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193-181
' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM N WELMPLETION OR RECOMPLETION REP AND LOG 1a. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned l . Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Ii Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,of iband.:) 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 8/20/2015 - \ 193-181 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/8/1993 50-029-22424-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12/20/1993 PBU R-35 Surface: 608'FSL,826'FWL,Sec.32,T12N,R13E,UM • 17. Field/Pool(s): 9. KB(ft above MSL): 54.8' Top of Productive Interval: 1792'FSL,1949'FWL,Sec.33,T12N,R13E,UM GL(ft above MSL): 20.2' PRUDHOE BAY,PRUDHOE OIL • Total Depth: 1836'FSL,2075'FWL,Sec.33,T12N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 11807'/8899' ADL 028279&028278 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 634478 .y- 5977074 • Zone - ASP 4 . 12088'/9156' • TPI: x- 640854 y- 5978376 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 640980 y- 5978422 Zone - ASP 4 None 1900(Approx.) 5. Directional Survey: Yes 0 (attached) No 10 13. Water Depth.if Offshore: 21. Re-drillLateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 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 RLL/GR/MWD RECEIVED 23. SEP 112015 CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECAOGCC AMOUNT TOP BOTTOM TOP BOTTOM PULLED 20" 91.5# H-40 37' 116' 37' 116' 30" 280 cu ft Class'G'(Approx.) 10-3/4" 45.5# NT-80 36' 3128' 36' 3063' 13-1/2" 1920 cu ft CS III,431 cu ft Class'G' 7-5/8" 29.7# L-80 35' 12079' 35' 9148' 9-7/8" 878 cu ft Class'G',150 Bbls Class'G' 24. Open to production or injection? Yes 0 No RI 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 11639' 11465'/8590' f i , 11578'/8690' "" 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DA i Was hydraulic fracturing used during completion? Yes 0 No RI. Per 20 AAC 25.283(i)(2)attach electronic and printed information s, iE NOV 1 6 2015 1 �� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11866' Set Posiset Plug 11853' -12'Cement 11807' 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(corr): Press 24 Hour Rate ...O. Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only I' q/1�/ r(,,*--- RBDMS EP 15 2015 �/• 9' '�� 28. CORE DATA Conventional Core(s) Yes 0 No 0 • Sidewall Cores Yes 0 No 0 If Yes to either question,list formations and interva 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 TVD Permafrost-Top Well Tested? Yes 0 No 2 - Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Sag River 11755' 8851' AAC 25.071. Shublik 11804' 8898' Sadlerochit 11895' 8979' • Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well 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: Boltz,Travis Email: Travis.Boltz@bp.com Printed Name: Joe Lastuf,a A AI Title: Drilling Technologist Signature: Phone: +1 9075644091 Date: I/t f I/5 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 AAC 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 AAC 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 AAC 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 5/2015 Submit ORIGINAL Only • • R-35, Well History (Pre-Rig Sidetrack) „w DRIFTED WITH 20'x 3.70" DUMMY WHIPSTOCK, 2-1/2" SAMPLE BAILER TO 11,899' SLM/ 11,921' ELM (Perf Interval 11,770- 11,989 has—18' of cover and —151' of open perf). RAN DUAL SBHPS GAUGES, 4-1/2"TEL PER PROGRAM, LOC TT @ 11612' SLM/11634' ELM (22' CORRECTION TO ELMD). SET 4-1/2"WHIDDON ON XN NIP @ 11,594' SLM. PULLED BK-LGLV FROM STA#3 @ 6780' SLM/6794' MD. PULLED BK-LGLV FROM STA#4 @ 3355' SLM/3370' MD. SET BK-DGLV IN STA#4 @ 3355' SLM/3370' MD. MAKE TWO ATTEMPTS TO SET BK- DGLV IN STA#3. BRUSHED MANDREL AND POCKET W/4-1/2" BLB, 4-1/2" OK-1, 1" POCKET 7/8/2015 POKER W/TT PINS. T/1/0= 1480/1440/3 Temp= S/I Assist Slick line with Load and Test. Pumped 5 bbls Meth spear followed by 214 bbls of Crude down IA to load, Pumped 18 bbls Crude down IA to assist SLB set 7/8/2015 DGLV. T/I/O = 1500/1530/0. Temp= SI. IA FL. (SL request). ALP=2000 psi, AL SI @ casing valve. IA 7/8/2015 FL @ 6794' (Sta#3 SO, 180 bbls). SLB SL in control of well on departure. SET BK-DGLV IN STA#3 ©6,780' SLM /6,794' MD. LRS PERFORMED A PASSING MIT-IA TO 7/9/2015 3,000 psi. PULLED EMPTY 4-1/2"WHIDDON FROM 11,594' SLM. (SLB ELINE- MILL/XFLOW/POSISET/CEMENT DUMP/WHIPSTOCK). INITIAL T/I/O = 1650/440/0 7/9/2015 PSI. MIRU. WELLTEC PERFORM TOOL CHECKS. PERFORM SURFACE CHECKS. Assist Slickline (Set DGLV) MIT-IA @ 3000psi ***PASS*** Pumped 12 bbls crude to assist SLB set DGLV(44 bbls total) Pumped 15.54 bbls Crude down IA to achive test pressure. 1st 15 min loss of 80 IA psi, 2nd 15 min. loss of 21 IA psi, for a total loss of 101 IA psi. ***PASS***. Bled 12 bbls crude back to 300 IA psi. Notify Pad-OP, hang AFE sign &caution tags, FWHP= 1578/300/3 7/9/2015 SLB on well upon departure. (SLB ELINE- MILL/XFLOW/POSISET/CEMENT DUMP/WHIPSTOCK). WELLTEC SURFACE CHECKS COMPLETE. PT. RUN 1: RIH WITH WELLTEC MILL. CCL TO BIT=26.5'/ANCHORS TO BIT= 15.5'/BIT OD= 3.807"/LOST COMMUNICATION WITH TOOL. POOH. RUN 2: RIH WITH WELLTEC MILL. CCL TO BIT=26.5'!ANCHORS TO BIT= 15.5'/BIT OD = 3.807"/MILL AND PASS THROUGH NIP AT 11623' CLEANLY/ FINAL BIT OD = 3.806. RUN 3: RIH WITH CROSS FLOW TOOLSTRING/OAL = 34'/OAW= 265LB/MAXOD = 1.69"/60 FPM UP/DOWN PASSES/ NO CROSS FLOW DETECTED/TAGGED 11879'. RUN 4: RIH WITH POSISET PLUG/ OAL=41'/OAW=272LB/MAXOD = 2.125"/CCL TO TOP ELEMENT= 23.5'/CCL TO BOTTOM TOOL= 32.35'/CCL TO TOP ELEMENT =23.5'/CCL STOP DEPTH = 11842.5'/TOP OF PLUG SET AT 11866'/CORRELATED TO ATLAS GR/CCL LOG DATED 29-JAN-1994. POSISET MOTOR HAD A SHORT 52MIN INTO SETTING. TROUBLESHOOTING INDICATED SHORT DOWNHOLE. UNABLE TO MOVE DOWNHOLE INDICATING BOTTOM ANCHORS SET FULLY. 7/10/2015 WAITING FOR PERMISSION TO SHEAR OFF PLUG. (SLB ELINE - MILL/XFLOW/POSISET/CEMENT DUMP/WHIPSTOCK). RUN 4 (CONTINUED) : SHEARED OFF POSISET. RUN 5 : RIH WITH DUMP BAILER#1. DUMP CEMENT 10'ABOVE PLUG. RUN 6 : RIH WITH DUMP BAILER#2. CEMENT DID NOT RELEASE. RUN 7 : RIH WITH DUMP BAILER#2 SECOND ATTEMPT. DUMP CEMENT 10'ABOVE PLUG. RUN 8 : RIH WITH DUMP BAILER#3. DUMP CEMENT 10'ABOVE PLUG. RUN 9 : RIH WITH DUMP BAILER#4. DUMP CEMENT 10'ABOVE PLUG. RUN 10 : RIH WITH DUMP BAILER#5. DUMP CEMENT 12' 7/11/2015 ABOVE PLUG. TOP OF CEMENT @ 11853'. RUN 11: RIH WITH WHIPSTOCK. (SLB ELINE-MILL/XFLOW/POSISET/CEMENT DUMP/WHIPSTOCK). SET TOP OF BAKER WHIPSTOCK AT 11805' (3 DEG LOHS ORIENTATION). TWO RA PIP TAGS INSTALLED 8.6' FROM TOWS PUTTING THEM @ 11,796.4' ELMD. CORRELATED TO ATLAS GR-CCL LOG DATED 29-JAN-1994. WELL SHUT-IN UPON DEPARTURE- DSO NOTIFIED OF STATUS. 7/12/2015 FINAL T/I/O = 1460/400/0 PSI. 7/15/2015 Was not able to do job due to RAP not being signed by AA. T/I/O=0/0/0. Pre CTD. Set 4"TWC#293, Install TS-01 and PT to 5000 psi. Final WHP's TWC/300!0. 7/16/2015 Drill: Perform H2S drill with crew and foreman. • S R-35, Well History (Pre-Rig Sidetrack) T/I/O =TWC/160/0. Temp = SI. Bleed WHPs to 0 psi (Pre CTD). Wellhouse and scaffold removed, flowline and AL disconnected. Bled IAP from 160 psi to 0 psi in 2 hrs (1.5 bbls) and held open bleed 7/29/2015 on IA for 2 hrs. Final WHPs = TWC/0/0. SV, WV= ? MV, SSV= C. IA, OA= OTG. 16:30 hrs. :T/I/O =TWC/65/3. Temp= SI. WHPs (pre rig). Scaffold, wellhouse, flowline&AL line removed. 7/30/2015 "SV, WV, SSV, MV= C. IA&OA= OTG. 11:45. T/I/O= TWC/260/3. Temp=Sl. Bleed WHPs to 50 psi or less (Pre Rig). No wellhouse, AL, scaffold or flowline. IA FL near surface. Bled IA from 260 psi to 0+ psi (all gas)to slop tank in 1.75 hrs. Monitored for 30 mins. IAP increased 16 psi. Final WHPs=TWC/16/3. SV=Unk. WV& 8/17/2015 SSV=LOTO. MV=O. IA& OA=OTG. 0100 hrs (8/18/15). i • North America-ALASKA-BP Page 1 ceY Operation Summary Report Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4.687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor:NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 8/18/2015 00:00 - 03:30 3.50 RIGD P PRE RELEASED FROM R-39AL1 AT 23:59 HRS ON 08/17/2015 RIG DOWN CELLAR AND PREPARE TO MOVE RIG TO R-35 03:30 - 04:30 1.00 MOB P PRE MOVE RIG FROM R-39AL1 TO R-35 AND SPOT OVER THE WELL. RIG OVER THE WELL AND ACCEPTED AT 04:30HRS 04:30 - 09:30 5.00 RIGU P PRE RIG UP CELLAR AND HARD LINE TO FLOW BACK TANK -PJSM AND PRESSURE TEST HARDLINE. -GREASE ALL THE VALVES. OPEN THE SSV AND INSTALL THE FUSIBLE CAP. LEAK TIGHT TEST AND NIPPLE DOWN TREE CAP. 09:30 - 10:30 1.00 BOPSUR P PRE HOLD PJSM AND NIPPLE UP BOP 10:30 - 11:00 0.50 BOPSUR P PRE HOLD RIG EVACUATION DRILL AND AAR 11:00 14:30 3.50 BOPSUR P PRE PREP 2-3/8"COIL -CHANGE GRIPPER BLOCKS FOR 2-3/8"COIL AND STAB STUFFINGS BOX -PULL CABLE BACK THROUGH INJECTOR AND BACK TO REEL -INSTALL AND TEST GRAPPLE,PULL COIL ACROSS RIG FLOOR;ADJUST GOOSENECK AND SECURE END OF COIL 14:30 - 15:30 1.00 BOPSUR P PRE SHELL TEST BOP -HOLD PJSM AND MAKE UP NIGHT CAP -FLUID PACK AND TEST BOP TO 250 PSI LOW /4500 PSI HIGH FOR 5 MINUTES 15:30 - 18:00 2.50 BOPSUR P PRE PRESSURE TEST BOP -TEST BOP PER NORDIC,BP AND AOGCC TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES "•AOGCC REP JEFF JONES WAIVED WITNESS VIA EMAIL ON 8/18/2015 AT 0645"*" 18:00 - 00:00 6.00 BOPSUR P PRE CONTINUE PRESSURE TESTING BOP -CREW CHANGE;HOLD PJSM AND DISCUSS PRESSURE CROSSCHECK CARD PRIOR TO HANDING OVER OPERATIONS TO ONCOMING DRILLER -CONTINUE TESTING BOP PER NORDIC,BP AND AOGCC TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -PERFORM ACCUMULATOR DRAWDOWN TEST 8/19/2015 00:00 - 01:30 1.50 BOPSUR P PRE CONTINUE PRESSURE TESTING BOP I-CONTINUE TESTING BOP PER NORDIC,BP AND AOGCC TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -FILL COIL WITH 58 BBLS FRESH WATER 01:30 - 02:15 0.75 BOPSUR P PRE PERFORM E-LINE SLACK MANAGEMENT -HOLD PJSM AND BOOT E-LINE Printed 8/31/2015 10:34:47AM • North America-ALASKA-BP Page 2 prey Operation Summary Report Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor:NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.8ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 02:15 03:15 1.00 BOPSUR P PRE 'PRESSURE TEST INNER REEL VALVE, PACK-OFF AND INNER REEL IRON -STAB ON INJECTOR,PRESSURE TEST INNER REEL VALVE AND PACK-OFF TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 03:15 - 06:00 2.75 BOPSUR P PRE PERFORM E-LINE SLACK MANAGEMENT -PUMP SLACK BACK TO REEL `-RIG UP HYDRAULIC CUTTER AND CUT 300' COIL -MU CTC AND NOZZLE TO PUMP SLACK FOWARD -STAB ON INJECTOR AND PUMP SLACK FORWARD -TEST ELINE AND HEAD UP 06:00 - 06:10 0.17 BOPSUR P PRE CREW CHANGE 06:10 - 06:20 0.17 BOPSUR P PRE HOLD PJSM TO PT THE CTC&UQC 06:20 - 07:10 0.83 BOPSUR P PRE VERIFY PUMP LINE UP WITH PRESSURE CROSSCHECK LIST PT THE CTC AND UQC GOOD PT PT THE DFCVS HOLD PJSM WITH VALVE CREW TO CHECK TREE BOLTS 07:10 - 07:40 0.50 BOPSUR P PRE GOOD PT,RD TEST EQUIPMENT TREE BOLTS CHECKED AND ALL GOOD,NO LOOSE BOLTS 07:40 - 08:10 0.50 BOPSUR P PRE HOLD PJSM WITH VC TO LOAD EQUIPMENT ON RIG AND PULL TWC 08:10 - 09:00 0.83 BOPSUR P PRE LOAD VC EQUIPMENT ON THE RIG TO PULL TWC VALVE CREW CHANGE OUT,HOLD PJSM WITH DAY CREW 09:00 - 10:00 ' 1.00 BOPSUR P PRE RU PULLING TOOLS ENGAGE TWC EQUALIZE VALVE 1955 PSI WHP PULL TOOLS ABOVE THE SWAB CLOSE THE MASTER&SWAB AND BLEED OFF TO THE TIGER TANK 10:00 - 10:30 0.50 BOPSUR P PRE LOAD OUT VC EQUIPMENT 10:30 - 10:45 0.25 BOPSUR P PRE INSTALL NIGHT CAP AND TEST 10:45 - 11:00 0.25 BOPSUR P PRE HOLD PJSM TO BH KILL THE WELL 11:00 - 11:15 0.25 BOPSUR P PRE LINE UP TO METHANOL PUP Printed 8/31/2015 10:34:47AM • • • North America-ALASKA-BP Ease 3 Operation Summary Report Common Well Name.R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor:NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:15 - 13:30 2.25 BOPSUR P PRE SET PUMP TRIPS TO 3500 PSI ONLINE WITH 10 BBLS OF NEAT METHANOL FOLLOWED BY 290 BBLS OF 118°1%KCL 185 BBLS OF MUD RATE=5.0 BPM 00 BBLS AWAY WHP=1951 PSI IAP=101 PSI I OAP=18 PSI 40 BBLS AWAY WHP=1540 PSI IAP=133 PSI OAP=18 PSI 100 BBLS AWAY WHP=531 PSI IAP=178 PSI OAP=20 PSI 140 BBLS AWAY WHP=30 PSI IAP=181 PSI OAP=20 PSI 180 BBLS AWAY WHP=4 PSI IAP=157 PSI OAP=20 PSI KCL AT THE TOP PERF 290 BBLS AWAY WHP=1 PSI IAP=142 PSI OAP=20 PSI 12:20 SWAP TO MUD 60 BBLS AWAY WHP=0 PSI IAP=105 PSI OAP=20 PSI 170 BBLS AWAY WHP=43 PSI IAP=83 PSI OAP=20 PSI REDUCE RATE BEFORE MUD GETS TO THE PERFS '185 BBLS AWAY REDUCE THE PUMP RATE AND OPEN THE CHOKE NO RETURNS AT 1 BPM,INCREASE RATE TO 2.5 BPM 13:30 - 13:35 0.08 1 BOPSUR P PRE WHEN WE ARE PUMPING THE WELL IS ON A VAC,SHUT DOWN THE PUMP AND GET POSITIVE PRESSURE COMING OUT OF THE WHITEY VALVE ON THE FLOOR THEN STOPS LIKE THE FLUID LEVEL HAS DROPPED ENOUGH TO BE BALANCED WITH THE FORMATION. TURN ON THE CHARGE PUMP AND WELL GOES RIGHT ON A VAC,SHUT DOWN THE PUMP AND STARTS BLOWING THEN STOPS AND NOTHING CALL ODE 13:35 - 13:50 0.25 BOPSUR P PRE ONLINE AT MAX RATE TO ESTABLISH A LOSS RATE PUMPS AT 8.0 BPM WE ARE STARTING TO GET RETURNS&WHP IS CLIMBING,OUT RATE LEVELED OFF AT 3.12 BPM REDUCE RATE TO 7 BPM OUT RATE AT 2.85 BPM AT 60 PSI WHP 3.12 BPM IN 0.42 BPM OUT 2.64 BPM LOSS RATE =158.4BPH Printed 8/31/2015 10:34:47AM • :p F,' / ff r '�g,%r'" rf X,r ifs ri' /ar r.��.. s ,' ,�r r r,�..f y •r .�",',7"rrsF r, r,r+//11,x,^ r Y'- F ✓:yi"�� .' :F � f�F Jar v' � r �jl%r � �r/fir ��! pgf ,'.' i.:.� /i/�r� ✓��,,F,!.�j"fi Fr'' r...+,;�,�F',%' '�"i:f �y� %A� /+/���,.' ,i /.:... �r uy l gA' ""' r: 'f' r f.'1 :f :tF ,' .: r '.':v -` fr � ..5, .,jam. /! �+:'/F'.. Uir ;,; f ,.:f/ �,r✓r,� ,,��`I'f�` r f 3�f.r /f �,,::l F l�r F �, Jlf1'+, r�`r` � �'��!;�/`!%� . 1/. ,',:;� r-.r:i it r �` r'fr t,' ,,`myµ F :" �" a �`t /rf "itr {�,1 wy4 ,; r. �,- /.p ! i/ 'sl s,F,:,!f// /,r,+ "r`,�,pc ,; ,'`",s' ,+�1,t� ;. ','Fj/�F,/ 'i� ''/,�, ;r/r ,�, ,�;�.�,��;, f�rf�, ,, s �''� d Operation Summary Report ,, /, /, , Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:50 - 22:30 8.67 BOPSUR N DPRB PRE SHUT DOWN PUMP AND SHUT IN WELL, ESTABLISH FLUID SUPPORT FOR HIGH VIS KCL AND WAIT ON OCN FOR A POLYSWELL PILL BEFORE CONTINUING OPERATIONS SEND 2 TRUCKS ON LOCATION USED FOR THE BH KILL TO THE HOT WATER PLANT NO OTHER TRUCKS AVAILABLE,BUT WE ARE IN LINE FOR THE NEXT 4 AVAILABLE RT TIMEX LOSS RATE=BBLS PUMPED/290 =TRUCKS PUMPED 240 MIN 2.90 BPM = 696 BBLS /290 =2.40 TRUCKS PUMPED WHILE ROUND TRIPPING EACH TRUCK THE 4th TRUCK WOULD HAVE 0.60 BBLS OR 174 BBLS ON IT WHEN EACH TRUCK RETURNS NEED 4 TRUCKS PLUS 2,6 TRUCKS TO SUPPORT OUR OPERATION 2 MORE PEAK TRUCKS AVAILABLE BUT MI IS RUNNING OUT OF WATER,RT PEAK TRUCKS 'OBTAIN APROVAL TO PROCEED WITH LEVEL 2 OCN 22:30 - 23:00 0.50 BOPSUR N DPRB PRE HOLD PJSM WITH NORDIC,SCHLUMBERGER AND MI;DISCUSS BULLHEAD KILL,OCN#1, MIXING OPTIONS AND WELL CONTROL WHILE BULLHEADING POLYSWELL. 23:00 - 00:00 1.00 BOPSUR N DPRB PRE BULLHEAD KILL&LCM PILL,PER OCN#1 -SET TRIPS TO 3500 PSI -ONLINE WITH 5 BBLS OF NEAT METHANOL FOLLOWED BY -280 BBLS OF 100°,1%KCL AT 5 BPM -25 BBLS POLYSWELL PILLAT 3 BPM -159 BBLS 1%KCL AT 3 BPM -CATCH-50 PSI AT 60 BBLS AWAY -0 BBLS AWAY WHP=0 PSI IAP=120 PSI OAP=18 PSI -50 BBLS AWAY WHP=0 PSI IAP=140 PSI OAP=18 PSI -100 BBLS AWAY WHP=285 PSI IAP=146 PSI OAP=18 PSI Printed 8/31/2015 10:34:47AM S -,./;(7 ,;,*.e/1.01;17.,le,"*" :At0-E0**iaijiOwtAVAtf',v,4i,'Se,/, /-707;*04,..#4/V4' 4,43/3"4"/A /// "7/4 : •;*,- •-•<• • ;" • •" :••• •,•'•'•• • g`; • •'•b•, , •4': <';';Y , , ,44.7 4'; ;0,1, Operation Summary Report Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor:NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/20/2015 00:00 - 01:30 1.50 BOPSUR N DPRB PRE CONTINUE BULLHEAD KILL&LCM,PER OCN #1 -150 BBLS AWAY WHP=655 PSI IAP=139 PSI OAP=18 PSI -200 BBLS AWAY WHP=895 PSI IAP=127 PSI OAP=18 PSI -250 BBLS AWAY WHP=915 PSI IAP=121 PSI OAP=18 PSI(CUT AND MIX 9 SACKS OF 55 LB/BBL POLYSWELL) -280 BBLS AWAY WHP=925 PSI IAP=119 PSI OAP=18 PSI F 00:40 SWAP TO POLYSWELL(25 BBLS) SPOT POLYSWELL AT TOP PERF WITH 159 BBLS,1%KCL,AT 5 BPM -50 BBLS AWAY WHP=685 PSI IAP=112 PSI OAP=18 PSI 100 BBLS AWAY VVHP=905 PSI IAP=110 'PSI OAP=18 PSI -150 BBLS AWAY WHP=952 PSI IAP=109 PSI OAP=18 PSI -184 BBLS AWAY WHP=960 PSI IAP=109 PSI OAP=18 PSI(LEADING EDGE OF :POLYSVVELLAT TOP PERF) 01:30 - 02:30 1.00 BOPSUR N DPRB PRE ASSESS LOSS RATE WITH LCM PILL SPOTTED AT TOP PERF -SHUT DOWN PUMPS AND TRAP-400 PSI WHP;OPEN CHOKE,BLEED PRESSURE AND CIRCULATE ACROSS THE TOP FROM PIT 1 -PVT START=81 BBLS AT 0130;INITIAL LOSS RATE WITH LCM AT PERFS IS SLIGHTLY OVER 1 BPM -PVT END=40 BBLS AT 0230;LOSS RATE AFTER 1 HOUR-0.5 BPM -HOLD PJSM FOR MAKING UP 3.8"MILLING ASSEMBLY 02:30 - 03:00 0.50 STMILL P WEXIT MAKE UP 3.8"MILL ASSEMBLY -MILLS GAUGE 3.79 NO-GO -MAINTAIN HOLE FILL WITH CHARGE PUMP; LOSS RATE<0.5 BPM -MAKE UP MILL BHA ,03:00 - 03:45 0.75 STMILL P WEXIT E-LINE SLACK MANAGEMENT -STAB ON INJECTOR,CIRCULATE 1X COIL VOLUME(57 BBLS)THROUGH EDC FOR SLACK MANAGEMENT ON INITIAL RIH -PRESSURE TEST QTS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES WHILE CIRCUALTING -LOSS RATE CONTINUES TO IMPROVE;IN/ OUT RATE=2.70/2.62 BPM WHILE CIRCULATING AT SURFACE FOR SLACK MANAGEMENT Printed 8/31/2015 10:34:47AM • • North America-ALASKA-BP Page 6 pQt6a' Operation Summary Report Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor:NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:45 06:00 2.25 STMILL P WEXIT RIH WITH MILL ASSEMBLY -CLEAN OUT PIT 1 FOR KCL RETURNS WHILE TRIPPING -RIH WITH MILL ASSEMBLY AT 100 FPM IN/OUT RATE=1.47/2.00 BPM -OUT RATE DROPS TO 1.6 BPM AT 2400', PICKS UP AND DROPS AGAIN AT 5000';LOSE FULL RETURNS AT 5200',LINE UP TO FILL 'ACROSS THE TOP AND OUT RATE PICKS UP TO-0.4 BPM PRIOR TO LINING UP;CONTINUE RIH CIRCULATING THROUGH COIL WITH-1 BPM LOSS RATE 06:00 - 07:45 1.75 STMILL P WEXIT LOG TIE IN 07:45 - 08:05 0.33 STMILL P WEXIT GEO CAN'T PICK TIE IN,WILL HAVE TO LOG THE SAG WITH THE DRILLING BHA RIH TO TAG PINCH POINT TAG AT 14813.8'(TOWS 6.8'UP)TOWS AT 11807'UNCORRECTED 1641,4 t 08:05 - 11:25 3.33 STMILL P WEXIT TAG PINCH(_OINT,START MILLING • 11:25 - 14:30 3.08 STMILL P WEXIT JUST GOT OWS TO OPEN CONTINUE MILLING WINDOW FREE SPIN=2714 PSI AT 2.69 BPM RATE IN=2.71 BPM RATE OUT=1.95 BPM LOSS RATE=0.76 BPM OR 45.6 BPH MW IN=8.48 PPG MW OUT=8.42 PPG ECD =9.63 PPG ROP=1 FPH WOB=3.72 K CIRC PSI= 2809 PSI IAP=181 PSI OAP=20 PSI 14:30 - 16:20 1.83 STMILL P WEXIT LAST TENTH TO 11819.0 GETTING MORE MOTOR WORK AND WOB WENT FROM 2.0K TO 4.5K WOB SLOWLY MILLED OFF OVER 20 MINUTES MIGHT HAVE EXITED EARLY 16:20 - 16:30 0.17 STMILL P WEXIT MILLED TO PROPOSED FULL WINDOW DEPTH STILL SHOWING DECENT WOB AND MOTOR WORK 16:30 - 16:50 0.33 STMILL P WEXIT GAVE IT ANOTHER TENTH AND WOB INCREASED TO 1.2K THEN DROPPED OFF TO 0.9KAND WE LOST-300#OF MOTOR WORK LOOKS LIKE THE BOTTOM OF THE WINDOW 16:50 - 18:00 1.17 STMILL P WEXIT GETTING INCREASE IN MOTOR WORK LOOKS LIKE THE STRING MILL IS CLEANING UP THE _-_ BOTTOM OF THE WINDOW 18:00 - 19:45 1.75 STMILL P WEXIT MILL RAT HOLE FROM 11,820'TO 11,830'; SAMPLE FROM 11,827'CONFIRMS OPEN TO FORMATION 19:45 - 22:00 2.25 STMILL P WEXIT REAM/DRIFT WINDOW -BACK REAM AND MAKE THREE UP/DOWN PASSES AT 1 FPM -WINDOW APPEARS CLEAN WITH NO MOTORWORK DRY DRIFT WINDOW AND PREP PITS FOR TRIP OUT OF HOLE Printed 8/31/2015 10:34:47AM • S North America-ALASKA-BP Page 74121a Operation Summary Report Common Well Name:R-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/18/2015 End Date:8/25/2015 X3-0176H-C:(4,687,610.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:NORDIC 1 Spud Date/Time:12/8/1993 12:00:00AM Rig Release:8/28/2015 Rig Contractor NORDIC CALISTA UWI:500292242400 Active datum:R-35 OKB @54.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 00:00 2.00 STMILL P WEXIT PULLOUT WITH MILL ASSEMBLY -FLOW CHECK,OPEN EDC,PULL INTO 1 TUBING AND POH AT 100 FPM -IN/OUT RATE=3.66/2.90 BPM -IN/OUT DENSITY=8.56/8.54 PPG 8/21/2015 00:00 - 00:45 0.75 STMILL P WEXIT POH WITH 3.8"MILL ASSEMBLY -TAG UP AND FLOW CHECK;HOLD PJSM FOR HANDLING BHA 00:45 - 01.30 0.75 DRILL P PROD1 HANDLE BHA -POP OFF INJECTOR,LAY DOWN MOTOR AND GAUGE MILLS,3.79 NO-GO PICK UP 2-7/8"M1XLS MOTOR AND 4.25" HYC INFERNO BIT -STAB ON INJECTOR -HOLD KICK WHILE TRIPPING DRILL AND AAR 01:30 - 05:00 3.50 DRILL P I PROD1 RIH WITH 4.25"BUILD ASSEMBLY -PRESSURE TEST QTS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES -OPEN EDC AND RIH AT 100 FPM IN/OUT RATE=3.1/3.3 BPM IN/OUT DENSITY=8.50/8.51 PPG -TAKE INITIAL FINGERPRINT AT MAX DRILLING RATE OF 3.1 BPM(7 BBLS/10 MINUTES) -UNABLE TO TIE-IN TO FORMATION;DISCUSS OPTIONS WITH TOWN GEO GEOLOGY DISCUSS OPTIONS FOR TIE-IN PRIOR TO DRILLING AHEAD 05:00 - 06:00 1.00 DRILL N WAIT 11,830.00 PROD1 TAG AT 11801,PU AND RAN PAST THEN TAGGED AT 11822 PU AND TRY WORKING DOWN,TD SHOULD BEAT 11830 NOTABLE TO GET ANY DEEPER,START PUMPNG AND TRY WORKING DOWN TAKING A LOT OF WOB,MOTR STALLING PU TO 11780'AND CHECK NUMBER 06:00 08:10 2.17 DRILL P PROD1 RIH AND TAG AGAIN AT 11801'COULD BE THE WEAR RING ON THE MOTOR TAGGING ON THE TOWS PU AND RIH AT 30 FPM AND RAN PAST TAG HARD AT 11822 ALL DEPTHS ARE UNCORRECTED AS THE GEO'S ARE NOT ABLE TO PICK ANYTHING FROM THE LOGS BUT WE ARE 8' SHALLOWER THAN WHERE WE LEFT OFF WITH THE MILLING BHA PU AND RIH AGAIN TAGGED AGAIN AT 11801,TRY AGAIN AT FASTER SPEED AND MADE IT PAST TAG AT 11822',PU TO UP WT AND STOP BRING PUMP ON AT MIN RATE AND WORK RATE UP TO DRILLING RATE PUMPS AT FULL RATE,PRESSURE IS STABLE AND NO VIBRATION WORK DOWN TILL WE SEE MOTOR WORK STILL TAKING A LOT OF WEIGHT BUT WE ARE MAKING HOLE,NO PRESSURE SPIKES OR VIBRATION,LOOKS LIKE OH BASED ON THE UNCORRECTED DEPTHS IF THE RA MARKER IN THE WS COMES IN AT 11838.6'THEN WE ARE OK AND WE WERE ON BOTTOM Printed 8/31/2015 10:34:47AM IFQE= 4-1116'5M CNV IV NOTES: "'CHROME TBG—• WELCH EAD= 13-5/8'5M FMC W 5 ACTUATOR= BAKER OKB.ELEV= 54.8' 1 1 /I 111 11 2134' —4-1/2"HES X NP,D=3.813' BF.REV= 21.7' 111 1 1 11 KOP= 1000' 111 11 Aix Angle= 55 ®10600 20'CONDUCTOR, — 114' 11 0; 2966' —17-5/8"FES ES CEMENTER Datura MD= 11758' 91.5#,H-40, 44 �1 Cot=TVD= 6800'SS 13=19.124' A 7-5/8"CSG,29.7#,L-80 VA M TOP I-IC,13=6.875' — 2963' 7-5/8' I F4&E CORN SCREW SUB,D=6.875" -4 2971' ' 110-3/4'CSG,45.5#,NT-80 BTC,D=9.953' — 3127' ( GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 11 I 4 3370 3293 19 KBG2 CI BK 0 *07/09/15 4 3 6794 5702 52 KBG2 DMY BK 0 07/09/15 Minimum ID = 3.806" 11623' ' 2 9541 7368 54 KBG2 DM' BK 0 06/03/06 1 11368 8509 35 KBG2 MY BK 0 06/03/06 4-1/2" OTIS XN NIP (MILLED OUT) ' ' 1143T H4-12"HES X NP,D=3.813" M , 11458' —17-5/8'X 4-1/2'BKR S-3 PKR,D=3.870' 1 Xr 11482' H412"FES XNP,D=3.813" 4-1/2'TBG, 12.6#,13CR.0152 bpf,D=3.958" — 11545' 4-1/2"TBG STUB(04/24/06) — 11550' 1 • 11555' —17-5/8"X 4-1/2 LUQQIE MACFIINE OVERSHOT M. 11575' 1—7-5/8"x 4-12"BKR SABL-3 PKR VVI K-22 ANCHOR LATCH,D=3.937' I ' 11606' 1—4-12'OTIS X NP,D=3.813' I - I 11623' H412'OTIS XN NP,MLLED TO 3.806' (7/12/15) 4-1/2"TBG, 12.6#,13CR,.0152 bpf,13=3.958' — 11636' 11636' —41/2'VN-EG,D=3.958' 7-5/8"X 41/2"BKR DELTA WS(07/12/15) —1 1180T _ I 11634' —{ BAC TT LOGO 02/08/94 1 PERFORATION SUMMARY — 11863' ESTMATED TOP OF CMT(07/11/15) •1.1'1'1.1.1.1'1. 1 1, REF LOG:SBT/GiJCCL ON 01/29/94 .` � ANGLE AT TOP PERF:24° 11770' 11 ;' —2,125'POSISET PLUG(07/10/15) Note:Refer to Roduction DB for historical perf data w/SETTING ROD IN TOP -11857' SIZE SPF V1TB VAL Opn/Sqz SHOT SQZ U 3-3/8' 6 11770-11810 0 05/18/94 3-3/8' 6 11899-11939 0 02/01/94 PBTD — 11194' 1111111111 111111111111111111111 7-5/8"CSG,29.7#,L-80 NSCC, — 12076' ./././././././.1.S 1.1 .0459 bpf, D=6.875' DATE FEV BY COM.U4TS DATE REV BY COMrENTS PRUC1-10E BAY INT 12/25/93 N28E ORIGINAL COMPLETION O6/18/15� TRJM) ADDED CONCI CTOR DEPTH WILL: R-35 06/04/06 N2ES RIND 07/09/15 MICJPJC GLV CIO PERANT No: 1931810 06/13/06 EL TLH GLV CJO '07/10/15 CIS/PJC MLL XN,SET FOS1SET PLUG/CMT AR No: 50-029-22424-00 a 06/17/06 HJW(RH DRLG DRAFT CORRECTIONS 07/12/15 CLS/PJC SET W-PSTOCK SEC 32,T12N,R13E,608'FSL&826'FAL 05/13/15 JTMJMJ GLV C/O(05/06/15) '07/17/15. PJC CSG/LPR CORRECTIONS S 06/15/15 PJC LP1F,CSG,TBG IPDATES 08/28/15 TR/JMD UPDATED WS DEPTH BP Exploration(Alaska) pro 1 g 3-/r/ Loepp, Victoria T (DOA) From: Boltz,Travis <Travis.Boltz@bp.com> Sent: Thursday,July 30, 2015 2:48 PM To: Loepp,Victoria T (DOA) Cc: Lastufka,Joseph N Subject: R-35A Sundry and PTD Follow Up Flag: Follow up Flag Status: Flagged Victoria, For well R-35A PTD and Sundry I failed to add the statement*Approved alternate plug placement per 20 AAC 25.112(i) under the rig work table. However the statement is in the sundry Proposed Plan R-35A. Please let me know if you need anything else.Thank you. Respectfully, Travis Boltz Coiled Tubing Drilling Engineer Cell:502-640-1645 Office:907-564-5750 SCANNED • r0 <OF ry s THE STATE Alaska Oil and Gas 4ALAJ� KA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 of tM Main 907.279 1433 AI,Asli Fax 907 276 7542 NN'�U s\ `IL 0 ?_V�,1 www.aogcc alaska.gov John McMullen y(,p► Engineering Team Leader 3 t v f BP Exploration(Alaska), Inc. I 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-35 Sundry Number: 315-385 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 5 day of June, 2015 Encl. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMioSION JUN 1 $ air APPLICATION FOR SUNDRY APPROVAL cops b 12-7115 20 AAC 25.280 ,ar,nnt- 1. Type of Request' • ❑Abandon ®Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension O Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2 Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑Stratigraphic 193-181 • 3. Address. 6. API Number: ® Development ❑Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22424-00-00 • 7 If perforating 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU R-35 • Will planned perforations require a Spacing Exception? ❑Yes No 9. Property Designation 10.Field/Pool(s). ADL 028279&028278 • Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD (ft): Plugs(measured): Junk(measured) 12088' • 9156' • 11995' 9071' None None Casing Length Size MD TVD - Burst Collapse Structural Conductor 79' 20" 37'- 116' 37'- 116' 1490 470 Surface 3092' 10-3/4" 36'-3128' 36'-3063' 5210 2480 Intermediate • Production 12044' 7-5/8" - 35'- 12079' 35'-9148' 6890 4790 Liner Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11770'- 11939' 8865'-9019' 4-1/2", 12.6# 13Cr80 11639' Packers and SSSV Type: 7-5/8"x 4-1/2" Baker S-3 Packer; Packers and SSSV 11465'/8590'; 7-5/8"x 4-1/2" Baker SABL-3 Packer MD(ft)and TVD(ft): 11578'/8690' 12. Attachments: 13.Well Class after proposed work: 0 Description Summary of Proposal 0 BOP Sketch ❑Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14 Estimated Date for 15. Well Status after proposed work: Commencing Operation' June 30,2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval. Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Boltz,564-5750 Printed Name' John McMullen Title: Engineering Team Leader Email. Travis.Boltz@bp.com Signature: y7ear...7 .e. Phone 564 4711 Date: 6/(7/W i/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 �� �j i J ❑Plug Integrity 33..• i BOP Test ❑Mechanical Integrity Test ❑ Location Clearance Other. 00P ti-5/ -fo .. 5-6'0s ; ( N`P5P 1S Z5-4F:p5) n rJ la lr prG�`vz t�14�i5rt✓r �- o 0 oS✓te d c r a o /t ihC Z S, //2-0-. 2 L t A 11-c rrn a tc /� p /�/' P in Exception Required? Subsequent Form Required' — Spac g p q El dNo q q (J 9:7).-6...t.„).4 � , APPROVED BY Approved By' / / � Z COMMISSI THE COMMISSION Date. ! –30--/5 Form 10-403 Revised 10/2012 Approved applicatio #o 1 �rcikkhs r ie date of ap oval Submit In Duplicate VTL 6/23/i ! ' e. ZZ fS RBDM JUN 3 0 1015% To: Alaska Oil & Gas Conservation Commission From: Travis Boltz 0 by CTD Engineer Date: June 16, 2015 Re: R-35 Sundry Approval Sundry approval is requested to plug the R-35 perforations as part of drilling and completing the proposed R-35A coiled tubing sidetrack. History of R-35: R-35 was completed in 1994. An Ivishak and Sag frac were completed in 1995. The well operated under a waiver for a SC leak from 2003-2005. After the waiver was cancelled in 2005, R-35 was SI. A RWO repaired the SC leak, performed a tubing swap, and cemented the OA to surface. In 2009, a failed MIT-OA resulted in crude returns to surface. An OA top job with cement fixed the compromised integrity. The well failed a pre-rig MIT-OA to 1200 psi; however, no returns were noted to surface and there was no pressure response in the IA. Therefore, the well does not have any further integrity issues and is fit for CTD sidetrack. Proposed plan for R-35A: Drill a through tubing sidetrack with Coiled Tubing Drilling rig on or around 15 July, 2015 with Nordic 1. The R-35A sidetrack will exit the existing 7-5/8" liner and kick off in the Sag River and access Sag River reserves. The proposed sidetrack is a -3,386' horizontal Sag River producer and will be completed with a 3-1/2" L-80 solid x 3-1/4" L-80 x 2-7/8" L-80 slotted liner, with the solid liner cemented in place. This Sundry covers plugging the existing R-35 perforations via the R-35A liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). 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 30 June, 2015) 1. E Mill XN 11,623'MD, Set Posi-Set -11,885' MD and 10' of cement (Sundry Required). Set 4-1/2" x 7-5/8" Delta WS with TOWS -11,805'MD 3. V Swab Valve Test, Install Sarber Spool, Set TWO 4. 0 Remove Wellhouse and level pad Rig Work (scheduled to begin July 15th, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (2595 psi MASP). 2. Mill 3.80" window and 10' of rathole. 3. Drill Build section: 4.25" OH, -627' (35° deg/100 planned) 4. Drill Lateral section: 4.25" OH, -2,039' (12° deg/100 planned) Run 3-1/2" solid liner L-80 x 3-1/4" solid liner L-80 x 2-7/8 slotted L-80 to leaving 5. TOL 11,585' MD. Pump primary cement TOC/TOL 11,585' MD through ported sub in 3-1/4" solid 6. liner with 11.8 bbls of 15.8 ppg cement planned. 7. Freeze protect well to 2500' MD 8. Set TWC, RDMO Post-Rig Work: 1. Re-install wellhouse, flowline and pull TWC. 2. Set generic GLV's, SBHPS, ASRC flow back, SIT. Travis Boltz CC: Well File CTD Engineer Joe Lastufka 564-5750 TREE= 4-1/16'SM CNV s ' NOTES: ""CHROME TBG"" VIELL•HEAD= 13-5/8"5M FMC ACTUATOR= BAKE R-35 OKE_ELEV= 54.8' I BF.KOP= = 21.7' 4•11 wx Angie= 55" 10600' 20'CONDUCTOR, — 114' v��1 I I 141 2134' — 4-1/2"FES X tom.D=3.813' Datum MD= 11758' 91.5#,H-40, X1'1 $1 Datum TVD=--- 8800'SS D=19.124' $� 7-5/8'CSG,29.7#,L-80 VAM TOP HC,C=6.875' — 2963' ��� ���� 2955' --19-5/8-HES CvrER 7-5/8"CSG,29#,L-80 BTC,D=6.875' --I 2971' *'t ��� 10-3/4"CSG,45.5#,NT-80 BTC,D=9.953' —I 3127' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" c 11623' 4 3370 3293 19 KBG2 DOME BK 16 '05/06/15 3 6794 5702 52 KBG2 DOW BK 16 05/06/15 4-112" OTIS XN NIPPLE 2 9541 7368 54 KBG2 DMY BK 0 06/03/06 1 11368 8509 35 KBG2 DM'( BK 0 06/03/06 11437' 1--14-1/2"HES X!W",D=3.813" _TA ' 11458' H 7-5/8"X 41/2"BKR S-3 PKR,13=3.870" 11482' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#,13CR.0152 bpf,D=3.958" 11545' 4-1/2'TBG STUB(04/24/06) 11550' 11555' —17-5/8"X 4-1/2 UNIQUE MAC*€OVERSHOT 11575' H 7-5/8'x 4-1/2'BKR SABL-3 R(R W/K-22 ANCHOR LATCH,D=3.937" 11606' —{4-12'OTtS X NP,D=3.813" 11623' 44-12'OTIS XN NP,D=3.725" 4-12"TBG,12.6#,13CR,.0152 bpf,D=3.958" —{ 11636' —3 11636' ---I4-1/2"VI/LEG,D=3.958" 11634' —{ELK)TT LOGGED 02/08/94 PERFORATION SUMMARY REF LOG:SBT/GRJCCL ON 0129/94 ANGLE AT TOP PERF:24'@ 11770' Note:Refer to Ptoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ [L1 3.3/8" 6 11770-11810 0 05/18/94 3-3/8' 6 11899-11939 0 02/01/94 PBTD — 11194' ••••1••1•• ..11.• 7-5/8'CSG,29.7#,L-80 NSCC, -3 12076' •�•�•�`�•�'�•�•�•�•�•1 .0459 bpf, D=6.875' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY (KT 12/25/93 ORIGINAL COMPLETION 06/18/15 TR/JM? ADDED CONDUCTOR DEPTH WELL: R-35 06/04/06+ N2E8 RttilO PERMIT Na:'1931810 06/13106 EUTLH GLV C/O AR No: 50-029-22424-00 06/17/06 HJW/TLH DRLG DRAFT CORRECTIONS SEC 32,T12N,R13E,608'FSL&826'FWL 05/13/15 JTMJM3 GLV CIO(05/06/15) 06/15/15 PJC LN2,CSG,TBG UPDA itb BP Exploration(Alaska) TREE=• 1-1/16"5MCIW SAr__. NOTES: ""CHROME TBG'"' WELLHEAD= 13-5/8"5M FMC R-35A ACTUATOR= BAKER CTD Sidetrack KB.REV= 54.8' BE REV= 21.7' 11 T1! KOP= 1000' 1 1 Max Angle= 55 @ 10600' ..4 I I +.4 2134' —I4-1/2"HES X NP,D=3.813" Datum MD= 11758' 1i �,/ Datum TVD= 8800'SS #111. 7-5/8"CSG,29#,L-80 VAM TOP,D=6.875" —I 2918' 11' .� 2955' HESES �� 1.. ;1; 7-5/8"CSG,29#,L-80 BTC,D=6.875" H 2966' 10-3/4"CSG,45.51t,NT-80 LI-E,ID=9.953" H 3125' GAS LET MANDRELS ST M3 TVD DEV TY FE VLV LATCH PORT DATE 11 4 3370 3293 19 KBG2 DOME BK 16 06/13/06 3 6794 5702 52 KBG2 SO BK 20 06/13/06 2 9541 7368 54 KBG2 DMY BK 0 06/03/06 Minimum ID = 3.725" @ 11623' 1 113688509 35 KBG2 DMY BK 0 06/03/06 4-1/2" OTIS XN NIPPLE I I 1143T H4-1/2"HES X NP,D=3.813" Z. Zr11458' H7-5/8"X 4-1/2"BKR S-3 PKR,D=3.870" I ` 11482' —14-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,13=3.958" —1 11545' . " 11550' H4-1/2"TBG STUB(04/24/06) 11555' -17-5/8"X 4-1/2 UNIQUE MAC/-W'E OVERSHOT ,R XN11575' -7-5/8"x 4-1/2"BKR SABL-3 PKR W/K-22 ANCHOR LATCH,13=3.937" TOC/TOL -11,585' MD _ 1 11606' —14-1/2"OTIS X NP,D=3.813" I t 11623' H4-1/2"OTIS XN NP,D=3.725" Mill XN to 3.80 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,ID=3.958" H 11636' / ‘ 11636' H4-1/2"WLEG,0=3.958" 11634' H BMD TT LOGGED 02/08/94 4-1/2"x 7-5/8"Baker TT whipstock @ 11,801'MD- ihiL- 35°/100' BUR 24°inc @ window TOWS at 11,821' MD (Set in perfs) PERFORATION SUMMARY 2-7/8" SlottedL-80 Liner to 14,467' MD FZEL LOG:SBT/GWOCL ON 01/29/94 / ANGLE AT TOP PERE:24 @ 11770' "'ill. ----------414/ Note:Refer to Roduction DB for historical perf data SIZE SPF _ NTERVAL Opn/Sqz DATE 3-3/8" 6 11770-11810 0 05/18/94 3-1/4" 13Cr ported sub @ -12,715'MD 3-3/8" 6 11899-11939 O 02/01/94 Cement(dump bailed) 11,870'MD Posi-set plug-11,880' MD PBTD H 11995' 1111111111111111111/11 1111111111111111.0 7-5/8"CSG,29.7#,NT-95 HS,D=6.875" H 12075' DATE REV BY COMMENTS . DATE REV BY COMMENTS NITS PRUDHOE BAY UNIT 12/25/93 ORIGINAL COMPLET1ON WELL R-35 06104/06 N2ES RWO PERMIT No:F1931810 06/13/06 EUTLH GLV CIO AR No: 50-029-22424-00 06/17/06 FUWITLH DRLG DRAFT CORRECTIONS SEC 32,T12N,R13E BP Exploration(Alaska) il v • (Ili' m c N cf. N IK 11i b m u uo LL m 11 2 9 k C � LL 211 v u u w M t f r. 1 1 1 1' °m 1 f Y II a. e e c.,1 'I :. a s � m. m I f ME u �x oa �1 U �m u 2 5 C ,0 P O M N (9 o s 1 Q a m I o H I -- l i o ,,, I II 0 1 ...-.-1 I = III;� 1 O 511 ; Ili ill a IL iii I e a " // `v I = m m Q I LL e ® _ I11 0 III 0 f I15 II . „_ 2 • I «J 1111 Z I g c°o 111 �` ci o ♦, Q > > Iri 4.1 II11 !11 1 mm 0 o E o 111 p 21 0 p- Wy ee i.l N� #�' • I , . . NII I W C a a U WId r a IN ds m U f o f f © , c \ • • 16 W i Y } • O I N • 2 U Ids mii , I 1— a N ~ J Q II U 1 U 3 1 m 11 Li 1 N 17 , O m I m UM Z s I d0 I' in m I 111 ■ M og A. 1 M I■ ■ 11 oa 1 ¢ r as ■ C o I Vii ° / I 111 ¢ 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 in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" / boxes are also checked, cross out that erroneous entry and initial it on both V 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 Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria 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 for Jenni 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 History tab Jenni 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 change Jenni 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 Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs-of vadous kinds . [] Other COMMENTS: · Scanned by( B iann~Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 t-.. i ~c ~~~~~„~ ,J~~~L July 10, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, (j~3--~g~ ~ -I ~`~ 3 S'_ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- 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, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator JI~~ ~ ~ ~OA~ ~ ~ ~~~~ ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initial 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 al R-02 50029203540000 1781000 1.25 NA 125 NA 6.8 5/11 /2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206150000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 025 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5l14/2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/1 S/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 -~ ~~' ~3 ~ (~~~ Mr. Tom Maunder ``~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, r1 U ~~ .~ ~~~ ;;;: 3. ~~ j ~ ~ , : JUL Q ~ 2009 ~i~€~~ ~~~ ~ Ga~ ~an~a ~Arn~t~~ia~ Anchora Enclosed please find a spreadsheet with a list of wells from R-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, 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, ~.. ? ?D~' ; ,.x ~~~.~~~:~ ~i l~ ~ ~: ~ Torin Roschinger BPXA, Well Jntegrity Coordinator ~ • BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) natp R-pad 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na af R-02 1781000 1.25 NA 1.25 NA 6.8 5/11 /2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 1830350 0.25 NA 025 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 272 5/15/2009 R-1 SB 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5l11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11 /2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 -VA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 IÆ.b~ STATE OF ALASKA _ ' ,. ALASalL AND GAS CONSERVATION ~MISSION RECeiVED REPORT OF SUNDRY WELL OPERATION~UN 202006 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program S Repair Well S Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 53.4' 8. Property Designation: ADL 028278 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 12088 9156 11623 8730 Casing Structural Conductor Surface Intermediate Production Liner Length 80' 3092' 12044' Perforation Depth MD (ft): Perforation Depth TVD (ft): . . o Stimulate o Waiver o Time Extension Alaska I a Anchorage o Other o Re-Enter Suspended Well 4. Well Class Before Work: S Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 193-181 6. API Number: 50-029-22424-00-00 9. Well Name and Number: PBU R-35 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool feet feet Plugs (measured) feet Junk (measured) feet Size MD 20" 112' 10-3/4" 3127' 7-5/8" 12076' . ", " ,, r"c ,ji"~'l\r:h~~~..." 11770' - 11939' 8865' - 9019' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 11623 None TVD Burst Collapse 1490 470 5210 2480 6890 4790 112' 3062' 9145' 13CrBO I 13Cr 11636' Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker 'SABL-3' packer; 7-5/8" x 4-1/2" Baker Chrome 'S-3' packer 11575'; 11458 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JUN ,2 ¡ 1006 Treatment description including volumes used and final pressure: Cut and pull 4-1/2" tubing. Cut 7-5/8" casing at -2950' and pull. Run new 7-5/8" casing tieback to surface. Cement wI 150 Bbls Clas 'G', Run new 4-1/2" tubing to cut located at approximately 11550', 13. Re resentative Dail Oil-Bbl Gas-Mcf Water-Bbl Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: o Exploratory S Development 0 Service 16. Well Status after proposed work: SOil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt 306-144 o Copies of Logs and Surveys run S Daily Report of Well Operations S Well Schematic Diagram Contact Printed Name Terrie Hubble Signature /fÔ. Form 10-404 Revised 04/2006 correct to the Title Technical Assistant Phone 564-4628 0"" I W L I _ Prepared By Name/Number: Date I' 'lOop Terrie Hubble, 564-4628 Submit Original Only TREE = 4-1/16" 5MCIW . R-35 ~OTES: ***CHROM E TBG*** I WELLHEAD - '13-5/8" 5M FMC ACTUATOR = BAKER FROM DRLG DRAFT KB, ELEV = 54.8' - BF, ELEV = 21.7' H4-1/2" HES X NIP, ID - 3.813" I KOP= 1000' I 1 2134' Max Angle = 55 @ 10600' Datum MD = 11758' Datum TV D = 8800'SS GAS LIFT MANDRELS 7-5/8",29#, L-80, Yam Top HC (non IPC) 1-1 -2971 ST MD TVD DEV 1YPE VLV LATCH PORT DATE 4 3370 3293 19 KBG2 OCR BK 06/03/06 110-3/4" CSG, 45.5#, NT-80 LHE, ID = 9.953" 3125' L 3 6794 5702 52 KBG2 DMY BK 0 06/03/06 2 9541 7368 54 KBG2 DMY BK 0 06/03/06 1 11368 8509 35 KBG2 OMY BK 0 06/03/06 Minimum ID= 3.725" @ 11623' I I 1 N/A H4-1/2" ons x NIP, ID = 3.813" I 4-1/2" OTIS X NIPPLE 11431' 4-112" OTIS X NIP.ID = 3.813" I I 11458' 7 5/8" x 4 1/2" Baker Chrome S-3 I 81 IX packer I . 11482' 1--14-1/2" OTIS X NIP, 10 - 3.813" I I } 1 11545' H 7 5/8"x 4-1/2" UMI Chrome Overshot I I 8 15< I 11575' 7-518" x 4-1/2" BKRSABL~3 PKR I WI K~22 ANCHOR LATCH, tD = 3.937" 4-1/2" TBG. 12.61#, 13.CR, .0152 bpf, 10 "" 3.958" 11636' I 1 11623' 1-;4-112" OTIS XN NIP, ID = 3.725" I I 11636' H4-112"V\lLEG, 10= 3.958"' J I I 11634' H B.MoiTLOOGED02lO8194 PERFORA IDN SlJMIM.RY I REF LOG: SBT1GRlCCL ON 01129194 ANGLE AT TOP PERF: 24 @ 11770' .Note.: Refer to A'oduction DB for hìs.t~11 perf data S~E S~ ~AL ~~ 3-3/8" 6 11770-11810 0 05/18/94 3-3/8" 6 11899 - 11939 0 02101/94 I PBTD I 11995' I I 7-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" I 12075' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrr 12/25/93 ORIGINAL COMPLETION 12/13/05 MORlTLH XXN TIP SET WELL: R-35 09/24/01 RN/TP CORRECTIONS 12/13/05 DAV/PJC GL V C/O PERMrr No: '1931810 08/26101 JJ/KA K SET XXN PLUG OS/25/06 HJW API No: 50-029-22424-00 11/28/03 KDClPAG WAIVER SAFE1Y NO~ 06/05/06 RBN SEC 32, T12N, R13E 10/16/05 RPH/PJC WAIVER SF1Y NOTE DELETED 06/14/06 KOMlPAG GLM CORRECTIONS-RIG ERROF 12/08/05 RBRlPJC PULL PLUG@11623'(11/30/03) I BP Exploration (Alaska) . . R-35 Rig Workover Prudhoe Bay Unit 50-029-22424-00-00 193-181 Accept: Spud: Release: Ri: OS/23/06 N/A 06/04/06 Nabors 2ES PRE-RIG WORK 04/20/06 RIH W/4 1/2" CHECK SET, TAGGED TIP AT 11602' SLM, CHECK SET SHOWED GOOD SET. 04/23/06 CHEMICAL CUT TUBING MIDDLE OF FIRST JOINT ABOVE PACKER AT 11550', SHOT TUBING PUNCHER FROM 11524' -11526'. 2 STRAND STRING SHOT RAN FROM 11539' - 11551'. 3-5/8" CHC SHOT AT 11550'. TOOL STUCK FOR A SHORT PERIOD OF TIME. CAME FREE WITH JAR LICK, NO PROBLEMS RIH OR POOH. POSITIVE INDICATION OF CUT. WELL LEFT SHUT IN. TURNED OVER TO DSO. 04/30/06 T/I/O=OIOIO CIRC OUT (PRE RWO) - CIRCULATE DOWN TUBING UP IA TAKING RETURNS THROUGH CIRC LOOP TO FLOW LINE W/5 BBL NEAT METHANOL SPEAR, 722 BBLS 80°F 1% KCL. PUMP DOWN IA W/92 BBLS 80°F DIESEL. U-TUBE TXIA TO FREEZE PROTECT. FREEZE PROTECT FLOW LINE W/10 BBLS NEAT METHANOL, 13 BBLS 80°F DIESEL. 05/01/06 CMIT TXIA 3500 PSI. PASSED. PRESSURED UP TXIA W/6 BBLS DIESEL. T/IA LOST 20 / 20 PSI IN 1ST 15 MIN. TIIA LOST 20 120/PSIIN 2ND 15 MIN. PASS. BLED TXIAXOAP. FINAL WHP'S=OIOIO. JOB COMPLETE. · legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRilLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 5122/2006 12:00 - 14:30 2.50 RIGD P POST Prepare to lay down derrick, move shop and portable buildings. 14:30 - 19:00 4.50 RIGD P POST Lay down derrick and jack rig to remove matting boards. 19:00 - 00:00 5,00 RIGD P POST Move rig off well and move to R-pad. 5/23/2006 00:00 - 10:30 10.50 MOB P PRE Move rig to R pad 10:30 - 12:00 1.50 RIGU P PRE Spot rig on R-35, lay herculite 12:00 - 16:00 4.00 RIGU P PRE PJSM. Raise and pin derrick. Berm around rig and rig up. 16:00 - 19:00 3.00 RIGU P PRE Spot buildings. rig acceptted @ 18:30hrs 23/05/2006. Tbg pressure Opsi. Annulus pressure Opsi. 19:00 - 21 :00 2.00 WHSUR P DECOMP Pre-Spud meeting. Take on 11 Odeg seawater. Run eletrical lines to shop. 21 :00 - 22:00 1.00 WHSUR P DECOMP Install secondary annulus valve. Rig up circulating lines and test mud system to 3500psi. 22:00 - 23:00 1.00 WHSUR P DECOMP PJSM. Rig up DSM lubricator and pull BPV.Rig down lubricator. Cut and fit boards over cellar box. Test circulating lines to 1000psi. 23:00 - 00:00 1.00 WHSUR P DECOMP Reverse circulate freeze protection diesel from tubing, 5BPM @ 450 psi. 5/24/2006 00:00 - 02:00 2.00 WHSUR P DECOMP Pump 35 bbl soap pill through tubing cut @ 11550'. 775 psi @ 6.2 BPM. 02:00 - 02:30 0.50 WHSUR P DECOMP Dry rod TWC, test from below to 1000 psi. 02:30 - 03:00 0.50 WHSUR P DECOMP Blow down and rig down circulating lines 03:00 - 05:00 2.00 WHSUR P DECOMP Nipple down tree and adapter flange. Inspect tubing hanger threads, OK. 05:00 - 07:30 2.50 WHSUR P DECOMP Nipple up BOP 07:30 - 08:00 0.50 WHSUR P DECOMP Make up 4 1/2" test joint. Grease Choke valves. 08:00 - 14:00 6.00 WHSUR P DECOMP Test BOP's and related valves to 250 psi low and 3500 psi high. Test waived by AOGCC rep. John Crisp, Test witnessed by BP rep. John Rail. 14:00 - 15:00 1.00 WHSUR P DECOMP Rig down test equipment. Blow down lines. Make up cross over on landing joint. 15:00 - 16:00 1.00 WHSUR P DECOMP Rig up DSM lubricator and pull TWC. Rig down lubricator. 16:00 - 17:00 1.00 PULL P DECOMP Make up landing joint,back out lock down screws. Pull hanger, 160k to free, 145k up wt. Lay down landing joint and hanger. 17:00 - 19:00 2.00 PULL P DECOMP Rig up Camco spooling unit. Rig up casing tools with compensator. 19:00 - 00:00 5.00 PULL P DECOMP POOH with 41/2" 12.6# 13CR80 NSCTtubing from 11550' to 9515' with dual control lines. Recovered 9 of 9 SS bands and 22 of 22 clamps. Rig down spooling unit. 5/25/2006 00:00 - 11 :00 11.00 PULL P DECOMP POOH with 41/2" 12.6# 13CR80 NSCT tubing from 9515' with compensator. 11 :00 - 12:00 1.00 PULL P DECOMP Rig down tubing handling equipment. Clear and clean rig floor. 292 jts tubing, 1 SSSV, 5 GLM's,1 GLM w/X nipple, 1 cut off jt 19.03'. No flare on cut but jagged notch on one side. 12:00 - 13:00 1.00 PULL P DECOMP Remove compensator sub from top drive,install saver sub. Install safety clamp and grease backup gripper. 13:00 - 13:30 0.50 CLEAN P DECOMP Check gland nuts. Make up 4" test joint,safety valve, test plug, and set test plug in wellhead. 13:30 - 15:00 1.50 CLEAN P DECOMP Test BOP with 4" test joint, toplbottom rams and annular. 250 psi low, 3500 psi high. Record on chart. Rig down test equipment, blow down lines. Install 8 11/16" wear bushing. 15:00 - 18:00 3,00 CLEAN P DECOMP Pick up and make up BHA #1 18:00 - 22:30 4.50 CLEAN P DECOMP Pick up drill pipe from pipe shed & RIH 315' to 6900'. 22:30 - 00:00 1.50 CLEAN P DECOMP Cut and slip drilling line. Inspect brake system. Service Elmago Printed: 6/512006 11 :44,57 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 5125/2006 22:30 - 00:00 1.50 CLEAN P DECOMP Spline.Service draworks and topdrive. 5/26/2006 00:00 - 04:00 4.00 CLEAN P DECOMP Pick up drill pipe from pipe shed & RIH 6900' to 11519'. 04:00 - 05:00 1,00 CLEAN P DECOMP Break circulation 4 BPM @440 psi. Up wt 195k,down wt. 145k, rotating wt. 168k. Wash down and tag stump at 11544'. Dress stump. 05:00 - 05:30 0.50 CLEAN P DECOMP Break off and blow down top drive. Rig up circulating lines to reverse circulate. 05:30 - 07:00 1.50 CLEAN P DECOMP Reverse circulate 30 bbl hi-vis sweep @ 11550', 7.5 BPM @2050 psi.No debris on bottoms up. Pump sweep to surface. Pump dry job blow down surface equipment. 07:00 - 08:00 1.00 CLEAN P DECOMP Rig down circulating hoses, remove blower hose from top drive. Lay down 5' pup joint, POOH 11,550' to 11,517' ,lay down single. 08:00 - 11 :00 3.00 CLEAN P DECOMP POOH 11,517' to 3770' 11 :00 - 12:00 1.00 CLEAN N RREP DECOMP Draworks Hi-transmission chain broke, remove chain. Function test oiler (OK). 12:00 - 14:30 2.50 CLEAN P DECOMP POOH 3770' to 315' Stand back drill collars. 14:30 - 15:30 1.00 CLEAN P DECOMP PJSM Lay down dressing tool BHA from 39'. Clear floor. 15:30 - 16:30 1.00 CLEAN P DECOMP PJSM with wireline crew. Rig up wireline to run US IT log. 16:30 - 19:30 3.00 CLEAN P DECOMP RIH with US IT log to 6500'. Log up from 6500' to surface. 19:30 - 20:00 0.50 CLEAN P DECOMP Rig down Wireline unit,clear and clean floor. 20:00 - 21 :00 1.00 CLEAN P DECOMP Make up Halliburton RBP to 10'. RIH with BHA to 286'. 21 :00 - 23:00 2.00 CLEAN P DECOMP RIH 286' to 4013'. Up wt. 95k, down wt. 90k. 23:00 - 23:30 0.50 CLEAN P DECOMP Set RBP.Top of plug @ 4005'. Verify plug set. Rack back one stand to 3922'. 23:30 - 00:00 0.50 CLEAN P DECOMP Dump 1000 Ibs. of 20/45 sand on top of RBP @4005' 5/27/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP POOH to 3862'. Test casing to 1000 psi. 01 :00 - 01 :30 0.50 CLEAN P DECOMP Displace well to 9.8 ppg brine. Pump at 150 gpm @90 psi to clear sand from pipe then 235 gpm @ 185 psi. 01 :30 - 02:30 1.00 CLEAN P DECOMP RIH and tag sand 10' above RBP@ 3995'. POOH to 3922' and dump 500 Ibs of 20/45 sand on top of RBP. 02:30 - 04:00 1 .50 CLEAN P DECOMP POOH from 3922' to 279'. Change out elevators. 04:00 - 05:00 1.00 CLEAN P DECOMP POOH from 279',rack back drill collars,and lay down RBP running tool. Clear and clean floor. 05:00 - 06:00 1.00 CLEAN P DECOMP Make up Baker casing cutter and stabilizer, 3 stds 4 3/4" collars, and cross over to 283'. 06:00 - 06:30 0.50 CLEAN P DECOMP RIH with Baker casing cutter 283' to 2993'. Install blower hose. Break circulation, establish parameters & SPR's, Up wt. 80k, down wt. 75k, rotating wt. 77k. Torque off bottom 1-4k, 200GPM @ 575 psi. 06:30 - 09:00 2.50 CLEAN P DECOMP Rig up circulating lines. Rig up Little Red Hot Oil services, Test circulating lines to 1000 psi. PJSM. 09:00 - 10:30 1.50 CLEAN P DECOMP Locate collars on 7 5/8" casing & space out from cut. Cut 7 5/8" casing @2950' 200 gpm @575 psi. Confirm cut, close hydrill , open annulus to cuttings tank. Pump 80 bbls. hot diesel followed by 9.8 ppg heated brine. 10:30 - 11 :00 0.50 CLEAN P DECOMP Shut down pump, check for flow, shut Hydril. Blow down lines, remove blower hose, open Hydril. 11 :00 - 13:00 2.00 CLEAN P DECOMP POOH 2950' to 283'. Stand back Drill collars to 9' 13:00 - 13:30 0.50 CLEAN P DECOMP Pull wear ring, install test plug. 13:30 - 14:30 1.00 CLEAN P DECOMP Change top rams to 7 5/8" rams. 14:30 - 16:00 1.50 CLEAN P DECOMP Make up 7 5/8" test joint. Test top rams 250 psi low 3500 psi high. Rig down test joint. Clear floor. Printed: 6/512006 11 A4:57 AM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRilLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 5127/2006 16:00 - 17:00 1.00 CLEAN P DECOMP Pick up fishing tools. Make up spear & packoff assembly to 50'. Engage 7 5/8" mandrel. 17:00 - 18:00 1.00 CLEAN P DECOMP Back out lock down screws, pull Mandrel to floor. Pull free @ 125k. Monitor well. 18:00 - 18:30 0.50 CLEAN P DECOMP Circulate casing volume @ 2920'. 6 BPM @580 psi. 18:30 - 19:00 0.50 CLEAN P DECOMP Release and lay down spear. Lay down Mandrel. 19:00 - 20:00 1.00 CLEAN P DECOMP Rig up 7 5/8" handling equipment. 20:00 - 00:00 4.00 CLEAN P DECOMP Lay down 7 5/8" casing from 2920'. 74 jts, 1 cut5 off jt @ 20.39'. Average breakout torque 10k. 5/28/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Rig down casing handling equipment. 00:30 - 01 :30 1.00 CLEAN P DECOMP Change 7 5/8" rams to 3 1/2" x 6" variables. 01 :30 - 02:00 0.50 CLEAN P DECOMP Test variable rams with 4" test joint. 250 psi low, 3500 psi high. 02:00 - 05:30 3.50 CLEAN P DECOMP Make up washpipe BHA to 342'. Change out elevators. RIH 342' to 2895' (slow I fluid running over). 05:30 - 07:30 2.00 CLEAN P DECOMP Wash down from 2895' to 2981'. Circulate hi-vis sweep around, 13 BPM @ 1400 psi. Blow down top drive. 07:30 - 09:30 2.00 CLEAN P DECOMP POOH 2981' to 342'. Change out handling equipment. POOH from 342',lay down boot baskets and washpipe. 09:30 - 12:30 3.00 CLEAN P DECOMP Make up back-off tool BHA to 309'. Change out handling equipment. RIH 309' to 3268', fill every stand with fresh H2O. 12:30 - 13:00 0.50 CLEAN P DECOMP Make up head pin and circulating lines. Space out back-off tool. Cycle tool 5 full turns to left. 3000 psi down to 700 psi. 13:00 - 13:30 0.50 CLEAN P DECOMP Drop dart, open circulating sub. Displace fresh water out of drill pipe, 6 BPM @ 1000 psi. Blow down and rig down circulating lines. 13:30 - 15:30 2.00 CLEAN P DECOMP POOH 3268' to 309'. Lay down back-off tool and stand back drill collars. Clear and clean floor. 15:30 - 16:30 1.00 CLEAN P DECOMP Make up spear assembly to 34'. RIH with drill collars to 311' 16:30 - 17:00 0.50 CLEAN P DECOMP RIH from 311' to 2950'. 17:00 - 17:30 0.50 CLEAN P DECOMP Engage 7 5/8" casing stump @ 2950' Up wt. 77k, Down wt.77k, Rotating wt. 77k. Pick up 15k to verify engaged, rotate 7 turns to the left. 17:30 - 18:00 0.50 CLEAN P DECOMP Hole annulus overbalanced, pump drill pipe volume, 6 BPM @ 600 psi. Blow down top drive. 18:00 - 20:30 2.50 CLEAN P DECOMP POOH 2950' to 311 '. Stand back drill collars. Lay down fish and spear assembly.Clear floor. 75/8" casing cut off 21.31' 03:00 - 21 :30 18.50 CLEAN P DECOMP Pick up 10 3/4" RTTS and make up to 11'. RIH with drill collars to 287'. 21 :30 - 22:30 1.00 CLEAN P DECOMP RIH 287' to 2900' 22:30 - 23:30 1.00 CLEAN P DECOMP Set RTTS. Pump down drill pipe & test 103/4" shoe -7 5/8" casing from below to 1000 psi. No leaks. Pump down annulus to 1500 psi. Pressure bleeds off @ 100 psilmin to 300 psi. Attempt to establish injection rate at 5 stks/min. Pumped 1 bbl. away to 1500 psi. 23:30 - 00:00 0.50 CLEAN P DECOMP Release RTTS. Blow down top drive. POOH 2900' to 2437' 5/29/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP POOH 2437' to 287'. Change out handling equipment. 01 :30 - 02:00 0.50 CLEAN P DECOMP POOH from 287'. Service break and lay down RTTS, Clear floor, 02:00 - 03:00 1.00 CLEAN P DECOMP Install test plug. Change out upper 3 1/2" x 6" variable rams to 75/8". 03:00 - 04:00 1.00 CLEAN P DECOMP Make up test joint and test 7 5/8" rams to 250 psi low and 3500 psi high. Remove test plug & lay down. Printed: 6/5/2006 11,44,57 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 5129/2006 04:00 - 05:00 1.00 CASE P DECOMP Install long bales. 05:00 - 06:00 1.00 CASE P DECOMP Rig up to run 7 5/8" 29.7# L-80 casing, 06:00 - 12:00 6.00 CASE P DECOMP PJSM. Make up overshot I ES cementer assembly. Run 7 5/8" 29.7# L-80 VAM Top casing to 2909'. Space out to rig floor- screw in top drive. 12:00 - 13:00 1.00 CASE P DECOMP Up wt. 107k, Down wt. 107k, Rotating wt. 107k. Engage screw in sub with 7 5/8" pin. Work torque down with 10k ft/lbs at screw in sub. Pull test to 200k, pressure test to 2000 psi. OK 13:00 - 14:00 1.00 CASE P DECOMP Rig down top drive,rig up cement head,manifold ,and circulating lines. 14:00 - 16:00 2.00 CASE P DECOMP Rig up Schlumberger, PJSM with all personell. 16:00 - 17:30 1.50 CASE P DECOMP Wait on cement blend test. Open ES cementer with rig pump - partially open. Drop bomb - open ES cementer with 470 psi. OK. 17:30 - 19:00 1.50 CASE P DECOMP Pump 5 bbl to wash lines. Test lines to 4500 psi. Pump 140 bbl class G 15.8 ppg cement. Drop ES cementer closing plug. Displace with 105 bbl 9.8 brine. CI9se hydril and squeeze 1 bbl into 103/4" casing hole, into cellar box. Displace 138 bbl total to bump plug. Cement in place 19:10 hrs. 20 bbl cement recovered. 19:00 - 20:30 1.50 CASE P DECOMP Flush all surface equipment & BOP stack. Blow down surface equipment. Rig down cement head and adapter. Drain cut off joint,clear floor. 20:30 - 23:00 2.50 CASE P DECOMP Split stack. Set emergency slips with 100k. Cut 7 5/8" casing using WACHS cutter. Lay down cut off joint and clear floor. 23:00 - 00:00 1,00 CASE P DECOMP Install 7 5/8" pack off. Nipple up BOP and test tubing spool. 5/30/2006 00:00 - 01 :00 1.00 CASE P DECOMP Nipple up BOP 01 :00 - 02:00 1.00 CASE P DECOMP Test 75/8" pack off to 3500 psi 02:00 - 03:00 1.00 CASE P DECOMP Install 3 1/2" x 6" variable rams. 03:00 - 08:30 5.50 CASE P DECOMP Rig up 4" test equipment. Test BOP and related valves to 250 psi low and 3500 psi high. Make up 4 1/2" test joint, test lower I upper rams and hydril. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP reps Blair Neufeld and John Rail. 08:30 - 09:00 0.50 CASE P DECOMP Pull test plug,install wear ring. 09:00 - 10:00 1.00 CASE P DECOMP Make up drill out BHA to 308'. Change out handling equipment. 10:00 - 11 :00 1.00 CASE P DECOMP RIH 308' to 2925'. 11 :00 - 11 :30 0.50 CASE P DECOMP Service Top drive. 11 :30 - 12:00 0.50 CASE P DECOMP Break circulation - 220 gpm @ 350 psi. Wash down to 2953'. Clean out from 2953' to 2960'. Up wt. 80k, Down wt. 75k, Rotating wt. 80k @ 90 RPM. Torque 2000 off bottom & 2500 on bottom. WOB 10k. 12:00 - 13:00 1.00 CASE P DECOMP Mill ES closing plug,bomb, and ES cementer @ 2961 '. 13:00 - 15:00 2.00 CASE P DECOMP Attempt to test 75/8" casing @2961'. No test. Rig up head pin and isolate surface equipment. Attempt to test,no test. 15:00 - 16:30 1.50 CASE N CEMT DECOMP Circulate @ 2961' 12 BPM @ 1600 psi. 16:30 - 18:00 1.50 CASE N CEMT DECOMP Remove blower hose. POOH 2961' to 30T. Stand back drill collars. Lay down milling assembly. Clear floor. 18:00 - 22:00 4.00 CASE N CEMT DECOMP Pick up and make up RTTS. RIH with drill collars to 284'. RIH 284' to 530'. Test through RTTS (below) to 3500 psi. No test. Test from above to 3000 psi. Good test. RIH to 1494', test from below. to 2500 psi. No test. Test from above to 2500 psi. Good test. RIH to 295T,test from below to 2500 psi. No test. Test from above to 2500 psi. Good test. Printed, 6/5/2006 11,44,57 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 5130/2006 22:00 - 23:30 1.50 CASE N CEMT DECOMP Blow down surface equipment. POOH 2957' to 284'. Stand back drill collars. Lay down RTTS. Clear floor. 23:30 - 00:00 0.50 CASE N CEMT DECOMP Make up mule shoe, run in hole to 563' 5/31/2006 00:00 - 01 :00 1.00 CASE N CEMT DECOMP RIH 563' to 2875' 01 :00 - 02:00 1.00 CASE N CEMT DECOMP Cut and slip 75' drilling line. Inspect and service Draworks. 02:00 - 02:30 0.50 CASE N CEMT DECOMP Service Top drive. 02:30 - 03:00 0.50 CASE N CEMT DECOMP Tag bottom at 2964'. Rig up to squeeze cement. 03:00 - 04:30 1.50 CASE N CEMT DECOMP Wait on cementers. 04:30 - 06:00 1.50 CASE N CEMT DECOMP Rig up to squeeze cement. Pre-job safety meeting. 06:00 - 07:00 1.00 CASE N CEMT DECOMP Pump 5 bbl. H20 - pressure test lines to 3000 psi. Pump 5 bbl. H20, 10 bbl. 15.8 ppg class G cement. Displace with 5 bbl. H20, 21.5 bbl. 9.8 ppg. brine. POOH 2961' to 2680', circulate bottoms up, 500 gpm @ 750 psi. 07:00 - 14:00 7.00 CASE N CEMT DECOMP Close pipe rams, squeeze cement. Stage pressure up in 500 psi increments 10 minutes each to 3000 psi. Hold 3000 psi for 1 hour - bleed pressure down to 2500 psi & hold while waiting on cement compressive strength of 500 psi. Bleed pressure, blow down surface equipment. 14:00 - 15:00 1.00 CASE N CEMT DECOMP POOH 2680' to surface, lay down mule shoe. Clear floor. 15:00 - 16:30 1.50 CASE N DECOMP Make up cement drilling assembly to 307'. Change out elevators. RIH to 2735'. Install blower hose. 16:30 - 22:30 6.00 CASE N DECOMP Wash from 2735' 84 gpm @70 psi. Tag cement @ 2753'. Wash soft cement to 2763',345 gpm @ 830 psi. Circulate bottoms up @ 2763'. Drill cement from 2763' to 2864'. Circulate bottoms up @ 2864'. Wait on cement 1 hour. Drill cement 2864' to 2874' circulate bottoms up. Wait on cement for 1 hour. Drill cement 2874' to 2884', circulate bottoms up. Wait on cement for 1 hour. Drill 2884' to 2964', circulate bottoms up. 22:30 - 00:00 1.50 CASE N DECOMP Stage pump to 2500 psi. Test 7 5/8" casing and cement squeeze @ 2964' to 2500 psi. Chart and hold for 30 minutes. Blow down surface equipment. 6/1/2006 00:00 - 01 :00 1.00 CASE P DECOMP Drill junk & baffle plate 2964' - 2969',205 gpm @350 psi. 90 RPM, 15k WOB, 2500 troque, Up wt. 80k, down wt. 75k,rotating wt. 80k. 01 :00 - 01 :30 0.50 CASE P DECOMP RIH 2969' to top of sand at 3978', 01 :30 - 02:30 1.00 CASE P DECOMP Wash down 3978' to 3984'. Circulate hi-vis sweep @ 500GPM 1950 psi. Verify sand returns. 02:30 - 04:30 2.00 CASE P DECOMP Pressure test casing to 2500 psi 04:30 - 06:00 1.50 CASE P DECOMP POOH from 3945' to 307'. Change out handling equipment. POOH with BHA from 307'. Break bit, empty boot baskets. 06:00 - 08:00 2.00 CASE P DECOMP Make up reverse circulating basket assembly. RIH with drill collars to 314'. Change out handling equipment. RIH 314' to 3960'. Tag sand @ 3984' 08:00 - 09:00 1.00 CASE P DECOMP Break circulation 350 gpm @ 1900 psi. Circulate down with reverse basket from 3984' to 3995'. Remove blower hose. 09:00 - 11 :00 2.00 CASE P DECOMP POOH 3995' to 314'- Break off shoe and retrieve junk. Clean boot baskets. 11 :00 - 13:00 2.00 CASE P DECOMP Make up reverse circulating basket and RIH to 314'. Change out handling equipment. RIH 314' to top of sand @ 3986' 13:00 - 13:30 0.50 CASE P DECOMP Wash from 3986' to 3996' 400 GPM @ 2500 psi. Blow down top drive. Printed: 6/5/2006 11 :44'57 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 61112006 13:30 - 16:30 3.00 CASE P DECOMP POOH from 3996' to 313'. Stand back drill collars. Lay down reverse circulating basket. Clear floor 16:30 - 18:00 1.50 CASE P DECOMP Make up 7 5/8" RBP overshot. Run drill collars out of derrick. Change handling equipment. RIH 279' to top of sand @3987' 18:00 - 19:30 1.50 CASE P DECOMP Rig up circulating lines and reverse circulate 40 bbl. Hi-Vis sweep. Displace well to 8.5 ppg seawater while washing down to RSP. Tag RBP @ 4005'. Reverse circulate hole clean, 350 gpm @ 1750 psi. Engage RSP, rotate and pick up to release. Slow down surface equipment. 19:30 - 22:00 2.50 CASE P DECOMP POOH from 4005' to 279'. Stand back drill collars. Lay down RBP. Clear floor, 22:00 - 22:30 0.50 CASE P DECOMP Test casing to 2500 psi. Chart and hold for 30 minutes. 22:30 - 00:00 1.50 CASE P DECOMP Pick up 3 3/4" reverse circulating jet basket tools. Rig up 2 7/8" handling equipment. Make up tools to 41'. 61212006 00:00 - 01 :00 1.00 CASE P DECOMP Make up BHA to 435'. Change out handling equipment. 01 :00 - 04:00 3.00 CASE P DECOMP RIH 435' to 11,544'. Tag tubing cut off. 04:00 - 05:30 1.50 CASE P DECOMP Dress tubing stump @ 11,544'. Clean out tubing to XXN nipple @ 11,616'. Reverse circulate 300 gpm @ 1825 psi. Pump dry job, and blow down surface equipment. 05:30 - 11 :00 5.50 CASE P DECOMP POOH 11,616' to 435'. Stand back drill collars. Rig up 2 7/8" handling equipment. Lay down reverse circulating basket. Clear floor. 11 :00 - 15:30 4.50 CASE P DECOMP Make up 3.625" GS spear and shear pin guide assembly. Rig down 2 7/8" handling equipment. Run drill collars out of derrick to 430'. RIH 430' to 11,449'. 15:30 - 16:30 1.00 CASE P DECOMP PJSM cut 68' drilling line, service drawworks & splines. Inspect brushes, drum, brakes, and chain. Service crown. 16:30 - 17:00 0.50 CASE P DECOMP Service top drive. install blower hose. 17:00 - 18:30 1.50 CASE P DECOMP RIH 11,449' to 11,616'. Spear into TIP. Pick up 25k over to free. Well took 50 bbl. seawater initially then losses @ 4 SPM. Drop dart & open circulation sub, Slow down top drive. Fill on back side with charge pump. 18:30 - 00:00 5.50 CASE P DECOMP Lay down drill pipe from 11,616' to 3702'. Double displacing with seawater. Total losses 320 bbl. 6/3/2006 00:00 - 02:30 2.50 CLEAN P CLEAN POOH 3702' to 430' laying down pipe. 02:30 - 04:30 2.00 CLEAN P CLEAN Lay down drill cOllars,jars,and bumper sub. Rig up 2 718" handling equipment. Lay down 2 7/8" drill pipe. Lay down spear and plug. Clear floor, 04:30 - 07:30 RUNCMP PJSM Pull wear ring. Rig up compensator, power tongs and tubing equipment. Pre job safety meeting on running completion. 07:30 - 22:00 14.50 RUNCMP Run 41/2" 12.6# 13CR Yam top tubing to 11,485', make up torque = 4440 ft/lbs. 22:00 - 23:00 1.00 RUNCMP Space out - swallow tubing stump - Shear set screws - bottom out at 11,556' 10k down, Run total of 270 jts tubing, 4 x GLM's,3 x X nipples - 1 x unique machine overshot. Tubing up wt. 155k down wt. 105k. 23:00 - 00:00 RUNCMP Rig down compensator, change out elevators,Make up landing joint and hanger. Land hanger,run in lock down screws. Rig down 4 1/2" tubing equipment. Clear floor. Rig up circulating lines to annulus. 6/4/2006 00:00 - 02:30 RUNCMP Rig up circulating line in cellar. Pump 225 bbl. inhibited seawater down annulus @ 3 SPM. Displace with 89 bbl. clean Printed: 6/5/2006 11 :44:57 AM .. , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-35 R-35 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 5/22/2006 Rig Release: 6/4/2006 Rig Number: 2ES Spud Date: 12/8/1993 End: 04:30 - 05:00 05:00 - 07:30 07:30 - 09:00 09:00 - 11 :00 11 :00 - 11 :30 11 :30 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 18:00 0.50 RUNCO P 2.50 BOPSU P 1.50 WHSUR P 2.00 WHSUR P 0.50 WHSUR P 2.00 WHSUR P seawater to 3361 '. Make up landing joint & drop 1 7/8" ball and rod. Pressure up tubing to 3500 psi to set packer. Hold and chart for 30 minutes.. Bleed off tubing to 1500 psi and pressure up annulus to 2500 psi. Hold and chart for 30 minutes. Bleed off tubing and observe DCK valve sheer. RUNCMP Dry rod TWC and test to 1000 psi from below. RUNCMP Nipple down BOP. RUNCMP Nipple up adapter flange and tree. RUNCMP Test Tree to 5000 psi. RUNCMP Rig up drill site maintenance lubricator and pull TWC. RUNCMP Rig up circulating lines to Little Red Hot Oil Services and reverse circulate 85 bbl. Diesel freeze protect. 2.5 bbl.lmin @800 psi. RUNCMP U-Tube annulus and tubing. RUNCMP Rig down circulating lines. RUNCMP Dry rod BPV and test from below to 1000 psi. Rig down Little Red Hot Oil and fill tree with Diesel. RUNCMP Rig down 2nd annular valve - secure well. Rig release 06/04/2006. 2.00 WHSUR P 0.50 WHSUR P 1.00 WHSUR P 1.00 WHSUR P Printed, 6/512006 11,44,57 AM RECE\VED Schlumberger JU~~ 0 8 2006 NO. 3828 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth \sSiOO ,~~ C1l& Gas CCI1S· ecmm ,~~ "" ,~"._.. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .., \.~ t Field: Prudhoe Bay \ q '3 Well Job# Loa DescriDtion Date BL Color CD IP2·22 1'1 t- - 8¿A 11136744 GLS 11/13T05 1 IP2·16 fC,~ - I~-~ 11058238 WFL 08/18/05 1 P2-36 i C¡'f - I (-,() N/A LDL 07/13/05 1 P2-50B ¡ ¿;¡'/\ - 0<7 e.- N/A LDL 07/16/05 1 16-03 !~i -(, II 11076454 INJECTION PROFILE 07/28/05 1 P2-36 l'ì1 -1Gb 11051061 GLS/LDL 06/15/05 1 4-18/5-30 ì~'Ý, -! /6 10564459 PSP GLS 04/18/03 1 1-33B/L-24 J q ')( - ::J-<;ó- 10889175 SCMT 10/12/04 1 04-41A c) ~ -o5S N/A LDL 07/18/05 1 15-09A C¡ '_ - ,~<7< N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09-17 ~ ~ -r.:;z,"i( 11076460 INJECTION PROFILE 08/18/05 1 16-09A C¡ - (,,?\-K 11051089 PRODUCTION LOG W/DEFT 08/18/05 1 16-11 i'"7([î -II'$( 11058249 LDL 09/14/05 1 17-02 I ~C ; O--rO N/A SENSA MEMORY LDL 10/17/05 1 NK-38A .0(~<../ -;:::¡ 'I I 10687734 MDT 02/27/05 1 R-35 ¡C¡'~-/f¡ 11212863 USIT OS/26/06 1 D-09A I e¡c; - 0-; .,.<,- 11221576 USIT OS/27/06 1 L5-16 ;"i("1- - n 1(::' 11212864 USIT OS/28/06 1 K-08A :::J r"'~~ -- ILl ..... 11054182 MCNL ~ ì,,~..-¡q::.l 06/06/05 1 1 H-04A _V:::¡ "/f,- / 10715365 MCNL c;:t. 1:-'; <./'7 "=? 11/27/03 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2636 ATTN: Beth (J / ('~ 1" I\..!... " Vvv 06/01/06 e e R-35, sundry #306-144 e lq~..lil e Winton, As per our conversation, regarding R-35 work over (sundry # 306-144), I would like to let you know that we are no longer performing any of the work on the 10 3/4" surface casing, nor will we be replacing the wellhead. Please let me know if you have any questions or comments, Howard Howard West RWO Engineer 564-5471 (w) 230-6629 (c) . ¡ ¡' \ ~ (" SC':;~\\h\!E}- .J '" ï'~ ' ti 1 of 1 5/25/2006 2:33 PM e e FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OILAlQ) GAS CONSERVATION CO.MMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard West Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 17\ \o...y \'<> Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-35 Sundry Number: 306-144 Dear Mr. West: - rl "'Ii' ¡\\jI,.~N\~V P ~)~:-5'k'~:~ y:, \~"... l~ a:t ?'; 1(' '1.;.1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this U day of April, 2006 Encl. /"ffcwJ~t'~ 0 l{ #0 2j / ~o/00 l' f ~ STATE OF ALASKA e ALASKA 01 AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ()trJ 1-/2 tj b 20 MC 25 280 Alas!\? 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program \NG f\- 4( 'LIt z.o 0 (P RECEIVED .APR 2 0 ð! ,1\ ..., .,!,,,""",r> v GomrmS5!Oil o Suspend 0 Operation Shutdown 0 Perforate 0 Other œI Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well œI Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): ADL 028278 11. , " " ' , H_~"" Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12088 9156 11623 CasinQ LenQth Size MD Structural Conductor Surface Intermediate Production Liner 8. Property Designation: 80' 3092' 12044' 4. Current Well Class: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 193-181/ 6. API Number: 50-029-22424-00-00 /' 99519-6612 53.4' 9. Well Name and Number: PBU R-35 / 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ..,....(',L\\"., Effective Depth TVD (ft) Plugs (measured): / 8730 11623 , TVD Burst "." Junk (measured): None Collapse 20" 10-3/4" 112' 3127' 112' 3062' 1490 5210 470 2480 7-5/8" 12076' 9145' 6890 4790 Perforation Depth MD (ft): I Perforation Depth TVD (ft): 11770' - 11939' '/ 8865' - 9019' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'SABL-3' packer 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: Tubing Size: 4-1/2",12.6# Tubing Grade: I Tubing MD (ft): , 13Cr 11636' / Packers and SSSV MD (ft): 11575' /' 13. Well Class after proposed work: / o Exploratory 181 Development 0 Service MaQ006 Date: 15. Well Status after proposed work: 181 Oil 0 Gas / o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Howard West Title Drilling Engineer Sianature 1lJ I! LJ~ . . , Contact Howard West, 564-5471 -' Prepared By Name/Number: Terrie Hubble, 564-4628 Phone 564-5471 Commission Use Only Date '( - I'{ - DIP I Sundry Number: ?r1 n- :L~ 1 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other:UC;. t- E t? P E +0 ;Çoo pr,·. Subsequent Form Required: I ~ - Approved By: Form 10-403 Revised 07/2005 RBDMS 8Ft APR .'l 4 7006 4-l!) ! )'(/t?{ r~ONER o RrG \ ~í-Äl APPROVED BY THE COMMISSION Date 4 .."t/-o6 Submit In Duplicate e e Well Status: Shut-in producer. Well has surface casing leak. / Maximum Anticipated Surface Pressure: -2,500 p.s.i. / Sea e' trieve existing 4.5", 12.6#, 13Cr-80 completion down to the tubing cut @ - 55 MD. Replace existing wellhead with FMC GEN 5 wellhead confi tion. Replace -3000' of 7 5/8" casing and cement to surface. Replace top 2 joints of 10 %" casing and cement to surface. Re-complete with 4.5", 12.6#/ft, 13Cr80 Vam Top tubing with 75/8" x 4-1/2" stacker packer. 1. MIRU Work Over Rig. Pull BPV. Fully circulate thru the pre-RWO tubing cut with heated seawater. 2. Set and test TWC in tubing hanger. ND tree and adapter flange. NU BOPE/ Test BOPE per BP and AOGCC regulations to 250 psi (low)/3500 psi (high). 3. Decomplete well down to the tubing cut. 4. Set 7-5/8" Model 3L RBP just above tubing stub @ 11550' MD. PT casing to / 3500 psi. 5. Run 7-5/8" USIT to locate top of cement in 7-5/8" x 10-3/4" annulus. 6. Set 2nd RBP -1000 ft below the TOC indicated on the USIT log. Spot -20' of /' sand on RBP. 7. Mechanically cut the 7-5/8" casing in the 1st full joint above the TOC. 8. Pull 7 5/8" down to the cut. RIH with 10 %" casing scraper down to 7 5/8" tubing stub. 9. Set 10-3/4" Model3L RBP just above tubing stub. Spot -30' of sand on RBP. / 10. Mechanically cut the 10-3/4" casing in the 2nd joint below the wellhead. ND stack and tubing spool, cut off starting head. 11. Pull 1 0-314" down to the cut. RIH and back off stub leaving connection looking up. 6"') 12. RIH wI 10-3/4" screw in sub, screw back in to casing string. Fully e nt to /' surface. ". 13. Cut the excess 1 0 3/4" at the surface and install new starting head. 14. NU 11" x 11" 5M tubing spool. 15. NU and test BOPs, and new spool as per step #2. I / 16. Test casing to 3000 psi f/30-min. 17. RIH with DP and circulate the sand from the 103/4" RBP. Recover the RBP. 18. RIH and back off stub leaving connection looking up. 19. RIH wI 7-5/8" screE' su', screw back in to casing string with premium // connections. Fully em t to surface. Land 7-5/8" on slips. 20. Cleanout shoe-tra ",the 7-5/8" RBP. PT 7-5/8" casing to 3500psi f/30 min. 21. RIH with DP and circulate the sand from the 7 5/8" RBP. Recover the RBP. 22. RIH, retrieve lower 7 5/8" RBP. 23. Run new 4.5", 12.6#/ft, 13Cr80 stacker packer completion. Set and test packer to 3500 psi. ./ 24. RDMO. TREE = 4-1/16" 5M CIVV SAF TES: CHROM E TBG. I W8...LHEA 0 = 13-5/8" 5M FMC R-35 ACTUA TOR = BAKER KB. ELEV = 54.8' BF. ELEV = 21.7' KOP= 1000' 2017' H4-1I2" OTIS HXO SSSV NP, ID = 3.813" 1 Max Angle = 55 @ 10600' . Datum MO = 117S8' DatumlVD= 8800' SS 110-3/4" CSG, 45.5#, NT-80 LHE, ID = 9.953" I 3125' r--J ~ GAS LIFT MANDR8..S ST MD lVO DEV lYPE VLV LA TCH PORT DATE 6 3053 2935 17 CAMCO DOME BK-5 16 12/13/2005 5 5544 4882 53 CAMCO DMY BK-5 0 12/13/2005 Minimum ID = 3.725" @ 11623' L 4 7940 6370 53 CAMCO DOME BK-5 16 12/13/2005 3 9658 7396 54 CAMeO DMY BK-5 0 12/13/2005 4-1/2" OTIS XN NIPPLE 2 11048 8236 47 CAMCO DMY BK-5 0 12/13/2005 1 11503 8594 29 CAMeO DMY BK-5 0 12/13/2005 I I 11520' H4-1I2" OTIS X NIP, 10 = 3.813" I ~ ,.,.....,. 11575' 7-5/8" x 4-112" BKR SABL-3 PKR I """'" W/ K-22 ANCHOR LA TCH, ID = 3.937" . 11606' H4-1/2"OTISXNIP,ID=3.813" I 11623' H4-1/2"OTISXNNIP,10=3.725" -I 11623' H4-1/2" XXNTTP(12/13/0S) I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958"1 11636' 11636' 1-l4-1/2" WLEG, 10 = 3.958"1 I 11634' H 8..MO TT LOGGED 02/08/94 I I ÆRFORA TION SUt-RMRY I REF LOG: SBT/GRlCCL ON 01129/94 ANGLE AT TOP ÆRF: 24 @ 11770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 " 6 11770 - 11810 0 05/18/94 3-3/8" 6 11899 - 11939 0 02/01/94 I PBID I 11995' 17-S/8" CSG, 29.7#, NT-9S HS, ID = 6.87S" I 12075' DATE REV BY COfvtÆNTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 12/25/93 ORIGINAL COMPLETION 12/13/05 MORfTLH XXN TTP SET I W8...L: R-35 09/24/01 RNITP CORRECTIONS 12/13/05 DAVIPJC GL V C/O ÆRMIT No: '1931810 08/26/01 JJ/KAK SET XXN PLUG API No: 50-029-22424-00 11/28/03 KDClPAG WAWER SAFETY NOTE SEC 32, T12N, R13E 10/16/0S RPHlPJC WAWER SFTY NOTE D8..ETED 12/08/05 RBRlPJC PULL PLUG @11623' (11/30/03) BP Exploration (Alaska) . . I TREE = 4-1/16" 5M CIW R-35 SA TES: CHROMETBG. W8.LHEAD = 13-5/S" 5M FMC ACTUATOR = BAKER KB. 8.EV = 54.S' Proposed BF. 8.EV = 21.7' I KOP= 1000' I I I 1-14-1/2" HES X NP, II) = 3.S13" Max Angle = 55 @ 10600' Datum MD = 1175S' DatumlVD= SSOO' SS ST M) lYFE VEl:oJe 110-3/4" CSG, 45.5#, NT-SO LHE, to = 9.953" 4 3378 1112" MÆ IXR I 3125' 3 6792 1112" MÆ CG..V Top 2 joints: 45.5#, TC-II ./ 1 #### 1112" WM: CG.. V Minimum ID = 3.725" @ 11623' I I I 1-14-112" OllS X NIP, II) = 3.S13" I 4-1/2" OTIS XN NIPPLE I 4-1/2" OTIS X NP, 11). 3.813" I I - . 7 5/S" x 4 1/2" Baker Chrome 5-3 I ~ 15< packer I . I 4-1/2" OllS XN NIP, II) = 3.725" I I I 11550' H 7 5/S"x 4-1/2" UMt Chrome Overshot I " :8 15< I 11575' 7-5/8" x 4-1/2" BKR SABL-3 PKR I W K-22 ANCHOR LATCH, II) = 3.937" 4-1/2" TBG, 12.6#, 13-CR. .0152 bpf, 11).3.958" 11636' I 11623' 4-1/2" OTIS XN NP, з 3.725" I 11636' 4-112" II'tIL.EG, з 3.958" I 1 I 11634' H 8.MD TT LOGGED 02108194 I ÆRFORATDN SUMMARY I] REF LOG: SBT/GRlCCl ON 01/29/94 ANGLE AT TOP ÆRF: 24 @ 11770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-318" 6 11770-11S10 0 05/1S/94 3-3/S" 6 11S99 -11939 0 02/01/94 I PBTD I 11995' I 7-5/S" CSG, 29.7#, NT-95 HS, II) = 6.S75" I 12075' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 12/25/93 ORIGINAL COM PLETION 12/13/05 MORITlH XXN TIP SET W8.L: R-35 09/24/01 RNITP CORRECTIONS 12/13/05 DAV/PJC GL V ClO PERMIT No: 'í931S10 OS/26/0 1 JJ/KA K SET XXN RUG API No: 50-029-22424-00 11/2S/03 KDClPAG WAIVER SAFETY NOTE SEC 32, T12N, R13E 10/16/05 RPHIPJC WAIVER SFTY NOTE D8.ETED 12/0S/05 RBRlPJC PUlL RUG @11623' (11/30/03) BP exploration (Alaska) STATE OF ALASKA '\ ALAt.) OIL AND GAS CONSERVATION COMrvla...,SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 1 ø: ~'ØO.& 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 53.4 KB 8. Property Designation: ADL-028278 11. Present Well Condition Summary: Total Depth measured 12088 true vertical 9156.04 Effective Depth measured 11995 true vertical 9070.77 Casing Conductor Surface Production ......~Gas. C.~ ~, WaiverD Time Extension nJMtlI ... Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory [] 193-1810 Service [] 6. API Number: 50-029-22424-00-00 9. Well Name and Number: li:r. Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development ß?'! Stratigraphic cr Stimulate D R-35 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 11623 TT None feet feet Length Size MD TVD 80 20" 91.5# H-40 32 - 112 32 - 112 3090 10-3/4" 45.5# NT-80 35 - 3125 35 - 3059.78 12043 7-5/8" 29.7# NT-95 32 - 12075 32 - 9144.12 Collapse 470 2480 5120 Perforation depth: Measured depth: 11770 - 11810 True Vertical depth: 8864.73 - 8901.31 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Burst 1490 5210 8180 11899 - 11939 8982.78 - 9019.44 4-1/2" 12.6# 13CR80 29 - 11636 4-1/2" Baker SABL-3 Packer 5tANNEJ{) \O]AN 2 0 2005 11575 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x RBDMS 8Ft JAN 1 9) 2006 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure Tubing pressure SHUT-IN SHUT-IN 15. Well Class after Droposed work: Exploratory r Development R' Service r 16. Well Status after proposed work: Oil P' Gas r WAG r GINJ r WINJ r WDSPLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A / Title Data Mgmt Engr Signatur~~~" ??~ Phone 564-4424 Form 10-404 Revised 04/2004 0 RIG I N A L Date 1/17/2006 Submit Original Only ) ) R-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/13/2005 ***WELL SI ON ARRIVAL*** (secure well) RAN BRUSH & 3.70 G-RING TO XN-NIPPLE @ 11 605' SLM. SET 4.5" XXN PLUG @ 11,605' SLM. RAN CHECK SET TO PLUG, GOOD SET. SET 4-1/2" WHIDDON CATCHER SUB @ 11597' SLM... PULL S/O FROM STA #1 @ 11497' SLM. ***CONTINUE WSR TO 12-14-05*** 12/14/2005 Continued from 12-13-05 T/I/O = 1850/1820/0 (SECURE WELL) Pumped 10 bbls meth spear and 580 bbls crude to circ out Tbg & LA. Pumped 6.3 bbls crude for (CMIT Tx LA.) (PASSED) Tubing lost 70 psi. LA. lost 60 psi. in 1 st 15 min. Tubing lost 0 psi. LA. lost 10 psi in 2nd 15 min. Bleed TxIAP. Freeze protect flow line per WOA procedure. Final WH P's=O/O/O FLUIDS PUMPED BBLS 621 Crude 17 Meth 638 TOTAL AOGCC ind±vidual Well Geological Mater±als inventory Page · Date · 1 10,/13/'95 T DATA_PLUS / 93-181 60212 . T I14i0-1!994, CH-CN/GR / 93-181 606~// T It623-12070, OH-HWD e~i~i 407 o/ ~ COMP DATE'02/01/94 93-181 DALLY WELL OP~/R 12/09-12/26/93 c-'-~-181 .oUR~m~ R 0.00-12088, ~P~RR~ SUN 93~i8i ~L/GR L 11400-11986 9J ~8i ~-Ri~-~f ~ _ , ~ , Ew~, F~T L 11648-12088 MWD-MD 93-181 ~ '~R/EWR/FET L 8760-9183, MWD-TVD 9~-~81 ~/CCL (JWL). L 11400-11986 _- _ /~ /r,~~ 1700 11816 Q3~-!8~ PFC/~n/~ L I - 93-181 ~C/GR/CL (PERF) L 11800-11973 ~-Isi ~is L iisoo-iis7o 93~18i PL~ L ii65o-ii93o 9?j~18~ ~S (GAS LIFT) L 2c~80-it560 93-i8! ~S {STAT/TEHP) L 11621-11991 eo 181 ~'' .... ~ /eR/CC~ L 11400 11986 RUN DATE_RECVD 03/09/94 04/iS/94 02/ii/94 02/ii/94 02/ii/94 03/09/94 01/19/94 01/'19/94 03/09/94 06/08/94 03/09/94 05/i0/94 06/14/94 05/10/94 04/12/94 03/'09/94 Are dry ditch samples required? Was the well cored? yes ne Are we~ ~ tests ree~uired? yes Well is iii compiia:~ce ' I al COMMENT S yes And receiv~ed?~~s-- no Analysis & description received? yes no Received? yes no ~1~ ~ }% ~o ilo / STATE OF ALASKA ALA,d-~-"--"IL AND GAS CONSERVATION COMMISSI¢" REPORT f.,,- SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing __ Repair well Perforate × Other_Z_ /~/ ~ 6. DaturC~ef'~',jatlgn ~,,,D, F or KB) l /~' ~ ')K~E=53. 4 feet 7. Unit or Properb] Prudhoe Bay Unit 8. Well number ' 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 608' NSL, 826' EWL, SEC. 32, T12N, R13E At top of productive interval 1740' SNL, 2008' EWL, SEC. 33, T12N, R13E At effective depth 3456' SNL, 3240' WEL, SEC. 33, T12N, R13E At total depth 1767'SNL, 2093' WEL, SEC. 33, T12N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service R-35(23-33-12-13) 9. Permit number/approval number 93-181 / 10. APl number 50- 029-22424 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 12088 feet 9183 feet Effective depth: measured 11995 feet true vertical 9098 feet Plugs (measured) Junk (measured) Casing Length Size Structural -- Conductor 110 20" Surface 3074 '0 3/4" Intermediate 12023 7 5/8" Production -- Liner Perforation depth: measured 11770'-11810', 11899'-11939' Cemented Measured depth True vertical depth BKB 280 c.f. Class "G" 163 163 1920/431 c. f CSII! "G" 3127 3061 1145 sx Class "G" 12076 9144 true vertical subsea8811L8848~892958966' Tubing (size, grade, and measured depth) 4-1/2",13CR80@ 11636' Packers and SSSV (type and measured depth) Packer @ 11575', SSSV @ 2017' RECEIVED jUN ,A. , sva & Gas Cons. Commission , ~nch0r~ 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1589 ~ 351 26 1970 4517" 5278 158 261 Tubing Pressure 225 134 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby ce. rtify that t..he~foregojp~j~s t.~/?d correct to the best of my knowledge. S igne~'~,,{,,2,,vl~ (/'/ ,,~~,~ Title Senior Technica/ Assistant /I Form 10-4-"~ F~ev (:J6/15/88 7 ' D at e SUBMIT IN D~CPL/[CATE 5/15/94 5/18/94 5/22/94 WELL R-35(23-33-12-13) Frac/Addperf Operation Performed a Hydraulic Fracture using the following fluids: Fluid Sununary 20/0 20 Stage pad 12/0 32 Stage 1 ppg 7/0 39 Stage 2 ppg 1/0 40 3 ppg. 1/0 41 4 ppg 2/0 43 5 ppg 3/0 46 6 ppg 5/0 51 7 ppg 6/0 57 8 ppg 67 209 Pad at perfs 79 1 ppg on perfs 86 2 ppg on perfs 87 3 ppg on perfs 88 4 ppg on perfs. 90 5 ppg on perfs 93 6 ppg on perfs 98 7 ppg on perfs 789 BBLS TOTAL FLUIDS PUMPED (LOAD VOLUME) The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 11770 - 11810' MD Performed a Hydraulic Fracture using the following fluids: Fluid Sununary Establish rate with 40g gel 30/0 30 Stage pad 183 213 Pad at perfs 424/0 454 Stage 1 ppg 20/40 CL 183 637 1 ppg on perfs 189/0 643 Stage 2 ppg 28/0 671 3 ppg. 38/0 708 4ppg 46/0 754 5ppg 52/0 806 6ppg 20 826 2 ppg on perfs 48 854 3 ppg on perfs 56/0 862 7ppg 29 891 4 ppg on perfs. 60/0 922 8ppg 15 937 5 ppg on perfs 55 977 Design TSO. 67 989 6 ppg on perfs 123 1045 7 ppg on perfs 183 1105 8 ppg on perfs 2841 RECEIVED dUi'q ~'~' ~,~,~" Anchor~ ". TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME RECEIVED JUN 1'-i i994 AJaska Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE~ AK, 99501. USA .. Date: 9 June 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, 'please'find the data as described below: -. .- . _ · q[~ P-03 (12-32-11-13) · . ~5--[~1 R-35 23-33-12-12) ~__ ~,0[0 H-..17 (34-15-11-13) ~ DESCRIPTION /1 PLS FINAL BLUELINE 1 PLS FINAL RF SEPIA ',/1 PLS PROFILE FINAL BL 1 PLS PROFILE RF SEPIA /1 PLS FINAL BL 1 PLS FINAL RF SEPIA /'1 PLS iNJPROF.FINAL BL 1 PLS INJPROF.RF SEPIA /1 PLS FINAL BL 1 PLS FINAL RF SEPIA ECC No. Run ~ 1 5073.02 Run ~ 1 Run ~ 1 5716.02 Run ~ 1 Run ~ 1 6136.05 Run # 1 Run # 1 Run ~ 1 5833.05 Run ~ 1 5665.06 Run ~ 1 · /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 585.06 Run ~ 1 Please ~ign and return to: Atlas Wireline Services i! 5600 B Street Suite 201 : Anchorage, AK 99518 · Attn. Rodney D. Paulson Received by:" .% i .. Date: Please s LdO' and return to: Pe%ro~echnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 26 May 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION R-04 (22-05-11-13) A-ii E-06 (33-6-11-14) F-Ii F-14 (33-35-12-13) R-13 B-02 (32-11-14) R-35 (23-33-12-13) X-07 (43-08-10-14) S-32 (33-26-12-12) 1 CN/GR FINAL BL CN/GR FINAL RF SEPIA /1 CCL/PACKER FINAL BL 1 CCL/PACKER RF SEPIA / ! SPNR/TEMP FINAL BL 1 SPNR/TEMP RF SEPIA / 1 DTEMP FINAL BL 1 DTEMP FINAL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL /1 PFC/PERF RF SEPIA Cont/ ECC No. Run # 1 5627.05 Run ~ 1 Run # 1 3560.02 · Run ~ 1 Run # 1 3573.01 Run # 1 Run # ! 1022.02 Run # 1 Run ~ 1 959.07 Run # 1 Run ~ 1 4515.04 Run ~ 1 Run # 1 5803.04 Run # 1 Run $ 1 6136.04 Run # 1 Run $ 1 4046.02 Run ~ 1 Run $ 1 6202.00 Run # 1 R VED JUN 08 Alaska Oil & Gas Cons. C, ornmission Anchorage RECEIVED Alaska 011 & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 April 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION °]'~-.i,'~\ R-3S (23-33-12-13) 1 PLS PROFILE FINAL BL /1 PLS GASLFT FINAL BL 1 PLS PROFILE RF SEPIA //1 PLS° GASLFT RF SEPIA ~%'1~ R-32 (22-33-12-13) /1 PLS INJPROF.FINAL BL 1 PLS INJPROF.RF SEPIA --7-q.-%'L R-06 1 PLS FINAL BL /1 PLS FINAL RF SEPIA ~b~. F-14 (33-35-12-13) PLS FINAL BL 1 PLS FINAL RF SEPIA /I PLS FINAL BL 1 PLS FINAL RF SEPIA ~0.~' F-14 (33-35-12-13) 1 PLS FINAL BL /~ PLS FINAL ~ SEPIA 1 PFC/PERF RF SEPIA $L-190 ~-17 (34-15-1[-13) /1 DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA c~ Run ~ 1 Run # 1 Run ~ 1 Run ~ 1 Run ~ 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run ~ 1 Run ~ 1 Run.~ Run Run # 1 Run ~ 1 ECC No. 6136.03 6106.05 1680.02 959.06 3560.01 959.05 .. 6074.03 ... 5665.05 I'1 I~ I/1__1 N I~ S I=: F! L/I I::::: E g '7- WELL LOG TRANSMITTAL To: State of Alaska April 15, 1994 Alaska Oil and Gas Conservation Comm. Atto: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - R-35 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG Format LIS Tape with Verification Listing. RECEIVED APR 1 8 lg 4 Date 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 · (907)563-3256 ° Fax (907)563-7252 A Baroid Company ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 6136.02 Data: PL Dear Sir/Madam, Reference: BP R-35 (23-33-12-13) PRUDHOE BAy NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PLS STATIC FINAL BL PLS~TATI~~EPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 February 1994 RE: Transmittal of Data ECC ~: 6136.01 Data: PL Dear Sir/Madam, Reference: BP R-35 (23-33-12-13) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL Sent by U.S. MAIL Run # 1 Run # ~D Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 February 1994 RE: Transmittal of Data FCC #: 6136.00 Data: CN/GR Dear Sir/Madam, Reference: BP R-35 (23-33-12-13) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL SBT/GR/CCL FINAL BL GR/CCL FINAL BL CN/GR FINAL BL GR_~_~ FINAL RF (~b~ CN~GR FINAL RF Run # 1 Run # 1 Run # 1 Run # ~ [[~00--~[~ ~ Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: PERMIT DATA 93-181 DGR/EWR/FET 93-181 DGR/EWR/FET 93-181 407 93-181 DAILY WELL OP. AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 93-181 SURVEY L 11648-12088, MWD-MD L 8760-9183, MWD-TVD R COMP DATE:02/O1/94 R 12/09-12/26/93 R 0.00-12088, SPERRY SUN Page: Date: 03/03/94 RUN DATE_RECVD 01/19/94 01/19/94 02/11/94 02/11/94 02/11/94 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial yes no yes no Comments ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LI=TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I SUSPEI~I3ED [] ABANDONED [] SERWCE [] 2. Name of Operator 7. Permit Number BPExploration ~'/'~ ~/t~[Z~'~ L 93-181 3. Address / / i 3. APl Number !x~ ~ 50 029-22424 P. 0. Box 196612, Anchorage, Alaska 99519-6612 - 4. Location o! well at surface 9. Unit or Lease Name 608' NSL, 826' EWL, SEC. 32, T12N, R13E ~ u.~., .......... i ' i. ~i ~ 5::~'~.~ Prudhoe Bay Unit At Top Pr°ducin9 Interval !c~/ ~--~ ~f~ R-35(23-,.?13-12-1~) 1740' NSL, 2008'EWL, SEC. 33, T12N, R13E ~ ~.~,~,~:~,~, ~ :i.:~-~ 111. Field and Pool At Total Depth i ~ ....... '~ _ i ~.:~.~..,~-,~'.~,?: Prudhoe Bay Field/Prudhoe Bay Pool 1767'NSL, 2093'EWL, SEC. 33, T12N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 53.4' I ADL 28278 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offsho re 16. No. of Completions 12/8/93 12/20/93 2/1/94 ~"I N/A feet MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Survey ~:~0. Depth where SSSV set ~21. Thickness of Permafrost 12088' MD/9183' TVD 11995' MD/9098' TVD YES E] NO []! 2017' teet MD! 1900' (Approx.) 22. Type Electric or Other Logs Run RLL/GR/MWD 23. CASING, LINER AND CEMENTING SE'I-rl,~IG DEPTH MD CASING SIZE W3'. PER FT'. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 112' 30" 280 cu fl C/ass "G" (Approx.) 10-3/4" 45.5/1 NT-80 35' 3127' 13-1/2" 192o cu ft cs IIl/431 cuff"G" 7-5/8" 29. 7# L-80 32' 12076' 9-7/8" 878 cu fl C/ass "G" 24. Perforations open to Production (MD+TVD of Top and Boltom and 25. TUB~RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter3-3/8", 6 spf 4-1/2; 13CR80 11636' 11575' MD TVD 11899'-11939' 9010'-9047' 26. ACID, FRACTURE, CEMENT SQUEE2~ ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED Freeze protected tubing & annulus w/ 85 bb/s diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/2/94 I F/owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 3AS-MCF WATER-BBL CHOKE SiZE IGAS-OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED=~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED FEB 1 1 1994 ~,,~aska UiI & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. { 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 11755' 8822' Shublik 11804' 8867' Top Sadlerochit 11895' 8952' 31. LIST OF ATI'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drilling Engineer Su.oervi~Qr Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 FEB ! 1 1994 ~l~ska Oil & Gas Cons. Commission Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: R-35 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/08/93 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 12/09/93 (1) TD: 1050' ( 0) 12/10/93 (2) TD: 3145' (2095) 12/11/93 (3) TD: 3145' ( 0) 12/12/93 ( 4) TD: 4380' (1235) 12/13/93 (5) TD: 5840' (1460) 12/14/93 ( 6) TD: 6925' (1085) DRILLING 13 1/2" HOLE MW: 8.8 VIS:300 MIRU ON R-35 FROM R-32I. RIG UP FLOOR. NU DIVERTER SUSTEM, TAKE ON WATER AND MIX SPUD MUD. RIG ACCEPTED AT 10:00 HRS ON 12/08/93. FUNCTION TEST DIVERTER. PICK UP BHA TO FLOOR AND STRAP. M/U BHA, DRESS 3 STABILIZERS, CHANGE OUT MOTOR DUE TO THREAD DAMAGE. POH TO DE-ICE MOTOR. SPUD WELL AT 20:00 HRS 12/08/93. DRILL FROM 100-135'. P/U STABILIZER AND ORIENT SUB WITH MWD. WORK ON FLOW LINE AND UNPLUG AUGER IN CUTTINGS BOX. DRILL F/ 135-1050' MAKE WIPER TRIP F/ CASING MW: 9.8 VIS:300 DRILL F/ 1050-2413' CIRC AND SHORT TRIP 11 STAMDS F/ 2413-1350' DRILL ~/ 2413-2899' CHANGE SHAKER SCREENS. DRILL F/ 2~99-3145'. CIRC F/ WIPER TRIP. MAKE WIPER TRIP F/ SURFACE CASING. POH TO CLEAN OFF STABILIZERS. NU BOPE MW: 0.0 VIS: 0 POH TO CLEAN BHA. HOLE TRIED TO SWAB. RIH NO PROBLEMS. CIR BOTTOMS UP. POH. NO PROBLEMS. LAY DOWN BHA. CLEAN FLOOR. R/U AND RUN 78 JTS 10 3/4 NT-80 45.5# BTC CSG, LAND AT 3147' ON 10 3/4 FLUTED MLH. CIRC CSG, WORK PIPE. TEST BJ AND CEMENT LINES. R/U FOR TOP JOB. LAY DOWN CMT HEAD, LANDING JT., CSG TOOLS. ND DIVERTER SYSTEM. NU SPLIT UNIHEAD AND TEST. NU BOPE. DRILL 9 7/8 HOLE MW: 9.3 VIS: 43 UNPLUG FLOW LINE. THICK MUD/CMT. NU FLOW LINE AND RISER. TEST BOPE. INSTALL WEAR RING. M/U NEW BHA. RIH TAG FC AT 3046'. TEST CSG. DRILL FLOATS AND HARD CEMENT, 10' NEW HOLE. PERFORM LOT. DRILL F/ 3155-4189'. SHORT TRIP TO SHOE NO PROBLEMS. DRILL F/ 4189-4380'. DRILLING 9 7/8 HOLE MW: 9.7 VIS: 40 DRILL F/ 4380-5237'. CIRC / SHORT TRIP / F/ 5237-4180'. DRILL F/ 5267-5656' CIRC F/ BIT TRIP. POH. W/ BIT #2. CHANGE BITS, RIH. ~UT/SLIP 104' DRILLING LINE. RIH. PRECAUTIONARY REAM F/ 5600-5656' DRILL F/ 5656-5840'. WASH TO BTM. MW: 9.7 VIS: 42 DRLG F/ 5840'-6861'. SHORT TRIP 12 STDS. DRLG F/ 6861'-6925'. CBU. POOH. CHANGE BIT. RIH. RECEIVED FEB ! ] 199~r ~q~,ska Oi~ & Gas Cons. Commission Anchorage WELL : R-35 OPERATION: RIG : NABORS 28E PAGE: 2 12/15/93 ( 7) TD: 8150' (1225) 12/16/93 ( 8) TD: 9480' (1330) 12/17/93 ( 9) TD:10425' ( 945) 12/18/93 (10) TD:10940' ( 515) 12/19/93 (11) TD:11445' ( 505) 12/20/93 (12) TD:11675' ( 230) 12/21/93 (13) TD:12088' ( 413) 12/22/93 (14) TD: 12088' ( 0) 12/23/93 (15) TD:12088 PB: 0 DRILLING WPDC MW: 9.8 VIS: 43 DRILL FROM 6925-7942'. SHORT TRIP TO 6895' DRILL FROM 7942-8150'. DRILLING WPDC MW: 9.7 VIS: 43 DRILL FROM 8150-8916'. SHORT TRIP 10 STANDS. NO PROBLEMS. DRILL FROM 8916-9480' DRILLING WPDC MW: 9.7 VIS: 45 DRILL FROM 9480-1--52' SHORT TRIP 10 STANDS. NO PROBLEM . DRILL FROM 10052-10425' · DRILLING WPDC MW: 9.7 VIS: 44 DRILL F/ 9480-10712'. CIRC SWEEP. TRIP OUT OF HOLE FOR BHA CHANGE. PULL WEAR BUSHING & TEST BOPE. CHANGED OUT VARIABLE RAMS TO 5' PIPE RAMS. TRIP IN HOLE TO 10 3/4" CSG SHOE. CUT AND SLIP DRLG LINE. TRIP IN HOLE. PRECAUTIONARY REAM F/ 10659-10712'. DRILL F/ 10712-10940' DRILLING WPDC MW: 9.7 VIS: 46 DRILL F/ 10940-11207' NO FORWARD ON ROTARY. LOST 500 PSI PUMP PRESSURE. POOH & FOUND WASH OUT IN SLIP AREA 5 STDS & DOUBLE OUT. RIH. REPLACE ROTARY TABLE SWITCH. DRILL F/ 11207-11445'. DRILLING MW: 9.7 VIS: 47 DRILL F/ 11445-11646'. CIRC SWEEP. TRIP OUT OF HOLE TO 10406'. HOLE TIGHT & SWABBING. TRIP BACK TO BOTTOM. CIR LOW & HIGH VIS SWEEPS. TRIP OUT OF HOLE. MAKE UP BHA #6. -TRIP IN HOLE. WASH AND REAM F/ 11550-11646'. CIRC AND CONDITION HEAVY FROM TRIP MUD OUT BEFORE DRILLING SAG. DRILL F/ 11646-11675'. TRIP OUT OF HOLE MW: 9.7 VIS: 44 DRILL FROM 11675-12088' HOLE TIGHT. TRYING TO DIFFERENTIAL STICK BIG TIME. ROTATE & WORK PIPE WHILE CIRCULATE LCM @ REDUCED PUMP RATE. TRIP OUT OF HOLE. RLL LOG FROM 12088-11575'. HOLE TRIED TO SWAB FROM 10442-10159' RUN 7-5/8" CSG. MW: 9.7 VIS: 39 POOH. L/D BHA. RIH W/ BHA, BIT. CIRC. RIH TO BTM. REAM TO BTM. CIRC. SPOT 20 BBLS LCM PILL. POOH. TEST BOPE. RIH W/ 7-5/8" CSG. PREP TO CLEANOUT. MW: 9.8 WBM RIH W/ 7-5/8" CSG. CIRC @ SHOE. RIH W/ CSG. CIRC. PUMP 20 BBLS WATER, 50 BBLS MCS-4 SPACER, 280 BBLS LEAD CMT, 60 BBLS TAIL CMT. DISP W/ MUD. NO BUMP PLUG. L/D CMT HEAD, LAND JT. SET PACKOFF. TEST SAME. OK. TEST BOPE. RIH. RECEIVED FEB i 1 1994 Aiaska UiJ & Gas 6ons. Commission Anchorage WELL : R-35 OPERATION: RIG : NABORS 28E PAGE: 3 12/24/93 (16) TD:12088 PB:11995 L/D DP. MW: 8.5 Seawater RIH. DRLG CMT F/ 11952'-11995'. CBU. TEST CSG. OK. DISP WELL TO SEAWATER. POOH, L/D DP. 12/25/93 (17) TD:12088 PB:11995 RIH W/ TBG. MW: 8.5 Seawater POOH, L/D DP. RIH W/ 4-1/2" TBG, SSSV, CNTRL LINES. 12/26/93 (18) TD:12088 PB:11995 RIG RELEASED. MW: 8.5 Seawater N/D BOPE. N/U TREE. TEST TREE. OK. PULL BPV. SET PKR @ 11575' W/ 4000 PSI. TEST TBG. OK. TEST ANNULUS. OK. SHEAR RP VALVE. F/P WELL W/ 83 BBLS DIESEL. INSTALL BPV. SECURE WELL. RIG RELEASED @ 19:00 HRS, 12/25/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED FEB 1,.'l 1996 Uil & Gas Cons. Commission Anchorage SPA,,RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DATE OF SURVEY: 122193 MWD SURVEY JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -54.80 177 177.00 122.20 266 265.99 211.19 355 354.97 300.17 444 443.89 389.09 0 0 N .00 E .00 0 24 N 82.50 E .23 0 42 S 69.00 E .45 1 36 S 67.50 E 1.01 3 5 S 66.80 E 1.69 .00N .00E .00 .08N .61E .62 .07S 1.43E 1.39 .74S 3.08E 2.91 2.17S 6.44E 5.97 534 533.63 478,83 624 623.10 568.30 714 712.33 657.53 804 801.30 746.50 899 894.90 840.10 5 18 S 66.90 E 2.44 4.76S 12.50E 11.48 7 0 S 67.90 E 1.89 8.45S 21.41E 19.61 8 0 S 61.50 E 1.45 13.50S 31.99E 29.15 9 18 S 59.40 E 1.49 20.19S 43.76E 39.56 10"23 S 58.20 E 1.18 28.62S 57.65E 51.78 995 989.30 934.50 1090 1082.67 1027.87 1184 1175.03 1120.23 1279 1268.38 1213.58 1374 1361.71 1306.91 10 30 S 57.50 E .17 37.88S 72.39E 64.68 10 48 S 62.10 E .95 46.70S 87.56E 78.07 10 36 S 57.90 E .86 55.42S 102.67E 91.43 10 48 S 56.50 E .35 64.97S 117.49E 104.36 10 41 S 59,30 E .56 74.39S 132.50E 117.49 1470 1455.83 1401.03 1565 1548.70 1493.90 1660 1641.54 1586.74 1756 1735.32 1680.52 1851 '1827.92 1773.12 12 0 S 56.70 E 1..45 84.42S 148.50E 131.50 12 18 S 55.10 E .47 95.63S 165.05E 145.85 12 11 S 59.00 E .88 106.59S 181.96E 160.58 12 30 S 57.60 E .44 117.38S 199.42E 175.90 13 18 S 65.10 E 1.95 127.49S 218.02E 192.44 1946 1920.43 1865.63 2041 2012.90 1958.10 2136 2105.23 2050.43 2232 2198.44 2143.64 2327 2290.64 2235.84 13 0 S 63.20 E .55 136.91S 237.46E 209.95 13 30 S 65.70 E ,80 146.29S 257.1IE 227.66 13 41 S 63.40 E .61 155.89S 277.27E 245.84 14 0 S 62.20 E .43 166.39S 297.71E 264.13 13 53 S 58.10 E 1.05 177.78S 317.56E 281.70 ,2423 2383.70 2328.90 14 30 2517 2474.63 2419.83 14 53 2613 2567.38 2512.58 15 0 2708 2659.01 2604.21 15 36 2803 -2750.44 2695.64 15 53 S 62.30 E 1.24 189.46S 337.99E 299.78 S 64.40 E . .71 200.15S 359.31E 318.90 S 64.10 E .13 210.91S 381.62E 338.99 S 64.60 E .65 221.76S 404.22E 359.35 S 63.40 E .47 233.07S 427.39E 380.20 2899 2842.79 2787.99 2993 2932.91 2878.11 3059 2995.88 2941.08 3170 3101.77 3046.97 3266 3193.14 3138.34 15 48 S 60.70 E .78' 245.35S 450.55E 400.86 17 12 S 62.90 E 1.63 257.95S 474.08E 421.83 17 42 S 62.70 E .76 266.99S 491.68E 437.59 17 12 S 62.90 E .45 282.21S 521.29E 464.09 18 30 S 63.70 E 1.38 295.42S 547.57E 487.67 FEB '! q 1994- Date II ~tC)~_, _ . A!&$kaOJl&GasCons. Commissior: Anchm'age SPA~cRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 3360 3282.07 3227.27 3452 3368.28 3313.48 3548 3456.57 3401.77 3644 3543.27 3488.'47 3740 3628.83 3574.03 19 17 21 30 24 42 26 12 27 42 COURSE DIRECTION DEGREES DG/ DATE OF SURVEY: 122193 MWD SURVEY JOB NUMBER: 'AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION DLS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST S 64.80 E .93 S 63.20 E 2.47 S 62.20 E 3.36 S 67.40. E 2.80 S 71.30 E 2.41 VERT. SECT. 308.65S 575.00E 512.37 322.72S 603.81E 538.28 340.01S 637.26E 568.20 357.51S 674.57E 601.90 372.81S 715.27E 639.30 3835 3712.23 3657.43 3930 3794.83 3740.03 4025 3876.60 3821.80 4120 3955.62 3900.82 4216 4032.53 3977.73 4310 4105.93 4051.13 4405 4178.22 4123.42 4500 4249.25 4194.45 4596 4319.34 4264.54 4692 4387.39 4332.59 29 30 29 42 31. -30 35. 54 37 35 39 42 41 1.2 42 0 44 12 45 30 S 74.50 E 2.49 S 74.30 E .24 S 75.50 E 2.00 S 78.70 E 4.99 S 80.60 E 2.13 .S 81.10 E 2.26 S 83.60 E 2.33 S 85.40 E 1.51 S 86.20 E 2.36 S 88.30 E 2.05 386.14S 758.73E 679.77 398.76S 803.92E 722.07 411.34S 850.61E 765.85 423.02S 901.98E 814.39 433.32S 958.47E 868.22 442.65S 1016.42E 923.66 450.83S 1077.49E 982.37 456.87S 1140.27E 1043.13 461.66S 1205.67E 1106.70 464.89S 1273.28E 1172.71 4788 4454.50 4399.70 4882 4519.44 4464.64 4977 4583.55 4528.75 5073 4646.16 4591.36 5168 4706.10 4651.30 45 47 46 47 -48 17 50 17 51 30 N 89.50 E 1.67 N 87.60 E 1.81 N 85.30 E 2.38 N 81.80 E 3.46 N 76.40 E 4.59 465.61S 1341.91E 1240.16 463.88S 1409.84E 1307.35 459.52S 1479.78E 1376.98 451.32S 1552.07E 1449.59 437.36S 1624.41E 1523.26 5263 4764.98 4710.18 5358 4823.40 4768.60 5454 4882.11 4827.31 5549 4939.81 4885.01 5645 4997.92 4943.12 51 54 52 12 52 24 52 47 52 42 N 74.30 E 1.79 N 72.70 E 1.37 N 72.80 E .22 N 70.60 E 1.89 N 69.50 E .92 418.50S 1696.53E 1597.56 397.22S 1768.35E 1671.99 374.70S 1840.89E 1747.34 351.00S 1912.53E 1822.02 324.93S 1984.35E 1897.29 5740 5055.55 5000.75 5836 5114.06 5059.26 5932 5172.77 5117.97 6028 5231.47 5176.67 6123 5289.77 5234.97 6219 5348.94 5294.14 6314 5407.49 5352.69 6410 5466.53 5411.73 6505 5525.01 5470.21 6601 5584.51 5529.71 52 35 52 17 52 17 52 17 52 0 51 54 52 0 52 5 51 54 51 30 N 68.50 E .84 N 68.30 E .35 N 71.40 E 2.55 N 68.30 E 2.55 N 69.90 E 1.'37 N 69.70 E .19 N 70.20 E .43 N 69.30 E .75 N 68.80 E .47 N 68.50 E .48 297.87S 2054.85E 1971.43 269.85S 2125.62E 2046.00 243 . 70S 2196.90E 2120.75 217.54S 2268.19E 2195.50 190.78S 2338.26E 2269.16 164.68S 2409.20E 2343.58 139.03S 2479.48E 2417.25 112.83S 2550.50E 2491.75 86.06S 2620.41E 2565.25 58.64S 2690.58E 2639.13 RECEIVED Ai~ska Oil & Gas Cons. Commission Anchorage SP,'.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/9 DATE OF SURVEY: 122193 MWD SURVEY JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH- 6696 5643.78 5588.98 6792 5703.67 5648.87 6856 5743.47 5688.67 6951 5802,48 5747.68 7047 5862.83 5808.03 COURS INCLN DG MN 51 17 51 30 51 35 51 35 5O 30 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 68.60 E .23 31.48S 2759.68E 2711.91 N 69.70 E .92 4.78S 2829.79E 2785.60 N 69.90 E .29 12.52N 2876.83E 2834.94 N 67.90 E 1.65 39.32N 2946.28E 2907.99 N 70.70 E 2.54 65.72N 3016.09E 2981.34 7142 5923.70 5868.90 49 47 7237 5985.02 5930.22 49 47 7334 6047.69 5992.89 49 42 7428 6108.62 6053.82 49 30 7524 6170.06 6115.26 50 54 N 72.50 E 1.63 88.74N 3085.28E 3053.48 N 72.50 E .02 110.56N 3154.48E 3125.43 N 71.30 E .95 133.56N 3224.85E 3198.73 N 72.50 E 1.00 155.80N 3292.89E 3269.60 N 71.30 E 1.75 178.72N 3362.98E 3342.62 7619 6230.10 6175.30 7714 6288.97 6234.17 7809 6346.28 6291.48 7905 6403.78 6348.98 8000 6460.43 6405.63 50 42 52 42 53' 5 53 17 53 30 N 72.00 E .61 201.89N 3432.86E 3415.47 N 72.70 E 2.18 224.49N 3503.89E 3489.35 N 72.10 E .66 247.40N 3576.11E 3564.46 N 72.70 E .54 270.64N 3649.38E 3640.66 N 70.40 E 1.96 294.77N 3721.72E 3716.10 8096 6518.20 6463.40 52 8191 6576.03 6521.23 52 8283 6632.10 6577.30 52 8378 6689.73 6634.93 52 8473 6747.10 6692.31 52 30 N 71.60 E 1.44 319.74N 3794.20E 3791.82 30 N 72.30 E .58 343.09N 3865.86E 3866.45 24 N 73.50 E 1.04 364.54N 3935.57E 3938.84 54 N 72.10 E 1.28 386.87N 4007.70E 4013.76 47 N 74.80 E 2.27 408.43N 4080.27E 4088.97 8568 6804.67 6749.87 52 35 8661 6860.90 6806.10 53 0 8755 6917.27 6862.48 53 17 8847 6972.00 6917.20 53 42 8942 7028.17 6973.37 53 47 N 74.30 E .47 428.57N 4153.10E 4164.21 N 74.40 E .44 448.55N 4224.44E 4237.93 N 72.80 E 1.40 469.79N 4296.59E 4312.68 N 73.40 E .68 491.28N 4367.35E 4386.10 N 73.00 E .36 513.43N 4440.69E 4462.18 9035 7083.03 7028.23 53 54 9130 7139.34. 7084.54 53 24 9226 7196.44 7141.64 53 35 9321 7252.35 7197.55 54 17 9416 7307.52 7252.72 54 42 N 75.00 E 1.74 534.12N 4512.86E 4536.86 N 73.20 E 1.61 555.08N 4586.44E 4612.96 N 73.00 E .27 577.51N 4660.28E 4689.58 N 73.00 E .74 599.97N 4733.73E 4765.82 N 73.40 E .54 622.32N 4807.77E 4842.63 9511 7363.29 7308.49 53 24 9607 7420.46 7365.66 53 30 9701 7476.30 7421.50 53 35 9795 7532.62 7477.82 52 47 9887 7587.93 7533.13 53 17 N 72.70 E 1.49 644.73N 4881.33E 4918.97 N 74.10 E 1.18 666.77N 4955.23E 4995.58 N 75.30 E 1.03 686.72N 5028.16E 5070.87 N 71.60 E 3.26 708.14N 5100.29E 5145.63 N 71.10 E .70 731.65N 5169.95E 5218.32 RECEIVED Gas Cons. Commission Anchorage SPeRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 DATE OF SURVEY: 122193 MWD SURVEY JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN .DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9983 7645.16 7590.36 53 30 N 72.00 E .78 756.04N 5243.06E 10077 7700.68 7645.88 54 5 N 72.50 E .77 779.16N 5315.30E 10173 7757.91 7703.11 52 42' N 73.20 E 1.57 801.89N 5388.93E 10265 7813.60 7758.80 52 47 N 71.60 E 1.39 824.03N 5458.73E 10359 7870.23 7815.44 53 5 N 73.90 E 1.98 846.27N 5530.36E 5294.56 5369.73 5446.20 5518.79 5593.20 10454 7926.81 7872.01 53-47 N 72.30 E 1.54 868.46N 5603.38E 10548 7981.93 7927.13 54 24 N 73.40 E 1.14 890.91N 5676.13E 10643 8037.30 7982.50 54 17 N 72.70 E .61 913.41N 5749.97E 10739 8093.52 8038.72 54. 0 N 73.20 E .52 936.23N 5824.36E · 10832 8148.90 8094.10 52 54 N 72.10 E 1.52 958.50N 5895.67E 10927 8207.91 8153.11 50 17 N 72.80 E 2..80 980.96N 5966.65E 11023 8272.06 8217.26 45 47 N 73.20 E 4.70 1001.83N 6034.90E 11117 8339.50 8284.70 42 30 N 72.80 E 3.52 1020.97N 6097.51E 11212 8410.69 8355.89 40 24 N 73.20 E 2.23 1039.36N 6157.64E 11304 8482.43 8427.63 37 5 N 74.10 E 3.64 1055.58N 6212.88E 5668.97 5744.52 5821.15 5898.39 5972.48 6046.29 6117.14 6182.12 6244.54 6301.76 11397 8558.14 8503.34 33 54 N 72.80 E 3.54 1070.94N 6264.65E 11492 8639.07 8584.27 29 12 N 72.70 E 4.95 1085.67N 6312.11E 11556 8695.78 8640.98 26 0 N 72.80 E 5.00 1094.46N 6340.42E 11677 8805.60 8750.80 23 36 N 73.30 E 1.99 1109.27N 6388.95E 11772 8892.69 8837.89 23 30 N 72.10 E .52 1120.55N 6425.19E 11866 8978.92 8924.13 23 23 N 72.30 E .13 1131.99N 6460.81E 11961 9066.11 9011.31 23 23 N 72.10 E .08 1143.52N 6496.73E 12088 9182.70 9127.90 23 19 N 72.10 E .05 1159.00N 6544.66E 6355.41 6404.71 6434.13 6484.50 6522.15 6559.21 6596.60 6646.49 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6646.49 FEET AT.NORTH 79 DEG. 57 MIN. EAST AT MD = 12088 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 79.96 DEG. SPA~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 INTERPOLATED VALUES DATE OF SURVEY: 122193 JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH : DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 0 .00 -54.80 .00 N .00 E .00 1000 994.22 939.42 38.37 S 73.16 E 5.78 2000 1973.03 1918.23 142.35 S 248.38 E 26.97 3000 2939.60 2884.80 258.89 S 475.92 E 60.40 4000 3855.28 3800.48 408.07 S 837.96 E 144.72 VERTICAL CORRECTION 5.78 21.19 33.43 84.32 5000 4598.78 4543.98 457.98 S 1496.95 E 401.22 6000 5214.35 5159.55 225.73 S 2247.60 E 785.65 · . 7000 5832.93 5778.13 53.73 N 2981.86 E 1167.07 8000 6460.43 6405.63 294.77 N 3721.72 E 1539.57 9000 7062.41 7007.61 526.80 N 4485.55 E 1937.59 256.50 384.43 381.42 372.51 398.01 10000 7655.27 7600.47 760.26 N 5256.05 E 2344.73 11000 8256.18 8201.38 997.01 N 6018.98 E 2743.82 12000 9101.90 9047.10 1148.28 N 6511.47 E 2898.10 12088 9182.70 9127.90 1159.00 N 6544.66 E 2905.30 407.14 399.09 154.28 7.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. REC£1V D FEB 1 i 1994 Oil & Gas 6ons. 6ommJssion Anchorage SP~.~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 INTERPOLATED VALUES FOR EVEN 100 DATE OF SURVEY: 122193 JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -54.80 54 54.80 .00 154 154.80 100.00 254 254.80 200.00 354 354.80 300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 N .00 E .00 N .00 E .06 N .46 E · 02 S 1.30 E .74 S 3.08 E MD-TVD VERTICAL DIFFERENCE CORRECTION .0O .00 .00 .00 .00 .01 .00 · 03 .02 454 454.80 400.00 555 554.80 500.00 655 654.80 600.00 756 754.80 700.00 858 854.80 800.00 2.40 S 6.99 E 5.53 S 14.31 E 9.92 S 25.01 E 16.36 S 37.25 E '24.75 S 51.41 E .13 .10 .46 .33 .13 .67 .09 .96 .44 1.35 959 954.80 900.00 1061 1054.80 1000.00 1163 1154.80 1100.00 1265 1254.80 1200.00 1366 1354.80 1300.00 34.45 S 67.00 E 44.21 S 82.86 E 53.40 S 99.46 E 63.54 S 115.33 E 73.72 S 131.37 E 5.11 1.67 6.83 1.72 8.62 1.79 10.37 1.76 12.16 1.79 1468 1454.80 1400.00 1571 1554.80 1500.00 1673 1654.80 1600.00 1775 1754.80 1700.00 1878 1854.80 1800.00 84.30 S 148.32 E 96.39 S 166.14 E 108.06 S 184.41 E 119.69 S 203.07 E 130.16 S 223.78 E 14.15 1.98 16.44 2.29 18.77 2.33 21.16 2.39 23.82 2.67 1981 1954.80 1900.00 2084 2054.80 2000.00 2187 -2154.80 2100.00 2290 2254.80 2200.00 2393 2354.80 2300.00 140 150 161 173 185 .48 S 244.55 E .45 S 266.28 E .34 S 288.09 E .10 S 310.03 E .99 S 331.37 E 26.48 2.66 29.30 2.82 32.23 2.93 35.28 3.05 38.34 3.06 2496 2454.80 .2400.00 2599 2554.80 2500.00 2703 2654.80 2600.00 2807' 2754.80 2700.00 2911 2854.80 2800.00 197 209 221 233 247 .88 S 354.55 E .44 S 378.59 E .26 S 403.15 E .62 S 428.50 E .02 S 453.51 E 41.68 3.34 45.18 3.50 48.83 3.65 52.73 3.90 56.68 3.95 3015 2954.80 2900.00 3120 3054.80 3000.00 3225 3154.80 3100.00 3331 3254.80 3200.00 3437 3354.80 3300.00 261 275 289 304 320 .03 S 480.11 E .59 S 508.34 E .74 S 536.07 E .58 S 566.36 E .33 S 599.06 E 61.11 4.43 66.04 4.92 70.77 4.74 76.31 5.54 82.71 6.40 RECEIVED FEB 'l'i 1994 0il & Gas Cons. Commission Anchorage SP,-.~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 DATE OF SURVEY: 122193 JOB NUMBER: AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3546 3454.80 3400.00 3656 3554.80 3500.00 3769 3654.80 3600.00 3883 3754.80 3700.00 3999 3854.80 3800.00 339.63 S 636.56 E 359.69 S 679.81 E 377.18 S 728.19 E 392.59 S 781.95 E 408.00 S 837.68 E 91.25 8.55 102.05 10.80 114.53 12.47 129.11 14.59 144.64 15.52 4118 3954.80 3900.00 4244 4054.80 4000.00 4373 4154.80 4100.00 4507 4254.80 4200.00 4645 4354.80 4300.00 422.90 S 901.41 E 436.12 S 975.39 E 448.54 S 1057.12 E 457.27 S 1145.24 E 463.84 S 1240.23 E 164.20 19.56 189.31 25.11 219.08 29.77 252.66 33.58 290.77 38.10 4788 4454.80 4400.00 4933 4554.80 4500.00 5086 4654.80 4600.00 5246 475'4.80 4700.00 5409 4854.80 4800.00 465.61 S 1342.22 E 462.07 S 1447.72 E 449.72 S 1562.40 E 422.01 S 1684.03 E 385.19 S 1807.03 E 333.63 42.86 379.06 45.43 431.75 52.69 491.70 59.94 554.45 62.76 5573 4954.80 4900.00 5738 5054.80 5000.00 5902 5154.80 5100.00 6066 5254.80 5200.00 6228 5354.80 5300.00 344.44 S 1931.15 E 298.23 S 2053.94 E 251.11 S 2174.87 E 206.41 S 2296.23 E 162.08 S 2416.22 E 618.99 64.54 683.96 64.97 747.82 63.86 811.33 63.52 873.70 62.37 6390 5454.80 5400 6553 5554.80 5500 6713 5654.80 5600 6874 5754.80 5700 7034 5854.80 5800 .00 .00 .00 .00 .00 118.15 S 2536.41 E 72.33 S 2655.77 E 26.47 S 2772.48 E 17.44 N 2890.25 E 62.50 N 3006.90 E 936.11 62.41 998.43 62.32 1058.82 60.39 1119.44 60.61 1179.58 60.14 7190 5954.80 5900 7344 6054.80 6000 7499 6154.80 6100 7657 6254.80 6200 7823 6354.80 6300 .00 .00 .00 .00 .00 99.81 N 3120.38 E 136.24 N 3232.79 E 172.69 N 3345.19 E 211.22 N 3461.55 E 250.89 N 3586.91 E 1235.38 55.80 1290.19 54.81 13'45.00 54.81 1403.19 58.19 1468.39 65.20 7990 6454.80 6400 8156 6554.80 6500 8320 6654.80 6600 8485 6754.80 6700 8650 6854.80 6800 .00 .00 .00 .00 .00 292.22 N 3714.55 E 334.67 N 3839.50 E 372.91 N 3963.83 E 411.09 N 4090.05 E 446.37 N 4216.64 E 1535.74 67.35 1601.33 65.58 1665.41 64.08 1730.93 65.52 1796.06 65.13 RECEIVED Gas Cons. Commission An~,hnr~n~ SP~,~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/R-35 500292242400 NORTH SLOPE COMPUTATION DATE: 12/22/93 DATE OF SURVEY: 122193 JOB NUMBER: 'AK-MW-30094 KELLY BUSHING ELEV. = 54.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8817 6954.80 6900.00 8987 7054.80 7000.00 9155 7154.80 7100.00 9325 7254.80 7200.00 9496 7354.80 7300.00 484.59 N 4344.91 E 1863.15 67.09 523.96 N 4475.52 E 1932.30 69.15 561.09 N 4606.37 E 2001.13 68.83 600.96 N 4736.99 E 2070.40 69.27 641.34 N 4870.42 E 2141.97 71.57 9664 7454.80 7400.00 9831 7554.80 7500.00 9999 7654.80 7600.00 10167 7754.80 7700.00 10333 7854.80 7800.00 10501 7954.80 7900.00 10672 8054.80 8000.00 10841 8154.80 8100.00 10997 8254.80 8200.00 11137 8354.80 8300.00 679.31 N 4999.94 E 2209.96 68.00 717.36 N 5128.01 E 2276.88 66.92 760.06 N 5255.44 E 2344.40 67.52 800.71 N 5385.02 E 2413.06 68.66 840.57 N 5510.61 E 2478.49 65.43 880.07 N 5639.84 E 2546.61 68.12 920.66 N 5773.23 E 2618.20 71.58 960.88 N 5903.05 E 2686.94 68.74 996.57 N 6017.54 E 2743.16 56.22 1025.11 N 6110.90 E 2782.95 39.79 11269 8454.80 8400.00 11392 8554.80 8500.00 11509 8654.80 8600.00 11621 8754.80 8700.00 11730 8854.80 8800.00 1049.64 N 6192.30 E 2814.24 31.29 1070.27 N 6262.46 E 2838.16 23.92 1088.22 N 6320.30 E 2855.12 16.96 1102.89 N 6367.70 E 2866.76 11.65 1115.50 N 6409.51 E 2875.88 9.12 11839 8954.80 8900.00 1128.81 N 6450.86 E 2884.91 9.03 11948 9054.80 9000.00 1142.02 N 6492.07 E 2893.88 8.96 12057 9154.80 9100.00 1155.30 N 6533.21 E 2902.82 8.94 12080 9175.35 9120.55 1158.03 N 6541.65 E 2904.65 1.83 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED FEB '!'i 1994 Uti & Gas Cons. Commission Anchorage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - R-35 · January 19, 1994 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Paul Radzinski, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs' 2" x 5" TND Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia Received: /? 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Baroid Company MEMORANDb.J State Alaska Alaska Oil and Gas Conservation Commission Chairmari ~ THRU: FILE NO: Blair Wondzell, ~~ > P. I. Supervisor IA FROM: Bobby Fost~~ SUBJECT: Petroleum Inspector December 17, 1993 AIRILQAD.doc BOP Test- Nabors 28 E BPX - PBU - R - 35 PTD#93- 181 Friday, December 17, 1993: I traveled to Nabors rig 28 E this date and witnessed the BOPE test. As the attached AOGCC BOPE test report shows there was one failure which was repaired before I departed the location. The upper pipe rams leaked on the high pressure test. This set of rams were variable bore. They were replaced with a set of standard 5" ram block type. Mike Downey, Nabors 'toolpusher, said he would change out the elements and put the variable bore rams back in service when he got ready to run the 7" casing. The rig was in good shape and the crew was very knowledge about the work being performed. The location was clean and all the drilling related equipment ie - subs, drill motors, ect.- were stored properly leaving clear access to the rig. Summary: I witnessed the BOPE test on Nabors rig 28 E on BPX's R - 35 o test time 3 hours - one failure. Attachment: AIRILQAD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: , Well Name: Casing Size: 10 3/4 Test: Initial Workover: DATE: 12/17/93 NABORS Rig No. 28 E PTD # g3- 181 Rig Ph.# 65g- 4863 , BPX Rep.: JAMES CARLILE R - 35 Rig Rep.: MIKE DOWNEY Set @ 3, 127 Location: Sec. '32 T. 12 N R. 13 E Meridian U Weekly X Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Quan, I 1 ,: 1 FLOOR SAFETY VALVES: Quan. Pressure P/F Well Sign OK Upper Kelly/IBOP . 1 i 500t5000 ! P Drl. Rig OK Lower Kelly / IBOP I! 500~5000 I P Ball Type I 500~5000 P Inside BOP I 500~5000 P Test Pressure P/F 500t5000 P 500t5000 P 500~5000 P I 500~5000 P ;I 500~5000 P 2 500t5000 P I 500~5000 P Reserve Pit OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: ~/~sual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES · Gas Detectors YES 'YES CHOKE MANIFOLD: No. Valves 18 No. Flanges '42 Manual Chokes "2 Hydraulic Chokes I Test Pressure 500~5000 500~5000 PIF P P P ACCUMULATOR SYSTEM: System Pressure 3,000 _ I P Pressure After Closure 1,400 I P 200 psi Attained After Closure 0 minutes 25 System Pressure Attained 1 minutes 45 Blind Switch Covers: Master:' YES Remote: Nitgn. Btl's: 8 ~ 2000 Psig. sec. ,, sec, YES Number of Failures: 1 ,Test Time: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The upper pipe rams leaked- changed rams out and retested- OK Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES NO X 24 HOUR NOTICE GIVEN YES X NO . I I II I I I I .I I I Waived By: Wr~nessed By: ~~,~ ~ ~'O~'T-~-~ FI-O'ZI L (Rev. 7t19) AtRILQAD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging x Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate__ Other x __ Plugback for redrill 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 608' NSL, 826' EWL, SEC. 32, T12N, R13E At top of productive interval 3560' SNL, 3300' WEL, SEC. 33, T12N, R13E 5. Type of Well: Development x Exploratory __ Stratigraphic__ Service .__ 6. Datum elevation (DF or KB) KBE-- 52.7' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-35 (23-33-12-13) 9. Permit number 93-181 At effective depth 10. APl number N/A At total depth 3532' SNL, 3230' WEL, SEC. 33, T12N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3096' Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 11. 5O- 029-22424 Field/Pool Prudhoe Bay Field/Oil Pool 9480 feet Plugs (measured) 7345 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20" 260 sx Arcticset (appx) 10-3/4" 1000 sx CS 11/375 sx "G" 112' 3127' 112' 3060' RECEIVED DEC 1 6 199~ Aiaska 0ii & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 12/2O/93 16. If proposal was verbally approved Oil X Gas __ Name of approver Date approved Service 17. I hereby certjf~t~t the foreggi'ng is true and correct to the best of my knowledge. S~gned Title Drilling Engineer Supervisor 15. Status of well classification as: Suspended __ FOR COMMISSION USE ONLY / / Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integri' 'ty Test Subsequent form required 10- ~.~ Original Signed By Approved by order of the Commission David W. Johnston J Approval No. /Approved Copy Returned Commlsslcncr - Date ( ~,./'~. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE R-35 Plucj and Abandonment If the reservoir is not economically viable and of poor quality for completion as a producer, we request permission for the following: 1. Abandon the reservoir section by laying a cement plug from TD up to 200' above the top of the Sag River, i.e. 12092' MD to 11435' MD (657' of cement). Cement volume for 657' of 9-7/8" hole plus 30% excess = 400 sx Class "G" cement 2. WOC 12 hours. RIH and tag cement plug to confirm position and strenth. AOGCC inspector will be contacted to witness tagging of plug. 3. POH. 4. Rih w/OEDP. Lay balanced cement plug in open hole section from 5850' MD up to 5550' MD (300 linear feet). POH. WOC. 5. P/U bit & BHA. Dress off cement plug to KOP @ 5650' MD. 6. Kick-off and sidetrack well to revised bottom hole location as detailed in attached permit to drill. If there are any questions regarding this procedure please contact Terry Jordan @ 564-5589. It is estimated that this abandonment procedure may start, if required ,on 12/20/93. DEC 1 6 199~ oii & I~a~ Oons. Oommission Anohora..Cle STATE OF ALASKA ALA,..-,A OIL AND GAS CONSERVATION COMMISS~,,.~N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown Re-enter suspended well__ . Alter casi~-- Repair ~ Plugging -~Time extension Stimulate __ Change appr--~ program x Pull tubing Vadance P--~-~rate Other 1. Type of Request: 2. Name of Operator BP Exploration 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) ' KBE = 52. 7' feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 608' NSL, 826' EWL, SEC. 32, T12N, R13E At top of productive interval 9. 3560' SNL, 3300' WEL, SEC. 33, T12N, R13E At effective depth 10. N/A At total depth 11. 3532' SNL, 3230' WEL, SEC. 33, T12N, R13E Well number R-35 (23-33-12-13) Permit number 93-181 APl number 50- 029-22424 Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3145 feet Plugs (measured) 3077 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth RECEIVED DEC 1 0 199,~ Al~sk~ Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 12/16/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify/that the foregoi~"is true and correct to the best of my knowledge. Signed ,_~'~'~"~~"~.~~~,~ ~/ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10-/,/c~ ?' Original Signed By Approved by orderofthe Commission David W. Johnston J Approva, No? ~Approved Oopy Returned Co~,,~,,i~c~r,~r - - Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 12/10/93 R-35 Chanae of a_o.Droved pro_cram 15ermit #93-181 Current depth 3145' MD/3077' TVD Current operations- preparing to run 10-3/4" casing. Due to concern about reservoir quality at the proposed bottom hole location it is requested that the approved program be changed. In lieu of 7-5/8" intermediate casing and 5-1/2" liner to TD a 7-5/8", 29.7#, NT95HS/13CR80 Iongstring will be run to TD, cemented with 750 sacks of Class "G" cement. A Iongstring completion would allow evaluation of the reservoir with FE MWD (GR/Res.) without committing casing to the well. Depending on Icg results, the open hole section may be abandoned and the well sidetracked to a new BHL. RECEIVED DEC 1 0 199~ Ataska 0il & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION November 30, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 R. C. Maskell Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit R-35 BP Exploration (Alaska), Inc. Permit No: 93-181 Sur. Loc. 608'NSL, 826'EWL, Sec. 32, T12N, R13E, UM Btmhole Loc. 3532'SNL, 3230'WEL, Sec. 33, T12N, R13E, UM Dear Mr. Maskell: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dll b. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 52.7' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28278 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(se`' 20 ^^c 25.o~5) 608' NSL, 826' EWL, SEC. 32, T12N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3560' SNL, 3300' WEL, SEC. 33, T12N, R13E R-35 (23-33-12-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 3532' SNL, 3230' WEL, SEC. 33, T12N, R13E 12/7/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 28279-2048' feet R-1-18' @ 800' MD feet 2560 12092' MD/9239' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (eM 20 Mc 25.035 (,,)(2)) Kickoff depth 25o'feet Maximum hole angle52.9 0 Maximum surface 3330 psig At total depth (TVD) ~00'/4~0 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NTaOLHE Butt 3091' 31' 31' 3122' 3051' 1000sxCSIIl/375sx"G"/250sxCSll 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11605' 30' 30' 11635' 8813' 715 sx Class "G" 6-3/4" 5-1/2" 17# 13CR80 NSCC 607' 11485' 8672' 12092' 9239' 120 sx Class "G" i19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate Production ['iOV ] Liner Aiaska fJit & 6as Cons. Commission Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program IT1 Drilling fluid program__,..,_[] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certi~./that____ the fore, going ist~e and correct to the best of my knowledge / / D at e/~',//' 7'/~_~ Signed ~~'~.4:¢~,~~_~/(.~../~./ Title Or, llingEng,neerSuperv, sor "~-~-~- Commission Use Only Permit Number IAPI number IApproval_date ISee cover letter ¢3-/?/ 150- zz ¢-./4"_~Iforother requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOPE D2M; D3M; I~5M; I-IIOM; F-I15M; by order of Other:Approved by Fl~lvirl0r[g[nalw Signed~,.,h,~,.,+,,~.By Commissioner tne commission Date,-/./'~¢;,/¢~ Form 10-401 Rev. Submit ir~ triplicate [Well Name: [R-35 Well Plan Summary Type of Well (producer or injector): [ Producer i Surface Location: 10608' FSL 0826' FWL Sec 32 T12N R13E UM. Target Location: i 3560' FNL 3300' FEL Sec 33 T12N R13E UM. Bottom Hole Location' 3532' FNL 3230' FEL Sec 33 T12N R13E UM. [AFE Number: ]4P0517 ] [ Estimated Start Date: [ Dec 7 1993 [MD: ] 12092' I I Rig: I Nabors 28-E [ Operatin$ days to complete: 1 22 [TVD: [ 9239' ] I KBE: 152.7' Well Design (conventional, slimhole, etc.): .- [ Slimhole producer Formation Markers: Formation Tops MD TVD (BKB) Ugnu Zone 4A 4552' 4303' West Sak Sands 5899' 5201' Top Seabee 7179' 5973' Kup/Put River Absent IKRU/LCU 9571' 7417' Top Sa~ River 11635' 881Y Top Shublik 11680' 8853' Eileen Member Absent Target 11818' 8981' Top Sadlerochit 11826' 8989' Total Depth 12092' 9239' Casing/Tubin[ram: Hole Size Cs#/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80 32/32 110/110 13 1/2" 10 3/4" 45.5# NT-80LHE Butt 3091 31/31 3122/3051 9 7/8" 7 5/8" 29.7# NT95HS NSCC 11605 30/30 11635/8813 6 3/4" 5 1/2" 17# 13Cr80 NSCC 607 11485/8672 12092/9239 N/A 4 1/2" 12.6g 13Cr80 NSCT 11456 29~29 11485/8672 I Well Plan Summary Page 1 RECEIVED l'~OV 1 7 Oil & Gas Cons. Commission Anchorage Logging Program: Open Hole Logs: Surface I None INone DIL/Sonic/CNL/GR. Optional RFT Possible Gyro and SBT. Intermediate Final I Cased Hole Loss: Mud Program: ! Special design considerations I None · Surface Mud Properties: I Denslty Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 tO tO tO tO tO tO tO 9.5 300 60 60 80 10 25 Intermediate Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 to to to to to to to - 10.4 50 15 -10 20 10 10 Production Mud Properties:. ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8' 30 8 3 7 8 6 tO tO tO tO tO tO tO 9.2 45 13 10 15 9 8 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind 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 AOGCC. Directional'. I KOP: 1250' I Maximum Hole Angle: [ 52.9 de~rees Close Approach Well: R-01 and R-12 The above listed wells will be secured during the close approach. Well Plan Summary Page 2 RECEIVED i40V 1 ? Gas Cons. Commission Anchorage Prudhoe Bay Prudhoe BaY Uni[ IR-PAD R-35 iR- 35 WP2 HALL I BURTON~ · 400 800' I~00 1600 ~ooo ~400 L~I00 3~00 1130004 3051t 3~00 3~Oe 40001 4a00 43 - 4~00 4&00 48 ICJ.e'~' · 3a~,,, .D 2G.6-4' ! 3l~ KO ~r3 / TT4 / 1'5 CASING POINT DATA OD MD ]nc AziTVD No~th East i1. 750 in. ~516 ]4.85 ]]6.57 2473 -175 350 .625 In ~]635 25.47 73.25 8813 1092 6363 CRITICAL POINT DATA HD [nc Azi TVD North E~s~ TIE IN, RKB 53' 00.00 0.00 0 0 0 KDP. ;TART DF ~50 0.00 0.00 250 0 0 BUIL~ e 1.00 DEG/IO0 FT END OF BUILD 1735 14.85 116.571719 -86 171 BASE 1998 14.85 116.571973 -116 232 PERMAFROST START DF BUIL~2544 14.85 116.572500 -178 357 @ 1.00 DEG/IO0 SV3 / TT4 / T5 3122~0.64 116.573051. -257 514 START OF 3544 24.85 116.573439 -330 660 CURVE 8 2.00 DEG/]O0 FT - UGNU ZONE 4A 4552 38.09 86.55 4303 -407 ~65 (UG4A) END OF CURVE 5427 52.88 73.26 491G -289 1774 WS2 / TK4 5899 52.88 73.26 5201 -181 2134 TOP SEABEE 7179 52,88 73,26 5973 113 3~LI (CH3) IKRU / LCU 9571 5~.88 73.~6'7417 663 4938 START OF DROP10722 52.88 73.26 Bill 927 5816 ~ 3.00 DEG/IO0 FT TOP SAG RIVER 1163525.47 73.26 8813 1092 6363 ~OP SHUBL]K 11680 ~4.14 73.a6 8853 1097 6381 TARGET 11818 20,00 73.a6 8981 1112 6431 PRUDHOE BAY 11826 20.00 73.26 8989 1113 6434 MEMBER (TSAD) / Z4B CURRENT OUC 1185~ ~O.O0 73.~6 9013 1115 644~ TDP HEAVY DIE 11889 ~0.00 73.26 9048 I~1~ 6454 / jORIGINAL DUC ~1942 ~0.00 73.26 9098 11~4 6472 _ -- , · ~ K / L~ -~oa D ~0D 400 G0O 800 t000 12oo 1400 J6OO 1800 ~000 8700 ~400 a600 ~800 3000 3700 3400 ~00 3e05 4000 4~00 4400 4&oo 4800 5000 ~00 5400 VERTICAL SE~ION P~E: BO.O~ l~b REt: R~ goo ~ ~o~ ~r: wc~ . · ~,~.-i i~z~ ~- - 7.~ oD. e IL6~ ~). ~13 TVD 940 , , , , , , , , , ~oo 6000 6~00 &400 ~00 ~00 7000 7~00 7400 7600 ~R~CAL SEC~ON P~N~: 80.09' RECEIVSD i~i(')V 1'/ """'~ iJ ./'J Gas Cons. CommJs6ion Anchorage JBHL DATA TVD 9238.96 MD 12092.18 VS 6619.49 North 1139.07 East 6520.75 SURFACE LOCATION A~P - X: 634478.].7 Y, 5977074.1:3 TARGET LOCATION BOTTOM HOLE LOCATION ASP - X: 640887.21 ASP - X: 640976.59 'Y: 5978304.03 jj Y: 5978332.77 CLOSURE: 6526.28 ~ 80.!9~1, CLOSURE: 6619.49 ~ 80.09 ' Do~e Created by DraFting By Checked By Approved By : I~nce J. Spencer Unit P udhoe }ay Pp ud¼oe Bay R-PAD R-35 R-35 "rr, c~veUin9 Cxlindem - No~mol ~eFepence Well - ~-35 WP~ ~: 0 - J~O9~ ~. ~n~epveU ~5 ~. All ~pec~ions 33O° 550 ) HALLIBURTBN I~ILL Ir,G SYgTEMS 11/09/1993 1032 om 270o go° 240° 120° 210o CLOSEST Fc'JINTS J 44.51 263.95 ~.57 75.15 453.53 503.41 533.89 N/A I J4.~ N/A ~A N/A N/A ~A N/A N/A 5~.~ N/A N/A 437.93 N/A N/A 887.~ N/A J ~.67 J ~.87 65.53 ~9.37 J~.45 J 37.83 8~8-~ 83~.~ N/A N/A 24..o9. L~57.84 344~ N/A ~.~5 3J 3.~ N/A N/A N/A N/A N/A N/A N/A 13.~ N/A N/A ~A ~A 3.73 N/A ~7.~ ~7~ ~7.~ ~4.8 ~ ~6.~ ~.3~ ~ .34 ~.~3 ~.~7 ~7.78 74.97 7~.~ 735i ~.57 51.78 N/A N/A 800.00 ! 37500 21.5,9.00 OEO 3325.00 65L:5,O9 N/A 4425.00 5L>59.00 N/A N/A N/A N/A N/A 4900,00 N/A N/A N/A 5975.00 N/A 275.00 250.03 127500 1 ~D.O9 1275.00 J 50C).00 ! 550,00 .~ 575.09 8?5,00 87509 775.CFJ ~ 459.00 1550.O9 I,I/A N/A ReF 799.16 ! ~S7.7¢ ! 78t 2119,56 P746.~ 0,~ ~78,~ N/A. . 4~J .37 N/A ~A ~A N/A N/A N/A N/A N/A N/A 467 ~ .~ N/A N/A N/A ~75.~ ~69.~ 1~4.13 '14~.11 5~.87 ~3.~ 873.76 ~73.76 774.P7 441,~ 53~.87 N/A N/A 180° Sep.Fo c't o¢' 2-50 8.70 9.0'3 11.80 9.40 12.10 542.00 17.10 14 20 3.20 N/A 1.70 3.60 N/A N/A N/A N/A N/A N/A N/A 7.60 N/A N/A 5.20 N/A N/A N/A 27.~D 6.80 6.50 14.70 11.60 10A0 1000 9.50 83.20 83,10 59.40 27.40 N/A N/A RECEIVED Anchorage 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP 38°F SPACER: 50 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ColdSet Ill ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX #SACKS: 1000 YIELD:1.92 ft3/sx MIX WATER: 10.5 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Class G ADDITIVES: 2% A-7, lghs FP-6L - . WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 375 MIX WATER: 4.95 gal/sk THICKENING TIME: Greater than 3 1/2 hours at 50° F. TOP JOB CEMENT TYPE: Coldset II ADDITIVES: Retarder WEIGHT: 14.9 ppg YIELD: 0.96 cu ft/sk. APPROX NO SACKS: 250 CENTRALIZER PLACEMENT 1. Run one (1) bow type centralizer per joint for the first 20 joints. 2. Place centralizers in the middle of each joint with a stop collar. CEMENT VOLUME 1. Lead slurry to sudace with 100% excess. 2. Tail slurry volume is 500' MD with 100% excess 3. Top job volume is 250 sx. _ MIX WATER: 3.89 gal/sk RECEIVED , ::f~ ".~a 0[I & C-':as Cons. Commission Anchorage 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F SPACER' 50 bbls BJ MCS-4 weighted to current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3 % A~2+0.4 % FL-52 + 0.5 % CD-32 +1 ghs FP-6L for greater than 5 hr thickening time WEIGHT: 11.0ppg YIELD: 3.31 cu ft/sk MIX WATER: 20.92 gal/sk APPROX # SACKS: 450 TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3 %FL-52 + 0.5 % CD-32 + 0.1% A-2 + lghs FP-6L WEIGHT: 15.8ppg YIELD: 1.14 cu flJsx MIX WATER' 4.85 gal/sk APPROX #SACKS: 265 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: 100-150cc @ 140° F FREE WATER: 0cc CENTRALIZER PLACEMENT: I Turbulator centralizer per joint on the bottom 500' of 7- 5/8" casing ( 12 required ). One solid bodY 7-3/4" x 9-1/4" centralizer or turbulator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS' Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. DO NOT batch mix tail cement. CEMENT VOLUME: 1. Lead slurry to 5400' (500' MD above West Sak) with 30% excess to isolate Cretaceous interval. 2. Tail G slurry to 1000' md above casing point with 30% excess. 3. 120' MD 7-5/8", 29.7# capacity for float joints. ~J..t ;~?:;,~,'.a. ';~' & G~.s Cons. Anchorage 5-1/2" PRODUCTION LINER CEMENT PROGRAM - BJ SERVICES CIRC. TEMP 140° F PREFLUSH: 20 bbls fresh water BHST 226 deg F at 8800' TVDSS. SPACER: 70 bbls BJ MCS-4 weighted 1.0 ppg above mud weight. WEIGHT: 15.7 ppg APPROX #SACKS: 120 FLUID LOSS: < 50 cc @ 140° F CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% Gel + 2 ghs FP-10L YIELD:1.17 ft3/sx MIX WATER: 3.58 gps THICKENING TIME: 45 min @ surface + 3-4 hrs @ 140° F FREE WATER: 0 cc at 45° angle Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, I per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. A field fluid loss test on the batch mixed slurry is no longer required. Displace @ 6-8 bpm. LINER CEMENT VOLUME: I . . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. RECEIVED l, OV i 7 Oil & Gas Cor~s. Oo~nrnission /~nchorage ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee ~2/Pc ///2~7 (]2) Loc. ~/~__ ~ [2 thru 8] '[]'9 thru 15] ' ' [10 & 13] (4) Casg ~ [14 thru 2'2] (5) BOPE ~ ~,c/~f [23 thru '28] Company Lease & Well Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings Will cement cover all known productive horizons ..................... YES NO 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. ~· 3. Is well located proper distance from property line ................... .~ _ 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated @ is wellbore plat included ................... 7. 8 eeeeleeeeeeeeeeee®e eeeeel®eeeeeeelelel pment adequate ..... & BOPE attached .... to ,.~o¢o psig ..... eeeeeeeeeeeeeeeeeee e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Will all casing give adequate safety in collapse, tension, and burst. ~[~ Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. ~- Is adequate wellbore separation proposed .......... ..~ Is a diverter system required ..................... Is drilling fluid program schematic & list of equi ~ Are necessary diagrams & descriptions of diverter _~_ Does BOP[ have sufficient pressure rating -- test 1~ Does choke manifold comply w/API RP-53 (May 84)... ~ Is presence of H2S gas probable ................... d~J REMARKS (6) Other [29 thru 31] .Contact/F¢¢~ (7) [32] (8) Addl ~ geology' engineering: R PC/fWd_ BE~ aDH · rev 6/93 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data .... ,. Additional requirements ............................................. / INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' MERIDIAN' UM ~ SM WELL TYPE' Exp/e~2~7( Inj. Red r i 11 Rev O --I -rz ~-~C) Z Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simp!ify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT RUN 1 6171.00 HENNINGSEN J. CARLILE REMARKS: R - 35 500292242400 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 18-MAR-94 OPEN HOLE BIT RUN 2 32 12N 13E 608 826 BIT RUN 3 54.80 53.30 20.20 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 110.0 10.750 3127.0 12088.0 MWD - DGR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. A MAD PASS WAS RUN IN ADDITION TO MAIN MWD PASS. THE MAD PASS IS IDENTIFIED ON THE BLUELINE AS THE REPEAT PASS. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11623.0 12063.0 RP 11630.0 12070.0 $ BASELINE CURVE FOR SHIFTS: GR (OPEN HOLE) CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 11604.7 11637.0 11646.7 11651.5 11744.0 11756.2 11768.9 11809.2 11825.4 11841.9 11862.8 11900.2 11941.0 11968.8 12104.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 11600.0 11633.2 11642.0 11648.0 11741.0 11750.2 11763.5 11804.5 11820.0 11837.0 11859.0 11897.0 11937.0 11964.3 12100.0 BIT RUN NO MERGE TOP 1 11648.0 MERGE BASE 12088.0 ALL MWD CURVES WERE SHIFTED WITH THE GR. / ? ? SHIFT. OUT $ CN : BP EXPLORATION WN : R - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: API API API API Name Tool Code Samples Units 1 GR MWD 68 1 AAP I 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OH/~4 5 RPD MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR 7 FET MWD 68 1 HR Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 91 948 38 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 99 789 97 5 4 62 202 97 6 28 * DATA RECORD (TYPE# 0) Total Data Records: 32 998 BYTES * Tape File Start Depth = 12090.000000 Tape File End Depth = 11600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7849 datums Tape Subfile: 2 125 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 11619.0 EWR4 11626.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12059.0 12066.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 21-DEC-94 1.98 3.93/1.14P4 MEMORY 12088.0 11648.0 12088.0 0 0.0 0.0 TOOL NUMBER P0202CGR6 P0202CGR6 9.875 3127.0 LSND 9.70 46.0 9.4 700 6.4 2.500 1.060 2.900 3.800 69.0 172.0 69.0 69.0 0.00 0.000 0.0 2 REMARKS: .MWD RUN 1. $ CN : BP EXPLORATION WN : R - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHM/~ 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHM/~ 5 RPD MWD 68 1 OPIMM 6 ROP MWD 68 1 FPHR 7 FET MWD 68 1 HR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 91 948 38 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 99 789 97 5 4 62 202 97 6 28 * DATA RECORD (TYPE# 0) Total Data Records: 31 998 BYTES * Tape File Start Depth = 12080.000000 Tape File End Depth = 11600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7689 datums Tape Subfile: 3 96 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 11600.0 EWR4 11600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIM UMANGLE: MAXIMUM ANGLE: STOP DEPTH 12058.0 12066.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 21-DEC-94 1.98 3.93/1.14P4 MEMORY 12088.0 11600.0 12087.0 0 0.0 0.0 TOOL NUMBER P0202CGR6 P0202CGR6 9.875 3127.0 LSND 9.70 46.0 9.4 700 6.4 2.500 1.060 2.900 3.800 69.0 172.0 69.0 69.0 0.00 0.000 TOOL STANDOFF (IN) : 0.0 EWR FREQUENCY (HZ): REMARKS: MAD PASS (REPEAT). $ CN : BP EXPLORATION WN : R - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 2 RPX MAD 68 1 OHMM 3 RPS MAD 68 1 OHMM 4 RPM MAD 68 1 OHMM 5 RPD MAD 68 1 OHMM 6 ROP MAD 68 1 FPHR 4 4 54 433 96 6 4 4 16 987 05 1 4 4 16 987 05 1 4 4 16 987 05 1 4 4 16 987 05 1 4 4 37 304 39 5 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 12090.000000 Tape File End Depth = 11600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14717 datums Tape Subfile: 4 94 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 94/ 3/20 01 **** REEL TRAILER **** 94/ 3/20 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 20 MAR 94 9:28a Elapsed execution time = 7.64 seconds. SYSTEM RETURN CODE = 0 ', i 440 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD R-35 (23-33-12-13) 500292242400 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 23-FEB-94 6136.00 R. ECK C. HUGHES 32 12N 13E 608 826 54.80 21.70 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 10.750 3125.0 PRODUCTION STRING 9.875 7.625 12075.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GRCH 1 1 29-JAN-94 ATLAS WIRELINE SERVICES EQUIVALENT UNSHIFTED DEPTH - PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: CN/GR CASED HOLE (MARKED LINE). 45.50 29.70 LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. CN LOGGING PARAMETERS: SANDSTONE MATRIX CHISM ON CASING CORRECTION ON CASING THICKNESS = 0.375 INCH CEMENT THICKNESS = 1.125 INCH CALIPER CORRECTION = 9.875 INCH SALINITY = 0 PPM. SHIFT PROCEDURE AS FOLLOWS: l) THE NEUTRON WAS DEPTH MATCHED TO THE CASED HOLE GAMMA RAY (MARKED) LINE). FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2435 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 11440.0 11451.0 STOP DEPTH 11978.0 11985.0 (MEASURED DEPTH) BASELINE DEPTH NPHI 11424.0 11424.0 11452.5 11452.5 11453.5 11453.5 11461.0 11460.0 11463.5 11463.5 11469.5 11469.5 11494.0 11494.0 11499.5 11499.5 11509.5 11509.5 11518.5 11519.0 11528.5 11528.5 11556.0 11552.5 11558.0 11554.5 11558.5 11555.0 11567.0 11565.0 11574.5 11576.0 11580.0 11580.0 11606.0 11606.0 11609.5 11608.0 11615.5 11616.0 11625.0 11625.0 11632.5 11632.5 11634.5 11633.5 11636.5 11636.5 11638.5 11638.5 11648.5 11649.0 11650.5 11651.0 11651.5 11652.0 11654.0 11654.0 11673.5 11673.5 11684.0 11684.0 11686.0 11687.5 11689.0 11690.0 11692.5 11694.0 11703.5 11703.5 11705.0 11705.0 11706.5 11706.5 11744.0 11745.0 11755.5 11755.5 in separate files. EQUIVALENT UNSHIFTED DEPTH 11756.5 11758.0 11761.0 11762.5 11764.0 11771.5 11790.0 11791.5 11803.0 11806.5 11814.5 11825.0 11830.0 11841.5 11850.0 11869.5 11885.0 11893.5 11917.0 12004.0 $ REMARKS: 11756.5 11757.0 11760.0 11762.0 11764.0 11771.5 11791.5 11793.5 11803.0 11806.0 11814.5 11824.5 11830.5 11840.5 11849.0 11870.0 11884.0 11893.5 11918.0 12004.0 MAIN PASS. CN WN FN COUN STAT / ??MATCH1. OUT $ : BP EXPLORATION : R- 35 (23-33-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 23 Tape File Start Depth Tape File End Depth = 11440.000000 = 11994.000000 Tape File Level Spacing = Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5546 datums Tape Subfile: 2 180 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes 0,500000 Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11439.5 2435 11446.0 $ LOG HEADER DATA STOP DEPTH 11988.5 11994.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAMMA RAY CN COMPENSATED NEUTRON ACOM ACOUSTILOG COMMON $ 29-JAN-94 FSYS REV. J001 VER. 1.1 2352 29-JAN-94 11995.0 11994.0 11400.0 11986.0 1500.0 YES TOOL NUMBER 2330NA 1309XA 2435XA 1633EA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12075.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER / DIESEL 0.00 0.0 0.0 0 0.0 0.000 0.O0O 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 9.875 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 30 FAR COUNT RATE HIGH SCALE (CPS): 830 NEAR COUNT RATE LOW SCALE (CPS): 100 NEAR COUNT RATE HIGH SCALE (CPS): 1100 TOOL STANDOFF (IN): 0.0 REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION : R- 35 (23-33-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 2 CNC 2435 68 1 PU-S 3 CNCF 2435 68 1 PU-L 4 CN 2435 68 1 CPS 5 LSN 2435 68 1 CPS 6 SSN 2435 68 1 CPS 7 CCL 2435 68 1 F/MN 8 SPD 2435 68 1 LB 9 TEN 2435 68 1 LB 4 4 08 501 10 0 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 90 640 78 6 4 4 54 376 29 5 4 4 19 912 29 5 4 4 19 912 29 5 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 93 Tape File Start Depth = 11424.000000 Tape File End Depth = 12003.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23171 datums Tape Subfile: 3 Minimum record length: Maximum record length: 168 records... 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11785.0 2435 11791.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 11988.0 11997.0 TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAMMA RAY CN COMPENSATED NEUTRON ACOM ACOUSTILOG COMMON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 29-JAN-94 FSYS REV. J001 VER. 1.1 2328 29-JAN-94 11995.0 11994.0 11400.0 11986.0 1500.0 YES TOOL NUMBER 2330NA 1309XA 2435XA 1633EA 0.000 12075.0 0.0 SEAWATER / DIESEL 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 9.875 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 30 FAR COUNT RATE HIGH SCALE (CPS): 830 NEAR COUNT RATE LOW SCALE (CPS): 100 NEAR COUNT RATE HIGH SCALE (CPS): 1100 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION : R- 35 (23-33-12-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 2 CNC 2435 68 1 PU-S 3 CN 2435 68 1 PU-L 4 CNCF 2435 68 1 CPS 5 LSN 2435 68 1 CPS 6 SSN 2435 68 1 CPS 7 CCL 2435 68 1 F/MN 8 SPD 2435 68 1 LB 9 TEN 2435 68 1 LB 4 4 08 501 10 0 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 90 640 78 6 4 4 54 376 29 5 4 4 19 912 29 5 4 4 19 912 29 5 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 14 Tape File Start Depth = 11772.000000 Tape File End Depth = 11856.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8917 datums Tape Subfile: 4 Minimum record length: Maximum record length: 89 records... 62 bytes 1006 bytes Tape Subfile 5 is type: LIS 94/ 2/23 01 **** REEL TRAILER **** 94/ 2/23 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 23 FEB 94 5:17p Elapsed execution time = 20.48 seconds. SYSTEM RETURN CODE = 0
