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204-108
STATE OF ALASKA ' LASKA OIL AND GAS CONSERVATION COMMIS WELLIMPLETION OR RECOMPLETION REPOPAND LOG 1a. Well Status: Oil 0 Gas 0 SPLUG 0 Other ❑ Abandoned m ' Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ®Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 10/19/2016 , 204-108 ' 316-318 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/26/2004 50-029-21950-02-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 9/4/2004 PBU Z-23B • Surface: 720'FNL,1739'FWL,Sec.19,T11N,R12E,UM 9 KB Ref Elevations 17. Field/Pool(s): 81.06 ' Top of Productive Interval: 458'FSL,1545'FWL,Sec.18,T11N,R12E,UM GL 54.04• BF 55.36 , PRUDHOE BAY,PRUDHOE OIL • Total Depth: 712'FSI,405'FWL,Sec.18,T11N,R12E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9280'/8917' ADL 028262 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 599459• y- 5959360• Zone - ASP 4 '10550'/9050' ' 85-009 TPI: x- 599250 y- 5960535 Zone - ASP 4 12. SSSV Depth(MD/TVD): P0. Thickness of Permafrost MD/TVD: Total Depth:x- 598107 y- 5960774 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ® 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 6718'/6699' • 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary DIR/GR/RES/PWD,DIR/GR/RES/PWD ������0 App 2 „ 2.01 ' 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT F r. PULLED TOP BOTTOM TOP BOTTOM 20" 28' 108' 28' 108' 13-3/8" 68# L-80 P7' 2647' 27' 2646' 17-1/2" 3684 cu ft Permafrost 9-5/8" 47# L-80 25' 6718' 25' 6699' 12-1/4" 1894 cu ft Class'G' 7" 26# L-80 6565' 8913' 6552' 8707' 8-1/2" 488 cu ft Class'G' 4-1/2" 12.6# L-80 8747' 10548' 8567' 9049' 6-1/8" 281 cuftClass'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 8767' 8710'/8535' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. .,f. :',..1.. f);t RECEIVED Was hydraulic fracturing used during completion? Yes ❑ No El • Per 20 AAC 25.283(i)(2)attach electronic and printed information (0!141/) Nov 15 2016 , I ;r_r; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED a 0 GCC 9312' Set CIBP 9280' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(cor): Press 24 Hour Rate '" Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only , Ktri7 vn #/24//7-- RBDMS c.i- NOV 1 6 2016 ,s.-N. 3-/3./71 28. CORE DATA • Conventional Core(s) Yes ❑ No 0 • Sidewall Cores Yes ❑ No IZI • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No lid Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9168' 8877 separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Sag River 8909' 8704' Shublik 8947' 8734' Eileen 9101' 8841' Sadlerochit-Zone 4B 9168' 8877' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Leemhuis,Jacob Email: Jacob.Leemhuis@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: phone: +1 907 564 4091 Date:11/ 5/1 co / 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.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 MC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.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 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • s Z-23B Well History (Pre-Rig Sidetrack) CTU #9- 1.75" Coil Job Objective: Mill XN nipple, Drift, Caliper, set CIBP MIRU CTU. Standby for weather to raise mast. Make up a 3.80" no-go centralizer and LH 2 7/8" motor with 3.80" diamond parabolic mill and string reamer with a 3.80". Load well with 8/18/2016 SafeLube and RIH to mill XN at 8755'. CTU #9 - 1.75" Coil ***Cont. from WSR 8-18-16*** Job Objective: Mill XN, Drift, Caliper, set CIBP Tag XN nipple at 8446' CTMD. Mill through XN Nipple with 3.80" diamond parabolic mill and string reamer, drift with 3.80" no-go centralizer to confirm ID. Drift to 9400' and paint white/yellow TD flag for the caliper. POOH. Lay down tools and gauge Mill and Reamer at 3.77", no-go centralizer still 3.80". MU RIH w/ PDS 40 arm caliper.Stopped at the TD flag 9408' ctm. PUH to 9400' ctm. Waited for the arms to open, once opened started to log up @ 50 fpm. Stopped at 9249.6' ctm (9267 mech), painted a red/green flag. Logged up at 50 fpm. Stopped at 9000'. Logged up at 50 fpm to surface. Good data at surface. -2' correction. Pressure tested the MHA and made up BOT CIBP. RIH. Tie in at Red/Green flag and set 8/19/2016 CIBP ME at 9313' (9312' top of CIBP). POOH and FP well. RDMO CTU. T/I/O= 750/500/125 flowline temp= shut in. Post CTD MIT-IA to 2500 psi ***job continued to 8/20/2016 8/21/2016 ***WSR continued from 8/20/2016 Post CTD MIT-IA 2500 max applied 2750 psi ***PASSED*** Pumped 3.7 bbls of 45*crude to reach an MIT test pressure of 2747. 1st 15 min IA lost 71 psi, 2nd 15 min IA lost 25 psi for a total lost of 96 psi. bled back —4 bbls crude. Tag hung on well. Fluid packed annulus on well 8/21/2016 FWHP= 740/487/19 swab, wing, ssv= closed IA, OA= OTG T/I/O = 640/620/160. Temp = SI. WHPs (APE Request). ALP = 1550 psi, SI @ CV. 9/16/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 11:00. T/I/O = 640/620/160. Temp = SI. Bleed IAP to 250 psi (Eval TxIA). ALP = 1590 psi, SI @ casing valve. IA FL @ surface. Bled IAP to slop tank from 620 psi to 240 psi in 10 min (fluid —0.25 bbl). Monitor 30 min. TP unchanged, IAP increased 20 psi, OAP unchanged, IA FL unchanged. Final WHP's = 640/260/160. 9/18/2016 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 09:30. T/I/O = SSV/280/150. Temp = SI. WHP's., (Post bleed). IAP increased 20 psi, OAP decreased 10 psi overnight. 9/19/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:10 ***WELL S/I ON ARRIVAL***(ctd) DRIFTED TBG W/2.50" CENT & 1-3/4" S.BAILER TO DEVIATION @ 9,308' SLM.(no sample) RAN SBHPS AS PER PROGRAM W/SLB MEMORY GAUGES. (good data) 9/21/2016 ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** T/I/O = 590/530/160. Temp = SI. Bleed IAP to 0 psi (Eval TxIA). ALP = 820 psi, SI @ CV and lateral. IA FL near surface. Valve crew serviced AL lateral and CV yesterday. Bled IAP to BT from 530 psi to 0 psi in 30 min (Gas to fluid, —1/4 bbl). OAP decreased 20 psi during IA bleed. Bled ALP to 0 psi. Monitored for 30 min. IAP increased 10 psi. Final WHPs = 590/10/140. 9/22/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 10:20. T/I/O = 590/40/150. Temp = SI. WHP's (Post bleed). IAP increased 30 psi overnight. 9/23/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 12:10 • • Z-23B Well History (Pre-Rig Sidetrack) T/I/O = 591/29/127. Conducted LTT on tree valves (PASS). Set 4" H TWC#297 @124" Through tree. Conducted LTT on TWC (PASS). Installed TS#03 and XO#03 . W/Tapped blind flange on SV. Torqued and PT'd to API specs. (PASS). Installed 4" Int. on WV with hardline. Torqued and PT'd to API specs. (PASS). PT'd bottom and top side SV to 3500 Psi. (PASS). Installed rupture disk in SSV and PT'd (PASS). Installed nordic platform W/Square holes. Removed OA riser and installed 2" Int. torqued and PT'd to API specs (PASS). Evacuated fluid from tree down to flowcross. RDMO. ***Job Complete*** FWHP = 10/8/2016 TWC/29/127. See log for details. T/I/O = TWC/30/160. Temp = SI. Bleed IA& OA to 0 psi (Pre CTD). OA FL near surface. Bled OAP from 160 psi to BT to 0 psi in 2 hrs (gas/fluid .5 bbl). IA FL @ surface. Bled IAP from 30 psi to 0 psi in 10 min (10 gal). Monitored 30 min. IAP &OAP unchanged. FWHP's =TWC/0/0. 10/11/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:25. T/I/0 = TWC/0/100. Temp = SI. WHP's (Pre CTD). OAP increased 100 psi overnight. Bled OAP to BT ffom 100 psi to 0 psi in <1 min (gas). Held open bleed for an additional 1 hr. Monitor 30 min. OAP unchanged. FWHP's =TWC/0/0. 10/12/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:30. T/I/0 = TWC/0/150. Temp = SI. WHP's (Pre CTD). OAP increased 150 psi overnight. Bled OAP to BT ffom 150 psi to 0 psi in 1 hr(gas/fluid 0.5 bbl). Held open bleed for an additional 1 hr. Monitor 30 min. OAP unchanged. FWHP's =TWC/0/0. 10/14/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:15. T/I/O = TWC/0/150. Temp = SI. WHPs (Pre CTD). No wellhouse, flowline or AL. Bled OAP from 150 psi to 5 psi in 30 min (gas &fluid) (0.5 bbls). OAP increased 30 psi in 30 min. FWHPs = 0/0/35. 10/15/2016 SV, SSV= C. MV= O. IA, OA= OTG. 14:00 • • North America-ALASKA-BP Page 1 Operation Summary Report ---- ----- ---------- --_ -- - - ------ - - - --------------- Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) I, Start Date:10/16/2016 End Date:10/27/2016 X3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:00AM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA UWI:500292195000 Active datum:Z-23B @81.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/16/2016 09:00 - 09:30 0.50 MOB P PRE PREP TO JACK UP RIG AND MOVE 09:30 - 09:50 0.33 MOB P PRE PJSM WITH ALL INVOLVED PARTIES. DISCUSS TIGHT TURN COMING OFF WELL -TESTED AND VERIFIED ESD WAS FUNCTIONAL AND IS MANNED BY TOOLPUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE -ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY -AGREED ON STOP WAS THE COMMAND TO STOP RIG. -PERFORMED RADIO CHECK PRIOR TO MOVING RIG. ,-DISCUSSED WITH CREW THAT THERE WAS NO BPV INSTALLED I-VERIFIED S-103,S-107&S-111 SHUT IN, DEPRESSURED TO HEADER PRESSURE AND I ALL TREE&CASING VALVES ARE LOTO VERIFIED S-113 TREE AND CASING VALVES ARE SHUT IN 09:50 - 10:10 0.33 MOB P PRE [JACK UP RIG AND MOVE OFF S-113 10:10 - 11:00 0.83 MOB P PRE RIG STAGED ON PAD,PU RIG MATS AND CELLAR T-MATS WELL WORK TRANSFER FORM CLOSED OUT WITH S-PAD OPERATOR S-103,S-107&S-111 LOTO'S REMOVED AND CASING VALVES OPENED BY PAD OP TOOL PUSHER AND DRILLER PERFORMING ROUTE DRIVE WHILE LOADING MATS 11:00 - 13:45 2.75 MOB P PRE MOVE RIG FROM S-PAD TO MOBILE PAD CORNER AND SET RIG DOWN WHILE TOOL SERVICES MOVES RIG MATS TO THE FRONT OF THE RIG 13:45 - 18:00 4.25 MOB N WAIT PRE RIG STAGED AT MOBILE PAD CORNER WAITING ON RIG MATS TO BE MOVED AHEAD OF THE RIG DETERIORATING ROAD CONDITIONS REQUIRE RIG MATS TO BE USED FOR RIG MOVE. 18:00 - 00:00 6.00 MOB N WAIT PRE CONTINUE MOVING MATS AHEAD OF RIG. 'RIG IS PARKED AT MOBIL PAD ENTRANCE. CREW CONTINUES HOUSEKEEPING AND MAINTENANCE TASKS. 10/17/2016 00:00 - 08:20 8.33 MOB N WAIT PRE STAGE RIG AT MOBIL PAD,WAIT FOR RIG MATS TO BE PLACED AHEAD OF RIG. CREW CONTINUES HOUSEKEEPING AND MAINTENANCE TASKS. BRUSH AND OIL 1"CSH IN THE PIPE SHED. COMPLETE RIG MOVE CHECKLIST AND CRITICAL ITEMS INSPECTION CHECKLIST. 08:20 - 10:00 1.67 MOB P PRE RIG MATS ARE READY MOVE RIG TO Z-PAD ACCESS ROAD 10:00 - 15:00 5.00 MOB P PRE RIG STAGED AT Z-PAD ACCESS ROAD,WAIT FOR RIG MATS TO BE PLACED WHERE NEEDED Printed 11/1/2016 8:35:36AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 2 a&W— Operation Summary Report Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/16/2016 End Date:10/27/2016 X3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:00AM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA UWI:500292195000 Active datum:Z-23B @81.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:00 3.00 MOB P PRE RIG MATS ARE IN PLACE,CONTINUE MOVE TO Z-PAD 18:00 - 18:30 0.50 MOB P PRE RIG IS ON Z-PAD,POSITION RIG TO PULL OVER WELL. CONDUCT PJSM FOR PULLING OVER THE WELL. DISCUSS TESTING AND MANNING ESD WHILE PULLING OVER WELL. DISCUSS USE OF CHOCK BLOCK AND RADIO CHECKS,EVERYONE UNDERSTANDS THE STOP COMMAND. ESD FUNCTION AND PULL OVER WITNESSED BY WSL,TOURPUSHER AND TOOLPUSHER. PULL RIG OVER WELLAND SET DOWN. RIG ACCEPTED 18:30. 18:30 - 20:30 2.00 MOB P PRE !RIG UP,START SPOTTING AUXILIARY EQUIPMENT. CYCLE TREE VALVES AND INSTALL FUSIBLE CAP,CAP WITNESSED BY WSL. GET GOOD LEAK TIGHT TEST ON SWAB AND MASTER VALVES. 20:30 - 00:00 3.50 MOB P PRE PJSM WITH CH2 DRIVERS FOR LIFTING REEL UP. LIFT REEL UP AND SECURE IN THE REEL FRAME. INSTALL 1502 LINE INSIDE REEL. SIMOPS: CONTINUE REMOVING TREE CAP, INSTALLING BOPS. ASSEMBLE GOOSENECK AND STRIPPER. 10/18/2016 00:00 - 02:45 2.75 MOB P PRE INSTALL GRAPPLE AND PULL TEST. -PULL CT ACROSS PIPE SHED ROOF AND INTO INJECTOR. -SIMOPS: CONTINUE INSTALLING BOPS. CONDUCT H2S RIG EVAC EXERCISE WITH BEZOLD CREW,AND AAR AFTERWARDS. 02:45 - 10:45 8.00 BOPSUR P PRE SHELL TEST BOPS,GOOD. -BEGIN BOP TESTAS PER AOGCC AND BP REGS. -TEST WITNESS IS WAIVED BY AOGCC REPRESENTATIVE CHUCK SCHEVE. -FUNCTION BOP RAMS FROM BOTH REMOTE STATIONS,OK. -TEST ALL RAMS AND CHOKE VALVES @ 250 /3500 PSI. -TEST ANNULAR PREVENTOR @ 250/2500 PSI. -TEST(2)FLOOR SAFETY VALVES @ 250/ 3500 PSI. -PERFORM DRAWDOWN TEST ON ACCUMULATOR. -RIG DOWN TEST EQUIPMENT. -(1)FAIL/PASS...CHOKE VALVE#1 INITIAL TEST FAILED,GREASED AND FUNCTIONED AND PASSED RE TEST. 10:45 - 11:15 0.50 CONDHL P PRE PJSM.CIRCULATE COIL TO FRESH WATER. 11:15 - 11:45 0.50 CONS P PRE PJSM.BOOT ELINE. -INJECTOR ON WELL,CHECK TREE BOLTS } FOR PROPER TORQUE. Printed 11/1/2016 8:35:36AM *All depths reported in Drillers Depths* • � North America-ALASKA-BP Page 3 oC Operation Summary Report Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/16/2016 End Date:10/27/2016 X3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:00AM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA UWI:500292195000 Active datum:Z-23B©81.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:45 - 12:00 0.25 CONS P PRE CONDUCT RIG EVACUATION DRILL,H2S RELEASE IN CELLAR. -ALL HAND MUSTERED AND ACCOUNTED FOR...(4)MINUTES TO MUSTER AND HEAD COUNT. -CONDUCT AAR.WIND DIRECTION ACCOUNTED FOR,TRUCK DRIVERS MUSTERED ON OTHER SIDE OF RIG. 12:00 - 13:00 1.00 CONS P PRE I PJSM.PRESSURE TEST PACK OFF AND INNER REEL. -PRESSURE TEST STANDING IRON AND INNER REEL IRON. 13:00 - 14:30 1.50 CONS P PRE PJSM.PUMP SLACK INTO REEL. -CUT 266'OF COIL. 14:30 - 15:00 0.50 CONS P PRE PJSM.MAKE UP CTC AND PULL TEST TO 45K, GOOD. -PRESSURE TEST TO 250/3500 PSI,GOOD TEST. 15:00 - 15:45 0.75 CONDHL P PRE PJSM.CIRCULATE THE COIL TO MUD. 15:45 - 18:00 2.25 CONDHL P PRE PJSM.HEAD UP WITH BAKER. MAG E LINE-550/52 PRESSURE TEST BAKER FLOATS,250/3500 PSI,OK. REMOVE TEST PLUG. 18:00 - 21:30 3.50 CONDHL P PRE STAB ON AND PT BPV LUBRICATOR. DIFFICULT TO LATCH INTO PLUG. REMOVE BPV LUBRICTOR AND INSPECT PULLING TOOL,LOOKS OK. STAB ON WITH BPV LUBRICATOR AGAIN AND PT. 21:30 - 00:00 2.50 CONDHL P PRE PT BPV LUBRICATOR A SECOND TIME. CONTINUE TO TRY AND ENGAGE PULLING TOOL. SHIFT CHANGE FOR BPV CREW. CONTINUE TRYING TO ENGAGE THE PULLING TOOL,ABLE TO GET IT. PULL TWC ABOVE TREE VALVES. ABOUT 560 PSI. CLOSE MASTER VALVE AND BLEED OFF PRESSURE TO TIGER TANK. FILL TREE WITH MEOH TO BPV LUBRICATOR TO PURGE ANY RESIDUAL GAS. CLOSE SWAB VALVE,REMOVE BPV LUBRICATOR. 10/19/2016 00:00 - 02:30 2.50 BOPSUR P PRE CONTINUE PULLING TWC. GOT IT ON THE SECOND ATTEMPT. CLOSE MASTER VALVE AND BLEED OFF PRESSURE TO TIGER TANK. FILL TREE WITH MEOH TO BPV LUBRICATOR TO PURGE ANY RESIDUAL GAS. CLOSE SWAB VALVE,REMOVE BPV LUBRICATOR. OFFLOAD TWC LUBRICATOR AND PULLLING TOOLS. Printed 11/1/2016 8:35:36AM *All depths reported in Drillers Depths* • 1111 North America-ALASKA-BP Page 44:211- Operation 4Operation Summary Report Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/16/2016 End Date:10/27/2016 X3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:00AM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA UWI:500292195000 Active datum:Z-23B @81.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:30 2.00 BOPSUR P PRE BULLHEAD KILL WELL AS PER OCN#1. PUMP 5 BBLS MEOH,290 BBLS 1%KCL,20 BBLS HI-VIS,150 BBLS MUD. FINAL WHP IS 1710 PSI. I SHUT DOWN PUMP,ALLOW PRESSURE TO BLEED OFF. BLEED GAS CAP IN RISER OUT TO TIGER TANK. BLEED OFF ALL PRESSURE AND OBSERVE 6.5 BBLS BACK WITH SLOWLY DECREASING RATE. NOW FLOWING BACK ABOUT 1-2 BBUHR. SHUT IN HAND CHOKE AND OBSERVE PRESSURE BUILD AND STABILIZE @ 256 PSI. '04:30 - 06:00 1.50 BOPSUR P PRE '-SHUT IN AND MONITOR PRESSURE, STABILIZE AT 250 PSI. 1-DISCUSS WITH WOS,TRY TO BLEED BACK 1 BBL TO OBSERVE PRESSURE RESPONSE. BLED BACK 0.7 BBLS AND MICROMOTION OUT READS"0". -MONITOR WELL,FLOW SLOWLY DROPPING FROM VERY SMALL STREAM TO TRICKLE AND THEN TO INTERMITTENT. CONTINUE TO MONITOR WELL. 06:00 - 07:15 1.25 BOPSUR P PRE MONITOR WELL FOR 1/2 HR,WELL IS DEAD. -NO INDICATION OF GAS THROUGHOUT OPERATION. -CALL IN AND REQUEST PERMISSION TO OPEN WELLAND MOVE FORWARD. REQUEST ACCEPTED AS PER GREG SARBER AND PERMISSION GRANTED. 07:15 - 08:10 0.92 STWHIP P WEXIT PJSM.PICKUP WHIPSTOCK BHA. MAKE UP INJECTOR,INJECTOR ON WELL @08:10 HRS. -TEST QTS @ 250/4000 PSI,OK.OPEN EDC. 08:10 - 11:30 3.33 STWHIP P WEXIT PJSM.RIH PUMPING @.8 BPM. -TIE IN FROM 8930...MINUS 28' CORRECTION. I-WT CHECK 43K UP WT @ 9000'. -STOP AND FLOW CHECK WELL DUE TO SIGNIFICANT DROP IN OUT DENSITY. -OUT DENSITY DROPPED TO 8.5 PPG,NO FLOW,WELL BORE STATIC. -LOG CCL DOWN W/PUMPING A BTMS UP. OUT DENSITY CLIMBED BACK UP TO 9.48 PPG AFTER APPROXIMATELY 15 BBLS PUMPED. -ATTRIBUTE DENSITY DROP TO BREATHING FLUID AND COMINGLE.NO SIGN OF GAS. -0/A=228,I/A=0 PSI.DOUBLE CHECK VALVE ALIGNMENT ON I/A.GOOD. 11:30 - 11:45 0.25 STWHIP P WEXIT PJSM.CONFIRM AND SET WHIPSTOCK @ 9292.5' -CLOSE EDC AND PRESSURE UP TO 4200 PSI,OBSERVE WHIPSTOCK SET. Printed 11/1/2016 8:35:36AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 5 gf et Operation Summary Report Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/16/2016 End Date:10/27/2016 X3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:OOAM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA UWI:500292195000 Active datum:Z-23B @81.06usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:45 - 12:45 1.00 STWHIP P WEXIT PJSM.CIRCULATE BOTTOMS UP THROUGH MUD GAS SEPARATOR. -PUMPING 1.5 BPM @ 1350 PSI,9.48 PPG IN/ 9.46 PPG OUT. -I/A=0 PSI,0/A=230 PSI.125 BBLS PUMPED. 1-MONITOR WELL,(10)MINUTES,STATIC WELL CHECK, NO FLOW. -NO SIGN OF ANY GAS WHILE CIRC BTMS UP. 12:45 - 14.30 1.75 STWHIP P WEXIT FLOW CHECK ALL GOOD AFTER CIRCULATING BOTTOMS UP. POH WITH BHA TO SURFACE. -FLOW CHECK WITH BHA BELOW STACK,NO FLOW PULL BHA INTO BOP STACK,POP OFF WITH !INJECTOR -INJECTOR OFF AT 14:30 14:30 - 16:30 2.00 STWHIP P WEXIT LAY DOWN WHIPSTOCK SETTING BHA. NO DAMAGE TO EQUIPMENT. -LINE UP TO FLUSH MUD GAS SEPARATOR -HOLE STATIC AT SURFACE -STAB ON WITH INJECTOR,ON AT 16:30 16:30 - 19:00 2.50 STWHIP P fi WEXIT PRESSURE TEST QUICK TEST SUB WHILE MWD EQUIPMENT IS POWERED UP AND FUNCTION TESTED. -BREAK CIRCULATION ON WELL,IMMEDIATE RETURNS -RIH WITH 3.80"MILLING BHA#2 ON.6°BEND MOTOR 3pp�� 19:00 - 00:00 5.00 STWHIP P WEXIT MILL 3.80"WINDOW IN 4-1/2"CASING PER TAY/t BAKER REP FROM 9280'MD TO 9282'MD 73C -RATE:2.71 BPM IN,2.71 BPM OUT -MUD WEIGHT:9.50 PPG IN,9.48 PPG OUT -DWOB:1-3 KLBS -CIRC PRESSURE:3400 PSI -AT 9284'DWOB DECREASES FROM ABOUT 1.3K TO 900#. LOSS OF ABOUT 500 PSI MOTOR WORK. 10/20/2016 00:00 - 05:30 5.50 STWHIP P WEXIT MILL 3.80"WINDOW IN 4-1/2"CASING PER BAKER REP FROM 9282'MD TO 9287'MD -RATE:2.71 BPM IN,2.71 BPM OUT ! -MUD WEIGHT:9.50 PPG IN,9.48 PPG OUT -DWOB:1-3 KLBS -CIRC PRESSURE:2970 PSI 03:00-DURING TIME MILLING AT 9286.3 FT, BHA ADVANCED IN A STICK-SLIP FASHION. HAD TO PICK UP TO 9286 FT AND TIME DRILL DOWN AGAIN. -9,285'SAMPLE SHOWS ALMOST ALL METAL, TRACE OF CEMENT. 05:30 - 06:45 1.25 STWHIP P WEXIT MILL 3.80 RATHOLE FROM 9,287'TO 9,297'AT 20-30 FT/MIN. -RATE: 2.73 BPM IN,2.75 BPM OUT -MUD WEIGHT: 9.52 PPG IN,9.48 PPG OUT -DWOB 1.5KLBS -CIRC PRESSURE: 3,170 PSI Printed 11/1/2016 8:35:36AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 6 bait Operation Summary Report Common Well Name:Z-23 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/16/2016 End Date:10/27/2016 r)(3-017YD-C:(3,155,216.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/7/1989 12:00:OOAM Rig Release:10/30/2016 Rig Contractor:NORDIC CALISTA •UWI:500292195000 Active datum:Z-23B @81.06usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:45 - 08:00 1.25 STWHIP P WEXIT CONDUCT REAM PASSES PER WELL PLAN AND UNDER GUIDANCE OF BOT REP. -PERFORM 3 REAMING PASSES AT 1'/MIN. -REAM UP AT:AS MILLED;MINOR MOTORWORK WHEN AT+15 DEG,-15 DEG -PASSES LOOK GOOD. NO LOSSES TO FORMATION DURING MILLING OR REAM PASSES. I-SAMPLE FROM 9297'ALMOST FULLY FORMATION. CIRCULATE DOWN HI-VIS PILL IN CONJUNCTION WITH LAST REAM PASS. -CONDUCT DRY DRIFT AT 30 DEG LOHS(AS MILLED),ALL GOOD FLOW CHECK,NO FLOW 08:00 - 10:10 2.17 STWHIP P WEXIT POH WITH MILLING ASSEMBLY -NO ISSUES POH. GOOD RETURN OF METAL WITH RETURN OF HI-VIS SWEEP -FLOW CHECKAT SURFACE,ALL GOOD WITH NO FLOW -PULL BHA INTO BOP STACK,POP OFF WITH INJECTOR 10:10 - 11:25 1.25 DRILL P WEXIT LAY DOWN MILLING BHA. MILLS GAUGE AT 3.80"GO,3.79"NO-GO. CHANGE OUT TO BUILD BHA -MU BUILD BHA#3 WITH 4.25"BIT ON 3.16° BEND MOTOR AND BHI SMART TOOLS -STAB ON WITH INJECTOR 11:25 - 14:15 2.83 DRILL P WEXIT PRESSURE TEST QUICK TEST SUB WHILE TOOLS ARE BEING POWERED UP,FUNCTION TESTED -RIH WITH BUILD BHA -LOG TIE-IN WITH-30'CORRECTION -NO ISSUES EXITING WINDOW 14:15 - 19:00 4.75 DRILL P PROD1 DRILL AHEAD FROM 9297'. FREE SPIN OF 3030 PSI AT 2.83 BPM. -DRILL BUILD TO 9,630'MD -RATE:2.60-2.85 BPM IN,2.60-2.85 BPM OUT. CIRC PRESSURE:3150-3615 PSI -MICROMOTION MUD WEIGHT:9.55 PPG IN, 9.55 PPG OUT,ECD:10.70 PPG -ROP:68-115 FT/HR,WOB:1.3-4.6 KLBS -INFREQUENT SHALE STRINGERS BUT OTHERWISE GOOD DRILLING 19:00 - 22:00 3.00 DRILL P PROD1 POOH. PUMP 10 BBLS LO/HI VIS SWEEPS AROUND. MONITOR WELL FOR 10 MINUTES WITH DYNAMIC FLOW CHECK,GOOD. -0.52 BPM IN/0.47 BPM OUT -MUD WEIGHT:9.56 PPG IN,9.59 PPG OUT -RATE:2.80 BPM IN,2.79 BPM OUT -OPEN EDC,POH FROM 9,280'MD TO SURFACE. -JET WHIPSTOCK TRAY WITH OPEN EDC. -RATE:3.5 BPM.CIRC PRESSURE:3,000 PSI -SWEEPS RETURN ABOUT 20%EXCESS CUTTINGS WHEN RETURNED TO SURFACE. Printed 11/1/2016 8:35:36AM *All depths reported in Drillers Depths* TIS 4"CNV •VV�LrEAD= FMC ""• _� **"�'!RU RO NOTES: WELL ANGLE>700 @ 9236'. ACTUATOR= BAKE32 KB.EEV= 91.74' Rff__BEV= 81.06' _BF.f3La/_-=7.— 55.36' KOP= 3100 2205' H4-1/2"HES X NP,D=3.813" Max Angle= 930 @ 9799' Datum MD= 9,197' GAS LFT MANDRELS Datum 1VD= 8800'SS ST ND I V'rDEV TYPE VLV LATCH FORT DATE 6 3095 3095 1 MM3 DMY RK 0 03/20/16 13-3/8"CSG,68#,L-80,D=12.415" —{ 2657' 5 4995 4994 1 MM3 DMY RK 0 03/20/16 4 6386 6379 13 MM3 DMY RK 0 03/20/16 3 7451 7373 21 KBG2 DMY RK 0 03/20/16 Minimum ID =3.80" @ 8766' 2 8222 8083 22 KBG2 DMY BK 0 03/20/16 1 8580 8417 23 KBG2 DMY BK 0 08/02/11 4-1/2" MILLED XN NIPPLE I 6565' H 9-5/8"X 7"BKR ZXP LW w/EBK SLV,ID=6.28" M 6579' H9-5/8"X 7"BKR HMC LNR HNGR w/R NIP,D=6.18" MILLOUT WINDOW(Z-23B) 6718'-3734' MECHANICAL WHIPSTOCK(08/25/04) —I 6718' 8690' H4-1/2"HES X NP,D=3.813" 8710' —17"X 4-1/2"BKR S-3 PKR,D=3.870" 8734' H4-1/2"HES X NP,Co 3.813" 9-5/8"HES EZSV(08/24/04) H 6740' �; 8747' —7"X 5"BKR ZXP LNR TOP PKR Mk w/T183K SLV,D=4.360" 9-5/8"CSG,47#,L-80,D=8.681" — 7472' I On 1 IP 8755' 4-1/2"HES XN NP MLL®TO SEE PREVIOUS .�1itt 0� ' 3.80'(08119/16) 4����'�'�'�'�, 4 8766' —7"X 5"BKR HMC LNR SCHEMATIC FOR .W.Y1 i�A1*r `111.44....' 4 HNGR w/R NP,D=4.25" WELL Z-23A& Z-23AL1 •4.0'. . . 4000.0Ililk TBG & LNR DETAILS ,,,. ''-a r> 8767' _14-1/2"W-EG,D=3.958" Y 8776' —5"X 4-1/2"XO . D=3.99" PERFORATION SUMMARY III REF LOG: MWD VISION RES LOG ON 08/22/04 17.707.747476N A 9154' —4-1/2"MARKER ANGLE AT TOP PERF: 63° @ 9175' 4-1/2"1BG,12.6#,13CR NAM, H 8767' JT w/RA TAG Note:Refer to Production DB for historical perf data SIZE SPF NTEF21/AL Opn/Sqz PATE .0152 bpf,D=3.958" N? 9317 —4-1/2"BKR 2-7/8" 4 9175-9185 0 06/14/11 CIBP(8/19/16) 7"LNR,264,L-80 BTC-M, H 8913' �/ ` 2-7/8" 4 9205-9225 0 06/16/11 2-7/8" 4 9275-9305 0 06/16/11 .0383 bpf,D=6.276" ` 2-7/8" 4 9405-9435 C 06/15/11 4-1/2"WHPSTOCK(10/19116) 9280' 2-7/8" 4 9640-9660 C 06/15/11 ` 2-7/8" 4 9680-9710 C 06/15/11 2-1/2" 4 9745-10160 C 09/08/04 4 2-1/2" 4 10224-10254 C 09/08/04 PBTD J limey X44140\ 2-1/2" 4 10292-10390 C 09/08/04 I N;��' 2-1/Z' 4 10400-10436 C 09/08/04 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,ID=1958" — 10548' 2-1/2" 4 10454-10460 C 09/08/04 DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 10/18/89 FH ORIGINAL COMPLETION 06/26/11 SJW/PJC ADFEJ S(06/15-17/11) WELL: Z-23B 05/05/95 LINDB2 SIDETRACK(Z-23A) 08/15/11 TAR!PJC GLV GO(8/2/11) PERMT No: 2041080 07/08/03 DAV/IO( SDTIICKATTBNPT(Z-23AL1 03/28/16 JPK/JMD GLV GO(03/20/16) API No: 50-029-21950-02 09/19/04 Dt6 SIDETRACK(Z-23B) 08/24/16 SW/JMD KILLED XN NIFfSET CEP SEC 19,T11 N,R12E,4560'NSL&3214'WB_ 09/23/04 CAO/PJC GLV GO 09/09/16 JNU PRE RIG EDITS 02/27/06 JLJ/TLH DRLG DRAFT CORRECTIONS BP Exploration(Alaska) OF T • • w\ )y7,'s9 THE STATE Alaska Oil and Gas .�,�—�is Li\ SIKII\.0 f Conservation Commission 1� s t _ 333 West Seventh Avenue Anchorage,e, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Supervisor BP Exploration(Alaska), Inc. CANNEDDEC4 2016 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-23B Permit to Drill Number: 204-108 Sundry Number: 316-318 Dear Ms. McLaughlin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 27 day of June, 2016. RBDMS (," JUN 2 8 2016 STATE OF ALASKA 411,\LASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROV S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill RI . Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 204-108 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21950-02-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q ' PBU Z-23B • _ _ 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028262 • PRUDHOE BAY,PRUDHOE OIL • l J N 0 7 201h 11. PRESENT WELL CONDITION SUMMARY 412C /i 7 P J c Total Depth MD(ft): Total Depth TVD(ft . (): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): : GC 10550 9050 10461 9001 2779 None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 28-108 28-108 Surface 2619 13-3/8" 27-2647 27-2647 4930 2270 Intermediate 6693 9-5/8" 25-6718 25-6699 6870 4760 Liner 2348 7" 6565-8913 6552-8707 7240 5410 Liner 1801 4-1/2" 8747-10548 8567-9049 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9175-10460 8880-9001 4-1/2"12.6# 13Cr80 23-8767 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and TVD(ft): 8710/8535 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary E1 Wellbore Schematic Q 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 11 Exploratory 0 Stratigraphic 0 Development ll Service 0 14.Estimated Date for Commencing Operations: July 1,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended WI 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Leemhuis,Jacob be deviated from without prior written approval. Email Jacob.Leemhuis@bp.com Printed Name Sean McLaughlin Title Drilling Supervisor 1 Signature ;' ►. _- C ,gyp SEhfJ 14_1410 Gt♦u Phone +1 907 564 4387 Date �/7/1 6 r E-/�' COMMISSION USE ONLY J b Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test Cg Mechanical Integrity Test 0 Location Clearance 0 Other: ,8 e,P rrs t fo 3 6--1 0 p 5!J G 4!�vt,i1cv 1p✓f.. rvi1111- 1-'7-51- fc 25 v/J511 il'61-1 r--r-t cz f C p 11,- pig(r-ki,T,-,-i-' Apr,ro ve-cl pr,-- a0 44-C. Post Initial Injection MIT Req'd? Yes 0 No I '/ d / 25. 1 all) Spacing Exception Required? Yes 0 No N Subsequent Form Required: /C '4 d aV /f" / CPPROSSD BYTHE Approved by: I �L.(�_ COMMISSIONER COMMISSION Date:6_2.7_// V t_ 40/2 //L. Jo ORIGINAL RBDMS y-" JUN 282016 // Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval/"v" �`✓��� Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis b CTD Engineer Date: June 3, 2016 Re: Z-23B Sundry Approval Request Sundry approval is requested to plug the Z-23B perforations as part of the preparation, drilling and completing the proposed Z-23C coiled tubing sidetrack. History of Z-23B: Z-23B is a CTD zone 4 horizontal sidetrack which was initially put on production October, 2004. The decreased production rate was thought to be due to a combination of drilling damage, scaling, or fines migration. A 2011 coiled tubing job included the milling of scale, acidizing and perforating resulting in an increase in gross fluid rate, but was mostly due to an increase of all water. The well has been shut-in for the past 3 years due to high WC. All well work options have been exhausted aqd the well is deemed to have,no remainin value. ,6/i<<e Z6.->/3 Proposed plan for Z-23C: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig �� on or around November 15th, 2016. The Z-23C sidetrack will be a single string exit from the existing 4- , 1/2" liner. A monobore whipstock will be set on top of a CIBP that was set pre-rig. Z-23C is designed ,f�, to kick out in the 45P sands (underneath the 45N shale). The well will drill down through the 45P sands and land (90 degree Inc) after crossing fault#1. Once structure is confirmed, the well will undulate within the 46P sands with TD being called once the OWC is logged or 8,966' TVDss is reached. Z-23C will be completed with a 3-1/4" x 2-7/8" 13Cr-85 solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing Z-23B perforations via the CIBP and liner cement iob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). � N The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin July 1st,2016) 1. C Mill XN Nipple to 3.80", Drift, GR/CCL/Caliper, Set CIBP SA 2. V Pre-CTD tree work. Rig Work(scheduled to begin November 15,2016) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,779 psi). " szy 2. Set 4-1/2" Monobore Whipstock o 3. Mill 3.80"window and 10' of rathole. ; 4. Drill Build: 4.25" OH, -324' (35 deg DLS planned). 5. Drill Lateral: 4.25" OH, 2,615' (12 deg DLS planned). b 6. Run 3-1/4" x 2-7/8" 13Cr-85 liner leaving TOL at-9,050' MD. 7. Pump primary cement job: 36 bbls, 15.3 ppg Class G, TOC at-9,050' MD. \ � 8. Perform cleanout run if neededco ~ E 9. Perform liner lap test*. -� 10. Perforate -1,600' 11. Freeze protect well to a min 2,100'TVDss. 12. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) < �4:-' a S Post-Rig Work: 1. Pull TWC. Tree work as necessary. 2. Set live GLVs. 3. Set liner top packer if liner lap test fails.* 4. Pressure Test LTP (if necessary) 5. ASRC flowback 6. SIT Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 TREE= 4"CW WELLHEAD= FMC • SO NOTES: 70°@ 9236' .ACTUATOR= BAKER Z-2 3 B ***CHROME TBG*** KB.ELEV= 91.74' BF.ELEV= 55.36' KOP= 3100' Max Angle= 93©9799' I 2205' H 4-1/2"HES X NIP, ID=3.813" Datum MD= 9,197' Datum TVD= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,68#,L-80. ID=12.415" —I 2657' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3095 3095 1 MMG DOME RK 16 09/24/04 5 4995 4994 1 MMG DOME RK 16 09/24/04 4 6386 6379 13 MMG DOME RK 16 09/24/04 3 7451 7373 21 KBG2 DOME BK 16 09/24/04 Minimum ID = 3.725°' 8755° 2 8222 8083 22 KBG2 SO BK 22 08/02/11 1 8580 8417 23 KBG2 DMY BK 0 08/02/11 4-1/2" HES XN NIPPLE 6565' H 9-5/8"X 7"BKR ZXP LTP w/TIEBK SLV, ID=6.28" 6579' —I -95/8"X 7"BKR HMC LNR HNGR w/R NIP, ID=6.18" MILLOUT WINDOW (Z-23B) MECHANICAL WHIPSTOCK(08/25/04) H 6718' 6718'-6734' 8690' —14-1/2"HES X NIP,ID=3.813" 8710' H 7"X 4-1/2"BKR 5-3 PKR,ID=3.875" 9-5/8"HES EZSV(08/24/04) — 6740' 8734' —14-1/2"HES X NIP, ID=3.813" SN 8747' 7"X 5"BKR ZXP LNR TOP PKR 9-5/8"CSG,47#,L-80.ID=8.681" --I 7472' ;; w/TIEBK SLV,ID=4.360" ��'1�1� �� 8755° -f4-112"HES XN NIP, ID=3.725" SEE PREVIOUS �•1�1�1�1�1�1i ,v^,R, ' 8766' 7"x 5"BKR NMC LNR SCHEMATIC FOR \14�.j�'�1. "�,1�•••�111, ' %./ 8766' 1HNGRw(RNIP, ID=4.25" ..1A 1.h WELL Z-23A& Z-23AL1 ,.""�'��i 8767' _14-1/2"WLEG, ID=3.958" TBG & LNR DETAILS Y 4,. 8776' 5"x4-1/2"xo �-- ID=3.99" PERFORATION SUMMARY ■ 1717•37•7.7.74 9154° -t 4-1/2"MARKER REF LOG: MWD VISION RES LOG ON 08/22/04 JTw/RA TAG ANGLE AT TOP PERF: 63° @9175' 4-1/2"TBG. 12.6#.13CRVAM, H 8767' ` Note: Refer to Production DB for historical perf data .0152 bpf,ID=3.958" SIZE SPF INTERVAL OpnlSgz DATE ` 2-7/8" 4 9175-9185 0 06/14/11 7"LNR,26#,L-80 BTC-M, J I 8913' 2-7/8" 4 9205-9225 0 06/16/11 .0383 bpf, ID=6.276" ` 2-7/8" 4 9275-9305 0 06/16/11 2-7/8" 4 9405-9435 0 06/15/11 2-7/8" 4 9640-9660 0 06/15/11 • 2-7/8" 4 9680-9710 0 06/15/11 2-1/2" 4 9745-10160 0 09/08/04 �O PBTD --I 10461' l'ikikiii' 2-1/2" 4 10224- 10254 0 09/08/04 ;,;�,' 2-1/2" 4 10292- 10390 0 09/08/044-1(2"LNR, 12.6#. L-80 BTC-M, .0152 bpf,ID=3.958" — 10548' • 2-1/2" 4 10400- 10436 0 09/08/04 2-1/2" 4 10454- 10460 0 09/08/04 DATE REV BY COMMENTS ® DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18/89 FH ORIGINAL COMPLETION " 06/26/11 SJW/PJC ADPERFS(06/15-17/11) WELL: Z-236 05/05/95 LINDER SIDETRACK(Z-23A) 08/15/11 TAR/PJC GLV C/O(8/2/11) PERMIT No: 2041080 07/08/03 DAV/KK SDTRCK ATTEMPT(Z-23AL1) API No: 50-029-21950-02 09/19/04 D16 SIDETRACK(Z-238) SEC 19,T11 N,R12E,4560'NSL&3214'WEL 09/23/04 CAO/PJC GLV C/O 02/27/06 JLJ/TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) WELLHEAD= 4"FMC • -23C 1 S NOTES: "70°ra 9236' ACTUATOR= BAKER "'CHROME TBG` KB.ems,/ 91.74' CTD Sidetrack I BF.ELEV= 55.36' KOP= 3100' 2205' 4-1/2"HES X NTP,D=3.813" Max Angle= 93(f 9799' Datum MD= 9,197' Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,68#,L-80,D=12.415" 2657 J 6 3095 3095 1 MMG DOME RK 16 ' 09/24/04 5 4995 4994 1 MMG DOME RK 16 09/24/04 4 6386 6379 13 MMG DOME RK 16 09/24/04 3 7451 7373 21 KBG2 DOME BK 16 09/24/04 2 8222 8083 22 KBG2 SO BK 22 08/02/11 Minimum ID = 3.725" @ 8755' 1 1 8580 8417 23 KBG2 DMY BK 0 08/02/11 4-1/2" HES XN NIPPLE 1 6565' H9-5/8"X 7"BKR ZXP LIP w MEEK SLV,D=6.28" • 8579' H9-5/8"X 7"BKR HMC LNR MGR w/R NP,D=6.18" MILLOUT WINDOW(Z-23B) 6718'-3734' MECHAMCAL WHPSTOCK(08/25/04) H 6718' I 8690' H4-1/2-Hes X NP,D=3.813" 8710' H 7"X 4-1/2"BKR S-3 PKR,ID=3.875" 9-5/8"HES EZSV(08/24/04) —I 6740• 8734' —{4-1/2'HES X NP,13=3.813" N; 8747' -{7'X 5"BKR ZXP LNR TOP PKR 9-5/8"CSG,47#,L-80,D=8.681" H 7472' = 4Ilk w/TEBK SLV,D=4.360" \I SEE PREVIUS AV �/ NS 8755' H4-1/2"FES XNNP,D=3.725" • 44444 • 4444SCHEMATIC FOR 111111 1101/41e �, 8766' 1F*IGRwIRNP,13=4.25 7'X 5'BKR MAC LNR 141111111A ►4111141111'_. . • W ELL Z-23A & Z-23AL1 4,v ia•,,"1.i,1:� M ,7!Xr; ' TBG & LNR DETAILS ) •,`�� . 8767' I�41/2"WLEG,D=3.958" I ' 8776' 5'X 4-1/2"XO 7"LNR,26#,L-80 BTC-M, — 8913' . ►, D=3.99" .0383 bpf,D=6.276" , 11111.111.0 ►7.7•747474747471 9154' 4-1/2"MARKER PERFORATION SUMMARY 4-1/2"TBG,12.6#,13CR VAM, 8767' c�'/ � 137'w/RA TAG REF LOG: MWD VISION RES LOG ON 08/22/04 .0152 bpf,D=3.958' ` p TOL - 9,050MS ANGLE AT TOP PERF: 63" @ 9175' Note:Refer to Production DB for historical pert data 3-1/2"x 3-1/4"X0 above w iadow ` 77°nc @ w ndow SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8" 4 9175-9185 0 06/14/11 41/2"BakerMonoboxewhtstnck@ 9,280MD , 35°/100' BUR 2-7/8" 4 9205-9225 O 06/16/11 '/ ` 2-7/8' 4 9275-9305 0 06/16/11 TD @ 12,249'M D / 2-7/8" 4 9405-9435 0 06/15/11 � ` 2-718' 4 9640-9660 0 06115/11 C IB P 9,310 2-7/8' 4 9680-9710 O 0615/114At\ 2-1/2" 4 9745-10160 0 09/08/04 3-1/4"x2-7�$"13Cr-85Linerto TD \\ , 2-1/2• 4 10224-10254 0 09/08/04 NO' 2-1/2" 4 10292-10390 O 09/08/04 2-1/2• 4 10400-10436 0 09/08/04 STD — 10461' 2-1/2" 4 10454-10460 0 09/08/04 4-1/2"LNR 12.6#,L-80 BTC-1111,.0152 bpf,D=3.958" H 10548' DATE REV BY COMMENTS , DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18189 FH ORIGINAL COMPLETION 06/26/11 SJW/PJC ADPERFS(0615-17/11) _ WELL: Z-23B 05/05/95 UNDER SIDETRACK(Z-23A) 08/15/11 TAR/PJC GLV C/O(8/2/11) PERMIT No: 2041080 07/08/03 DAV/KK SDIRCK ATTEMPT(Z-23AL1) API No: 50-029-21950-02 09/19/04 016 SIDETRACK(Z-23B) SEC 19,T11N,R12E,4560'NSL&3214'WEL 09/23/04 CAO/PJC GLV C/O 02/27/06 JU/TLH DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • 0 . • 1 1 .. 1 I I �I 1 °i ;1it I S %\...1.4 I Uf U lit • I I 1 1 0 • — 0:4 , St I I IMMM 4.- L §/ i � 1 1 ' 1 'm 1 1 °s Il 0 1 a a I O , S i Il ' .. .{I 1 Z- �0, 1 I Q .� 2 ® 1 { I 1 . ry t V U Z I .� O 1 x ®� ,, I H T. U a_i• 41 t I 1 a.,,,a{5nI >11 U- u etI I_ _ 1 � f f 1 re ® I I o u m m 1 (� � ' I :I rc r I � � W 1 A jji I+ �Iii g� I pe. WJLU- I ..� 1.,Mill .Y ! .[r;: 1 ��r. Sil ~ U \ MIV t EI I . . 't 1 p!--)216 f. 2 \ g - I- 1 . I c,) t? ,f m ) ' : x n m O- ac �1, I - . .`I ^ - I 0 o LIE 2m - - i x z I I Vr,r Z f - ; 1 N ¢ iik I , CD E f I a 1 1 _; 7. LL U 1 mE :.;1�' Uw' V 1 2 .Av I 1I Ohl,r- 'G I = + n x 1 - • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or 1 "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then/ j it on both copies of the Form 10-403 (AOGCC's and operator's copies). V Instead, check the "Suspended"box and initial that change. Drilling Engineer \/1 The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the"Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. e e Image Project Well History File Cover Page XHVZE 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. {2a ~ - L Q 8' Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 R,CAN ~COlor Items: o Greyscale Items: DIGITAL DATA ¢'Óiskettes, No. o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Daje ¡I/o lOb o Other:: BY: ~ /s/ vvtP Project Proofing 11111111111 III "III BY: ~ Date 11/g-lob /s/ mP 5(0 ,p BY: + 'J-& = TOTAL PAGES (Count does not include cover sheet) /5/ Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: 111'& /00 11111111I111111111I NO /5/ VY1F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /5/ 111111111111111111I Scanning is complete at this pOint unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ WaiverE Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ • 204 -1080 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 .+ 50- 029 - 21950 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028262 , PBU Z -23B 10. Field /Pool(s): , PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10550 feet Plugs (measured) None feet true vertical 9050.2 feet Junk (measured) None feet Effective Depth measured 10461 feet Packer (measured) 6571 8710 8758 feet true vertical 9001.39 feet (true vertical) 6558 8535 8577 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 87' 20" 91.5# H-40 31 - 118 31 - 118 1490 470 Surface 2627' 13- 3/8 "68# L -80 30 - 2657 30 - 2657 4930 2270 Production 6705' 9 -5/8" 47# L -80 29 - 6734 29 - 6714 6870 4760 Liner 2348' 7" 26# L -80 6565 - 8913 6552 - 8707 7240 5410 Liner 1801' 4 -1/2" 12.6# L -80 8747 - 10548 8567 - 9049 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ - - True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 8767 27 - 8585 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 6571 6558 4 -1/2" Baker SAB Hvdro -set Packer 8710 8535 5" Baker ZXP Too Packer 8758 8577 12. Stimulation or cement squeeze summary: e _ (j,,' Intervals treated (measured): 4 3 Z O y Treatment descriptions including volumes used and final pressure: :,,;s :., , t, , ^ '� '' l < a 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 15 126 96 273 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed ili e Last i i Title Petrotechnical Data Technologist Sign ��� Phone 564 -4091 Date 7/11/2011 713 t( Form 10 -404 Revised 10/2010 RBS JUL 111011 �% Submit Original Only //7%34 Z -23B 204 -108 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -23B 9/7/04 PER 9,745. 10,160. 8,916.89 8,913.27 Z -23B 9/7/04 PER 10,224. 10,254. 8,916.09 8,920.33 Z -23B 9/7/04 PER 10,292. 10,390. 8,928.84 8,966.92 Z -23B 9/7/04 PER 10,400. 10,436. 8,971.76 8,989.21 Z -23B 9/7/04 PER 10,454. 10,460. 8,997.96 9,000.9 Z -23B 6/15/11 APF 9,680. 9,710. 8,919.33 8,917.91 Z -23B 6/15/11 APF 9,405. 9,435. 8,926.09 8,925.25 Z -23B 6/15/11 APF 9,640. 9,660. 8,921.03 8,920.24 Z -23B 6/16/11 APF 9,275. 9,305. 8,916.07 8,922.09 Z -23B 6/16/11 APF 9,205. 9,225. 8,893.17 8,900.78 Z -23B 6/17/11 APF 9,175. 9,185. 8,880.31 8,884.79 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1 I 1 • • • Z -23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/15/2011i CTU #9 w/1.75" CT. Obj: Add Perf, Acidize. ***Job cont from 06/15/2011*** Memory 'log data good. RIH w/ 30' 2 -7/8" HSD PJ2906 HMX 4 SPF. Correct depth to flag !correlated to SLB MWD dated 04- Sept -2004. Perforate 9680- 9710'.. POOH. RIH w/ 120' 2 -7/8" HSD PJ2906 HMX 4 SPF. Perforate 9640- 9660'. POOH. RIH w/ 30' HSD PJ2906 HMX 4 SPF. Perforate 9405 - 9435'. POOH. RIH w/ SLB memory 1 ?gamma /CCL logging tools. « <Job Continued on 6/16/2011>>> 6/16/2011 j CTU #9 1.75" Coiled Tubing - Job Scope = Tie in log, Add Perf, Acid Job continued from 6/15/2011. Run tie in log, pooh. RIH w/ 30' x 2 -7/8" HSD PJ2906 HMX 4 SPF guns. Perforate 9,275 - 9,305'. POOH. RIH w/ 20' x 2 -7/8" 'HSD PJ2906 HMX 4 SPF guns. Perforate 9.205- 9,225'. POOH. RIH w/ 10' x 2 -7/8" HSP PJ2906 HMX 4 SPF pert gun. « <Job Continued on 6/17/2011>>> 6/17/2011 ASRC Test Unit #2, Standby while CTU pumps acid stim. Line up wells while CTU rig 'down. Open G/L to well. Prepare to open well to separator. ** *Job in progress * ** ;* *Inlet Z -23, outlet Z -21 ** 6/17/2011 CTU #9 1.75" Coil Tubing - Job Scope = Add perf, Acid Stimulation. « <Cont from 1 06/17/11 »> Perf 2 -7/8" HSD PJ2906 HMX 4 SPF guns. Shoot 9175 -9185' POOH. RIH w/ 2.50" ;JSN. Bullhead 40 bbls diesel down backside. Dry tag scale at 10427' CTM. ;Bullhead 240 bbls of NH4CI down CT. Perform inj test down CT: 2 bpm @ 1455 psi 'WHP using 20 bbl NH4CI preflush. Reciprocate 30 bbls of HCI and 30 bbls of HF :down CT. Park above perfs at 9745' CTM and pump 50 bbls of NH4CI overflush, 10 bbls of wax bead diversion in oilseeker, 10 bbls NH4CI spacer. Shut down to replace leaking chiksan. Reciprocate 30 bbls of HCI and 30 bbls of HF down CT. Park above perfs at 9745' CTM and pump 50 bbls of NH4CI overflush, 10 bbls of wax 'bead diversion in oilseeker, 10 bbls NH4CI spacer. Reciprocate 30 bbls of HCI and :27 bbls of HF down CT. Perform inj test down CT: 2 bpm @ 968 psi WHP using 20 !bbl NH4CI overflush. Final pressures with overflush 1660 psi © 2bbl min. Pooh and 'turn over to test seperator to POP. «<Job Complete »> • • 6/17/2011 * *Cont. from prey. WSR ** ;T /I /0= 155/40/140 Assist CTU #9 as directed. (Acid Stim) Pumped 2 bbls neat and '130 bbls crude down IA for CTU #9. Flushed hardline w/2 bbls neat per coil. Tag hung on IA. All hardline valve from choke skid to IA transducer = closed. CTU in :control of well and all valves upon departure, operator notified. FWHP's= 570/0/174 { { FLUIDS PUMPED BBLS 290 NH4C1 40 DIESEL 90 HF 90 HC1 20 OILSEEKER 4 NEAT METH 130 CRUDE 664 TOTAL TREE = 4" CIW WELLHEAD = FMC • SAFETY OS: 70° @ 9236' ACTUATOR = BAKER Z -2 3 B ** * CHROME TBG* ** KB. ELEV = 91.74' BF. ELEV = 55.36' - KOP = 3100' Max Angle = 93 @ 9799' 1 1 I 2205' H4 -1/2" HES X NIP, ID = 3.813" I Datum MD = 9,197' Datum TV D = 8800' SS GAS LIFT 113 -3/8" CSG, 68 #, L -80, ID = 12.415" 1-1 2657' I A J I ST MD ' VLV LATCH 1VD DEV TYPE VLV LATCH PORT DATE C 6 3095 3095 1 MMG DOME RK 16 09/24/04 5 4995 4994 1 MMG DOME RK 16 09/24/04 4 6386 6379 13 MMG DOME RK 16 09/24/04 3 7451 7373 21 KBG2 DOME BK 16 09/24/04 2 8222 8083 22 KBG2 DMY BK 0 09/10/04 Minimum ID = 3.725" @ 8755' 1 8580 8417 23 KBG2 SO BK 24 09/24/04 4 -1/2" HES XN NIPPLE I 6565' 1 - 1 9 X 7" BKR ZXP LTP w /TIEBK SLV, ID = 6.28" I I 6579' H9-5/8" X 7" BKR HMC LNR HNGR w /R NIP, ID = 6.18" I MILLOUT WINDOW (Z -23B) (MECHANICAL WHIPSTOCK (08/25/04) H 6718' 1 . 6718' - 6734' 8690' I — I4 - 1/2" HES X NIP, ID = 3.813" I 8710' I--17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 8734' H4-1/2" HES X NIP, ID = 3.813" I I9 -5/8" HES EZSV (08/24/04) I — I 6740' $ I 8747' 17" X 5" BKR ZXP LNR TOP PKR 9 -518" CSG, 47 #, L-80, ID = 8.681" I 7472' 7 w /TIEBK SLV, ID = 4.360" 1 o �� ,\ 8755' 1-14 112" HES XN NIP, ID = 3.725" I ♦/•• • 1 . � � � � +4 , 8766' — 7" X 5" BKR HMC LNR SEE PREVIOUS * 1 `1 * *11 4.1... ` HNGRw /RNIP, ID= 4.25" SCHEMATIC FOR 4 •!.���' �.;�i * *!�, • WELL Z -23A & Z -23AL1 °-44 ■ I 876T I_I4 -1/2" WLEG, ID = 3.958" I TBG & LNR DETAILS ® 8776' 115" x 4 -1/2' XO ID =3.99" PERFORATION SUMMARY 9154' — 4-1/2" MARKER REF LOG: MWD VISION RES LOG ON 08/22/04 ANGLE AT TOP F'ERF: 63° @ 9175' tA_�.�.�.�.�.�.� 4 -1/2" TBG, 12.6 #, 13CRVAM —I 8767 J JTw /RA TAG ` Note: Refer to Production DB for historical perf data .0152 bpf, ID = 3.958" SIZE SPF INTERVAL Opn /Sqz DATE • 2 -7/8" 4 9175 - 9185 0 06/14/11 7" LNR, 26 #, L -80 BTC-M, — 8913' I 2 -7/8" 4 9205 - 9225 0 06/16/11 .0383 bpf, ID = 6.276" • 2 -7/8" 4 9275 - 9305 0 06/16/11 2 -7/8" 4 9405 - 9435 0 06/15/11 ` 2 -7/8" 4 9640 - 9660 0 06/15/11 2 -7/8" 4 9680 - 9710 0 06/15/11 2 -1/2" 4 0224 - 10254 0 09/08/04 I PBTD I--I 10461' 1141,440 2 -1/2" 4 10292 - 10390 0 09/08/04 1 4-1/2" LNR, 12.6#, L -80 BTC-M, .0152 bpf, ID = 3.958" H 10548' I 2 -1/2" 4 10400 - 10436 0 09/08/04 2 -1/2" 4 10454 - 10460 0 09/08/04 I 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18/89 FH ORIGINAL COMPLETION 06/26/11 SJW/ PJC ADPERFS (06/15 - 17/11) WELL: Z -23B 05/05/95 LINDER SIDETRACK (Z -23A) PERMIT No: 2041080 07/08/03 DAV /KK SDTRCK ATTEMPT (Z- 23AL1; API No: 50- 029 - 21950 -02 09/19/04 D16 SIDETRACK (Z -23B) SEC 19, T11N, R12E, 4560' NSL & 3214' WEL 09/23/04 CAO /PJC GLV C/0 02/27/06 JLJ/TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) ~ BP Exploration (Alaska) Ina Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~~~1~.~~~~ <<~ ~ : 't ~ 20~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, ~ bp ~~~s~~~~~ OCT 0 5 20Q9 ~I~sk~ ~il F~ Gas Cons. Gor~xr~iR~ian Anchorape ~O~ r C~V ~.- ~3 ~ 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 Expioration (Alaska ) lnc. 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 # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na ai 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 7/24/2009 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 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 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-146 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 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 500292197t0000 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 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-236 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 50029219540W0 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-3i 1881120 50029218710000 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 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z38 1980600 50029228730000 NA 1.2 NA 11.90 ~/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 50029231820000 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-1o8 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 50029233800000 NA surface NA r • <~.._ >,~--- ~~'. ;' ,;t;. ~~ '• ~ 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I.aserFiche\CvrPgs_Inserts\Microfilm Marker.doc i STATE OF ALASKA /-/O-O~ .. ALA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS f~E~EI ~l JAN Q 9 20~?_j 1. Operations Abandon ~ Repair Well a Plug Perforations ~ Stimulated Q~~ C;T^(~~SEO~i Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extens~fl~j r~~2 Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 2oa-1o8o' 3. Address: P.O. Box 196612 Stratigraphic ~ ServlCe 6. API Number: Anchorage, AK 99519-6612 50-029-21950-02-00 7. KB Elevation (ft): 9. Well Name and Number: 81.06 KB PBU Z-236 ' 8. Property Designation: 10. Field/Pool(s): - ADLO-028262 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10550 - feet Plugs (measured) None true vertical 9050.2 - feet Junk (measured) None Effective Depth measured 10461 - feet t(~~;~~~~,,gy~~((~i ~~ hp ry~y~y E:~tl9 J/i~ ~ ~ LUU true vertical 9001.39 - feet Casing Length Size MD TVD Burst Collapse Conductor 87 20" 91.5# H-40 31 - 118 31 - 118 1490 470 Production 6689 9-5/8" 47# NT80S 29 - 6718 29 - 6699 6870 4760 Surface 2627 13-3/8" 68# L-80 30 - 2657 30 - 2657 4930 2270 Liner 2348 7" 26# L-80 6565 - 8913 6553 - 8707 7240 5410 Liner 1801 4-1/2" 12.6# L-80 8747 - 10548 8567 - 9049 8430 7500 Perforation depth: Measured depth: 9745 - 10160 10224 - 10254 10292 - 10390 10400 - 10436 10454 - 10460 True Vertical depth: 8916.89 - 8913.27 8916.09 - 8920.33 8928.84 - 8966.92 8971.76 - 8989.21 8997.96 - 9000.9 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 27 - 8767 0 0 - Packers and SSSV (type and measured depth) 7" Baker ZXP Top Packer 6571 4-1/2" Baker SAB Hydro-set Packer 8710 5" Baker ZXP Top Packer 8758 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT IN Subsequent to operation: 181 406 554 267 14. Attachments: 15. Wetl Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas '' WAG ~' GINJ ~ ~ WINJ ~' WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature -_ Phone 564-4944 Date 1/8/2008 Form 10-404 Re4ised 04/2006 ~- -•- ~~~!~ ~~' r'`~~ f ~ ZQ~~ ~ ` ~~,~c~ Submit Original Only • Z-23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/3/2007 T/I/O = SSV/110/140. Temp = SI. Assist Sealtite (wellhead leak). Assisted Sealtite with pumping 35 gal of Sealtite into OA. OAP increased to 500 psi. SI, monitored for 45 min. OAP decreased to 350 psi. Will return tomorrow. Final WHPs = SSV/110/350. 12/3/2007 T/I/0= SSV/110/140, Temp= SI. Assist Seal Tite/ braiden head repair. Rigged up pump equipment to OA. Pumped Gel- seal to 500 psi (20 gal). Monitored pressure for 45 min, OAP decreased to 350 psi. Pumped Gel-seal to 500 psi (15 gal), no leak on braiden head observed. Will return in AM to check braiden head, will repressure OAP to 500 psi. 12/4/2007 T/I/O =SSV/80/140. Temp = SI. Assist Seal Tite. OAP decreased 210 psi overnight. Assisted Seal Tite with pumping 15 gal Gel Seal into the OA. OAP increased to 500 psi. SI, montored for 30 min. OAP decreased to 280 psi. No .leaks on the Braden head. RDMO. Final WHPs =SSV/80/280. 12/4/2007T/I/O=SSV/80/140, Temp=S1. Assist Seal Tite/ Braiden head repair. Rigged up pump equipment to OA, pumped 15 gal of Gel-seal. Pressure increased to 500 psi. No leak observed on braiden head. RDMO. RECEIVED Scblumbepgep OCT 1 6 2006 NO. 3990 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: ~ C11 & Gas Cons. Commission Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 dló4f- }I(.þf) 1.;. It-I <1-'1 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 12-29 11072867 INJECTION PROFILE 07/07/05 1 Z-19A 11212887 USIT 09/12/06 1 MPH-14 11414383 LDL 09/21/06 1 Z-23B 40010787 OH EDIT OF MWD/LWD 09/04/04 2 1 P-27 40010459 OH EDIT OF MWD/LWD OS/21/04 2 1 .. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10/12/06 . . PBU Z-23B . . Andy, No open hole logging data was submitted for: PBU Z-23B API 50-029-21950-02 Please send over bluelines, reproduceables. and digital logging data for this well as soon as possible. TNX Howard 1 of 1 10/3/2006 8:56 AM q D ù\- ,(.ð~ (p DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041080 Well NamelNo. PRUDHOE BA V UNIT Z-23B"""-- Operator BP EXPLORATION (ALASKA) INC API !!5~2¿~5~O~ ~ MD 10550·'-- TVD 9050- Completion Date 9/9/2004 - Completion Status 1-01L Current Status 1-01L UIC N --- --- ~.~,~-~. REQUIRED INFORMATION Mud Log No Samples No Directional surv~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Name Log Log Run Scale Media No Interval Start Stop . Log/ Data Type ko A~ Well CoreslSamples Information: Electr Digital Dataset MedlFrmt Number OHI CH Received Comments ~------l I I I Directional Survey Directional Survey 6700 10550 6700 10550 10/4/2004 10/4/2004 Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION vkb Daily History Received? ~ . Well Cored? Chips Received? '- Y I t..r,.- Formation Tops Analysis Received? ~ -~~- Comments: Compliance Reviewed By: -k Date: ð ()'à--~~ · STATE OF ALASKA . RECE¡VEr'~: ALAS~ILAND GAS CONSERVATION COf, SSION MAv, U ~N$1 0 2005 REPORT OF SUNDRY WELL OPER I!Q ^ 1. Operations Performed: -.. u ¡':ii11i t.mì5. Ctìiìlí1:jSi!J! Abandon 0 Repair WellO Pluç¡ Perforations 0 Stimulate 00 Ailchoraae Other . ~ Alter CasingD Pull Tubing 0 Perforate New PoolD WaiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development (]] ExploratoryD 204-1080 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 Service 0 50-029-21950-02-00 7. KB Elevation (ft): 9. Well Name and Number: 81.06 Z-23B 8. Property Designation: 10. Field/Pool(s): ADL-028262 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10550 feet true vertical 9050.2 feet Plugs (measured) None Effective Depth measured 10461 feet Junk (measured) None true vertical 9001.4 feet Casing Length Size MD TVD Burst Collapse Conductor 87 20" 91.5# H-40 31 - 118 31.0 - 118.0 1490 470 Liner 2348 7" 26# L-80 6565 - 8913 6552.5 - 8706.9 7240 5410 Liner 1801 4-1/2" 12.6# L-80 8747 - 10548 8567.1 - 9049.1 8430 7500 Production 6689 9-5/8" 47# NT80S 29 - 6718 29.0 - 6698.8 6870 4760 Surface 2627 13-3/8" 68# L-80 30 - 2657 30.0 - 2656.8 4930 2270 Measured depth: 9745 -10160,10224 -10254,10292 - 10390,10400 - 10436,10454 -10460 True vertical depth: 8916.89 - 8913.27, 8916.09 - 8920.33, 8928.84 - 8966.92, 8971.76 - 8989.21, 8997.96 - 9000.9 Tubinç¡ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 27 - 8767 Packers & SSSV (type & measured depth): 7" Baker ZXP Top Packer @ 6571 RBDMS BFL MAY.:t1 2005 4-1/2" Baker SAB Hydro-set Packer @ 8710 5" Baker ZXP Top Packer @ 8758 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9745' - 10460' Treatment descriptions including volumes used and final pressure: 661 Bbls 7.5% HCL, 661 Bbls 9:1 Mud Acid @ 3480 psig 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 288 0.4 112 0 294 Subsequent to operation: 582 0.7 1297 0 283 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development ŒI Service 0 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ~ OilŒl GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or NIA if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature )1tl~ C,dJ··- Phone 564-4657 Date 5/6/05 ·t....,. -'-&I ""'" ^ , Form 10-404 Revised 4/2004 . . Z-23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/15/05 MIRU CTU #5. PT WELLHEAD STACK AND LINES TO 4000 PSI. LOAD IA WI 280 BBLS OF CRUDE AND 120 BBLS OF DIESEL. LOAD WELLBORE WI 350 BBLS OF NH4CL AND 40 BBLS OF DIESEL. PRE-INJECTIVITY = 1.8 BPM @ 1900 PSI WHP. PUMP 10 BBL 7.5% HCL PICKLE THROUGH CT. CONTINUED ON 03/16/05 WSR. 03/16/05 CONTINUED FROM 03/15/05 WSR. COMPLETE TBG PICKLE. RIH WI 2.5" JSN. BEGIN PUMPING MULTI STAGES OF 7.5% HCL, 9:1 MUD ACID, 3% NH4CL OVERFLUSH, 65 QUALITY FOAM WI J529 DIVERTER AND 3% NH4CL SPACER STAGES ACROSS PERF INTERVALS FROM 10455'-9865'. STAGE 671N PROGRESS. CONTINUED ON 03/17/05 WSR. 03/17/05 CONTINUED FROM 03/18/05 WSR. STAGE 671N PROGRESS. PUMPING MULTI STAGES OF 7.5% HCL, 9:1 MUD ACID, 3% NH4CL OVERFLUSH, 65 QUALITY FOAM WI J529 DIVERTER AND 3% NH4CL SPACER STAGES ACROSS PERF INTERVALS FROM 9865'· 9745'. COMPLETE 89 STAGES. RDMO. FLUIDS PUMPED BBLS 31 60/40 Methonal/Water 500 3% NH4CL wi 0.2% F-103 661 7.5% HCL 661 9: 1 Mud Acid 90 3% NH4CL wi J529 5 Fresh Water 1948 TOTAL Page 1 . Completion . FROM 13-3/8" CSG, 68#, L-80, ID= 12.415" I 2657' X Nipple 10 :::: 3,813" ST MD 6 3094 5 4995 4 6386 3 7451 2 8221 1 8580 lVD 3094 4993 6379 7384 8085 8425 GAS LIFT MANDR8..S DEV TYÆ VLV LATCH o MMG DOME RK o MMG DOME RK 12 MMG DOME RK 21 KBGS DOME RK 22 KBGS DMY RK 23 KBGS SO RK PORT DATE 16 09/24/04 16 09/24/04 16 09/24/04 16 09/24/04 o 09/10104 24 09/24/04 4-1/2{; '12.6# 1 Yam TOP Tubing 8,767' 9-5/8" CSG, 47#, L-80. ID = 8,681" H 7472' ~9-5/8" x T' HMC!ZXP hgr/pkr 6,571' MO X Nipple 10 :::: 3.813" 8,689' T x 4-1/2" HCM/ZXP hgr/pkr 8.110' MO X 10:::: 3.813" 8.734' XN Nipple 10:::: 3.725" 9-5/8" whipstock at 6835'MD ~ I 7299' I TOP OF BKRTIEBACK SLV, D=6.~ ~ 7306' I 9-518" X 7" BKR H LI\R T(P T 26# L-80 BTC-M Liner 8.915' MO / Baker T' x 5" at 8,758'MO 19-5/8" MILLOUT WINDOW 7472' - 7527' I I PiP Tag 8996' 7" X 4-1/2" BKR S-3 PKR. NO LA TCH. 10 3.938" 154' Pre-rig P&A over fish and tbg cut at 7400'MDFloat Collar 10.461'MD Shoe at 10,548'MO TOP OF 2ND WHIPSTOCK I" 9010' 19020' SLM I FISH· 2.75" 00 x 3.25" LONG SPIRAL GRAPPLE 1" 00 x 2" LONG SPIRAL GRAPPLE 18" BENT WHIPSTOCK FISHING TIP 3.80" HC OP0261 OS MILL 9 1 4 8 . 1-1 S TAN 0 IN G V A L V E W / C H E C K I PBTD I 9489' 7" LNR, 29#, L-80, 0.0371 bpf, ID - 6.184" 9575' DA TE REV BY COMMENTS 10/18/89 FH ORIGINAL COMPLETION 05/05/95 LINDER SIDETRACK (Z-23A) 07108/03 DA V IKK A HEM PTED Z-23AL 1 03/24/05 CAO/PJC GLV CIO (09/24/04) DATE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: Z-23B proposed ÆRMrr No: API No: TBD SEe 19, T11N, R12E, 4560' NSL & 3214' WEL BP Exploration (Alaska) _ STATE OF ALASKA ALAS~ AND GAS CONSERVATION COM.ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~\/ED OCT 122004 ø, ,j, ,"J:.¡ P. r,;.u· í",,,,,r;; í' , 1a. Well Status:·a Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. WãnClass: , ,i 20AAC 25.105 20AAC 25.110 a Developmenf\i't]ì~xiJlðratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/9/2004 204-108 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/26/2004 50- 029-21950-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/4/2004 PBU Z-23B 4560' NSL, 3214' WEL, SEC. 19, T11N, R12E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 510' NSL, 3430' WEL, SEC. 18, T11N, R12E, UM 81.06' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 712' NSL, 4541' WEL, SEC. 18, T11N, R12E, UM 10461 + 9001 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 599459 y- 5959360 Zone- ASP4 10550 + 9050 Ft ADL 028262 ~- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 599222 y- 5960586 Zone- ASP4 Total Depth: x- ~- (Nipple) 2205' MD 598107 y- 5960774 Zone- ASP4 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost aYes DNo NI A MSL 1900' (Approx.) 21. Logs Run: DIR I GR I RES I PWD, DIR I GR I RES I PWD 2. CASING, liNER AND CEMENTING RECORD CASING SE"rT'INGPEif>1"HMP '¡:)I:'TTI I G'DEPTHTVO ~~i€ / ~~'::'I'II SIZE WT.PERFT. .GRAD~ . TOR BOttOM TOp I BOTTOM .......... t"'UI.LiEO 20" Conductor Surface 118' Surface 118' 13-3/8" 68# L-80 Surface 2657' Surface 2657' 17-1/2" 3684 cu ft Permafrost 9-518" 47# NT80S Surface 6718' Surface 6699' 12-1/4" 1894 cu ft Class 'G' 7" 26# L-80 6565' 8913' 6552' 8707' 8-1/2" 488 cu ft Class 'G' 4-1/2" 12.6# L-80 8747' 10548' 8567' 9049' 6-1/8" 281 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24. T JBING . ii Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MO) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8767' 8710' MD TVD MD TVD 9745' - 10160; 8917' - 8913' 25. ACIE), 10224' - 10254' 8916' - 8920' ',"' "",'. 1 0292' - 1 0390' 8929' - 8967' DEPTH INTERVALi(MD) AMOUNT & KIND OF MATERIAL USED 10400' - 10436' 8972' - 8989' 10454' - 10460' 8998' - 9001' Freeze Protect with 160 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 4,2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAs-all RATIO 10/9/2004 8 TEST PERIOD .. 338 273 36 1760 806 Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBLi all GRAVITY-API (CORR) Press. 305 960 24-HoUR RATE 1,015 818 108 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). -:"F,;: · rnme, smre "rnme" ORIGINAL . ~~.;;J ~~ ^ Form 10-407 Revised 1212003 CONTINUED ON REVERSE SIDE Ð'Œ iW1S c.;:;Jt . , !1 28. GEOLOGIC MARKERS NAME MD Sag River 8909' Shublik 8947' Eileen 9101' Sadlerochit 9168' 45N 9232' 45P 9273' 45P (Invert) 9665' 45N 9742' 45N (Revert) 10255' 29. RMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8704' None 8734' 8841' 8877' 8903' 8916' 8920' 8917' 8921' 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 PBU Z-23B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Jim Smith, 564-5773 204-108 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-Altemating-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-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8/18/2004 08:00 - 15:00 7.00 MOB P PRE Prepare rig for move to Z-23B. Install boosters, lay derrick over. 15:00 - 00:00 9.00 MOB P PRE Move rig off w-pad and down access road. Road conditions required extensive matting. 8/19/2004 00:00 - 00:00 24.00 MOB P PRE Continue move to Z-23B. Move rig to Chevron pad at the intersection of the Spine Road and Z-Pad access road. Wait on Chervron pad while mats are staged on Z-Pad and the access road. Begin moving the rig down Z-Pad access road. 8/20/2004 00:00 - 04:00 4.00 MOB P PRE Continue moving rig to Z-23B 04:00 - 06:00 2.00 MOB P PRE Spot rig on Z-pad. At 0600 rig on Z-Pad and ready to begin mods and repairs. 06:00 - 00:00 18.00 MOB P PRE Perform rig mods and repairs. Repair Dyna-Matic and prepare to change out crown sheaves. Install equalizer line in Pits #1 & #2 8/21/2004 00:00 - 00:00 24.00 MOB P PRE Continue performing rig mods and repairs. Install mud transfer line and equalizer line in Pits #1 & #2. Unstring derrick and change out crown sheave cluster, re-string derrick. Change out boiler. Hold a PJSM prior to all operations. 8/22/2004 00:00 - 03:30 3.50 RIGU P PRE Inspect and raise derrick. 03:30 - 04:30 1.00 RIGU P PRE Spot rig over Z-23, shim and level rig. 04:30 - 09:30 5.00 RIGU P PRE RU floor and cattle chute. Unbridle and hang lines. 09:30 - 17:00 7.50 RIGU P PRE Spot and RU pit and pump modules. Install bridle line pockets in derrick. Welding on mud transfer line in pits. RIG ACCEPTED @ 18:00 18:00 - 18:30 0.50 WHSUR P DECOMP Pre-spud meeting with all rig personnel. 18:30 - 19:00 0.50 WHSUR P DECOMP RU lines to circulate out freeze protect. PU top drive. 19:00 - 19:30 0.50 WHSUR P DECOMP RU little red to pump hot diesel. 19:30 - 20:30 1.00 WHSUR P DECOMP RU DSM and pull BPV through lubricator. RD DSM. 50 psi tbg pressure after pulling BPV. 20:30 - 21 :00 0.50 WHSUR P DECOMP RU vac trucks to pump hot seawater. 21 :00 - 21 :30 0.50 WHSUR P DECOMP PJSM with all rig personnel on pressure testing lines and pumping diesel and seawater. 21 :30 - 22:00 0.50 WHSUR P DECOMP Pressure test all lines to 1000 psi. 22:00 - 22:30 0.50 WHSUR P DECOMP Pump 50 bbls 160 degree diesel. 22:30 - 00:00 1.50 WHSUR P DECOMP Switch to rig pump and displace well with 160 degree seawater. 5 bpm @ 300 psi 8/23/2004 00:00 - 01 :00 1.00 WHSUR P DECOMP Continue displacing well with 750 bbls 160 degree seawater, 5 bpm @ 400 psi. circulated out 190 bbl diesel to slop tank 01 :00 - 01 :30 0.50 WHSUR P DECOMP Bleed off well. Flow check - Static. RD and blow down lines. 01 :30 - 02:00 0.50 WHSUR P DECOMP Install TWC and pressure test to 1000 psi from below. 02:00 - 02:30 0.50 WHSUR P DECOMP PJSM with FMC and rig personnel on nipple down tree and adapter flange. 02:30 - 04:00 1.50 WHSUR P DECOMP NO tree and adapter flange. 04:00 - 09:30 5.50 BOPSU P DECOMP NU BOPE. Install HCR valves. Hook up choke & kill lines to HCR valves. NU riser & flow line. 09:30 - 10:30 1.00 BOPSU P DECOMP RU test equipment. 10:30 - 16:00 5.50 BOPSU P DECOMP Test BOPE - 250/3500 psi, annular 250/3500 psi. All tests charted and held for 5 minutes. Witness of test waived by Chuck Sheave with AOGCC. Printed: 9/13/2004 10: 14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 617/1989 End: Upper variable rams would not test, change out with 5" solid rams. 16:00 - 16:30 0.50 BOPSU DECOMP Blow down lines and RD BOP test equipment. LD test joint. 16:30 - 17:30 1.00 PULL DECOMP RU DSM lubricator and pull TWC. RD DSM lubricator. 17:30 - 19:00 1.50 CASE DECOMP RU to test casing. Pressure up to 200 psi to check for leaks. HCR valve weeping fluid, change out HCR valve 19:00 - 19:30 0.50 CASE P DECOMP Test 9-5/8",47# casing to 3500 psi for 10 minutes. 19:30 - 20:00 0.50 PULL P DECOMP PJSM with BOT and all rig personnel on spearing tbg and pulling hanger. 20:00 - 21 :00 1.00 PULL P DECOMP MU tbg spear and 1 jt 5" DP. RIH and spear tbg hanger. BOLDS. PU 120k string weight and unseat tbg hanger. Up weight w/ tbg 120k. Pull hanger to floor. 21 :00 - 22:30 1.50 PULL P DECOMP RU circulating head and lines to 4-1/2" tbg. CBU, 10 bpm @ 1000 psi. RU Cameo spooling unit to spool control line. 22:30 - 23:00 0.50 PULL P DECOMP Monitor well - static. PJSM on pulling and laying down 4-1/2" tbg. 23:00 - 23:30 0.50 PULL P DECOMP Terminate control lines. Breakout and LD tbg hanger. 23:30 - 00:00 0.50 PULL P DECOMP POH, laying down 4-1/2" tbg, spooling up dual 1/4" control lines with Camco spooling unit. 8/24/2004 00:00 - 01 :30 1.50 PULL P DECOMP POH, laying down 4-1/2" tbg, spooling up dual 1/4" control lines with Camco spooling unit. Recovered: 53 - joints 4-1/2" tbg 56 - stainless steel bands 1 - HES "HXO" SSSV assembly 01 :30 - 02:00 0.50 PULL P DECOMP RD Camco spooling unit. LD HES 4-1/2" SSSV assembly. 02:00 - 07:30 5.50 PULL P DECOMP Continue POH laying down 4-1/2" tbg and completion jewelry. Recovered: 131 - joints 4-1/2" tbg 4 - GLM assemblies 1- 19.31'cutjointoftbg Tubing stub @7390' KB 07:30 - 08:00 0.50 PULL P DECOMP RD 4-1/2" tbg equipment. 08:00 - 09:00 1.00 PULL P DECOMP Clear tools & scrub rig floor. 09:00 - 09:30 0.50 DHB P DECOMP RU Schlumberger e-line unit. PJSM with SWS, HOWCO and all rig personnel on running JB/GR and setting EZSV. 09:30 - 11 :30 2.00 DHB P DECOMP Run Schlumberger junk basket and 8.5" gauge ring, with GR/CCL. Tag up on 7" liner at 7299'. Log up with GR/CCL from 7299' to 6300. POH with wireline 11 :30 - 13:30 2.00 DHB P DECOMP MU Halliburton 9-5/8" EZSV bridge plug on e-line setting tool. RIH with EZSV to 6800'. Log up and tie in to GR on previous run. Set EZSV @ 6740'. Continue logging up with CCUGR to 6600' to confirm tools on depth. RIH and tag up on EZSV @ 6740'. POH with e-line. 13:30 - 14:30 1.00 CASE P DECOMP PJSM with all rig personnel on Pressure testing csg. Close blind rams and test 9-5/8", 47# casing to 3500 psi for 30 minutes. Bleed pressure and RD test equipment. 14:00 - 16:00 2.00 BOPSU P DECOMP PJSM with all rig person on changing rams and pressure testing BOPE. Change out upper pipe rams to 3-1/2" X 6" variables. Change out HeR valve. Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: Pull wear bushing and RIH with test plug. RU test equipment. Test HeR valve and upper and lower variable pipe rams to 250 psi I 3500 psi. RD test equipment. 17:30 - 18:00 0.50 BOPSU P DECOMP Pull test plug and install wear bushing. 18:00 - 18:30 0.50 STWHIP P DECOMP PJSM with all rig personnel on picking up DP from pipe shed. 18:30 - 00:00 5.50 STWHIP P DECOMP PU 5" DP from pipe shed. At midnight 150 jts picked up 8/25/2004 00:00 - 03:00 3.00 STWHIP P DECOMP Continue PU 216 jts of 5" DP from pipe shed. 03:00 - 04:30 1.50 STWHIP P DECOMP Cut and slip 70' of drill line. Service top drive and crown. Calibrate block height for MWD 04:30 - 09:00 4.50 STWHIP P DECOMP POH racking 5" DP back in derrick. 09:00 - 12:00 3.00 STWHIP P DECOMP RIH with 9 6-1/4" DC's and 18 jts of 5" HWDP. 12:00 - 12:30 0.50 STWHIP P DECOMP POH with DC's and HWDP racking stands back in derrick. 12:30 - 16:00 3.50 STWHIP P WEXIT PU whipstock assembly and RIH. Shallow test MWD, 16:00 - 19:30 3.50 STWHIP P WEXIT RIH with whipstock assembly. Fill pipe at 2814' and 4695' 19:30 - 20:00 0.50 STWHIP P WEXIT Orient whipstock 47L. P/U 204K Ibs S/O 200k Ibs 20:00 - 20:30 0.50 STWHIP P WEXIT RIH and set whipstock anchor with 25 klbs. PU to 210k and verify anchor set. Slack off and shear lug with 45 klbs. TOW will be @ 6718' 20:30 - 21 :30 1.00 STWHIP P WEXIT Empty seawater from pits and fill with 10.6 ppg LSND mud. 21 :30 - 22:00 0.50 STWHIP P WEXIT PJSM with BOT, VECO, Peak and all rig personnel on displacing well to LSND mud and milling window. 22:00 - 23:00 1.00 STWHIP P WEXIT Displace well to 10.6 ppg LSND mud. 630 gpm @ 1500 psi 23:00 - 00:00 1.00 STWHIP P WEXIT Mill window from 6718' to 6719'. WOM = 0-2 klbs RPM = 80 Torque on Btm = 7-12k FtLb GPM = 500 @ 1420 psi on Btm, P/U 190k S/O 190k ROT 192k 8/26/2004 00:00 - 06:30 6.50 STWHIP P WEXIT Continue milling window and from 6719' to 6734'. Drill new hole to 6748' for FIT and to ensure window is full 8.5" gauge. WOM = 10-25 klbs RPM = 110 Torque on Btm = 5-1 Ok FtLb, off Btm = 4k FtLb GPM = 500 @ 1400 psi on Btm P/U 195k S/O 185k ROT 195k TOW - 6718' BOW - 6734' 06:30 - 07:30 1.00 STWHIP P WEXIT Pump and circulate around 20 bbl Super sweep, 11 bpm @ 3300 psi. Total metal cuttings recovered = 280 Ibs Printed: 9/13/2004 10: 14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8126/2004 07:30 - 09:00 1.50 STWHIP P WEXIT 09:00 - 09:30 0.50 STWHIP P WEXIT 09:30 . 13:00 3.50 STWHIP P WEXIT 13:00 - 14:00 1.00 STWHIP P WEXIT 14:00 - 14:30 0.50 STWHIP P WEXIT 14:30 - 15:00 0.50 BOPSU P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 17:00 1.50 STWHIP P WEXIT 17:00 - 17:30 0.50 STWHIP P WEXIT 17:30 - 20:00 2.50 STWHIP P WEXIT 20:00 - 22:00 2.00 STWHIP P WEXIT 22:00 - 22:30 0.50 STWHIP P WEXIT 22:30 - 23:00 0.50 STWHIP P WEXIT 23:00 - 00:00 1.00 DRILL P INT1 8/2712004 00:00 . 00:00 24.00 DRILL P INT1 Pull mills above whipstock and perform 11.9 ppg EMW FIT: TMD = 6726' TVD = 6706' MW = 10.5 ppg Surf press = 490 psi Monitor well - Static. Blow down top drive. Slug DP and POH with milling assembly. Monitor well - static. LD Milling BHA. Clean and clear rig floor. MU ported sub and flush BOP stack. PJSM with Anadrill and all rig personnel on picking up and running directional BHA. PU and MU BHA #2, 8-1/2" directional assembly. Shallow test MWD tools. RIH with directional BHA picking up 57 joints of 4" DP from pipe shed. Fill DP and test MWD. Continue RIH with BHA #2 on 5" DP. Break circulation every 35 stands. Orient tool face 45L and RIH with no rotation or pump to 6744'. P/U 180k S/O 180k Stage up pumps to 600 gpm and wash down to 6748' Establish baseline ECD of 11.28 ppg Directional drill 8-1/2" intermediate hole from 6748' to 6795', sliding 100%. WOB = 10-15 klbs RPM Surf= 0, DH = 204 GPM = 560 @ 2050 psi on Btm, 2250 psi off Btm P/U 178k S/O 174k Calculated ECD = 11.28 ppg Actual ECD = 11.4 ppg ART last 24 hrs = 0.0 hrs AST last 24 hrs = 0.8 hrs Directional drill 8-1/2" intermediate hole from 6795' to 8384', sliding as required to build angle and azimuth. WOB = 8-11 klbs RPM Surf= 100-140, DH = 265 GPM = 530 @ 2320 psi on Btm, 2100 psi off Btm P/U 215k SIO 193k ROT 205k Circulate sweeps around, alternating between hi-vis and weighted, as need to clean hole. Backream each stand at full rate, reducing pump rate to -400 gpm on the down stroke. Calculated ECD = 11.43 ppg Actual ECD = 11.56 ppg Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8/27/2004 00:00 - 00:00 24.00 DRILL P INT1 ART last 24 hrs. = 7.48 hrs. AST last 24 hrs. = 7.82 hrs. Total drilling hours = 16.1 hrs 8/28/2004 00:00 - 23:00 23.00 DRILL P INT1 Directional drill 8-1/2" intermediate hole from 8384' to 8900', sliding as required to build angle and azimuth. WOB = 5-8 klbs RPM Surf= 100-120, DH = 265 GPM = 530 @ 2300 psi on Btm, 2150 psi off Btm Torque = 9k FtLbs on Btm, 7K off Btm P/U 228k S/O 202k ROT 216k Circulate sweeps around, alternating between hi-vis and weighted, as needed to clean hole. Backream each stand at full rate, reducing pump rate on the down stroke. At 03:00 started seeing splintered shales across the shakers, weighted up the mud by 0.2 ppg to 10.8 ppg. This alleviated the problem, only occasional shales across the screens for the rest of the day Calculated ECD = 11.25 ppg Actual ECD = 11.42 ppg ART last 24 hrs. = 1.95 hrs. AST last 24 hrs. = 11.88 hrs. Total drilling hours = 29.93 hrs 23:00 - 00:00 1.00 DRILL P INT1 Circulate samples up for geologist to pick casing point. Reciprocated DP within 5' of bottom RPM = 100 GPM = 530 @ 2180 psi 8/29/2004 00:00 - 01 :00 1.00 DRILL P INT1 Drill 1 0' to 8910' and circulate up samples for the geologist. Reciprocated DP within 5' of bottom RPM = 100 GPM = 530 @ 2180 psi 01 :00 - 01 :45 0.75 DRILL P INT1 Drill 5' to 8915' and circulate up samples for the geologist. Reciprocated DP within 5' of bottom RPM = 100 GPM = 530 @ 2180 psi ART last 24 hrs. = 0.2 hrs. AST last 24 hrs. = 0.0 hrs. Total drilling hours = 30.43 hrs 01 :45 - 02:00 0.25 DRILL P INT1 Monitor well - static 02:00 - 03:30 1.50 DRILL P INT1 POH 23 stands to the window at 6718'. Prior to short trip: calculated ECD = 11.42 ppg, actual ECD = 11.34 ppg. P/U 215k S/O 195k ROT 21 Ok Pulled 20-30k over at: Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8/29/2004 02:00 - 03:30 1.50 DRILL P INT1 7898' 7757' 7507' 7089' Wipe through with no problems. 03:30 - 03:45 0.25 DRILL P INT1 Monitor well - static 03:30 - 04:30 1.00 DRILL P INT1 RIH to TD at 8853. No problems going back through tight spots on short trip. 04:30 - 05:00 0.50 DRILL P INT1 MU top drive and wash last stand down to 8915'. 05:00 - 06:30 1.50 DRILL P INT1 Circulate 20 bbls hi-vis sweep surface to surface. Continue circulating to clean hole, BU X 2. 06:30 - 06:45 0.25 DRILL P INT1 Monitor well - static 06:45 - 11 :00 4.25 DRILL P INT1 Pull 2 stands, slug DP and POH to the BHA. No problems encountered on the trip out. 11 :00 - 13:30 2.50 DRILL P INT1 Monitor well - static. LD BHA #2 13:30 - 14:30 1.00 BOPSU P LNR1 Change top BOP rams to 4-1/2" - 7" VBR's. 14:30 - 15:30 1.00 BOPSU P LNR1 Pull wear bushing. RIH with test plug. Test upper rams to 250/3500 psi. Pull test plug and install wear bushing. 15:30 - 16:00 0.50 CASE P LNR1 RU 7" casing equipment. 16:00 - 16:30 0.50 CASE P LNR1 PJSM with all rig personnel on picking up and running 7" liner. 16:30 - 20:30 4.00 CASE P LNR1 PU and MU float equipment, check floats. Run 56 joints 7", 26#, L-80, BTC-M liner. 20:30 - 22:00 1.50 CASE P LNR1 MU Baker HMC hydraulic liner hanger and ZXP liner top packer. CO to 5" handling equipment. 22:00 - 00:00 2.00 CASE P LNR1 RIH with 7" liner on 5" DP, 1-1/2 minute per stand maximum running speed while in 9-5/8" csg. Fill DP every 10 stands. Midnight: 20 stands in, liner depth = 4433' 8/30/2004 00:00 - 01 :30 1.50 CASE P LNR1 Continue RIH with 7" liner on 5" DP, 1-1/2 minute per stand maximum running speed while in 9-5/8" csg. Fill DP every 10 stands. 01 :30 - 02:30 1.00 CASE P LNR1 Stage pumps to 6 bpm, CBU prior to entering OH. While circulating change elevators and move 4" DP across derrick to continue running liner on 5" DP. 6 bpm @ 750 psi 02:30 - 03:00 0.50 CASE P LNR1 Change to 5" elevators and LD a single joint of DP for cement head space out. MU TD cement head and DP pup jts, lay on skate. 03:00 - 05:00 2.00 CASE P LNR1 Continue RIH with 7" liner on 5" DP. 1.5 min per stand inside casing, reducing running speed to 2 minutes per stand while in OH. Fill DP every 10 stands. P/U 230k SIO 182k 05:00 - 06:00 1.00 CASE P LNR1 Tag up on bottom at 8915'. PU 2'. Stage up pump to 6 bpm and circulate 2+ OH volumes while reducing YP to 20-25. 6 bpm @ 1000 psi P/U 230k SIO 189k 06:00 - 06:30 0.50 CEMT P LNR1 PJSM with Schlumberger, Veco and all rig personnel on cementing. 06:30 - 06:45 0.25 CEMT P LNR1 Pump 3 bbls water to fill cement lines. Pressure test lines to Printed: 9/13/2004 10: 14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-23 2-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8/30/2004 06:30 - 06:45 0.25 CEMT P LNR1 4500 psi. 06:45 - 07:00 0.25 CEMT P LNR1 Pump 30 bbls 11.6 ppg mud push 15 gallon mud push leak while mixing. 07:00 - 07:25 0.42 CEMT P LNR1 Mix and pump 87 bbls (420 sxs) 15.8 ppg class G cement. 6 bpm @ 900 psi 07:25 - 07:40 0.25 CEMT P LNR1 Release dart and kick out with 10 bbls water to flush cement lines. 07:40 - 08:00 0.33 CEMT P LNR1 Switch to rig pump and displace with mud. Displace at 6 bpm for the first 93 bbls pumped. Rate reduced to 3 bpm to pick up the liner wiper. Rate increased to 6 bpm until 25 bbls prior to bump. Bumped plug on calculated strokes. 08:00 - 08: 15 0.25 CASE P LNR1 Pressure up to 2600 psi to set hanger, hold for 2 minutes. continue pressuring up to 3400 psi to release from hanger. Bleed pressure. Parted hard line attached to cement head while slacking off to verify hanger set, resulted in mud leak. 08:15 - 08:30 0.25 CASE P LNR1 Pick up and set liner top packer. 08:30 - 09:00 0.50 CEMT P LNR1 Circulate excess cement out of the hole. 12 bpm @ 2200 psi Overflowed cuttings box while circulating resulted in 3 bbl recordable spill. 09:00 - 09:30 0.50 CEMT N HMAN LNR1 Clean up 3 bbl mud spill due to overflowed cuttings box. 09:30 - 10:00 0.50 CEMT N HMAN LNR1 Safety stand down with all rig and contractor personnel, Tool Pusher, Drilling Rep and ADW HSE Advisor. 10:00 - 17:00 7.00 CEMT HMAN LNR1 Clean up mud in rig from parted cement line. 17:00 - 20:00 3.00 CEMT LNR1 Slug DP and POH. 20:00 - 20:30 0.50 CEMT LNR1 Break out and LD running tool. Break out cement head. 20:30 - 21 :00 0.50 BOPSU LNR1 PJSM with all rig personnel on changing upper pipe rams, blind rams and pressure testing. 21 :00 - 22:00 1.00 BOPSU LNR1 Install 3-1/2" X 6" VBR's and blind/shear rams in BOP. 22:00 - 22:30 0.50 BOPSU LNR1 Pull wear bushing and install test plug. 22:30 - 00:00 1.50 BOPSU LNR1 Test upper 3-1/2" X 6" VBR's and blind/shear rams to 250/3500 psi. Unable to get 3500 psi test on blind/shear rams 8/31/2004 00:00 - 01 :00 1.00 BOPSU SFAL LNR1 - Change out blind/shear rams. 01 :00 - 01 :30 0.50 BOPSU SFAL LNR1 - Install test plug. test blind/shear rams to 250/3500 psi. Pull test plug and install wear bushing. 01 :30 - 02:00 0.50 BOPSU LNR1 - RD test equipment and clear rig floor. 02:00 - 03:30 1.50 CASE PROD1 - PU 6-1/8" mill tooth assembly. 03:30 - 05:00 1.50 CASE PROD1 - RIH with 4" DP from derrick. 05:00 - 06:00 1.00 CASE PROD1 - RIH picking up 18 joints of 4" DP from pipe shed. 06:00 - 09:00 3.00 CASE PROD1 - CIO to 5" handling equip't. - RIH wI 5" DP to 8624' filling every 20 stds. 09:00 - 09:30 0.50 CASE P PROD1 - R/U test equip't. 09:30 - 10:30 1.00 CASE P PROD1 - Test 9 5/8" x 7" casing to 3500 psi for 30 min. - RID test equip't. 10:30 - 11 :30 1.00 CASE P PROD1 - Wash from 8620' to 8730'. Tag cement stringers @ 8730'. Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 8/31/2004 11 :30 - 12:30 1.00 CEMT P PROD1 - Drill cement from 8730' to 8829'. 12:30 - 15:30 3.00 CEMT P PROD1 - Drill float equip't from 8829' to 8915'. - UC @ 8829', FIe @ 8873', & FIS @ 8813'. 15:30 - 21 :00 5.50 CEMT P PROD1 - Clean pits & take on 8.4 ppg flo-pro mud. - Mix 40 bbl flo-vis spacer for displacement. 21 :00 - 23:00 2.00 CEMT P PROD1 - Displace well to 8.4 ppg flo-pro @ 6 BPM, 1860 psi, 40 RPM & reciprocating. 23:00 - 00:00 1.00 DRILL P PROD1 - Drill 20' new hole from 8915' to 8935'. 9/1/2004 00:00-01:15 1.25 CASE P PROD1 - CBU until MW in = MW out. 01:15 - 02:00 0.75 CEMT P PROD1 - Stand back 1 stand 5" DP. - R/U & perform FIT to 10.0 ppg EMW wI 8.4 ppg. Pressure taken to 725 psi wI 1.7 bbls mud. 02:00 - 08:00 6.00 CEMT P PROD1 - POH from 8935'. UD 9 singles of 5" DP. 08:00 - 08:30 0.50 CASE P PROD1 - Clear & clean floor of tools. - PJSM for P/U BHA. 08:30 - 09:45 1.25 DRILL P PROD1 - M/U BHA # 4. 09:45 - 10:45 1.00 DRILL P PROD1 - Shallow test MWD @ 257 GPM 920 psi. - RIH wI BHA on 4" DP to 2611'. 10:45 - 14:00 3.25 DRILL P PROD1 - RIH from 2611' to 4516' P/U 4" DP singles from pipeshed. - Filling pipe every 25 stands. 14:00 - 15:00 1.00 DRILL P PROD1 - Continue RIH wI 5" DP to 6500' & fill DP. 15:00 - 15:30 0.50 DRILL P PROD1 - Service TD, blocks, drawworks, iron roughneck, & crown. 15:30 - 16:30 1.00 DRILL P PROD1 - Continue RIH wI 5" DP from 6500' to 8195' & fill DP. 16:30 - 17:30 1.00 DRILL P PROD1 - Slip & cut 148' of drilling line. 17:30 - 18:30 1.00 DRILL P PROD1 - RIH from 8195' to 8935' washing last stand down. 18:30 - 00:00 5.50 DRILL P PROD1 - Slide from 8935' to 9027'. Drilling parameters: Wt on bit 5K - 8K, 280 GPM, pump pressure on bottom 1750 psi, off bottom 1550 psi, P/U wt 195K, SIO wt 180K. Calc ECD 8.89, actual ECD 8.95. - At 8985' md - Incl 43.22 deg, AZ 346.67 - Top of Sag formation @ 8918' md. - Top of Shublik @ 8947' md. AST 2.12 hrs, ART 0 hrs, ADT 2.12 hrs. 9/2/2004 00:00 - 00:00 24.00 DRILL P PROD1 - Drill & slide in 6 1/8" hole from 9027' to 9535' - Last survey @ 9453' MD - 8923' TVD, Incl 92.26 dg, AZ 323.27 dg. - Drilling parameters: wt on bit 5K - 13K, PP on bottom 1900 psi - off bottom 1700 psi, Tq 6K on bottom, Tq 4K off bottom @ 50 RPM, P/U wt 205K, SIO wt 188K, Rot wt 192K. Calc ECD 9.01, actual ECD 9.2 AST 9.15 hrs ART 2.42 hrs ADT 11.57 hrs 9/3/2004 00:00 - 01 :30 1.50 DRILL N SFAL PROD1 - Lost power to AnadrilllRCT computer on rig floor when a circuit breaker tripped. Reset breaker & troubleshoot electrical problem wI AnadrilllRCT computer. C/O AnadrilllRCT computer. 01 :30 - 00:00 22.50 DRILL P PROD1 - Drill & slide in 61/8" hole from 9535' to 10220'. Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 913/2004 01 :30 - 00:00 22.50 DRILL P PROD1 - Last survey @ 10171' MD - 8912' TVD, Inc190.07 dg, AZ 250.59 dg. - Drilling parameters: wt on bit 5K - 14K, PP on bottom 1900 psi' off bottom 1700 psi, Tq 6K on bottom, Tq 4K off bottom @ 40 RPM, P/U wt 205K, S/O wt 188K, Rot wt 182K. - Calc ECD 9.2, actual ECD 9.3 AST 9.08 hrs ART 2.25 hrs ADT 11.33 hrs 9/4/2004 00:00 - 13:00 13.00 DRILL P PROD1 - Drill directional in 61/8" hole from 10220' to TD @ 10550' MD. - Drilling parameters: wt on bit 5K - 14K, PP on bottom 1900 psi, off bottom 1700 psi, Tq on bottom 6K, off bottom 4K @ 60 RPM, P/U wt 210K, S/O wt 185K, Rot wt 195K. AST 5.2 hrs ART 1.4 hrs ADT 6.6 hrs 13:00 - 15:30 2.50 DRILL P PROD1 - Pump hi-vis sweep surface to surface & 1 additional BU @ 6.5 BPM 1700 psi. 15:30 - 17:30 2.00 DRILL P PROD1 - Wiper trip back to 7" shoe - backream build section from 9400' to 8915' to knock out any potential ledges. 17:30 - 18:00 0.50 DRILL P PROD1 - RIH from 8915' to 10550. Hole slick. 18:00 - 21 :00 3.00 DRILL P PROD1 - Pump hi-vis weighted sweep surface to surface & 1 additional B/U @ 6.5 BPM 1700 psi rotating @ 60 RPM & reciprocating. 21 :00 - 22:30 1.50 DRILL P PROD1 - Monitor well - POH from 10550' to 8750' wI no overpulls. 22:30 - 00:00 1.50 DRILL P PROD1 - Mad pass from 8750' to 8900' @ 300 FPH wI 6 BPM 1400 psi. 9/5/2004 00:00 - 01 :00 1.00 DRILL P PROD1 - Mad pass from 8900' to 9020' @ 300 FPM, 6 BPM 1400 psi. - Monitor well - static. 01 :00 - 02:30 1.50 DRILL P PROD1 - POH from 9020' to 6749'. Circ sub @ 7" liner top @ 6564'. 02:30 - 03:30 1.00 DRILL P PROD1 - Drop dart & shear open circ sub wI 2400 psi. - Circulate @ 10 BPM 920 psi for 15 min. - Rack back 2 stds DP & continue circulate until shakers cleaned up @ 10 BPM 920 psi, rotating 100 RPM & reciprocating. 03:30 - 04:00 0.50 DRILL P PROD1 - Monitor well - Pump dry job - drop rabbit. 04:00 - 08:30 4.50 DRILL P PROD1 - POH from 6550' to 216' wI 4" & 5" DP. - UD 60 jts 4" DP 1 x 1. 08:30 - 10:00 1.50 DRILL P PROD1 - UD BHA & clear floor. 10:00 - 11 :00 1.00 BOPSU P PROD1 - Pull bowl protector, install test plug, & R/U test equip't. 11 :00 - 15:00 4.00 BOPSU P PROD1 - Test BOPE per BP & AOGCC regs. to 250 psi I 3500 psi. Test witnessed by AOGCC Rep John Spaulding. 15:00 - 15:30 0.50 BOPSU PROD1 - Pull test plug - install bowl protector. 15:30 - 16:30 1.00 BOPSU PROD1 - RID test equip't - BID choke & kill lines. 16:30 - 18:00 1.50 CASE RUNPRD - Clear floor & RlU liner running equip't. 18:00 - 18:30 0.50 CASE RUNPRD - PJSM for running 4 1/2" liner. 18:30 - 21 :30 3.00 CASE RUNPRD - Run 42 jts 12.6# L-80 IBT-M liner. Avg M/U Tq - 4000 ftllbs Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-23 Z-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 915/2004 21 :30·22:30 1.00 CASE P RUNPRD - M/U liner hanger I packer. - Pour "pal mix" inside hanger & allow to set for 30 min. · RID tubing handling equip't & CIO elevators. 22:30 - 23:00 0.50 CASE P RUNPRD - Circulate liner volume @ 5 BPM 340 psi. - P/U wt 60K, SIO wt 60K. 23:00 - 00:00 1.00 CASE P RUNPRD - RIH wi 41/2" liner on 4" DP filling every 10 stands. 9/6/2004 00:00 - 04:30 4.50 CASE P RUNPRD · RIH wi 4 1/2" liner on 4" & 5" DP to 7" shoe. 04:30 . 05:30 1.00 CASE P RUNPRD - Circulate liner & DP volume @ 7" shoe. - M/U pup jts on TD head. 05:30 - 06:30 1.00 CASE P RUNPRD - Continue RIH wi liner in OH to 10500'. 06:30 . 07:00 0.50 CASE P RUNPRD · MU plug dropping head & lines. Cont RIH & tag bottom at 10550'. PU to put shoe at 10548'. 07:00 - 07:45 0.75 CEMT P RUNPRD - Break circ and stage pumps up to 6.5 bpm at 1320 psi with pipe reciprocation. 07:45 - 08:00 0.25 CEMT P RUNPRD PJSM with all service companies· Doyon, Baker, Veco, MI. 08:00 - 08:45 0.75 CEMT P RUNPRD - Cont circ 6.5 bpm @ 1330 psi while cementers batch mix cement. 215 klbs up. 185 klbs dn. 08:45 - 09:15 0.50 CEMT P RUNPRD - Switch to cementers. Pump 2 bbl water. Test lines to 4500 psi. Chg leaking valve on cement hose. Re-test . OK. 09:15 - 09:30 0.25 CEMT P RUNPRD · Pump 15 bbl CW 100 followed by 25 bbls Mudpush " @ 9.6 ppg. Pump 50 bbls (185 sx) 15.8 ppg GasBlock slurry. 5 bpm @ 400 psi final pressure. 09:30 . 10:00 0.50 CEMT P RUNPRD · Flush cement line with water down a wash up line. Release drillpipe dart and pump 25 bbls perf pill followed by 2 bbls water from cementers. Switch to rig pumps and displace cement with an additional 108 bbl mud until PU liner wiper plug. Shear wiper plug and continue displacement with 134 bbls mud total. Bump plug on landing collar. Reciprocated pipe until cement rounded corner· then started getting sticky. Park pipe with shoe at 10548'. CIP at 10:00 hrs. 10:00 - 10:20 0.33 CEMT P RUNPRD - Pressure up to 2800 psi to set liner hanger. Slack off to 125 klbs string wt. Continue pressure up to 3500 psi to release from liner hanger. PU to verify released· NO GO. Re-pressure to 4000 psi. Hold pressure then bleed off to zero. PU and verify released - OK. Continue PU 5'. 10:20 - 10:30 0.17 CEMT P RUNPRD · Rotate DP at 30 rpm and slack off 60 klbs pipe weight to set liner top packer. Repeat to ensure set. 10:30 - 11 :30 1.00 CEMT P RUNPRD - Circulate at 11 bpm with pipe rotation to clear excess cement from annulus. Got back approx 10-15 bbls cmt and also cement contaminated mud. Divert to cuttings tank and slow to 8 bpm so as not to overload dump line. 11 :30 - 12:00 0.50 CEMT P RUNPRD - BIO & UD cement head. 12:00 - 16:00 4.00 CEMT P RUNPRD - Clean pits. 16:00 - 17:30 1.50 CEMT P RUNPRD - Take on 8/W in pits. - Build 40 bbl viscosified spacer. 17:30 - 19:30 2.00 CEMT P RUNPRD - Pump 40 bbl viscosified spacer & displace well to clean S/W @ 10.5 BPM 1100 psi @ 15 RPM & reciprocating. 19:30 - 22:30 3.00 CEMT P RUNPRD - Monitor well· static - POH wi 5" DP - UD 1 stand. Washout on face of box on one jt. Printed: 9/13/2004 10:14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-23 2-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: 916/2004 22:30 - 00:00 1.50 CEMT P RUNPRD - CIO to 4" handling equip't. - POH wI 25 stands 4" DP. - UD liner hanger running tool. Dog sub sheared. 9/7/2004 00:00 - 00:30 0.50 CASE P RUNPRD - Clear rig floor of tools & R/U for casing test. 00:30 - 01 :00 0.50 CASE P RUNPRD - Pressure test 9 5/8" casing x 4 1/2" liner to 3500 psi. Chart & hold for 30 minutes. 01 :00 - 01 :30 0.50 CASE P RUNPRD - RID equip't & BID lines. 01 :30 - 03:30 2.00 CASE P RUNPRD - PJSM - R/U & run 17 21/2" perf guns. (4 spf) 03:30 - 05:30 2.00 CASE P RUNPRD - P/U 35 jts PAC DP & RIH wI perf guns. 05:30 - 10:00 4.50 CASE P RUNPRD - C/O to 4" handling equip't & RIH wI 25 stds 4" DP. - CIO to 5" handling equip't & RIH wI 5" DP to 10445'. - Space out & tag top of UC @ 10461'. 10:00 - 11 :30 1.50 CASE P PROD1 - PJSM - - Close annular preventer & pressure up on annulus to 2700 psi. Hold for 2 minutes & bleed off pressure. - Await verification of perf guns fired for 30 min. 11 :30 - 12:00 0.50 CASE P PROD1 - POH w/8 stands above top perfs. 12:00 - 13:30 1.50 CASE P PROD1 - CBU @ 6.3 BPM 1300 psi. - BID choke & kill lines. 13:30 - 14:00 0.50 CASE P PROD1 - Monitor well for 10 min - no flow - no losses. - Pump dry job & BID TD. 14:00 - 20:30 6.50 CASE P PROD1 - POH wI 5" DP & UD 1 x 1 monitoring well every 20 stands. Well taking .5 to 1 bbl every 5 stands pulled. Hole static wI no pipe movement. - RIH wI 10 stands 5" DP from derrick - POH & UD 1 x 1. 20:30 - 23:00 2.50 CASE P PROD1 - C/O to 4" handling equip't & POH wI 25 stands 4" DP. UD 1 x 1. - Monitor well - static. 23:00 - 00:00 1.00 CASE P PROD1 - C/O to 2 7/8" handling equip't & POH w/2 7/8" DP. UD 1 x 1. 9/8/2004 00:00 - 01 :00 1.00 CASE P PROD1 - POH w/2 7/8" PAC DP & UD 1 x 1. 01 :00 - 01 :30 0.50 CASE P PROD1 - PJSM - POH wI perf guns. - Monitor well - static. 01 :30 - 04:00 2.50 CASE P PROD1 - POH & UD 21/2" perf guns. - All loaded guns fired ( 4 spf ) - Perf intervals - 9745' to 10160', 10224' to 10254', 10292' to 10390' , 10400' to 10436', & 10454' to 10460'. 04:00 - 05:00 1.00 CASE P PROD1 - P/U test jt & pull bowl protector. - Clear rig floor. 05:00 - 06:30 1.50 RUNCO RUNCMP - RlU to run 4 1/2" Vam Top completion. 06:30 - 22:00 15.50 RUNCO RUNCMP - Run WLEG, XN nipple assy. lower X nipple assy, S-3 packer, upper X nipple assy & 205 jts 41/2" 12.6# 13CR80 Vam Top tubing. 6 GLM's per program & X nipple assy @ -2200'.- - All connections below packer Bakerlocked. P/U all jts wI compensator & utilize Torque Turn for connections. M/U Tq 4500 ft/lbs. 22:00 - 23:30 1.50 RUNCO RUNCMP - RID compensator & M/U circ head & hose. - RIH & tagged up 8' in on jt - P/U 20' & wash down @ 5 BPM 440 psi. Pressure increase to 530 psi inside tie back sleeve. Rotate string 3/4 turn & repeat sequence to confirm tag up. Printed: 9/13/2004 10: 14:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-23 2-23 REENTER+COMPLETE DOYON DOYON 16 Start: 8/18/2004 Rig Release: Rig Number: Spud Date: 6/7/1989 End: - RID circ head & hose. UD pup jt & 2 full jts. - M/U space out pups, 1 full jt, hanger pup jt, tubing hanger, & landing jt. Land tubing hanger & RILDS. 02:00 - 04:30 RUNCMP - PJSM - - Pump 190 bbls S/W down IA @ 3 BPM 220 psi followed by 200 bbls S/W treated wI corrosion inhibitor. RUNCMP - Drop 1 7/8" ball & rod. - Pressure up to 3500 psi on tubing to set packer - hold & chart for 30 min. - Bleed tubing pressure to 1500 psi. Pressure up on annulus to 3500 psi - hold & chart for 30 min. RUNCMP - Bleed tubing pressure & shear DCK valve. Bleed off all pressures. - Pump down tubing, then annulus to ensure DCK valve fully sheared. 3 BPM 200 psi. - RID circ head & lines. - BIO & UD landing jt. - Set TWC & test from below to 1000 psi. - PJSM - N/D BOPE - FMC Rep chased & redressed threads on gland nuts & LOS on tubing spool. - N/U adaptor flange & tree. Test neck seals on hanger & tree to 5000 psi. - R/U Drill Site Maint. & pull TWC. - PJSM - RlU Little Red - Test lines to 3000 psi. - Pump 160 bbls diesel in IA @ 2.5 BPM 900 psi. - Allow diesel to U-tube. - Prepare rig for move. - Install BPV, VR plugs in IA annulus valves & secure well. - Release rig @ 20:00 hrs. 04:30 - 06:00 06:00 - 06:30 06:30 - 07:00 RUNCMP 07:00 - 09:30 RUNCMP 09:30 - 13:00 RUNCMP 13:00 - 15:00 2.00 WHSUR P RUNCMP 15:00 - 15:30 0.50 WHSUR P RUNCMP 15:30 - 17:30 2.00 WHSUR P RUNCMP 17:30 - 19:00 1.50 WHSUR P RUNCMP 19:00 - 20:00 1.00 WHSUR P RUNCMP Printed: 9/13/2004 10: 14:51 AM Printed: 9/13/2004 10: 14:45 AM Ö Schlumberger .{;þ. Z-23B Survey Report Report Date: 8-Sep-04 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 356.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Z-PAD I Z-23 TVD Reference Datum: Rotary Table Well: Z-23 TVD Reference Elevation: 81.06 ft relative to MSL Borehole: Z-23B Sea Bed 1 Ground Level Elevation: 54.04 ft relative to MSL UWI/API#: 500292195002 Magnetic Declination: 24.829° Survey Name 1 Date: Z-23B 1 September 8, 2004 Total Field Strength: 57589.391 nT Tort 1 AHD 1 DDII ERD ratio: 277.021° 12663.03 ft 15.9341 0.294 Magnetic Dip: 80.785° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 01, 2004 Location LatlLong: N 70.29840007, W 149.19453702 Magnetic Declination Model: BGGM 2004 . Location Grid N/E YIX: N 5959360.030 ftUS, E 599459.070 ftUS North Reference: True North Grid Convergence Angle: -+{).75831778° Total Corr Mag North .> True North: +24.829° Grid Scale Factor: 0.99991124 Local Coordinates Referenced To: Well Head Comments Inclination Azimuth TVD Sub·Sea TVD Closure NS EW DLS Northing Easting Latitude Longitude Surface Tie In N 70.29840007 W 149.19453702 GYD - GC - MS N 70.29840007 W 149.19453702 N 70.29839987 W 149.19453788 N 70.29839956 W 149.19454027 N 70.29839907 W 149.19454212 400.02 0.23 229.48 400.02 318.96 -0.58 1.10 1.04 -0.64 -0.82 0.13 5959359.38 599458.26 N 70.29839832 W 149.19454368 500.02 0.37 218.67 500.02 418.96 -0.94 1.62 1.56 -1.02 -1.18 0.15 5959358.99 599457.91 N 70.29839728 W 149.19454655 600.02 0.15 141.82 600.02 518.96 -1.28 2.02 1.89 -1.38 -1.30 0.37 5959358.63 599457.79 N 70.29839631 W 149.19454753 700.02 0.41 180.59 700.01 618.95 -1.75 2.49 2.21 -1.84 -1.22 0.31 5959358.18 599457.87 N 70.29839505 W 149.19454690 800.02 0.27 129.09 800.01 718.95 -2.27 3.05 2.57 -2.35 -1.04 0.32 5959357.67 599458.06 N 70.29839367 W 149.19454545 900.02 0.19 130.05 900.01 818.95 -2.54 3.45 2.70 -2.60 -0.73 0.08 5959357.42 599458.37 N 70.29839297 W 149.1.4 1000.02 0.39 179.02 1000.01 918.95 -3.00 3.93 3.11 -3.05 -0.60 0.30 5959356.98 599458.51 N 70.29839175 W 149.1 7 1100.02 0.45 165.72 1100.01 1018.95 -3.72 4.66 3.80 -3.77 -0.50 0.11 5959356.26 599458.62 N 70.29838978 W 149.1 04 1200.02 0.39 171.06 1200.01 1118.95 -4.45 5.39 4.50 -4.49 -0.35 0.07 5959355.54 599458.78 N 70.29838782 W 149.19453982 1300.02 0.48 148.45 1300.00 1218.94 -5.16 6.14 5.18 -5.18 -0.07 0.19 5959354.85 599459.06 N 70.29838593 W 149.19453762 1400.02 0.50 101.37 1400.00 1318.94 -5.65 6.95 5.65 -5.62 0.57 0.39 5959354.42 599459.72 N 70.29838472 W 149.19453238 1500.02 0.73 100.25 1499.99 1418.93 -5.92 8.02 6.04 -5.82 1.63 0.23 5959354.23 599460.77 N 70.29838417 W 149.19452384 1600.02 0.93 90.77 1599.98 1518.92 -6.14 9.47 6.69 -5.94 3.07 0.24 5959354.13 599462.21 N 70.29838383 W 149.19451220 1700.02 1.32 83.32 1699.96 1618.90 -6.16 11.43 7.69 -5.82 5.02 0.42 5959354.28 599464.17 N 70.29838417 W 149.19449636 1800.02 1.08 82.75 1799.94 1718.88 -6.05 13.52 9.02 -5.57 7.10 0.24 5959354.56 599466.24 N 70.29838486 W 149.19447953 1900.02 1.11 81.55 1899.92 1818.86 -5.92 15.43 10.44 -5.31 8.99 0.04 5959354.84 599468.13 N 70.29838557 W 149.19446420 2000.02 1.17 88.42 1999.90 1918.84 -5.89 17.42 12.11 -5.14 10.97 0.15 5959355.04 599470.11 N 70.29838604 W 149.19444818 2100.02 1.14 81.85 2099.88 2018.82 -5.86 19.43 13.90 -4.97 12.98 0.14 5959355.23 599472.11 N 70.29838650 W 149.19443194 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Z-231Z-231Z-23BIZ-23B Generated 9/17/2004 11 :20 AM Page 1 of 5 Comments Latitude Longitude N 70.29838704 W 149.19441635 N 70.29838708 W 149.19440217 2400.02 0.74 118.35 2399.84 2318.78 -6.35 24.55 18.74 -5.11 18.03 0.41 5959355.16 599477.17 N 70.29838612 W 149.19439101 2500.02 0.77 108.48 2499.83 2418.77 -6.96 25.87 20.04 -5.63 19.24 0.13 5959354.66 599478.38 N 70.29838470 W 149.19438125 2600.02 0.76 139.30 2599.82 2518.76 -7.75 27.17 21.28 -6.34 20.31 0.41 5959353.96 599479.46 N 70.29838274 W 149.19437258 2700.02 0.60 132.62 2699.82 2618.76 -8.66 28.36 22.32 -7.20 21.12 0.18 5959353.11 599480.29 N 70.29838040 W 149.19436596 2800.02 0.51 170.4 7 2799.81 2718.75 -9.48 29.29 23.02 -7.99 21.58 0.37 5959352.32 599480.76 N 70.29837823 W 149.19436225 2900.02 0.52 170.41 2899.81 2818.75 -10.38 30.19 23.48 -8.88 21.73 0.01 5959351.44 599480.92 N 70.29837581 W 149.19436104 3000.02 0.33 192.45 2999.80 2918.74 -11.10 30.92 23.78 -9.61 21.75 0.25 5959350.71 599480.94 N 70.29837382 W 149.19436093 3100.02 0.60 195.69 3099.80 3018.74 -11.87 31.74 23.92 -10.40 21.54 0.27 5959349.92 599480.75 N 70.29837167 W 149.19436258 3200.02 0.19 208.80 3199.80 3118.74 -12.51 32.42 24.01 -11.04 21.32 0.42 5959349.27 599480.53 N 70.29836990 W 149.19436437 3300.02 0.20 217.65 3299.80 3218.74 -12.77 32.76 23.98 -11.33 21.14 0.03 5959348.98 599480.35 N 70.29836913 W 149.1.8 3400.02 0.37 137.91 3399.80 3318.74 -13.16 33.19 24.26 -11.71 21.24 0.39 5959348.61 599480.47 N 70.29836809 W 149.19436499 3500.02 0.37 135.80 3499.79 3418.73 -13.66 33.84 24.87 -12.18 21.69 0.01 5959348.14 599480.91 N 70.29836681 W 149.19436142 3600.02 1.74 337.73 3599.78 3518.72 -12.46 35.18 24.01 -11.00 21.34 2.09 5959349.31 599480.55 N 70.29837001 W 149.19436425 3700.02 4.12 326.92 3699.64 3618.58 -7.88 40.28 19.92 -6.59 18.80 2.43 5959353.69 599477.95 N 70.29838208 W 149.19438479 3800.02 4.68 325.94 3799.35 3718.29 -1.21 47.95 14.56 -0.20 14.55 0.57 5959360.02 599473.62 N 70.29839953 W 149.19441917 3900.02 3.88 328.20 3899.07 3818.01 5.31 55.41 12.11 6.06 10.49 0.82 5959366.22 599469.47 N70.29841662 W149.19445211 4000.02 2.26 325.90 3998.92 3917.86 10.01 60.77 13.01 10.57 7.60 1.62 5959370.69 599466.53 N 70.29842894 W 149.19447550 4100.02 1.69 319.00 4098.86 4017.80 12.89 64.21 14.41 13.31 5.53 0.62 5959373.41 599464.42 N 70.29843644 W 149.19449228 4200.02 1.55 288.59 4198.82 4117.76 14.59 66.97 15.21 14.86 3.28 0.86 5959374.93 599462.15 N 70.29844066 W 149.19451049 4300.02 2.15 268.22 4298.77 4217.71 15.18 70.17 15.23 15.23 0.12 0.88 5959375.26 599458.99 N 70.29844168 W 149.19453606 4400.02 2.02 255.22 4398.71 4317.65 14.93 73.79 15.12 14.72 -3.46 0.49 5959374.70 599455.42 N 70.29844029 W 149.19456504 4500.02 1.62 262.96 4498.66 4417.60 14.52 76.96 15.55 14.10 -6.57 0.47 5959374.04 599452.32 N 70.29843859 W 149.19459020 4600.02 1.35 271.58 4598.62 4517.56 14.56 79.55 16.69 13.96 -9.15 0.35 5959373.86 599449.74 N 70.29843820 W 149.19461109 4700.02 1.07 257.81 4698.60 4617.54 14.54 81.65 17.79 13.79 -11.24 0.40 5959373.67 599447.65 N 70.29843775 W 149.19462802 4800.02 0.93 241.19 4798.59 4717.53 14.07 83.38 18.43 13.20 -12.86 0.32 5959373.06 599446.04 N 70.29843614 W 149.19464116 4900.02 0.80 231.62 4898.57 4817.51 13.33 84.89 18.78 12.38 -14.12 0.19 5959372.22 599444.79 N 70.29843389 W 149.19465135 5000.02 0.86 244.05 4998.56 4917.50 12.66 86.33 19.24 11.62 -15.34 0.19 5959371.44 599443.58 N 70.29843181 W 149.1.5 5100.02 0.76 250.22 5098.55 5017.49 12.20 87.74 19.98 11.06 -16.64 0.13 5959370.87 599442.29 N 70.29843030 W 149.1 7 5200.02 0.58 247.76 5198.55 5117.49 11.86 88.91 20.68 10.65 -17.73 0.18 5959370.44 599441.20 N 70.29842916 W 149.19 061 5300.02 0.67 249.45 5298.54 5217.48 11.53 90.00 21.37 10.25 -18.75 0.09 5959370.03 599440.19 N 70.29842808 W 149.19468884 5400.02 0.75 248.17 5398.53 5317.47 11.17 91.24 22.19 9.80 -19.90 0.08 5959369.57 599439.04 N 70.29842685 W 149.19469819 5500.02 0.96 225.79 5498.52 5417.46 10.43 92.72 22.94 8.98 -21.11 0.39 5959368.72 599437.84 N 70.29842459 W 149.19470797 5600.02 0.78 229.82 5598.51 5517.45 9.48 94.23 23.61 7.95 -22.23 0.19 5959367.69 599436.74 N 70.29842180 W 149.19471705 5700.02 0.86 242.20 5698.50 5617.44 8.78 95.66 24.49 7.16 -23.42 0.19 5959366.88 599435.56 N 70.29841964 W 149.19472663 5800.02 0.72 250.51 5798.49 5717.43 8.31 97.04 25.54 6.60 -24.67 0.18 5959366.31 599434.31 N 70.29841811 W 149.19473681 5900.02 2.85 9.02 5898.45 5817.39 10.56 99.51 26.40 8.85 -24.88 3.26 5959368.55 599434.08 N 70.29842425 W 149.19473845 6000.02 5.24 19.05 5998.20 5917.14 17.19 106.55 27.80 15.62 -22.99 2.48 5959375.35 599435.87 N 70.29844275 W 149.19472322 6100.02 7.44 22.77 6097.58 6016.52 27.17 117.59 32.13 25.91 -19.00 2.24 5959385.68 599439.73 N 70.29847086 W 149.19469086 6200.02 9.42 19.55 6196.50 6115.44 40.46 132.24 41.91 39.59 -13.75 2.03 5959399.43 599444.80 N 70.29850824 W 149.19464839 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 81d( do31 rt-546 ) Z -231Z-231Z -2381Z-238 Generated 9/1712004 11 :20 AM Page 2 of 5 Comments Inclination Azimuth TVO Sub·Sea TVO Closure NS EW OLS Northing Easting Latitude Longitude N 70.29855427 W 149.19459938 6400.02 12.93 21.54 6392.66 6311.60 75.83 171.06 75.99 75.99 -0.28 1.75 5959436.00 599457.78 N 70.29860767 W 149.19453928 6500.02 14.70 25.35 6489.77 6408.71 96.98 194.93 98.30 97.87 9.26 1.99 5959458.00 599467.03 N 70.29866743 W 149.19446202 GYD - GC - MS 6600.02 16.19 26.97 6586.15 6505.09 120.00 221.56 123.56 121.76 21.02 1.55 5959482.04 599478.47 N 70.29873271 W 149.19436683 Tie-In Survey 6700.02 18.08 28.71 6681.71 6600.65 145.01 251.02 151.84 147.80 34.80 0.76 5959508.26 599491.90 N 70.29880384 W 149.19425526 Top Window (Blind) 6718.00 18.74 28.80 6698.77 6617.71 149.78 256.69 157.32 152.77 37.53 3.67 5959513.27 599494.57 N 70.29881744 W 149.19423314 Base Window (Blind) 6734.00 20.10 24.71 6713.86 6632.80 154.36 262.01 162.50 157.52 39.91 12.02 5959518.05 599496.89 N 70.29883042 W 149.19421381 (Blind) 6748.00 20.10 24.71 6727.01 6645.95 158.58 266.82 167.24 161.89 41.93 0.00 5959522.45 599498.85 N 70.29884236 W 149.19419752 First MWD+IFR+MS 6809.92 22.39 14.05 6784.74 6703.68 179.13 289.20 189.52 183.01 49.24 7.24 5959543.66 599505.88 N 70.29890004 W 149.19413829 6905.74 25.03 12.80 6872.46 6791.40 215.89 327.73 228.03 220.49 58.16 2.80 5959581.25 599514.30 N 70.29900243 W 149.19406604 7001.11 24.90 2.42 6958.96 6877.90 255.18 367.89 267.87 260.24 63.48 4.59 5959621.06 599519.10 N 70.29911103 W 149.1~.5 7095.11 25.06 352.30 7044.21 6963.15 294.73 407.50 306.03 299.76 61.65 4.54 5959660.55 599516.74 N 70.29921899 W 149.19 9 7185.50 23.33 347.62 7126.66 7045.60 331.54 444.53 340.73 336.22 55.25 2.86 5959696.92 599509.86 N 70.29931859 W 149.19408964 7280.04 22.07 344.11 7213.88 7132.82 367.45 481.00 374.47 371.59 46.37 1.96 5959732.16 599500.51 N 70.29941522 W 149.19416152 7373.61 21.59 344.05 7300.74 7219.68 401.49 515.80 406.72 405.05 36.83 0.51 5959765.49 599490.53 N 70.29950663 W 149.19423881 7466.08 21.10 344.68 7386.87 7305.81 434.46 549.45 438.34 437.46 27.75 0.59 5959797.78 599481.03 N 70.29959517 W 149.19431227 7561.90 22.96 345.89 7475.69 7394.63 469.77 585.39 472.59 472.22 18.64 2.00 5959832.41 599471.46 N 70.29969014 W 149.19438608 7653.80 22.75 345.60 7560.38 7479.32 504.89 621.09 506.91 506.82 9.85 0.26 5959866.89 599462.21 N 70.29978465 W 149.19445725 7749.78 22.55 345.65 7648.95 7567.89 541.25 658.05 542.62 542.62 0.67 0.21 5959902.56 599452.56 N 70.29988247 W 149.19453156 7840.56 23.78 342.19 7732.42 7651.36 576.15 693.75 576.99 576.91 -9.24 2.02 5959936.72 599442.20 N 70.29997615 W 149.19461183 7933.11 23.78 342.55 7817.11 7736.05 612.42 731.07 612.82 612.48 -20.54 0.16 5959972.13 599430.43 N 70.30007332 W 149.19470336 8029.57 22.52 341.35 7905.80 7824.74 649.21 768.99 649.34 648.53 -32.28 1.39 5960008.02 599418.21 N 70.30017182 W 149.19479843 8126.87 22.31 341.28 7995.75 7914.69 685.10 806.09 685.11 683.68 -44.17 0.22 5960043.00 599405.86 N 70.30026784 W 149.19489469 8224.65 21.93 341.08 8086.33 8005.27 720.69 842.91 720.71 718.53 -56.04 0.40 5960077.69 599393.53 N 70.30036304 W 149.19499087 8320.16 21.26 340.91 8175.14 8094.08 754.64 878.06 754.79 751.77 -67.49 0.70 5960110.77 599381.64 N 70.30045384 W 149.19508357 8405.39 20.98 342.97 8254.64 8173.58 784.43 908.77 784.75 780.96 -77.01 0.93 5960139.83 599371.74 N 70.30053359 W 149.19516069 8502.06 21.96 344.82 8344.61 8263.55 819.02 944.15 819.56 814.95 -86.81 1.23 5960173.69 599361.49 N 70.30062646 W 149.19524007 8596.05 22.96 344.95 8431.46 8350.40 854.26 980.05 855.04 849.62 -96.18 1.07 5960208.22 599351.67 N 70.30072116 W 149.19531589 8690.49 26.63 345.46 8517.18 8436.12 893.16 1019.65 894.24 887.91 -106.28 3.89 5960246.37 599341.06 N 70.30082576 W 149.1.r 8784.16 30.86 344.79 8599.29 8518.23 937.38 1064.69 938.85 931.43 -117.86 4.53 5960289.73 599328.91 N 70.30094466 W 149.1 6 8849.33 33.97 343.37 8654.30 8573.24 971.55 1099.62 973.39 965.01 -127.45 4.91 5960323.18 599318.87 N 70.30103641 W 149.19 919 8923.61 34.87 344.05 8715.58 8634.52 1012.58 1141.60 1014.91 1005.31 -139.23 1.32 5960363.32 599306.56 N 70.30114651 W 149.19566455 8954.57 39.13 344.30 8740.30 8659.24 1030.81 1160.23 1033.36 1023.24 -144.31 13.77 5960381.17 599301.25 N 70.30119547 W 149.19570568 8985.11 43.40 344.54 8763.25 8682.19 1050.54 1180.37 1053.33 1042.63 -149.71 13.99 5960400.50 599295.59 N 70.30124846 W 149.19574947 9017.29 47.60 346.11 8785.80 8704.74 1073.09 1203.32 1076.13 1064.83 -155.51 13.51 5960422.62 599289.49 N 70.30130911 W 149.19579646 9047.03 48.27 345.35 8805.72 8724.66 1094.81 1225.39 1098.09 1086.23 -160.96 2.95 5960443.94 599283.77 N 70.30136757 W 149.19584055 9078.35 49.18 342.64 8826.39 8745.33 1117.83 1248.93 1121.42 1108.85 -167.45 7.12 5960466.47 599276.98 N 70.30142936 W 149.19589313 9110.77 53.62 339.92 8846.61 8765.55 1142.32 1274.26 1146.36 1132.83 -175.60 15.18 5960490.34 599268.51 N 70.30149488 W 149.19595911 9141.88 58.29 338.69 8864.02 8782.96 1167.00 1300.03 1171.59 1156.94 -184.71 15.36 5960514.32 599259.08 N 70.30156073 W 149.19603292 9172.00 62.41 333.74 8878.93 8797.87 1191.61 1326.20 1196.90 1180.86 -195.28 19.77 5960538.10 599248.20 N 70.30162609 W 149.19611854 9205.78 66.53 331.48 8893.48 8812.42 1219.57 1356.67 1225.92 1207.91 -209.31 13.61 5960564.96 599233.81 N 70.30170000 W 149.19623215 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Z-231Z -231Z -23BIZ -23B Generated 9/17/2004 11 :20 AM Page 3 of 5 Comments Latitude Longitude 9235.75 70.17 330.51 8904.54 8823.48 1244.81 1384.52 1252.25 1232.27 -222.82 12.51 5960589.13 599219.99 N 70.30176653 W 149.19634155 9263.64 73.99 328.98 8913.12 8832.06 1268.60 1411.05 1277.21 1255.19 -236.19 14.66 5960611.87 599206.31 N 70.30182913 W 149.19644984 9295.00 79.26 327.89 8920.37 8839.31 1295.64 1441.55 1305.75 1281.17 -252.15 17.14 5960637.64 599190.01 N 70.30190012 W 149.19657916 9327.66 84.73 329.01 8924.92 8843.86 1324.30 1473.88 1336.10 1308.72 -269.07 17.09 5960664.96 599172.73 N 70.30197539 W 149.19671616 9356.47 89.23 326.72 8926.44 8845.38 1349.66 1502.64 1363.07 1333.08 -284.37 17.52 5960689.10 599157.11 N 70.30204192 W 149.19684007 9391.69 91.01 327.50 8926.36 8845.30 1380.50 1537.86 1396.04 1362.65 -303.49 5.52 5960718.42 599137.60 N 70.30212271 W 149.19699497 9422.77 91.68 326.20 8925.63 8844.57 1407.64 1568.93 1425.16 1388.66 -320.48 4.70 5960744.20 599120.27 N 70.30219377 W 149.19713257 9453.57 92.22 322.99 8924.58 8843.52 1433.91 1599.72 1453.67 1413.75 -338.31 10.56 5960769.05 599102.11 N 70.30226231 W 149.19727700 9482.46 91.44 317.00 8923.66 8842.60 1457.25 1628.59 1479.54 1435.86 -356.87 20.90 5960790.91 599083.26 N 70.30232270 W 149.19742728 9514.10 91.07 313.66 8922.97 8841.91 1481.24 1660.22 1506.82 1458.35 -379.10 10.62 5960813.10 599060.74 N 70.30238414 W 149.19760736 9545.52 90.44 307.93 8922.55 8841.49 1503.37 1691.64 1532.76 1478.87 -402.88 18.35 5960833.30 599036.69 N 70.30244019 W 149.1~.2 9579.31 90.43 303.29 8922.30 8841.24 1524.90 1725.43 1559.10 1498.54 -430.34 13.73 5960852.60 599008.98 N 70.30249392 W 149.19 5 9610.71 91.17 300.68 8921.86 8840.80 1543.35 1756.83 1582.58 1515.17 -456.97 8.64 5960868.88 598982.13 N 70.30253935 W 149.19823802 9643.37 92.16 296.70 8920.91 8839.85 1560.98 1789.47 1606.01 1530.83 -485.60 12.55 5960884.17 598953.30 N 70.30258215 W 149.19846993 9673.96 92.69 291.94 8919.61 8838.55 1575.47 1820.03 1626.58 1543.42 -513.44 15.64 5960896.38 598925.29 N 70.30261652 W 149.19869543 9705.12 92.75 288.17 8918.13 8837.07 1588.16 1851.16 1646.11 1554.09 -542.68 12.09 5960906.66 598895.93 N 70.30264567 W 149.19893219 9735.35 91.14 283.64 8917.11 8836.05 1598.44 1881.37 1663.69 1562.37 -571.72 15.90 5960914.55 598866.77 N 70.30266828 W 149.19916745 9769.38 91.93 278.85 8916.20 8835.14 1607.38 1915.39 1681.63 1569.00 -605.08 14.26 5960920.74 598833.34 N 70.30268639 W 149.19943760 9798.57 93.18 276.82 8914.89 8833.83 1613.36 1944.55 1695.92 1572.97 -633.96 8.16 5960924.33 598804.40 N 70.30269724 W 149.19967156 9828.21 89.70 275.92 8914.15 8833.09 1618.70 1974.17 1710.18 1576.26 -663.41 12.13 5960927.23 598774.92 N 70.30270621 W 149.19991002 9863.81 89.64 270.14 8914.35 8833.29 1623.05 2009.77 1725.99 1578.14 -698.94 16.24 5960928.64 598739.37 N 70.30271134 W 149.20019782 9891.69 90.71 265.43 8914.27 8833.21 1623.92 2037.65 1736.48 1577.06 -726.79 17.32 5960927.19 598711.54 N 70.30270839 W 149.20042339 9920.82 92.10 261.34 8913.56 8832.50 1622.59 2066.77 1745.76 1573.71 -755.71 14.82 5960923.46 598682.67 N 70.30269922 W 149.20065762 9955.36 91.99 256.65 8912.32 8831.26 1618.38 2101.29 1754.80 1567.12 -789.59 13.57 5960916.42 598648.89 N 70.30268122 W 149.20093196 9986.70 89.52 258.24 8911.91 8830.85 1613.72 2132.63 1762.74 1560.31 -820.17 9.37 5960909.21 598618.40 N 70.30266260 W 149.20117966 10014.09 88.79 253.70 8912.31 8831.25 1608.95 2160.01 1769.42 1553.67 -846.73 16.79 5960902.22 598591.93 N 70.30264446 W 149.20139478 10048.67 88.21 252.11 8913.22 8832.16 1601.12 2194.58 1776.64 1543.51 -879.77 4.89 5960891.63 598559.03 N 70.30261669 W 149.20166237 10079.66 88.96 250.07 8913.98 8832.92 1593.15 2225.56 1782.69 1533.4 7 -909.08 7.01 5960881.20 598529.86 N 70.30258925 W 149.20189972 10108.21 90.97 251.76 8914.00 8832.94 1585.72 2254.11 1788.63 1524.14 -936.06 9.20 5960871.51 598503.01 N 70.30256374 W 149.2.0 10141.50 90.86 250.88 8913.47 8832.41 1577.29 2287.40 1796.34 1513.48 -967.59 2.66 5960860.43 598471.62 N 70.30253461 W 149.2 7 10171.18 90.06 251.25 8913.23 8832.17 1569.64 2317.07 1803.58 1503.85 -995.66 2.97 5960850.43 598443.68 N 70.30250829 W 149.20260092 10205.40 85.96 252.78 8914.42 8833.36 1561.37 2351.27 1813.03 1493.29 -1028.18 12.79 5960839.45 598411.31 N 70.30247943 W 149.20286430 10237.71 82.11 255.68 8917.78 8836.72 1554.82 2383.40 1823.62 1484.56 -1059.10 14.89 5960830.31 598380.51 N 70.30245556 W 149.20311467 10268.81 77.79 256.76 8923.20 8842.14 1549.62 2414.01 1835.17 1477.26 -1088.83 14.31 5960822.62 598350.88 N 70.30243562 W 149.20335547 10298.63 72.99 257.75 8930.72 8849.66 1545.23 2442.86 1846.93 1470.90 -1116.97 16.41 5960815.88 598322.84 N 70.30241822 W 149.20358333 10330.79 68.27 259.40 8941.39 8860.33 1541.30 2473.19 1860.32 1464.88 -1146.70 15.45 5960809.48 598293.19 N 70.30240178 W 149.20382409 10361.05 64.01 260.89 8953.62 8872.56 1538.4 7 2500.86 1873.55 1460.14 -1173.95 14.78 5960804.37 598266.00 N 70.30238881 W 149.20404484 10392.69 61.03 259.96 8968.22 8887.16 1535.75 2528.92 1887.41 1455.47 -1201.63 9.77 5960799.34 598238.39 N 70.30237606 W 149.20426899 10424.22 61.01 259.08 8983.50 8902.44 1532.64 2556.51 1900.96 1450.46 -1228.75 2.44 5960793.97 598211.34 N 70.30236234 W 149.20448863 10455.70 6D.88 258.85 8998.79 8917.73 1529.27 2584.02 1914.55 1445.19 -1255.76 0.76 5960788.34 598184.41 N 70.30234794 W 149.20470738 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Z -23\Z -23\Z -23B\Z-23B Generated 9/17/2004 11 :20 AM Page 4 of 5 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) Idea) Idea) 1ft) 1ft) (ft) (ft) 1ft) (ft) 1ft) (dea/100 ft) (ftUS) IftUS) Last MWD+IFR+MS TD ( Projected) Le!!a' Descriøtion: 10484.01 10496.63 10550.00 57.39 55.86 55.86 261.22 260.19 260.19 9013.31 9020.25 9050.21 8932.25 8939.19 8969.15 1526.73 1525.76 1521.29 2608.32 2618.86 2663.03 1927.18 1932.83 1956.64 1440.98 1439.28 1431.75 -1279.69 -1290.09 -1333.61 14.27 13.91 0.00 5960783.82 5960781.98 5960773.88 Surface: 4560 FSL 3214 FEL S19 T11N R12E UM BHL: 712 FSL 4542 FEL S18 T11N R12E UM Survey Type: Definitive Survey NOTES: GVD GC MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. ) MWD + IFR + MS - ( In·field referenced MWD with mult-station analysis and correction applied in post-processing.) SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Northln!! (V) rftUS1 5959360.03 5960773.88 Eastin!! (X) rftUS1 599459.07 598106.75 Z -231Z -231Z -23 BIZ -23B 598160.54 598150.17 598106.75 N 70.30233642 W 149.20490115 N 70.30233176 W 149.20498537 N 70.30231118 W 149.20533788 . . Generated 9/17/2004 11 :20 AM Page 5 of 5 !W~ SCHLUMBERGER Survey report Client... ............ ....: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: PBU Well. . . . . . . . . . . . . . . . . . . . .: Z-23B API number............ ...: 50-029-21950-02 Engineer. . . . . . . . . . . . . . . . . : Rig:.....................: Doyon 16 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum....... ...: Mean Sea Level Depth reference....... ...: Driller's Pipe Tally GL above permanent.......: 55.36 ft KB above permanent.......: N/A Top Drive ft OF above permanent.......: 81.06 ft ----- Vertical section origin---------------- Latitude (+N/S-). ........: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) ....... ..: N 70.29840007 ft Departure (+E/W-) ........: W 149.19453702 ft Azimuth from rotary table to target: 255.00 degrees [(c)2004 IDEAL 108 lC_02] 8-Sep-2004 13:27:49 Spud date..... . . . . . . . . . . . : Last survey date.... .....: Total accepted surveys...: MD of first survey... ....: MD of last survey........: c::<(!) tf - (éJ &> Page 1 of 4 22-Aug-04 04-Sep-04 80 6700.06 ft 10550.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2002 Magnetic date..... .......: 25-Aug-2004 Magnetic field strength..: 1151.52 HCNT Magnetic dec (+E/W-) ... ..: 24.88 degrees Magnetic dip.............: 80.81 degrees ----- MWD survey Reference Reference G... ....... ....: Reference H.. ..... .... ...: Reference Dip............: Tolerance of G...........: Tolerance of H...... .....: Tolerance of Dip...... ...: Criteria --------- 1002.68 mGal 1151.52 HCNT 80.81 degrees (+/-) 2.50 mGal ( + / - ) 6. 00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 24.88 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 24.88 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ . SCHLUMBERGER Survey Report 8-Sep-2004 13:27:49 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 6700.06 18.08 28.71 0.00 6681. 75 -71.87 147.80 34.80 151.84 13.25 0.00 TIP None 2 6718.00 18.74 28.80 17.94 6698.77 -75.79 152.77 37.53 157.31 13.80 3.68 Top of Window 3 6734.00 20.10 24.71 16.00 6713.86 -79.32 157.52 39.91 162.50 14.22 12.02 Bottom of Window 4 6748.00 20.10 24.71 14.00 6727.01 -82.40 161. 89 41. 92 167.23 14.52 0.00 MWD IFR MS - 5 6809.92 22.39 14.05 61.92 6784.74 -94.93 183.00 49.24 189.51 15.06 7.24 MWD IFR MS - 6 6905.74 25.03 12.80 95.82 6872.46 -113.24 220.48 58.16 228.02 14.78 2.80 MWD IFR MS . - 7 7001.11 24.90 2.42 95.37 6958.96 -128.67 260.23 63.48 267.86 13.71 4.59 MWD IFR MS - - 8 7095.11 25.06 352.30 94.00 7044.21 -137.13 299.75 61. 65 306.02 11. 62 4.54 MWD IFR MS - 9 7185.50 23.33 347.62 90.39 7126.67 -140.38 336.21 55.25 340.72 9.33 2.86 MWD IFR MS - - 10 7280.04 22.07 344.11 94.54 7213.88 -140.96 371.58 46.37 374.46 7.11 1.96 MWD IFR MS - 11 7373.61 21. 59 344.05 93.57 7300.74 -140.40 405.04 36.83 406.71 5.19 0.51 MWD IFR MS - - 12 7466.08 21.10 344.68 92.47 7386.87 -140.03 437.45 27.75 438.33 3.63 0.59 MWD IFR MS - 13 7561.90 22.96 345.89 95.82 7475.69 -140.22 472.21 18.64 472.58 2.26 2.00 MWD IFR MS - - 14 7653.80 22.75 345.60 91. 90 7560.38 -140.69 506.81 9.85 506.90 1.11 0.26 MWD IFR MS - 15 7749.78 22.55 345.65 95.98 7648.95 -141. 09 542.61 0.67 542.61 0.07 0.21 MWD IFR MS - 16 7840.56 23.78 342.19 90.78 7732.42 -140.39 576.91 -9.24 576.98 359.08 2.02 MWD IFR MS - 17 7933.11 23.78 342.55 92.55 7817.11 -138.68 612.47 -20.54 612.82 358.08 0.16 MWD IFR MS - 18 8029.57 22.52 341.35 96.46 7905.80 -136.67 648.53 -32.28 649.33 357.15 1. 39 MWD IFR MS - 19 8126.87 22.31 341. 28 97.30 7995.75 -134.28 683.67 -44.17 685.10 356.30 0.22 MWD IFR MS - 20 8224.65 21. 93 341. 08 97.78 8086.33 -131.83 718.52 -56.05 720.71 355.54 0.40 MWD IFR MS - - 21 8320.16 21.26 340.91 95.51 8175.14 -129.38 751. 76 -67.49 754.78 354.87 0.70 MWD IFR MS . - 22 8405.39 20.98 342.97 85.23 8254.64 -127.74 780.95 -77.01 784.74 354.37 0.93 MWD IFR MS - 23 8502.06 21. 96 344.82 96.67 8344.60 -127.07 814.94 -86.82 819.56 353.92 1. 23 MWD IFR MS - 24 8596.05 22.96 344.95 93.99 8431. 46 -126.99 849.61 -96.18 855.04 353.54 1. 07 MWD IFR MS - 25 8690.49 26.63 345.46 94.44 8517.18 -127.15 887.90 -106.28 894.24 353.17 3.89 MWD IFR MS - 26 8784.16 30.86 344.79 93.67 8599.29 -127.23 931. 42 -117.86 938.85 352.79 4.53 MWD IFR MS - - 27 8849.33 33.97 343.37 65.17 8654.30 -126.65 965.00 -127.45 973.39 352.48 4.91 MWD IFR MS - - 28 8923.61 34.87 344.05 74.28 8715.58 -125.71 1005.31 -139.23 1014.90 352.12 1. 32 MWD IFR MS - 29 8954.57 39.13 344.30 30.96 8740.30 -125.44 1023.23 -144.31 1033.35 351. 97 13.77 MWD IFR MS - 30 8985.11 43.40 344.54 30.54 8763.25 -125.24 1042.63 -149.71 1053.32 351.83 13.99 MWD IFR MS - [(c)2004 IDEAL 108 1C 02J ..- SCHLUMBERGER Survey Report 8-Sep-2004 13:27:49 Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 9017.29 47.60 346.11 32.18 8785.80 -125.38 1064.83 -155.52 1076.12 351. 69 13.51 MWD IFR MS - 32 9047.03 48.27 345.35 29.74 8805.72 -125.66 1086.22 -160.96 1098.08 351. 57 2.95 MWD IFR MS - 33 9078.35 49.18 342.64 31. 32 8826.38 -125.24 1108.84 -167.45 1121.42 351.41 7.12 MWD IFR MS - 34 9110.77 53.62 339.92 32.42 8846.61 -123.58 1132.82 -175.60 1146.35 351.19 15.18 MWD IFR MS - 35 9141. 88 58.29 338.69 31. 11 8864.02 -121. 02 1156.93 -184.71 1171.58 350.93 15.36 MWD IFR MS 36 9172.00 62.41 333.74 30.12 8878.92 -117.00 1180.86 -195.28 1196.89 350.61 19.77 MWD IFR MS . - 37 9205.78 66.53 331.48 33.78 8893.48 -110.45 1207.91 -209.31 1225.91 350.17 13.61 MWD IFR MS - 38 9235.75 70.17 330.51 29.97 8904.54 -103.71 1232.26 -222.82 1252.25 349.75 12.51 MWD IFR MS - 39 9263.64 73.99 328.98 27.89 8913.12 -96.72 1255.18 -236.19 1277.21 349.34 14.66 MWD IFR MS - 40 9295.00 79.26 327.89 31. 36 8920.37 -88.03 1281.16 -252.16 1305.74 348.87 17.14 MWD IFR MS - 41 9327.66 84.73 329.01 32.66 8924.92 -78.82 1308. 71 -269.07 1336.09 348.38 17.09 MWD IFR MS - 42 9356.47 89.23 326.72 28.81 8926.43 -70.34 1333.07 -284.37 1363.06 347.96 17.52 MWD IFR MS - 43 9391.69 91. 01 327.50 35.22 8926.36 -59.53 1362.64 -303.49 1396.03 347.44 5.52 MWD IFR MS - - 44 9422.77 91. 68 326.20 31. 08 8925.63 -49.85 1388.66 -320.48 1425.16 347.00 4.70 MWD IFR MS - - 45 9453.57 92.22 322.99 30.80 8924.58 -39.12 1413.74 -338.32 1453.66 346.54 10.56 MWD IFR MS 46 9482.46 91.44 317.00 28.89 8923.66 -26.92 1435.85 -356.87 1479.53 346.04 20.90 MWD IFR MS - 47 9514.10 91. 07 313.66 31. 64 8922.96 -11.26 1458.34 -379.10 1506.81 345.43 10.62 MWD IFR MS - - 48 9545.52 90.44 307.93 31. 42 8922.55 6.39 1478.86 -402.88 1532.76 344.76 18.35 MWD IFR MS - 49 9579.31 90.43 303.29 33.79 8922.29 27.83 1498.53 -430.34 1559.10 343.98 13.73 MWD IFR MS - 50 9610.71 91. 17 300.68 31.40 8921. 86 49.25 1515.16 -456.97 1582.57 343.22 8.64 MWD IFR MS 51 9643.37 92.16 296.70 32.66 8920.91 72.85 1530.83 -485.60 1606.00 342.40 12.55 MWD IFR MS . - 52 9673.96 92.69 291.94 30.59 8919.61 96.48 1543.41 -513.44 1626.57 341. 60 15.64 MWD IFR MS - 53 9705.12 92.75 288.17 31.16 8918.13 121. 96 1554.08 -542.68 1646.11 340.75 12.09 MWD IFR MS - - 54 9735.35 91.14 283.64 30.23 8917.11 147.87 1562.36 -571.72 1663.68 339.90 15.90 MWD IFR MS - - 55 9769.38 91. 93 278.85 34.03 8916.19 178.38 1568.99 -605.08 1681. 62 338.91 14.26 MWD IFR MS - 56 9798.57 93.18 276.82 29.19 8914.89 205.25 1572.97 -633.97 1695.92 338.05 8.16 MWD IFR MS - - 57 9828.21 89.70 275.92 29.64 8914.15 232.84 1576.25 -663.41 1710.17 337.17 12.13 MWD IFR MS - - 58 9863.81 89.64 270.14 35.60 8914.35 266.68 1578.13 -698.94 1725.99 336.11 16.24 MWD IFR MS - 59 9891.69 90.71 265.43 27.88 8914.27 293.86 1577.06 -726.79 1736.47 335.26 17.32 MWD IFR MS - 60 9920.82 92.10 261.34 29.13 8913.55 322.66 1573.70 -755.71 1745.75 334.35 14.82 MWD IFR MS - [(c)2004 IDEAL IDB_1C_02J SCHLUMBERGER Survey Report 8-Sep-2004 13:27:49 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 9955.36 91. 99 256.65 34.54 8912.32 357.08 1567.12 -789.59 1754.79 333.26 13.57 MWD IFR MS - 62 9986.70 89.52 258.24 31. 34 8911. 91 388.39 1560.30 -820.17 1762.73 332.27 9.37 MWD IFR MS - 63 10014.09 88.79 253.70 27.39 8912.31 415.76 1553.67 -846.74 1769.42 331.41 16.79 MWD IFR MS 64 10048.67 88.21 252.11 34.58 8913.21 450.31 1543.51 -879.78 1776.63 330.32 4.89 MWD IFR MS 65 10079.66 88.96 250.07 30.99 8913.98 481.21 1533.47 -909.08 1782.68 329.34 7.01 MWD IFR MS - 66 10108.21 90.97 251. 76 28.55 8914.00 509.69 1524.13 -936.06 1788.63 328.44 9.20 MWD IFR MS . 10141.50 - 67 90.86 250.88 33.29 8913.47 542.91 1513.47 -967.59 1796.34 327.41 2.66 MWD IFR MS 10171.18 - 68 90.06 251.25 29.68 8913.23 572.52 1503.84 -995.66 1803.58 326.49 2.97 MWD IFR MS - - 69 10205.40 85.96 252.78 34.22 8914.42 606.66 1493.28 -1028.19 1813.03 325.45 12.79 MWD IFR MS - 70 10237.71 82.11 255.68 32.31 8917.77 638.78 1484.55 -1059.10 1823.62 324.50 14.89 MWD IFR MS - 71 10268.81 77.79 256.76 31.10 8923.20 669.39 1477.26 -1088.83 1835.17 323.61 14.31 MWD IFR MS - 72 10298.63 72.99 257.75 29.82 8930.72 698.22 1470.89 -1116.97 1846.93 322.79 16.41 MWD IFR MS - - 73 10330.79 68.27 259.40 32.16 8941. 38 728.49 1464.87 -1146.70 1860.31 321.95 15.45 MWD IFR MS 74 10361.05 64.01 260.89 30.26 8953.62 756.04 1460.13 -1173.95 1873.54 321. 20 14.78 MWD IFR MS - 75 10392.69 61.03 259.96 31. 64 8968.22 783.98 1455.47 -1201.63 1887.41 320.46 9.77 MWD IFR MS - 76 10424.22 61. 01 259.08 31. 53 8983.50 811.48 1450.45 -1228.75 1900.96 319.73 2.44 MWD IFR MS - 77 10455.70 60.88 258.85 31.48 8998.79 838.93 1445.18 -1255.76 1914.55 319.01 0.76 MWD IFR MS - 78 10484.01 57.39 261.22 28.31 9013.31 863.13 1440.97 -1279.69 1927.17 318.39 14.27 MWD IFR MS - 79 10496.63 55.86 260.19 12.62 9020.25 873.62 1439.27 -1290.09 1932.83 318.13 13.91 MWD IFR MS - - 80 10550.00 55.86 260.19 53.37 9050.20 917.61 1431.74 -1333.61 1956.63 317.03 0.00 Projected to TD . [(c) 2004 IDEAL ID8 lC 02] - - '" 9-5/8" whipstock·at 68351MD 9 ' FISH· 2.75" OD x 3.25" LONG 1" OD X 2" LONG SPIRA L GF!A PPLE 18" 8ENT WHIPSTOCK FISHING TIP 3.80" HC DP0261 . . (ill /^\ ILL Lrù FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-23B BP Exploration (Alaska) Inc. Permit No: 204-108 Surface Location: 4560' NSL, 3214' WEL, SEC. 19, TIIN, RI2E, UM Bottomhole Location: 684' NSL, 4728' WEL, SEC. 18, TUN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). Chair BY ORDER O_F '!JIE COMMISSION DATED thi~ay of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encL Department of Environmental Conservation w/o encl. ~...¡G A- (~I t i( Z-CC~ 1a. Type of work DDrill . Redrill 1b. Current Well Class D Exploratory . Development Oil D Multiple Zone D Re-Entry D Stratigraphic Test D Service D Development Gas D Single Zone 2. Operator Name: 5. Bond: !HI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU Z-23B .,/ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10792 TVD 9046 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028262 4560' NSL, 3214' WEL, SEC. 19, T11N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: July 15, 2004 ./ 617' NSL, 3453' WEL, SEC. 18, T11N, R12E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 684' NSL, 4728' WEL, SEC. 18, T11N, R12E, UM 2560 5570' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 599459 y- 5959360 Zone- ASP4 (Height above GL):Plan 82.5 feet Z-28 is 2550' away at 8800' ss 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 0 Kickoff Depth 6819 ft Maximum Hole Angle 90 Downhole: 3807 psig Surface: 2936 psig 18..Ç)asing Program ~~1.'t¡I'IQPepth ~\ Size TÖpi ii . . . Bottom Hole Casino Weioht Grade CouplinQ LenQth MD TVD MD TVD 8-1/2" 7" 26# L-80 BTC-M 2257' 6669' 6653' 8928' 8718' 78 ~ . ¡Joo fin ""..,.",,_ 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1953' 8778' 8581' 10792' 9046' 86 ~u' V ,..... J .II/AI 'Î r ^_ vv., '"J (fUlf 19. ~~A~. PRESENT WELL GONDITION SUMr\i1¡1\R.)' (To be completedfOl'FtedrillANpR~-entrYº~r :::. ""- Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):J nk (measured): 9580 9248 Whipstock at 9010' 9020 8717 9020 ii /i ........... i. .? i·i .ii.??;.'. ·.·.i. it iiii," lip;·?".? lII.x¡;. ¡; ~trll~h 1r~1 Conductor 118' 20" 118' 118' ~ - 2657' 13-3/8" 3684 cu ft Permafrost 2657' 2657' I ntArmArl i~tA 7472' 9-5/8" 1894 cu ft Class 'G' 7472' " 7369' Production I inAr 2290' 7" 372 cu ft Class 'G' 7285' - 9575' / 7212' - 9243' Perforation Depth MD (ft): 9192' - 9328' IPerfOration Depth TVD (ft): 8876' - 9006' 20. Attachments !HI Filing Fee, $100 o BOP Sketch !HI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report !HI Drilling Fluid Program !HI 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 Jim Smith, 564-5773 Printed Name Bill Isaacson Title Senior Drilling Engineer 1 .J.l 1 LB (./10 I O~\ Prepared By Name/Number: Signature Phone 564-5521 Date Terrie Hubble, 564-4628 ?i ~ i)"X .; i. .",,"':1; .!'.'.'. ....·..··.··............·....i iXi} ..; ., . i'.., . Permit To Drill API Number: Permit AfTi.1 1...1 I See cover letter for Number: 20 9-/0 5r 50- 029-21950-02-00 Date: . - other requirements Conditions of Approval: Samples Required DYe~Æ"~o Mud Log R~quired - -.' ~es~No Hydrogen Sulfide Measures ~es D No Directional Survey Required es DNo Dther:Te<;,~çCD pc,' P¿y" e,O. S l ¿, 4 000 , b¡-z,v¡;C¡VV Aooroved Bv: I-A J BY ORDER OF THE COMMISSION Date Form 10-401 ~ised 12~ '- ; '. !. ;'\.1 /~! Submit (n Duplicate . STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 · . I Well Name: I Z-238 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 599,459' Y = 5,959,360 Estimated 4560' FSL 3214' FEL Sec. 19, T11 N, R12E Umiat / Target Location: X = 599,202' Y = 5,960,649 8850' TVDss Ivishak Zone 4 572' FSL 3449' FEL Sec. 18, T11 N, R14E Umiat Bottom Hole Location: X = 597,921 Y = 5,960,743 TVDss 8,963' 683' FSL 4728' FEL Sec. 18, T11 N, R12E Umiat /' I AFE Number: I PBD4P2213 I I Estimated Start Date: 17/15/04 (Î I Rig: I Doyon 16/ I Operating days to complete: 117.2 ~ 10792' 1 'TVD: 19046' I @g54' I KB: 128.5' I I KBE: 182.5' I Well Design (conventional, slim hole, etc.}: 'Dual Casing String Horizontal Sidetrack I Objective: 'Ivishak Zone Upper 4; Z4B target Formation Markers (Anadril wp04) Formation Tops MD TVD TVDss Comments Kickoff in the Kuparuk. TKUP 6818 6793 6710 Hydrocarbon bearing, 8.7 ppg EMW KOP 6819 6793 6710 Cement is anticipated outside the 9-5/8" casing LCU 6871 6842 6759 TKNG 7603 7518 7435 Drill the Kingak with 10.6 PDq mud for stability TJF 7944 7831 7748 8.7 ppg EMW TJD 8401 8252 8169 8.7 ppq EMW Fault #1 8723 8533 8450 TJB 8760 8575 8492 8.7 PPQ EMW TSAG (7" casinq point) 8928 8718 8635 Hvdrocarbon bearina GAS 8.4 ppg EMW TSHU 8966 8751 8668 Hydrocarbon bearing 8.3 ppg EMW TElL 9104 8852 8760 TSAD 9168 8887 8804 Hydrocarbon bearing 8.3 ppa EMW T45N 9236 8914 8831 Hvdrocarbon bearina 8.3 ppa EMW T45P 9250 8918 8835 Hydrocarbon bearing 8.3 ppg EMW Total Depth 10792 9046 8963 TD Criteria: Taq or loq POWC at end of well, will turn down to look for POWC prior to TD 10- 1- ~,' Z-23B Permit Application Page 1 . . Directional - Anadril plan 5 KOP: 6,819' M D/671 O'TVDss Maximum Hole Angle: _240 in 8-1/2" Intermediate section _900 in 6-1/8" horizontal section. Close Approach Wells: There are no collision risks on this well Survey Program: MWD, run IFR in 8-1/2" and in 6-1/8" hole Nearest Property Line: The nearest property line is 5570' WSW from TD of the S-123. Casi n Hole Size WtlFt Grade" Con~/ Length Top / ft MDITVD ft Existin 9-5/8" 47# L-80 NSCC 28/28 8-1/2" 7" 26# L-80 BTC-M 2257 6669/6653 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1953 8778/8581 Tubin 4-1/2" 12.6# 13CR VAM-To 8748 28/28 Burst si Colla se si Tension #M 6870 4750 1086 7" 7240 5410 604 4-1/2" liner 8430 7500 288 4-1/2" tubin 8430 7500 288 PH 9.0- 9.5 8-1/2" hole section YP 10 sec el Chlorides PH 25-33 15-20 <500 9.0 TauO PV 3-7 8-12 6-1/8" hole section LSYP >30000 Chlorides < 3,000 Production Mud Properties: Flo-Pro, solids free Lo Pro ram 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes/PWD- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlRES/PWD - Real time Open Hole: Potential E-line CNL if the reservoir comes in more than 10' shallow. Cased Hole: None 2-23B Permit Application Page 2 . . cks Class G @ 15.8 4.5" 12.6#, L-80 Production Liner None I 51 bbls,286 ft3, 82ßacks Class G+latex+silica @ 15.8 ppg and 1 .57 ft3/sack ~/- Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure 9-5/8" Casin " Liner Test Inte rit Test - 6-1/8" hole Planned com letion fluids Diesel DisDOSal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Z-23B Permit Application Page 3 . . Sidetrack and ¡Complete Procedure Summary Pre-RiQ Work: 1. Rig up coil, RIH to the top of fish @ '-9020' MD. 2. Place cement from the top of fish to¡about 8775' (245' of cement). 3. Chemical cut the 4-1/2", 12.6#, l-8q BTC-M tubing at -7400' MD. 4. Pressure test tubing and 9-5/8" casir-g to 3500 psi. 5, Fluid pack T X IA with seawater and freeze protect same with diesel. 6. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 3000 psi. 7. Function all lock-down screws. Repair or replace as needed. 8. Bleed casing and annulus pressure$ to zero. 9. Set a BPV in tubing hanger. Secure well. 10. Remove the well house & if necessary level the pad. Please provide total well prep cost on the handover form. RiQ ODerations: 1. MIRU Doyon 16 2. Pull BPV. Circulate out freeze protection and¿isplace well to seawater. Set TWO. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. / 4. Pull 4-1/2" tubing from above pre-rig cut at about 7400'. / 5. RU e-line. Run GR/JB for 9-5/8",47# casing to just above top of 7" liner at 7299'MD. / 6. MU 9-5/8", 47# bridge plug on e-line with CCl & GR. RIH and set at 6840' MD, set .as needed to avoid cutting a casing collar and to place the whipstock window in the Kuparuk forrlJation. ,/ 7. Pressure test casing to 3500 psi for 30 minutes. / 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Swap over to 10.2 ppg lSND drilling and milling fluid. / . 10. Mill window in 9-5/8" casing at 6819' MD (top of window) plus 20' past middle of window. Perform FIT. POOH. I" 11. MU 8-1/2" drilling assembly with Dir/GR/RES and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 4°/100' to a 24° hold angle and 342° azimuth. 12. Drill ahead to casing point at Top Sag River to an estimated depth of 8928' MD. 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150' of o~l¡'lap. Displace cement with mud. POOH. 14. MU 6-1/8" rotary drilling BHA with tricone drillout bit and RIH to the landing collar. // 15. Pressure test wellbore to 3500 psi for 30 minutes. 16. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. 17. POOH and pick up 6-1/8" BHA with Dir/GR/RES/PWD and RIH to drill. 18. Drill the 6-1/8" production interval building at 15°/100' to horizontal, targeting 24 Ivishak. 19. Possible trip for BHA and bit change after landing and turning to 265 deg azimuth. Drill ahead to an estimated TD of 10,792' MD. / 20. Run and cement a 4-1/2" l-80 liner throughout the 6-1/8" wellbore and back into the 7" drillingAiner to place top of liner with 150' of overlap. Place a perf pill in the liner during cement displacement. ('" 21. Displace well to clean seawater above the liner top. 22. RIH with DPC perf guns. Perf intervals as determined from lWD log. 23. POOH. lD DP and perf guns. 24. Run 4-1/2",12.6#, 13CR completion tying into the 4-1/2" liner top. 25. Set 7" x 4-1/2" packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 26. Set and test TWC. 27. ND BOPE. NU and test the tree to 5000 psi. 28. Freeze protect the well to -2200' and secure the well. 29. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 2-23B Permit Application Page 4 . . Z-238 Drilling Program Job 1: MIRU Hazards and Contingencies > No wells will require well house removal or shut-in (adjacent wells are the Z-22 and Z-24). Care should be taken while moving onto the well. Spotters will be use¡d at all times. f'" > Z pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should De fonõwed at all times. Planning involves pre-rig arrival readings of H2S prior to this well. Existing recent H2S data from the pad is as follows: Well Name Z-35 Closest SHL with H2S Readin H2S Readin 20 Date 8/17/2000 > Post the Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: De-comolete Well Hazards and Contingencies > Z-23A is currently shut-in at surface. Pre-Rig operations include the cement work for P&A of the existing completion, a summary of the cementing and casing pressure testing is attached. > Note and record required PU weight to pull tubing from the cut point (planned cut at 7400'MD). > NORM test all retrieved well head and completion equipment. > Verify the tubing hanger type and connection. Be prepared with necessary equipment to remove. All packoffs and wellhead equipment is to have been tested in the pre-rig work. The well history reports that there were numerous difficulties achieving pressure integrity of the 9-5/8" packoff even after a new tubing spool was installed. It was necessary to install a W' spacer plate over the packoff to allow the lock down screws to move the compression plate enough to manifest a seal. Beware of extra components in the system if changeout is again required. > It was reported in previous well work that heavy asphaltines were present in the tree. Prepare for capture and containment if these are again present (they may be outside the tubing also and gunk may be present above the tubing hanger). ~ > Barriers: BHP is 3590 at 8800 TVDss, 8880TVD which equates 7.8 g EMW. At rig arrival the barriers in place will be; a) cemented and tested P&A plugs fro ... e-rig work, 8.4 brine in the hole, / tested casing strings down to the P&A. Job 3: Window Mill Hazards and Contingencies > Wellbore obstructions: Prior to placement of the bridge plug a GR/JB run will confirm there are no obstructions in the 9-5/8" casing. > KOP placement: Concurrent with the GR/JB run, a GammaRay log will be included to confirm placement of the KOP within the Kuparuk sands. (There are no existing uphole logs on this well, the rigsite geologist will need to pick the top of Kuparuk onsite). > Metal shavings in the BOP's: Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Z-23B Permit Application Page 5 . . Þ- Barriers: Prior to EZSV placement there will be a P&A plug as noted above, after placement of the EZSV for sidetracking the casing and EZSV will be pressure tested to 3500 psi. The surface BOPE will constitute a second barrier. Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies Þ- The intermediate section will kick off in the Kuparuk sand interval and drill to the top of Sag River. For this / well (tangent at 23° to 34° inclination at a 343° azimuth) maintain mud weight at 10.6 ppg, from above the top of the Kingak to the 7" liner point. Follow all shale drilling practices to minimize potential problems. Þ- There is one fault crossing in the intermediate section, the fault is expected to be crossed at 8723'MD in the Kingak shale interval. The fault is not expected to produce major problems for drilling but it could introduce breathing of the wellbore Þ- There are no close approach issues on this sidetrack. Þ- LERANCE: In the worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture f 11.9 ppg at the 9-5/8" casing window, and 10.6 ppg mud in the hole, the kick tolerance is Job 6: Install 7" Intermediate Liner Hazards and Contingencies Þ- Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. Þ- Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 7: Dril/6-1/B" Production Hole Hazards and Contingencies Þ- It is expected that there may be a bit/BHA trip made after the well is landed at horizontal if the recommended bit and BHA combination cannot facilitate steering in the horizontal as planned. Þ- There is one fault crossing possible in the production section. This occurs at -9,960' MD (if at all), the potential fault has an estimated throw of 10'-15' down to the east. Lost circulation is possible but is not anticipated. Follow the lost circulation decision tree should LC become problematic. Þ- There are no close approach issues while drilling the production hole section. Þ- KICK TOLERANCE: In the worst-case scenario of 8.5 ppg pore pressure in th ish , a fracture gradient of 10.0 ppg at the 7" shoe, and 8.6 ppg mud in the hole, the kick tolerance is nfin·_. ~ Barriers: There will be casing and liner (9-5/8" and 7") pressure tested 0 Ó psi, tested BOPE and KWM (8.4ppg mud vs. 7.9 ppg pore pressure) in the borehole. Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies Þ- Differential sticking is a potential concern. The 8.6 ppg mud will be -300psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. Z-23B Permit Application Page 6 . . Þ- Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after liner is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Job 10: DPC Perforate Production CasinQ Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. ~ Sticking of guns is a risk, gun size will be adapted to suit the tortuosity of the completed wellbore. ~ Barriers: the 4-1/2" liner, 7" liner and 9-5/8" casing will all be pressure tested to 3500 psi, the BOPE equipment will have been tested, there will be a full column of Kill Weight Brine (8.4ppg) in the borehole. Job 12: Run Completion HazardsandConüngencres ~ Handling damage to the 13CR completion during pickup and running. ~ Pressure requirements for packer setting and casing/tubing testing. Þ- Barriers: Kill weight fluid in the well, BOPE Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No specific hazards identified ~ Barriers: The TWC will be set and tested to 1000 psi, a second annulus valve will remain in place until the tree is on and tested, the annulus and tubing above the packer will have been tested, there will be a RHC plug/rod and ball landed in the tailpipe with kill weight seawater above. Prior to rig release the tree and tubing hanger packoff will be tested. Z-23B Permit Application Page 7 . . Z-23B Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There is one fault crossing in the intermediate interval near 8723'MD. Utilize caution when crossing to fault to observe potential mud losses and then minimize swab and surge loads once the interval is exposed. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · Lost circulation while drilling the intermediate hole has not been problematic on Z pad unless major faulting was cut in the wellbore. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.6 ppg to ensure shale stability in the Kingak (once the Kingak is exposed). · Kick tolerance is Infinite with a 11.9 ppg FIT. Production Hole Section: · There is one fault possible in the production section. This occurs at -9,960' MD where a fault with 10'-15' estimated throw may be cut. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings samples. · There are no close approach issues while drilling the production hole section. · Kick tolerance is Infinite with a 10.0 ppg FIT. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE Z PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Z-238 Permit Application Page 8 'TREE= , WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 4" CrN FMC BAKER 91.74' 55.36' 3100' 33 @ 7389' 9,197' 8800' SS . . Z-238 Proposed 13-3/8" CSG, 68#, L-80,ID= 12.415" I 2657' X nipple at 2200' GLM's at xxx 4-1/2" 12.6# 13CR Baker 9-5/8" x 7" HMC/ZXP hgr/pkr -- TOl at approx 6670'MD ,/' 9-5/8" whipstock at 6829'MD ~ I 7299' I TOP OF BKRTIEBACK SLV, ID=6.~ ~ 7306' I 9-518" X T' BKR H Lf\R TŒ' 19020' SLM I FISH - 2.75" OD x 3.25- LONG SPIRAL GRAPPLE 1" OD x 2" LONG SPIRAL GRAPPLE 18" BENT WHIPSTOCK FISHING TIP 3.80" HC DP0261 DS MILL /7" 26# l80 BTCm liner 6670' to 8900'MD Baker 7" x 4-1/2" pkr at / approx 8700'MD 9-5/8" CSG, 47#, L-80, ID = 8.681" H 7472' Baker 7" x 4-12" hgr/9kr at 8750'MD 4-1/2" 12.6# l80 IBTm 19-5/8" MILLOUT WINDOW 7472' - 7527' I ,/' RA tag in heel/ 8996' 7" x 4-1/2" BKR S-3 PKR. NO LA TCH. ID - 3.938" Pre-rig P&A over fish .,,/ and tbg cut at 7400'MD Shoe at 10747'MD TOP OF 2ND WHIPSTOCK 1-1 9010' 9 1 4 8 ' 1-; S TAN D IN G V A L V E W / C H E C K I PBTD 9489' 7" LNR, 29#, L-BO, 0.0371 bpf, ID 6.184" 9575' DATE 10/18/89 05/05/95 07/08/03 REV BY COMMENTS FH ORIGINAL COMPLETION LINDER SIDETRACK (Z-23A) DAV/KK ATTEMPTEDZ-23AL1 DATE REV BY COMMENTS PRUDHOE BAY UNrT WELL: Z-23B proposed ÆRMrT No: API No: TBD SEC 19, T11N, R12E. 4560' NSL & 3214' WEL BP Exploration (Alaska) Z-238 (P5) Proposal lum rger Report Date: March 1, 2004 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 343.000" Field: Prudhoe Bay Unit - WOA st ~dY Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Z-PAD 1 Z-23 Feasibility TVO Reference Datum: Rotary Table Well: Z-23 TVD Reference Elevation: 82.54 ft relative to MSL Borehole: Plan Z-238 Sea Bed I Ground level Elevation: 54.04 ft relative to MSL UWI/API#: 500292195002 Magnetic Declination: 24.982" Survey Name I Date: Z-238 (P5) 1 March 1,2004 Total Field Strength: 57568.054 nT Tort I AHD I DDII ERD ratio: 258.954" 14709.64 ft/6.163/ 0.521 Magnetic Dip: 80.805" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 02, 2004 Location LatlLong: N 70.29840007, W 149.19453702 Megnetic Declination Model: 8GGM 2003 Location Grid N/E Y/X: N 5959360.030 ftUS, E 599459.070 ftUS North Reference: True North Grid Convergence Angle: +0.75831778" Total Corr Mag North·> True North: +24.982" Grid Scale Factor: 0.99991124 Local Coordinates Referenced To: Well Head . Comments Tie-In Survey Top Kuparuk Top Whipstock Base Whipstock Crv 4/100 LCU 6871.42 22.31 22.45 6841.54 6759.00 178.35 312.12 206.35 64.94 4.00 -1.14 -10.04 -105.45G 5959567.20 599521.26 N 70.29896380 W 149.19401119 6900.00 22.03 19.51 6868.01 6785.47 186.84 322.90 216.41 68.80 4.00 -0.97 -10.28 -102.72G 5959577 .32 599524.99 N 70.29899130 W 149.19397992 7000.00 21.49 8.81 6960.92 6878.38 218.42 359.88 252.20 77.87 4.00 -0.54 -10.71 -92.78G 5959613.22 599533.59 N 70.29908907 W 149.19390647 7100.00 21.65 357.92 7053.96 6971.42 252.74 396.54 288.75 80.00 4.00 0.16 -10.89 -82.65G 5959649.79 599535.24 N 70.29918891 W 149.19388918 7200.00 22.49 347.50 7146.67 7064.13 289.65 434.03 325.87 75.19 4.00 0.85 -10.42 -72.99G 5959686.84 599529.93 N 70.29929033 W 149.19392814 End Crv 7248.99 23.14 342.73 7191.82 7109.28 308.62 453.01 344.22 70.30 4.00 1.32 -9.74 O.OOG 5959705.11 599524.81 N 70.29934044 W 149.19396771 Top Kingak 7603.20 23.14 342.73 7517.54 7435.00 447.82 592.21 477.13 28.97 0.00 0.00 0.00 O.OOG 5959837.46 599481.73 N 70.29970357 W 149.19430239 TJF 7943.59 23.14 342.73 7830.54 7748.00 581.58 725.97 604.86 -10.74 0.00 0.00 0.00 O.OOG 5959964.64 599440.33 N 70.30005252 W 149.19462401 TJE 8148.03 23.14 342.73 8018.54 7936.00 661.92 806.32 681.58 -34.60 0.00 0.00 0.00 O.OOG 5960041.04 599415.46 N 70.30026211 W 149.19481719 TJD 8401.42 23.14 342.73 8251.54 8169.00 761.49 905.89 776.67 -64.16 0.00 0.00 0.00 O.OOG 5960135.71 599384.64 N 70.30052187 W 149.19505662 . Crv 2.5/100 8493.71 23.14 342.73 8336.40 8253.86 797.76 942.16 811.30 -74.93 0.00 0.00 0.00 -2.16G 5960170.19 599373.42 N 70.30061648 W 149.19514382 8500.00 23.30 342.71 8342.19 8259.65 800.24 944.64 813.67 -75.67 2.50 2.50 -0.24 -2.14G 5960172.55 599372.65 N 70.30062295 W 149.19514979 8600.00 25.80 342.50 8433.14 8350.60 841.78 986.18 853.31 -88.09 2.50 2.50 -0.21 -1.95G 5960212.02 599359.70 N 70.30073124 W 149.19525039 TJC 8637.24 26.73 342.43 8466.54 8384.00 858.25 1002.65 869.02 -93.05 2.50 2.50 -0.19 -1.89G 5960227.66 599354.53 N 70.30077416 W 149.19529060 8700.00 28.29 342.32 8522.20 8439.66 887.24 1031.64 896.64 -101.83 2.50 2.50 -0.17 -1.79G 5960255.17 599345.39 N 70.30084963 W 149.19536170 TJB 8759.87 29.79 342.22 8574.54 8492.00 916.30 1060.70 924.33 -110.68 2.50 2.50 -0.16 -1.71G 5960282.73 599336.17 N 70.30092526 W 149.19543337 8800.00 30.79 342.17 8609.19 8526.65 936.54 1080.95 943.60 -116.87 2.50 2.50 -0.15 -1.66G 5960301.91 599329.73 N 70.30097791 W 149.19548350 8900.00 33.29 342.03 8693.95 8611.41 989.58 1134.00 994.08 -133.18 2.50 2.50 -0.13 -1.55G 5960352.17 599312.76 N 70.30111582 W 149.19561558 7" Csg PI 8928.32 34.00 342.00 8717.53 8634.99 1005.27 1149.69 1009.01 -138.03 2.50 2.50 -0.12 O.OOG 5960367.03 599307. 72 N 70.30115660 W 149.19565481 End Crv 8928.34 34.00 342.00 8717.54 8635.00 1005.28 1149.70 1009.01 -138.03 2.50 2.50 -0.12 O.OOG 5960367.04 599307.71 N 70.30115662 W 149.19565483 Top Sag River 8928.35 34.00 342.00 8717.55 8635.01 1005.29 1149.70 1009.02 -138.03 0.00 0.00 0.00 O.OOG 5960367.04 599307.71 N 70.30115663 W 149.19565485 Crv 15/100 8948.34 34.00 342.00 8734.12 8651.58 1016.46 1160.88 1019.65 -141.48 0.00 0.00 0.00 177.59G 5960377.63 599304.12 N 70.30118567 W 149.19568282 8961.06 32.09 342.15 8744.78 8662.24 1023.40 1167.82 1026.25 -143.62 15.00 -14.99 1.19 O.OOG 5960384.20 599301.90 N 70.30120371 W 149.19570012 Top Shublik 8967.85 32.09 342.15 8750.54 8668.00 1027.01 1171.43 1029.69 -144.73 0.00 0.00 0.00 O.OOG 5960387.62 599300.74 N 70.30121309 W 149.19570908 Well Design Ver 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) Z-231Z-23\Plan Z-23BIZ-23B (P5) Generated 3/1/2004 3:51 PM Page 1 of 2 Comments 9000.00 36.39 342.13 8777.18 8694.64 1044.98 1189.40 1046.79 -150.24 15.00 15.00 -0.08 O.OOG 5960404.65 599295.01 N 70.30125983 W 149.19575372 9100.00 51.39 342.08 8849.05 8766.51 1114.10 1258.53 1112.58 -171.49 15.00 15.00 -0.05 O.OOG 5960470.14 599272.89 N 70.30143954 W 149.19592582 TElL 9104.02 51.99 342.07 8851.54 8769.00 1117.26 1261.69 1115.58 -172.46 15.00 15.00 -0.04 O.OOG 5960473.13 599271.88 N 70.30144775 W 149.19593369 Top Sadlerochit 9168.00 61.59 342.05 8886.54 8804.00 1170.72 1315.15 1166.45 -188.93 /15.00 15.00 -0.04 O.OOG 5960523.77 599254.74 N 70.30158671 W 149.19606707 9200.00 66.39 342.04 8900.57 8818.03 1199.46 1343.90 1193.80 -197.79 15.00 15.00 -0.03 O.OOG 5960551.00 599245.52 N 70.30166143 W 149.19613884 T45N 9236.41 71.85 342.03 8913.54 8831.00 1233.46 1377.91 1226.14 -208.28 15.00 15.00 -0.03 O.OOG 5960583.20 599234.61 N 70.30174979 W 149.19622378 T45P 9249.99 73.89 342.03 8917.54 8835.00 1246.44 1390.88 1238.49 -212.28 15.00 15.00 -0.03 O.OOG 5960595.49 599230.44 N 70.30178352 W 149.19625621 9300.00 81.39 342.01 8928.24 8845.70 1295.25 1439.70 1284.92 -227.35 15.00 15.00 -0.03 O.OOG 5960641.71 599214.76 N 70.30191037 W 149.19637826 Crv 15/100 9355.41 89.70 342.00 8932.54 8850.00 1350.43 1494.89 1337.41 -244.40 15.00 15.00 -0.03 -90.09G 5960693.97 599197.02 N 70.30205377 W 149.19651635 9400.00 89.69 335.31 8932.78 8850.24 1394.87 1539.48 1378.92 -260.62 15.00 -0.02 -15.00 -90.06G 5960735.26 599180.25 N 70.30216717 W 149.19664774 9500.00 89.69 320.31 8933.32 8850.78 1491.10 1639.48 1463.31 -313.74 15.00 0.00 -15.00 -89.98G 5960818.93 599126.02 N 70.30239770 W 149.19707797 . 9600.00 89.70 305.31 8933.86 8851.32 1577.29 1739.48 1531.07 -386.89 15.00 0.02 -15.00 -89.90G 5960885.71 599051.99 N 70.30258282 W 149.19767043 9700.00 89.74 290.31 8934.34 8851.80 1647.56 1839.48 1577.59 -475.08 15.00 0.04 -15.00 -89.82G 5960931.06 598963.19 N 70.30270990 W 149.19838476 9800.00 89.80 275.31 8934.75 8852.21 1697.13 1939.48 1599.70 -572.31 15.00 0.05 -15.00 -89.76G 5960951.87 598865.69 N 70.30277028 W 149.19917227 9900.00 89.86 260.31 8935.05 8852.51 1722.62 2039.48 1595.89 -671.96 15.00 0.07 -15.00 -89.72G 5960946.75 598766.11 N 70.30275985 W 149.19997927 End Crv 9946.29 89.90 253.37 8935.14 8852.60 1725.72 2085.77 1585.36 -717.00 15.00 0.08 -15.00 O.OOG 5960935.62 598721.22 N 70.30273106 W 149.20034408 Crv 10/100 10143.22 89.90 253.37 8935.49 8852.95 1726.98 2282.70 1528.99 -905.69 0.00 0.00 0.00 89.04G 5960876.76 598533.31 N 70.30257702 W 149.20187226 10200.00 90.00 259.04 8935.54 8853.00 1730.16 2339.48 1515.46 -960.81 10.00 0.17 10.00 89.03G 5960862.51 598478.37 N 70.30254003 W 149.20231868 Tgt3 10202.45 90.00 259.29 8935.54 8853.00 1730.42 5936.77 1515.00 -963.22 10.00 0.17 10.00 90.00G 5960862.01 598475.97 N 70.30253877 W 149.20233818 End Crv 10202.50 90.00 259.29 8935.54 8853.00 1730.42 6836.82 1514.99 -963.27 10.00 0.00 10.00 O.OOG 5960862.00 598475.93 N 70.30253874 W 149.20233855 Drp 10/100 10423.05 90.00 259.29 8935.54 8853.00 1754.61 7057.37 1474.02 -1179.98 0.00 0.00 0.00 -90.00G 5960818.17 598259.79 N 70.30242673 W 149.20409368 Tgt4 10423.10 90.00 259.29 8935.54 8853.00 1754.61 7957.42 1474.01 -1180.03 10.00 0.00 -10.00 -176.72G 5960818.16 598259.75 N 70.30242671 W 149.20409405 10500.00 82.32 258.85 8940.68 8858.14 1762.72 8034.09 1459.48 -1255.31 10.00 -9.98 -0.57 -176.70G 5960802.63 598184.67 N 70.30238696 W 149.20470373 10600.00 72.34 258.25 8962.59 8880.05 1772.15 8131.53 1440.14 -1350.81 10.00 -9.98 -0.60 -176.56G 5960782.03 598089.44 N 70.30233409 W 149.20547718 10700.00 62.36 257.57 9001.05 8918.51 1780.06 8223.70 1420.85 -1440.94 10.00 -9.98 -0.67 -176.30G 5960761.56 597999.58 N 70.30228135 W 149.20620710 End Drp 10712.97 61.06 257.48 9007.20 8924.66 1780.96 8235.12 1418.38 -1452.09 10.00 -9.98 -0.74 O.OOG 5960758.94 597988.47 N 70.30227461 W 149.20629740 POWC 10732.28 / 61.06 257.48 9016.54 8934.00 1782.28 8252.02 1414.72 -1468.59 0.00 0.00 0.00 O.OOG 5960755.06 597972.02 N 70.30226459 W 149.20643101 TD / 4-1/2" Lnr 10792.22 61.06 257.48 9045.54 8963.00 1786.37 8304.48 1403.35 -1519.80 0.00 0.00 0.00 O.OOG 5960743.01 597920.97 N 70.30223349 W 149.20684573 Leaal Description: Northina (YI [flUS] Eastina IX) [ftUS1 Surface 4560 FSL 3214 FEL S19 T11N R12E UM 5959360.03 599459.07 . Tie-In 4560 FSL 3214 FEL S19 T11N R12E UM 5959360.05 599459.03 Sag T gt 289 FSL 3348 FEL S18 T11N R12E UM 5960367.04 599307.71 Tgt2 617 FSL 3453 FEL S18 T11N R12E UM 5960693.97 599197.02 Tgt 3 795 FSL 4171 FEL S18 T11N R12E UM 5960862.01 598475.97 Tgt4 754 FSL 4388 FEL S18 T11N R12E UM 5960818.16 598259.75 TD / BHL 683 FSL 4728 FEL S18 T11 N R12E UM 5960743.01 597920.97 Well Design Ver 3.1RT-SP3.03-HF4.00 Bld( do31rt-546) Z-231Z-23\Plan Z-23BIZ-23B (P5) Generated 3/1/2004 3:51 PM Page 2 of 2 . . Schl WELL Z-23B (P5) Prudhoe Bay Unit - WOA STRUCruRE Z-PAD Magnetic Parameters Model: BGGM2003 Dip: 80.805' Mag Dee: +24.982' Date: JUf\602,2004 FS: 57568.t roT Surfaaelocation Lat: N701754.240 lon" W1491140.333 NAD27 Alaska State Planes. Zona 04, US Feet Northing: 5959360.03 ftUS Grid COOv: +0.75831778' Easllng: 599459.07ftUS ScaleFa~: 0.9999112373 MisœØaneous Slot: Z-23 Plan: Z-238!P5) TVDRef: RaIary Table (82.54 fI above MSL) Slvy Date: March 01, 2004 o 300 600 900 1200 1500 9000 6900 6900 7200 7200 7500 7500 :2 a 0 ~ & 7800 7800 ~ II Q) (ij () (/) 0 ~ 8100 8100 8400 8400 8700 8700 9000 o 300 600 900 1200 Vertical Section (ft) Azim = 343°, Scale = 1 (in):300(ft) Origin = 0 Nt-S, 0 Et-W 1500 Z-238 (PS) Proposal S urn ger Report Date: March 1. 2004 Survey f DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 255.000' Field: Prudhoe Bay Unit - WOA st dy Vertical Section Origin: N 0.000 ft. E 0.000 ft Structure I Slot: Z-PAD / Z-23 FeaslblU TVO Reference Datum: Rotary Table Well: Z-23 TVD Reference Elevation: 82.5 ft relative to MSL Borehole: Plan Z-23B Sea Bed I Ground level Elevation: 54.000 ft relative to MSL UWlfAPI#: 500292195002 Magnetic Declination: 24.982' Survey Name I Date: Z-23B (P5) I March 1. 2004 Total Field Strength: 57568.054 nT Tort f AHD f DDI f ERD ratio: 258.954'/4709.64 ft /6.1631 0.521 Magnetic Dip: 80.805' Grid Coordinate System: NAD27 Alaska State Planes. Zone 04, US Feet Declination Date: June 02. 2004 Location Lat/Long: N 70.29840007, W 149.19453702 Magnetic Declination Model: BGGM 2003 . Location Grid NfE YfX: N 5959360.030 ftUS, E 599459.070 ftUS North Reference: True North Grid Convergence Angle: ;().75831778' Total Corr Mag North -> True North: +24.982' Grid Scale Factor: 0.99991124 Local Coordinates Referenced To: Well Head Comments Tie-In Survey Top Kuparuk Top Whipstock Base Whipstock Crv 4/100 LCU 6871.42 22.31 22.45 6841.54 6759.00 -116.13 312.12 206.35 64.94 4.00 -1.14 -10.04 -105.45G 5959567.20 599521.26 N 70.29896380 W 149.19401119 6900.00 22.03 19.51 6868.01 6785.47 -122.47 322.90 216.41 68.80 4.00 -0.97 -10.28 -102.72G 5959577.32 599524.99 N 70.29899130 W 149.19397992 7000.00 21.49 8.81 6960.92 6878.38 -140.49 359.88 252.20 77.87 4.00 -0.54 -10.71 -92.78G 5959613.22 599533.59 N 70.29908907 W 149.19390647 7100.00 21.65 357.92 7053.96 6971.42 -152.01 396.54 288.75 80.00 4.00 0.16 -10.89 -82.65G 5959649.79 599535.24 N 70.29918891 W 149.19388918 7200.00 22.49 347.50 7146.67 7064.13 -156.97 434.03 325.87 75.19 4.00 0.85 -10.42 -72.99G 5959686.84 599529.93 N 70.29929033 W 149.19392814 End Crv 7248.99 23.14 342.73 7191.82 7109.28 -157.00 453.01 344.22 70.30 4.00 1.32 -9.74 O.OOG 5959705.11 599524.81 N 70.29934044 W 149.19396771 Top Kingak 7603.20 23.14 342.73 7517.54 7435.00 -151.48 592.21 477.13 28.97 0.00 0.00 0.00 O.OOG 5959837.46 599481.73 N 70.29970357 W 149.19430239 TJF 7943.59 23.14 342.73 7830.54 7748.00 -146.17 725.97 604.86 -10.74 0.00 0.00 0.00 O.OOG 5959964.64 599440.33 N 70.30005252 W 149.19462401 TJE 8148.03 23.14 342.73 8018.54 7936.00 -142.99 806.32 681.58 -34.60 0.00 0.00 0.00 O.OOG 5960041.04 599415.46 N 70.30026211 W 149.19481719 TJD 8401.42 23.14 342.73 8251.54 8169.00 -139.04 905.89 776.67 -64.16 0.00 0.00 0.00 O.OOG 5960135.71 599384.64 N 70.30052187 W 149.19505662 . Crv 2.5/100 8493.71 23.14 342.73 8336.40 8253.86 -137.60 942.16 811.30 -74.93 0.00 0.00 0.00 -2.16G 5960170.19 599373.42 N 70.30061648 W 149.19514382 8500.00 23.30 342.71 8342.19 8259.65 -137.50 944.64 813.67 -75.67 2.50 2.50 -0.24 -2.14G 5960172.55 599372.65 N 70.30062295 W 149.19514979 8600.00 25.80 342.50 8433.14 8350.60 -135.76 986.18 853.31 -88.09 2.50 2.50 -0.21 -1.95G 5960212.02 599359.70 N 70.30073124 W 149.19525039 TJC 8637.24 26.73 342.43 8466.54 8384.00 -135.04 1002.65 869.02 -93.05 2.50 2.50 -0.19 -1.89G 5960227.66 599354.53 N 70.30077416 W 149.19529060 8700.00 28.29 342.32 8522.20 8439.66 -133.71 1031.64 896.64 -101.83 2.50 2.50 -0.17 -1.79G 5960255.17 599345.39 N 70.30084963 W 149.19536170 TJB 8759.87 29.79 342.22 8574.54 8492.00 -132.32 1060.70 924.33 -110.68 2.50 2.50 -0.16 -1.71G 5960282.73 599336.17 N 70.30092526 W 149.19543337 8800.00 30.79 342.17 8609.19 8526.65 -131.33 1080.95 943.60 -116.87 2.50 2.50 -0.15 -1.66G 5960301.91 599329.73 N 70.30097791 W 149.19548350 8900.00 33.29 342.03 8693.95 8611.41 -128.64 1134.00 994.08 -133.18 2.50 2.50 -0.13 -1.55G 5960352.17 599312.76 N 70.30111582 W 149.19561558 7"CsgPI 8928.32 34.00 342.00 8717.53 8634.99 -127.83 1149.69 1009.01 -138.03 2.50 2.50 -0.12 O.OOG 5960367.03 599307.72 N 70.30115660 W 149.19565481 End Crv 8928.34 34.00 342.00 8717.54 8635.00 -127.83 1149.70 1009.01 -138.03 2.50 2.50 -0.12 O.OOG 5960367.04 599307.71 N 70.30115662 W 149.19565483 Top Sag River 8928.35 34.00 342.00 8717.55 8635.01 -127.83 1149.70 1009.02 -138.03 0.00 0.00 0.00 O.OOG 5960367.04 599307.71 N 70.30115663 W 149.19565485 Crv 15/100 8948.34 34.00 342.00 8734.12 8651.58 -127.24 1160.88 1019.65 -141.48 0.00 0.00 0.00 177.59G 5960377.63 599304.12 N 70.30118567 W 149.19568282 8961.06 32.09 342.15 8744.78 8662.24 -126.89 1167.82 1026.25 -143.62 15.00 -14.99 1.19 O.OOG 5960384.20 599301.90 N 70.30120371 W 149.19570012 Top Shublik 8967.85 32.09 342.15 8750.54 8668.00 -126.71 1171.43 1029.69 -144.73 0.00 0.00 0.00 O.OOG 5960387.62 599300.74 N 70.30121309 W 149.19570908 Well Design Ver 3.1RT-SP3.03-HF4.00 Bld( do31rt-546) Z-23\Z-23\Plan Z-23BIZ-23B (P5) Generated 3/1/2004 3:58 PM Page 1 of 2 Comments 9000.00 36.39 342.13 8777.18 8694.84 -125.81 1189.40 1046.79 -150.24 15.00 15.00 -0.08 O.OOG 5960404.65 599295.01 N 70.30125983 W 149.19575372 9100.00 51.39 342.08 8849.05 8766.51 -122.31 1258.53 1112.58 -171.49 15.00 15.00 -0.05 O.OOG 5960470.14 599272.89 N 70.30143954 W 149.19592582 TElL 9104.02 51.99 342.07 8851.54 8769.00 -122.15 1261.69 1115.58 -172.46 15.00 15.00 -0.04 O.OOG 5960473.13 599271.88 N 70.30144775 W 149.19593369 Top Sadlerochit 9168.00 61.59 342.05 8886.54 8804.00 -119.41 1315.15 1166.45 -188.93 15.00 15.00 -0.04 O.OOG 5960523.77 599254.74 N 70.30158671 W 149.19606707 9200.00 66.39 342.04 8900.57 8818.03 -117.93 1343.90 1193.80 -197.79 15.00 15.00 -0.03 O.OOG 5960551.00 599245.52 N 70.30166143 W 149.19613884 T45N 9236.41 71.85 342.03 8913.54 8831.00 -116.17 1377.91 1226.14 -208.28 15.00 15.00 -0.03 O.OOG 5960583.20 599234.61 N 70.30174979 W 149.19622378 T45P 9249.99 73.89 342.03 8917.54 8835.00 -115.50 1390.88 1238.49 -212.28 15.00 15.00 -0.03 O.OOG 5960595.49 599230.44 N 70.30178352 W 149.19625621 9300.00 81.39 342.01 8928.24 8845.70 -112.96 1439.70 1284.92 -227.35 15.00 15.00 -0.03 O.OOG 5960641.71 599214.76 N 70.30191037 W 149.19637826 Cry 15/100 9355.41 89.70 342.00 8932.54 8850.00 -110.08 1494.89 1337.41 -244.40 15.00 15.00 -0.03 -90.09G 5960693.97 599197.02 N 70.30205377 W 149.19651635 9400.00 89.69 335.31 8932.78 8850.24 -105.15 1539.48 1378.92 -260.62 15.00 -0.02 -15.00 -90.06G 5960735.26 599180.25 N 70.30216717 W 149.19664774 9500.00 89.69 320.31 8933.32 8850.78 -75.69 1639.48 1463.31 -313.74 15.00 0.00 -15.00 -89.98G 5960818.93 599126.02 N 70.30239770 W 149.19707797 . 9600.00 89.70 305.31 8933.86 8851.32 -22.57 1739.48 1531.07 -386.89 15.00 0.02 -15.00 -89.90G 5960885.71 599051.99 N 70.30258282 W 149.19767043 9700.00 89.74 290.31 8934.34 8851.80 50.58 1839.48 1577.59 -475.08 15.00 0.04 -15.00 -89.82G 5960931.06 598963.19 N 70.30270990 W 149.19838476 9800.00 89.80 275.31 8934.75 8852.21 138.78 1939.48 1599.70 -572.31 15.00 0.05 -15.00 -89.76G 5960951.87 598865.69 N 70.30277028 W 149.19917227 9900.00 89.86 260.31 8935.05 8852.51 236.01 2039.48 1595.89 -671.96 15.00 0.07 -15.00 -89.72G 5960946.75 598766.11 N 70.30275985 W 149.19997927 End Cry 9946.29 89.90 253.37 8935.14 8852.60 282.25 2085.77 1585.36 -717.00 15.00 0.08 -15.00 O.OOG 5960935.62 598721.22 N 70.30273106 W 149.20034408 Cry 10/100 10143.22 89.90 253.37 8935.49 8852.95 479.10 2282.70 1528.99 -905.69 0.00 0.00 0.00 89.04G 5960876.76 598533.31 N 70.30257702 W 149.20187226 10200.00 90.00 259.04 8935.54 8853.00 535.84 2339.48 1515.46 -960.81 10.00 0.17 10.00 89.03G 5960862.51 598478.37 N 70.30254003 W 149.20231868 Tgt 3 10202.45 90.00 259.29 8935.54 8853.00 538.29 5936.77 1515.00 -963.22 10.00 0.17 10.00 90.00G 5960862.01 598475.97 N 70.30253877 W 149.20233818 End Cry 10202.50 90.00 259.29 8935.54 8853.00 538.34 6836.82 1514.99 -963.27 10.00 0.00 10.00 O.OOG 5960862.00 598475.93 N 70.30253874 W 149.20233855 Orp 10/100 10423.05 90.00 259.29 8935.54 8853.00 758.27 7057.37 1474.02 -1179.98 0.00 0.00 0.00 -90.00G 5960818.17 598259.79 N 70.30242673 W 149.20409368 Tgt4 10423.10 90.00 259.29 8935.54 8853.00 758.32 7957.42 1474.01 -1180.03 10.00 0.00 -10.00 -176.72G 5960818.16 598259.75 N 70.30242671 W 149.20409405 10500.00 82.32 258.85 8940.68 8858.14 834.79 8034.09 1459.48 -1255.31 10.00 -9.98 -0.57 -176.70G 5960802.63 598184.67 N 70.30238696 W 149.20470373 10600.00 72.34 258.25 8962.59 8880.05 932.05 8131.53 1440.14 -1350.81 10.00 -9.98 -0.60 -176.56G 5960782.03 598089.44 N 70.30233409 W 149.20547718 10700.00 62.36 257.57 9001.05 8918.51 1024.10 8223.70 1420.85 -1440.94 10.00 -9.98 -0.67 -176.30G 5960761.56 597999.58 N 70.30228135 W 149.20620710 End Orp 10712.97 61.06 257.48 9007.20 8924.66 1035.51 8235.12 1418.38 -1452.09 10.00 -9.98 -0.74 O.OOG 5960758.94 597988.47 N 70.30227461 W 149.20629740 POWC 10732.28 61.06 257.48 9016.54 8934.00 1052.39 8252.02 1414.72 -1468.59 0.00 0.00 0.00 O.OOG 5960755.06 597972.02 N 70.30226459 W 149.20643101 TO I 4-1/2" Lnr 10792.22 61.06 257.48 9045.54 8963.00 1104.80 8304.48 1403.35 -1519.80 0.00 0.00 0.00 O.OOG 5960743.01 597920.97 N 70.30223349 W 149.20684573 Leqal Description: Northinq IY) [ftUS] Eastinq (X) [ftUS] Surface 4560 FSL 3214 FEL S19 T11N R12E UM 5959360.03 599459.07 . Tie-In 4560 FSL 3214 FEL S19 T11N R12E UM 5959360.05 599459.03 Sag T gt 289 FSL 3348 FEL S18 T11N R12E UM 5960367.04 599307.71 Tgl2 617 FSL 3453 FEL 518 T11N R12E UM 5960693.97 599197.02 Tgl3 795 FSL 4171 FEL 518 T11N R12E UM 5960862.01 598475.97 Tgt4 754 FSL 4388 FEL S18 T11N R12E UM 5960818.16 598259.75 TO I BHL : 683 FSL 4728 FEL S18 T11N R12E UM 5960743.01 597920.97 WellDesign Ver 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) Z-231Z-23\Plan Z-23BIZ-23B (P5) Generated 3/1/2004 3:58 PM Page 2 of 2 g o o ~ ~ ~ II ( ) «i () C/) o ç WELL Magnetic Parameters Model" BGGM2003 8600 8800 9000 9200 -400 -400 Z-23B (P5) Dip: 80.805' Mag Dec" +24.982' -200 -23A T~;:9( ~~ Cry Ii ,nn IOO~ "0" ~rv 15/100 Z-23A -200 Data: June 02,2004 FS' 57568.1 nT o 'JC rJB "0 101' :;nuoII' FIELD Prudhoe Bay Unit - WOA II SurfaœLocation Lal N701754.240 Lon: W1491140.333 NAD27 Alaska state AarleS, Zone 04. US Feel Northing: 5959360.03ftU$ GridCoov: +0.75831776' EasUng: 599459.07ftU$ $ca aFact: 0.9999112373 STRUCTURE Z-PAD $101 Z-23 Plan: Z-23B{P5) 1VD Rat" Rotary Table (82.54 II. aboVe MSL) SNyOale: Marcn01.2004 200 400 600 800 1000 TElL EndC/ Cr 10/100/ Tg1/\End C rv Drp 10/100I\Tg14 ~ Cd.Dr~./~ ..-..- PO IC ~ o 200 400 600 800 Vertical Section (ft) Azim = 255°, Scale = 1 (in):200(ft) Origin = 0 N/-S, 0 E/-W 1000 --- 1200 . 8600 8800 ,,.. 9000 . 9200 1200 f'" WEll sTRueruR< Z-P AD ger FiElD Z-23B (P5) Prudhoe Bay Unit - WOA MagneticPararneten; Model' BGGM 2003 Surfacelocalion lat· N701754,240 Lon: W1491140.333 TVD Ref: Rotary Table (82,54 II. above MSl) SrvyData: March01,2004 NA027 Alaska Stale Planes, Zona 04. US Feet Northing: 5959360.03 ftUS Grid Con~: +0,75831778' Eastir.g: 599459.07ftUS Scala Fact: 0.9999112373 Miscellaneous Slot: %-23 Plan: Z-23B{PS} Dip: 80.805' Mag Dee: +24.982' Date: FS June02,2004 57568.1 nT -1200 -800 -400 o 400 800 1600 1600 . 1200 1200 ^ ^ ^ z 4? a 0 ~ ~ ~ II 800 800 Q) (¡; <.> . en en v v v 400 o -1200 -800 -400 o 400 800 400 o · e BPX AK Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation MethodMD Interval: 50.00 ft Depth Range: 6819.00 to 10792.22 ft Maximum RadidDOOO.OO ft Survey Program for Definitive Wellpath Date: 1/21/2004 Validated: No Version: 2 Planned From To Survey Toolcode ft ft 28.54 6800.74 1 : Gyrodata gyrocompassing ml (28.54-95æt{00þÇJ-¡v1S 6800.74 10792.22 Planned: Plan #5 V1 MWD+IFR+MS Casing Points Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Gyrodata gyrocompassing mls MWD + IFR + Multi Station 2647.84 2647.64 13.375 17.500 133/8" 6819.00 6793.84 9.625 12.250 9 5/8" 8927.38 8717.54 7.000 8.500 7" 10792.22 9046.34 4.500 6.125 4 1/2" Summary PBChevTr CHEV181112 CHEV181112V1 PB Z Pad - ExpansiorPlan Ivi Z-19i Plan Ivi Z-19i VO Plan PB Z Pad - ExpansiorPlan Ivi Z-41p Plan Ivi Z-41p VO Plan PB Z Pad - ExpansiorPlan Ivi Z-42p Plan Ivi Z-42p VO Plan PB Z Pad - ExpansiorPlan Ivi Z-43p Plan Ivi Z-43p VO Plan PB Z Pad - ExpansiorPlan Ivi Z-44p Plan Ivi Z-44p VO Plan PB Z Pad - ExpansiorPlan Kup PZ5 Plan Kup PZ5 VO Plan: PB Z Pad - ExpansiorPlan Kup PZ6 Plan Kup PZ6 VO Plan: PB Z Pad - ExpansiorPlan Sch 3-02HAW Plan Sch 3-02HAW VO PI PB Z Pad - ExpansiorPlan Sch 3-03HAW Plan Sch 3-03HAW V1 PI 6847.00 PB Z Pad - ExpansiorPlan Sch 13-07 Plan Sch 13-07 VO Plan 6862.77 PB Z Pad - ExpansiorPlan Sch 13-08 Plan Sch 13-08 VO Plan PB Z Pad - ExpansiorPlan Sch 13-09 Plan Sch 13-09 VO Plan PB Z Pad - ExpansiorPlan Sch 13-11 Plan Sch 13-11 VO Plan PB Z Pad - ExpansiorPlan Sch 13-12 Plan Sch 13-12 VO Plan PB Z Pad - ExpansiorPlan Sch 13-13 Plan Sch 13-13 VO Plan PB Z Pad - ExpansiorPlan Sch 13-14 Plan Sch 13-14 VO Plan PB Z Pad - ExpansiorPlan Sch 13-15 Plan Sch 13-15 VO Plan PB Z Pad - ExpansiorPlan Sch 13-16 Plan Sch 13-16 VO Plan PB Z Pad - ExpansiorPlan Sch 13-17 Plan Sch 13-17 VO Plan PB Z Pad - ExpansiorPlan Sch 13-18 Plan Sch 13-18 VO Plan PB Z Pad - ExpansiorPlan Sch 13-22 Plan Sch 13-22 VO Plan PB Z Pad - ExpansiorPlan Sch P2-07HAW Plan Sch P2-07HAW VO f10450.00 PB Z Pad - ExpansiorPlan Sch P3-04HAW Plan Sch P3-04HAW VO P PB Z Pad - ExpansiorPlan Sch P3-06HAW Plan Sch P3-06HAW VO P PB Z Pad Ivi_Z-19i Ivi_Z-19i VO Plan: Ivi PB Z Pad Plan Ivi Z-19i Plan Ivi Z-19i V1 Plan PB Z Pad Plan Ivi Z-34i Plan Ivi Z-34i VO Plan PB Z Pad Plan Ivi Z-40p Plan Ivi Z-40p VO Plan PB Z Pad Plan Ivi Z-41 p Plan Ivi Z-41 p VO Plan PB Z Pad Plan Ivi Z-42p Plan Ivi Z-42p VO Plan PB Z Pad Plan Ivi Z-43i Plan Ivi Z-43i VO Plan PB Z Pad Plan Ivi Z-44p Plan Ivi Z-44p VO Plan PB Z Pad Plan Ivi Z-45p Plan Ivi Z-45p VO Plan PB Z Pad Plan Ivi Z-46p Plan Ivi Z-46p VO Plan PB Z Pad Plan Ivi Z-47i Plan Ivi Z-47i VO Plan PB Z Pad Plan Ivi Z-48p Plan Ivi Z-48p VO Plan PB Z Pad Plan Ivi Z-49i Plan Ivi Z-49i VO Plan PB Z Pad Plan Ivi Z-50p Plan Ivi Z-50p V1 Plan PB Z Pad Plan Ivi Z-51p Plan Ivi Z-51p VO Plan PB Z Pad Plan Ivi Z-52i Plan Ivi Z-52i VO Plan 9750.00 6819.00 6847.00 6819.00 6819.00 6939.39 6821.21 6819.00 6871.73 6819.00 6847.00 6819.00 6819.00 6819.00 10950.00 817.22 224.16 593.06 11050.00 6965.71 60.93 6904.78 6700.00 3011.11 60.80 2950.31 8600.00 4501.83 63.74 4438.09 7600.00 3766.04 62.25 3703.79 6615.15 1389.07 59.04 1330.03 7050.00 4532.60 82.75 4449.85 8400.00 5392.80 67.00 5325.80 7600.00 5717.25 67.50 5649.75 9550.00 5498.68 85.71 5412.97 10750.00 7105.04 65.72 7039.32 6850.00 3901.93 64.12 3837.81 10100.00 7041.00 66.25 6974.75 6600.00 2576.11 60.03 2516.08 8600.00 4499.45 63.38 4436.07 7550.00 3675.87 62.04 3613.82 11550.00 8298.76 66.88 8231.88 Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range . BPX AK Anticollision Report . PB Z Pad Plan Ivi Z-53p Plan Ivi Z-53p VO Plan Out of range PB Z Pad Plan Ivi Z-54p Plan Ivi Z-54p VO Plan 6844.42 7050.00 618.08 56.43 561.64 Pass: Major Risk PB Z Pad Plan Ivi Z-55p Plan Ivi Z-55p VO Plan 10785.82 11500.00 1178.73 105.14 1073.59 Pass: Major Risk PB Z Pad Plan Ivi Z-57p Plan Ivi 2-57p VO Plan 9875.00 8850.00 1823.24 82.85 1740.39 Pass: Major Risk PB 2 Pad Plan Ivi 2-58i Plan Ivi 2-58i VO Plan 6840.61 6650.00 1152.06 59.49 1092.57 Pass: Major Risk PB Z Pad Plan Iv Plan Iv VO 6819.00 30.00 6809.91 No Offset Stations PB Z Pad Plan Kup P 26 Plan Kup P Z6 VO Plan: 6847.00 7250.00 4520.37 55.03 4465.33 Pass: Major Risk PB 2 Pad Plan Kup 2 IN2 Plan Kup Z IN2 VO Plan 6870.08 7900.00 6415.12 63.36 6351.76 Pass: Major Risk PB 2 Pad Plan Kup Z IN3 Plan Kup Z IN3 VO Plan 6847.00 6550.00 3782.41 56.54 3725.87 Pass: Major Risk PB 2 Pad Plan Kup 2 IN4 Plan Kup Z IN4 VO Plan 10774.89 7050.00 5759.46 74.26 5685.20 Pass: Major Risk PB Z Pad Plan Kup Z IN6 Plan Kup Z IN6 VO Plan 7443.98 7053.53 2523.15 52.58 2470.57 Pass: Major Risk PB 2 Pad Plan Kup Z IN7 Plan Kup 2 IN7 VO Plan Out of range PB 2 Pad Plan Kup Z P1 Plan Kup Z P1 VO Plan: 6884.87 8350.00 6702.49 63.31 6639.18 Pass: Major Risk PB Z Pad Plan'Kup Z P5 Plan Kup Z P5 VO Plan: 6939.40 6587.64 1389.09 60.65 1328.44 Pass: Major Risk PB Z Pad Plan Kup Z P8 Plan Kup 2 P8 VO Plan: 10782.31 7850.00 3779.51 67.38 3712.13 Pass: Major Risk PB Z Pad Plan Kup Z P9 Plan Kup 2 P9 VO Plan: Out of range PB Z Pad Plan Kup Plan Kup VO 6819.00 30.00 6811.82 No Offset Stations PB 2 Pad Plan Sch2 12-19 Plan Sch212-19 VO Pia Out of range PB 2 Pad Plan Sch2 12-20 Plan Sch2 12-20 V1 Pia Out of range PB Z Pad Plan Sch2 12-21 Plan Sch2 12-21 VO Pia Out of range PB Z Pad Plan Sch2 P2-07HAW'lan Sch2 P2-07HAW V010450.00 9250.00 5499.53 84.23 5415.30 Pass: Major Risk PB 2 Pad Plan Sch3 13-07 Plan Sch3 13-07 VO Pia 6865.48 7450.00 5729.26 66.12 5663.14 Pass: Major Risk PB 2 Pad Plan Sch3 13-08 Plan Sch3 13-08 V1 Pia Out of range PB Z Pad Plan Sch3 13-09 Plan Sch3 13-09 VO Pia Out of range PB Z Pad Plan Sch3 13-10 Plan Sch3 13-10 VO Pia Out of range PB Z Pad Plan Sch3 13-11 Plan Sch3 13-11 VO Pia Out of range PB Z Pad Plan Sch3 13-12 Plan Sch3 13-12 V1 Pia Out of range PB 2 Pad Plan Sch3 13-13 Plan Sch3 13-13 VO Pia Out of range PB Z Pad Plan Sch3 13-14 Plan Sch3 13-14 VO Pia Out of range PB Z Pad Plan Sch313-15 Plan Sch3 13-15 VO Pia Out of range PB Z Pad Plan Sch3 13-16 Plan Sch3 13-16 VO Pia Out of range PB Z Pad Plan Sch3 13-17 Plan Sch3 13-17 VO Pia Out of range PB Z Pad Plan Sch3 13-18 Plan Sch3 13-18 V1 Pia Out of range PB Z Pad Plan Sch3 13-22 Plan Sch3 13-22 VO Pia Out of range PB Z Pad Plan Sch3 P3-02HAW'lan Sch3 P3-02HAW VO Out of range PB 2 Pad Plan Sch3 P3-03HAW'lan Sch3 P3-03HAW VO 6847.00 8250.00 5373.59 66.58 5307.00 Pass: Major Risk PB 2 Pad Plan Sch3 P3-06HAW'lan Sch3 P3-06HAW VO Out of range PB Z Pad Plan Sch Plan Shrd VO 6819.00 30.00 6813.78 No Offset Stations PB 2 Pad Plan Z-220 (0.5) Plan Z-220 V1 Plan: PI Out of range PB 2 Pad Plan 2-220 (14.5) Plan 2-220 V1 Plan: PI Out of range PB 2 Pad Plan 2-41 Plan 2-41 V5 Plan: Pia Out of range PB 2 Pad Z-01 Z-01 V1 6819.00 10150.00 5079.85 74.33 5005.53 Pass: Major Risk PB Z Pad Z-02A 2-02A V1 7130.59 8450.00 2428.56 66.34 2362.22 Pass: Major Risk PB 2 Pad Z-02 Z-02 V1 6819.00 8450.00 3070.01 68.97 3001.03 Pass: Major Risk PB 2 Pad Z-03 2-03 V4 6825.00 8400.00 3358.77 71.07 3287.70 Pass: Major Risk PB 2 Pad Z-04 2-04 V1 7346.20 7650.00 2087.51 64.96 2022.55 Pass: Major Risk PB Z Pad Z-05 Plan#3 2-05APB1 VO Pia 10789.41 7700.00 2367.14 91.02 2276.12 Pass: Major Risk PB 2 Pad Z-05 Plan#4 2-05A VO Plan: 10789.41 7700.00 2367.14 91.06 2276.08 Pass: Major Risk PB Z Pad 2-05 2-05 V3 10789.41 7700.00 2367.14 91.02 2276.12 Pass: Major Risk PB Z Pad 2-06 Plan#7 2-06A V3 Plan: Out of range PB 2 Pad Z-06 2-06 V1 Out of range PB Z Pad Z-07A Z-07 A V1 Out of range PB Z Pad 2-07 2-07 V1 Out of range PB 2 Pad 2-08A 2-08A V1 Out of range PB Z Pad Z-08 2-08 V1 Out of range PB Z Pad Z-09 Z-09 V1 Out of range PB Z Pad 2-1 00 Z-100 V7 7200.00 7163.00 1353.46 47.92 1305.54 Pass: Major Risk PB Z Pad 2-101 Plan Z-101A V3 Plan: Z 10550.00 7400.00 5521.76 90.69 5431.07 Pass: Major Risk PB Z Pad 2-101 Plan 2-101APB1 VO Plan 1 0550.00 7400.00 5521.76 90.73 5431.03 Pass: Major Risk PB Z Pad 2-101 Z-101 V5 10650.00 9450.00 4768.71 120.18 4648.53 Pass: Major Risk PB Z Pad Z-10 2-10 V1 Out of range PB Z Pad 2-10 2-10A WPS V1 Plan: Z-1 Out of range PB Z Pad 2-11 2-11 V1 6822.04 8450.00 3126.08 71.03 3055.05 Pass: Major Risk . BPX AK Anticollision Report . PB Z Pad Z-12 Z-12V1 6819.00 10850.00 5773.96 80.42 5693.54 Pass: Major Risk PB Z Pad Z-13 Z-13 V1 6882.19 7200.00 2484.92 81.06 2403.86 Pass: Major Risk PB Z Pad Z-14A Z-14AV1 6847.00 6800.00 1683.48 69.14 1614.34 Pass: Major Risk PB Z Pad Z-14 Plan Z-14B V4 Plan: PI 6847.00 7000.00 2259.26 63.84 2195.42 Pass: Major Risk PB Z Pad Z-14 Z-14 V1 6847.00 6800.00 1683.48 69.25 1614.23 Pass: Major Risk PB Z Pad Z-15 Z-15 V1 6847.00 7050.00 3580.92 92.11 3488.81 Pass: Major Risk PB Z Pad Z-16 Z-16V1 6819.00 11300.00 7319.95 94.03 7225.92 Pass: Major Risk PB Z Pad Z-17 Z-17V1 6819.00 12900.00 8941.81 91.03 8850.78 Pass: Major Risk PB Z Pad Z-18 Z-18 V1 Out of range PB Z Pad Z-19 Z-19 V1 6923.92 7550.00 4685.22 105.90 4579.32 Pass: Major Risk PB Z Pad Z-20 Z-20 V1 6831.08 7350.00 2995.07 126.86 2868.21 Pass: Major Risk PB Z Pad Z-21 Z-21 V3 6915.06 7050.00 2369.88 71.85 2298.03 Pass: Major Risk PB Z Pad Z-21 Z-21A V5 6925.45 7050.00 2372.76 71.81 2300.94 Pass: Major Risk PB Z Pad Z-22A Z-22A V1 10423.05 7350.00 4751.15 118.80 4632.35 Pass: Major Risk PB Z Pad Z-22B Z-22B V1 10423.05 7350.00 4751.15 118.80 4632.35 Pass: Major Risk PB Z Pad Z-22 Z-22 V1 10423.05 7350.00 4751.15 118.80 4632.35 Pass: Major Risk PB Z Pad Z-23 Z-23 V3 6842.58 6850.00 6.04 0.00 6.04 Pass: NOERRORS PB Z Pad Z-23 Z-23A V2 6851.48 6850.00 0.73 0.00 0.73 Pass: NOERRORS PB Z Pad Z-24 Z-24 V1 6879.01 6800.00 1973.90 72.98 1900.92 Pass: Major Risk PB Z Pad Z-25 Z-25 V1 6847.00 6900.00 2374.74 72.79 2301.95 Pass: Major Risk PB Z Pad Z-26 Z-26 V1 6847.00 6900.00 2481.84 73.46 2408.38 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 6944.33 7200.00 3768.52 96.62 3671.90 Pass: Major Risk PB Z Pad Z-28 Z-28 V1 9800.00 9050.00 1704.56 97.25 1607.31 Pass: Major Risk PB Z Pad Z-29 Z-29 V1 9875.00 8200.00 3337.91 102.65 3235.25 Pass: Major Risk PB Z Pad Z-30 Z-30 V7 9875.00 7550.00 4839.78 113.49 4726.29 Pass: Major Risk PB Z Pad Z-30 Z-30A V9 9875.00 7550.00 4840.95 113.59 4727.36 Pass: Major Risk PB Z Pad Z-31 Z-31 V1 10005.96 7350.00 4632.43 1 08.45 4523.98 Pass: Major Risk PB Z Pad Z-32A Z-32A V6 10280.67 8550.00 2468.04 101.00 2367.04 Pass: Major Risk PB Z Pad Z-32BL 1 Z-32BL 1 V2 10280.83 8550.00 2487.00 100.84 2386.17 Pass: Major Risk PB Z Pad Z-32BPB1 Z-32BPB1 V2 10280.83 8550.00 2487.00 100.84 2386.17 Pass: Major Risk PB Z Pad Z-32BPB2 Z-32BPB2 V2 10280.83 8550.00 2487.00 100.84 2386.17 Pass: Major Risk PB Z Pad Z-32BPB3 Z-32BPB3 V2 Plan: Unde10280.83 8550.00 2486.94 100.84 2386.10 Pass: Major Risk PB Z Pad Z-32B Z-32B V2 10280.83 8550.00 2487.00 100.84 2386.17 Pass: Major Risk PB Z Pad Z-32 Z-32 V2 10280.83 8550.00 2487.00 100.84 2386.17 Pass: Major Risk PB Z Pad Z-33 Plan Z-33B V2 Plan: PI 6825.00 8050.00 2146.29 66.15 2080.14 Pass: Major Risk PB Z Pad Z-33 Z-33 V1 6825.00 7750.00 1806.93 53.89 1753.04 Pass: Major Risk PB Z Pad Z-33 Z-33A V1 6825.00 8050.00 2146.29 66.15 2080.14 Pass: Major Risk PB Z Pad Z-35PB1 Z-35PB1 V2 10700.00 8100.00 3406.29 94.21 3312.08 Pass: Major Risk PB Z Pad Z-35 Z-35 V2 10780.56 8750.00 675.81 92.09 583.72 Pass: Major Risk PB Z Pad Z-38PB1 Z-38PB1 V3 Out of range PB Z Pad Z-38 Z-38 V5 Out of range PB Z Pad Z-39 Z-39 V16 6819.00 7400.00 2298.89 64.61 2234.28 Pass: Major Risk 277 ····zoo ·..····100 . 100 200 77 Field: Prudhoe Bay Site: PB Z Pad Well: Z-23 Wellpath: Plan Z-23B 27 90 180 Travelling Cylinder Azimuth (TFOt AZI) [deg] vs Centre to Centre Separation [1 Oûft/in] · . TERRIE L HUBBLE BP EXPLORA 110N AK INC "M d Ch- k" PO BOX 196612 MB 7-5 - astercarec ANCHORAGE, AK 99519-6612 First Na ionalBankAlaska Anchorage, Aì( 99501 MEMO 2;.. ;2..3B I: ¡. 25 2000 bOI: ~~ ¡'l.". b 22 7..1 ¡. 5 5 bll. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME j78t( 2-;23,8 PTD# .Lot¡ -/6~ )( Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new welJbore segment of LATERAL existing well , Permit No, API No. . (If API number Productionsbould continue to be reported as last two (2) digits a function ·of tbe original API number. stated are between 60-69) above. Pll.OT HOLE In accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for wen (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH A)) dry ditch 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 caugbt and ] 0' sample intervals tbrough target zones. 640150 Well Name: PRUDHOE BAY UNIT Z:-23B. ~ Program DEV Well bore seg 0 INC nitial ClassfType DEV 11~ GeoArea 890 Unit 1j~ On/Off Shore Qn__ Annular Disposal 0 - - - Administration Yes - - - - - 2 .Leas.e _number .ap :)rO :!rI<lte Y~s 3 .U.nique welt narn~ .a!1d OUJlJb.er - - - -- ........ Yes - - - - . - - - - - - - - -- - - - - 4 W~II Jocated in_a d.efine.dpool. Y~s 5 WeJlJocaled pr.oper .distance. from drìJIing unilb.ound.a¡:y Y~s 6 WeJlJocat~d Proper .distance. from otber wells. . . . Y~s - - - - - 7 S.ufficient .acreageayailable in.dri[liog unit. . _ Yes 8 Kdeviated. is. weJlbore pl¡¡Ul'Jclu_ded . . · Y~s - - - - - 9 .Operator Only affected party. . . - - - - - Y~s - - - - 10 .Operator bas.apprppriateJ~o!1d tnJorç~ . . . . . . . . . . - - - - - ...__...Yes - - - - - - - - - - - - - - - - - - - - 11 Permil cao be issl!ed witbout co.nservatiol'J order. . Y~s - - - - Appr Date 12 P.e(ll)il ca!1 be issued witbout ê1Idmil'JistratilleapprovaJ . . Y~s RPC 6/17/2004 13 Can permit be approved before 15-day wait Yes . 14 Well Jocated within area and.strata .authortzed byJ!1jectiolJ Ord.er # (putlO# in c.o(f1rn.e!1ts) (For NA - - -- - - - - 15 .AJlwells.wit!'1in.1l4.l'Uile.ar~a.ofreyieW id~otlfjed (ForsefVj~w.ell only). . . . . . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - -- 16 Pr~-produ.ced i!1jector; .dur.ation.of pre-production I~s$. than 3 montbs. (For.service well only) . . .NA - - - - - - - - - - - 17 AÇMP Fjnding .of Con.si~te!1CY. has been i$.sued. for. tbis pr.ojecl . NA - - Engineering 18 .C.o!1ductor string.prov[ded . NA 19 .Sudaœ .ca$.ing prQtect$. alLknown_ USQWs . NA 20 .CMT vol adequate. to çirc.utate.on .cQl'Jd.uctor & SUJ(csg . . NA 21 .CMT v_ol adeQu.ateto tie-tnlong .string to.sud ~g. . . . . · NA 22 CMT will coyer _all !<l'Jow.npro.ductiye borizOlls. - - - - - · Yes 23 C.asing d~signs ê1Id.eQua.t~ for CoT. B&. perl'Uafr.osl . . . · Yes - - -- 24 .Adequ.ateJankageoJ reser:ve pit. . Y~s Doyoo :16.. . 25 Jtue-drilL bas_a 1.0-4.03 for <lbandonme.nt been ¡¡PPJoved _ . . _ Yes 6/:16/2004.. . 26 A.dequate w.ellbor~ separatio.n proposed. . . . . . . . . . . . . . . . . . . .. Y~s - . - - - - - - - - - - - - - - - - - - 27 Jtdivecter Jeq_uired, does it meet reguJations. . .NA Sidetrack.. . Appr Date 28 ÐJilling fluid. program schematic&' ~quiplisladequat~. . . . · Y~s Max MW to.6.ppg.. . . WGA 6/18/2004 29 BOPEs..do they meet reguJatiol'J . . . . Yes . 30 .BOPEpress rating appropriate;te.st toJput psig in.comments} . . . · Yes Test 1.03500 psLMSF' 2936 psi._ 31 CMkel'Uanifold cQmpJies w/APtRF'-53. (May 84) . - - - - · Yes 32 WQrk will occur withoutoper¡¡tion _shutdown. . Yes 33 .1& :)re&ence. of H2S gas. prohable . No 34 Meçt]a.n[calcooditlo!1 of wells within AOR yerifiecl (for. service welJ only) NA - Geology 35 P~rmit ca!1 be issued wlQ hydrogen s.ulfide meê1ls.uces. . . No 36 .D.ata.preseoted on. pote.ntial oveJpres.sl.lre .zone~. . · NA Appr Date 37 .Seismic.analysis. Qf sbaJlow gaszooes. . . NA RPC 6/17/2004 38 .S~abed .conditiolJ survey.(if off-sh.oce) _ . NA - - - - - 39 . CQnta_ct namelp!'1oneJorweekly prpgre&s.reports [exploratoryo!1ly] · NA - - - Geologic Date: Engineering Date Commissioner: Commissioner: .e $JJ 6 JI ~ J <1- z¡;;~
