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183-091
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ON WEL OMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG 0 Other ❑ Abandoned 2 Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero ' Service 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 6/9/2016 183-091 - 316-229 3. Address: 7. Date Spudded: t5' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 6/15/1983 50-029-20970-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 6/25/1983 PBU 14-24 • Surface: 1519'FNL,1992'FEL,Sec.09,T1ON,R14E,UM • 9 Ref Elevations KB 72 17. Field/Pool(s): 270'FNL,2680'FEL,Sec.09,T1ON,R14E,UM GL 42.26 PRUDHOE BAY,PRUDHOE OIL • Top of Productive Interval: BF 44.3 Total Depth: 28'FSL,2718'FEL,Sec.04,T1ON,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9017'/8702' ADL 028312 ' 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 674488• y- 5938804 • Zone - ASP 4 9586'/9203' 77-043 TPI: x- 673768 y- 5940038 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 673722 y- 5940334 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 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 DIL/SP/BHCS/GR,FDC/CNL/GR/CAL,CBL,Gyro 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 31' 111' 31' 111' 30" 400 sx PF II 13-3/8" 72# L-80 30' 2532' 30' 2532' 17-1/2" 2000 sx Fondu,400 sx PF C 9-5/8" 47# L-80/US-95 P7' 8974' 27' 8664' 12-1/4" 500sx Class'G',244 sx PF C 7" 29# N-80 8660' 9586' 8385' 9203' 8-1/2" 300 sx Class'G' 24. Open to production or injection? Yes ❑ No II 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): 5-1/2"17#L-80 8706' 8624'/8352' x 4-1/2"12.6#L-80 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ,gt,04)J,)'eThO RECEIVED Was hydraulic fracturing used during completion? Yes ❑ No RI DATE Per 20 AAC 25.283(i)(2)attach electronic and printed �' ` t information JUL 0 5 2016 VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ��_ AAGrC 9017' 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 .....41. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only VA, ITL X1311 'f RBDMS tA- JUL 0 6 2016 .� i ,i4., IG 28,. CORE DATA • Conventional Core(s) Yes 0 No E . Sidewall Cores Yes 0 No l If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No Q Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8954' 8647' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8954' 8647' Sadlerochit 9059' 8739' Formation at total depth: 1 3 List of Attachments: Summary of Pre-Rig Work,Summaryof Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Minge,David Email: David.Minge@bp.com Printed Name: Joe Lastu a j Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: /15 1 1 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 lb.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 11/2015 Submit ORIGINAL Only . • 14-24 Well History (Pre-Rig Sidetrack) Vvi *70 CTU#6 1.75" HS-110 Job Scope: Mill Cement Sheath/FCO - Pre CTD MIRU CTU. 5/7/2016 ***In Progress*** CTU#6 1.75" HS-110 Job Scope: Mill Cement Sheath/FCO - Pre CTD MIRU CTU. MU BOT milling assembley w/3.80" Diamond String Reamer& 3.80" Diamond Parabolic Mill - RIH 5/7/2016 ***Continue on WSR 5/8/16*** CTU#6 1.75" HS-110 Job Scope: Mill Cement Sheath/FCO - Pre CTD RIH w/ BOT milling assembly w/3.80"String Reamer&3.80" Diamond Parabolic Mill. Dry tag at 8742'. Perform 3 milling passes from 8500'to 8850' (90% returns)with minimal motor work seen. Circulate btms up. From 8445', rih dry&tag bottom at 9022' (uncorrected ctm). Correct depth to 8981' per program. FCO with gel sweeps down to 9055' (down depth). Up depth = 9050' E corrected /9088' E Uncorrected/9054' M Uncorrected. Chase up hole &circ btms up. From 8330', rih dry&tag at 9031', appears we left some fill. Attempt to fluff/stuff down to 9050' but sand is plugging off perfs. Go back to normal circulation and clean out to 9052'with gel sweeps. Dry tag at 9047' down /9043' up. Call this depth good, chase ooh. FP Coil. Mill/String Reamer gauged at 3.80". RIH w/ Baker Dmy Whipstock. Tag TD at 9071' uncorrected ctm. Pooh. FP Tbg w/50/50 Meth. 5/8/2016 Rig Down CTU. CTU#6 1.75" HS-110 Job Scope: Mill Cement Sheath/FCO - Pre CTD RIH w/ BOT milling assembley w/3.80" Diamond String Reamer&3.80" Diamond Parabolic Mill -Tag 8719' CTM - Perform 3 milling passes from 8500'to 8850' (90% returns) -Circ Btm Up- 5/8/2016 ***In Progress*** ***WELL S/I ON ARRIVAL***(ctd) DRIFTED 10' x 3.70" DUMMY WHIP STOCK, 2.50" SAMPLE BAILER TO 9034' SLM RAN PDS 40 ARM CALIPER W/CCL GAMMA RAY FROM 9030' SLM TO 8000' SLM SET 5-1/2" SLIP STOP CATCHER SUB © 4903' SLM PULLED RK-DGLV FROM STA#2 © 4797' SLM/4817' MD SET RK-CIRC GLV IN STA#2 ©4797' SLM/4817' MD PULLED 5-1/2"SLIP STOP CATCHER SUB FROM 4903' SLM LRS CIRC OUT IA W/ DIESEL. 5/9/2016 ***JOB CONTINUED ON 05/10/16 WSR*** T/I/O=0/200/20 Temp= SI Assist SLB Slickline (PRECTD) Pumped 2 bbls Methanol, followed by 83 bbls Diesel down IA to load. 5/9/2016 ***Continued to 5-10-16*** ***JOB CONTINUED FROM 05/09/16 WSR***(ctd) LRS CIRC OUT IA W/290 BBLS DIESEL(see Irs wsr for details) SET 5-1/2"SLIP STOP CATCHER SUB ©4901' SLM LRS FREEZE PROTECT FLOWLINE &TBG W/CRUDE (see Irs wsr for details) PULLED RKP-FLOW SLV FROM STA#2 ©4797' SLM/4817' MD PULLED RK-DGLV FROM STA#1 © 2883' SLM/2903' MD SET RK-LGLV(16/64" ports, 1500psi tro) IN STA#1 © 2883' SLM/2903' MD SET RK-S/O (20/64" ports) IN STA#2 ©4797' SLM/4817' MD PULLED EMPTY 5-1/2" SLIP STOP CATCHER SUB FROM 4901' SLM 5/10/2016 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** ***Continued from 5-9-16*** Pumped 204 bbls of diesel down the IA to load for CTD. Pumped 4 bbls Methanol and 88 bbls crude down FL, and 60 bbls of crude down TBG to Freeze protect. AFE sign was already hung on Master valve. SLB Slickline in control of well upon LRS departure. 5/10/2016 FWHP=2800/800/18 • 14-24 Well History (Pre-Rig Sidetrack) ***WELL S/I UPON ARRIVAL***(SLB E-LINE -WHIPSTOCK) INITIAL T/I/O =200/200/0 MIRU. PT. RIH W/ 3.625" BAKER WHIPSTOCK. SET 3.625" BAKER WHIPSTOCK AT 9007'. WHIPSTOCK ORIENTATION WAS 6° ROHS, CCL TO TOP OF WHIPSTOCK= 14.1', CCL STOP DEPTH =8992.9'. LOG CORRELATED TO PDS COIL FLAG. DATED 02-NOV-2012. POOH. RDMO. FINAL T/I/O = 260/260/0 5/14/2016 ***WELL SHUT IN UPON DEPARTURE***JOB COMPLETE ****WELL S/I UPON ARRIVAL****(pre ctd) SET 5 1/2" SSCS 8197' SLM MADE 3 ATTEMPTS TO PULL ST#7 @ 8,126' MD (unable to latch, see log) RAN 1.75" LIB TO ST#7 @ 8,126' MD (impression of rk latch) 6/1/2016 ***CONTINUE WSR ON 06/02/2016*** T/I/O=SI Circ Out (CTD) 6/1/2016 ****Job continued on 6/2/16 **** T/I/0=62/32/2 Temp=SI Assist S-line ( Pre CTD) Pumped down IA through station #7 up TBG down hard line jumper to neighboring well (07-24) F-line with 5 bbls of 35* meth followed by 293 bbls of Inhibited (KI 3869 =55 gallons) 9.8 NaCI brine F-protect IA with 83 bbls of 35*diesel. F-protect hard line jumper with 1 bbl of meth followed by 3 bbls diesel. 6/2/2016 Slickline on well upon LRS departure. Casing valves= OTG's Tags &AFE sign hung. ***CONTINUE WSR FROM 06/02/2016***(pre ctd) PULLED RK-DGLV FROM ST#7 @ 8,126' MD PULLED RK-OGLV FROM ST#2 @ 4,817' MD PULLED RK-LGLV FROM ST#1 @ 2,903' MD SET RK-DGLV IN STA.#1 @ 2903' MD SET RK-DGLV IN STA#2 @ 4817' MD LRS CIRCULATED IA W/290BBLS OF BRINE FOLLOWED BY 83BBLS OF DIESEL FREEZE PROTECT SET RK-DGLV IN ST#7 @ 8,126' MD LRS FREEZE PROTECTED HARDLINE PULLED EMPTY SLIP STOP CATCHER FROM 8,197' SLM 6/2/2016 ***CONTINUE WSR ON 06/03/2016*** ****Job continued from 6/1/16 **** 6/2/2016 ***GOT PULLED, TO GO DO ANOTHER JOB *** ***CONTINUE WSR FROM 06/02/2016***(pre ctd) SWCP 4518 RIG DOWN 6/3/2016 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** T/I/O = 200/0/0. Temp =SI. WHP's (pre rig). Well is demobed with rig scaffolding in 6/6/2016 place. BPV crew on well upon departure. 1200. T/I/O= 200/0/0. Installed 5" K-Plug BPV#606, tagging @125". Installed TS#08, Pumping manifold with integral flange on WV and installed IA piggyback valve TEMP#52. Torqued and PT'd to API specs. RDMO***Job Complete***. SEE LOG FOR DETAILS. Final T/I/O= 6/6/2016 BPV/0/0. Hung BPV and Pressure Test signs on MV. • • North America-ALASKA-BP Page 1 Operation Summary Report Common Well Name:14-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2016 End Date:6/14/2016 X3-017WF-C:(3,026,127.00) Project:Prudhoe Bay r Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:6/15/1983 12:00:00AM Rig Release:6/17/2016 Rig Contractor:NORDIC CALISTA j UWI:500292097000 Active datum:45:24 6/15/1983 00:00 @72.00usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 6/7/2016 17:00 - 19:00 2.00 RIGD P PRE RIG RELEASED FROM DS 11-12 AT 1700 HRS. -CLEAN PITS,WORK ON RIG MOVE CHECKLIST -WARM UP MOVING SYSTEM -CONTINUE WITH BREAKING DOWN AND MOVING SUPPORT EQUIPMENT -STATE AOGCC WAS NOTIFIED OF REQUEST TO TEST BOP AT 1330 HRS ON JUNE 7TH, RECEIVED REPLY OF WITNESS WAIVED BY LOU GRIMALDI AT 1400 HRS UNLESS RIG _—_ OPERATIONS ARE DELAYED BY 48 HRS 19:00 - 00:00 5.00 RIGD P i PRE PJSM FOR PULLING OFF OF WELL. REVIEW 1 RIG MOVE PROCEDURE. ASSIGN ROLES AND RESPONSIBILITIES,DISCUSS VISUAOL STOP SIGNAL. 1-FUNCTION TEST THE ESD,ENSURE 12"X 112"BLOCK IS IN PLACE,TEST RADIOS 6/8/2016 00:00 - 06:00 I 6.00 MOB P PRE i CONTINUE WITH RIG MOVE. MOVE ON TO DRILL SITE 14, 06:00 - 07:00 1.00 MOB P I PRE i MOVE RIG TO STAGE IN FRONT OF 14-24. PJSM FOR MOVING OVER WELL. I i I DISCUSSION FOCUSED ON VERBALAND [VISUAL COMMANDS FOR STOP,ROLES AND ,RESPONSIBILITIES. -FUNCTION ESD,PERSON IN PLACE WITH 12"X 12"BLOCK. NO PRESSURES ON OA OR IA,TWC IN WELL. -MOVE OVER WELL,RIG ACCEPT AT 0700 L HRS 07:00 - 12:00 5.00 RIGU P PRE STAGE SUPPORT EQUIPMENT PREP RIG FOR OPERATIONS -STROKE SSV,STROKE OPEN AND INSTALL FUSIBLE CAP -CYCLE ALL TREE VALVES TO OPEN,NO PRESSURES -TESTAND PULL TREE CAP -NU BOP -BEGIN TAKING ON KCL INTO PITS 12:00 - 18:00 6.00 BOPSUR P PRE TEST BOP EQUIPMENT PER AOGCC,BP,AND NORDIC PROCEDURES -ALL TESTS TO 250 PSI LOW/3500 PSI HIGH, ANNULAR TESTED TO 250 PSI LOW/3500 PSI HIGH FUNCTION RAMS FROM DRILLERS I CONSOLE DURING PRESSURE TESTING -FUNCTION RAMS FROM REMOTE CTS CONSOLE DURING ACCUMULATOR DRAWDOWN TEST -WELL 14-19 IS FREEZE PROTECTED AND SHUT IN/LOCKED OUT -TEST INNER REEL IRON,INNER REEL VALVE AND PACKOFFS TO 250 PSI LOW/3500 PSI HIGH 18:00 - 18:15 0.25 RIGU P PRE CONDUCT H2S EVAC DRILL WITH RIG CREW. CONDUCTAAR,DISCUSS ALARMS AND i l MITIGATIONS. 18:15 - 19:30 1.25 RIGU P PRE PUMP SLACK BACK. CUT 265'OF COIL FOR 1.7%SLACK CALCULATION. Printed 6/27/2016 11:28:51AM *All depth reported in Drillers Depths* • • North America-ALASKA-BP Page 2 Operation Summary Report Common Well Name:14-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:6/7/2016 End Date:6/14/2016 X3-017WF-C:(3,026,127.00) -- Project:Prudhoe Bay I Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:6/15/1983 12:00:00AM Rig Release:6/17/2016 Rig Contractor:NORDIC CALISTA I UWI:500292097000 Active datum:45:24 6/15/1983 00:00 @72.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 22:45 3.25 RIGU P PRE --INSTALL COIL CONNECTOR. PULL TEST TO 35K,PRESSURE TEST TO 250 PSI LOW/4700 PSI. CAPTURE REEL HOUSE HARD-IRON IN THIS TEST. --PUMP SLACK FORWARD --TESTE-LINE GOOD --MAKE UP UQC WITH DUAL FLOATS. ' TEST UQC TO 4400#. PERFORM CHARTED TEST ON FLOATS 300#/3500# SET INJECTOR IN BUNG HOLE, PUMP SLACK FORWARD PER PROCEDUREAT2.4 1 'BPM --SIMOPS WITH GREASE CREW/ CHECK TORQUE ON TREE. GOT SOME MOVEMENT ON NUTS BETWEEN THA AND MASTER VALVE 22:45 - 00:00 1.25 RIGU P 1 PRE I PJSM WITH VALVE CREW IDISCUSS PROCEDURE FOR PULLING BPV —DISCUSS PRESSURE TESTING PER WELL PROGRAM/PRESSURE CROSSCHECK —BRING TOOLS/LUBRICATOR TO RIG FLOOR —VERIFY SPACE OUT FOR PULLING BPV ABOVE SWAB VALVE --STAB VALVE CREW LUBRICATOR. FILL I LUBRICATOR WITH METHANOL. I --PERFORM LOW 300#/ BRING PRESSURE ,TO 3700# 6/9/2016 00:00 - 01:30 I 1.50 CONDHL I P PRE CONTINUED WITH PRESSURE TEST OF BPV Ij E !LUBRICATOR RIH WITH ROD. PUMP THROUGH BPV WITH 1 TEST PUMP TO VERIFY EQUALIZATION PULL BPV. WELL 0+. CLOSE MASTER AND SWAB/PERFORM LEAK TIGHT TO 3500# RECOVERED PLUG WITH SEAL ___ OFF LOAD VALVE CREW EQUIPMENT 01:30 - 02:00 0.50 CONDHL P I PRE I PERFORM H2S/RIG EVACUATION DRILL --WIND BLOWING CELLAR TO REEL HOUSE. —MUSTER WAS EXPEDIANT AND PERSONNEL ION DRILLERS SIDE OF RIG MUSTERED AT -- j !SECONDARY 02:00 - 03:00 1.00 CONDHL P PRE MAKE UP NOZZLE BHA#1 STAB INJECTOR. PT QTS 300#/4000# PJSM WITH GREASE CREW/ SERVICE TREE. PERFORM PRE SPUD WITH CREW WHILE GREASING TREE 03:00 05:30 2.50 CONDHL I P PRE BOTTOM KILL I OPEN WELL UP TO CLOSED CHOKE 0+ RIH WITH CLOSED CHOKE AT MINIMUM RATE 10.5 BPM UNTIL THERE IS 100#POSITIVE IPRESSURE -1000'IN HOLE AND 9 BBLS AWAY STARTED GETTING POSITIVE PRESSURE I -CRACK HAND CHOKE AND MAINTAIN .100-150#WELLHEAD INCREASE RATE TO 1.5 BPM WHILE 1 I RUNNING IN HOLE I-WEIGHT CHECK AT 8500'AT 39K UP/20K RIH -LIGHTLY TAG WHIPSTOCK AT 9047.5 �— ______i___ i ,UNCORRECTED. Printed 6/27/2016 11 28 51AM *AII depth reported in Drillers Depths* North America-ALASKA-BP Page 3 arta Operation Summary Report Common Well Name:14-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2016 End Date:6/14/2016 X3-017WF-C:(3,026,127.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:6/15/1983 12:00:00AM Rig Release:6/17/2016 Rig Contractor.NORDIC CALISTA ,UWI:500292097000 Active datum:45:24 6/15/1983 00:00©72.00usft(above Mean Sea Level) Date From-To j Hrs j Task I Code NPT NPT Depth 1 Phase 1 Description of Operations (hr) . (usft) 05:30 - 09:30 , 4.00 CONDHL i P PRE 'I START BOTTOM KILL 4.05 BPM IN/ 3.77 BPM WOC AT 238#WELLHEAD/CIRC PRESSURE 2194# -63 BBLS OUT NOZZLE INCREASE RATE TO 4.4 BPM IN/4.14 OUT 8.40 PPG IN/9.21 OUT (LOSING 12 BPH) -125 BBLS OUT NOZZLE. 4.4 BPM IN /4.25 1 BPM OUT 8.37 PPG IN/8.83 PPG OUT I(LOSING 9 BPH) -165 BBLS OUT NOZZLE 4.4 BPM IN/4.27 BPM OUT 8.37 PPG IN /8.32 PPG OUT LOSING 8 BPH) BOTTOMS UP WOC AT 271#WELLHEAD/2329#CIRC !PRESSURE IA/OA=494#/0# -IA PRESSURE REMAINED AT 480 PSI WITH 8.5 PPG KCL ALL THE WAY AROUND,OAATO PSI,WELLHEAD AT 250 PSI. -SWAP OVER TO 8.6 PPG MUD. LOSING-4 BPH WHILE CIRCULATING MUD OUT OF BIT AT 4.25 BPM,CONDUCT FLOW CHECK ON BOTOM WHILE RIG TEAM PULLS FLUID FROM FLOW BACK TANK. FLOW CHECK IS GOOD, WELL STATIC. -PULL TO SURFACE,WELL IS ON-1 BPH LOSSES CIRCULATING 8.51 PPG FLUID AT 2.15 BPM,1600 PSI. IAAT 265 PSI WHILE I PUMPING. I -PJSM FOR LAYING DOWN BHA. DISCUSS FLOW CHECK. -PULL BHA INTO STACK,FLOW CHECK. WELL IS STATIC,NO FLOW. 09:30 - 10:00 0.50 STWHIP P WEXIT BREAK OFF NOZZLE BHA. MAKE UP 3.80" WINDOW MILLING BHA#2. GAUGE:WINDOW MILL 3.80"GO,3.79"NO-GO,STRING REAMER 3.81"GO,3.80"NO-GO. , -MU MILL ASSEMBLY AND MOTOR TO BHI SMART TOOLS. STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB WHILE TOOLS ARE BEING POWERED ON AND EDC OPENED. 10:00 - 11 30 1.50 STWHIP P WEXIT RIH WITH MILLING BHA. LOSING AVERAGE OF 2.5 BPH WHILE RIH AT 100 FPM AND CIRCULATING AT.55 BPM. MW IN 8.56 PPG,IA _ + PRESSURE AT 265 PSI. 11:30 - 12:45 1.25 I STWHIP P WEXIT -LOG PRIMARY TIE-IN FOR GEO TEAM WITH -30'CORRECTION. LOG CCL FOR EVENTUAL ,LINER TOP PLACEMENT. 12:45 - 13:00 0.25 I STWHIP P WEXIT ,RIH WITH MILLING BHA. COME ON WITH PUMPS TO 1.65 BPM,1395 PSI,IA OF 270 PSI, • I TO MOVE THROUGH CEMENT SHEATH THAT j I HAD BEEN PREVIOUSLY MILLED TO 3.80 TAG WHIPSTOCKAT 9017'MD. PRE-RIG SET POINT HAS TOP OF WHIPSTOCK AT 9007' ELMD. �__ 1 -PICK UP. PICKUP WEIGHT OF 38K. Printed 6/27/2016 11.28:51AM "All depth reported in Drillers Depths* • North America-ALASKA-BP Page 4r5E14, Operation Summary Report Common Well Name:14-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) 1 Start Date:6/7/2016 End Date:6/14/2016 1X3-017WF-C:(3,026,127.00) Project:Prudhoe Bay Site:PB DS 14 Rig Name/No.:NORDIC 2 Spud Date/Time:6/15/1983 12:00:00AM I Rig Release:6/17/2016 Rig Contractor:NORDIC CALISTA 1UVVI:500292097000 Active datum:45:24 6/15/1983 00:00 @72.00usft(above Mean Sea Level) • Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3rA1300 - 00-00 11.00 STWHIP P ; WEXIT MOVE DOWN AND BEGIN MILLING itif OPERATIONS FROM 9016.6' t6V'2IA -FREEINITIAL SP CI NI ROCFU MILL PER WELL PLAN AND BOT 2215 5I OPNSIR, ATAETO3F002.P5s5 IBPM, REPRESENTATIVE WOB RANGING FROM.32-2.67K, DIFFERENTIAL PRESSURE OF 80-300 PSI -LOSSES AT—2 BPH WHILE MILLING AT 2.55 BPM. MW IN 8.60 PPG,MW OUT 8.54 PPG,IA STEADYAT 305-310 PSI THROUGHOUT. -9022' TAKING A LOT OF WEIGHT. LET DRILL OFF, -MILL OUT AT 9024.5' STRING REAMER OUT AT 9025.5' START MILLING RATHOLE 6/10/2016 00:00 - 02:20 2.33 STWHIP P WEXIT FINISH MILLING RATHOLE 12.53 BPM IN/2.53 BPM OUT I 18.56 PPG IN /8.52 PPG OUT 'MINIMAL LOSSES 102:20 - 04:00 1.67 STWHIP P WEXIT PERFORM REAMING PASSES WITH NO ISSUE DRY DRIFT. NO ISSUES PUMP 5 BBL HI VIS SWEEP AND CHASE UP ON FINAL PASS 04:00 - 04-10 0 17 ; STWHIP P WEXIT ,OPEN EDC PERFORM 10 MINUTE FLOWCHECK. WELL STATIC 04:10 - 05:35 1.42 STWHIP P WEXIT POOH FOR BUILD BHA 4.12 BPM IN /3.50 BPM OUT(120 FPM) 8.61 PPG IN/8.52 PPG OUT 12 BBLS LOST ON TRIP OUT 05:35 - 05:55 0.33 STWHIP P WEXIT PERFORM 10 MIN FLOW CHECK. WELL STATIC. 1 1-POP OFF WITH INJECTOR 05:55 - 07:00 1.08 DRILL P WEXIT LAY DOWN MILLING BHA. MILLS GAUGE AT 3.80"GO,3.79"NO-GO FOR WINDOW MILL AND 3.80"NO-GO FOR STRING REAMER. -MAKE UP BHA#3:3.75"BY 4.25"HYCALOG BIT TO 2-7/8"ULTRA LOW SPEED MOTOR WITH 2.95°AKO BEND ONTO SMART TOOLS WITH FLOATS IN ASSEMBLY. -STAB ON WITH INJECTOR AT 0700 HRS -WELL WAS STATIC AT SURFACE,NO LOSSES 07:00 - 09:45 2.75 DRILL P PROD1 PRESSURE TEST QUICK TEST SUB VVHILE MWD PACKAGE IS POWERING UP AND EDC 1 IS OPENED. RIH WITH BHA. 1 -MW IN 8.52 PPG,MW OUT 8.53 PPG, LOSSES OF 2.5 BPH WHILE RUNNING IN,IA AT 210 PSI WITH 8.52 PPG FLUID -SOME SLIGHT BOBBLES MOVING DOWN THROUGH CEMENT SHEATH WITH THE 2.95° BEND MOTOR 1-LOG TIE-IN WITH-31'CORRECTION. TAG BOTTOM AT Printed 6/27/2016 11-28-51AM *All depth reported in Drillers Depths" TREE= 5"FRAC 120 0 WELLHEAD= GRAY I -2 4 ' SAFETY NOTES: T x IA LEAK AT SSSV NIP""" ACTUATOR= BAKER C OKB= 72' I ill REF ELEV= 7Z / 2142' H5-1/2"CAM BAL-O SSSV NP,ID=4.562" I BF-ELEV= 44-3' _"CONDUCTOR - ? I �J�' KOP= 530(Y .-#, MaxAngle= 29°@ 9000' D= " 4 CAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE Datum MD= 9210' Datum ND= 8800'SS 2 1 2903 2903 1 CA DMY RK 0 06/02/16 2 4817 4817 1 CA DMY RK 0 06/02/16 13-3/8"CSG,72#,L-80 BT&C,D=12.347" --I 2532' ILI 3 6215 6139 27 CA DMY RK 0 01/13/16 4 7206 7037 23 CA DM' RK 0 01/13/16 5 7757 7550 21 CA DMY RK 0 08/27/00 9-5/8"CSG,474,L-80 BT&C XO TO US-95 BT&C - 8137' X ^ 6 7819 7608 21 CA DMY RK 0 06/30/83 7 8126 7895 21 CA DMY RK 0 06/02/16 8" 8197 7961 21 CA DMY RIC 0 06/30/83 9"•" 8462 8205 24 CA DMY RK 0 06/30/83 Minimum ID =3.80" @ —8622' 10"" 8531 8268 25 CA DMY RK 0 06/30/83 TOP OF CEMENT SHEATH ""CEMENT INMANDREt-S-UNABLE TOPULL r -8522'--8760' -CEMENT SHEATH.,MILLED TO 3.80" :*,:y.-'4:. + 5-1/2"TBG-PC, 17#,L-80,.0232 bpf,D J=4-892" L. 8614' •+. (05/08/16) y Irti t, * 8600' --I 5-1/2"BKR FBR ASSY rte,•. ' 4.Ar: '--- 8614' --15.1/2"X 4-1/2'XO,D=3.958" - 31.-1°1'. 8624' -9-5/8'X 4-1/2'BKR FHL HY D PKR TOP OF 7"LNR -I 8660' •"' CUT SQZ(12/14/93) { 8692' H4-1/2"CAMCO DB-6 LANDING NP,ID=3.813" 511 hi 8705' -4-1/2"BKR SF-EAROUT SUB 4-1/2"TBG-PC,12.6#,L-80 BT&C, - 8706' AP" 8706' H4-1/2"VVLEG,D=3.958" .0152 bpf,D=3.958" 8685' --I amp TT LOGGED 08/27183 9-5/8'CSG,47#,US-95 BT&C XO TO L-80 BT&C -{ 8972' --._.X II 9-5/8"CSG,47#,L-80 BT&C,D=8.681" H 8974' '---4 4-1/2"X 7"BKR DELTA WS w/2 PIP TAGS(05/14/16)- 901T ' 9032' ELM --I ESTIMATE TOC CAP 11!04/12) i*.fY • 9059'ELM --I TOP OF SAND(11/04/12) PERFORATION SUMMARY REF LOG: BHCS ON 06/26/83 9177' -COLLASPED LNR(01/13/01 VIDEO),PASSED ANGLE AT TOP FERE:28"@ 8960' THRU RESTRICTION w/2.6"BELL GLADE 12/27/06 Note:Refer to Production DB for historical perf data I ? -{FISH-KINLEY CUTTER,OAL 52'(05/29/12) SIZE SPF INTERVAL Cpn/Sqz SHOT SQZ -I ? FISH-SL T-STRNG;FLAT BTM GO-BEVEL 2-1/2' 6 8960-8980 0 11/28/12 &CALIPER CENTRALIZER ARMS (06/26/12) 2-1/2' 5 8968-8978 0 03/06/03 2-7/8' 6 9125-9145 C 11/06/10 ? -j FISH-SL TOOL STRING,OAL 33'(12/21/00) 3-318" 4 9161-9186 S 12/06/94 04/04/00 v.r., vv., 9249' -4C MENTCAP 1 3-1/8" 4 9161-9197 S 03/09/84 04/04/00 ti..►�},.*,.v,-0 3-1/8" 4 9202-9212 S 03/09/84 04/04/00 2-7/8" 4 9202-9212 C 12/12/00 9676' 1-FISH-TB_TRIGGER 3.75 X 1.40"X 40^ I 3-1/8" 4 9215-9235 C 03/09/84 04/04/00 - _ 9581' _--FISH-BP PE BTD -{ 954T / ;•r> ''•C:* 9586' H TD 7"LNR,29#,N-80 BT&C, .0371 bpf,D=6.184" -I 9584' ! {}� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/30/83 RWN 176 IMTIAL COMPLETION 06/06/161JGUJM)GLV C/O(06/02/16) WELL: 14-24 02/16/15 PJC GLV WBS/FINDER CLEANUP 06/06/16 RR VJMD WHIPSTOCK DEPTH CORRECTION PERMIT No:'1830910 01/26/16 RIK/JMD GLV GO(01/13/16) 07/05/16 DW/JM) EDIT®WS DEPTT-VADDED REF&BF EL AFt No: 50-029-20970-00 05/10/16 BLS/JAIL?MLLED CMT SHEATH(05/08/16) SEC 9,T1ON,R14E,1519'F'&&1992'FEL 05/13/16 DLW/JMJ GLV GO(05/10/16) 05/16/16 KFS/JMD SET WHIPSTOCK(05/14/16) BP Exploration(Alaska) • • OF Tk g II/7, THE STATE Alaska Oil and Gas A1,9 I-716 o f e TT Lea1Zc TT �����1Z Conservation Commission ___ AV ft Oh= _ 333 West Seventh Avenue 2'- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g OTM ' Main: 907.279.1433 ALA`3� Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Lead BP Exploration(Alaska), Inc. %A P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-24 Permit to Drill Number: 183-091 Sundry Number: 316-229 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 IS 1 y of April, 2016. RBDMS t," APR 1 8 2016 r "_. i LT 57. 'Co!: STATE OF ALASKA AI ALASKA OIL AND GAS CONSERVATION COMM ION 07-c 4/ t s l /c. IF APPLICATION FOR SUNDRY APPROW.S ' ;; 0 8 2016 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ x , p �a utdown 0 Suspend 0 Perforate El Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill Q - Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 i 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 183-091 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q. 6. API Number 50-029-20970-00-00. 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating. 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PBU 14-24 . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028312 • PRUDHOE BAY,PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓� Plugs(MD): Junk(MD): 9586 • 9203 • 9032 8715 2474 9032(TOC) Unknown,9576,9581 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-111 31-111 1490 470 Surface 2502 13-3/8" 30-2532 30-2532 4930 2670 Intermediate 8947 9-5/8" 27-8974 27-8664 6870 4760 Production Liner 926 7" 8660-9586 8385-9203 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8960-9235 8652-8894 5-1/2", 17#x 4-1/2", 12.6# L-80 25-8706 Packers and SSSV Type: 4-1/2"Baker FHL Packer Packers and SSSV MD(ft)and TVD(ft): 8624/8352 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory 0 Stratigraphic 0 Development Z. Service ❑ 14.Estimated Date for Commencing Operations: April 15,2016 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended Q - 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG o Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Minge,David be deviated from without prior written approval. Email David.Minge@bp.com Printed Name John McMulle Title Engineering Team Lead Signature Phone +1 907 564 4711 Date 4((e//L COMMISSION USE ONLY �l Conditio approval:Notify Commission so that a representative may witness Sundry Number: 31(fl a Plug Integrity 0 BOP Test iY Mechanical Integrity Test ❑ Location Clearance 0 Other: 13OP t fid 35-10 p5)9 /T-nnI,lavpr-ev ±rr' t�5�ID Z✓aOP5 ) �G �L f-Angel--raid -ofl Post Initial Injection MIT Req'd? Yes❑ No [tY'"� �`tf`n fc p 7 121 1 tl�vZ U /�}'C 7i,!- //�O Spacing Exception Required? Yes 0 No P Subsequent Form Required: /I) — 4a 77" 90(.4,_14.,__ __ � / 5,� APPROVED BYTHE / Approved by: geti7 _j0 _ _!/ COMMISSIONER COMMISSION Date: c4_/ //_ yr g`ifl i , r to ORIGINAL RBDMS I,V APR 1 8 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ti>g ...-.Ss 47/3 -/6 o • To: Alaska Oil & Gas Conservation Commission From: David Minge • CTD Engineer h � A,.,_a -7th nnwn LI LC. I-yi I I / , G V I U Re. 14-24 Sundry Approval Sundry approval is requested to plug the 14-24 perforations as part of the drilling and completion of proposed 14-24A coiled tubing sidetrack. History and current status: 14-24 is a Zone 4 producer that was drilled in 1984. A cement channel was discovered down to Zone 3, and in 2000 the entire well was squeezed and selectively re-perfed. Perforations were added in both the Sag and shallower in the Ivishak, which was effective until the well reached marginal GOR in 2012. A Sag frac was completed in 2015 but the well was incapable of sustaining production. There are no remaining well work options to enhance production. Proposed plan: 14-24A will be drilled from well 14-24 by the Nordic 2 Coiled Tubing Drilling rig on or around May 1st, 2016. The 14-24A sidetrack will exit through the existing 7" liner and kick off in the Shublik, and target Sag River reserves. The proposed sidetrack is a -2,300' horizontal Sag River producer, which will access a -60 acre reserves target off of DS14. The lateral will be completed with a 3-1/2"X 3-1/4" X 2-7/8" L-80 liner which will be fully cemented and perforated. This Sundry covers plugging the existing 14-24 perforations via the 14-24A liner cement job or a liner top packer set post rig with slick line if liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. f'odcice7Wye ( r rOdvfc Cn cj (e &h/( /l/f (ic ;,-e// 1 Concur. P rep kr R f q G o k o f i"- � P7(4�4 wi/4 at wares CO- �� eKceff �� 9D% a t>grnt1 c7c,04, -do (�ie/dr� 20 , 0'4 -I'r�l 4,f4 l��Q iCf�I- 1 1,1of er c r to 7l r co"4 b" OF 4'x'71 6°11 417 �1f 1/0/Lr-'6`'T I Gere 1 j l;rile ;f a,,/, Po i��'l,'rj or faCGef /y recoof/et,� �;{ k.e/% (11',9' 1�{ wtll i:' c (.vdr."l reffaerir3 7''IC 6e57 Cr '04 for i%ro✓% g4ve- f off► Thi if 'Orr D'? oc rye pool. 111 • Pre-Rig Work(scheduled to begin April 10th, 2015) 1. C Mill cement sheath. 2. S Drift for whipstock. Run GR/CCL/caliper log. Set generic GLV design. 3. F A/SL: Load well with 1% KCL. Load IA with diesel down to deepest GLV. 4. E Set 4-1/2"x 7" Delta whipstock highside at 9,007' MD. 5. V Pre-CTD tree work (remove S-Riser). Set TWC. 6. 0 Remove wellhouse and level pad. Rig Work(scheduled to begin May 1st, 2016) TLi i 5 1 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,474 psi) 2. Mill 3.80"window and 10' of rathole. Swap well to 8.5 ppg FloPro. 3. Drill build: 4-1/4" OH, 587' (35 deg DLS planned). 4. Drill lateral: 4-1/4" OH, 1,683' (12 deg DLS planned). A -Cw 5. Run 3-1/2"x 3-1/4"X 2-7/8" L-80 liner leaving TOL at—8,400' MD. ?7� 6. Pump primary cement job: 39.3 bbls, 15.8 ppg, TOC at TOL* 7. Contingency second stage cement job. 8. Perform liner lap test to 2,400 psi 9. Perforate liner based on log interpretation (-1200'). 10. Freeze protect well to 2,500' MD. 11. RDMO. Post-Rig Work 1. 0 Re-install wellhouse 2. S Set 45KB liner top packer if needed * *Approved alternate plug placement per 20 AAC 25.112(i) David Minge CTD Engineer 250-2917 CC: Well File Joe Lastufka TREE= 5"FAAC 120 WELLFIEAD= GRAY1 410 1 4-24 ..NOTES: T x IA LEAK AT SSSV NIP*** ACTUATOR= BAKER C1 INITIAL KB Fl F 77! I I 1 BF ELEV = ! 2142' -5-1/2"CAM BAL-0 SSSV NP,IC)=4.562' KOP= 5300' L-CONDUCTOR, ? ____ Max Angle= 29°@ 9000' #, 0 ! Datum MD= 9210', .0-. . , GASP IFT MA NOIRE S Datum TVD= 8800'SSII .1 ST MD ND De/'TYPE VLV LATCH PORT DATE 1 2903 2903 1 CA DMY RK 0 01/13/16 13-3/8'CSG, 72#,L-80 BT&C,Cr 12.347" - 2532' 1 , 2 4817 4817 1 CA DM' RK 0 01/13/16 1 L 3 6215 6139 27 CA DMY RK 0 01/13/16 4 7206 7037 23 CA DMY RK 0 01/13/16 5 7757 75501 21 CA DM' RK 0 08/27/00 9-5/8"CSG,47#,L-80 BT&C X0 TO US-95 BT&C 1-1 813T x 6 7819 7608 21 CA DWI' RK 0 06/30/83 7 8126 7895 21 CA DM' RK 0 12/28/12 FISH-SPRING FROM 1-1/2"RK LATCH(2/13/15) - ? 8** 8197 7961 21 CA DMY RK 0 06/30/83 9' 8462 8205 24 CA CSAY RK 0 06/30/83 Minimum ID =3.626" @ -8622' 10** 8531 82681 25 CA DM( RK 0 06/30/83 TOP OF CEMENT SHEATH "CEMENT IN MA 1..: S- •BLE TO "' , L -8522' --8760 -CENT SHEATH,KILLED TO 3.625" Pr- '.::• b A DMUS)OUT 8525'-8779'(03/2/94) 5-1/2'TBG-PC, 17#,L-80,.0232 bpf,13=4,892" H 8614' : k 8600' H5-1/2"BKR FRASSY 1". .)...,•.": 8614' -5-1/7'X4-1/2'XO,ID=3.958" 1.'1.• ▪ ' . . .. i -Ah- It r 8624' -9-5/8"X 4-1/2"BKR Fit HYD PKR CUT S137(12/14/93) TOP OF 7"LM -I 8660' 8692' -14-1/2"CAMCO DB-6 LANDING NV,ID=3.813" I 8705' -4-1/2"BKR SFEAROLIT SUB . s Ar*t.., ?ell ill 8706' H4-1/2"WLEG,ID=3.958" 4-1/2"TBG-PC, 12.6#,L-80 BT&C, 1-1 8706' ! .0152 bpf,ID=3.958" 1 8685' H BMD TT LOGGED 08/27/83 1 9-5/8'CSG,47#,US-95 BT&C XO TO L-80 BT&C -1 8972' --x I 9-5/8"CSG,47#,L-80 BT&C,ID=8.681" H 8974' A 9032' ELM HIESTIMATE TOC CAP 11/04/12) I PERFORATION SUIMAARYF Ar Ar Ar 47-+ 9059' ELM --ITOP OF SAND(11/04/12) 0,........-41.*.:,`1. REF LOG: BRCS ON 06/26/83 ANGLE AT TOP FERE.28°@ 8960' `.)---e-- , 9177' 1COLLA SPED LNR(01/13/01 VICE-0),PASSED Note:RR- efer to oduction DB for historical perf data THRU RESTRICTION w/2.6"BELL GLACE 12/27/06 SIZE SPF INTERVAL Opn/Sqz Si-OT SQZ =MUM WNW' FISI-i-KINLEY CUTTER,OAL 52'(05/29/12) 2-1/2" 6 8960-8980 0 11/28/12 ii....../A ? H 2-1/2" 5 8968-8978 0 03/06/03 lini:. -- ? -FISH-SL T-STRING-,FLAT BTM GO-DEVIl Il 2-7/8' 6 9125-9145 C 11/06/10 Milt &CA LFER CENTRALIZER ARMS (06/26/12) 3-3/8" 4 9161 -9186 S 12/06/94 04/04/00 I -FISH-SL TOOL STRING,OAL 33'(12/21/00) 3-1/8" 4 9161 -9197 S 03/09/84 04/04/00 3-1/8" 4 9202-9212 S 03/09/84 04/04/00 .. 9249' 1-CEMENT CAP 1 I *•,•4.***..;*.i.-tt4,-.: 2-7/8" 4 9202-9212 C 12/12/00 . . . 3-1/8' 4 9215-9235 C 03/09/84 04/04/00 Mil 9676' 1H-F1SH-Tta TRIGGER 3.75"X 1.40"X 40" 1 i 1 . 9581' iH FISH-IBP Faro H 954T •-‘74,74:', *7' .-...,...r_.-0-.7,,..••••. 7"LNR,23/4,N-80 BT&C, .0371 bpf,ID=6.184" - 9584' --'•-•:‘,;‘7* / 9586' H TD 1 — _ DA IE REV BY COMMENTS 1DATE REV BY COM1NTS PRUDHOE BAY UNIT 06/30/83 RWN 176 IMTIAL COM PLET1ON 04/29/13 LB/PJC PULL Rf3P/SET FRAC SLV(3/25/13) WELL: 14-24 11/29/12 SET/JMD REFERF(11/28/12) 02/10/15 GJB,IPJC PULL FRAC SLV/FISH LEFT CH PERMT No:'1830910 101/06/13 RKT/PJC SET IBP/FULL FRAC SVL(12/28/12)02/14/15 GJB/PJC GLV 00 API No: 50-029-20970-00 101/08/13 PJC CMT SHEATH CORRECTION 02/16/15 PJC GLV WBS/FINDER CLEANUP SEC 9,T1ON,R14E, 1519'FN.&1992'FEL I 1 02/20/13 WV/JAI) TRD() _EE (02/11/13) 01/26/16 RJK/JMD GLV C/0(01/13/16) i 04/29/13 LER PJC GLV C/0(03/21f/13) F3P Exploration(Alaska) 1 TREE='E1LHEAD=_ 1 4 24 ► GRAY P���'" ��� � S�NOTES: T x IA LEAK AT SSSV NIP"• ACTUATOR= REV 2 IJTIAL KB_at 72 BF.aEV= 2142' H 5-1/2"CAM BAL-O SSSV PP,ID=4.562" KOP= __ 5300' _"CONDUCTOR 0 GAS LIFT MANDRELS )1 , , Max Angle= °@-- —# , 5Tl() TVD DEV TYPE VLV LATCH FART DATE Datum MD= 0= 1 12903 2903 1 CA I DRAY RK 0 101/13/16 Datum TVD= 8800'SS + 2 4817 4817 1 CA DAY RK 0 01/13/16 13-3/8"CSG,72#,L-80 BT&C,13=12.347" H 2532' I U 3 6215 6139 27 CA [MY RK 0 01/13/16 4 7206 7037 23 CA DMY RK 0 01/13/16 9-5/8"CSG,47#,L-80 BT&C XO TO US-95 BT&C —1 8137' X 5 7757 7550 21 CA DAY RK 0 08!27/00 6 7819 7608 21 CA ❑MY RK 0 06/30/83 7 8126 7895 21 CA DMY RK 0 12/28/12 Minimum ID = as ,a 8" 8197 7961 21 CA CMY RK 0 06/30/83 9" 8462 8205 24 CA ow RK 0 06/30/83 10" 8531 8268 25 CA [MY RK 0 06/30/83 **CEMENT IN MANDRELS-1MABLE TO PULL TOP OF LNR --I 00° 8400' —13.70"DEPLOY SLV,ID=3.00" i —8522'-—8760±1 CEMENT SHEATH,MLLED TO 3.625" 5-1/2"113G-PC, 17#,L-80,.0232 bpf,D '=4.892" — 8614' 4. DRILLED OUT 8525'-8779'(038194) 1! ►► MLLED TO 3.80"PRE-RIG r 8600' H5-1/2"BKR FBRASSY 1- � Ale8614' H5-1/2"X4-1/2'XO,ID=3.958' �� 8624'J-j 9-5/8"X 4-1/2"BKR FHL HYD PKR :› TOP OF 7"LNR —I 8660' r��*T CMT SQZ(1u11193) l 8692' _HI4-1/7 CAMCO DB-6 LAM k3 NP,D=3.813" IF KA plr 4-1/2"TBG-PC, 12.6#,L-80 BT&C, —1 8706' 8705' 1-14-1/2"BKR SHEAROUT Sl83 0152 bpf,13=3.958' 8706' —14-1/2"'LEG,D=3.958" 3-1/2"LNR, #,L-80 STL,.0087 bpf,ID=2.992" H $940° 8685° H ELMO TT LOGGED 08/27/83 8940' H3-1/2"X 3-3/16"XO,D= 9-5/8'CSG,47#,US-95 BT&C XO TO L-80 BT&C —1 8972' �X I X 9-5/8"CSG,47#,L-80 BT&C,13=8.681" 8974' 1 , , 1 4-112'X 7"DELTA WHPSTOCK(XX/XX/XX) —19007° 7"MLLOUT WINDOW(14-24A)9007'- 117"LtYR 294,N-80 B T&C, ii "' 7' I .0371 bpf,ID=6.184" 3-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,13=2.85" — 10050' 1 -------- 10050'10050' H 3-3/16"X 2-718"XO,ID=2.377" PERFORATION SUMMARY FEE LOG: BRCS ON 06/26/83 ANGLE AT TOP FERF:28°@ 8960' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SEDT SQZ 2-1/2" 6 8960-8980 0 11/28/12 2-1/2" 5 8968-8978 0 03/06/03 FBTD 1 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,1D=2.441' 11276' 4 DATE REV BY COI? TS DATE REV BY COIMAENTS PRUDHDE BAY UNIT 06/30/83 R]IVN 176 IMTIAL COMPLETION WELL: 14-24A _/ 1 CTD SIDETRACK(14-24A) _ FERMI No: 02/17/16 ,)IIID BUILT PROPOSAL API No: 50-029-20970-01 02/18/16 I)M3A13 RROPOSAL REV 2 SEC 9,T1ON,R14E,1519'FPL&1992'FEL BP Exploration(Alaska) r • . 1 1 1 kl 1 a 41 I I rc % 1 �< $ 31 U : I 1 F 2 f , ti"..',„,/../:774, iii d t I I } !,-- ; '. I I > rc 1 U_ ,, I E 0 ,4';'/1 I Ce v D a o I I Cli Y �', S I LL i O J� I Q— • I INNI.. X11 I i Z I 1 O o x d 1 I � i I-• A U I , fill a1 I 8 ivy Eisti i' I \\ ft r. v 1 a w I W a = F wr . �i p I Y .�, d g u o r r- 2 U i O 5 " g 1 1 U '4 o m 1 ` F. i c4 s _ x x —x U i \ o' * • :II: :.: 1 -5,4 \ . ilmir I s .. § 1 of j 4 f .. a ._ ,TI I— ,..! / , - m ,1 .T. ,, . . . ` % 1 0 ,I 1 Z ¢ Tei — _ 1 i s .i v t I f I • . �P. APh A, MI" "i z 1 Ia P. I z3 I LLe g I �' e ; il ✓ 1 V6 .1 e I _ Uu I = x I� .. ., • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or v "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then / it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, April 12, 2016 2:12 PM To: 'Catron, Garry R (Wipro)' Cc: 'Schultz, Kirsten L'; 'Lastufka,Joseph N'; 'Minge, David'; Guhl Meredith D (DOA); Bender, Makana K (DOA); Colombie,Jody J (DOA); Carlisle, Samantha J (DOA) Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing All, Every application or report received by the AOGCC is logged in at our front desk. None of AOGCC's staff has record of this particular Sundry Report. So, although the information was typed into FracFocus, apparently the Sundry Report for the PBU 14-24 hydraulic fracturing operations was not submitted to the AOGCC. The pdf-format files provided by Gary Catron will be printed and placed into AOGCC's well history file, and the pdfs will be placed in the AOGCC's electronic files. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, April 12, 2016 10:26 AM To: 'Catron, Garry R (Wipro)' Cc: Schultz, Kirsten L; Lastufka, Joseph N; Minge, David Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Thank you Gary. I rechecked, and I still can't find any record of AOGCC having received this Sundry Report. It's not listed in our front-desk log of received Sundry Reports and it's not in the well history file for PBU 14-24. I'll keep looking to find where the gap occurred. Thanks again for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 1 • Phone: 907-793-1224 ADGCC: 907-2794433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Catron, Garry R(Wipro) [maiito:Garry.Catron@bp.com] Sent: Tuesday, April 12, 2016 8:34 AM To: Davies, Stephen F (DOA) Cc: Schultz, Kirsten L; Lastufka, Joseph N; Minge, David Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Steve, Attached please find the 10-404 BP submitted to the AOGCC on March 23, 2015 along with the Frac Focus submission. If I can be of further assistance, please don't hesitate to contact me. Regards, Garry Catron PDC PE 907-564-4424 From: Lastufka, Joseph N Sent: Tuesday, April 12, 2016 8:12 AM To: Minge, David Cc: Catron, Garry R (Wipro); Schultz, Kirsten L Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Garry, Was a frac completed and 10-404 submitted? Thanks, Joe From: Minge, David Sent: Monday, April 11, 2016 8:27 PM To: Schultz, Kirsten L; Lastufka, Joseph N Subject: Fwd: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Kirsty, 2 • • D'o you know anything about this? Joe, is this your realm? David Sent from my iPhone Begin forwarded message: From: "Davies, Stephen F (DOA)" <steve.davies@alaska.gov> Date:April 11, 2016 at 5:04:36 PM AKDT To: "David.minge@bp.com" <David.minge@bp.com> Cc: "Loepp, Victoria T(DOA)" <victoria.loepp@alaska.gov>, "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Subject: PBU 14-24(PTD No. 183-091)-Question Regarding Hydraulic Fracturing David, While reviewing BP's Sundry Application to plug PBU 14-24 for a planned redrill, I noticed this sentence in the section titled "History and Current Status": "A Sag Frac was completed in 2015 but the well was incapable of sustaining production." AOGCC's database records an approved Sundry Application (Sundry No. 315-037)to fracture stimulate the Sag River interval within the well, but I do not see any record of a follow-up Sundry Report detailing the results of that fracturing operation. Could you please provide an update on the status of this well? Was PBU 14-24 fracture stimulated? If so, could you please provide the corresponding Sundry Report? If fractured, was information entered into the FracFocus Chemical Disclosure Registry as required by Sundry No. 315-037? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 3 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday,April 11, 2016 5:05 PM To: David.minge@bp.com Cc: Loepp,Victoria T(DOA);Wallace, Chris D (DOA) Subject: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing David, While reviewing BP's Sundry Application to plug PBU 14-24 for a planned redrill, I noticed this sentence in the section titled "History and Current Status": "A Sag Frac was completed in 2015 but the well was incapable of sustaining production." AOGCC's database records an approved Sundry Application (Sundry No. 315-037)to fracture stimulate the Sag River interval within the well, but I do not see any record of a follow-up Sundry Report detailing the results of that fracturing operation. Could you please provide an update on the status of this well? Was PBU 14-24 fracture stimulated? If so, could you please provide the corresponding Sundry Report? If fractured,was information entered into the FracFocus Chemical Disclosure Registry as required by Sundry No. 315-037? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 1 ® r lg3- 9/ Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday,April 12, 2016 2:12 PM To: 'Catron, Garry R(Wipro)' Cc: 'Schultz, Kirsten L'; 'Lastufka,Joseph N'; 'Minge, David'; Guhl, Meredith D(DOA); Bender, Makana K(DOA); Colombie,Jody J (DOA); Carlisle, Samantha J (DOA) Subject: RE: PBU 14-24(PTD No. 183-091) - Question Regarding Hydraulic Fracturing All, Every application or report received by the AOGCC is logged in at our front desk. None of AOGCC's staff has record of this particular Sundry Report. So, although the information was typed into FracFocus,apparently the Sundry Report for the PBU 14-24 hydraulic fracturing operations was not submitted to the AOGCC. The pdf-format files provided by Gary Catron will be printed and placed into AOGCC's well history file, and the pdfs will be placed in the AOGCC's electronic files. Thank you for your help. Regards, Steve Davies _._ _..___� �....._... Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-7934224 AOGCC: 907-2794433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 4 ' + p� ` , Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving.or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska,gov. From: Davies, Stephen F (DOA) Sent: Tuesday, April 12, 2016 10:26 AM To: 'Catron, Garry R(Wipro)' Cc: Schultz, Kirsten L; Lastufka, Joseph N; Minge, David Subject: RE: PBU 14-24 (PTD No. 183-091) -Question Regarding Hydraulic Fracturing Thank you Gary. I rechecked, and I still can't find any record of AOGCC having received this Sundry Report. It's not listed in our front-desk log of received Sundry Reports and it's not in the well history file for PBU 14-24. I'll keep looking to find where the gap occurred. Thanks again for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 1 • S Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Catron, Garry R (Wipro) [mailto:Garry.Catron@bp.com] Sent: Tuesday, April 12, 2016 8:34 AM To: Davies, Stephen F (DOA) Cc: Schultz, Kirsten L; Lastufka,Joseph N; Minge, David Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Steve, Attached please find the 10-404 BP submitted to the AOGCC on March 23, 2015 along with the Frac Focus submission. If I can be of further assistance, please don't hesitate to contact me. Regards, Garry Catron PDC PE 907-564-4424 From: Lastufka,Joseph N Sent: Tuesday, April 12, 2016 8:12 AM To: Minge, David Cc: Catron, Garry R (Wipro); Schultz, Kirsten L Subject: RE: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Garry, Was a frac completed and 10-404 submitted? Thanks, Joe From: Minge, David Sent: Monday, April 11, 2016 8:27 PM To: Schultz, Kirsten L; Lastufka, Joseph N Subject: Fwd: PBU 14-24 (PTD No. 183-091) - Question Regarding Hydraulic Fracturing Kirsty, 2 a S Do you know anything about this? Joe, is this your realm? David Sent from my iPhone Begin forwarded message: From: "Davies, Stephen F (DOA)" <steve.davies@alaska.gov> Date:April 11, 2016 at 5:04:36 PM AKDT To: "David.minge@bp.com" <David.minge@bp.com> Cc: "Loepp,Victoria T(DOA)" <victoria.loepp@alaska.gov>, "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Subject: PBU 14-24(PTD No. 183-091)-Question Regarding Hydraulic Fracturing David, While reviewing BP's Sundry Application to plug PBU 14-24 for a planned redrill, I noticed this sentence in the section titled "History and Current Status": "A Sag Frac was completed in 2015 but the well was incapable of sustaining production." AOGCC's database records an approved Sundry Application (Sundry No. 315-037)to fracture stimulate the Sag River interval within the well, but I do not see any record of a follow-up Sundry Report detailing the results of that fracturing operation. Could you please provide an update on the status of this well? Was PBU 14-24 fracture stimulated? If so, could you please provide the corresponding Sundry Report? If fractured, was information entered into the FracFocus Chemical Disclosure Registry as required by Sundry No. 315-037? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 3 • 0 N._V), a) E E ;r o :- 0 0.6 r- C CO CO CT) � N- O CO M LC) CO Cl3 V X,,,, C ON) (NI 00(C) M C)N- N O CO M CO O E C p � o M N O o o O 0 0 0 0 = a) 4 cif o 0 o co 0 0 . . . E � :' L_ E N MI i:5 * Cp O M OD N m M CO O > I C O (C O CO M O N N Cb 144 iE C O o ' N In to V ,- .- O O O Co) = -a) - > Ry 0 ,- 0 0 0 0 0 0 0 0 c6 rn tq 0 E � �' E CI V a' � Q � O Z.", * t) ++ IA S U 0 a) k co -0 , r- L a) O Q 0 O N O 0 N (9 0 la -C Et5-"Z U CO M e. 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O ( Ox , aO o N TO ❑ c ( .0 15 NO = C X _ -O O M U L N •N O L U ' d- ON c O a) L Uo o Or 6 C0O� Ep Ch - O N..(- >c> dmma ) . °mE a082Nwq n a(.I q q N (n E . (6'.c x� c .y E ° c.- ' a)c >` . OTN , C O _ >- O O '6. N I c CLO O O Q O EO • O Up O N O co EO O ' EOOLO d N-o L p N p N 2O J J U > O UV) i5 U z ❑ Cn E.)Lr) u> N O. 2 N CO LL U LL a O_.()M R_N a)_c S!) O U) - cco N O _ - Q( O LL c ❑0- -O O LL O U LN N o• 0 �c) •c O CNO O — N ce 3 0 LL �U L,C6 N N N j2N O oa aa a0 j � U (/) 0 E U N T X ..3 O E• a E O U .� 0_c c c 0 U 3 C • N O O C E m > D2 a) O • N C3 E C a)w a) O C C00• 11-.- • E c d'-.) N N 2 F C O co + Z= STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well LJ Performed: Alter Casing ❑ Pull Tubing❑ Change Approved Program ❑ Operat. Shutdown❑ Plug Perforations U Stimulate - Frac Q Stimulate - Other ❑ Perforate Other Waiver ❑ Time Extension❑ Re-enter Suspended Well❑ 371752' l�YI�11�1I�'�1��1��11�iIlI�IGf 2, Operator 4 Well Class Before Work: 5 Permit to Drill Number: Name: BP Exploration (Alaska), Inc Develo mert Ex p ❑ Exploratory ry ❑ Stratigraphic❑ Service ❑ 183-091-0 3 Address: P O Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20970-00-00 7 Property Designation (Lease Number): 8. Well Name and Number: ADL0028312 PBU 14-24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: Total Depth measured 9586 feet Plugs measured 9032 feet true vertical 9202,87 feet Junk measured See Attachment feet Effective Depth measured 9032 feet Packer measured 862383 feet true vertical 8715 11 feet true vertical 835222 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91 5# H-40 305-110.5 30-110 1490 470 Surface 2501.68 13-3/8" 72# L-80 30-2531,68 28-8090.11 4930 2670 Intermediate 894677 9-5/8" 47# L-80 27 25 - 8974.02 8092 23 - 8845 51 6870 4760 Production None None None None None None Liner 926.36 7" 29# N-80 8660 - 9586 36 8626 32 - 9076.06 8160 7020 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker FHL Packer 8623.83 835222 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8960'- 8980' Treatment descriptions including volumes used and final pressure: 70269.2 GALS J957 YF 100FLEXD CONVERSION, 84 GALS F103 SURFACTANT, EZEFLO, 165 GALS L64 CLAY STABILIZER, 82 GALS L65 SCALE INHIBITOR, 70 GALS B882 GUAR POLYMER, 3 GALS D206 ANTI FOAMING AGENT, 131400 LBS S018 SAND, 2235 LBS J580 GELLING AGENT, 275 LBS J569 BREAKER, EB - CLEAN MT, 18 LBS J134 ENZYME BREAKER, 36 LBS M275 MICROBIOCIDE, 44 LBS J218 LIVE BREAKER, 77.683 16/30 PROPANT 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 251 17034 3237 0 813 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 1'/1 Gas Ll WI)SPLLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. 1 hereby certify That the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA If C.O. Exempt: 315-037 Contact Nita Summerhays Email NIta.Summerha s b .Com Printed Name Nita mmerh Title Petrotechnical Data Engineer Signatu Phone 564-4035 Date 3/23/2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028312 WrEE 971 13N MR17AL "' rac urmg TAGGED T.T. @ 8,677' SLM/ 8,706' MD (+8' correction elmd). DRIFTED W/ 10' x 3.70" DUMMY WHIPSTOCK TO 8,656' SLM. SET 4-1/2" EVO TRIEVE AT 8,656' SLM (8,685' MD) (ser# p103972180-3) DRIFT TREE W/ 4.8595" SWAGE (s/d tubing hanger) DRIFT TREE W/ 4.751" CENT (s/d tubing hanger) DRIFT TREE W/ 4.66" CENT (pass tubing hanger) 1/19/2015 *'* CONT ON 1/20/15 WSR *** VVELL 5 rac urmg) TAGGED T.T. @ 8,677' SLM/ 8,706' MD (+8' correction elmd). DRIFTED W/ 10' x 3.70" DUMMY WHIPSTOCK TO 8,656' SLM. SET 4-1/2" EVO TRIEVE AT 8,656' SLM (8,685' MD) (ser# pl03972180-3) DRIFT TREE W/ 4.8595" SWAGE (s/d tubing hanger) DRIFT TREE W/ 4.751" CENT (s/d tubing hanger) DRIFT TREE W/ 4.66" CENT (pass tubing hanger) 1/19/2015 *** CONT ON 1/20/15 WSR *** 1/19/2015 Assist Slickline with Continued on 01-20-15— - -***WSR ***WSRContinued from 01-19-15*** T/I/O= 11/80/4. Temp= S/I. Assist Slickline (Pre-Frac.) MIT -T 4400 psi ***PASSED***, MIT -IA 4000 psi ***PASSED*** Pumped 14bbls amb. Diesel down TBG to reach MIT -T pressure of 4400 psi. 1 st 15 min TBG loss 72 psi, 2nd 15 mn TBG loss 36 ps, total loss of 108 psi for 30 min test. Pumped 8 bbis amb Diesel down IA to reach MIT -IA pressure of 4000 psi. 1st 15 min IA lost 91 psi, 2nd 15 min IA lost 31 psi for a total loss of 122 psi in 30 min test. Bled -8 bbis back to achieve IA pressure of 300 PSI. Tags hung, Slick -Line on well upon departure. Fluid 1/20/2015 packed annulus sign hung on MV. FWHP= 1000/300/0. IA/OA= OTG rac urmg LRS PERFORMED PASSING MIT -T. (see Irs log) LRS PERFORMED PASSING MIT -IA. (see Irs PULLED 4-1/2" EVO TRIEVE FROM 8,649' SLM. 1/20/2015 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 1/25/2015 ea rac anKs to —Job continued on 1-26-15 WSR*** - - 1/26/2015 1/26/2015 ...Job continued trom 1-25-15 Continue to heat rac tans to 1/26/2015 Heat Frac anks tor 3LB Frac. SB for snow removal o exit pa . Assist Frac Crew, Heat LVT 2UO MineralI ranspo o 9011 and frac tanks to 1/29/2015 continued to 1-30-15*** 5 con roue rom 1-29-19— (AssistFrac) on roue Fo —roll and heatfrac tanks. Job Cancelled 1/30/2015 due to weather (Assist Frac) Ensure Frac tanks are and M-200 transportare continued o 2-2- - -2/1/2015 2/1/2015 15*** continued from 2-1-15"* = ssvTemp = f Frac). Pumped 14 bbls Diesell down IA to load and to maintain 2500-2600 psi on IA during Frac operations. Frac crew in controle notified DSO upon departure. AFE sign hung on master and fluid packed caution tags hung o IA and wing.. Fluid packed IA also stated on the permit. FWHP = SSV/506/0 SV/WV/SSV/MV = Frac 2/2/2015 IA/OA = OTG Daily Report of Well Operations ADL0028312 SLB Fracture Treatment Job Scope: Fracture Treatment Targeting Sag Sands. InterAct Publishing. Rig up frac equipment, LRS and Stinger tree saver. Pump injection test with linear WF127FIexD, Scour Stage @ 40 bpm w/ 1 ppa. Hard shut down, ISIP = 2097 psi. Pump Frac at 40 bpm using YF125FIexD (x -link) system. 1 ppa flat stage. Ramp 1-8 ppa. Sand chief down at 6.7 ppa cont. Call overFlush. Underdisplace by 5 bbls. Pumped 41,370# 16/30 sand. Perform re-frac. Lead w/ YF127FIexD Pad at 40 bpm. 1 ppa 16/30 flat stage. 1-8 ppa ramp. Flush. Underdisplace by 12 bbls. Total of 77,683# 16/30 sand pumped, 72, 834# in formation, 4849# left in wellbore. Total sand from both stages 119,053#. Posttreatment ISIP 3007 psi. Net pressure gain 3007 -2097 = 910 psi. Left well w/ 12 bbls X -Link w/ proppant, 92 bbls X -Link clean, 2/2/2015 87 bbls linear gel, 19 bbls LVT FP. ***Job Complete*** CTU#6 1.75" CT (CV= 31.2 bbls) Objective: FCO post Frac, Perform weekly BOP Test. MU 2.75" BDN for reverse FCO and RIH. Circulate mineral and frac gel OOH w/ slick 1 % KCI. Dry drift down and tag frac sand at 8774'. Begin reverse FCO. 2/5/2015 ***In Progress*** CTU#6 1.75" CT (CV= 31.2 bbls) Objective: FCO post Frac, Begin reverse FCO from 8774' down to 8806'. Unable to reverse out past 8806' at 2bpm, stacking 8k down multiple times. Perform conventional FCO w/ gel from 8806' down to 8930', 1:1 returns. PUH to 8500' and circulate BU. Dry drift down to 8921'. PUH and perform reverse FCO down to 8940', getting 60% returns. POOH. FP well with 58bbls of 60/40 methanol. 2/6/2015 ***Job Complete*** 17173=4019, Temp=Sl, AssistTemp= s is ine With pulling valves main am tbg pressure continued 2/10/2015 on 2-11-15*** (fracturing) TAGGED 5 1/2" FRAC SLEEVE W/ 4.63" GUAGE RING @ 2,121' SLM (2,143' MD) PULLED 5-1/2" FRAC SLEEVE FROM SSSV NIP @ 2,121' SLM (2,143' MD) (no issues) TAGGED TOC @ 8,901' SLM W/ 2.5" SAMPLE BAILER, 3" CENT (recovered 1tbs sand) LOCATED TT @ 8,675' SLM (+10' corrected to ELMD, —49' fill) RAN 5'2.25 DRIVE DOWN BAILER TO 8,901' SLM (recovered --2 cups sticky sand) SET SLIP STOP CATCHER SUB @ 8,579' SLM MADE 2ATTEMPTS TO PULL STA#4 @ 7,206' MD (unsuccessful) 2/10/2015 ***CONT WSR ON 2/11/15*** continued from 2-10-2515 * Assist s is ine with pulring valves (maintain tbg pressure 2/11/2015 Pumped 35.5 bbls of crude down the tbg to hold 300 psi for slickline to pull valves. rat urmg RAN 1.70" LIB TO STA#4 @ 7,206' MD (impression of latch) PULLED RK-DGLV FROM STA#4 @ 7,206' MD MADE 3 UNSUCCESSFUL ATTEMPTS TO PULL STA#3 @ 6,215' MD PULLED RK-DGLV FROM STA#2 @ 4,817' MD 2/11/2015 ***CONT WSR ON 2/12/15*** i VVSR r _ (racturing) PULLED RK-DGLV FROM STA#1 @ 2,903' MD MADE 2 ATTEMPTS TO PULL STA#3 FROM 6,215 MD RAN 1.75 LIB TO ST#3@ 6,215' MD (impression of latch) MADE 2 ATTEMPTS TO PULL ST#3 @ 6,215' MD W/ 1-5/8" JDS MADE 3 ATTEMPTS TO PULL ST#3 @ 6,215' MD W/ 1-5/8" DANIELS RAN 1.80" SAW TOOTH GAUGE RING TO ST#3, ATTEMPT TO CLEAN F/N 2/12/2015 ***GO ON WEATHER TICKET*** ***VVSR continued from 2-1`1-20`15 Assist slit me with pulling valves (maintain tbg pressure Rig down. FWHP=50/67/18 2/12/2015 Slickline still on well upon departure. Daily Report of Well Operations ADL0028312 (fracturing) MADE TWO UNSUCCESSFUL ATTEMPTS TO PULL ST #3 W/ 1 5/8" DANIELS BRUSHED STA#3 @ 6,215' MD W/ 5 1/2 " BRUSH, 4.0" GAUGE RING PLANTED 1.80" NON RELEASABLE OVER SHOT @ 6,200' SLM JARRED FOR 1 HOUR (recovered fishing neck and core) RATTLED ALL MANDRELS W/ 5 1/2" BRUSH, 3" GAUGE RING DOWN TO CATCHER SUB @ 8,578' SLM (no issues) RAN 4.5" LIB TO SLIP STOP CATCHER SUB @ 8,578' SLM (impression of latch body) 2/13/2015 ***CONT WSR ON 2/14/15*** ***CONT WSR FROM 2/13/15*** (fracturing) PULLED RK-DGLV FROM SS CATCHER @ 8,580' SLM (still missing wobble ring and spring) SET RK-LGLV (1693psi, 16/64"ports) IN STA#1 @ 2,903' MD SET RK-LGLV (1673psi,16/64"ports) IN ST#2 @ 4,817' MD SET RK-LGLV (1647psi,16/64"ports) IN ST#3 @ 6,215' MD SET RK-DGLV (24/64" ports) IN ST#4 @ 7,206' MD PULLED 5 1/2" SLIP STOP CATCHER SUB FROM 8,584' SLM (recovered wobble ring) ****RK LATCH SPRING STILL INHOLE****** 2/14/2015 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** TiIIO= 88015007250 Temp=(Freeze protect T9G & FL on well 14-23 tor Well testers r ow back on well 14-24) Pump 5 bbl Neat spear down Flowline. followed by 81 bbis Crude, and 5 bbl Neat tail to pressure up Flowline to 1500 psi per DSO. Pump 38 bbis Crude down TBG. Hang FP tags, notify DSO. SV,WV,SSV, ALV= Closed MV=Open IA/OA=OTG FWHP = 109/500/200 2/18/2015 Well shut in upon departure. Test Unit Inlet - u let - on -nue on WSK 2/20/2015 2/21/2015 AMC Test Unit net 14-24 Outlet 14- ow Well 2/21/2015 Continued on WSR 2/22/2015 ASKU - est Unitinlet - u et 14-23 WSR 2122120 15. **Flow Well, 51 for , 2/22/2015 iPOP/Flow Well *** Continued on WSR 2/23/2015 est Unit. Inlet 14-24Outlet - continue from ow Well 2/23/2015 Continued on WSR 2/24/2015 ASRC Test n- Inlet - utlet 14-23 Continue from owa es , 2/24/2015 RD ***Continue on WSR 2/25/2015 DIM =1 9.3 i - emp.= ) Assist well testers by treeze protecting14-24 TBG & 14-23 FL. Pumped 2 bbis meth spear followed by 59 bbis crude tailed with 2 bbis meth down 14-24 TBG. FWHP = 2110/1967/0 SV,SSV,WV=Closed MV= Open IA,OA = Open to gauge FP tag hung on WV. 14-23 T/I/O= 1440/440/140 Pumped 2 bbis meth followed by 80 bbls of 90* crude tailed by 2 bbls meth down FL to freeze protect FL pressure up to 1041 psi per DSO. FP tubing with 2 meth, 58 crude, and 2 meth. FWHP = 880/440/140. SV,SSV,WV=Closed MV= Open IA,OA = 2/25/2015 Open to gauge FP tag hung on WV. 2/25/2015 ASRC Test Unit #1. Inlet 14-24, Outlet 14-23. Continue from WSR 2/24/15. ***RD*** End Job*** FLUIDS PUMPED BELS 170 60/40 METH 25 12% HCL ACID 675 SLICK 1% KCL 31 POWERVIS 376.5 CRUDE 22 METH 40.5 DIESEL Daily Report of Well Operations ADL0028312 1340 TOTAL FLUIDS PUMPED GALS 70269.2 J957 YF 100FLEXD CONVERSION 84 F103 SURFACTANT, EZEFLO 165 L64 CLAY STABILIZER 82 L65 SCALE INHIBITOR 70 B882 GUAR POLYMER 3 D206 ANTI FOAMING AGENT 70673.2 TOTAL ILBS FLUIDS PUMPED 131400 i 5018 SAND 2235 J580 GELLING AGENT 275 J569 BREAKER, EB -CLEAN MT 18 J134 ENZYME BREAKER 36 M275 MICROBIOCIDE 44 J218 LIVE BREAKER 77.683 16/30 PROPANT 134085.683 'TOTAL ❑ d N W i0 CO O fD N O ti (O O 00 00 I� (7S ❑ O w O O M LO M w H0 0 LO CO M � Mqt Lo (O I*- MM U U W O (O (O (O O w 00 O 00 w w 00 Z 0 <<moomwa 0 CO 00 00 00 00 00 00 00 00 w m zp 1 w Q 2 2 2 a O (n (n (n J (n cn CL 0 H LO 00 1- O a ti 00 N - CO (O w 00 00 (O O P- N O P- 00 N O 9. - d Lo o0 r- to (O (O O 00 N' O) M 00 O Lo qq O (O r- ►) o0 ❑ (O (O (O I-- ao m w w w w 00 m m m r 00 00 O Lo M M (O f-- N (() U) 4 (O f� M qq t- M M M N M = d O) ❑ m O) M m m m m m r O m N m N m N m W m E d N C Mco Q C4 a 0 O CoramWLo ~ mmmNU-)0 }r Q 00a000000000)OO m N O d a O LLLLLL(ncn(ncn(nW0W �a�aa�aaaaaa 0<<<mmmmmmmm CL O r- 0) CL N N N N N N N N N N N ❑ p 0 C I C N N N 0 0 0 0 0 O O O I O = 00 00 00 FIT m E ca z L v N v N N v (V v N N v N v (V N 14- N N mvst�v'�vv��vv c � ❑ W O 2 w ❑ ❑ ❑ w m z w w H0 a ❑ LLJ g g Y L) O U U W o' W J J J Q Q (/i W U U U -j W w O Z 0 <<moomwa 2 2 x z❑❑ W 0 r- 0 w w zp zQ w Q 2 2 2 a O (n (n (n J (n cn 2 O w 0 w 0 0 ❑ LU D vi F- w O U =O J Q ❑ ❑ W LL (L d Q W W W W W J w W Ix a O C7 U W W IL W ❑ ❑ 0 w� d a w w Q m m LL LL cn (n a W J Q m m Ui LL w w 0w.. w I a� N C It It � N NO (DCV O U � O� (O M qq M m (O 00 r- 00 LO (O O N 00 N CY) Lr) Iq (O t` O O U.) O 0) 00 00 O 0) It 00 ti N O 00 N M O nj (p 00 M CO M 07 N N N N O 00 (O 00 a) �+ O r- (O 00 M O LO 0) N 0000 LO N 000 0 00 0 V CN 0) l(•) }moi Q r O M P_ N 0 CO M M N O N 000 000 N C O (D O a Z a Q0 ��g, CD (n cl)co z C)0 loo 0000°1 C 2 •N d Z O, p0l'04 N Lo (O U 4 N 0') � - U O)�N 0 CU C-4 N O j� U () C? r N Cn N Lo 4 U CV— N co 00 M 'IT CM C 0c0 (O rnNcfl (O 'It I � C) LO r- Lf) d J 00 N 00 � Q - = 0 Q W Nps WW C) (D Z W Z d d U -ZZ W m m 1U O 5 U Z ::i z z 0 14-24 183-091-0 Junk Attachment SW Name MD Date Description 14-24 9180 36881 SL Tool String, OAL 33' 14-24 9180 5/29/2012 0:00 Kinlej Cutter 14-24 9180 6/25/2012 0:00 Go Devil, OAL 55' 14-24 9576 35600 TEL Trigger 14-24 95811 34422 IBP TREE = 5" FMC 120 WELLHEAD= GRAY ACTUATOR = BAKER C', NWAL KB_ ELE 77 BF. ELEV = 6 KOP = 530V Max Angle = 29" @ 9000' Datum MD = 9210' Datum TVD = 8800' SS 14-24 SAFETY NOTES: T x IA LEAK AT SSSV NIP " 'T�I. S- i!?" C -A FA RA I -n C ---w rip 6] = d - 575- �li■III� 13-3/8" CSG, 72#, L-80 BTBC, D = 12.347" 2532' 9-5/8" CSG, 47#, L-80 XO TO US -95 BT&C813T FISH - SPRING FROM 1-1/2" RK LATCH (2/13/15) Minimum ID = 3.626" @ -8622' TOP OF CEMENT SHEATH 5-1/2" TBG -PC, 17#, L-80_0232 bpf, D = 4.892" 8614' TOP OF 7" LNR I--{ 8660' 14-1/2- TBG -PC, 12.611, N-80,.0152 bpf, D = 3.958" J--� 8706- 9-5/8- CSG, 47#, LJS-95 XO TO L-80 BT&C 8972' 9 &W CSG, 47#, L-80 BT&C� D = 8.681" 8974' PERFORATION SUMMARY RE= LOG: BFICS ON 06/26/83 ANGLE AT TOP PERF: 2B" Q 896(Y Nota: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgx SHOT SOZ 2-1/2" 6 8960 - 8980 O 11/28/12 2903 2-1/2" 5 8968-8978 O 03/06/03 02J14115 2-7/8' 6 9125-9145 C 11/06/10 CA DOME 3-30' 4 9161-9186 S 12/06/94 04/04/00 3-1/8" 4 9161-9197 S 03/09/84 04/04/00 3-1/8" 4 9202-9212 S 03/09/84 04104!00 2-7/8" 4 9202-9212 C 12/12/00 5 3-11W 4 9215-9235 C 03/09/84 04/04/00 9647 7" LNR, 29#, 14-80 BT&C, .0371 bpf, D = 6.184" ' le -5-3 F2 1:[l -:N9 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2903 2903 1 CA DOME RK 16 02J14115 2 .4817 4817 1 CA DOME RK 16 02114115 3 6215 6139 27 CA DOME RK 16 02/14115 4 7206 7037 23 CA SO RK 24 0214115 5 7757 7550 21 CA DMY RK 0 08127!00 6 7819 7608 21 CA DMY RK 0 06/30/83 7 8126 7895 21 CA DMY RK 0 12/28/12 8197 7961 21 CA DMY RK 0 06/30183 8462 8205 24 CA DMY RK 0 06130183 10" 8531 8268 25 1 CA DMY I RK 0 06130183 —CEME M IN MANGIRELS - 11NABLETO PILL ^8522' - 8760' CBff3 iT SHEATH, MLL® TO 3.625" ORiLLED OUT 8625' - 8779' (0312184) 86Q0' S-1l2"BKRPBRASSY 8614' 5-112" X 4-112" XO, D =3.958" 8624' 9.518" X 4-112" BKR FHL PKR CMT SGZ(1?114l93) 8692' 4-1/2" CAMCO D13-6 LANDING NP, D = 3.813" 8705' 4-112" BKR SHFAROIJT SIJB 8706' 4-1/2" VVLEG, D = 3.956" 8686' �l3MD Ti LOGG®08127/83 9032' ELM -1 ESTIMATE TOG CAP 11/04/12) 9059' ELM TOP OF SAND (11/04/12) 91�ICOLLASPEDLNR(01/13/01 VOW), PASSED THRU RESTRICTION w /2.6" BELL GLADE 12127/06 FISH- KINLEY CUTTER; OAL 52' (05129112) FISH- SL T STRING; FLAT BTM GO- DEV EL & CALFER CBYfRALIZERARMS (06/26112) FISH- Sl- TOOL STRING, OAL 33' (12/21/00) 8� CB�VT CAP --} 9676' -1 FISH - TIi TRIGGER 3.75" X 1.40" X 40' 968 FISH- BP ��Ci17 DATE REV BY COMMBYTS DATE REV BY COMMENTS 06/30/83 IRWN 170 INITIAL COMPLETION 04129113 LEFT PJC PULL RBP1 SET FRAC SLV (3/25113) 11/29/12 SET/.HAD REPERF (11128112) 02110/15 GJB/PJC PULL FRAC SLVI FISH LEFT DH 01/06/13 IRKT/ PJC SET IBR' RAL FRAC SVL (12128112),02/14115 GJBIPJC GLV C/O 01/08/13 PJC CMT SHEATH CORF43MM 02/16/15 PJC GLV VVBS/ FINDER CLEANUP 02/20/13 MW/JMD TREE C10 (02111/13) 04/29/13 LE=/ PJCj GLV CJO (03124113) PRI DHOE BAY UW WELL: 14-24 PERMIT No: '1830910 API No: 50-029-20970-00 SEC9, TION, R14E, 151V FNL & 1992' FEL BP Ekploration (Alaska) Date: January 14, 2015 Subject: 14-24 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Sag interval of well 14- 24. 14-24 is a vertical well in the East Waterflood area. The Ivishak has been temporarily isolated with a sandback and cement cap. An isolated sag well test was attempted to confirm watercut and GOR. Unfortunately, the Sag did not produce even with 1500 psi drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivity. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages Per plat above, the following wells have been reviewed for casing and cement information: 14-43: Spud Date: 10/21/1992 20" 91.50, H-40 Conductor set and cemented with 20000 Coldset II in a 30" hole 10-3/4" 45.5# NT -80 Surface casing set and cemented with 1978 cu ft of CS II and 403 cu ft class G in a 13-1/2" hole. 7-5/8' 29.7# NT -95 Production casing set and cemented at 1179 cu ft class G in a 9-7/8" hole. TOC 5580' per 10/92 CBL. 5-1/2" 17# 13 Cr80 set and cemented with 125 sx class G in 6-3/4" hole. Fully cemented to 7-5/8" casing per 11/92 CBL 4-1/2" 13Cr80 tubing @ 8933', Packer C 8872'. 14-19: Spud Date: 6/8/92 20" 94# H-40 conductor set and cemented with 232 sx of SA II in a 32' hole. 13-3/8" 72# N-80 surface casing set and cemented with 3000 sx AS III and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L -80/S0095 production casing set and cemented with 500 sx Class G in a 12-1/4' hole which gives 1950' of cement. 7" 26# L-80/13Cr80 liner set and cemented with 435 cu ft of class G cement in a 8-1/2" hole which gives 2640' of cement. 4-1/2" & 3-1/2" tubing set @ 9576', packer @ 9507' 14-18 Sidetracked 2007 20" 94# H-40 conductor set and cemented with 300 sx Permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2615 sx Fondu and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx of class G in a 12-1/4" hole which gives 1500' of cement. 7' 26# L-80 liner set and cemented with 437 sx class G and 169 sx Class G in 8-1/2" hole which gives 4410 feet of cement. 4-1/2" 12.6# 13Cr80 set and cemented with 102 sx class G in a 6-1/8" hole which gives 100 feet of cement. 4-1/2" 12.6# 13Cr80 tubing set @ 10,563'. Packer @ 10.445' 14-37 20" 91.5# H-40 conductor set and cemented with 21500 of poleset in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 ax CS III and 600 sx class G a top job was performed with 200 sx CS II. 9-5/8" 47# L-80 production casing was set and cemented with 880 sx class G in a 12-1/4" hole. This gives 2600' of cement. 7" 29# L-80 liner was set and cemented in place with 300 sx class G, the liner lap was cemented with 150 sx class G liner set in 8-1/2" hole. A CBL ran 10/88 shows the liner fully cemented. 4-1/2" tubing set @ 9426' with a packer at 9300' 14-36: Spud date: 12/83 20" 91.5# H-40 conductor set and cemented with 375 sx PF II in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx Fonda and 400 sx PF C in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx class G and 300 sx of CSI in a 12- 1/4" hole. This puts 2350' of cement. 7" 29# L-80 set and cemented with 300 sx of class G in a 8-1/2" hole, fully cemented per 1/84 CBL 5-1/2" & 4-1/2" tbg set Cad 8787' packer @ 8694' 14-05 Spud date: 1/92 20" 94.5# conductor set and cemented with 300 sx Articset in a 30" hole 13-3/8" 72# N-80 set and cemented with 4234 sx Permafrost in a 17-1/2" hole 9-5/8" 47# L-80 set and cemented with 1000 sx class G in a 12-1/4" hole this put 2980 feet of cement behind pipe. 7" 29# 13Cr80 liner set and cemented with 493 cu ft of class G in a 8-1/2" hole. A successful foam squeeze performed 7192 to address a channel from 8994' to 9162'. In 7/93, a BPNL showed the channel went up to 8820' but no channel down. In 1998 a cretaceous leak caused the well to go to 100% WC required a RWO which installed a fully cemented 7" tieback. 4-1/2" tubing @ 8493' with packer @ 8380' 14-35 Spud date: 11/83 20" 91.50 H-40 set and cemented with 20500 Poleset in a 30' hole 13-3/8" 72# L-80 surface set and cemented with 1800 sx Foudu and 400 sx PF C in a 17-1/2" 9-5/8" 47# L-80 production set and cemented with 500 sx class G and 300 sx PF C in a 12-1/4" hole. This put 2950' of cement in the annulus. 7" 290 L-80 liner set and cemented with 334 sx class G in an 8-1/2' hole. Fully cemented per 11/83 CBL. 5-1/2" & 4-1/2" tbg Q 8554' with a packer at 8445' 14-20 Spud date: 6/81 20" 940 H-40 conductor set and cemented with 300 sx permafrost in a 32" hole 13-3/8" 720 L-80 surface casing set and cemented with 2800 sx Fonda and 400 sx PF and 138 sx AS II in a 17-1/2" hole 9-5/8" 470 L-80 & S95 production set and cemented with 500 sx class G in a 12-1/4' hole. This places 1470' of cement in the annulus. 7" 29# L-80 production casing set and cemented with 400 sx class G in a 8-1/2" hole. Per 6/81 CBL, fully cemented. 5-1/2" tubing @ 9091', packer @ 9015' 14-41 20" 940 BTC conductor set and cemented with 2000# Poleset in a 30" hole 10-3/4" 45.5# surface set and cemented with 1050 sx CS III and 350 sx class G in a 13-1/2" hole 7-5/8" 29.7# NT95 production set and cemented with 1320 cu ft class G in a 9-7/8" hole. This places 1560 feet of cement in the annulus. 5-1/2" 17# 13Cr80 set and cemented with 1778 cu ft class G in a 6-3/4" hole. This places 1640 feet of cement in the annulus. Af idavlt of Notlflcatlon (20 AAC 25.283, a, 1) All partners and landowners have been notified of operations planned for well 14-24. Plat Identifying Wells (20 AAC 25.283, a, 2, A -C) and Faults (20 AAC 25.283, a, 11) 1, ® TD/bottom of Sag/lvishak `f Top of Sag River 1, 4-0'*14-?Pfl. w Wells within '/ mile of 14-24. 14-23 14-36 14-43 14-05 14-19 14-35 14-18 14-20 14-37 14-41 Per the plat above, there are no water wells within % mile of the subject well. Three faults of concern as shown above are to the east (-300' away) and to the south and west (both -550' away). The maximum stress direction from log data runs almost due North-South, thus the primary fault of concern is the fault to the south. In order to ensure this fault does not affect the fracture treatment, the half-length of the frac will be designed to be -400'. The fracture and the frac fluid should not come in contact with the fault of concern. Exemption for Freshwater Aquilm (20 AAC 25.283, a, 3-4) Well 14-24 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non -hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within '/ mile radius per10 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 54) Well 14-24 was spudded on 6/15/83. A 17-1/2" hole was drilled to 2553' where 65 joints of 13-3/8" 72#, L-80, BTC csg w/ FS a 2532 was run and cemented in place with 2000 sx Fondu and 400 sx of PF C cmt. After the BOP was NU and tested to 5000 psi, the casing was tested to 1500 psi for a passing MIT. After drilling the shoe, the casing was again tested to 11.1 EMW for another successful test. A 12-1/4" hole was drilled to 5252', the hole was reamed from 5075'-5252', continued to drill to production casing TD where more tight hole was encountered in several places requiring back - reaming. Once past casing set point, 220 joints of 9-5/8', 47#, L-80 and US -95 BTC csg with the Float shoe @ 8974' and cemented in place with 500 sx of Class G cmt. Casing was tested to 3000 psi for a passing MIT. After drilling out the shoe, a 11.4 ppg EMW test was successfully achieved A 8-1/2" hole was drilled to TD of 9586'. Openhole logs were run, two attempts at running FDC/CNL/GR/Cal resulted in two stuck toolstrings. Both fish were recovered. 21 joints of 7% 29#, N- 80, BTC csg was run from 8660'-9586', the liner was cemented with 300 sx of class G cement. The cement was drilled to 9547' PBTD, the liner lap was tested o 3000 psi successfully. A CBL run 6/83 confirmed liner was fully cemented. After swapping well out to 9.6 ppg NaCl, the completion assembly consisting o f5-1/2" tubing was run to 8706' with the packer at 8624'. S LDL on 8/30/93 found that the packer was leaking, so a packer cement squeeze was required and cemented from 8522-8760'. There are 10 gas lift stations in the well, the bottom one at 8531 is behind a cement sheath. A BPNL from 8/98 found a channel from the bottom perfs down to Zone 3 at 9348'. A sand back cement squeeze was performed in 4/00 and placed the TOC (a 9250' When re -perforations were shot on 9/00, the pert guns were left in the hole. They were successfully fished the next day. When shallower perforations were shot on 12/12/00, the pert guns were again left in the hole. The fishing tools were left as an additional fish across the bottom perforations (9202'), and neither were retrieved. Subsequently, a collapsed liner was identified at 9177', a drift and tag on 6/30/02 was able to get passed the collapsed section with a 2.25" centralizer, and the collapse doesn't appear to be detrimental. The 16' of Sag ad-perfs that were shot in March 2003 did not bring in any appreciable benefits. The caliper from 10/06 shows the 4-1/2" N-80 tbg to be in relatively good condition with a maximum penetration of 27" recorded in 1 joint. A 12/06 RST found the GOC at 9142'MD/8740' TVD. E -line was also able to recover the 24' of perf guns that had been lost downhole in 12/00. On 1/20/2015, a successful MIT -T was performed to 4400 psi, a successful MIT -IA was performed to 4000 psi. Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) f Ili I - 5' FM: 120 1M I I IIF All - ORAY AiAtV1IOR_ BAKkNC MNL Kt7 EE 77 � 61 LLEV 12.347" . NC31" s.1nIT Mt. Ar.)le Nr rid <I7UU L11t nm NII 97 I lY lL.rauu IVI7 UgryyS�: tllsf, ID 1)9.1T' 2632' 1 P. S19' CS.;G 470 L 63 )(G TO IN 115 C1T8i: ] I- - I Min1mum ID = 3.626" @ —8522' TOP OF CEMENT SHEATH I S 117' IIS(: i', I?k, I -110, (I)sZ h(f IU 1 9�T I 8814' ITOP(X 7. 1 Ps7 1 -[ 0660' I.1 II?" IHC: Fk:, 12 to +do, 0157LvI, n 3 959' 1-1 6706' 1 9-t' USG dll, )S, 45 YU TO1 4 sent rr(3 :?k• I .91) 8 f&c 11 = 8681. 1 827W H I ORVION S~A!Y 14 i i Or Ill IC ; CIN 002(A3 AWLLA; T041 I-113 :6 rid M1I)G[I' Nose: Idrfet lu ftd-:orl M fc, hr;!.nrk..alper( tldta H„11 yilC 1V16'17 7 1 � k I11M•!7 6674 O U;S1gp,'R9 2 ,C V ,x125 4!49 (; 111gri�1C xa- J Wei v16C 177!7(.'94 :KI�NfI?7i 1 116' 4 4161 !11:11 5 0310PS4 f'f3' 8 9:117 921:' S U:4'. 84 fmi- Siff 9,TIt". 1 `:1;1,16 92;77x, c 11.1 W 4 a4104.V0 14-24 SAI NOTE&; TzIALEAI(A15s6VN1P.fill.1 TVIII - IIB6P PKR WA$ SOZ'D WI CEMENT 12114/97 J 2143' 1-4 5- 112- CAM ISM1L-O S`55V W 11)_ 4;G'2' 2143 1 j6Y IRAC 9 V, Q iA4' Ifl;1J>l17I CV, S I Ff M1N71*]1S SII M71 I1vl'7' lMVIjyn] i14.V ftmodIk71MB nA1t L 1 2+k13' 9b97 1 CA CW RK r± a;Y741i1 12.347" 5380 2670 4817 4017 1 CA DMY 13( It nV74r1 T' 29# N-80 :I Q15 G12) 27 LA cw IQ( 41 1121!91011 6290 Wellhead: 4 7240 loaf 73 ' CA WY I0( a 03x141 LY 5 !111l 15 t5o 71 CA OMY RK 0 OW7,0XI B 7815 7F.tla 71 CA 061Y f0( U `(Y$Irwflj 1 81M 16-0 71 CA DAM NX 11 12IM12 B" a lllr 7961 71 CA DIM� lix U (167a0n13� 90^ " n4G2 a7M24 CA DW w( a 92tIDV0 fII!:L1 f#6d 2S CA I)1 ' W a 9b3dE7 •'C1y IN Ito M AN:%Si s.'i111U1k.- 6PILL_.- l -1 -8527 -8)60'1 MVINITSIIFAT" MI1Ff1103625' "- OitlLl®0013516'-iili'IDut/wB i, 1 5600' � �S IrT HKR HIH Al35Y � ' � r'F �� 6614' 4 1rr x 4 io' xO in i q$8' '� a624' � 1u 516'x4lrre�uenis�n) 8692' _411! (Jt1Ac.r) alis Lnwrx> �, iu T 913' j 6T6lS' I 4112' L'i6i SIfAHGIr .t,I.H --1 h __._ 1 _6704' 1 { 1 I,w Y,t FG D = V, 6'_1 1 4686' -B A M} 17 LCX;GM 06,'27793 1 19032' ELMJ-f--L7A IF ICX; F-1 1 1131,11, 8049' HIM-11o1>cx snN:llt�nl/171 0177' P i 924x• 1— (;(11 1 A.714pi NIR-mr 1:1'01 VLX-0), ly ,duan 7041,1 H1-ti1HK IfUN'w 2,6'U1L G.AY 1'.'±97r0E J It wo 1(A!. t1 C11iim 0"I ST jwe oII91� 1 vol 4 1`3rfwx'r " A 1r#fMi:[k 13Vtt "CA-ffAkPlk(ALf4Ut ANkZ (W.t1lr'I I'mi, -(IJ itwA 4TIIHt1, iiAl ;_4 11tR7IR171 iznca:r t.Ap - 9676' -_H I_ Tal I !1 ! IFQT(;F?( 1 !.'i' % 1 •1(1' Y 40' 1 9691' 1 1 i r;l klv, ioTn 9547' 1 7' 0_4'', 2W 14 60 B lsc, WIT- LpH T1 E 7-11-111 lyil� l l+t U' €i7 Z>I)A14CHI t�-Il'„�'I`f !16 txJldi,El11S � PRl1tlI10E 1i�1'• LIP -111p 13�1i $ 1 !i �I F '1} Lr 11. MIT S7: F S.SkN f1i2J113 WH_L: 14-4 2 I IfY?Y12 ".'J 11.U.t} f1ilFi8 1117707721 4976111 r3(T7p� ;FQ=Y T "R.I. F-i!A(: 5;VL 117,2&f1IFT2fdF re 14-4 1 APIN17 5 gjo. 01f0U113 R)c (Ul -14 A1Ha[7Was.'11(»I :'�Ei: J, 11014 FINE 5O LkTH 8 1992'1'JU9i0 UU 44Y7'rTL o7f7U11 , 6F1r.Kn i "j., (90 (09l L1113} I 9713 1 FF1IJCI I.1 V G(1(0317Jr'I J) HH Exploration (Au4110) Mame/Size Weight Grade ID Burst, psi Collapse, psi 13-3/8” Surface 72# L-80 12.347" 5380 2670 9-5/8" Production 47# L-80 8.681" 6870 4760 7" Liner 29# N-80 6.184 8160 7020 5-1/2# Tubing 17# - L-80 4.892 7740 6290 Wellhead: Grey manufactured wellhead, rated to 5000 psi. Tree: 7-1/16' 5,000psi w/5-1/8' bore Tubing head adaptor: 13-5/8" 5,000psi x 7-1/16" 5,000psi w/ 5-1/8' bore. Tubing Spool: 13-5/8" 5,000psi w/ 3-1/8" side outlets Casing Spool: 13-5/8' 6,000psi w/ 3-1/8" side outlets Tree saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" The treesaver is rated to 10,000 psi. i Geological Frac Information (20 AAC 25.283, a, 9) 040htqn o of Stre" etraaa ar. ot elrodd Zone 01)011vana l]radart lrQlrl6ur+rw Top d Zal1o, Q w� elan d Zan Moduka = Lapai' i ROO l 9 � e' 7 L'S72.0 :-M O 59.1 btJ7 S Bt9 6t67 S 2 56it40 .aa a 9 _ Mao * 491,+ 442 7618 Od".Q 876E3 20GON$+ Q, 10 6646.tl A76$ g74d 7J1.7 0.400 419 s 11 47t 0.p a s. • 1201 'F .72� 287A $00, 9YGQ.1 t � {. - . to t , �� -. - . 1140.0 0.7271 6var .5 0.b: 1 `"' : x.260040 .52 Mechanical Information of nearby wells (20 AAC 25.283, a, 10) P"d loan Caaledaa OPL" pjq"a Summary Hydraulic Fracture Program (20 AAC 25.283, a, 12) (Detailed program attached) Pump Schedule. 71pf• 19. • f3.1..ywrt rkQ 721• _ CUP fa.... W� *� W� 7158_.:. 1.14.._.. 1;.- a- 044 .. �.�.. 4;.- �.. 11067 'Y . L'Ir . - s'..�14" O;w W. M, �� I Y- I R� �..>'.. 11r. I �-� N�0 1. ilk Tdd 4851S0 91stl M0020-.) 170 0dn ",* 1 I.Md1+.1• t..Wvr.. 4= 6,23> 710.0 1000 00 UW .A9 1000 VA 0 0 0 5 m.00 I 2000 2 100 1612. 710 %W MO 400 A "a I M4 =a M 0 0 B m tm 2100 9 444 'N ify.prr. td0 .PIR 238 1136 1,000 9007 „ 070 0630 !M 0 0 0 m tv 2219 4 5 T- r.01 164 W W ..0 wan 1,700 nm 1040 0.770 "a= 2100 243.8 4538 >6 N 1144 14310 � 000 ISM 700 2416 4518 1.a 764 0 0 0 0 0 0 m m III SOD 2150 21.9 3769 s O.e n 0 0.12,0 00 4539 0WJ310 1 0.0 453.8 rW 0 0 0 0 - s3LLW 0769 7! q61 *Wl o to 711q 50.0 6038 LW JL110 1 X. 1 5030 M 6 0 0 m 9.00 0289 ! !y B7f*o MW 8016 2000 7038 LL070 /'J.¢➢ i5g0 1 7030 f0t 0 0 0 30 867 6938 4 1 9V W '-W ri'4'+f:41 rrRi11r4 2p06 01300 176 tm 34 17 600 75tB 617.8 ;104 3W 7[A0 WA 77,010 700 7518 Bte.e 1M0.4[e 11.10-d 8 2.000 9l9 2,008 10- 3o 30 t07 z5o 9102 9352 71 0 L3 WRM•.0 Y741M.d) 3y7 S1,OSf 766 0.Y4 41101 180.9 6961 10610 4,700 14f17 786710 7]00 8+106 ,CLO 9266 t536 940yp, "mum 4 0 9,706 95389 30,106 06500 30 30 3.33 790 9806 21630 0 001' Y112.7!r.tl 73.0 L9613 462 L992 y/00 974Mp 17L0 13298 IR8 -W 0 0.3183 WBN 30 S03 710 a 0 r- Weir -O ],060 53'll* 000 I 13092 f6,3R1 000 18000 %A 0 0 Y0501 30 201 11206 M 7116 06'07 }308 94.906 W0 13402 I= 0ti7b 000 14% 1N 0 0 ROSM 30 207 M- +} ISI::.- --.IY,Iifx 7. ++7 ^7.*•?1 �_ ' 4!81_ X7.9- _S'`»g. 1 v 3e?>' x ler me. I 07.16. v.7r. Rds Y0000� •-.d.r. Ped g8J00 21611. 8002Ipip.exq 880 pdw. w 9- 36.000 76.4% 31r. -b.) 06 2 m OdVxnW Tdd 4851S0 91stl M0020-.) 170 0dn ",* J6010d.16y80x.1 4.00 Od Ox -d P.*'rC•-.-• R.11• rm reuI" O 100 sdwegd Rgwx 1-0 30106 234% LOB4rrJ4>S.bkw1 200 04wl'd Rggrd>em 90,470 7s6/. L06519wbN61" 100 9dyn ni0d 7dJ 129501 MVS18.dd.1 Ja�15o.ow2•.d6•d1x1 430 45-40 9dp1 Md 6pwmy.l H1dd f C..ITx+PaOM i111.br.x N.P0•xed 1/MWW-6• kgpp Rgpx6p40 9179 2 806Y -1 950 Bd Vx"0 f3.N(pd711 2Am 3.f --j F79(10,&.b 1.W 0d P•I"al L0811L3.6h,".1 2.00 edpwngd N..xi.IB•pi•x211• Atl3F•giele..x WOO MZ75 a•LY�hbl•d f5W1E mW.) 430 m 9d,Ma 0dP•1e17•1 Wxx.Ypdww.R Reppwfigi...w• 1379 WI. bb6 40501 fa ,bE]IEnymYM01•eWd 4Sfl0 6pwnVW W/ d pggrt 66085 Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 5500 psi Anticipated half length: -340' TVD Frac top: 8647' MD Frac top: 8954 TVD Frac bottom: 8709' MD Frac bottom: 9025' Hyd(611on CWWA for 8067 @ 511 1 s sit.!•'<�S1d Q +1 P. 11l�all �3P==1611 id �`�=.� :1G 1111 fiF AP f4 !0 .4 .7 1: it! IM I:n 1.-4+sy'lw+k bl+ The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of -0.57 psi/ft or 4900 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the harder Sag formation and the softer confining layers. Average confining layer stress is 0.655 psi/ft. Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values we used, a half length of 340' is expected. Pressure Test Information (20 AAC 25.283, a, 7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4400 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treatinq Pressure: 7000 _ Stagger Pump Kickouts between: Global Kickout: IA pop-off set pressure: Treating line test pressure: 6300 psi and 6650 psi 190% to 95% of MATP) 6650 psi 95% of MATP 3000 psi (75% of MIT -IA) 8000 psi Sand Requirement 130,000# 16/30 Sand Minimum Water Requirement 1600 bbls (pump schedule: 1400 bbis) IA Hold Pressure 2500-3000 OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kidcout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r D�Ir _;Z� w� V. 14-24 ilg Up aoatol Chemical Disclosure (20 AAC 25.283, a, 12) YF125FLE)(D:WF125 54,471 Gal Contalns: Water, AntlFoam Agent, Surfactant, Breaker, Stabilizing Agent, Gelling Agent, Crosslinker, Clay Control Agent, Scale Inhibitor, Additive, Bactericide, Pr M2 j Agent firrotalVaWpM nrrM fn Na mbYs aew.,.p,.r.no,Mummpdpn gwphr erd undldgc W—ixj ppArdbydiu 14808-60-7 9000-30-0 75-57-0 107-P1-1 30-10-4 l5122•G9.a 7727-54-0 129898-01-7 1310-73-2 67•d3.0 111-7f:2 25038-72-6 111311-66-2 69131,11-5 34398- 11)3EO) 34396-01_3 7E0 1330-43-4 7647-14-5 51053.39.1 30043-52 10377-60-3 7631-86-9 _ 2617iss� - 7786.30-3 111-4" 9002.84-0 i4807.9d6 2"2.20-d CrystaR ne Oca -22 !4 <w 21 telea!nei11y11mmCaEeml Rt7;D7f Eene Glyeol.,.. _ <0.1 % -- Sorbitol _ — —. - <.04 % _ _50.114 eah,propyianaglycoI _ _ — D1.11,0101'lum ib?eoskittu IphatR� <0.1 % __ 2•PAapanalc "Cid. iiolymer wilh SadluSl pllalp�lYetgT -- - — <0.1 % „ Sodlumhydroxrde _ _ <O.1 % Propon•2rol <O.1 1E 2•butox$01anol_ 0,1% Vinylidene crlorldOrnathylacrylatecopolymer <0.01 % Gum, xanthan <0.01 % _ _ _ _ G12•;5 allOt1a14illyalllfatQit _ Linear CIL almboi erhoxyla�ta t3euj _ <OM % _ <O.OI% _ UnearCll alcohol elhaXylate{7"o <0.01% _ _ "V Sadwmchkirlde <OAI Diatcmuoovaurth calcined - CMOI 14 Calcium chwhk < CAI %. MaOrlum nitrate c0A01 % Kant teiloe111lra _ _ _ _ 5-thl9r9-2•mvthyl-2Mrseftawtala-0ne <o.001 i5 '(04101 % MagneSlum"rlde <_01001_% _ 2 2`�x Itianol <Owl % _ <0.001 % p0lyterrAflumraulhylane) _ <ODOI % Magnesium s�itcate r�ydrata utak) I-rnethyl-21--isathialvi-3•asu _ _ <0A01 % Date: 1/7/14 From; David Wages ADW Engineer Josh Allely ADW Engineer Subject: 14-24 Recomplete Procedure Est. Cost: $1000M Est. IOR: 100 BOPD Objective: 14-24 is a vertical well in the East Watertlood area. The Ivishak has been temporarily isolated with a sandback and cement cap. An isolated Sag well test was attempted to confirm watercut and GOR. Unfortunately the Sag did not produce even with 1500 psi drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivity. 1. S Drift and Tag, Set Plug, Pull Plug MIT -IA, MIT -T (assist Slickline) Hydraulic Fracture Treatment FCO Tag, Install Deep GL Design Frac Flowback 1. F 2. F 3. C 4. S 5. T Last Test: 5/19/12 Deviation: vertical to 5100', —25 deg to TD of 9586' MD Max Deviation: 28.6 deg at 9000' MD Min. ID: 3.625" drilled cement sheath from 8525'-8779' MD GLMs: 2903', 4817', 6215', 7206', 7757', 7819', 8126', 8197'**, 8462'**, 8531'** (**Cement in Mandrels -Unable to pull) Last Downhole Ops: SBHPS, set and pulled RBP for MIT Latest H2S value: 24 ppm, 1/20/2012 BHT & BHP: 216° F & 3300 psig @ 8800' TVDSS (0.375 psi/ft, 7.2 ppg) Wellbore Volume: 209 bbls to top-perf Annulus Fluid: Diesel Contacts Office £ell David Wages 564-5669 713-380-9836 Josh Allel 564-5732 350-7362 Matt Brown 564-5874 223-7072 11.0cidW I Drift and Tag, Set Plug, Pull Plug Drift and tag to TD a) Cement sheath milled to 3.625" Set 4-1/2" plug close to BD nipple b) According to caliper report, no apparent cement sheath to this depth (see Caliper report attached). 1. Fuldmie I MIT -IA, MIT -T (assist Slickline) 3. 4. MIT -IA to 4000 psi c) Use diesel as the IA is currently filled with diesel MIT -T to 4400 psi d) Per new AOGCC regulations regarding frac treatments. 1. Slickline Pull Plug 5. Pull plug set in the tubing for the MIT -T '2. Fullbore Hydraulic Fracture Treatment Pressure testing and material requirements Maximum Allowable Treating Pressure: Stagger Pump Kickouts between: Global Kickout: 7000 psi 6300 psi and 6650 psi (90% to 95% of MATP) 6650 psi 95% of MATP IA pop-off set pressure: 3000 psi (75% of MIT4A) Treating line test pressure: Sand Requirement 8000 130,0000 20/40 Sand Minimum Water Requirement 1600 bbls (pump schedule: 1400 bbls) IA Hold Pressure OA 2500-3000 psi Monitor and maintain open to atmosphere 1. Fill frac tanks with clean water treated with biocide. a. Send water sample to SLB for QA/QC testing at least 3 days in advance. b. Perform QAQC Testing per attached procedure, use chemical of the same lot number as chemicals to be used for the frac. c. Heat water to 100 deg F prior to the frac, water should be at least 80 deg F on frac day. 2. Stage Sand Chief on location and load with sand 3. Ensure location is prepped as required for frac operations (i.e. snow removal, pad grading, barriers and cages installed, ground rods installed, etc.) 4. MIRU frac equipment. a.MIRU enough treating iron and horsepower to maintain 40 BPM and 7000 psi. 5. Prime up pumps and pressure test main treating line a. Stage up to high pressure test 6. Function test check valve(s) 7. Stagger individual pump kickouts and function test 6. Set global kickout and function test 9. Function test the manual kickout 10. Install pressure transducer to monitor the IA, we will maintain 2500-3000 psi 11. Perform loop test on blender and hydration unit to ensure meter consistency a.This test may be done in the shop, verify on location. 12. Perform bucket test on all additive pumps (including back-up additive pumps) and flow meters; calibrate as necessary 13. WSL to walk the lines and manifolds to ensure proper valve alignment and pertinent valves are open/closed. 14. Inventory water, chemicals, and proppant Frac well per excel spreadsheet provided by WIE During all pumping and pressure testing operations, all personnel shall either be: 1. Shielded by heavy equipment or structures and out of the line of sight of the wellhead, treating line, and pump discharge, or 2. Positioned at least 75 ft from the wellhead, treating line, and pump discharge. a. Exemptions to the above policy are: the blender operator and One designated service Company rep during pressure testing to check for leaks NOTE: The Excel file will include the engineer's pump schedule, the QA/QC checklist, Contingencies, PJR Checklist and the GHG reporting form. A. During all shutdowns after initial formation breakdown, measure and record an ISIP in AWGRS B. If pressure begins to rise, drop proppant concentration and/or decrease rate C. Back off pump rate to get a "soft" shut in, we want to slowly bring down the rate over the period of a1 minute. D. Flush to top perforation -20' Contingencies including what we do given a screenout or a rise in casing pressure will be submitted with the pump schedule. 3. Coll Twp I Frac FCO 6. See Appendix A for FCO procedure. 4. SUCkSM I Tag, Install Deep GL Design 7. Drift and tag sand top 8. Install Deep GL Design & To" Frac Flowback 9. See Appendix B for flowback procedure. Appendix A - CT FCO Procedure Notes: • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate frac flowback. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU and reverse out BHA. 3. RI down to estimated sand top and begin reversing out with slick 1% KCL. 4. Continue reversing down to 8,920' CTMD. At this point we are -40' from the open perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the perfs. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly reverse until returns fall off to -80%. If returns are still good even after the nozzle is past the top perfs (not likely but possible), it is acceptable to continue reversing down to TD 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. Appendix B - Test Separator Flowback Procedure 7. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake -outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1 %, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1 % continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1 %; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Ti�EE = 5' FMC 120 WII1AO= QTAY ►tC'TLIATDFt - BAKFiiC� 1`dfl1L Isn, 9 E TY 7900 11MU10 33111' L11F.S/TVO= S 00121x13 12/58104 0444M 3-Iff 890PT3S IS KYA 1s1a�6'Clil74IN,1�oxOInt69b9IGC BT37' [Minimum ID - 3825" Q -"852Y TOP OF CeMEWT SHEATH S-1 /2 T13(1PC', t iN. LSO, .0?32 W, ID" 4 AD2" r LNt 1-1 BMW 112' TOG FC, 12 ISM, i��. 0762 6pt, Tl .'1956' 6TIS6" RI*DWTM9 -§AWRY REF LO& BIAS ON AAMM3 AHC1EATTT]PPG 2raMW NbM; tAld4r to Rodualbn OB for tltrbrl�N �H 4au 2-1271 5 A066 - "-M O TYIE VLV 0.'Tg5103 �JJ6 6 91T5.9M5 C 7900 11MU10 33111' 4 M I . 91110 S 00121x13 12/58104 0444M 3-Iff 4 Owl -6107 3 RIC OWW84 04M4070 1U9' 4 0202 - 0112 S 27 0300M 041041n0 2-7Jr 4 11707 - wly C 4 7205 141700 1115 4 U9.T8 6734 C 0 03100164 06MMO s 7757 7550 21 FTiTiT -�s4r �4t 291i. PLSt) OTtC .0371 dAr. D =0:154"� Arial' 14-24 6A/r!_TY NOTED_ T ¢ IA L4AK AT G$SV MP- MI. ! I TWI- HOOP PKR WAIS SWD W1 CE113Q 12N403 43" b-il7' Glut 6AL-Cl SSSY �', O7 = 4.502' y.__ 63'FRACSIV,_D=380'�(if2I5H3J� - BT AD 7W O9/ TYIE VLV IJITT}I FONT DATA 1 2409 7900 1 CA p114p _ Po( 0 00121x13 2 4817 4817 1 G OW RIC 0 02613 3 8215 6139 27 G OW RK 0 axiom 4 7205 1037 23 CA OM2 RK 0 OBI U s 7757 7550 21 CA OO4Y 1O( 0 05274011 6 7610 7400 21 CA OOK Tri( 0 05130,83 7 0128 7485 21 G OW 1O( 0 1b28�t2 � alsr r95t zt G [IW Ta( 5 CA OW tK 0 20V�Www24 25 G DW AK 0 x662? --�iT60' piNi41 BI#A 1N, � L�1 To 3 117 OWL L OTI OUT 5246' . 01TA' J gIPlA1 1� J {2.112' elfft P&e i car J 6fi4'b 111rk411,2^M,D-3,062 t_ icer _) {' lir ritita� i�iils l ani°�r� Iw; llx� ►.air` J - � Ti] TTi1A i4 10C CAP I IW rtelaa� sAn�;!1x01112) r rnnnL I.SIMM. FLAT BTU GO. OL3VO d OkLl9lMMACIVRARMg iO0121T►T2) �• i dII W IDOL BIRM, Mt ETT [t717410pj ►6r J—{1118"- TLL 1iOMOdS.TS'r x t,4R' x 40' !!1 7FAHPEY+ RtCHfEBAY IAAr tAELL: 14-24 PHa>alr1W 1530010 AR W 50-029-20010-00 .10K RK lair RLdiftz OP &PkfM On JAMkaj Triaxial Safety Factor: ae ......... .. .. ..... .......... ....... ...... . 0 C. ..... ..... ........ ------ ------ ----- — 4 .......... ... ....... ..... ....... ------ — .. ....... I ..... ........... ..... ...... . ........... .... . ............ ......................... ... .... ............ ..... ........................ . C4 el ............... ......... ....... ..... . ..... ----- . ...................... - --------- - ......... ...... ------ * ------------------- - 4.A ........... ...... ............. -- ----- — «'n .W!• 4 ..... ...... ....... ------ J.... ...... .... ................... .. ..........a. ...... ....._«_-__. Cla ............ ....... — ------------ .................. ....... ..... ...... . ........... ..... - ------------------ ----- . . ......... .......... r ............ ..... ........... ........... ...... ............ 1 ...... ..... ............ . 6- ................. . .... I ................... ------ Ir ..... ------ ...... e .................. . C; ...... .............. ---- Ln ..... .................... .............. ----------- I o (U) OAL 4-112" Caliper Report Joint Jt Depth I Pen `01n. n. Penhek�l h1in_ No. (Ftl Lpset ao Loss 1'. D. (Ins) (Ins_) °. , Ons.) Damage Profile Comments (% wall) 0 50 100 SPenetrabon Body Metal Loss Body Date: January 14, 2015 Subject: 14-24 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 711 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture strrrtiuj to the Sag interval of well 14- 24. �l 14-24 is a vertical well in the East Waterflood area. The Ivishak as been temporarily isolated with a sandback and cement cap. An isolated sag well test was at meted to confirm watercut and GOR. Unfortunately, the Sag did not produce even with 1 500 si drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivi . We are requesting a variance to sections 20 AAC water aquifers and a plan for basewater sampling,, Please direct questions or comments to a, 3-4 which require identification of fresh Plat Identifying Wells (20 AAC 25.283, a, 2, A -C) and Faults (20 AAC 25.283, a, 11) Fault at TSGR TD/bottom ofSag/lvishak Top of Sag River Wells within 1/z mile of 14-24: 14-23 14-43 14-19 14-18 14-37 14-36 14-05 14-35 14-20 14-41 X14 -06A t- .4,35 • X14 1428A Three faults of concern as shown above are to the east (-300' away) and to the south and west (both —550' away). The maximum stress direction from log data runs almost due North-South, thus the primary fault of concern is the fault to the south. In order to ensure this fault does not affect the fracture treatment, the half-length of the frac will be designed to be —400'. The fracture and the frac fluid should not come in contact with the fault of concern. Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4) Well 14-24 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within 1h mile radius per20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6) Well 14-24 was spudded on 6/15/83. A 17-1/2" hole was drilled to 2553' where 65 joints of 13-3/8" 72#, L-80, B'i _ csg w/ FS @ 2532 was run and cemented in place with 2000 sx Fondu and 400 sx of PF C cmt.ter the BOP was NU and tested to 5000 psi, the casing was tested to 1500 psi for a passing MIT After drilling the shoe, the casing was again tested to 11.1 EMW for another successful test. r 1 A 12-1/4" hole was drilled to 5252', the hole was reamed from 5,675'-5252', continued to drill to production casing TD where more tight hole was encountered fn several places requiring back- reaming. Once past casing set point, 220 j/wasemented f 9-5/8", 47#, L- and US-95 BTC csg with the Float shoe ® 8974' and cemented in place with of Class G c Casing was tested to 3000 psi for a passing MIT. After drilling out the shoe, a 1g EMW tes as successfully achieved A 8-1/2" hole was drilled to TD of 95penhole s were run, two attempts at running FDC/CNL/GR/Cal resulted in two stuck toos Bot is were recovered. 21 joints of 7", 29#, N- 80, BTC csg was run from 8660'-9586', thwas emented with 300 sx of class G cement. The cement was drilled to 9547' PBTD, the lina tested o 3000 psi successfully. A CBL run 6/83 confirmed liner was fully cemented. Aftpang well out to 9.6 ppg NaCl, the completion assembly consisting o f5-1/2" tubing was r706' with the packer at 8624'. S LDL on 8/30/93 found that the packer wing, so a packer cement squeeze was required and cemented from 8522'-8760'. There are 10 gas lift stations in the well, the bottom one at 8531 is behind a cement sheath.. A BPNL from 8/98 found a channel from the bottom perfs down to Zone 3 at 9348'. A sand back cement squeeze was performed in 4/00 and placed the TOC ® 9250' When re-perforations were shot on 9/00, the perf guns were left in the hole. They were successfully fished the next day. When shallower perforations were shot on 12/12/00, the perf guns were again left in the hole. The fishing tools were left as an additional fish across the bottom perforations (9202'), and neither were retrieved. Subsequently, a collapsed liner was identified at 9177', a drift and tag on 6/30/02 was able to get passed the collapsed section with a 2.25" centralizer, and the collapse doesn't appear to be detrimental. The 16' of Sag ad-perfs that were shot in March 2003 did not bring in any appreciable benefits. The caliper from 10/06 shows the 4-1/2" N-80 tbg to be in relatively good condition with a maximum penetration of 27" recorded in 1 joint. A 12/06 RST found the GOC at 9142'MD/8740' TVD. E-line was also able to recover the 24' of perf guns that had been lost downhole in 12/00. Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) T141 5' FALL: 120 N1 111 A Ail GRAY GAS LF7. LOAN AVIIIAT00- BAKHeC 72# MNL KS Ell T2' Nose: here! to Ilu4utbn OF f« I+n'lorealpad data So fl.fv S9i 4VITRVAtL,�yy5i1[ PURI BATE w0l. 51w 7 w W. A Ulo 257' 0 90(l(7 _9 i1 1Lww"LIT2 92111' ? 1�2' Mum IVIS 8400'S$ 0 (I:y 3'6'R:;l`,12r1 L•6(I stat n 12 :LIT' f + 2632• 0 -,"'CSG 470, L 80 X0 TO Uit g5 RP11: 1 f 8137• Minimum 10 .3.625" @ -8522' TOP OF CEMENT SHEATH 5 1'2'rgf R;, I'k L.OID, )_,jztp, 10_ 1682- I I 8614' _J- i Tor or r 1 No; I L SISO• - I4 1�?'71St1� 1: ev 9.60, 01576p1�p 39511' i-{ I7otr _ _ t 9-516" 1.un 411, US 95 MO fq; -0 411IC 69'/2' 100 BTac IJ = 0 6fl 1' I-- f 6974' �T�`T LTW11•II BPTP5; f X IA LEAK AT SS5V NIP FW t KRWAS 60ZDWTCEMENT 131114103 T14]' I� U2' CJ1M aAL-n sssv 144+ to) a � 5112gfj2•_ 2143" I-583' rRACkv,D-.780.(,w1 511J)l Weight fT F&ORAT10N SUTAAR7 ID GAS LF7. LOAN 14f LOG ri)lf., i)N *26-83 13-3/8" Surface 72# ANCLf AT 1(W MTff 26' 9960' Nose: here! to Ilu4utbn OF f« I+n'lorealpad data Sr& S9i 4VITRVAtL,�yy5i1[ PURI BATE bkf]1 511/. 7 w �8 1)9KI1960 _9 i1 11!23117 . ? 1�2' 3 0960 6976 0 DN%101 0 OW4M.) 2 7+0 4 9125 914, C; 11)011114 WC 3 A'6- 4 9161 aw, } 121ORN :N,".f4N2J { Ir 6' 4 9161 4191 5 O.Y&_VI54 LW241W ? 1755 4 @71{7 31)7- S 0IVW84 34AT41:n1 4 7201 !1717. C 12716100 1•':� 4 'YM h VM5 C 113iftR4, 04"W(O 1 61711 MIS 21 CA DW �T�`T LTW11•II BPTP5; f X IA LEAK AT SS5V NIP FW t KRWAS 60ZDWTCEMENT 131114103 T14]' I� U2' CJ1M aAL-n sssv 144+ to) a � 5112gfj2•_ 2143" I-583' rRACkv,D-.780.(,w1 511J)l 1 -6.529 -07001 f (] oUU SHFA 161. A5_ L 13;1 10 3 625' OALkED 013T !!16' - 9ns' i0a7]194} ISCO' 1414 80t FOR A_55V 'A 7 8611' ; - i S ur X4 v2' non 5 IiE74' 1FSr6' }f 4_1?24_1 rx' 8k F}L r4U2 f 8E 92' 1 14-rCAM;()1ie-6LAtjjN 149. IU -.1 0709• 4-1,2-BiMSHEAF06YT_SLj6 i - f DTII' ��f4112'YIL rG,O=]ASE'�T f Sees I i a,r� rr L(JGC Ell W21 83 ) 14 9092' ELM 1'3.4TVMTETUCf;AT'lItM712'} 90b9' EUA -{ ra�tir s,lPn11150u121 9177' ��ccnlArOt>1Mer0vi0ivaEo),1HssfrJ 1IKIU Ftt.91Wt-TF1N rr 12.0' BELL Gi&X I Z/;?i06 !I I 7 J IF -fill K4! t:V CUrnR CA 47' 1d"✓1gII7k I ..i '7 I Atil t i t :378id/;. I g A 1 BTA164y rr]Fjli3 'f a CA:f'F/i f>f'f'1I1fAlal FJt AIIA6 (OL4262'I31 7 , Iti34f1 ti11t11 RTrIld: r�iA�-a3, [5782 f10Up 5240' - GDN_JN, LAA, 9676' 1--1 CISI I ILL rRl IOFB 3 77 X 1 47 IT 40r 6661 I I r d:f l VF'] [lfliof-f 9asi• 7' L W, 29k, µBO B18q 0371 bpi--- awj i FF i:Tl iB.V . r - d01.F(I�. _ PRI.C{i0E BAY I.HI f kL SLv 1312yf1J1 WFLL 14-24 11 i19f1 J I1.DA) ter l►Hf (111205121 PFJaAI W 1430910 011Y> i1t 14c r1Yir' •:f=3 OFN RJLLFRAC SvL (1717 123 ARNa 50-IY1}209MLIU 01A78f 13 R1L' f]fi- $P¢'A 11-3 CD1d1�1.'1k1F1 .. _ 56; 9, T 101{ PH 41; 1519' 1 ra d 1992' FEL 02millT ►B1W�1(} n1Q 00102!1111:1; 46129117 1FFI pip 14 v tjo'pvz4l13j • 6P 6lplarstlon (ALAkaI Name/Size Weight Grade ID GAS LF7. LOAN RS 13-3/8" Surface 72# SI A47 ev131 Lkv� rYPE YLV LArai PURI BATE L-80 1 7111:1+791171 4760 G4 Dow� R( 0 OV7 rF7 --- 7 401714SII 5-1/2" Tubing I CA Lfr1/ R( 0 OW4M.) 7740 -3 4215 16137 21 CA CW WC 0 02) IBM 4 1704 1031 23 CJI DI1fl' RL 0 .03174)95 5 F151' A•s50 21 CA I)MY w 0 ,.wzf 0o 6 ?8119 7606 21 G1 DMT )a( 0 Gf513Q163 1 61711 MIS 21 CA DW RK 0 ".97126112 e^ 0137 7961 21 CA 1)IAY NK 0 09rI1k43 9` 1W 02 SM 24- cel DM' R< QyY0N0 NI" 4531 $269 25 cA nW RK 0 Lows041,1 1 -6.529 -07001 f (] oUU SHFA 161. A5_ L 13;1 10 3 625' OALkED 013T !!16' - 9ns' i0a7]194} ISCO' 1414 80t FOR A_55V 'A 7 8611' ; - i S ur X4 v2' non 5 IiE74' 1FSr6' }f 4_1?24_1 rx' 8k F}L r4U2 f 8E 92' 1 14-rCAM;()1ie-6LAtjjN 149. IU -.1 0709• 4-1,2-BiMSHEAF06YT_SLj6 i - f DTII' ��f4112'YIL rG,O=]ASE'�T f Sees I i a,r� rr L(JGC Ell W21 83 ) 14 9092' ELM 1'3.4TVMTETUCf;AT'lItM712'} 90b9' EUA -{ ra�tir s,lPn11150u121 9177' ��ccnlArOt>1Mer0vi0ivaEo),1HssfrJ 1IKIU Ftt.91Wt-TF1N rr 12.0' BELL Gi&X I Z/;?i06 !I I 7 J IF -fill K4! t:V CUrnR CA 47' 1d"✓1gII7k I ..i '7 I Atil t i t :378id/;. I g A 1 BTA164y rr]Fjli3 'f a CA:f'F/i f>f'f'1I1fAlal FJt AIIA6 (OL4262'I31 7 , Iti34f1 ti11t11 RTrIld: r�iA�-a3, [5782 f10Up 5240' - GDN_JN, LAA, 9676' 1--1 CISI I ILL rRl IOFB 3 77 X 1 47 IT 40r 6661 I I r d:f l VF'] [lfliof-f 9asi• 7' L W, 29k, µBO B18q 0371 bpi--- awj i FF i:Tl iB.V . r - d01.F(I�. _ PRI.C{i0E BAY I.HI f kL SLv 1312yf1J1 WFLL 14-24 11 i19f1 J I1.DA) ter l►Hf (111205121 PFJaAI W 1430910 011Y> i1t 14c r1Yir' •:f=3 OFN RJLLFRAC SvL (1717 123 ARNa 50-IY1}209MLIU 01A78f 13 R1L' f]fi- $P¢'A 11-3 CD1d1�1.'1k1F1 .. _ 56; 9, T 101{ PH 41; 1519' 1 ra d 1992' FEL 02millT ►B1W�1(} n1Q 00102!1111:1; 46129117 1FFI pip 14 v tjo'pvz4l13j • 6P 6lplarstlon (ALAkaI Name/Size Weight Grade ID Burst, psi Collapse, psi 13-3/8" Surface 72# L-80 12.347" 5380 2670 9-5/8" Production 47# L-80 8.681 " 6870 4760 7" Liner 29# N-80 6.184 8160 7020 5-1/2" Tubing 17# L-80 4.892 7740 6290 Wellhead: ARCO MN. ip WRLi ima Grey manufactured wellhead, rated to Tree: 7-1/16" 5,OOOpsi w/ 5-1/8" bore Tubing head adaptor: 13-5/8" 5,OOOpsi Tubing Spool: 13-5/8" 5,OOOpsi w/ 3 -1/I Casing Spool: 13-5/8" 5,OOOpsi w/3-1/! Tree saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" wwaal ww�l O d . Geological Frac Information (20 AAC 25.283, a, 9) 11 ND Oaplito -rap Blraw kawmma Blraw d Mews d zom 611 Or~ oRa IramSLdaoa Top d Gra so= d Much" Mum% tale q �7 Zaw �2,ow iL1WDey ROD 3 4 6856.0 AB6d8 _.B pOp0f,10206 MMO w ABd}0 .00@ 4fi6A.5 600110024 63174 duv 132, 6i A76 p.60p '6967,6 2.600000..24B8G9Al Ci ;VO 676+,8 0.690 6768,4 20000010 -2896R3i9.7 1.8 4,OOI7pD0,3O,4 ,4 1.13 61240 . ,0 .800 +.4 Y.2617pOR .3? Mechanical Information of nearby wells (20 AAC 25.283, a, 10) Per plat above, the following wells have been reviewed for casing and cement information: 14-43: Spud Date: 10/21/1992 20" 91.5#, H-40 Conductor set and cemented with 2000# Coldset II in a 30" hole 10-3/4" 45.5# NT -80 Surface casing set and cemented with 1978 cu ft of CS II and 403 cu ft class G in a 13-1/2" hole. 7-5/8" 29.7# NT -95 Production casing set and cemented at 1179 cu ft class G in a 9-7/8" hole. TOC a 5580' per 10/92 CBL. 5-1/2" 17# 13 Cr80 set and cemented with 125 sx class G in 6-3/4" hole. Fully cemented to 7-5/8" casing per 11/92 CBL 4-1/2" 13Cr80 tubing @ 8933', Packer ® 8872'. 14-19: Spud Date: 6/8/92 20" 94# H-40 conductor set and cemented with 232 sx of SA II in a 32" hole. 13-3/8" 72# N-80 surface casing set and cemented with 3000 sx AS III and 00 sx AS II in a 17-1/2" hole / 9-5/8" 47# L -80/S0095 production casing set and cemented with 500 ,C Class G in a 12-1/4" hole which gives 1950' of cement. 7" 26# L-80/13Cr80 liner set and cemented with 435 cu ft of class GA—meet in a 8-1/2" hole which gives 2640' of cement. 4-1/2" & 3-1/2" tubing set ® 9576', packer ® 9507' , 14-18 Sidetracked 2007 20" 94# H-40 conductor set and cemented with 300 sxPe afrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 15 sx Fondu and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx of class G in a 12-1/4" hole which gives 1500' of cement. 7" 26# L-80 liner set and cemented with 437 sx class G and 169 sx Class G in 8-1/2" hole which gives 4410 feet of cement. 4^1/2" 12.6# 13Cr80 set and cemented with 102 sx class G in a 6-1/8" hole which gives 100 feet of cement. 4-1/2" 12.6# 13Cr80 tubing set ® 10,563'. Packer ® 10.445' 14-37 20" 91.5# H-40 conductor set and cemented with 2150# of poleset in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx CS III and 600 sx class G a top job was performed with 200 sx CS II. 9-5/8" 47# L-60 production casing was set and cemented with 880 sx class G in a 12-1/4" hole. This gives 2600' of cement. 7" 29# L-80 liner was set and cemented in place with 300 sx class G, the liner lap was cemented with 150 sx class G liner set in 8-1/2" hole. A CBL ran 10/88 shows the liner fully cemented. 4-1/2" tubing set ® 9426' with a packer at 9300' 14-36: Spud date: 12/83 20" 91.5# H-40 conductor set and cemented with 375 sx PF II in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx Fonda and 400 sx PF C in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx class G and 300 sx of CSI in a 12 1/4" hole. This puts 2350' of cement. 7" 29# L-80 set and cemented with 300 sx of class G in a 8-1/2" hole, fully cemented per 1/84 CBL 5-1/2" & 4-1/2" tbg set ® 8787' packer ® 8694' 14-05 Spud date: 1/92 20" 94.5# conductor set and cemented with 300 sx Articset in a 30" hole 13-3/8" 72# N-80 set and cemented with 4234 sx Permafrost in a 17-1/2" hole 9-5/8" 47# L-80 set and cemented with 1000 sx class G in a 12-1/4" hole this put 2980 feet of cement behind pipe. 7" 29# 13Cr80 liner set and cemented with 493 cu ft of class G in a 8-1/2" hole. A successful foam squeeze performed 7/92 to address a channel from 8994' to 9162'. In 7/93, a BPNL showed the channel went up to 8820' but no channel down. In 1998 a cretaceous leak caused the well to go to 100% WC required a RWO which installed a fully cemented 7" tieback. 4-1/2" tubing ® 8493' with packer ® 8380' 14-35 Spud date: 11/83 20" 91.5# H-40 set and cemented with 2050# Poleset in a 30" hole 13-3/8" 72# L-80 surface set and cemented with 1800 sx Foudu and 400 sx PF C in a 17-1/2" 9-5/8" 47# L-80 production set and cemented with 500 sx class G and 300 sx PF C in a 12-1/4" hole. This put 2950' of cement in the annulus. 7" 29# L-80 liner set and cemented with 334 sx class G in an 8-1/2" hole. Fully cemented per 11/83 CBL. 5-1/2" & 4-1/2" tbg ® 8554' with a packer at 8445' 14-20 Spud date: 6/81 20" 94# HA0 conductor set and cemented with 300 sx permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2800 sx Fonda and 400 sx PF and 138 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 & S95 production set and cemented with 500 sx class G in a 12-1/4" hole. This places 1470' of cement in the annulus. 7" 29# L-80 production casing set and cemented with 400 sx class G in a 8-1/2" hole. Per 6/81 CBL, fully cemented. 5-1/2" tubing @ 9091', packer® 9015' 14-41 20" 94# BTC conductor set and cemented with 2000# Poleset in a 30" hole 10-3/4" 45.5# surface set and cemented with 1050 sx CS III and 350 sx class G in a 13-1/2" hole 7-5/8" 29.7# NT95 production set and cemented with 1320 cu ft class G in a 9-7/8" hole. This places 1560 feet of cement in the annulus. 5-1/2" 17# 13Cr80 set and cemented with 1778 cu ft class G in a 6-3/4" hole. This places 1640 feet of cement in the annulus. Summary Hydraulic Fracture Program 120 AAC 25.283, a, 12) (Detailed program attached) Pump Schedule: Sirg. '.ga0r R61sy,rden Ywal1 ' + 1 V h - Wer f.11ae Ve . F,4rn Vir �1P Ions Yoluww lw. SIynY ihm Pwn1 Arte- Lane. ,.P S'— — i 6r- Pr.P I6Pm1 1Mr 2 P— rr.. ro 1 urwlr adfm6C r.a3J-x 1,w.niF'r 1• 4200 4200 1000 1000 4200 000 1000 1800 INR 0 ....116"l 0 p 5 2000 2000 ! brrWvm 4Y OF 010 6,010 200 1200 610 6Aq 200 1200 INA 0 0 Y 20 100 2100 3 Ped H61.4rax 1000 OA40 230 1430 t= 8,90 238 1430 IWI 0 0 0 20 Ifl 2219 141 Tn1 YfR•lrG 120D A2W 11a1 2038 4200 O.2W 10V0 2438 INA 0 0 R 20 500 2719 B S 09a<an.wa Ok.=n YF47i !)220 0 740n 2VU >1AlIM0 0 0 4538 953 B IIAM I 0 I%= 73080 i 2V0 0 fl 6536 153 B IW IW 0 D 0 0 q 20 a 0 1050 30,00 3T 69 BT 69 6 PprYA Yt/Ie10 AW M!0 500 5038 + 2,103 2110 500 5038 1W6 0 0 0 30 1500 8263 t PM 0V711.a0 01100 '20,010 2000 7030 8A00 ft= 2000 7030 IW 0 0 0 10 067 8336 fl " QTn.0 2A06 81,700 971 1516 1 2,110 31010 500 7530 IN30—d 1 2,f1pB 2000 30 167 9102 3 YF12774-0 t2F1 34A36 660 :176 3,1p 3UR 75.0 920.8 16130—d 1 0,313 10321 30 250 8352 Y3 KF 01F6.0 3276 37x77 I 785 8961 4200 31AO 1CV0 9288 '16130.s 6 19-706 30108 30 333 9016 11 'Jtf Y74A44 0201 41.181 1PA9 1.!1510 SAN 40,410 2250 1.1538 •0130,,M 6 55393 85500 30 750 IOC 36 0 711' 17121}1117 4316 44310 IIB2 11832 7,910 "" 1750 1320.8 118711 rrM 0 93063 120,560 30 503 ll0fl rl flalh O7YIY2.J0 3M 63,706 800 12632 3311 34710 000 1,9008 IWl 0 6 126,589 30 267 1488 M RA 4T7t7 7A60 MAN 030 13082 � 33M 8200 800 'ABB.8 IW 0 0 128589 30 267 11552 q..w V.W—R— Pad WSOOO 216% 54ry faJ 36MO 769% 4851110 13451bN1 P'WPMI Conexnn ,—R.I. A.P-7-6 10108 234% Pioppwv.>6ppY 98476 766% TIA 126586 64.W I P.—., — Nn I1W.11— NxPayT..", 20 R I -) SAM FA.df6eW0 2426 M.1x W f1.eW,ww.nlz kwp—. 1.000 P.-- rmr lapvrx R.qui.m'rni 1379 bbbi, 728580 b, 66i.dv�epp-+ 64865 YF128FIax0 oxxahs: RBB21Y�B a0•^U J6Uq fcndekPU M702Itiarul JSn Iu.A F703:1a.Sda.l L0641LIy ;.x1 L06515aJ.IJb:in1 561Qre r,uy+d &+Jnl MF120 avrn-hs: FV] ISwfacim�l to6/Iuey9.abAcx7 LOBS IR J.hl�ban] M2751�dd.1 J5691Env�s1-edda�xl Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 5500 psi Anticipated half length: —340' TVD Frac top: 8647' MD Frac top: 8954 TVD Frac bottom: 8709' MD Frac bottom: 9025' 64 22C LM 4 O l00 2 00 100 U 0 OS -e 0 B 00 100 200 L 030 05-60 0 The above values were calculated using modeling sof4rare. Surface pressure is calculated based on a closure pressure of —0.57 psi/ft or 4900 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the harder Sag formation and the softer confining layers. Average confining layer stress is 0.655 psi/ft. Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values we used, a half length of 340' is expected. Pressure Test Information (20 AAC 25.283, a, 7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4400 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treatin Pressure: Stagger Pump Kickouts between: Global Kickout: IA pop-off set pressure: 7000 psi 6300,psi and 6650 psi 90% to 95% of MATP 6650 psi (95% of MATP) 3000 psi (759/6 of MIT -IA) Treating line test pressure: Sand Requirement Minimum Water Requirement IA Hold Pressure OA 8000 psi 130,000# 16/30 Sand 1600 bbis (pump schedule: 1400 bbls) 2500-3000 psi Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. .r Nm —� 14-24 Rig Up "\\ Innu Annulus Line _..ei,nt�. r DMUIfMsEiFICI -. ���'1♦i! p¢mp ForL4prau:s p cool FMTMk Frail Bad Free Talk L _ rr� •rte �. J Chemical Disclosure (20 AAC 25.283, a, 12) MOM IYF1!25FLEXI):WFt25 54,471 Gal Contains: Water, AntiFoam Agent, Surfactant, Breaker, Stabilizing Agent, Gelling Agent, Crosslinker, Clay Control nt, Scale Inhibitor, Additive, Gmtedelde, Pro"d,n &"t The rorol volume h"s�ed.n the rabks above mpresentr Me summation of woler aM adtlilivex Wahr is supplktl b, tlienc 14808-60-7 _" _ Water acludlnAa1x Wator Su plled iIMC ton90 __ Ciystalllne 51PIca _ _ 91053.39.3 _ Guar gwlt _ " _ 75.574 Te_ methylamnoonEum chloride 107-21-1_ Ethylene Glycal 36.7D•d — — — Sorbitol PolYp{paYlen;�,IYeal _ 25322-69-4 772'I -P" Diammonium peroxidisulphate 12464$-0_1.7_ _ 2-Propeno_m acid, polyrmer with sodium_ phos_phinate � k311�78-2 � sodium hydroxide 67-63-0 _ _ PrelTan-2•al 111-76-2 2-bulturyek anol 25038-72-6 Vinrli$enr chlaride�muthyPacryla[e capalYrner 11138.66.2 Gum,aanthen _ �C 1T-13. alwlrol ethYoylated -_ 34398-01-1 BEOJ. - U_ near CII ilcohal elhaxylate Deal 7r.I 7 s4 S SodluM chloride 91053.39.3 _ _ Diatomaceous earth, calcined 100~1.5;•4 Colclurn ch Parkie — 10377-60.3 _ M Veswn nl trate 7631-86-9 Non-croralhne silka (Impurity) M72 554 5-chloro-2•meihyi•2Pi•cso0i[arolo9-3 erre 1786-30-3 _ Mngne iim ch€orcde axYdle Lhanol 9002_84-0 polyllerraflu oraethylene) 14807-96-6 _ Mavl53 irn vp ate hydrate utak:] 2662-20-4 2•metbyl-2h-isothraxol•3-ane 111464.461Crisrabal�te 22 % ji4 < 0.1 % <01 % '0.1 <0.1 <0.1 % <0.1 % < 0.1 % <0.1 % _% _ N_w <0.01 % <OAU % <4AD1 % <4A01 % u.Dut % <OADY % Loepp. Victoria T (DOA) 11� li■il - ■ w� - �I From: Loepp, Victoria T (DOA) Sent: Friday, January 23, 2015 3:58 PM To: 'Wages, David' Subject: PBU 14-24(PTD 183-091, Sundry 315-037) Fracture Stimulation David, Verbal approval is granted on this fracture stimulation sundry. You may proceed with the stimulation. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 V-1c1.Q a.Lq p.@aiaska,goy CONFIDENr1ALITY NOTICE This e -mall message, Including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended reciprent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding It, and, so that the AOGCC is aware of the mistake in sending It to you, contact Victoria Loepp at (907)793-1247 or Vicloria-Loe p(ayalas`a.o©v Loepp, Victoria T (DOA) From: Wages, David <David.Wages@bp.com> Sent Friday, January 23, 2015 12:55 PM To: Loepp, Victoria T (DOA) Subject: 14-24 Fracture treatment notification update Attachments: AOGCC Notification.docx Victoria, Per our conversation, Attached is an update notification letter. Updates include: Treesaver pressure rating: 10,000 psi ✓ Results of the pressure tests: MIT -T to 4400 psi, MIT -IA to 4000 psi on 1/20/15. Treating pressure, IA pressure and OA pressure will be monitored in the frac van. ✓ Added: Statement of no water wells within % mile of subject well. . Affidavit notifying partners and landowners of planned operations. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK ck-no 4R,444,te— 1. i.3 !s{ Loeee. Victoria T (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, January 22, 2015 5:37 PM To: Loepp, Victoria T (DOA) Subject: Fwd: 14-24 frac Victoria, This is about the fiaction sundry we probably received this afternoon. Thanks Chris -------- Original message -------- From: "Wages, David" <David.Wages@bp.com> Date:01 /22/2015 5:00 PM (GMT -09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: Subject: RE: 14-24 frac Hey Chris, We are out of the office tomorrow so I will be available on the cell phone, number below. Thanks David Wages o. 907.564.5669 c. 713.380.9836 W I E -AK From: Wallace, Chris D (DOA)[mailto:chris.wallace@alaska.gov] Sent: Thursday, January 22, 2015 9:00 AM To: Wages, David Subject: RE: 14-24 frac David, I do understand. I have started reviewing the information. I may have missed it on my first pass but I did not see - so please verify: (a) (8) pressure ratings and schematics for all equipment? Not seeing the wellhead and any isolation by a tree saver/goat head etc and the pressure ratings. (d) treating lines and schematic showing pressure relief (s) and shut down protocols? (f) how the IA and OA will be monitored and pressure relief (s) set? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Wages, David [maI1to:David.Wages@bn,com Sent: Thursday, January 22, 2015 8:39 AM To: Wallace, Chris D (DOA) Subject: RE: 14-24 frac Will do today, I just wanted to be able to get started as we are on a time crunch. Thanks David Wages o. 907.564.5669 c. 713.380.9836 W I E -AK From: Wallace, Chris D (DOA)[mailto:chd_s.wallace(aalaska.govI Sent: Thursday, January 22, 2015 7:08 AM To: Wages, David Subject: RE: 14-24 frac David, Thank you for the information. Please deliver to AOGCC (via courier or mail) a hardcopy original signed, and a hardcopy copy signed. We cannot process electronic submissions at this time. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.waIlace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Wages, David [ma ilto:David .Wageaftp.com] Sent: Wednesday, January 21, 2015 5:30 PM To: Wallace, Chris D (DOA) Subject: RE: 14-24 frac Chris, I apologize for the delay. Please find the attached documents including the 10-403 form, the detailed procedure and the document meeting the requirements per the new hydraulic fracturing regulations. If you have any questions, please let me know. David Wages o. 907.564.5669 c. 713.380.9836 W I E -AK From: Wallace, Chris D (DOA) [rnailta:chris.wallace -laska.gov] Seat: Wednesday, January 14, 2015 3:42 PM To: Wages, David Subject: RE: 14-24 frac David, We look forward to receiving it. Signed original plus a copy. Remember to make sure if there is a request for a variance — state the waiver requested in the cover letter, and go into the detail of the justification in the body of the sundry application. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.eov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Wages, David frnailto:D vId,M,ge5(6bo.C9rW Sent: Wednesday, January 14, 2015 3:34 PM To: Wallace, Chris D (DOA) Subject: 14-24 frac Hey Chris, This is David Wages with BP. We had spoke on the phone around the end of December about the new frac regulations. We've got a well to be frac'd on our schedule for the 25"' of January, so next weekend. Since we had our meeting, I've finally been able to get most of what we need together but I was wondering if I could get this to you tomorrow, if I might be able to get it moved to the top of your pile. I apologize for the late notice, but I wanted to let you know of this well. Thank you, If you have any questions or issues with the submitted paperwork, please let me know. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK 4 Lil Iv 5 _ . co � V W 0- m In m .. q m o2S 0 I fmw ce STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ;,•(�� N -2-i4 Re: THE REQUEST OF ARCO ALASKA, ) Area Injection Order No. 4 INC. for an Area Injection ) Order for that portion ) Eastern Operating Area of the Prudhoe Bay Unit ) Prudhoe Bay Unit �,� ��►} commonly known as the ) Eastern Operating Area ) July 11, 1986 IT APPEARING THAT: 1. ARCO Alaska, Inc. (ARCO) requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non -hazardous oil field waste fluids. 2. Notice of an opportunity for a public hearing on July 16, 1986 was published in the Anchorage Times on June 9, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hear- ing. FINDINGS: 1. An order permitting the underground injection of non -hazardous fluids on an area basis, rather than for each injection well individually, provides for effi- ciencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The Eastern Operating Area constitutes a compact "proj- ect area" for the operation of a portion of the Prudhoe Bay Unit and can readily be described by governmental subdivisions. The Project .Area is operated by a single operator. 3. The Project Area encompasses approximately the eastern one-half of the Prudhoe Oil Pool and -al-1 of the Lisburne Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery from this portion of the Area Injection Oraer No. 4 Page 2 July 11, 1986 Prudhoe Oil Pool, and from all of the Lisburne Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for disposal by injection into Cretaceous and Tertiary strata of oil field waste fluids developed from the operation of this portion of the Prudhoe Bay Unit. 4. The vertical limits of injection strata and the con- fining formations may be defined in the ARCO (Atlantic Richfield -Humble) Prudhoe Bay State Well No. 1 and the ARCO Sag River State Well No. 1. 5. Within the Project Area, injection into, through, or above a fresh water aquifer or underground source of drinking water will not occur. 6. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. Less stringent requirements for well construction, operation, monitoring and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to in- jection strata, the mechanical integrity of an in- jection well should be demonstrated periodically and monitored routinely for disclosure of possible abnor- malities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: UMIAT MERIDIAN T12N R14E Sections 22, 23, 24, 25, 26, 35 and 36 ,SGAl•ZNELr JUN 3 0 2004 Area Injection Oyuer No. 4 Page 3 July 11, 1986 T12N R15E Sections 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35 and 36 T12N R16E Sections 28, 29, 30, 31, 32, 33 and Section 34: W 2 NW 4, SW 4f SW 4 SE 4 T11N R14E Sections 1, 2, 9, 10, 11, 12, 13, 14, 15, 16, 21, 22, 23, 24, 25, 26, 27, 28, 33, 34, 35 and 36. T11N R15E Entire Township. T11N R16E Section 2: SW A, NW 4f SW k, S k SE 4 Sections 3, 4, 5, 6, 7, 8, 9, 10, 11 Section 12: NW k, S k NE 47 SE 4, SW 4 Sections 13, 14, 15, 16, 17, 18, 19, 20, 21, 28, 29, 30, 31, 32 and 33. TION R14E Sections 1, 2, 3, 4, 9, 10, 11, 12, 13, 14, 15, 16, 21, 22, 23, 24, 25, 26, 27, 28 and 36. T10N R15E Entire Township T10N R16E Sections 4, 5, 6, 7, 8, 9, 16, 17, 18, 19, 20, 29, 30 and 31. Rule 1 Authorized Injection Strata for Enhanced Recove Within the affected area, non -hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in ARCO (Atlantic Richfield -Humble) Prudhoe Bay State No. 1 between the measured depths of 8110 feet and 8680 feet for the Prudhoe Oil Pool and between the measured depths of 8790 feet and 10,440 feet for the Lisburne Oil Pool. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non -hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in ARCO Sag River State Well No. 1 between the measured depths of 1900 feet and 6750 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service UVINNElk Qful< << f 200. Area Injection Oraer No. 4 Page 4 July 11, 1986 well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Pumping of excess non -hazardous fluids that are developed solely from well operations, or necessary to control the fluid level of reserve pits, into surface/production casing annuli is exempted from the above requirements. Rule 4 Monitoring The Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly as a routine duty to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Tubing/CasingAnnulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observances or pressure tests indi- cate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25.105. Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission's satisfaction that sound engineering practices are 7/25/86 Revision &CANNED JUN. (' G 20CZ1 Area Injection Oraer No. 4 Page 5 July 11, 1986 maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated July 11, 1986. Oil, q.� atter o w Alaska Oil and as Conservation Commission 166nnie C. Smit!h,`_-Qommissoner r=O C�,.� Alaska Oil and -Gas Conservation Commission Alaska Oil and Gas Conservation Commission Hydraulic Fracturing Fluid Product Component Information Disclosure Hydraulic Fracturing Fluid Composition: Job Start Date:2/2/2015 Job End Date:2/2/2015 State:Alaska County:Beechey Point API Number:50-029-20970-00-00 Operator Name:BP America Production Company Well Name and Number:14-24 Longitude:-148.59095600 Latitude:70.24270640 Datum:NAD27 Federal/Tribal Well:NO True Vertical Depth:8,660 Total Base Water Volume (gal):93,346 Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments Proppant Transport Schlumberger Antifoam Agent, Surfactant , Breaker, Gelling Agent, Crosslinker, Clay Control Agent, Scale Inhibitor, Additive, Bactericide, Propping Agent Water (Including Mix Water Supplied by Client)* NA 85.09231 Crystalline silica 14808-60-7 96.27887 14.35296 Guar gum 9000-30-0 1.56409 0.23317 Ethylene Glycol 107-21-1 0.53039 0.07907 Tetramethylammonium chloride 75-57-0 0.47695 0.07110 Sodium hydroxide (impurity)1310-73-2 0.13323 0.01986 Diammonium peroxidisulphate 7727-54-0 0.12096 0.01803 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.11236 0.01675 2-butoxyethanol 111-76-2 0.09246 0.01378 Propan-2-ol 67-63-0 0.09246 0.01378 Gum, xanthan 11138-66-2 0.05864 0.00874 Ingredients shown above are subject to 29 CFR 1910.1200(i) and appear on Material Safety Data Sheets (MSDS). Ingredients shown below are Non-MSDS. Total Base Non Water Volume:0 * Total Water Volume sources may include fresh water, produced water, and/or recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Linear C11 alcohol ethoxylate (7eo) 34398-01-1(7EO)0.04623 0.00689 Linear C11 alcohol ethoxylate (3eo) 34398-01-1(3EO)0.04623 0.00689 C12-15 alcohol ethyoxylated 68131-39-5 0.04623 0.00689 Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.04278 0.00638 Sodium tetraborate 1330-43-4 0.03751 0.00559 Sodium chloride 7647-14-5 0.02269 0.00338 Diatomaceous earth, calcined 91053-39-3 0.01282 0.00191 CALCIUM CHLORIDE 10043-52-4 0.01147 0.00171 Non-crystalline silica (impurity)7631-86-9 0.00392 0.00058 Dimethyl siloxanes and silicones 63148-62-9 0.00288 0.00043 Magnesium nitrate 10377-60-3 0.00256 0.00038 Siloxanes and Silicones, di-Me, reaction products with silica 67762-90-7 0.00183 0.00027 5-chloro-2-methyl-2h- isothiazolol-3-one 26172-55-4 0.00137 0.00020 Magnesium chloride 7786-30-3 0.00128 0.00019 2,2''-oxydiethanol (impurity)111-46-6 0.00121 0.00018 poly(tetrafluoroethylene)9002-84-0 0.00061 0.00009 Magnesium silicate hydrate (talc)14807-96-6 0.00050 0.00008 2-methyl-2h-isothiazol-3-one 2682-20-4 0.00042 0.00006 Sorbitan stearate 1338-41-6 0.00035 0.00005 Potassium chloride (impurity)7447-40-7 0.00036 0.00005 Cristobalite 14464-46-1 0.00026 0.00004 Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 68308-89-4 0.00018 0.00003 Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 68937-55-3 0.00018 0.00003 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2- hydroxyethyl 2-propenoate 36089-45-9 0.00018 0.00003 Sorbitan monooleate, ethoxylated 9005-65-6 0.00006 0.00001 Sodium carboxymethylcellulose 9004-32-4 0.00005 0.00001 Tetrahydro-3,5-dimethyl-1,3,5- thiadiazine-2-thione 533-74-4 0.00004 0.00001 Sodium nitrite 7632-00-0 0.00004 0.00001 1,2-benzisothiazolin-3-one 2634-33-5 0.00002 .s.;or Tk hw\*�\�//y,:s?. THE STATE Alaska Oil and Gas ofALASKA Conservation Commission _:=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Q. Fax: 907.276.7542 www.aogcc.alaska.gov David Wages Well Interventions Engineer SCANNFV FEE 2 2015 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-24 Sundry Number: 315-037 Dear Mr. Wages: 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. Variance to 20 AAC 25.283(a)(3-4) is GRANTED per Finding 5 of AIO 4. Variance to 20 AAC 25.283 (d) is GRANTED. 20 AAC 25.283(d) requires that a pressure relief valve be installed on the treating line between the pump and the wellbore, and requires that the well be equipped with a remotely controlled shut in device. Information supplied on the automatic and manual pump shutdown parameters provides at least an equally effective means of complying with the requirement of protecting the surface equipment and wellbore from overpressure. 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, Daniel T. Seamount, Jr. / Commissioner DATED this Z1 day of January, 2015 Encl. l- RECEIVED JAN 2 2 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate 0 ' Alter Casing❑ Other Fracture 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. Exploratory ❑ Development El 183-091-0 - 3 Address: Stratigraphic ❑ Service ❑ 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20970-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU 14-24 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028312 PRUDHOE BAY, PRUDHOE OIL • 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). 9586 9203 9032 8715 9032 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 • 30.5-110.5 30.5-110.5 Surface 2502 13-3/8"72#L-80 30-2531.68 30-2531.6 4930 2670 Intermediate 8947 9-5/8"47#L-80 27 25-8974.02 27.25-8664.17 6870 4760 Production None None None None None None Liner 926 7"29#N-80 • 8660-9586.36 • 8384.84-9202.98 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"Baker FHL Packer Packers and SSSV MD(ft)and TVD(ft): 8623.83,8352.22 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work. 1/25/15 Commencing Operations. `1 Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. GSTOR El SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Wages Email David.Wages@BP.Com Printed Name David Wages Title Well Intervetions Engineer Signature Phone 564-5669 ate Prepared by Garry Catron 564-4424 �, Z�1t5 COMMISSION USE ON Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3\S- 037 Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test ❑ Location Clearance El Other: /er ii ) Forvvra- fi'oh rc-f L"r<d to ti-, c Era 6Fccus aLz4' r`cs1 13)5CJO5 t1rc 1rgi5tr.y wbvtu .fraCfocus . er a5 well a5 reT IV-ervir,-ifs of ,2c ifi`1-C-2i-5' z/ 3 . Vo_r r.t-K,:_..,_ --(--r, 2 AMC- L7 2.6 3L` �- ;¢ _ , 'S A r'ci i�-1,----J a_✓ r-i Ytc-4r Vlk 5- u I /14-c% cT. Spacing Exception Required? Yes El No Subsequent Form Required: /e - 1 p 4- APPROVED BY ' Approved by: ' 1 COMMISSIONER THE COMMISSION Date: 27 ( S vi;L l i2 // OIIGINAL Form 10-403 Revised 10/2012 ACpproved applicais valid for 12 months from the date of apeLoval. Submit Form and Attachments in Duplicate RBDMS-AA JAN 2 7 2015 ..%.D (•z3./s' JUNK SUMMARY ADL0312828 SW_NAME MEAS_DEPTH RUN DATE COMMENTS TVD 14-24 9180 12/21/2000 SL Tool String, OAL 33' 8845 14-24 9180 5/29/2012 Kinley Cutter 8773 14-24 9180 6/25/2012 Go Devil, OAL 55' 8773 14-24 9576 6/19/1997 TEL Trigger 9122 14-24 9581 3/29/1994 IBP 9126 Perforation Attachment ADL0028312 Well Date Perf Code MD Top MD Base TVD Top TVD Base 14-24 11/28/12 APF 8960 8968 8652 8659 14-24 11/28/12 APF 8968 8978 8659 8668 14-24 11/28/12 APF 8978 8980 8668 8669 14-24 11/4/12 BPS 9125 9145 8797 8815 14-24 11/4/12 BPS 9161 9173 8829 8839 14-24 11/4/12 BPS 9173 9183 8839 8848 14-24 11/4/12 BPS 9183 9186 8848 8851 14-24 11/4/12 BPS 9186 9197 8851 8860 14-24 11/4/12 BPS 9202 9212 8865 8874 14-24 11/4/12 BPS 9215 9225 8876 8885 14-24 11/4/12 BPS 9225 9235 8885 8894 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 0 0 0 0 0 0 *cr op CO c0 CO CO 0 = J Z J J J a) Q O 0 0 0 0 CD co so N r CD 00 N O CO LU N p V N- N N- CO U CD Co 0 0 0 CD CO CO M V 't CO W N- CO CO 00 CO I'- a)N N -i• CO N CO CO 0 CO N QO N tt M > 0o CT N CO CO H Q 0 Ln _ ~ I� CO O M Ln CO N CO CO CO N > CO CO L H N E co oco _ N- 0o M o 0 (n O Q 000 Lr) N CO CO 00 C J •— O c 0 CD C000LU U Q M N O CO CO N CO CO O 0 CO CO O CO 0 , 00 = J CO J J Z co *k N tor-- "Cr) rn C7� OD CV CO - tf) - i":;")". CV O co t) L_ N 0 CO O CO C CO CA a LU J a0 co W Cr Q m0 Q C73 0 w U O a c u_ Z Z Z LU co co O H Z D > 0 &- U) HH TREE= 5"FMC 120 S,. Y NOTES: T x IA LEAK AT SSSV NIP.FHL/ !W -LHEAD= GRAY 14_2 4 TWI-HBBP PKR WAS SQZ'D WI CEMENT 12/14/93 (ACTUATOR= BAKER A PETAL KB.ELE 72 BF.8 8/= 2143' _45-1/2"CAM BAL-0 SSSV NP,ID=4.562" (COP= 5300' \ q,9000' 2143' —163"FRAC SLV,D=3.80"(03/25/13) Max Angle= 29 Mr Datum MD= 9210' / GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TY FE VLV LATCH PORT DATE 1 2903 2903 1 CA DMY RK 0 03/24/13 13-3/8"CSG,72#,L-80 BT&C,D=12.347" H 2532' H , 2 4817 4817 1 CA DMY RK 0 03/24/13 L I3 6215 6139 27 CA DMY RK 0 02/10/00 y 4 7206 7037 23 CA DMY RK 0 03/24/13 5 7757 7550 21 CA DMY RK 0 08/27/00 9-5/8"CSG,47#,L-80 XO TO US-95 BT&C --i 8137' X X 6 7819 7608 21 CA DMY RK 0 06/30/83 7 8126 7895 21 CA DMY RIC 0 12/28/12 8" 8197 7961 21 CA DMI RK 0 06/30/83 9" 8462 8205 24 CA DMY RIC 0 02/10/00 Minimum ID =3.625" @ -8522' 10" 8531 8268 25 CA DMI RK 0 06/30/83 TOP OF CEMENT SHEATH "CEMENT IN MANDRELS-UNABLE TO PULL 40../I �I:rI —8527-"'8760 CEMENT SHEATH,MILLED TO 3.625" �' ► ►� I.,,v e DRILLED OUT 8525'-877V(03/2/94) 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" H 8614' 7C ,I, RI ,0W V 8600' H5-1/2"BKR PBR ASSY 14 49 10k 8614' H5-1/7 X 4-1/2'XO,D=3.958" MI 1 ►�� 8624' H9-5/8"x 4-1/2"BKR FHL PKR ►'i% TOP OF 7"LIR —{ 8660' ''A: I. a 4` 8692' H4-1/2"CAMCO DB-6 LANDING NP,D=3.813" 60 g V 8705' H4-1/2"BKR SHEAROL/T SUB ifs 6 ►4 41 0.r ,`, 8706' —4-112"WLEG,D=3.958" 4-1/2"TBG-PC,12.6#,N-80,.0152 bpf,D=3.958" H 8706' ►A, : 8685' H ELM)TT LOGGED 08/27/83 9-5/8"CSG,47#,US-95 XO TO L-80 BT&C—{ 8972' 1-----.X 9-5/8"CSG,47#,L-80 BT&C,ID=8.681" H 8974' }--, I ' I 9032' ELM --I ESTIMATE TOC CAP 11/04/12) PERFORATION SUMMARY ww..,,,'411.4441,4,i 9059'ELM --I TOP OF SAND(11/04/12) REF LOG: BRCS ON 06/26/83 ANGLE AT TOP PEW:28°@ 8960' 9177' -4COLLASPEO LNR(01/13/01 VIDEO),PASSED Note:Refer to Roduction DB for historical perf data THRU RESTRICTION w/2.6"BELL GUIDE 12/27/06 SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-1/2" 6 8960-8980 0 11/28/12 I ? IHFISH-KNLEY CUTTER,OAL 52'(05/29/12) 2-1/2" 5 8968-8978 0 03/06/03 — I ? I FISH-SL T-STRING;FLAT BTM GO-DEVEL 2-7/8' 6 9125-9145 C 11/06/10 1&CA CENTRALIZER ARMS (06/26/12) 33/8" 4 9161-9186 S 12/06/94 04/04/00 ? —FISH SL TOOL STRING,OAL 33'(12/21/00) 3-1/8" 4 9161-9197 S 03109/84 04/04/00 3-1/8" 4 9202-9212 S 03/09/84 04/04/00 r ��+ 9249' --I CEMENT CAP 2-7/8' 4 9202-9212 C 12/12/00 31/8" 4 9215-9235 C 03/09/84 04/04/00 9676' —1--I FISH-TR.TRIGGEFt 3.75'X 1.40'X 40' —I — = 9581' H FISH-BP PBTD —1 9547' ‘14.1400.• 7"LW,29#,N-80 BT&C,-0371 bpf,D=6.184" H 9584' mgc AN DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/30/83 MIN 176 IMTIAL COMPLETION 04/29/13 LER PJC PULL RBR SET FRAC SLV(3/25/13) WELL: 14-24 11/29/12 SET/JM) REFERF(11/28/12) PERMT No: 1830910 01/06/13 RKT/PJC SET BR RILL FRAC SVL(12/28/12) AR No: 50-029-20970-00 01/08/13 PJC CMT SHEATH CORRECTION SEC 9,T1ON,R14E,1519'RI_&1992'FEL 02/20/13 MN/JMJ TREE C/0(02/11/13) 04/29/13 LEF!PJC GLV C/0(03/24/13) 8P Exploration(Alaska) Date: January 14, 2015 Subject: 14-24 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Sag interval of well 14- 24. 14-24 is a vertical well in the East Waterflood area. The Ivishak has been temporarily isolated with a sandback and cement cap. An isolated sag well test was attempted to confirm watercut and GOR. Unfortunately, the Sag did not produce even with 1500 psi drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivity. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages Per plat above, the following wells have been reviewed for casing and cement information: - 14-43: Spud Date: 10/21/1992 20"91.5#, H-40 Conductor set and cemented with 2000#Coldset II in a 30" hole 10-3/4" 45.5# NT-80 Surface casing set and cemented with 1978 cu ft of CS II and 403 cu ft class G in a 13-1/2" hole. 7-5/8" 29.7# NT-95 Production casing set and cemented at 1179 cu ft class G in a 9-7/8" hole. TOC @ 5580' per 10/92 CBL. 5-1/2" 17# 13 Cr80 set and cemented with 125 sx class G in 6-3/4" hole. Fully cemented to 7-5/8" casing per 11/92 CBL 4-1/2" 13Cr80 tubing @ 8933', Packer @ 8872'. 14-19: Spud Date: 6/8/92 20" 94#H-40 conductor set and cemented with 232 sx of SA II in a 32" hole. 13-3/8" 72# N-80 surface casing set and cemented with 3000 sx AS Ill and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-801S0095 production casing set and cemented with 500 sx Class G in a 12-1/4" hole which gives 1950'of cement. 7" 26# L-80/13Cr80 liner set and cemented with 435 cu ft of class G cement in a 8-1/2" hole which gives 2640'of cement. 4-1/2" & 3-1/2"tubing set @ 9576', packer @ 9507' 14-18 Sidetracked 2007 20"94#H-40 conductor set and cemented with 300 sx Permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2615 sx Fondu and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx of class G in a 12-1/4" hole which gives 1500'of cement. 7"26# L-80 liner set and cemented with 437 sx class G and 169 sx Class G in 8-1/2" hole which gives 4410 feet of cement. 4-1/2" 12.6# 13Cr80 set and cemented with 102 sx class G in a 6-1/8" hole which gives 100 feet of cement. 4-1/2" 12.6# 13Cr80 tubing set @ 10,563'. Packer @ 10.445' 14-37 20" 91.5#H-40 conductor set and cemented with 2150#of poleset in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx CS Ill and 600 sx class G a top job was performed with 200 sx CS II. 9-5/8" 47# L-80 production casing was set and cemented with 880 sx class G in a 12-1/4" hole. This gives—2600' of cement. 7" 29# L-80 liner was set and cemented in place with 300 sx class G, the liner lap was cemented with 150 sx class G liner set in 8-1/2"hole.A CBL ran 10/88 shows the liner fully cemented. 4-1/2"tubing set @ 9426'with a packer at 9300' 14-36: Spud date: 12/83 20"91.5#H-40 conductor set and cemented with 375 sx PF II in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx Fonda and 400 sx PF C in a 17-1/2" hole • 9-5/8" 47# L-80 production casing set and cemented with 500 sx class G and 300 sx of CSI in a 12- 1/4"hole. This puts 2350'of cement. 7"29# L-80 set and cemented with 300 sx of class G in a 8-1/2" hole, fully cemented per 1/84 CBL 5-1/2" &4-1/2"tbg set @ 8787' packer @ 8694' 14-05 Spud date: 1/92 20" 94.5#conductor set and cemented with 300 sx Articset in a 30"hole 13-3/8"72#N-80 set and cemented with 4234 sx Permafrost in a 17-1/2" hole 9-5/8"47#L-80 set and cemented with 1000 sx class G in a 12-1/4" hole this put 2980 feet of cement behind pipe. 7"29# 13Cr80 liner set and cemented with 493 cu ft of class G in a 8-1/2" hole. A successful foam squeeze performed 7/92 to address a channel from 8994' to 9162'. In 7/93, a BPNL showed the channel went up to 8820' but no channel down. In 1998 a cretaceous leak caused the well to go to 100%WC required a RWO which installed a fully cemented 7"tieback. 4-1/2"tubing @ 8493'with packer @ 8380' 14-35 Spud date: 11/83 20"91.5#H-40 set and cemented with 2050#Poleset in a 30" hole 13-3/8" 72#L-80 surface set and cemented with 1800 sx Foudu and 400 sx PF C in a 17-1/2" 9-5/8"47# L-80 production set and cemented with 500 sx class G and 300 sx PF C in a 12-1/4" hole. This put 2950' of cement in the annulus. 7" 29# L-80 liner set and cemented with 334 sx class G in an 8-1/2" hole. Fully cemented per 11/83 CBL. 5-1/2" &4-1/2"tbg @ 8554'with a packer at 8445' 14-20 Spud date: 6/81 20" 94#H-40 conductor set and cemented with 300 sx permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2800 sx Fonda and 400 sx PF and 138 sx AS II in a 17-1/2" hole 9-5/8"47#L-80 &S95 production set and cemented with 500 sx class G in a 12-1/4" hole. This places 1470'of cement in the annulus. 7" 29# L-80 production casing set and cemented with 400 sx class G in a 8-1/2" hole. Per 6/81 CBL, fully cemented. 5-1/2"tubing @ 9091', packer @ 9015' 14-41 20"94#BTC conductor set and cemented with 2000# Poleset in a 30" hole 10-3/4"45.5#surface set and cemented with 1050 sx CS III and 350 sx class G in a 13-1/2" hole 7-5/8" 29.7# NT95 production set and cemented with 1320 cu ft class G in a 9-7/8" hole. This places 1560 feet of cement in the annulus. 5-1/2" 17# 13Cr80 set and cemented with 1778 cu ft class G in a 6-3/4" hole. This places 1640 feet of cement in the annulus. Affidavit of Notification(20 AAC 25.283, a, 1) All partners and landowners have been notified of operations planned for well 14-24. Plat Identifying Wells (20 AAC 25.283,a, 2,A-C)and Faults(20 AAC 25.283,a, 11) .,:.CI ... . e_4_.I.1.10044, i 4- sII _ ¢ �1, 19 B1 J �� r.; 19 r' J ti 300' , 24 :' 35 iC-15 . ... —550' \ ..\. I' '47--‘-. •,:.:----.---___;: 14- :,,,i.. .:rii,.. -,, - _„_____ . V.:::- --- . , pia:: 40 -`;. \11141114111111111111111111111 . ,. , , ..., -.. ., 1"...""` Fault at TSGR -r ♦ TD/bottom of Sag/Ivishak \ ',\: ' : : '', ' • :. • Top of Sag River 1 -F-06A 14-28A Wells within 'A mile of 14-24: 14-23 14-36 14-43 14-05 14-19 14-35 14-18 14-20 14-37 14-41 Per the plat above,there are no water wells within '/Z mile of the subject well. Three faults of concern as shown above are to the east(-300' away) and to the south and west(both —550' away). The maximum stress direction from log data runs almost due North-South, thus the primary fault of concern is the fault to the south. In order to ensure this fault does not affect the fracture treatment, the half-length of the frac will be designed to be —400'. The fracture and the frac fluid should not come in contact with the fault of concern. Exemption for Freshwater Aquifers (20 AAC 25.283,a, 3-4) Well 14-24 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within 'A mile radius per20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC .. 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a, 5-6) Well 14-24 was spudded on 6/15/83. A 17-1/2" hole was drilled to 2553' where 65 joints of 13-3/8" 72#, L-80, BTC csg w/ FS @ 2532 was run and cemented in place with 2000 sx Fondu and 400 sx of PF C cmt. After the BOP was NU and tested to 5000 psi, the casing was tested to 1500 psi for a passing MIT. After drilling the shoe, the casing was again tested to 11.1 EMW for another successful test. A 12-1/4" hole was drilled to 5252', the hole was reamed from 5075'-5252', continued to drill to production casing TD where more tight hole was encountered in several places requiring back- reaming. Once past casing set point, 220 joints of 9-5/8", 47#, L-80 and US-95 BTC csg with the Float shoe @ 8974' and cemented in place with 500 sx of Class G cmt. Casing was tested to 3000 psi for a passing MIT.After drilling out the shoe, a 11.4 ppg EMW test was successfully achieved A 8-1/2" hole was drilled to TD of 9586'. Openhole logs were run, two attempts at running FDC/CNUGR/Cal resulted in two stuck toolstrings. Both fish were recovered. 21 joints of 7", 29#, N- 80, BTC csg was run from 8660'-9586', the liner was cemented with 300 sx of class G cement. The cement was drilled to 9547' PBTD, the liner lap was tested o 3000 psi successfully. A CBL run 6/83 confirmed liner was fully cemented. After swapping well out to 9.6 ppg NaCI, the completion assembly consisting o f5-1/2"tubing was run to 8706'with the packer at 8624'. S LDL on 8/30/93 found that the packer was leaking, so a packer cement squeeze was required and cemented from 8522'-8760'. There are 10 gas lift stations in the well, the bottom one at 8531 is behind a cement sheath. A BPNL from 8/98 found a channel from the bottom perfs down to Zone 3 at 9348'. A sand back cement squeeze was performed in 4/00 and placed the TOC @ 9250' When re-perforations were shot on 9/00, the perf guns were left in the hole. They were successfully fished the next day. When shallower perforations were shot on 12/12/00, the perf guns were again left in the hole. The fishing tools were left as an additional fish across the bottom perforations (9202'), and neither were retrieved. Subsequently, a collapsed liner was identified at 9177', a drift and tag on 6/30/02 was able to get passed the collapsed section with a 2.25" centralizer, and the collapse doesn't appear to be detrimental. The 16' of Sag ad-perfs that were shot in March 2003 did not bring in any appreciable benefits. The caliper from 10/06 shows the 4-1/2" N-80 tbg to be in relatively good condition with a maximum penetration of 27" recorded in 1 joint. A 12/06 RST found the GOC at 9142'MD/8740' TVD. E-line was also able to recover the 24' of perf guns that had been lost downhole in 12/00. On 1/20/2015, a successful MIT-T was performed to 4400 psi, a successful MIT-IA was performed to v 4000 psi. Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283,a, 8) • _-__- 111311- 5'FI11C110 ..-__ —_. _ _ 8_888 WLit TAll GRAY 1 ■ 24 SAF NOTES:WASSQAKAT53SVNT12/1 / (; TW I-14813P PKR WAS SGZ'D WI CEM ENT 12/11183 ACR3ATOR: BAKFi4C INITIAL KB.E E 22' BF B-� 2143' i-�12'CAM BAL-O SSSV NP.B)=1562• 11 KnP 53001 1b.Aryls.. 29" 9000' 2147 1-163-rRAC SLY.Q=3.80'103r25-113l Gal an At) GAS Err MATCf4.S T)11um IVO- BSOO4S ST 1D'1VU(DEY 1YIt VLV LATD1 PORT GATE" J ' 1 2903 2903 1 C/4 CON RK 0 0312/1113 i 2 .38'CSC 729 L-60 BT&C II-12 34r f-{ 2532' . 7 4817 4817 1 CA t*r !a( 0 03/24113 L 3 6215 6139 27 CA OW 04C 0 027100 4 7206 7037 73 CA CAN 49( 0 03024713 5 7157 7.550 21 CA DRY RK 0 00&2710 i o-',-a- a ",1479,L,807%O F{3 0S,95 BT3C1 L 8137' '—•r - . X 6 7819 7608 21 CA phis` RK 0 106130183 ... �' 7 8176 7895 21 CA DAY RK 0 112728'121 9"18197 7961, 21 CA DM RK 0 0600183 9"18462 8205' 24 CA (JAY IK I 0 02/1003 [Minimum ID=3.625" -8522' 10"' 8531.8268. 25 CA OW RK 0 06130/83 TOP OF CEMENT SHEATH CEMENT'SMAPAGRE 8-UNABLE TO PULL y4 -8527--8760' CHYBIT SHEAM MLL®TO 3 625' i S 112'TBC 4C:,074 160,.073::6pr 10_4B.:" 8614..._.._; •` ' ORILL®0111>�26'-8778'(031/084) „, • r 8600' I5-Itt?BKRRBRASSY 1 ' ' '•r' k-.-1., L'.' - 8614 -{sire'X 4 82-xo n 3 f 541 1 8624' 19-578'x 4-1r!BKR TM_FKR j ••• '-.14 Lt V w 4 1T-41‘,±,..t^, 1,L, [R3PCF7-i 14,4 1-i 8680' -11' ' li 8692'...t4-1/2*CA 011817 C13-6 LOS:MGlF o=3813' , --.. -. . 8705' 1-11412 BKR SFEAROur Stb 1 4-tit'Tec.-Pc,12 so,N-60, 01524:4 . 0-3.956'j--1 8706' + y �-f 8706' 1--14-111W1G.L3=1956'} .._._...._�_: ! 6685' -r1?A 111 LOGGED0872741 1 9-5/6'CSG,4711,1k3 95 80 TOL 80 BTS(-� 8972 X — I _ — -- _ F4511" 4711 I-AnBT&'0=8.661' I L 8888--0'_8914' -8888 _.- _ ' 9032'ELM ESTtN1TETOC CAP 1104712)' RiaCRAT1pNSITMNARY ,.:.y., 9059'EL/IF-Foe GFSAno111Aw/211 (84LOG RICSON0926r83 ANGLE A T ICP HI4 78'94 8960' - .._ .. —._ ` C. i-9iy'' } WLLASPal L NFi(01/13N1 NICK-0)PASSED Note Refer to 110dvcmo GR to.hlc,orlcat perf(lata --- '- SItE SPT 4.TTRVAI Th14LJI4t5INiCIIONw2.6'BE1L GM._17127706 OP1VCpz 5Rf)T S(12..., w■. _� '-- .. _ - Z iFell-KIM.EY CUTTER.OA:_5 105'797121 7 117'' 6 8960-8983; U 11/26'12- - - . _.. _ .. 7-U2' 9 9998-8979 I 0 03'06/03 -_= 7 FV:II SI 7.STRINt; I A T BTM GO-UL-IR. 2-7/8 6 9125 91450 C 11/06'10 - 9CA PEfF(EN1RA1-{LERAW6 1:06.@61121 3.318' 4 91619186 S 12106/94 ;MYJ4'00 r"m"""'I 3 06' 4 9167 919T S (0:/09/84 04804X00 _ u ' 9 .__-i {FRl� >I 804)! STRMt;,CVit.33(12121p0Y 3 118' 4 9202-9212 S 03109184:041041311 .' '. 9241' 1.-CL1.F.N7 CAP ' FdaG7.21r4 9202-32)2. C t7;17100' ._.. -_-.. Sv5' 4 9215 9235 C 03r�09184 04/174110 9174' 4014-TR 196141144 3 75'K 1 40'x 40' 1 e [511 [ter M` I..{`ID. 141 7'L.N<i,299,N ilo 9160,.0371:.bpf 0-6 I!N-a-i-9683. 4'4.4*** ** 'm_}i 9586' � .. , DATE RHI 8Y 1"—CONNEICITS 1)A11 ' RP!tlrCx,*15 PRLOriEE BAY IMI 06130183 FINN178 INTIAL COMP'MON 0429113'LET.PIC ROLL RBR SET FRAC 5LY(3/251134 WH.L- 14-24 11129112 .#11.160 RFPERF 411.'79/121 !iR84T(kr 1830910 07106/13 1111117 PJC SET BFT PULL rRAC 5VL(1212E1,131 8888 _..__ _8888. AR No 50-029-70910-00 01108/13 PJC C.PATTfi CDlatelil7WI.. ;8_J,`ION R141:1519''Pt&1992'Fli -07720713 141.46.141) G[5 ATRIM T_� — — - 0429/13 I.FR PJC IGI V 4"JO(03724r13) . 888 8 -.. 1111'Exploration(Alaska) Name/Size Weight Grade ID Burst,psi Collapse, psi 13-3/8"Surface 72# L-80 12.347" 5380 2670 9-5/8"Production 47# L-80 8.681" 6870 4760 7"Liner 29# N-80 6.184 8160 7020 5-1/2"Tubing 17# L-80 4.892 7740 6290 Wellhead: 1111111111111111 /Ail 1{ r .. 1 - "MI - M git Pe I 1 , ARCO GE5-i,,6ELL-E Grey manufactured wellhead, rated to 5000 psi. Tree: 7-1/16" 5,000psi w/5-1/8" bore Tubing head adaptor: 13-5/8"5,000psi x 7-1/16" 5,000psi w/5-1/8" bore. Tubing Spool: 13-5/8"5,000psi w/3-1/8" side outlets Casing Spool: 13-5/8" 5,000psi w/3-1/8" side outlets Tree saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" The treesaver is rated to 10,000 psi. eTh 0 0 .6101it Immo mom • INEWEIEMIIq lp , 411111111111r - L • - 1\ Z. ) Imo .Z" Geological Frac Information(20 AAC 25.283,a,9) TVO Owth to GraPent Top .cress Stress Stress at Stress at Fkod Loss Zone(ft) Difference Gradate Top at Stress Bcoc, of CoeMoent Spurt Proopant from Surface ZonazoOG Moou-us Po,sson s (ft/roof Loss EmPearna'7. UM.) Os Layer 7 os ( " (p,, th4f.tos, Rato K-ic Om) gad1004,2, rs'At42, 2 aleD T31111 .17:MB ZION asoo 6018.1 1260000 0.34 2000.0 0.001280 00000 0.511000 2 8649.0 'er". •6509 EI05 EzzEn 0 600 6667.6 1 000000 0.32 2000.0 0.000630 3.00000 0.10000 4 'aila a025lonD mg. Egm gm= 3.E22 4854.5 .1.22222,2 2.22 22222 233E222 ?. 2.12222 6 j -40 aric - UM gum3.633 4995.6 2.532223 2.24 2222.2 3322323 3. 2.12222 6 1:11111ag - Ea= 6Z Eigm 0 600 5350 9 1.000000 0.29 2000.0 0. 630 3 00000 0 10000 7 MEINII ck HEM ME= 56r 21CC 1157€ 2E22.22: 224 22.222 222E2-2 2222:2 212222 IBM ra EU= MUM ISMEMI C1:= 4 2 321 2:332 3 3 -33:3 9 EOM a Eli= NEM 524'2 32 222:C C 32-'3'f.: 122323 10 fr7ZIEMI hubick- MEM 13 = COCE 0 600 50567 2.600000 023 2000 0 0004030 3 00000 0 10000 11 MIMI e MEM El= Hi= :EC: 02024 ',r3-23 22 23232 2 22-322 5 : 2232 12 .111"r. a 12 11=1. COEN mom 0 600 6183.6 2.600000 0.24 2000.0 0.005670 3 00000 0.10000 13 . '.0 .. as C-2- 2242 :223 1377'4 2E0232 252 Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program attached) Pump Schedule: '.,Stage Stage Fluid Tope Dean Cmm Corr Com 911pr1r Com Sharp Com P.o pnt T,pe Prop Rap I Cure Rate Prplsg Cr o.aa.Iptia Volae Clea Volume Clean Volt `ono Volo Shap Coro. Stage Rap (bend It.. Rrp (gall (ouR (WO (b60 (gall loan (65) (1451) (Pea) (ba) pa) Tee O PT,se k6 Treated Wale 0 0 0 1 Load hole Treated Wee 4200 4,200 100.0 100.0 4200 4200 100.0 100.0 NA 0 0 0 5 20.00 20.00 2 Breakdown 801727 840 5,040 20.0 120.0 840 5040 20.0 200 NA 0 0 0 20 100 2100 3 Add HCl,spacer 1,000 6,040 238 143.8 1000 8,040 23.0 1438 NA 0 0 0 20 1.19 22.19 4 OV Ten 1125180.0 4,200 10.240 60.0 243.8 4200 10240 100.0 2438 NA 0 0 0 20 5.00 2719 5 6p80oernro 60F27 8820 19,080 2100 4538 8820 19.060 211.0 453.8 NA 0 0 0 20 1050 3769 5 Shat, 0 19860 0.0 453.8 0 19080 0.0 4538 NA 0 0 0 0 30.00 67.69 8 Preyrad 3127180,0 2,100 21.180 50.0 501.8 2100 21160 50.0 503.8 NA 0 0 0 30 1500 8269 7 Pad Y127F1.,0 8,400 29.560 200.0 703.8 8.400 29,580 200.0 703.8 NA 0 0 0 30 6.67 89.36 B YF VF27F443 2008 31,568 47.8 751.6 2,131 31680 50.0 7538 16130 said 1 2.000 2,008 30 1.67 9102 9 Si! 11271150 2,771 34339 66.0 817.6 3,150 34,810 75.0 8208 16/30 sand 3 8.313 13,321 90 250 93.52 10 SLF 31271800 3,298 37,637 78.5 820.1 4200 391013 100.0 9208 6030 sand 6 19.786 30.118 30 3.33 96.86 ' 11 SLF 3627180,0 6,929 44,561 164.5 10610 9,450 98,480 225.0 11538 6730 sed 8 55,393 85,500 30 750 10.36 2 51,1 312711W0 5,365 49,948 128.2 1632 7,350 55,810 175.0 1,328.8 16130 sand 8 43.083 128,564 30 583 16.19 13 Flush 3127F1000 3.360 53,306 80.0 12642 3,360 59,170 80.0 1,408.8 NA 0 0 128.584 30 267 112.86 • 14 Flush 601127 3.360 56,666 80.0 1,3442 3,360 62.530 80.0 1,4888 NA 0 0 128.584 30 267 15.52 15 Flush LVT200 2,100 58,766 50.0 1,399.2 2,100 641630 50.0 1,5388 NA 0 0 28,584 30 167 117.6 U .Volume Ratio VFZBFM,O.Penns Hydration Curves(or 0887 t-511 1 s Pad 10.5000 216%. B882(gang agm0 6.50 odyn Mg., Shins 38.011.0 7840 3604(crossiiedl 220 gal on moat I 14711b IWM104 .08.:000•I.1 Tad 48,511.0 1345661. M0021Aotaaal 170 gripe myd I I 784, 88)gal ROM Is 0.leo.4 411l0.iuoeg Agent) 4.00 OdPar rogd 20 83 1000 4x1 MON It 11.leo..,1Rowans Condeatrrmn Ratio F10315udadwl 100 gat oarmgd Mb 10004.1 Proopal-6 30,118 2340 L064 lass Stabi0M 200 gat perogd P copan>6069 90.476 76.6% L065(scale hkbsa) 1.00 gdp,rood T..411.ramry'1646' lad 128584 1427S(Einodal 0.30 DO on agd 4 10 le :1 27 12 74 41 49 J5691E,caps,ardlreaker) 05-60 bp/aryd `6 Fluid 1 Prappra pas Met Thkbress Ne Pay.(I16( 42 VF 25435.3.. t/� Flid(gasl6dtl 6.429 F133 Sal.gag1 600 94 Pm ogd Fluid(gal/16 2,426 1103(Salaams) LW gat P.mod o 4/ ii L1365/Sot. .b40 200 grier ro P. 1455Requirements1Requirements L065(Soaqhhlwal 500 gal pe rood Aad Req,nanwv 1,000 gallons M275[&oddel 03) gat Pe mod 5 34 WaeOaavarwa 3379 bl4s ,b65(Erv:aps4aad freak.) 05-60 bpn'noel • Po/spent Repuemen 128.584 bac _0 660.4.45.4. 84.865 10 40 10 c0 76 40 al 100 III IN Toop..rala m.4e4G, Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 5500 psi Anticipated half length: -340' TVD Frac top: 8647' MD Frac top: 8954 TVD Frac bottom: 8709' MD Frac bottom: 9025' The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of -0.57 psi/ft or -4900 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the harder Sag formation and the softer confining layers. Average confining layer stress is-0.655 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values we used, a half length of 340' is expected. Pressure Test Information (20 AAC 25.283,a, 7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4400 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 7000 psi Stagger Pump Kickouts between: 6300 psi and 6650 psi (90%to 95%of MATP) Global Kickout: 6650 psi (95%of MATP) IA pop-off set pressure: 3000 psi (75%of MIT-IA) Treating line test pressure: 8000 psi Sand Requirement 130,000#16/30 Sand Minimum Water Requirement 1600 bbls(pump schedule: 1400 bbls) IA Hold Pressure 2500-3000 psi OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. rms 14-24 Rig Up 1 `e •ak.lia. Treesa�-er _\\ #44 \ mounted on well // 11 a. --- o-' Flonback :lawn Annulus Luke Tank , 0.L ►0 f. ontralma lme rcmr:or.Apres ns= control Fru Tank ii II Prcp. Frac Tank 1111111imisimiswidiA L_I Frac Tank L — Fra:Tank • Chemical Disclosure(20 AAC 25.283,a, 12) rF125FtEXD:WF125 54,471 Gal Contains:Water,AntiFoam Agent,Surfactant,Breaker,Stabilizing Agent,Gelling Agent.Crosslinker,Clay Control • ent,Scale Inhibitor,Additive,Bactericide,Pro..in: • nt The total,va,me listed In N.rabies above represents mm summ.don of water and additives.Water.,supplied by diens • Water(Including Mix Water Supplied by C9ent)• '"77% 14808-60-7 _ Crystalline silica "22% 9000-30-0 Guar gum <1% 75-57-0 Tetramethylammonium chloride <0.1% 107-21-1 Ethylene Glycol <0.1% 50-70-4 Sorbitol <0.1% 25322-69-4 Polypropylene glycol <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 1310-73-2 Sodium hydroxide <0.1% 67-63-0 Propan-2-ol <0.1% 111-76-2 2-butoxyethanol <0.1% 25038-72-6 Vinylidene cMoride/methylacrylate copolymer <0.01% 11138-66-2 Gum,xanthan <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01% 34398-01-1(3E0) Unear C11 alcohol ethoxidate(Up) <0.01% 34398-01-1(780) Linear C11 alcohol ethoxylate(leo) <0.01% 1330-43-4 Sodium tetraborate <0.01% 7647-14-5 Sodium chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 10043-52-4 Calcium chloride <0.01% 10377-60-3 Majnesium nitrate <0.001% 763146-9 Non-crystalline silica(Impurity) <0.001% 26172-55.4 5-chloro-2-met 42h-isothiazolol-3-one <0.001% 7786-30-3 Magnesium chloride - <0.001% 111-46-6 2,2'-oxydiethanol <0.001% 9002-84-0 poly(tetrafluoroethylene) <0.001% 14807-96-6 Magnesium silicate hydrate(talc) _ <0.001% 2682-20-4 2-methyl-2h-isothiazol-3-one <0.001% 14464-46-1 Crlstobalite <0.0001% Date: 1/7/14 From: David Wages ADW Engineer Josh Allely ADW Engineer Subject: 14-24 Recomplete Procedure Est. Cost: $1000M Est. IOR: 100 BOPD Objective: 14-24 is a vertical well in the East Waterflood area. The Ivishak has been temporarily isolated with a sandback and cement cap. An isolated Sag well test was attempted to confirm watercut and GOR. Unfortunately the Sag did not produce even with 1500 psi drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivity. 1. S Drift and Tag, Set Plug,Pull Plug 1. F MIT-IA,MIT-T (assist Slickline) 2. F Hydraulic Fracture Treatment 3. C FCO 4. S Tag,Install Deep GL Design 5. T Frac Flowback Last Test: 5/19/12 Deviation: vertical to 5100', —25 deg to TD of 9586' MD Max Deviation: 28.6 deg at 9000' MD Min. ID: 3.625" drilled cement sheath from 8525'-8779' MD GLMs: 2903', 4817', 6215', 7206', 7757', 7819', 8126', 8197'**, 8462'**, 8531'** (**Cement in Mandrels-Unable to pull) Last Downhole Ops: SBHPS, set and pulled RBP for MIT Latest H2S value: 24 ppm, 1/20/2012 BHT& BHP: 216° F & 3300 psig @ 8800' TVDSS (0.375 psi/ft, 7.2 ppg) Wellbore Volume: 209 bbls to top-perf Annulus Fluid: Diesel Contacts Office Cell David Wages 564-5669 713-380-9836 Josh Allely 564-5732 350-7362 Matt Brown 564-5874 223-7072 1. Slickline Drift and Tag, Set Plug,Pull Plug 1. Drift and tag to TD a) Cement sheath milled to 3.625" 2. Set 4-1/2" plug close to BD nipple b) According to caliper report, no apparent cement sheath to this depth (see Caliper report attached). 1. FUllbore MIT-IA,MIT-T (assist Slickline) • 3. MIT-IA to 4000 psi c) Use diesel as the IA is currently filled with diesel 4. MIT-T to 4400 psi d) Per new AOGCC regulations regarding frac treatments. 1. Slickline Pull Plug 5. Pull plug set in the tubing for the MIT-T • 2. Fullbore Hydraulic Fracture Treatment Pressure testing and material requirements Maximum Allowable Treating Pressure: 7000 psi Stagger Pump Kickouts between: 6300 psi and 6650 psi (90% to 95% of MATP) Global Kickout: 6650 psi (95% of MATP) IA pop-off set pressure: 3000 psi (75% of MIT-IA) Treating line test pressure: 8000 psi Sand Requirement 130,000# 20/40 Sand Minimum Water Requirement 1600 bbls (pump schedule: 1400 bbls) IA Hold Pressure 2500-3000 psi OA Monitor and maintain open to atmosphere 1. Fill frac tanks with clean water treated with biocide. a. Send water sample to SLB for QA/QC testing at least 3 days in advance. b. Perform QAQC Testing per attached procedure, use chemical of the same lot number as chemicals to be used for the frac. c. Heat water to 100 deg F prior to the frac, water should be at least 80 deg F on frac day. 2. Stage Sand Chief on location and load with sand 3. Ensure location is prepped as required for frac operations (i.e. snow removal, pad grading, barriers and cages installed, ground rods installed, etc.) 4. MIRU frac equipment. a.MIRU enough treating iron and horsepower to maintain 40 BPM and 7000 psi. 5. Prime up pumps and pressure test main treating line a. Stage up to high pressure test 6. Function test check valve(s) 7. Stagger individual pump kickouts and function test 8. Set global kickout and function test 9. Function test the manual kickout 10. Install pressure transducer to monitor the IA, we will maintain 2500-3000 psi 11. Perform loop test on blender and hydration unit to ensure meter consistency a.This test may be done in the shop, verify on location. 12. Perform bucket test on all additive pumps (including back-up additive pumps) and flow meters; calibrate as necessary 13. WSL to walk the lines and manifolds to ensure proper valve alignment and pertinent valves are open/closed. 14. Inventory water, chemicals, and proppant Frac well per excel spreadsheet provided by WIE During all pumping and pressure testing operations, all personnel shall either be: 1. Shielded by heavy equipment or structures and out of the line of sight of the wellhead, treating line, and pump discharge, or 2. Positioned at least 75 ft from the wellhead, treating line, and pump discharge. a. Exemptions to the above policy are: the blender operator and One designated service Company rep during pressure testing to check for leaks NOTE: The Excel file will include the engineer's pump schedule, the QA/QC checklist, Contingencies, PJR Checklist and the GHG reporting form. A. During all shutdowns after initial formation breakdown, measure and record an ISIP in AWGRS B. If pressure begins to rise, drop proppant concentration and/or decrease rate C. Back off pump rate to get a "soft" shut in, we want to slowly bring down the rate over the period of—1 minute. D. Flush to top perforation -20' Contingencies including what we do given a screenout or a rise in casing pressure will be submitted with the pump schedule. 3. Coil Tubing Frac FCO 6. See Appendix A for FCO procedure. 4. Slickline Tag, Install Deep GL Design 7. Drift and tag sand top 8. Install Deep GL Design 5. Test Frac Flowback Separator 9. See Appendix B for flowback procedure. Appendix A - CT FCO Procedure Notes: • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate frac flowback. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU and reverse out BHA. 3. RIH down to estimated sand top and begin reversing out with slick 1% KCL. 4. Continue reversing down to 8,920' CTMD. At this point we are -40' from the open perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the perfs. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly reverse until returns fall off to -80%. If returns are still good even after the nozzle is past the top perfs (not likely but possible), it is acceptable to continue reversing down to TD 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. Appendix B - Test Separator Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. • 4- TFC= 5 F11E 120 ! SAFETY NO169: 1 i IA LEAK AT 8689 NIP.FHi 1 WF'(l l'-AD= GRAY 1 14-2 4 AGITATOR- _ .f3Al0*-01 TIM-HBBP PKR WAS SOZ'O Wi CEMENT 12114/83 FETAL KB-9.E 7? BF.aDI= 2143' 1—,5-1/2"CAM SAL-O SSSV NP,13=4.562 I KOP= 5.700 Ant* X9000 11 2142' J-_[ FRAC St V, 33B'U25713,1J Datum FO" 9210 GAS LIT WORMS IJatunTVD= 8900 SS ■ ST FD TVH) CEV TY FE VLV LATCH PORT DATE-- 1 2903 2003 1—CA (1444 RK 0—03724.13 C3 3714'09G,7211,L-80 BTEC,D.12.347" $ 2072' 1.--A 2 4817 4817 1 CA CFif RK 0 03124413 3 6215 6139 27 CA CFM RK 0 07/1003 4 7206 7037 23 CA C90 FK 0 007226.13 5 7757 7550 21 CA CFM RK 0 0672740 1.11 5.61"L770,4711,100 x0 1()US t,B 1 SCJ-L11$7"L�X r. S 7819 7600 21 CA [1417 RK 0 OB/30.83 7 8128 7895 21 CA OW RK 0 122812 P,8197 7961 21 CA CFR/ FK 0 0/130.83 $ 8467 8705 24 CA (*41' RK 0 92/131001 Minimum ID=3.625"@-8522 1 10",8531 6288 25 1 CA DM' PC 0 0430431 TOP OF CEMENT SHEATH •"CCH7ee4TINMAMMA-U4WLET0POLL .. . .� -9622'---1790' 294111 SI4 A 1H,1*tI)T03 678" oi. 45 llFlllf3)OUT M C-11778'(639111614) 5-112 19O4,C,174,LEO, 0Q32 hp1,ID 4.692' , >� (1614' -e�^ 45* _ ' j+ r !! , {X112'BKFt F6tt 4'+':Y •At ` IN,. $614' Hs,117x4 11:11`KO,D-3.968 j Witt C► 8024' Ha5/6'x4-97spat A4_PKR ttr•t 4740 110P a r JNR H 8660' I ;r,t e ', ,' `t- 19992' , {4 1!7 CA61:0`IliTi,4iC1NG Nig.113 3 813'-J •+ j,5, 6705' I—f 4-1 'MI Si-EAnom Sts 1 • 4s, 4 112'1BG PC,12.611,11.60,0152 bp1,10.3.956' —f 1170$' •j 4.-: 0706' 4.1/2'WIG, -3.9,90'! ` $88$' --lawn TT L000LD0612T/63 I C 9.6 T1.7(-ns xa r��L i uTac1-{y'e(air''1---x 9576` I,K I CSC,4711.1 80 BT&C D H 6.861" sem NM''ELM 1- iT11fA(E TOC CAP 19711//12, 1 Mr-ORATION StILWARY 1 e- vvv�e 79069'ELM 1-L[IPOFSAND(118W12)I REF LOG 13/CS 01406/26/63 1 ANG(EAT TOP PERF 78'a 806011 i "'' .'"--, )/ —C LLASPFEO LNR 101113101 V10501,PASSED Note.Refer to F#oduelon DB for historical peri data 1 Tt I4,/FtEZTRICTION a 2-0`DELL.owe 12/27Affi SIZE SPF M1FEtVAt t)prUSgz SHOT 502 ? FISH-KM1Ef CUTTERt 1L 52'(05/19712) 2-1/2' 6 8960-8980 0 11/28/12 — 89+ 1_ 2-112'' 5 8968-8979 0 03/06/03 j 7 FSL T•SI14. FLAT BTM GO-DRUG. 1-719' 6 9125-9145 C 11/06/10 1 &CALM/CENTRALIZER ARIAS(06,28/12) 3-3/8• 4 9161 9188 S 12/06794 040400 T 1- F CM 391.IOOI.STFll4f3,t71A1 33'117r/1100)- 3-118" 4 9161-9197 S 03/09/84 04/04/00 _._ .�.--- L. -- .-._. _- _ ..._ 3116" 4 9202-9212 S 0309/66 014440! i 924W CAP 1 2-118' 4 9702-9217 C 17/17/00 1 3-1/Fr 4 11216-9736 C 03109/84 04X)4811, ( 6672' H -111_DIGGER.3.75'x 1.48'X40' ---------- --- -- _ FWD ♦it•♦ f`I,I`I,I` 7'LFR,29R,11-80 BTEC,.2371 Dpi,D=6.184' 194' `>«Ytr+f FIT'1—f $4---ii—j—]' NATE REV BY 031,611345OK1E 1 1L1/BY i 0061&411E 1RIDHDEBAY t64T 06138/83 RMN1T6114TIALCON PLE710H 0441/13Lt`3=7PJC iRILRBPSET FRAC SLY(3125/13) WELL: 14-24 11129)12111 SET,JM7 R13 (11/28112) —~ PERK 1.6. 1830910 01/06/13 i FET/RC Sr SP'PUJ_FRAC S1/1 412175t121 API too:50-029-20970-00 01108/13 I PJC CMI SHEATH CORRECTION SEC 9,T10N,R14E,1519'FTL S 1992'FO. 07!70113 MAQJM) iTttf CJO(00/i 1/13) 04/29113 Lffl PJC GLV C70(03/24/13) 8P Blp oratbn(418592) 4 • . Triaxial Safety Factor: 0 1.0 �i Cslr i.0 ! N. O Nu. C C - a 00 O •V C ( . v 1*- d .r .f. O E• F o N ` I= 4/ C = LL LL 2 I— } x « • .� J . �f�J I... J ♦ J J N j a • V.J J L J J .�. .� J l A J t J J 0$ ei '- -(41 - ---. ---ee • ri .✓ I " J^T14 f 1 M WI f • gA 40./ 'N •�' ,• t �,. [ Cr) •� I N .n .� .. J . — .,4.._�1A_ . �—.> .7-^.... -.t_ ... J 0 . .....__r___---- ... _r . te :. ._ c., ' ✓ L hx'�.: (y . . '�-•--.R Ers o `,-,. • aael..- I l 1 1 r 1 1 r r 1 r , r , 0 C C L] 7 I- co C I I r l I r r I r I r r 1 co O t` B 0 7 9 O D. to , ' 4N, Sc 0 N Sn C) J J 1. A J t J ... A J J l J 4:. N t 0 COU.U. ✓ 0 at f I f I I t t t 1 I t I I t f t f t f t o O O O O 0 0 o O 0 0 O 0 0 0 0 O 0 0 O O 0 O m O O o 0 0 O O O O O O 0 0 O O O O O O 0 0 0 x LO O LO 0 LO 0 LO u-, O n. O to O LO O n O LO O ito N - N N M CO O V In in l0 LD t•-• t'... 00 CO O 01 O O i- (WO t r r 4-1/2" Caliper Report 4 Joint Jt Depth Pen. Pen. Pen_ Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) e;, (ins.) 0 50 100 .1 8587 0 0 0 0 N/A 5.5"x 4.5"X-Over _2 8591 0 0.03 11 I 3.87 PUP Too of 4.5"Tubing Tail Loa 3 8597 0 0 0 0 N/A 9.625"x 4.5"Baker FHL Packer 1 8606 0 0.11 39 b 3.88 Corrosion. 2 8635 0 0.03 10 0 3.88 • 2.1 8661 0 0 0 0 3.81 4.5"Camco DB-6 Landing Nipple 2.2 8667 0 0.03 10 1 3.89 PUP 2.3 8676 0 0 0 0 N/A 4.5"Tubing Tail 1 8679 0 0 0 0 3.76 Cement Sheath. 2 8695 0 0 0 0 3.67 Cement Sheath. 3 8741 0 0.02 5 2 3.36 Cement Sheath. "'Penetration Body Metal Loss Body Date: January 14, 2015 Subject: 14-24 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Sag interval of well 14- 24. 14-24 is a vertical well in the East Waterflood area. The Ivishak has been temporarily isolated with a sandback and cement cap. An isolated sag well test was attempted to confirm watercut and GOR. Unfortunately, the Sag did not produce even with 1500 psi drawdown applied. It is planned to perform a fracture stimulation to increase Sag productivity. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages Plat Identifying Wells(20 AAC 25.283,a,2,A-C) and Faults(20 AAC 25.283,a, 11) LVL. i - -- — , -14.1111111141111111L, - liPlk ..6Tiii 111110100. , ----ivi - .7 kiiii 1 ' 14 1 • t \ .— ' •j- 14s , 3 , . 19 • f .. 300' '�` ,,, ': ' -- : 24 .. -.�-: !' i 14-35 \ 45(-15 -550' '',�:5 : ' 'S(--°\! .— .4 A • A \ ti fit, - -I fill IIN: .11,7A, "..""`ga Fault at TSGR - • TD/bottom of Sag/Ivishak *Top of Sag River ,14-06A ' , .14-28A- Wells within �h mile of 14-24: 14-23 14-43 14-19 14-18 14-37 14-36 14-05 14-35 14-20 14-41 Three faults of concern as shown above are to the east (-300' away) and to the south and west(both -550' away). The maximum stress direction from log data runs almost due North-South, thus the primary fault of concern is the fault to the south. In order to ensure this fault does not affect the fracture treatment, the half-length of the frac will be designed to be -400'. The fracture and the frac fluid should not come in contact with the fault of concern. Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well 14-24 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within 1/z mile radius per20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well 14-24 was spudded on 6/15/83. A 17-1/2" hole was drilled to 2553' where 65 joints of 13-3/8" 72#, L-80, BTC csg w/FS @ 2532 was run and cemented in place with 2000 sx Fondu and 400 sx of PF C cmt. After the BOP was NU and tested to 5000 psi, the casing was tested to 1500 psi for a passing MIT. After drilling the shoe, the casing was again tested to 11.1 EMW for another successful test. A 12-1/4" hole was drilled to 5252', the hole was reamed from 5075'-5252', continued to drill to production casing TD where more tight hole was encountered in several places requiring back- reaming. Once past casing set point, 220 joints of 9-5/8", 47#, L-80 and US-95 BTC csg with the Float shoe @ 8974' and cemented in place with 500 sx of Class G cmt. Casing was tested to 3000 psi for a passing MIT. After drilling out the shoe, a 11.4 ppg EMW test was successfully achieved A 8-1/2" hole was drilled to TD of 9586'. Openhole logs were run, two attempts at running FDC/CNL/GR/Cal resulted in two stuck toolstrings. Both fish were recovered. 21 joints of 7", 29#, N- 80, BTC csg was run from 8660'-9586', the liner was cemented with 300 sx of class G cement. The cement was drilled to 9547' PBTD, the liner lap was tested o 3000 psi successfully. A CBL run 6/83 confirmed liner was fully cemented. After swapping well out to 9.6 ppg NaCI, the completion assembly consisting o f5-1/2" tubing was run to 8706' with the packer at 8624'. S LDL on 8/30/93 found that the packer was leaking, so a packer cement squeeze was required and cemented from 8522'-8760'. There are 10 gas lift stations in the well, the bottom one at 8531 is behind a cement sheath. A BPNL from 8/98 found a channel from the bottom perfs down to Zone 3 at 9348'. A sand back cement squeeze was performed in 4/00 and placed the TOC @ 9250' When re-perforations were shot on 9/00, the perf guns were left in the hole. They were successfully fished the next day. When shallower perforations were shot on 12/12/00, the perf guns were again left in the hole. The fishing tools were left as an additional fish across the bottom perforations (9202'), and neither were retrieved. Subsequently, a collapsed liner was identified at 9177', a drift and tag on 6/30/02 was able to get passed the collapsed section with a 2.25" centralizer, and the collapse doesn't appear to be detrimental. The 16' of Sag ad-perfs that were shot in March 2003 did not bring in any appreciable benefits. The caliper from 10/06 shows the 4-1/2" N-80 tbg to be in relatively good condition with a maximum penetration of 27" recorded in 1 joint. A 12/06 RST found the GOC at 9142'MD/8740' TVD. E-line was also able to recover the 24' of perf guns that had been lost downhole in 12/00. Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8) Fr-T637--- — 5'FMC/20 SAF NOTES:Ta IA LEAK AT SSBV MP.Fia t NAll l[AO .._ GA/1Y 1 4-/A TW I.1488P PKR WAS sari)MI;CEMENT 11114163 AC'UTATOR= BAKERC i�'T 111 HMI nB.t3E 72 2143'_f 5-1/22 CAMBAL•OSSSV NW ID=4562' KOP 5308 : 1143' ]�63'FRAC SL V,CT=380-(0',/25713) MaaAngle� 29.09000 !)alum AD- 9710' _GAS t FT WM4NDR9.S [,dND,.arn O=- -.-8800'SS ST MD 1 IV0r DEV TY/I 0111E VLV LATCH PORT - f13 31/7 C9G,7211.L-90 BTEC D 17.347' ( 2532' ' 1.._'2903 2903 1 CA tom RK 4 .03'?AJ13 -- 7 4817 4817 1 CA MAY lac 0 03124113 3 6215 6139 27 : CA OW FIN 0 02110700 4 7206 7037 23 i CA OAK Poi 0 03124/13 5 7757 7550 21 CA OTA/ 18< 0 09177100 8 5/8'CSG,478,L 80 NO TO 11595 BTS{; L 8137 6 7619 7608 21 • CA OAK RK 0 08/30/83 7 6178 7895 21CA DMY RK 0 12726/12 8" 6197 79611 21 f CA OAK R0&30183r 0 00183 r-____ —_ 9" 6462 8205. 24 III CA COAT 19< 0 02/10/00 Minimum ID=3.626"@-852T 1 ter 6531L8268 25 CA CW" IW 0 06+3216.3 :TOP OF CEMENT SHEATH t'Ca$$I'IINMANORS-6-LI aLETOPLLL j.R -8522'---8760'-caarr SNEAIH.r a r)to 3 6255 -- — 1.70 ORRIS)OUT MS-1771E 7312814) (s vr-1.9 ., ,,.6 L-60.0232*LS=4 NT 1 i('s614'-) ..7 - _ I,- 1pt� 88Q6' 1-j5-112'BKRPBRASSr1 ` Cr'c', 1'1.'Ii eol 8814' ` suz'xCV?KO D=3.956'ii �+F Cr''" Mr 1 l .t-twer X 4-we out FTL R<RR 1TOPO T'IIVt1-1 +666• 1 % .9 a ?4!l-L4 tu.' Ivo:, ...,, ' tz [-ac 6192'—I-14.1/2 CAtionCB18L M39IG&'13.3813- 1 'in {R 670 '»._ -(4-VY SFEAROUT646 I4-112'TEIGJT C,12.&1.N-60,.0152W,D.3.956' 1-{ 870W L i kill 8706` 4-112'KL FG,D=7.95e•�1 . L8 1--rii.MO TT LOCA 08177,63 1 9-518'CSG,4711 US 95 X0101:11. 972' ;...-__)c I 1-91-5711"C9G.476,Coo BTEC D=tray H 89741 -+i -- - ' f9037 ELMJ-�BSTMAIE TOC CAI'1110112) 1 FERFC47ATIONSUMMARY 1,1045 g X, 9059'ELM--I TOP OFSAND111104A2) FEE LOG. RI=ON 08126/83 _ ANGLE A1TOP 76378" 8960' fl1etr -0QLATAR(01113,01 vivo),PASSED Abe:Refer$0 PIOebn OB for Aisbricalper(data I 1 M T}{RU N TRiCTp 4 , 8 8EL1 GW[17727708 Srg NI NAI WTI ansa_..: __ __.... 2-177 6 8960-8980 • 1 ii:: 2 ..`.— ..---. - 7 1, (F151+KEEEYELITV6Fi OAL 52'(05179x$21 J ?-1r7 5 8968-8978 0 03/06/03 7 `r FISH SI 1-511910 FLAT BTM GO-0EVEL 2-718' 6 9125 9145 C 11/06/10 IIIETEME — &CALM OENIRA L17ERAfA6(0626+12) 3-318' 4 81Et 9186 i 5 17Mi0194 54/347C0 ---- =� 1 gµbt TUOL STRM3,OAL 33`(12/21100) 3 1/8' 4 8161-91971 S 00109/84 04644100 -- 3 I/8' 4 9207-92121 S 031W/84.940440 -- - 'St; L'• I•CEMENT GAP_ 7-718' 4 9202-9212, C 12/12/00; .�'i.4>N - ZY/3' 4 9215 9235 C 03/09/84'04'04100 11676' FISH 773 MOOCH 375'1/1 40')i Off I r r T 111,....= PBTO ss47' -- ; 861,' '-�rE+, RP] T ue,298,1180 BTBG,0371 bpi,O-6 t� 111684• *I RN``r a FDT Fi 858V-1 • TC"- RY 4:4' r m' Mir REV BY .. _....CifeArriNfr PF1.A7Ft0EBAX LW 06f3a113 RON178INTIALcaw pi_ET10N '04/29/13 LEFT PJC R,ILI PSET FRAC Sim(3125/13) WTIL' 14-24 11/29/12 SFT/AU 1$$JF11918112) ...._-.-- _. _ .. _..._ R32661Na 1830910 '01/16/13 FKT1PJC SETIBA-FULL Me ,12) ----..- _--_ -- AR Pb 50009-20970-00 01/06/13' PJC CM!St£AIM036PECTDN 02/20/11 Mh1JAF319Ef 2.0 j6'd1i)i31--- '.4,110F1 Rt4k 1519 FALL d 1992's8 041.19/!3 I FT'1 PJC Zit.G'_(9b(0424113) _. --7 .. _ __ 8P BrpbnNna Wes ILO Name/Size Weight Grade ID Burst,psi Collapse,psi 13-3/8" Surface 72# L-80 12.347" 5380 2670 9-5/8" Production 47# L-80 8.681" 6870 4760 7" Liner 29# N-80 6.184 8160 7020 5-1/2" Tubing 17# L-80 4.892 7740 6290 Wellhead: F. 1.---'''' ', .- , �/ k , lit; .4..,nviii. A � l ', ARCO GEN.i!WELLHEAD G . /. i/ ",,,g"..'„;,;:'• , :" '",. } T Grey manufactured wellhead, rated to 5000 psi. Tree: 7-1/16" 5,000psi w/5-1/8" bore Tubing head adaptor: 13-5/8" 5,000psi x 7-1/16" 5,000psi w/5-1/8" bore. Tubing Spool: 13-5/8" 5,000psi w/3-1/8" side outlets Casing Spool: 13-5/8" 5,000psi w/3-1/8" side outlets Tree saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" .......:47. rr mom rr. ION, misni J �___ y 'u' P ( ' Imo 7V z N 6 s 1I L 1 ii S a Z. D4; x E rI rJ MO1111:.fi Geological Frac Information (20 AAC 25.283,a,9) to Tap at mess Stress d Stress Stress at ,g Fluid lots ' a II Graded Topa Bottom of CodRdmrd SOLO ProPl+wti . Zane f03 Oiiererwe 1tato Surface Zone GradientZone Modals PobeaPB .,. Oukoat lass Embedment fi-w-`.ti T . V ,. ,t_.D= :,_, - ,_J ( � FtaMlo. Kao ,.._ ,+:..2.1 2 ._G I f i i::r'L 9 r!{�� p 4 ,z..r 0 cum ocam 4866.6 .600 _ -.000000 MOM 2000.0 +.008300 4 00000 0.10000 6 =Vv-- .o El= r =1111 =gm !::; °.600000 woo) +.000000 ,00000 ,0.10000 6 " . ' 0 Emil maw um 0600 ® 2.600000 com. 2000.0 0.006670 '3.00000 :010000 a =MI" p 694.1 =EN mum o.eoo =CM p tre.'•+i 2000.0 0.002620 ,3.00000 0.10000 9 =" 0 Milli NUM =II 'r''' ...ail 000000 =Ms '1100.0 ,.001260'',.aa000 0.10000 10 o 11 .tomp 0=1011 MIIII :. 1.600000 MEI 2000.0 +,001260 '<00000 0.10000 1212 13 ': .:0 ,-- 0 100.0 .727 • ,.6 +.600 :'.1.4 1.250000 ,.92 20000 -+.001260 " : + 0.1000o Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Per plat above, the following wells have been reviewed for casing and cement information: • 14-43: Spud Date: 10/21/1992 20" 91.5#, H-40 Conductor set and cemented with 2000#Coldset II in a 30" hole 10-3/4" 45.5# NT-80 Surface casing set and cemented with 1978 cu ft of CS II and 403 cu ft class G in a 13-1/2" hole. 7-5/8" 29.7# NT-95 Production casing set and cemented at 1179 cu ft class G in a 9-7/8" hole. TOC 5580' per 10/92 CBL. 5-1/2" 17# 13 Cr80 set and cemented with 125 sx class G in 6-3/4" hole. Fully cemented to 7-5/8" casing per 11/92 CBL 4-1/2" 13Cr80 tubing @ 8933', Packer @ 8872'. 14-19: Spud Date: 6/8/92 20" 94# H-40 conductor set and cemented with 232 sx of SA II in a 32" hole. 13-3/8" 72# N-80 surface casing set and cemented with 3000 sx AS III and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80/S0095 production casing set and cemented with 500 sx Class G in a 12-1/4" hole which gives 1950' of cement. 7" 26# L-80/13Cr80 liner set and cemented with 435 cu ft of class G cement in a 8-1/2" hole which gives 2640' of cement. 4-1/2" &3-1/2" tubing set @ 9576', packer©9507' 14-18 Sidetracked 2007 20" 94# H-40 conductor set and cemented with 300 sx Permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2615 sx Fondu and 400 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx of class G in a 12-1/4" hole which gives 1500' of cement. 7" 26# L-80 liner set and cemented with 437 sx class G and 169 sx Class G in 8-1/2" hole which gives 4410 feet of cement. 4-1/2" 12.6# 13Cr80 set and cemented with 102 sx class G in a 6-1/8" hole which gives 100 feet of cement. 4-1/2" 12.6# 13Cr80 tubing set @ 10,563'. Packer© 10.445' 14-37 20" 91.5# H-40 conductor set and cemented with 2150#of poleset in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx CS III and 600 sx class G a top job was performed with 200 sx CS II. 9-5/8" 47# L-80 production casing was set and cemented with 880 sx class G in a 12-1/4" hole. This gives —2600' of cement. 7" 29# L-80 liner was set and cemented in place with 300 sx class G, the liner lap was cemented with 150 sx class G liner set in 8-1/2" hole. A CBL ran 10/88 shows the liner fully cemented. 4-1/2" tubing set©9426' with a packer at 9300' 14-36: Spud date: 12/83 20" 91.5# H-40 conductor set and cemented with 375 sx PF II in a 30" hole 13-3/8" 72# L-80 surface casing set and cemented with 2000 sx Fonda and 400 sx PF C in a 17-1/2" hole 9-5/8" 47# L-80 production casing set and cemented with 500 sx class G and 300 sx of CSI in a 12- 1/4" hole. This puts 2350' of cement. 7" 29# L-80 set and cemented with 300 sx of class G in a 8-1/2" hole, fully cemented per 1/84 CBL 5-1/2" &4-1/2" tbg set @ 8787' packer @ 8694' 14-05 Spud date: 1/92 20" 94.5#conductor set and cemented with 300 sx Articset in a 30" hole 13-3/8" 72# N-80 set and cemented with 4234 sx Permafrost in a 17-1/2" hole 9-5/8" 47# L-80 set and cemented with 1000 sx class G in a 12-1/4" hole this put 2980 feet of cement behind pipe. 7" 29# 13Cr80 liner set and cemented with 493 cu ft of class G in a 8-1/2" hole. A successful foam squeeze performed 7/92 to address a channel from 8994' to 9162'. In 7/93, a BPNL showed the channel went up to 8820' but no channel down. In 1998 a cretaceous leak caused the well to go to 100% WC required a RWO which installed a fully cemented 7" tieback. 4-1/2" tubing @ 8493' with packer @ 8380' 14-35 Spud date: 11/83 20" 91.5# H-40 set and cemented with 2050# Poleset in a 30" hole 13-3/8" 72# L-80 surface set and cemented with 1800 sx Foudu and 400 sx PF C in a 17-1/2" 9-5/8" 47# L-80 production set and cemented with 500 sx class G and 300 sx PF C in a 12-1/4" hole. This put 2950' of cement in the annulus. 7" 29# L-80 liner set and cemented with 334 sx class G in an 8-1/2" hole. Fully cemented per 11/83 CBL. 5-1/2" &4-1/2" tbg @ 8554' with a packer at 8445' 14-20 Spud date: 6/81 20" 94# H-40 conductor set and cemented with 300 sx permafrost in a 32" hole 13-3/8" 72# L-80 surface casing set and cemented with 2800 sx Fonda and 400 sx PF and 138 sx AS II in a 17-1/2" hole 9-5/8" 47# L-80 & S95 production set and cemented with 500 sx class G in a 12-1/4" hole. This places 1470' of cement in the annulus. 7" 29# L-80 production casing set and cemented with 400 sx class G in a 8-1/2" hole. Per 6/81 CBL, fully cemented. 5-1/2" tubing @ 9091', packer @ 9015' 14-41 20" 94# BTC conductor set and cemented with 2000# Poleset in a 30" hole 10-3/4" 45.5#surface set and cemented with 1050 sx CS III and 350 sx class G in a 13-1/2" hole 7-5/8" 29.7# NT95 production set and cemented with 1320 cu ft class G in a 9-7/8" hole. This places 1560 feet of cement in the annulus. 5-1/2" 17# 13Cr80 set and cemented with 1778 cu ft class G in a 6-3/4" hole. This places 1640 feet of cement in the annulus. s. Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program attached) Pump Schedule: Stage Stage Fluid Type Clean' Cr Clean Cum Slung Clem Slum Curs Preppant Type Prop Prop 0 Cum Rae Pumping Cum Description Valente Clem Volume Clean VolumeV.haae ShesCo... Stage Prop (bend Time Pump lea0 0.. 86600 Ibb7d M.B IbAn IbWI y (peal Ma Obs( Time 0 PT,serkis Treated Water 1 Load hob Treated Water 4,200 4108 1000 100.0 4200 4,200 1000 000 NA 5 2000 2003 2 Breakdown WF127 840' 5.040 200 120.0 040 5040_ 20.0 1200 NA 20 100 21.00 3 Arid HD.spacer 1,000 690 238 1438 9200 8040 238 1038 NA 20 119 2219 4 64 Test V112551.3 4020 0240 1000 243.8 42133 00,240 00.0 2438 NA 20 5.00 27.19 5 Displacement WF27 8,8210 01.060 211.0 453.8 8,820 10,080 20.0 453.8 NA 20 13.50 37.69 5 Sha-In 0 1003 00 453.8 0 15¢10 0.0 453.8 NA 0 30.00 67.69 6 P00-pad '4512754.0 2.10 21101 500 503.6 '2100 29120 500 5038 NA 30 15.03 82.69 7 Pad W2751i 13 8,400 20.0602000 703.8 8,400 79200 200.0 7038 NA 30 6.67 89.36 8 SIF VF127Fbx0 2106 31.588 47.8 751.6 2100 3080 50.0 7536 3630sarid 2908 2.008 30 167 9102 9 5(2' '452751.113 2771 34,339 660 617.6 3,150 3490 75.0 828.6 16430 sand 8.313 1,321 30 2.50 33.52 0 315 '1512751e45 3298 37037 78.5 636.1 4.20 '- 490 010 928.8 16430 sand 19,766 30,18 30 333 96.86 11 SLF V52751k43 6.924 44,581 164.9 1,0650 5450 48,480 2250 1,238 0130 sand 55,393 85,500 30 7.50 14,36 2 515 552751et0 5305 45346 128.2 1,169.2 7,350 0590 175.0 1,3268 0130 sand 03,083 128,584 30 583 10.13 13 Flush VF127f1at0 3,360 53.336' 80.0 1,269.2 3,360 55,770 80.0 1,408.8 NA 0 28,584 30 2.67 02.86 14 Flush 04527 3.363 50,860 80.0 1,349.2 1380 82.630 80.0 1,4888.8 NA 0 128.584 30 2.67 115.52 15 Flush 101200 2100_ 56.788 50.0 1,339.2 "710 54,001 500 1,538.8 NA 0 128,584 30 167 117.19 Clean Volume Ratio VF28FIea0....taios: Hydration Curves for 0087 @ 511 1/s Pad 10,500.0 2164 6882(ge4ing.0441 6.50 PIM mild Skau 38,00.0 78.4% J6041crosslinkerl 2.20 pipet cgs! I I 40 11,10111 9d I I 3515,1004 lel Tad 48.500 1345164 M0021Aai.atal 1.70 gdp«mgd I I ''I It tett pi I -, :,1 2512.1000041 J5110Osleng Agent 4.00 plowman V' 1 ;016;1400901 I I 158,1000 041 Mennen.Coneentrmlen Ratio F1315ufadanl 1.00 pdpw mild I I 1016..1101441 Prop04t1-6 30.18 234/ L064 Claysrabaserl 200 gd Om mad Rap0«0 6ppg 98476 7604 L065(Sode Vida.) 1.03 gd p«mgd Tatimet1e0 Acgti Tad 128.584 P275(Biocide) 0.30 peonngd J 10 16 21 27 32 38 43 49 • 1563(5rc.pnlated Breaker) 05-6.0 bow mgal .. Fluid I P.Ppant per Neo ihiek..ss Net Pay Treated 20 V525 contains, S0 ,, ... Roppan Mid 6,029 88132(pinigap.nl 8.50 Pal Per mild Rid 1p1/10 2,426 F1031Suiavant) 100 gal P«mgd Ly5ta 44«I 200 Operand 40� ""'- •�.`�. Material Requirements LOSS 1365(5. H�ciale ral 100 palm's,/ Acid Requitement 1,000 gallons M231Bocidel 0.30 plowman - 30"----........i____________.._ �--.� • Weer Requirement 1,373 bbls J56918ncepsaatedecaked 05-6 « 0 lb �-�--. Pmpyan Requirement 28.584 lbs `F 20 L_�-..... ,.." - • 664 d Pioppant 84,865 0 I 40 50 40 10 00 10 100 110 120 Temperature WWWOFi Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 5500 psi Anticipated half length: -340' TVD Frac top: 8647' MD Frac top: 8954 TVD Frac bottom: 8709' MD Frac bottom: 9025' The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of -0.57 psi/ft or -4900 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the harder Sag formation and the softer confining layers. Average confining layer stress is -0.655 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values we used, a half length of 340' is expected. Pressure Test Information (20 AAC 25.283,a,7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4400 psi. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 7000 psi Stagger Pump Kickouts between: 6300 psi and 6650 psi (90%to 95%of MATP) Global Kickout: 6650 psi (95%of MATP) IA pop-off set pressure: __ 3000 psi(75%of MIT-IA) Treating line test pressure: 8000 psi Sand Requirement 130,000#16/30 Sand Minimum Water Requirement 1600 bbls(pump schedule: 1400 bbls) IA Hold Pressure 2500-3000 psi OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. r 14-24 Rig Up stif 1ti 300011 .�. .. PR V aceded m . TA TOY Inner Annulus Line • CLL bl *ID pump 4 pump for'Apressure control =.11.M BOOtTiBC ! r • I I • • • • Talk r Prop End^^ Y Y tiskt o-v0v( Li-. ✓a.. vi 7 r( a�i n % t'� 0A • Chemical Disclosure (20 AAC 25.283,a, 12) Fluid Description(s) v=1251 EXO:WF125 54,471 Gal ' Contains:Water,AntiFoam Agent,Surfactant,Breaker,Stabilizing Agent,Gelling Agent,Crosslinker,Clay Control Agent,Scale Inhibitor,Additive,Bactericide,Propping Agent The total volume listed in the tables above represents the summanan of waver and additives.Water is supplied by chert CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)" -77% 14808-60-7 Crystalline silica "'22% 9000-30-0 Guar gum <1% 75-57-0 Tetramethylammonium chloride <0.1% 107-21-1 _ Ethyllene Glycol <0.1% 50-70-4 Sorbitol <0.1% 25322-69-4 Polypropylene glycol — <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 1310-73-2 Sodium hydroxide <0.1% 67-63-0 Propan-2-ol <0.1% 111-76-2 2-butoxyethanol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.01% 11138-66-2 Gum,xanthan <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01% 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) <0.01% 1330-43-4 Sodium tetraborate <0.01% 7647-14-5 Sodium chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 10043-52-4 Calcium chloride <0.01% 10377-60-3 Magnesium nitrate <0.001% 7631-86-9 Non-crystalline silica(impurity) <0.001% 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001% 7786-30-3 Magnesium chloride <0.001% 111-466 2,2'-oxydiethanol <0.001% 9002-84-0 poly(tetrafluoroethylene) <0.001% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 2682-20-4 2-methyl-2h-isothiazol-3-one <0.001% 14464-46-1 Cristobalite <0.0001% Total 100% Loepp. Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Friday,January 23, 2015 3:58 PM To: Wages, David' Subject: PBU 14-24(PTD 183-091, Sundry 315-037) Fracture Stimulation David, Verbal approval is granted on this fracture stimulation sundry.You may proceed with the stimulation. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria.Loeop oaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 Loepp, Victoria T (DOA) From: Wages, David <David.Wages@bp.com> Sent Friday,January 23, 2015 12:55 PM To: Loepp,Victoria T(DOA) Subject 14-24 Fracture treatment notification update Attachments: AOGCC Notification.docx Victoria, Per our conversation,Attached is an update notification letter. Updates include: Treesaver pressure rating: 10,000 psi ✓ Results of the pressure tests: MIT-T to 4400 psi, MIT-IA to 4000 psi on 1/20/15. Treating pressure, IA pressure and OA pressure will be monitored in the frac van. ✓ Added: Statement of no water wells within'mile of subject well. Affidavit notifying partners and landowners of planned operations. ' £-, - - ' c 'T =;.14-k- David Wages a---T o.907.564.5669 U L 3 /S� c. 713.380.9836 W I E-AK 1 Loepp, Victoria T (DOA) From: Wallace, Chris D (DOA) Sent: Thursday,January 22, 2015 5:37 PM To: Loepp,Victoria T(DOA) Subject: Fwd: 14-24 frac Victoria, This is about the fraction sundry we probably received this afternoon. Thanks Chris Original message From: "Wages, David" <David.Wages@bp.com> Date:01/22/2015 5:00 PM(GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: Subject: RE: 14-24 frac Hey Chris, We are out of the office tomorrow so I will be available on the cell phone, number below. Thanks David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday,January 22, 2015 9:00 AM To: Wages, David Subject: RE: 14-24 frac David, I do understand. I have started reviewing the information. I may have missed it on my first pass but I did not see-so please verify: (a) (8) pressure ratings and schematics for all equipment? Not seeing the wellhead and any isolation by a tree saver/goat head etc and the pressure ratings. (d)treating lines and schematic showing pressure relief(s) and shut down protocols? (f) how the IA and OA will be monitored and pressure relief(s) set? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue 1 Anchorage,AK 99501 ' (907) 793-1250(phone) (907) 276-7542 (fax) chris.wal lace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.cgov. From: Wages, David [mailto:David.Wages@bp.com] Sent:Thursday, January 22, 2015 8:39 AM To: Wallace, Chris D (DOA) Subject: RE: 14-24 frac Will do today, I just wanted to be able to get started as we are on a time crunch. Thanks David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Thursday,January 22, 2015 7:08 AM To: Wages, David Subject: RE: 14-24 frac David, Thank you for the information. Please deliver to AOGCC(via courier or mail) a hardcopy original signed, and a hardcopy copy signed. We cannot process electronic submissions at this time. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 2 please delete it, without first saving or forwarding it, and, so that the AOGCL is aware of the mistake in sending ' it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Wednesday,January 21, 2015 5:30 PM To: Wallace, Chris D (DOA) Subject: RE: 14-24 frac Chris, I apologize for the delay. Please find the attached documents including the 10-403 form,the detailed procedure and the document meeting the requirements per the new hydraulic fracturing regulations. If you have any questions, please let me know. David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Wednesday,January 14, 2015 3:42 PM To: Wages, David Subject: RE: 14-24 frac David, We look forward to receiving it. Signed original plus a copy. Remember to make sure if there is a request for a variance—state the waiver requested in the cover letter, and go into the detail of the justification in the body of the sundry application. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Wednesday,January 14, 2015 3:34 PM 3 TO: Wallace, Chris D (DOA) Subject: 14-24 frac Hey Chris, This is David Wages with BP.We had spoke on the phone around the end of December about the new frac regulations. We've got a well to be frac'd on our schedule for the 25th of January,so next weekend.Since we had our meeting, I've finally been able to get most of what we need together but I was wondering if I could get this to you tomorrow, if I might be able to get it moved to the top of your pile. I apologize for the late notice, but I wanted to let you know of this well. Thank you, If you have any questions or issues with the submitted paperwork, please let me know. David Wages o.907.564.5669 c. 713.380.9836 W I E-AK 4 J , I1 ''n o ., � 'Zil 1f ! 0 ;i\ p 1 if..* rfl,p. -..\.' /4 E 0El LI P V ® Q L E C4 • (� (�(� t (3) „= \ 1� L t c>.?30:1 Illilitilic4 ';': v N 1 \ 4141 ji -C i - ® ; O N 12• ,E, % % .1 1, ,Ili a ,c,,, ,. • E rii: L L 1 _ _ -- cp er. } V) QJ O co n d N sr « a a m _ I Kai o f ! L° = cv o � ' �_ ” / \ a x 9 u m• 'J s a. g g gII 11 i '..00A4V pi, NJ � -/'� � 2' ���r a c � In $, EE c `y 1 O mI M T b ��' +-+ N 7. A • o k 1 2?, cu i ra .1 - • R n V :7, ma g�ga 4) Z4 1 E QCO Q c y ( r VI .. L a v4 a a a a d \ = a) c ,L-_ v u \N 4! ,' a O +, E� ti ra I- a = • 2) a Z) cr, cc 3 m o2S Ste' 1 1 J ;5 --) 1 A 0 4 4 0► +..., 1111*■ — Z a, = E. d N -71 L I E 9utd rj J7" ! -b37 �k� 'zt/ S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 3001 Porcupine Drive Anchorage, Alaska 99501-3192 4 ( ,es iL / -ZL( Re: THE REQUEST OF ARCO ALASKA, ) Area Injection Order No. 4 INC. for an Area Injection ) Order for that portion ) Eastern Operating Area of the Prudhoe Bay Unit ) Prudhoe Bay Unit /,L - /5 commonly known as the ) Eastern Operating Area ) July 11 , 1986 IT APPEARING THAT: 1 . ARCO Alaska, Inc. (ARCO) requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids . 2. Notice of an opportunity for a public hearing on July 16 , 1986 was published in the Anchorage Times on June 9 , 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will , in its discretion, issue an order without a public hear- ing. FINDINGS: 1 . An order permitting the underground injection of non-hazardous fluids on an area basis , rather than for each injection well individually, provides for effi- ciencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25 . 460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis . 2. The Eastern Operating Area constitutes a compact "proj- ect area" for the operation of a portion of the Prudhoe Bay Unit and can readily be described by governmental subdivisions . The Project Area is operated by a single operator. 3. The Project Area encompasses approximately the eastern one-half of the Prudhoe Oil Pool and all of the Lisburne Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery from this portion of the CANNEL JUN 3 0 2004 Area Injection Oraer No. 4 Page 2 July 11 , 1986 Prudhoe Oil Pool, and from all of the Lisburne Oil Pool . The Project Area includes all existing injection wells and injection well sites planned for disposal by injection into Cretaceous and Tertiary strata of oil field waste fluids developed from the operation of this portion of the Prudhoe Bay Unit. 4 . The vertical limits of injection strata and the con- fining formations may be defined in the ARCO (Atlantic Richfield-Humble) Prudhoe Bay State Well No. 1 and the ARCO Sag River State Well No. 1 . 5. Within the Project Area, injection into, through, or above a fresh water aquifer or underground source of drinking water will not occur. 6 . The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations . 7 . Less stringent requirements for well construction, operation, monitoring and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to in- jection strata, the mechanical integrity of an in- jection well should be demonstrated periodically and monitored routinely for disclosure of possible abnor- malities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25. 412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: UMIAT MERIDIAN T12N R14E Sections 22 , 23, 24 , 25 , 26, 35 and 36 SCANNEL JUN 3 0 2004 Area Injection Oiuer No. 4 Page 3 July 11 , 1986 T12N R15E Sections 19, 20 , 21 , 22 , 23, 24 , 25 , 26, 27 , 28, 29 , 30, 31 , 32 , 33 , 34 , 35 and 36 T12N R16E Sections 28, 29 , 30, 31 , 32, 33 and Section 34 : W NW 47 SW 4f SW 4 SE 4 T11N R14E Sections 1 , 2 , 9 , 10 , 11 , 12, 13, 14 , 15 , 16, 21 , 22, 23, 24 , 25 , 26, 27 , 28, 33 , 34 , 35 and 36. T11N R15E Entire Township. T11N R16E Section 2: SW 3 NW 4f SW 4, S 2 SE 4 Sections 3 , 4, 5 , 6, 7 , 8, 9, 10 , 11 Section 12 : NW 4f S 2 NE 3, SE 4, SW 4 Sections 13 , 14 , 15 , 16, 17 , 18, 19 , 20 , 21 , 28, 29, 30, 31 , 32 and 33. T1ON R14E Sections 1 , 2 , 3, 4 , 9 , 10 , 11 , 12 , 13, 14 , 15 , 16 , 21 , 22, 23, 24 , 25 , 26, 27, 28 and 36. T1ON R15E Entire Township T1ON R16E Sections 4 , 5 , 6, 7 , 8, 9, 16, 17 , 18, 19, 20 , 29 , 30 and 31 . Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in ARCO (Atlantic Richfield-Humble) Prudhoe Bay State No. 1 between the measured depths of 8110 feet and 8680 feet for the Prudhoe Oil Pool and between the measured depths of 8790 feet and 10, 440 feet for the Lisburne Oil Pool. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in ARCO Sag River State Well No. 1 between the measured depths of 1900 feet and 6750 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25. 005 ; 2) through an existing well that has been approved for conversion to a service SGA'NrNE1 JUN 3 (' 2.004 Area Injection Oraer No. 4 Page 4 July 11 , 1986 well for injection in conformance with 20 AAC 25. 280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Pumping of excess non-hazardous fluids that are developed solely from well operations , or necessary to control the fluid level of reserve pits , into surface/production casing annuli is exempted from the above requirements. Rule 4 Monitoring The Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly as a routine duty to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing' s minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0. 25 psi/ft multiplied by the vertical depth of the packer, which ever is greater , but not to exceed a hoop stress greater than 70% of the casing' s minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observances or pressure tests indi- cate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25. 105. Rule 9 Administrative Relief Upon request , the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission' s satisfaction that sound engineering practices are 7/25/86 Revision S AN EL JUN 3 0 20e4 Area Injection Oraer No. 4 Page 5 July 11 , 1986 maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated July 11 , 1986. rOI / �I//►/ - r/��d � atter o , C' airman ;if ,,, c� Alaska Oil and ' as Conservation Commission ,:=Y—,,, V' ,,, �,i_e ; #--',gay'al 0,,„,,) '--/L1 M nnie C. Smi , ommissioner - "i-,. Alaska Oil and Gas Conservation Commission Wi iam W. Barnwe Commissioner Alaska Oil and Gas Conservation Commission SCANNEL MN 3 0 2004 Ima~roject Well History File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing(done) [~Two-Sided IIIrlllllrlllllllll D RescanNeeded IIIIIIIIIIIIIIIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [3 Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Origi hals: OVERSIZED (Non-Scannable) [] Other: . NOTES: [] Logs of various kinds [] Other BY: BEVERLY BREN VINCE~ MARIA LOWELl. DATE:o(~'--/,~~, ~SI Project Proofing ., BY: ~ BREN VINCENT SHERYL MARIA LOWELl. Scanning Preparation ' ~/x 30= ~¢~ BY: BEVERLY BREN(~ SHERYL MARIA LOWELL Production Scanning Stage '/ PAGE COUNT FROM SCANNED Stage 2 :COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY~ (SCANNING IS COMPLETE AT THIS POINT UNLES~ SPECIAL ATTENTION IS REQUIRED ON AN INOIVIOUAI. PAG6 BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III I Illllllll II III ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd • • F Regg, James B (DOA) !'TD fits - o ito From: AK, D &C Well Integrity Coordinator ( AKDCWeIllntegrityCoordinator ©bp.com] Sent: Wednesday, March 27, 2013 5:18 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A; Grey, Leighton (CH2M Hill) Subject: OPERABLE: Producer 14 -24 (PTD #1830910) Passing MIT -IA All, Producer 14 -24 (PTD #1830910) passed a MIT -IA to 3000 psi on 03/25/2013 post tree change out. This confirms the presence of two competent barriers in the well. At this time the well is reclassified as Operable, and may be placed on production. Regards, Laurie Climer (Alternate: Jack Di,shro14) BP Alaska - Well Integrity Coordinator GW C'oi !Wa Ofian■zal.on WIC Office: 907.659.5102NN JUL 2.013 WIC Email: AKDCWeIllntegrityCoordinator (c�BP.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, January 10, 2013 7:49 AM To: 'Schwartz, Guy L (DOA)' (auv.schwartz(aalaska.gov); 'jim.regg @alaska.gov'; A , OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operation "Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; A OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordin-- or; 'Shane.Wills @bp.com'; Stechauner, Bernhard Subject: NOT OPERABLE: Producer 14 -24 (PTD #1830910) Well Se •red With Tubing Tail Plug and Passed CMIT -TxIA All, Producer 14 -24 (PTD #1830910) has been secured with a t , •ing tail plug and passed a CMIT -TxIA on 12/28/2012. The well is reclassified as Not Operable. Plan forward: 1. Valve shop: Tree change out 2. E -line: Leak detect log Please call if you have any questions. Thank you, 1 STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMMON JAN 2 9 2013 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well Li Plug Perforations U Perforate U Other AOGGO Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weli❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development is Exploratory ❑ • 183 -091 -0 3. Address: P.O. Box 196612 Stratigraphit❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20970 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028312 - PBU 14 -24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9586 feet Plugs measured 9032 feet true vertical 9202 feet Junk measured See Attachment feet Effective Depth measured 9032 feet Packer measured 8624 feet true vertical 8715.11 feet true vertical 8352.37 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 Surface 2502 13 -3/8" 72# L -80 30 - 2532 30 - 2531.92 4930 2670 Intermediate None None None None None None Production 8947 9 -5/8" 47# L -80 27 - 8974 27 - 8664.16 6870 4760 Liner 926 7" 29# N -80 8660 - 9586 8384.84 - 9202.67 8160 7020 Perforation depth Measured depth See Attachment feet MAR True Vertical depth See Attachment feet SCANNED 0 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See 5 Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker FHL Packer 8624 8352.37 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 207 13036 2318 256 934 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator)Q Development 0 .- Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , U Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summer Printed Name Ni . Summerhay- Title Petrotechnical Data Technician • .nature �/ /1.�i - ., . 1 Phone 564 -4035 Date 1/29/2013 Rl3DMS JAN 3 0 701 1- 7 /� ?, `l / Form 10 -404 Revised 10/2012 Submit Original Only I • • Daily Report of Well Operations ADL0028312 idol f7,!4 . , '�MAR �, - : of u.mg - o• cope = • ' emory ie in, an.'...... � ug, Cement Cap MIRU, complete weekly BOP test. Stop for culture interview. Make up BOT connector with PDS memory gamma ray /CCL logging string insid eof the 2.2" carrier and a 2.25" nozzle on the bottom. RIH. At 6614' ctm noticed a gas leak below the PCE. Killed the well. POOH. Swapped the ring gasket out at surface. 11/2/2012 « <Job continued on 11/3/2012 »> CTU #9 1.75" Coil Tubing - Job Scope = Tie in log, Sand dump, Cement Cap « <Job continued from 11/2/2012 »> RIH with BOT ctc and PDS memory gamma ray /ccl logging string and a 2.25" JSN. Stopped at 9180' ctm. PUH ten feet. Logged up at 40 fpm. Stopped at 8900' ctm and flagged coil. Logged up to 8400'CTM. POOH. Confirmed good data at surface. -4' correction. Make up SLB tool string with a 2.3" BDN and RIH. Correct depth at Flag to 8896'ELM. Underbalance well w/ 133 bbls of diesel down backside. Pump sand slurry#1: 5 bbl 40 #HEC spear, 16 bbl 6 ppa 20/40 river sand slurry, 5 bbls HEC chaser. Inject 1 bbl of sand then lay in 16 bbls of sand at 1:1 (no losses). Wait at safety for 3 hrs. RIH to 9165'ELM, just above collapsed liner, no tag. PUH. Attempt to wash unsettled sand down. No tag. PU. Reflag pipe. Pump 20/20 river sand slurry #2 at 6 ppa: 3 bbls HEC, 16 bbls sand slurry, 3 bbls HEC gel. Lay in sand slurry 1:1 (no losses) from 9150'ELM. Wait for sand to settle. 11/3/2012 « <Job in Progress »> CTU #9 1.75" CT. Job Scope: Sand plug w/ cement cap « <Job continued from 11/3/2012 »> Pumped sand slurry #3 w/ 2400 lbs of 20/40 in 40# HEC gel at 6 ppa. Waited for sand to settle. Tagged TOS at 9054'ELM. POOH. RIH w/ 2.25" Pig Shear Nozzle. Tag TOS at 9059'ELM. Pump 5 bbls FW, Foam Pig, 1 bbl 15.8 ppg G Cement, Foam Pig, 7/8" ball, 5 bbls FW, 33 bbls 2 %KCI. With nozzle at 9049'ELM pump 1 bbl of cement. PU to 9010'ELM and shear Pig Shear Nozzle. Wait 15 minutes for residual cement to fall out of coil. Estimated TOC —9032'ELM. Circulate KCI at 80% pumping 2 bpm while POOH. FP to 2500' w/ 60/40. RDMO. 11/4/2012 « <Job Complete »> ** *WELL S/I ON ARRIVAL ** *(fracturing) DRIFT W/ 20' x 2.50" DUMMY GUNS. TAGGED TOC © 9049' SLM.(recovered 1/4 cup of cement) 11/12/2012 ** *WELL S/I ON DEPARTURE, DSO NOTIFIED * ** ** *WELL S/I ON ARRIVAL * ** (pre - adpert) DRIFT AND TAGGED DSSSV W/ 4.63" G.RING © 2,118' SLM PULLED 5 1/2" DSSSV FROM 2,118' SLM / 2,143' MD SET 5 1/2" FRAC SLEEVE @ 2,118' SLM / 2,143' MD (4.62" no -go, oal- 60 ", 3.0" id, 51" from center to center of o- rings) WEEKLY WLV TEST SET #20312013 TO 3800psi * *PASS ** 11/26/2012 ** *WELL S/I UPON DEPARTURE * ** • • Daily Report of Well Operations ADL0028312 ** *WELL SHUT IN ON ARRIVAL * ** (ELINE PERF) INITIAL T /I /O= 500/800/280 PSI INITIAL VALVE POSITIONS: MASTER / VALVES TO CASING= OPEN, SWAB /SSV/WING= CLOSED PERFORATE 8960' -8980' WITH 20' LOADED 2506 HSD PJO HMX, 6 SPF, 60 DEG PHASE. CORRELATED TO SLB RST DATED 26 -DEC- 2012. LOG FROM 9024'- 8450'. DEEPEST DEPTH= 9048'. FINAL VALVE POSITIONS: MASTER/ VALVES TO CASING= OPEN, SWAB /SSV /WING= CLOSED FINIAL T /I /O= 500/800/280 PSI 11/28/2012 ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 302 60/40 METH 1 METH 165 DIESEL 2 CEMENT 17 FRESH WATER 161 2% SLICK KCL 648 TOTAL e -----1- - f- — 1.0ratiCT- ent ADL0028312 / SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base ,. ( 14 -24 11/28/2012 APF 8960 8968 8651.85 8658.88 14 -24 11/28/2012 APF 8968 8978 8658.88 8667.67 `' 14 -24 11/28/2012 APF 8978 8980 8667.67 8669.43 14 -24 11/4/2012 BPS 9125 9145 8796.99 8814.61 14 -24 11/4/2012 BPS 9161 9173 8828.71 8839.27 14 -24 11/4/2012 BPS 9173 9183 8839.27 8848.08 14 -24 11/4/2012 BPS 9183 9186 8848.08 8850.72 14 -24 11/4/2012 BPS 9186 9197 8850.72 8860.41 • / 14 -24 11/4/2012 BPS 9202 9212 8864.81 8873.61 \ 14 -24 11/4/2012 BPS 9215 9225 8876.26 8885.06 \14-24 11/4/2012 BPS 9225 9235 8885.06 8893.86 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADL0028312 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 LINER 926 7" 29# N -80 8660 - 9586 8384.84 - 9202.67 8160 7020 PRODUCTION 8947 9 -5/8" 47# L -80 27 - 8974 27 - 8664.16 6870 4760 SURFACE 2502 13 -3/8" 72# L -80 30 - 2532 30 - 2531.92 4930 2670 TUBING 8575 5 -1/2" 17# L -80 25 - 8600 25 - 8330.69 7740 6280 TUBING 106 4 -1/2" 12.6# L -80 8600 - 8706 8330.69 - 8426.23 8430 7500 • • VI E3 !HEAD _ GRAY GRAY • S/�Y NOTES: T x IA LEAK AT SSSV NIP. FHL / ACTUATOR= GRAY 1 4 -24' TWI - HBBP PKR WAS SQZ'D W/ CEMENT 12/14/93 MIAL KB. ELE _ 72' BF. ELE4/ = . 2143' H5-1/2" CAM BAL -O SSSV NP, ID = 4.562" KOP = 5300' Max Angle = 29° 1 9000' Datum MD= 9210' GAS LET MANS Datum TVD= 8800' SS ST MD TVD DEV TYPE VLV LATCH FORT DOTE 1 2903 2903 1 CA DOLE RK 16 08/03/09 113 -3/8" CSG, 72#, L -80 BT&C, D = 12.347" —1 2532' , 2 4817 4817 1 CA DOME RK 16 08/03/09 3 6215 6139 27 CA DMY RK 0 02/10/00 4 7206 7037 23 CA DOME RK 16 08/03/09 5 7757 7550 21 CA DMY RK 0 08/27/00 [5/8" CSG, 47# L -80 XO TO US-95 BT &C 8137' 6 7819 7608 21 CA DMY RK 0 06/30/83 � 1/2 BKR REP (12128/12) —I 8165' ( ` _ — 7 8126 7895 21 CA DMY RK 0 12/28/12 8"' 8197 7961 21 CA DMY RK 0 06/30/83 9" 8462 8205 24 CA DMY RK 0 02/10/00 Minimum ID = 3.625" @ -8522' 10" 8531 8266 25 CA DMY RK 0 06/30/83 TOP OF CEMENT SHEATH " CBW ENT INMANDRELS- UNABLE TOPULL ,,`�,. �V'.. 40 —8522' - - -8760' � CBVENE SHEATH, F ILL ®TO 3.625" �.,�I DRILLED OUT 8525' - 8779' (03/2/94) i. I ' ( 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 8614' ( I ■ I ; kI•4I ►1,1. ‘I' 1�i ti, 8600' H5 -1/2" BKR FBRASSY � + ► • . ♦ • 8614' H5 -1/2" x 4- 112" xo, D = 3.958" , , �rIM ► li■A 8624' J 9-5/8" X 4-1/2" BKR FFL PKR ILE 4'O/ (TOP OF 7" LNR H 8660' r�� i P A: I►1. 8692' 4-112" CAW() DB 6 LANDING NP, D = 3.813" 1, , ►�. , t �� ' 8705' H 4-1/2" BKR SFEAROUT SUB f • ` • , k � �� 8706' H4 -1/2" WLEG, D = 3.958" 14 -1/2" TBG -PC, 12.6#, N-80, .0152 bpf, D = 3.958' H 8706' /- .. • ! ( 8685' (—{ ELM O TT LOGGED 08/27/83 ( 9-5/8" CSG, 47 #, US-95 XO TO L -80 BT &C H 8972' ( 9-5/8" CSG, 47 #, L -80 BT &C, ID= 8.681" H 8974' _____N( \ 9032' ELM H ESTMATE TOC CAP 11/04/12) ( PERFORATION SINIVIARY C���I S 4 P14ftlITI TOPOF SAND (11/04/12) REF LOG: BRCS ON 06/26/83 / ( ANGLE AT TOP P62F: 28° @ 8960' ( 9177' — COLLASPED LNR (01/13/01 VDEO), PASSED Note: Fifer to Roduction DB for historical pert data J THRU RESTRICTION w /2.6" MIL GIME 12/27/06 SIZE • •I :• A Opn/ .. ; 87 • 2 -1 6 8960 8980 O 11/28/12 i ? --(FISH- KINLEY GLITTER, OAL 52' (05129/12) 2 -1/2" 5 .�: 8978 0 03/06/03 i� ( ? -jFISH - a T- STFSVG; FLAT BTM GO- DEVEL 2 -7/8' 6 9125 - 9145 C 11/06/10 MI. CALIPER CENTRALIZER ARMS (06/26/12) 3-318" 4 9161 - 9186 S 12/06/94 04/04/00 3-1/8" 4 9161 - 9197 S 03/09/84 04/04/00 I I ? --I PIFISH- SL TOOL STRING, OAL 33' (12/21/00) � & 3-1/8" 4 9202 - 9212 S 03/09/84 04/04/00 9249' (- rCa,E�IT CAP 2 -7/8' 4 9202 - 9212 C 12/12/00 A,����� „� ..so 3-1/8' 4 9215 - 9235 C 03/09/84 04/04/00 Ems ■ ( 9676' HASH - TEL TRIGGER 3.75” X 1.40" X 40' 1 =IRa 9581' —( FISH - BP ( (PBTD 9547' r♦♦ 7" LNR, 29#, N-80 BT &C, .0371 bpf, ID= 6.184 " --1 9584' ( 4♦4 ♦j ♦I ♦j ♦ (m H ri�i ♦i ♦i ♦iii DATE REV BY COMMENTS DATE REV BY OOMMENTS I PRUDHOE BAY LINT 06/30/83 MN 176 INITIAL COMPLETION 11/29/12 ARUM PULL DSSSV /SET FRAC SLV (11/26/12 WELL: 14-24 06/07/12 JSMJMD 2 -FISH- E L TOOL STING (05/29/ 11/29/12 SET/AID F R3 F (11/28/12) PERMIT No: "1830910 06/26/12 GJF/ PJC FISHES- PREVIOUS/ CURRENT 12/02/12 PJC PERES/ FRAC SLV CORRECIT'ONS API No: 50- 029 - 20970 -00 06/26/12 GJF/ PJC FISHES- PREVIOUS/ CURRENT 01/06/13 RKT/ PJC SET BR' PULL FRAC SVL (12/28/12) SIC 9, T1ON, R14E, 1519' FNL & 1992' FEL 11/07/12 JJUJMD SAND DLWCMT CAP (11/04/12 01/08113 PJC C MT SHEATH CORRECTION 11/10/12 PJC CMT CAR SAM) CORRECTIONS BP Exploration (Alaska) PBC& 14 -z4 • P1N6 1030710 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Z 0(13 Sent: Sent: Thursday, January 10, 2013 7:49 AM ! c To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Shane.Wills @bp.com; Stechauner, Bernhard Subject: NOT OPERABLE: Producer 14 -24 (PTD #1830910) Well Secured With Tubing Tail Plug and Passed CMIT -TxIA All, Producer 14 -24 (PTD #1830910) has been secured with a tubing tail plug and passed a CMIT -TxIA on 12/28/2012. The well is reclassified as Not Operable. Plan forward: 1. Valve shop: Tree change out 2. E -line: Leak detect log Please call if you have any questions. Thank you, SCANNED APR 1 1 2013 Gerald Murphy BP Alaska - Well Integrity Coordinator GW SIo al Wells OrganizaFEor WIC Office: 907.659.5102 WIC Email: AKDCWe1lIntegyCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, December 19, 2012 5:27 PM To: 'Schwartz, Guy L (DOA)' (quv.schwartz @alaska.gov); 'jim.regg @alaska.gov'; , OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operatio . Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; A , OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordin. or; Holt, Ryan P; Walker, Greg (D &C); Climer, Laurie A Subject: UNDER EVALUATION: Producer 14 -24 (PTD #1830910) Sust. ned IA Casing Pressure Above MOASP All, Producer 14 -24 (PTD # 1830910) has confirmed sustained IA c- ing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/2080/330 psi on 12/18/2012. he well has been reclassified as Under Evaluation and may remain online while work is conducted to attempt to res .re integrity. Plan forward: 1 • p &i,-t 14z¢ Regg, James [3 (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, December 19, 2012 5:27 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; AK, OPS EOC Specialists Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P; Walker, Greg (D &C); Climer, Laurie A Subject: UNDER EVALUATION: Producer 14 -24 (PTD #1830910) Sustained IA Casing Pressure Above MOASP Attachments: 14- 24.pdf; Producer 14 -24 (PTD 1830910).docx All, Producer 14 -24 (PTD # 1830910) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/2080/330 psi on 12T1872012. The well has been reclassified as Under Evaluation and may remain online while work is c' o�nc acted to attempt to restore integrity. Plan forward: 1. Slickline: Pull frac sleeve in SSSV, run Dummy SSSV with extended packing 2. DHD: TIFL 3. WIE: Evaluate for gas lift valve change out if TIFL fails A TIO plot and wellbore schematic have been included for reference. Please call if you have any questions or concerns. SC`- Thank you, SC'-P - 2-r. , Gerald Murphy titS{P= isvr ~ BP Alaska - Well Integrity rity Coordinator GVq lobaI Wells 2rclafizatitn WIC Office: 907.659.5102 WIC Email: AKDCWe1IlntegrityCoordinator @BP.com SCANNED APR 17 2013 • S PBU 14 -24 PTD #1830910 12/19/2012 TIO Pressures Plots Well 14 A OCO � -s- IA -A-- OA Z XO OOA OOOA —On 000 T �•.•,.'0 02 "2 — Gl "td' 0515'2 U8'5 ^2 C (€1V2 08'8': `21112 1•'1 ;12 12 12/1/2012 — 12/19/2012 Wd1:14 -24 A 000. 3.000 �- Thp - IA OA 00A 000A — a 1Ab0- 7- =a 12 , 12 . 210222 • 1200 12104.12 1200512 124/12 1200712 1248/12 1200912 1212012 12114112 12/106112 11117112 17/19112 II<EL = GRAY GE1t 3 • SAFAOTES: T x IA LEAK AT SSSV NIP, FHL / IAELLWAD = GRAY 1 4 r, 2 4 ..�..._ _ ... — _ ..__ -- TWI - HBB Z' P PKR WAS SQf7 W/ CEMENT 12/14193 ACTUATOR = AXELSON ,e . .. INITIAL KB. ELE 72' BE ELEV = 2143' 1 - 5 CAM BAL -O SSSV hp, C = 4.567 KOP 6300 5 FRAC SLEEVE (11/26/12 ), D — 3.00' 11u4ex Angle = 29° @ 9(3©0' Oetum MD= = 9210' GAS LFT MANDRELS Daturn WD= — 8800' S S ST N[) t ND DEV TYPE VLV LATCH FORT) DATE 1 2903 2903, 1 CA COME ` FE 16 I .'t rr x [13 CSG, 72#, L - r +1 BT&C, ID= 12.34r I— I 2532' 1 - 41 2 4817 4817' 1 CA (X*.E RK 16 08/33109 3 6215 6139 27 CA , DW RK 0 :02/10/00 4 7206 7037 23 CA DOME RK 16 ' 08/03/09 5 7757 7550 21 CA OW RK 0 08/27/00 9 CSG, 47#, L -8 XO TO 115 - 95 BT&C I--{ 8137' } — x X 6 7819 7: r >+ 21 CA DMY RK 0 06/30/83 7 8126 7: 5 21 CA SO FE 24 , 08/03)09 Min I ©= 3.0 ©" 2143' 8" 6197 7961. 21 CA C*W FE 0 06/30/83 9" 8462 8205' 24 CA OW FE 0 02/10/00 5 -112" FRAC SLEEVE 10" 8531 8268 25 CA . OMd1' RK 0 06/30/83 "C9NENT IN MANDRELS - UNABLE TO PILL , te , *00 ,,, , ,, —8527 - '•8760' I--1 CEMENT SI-EATH, ID = 2.50 (12/14/93) 1 „ N , Kb 8525' -- CMT DRLLED OUT 8525' - 8779 ID = 3.625' { 5-112" TB U H G -PC, 17 #, L-80, .0232 bpi, = 4.892 " t -s . ' ' H5 -1/2" • BKRPBRASSY i %,, #4 : "' 8614' 5.1 /7 X 4-1/2' X0, ©= 3658 — "N ►Z • 24' _- -5/8" X 4-1/7 BKR RI_ PKR I I TOP OF 7' LW — I 8660' t I k ► ' 1,' 8692' " LANDING NP, ID = 3.813" 1 ie, bli I. ,P4 — 4-1/2 CAM1:0 DEI-6 '. C + P 8705' H4-1/2" BKR SFEAROUF 5118 4 TBG - PC, 12.6#, N .0152 bpi, ID = 3.958' - I 8706' � *j 8706' - �4 1/2' HVLEG, © 3.958" 1 ___ --- 8685' I — , ELM.) TT LOGGED 98/27/83 MJtVF- ` 2t5vps , 9-5/8" CSG, 474, US 95 XO TO L-80 8T8C 8972' 1--.� ?C 1 9-5/8' CSG, 47 #, L -80 BT&C, D= 8.681' H 8974' I•--• ' ' 9032' ELM — ESTIMATE TOC CAP 11/04/12) I PERFORATION sIJw 4AFi1' 9059' ELM --{TOP OF SAND (11/04/12) I REF LOG: 81-CS ON 06/26/83 ANGLE AT TOP F : 28° f� 8960' I 9177' I — COLLASPED LNR (01/13/01 VIDEO), PASSED Note: Refer to Production DB for historical perf data THRU RESTRICTION w /2.6" BELL GUIDE 12/27/06 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ , I 2 - 1/2' 6 8960 - 8980 0 11/28/12, { ? 1—I FISH- KNLEY CUTTER, OAL 52' (05/29/12) I Vik 2 - 1/7 5 8968 - 8978 0 03/06/03 1• 7 — FISFI- SL T- STRING; FLAT BTM GO- DEVEL. 2 - 7/8' 6 9125 - 9145 C 11/06/10 8 CALDER CENTRALIZER ARMS (06/26/12) 3 4 9161 - 9186 S 12/06194 04/04/00 MEM INN ? HASH- SL TOOL STRING, OAL 33' (12121/00) 3 4 9161 9197 S 03/09/84 04/04/00 3 4 9202 - 9212 S 03/09/84 04/04/00 I 9249' CHIT CAP 2 4 9202 - 9212 C 12/12/00 3 4 9215 - 9235 C 03/09/84 04/04/00 ' 9576' HFLSH - TEi TRIGGER 3.75' X 1.40' X 40' 9581' 1--I FI5!-I - SP I I PBTD 9547' h � 7" LNR 29#, L-80„0371 bpf, C = 6. 184" 9584' I 1- D J — I 9 I . DATE REV BY . COM AE TS - DATE REV BY COA+ IEIVIS , I F E BAY LMT 06/30/83 FINN 176 IIITIAL COMPLETION 11/29/12 AMNJIAD FULL DSSSV /SET FRAC SLV (11/26/12 W73L 14-24 06/07/12 JSM'JM30.2 -FIST F EL TOOL STING (05/29! 11/29/12 SET /J•) REFERF (11/28/12) I Fir N©: 1830910 06/26/12 GJF/ PJC FISHES- PREVK)US/ C >IRRBYT , 12/02/12 PJC F13 S/ FRAC SLV, ETC STONE AR No: 50- 029 - 20970 -00 06/26/12 GJF/ PJC FISHES' PREVIOUS/ CURRENT SEC 9, T1ON, R14E, 1519' RC 8 1992' Fa 11/07/12 JJUJMf.) SAM) OIWP/CMT CAP (11/94/12 11/10/12 PJC CMT CAF1' SAND es -,-. • 4.1 BP Exploration (Alaska) OPERABLE: Producer 14 -24 (PTD #10910) Tubing integrity restored - Passi TIFL Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] �/ 2,.3/11 Sent: Thursday, February 03, 2011 8:47 AM l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: Winslow, Jack L (ASRC); Sinyangwe, Nathan; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer 14 -24 (PTD #1830910) Tubing integrity restored - Passing TIFL All, Producer 14 -24 (PTD #1830910) passed a TIFL on 2/2/11 after a DSSSV was set. The passing test verifies tubing integrity has been restored eTh well has been reclassified as Operable and may be placed on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 ,.. i , F > " ; 3 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, January 13, 2011 10:38 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS - " DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D:. Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt • s r; AK, OPS PCC EOC TL; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Sinyangwe, N. an Subject: UNDER EVALUATION: Producer 14 -24 (PTD #1830910) •stained Casing Pressure on the IA All, Producer 14 -24 (PTD #1830910) has been found to h. , e sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SS 050/640 psi on 01/08/2011. A subsequent TIFL failed after the tubing pressure was seen trackin. e IA pressure during the bleed. The well has been reclassified as Under Evaluation and may be • educed under a 28 -day clock. The plan forward is as follows: 1. DHD: TIFL - Failed 2. DHD: Re -TIFL when BOL 3. Slickline: C/O OGLV or set DGLVs pending TIFL results 2/3/2011 UNDER EVALUATION: Producer 14- 4 (PTD #1830910) Sustained Casing P,sure on the IA Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com]� / ¢11( Sent: Thursday, January 13, 2011 10:38 PM ( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Sinyangwe, Nathan Subject: UNDER EVALUATION: Producer 14 -24 (PTD #1830910) Sustained Casing Pressure on the IA Attachments: 14 -24 TIO Plot 01- 13- 11.doc; 14- 24.pdf All, Producer 14 -24 (PTD #1830910) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV/2050/640 psi on 01/08/2011. A subsequent TIFL failed after the tubing pressure was seen tracking theTA during the bleed. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. The plan forward is as follows: 1. DHD: TIFL - Failed 2. DHD: Re -TIFL when BOL 3. Slickline: C/O OGLV or set DGLVs pending TIFL results - 4. DHD /Pumping: TIFL /MITIA A TIO plot and wellbore schematic have been included for your reference. «14 -24 TIO Plot 01- 13- 11.doc» «14- 24.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator IAN 0 ZUll Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, January 11, 2011 6:58 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA due to proration Jim/Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 14 -24 (PTD #1830910) W -26A (PTD #1990810) 1/14/2011 UNDER EVALUATION: Producer 14-24 (PTD #1830910) Sustained Casing P sure on the IA Page 2 of 2 The found following wells was fo nd t have sued casing pressure on the OA during the oration January 10. The 9 to 9 p 9 rY immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. U -06B (PTD #2050640) U -12A (PTD #2041470) Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/14/2011 PBU 14 -24 PTD 1830910 1/13/2011 TIO Pressures Plot Well: 14 -24 4.000 - • 3,000 - Tbg —CIA 2.000 - —A-- OA OOA -� 000A On 1,11011 • 10/23/10 11/0E110 11/20/10 12 ?04/10 12118/10 01/01/11 TREE = GRAY GEN 3 SAFETY S: T x IA LEAK AT SSSV NIP. FHL / ACTUATOR = AXELSON 14-2 WELLHEAD = GRAY TWI - HBKR WAS StIZ'D W/ CEMENT 12/14/93 KB. ELEV = 72 BF. ELEV = KOP = 5300' 1 2143' 5 -1/2" CAM BAL -O SSSV NIP, ID = 4.562" Max Angle = Datum MD = 29 @ 9000' w 1 DSSSV (08/03/09), ID = 3.00" 9210' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2903 2903 1 CA DOME RK 16 08/03/09 113 -3/8" CSG, 72 #, L -80 BT &C, ID = 12.347" I-I 2532' F-441 2 4817 4817 1 CA DOME RK 16 08/03/09 3 6215 6139 27 CA DMY RK 0 02/10/00 19 -5/8" CSG, 47 #, L -80 XO TO US -95 BT &C H 8137' I NM 4 7206 7037 23 CA DOME RK 16 08/03/09 5 7757 7550 21 CA DMY RK 0 08/27/00 6 7819 7608 21 CA DMY RK 0 Minimum ID = 3.00" @ 2142' 7 8126 7895 21 CA SO RK 24 08/03/09 5 -112" {.Q DSSSV 8 ** 8197 7961 21 CA DMY RK 0 9 ** 8462 8205 24 CA DMY RK 0 02/10/00 10** 8531 8268 24 CA DMY RK 0 _ .* *CEMENT IN MANDRELS - UNABLE TO PULL W1 V ., - ,y - A 8522' -I TOP OF CEMENT SHEATH 1 ► � 4 ►,, ► ,,: n i. 8525' I-I CMT DRILLED OUT 8525' - 8779', ID = 3.625" I 1 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" I 8614' ►' +r1 - / . 434, •:'''.! 8600' -I5 -1/2" BKR PBR ASSY I .411 ►� I * • • 4 4 ; *•-:- • 8614' — I5 -1/2" X 4 -1/2" XO, ID = 3.958" I TOP OF 7" LNR I 8660' " + ' • 8624' 9 -5/8" X 4 -1/2" BKR FHL PKR P 4/ iow ■� ���1 . i 1 ��� 4 =� -; 8692' H4 -1/2" CAMCO DB -6 LANDING NIP, ID= 3.813" I , rg E 440 k 8705' -14-1/2" BKR SHEAROUT SUB , ,1 i 14-1/2" TBG -PC, 12.6 #, N -80, .0152 bpf, ID = 3.958" I 8706' ,,- i!.•.,, fill 8706' 14 -1/2" TUBING TAIL, ID = 3.958" I 0 i ( 9 -5/8" CSG, 47 #, US -95 XO TO L -80 BT &CH 8972' I- W k: I 8760' H BOTTOM OF CEMENT SHEATH I 19 -5/8" CSG, 47 #, L -80 BT &C, ID = 8.681" H 8974' I 8685' H ELMD 17' LOGGED 08/27/83 I I PERFORATION SUMMARY I REF LOG: BHCS ON 06/26/83 ANGLE AT TOP PERF: 28 © 8968' I 9177' I jCOLLASPED LNR (01/13/01 VIDEO), PASSED Note: Refer to Production DB for historical perf data THRU RESTRICTION w /2.6" BELL GUIDE 12/27/06 SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 5 8968 - 8978 0 03/06/03 2 -7/8' 6 9125 - 9145 0 11/06/10 3 -3/8" 4 9161 - 9186 S 12/06/94 3 -1/8" 4 9161 - 9197 S 03/09/84 '�� �.�.t 9 r 9249' I-I CEMENT CAP I 3 -1/8" 4 9202 - 9212 S 03/09/84 M 2 -7/8" 4 9215 - 9235 0 03/09/84 9576' ,-I FISH - TEL TRIGGER 3.75" X 1.40" X 40" I 1111111116. IMMO IIIMNIUMME 9581' I---I FISH - !BPI (PBTD I 9547' !1• I 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 9584' �4'••�•�•�• J TD I I / / 1 4 A H 9586' DATE REV BY COMMENTS II DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/30/83 ORIGINAL COMPLETION 1111/18/10 CSR/PJC PERF CORRECTIONS WELL: 14 -24 01/04/07 RRD /TLH 2 EL TOOLSTRING FISH (12/26/06) PERMIT No: 1830910 09/28/09 RRD /SV ADPERF (07/30/09) API No: 50 -029- 20970 -00 09/28/09 CJN/SV GLV C/O (08/03/09) SEC 9, T1 ON, R14E, 2715.89' FEL & 5249.1' FNL 11/16/10 MSS /PJC FISH PULLED (12/28/06) 11/16/10 SRD /PJC PERFS (11/06/10) BP Exploration (Alaska) Producers with sustained casing pressuon IA and OA due to proration �' Page 1 of 1 Regg, James B (DOA) YI'� /63- 0 Z j From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] { „ I I fl 1( Sent: Tuesday, January 11, 2011 6:58 AM (� To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA due to proration Jim /Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 14 -24 PT .18830 0r W -26A (PTD #19 ) The following wells was found to have sustained casing pressure on the OA during the proration January 10. The immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. U -06B (PTD #2050640) U -12A (PTD #2041470) Please call with any questions or concerns. Thank you, KANNED JAN 2 0 Za'l'l Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/11/2011 STATE OF ALASKA ALASK AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑J Exploratory ❑ " 183 -0910 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 41 50- 029 - 20970 -00 -00 8. Property Designation (Lease Number) : 5 9. Well Name and Number: ADLO- 028312 S PBU 14 -24 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9586 feet Plugs (measured) 9249 TO C feet true vertical 9202.6 feet Junk (measured) 9576,958 feet Effective Depth measured 9177.5 feet Packer (measured) 8624 feet true vertical 8843 feet (true vertical) 8352 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 112 SURFACE - 112 Surface 2500 13 -3/8" 72# L -80 SURFACE - 2532 SURFACE - 2532 5380 2670 Intermediate 8942 9 -5/8" 47# L -80 SURFACE - 8974 SURFACE - 8664 6870 4760 Production Liner 924 7'29# L -80 8660 - 9584 8385 - 9201 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 SURFACE - 8614 SURFACE - 8343 4 -1/2" 12.6# N -80 8614-8706 8343-8426 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 4 -1/2" BAKER FHL PKR 8624 8352 12. Stimulation or cement squeeze summary: Intervals treated (measured): N 0 9 2 010 MU o Treatment descriptions including volumes used and final pressure: t+�'�!I � G �� cons. �����ce Acchera 13. Representative Daily Average Production or lfifflln Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development ❑J W Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 9 J Gas WDSPL I GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Joe Lastufka Printed Na a Jo Lastufk Title Data Manager Signatu Phone 564 -4091 Date 11/8/2010 CMS Nov 10 11 a Form 10 -404 Revised 10/2010 Submit Original Only i 14 -24 183 -091 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth ToF Tvd Depth Bas 14 -24 3/9/84 PER 9,161. 9,186. 8,828.71 8,850.72 14 -24 3/9/84 PER 9,186. 9,197. 8,850.72 8,860.41 14 -24 3/9/84 PER 9,202. 9,212. 8,864.81 8,873.61 14 -24 3/9/84 PER 9,215. 9,235. 8,876.26 8,893.86 14 -24 12/6/94 RPF 9,161. 9,186. 8,828.71 8,850.72 14 -24 4 /4/00 SQZ 8,556. 9,235. 8,290.83 8,893.86 14 -24 9/19/00 RPF 9,173. 9,183. 8,839.27 8,848.08 14 -24 9/19/00 RPF 9,215. 9,225. 8,876.26 8,885.06 14 -24 12/12/00 RPF 9,202. 9,212. 8,864.81 8,873.61 14 -24 3/6/03 APF 8,968. 8,978. 8,658.88 8,667.67 14 -24 11/6/10 APF 9,125. 9,145. 8,796.99 8,814.61 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL T SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • I • 14 -24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY j 10/26/20101 Load fluids, Road to location a 4 WWW 10 /26/2010!* *"WELL WAS SHUT IN ON ARRIVAL * ** (pre adperf) F 'ARRIVE ON PAD AND STANDING BY FOR SNOW REMOVAL. t € € 1 t I 10/27/2010`T/1/0 2750/1750/500 Assist S -Line W/ Load & Kill Pumped into Tbg w. 10 bbl meth spear, 293 bbls 1% KCL. Freeze protected W/ 1 bbl meth spacer, 60 bbls diesel. I FWHP= 600/1750/500 SV,WV,SSV shut. MV,IA,OA Open. S -Line on location upon I 1 departure j i I l i 3 10/27/20101 ** *WSR CONTINUED FROM 10/26/2010 * ** (pre adperf) } 1LRS PUMPED 290 BBLS OF 1% KCL AND 60 BBLS OF DIESEL TO LOAD WELL PULLED RELEASABLE SPEAR FROM 4 -1/2" OVERSHOT ON TOOLSTRING FISH 1@ 2,098' BLM SET 4 -1/2" UNIQUE MACHINE RELEASABLE SPEAR @ 2,098' BLM HIT TWO OJ LICKS AND UNIQUE MACHINE SPEAR CAME FREE I RESET 4 -1/2" UNIQUE MACHINE RELEASABLE SPEAR @ 2,098' BLM * ** *JOB STILL IN PROGRESS, WSR CONTINUED ON 10/28/2010 * * ** j 10/28/2010 ** *WSR CONTINUED FROM 10/27/2010 * ** (pre adperi PULLED TOOL STRING & 5 -1/2" DUMMY SSSV FROM SLVN @ 2,142' MD (recovered all tools) DRIFTED WITH 2 7/8" DUMMY GUN AND SAMPLE BAILER TO 9,145' SLM WITH NO PROBLEMS (bailer was empty) CURRENTLY RUNNING IN HOLE W/ PDS 40 ARM CALIPER € * ** *JOB STILL IN PROGRESS, WSR CONTINUED ON 10/29/2010 * * ** t j 1 j 10/29/20101 ** *WSR CONTINUED FROM 10/28/2010 * ** (pre adperf) I IRAN PDS 40 ARM CALIPER FROM 9,145' SLM TO SURFACE. (good data) 'DRIFTED W/ 2 7/8" DUMMY PERFORATION GUN & SAMPLE BAILER, TAGGED TD @ 9252' SLM. (bailer was empty) TOOLS HUNG UP SLIGHTLY @ 9,145' SLM ON THE WAY OUT OF HOLE. ** **WELL LEFT SHUT IN, DSO WALK THROUGH UPON DEPARTURE * * ** { 11/6/2010' ** *WELL SHUT IN ON ARRIVAL * * ** (ELINE: ADPERF) INITIAL T/ 1/ O = 1300/ 1350/ 500 PSI PERFO 9125' -9145' USING 2 -7/8" HSD 2906 PJ HMX, 6 SPF, 60 DEG PHASING, API DATA FOR GUN: ENTRANCE HOLE = 0.36'; PENETRATION = 27.7 ". 4 FINAL T/ 1/ O = 1300 / 1350/ 500 PSI. MASTER OPEN, SSV OPEN, SWAB f ;CLOSED. ALL GAUGES OPEN TO PRESSURE, WELL TURNED OVER TO DSO. E ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 10 METH 293 1% KCL 62 DIESEL 365 TOTAL REE = GRAY GEN 3 WELLHEAD = GRAY SAFEfYOES: T x IA LEAK AT SSSV NIP. FHL / ACTUATOR = AXELSON 14=24 TWI - HBBP PKR WAS SQTD W/ CEMENT 12/14/93 KB. ELEV = 72' BF. REV= KOP = 5300' 2142' 5 -1/2" CAM BAL -0 SSSV NIP, ID = 4.562" Max Angle= 29 @ 9000' 2142' 5 -1/2" CA DSSSV, ID = 3.00" (08/03/09) Datum MD = 9210' GAS LIFT MANDRELS Datum TVD= 8800' SS ST MD TVD DEVITYPE1 VLV LATCH PORT DATE 1 2903 2903 1 CA DOME RK 16 08/03/09 2 4817 4817 1 CA DOME RK 16 08/03/09 13 -3/8" CSG, 72 #, L -80, ID = 12,347" 2532' 3 6215 6139 27 CA DMY RK 0 02/10/00 4 7206 7037 23 CA DOME RK 16 08/03/09 5 7757 7550 20 CA DMY RK 0 08/27/00 6 7819 7608 21 CA DMY RK 0 7 8126 7895 21 CA SO RK 24 08/03/09 Minimum ID = 3.00" @ 2142' 8* 8197 7961 21 CA DMY RK 0 5 -1/2" CA DSSSV 9* 8462 8205 24 CA DMY RK 0 02/10/00 10** 1 8531 8268 24 1 CA I DMY I RK 1 0 "CEMENT IN MANDRELS - UNABLE TO PULL 8522' TOP OF CEM SHE ATH 8525' CMT DRILLED OUT 8525' - 8779', ID = 3.625" 8600' 51 /2 " BAKER P 5 -1/2" TBG -PC, 17 #, L-80_0232 bpf, ID = 4.892" 8614' $614' — F - 5- — 1/2 - 7 - 4-T - 2 - 75 1 8624' 9 -5/8" X 4 -1/2" BAKER FHL PKR TOP OF 7" LNR $660' $692' 4 -1/2" CAMCO DB-6 LANDING NIP, $705' 4 -112" BAKER SHEAROUT SUB 4 -1/2" TBG -PC, 12.6 #, N-80, .0152 bpf, ID = 3.958" 8706' 8706' 4 -1/2" TUBING TAIL $760' BOTTOM OF CEMENT SHEATH 9 -5/8" CSG, 47 #, L 80, ID = 8.681" 8974' 8685' EMD TT LOGG 08/ PERFORATION SUMMARY REF LOG: BHCS ON 06/26/83 ANGLE AT TOP PERF: 28 @ 8968' 9177' COLLASPED LNR (01/13/01 VIDEO), PASSED Note: Refer to Production DB for historical perf data ITHRU RESTRICTION w/2.6" BELL GUIDE 12/27/06 SIZE SPF INTERVAL Opn /Sqz DATE UNKNOWN FISH: SL TOOLSTRING (12/21/00) 3 -3/8" 5 8968-8978 0 03/06/03 (BELOW COLLAPSED LNR) 3 -3/8" 4 9161-9186 S 12/06/94 3-1/8" 4 9161 -9197 S 03/09/84 3 -1/8" 4 9202-9212 S 03/09/84 9249 -CEMENT CA P 2 -7/8" 4 9215-9235 0 03/09/84 3 -3/8" 6 10531 -10551 0 07/30/09 9576' FISH - TEL TRIGGER 3.75" X 1.40" X 40" 3 -3/8" 6 10708 - 10732 0 07/30/09 9581' FISH - IBP PBTD 9547' 7" LNR, 29 #, L-80_0371 bpf, ID 66.184" 95$4' TD 9586' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/30/83 ORIGINAL COMPLETION 01/04/07 RRD/TLH 2 EL TOOLSTRING FISH (12/26/06) WELL: 14 -24 01/08/02 RN/TP CORRECTIONS 09/28/09 RRD /SV ADPERF (07/30/09) PERMIT No: 1830910 01/13/03 BHC/tlh MIN ID CORRECTION 09/28/09 CJN/SV GLV C/O (08/03/09) API No: 50- 029- 20970 -00 03106/03 RL/TP ADD PERF SEC 9, T1 ON, RI 4E, 2715.89' FEL & 5249.1' FNL 10/23/06 WTS /PAG GLV C/O 12/07/06 1 KSB/TLH I GLV C/O (11/27/06) BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 bP _-_,:~.~ ~E( ~ °~ 2J~l9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, `` . ~g3-oq! i ~t -apt Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely,. Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # 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 al t4-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA t4-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA t4-06A 2040360 500292032801 Sealed Conductor NA NA 1a-o7 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-O9B 1820340 500292053402 Sealed Conductor NA NA t4-10 1801300 500292052800 Sealed Conductor NA NA 14-itA 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA t4-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 1a-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-18B 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 1a-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA t4-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA t4-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11!24/2009 OPERABLE: 14-24 (PTD #183~0) Tubing Integrity Restored Page 1 of 2 ~ SchwartZ, Guy L (DOA) ~~ 3,0~ From: NSU, ADW Well Integrity Engineer [NSUADWWeillntegrityEngineer(a~BP.com~ Sent: Friday, July 31, 2009 1:53 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Wefl Operations Supervisor; Rossberg, R Steven; Engei, Harry R; GPB, Wells Opt Eng; GPB, E~C Specialists; GPB, Optimization Engr; GPB, Gas Lift Engr Cc: Bommarito, Olivia O; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 14-24 (PTD #1830910) Tubing Integrity Restored All, Well 14-24 (PTD #1830910) has passed a MITIA after setting dummy gas lift valves proving tubing integrity has been restored. The well has been reclassified as Operable and may be returned to production once a live gas lift design has been set. Please let us know if yau have any questions. Thank you, ,~nna ~Du6e, ~.~. ~~~t Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 ~~w~,i` ~~*-~ ,,;; _ - ~r ;r; Pager: (907) 659-5100 x1154 ~ J `~ -` f~~ °' From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 23, 2009 10:19 AM To: NSU, ADW Well I~tegrity Engineer; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; 'Schwariz, Guy (DOA) Cguy.schwariz@alaska.gov>'; GPB, FS3 DS Ops lead; GPB, FS3 DS Operators; GPB, Area Mgr Central (GCi/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Bommarita, Olivia O; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 14-24 (PTD #2830910) Sustained casing pressure due to TxIA communication All, Well 14-24 (PTD #1830910) has been found to have sustained casing pressure on the IA. The well broke MOASP on 07/21/09 with TIO pressures of SSV/2050/700 psi. A TI~L was conducted on 07/22/09 that failed when the IA pressure tracked the tubing pressure during the bleed. The well has been reclassified as Under Evaluation and has been placed under the 28 day clock. The following corrective action has been put in place. 1. D: TIFL - FAILED 2. S: Change out OGLV in STA # 7, caliper 3. D: Re-TIFL A TIO plot and wellbore schematic are attached. Please call with any queskions or concerns. « File: 14-24 TIO Plot.doc» « File: 14-24.pdf» 8/3/2009 OPERABLE: 14-24 (PTD #183~0) Tubing Integrity Restored Page 2 of 2 ~ Thank you, Torin Roschinger (alt. Anna Dube) Weil Integrity Coordinator Office (907) 659-5102 Ceil (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/3/2009 ~ 14-24 PTD# (1830910) TIO Plot a.oor~ .•••••••• 3.00 z,oon ~ I ~ ~ ~ Tbg ^ IA ~, .~~ -~ OA . - OOA ODOA ~ ~ ~~'~ ~ On 14/25/09 05/02.~Oi iiF~ii~~;; ~ ~l3 06113I09 06I20/09 06/27I09 07/04/09 07/11/09 07/16/09 14-24 (PTD # 1830910) UNDER EV.A nON for sustained casing pressnreeX1A commnnication Regg, James B (DOA) Page 1 of 1 From: 'Uti C31 (éL( íJ 7 NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sunday, August 19, 20077:15 AM Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADWWell Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Chebul, Josh M Subject: 14-24 (PTD #1830910) UNDER EVALUATION for sustained casing pressure - TxlA communication Attachments: 14-24.pdf Sent: To: All, Well 14-24 (PTD #1830910) has been found to have sustained casing pressure on the IA. The TIO pressures were 2050/2030/400 psi on 08/18/07 at which time the well failed a TIFL. The well has been classified as Under Evaluation and placed under a 28-day clock. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: C/O LGL Vs 3. D: Re-TIFL A well bore schematic has been included for reference. «14-24.pdf» Please call with any questions or concerns. SCA,"iNED SEP 1 1 2007 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/29/2007 TREE = GRA Y GEN 3 WELLHEAD = GRA Y ACTUA TOR = AXELSON KB. ELEV = 72' BF. ELEV = KOP= Max Angle = Datum MD = Datum TVO = 5300' 29 @ 9000' 9210' 8800' SS 113-3/8" CSG, 72#, L-80, 10= 12.347" I 2532' Minimum ID:: 3.625" @ 8525' CEMENT COLLAR 15-1/2" T8G-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1 1 TOP OF 7" LNR I 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, 10 = 3.958" 1 8706' 9-5/8" CSG, 47#, L-80, 10 = 8.681" I PERFORA TION SUMMARY REF LOG: BHCS ON 06/26/83 ANGLE AT TOP PERF: 28 @ 8968' Note: Refer to Production DB for historical perf data SIZE INTERV AL Opn/Sqz OA TE 8968 - 8978 0 03/06/03 9161 - 9186 S 12/06/94 9161 - 9197 S 03/09/84 9202 - 9212 S 03/09/84 9215 - 9235 0 03/09/84 3-3/8" 3-1/8" 3-1/8" 2-7/8" 4 4 4 4 IPBTD I 7" LNR, 29#, L-80. .0371 bpf, 10 = 6.184" I [iD 9584' 9586' DATE 06/30/83 01/08/02 01/13/03 03/06/03 10/23/06 12/07/06 REV BY COMMENTS ORIGINAL COM PLETION CORRECTIONS MIN 10 CORRECTION ADO PERF '0 KSB/TLH GLV C/O (11/27/06) 14-24 SA NOTES: T X IA LEAK AT SSSV NIP. AiL / lWl . HBBP PKR WAS SQZ'D W! CEMENT 12/14/93 2142' -1 5-1/2" CAM BAL-O SSSV NIP, 10 - 4.562" 1 . GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 2903 2903 1 CA DOME RK 16 11/28/06 2 4817 4817 1 CA DOME RK 16 11/28/06 3 6215 6139 27 CA DMY RK 0 02/10/00 4 7206 7037 23 CA DOME RK 16 11/28/06 5 7757 7550 20 CA OMY RK 0 08/27/00 6 7819 7608 21 CA OMY RK 0 7 8126 7895 21 CA SO RK 24 11/28/06 8** 8197 7961 21 CA DMY RK 0 9** 8462 8205 CA OMY RK 0 02/10/00 10** 8531 8268 CA DMY RK 0 **CEMENT IN MANDRB...S· UNABLE TO PULL 8522' -i TOP OF CEMENT SHEA TH I 8525' -iCMT DRILLED OUT 8525' - 8779',10 = 3.625" 8600' -j 5-1/2" BAKERPBRASSY I -i 5-1/2" X 4-1/2" XO I -i 9-5/8" X 4-1/2" BAKER FHL PKR I 8692' -i 4-112" CAMCO DB-6 LANDING NIP, 10 = 3.813" -j 4-112" BA KER SHEA ROUT SUB -j 4-1/2" TUBING TAIL I -j BOTTOM OF CEMENT SHEATH H ELMO TT LOGGED 08í27/83 I COLLA SPED LNR (01/13/01 VIDEO), PASSED THRU RESTRICTION w /2.6" BELL GUIDE 12/27/06 FISH: SL TOOL STRING (12/21/00) (BB...OW COLLAPSED LNR) CEMENT CAP I FISH - TEL TRIGGER 3.75" X 1.40" X 40" DA TE REV BY COMMENTS 01/04/07 RRDlTLH 2 EL TOOLSTRING FISH (12/26/06) RNlTP BHCltlh RLrTP PRUDHOE BA Y UNIT WELL: 14-24 PERMIT No: 1830910 API No: 50-029-20970-00 SEC 9, T10N, R14E, 2715.89' FEL & 5249.1' FNL BP Exploration (Alas ka) Well o # og Description ate o or Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-06B N/A MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02/19/07 1 03-02 ' 11626072 USIT CORROSION EVALUATION 02/22/07 1 03-02 11626072 US IT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 4-18/S-30 11638613 US IT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 . 11549359 RST 12/26/06 1 1 U-06BPB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWD/LWD 05/08/05 2 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth J b 163 -oq{ # (¿153~5 L 03/15/2007 NO. 4184 Company: State of Alaska Alaska Oil & Gas Cons Gomm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D CI . BL CD . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, ß '.) '>007 Petrotechnical Data Center LR2-1 sCANNED APR V cJ." II 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: /4 ¡'~AP (,þ, (, [no"!, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /ì Received by: Ü... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1518' FNL, 1989' EEL, Sec. 09, T10N, R14E, UM At top of productive interval 221' FNL, 2704' EEL, Sec. 09, T10N, R14E, UM At effective depth 164' FNL, 2691' EEL, Sec. 09, T10N, R14E, UM At total depth 5249' FNL, 2716' FEL, Sec. 04, T10N, R14E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 674488, 5938804~ (asp's 673740, 5940088) (asp's 673754,5940143) (asp's 673722, 5940334) 12. Present well condition summary Total depth: measured true vertical 9586 feet Plugs (measured) 9203 feet Effective depth: measured true vertical 9177.5 feet Junk (measured) 8843 feet Casing Length Conductor 80' Surface 2500' Intermediate 8942' Liner 924' 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-24 9. Permit number / approval number '~J 183-091 10. APl number 50-029-20970-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Obstruction @ 9177.5' MD (01/13/2001). Cement Cap @ 9249'. peri guns & pump bailer tool string in hole as fish below obstruction. Size Cemented Measured Depth True Vertical Depth 20" 400 sx PF II 112~ 112' 13-3/8" 2000 sx Fondu, 400 sx 2532' 2532' PF 'C' 9-5/8" 500 sx Class 'G', 244 sx PF 'C' 8974' 8664' 7" 300 sx Class 'G' 8660' - 9584' 8385' - 9201' Perforation depth: measured Open Peris 8968'-8978', 9215'-9235'. Sqzd Peris 9161'-9197', 9202'-9212'. true vertical Open Peris 8659'-8668', 8876'-8894'. Sqzd Peris 8829'-8860', 8865'-8874'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, N-80 TBG-PC @ 8706'.'i"~ 9-5/8" x 4-1/2" Baker FHL Packer @ 8624'. 5-1/2" Camco BAL-O SSSV Nipple @ 2142' MD. ... ~, ,~ o '~nn') 13. Stimulation or cement squeeze summary IVI~ ~ ~ LuuJ Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/02/2003 155 244 776 211 Subsequent to operation 03/10/2003 156 247 798 209 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 certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · SD tS BFL ORiGiNAL Date March 11,2003 Prepared b~/DeWayne R. Schnorr 564-517~4~ SUBMIT IN DUPLICATE 14-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/20/2003 PERFORATING: DRIFT/TAG 03/06/2003 PERFORATING: PERFORATING 03/07/2003 TESTEVENT --- BOPD: 111, BWPD: 739, MCFPD: 3,205, AL Rate: 3,007 EVENT SUMMARY 02/20/03 <<< WELL FLOWING ON ARRIVAL >>> DRIFT W/2.5" DUMMY GUN. TAG TD @ 9261' ELM CORRECTED. BTM SHOT OF UPCOMING PERFS @ 8978'. <<< WELL FLOWING UPON DEPARTURE >>> 03/06/03 PERF INTERVAL 8968' - 8978' USING A 2.5" POWER SPIRAL ENERJET STRIP GUN, 5 SPF, 45 DEG PENDULUM PHASING. TIED IN TO SWS CBL LOG DATED 30 JUN 1983. SHUT IN WELL & GL TO RIH. DID NOT TAG TD. APl DATA: PENE: 38.6", EH; 0.39", 1.6' FILL. <<< RELEASE WELL TO DSO FOR PRODUCTION >>> 03/07/03 TESTEVENT --- BOPD: 111, BWPD: 739, MCFPD: 3,205, AL Rate: 3,007 Fluids Pumped ~ BBLS 1, DIESEL FOR PRESSURE TESTIN~ SURFACE PRESSURE EQUIPMENT I TOTAL 03/06/2003 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED usING THE 2.5" POWER SPIRAl. ENERJET STRIP GUN, 5 SPF, 45 DEGREE PENDULUM PHASING, RANDOM ORIENTATION. 8968'-8978' Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 72 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1518' FNL, 1989' FEL, Sec. 9, T10N, R14E, UM (asp's 674488, 5938804) 14-24 At top of productive interval 9. Permit number / approval number 221' FNL, 2704' FEL, Sec.9, T10N, R14E, UM (asp's 673740, 5940068) 183-091 At effective depth 10. APl number 50-029-20970 At total depth 11. Field / Pool 5249' FNL, 2716' FEL, Sec. 4, T1 ON, R14E, UM (asp's 673722, 5940334) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9586 feet Plugs (measured) Obstruction @ 9177.5' MD on 1/13/2001. true vertical 9203 feet Effective depth: measured 9177.5 feet Junk (measured) perf guns & pump bailer tool string in hole true vertical 8843 feet as fish below obstruction Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 400 Sx PF II 80' 80' Surface 2460' 13-3/8" 2000 Sx Fondu & 400 Sx PFC 2532' 2532' Production 8902' 9-5/8" 500 Sx Class G & 244 Sx PFC 8974' 8664' Liner 924' 7" 3oo Sx C~ass G 9584' 9201' Perforation depth: measured 9161' - 9197'; 9202' - 9212'; 9215' - 9235'. --~' true vertical 8829' - 8860'; 8865' - 8874'; 8876'- 8894'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8614' MD; 4-1/2", 12.6#, N-80 PCT @ 8706' MD. Anchorage Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER FHL PACKER @ 8624' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE W/DMY SSSV @ 2142' ME). 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 241 1231 571 - 231 Subsequent to operation 205 1402 765 246 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations._X Oil X Gas__ Suspended __ Service 17. I hereb¥,,¢certify that the foregoi~ is true and correct to the best of my knowledge. Signed /~.~ ~/f/'~ Title: DS 14 Surveillance Engineer Date February 9, 2001 Brando~iCFrance f~' Prepared by Paul Rauf 564-5799~m, Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICA 14-24 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/28/2000: 12/12/2000: 12/15/2000: 1 2/19/2000: 12/20/2000: 12/21/2000: 12/22/2000: 12/23/2000: 1/13/2001: RIH w/dummy perf guns & drifted to 9267' SLM. MIRU ELU. PT'd equip. RIH w perforating guns & reperf'd the following intervals: 9202' - 9212' (Zone 4) Reference Log: BHCS 6/26/1983. Used 2-1/2" carriers & all shots @ 4 SPF. Lodged perf gun in hole during POOH. Flowed well. Unable to free so disconnected. Top of fish @ 9167'. FP'd well. RD. Attempted to fish per[ guns w/slickline - no recovery. Sat down @ 9245' WLM. RIH & performed FCO to 9262' CTM w/Biozan sweeps. BOL. Ran LIB to 9156' SLM. Stuck momentarily. Inconclusive marks on LIB. Placed BOL. Ran LIB to 9246' SLM. Made 2 runs wi pump bailer -stuck tools on second run. Dropped Kinley cutter & cut wire. POOH w/cutter. Left 10' of wire, 1-7/8" rope wiresocket, quick connect, 8' of 1-7/8 stem, 1-3/4 oil jars, K J, 1-7/8 short stroke spangs, quick connect, XO, & 2" pump bailer in hole as fish. Ran 3" LIB to 9173'. Tapped down & fell away. POOH w/LIB. Indicated cement nodes or collapsed liner. Ran 3.2 LIB to 9175' - flat circle on edge. Made 2 more LIB runs. Encountered tight spot @ 9156'. LIBS had gouges on sides of lead & on sides of metal. Saw no fishing neck f/lost tools. Killed well w/500 bbls of Filtered Seawater. FP'd well. Performed video log. Recorded obstruction @ 9177.5'. Placed well on production & obtained a well test. Evaluation options to remove fish f/hole. aias?,a Oil & Gas Cons. commission Anchorage Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perlorate _ Pull tubing _ Alter casing _ Repair well _ Other_X (Sqz f/WSO) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_X RKB 72 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 StratigraphY__ Anchorage, AK 99510-0360 Servi~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1518' FNL, 1989' FEL, Sec. 9, T1 ON, R14E, UM (asp's 674488, 5938804) 14-24 At top of productive interval 9. Permit number / approval number 221' FNL, 2704' FEL, Sec.9, T10N, R14E, UM (asp's 673740, 5940088) 183-091 At effective depth 10. APl number 50-029-20970 At total depth 11. Field / Pool 5249' FNL, 2716' FEL, Sec. 4, T1 ON, R14E, UM (asp's 673722, 5940334) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9586 feet Plugs (measured) PBTD Tagged @ 8556' MD on4/07/2000. true vertical 9203 feet Effective depth: measured 8556 feet Junk(measured) true vertical 8291 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 400 Sx PF II 80' 80' Surface 2460' 1 3-3/8' 2000 Sx Fondu & 400 Sx PFC 2532' 2532' Production 8902' 9-5/8" 500 sx Class G & 244 Sx PFC 8974' 8664' Uner 924' 7" 300 sx c~ss G 9584' 9201' ~-.~.~:._~ ..;.,_. ~ ~:- ~ ~ ,~ ,, ¥..,: . Perforation depth: measured 9161' - 9197'; 9202' - 9212'; 9215' - 9235'. .~, ,. .... true vertical 8829' - 8860'; 8865' - 8874'; 8876' - 8894'. ~ ,'. ,~v Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80 PCT @ 8614' MD; 4-1/2', 12.6#, N-80 PCT @ 8706' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2' BAKER FHL PACKER @ 8624' MD. 5-1/2" CAMCO BAL-O SSSV NIPPLE W/DMY SSSV @ 2142' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiFBbl Gas-Mc~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 34 5188 257 Subsequent to operation 221 115 942 269 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas ~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -"'~A-''v,x., ,~ v~-.~ --,'7~v3 ,,, -~ Title ARCO Engineering Supervisor Date Erin Oba Prepared by Paul Rauf 263-4.g90 SUBMIT IN DUPLICA~ Form 10-404 Rev 06/15/88 · 14-24 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE FOR WSO Date Event Summary 2/10/2000: 2/27/2000: 4/04/2000: 4/07/2000: 4/21/2000: 4/22/2000: Performed Injectivity Test. MITIA to 2500 psi - passed. An Acid Wash / Cement Squeeze for WSO (target = channel f/9235' - 9348' MD) as follows: MIRU CTU. PT'd equip to 4500 psi. Fluid packed the well w/Slick 1% KCL Water & Crude. RIH w/CT nozzle & tagged PBTD @ 9387'. Injectivity @ 2.2 bpm @ 300 psi. Pumped 41 bbls of Neat 15.6 ppg Latex Acid Resistive Cement, followed by 34 bbls of LARC w/Fibers to squeeze off the open perforations listed below: 9161' - 9197' (Zone 4) Reference Log: BHCS 6/26/1983. 9202' - 9212' (Zone 4) 9215'- 9235' (Zone 4) Placed 29 bbls behind pipe. Held 1800 psi squeeze press for I hr. Max squeeze press was 2300 psi before breakback. Contaminated Cement w/Biozan & cleaned out contaminated Cement f/wellbore in 3 passes to 9350' MD. Spotted TEA across perfs. POOH w/CT. FP'd well. RD. WOC. RIH w/slickline & tagged TOO @ 8556' MD. Attempted to PT tbg - failed. Brought well online to production. Obtained well test (4 hrs). Page 1 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9250 Company: 2/1 3/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RR Sepia Mylar Disk D.S. 14-24 ~o5,,~.'7 94248 CNTD 061594 1 D.S. 4-19 ~>.~_R ~ 94395 DUAL BURST TDT-P 112194 1 D.S. 14-3 /C'/~'' ;I(~,2,'~ 95027 DUAL BURST TDT-P 061594 1 _D.S. 14-16 94336 DUAL BURST TDT-P 100494 1 , , D.S, 1-22A ~ 95028 CBT SONIC 0112951 .... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED 1995 Thank you. STATE OF ALASKA ALAS[ OILAND GAS CONSERVATION ~ MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 27' FSL, 2723' FEL, Sec. 4, T10N, R14E, UM 5. Type of Well Development Exploratory StratJgraphic Service 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-24 9. Permit number/approval number 83-91 10. APl number 50 - 029-20970 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9586 feet 9292 feet Plugs(measured) Fill Tagged @ 9469' MD (12/1/94) Effective depth: measured 9469 feet true vertical 9114 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 400 sx PF II 80' 80' Sudace 2460' 13-3/8" 2000 sx Fondu & 400 sx PFC 2532' 2532' Production 8902' 9-5/8" 500 sx G & 244 sx PFC 8974' 8664' Liner 926' 7" 300 sx CIG 8660-9584' 8384-9201' Perforation depth: measured 9161-9197'; 9202-9212'; 9215-9235' true vertical 8829-8860'; 8865-8874'; 8876-8894' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 8614' MD; 4-1/2", 12.6#, N-80, PC tubing @ 8706' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 8624' MD; Camco Bal-O SSSV @ 2142' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached JAN 2 4 1995 Treatment description including volumes used and final pressure Ai~ska Oil & Gas Cons. Commission A ~h~,,.- ,-. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 750 1473 2235 - 273 869--~/"' 1790 2150 - 257 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 certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/$8 ~-,,,-, · !~'7 I%AID Title Engineering Supervisor Date //- '/ /<;;~- SUBMIT IN DUPLICATE 14-24 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 2/1/94 - RIH & tagged PBTD at 9469' MD. I 2/6/94' MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 25' of reperforations as follows: 9161 - 9186' MD (Z4) Ref. Log: BHCS 6/23/83. Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED JAN 2 4 1995 Alaska Oil & Gas Cons. Commission Anchor~,~-~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9174 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/5/95 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk I~I ~. 3-13 "7 d'/--~7 ! INJEC PROFILE (12-4-94) I 1 ~_ . 3-14 -7 cl ---~_.- BACK-OFF RECORD (12-3-94) I 1 D.S. 11-24A~~~ PROD PROFILE (12-6-94) I .1 D.S. 14-9B ~~ O~ PROD PROFILE (12-8-94) I 1 D.S. 14-24 ~ ~- ~ PERF RECORD (12-6-94) I 1 D.S. 16-20 PROD PROFILE (12-6-94) I 1 D.S. 17-2 ~0- G~ O STATIC BH PRESS SURVEY (12-10-94) 1 I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~uest ~ W. International Airport Road Anchorage, AK 99618-1199 ATTN: Sherrle NO. 8945 Oompany: I Alaska Oil & Gc~ Cons Corem Attn: Lam/Grant 3001 Porcupine Drive Anchorage, AK 99501 9/21/94 Field: Prudhoe Bay Well / Log Description BL RR Sepia RF Sepia Mylar D.$.4.03 "'~ '~ D~ PROD LOG (9/4/94) 1 " 1 . DS7-13 ~ -' . · . ~ ~ TUBG CUT RECORD (9/1/94) 1 1 D.$.9-20~/ '/ ,- ~/ I . MI INJEOT PROFILE (9/5/94) 1 1 .. D.5.13-33 ~?--" I/~ PROD PROFILE (9/3/94) 1 1 D.S. 14.5A c~-?..,.. ~ j' 'PROD PROFILE (9/1/94) 1 1 D.S. 14-24 j~'~,-~ / _..,, IPROD PROFILE (9/3/94) 1 1 iD.S. 16-31 ~'2~-"" ?.~ PATCH SET RECORD (9/6/94~] 1 1 , , Sl PI copy of this transmittal to Sherrle at the above address. Thank you. ARCO Alaska, Inc. Date- Subject: From/Location: Telephone: To/Location: July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution P.O. Box 100360, .borage, AK 99810,d~~ Transmittal #: 94054 '~~' IeECE. I.VED JUL I ?' 7994 .4~&s~ Oil & Gas Cons. A,~chor. a~ 'C°.rn~SsliO,n iWell i Log Date · Number. (M-D-Y) ! (~O I 1-05ST ! 6-21-94 0%, ! 1-17 i 6-20-94 2-20 ! 6-18-94 2-28 ! 6-28-94 . 3-2 I 6-22-94 4-2 i 6-17-94 ! 4-30STI 6-25-94 ~'5~ ! 4-40 ! 6-25-94 4-43 !,6-23-94 4-44 i 6-20-94 4-45 i 6-25-94 5-03A I 6-9-94 '~ ! 5-03A ! 6-9-94 \i 5-03A i 6-9-94 7.J.p ! 5-13 i 6-17-94 (05 i 5-33 ! 6-29-94 '~?_.. ! 6-8 ! 6-15-94 i 6-12A I 6-24-94 7-6 i 6-28-94 Tool Type i Run, 1. Scale Prod Prof i 1,1"&5" / Prod Prof i 1, 5" IBP Setting Rec i 1, 5" Leak Detection i 1, 2" & 5" / Leak Detection ! 1,1"&5" Patch Set Rec i 1, 5" / Perf Rec i 1, 5" /' Per[ Rec i ~' Comp Rec ! 1, 5" Contractor SCH SCH SCH SCH SCH SCH SCH 1, 5" SCH [ Slim 1 GR / Perf Rec ! 1, 5" ~'~ Per[ Rec ! 1, 5" " CDN i 1,2" &5" 2" 5" i 1, & CDR i 1, 2" & 5" · ,-Leak Detection i 1,1" & 5" -' Per[ Record ! 1, 5" / TDTP I 1,5" .-- Per[ Rec I 1, 5" f Per[ Rec I 1,5" ~ i 7-26 i 6-19-94 t.,. Per[Rec Per[ Rec ! 1, 5" ~ ./! 9-05A i 6-21-94 ! 9-05A i 6-22-94 I~l;' 9-30ST 6-29-94 .~ Per[Rec I 1, 5" '" Dual Burst l 1, 5" 6-22-94 /"' Prod Prof 6-27-94 6-28-94 6-27-94 6-27-94 6-28-94 6-27-94 6-30-94 I 1, l"& 5" ..-" Per[ Rec i 1, 5" · -'" Ini Pmf i 1, 5" -"Leak Detection '~- Inj Prof /~ Ini Pmf ~ Prod Prof , 5II 1,5" 1, 5" 1, 5" Per[ Prof i 1, 5" CNL I 1, 5" 1, 1" &5" 1,2" 6-15-94 6-19-94 i /'Leak Detection 6-19-94 r Leak Detection 6-20-94 ~ '" Per[ Rec 1 5ll ~'!~~7--5 i 11-29i 12-02 12-7A ~ i 12-19 ~t I12'23 12-28 ~::~}~ ~ 13-08 14-24 [3%~ 14-39 14-39 G2._ ! 16-28 SCH i SCH SCH SCH SCH i SCH SCH SOH SOH SCH. SCH SCH SCH SCH SCH SCH SOH SCH SCH SCH SCH SCH SCH SCH SCH SCH f SCH * DS# 04-02 The APl# is $0-029-20088-00 Number of Records: 35 ARCO AlasKa, Inc. is a Subsidiary of AlJantlcRIchfleldCompany __.. STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC /IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 5. Type of Well Development Exploratory Stratigraphic Service 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 27' FSL, 2723' FEL, Sec. 4, T10N, R14E, UM 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-24 feet 9. Permit number/approval number 83-91 10. APl number 50 - 029-20970 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9586 feet 9292 feet Plugs(measured) Fill Tagged @ 9446' MD (6/15/94) Effective depth: measured 9446 feet true vertical 9079 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 400 sx PF II 80' 80' Surface 2460' 13-3/8" 2000 sx Fondu & 400 sx PFC 2532' 2532' Production 8902' 9-5/8" 500 sx G & 244 sx PFC 8974' 8664' Liner 926' 7" 300 sx CIG 8660-9584' 8384-9201' Perforation depth: measured 9161-9197'; 9202-9212'; 9215-9235' ORIGINAL true vertical 8829-8860'; 8865-8874'; 8876-8894' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 8914' MD; 4-1/2", 12.6#, N-80, PC tubing @ 8706' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 8624' MD; Camco Bal-O SSSV @ 2142' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. 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-Md Water-Bbl Casing Pressure Shut-in 863 1070 2710 Tubing Pressure 234 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~ ~, ~-'~'L' ~'a'~t'~-it lo Engineering Supervisor Form 10-404 Rev 06/15/88 4 4 ~"~ 4 I/'~ ,f'~ L'~ L''~ ----, I I'~ I-'~ Ii & irq~ Date '~/~, / f'~'- SUBMIT IN DUPLICATE 14-24 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE OF LEAKING PACKER 8/30/93: Performed a Leak Detection log that indicated the Baker 'FHL' Packer was leaking at 8624' MD. 9/23/93: MIRU & PT equipment to 4000 psi. RIH w/CT mounted Inflatable Bridge Plug, and set in the 7" liner at 8835' MD, above the open perforation intervals located between 9161' MD & 9235' MD. Pumped 11 bbls of Gelled Sand Slurry containing a total of 2950 lbs of 20/40 mesh sand, to spot a sand plug on top of the Bridge Plug to 8730' MD. 9/25/93: Completed an MIT on the tubing; passed. 11/19/93: RIH & tagged top of sand plug at 8787' MD. 12/5/93: POOH w/CT. Rigged down. RE EiVF_,D dUL 11 1994 Alaska 0il & Gas Cons. Commission Anchorage MIRU CTU & PT equipment. RIH w/CT & tagged sand plug at 8767' MD, then pumped 10 bbls Seawater to establish injection up the 9-5/8" past the packer. Fluid packed wellbore w/Hot Seawater from bottom, then switched to pumping 2 bbls Neat Latex Acid Resistive cement, followed by 9 bbls Latex Acid Resistive cement w/40 lbs Polypropylene Fibers/bbl, followed by 35 bbls Seawater Flush, followed by Shutdown. Took returns up 9-5/8" x Tubing annulus, then switched to taking returns up Tubing, w/CT nozzle in the Tubing Tail, before Shutdown to let well stabilize. POOH w/CT while holding pressure on the tubing & circulating Meth Water. Left well w/estimated cement tops at 8567' MD in the tubing, & at 8547' MD in the 9-5/8". Rigged down. 12/6/93: RIH & tagged top of cement in the tubing at 8522' MD. 12/8/93: MIRU CTU & PT equipment. RIH w/CT mounted 3-5/8" Carbide Button Milling assembly, and drilled cement from 8525' to 8709' MD. Circulated wellbore clean w/Biozan Gel. POOH w/CT. Rigged down. 12/9/93: MIRU CTU & PT equipment. RIH w/CT mounted 3-5/8" Milling assembly, and drilled cement from 8709' MD to 8779' MD before breaking into the sand plug (above). Circulated wellbore clean w/Biozan Gel. POOH w/CT. Rigged down. 2/23/94: PT 9-5/8" Packer Squeeze to 2000 psi; passed test. 3/22/94 - 3/23/94: MIRU CTU & PT equipment. RIH w/CT to jet a fill cleanout, but could not pass 8655' MD. POOH w/CT & RIH w/a 3-5/8" CT mounted milling assembly. Milled down to IBP at 8851' MD, then backreamed OOH while circulating Biozan. MU fishing tools & RIH to retrieve the Bridge Plug. Could not pass work tools past 8834' MD; suspected cement cuttings on top of plug. POOH leaving internal grapple from hydraulic overshot downhole. Rigged down. 3/29/94: MIRU CTU & PT equipment. RIH w/CT & jetted a fill cleanout w/2# XCD Gel, and tagged top of Bridge Plug at 9480' MD (slid downhole). Attempted to latch IBP. POOH without plug. RD. Placed the well on production w/lift gas & obtained a valid welltest. Drill Site: 14 Well: 24 K-VALVE DESIGN Sun Apr 17 14:50:02 1994 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A, B, C ): 190 PSIG @ 60 DEG F 204 PSIG B COMMENTS- Dump pressure close to normal FTP, so well will have to be choked back to keep from dumping. Test K-valve by opening choke. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) J.E. Fausett / S. Piggot PRB 13 (COVER ONLY) R.J. Reints (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: L A Boughton ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~-'~-.chorage, AK Mar 15,' 1994 Transmittal #: 94029 ~_ John E. DoGrey/ATO- 1529 (907) 263-4310 Distribution 9951°,d~ ~' iweilNumber iL°g Bate(M'D-Y)Tool Type l RUn,scale Contractor tlc~ i 01-02 I 2-26-94 Prod/Spin/TempI.~,~;..~ 1,5" Schlumber I 01-03I 2-19-94 Prod/,FBS/Temp~'~ 1,5" Schlumber ~(~ i 01-09 I 3-01-94 Tubing Cutter ~ 1, 5" Schlumber %~ i 01-11,, 2-27-94 Prod Prof/Spin ~ 1, 5" Schlumber Z-ct i 01-18 ! 2-23-94 Leak Detection I 1, l"& 5" Schlumber ?..b'5i 01-25 ! 3-06-94 CNL I 1, 5" Schlumber uf~ ~3-20A i 2-17-94 Peri i 1, 5" Schlumber 'k03-20A I 3-03-94 Dual Burst '1'¢:i? 1, 5" Schlumber ~D'~ i 03-32 I 2-26-94 Leak/Press/'l'emp 1, 2" Schlumber L~2 I 03-34Ai 2-24-94 Prod/Press/Temp 1, 2"&5" Schlumber i 04-01f 2-19-94 Prod 1, 5" Schlumber ~* I 04-24 ! 2-22-94 Prod 1, 5" Schlumber ~ ! 04-40 ! 2-22-94 Peri 1, 5" Schlumber [a,~ ! 04-46 ! 2-16-94 Rope Peri 1, 5" Schlumber (-2'~ ~/04-47f 2-18-94 v Perf 1, 5" Schlumber ~ 04-47 f '2-15-94 ,/CBT-GR 1, 5" Schlumber ~Ob5°6II 2-11-94 Perf 1, 5" Schlumber ~I~f 05-i4A I 7-11-93 USlT/Cem&Oorr ('j~"~l, 5" Schlumber ~l~' I 05-15AI 05-15A ~ GND/GR-t.v,~:~%t.. 1, 5" Schlumber ~t'~i 05-26 3-02-94 Dual Burst 'ID'I(' 1, 5" Schlumber 2'2. /'06-15 2-21-94 Prod 1, 5" Schlumber \ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 5-'~- 06-22A 3-01-94 Perf 1, 5" Schlumber ~1o 07-08 3-02-94 Prod~ ~ 1, 5" Schlumber Iq~ 07-23 3-07-94 Leak/Spin/Teml~ ,~ 1, 5" Schlumber Iz~ 09-34 2-21-94 Tubing Cutter ~ 1, 5" Schlumber r4~ 11-02 2-10-94 Inj Pmf/~~f~, 5" Schlumber ~ /11-04 2-20-94 Tubing Cutter ~.. 1, 5" Schlumber i~11-04 2-17-94 Tubing {)~r..~f ¢v_.J, 5" Schlumber t"'Jr~ 11-7ST 3-06-94 Inj Prof/Spin ~ It"C-- 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ~ 16ST /Spin/~,¢4, IX111'6ST 3-08-04 Comp/l~l~table I ZoCo--,%~.~" 5" oSChlumber ~ 1/11-17 I .2-20-94 Leak 1, 5" Schlumber 1-17 i 3-08-94 Prod 1, 5" Schlumber ~1,% i 11-23! 8-09-91 TMD 1, 5" Halliburton ~ J/11-24At 3-05-94 Peri/GR/CCL 1, 5" Schlumber 1-24At 2-22-94 Comp/Peri t 1, 5" Schlumber q LSo-~ It 5~6o--~1t~5o %co0-~isq o ARCO Alask~ In¢. Is · Sub~l¢lary ol 2coo-~o~oo 4-24 the correct Number ot RecordS: n ~. oeGre¥ Centr~ l:[les /xNO-8 Ois~ribUt~°n: ChevfOO EX~0 ...B~%.~.O~..Nas~~ .. Mob~t - ~ coP~ o~ transmitter. -:State , : -- ~-~ m RECEIVED ARCO Alaska, Inc. P.O~ox 10036O Anchorage, Alaska 99510 DATE: 10-8-93 1-11 4-29 ~-1 6-17 -2~ ~-2~ ~-~-7-8 11-25 11-28 13-1 14-24 ~5-18 15-3o 16-7 ~17-21 8-29-93 Prod Proflle/f~~~> R~_m 1, 5" I~0~~ch 8-29-93 Prod Proflle/~-aai~z~ Run 1, 5" ~u00-~\~0Sch 8-29-93 ~od ~offie (~¢~~~~ 5" 9-7-93 ~j ~offie & S~cl~[~~~ 5" ~~Sch 9-7-93 ~j ~offie & S~tic]~'o~'~ 1" -~ 5,'~o-t~ch 9-3-93 ~ml B~t T~P R n L 5" 9-8-93 ~j ~offie & Static I~1~~'' ~?~-a,~ Sch 9-3-93 ~ml B~t T~ R~ 1, 5"~~o Sch 9-4-93 Pe~ Record ~-~o~ R~n 1, 5" Sch 9-4-93 Pe~ Record ~-~ R~ 1, 5" Sch 9-10-93 ~uc~on~al~]~e R~ 1, 1"&5" 0~ Sch~ 8-31-93 USIT (Cement) Color R~m 1, 5"~ 8-31-93 USIT (~sion) ~lor R!!n 1, 5"t~l~sq Sch 9-2-93 ~ B~t ~ R~m 1, 5"~~- Sch~%5 9-10-93 ~od ~offie~O[~~ R~ 1, 5'~ Sch 8-29-93 ~od ~offiel~l~~ R~ 1, 5" 9-5-93 C~ t~ ~1~~ Rim 1, 5" Sch 9-12-93 ~P ~%o R~m 2, 5" Sch 8-30-93 ~ ~tecti~l~R~m 1, 2" 9-10-93 Pe~ Record ~ zz~-~ R~ 1, 5" Sch 9-3-93 GR/CCL (TCP ~e-~) R~ 1, 5" 9-5-93 ~ ~/ae,a/~/~/~ R~m 1, 1"&5" 9-7-93 ~~ ~-~ R~ 1, 1"&5" Sch 9-4-93 Pe~Record ~a~o R~m 1, 5" Sch RECEIVED BY~~~~_-~_ '~ Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL the attached copy as receipt of data. APPROVED__.~~__ Trans# 93109 # PHILLIPS PB WELL # BPX # STATE OF The correct top logged interval for this log is 12,900 feet. The correct top logged interval for this log is 10,400 feet. Drill Site: 14 Well: K-VALVE DESICN Thu Apr 15 08:03:17 1993 DOME 'SET PRESSURE: 145 PSIC @ 60 DEC F FTP @ CLOSE (PSIC): .160 PSIC K-VALVE CLASS (A,B,C): C mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~ COMMENTS: Decrease in total fluids and increase in wc prompted this new design.Will have to pull to test. Well is currently choked back, but has been wide open within the last week with little affect on the ftp, so CC:~NEERINO FILE / COORDINATOR (WITH ATTACHMENTS) ~.c. SM~ / M.C. s~omeu= (WITHOUT ATTACHMENTS) J.E. FAUSETT ! C.W. SHUMWAY (COVER ONLY) PRB 24 PRB 20 PRB 13 J.L. Bacak AT) 1578 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) RECEIVED APR 2 7 1993 Alaska 0il & ~as Cons. Commi~ion Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-12-93 REFERENCE: ARCO CASED HOI.~- FINALS ~~-42 ~~9-49 4-24 ~Z-'IZ0 AGI-2 ~ a~.AGI-3 8-4-92 TMD (Boron) 7-3-92 DSN **Corrected** 1-2-93 USIT Color 1-3-93 CBT Color 1-3-93 USIT Color 12-9-91 TMD 1-9-93 Segmented Bond/GR/CCL 1-14-93 Segmented Bond/GR/CCL R11ri 1 t Run 1, R._n 1, Run 1, Run 1, Run 1, R!!n 1, Run 1, Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace ATO-1529 APPROVED___~ Trans# 93031 5t~ 5' 5" 5' 5' 5" 5' 5' HLS HLS Sch Sch Sch HLS Atlas Arias # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA. TEXACO RECEIVED MAR 1 9 1995 Alaska 0il & Gas Cons. Commission Anchorage // P.O.Box 100360 [...._jch~rage, ~ REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS I Job~L91977~ HI~ TMD l~m I Job~7604~ HLS TMD Rml I Job~I2~7(Lg-3 HL~ Tltd~ l~m I JOb~L751~6-8 · · DSN Run 1 Job~18-6 TBID Run -r~rr~ (Borax} Run DSN Run TMD Run DSN Run TMI~ Yum z,zJzi-xOu/c, ic gzm HL8 1 Job~L84771-5 HIS I J0b~l~2~ li~ci~ I J~~71~ ~ I J~~71~3 ~" I J~l~ ~ ~ 1 J~~ lths ' Please sign and return~e ,t~.hed copy as .receipt of data. RECEIVED B~<~_ ~_~ # CENTRAL FILES (CH) CHEVRON D&M BOB OCANA~ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 1-5ST is 50-029-20076-00. Drill Site: 14 Well: 24 Y3- ?/ K-VALVE DESIGN Sat Nov 14 16:11:56 1992 DOME SET PRESSURE: 170 PSIG @ 60 DEE F FTP @ CLOSE (PSIG): 170 PSI~ K-VALVE CLASS (A,B,C): C COMMENTS: Current design may dump - if pulled, this should be CC: / W.D. COOPER J.C. SMART / M.~. SHOEMAKE J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 T.L. RUT ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: MMM RECEIVED NOV 1 9 1992 Alaska Oil & (~as Cons. Commission Anchorage Drill Site: 14 Well: 24 Sat Nov 14 15:51:42 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2142 FTP @ CLOSE (PSIG): 170 PRESS ADJUSTMENT: 63 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR GLR LIQ 84 0 236 1395 65.1 5537 1928 4005 'CONDITIONS AT CLOSURE: 84 0 170 1416 65.1 5537 1928 4065 WELL TEST @CLOSE TEMPERATURE @ SSSV: 173 173 PRESSURE @ SSSV: 362 300 SEP COML PWF PI TEMP PRES DATE SEL 905 1.45 158 0 11/12/92 Y 810 1.45 158 0 DOME SET PRESSURE: 170 PRIOR DESIGNS: DATE: 05/01/92 SET PRESSURE: 185 FTP @ CLOSURE: 160 TEMP: PIPROF 03/31/92 185 170 LINEAR 10/29/91 190 170 LINEAR · · ESC=EXIT; Fi=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITi~ITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..24083e-3 N= 1.000000 NEW C= ..21156e-3 ENTERED N= 1.000000 Drill Site: 14 Well: 24 SENSITIVITY TABLE P.I. 1.45 1.45 1.45 1.45 %WTR 65.0 70.0 65.0 70.0 GOR 5550 5550 6000 6000 : LGR 0 0 0 0 FTP 1 236 363 363 366 364 FTP 2 170 300 296 306 300 FTP 3 100 247 237 256 245 Sat Nov 14 15:56:46 1992 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fi=HELP; F2=WELL TESTS; F3=DESI~N; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Drill Site: 14 Well: 24 COMMENTS: Sat Oct 26 07:57:56 1991 K-VALVE DESIGN t DOME SET PRESSURE:. 190 PSIG @ 6O DEG F FTP @ CLOSE (PSIG). 170 PSIG K-VA.LVE~.~S (A,B,C): C New design to reflect increasing GOR Bench test K-Valve CC: C.P. FARMER / W.D. COOPER J. C. Smart / M. G. Shoemake J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 J. L. Bacak ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: Kara ID~ Printing contents of current screen - wait for message to clear O V O /' ' Alaska Oil & Gas Co,~. ? / Anchorage Drill Site~ 14 Well: 24 Sat Oct 26 07:49:45 1991 K-VALVE DESIGN SSSV DEPTH (MEAS): 2142 FTP @ CLOSE (PSIG): 170 PRESS ADJUSTMENT: 42 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR GLR LIQ 86 0 225 1807 56.8 5611 2423 4184 CONDITIONS AT CLOSURE: 86 0 170 1841 56.8 5611 2423 4262 WELL TEST @CLOSE TEMPERATURE @ SSSV: 171 171 PRESSURE @ SSSV: 365 322 SEP COML PWF PI TEMP PRES 882 1.50 156 0 830 1.50 156 0 DATE SEL 10/10/91 x DOME SET PRESSURE: 190 PRIOR DESIGNS: DATE: 04/0'8/91 SET PRESSURE: 185 o o 1o 18 o FTP @ CLOSURE: 170 TEMP: LINEAR 0 NA 0 NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 24 Sat Oct 26 07:54:07 1991 SENSITIVITY TABLE P.I. 1.50 1.50 1.50 1.30 %WTR 56.8 56.8 65.0 60.0 GOR 5611 6500 ... 6000 6000 LGR 0 0 0- 0 FTP 1 225 365 375 359 347 FTP 2 170 322 335 312 300 FTP 3 100 282 300 267 256 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Printing contents of current screen - wait for message to clear MEMORAhdUM State of Alaska 'ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Commissioner DATE:October 30, 1991 FILE NO:HH1030-7.DOC THRU:Blair Wondzell Sr. Petr. Eng. TELEPHONE NO: SUBJECT:Bench Test K-Valve AAI PBU DS 14-24 Prudhoe Oil Pool FROM: Harold R Hawkins Petr Inspector Sunday. october 27, 1991 I witnessed a K-valve being dome charged and bench tested to trip and close at 190 PSIG @ 60 DEGF, serial no. KO-9A for AAI PBU well DS 14-24, at Otis Workshop in Deadhorse. Mark Sant with Arco was present at the test. The valve was tripped 4 times before accepted as a good test. In summary, the K-valve serial no. KO-9A to be set in AAI PBU DS 14-24 was tested satisfactorily. Attachment 02-O01A (Rev. 6/89) 20/11/MEMO1.PM3 Drill Site: 14 Well: 24 K-VALVE DESIGN Sat Oct 26 07:57:56 1991 DOME SET PRESSURE: 190 'PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 170 PSIG K-VALVE CLASS (A,B,C): C COMMENTS:. New design to reflect increasing GOR Bench test K-Valve CC: C.P. FARMER / W.D. COOPER J. C. Smart / M. G. Shoemake J.E. FAUSETT / C.W. SHUMWAY ENGINEERIN~WELL FILE' PRB 24 PRB 20 PRB 13 J. L. Bacak ATO 1578 STATE OF ALASKA (COVER) DESIGNED BY: Kara ID~ -. Printing contents, of current .screen - wait for message to clear Drill Site: 14 Well: 24 K-VALVE DESIGN Thu Mar 21 13:4.6:20 1991 DOME SET PRESSURE: 185 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 170 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: Bench Test K-valve C.P. FARMER /~% PRB 24 K.M. KENNEDY / W.S. WILDER PRB 20 J.P. WINTERS ! C.W. SHUMWAY PRB 13 ENGINEERING WELL FILE M.O. JORNSON ATO 1552 STATE OF ALASKA (COVER) DESIGNED BY: KABA Printing contents of current screen - wait for message to clear ARCO ALASKA: iNC,. l:'~ E-'. ,, Bt];-': "i 00:360 ANCHOR. AGE, ALA,.SK A .. D A T Fi ' '7 - ,-'5 ':') -90 99~ 1 E:, F' k U i D I:;.: i-.':: 21,5; 7' l V 'J; '[' Y F !_ U I b F.'. E $ .[ $ T ! V I T Y P-'.:...-'. F:. F ,.-.;, i::- r'- ,] i;, i-; F, i:.- ~:;, i_- i:;.,, i::,", rq R D (": B T ,_.r'F-T C-R 'iN CASING ~:', ~:",_ i:;.'. F' F:'. F_._.. ~, .r' ni.;, O. C 0 i.. L. A Fi: / P rz F.'. F C'OI_~ F'i...U i' D RF'3-'i,?. T ]: V i TY Ci"i RE,5't E'. TIV l TY FL. UID i:;.'. E 2 i ::.:T ]: V l' T Y C'. 0 L L A F.'. / F' E R F i'-'i-~' ' A --, /Fd'~-- , - .... t_Ltal',.; ~ .-_RF F,'.t.J N i , i.;:U Ni , I:;.'. t.j N i, RUN i , Fi: U i'.-! 'i , F,.'tJNi, F;.:tJ N 'i , F.:UN !, F;.'.tJ N 'i , RUN i, I:,: U N i , RIjN i, RtJN i, RUN i, RUN i, F' !_ E A :",,-' E SIGN AND..._F.'F---TilI-;'N, ._.... T!.-!IE ATTACHED COPY Av... SAI...L.Y HOF'FEC:K EF;:. ATO-'i 529 RECEIF'T OF' DR'[A. APF'ROVED~ T RANS:.": 9 11 Ia il -., I;? II (N ..:' II II ii D I :'-]' T R I BUT I ON :'" f:: ~"-~ 'r i;,' A L FILES :~ PFtILL IF':i: CI-!EVF.:ON F'B WELL FILE..";: D & M R & D FXTENSiON EXPLORATIOh! ~ .f'": F' X i:'--"'X'ON -{: ~.'TAT~'. IjF ALA;SKA HARATHON TEX~C{] MOBIL PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-24 Date: 7/1 ~/90 Comments: K-valve continues to dump early. Commonline pressure swings below 200 psi. New design needed to drop FTP at closure to keep away from swings. C catagory valve Previous K-valve Settings: Production Data: ROR = 1900 BOPD CFR = BOPD Swing Well (very high or Iow GOR)._ ............. No Design Parameters: Design parameters are based on (Mark one of these) Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Set Pressure, psig Date 180 6/23/90 190 3/8/90 @ 9 0 deg. choke @ deg. choke Choke Priority Well ..................... no Actual Well Test .....Date of Test ....................6/7/90 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... 18OO BOPD 5 9 percent 4045 scf/stbo 0 mscfpd 1654 scf/stbl 205 psig 161 deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 174 deg. F 340 psig 55 psig Calculated Dome Set Pressure = 162.2 psig @ 60 deg. F !Actual Dome Set Press. 160 FTP at K-valve Closure = 1 60 psig @ 60 deg. F I psig ~ surface I cc: Ferguson / Farmer -/~4,~J'~' Wilder/ Kennedy (2 copies) State of Alaska cc: D.S. Engnr. J. Michels ATO 1554 D.S. Supvsr. Shumway/Winters PRB#15 Prepared by J. Scheidt WT44,14-24,12 07-11-90 1403 ~ELL DATE 14-24 06-07 14-24 (i6-07 14-24 04-30 14-24 04-£~ 14-24 03-23 14-24 03-02 t4-24 02-01 14-24 01-09 ~4-~4 12-03 14-24 10-01 14-24 09-!3 i4-24 08-31 WELL ENTRY NO. NO. 14-24 12 I1 i0 9 8 7 6 5 2 1 AVG TIME CHOKE ~P FTP COMP POS TEMP TEST 1016 85 161 2~ 0701 85 1~- 2M 2~I 85 16~ ~6 1'401 85 1~ 2~ 1516 86 162 2~5 0~, 85 161 ~7 2106 ~, 160 0756 66 163 257 15~8 55 165 275 1445 85 167 234 1614 86 1~ 340 [~qTE TIME 04-30-90 0~-~c,-90 21(~1 03-23-90 1959 03-02-90 1745 (8-13-89 2330 08-14-~ 0200 06-25-89 1100 03-31-89 12-05_,-88 1600 10-20-88 2300 !0-15-88 22~) WELL TEST REPORT AVG S~ OIL PRES STBD TESTED RATES TOT~ LIFT FORM WTR GAS GAS % GOR BPD MSCFD ME~FD WTR S4~F/B TOTAL TEST OLR LENGTH SCF/B HOURS 2(~5 1774 2.~71.. 7176 o. v=°, 4045 220 1695 2414 6726- 0 59 3968 ~o9 1975 2481 8163 0 56 4133 210 19~r2 145- 8396 0 7 4215 211 1966 2646 ...~,:°~' ~.i.~ 4157 o~-, 1881 -,o~ 845~ 0 ~ 4482 ~ · ~ ~ . .. 199 ~76 2732 8512 0 57 22~ ~105 26~ 85~1 0 56 4076+ ~I~ ~ ~.,, 7778 o. ._ 3406 204 -,~,o~.,~. 2644 ~o~,,,.~., o. 52 3207 209 2514 2767 76S9 0 52 3~6 217 ~ 271I 7067+ 0 55 3184+ 1651 1637 1832 3929 1772 1791 1770 1810 I~O,D 1545 1450 1433 2,° 3.0 8.6 7.9 8.0 7.8 8.0 8.0 7.2 8.0 7.9 12.4 WELL SH~:E-[&!T [~TA PER[ENT PERCENT H2S PER LCE: SAMPLE ~TER EYJLI[6 MILLION ENTERED BY TAKEN FROM 60. L~ O. CE) PRO[kE:TiON SEPARATOR 60.¢~ 0.00 PRODL~TION HEALER 55.5~ 0.00 PRO[EICTIC~4 HEADER 56.~ 0.00 ~O[&ICTION 50.50 O.(X~ PRO[~:TION HEADER 49. O0 10.0 PRO[&E:TION HEAIER · _~.00 0.00 0.0 PRO[~E:TI~ HEADER 11.0 PROJECTION SEPARATOR 54.00 0.00 PRO~]CTION HEADER 47.00 0.00 PRO~.~TION SEPARATOR 41.(~) 0.00 ~O[~]CTION HEADER 48.[~ 0.00 5,0 PRODUCTION HEADER ..... EXPECTED .... FORM TT AF ORIFC OIL GOR % SY LL DIA STBD SCF/B WTR T P L G INCHES 1964 4157 57 NRNG 5.(~ 1956 4153 57 ERNG 5.00 1961 4154 57 NRN O 4.00 1960 4153 57 E RN B 4.00 lOA~ 4484 ^o NR Y n 4.(~ ~ ~ - . . 2132 4103 56NRNG 4.5~ 2140 4111 56NRN G 5.00 2433 3183 ~.~ERNG 4.00 2464 3221 52NRNG 3.25 2478 3010 52NRN G 5.50 2306 3236 55NRN G 4.~X~ 2390 2482 51EDNO 4.00 ARCO ALASKA, ][NC~ P,. 0_. BOX ANCHORA&]E " "'"~KA , DATE · i -2-9,3 REFERENCE' ARCO CASED HOLE FINALS - "; ~' R U N ~'"" · .-_. t ,':; - ""--'- 8 9,, .- ~_ THD i , _. -26 i ,';;-2.. i -89 TMD Rl_,lxl. i , r.~.,., 4-i 6 i;3-26-89 GAMMA DSN RUN i , 5 '~ 4'-24 i':~'-26-89 GAMMA D2. N RUN i , 5" . '= - ~ z,. i ~-~, ''~ o _ o c., G A H M A P ~- ~'~ R U N i , =':" PLEAZE $:[(-;N AND F:.ETUF'.N "FHE ATTACHED COF'Y AS REC, EIF"¥ OF DA'FA, RECEIVED BY ...... HAVE A NiCE r:,AY; JAN 10 £ALLY HOFFECKER ' A'r o- ~: ~',.~ ? Alaska Oil ~ ~ An~o~ge A P F:R 0 V FZ i):.~ ~.~~ ~__ 'i'RAN'~J ~- 9 HL.S Fi !_ ;".-.~ HL.,S' Hi_$ .i.) I 'J..' T R I BUT ]: ON '".,-C, ENTRAL FILEY '" CHEVRON D & M ~,. FXTEN$ION EXF't_Ot'~AT I ON '"' EXXON HARATI40N "- MFIRII_ F'I-I ILL I F',S' F'B WEI. I_ R & D BPX YTATE OF ALAYI<A TEXACO ARCO r-~Li~KA, INC. F'~O. BOX i':".~036('D ANCHORAGE, ALASKA 995i0 DATE' -t-°-¢e~ , REFERENCE' ARCO MAGNETIC TAPE(S) WITH LISTING(S) -25 i 0-22-89 TMD '~6 i,q 2i-°o TMD 4-i 6 1 0-26-89 GAMMA DSN 4-24 ~ ~-26-89 GAMMA DiN 5-i 4 t 0-28-89 GAMMA DSN JOB:~iS6400 JOB~iS6S9X JOB:~367279 JOB~S6728X JOB:~S6'?290 F'i_EASE SIGN ANI) RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. H!_S H I..."--,' F-ILS FIt.$ HLS RECEIVED BY HAVE A NICE DAY'! RECEIVED 'DALLY HOFFECKER JAN 1 0 t990 ATO-i 529 A;a~ka 0~I;~ % Cons. Anchorage DISTRIBUTION UENTRHL FILES ~',CH) CHEVRON D & M TAMMA£' BROWN (OH) EXXON MARATHON ~OBIL AF'F'ROVEI) ~~_ TRANS~ 90 _ ..--"' PHIL. LIPS F'B WELL FILES R & D -'" BPX STATE OF ALASKA TEXACO ARCO ALASKA, F'~O. BOX i00360 ANCHORAGE, ALASKA 995 t 0 DATE' .9-48-89 REFERENCE' ARCO CASED HOLE FINALS 4-7 8-23-89 PRODUCTION PROFILE 2-4 9-2-89 LEAK DETECTION SURVEY 2-4 9 8-24-89 F'IT$ 3-~6 8-25-89 INJECTION PROFILE 4-'5 8-3(D-89 STATIC TEMF' SLIRVEY 4-t9 8-29-89 STATIC TEMF' SURVEY 4-t 9 8-30-89 TERP FM 6- i 4 9- t (D-89 COLLAR 7-i'~ 8-34-89 LEAK DETECTION SURVEY t~_~-"~t~. 8-30-89 TEMF' SURVEY t3-22 8-34 -89 INJECTION FROFILE 4-.-~ 8-30-89 PRODUCTION PROFILE t4-24 8--~t-89 PRODUCTION PROFILE t4-34 8-30-89 PRODUCTION PROFILE t6-4 8-4 3-89 LEAK DETECTION i7-7 5-t9-89 LEAK DETECTION i7-it 5-19-89 LEAK DETECTION RUN l, RUN t, 2' RUN RUN 4, 5' RUN '~l · · RJN RUN t, 2' RUN RUN l, 2'&5' RUN RUN RUN RUN t, 5' RUN t, 5' RUN t, RUN£ t-~, RUNS F'LEASE SIGN AND RETURN THE ATTACHED COPY A~ RECEIPT OF DATA~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO A'FI..AS [;ARCO HR$ CAMCO CAMCO CAMCO CAMCO CAMCO OTIS OTI$ RECEIVED BY HAVE A NICE DAY! SALLY HOF'F'ECKER AT0-4529 CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ BF'X EXXON ~ ~ ~']'AI'E OF ALASKA MARATHON $ TEXACO MOBIL ARCO ALASKA, INC. F'.O. BOX i0~360 ANCHORAGE, ALASKA DATE' 8-ii-89 REFERENCE: ARCO CASED HOLE FINALS 2-i4 ?-i4-89 PITS RUN 2-22 ?-i6-89 PITS RUN 4-2~~ 8-4-89 COI. LAR/F'ERF RUN 4-26 ?-t2-89 TEMP RUN 9-5 ?-i9-89 GR/CCL RUN 7-?A ?-3~-89 SPINNER/TEMP RUN 9-i4 ?-28-89 SPINNER/TEMP RUN ?-33 9-23-89 COLLAR RUN ii-J8 5-i8-89. TMD RUN it-24 5-t7-89 TMD RUN ii-25 9-i2-89 TEMF' RUN i2-3~ ?-23-89 COLLAR RUN i4-i5 ?-20-89 PITS RUN t4-t6 ?-i?-89 PITS RUN i4-2~ 7-2i-89 PITS RUN i4-24 7-22-89 PITS RUN PLEASE SIGN AND RETURN THE ATTACHED COF'¥ AS RECEIPT OF DATA 2'&5' 5' 5' 5' 5' 2'&5~ 5' 5' 5' 5' CAMCO CAMCO ATLAS CAMCO CAMCO OTIS OTIS CAMCO HLS HLS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO HAVE A NICE DAY! SALLY HOFFECKER APPROVED ...... ATO-t 529 O~&GS~(~O~l,~,~~~NS~ 89J4t Anchorage DISTRIBUTION CENTRAL FILES ¢ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL * THE CORRECTED AF'I~ FOR t4-t6 IS PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 1 4-24 Date: 7/30/89 Comments: K-valve has been closing regularly. Needed to drop FTP at closure to keep away from FTP swinqs. Well will have to be dumped to depressured test separator to pass state test. Previous K-valve Settings: Set Pressure~ psig Date 220 2/8/89 Production Data: ROR = 2680 CFR -- Swing Well (very high or Iow GOR) ........... Design Parameters: Design parameters are based on (Mark one of these) Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 2533 45 3367 0 1863 340 160 BOPD @ 8 7 deg. choke BOPD @ deg. choke No Choke Priority Well .................. Actual Well Test ..... Date of Test ..................... 7 / 5 / 89 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... BOPD percent scf/stbo mscfpd scf/stbl psig deg. F XXX Temp. @ SSSV ............. 1 75 Pressure @ SSSV ....... 479 Pressure Adjustment 1 25 PH2 PH3 PRUDHYD Other deg. F psig psig Calculated Dome Set Pressure = 207.0 psig @ 60 deg. F IActual Dome Set Press. FTP at K-valve Closure 210 215 psig @.60 deg. F psig @. surface cc: Sennett/Farmer Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. Keith Ferguson, ATO 1512 D.S. Supvsr. Shumway/Winters PRB#15 Prepared by: K. Lofgren ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 4, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-24 Approval No. 8-46 Dear Mr. Chatterton: Attached is the Report of Sundry Well performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi (DS 14-24)W1-3 Operations detailing work ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMN,,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Operation shutdown ~ Stimulate Alter Casing ~ Other ~ Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 27' FSL, 2723' FEL, Sec. 4, T10N, R14E, UM 11. Present well condition summary Total depth: measured true vertical Plugging ~ Perforate ~ Pull tubing 5. Datum elevation (DF or KB) 72 ' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-24 8. Approval number 8-46 9. APl number 50-- 029-20970 10. Pool Prudhoe Bay Oil Pool 9586 feet 9292 feet Plugs (measured) Effective depth: measured 9547 feet true vertical 9168 feet Junk (measured) Casing Length Size Conductor 80' 20" Surface 2532' 13-3/8" Production 8974' 9-5/8" Liner 926' 7" Cemented Measured depth ~ue Verticaldepth 400 sx 80' 80' 2000 sx + 400 sx 2532' 2532' 500 + 244 sx 8974' 8664' 300 sx 8660-9586' 8384-9202' Perforation depth: measured 9161-9197'; 9202-9212'; 9215-9235' true vertical 8829-8860'; 8865-8874'; 8876-8894' Tubing (size, grade and measured depth) 5~", 17#, L-80, PC tubing @ 8914' MD; 4~", Packers and SSSV (type and measured depth) RECEIVED MAR 0 7 !988 Alaska 0il & Gas Cons. C0mm[ssI0~ A,ch0rage 12.6#, N-80, PC tubing @ 8706' MD Baker FHL Packer @ 8624' MD; Camco Bal-0 SSSV @ 2142' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2400 4080 3200 -- 1450 1885 1900 Tubing Pressure 550 7OO 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run © 15., hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 WELL.g2/S8 .T.M. Vitucci Operations Engineering Manager Date Submit in Duplicate DRILL SITE 14-24 MALEIC COPOLYMER/AMINE PHOSPHONATE SCALE INHIBITION TREATMENT ARCO Alaska Inc. performed the following scale inhibition treatment on Well 14-24 on 2/18/88: 1. Obtained a valid well test. 2. MIRU pump trucks and transports. 3, Fluid packed the 5-1/2" x 9-5/8" annulus with crude. 4, Pumped the following fluids: A. 48 bbls of EDTA w/additives B. 64 bbls of maleic copolymer/scale inhibitor solution C. 320 bbls of diesel D. 210 bbls of dead crude E. 5 bbls of diesel 5. Shut in well for 12 hrs. RD and released equipment. 6. Returned well to production following 12 hr shut-in period, 7. Obtained a valid well test. REFERFNCE' ARCO F'RE221)RE DATA BHF'-gTATT£ ¢RAOTFNT ~NF'-FI..OWTNR RRADTFNT ~NF'-~TATIC RRAOIENI' ~HF'-~TATTC GRADIENT ~HP-~TATIC RRADTENT F'I. EA.~F 2TGN AND RETI.!R'N THF ATTAC. HFD RRF'Y A,t' RECEIPT OF F.'I= C E .T. V F"[.) BY ATO ~ ...... 9 TRAN~ ~88.~?! /~ AF'F'ROYED DT2TRTRI. ITTON OTT~ FiTTY nTT~ nTT~ CENTRAl_ FILE,? CHEVR'ON D & M FYTEN,.~I ON EXPLORATION EXXON MARATNON HOBIL ARCO Alaska, Inc · F'.O. BOX t003;60 Anchorage, ,Alaska 995 t 0 DATE' M~rch 27~ ~986 REFERENCE' ARCO Ca.~ed HoLe Final. ----' I)S' ~J D!-': -~4 D~ "~-J DS '~*J DS' '~'J DS -.¢-xtDY, ,. 4- i t (:-~-"-"4-85.. ... CNL I:;.' ur, 4-t t 0-24--85 Ep i Log Run 4-7 2-3-85 CET I:;~ u r, t 5" 4-t0 t2-26-85 Diff Temp Run 4-.t 5 t...")-~-~":;..,., ,.,_ D iff Temp Rut, t 5 ' 4-24 t t-9-85 Ep i Log Run ~ /~-.l~ ~ t-9-85 CNL ~.~, '~ Ru~ t 5" 4-28 t2-2t-85 Di ff Temp ' Run t4-2~, t¢,-~-~-..q~... ~, ~..Diff Temp Run ~ o ,q '" Run I 5' 'i 5-7 .~-.~0-,~ 6 ,:,F' i hr, er 6-5 3-6-86 Yi:'inner-Temp Run I '5" i o-'- i S' ,..~-- i 9-'86 ~'p i nr~¢*r--GR.. Run i "~'.,. ~--t~- ~ ~ 2--28-85 ACBI.../VDL/~ i g/(~R Run t '~." 6'-t6 ~.~ .... t9-'86 Wa+.er I~jec~ion Ru~ t ":" 6-t' 9. t - t -- '"d ~:>' A C L,L../f~ ' VI)L/' ;~' i g../DR Rtlr~ t .2r: ,, ¢'iq/GR Run t "~'" 6-2(:, t ...-~_o~.=. ,_,,,ACBL/VI)L/.., .. -,. I)A I)A $'c h DA I)A I)A I)A DA DA C ;..I Iff C: 0 C a m c o C. a m c o DA 0+. is I) A DA F'Lea:~-e 2:ign and re't'u.;"r, -I.'he attached COl::y a~ receip't' of da'l:a. ,_R.. I D F.'.eceivecl By DAY HAVE A NICE I r m a C a ;- L in ( / Nl~sk~ 011 & Gas Cons, Commission A T O- ~ 4 2 9 F ~ Anchorage I'RAN$ ~:8¢.,2~ 5 D I ,S'1' R I BLIT I ON · '- Phi LLip$ ~ Cen'traL Fi ie$ -.. ~ Chevron PB Wc.?LL Fi Les D & H R& D ~ Ex'i:er~$ior, Explora'tion ~: Sohio · "' Exxon ..f,:Stat:e of ALaska Hara'l:hon ~- Texaco · .-'"' Mob i L ARCO Alaska, Inc. Prudhoe Bay ,_,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 25, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-24 Permit No. 83-91 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi (DS 14-24)W1-3 RE.¢£1VED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C '~-'-'- STATE Of ALASKA ALAS,.. OIL AND GAS CONSERVATION CON,,. SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Suspend ~ Operation Shutdown ~ Re-enter suspended well -' Alter casing" Time extension ~ Change approved program [~ Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO AI~ ~ka_. In c. 3. Address P.O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM At effective depth At total depth 27' FSL, 2723' FEL, Sec. 4, T10N~ R14E~ UM 11. Present well condition summary Total depth: measured 9586 feet true vertical 9292 feet Plugs (measured) 5. Datum elevation (DF or KB) 7 ?. ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-24 feet 8. Permit number 83-91 9. APl number 50-- 029-20970 10. Pool Prudhoe Bay Oll Pool Effective depth: measured 9547 feet true vertical feet 9168 Casing Length Size Conductor 80' 20" Surface 2532' 13-3/8" Production 8974' 9-5/8" Liner 926' 7" Junk (measured) Cemented Measured depth True Vertical depth 400 sx 80' 80' 2000 sx + 400 sx 2532' 2532' 500 + 244 sx 8974' 8664' 300 sx 8660-9586' 8384-9202' Perforation depth: measured 9161-9197'; 9202-9212'; 9215-9235' true vertical 8829-8860'; 8865-8874'; 8876-8894' Tubing (size, grade and measured depth) Anchorage 5~", 17#, L-80, PC tubing @ 8914' MD; 4k"~ , 12.6#, N-80, PC tubing @ 8706' MD Packers and SSSV (type and measured depth) Baker FHL Packer 0 8624' MD; Camco Bal-O .q.q,qv ¢ 2142' MD 12.Attachments Description summary of proposal 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/~ertify that tJ~e foregoing is true and correct to the best of my knowledge Signed ~-///¢'y[~~~ Title Operations Engineering Mana. ger Commission Use Only Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Date Form 10-403 Rev 12-1-85 Notify commission so representative may witness Q Plug integrity ~; BOP Test ~ Location clearance Approved Copy Returned_ .-, Commissioner the commission Date Submit in triplicate WELLS2/58 J. M. Vitucci z~ DRILL SITE 14-24 MALEIC COPOLYMER/AMINE PHOSPHONATE SCALE INHIBITION TREATMENT ARCO Alaska Inc. proposes to perform the following scale inhibition treatment on Well 14-24: 1. Obtain a valid well test. 2. Perform a fluid level survey on the 5-1/2" x 9-5/8" annulus. 3. Flush pumper with 2 bbls of filtered fresh water. 4. Mix 2000 gals. (48 bbls) of filtered fresh water with 1550 lbs of Na2EDTA. 5. Flush pumper with 2 bbls of filtered 2% NaCI water and mix the following blend: 53 bbls 2% NaCI water (150°F minimum) 445 gals of FLOCON 287 DWG (4500 lbs) 5 gals of LoSurf 300, F75N, or J-18 6. MIRU pump trucks and transports. 7. Fluid pack the 5-1/2" x 9-5/8" annulus with crude. 8. Pump the following fluids: A. 48 bbls of EDTA w/additives B. 64 bbls of maleic copolymer/scale inhibitor solution C. 320 bbls of diesel D. 210 bbls of dead crude E. 5 bbls of diesel 9. Shut in well for 12 hrs. RD and release equipment. 10. Return well to production following 12 hr shut-in period. 1 1. Obtain a valid well test. ,.~.~s.s':;.~. Oil & G~s Co~ns. ¢ommlSsiO~i l..I o I. e I:-- ir, a I. :.=.: D;?. t.4 .... 24 i'2. .... i6....85 Di ff T emp l-'-.': ,:.:.': ,. i. y i'i c }::' a 'r' i. a 'n (:! A 'f'C--' .... ! 429 F' D ]: ."-:: '¥' {:;.'. i B t.!'f' I 0 N C 0 I::' Y i. e :F; iii: × p I. o ¥' a ! i ,::.'-='n ARCO Alaska, Inc. Post Office 13¢~-"~D Anchorage, A, 99510 Telephone 907 277 $637 December 11, 1985 Reference: ARCO Magnetic Tapes w/listings DS 14-1 DS 14~24 11-29-85 CH tape #2272 11-18-85 CH tape ~2267 7 DA DA Please sign and return the attached copF as receipt of data. Kelly McFarland ATO-1429F Trans # 5!5 DISTRIBUTION Chevron D&M Exploration Services Extension Exploration Exxon Marathon Mobil · ~ Alaska Oil & G Phillips ' as Cons. Commission nnchora~oe ~rudhoe ~a~ Files R&D .Sohio $=ate of Alaska Texaco ARCO ALas'ka, Inc F'.O~ Box Anchorage, Alaska 995i0 DATE' Sept~ember i2, t984 REFERENCE' ARCO Cas'ed HoLe Fina 4-7~'~'"~'?-26-84 TemperaCure Log 4-'~0~. 7-28-84 Temperature Log 6-6 ~- 8-4-84 CH CNL 9-28 ~-~-3--26--84 Temperature Log J4--~~ ~8-3-84 FLuid Den~t'iy t 4-~ 6 ~8--~ 0-84 DQT/NLL/GR ~ 4-24-- 5-~ 7-84 Xp inner Log J6-2" 7.-29/~8-84 Injec'tion Profi[e Log Run J Run J Run J Run 7 Run ~ Run 2 R~n J Run J ii 5' 5' 5' 5' 5" C 8 ~11 (.'. o C 8 ~1 c: o 60 C a m c: o DA DA C .~ h~ (.'. 0 C a m c o ~iign mhd ret'urn Che a¢¢ached copy a:~ receJp't of da'fa. Received HAVE A Kelly McFarland ATO'-i 429F TRANS. ~322 DISTRIBUTION Ch evr on Explora¢ion Services ExCen~ion Exp loraf ion Exxon 6e~y MaraChon Mob i L MobiL E & F' Phi LLJp~ F'rudhoe Bay WeLL R&D $oh Jo $~a~e of ALaska Fi Le_s ARCO Alaska, In~, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals D.S. 3-6~? D.S. 3-19 D.S. 3-22 ~ D.S. 6-10f D.S. 7-3--- D.S. 7-18~ D.S. 7-24' D.S. 9-18-~ D.S. 12-15'-- D.S. 12-18- ~.- D.S. 13-1/ D.S. 13-10f- D.S. 13-12~- D.S. 13-13~'~ D.S. 13-16J'~ ~. S. 13-27 D.S. 13-28~- D.S. 13-28~- D.S. 13-28f D.S. 13-33~J D.S. 13-33'~ D.S. 14-3~/ D.S. 14-21- D.S. 14-24/ D.S. 14-34-~' D.S.- 17-10j se szgn a data. 6-10-84 Diff Temp 5-25/26-84 Spinner Survey 6-29-84 Spinner Survey 7-4-84 Temp Log 7-6-84 Temp Survey 7-4/5-84 Spinner 4-19-84 Spinner 6-21-84 Diff Temp 4-13-84 Spinner 4-14/16-84 Spinner 6-17-84 6-22-84 6-18-84 5-31-84 4-12-84 6-2-84 6-3-84 6-3-84 7-8-84 6-22-84 6-23-84 6-30-84 7-7-84 3-25-84 5-19-84 6-17-84 nd return Diff Temp Temp Log Diff Temp CFS/Spinner Diff Temp CFS/Spinner CFS/Spinner Temp Survey Temp Log Diff Temp Spinner Log Diff Temp Caliper Log Caliper Log Spinner Log Diff Temp Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco Run 1 5" Camco the attached copy as receipt of Kelly McFarland ATO-1429F · Trans. 9301 DISTRIBUTION ChevroR D & M Drillins Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P ,4~chor~qe ~hi11ips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Ira,. Post Office Box 360 Anchorage, Alaska 99510 Telel3hone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data D.S. 1-4 --~ D.S. 1-25 D. S. D.S. 3-19 D.S. 3-22f D.S. 3-23 D.S. 6-17-~ D. S. 7-7A D.S. 7-13 D.S. 7-14 D.S. 7-16~ D. S. 7-16 ~ D.S. 9-8~ D.S. 9-18/ ._ D.S. 12-16J D.S. 12-17f D.S. 13-33-~ D.S. 14-8 D.S. 14- D.S. 14- D.S. 14- D.S. 14- D.S. 14- D.S. 14- 3-15-84 PBU/CDBR Otis 5-25-84 PBU/CDBR Camco 5-30-84 PBU/CDBR GO 5-25-84 PBU/CDBR Camco 6-29-84 PBU Camco 5-24/25-84 CDBR GO 6-16-84 Static Survey GO 6-15-84 Static Survey GO 6-14-84 Static Survey GO 6-14-84 Static Survey GO 6-30-84 PBU GO 7-2-84 PBU/CDBR GO 6-20-84 Static Survey Camco 6-20-84 Static Survey Camco 6-21-84 Static. Survey Camco 5-19-84 CDBR 5-20-84 CDBR 6-22-84 PBU/CDBR Camco 6-28-84 Static Survey Camco 23~--5-16-84 CDBR 24~ 5-17-84 CDBR 25 5-18-84 CDBR 32j 5-20-84 CDBR 33~ 4-29/30-84 CDBR 34 r 5-19-84 CDBR .. //Please sign and ~ data. return the attached copy as receipt of Kelly McFarland ATO-1429F Trans'. ~290 DISTRIBUTION ~hevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon o 3 Mobil E & P '~Chomge'6'°mmiSsioe Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, In,.. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 · July 10, '1984 Reference: ARCO Pressure Data D.S. 1-26~ 5-20-84 Static D.S. 3-23 '~5-24-84 PBU D.S. 12-16~ 5-20-84 PBU D.S. 12-17. 5-20-84 PBU D.S. 13-3~ 5-27-84 PBU ~ 5-27-84 Common Data Base Report D.S.-14-23~-~ 5-16-84 PBU D.S. 14-24-J 5-17-84 PBU D.S. 14-25~I 5-17-84 PBU . D.S. 14-32/I 5-20-84 PBU D.S. 14-34 ~ 5-19-84 PBU GO GO DA Otis Camco GO Camco GO GO Camco P~~lease sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO-1429F Trans. #261 DISTRIBUTION Chevron Drilling Exp. Services Ext. Exploration Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well~ Files R&D Carolyn Smith So.'h£o'. ' ' SCaCe .of Alaska . ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 19 84 Reference: ARCO Cased Hole Finals D.S. 1'9~'~/~ 4-20-84 ~~- D.S. 4-13~4 ~ ; D~i~// 4 ~ TDT CH CNL TDT CN/MSN/GR CET Log TDT > TDT 5" Sch Run 5 5" GO Run 2 5" Sch Run 2 5" DA Run 1 5" Sch Run 3 5" Sch Run 1 5" Sch ~~ D.S. 12~17~/~84 Spinner --~ ~ ~-----~D.S. 12-21~//5-2-84 ACBL/VDL/Signature/GR ~ --D.S. 13-16.~v 4-12-84 Spinner ~ ~-DTS~'-. ~4- 30- 84 TDT D.S~ 16-3~/. ~5~E-~I D.S. 16-8 ', 5-10-84 CET D.S. 16-9/~/ 5-13-84 Collar/Perf NGI ~11 ~/~" 4-17-84 CET ~ 4-19-84 EPL ~_.S-~6c-18 ~ 4-28-84~ Run 1 5" Sch u.~ /- 21~2~/ 4- z-gc- 84 PLS Run D. S 7-26~/4-27-84 PLS Run D.S 9-19 .~ 5-11-84 Collar/Perf Log Run D.S 11-5~-/ 3-?_9-84 i~r/Basket Flw Mtr.. Run 1 5" DA 1 5" DA 1 5" GO 2 5" Camco Run 2 5" Sch Run 1 5" Otis Run 2 5" Sch Run 1 5" DA Run 1 5" Camco Run 3 5" DA Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO Run 1 5" Sch Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFar land ATO- 14 29F Trans. ~221 DISTRIBUTION ~hevron D&M Drilling Exp. Services Ext. Exploration lixxon Getty Marathon Have A Nice Day! JUN 0 Al~tska 0il ,~ Cas Cons . Mob x 1 - Anchorag-e. Comfll/,~$lOl7 Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio S~aCe of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Magnetic Tapes D.S. 14-24 v/ 5-24-84 _CH/CNS w/listing D.S. 1-10 v- 5-23-84 CH/CNS w/listing D. S. 6 - 18 ~z~8-~8'~DR~-.M--A~swe~/1 i s t i ng 7 7 - 7c - c/ R e - ~4-28-84 TDT-M Lis w/listing /D.S. 13-98~/~5-16-84 CH DIL GO GO Run 1 Sch Run 1 Sch Run 12 Sch -'f/~P]~as= s~an and return the attached copy as receipt of data. Have A Nice Day! Kelly McFarland ATO-1429F Trans. #225 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio Sta~e of Alaska ARCO Alaska, Inc. Prudhoe BaY -ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 16, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-5 DS 14-23 DS 14-24~' DS 14-25 DS 14-34 Permit No. 78-64 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Permit No. 83-133 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 14-5,23,24,25,34)W4-3 RECEIVED APR 2 0 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Aiaske, Inc. I~ a Subsidiary of AflanticRIchfieldCompany ALASK'0~AND~A$CONSERVATIONL !vlMI$$iON WELL COMPLETI OR RECOMPLETION REPORT AND LO 1. Status of Well REVI S I0N Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] // 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-91 / / 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of well at surface 9. Unit or Lease Name 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM 14-24 At Total Depth 11. Field and Pool 27' FSL, 2723' FEL, See. 4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 72' RKBI ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions 06/15/83 06/25/83 07/06/83I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 9586'MD,9202'TVD 9547'MD,9168'TVD YES [] NO []'INipple ~ 2142 feet MD 1900' 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Cmtd w/400 sxs PF II cmt 13-3/8" 72.0# L-80 Surf 2532' 17-1/2" Cmtd w/2000 sxs Fondu + 400 sxs PF "C" cmt 9-5/8" 47.0# L-80 Surf 8106' 12-1/4" Cmtd w/500 sxs "G" cmt + 244 sxs PF "C" cmt 9-5/8" 47.0# US-95 8106' 8974' 12-1/4" 7" 29.0# N-80 8660' 9586' 8-1/2" Cmtd w/300 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9161-9197' MD 4 spf 5-1/2" 8706' 8624' 9202-9212 ' MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9215-9235' MD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8829-8894' TVD N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS-OIL RATIO 3-25-84 4.6 TEST PERIOD ~ 950 556 , 0 48] 586 Flow Tubing Casing Pressure CALCULATED '. , OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press: 878 NA 24-HOUR RATE I~ 4954 2902 0 27 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . NoneRECEIVED APR 2 01904 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 DRN/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. NAME Include interval tested, pressure data, all fluids recover~ and gravity, --' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.- - _ - i . _ : Top Sadlerochit 9059~ 8739~ 0WC . .-.9~30~ 9065~ ' N/A Base Sadlerochit - NOT REA~ . -. , . . . . . . . . . . . : . . . . . 31. LIST OF ATTACHMENTS . - . ~ --~ --~.... 32. I hereby ce~ifY that t'he foregoing is true and-correct to the best of my knowledge 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 (G L) or other elevation (DF, KB, etc.). ... Iteml 2~'i ~tta'.~ed Sul~plemental records for this well should show the details of any multiple stage cement- ing an~ the location of the cementing tool. .: Item 27'-Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I~jection, Shut:in, Other-explain. Item 28: I~"no cores taken, indicate "none". ARCO Alaska, Inc" Post Office box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-23 DS 14- 24 DS 14-25 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Attached are Subsequent Sundry Notices for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File PI(DS 14-23)W1-3 PI(DS 14-24)W1-3 P1 (DS 14-25)W1-3 /~RCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany ~---. STATE OF ALASKA '--: ALASK, ¢IL AND GAS CONSERVATION L XIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] coMpLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20970 OTHER [] 4. Location of Well 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM 27' FSL, 2723' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 12. 4, T10N, R14E, UM I 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 3/9/84. RU perf unit. Pressure tested equipment. RIH w/gun #1, shot 9215-9235 MD, 4 spf (20' Ref: BHCS 6/26/83). Flowed well. SI well, POH, all shots fired. RIH w/gun #2, flowed well, shot 9202-9212' MD, 4 spf, (10' Ref: BHCS 6/26/83), SI well, POH, all shots fired. RIH w/gun #3, flowed well, shot 9161-9177' MD, 4 spf, (16' Ref: BHCS 6/26/83), SI well, POH, all shots fired. RIH w/gun #4, flowed well, shot 9177-9197' MD, 4 spf, (20' Ref: BHCS 6/26/83), SI well, POH, all shots fired. RD and secured well. APR'. A{aska 0il & Gus Cons. 14. I hereby 9~tify that the_foregoing is true and correct to the best of my knowledge. Signed ~.~~~. ~~ Title Regional Engineer 'The space beIQw for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date ...... Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate AH(JU AlasKa, Inc. Post Office/m.qx 360 Anchorag~ }ska 995"10 Telephone ~,~T 277 5637 April. 2, 1984 Reference: ARCO Pressure Data D.S. 3-10 /' 3-18-84 D S 3-15 / 3-18-84 D.S. 3-18.// 3-18-84 D.S. 4-5/~ 3-17-84 · D.S. 4-16/'~ 3-9-84 D.S. 9-1:~/ 3-18-84 D.S. 9-6 3-18-84 D.S. 9-10 '/ 3-19-84 D.S. 11-2~' 3-17-84 D.S. 13-27/ 3-4-84 D.S. 13-28 ~' 3-5-84 -~3-5-84 D.S. 13-29~ 3-12-84 D.S. 14-23~ 3-10-84 D.S. 14-24r~ 3-10-84 D.S. 14-25 ? 3-11-84 Static Survey Static Survey Static Survey Static Survey PBU '_ Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey PBU Data Sheet Static Survey Static Survey Static Survey Static Survey Camco Camco Otis Camco Camco Otis Camco Camco Otis DA DA DA Otis Otis Otis ~ P1/~ease sign and return the attached copy as receipt of data. HAVE A-HAPPY EASTER! Ke 1 ly McFar land ATO- 1429F Trans. # 112 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay ,-.gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 24, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-23 ~ DS 14-24 DS 14-25 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany J ECEI /ED JAN 2 5 ]984 Naska Oil & Gas Cons, Anchcra,oo Commis,~lon ,~--~., STATE OF ALASKA -- ALASKA _AND GAS CONSERVATION C. "'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20970 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM 27' FSL, 2723' FEL, Sec. 4, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 72' ~ 6. Lease Designation and Serial No. ADL 28312 10. Well Number DS 14-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTIQN TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Propose~ or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to a tank for clean-up and production. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9161-9197' MD (36') BHCS: 6/26/83 9202-9212' MD (10') 9215-9235' MD (20') JAN2 5 ]984 Alaska 0il & Gas Cons. Commission Anch0rag0 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of APproval, if any: Approved by Form 10-403 ORIGINAL BY ION;tIE C. Approved Cop:l Returned . By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~ Post Office bvx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-24 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU5/LIO2'tw Enclosure If RECEIVED r~i ~ ~ ,'~,..,,i/l 0il ~, ~:~,~:; - ~ ..... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... .- ALASKA _.,.IL AND GAS CONSERVATION C,..,¢IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of Well Surface: 1519' FNL, 1992' FEL, Sec.9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 12. I 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-24 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Spudded well @ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'; ran, cmtd & tstd 13-3/8" casing. Drld 12-1/4' hole to 8987'. Ran: 201 jts 9-5/8", 47.0#/ft, L-80, BTC csg & 19 jts 9-5/8", 47.0#/ft, US-95, BTC csg (9-5/8" shoe ~ 8974') Cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to TD; ran logs. Ran, cmtd & tstd the following 7" csg f/8660' - 9586': 20 jts 7", 29.0#/ft, N-80, BTC SMLS csg 1 jt 7", 29.0#/ft, US-95, BTC csg (marker joint) Ran 5-1/2" completion assembly. Secured well & released rig @ 2100 hfs, 06/30/83. · 14. I hereby certify th.at thc/~oregoing is true and correct to the best of my knowledge. The space below for Commission use Area Drilling Engineer Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU5/SN56 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office,'"-'"' 360 Anchorage. ka 99510 Telephone 907 277 5637 November 30, 1983 Reference: Arco Cased Hole Finals D.S, 3-22 8-30-83 D.S.' 5-7 / 9-12-83 D.S. 5-14¥' 9-23-83 D.S. 5-14 ~-'~ 9'-22-83 D.S. 14-32~--' 8-29-83 D.S. 14-32 8-30-83 D.S. 13-98'~/ 11-9-83 D.S. 14-24 ?' 8-27-83 D.S. 5-2' 8-17-83 · / D.S. 3-7 8-17-83 D.S. 5-8 TM 8-25-83 D.S. 5-8'1' 9-3-83 CBL/VD GR Production Packer/Collar Log GR CBL/VD CCL & Perf Record Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" Sch Squeeze Run on 5" Sch CPL/CNT-A (Therman) & CNT-G (Thermal & Epithermal) 5" Sch CET EPL CCL & Perf Log Collar Log for Casing Cutter GR/CCL Correlation Log Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch. Run 1 5" Sch Run 1 5" Sch ~i'ign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F fChevron Trans.-.# 649 D & M Dallas Drilling . Exxon Getuy DISTRIBUTION ~ North Geology · , · Phillips Prudhoe ~. Zaro!ime Sohio State of Alaska ,.-'--. ; ,-'-", STATE OF ALASKA ALASKA ,..~.L AND GAS CONSERVATION C IMISSION ('~/ WELL COMPLETiUN OR RECOMPLETION REPORT AND LOG 1. Status of Well REVISION #2 Classification of Service Well I OILT/~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of well at surface 9. Unit or Lease Name 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM 14-24 At Total Depth 11. Field and Pool 27' FSL, 2723' FEL, Sec. 4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 72' RKBI ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/15/83 06/25/83 07/06/83I N/A , feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9586'MD,9202'TVD 9547'MD,9168'TVD YES rX~ NO [] Nipple ~ 2142 feet MD 1900' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Z0" 91.5# H-40 Surf 80' 30" Cmtd w/400 sxs PF II cmt 13-3/8" 72.0# L-80 Surf 2532' 17-1/2" Cmtd w/2000 sxs Fondu + 400 sxs PF "C" cmt 9-5/8" 47.0# L-80 Surf 8106' 12-1/4" Cmtd w/500 sxs "G" cmt + 244 sxs PF "C" cmt 9-5/8" 47.0# US-95 8106' 8974' 12-1/4" 7" 29.0# N-80 8660' 9586' 8-1/2" Cmtd w/300 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 8706 ' 8624 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Flow Tubing Casing Pressure CALCULATED 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. ~!. ~ .~ ~ .~ ,., None Form 10-407 DRN/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' GEOLOGIC MARKERs . . ' :' ' :'--. '-' '- ;. :"'i ':"" FORMATION ~FESTS '.' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 9059' 8739' 0WC 9430' 9065' N/A Base Sadlerochit NOT REACHED · 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to- the best of my knowledge Signed ~. ~. /~'~ / Title Area Dril ling Engr. Date ~0 -Z.~ '-~J ~, ., 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". 14-24 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/FS @ 2532'. Cmtd 13-3/8" csg w/2000 sx Fondu & 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 12' new form. Tstd form to 11.1 ppg EMW - ok. Drld 12-1/4" hole to 5252'. Ream 5075'-5252'. Drld to 7634'. Tight hole 7558'-7495'. Wash & ream 7463'-7634'. Drld to 8808'. Ream 8713'-8808'. Cont'd drlg 12-1/4" hole to 8987' (06/24/83)..Ran 220 jts 9-5/8" 47#/ft, L-80, US-95 BTC csg w/FS @ 8974'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. 'Drld FS and form to 8995'. Tstd form to 12.5 ppg EMW. Held 11.4 ppg after 2 min. Drld 8-1/2" hole to 9586' TD (06/25/83). Ran DIL/SP/BHCS/GR fr/9148'-9571'; FDC/CNL/GR/Cal fr/9148'-9571'; stuck tool @ 9362'. Strip over WL w/DP - recovered fish. TIH and circ and condition. POH. Ran FDC/CNL/GR/Cal. Stuck tool @ 9143'. Strip'over WL w/DP - recovered fish. Ran 21 jts 7" 29#/ft, N-80, BTC csg fr/8660'-9586'. Cmtd 7" lnr w/300 sx Class G cmt. Drld cmt to 9547' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL 9540'-8500'. Ran 5-1/2" completion assy w/tail @ 8706' & pkr @ 8624'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Pull BPV. · Secured well & released rig @ 2100 hrs, 06/30/83. Gyroscopic survey run on 07/06/83. NOTE' Inject salt water in the 13-3/8" x 9-5/8" annulus for freeze protection until the reserve pit disposal operation began. DRN/DH22'tw. WELL COMPLETION OR RECOMPLETION REPORT AND LOG STATE OF ALASKA ALASKA i~LAND GAS CONSERVATION 1. Status of Well Classification of Service Well REVISION OIL~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of well at surface 9. Unit or Lease Name 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 221' FNL, 2704' FEL, Sec. 9, T10N, R14E, UM 14-24 At T~lDepth 11. Field and Pool 27',~-~1_, 2723' FEL, Sec. 4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 72' RKBI ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/15/83 06/25/83 07/06/83 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey / 20. Depth where SSSV set [ 21. Thickness of Permafrost 9586'ND,9202'TVD 9547'MD,9168'TVD YES [] NO []~lipple ~ 2142 feet MDI 1900' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Cmtd w/400 sxs PF II cmt 13-3/8" 72.0# L-80 Surf 2532' 17-1/2" Cmtd w/2000 sxs Fondu + ~00 sxs PF "C" cmt 9'-5/8" 47.0# L-80 Surf 8106' 12-1/4" Cmtd w/500 sxs "G" cmt + 244 sxs PF "C" cmt 9-5/8" 47.0# US-95 8106' 8974' 12-1/4" 7" 29.0# N-80 8660' 9586' 8-1/2" Cmtd w/300 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 8706' 8624 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ 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. None ~-,:i ' (;,ii'.' l:'._:~ili".djb..; :~: ., i -,,,,.,,. CONTINUED ON REVERSE SIDE Submit in duplicate Form 10-40'DRN/WC13 Rev. 7-1-80 '..: ......... ;.' '- ' GEOLOGIOMARKERS~-:'~- 'w-: ~-:~ '-,,-~ .... . ~ ": ', ~:':;;?;~--':~':;~ :.~;' :: :~.~" :',--:-'~:.ORM'AT-ION NAME Include intecval tested, pressure data, all fluids recovered and gravity, " - - ' MEAS. DEPTH TRUE VERT. DEPTH GOR, and.ti~e.0f each phase .. . . . · Top Sad] erochit 9059~ 8739~ ' OWC 9430~ ' ' 9065~ N/A '" Base Sadlerochit . _ NOT REACHED -. . -- : · . . ~:~- ] . . . . , _ . : . . . - . . ~ i. ' ' .. . . , . . . . . . , . · , 31. LIST OF ATTACHMENTS ' Drilling History, GYroscopic Survey (2 coPies) . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~.~,~ 2 Title Area Dril ling Engr. 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". 14-24 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/FS @ 2532'. Cmtd 13-3/8" csg w/2000 sx Fondu & 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 12' new form. .Tstd form to 11.1 ppg EMW - ok. Drld 12-1/4" hole to 5252'. Ream 5075'-5252'. Drld to 7634'. Tight hole 7558'-7495'. Wash & ream 7463'-7634'. Drld to 8808'. Ream 8713'-8808'. Cont'd drlg 12-1/4" hole to 8987' (06/24/83)..Ran 220 jts 9-5/8" 47#/ft, L-80, US-95 BTC csg w/FS @ 8974'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. 'Drld FS and form to 8995'. Tstd form to 12.5 ppg EMW. Held 11.4 ppg after 2 min. Drld 8-1/2" hole to 9586' -TD (06/25/83). Ran DIL/SP/BHCS/GR fr/9148'-9571'; FDC/CNL/GR/Cal fr/9148'-9571'; stuck tool @ 9362'. Strip over WL w/DP - recovered fish. TIH and circ and condition. POH. Ran FDc/CNL/GR/Cal. Stuck tool @ 9143'. Strip over WL w/DP - recovered fish. Ran 21 jts 7" 29#/ft, N-80, BTC csg fr/8660'-9586'. Cmtd 7" lnr w/300 sx Class G cmt. Drld cmt to 9547' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL 9540'-8500'. Ran 5-1/2" completion assy w/tail @ 8706' & pkr @ 8624'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Pull BPV. Secured well & released rig @ 2100 hrs, 06/30/83. Gyroscopic survey run on 07/06/83. NOTE' Inject salt water in the 13-3/8" x 9-5/8" annulus for freeze protection until the reserve pit disposal operation began. DRN/DH32'tw · D:'-: .1. 4-, AlE LL FIO: 2 zl. T EL EC fl ' ("E_:DC,)' "~:'i" . .' F::'RUDHOE B(.~Y., NOR]'H SLOF'E, ALA'Lf-:I':r.A; : ": ' ......... I"EL. ECO'; O:-; .-.~'.5.'5:~:" 1'113 i ......... .SI..IRVEY~ F:'Rf'~V"~iDE[t;':BY' C:ON'f'F(OLLE[I DR ! LL I'NC'i .CC. IN'..=_;UL.'r(-.~NT...'E.;, ..' DR I I..I_E::R: g t-.:lqgF'l*l(~l~l : ' . · ,, " · ,. . . · I::~: I ~3" I:::'(..1Rt:::ER J. 7/_':.; ,. ., :,,~,!,.,:,.: ., :. ,> ~ ..... ' :~i ~,,.~ , .' ,, ..... .' ~ , ~,~.2, · "' ~'~ ~, ,,' ~ .. , , <D . ,L~.~.' ,: '. ., i~! .' , ...'. · .,. . . · · , . ,. , ;,, .; · · · .., .. ,. · ,~,?,' ,~,,,:,,...:,~ ~ ~ . .: . . . . · ' .JL' r:,-"~'~f '"t'~ F:~':' ~'"' ':'"'~ ''~* ,'"~"~"t,'h ' ' · .. : ..... ' '~.,:i,,~,':~[~' ":': :::, ,, ~'?~ ,,,,~:'!' .'ii" ~;J! " .:.t-_,_. r z r.N r: i;::i:l: N. 'F'I_'¢~I~I~..,, oF, .,.! DIRECT.ION.' · ' "?',? ,!i: :"?'¥:'::': '"" .' 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I"~ E F:'"I' H A R E I"1D · .. · EIEF'TH WE I GH1 .... ::.' ....... :{..:: ............................................. ._,,(.),:,. O0 /-,0 00 141 ~ (')':') /- ~ (") · '"! ~ I~': ."1 ..'. · .::.._, .... _',. 00 ' ' 4(') ' (')0 .... .,, 5006. (").. 0 1 ._, '= . (') 0 .. 501/:,. 0(') :'-,",0.00 " · . r=,'-'"'-'-' 00 ..... ~'--; 0() ...,:% ._~ ~,' ._ ._ . ....... , ,.. · , 557/1. O0 55 ()0 : .-'-.. ,,. .- · _,,--, o ._-,. 00 6."--.]. C)() · ' .4:,4.:,,=,. (-)r) .......... /-,5; 0(') ..................... ;; ~'' ........ :"'". 7/-,:::4. ()(') ~':'~ (')0 ..... ,.,I ,..I # ,":, o(') c, (') ('! /-',(") 0 ,..11_, . i.., ,i .... i, . DEF'TH 50R. 00 1415.00 2553.00 5 (]) 0/_-.. 00 5 0 1 6.0 0 5 2 5 2.0 0 5 5'? 1.0 · _,,:, 6.:,. 0 () 64-38.00 76:34.00 88 O:-q. (])0 L:,'787.00 R E VOL U T I 01',i! V A L L.I E S U S E D I:': OIR D E P T 14 A R E M D R. F'. H,, 180.00 180.00 150 ~ 00 0.0C) O. O0 1 O0. O0 1 (])0. O0 110. O0 110 ~ O0 9 ('), 0(-) 1 10. 00 '? 0 ~ 00 BOTTOM HOL.E AS:EiE;MBEY : i " V t~ L U E S U S F D F O R D E I::y'T' H g R E FI D , " ..... V~LLIES .USED FOF~:-E~.F'TH- ~RE,.~D ...................... i'. ' . ..... , . , 0 CUSTOMER : ARCO LOCATION : PRUDHOE BAY, WELL PAD : DS-14 WELL NO. DRILLING CO. I PARKER CUSTOMER JOB NO. : TELECO JOB NO. : 287-AK MAGNETIC DECLINATION : 30.30 E PLANE OF PROPOSED DIRECTION IS : DI RE~T,I ONAL ALASKA o' ' CO . .., ; REPo R-l[- .. TELECO OILFIELD ~RVICES OF nLnsun, INC. 6116 NIELSON WY.;'i: ANCHORAGE, ALASKA, 99502 TEL,',: (907} 56~-.~46~ '.. DATA REDUCED BY RADIUS OF CURVATURE METHOD TYPE OF SURVEY :'!/i~MAGNETIC START DATE : 06/1.7/83 FINISH DATE : 06/27/83 o. REPORT PREPARED B¥~ : DAVE REIMER PAGE 1 MEASURED DRIFT TRUE DEPTH ANGLE VERTICAL DEG MIN DEPTH 2738 0.00 2738.00 3266 0.30 3265.99 3792 0. S6 3791.97 4289 1.06 4288.92 4750 1.12 4749.82 5042 2.12 5041.69 5104 4.42 5103.58 5165 7.00 5164.26 5307 12.18 5304.26 5432 16.06 5425.44 5523 19.12 5512.15 5646 22.12 5627.21 5770 25.24 5740.67 6099 27.12 6035.61 6382 26.12 6288.44 6852 25.18 6711.76 7318 22.42 7137.48 7568 20.54 7369.60 7820 20.42 7605.17 8100 20.48 7867.01 8476 24.12 8214.39 8882 28.12 8578.68 ',.JERTICAL )ECTIDN .. · . -.'0.00 .. · ·'2.13 .. ·.2.53 9.34 .... 0.87 ,. '.4.62 · · 1.14 '"23.76 :53.37 · ... 80.28 . ...122.95 · 1-72.15 315.63 ,. · 440.86 .,. .-. ,.641.96 828.51 919.99 ""/' ~oo8.35 ~ . · 1107.23 . · . : '.' 1250.59 '" 1424.87 DRIFT TOTAL COORDINATES C L 0 S U R E S DOG - LEG DIRECTION ~ DISTANCE ANGLE SEVERITY DEG MIN DD MM SS DEG/100 FT. N 0.00 E 0.00 - :' 0.00 - 0.00 N 0.12 W 2,30 S 0.00 E 2.30 S 0 06 00 E 0.095 N 0.06 W 2.75 N 0.01W 2.75 N 0 11 31W 0.019 N **.** E 10.12 N 0.02 W 10.12 N 0 05 18 W 0.101 N 2.00 E 0.87 N 0.18 W 0.89 N 11 32 26 W 0.023 N 77.24 W 5, 99 S N 47. 12 W 4.25 S N 42.36 W 0. 15 N N 39.06 W 18, 16 N N 36.36 W 42, 37 N 5.12 E 1.82 E 2.57 W 18. 14 W 36.96 W N 34.30 W 64,82 N 53.00 W N 33.06 W 100.95 N ... 77. 18 W N 33.30 W 142.77 N ~. 104.66 W N 32.24 W 265, 09 N 183.94 W N 33.06 W 372.04 N 252.73 W N 32.24 W 543.77 N 363.19 W N 33.30 W 702,82 N 466.28 W N 31.42 W 781.03 N 516.31 W N 32.06 W 857.01 N 563.59 W N 22.36 W 945.12 N 609.17 W N 13.06 W 1082.08 N 653.27 N 5.24 W 1259.00 N 682.09 7.88 S 40 32 23 E 4.62 S 23 08 07 E 2.58 N 86 37 27 W 25.67 N 44 58 29 W 56.22 N 41 05 45 W 83.73 N 39 16 15 W 127.07 N 37 24 05 W 177.02 N 36 14 35 W 322.66 N 34 45 21 W 449.76 N 34 11 20 W 653.91 N 33 44 22 W 843.43 N 33 33 43 W 936.26 N 33 28 00 W 1025.72 N 33 19 48 W 1124.43 N 32 48 12 W 1263.99 N 31 07 12 W 1431.90 N 28 26 50 W 0.789 4.853 3.845 3.753 3.079 3.477 2.472 2.584 0.567 0.370 0.202 0.566 0.768 0.097 1.201 1.321 1.291 JOB NUMBER : 287-AK CUSTOMER : ARCO DRILLINE PAGE 2 PAD : DS-14 : 24 8URVEY RE po R'T .. ,: MEASURED DRIFT TRUE VERTICAl' .' DRIFT ' TOTAL COORDINATES C~'iL-O S U R E S DOG - LEG DEPTH ANGLE VERTICAL SECTION, ~.~ DIRECTION DISTANCE ANGLE SEVERITY DEG MIN DEPTH ~ ~ ~ · DEG MIN .,~ DD MM SS DEG/100 FT. · BOTTOM HOLE CLOSURE: 1431.89 FEET AT'~.~:, N ~8 ~ 50 W i!' ~'~'' PRINTED : 28 JUN, 1983 ' COPYRIGHT (C) 1983 · ' ' " ABACUS COMPUTER SERVICE 3~56:20 PM ,;,' ' :~ 820..W. 71st AVENUE · , . ".i.-.." ANCHORAGE, AK. 99502 ., ( ~07 ) 344-07~1 · '~ .~ ~..~ .. .: - ," . · · .... .. .. .'. ·. ' -?.. .. · . · . . , .... ... ~: .~,. .' .. · · · . · . .. · · .. RADIi.l:; OF F" t~- ..... ..... r.,,,,.~--,TI_tF~:E METHOD · lC)C) (") 12 ..... . .. ....i ..... . ....... ~, ..... ,, .... . aL. '.,.' ,, . . ........· :::' (') (")., (') A._, :i.:; .'.::,' ..., = ,..,/- E .1. ..... (') (') . 2 ........ (":~ ("~ ,, 00 - O.. 4 .1. 12 :i?, ,, () () :B()O. ,:} ! 2 S :'::7 1:3 E 1C)C). :?,,::.)0 ,, ,:}0 -.0.64 22:3 ,, 0,:") Zl. O0 ,, 0 .1. :2: O. O0 ..................... O. 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','-?, :2:7 ,, 95 :::4 N 1 N :.':-:F) !:i5: :_:; 7:.:_": 54 Er 2.4 :!'-; 21 4:3 E 4.2 S 15 42 E ,:~:3 '.5 ]!5 0 E 4 4:3 .,%.7.4 5.09 :;.-::500 ,, :26 (:),.'). 270 O. 2:300 ,, 2 '? ,:.-.~ ~.'.:,. ].I 73 c- .!.2. D7 ::; 13. 1 9 '.::; '1:3 :_--:6. '-' 14.74. :---; ~ ~.-~ - .., ~ ,_, .' E 6,. ! :3:E 6,. 97 E 7 77 '-- ::-',.47 E O. 2.~ O. 2: 0.. 1 ,', 0.2:: (.'.~Rr":F'~ ALA...-:,t.,..A :, ! t',t(::, CAMF'I_ITAT I l..':{N F'AGE- Ni.:], . 2 , )7)'.E; ]..4., WE]I... ! .... ,klO: 2,.! '.~.i; T (3NA.....t'./YFRO .... lOB NO: AO7E::::',RO:B4 'T., .... -1 Z ]" ]' .ME DATE f::'F:i:i..IDHOI:,{ BA'¥', I',.ll:.':.!lR"r'f.-.l ',i:i;L.L:)F'F::., ALA'.!F;KA 1 .1.: 1. (:): 24: :7..i:':.3-.;~. G-',::::'i: ... '1" R ~. J E I"IE:'Ai!i;Ut::;:E:!: '[) F;,: !: I:::"T' .'(:~:::]:F:"I" F:I-II..tF;~EE VF::':.F~'.7"]:r,7:A,I .... 'v'IEF;~TI(:::A! .... '..E:UB'.E!:I::!;A t::;~ E f.": T A Iq C!i I..I L.. A R i'_:: L i_':.1 S I_1 R E Tu"iC.~L.E EF:.F:'TH AF.t[3t..E D'.I:F~'EETZON I.~E.:t'IGTH Dt-7.:F:'TH EE::C'I"TOFt 'T'V'O C 0 ~'"~ R D..I I",.I A T E S DISTANCE:' T)IRE"C]':ION '.:.'];E"'VE]RI F:' E F:: "t" D M I) N F' E E': T F::' Ii!i: I!! 'I" F:' F.:.': E: 'r' F:' 17 E T F .F E T F E [.:-" T .T) M ]:) G / .1. 0 C ,:"~ 4:3 '.E: 2:B 4',E', W ...... :::, 31:2's' F:..:':.') -2 (:) ,, 27 :3':.'i: 2 7. :'+.': 9 .... :21.20 :3327.88 ..... 23 4 1 ":' ..'- '-'"' :::"7 .... _, ,.., .,::. / ,, .-72::3,, 97 ::7,7:27,, 87 24 ,.:!:, 3 :}.", :?, 2'7 '::' ".. 16, 1.6 '7.; 10, 11 E: 1.4:,. ::::5 S 10. 4'7 E t 7., 46 '":' t C) F.::(') E · ,~.l ......... it .... .1. 8.3 4 ..~,'--.-' i 1. 1 c). IF. t9,,:30 S t1,, t,'5, E 20. 0 C) :..":'; :I..1. ,, ]. '? Ii::: i:::0,7 t.'.:, '.E; 1 1.0 :.':!: E :21. ,, !5.:,4:3 · ]. O, 6::3 E ""'-' 4 z., .,:. ,.' ....S 10 ,, ]. ,.'.1 E :l :ii:. 0 7 S :3 :l ]. E 0.2'7 ]. 9.0 6, L:.; :B 2 i:!: E 0. :2 C: 1'.:-~ L:.':4. 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()(::,, ,a '7'.:,;".:;';' ,, '.'.;' 4. 100 ,, 4. :::i', 5:" 9 ,. 7 2 .... ::ii: '! ,, (':, E, .4. !1527., 79 -- ":" "':' .% ::7: 4./., ':.:' 7 7/-, - :':; :..:.:, '7 :.:: .a 7' :27,, 74 · --:-:: 4 ,, 5:' Vii 4. 8'2 7, ':7 :,.-.:: !:5 ! 0 C). .,:i. 1 '2 hi 4.:B -'1.:2: r~- "-, .' .- .... · :L):.)., 7 54 N 4 ]. 0 W 5:300. .1. ]. 4:2 r',l :'-".',F.: 1'5: W 5400. ~ 4 36 i',.! :3,/_.-, 1:2 ~,.I ! 0 ().., 4 'P !;."i.::.', 70 ! 00 ,. 5 C)'.--.,' 9' ,, 57 ! () (:,., !5; 'L 'i;.'"'.:.:". 0 0 :!. 0 0 ,. E; :':2'.-:'; 7 ,, 5 :T..: ] 0 (), 5 :.7..:'i::' 4. ,, E:'.-.:' F::'F;tl..t.EIHF]E:' Z',/:'.,Y ,. .?.I(;IF:~"T'H '.:::;L..EtF'E, /::~L.f-q:F-';I<F~ :'::: 4:3. ,52 N 2 ./::. 1.90 W q-:'".'::2. C',5 I',1:37 ]. '? W C) ,, 11 ,.'.'.) ,, 21 ('_',...:..:: ( ,:.::, ,, t";90. :.'-.':q N 424.39 W . · ~8 N' 445 7:2 L.,.~ 6S:3. t0 N 4. :37.00 N ("). :3:1 ,.")..,.i. ( C, o .5: ,:"). Zl.Z :iii:50C),, :2-,:i- !.::]: f'q !4:2:,'.::,1,4 ('3,:7), '2'::!., C, F,! .1 ::7) :;;it 4 !.4 :_:!::::C~O,, :;2,'_'.:, :::;4 r-d "7:7:(:) b.l ...... 'T..' ,7) C) ,...:.,.. ," .' '::' _1 ARE:O AL..,/.-~:E::KA, I Nr-: r::Cd"IF'UTAT I ON F'AGE.....~,.1~.,, ](::t:~-..; ]....{il :, t,.,!r...:::L..L. I',!Cf: :..]:4. '..:.i: ;f. C~;plh.'..1-1.':i:'.,/F;:EI .... IO.'f3 f,.Ir:),". A () 7 ::.3 :7.', f::?:, ::ii', ,'-l 'P ..-. r: Z '[' I NE .r..:ATE PRI...IE~HCII7 }':{g~ '/ -., NOR 'FH SL. Ii]F'tF-, At...ASI<A 1:1.: I C'):: :;:'J/=, 22.-AI..IG-C-:::!!: ., 'T' r.:~ U IE NF.i:ASI...IF;'.E:D I')I::4IF:'T I]R]:F'T CCH..It::;,'i!!I.7. VIi.:.:RT]:C:;:.~I... VE:I::;t'T".I'(7.:AL. =; ~ .I E,, '.:_:.; [~: P~ F;~ E C: T ~..q. N G I_1 L '(.'~ R C L. O '..]i; U F;.'. E I:)AGLE DEF'TH Ah. fGt..E IhI RETTION I..ENr'.~'T'H !]EF:"T'H '..'=';F'CTIOr, J 'f'VO C:: ri 0 R D I N-..A..-T E :i:;. Dt'.3TANL-.:E DIREC:TION ~.SEVER~I. F' IE F..E 'T' Ii N D I',t 1::: E E T F' [.1: E: "1- F.' E: FZ 'T' F' E E "i" F' F E T F tF: ~:' '1' :D M D IS / 1 o C F:'t::(' rh,. I1:..:-(7: T L:::_' E -I' r-) F::' E{ T.EI () ,, O( ]. 7 1. C, ,, :7.': 5 1::: F.-'. E"f' ,! I:::~ [::' I-_: Iiilt t::;~ ~"_t I.-'I .r.z' 'Ii ]"q Z [?.!~:~ I::' 151L. ~'T' ~ ~i! :~;I._IF?..u ~ y !')S 14., WE]....I .... l',.l(.'.l: 2zl. E; I GMA-..-GYRCt ,JOB I',.I0: AO7C:::'::I:~O:34'F.~-OZ 'T' I I"!E-" DATE F'rq'.UDHOF_' BAY.., I'..~OI.~TH :i.:.';L_.CIF'E, AL.A::2;I<A .1. i: 1 :E', :: 25 2:;::'--AI...IC~-E',:_.-:~ .......................... I"I~'.:.] R i'::; [:'E ~:';.: .......................... T F,t i..I E E; I...I ?, '.E; lei[ A ................................ C: (] ..f.) E] ...................... MEAE;IJRE.Ei VERTICAl_ MD'"'-TVD VE"RTIC:AL R E E: T A N G U L A R C I.... 0 '.E'; U R IF.. VERTIC:AI_ ................ NAt;tE ............ DEPTH DEPTH OIF:'F DEPTH C 0 Ct R'. D .... T ..... N-.-.A--..-T.....-E S..f.)t:.:.';T~NCE f]IRECTI(]N THIC:KNES'.!i F'E E ]" F E E'I" F' E E T F liE; E T F E E T F E E"r' [ii M "I"OF' Ei:I-..II.JBI_.. I K T L')I::' :'_-'}: A D L. E IR 0 C H 11" (}/0 COIX!"rAC:T 't" E.'t F:' Z (.] N !F.' :3 '' i ' · , Suggested ..m to be inserte~ in each "Act "well folder to d~eck for timely compliance wi~h our rc<julations. Operator, Well Nam~ and Number Reports and Materials tO be received by:~.;'- 0~'-~3 Date _Required Date Received Remarks · Ccmple~on Report Yes / ~. -' 0-..~--~3 /' "''''f -~';; i, . ~ ': ~"~. ~ ,. -- - .. _Samples · Mud. Log /~ -- _ ,, Core Chips .-,-~ .' f -. · ,. Core ~,~scr~u~on Registered ~e~ P~ Inclina~on S~ey 1~-~ ~-~. --=- ~ /.,-) ./ ' , Drill sero Test Re. ms · , , " - ' /~" STATE OF ALASKA '-'" ALASK. ,)IL AND GAS CONSERVATION .. .~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OI LY~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of well at surface '~'['OC~ 9. Unit or Lease Name 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UMt VEktFIED Prudhoe Bay Unit I At Top Producing Interval I Sur[.__~ 10. Well Number 2817' FNL, 2689' FEL, Sec. 9, T10N, R14E, UM[~.H. ___~i 14-24 At Total Depth 11. Field and Pool ' _~-j~_., 2723' FEL, _j~~.., T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i I Pool 72' RKBI ADL -28312 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore [16. No. of Completions 06/15/83 06/25/83 07/06/83I N/A feet MS LI 1 (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey / 20. Depth where SSSV set 21. Thickness of Permafrost 17. Total Depth 9586'ND,9202'TVD 9547'MD,9168'TVD YES~ NO [] ~lipple ~ 2142 feet MD 1900' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Cmtd w/400 sxs PF II cmt 13-3/8" 72.0# L-80 Surf 2532' 17-1/2" Cmtd w/2000 sxs Fondu + 00 sxs PF "C" cmt 9-5/8" 47.0# L-80 Surf 8106' 12-1/4" ) Cmtd w/500 sxs "G" cmt 1 9-5/8" 47.0# US-95 8106' 8974' 12-1/4" 7" 29.0# N-80 8660' 9586' 8-1/2" Cmtd w/300 sxs "G" crnt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 8706' 8624 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date[~/~st Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD . 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. None Alaska Oil & Oas Cons, OommJssior~ ,Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... - '' ': .... '~ ~ ~':.~-~ GEOEOGIC MARKERS ~--'- : ~ ''; ,~ '~'~'' ;-,~:" ~:~ ':"; - "' "~;"~'~' ~ ';:':FORmaTION TESTS .... . , . NAME Include interval tested, pressure data, all fluids r~overed and gravity, .. MEAS. DEPTH TRUE VERT. DEPTH. GOR, and time of each phase.- Top Sadlerochit 9059~ 8739~ O~C 9~30 ~ 9065 ~ N/A Base Sadlerochi~ . - NOT R~ED . '. . . . . .. . ~ , . . 31. LIST OF ATTACHMENTS , Dri]]ing-His~ory~ ~mp]e~ion Su~ary~ ~yroscopic Survey (2 copies) 32. I hereby ce~ify that the foregoing is true and correct to the best of my Enowl~ge ~C Signed ~ ~ Title Area Drilling Engr. Date ~0--~ . 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- lng 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". 14-24 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/FS @ 2532'. Cmtd 13-3/8" csg w/2000 sx Fondu & 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 12' new form. Tstd form to 11.1 ppg EMW - ok. Drld 12-1/4" hole to 5252'. Ream 5075'-5252'. Drld to 7634'. Tight hole 7558'-7495'. Wash & ream 7463'-7634'. Drld to 8808'. Ream 8713'-8808'. Cont'd drlg 12-1/4" 'hole to 8987' (06/24/83). Ran 220 jts 9-5/8" 47#/ft, L-80, US-95 BTC csg w/FS @ 8974'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS and form to 8995'. Tstd form to 12.5 ppg EMW. Held 11.4 ppg after 2 min. Drld 8-1/2" hole to 9586' TD (06/25/83). Ran DIL/SP/BHCS/GR fr/9148'-9571'; FDC/CNL/GR/Cal fr/9148'-9571'; stuck tool @ 9362'. Strip over WL w/DP - recovered fish. TIH and circ and condition. POH. Ran FDC/CNL/GR/Cal. Stuck tool @ 9143'. Strip over WL w/DP - recovered fish. Ran 21 jts 7" 29#/ft, N-80, BTC csg fr/8660'-9586'. Cmtd 7" lnr w/300 sx Class G cmt. Drld cmt to 9547' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL 9540'-8500'. Ran 5-1/2" completion assy w/tail @ 8706' & pkr @ 8624'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Pull BPV. Secured well & released rig @ 2100 hrs, 06/30/83. Gyroscopic survey run on 07/06/83. NOTE' Inject salt water in the 13-3/8" x 9-5/8" annulus for freeze protection until the reserve pit disposal operation began. DRN/DH32-tw ARCO Alaska. Inc. ~ Post Office Bo Anchorage. Alas~ 99510 "reie~h.,--,--,e ~7 ?..-7 ~.~ September 9, 1983 Reference' Arco Directional Data D.S. 3-19~. 7-8-83 D.S. 3-20~'' 7-18-83 D.S. 3-21-- 8-8-83 D.S. 3-22~' 8-24-83 D.S. 14-24f 7-8-83 6-17-83 D.S. 14-25'~ 7-18-83 D.S. 14-31 .... 8-22-83 D.S. 14-32 8-24-83 Single Shot Teleco Single Shot Single Shot Single Shot Magnetic Survey Single Shot Single Shot Single Shot EW EW EW EW EW Teleco EW EW EW ~Please sign and return the attached copy as receipt of data. - Kelly McFarland ATO-1429F Trans. # 510 Chevron D & M Dallas Drilling Exxon Getty Marathon D I $ Tt~I BUTI ON North Geology Caroling Smith Sohio State cf Alaska ARCO Alaska, Inc. Post Office Anchorage ..... ka 99510 Teic-~nor-e ~07 August 29, 1983 Reference: Arco Cased Hole Finals D.S. 3-19 ~ 7-2-83' CBL/VD D.S. 4-8 ~/ 6-22-83 EPL D.S. 5-17 ¢ 6-24-83 EPL D.S. 6-9 /' 3-3-83 Epilog D.So 12-12 / 6-24-83 CET 7-23-83 CCL & Perforating Record 7-21-83 Completion Record D.S. 13-3j 3-13-83 Epilog D.S. 13r7/ 3-12-83 Epilog D.S. 14-5/ 8-22-80 Epilog D.S. 14-7/ 1-12-81 Epilog 3-9-83 Epilog D.S. 14-9B'~/ 3-11-83 Epilog D.S. 14-24/ 6-30-83 CBL/VD D.S. 14-26~/ .2-27-83 Epilog D.S. 16-11-~7 7-30-83 Spinner Log Run 1 5" Sch Run 2 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 1 '5" Sch Run 1 5" Sch Run 1 5" DA' Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 2 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" DA 5" Camco /~/Please sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. # 492 Chevron D & M Dallas Drilling ~xxon Getty Mobil DI STKIBUTION NotCh Geology Phillips Prudhoe Bay R & D ' '. · Sohio --. State of Alaska ',. ARCO Alaska, inc.," Post Office ,_ _.,, 360 Anchorage. Alaska 99510 Teie~hor"e 90.7 ~7'7 5537 July 20, 1983 Reference: Arco Magnetic Tape w/Listing 'D.S. 14-24 OH tape w/listing #228625 P~~lease sign-and return GO the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 433 Chevron D &M Dallas Drilling Exxon Getty Marathon Mobi ! DISTRIBUTION /mc/ / ~, /~? North Geolo~ Phillips Al~.~:~:k~ Prudhoe Bay ~ & D Caroling Smith Sohio State of Alaska ARCO Alaska, inc. Post Office r¢ 60 Anchorage. ,,-, ._~ka 99510 Teiephor',,=, 907 ~77 5537 July 20, 1983 Reference: Arco Open Hole Final's D.S. 13-27 .D.S. 14-24 6-7-3 CPL/Cyber look 6-7-83 BHCS 6-7-83 DIL/SFL · 6-7-83 LDT/CNL/GR (Poro) 6-7-83 GR in Casing 6-26-83 WEL 6-26-83 BHCS 6-26-83 DILL 6-27-83 CDL 6-27-83 CDL/CNL 6-27-83 GR~ Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 2" & 5" 5" GO. Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" RUn 1 5" '~~Ptease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 442 Chevron D &M Dallas Drilling Exxon ~e~ty Marathon DISTRIBUTION North Geology Phillips Prudhoe Bay · - - Sohio ':C~/ / - State of Alaska ARCO Alaska, In,r - Post OfficL _.~,,.f00360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly 'Report of Drilling & Workover Operations Dear Mr. Chatterton- Enclosed are Monthly Reports of Drilling and Workover Operations for the following- DS 14-23 DS 14-24 DS 13-27 DS 3-19 Pingut State #1 South Point State #1 and Well Completion or Recompletion Reports and Logs for- DS 7-24 DS 13-28 Also enclosed are revised Well Completion or Recompletion Reports and Logs for- DS 1-25 DS 13-29 DS 7-25 Sincerely, M. A. Major Area Drilling Engineer MAM/CSM34-sm Enclosures APCO Al,~ska Inc is ;~ Subsic:.~r~ ~,t AlianllrRich::~.~.~C;~,~tpan¥· , f.-~-~. STATE OF ALASKA ~ ~ ~ ~ ' ALASF' ,:L AND GAS CONSERVATION AMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI !1. Drilling wellx[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-91 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20970 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 1519' FNL, 1992' FEL, Sec. 9, T10N, R14E, UH 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 28312 10. Well No. DS 14-24 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. June ,1983 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded ~ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'. Ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 8987'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 9586'. Ran logs. Ran, cmtd & tstd 7" lnr. Ran CBL. Ran 5-1/2" Compl assy. Secured well & released rig @ 2100 hfs, 06/30/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#, H-40 Weld Conductor set ~ 80'. 13-3/8", 72#/ft, L-80 BTC csg w/FS @ 2532'. 9-5/8", 47#/ft, L-80 BTC csg w/FS ~ 8974'. 7", 29#/ft, N-80, BTC csg fr/8660'-9586'. Instld w/400 Sx PF II cmt. Cmtd w/2000 sx Fondu & 400 sx PFC cmt. Cmtd w/500 sx Class G cmt. Cmtd w/300 sx Class G cmt. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR fr/9148'-9571' FDC/CNL/GR/Cal fr/9148'-9571' CBL fr/9540'-8500' 6. DST data, perforating data, shows of H2S, miscellaneou~ data --;~ N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Area Drilling Engineer SIGNED TITLE DATE · NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 CSM/IqR21 Submit in duplicate 14-24 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0430 hrs, 06/15/83. Drld 17-1/2" hole to 2553'. Ran 65 jts 13-3/8" 72#/ft, L-80, BTC csg w/FS @ 2532'. Cmtd 13-3/8" csg w/2000 sx Fondu & 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 12' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 5252'. Ream 5075'-5252'. Drld to 7634'. Tight hole 7558' -7495'. Wash & ream 7463' -7634'. Drld to 8808'. Ream 8713'-8808'. Cont'd drlg 12-1/4" hole to 8987' (06/24/83). Ran 220 jts 9-5/8" 47#/ft, L-80, US-95 BTC csg w/FS @ 8974'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS and form to 8995'. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9586' TD (06/25/83). Ran DIL/SP/BHCS/GR fr/9148'-9571'; FDC/CNL/GR/Cal fr/9148'-9571'; stuck tool @ 9362'. Strip over WL w/DP - recovered fish. TIH and circ and condition. POH. Ran FDC/CNL/GR/Cal. Stuck tool @ 9143'. Strip over WL w/DP - recovered fish. Ran 21 jts 7" 29#/ft, N-80, BTC csg fr/8660'-9586'. Cmtd 7" lnr w/300 sx Class G cmt. Drld cmt to 9547' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL 9540'-8500'. Ran 5-1/2" completion assy w/tail @ 8706' & pkr @ 8624'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Pull BPV. Secured well & released rig @ 2100 hrs, 06/30/83. CSM/DH18- sm 07/08/83 '"' --"MEMORANDUM TO: THRU: FROM: State of Alaska 10SA:A/1 ~~, o~ ~ ~s c°~s~.w~zo~, te~on DATE: June 2 0 cna%~/ FILE NO: ~nnie C. Commissioner TELEPHONE NO: ~ / Ed~a~ ~. Si~ple~ J~~ SUBJECT: Petroleum Inspe~or - 1983 Witness BOPE Test on ARCO's Prudhoe DS 14-24 Sec. 9, T10N, R14E, UM., Permit No. 83-91, Parker Rig 176. Thursday,~ June.. 16, 1983 I left Parker 141, Kuparuk, (subject of another repgrt) and came to ARCO's Prudhoe DS 14-24 to witness a BOPE test. Parker Drilling Company Rig 176 was in the process of running casing. The BOPE test commenced at 8:50 PM .and w~s concluded at 10:10 PM, there we re- no failures. I filled out the AOCCC BOPE report, which is attached to this report. In summary, I'witnessed the BOPE test on ARCO's DS 14-24, Parker Rig 176. There were no failures. At t achme nt 02-00lA,Rev. 10/79) O&C, ~ ,1 ~ 4T80 STATE OF AI,ASKA ALASY~A OIL & GAS CONSERVATION COHblISSION B.O.P.E. Inspection Report Inspector ~)~ ~, Sl/~F/~_~/(o Operator ~ ~ .~_ ~ ~/~//~ ~ Well /3~ - / ~/~' ~/ Location: Sec ~ T/~;J R/Q~' ~% Drilling Contractor Date ~//~/.~' Well /~5/~/~?t/ ,. , Representative Permit ~ ~ ~ /~3/~ Casing Se Rig ~ '/~/- Representativ~ t @ ~-~.?- ft. Location, General Well Sign o General Housekeeping~ O({ Reserve pit O~( BOPE Stack /z~ Preve%~ter Annular Pipe Rams Blind Ram Line Valves H.C.R.' Valve Kill Line Valves Check~ Valve Test Pres.~ure ACCUHULATOR S'Y S T EI.I Full Charge Pressure ~0~O ps.ig Pressure After Closure /~OO psig 200 psig Above Precharge Attained: ~ min~2~ sec Full~ Charge Pressure Attained: ~ minOJZ-sec CqntrolS: Master ~_~ Lo~,~ ~ ~i~aO Remote ~li Blinds switch co=ve_r Kelly and Floor Safety Valves - Failures Upper Kelly Lower Kelly Ball Type Inside BOP' O~ ~est Pressure ~/< ~Test Pres sure ~,K ~st Pressure O/~"Test Pressure. Choke Manifold N°. Valves /a No. 'flanges ~O ,' Adjustable Chokes ~_ A~AO }lydrauically opera~ed choke ]--I.~. ~ O '--- Test Time hrs...~_O ~%~?~ Test Results: =~ ~ Repair or Replacement of failed equipment to be made within ~///~ days and. 'Inspector/Commission office notified. Remark s: · Distribution orig ' - AO&GCC cc - Operator cc - Supervisor. ARCO Alaska, Inc. Post Office Bo~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 14-24 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to alter the 9-5/8" and 7" casing programs. Since this well spudded today, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. Sincerely, M. A. Major Area Drilling Engineer MAM/JG3L47'sm Enclosures RECEIVED JUN Alaska Oil & [-;~s Cons, Anchora~a ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ;'"t---, ~ STATE OF ALASKA ALASKA 0mL AND GAS CONSERVATION C~J,v~MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS ,¥ 1. DRILLING WELL I~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc, 83-91 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-20970 4. Location of Well 9. Unit or Lease Name Surface: 1519' FNL, 1992' FEL, Sec. 9, TION, R14E, UN Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) 72 ' RKB 6. Lease Designation and Serial No. ADL 28312 10. Well Number 14-24 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing J~]X Perforations [] Altering Casing [] Stim u late [] Abandon [] Stim u lation [] Aba ndonment [] Repair Well [] Change Plans J~]X Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to alter the 9-5/8" and 7" casing programs as follows: ~~ 9-5/8" casinq: Propose to run 19 jts 9-5/8", 47.0 #/ft, US-95, BTC casing on the bottom portion of the 9-5/8" string. The remainder of the string will be the normal 9-5/8", L-80, BTC casing. 7" oasi nq: Propose to run 7", 29#/ft, N-80, BTC, SMLS, R3 casing. joints of 7", 29.0 #/ft, US-95, BTC casing. Estimated Start: June 17, 1983 (Well spudded 06/15/83) The marker joint will use 2 ~ -- RECEIVED t983 0il & Gas 60ns. bm.~mlssi0n 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Area Drilling Engineer Signed .~ ~ Tide The space below for Commission use Date Conditions of Approval, if any: Approved by O,-'q,i ~ ~,qA[ SIGNED' ~'~Y.. ~'fiR¥, iV, KIIGLEII.~ A~;P r,o','-.-,d ·/..:? 'i I-b-~tur:: * d By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU3/SN21 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate June 3, 1983 }!r. ~ark A. Major Area Dr il ling Engineer ARCO Alaska, Inc. P. O. Box 360 Anci~orage, Alaska 99510 Re: Pru~hoe Bay Unit DS 14-~4 ~CO Alaska, lnc. Per,:it No. 83-91 I.~-~. Sur. Loc. 1519'FNL, 1992''~ Sec 9 T10i:t R14E TI 0N R14E Bt~ole Loc. 97'FSL, 2665'FEL, Sec. 4, , , Dear Mr. Major~ Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be subnitted on a._i logs ~or copying e×ceDt experim.ental lo~s, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or nigration of anadromous fish. Operations in t~:ese areas are .~ubject to AS 16.05.870 and the regulations promulgated thereunder ~:~,~ie:~'~'~ 5, Alaska Ad~inistrat~ve Code). Prior to co~p~encin~.~ operations you may be contacted by the Habitat Coordinator's Office, Departnent of Fish and Gm~e. Pollution of any ~aters of the State is prohibited by AS A6, , " :.:, .~ . Chapter 3 Article. 7 and the ~e~.~ulations promulKate~ thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ended. Prior to commencing operations, you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduizn~ fieia ~or~, please notity this office 24 hours prior to commencing installation of the Mr. ~rk A. Major Prudhoe Bay Unit DS 14-24 -2- June 3, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below, the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. VerDL.truly Jgo3~ s, C. V. Chattert"~ni ~¥ o~[~ o~ 'r;.:~, Chairman of Alaska Oil and Gas Conservation Commission EnClosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. be · ARCO Alaska, Inc. ' Post Office B~_ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Nay 25, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 14-24, Permit to Drill Dear Mr. Chatterton' Enclosed are: Enclosed is our application for Permit to Drill DS 14-24 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we expect to spud this well on June 6, 1983, your earliest approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG3/L16 Enclosures ARCO Alaska. inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t,,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1519' FNL, 1992' FEL, Sec. 9, TION, R14E, UN At top of proposed producing interval 101' FNL, 2583' FEL, Sec. 9, TION, R14E, UM At total depth 97' FSL, 2665' FEL, Sec. 4, TION, R14E, UN (- EI VE[ "~ 01/~ Gas Cons 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 72' RKB I ADL 28312 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 ) 9. Unit or lease name Prudhoe Bay Unit 10. Well number 14-24 ~'i~ll"J Field and pool Prudhoe Bay Field Prudhoe Bay Oil Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 5 mi. NE of Deadhorse miles 2615' ~TD fr/ADL 28312 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9611' MD, 9236' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 5000' feet. MAXIMUM HOLE ANGLE 25 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 4-19 well 92' ~ 4210~TVD feet 18. Approximate spud date 06/06/83 3388 4141 psig@____ Surface psig@_923R ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE 0~°le 2~sing ~17-1/2" ] 13-3/8" i 2-1/4,'I 9-5/8,, 8-1/2" 17" ;ASING AND LINER Grade Coupling H-40 Welded L-80 BTC L-80 BTC L-80 BTS Weight 91.5# 72.0# 47# 29# 22. Describe proposed program: SETTING DEPTH Length MD TOP TVD 80' 30' 2470' 30' 8966' 130' 30' 29' 129' I 916' 8695' 18407 ' I MD BOTTOM TVD 110' I 110' 2500' 12500' 8995' 18679' I 9611 ' !9236' QUANTITY OF CEMENT (include stage data) 375 sx Permafrost II 2300 sx Fondu+400sx PF 500 sx G 1st Stage 300 sx PF 1, 2nd stage 400 sx Class "G" cement ARCO Alaska, Inc., proposes to directionally drill this well to 9611' MD (9236' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 14-19 will be 92' away from DS 14-24 at 4210' TVD, which is in the straight-hole portion of the well. There are no closer wellbores anywhere downhole. This well is planned to be used to dispose of reserve pit fluid down the 13-3/8" x 9-5/8" annulus. If an extended period of time is required for the pumping operation, the rig will be moved off the well and disposal continued. A non-freezing fluid will be placed in the annulus -prior to rig release.~ After. dispes~T-is cOmpleted, the well will be Arctic packed in the normal manner. SIGNED TITLE Area Drilling Engineer DATE ~./,~i/ The space below for Commission use CONDITIONS OF APPROVAL Samples required i Mud log required Directional Survey required I APl number I [~yES []NO I 50- O%''~/~ %, ~' ~ '~ []YES [~10 DYES ~LQ Permit number I Approvai date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission June 3, 1983 Submit in triplicate FEL · : I DEG)I t .. ~00- '--t--,..,.,.,. i , ' i I i : ;I,Ji~"~: :~ -! ',g,~ i ' !\ : i ! :. ._.T . _..._ __ '. i i i ' I,~.~ i'*r"~' ,I'~ i . i i ' i i i ~ ~j ~ ~ ; ..... !-~.-,.-~-~--:--:--- ~ii; ,;i :i ~ i i i : ,. :' ! : ; · ' , , ' i, i , ;, ] ,"~i !t"~, 4~fl. I , I, qk: : ; '-?'~ ..... F'i-.;'-i.' ff --'- i i i i i } ; ; i ~ i i ! ~ : ~i ! 'ii! !I!! ;11 i i I !l;,,. ``'% ~ii !~ iill '' }:;! ..... ;---- , ....... ~---¢ : ........ i .... ..... ' .... ' ' ' , ~ ..... ; ,:~- ;: ~',1, I: ,, , ,ii. ; ; ; ! ; : : i ! i i ', i J : : ' i I ; : - ''i' !~'i '.':i 'I'': 'i ;:'i . ! i ; ; : T ', : ' '"~1. ~i~"~ , .: :, , ..... ! :iii ~ii i i ; - ; i ~ : , , ', ~ , , ; , , ; , : ! :: ; , i i ; ,_:-;- ', ! ; .... ~-.:-£ ..... ,--,-~--- i i : ,, ; , . i~ ; ; : il'. ~ '. ! ': ! ~ ! i ~ ! i ': ; ; ; ~ i ! :. : . ; ; ~ '_~ , __L_~__;___L'_L_. ._.~-_,_; ....... -~----~ ~~ '---r%-....-'~'-- . . , '~-F'"-- .... .---F-'- ~~~~~ ....... .................. , ----~-~ ~ i ! ! i , , , ~ ' ~ ' -t I i i ': ! ~ i i , : : ~ ~ ~ : i ! ! '' ~ ~ i ~---'--~-;-, .ill -- !~'~- , : , · ANNULAR PREVENTER BLIND RAMS PIPE RAN5 "'"--"-'t~$POOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Caoacit,v Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with cl~arging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-$/8' BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. S. Increase presure to 3000 psi and hold for a minima, of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to SO00 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and, open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside 80P to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. 5 Rev. 5/13/81 ',. SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM ]'NC'. SCHEMATIC ~ I0" HYD. OPR. BALL VALVE / ~ WELL BORE (SEE DETAIL) .~ ,.,"..,-~ I0" HYD. OPRo BALL VALVE /' //'-,/" mALL 90° TURNS ARE "TEE" ~ ]CUSHION . _1 --! WELL RESERVE PIT AREA NOTE' FLOWL INE DR ILL ING RISER 20" 2OOO PSI WP ANNULAR PREVENTOR ~~~10" DIVERTER LINE Valves on diverter lines open automati- cally when the annular preventer is closed. -- DR ILL ING SPOOL 20" CONDUCTOR PIPE I O" HYDRAULIC OPERATED BALL VALVES "DETAIL" 20?,.6O I( CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~, :~ ~. ITEM APPROVE DATE / (,.'~- thru 8)' (3) A min(, (12 thru 20) (5) BOPE ~T/?' ~/~z? '~?j~ (21 thru 24) le e 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ............................ Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... REMARKS Does operator have a bond in force ............... Is a conservation order needed ... Is administrative approval needed ]iiiiii{i]ii::i:{iiiii.:{i]]]]:[.[[ i~- .... Is conductor string provided .................................. .,,, ~ _ Is enough cement used to circulate on conductor and surface ...11'''' ~ ~ , Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .............. Will surface casing protect fresh water zones .... ' .......... Will all casing give adequate safety in collapse, tension and burst ,~ Is this well to be kicked off from an existing wellbore ............. Is old' wellbore abandonment procedure included ,on 10-403 ............ Is adequate well bore separation proposed ............ . ............. Is a diverter system required lie Are necessary diagrams of diverte~'~'~;~';~gl;~;~;'~;[~g~;~'[]][]. Does BOPE have sufficient pressure rating - Test to ~/~ psig Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: ~-'i ..... / .xf ?£'R k',:.{D 7/-"-' ,"V :' o: Geology: Enginj~er ing: ~-~-./2-- LCS~'~EW ~ WVA ~ JK~HJH f rev: 12/06/82 INITIAL GEO. UNiT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. .o * ALASKA COMPUTING CENTER * * . ****************************** * ............................ * ....... SCHLUMBERGER ....... * * ............................ . ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 14-24 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292097000 REFERENCE NO : 99139 RECEIVED 1990 Alaska Oil & Gas Cons. Commi~Jon Anohorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/22 ORIGIN : FLIC REEL NAME : 99139 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, DS 14-24, PRUDHOE BAY, API# 50-029-20970-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE ': 99/03/22 ORIGIN : FLIC TAPE NAME : 99139 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA, DS 14-24, PRUDHOE BAY, API # 50-029-20970-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: DS 14-24 API NUMBER: 500292097000 OPERATOR: Arco Alaska Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22 -MAR- 99 JOB NUMBER: 99139 LOGGING ENGINEER: Johnson OPERATOR WITNESS: SCHUMWAY SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL : 1819 FSL: FEL: 1992 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 71. O0 DERRICK FLOOR: GROUND LEVEL: 42. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9584.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 1983 LOGGING COMPANY: GEARHART BASELINE DEPTH 88888.0 9346.5 9337.0 9334.5 9331.5 9324.0 9320.5 9318.5 9314.5 9313.5 9311.0 9309.5 9303.5 · 9298.5 9296.0 9287.5 9283.0 9280.0 9273.0 9271 5 9267 0 9259 0 9253 0 9251 0 9250 0 9248 5 9245.0 9243.0 9242.5 9239.0 9238.5 9237.5 9236.0 9235.5 9233.0 9230.0 9229.5 9225.0 9215.0 9214.0 9212.0 9199.0 9197.5 9180.0 9177.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.0 9346.5 9337.0 9333.5 9324.0 9320.0 9315.0 9311.5 9299.5 9284.5 9281.0 9275.5 92 72.5 9263.5 9251.0 9243.5 9239.5 9235. 0 9228.0 9213.5 9199.5 88889.5 9333.0 9319.5 9315.0 9311.5 9304.5 9296.5 9289.0 9281.0 9275.5 9255.5 9253.5 9252.0 9245.0 9243.5 9241.0 9239.0 9237.5 9233.5 9230.0 9226.5 9216.0 9213.5 9199.5 9182.0 9179.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 9166.0 9165.0 9158.5 9156.5 9156.0 9151.0 9148 0 9144 5 9142 5 9139 0 9137 0 9133 5 9132 0 9123 0 9118.0 9117.0 9114.5 9113.0 9110.0 9105.0 9095.0 9088.5 9088.0 9085.5 9085.0 9083.0 9082.0 9078.0 9077.0 9071.0 9070.5 9067.5 9062.0 100.0 $ REMARKS: 9167.0 9167.0 9160.5 9157.5 9157.5 9153.0 9149.0 9146.0 9143.0 9142.5 9139.0 9135.5 9133.0 9124.5 9119.0 9119.0 9116.0 9114.0 9109.5 9103.5 9094.5 9089.5 9089.5 9086.5 9086.5 9083.5 9084.0 9079.0 9079.0 9073.5 9072.5 9069.0 9063.5 101.5 102.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 14-24 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAM~A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GA~A RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: FILE HEADER FILE NIIM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUM~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9352 . 0 9061 . 5 RST 9364.5 9062.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 5 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274711 O0 000 00 0 1 1 1 4 NBAC RST CPS 1274711 O0 000 O0 0 1 1 1 4 FBAC RST CPS 1274711 O0 000 O0 0 1 1 1 4 SBNA FIL CU 1274711 O0 000 O0 0 1 1 1 4 SFNA FIL CU 1274711 O0 000 O0 0 1 1 1 4 SBFA FIL CU 1274711 O0 000 O0 0 1 1 1 4 SFFA FIL CU 1274711 O0 000 O0 0 1 1 1 4 TRAT FIL 1274711 O0 000 O0 0 1 1 1 4 IRAT FIL 1274711 O0 000 O0 0 1 1 1 4 CIRNFIL 1274711 O0 000 O0 0 1 1 1 4 CIRF FIL 1274711 O0 000 O0 0 1 1 1 4 BSALRST PPK 1274711 O0 000 O0 0 1 1 1 4 SIBF RST CU 1274711 O0 000 O0 0 1 1 1 4 TPHI RST PU-S 1274711 O0 000 O0 0 1 1 1 4 SFFC RST CU 1274711 O0 000 O0 0 1 1 1 4 SFNC RST CU 1274711 O0 000 O0 0 1 1 1 4 SIGM RST CU 1274711 O0 000 O0 0 1 1 1 4 DSIG RST CU 1274711 O0 000 O0 0 1 1 1 4 FBEF RST UA 1274711 O0 000 O0 0 1 1 1 4 CRRARST 1274711 O0 000 O0 0 1 1 1 4 GRCH RST GAPI 1274711 O0 000 O0 0 1 1 1 4 TENS RST LB 1274711 O0 000 O0 0 1 1 1 4 CCL RST V 1274711 O0 000 O0 0 1 1 1 4 GR BCS GAPI 1274711 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. SFNA . FIL IRA T. FIL SIBF. RST SIGM. RST GRCH. RST DEPT. SFNA. FIL IRAT.FIL SIBF. RST SIGM. RST GRCH. RST 9542.000 NBAC.RST -999.250 SBFA.FIL -999.250 CIRN. FIL -999.250 TPHI.RST -999.250 DSIG.RST -999,250 TENS.RST 8954 000 NBAC.RST -999 250 SBFA.FIL -999 250 CIRN. FIL -999 250 TPHI.RST -999 250 DSIG.RST -999 250 TENS.RST -999 250 FBAC.RST -999 250 SFFA.FIL -999 250 CIRF. FIL -999 250 SFFC.RST -999 250 FBEF.RST -999 250 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF.RST -999.250 CCL.RST -999,250 SBNA.FIL -999,250 TRAT. FIL -999,250 BSAL.RST -999,250 SFNC.RST -999,250 CRRA.RST -999,250 GR.BCS -999,250 SBNA.FIL -999,250 TRAT.FIL -999,250 BSAL.RST -999,250 SFNC.RST -999,250 CRRA.RST -999.250 GR.BCS -999,250 -999,250 -999.250 -999.250 -999.250 25.200 -999.250 -999.250 -999.250 -999.250 -999.250 120.800 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VBRSION · O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves'for each pass in separate files. PASS NOY4~ER: 2 DEPTH INCREMENT: 0.5000 FILE SU~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9353.5 9061.5 RST 9365.0 9063.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NONBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88889.5 88890.0 9353.0 9355.0 9346.0 9347.5 9332.0 9333.5 9331.5 9333.0 9327.5 9329.0 9324.5 9325.5 9323.5 9324.0 9319.0 9319.5 9313.5 9315.5 9311.5 9312.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 9310. 5 9303.5 93 O1.0 9296.0 9291 5 9289 5 9287 5 9280 5 9280 0 9272 0 9267 5 9266.0 9264.0 9261.5 9259.0 9257.0 9253.0 9249.5 9248.5 9246.0 9243.0 9239.0 9238.5 9238.0 9236.0 9235.5 9233.0 9232.5 9229.5 9228.0 9220.0 9219.5 9217.0 9212.0 9206.5 9204.0 9197.5 9193.0 9182.0 9180.0 9174.5 9174.0 9168.0 9165.0 9159.0 9156.0 9152.0 9151.0 9148.0 9147.0 9141.5 9139.0 9136.5 9134.0 9129.5 9302.0 9292.0 9289.0 9281.5 9276.0 9272.5 92 69.0 9259.5 9249.0 9248.0 9243.5 9239.0 9235.0 9231.5 9228.0 9218.5 9215.0 9206.0 9193.5 9182.5 9174.5 9169.0 9153.0 9149.0 9143.0 9130.5 9311.5 9304.5 9296.5 9292.5 9288.5 9281.0 9269.0 9265.5 9264.0 9261.5 9255.5 9252.0 9243.5 9241.0 9239.0 9237.5 9233.0 9228.5 9221.5 9213.5 9206.0 9199.5 9182.0 9175.5 9167.0 9161.5 9157.5 9153.0 9148.5 9142.0 9139.5 9136.0 9131.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 9123.5 9126.0 9121.0 9121.0 9120.0 9121.5 9117.0 9119.0 9116.5 9119.0 9115.0 9115.5 9111.0 9112.0 9109.0 9109.0 9108.0 9109.5 9106.0 9107.0 9104.5 9104.5 9102.5 9103.0 9099.5 9100.0 9098.5 9097.5 9096.0 9095.5 9095.5 9095.5 9094.5 9094.5 9091.5 9093.0 9089.0 9089.5 9088.0 9089.5 9085.5 9086.5 9084.5 9086.5 9083.0 9083.5 9081.5 9084.0 9078.0 9079.0 9077.5 9079.5 9075.0 9077.0 9071.5 9072.5 9074.0 9067.0 9068.5 9063.0 9066.0 100.0 101.5 103.0 $ RE~L~u~S: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 ArBACRST CPS 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1274711 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9365.000 NBAC.RST 2676.827 FBAC.RST 3468.025 SBNA.FIL SFNA.FIL 19.287 SBFA.FIL 44.047 SFFA.FIL 17.202 TRAT. FIL IRAT. FIL 0.505 CIRN. FIL 1.136 CIRF. FIL 2.441 BSAL.RST SIBF. RST 35.757 TPHI.RST 23.546 SFFC.RST 14.524 SFNC.RST SIGM. RST 14.519 DSIG.RST 0.329 FBEF.RST 27.274 CRRA.RST 53.287 0.918 38.873 14.594 1.994 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 10 GRCH.RST -999.250 TENS.RST 1183.000 CCL.RST DEPT. 9061.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT.FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 112.891 TENS.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF.RST -999.250 CCL.RST 0.000 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCRE~IENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITH~ETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1274711 NBAC RST CPS 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF RSAV 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRSAV PPK 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARSAV 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1274711 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 12 ** DATA ** DEPT. 9364.500 ArBAC. RST 2474.806 FBAC.RST SFNA.RSAV 19.273 SBFA.RSAV 46.723 SFFA.RSAV IRAT.RSAV 0.505 CIRN. RSAV 1.147 CIRF.RSAV SIBF. RSAV 36.545 TPHI.RSAV 22.962 SFFC.RSAV SIGM. RSAV 14.452 DSIG.RSAV 0.303 FBEF. RSAV GRCH.RST -999.250 321 O. 695 SBNA. RSAV 17.122 TRAT. RSAV 2.493 BSAL. RSAV 14.456 SFNC. RSA V 25. 715 CRRA. RSAV 54.428 0.907 41.068 14.513 1.978 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE ' FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 -MAXREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AKIMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9398.5 $ LOG HEADER DATA DATE L~ED : SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH .......... 9007.5 09-AUG-98 8Cl -205 9409.0 9387.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 13 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) 9060.0 9363.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAN~4A RAY RST RESERVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 9584.0 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) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) '. BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): CORRELATED TO CBL DATED 6/30/83 PUMPED 320 BBLS CRUDE INTO TUBING THEN MADE 2 BASE PASSES. PUMPED 90 BBLS BORAW WATER AND 161 BBLS CRUDE THEN MADE THREE BORAX PASSES. CHANNEL FROM PERFS TO 9348' GOC AT 9143 ' THIS FILE CONTAINS THE RAW DATA FOR BBASE PASS #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 14 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NPHVPS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PSi V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PSi 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RCAKPSi 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PSi 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 15 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FSCE PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PSi UA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PS1 MA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 XArV PSI V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PS1 V 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 1274711 O0 000 00 0 4 1 1 4 68 0000000000 3C42V PS1 V- 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PSi CPS 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SF1VAPS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PSi CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 16 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIBF SIG CU 1274711 O0 000 O0 0 4 1 1 4 SIGM SIG CU 1274711 O0 000 O0 0 4 1 1 4 TRAT PS1 1274711 '00 000 O0 0 4 1 1 4 TRAT SIG 1274711 O0 000 O0 0 4 1 1 4 TRAT FIL 1274711 O0 000 00 0 4 1 1 4 GR PS1 GAPI 1274711 O0 000 O0 0 4 1 1 4 RDIX PS1 1274711 O0 000 O0 0 4 1 1 4 CRNI PS1 K~Z 1274711 O0 000 O0 0 4 1 1 4 CRFI PS1 KHZ 1274711 O0 000 O0 0 4 1 1 4 CTM PS1 DEGC 1274711 O0 000 O0 0 4 1 1 4 XTM PS1 DEGC 1274711 O0 000 O0 0 4 1 1 4 TAV PS1 KV 1274711 O0 000 O0 0 4 1 1 4 FICU PS1 AMP 1274711 O0 000 O0 0 4 1 1. 4 CACU PS1 AMP 1274711 O0 000 O0 0 4 1 1 4 BUST PS1 1274711 O0 000 O0 0 4 1 1 4 BUSP PS1 1274711 O0 000 O0 0 4 1 1 4 RSXS PS1 1274711 O0 000 O0 0 4 1 1 4 TPHI PS1 PU 1274711 O0 000 O0 0 4 1 1 4 TPHI SIG PU 1274711 O0 000 O0 0 4 1 1 4 CCLC PS1 V 1274711 O0 000 O0 0 4 1 1 4 RSCS PS1 1274711 O0 000 O0 0 4 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PSI CM2 V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL. PSi CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 9398.500 CS.PS1 1463.548 NSCE. PS1 0.441 CHV, PS1 -12.211 RCFR~PSl 2.000 RTDF, PS1 1.791 FSCR.PS1 160.401 BMCU. PS1 12.321 FBEF. PS1 38.072 BSPR.PS1 5.060 XP2V, PS1 0.000 RXRC, PS1 -999.250 BSAL.SIG -999.250 CIRF. FIL -999.250 IRAT. FIL -999.250 SBNA.PS1 -999 250 SBNA.SIG -999 250 SBNA.FIL -999 250 SFFC. PS1 -999 250 TRAT. PS1 1668.211 TENS. PSi 2.624 CRRA.PS1 201.581 CP5V. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.240 AQTF. PS1 35.449 GDCU. PS1 24.092 NPGF. PS1 1.112 MARC. PSI 12.100 X~42V. PS1 0.000 RXAK. PS1 -999.250 CIRN. PS1 -999.250 DSIG.PSl -999.250 NBAC. PS1 -999.250 SBFA.PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 TRAT. SIG 13 561 RDIX. PS1 158903.000 CRNI.PS1 104 004 XTM. PS1 102.051 TAV. PS1 2.446 BUST. PSi 3.000 BUSP. PS1 -999.250 TPHI.SIG -999.250 CCLC. PS1 -999 -999 -999 -999 -999 -999 898.000 NPHV. PS1 1.955 NSCR.PS1 5.050 CP2V. PS1 0.000 RCRC. PS1 1416.017 FPDE. PS1 0.441 SF6P. PS1 60.340 EXCU. PS1 1.013 FPGF. PS1 0.000 XHV. PS1 -12.328 RXFR.PS1 0.000 SHCU. PS1 -999.250 CIRF. PSl -999 250 FBAC. PSl 250 SFNA.PSl 250 SFNA.SIG 250 SFNA.FIL 250 SIBF. PS1 250 SIBF.SIG 250 TRAT. FIL 446.290 CRFI.PS1 95.031 FICU. PS1 3.000 RSXS.PS1 0.010 RSCS.PS1 1494.142 0.195 12.158 0.000 1389.352 178 474 26 433 1 001 200 854 0 000 35 121 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 228.244 2.168 8878.000 8459.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 17 DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAIf. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 9007.500 1464.845 0.661 -12.191 0.000 1.799 160.348 10.756 51.661 5 075 0 000 24 784 0 791 0 533 32 567 0.666 31.158 29.029 0.464 165.896 101.074 2.467 34.607 CS.PS1 1855.443 TENS.PSI NSCE. PS1 2.626 CRRA.PS1 CHV. PS1 201.339 CPSV. PS1 RCFR.PS1 0.000 RCLC. PS1 RTDF. PS1 0.000 FPHV. PS1 FSCR.PS1 0.831 AQTF. PS1 BMCU. PS1 34.193 GDCU. PS1 FBEF. PS1 20.143 NPGF. PS1 BSPR.PS1 1.091 MARC. PSi XP2V. PS1 12.079 3~42V. PS1 RXRC.PSl 0.000 RXAK.PS1 BSAL.SIG 2.847 CIRN. PS1 CIRF.FIL 1.302 DSIG.PS1 IRAT. FIL 0.538 NBAC. PS1 SBNA.PS1 55.034 SBFA.PS1 SBNA.SIG 4.088 SBFA.SIG SBNA.FIL 52.103 SBFA.FIL SFFC.PS1 29.114 SIGM. PS1 TRAT. PS1 1.155 TRAT. SIG RDIX. PS1 169348.000 CRNI.PSl XTM. PS1 98.145 TAV. PS1 BUST. PSi 3.000 BUSP.PS1 TPHI.SIG 1.034 CCLC. PS1 1163.000 1.873 5.050 0.000 1418.458 0.661 60 059 1 006 0 000 -12 356 1 000 0 801 -0 613 2594 118 45 594 3 795 42 536 28.901 0.023 474.966 94.990 3.000 -999.250 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 1501.466 0.131 12.070 0.000 1391.145 177.871 26.067 1.002 200.750 0.000 37.583 1.249 3481.169 32.659 0.798 31.155 30.751 1.003 1.131 253.634 2.204 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 18 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT.. 0.5000 FILE SU~k~RY VENDOR TOOL CODE START DEPTH RST 9399.0 $ LOG HEADER DATA 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): STOP DEPTH 9006.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~VA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS 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) .. 09-AUG-98 8Cl -205 9409.0 9387.0 9060.0 9363.0 TOOL NUMBER CGRS-A RST-A 8.500 9584.0 CRUDE THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 19 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO CBL DATED 6/30/83 PUMPED 320 BBLS CRUDE INTO TUBING THEN MADE 2 BASE PASSES. PUMPED 90 BBLS BORAW WATER AND 161 BBLS CRUDE THEN MADE THREE BORAX PASSES. CHANNEL FROM PERFS TO 9348' GOC AT 9143' THIS FILE CONTAINS THE RAW DATA FOR BBASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 368 1 0.5 FT 2 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2F/HR 1274711 O0 000 O0 0 $ 1 1 4 68 0000000000 TENS PS2 LB 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 2O NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NPDE PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 1274711 O0 000 O0 0 $ 1 1 4 68 0000000000 CRRAPS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS2 PSIG 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 ArBEF PS2 UA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS2 UA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1274711 O0 000 O0 0 $ 1 1 4 68 0000000000 X~2V PS2 V 1274711 O0 000 O0 0 $ 1 1 4 68 0000000000 RXFR PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 21 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI_.dtSS MOD NUmB S~'vlP ELI~ CODE (HEX) SFNA PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS2 CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 tCHZ 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS2 DEGC 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 KV 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS2 V 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 1274711 O0 000 O0 0 5 1 1 4 68 0000000000 * * DA TA * * DEPT. 9399.000 CS.PS2 1100.245 TENS.PS2 813.000 NPHV. PS2 NPDE. PS2 1465.760 NSCE.PS2 2.679 CRRA.PS2 1.954 NSCR.PS2 AQTM. PS2 0.661 CHV. PS2 200.854 CPSV. PS2 5.079 CP2V. PS2 CM2V. PS2 -12.231 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 1423.341 FPDE. PS2 FSCE.PS2 1.806 FSCR.PS2 0.353 AQTF. PS2 0.661 SF6P. PS2 HVPV. PS2 160.156 BMCU. PS2 36.621 GDCU. PS2 59.684 EXCU. PS2 NBEF. PS2 13.465 FBEF. PS2 26.313 NPGF. PS2 1.010 FPGF. PS2 BSTR.PS2 50.149 BSPR.PS2 1.106 MARC. PS2 0.000 XHV. PS2 1501.466 0.394 12.173 0.000 1391.374 178.218 24.460 1.006 200.370 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 22 XP5V. PS2 5.079 XP2V. PS2 RXLC.PS2 0.000 RXRC.PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF.FIL IRAT.PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT.PS2 GR.PS2 184.265 RDIX. PS2 CTM. PS2 99.121 XTM. PS2 CACU. PS2 2.476 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG DEPT. 9006.000 CS.PS2 NPDE. PS2 1465.150 NSCE. PS2 AQTM. PS2 O. 661 CHV. PS2 CM2V. PS2 -12. 231 RCFR . PS2 RCAK. PS2 O. 000 RTDF. PS2 FSCE. PS2 1.778 FSCR.PS2 HVPV. PS2 160.540 BMCU. PS2 NBEF. PS2 11.134 FBEF.PS2 BSTR.PS2 51.593 BSPR.PS2 XPSV. PS2 5.074 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 23.064 BSAL.SIG CIRN. FIL 1.023 CIRF. FIL IRAT. PS2 0.540 IRAT. FIL SFFA.PS2 24.801 SBNA.PS2 SFFA.SIG 0.384 SBNA.SIG SFFA.FIL 26.075 SBNA.FIL SFNC.PS2 22.917 SFFC. PS2 SIGM. SIG 0.423 TRAT. PS2 GR.PS2 135.307 RDIX. PS2 CTM. PS2 101.074 XTM. PS2 CACU. PS2 2.472 BUST. PS2 TPHI.PS2 31.819 TPHI.SIG 12.085 X~2V. PS2 0.000 RXAK. PS2 -999.250 CIRN. PS2 -999.250 DSIG.PS2 -999.250 NBAC. PS2 -999.250 SBFA.PS2 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS2 -999.250 TRAT. SIG 172257.000 CRNI.PS2 97.656 TAV. PS2 3.000 BUSP.PS2 -999.250 CCLC. PS2 1801.672 2.595 201.339 0 000 0 000 0 297 33 670 20 374 1 143 12.076 0.000 2.772 1.717 0.540 50.903 4.942 48.935 23.585 1.093 183013.000 97.377 3.000 0.862 TENS. PS2 CRRA.PS2 CP5V. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XM2V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP. PS2 CCLC. PS2 -12.348 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 454.041 94.457 3.000 0.010 1187.000 1.830 5.050 0.000 1423.341 0.661 60.012 0.998 0.000 -12.356 0.000 1.079 -0.184 2746.167 42.530 3.416 44.495 23.877 0.018 477.292 94.939 3.000 -999.250 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT.FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 0.000 35.121 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 232.338 2.217 8878.000 8459.000 1499.024 -0.713 12.202 0.000 1391.374 178.218 26.095 0.997 200.906 0.000 39.372 1.827 3568.984 25.174 0.662 26.211 30.146 0.974 1.077 260.823 2.190 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE ' FLIC VERSION : O01CO1 DATE : 99/03/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 14:06 PAGE: 23 **** TAPE TRAILER **** SERVICE NAM~ .. EDIT DATE : 99/03/22 ORIGIN : FLIC TAPE NAME : 99139 CONTINUATION # : 1 PREVIOUS TAPE : CO~ : ARCO ALASKA, DS 14-24, PRUDHOE BAY, API# 50-029-20970-00 **** REEL TRAILER **** SERVICE NAF~ : EDIT DATE : 99/03/22 ORIGIN : FLIC REEL NAME : 99139 CONTINUATION # : PREVIOUS REEL : COf~4ENT : ARCO ALASKA, DS 14-24, PRUDHOE BAY, API# 50-029-20970-00 D~RECT DIGITAL L. OGGINO COMPUTER PROCESSED ANALYSIS ot-,A INC. Compmn? ARCO ALA~?'' 4-24 CH,,'CNS Fimld PRUDHOE BAY C o u n t.,.~., N 0 R T H S L 0 P E St.mtm ALASKA Countr.~, USA CL I ENT FORMAT DATA TAPE LOG I NFORMAT I ON o T AN [:'AR[, F' O.R M A T' ( L, I , S, ) : ,~RCO ~4-24 895i , O0 to 9555, O0 Name: [.',S I~--.::'4 CH~,'C,'NF.~ F'i ~ 1,-t: PRUDHL-'E BAY [:,ate: 24 MAY., 1984 Time: i0:24 AM THU, L, I, TAPE RECORDS GF.A/~HA/~T +:** F.:EEL HEADER C,.-~t.¢:: 84,," 05/24 Comment~: HEADER Origin: RECORD'-' R~i name: oo1786 C,antinuation ~: 01 TAPE HEADER .'~- * :+: :,*= S¢_r, vica n._=,mm: &GSFOi Date~ 84,/05/24 Comments ~ Or. igin: 281 786 C o r,'l:, i n u a t i c, r, .iT: 0 i "~': E 0 F :4.: :+: HEADER RECOR[)S length: i024 File tppe: L.O Previous ?i'!e: Dat~ H iq E H CN i.,.i FN C 0 U N STR'F C T R Y SECT TOi.:iN RANG EKB EC, F EG'L P[:, LHF DHF R U N LCC SON L U N FL LUL E: N C..; i t.d i "1" H Ti_i B L 'T' C: S 'FLAB BH¥ ' HT l"t S F; MViS RH RHF H F S T i'"t F S S R M C: HC S"[' N C S S I N F 0 R H A T I 0 N PECF.._ _ J F' D'-'..., r: 0 H T E N T S UH iT AF.:C:O ALASKA [:,S 14-24 C:H i'Z_, ~ i i_ _ ! ,:._.F~HnE BAY NORTH SLOF'E ALASKA U'3 A 'i 4E ,'"'""2,000 ............................................. 7'i , 8 O0 ........................................... 4::.'., 000 ......................................... Si_ : i i i I i : 28 1786 ................ NORTH SLOF'E NORTH SLOPE A R N 0 L I} HOLHRN 9547, 95 ..... .:, 0,000 ................. 8950, 9529, O 00 0,00 O 2OO, OOO 200, OOO CRUDE O, O,OOO O, O, 0 O 0 0 O , 0, 00 O i r : : : z t .... FT .... FT .... FT .... FT ......... HR HR DEG. F DE6F' CP OHHH OHHN DEGF' 0 H t"l i'.I DEGF TYPE CATG SIZE L: LJ 12 0 0 40 65 0 iD 40 65 0 0 4 i'i 6 5 0 0 20 65 0 0 20 65 0 0 2 0 6 5 0 0 ~.": 6 5 ]"~ 0 3 65 O O 3 65 0 3 4 6 8 0 3 4 6 E: 0 S 2 65 0 3 2 'S 5 n.. 3 ,::"" 65 0 O 2 79 t'l Ii '::' 7 g 0 0 i O 6,5 0 0 i 0 65 0 0 20 6,5 0 0 '20 65 0 0 2 0 65 0 0 ;7" O 55 0 ."'3 4 6,8 0 3 4 6 S 0 :4 4 6 8 0 3 4 <.:, 8 I"* '~'' 0 2 't O 4 4 68 O i 4 68 0 ~ 4 r;c, ,,.,,~ ,,.,~ O 2 2 0 6 5 0 ":' "" 8 F., ~ 0 2 4. GE: 0 2 4. ,-.:. 4 ~:; 8 0 2 4 68 0 2 i2 65 0 2. 4 68 0 2 4 68 0 '""' ~. 12 65 COMMENT RE CORDS ~-'~ This LIS trope was writtmn bs..' G~_ar. hart InH_u==trims Wirmiinm Smrvicms~ _ _ · :e Ali curve and tool mnemnnic~ u~ed :~:,~ Gearhart curve and tool mnemonics, GEARHART TO SCHLUt'~BE,R GER MNEM SERV IC:E UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT GR MCP t=ell-"" "' I GR I.,,RP"' ' I C:CL MCP MV CCL MV FCNS MOP CPS FCNL CPS !,l .... N ..~ M L. P C P S N C H L C P S CNSS MCP ?. SAND NPHI PU RAT COMPUTED RAT AVC.' COMPU:FED AVG DATA FORMAT SPEC I F I CAT IONS EN TRY TYPE S I ZE C FiC, E 0 i 6 6 :+::~-* ENTRY BLOCk: LE6END T'?PE DESCRIPTION 0 TerD',.~.na(.oP ,:: no mc:r,~_ .¢_ntri,~_z ) G~ [)ATA F 0 R M A T SERVICE SERViC. E API i D u ~] L) 1- ~ ~ ~J ~ i T L 0 Ii AP I AP i AP I F i LE TYPE C:LASS HO[:, % [::EF:T 281786 FT 0 C4R '28 i 7.96 GAP i 0 .,.'" C: L ..=..'~ ,...° 1 786 f"I, V t'~ FCNL. 28 i 786 L.'"-' et.. ,... fi. '[-' ~-. -. , -- -- h,.L.i,i~ 28i 7~ CPS 0 NF-'H: .[ 281 786 PU O F,,: A T 28 'J 7 :--~ 6 0 A ',,' ~9, 28 i ;,-' 86 ,.,'" O' 0 .7, i 0 0 0 0 0 6 8 ._"3 r., '"' 0 0 :SPEC i F I C:AT I ONR P Ri_-:. % SiZE LVL SHPL 4 0 i 6 8 4 0 i 68 4 0 i 6 8 4. 0 i 68 4 0 1 68 4 0 ~ 68 4 0 i 6 8 PF<OC:ESS iNDiCA lOt,-,':5 00 iii l.'t 00 t."100 i."i 0 Ct 0 t:1 i.] 0 i] 0 000000 000000 000000 000000 000000 000000 L]I.'IOOrJO O000L'IO 000000 000000 O00000 000000 O00OO0 000000 000000 000000 000000 000000 000000 LqO0000 000000 DATA RECORD'-'.:, F_)EPT G R C E: L F C N L N C N L N P H i R A T A ',,"' G ,...m .4..~ .-%. 23 lO0 24 ,5.':" 0 _ 24, ,~:05 9355 000 -' -" -'"=' :'.-': 00 , 0 .-', 0 ,.-', 4 .:,, 4 00 .?, 67, '-2i i ~8 i , 065 2~ , OS~: 9255 '9~ 55 n O0 '"'"3 00 0 58 00 n 04 ¢, m.~ 2 7 ia. n 394 3 n n '~. '.' i. . . ~ . . ~ . . ,400 , O~ 0 56~ ,400 5:.:.:0,900 i8 760 1 , 035 20,205 9 055, 000 99 700 ::'5 23 O 1 , 199 26,650 8955, 000 ,080 .'387,7 00 .368,908 25 ~5 0 25,518 TRAILER RECORDS Maximum length: i024 File t,.:.:pe: i._O Next ¢ile: EOF Fil~ nam,~: &GSFO~ ,~)02 HEADER ~la::,'.imu~ length: i024 Fii~ 'typ~-: LO Pt--ex~iou~ ~"iie: I NFORMAT I RECORDS P..ag ~ 1i i"i i'-.i E Ht_-:. 0 N T E i'.l T S U i'..I i T T Y P E C: A T G S i Z E C: 0 D E r.:: H i.,.l i'..i FN C 0 i.j STAT C T R Y SECT ]' 0 i.,.i Fi ['.. H f"l Ij E i< B ED F EG L F'[:, LHF .r_:, t"! F F,;: t..i H LC C SON LLH FL b .: b E i-..i G 'f bJ Z T i-.,i [:, L TLi BL.I I L'. TLAB P:, H T M F.: T M T M c. S H V 'f S F.: M R i'i F F'i F' ii; T H F S :.:.i; F: i',i C: i',i C: '.3 T H C' S ':' ARCO ALASKA [:, S i 4- 24 C H,..¢ PRtj[:,HOE BAY NORTH SLOF'E AL~SK~ LiSA !:19 z : ~ ~ : : , : 1 U M ..................................................... ~o OrlO ....................................... ,"I , 000 .................................................. 42, O00 .................................................. S L K B KB ' "~ ~ FiORTH SL NORTH SLOPE 9547, OOO .................................. ':":' ~ 0 0 O 0 ~ 5 2 9 0 n n O,OOO O, OOO .................................. ':'00 OOO .................... 200, 000 ............................... CRUDE O, 000 0,0 O 0 0,000 Cf, 000 0 0 4 Iii 65 O 0 4 0 A 5 0 ili ,40 6 =' 0 0 2 0 E, 5 0 0 20 65 0 0 2 0 E, 5 0 0 '2 6 ."-; 0 0 :~ 65 0 0 ..,] 65 F T O :3 4. 6 8 F T n . z-.-: .'3 6 ,S FT O ..3 4 68 0 3 2 65 O S 2 65 0 0 2 79 d. 0 2 '"r:.~'- 0 0 iO 65 0 n i 0 65 0 0 2 O 6,5 0 0 2 0 65 0 ri 2 0 65 0 ~] ;:'.! 0 6 .=5 F T 0 :3 4 68 F T 0 .3 4- 6 :-3 F 7' 0 7.4 4 6 9 F T 0 3 4 ': H R 0 '2 "~ 6 8 H R 0 4 4 68 i} E G F' 0 i 4 6 8 D E G F O t 4. sS E: 0 2 20 65 O 2 ':' 0 6 ~ ., 1;;. , %.. C P O ,-~.":' 4 6.8 0 t't i"1 l'i 0 ~,'" 4 68 0 H H i'i 0 2 4 E, 8 D rS: ~'.'; F 0 2 4 68 O. '2 i 2 6 5 0 H kt i'd 0 2 ,':~ 6 8 D E 6 F 0 ~'" 4 E, F::_ 0 2 t ":',. 6 ..F; C: 0 H M E N T R E C: 0 m D .-_~ :.~:+: This LIS tape was ,.,;~-~i'~..i:.~r, b,.:., ~:.~.' All curve and tool mnemoni,zs used .are th,--,se which most closel,.:., m.atch :'~:+: ,.~:.~.~ Gc_:arhart. ,-urv,=_: and tooi mr, emor, i,-s :-t-: :-I.: :-t-: :'b :'i': .'st.: :..1.: ."F: :'l-~ :-I': :i-: H-; ;4.: :.I': :'l": -"t': :'1-: :'i-: :-I-: :'l'~ :.l.: :-I': :-l': ."t': :'t.; :.l.: :'l': GEARHART TO SCHLUMBERGER M N E H S E R '¢ I C: E Li N i T i:l N E f::, F. P T l'-I F. E E T C, E P T L-: f',l S S i M L': P ,% S A f-I [:, N F' H i G R i M L': F' G A P i G R C C L 1 H C: P H V C C L. F'C i,I F; i M C: P C P.:~'-': F C. N L N L-: ~'.1S i M C: P C F' S N C: N L. F..: A T i C 0 H F' U T E C, R A T SERV I CE UNIT FT PU GAPI HV CPS CPS DelTA F¢'IF.':MC~T '.:_;F:'EC Z F l C:~T I ON=, ENTRY 0 T ,?. r m i r', .-~ t,:) r. ,:: n ,-~ m o r. e ~ n t r i e s ::, TYPE._.c'~ZE '-' 0 £:, E O i 6 6 t3 DATA FORMAT SER',/ICE SERVICE API APi APi APl FiLE fliqEM Z E:, ORE)ER ~ UNiT LOG TYPE CLASS MOD ~ DEF'T 281 785 FT 0 0 0 0 0 NF'H ~ ,.'--':q,. i 7:-=;6 PU 0 68 3 0 i GR 2,_°, i 786 ~]~P '~ 0 3 i 0 0 C. CL 28i786 MY 0 0 0 0 i FC:HL .~oi 7c:£, CPS NC:i'.iL. 28i 7,o_,6 CPS O F,: A T 281 786 · :, P E C: I F ! F:A_ T 1 0 H ._,':' P R C: ~ '-'.:,iZE i_YL SMF'L PF,:OL:bU::; i ND i CATORS DEF'T NF'HI G R [:,A C C L TA R E C: 0 R [:, S F C N L NCNL RAT 1:=; ;26,91 0 0 0 0 0 fl, O 00 '.'"45, 1 00 oq.-- 9FIFI · -' . 1/ _ 9 44 t , 0 00 2.3 I 00 '2 70, I 00 .-']27 2 O0 I °I I .- 93,4 t , 0 00 "~ 0 A F-:. 0 '-'0.-" 800 , ";94,408 421 000 i 067 924 1 , 0 00 9 i 4 i , 000 2i , 660 25,350 4i 25 600 600 ,06 0 , 05 0 400 454,900 442 524 500 400 i i53 62 .300 ,090 815,800 769 600 943 FiLE TRAILER F~la name: ~.GSFO~ , UO.~ Ma>::imum i~ngth: 10':.~4 TRAILER RECORDS type: LO Ne>'t f'ii~: [)~t~; 16 :'~. E 0 F :e :+: :+: :+: :+:* FiLE HEADER :+:*** :+: :t .~: :,~ :+:: P.: k :~: k :'k .,~ :~ >~: :~ :+: .~..~: :~. ~: :+: :3: :~. File n,:-,.mm: ~GSF01 , I]03 HEADER R E C 0 R [",, "''' V~rzion ~: Fiie. type: i_,0 F'r,~vious ~'ii~: PaD c !7 H N E M C N FN C 0 U N C T R Y SEC T T 0 i.d N Ei.< B E D F EGL Pb L M F' P M F R U N L C C S 0 N L U N F'L. LUL W ~ T N 19 D DL TL. ~ T C: S 'FLAB B H T i"i R T M T i"!R o MVZ S RM RHF H F S T MFSS RMC M C S "F H C: S S I NFORMAT I ON RECORDS C 0 N T E 1'4 T S AR' DS PF..: N0 AL. US O9 iO 42. ~,L 'i , 3 0 '..,Z ::: U N t T FT F'T' -- -- 0 H f'l O i'-,i M M DEGF iD H MM T ":' P E C A T G Si ZE C 0 D E 1::3 C O M M E N T RECORDS This LIS f~ap~ ,.~.~s uri'b't~:n bF' Ge..ar.h.~r't indus'k, rim~ Wir~ziin~ S~rvic:,~s, Ail ,curve and t. ooi mn~moni,zs 'usmd arm thosm which most ,zlos~:lp mat. ch [le:ar.~ar't. curv,~ and tool mr,~smor, i,zs:, :~: :.~ ~ · ~: W< :+~ :~ · :~ :~ :~': :4< >~ · ~: :~ :+: :,~ >~ W~ :+: ~'I': ~'B ~ :~ ~: :4~ :~ ~ :.l': :~: ~ :,~ ~< :~ :'~: :~: :~ :'B :"~ >~ ~ · ~: :~ >~ · ~: >~ ~ :~: · :~ :'~: ~': >I< :'I< >H :~ :~ ~': :~ :~ · :~: · · GEARHART TO SCHLUHBERGER F1NEH SERV ICE UNIT HNEH [:,EP TH FEE T i.":., EP T C H S S 2 H C P ,% 'S A N [:, N P H I N C: N S 2 M C P C P S t'.t C N L GR2 HCP GAP I GR C C: L.~ '~ M C: P H V C C L _ ~ P .~ F C N L F r': i".l S 2 H C P ~.- e RAT2 COHF'UTED RAT SERVICE UNIT FT PU CPS GAPI MV CPS [)A T A E N T I;~'. "t FORMAl' TYPE SIZE ,PEC: i F I C 0 D E 0 i 66., T i 0 N .S ** ENTRY BLOCK LEGEND :,~: :~': .I: :+: ~: :+: :k, :.i,: :+: .'9. :,~ :B :+: .~: :~ .-i'..'k :~ ?;': :,P.. :+: :~': :~ -"1.: :~: .~ -'i,: 4.: TYPE DESCRIPTION DATA F:FjRMAT SPEC: i F'I C:ATI ONe=, ..-,,..-.,., ,I _.E oE~..ViUE i"iNEi'd i D OF:~t}ER ~. APl API APl API FILE UNIT LOG TYPE CLASS MOi":' ~ DEF'T NPH I NCNL GR CCI,.. FCNL R¢tT ,:.":',q,. t '~, o~:: ,_, _, FT 28i 706 PU 2 q I 7':',::: C: P '::' 28'i786 (iAPi 2:8 '~ 7.96f. lV 2:~ 17.o,~ 0 0 0 0 0 0 6,9 3 0 ;-2 0 0 0 0 2 0 3i 0 0 2 0 0 0 0 2 0 0 0 0 2 0 0 0 0 2 P RC ~ SIZE L. VL. SMPL RC 6,.°, 68 68 6,'...3, 6,8 ,5,3.', UU E ,, .. P R .... c. g 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 :2 't DEP '"' N F: H i NCNL GR T A R E C 0 R D...,c' CCL FCNL. RP, T ..... : .~, 00 0 41 ,350 339,600 O, OOO 0 000 243,200 1 ,396 9455 O0 0 24,670 .324,70 O 090 282,900 't 148 9::~55 O00 2i,000 367, 22,500 070 343.400 071 9i55 000 000 22,540 21 , 040 399, 'F 00 577,308 24,,900 62.500 160 130 362.900 531,200 101 i 087 9055 000 464,500 1 i''~ 0 ..... 60 080 393,00.0 1 182 8955 000 25,540 412,200 78,500 O7 0 .353,200 1 167 Fi,t,m r,a~ &.GSFO~ , F~03 TRAILER REPORDC· ',,,'6 r' s i on Fii~i 'typm~ LO ~ ,,~ Ne:xt ¢iI~: E 0 F :.t.: :.,k ~ EOF *** DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSIS Company2 ARCO ALASKA INC, Well DS 14-24 Field PRUDHOE BAY Count~ NORTH SLOPE Stmtm ALASKA Countc~ USA CLIENT FORMAT OATA TAPE LOG I NF ORMA T I ON STANDARD FORMAT ( L, I , S , ) Well No,: ARCO DS;'i4-24 ~4.,.,::,, O0 to 9 .... ,4, on Name: DS 14-24 Fi e 1 d: PRUDHOE_ BAY Date' 14 dULY, 1~8~ Time: tO:O0 AM THU, Pagm: 1 TAPE RECORDS Sm~-vicm nature; &G5FOI Date...: 83/0771 4 HEADER Origin: RECORDS Reel. name: 228625 Page Continuation #: Oi Servi,:,z name_; &G.SF'OJ Pr'eviou:.~ 'tape: [:,at .i.: 83,..' 07/14- c ~mm~_nt_q, Origin: 228625 Continuation #: Oi II ~': EOF ~..~: · FILE HE~DER Fit,~ narD.~.".: &GSFOi, Maximu~ 'l~n~th' 1024 HEADER RECORDS File. type.; LO V~rsi. on ~: Pravious ?il~: MNEM CN WN FN L:U UH 9T~T u't' N Y SECT TOWN RANG EKB EOF EGL PO LMF DHF RUN LCC LUN FL LUL ENGI W ITN TLI BL.i TCS TLA8 8HT H R T i'tT H Scj HV~ S RM HKST HKSS R N C HC~.T INFORMATION C 0 N T E N T S ARCO AL, ASKA DS i 4-'24 PRUDHOE 8AY NORTH SLOPE ALASKA USA ~ OH .. , , 14E, , , 72, 71,000 ~2,000 9L KB KB .... 30 228625 76i i NORTH SLOPE NORTH SL. OPE WA!TE KiHNEL 9586, O 0 9575,0 O 0 8954, O O 0 9570, OOO, 23~5, OOO, 452,00 O, ~98, OOO,, ~98,800, , L i GNOS FLOWL I NE 38, OOO ...... i ,950 ~ eXO , ,, 60,000 HEAS, 2.85 0 ....... 67,000 ...... MEAS, I NC, IsltIIllil I|lll|lIIl IllllIllIIll.lltl ! Il II111111 Illl II IIIllllI Illlllll IIIIllII IlIlIItI IIII IIIlIIII I I I RECORDs UNIT TYPE CATG SiZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 O 2 65 0 0 ~ 65 0 0 3 65 F'T 0 S 4 68 FT 0 3 4 68 FT 0 3 4 68 0 ~ 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 iO 65 0 0 JO 65 0 0 20 65 0 0 20 65 0 0 20' 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF O 1 4 68 DEGF 0 1 4 68 0 2 20 65 0 2 20 65 CF' 0 2 4 68 OHHH O 2 4 68 OHHH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHH 0 2 4 68 DEGF O 2 4 68 0 2 12 65 IIIll, lilt IIImIIIII Page GEA COMMENT RECORDS "[his LIS tap~ wa'.,~ writ't, mn bp G~arh~ct Industric_s Wir~lin~ S~rvic~s, All curv~: and tool mnmmonici: used ar~ thosm which most. closmly match Gearhart cur'vm and tool mnmmoni,zs, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SEEVICE UNIT DEPTH FEET DEPT FT TEN D ! L,.~B.;S MV TENS QIt..SCS MV SP OI~ ~rc. MV SP DILBCS MV GR D IL~'"SCS 6APt GR DILSCS GAPi ILD D I L.,-- 8C.~ OHMM ILO DILSCS OHMM ILM [:, I L,."BCS OHMM iLM DILBCS OHMM LL~ [:, I L,.,' B f':S OHMM LLSU DILBCS OHMf,1 DELT [:, I L,.,'BCS US,--'F DT DILBCS US,.."F AMPS D I L,."BCe MV AMPL DILBCS MV C I LD D i L,.,'B r: S MHHO C ! LD D ILBCS MMHO Page, DATA ENTRY 8L. OCKS ****- E N T R ¥ FORMAT SPECIFICA TYPE SIZE CODE 0 I 66 TIONS Page TYPE f,)ESCR IPT ION 0 T,.~rminator. < no mote mntcims ) D TR FORMRT SPEC I F Il ONS ~-.~:~. DATUN SPECIFICATION 8LOCKS SERVICE SERVICE AP1 APl AP1 APl FILE MHEH ID ORDER ~ UNIT LOG TYPE CLASS HOD # DEPT 228625'FT' 0 0 0 0 0 TEHS DiLSCS 228625 ~V 0 0 0 0 0 SP OiLBCS 2286~5'~V O i 0 0 O 6R DILBCS 228625 GAPI 0 ~i O 0 O iLD DiL. BCS 228625 OHMM 0 i2 46 0 0 ILM DILSCS 228625 OH~M 0 i2 44 0 0 LLSU DIt. SCS 228625 OH~M 0 22 8 0 0 ..... 'l' '- ~' DT DILSr:A 228625 bs,.'h 0 52 .¢2 O O AMPL DILBCS 228625 ~V 0 5S ~ O 0 CILD DiLBCS 228625 MI~HO 0 68 46 0 0 PRC ~ SIZE LVL SMPL RC 4 0 i 68 4 0 i 68 ,4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 . ;,-.ES~ F'R~L. 5 INDICATORS 000000 000000. 000000 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 D E P 'F AMF'i_ SP DA TA RECORDS lED ILM LLod DT Pagm , 000 ,800 8,000 f000.000 0,000 0 000 I .000 I 000 1 ,400 0 000 ,4,'9 0O0 i 4.2,300 .-3,000 i .... r,, 660 t ::F.' 5,800 67 700 7,482 9 550 7 244. 75400 9S79,000 i ;36,5 0 O 82.200 22 500 4,121 4 539 776 85 000 9279.000 i26,000 -1,000 64,7i4 91 ,400 400 15.453 15 031 066 88 700 9:)79,000 131 , 7 O0 -i , 000 34, i i9 69,900 · '3.0 200 29 '~ 09 28 708 2.3 014 95 600 9079,000 iOl ,200 -2,000 ,_,R 0 ,7'24 i 06,900 70 500 12,388 10 568 12 023 90 000 897'9.00 0 96. 000 .S, 000 60,1i7 96,200 112 4.00 16,634 i6 i81 36i 80 400 ~: m .,e. F~.LE TRAILER File name: &.G5FO~ Na×imum l~.ng~.h~ 1 1'~ TR~ILER RECORDS Version .~: File type: LO Next film: Date: Page File name: 8, GSFOi .002 Maximum length: 1024 HEADER RECORDS File type: LO VersionS: Prmviou~ ~ilm: Date: Page 10 M N E M CN WN FN COUN STAT CTRY SEC T T 0 i.,.I N RANG EKB EOF' PD LMF DMF' RUN L. CC SON LUN Fi. LUL ENG! WITN DD DL TLI BLi TCS TLAB BHT HRT MT bi S S MV!S RM RMF MFST MFSS RFiC MCST MCS:-_; ,,, Jh r Eh T..-, H R I,. U A i_ A S K A DS 14-24 PRUDHOE BAY NORTH SLOPE i_ H o K. H US A 09 1 ON, , , i 4E'.... ,~ OOO 7i 000 SL i<8 . . , NORTH ._LOFE NORTH WA ] TE K I MMEL 9586 , 000 ':oro,O00 ',E:95~, 000 9570 ~ 0 '231>~,000, , 452,000, , , ~98,000. , , ~9~,000, . , L I G N 0 S FLOb.iL i NE ..~,:, , 000 ....... i, 950 ....... i: 830 ....... 60,000 ...... MEA8, :Z, 850 ....... 67,000 ...... t,iE~S, INt., i111 iiii INFORMATION RECORDS UNIT TYPE CATG.~,c~IZE i : I : i I i CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2 ~5 0 0 7 65 0 0 3 ~5 FT u 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 JO 65 0 0 10 ~5 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 ~ 4 68 HR 0 2 4 68 HR 0 4 4 ~8 DEGF 0 1 4 ~8 DEGF 0 1 4 ~8 0 2 20 65 0 2 20 ~5 CP 0 2 4 68 OHHH 0 2 4 ~8 OHMM 0 2 4 68 DEGF 0 2 4 68 0 '2 i2 65 OHMH 0 2 4 68 DEGF 0 2 4. 6o~, 0 2 i2 ~5 Pag~ 11 COMMENT RECORDS Thi:~ LIS tapm ,.,~a:s writt.~n by G~arhact Indu~trim~ Wir~linm S~rvic~, All cucv~ and tool mn,smonics us~:d acm thosm which mo~t closely match Gemr-hact cur'v,~: and tool mnmmonic~, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET OEPT FT CNSS~ CDL/'CNS ,"..' SAND NPHI FDCCNL PU CNDO 1 L. uL., ~NS ,. OnL... NPH I FDCCNL PU TEN! bD~.~ Ui'.~S MV TENS FD~;L:NL MV GR I CDL,?CNS ~AP I GR FD~SUNL GAP I XCAI_t P_.D~,." "'~N~.o IN CALl FDCCNL IN YCALi CDL,.'CNS IN CAL~ FDCCNL FC [:.L I .... L. DL,-uN~. CPS FFDL FDCCNL CPS ~CDL ~ CDL/CHS CPS NFDC FDCCNL CPS RHOB t CDL/CNS 6/C3 RHOB FDCCNL DRHO i CDL/CHS G/C~ DRHO FDCCNL G/C3 CNS1 CDL/CN'S N LIME NPHI FDCCNL PU FCNSI CDL/CNS CPS FCNL FDCCNL CPS N C N S i C [:, L ? C N S C P S N C N L F D C C N L C P S Pagm DATA ENTRY T"¢PE DE~uRIPTION 0 Tmrminator ( no morm entries ) FORMAT SPECIFICA TYPE SIZE CODE 0 i 66 T IONS Page DATA FORMA T SPECIFICATIONS SERVICE SERVICE APl APl APl AP'.( FILE t'IFIEM iD ORDER ~ UNIT' LOG TYPE ..L. AS~ MOl} ~. 0 0 0 3 0 1 0 0 0 0 i 0 0 I 0 0 0 0 0 0 1 1 0 1 0 0 1 2 0 0 0 1 0 0 DEPT 228625'FT 0 0 NPHI FDCCHL. 228625 PU 42 68 NPHi F'DCCNL 228625 PU 42 68 TENS F'DCCNL 228625 MM 42 O GR FDCCHL 228625 GAPi 42 31 CALl FDCCHL 228625 IN 4.2 28 CAL2 FDCCNL 228625 IN 42 0 FFDL FDCCNL 228625 CPS 42 O NFDC FDCCNL 228625 CPS 42 0 RHOB FDCCNL 228625 6/03 42 35 DRHO FDCCNL 228625 G?C3 42 ~9 NPHI FDCCNL 228625 PU 42 68 FCNL FDCCNL 228625 CPS 42 O NCHL FDCCHL 228625 CPS 42 0 PRE: ~$ :3IZE LVL..:,MPL RC 4 O ~ 68 4. 0 ~ 68 4 0 ~ 68 4 0~ ~ 68 4, 0 ~ 68 4 0 1 68 4 0 ~ 68 4 O 1 68 4, 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 i 68 PROCES~ IND ICATOi~, 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ,000000 000000 000000 000000 000000 000000 000000 O0000O O00OO0 OOO00O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 O0000O 000000 Page 14 ATA RECORDS DEPT NPHI NPHI TENS GR CALI NFDC RHOB DRHO NPHI FCNL NCNL .~c,~ 000 4,000 '-i,'~'~ , ~e.~ 0 000 0 000 0 000 O,OOO 0,000 0,000 0,000 0,000 0,000 94,8-';., O08 27,520 20,5.3I O, 000 63,700 8,460 606 400 ..7 ~q.-.~ 141 23 52n S24 700 ~21 8On 9384, 000 23,400 16,400 5,00'0 27,200 8,400 64i 600 2 35t ,083 19,400 4,'~'-', , , , t..- 000 ~62 7'00 9'28-.'~, O00 22., 5I 0 15, .511 -3'3,000 34,400 8,460 ,Si O, 000 2,448 ,08.'.~', ~8,51 0 395,400 358,700 "Bi 84. OOO 29,460 22,497 -3, OOO 29,900 8,590 ,S".;' 1... ,300 ':.~..., :353. , 07i ,.,.o.~._, 460 269 ,800 276. ,200 9884,000 24, 150 i 7.150 --3,000 37,200 8,550 613,200 2,4,0'2 , 067 20, i 50 .352,000 322,400 :~...¢U4 000 ii 0.S, 0 4 435 -1 00'0 56 200 563,~.°nO ._,'2 67,.0. , n ~.';'.... 7 ,030 865 ,400 CAL2 FFDL 0 000 O, OOO 8 '200 243,700 8 2i0 8 260 308. 300 8 27O ~46,500 9.180 552,300 8 940 2i2,300 Page. 15 ~** FILE TRAILER *~* Fil~_ name:: ~.~GSF01, O0'~ Maximum l~.ngth; ;024 TR, AILER RECORDS Version Film type: LO Hext 'Pil'~; Datm: Pag~ 16 EOF ***- File name: &GSF0i .003 Maximum l~ngth: 1024 HEADER RECORDS Vets i on ~: Fil~ typ~: LO Previous ¢ile: Page 17 HNEH CN Wi'.i FN COUH S'TAT CTRY SECT TOWN RANG EKD EDF EGL F'[:, LMF DMF RUN LCC SON LUN FL. LUL EHG I WITN DD DL TLi 8Li TC: S TLAB BHT MRT tiT MS S: HV!S RH RHF MFST MF:.~" ..... RHC: MCST bi C S '._-'; INFORMATI'ON RECORDS CONTENTS UNIT ARCO ALASKA DS 14.-24 PRUDHOE BAY NORTH SLOPE ALASKA USA iON, , , i4E, , , 72 7i OOO 42 OOO SL ,,, KB ,,, KB 761 i NORTH SLOPE NORTH SLOPE WAITE KiHMEL 9586,80 O, 9575, O O O, 8954, O O O, 9570, OOO, 2~! 5, 452, OOO,, i 98, OOO.. 198, OOO,, L i GNOS FLOWLINE I NC, IIIIlllllll IIl|l:|l|ll · 38, OOO .............. i ,950 .................................. i ,8~0 ................................. 60,0 n 0 ................................ H E A S ........................... 2,85n ...................... E, 7 , ti. i'1. ii. biERS ................ IIIIlII IlIliII IIlIIll IIIIIII IIIlIII IllIlllllIlllllllIlIll IlIIIllIIIllllllllllll IIIIIIIIlllllllllllIII lllIlIIIIIIll I I I TYPE CATG SI --" E CODE 0 0 40 65 0 0 413 65 0 0 ,40 65 0 0 20 65 O O 20 65 0 O 20 "F, 0 0 2 65 0 0 ~ 65 0 0 ~ 65 FT 0 7, 4 68 FT O ~ 4 68 FT' 0 7, 4 68 0 :~ 2 65 0 7, 2 65 0 7, 2 65 0 0 2 "~: q.. 0 0 2 79 O 0 iO 65 O 0 i O 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 ~ 4 6E: FT 0 7, 4 6S FT 0 ~ 4 68, FT 0 ~ 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 CF' O 2 4 68 OHi'IM 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 O 2 1 '2 65 OHMM O 2 4 68 DEGF O 2 4 68 O 2 12 65 18 COMMENT RECORDS This LIS tape was s.,.,rit, t.~n b.~., G~_arhar~ Indust. ri~_s Wireline $~rvices, All curve and tool mnemonics used arm those which mo~t closml~ match Gmarhar~. curve and tool mnemonics, :~ GEARHART TO SCHLUMBERGER MHEH SERVICE UNIT MNEM SER¥ICE UNIT DEPTH FEET DEFT FT TEN2 D I L ,..'~ B l" ':'....., NV TEHS O I L. B C ·°, ._ MV GR2 DI' ' r: GR ,-,' B ~..S GAPI DILBCS GAPI Page DATA FORMA TYPE T SPECIFICAT SIZE CODE 0 i 66 Pag,~ 2O :+:-~ E N T R Y " f .... 8LO.,k LEGEND TYPE [)ESCR I PT 101'4 0 T~cminatop ( no mor-~ mnt. r':i.,=_,~ ) DATA FORMAT .SPEC 1 F I CAT i ONS ., ._.E~VI.,E SERVICE APl' AP1 APl APl FILE MNEM ID ORDER ~ UNIT LOci TYPE CLASS MOD ~ DEPT 228625 FT 0 0 0 0 0 T E N E; D I I iq. ¢I. o.~ .'~ o .,' .-, =.'. M V 0 0 0 0 2 GR Di' -,c. :>m~.~.~ ', LBJ. .... 2 ~.~AP i 0 7. i 0 0 2 SIZE PRC # LVL SMPL 4. 0 1 4 0 1 4 0 I RC 68 68 68 PROCE.q"' ~ INDiC:ATORS 000000 000000 000000 000000 O0000. O 000000 000000 000000 000000 21 DEPI" TEHS GR DATA RECORDS Page 22 8896 O00 0 000 0 000 8796 000 i 000 4? ~00 8696 000 i 000 50 .'SOO 8596 8,:t. 96 000 000 -1 000 -I 000 54 52 80O 8396 000 1 000 49 000 8296 000 t 000 4:8 900 8196 000 0 000 53 600 8096 000 -2_ 000 66,100 7996 000 0 000 85,300 7896 7796 000 000 -3 000 000 53,100 65,300 7696 000 1 000 92:900 7596 O00 0 000 60,400 7496, 000 0 000 57,900 7S96, 000 -1 000 53.t00 7296,000 o 000 51, ~.'700 7i96, 000 000 4.3,400 DEPT 70~6., , 000 6996 .. 000 6796,000 6696, 0 0 .fl 6596,000 6496,000 6396,000 6296,000 6196 000 6096 000 5996 000 s°96 OOO 5796 000 5696 000 5596 000 5496 OOO 5396 OOO TENS -2, 000 -1 , 000 -2.. OOO -i ,000 -1 ,,000 -2. 000 0,000 1,000 0.000 0 000 1 000 -7 000 -2 000 -2 000 '-2 O00 -5 000 -2 000 i 000 DATA RECORDS 900 36,200 65,700 52 100 44 900 44 800 37 300 38 500 28 400 28 700 41 900 29 500 26 200 34 ?00 19 900 24. ,400 24,500 3,4,,300 Page_ 23 DEPT 5296,000 5196,000 5096,000 4996,000 48 '"" 6 n ~] 0 4796,000 4696,008 4596,000 4496,000 4396,000 4296,000 4196,000 4096,000 3996,000 3896,000 3796,000 ..3696,000 3596,000 TENS -3 -2 '-2 -I GR.. 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 OOO 000 RECORDS Page 25,900 3;,7 20n 42 800 29 000 29 200 45 600 42 700 30 400 35 ?00 18 800 30 900 29 600 100 31 ,600 4.2,200 4.0,300 36,700 ..7,1 ,800 24 DEPT TENS DATA RECORDS Page 34.96 000 1 000 32 600 3S96 000 1 000 35 600 3296 3196 000 000 0 000 0 000 46 300 38 300 3096 000 -1 000 42 000 2996 000 1 000 34 100 2.896 000 1 000 26 600 2796,000 0 000 29 600 2696,000 0 000 21 200 2596,000 0,000 21 900 24.96,000 · -2,000 25 900 File name: &G5FOi . 00.~ Ma:~imum l~ngth: 1024 TRAILER RECORDS Sepvice Version File typm: LO Naxt ~ile: Date: Page 26 ~-m EOF ~*.EOF *** ....... . , . , . . . , : . , , . , ........ , , , , , , , :...} ..il ) ~: 'iii ';::: i?, ,.",=_, :~.: c, 'i ..'~ .:....: ,.- :. ,. :. , ........................................ . "i:.' t ~_i ! 5:: :..!.. /.. =.. , ,. ,. ,.. , , , , .. , . ......... ;--.f ~5 ,-:' '.'- t.i ,-" :5 '."? .5 :i ....... , , . , . ...... b! 0 i:;.': 7 ~,."i :iii i... c', i::' i:::' i...i ~"'i i:;:' "i" .-~ c.::: "' !:., iz ':::'.....-."":: '? 7 0 ~"~ ': ~"~ ,:::, ,.-i ;:.': !5 ~"I I"~ f'I f',: i"} i"I i:::' ",? i::' 7' -':.' :j ..., , . .,. ..... ,:ti. ,:'.i. ':ii' ..~. i:::' C: !"-l i, 'i !".i i:;: !:::! 'T ! LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO A,LASKA~ INC. Well D.S. 14-24 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date 11/18/85' Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN 1 COMP~IsATED NEUTRON PASS 1 CN/MS 60 - 0 .. CN 2 COI~ENSATED NEUTRON PASS 2 " " CN 3 -COMPENSATED NEUTRON PASS 3 " " , , , · . CNAV COMPENSATED NEUTRON 3 PASS AVG. " " GR G~M%iA RAY " - 0 - I00 · , , - , -? :I - · ~d ' i - - ''7' ' ~ . '- . ~ - . , ~ ~ , -..~ ~. ~.:.-'-':,'..-- '~-:. :~'i::...?..'" ::';"' ':."' '-::.- '"/:{- "-'.'..'.' :. ".{}: '"'..'." '"'..:':'..' :.' -: . "'" ". .. '." .'. '.~ .-'. _'7.- ~. "" ..." ~ ~ ~ 0'.'~- .----~:'?7..'~'>~:}~v''::::>:.~",.". :.:.'. '"-:-.. '.'._ - ...: ...'_::. ....... '-: .......... - ....... - ........ ~ '_ . . ;_, . ~ - } f; '-'~ ":: ~: -~ ~ :7, ).~ ~'-~ -- ',~>?'~,...~']a'L' · ~ .'.'. "-:' '..'. '".'. '.'..:' ' ':'"."..--:.' --.: '.".-.' -- - --- : - - ....- ~; . ~ -: - '*'7 :..' ~. · - '-'"'-:'::i::...'.:.. ""-'"'"'" ...... '" ......... '-' '! i ': 1 . ' 'Z '; d 7 4 / , '- : : ;::::: :: : z: '..}':.'.::...::;":. '" ' 'i ",' : ;::- ~ ~ ~:-:; :::::::::::::::::::::::: '" '..: .'~ .::.' .':....;'.. ". '.L.' .. ":. ' ~'~¢¢'~Z~ : :~:;~X :t :~% ~:?~:~.'":'."~ '7.;.t: '......: ."' '.t.':'... ':.-. 't' ':.'.'.': : .' t" f¢ -; ~ ~ '. :; ~ ,,-,¢.z: ~ :~ t ~ :, ~ :~:::~:::::~ ::~ ..~:::: ::. :::::< ........ ::~ ....... .: ..... ~:~ ............ .: .. · : ................. .., ~ ~:f :': ...... ;: ~ :~ :;~::. ::: z}: : :~ :s :::::::::::::::::::::::: :: :::: : ::: ::: ::: ::: :: :::: ::::::::: :::: t::. :::::::::::::::::::::::::::::::::::::: :::: ~ ,' I '~'Y:~ :: ":. "... '~' ... ~ :: ~ q~:;:: ~:¢~ ~: ~ :~ .....;~.~. ~:........~_....::. ~ .... :-:.; .::....... :....~.....:..:...:...4:.........:....{..: .:.......: ......... '2: ~. · ~- ';~ ,.:.. .- ~ ~;;~ ~t.:::..:.~3::~:~..k.;:~y.':::t:::;'.:.:....':>....:::: ...;;'~.......:: ~;::.. ~ ::: ..:~:~: ~: ~ ~ ~ ~'., ~ ~ [ i~C::~::::.:z.¢~.:~{~',~.}~'..'; :.f.o '....:: ...' .'..:.. ... :.:.".-:., "....:. ..~.,.f;:.,..,: ,.~ : :. ...... ~' - 'I ~ 3~ :- :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::: LIS TAPE VERIFICATION LISTING LDWG FORMAT Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/01/06 --- ANCH --- 739629 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/01/06 --- ANCH COMMENT RECORD TYPE 232 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 OPEN HOLE 14-24 500292097000 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 06-JAN-93 L73962-9 KILLINSWORTH K.MORRIS 09 10N 14E 1519 1992 72.00 71.00 42.00 CASING DRILLER'S CASING Page 2 _ BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2532.0 72.00 2ND STRING 12.250 9.625 8974.0 47.00 3RD STRING 8.500 7.000 9584.0 29.00 PRODUCTION STRING 8.500 4.500 8706.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BHC PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH TMD EQUIVALENT UNSHIFTED DEPTH 8898.5 8957.0 9009.0 9017.0 9049.5 9061.0 9086.5 9150.5 9202.0 9248.0 9311.0 9350.0 9390.0 9444.5 $ REMARKS: 8898.5 8957.0 9009.0 9015.0 9047.0 9058.5 9085.5 9150.5 9202.0 9248.0 9311.0 9350.0 9390.0 9444.5 TIED INTO BHCS LOG DATED 29-JUN-83. TUBING VOLUME: 201.27 BBLS. CASING VOLUME TO TOP OF PERFORATIONS: 32.305 BBLS. TOTAL: 233.573 BBLS. $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 93/01/06 --- 1024 --- LO COMMENT RECORD TYPE 232 FILE HEADER Page 3 FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9436.0 8905.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD THIS FILE CONTAINS DATA FOR PASS #1. PUMPING INFORMATION PRIOR TO PASS #1: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 87 BBLS. TOTAL: 531 BBLS. PUMPING INFORMATION DURING PASS #1: CRUDE: 40 BBLS. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F _ 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# DEPT F 00000000 0 SIZE #SAMP REPR. 4 1 68 Page 4 SGFN TMD 739629 CU 00000000 0 4 1 68 SGFF TMD 739629 CU 00000000 0 4 1 68 SGBH TMD 739629 CU 00000000 0 4 1 68 NSBF TM/) 739629 CPS 00000000 0 4 1 68 FSBF TMD 739629 CPS 00000000 0 4 i 68 NTMD TMD 739629 CPS 00000000 0 4 1 68 FTMD TMD 739629 CPS 00000000 0 4 1 68 RTMD TMD 739629 00000000 0 4 1 68 CRNF TMD 739629 00000000 0 4 1 68 PHIT TMD 739629 PU 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GRCH TMD 739629 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9436.000 SGFN = 21.061 SGFF = 18.179 SGBH = 70.823 NSBF = 16.623 FSBF = 2.118 NTMD = 15635.370 FTMD = 2663.453 RTMD = 5.870 CRNF = 6.331 PHIT = 35.175 SGFM = 17.724 SIGQ = .986 RSBF = .951 SGIN = 16.682 SIGC = 1.123 GRCH = -1.000 DEPT = . 9236.000 SGFN = 25.072 SGFF = 21.468 SGBH = 68.365 NSBF = 59.414 FSBF = 15.983 NTMD = 10948.280 FTMD = 1975.282 RTMD = 5.543 CRNF = 5.955 PHIT = 29.593 SGFM = 21.981 SIGQ = .976 RSBF = .971 SGIN = 21.253 SIGC = 1.054 GRCH = 180.980 DEPT = 9036.000 SGFN = 21.078 SGFF = 16.660 SGBH = 71.942 NSBF = 83.674 FSBF = 10.016 NTMD = 13907.220 FTMD = 3240.149 RTMD = 4.292 CRNF = 4.805 PHIT = 14.355 SGFM = 16.186 SIGQ = .981 RSBF = 1.180 SGIN = 14.973 SIGC = 1.160 GRCH = 62.004 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 93/01/06 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 Page 5 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 u~ 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9349.5 8899.5 $ #- CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD 8899.5 8900.0 8957.0 8957.5 9015.0 9015.5 9047.0 9047.5 9085.5 9086.0 9150.5 9151.0 9202.0 9202.5 9248.0 9248.5 9309.0 9309.5 9349.5 9350.0 $ REMARKS: THIS FILE CONTAINS DATA FOR PASS #2. PUMPING INFORMATION PRIOR TO PASS #2: M~THANOL: l0 BBLS. SEAWATER: 434 BBL$. CRUDE: 127 BBL$. TOTAL: 571 BBLS. PUMPING INFORMATION DURING PASS #2: CRUDE: 37 BBLS. $ LIS FORMAT DATA Page 6 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR DEPT F 00000000 0 4 1 68 SGFN TMD 739629 CU 00000000 0 4 1 68 SGFF TMD 739629 CU 00000000 0 4 1 68 SGBH TMD 739629 CU 00000000 0 4 1 68 NSBF TMD 739629 CPS 00000000 0 4 1 68 FSBF TMD 739629 CPS 00000000 0 4 1 68 NTMD TMD 739629 CPS 00000000 0 4 1 68 FTMD TMD 739629 CPS 00000000 0 4 1 68 RTMD TMD 739629 00000000 0 4 1 68 CRNF TMD 739629 00000000 0 4 1 68 PHIT TMD 739629 PU 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GRCH TMD 739629 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9349.500 SGFN = 19.973 SGFF = 16.041 SGBH = 72.634 NSBF = 85.591 FSBF = 10.069 NTMD = 15196.210 FTMD = 2791.138 RTMD = 5.444 CRNF = 5.919 PHIT = 29.055 SGFM = 16.577 SIGQ = .988 RSBF = .831 SGIN = 15.397 SIGC = 1.077 GRCH = -1.000 DEPT = 9149.500 SGFN = 21.099 SGFF = 17.906 SGBH = 69.282 NSBF = 100.568 FSBF = 11.314 NTMD = 12340.470 FTMD = 2153.212 RTMD = 5.731 CRNF = 6.164 PHIT = 32.703 SGFM = 17.767 Page 7 SIGQ = .984 RSBF = .766 SGIN = 16.686 SIGC = 1.065 GRCH = 45.180 DEPT = 8949.500 SGFN = 35.459 SGFF = 35.846 SGBH = 72.960 NSBF = 119.812 FSBF = 22.030 NTMD = 9874.230 FTMD = 1487.021 RTMD = 6.640 CRNF = 7.493 PHIT = 54.990 SGFM = 33.125 SIGQ = .988 RSBF = .488 SGIN = 35.335 SIGC = .937 GRCH = 300.246 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 93/01/06 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 93/01/06 --- 1024 --- LO --- COMCEN.002 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9335.0 8899.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... Page 8 BASELINE DEPTH TMD 8899.0 8957.0 9015.0 9047.0 9085.5 9150.5 9202.0 9248.0 9335.0 $ REMARKS: 8900.0 8958.0 9016.0 9048.0 9086.5 9151.5 9203.0 9249.0 9336.0 THIS FILE CONTAINS DATA FOR PASS #3. PUMPING INFORMATION PRIOR TO PASS #3: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 164 BBLS. TOTAL: 608 BBLS. PUMPING INFORMATION DURING PASS #3: CRUDE: 36 BBLS. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 68 4 1 66 1 5 i 66 1 8 4 73 60 9 4 65 .lin 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F SGFN TMD 739629 SGFF TMD 739629 SGBH TMD 739629 NSBF TMD 739629 FSBF TMD 739629 NTMD TMD 739629 FTMD TMD 739629 RTMD TMD 739629 CRNF TMD 739629 cu CU CU CPS CPS CPS CPS API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 Page 9 PHIT TMD 739629 PU 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GRCH TMD 739629 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9335.000 SGFN = 18.555 SGFF = 15.506 SGBH = 72.203 NSBF = 106.584 FSBF = 13.617 NTMD = 16005.970 FTMD = 3055.781 RTMD = 5.238 CRNF = 5.706 PHIT = 26.008 SGFM = 15.089 SIGQ = .985 RSBF = .915 SGIN = 13.784 SIGC = 1.095 GRCH = -1.000 DEPT = 9135.000 SGFN = 20.624 SGFF = 16.771 SGBH = 70.258 NSBF = 113.120 FSBF = 12.521 NTMD = 19618.620 FTMD = 3897.155 RTMD = 5.034 CRNF = 5.477 PHIT = 22.758 SGFM = 17.200 SIGQ = .988 RSBF = .461 SGIN = 15.158 SIGC = 1.135 GRCH = 44.931 DEPT = 8935.000 SGFN = 35.965 SGFF = 34.835 SGBH = 88.802 NSBF = 136.606 FSBF = 30.889 NTMD = 9035.809 FTMD = 1248.455 RTMD = 7.238 CRNF = 8.781 PHIT = 80.890 SGFM = 33.671 SIGQ = .990 RSBF = .479 SGIN = 31.588 SIGC = 1.066 GRCH = 477.661 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 --- 93/01/06 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 93/01/06 --- 1024 --- LO --- COMCEN.003 Page 10 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9334.0 8898.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 BASELINE DEPTH TMD EQUIVALENT UNSHIFTED DEPTH THIS FILE CONTAINS DATA FOR PASS #4. NO PASS TO PASS DEPTH SHIFTS WERE REQUIRED. PUMPING INFORMATION PRIOR TO PASS #4: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 200 BBLS. TOTAL: 644 BBLS. PUMPING INFORMATION DURING PASS #4: CRUDE: 8 BBLS. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 15 1 66 68 Page 11 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 739629 CU 00000000 0 4 i 68 SGFF TMD 739629 CU 00000000 0 4 1 68 SGBH TMD 739629 CU 00000000 0 4 1 68 NSBF TMD 739629 CPS 00000000 0 4 1 68 FSBF TMD 739629 CPS 00000000 0 4 1 68 NTMD TM/) 739629 CPS 00000000 0 4 1 68 FTMD TM/) 739629 CPS 00000000 0 4 1 68 RTMD TMD 739629 00000000 0 4 1 68 CRNF TMD 739629 00000000 0 4 1 68 PHIT TMD 739629 PU 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GRCH TM/) 739629 GAPI 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9334.000 SGFN = 18.841 SGFF = 16.348 SGBH = 71.046 NSBF = 110.329 FSBF = 15.112 NTMD = 15653.730 FTMD = 2976.098 RTMD = 5.260 CRNF = 5.710 PHIT = 26.064 SGFM = 15.389 SIGQ = .984 RSBF = .911 SGIN = 14.109 SIGC = 1.091 GRCH = -1.000 DEPT = 9134.000 SGFN = 20.136 SGFF = 17.058 SGBH = 66.612 NSBF = 117.620 FSBF = 14.191 NTMD = 21406.790 FTMD = 4396.109 RTMD = 4.869 CRNF = 5.259 PHIT = 19.878 SGFM = 16.647 SIGQ = .992 RSBF = .367 SGIN = 14.500 SIGC = 1.148 GRCH = 46.503 DEPT = 8934.000 SGFN = 36.248 SGFF = 36.312 SGBH = 88.664 NSBF = 139.507 FSBF = 31.542 NTMD = -8556.266 FTMD = 1147.122 RTMD = 7.459 CRNF = 9.186 PHIT = 89.905 SGFM = 33.976 SIGQ = .990 RSBF = .521 SGIN = 32.011 SIGC = 1.061 GRCH = 482.417 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 004 --- 93/01/06 Page 12 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 1024 --- LO --- COMCEN.005 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 --- 93/01/06 --- 1024 --- LO --- COMCEN.004 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9334.0 8899.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD THIS FILE CONTAINS DATA FOR PASS #5. NO PASS TO PASS DEPTH SHIFTS WERE REQUIRED. PUMPING INFORMATION PRIOR TO PASS #5: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 208 BBLS. TOTAL: 652 BBLS. PUMPING INFORMATION DURING PASS #5: CRUDE: 16 BBLS. $ LIS FORMAT DATA ****************************************************************************** Page 13 DATUM FORMAT SPECIFICATION RECORD TYPE ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 I 66 0 3 2 79 68 4 1 66 5 1 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# DEPT F 00000000 0 SGFN TMD 739629 CU 00000000 0 SGFF TMD 739629 CU 00000000 0 SGBH TMD 739629 CU 00000000 0 NSBF TMD 739629 CPS 00000000 0 FSBF TMD 739629 CPS 00000000 0 NTMD TMD 739629 CPS 00000000 0 FTMD TMD 739629 CPS 00000000 0 RTMD TMD 739629 00000000 0 CRNF TMD 739629 00000000 0 PHIT TMD 739629 PU 00000000 0 SGFM TMD 739629 CU 00000000 0 SIGQ TMD 739629 00000000 0 RSBF TMD 739629 00000000 0 SGIN TMD 739629 CU 00000000 0 SIGC TMD 739629 00000000 0 GRCH TMD 739629 GAPI 00000000 0 64 SIZE 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 DATA RECORD TYPE 0 #SAMP 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 REPR. 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 DEPT = 9334.000 SGFN = 19.239 SGFF = SGBH = 73.381 NSBF = 89.274 FSBF = NTMD = 15436.400 FTMD = 2936.342 RTMD = CRNF = 5.743 PHIT = 26.528 SGFM = SIGQ = .987 RSBF = .900 SGIN = $IGC = 1.085 GRCH = -1.000 15.471 13.239 5.257 15.806 14.561 DEPT = 9134.000 SGFN = 19.510 SGFF = SGBH = 66.683 NSBF = 97.755 FSBF = NTMD = 20342.960 FTMD = 4003.526 RTMD = CRNF = 5.467 PHIT = 22.629 SGFM = SIGQ = .983 RSBF = .454 SGIN = SIGC = 1.163 GRCH = 52.010 16.602 11.783 5.081 16.081 13.825 Page 14 DEPT = 8934.000 SGFN = 36.029 SGFF = 35.450 SGBH = 81.978 NSBF = 123.501 FSBF = 27.886 NTMD = 7871.992 FTMD = 1030.983 RTMD = 7.635 CRNF = 9.401 PHIT = 94.856 SGFM = 33.740 SIGQ = .992 RSBF = .585 SGIN = 35.343 SIGC = .955 GRCH = 475.405 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 93/01/06 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --- 93/01/06 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS TMD LIS FORMAT DATA 01,02,03,04,05 Page 15 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN PNAV 739629 CU 00000000 0 4 1 68 SGFF PNAV 739629 CU 00000000 0 4 1 68 SGBH PNAV 739629 CU 00000000 0 4 1 68 NSBF PNAV 739629 CPS 00000000 0 4 i 68 FSBF PNAV 739629 CPS 00000000 0 4 1 68 NTMD PNAV 739629 CPS 00000000 0 4 1 68 FTMD PNAV 739629 CPS 00000000 0 4 1 68 RTMD PNAV 739629 00000000 0 4 1 68 CRNF PNAV 739629 00000000 0 4 i 68 PHIT PNAV 739629 PU 00000000 0 4 1 68 SGFM PNAV 739629 CU 00000000 0 4 1 68 SIGQ PNAV 739629 00000000 0 4 1 68 RSBF PNAV 739629 00000000 0 4 1 68 SGIN PNAV 739629 CU 00000000 0 4 1 68 SICG PNAV 739629 00000000 0 4 1 68 GRCH PNAV 739629 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9334.000 SGFN = 18.845 S~FF = 15.802 SGBH = 72.224 NSBF = 42.924 FSBF = 4.927 NTMD = 15855.820 FTMD = 3028.331 RTMD = 5.236 CRNF = 5.704 PHIT = 25.985 SGFM = 15.393 SIC-Q = .985 RSBF = .925 SGIN = 14.114 SICG = 1.110 GRCH = 19.996 DEPT = 9134.000 SGFN = 19.621 SGFF = 16.292 SGBH = 68.639 NSBF = 67.152 FSBF = 6.651 NTMD = 19061.890 FTMD = 3804.133 RTMD = 5.017 CRNF = 5.434 PHIT = 22.233 SGFM = 16.176 SIGQ = .987 RSBF = .532 SGIN = 14.367 Page 16 SICG = 1.143 GRCH = 19.261 DEPT = 8934.000 SGFN = 37.832 SGFF = 36.928 SGBH = 87.630 NSBF = 95.054 FSBF = 23.527 NTMD = 7882.859 FTMD = 1038.161 RTMD = 7.647 CRNF = 9.550 PHIT = 98.870 SGFM = 35.689 SIGQ = .989 RSBF = .555 SGIN = 34.433 SICG = 1.039 GRCH = 415.517 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 tt~ 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 t~ 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9444.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): 8905.5 09-DEC-91 DLS 4.01 2125 09-DEC-91 9586.0 9450.0 Page 17 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 8900.0 9350.0 900.0 NO TOOL NUMBER GR GAMMA RAY TMD THERMAL MULTIGATE $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9584.0 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/CRUDE 0.0 1.215 0.570 86.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9250.0 BASE NORMALIZING WINDOW (FT): 9280.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS DATA FOR PASS #1. PUMPING INFORMATION PRIOR TO PASS #1: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 87 BBLS. TOTAL: 531 BBLS. PUMPING INFORMATION DURING PASS #1: CRUDE: 40 BBLS. $ LIS FORMAT DATA Page 18 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 80 4 I 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 739629 CU 00000000 0 4 1 68 SGFF TMD 739629 CU 00000000 0 4 1 68 SGBH TMD 739629 CU 00000000 0 4 1 68 NSBF TMD 739629 CNTS 00000000 0 4 1 68 FSBF TMD 739629 CNTS 00000000 0 4 1 68 NTMD TMD 739629 CNTS 00000000 0 4 1 68 FTMD TMD 739629 CNTS 00000000 0 4 1 68 RTMD TMD 739629 00000000 0 4 1 68 CRNF TMD 739629 00000000 0 4 1 68 PHIT TMD 739629 DECI 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 G4ER TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 ABTN TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GR TMD 739629 GAPI 00000000 0 4 1 68 CCL TMD 739629 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9444.500 SGFN = 20.185 $GFF = 16.840 SGBH = 62.987 NSBF = 4.753 FSBF = 1.560 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.080 PHIT = .001 SGFM = 19.043 SIGQ = .982 G4ER = .004 RSBF = .850 ABTN = 9956.285 SGIN = 18.252 SIGC = 1.097 GR = -1.000 CCL = 599.000 Page 19 DEPT = 9344.500 SGFN = 18.998 SGFF = 15.831 SGBH = 71.271 NSBF = 40.772 FSBF = 4.466 NTMD = 16047.480 FTMD = 2990.727 RTMD = 5.366 CRNF = 5.819 PHIT = .276 SGFM = 15.554 SIGQ = .986 G4ER = .006 RSBF = .885 ABTN = 30299.180 SGIN = 14.288 SIGC = 1.178 GR = 22.798 CCL = 10.502 DEPT = 9244.500 SGFN = 21.790 SGFF = 19.030 SGBH = 72.669 NSBF = 55.317 FSBF = 6.571 NTMD = 14499.200 FTMD = 2570.775 RTMD = 5.640 CRNF = 6.118 PHIT = .320 SGFM = 18.495 SIGQ = .983 G4ER = .011 RSBF = .819 ABTN = 27016.550 SGIN = 17.476 SIGC = 1.107 GR = 27.877 CCL = 10.879 DEPT = 9144.500 SGFN = 21.525 SGFF = 17.966 SGBH = 73.009 NSBF = 67.270 FSBF = 8.002 NTMD = 14986.410 FTMD = 2685.179 RTMD = 5.581 CRNF = 6.063 PHIT = .312 SGFM = 18.215 SIGQ = .987 G4ER = .003 RSBF = .732 ABTN = 25977.320 SGIN = 17.173 SIGC = 1.113 GR = 34.341 CCL = 11.074 DEPT = 9044.500 SGFN = 21.871 SGFF = 18.668 SGBH = 74.193 NSBF = 81.800 FSBF = 11.486 NTMD = 13417.480 FTMD = 2755.471 RTMD = 4.869 CRNF = 5.380 PHIT = .216 SGFM = 18.512 SIGQ = .980 G4ER = .017 RSBF = 1.135 ABTN = 34487.580 SGIN = 17.494 SIGC = 1.107 GR = 71.703 CCL = 11.127 DEPT = 8944.500 SGFN = 44.578 SGFF = 43.984 SGBH = 86.456 NSBF = 92.698 FSBF = 19.944 NTMD = 5316.766 FTMD = 691.249 RTMD = 7.692 CRNF = 9.592 PHIT = .995 SGFM = 42.987 SIGQ = .972 G4ER = .025 RSBF = .922 ABTN = 22171.680 SGIN = 42.345 SIGC = .957 GR = 348.425 CCL = 10.644 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 93/01/06 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** FILE HEADER RECORD TYPE 128 Page 20 FILE NAME SERVICE SUB LEVEL NAM~ VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 ~ 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.007 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD LOG HEADER DATA 9360.0 8900.0 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 09-DEC-91 DLS 4.01 2214 09-DEC-91 9586.0 9450.0 8900.0 9350.0 900.0 NO TOOL NUMBER GR GAMMA RAY TMD THERMAL MULTIGATE $ 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): 106312 106312 8.500 9584.0 SEAWATER/CRUDE 0.0 Page 21 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): 1.215 0.570 86.0 THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9250.0 BASE NORMALIZING WINDOW (FT): 9280.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 THIS FILE CONTAINS DATA FOR PASS #2. PUMPING INFORMATION PRIOR TO PASS #2: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 127 BBLS. TOTAL: 571 BBLS. PUMPING INFORMATION DURING PASS #2: CRUDE: 37 BBLS. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 i 66 0 2 i 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. Page 22 DEPT F 00000000 0 4 i 68 SGFN TMD 739629 CU 00000000 0 4 i 68 SGFF TM/) 739629 CU 00000000 0 4 i 68 SGBH TM/) 739629 CU 00000000 0 4 1 68 NSBF TMD 739629 CNTS 00000000 0 4 1 68 FSBF TMD 739629 CNTS 00000000 0 4 1 68 NTMD TMD 739629 CNTS 00000000 0 4 I 68 FTMD TMD 739629 CNTS 00000000 0 4 1 68 RTMD TMD 739629 00000000 0 4 I 68 CRNF TMD 739629 00000000 0 4 I 68 PHIT TMD 739629 DECI 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 1 68 SIGQ TMD 739629 00000000 0 4 1 68 G4ER TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 ABTN TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GR TMD 739629 GAPI 00000000 0 4 1 68 CCL TMD 739629 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9360.000 SGFN = 41.379 SGFF = 43.318 SGBH = 82.400 NSBF = 95.556 FSBF = 24.816 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.811 PHIT = -999.000 SGFM = 39.656 SIGQ = .969 G4ER = -.007 RSBF = .876 ABTN = 13625.550 SGIN = 41.046 SIGC = .966 GR = -1.000 CCL = 599.000 DEPT = 9260.000 SGFN = 21.990 SGFF = 18.764 SGBH = 74.775 NSBF = 94.931 FSBF = 9.385 NTMD = 13941.100 FTMD = 2471.846 RTMD = 5.640 CRNF = 6.149 PHIT = .325 SGFM = 18.707 SIGQ = .988 G4ER = .006 RSBF = .804 ABTN = 25997.360 SGIN = 17.705 SIGC = 1.057 GR = 50.455 CCL = 10.882 DEPT = 9160.000 SGFN = 20.560 SGFF = 17.995 SGBH = 66.747 NSBF = 96.478 FSBF = 10.474 NTMD = 16269.220 FTMD = 3022.873 RTMD = 5.382 CRNF = 5.768 PHIT = .269 SGFM = 17.196 SIGQ = .983 G4ER = .016 RSBF = .769 ABTN = 26672.680 SGIN = 16.067 SIGC = 1.070 GR = 41.460 CCL = 10.300 DEPT = 9060.000 SGFN = 24.864 SGFF = 20.581 SGBH = 73.507 NSBF = 109.870 FSBF = 20.774 NTMD = 14282.800 FTMD = 3030.854 RTMD = 4.712 CRNF = 5.221 PHIT = .195 SGFM = 21.183 SIGQ = .981 G4ER = .013 RSBF = .836 ABTN = 27749.930 SGIN = 20.388 SIGC = 1.039 Page 23 GR = 189.563 CCL = 10.316 DEPT = 8960.000 SGFN = 26.145 SGFF = 22.493 SGBH = 72.846 NSBF = 119.284 FSBF = 21.228 NTMD = 13971.290 FTMD = 2554.863 RTMD = 5.469 CRNF = 5.946 PHIT = .294 SGFM = 23.125 SIGQ = .981 G4ER = .008 RSBF = .765 ABTN = 25984.450 SGIN = 22.212 SIGC = 1.041 GR = 278.055 CCL = 11.800 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 --- 93/01/06 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 --- 93/01/06 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files~ raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9345.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): 8900.0 09-DEC-91 DLS 4.01 2251 09-DEC-91 9586.0 Page 24 TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9450.0 8900.0 9350.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY TMD THERMAL MULT IGATE $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9584.0 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/CRUDE 0.0 1.215 0.570 86.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9250.0 BASE NORMALIZING WINDOW (FT): 9280.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 THIS FILE CONTAINS DATA FOR PASS #3. PUMPING INFORMATION PRIOR TO PASS #3: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 164 BBLS. TOTAL: 608 BBLS. PUMPING INFORMATION DURING PASS #3: CRUDE: 36 BBLS. $ Page 25 LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY I I 66 0 2 i 66 0 3 2 79 80 4 I 66 1 5 1 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 1 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F SGFN TMD 739629 CU SGFF TMD 739629 CU SGBH TMD 739629 CU NSBF TMD 739629 CNTS FSBF TM/) 739629 CNTS NTMD TMD 739629 CNTS FTMD TMD 739629 CNTS RTMD TMD 739629 CRNF TMD 739629 PHIT TMD 739629 DECI SGFM TMD 739629 CU SIGQ TMD 739629 G4ER TMD 739629 RSBF TMD 739629 ABTN TM/) 739629 ~ SGIN TMD 739629 CU SIGC TMD 739629 GR TMD 739629 GAPI CCL TMD 739629 MV API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9345.000 SGFN = 37.253 SGFF = 39.047 SGBH = 90.071 NSBF = 129.442 FSBF = 43.367 NTMD = .000 FTMD = - .000 RTMD = .000 CRNF = 2.342 PHIT = -999.000 SGFM = 35.061 SIGQ = 1.001 G4ER = -.007 RSBF = .286 ABTN = 7147.820 SGIN = 34.954 SIGC = 1.003 GR = -1.000 CCL = 599.000 Page 26 DEPT = 9245.000 SGFN = 20.793 SGFF = 17.975 SGBH = 70.295 NSBF = 107.159 FSBF = 12.505 NTMD = 14230.640 FTMD = 2535.343 RTMD = 5.613 CRNF = 6.056 PHIT = .311 SGFM = 17.442 SIGQ = .984 G4ER = .010 RSBF = .777 ABTN = 24795.450 SGIN = 16.334 SIGC = 1.068 GR = 57.162 CCL = 10.312 DEPT = 9145.000 SGFN = 21.082 SGFF = 18.502 SGBH = 65.548 NSBF = 112.921 FSBF = 13.015 NTMD = 18241.390 FTMD = 3372.722 RTMD = 5.409 CRNF = 5.777 PHIT = .269 SGFM = 17.748 SIGQ = .981 G4ER = .023 RSBF = .492 ABTN = 21279.000 SGIN = 15.810 $IGC = 1.123 GR = 56.146 CCL = 10.677 DEPT = 9045.000 SGFN = 23.249 SGFF = 19.409 SGBH = 77.675 NSBF = 119.461 FSBF = 16.748 NTMD = 19102.130 FTMD = 4109.426 RTMD = 4.648 CRNF = 5.230 PHIT = .195 SGFM = 19.565 SIGQ = .989 G4ER = .014 RSBF = .526 ABTN = 25689.060 SGIN = 17.974 SIGC = 1.089 GR = 91.958 CCL = 10.458 DEPT = 8945.000 SGFN = 35.693 SGFF = 35.223 SGBH = 88.954 NSBF = 133.541 FSBF = 28.202 NTMD = 9013.098 FTMD = 1249.681 RTMD = 7.212 CRNF = 8.739 PHIT = .800 SGFM = 33.382 SIGQ = .993 G4ER = -.002 RSBF = .505 ABTN = 17455.570 SGIN = 31.183 SIGC = 1.071 GR = 410.431 CCL = 10.137 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 tgm 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 --- 93/01/06 --- 1024 --- LO --- COMCEN.009 Page 27 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9342.0 $ LOG HEADER DATA 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): 8898.5 09-DEC-91 DLS 4.01 2328 09-DEC-91 9586.0 9450.0 8900.0 9350.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY TMD THERMAL MULTIGATE $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9584.0 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/CRUDE 0.0 1.215 0.570 86.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: THERMAL SANDSTONE Page 28 MATRIX DENSITY: HOLE CORRECTION (IN): 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9250.0 BASE NORMALIZING WINDOW (FT): 9280.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS DATA FOR PASS #4. PUMPING INFORMATION PRIOR TO PASS ~4: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 200 BBLS. TOTAL: 644 BBLS. PUMPING INFORMATION DURING PASS #4: CRUDE: 8 BBLS. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 I 66 0 2 i 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS_ API CODE DEPT F 00000000 SGFN TM/) 739629 CU 00000000 SGFF TMD 739629 CU 00000000 SGBH TMD 739629 CU 00000000 NSBF TMD 739629 CNTS 00000000 FSBF TMD 739629 CNTS 00000000 NTMD TMD 739629 CNTS 00000000 FTMD TMD 739629 CNTS 00000000 FILE~ 0 0 0 0 0 0 0 0 SIZE 4 4 4 4 4 4 4 4 #SAMP 1 1 1 1 1 1 1 1 REPR · 68 68 68 68 68 68 68 68 Page 29 RTMD TMD 739629 00000000 0 4 1 68 CRNF TMD 739629 00000000 0 4 1 68 PHIT TMD 739629 DECI 00000000 0 4 1 68 SGFM TMD 739629 CU 00000000 0 4 i 68 SIGQ TMD 739629 00000000 0 4 i 68 G4ER TMD 739629 00000000 0 4 1 68 RSBF TMD 739629 00000000 0 4 1 68 ABTN TMD 739629 00000000 0 4 1 68 SGIN TMD 739629 CU 00000000 0 4 1 68 SIGC TMD 739629 00000000 0 4 1 68 GR TMD 739629 GAPI 00000000 0 4 1 68 CCL TMD 739629 MV 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9342.000 SGFN = 35.905 SGFF = 37.621 SGBH = 89.739 NSBF = 127.879 FSBF = 28.131 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 2.090 PHIT = -999.000 SGFM = 33.606 SIGQ = .992 G4ER = -.006 RSBF = .488 ABTN = 11201.160 SGIN = 33.480 SIGC = 1.004 GR = -1.000 CCL = 599.000 DEPT = 9242.000 SGFN = 20.843 SGFF = 17.803 SGBH = 66.143 NSBF = 112.236 FSBF = 13.266 NTMD = 14461.170 FTMD = 2578.918 RTMD = 5.607 CRNF = 5.990 PHIT = .301 SGFM = 17.495 SIGQ = .984 G4ER = .000 RSBF = .956 ABTN = 26314.060 SGIN = 16.392 SIGC = 1.067 GR = 61.654 CCL = 10.652 DEPT = 9142.000 SGFN = 20.486 SGFF = 17.424 SGBH = 65.768 NSBF = 113.875 FSBF = 13.541 NTMD = 21448.830 FTMD = 4333.770 RTMD = 4.949 CRNF = 5.323 PHIT = .207 SGFM = 17.099 SIGQ = .991 G4ER = .004 RSBF = .390 ABTN = 19833.080 SGIN = 15.038 SIGC = 1.137 GR = 46.045 CCL = 10.725 DEPT = 9042.000 SGFN = 21.255 SGFF = 16.889 SGBH = 75.489 NSBF = 123.369 FSBF = 15.809 NTMD = 20078.700 FTMD = 4707.770 RTMD = 4.265 CRNF = 4.842 PHIT = .147 SGFM = 16.480 SIGQ = .989 G4ER = .010 RSBF = .573 ABTN = 26509.980 SGIN = 14.300 SIGC = 1.152 GR = 83.915 CCL = 10.871 DEPT = 8942.000 SGFN = 35.807 SGFF = 35.137 SGBH = 83.510 NSBF = 134.059 FSBF = 29.471 NTMD = 8511.410 FTMD = 1184.232 RTMD = 7.187 CRNF = 8.595 PHIT = .769 SGFM = 33.501 SIGQ = .993 G4ER = -.001 RSBF = .574 Page 30 ABTN = 18191.660 SGIN = 34.159 SIGC = .981 GR = 447.722 CCL = 10.894 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.010 --mw 0 --- 93/01/06 --- 1024 --- LO --- COMCEN.011 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 --- 93/01/06 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9342.0 $ LOG HEADER DATA 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 8899.0 09-DEC-91 DLS 4.01 0015 10-DEC-91 9586.0 9450.0 8900.0 9350.0 900.0 NO TOOL NUMBER Page 31 GR GAMMA RAY TMD THERMAL MULTIGATE $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9584.0 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/CRUDE 0.0 1.215 0.570 86.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9250.0 BASE NORMALIZING WINDOW (FT): 9280.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS DATA FOR PASS #5. PUMPING INFORMATION PRIOR TO PASS #5: METHANOL: 10 BBLS. SEAWATER: 434 BBLS. CRUDE: 208 BBLS. TOTAL: 652 BBLS. PUMPING INFORMATION DURING PASS #5: CRUDE: 16 BBLS. . LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY Page 32 1 I 66 2 I 66 3 2 79 4 1 66 5 1 66 8 4 73 9 4 65 11 2 79 12 4 68 14 4 65 15 1 66 16 1 66 0 1 66 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES DEPT SGFN TMD 739629 SGFF TMD 739629 SGBH TMD 739629 NSBF TMD 739629 FSBF TMD 739629 NTMD TMD 739629 FTMD TMD 739629 RTMD TMD 739629 CRNF TMD 739629 PHIT TMD 739629 SGFM TMD' 739629 SIGQ TMD 739629 G4ER TMD 739629 RSBF TMD 739629 ABTN TMD 739629 SGIN TMD 739629 SIGC TMD 739629 GR TMD 739629 CCL TMD 739629 *********************** DATA RECORD 0 0 80 1 1 30 . lIN 12 -999.000 F 68 1 0 UNITS API CODE FILE~ SIZE #SAMP REPR. F 00000000 0 4 1 68 CU 00000000 0 4 1 68 CU 00000000 0 4 1 68 CU 00000000 0 4 1 68 CNTS 00000000 0 4 1 68 CNTS 00000000 0 4 1 68 CNTS 00000000 0 4 1 68 CNTS 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DECI 00000000 0 4 1 68 CU 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 CU 00000000 0 4 1 68 00000000 0 4 1 68 GAPI 00000000 0 4 1 68 MV 00000000 0 4 1 68 ******************************************************* TYPE 0 DEPT = 9342.000 SGBH = 101.996 NTMD = .000 CRNF = 2.442 SIGQ = 1.002 ABTN = 5342.938 GR = -1.000 SGFN = 38.066 SGFF = 37.899 NSBF = 140.662 FSBF = 42.391 FTMD = .000 RTMD = .000 PHIT = -999.000 SGFM = 35.940 G4ER = -.011 RSBF = .200 SGIN = 35.861 SIGC = 1.002 CCL = 599.000 DEPT = 9242.000 SGBH = 70.423 NTMD = 14201.830 CRNF = 6.118 SIGQ = .978 ABTN = 25540.970 GR = 67.482 SGFN = 21.620 SGFF = 18.780 NSBF = 94.541 FSBF = 11.835 FTMD = 2504.183 RTMD = 5.671 PHIT = .320 SGFM = 18.316 G4ER = .010 RSBF = .911 SGIN = 17.281 $IGC = 1.060 CCL = 11.388 Page 33 DEPT = 9142.000 SGFN = 20.606 SGFF = 17.159 SGBH = 71.113 NSBF = 99.638 FSBF = 11.414 NTMD = 19711.820 FTMD = 3871.655 RTMD = 5.091 CRNF = 5.545 PHIT = .237 SGFM = 17.245 SIGQ = .992 G4ER = .004 RSBF = .421 ABTN = 19568.630 SGIN = 15.212 SIGC = 1.134 GR = 51.972 CCL = 11.949 DEPT = 9042.000 SGFN = 20.941 SGFF = 16.566 SGBH = 75.974 NSBF = 105.915 FSBF = 14.939 NTMD = 18644.080 FTMD = 4295.723 RTMD = 4.340 CRNF = 4.919 PHIT = .156 SGFM = 16.384 SIGQ = .986 G4ER = .007 RSBF = .624 ABTN = 26442.390 SGIN = 14.187 SIGC = 1.155 GR = 85.065 CCL = 11.120 DEPT = 8942.000 SGFN = 37.172 SGFF = 35.932 SGBH = 89.658 NSBF = 121.186 FSBF = 26.178 NTMD = 7785.637 FTMD = 1015.328 RTMD = 7.668 CRNF = 9.604 PHIT = .996 SGFM = 34.970 SIGQ = .996 G4ER = .008 RSBF = .562 ABTN = 17047.670 SGIN = 32.527 SIGC = 1.075 GR = 438.464 CCL = 11.574 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.011 --- 93101/06 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 93/01/06 --- ANCH ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME --- COMCEN DATE --- 93/01/06 Page 34 ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- ANCH --- 739629 ****************************************************************************** END OF TAPE ENCOUNTERED Page 35 RECEIVED FEB 1 4 1995 Alaska Oil & Gas Cons. Commission Anchorage , ALASKA COMPUTING CENTER , ****************************** )mm~mmm~mmmmmmmmmmmmmmmmm~ ,------- SCHLUMBERGER = .... ~mee~$emm~meemmmmmmmmmmmmmmmm~ ****************************** COMPANY NAME : ARCO AI,ASKA INC. WELL NAME : DS 14-24 FIELD NAME ~ PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA APl NUMBER : 50-029-20970-00 REFERENCE NO : 94248 ,,IS Wa~e Verification Llst~nc ;cblumberger AlasKa Computinq Center 13-FEB-1995 09145 ***$ REEL HEADER **$~ SERVICE NAME : EDIT DATE : 95/02/13 ORIGIN : FLIC REEL NAME : 94248 CONTINUATION # : PREVIOUS REEL : COMNENT : ARCO ALASKA INC., PRUDHOF BAY, DS 14-24, 500292097000 **** TAPE HEADER S~RVICE NANE : EDIT D~TF : 95/02/~3 O~IGIN : FLIC TAPE NA~E : 94248 CONTINUATION P~EVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 14-24, 500292097000 TAPE HEADER PRUDHOE. BAY CASED HOSE WIRELINE LOGS W~Ll, NAME: A~I NUMBER~ OPERATOR~ LOGGING COMPANY~ ~APE CREATION DATE: 40B NU~BER~ LOGGING ENGINEER OPERATOR WITNE$S~ SURFACE LOCATION SECTION: TONNSHIP~ RANGEI FNL: FWL~ ELEVATION(f'T FROM MSL O) KELLY BUSHING: ,DERRICK FLOOR: ~ROUND LEVEL: # WFbL CASING RECORD ~ST STRING 9ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BlT SIZE (IN) D.$. 14-~4 500292097000 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES IS-FEB-94 94248 BAILEY DAVE REEM 9 14E 151,9 1992 72.00 71.00 42..00 CASING DRILL~'RS CASING F SIZE (IN) DEPTH (FT) WEIGHT (LB/ T) '~'''''''.625 '~974.0'''''''' '''''''"''''''47.00 7.000 9.584,0 29 ~0 s.soo 614.o 4,500 B706.0 12'60 # CURVE SHIFT DATA - ALL PASSES PAGE: ,,IS Tape Yerlficatlon Llstino ;¢hlUm~erger AlasKa ComputimO Cemter BASELINE CURVE FOR LDWG TOOL CODF{ LDWG CURVE CODE: RUN NUMBER{ PASS NUMBER~ DATE LOGGED: LOGGING COMPANY: SHIFTS BCS GR ELINE DEPTH 88,0 29,0 AS 9 939! 9320 9313 928! 9279 9273 9245 9236 92t2 9~66 9t58 9~56 9~5! 9150 9! 9076 9038 9024 902~ 90~ 8988 8984 8955 tO0 CNTD GRCH .mmmm~m 9431,5 939~,0 9321.5 9313,0 928~.0 9273.0 9243,5 9237.5 9214.0 9167,0 9157,5 9157.5 91,51.5 9551,5 9142.5 9119,0 9118,5 9086.5 9086.5 9078.5 9078.5 9039,0 9024,5 9024.5 9009,0 8987,0 8984,5 8955.5 100,0 99.0 13-FEB-1995 09:45 ENT UNSHIFTED DEPTH---------- TME INFORMATION PERTAINING TO'THE OPEN MOI,,E LOG SUCH AS LOGGING DATE. bOGgING COMPANY. PASS NUMBER AND RUN NUMBER WAS NOT PROVIDED WITH THE TAPE SUPPLIED BY THE CLIENT. THE DE~TM CORRECTION SHOWN ABOV~ REFLECT CASED HOLE GR O OPEN HOLE. GR AND CASE[) HOLE NPHI TO OPEN HOLE ~Lh OTHER CNT CURVES WERE CARRIED ~ITH THE NPHi SHIFTS,~ S $ PAGE: ~IS Tape Verification Listing ~chlUmberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT ,001 SERVICE : FhIC VERSION : O01CO1 DAT~ : 95/02/13 MAX AEC SIZE : 1024 FILE TYPE : LO LAST FILE : 13-FEB-1995 0g:45 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 0.5000 DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE CNTD $ START DEPTH 9445,5 STOP DEPTH 8945,0 8948,0 # CURVE SHIFT DATA - PASS TO PASSCMEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUNBER: , . ------'---EOUIVALENT UNSHIFTED BASELINE DEPTH $ REMARKS: THIS FILE CONTAINS PASS, #1 OF THE CNTD. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA.. .$ FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** **.SET TYPE = &4EB TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 ~I$ Tape Yeriflcat~on Listing ;chlumbergerAlasKa Computing Center 13-FEB-1995 09:45 PAGE; ...................mm.mm;mmmm. TYPE REPR CODE AbUE 5 66 6 73 7 65 8 68 0.5 9 65 11 66 21 12 68 13 66 0 14 65 FI 15 66 68 16 66 0 66 0 ....I.............m.....'.'.I' ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 ID ORDER # bOG T DEPT FT 487978 O0 NPH! CNTD PU-S 487978 00 NRAT CNTD 487978 O0 C~AT CNTD 487978 00 NCNT CNTD CPS 487978 00 FCNT CNTD CPS 487978 O0 CFTC CNTD CPS 487978 O0 C~TC CNTD CPS 487978 O0 GRCH CNTD GAPI 487978 O0 TENS CNTD LB 487978 O0 CCh CNTD V 487978 00 GR SCS ,GAPI 487978 O0 mmmmm.~mmm.mmm..mmmmm.mmmmmmmmmmmmmmm..mmmmmmm.~mm~mmm-- AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PRUCE$$ YPE CLASS MOD NUmB SAMP EbEM CODE (HEX) 000 O0 0 I ) 1 4 68 0000000000 000 O0 0 1 1 ! 4 68 0000000000 000 O0 0 I 1. 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 ! 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000'000 000 O0 0 1 ! 1 4 68 0000000000 000 O0 0 .1 ! 1 4 68 0000000000 000 O0 0 .1 ~ ,1 4 68 0000000000 ** DATA ** D~PT 9542.000 NCNT:CNTD -999.250 GRCH..CNTD -999'250 DEPT' 8948'000 NCNT,CNTD 2313,646 GRCH.CNTD 262,250 NPHI:.CNTD -999.250 NRAT'.CNTD -999250 CRAT.CNTD 50 CFTC,CNTD -999:250 CNTC.CNTD FCNT..~NTD -999.2502 . TD ~99'250 GR.BC$ TENS.CNTD -999. CCL,CN 9 NPHI.CNTD 41.257 NRAT,-CNTD 6.636 CRAT.CNTO FCNT'.CNTD 358.452 CFTC,CNTD 356:~88 CNTC..CNTD TENS.CNTD 1335'000 CCL.CNTD 0 O0 GR..SCS -999.250 -999.250 25,200 046 -999.250 END OF DATA -,IS Tape VerIAficatlon Listen ;chlumDerger las~a Comput ng Center 13-FEB-~995 09:45 PAGE: ***~ FILE TRAILER ~ FILE NAME : EDIT ,001 SERVICE : FbIC VFRSION : 001C01 DATE : 95/02/13 MAX R~C SIZE : 1024 FIL~ TYPE : LO bAST FILE : FIL~ NA~E : EDIT ,002 SERVICE : FLIC YER$ION : O01CO~ DAT~ : 95/02/13 MAX REC SIZ~ t ~024 FILE TYPE : LO L.AST FILE : FILE HEADER FILE NUMBER~ 2 EDITED CURVES Depth shifted an~ clipped curves for each pass 'in separate files, PASS NUMBER: 2 DEPTH INC~EMENT~ 0,5000 FIL~ SUMMARY LDWG TOOL CODE START DEPTM STOP DEPTH ~N~)~m~m ~mmmmmmm~m~ ~mm~mmmmmm CN?D 9390,0 Bg48,0 ~t, RVE SHIFT DATA PASS TO P,ASS(~EASU~ED DEPTH) BASELINE CURVE~ FOR SHIFTS LDWG CURVE CODE~ GRCH ~ASELINE: DEPTH 88888 0 392 g3~4 9 8O 9 75 1 9367 9]64 9363 '''''''""'EOUIVASENT UNSHIFTED DEPTH---'~---'- 8888~,0 9375 9372.~0 9367 9364,0 CNTD ~389,0 9381 9 ] 65, O ;chi erger Alaslc Co,,puLing Center 13-FEB-19q5 09:45 9336 5 9332 5 9328 5 9304 5 9303 5 9300 5 9299 5 9296 5 9295,5 9291 9283,5 9279.5 9276.5 9275 5 927! 5 9263 5 9259 5 9256 5 9252 5 9248 5 9236 5 92325 9228 5 9148 5 9144 5 9140 9088 9084 5 90 5' 9068 5 90~4 5 9056 5 9052 5 9044 5 9043 5 9040 5 90395 90.31 9027 9004 5 000:5 996 5 8976 5 897~5 896 5 8964 8960 5 S loo o REMARKS: 9304.0 9300,5 9296,5 9~93,0 9288.5 9284.5 9280.0 9276,0 9271,5 9263.5 9260.0 904' 4 9039 9031 9028 1,00. 5 9337.0 9333.5 9329.0 9305.0 9302.0 9297,0 9277,0 9257.5 9253,5 9249,0 9237 0 9232 9229 9149 9144 9141 9089 9084 9076 9073 9068 9065 9057 0 90 5 9041.0 9005 0 9001 5 8997 0 8977 8972 8968 8964 8961 100 5 0 0 5 0 0 5 5 0 5 0 0 0 0 5 0 5 THIS FILE; CONTAINS PASS #2 OF THE CNTD THE DEPTH CORRECTIONS SHOWN ABOVE REFLEC~ PASS #~ (;RCH TO PAS8 GPCH AND PASS #2 NP~I TO PASS #1 NPH'I, 'ALL OTHER CNTD ,chlumberger Alaska Computing. Center 13-FEB-1995 09145 CURVES WERE CARRIED WITH THE ~PHI SHIFTS, $ bls FORMAT DATA PAGE~ ** ~ATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB TYPE REPR C DE 1 66 0 2 66 0 3 73 44 4 66 ] 5 66 6 73 7 65 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 ~ 66 I .,** SET TYPE NAME SERV UNIT SERVICE AP1 iPI APl AP1 FILE' NUMB NUMB SIZE REPR PRUCESS 'ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) 1 I 4 68 NRAT CNTD 487978 O0 000 O0 0 ~ CRAT CNTD 487~78 O0 0~0 O0 0 2 ll 1 4 68 1 4 68 F~NT CNTD CPS 487978 O0 000 O0 0 2 ! 1 4 68 CFTC CNTD CPS 487978 O0 000 O0 0 2 1 I 4 68 CNTC CNTD CPS 487978 O0 000 O0 0 2 1 I 4 68 GRCH CNTD GAP! 487978 O0 000 O0 0 2 I I 4~ 68 .TKNS ~CNTD bB 487978 O0 000 O0 0 2 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 CCh. CNTD, V 487978 00. 000 O0 0 2 1 I 4 68 ,0000000000 ~m~NN~N~mmm~m~mM~m~mmm~mmmmmmmmm:mmmmmm~m~mmmmm~mmmmmmmmmmmmmmmmm~mmm~mmmm~m :**. DATA ** ,,IS TaPe Verification f, istin~ ;ChlUmberger AlasKa Computing Center 13-FEB-~.g95 09:45 PAGEt DEPT, 9390.000 NPHI.CNTD 24.060 NRAT.CNTD NCNT.CNTD 3740.750 FCNT.CNTD 841.250 CFTC,CNTD GRCH,CNTD -999.250 TENS.CNTD 137~..227 CCL.CNTD 4.33] CRAT.CNTD 824.406 CNTC.CNTD 0.000 4.296 3769.875 ** END OF ~ATA **** FILE TRAILER **** F~LE NAME : EDIT .0o2 SERVICE : FLIC VEESXON : O01CO1 DATE : 95/02/13 ~AX REC SIZE t 1024 FInK TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME ~ EDIT ,003 SERVICE : FbIC VERSION : OO1C01 ATE : 95/02/13 ~X REC SIZE : 102,4 FILE TYPE : LO LAST FILE : FXLE NUMBER: 3 EDITED CURV!$ DePth Sh fted and cliPped curves for each pass in separate files, PASS NURBER 3 0,5000 DEPTH INCREMENT[ # FILE SUMMARY I, DW¢ TOOL CODE START DEPTH STOP DEPTH GRCH 936 0 8948,0 ~URVE:SOIFT'DATA - PASST0 PASSCMEASURED DEPTH) BASELINE CURVE'FOR SHIFTS LDWG CURVE CODE: GRCH 94 . :5 ''"-''=--=EQUIVALENT UNSHIFTED DEPTH--------'- GRCH CNTD Tape verification Listing ;¢hlumberger Alaska Computlno Center 13-FEB-1995 09:45 PAGE: 9 9 9 9 9 9 9 9392,5 9388,5 9384,5 9380 5 9379 5 9376 5 9352 5 9348 5 9344 5 9340 5 9336 5 9332 5 9300 5 9296 5 9288 5 9284 5 9283 5 9279 5 9276 5 9275 5 9272 5 9271 5 9268 5 9267 5 264 5 263 5 259 5 240 5 236 5 224 5 220 5 921~ 5 921 $ 921~ 5 920 5 9207 5 9204 5 9200 5 9188 5 9184 5 9180 5 917:6 5 9172 5 9168 5 9164 5 9160 5 9.156 5 9152 5 9144 5 9143 5 91.40 5 5 9t 13~ 5 ~1.3 5 9380.0 9284.0 9279.5 9275.5 927~.0 9268,0 9263 5 9260:0 9216,0 9~11.5 9208,0 9144.0 9140.5 9136,5 9393 93 9382,5 9377 0 9353 0 9350 0 9345 0 9341 0 9336 5 9333 0 9301.0 9297,5 9289,5 9285.0 9277,0 9272,5 9268.5 9265.0 9241,0 9236.5 9224,5 9221,0 9213,0 9208.5 9204 5 92o~ 0 91,8 0 918 4 5 918:1. 0 9177 0 9172 0 9169 5 91.65 0 9161 0 9156 5 9153 0 9145 0 9140,0 9136,5 91,33.0 ~IS Tape Verification Listing ;chlumberger AlasKa Computing Center 13-FEB-1995 09:45 10 9131,5 9124,5 9120,5 9116.5 9112.5 9100 5 9096 5 9088 5 9084 5 9056 5 9052 5 9044 5 9043 5 9040 5 9039 5 9036 5 9032 5 9028 5 9027 5 9024 5 9023 5 9020 5 9016 5 9008 5 9004 ,5 9003 5 90OO 5 8999 5 8996 5 8995 5 8992 $ 8988 5 8984 5 8976 5 8972 5 '8968 5 .100 0 $ 913~.0 9044,0 9039.5 9027,5 9024,0 9004,0 8999,5 8996,0 100,5 9125.0 9120.5 9117.0 9112.5 9100.5 9097.0 9089.0 9084.5 9056.5 9053.0 9045.0 9040.5 9037,0 9033.0 9028.5 9025.0 9020,5 9017,0 9009,0 9005,5 9001,0 8997,0 8992,5 8988 5 8985 0 8977 0 8973 5 8969 0 lO0 5 THIs,FI[,E CONTAINS PASS #3 OF THE CNTD~! THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT PASS ~ GRCH Ti] PASS #1 GRCH AN'D PASS ~3 NPHI TO PASS ~1 NPHI ALL OTHER CNTD CURVES WErE CARRIED WITH THE NPHI SHI~TS': $ FORMAT DATA ,IS Tape Verification Listing ;chlumberger AlasKa Computin~ Center 13-FEB-~995 09:45 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE REPR CODE VALUE i 66 2 66 0 ] 73 44 4 66 1 5 66 6 73 7 65 11 66 23 12 68 13 66 0 14 65 F~' 15 66 68 16 66 ! 0 66 1 gmo~mmmm~mm#mmm~m~mmmmmmm ** SET TYPE - CHAN ** NAME '$ERV UNIT SERVXCE API AP1 APl AP1 FILE NU~ .NUMB $1ZE REPR PROCESS ~D ORDER # LOG TYPE CLASS HOD NUMB SAMP EbEM CODE (HEX) N~.~ CN~D ~u-s ~aT~ oo ooo ooo ~ ~ ~ ~ ~, NRAT CNTD 4579?8 O0 000 O00 3 ! 1 4 68 c~ c.~ 48v~?$ oo ooo ooo ) ~ ~ ~ 68 ~c.? c.~ cps 4~gvs oo ooo ooo ) ~ ~ ~ 68 c~c c.~cps ~sv~vs oo ooo ooo ) ~ ~ ~ e~ c.~c c.?~ c~s 4sv~vs oo ooo ooo ~ ~ ~ ~ ~s ~.c.c.~~e'~ 48vgv8 oo ooo ooo ~ ~ ~, ~ ~ ~e.s c~o u~ ~.v978 oo ooo ooo ~ ~ ~. ~ ~s 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 CCL CNTD V 487978~ O0 000 00, 0 3 1' 1' 4 68 0000000000 11 ** DATA '** DF_,PT NCNT CNYD GRCH CNTD !~:~'000 NPH!'CNTD 2~.073 N.RAT,CNTD 4:458 Cf ~ C,CNTD 826:?50 ,750 FCNT.CNTD 85 .,6.2.5: 'T' 9991250 TENS.CNTD ~38~.7 73 CCL.CNTD 0.000 RAT'CNTD NTC,CNTD 387 .&bi, 4:2 ,68 ** END OF DATA ,IS Tape Verlftcation Listing ;chlumberger Alaska Computing Center **** FILE TRAILER FILE NAME SFRVICE : FLIC VERSION : O01CO1 DATE : g5/02/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT ,004 SFRVICE t FLIC VERSION : OOlCOl DAT~ ~ ~5/02/13 MAX REC SIZE ~ 1024 FILE TYPE : LO LAST FILE : 13-FEB-1. gg5 09:45 PAGE: 1,2 FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron{ Arithmetic average o~ edited passes for all :~rvesl ithmetic, average Pulsed Ne~tron~ Unaveraged edited Pass 1 Gamma Ray and backround counts, ar of edited static ~aseline passes for all other curves, DEPTH INCREMENT 0,5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNTD 1, ~, REMARKS~ THIS F~LE CONTAINS THE ARITHMETIC AVERAGE OF THE THREE CN~D PASSE$,~ A~L DEPTH CORRECTIONS WERE MADE BEFORE: THE, AVERAGE WAS COMPUTED, ~$ FORMAT DATA ** OATA FORMAT SPECIFICATION RECORD ** SET TYPE,- 64EB ** , TYPE REPR CODE VALUE, 1 66 0 ] 66 0 73 36 4 66 I ;cl~lu~berger Alas~c8 Computing Center 13-FEB-],995 09:45 PAGE: TYPE PR CODE ..m~...mm..qllt..............--.--~--. 5 66 6 7 65 9 65 1! 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 mmm~mmmmmmmmmmmmm~mmmmmmmmmm~! ** SET TYPE - CHAN ** A~E SERV NIT SER , AP1 AP1 . AP1 FILE SIZE REPR 0CE$$ ID ORDER # LOG TYPE CLASS MOD NUMS SAMP ELE~ CODE (HEX) .............,,...........,,-......-..,.-.---......----.----.----------.----.--,-,------ DEPT 487978 000 O0 0 4 1 I 4 68 000 0 0000 NPHI CNAV PU-S 487978 O0 000 O0 0 4 ! 1 4 68 0000000000 NRAT CNAV 487978 O0 000 O0 CRAT CNAV 487978 O0 000 O0 NCNT CNAV CPS 487978 O0 000 O0 FCNT CNAV CPS 487978 O0 000 O0 CFTC CNAV CPS 487978 O0 000 O0 CNTC CNAV CPS 487978 O0 000 O0 0 4 1 0 4 1. 0 4 1 0 4 1 0 4 ! 0 4 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 '4' 68 0000000000 GRCH CNTD GAPI 487978 O0 000 00. 0 4 1 I 4 68 0000000000 .m~m~m~,mN~mmmm~mmmmmmmmmmmmmmmmmmm, mmmmmmmmmmmmmmmmmmmmmmmmmm~mmmm~mmm'mmmmmm'mmm'm'm CH'CNTD ~418 000 999,:250 28.516 END OF DATA NPHI.CNAV FCNT.CNAV -999.250 NRAT.CNAV -999.250 CFTC.CNAV -999.250 CRAT.CNAV -999.250 CNTC.CNAV '999.250 '999.250 '****' FILE TRAILER **** FILE NAME : EDIT ,004 SERVICE : F VERSION : O~IC ]C01 DATE : 95/02/13 MAX REC SIZE ) 1024 FILE TYPE : LO LAST FILE : ~IS Tape Verification Listine ;chlum~erqer Alaska Computind Center 13-FEB-1995 0q:45 PAGE: 14 ***~ FILE HEADER **** FILE NAME : EDIT .005 SERVICE : VERSION : DATE : 95/02/13 MAX REC SIZE : ~024 FILF TYPE : LO LAST FILE : FILE HE~DER FILE NUMBER 5 RaW CURYES Curves and log header data for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 46 ~OG HEADER DATA STOP DEPTH 8944.0 CNTD CNTD CNTD CNTD CNTD CNTD S DATE LOGGED= V~NDOR TOOL CODE ?00~ COmPENSATeD NEUTRON COmPEnSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON BOREMOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASI~IG DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): files; raw backoround pass in last fi 15-dUN-94 9443,0 9445,0 9442 1800. 15-dUN-94 TOOL NUMBER CNC DAIO1 CPSC-A-867 CPLE-A-867 CGRS-A-862 CTSM-BA-324 TDIC-796 8974.0 Tape Verification Listing lumberger Alaska ¢O~pUtin<3 Center 13-FE,R-1995 09C45 # SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DE~F): FLUID SALINITY FLUID LEVEL FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIOC CHOKE NEUTRON TOOL TOOL TYPE (EP~THERMAL OR THERMAL)~ ~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORNALIZING WINDOW BASE NORMALIZING WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE bOW SCALE (CPS): FAR COUNT RATE HIGH SCALE NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): THERMAL SANDSTONE 2.65 TIED IN TO SWSCBL DATED 6-30-8~ 'HOLE FLUSHED WITH SEAWATER PRIu~ TO LOGGING, LOGGED WHILE INJECTING AT 3 BP~. FIVE PASSES MADE BUT ONLY LAST THREE PRESENTED DUE TO INCOMPLETE GAS FLUS}{ ON FIRST TWO PASSES,., LOG RUN TO DETERMIi~E G.O~C,. G.O.C, APPEARS TO HAVE MO¥~D UP FROM 9~44 TO A PRDXIMATED 9090'. $ LIS FORMAT DATA 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE -~ 64EB ** TYP~ REPR CODE VALUE mmmm~mmmmmmmm~mmmm..mmmm.mmm~:mm I 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0,5 ,I$ Ta~e Verification t, istinq ichlumberger Alaska Computing Center 13-FEB-1995 09:45 PAGE: 16 9 65 FI 11 66 25 12 68 13 66 0 14 65 FI 15 66 6B 16 66 1 0 66 1 mmmmmmmmmmmmmmmmmmmmmmmmmmmmm$ ** SET TYPE - CHAN NA~ RV UNIT S R ID ORD mmmmmmMwmmmmmmmmmmmmmm DEPT FT 487978 O0 000 O0 NPH! P$1 PU 487978 O0 000 O0 RTN~ PS1 487978 O0 000 O0 TNRA P$1 487978 O0 000 O0 RCNT PS1 CPS 487975 O0 000 O0 RCFT PS! CPS 487978 O0 000 O0 CNT~ PSi CPS 487978 O0 000 O0 CFTC PSi CPS 487978 O0 000 O0 GR P$1 GAPI 487978 O0 000 O0 TENS P81 LB 487978 O0 000 O0 mmmmmmmmmmmm~mmmmmmmmmmmmmwm~mmmmm~mm.mm~mmmmw~mmmmmmmmmmmmMmm 0 5 ! I 4 68 0000000000 0 5 ! ! 4 68 0000000000 0 5 ! ! 4 68 0000000000 0 5 ! ! 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 1 1 4 68 0000000000 mmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmm,mmm#mmmmmmmmmmmmmmmmm DATA D~PT., RCNT.PSl G~,P81 DEPT. RCN?,P$1 G~.,PS1 9465'500 NPHi.PSI 2666.667 RCFT.P$1 24.672 TENS'PS1 29.124 RTNR,PS1 4 857 TNRA.P$1 549.020 CNTC, PSi 26771907 CFTC.PS1 1120.000 8944.000 NP.HI.PS! 48 212 RTNR-PS! 6 500 TNRA.P$1 2476.578 RCFT.P$1 391]039 CNTC,PS1 2495:651 CFTC,PS1 346.750 TENS.PS1 1335.000 *'* END OF DATA 96{: 7.119 346,641 **** FILE TRAILER FIb~ NAME : EDIT .005 s~Rvlc~ : F~IC VERSION : O01CO1 DA.T~ : 95/02/1.3 M'AX REC SXZE : FILE TYPE : 50 LAST'FILE ,IS Tape. Verif~,catton Listing ;chlumberger AlasKa Computing Center 1]-FLB-1995 09:45 PAGE: t7 **** FILE HEADER **** F~LE NAME : EDIT .006 SERVICE : FLIC YERSION : O01CO1 DATE : 95/02/13 MAX REC SIZE : I024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD. 9409.5 8945,0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM.: TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL ~OTTOM LOG iNTER¥ FT Ab TOOL ST~ING.,(?OP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NTD COMPENSATED NEUTRON NTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON CN'TD COMPENSATED NEUTRO~ # 80REHOLE AND CASING DATA OPEN HOLE BIT SIZE. (IN)~ DRILLERS CASING DEPTH LOGGERS CASING DEPTH 80REHOLE CONDITIONS FLUID TYPE: FLUXD DENSITY (LB/G): files; raw background pass in last fi 38,2 2355 15-jUN-9~ 9443.0 9445°0 8942 0 9442:0 1800,0 NO TOOL NUMBER ~N¢ DA ~0~ CPSC-A-86? CPLE-A-867 CGRS'A'$62 CTS~-BA-324 TDIC'796 8974.0 $~,A. ATER Tape Verification L/stinq ;chlumeergerAlaska Computing Center II-FEB-1995 09:45 # REMARKS: SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEgPERATURE (DEGF): FLUID SALINITY FLUID LEVEL CFT): FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIOI CHOKE (DEG)I NEUTRON TO0~ TOOL TYPE (EPITHER~AL OR THERMAL)I ~ATRIX: MATRIX DENSITY: HOLE CORRECTION ~LUELINE COUNT RATE NORMALIZATION IN OIL ZOnE TOP NORMALIZING WINDOW RASE NORMALIZING WINDOW 8LUELINE COUNT RATE SCAL~S SET BY F~ELD E~GINEER FAR COUNT RATE LOW SCALE (CPS)I FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE ¢ PS NEAR COUNT RATE HIGH SCALE oep : TOOL STANDOFF (IN): THERMAL SANDSTONE 2,65 TIE TO SWSCRL HOLE FLUSHED W~TH SEAWATER PRIOR TO LOGGING. LOGGED ~HILE INJECTING AT. 3 TO ,INCOMPLETE GAS FLUSH ON FIRST TWO PASSES, Los TO MOVED UP FROM 91~44' TO APP~uXIMATED $ LIS FORMAT DATA PAGEI 18 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR.CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 6~ Tape VerifiCation Llsttng ;chlumberqer Alaska Computing Center 13-FEB-1995 09:45 PAGE: 19 TYPE REPR CODE YALUE 9 65 T ii 66 25 12 68 13 66 0 14 65 FI 15 66 68 16 66 0 66 ** SET TYPE = CHAN ** NAME SERV UNIT SERVICE API APi API API FILE NUMB NUMB SIZE REPR PROCESS ED ORDE~ ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ..................;;;...........;...... ....... .......... .......... DEPT FT 978 O0 O 0 O0 0 1 4 00000000 NPH! P$2 PU 487978 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR P$2 487978 O0 000 O0 0 6 1 i 4 68 0000000000 TNRA PS2 487978 O0 000 O0 0 6 1 ! 4 68 0000000000 RCNT P$2 CPS 487978 O0 000 O0 0 6 t 1 4 68 0000000000 RCFT PS2 CPS 487978 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC P$2 CPS 487978 O0 000 O0 0 6 [ ! 4 68 0000000000 CFTC PS2 CPS 487978 O0 000 O0 0 6 1 I 4 68 0000000000 GR P$2 GAPI 487978 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 487978 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** 03 R:CFT'PS2 764.706 GR,PS~ 20-82 TENS,PS2 1320.000 DEPT, 8949'000 NPHI:*PS2 52 752 RCNT,PS'2 2313.646 RCFT.PS2 304:609 GR,P$2 308.000 TENS.PS2 1385.000 ** END OF DATA RTNR,PS2 CNTC,PS2 RTNR,PS2 CNTC.PS2 4','051 T~RA.PS2 3111.097 CFTC.PS2 7,895 TNRA.P$2 2332.174 CFTC.PS2 4.118 728,417 7.639 298,496 **** FILE TRAILER **** FILE NA~E ~ EDIT ,006 SERVICE : FLIC VERSION : O01CO1 DATE : 95/02/13 MAX R~C SIZE : 1024 FILE TYPE : LO Tape Verification Listing ;chlumberger AlasKa Computin~ Center 13-FEB-1995 09:45 PAGE: 20 **** FILE MEADER *~** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C0! DATF : 95/02/,3 MAX REC SIZE : 1024 FILE TYPE' : LO LAST FILE ~ F!LZ HEADER FYLE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate PASS NUMBERs 3 DEPTH INCREMENT: 0,5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD'''''''''''''''' '~'~2;4 .... $ LOG HEADER DATA STOP DEPTH U942,5 DATE ~OGGED: SOFTWARE VERSION: TIME~ ~OGGER ON BOTTO~I TD DRILLER TD LOGGER(FT): TOP LOG INTERVAU BOTTOM bOG INTERVAL,~T): LOGGING SPEEn (FPHR){ DEPTN CONTROL USED (YES/NO){ TD TD CNTD CNTD CNTD $ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEUTRON COMPENSATED NEOTRON COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN MOt, E BIT SI,ZE (IN): DRILLERS CASING DEPTH (FT)~ LOGGERS CASING DEPTH (FT):' BOREHOLE CONDITIONS FLUID TYPE: F~UID DENSITY (.LB/G) files; raw background pass in last 15-JUN-g4 23{ IS-JUN-94 94'4~i0 944 0 89'42 0 9442,0 ~800.,0 TOOL:NUMBER, CNCDA~O~ CP$C'A'867 CPLE'A~867 CGRS'A"862 CTSM-BA-324 TDIC'796 8974.0 SEAWATER Tape Verification L~st~na chlumberger AlasKa Computin.6. Center 13-FEB-1995 09~45 # SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUXD SALINITY (PPM)I FLUID LEVEL FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHER~AL Ok THERMAL): MATRI×I MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WXNDO~ (FT): ~LUE[,INE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS) TOOL STANDOFF (IN)~ THERMAL SANDSTONE 2.65 TIED IN TO SWSCBL DATED 6-30-83. HOLE FLUSHED WITH SEAWATER PRIOR TO LOGGING, ,bOGGED WHILE INJECTING AT 3 BP~ FIVE PASSES ~ADE BUT ONLY LAST ~HREE PRESENTED DUE TO INCOmpLETE GAS FLUSH ON FIRST TWO PASSES.~ LOG RUNTO DETERMINE G.O.C.. ~ O.C. APPEARS TO HAVE MOVED UP FRO~ 9144~ TO APPROXImaTED 9090', $ .# ~S FORMAT DATA PAGE: 2! *~ DATA FORMAT SPECIFICATION ~ECORD ** TYPE - 64EB ** TYP~; REPR CODE VALUE ! 6b 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 B 68 0,5 ,IS Ta~e Yeri~ic~tion Llstino ~chlu~berger Alaska ComPutin~ Center 13-FEB-].995 09:45 mm..--mmm.-- ..mm..m.--mm mm, 9 65 11 66 25 12 68 1~ 66 0 14 65 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** ............................................................................. .... . ..... NAME SE SER ICE API EPRRV UNIT V API AP1 APl FILE NUMO NUMB SIZE R PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) '~'~''''''''''''''''''''''''''''~''~''''E FT 487978 0 O0 0 ....7''''''''''''''''''''''I 1 .... 68 '''~~ 00000 ....... PU 487978 O0 000 O0 0 7 I 1 4 68 0000000000 NPH! PS] RCNT RCFT CNTC PS CFTC 487978 O0 000 O0 0 7 1 1 4 68 487978 O0 000 O0 0 7 1 1 4 68 CPS 487978 O0 000 O0 0 7 i 1 4 68 CPS 487978 O0 000 O0 0 7 1 1 4 68 CPS 487978 O0 000 O0 0 7 1 1 4 68 CPS 487978 O0 000 O0 0 7 1 1 4 68 GAPI 487978 O0 000 O0 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TENS PS3 LB 487978 O0 000 O0 0 '7 1 1 4 68 0000000000 m~-m~-mmm~-mmmmmmmmmmmmmmmmmmm-mmmmmm-~-~-~mm--m~m~----~-mmmmmmmmmm-mmmmmmm~-mmmmm ** DATA ** DEPT 9413,~500 NPHI.PS3 27.854 RTNR,PS3. RCNT:Ps3 ]411,765 RCFT.PS3 '725,490 CNTC~PS3 OR.PS3 23.578 TENS.PS3 1,405.000 DE:PT 8942.500 NPHI~, 3 47. 9 RTNR.~PS ** END Or DATA 4 703 TNRA.PS3 3426:145 CFTC.PS3 6 636 I'NRA.PS3 2557~530 CFTC.PS3 4.780 691.062 6,994 351,'538 ****' FILE TRAILER FILE NAME ~ EDIT ,007 VERSION : O01CO1 DATE : 95/02/13 MAX REC SIZE : 1024 FILF TYPE : 50 LAST FILE hlUm a rger A1 ska Comput ,,g Center 13-FEB-1995 0q:45 PAGE: 23 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/02/13 ORIGIN : FLIC TAPE NAME : 94248 CONTINUATION # : ! PREVIOUS TAPE : COMMENT : ARCO ALASKA INC,, PRUDHOK BAY, DS 14-24, 500292097000 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/02/13 ORIGIN : FLIC REEL NAME : 9424~ CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC,, PRUDHOE BAY, DS 14-24, 500292097000
