The URL can be used to link to this page

Home My WebLink About204-224 · . Image Project Well History File Cover Page XHVlE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q 4= - cQ. ~ W- Well History File Identifier Organizing (done) o Two-sided 1111/11111111111111 o Rescan Needed "11111111111" 1111 RES CAN ~olor Items: ~reYSCale Items: \ ~o..f" o Poor Quality Originals: DIGITAL DATA ~skettes, No. \ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date SI3/~7 o Other:: BY: ~ 151 tl1P 1111111111111111111 Project Proofing BY: ~ Date5!a/07 151 'mP Scanning Preparation BY: J + ~ ~ = TOTAL PAGES (Count does not include cover sheet) 151 Production Scanning Stage 1 Page Count from Scanned File: S:3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: CMa9 Date: 5/3 J 07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 "III NO 151 Yl1 P NO BY: Maria Date: 151 11111111111111 /111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 111I1 BY: Maria Date: 151 Comments about this file: Quality Checked 111111111I111111111 10/6/2005 Well History File Cover Page.doc ~ , bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14 2009 ~ T' ~`~' f~y ~' ~~~~~ ~ ~:~U.` ti , ~ ~ ~~~~~~. ~~C~1~~1~l~L~ Mr. Tom Maunder OCT 0 5 20Q9 Alaska Oil and Gas Conservation Commission p~k~ Qii & Gas Cons. Ge~r~r-i~~~an 333 West 7~h Avenue Anchora~e Anchorage, Alaska 99501 ~~`a~ Subject: Corrosion Inhibitor Treatments of GPB Z-Pad ,~... ~(~r j Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger ~ ~ BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Finai top of cement Cement top off date Corrosion inhibitor Corrosion inhibitorl sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/2M2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/2M2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-06 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870t00 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670t00 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 500292t8440200 NA 0.2 NA t.70 7/26/2009 Z-15 1880880 500292t8490000 NA 0.2 NA t.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50~29219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 5~29218710000 NA 0.3 NA 3.40 7/26/2009 Z-32BL1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 5002921895010o NA 0.5 NA 3.40 8/S/2009 Z-35 1980930 50029228840000 NA 1.3 NA 1 t.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 5002923t820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 5002923380000o NA surface NA • ~.e... '• ~ o~~o~~zoos DO NOT PLACE Cl µ. ri.:~ ~.-- ANY NEW MATERfAL UNDER THIS PAGE F:1LaserFic~iC`vrPgs_InsertslMicrofitm Marker.doc 5C~~ DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042240 Well Name/No. PRUDHOE BAY UNIT Z-39A Operator BP EXPLORATION (ALASKA) INC 5~J )À~~I- API No. 50-029-22995-01-00 MD 11555./ TVD 9046 / Completion Date 3/31/2005./ Completion Status 1-01L Current Status 1-01L UIC N --..--.,.- '-'~-'--"------'--~-~ ~_.~-~ .._~-~ REQUIRED INFORMATION Mud Log No Samples No ~-_.~._-- ~-"".-'._.~-- Directional Survey Yes ~~---- (data taken from Logs Portion of Master Well Data Maint Interval OH/ e Start Stop CH Received Comments 9230 11526 Open 4/29/2005 ! 9230 11526 Open 4/29/2005 9110 11545 Open 7/14/2005 9110 11545 Open 7/14/2005 9285 11555 Open 3/13/2006 GR ROP plus Graphics 9285 11555 Open 3/13/2006 GR ROP 9285 11555 Open 3/13/2006 GR ROP __J 9285 11555 Open 3/13/2006 GR ROP DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, MCNL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ¥D D Asc Directional Survey : Rpt Directional Survey ~ C Lis 13201 I nd uction/Resistivity ~g 13201 I nd u ction/Resistivity ': C Lis 13806 Gamma Ray t: 13806 LIS Verification 13806 Gamma Ray og 13806 Gamma Ray Log Log Run Scale Media No 25 Blu Blu Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments e ADDITIONAL INFORM~N Well Cored? Y ~ Daily History Received? 0N ~/N Chips Received? -rT'1'r Analysis ~ Received? Formation Tops ~-- Comments: -~----,._.,- -,-_._-~------------,.- .--~ -----~-~~-_.. DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042240 Well Name/No. PRUDHOE BAY UNIT Z-39A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22995-01-00 MD 11555 TVD 9046._ _. I 'I com. pletion Date 3/31/2005 Compliance Reviewed By: .. ~ Completion Status 1-01L Current Status 1-01¡L J 11.,1 UIC N Date: -jÀLïL~-~ e e . . Transmittal Form '&111 BAKI. NUGHU INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: Z-39A II II Contains the following: I 1 LDWG Compact Disc M } '1 8b ~ (Includes Graphic Image files) tr · 1 LDWG lister summary 1 blueline - GR/Directional True Vertical Depth Log 1 blueline - GR/Directional Measured Depth Log Sent By: G~ ¡ore. ¿ fI.'!J, Received By: ~ ~ Date: Feb 28,06 Date:/3~c PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Âl)Y- ~)y h¡~ i01 ,_:~ J -'o,i 1.-., v t::. u . STATE OF ALASKA I AUG 0 3 2005 ALASKA OIL AND GAS CONSERVATION COM ss1ð~a Oil & Gas Cons. Commissío" REPORT OF SUNDRY WELL OPERATIONSchorage (¡ 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate ŒI OtherD Alter Casing D Pull TubingD Perforate New PoolD WaiverD Time Extension D Change Approved ProgramD Operation ShutdownD Perforate D Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!l ExploratoryD 204-2240 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-22995-01-00 7. KB Elevation (ft): 9. Well Name and Number: 86.04 Z-39A 8. Property Designation: 10. Field/Pool(s): ADL-028262 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11555 feet true vertical 9045.9 feet Plugs (measured) Tagged TD @ 11200' CTMD (06/30/2005) Effective Depth measured 11409 feet Junk (measured) None true vertical 9027.4 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 91.5# H-40 31 - 113 31.0 - 113.0 1490 470 SURFACE 2993 9-5/8" 40# L-80 30 - 3023 30.0 - 2958.6 5750 3090 PRODUCTION 9244 7" 26# L-80 29 - 9273 29.0 - 8792.9 7240 5410 LINER 208 4-1/2" 12.6# 13Cr80 9077 - 9285 8599.0 - 8804.8 8430 7500 LINER 2407 2-3/8" 4.7# L-80 9043 - 11450 8565.3 - 9032.5 11200 11780 Perforation depth: Measured depth: 10200 -10650,10850 -11050 True vertical depth: 8956.7 - 8958.36, 8972.37 - 8988.29 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 27 - 9075 Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer @ 9016 3-1/2" Baker ZXP Mech Set Pac~ @ 9075 3-1/2" Baker HMC Hanger @ 9083 3-1/2" HES X Nipple @ 2014 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 211 307 35 266 Subsequent to operation: 212 618 1002 271 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ Oil[!] GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr ~ ,... Title Petroleum Engineer Signature A -:L_ ~ .Ä"J!. -- Phone 564-5174 Date 8/3/05 Form 1 0-404 Revised 4/2004 O I-¡ I "-'" ;!.-\~ , ,I. ~'.r iiU L RBDMS BFL AUG 0 4 2005 , . . Z-39A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/30/05 FCO/ACID TREATMENT. CTU #9 W/ 1.5" CT. CONTINUED FROM 6/29/05 WSR. MIRU. RIH, SLICK WITH 1.5" JSN TO 11200' CTM. DID NOT TAG. FCO W/ 3 FLOPRO SWEEPS FROM 11090' CTM FOLLOWED BY 1.5X BU. FLUID PACK IA WITH NH4CUDIESEL. LOAD WELL WITH NH4CUDIESEL. PUMP 1ST TWO STAGES WITHOUT THE DIVERTER TO ENSURE ACID WOULD BREAKDOWN FORMATION, SAW GOOD BREAKDOWN. CONTINUE PUMPING ACID AS PER PROGRAM WITH DIVERTER. CONTINUED ON 7/1/05 WSR. . . **** NOTE: INITIAL INJECTION RATE WAS 1.1 BPM AT 2230 PSI- AS ACID HIT PERFS WHP DROPPED TO 715 PSI WHILE WASHING PERFS. AFTER 1ST DIVERT STAGE HIT PERFS WHP INCREASED FROM-600 PSI TO 1050PSI, THEN SETTLED BACK TO-890 PSI.WHP REMAINED THE SAME -850 - 890 PSI WHEN NEXT ACID HIT PERFS. 07/01/05 FCO/ACID TREATMENT. CTU #9 W/ 1.5" CT. CONTINUED FROM 6/30/2005 WSR. CONTINUE PUMPING ACID TREATMENT WITH DIVERTER. COMBINED THE LAST 8 STAGES INTO 4 STAGES.NO FOAM DIVERTER WAS PUMPED FOLLOWING LAST ACID STAGE. - TOTAL FLUIDS PUMPED - 910 BBLS NH4CL - 780 BBLS 7 % HCL AND MUD ACID + 600 GAL N2. TURN WELL OVER TO PAD OPER AND ASRC TEST SEPERATER FOR FLOW BACK **** NOTIFY PO / PCC OF WELL STATUS **** RDMO **** JOB COMPLETE *****. . . **** NOTE **** FINAL INJECTION RATE/PRESSURE - 1.2 BPM/880 PSI. FLUIDS PUMPED BBLS 105 DIESEL 20 FLOPRO 48 DIVERTER 190 SLICK NH4CL 689 3% NH4CL 380 7% ACID 385 MUD ACID 1415 GALLONS NE 1817 TOTAL Page 1 , TREE= 4-1/16" CrN . I" WELLHEAO = FMC ACTUA TOR = BAKER KB~'ÊlEv ;·'~~----86.04~ FROM DRLG m BF. ELEV = 54.87' KOP-;'~~'~-~-2200; fI:'1ax A,~£Jl~..~", ,~,~"" @__,~~_!~' Datum MD = 9367' Datum TVO = 8800' SS -39 RAFT CTD Sidetrack ~NOTES: ~ 1074' H9-5/8" TAM PORT COLLAR I 2014' -13-1/2" HES X NIP, ID = 2.813" 9-5/8" CSG, 40#, L-80, ID::= 8.835" I Cement Sheath @ 76721, ID = 2.78 GAS LIFT MANDRELS ST MD TVDDEV TYPE VLV LATCH PORT OATE 6 3106 2947 26 MMG DOME RK 16 04/18/05 5 4756 4429 26 MMG SO RK 20 04/18/05 4 5836 5406 26 MMG DMY RK 0 08/29/03 3 6943 6437 17 MMG DMY RK 0 08/29/03 2 7960 7419 12 MMG DMY RK 0 08/29/03 1 8966 8403 8 MMG DMY RK 0 03/17102 Minimum ID = 1.926" @ 9049' 3-1/2" HES XN NIPPLE 3-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 2.992" TOPOF 2,3/8" LNR 8994' -13-1/2" HES X NIP, 10 = 2.813" I 9016' -17" x 4-1/2" BKR S-3 A<R, ID = 3.875" I 9042' -13-1/2" HES X NIP, ID = 2.813" , 9063' -13-1/2" HES XN NIP, 10 = 2.750" I Top of Cement I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" H 9074' -1 TOP OF BKR TIEBACK SL V, 10 = 5.250" -13-1/2" WLEG, 10 = 2.992" I -1 7" X 4-1/2" BKR ZXP A<R, ID '" 4.405" I - T' X 4-112" BKR HMC HGR, ID = 4.450" 9069' H ELMD TT LOGGED 02/25/02? I 7" CSG, 26#, L-80, 10 = 6.276" I Mechanical \¡Vhipsfock 9283' Fish at 11070' PERFORA TION SUMMARY REF LOG MWD-GR DATED 21iiv1AR/05 ANGLE /\ T TOP PEEF DEG @ 10200' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 1 6 10200-10550 OPEN 03!30!D5 156" 6 10850 11050 OPEN 2-3/8" crnt'Bò and perf ad 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9700' DATE 03/17/02 03/29/02 04/05/02 07/22/03 08/29/03 3i311G5 CHlTP TMNltlh JBM'KK JLJ/KK JGS COMMENTS ORIGINAL COM PLETION CORRECTIONS AOD PERFS GL V C/O GL V C/O COil SIDETRACK OA TE REV BY COMMENTS 04/23/05 RMHlTLH GLV C/O (04/18/05) 06/07/05 JPITLH IBP & PBTO CORRECTIONS PRUOHOE BA Y UNIT WELL: Z-39/\ PERMIT No: 204-224 API No: 50-029-22995-01-00 SEC 19, T11 N, R12E, 4301' NSL & 3238' WEL REV BY BP Exploration (Alaska) ·.. ... STATE OF ALASKA .. ALAS~L AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 3/31/2005 6. Date Spudded 3/22/2005 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4300' NSL, 3237' WEL, SEC. 19, T11N, R12E, UM Top of Productive Horizon: 3077' NSL, 1026' WEL, SEC. 19, T11N, R12E, UM Total Depth: 1832' NSL, 583' EWL, SEC. 20, T11 N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599440 y- ~959099_ Zone- ASP4 TPI: x- 601672 y- 5957907 Zone- ASP4 Total Depth: x- 603303 y- 5956684 Zone- ASP4 No. of Completions -- ---~ ---- -- 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD DIR, GR, MCNL 22. 7. Date T.D. Reached 3/25/2005 8. KB Elevation (ft): 86.04' 9. Plug Back Depth (MD+ TVD) 11409 + 9027 10. Total Depth (MD+ TVD) 11555 + 9046 11. Depth where SSSV set (Nipple) 2014' MD 19. Water depth, if offshore NI A MSL CASING SIZE 20· 9-5/8" 7" 4-1/2" 2-3/8" GRADE H-40 L-80 L-80 13Cr L-80 CASING, LINER AND ("EMENTING RECORD SETTING DEPTH MD ::JETTING UEPTH TVD HOLE lOP I BOTTOM lOP IOOTTOM SIZE Surface 113' Surface 113' 30" 34' 3023' 34' 2959' 12-1/4" 32' 9273' 32' 8793' 8-3/4" 9070' 9285' 8592' 8805' 6-1/8" 9043' 11444' 8565' 9032' 3" CEMENTING RECORD 260 sx Arctic Set (Approx.) 79 sx Arcticset Lite III, 221 sx 'G' 51 sx LiteCrete, 100 sx Class 'G' 8 sx Class 'G' 136 sx Class 'G' WT. PER FT. 91.5# 40# 26# 12.6# 4.7# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 1.56" Gun Diameter, 6 spf MD TVD MD TVD 10200' - 10650' 8957' - 8958' 10850' - 11050' 8972' - 8988' 24. SIZE 3-1/2",9.3#, L-80 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-224 13. API Number 50- 029-22995-01-00 14. Well Name and Number: PBU Z-39A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028262 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT . PULLED TUBING RECORD DEPTH SET (MD) 9075' " PACKER SET (MD) 9017' 25. AClD,fiRACTURE,/CEMI$NTSQUEt:ZE,ETC, ,. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH GAs-McF 401 WATER-Bsl 1 CHOKE SIZE I GAS-Oil RATIO 1760 801 Oil GRAVITY-API (CORR) 24.2 CORE DATA _ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attT·..... ",=!,""~r 'I- I ",~ el'ssary). Submit core chips; if none, state "none". -- - -' None ~ RBDMS BFl MAYO 3 20Dl Alaska ::~:~h;~~:~:mmi"iG¡; L~_! Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE\. t'i' GAs-McF 802 WATER-Bsl 2 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 24, 2005 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-Bsl 4/24/2005 12 TEST PERIOD .. 501 Flow Tubing Casing Pressure CALCULATED ...... Oll-BsL Press. 24C 900 24-HoUR RATE7 1,002 27. , . 28. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9240' 8760' None Shublik A 9269' 8789' Shublik B 9327' 8846' RECEIVED APR 27 2005 Alaska Oil & Gas Cons. Commission Anchorage Shublik D 9355' 8871' Eileen 9360' 8876' Sadlerochit 9384' 8897' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date 01(?'" 7 OS PBU Z -39A Well Number Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Sean McLaughlin, 564-4387 204-224 Permit No. I A roval 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. 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 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Anchorage Spud Date: 2/20/2002 End: 3/19/2005 04:00 - 05:00 1.00 MOB P PRE Make ready to move of End 4-02 05:00 - 11 :30 6.50 MOB P PRE Move rig off well, lower reel onto trailer, lower derrick Contaced SDI Pad Op and conducted pad walk through and completed Pad Inspection 11 :30 - 18:00 6.50 MOB P PRE Move rig camps to DS7 and spotted Rig left SDI at 1130 hrs via ice road and Endicott Road Crew change at 1800 hrs on Endicott road 18:00 - 00:00 6.00 MOB P PRE Continue MOB to Veco yard. Stand-by there and raise derrick. Waiting for Doyon 16 to complete their move to DS #11 before proceeding with our move. 3/20/2005 00:00 - 03:15 3.25 MOB P PRE Raised derrick at Veco Yard while waiting for Doyon 16 to finish thier move to DS #11 03:15 - 06:00 2.75 MOB P PRE Continue move to Z-39. Passed West gate at 0500hrs 06:00 - 08:00 2.00 MOB P PRE Continue move to Z-39. Passed Oxbow/Spine at 0800hrs. Moving at 1.6 mph average 08:00 - 21 :00 13.00 MOB P PRE Continue move to Z-39. Passing by W-Pad exit Spent 2 hrs at Kuparuk Bridge while tool service layed 100 rig mats. On Z PAd at 2030hrs. Spot rig close to well. 21 :00 - 21 :15 0.25 MOB P PRE Toolbox safety meeting. Discuss pulling over well. 21:15 - 22:00 0.75 MOB P PRE Pull over Z-39. Rig accepted at 2200 hrs 3-20-05 22:00 - 00:00 2.00 BOPSU P PRE NU 7-1/16" 5k BOP's. Take on 290 bbls 1% KCL w/2# bio. 3/21/2005 00:00 - 03:30 3.50 BOPSU P PRE Continue NU 7-1/16" BOP's. Same time hook-up all CT inner reel plumbing and electrical. 03:30 - 07:30 4.00 BOPSU P PRE Pressure test BOP's. AOGCC wavied witnessing test. Body test found leak in kill line. Tighten. Restest good. Test all componets to 250psi low/5min 3500psi high 5/min (annular 2500psi). 07:30 - 08:30 1.00 RIGU P PRE RU to pull coil across. Stab inject on stuffing box. 08:30 - 09:15 0.75 RIGU P PRE PJSM on pulling CT across pipe shed Pre Spud Meeting with Crew and Pad Operator. Coverd well operations and Hazards associated with working on Z-Pad 09:15 - 11 :30 2.25 RIGU P PRE Pulling CT across with hydraulic winch. Working on bulkhead on reel. Pump fluid for coiled tubing slack management 11:30 -14:15 2.75 RIGU P PRE Cut off 100 ft CT to find wire. Installed dimple CTC and pull tested to 35k Unable to Cir CT. BHllost high voltage supply and went to Deadhorse to PU another one. Rehead to BHllnstalled 2.35" Nozzle. Open well, WHP = Opsi. Stab on well 14:15 - 16:00 1.75 RIGU N SFAL PRE RIH steaming CT to un-thaw and re-gain circulation. RIH to 100 ft regain circulation. While waiting on BHI power supply, RIH to 2,500 ft and circulated out MEOH. POOH. 16:00 - 17:15 1.25 STWHIP P WEXIT PU BHI/BOT BHA Mega line and installed wet connect, stab on to CT 17:15 - 18:45 1.50 STWHIP P WEXIT RIH tagged cement at uncorrected deph of 9286'. 18:45 - 20:00 1.25 STWHIP P WEXIT Pull up to 9090' bit depth. Log CCL from 9000' to 9100'. Correct -19' RIH tagged TOC at 9268' paint flag 20:00 - 21 :40 1.67 STWHIP P WEXIT Drill cement f/9268' to 9285'. Free-spin 1.6bpm 2400psi 3-400psi MW 2k wob 15-20'/hr 21 :40 - 00:00 2.33 STWHIP P WEXIT Start time drilling window. 1.6bpm 2600FS 3-400psi MW 2.6k wob 3/22/2005 00:00 - 02:30 2.50 STWHIP P WEXIT .Continue milling window fl 9287' 1.6bpm 300-500psi mw Printe¡J: 4{4/2005 8:29:44 AM , . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 3/22/2005 00:00 - 02:30 2.50 STWHIP P WEXIT stalled at 9290.7' pick-up went back through without problems. Drilled formation to 9292.6'. 02:30 - 03:50 1.33 STWHIP P WEXIT Ream window area. TOW 9285' BOW 9290.7' Start swap to new 8.4ppg Flo-Pro wI 8#ppb KlaGard 3#ppb LubeTex at 0330hrs 03:50 - 05:15 1.42 STWHIP P WEXIT Drill formation f/9292.6' to 9300.4' 05:15 - 05:25 0.17 STWHIP P WEXIT Ream window area. Run through area wo pump. Looks good. 05:25 - 07:00 1.58 STWHIP P WEXIT Paint white flag at 9185' EOP. TOH 07:00 - 09:00 2.00 DRILL P PROD1 UD BHA #1. P/U BHA #2 surface test tools. 09:00 - 10:30 1.50 DRILL P PROD1 RIH 10:30 - 10:45 0.25 DRILL P PROD1 Correct to flag -18'. Tie-in +3' 10:45 - 14:45 4.00 DRILL P PROD1 Directional drill ahead f/ 9300' 1.7bpm 3000psi FS. Drilled to 9328' then lost partial returns slowly healed up to > 1 bpm loss. Lost all returns at 9391 '. 14:45 - 14:55 0.17 DRILL P PROD1 Wiper to window. 14:55 - 15:45 0.83 DRILL P PROD1 Drill ahead f/ 9391' @ 1.7bpm in 0.16bpm out and slowly increasing. 15:45 - 16:30 0.75 DRILL P PROD1 Drilling f/ 9415' 1.7bpm in .35bpm out (9425' 483bbls in pits ' .48 retu rns) 16:30 - 16:35 0.08 DRILL P PROD1 Wiper back through loss zone. 16:35 - 17:00 0.42 DRILL P PROD1 Drilling ahead 1.75 in 0.61 out 17:00 - 18:30 1.50 DRILL P PROD1 Drilling ahead. ROP 130 fph. TF=45L. Inc=33 deg. Drilling at 1.70/0.65/3420 psi. 411 bbls in the pits. Losing about 1 bbl/min in mud. More mud on the way. 18:30 - 19:00 0.50 DRILL P PROD1 9536', About 150' since we lost returns. Currently drilling at 1.72/0.90/3370 psi. Pit volume=327 bbls. Ordered an additional 600 bbls of mud. Doyon 15 was at J pad at 17:15 tonight. It will be difficult to get mud around the rig. A total of 870 bbls of mud has been ordered. 19:00 - 19:30 0.50 DRILL P PROD1 305 bbls of mud in the pits. 1 truck (290 bbls) of new mud on location. Losses have stabalized at 1.70/0.8/3570 psi. Free spin is 3000 psi at 1.70 bpm. 19:30 - 21 :20 1.83 DRILL P PROD1 Land well at 9586' MD, 8934.7', right on plan. Inc=81 deg at the bit. Pull out of hole for lateral section BHA. Last losses while drilling were 1.7/0.83 bpm. Clean PU off bottom at 28 klbs. Pull in open hole pumping at full rate. Drop rate to 0.5 bpm thru the window. Open the EDC, and pump at full rate while POOH. 21 :20 - 22:30 1.17 DRILL P PROD1 Tag up at surface. Stand back injector. Inspect motor. It appears tight. Inspect bit. Graded 1,2 with no obvious wear on the nose or wing cutters, and with 1 chipped backreaming cutter. Will rerun bit. Adjust motor AKO to 1.1 deg. Test MWD BHA electronically, passed ok. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with BHA #3 to begin drilling the lateral section of the hole. 3/23/2005 00:00 - 00:20 0.33 DRILL P PROD1 Continue to RIH with BHA #3 to begin drilling lateral section. 00:20 - 01 :25 1.08 DRILL P PROD1 Log tie in pass over RA tag, made +7' correction???? This did not compare with correction from last run of -15'. Relog tie in pass over a longer interval to confirm correction. Made a second correction of -21', for an actual total correction of -14. 01 :25 - 02:20 0.92 DRILL P PROD1 Tag up at 9584', and begin drilling lateral section. Free spin =2990 psi at 1.67 bpm. Drilling at 1.68/0.82/3150 psi. 414 bbls of mud in the pits, 2 additional vac trucks on location. The Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Anchorage Spud Date: 2/20/2002 End: 3/23/2005 01 :25 - 02:20 0.92 DRILL P PROD1 Doyon 15 rig move is staged on the spine road at the M pad turn off. 02:20 - 03:15 0.92 DRILL P PROD1 Returns just dropped again. Drilling at 1.67/0.48/3130 psi. 03:15 - 03:40 0.42 DRILL P PROD1 Returns have improved slightly. Drilling at 1.69/0.65/3300 psi. 304 bbls in the pits. Make wiper trip to the window. Clean up and back down. 03:40 - 04:00 0.33 DRILL P PROD1 Resume drilling lateral section. Pit volume = 288 bbls. Drilling ahead at 1.69/0.83/3330 psi. 80 fph. 04:00 - 04:30 0.50 DRILL P PROD1 Returns went to O. Drilling at 1.7/0.0/2930 psi. Make 100' pickup, and started getting slight returns. 04:30 - 05:00 0.50 DRILL P PROD1 1.69/0.5/3130 psi. 75 fph. INC=86 deg. IAP=O psi, OAP=180 psi. 05:00 - 05:30 0.50 DRILL P PROD1 Wiper trip to shoe. Clean up and down. 05:30 - 07:00 1.50 DRILL P PROD1 Resume drilling to 9901'. 1.7/0.6/3200 psi. 07:00 - 07:40 0.67 DRILL P PROD1 Wiper trip to shoe 07:40 - 08:05 0.42 DRILL P PROD1 Drilled f/ 9901' to 9932'. Lost all power to rig and camps. 08:05 - 12:00 3.92 DRILL N SFAL PROD1 Restored power short order but BHi's High Power Supply may have fried. TOH to 3-1/2" reduce to min pump rate. Make repairs to surface equipment. Main problem traced to poor grounding within the new trailer where BHi equipment is set-up. RIH to bottom 12:00 - 13:30 1.50 DRILL P PROD1 Drill ahead f/9932' to 10063' 1.72/.70 3000psi FS 3-400 psi mw 2k wob 80-100'/hr 13:30 - 14:15 0.75 DRILL P PROD1 Wiper trip to window. No problems 14:15 - 16:45 2.50 DRILL P PROD1 Drill ahead f/10063' 1.70/.75 mixing SW from Kuparuk CPF1with Flo-Pro 4:1 during the time when Doyon #15 has been blocking the Deadhorse road. Total SW added 580bbls. 16:45 - 17:10 0.42 DRILL P PROD1 Wiper trip to window. 17:10 - 17:45 0.58 DRILL P PROD1 Log tie-in. Make -11' correction. 17:45 - 18:00 0.25 DRILL P PROD1 Drill ahead. 18:00 - 19:15 1.25 DRILL P PROD1 Continue drilling ahead. Currently have full pits with a mixture of 50% seawater and 50% flopro. Free spin 1.73 bpm, 2330 psi. Drilling at 1.73/0.8/2800 psi. ROP 100 to 150 fph. IAP=10 psi, OAP=220 psi. 19:15 - 20:10 0.92 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 31 klbs. Clean to window. Clean back to bottom. 20:10 - 21 :40 1.50 DRILL P PROD1 Resume drilling. 1.73/0.88/2344 psi. Drilling with SO/50 water mud power fluid. ROP 100-150 fph. 21 :40 - 22:40 1.00 DRILL P PROD1 Starting to have trouble with stacking weight. May be cuttings building up behind us. Wiper trip to the window. 5k Ibs overpull off bottom. Clean to window and back down. 22:40 - 00:00 1.33 DRILL P PROD1 Resume drilling. 1.72/0.95/2388 psi. Returns have healed up a bit after the last wiper. Pit volume = 336 bbls. 2 Vac trucks on location with new mud. 3/24/2005 00:00 - 00:15 0.25 DRILL P PROD1 Continue drilling lateral section. 00:15 - 01:20 1.08 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. 4 klb overpulls at 10290',9860'. Slick back to bottom. 01:20-03:15 1.92 DRILL P PROD1 Resume drilling. 1.73/0.96/2400 psi. Pit vol=173 bbls, taking on new mud. IAP=10 psi, OAP=225 psi. ROP=60 fph. 03:15 - 03:50 0.58 DRILL P PROD1 Wiper trip to shoe. 5 k Ib overpull off bottom. Clean to the window. 03:50 - 04:10 0.33 DRILL P PROD1 Log tie in pass over RA tag. Make a -6' correction. 04:10 - 04:40 0.50 DRILL P PROD1 Continue the wiper trip back to TD. No problems while RIH. Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Anchorage Spud Date: 2/20/2002 End: 3/24/2005 04:40 - 06:00 1.33 DRILL P PROD1 Resume drilling. 1.74/0.94/2300 psi. Pit volume=31 0 bbls, 2 trucks of new mud on location. ROP=125 fph. 06:00 - 07:00 1.00 DRILL P PROD1 Drilling ahead 1.72/.90 2300psi FS (low pressures resulting from thinned out mud) 2-300psi mw. ECD 9.16ppg 10890' stacking wt every 5-10' drilled 5k overpulls. 07:00 - 08:15 1.25 DRILL P PROD1 Wiper trip to window. Clean pu off bottom. 08:15 - 13:15 5.00 DRILL P PROD1 Drilling ahead 1.72/.90 2500psi FS 2-300psi mw 2-3k wob 10-15"/hr shaley 5-10'/hr Pumping 50 bbl sweeps of new Flo-Pro without much help. 13:15 - 14:00 0.75 DRILL P PROD1 Wiper trip above window clean PU off bottom 5k overpull at 9960' 14:00 - 14:30 0.50 DRILL P PROD1 Tie-in to RA tag -19'.10990' corrected depth 14:30 - 15:00 0.50 DRILL P PROD1 RIH clean to bottom. 15:00 - 18:00 3.00 DRILL P PROD1 Drill ahead f/10990' 1.72/0.90 2800psi FS 1-200psi mw slow but drilling 1 O'/hr still in shale holding 84 deg 18:00 - 20:00 2.00 DRILL P PROD1 Drilling ahead. 1.71/0.68/3150 psi. Free spin is 3000 psi at 1.7 bpm. Drilling in shale with slow ROP af about 30 fph. Dropping hole angle to try to drill out of shale. 20:00 - 20:30 0.50 DRILL N DPRB PROD1 Possibly have balled up bit. Couldn't get any motor work or a stall. Spud bottom a few times. Can't really get it to drill. Can't get a stall, even when spudding bottom. Something is not right. Possibly a balled up bit, cored bit, or bad motor. POOH to inspect BHA. 20:30 - 22:50 2.33 DRILL N DPRB PROD1 POH for new BHA. Clean in open hole. Pump at full rate while POOH in tubing. Note - Mud has 8 ppb Kla-Gard. 22:50 - 00:00 1.17 DRILL N DPRB PROD1 Stop at 200', hold PJSM for BHA swap. Tag up with bha #3. Stand back injector. Break out bit and motor. Bit was graded 1,3. It had 4 chipped cutters on the wing section. It was balled up with mud also. Pick up BHA #4 - Hycalog DS100 bit, new Xtreme mud motor, same MWD package as last run. 3/25/2005 00:00 - 01 :50 1.83 DRILL N DPRB PROD1 RIH with BHA #4 to continue drilling lateral section. 01:50 - 02:10 0.33 DRILL P PROD1 Log tie in pass over RA tag. Make -16' correction. 02:10 - 03:05 0.92 DRILL P PROD1 RIH to resume drilling. Set down at 10935', worked our way thru it. Had to work the last 200' to bottom. 03:05 - 03:50 0.75 DRILL P PROD1 Free spin 3020 psi at 1.7 bpm. Resume drilling at 1.73/0.68/3350 psi. Pit volume = 307 bbls. 1 additional truck of new mud on location, 2nd truck round tripping for more mud. Inital ROP=100 fph. IAP=O psi, OAP=230 psi. ROP quickly slowed down to 20 fph. Looks like we are chewing our way thru some more shale. 03:50 - 05:10 1.33 DRILL P PROD1 Pickups sticky. Backream to clean up. Got motor work and overpulls up to 10935'. Make overpull was to 55 klbs. Normal up weight was 31 klbs. Make 2 additional reaming passes up and down from 11104' to 10800'. 05:10 - 08:20 3.17 DRILL P PROD1 Resume slow drilling in shale at 20-50 fph. Popped out of shale around 11130' drilling 50-60'/hr 20-30API1.75/0.72 Boosting Kly-Guard in system and further deliveries to 12ppb from 8ppb. At 11160' returns decreased to 0.30 bpm from 0.78 08:20 - 09:45 1.42 DRILL P PROD1 Wiper trip above window. 200psi mwat 11058' and 10664. Hang out in 4-1/2" with EDC open. Need to replace leaking liners and swabs in pump #1. Swabs are already oversized. Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/25/2005 09:45 - 11 :15 1.50 DRILL P PROD1 Replace liners and swabs in pump #1. 11 :15 - 12:10 0.92 DRILL P PROD1 RIH tag at 10919' - 10923' work through with little trouble, same at 11008-11023'. 12:10 - 15:30 3.33 DRILL P PROD1 Directionally drill f/11250' 1.70/0.44 3050psi free-spin 400psi mw 40-60'/hr in sand hitting small shale stringers ROP varying accordingly. Drill to 11402'. 15:30 - 17:30 2.00 DRILL P PROD1 Wiper trip to window. RIH setdown at 10993' pu went through, RIH to TD. 17:30 - 18:00 0.50 DRILL P PROD1 Drill ahead f/11402' 1.72/0.44 9.94ECD 3200psi FS 3-400psi mw 50-60'/hr 18:00 - 22:20 4.33 DRILL P PROD1 Continue drilling lateral section. 1.73/0.39/3200. Free spin 3100 psi at 1.7 bpm. IAP=O psi, OAP=210 psi. Pit volume = 329 bbls. 1 full truck of mud on location. 1 round tripping to MI for more mud. Having to snub to drill. String weight is -8000 Ibs, WOB from BHI MWD tool is 800 Ibs. Getting close to lock up. 22:20 - 23:05 0.75 DRILL P PROD1 11533', Returns went to O. Drilling now at 1.73/0.0/2860 psi. 123:05 - 00:00 0.92 DRILL P PROD1 At TD. Drilled 6' extra to account for typical minus correction of I past few days. Take survey on bottom. Backream to clean up shales. Clean PU off bottom. Ream from TD to 10800'. First trip - 1 slight overpull at 10970' on way up, weight bobble at 11080' on way down. Second trip - 1 slight overpull at 11144' on way up, weight bobble at 11025' on way down. No returns while reaming. 3/26/2005 00:00 - 01:1 0 1.17 DRILL P PROD1 Continue to condition shales. Third pass - Slight motor work at 11380', and 11144'. No overpulls. 01:10 - 01 :50 0.67 DRILL P PROD1 Make wiper trip to window. Clean in open hole to window. 01 :50 - 02:05 0.25 DRILL P PROD1 Log tie in pass over RA tag. Make -6' correction after tie in. 02:05 - 03:30 1.42 DRILL P PROD1 Run back in hole. Hole conditions smooth while RIH. No problems in shales below 10800'. 03:30 - 04:40 1.17 DRILL P PROD1 Tag bottom. Found corrected depth at 11555'. POH. Clean PU off bottom. No problems with overpulls on way up in open hole. Note - Very little returns. Pumped at full rate down and up on last wiper. 1.7/0.15/3000 psi. 04:40 - 06:00 1.33 DRILL P PROD1 Pull up thru window with pumps down. Open EDC. Pumps back to full rate. POOH 1.7/0.3/2400 psi. 06:00 - 07:00 1.00 DRILL P PROD1 Tag up. UD BHA #3 07:00 - 08:15 1.25 EVAL P PROD1 RIU PDS logging equipment. (RU to circulate and keep hole full. Inadvertently set-up to use trip tank and pump through fill-up line. We can ONLY do this during RWO modes, not in CTD modes. While in CTD mode we fill hole by installing cap on lubricator and pumping through kill line. The result of using fill-up line caused a released of 20 gals Flo-Pro drilling mud to cellar area. All fluids contained by cellar wall-to-wall secondary containment mats. All Slope contacts were reported to. Traction IR is 2005-IR-1295679) 08:15 - 09:45 1.50 EVAL P PROD1 RIH to 9085'. Up wt 28k dwn wt 15k Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/26/2005 09:45 - 11 :35 1.83 EVAL P PROD1 Log w/ PDS CTIL from 9085' at 30'/min pumping 1.0/.01 set down at 10992' increase pump 2bpm work through continue logging to 11525' (uncorrected) unable to continue. 11 :35 - 13:05 1.50 EVAL P PROD1 Log up 30'/min 1.68/0.32 13:05 - 14:50 1.75 EVAL P PROD1 TOH 14:50 - 15:05 0.25 EV AL P PROD1 UD logging tools. 15:05 - 16:30 1.42 EVAL P PROD1 Wait on confirmation logging tools accquired good data. Hole drank 38bbls during wait period. 16:30 - 17:00 0.50 DRILL P PROD1 P/U BHA #6 Faxed log to town. Corrected log depth was 11549'. 17:00 - 19:00 2.00 DRILL P PROD1 RIH pumping min rate .65 with .14 returns 19:00 - 17:25 22.42 DRILL P PROD1 Log tie in over RA tag in whipstock. Pumping at 1.7/0.37/2600 psi. Make -8' correction. 17:25 - 20:50 3.42 DRILL P PROD1 Close EDC. RIH pumping at full rate. Initial circ rate at window is 1.73/0.44/3150 psi. Slick most of the way in open hole. 1 slight weight bobble with motor work at 10090'. Clean down to 11014', another blip with motor work. Hard set down at 11096'. Tool face was pointing the correct as drilled orientation of 60L. PU, work thru the bad spot. 1.73/0.0/3285 psi. Hard set down at 11116'. Overpull to 40 klbs picking up. Pull up 100' to clean up. RIH, set down at 11020', worked thru. Smooth down to 20:50 - 23:00 2.17 DRILL P PROD1 Ream hole to clean up. On first pass had a couple of minor overpulls and motor work. On 2nd reaming pass had motor work at 11396',11114', 11071' up, and 10958', 11015', 11103' down. On 3rd reaming pass had slight motor work at 11104' down. On 4th pass up it looked pretty clean. 1.74/0.213030 psi. 23:00 - 23:50 0.83 DRILL P PROD1 Wiper trip to shoe, no problems. 23:50 - 0.00 DRILL P PROD1 Open EDC. Pull thru the window, and pump at full rate while POOH. Initial pump data at window is 1.70/0.0/ 3/27/2005 00:00 - 01 :20 1.33 DRILL P PROD1 Continue POOH. Hold PJSM Re: BHA swap while POOH. 01 :20 - 02:30 1.17 DRILL P PROD1 Tag up with BHA #6. Lay down BHA. Make up IBP setting tool on bottom of BHI MWD tool. 02:30 - 02:50 0.33 CEMT P RUNPRD RIH with BHA #7. Baker 2.5" IBP and setting tool on bottom of BHI MWD. Note EDC is open, there is a solid ball seat in the IBP setting tool. At 300', saw some drag on the coil string weight. Don't want to tear up the IBP. Pull back to surface to check it out. 02:50 - 03: 1 0 0.33 CEMT P RUNPRD Tag up at surface. Stand back injector. Examine IBP. No problems seen on the IBP or setting tool. Stab injector back on. 03:10 - 05:20 2.17 CEMT P RUNPRD Run back in hole with BHA #7 to set Baker IBP. 05:20 - 05:40 0.33 CEMT P RUNPRD Log tie in pass over RA tag. Make -17' correction. 05:40 - 07:00 1.33 CEMT P RUNPRD RIH, no pump smooth thru window. PU weight at the window is 30 klbs. RIH in open hole at 30 fpm. light setdown at 10090', 10990', 11020', then continued without problem to plsce center of IBP element at 11450'. PU to 28k to ge stretch out of coil. Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/27/2005 07:00 - 08:00 1.00 CEMT P RUNPRD Close EDC. Pressure up in 500psi/10min increments to 1500psi. Went to 1700psi and sheared setting tool. PU normal wt. RIH set 3k on IBP. Looks good. Bring on pump getting 1:1 retu rns. 08:00 - 10:30 2.50 CEMT P RUNPRD TOH 40'/min pumping 1.6bpm good returns initiallly but gradually decreasing to 38%-50% returns. PJSM review plan forward to blow down I/d bha. 10:30 - 11 :15 0.75 CEMT P RUNPRD UD BHA #7. 11:15 -11:30 0.25 CEMT P RUNPRD PJSM with N2 crews. Review procedures for blowing down. 11 :30 - 13:00 1.50 CEMT P RUNPRD Load coil w/30bbls FW followed by 10bbls methanol. Line up on choke start blowdown taking mud returns to rig tank. See FW take returns to Tiger Tank. Bleed down pressures. 13:00 - 15:00 2.00 CEMT P RUNPRD Pop off injector. Remove BHi connector. RU and unstab coil from injector and secure to reel. Remove inner reel valve. Back off drive plates. RU to run liner. 15:00 - 15:15 0.25 CASE P RUNPRD PJSM with Nordic crews/Baker reveiw liner running procedures. 15:15-18:00 2.75 CASE P RUNPRD Fill hole. Took 70bbls to fill this with continuious losses so hard to determine where static fluid level was. P/U 2jts 1" CSH and 1.90" drift and standback in derrick. Start running 2-3/8" liner 18:00 - 20:30 2.50 CASE P RUNPRD Continue running 2-3/7" liner. IAP=O psi, OAP=186 psi. Pit volume - 479 bbls. 20:30 - 23:00 2.50 CASE P RUNPRD Liner is in the hole. Circulate accross the top to keep the hole full. Rig up to stab coil tubing in injector. Pull coil over and stab into injector. Weld CTC onto coil. While waiting on weld to cool, fill 30 bbls in coil. Pull test CTC to 35 klbs. Pressure test CTC to 4500 psi. Passed ok. Bleed off CTP. Pump methanol out of coil to cuttings box. 23:00 - 23:30 0.50 CASE P RUNPRD Drop dart. Chase with mud. 23:30 - 00:00 0.50 CASE P RUNPRD Make up MHA to top of liner, stab coil. MU injector. 3/28/2005 00:00 - 01 :05 1.08 CASE P RUNPRD RIH with 2-3/8" liner string on coil tubing. Liner as per details for BHA #8, and as proceedure. 01 :05 - 01 :55 0.83 CASE P RUNPRD Weight check at the window is 32 klbs. RIH, smooth thru the window. Had many weight bobbles while RIH; 9750', 9949', 10011', 10106', 10559', 10840. very ratty below 10950', and set down at 11042'. Picked up 10', made it past set down spot (New Baker twirly shoe?), continued RIH. Ratty to 11139', then hard set down. Picked up 10', and got past the set down. (Twirly shoe again?). Continue RIH ratty to 11230', set down then fell thru. Continue RIH to 11294', set down then popped thru. RIH to 10318', set down and fell thru. RIH to 11367', and set down. Picked up 10', got thru it ok. (?) RIH to 10401', and set down. Picked up 10' and got thru. Set down at 11434', pick up 10', and RIH, and set down easy at 11457'. PU at 35 klbs. RIH easy, and set down again at 11459'. This is top of IBP set at a correlated depth of 11444'. (-8' correction). Stacked 3 klbs max on IBP. Note - When picking up at set downs, we picked up 10' on the counter. This is pickup weight, and probably just another 1 or 2' of BHA movement. 01 :55 - 02:30 0.58 CASE P RUNPRD Pick up to 11436'. Drop 5/8" ball to release from LRT. Chase Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/28/2005 01 :55 - 02:30 0.58 CASE P RUNPRD ball with flopro mud. Confirmed ball rolling. RIH to 11444'. LRT in compression. Displace ball at 2.34/0/57/3275 psi. Slow rate to 0.5 bpm at 30 bbls away. Ball on seat at 31.3 bbls away. Good indication of shear at 3700 psi. PU 2' to ensure free of liner, up weight is 28 klbs. Confirmed liner released. Slack weight back off to 13500 string wt. 02:30 - 02:55 0.42 CASE P RUNPRD Circulate mud accross top of well, taking returns of mud to tiger tank. No room in pits to displace the well to KCL, and no clean vac trucks available from dispatch to empty pits. Need to pump to the tiger tank for temporary pit volume. 02:55 - 04:30 1.58 CASE P RUNPRD Circulate KCL down the coil, taking mud returns to the tiger tank. Initial circ rate 1.50/0.29/2075 psi. With KCL in coil, liner, and open hole, mud on the backside, 1.50/0.0/2095 psi. Pump an additional 10 minutes, no measurable returns. Swap to pumping down the backside to displace backside to KCL. Bullhead KCL down the backside at 2.2 bpm, 1580 psi. Pumped 50 bbls down the backside. and swapped to circulating down the coil. Pumping at 1.54/0.75/1995 psi. Life is good, we can get a cement job off like this ok. 04:30 - 04:45 0.25 CASE P RUNPRD Circulate, waiting on cementers. 04:45 - 06:15 1.50 CEMT P RUNPRD Rig up cementers. Pumping 1.55/0.56/2098 psi. Blow remainder of truck into the pits. 06:15 - 06:30 0.25 CEMT P RUNPRD PJSM with SLB/Nordic and third party crews. Review plan forward for cementing liner. 06:30 - 09:05 2.58 CEMT P RUNPRD Batch mix 30 bbls cement. Pump 5 bbls water ahead PT lines to 4k. Follow wI 30 bbls cement w/ additives. Load/launch wiper dart. follow with 40bbls 2# biowater and 10 bbls 2% KCL water. All wiper darts hit on time. Wait 3 min slowly bleed off displacement pressure.Total returns after cement exited shoe was 13bbls. Annulus vol wo excess is 9 bbls. Retum rate average 40%. CIP 0855hrs. 09:05 - 11 :00 1.92 CEMT P RUNPRD TOH laying in biowater from top of liner to 8850' RIH back to 9030' recontaminating TOL area. TOH laying biowater to 7200'. TOH 11:00 -11:10 0.17 CEMT P RUNPRD UD CTLRT 11 :10 - 14:45 3.58 CEMT P RUNPRD P/U BHA#9 for liner cleanout 14:45 - 16:00 1.25 CEMT P RUNPRD MU injector. RIH with 1:1 returns. UCA shows 500+ compressive strength after 3:35 hrs. Ran into soft cement at 7800'. 16:00 - 17:30 1.50 CEMT P RUNPRD Drill soft cement from 7800' .90/.90 2350psi pumping 5bbl bio sweeps as needed. 17:30 - 19:00 1.50 CEMT P RUNPRD Into harder cement now. POH to pick up bigger mill and motor to clean out 3-1/2" tubing, and not leave a cement sheath. 19:00 - 19: 15 0.25 CEMT P RUNPRD PJSM re: standing back CS hydril. 19:15 - 22:30 3.25 CEMT P RUNPRD Stand back injector. Drop 1/2" ball to open lower circ sub. Stand back CS hydril in derrick to recover BHA #9. 22:30 - 22:50 0.33 CEMT P RUNPRD Recover BHA #9. Make up BHA #10: 2.78" D331 DSM,2-1/8" Baker motor, 1 jt of 2-1/16" CSH, MHA, CTC. 22:50 - 00:00 1.17 CEMT P RUNPRD RIH with BHA #10 to mill cement in 3-1/2" tubing. Pumping at full rate from surface. 1.211.5/1290 psi. Using 1-1/2" bio water Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/28/2005 22:50 - 00:00 1.17 CEMT P RUNPRD as power fluid. Will pump sweeps of 2# bio as we mill. 3/29/2005 00:00 - 00:15 0.25 CEMT P RUNPRD Continue RIH with BHA #10. 00:15 - 00:40 0.42 CEMT P RUNPRD Free spin 1430 psi at 1.5 bpm. Up weight is 24 klbs. Begin milling cement stringers from 7672'. Send 10 bbls of 2.5# biozan sweep, and continue to pump 10 bbls of 2.5# biozan for every 40 bbls of 1.5# bio-water pumped. 00:40 - 03:45 3.08 CEMT P RUNPRD 7816', tag up on hard cement. Mill same. ROP=80 fph. 03:45 - 05:00 1.25 CEMT P RUNPRD Very hard spot. Getting lots of stalls. Possibly on the GLM that is on the schematic at 7960'. 05:00 - 06:00 1.00 CEMT P RUNPRD Made slow progress from 7978'-7981'. Magnets are in the trough. No metal being recovered on magnets. ROP picked up at 7981', and now milling ahead at 100+ fph. 1.65/1.70/1846 psi. IAP=7 psi, OAP=310 psi. Pit volume = 393 bbls. Continuing to pump alternating sweeps of 40 bbls 2% KCL with 1-1/2 ppb bio, followed by 10 bbls of 2.5 # bio as a sweep. 06:00 - 10:45 4.75 CEMT P RUNPRD Drilling cement f/ 7981' - 8520'steady 200psi mw 1: 1 returns 100+'/hr 10:45 - 11 :15 0.50 CEMT P RUNPRD Broke through the hard cement W /R V 8520' 20'/min pumping bio sweeps 1:1 retums. Cement stringers at 8980' good cement at 8990' 20'/30'/hr 11 :15 - 12:00 0.75 CEMT P RUNPRD Drilling good cement f/ 8990' 12:00 - 15:50 3.83 CEMT P RUNPRD Continue drilling cement in the 3-1/2" tubing. 1.76/1.80/2040 psi. Pit volume = 310 bbls. IAP=46 psi, OAP=375 psi. ROP = 17fph. 15:50 - 17:30 1.67 CEMT P RUNPRD Tagged up on top of 2-3/8" liner deployment sleeve. Pump last high vis sweep, and POOH. 17:30 - 18:00 0.50 CEMT P RUNPRD Weekly function test BOP stack components. 18:00 - 21 :00 3.00 CEMT P RUNPRD Hold PJSM before MU BHA. MU BHA #11 (1.88 DSM & motor on 80 jts 1" CSH). Stab coil. Get on well. 21 :00 - 22:30 1.50 CEMT P RUNPRD RIH with clean out BHA. 27K# up wt @ 9000'. 1750 psi @ 0.92 bpm. 22:30 - 00:00 1.50 CEMT P RUNPRD Tag and stall at 9050'. Mill ahead slowly, 2100 psi @ 0.91 bpm. ROP increased at 9058'. Appear to be through the cement. Continue to clean out liner. Pump 10 bbls 2.5# bio for every 40 bbls 1.5# bio pumped. INONPVT: 81/342/330. 3130/2005 00:00 - 02:00 2.00 CEMT P RUNPRD Continue liner clean out to PBTD of 11409'. Tag btm three times with some motor work noted. No additional footage made. Assume hitting float assembly and no cement on bottom. Slioght over pulls off btm. POOH while circulating flo pro to bit. Try to run back in hole. Unable to go down, appear to be stacking out. Clean pick up, no over pull noted. Repeat this several times. Able to move up hole each time, but never able to RIH. Deepest depth stopped was 11070'. 02:00 - 03: 15 1.25 CEMT P RUNPRD Lay in flo pro into liner. 03:15 - 04:45 1.50 CEMT P RUNPRD Circulate OOH. Displace well to clean 1.5# bio. At surface. Get off well. Unstab coil. Drop ball to open circ sub. 04:45 - 08:10 3.42 CEMT P RUNPRD Stand back CSH. LD 26 joints. 08:10 - 09:15 1.08 CEMT P RUNPRD PT liner lap. Pressure up to 2000 psi, double block all surface valving. Bring perf guns into the pipe shed while pressure testing. 0 minutes, Pressure = 1890 psi. Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: 3/30/2005 08:10 - 09:15 1.08 CEMT P RUNPRD 15 minutes, Pressure = 1725 psi. 30 minutes, Pressure = 1677 psi. 45 mintues, Pressure = 1670 psi. 60 minutes, Pressure = 1666 psi. 09:15 - 09:50 0.58 CEMT P RUNPRD Continue organizing perf guns. 09:50 - 10:05 0.25 CEMT P RUNPRD PJSM prior to picking up perf guns. Attended by rig crews, SWS perf crew, SWS team leader, Nordic toolpusher, BP co Rep. 10:05 - 10:30 0.42 CEMT P RUNPRD Begin running SWS perf guns. Hold kick drill with 2 guns in the hole. Good response from all hands on rig floor, and good deployment of safety joint. 10:30 - 12:30 2.00 CEMT N DPRB RUNPRD SWS CT hand found mandrel from coil dart in bottom of mill that was used on clean out run. SWS records show that they were unable to RBIH past 11070' last night after cleaning out to PBTD. Call town to discuss situation. Most likely have rubber elements from liner wiper dart drug uphole to 11070'. Town may wish to clean out rubber prior to proceeding. Call town, fill them in on the situation. Wait on orders. 12:30 - 13:30 1.00 CEMT N DPRB RUNPRD Need to make another cleanout run. Call Baker TT for milling BHA, including jars. Wait on equipment. 13:30 - 15:45 2.25 CEMT N DPRB RUNPRD Change of plans. We will perforate instead of making a cleanout run. Call for SLB perforators to return to location. 15:45 - 16:00 0.25 LOWER1 PJSM with rig crews, new SLB perforator crew, Nordic toolpusher, BP Co Rep. 16:00 - 18:00 2.00 LOWER1 Run perf guns as per proceedure and Bob Dawson perforation letter. 41 guns total. 18:00 - 20:15 2.25 LOWER1 Continue to make up perf gun BHA assembly. Run 54 jts from derrick. Stab coil. Get on well. BHA length 2553'. Subtract 15' correction. 20:15 - 23:00 LOWER1 RIH. 31 k# up, 14k# dn wt at 8900'. Continue to RIH, through liner top at 9055'. 25 fph running speed. Perform weight check every 500'. Circ at min rate: 0.22 bpm @ 800 psi. 9500' : 32k# up /16k# dn wt 10000' : 31k# up /15k# dn wt 10500' : 31 k# up I 14.5k# dn wt. 11000' : 30.7k# up /14.3k# dn wt. RIH to 11070'. No sign of any junk. 23:00 - 00:00 1.00 PERFO P LOWER1 Pump 5 bbls flopro. Park reel. Insert 0.5" aluminum ball. Pressure reel valve to 500 psi. Open reel valve and pump additional 3 bbls flopro. Stop at 11055'. Zero micro in. Pump 4 bbls additional flo pro. Displace with 2% KCL water. Displace ball at 2850 psi at 1.42 bpm. 3/31/2005 00:00 - 00:15 0.25 PERFO P LOWER1 Continue to circulate. Reduce rate to 0.5 bpm @ 1000 psi with 31 bbls away. Ball on seat at 37.8 bbls pumped. Begin to POOH. Shot indication at 3450 psi. Continue to POOH. Perf intervals: 10200' to 10650', 10850' to 11050'. 00:15 - 02:00 1.75 PERFO LOWER1 Continue to POOH. Fill well across top as coil exits liner from pits. Monitor hole fill. No losses or gain noted. 02:00 - 02:15 0.25 PERFO LOWER1 Hole fill short by 3-4 bbls. Stop and monitor flow. No flow. Fill coil. Took 3-4 bbls to fill coil, fluid apparently falling out of coil while POOH. Hole fill now correct. 02:15 - 04:15 2.00 PERFO P LOWER1 Continue to POOH filling across top. Printed: 4/4/2005 8:29:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-39 Z-39 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2005 Rig Release: Rig Number: 2 Spud Date: 2/20/2002 End: LOWER1 Hold PJSM with crew to discuss handling BHA. LD CSH from well in singles. Prep to LD guns. Hold PJSM with gun & rig crews. Shut down operations to let crews change out. Safety meeting to discuss laying down spent perf guns. Lay down perf guns. All guns fired. All shots fired. A slight amount of trapped pressure in blanks. Situation handled safely by SWS perf hands on rig. No incidents, no problems. Pick up injector with a swirly stick nozzle. Jet stack to remove cement cuttings. Make up BHA to swap well to KCL and freeze protect. RIH with cement nozzle to swap well to KCL. POOH, pumping 2% KCL. Swap to methanol and FP well from 2000' to surface. Get off well. Unstab coil. ND BOPS. NU tree cap and test same. Continue to clean rig pits. Continue with rig down. Rig released at 17:00. Further telex entries carried on the Z-22 MR. 06:00 - 06:15 06:15 - 06:30 06:30 - 09:30 09:30 - 10:15 0.75 CHEM P 10:15-11:30 1.25 CHEM P 11 :30 - 13:30 2.00 CHEM P 13:30 - 15:30 2.00 CHEM P 15:30 - 17:00 1.50 BOPSU P LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 POST Printed: 4/4/2005 8:29:44 AM ObP . Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report lB.. BAKU HUGIll. I.NTEQ ...... Company: BP Amoco Date: 4/11/2005 Time: 09:48:13 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-39, True North Site: PB Z Pad Vertical (TVD) Reference: Z-39: 86.0 Well: Z-39 Section (VS) Reference: Well (0.OON,O.00E,127.00Azi) Wellpath: Z-39A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB Z Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: 5957230.17 ft Latitude: 70 17 33.051 N From: Map Easting: 601304.82 ft Longitude: 149 10 47.365 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.77 deg Well: Z-39 Slot Name: Well Position: +N/-S 1894.78 ft Northing: 5959099.82 ft Latitude: 70 17 51.684 N +E/-W -1839.57 ft Easting : 599440.05 ft Longitude: 149 11 40.988 W Position Uncertainty: 0.00 ft Wellpath: Z-39A Drilled From: Z-39 500292299501 Tie-on Depth: 9230.28 ft Current Datum: Z-39: Height 86.04 ft Above System Datum: Mean Sea Level Magnetic Data: 10/27/2004 Declination: 24.76 deg Field Strength: 57596 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.24 0.00 0.00 127.00 Survey Program for Definitive Wellpath Date: 10/27/2004 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 140.32 9230.28 Z-39 (140.32-9602.61) (0) MWD MWD - Standard 9283.00 11526.07 MWD (9283.00-11526.07) MWD MWD - Standard Annotation MD TVD ft ft 9230.28 8750.63 TIP 9283.00 8802.84 KOP 9311.27 8830.53 Interpolated Azimuth 9345.02 8862.34 Interpolated Azimuth 11555.00 0.00 Projection to TO Survey: MWD Start Date: 3/22/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path )~tf-J).L( ObP .Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report B¡¡. IIAKR HUGIll. --~'._------- lNTEQ .... Company: BP Amoco Date: 4/11/2005 Time: 09:48: 13 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-39, True North Site: PB Z Pad Vertical (TVD) ~eference: Z-39: 86.0 Well: Z-39 Section (VS) Reference: Well (0.00N,0.00E.127.00Azi) Wellpath: Z -39A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/10OO 9230.28 8.14 117.03 8750.63 8664.59 -1189.76 2194.46 5957939.30 601649.86 2468.59 0.00 MWD 9283.00 7.80 118.48 8802.84 8716.80 -1193.17 2200.93 5957935.98 601656.38 2475.80 0.75 MWD 9311.27 15.13 137.00 8830.53 8744.49 -1196.78 2205.14 5957932.42 601660.63 2481.34 28.70 MWD 9345.02 23.82 154.00 8862.34 8776.30 -1206.16 2211.14 5957923.13 601666.76 2491.78 30.49 MWD 9375.16 28.91 170.49 8889.38 8803.34 -1218.84 2215.02 5957910.50 601670.81 2502.51 29.45 MWD 9406.49 33.11 193.78 8916.32 8830.28 -1234.68 2214.23 5957894.65 601670.23 2511.42 40.32 MWD 9439.09 36.88 177.88 8943.08 8857.04 -1253.15 2212.47 5957876.16 601668.71 2521.12 30.18 MWD 9470.18 45.43 166.85 8966.50 8880.46 -1273.32 2215.34 5957856.03 601671.85 2535.56 35.99 MWD 9497.42 51.84 159.25 8984.50 8898.46 -1292.82 2221.36 5957836.62 601678.12 2552.09 31.47 MWD 9532.54 62.00 152.55 9003.66 8917.62 -1319.58 2233.44 5957810.02 601690.55 2577.85 33.03 MWD 9564.56 74.47 153.99 9015.51 8929.47 -1346.10 2246.77 5957783.69 601704.23 2604.45 39.17 MWD 9594.44 81.55 149.65 9021.72 8935.68 -1371.83 2260.57 5957758.14 601718.38 2630.96 27.62 MWD 9624.19 84.52 145.04 9025.33 8939.29 -1396.68 2276.50 5957733.51 601734.63 2658.64 18.34 MWD 9653.75 86.92 140.80 9027.53 8941.49 -1420.19 2294.27 5957710.24 601752.71 2686.98 16.45 MWD 9683.85 86.76 136.68 9029.19 8943.15 -1442.78 2314.09 5957687.91 601772.82 2716.40 13.68 MWD 9721.10 86.33 133.83 9031.44 8945.40 -1469.18 2340.26 5957661.86 601799.34 2753.19 7.72 MWD 9758.36 91.58 130.60 9032.12 8946.08 -1494.20 2367.84 5957637.21 601827.24 2790.27 16.54 MWD 9789.90 96.69 128.55 9029.85 8943.81 -1514.24 2392.08 5957617.50 601851.74 2821.69 17.45 MWD 9820.58 98.98 125.06 9025.66 8939.62 -1532.44 2416.41 5957599.62 601876.30 2852.07 13.52 MWD 9850.37 99.17 121.70 9020.96 8934.92 -1548.63 2440.97 5957583.76 601901.07 2881.43 11.16 MWD 9884.38 100.78 126.27 9015.07 8929.03 -1567.34 2468.73 5957565.42 601929.08 2914.87 14.05 MWD 9915.04 101.88 131.40 9009.04 8923.00 -1586.18 2492.14 5957546.89 601952.74 2944.90 16.79 MWD 9946.60 102.40 136.18 9002.40 8916.36 -1607.53 2514.41 5957525.84 601975.29 2975.53 14.90 MWD 9980.20 101.76 139.83 8995.37 8909.33 -1631.94 2536.39 5957501.72 601997.58 3007.78 10.79 MWD 10011.51 101.72 136.18 8988.99 8902.95 -1654.72 2556.89 5957479.22 602018.39 3037.86 11.41 MWD 10041.40 101.08 132.29 8983.08 8897.04 -1675.16 2577.88 5957459.07 602039.64 3066.92 12.94 MWD 10069.88 100.37 129.39 8977.78 8891.74 -1693.45 2599.05 5957441.05 602061.05 3094.84 10.31 MWD 10100.42 99.67 125.77 8972.47 8886.43 -1711.79 2622.88 5957423.04 602085.12 3124.91 11.90 MWD 10130.36 1 00.23 122.32 8967.29 8881.25 -1728.30 2647.31 5957406.85 602109.76 3154.35 11.50 MWD 10160.96 99.41 126.12 8962.07 8876.03 -1745.25 2672.24 5957390.23 602134.91 3184.46 12.53 MWD 10190.65 97.12 129.90 8957.80 8871.76 -1763.34 2695.38 5957372.45 602158.29 3213.83 14.77 MWD 10220.71 94.68 132.70 8954.71 8868.67 -1783.07 2717.84 5957353.02 602181.00 3243.64 12.32 MWD 10252.34 91.86 138.27 8952.91 8866.87 -1805.58 2739.97 5957330.81 602203.42 3274.86 19.71 MWD 10284.69 90.11 138.18 8952.35 8866.31 -1829.70 2761.51 5957306.98 602225.29 3306.59 5.42 MWD 10322.55 92.23 132.93 8951.58 8865.54 -1856.72 2788.01 5957280.32 602252.13 3344.00 14.95 MWD 10351.87 88.39 129.09 8951.42 8865.38 -1875.95 2810.12 5957261.38 602274.50 3373.24 18.52 MWD 10383.41 88.51 125.58 8952.27 8866.23 -1895.07 2835.19 5957242.60 602299.81 3404.76 11.13 MWD 10425.24 89.16 121.50 8953.12 8867.08 -1918.17 2870.04 5957219.96 602334.96 3446.50 9.87 MWD 10463.91 89.43 116.38 8953.60 8867.56 -1936.87 2903.87 5957201.71 602369.03 3484.77 13.26 MWD 10497.59 90.72 113.42 8953.55 8867.51 -1951.05 2934.41 5957187.94 602399.76 3517.70 9.59 MWD 10528.24 89.89 110.05 8953.39 8867.35 -1962.40 2962.88 5957176.97 602428.37 3547.26 11.32 MWD 10558.36 88.48 106.40 8953.82 8867.78 -1971.82 2991.48 5957167.93 602457.09 3575.77 12.99 MWD 10591.74 86.52 103.70 8955.28 8869.24 -1980.47 3023.68 5957159.70 602489.40 3606.70 9.99 MWD 10622.07 86.82 107.61 8957.04 8871.00 -1988.64 3052.83 5957151.92 602518.65 3634.89 12.91 MWD 10654.10 87.90 111.91 8958.51 8872.47 -1999.46 3082.93 5957141.50 602548.89 3665.44 13.83 MWD 10689.64 87.37 115.11 8959.98 8873.94 -2013.62 3115.49 5957127.77 602581.63 3699.97 9.12 MWD 10722.90 86.27 119.88 8961.83 8875.79 -2028.95 3144.94 5957112.84 602611.28 3732.71 14.70 MWD 10753.94 85.98 124.05 8963.93 8877.89 -2045.34 3171.21 5957096.80 602637.76 3763.55 13.44 MWD 10784.92 84.60 126.46 8966.47 8880.43 -2063.16 3196.42 5957079.32 602663.20 3794.41 8.94 MWD 10816.43 84.52 130.35 8969.46 8883.42 -2082.64 3220.99 5957060.16 602688.03 3825.76 12.29 MWD 10860.88 85.83 130.86 8973.20 8887.16 -2111.47 3254.62 5957031.79 602722.03 3869.97 3.16 MWD 10890.73 85.86 128.49 8975.36 8889.32 -2130.47 3277.53 5957013.09 602745.19 3899.71 7.92 MWD 10921.45 86.67 125.10 8977.36 8891.32 -2148.83 3302.08 5956995.06 602769.98 3930.36 11.32 MWD ObP .Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report .¡¡. BAKU HUGIIIS ~--~-- INTEQ Company: BP Amoco Date: 4/11/2005 Time: 09:48:13 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Z-39, True North Site: PB Z Pad Vertical (TVD) Reference: Z-39: 86.0 Well: Z-39 Section (VS) Reference: Well (0.00N,O.00E,127.00Azi) Wellpath: Z-39A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/10Oft 10949.92 86.45 123.05 8979.07 8893.03 -2164.75 3325.62 5956979.45 602793.72 3958.74 7.23 MWD 10980.78 86.64 120.36 8980.93 8894.89 -2180.94 3351.82 5956963.61 602820.13 3989.40 8.72 MWD 11010.54 83.51 117.97 8983.49 8897.45 -2195.39 3377.70 5956949.51 602846.21 4018.77 13.21 MWD 11042.52 82.70 113.61 8987.33 8901.29 -2209.20 3406.28 5956936.08 602874.96 4049.91 13.77 MWD 11083.26 81.49 1 08.43 8992.93 8906.89 -2223.67 3443.94 5956922.11 602912.80 4088.69 12.94 MWD 11116.09 84.06 104.12 8997.06 8911.02 -2232.79 3475.19 5956913.40 602944.17 4119.14 15.19 MWD 11156.70 83.65 99.72 9001.41 8915.37 -2241.13 3514.69 5956905.59 602983.77 4155.70 10.82 MWD 11186.03 83.87 105.36 9004.60 8918.56 -2247.46 3543.14 5956899.64 603012.30 4182.23 19.13 MWD 11222.11 85.07 111.24 9008.08 8922.04 -2258.73 3577.22 5956888.82 603046.52 4216.23 16.56 MWD 11250.45 85.62 117.50 9010.39 8924.35 -2270.38 3602.93 5956877.51 603072.39 4243.78 22.10 MWD 11280.20 84.66 121.44 9012.91 8926.87 -2284.96 3628.73 5956863.27 603098.38 4273.16 13.58 MWD 11310.31 83.85 126.65 9015.92 8929.88 -2301.73 3653.55 5956846.84 603123.41 4303.07 17.43 MWD 11340.16 82.72 131.94 9019.42 8933.38 -2320.49 3676.48 5956828.38 603146.59 4332.68 18.00 MWD 11380.68 83.74 137.91 9024.20 8938.16 -2348.89 3704.96 5956800.36 603175.43 4372.51 14.85 MWD 11412.16 83.25 141.32 9027.76 8941.72 -2372. 71 3725.22 5956776.81 603196.01 4403.03 10.87 MWD 11442.62 82.41 138.17 9031.57 8945.53 -2395.78 3744.75 5956754.01 603215.83 4432.50 10.62 MWD 11473.95 82.14 133.27 9035.78 8949.74 -2418.00 3766.41 5956732.08 603237.79 4463.18 15.52 MWD 11507.81 83.11 129.25 9040.13 8954.09 -2440.14 3791.65 5956710.28 603263.32 4496.66 12.12 MWD 11526.07 82.99 126.46 9042.34 8956.30 -2451.26 3805.96 5956699.35 603277.77 4514.78 15.18 MWD 9,3#, L-80. .0081 ID '" 2.992" It ~~i%~Œ lID~ i%~i%~æi% . A. ItA..SIiA. OIL AlÐ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-39A BP Exploration (Alaska) Inc. Permit No: 204-224 Surface Location: 4300' NSL, 3237' WEL, SEC. 19, TUN, R12E, UM Bottomhole Location: 1872' NSL, 599' EWL, SEC. 20, T11N, R12E, UM Dear Mr. McLaughlin: 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 ·tness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (p ger). BY ORDER 2t!HE COMMISSION DATED thiSt- day of November, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA . ALAS~ OIL AND GAS CONSERVATION ~MMISSION PERMIT TO DRILL 20 MC 25.005 /' v,.JGA- 11/ 4J¿oo4 \f \, ;2004 1 a. Type of work D Drill II Redrill rb. Current Well Class D Exploratory II DeveloþmeritOilC MwtlpIEÍ.-Zøne < < D Re-Entry D Stratigraphic Test D Service D Development Gas D Singl~ Zone 2. Operator Name: 5. Bond: 1m Blanket o Single Well 11. Well Name and Number: c' BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU Z-39A "'. 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11550 TVD 892055 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028262 4300' NSL, 3237' WEL, SEC. 19, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3097' NSL, 1025'WEL, SEC. 19, T11N, R12E, UM December 20, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1872' NSL, 599' EWL, SEC. 20, T11 N, R12E, UM 2560 9150' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 599440 y-5959099 Zone- ASP4 (Height above GL): 86.04' feet 1250' 16. Deviated Wells: Kickoff Depth: 9283 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.!~~5) Maximum Hole Angle: 101 deç¡rees Downhole: 3600 Surface: 2720 18. . Ca$il1p~I!"!:!: """, .. ..:............ .......... ~åCkS),... zé < <, '"1"' !p.. ,c"," c...~,;. ,; ..' " Hole Casino WeiQht Grade Couclina Lenath MD TVD MD TVD (including staae data) 3" 2-3/8" 4.6# L-80 ST-L 2500' 9050' 8486' 11550' 8920' 61 sx Class 'G' .19. PRESEN."1" WELL CONDJ"llON. SUMf)1~~Y(To be comp.leted forg~qôll~N(')Re+~n~ryOPer~tíQI')$) ; Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 9700 9216 None 9612 9129 None ..., ;<. ", ~!~~;ii ! "", ./;? lIu!:!,. \;tMP'; ,i, ~ø t I r.nnrlur.tnr 113' 20" 260 sx Arcticset (Approx.) 113' 113' 2989' 9-5/8" 670 sx Arcticset Lite III, 221 sx Class 'G' 3023' 2959' Intl'!rml'!rli~tl'! 9241' 7" 351 sx LiteCrete, 100 sx Class 'G' 9273' 8793' Production I inl'!r 630' 4-1/2" 78 sx Class 'G' 9070' - 9700' 8592' - 9216' Perforation Depth MD (ft): 9380' - 9516' IPerfOration Depth TVD (ft): 8899' - 9034' 20. Attachments 1m Filing Fee, $100 1m BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer (.-. lult~ Date II lei...../O:-( Prepared By Name/Number: SiQnature Phone 564-4694 Terrie Hubble, 564-4628 ,......, ? ?~ .' ;; ';;; ",'¡;:i, ;;¡m/i·;.< '?iT 1';. "«.;.<;. ';<;' ?! ;; Permit To Drill API Number: Permit APpr%¡¿ I ~ee cover letter for Number: 207l~ 2.2.. S! 50- 029-22995-01-00 Date: / /, ~ It) t.f other requirements Conditions of Approval: Samples Required DYes E)'No Mud Log Required o Yes ~No y;:::¡e, Sultide Measures RT'Yes DNo Directional Survey Required )8Yes D No OtherT~p~ I !;ÇOO p< . I//J W Aonmved sf -/Î ~ n R I h I f\l ^ I APPROVED BY THE COMMISSION Date Form 10-401 Revise! 1-e612004 "- -....,'&... ~u'rlm! In Óuplicate . BP Z-39A Sidetrack . CTD Sidetrack Summary 1) Run mechanical WS 2) Plugback Z-39 3) Mill window off whipstock 4) Drill sidetrack 5) Run liner, cement and perforate Mud Program: · Well kill: 8.4 - 8.9 ppg QJine · Milling/drilling: 8.5 -~g used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8" solid cemented liner completion 9050' --41550'. · The liner cement volume is planned to be-A251>bls of 15.8 ppg class G. Casin2lLiner Information G;;? 95/8", L-80, 40#, Burst 5750, collapse 3090 psi 7", L-80, 26#, Burst 7240;collapse 5410 psi /- 4-1/2", L-80, 12.6#, Burst 8431, collapse 7500 psi 3-1/2", L-80, 9.3#, Burst 10159, collapse 10533 psi Planned Liner 2 3/8" L-80 STL 4.6#, Burst 11200 psi; collapse 11780 psi (hole size 3.0") Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. ./ · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 100 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property line: 9150' ft · Distance to nearest well within pool: 1250 ft Logging · MWD directional and Gamma Ray will be run over all of the openhole section. · MCNL will be run cased hole. Hazards · Z pad is not designated as an H2S pad. --- · There are two planned fault crossing. · Lost circulation risk is considered medium. Reservoir Pressure · Res. press. is estimated to be 3600 psi at 8800'ss (7.9 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2720 psi. /" 5&'00 - ~.go : 2. 7Z 0 TREE:' 4-1/16" CWV . . I I WELLHEAD = FMC SAFETY NOTES: ACTUA TOR = BAKER Z-39 KB. ELEV - 86.04' BF. ELEV - 54.87' KOP= 2200' ~ 1074' 1-19-5/8" TAM PORT COLLAR I Max Angle = 27 @ 3518' Datum MD = 9367' I 2014' 1-13-1/2" HES X NIP, ID = 2.813" I Datum 1VD = 8800' SS I I 9-5/8" CSG, 40#, L-80, ID = 8.835" I 3023' 1----4 ~ GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE Minimum ID = 2.750" @ 9063" L f-- I-- 6 3106 2947 26 MMG DOME RK 16 08/29/03 3-1/2" HES XN NIPPLE 5 4756 4429 26 MMG DOME RK 16 08/29/03 4 5836 5406 26 MMG DOME RK 16 08/29/03 3 6943 6437 17 MMG SO RK 24 08/29/03 2 7960 7419 12 MMG DMY RK 0 08/29/03 1 8966 8403 8 MMG DMY RK 0 03/17/02 I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" : I .-- 8994' 1-l3-1/2"HESXNIP,ID=2.813" I ~ ' 9016' 1...17" x 4-1/2" BKR S-3 A<R, ID = 3.875" I ~ , I .-- 9042' !-l3-1/2" HES x NIP, ID = 2.813" I I I 9063' "3-1/2" HES XN NIP, ID = 2.750" I I , r 9070' -lTOPOF BKR TIEBACK SLV, ID = 5.250" I I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 9074' I I ~¡ V 9075' J 3-1/2" WLEG, ID = 2.992"1 ï - 9077' - 7" X 4-1/2" BKR ZXP A<R, ID = 4.405" I ---- 9083' -1 7" X 4-1/2" BKR HMC HGR, ID = 4.450" I I 9069' 1-1 ELMD TT LOGGED 02/25/02? I I 7" CSG, 26#, L-80, ID = 6.276" I 9273' ~ PERFORA TION SUMMARY REF LOG: **MWD GRlRES ON 02/25/02 ANGLE AT TOP PERF: 8° @ 9380' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/2" 6 9380 - 9405 0 04/05/02 2-1/2" 6 9420 - 9435 0 04/05/02 2-1/2" 6 9440 - 9450 0 04/05/02 2-1/2" 6 9477 - 9485 0 04/05/02 2-1/2" 6 9494 - 9516 0 04/05/02 I PBTD I 9612' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9700' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 03/17/02 ORIGINAL COM PLETION WELL: Z-39 03/29/02 CHITP CORRECTIONS PERMIT No: 2002080 04/05/02 TMNltlh ADD PERFS API No: 50-029-22995-00 07/22/03 JBMlKK GLV C/O SEC 19, T11 N, R12E, 4301' NSL & 3238' WEL 08/29/03 JLJ/KK GLV C/O BP Exploration (Alaska) SAFETY NOTES: GAS liFT MANDRElS DATE 3-1/2" TBG, 9.3#, l·80, ID ~ 2.992" PERFORA TION SUMMARY REF LOG: **MWD GRlRES ON ANGLE AT TOP PERF: 8° @ 9380' Note: Refer to Production DB for historical ert data INTERV AL Opn/Sqz 9380 - 9405 9420 - 9435 9440 9450 9477 9485 9494 - 9516 4-1/2" LNR, 12.6#, Obp . . BP-GDB Baker Hughes INTEQ Planning Report ... ..... lNT&Q Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Z Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957230.17 ft 601304.82 ft Latitude: 70 17 Longitude: 149 10 North Reference: Grid Convergence: 33.051 N 47.365 W True 0.77 deg Well: Z-39 Slot Name: Well Position: +N/-S 1894.78 ft Northing: 5959099.82 ft Latitude: +E/-W -1839.57 ft Easting: 599440.05 ft Longitude: Position Uncertainty: 0.00 ft 70 17 51.684 N 149 11 40.988 W Wellpath: Plan#5 Z-39A 500292299501 Current Datum: Z-39: Magnetic Data: 10/27/2004 Field Strength: 57596 nT Vertical Section: Depth From (TVD) ft 33.24 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Z-39 9230.28 ft Mean Sea Level 24.76 deg 80.78 deg Direction deg 127.00 Height 86.04 ft Targets Z-39A Polygon4.1 0.00 -1420.14 2121.54 5957708.00 601580.00 70 17 37.714 N 149 10 39.158 W -Polygon 1 0.00 -1420.14 2121.54 5957708.00 601580.00 70 17 37.714 N 149 10 39.158 W -Polygon 2 0.00 -1965.55 2674.42 5957170.00 602140.00 70 17 32.348 N 149 10 23.050 W -Polygon 3 0.00 -2697.79 3967.96 5956455.00 603443.00 70 1725.141 N 149 9 45.365 W -Polygon 4 0.00 -2344.26 4083.65 5956810.00 603554.00 70 17 28.617 N 149 941.988 W -Polygon 5 0.00 -1679.97 2861.23 5957458.00 602323.00 70 17 35.156 N 149 10 17.603 W -Polygon 6 0.00 -1185.46 2451.70 5957947.00 601907.00 70 17 40.021 N 149 10 29.533 W Z-39A Fault 1 0.00 -1283.52 1850.30 5957841.00 601307.00 70 17 39.058 N 149 10 47.062 W -Polygon 1 0.00 -1283.52 1850.30 5957841.00 601307.00 70 17 39.058 N 149 10 47.062 W -Polygon 2 0.00 -1243.38 2217.89 5957886.00 601674.00 70 17 39.452 N 149 10 36.348 W -Polygon 3 0.00 -986.98 2493.33 5958146.00 601946.00 70 1741.973 N 149 10 28.318 W -Polygon 4 0.00 -1243.38 2217.89 5957886.00 601674.00 70 17 39.452 N 149 10 36.348 W Z-39A Regional Fault 1 0.00 -1705.21 384.46 5957400.00 599847.00 70 17 34.913 N 149 11 29.784 W -Polygon 1 0.00 -1705.21 384.46 5957400.00 599847.00 70 17 34.913 N 149 1129.784W -Polygon 2 0.00 -1975.70 1325.05 5957142.00 600791.00 70 17 32.252 N 149 11 2.374 W -Polygon 3 0.00 -3001.61 3571.87 5956146.00 603051.00 70 17 22.155 N 149 956.911 W -Polygon 4 0.00 -1975.70 1325.05 5957142.00 600791.00 70 17 32.252 N 149 11 2.374 W Z-39A Regional Fault 2 0.00 -999.74 811.87 5958111.00 600265.00 70 1741.851 N 149 11 17.326 W -Polygon 1 0.00 -999.74 811.87 5958111.00 600265.00 70 1741.851 N 149 11 17.326 W -Polygon 2 0.00 -647.98 2875.88 5958490.00 602324.00 70 1745.305 N 149 10 17.164 W Z-39A Fault 2 0.00 -2012.24 2801.82 5957125.01 602268.00 70 17 31.888 N 149 10 19.338 W -Polygon 1 0.00 -2012.24 2801.82 5957125.01 602268.00 70 17 31.888 N 149 10 19.338 W -Polygon 2 0.00 -1453.24 2960.25 5957686.01 602419.00 70 17 37.385 N 149 10 14.714 W -Polygon 3 0.00 -1257.78 3305.89 5957886.01 602762.00 70 17 39.306 N 149 10 4.638 W -Polygon 4 0.00 -1453.24 2960.25 5957686.01 602419.00 70 17 37.385 N 149 10 14.714 W Z-39A Regional Fault 3 0.00 -738.68 3305.76 5958405.01 602755.00 70 1744.412 N 149 10 4.636 W -Polygon 1 0.00 -738.68 3305.76 5958405.01 602755.00 70 1744.412 N 149 10 4.636 W Obp . BP-GDB Baker Hughes INTEQ Planning Report . ... ..... INTRQ -Polygon 2 0.00 -1932.88 4287.13 5957224.01 603752.00 70 17 32.662 N 149 9 36.052 W Z-39A Regional Fault 4 0.00 -1920.56 4263.29 5957236.01 603728.00 70 17 32.783 N 149 9 36.746 W -Polygon 1 0.00 -1920.95 4293.29 5957236.01 603758.00 70 17 32.779 N 149 9 35.872 W -Polygon 2 0.00 -3172.05 4510.78 5955988.01 603992.00 70 1720.473 N 149 9 29.556 W Z-39A T4.1 8815.00 -1331.08 2193.73 5957798.00 601651.00 70 17 38.589 N 149 10 37.053 W Z-39A T4.3 8865.00 -1772.60 2756.98 5957364.01 602220.00 70 17 34.245 N 149 10 20.642 W Z-39A T4.4 8920.00 -2428.13 3846.50 5956723.01 603318.00 70 17 27.793 N 149 9 48.900 W Z-39A T4.2 8945.00 -1458.22 2354.07 5957673.00 601813.00 70 17 37.338 N 149 10 32.381 W Annotation 9230.28 8664.59 TIP 9283.00 8716.80 KOP 9303.00 8736.57 end 9 DLS / begin 33 DLS 9353.00 8784.44 4 9403.00 8829.59 5 9591.07 8935.81 end 33 DLS / begin 15 DLS 9722.96 8945.08 7 9810.30 8937.46 8 9960.30 8910.58 9 10130.30 8879.04 10 10280.30 8865.01 11 10530.30 8870.73 12 10780.30 8882.36 13 11030.30 8894.33 14 11280.30 8906.59 15 11530.30 8919.06 16 11550.00 8920.02 TO 9440.00 8860.61 Fault 1 10380.00 8865.95 Fault 2 Plan: Plan #5 Date Composed: 10/27/2004 Truncated Plan #4 with modified TD TVD Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9230.28 8.14 117.03 8664.59 -1189.76 2194.46 0.00 0.00 0.00 0.00 9283.00 7.80 118.48 8716.80 -1193.17 2200.93 0.75 -0.64 2.75 150.12 9303.00 9.51 122.21 8736.57 -1194.69 2203.52 9.00 8.56 18.64 20.00 9353.00 23.73 154.94 8784.44 -1206.09 2211.33 33.00 28.43 65.46 50.00 9403.00 28.63 191.30 8829.59 -1227.09 2213.26 33.00 9.80 72.72 90.00 9591.07 82.00 148.19 8935.81 -1364.06 2257.98 33.00 28.38 -22.92 310.00 9722.96 90.00 130.03 8945.08 -1462.95 2343.75 15.00 6.07 -13.76 293.00 9810.30 100.00 121.52 8937.46 -1513.75 2414.16 15.00 11.45 -9.74 320.00 9960.30 100.38 144.39 8910.58 -1613.63 2521.46 15.00 0.25 15.24 87.00 10130.30 100.65 118.45 8879.04 -1723.21 2645.65 15.00 0.16 -15.26 273.00 10280.30 90.00 138.38 8865.01 -1815.58 2761.77 15.00 -7.10 13.29 117.00 10530.30 87.47 100.95 8870.73 -1937.13 2975.07 15.00 -1.01 -14.97 265.85 10780.30 87.39 138.49 8882.36 -2058.74 3188.08 15.00 -0.03 15.02 91.00 11030.30 87.32 100.95 8894.33 -2180.35 3401.08 15.00 -0.03 -15.02 269.00 11280.30 87.26 138.50 8906.59 -2301.94 3614.07 15.00 -0.02 15.02 91.00 11530.30 87.22 100.95 8919.06 -2423.54 3827.05 15.00 -0.02 -15.02 269.00 O· bp " ,. . . BP-GDB Baker Hughes INTEQ Planning Report .JIl1- ...... INTEQ 9230.28 8.14 117.03 8664.59 -1189.76 2194.46 5957939.30 601649.86 2468.59 0.00 0.00 TIP 9250.00 8.01 117.56 8684.11 -1191.03 2196.92 5957938.06 601652.34 2471.32 0.75 150.12 MWD 9275.00 7.85 118.25 8708.87 -1192.65 2199.97 5957936.49 601655.41 2474.73 0.75 149.60 MWD 9283.00 7.80 118.48 8716.80 -1193.17 2200.93 5957935.98 601656.38 2475.80 0.75 148.91 KOP 9300.00 9.25 121.74 8733.61 -1194.43 2203.10 5957934.74 601658.57 2478.31 9.00 20.00 MWD 9303.00 9.51 122.21 8736.57 -1194.69 2203.52 5957934.49 601658.99 2478.79 9.00 16.78 end 9 9325.00 15.22 143.85 8758.06 -1198.00 2206.76 5957931.23 601662.28 2483.37 33.00 50.00 MWD 9350.00 22.79 154.14 8781.69 -1205.02 2210.82 5957924.27 601666.42 2490.84 33.00 28.83 MWD 9353.00 23.73 154.94 8784.44 -1206.09 2211.33 5957923.20 601666.95 2491.89 33.00 19.07 4 9375.00 24.75 172.51 8804.53 -1214.67 2213.81 5957914.65 601669.54 2499.03 33.00 90.00 MWD 9386.59 26.05 180.90 8815.00 -1219.63 2214.08 5957909.70 601669.88 2502.24 33.00 73.96 Z-39A 9400.00 28.10 189.53 8826.95 -1225.69 2213.51 5957903.63 601669.39 2505.43 33.00 66.38 MWD 9403.00 28.63 191.30 8829.59 -1227.09 2213.26 5957902.23 601669.15 2506.07 33.00 58.68 5 9425.00 33.71 181.25 8848.42 -1238.38 2212.09 5957890.93 601668.13 2511.93 33.00 310.00 MWD 9440.00 37.55 175.88 8860.61 -1247.10 2212.33 5957882.21 601668.49 2517.37 33.00 318.61 Fault 1 9445.60 39.04 174.12 8865.00 -1250.56 2212.63 5957878.76 601668.84 2519.69 33.00 322.98 Z-39A 9450.00 40.23 172.81 8868.39 -1253.35 2212.95 5957875.97 601669.19 2521.62 33.00 324.36 MWD 9475.00 47.21 166.43 8886.46 -1270.30 2216.12 5957859.06 601672.59 2534.36 33.00 325.37 MWD 9500.00 54.47 161.37 8902.24 -1288.89 2221.53 5957840.55 601678.24 2549.87 33.00 329.99 MWD 9525.00 61.91 157.16 8915.41 -1308.73 2229.07 5957820.81 601686.05 2567.83 33.00 333.20 MWD 9535.27 65.00 155.61 8920.00 -1317.15 2232.76 5957812.45 601689.84 2575.84 33.00 335.42 Z-39A 9550.00 69.46 153.51 8925.70 -1329.41 2238.59 5957800.27 601695.84 2587.88 33.00 336.11 MWD 9575.00 77.08 150.20 8932.89 -1350.49 2249.89 5957779.33 601707.41 2609.59 33.00 336.93 MWD 9591.07 82.00 148.19 8935.81 -1364.06 2257.98 5957765.88 601715.68 2624.22 33.00 337.88 end 33 9600.00 82.53 146.94 8937.01 -1371.53 2262.73 5957758.47 601720.52 2632.50 15.00 293.00 MWD 9625.00 84.01 143.48 8939.94 -1391.91 2276.89 5957738.28 601734.96 2656.08 15.00 293.17 MWD 9650.00 85.52 140.03 8942.22 -1411.46 2292.30 5957718.94 601750.62 2680.15 15.00 293.57 MWD 9675.00 87.05 136.60 8943.84 -1430.09 2308.89 5957700.53 601767.45 2704.61 15.00 293.89 MWD 9700.00 88.58 133.17 8944.80 -1447.71 2326.59 5957683.15 601785.38 2729.35 15.00 294.11 MWD 9722.96 90.00 130.03 8945.08 -1462.95 2343.75 5957668.14 601802.74 2752.23 15.00 294.24 7 9725.00 90.23 129.84 8945.08 -1464.26 2345.32 5957666.85 601804.33 2754.27 15.00 320.00 MWD 9750.00 93.11 127.42 8944.35 -1479.86 2364.84 5957651.51 601824.05 2779.24 15.00 320.00 MWD 9775.00 95.97 125.00 8942.37 -1494.58 2384.94 5957637.06 601844.34 2804.16 15.00 319.93 MWD 9800.00 98.83 122.55 8939.15 -1508.36 2405.54 5957623.55 601865.13 2828.91 15.00 319.74 MWD 9810.30 100.00 121.52 8937.46 -1513.75 2414.16 5957618.28 601873.81 2839.03 15.00 319.42 8 9825.00 100.11 123.76 8934.90 -1521.56 2426.34 5957610.63 601886.10 2853.46 15.00 87.00 MWD 9850.00 100.26 127.57 8930.48 -1535.90 2446.33 5957596.56 601906.27 2878.06 15.00 87.39 MWD 9875.00 100.36 131.38 8926.00 -1551.53 2465.31 5957581.18 601925.46 2902.62 15.00 88.06 MWD 9900.00 100.42 135.19 8921.49 -1568.39 2483.21 5957564.56 601943.57 2927.06 15.00 88.75 MWD 9925.00 100.44 139.00 8916.96 -1586.40 2499.95 5957546.78 601960.54 2951.26 15.00 89.43 MWD 9950.00 1 00.40 142.82 8912.44 -1605.48 2515.45 5957527.91 601976.29 2975.13 15.00 90.12 MWD 9960.30 100.38 144.39 8910.58 -1613.63 2521 .46 5957519.83 601982.41 2984.84 15.00 90.81 9 9975.00 1 00.49 142.15 8907.92 -1625.22 2530.10 5957508.37 601991.21 2998.71 15.00 273.00 MWD 10000.00 100.63 138.34 8903.34 -1644.11 2545.82 5957489.69 602007.17 3022.63 15.00 272.59 MWD 10025.00 100.73 134.52 8898.70 -1661.90 2562.75 5957472.12 602024.33 3046.86 15.00 271.90 MWD 10050.00 100.79 130.70 8894.03 -1678.53 2580.82 5957455.74 602042.62 3071.30 15.00 271.19 MWD 10075.00 100.80 126.89 8889.35 -1693.91 2599.96 5957440.61 602061.96 3095.84 15.00 270.48 MWD 10100.00 100.76 123.07 8884.67 -1707.99 2620.07 5957426.80 602082.26 3120.38 15.00 269.76 MWD Obp .. BP-GDB Baker Hughes INTEQ Planning Report ..I: INTEQ 10125.00 100.67 119.25 8880.02 -1720.70 2641.09 5957414.37 602103.44 3144.81 15.00 269.05 MWD 10130.30 100.65 118.45 8879.04 -1723.21 2645.65 5957411.92 602108.04 3149.97 15.00 268.34 10 10150.00 99.30 121.11 8875.63 -1732.84 2662.49 5957402.51 602125.00 3169.21 15.00 117.00 MWD 10175.00 97.55 124.47 8871.97 -1746.24 2683.28 5957389.39 602145.96 3193.87 15.00 117.46 MWD 10200.00 95.78 127.80 8869.06 -1760.88 2703.33 5957375.02 602166.20 3218.69 15.00 117.95 MWD 10225.00 93.99 131.11 8866.93 -1776.70 2722.55 5957359.45 602185.63 3243.58 15.00 118.34 MWD 10250.00 92.19 134.40 8865.58 -1793.65 2740.88 5957342.75 602204.18 3268.41 15.00 118.62 MWD 10275.00 90.38 137.68 8865.02 -1811.63 2758.23 5957325.00 602221.76 3293.09 15.00 118.80 MWD 10280.30 90.00 138.38 8865.01 -1815.58 2761.77 5957321.10 602225.36 3298.29 15.00 118.87 11 10300.00 89.78 135.43 8865.04 -1829.96 2775.23 5957306.90 602239.00 3317.69 15.00 265.85 MWD 10325.00 89.51 131.69 8865.20 -1847.19 2793.34 5957289.92 602257.34 3342.52 15.00 265.86 MWD 10350.00 89.25 127.95 8865.47 -1863.19 2812.54 5957274.17 602276.74 3367.49 15.00 265.88 MWD 10375.00 88.98 124.21 8865.85 -1877.91 2832.73 5957259.72 602297.13 3392.48 15.00 265.92 MWD 10380.00 88.93 123.46 8865.95 -1880.70 2836.89 5957256.99 602301.32 3397.47 15.00 265.98 Fault 2 10400.00 88.72 120.47 8866.36 -1891.28 2853.85 5957246.63 602318.42 3417.39 15.00 265.99 MWD 10425.00 88.46 116.73 8866.97 -1903.24 2875.79 5957234.96 602340.51 3442.11 15.00 266.05 MWD 10450.00 88.22 112.99 8867.70 -1913.75 2898.46 5957224.76 602363.32 3466.53 15.00 266.14 MWD 10475.00 87.97 109.24 8868.53 -1922.74 2921.76 5957216.07 602386.74 3490.56 15.00 266.25 MWD 10500.00 87.74 105.50 8869.46 -1930.20 2945.60 5957208.93 602410.67 3514.09 15.00 266.38 MWD 10525.00 87.52 101.75 8870.50 -1936.08 2969.87 5957203.37 602435.01 3537.01 15.00 266.52 MWD 10530.30 87.47 100.95 8870.73 -1937.13 2975.07 5957202.40 602440.22 3541.78 15.00 266.67 12 10550.00 87.42 103.91 8871.60 -1941.36 2994.28 5957198.42 602459.49 3559.68 15.00 91.00 MWD 10575.00 87.37 107.66 8872.74 -1948.15 3018.31 5957191.94 602483.60 3582.96 15.00 90.87 MWD 10600.00 87.33 111.42 8873.89 -1956.51 3041.84 5957183.90 602507.24 3606.78 15.00 90.70 MWD 10625.00 87.31 115.17 8875.06 -1966.38 3064.77 5957174.34 602530.30 3631.03 15.00 90.52 MWD 10650.00 87.29 118.93 8876.24 -1977.74 3087.01 5957163.28 602552.68 3655.63 15.00 90.35 MWD 10675.00 87.28 122.68 8877.43 -1990.52 3108.45 5957150.78 602574.29 3680.45 15.00 90.17 MWD 10700.00 87.29 126.44 8878.61 -2004.68 3129.02 5957136.89 602595.04 3705.39 15.00 89.99 MWD 10725.00 87.31 130.19 8879.79 -2020.16 3148.61 5957121.67 602614.83 3730.35 15.00 89.82 MWD 10750.00 87.34 133.94 8880.96 -2036.89 3167.14 5957105.19 602633.58 3755.22 15.00 89.64 MWD 10775.00 87.38 137.70 8882.11 -2054.80 3184.54 5957087.52 602651.22 3779.90 15.00 89.46 MWD 10780.30 87.39 138.49 8882.36 -2058.74 3188.08 5957083.62 602654.81 3785.10 15.00 89.29 13 10800.00 87.34 135.54 8883.26 -2073.13 3201.50 5957069.41 602668.41 3804.47 15.00 269.00 MWD 10825.00 87.29 131.78 8884.43 -2090.37 3219.56 5957052.42 602686.70 3829.27 15.00 269.14 MWD 10850.00 87.25 128.03 8885.63 -2106.39 3238.71 5957036.66 602706.06 3854.20 15.00 269.31 MWD 10875.00 87.22 124.27 8886.83 -2121.11 3258.87 5957022.20 602726.41 3879.17 15.00 269.49 MWD 10900.00 87.21 120.52 8888.05 -2134.49 3279.95 5957009.10 602747.66 3904.05 15.00 269.67 MWD 10925.00 87.20 116.76 8889.27 -2146.46 3301.86 5956997.43 602769.73 3928.75 15.00 269.85 MWD 10950.00 87.21 113.01 8890.49 -2156.96 3324.51 5956987.22 602792.51 3953.16 15.00 270.04 MWD 10975.00 87.23 109.26 8891.70 -2165.96 3347.80 5956978.53 602815.91 3977.18 15.00 270.22 MWD 11000.00 87.26 105.50 8892.90 -2173.42 3371.62 5956971.39 602839.83 4000.70 15.00 270.40 MWD 11025.00 87.31 101.75 8894.08 -2179.30 3395.89 5956965.83 602864.17 4023.61 15.00 270.58 MWD 11030.30 87.32 100.95 8894.33 -2180.35 3401.08 5956964.86 602869.38 4028.39 15.00 270.76 14 11050.00 87.27 103.91 8895.26 -2184.58 3420.29 5956960.88 602888.64 4046.28 15.00 91.00 MWD 11075.00 87.22 107.66 8896.46 -2191.37 3444.32 5956954.41 602912.75 4069.56 15.00 90.86 MWD 11100.00 87.18 111.42 8897.69 -2199.72 3467.85 5956946.37 602936.39 4093.37 15.00 90.68 MWD 11125.00 87.16 115.17 8898.92 -2209.60 3490.78 5956936.80 602959.45 4117.63 15.00 90.50 MWD 11150.00 87.14 118.93 8900.17 -2220.95 3513.01 5956925.74 602981.83 4142.21 15.00 90.31 MWD 11175.00 87.14 122.68 8901.41 -2233.73 3534.45 5956913.25 603003.43 4167.03 15.00 90.12 MWD 11200.00 87.15 126.44 8902.66 -2247.89 3555.01 5956899.36 603024.18 4191.97 15.00 89.94 MWD 11225.00 87.17 130.19 8903.90 -2263.37 3574.60 5956884.14 603043.97 4216.93 15.00 89.75 MWD 11250.00 87.21 133.94 8905.12 -2280.10 3593.13 5956867.66 603062.72 4241.80 15.00 89.56 MWD . BP-GDB Baker Hughes INTEQ Planning Report . ... ..... lNTEQ Obp 11275.00 87.25 137.70 8906.33 -2298.00 3610.53 5956849.99 603080.35 4266.47 15.00 89.38 MWD 11280.30 87.26 138.50 8906.59 -2301.94 3614.07 5956846.10 603083.94 4271.67 15.00 89.20 15 11300.00 87.22 135.54 8907.54 -2316.34 3627.48 5956831.89 603097.54 4291.04 15.00 269.00 MWD 11325.00 87.17 131.78 8908.76 -2333.57 3645.54 5956814.89 603115.83 4315.84 15.00 269.14 MWD 11350.00 87.13 128.03 8910.01 -2349.59 3664.69 5956799.13 603135.18 4340.77 15.00 269.33 MWD 11375.00 87.10 124.27 8911.26 -2364.31 3684.85 5956784.68 603155.53 4365.73 15.00 269.51 MWD 11400.00 87.09 120.52 8912.53 -2377.69 3705.93 5956771.58 603176.78 4390.61 15.00 269.70 MWD 11425.00 87.09 116.76 8913.80 -2389.65 3727.84 5956759.91 603198.85 4415.31 15.00 269.89 MWD 11450.00 87.10 113.01 8915.07 -2400.16 3750.48 5956749.71 603221.63 4439.72 15.00 270.08 MWD 11475.00 87.12 109.25 8916.33 -2409.16 3773.77 5956741.01 603245.03 4463.73 15.00 270.27 MWD 11500.00 87.16 105.50 8917.58 -2416.62 3797.59 5956733.88 603268.95 4487.25 15.00 270.46 MWD 11525.00 87.21 101.75 8918.80 -2422.50 3821.86 5956728.32 603293.28 4510.16 15.00 270.65 MWD 11530.30 87.22 100.95 8919.06 -2423.54 3827.05 5956727.34 603298.49 4514.94 15.00 270.83 16 11550.00 87.17 103.91 8920.02 -2427.77 3846.26 5956723.36 603317.75 4532.83 15.00 91.00 TD Plan: Plan #5 (Z~391P¡an#5 Z~39A) Created By: Brii Potnis Date: 10/27/2004 I PM BP Amoco WELLPATH DETAlU Plan#5 Z-39A. 500%92299501 F'amnt WeUpath: %... Tteo!1Mt:I: 9230.28 Rig: Z>39¡ Be.64ft R<ri'.Dstum: V.Se.etkHI ~1li~ ~~~ ~::::~Ð ..... 1V'.OO· 0,00 .... 3'3.24 REFERENCE !NFORMA TION Co-ordinate (NfE) Reference: Vs:f¿~~~i ~~~~~~; Measured Depth Reference: Ca!culation Method· i 840cr £t. (D 1::1I8500 ~86' :e871 ~ (D881 :I t;.891 --200 ~250 --300 WELL DETAILS COMPANY DETAILS ANn-COLLISION SETTINGS 10,00 11550.00 Plan: P1an #5 Dqnh fm lkpth To Survey/Pla.n (¡2_~Ü_2¡': 11'i:"Onü P!<lJc\J\;.xL PI;", #5 VI 1-19 860411 Northing La.ti\ude t.olJgiwde 59)9099,82 59(144005 70ol7'S!_6M"I¡,N']1·40'ì¡(~\.V 326 ~300 250 200 150 100 50 o 50 100 150 326 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] SURVEY PROGRAM WEI.LI>ATH DETAILS P!¡¡¡¡íl5Z·39A 5002<>229<l501 !'aremWdlpath ¿·.W ¡,e¡;"MD 9?3(L28 Rig Ref Datu\JI VS~'C\iŒI Origin Angk, 'N/··S 0,00 Starting hX'nJ TVD 13.24 LEGEND Plan ¡vi Z-44p (Plan ¡vi Z-44p Plan lvi Z-44p (Plan ¡vi Z-44p Plan ¡vi Z-55p (Plan ¡vi Z-55p Z-39 (Z-39), NOERRORS Plan#5 Z-39A Plan #5 , ¡ fa II 12 II " 15 J~ PM Mf) me Plan: Plan (Z-39/Plan#5 9A) ¡::: o ....... ....... ro "..,; ro 0.. (j) r/J (j) "..,; ....... ¡::: (j) u o ....... (j) .t:í ¡::: (j) u 1 9000 9500 10000 11500 12000 10500 11000 Measured Depth Ivi (Z-39) . . ... ..... INTKQ Obp BP-GDB Anticollision Report 3023.00 9273.00 9283.00 11550.00 2958.60 8792.93 8802.84 9006.06 9.625 7.000 4.500 2.875 12.250 8.500 6.000 3.750 95/8" 7" 4 1/2" 2 7/8" Plan: Plan #5 Truncated Plan #4 with modified TD TVD Principal: Yes Date Composed: Version: Tied-to: 10/27/2004 1 From: Definitive Path PB Z Pad - ExpansiodPlan Ivi Z-44p PB Z Pad Plan Ivi Z-44p PB Z Pad Plan Ivi Z-55p PB Z Pad Z-39 Plan Ivi Z-44p VO Plan Plan Ivi Z-44p VO Plan Plan Ivi Z-55p VO Plan Z-39 V16 9290.00 9290.00 0.04 0.00 Pass: Major Risk Pass: Major Risk Out of range 0.04 Pass: NOERRORS Site: PB Z Pad - Expansion 2004 Well: Plan Ivi Z-44p Wellpath: Plan Ivi Z-44p VO Plan: Ivi Z-44p wp02 V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 11100.00 8983.73 8600.00 7750.68 57.32 25.31 87.88 336.46 8.500 1344.15 143.71 1200.43 Pass 11100.00 8983.73 8610.00 7759.51 57.32 25.35 87.76 336.34 8.500 1336.01 144.19 1191.82 Pass 11100.00 8983.73 8620.00 7768.34 57.32 25.38 87.64 336.22 8.500 1327.90 144.67 1183.23 Pass 11104.86 8983.96 8630.00 7777.17 57.52 25.47 88.20 336.06 8.500 1319.79 145.56 1174.23 Pass 11106.96 8984.07 8640.00 7785.99 57.60 25.53 88.37 335.91 8.500 1311.71 146.24 1165.47 Pass 11109.06 8984.17 8650.00 7794.82 57.68 25.59 88.54 335.77 8.500 1303.64 146.92 1156.72 Pass 11111.16 8984.28 8660.00 7803.65 57.77 25.64 88.71 335.62 8.500 1295.60 147.62 1147.98 Pass 11113.27 8984.38 8670.00 7812.48 57.85 25.70 88.87 335.46 8.500 1287.57 148.33 1139.25 Pass 11115.38 8984.48 8680.00 7821.31 57.93 25.75 89.03 335.31 8.500 1279.57 149.04 1130.52 Pass 11117.49 8984.59 8690.00 7830.13 58.02 25.81 89.19 335.15 8.500 1271.58 149.78 1121.80 Pass 11119.60 8984.69 8700.00 7838.96 58.10 25.86 89.35 334.99 8.500 1263.61 150.52 1113.09 Pass 11121.71 8984.80 8710.00 7847.79 58.19 25.92 89.50 334.82 8.500 1255.67 151.27 1104.39 Pass 11125.00 8984.96 8720.00 7856.62 58.32 25.98 89.82 334.65 8.500 1247.74 152.13 1095.61 Pass 11125.00 8984.96 8730.00 7865.45 58.32 26.01 89.66 334.49 8.500 1239.84 152.74 1087.10 Pass 11125.00 8984.96 8740.00 7874.27 58.32 26.05 89.51 334.33 8.500 1231.96 153.36 1078.61 Pass 11130.20 8985.22 8750.00 7883.10 58.47 26.12 90.08 334.13 8.500 1224.09 154.35 1069.75 Pass 11132.32 8985.32 8760.00 7891.93 58.54 26.17 90.22 333.95 8.500 1216.26 155.14 1061.12 Pass 11134.45 8985.43 8770.00 7900.76 58.60 26.22 90.36 333.77 8.500 1208.44 155.94 1052.50 Pass 11136.57 8985.54 8780.00 7909.59 58.66 26.27 90.49 333.58 8.500 1200.65 156.76 1043.89 Pass 11138.70 8985.64 8790.00 7918.41 58.73 26.32 90.62 333.~9 8.500 1192.88 157.58 1035.30 Pass 11140.83 8985.75 8800.00 7927.24 58.79 26.37 90.74 333.19 8.500 1185.14 158.42 1026.71 Pass 11142.96 8985.85 8810.00 7936.07 58.85 26.41 90.86 333.00 8.500 1177.42 159.28 1018.14 Pass 11145.09 8985.96 8820.00 7944.90 58.92 26.46 90.98 332.79 8.500 1169.73 160.15 1009.58 Pass 11150.00 8986.21 8830.00 7953.73 59.07 26.52 91.50 332.57 8.500 1162.07 161.21 1000.85 Pass 11150.00 8986.21 8840.00 7962.55 59.07 26.55 91.30 332.37 8.500 1154.42 161.97 992.45 Pass 11150.00 8986.21 8850.00 7971.38 59.07 26.59 91.10 332.18 8.500 1146.80 162.74 984.07 Pass 11153.62 8986.39 8860.00 7980.21 59.14 26.64 91.42 331.95 8.500 1139.21 163.71 975.50 Pass 11155.75 8986.49 8870.00 7989.04 59.18 26.68 91.52 331.73 8.500 1131.65 164.62 967.03 Pass All Measurements are from top of Riser ~ Q) en .- cr: top of bag bttm of bag ........................., middle of slips Blind/Shears middle of pipes .......................... middle of flow cross Mud Cross middle of blind/shears .......................... middle of pipe/slips .......................... Flow Tee 11/2/2004 Z -39A BAG TOTs Mud Cross TOTs . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ?ð0 7-.1?A PTD# 20~! "' 22 r X Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLJES (OPTIONS) MULTI Tbe permit is for a Dew we1lboresegmeut of LATERAL e:xistiug well . Permit No, API No. . (If API num ber Production. sbould continue to be reponed as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE )u accordance witb 20 AAC 25.005(f), al1 (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb Dame (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data aud logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPT) ON .' compliance witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex ception. (Companv Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample hiter:vaJs through target zones. .. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT Z-39A Program DEV Well bore seg PTD#: 2042240 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 1 P.e[ITJit fee attache.d . . . . . . . . . . . . . . . . . . . . . . . . .. Xe$..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 Lease number .apprORri<ite. . . . . . . . . . . .Ye$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .U.nique welt n.arn~.a!1d OUrTJQer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y.e$. . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WeUIQcated in.a.ctef¡ne.d.pool . . . . . . . . . . . . . . . . Xe$. . . . . . . . . . . . . . . . . . . . . . . . . 5 WeJIIQcated pr.oper .distance. from driJling unitb.ound.ary. . . . . . . . . . . . . Xe$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 We.ll IQcated proper .distance. from Qthe.r welJs. . . . . . . . . . . . . . . . . . . . . . . . . . . . Xe$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7S.uffjcientacreage.ayail<ible in.dJilIiog unJ!. . . . . . . . . . . . . . . . . . . . . . . . . .. .. Y.e$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Itd~viated, Js. weJlbQre plç¡tincJuded . . . . . . . . . . . . . . . . . . . Xe$. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Qperator only affected party. . . . . . . . . . . . . . . . . . . . . . . Xe$ . ....... . . . . . . . . . . . . . . . . . .. .... 10 .Qper.ator bas. appropriate. Qond inJorce. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Xe$ . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rrTJit GaO be iS$ued .wJtbQut co.n$erva.tion order. . . . . . . . . . . . . . . . . . . . . . . . . . . . Xe$. . . Appr Date 12 P.ermit GaO be iS$ued .wJtbQut actministratiye. appr.oval . . . . . Xe$ . . RPC 11/3/2004 13 Can permit be approved before 15-day wait Yes 14 We.IIIQcat~d within area <lnd strç¡ta authorized by.lojectioo Ord.er # (puUO# in.comrn.eots). (For .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 .AJI welJs.witJ1tn.1l4.mite.are.a.oJ reyiew id.eotified (For $ervJ~w.e!l OlJly). . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 PJe-producect iojector; .duratiQn.oJ pre-pro.dUGtion te$s. than 3 months. (For.sel'lltce well QnJy) . . NA . . . . . . . . . . . . . . . 17 ACMP.finding.ofCon.ststeocyha$ bee.nis.sued.fortbi$ project . . . . . . . NA . . . . . . 18 .Coodu.ctor string.PJQvided . . . . . . . . . . . . . . . . NA . . . . . . . . . . 19 .S.urf<l~.cas.ing.pJotects. aiL known USDWs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . 120 .CMTvoladeQuate.toçirc.ulate.o.n.cond.uctor.&$u.rf.C$g...... . . . . . . . . .NA. . .. . . . . . . . . .... . . . . . . . . . . . 21CMT v.ol adeQuate.to tie-inJQng .striog to.surf Ç$g. . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . . 22CMTwicoyeraJlJ<OQwnprQductiyehQrizons. ....................... Ye$......... 23 .C.asiog de.sigo$ acteClua.te for C,T, B&.permafr.o$t . . . . . . . . . Y.e$. . . . . _ 24 Adequ<iteJankç¡ge.orre.selYe pit. . . . . . . . . . . . . . . . . . . . . . . Xe$ . CTDU.. . . . . . . . . . . . . . . 25 JtaJe-drilL bas.a. 10Æ03 JQr .abandonment be~o apprQved . . . . . . . . . . . Xe$ . . . . . . . . . . . 26 Adequ<ite.wellbore. $eparatJo.n.propO$ed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.e$. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 JtdJverter Jeq.uiJed, dQes Jtmeet reguJations. . . . . . . . . . . . . . . . . . . . . . .NA . . . . Sidetrack.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 28 .DJilliogfJuJd.program$chematic.&eq.uiplistadequ<ite... ..................... Xes... . Mç¡xMW8,9RPgc ............................ WGA 11/4/2004 29 .B.oPES,dotheymeetregu.lation. ........ . . . .Ye$. . . . . . . . . . . . . . . . . . . . 30 .B.oP.E.pre.ss ra.ting appropriate;.test to.(pu.t psig tn.comment$). . . . . . . . . . . . . . . . . . . . Y.e$. . . . . . . Test to 350Q Rsi. .MSf' 27.20 psi.. . . . . . . . . . . . 31ChokemanJfold cQmplies. w/APt Rf'-53LMay 64). . . Xes . . . . . . . . . . . . . . . . . . . . 32 WQrk wiJI occ.ur withoy!.operationsbutdQwn . . Xes. . . . . . . . . . . . . . . . . . . 33 Is. Rres.e!1ce Qf H2S gas. probable. . . . . . No. . No!.ao H2S P<lct.. . . 34 .Meçha.nicaLcooctitlo!1of wells within AOR yerified (for s.ervice welJ only). . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . Administration Engineering Geology Appr RPC Date 11/3/2004 D D ~ - - - - - - - - - - - - - - -- . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 P.ermit GélO be issued .w/Q hydrogen. s.ulfide meas.ure$. . . . . . . . . . . . No. . 36D.ata pJesented on RotentialoveJRres.surezone$. . . . .NA . . . . . . 37 .S~tsrnic.a.n<llysjs. Qf $baJlow 9as.z.ones. . . . . . . . . . . . . . . . . . . . . . . . . . .NA . 38S~abedcondJtion survey (if off-shore) . . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . 39 . CQntact namelpJ1oneJorweekly prpgressreRorts [exploratoryonlYl . . . . . . .NA . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - _. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Commissioner: Date ù/S Date: n/c¡f 1- Engineering Commissioner: Public ~' ~/r Date . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . **** REEL HEADER **** MWD 06/01/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/15 867772 01 2.375" CTK !!!!!!!! !!!!!! !!!!! Remark File Version 1.000 ! !!!!!J!!! !!!!!!!!! Extract File: ldwg.las f I) 8Ö~ *** LIS COMMENT RECORD *** -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 9276.0000: STOP.FT 11555.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.TJNIT Value #--------- ------------------------- SECT. 19 TOWN. N 11N RANG. 12E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 86 DMF KB EKB .F 86 EDF .F N/A EGL . F 0 CASE.F 9290 OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Start.ing Dept.h Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. Z-39A Prudhoe Bay Unit 70 deg 17' 33.051" N 149 deg 11' 47.365" W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 26-MAR-05 500292299501 Description ------------------------------- Section Township Range Permanent. Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level casing Dept.h Other Services Line 1 ()v:) ~ - )..; L ~ . . (3) All Gamma Ray data (GRAX) presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included casing Collar Locator, an Electrical Disconnect and Circulating Sub a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub, with a Near Bit Inclination Sensor (6) Data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by PDS on March 26, 2005. (7) The sidetrack was drilled from Z-39 through a milled window in 4.5" liner. Top of Window 9285.0 ft. MD (8718.8 ft. TVD) Bottom of Window 9290.0 ft. MD (8723.7 ft. TVD) (8) The interval from 11528 ft. to 11555 ft. MD (8956.4 ft. to 8959.8 ft. TVD) was not logged due to bit to sensor offset at TD. (9) Tied to Z-39 at 9283 ft. MD (8716.8 ft. TVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD} (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 9289.38, 9289.17, 9291.25, 9291.04, 9311.2, 9311.62, 9316.39, 9315.56, 9320.97, 9320.76, 9326.79, 9327.82, 9339.67,9338.63, 9355.51, 9354.47, 9361.33, 9359.88, 9377.13, 9375.88, 9386.69, 9383.78, 9396.76, 9394.68, 9403.49, 9401. 82, 9408.68, 9406.6, 9423.28, 9419.95, 9429.3, 9426.81, 9434.92,9429.51, 9444.47, 9441.36, 9448.42, 9443.44, 9454.66, 9451.75, 9459.02, 9455.7, 9466.29, 9464.22, 9470.45, 9467.13, 9479.67,9476.34, 9488.4, 9485.28, 9495.88, 9491.72, 9502.21, 9497.64, 9507.41, 9503.67, 9514.89, 9511.77, 9518.21, 9514.68, 9522.37, 9518.42, 9525.7, 9521.12, 9530.27, 9526.11, 9534.42, 9529.44, 9550.5, 9545.93, 9553.62, 9549.25, 9557.15, 9552.58, 9561.52, 9560.89, 9569.83, 9568.37, 9572.11, 9571.07, 9589.05, 9587.59, 9594.45, 9592.16, DISPLACEMENT -0.208008 -0.207031 0.416016 -0.831055 -0.208008 1. 03906 -1.03906 -1. 03906 -1. 4541 -1.24707 -2.90918 -2.07812 -1. 66211 -2.07812 -3.32422 -2.49414 -5.40332 -3.11719 -4.9873 -2.90918 -3.3252 -2.07812 -3.3252 -3.3252 -3.11719 -4.15625 -4.57227 -3.74121 -3.11719 -3.53223 -3.94824 -4.57129 -4.15625 -4.9873 -4.57129 -4.36426 -4.57227 -0.624023 -1.45508 -1. 03906 -1.45508 -2.28516 . 9677.59, 9674.47, 9682.16,9679.67, 9703.09, 9700.39, 9730.32, 9725.95, 9790.06, 9785.7, 9794.42, 9790.48, 9802.95, 9798.58, 9824.71, 9820.14, 9897.13, 9891.72, 9904.61, 9897.54, 9927.41, 9919.72, 9934.89, 9925.54, 9942.37, 9934.06, 9947.98,9940.92, 9981.33, 9972.6, 9990.27, 9980.92, 10002.3, 9993.8, 10024.1, 10014.1, 10035.7, 10025.9, 10040.3, 10029.5, 10064.8, 10060, 10076.4, 10063.5, 10094.7, 10083.5, 10102.2,10090.1, 10180.7, 10168, 10184.6, 10172.8, 10238.2, 10235.7, 10249.8, 10247.1, 10256.6, 10253.9, 10282.9, 10279.6, 10288.7, 10285.4, 10302.6, 10298.1, 10306, 10302.2, 10310.3, 10306.4, 10321, 10317, 10339.5, 10335.1, 10349.7, 10345.3, 10409.4, 10405.1, 10413.4, 10408.6, 10475.7, 10470.9, 10522.3, 10515.7, 10539.7, 10532.4, 10543.2, 10535.3, 10548.2,10538.6, 10591, 10583.1, 10595.8, 10586.4, 10622.6, 10615.3, 10638.8, 10625.3, 10689.3, 10679.1, 10744, 10735.9, 10748.2, 10739.5, 10775.3, 10767, 10790.5, 10783, 10796.7, 10789.4, 10839.9, 10834.5, 10849.3, 10839.7, 10895.6, 10885.4, 10907.8, 10898.9, 10949.1, 10938.3, 10972.6, 10967, 10999.5, 10989.5, 11025.3, 11019, 11043.8, 11038.8, 11052.4, 11044.8, 11060.3, 11050.4, 11065.1, 11055.6, 11090.7, 11083.2, 11122, 11119.5, . -3.11719 -2.49414 -2.70117 -4.36426 -4.36426 -3.94824 -4.36426 -4.57129 -5.40332 -7.06543 -7.68945 -9.35156 -8.3125 -7.06543 -8.72754 -9.35156 -8.52051 -9.97461 -9.7666 -10.8066 -4.7793 -12.8848 -11. 2217 -12.0527 -12.6758 -11.8457 -2.49414 -2.70215 -2.70117 -3.32422 -3.3252 -4.57129 -3.74023 -3.94824 -3.94922 -4.36426 -4.36426 -4.36426 -4.78027 -4.7793 -6.65039 -7.27344 -7.89746 -9.55957 -7.89746 -9.35156 -7.27344 -13.5078 -10.1826 -8.10449 -8.72852 -8.3125 -7.48145 -7.27344 -5.40234 -9.55859 -10.1826 -8.93555 -10.8066 -5.61035 -9.97461 -6.23438 -4.9873 -7.68848 -9.97559 -9.55957 -7.48047 -2.49414 . 11219.6, 11215.1, 11223.6, 11219, 11234.1, 11228.9, 11240.7, 11236.4, 11271.6, 11267.6, 11277.6, 11269.9, 11295, 11289.6, 11305.7, 11298, 11311.3, 11303, 11315.1, 1130S.8, 11347, 11339.1, 11353.S, 11345.9, 11363.4, 11354.7, 1136S.2, 11359.6, 11390.8, 11380.2, 11396.6, 11385.2, 11433.4, 11420.5, 11470.1, 11459.9, 11476.1, 11465.5, 11491, 11481, 11495.3, 11485.6, 11507.4, 11501.4, 11516.3, 11509, EOZ END Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU . -4.57129 -4.57227 -5.19531 -4.36426 -3.94824 -7.68945 -5.40332 -7.68945 -8.3125 -6.23438 -7.89746 -7.89648 -8.72852 -8.52051 -10.5986 -11. 4297 -12.8838 -10.1826 -10.5977 -9.97461 ! -9.76758 ! -6.02637 -7.27344 197 records... 10 bytes 132 bytes ------------------------------------ WDFN LCC CN WN FN COUN STAT Z-39a.xtf 150 BP Exploration (Alaska) Inc. Z-39a Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Remark File Version 1. 000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by PDS on March 26, 2005 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP GR ROP ---------------------------------------------------- 0.0 0.0 GRAXOl ROPA01 . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: iF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 55 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9276.000000 11555.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 64 records... Minimum record length: Maximum record length: 54 bytes 4124 byt.es **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDrn LCC CN WN rn COUN STAT raw.xtf 150 BP Exploration (Alaska) Z-39a Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** . . !!! !!!!!! !!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F J Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units si ze Lengt.h 1 2 GRAX MWD ROPA MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 109 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth units 9276.000000 11555.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 118 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/07/15 867772 01 **** REEL TRAILER **** . MWD 06/01/04 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS . 2 records... 132 bytes 132 bytes . Tape Subfile 2 is type: LIS DEPTH 9276.0000 9276.5000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9700.0000 9750.0000 9800.0000 9850.0000 9900.0000 9950.0000 10000.0000 10050.0000 10100.0000 10150.0000 10200.0000 10250.0000 10300.0000 10350.0000 10400.0000 10450.0000 10500.0000 10550.0000 10600.0000 10650.0000 10700.0000 10750.0000 10800.0000 10850.0000 10900.0000 10950.0000 11000.0000 11050.0000 11100.0000 11150.0000 11200.0000 11250.0000 11300.0000 11350.0000 11400.0000 11450.0000 11500.0000 11550.0000 11555.0000 GR 74.9400 64.2019 257.6870 346.4396 33.0026 37.4620 80.4931 99.9940 34.6987 34.7218 38.0754 47.3737 33.0404 39.3679 49.2952 38.9899 34.2520 64.6906 48.3743 37.7784 41.1525 48.1353 52.8400 50.3562 52.3948 43.5855 37.6264 34.2942 38.8048 80.7833 43.6626 40.2237 48.4668 58.5788 146.3774 61.6728 187.3844 103.8088 221. 0558 42.4027 37.4708 45.3419 83.8188 43.3964 36.4614 31. 2350 56.9113 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP -999.2500 -999.2500 -999.2500 28.2144 35.2764 127.3030 113.7921 46.6037 105.0111 93.1729 94.8933 104.6682 68.4699 128.7508 92.0607 129.6928 119.8288 82.3186 119.1966 188.2393 173.6047 173.6995 133.4900 119.2285 97.5208 152.6285 134.5267 148.4579 153.3268 122.6929 134.4255 138.3583 137.0724 85.2185 110.8012 75.6806 10.4011 29.8275 43.7817 25.6693 99.3999 64.5546 54.7734 71.4134 86.5203 67.8033 25.7394 -999.2500 -999.2500 9276.000000 11555.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 9276.0000 74.9400 -999.2500 9276.2500 69.4950 -999.2500 9300.0000 262.2400 -999.2500 9350.0000 346.7100 29.2100 9400.0000 32.2700 36.0200 9450.0000 66.6320 162.6100 9500.0000 38.2000 120.3200 9550.0000 85.8500 69.9900 9600.0000 36.7850 101.4000 9650.0000 35.1400 93.1100 9700.0000 40.8000 111.6000 9750.0000 45.0200 92.6800 9800.0000 39.0850 121. 3800 9850.0000 45.8500 136.7700 9900.0000 269.8300 30.2600 9950.0000 48.5433 91.2900 10000.0000 53.7300 109.7100 10050.0000 54.3000 96.6000 10100.0000 246.5667 87.2100 10150.0000 51.8350 103.7500 10200.0000 36.8900 175.0900 10250.0000 61.6900 176.9600 10300.0000 50.9133 79.7800 10350.0000 67.1700 160.7400 10400.0000 50.8200 117.7500 10450.0000 35.7150 158.5300 10500.0000 44.7050 138.0400 10550.0000 36.8300 150.2900 10600.0000 34.1200 158.2100 10650.0000 66.8950 145.9000 10700.0000 46.6000 170.2200 10750.0000 37.1767 126.8600 10800.0000 58.2500 172.4200 10850.0000 53.0800 84.7200 10900.0000 75.2500 105.3900 10950.0000 97.1300 119.7100 11000.0000 126.1400 18.2800 11050.0000 185.2700 28.5200 11100.0000 235.6500 74.2100 11150.0000 43.9100 34.4800 11200.0000 34.3800 121. 8700 11250.0000 38.0600 84.9300 11300.0000 232.0600 64.1400 11350.0000 126.3800 70.1700 11400.0000 39.8100 77.5500 11450.0000 35.0167 42.4600 11500.0000 76.9000 58.0200 11550.0000 -999.2500 56.8500 11555.0000 -999.2500 -999.2500 Tape File St.art_ Depth 9276.000000 Tape File End Depth 11555.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet þ . . , , Tape Subfile 4 is type: LIS