth: 356.619° (True North) DrillQuest 3.03.02.002 ') ) sl:JE!.....I"'"'~-SUf1 BPXA Endicott DI-SDI DrillQuest~ ó"',Ti:. L:I N ti $fj(RVi't:'lifi Alaska State Plane 3 3-17E I K-30 Wp 11 A "',llIbl/nOll c~p.\~ 3·17E I K-30 Wp 11 Proposal Data Vertical Origin: Well ~~~~~~~~~~~i;S : Well Current Well Properties It North Reference: True North Well: 3-17 Dogleg severity : Degrees per 100 feet (U$) Horizontal Coordinates: Vertical Section Azimuth: 356.619° Ref. Global Coordinates: 5970973.83 N, 270243.36 E Vertical Section Description: Well Ref. Structure Reference : 1590.05 N, 2038.60 W Vertical Section Origin: 0.00 N,O.OO E Ref. Geographical Coordinates: 70' 19' 20.3471" N. 147' 51' 46.9665" W Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg RKB Elevation: 55.00ft above Mean Sea level Depth Depth Section Rate 1??oo,00 47.442 3.980 7750.27 5171.64 N 373.17E 514D.63 North Reference: True North 10050.00 47.474 1.266 7784.08 5208.43 N 374.85 E 5177.26 4.000 Units: Feet (US) 10492.44 62.955 341.848 8037.34 5563.06 N 316.34 E 5534.72 5.000 11641.72 62.955 341.848 8559.91 6535.73 N 2.55 W 6524.50 0.000 12263.30 38.092 341.848 8952.00 6988.07 N 150.86 W 6984.80 4.000 13075.22 38.092 341.848 9591.00 7464.03 N 306.91 W 7469.14 0.000 13415.10 32.993 341.820 9867.47 7651.69 N 368.48 W 7660.11 1.500 13865.23 32.993 341.820 10245.00 7884.57 N 444.96 W 7897.09 0.000 14015.23 32.993 341.820 10370.81 7962,18 N 470.45 W 7976.06 0.000 3-17E I K-30 Wp 11 Measurement Units: It Target Coordinate Vertical Depth Northlngs Eastlngs Vertical Depth Northlngs Eastlngs Target Name Point Type Well Well Well Mean Sea Level ASP ASP Shape (ft) (ft) (ft) (ft) (tt) (tt) 3-17E/K30 Faull I Entry Point 55.00 7373.53 N 199.19W 0.00 5978350.00 N 270270.00 E Polygon Boundary Point A 55.00 7373.53 N 199.19W 0.00 5978350.00 N 270270.00 E B 55.00 7281.71 N 788.09 E 0.00 5978228.00 N 271254.00 E C 55.00 7373.53 N 199.19 W 0.00 5978350.00 N 270270.00 E 3-17E/K30 Fault3 Entry Point 55.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E Polygon Boundary Point A 55.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E B 55.00 7497.10 N 699.45 E 0.00 5978446.00 N 271172.00 E C 55.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E 3-17E/K-30Hardlinel Entry Point 9867.00 7481.67 N 163.48 W 9812.00 5978457.00 N 270309.00 E Polygon Boundary Point A 9867'(x) 7481.67 N 163.48 W 9812.00 5978457.00 N 270309.00 E B 9867.(X) 7469.43 N 563.29 W 9812.W 5978457.00 N 269909.00 E C 9867.(X) 7481.67 N ]63.48 W 9812.(X) 5978457.W N 270309.00 E 3-17E/K-30 TI Entry Point 9867.(X) 7651.41 N 368.39 W 98]2.00 5978632.93 N 270109.38 E Polygon Drillers @ 95 % WI MWD Boundary Point A 9867.00 7761.15 N 361.99W 9812.(X) 5978742.42 N 270119.14 E B 9867'(x) 7742.67 N 320.82 W 9812.(X) 5978722.69 N 270159.72 E C 9867.00 7711.07 N 294.78 W 9812'(x) 5978690.31 N 270184.78 E D 9867.00 7677.10 N 280.78 W 9812.00 5978655.93 N 270197.74 E E 9867 ,(X) 7641.64 N 275.99 W 9812.00 5978620.34 N 270201.44 E F 9867'(x) 7603.63 N 280.9] W 9812.00 5978582.50 N 270195.36 E G 9867.W 7564.20 N 299.62 W 98 I 2.(X) 5978543.66 N 270175.45 E H 9867.00 7536.63 N 337.94 W 9812.(X) 5978517.27 N 270136.30 E I 9867 ,(X) 7541.05 N 385.12W 9812.00 5978523.14 N 27(X)89.28 E J 9867 ,(X) 7570.58 N 419.9OW 9812.00 5978553.72 N 270055.42 E K 9867 ,(X) 7605.98 N 439.27 W 9812.00 5978589.69 N 270037.14E L 9867.00 7641.73 N 447.37 W 9812.00 5978625.67 N 270030.14 E M 9867.(X) 7677.97 N 446.17 W 9812.(X) 5978661.86 N 270032.45 E N 9867.00 7715.40 N 434.25 W 9812.00 5978698.91 N 270045.51 E 0 9867.00 7749.38 N 406.25 W 9812.00 5978732.01 N 270074.54 E 3-17E/K30T] Entry Point 9867.00 7651.41 N 368.39 W 9812.(X) 5978632.93 N 270109.38 E Circle 3-17E/K-30Hardline3 Entry Point 10245.00 7740.44 N 240.44 W 10190.00 5978718.00 N 270240.00 E Polygon Boundary Point A 10245,(X) 7740.44 N 240.44 W 10190.00 5978718.1X) N 270240.00 E B 10245.(X) 7728.19 N 640.25 W 10190.00 5978718.00 N 269840.00 E C 10245'(x) 7740.44 N 240.44 W 10190.00 5978718.00 N 270240.00 E 3-17E/K30 1'2 Entry Point 10245.00 7884.57 N 444.96 W 10190.00 5978868.33 N 27W39.99 E Circle 3-17E/K-30 1'2 Entry Point 10245'(x) 7884.57 N 444.96 W 10190.00 5978868.33 N 270039.99 E Pulygon Drillers @ 95 % WI MWD Boundary Point A 10245.00 7960.75 N 437.98 W 10190.00 5978944.26 N 270049.29 E bp B 10245.00 7946.20 N 410.23W 10190.00 5978928.86 N 270076.59 E C 10245.00 7923.76 N 393.98 W 10190.00 5978905.94 N 270092.14E D 10245.00 790 1.34 N 385.47 W 10190.00 5978883.27 N 270099.96 E E 10245.00 7878.34 N 381.84 W 10190.00 5978860.17 N 270102.89 E F 10245'(x) 7852.57 N 383.49 W 10190.00 5978834.46 N 270100.45 E G 10245.00 7823.61 N 394.35 W 10190.00 5978805.85 N 270088.71 E H 10245.00 7802.79 N 420.85 W 10190.00 5978785.85 N 270061.58 E I 10245.00 7807.42 N 454.17W ]0190.00 5978791.49 N 270028.42 E J 10245.00 7830.16 N 477.04 W 10190.00 5978814.92 N 270006.25 E K 10245.00 7854.90 N 488.68 W 10190.00 5978840.01 N 269995.38 E L 10245.00 7878.40 N 493.69 W 10190.00 5978863.65 N 269991.09 E M 10245.00 7902.23 N 493.55 W 10190.00 5978887.47 N 269991.96 E N 10245.00 7928.14 N 487.09 W 10190.00 5978913.17 N 269999 .21 E 0 10245.00 7952.83 N 468.80 W 10190.00 5978937.28 N 270018.25 E 3-17E1K-30Hardlinc2 Entry Point 10245.00 8040 JO N 249.62 W 10190.00 5979018.00 N 270240.00 E Polygun Boundary Poinl A 10245.00 8040JO N 249.62 W 10190.00 5979018.00 N 270240.00 E B 10245.00 8028.05 N 649.43 W 10190.00 5979018.00 N 269840.00 E C 10245.00 8040.30 N 249.62 W 10190.00 5979018.00 N 270240.00 E 3-17E1K30 Fau1l2 Entry Point 55.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00 E Polygon Boundary Point A 55.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00 E B 55.00 8228.64 N 804.11 E 0.00 5979174.00 N 271299.00 E C 55.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00E DrillQuest 3.03.02.002 Sperl )-Sun Drilling Se. )ices Proposal Data - 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 MD Delta Inclin. . Azimuth TVD Northings Eastlngs Dogleg TooIface· (ft) MD (ft) (0) (0) (ft) (ft) (ft) (°/1 OOft) (0) C~1-··"··Ú)·~Oõ':Õ~--::··.~-~"~::~=47Mi-==.... .~~"~~~..~=~~5Õ~?~-517.1._]34-N ._....~~~!_.§.... .::~:~~~:~:~~:=.=~=~~~~~' l . :2 10050.00 50.00 47.474 1.266 7784,08 5208.43 N 374.85 E 4.000 270.000 I .3 ·10492.44 442.44 62.955 341.848 8037.34 5563.06 N' . 316.34 E 5.000 308.160 i 4 11641.72 1149.28 62.955 341.848 8559.91 6535.73N.2.55W 0.000 .0.000 i 5' 12263:30 621.58 38.092 341.848 8952.00 6988.07N 150.86 W 4.000 180.000 I· 6' 13075.22 811.92 38.092 341.848 9591.00 7464.03 N 306.91 W 0.000 - 0.000 7· 13415.10 339.88 32.993 341.820 9867.47 7651.69N 368.48W 1.500 180.172 8T 13865.23 450.12 32.993 341.820 10245.00 7884.57 N 444.96 W 0.000 0.000 l_._~.....L!~1~~?~L~0.00 I.....~~..:~~~J.... ~.~.~:..~?9.........~..9~?.~:.~)..:_.. ~~~?~..!..~_~l...~.?"Q:.~.~~~.l~·~~..~L_._.....:_~_~~.. 18 February, 2003 - 16:17 - 1 - DrillQuest Sperry-Sun Drilling Service Alaska State Plané"'3 3-17D/M-31 Recc 7./ K-30 Wp 11 roposal Report 18 February, 2003 Surface Coordinates: 5970973.83 N, 270243.36 E (70019'20.3471" N, 147051' 46.9665" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Kelly Bushing: 55.00ft above Mean Sea Level speI'I'Y-su" DR I L. ~ fNG=~ e RV Ie:: e 5 A HaUiburton Company ~ -- Proposal Ref: pro1001 DrillQuest 3.03.02.002 Page 2 of 11 18 February, 2003 - 16:21 Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E I K-30 Wp 11 Revised: 18 February, 2003 BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings \Bate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10000.00 47.442 3.980 7695.27 7750.27 5171.64N 373.17 E 5976131.62 N 270774.68 E 5140.63 Sidetrack Point TF 90° Left 4.000°/1 OC : 10000.00ft MD, 7750.27ft TVD 10050.00 47.474 1.266 7729.08 7784.08 5208.43 N 374.85 E 597616ª~4!J~¡¡r¡~, E 4.000 5177.26 Increase Dir Rate @ 5.0000/100ft : 1 0050.0OOM D, 7784.08ftTVD 10100.00 49.049 358.663 7762.36 7817.36 5245.73 N 5976205.63 N \1¡¡IÞ 270778.60 E 5.000 5214.50 10169.71 51.336 355.238 7807.00 7862.00 5299.19 N ~762§f}~15 N 270777.36 E 5.000 5268.03 Seabee 10200.00 52.359 353.819 7825.71 7880.71 5322.90 N !;'j~282:92 N 270775.81 E 5.000 5291.83 .~ 10300.00 55.851 349.399 7884.35 7939.35 5402.98 N 5976363.33 N 270766.39 E 5.000 5372.48 10400.00 59.488 345.337 7937.84 7992.84 5485.38 N 5976446.25 N 270750.39 E 5.000 5455.83 10492.44 62.955 341 .848 7982.34 8037.34 5563.06 N 5976524.60 N 270729.86 E 5.000 5534.72 End Dir, Start Sail @ 62.955° : 10492.44ftMD,8037.34ftTVD 10500.00 62.955 341 .848 7985.78 8040,.78 314.25 E 5976531.06 N 270727.96 E 0.000 5541 .24 10600.00 62.955 341 .848 8031 .25 8086:25 286.50 E 5976616.50 N 270702.82 E 0.000 5627.36 10700.00 62.955 341 .848 8076.72 8131.72 5738.73 N 258.75 E 5976701.95 N 270677.67 E 0.000 5713.48 10800.00 62.955 341 .848 81:22;19 ...... 81~.19 5823.36 N 231.00 E 5976787.39 N 270652.53 E 0.000 5799.60 10900.00 62.955 341 .848 . .·~f67:§§ ;" 822g.fP6 5907.99 N 203.26 E 5976872.83 N 270627.39 E 0.000 5885.72 11000.00 62.955 341 .84~ /8213~18 'i8268:i 3 5992.62 N 175.51 E 5976958.27 N 270602.24 E 0.000 5971.84 11100.00 62.955 341.848 ag§8.6q \8313.60 6077.26 N 147.76 E 5977043.71 N 270577.10 E 0.000 6057.96 11200.00 62.955 841 .848 8304.07 8359.07 6161.89 N 120.01 E 5977129.16 N 270551 .96 E 0.000 6144.09 11300.00 62.955 341 .848 8349.54 8404.54 6246.52 N 92.27 E 5977214.60 N 270526.81 E 0.000 6230.21 11400.00 62.955 341.848 8395.00 8450.00 6331 .15 N 64.52 E 5977300.04 N 270501 .67 E 0.000 6316.33 11500.00 62.955 341 .848 8440.47 8495.47 6415.79 N 36.77 E 5977385.48 N 270476.52 E 0.000 6402.45 11600.00 62.955 341 .848 8485.94 8540.94 6500.42 N 9.02 E 5977470.92 N 270451.38 E 0.000 6488.57 11 641 .72 62.955 341 .848 8504.91 8559.91 6535.73 N 2.55W 5977506.57 N 270440.89 E 0.000 6524.50 Begin Dir @ 4.0000/100ft : 11 E. --,,2r MD, 8559.91ft TVD 11700.00 60.624 341.848 8532.46 8587.46 6584.52 N 18.55 W 5977555.84 N 270426.39 E 4.000 6574.16 11800.00 56.624 341 .848 8584.52 8639.52 6665.63 N 45.15 W 5977637.72 N 270402.30 E 4.000 6656.70 11900.00 52.624 341 .848 8642.40 8697.40 6743.10 N 70.54 W 5977715.93 N 270379.28 E 4.000 6735.52 12000.00 48.624 341 .848 8705.83 8760.83 6816.54 N 94.62 W 5977790.07 N 270357.46 E 4.000 6810.25 12100.00 44.624 341 .848 8774.49 8829.49 6885.59 N 117.26 W 5977859.78 N 270336.95 E 4.000 6880.52 12200.00 40.624 341 .848 8848.06 8903.06 6949.92 N 138.35 W 5977924.73 N 270317.84 E 4.000 6945.99 12263.30 38.092 341 .848 8897.00 8952.00 6988.07 N 150.86 W 5977963.24 N 270306.50 E 4.000 6984.80 End Dir, Start Sail @ 38.092° : 12263.3OOMD,8952.0OOTVD 12300.00 38.092 341 .848 8925.88 8980.88 7009.58 N 157.91 W 5977984.96 N 270300.11 E 0.000 7006.69 12390.36 88.092 341 .848 8997.00 9052.00 7062.55 N 175.28 W 5978038.44 N 270284.38 E 0.000 7060.60 Top Tuff Marker DrillQuest 3.03.02.002 Page 3 of 11 18 February, 2003 - 16:21 Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E I K-30 Wp 11 Revised: 18 February, 2003 BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastií1g$ 'Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12400.00 38.092 341 .848 9004.58 9059.58 7068.20 N 177.13 W 5978044.14 N 270282.70 E o.ooer 7066.35 12500.00 38.092 341 .848 9083.29 9138.29 7126.82 N 196.35 W 59781 03.32N~.. ,~¡,o265,61t;,E 0.000 7126.00 12600.00 38.092 341 .848 9161 .99 9216.99 7185.45 N 215.57 W 5978162.51 N ~~~~7.86 E 0.000 7185.65 12700.00 38.092 341 .848 9240.69 9295.69 7244.07 N 234.79 W 5978221.69 N 216230.45 E 0.000 7245.31 12800.00 38.092 341 .848 9319.39 9374.39 7302.69 N 254.01 W 5978280.87 N Y270213.03 E 0.000 7304.96 12900.00 38.092 341 .848 9398.10 9453.10 7361.31 N ~i~:23 §aì8340.06 N 270195.62 E 0.000 7364.61 .~ 13000.00 38.092 341 .848 9476.80 9531 .80 7419.93N 2~,f~5 5.8399.24 N 270178.20 E 0.000 7424.26 13075.22 38.092 341 .848 9536.00 9591 .00 7464.03 N 306¡~1 5978443.76 N 270165.10 E 0.000 7469.14 Begin Dir @ 1.500° 1100ft : 13075.22t MD, 9591.000 TVD Top HRZ 13100.00 37.720 341 .846 9555.55 9610.55 7478.49 N 311.65 W 5978458.36 N 270160.80 E 1.500 7483.86 13200.00 36.220 341 .838 9635.44 330.39 W 5978516.05 N 270143.82 E 1.500 7542.01 13300.00 34.720 341 .830 9716.88 N 348.48 W 5978571.71 N 270127.42 E 1.500 7598.11 13400.00 33.220 341.821 9799.81 7643.86 N 365.91 W 5978625.31 N 270111 .63 E 1.500 7652.13 13414.55 33.002 341 .820 9812:00 7651.41 N 368.39 W 5978632.93 N 270109.38 E 1.500 7659.82 Base HRZ 1 LCU 1 K3A 1 Possible P3 Coals Target - 3-17E/K30 T1, 175.00 Radius 13415.10 32.993 341.820 9812.47 . 9867.47 7651.69 N 368.48 W 5978633.22 N 270109.30 E 1.500 7660.11 End Dir, Start Sail @ 32.993° : 13415.1 OftMD ,9867 .46ftTVD 13456.28 32.993 341 .820 9847.00 9902.00 7673.00 N 375.48 W 5978654.73 N 270102.96 E 0.000 7681.79 K2B 13500.00 32.993 341.820 9883.67 9938.67 7695.62 N 382.91 W 5978677.56 N 270096.22 E 0.000 7704.80 13570.74 32.993 341.820 9943.00 9998.00 7732.21 N 394.93 W 5978714.51 N 270085.33 E 0.000 7742.05 K2M 13600.00 32.993 341 .820 9967.55 10022.55 7747.35 N 399.90 W 5978729.79 N 270080.83 E 0.000 7757.45 13610.08 32.993 341 .820 9976.00 10031.00 7752.57 N 401.61 W 5978735.06 N 270079.27 E 0.000 7762.76 Top K2A 1 S2A3 13694.73 32.993 341 .820 10047.00 10102.00 7796.36 N 415.99 W 5978779.27 N 270066.24 E 0.000 7807.33 S2A2 Shale - 13700.00 32.993 341 .820 10051.42 10106.42 7799.09 N 416.89 W 5978782.03 N 270065.43 E 0.000 7810.10 13725.73 32.993 341 .820 10073.00 10128.00 7812.40 N 421.26 W 5978795.46 N 270061 .47 E 0.000 7823.65 S2A1 13800.00 32.993 341 .820 10135.29 10190.29 7850.82 N 433.88 W 5978834.26 N 270050.03 E 0.000 7862.75 13803.23 32.993 341 .820 10138.00 10193.00 7852.50 N 434.43 W 5978835.94 N 270049.53 E 0.000 7864.45 K1 (top Zone 1) 13865.23 32.993 341 .820 10190.00 10245.00 7884.57 N 444.96 W 5978868.33 N 270039.99 E 0.000 7897.09 Target - 3-17E/K-30 T2 Drillers @ 95 ( 13900.00 32.993 341 .820 10219.17 10274.17 7902.56 N 450.87 W 5978886.49 N 270034.63 E 0.000 7915.40 14000.00 32.993 341 .820 10303.04 10358.04 7954.30 N 467.86 W 5978938.72 N 270019.23 E 0.000 7968.04 14015.23 32.993 341 .820 10315.81 10370.81 7962.18 N 470.45 W 5978946.68 N 270016.89 E 0.000 7976.06 Total Depth: 14015.23ftMD,1 0370.81 ftTVD 4 1/2" Liner Alaska State Plane 3 Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 Revised: 18 February. 2003 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 356.619° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14015.23ft., The Bottom Hole Displacement is 7976.06ft., in the Direction of 356.619° (True). The Along Hole Displacement is 8112.45ft, the Planned Tortuosity is 1.668°/1 OOft and the Directional Difficulty Index is 5.9. Comments Measured Depth (ft) _. 10000.00 10050.00 10492.44 11641.72 12263.30 13075.22 13415.10 " 14015.23 18 February, 2003 - 16:21 S tat ion Coo r d i na t TVD Northings (ft) (ft) 7750.27 7784.08 8037.34 8559.91 8952.00 9591.00 9867.46 10370.81 5F1,~N 5208;43 N 55§~.:g9·.~······ 653!?;73N 6988.07 N 7464.03 N 7651.69 N 7962.18 N Sidetrack Point TF 90° Left 4.000°/1 OOft : 1 OOOO.OOft MD, 7750.27ft TVD Increase Dir Rate @ 5.0000/lOOft: 10050.0OftMD,7784.08ftTVD End Dir, Start Sail @ 62.955° : 10492.44ftMD,8037.34ftTVD Begin Dir @ 4.0000/100ft: 11641.72ft MD, 8559.91ft TVD End Dir, Start Sail @ 38.092° : 12263.30ftMD,8952.00ftTVD 306.91 W 368.48 W 470.45 W Begin Dir @ 1.500°/1 OOft : 13075.22ft MD, 9591.0Oft TVD End Dir, Start Sail @ 32.993° : 13415.10ftMD,9867.46ftTVD Total Depth: 14015.23ftMD,10370.81ftTVD Page 4 of 11 BPXA .~ ~ DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 .--- .--- BPXA 394.93 W K2M 401.61 W Top K2A / S2A3 415.99 W S2A2 Shale 421.26 W S2A 1 434.43 W K1 (top Zone 1) 371.95 E Seabee 175.28 W Top Tuff Marker 306.91 W Top HRZ 368.39 W Base HRZ / LCU / K3A / Possible P3 Coals 375.48 W K2B Eastings (ft) Page 5 of 11 4 1/2" Liner Casing Detail Penetration Point Sub-Sea Depth (ft) Northings (ft) Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 Revised: 18 February, 2003 18 February, 2003 - 16:21 7750.27 <Run-TO> <Run-TO> 10000.00 To Measured Vertical Depth Depth (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) Casinø details 7807.00 0.000 0.000 10169.71 7862.00 8997.00 0.000 0.000 12390.36 9052.00 9536.00 0.000 0.000 13075.22 9591.00 9812.00 0.000 0.000 13414.55 9867.00 9847.00 0.000 0.000 13456.28 9902.00 9943.00 0.000 0.000 13570.74 9998.00 9976.00 0.000 0.000 13610.08 10031.QØ¡r 10047.00 0.000 0.000 13694.73 10102.00 10073.00 0.000 0.000 13725.73 10128.00 10138.00 0.000 0.000 Profile Measured Vertical Depth Depth (ft) (ft) Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. Formation Tops Alaska State Plane 3 DrillQuest 3.03.02.002 Page 6 of 11 18 February, 2003 - 16:21 55.00 7373.53 N 199.19 W 55.00 7281.71 N 788.09 E 55.00 7373.53 N 199.19 W 0.00 5978350.00 N 270270.00 E 0.00 5978228.00 N 271254.00 E 0.00 5978350.00 N 270270.00 E Geographical Coordinates #1 700 20' 32.8680" N 147051' 52.7860" W #2 700 20' 31.9645" N 1470 51' 23.9435" W #3 700 20' 32.8680" N 147051'52.7860" W 3·17E/K30 Fault3 55.00 7502.89 N 124.11 W Polygon Mean Sea LeveVGlobal Coordinates: 0.00 5978477.00 N 270349.00 E Geographical Coordinates: 700 20' 34.1403" N 1470 51' 50.5928" W Target Boundary Point #1 55.00 7502.89 N 124.11 W #2 55.00 7497.10 N 699.45 E #3 55.00 7502.89 N 124.11 W --- Mean Sea LeveVGlobal Coordinates #1 0.00 5978477.00 N 270349.00 E #2 0.00 5978446.00 N 271172.00 E #3 0.00 5978477.00 N 270349.00 E Geographical Coordinates #1 700 20' 34.1403" N 1470 51' 50.5928" W #2 700 20' 34.0830" N 1470 51' 26.5323" W #3 700 20' 34.1403" N 1470 51' 50.5928" W Target Type Target Shape Polygon 7373.53 N 199.19 W 5978350.00 N 270270.00 E 700 20' 32.8680" N 1470 51' 52.7860" W Mean Sea LeveVGlobal Geographical ~ 3-17E/K30 Fault 1 Target Name Tarqets associated with this welløath Alaska State Plane 3 BPXA Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E I K-30 Wp 11 Revised: 18 February, 2003 DrillQuest 3.03.02.002 .~ Target TVD '¥Eastings Target Target (ft) (ft) Shape Type 9867.00 .67N 163.48 W Polygon 9812.00 ;;;5978457.00 N 270309.00 E 70020' 33.9316" N 147051' 51.7429" W r867.00 7481.67 N 163.48 W 9867.00 7469.43 N 563.29 W 9867.00 7481.67 N 163.48 W 9812.00 5978457.00 N 270309.00 E 9812.00 5978457.00 N 269909.00 E 9812.00 5978457.00 N 270309.00 E 70020' 33.9316" N 147051' 51.7429" W 70020' 33.8109" N 147052' 03.4234" W 70020' 33.9316" N 147051' 51.7429" W 9867.00 7651.41 N 368.39 W Polygon 9812.00 5978632.93 N 270109.38 E 700 20' 35.6009" N 1470 51' 57.7297" W 9867.00 7761.15N 361.99 W 9867.00 7742.67 N 320.82 W 9867.00 7711 .07 N 294.78 W 9867.00 7677.10 N 280.78 W 9867.00 7641.64 N 275.99 W 9867.00 7603.63 N 280.91 W 9867.00 7564.20 N 299.62 W 9867.00 7536.63 N 337.94 W 9867.00 7541.05 N 385.12 W 9867.00 7570.58 N 419.90 W 9867.00 7605.98 N 439.27 W 9867.00 7641.73 N 447.37 W 9867.00 7677.97 N 446.17 W 9867.00 7715.40 N 434.25 W 9867.00 7749.38 N 406.25 W ~ BPXA Page 7 of 11 Target Boundary Point #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 #14 #15 Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Geographical Coordinates #1 #2 #3 Mean Sea LeveVGIobaI Coordinates #1 #2 #3 Target Boundary Point #1 #2 ;¡#3 Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E I K-30 Wp 11 Revised: 18 February, 2003 18 February, 2003 - 16:21 3-17E/K-30Hardline1 Target Name Targets associated with this well path (Continued) Alaska State Plane 3 Mean Sea LeveVGlobal Coordinates #1 9812.00 5978742.42 N \¡;;i¡g70119.14 E #2 9812.00 5978722.69 N \270159.72 E #3 9812.00 ªª7869Q~~1 N 270184.78 E #4 9812.00 5~í~~55:93 N 270197.74 E #5 9812.00 5970020.34 N 270201 .44 E #6 9812.00 N 270195.36 E 9812.00 5978543.66 N 270175.45 E 812.00 5978517.27 N 270136.30 E 812.00 5978523.14 N 270089.28 E 9812.00 5978553.72 N 270055.42 E 9812.00 5978589.69 N 270037.14 E 9812.00 5978625.67 N 270030.14 E 9812.00 5978661 .86 N 270032.45 E 9812.00 5978698.91 N 270045.51 E 9812.00 5978732.01 N 270074.54 E Geographical Coordinates #1 700 20' 36.6802" N 147051' 57.5428" W #2 700 20' 36.4985" N 1470 51' 56.3401" W #3 700 20' 36.1877" N 147051' 55.5793" W #4 700 20' 35.8537" N 147051' 55.1700" W #5 700 20' 35.5049" N 147051' 55.0301" W #6 70020' 35.1311" N 147051'55.1738" W #7 70020' 34.7433" N 1470 51' 55.7204" W #8 700 20' 34.4720" N 1470 51' 56.8400" W #9 700 20' 34.5156" N 1470 51' 58.2183" W #10 700 20' 34.8060" N 147051' 59.2345" W #11 70020'35.1541" N 147051'59.8005" W #12 700 20' 35.5056" N 147052' 00.0372" W #13 700 20' 35.8621" N 1470 52' 00.0022" W #14 700 20' 36.2303" N 1470 51' 59.6540" W #15 700 20' 36.5644" N 1470 51' 58.8359" W 3-17E/K30 T1 9867.00 7651.41 N 368.39 W Circle Mean Sea LeveVGlobal Coordinates: 9812.00 5978632.93 N 270109.38 E Geographical Coordinates: 700 20' 35.6009" N 147051' 57.7297" W Target Radius: 175.000 DrillQuest 3.03.02.002 Page 8 of 11 .7' -' BPXA Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 Revised: 18 February, 2003 18 February, 2003 - 16:21 Targets associated with this wellpath (Continued) Alaska State Plane 3 Target TVD ¡¡!Eastings Target Target (ft) (ft) Shape Type N 240.44 W Polygon Mean Sea LeveVGlobal Coordinates: Þ5978718.00 N 270240.00 E Geographical Coordinates: 't;;;,u 700 20' 36.4766" N 1470 51' 53.9915" W Target Boundary Point #1 1,~45.00 7740.44 N 240.44 W -- #2 10245.00 7728.19 N 640.25 W iJÞ3 10245.00 7740.44 N 240.44 W Mean Sea LeveVGlobal Coordinates #1 10190.00 5978718.00 N 270240.00 E #2 10190.00 5978718.00 N 269840.00 E #3 10190.00 5978718.00 N 270240.00 E Geographical Coordinates #1 700 20' 36.4766" N 1470 51' 53.9915" W #2 700 20' 36.3559" N 1470 52' 05.6724" W #3 700 20' 36.4766" N 147051'53.9915" W 10245.00 7884.57 N 444.96 W Circle Mean Sea LeveVGlobal Coordinates: 10190.00 5978868.33 N 270039.99 E Geographical Coordinates: 700 20' 37.8941" N 1470 51' 59.9671" W Target Radius: 150.000 10245.00 7884.57 N 444.96 W Polygon Mean Sea LeveVGlobal Coordinates: 10190.00 5978868.33 N 270039.99 E Geographical Coordinates: 700 20' 37.8941" N 147051'59.9670" W Target Boundary Point #1 10245.00 7960.75 N 437.98 W '~ #2 10245.00 7946.20 N 410.23 W #3 10245.00 7923.76 N 393.98 W #4 10245.00 7901.34 N 385.47 W #5 10245.00 7878.34 N 381.84 W #6 10245.00 7852.57 N 383.49 W #7 10245.00 7823.61 N 394.35 W #8 10245.00 7802.79 N 420.85 W #9 10245.00 7807.42 N 454.17 W #10 10245.00 7830.16 N 477.04 W #11 10245.00 7854.90 N 488.68 W #12 10245.00 7878.40 N 493.69 W #13 10245.00 7902.23 N 493.55 W #14 10245.00 7928.14 N 487.09 W Page 9 of 11 DrillQuest 3.03.02.002 BPXA Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 Revised: 18 February, 2003 18 February, 2003 - 16:21 3-17EIK-30 T2Drillers@95 % 3-17E/K30 T2 3-17E/K-30Hardline3 Target Name Targets associated with this well path (Continued) Alaska State Plane 3 DrillQuest 3.03.02.002 Page 10 of 11 .~ BPXA #15 10245.00 7952.83 N 468.80 W Mean Sea Level/Global Coordinates #1 10190.00 597894426 N 270049.29 E #2 10190.00 5978928.86 N ;;i~)~70076.59 E #3 10190.00 5978905.94 N '{£70092.14 E #4 10190.00 ~?88~~k N 270099.96 E #5 10190.QQ 5I~ª§60:'f7 N 270102.89 E #6 10190.00 5978'834.46 N 270100.45 E #7 10190.00 N 270088.71 E 10190.00 5978785.85 N 270061 .58 E 190~mv 5978791.49 N 270028.42 E 90.00 5978814.92 N 270006.25 E 10190.00 5978840.01 N 269995.38 E 10190.00 5978863.65 N 269991 .09 E 10190.00 5978887.47 N 269991 .96 E 10190.00 5978913.17 N 269999.21 E 10190.00 5978937.28 N 270018.25 E 'á.phical Coordinates #1 700 20' 38.6434" N 1470 51' 59.7635" W #2 700 20' 38.5002" N 1470 51' 58.9524" W #3 700 20' 38.2796" N 147051' 58.4778" W #4 700 20' 38.0591" N 147051' 58.2291" W #5 700 20' 37.8329" N 147051' 58.1228" W #6 700 20' 37.5794" N 147051'58.1711" W #7 700 20' 37.2946" N 1470 51' 58.4883" W #8 700 20' 37.0898" N 147051' 59.2626" W #9 700 20' 37.1352" N 147052' 00.2360" W #10 700 20' 37.3589" N 1470 52' 00.9044" W #11 70020' 37.6023" N 147052' 01.2444" W #12 70020' 37.8334" N 1470 52' 01.3908" W #13 700 20' 38.0678" N 1470 52' 01 .3868" W #14 700 20' 38.3226" N 1470 52'01.1981"W #15 70020' 38.5654" N 1470 52' 00.6637" W 10245.00 8040.30 N 249.62 W Polygon Mean Sea Level/Global Coordinates: 10190.00 5979018.00 N 270240.00 E Geographical Coordinates: 700 20' 39.4258" N 147051' 54.2602" W Target Boundary Point #1 10245.00 8040.30 N 249.62 W #2 10245.00 8028.05 N 649.43 W #3 10245.00 8040.30 N 249.62 W - Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E I K-30 Wp 11 Revised: 18 February, 2003 18 February, 2003 - 16:21 3-17E/K-30Hardline2 Alaska State Plane 3 DrillQuest 3.03.02.002 Page 11 of 11 18 February, 2003 - 16:21 .~ Mean Sea Level/Global Coordinates #1 10190.00 5979018.00 N #2 10190.00 5979018.00 N #3 10190.00 N Geographical Coordinates #1 147051' 54.2602" W #2 147052' 05.9416" W 147051' 54.2602" W 3-17E/K30 Fault2 55.00 8485.80 N 403.33 W Polygon '-' 5979468.00 N 270100.00 E - - 70020' 43.8074" N 147051'58.7519" W Target Boundary Point #1 55.00 8485.80 N 403.33 W #2 55.00 8228.64 N 804.11 E #3 55.00 8485.80 N 403.33 W Level/Global Coordinates #1 0.00 5979468.00 N 270100.00 E #2 0.00 5979174.00 N 271299.00 E #3 0.00 5979468.00 N 270100.00 E Geographical Coordinates #1 70020' 43.8074" N 1470 51' 58.7519" W #2 700 20' 41 .2779" N 1470 51' 23.4727" W #3 70020'43.8074" N 147051' 58.7519" W BPXA Targets associated with this wellpath (Continued) Alaska State Plane 3 Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 11 Revised: 18 February, 2003 ~ ) CQ:1 .r:~.! ® 7 :[ ~llA\LJ L6 ~ 1: ® ~ ® @ -r¡ ® ~,_r lA\ ~ lA\ ciD '.~J\\ L0J FRANK H. MURKOWSKI, GOVERNOR AItA~1iA OIL AND GAS CONSERVATION COMMISSION ADMINISTRATIVE APPROVAL NO. 202.41 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska) Inc. P. O. Box196612 Anchorage, AK 99519-6612 Re: Spacing Exception for Endicott 3-17E/K-30 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated February 19, 2003, requesting a spacing exception for drilling and completion of the Endicott 3-17E/K-30 well. Well 3-17E/K-30 will be a producer in Subzone 2A of the Kekiktuk Fonnation. Nearby existing well 3-07 A/L-29 is a producer that is completed in this same interval. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the pool." The Commission understands that the interval intended for completion within 3-17E/K~30 is approximately 975 feet horizontal distance from the existing 3- 07 A/L-29 well. These two wells lie on opposite sides of the Midfield Fault, which is a sealing fault based on reservoir pressure infonnation. Because these wells lie on opposite sides of a sealing fault, production from Kekiktuk Subzone 2A in well3-17E/K-30 will not interfere with production from we1l3-07A/L-29~ The Commission has detennined drilling and completion of the Endicott 3-17E/K-30 well will not promote waste, will enhance recovery, and hereby approves the drilling and completion of the well within Kekiktuk Subzone 2A as proposed pursuant to Rule 3 of Conservation Ord~r No. 202. DONE in Anchorage, Alaska this 21 st day of February 2003. BY ORDER OF THE COMMISSION r '- Daniel T. Seamount, Jr. Commissioner [wet,.L ~E~MIT ÇHEC~IST COMPANY BPX FIELD & POOL 220100 - Endicott, Endicott ADMINISTRATION APPR /6 WELL NAME DIU 3-17/K-30 Initial ClasslType DEV 11-01L PROGRAM Exploratory (EXP) _ Development (DEV) ~ Redrill-1L Service (SER) _Well bore seg _ Annular disposal para req GEOL AREA 890 UNIT No. 10450 ON/OFF SHORE On Permit fee attached ......................................................................................... Lease number appropriate ... ... ... ... ... ... ... ... ...... ... ... ... ... ... ... ... ... '" ... ... ... ...... ... ..... Unique well name and number ...... ... ...... ... ... ... ... ...... ...... ... ...... ... ... ... ... ... ... ........ Well located in a defined pool... ... ... ... ... ... ... ... ...... ......... ...... ... ... ... ... ...... ... ...... .... Well located proper distance from drilling unit boundary ... .,. ... ... ... ... ... ... ...... ... ... ... ... Well located proper distance from other wells ... ... ... ... ... ... ...... ... ... ... ... ... ... ... ... ... .... Sufficient acreage available in drilling unit...... ...... ...... ... ...... ...... ............ ...... ... ...... If deviated, is well bore plat included ... ... ... ......... ...... ...... ...... ... ...... ... ... ...... ... ........ Operator only affected party... ... ... ...... ... ... ......... ... ... ... ...... ... ... ...... ...... ... ......... ... 10. Operator has appropriate bond in force... ...... ...... ...... ...... ............... ......... ...... ..... 11. Permit can be issued without conservation order ...... ... ... ... ...... ... ... ...... ...... ... ....... 12. Permit can be issued without administrative approval... ... ... ... ... ... ... ... ............ ... ..... 13. Can permit be approved before 15-day wait......... ... ... .. . ...... '" ...... ...... ... .. .... ... ... .. 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified ... ......... ... ...... ... ...... ............ ... ..... 16. Pre-produced injector: duration of pre-production less than 3 months......... ... ... ... ... . 17. ACMP Finding of Consistency has been issued for this project........................ ...... . 1. 2. 3. 4. 5. 6. DATE 7. 8. 2. -19·t::>3 9. (For Service Well Only) (For Service Well Only) (For Service Well Only) \¡,JbA- zltJlo 3 ENGINEERING APPR DATE 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. Conductor string provided ... ...... ............ ...... ......... ...... ... ... ... ... ...... ... ... ... ... ... .... Surface casing protects all known USDWs ............ ...... ...... ............ ...... ...... ...... ... CMT vol adequate to circulate on conductor & surf csg ......................................... CMT vol adequate to tie-in long string to surf csg ... ... ......... ... ... ... ... ... ............ ... .... CMT will cover all known productive horizons ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... Casing designs adequate for C, T, B & permafrost......... ... ...... ...... .. .... .. .... .. .. .. ..... Adequate tankage or reserve pit...... ......... ...... ...... ...... ...... ...... ...... ...... ... ... ... ... .. If a re-drill, has a 10-403 for abandonment been approved ... ... ...... '" ... ... ......... ... .... Adequate well bore separation proposed ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .... If diverter required, does it meet regulations...... ... ......... ... ......... ......... ... ...... ...... .. Drilling fluid program schematic & equip list adequate ............... ...... ... ... ................ BOPEs, do they meet regulation ... .,. ... ... '" ... ... '" ... ... ... ...... ... '" ... ... ... ... ... '" ... ..... BOPE press rating appropriate; test to ...... ............ .....4500 psig ... ... ... ...... ..... Choke manifold complies w/API RP-53 (May 84) ................................................. Work will occur without operation shutdown ... ... ... ... ... ... ... ... ... ... .., ... ... ... ... ... ... ..... Is presence of H2S gas probable ... ... ...... ... ... ... ... ... ... ...... ...... ... ... ... ... ... ... ... ... .... Mechanical condition of wells within AOR verified ... ... '" ... ... '" ... ... ... ...... ... ... ... ... ... GEOLOGY (For Service Well Only) ¡;: 35. Permit can be issued w/o hydrogen sulfide measures...... ...... ...... ...... ...... ...... ...... . 36. Data presented on potential overpressure zones...... ...... ...... ...... ... ...... ...... ...... ..... DATE 37. Seismic analysis of shallow gas zones ... ... ... ... ... ...... ... ... ... ... ... ... ... ... ... ... ... ... '" ... 2.38. Seabed condition survey (if off-shore) ............................................................... 2 ·1t¡~C>J39. Contact name/phone for weekly progress reports [exploratory only] ..................... GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: ~SP 11 ~~:: 02f7lI{C] RPC: TEM: JDH: SF~ WGA: ~ MJW NA Not required as this is a change of bottom hole location prior to spudding the well. Yes Surface location and top productive interval in ADL 047502; TD is in ADL 312828. Yes Yes Yes No SPACING EXCEPTION Required. Well will be within 1000' of existing weIl3-07A1L-29. Application for spacing exception received 2/19/03. SFD Yes Yes Yes Yes Yes No Administrative Approval required. Text for 202.41 drafted 2/19/03. SFD Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable I ~ Yes Yes Yes Yes Yes Doyon 15 11/22/02 Yes Yes Yes Yes Yes Yes NA Not Applicable Max MW 10.3 ppg MSP 3942 NA Not Applicable No NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable Comments/lnstructions ~~~~lfÆ~:~ E: F fÆ ~fÆ ~ .~~!Æ ) AlASKA OIL AND GAS CONSERVATION CO.MMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 3-17E/K-30 BP Exploration (Alaska) Inc. Permit No: 202-247 Surface Location: 2524' SNL, 799' WEL, SEC. 08, T11N, R17E, UM Bottomhole Location: 5222' SNL, 598' WEL, SEC., 32, T12N, R17E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exenlpt you from obtaining additional penllits or approvals required by law from other govenlmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Conlmission reserves the right to withdraw the permit in the event it was erroneously issued. Operations nlust be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Conlmission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ;2?t!'day of January, 2003 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ) STATE OF ALASKA I \ ALASK,-. ';'IL AND GAS CONSERVATION COMIv"ðSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well IJ Exploratory IJ Stratigraphic Test II Development Oil IJ Service IJ Development Gas IJ Single Zone IJ Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 55' Endicott Field I Endicott Pool 6. Property Designation ADL 312828 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number / 3-17E/K-30 9. Approximate spud date 02/09103 / Amount $200,000.00 /' 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13801' MD 110322' TVD o 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 59 Maximum surface 3942 psig, At total depth (TVD) 10276' / 4970 psig Setting Depth Too Botom Quantitv of Cement Lenath MD TVD MD TVD (include staae~data) 3785' 10016' 7750' 13801' 10322' 858 cu ft Class 'G' '" 1 a. Type of work IJ Drill II Redrill IJ Re-Entry IJ Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM At top of productive interval 206' SNL, 583' WEL, SEC. 05, T11 N, R17E, UM At total depth 5222' SNL, 598' WEL, SEC. 32, T12N, R17E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 047502, 57' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10100' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Hole Casino Weiaht Grade Couolina 8-1/2" 4-1/2" 12.6# 13Cr Hydril VJ 4í\- I 17-'-/ D 3 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13010 feet Plugs (measured) true vertical 10146 feet Effective depth: measured 12878 feet Junk (measured) true vertical 10018 feet Casing Length Size Cemented Structural Conductor Su rface Intermediate Production Liner 142' 30" 2498' 13-3/8" 10500' 9-5/8" 386' 7"x4-1/2" 2706' 2-7/8" Perforation depth: measured 12897' - 12902' MD TVD Driven 4185 cu ft Permafrost 575 cu ft Class 'G' 142' 2498 10500' 142' 2496' 8082' RlCŒ~::UE:D DEC 1 7 2002 10312' - 10698' 10304' - 13010' 7959' - 8225' 7954' - 10146' true vertical 10037' - 10041' Alaska Oil & Gas Cons. Commission Anchorage II Filing Fee IJ Property Plat IJ BOP Sketch IJ Diverter Sketch II Drilling Program II Drilling Fluid Program IJ Time vs Depth Plot IJ Refraction Analysis IJ Seabed Report 1120 AAC 25.050 Requirements Contact Engineer Name/Number. Walter Quay, 564-4178 Prepared By Name/Number: Sandra Stewman, 564-4750 21, ~;~:~y eF~:~O:::nthe J~¡z::rreetto the b;::eot ;:n:~o~ri~;ge Engineer Date / ¡-/I 7 ~ l- . '. , .:... . ,. .. . '. ,.,~",m,i.'qnUse.º,,~y Permit Number API Number APprQ~,.1 Dat~/ /J See cover letter 2. CI ¿ - 2.. 7' /> 50- 029-21946-05 , Å1fv /j for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Re uired 0 Yes ~ No Hydrogen Sulfide Measures f! Yes 0 No Directional Survey Required .EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: ·T~t-1>oPE- ~ 4':;;DO pSt'. ORIGINAL SIGNED BY \1 \ ::.¡,~' 20. Attachments Approved By Form 10-401 Rev. 12-01-85 Commissioner by order of the commission Date i J ¿l..1 ) ~ (Submit In Triplicate ) ) Endicott 3-17E1K30 Well Program I Well Name: 3-17E/K-30 Drill and Complete Plan Summary I Type of Well (service I producer I injector): Surface Location: Target Location: K-30 K2B Target Location: K-30 K2A Target Location: K-30 K1 Target Location: BHL Well TD I AFE Number: I Estimated Start Date: I Producer 2524'FNL,799'FEL,SEC.8,T11N,R17E X=270,243.36 Y=5,970,973.83 206' FNL, 583' FEL, SEC. 5, T11 N, R17E X=270,669.00 Y=5,978,563.01 2=9895' TVD 119' FNL, 588' FEL, SEC. 5, T11 N, R17E X=270,666.53 Y=5,978,649.88 2=10,031.00' TVD 351 FNL,593' FEL, SEC. 5, T11N,R17E X=270,664.15 Y=5,978,733.88 2=10,193.00' TVD 5222'FNL,598'FEL,SEC.32, T12N, R17E X=270',661.53 Y=5,978,826.07 2=10,322.51' TVD / / /' I END 727111 I I Rig: I Doyon 15 ./ I Feb. 9, 2003 /' 1 OperatinQ days to complete: 24 I MD: 113,801' I 1 TVD: 110,322 I 1 Max Inc: 159 @ 11,000' 1 I KOP: 110,166' I 1 KBE: 155.0 I Objective: I Well Design (conventional, slimhole, etc.): I Conventional Sidetrack Kekiktuk S2A3 & S2A1 Sands Overview: Mill Window in 9-5/8" at -10,100' in Seabee shale. Directionally drill to TD @ -13,800' MD, 150' below the K1 Zone in the Kekiktuk. Run and cement a 4-1/2" liner in this 8-1/2" hole, followed by a 4-1/2" completion. ' Version 1.0 16 Dee 2002 ) ) Endicott 3-17E1K-30 Well Program Mud Program: 9-5/8" Milling Fluid Properties: Density Viscosity Yield Point (ppg) / (seconds) (lb/100ft2) 9.7 200 - 300 > 70 I Bentonite Milling Fluid tauO Gel Strengths (lb/100ft2) 1 Osec/1 Omin > 15 25-40/30-60 APIFL (mls/30min) <8 pH 8.5- 9.5 8.5-in Intermediate Hole Mud Properties: I GEM Freshwater Mud Density Plastic Viscosit Yield Poi TauO 10' G API/ HTH pH LGS (ppg) (cp) (lb/100ft~ (lb/100ft~ (mls/30mi % vo Drill out of Surf 9.7 10 -15 27 - 32 4 -7 10 6-10 8.5-9.5 < 5 Casing To Top HRZ TopHRZtoTD 10.3 / 10-15 20-25 3-7 10 <4/<10.0 8.5-9.5 <5 LCM Restrictions: Minimize use of organic LCM products in the Kekiktuk Waste Disposal: Waste mud and drill cuttings taken to DS-4 disposal site Notify Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Cement Program: Casin~ Size I 4.5", 1 ~:,6-lb/ft 13Cr Hydril 563 Production Liner Basis 50% excess,~::l gauge hole. Planned TOC - 1/~ MD. 1500' above top of Kekiktuk, but keep> 1000' from window if possible. L~,,,·,,,,·· Spacer 75 bbI11.5-lb/gal MudPush XL Spacer Lead ~'J ./ Tail 1 sx (152.8-bbl) 15.8 Ib/gal Prem G - 1.15 cuft/sx (top of tail - ~';~9~~!~~[?L ' Temp IŠHST::= 2180 F estimated by Dowell Evaluation Program: 8-1/2" Hole Section: Open Hole: MWD/GR PWD for the entire section RES/NEU/DEN through Kekiktuk Version 1.0 2 of 8 16 Dec 2002 , ) ) Endicott 3-17E1K-30 Well Program Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (lb/Qal)* KOP in Seabee 10,166 7862 Tuff 12,260 9052 THRZ 12,928 9591 lb. .~ LCU/P2 Coals 13,265 9867 K3A 13,265 9867 4819 9.44 K2B 13,307 9902 4484 8.76 K2A 13,461 10,031 4240 8.17 K1 13,651 10,193 4910 9.31 *Based on sub-surface depths. Casingrrubing Program: Hole Csgl WtlFt Grade Con" Length Top Bottom Size Tbg O.D. / MD I TVDrkb MD I TVDrkb 8.5-in 4.5" 12.6 # 13Cr Hydril563 3785 ft 10,016'/7750' 13,801 '/1 0,322' Tubing 4.5" 12.6# 13 Cr Vam ACE 10,016' 0/0 10,016'/7750' Version 1.0 3 of 8 16 Dee 2002 Well Control: Production Intervals BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure Casing Test Pressure (9-5/8" x 4-1/2") Planned completion fluids } ) Endicott 3-17E1K-30 Well Program 13-3/8", 5M, Double ram with annular (Hydril - GK) 4970-psi (9.3-lb/gal @ 10276-ft TVD) 3942-psi (0.1-psi/ft gas gradient to surface) /' Infinite with 12.0 PP9--·emw FIT Rams test to 4500-psi/250-psi. Annular test to 3,500-psi/250-psi 3,OOO-psi 8.5 Seawater & Diesel packer fluid 3-17E/K-30 is being drilled as a K2A producer~The 10.3 Ib/gal recommended mud weight for the HRZ is the controlling mud weight requirement. All of the anticipated Kekiktuk intervals should be overbalanced with this mud weight. Version 1.0 4 of 8 16 Dee 2002 ). ) Endicott 3-17E1K-30 Well Program Sidetrack and Complete Procedure Summary Pre-Ria Work: 1. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. COMPLETE (10/10/01): Packoff passed test to 3000 psi, Tubing hanger passed test to 5000 psi. All lock-down screws functioned. Some lockscrews are hard to operate. 2. RU slickline, drift tubing and tag PBTD. Well drifted on 11/11/02 w/2.25" OD to ·12,839' and w/3.625" OD to 10,266'. Dummy off all GLM's. Test the integrity of the dummied off tubing string by applying -3000 psi on the annulus. GLMs dummied off and IA x tubing annulus tested to 3000 psi on 10/27/02 3. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement. Use adequate cement volume to fill the 2-7/8" casing from PBTD (12,878') and extend the cement plug up to the 4-1/2" tubing @ - 10,290'. approximately 15' above the 2-7/8" X 4-1/2" liner hanger, plus squeeze 2 bbls to the perforations. Circulate to clean any residual cement above this depth as the casing cut is planned for just 40' above this depth, at -10,250'. 4. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut @ -10,250'. 5. Test the integrity of the cement plug and 2-7/8" casing by pressure testing the tubing to 3000 psi for 30 minutes. 6. Pull one of the lower DGLMs. Displace the well to clean seawater by circulating down the tubing via the lower GLM. Freeze protect top 1500· MD with diesel. 7. RU E-line. Cut the 4 V2" L-80 tubing at approximately 10,250' MD using either a jet or chemical cutter. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. If necessary, level the pad. Ria Operations: /' 1. MIRUDoyon15. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree~lignment marks should be made before removing the old tree. Nipple up and test BOPE to 250/4500 psi. Pull TWO. 4. Pull and lay down 4-1/2" tubing from E-line cut and above. ,- 5. MU 9-5/8" window section milling assembly and RIH with 5" DP to top of tubing stub. Displace well to milling fluid. .,/ 6. Spot a balanced 18.0 ppg mud pill from -10,250' to 10,150'. 7. Section mill window from 10,150' to 10,200'. POOH. ~ 8. MU cementing mule-shoe and TIH to 10,250'. Circulate and condition. 9. Mix and pump cement kickoff plug. POOH. /"' 10. MU 8-1/2" PDC drilling assembly including MWD/GR RIH to top of cement. Clean out cement to kick-off point. 1 ~ go\ /' 11. Kick-off and drill the 8-1/2" hole section as per directional plan to TD at +/-1.3if86" MD (10,332' TVD). Condition hole for running liner, spot liner running pill, and POOH. 12. Run and cement a 4 V2", 12.6# 13 Cr80 production li~ Release from liner and set liner top packer. Test backside to 1000 psi to verify liner top packer is set. ,/ 13. Run 4-1/2", 12.6# 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie- back sleeve. 14. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect and secure the well. ../' 17. Rig down and move off. Post-Ria Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below t!)e production packer. 2. RU CTU to clean much from 4-1/2" liner. / 3. Install gas lift valves. 4. RU e-line. Perforate -50' of Kekituk interval with 2-7/8" guns. Version 1.0 5 of 8 16 Dec 2002 ), ) Endicott 3-17E1K-30 Well Program Job 1: MIRU Hazards and Contingencies } Three wells, 3-21, 3-19 and 3-15 will require shut-in before the 3-17 rig move. The well is located -10' from 3-15 & 3-19 and 20' from 3-21. These wells will need to be shut-in at the both at the surface and the SSSV. All surface flowlines and gas lift lines will be de-pressured to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. } SDI is designated as an H2S site. Follow Standard Operating Procedures for H2S at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: 3-11 Max: 800 ppm (10/1/00), Last: 380 ppm (2I28/02) /" 3-15 Max: 128 ppm (7/1/01), Last: 52 ppm (2I22102) 3-19 Max: 1600 ppm (3/2199), Last: 160 ppm (12110/00) 3-21 Max: 167 ppm (3/1/02), Last: 47 ppm (3/07/02) The maximum recorded level of H2S on the pad was 2000+ ppm from 3-43 on June 19,1999. Job 2: Decomplete Well Hazards and Contingencies } The existing perforations should be isolated by the pre-rig cement plug. The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. Seawater will be underbalanced to the Kekiktuk reservoir pressures. } NORM test all retrieved well head and completion equipment. Reference RP .:. "De-completions" RP Job 4: Section Mill Hazards and Contingencies } Ensure that the Baker section mill is dressed with the older style 3-arm cutters. } Ensure that the milled cuttings are being cleaned from the hole. Adjust mud and milling parameters as required to provide for good hole cleaning. } Once section milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Version 1.0 6 of 8 16 Dee 2002 ') ) Endicott 3-17E1K-30 Well Program Job 7: DrillinQ Intermediate/Production Hole Hazards and Contingencies ~ The well will kick off in the Seabee with a 9.7 Ib/gal mud. The mud weight will be increased to 10.3 Ib/gal prior to drilling the HRZ. The 10.3 mud weight requirement for the HRZ should result in being overbalanced to all of the Kekiktuk reservoirs. Follow all shale drilling practices to minimize potential problems. ~ The well path will drill full sections of the Tuffs and HRZ shales, and both formations have been troublesome in the Endicott area. The Tuffs is typically slow and erratic drilling, which can wipe out a PDC bit if proper drilling parameters are not maintained. The HRZ on the other hand has shown severe hole instability problems if insufficient mud weight is used. Follow all (1) shale drilling practices, (2)ECD management to limit high ECD's, and (3) maintain proper mud weights and shale stabilizers in the drilling fluid. ~ The P-3 coal sections should be encountered at the top of the Kekiktuk interval in this well. These coals have caused packoff and stuck pipe problems in the past. Follow good coal drilling practices. ~ Differential sticking is the largest operational risk in this well. Differential sticking will be a problem if the drill string or liner is left stationary for any period of time across the high permeability Kekiktuk Sands. The GEM enhanced LSND drilling mud must be kept in excellent shape when drilling the Kekiktuk to provide good filter cake properties. The Kekiktuk K2A reservoir pressure is expected to be 4300 psi (8.2 ppg EMW) at the bottom hole location. The 10.3 Ib/gal mud required for HRZ stability will be 2 Ib/gal over balanced to the Kekiktuk. This 1200 psi pressure differential creates a severe differential sticking risk. ~ No major fault crossings are planned in the drilling of this well. The well path will cross over the major Midfield Fault but this fault does not extend upwards into the wellbore path. The directional plan will need to followed closely in the target interval to prevent hitting the smaller faults to the south and north of the target. Job 9: Install 4Y2" Production Liner Hazards and Contingencies )0> Long shale intervals will be exposed while running the liner. Rotation of the liner may be necessary if downward progress is not possible. To minimize ECD spikes and associated shale stability problems, bring pumps on slow and minimize downward surges with pipe. The limits for working the liner to bottom are: WorkinQ RanQes o Torque in liner: < 5000 ft-Ibs o RPM in liner < 35 rpm o Pressure in liner < 2000 psi o Compression in liner < 50K Ibs o Tension in liner < 100 K Basis Max: Connections MU to 6000 ft-Ibs Max: 2625 psi sets Flexlock LH Max: 200K (HRD Setting Tool) Max: 288K (pipe) ~ Differential sticking is a significant potential problem in the Kekiktuk. Minimize the time the pipe is left stationary while running the liner through this interval. )0> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 12: Run Completion Hazards and Contingencies Version 1.0 7 of 8 16 Dec 2002 ') ) Endicott 3-17E1K-30 Well Program ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release Rig Hazards and Contingencies ~ See Job 1 for adjacent well spacing. These are close well centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Version 1.0 8 of 8 16 Dec 2002 T. ELEV = 56' SF. ELEV= 17.2' MAX. DEV.::::: 56 Deg. @ 6100' Pr\,"þosed Completior': ~~-17E TEE: 4-1/16"/5000 psi 1 CIW ISakerAct. WELLHEAD: 13-5/8" 1 5000 1 FMC SSH big 13-3/8", 68#/ft, L-80, CYHE BTRS. 12498' Á 9-5/8", 4 7#/ft NT80S xo to NT 95HS . o HES 'HXO' SVL (3.813" MIN. ID) ... W/SSSV MIN I.D. 2" 1,522' I. I. I. I. 4-1/2" 12.6Ib/ft 13 Cr80 VAM ACE TBG 6 --> 4-1/2x1-1/2" GLMs. Depth TBD 4-1/2" X Nipple -- 3.813" ~ ~ 9-5/8" BAKER S-3 PACKER 9-5/8"x7" BAKER FLEXLOCK LINER HANGER + LTP AT 10000' . I 4-1/2" X Nipple -- 3.813" u ........... ....... 7" X 4-1/2" X-Over ~ SECTION MILL 50' WIND~-7.·/"- KICKOFF CMT PLUG AT ~ ~ :z¡ \ Btm. 9-5/8" Csg ~ 10,500' PBTD 2-7/8" Float Shoe 12940' 13010' DATE 8/20/2002 11/14/02 REV. BY FJ wa COMMENTS Proposed Completion Proposed Completion . 4-1/2" XN Nipple -- 3.725" 8-1/2" HOLE x 4-1/2" LINER 13 CR HYDRIL 563 LINER I :~) -¡ v X X X ' --XX'./' TD 13802'MD, 1032:¿" fV LJ 2-7/8" 6.4#/ft. ST-Liner ~ ENDICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM BP EXPLORATION, INC. . . ~1 ) 2 ) 3 ) 4 ) 5 ) 6 ) 7 ) 8 ) Ço¡¿¡¿~TeD Q).Pj! ) BP EXPLORATION (ALASKA), INC. WELLHEAD LOCATION DATA WFII: 3-17/J-30 FIFJ n: SDI Well Head J ocation: 2524' from North line 799' from East line Section 8, T11 N, R17E, UPM x = 270243.36 Y c: 5970973.83 ASP Zone 3 LAT = 700 19' 20.3471" N, LONG = 1470 51' 46.9664" W Local Benchmark Elevation Ft. AMSL Top Edge of Cellar 14.5 Ft. AMSL Rotary Table to Base Flange· 39.25 Ft. Rotary Table to Ground Level· 40.50 Ft. Base Flange Elevation 15.75 Ft. AGL Rotary Table Elevation 55.0 Ft. AMSL · Measured by Drilling Foreman CIRCUJ ATION: /rh Endicott Reservoir Engineering Operations (MB 7-1) - 1 North Slope· to Rig for Posting (North Slope, BOC) - 2 Well Files (MB 12-1) - 1 Drilling Engineer (MB 12-1) - 1 Graphic Services, Supv., Cartography (MB 4-4) - 1 #J;Ä 7/;7/£7' Date ) 1 !II::J........y-.LJ1, BPXA ClIAIII 1 IN" ....Vlc:n A HIIIIIMIoII COmpany North Slope Alaska Endicott SDI 3-17E1K-30 Wp 9.0 Eastings(Well) Scale: 1 inch = 750ft o DrillQu,est" We.: Current Well Propertl.. 3-17E1K-30 Horizontal Coordinates: Ref. Global Coorclnates : Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: North Reference: Units: Total Depth: 13802.38ftMD,10322.51ftTVD 1~~~~D 3-17E/K30 T3 10321.51ftTVD Circle, Radius: 15O.OOIt I 10193.00 TVD, 7785.83 N, 182'05~' ~ . 3-17E/K-30 T3 Drillers @ 95 % I.. ,\ 3-17E/K30 T2 I \ True North Circle, Radius: 150.00ft . " Feet (US) 10031.00 TVD, 7686.45 N, 187.92 E ,''''6 3-17E/K-30 T2 Drillers @ 95~% . ". Begin Rotary Drop @ 0.7500/10Oft: 12974.64ft MD, 9627.38ft TVD 3-17E/K30 T1 - Point Target I 9895.00 TVD, 7598.64 N, 193.11 E 12570.27 End Dir, Start Sail @ 35.942° : 12273.01ftMD,9059.33ftTVD I I Begin Dir @ 3.5000/10Oft: 11595.56ft MD, ~07.05iCTVD ~ I ~ d1384.23 !!! '.' ~ ~ 5970973.83 N, 270243.36 E 1590.05 N, 2038.60 W 70·19'20.3471· N,147° 51'46.9665' W 55.0011 above Mean Sea Level 55.0011 above Structure Reference "I~ 'II~I ~IIIII I~' I I I cø c I il<H1<IH 0791.99 I \1'1"""'< End Dir, Start Sail @ 59.566°: 10437.87ftMD,8020.6~TVD - I Decrease Dir Rate @ 5.0000/10Oft : 10186.0OftMD,7874.8· ftTVD "'-I 0226.80 Kop TF 44° Left Begin Dlr 10.0000/100ft : 10166.0Oft MD, 7861.69ft TVD ---; '~)7\SS I 1823.19 II I ,II" 1II,lli"ill: ~I~I' ,,,,,,,11111'" ':1'11ll!,!1 ~III' ¡~: I· 3· ('¡O/M-3/ -'206H2 7500- op TF 44° Left Begin Dir 10.000°/1000: 10166.00ft MD, 7861.69ft TVD ()(~ Decrease Dir Rate @ 5.0000/10Oft: 10186.0OftMD,7874.81ftTVD 200.00 End Dir, Start Sail @ 59.566°: 10437.87ftMD,8020.62ftTVD _ 8250- 1i) ~ , ,,~,).(~) egin Dir @ 3.5000/10Oft: 11595.56ft MD, 8607.05ft TVD ~ õ.. () c B t: () 9000- > Top .l'l..í,:ln~'~~r, /~'" 2~nd Dir, Start Sail @ 35.942°: 12273.01ftMD,9059.33ftTVD :onu.on Begin Rotary Drop @ 0.750°/1000: 12974.64ft MD, 9627.38ft TVD r,wHFZ, ..~5t).).t:1I) 9750 - u,'~'c! HRZ LCU. 1\30'1. ~.:8ÔiOO,'1rVD š .... II -£ .5 ... k>~Jfj ,ll~N.)2 oourv{, f-'ossJi),'e p~~ C{1~l¡'S. .QS,(5,:". OOrz TVO ~ ~ ...~.oo" T..~~~, .~~,!\ d-._ ~?~~} IOe~!~·Ci(.IhC~~.'~~, ,. ~....,;.-3~-17E/,!30 T3 _ _._Circle, Radius: 150.00ft 10193.00 TVD, 7785.83 N, 182.05 E .00 3-17E/K-30 T3 Drillers tJ 95 % 4 112'Uner 13801.22ttMD 10321.511!'ND Total Depth: 13802.38ftMD,10322.51ftTVD I I 5625 6375 7125 Vertical Section (Well) Section Azimuth: 26.680° (True North) J2 B en 10500 """'\ I 4125 Scale: 1 inch = 750ft I 4875 DrillQuest 3.03.02.002 750 I Fauit3 - 7500 Fault 1 :::- ~ - 6750 (I) C) c: :ë 1::: o Z - 6000 š .... II ~ ... - 5250 ~ ) " sp........y-!IUI1 BPXA HUI- LI~~ A:'=~: North Slope Alaska Endicott 3-17E1K-30 Wp 9.0 DrillQuest'" North Reference : Units: 5970973.83 N, 270243.36 E 1590.05 N, 2038.60 W 70019' 20.3471" N, 147051' 46.9665" W 55.00ft above Mean Sea Level 55.00ft above Structure Reference True North Feet (US) II~ I '~ I, .1. I ,I Well: Current Well Properties 3-17E1K-30 Wp 9.0 Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference : Ref. Geographical Coordinates : RKB Elevation: 3-17E1K-30 Wp 9.0 Target Data Measurement Units: ft Target Coordinate Vertical Depth Northing. Eaatlng. Vertical Depth Northing. Eaatlng. Target Name Point Type wen Well Wen Mean Sea Level Global Global Shape (ft) (ft) (ft) (ft) (ft) (ft) 3-17E1K30 Hard Lines 1 Entry Point 0.00 963484.99 S 259374.19 E 0.00 5000ooo.00 N 50??oo.00 E Polygon Boundary Point A 0.00 7971.21 N 42.63 E 0.00 5978940.00 N 270530.00 E B 0.00 7980.70 N 352.49 E 0.00 5978940.00 N 270840.00 E C 0.00 7556.41 N 55.34 E 0.00 5978525.00 N 270530.00 E D 0.00 7565.90 N 365.19 E 0.00 5978525.00 N 270840.00 E 3-17E1K30 Hard Lines 2 Entry Point 0.00 963484.99 S 259374.19 E 0.00 5000ooo.00 N 500000.00 E Polygon Boundary Point A 0.00 7921.23 N 44.16 E 0.00 5978890.00 N 270530.00 E B 0.00 7930.73 N 354.02 E 0.00 5978890.00 N 270840.00 E C 0.00 7621.38 N 53.35 E 0.00 5978590.00 N 270530.00 E D 0.00 7630.87 N 363.20 E 0.00 5978590.00 N 270840.00 E 3-17E1K30 Fault 1 Entry Point 0.00 7373.53 N 199.19 W 0.00 5978350.00 N 270270.00 E Polygon Boundary Point A 0.00 7373.53 N 199.19 W 0.00 5978350.00 N 270270.00 E B 0.00 7281.71 N 788.09 E 0.00 5978228.00 N 271254.00 E C 0.00 7373.53 N 199.19 W 0.00 5978350.00 N 270270.00 E 3-17E1K30 Fault3 Entry Point 0.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E Polygon Boundary Point A 0.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E B 0.00 7497.10 N 699.45 E 0.00 5978446.00 N 271172.00 E C 0.00 7502.89 N 124.11 W 0.00 5978477.00 N 270349.00 E 3-17E1K30 T1 Entry Point 9895.00 7598.64 N 193.11E 9840.00 5978563.00 N 270669.00 E Point 3-17E1K30 T2 Entry Point 10031.00 7686.45 N 187.92 E 9976.00 5978650.92 N 270666.50 E Circle 3-17E1K30 T3 Entry Point 10193.00 7785.83 N 182.05 E 10138.00 5978750.44 N 270663.68 E Circle 3-17E1K30 Fault2 Entry Point 0.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00 E Polygon Boundary Point A 0.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00 E B 0.00 8228.64 N 804.11 E 0.00 5979174.00 N 271299.00 E C 0.00 8485.80 N 403.33 W 0.00 5979468.00 N 270100.00 E 3-17E I K-30 Wp 9.0 Proposal Data Vertical or~in : Well Horizontal ri~n: Well Measurement nits: ft North Reference : True North Dogleg severity : ~ees per 100 feet (US) Vertical Section Azimuth: 26. 0 Vertical Section Descriptlon:Well Vertical Section Origin: 0.00 N,O.OO E U.....red Incl. Azlm. Vertical Northing. Ealtlnga Vertical caa:u Depth Depth SectIon 10166.00 48.315 5.398 7861.69 5294.28 N 383.07 E 4902.59 10186.00 49.769 3.579 7874.81 5309.33 N 384.25 E 4916.57 10.000 10236.00 51.588 1.363 7906.49 5347.97 N 385.91 E 4951.84 5.000 10437.87 59.566 353.850 8020.62 5513.99 N 378.45 E 5096.83 5.000 11595.56 59.566 353.850 8607.05 6506.43 N 271.51 E 5935.59 0.000 12273.01 35.942 356.656 9059.33 7002.38 N 228.01 E 6359.20 3.500 12974.64 35.942 356.656 9627.38 7413.51 N 203.99 E 6715.77 0.000 13266.93 33.750 356.620 9867.24 7580.22 N 194.20 E 6860.33 0.750 13300.26 33.500 356.620 9895.00 7598.64 N 193.11 E 6876.31 0.750 13652.38 30.859 356.620 10193.00 778S.83 N 182.05 E 7038.60 0.750 13802.38 29.734 356.620 10322.51 7861.37 N 177.59 E 7104.09 0.750 Drill Quest 3.03.02.002 Sper y-Sun Drilling S( Jvices Proposal Data - 3-17E / K-30 Wp 9.0 Approved , "i 11I1I l I I ¡illlj I I,i i 'Ii,' "" , I I i;,11I II :,i::, Ii i Iii' Ii. i 1111'111 II'! ii,I:1 :;"I,!I I,ll Ii I I! I' II ill I ~ II I ¡ I I, ¡ , I, 10166.00 1111" Illilli : III I Ilil i! I' :'1 20.00 I !. 50.00 i 201.87 353.850 ~ 1157.69 II 'i Ii Ii ,\ : " I 1'1 ! ¡i!111 I 'I II' II I I ,: , 1 ' I' . I ,I I I ! I I" 'II I',' i I ]1,,' I' 'I ",':11 ,,' I' ,'~ 33.750 356.620 I ,I i ~', II .!; Iii II I " i, J/ 33.33 33.500 356.620 9895.00 7598.64 N 193.11 E, ¡ II, : I, ' 10193.00 IIlli ! Ii 11'~rl ¡i I, "¡I If I,l' 150.00 ,il i ! I ii, I 356.620 :11111111111111.1111111 1,,1 : I ~ ,I i i I ¡ , I i i I I :1 'I I ,,: I : " \ ,I 'I I li'l' I: ",' ,1m I in ~Amhør ~nn~. 1R-!t4. III, III ' I i I I I ' .1. 10.000 5.000 5.000 11 0.000 3.500 0.750 "I 0.750 0.7501 i I Ii, I ! 316.000 316.000 , ~ 180.000 nrillf1, 'Act Proposal Ref: pro988 ~: -~. -; -.. -'V-=UIl DRILLING SERVICES A HaIßÞurton Company Surface Coordinates: 5970973.83 N, 270243.36 E (70019' 2O.3471u N, 147051' 46.9665u W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Kelly Bushing: 55.00ft above Mean Sea Level -~' 10 December, 2002 ....~ -roposal Report Sperry-Sun Drilling Services Sperry-Sun Drilling Services Proposal Report for 3-17DIIf-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 BPXA Alaska State Plane 3 - Measured Sub-8ea Vertical Local Coordinates Global Coordinates Depth Incl. Azlm. Depth Depth Northlngs Eastings Northings Easti~·-=-=. Ra~ ~on Comment (ft) (ft) (ft) (ft) (ft) (ft) (, --- --- -- ~--- -- --- -- ~= 10166.00 48.315 5.398 7806.69 7861.69 5294.28 N 383.07 E 5976253jp N _ -A:7~788.33 ~. . 4902.59 Kop TF 44° Left Begin Dir 1 0.000°/1 00ft : 10166.00ft MD, 7861.600 TVD 10186.00 49.769 3.579 7819.81 7874.81 5309.33 N,384.25 E ~59~~4 -,89.97 E '-10.000 4916.57 Decrease Dir Rate @ 5.00001100ft: 1 0186.00ftMD,7874.81 ftTVD: 10200.00 50.274 2.947. 7828.80 7883;80 5320.04 N 3ä&6 E BllØli'9.6œPf ?ro790.91 E 5.000 4926.41 1023a-.00 51.588 1.363 7851.49 7906.49 5347.97N liS.tiE 59-,-7.48N 270792.81 E 5.000 4951.84 ~c 10300.00 54.066 358.821 7890.16 7945.16 5398.96 N ~ 585JTk. 5976~.44 N 270794.44 E 5.000 4997.42 - - - - = = ~ ~ ~ ~ - - - - >===-~ ~ -=::0= _ ~ 10400.00 58.036 355.155 7946.01 8001.01 51§1.75 N ~ ~~381 ==- 5976441.33 N 270792.55 E 5.000 5069.42 10437.87 59.566 353.850 7965.62 8020.62 III 3.99 N ~ -'78.45 E 5976473.65 N 270790.44 E 5.000 5096.83 End Dir, Start Sail @ 59.566° : 10437.87ftMD,8020.62ftTVD 10500.00 59.566 353.850 7997.1 0 8052~ 10 ~~ ~y;a7 25 N 372.71 E 5976527.06 N 270786.33 E 0.000 5141.85 10600.00 59.566 353.850 8047.75 810¥l5 ~(jÕl7 ~~ 363.47 E 5976613.03 N 270779.72 E 0.000 5214.30 10700.00 59.566 353.850 8098.41~ 815.1 ~38.1t) N 354.24 E 5976699.00 N 270773.11 E 0.000 5286.75 10800.00 59.566 353.850 .814@18f1 8204.'- ~24.43 N 345.00 E 5976784.97 N 270766.51 E 0.000 5359.20 10900.00 59.566 353.850 ~J99.71 fI 8254.7. 5910.16 N 335.76 E 5976870.94 N 270759.90 E 0.000 5431.65 11000.00 59.566 353.850. ... 50...3. 7 __ 8305.37 5995.88 N 326.53 E 5976956.90 N 270753.29 E 0.000 5504.10 11100.00 59.566 353.850 v'· 1.02 ~ 8356.02 6081.61 N 317.29 E 5977042.87 N 270746.68 E 0.000 5576.55 11200.00 59.566 (/'ti.850 d. 8 - ~68 v- 8406.68 6167.33 N 308.05 E 5977128.84 N 270740.07 E 0.000 5649.00 11300.00 59.566 ~ ~~ 8402.33 8457.33 6253.06 N 298.81 E 5977214.81 N 270733.46 E 0.000 5721.45 11400.00 59.566 53 0 8452.99 8507.99 6338.78 N 289.58 E 5977300.77 N 270726.86 E 0.000 5793.90 11500.00 59.566 0 8503.64 8558.64 6424.51 N 280.34 E 5977386.74 N 270720.25 E 0.000 5866.35 11595.56 59.566 353.850 8552.05 8607.05 6506.43 N 271.51 E 5977468.89 N 270713.93 E 0.000 5935.59 Begin Dir @ 3.5000/100ft: 1" 5 MD, 8607.05ft TVD_J 11600.00 59.411 353.863 8554.30 8609.30 6510.23 N 271.10 E 5977472.71 N 270713.64 E 3.500 5938.80 11700.00 55.920 354.165 8607.78 8662.78 6594.25 N 262.29 E 5977556.96 N 270707.40 E 3.500 6009.92 11800.00 52.431 354.494 8666.30 8721.30 6674.92 N 254.27 E 5977637.84 N 270701.86 E 3.500 6078.40 11900.00 48.942 354.854 8729.65 8784.65 6751.94 N 247.09 E 5977715.04 N 270697.03 E 3.500 6143.99 12000.00 45.454 355.255 8797.58 8852.58 6825.03 N 240.76 E 5977788.29 N 270692.94 E 3.500 6206.45 12100.00 41.968 355.707 8869.86 8924.86 6893.90 N 235.30 E 5977857.30 N 270689.60 E 3.500 6265.55 12200.00 38.484 356.225 8946.19 9001.19 6958.31 N 230.75 E 5977921.82 N 270687.02 E 3.500 6321.06 12263.94 36.258 356.600 8997.00 9052.00 6997.04 N 228.32 E 5977960.60 N 270685.78 E 3.500 6354.57 Top Tuff Marker 12273.01 35.942 356.656 9004.33 9059.33 7002.38 N 228.01 E 5977965.94 N 270685.63 E 3.500 6359.20 End Dir, Start Sail @ 35.942° : 12273.01 ftMD,9059.33ftTVD 12300.00 35.942 356.656 9026.19 9081.19 7018.19 N 227.08 E 5977981.78 N 270685.19 E 0.000 6372.91 12400.00 35.942 356.656 9107.15 9162.15 7076.79 N 223.66 E 5978040.46 N 270683.56 E 0.000 6423.74 10 December, 2002 - 18:47 Page 2 of 11 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 Page 3 of 11 10 December, 2002 -18:47 Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E I K-30 Wp 9.0 Revised: 10 December, 2002 BPXA Alaska State Plane 3 - Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azlm. Depth _ Depth Noñhlngs Eastings Northings Easti~---- Ra~ ~tion Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft: ~ -- ----- == = --- -- --- - -- - - - - --- - - ~ - - - - . 12500.00 35.942 356.656 9188.11 9243.11 7135.39 N 220.24 E 5978099jtJ N _ ~n681.93 r-.::; 0.000 6474.56 12600.00 35.942 356.656 9269.07 9324.07 7193.98 N 216.81 E 597fl1511i11~~0.31 ~ 0.000 6525.38 12700.00 35.942 356.656 9350.03 9405.03 7252.58 N 213.39 E 59ï/l&t6._N -~- 271178.68 E 0.000 6576.20 12800.00 35.942 356.656 9430.99 9485.99 7311.18 N 209.97 E . ~-=--59~'fItJ ~---¡)77.05 E 0.000 6627.02 12900.00 35.942 356.656 9511.95 9566.95 7369.77 N 206.54 E -'¡&7113",···' _0675.42 E 0.000 6677.84 --- - - - . - ~~ 12929.71 35.942 356.656 9536.00 9591.00 7387.18 N Ø5·WE 59/~,.26N 270674.94 E O.OOU- 6692.94 -Top HRZ 12974.64 35.942 356.656 9572.38 9627.38 - 7413.51 N - 203:- __. 5978377.62 N 270674.21 E 0.000 6715.77 Begin Dir @ 0.75Oo/100ft: 12974.6 MD,9627.38ftTVD 13000.00 35.752 356.653 9592.94 9647.94 7138.34 NT~- 203 ~ ~ 5978392.47 N 270673.79 E 0.750 6728.63 13100.00 35.002 356.641 9674.47 9729.47 )lB6.13N_ ;¡¡[99.73E 5978450.34 N 270672.18 E 0.750 6778.75 13200.00 34.252 356.629 9756.76 9811.76 -é._ ~2.86;Ç· ~6.40 E 5978507.14 N 270670.58 E 0.750 6827.94 ~ == --- ~ 13266.63 33.752 356.620 9812.00 986'ÍPO ~~:2¡~ 194.20 E 5978544.38 N 270669.53 E 0.750 6860.19 Base HRZ I LCU I K3A 13266.93 33.750 356.620 9812.24 9867t4 194.20 E 5978544.55 N 270669.52 E 0.750 6860.33 13300.00 33.502 356.620 ~ 9894" -.598.50 N 193.12 E 5978562.86 N 270669.00 E 0.750 6876.18 13300.26 33.500 356.620. . 9895.01. 7598.64 N 193.11 E 5978563.00 N 270669.00 E 0.750 6876.31 Target - 3-17E1K30 T1 13308.65 33.437 356.620 ~.oo ¡¡¡; 9902.08' 7603.26 N 192.83 E 5978567.63 N 270668.87 E 0.750 6880.31 K2B 13400.00 32.752 356.620 'i" . I .53 \. 9978.5~ 7653.05 N 189.89 E 5978617.48 N 270667.45 E 0.750 6923.48 13423.13 32.578 "'.620 ~_ 9 ~OO r 9998.00 7665.52 N 189.16 E 5978629.96 N 270667.10 E 0.750 6934.29 K2M 13462.23 32.285 . _.62~ 9971bo 10031.00 7686.45 N 187.92 E 5978650.92 N 270666.50 E 0.750 6952.44 Top K2A I S2A3 Target - 3-17E1K3O T2, 150.00 Radi 13500.00 32.002 ag 10007.98 10062.98 7706.51 N 186.74 E 5978671.01 N 270665.93 E 0.750 6969.83 13545.92 31.658 10047.00 10102.00 7730.69 N 185.31 E 5978695.22 N 270665.25 E 0.750 6990.79 S2A2 Shale 13576.43 31 .429 356.620 10073.00 10128.00 7746.62 N 184.37 E 5978711.17 N 270664.79 E 0.750 7004.60 S2A1 "-' 13600.00 31.252 356.620 10093.13 10148.13 7758.86 N 183.64 E 5978723.43 N 270664.45 E 0.750 7015.21 13652.38 30.859 356.620 10138.00 10193.00 7785.83 N 182.05 E 5978750.44 N 270663.68 E 0.750 7038.60 K1 Target - 3-17E1K3O T3, 150.00 Radi 13700.00 30.502 356.620 10178.96 10233.96 7810.09 N 180.62 E 5978774.73 N 270662.99 E 0.750 7059.63 13800.00 29.752 356.620 10265.45 10320.45 7860.19 N 177.66 E 5978824.90 N 270661.57 E 0.750 7103.07 13802.38 29.734 356.620 10267.51 10322.51 7861.37 N 177.59 E 5978826.08 N 270661.53 E 0.750 7104.09 Total Depth : 13802.38ftMD,10322.51ftTVD 4 1128 Uner Alaska State Plane 3 Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 BPXA All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 26.680° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13802.38ft., The Bottom Hole Displacement is 7863.37ft., in the Direction of 1.294° (True). Comments Measured Depth (ft) 10166.00 10186.00 10437.87 11595.56 12273.01 12974.64 13802.38 '~" Station Coordinates TVD Northlngs ngs (ft) (ft) ) 10 December. 2002 - 18:47 3.07E ~.25E 318.45 E 271.51 E 228.01 E Kop TF 44° Left Begin Dir 10.000°/1000: 10166.000 MD, 7861.69ftTVD Decrease Dir Rate @ 5.000°/1000: 10186.ooftMD,7874.81ftTVD End Dir, Start Sail @ 59.566° : 10437.87ftMD,8020.62ftTVD Begin Dir @ 3.500°/1000: 11595.56ft MD, 8607.05ft TVD End Dir, Start Sail @ 35.942°: 12273.01ftMD,9059.33ftTVD Begin Dir @ 0.750°/1000: 12974.64ft MD, 9627.38ft TVD Total Depth: 13802.38ftMD,10322.51ftTVD 203.99 E 177.59 E '~ Page 4 of 11 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 '--- ~I BPXA 189.16 E K2M 187.92 E TopK2A/S2A3 185.31 E S2A2 Shale 184.37 E S2A 1 182.05 E K1 Top Tuff Marker Top HRZ Base HRZ I LCU I K3A Possible P3 Coals K2B ame ~ PageS of 11 4 1/2" Liner Casing Detail 8997.00 9536.00 9812.00 9812.00 9847 Penetration Point Sub-Sea Depth (ft) Northlngs (ft) Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E I K-30 Wp 9.0 Revised: 10December 2002 10 December, 2002 - 18:47 <Surface> <Surface> <Run-TO> <Run-TO> To Measured Vertical Depth Depth (ft) (ft) From Measured Ve Depth (ft) Casing details Formatl on Plane Profile (Below Well Origin) Measured Vertical Sub-Sea Dip Up-Dip Depth Depth (ft) Angle Dlrn. (ft) (ft) 8997.00 0.000 358.246 12263.94 9052.00 9536.00 0.000 358.246 12929.71 9591.00 9812.00 0.000 358.246 13266.63 9867.00 9812.00 0.000 358.246 13266.63 9867.00 9847.00 0.000 358.246 13308.65 9902.00 9943.00 0.000 358.246 9976.00 0.000 358.246 10047.00 0.000 358.246 10073.00 0.000 358.246 10138.00 0.000 358.246 Formation TODS Alaska State Plane 3 DrillQuest 3.03.02.002 '-- Polygon '-- Target Target Shape Type Polygon BPXA inates Eastings (ft) 259374.19 E 50??oo.00 E 146000' 00.0000" W 55.00 7921.23 N 44.16 E 55.00 7930.73 N 354.02 E 55.00 7621.38 N 53.35 E 55.00 7630.87 N 363.20 E 0.00 5978890.00 N 270530.00 E 0.00 5978890.00 N 270840.00 E 0.00 5978590.00 N 270530.00 E 0.00 5978590.00 N 270840.00 E 70020' 38.2548" N 147051'45.6767" W 70020' 38.348111 N 147051'36.623711 W 70020' 35.305611 N 147051'45.408411 W 70020'35.398911 N 147051'36.355811 W 55.00 963484.99 S 259374.19 E 0.00 5000000.00 N 500000.00 E 67040'43.068411 N 146000' 00.??oo11 W 55.00 7971.21 N 42.63 E 55.00 7980.70 N 352.49 E 55.00 7556.41 N 55.34 E 55.00 7565.90 N 365.19 E 0.00 5978940.00 N 270530.00 E 0.00 5978940.00 N 270840.00 E 0.00 5978525.00 N 270530.00 E 0.00 5978525.00 N 270840.00 E Page 6 of 11 Mean Sea leveVGlobal Coordinates #1 #2 #3 #4 Target Boundary Point #1 #2 #3 #4 Mean Sea leveVGloba1 Coordinates: Geographical Coordinates: Geographical Coordinates #1 #2 #3 #4 IobaI Coordinates #1 #2 #3 #4 Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 10 December, 2002 - 18:47 3-17E1K30 Hard Lines 2 Target Name Taraets associated with this well oath Alaska State Plane 3 Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 BPXA Targets associated with this wellpath (ContInued) Alaska State Plane 3 Geographical Coordinates #1 700 20' 38.7 7ðfØ1'45.7214u W #2 700 .8397 470 51' 36.6684u W #3 .6666 1470 51'45.3503u W #4 75998 N 1470 51'36.2977u W 3-17E1K30 Fault 1 199.19W Polygon 270270.00 E 147051' 52.7860· W 55.00 7373.53 N 199.19 W 55.00 7281.71 N 788.09 E 55.00 7373.53 N 199.19 W M 0.00 5978350.00 N 270270.00 E 0.00 5978228.00 N 271254.00 E 0.00 5978350.00 N 270270.00 E Geographical Coordinates #1 700 20' 32.8680· N 147051' 52.7860a W #2 70020' 31.9645· N 147051'23.9435" W #3 700 20' 32.8680· N 147051' 52.7860" W 55.00 7502.89 N 124.11 W Polygon Mean Sea LeveVGloba1 Coordinates: 0.00 5978477.00 N 270349.00 E Geographical Coordinates: 70020'34.1403. N 147051'50.5928" W Target Boundary Point #1 55.00 7502.89 N 124.11 W #2 55.00 7497.10 N 699.45 E #3 55.00 7502.89 N 124.11 W Mean Sea LeveVGIobaI Coordinates #1 0.00 5978477.00 N 270349.00 E #2 0.00 5978446.00 N 271172.00 E #3 0.00 5978477.00 N 270349.00 E Geographical Coordinates #1 700 20' 34.1403" N 147051' 50.5928" W #2 700 20' 34.08308 N 147051' 26.53238 W #3 70020' 34.14038 N 147051' 50.59288 W '-" ~ 10 December, 2002 -18:47 Page 70f11 DrillQuest 3.03.02.002 Point #1 10031.00 7768.98 N 192.66 E #2 10031.00 7756.46 N 225.57 E #3 10031.00 7730.35 N 245.40 E #4 10031.00 7703.15 N 254.54 E #5 10031.00 7676.33 N 256.77 E #6 10031.00 7648.38 N 252.48 E #7 10031.00 7618.87 N 238.97 E #8 10031.00 7595.23 N 211.16E #9 10031.00 7595.30 N 174.17 E #10 10031.00 7619.02 N 146.46 E #11 10031.00 7648.43 N 132.92 E #12 10031.00 7676.33 N 128.55 E #13 10031.00 7703.18 N 130.69 E #14 10031.00 7730.42 N 139.83 E #15 10031.00 7756.64 N 159.66 E ---- Mean Sea LeveVGlobal Coordinates #1 9976.00 5978733.27 N 270673.77 E #2 9976.00 5978719.75 N 270706.28 E #3 9976.00 5978693.04 N 270725.30 E #4 9976.00 5978665.58 N 270733.60 E #5 9976.00 5978638.70 N 270735.01 E #6 9976.00 5978610.90 N 270729.87 E #7 9976.00 5978581.81 N 270715.46 E #8 9976.00 5978559.04 N 270686.94 E #9 9976.00 5978560.24 N 270649.97 E #10 9976.00 5978584.80 N 270623.00 E #11 9976.00 5978614.61 N 270610.37 E #12 9976.00 5978642.63 N 270606.85 E #13 9976.00 5978669.40 N 270609.81 E #14 9976.00 5978696.35 N 270619.78 E #15 9976.00 5978721.95 N 270640.41 E 10 December, 2002 - 18:47 Page 8 of 11 DrillQuest 3.03.02.002 Polygon 7686.45 N 187.92 E 5978650.92 N 270666.50 E 70020' 35.9456" N 147051' 41.4768" W '-" 193.11 E 270669.00 E 1470 51'41.3252D W Mean Sea LeveVGlobal Coordinates: Geographical Cf\Q._~tes: Point Target Target Shape Type I...t e s Eastlngs (It) BPXA Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E I K-30 Wp 9.0 Revised: 10 December, 2002 3-17E1K-30 T2 Drillers @ 95 % 3-17E1K30 T1 Target Name Targets associated with this wellpath (Continued) AlaslaJ State Plane 3 Alaska State Plane 3 Targets associated with this wellpath (Continued) 3-17E1K30 T2 10 December, 2002 - 18:47 Sperry-Sun Drilling Services Proposal Report for 3-17DIM-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 Geographical Coordinates #1 #2 #3 #4 #5 #6 #7 #8 BPXA 70° 20' 36.7 7CW1'41.33810 W 70° , 6.634 47° 51' 40.37660 W .3774 147° 51'39.79730 W 10990 N 147° 51'39.53040 W .8461" N 147° 51'39.4652· W 5.57130 N 147° 51'39.59050 W 5.2809" N 147° 51'39.9853· W 70° 20' 35.0485" N 147° 51'40.7978· W 70° 20' 35.0492" N 147051'41.8784. W 70° 20' 35.2825" N 147051'42.6880. W 700 20' 35.5718" N 147051'43.08348 W 70° 20' 35.8462" N 147° 51'43.2113° W 70° 20' 36.1102" N 147051'43.1488° W 70° 20' 36.3782" N 147° 51'42.8817" W 70° 20' 36.6360° N 147051'42.3022. W 10031.00 7686.45 N 187.92 E Circle 9976.00 5978650.92 N 270666.50 E 70° 20' 35.9456" N 147° 51' 41.4768° W 150.000 10193.00 7785.83 N 182.05 E Polygon 10138.00 5978750.44 N 270663.68 E 700 20' 36.9231" N 147° 51'41.64818 W 10193.00 7852.18 N 187.88 E 10193.00 7839.34 N 220.52 E 10193.00 7813.11 N 239.80 E 10193.00 7786.32 N 248.72 E 10193.00 7759.97 N 250.84 E 10193.00 7732.45 N 246.74 E 10193.00 7703.01 N 233.73 E 10193.00 7679.00 N 206.32 E 10193.00 7679.19 N 169.48 E 10193.00 7703.33 N 142.26 E 10193.00 7732.51 N 129.12 E 10193.00 7759.97 N 124.99 E 10193.00 7786.35 N 126.98 E 10193.00 7813.34 N 135.71 E 10193.00 7839.60 N 155.12 E Mean Sea LeveVGIobaJ Coordinates: Geographical Coordinates: Target Radius: Mean Sea LeveVG1oba1 Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 #14 #15 Page 9 of 11 ""~ ~" DrillQuest 3.03.02.002 Mean Sea LeveVGloba1 Coordinates #1 10138.00 597881 b._~' ~ ~ 270671.54 E #2 10138.~ ~8802.7"'~1-~ 270703.77 E #3 10138.0& ~ò~775.94~ 270722.24 E - - -- ::~-~==~~ =:~:::~ 270730.33 E 270731.64 E #6 ~01ll8.- -= "78695.10 N 270726.70 E #7 ~.OO ~ - 51'78666.07 N 270712.80 E #8 1 v~OO 5978642.91 N 270684.67 E 1 01 ~.oo 5978644.23 N 270647.85 E 10138.00 5978669.19 N 270621.38 E 10138.00 5978698.76 N 270609.14 E 10138.00 5978726.34 N 270605.85 E 10138.00 5978752.64 N 270608.65 E 10138.00 5978779.35 N 270618.20 E 10138.00 5978805.01 N 270638.41 E . -eographical Coordinates #1 70020' 37.5757· N 1470 51'41.4777N W #2 70020' 37.4493· N 147051' 40.52418 W #3 70020' 37.1914· N 147051'39.96088 W #4 70020'36.92798 N 1470 51'39.7004N W #5 70020'36.6687. N 147051'39.6385. W #6 70020' 36.3980N N 147051'39.75838 W #7 700 20'36.1085N N 1470 51'40.1383N W #8 70020'35.87238 N 147051'40.93908 W #9 70020' 35.8742" N 147051' 42.01548 W #10 70020' 36.11168 N 147051'42.8107" W #11 70020' 36.39868 N 1470 51' 43.1946" W #12 70020' 36.6688" N 147051'43.31538 W #13 70020'36.92828 N 147051'43.25718 W #14 70020' 37.19368 N 1470 51'43.oo21N W #15 70020' 37.45208 N 147051' 42.4348" W 3-17E1K30 T3 10193.00 7785.83 N 182.05 E Circle Mean Sea LeveVGIobaI Coordinates: 10138.00 5978750.44 N 270663.68 E Geographical Coordinates: 70020' 36.9231 n N 147051' 41.6481" W Target Radius: 150.000 DrillQuest 3.03.02.002 Page 100t11 .--.....,,/ ""- BPXA Sperry-Sun Drilling Services Proposal Report tor 3-17DIM-31 Recca . 3-17E I K-30 Wp 9.0 Revised: 10 December, 2002 10 December, 2002 -18:47 Targets associated with this wellpath (Continued) Alaska Slate Plane 3 Alaska State Plane 3 Targets associated with this wellpath (Continued) Target Name 3-17E/K30 Fault2 10 December, 2002 -18:47 Sperry-Sun Drilling Services Proposal Report for 3-17D/M-31 Recca - 3-17E / K-30 Wp 9.0 Revised: 10 December, 2002 Mean Sea LeveVGlobal Coordinates: Geographical C . tes: 8485.80 N 8228.64 N 8485.80 N M 0.00 0.00 0.00 5979468.00 N 5979174.00 N 5979468.00 N I rRIPt e s Eastlngs (ft) 403.33 W 270100.00 E 147051' 58.7519" W 403.33 W 804.11 E 403.33 W 270100.00 E 271299.00 E 270100.00 E 70020'43.8074" N 147051' 58.7519" W 70020'41.2779" N 147051' 23.4727" W 70020'43.8074" N 1470 51'58.7519u W Page 11 of 11 BPXA Target Target Shape Type Polygon .~ ~ DrillQuest 3.03.02.002 WELU'Am DErAILS Pm 3-17FJK-3O ""'"'¥:~~ io\~-31 Rig: Ref. Datum: 20: 171CY4II99909:S5 55.00f V.SeeIi>D Origil Origil SIriIg AnP: +W-S +F1-W From TVD y,.(Ø O.C; 0.00 0.00 lBiEND - '·""\11. .-' I u'<lVL·29). Major Risk - LI.....:i!A' u~ .28A), Major Risk = ::~~w;:~~~/11~lr~":iR~ - . .7/i w.I\ I-L .7,. W>A). NOBt.RORS - L I i'BIU III L. I iBIM-31). NOBm.ORS - "'C/IIoI 'I" PLIM-31), NOERRORS ~ . ,1CJ-I<"qfL/PBI),NOERRORS ~ L' r¡XM ".. 17[~-31), NOFRRORS - L?IILt"'L·III.!33),MajorRisk == ~~1 :::::'~~~;1I~~ORS - L :-..,1 .......... . :">AIK3O), NOERRORS L I"j¡. I'-I L 11'l\, 12). Major Risk - PIil!LI'7L1Þ.. III - 1.171..... u''''P'''' Tool MWD SURVEY PROORAM Depth To S1II'\-.y1Plan 13802.60 PIæmod: 3-17FJK-3O v.p09 V16 Deplh Fm 10166.00 COMPANY DErAILS BP Amxo CakulaOOn MeIbod: Mmœm C1II'\1I!ure Emu S}..tem: ISCWSA Scan MeIbod: Tm' Cyli>:Ier North Fnor SIIIfæe: ~ + Casilg W3IIÜJg MeIbxI: Rules Based ANTI-COLUSION SETIINGS Interpolation Method:MD Interval: 50.00 Deptb Range From: 10166.00 To: 13802.60 Maximum Range: 1576.21 Reference: Plan: 3-17FJK-30 wp09 Slot NlA Longìude 147"sr46.966W lJüude 7(),19'20.347N WElL IJIoT AILS NonJmg Easœg 5970973.83 270'..43.36 +1!1-W -2037.70 +NI-S 1590.34 lIDO 17IYM- l _ Plan: 3-17FJK-3O v.p09 (3-11Mf-31JP1an 3',_j) CreaICd By: IIGoff Dole: 121lCY2002 Checked: Dole: R~: Dole: "PPro..-.d: Dole: ~_J ToMD 10166 10250 10500 10750 11000 11250 11500 11750 12000 12250 Colour -90 ToMD 10166 10250 10500 10750 11 000 11250 11500 11750 12000 12250 18Ò"'U From 10166 10166 10250 10500 10750 11 000 11250 11500 II 750 12000 9("'""" œ7Q -20.0 -15.0 -10.0 -10.0 -15.0 -20.0 --5.0 --5.0 ColoUI' o 100 From 10166 10166 10250 10500 10750 11 000 11250 11500 11750 12000 27() -100 ---6() -go -100 -so -40 -20 ---6() --20 -40 -0 vSee Target 4902.64 4916.62 4951.89 5096.88 5935.63 6359.25 6715.82 6860.38 6876.35 1038.65 71M.23 Dùg 11'ace 0.000 0.00 10.003 316.03 4.999 315.99 5.000 319.91 0.000 0.00 3.500 175.90 0.000 0.00 0.750 180.52 0.750 180.00 0.750 180.00 0.750 180.00 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [l5ft/in] SECTION DErAIL'> 1VD +NI-S +FJ-W 7861.64 5294.31 383.13 1814.75 5309.36 384.31 7906.43 5348.00 385.96 8020.57 5514.02 318.50 8606.99 6S06.45 271.56 9059.28 7002.41 228.06 9621.33 7413.54 2Of.03 9861.19 7580.25 194.24 9894.95 7598.67 193.15 10192.95 7785.86 182.10 10322.65 7861.51 177.63 Azi 5.40 3.58 1.36 353.85 353.85 356.66 356.66 356.62 356.62 356.62 356.62 ¡.., 48.31 49.77 51.59 59.57 59.57 35.94 35.94 33.75 33.50 30.86 "B.73 MD 10166.00 10186.00 10236.00 10431.81 11595.56 12213.01 12914.64 13266.93 13300.26 13652.38 13802.60 See ~ 3 4 5 6 7 8 9 10 11 - [deg] vs Centre to Centre Separation [40ft/in] Travelling Cylinder Azimuth (TFO+AZI) - ) Sperry-SUD Anticollision Report , 1~\ J GLOBAL SCAN APPLŒD: All wellpaths within 200'+ 100/1_ of reference - There are'Dilll:..us in tbis fRliI1cipaJ Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 10166.00 to 13802.60 ft Scan Metbod: Trav Cylinder North Maximum Radius: 1576.21 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpatb Date: 05131/2002 Validated: No Planned From To Survey ft ft 40.50 10166.00 2 : Gyrodata cont.drillpipe mI 10166.00 13802.60 Planned: 3-17E1K-30 wp09 V16 Version: Toolcode GVO-CT-DMS MWD Casing Points Tool Name Gyrodata cont.drillpipe mIs MWD - Standard 13801.05 10321.30 4.500 8.500 41/2" Summary End SDI 3-07 AIL-29 3-07A1L-29 V5 13502.44 14994.00 1325.87 356.45 980.10 Pass: Major Risk End SDI 3-09/L-28A 3-09/L-28A V2 12603.93 13950.00 901.63 307.13 743.04 Pass: Major Risk End SDI 3-11/M-30 3-11/M-30 V1 10228.31 10450.00 1070.39 262.06 819.86 Pass: Major Risk End SDI 3-17/J-3O 3-17/J-30 V9 10200.04 10200.00 0.75 0.00 0.75 Pass: NOERRORS End SDI 3-17/J-3OA 3-17/J-30A V3 10200.04 10200.00 0.75 0.00 0.75 Pass: NOERRORS End SDI 3-17B1M-31 3-17B/M-31 V6 10200.04 10200.00 0.75 0.00 0.75 Pass: NOERRORS End SDI 3-17C/M-31 3-17C/M-31 V3 Plan: Un 10200.04 10200.00 0.75 0.00 0.75 Pass: NOERRORS End SDI 3-17CIPB 1 3-17C/PB1 V3 10200.04 10200.00 0.75 0.00 0.75 Pass: NOERRORS End SDI 3-17D/M-31 3-17D/M-31 V13 10199.97 10200.00 0.92 0.00 0.92 Pass: NOERRORS End SDI 3-27/M-33 3-27/M-33 V1 10166.00 10400.00 1427.91 244.98 1265.88 Pass: Major Risk End SDI 3-29/J-32 3-29/J-32 V1 10166.00 10450.00 1139.05 261.48 922.47 Pass: Major Risk End SDI 3-29/J-32 Plan 3-29a1J-30 VO 10166.00 10450.00 1139.05 0.00 1139.05 Pass: NOERRORS End SDI 3-29/J-32 Plan 3-29A/K30 V1 Plan 13690.26 14150.00 83.46 0.00 83.46 Pass: NOERRORS End SDI 3-31/K-32 3-31/K-32 V6 10166.00 9750.00 1089.20 358.71 768.55 Pass: Major Risk Site: End SDI Well: 3-07A/L-29 Rule Assigned: Wellpatb: 3-07A/L-29 V5 Inter-8ite Error: ',',".'··,:I·..,Ret1,·....·.'.','.,,.1" ...,'.1,','.,",',':,.',',.':'.',-.',.':,',.,',',',."'. :, " "1,".".':"::., ,',., ',." AIII'....t I I ',:,~I:;M'''I,' "'~Ii'AQ~I:",J, 1.I"'·.,.~:1 ',':' "'11,,::,1'11,"" ',",\": ,"':<:"".'.' .,.;", i·.:';,I':~i::!'1 '~~~",:,',:~;Gt)"" ','"::;",, ::or 'r'-:~"!,,,: 1~&;I:~~I~,m .I~.~r~"", .I~,,'II.., 1',1' .,.,,,,,,",,.,,,,'0,1,,,.',-, ",1,1.. "", " I",.I.,I...,I~~;I""""'I"· .I",·:~:l~~~ll" "':1 Mr>I,"',',"'~"TVD '.' MP I , I"I,'I.'~ ,'::.Ref,IJi"I::~t':TfØf~~~BS,"~',:,:I:,,~-:e""~,'::,' ,'ft.'I"" ,,'I, I 1ft I ,I ",ft "I!i"'I"(.I:;"I,::I:",!I~'I,:"I':,':!'h::,').II,1"1,1,,I',~,':",;1,1~:':I:I,:,'lih':,l,:'i,I':I,'::,',)\~':!:"",',"',,'~: :1:, 13386.89 9967.45 14750.00 10090.78 49.76 54.39 258.14 261.52 1542.26 352.00 13413.67 9989.97 14800.00 10109.65 49.87 54.43 258.11 261.49 1499.59 352.77 13436.99 10009.63 14850.00 10125.35 49.97 54.47 258.10 261.48 1455.02 353.40 13459.60 10028.73 14900.00 10140.29 50.06 54.52 258.11 261.49 1410.11 354.03 13482.34 10047.96 14950.00 10155.35 50.15 54.56 258.12 261.50 1365.28 354.66 13502.44 10065.00 14994.00 10168.93 50.23 54.63 258.11 261.49 Site: End SDI Well: 3-09/L-28A Wellpath: 3-09/L-28A V2 Reference MD TVD ft ft 11008.00 8309.37 11038.45 8324.79 11068.66 8340.09 11098.86 8355.39 11129.12 8370.72 Offset MD TVD ft ft 11950.00 8796.42 12000.00 8823.48 12050.00 8850.47 12100.00 8877.15 12150.00 8903.31 Semi-MaJor Asis Ref Offset· TFO+AZI .TFO-BS CasiDg ft ft deg deg In' 38.75 39.21 242.64 248.79 4.750 38.87 39.32 241.66 247.81 4.750 38.99 39.43 240.64 246.79 4.750 39.11 39.53 239.59 245.74 4.750 39.24 39.64 238.52 244.67 4.750 1325.87 356.45 Rule Assigned: Inter-8ite Error: Ctr-Ctr ·No-Go DIstaDee Area ft ft 1561.07 267.40 1531.42 268.11 1502.08 268.81 1472.97 269.51 1443.96 270.49 Major Risk 0.00 ft r.¡c:!::'~~~i...· 1191.34 Pass 1148.00 Pass 1102.90 Pass 1057.47 Pass 1012.10 Pass 980.10 Pass Major Risk 0.00 ft Allowable Deviation WamiDg ft 1305.34 Pass 1276.25 Pass 1247.60 Pass 1219.29 Pass 1190.92 Pass 11159.51 8386.11 12200.00 8928.75 39.38 39.76 237.44 243.59 4.750 1414.89 271.24 1162.79 Pass ) Sperry-SUD Anticollision Report J Site: End SDI Well: 3-09/L-28A Wellpath: 3-09/L-28A V2 Rule Assigned: Major Risk Inter..site Error: 0.00 ft 11189.70 8401.40 12250.00 8953.76 39.51 39.87 236.32 242.47 4.750 1385.92 272.00 1134.91 Pass 11219.38 8416.44 12300.00 8978.63 39.65 39.98 235.14 241.29 4.750 1357.27 273.00 1107.29 Pass 11249.03 8431.46 12350.00 9003.52 39.79 40.09 233.91 240.06 4.750 1329.22 273.78 1080.66 Pass 11279.07 8446.67 12400.00 9028.58 39.94 40.21 232.63 238.78 4.750 1302.05 274.56 1055.05 Pass 11309.48 8462.08 12450.00 9053.96 40.09 40.32 231.30 237.45 4.750 1275.92 275.60 1030.46 Pass 11340.24 8477.66 12500.00 9079.79 40.25 40.44 229.92 236.07 4.750 1251.00 276.45 1007.47 Pass 11371.16 8493.32 12550.00 9106.03 40.41 40.56 228.47 234.62 4.750 1227.27 277.29 985.88 Pass 11402.07 8508.98 12600.00 9132.64 40.58 40.67 226.95 233.10 4.750 1204.73 278.37 965.54 Pass 11432.91 8524.60 12650.00 9159.57 40.75 40.79 225.36 231.51 4.750 1183.39 279.25 946.85 Pass 11463.57 8540.13 12700.00 9186.79 40.92 40.90 223.70 229.85 4.750 1163.27 280.12 929.65 Pass 11494.12 8555.61 12750.00 9214.21 41.10 41.02 221.98 228.13 4.750 1144.39 280.98 913.97 Pass 11524.60 8571.05 12800.00 9241.76 41.28 41.13 220.19 226.34 4.750 1126.71 282.09 899.60 Pass 11555.09 8586.49 12850.00 9269.57 41.46 41.25 218.34 224.49 4.750 1110.47 282.97 887.08 Pass 11585.66 8601.97 12900.00 9297.76 41.64 41.36 216.43 222.58 4.750 1095.86 283.87 876.47 Pass 11634.04 8626.87 12950.00 9325.84 41.87 41.47 214.52 220.56 4.750 1082.22 285.12 867.13 Pass 11691.88 8658.19 13000.00 9353.35 42.11 41.59 212.62 218.48 4.750 1068.52 286.20 858.19 Pass 11751.64 8692.33 13050.00 9380.51 42.36 41.71 210.70 216.37 4.750 1054.90 287.55 849.34 Pass 11814.12 8729.90 13100.00 9407.53 42.63 41.83 208.81 214.27 4.750 1041.42 288.93 840.71 Pass 11878.64 8770.67 13150.00 9434.63 42.92 41.95 206.91 212.13 4.750 1028.29 290.17 832.67 Pass 11944.65 8814.37 13200.00 9462.01 43.21 42.07 204.99 209.96 4.750 1015.77 291.62 825.28 Pass 12012.40 8861.26 13250.00 9489.39 43.50 42.20 203.06 207.75 4.750 1003.41 293.07 818.13 Pass 12081.93 8911.43 13300.00 9516.54 43.80 42.33 201.15 205.52 4.750 990.69 294.42 810.21 Pass 12152.31 8964.24 13350.00 9543.38 44.10 42.46 199.22 203.25 4.750 977.65 295.90 801.85 Pass 12222.70 9019.01 13400.00 9569.87 44.38 42.60 197.25 200.90 4.750 964.38 297.33 793.25 Pass 12282.34 9066.83 13450.00 9596.09 44.62 42.73 195.22 198.56 4.750 951.16 298.53 784.54 Pass 12314.98 9093.26 13500.00 9622.12 44.76 42.86 193.04 196.38 4.750 939.14 299.43 776.46 Pass 12347.10 9119.26 13550.00 9648.00 44.91 42.98 190.77 194.12 4.750 928.86 300.23 769.82 Pass 12378.64 9144.80 13600.00 9673.77 45.06 43.10 188.43 191.77 4.750 920.55 301.02 764.61 Pass 12410.37 9170.49 13650.00 9699.59 45.21 43.22 186.05 189.39 4.750 913.67 301.91 760.19 Pass 12442.96 9196.88 13700.00 9725.60 45.37 43.35 183.70 187.04 4.750 907.62 302.75 755.62 Pass 12475.74 9223.41 13750.00 9751.69 45.53 43.48 181.32 184.67 4.750 903.02 303.60 751.65 Pass 12508.09 9249.60 13800.00 9777.76 45.68 43.61 178.91 182.25 4.750 900.51 304.52 748.84 Pass 12540.14 9275.55 13850.00 9803.58 45.84 43.75 176.46 179.81 4.750 899.59 305.36 746.58 Pass 12572.03 9301.37 13900.00 9828.92 46.00 43.88 174.01 177.36 4.750 899.73 306.19 744.39 Pass 12603.93 9327.19 13950.00 9854.33 46.16 44.01 171.56 174.91 4.750 901.63 307.13 743.04 Pass 12635.98 9353.14 14000.00 9880.32 46.32 44.15 169.15 172.49 4.750 905.91 307.97 . 743.25 Pass 12668.21 9379.24 14050.00 9906.66 46.48 44.28 166.77 170.11 4.750 912.11 308.82 744.77 Pass 12700.65 9405.50 14100.00 9933.18 46.65 44.41 164.44 167.78 4.750 919.83 309.76 747.26 Pass 12733.20 9431.85 14150.00 9959.91 46.81 44.54 162.16 165.50 4.750 929.22 310.61 751.05 Pæs 12765.78 9458.23 14200.00 9986.90 46.98 44.68 159.94 16328 4.750 940.43 311.51 756.38 Pass 12798.63 9484.83 14250.00 10014.21 47.15 44.81 157.79 161.13 4.750 953.10 312.45 763.05 Pass 12831.98 9511.83 14300.00 10041.91 47.33 44.95 155.72 159.07 4.750 966.89 313.52 770.78 Pass 12865.70 9539.13 14350.00 10070.21 47.51 45.08 153.75 157.09 4.750 982.24 314.48 780.15 Pass 12899.65 9566.62 14400.00 10099.30 47.69 45.22 151.88 155.22 4.750 999.54 315.44 791.61 Pass 12933.87 9594.32 14450.00 10128.94 47.87 45.35 150.10 153.44 4.750 1018.24 316.48 804.65 Pass 12968.39 9622.26 14500.00 10158.88 48.06 45.49 148.41 151.75 4.750 1037.84 317.45 818.76 Pass 13006.89 9653.48 14550.00 10188.97 48.24 45.63 146.78 150.13 4.750 1058.25 318.56 833.96 Pæs 13046.28 9685.52 14600.00 10219.06 48.39 45.78 145.21 148.57 4.750 1079.33 319.49 849.96 Pæs 13085.70 9717.71 14650.00 10249.15 48.55 45.92 143.70 147.06 4.750 1101.03 320.42 866.73 Pass 13124.36 9749.40 14699.00 10278.64 48.70 46.07 142.27 145.64 4.750 1122.87 321.43 883.86 Pass ) 1,1 Sperry-SUD Anticollision Report ) - ~ Site: End SDJ Well: 3-11/M-3Q Wellpath: 3-11/M-3O V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 10228.31 7901.64 10450.00 8241.05 37.57 38.63 247.73 246.03 1070.39 262.06 819.86 Pass 10295.45 7942.43 10500.00 8276.98 37.51 39.01 246.35 247.36 1075.57 263.38 824.40 Pass 10361.29 7980.02 10550.00 8312.89 37.42 39.35 244.86 248.32 1080.84 264.29 829.14 Pass 10425.97 8014.50 10600.00 8348.69 37.33 39.69 243.22 248.97 1085.39 265.20 833.28 Pass 10477.12 8040.45 10650.00 8384.43 37.36 40.01 242.37 248.52 1089.38 266.16 836.87 Pass 10525.42 8064.92 10700.00 8420.03 37.44 40.32 241.72 247.87 1093.34 267.08 840.28 Pass 10573.71 8089.38 10750.00 8455.64 37.52 40.62 241.08 247.23 1097.37 268.25 843.89 Pass 10622.01 8113.85 10800.00 8491.20 37.61 40.94 240.44 246.59 1101.44 269.25 847.28 Pass 10670.33 8138.32 10850.00 8526.73 37.72 41.26 239.80 245.95 1105.55 270.52 850.91 Pass 10718.62 8162.78 10900.00 8562.31 37.83 41.56 239.17 245.32 1109.77 271.53 854.50 Pass 10766.90 8187.24 10950.00 8597.94 37.96 41.87 238.54 244.69 1114.09 272.84 858.36 Pass 10815.13 8211.67 11000.00 8633.65 38.09 42.18 237.90 244.05 1118.44 274.00 862.04 Pass 10863.30 8236.07 11050.00 8669.56 38.24 42.45 237.26 243.41 1123.20 275.28 866.44 Pass 10911.36 8260.41 11100.00 8705.80 38.40 42.71 236.63 242.78 1129.25 276.75 871.98 Pass 10959.35 8284.72 11150.00 8742.17 38.57 42.97 236.03 242.18 1136.69 278.05 879.05 Pass 11007.43 8309.08 11200.00 8778.27 38.74 43.26 235.46 241.61 1144.54 279.66 886.22 Pass 11055.69 8333.52 11250.00 8813.92 38.94 43.57 234.93 241.08 1152.04 281.18 893.08 Pass 11104.12 8358.05 11300.00 8849.12 39.13 43.89 234.42 240.57 1159.11 282.96 899.27 Pass 11152.68 8382.65 11350.00 8883.93 39.35 44.21 233.94 240.09 1165.90 284.57 905.30 Pass 11201.35 8407.31 11400.00 8918.42 39.56 44.54 233.48 239.63 1172.42 286.44 910.83 Pass 11250.11 8432.00 11450.00 8952.67 39.80 44.87 233.03 239.18 1178.69 288.15 916.24 Pass 11298.86 8456.70 11500.00 8986.93 40.04 45.19 232.58 238.73 1184.90 289.84 921.65 Pass 11347.56 8481.37 11550.00 9021.34 40.29 45.50 232.13 238.28 1191.23 291.75 927.02 Pass 11396.25 8506.03 11600.00 9055.79 40.55 45.81 231.68 237.83 1197.66 293.45 932.69 Pass 11444.93 8530.69 11650.00 9090.31 40.82 46.12 231.24 237.39 1204.20 295.44 938.24 Pass 11493.59 8555.34 11700.00 9124.84 41.09 46.44 230.79 236.94 1210.79 297.21 944.03 Pass 11542.26 8579.99 11750.00 9159.37 41.38 46.76 230.35 236.50 1217.44 299.26 949.66 Pass 11590.91 8604.64 11800.00 9193.95 41.67 47.09 229.91 236.06 1224.10 301.13 955.47 Pass 11666.42 8644.19 11850.00 9228.47 42.00 47.42 229.61 235.55 1230.23 303.37 960.73 Pass 11746.17 8689.13 11900.00 9262.83 42.34 47.74 229.43 235.12 1235.10 305.58 964.66 Pass 11827.01 8737.89 11950.00 9296.98 42.69 48.06 229.36 234.77 1238.65 307.80 967.13 Pass 11908.49 8790.18 12000.00 9331.13 43.05 48.38 229.38 234.50 1240.95 310.04 968.21 Pass 11990.20 8845.68 12050.00 9365.57 43.41 48.68 229.49 234.28 1242.19 312.07 968.31 Pass 12071.85 8904.03 12100.00 9400.29 43.76 48.98 229.68 234.11 1242.36 314.24 967.10 Pass 12153.08 8964.83 12150.00 9435.17 44.10 49.29 229.96 233.99 1241.37 316.39 964.60 Pass 12233.52 9027.59 12200.00 9470.08 44.43 49.63 230.33 233.91 1239.10 318.53 960.66 Pass 12297.84 9079.38 12250.00 9505.02 44.69 49.96 230.73 234.07 1235.76 320.37 955.38 Pass 12347.13 9119.29 12300.00 9540.10 44.91 50.28 231.08 234.43 1232.34 322.12 949.76 Pass 12396.47 9159.24 12350.00 9575.39 45.15 50.60 231.42 234.77 1229.00 323.78 944.32 Pass 12445.90 9199.25 12400.00 9611.03 45.38 50.92 231.74 235.09 1225.76 325.55 938.93 Pass 12495.39 9239.32 12450.00 9646.97 45.62 51.24 232.04 235.38 1222.54 327.23 933.67 Pass 12544.96 9279.45 12500.00 9683.29 45.86 51.55 232.31 235.65 1219.43 329.01 928.49 Pass 12594.61 9319.65 12550.00 9720.01 46.11 51.86 232.55 235.89 1216.45 330.68 923.60 Pass 12644.33 9359.90 12600.00 9757.16 46.36 52.17 232.76 236.10 1213.61 332.46 918.79 Pass 12694.10 9400.20 12650.00 9794.70 46.61 52.48 232.94 236.29 1210.88 334.13 914.26 Pass 12743.93 9440.54 12700.00 9832.62 46.87 52.78 233.10 236.44 1208.31 335.91 909.85 Pass 12793.80 9480.91 12750.00 9870.84 47.13 53.07 233.23 236.57 1205.89 337.58 905.71 Pass 12843.70 9521.32 12800.00 9909.50 47.39 53.36 233.33 236.68 1203.81 339.33 901.91 Pass 12893.64 9561.75 12850.00 9948.44 47.66 53.65 233.42 236.76 1201.97 340.99 898.47 Pass 12943.57 9602.17 12900.00 9987.43 47.92 53.95 233.50 236.85 1200.16 342.78 894.93 Pass 12995.31 9644.08 1295Q.00 10026.46 48.19 54.25 233.58 236.93 1198.34 344.52 891.47 Pass ) Sperry-SUD Anticollision Report ) Site: End SDI Well: 3-11/M-3O Wellpath: 3-11/M-3O V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 13049.99 9688.55 13000.00 10065.75 48.41 54.54 233.66 237.01 1196.52 346.14 888.19 Pass 13104.66 9733.24 13050.00 10105.48 48.63 54.83 233.71 237.07 1194.71 347.75 884.97 Pass 13159.33 9778.15 13100.00 10145.59 48.84 55.13 233.74 237.10 1192.73 349.29 881.69 Pass 13213.97 9823.26 13150.00 10185.91 49.06 55.42 233.76 237.13 1190.52 350.89 878.15 Pass 13268.60 9868.58 13200.00 10226.48 49.28 55.70 233.78 237.16 1188.24 352.42 874.61 Pass 13323.15 9914.05 13250.00 10267.70 49.50 55.97 233.76 237.14 1186.23 353.98 871.39 Pass 13377.70 9959.74 13300.00 10309.88 49.73 56.23 233.68 237.06 1184.85 355.41 869.07 Pass 13432.24 10005.62 13350.00 10352.81 49.95 56.47 233.56 236.94 1184.08 356.89 867.41 Pass 13486.76 10051.71 13400.00 10396.15 50.17 56.71 233.41 236.79 1183.49 358.28 866.06 Pass 13541.32 10098.03 13450.00 10439.51 50.39 56.95 233.28 236.66 1182.71 359.73 864.45 Pass 13595.90 10144.57 13500.00 10482.87 50.61 57.18 233.16 236.54 1181.74 361.09 862.70 Pass 13650.50 10191.34 13550.00 10526.23 50.83 57.41 233.06 236.44 1180.58 362.47 860.71 Pass 13693.24 10228.08 13589.12 10560.15 51.01 57.58 232.99 236.37 1179.53 363.56 858.99 Pass Site: End SDI Well: 3-17/J-30 Rule Assigned: NOERRORS Wellpath: 3-17/J-3O V9 Inter-Site Error: 0.00 ft 10200.04 7883.77 10200.00 7884.22 37.58 37.63 144.79 141.84 9.625 0.75 0.00 0.75 Pass 10249.81 7914.96 10250.00 7917.38 37.55 37.86 136.03 135.23 9.625 4.31 0.00 4.31 Pass 10299.14 7944.60 10300.00 7950.7;2 37.51 38.05 136.16 137.31 9.625 10.29 0.00 10.29 Pass 10347.92 7972.58 10350.00 7983.75 37.44 38.23 135.03 138.01 9.625 18.13 0.00 18.13 Pass 10396.07 7998.86 10400.00 8016.28 37.38 38.40 133.48 138.18 9.625 27.59 0.00 27.59 Pass 10443.58 8023.46 1045Q.00 8048.70 37.31 38.55 132.58 138.73 9.625 38.94 0.00 38.94 Pass 10492.13 8048.05 10500.00 8081.19 37.38 38.55 132.91 139.06 9.625 50.88 0.00 50.87 Pass 10540.65 8072.63 10550.00 8113.69 37.46 38.55 132.99 139.14 9.625 62.96 0.00 62.96 Pass 10589.10 8097.17 10600.00 8146.26 37.54 38.55 132.95 139.10 9.625 75.32 0.00 75.32 Pass 10637.48 8121.68 10650.00 8178.85 37.64 38.56 132.80 138.95 9.625 87.92 0.00 87.92 Pass 10685.84 8146.17 10700.00 8211.42 37.75 38.57 132.61 138.76 9.625 100.64 0.00 100.64 Pass 10734.15 8170.65 10750.00 8244;06 37.87 38.58 132.45 138.60 9.625 113.50 0.00 113.50 Pass 10782.46 8195.12 10800.00 8276.62 38.00 38.60 132.26 138.41 9.625 126.39 0.00 126.39 Pass 10830.76 8219.59 10850.00 8309.08 38.14 38.61 132.02 138.17 9.625 139.31 0.00 139.31 Pass 10879.05 8244.04 10900.00 8341.44 38.29 38.63 131.74 137.89 9.625 152.28 0.00 152.28 Pass 10927.31 8268.49 10950.00 8373.74 38.45 38.65 131.44 137.59 9.625 165.32 0.00 165.32 Pass 10975.55 8292.93 11000.00 8406.01 38.63 38.68 131.16 137.31 9.625 178.44 0.00 178.44 Pass 11023.77 8317.35 11050.00 8438.14 38.81 38.71 130.83 136.98 9.625 191.62 0.00 191.62 Pass 11071.97 8341.77 11100.00 8470.23 39.00 38.74 130.50 136.65 9.625 204.87 0.00 204.87 Pass 11120.15 8366.17 11150.00 8502.29 39.20 38.76 130.20 136.35 9.625 218.18 0.00 218.18 Pass 11168.34 8390.58 11200.00 8534.34 39.42 38.78 129.93 136.08 9.625 231.48 0.00 231.48 Pass 11216.55 8415.01 11250.00 8566.32 39.64 38.80 129.68 135.83 9.625 244.67 0.00 244.67 Pass 11264.78 8439.44 11300.00 8598.22 39.87 38.83 129.44 135.59 9.625 257.81 0.00 257.81 Pass 11312.99 8463.86 11350.00 8630.21 40.11 38.85 129.23 135.38 9.625 271.04 0.00 271.04 Pass 11361.19 8488.27 11400.00 8662.21 40.36 38.89 129.05 135.20 9.625 284.33 0.00 284.33 Pass 11409.35 8512.67 11450.00 8694.25 40.62 38.93 128.87 135.02 9.625 297.72 0.00 297.72 Pass 11457.49 8537.05 11500.00 8726.28 40.89 38.97 128.70 134.85 9.625 311.21 0.00 311.21 Pass 11505.59 8561.42 11550.00 8758.40 41.16 39.01 128.54 134.69 9.625 324.83 0.00 324.83 Pass 11553.67 8585.77 11600.00 8790.50 41.45 39.05 128.39 134.54 9.625 338.52 0.00 338.52 Pass 11602.94 8610.75 11650.00 8822.50 41.74 39.10 128.23 134.36 9.625 352.19 0.00 352.19 Pass 11660.71 8641.10 11700.00 8854.22 41.98 39.18 128.00 133.96 9.625 364.92 0.00 364.92 Pass 11719.10 8673.52 11750.00 8885.70 42.22 39.26 127.56 133.34 9.625 376.25 0.00 376.25 Pass I _) Sperry-Sun Anticollision .Report ) Site: End SDI WeD: 3-17/J-3O Wellpatb: 3-17/J-30 V9 Rule Assigned: NOERRORS Inter-8ite Error: 0.00 ft 11777.94 8707.91 11800.00 8916.80 42.48 39.34 126.92 132.50 9.625 386.14 0.00 386.14 Pass 11837.00 8744.14 11850.00 8947.48 42.74 39.42 126.06 131.43 9.625 394.62 0.00 394.62 Pass 11896.07 8782.01 11900.00 8977.68 42.99 39.51 124.98 130.14 9.625 401.73 0.00 401.73 Pass 11954.95 8821.37 11950.00 9007.58 43.25 39.59 123.71 128.64 9.625 407.59 0.00 407.59 Pass 12013.53 8862.06 12000.00 9037.56 43.51 39.67 122.31 127.00 9.625 412.56 0.00 412.56 Pass 12071.69 8903.92 12050.00 9067.67 43.76 39.73 120.78 125.21 9.625 416.77 0.00 416.77 Pass 12129.33 8946.78 12100.00 9097.92 44.00 39.80 119.13 123.28 9.625 420.32 0.00 420.32 Pass 12186.35 8990.49 12150.00 9128.41 44.24 39.88 117.35 121.20 9.625 423.38 0.00 423.37 Pass 12242.64 9034.86 12200.00 9159.05 44.46 39.95 115.45 118.98 9.625 425.95 0.00 425.95 Pass 12294.58 9076.75 12250.00 9189.91 44.67 40.01 113.41 116.75 9.625 428.30 0.00 428.30 Pass 12342.05 9115.17 12300.00 9220.87 44.89 40.07 111.34 114.69 9.625 431.14 0.00 431.14 Pass 12389.52 9153.61 12350.00 9251.90 45.11 40.13 109.32 112.66 9.625 434.58 0.00 434.58 Pass 12437.04 9192.08 12400.00 9283.04 45.34 40.18 107.35 110.69 9.625 438.58 0.00 438.58 Pass 12484.59 9230.58 12450.00 9314.28 45.57 40.24 105.43 108.77 9.625 443.12 0.00 443.12 Pass 12532.22 9269.14 12500.00 9345. iT 45.80 40.31 103.59 106.93 9.625 448.28 0.00 448.28 Pass 12579.96 9307.79 12550.00 9377.59 46.04 40.37 101.84 105.19 9.625 453.99 0.00 453.98 Pass 12627.78 9346.50 12600.00 9409.68 46.28 40.44 100.18 103.53 9.625 460.16 0.00 460.16 Pass 12675.69 9385.30 12650.00 9442.08 46.52 40.51 98.62 101.96 9.625 466.77 0.00 466.77 Pass 12723.65 9424.13 12700.00 9474.66 46.76 40.59 97.13 100.47 9.625 473.84 0.00 473.84 Pass 12771.59 9462.93 12750.00 9507.23 47.01 40.67 95.68 99.02 9.625 481.37 0.00 481.36 Pass 12819.47 9501.70 12800.00 9539.72 47.26 40.75 94.26 97.61 9.625 489.30 0.00 489.30 Pass 12867.32 9540.44 12850.00 9572.08 .47.52 40.82 92.88 96.22 9.625 497.57 0.00 497.57 Pass 12915.13 9579.15 12900.00 9604.35 47.77 40.90 91.52 94.87 9.625 506.16 0.00 506.16 Pass 12962.84 9617.77 12950.00 9636.48 48.03 40.99 90.20 93.55 9.625 515.39 0.00 515.39 Pass 13010.54 9656.44 13000.00 9668.65 48.25 41.08 88.93 92.28 9.625 525.44 0.00 525.44 Pass 13058.07 9695.14 13050.00 9700.86 48.44 41.18 87.70 91.06 9.625 536.26 0.00 536.26 Pass 13105.36 9733.81 13100.00 9733.00 48.63 41.27 86.49 89.85 9.625 547.77 0.00 547.77 Pass 13152.43 9772.47 13150.00 9765.11 48.82 41.37 85.31 88.67 9.625 559.87 0.00 559.87 Pass 13199.26 9811.09 13200.00 9797.11 49.00 41.46 84.14 87.51 9.625 572.55 0.00 572.55 Pass 13245.83 9849.67 13249.99 9829.05 49.19 41.56 83.01 86.38 9.625 585.87 0.00 585.87 Pass 13292.14 9888.17 13300.00 9860.76 49.38 41.67 81.88 85.26 9.625 599.83 0.00 599.82 Pass 13338.11 9926.56 1335Q.00 9892.11 49.56 41.76 80.75 84.13 9.625 614.38 0.00 614.38 Pass 13383.85 9964.90 13400.00 9923.37 49.75 41.87 79.64 83.02 9.625 629.38 0.00 629.38 Pass 13429.32 10003.16 13450.00 9954.45 49.93 41.98 78.54 81.92 9.625 644.84 0.00 644.84 Pass 13474.50 10041.32 13500.00 9985.32 50.12 42.09 77.47 80.85 9.625 660.84 0.00 660.84 Pass 13519.41 10079.40 13550.00 10016.08 50.30 42.20 76.42 79.80 9.625 677.35 0.00 677.35 Pass 13564.11 10117.43 13600.00 10046.84 50.48 42.31 75.41 78.79 9.625 694.33 0.00 694.33 Pass 13608.57 10155.40 13650.00 10077.47 50.66 42.41 74.41 77.79 9.625 711.64 0.00 711.64 Pass 13652.38 10192.95 13700.00 10107.94 50.84 42.52 73.43 76.81 9.625 729.33 0.00 729.33 Pass 13696.73 10231.08 13750.00 10138.35 51.02 42.62 72.48 75.86 9.625 747.44 0.00 747.44 Pass 13740.51 10268.86 13800.00 10168.77 51.20 42.72 71.56 74.94 9.625 765.82 0.00 765.82 Pass 13784.06 10306.56 13850.00 10199.04 51.37 42.81 70.65 74.03 9.625 784.44 0.00 784.44 Pass Site: End SDI WeD: 3-17/J-3OA Rule Assigned: NOERRORS WeUpath: 3-17/J-30A V3 Inter-8ite Error: 0.00 ft RefereDœ 0Irset Semi-Maù~ .uis etr-çar... .N~ ADo'" MD TVD MD TVD ~ ~ .TFO+AZ¡U'O-BS QØoa ....Aro DevIatIon WBI'Ding ft ft ft ft ft ft deg deg in ft ft It 10200.04 7883.77 10200.00 7884.22 37.58 37.63 144.79 141.84 9.625 0.75 0.00 0.75 Pass 10249.81 7914.96 10250.00 7917.38 37.55 37.86 136.03 135.23 9.625 4.31 0.00 4.31 Pass 10299.14 7944.60 10300.00 7950.72 37.51 38.05 136.16 137.31 9.625 10.29 0.00 10.29 Pass 1) Sperry-SUD Anticollision Report ) Site: End SDI Well: 3-17/J-3OA Wellpath: 3-17/J-3OA V3 RweAa.n~: NOERRORS Inter-Site Error: 0.00 ft 10347.92 7972.58 10350.00 7983.75 37.44 38.23 135.03 138.01 9.625 18.13 0.00 18.13 Pass 10396.07 7998.86 10400.00 8016.28 37.38 38.40 133.48 138.18 9.625 27.59 0.00 27.59 Pass 10443.58 8023.46 10450.00 8048.70 37.31 38.55 132.58 138.73 9.625 38.94 0.00 38.94 Pass 10492.13 8048.05 10500.00 8081.19 37.38 38.55 132.91 139.06 9.625 50.88 0.00 50.88 Pass 10540.65 8072.63 10550.00 8113.69 37.46 38.55 132.99 139.14 9.625 62.96 0.00 62.96 Pass 10589.10 8097.17 10600.00 8146.26 37.54 38.56 132.95 139.10 9.625 75.31 0.00 75.31 Pass 10637.49 8121.68 10650.00 8178.85 37.64 38.56 132.80 138.95 9.625 87.91 0.00 87.91 Pass 10685.84 8146.18 10700.00 8211.42 37.75 38.57 132.61 138.76 9.625 100.63 0.00 100.63 Pass 10734.16 8170.65 10750.00 8244.06 37.87 38.59 132.45 138.60 9.625 113.49 0.00 113.49 Pass 10782.47 8195.12 10800.00 8276.62 38.00 38.60 132.26 138.41 9.625 126.37 0.00 126.37 Pass 10830.81 8219.61 10850.05 8309.12 38.14 38.62 132.02 138.17 9.625 139.31 0.00 139.31 Pass 10879.05 8244.05 10900.00 8341.44 38.29 38.63 131.74 137.89 9.625 152.26 0.00 152.26 Pass 10927.31 8268.49 10950.00 8373.75 38.45 38.66 131.45 137.60 9.625 165.30 0.00 165.30 Pass 10975.55 8292.93 11000.00 8406.01 38.63 38.68 131.16 137.31 9.625 178.42 0.00 178.42 Pass 11023.77 8317.36 11050.00 8438.15 38.81 38.71 130.84 136.99 9.625 191.60 0.00 191.60 Pass 11071.97 8341.77 11100.00 8470.23 39.00 38.74 130.51 136.66 9.625 204.85 0.00 204.85 Pass 11120.15 8366.18 11150.00 8502.30 39.20 38.77 130.21 136.36 9.625 218.16 0.00 218.16 Pass 11168.34 8390.59 11200.00 8534.35 39.42 38.78 129.94 136.09 9.625 231.46 0.00 231.45 Pass 11216.56 8415.01 11250.00 8566.33 39.64 38.80 129.69 135.84 9.625 244.66 0.00 244.65 Pass 11264.79 8439.44 11300.00 8598.23 39.87 38.83 129.44 135.59 9.625 257.79 0.00 257.79 Pass 11313.00 8463.86 11350.00 8630.22 40.11 38.85 129.24 135.39 9.625 271.02 0.00 271.02 Pass 11361.19 8488.27 1140QrOO 866g.~~ .40.36 38.89 129.05 135.20 9.625 284.30 0.00 284.30 Pass 11409.36 8512.67 11450..00 8694.26 40.62 38.93 128.88 135.03 9.625 297.70 0.00 297.70 Pass 11457.50 8537.06 11500.00 8726.29 40.89 38.97 128.70 134.85 9.625 311.18 0.00 311.18 Pass 11505.60 8561.42 11550.00 8758.40 41.16 39.01 128.55 134.70 9.625 324.80 0.00 324.80 Pass 11553.68 8585.78 11600.00 8790.51 41.45 39.06 128.40 134.55 9.625 3$.49 0.00 338.49 Pass 11602.95 8610.75 11650.00 8822.51 41.74 39.11 128.24 134.37 9.625 352.16 0.00 352.16 Pass 11660.71 8641.10 11700.00 8854.24 41.98 39.18 128.01 133.96 9.625 364.89 0.00 364.89 Pass 11719.11 8673.52 11750.00 8885.72 42.22 39.26 127.57 133.35 9.625 376.23 0.00 376.23 Pass 11m.95 8707.92 11800.00 8916.83 42.48 39.34 126.93 132.51 9.625 386.12 0.00 386.12 Pass 11837.02 8744.14 11850.00 8947.51 42.74 39.43 126.07 131.44 9.625 394.60 0.00 394.60 Pass 11896.08 8782.02 11900.00 8977.72 42.99 39.51 124.99 130.15 9.625 401.71 0.00 401.71 Pass 11954.96 8821.38 11950.00 9007.63 43.25 39.59 123.72 128.65 9.625 407.57 0.00 407.57 Pass 12013.55 8862.07 12000.00 9031.60 43.51 39.67 122.32 127.01 9.625 412.54 0.00 412.54 Pass 12071.71 8903.93 12050.00 9067.71 43.76 39.73 120.79 125.22 9.625 416.75 0.00 416.75 Pass 12129.34 8946.79 12100.00 9097.95 44.00 39.81 119.14 123.29 9.625 420.29 0.00 420.29 Pass 12186.37 8990.50 12150.00 9128.44 44.24 39.88 117.36 121.21 9.625 423.34 0.00 423.34 Pass 12242.66 9034.87 12200.00 9159.08 44.46 39.95 115.46 118.99 9.625 425.92 0.00 425.92 Pass 12294.60 9076.76 12250.00 9189.94 44.67 40.01 113.41 116.76 9.625 428.26 0.00 428.26 Pass 12342.06 9115.18 12300.00 9220.90 44.89 40.07 111.35 114.69 9.625 431.10 0.00 431.10 Pass 12389.54 9153.62 12350.00 9251.93 45.11 40.13 109.33 112.67 9.625 434.53 0.00 434.53 Pass 12437.06 9192.09 12400.00 9283.06 45.34 40.19 107.35 110.70 9.625 438.53 0.00 438.53 Pass 12484.61 9230.59 12450.00 9314.30 45.57 40.25 105.43 108.78 9.625 443.08 0.00 443.08 Pass 12532.23 9269.15 12500.00 9345.78 45.80 40.31 103.59 106.93 9.625 448.23 0.00 448.23 Pass 12579.96 9307.79 12550.00 9377.52 46.04 40.35 101.83 105.18 9.625 453.81 0.00 453.81 Pass 12627.77 9346.50 12600.00 9409.49 46.28 40.37 100.16 103.50 9.625 459.71 0.00 459.71 Pass 12675.67 9385.28 12650.00 9441.65 46.52 40.38 98.55 101.90 9.625 465.86 0.00 465.86 Pass 12723.49 9423.99 12700.00 9473.18 46.76 40.39 96.90 100.24 9.625 471.34 0.00 471.34 Pass 12770.84 9462.33 12750.00 9502.88 47.01 40.42 95.02 98.36 9.625 475.31 0.00 475.30 Pass 12817.71 9500.27 12800.00 9531.11 47.25 40.45 92.96 96.30 9.625 478.49 0.00 478.49 Pass 12864.42 9538.09 12850.00 9558.86 47.50 40.50 90.87 94.21 9.625 481.76 0.00 481.76 Pass ) Sperry-SUD Anticollision Report ) I'll 12911.22 9575.98 12900.00 9586.69 47.75 40.55 88.81 92.16 9.625 484.87 0.00 484.87 Pass 12958.09 9613.93 12950.00 9614.62 48.00 40.61 86.80 90.14 9.625 488.01 0.00 488.01 Pass 13004.92 9651.88 13000.00 9642.65 48.23 40.68 84.81 88.16 9.625 491.70 0.00 491.70 Pass 13051.64 9689.89 13050.00 9670.98 48.41 40.75 82.87 86.23 9.625 496.37 0.00 496.37 Pass 13098.20 9727.94 13100.00 9699.39 48.60 40.83 80.94 84.30 9.625 501.37 0.00 501.37 Pass 13144.51 9765.95 13150.00 9727.68 48.78 40.92 79.01 82.37 9.625 506.81 0.00 506.80 Pass 13190.69 9804.02 13200.00 9756.17 48.97 41.02 77.10 80.47 9.625 512.62 0.00 512.62 Pass 13236.74 9842.13 13250.00 9784.81 49.15 41.12 75.23 78.60 9.625 518.95 0.00 518.95 Pass 13282.80 9880.40 13300.00 9813.90 49.34 41.23 73.41 76.79 9.625 525.33 0.00 525.33 Pass 13328.90 9918.86 13350.00 9843.51 49.53 41.34 71.66 75.04 9.625 531.82 0.00 531.82 Pass 13374.78 9957.29 13400.00 9873.14 49.71 41.45 69.95 73.33 9.625 539.41 0.00 539.40 Pass 13420.43 9995.67 13450.00 9902.71 49.90 41.57 68.25 71.63 9.625 547.61 0.00 547.61 Pass 13465.79 10033.96 13500.00 9932.08 50.08 41.71 66.55 69.93 9.625 556.26 0.00 556.26 Pass 13510.78 10072.07 13550.00 9961.07 50.27 41.85 64.82 68.20 9.625 565.34 0.00 565.33 Pass 13555.38 10110.00 13600.00 9989.71 50.45 42.00 63.09 66.47 9.625 575.14 0.00 575.14 Pass 13600.00 10148.08 13650.00 10018.45 50.63 42.15 61.40 64.78 9.625 585.55 0.00 585.55 Pass 13644.35 10186.06 13700.00 10047.93 50.81 42.30 59.81 63.19 9.625 596.10 0.00 596.09 Pass 13688.82 10224.27 13750.00 10077.69 50.99 42.47 58.29 61.67 9.625 607.00 0.00 607.00 Pass 13733.32 10262.65 13800.00 10108.00 51.17 42.63 56.85 60.23 9.625 618.20 0.00 618.20 Pass 13778.07 10301.37 13850,00 10139.32 51.35 42.81 55.54 58.92 9.625 629.47 0.00 629.47 Pass I" ·1' 7950.72 7983.75 8016.28 10443.58 8023.46 10450.00 8048.69 37.31 38.55 132.57 138.72 9.625 38.94 0.00 38.94 Pass 10492.08 8048.03 10500.00 8081.06 37.38 38.83 132.41 138.56 9.625 51.11 0.00 51.10 Pass 10540.49 8072.55 10550.00 8114.70 37.46 39.09 134.32 140.47 9.625 63.39 0.00 63.39 Pass 10588.65 8096.95 10600.00 8150.33 37.54 39.33 138.84 144.99 9.625 75.59 0.00 75.59 Pass 10636.26 8121.06 10650.00 8187.58 37.64 39.56 144.68 150.83 9.625 88.35 0.00 88.35 Pass 10682.93 8144.70 10700.00 8226.51 37.74 39.77 150.79 156.94 9.625 103.12 0.00 103.12 Pass 10728.40 8167.73 10750.00 8267.00 37.86 39.96 156.58 162.73 9.625 120.57 0.00 120.57 Pass 10772.69 8190.17 10800.00 8308.65 37.97 40.14 161.77 167.92 9.625 140.53 0.00 140.53 Pass 10815.91 8212.06 10850.00 8351.22 38.09 40.30 166.14 172.29 9.625 162.86 0.00 162.86 Pass 10857.53 8233.14 10900.00 8394.82 38.22 40.45 169.99 176.14 9.625 187.94 0.00 187.93 Pass 10896.60 8252.94 10950.00 8439.38 38.35 40.57 173.69 179.84 9.625 216.24 0.00 216.24 Pass 10933.25 8271.50 11000.00 8484.52 38.48 40.67 177.04 183.19 9.625 247.44 0.00 247.44 Pass 10968.30 8289.25 11050.00 8529.98 38.60 40.76 179.82 185.97 9.625 280.72 0.00 280.72 Pass 11001.95 8306.30 11100.00 8575.75 38.72 40.83 182.09 188.24 9.625 315.77 0.00 315.77 Pass 11033.69 8322.38 11150.00 8621.87 38.85 40.88 183.96 190.11 9.625 352.83 0.00 352.83 Pass 11063.05 8337.25 11200.00 8668.32 38.97 40.91 185.49 191.64 9.625 392.05 0.00 392.05 Pass 11089.85 8350.82 11250.00 8714.74 39.07 40.91 186.83 192.98 9.625 433.14 0.00 433.14 Pass 11114.35 8363.24 11300.00 8760.60 39.18 40.90 188.11 194.26 9.625 475.51 0.00 475.51 Pass 11136.80 8374.61 11350.00 8805.76 39.28 40.88 189.34 195.49 9.625 518.90 0.00 518.90 Pass 11157.93 8385.31 11400.00 8850.56 39.37 40.85 190.43 196.58 9.625 563.02 0.00 563.02 Pass ) Sperry-SUD Anticollision Report ) Site: End SDI Well: 3-17B/M-31 Wellpath: 3-17B/M-31 V6 Rwe~.~: NOERRORS Inter-Site Error: 0.00 ft 11178.72 8395.84 11450.00 8895.44 39.46 11199.37 8406.30 11500.00 8940.51 39.55 11219.86 8416.68 11550.00 8985.67 39.65 11240.39 8427.08 11600.00 9030.73 39.75 11261.03 8437.54 11650.00 9075:71 39.85 11281.82 8448.06 11700.00 11302.86 8458.72 11750.00 11323.96 8469.41 11800.00 11345.18 8480.16 11850.00 11367.24 8491.34 11900.00 11389.94 8502.83 11950.00 11412.51 8514.27 12000.00 11434.68 8525.50 12050.00 11456.36 8536.48 12100.00 11477.04 8546.95 12150.00 11496.57 8556.85 12200.00 11515.35 8566.36 12250.00 11533.24 8575.42 12300.00 11548.85 8583.33 12350.00 11560.32 8589.14 12400.00 11567.31 8592.68 12450.00 11570.19 8594.14 12500.00 9120.75 39.95 9165.97 40.06 9211.28 40.17 9256.70 40.28 9302.48 40.39 9348.61 40.51 9394.77 40.64 9440.64 40.76 9485.74 40.88 9530.20 41.00 9574.33 41.11 9617.43 41.22 9658.74 41.33 9698.07 41.42 9735.77 41.49 9772.17 41.53 9806.91 41.55 40.81 191.34 197.49 40.78 192.09 198.24 40.75 192.71 198.86 40.72 193.28 199.43 40.70 193.80 199.95 40.69 194.25 200.40 40.68 194.64 200.79 40.65 194.98 201.13 40.63 195.27 201.42 40.63 195.49 201.64 40.62 195.66 201.81 40.61 195.81 201.96 40.58 195.98 202.13 40.56 196.22 202.37 40.53 196.50 202.65 40.49 196.78 202.93 40.45 197.12 203.27 40.42 197.58 203.73 40.37 198.11 204.26 40.29 198.64 204.79 40.18 199.12 205.27 40.03 199.57 205.72 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 607.54 652.34 697.35 742.38 787.39 832.41 877.40 922.42 967.43 1012.13 1056.58 1101.11 1145.80 1190.57 1235.71 1281.33 1327.00 1372.44 1418.12 1464.88 1512.77 1561.23 0.00 607.54 0.00 652.34 0.00 697.35 0.00 742.38 0.00 787.39 0.00 832.41 0.00 877.39 0.00 922.42 0.00 967.43 0.00 1012.13 0.00 1056.58 0.00 1101.11 0.00 1145.80 0.00 1190.57 0.00 1235.70 0.00 1281.33 0.00 1327.00 0.00 1372.44 0.00 1418.12 0.00 1464.88 0.00 1512.77 0.00 1561.23 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Site: End SDI Well: 3-17C/M-31 , Rwe Assigned: NOERRORS Wellpath: 3-17C/M-31 V3Plan: Undefined Inter-Site Error: 0.00 ft ""."". " ; ""'Di."".';!~,· "~', "~,:. ""." :,.," """"'1"'''::'.''''. ;"','1:;;,'.'1 ".'1' "';'I":".Å.'·,'~l:. "':".':"."::,1"'" """1,' ','.'.""".".III.;I"ó:;::;;¡".:.W:'~j~. ','''','' "",,','1 , ,:.t¡"u;'¡,' 1"'.'"''''',).'''')''''''''''''' "..1:1,,:' "'::':1,,1:.,""" ,:.,;,: ,," ",,' ,': ,i.', ""'.'.".'" "" ::,:"".:""""';" ","'1';"'1,.1'1'. i"j,4~:::t","'.' . ....',"""'.","'.·,NI;;AI~.;',' , I," "I' "";'. '.{I.,,:,"'. "~B~.'..' "'. \:,'''.. 'I""., I"';'. " ,'. I:".':'.,"," .'" .'.',', ",,,,, ',' 'MD"'" "",""', ;""",','Qö"':/" ': """"&.Ð"""':"""""''''''''':'~'''''''',, ,,,,,1',:....,,1 :'I""·'I"",,'IOIJ.t/IT""~~'.a.'I7.f.""'ØAR!Q,,:,'l1I!"'~,""'11"" ' " .' ':("."" ",' ',I,',', "I,~.n;6ÎIiWi.",'I"II;,,":I'W~..w.Inø'"'',i''''' :. : II:,'" -;I' ~ "' "\::. :,. ':,,',"; ".:",~'~I'.:,;",>:.",:: '.";"'., ;'I'¡':>: I,:.:.:, ;,: :.,1,,' : ":'~~'.I ,.;. ,:"">',:,":;:':: :"",/:,t)~'·r:':,I.;:I.',·, ';':: ".<t't~r ::I,,';;:·/"'i:'I.",:,. ',:'.,',,:: . .".",1,:::',:,'1:: I,:,,:'i:'~""" ":",:;,~,;,::"'I,,,..: ":':'~'~~I;d"':::;':','~,~,¡:I,::I, :>:,::,:;"",:,~""",:", ,"'¡'j,!' I'",,:,: ","::::'1,;:;''1':'': "1,'1,,:;1/:,:":.;' ":",1"; I:,': ,::,' :ø" ';':':~~'~"':¡:'I "''",:;: ':"::';"'~:~~~:'",:'i:'::::'; 'i, ,." ',,". '~"" ,., "","',,' ,"" ",""ft""·',':t"",,, ,I' """,,'K""''''''I'' ,'..' "",'1"':"'1'",,',,1,,'," " ,,,,,,¡'ft ,i"""....:,'I'I""·II"",,.,,,,·':","""II"I,',,,, ",.,,",I,'I,!'," I,': "1'1,'1" "I'i"',II"'li""",I""I'''I,,,,I,:,',I''''':I,',¡,'r'''ft'!,"'1""'1'1"1'1':"'· l"""""""" "",)""",1,' 1'1,1 ,,"","1"""1""'" I",,"'" ,," "'I"" .:' ", 'I, 10200.04 10249.81 10299.14 10347.92 10396.07 7883.77 10200.00 7914.96 10250.00 7944.60 10300:00 7972.58 10350.00 7998.86 10400.00 10443.58 8023.46 10450.00 10492.08 8048.03 10500.00 10540.49 8072.55 10550.00 10588.65 8096.95 10600.00 10636.26 8121.06 10650.00 10682.93 8144.70 10700.00 10728.40 8167.73 10750.00 10772.69 8190.17 10800.00 10815.91 8212.06 10850.00 10857.53 8233.14 10900.00 10896.60 10933.25 10968.30 11001.95 11033.69 11063.05 11089.85 8252.94 10950.00 8271.50 11000.00 8289.25 11050.00 8306.30 11100.00 8322.38 11150.00 8337.25 11200.00 8350.82 11250.00 7884.22 37.58 7917.38 37.55 7950.72 37.51 7983.75 37.44 8016.28 37.38 8048.69 37.31 8081.06 37.38 8114.70 37.46 8150.33 37.54 8187.58 37.64 8226.51 37.74 8267.00 37.86 8308.65 37.97 8351.22 38.09 8394.82 38.22 8439.38 38.35 8484.52 38.48 8529.98 38.60 8575.75 38.72 8621.87 38.85 8668.32 38.97 8714.74 39.07 37.63 144.79 141.84 37.86 136.03 135.23 38.05 136.16 137.31 38.23 135.03 138.01 38.40 133.48 138.18 38.55 132.57 138.72 38.83 132.41 138.56 39.09 134.32 140.47 39.33 138.84 144.99 39.56 144.68 150.83 39.77 150.79 156.94 39.96 156.58 162.73 40.14 161.77 167.92 40.30 166.14 172.29 40.45 169.99 176.14 40.57 173.69 179.84 40.67 177.04 183.19 40.76 179.82 185.97 40.83 182.09 188.24 40.88 183.96 190.11 40.91 185.49 191.64 40.91 186.83 192.98 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 0.75 4.31 10.29 18.13 27.59 38.94 51.11 63.39 75.59 88.35 103.12 120.57 140.53 162.86 187.94 216.24 247.44 280.72 315.77 352.83 392.05 433.14 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.75 4.31 10.29 18.13 27.59 38.94 51.10 63.39 75.59 88.35 103.12 120.57 140.53 162.86 187.93 216.24 247.44 280.72 315.77 352.83 392.05 433.14 I.":":";":";': "I:(:::J.", Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass ) Sperry-SUD Anticollision Report ) Site: End SDI Well: 3-17C/M-31, Wellpath: 3-17C/M-31 V3,Plan: Undefined Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 11114.35 8363.24 11300.00 11136.80 8374.61 11350.00 11157.93 8385.31 11400.00 11178.72 8395;84 11450.00 11199.37 8406;30 11500.00 11219.86 8416.68 11550.00 11240.39 8427.08 11600.00 11261.03 8437.54 11650.00 11281.82 8448.06 11700.00 11302.86 8458.72 11750.00 11323.96 8469.41 11800.00 11345.18 8480.16 11850.00 11367.24 8491.34 11900.00 11389.94 8502.83 11950;00 11412.51 8514.27 12000.00 11434.68 8525.50 12050.00 11456.36 8536.48 12100.00 11477.04 8546.95 12150.00 11497.03 8557.08 12200.00 11517.03 8567.21 12250.00 11537.02 8577.34 12300.00 11557.02 8587.47 12350.00 11577.02 8597.60 12400.00 8760.60 39.18 8805.76 39.28 8850.?6 39.37 8895.44 39.46 8940.51 39.55 8985.67 39.65 9030.73 39.75 9075.71 39.85 9120.75 39.95 9165.97 40.06 9211.28 40.17 9256.70 40.28 9302.48 40.39 9348.61 40.51 9394.77 40.64 9440.64 40.76 9485.74 40.88 9530.20 41.00 9574.52 41.11 9618.84 41.23 9663.16 41.35 9707.48 41.47 9751.81 41.59 40.90 188.11 194.26 40.88 189.34 195.49 40.85 190.43 196.58 40.81 191.34 197.49 40.78 192.09 198.24 40.75 192.71 198.86 40.72 193.28 199.43 40.70 193.80 199.95 40.69 194.25 200.40 40.68 194.64 200.79 40.65 194.98 201.13 40.63 195.27 201.42 40.63 195.49 201.64 40.62 195.66 201.81 40.61 195.81 201.96 40.58 195.98 202.13 40.56 196.22 202.37 40.54 196.50 202.65 40.81 196.77 202.92 41.07 197.02 203.17 41.34 197.25 203.40 41.61 197.46 203.61 41.88 197.66 203.81 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 3.750 475.51 518.90 563.02 607.54 652.34 697.35 742.38 787.39 832.41 877.40 922.42 967.43 1012.13 1056.58 1101.11 1145.80 1190.57 1235.71 1281.16 1326.65 1372.15 1417.68 1463.22 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 475.51 518.90 563.02 607.54 652.34 697.35 742.38 787.39 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass 11603.32 8610.94 12450.00 9796.13 41.74 42.16 197.86 203.99 3.750 1508.78 0.00 1508.78 Pass 11726.20 8677.57 12500.00 9840.45 42.25 42.45 198.23 203.98 3.750 1553.61 0.00 1553.61 Pass Site: End SDI Well: 3-17C/PB1 Wellpath: 3-17C/PB1 V3 0.00 832.41 0.00 877.39 0.00 922.42 0.00 967.43 0.00 1012.13 0.00 1056.58 0.00 1101.11 0.00 1145.80 0.00 1190.57 0.00 1235.70 0.00 1281.16 0.00 1326.65 0.00 1372.15 0.00 1417.68 0.00 1463.22 RuleAu.n~: NOERRORS Inter-Site Error: 0.00 ft 10200.04 7883.77 10200.00 7884.22 37.58 37.63 144.79 141.84 9.625 0.75 0.00 0.75 Pass 10249.81 7914.96 10250.00 7917.38 37.55 37.86 136.03 135.23 9.625 4.31 0.00 4.31 Pass 10299.14 7944.60 10300.00 7950.72 37.51 38.05 136.16 137.31 9.625 10.29 0.00 10.29 Pass 10347.92 7972.58 10350.00 7983.75 37.44 38.23 135.03 138.01 9.625 18.13 0.00 18.13 Pass 10396.07 7998.86 10400.00 8016.28 37.38 38.40 133.48 138.18 9.625 27.59 0.00 27.59 Pass 10443.58 8023.46 10450.00 8048.69 37.31 10492.08 8048.03 10500.00 8081.06 37.38 10540.49 8072.55 10550.00 8114.70 37.46 10588.65 8096.95 10600.00 8150.33 37.54 10636.26 8121.06 10650.00 8187.58 37.64 10682.93 10728.40 10772.69 10815.91 10857.53 10896.60 10933.25 10968.30 11001.95 11033.69 8144.70 10700.00 8167.73 10750.00 8190.17 10800.00 8212.06 10850.00 8233.14 10900.00 8226.51 37.74 8267.00 37.86 8308.65 37.97 8351.22 38.09 8394.82 38.22 8252.94 10950.00 8439.38 38.35 8271.50 11 000.00 8484.~2 38.48 8289.25 11050.00 8529.98 38.60 8306.30 11100.00 8575.75 38.72 8322.38 11150.00 8621.87 38.85 38.55 132.57 138.72 38.83 132.41 138.56 39.09 134.32 140.47 39.33 138.84 144.99 39.56 144.68 150.83 39.77 150.79 156.94 39.96 156.58 162.73 40.14 161.77 167.92 40.30 166.14 172.29 40.45 169.99 176.14 40.57 173.69 179.84 40.67 177.04 183.19 40.76 179.82 185.97 40.83 182.09 188.24 40.88 183.96 190.11 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 9.625 38.94 51.11 63.39 75.59 88.35 103.12 120.57 140.53 162.86 187.94 216.24 247.44 280.72 315.77 352.83 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. ()() 0.00 0.00 0.00 0.00 0.00 0.00 38.94 51.10 63.39 75.59 88.35 103.12 120.57 140.53 162.86 187.93 216.24 247.44 280.72 315.77 352.83 I~'I'I} I; , ; ';'I":!",I:':.:I,I'::'I':I.,',, Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass : Ii ) Sperry-SUD Anticollision Report ) Site: End SOl Well: 3-17C/ÞB1 Wellpatb: 3-17CIPB1 V3 Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 11063.05 8337.25 11200.00 8668.32 38.97 40.91 185.49 191.64 9.625 392.05 0.00 392.05 Pass 11089.85 8350.82 11250.00 8714.74 39.07 40.91 186.83 192.98 9.625 433.14 0.00 433.14 Pass 11114.35 8363.24 11300.00 8760.60 39.18 40.90 188.11 194.26 9.625 475.51 0.00 475.51 Pass 11136.80 8374.61 11350.00 8805.76 39.28 40.88 189.34 195.49 9.625 518.90 0.00 518.90 Pass 11157.93 8385.31 11400.00 8850.56 39.37 40.85 190.43 196.58 9.625 563.02 0.00 563.02 Pass 11178.72 8395.84 11450.00 8896.44- 39.46 40.81 191.34 197.49 9.625 607.54 0.00 607.54 Pass 11199.37 8406.30 11500.00 8940.51 39.55 40.78 192.09 198.24 9.625 652.34 0.00 652.34 Pass 11219.86 8416.68 11550.00 8985.67 39.65 40.75 192.71 198.86 9.625 697.35 0.00 697.35 Pass 11240.39 8427.08 11600.00 9030.73 39.75 40.72 193.28 199.43 9.625 742.38 0.00 742.38 Pass 11261.03 8437.54 11650.00 9075.71 39.85 40.70 193.80 199.95 9.625 787.39 0.00 787.39 Pass 11281.82 8448.06 11700.00 9120.75 39.95 40.69 194.25 200.40 9.625 832.41 0.00 832.41 Pass 11302.86 8458.72 11750.00 9165.97 40.06 40.68 194.64 200.79 9.625 877.40 0.00 877.39 Pass 11323.96 8469.41 11800.00 9211.28 40.17 40.65 194.98 201.13 9.625 922.42 0.00 922.42 Pass 11345.18 8480.16 11850.00 9256.70 40.28 40.63 195.27 201.42 9.625 967.43 0.00 967.43 Pass 11367.24 8491.34 11900.00 9302.48 40.39 40.63 195.49 201.64 9.625 1012.13 0.00 1012.13 Pass 11389.94 8502.83 11950.00 9348.61 40.51 40.62 195.66 201.81 9.625 1056.58 0.00 1056.58 Pass 11412.51 8514.27 12000.00 9394.77 40.64 40.61 195.81 201.96 9.625 1101.11 0.00 1101.11 Pass 11434.68 8525.50 12050.00 9440.64 40.76 40.58 195.98 202.13 9.625 1145.80 0.00 1145.80 Pass 11456.36 8536.48 12100.00 9485.74 40.88 40.56 196.22 202.37 9.625 1190.57 0.00 1190.57 Pass 11477.04 8546.95 12150.00 9530.20 41.00 40.54 196.50 202.65 9.625 1235.71 0.00 1235.70 Pass 11496.72 8556.92 12200.00 9574.38 41.11 40.66 196.78 202.93 9.625 1281.28 0.00 1281.27 Pass 11516.74 8567.06 12250.00 9618.42 41:23 40.67 197.05 203.20 9.625 1326.66 0.00 1326.66 Pass 11536.23 8576.94 123ÓÔ.00 9660.71 41.35 40.67 197.45 203.60 9.625 1371.71 0.00 1371.71 Pass 11554.33 8586.10 12350.00 9699.73 41.45 40.67 198.05 204.20 9.625 1415.99 0.00 1415.99 Pass 11570.72 8594.41 124PO.00 9734.53 41.55 40.67 198.83 204.98 9.625 1458.84 0.00 1458.83 Pass 11588.01 8603.16 12450.00 9765.04 41.65 40.68 199.80 205.95 9.625 1498.59 0.00 1498.59 Pass 11657.40 8639.31 12500.00 9791.69 41.96 40.69 200.97 206.94 9.625 1534.23 0.00 1534.22 Pass 11766.22 8700.93 12550.00 9813.89 42.43 40.70 202.34 207.96 9.625 1565.27 0.00 1565.27 Pass Site: End SOl Well: 3-170/M-31 Rule Assigned: NOERRORS Wellpatb: 3-170/M-31 V13 Inter-Site Error: 0.00 ft ,JW~nDeei'",' ,'., 'II,,: I,. .,',~ ~"':S::~~"'~~..".~ ,,·,:,,~~~:':'N~ !}~..: 1(:I";~:'I'i'\\,::I'.i,': " , ""'1.',:",' 1,,:,1 "';:.'i,''-.; 'MD"" TVD '~¥p','" '~ "."','~',,,:Ana..." W~'" ft .' :ft' ':",' , I ,.:ft 1'1" , "ftl,'. ' ,ft, , , ft' ,deg, ' 'deg., ,,' ',iii' ' ft.:" ft "'I ' " 1"'1 " " ¡'I'I 'I ,', I 10199.97 7883.73 10200.00 7884.17 37.58 37.72 132.02 129.07 9.625 0.92 0.00 0.92 Pass 10249.73 7914.91 10250.00 7917.32 37.55 37.95 133.68 132.88 9.625 4.49 0.00 4.49 Pass 10299.06 7944.55 10300.00 7950.67 37.51 38.13 135.14 136.28 9.625 10.46 0.00 10.46 Pass 10347.83 7972.53 10350.00 7983.70 37.44 38.31 134.45 137.43 9.625 18.30 0.00 18.30 Pass 10395.97 7998.81 10400.00 8016.23 37.38 38.49 133.10 137.81 9.625 27.75 0.00 27.75 Pass 10443.48 8023.41 10450.00 8048.65 37.31 38.64 132.31 138.46 9.625 39.11 0.00 39.11 Pass 10491.97 8047.97 10500.00 8081.02 37.38 38.91 132.22 138.37 9.625 51.27 0.00 51.27 Pass 10540.39 8072.50 10550.00 8114.67 37.46 39.18 134.16 140.31 9.625 63.55 0.00 63.55 Pass 10588.55 8096.89 10600.00 8150.30 37.54 39.41 138.72 144.87 9.625 75.74 0.00 75.74 Pass 10636.16 8121.01 10650.00 8187.55 37.64 39.64 144.57 150.72 9.625 88.48 0.00 88.48 Pass 10682.82 8144.65 10700.00 8226.48 37.74 39.85 150.68 156.83 9.625 103.24 0.00 103.23 Pass 10728.29 8167.68 10750.00 8266.98 37.85 40.04 156.49 162.64 9.625 120.66 0.00 120.66 Pass 10772.58 8190.11 10800.00 8308.63 37.97 40.22 161.70 167.85 9.625 140.61 0.00 140.60 Pass 10815.80 8212.01 10850.00 8351.19 38.09 40.38 166.07 172.22 9.625 162.93 0.00 162.93 Pass 10857.41 8233.09 10900.00 8394.79 38.22 40.53 169.93 176.08 9.625 187.99 0.00 187.99 Pass 10896.49 8252.88 10950.00 8439.36 38.35 40.65 173.64 179.79 9.625 216.28 0.00 216.28 Pass ) Sperry-Sun Anticollision Report ) Site: End SOl , ¡, ' Well: 3-170/M-31 Wellpath: 3-170/M-31 V13 Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 10933.13 8271.44 11000.00 8484.49 38.47 40.75 177.00 183.15 9.625 247.48 0.00 247.48 Pass 10968.17 8289.19 11050.00 8529.96 38.60 40.83 179.78 185.93 9.625 280.75 0.00 280.75 Pass 11001.82 8306.24 11100.00 8575.73 38.72 40.90 182.06 188.21 9.625 315.79 0.00 315.79 Pass 11033.56 8322.31 11150.00 8621.85 38.85 41.02 183.93 190.08 9.625 352.85 0.00 352.84 Pass 11063.03 8337.24 11200.00 8667.71 38.97 41.02 185.67 191.82 9.625 391.58 0.00 391.58 Pass 11090.35 8351.08 11250.00 8711.19 39.08 41.02 187.84 193.99 9.625 430.43 0.00 430.43 Pass 11115.68 8363.91 11300.00 8753.81 39.18 41.02 189.87 196.02 9.625 470.49 0.00 470.48 Pass 11138.46 8375.45 11350.00 8793.42 39.28 41.02 192.13 198.28 9.625 510.52 0.00 510.52 Pass 11158.54 8385.62 11400.00 8828.73 39.37 41.03 194.67 200.82 9.625 549.82 0.00 549.82 Pass 11178.11 8395.53 11450.00 8862.60 39.46 41.03 197.04 203.19 9.625 589.33 0.00 589.33 Pass 11197.13 8405.17 11500.00 8897.18 39.54 41.03 199.02 205.17 9.625 630.50 0.00 630.50 Pass 11214.33 8413.88 11550.00 8931.39 39.63 41.03 200.76 206.91 9.625 673.08 0.00 673.08 Pass 11229.27 8421.45 11600.00 8964.54 39.70 41.03 202.35 208.50 9.625 716.73 0.00 716.73 Pass 11243.85 8428.84 11650.00 8998.00 39.77 41.03 203.71 209.86 9.625 761.20 0.00 761.20 Pass 11261.38 8437.72 11700.00 9030.77 39.85 41.04 205.06 211.21 9.625 804.23 0.00 804.23 Pass 11279.98 8447.13 11750.00 9063.81 39.94 41.04 206.27 212.42 9.625 847.26 0.00 847.26 Pass 11298.26 8456.39 11800.00 9097.87 40.03 41.04 207.26 213.41 9.625 891.29 0.00 891.29 Pass 11318.00 8466.39 11850.00 9133.42 40.14 41.04 208.06 214.21 9.625 935.44 0.00 935.44 Pass 11339.98 8477.53 11900.00 9170.23 40.25 41.04 208.70 214.85 9.625 979.02 0.00 979.02 Pass 11363.37 8489.38 11950.00 9208.75 40.37 41.05 209.16 215.31 9.625 1022.47 0.00 1022.47 Pass 11387.79 8501.75 12000.00 9248.88 40.50 41.05 209.45 215.60 9.625 1065.77 0.00 1065.77 Pass 11414.53 8515.29 12050.00 9289.34 40.65 41.05 209.71 215.86 9.625 1107.72 0.00 1107.72 Pass 11443.29 8529.86 12100.00 9327.85 40.81 41.06 210.11 216.26 9.625 1147.82 0.00 1147.82 Pass 11472.63 8544.72 12150.00 9364.57 40.97 41.07 210.62 216.77 9.625 1186.99 0.00 1186.99 Pass 11502.49 8559.84 12200.00 9401.53 41.14 41.08 211.07 217.22 9.625 1225.93 0.00 1225.93 Pass 11532.43 8575.01 12250.00 9439.87 41.32 41.08 211.41 217.56 9.625 1265.28 0.00 1265.28 Pass 11559.85 8588.90 12300.00 9480.76 41.49 41.09 211.53 217.68 9.625 1306.97 0.00 1306.97 Pass 11586.35 8602.32 12350.00 9524.10 41.65 41.09 211.45 217.60 9.625 1349.30 0.00 1349.30 Pass 11645.47 8632.92 12400.00 9569.69 41.91 41.12 211.25 217.25 9.625 1390.43 0.00 1390.43 Pass 11728.46 8678.87 12450.00 9615.89 42.26 41.15 211.09 216.83 9.625 1430.40 0.00 1430.40 Pass 11817.97 8732.28 12500.00 9662.40 42.65 41.19 210.94 216.38 9.625 1470.07 0.00 1470.07 Pass 11916.86 8795.73 12550.00 9709.30 43.09 41.23 210.80 215.88 9.625 1508.91 0.00 1508.91 Pass 12024.63 8869.93 12600.00 9756.12 43.56 41.27 210.71 215.35 9.625 1547.47 0.00 1547.47 Pass Site: End SOl Well: 3-27/M-33 Rule Assigned: Major Risk Wellpath: 3-27/M-33 V1 Inter-Site Error: 0.00 ft Reference ~ SeøIi-~r~ ..... . .'. ..........' .....>. ............. .', ~iN...çO , AIIO~ MD TVD 'MD TVJ>. Ref ...... ~..... ~4ZITFQ-8S C8Iin& ~.·.Ateå DeViatioD Wlarnmg ft .ft ft ft ft ft, Øeg' .~ In' ft:. . .,ft, .Jt 10166.00 7861.64 10400.00 8917.13 37.52 32.98 176.42 171.02 1427.91 244.98 1265.88 Pass 10186.00 7874.75 10450.00 8958.82 37.58 33.18 175.67 172.09 1442.21 245.71 1280.13 Pass 10200.00 7883.74 10500.00 9000.77 37.58 33.38 175.29 172.34 1457.93 246.30 1295.39 Pass 10236.00 7906.43 10550.00 9042.67 37.56 33.57 174.53 173.17 1474.42 247.00 1311.94 Pass 10236.00 7906.43 10600.00 9084.22 37.56 33.80 174.33 172.97 1491.21 247.58 1327.86 Pass 10272.32 7928.65 10650.00 9125.46 37.53 34.01 173.53 173.63 1508.13 248.27 1344.88 Pass 10300.00 7945.10 10700.00 9166.46 37.51 34.22 172.83 174.01 1525.71 248.93 1362.31 Pass 10300.00 7945.10 10750.00 9207.20 37.51 34.48 172.55 173.72 1543.86 249.51 1379.47 Pass 10337.10 7966.49 10800.00 9247.69 37.46 34.67 171.64 174.22 1562.07 250.05 1398.00 Pass .. ) ) Sperry-SUD Anticollision Report Site: End SDI Well: 3-29/J-32 Wellpatb: 3-29/J-32 V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 10166.00 7861.64 8525.56 37.52 38.45 145.65 140.25 9.625 1139.05 261.48 922.47 Pass 10186.00 7874.75 10500.00 8562.27 37.58 38.54 145.04 141.46 9.625 1146.20 261.85 929.65 Pass 10213.00 7892.01 10550.00 8599.15 37.57 38.66 144.62 142.25 9.625 1154.89 262.24 938.41 Pass 10236.00 7906.43 10600.00 8636.13 37.56 38.80 144.26 142.90 9.625 1164.84 262.62 948.31 Pass 10261.55 7922.14 10650.00 8673.11 37.54 38.96 143.86 143.54 9.625 1175.89 263.14 959.37 Pass 10300.00 7945.10 10700.00 8710.04 37.51 39.10 143.25 144.43 9.625 1188.16 263.62 972.05 Pass 10300.00 7945.10 10750.00 8746.99 37.51 39.35 143.24 144.42 9.625 1201.26 264.14 984.26 Pass 10332.40 7963.83 10800.00 8783.98 37.46 39.44 142.71 145.11 9.625 1215.55 264.43 999.18 Pass 10355.42 7976.76 10850.00 8820.96 37.43 39.60 142.31 145.56 9.625 1231.00 264.89 1014.74 Pass 10400.00 8000.95 10900.00 8857.86 37.37 39.60 141.55 146.39 9.625 1247.84 265.04 1032.94 Pass 10400.00 8000.95 10950.00 8894.83 37.37 39.87 141.50 146.35 9.625 1265.01 265.75 1049.07 Pass 10422.46 8012.69 11000.00 8931.72 37.33 40.03 141.08 146.71 9.625 1283.49 266.26 1067.75 Pass 10451.20 8027.32 11050.00 8968.59 37.32 40.20 140.77 146.92 9.625 1302.88 266.73 1087.15 Pass 10497.18 8050.61 11100.00 9005.40 37.39 40.53 140.71 146.86 9.625 1322.47 267.89 1105.76 Pass 10543.18 8073.91 11150.00 9042.11 37.47 40.84 140.65 146.80 9.625 1342.01 268.83 1124.43 Pass , 10589.15 8097.20 11200.00 9078.79 37.54 41.10 140.58 146.73 9.625 1361.62 269.85 1143.20 Pass 10635.02 8120.44 11250.00 9115.57 37.64 41.33 140.52 146.67 9.625 1381.44 270.58 1162.40 Pass 10680.76 8143.60 11300.00 9152.61 37.74 41.53 140.46 146.61 9.625 1401.60 271.47 1181.91 Pass 10726.37 8166.70 11350.00 9189.91 37.85 41.72 140.41 146.56 9.625 1422.06 272.17 1201.85 Pass 10771.82 8189.73 11400.00 9227.51 37.97 41.92 140.38 146.53 9.625 1442.88 273.12 1222.02 Pass 10817.12 8212.68 11450.00 9265.35 38.10 42.12 140.35 146.50 9.625 1464.02 273.86 1242.64 Pass 10862.32 8235.57 11500.00 9303.40 38.24 42.31 140.34 146.49 9.625 1485.40 274.87 1263.37 Pass 10907.45 8258.43 11550.00 9341.60 38.38 42.53 140.33 146.48 9.625 1506.92 275.95 1284.31 Pass 10952.54 8281.27 11600.00 9379.90 38.54 42.74 140.32 146.47 9.625 1528.52 277.07 1305.21 Pass 10997.56 8304.08 11650.00 9418.36 38.70 42.97 140.32 146.47 9.625 1550.29 278.20 1326.26 Pass 11042.53 8326.86 11700.00 9456.99 38.88 43.17 140.33 146.48 9.625 1572.13 279.58 1347.55 Pass Site: End SDI Well: 3-29/J-32 Rule Assigned: NOERRORS Wellpatb: Plan 3-29a1J-30 VO Inter-Site Error: 0.00 ft ···.11, .' ...~. ..~,.,'I' ".',,'" ...... '. ..... '~.I"".".""'.'.'... .~.i,.....'~'/""I',",",·",:.',·II,."I,"'IIII".'."II~"I' "~, ""'1,,1"'1 . " "'~""'"''i'''~''' .1· . 'ft '." 'i·"···· 'I"I"~' 'I':,· ..',"..' "1",' I·'ff'·'···· "1 ,.,., '.' . "1'1. "ft ,.,' "'. """""ft' ..,,: .... .:.'.' I"'" . .,,,.,...:,11,,,, . "CIQ""" I ',' ,..., ." . .." . ,""'.,""'., '1""".11"" }"'I',':\ I"" '1, ft"; ',1'" """'::.:;,,. If . . ."', I' '.,..,' 'n"" ".. ': '''.' ,'.'.:. ,'. """ ..", ' 1 0166.00 7861.64 1 0450.00 8525.56 37.52 38.45 145.65 140.25 9.625 1139.05 0.00 1139.05 Pass 1 0186.00 7874.75 10500.00 8562.27 37.58 38.54 145.04 141.46 9.625 1146.20 0.00 1146.20 Pass 10213.00 7892.01 10550.00 8599.15 37.57 38.66 144.62 142.25 9.625 1154.89 0.00 1154.89 Pass 10236.00 7906.43 10600.00 8636.13 37.56 38.80 144.26 142.90 9.625 1164.84 0.00 1164.84 Pass 10261.55 7922.14 10650.00 8673.11 37.54 38.96 143.86 143.54 9.625 1175.89 0.00 1175.89 Pass 10300.00 7945.10 10700.00 8710.04 37.51 39.10 143.25 144.43 9.625 1188.16 0.00 1188.16 Pass 10300.00 7945.10 10750.00 8746.99 37.51 39.35 143.24 144.42 9.625 1201.26 0.00 1201.25 Pass 10332.40 7963.83 10800.00 8783.98 37.46 39.44 142.71 145.11 9.625 1215.55 0.00 1215.54 Pass 10355.42 7976.76 10850.00 8820.96 37.43 39.60 142.31 145.56 9.625 1231.00 0.00 1231.00 Pass 10400.00 8000.95 10900.00 8857.86 37.37 39.60 141.55 146.39 9.625 1247.84 0.00 1247.84 Pass 10400.00 8000.95 10950.00 8894.83 37.37 39.87 141.50 146.35 9.625 1265.01 0.00 1265.01 Pass 10422.46 8012.69 11000.00 8931.72 37.33 40.03 141.08 146.71 9.625 1283.49 0.00 1283.49 Pass 10451.20 8027.32 11050.00 8968.59 37.32 40.20 140.77 146.92 9.625 1302.88 0.00 1302.88 Pass 10497.18 8050.61 11100.00 9005.40 37.39 40.53 140.71 146.86 9.625 1322.47 0.00 1322.47 Pass 10543.18 8073.91 11150.00 9042.11 37.47 40.84 140.65 146.80 9.625 1342.01 0.00 1342.01 Pass 10589.15 8097.20 11200.00 9078.79 37.54 41.10 140.58 146.73 9.625 1361.62 0.00 1361.62 Pass 10635.02 8120.44 11250.00 9115.57 37.64 41.33 140.52 146.67 9.625 1381.44 0.00 1381.44 Pass 10680.76 8143.60 11300.00 9152.61 37.74 41.53 140.46 146.61 9.625 1401.60 0.00 1401.60 Pass 10726.37 8166.70 11350.00 9189.91 37.85 41.72 140.41 146.56 9.625 1422.06 0.00 1422.06 Pass ) Sperry-Sun Anticollision Report - ) Site: End SDI Well: 3-29/J-32 Wellpath: Plan 3-29a/J-30 VO Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 10771.82 8189.73 11400.00 9227.51 37.97 41.92 140.38 146.53 9.625 1442.88 0.00 1442.88 Pass 10817.12 8212.68 11450.00 9265.35 38.10 42.12 140.35 146.50 9.625 1464.02 0.00 1464.02 Pass 10862.32 8235.57 115,00.00 9303.40 38.24 42.31 140.34 146.49 9.625 1485.40 0.00 1485.40 Pass 10907.45 8258.43 11550.00 9341.60 38.38 42.53 140.33 146.48 9.625 1506.92 0.00 1506.92 Pass 10952.54 8281.27 11600.00 9379.90 38.54 42.74 140.32 146.47 9.625 1528.52 0.00 1528.52 Pass 10997.56 8304.08 11650.00 9418.36 38.70 42.97 140.32 146.47 9.625 1550.29 0.00 1550.29 Pass 11042.53 8326.86 11700.00 9456.99 38.88 43.17 140.33 146.48 9.625 1572.13 0.00 1572.13 Pass Site: End SDI Well: 3-29/J-32 Rule Assigned: NOERRORS Wellpath: Plan 3-29A/K30 V1 Plan: 3~29a/K-30 wp03 V2 Inter-Site Error: 0.00 ft 10166.00 7861.64 10450.00 8522.21 37.52 38.07 145.69 140.29 8.500 1131.91 0.00 1131.91 Pass 10186.00 7874.75 10500.00 8555.37 37.58 38.00 145.13 141.55 8.500 1131.78 0.00 1131.78 Pass 10214.27 7892.81 10550.00 8587.41 37.57 37.95 144.76 142.44 8.500 1130.77 0.00 1130.77 Pass 10236.00 7906.43 10600.00 8618.28 37.56 37.92 144.50 143.13 8.500 1128.73 0.00 1128.73 Pass 10264.61 7923.99 10650.00 8647.91 37.54 37.88 144.16 143.96 8.500 1125.63 0.00 1125.63 Pass 10300.00 7945.10 10700.00 8676.25 37.51 37.81 143.74 144.92 8.500 1121.59 0.00 1121.59 Pass 10300.00 7945.10 10750.00 8703.25 37.51 37.90 143.89 145.07 8.500 1116.52 0.00 1116.52 Pass 10340.03 7968.15 10800.00 8728.86 37.45 37.82 143.42 146.11 8.500 1110.13 0.00 1110.13 Pass 10365.16 7982.15 10850.00 8753.02 37.42 37.83 143.20 146.81 8.500 1102.90 0.00 1102.90 Pass 10400.00 8000.95 10900.00 8775.69 37.37 37.79 142.84 147.69 8.500 1094.73 0.00 1094.73 Pass 10415.39 8009.03 10950.00 8796.83 37.34 37.87 142.82 148.20 8.500 1085.38 0.00 1085.38 Pass 10442.98 8023.16 11000.00 8816.52 37.31 37.91 142.69 148.84 8.500 1075.27 0.00 1075.27 Pass 10491.73 8047.85 11050.00 8835.92 37.38 38.08 142.95 149.10 8.500 1065.22 0.00 1065.21 Pass 10540.47 8072.54 11100.00 8855.31 37.46 38.24 143.21 149.36 8.500 1055.19 0.00 1055.18 Pass 10589.21 8097.23 11150.00 8874.71 37.54 38.44 143.48 149.63 8.500 1045.18 0.00 1045.18 Pass I 10637.96 8121.92 11200.00 8894.11 37.64 38.63 143.75 149.90 8.500 1035.19 0.00 1035.19 Pass 10686.70 8146.61 11250.00 8913.51 37.75 38.85 144.03 150.18 8.500 1025.23 0.00 1025.23 Pass 10735.44 8171.30 11300.00 8932.91 37.87 39.07 144.31 150.46 8.500 1015.30 0.00 1015.30 Pass 10784.19 8195.99 11350.00 8952.30 38.00 39.31 144.60 150.75 8.500 1005.39 0.00 1005.38 Pass 10832.93 8220.68 1140å.oo 8971.70 38.15 39.56 144.89 151.04 8.500 995.50 0.00 995.50 Pass 10881.67 8245.37 11450.00 8991.10 38.30 39.83 145.19 151.34 8.500 985.64 0.00 985.64 Pass 10930.42 8270.07 11500.00 9010.50 38.46 40.10 145.50 151.65 8.500 975.81 0.00 975.81 Pass 10979.16 8294.76 11550.00 9029.90 38.64 40.39 145.81 151.96 8.500 966.01 0.00 966.01 Pass 11027.90 8319.45 11600.00 9049.29 38.82 40.68 146.13 152.28 8.500 956.24 0.00 956.24 Pass 11076.65 8344.14 11650.00 9068.69 39.02 40.99 146.45 152.60 8.500 946.49 0.00 946.49 Pass 11125.39 8368.83 11700.00 9088.09 39.23 41.31 146.79 152.94 8.500 936.78 0.00 936.78 Pass 11174.13 8393.52 11750.00 9107.49 39.44 41.64 147.12 153.27 8.500 927.10 0.00 927.10 Pass 11222.88 8418.21 11800.00 9126.89 39.67 41.98 147.47 153.62 8.500 917.46 0.00 917.45 Pass 11271.62 8442.90 11850.00 9146.28 39.90 42.34 147.82 153.97 8.500 907.84 0.00 907.84 Pass 11320.36 8467.59 11900.00 9165.68 40.15 42.69 148.19 154.34 8.500 898.27 0.00 898.27 Pass 11369.11 8492.28 11950.00 9185.08 40.40 43.07 148.55 154.70 8.500 888.73 0.00 888.73 Pass 11417.85 8516.97 12000.00 9204.48 40.67 43.44 148.93 155.08 8.500 879.22 0.00 879.22 Pass 11466.59 8541.66 12050.00 9223.87 40.94 43.84 149.32 155.47 8.500 869.76 0.00 869.76 Pass 11515.34 8566.35 12100.00 9243.27 41.22 44.23 149.71 155.86 8.500 860.34 0.00 860.33 Pass 11564.08 8591.04 12150.00 9262.67 41.51 44.65 150.11 156.26 8.500 850.95 0.00 850.95 Pass 11629.10 8624.28 12200.00 9282.07 41.84 45.07 150.57 156.62 8.500 841.45 0.00 841.45 Pass 11722.55 8675.49 12250.00 9301.47 42.24 45.52 151.06 156.83 8.500 829.89 0.00 829.89 Pass · ) Sperry-Sun Anticollision Report ) Site: End SDI Well: 3-29/J-32 Wellpath: Plan 3-29A/K3O V1 Plan: 3-29a/K-3O wp03 V2 RuØ~pHd: NOERRORS Inter-8ite Error: 0.00 ft 11813.72 8729.66 11902.15 8786.00 11987.47 8843.77 12400.00 12069.40 8902.24 .12450.00 9379.06 43.75 47.35 152.51 156.95 8.500 759.32 0.00 759.32 Pass 12147.76 8960.77 12500.00 9398.46 44.08 47.83 152.75 156.80 8.500 736.16 0.00 736.16 Pass 12222.44 9018.80 12550.00 ~417.85 44.38 48.30 152.94 156.59 8.500 711.06 0.00 711.06 Pass 12285.28 9069.21 12600.00 9437.25 44.63 48.78 153.06 156.41 8.500 684.22 0.00 684.22 Pass 12327.18 9103.13 12650.00 9456.65 44.82 49.25 153.12 156.46 8.500 656.94 0.00 656.94 Pass 12369.08 9137.06 12700.00 9476.05 45.02 49.73 153.18 156.52 8.500 629.66 0.00 629.66 Pass 12410.98 9170.98 12750.00 9495.45 45.21 50.22 153.24 156.59 8.500 602.39 0.00 602.39 Pass 12452.88 9204.90 12800.00 9514.84 45.42 50.71 153.31 156.66 8.500 575.11 0.00 575.11 Pass 12494.78 9238.82 12850.00 9534.24 45.62 51.21 153.39 156.74 8.500 547.84 0.00 547.84 Pass 12536.68 9272.75 12900.00 9553.64 45.82 51.72 153.48 156.82 8.500 520.57 0.00 520.57 Pass 12578.59 9306.68 12950.00 9573.06 46.03 52.21 153.58 156.92 8.500 493.32 0.00 493.32 Pass 12620.76 9340.82 13000.00 9592.94 46.24 52.65 153.70 157.04 8.500 466.47 0.00 466.47 Pass 12663.26 9375.23 13050.00 9613.41 46.46 53.03 153.86 157.20 8.500 440.17 0.00 440.16 Pass 12706.09 9409.90 13100.00 9634.47 46.67 53.41 154.06 157.40 8.500 414.41 0.00 414.41 Pass 12749.23 9444.83 13150.00 9656.13 46.90 53.80 154.31 157.66 8.500 389.20 0.00 389.20 Pass 12792.69 9480.02 13200.00 9678.38 47.12 54.18 154.62 157.97 8.500 364.56 0.00 364.56 Pass 12836.45 9515.45 13250.00 9701.21 47.35 54.58 155.01 158.35 8.500 340.49 0.00 340.49 Pass 12880.51 9551.12 13300.00 9724.62 47.59 54.97 155.47 158.82 8.500 317.01 0.00 317.00 Pass 12924.86 9587.02 13350.00 9748.61 47.82 55.37 156.04 159.39 8.500 294.11 0.00 294.11 Pass 12969.49 9623.15 1340Q.00 9773.17 48.06 55.77 156.74 160.08 8.500 271.83 0.00 271.83 Pass 13015.65 9660.60 13450.00 9798.29 48.27 56.18 157.57 160.92 8.500 250.08 0.00 250.07 Pass 13062.04 9698.38 13500.00 9823.98 48.46 56.59 158.58 161.93 8.500 228.71 0.00 228.71 Pass 13108.47 9736.36 13Sq.Q.00 9850.23 48.64 57.00 159.79 163.15 8.500 207.77 0.00 207.76 Pass 13155.08 9774.65 13600.00 9877.35 48.83 57.40 161.28 164.65 8.500 187.60 0.00 187.60 Pass 13202.14 9813.48 13650.00 9905.89 49.02 57.80 163.16 166.53 8.500 168.91 0.00 168.91 Pass 13249.63 9852.82 13700.00 9935.86 49.21 58.20 165.51 168.88 8.500 151.80 0.00 151.80 Pass 13297.52 9892.66 13750.00 9967.20 49.40 58.58 168.41 171.79 8.500 136.37 0.00 136.37 Pass 13345.77 9932.97 13800.00 9999.88 49.60 58.96 171.96 175.34 8.500 122.74 0.00 122.74 Pass 13394.34 9973.71 13850.00 10033.86 49.79 59.33 176.22 179.60 8.500 111.06 0.00 111.06 Pass 13443.20 10014.87 13~PQ·00 10069.10 49.99 59.68 181.22 184.60 8.500 101.46 0.00 101.45 Pass 13492.33 10056.43 1395Ö.00 10105.56 50.19 60.02 186.86 190.24 8.500 94.07 0.00 94.07 Pass 13541.69 10098.34 14000.00 10143.19 50.39 60.35 192.93 196.31 8.500 88.96 0.00 88.96 Pass 13591.23 10140.58 14050.00 10181.88 50.59 60.67 199.14 202.52 8.500 86.01 0.00 86.01 Pass 13640.77 10182.98 14100.00 10220.89 50.79 60.98 205.58 208.96 8.500 84.24 0.00 84.24 Pass 13690.26 10225.52 14150.00 10260.03 50.99 61.29 212.23 215.61 8.500 83.46 0.00 83.46 Pass 13720.82 10251.85 14180.88 10284.28 51.12 61.48 216.38 219.76 8.500 83.49 0.00 83.49 Pass Site: End SDI Well: 3-3111<-32 Rule ~gned: Major Risk Wellpath: 3-3111<-32 V6 Inter-8ite Error: 0.00 ft Refereaœ Offset Semi-Maùor Am ar-Qr.No-Go Allowable MD TVD Mo TVD Ref 0Ifset 'Ø'Q+AZl1TØ-BS ..C8IIiDc. .~... ~A.rea .Deviation Warning It ft ft ft ft ftdeg . deg· in ft It It 10166.00 7861.64 9750.00 7481.63 37.52 69.90 67.59 62.20 1089.20 358.71 768.55 Pass 10200.00 7883.74 9800.00 7518.83 37.58 70.01 67.21 64.26 1091.52 358.79 768.87 Pass 10236.00 7906.43 9850.00 7556.11 37.56 70.16 67.19 65.82 1094.70 359.04 770.09 Pass 10275.26 7930.42 9900.00 7593.48 37.53 70.26 67.24 67.45 1098.77 359.50 771.91 Pass 10312.58 7952.44 9950.00 7630.88 37.49 70.32 67.38 69.04 1103.38 359.57 774.39 Pass ') Sperry-SUD Anticollision Report ) Site: End SDI Well: 3-31/K-32 Wellpath: 3-3111<-32 V6 Rule Assigned: Major Risk Inter-8ite Error: 0.00 ft 7705.71 7743.17 7781.00 7819.25 10549.74 8077.23 10250.00 7857.95 37.48 71.25 70.97 77.12 1140.56 362.14 796.12 Pass 10594.64 8099.98 10300.00 7896.99 37.55 71.61 72.01 78.16 1147.52 363.44 800.11 Pass 10639.42 8122.66 10359·00 79¡a6.11 37.65 71.97 73.05 79.20 1155.02 364.56 804.89 Pass 10684.07 8145.28 10400.00 7975.31 37.75 72.33 74.09 80.24 1163.09 365.92 810.09 Pass 10728.59 8167.83 10450.00 8014.54 37.86 72.70 75.12 81.27 1171.79 367.09 816.19 Pass 10773.06 8190.36 10500.00 8053.83 37.97 73.05 76.14 82.29 1180.92 368.50 822.55 Pass 10817.55 8212.89 10550.00 8093.17 38.10 73.41 77.15 83.30 1190.25 369.70 829.42 Pass 10862.14 8235.48 10600.00 8132.55 38.24 73.77 78.14 84.29 1199.59 371.18 836.12 Pass 10906.91 8258.16 10650.00 8171.94 38.38 74.13 79.10 85.25 1208.75 372.44 842.95 Pass 10951.60 8280.80 10700.00 8211.36 38.54 74.49 80.06 86.21 1218.38 373.97 850.06 Pass 10996.03 8303.30 10750.00 8250.84 38.70 74.85 81.01 87.16 1228.98 375.51 858.21 Pass 11040.33 8325.74 10800.00 8290.38 38.87 75.20 81.96 88.11 1240.15 376.84 867.22 Pass 11084.57 8348.15 10850.00 8330.01 39.05 75.55 82.89 89.04 1251.66 378.40 876.41 Pass 11128.81 8370.56 10900.00 8369.66 39.24 75.90 83.80 89.95 1263.43 379.76 886.15 Pass 11173.08 8392.99 10950.00 8409.32 39.44 76.25 84.70 90.85 1275.42 381.36 895.94 Pass 11217.33 8415.40 11000.00 8449.13 39.64 76.60 85.59 91.74 1287.49 382.77 906.09 Pass 11261.55 8437.80 11O&Q.00 8489.12 39.86 76.95 86.48 92.63 1299.60 384.44 916.08 Pass 11305.73 8460.18 11100.00 8529.35 40.07 77.30 87.36 93.51 1311.64 385.88 926.30 Pass 11349.81 8482.51 1115q.00 8569.84 40.30 77.64 88.24 94.39 1323.67 387.57 936.33 Pass 11393.59 8504.68 112Qã.00 8610.71 40.53 77.98 89.13 95.28 1336.12 389.24 946.87 Pass I 11437.09 8526.72 11250.00 8651.92 40.77 78.31 90.03 96.18 1348.92 390.70 958.04 Pass 11480.55 8548.73 11300.00 8693.43 41,02 78.64 90.93 97.08 1361.46 392.39 968.81 Pass 11523.95 8570.71 11350.00 8735.22 41.27 78.96 91.83 97.98 1373.84 393.87 979.69 Pass 11567.12 8592.58 11400.00 8777.26 41.53 79.28 92.74 98.89 1386.59 395.58 990.81 Pass 11613.77 8616.30 11450.00 8819.57 41.78 79.66 93.66 99.76 1399.74 397.22 1002.47 Pass 11668.74 8645.45 11500.00 8862.23 42.01 80.16 94.61 100.54 1412.98 399.43 1013.66 Pass 11725.43 8677.14 11550..00 8905.20 42.25 80.67 95.50 101.25 1426.09 401.47 1024.87 Pass 11783.95 8711.52 11600.00 8948.47 42.50 81.19 96.34 101.90 1438.83 403.74 1035.44 Pass 11844.34 8748.75 1165&.00 8991.94 42.77 81.70 97.12 102.47 1451.28 406.21 1045.66 Pass 11906.63 8788.95 117bQ,.00 9035.46 43.04 82.23 97.83 102.95 1463.54 408.72 1055.64 Pass 11970.40 8831.96 11750.00 9079.36 43.32 82.74 98.50 103.37 1475.74 411.03 1065.60 Pass 12035.29 8877.55 11800.00 9123.95 43.60 83.24 99.14 103.73 1488.05 413.46 1075.66 Pass 12101.49 8925.91 11850.00 9169.35 43.89 83.72 99.78 104.06 1499.62 415.80 1085.06 Pass 12168.96 8977.03 11900.00 9215.60 44.17 84.18 100.42 104.36 1510.25 417.93 1093.64 Pass 12237.81 9031.00 11950.00 9262.52 44.44 84.61 101.04 104.60 1520.10 420.04 1101.55 Pass 12296.39 9078.21 12000.00 9309.96 44.68 84.91 101.62 104.96 1529.21 421.66 1109.24 Pass 12343.24 9116.14 12050.00 9357.75 44.90 85.09 102.18 105.52 1538.25 422.93 1117.39 Pass 12389.83 9153.86 12100.00 9405.78 45.11 85.26 102.76 106.10 1547.41 424.10 1125.73 Pass 12436.08 9191.30 12150.00 9454.08 45.34 85.41 103.37 106.71 1556.84 425.32 1134.43 Pass 12481.94 9228.43 12200.00 9502.62 45.56 85.56 104.00 107.35 1566.62 426.42 1143.57 Pass WELL PERMIT CHECKLIST CÖMPANY 15fJ X WELL NAMED1"c., :) -/7£ft- 3ð PROGRAM: Exp _ Dev ~ Redrll L Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL z ZOJOd INIT CLASS /)'P")'/ ) -o~ I) GEOL AREA ? t /) UNIT# /0 y. ç ~ ON/OFF SHORE ..s1!0 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ? N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Welllocated in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. W ell located proper distance from other wells. . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 'lL J.. J.-')~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ~Z- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ ~.Y ~..;CJ I (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ,/' N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . -¥---f'r 16. Surface casing protects all known USDWs. . . . . . . -¥--N- 17. CMT vol adequate to circulate on conductor & surf csg. . . . Y N NIIt- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . Y N 19. CMT will cover all known productive horizons. . . . . . . . . . &íN 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N D 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N I "1 ~ I ç . 22. If a re-drill, has a 10-403 fo.r abandonment been approved. . . N îi I U'LI t) L . 23. Adequate wellbore separation proposed.. .... . . . . . . . . . N. 24. If diverter required, does It meet regulations. .. . . . . . . . ~y N N IA- . 25. Drilling fluid program schematic & equip list adequate. . . . . . N IVl"I..-,i fJ1 IJ 1<' ,š PP J 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N. P' "I ~ APPR DATE ~7.. BOPE press rating appropriate; test to 4500 psig. él2. N,AIl s s·L? 'T 2- pc, t· . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 0') N \dlAr ,I.. ..¡""or ~ ","'\.1 ..."- v";) 29. Work. will occur without operation shutdown. . . . . . . . . . ., N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . . N 31. Mechanical condition of wells within AOR verified. . . . . . . . .-¥-# ¡JIlt- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . if 33. Data presented on potential overpressure zones. . . . . . . . Y 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N· )V..;4 ~ 35. Seabed condition survey (if off-shore). . ; . . .. ...... 36. Contact namelphone for weekly progress reports. ...... Y . N APPR DATE (Service Well Only) GEOLOGY APPR DATE /þ /z-)¡~4.?" . (ËXploratory Only) ( ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/I nstructions: RP~ TEM JDH JBR COT DTS 01 J <..1{ CZJ V'" MJW MLB 0V-ZY03 SFD WGA Rev: 10/15/02 - G:\geology\perm its\checklist.doc p054971 DATE 11/18/02 CHECK NO. P054971 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET H 11/18/02 INV# CKll1402L PERMIT TO DRILL FEE <)-II[\k-30 REC:IVED DEC 17 2002 1\1 ka Ou & Gas Cons. Commission twas Anclorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT POBOX 196612 ANCHORAGJ;:. AK995J9-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 """'412 No. P 054971 CONSOLIDATED COMMERCIAL ACCOUNT .-:!!?::;:- -{::_-::~:- -;:=-:;:_~> -.;: - =.; ·····ALASKA QILi& GAS CbN SE RVÃT ION < .- __ ._n COMMISS;PO~ 333-w1r;rtlA~þ1UE SUITE 100 ANCHO:R~GE ,~K 99501 ----" -- -.-. ~ - .-. p- . Ð. ,:.:é........lfJ. tf.tÌ. ·.It.w. .. ..4". .... " '¡~.1. ;(j,...~...;.~........ .·.f.~l.;: ,,/::~ - F-- -. -..:d \U.. tft~ __ -:_: ~IIJI rJ - -_ -~u' ~hh PAY DATE AMOUNT TO THE ORDER OF NOV 18,2002 ****$100.00**** NOT VALID AFTER 120 DAYS UIO 5... q ? ~ UI I: 0 ~ ~ 20 :I B q 51: 0 ¡ 2 ? B ~ bU· ~~~::::~~::"\:::~:'::':':~~\:::~:.]i;~2: :".;~..}:~:,::;i.;~:::; ~\:~; j:::~.?~ . ..~...:;¡ .... ...................N............,..... .......:. . -.:.... 0, _ -'0 0 A. ..~.~..\ ::.... :..... :'.. ::. _... .. ..,;'.~ ~ ~, ....¡. ___'''''f''Z> '.: ¿·LL.··{.::'\'.. :·~:~:\f;?/<:·;:~>~~:~~;:\~;:\}:~¿~' ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. .) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding information, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. f)O(}. -ô 1-17- ) ) } I 'foe{, Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 17 15:50:01 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/17 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. . . . . . . . . . . . . . . . . . . . .03/12/17 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2298594000 J. PITCHER E. VAUGHN MWD RUN 2 MW2298594000 P. ORTH E. VAUGHN MWD RUN 3 MW2298594000 J. PITCHER E. VAUGHN ~~ c0LQ ~~9-V~ ~~ 3-17E/K-30 Reprocess 500292194605 BP Exploration Inc. Sperry Sun 17-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW2298594000 J. PITCHER E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 llN 17E 2524 799 .00 36.85 15.75 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 8.500 8.500 CASING SIZE (IN) 9.625 9.625 9.625 DRILLERS DEPTH (FT) 9976.0 9976.0 9976.0 RECEIVED # REMARKS: 1. THIS FILE SUPERCEDES ALL PREVIOUS DEC 22 2003 Alaska Oil & Gas Cons. CommiS8i0n Anchorage Ì\~~ì""''''-~ ) ) VERSIONS/CORRECTIONS, IS DATED 12/17/03, AND CONTAINS COMPENSATED THERMAL NEUTRON LWD DATA THAT IS REPROCESSED WITH UPDATED ALGORITHMS. 2. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. MWD RUNS 1 -3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 4 COMPRISED DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND PRESSURE WHILE DRILLING (PWD) . 6. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER DEPTH CONTROL LOG OF 25 FEBRUARY 2003, PER THE 6/11/2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL 3-17E/K-30 WITH API#: 50-029-21946-05. THIS WELL REACHED A TOTAL DEPTH (TO) OF 14048'MD / 10403'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . ACAL = SMOOTHED ACOUSTIC CALIPER (MERGED FILE:LESSER OF ACAL AND SLD CALIPER) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: COMBINED ACAL/SLD CALIPERS MUD WEIGHT: 10.4 PPG MUD FILTRATE SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 16800 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/17 Maximum Physical Record..65535 ') ) File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shi fted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NPHI NCNT FCNT CALA DRHO RHOB PEF FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9239.5 9964.0 12827.0 12827.0 12827.0 12842.5 12843.5 12843.5 12843.5 12872.5 12872.5 12872.5 12872.5 12872.5 STOP DEPTH 14020.0 14060.0 13964.0 13964.0 13964.0 13965.5 13977.5 13977.5 13977.5 14010.0 14010.0 14010.0 14010.0 14010.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9239.5 9241. 5 9250.0 9262.0 9282.5 9287.0 9293.0 9296.5 9956.5 9966.0 9998.0 10049.0 10052.0 10980.5 11492.5 11799.0 11829.0 11872.5 11921.5 12071.5 12125.0 12134.0 12288.5 12294.0 12303.0 12322.5 12326.5 12342.0 12371. 0 12379.5 12382.5 12399.5 12409.5 12420.0 12426.0 12447.0 12460.5 12463.5 12471.0 12476.0 12492.0 12497.5 12502.0 12506.0 GR 9243.0 9245.0 9252.5 9262.5 9285.5 9291.0 9297.0 9299.0 9964.0 9974.0 10003.0 10055.5 10058.0 10977.5 11487.0 11789.5 11820.5 11865.0 11912.5 12060.5 12112.5 12122.5 12277.0 12283.0 12290.0 12311.0 12316.0 12331. 5 12360.5 12368.0 12371. 0 12389.0 12399.0 12407.0 12413.5 12435.0 12450.0 12453.0 12458.5 12464.0 12480.0 12487.0 12491.0 12495.5 ') ) 12509.5 12497.5 12519.0 12507.5 12528.0 12517.5 12531. 0 12520.5 12545.5 12534.5 12561. 5 12550.5 12579.5 12568.0 12586.0 12575.5 12597.5 12588.0 12610.0 12599.5 12616.5 12606.5 12621.5 12612.5 12632.0 12622.0 12641.0 12630.0 12648.0 12637.0 12650.5 12640.5 12655.5 12646.5 12661. 0 12650.5 12663.5 12653.0 12676.0 12665.5 12689.0 12679.5 12694.5 12686.5 12709.0 12699.0 12713.0 12702.0 12720.5 12709.5 12730.0 12719.0 12738.5 12728.5 12764.5 12753.5 12774.5 12763.0 12806.5 12795.5 12814.0 12803.0 12816.5 12805.5 12832.0 12820.5 12838.5 12826.0 12843.0 12832.0 12853.5 12844.5 12867.5 12860.5 12879.5 12872.0 12915.5 12905.5 12927.5 12915.5 12936.5 12923.5 12955.5 12943.0 12965.0 12953.0 12978.5 12966.5 12981.5 12969.5 12983.5 12971.0 13007.0 12994.0 13017.0 13003.5 13029.5 13015.0 13035.5 13022.0 13050.0 13037.0 13082.0 13068.5 13085.0 13071. 5 13094.0 13080.0 13097.0 13082.5 13098.5 13084.5 13105.0 13091.0 13109.0 13094.5 13112.5 13097.0 13116.0 13100.5 13126.0 13111.0 13130.0 13114.5 13140.0 13124.5 13142.5 13126.5 13161.5 13146.0 13164.0 13148.0 13166.0 13150.0 13169.5 13154.0 13178.5 13164.0 13190.0 13175.5 13195.0 13180.5 13203.5 13189.5 13207.0 13192.5 13213.0 13198.5 13215.0 13199.5 13220.0 13204.0 ) ) 13223.5 13232.5 13235.5 13240.5 13246.0 13256.0 13270.5 13276.0 13280.5 13286.5 13291.0 13295.5 13298.0 13307.0 13313.5 13315.5 13318.5 13320.5 13324.0 13329.0 13334.5 13352.5 13413.5 13443.0 13468.5 13477.0 13488.0 13492.0 13500.0 13502.5 13512.5 13526.5 13566.5 13574.5 13618.0 13649.0 13651. 0 13655.0 13660.0 13667.0 13672.0 13674.5 13677.0 13684.0 13690.5 13691.5 13694.5 13741.5 13753.5 13785.0 13831. 5 13839.5 13843.0 13846.0 13855.5 13883.0 13888.0 13902.0 13909.0 13922.5 13929.5 13935.5 13938.5 13946.0 13952.5 13978.5 13983.0 13985.5 13993.0 13997.5 14000.0 14062.5 $ 13207.5 13216.0 13219.0 13223.5 13229.5 13239.5 13255.0 13259.5 13263.5 13270.5 13275.5 13280.0 13281. 5 13290.5 13297.0 13298.5 13302.0 13303.5 13307.5 13313.5 13318.5 13335.5 13395.5 13425.5 13452.0 13460.0 13473.0 13477.0 13485.0 13486.5 13497.5 13511. 0 13550.5 13558.5 13602.5 13633.0 13634.5 13638.5 13644.0 13651. 0 13655.5 13658.0 13660.0 13667.0 13673.5 13675.0 13678.0 13724.5 13737.5 13768.5 13815.5 13823.0 13826.5 13829.5 13839.0 13867.0 13871.5 13885.5 13891.5 13905.0 13911.5 13917 . 5 13921.5 13926.5 13932.0 13957.5 13963.5 13968.5 13975.5 13978.5 13980.0 14042.5 # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD MWD $ # REMARKS: ) ) 1 2 3 4 9900.0 10614.0 12072.0 12922.0 10614.0 12072.0 12922.0 14048.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction............ .... . Down Optical log depth units. ......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CALA MWD Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN IN Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 56 Nsam Rep 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9239.5 14060 11649.8 9642 9239.5 14060 ROP MWD FT/H 0.04 330.46 75.728 8193 9964 14060 GR MWD API 13.52 397.4 112.877 8303 9239.5 14020 RPX MWD OHMM 1.15 2000 281.135 2276 12872.5 14010 RPS MWD OHMM 1.12 2000 219.646 2276 12872.5 14010 RPM MWD OHMM 0.9 2000 154.631 2276 12872.5 14010 RPD MWD OHMM 1. 01 2000 277.079 2276 12872.5 14010 FET MWD HOUR 0.46 36.8543 2.93074 2276 12872.5 14010 NPHI MWD PU-S 12.36 89.75 31.7869 2275 12827 13964 FCNT MWD CNTS 484 3199 1364.88 2275 12827 13964 NCNT MWD CNTS 103227 175435 138843 2275 12827 13964 RHOB MWD G/CM 1. 209 2.912 2.34676 2269 12843.5 13977.5 DRHO MWD G/CM -0.172 0.316 0.0375778 2269 12843.5 13977.5 PEF MWD BARN 1.11 8.02 3.40881 2269 12843.5 13977.5 CALA MWD IN 8.25 10.4519 8.55636 2247 12842.5 13965.5 First Reading For Entire File......... .9239.5 Last Reading For Entire File.......... .14060 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/17 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...... .03/12/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 9900.0 9976.5 STOP DEPTH 10582.5 10614.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENS ITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ .II "IT Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction....... ....... ...Down Optical log depth units...... .....Feet 05-MAR-03 Insite 6.02 Memory 10614.0 9900.0 10614.0 47.4 60.7 TOOL NUMBER 155789 134758 8.500 9976.0 GEM 9.70 46.0 9.2 400 4.1 .000 .000 .000 .000 .0 134.6 .0 .0 ) ) Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units..................... . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWDOI0 GR MWDOI0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9900 10614 10257 1429 9900 10614 ROP MWDOI0 FT/H 1. 07 269.66 50.3014 1276 9976.5 10614 GR MWDOI0 API 43.1 115.55 85.8777 1366 9900 10582.5 First Reading For Entire File......... .9900 Last Reading For Entire File.......... .10614 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/17 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...... .03/12/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10571. 0 10572.5 STOP DEPTH 12072.0 12029.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 07-MAR-03 Insite 6.02 Memory 12072.0 10614.0 12072.0 53.7 64.2 # TOOL STRING (TOP TO BOTTOM) ) VENDOR TOOL CODE DGR EWR4 $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point..... ....... ..Undefined Frame Spacing............ ....... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 TOOL NUMBER 155789 134758 8.500 9976.0 GEM 9.70 42.0 9.5 300 4.6 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 10571 0.22 72 .17 Max 12072 288.9 128.9 First Reading For Entire File......... .10571 Last Reading For Entire File.......... .12072 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .03/12/17 Maximum Physical Record. .65535 File Type................ LO Next File Name.. ........ .STSLIB.004 Physical EOF Mean 11321.5 101.638 103.545 Nsam 3003 3003 2915 ) .0 149.0 .0 .0 First Reading 10571 10571 10572.5 Last Reading 12072 12072 12029.5 ) File Header Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/17 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name. ..... .STSLIB.003 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 12030.0 12072.5 STOP DEPTH 12886.0 12922.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction....... ... ...... . Down Optical log depth units... ....... .Feet 09-MAR-03 Insite 6.02 Memory 12922.0 12072.0 12922.0 31.8 52.5 TOOL NUMBER 155789 134758 8.500 9976.0 GEM 10.40 45.0 9.5 250 2.8 .000 .000 .000 .000 .0 156.0 .0 .0 ) Data Reference Point........ ..... .Undefined Frame Spacing....... ............. .60 .1IN Max frames per record............ .Undefined Absent value........ ............. .-999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API Min 12030 0.72 53.57 Max 12922 318.1 272.28 Mean 12476 34.2727 143.562 First Reading For Entire File.. ....... .12030 Last Reading For Entire File.. ........ .12922 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/12/17 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. ..... .03/12/17 Maximum Physical Record..65535 File Type............. ...LO Previous File Name.. .....STSLIB.004 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI CALA PEF RHOB DRHO FET RPD RPM RPS RPX GR ROP $ 5 Nsam 1785 1700 1713 ) First Reading 12030 12072.5 12030 Last Reading 12922 12922 12886 header data for each bit run in separate files. 4 .5000 # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 12824.5 12824.5 12824.5 12838.0 12838.0 12838.0 12838.0 12871. 0 12871.0 12871. 0 12871.0 12871. 0 12885.0 12922.5 STOP DEPTH 13949.0 13949.0 13949.0 13951.5 13962.0 13962.0 13962.0 13995.5 13995.5 13995.5 13995.5 13995.5 14005.5 14048.0 12-MAR-03 ) SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # 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..................O Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999.25 Depth Units....................... Datum Specification Block sub-type. ..0 ) Insite 6.02 Memory 14048.0 12922.0 14048.0 31. 3 34.9 TOOL NUMBER 155789 134758 120993 179954 8.500 9976.0 GEM 10.40 40.0 9.5 300 2.6 2.500 1.164 2.300 3.250 80.0 179.6 80.0 80.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 CALA MWD040 IN 4 1 68 56 15 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12824.5 14048 13436.3 2448 12824.5 14048 ROP MWD040 FT/H 0.04 330.46 85.9668 2252 12922.5 14048 GR MWD040 API 13.52 397.4 119.364 2242 12885 14005.5 RPX MWD040 OHMM 1.15 2000 285.392 2250 12871 13995.5 RPS MWD040 OHMM 1.12 2000 224.458 2250 12871 13995.5 RPM MWD040 OHMM 0.9 2000 158.205 2250 12871 13995.5 RPD MWD040 OHMM 1. 01 2000 282.831 2250 12871 13995.5 FET MWD040 HOUR 0.46 36.8543 2.78035 2250 12871 13995.5 NPHI MWD040 PU-S 12.36 89.75 31.7339 2250 12824.5 13949 FCNT MWD040 CNTS 484 3199 1369.57 2250 12824.5 13949 NCNT MWD040 CNTS 103227 175435 138961 2250 12824.5 13949 RHOB MWD040 G/CM 1. 209 2.912 2.3462 2249 12838 13962 DRHO MWD040 G/CM -0.172 0.316 0.0374362 2249 12838 13962 PEF MWD040 BARN 1.11 8.02 3.40778 2249 12838 13962 CALA MWD040 IN 8.25 10.4519 8.55594 2228 12838 13951.5 First Reading For Entire File.... .... ..12824.5 Last Reading For Entire File..... ..... .14048 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/12/17 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File