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184-244
RECEIVED STATE OF ALASKA Aft ALASKA OIL AND GAS CONSERVATION CO ION W OMPLETION OR RECOMPLETION REI�RT AND LOG MAR 0 9 2018 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Developrr (tat C 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero + e A A lIJJ Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp., r Aban 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 2/12/201$ 184-244. 317-546 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/18/1985 50-029-21259-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 3/7/1985 PBU 17-11 • Surface: 2710'FNL,1029'FWL,Sec.22,T1ON,R15E,UM • 9 Ref Elevations KB 71.00 - 17. Field/Pool(s): Top of Productive Interval: 2183'FSL,539'FWL,Sec.15,T1ON,R15E,UM GL 36.90 • BF 38.15 • PRUDHOE BAY,PRUDHOE OIL . Total Depth: 2594'FSL,578'FWL,Sec.15,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10900'/8766' ADL 028331 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 709288• y- 5927935 • Zone - ASP 4 . - 11505'/9228' . 87-127 TPI: x- 708653 y- 5932813 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 708680 y- 5933224 Zone - ASP 4 None 1900'(Approx.) 1 5. Directional or Inclination Survey: Yes 0 (attached) No EI • 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Wndow 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/LSS/SP/GR,FDC/CNL/Cal/GR,Gyro 23. CASING,LINER AND CEMENTING RECORD •CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 35' 113' 35' 113' 30" 2000#Poleset 13-3/8" 68#/72# K-55/L-80 34' 2510' 34' 2510' 17-1/2" 2400 sx CS III,400 sx CS II 9-5/8" 47# L-80 33' 10860' 33' 8732' 12-1/4" 500 sx Class'G',300 sx CS II 7" 29# N-80 10558' 11490' 8489' 9217' 8-1/2" 340 sx Class'G' 24. Open to production or injection? Yes 0 No EI • 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): - 4-1/2"12.6#13Cr85 10644' 10452'/8408' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No Iii • Per 20 AAC 25.283(i)(2)attach electronic and printed information JUN 1 •9 ZUT \ - "�: (' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED SCANNEDILL 10900' Set Whipstock 10905' 15 Bbls Class'G' 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 .4.414 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate 4#4404 Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 1/r1-- ‘'/ / ' Z4 r ROOMS LL., h`"'. , .. 2318 6.4:./3 6 28. CORE DATA Conventional Core(s) Yes 0 No El• Sidewall Cores Yes 0 No El If Yes to either question,list formations and in ervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No l Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10855' 8728' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 10855' 8728' Shublik A 10918' 8781' Shublik B 10939' 8798' Shublik C 10960' 8816' Sadlerochit-Zone 4 11005' 8853' Formation at total depth: Zone 4 11005' 8853' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Leemhuis,Jacob Authorized Title: SIM Spegle Contact Email: Jacob.Leemhuis@bp.com Authorized Signature: 1• Date: /,toContact Phone: +1 907 564 4989 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 ND for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only . • Daily Report of Well Operations 17-11 ACTIVITYDATE SUMMARY T/I/O = SSV/210/160. Temp = SI. IA& OA gas samples (Eval IA x OA). AL SI @ casing valve (1900 psi). E-line on location. IA FL= near surface. IA& OA gas samples taken. 12/22/2017 SV, WV, SSV, MV= E-Line. IA& OA= OTG. 1440 hrs. ***WELL S/I ON ARRIVAL*** (SLB ELINE CIS MILL AND WHIPSTOCK) INITIAL T/I/O = 2275/190/140. MIRU, LPT/HPT= PASS. RUN 1: RIH W/ HEAD(FN 1 3/8")/WELLTEC MILL TOOLSTRING OAL = 35', OAW = 550 LB, MAX OD = 3.806" (MILL BIT). TIE-IN TO 4.5"TUBING TALLY DATED 12-APRIL-2005. MILL XN NIPPLE AT 10,610' MD. POOH AND GAUGE MILL AT SURFACE = 3.806". RUN 2: RIH W/ HEAD (FN 1 3/8")/ERS/SWIVEL/CENT(X2)/WPP/BAKER 10/FH/4-1/2"X 7" BAKER DELTA WHIPSTOCK. OAL = 52', OAW= 700 LBS, MAX OD = 3.63". TIE INTO SLB CEMENT EVALUATION TOOL LOG DATED 23-MARCH-1985. SET TOWS AT 10900', ORIENTATED 30 DEG LOHS. CCL TO TOWS = 14.1'. CCL STOP DEPTH = 10885.9'. TAG WS, POOH, RDMO. WELL S/I ON DEPARTURE. FINAL T/I/O = 2275/190/140. 12/22/2017 ***JOB COMPLETE 22-DECEMBER-2017*** CTU #8 1.75" CT Job Scope: Cement Whipstock, Squeeze Perfs Travel from SLB yard to DS 17.Arrive on location and start rigging up. 1/2/2018 **Continued on 01/03/18** CTU #8 1.75" CT Job Scope: Cement Whipstock, Squeeze Perfs MU & RIH w/cementing bha w/2.50" BDJSN. Tag pinchpoint of whipstock and correct to 10905', paint red flag. Load well w/278 bbls 1% KCL and 137 bbls diesel. Establish 1 bpm injectivity baseline @ 320 psi, static baseline @ 298 psi. Come online w/cement and lay in from 10905' up to 10800', close choke and squeeze in 37 bbls before getting 500 psi bump, cut cement and swap to fresh water, @ 39 bbls away lay in remaining 28 bbls up to 9224', PUH to safety @ 8850' and begin hesitation. Squeeze consisted of 5 bbls neat, 15 bbls 15.8 ppg Class G w/ 12 ppb aggregate, and 77 bbls 15.8 neat 1/3/2018 **In progress** CTU #8 1.75" CT Job Scope: Cement Whipstock, Squeeze Perfs MU & RIH w/cementing bha w/2.50" BDJSN. Tag pinchpoint of whipstock and correct to 10905', paint red flag. PUH to 10800'. Load well w/278 bbls 1% KCL and 137 bbls diesel. Establish 1 bpm injectivity baseline @ 320 psi, static baseline @ 298 psi. Rlh and park at flag. Let 1.5 bbls above nozzle & lay in cement up to 10800'. Close choke and pump 37 bbls and got a 500 psi bump. Reopen choke and lay in cement 1:1. Puh to safety. Park at 8850' and begin squeeze. Pressure up to 1600 psi, dropped to 1300 psi. Pressured up to 2354, held for 15 mins. Pressured up to 2367 psi, slowly fell to 2217 psi in 30 mins. Monitored for another 10 mins. Lost 44 psi. Slowly bleed down to 500 psi. Drop 3/4" ball and pump PowerVis. Contaminate cement down to flag. Reduce rate to 1.3 bpm when jetting across perfs. Let 1% slk water above nozzle and chase ooh at 80%. Jet jewelry on the way out. Jet BOP's and tree. Rbih to lay in 60/40 freeze protect from 2600'. 1/3/2018 ***Continued on 01/01/18*** CTU #8 1.75" CT Job Scope: Cement Whipstock, Squeeze Perfs Lay in 60/40 freeze protect from 2600'. Pump 10 bbls of corrision inhibitor in coil. Blow down reel with N2. Begin rig down. 1/4/2018 ***Job complete*** T/I/O 300/140/166 MIT-T Post coiled tubing cement whipstock. ***WSR continued on 1/5/2018 01/06/2018*** • • Daily Report of Well Operations 17-11 ***WSR continued from 01/06/2018*** (LRS Unit 46 - MIT-T Post Whipstock Cement Squeeze) MIT-T***FAILED***2 attempts. Max applied pressure= 3000 psi, target pressure of 2750. first attempt pressured up TBG with 6.4 bbls dsl to pressure TBG up to 3000 psi. 1st 15 min TBG lost 784 psi 2nd 15 min TBG lost 405 psi for a total loss of 1189 psi. Second attempt pressured TBG up with 2.2 bbls of diesel to a max applied pressure of 3000 psi, 1st 15 min TBG lost 1031 psi, 2nd 15 min TBG lost 476 psi for a total loss of 1507 psi. Valve positions= SV, WV, SSV= Closed. IA, OA= OTG **MIT Tag hung on WV** 1/6/2018 FWHP= 729/3/163 T/I/O=VAC/0/0. Pre- CDR2. R/U CIW lubricator#68-840. Ran down and set 4" TWC#292 @ 125" LTT (PASS). Removed companion blind flange from FC and installed Target 90 and Temp valves 23 and 79. torqued to API specs. PT'd to 350 low and 5000 high. (PASS). 1/28/2018 RDMO ***Job Complete*** SEE LOG FOR DETAILS. TWC sign hung on well. T/I/O = TWC/40/150. Temp = SI. Bleed IA& OA to 0 psi. (Pre CTD). No Wellhouse, flowline, or scaffolding. IA FL near surface. OA FL near surface. Bled OAP from 150 psi to 2 psi in 1 hour and 30 minutes to BT (All gas). Bled IAP from 40 psi to 0 psi in 15 minutes to BT (All gas). During IA bled OAP increased 18 psi. Bled OAP from 20 psi to 0 psi in 30 minutes to BT, held open bleed on OA for 1 hour. During 30 minute monitor IAP unchanged and OAP increased 5 psi. Final WHPs TWC/0/5. 1/30/2018 SV, WV, CV, CV, SSV= C. MV= O. IA, OA= OTG. 05:00 T/I/O = TWC/6/20. Temp = SI. Bleed OAP to 0 psi (pr CTD). Wellhouse,AL, flowline, and scaffolding removed. IA& OA FL near surface. Bled IAP from 6 psi to 0 psi in <1 min (all gas). Bled OAP from 20 psi to 0 psi in 5 min (all gas). Held open bleed for 30 min. IAP increased to 0+, OAP increased 4 psi. Final WHPs = TWC/0+/4. 1/30/2018 SSV= C. MV= O. IA, OA= OTG. 10:30 T/I/O = TWC/6/20. Temp = SI. WHPs (Pre CTD). No Wellhouse, flowline, or scaffolding. IAP increased 6 psi and OAP increased 15 psi in 11 hours. 1/30/2018 SV, WV, CV, CV, SSV= C. MV= O. IA, OA= OTG. 21:30 T/I/O=TWC/0/0. R/D CDR2 Target 90. Installed Tapped Blind. Torqued BF x FC to 573 ft lbs. PT'd agains SSV to Low 300psi High 5000psi. (Passed). RDMO ***Job Complete*** FWHP= 2/2/2018 TWC/0/0. See Log for Details.. TWO = TWC/0/0. Pre CDR2 tree work. Removed Tapped Blind Flange off FC companion side. Installed CDR Killline#1 FC companion side. Torqued to API specs. PT'd to 350/5000 2/8/2018 psi. (PASS). RDMO Job Complete. SEE LOG FOR DETAILS Final T/I/O = TWC/0/0. T/I/O = TWC/10/30. Temp = SI. Bleed WHPs to 0 psi. (Pre CTD). No wellhouse, flowline, or scaffolding. IA& OA FL near surface. Bled IAP from 10 psi to 0 psi in <1 minute to BT.(All gas). Bled OAP from 30 psi to 0 psi in 10 minutes to BT. (All gas). Held open bleed on OA for 3 hours. During 30 minute monitor, IAP and OAP unchanged. Final WHPs = TWC/0/0. 2/10/2018 SV, WV, CV, CV, SSV= C. MV= O. IA, OA= OTG. 05:00 • • i North America-ALASKA-BP Page 1 Qty Operation Summary Report Common Well Name:17-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/11/2018 End Date:2/19/2018 X3-0183Y-C:(2,231,784.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:CDR-2 Spud Date/Time:2/18/1985 12:00:00AM I Rig Release:2/22/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001523 Active datum:Kelly Bushing/Rotary Table @71 O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)- ! (usft) 2/11/2018 00:00 - 00:30 I 0.50 MOB P PRE PREP FOR RIG MOVE. -PJSM W/TRUCK PUSHER,DRIVERS AND RIG CREW. -USE OF STOP BLOCK BETWEEN WELLAND BACK TIRES OF SUB. -AGREE ON ALL STOP COMMAND TO STOP ACTION. '-ANYONE CAN CALL ALL STOP OR STOP THE JOB. -EMPHASIS ON REPEATING BACK ANY TRANSMITTED RADIO COMMUNICATIONS. 00:30 - 03:15 2.75 MOB P PRE -ENSURE ALL VALVES CLOSED,WELL :SECURED.DRILL SITE OPERATOR NOTIFIED. -HOOK UP TO MUD PIT MODULE AND MOVE OFF. -STOP BLOCK IN PLACE. -HOOK UP TO SUB AND MOVE OFF OF WELL. -NABORS TOOL PUSHER AND BP WSL WITNESS MOVING OFF OF WELL. -DRILL SITE OPERATOR WAIVED WITNESS TO MOVE OFF. -HOOK UP TO JEEPS AND SECURITY TOOL BOX MEETING. -MOVE TO DRILL SITE 17.3.3 MILE MOVE. -ON LOCATION @ 03:15 HRS. 03:15 - 06:30 3.25 MOB P PRE UNHOOK SUB MODULE FROM JEEP. -ENSURE STOP BLOCK IS IN PLACE. -DOUBLE CHECK VALVES ON TREE,WELL IS SECURED. -NABORS TOOL PUSHER AND WSL WITNESSING. -DRILL SITE OPERATOR ALSO WITNESSING SPOTTING SUB OVER WELL. -STOP COMMAND AGREED UPON. -SPOT SUB OVER WELLAND SET DOWN,NO ISSUES. -HOOK UP MUD PIT MODULE AND SPOT NEXT TO SUB. -RIG ACCEPTED @ 06:30 HRS,02/11/2018. 06:30 - 10:00 3.50 RIGU P PRE BEGIN R/U CHECKLIST. HOOK UP INTERCONNECT LINES. SPOT AUXILIARY EQUIPMENT. VALVE CREW COMES OUT TO OPEN SSV, INSTALL FUSIBLE CAP AND BLEED OFF HYDRAULIC PRESSURE. GREASE TREE VALVES. 10:00 - 13:00 3.00 BOPSUR P PRE INSTALL MANAGED PRESSURE LINE. CONTINUE R/U CHECKLIST. 'PERFORM LEAK TIGHT TEST ON SWAB AND MASTER,GOOD. REMOVE TREE CAP AND INSTALL BOPS. -7 1/6"X 5M BOPE CONFIGURATION AS FOLLOWS F/TOP DOWN. -ANNULAR PREVENTOR,BLIND/.SHEAR RAMS, 2 3/8"PIPE/SLIP RAMS. -MUD CROSS,2 3/8"X 3 1/2"VBR,2 3/8"PIPE /SLIP RAMS. Printed 3/2/2018 2:57:41 PM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 2 lirPI& Operation Summary Report Common Well Name:17-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/11/2018 End Date:2/19/2018 X3-0183Y-C:(2,231,784.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:CDR-2 Spud Date/Time:2/18/1985 12:00:00AM Rig Release:2/22/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001523 Active datum:Kelly Bushing/Rotary Table @71.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:00 - 14:00 1.00 BOPSUR P PRE LINE UP VALVES AND REVIEW PROCEDURE FOR TESTING BOPS. GET MULTIJOINT READY. ESTABLISH EXCLUSION ZONES ON RIG FLOOR. 14:00 - 19:00 5.00 BOPSUR P PRE TEST BOPS AS PER AOGCC AND BP REGS. TEST ANNULAR PREVENTER,BLIND RAMS, `UPPER 2-3/8"PIPE SLIP RAMS,2-3/8"X 3-1/2" VBR,LOWER 2-3/8"PIPE/SLIP RAMS. TEST CHOKE LINE VALVES AND MPD VALVES. ALL TESTS TO 250/3,500 PSI.NO FAILURES. -PERFORM DRAWDOWN TEST ON ACCUMULATOR. AOGCC INSPECTOR LOU LAUBENSTEIN WAIVES WITNESS. '19:00 - 22:00 3.00 BOPSUR P PRE PREP TO TEST INNER REEL VALVE. -MAKE UP INJECTOR TO WELL,CHECK PACKOFFS/CHANGE PACKOFFS. -PJSM.LINE UP AND PUMP A COIL VOLUME (WATER) -LINE UP AND PRESSURE TEST INNER REEL VALVE,PACKOFFS. -ALSO REVERSE TESTING C-9&C-10.250/ 3500 PSI/5 MIN EA/CHARTED. 22:00 - 00:00 2.00 WHSUR P PRE PJSM W/VALVE SHOP CREW.HIGHLIGHT I BARRIER AWARENESS. -REVIEW PROCEDURE AND EMPHASIS ON I COMMUNICATION TECHNIQUE. -CHECK TORQUE ON TREE BOLTS,OK. BREAK OFF AND TROLLEY BACK INJECTOR. PICK UP AND MAKE UP LUBRICATOR TO PULL TWC VALVE. 2/12/2018 03:00 - 04:00 1.00 KILLW P WEXIT PJSM.MAKE UP NOZZLE BHA. -MAKE UP NOZZLE ASSEMBLY.INJECTOR ON WELL @ 03:50 HRS. 00:00 - 01:30 1.50 WHSUR P PRE PJSM W/VALVE CREW AND CREW COMING ON TOUR. -FLUID PACK LUBRICATOR W/METHANOL -PRESSURE TEST LUBRICATOR @ 250/3500 PSI/5 MIN EACH/CHARTED. 01:30 - 03:00 1.50 WHSUR P PRE PULL TWO WAY CHECK VALVE,SITP-60 PSI. -STARTING PRESSURES:0/A-0 PSI I/A-7 PSI TBG-60 PSI. -RIG DOWN LUBRICATOR. 04:00 - 05:00 1.00 KILLW P WEXIT PJSM.LINE UP TO DISPLACE WATER, 5 BBLS MEOH AND KCL. -PRESSURE TEST BAKER FLOATS,3500 PSI/ 5 MIN/CHARTED 05:00 - 05.30 0.50 KILLW P WEXIT CONDUCT RIG EVAC EXERCISE WITH JURY CREW.H2S RELEASE IN CELLAR -ALARM SOUNDED AT CHANGE OUT FOR WSLAND TOOL PUSHER -ALL PERSONNEL MUSTER AND ACCOUNTED FOR IN 3 MIN. -GOOD AAR WITH CREW,NO SIGNIFICANT GAPS Printed 3/2/2018 2.57.41PM `AII depths reported in Drillers Depths* gat- • • North America-ALASKA-BP •Y' • Operation Summary Report Common Well Name:17-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.2/11/2018 End Date:2/19/2018 X3-0183Y-C:(2,231,784.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:CDR-2 Spud Date/Time:2/18/1985 12:00.00AM Rig Release.2/22/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001523 Active datum:Kelly Bushing/Rotary Table @71.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:30 - 09:00 3.50 KILLW P 10,932.00 WEXIT OPEN WELL UP. -WHP=60 PSI. -HOLD 200 PSI WHP AND RIH,CIRCULATE MINIMUM RATE. -TAG PINCH POINT AT 10,932'UNCORRECTED DEPTH. -CIRCULATE 1%SLICK KCL AT 0.3 BPM 09:00 - 12:00 3.00 KILLW P 10,932.00 WEXIT FINISH DISPLACING THE WELL TO KCL THEN DISPLACE KCL OUT W/ 8.7 PPG DRILLING MUD. -INCREASE RATE UP TO 3.3 BPM MAINTAINING LESS ThAN 150 PSI DOWNSTREAM OF CHOKE -GAS BACK TO FLOW BACK TANK IN SMALL 'AND INTERMITTENT AMOUNTS. -FLOWCHECK WELL FOR 10 MINUTES-WELL IS STABLE,8.7 PPG MUD IN AND OUT. 12:00 14:30 2.50 KILLW P 10,932.00 WEXIT POOH W/NOZZLE ASSEMBLY. -FLOW CHECK WELL AT SURFACE,(10 MIN). WELL BORE STABLE. -8.7 PPG MUD IN AND OUT.1.8 BBLS LOST TO FORMATION ON TRIP OUT. -DATA COLLECTED FROM TRIP SHEET/PIT WATCHER. -INJECTOR OFF 14:25 HRS 14:30 - 15:30 1.00 KILLW P 10,932.00 WEXIT CHANGE OUT BHA -FLOWCHECK WELL AT BHA FOR 10 MINUTES,PJSM FOR C/O BHA -LD NOZZLE -MU BHA#2 WITH 3.80"MILL AND 3.78 REAMER -INJECTOR ON AT 15:30 15:30 - 19:00 3.50 STWHIP P 10,900.00 WEXIT RIH W/WINDOW MILLING BHA.(STRAIGHT MOTOR). -TIE IN W/GAMMA F/10,765'-10,783'@ 4 FPM. -MINUS 21'CORRECTION. (1� 19:00 - 00:00 5.00 STWHIP P 10,911.00 WEXIT RIH PUMPING 2.77 BPM @ 2950 PSI.56K UP WT,26K DOWN WT. I� « -TAG @ 10,906.6'AND SEE DIFFERENTIAL AND SOME WOB. -MILLED TO 10,907'FAIRLY QUICKLY, LOOKED LIKE RESIDUAL CEMENT. -CALL HARD TAG @ 10,907'AND COMMENCE MILLING WINDOWAS PER PROGRAM. -2.76 IN/2.77 OUT,8.77 PPG IN/8.72 PPG OUT.2950 PSI FREE SPIN PRESSURE. -MILLING 1'/HR.WOB 2-4K.3025-3150 PSI MILLING PRESSURE. -MILL WINDOW IN 7"CASING F/10,907'- 10,911'.NO ISSUES.NO LOSSES. 2/13/2018 00:00 - 04:00 4.00 STWHIP P 10,914.00 WEXIT CONTINUE MILLING 7"CASING EXIT WINDOW. -2.76 BPM IN/2.77 BPM OUT,2925 PSI FREE SPIN. -MILL WINDOW F/10,911'-10,914'.WOB 2-4 K,1'/HR. -MILL EXITING,CONTINUE DOWN,CONTROL DRILLINNG W/STRING REAMER ACROSS WINDOW. Printed 3/2/2018 2.57:41PM *All depths reported in Drillers Depths* Vv LEAD= �Mb OY • 17-11 7-11 NOTES: **4-112"CHROME TBG** ACTUATOR= AXELSON OKB.ELEV= 71' REF ELEV= 71' BF.ELEV= 38.15' I I 2099' H4-112"HES X NP,0=3.813' KOP= 3700' Max Angle= 54°@ 7300' GAS LFT MANDRELS Datum MD- 11027' ST PA) P.i > DEV TYPE VLV LATCH FORT DATE Datum TVD= $8Q0*SS 13-3<8"CSG,72#, —{2508' L-80,D=12.347" 6 3217 3217 0 MMG DRAY RK 0 12/10/17 5 4439 4385 31 MAG DMY RK 0 12/11/13 4 5911 5439 49 MAG DMY RK 0 12/10/17 3 7445 6386 54 MAG DMY RK 0 12/11/13 2 8979 7333 46 MAG DMY RK 0 11/09/09 Minimum ID = 3.806" @ 10610' 1 10233 8245 43 MAG DMY RK 0 11/09/09 4-1/2" MILLED HES XN NIPPLE I I 10419' 1-1,4-1/r HES X NP,ID=3.813" X 10440' --I9-5/8"X 4-1/2"BKR S3 PKR,D=3.875" ' 10464' —4-1/2-HES X NP,ID=3.813" TOP OF 7"LNR — 10566' I , ( 10610' 1-4 1!2"FES XN NP TO 3.806"ON 12/22/17 i 4-1/2"TBG,12.6#,13CR-85,_0152 bpf,0=3.958" H 10632' 10632' —14-1/2"WLEG,0=3.958" 9-5/8"CSG,47#,L-80 BTC,D=8.681" H 10858' _All L FERFORATION SIMvIARY REF LOG:BHCS ON 03/07/85 10900' —4-1/2"X 7"BKR DELTA WHPSTOCK w/RA : ANGLE AT TOP PERF:33°@ 10893 . .#. TAGS(12/22/17) -. * 4.4'x.4 Note:Refer to Roduction DB for historical perf data 111111 10905' —SQZD PSS_CLEANOUT CMT TO 10905'- SIZE SPF V'1TG IAL Opn/Sgz SHOT SQZ 111/1/1111i1 per{PONT OF WS{01103/18} ? 6 10893-10916 S 04/26/91 111111111111 3-3/8" 13 10893- 10916 S 02/28/92 01/03/18 111111111/111 3-318" 4 10905- 10907 S 07/19/91 01/03/18 11111/111/111 3-3/8" 4 10924- 10930 S 04/30/92 01/03/18 111111111111 111111111111 4 10930-10935 S 04/30/92 01/03/18 1111111 3-3/8" 8 10935-10952 S 04/30/92 01/03/18111111111111 3-3/8" 4 10980- 10993 S 04/30/92 01/03/18 11111111111/1 3-3/8" 1 11014- 11054 S 04/26/91 111111111111 11111111111/ 3-3/8" 5 11014-11054 S 07/19/91 01/03/18 111111 3-3/8" 1 11066- 11118 S 04/26/91 111111 1111111111111 3-3/8" 5 11066-11118 S 07/19/91 01/03/18 111111111111 3-3/8" 4 11130-11150 S 07/19/91 01/03/18 11111111111i1 3-3/8" 1 11130- 11174 S 04/26/91 111111111111 2-1/2' 2 11198-11206 S 02/18/08 01/03/18111111 1111111 3-3/8" 1/3 11198-11206 S 04/26/91 111111111111 2-7/8" 6 11198- 11218 S 07/18/17 01/03/18 1111111111111 2-1/2" 2 11208-11216 S 02/18/08 01/03/18 111111111111 1.11.4 3-3/8" 1/4 11208-11216 S 04/26/91 2-7/8" 6 11220- 11235 5 07/18/17 01/03/18 11350' -I FLL&JUN((04/12/05 DING) 3-3/8" 6 11250-11266 S 05/03/05 01/03/18 ilk 11350' PBTD H 11449' • 1 1111111 7"LNR,29#,L-80,.0371 bpf,0=6,184" —1 11488' _1 11111111111111 TD — 11505' 11/111111111 DATE _ REV BY C NANTS DATE REV BY COIAV N[S PRLIDHDE BAY ma 03/11/85 "ORIGINAL COMPLETION 10/27/16 ZV/JMD GLV C/O(10/24/16) WELL: 17-11 + + 02/16/86 MO 01/04/17 JNUJMD ADDED REF&BF ELEV PERMIT No: 1842440 04/15/05 N4E1; RWO 07/24/17 AB/JPA) ADPERFS(07/18/17) API No: 50-029-21259-00 12/20/13 LE3C/JMD GLV C/O(12/11/13) 12/12/17 JFK/IAD GLV C/O(12/09/17) SEC 22,1-10N,R15E,2710'EFL&1029'FWL 06/14/16 JMWJMD GLV CIO(06/12/16) 12/27/17 MS/JMD MLLED XN NP&SET WS 06/23/16 JMD LA,DATH)CSG&LNR DEP I1- 01/05/18 MS/JMD CMT WS&SQZD PERFS BP Exploration(Alaska) • • or 4 I j4's THE STATE Alaska Oil and Gas of A LAsKA Conservation Commission 333 West Seventh Avenue � 2 Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 ®J;ALAS- Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Leader BP Exploration(Alaska), Inc. DEC � 17 PO Box 196612 Anchorage, AK 99519-6612 SCOW Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-11 Permit to Drill Number: 184-244 Sundry Number: 317-546 Dear Mr. Egbejimba: 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, Hollis. S. French Chair, Commissioner DATED this‘'2- day of December, 2017. STATE OF ALASKA RE C "'ALASKA• OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPRO S 1T7 C7 ! 7 20 AAC 25.280 N O V 1 ;1017 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 0 erations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Ch dram ❑ Plug for Redrill El • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 184-244 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0' 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21259-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 17-11 . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028331 • 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): v/ Plugs(MD): Junk(MD): 11505 • 9228 • 11350 9119 2525 11350 3(unknown) Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 35-113 35-113 1490 470 Surface 2476 13-3/8" 34-2510 34-2510 3450/4930 1950/2670 Intermediate 10827 9-5/8" 33-10860 33-8733 6870 4760 Production Liner 932 7" 10558-11490 8489-9217 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10893-11266 8760-9057 4-1/2"12.6# 13Cr85 31 -10644 Packers and SSSV Type: 4-1/2"BAKER S-3 PERM PACKER Packers and SSSV MD(ft)and ND(ft): 10452/8408 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for Commencing Operations: December 15,2017 15. Well Status after proposed work: , Oil ❑ WINJ 0 WDSPL ❑ Suspended 0 ' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Leemhuis,Jacob be deviated from without prior written approval. Contact Email: Jacob.Leemhuisa]bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 4989 Authorized Title: Engineer g Team Leader-CTD&RWO ' �� Authorized Signature: •/A • 9 - Date: ' 17 v/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1n Plug Integrity ❑ BOP Test IN''' Mechanical Integrity Test 0 Location Clearance 0 311 54 `' Other: 5p tt5f f-z, 35cO p5 L' 9 f}-r v-)v 1 A r p r-e V f k) 1�5 t- fa Z 5--- c.) psi 1 � �tpet, vr >�� � Z5 r1r��� o Z - No � p. A61-. rn ±e Pi '', t Post Initial Injection MIT Req'd? Yes 0 � G Spacing Exception Required? Yes 0 No Q// Subsequent Form Required: /(9„—40 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: (Z I vA0RIGI NALL REQ 43 V-- La- C b 26I7 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attach ents in Duplicete • • To: Alaska Oil & Gas Conservation Commissionto-% bnFrom: Jacob Leemhuis CTD Engineer Date: November 17, 2017 Re: 17-11 Sundry Approval Request Sundry approval is requested to plug the 17-11 perforations as part of the preparation, drilling and completing the proposed 17-11A coiled tubing sidetrack. This is a previously approved Sundry that is requesting renewal. The delay in well work was due to not being able to drill this well due to the Sag River Ice Road. This is currently • on the schedule for Spring 2018. History of 17-11: 17-11 is a Rotary horizontal sidetrack which was drilled in 1985. The well had a RWO in 2005 and was re-perfed in 2008 to increase EOR offtake from 03-07A MIST Injection. 03-07A has plugged off the perfs that were influencing 17-11 and started injecting uphole recently. Any future MI benefits from this interaction are minimal at best. The parent well-bores production will be retain in the sidetrack with.perfs placed in the sump of the well plan. ~~`-- (o4Cur '1/17 7 Proposed plan for 17-11A: Drill a through tubing sidetrack with the Nabors CDR2 Coiled Tubing Drilling rig on or around March 1st, 2018. The 17-11A sidetrack will be a single string exit from the existing 7" liner. A 4-1/2" x 7" whipstock will be set pre-rig and cemented in place. 17-11A will target attic oil trapped along the large E-W fault just to the north of the pad targeting Z4 sands. The well will have one small undulation to crosscut the discontinuous Z4B shales. Well design involves kicking off a 7" delta whipstock, drilling build section with 18 DLS, drilling lateral with 12 DLS, run 3-1/2" x 3-1/4" x 2-7/8" 13Cr-85 production liner, cemented and perforated. This Sundry covers plugging the existing 17-11 perforations via the cement squeeze and liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin December 15,2017) 1. E Set whipstock 2. C Mill XN Nipple to 3.80", squeeze cement/cement whipstock 3. V Set BPV. Pre-CTD tree work. Rig Work(scheduled to begin March 1,2018) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,525 psi). 2. Mill 3.80"window and 10'of rathole. 3. Drill Build:4.25"OH, —594' (18 deg DLS planned). 4. Drill Lateral: 4.25"OH, 2,141' (12 deg DLS planned). 5. Run 3-1/4"x 2-7/8" 13Cr-85 liner leaving TOL at—10,560' MD. 6. Pump primary cement job: 36.7 bbls, 15.3 ppg Class G,TOC at—10,560' MD. 7. Perform cleanout run if needed 8. Perform liner lap test*. 9. Perforate—500' 10. Freeze protect well to a min 2,100'TVDss. 11. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) • . Post-Rig Work: 1. Pull TWC. Tree work as necessary. 2. Set liner top packer if liner lap test fails.* 3. Pressure Test LTP (if necessary) 4. ASRC flowback 5. SIT Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 TREE McEVOY SSH •WELLHEAD= M EVOY • 1 7_1 1 SA•NOTES: "4-1/2"CHROMETBG"' ACTUATOR= AXELSON OKB.ELEV= 71' REF ELEV= 71' BF.ELEV= 38.15' I IIIL 2099 —14-112"HES X N D=3.813' KOP= 3700' Max Angle= 54"@ 7300' GAS LFT MANDRELS Datum MD= 11027' ) ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8800'SS 13-3/8"CSG,72# i, 2508' L-80,D=12.347" 6 3217 3217 0 MMG DOME RK 16 10/24/16 5 4439 4385 31 MAG DMY RK 0 12/11/13 4 5911 5439 49 MMG SO RK 20 10/24/16 3 7445 6386 54 MMG DMY RK 0 12/11/13 2 8979 7333 46 MAG DMY RK 0 11/09/09 Minimum ID =3.726" @ 10610' 1 10233 8245 43 MING OMY RK 0 11/09/09 4-112" HES XN NIPPLE ' , 10419' --1 4-1/2"HES X NP,D=3.813" X 10440' H 9-5/8"X 4-1/2"BKR S3 PKR,D=3.875" I I 10464" H41/2"HES XNP,D=3.813" TOP OF 7"LNR H 10556 ' ' 10610' —141/2"HES XN NP,ID=3.725" 4-1/2"TBG,12.6#,13CR-85,.0152 bpf,D=3.958" H 10632' / • 10632' —+4-1/2"WLEG,D=3.958- 9-5/8"CSG,47#,L-80 BTC,0=8.681" H 10858 PERFORATION SUMMARY REF LOG:BHCS ON 03/07/85 ANGLE AT TOP PERF:33°@ 10893' ' Note:Refer to Production DB for historical pert data SIZE SPF N ERVAL Opn/Sqz SHOT SQZ ' ? 6 10893-10916 S 04/26/91 3-3/8" 13 10893-10916 0 02/28/92 3-3/8" 4 10905- 10907 0 07/19/91 3-3/8" 4 10924-10930 0 04/30/92 I 4 10930- 10935 0 04/30/92 3-3/8" 8 10935-10952 0 04/30192 3-3/8" 4 10980-10993 0 04/30/92 I 3-3/8" 1 11014-11054 S 04/26/91 3-3/8" 5 11014-11054 0 07/19/91 3-3/8" 1 11066-11118 S 04/26/91 3-3/8" 5 11066-11118 0 07/19/91 ' 3-3/8" 4 11130-11150 0 07/19/91 3-3/8" 1 11130- 11174 S 04/26/91 2-1/2" 2 11198-11206 0 02/18/08 3-3/8" 1/3 11198-11206 S 04/26/91 I 2-7/8" 6 11198-11218 0 07/18/17 2-1/2" 2 11208-11216 0 02/18/08 I 3-3/8" 1/4 11208- 11216 S 04/26/91 2-7/8" 6 11220-11235 0 07/18/17 11350" _H FLL&JUNK(04/12/05 DSAS) 3-3/8" 6 11250- 11266 0 05/03/05 f PSTD H 11449' 1111111 1111111 7"LN2,29#,L-80,.0371 bpf,D=6.184" —{ 11488' 11111111111111 TD H 11505' 111111/111111 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/11185 ORIGINAL COMPLETION 10/27/16 ZV/JMD GLV C/O(10/24/16) WBI: 17-11 02/16/86 RWO 01/04/17 JNJJMD ADD )REF&BF REV PERMT No: 1842440 04/15/05 N4E5 FaNO 07/24/17 AB/JMD ADFERFS(07/18/17) API No: 50-029-21259-00 12/20/13 LEGUME) GLV CJO(12/11/13) SEC 22,T10N,R15E,2710'FNL&1029'FAL 06/14116 JMMIJMD GLV C/O(06/12/16) 06/23/16 JMD UPDATED CSG&LN2DEPTHS BP Exploration(Alaska) TREE= VIIEFLHEAD= McEVOY SOY NOTES: **4-1/2"CHROME TBG** ACTUATOR= PROPO AL 17-111k OKB.ELEV= 71' BF.ELEV= REV 1 KOP= 3700' Max Angle= _s_` @ __ ' ' 209W H4-1/2"HES X NP,D=3.813" Datum MD= __Datum TVD= _DatumTVD= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2508' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 < 3217 3217 0 MMG DOME RK ') 4439 4385 31 MMG DOME RK Minimum ID = . , " @ 4 5911 5439 49 MMG DOME RK " 3 7445 6386 54 MAG DOME RK . .......... 2 8979 7333 46 MUG DOME RK 1 10233 8245 43 MMCT DOW RK I I 10419' —I4-1/2"HES X NP,D=3.813" >K 10440' H9-518'x4-112'BKR S3 PKR,D=3.875" ' ' 10464' H 4-1/2"HES X NP,D=3.813" TOP OF 7"LNR H I 10556' - — TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNF' H i (,i,i' 1 ,ii'' —1<i70'DEFLOYWENT SLEEVE,ID=3.00" ' y I 10610' 14-1/2"HES XN NP MLLED TO 3.80"(_/_/ ) BEHIND CT LNR ��_____ !, 1" 'OI; 4-1/2"TBG,12.6#,13CR-85,.0152 bpf,D=3.958" H 10632' • 10632' H4-1/2"WLEG,D=3.958"BEHIND CT LNR 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 10858' I--4 _ , 0870` H3-1/2"X 3-1/4"X0,Li=2.786" 3-1/2"LNR, #,13CR-85 STI , I— 10870 7"MLLOUT WNDOW(17-11A) ' 7"X 4-1/2"DELTA WFIPSTOCK(_I /) H 10900' 7"LNR,29#,L-80,.0371 bpf,D=6.184" —I =10900' 3-1/4"LNR,6.6#,13CR-85 TC11,.0079 bpf,ID H 12000' 285" 12000' —13-1/4'X 2-7/8"X0,13=2.377" PERFORATION SUUUARY REF LOG: ON XX/XX/X' ANGLE AT TOP PERF:°@' Note:Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE SQZ PBTD — 2-7/8"LNR,6.5#,13CR-85 STT,.0058 bpf,D= H )3700' 71 2.441" /v1 DATE REV BY COMMENTS DATE REV BY OOM ENTS PRUDHOE BAY UNIT 03/11/85 ORIGINAL COMPLEf1ON 08/31/14- JCL. UPDA IED DEFERS VVELL: 17-11/`- 02/16/86 RWO Fff2Mf No: 04/15/05 N4ES MO AR No: 50-029-21259-0 it Cis (17-11A) SEC 22,T1 ON,R15E,2710'FN-&1029'FWL .16/23/16 JR/3 BOLT PROPOSED 36/27/16 JIJJND FROPOSED REV 1 BP Exploration(Alaska) Well Blank •DR2-AC BOP Schematic 'fate Quick Test Sub to Otis I -1.1 ft14— - - - - - Top of7"Otis I I CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub 1�\ Top of Annular I 0.0 ft • ► I 7-1/16"5k Flange X 7"Otis Box ".,Hydril 7 1/16" Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft ► .D=1. Blind/Shear CL Blind/Shears I 3.3 ft I ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft =7 r B8 " min VF 71/16• ILDeployment Line -65km.d h ilr gyros; �. yl �ll ISI Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft ► 2-3/8"x 3-1/2"VBR ss CL 2-3/8"x3-1/2"VBRs 7.4 ft ► t B1 J B2B3 I B4 Choke Line Kill Line I 1: PI' '114 4 w 1111, ,41,'4 V.; 0 1 40. ars ♦ _ Blind/Shear CL Blind/Shears 10.0 ft ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 10.7 ft • CL of Top Swab 13.3 ft ��� f---Swab 2 Test Pump Hose imp 40/Swab 1 CL of Bottom Swab 14.8 ft `A. je T1 Ai T2 &i CL Flow Tee 16.2 ft - BOP2 CL of SSV 17.5 ft M - I Master 2 Fusable CL of Master Valve 19.0 ft BOP1 46,4 Master 1 LDS 20.5 ft moi.— - n n n n n II II II iI II Gound Level •4• n n n n n n u n n.II 111 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or , / "Suspend"boxes are also checked, cross out that erroneous entry and ✓ initial it on both 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 42 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, they 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, they 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,they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • • X N. Thousand Cubic Feet of Gas ("MCF") per Month o6 NI N co <-1 (NJ O <-1 O n o O0 o O 0 0 0 N 00 O 0 0 O .1 e1 --i ee i ei C n ,•••••„ 1 X02 m Tr -rill 4P� o_I p N �. i r.i`^. II ; 4,„,,.,,,=4 •-- 1 ..... go •Tr � co 00 01 I. ♦ a t'I ea E �.°°� oaa °aa n8 r 8 4 0 44 Pci5 CU t 3 �I v • 1 N 4 Occ 0AO: a 44 ti _}O. O 0 v Y... j ° a 4 I 0 8 0 f o 0 © .y�p.0,, A G Qa° I •Bo 0 0 € a c a i ,. o 0 I— g ro a' a E a y Z 1 ihi. 4 O a a a .. Q -. O oe O_ o' °baa yaO 0 0 0 • ot, ~1 >- w Q o$ o w VI °_ t . --1 Q ALJ W h rn {I` f �:t4- 110°&.. CC re; 2 M �I as a ._ „♦ O .. ♦ s�e as • 4P 0 .2 au1 a� - CL Q oCe 7 n .IIII �� I i s 4 oa a - d°y —, a O = . Q 2 I q��4i: - a aIIIII t'.1 "Ilk YCe a it Q 1011 1 a Q m �■• . ° ,6.i.?„. �.a06 ■. L<I 040 1 O0 OA 0 ° y03 °. ' . • 4> V r ° • 0Q � CC o a ' oE ,* � ....-4 et ao t ' azIA"P — 4Pr oa a $ • -.-♦ W M •. CL CCI – S86t 0 0 0 0 0 4PP O O O O ei 00 O ,r0 0 -10 ei r-4 LOOM' .Iad JaleM lo siaiiee JO gluoAJ aad Ho to siaiie8 • Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Friday, November 17,2017 11:19 AM To: Loepp,Victoria T(DOA) Subject: Withdraw Sundry#317-001 17-11 PTD#184-244 Follow Up Flag: Follow up Flag Status: Flagged C. ( Victoria, Please withdraw sundry#317-001, plug for redrill 17-11 (PTD#184-244).The sundry will expire prior to our ability to start the work.We will submit a new sundry for plug for redrill this afternoon in replacement.The permit for 17-11A (PTD#217-001)will not expire before we begin the sidetrack. Please let me know if you have any questions. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 wo lefellif BP Exploration AlaskaI900 E. Benson Blvd.1Room: 788DlAnchorage, AK SCANNED .,. 1 RBC St,L. v 8 2517 STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMA, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate m Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 184-244 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21259-00-00 7. Property Designation(Lease Number): ADL 0028331 8. Well Name and Number: PBU 17-11 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 11505 RECEIVED Total Depth: measured feet Plugs measured feet true vertical 9228 feet Junk measured feet 2 2017 Effective Depth: measured 11455 feet Packer measured 10452 feet AUG�j U true vertical 9193 feet Packer true vertical 8408 feet OG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 35-113 35-113 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 10827 9-5/8"47#L-80 33-10860 33-8733 6870 4760 Production Liner 932 7"29#N-80 10558-11490 8489-9217 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 31-10644 31-8557 Packers and SSSV(type,measured and 4-1/2"BAKER S-3 PERM PACKER 10452 8408 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): y^, h' Treatment descriptions including volumes used and final pressure: SCANNED NOV V 0 22017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 114 610 5909 1747 309 Subsequent to operation: Shut-In 0 0 1805 225 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FSkEead P Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: „.„ Date: g/Z77 1 Contact Phone: +1 907 564 4594 RBDMS�MS �� AUG Form 10-404 Revised 04/2017 V TL /0/6 // � /,10, 252017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED AUG 222017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary August 22, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well 17-11, PTD # 184-244. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • nom, Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary August 18, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well 17-11, PTD # 184-244. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • NQ„o00000 R 1, 14) I"- CD N v. O Co Ps LC) G N V' I CO C.) N 0 0 0 0 0 0 a. 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L O a) a0 N CO C) ai N 3 C $ m .c to J N. -C CO +. t0 0 Q to • 0Cas •- rn :3UQ�' ON -a a,0 -a 0 o ' ` Q . o p a) Q -6Q O ' p C. m '3 0o ai J1- , -a = .Q eco d Q 0 U a) aoo ce Q U V N a c0 O 0- `- 2 U Di D a • NU o o i 0 c .0>+ a) o0o c - a • w0u O E .UCOJN � C ,Q J I- CU O 20 � N ' a) N a) o CO ,*, ,a ) 0C') iU) U) N � c0 0 y 0 `0r O CO a) u (13 mN- CON C) U VCOO- LL ' C C N 3 _ cNi _ Zw o O O �.,-a O '- 0 O W o C in• a. ? O � o Q J J C - 0 c o E Ccl) U 2 U -' = Cl) -0 Eo Y Y w N j J c O 7 N a) 't ' a) ) U) O C U Y _se a) v � 0 0da •• � c0 •30ao � c0Q. (CIa o � 2 D 't c' O J a) 0 D 't O 0 X N_ V`0 O 't ) to CT). Cn a) ai \ \ ci 0a. a0 J pi - 4t a2 aco o * � T- In w QN- 0 c Ln > N m N o 0 H 0 Q TREE= " McEVOY SSH • •WELLHEAD= MCEVOYSA NOTES: ""4-112"CHROME TBG"" (ACTUATOR= AXELSON -11 OKB.ELEV= 71' REF ELEV= 71' BF ELEV= 38 15' ' ' 2099' —14-1/2"HES X NIP,ID=3.813" KOP= 3700' Max Angle= 54"@ 7300' I Datum MD= 11027' GAS LFT MANDRELS Datum TVD= 8800'SS 13 3/8"CSG,72#, — 2508' ST MD TVD DEV TYPE VLV LATCH PORT DATE L-80,13=12.347" 6 3217 3217 0 WAG DOME RRC 16 10/24/16 5 4439 4385 31 MMG DMY RK 0 12/11/13 4 5911 5439 49 MMG SO RK 20 10/24/16 3 7445 6386 54 MMG DMY RK 0 12/11/13 2 8979 7333 46 MIG DMY RK 0 11/09/09 Minimum ID =3.726" @ 10610' 1 10233 8245 43 MMG DMY RK 0 11/09/09 4-1/2" HES XN NIPPLE ! ' ' 10419' —I4-112"1IMXNIR ID=3.813" ,' x ( 10440' H9-5/8"X 4-1/2"BKR S3 PKR D=3.875" ' ' 10464' —I4-1/2"FES X NP,D=3.813" TOP OF 7"LNR H 10556' ' ' 10610' 4-1/2"HES XN NP,ID=3.725" 14-1/2"TBG,12.6#,13CR-85,.0152 bpf,D=3.958" — 10632' / • 10632' 14-1/2"WLEG,D=3.958" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 10858' PERFORATION SUMMARY REF LOG BHCS ON 03/07/85 ANGLE AT TOP PERF:33°@ 10893' ' Note:Refer to Production DB for historical pert data SIZE SPF MTERVAL Opn/Sqz SHOT SQZ ' 6 10893-10916 S 04/26/91 3-3/8" 13 10893-10916 0 02/28/92 3-3/8" 4 10905-10907 0 07/19/91 3-3/8' 4 10924-10930 0 04/30/92 I 4 10930- 10935 0 04/30/92 3-3/8" 8 10935-10952 0 04/30/92 3-3/8" 4 10980- 10993 0 04/30/92 I 3-3/8" 1 11014- 11054 S 04/26/91 3-3/8" 5 11014-11054 0 07/19/91 3-3/8" 1 11066- 11118 S 04/26/91 3-3/8" 5 11066- 11118 0 07/19/91 ' 3-3/8" 4 11130- 11150 0 07/19/91 3-3/8" 1 11130- 11174 S 04/26/91 2-1/2" 2 11198-11206 0 02/18/08 3-3/8" 1/3 11198-11206 S 04/26/91 I 2-7/8" 6 11198- 11218 0 07/18/17 2-1/2" 2 11208- 11216 0 02/18/08 I 3-3/8" 1/4 11208-11216 S 04/26/91 2-7/8" 6 11220-11235 0 07/18/17 - 11350' H FLL&JUNK(04/12/05 DIMS) 3-3/8" 6 11250- 11266 0 05/03/05 — PBT ) --1 11449' 4♦ • .444441 17'LNR 29#,L-80,.0371 bpf,D=6.184' ,— 11488' a •4.111'..... .+1..1,..41 TO —{ 11505' •••••• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/11185 ORIGINAL COMPLETION 10/27/16 ZV/JM) GLV GO(10/24/16) WR I 17-11 02/16186 MNO 01/04/17 JNUJM) ADDED REF&BF ELEV PERMIT No 1842440 04/15105 NOES R#JO 07/24/17 AB/JM) ADPE FS(07/18/17) AR No: 50-029-21259-00 12/20/13 LEC/JM) GLV GO(12/11/13) SEC 22,T1ON,R15E,2710'FNL&1029'FW.. 06/14/16 Jt1/JM) GLV GO(06/12/16) 06/23/16 JM) LPDATEDCSG&LNR DEPTHS BP Exploration(Alaska) • 8,OF Tg g\��\ yyy� � THE STATE• Alaska Oil and Gas o Conservation Commission fALAsKA } 333 West Seventh Avenue /. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh' .--• ,. ..,_�_ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor BP Exploration (Alaska), Inc. SCANNED MAR '?.'? , P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-11 Permit to Drill Number: 184-244 Sundry Number: 317-001 Dear Mr. Egbejimba: 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 I ay of January, 2017. RBDMS Lc— JAN 2 5 2017 ED REPE STATE OF ALASKA I s • OLASKA OIL AND GAS CONSERVATION COMMION / f 3//7 APPLICATION FOR SUNDRY APPROVALS JAN 0 4 2U1( 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ AOGs GGIs El Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 . Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 / 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 184-244 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0• 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-21259-00-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No 0 PBU 17-11 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028331 • 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): 11505 • 9228 • 11350 9119 2525 11350' 3(Unknown) Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 2506 13-3/8" 35-2541 35-2541 4930 2670 Intermediate 10827 9-5/8" 33-10860 33-8732 6870 4760 Production Liner 932 7" 10558-11490 8489-9217 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10893-11266 8760-9057 4-1/2"12.6# 13Cr85 31-10644 Packers and SSSV Type: 4-1/2"BAKER S-3 PERM PACKER Packers and SSSV MD(ft)and ND(ft): 10452/8408 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: January 15,2017 15. Well Status after proposed work: • Oil 0 WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Leemhuis,Jacob be deviated from without prior written approval. Email Jacob.LeemhuisQbp.com Printed Name John Egbejimba Gar o. S},,,,tit,.v.r 1-0C Title Drilling Supervisor Signature � Phone +1 907 564 4139 Date I COMMISSION USE ONLY / Conditions of approval:Notify Commission so that Number a representative may witness Sundry at Plug Integrity 0 BOP Test 1( Mechanical Integrity Test 0 Location Clearance 0 Other: e U/J tl5 71- fp 3 5—C)Q p 5 t L �Y147 v 1 a r 1-�YC v-r-•0117-V �S l jLT� Z iO j�J 5 b� Post Initial Injection MIT Req'd? Yes 0 No ��� �,/�y Grp[/i�/G1I.5p_f�� 2 �}-•f-e 5 • I f z �"`-) Spacing Exception Required? Yes 0 No E Subsequent Form Required: /0- 4-13 ..7- P Date:/./3,/APPROVED BYTHE Approved by: COMMISSIONER COMMISSION 7 VTL 1 / 3//(' ORIGINAL RDDMS (/.JAS! 2. 52017 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. A chments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis 0 by CTD Engineer Date: January 4, 2017 Re: 17-11 Sundry Approval Request Sundry approval is requested to plug the 17-11 perforations as part of the preparation, drilling and completing the proposed 17-11A coiled tubing sidetrack. History of 17-11: 17-11 is a Rotary horizontal sidetrack which was drilled in 1985. The well had a RWO in 2005 and was re-perfed in 2008 to increase EOR offtake from 03-07A MIST Injection. 03-07A has plugged off • the perfs that were influencing 17-11 and started injecting uphole recently. Any future MI benefits from this interaction are minimal at best. The parent well-bores production will be retained in the sidetrack with perfs placed in the sump of the well plank Proposed plan for 17-11A: Drill a through tubing sidetrack with the Nabors CDR2 Coiled Tubing Drilling rig on or around February 19th, 2017. The 17-11A sidetrack will be a single string exit from the existing 7" liner. A 4-1/2" x 7" whipstock will be set pre-rig and cemented in place. 17-11A will target attic oil trapped along the large E-W fault just to the north of the pad targeting Z4 sands. The well will have one small undulation to crosscut the discontinuous Z4B shales. Well design involves kicking off a 7" delta whipstock, drilling build section with 18 DLS, drilling lateral with 12 DLS, run 3-1/2" x 3-1/4" x 2-7/8" 13Cr-85 production liner, cemented and perforated. This Sundry covers plugging the existing - 17-11 perforations via the cement squeeze and liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin January 15,2017) 1. E Set whipstock 2. C Mill XN Nipple to 3.80", squeeze cement/cement whipstock 3. V Set BPV. Pre-CTD tree work. Rig Work(scheduled to begin February 19, 2017) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,525 psi). 2. Mill 3.80"window and 10' of rathole. 3. Drill Build: 4.25" OH, -594' (18 deg DLS planned). 4. Drill Lateral: 4.25" OH, 2,141' (12 deg DLS planned). 5. Run 3-1/4"x 2-7/8" 13Cr-85 liner leaving TOL at-10,560' MD. 6. Pump primary cement job: 36.7 bbls, 15.3 ppg Class G, TOC at-10,560' MD. 7. Perform cleanout run if needed 8. Perform liner lap test*. 9. Perforate -500' 10. Freeze protect well to a min 2,100' TVDss. 11. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) L a r rut( /we..1/ ! ,� .-• /7-1( r 7l t-ff- g/ ✓?& .e-11(&-14-4. ,.5 ee"'f pteril 41-k(-C1- �✓ttc marc-�f2 ,^ j4 -a `t 7L' Vic../u� !rt t Oo c- tel veq( 4-ea-' -"re t ' 17-( ( Lde.-1( cQ b a.ccc� b..j { aJ �i f f'resal re-fid 17—/(,- , ve„.4 b./ Gem tt-dtui 5 l? /. S' /,"7\, t /-S-z /7 • Post-Rig Work: • 1. Pull TWC. Tree work as necessary. 2. Set liner top packer if liner lap test fails.* 3. Pressure Test LTP (if necessary) 4. ASRC flowback 5. SIT Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 7� fay ,r6�. Well ,�� r �- 2� e � 6+-i �� en�r obi'. 1 p�acvcT,,� Q 3 % /93 110,12Cli "i if r l 'rtee the p,Iie r- ,4W a warerevr over ecivc✓1`/ee 710 ,4/I or`CGw a0P Vrto TO 74e SA ecr well , 1 y , e` The S,'e/e r cccal 6e ge,-feel �€ i ft, (BCCI1eI ,ci/,4/✓,+c 1 '- - G7" 1-1c COlt e I— I0 eefft arl to,11rIC Ttle ilrel frV'l( 9/46 k 0,6/e to tee i‘r1© Ile i.. vw4, t4ti �' cvl�1 ll�, r ,•eV / le co-/e/), fro' 7-4, is � efwl. 1i.x2 TREE= AtEVOY SSH 018_11-1EAD= MbEVOY SA,NOTES: **4-112"CHROME TBG** ACTUATOR= AXELSON OKB.ELEV= 71' 'REF ELEV; ___. 71°. KOP=___�_._______._._3700' Max Angie= 54°@ 7300' Datum MD 11027' 2099' —14-1/2"HES X NP,D=3.813" Datum TVD= _— 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" —1 2508' —A GAS LFT MANDRELS ST MD I DEV TYPE VLV LATCH PORT DATE 6 3217 3217 0 MAG DOME RK 16 10/24/16 L5 4439 4385 31 WAG DMY RK 0 12/11/13 4 5911 5439 49 1 MG SO RK 20 10/24/16 3 7445 6386 54 MNG DMI' RK 0 12/11/13 2 8979 7333 46 MNG DMR' RK 0 11/09/09 1 10233 8245 43 MNG DMR' RK 0 11/09/09 Minimum ID =5.725" d(1 10610' I ' 10419' HI4-1/2"HES X NP,D=3.813" 4-1/2" HES XN NIPPLE 10440' H9-518x4-112'BKR S3 PKR D=3.875" I I 10464' —14-1/2"HES X NP,D=3.813" TOP OF 7"LNR —I 10556' 10610' H4-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR 85,.0152 bpf,0=3.958" H 10632' 10632' —I4-1/2"WLEG,D=3.958" 9-5/8"CSG,47#,L-80 BTC,ID J=8.681" - I 10858° , PERFORATION SUMMARY REF LOG:BRCS ON 03/07/85 ANGLE AT TOP FERE:33°@ 10893' Note:Refer to Production DB for historical perf data ' SIZE SFE INTERVAL Opn/Sqz SHOT SQZ ? 6 10893-10916 S 04/26/91 3-3/8" 13 10893-10916 0 02/28/92 3-3/8" 4 10905-10907 0 07/19/91 3-3/8" 4 10924-10930 0 04/30/92 4 10930-10935 0 04/30/92 3-3/8" 8 10935-10952 0 04/30/92 ' 3-3/8" 4 10980-10993 0 04/30/92 3-3/8" 1 11014-11054 S 04/26/91 3-3/8' 5 11014-11054 0 07/19/91 3-3/8" 1 11066-11118 S 04/26/91 ' 3-3/8" 5 11066-11118 0 07/19/91 3-3/8" 4 11130-11150 0 07/19/91 3-3/8" 1 11130-11174 S 04/26/91 2-1/2" 2 11198-11206 0 02/18/08 3-3/8" 1/3 11198-11206 S 04/26/91 ' 2-1/2" 2 11208-11216 0 02/18/08 3-3/8" 1/4 11208-11216 S 04/26/91 11350° --I FILL&JUNK(04/12/05 DIMS) 3-3/8" 6 11250-11266 0 05/03/05 — — PBTD H 11449' —- 7"LNR 29#,L-80,.0371 bpf,D=6.184" —I 11488' .'.'.'.'.'1'., .,.'.'.114 TD —I 11505' *At V DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 03/11/85 ORIGINAL COMPLETION 12/20/13 LEGJMD GLV GO(12/11/13) VVaL: 17-11 02/16/86 RWO 06/14/16 JMWJMD GLV GO(06/12/16) PERMIT No: 1842440 04/15/05 N4ES RWO 06/23/16 JMD UPDA I W CSG&LNR DEPTHS API Na: 50-029-21259-00 05/13/05 NBF/PJC PERFS 10/27/16 ZV/JMD GLV GO(10/24/16) SEC 22,T1ON,R15E,2710'FNL&1029'FVVL 06/14/05 RM-VPJC GLV GO 01/04/17 JNUJMD ADDED REF&BF ELEV 12/04/05 MUA/TLH DRLG DRAFT CORRECTIONS BP Exploration(Alaska) TREE= MLLI SAD= IuicEVOY SA (NOTES: **4-1/2"CHROME TBG* ACTUATOR= PROPORL 17-11 OKB.ELEV= 71' BF.ELEV= REV 1 KOP= 3700' Max Angle= °Q ' , ' 2099' ---I4-1/2"FES X NP,D=3.813" Datum LID Datum ND= 8800'SS GAS LIFT MANS 13-3/8"CSG,72#,L-80,D=12.347" H 2508' ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3217 3217 0 MMG DOME RK 5 4439 4385 31 MMG DOME RK Minimum ID = 4 5911 5439 49 MMG DOME RK 3 7445 6386 54 MMG DOME RK 2 8979 7333 46 MAG DOME RK 1 10233 8245 43 NM DOME RK I I 10419' H 4-1/2"HES X MP,D=3.813" 10440" H 9-5/8"X 4-1/2"BKR S3 PKR,D=3.875" I ' 10464' H 4-1/2"HES X NP,D=3.813" TOP OF 7"LNR —{ 10556' - — TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNIZ —{ 10560° 10560' —13.70"DEPLOYMENT SLEEVE,ID=3.00" ' r---1 10610' —14-1/2"HES XN NP MLL®TO 3.80'(_/ / ) BEHIND CT LNR —13.50"X NP 4-1/2"TBG, 12.6#,13CR-85,.0152 bpf,D=3.958" H 10632' ` 10632' —14-1/2"WLEG,D=3.958"BEHIND CT LNR 9-5/8"CSG,47#,L-80 BTC,ID=8.681" — 10858' I 10870' H 3-1/2"X 3-1/4"XO,D=2.786" 3 1/2"LNR, #,13CR-85 STL, — 108,> 1"MLLOUT WINDOW(17-11A) ' • 7"X 4-1/2"DELTA WHPSTOC K( l 1 } H '10900' 7"LNR,29#,L-80,.0371 bpf,D=6.184" H —10906:x" 3-1/4"LNR,6.6#,13CR-85 TC11,.0079 bpf,ID —I 12000" 2.85" 12000" —13-114"X 2-7/8"XO,D=2.377' PERFORATION SUINIAARY REF LOG: ON XX/XX/XX ANGLE AT TOP FERE:°@' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE Sn7 PBTD — 2-7/8"LNR,6.5#,13CR 85 STL,.0058 bpf,D H 13700' 2.441" j�1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY [NT 03/11/85 ORIGINAL COMPLETION I W_ I.)PDA IED DEPTHS WELL: 17-11 02/16/86 RWO FERMI No: 04/15/05 N4ES RWO AR No: 50-029-21259-0 CTD(17-11A) SEC 22,T1 ON,R15E,2710'FNL&1029'FWL 36/23/16 !MD BOLT PROPOSED `16/27/16 JUJMD PROPOSED REV 1 BP Exploration(Alaska) Well Blank •DR2-AC BOP Schematic *Date Quick Test Sub to Otis -1.1 ft Topof7"Otis �4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular I 0.0 ft., y ►� l� 7-1116"5k Flange X 7"Otis Box Hydril 7 1/16" >f,..„:),/-- Top Annular Element 0.7 ft Annular i Bottom Annular 2.0 ft ► -oonb Blind/Shear CL Blind/Shears 3.3 ft ► a211 • • 23/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft B5 I B6 " " :7 . . B8 Deployment Line " ® -. �;`/ Sk Mud.� 7-1/16" E lar."7-)I- YiY f "" .► Cross • • .. � Ill „.Cross. Ill choke Line 3"Slips CL 3"Slips 6.6 ft ► 2-3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft ► B1 �. _ B2 B3 � B4 Kill Line t ;— ♦ , ♦ r ET 111 Blind/Shear III CL Blind/Shears 10.0 ftIIH► AIP 2-3/8"Pipe/Slips II/ CL 2-3/8"Combi's 10.7 ft �AP rye- ♦ • CL of Top Swab 13.3 ft —Swab 2 Test Pump Hose 4/Swab 1 CL of Bottom Swab 14.8 ft T1 / T2 CL Flow Tee 16.2 ft - ��• - BOP2 CL of SSV L 17.5 ft • _ I Master 2 Fusable CL of Master Valve 19.0 ft BOP1 Master 1 LDS 20.5 ft —__►._ _ t_1 II I. .1 II n u o d Ii Gound Level • 46. II II II II II I < • • 0 N Produced Gas (Thousand Cubic Feet ("MCF") per Day) andLn Gas-Oil Ratio (MCF per Barrel) 0 0 0 0 0 0 0 0 ro cc O' to0 in cr M N O Oi r —aft. �r;7: C9 1: ' ,_.:67------7*;:. - i '92'": 41 miim...._. _Eo isiro FrT o t : ::: : 0 G O ., •0 CO _.41 — _-- G6:0 O 0 Q Ce �O' l -:r P 0 o N — u it ick 4l a 44. fa XIIli 0 4P/;O Y •(13- T 0 Ln eM-1 �i Oo, l0 P — - O r -•---_ o c O o0 4 a N e-i is P,- - o CO M 01 Q P r -° ti ui to .-_�' �C 4i O , to .....• 1 C c'0 2 l' 1 v l�Pel o I li = u 3 _ 4P O a; ll V a d � 66 i2' its a 8 G U 0 P 0 m ,; a a 3 = �6e,e.r0 a -0 — o 41 V V - 96 �I ° o_ b.O GPiO ~ °4 6 lII Q L- �' GPO Y ro > �6G410 c �; 6N4 o Q >; 6G l0 u e' ice. �'c lle 0 0 >- It a l6 it v o GPO o �~ 6GP 6to SGr0 0 P 86 it a- P en P o o 0 0 0 0 0 0 0 0,X 2 o a oo ist0 to M N c•1 Aea aad JaleM jo slane8 pue Aea . ad l!O Jo sla.i.ie8 w 0 a ® • Davies, Stephen F (DOA) From: Leemhuis, Jacob <Jacob.Leemhuis@bp.com> Sent: Thursday, January 5, 2017 11:37 AM To: Davies, Stephen F (DOA) Subject: Re: PBU 17-11 (PTD #184-244, Sundry Application #317-001) - Question Steve, I can see how that is confusing. Basically what I was trying to say was the original wellbore perfs will be P&Ad via cement squeeze and production liner cement, however we can still regain that production near the parent wellbore by perfing the heel of the new sidetrack. Thanks, Jacob C. Leemhuis Drilling Engineer CTD/ RWO C: (907) 223-6792 0: (907) 564-4989 On Jan 5, 2017, at 11:30 AM, Davies, Stephen F (DOA) <steve.davies@alaska.gpv>wrote: Jacob, The cover letter for BP's application for Sundry Approval contains this sentence: "The parent well-bores production will be retained in the sidetrack with perfs placed in the sump of the well plan." What does that sentence mean? Will any of the perforations that are currently open in well PBU 17-11 will be left open to production after drilling of the next planned wellbore? If so,that planned wellbore will be classified as a lateral well branch rather than a redrill. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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.daviesPalaska.gov. 1 • # Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 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 "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 1/ 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, they 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, they 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, they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ect Well History File Covel~bge 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. Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes. No. [] Maps: [] Grayscale items: n Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BREN VINCENT SHERYL MARIA LOWELL Other items scannable by large scanner OVERSIZED (Non-Scannable) D. Logs of various kinds [] Other Project Proofing BY: BEVERLY B~HERYL MARIA LOWELL Scanning Preparation x 30 = /~'- ~)+ BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Production Scanning Stage, PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~. YES_ NO STAGE 1, PAGE(S} DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: Is~ Quality Checked Pglt / 7 --t( • • PTO 1 84 Z/4 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] io ( Sent: Thursday, October 11, 2012 6:22 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Oestgaard, Finn Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: Producer 17 -11 (PTD #1842440) MIT -IA Passed All, Producer 17 -11 (PTD # 1842440) passed an MIT -IA after dummy gas lift valves were set. The passing test confirms two competent barriers in the wellbore and the well is reclassified to Operable Thank you, Mehreen Vazir SCANNED APR 0 9 2093 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Sunday, September 16, 2012 8:32 PM . To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Oestgaar I, Finn Cc: Walker, Greg (D &C); AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producer 17 -11 (PTD #1842440) Sustained IA Casing Pressure Over MOASP All, Producer 17 -11 (PTD #1842440) has confirmed sustained casing pressure on the above MOASP. The tubing /IA /OA were equal to 311/2100/340 psi on 09/13/2012. The well is recta'ssified as Under Evaluation and may be placed on production for diagnostics. The plan forward: 1. Operations: Put well on production 2. Downhole Diagnostics: TIFL 3. Well Integrity Engineer: Evaluate GLV change out 'ending TIFL results A TIO plot and wellbore schematic are attached for eference: « File: 17 - 11 TIO Plot 09 16 12.docx » « F' : 17 11.pdf » Thank you, 1 • • �t1 7 - II PrO 1 44o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator ©bp.com] 11 Z Sent: Sunday, September 16, 2012 8:32 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Oestgaard, Finn Cc: Walker, Greg (D &C); AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producer 17 -11 (PTD #1842440) Sustained IA Casing Pressure Over MOASP Attachments: 17 -11 TIO Plot 09- 16- 12.docx; 17- 11.pdf All, ✓ . Producer 17 -11 (PTD #1842440) has confirmed sustained casing pressure on the IA above MOASP. The tubing /IA /OA were equal to 311/2100/340 psi on 09/13/2012. The well is reclassified as Under Evaluation and may be placed on production for diagnostics. The plan forward: `NV`�` ti 1. Operations: Put well on production 2. Downhole Diagnostics: TIFL 3. Well Integrity Engineer: Evaluate GLV change out pending TIFL results A TIO plot and wellbore schematic are attached for reference: �A- SO' «17 -11 TIO Plot 09- 16- 12.docx» «17- 11.pdf» 5C'P "it co Fs," Thank you, A/1ryr : 6 - 743f-5; Mehreen V zir = 3a , BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator (a)BP.com 1 PBU 17 -11 PTD #1842440 9/16/2012 TIO Pressures Plot Well'. 17 -11 ' ?000 - • — 411 — Tu 2,0O0 �, • • • • - J•• IA --A-- OA OOA 000A —On 1.000- • • • 06+16"12 066112 0630!12 07107;12 07'14/12 07/2112 07,2812 08;6112 0811112 08/1812 08/25,12 09/01112 04/08+12 09/15/12 TREE = McEV OY SSH SAFETY NOTES: * *4 -1 /2" CHROME TBG** _ WELLHEAD: McEVOY 1 7 11 ACTUATOR= AXE LSON KB. ELEV = 71' BF. ELEV KOP = 3700' Max Angle = 54 @ 7300' Datum MD= 11027' 2099' 1-14-1/2" HES X NIP, ID = 3.813" Datum TV D = 8800' SS 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 1-1 2508' - GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE L 6 3217 3217 0 MMG DOME RK 16 11/09/09 5 4439 4385 31 MMG DMY RK 0 04/12/05 4 5911 5439 49 MMG DOME RK 16 11/09/09 3 7445 6386 54 MMG SO RK 22 11/09/09 2 8979 7333 46 MMG DMY RK 0 11/09/09 Minimum ID = 3.725" @ 10610' 1 10233 8245 43 MMG DMY RK 0 11/09/09 4-1/2" HES XN NIPPLE 1 1 10419' H 4-1/2" HES X NIP, ID = 3.813" I g g ---i 10440' 1-19 -518" X 4 -1 /2" BKR S3 PKR, ID = 3.875" 1 I I 10464' 1-1 -1 /2" HES X NIP, ID = 3.813" 1 I TOP OF 7" LNR 1'-1 10550' I � I I 10610' 1- � 4 -1/2" HES XN NIP, ID = 3.725" 1 14 -1/2" TBG, 12.6 #, 13CR -85, .0152 bpf, ID = 3.958" H 10632' 10632' H 4-1/2" WLEG, ID = 3.958" 9 -5/8" CSG, 474, L -80, ID = 8.681" H 10861' (_4 b. M3WP = 68 '7n (X21 PERFORATION SUMMARY REF LOG: BHCS ON 03/07/85 ' ANGLE AT TOP PERF: 33 @10893' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ? 6 10893 - 10916 S 04/26/91 3 -3/8" 13 10893 - 10916 0 02/28/92 3 -3/8" 4 10905 - 10907 0 07/19/91 3 -3/8" 4 10924 - 10930 0 04/30/92 4 10930 - 10935 0 04/30/92 3 -3/8" 8 10935 - 10952 0 04/30/92 I 3 -3/8" 4 10980 - 10993 0 04/30/92 3 -3/8" 1 11014 - 11054 S 04/26/91 3 -3/8" 5 11014 - 11054 0 07/19/91 3 -3/8" 1 11066 - 11118 S 04/26/91 I 3 -3/8" 5 11066 - 11118 S 04/26/91 3 -3/8" 4 11130 - 11150 0 07/19/91 3 -3/8" 1 11130 - 11174 5 04/26/91 ' 2 -1/2" 2 11198 - 11206 0 02/18/08 3 -3/8" 1/3 11198 - 11206 S 04/26/91 2 -1/2" 2 11208 - 11216 0 02/18/08 3-3/8" 1/4 11208 - 11216 S 04/26/91 L 11350' H FILL & JUNK (04/12/05 DIMS) 1 3 -3/8" 6 11250 - 11266 S 05/03/05 PBTD H 11449' ►IN1f!' 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 11488' + + + + + + + + + TD H 11505' . d. . . . . DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/11/85 ORIGINAL COMPLETION 02/08/08 GS /PJC WLEG MIN ID CORRECTION WELL: 17 -11 02/16/86 RWO 11/11/09 BSE/SV GLV 0/0 PERMIT No: 1842440 04/15/05 N4ES RWO API No: 50- 029 - 21259 -00 05/13/05 NBF /PJC PERFS SEC 22, T1 ON, R15E, 4700.31' FEL & 2682.68' FNL 06/14/05 RMH /PJC GLV 0/0 12/04/05 MJA /TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) ~~ 1Q~ lpu~ ~~v4K ~b Eal,l~ ~ ~~ ~ o`~~ 04,2,,,0 schlu~~rger NO. 5511 Alaska Data & Consulting Services Company: State of Alaska ~g~~~;, 2526 6ambell Slreat, Guile 400 a Anchorage, AK 99603.2938 Alaska Oil & Gas Cons Comm ATTN: Beth Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F-30 BBUO-00014 PRODUCTION PROFILE 03/1 / 12-14AL1 12.15 AYKP•00079 8380.00049 PRODUCTION PROFILE PRODUCTKN PROFILE 7 10 03/16/10 1 1 1 1 17-11 17-05 J•23A 8950.00059 8350.00052 BCUE•00010 PRODIICTK)N PROFN.E ~- PRODUCTION PROFILE MEM PRODUCTION PROFIL ! 03118/10 03/90110 09/29/10 1 1 1 1 1 1 07-18 BC72.00008 FL DETERMINATKNVIPERF LE OM14/10 04/17H0 04/14/10 1 1 1 1 1 1 P2-31A 83S0-00046 - CH EDIT POC JUN 04/17/10 1 i C-15A K-07E 01-28A AWJI.00089 B2NJ-00054 BAUJ-00004 K BASKET MCNL ~ ~ MCNL MCNL ~ 02/27/20 01127/10 02/18/10 12/18/09 1 1 1 1 1 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TO: - • ~.y,rv,ou~,,, \n,aaM) 1114. Petrolechnfcal Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Slreel, Suite 400 Anchorage, AK 99503-2838 • • Y t~::a' i ~~ ~ ~ 4 V ~a V Scdlu~berger Alaska Data & Consulting Services 2525 Gambell Street, Suba 400 Anchorage, AK 91)503-2836 ATTN: Beth Well Job A log Description Date. Alaska Data & Consulting Services 2525 Gambell Street, Suae 400 Anchorage, AK 99503-2838 P2-31A 5-134 P2-31A BBKA-00014 AP30-00083 8148-00101 CEMENT BOND LOG INJECTION PROFILE UI USIT (j - 03/16/10 03/26/10 03/27!10 1 1 1 1 1 1 03-22 17-078 17-OS B5JN-00047 BD88-00007 83S0-00052 PRODUCTION PROFILE MEM PRODUCTION PROFILE c ) PRODUCTION PROFILE 03/28/10 03/28/10 03/29/10 1 1 1 1 1 1 17-11 03-22 14-32 B3S0-00053 B5JN-00047 BAUJ-00012 PRODUCTION PROFILE RST/JEWELRY LOG MEM PRODUCTION PROFILE 03/30M0 03/30/10 03/31/10 1 1 1 1 1 1 W-25A AWYZ-00004 CH EDIT PDC DDL 12/08/09 1 --- - -- ---------r_.._._...-..-_-"---.. _...-...... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. `, -J. _. N0.5495 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 Wesi 7th Ave, Suite 100 Anchorage, AK 98501 BL Color CD 04/05/10 ., _ ..` l~~'R ~~~ 2010 C~ C~ b ~6A4-f0 ee l~da® ~~~ ~~~,~~ STATE OF ALASKA °2/ ~~ FEB 2 4 2008 ALA~A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS~~askaDil ~ Gas Gdns. Commissi4rl Anrhnran~s 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 Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development a~ Exploratory 184-2440 ' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21259-00-00~ 7. KB Elevation (ft): 9. Well Name and Number: 71 KB - PBU 17-11 ` 8. Property Designation: 10. Field/Pool(s): ADLO-028331 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11505 ~ feet Plugs (measured) None true vertical 9227.99 ~ feet Junk (measured) 11350' 4/12/05 Effective Depth measured 11455 feet true vertical 9193 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 SURFACE 2477 13-3/8" 72# L-80 31 - 2508 31 - 2508 4930 2670 PRODUCTION 10831 9-5/8" 47# L-80 30 - 10861 30 - 8733 6870 4760 LINER 938 7" 29# L-80 10550 - 11488 8483 - 9216 8160 7020 i/11y~~~6~r1.' S ~L1 .4, ~ 2008 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 29 - 10642 0 0 __ _ - Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 10450 5-1/2" BOT 3-H Packer 10504 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): `T~~la7 ~~.- raj' ~ " ,!~~~ 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: 159 828 2232 262 Subsequent to operation: 152 811 2219 265 14. Attachments: 15. Well Class after proposed work: Copies of Logs and surveys Run Exploratory ~ Development `` Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG f ' GINJ ~ WINJ (~" WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ s_ Phone 564-4944 Date 2/20/2008 Form 10-404 Revised 04/2006 ~~;J,} - Submit Original Only 17-11 184-2440 Perforations Attachment Perforation Depth MD (ft) Opn/Sqz Perforation Depth TVD (ft) 10893-10905 O 8760-8770 10893-10916 SQZ 8760-8779 10905-10907 O 8770-8772 10907-10916 O 8772-8779 10924-10930 O 8786-8791 10930-10935 O 8791-8795 10935-10952 O 8795-8809 10980-10993 O 8832-8843 1 1 01 4-1 1 054 O 8860-8893 1 1 066-1 1 1 1 8 O 8902-8944 1 1 1 30-1 1 1 50 O 8953-8988 1 1 1 30-1 1 1 74 SQZ 8953-8988 1 1 1 50-1 1 1 74 O 8969-8988 1 1 1 98-1 1 206 O 9006-9012 1 1 208-1 1 21 6 O 9014-9020 1 1 250-1 1 266 O 9045-9057 • • 17-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/17/2008 ~**WELL FLOWING UPON ARRIVAL"** INITIAL T/I/O = 1500/1600/150 PSI 2 PERF GUN RUNS. ALL PERFORATIONS MADE WITH 2.5" POWERJET OMEGA 6SPF, 60 DEG PHASE, 30.6" PENETRATION, 0.32" ENTRANCE HOLE. .'COULD NOT GET DOWN DEEP ENOUGH ON FIRST RUN FOR ADD-PERFS -FROM 11224'-11234'. TD FOUND AT 11230'. ADPERFS NOT SHOT. USED SLB CET LOG DATED 23 MARCH 85 FOR TIE IN (+0' TO TIE IN LOG TO =REFERENCE LOG -SLB BHCS DATED 07 MAR 85) i POOH WITH LIVE GUN. ***AWGRS CONTINUED ON 18 FEB 08*'`* 2/18/2008 *""CONTINUED FROM PREVIOUS DAY*** 'INITIAL T/I/O = 1850/1950/0 PSI '2 PERF GUN RUNS IN TOTAL. GUN #1 RUN NOT ABLE TO FALL BELOW ::10230'. ';GUN #2 RE-PERFS MADE AT:11198'-11206', 11208'-11216' ', 'ALL PERFORATIONS MADE WITH 2.5" POWERJET OMEGA 6SPF, 60 DEG ''PHASE, 30.6" PENETRATION, 0.32" ENTRANCE HOLE. 'USED SLB CET LOG DATED 23 MARCH 85 FOR TIE IN (+0' TO TIE IN LOG TO =REFERENCE LOG -SLB BHCS DATED 07 MAR 85) ;FINAL T/I/O = 1850/1915/0 PSI JOB COMPLETE. DSO CALLED. ': """WELL LEFT W ITH W ING VALVE OPEN*** FLUIDS PUMPED BBLS 1 diesel 1 Total 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .-' E', ~\I E l~'~ \ JUN 2 1 2005 RepairWellD Pull Tubing 0 Operation Shutdown 0 t'I. ~',\I\ì"~'~ Oi~ &. ~~; G.Q.J;!:~~.. f:C~tll¡;Ü,J1WI;.¡ç¡¡, Ullleru ' Æ\, \~¡f' ~'Ii \I~(I~I? Time Ext~H~iöh~U ,I ., Re-enter Suspended WellD 5. Permit to Drill Number: 184-2440 6. API Number 50-029-21259-00-00 Pluç¡ Perforations 0 Perforate New Pool D Perforate IXI Stimulate 0 WaiverD 4. Current Well Class: Development [!] BP Exploration (Alaska), Inc. Total Depth measured 11505 feet true vertical 9228.0 feet Effective Depth measured 11455 feet true vertical 9192.9 feet P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.00 8. Property Designation: ADL-028331 11. Present Well Condition Summary: Casing CONDUCTOR SURFACE PRODUCTION LINER Length 80 2477 10831 938 Perforation depth: Exploratory 0 StratigraphicD ServiceD 9. Well Name and Number: 17-11 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Plugs (measured) None Junk (measured) Rig WO --- FCO to 11350 (04/12/2005) Frac Sand --- Tagged TD @ 11283 (05/04/2005) Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 MD TVD Burst Collapse 32 112 32.0 112.0 1490 470 31 - 2508 31.0 - 2508.0 4930 2670 30 . 10861 30.0 - 8733.2 6870 4760 10550 - 11488 8483.0 - 9216.0 8160 7020 Measured depth: 10893-10916,10924-10952,10980-10993, 11014-11054, 11130-11150, 11250-11266 True vertical depth: 8760-8779,8786-8809,8832-8843,8860-8893, 8953-8969, 9045-9057 SCANNED ,JUL 0 7 2005 Tubinç¡ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 29 10642 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 10450 4-1/2" HES X Nipple @ 2099 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne Schnorr Printed Name DeWayne Schnorr Signature A-'...tYt~~ j <J~~ t-orm 1 0-404 HeVlse~ 4/;¿004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations _ RBDMS BFL JUN 2 2 2005 Oil-Bbl 88 88 Representative Dailv AveraQe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 260 251 262 246 3192 3005 ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: N/A Development ŒJ Service D Title Petroleum Engineer Phone C) F~ ì (~:; ~ ~\~ jÜ\ I 564-517 4 Date 6/16/05 ) ') 17-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/04/05 PERFORATED FROM 11250'·11266' WITH 3-3/8" POWERJETS, COULD NOT PERFORATE ENTIRE INTERVAL DUE TO SHALLOW TAG DEPTH, -11,283' ELM. FRAC SAND FOUND IMPACTED ON BOTTOM OF GUN. FLUIDS PUMPED BBLS o No Fluids Pumped o TOTAL Page 1 , TREE = McEvoy G3 'WELLHEAD = McEvoy ÃcrûÄToï=f;;"'· "'ÄxELsON t"".."",..,.."""""..,..,.."""....""""" KB. ELEV = 71' BF. ELEV =_N____ ~('Ö·p";"'.. .. , .. '''3'7CjÖ' ..."n,. ."..,.,..."..,,,,,,,,,.,,,,..,,...... ...WI.I\'?"..,I".',...,'..-.\\,..,....('.. ~~~~~~I~~ 54 @ 7300' DatumMb = 11Ó27' .."",,,,,,,,,.......,...,,,..,..,..',,...,,.. <0 .."". ......",,,,,..,,,,,,....,. "',' Datum TVD = 8800' SS ) FR 17-11 SP DRL ~ DRAFT r NOTES: 4-1/2" CHROME TBG . . 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2508' I~ L Min. ID = 3.725" @ 10610' 4-1/2" HES XN Nipple . . :8: :8: . I TOPOF 7" LNR 1-1 10550' 1 'I .. 10632' I-------ji l~ 14-1/2" TBG 12.6#, 13Cr-80, ,0152 bpf, ID = 3.958" 1-1 I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 10861' I---M ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/07/85 ANGLE AT TOP PERF: 33 @10893' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE ? 6 10893 - 10916 S 04/26/91 3-3/8" 13 10893 - 10916 0 02/28/92 3-3/8" 4 10905 - 10907 0 07/19/91 3-3/8" 4 10924 - 10930 0 04/30/92 4 10930 - 10935 0 04/30/92 8 10935 - 10952 0 04/30/92 4 10980 - 10993 0 04/30/92 1 11014 - 11054 S 04/26/91 5 11014-11054 0 07/19/91 1 11066 - 11118 S 04/26/91 5 11 066 - 11118 S 04/26/91 4 11130-11150 0 07/19/91 1 11130-11174 S 04/26/91 1/3 11198 - 11206 S 04/26/91 1/4 11208-11216 S 04/26/91 6 11250 - 11266 0 5/13/2005 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" I PBTO 1-1 11449' ~ ~~ I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6,184" 1-1 11488' DATE 03/11/85 02/16/86 04/12/05 04/26/05 04/28/05 05/13/05 REV BY COMMENTS ORIGINAL COM PLETION RWO RWO /TLH CORRECTIONS KSB/TLH GL V C/O (04/25/05) NBF/PJC PERFS REV BY COMMENTS DATE 2099' 1-1 4-1/2" HES "X" NIP, ID= 3.813" GAS LIFT MANDRELS ~ ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 6 3217 3217 0 MMG DOME RK 16 04/25/05 5 4439 4385 31 MMG DMY RK 0 04/12/05 4 5911 5439 49 MMG DOME RK 16 04/25/05 3 7445 6386 54 MMG DMY RK 0 04/12/05 2 8979 7333 46 MMG DOME RK 16 04/25/05 1 10233 8245 43 MMG SO RK 22 04/25/05 10419' 1-1 4-1/2" HES "X" NIP, ID= 3.813" 10440' 1-1 4-1/2" x 9-5/8" BKR S-3 , D= 3.875" 10464 ' 1-1 4-1/2" HES "X" NIP, D= 3.813" 10610' 1-1 4-1/2"HESXNNIP, ID = 3.725" 1 10632' 1-1 4-1/2" WLEG .. Zone :3 Add-Perfs '11230' - 11290' I -11350' 1-1 ASSORTED FISH & FILL PRUDHOE BA Y UNIT WELL: 17-11 PERMIT No: "'1842440 API No: 50-029-21259-00 SEC 22, T10N. R15E, 4700.31' FEL & 2682.68' FNL BP Exploration (Alaska) STATE OF ALASKA '\ ALASKA JL AND GAS CONSERVATION Cc....MISSIOiRECEIVED REPORT OF SUNDRY WELL OPERATIOfi§ 042005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028331 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structu ral Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): Alaska 01' & Gu~ CDna. Cgmmission AJJJ~ 181 Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 71' 11505 9228 11350 9119 110' 25081 10861' 937' o Time Extension 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 184-244 6. API Number: 50-029-21259-00-00 99519-6612 9. Well Name and Number: PBU 17-11 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 11350 feet Size MD TVD Burst Collapse 2011 110' 110' 1490 470 13-3/811 2508' 2508' 4930 2670 9-5/811 10861' 8733' 6870 4760 7" 1 0550' - 11487' 8483' - 9215' 8160 7020 SCANNED MAY 1 1 2005 10893' - 11150' 8760' - 8969' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Printed Name Terrie Hubble Signature /~ t, J Mez Form 10-404 Revised 04/2004 4-1/2", 12.6# 13Cr85 10632' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/811 x 4-1/211 Baker 'S-3' packer; 4-1/211 HES 'X' Nipple 10440' 2099' Treatment description including volumes used and final pressure: RBDMS BFL MAYO 9 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure 3,191 4,258 1,224 2,770 4,661 1,797 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A 13. Tubinq Pressure 251 256 Oil-Bbl Prior to well operation: 243 Subsequent to operation: 233 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Title Technical Assistant Phone OS /.Ö. 2. / Prepared By Name/Number: Date IC ~I n~ Terrie Hubble, 564-4628 Submit Original Only 564-4628 r)R\G1NAI ) ) Well: Field: API: Permit: 17-11 Rig Workover Prudhoe Bay Unit 50-029-21259-00-00 184-244 Accept: Spud: Release: Rig: 03/13/05 N/A 03/25/05 Nabors 4ES Accept: Spud: Release: Rig: 04/09/05 N/A 04/15/05 Nabors 4ES PRE-RIG WORK 12/22/04 RIH WI 4.5 CENT, TAG PATCH AT 10,368' SLM. POOH. 12/23/04 RIH W/3 3/8 DUMMY GUN, DRIFT DOWN TO 10,600' SLM. POOH. 02/26/05 SET 3.0" BAKER IBP MID ELEMENT AT 10557' ELMO. FISHING NECK 1.75 OD - 5500 TO PULL RELEASE - 2X6" RUBBER ELEMENTS. 03/03/05 RIH WI 3.5 LIB, SET DOWN AT PATCH AT 10,378' SLM. IMPRESSION OF THREADS AND HEAD OF BOLT. RIH WITH 3" LIB AND 3.625" CENT. ABLE TO JAR THRU PATCH. SET DOWN AT 10,463' SLM. POOH. LIB SHOW LOST KOT KICK SPRING ASSY. RUN 3.75" BRUSH WI 2.75" GAUGE RING. SET DOWN AT 10537' SLM. RIH WI 2.75 LIB SET DOWN AT 10537' SLM, LIB SHOWS FN OF IBP. CALL OUT PDS AND LRS FOR STP LOG. 03/04/05 RIH WI PDS STP LOG, LOG ABOVE IBP TO PACKER WHILE PUMPING DOWN TBG AT 2 BPM. TBG PRESSURED UP TO 2500 PSI. IA TRACKING AT 1900 PS. DISCONTINUE PUMPING, LOG OOH. TREE. HANGER STARTED LEAKING OUT THË CONTROL LINE PORT. UNABLE TO PERFORM CMIT T X IA UNTIL' REPAIRED. BLEED WELL DOWN TO ZERO. (GOOD DATA FROM PDS) 03/07/05 RAN 6 STRANDS OF 6' STRING SHOT ACROSS BOT PKR (10480' -10486'). TBG PUNCH (10268' -10270') 2 STRANDS, 12' STRING SHOT (10355' -10367'). CHEMICAL CUT TBG AT 10366' ELMD (MIDDLE OF FIRST FULL JOINT ABOVE PATCH). ) ) BPEXPLORA TION ···.O.pe.~~t·io.l1.s...·.~·u·l'11.m.a.ry···.Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 bate Fr6rn~ To Hours Task 3/912005 18:00 - 00:00 6.00 RIGD N WAIT PRE Continue to wait on weather, roads to be cleared of snow & the go ahead from roads & pads & security to move the rig. 3/10/2005 00:00 - 06:00 6.00 RIGD N WAIT PRE Continue to wait for wind to subside, snow to be cleared from roads" OK given by security to commence with rig move from Milne Pt F Pad to DS 17. 06:00 - 00:00 18.00 RIGD N WAIT PRE Continue to wait on weather. Weather upgraded to Phase III in MPU @ 19:15 hrs. 3/11/2005 00:00 - 06:00 6.00 RIGD N WAIT PRE Continue to wait on weather. Phase III conditions in MPU @ 06:00 hrs. 06:00 - 00:00 18.00 RIGD N WAIT PRE Continue to wait. Weather subsiding. Downgraded to Phase I level II opn pads @ 08:30. Continue wI snow removal. 3/12/2005 00:00 - 06:00 6.00 RIGD N WAIT PRE Wait on snow removal, still level II on pads. 06:00 - 09:00 3.00 RIGD N WAIT PRE Wait on OK from Roads & Pads I Security. OK given by Mike Calloway. Rig released off of stand by @ 09:00 hrs. 09:00 - 12:00 3.00 RIGD P PRE PJSM. Scope down & layo over derrick. Rig down rig components. 12:00 - 00:00 12.00 MOB P PRE PJSM. Commence rig move to DS 17. 3/13/2005 00:00 - 05:00 5.00 MOB P PRE Continue moving rig. Blew a tire, change same. 05:00 - 15:00 10.00 MOB P PRE Continue moving rig. 49 mile move. Rig & rig components on location. 15:00 - 17:00 2.00 MOB P PRE PJSM. Rig up on 17-11. Note: Rig accepted for well work at 17:00 hrs. 17:00 - 20:00 3.00 KILL P DECOMP Take on heated seawater. R/U secondary annulus valve. R/U and test lines. 20:00 - 21 :30 1.50 KILL P DECOMP R/U DSM. Pull BPV. RID DSM. 21 :30 - 22:00 0.50 KILL P DECOMP PJSM with crew regarding upcoming displacement operation. Discussed H2S potentials and risks. 22:00 - 00:00 2.00 KILL P DECOMP Open well, annulus and tbg on vac. Circulate out freeze protection taking returns to tiger tank. No gas encountered. Reverse circulated heated seawater till 1 % KCI returned (80 bbls pumped to get returns) at 4 bpm, 230 psi. Pump down tbg 5 bpm, 300 psi till returns cleaned to seawater. Total 467 bbfs pumped. 3/14/2005 00:00 - 00:30 0.50 KILL P DECOMP Monitor well. Dead. 00:30 - 01 :00 0.50 WHSUR P DECOMP Install TWC and test same. 01 :00 - 03:30 2.50 WHSUR P DECOMP ND tree. 03:30 - 08:00 4.50 BOPSUP P DECOMP NU BOPE. Change pipe rams to 3.5" x 6". 08:00 - 16:00 8.00 BOPSUF P DECOMP PJSM. Commence test on BOPE. Testing witnessed by AOGCC rep Jeff Jones, Nabors Tool Pusher & BP Company Man. Leak in Cameron test insert, (blanking plug), in hanger, pull & replace innards. Continue with test. Flange on #5 valve leaked, tighten up same, OK. Complete test on all choke valves & surafce equipment except 31/2" x 6" VBRs. No other failures. 16:00 - 18:00 2.00 BOPSUF P DECOMP PJSM. Pull blanking plug. M/U landing joint. BOLDs. Pull hanger to floor, 165K up wt. 22 bbls to fill the hole. UD hanger. 18:00 - 22:00 4.00 BOPSUP P DECOMP MU test plug in string and land same. RILDS. Attempt to test 3 1/2" x 6" variable rams. Test failed. Re-dressed test plug. Re-test pipe rams to 250 psi 10 I 3500 psi high. Good test. Test witnessed by AOGCC rep, Nabors Toolpusher and BP Company Rep. 22:00 - 23:30 1.50 BOPSUP P DECOMP RD test equipment. NU blind flange and test same, good test. Printed: 3/28/2005 8:05:49 AM ) ) BPE)(PL()RATION ·p.pør~t.ic).º!;···$.u.m.lTla.ry····ae·p().rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 Daté.·From-Tö Houts Task GodEr NP-r · ·.De~criptionofQpérati()nS·· 3/14/2005 22:00 - 23:30 1.50 BOPSUP P DECOMP LD test plug. 23:30 - 00:00 0.50 PULL P DECOMP RU Schlumberger control line spooler. 3/15/2005 00:00 - 03:30 3.50 PULL P DECOMP POOH LD 5.5" tbg. Spool up control line. Recovered 51 jts tbg, 27 clamps, 5 SS bands. RD spooling unit. 03:30 - 11 :30 8.00 PULL P DECOMP Continue POOH with 5.5" tbg. Retrieved total of 10 GLM, 244 jts tbg, 1 cut off joint 19.59' (smooth cut). 11 :30 - 12:30 1.00 PULL P DECOMP RD 5.5" tbg handling equipment. Clear and clean rig floor. 12:30 - 13:00 0.50 DHB P DECOMP Make up RBP. 13:00 - 16:30 3.50 DHB P DECOMP RIH with RBP on 3.5" drill pipe from shed to 5,061'. 16:30 - 17:30 1.00 DHB P DECOMP Circulate 4 BPM/500 psi for 10 minutes. Set RBP at 5,057' and test to 1,500 psi, good test. 17:30 - 18:00 0.50 DHB P DECOMP RD circ hose. LD DP single. Rack back one stand DP. PU storm packer and set just below surface. 18:00 - 18:30 0.50 DHB P DECOMP Test RBP to 1,000 psi, good test. 18:30 - 20:00 1.50 BOPSUP P DECOMP ND BOPE. 20:00 - 00:00 4.00 WHSUR P DECOMP ND Gen 3 tbg spool. Change out 9 5/8" packoff. NU SSH tbg spool. 3/16/2005 00:00 - 00:30 0.50 WHSUR P DECOMP Test packoff to 5,000 psi, good test. 00:30 - 02:00 1.50 BOPSUP P DECOMP NU BOPE 02:00 - 03:30 1.50 BOPSUP P DECOMP Install test plug. RILDS. Perform full body BOP test, 250 psi low 13,500 psi high, good test. Test witnessed by Nabors Toolpusher and BP Co Rep. Retrieved test plug. 03:30 - 04:30 1.00 DHB P DECOMP Install wear bushing. Engage and release storm packer. Monitor well. LD storm packer. 04:30 - 05:30 1.00 DHB P DECOMP Unseat RBP. Monitor well. 05:30 - 06:00 0.50 DHB P DECOMP Start POOH with RBP. 06:00 - 07:30 1.50 DHB P DECOMP Continue TOH with 3 1/2" Drill Pipe and Halco 9 5/8" RBP... Lay down RBP. 07:30 - 09:00 1.50 FISH P DECOMP Make up BHA #1 as follows: 83/8" Guide x 81/8" OS w/5 1/2" Grapple, Bumper Sub, Oil Jar, XO, 10 ea 6 1/4" DCs, XO. OAL = 331.88' 09:00 - 11 :00 2.00 FISH P DECOMP TIH with BHA #1 and 31/2" Drill Pipe from Derrick. 11 :00 - 14:00 3.00 FISH P DECOMP Continue TIH with 31/2" Drill Pipe from Pipe Shed. 14:00 - 15:00 1.00 FISH P DECOMP Pick-up and test Kelly at 250/3,500 psi. Good test. Set back Kelly. 15:00 - 15:30 0.50 FISH P DECOMP PUW = 145K. SOW = 117K. Continue in with Jt #317. Tag TOF (5 1/2" chemical cut stump, GLM #11, 1 Jt 51/2" Tbg, 5 1/2" Pup Jt and PBR Seal Assembly) at 10,366' rfd. Swallow 2 ft. Stack weight. PUW = 5K gain. Monitor Well. Lay down 2 singles. 15:30 - 19:30 4.00 FISH P DECOMP TOH with 31/2" Drill Pipe standing back in Derrick. 19:30 - 21 :30 2.00 FISH P DECOMP Rack back drill collars in derrick. Retrieved cut off joint (21.50'), 1 GLM assy, 1 joint 5.5" tbg., pup joint and seal assy. LD overshot. 21 :30 - 22:30 1.00 FISH P DECOMP MU BHA #2 as follows: 5.75 spear, extension, stop sub, 2 XO subs, Bumper sub, oil jars, XO, 10 6.25 DC's, XO. OAL=339.80 22:30 - 23:00 0.50 FISH P DECOMP TIH 10 stands. 23:00 - 00:00 1.00 FISH P DECOMP Slip & cut Drill line. 3/17/2005 00:00 - 00:30 0.50 FISH P DECOMP Slip & Cut Drill Line. 00:30 - 03:30 3.00 FISH P DECOMP TIH and tag fish at 10,463". PU=150K, SO=123K, ROT=135K. 03:30 - 04:30 1.00 FISH P DECOMP Spear fully inserted (7') into fish and encountered stop sub. Attempt to engage fish with spear. Upon pulling, noted 5-1 OK Printed: 3/28/2005 8:05:49 AM ) ) BPEXPLÖRATION ·O·pe.rêiti.().I"I~..···$.u.l11tnary.·.···R.è.þ()rt.·. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 þate Frol1i·~·.To . Höurs . Task Code NPT <Phase 3/17/2005 03:30 - 04:30 1.00 FISH P DECaMP overpull that slid off as we pulled up 10 feet. Re-engaged spear with same results. Re~inserted spear and put left hand torque in string to assure grapples in set position. Same results when pick up. After several more attempts to get positive latch indication without success, decided to POOH and see if we captured PBR. No positive surface indications of successful engagement of spear or release of PBR. 04:30 - 05:00 0.50 FISH P DECOMP Set kelly back and prepare for trip out of hole. 05:00 - 09:00 4.00 FISH P DECOMP POOH with 3 1/2" Drill Pipe (319 jts). Stand back Collars. 09:00 - 09:30 0.50 FISH P DECOMP Pull BHA to Floor. No recovery. Spear Grapple in "released" position. Grapple was packed with an Asphalt like material. Clean and re-dress Spear using same Grapple. Install a longer set-screw so as not to allow Grapple to release so easy. 09:30 - 12:00 2.50 FISH P DECOMP TIH with same BHA #2 and 319 jts 31/2" Drill Pipe. Pick-up Kelly. PUW = 150K. SOW = 125K. ROTW = 135K 12:00 - 12:30 0.50 FISH P DECOMP Bring Pump on line at 5 bpm/11 00 psi. Tag TOF at 10,463'. Plant Spear inside Fish to Stop Sub (7'). Shut down Pump. Pull up to 190 K. Unload Jars to "set" Grapple. . Slack-off to- 18K over ROTW. PBR Assy free after 9 1/2 turns. 12:30 - 17:00 4.50 FISH P DECOMP POOH 17:00 - 18:30 1.50 FISH P DECOMP Pull BHA to floor. No Recovery. Spear Grapple in "released" position. Clear and clean rig floor. 18:30 - 19:30 1.00 FISH P DECOMP MU BHA #3. Same as BHA #2 except included additional spear. Assured spears in latch position. 19:30 - 23:00 3.50 FISH P DECOMP RIH with BHA #3 on 3.1/2" DP. Pick up Kelly. PU=146K, SO=123K, ROT =135K. 23:00 - 23:30 0.50 FISH P DECOMP Bring pump up to 5 BPM/1020 psi. Tag TOF at 10,463". Engage spear into fish to stop sub (-10'). Shut down pump. PU to 195K and fire jars, repeated total of 3 times to assure grapples set. SO to 20K over rotating weight. Rotate to the right 13.5 turns. Weight dropped off indicating PBR free. Noted 5-10K additional drag when PU DP. 23:30 - 00:00 0.50 FISH P DECOMP Set kelly back. 3/18/2005 00:00 - 03:30 3.50 FISH P DECOMP POOH. Stand back collars 03:30 - 04:00 0.50 FISH P DECOMP Pull BHA to floor. No fish. Spears in "released" position. Discussed with baker fishing hand to arrange for wash pipe appropriate to wash over and mill PBR free. 04:00 - 05:00 1.00 FISH P DECOMP Clean BHA and lay down same. 05:00 - 06:00 1.00 FISH P DECOMP Clean and clear rig floor. Grease drawworks and service rig. 06:00 - 08:00 2.00 FISH P DECaMP Make-up BHA #4 as follows: 81/8" x 71/16" WP Shoe, 1 Jt 8 1/8" x 71/16" WP, XO, 2 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, XC, 10 ea 6 1/4" DCs, XO. 08:00 - 09:00 1.00 FISH P DECOMP Start to TIH with BHA and 31/2" drill Pipe. Stop to Cut and Slip Drilling Line. 09:00 - 1 0:00 1.00 FISH P DECOMP Cut and Slip Drilling Line. 10:00 - 13:00 3.00 FISH P DECOMP Finish TIH with BHA #4 and 31/2" Drill Pipe (318 jts and a 10 Pup Jt). Pick up Kelly. 13:00 - 13:30 0.50 FISH P DECOMP PUW = 150K. SOW = 125K. ROTW = 135K. Tag TOF at 10,463'. Bring Pump on line at 4.5 bpm/900 psi. Torque = -5,500 ft/lbs/150 Amps. RPM = -90. Washed down over PBR Barrel (19.01') to packer body. PBR Barrel had fill packed behind it. Pump pressure decreased to 4.5 bpm/700 psi when Shoe started milling on Packer body at 10,482'. Begin to Vis Printed: 3/28/2005 8:05:49 AM ) ) BPEXPLORA TION . . ·ppe.rations ·!)Unh11é1ry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 Date From-To Hours.<Task Code NPT Phase Description ofOþeratiohs 3/18/2005 13:00 - 13:30 13:30 - 23:00 0.50 FISH 9.50 FISH P P DECOMP up fluid system. DECOMP Begin Milling on Baker 3H Packer at -10,482'. to 10,483'. No gain in depth in 9.5 hrs decission made to POOH. Note! Spill 3-4 BBLS viscosified sea water on pad due to overflow of cuttings tank. 23:00 - 00:00 1.00 FISH P DECOMP POOH. 3/1912005 00:00 - 04:00 4.00 FISH P DECOMP POOH Stand back callors 04:00 - 05:00 1.00 FISH P DECOMP Clean and lay down BHA #4. 05:00 - 06:00 1.00 FISH P DECOMP MU Fishing BHA #5 as follows: 5 3/4" Double Spear w/6.220" Grapples, Spear Ext, Stop Sub, 2 ea XOs, Bumper Sub, Oil Jar, XO, 10 ea 6 1/4" Drill Collars, XO. 06:00 - 10:00 4.00 FISH P DECOMP TIH with BHA #5 and 31/2" Drill Pipe (319 Jts). Pick-up Kelly. PUW = 150K. SOW = 125K. Tag TOF at 10,463'. 10:00 - 11 :00 1.00 FISH P DECOMP Plant Spear in Fish. Pull up to 175K and unload Jar to set Grapples. Begin to Jar Fish at 225K (6 times). Jar Fish at 250K (10 times). Jar Fish at 275K (2 times). Fish came free. 11 :00 - 13:30 2.50 FISH P DECOMP TOH with 31/2" Drill Pipe and BHA #5. Fish to surface. 13:30 - 14:00 0.50 FISH P DECOMP Lay down Fish. PBR Barrel = 20.21'. 14:00 - 15:00 1.00 FISH P DECOMP Make-up BHA #6 as follows: Bullnose wI carbide 3-1/2",4-1/4" PRT wI 4-3/4" grapple,4-1/4" PRT extension, Tripille Conn. Bushing wI 8-1/2" MM Mill, Boot Baskets, Bit Sub, Oil Jar, X/O, 6-1/4" DC x 10, X/O. 15:00 - 18:30 3.50 FISH P DECOMP TIH BHA on 3-1/2" Drill Pipe 18:30 - 00:00 5.50 FISH P DECOMP Pick up Kelly, break circulation, Mill Packer at 10,482', Push Packer down to top of 7" Liner at 10,555'. Circulate Bottoms Up. 3/20/2005 00:00 - 05:00 5.00 FISH P DECOMP TOH with 9-5/8" PKR (Fish). 05:00 - 06:00 1.00 FISH P DECOMP Lay down Fish and BHA #6. Fish recovered = Packer and Tailpipe Assembly complete. 06:00 - 07:00 1.00 FISH P DECOMP Clear and Clean Rig Floor 07:00 - 07:30 0.50 CLEAN P DECOMP Make up BHA #7 as follows: 8 1/2" Bit, 95/8" Csg Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, 10 ea 61/4" Drill Collars, XO. 07:30 - 11 :00 3.50 CLEAN P DECOMP TIH with BHA #7 and 31/2" Drill Pipe to 10,528'. Encountered no problems. 11 :00 - 12:00 1.00 CLEAN P DECOMP Cut and Slip Drilling Line. 12:00 - 14:30 2.50 CLEAN P DECOMP TOH with 31/2" Drill Pipe and BHA #7. 14:30 - 16:00 1.50 CLEAN P DECOMP Lay down BHA #7. Also break out other Fishing Tools not needed anymore. 16:00 - 16:30 0.50 EV AL P DECOMP Pick-up Halco 9 5/8" RTTS Packer w/Circ Valve. 16:30 - 21 :00 4.50 EV AL P DECOMP TIH with Packer, Drill Collars, and 3 1/2" Drill Pipe. 21 :00 - 00:00 3.00 EVAL P DECOMP Set 9-5/8" RTTS Packer at 10,480' , Fill Annulus with 108 bbls Sea Water, Test 9-5/8" Csg. 3500 psi 30 minutes charted Good Test, Unseat Packer 3/21/2005 00:00 - 05:00 5.00 EVAL P DECOMP TOH with 3-1/2" DP and RTTS 05:00 - 06:00 1.00 EVAL P DECOMP Lay down 6 1/4" Drill Collars and RTTS Packer. 06:00 - 06:30 0.50 CLEAN P DECOMP Clear and Clean Floor. 06:30 - 08:00 1.50 CLEAN P DECOMP Make-up BHA #8 as follows: 57/8" Cable Shoe, 1 Jt 5 3/4" Washpipe, 3 ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, 9 ea Drill Collars. 08:00 - 11 :30 3.50 CLEAN P DECOMP TIH with BHA #8 and 31/2" Drill Pipe from Derrick. 11 :30 - 13:00 1 .50 CLEAN P DECOMP Continue RIH with 31/2" Drill Pipe singles from Pipe Shed. Tag Fill (Bridge) at 11,097'. Bring Pump on line at 6 bpm/800 Printed: 3/28/2005 8:05:49 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 bate From- To Hours Task··. Co.de 3/21/2005 11 :30 - 13:00 1.50 CLEAN P DECOMP 13:00 - 14:30 1.50 CLEAN P DECOMP 14:30 - 17:00 2.50 CLEAN P DECOMP 17:00 - 18:00 1.00 CLEAN P DECOMP 18:00 - 19:00 1.00 CLEAN P DECOMP 19:00 . 00:00 5.00 CLEAN P DECOMP 3/22/2005 00:00 - 03:00 3.00 CLEAN N STUC DECOMP 03:00 . 04:00 1.00 CLEAN N STUC DECOMP 04:00 . 06:00 2.00 CLEAN N STUC DECOMP 06:00 - 10:30 4.50 CLEAN N STUC DECOMP 10:30 - 11 :00 0.50 CLEAN P DECOMP 11 :00 - 14:30 3.50 CLEAN C DECOMP 14:30 - 16:30 2.00 CLEAN C DECOMP 16:30 - 17:00 0.50 CLEAN C DECOMP 17:00 - 18:00 1.00 CLEAN C DECOMP 18:00 - 00:00 6.00 CLEAN C DECOMP 3/23/2005 00:00 - 00:30 0.50 CLEAN C DECOMP 00:30 - 02:30 2.00 CLEAN C DECOMP 02:30 - 03:30 1.00 CLEAN C DECOMP 03:30 - 06:00 2.50 CLEAN P DECOMP 06:00 - 09:00 3.00 CLEAN P DECOMP 09:00 - 09:30 0.50 CLEAN P DECOMP 09:30 - 14:00 4.50 BOPSUF P DECOMP psi. (no returns to surface). Work through with little problem. Wait on additional Sea Water to build volume. Gel up new fluid in Pits. Continue picking-up singles. Encountered no fill. Short trip each joint with no over pull. Tagged soild Fill at 11,130'. Work down to 11,170'. Pump rate 6.0 bpm/900 psi. Finally got returns. Circ. work through to 11,195', Lay down single. Work tight at 11,170' Allow fluid to equalize. Work pipe holding torque free up to 11,138' Lay down single Circ. and rotate string P/U and lay down single, Work tight at 11 ,106'. Work pipe with torgue Working Torgue to free pipe, No circulation established Fill annulus 12 bbls pressure up annulus see break at 1700 psi, work pipe and torque. Rest hole allow to equilize Continue working stuck pipe (Shoe at 11,106'). Fill annulus (125 bbls). Continue to work Pipe. Saw movement. Set back Kelly. Work Pipe. Move 6'. Fill Annulus again (40 bbls). Work Pipe. Now able to rotate with slips set in RT. Work Pipe free... with much Joy! Lay down 4 singles. Pipe free with normal 150 K PUW and no drag. Stand back 5 Stands in Derrick. Shoe now up in 9 5/8" Casing (10,506'). Discuss plan forward with Anch Eng. Wait on Flo-Pro. Wait on CaC03. (Trucks in very short supply). Take on Flo-Pro. Mix 50 bbl with CaC03 pill. Pump & spot CaC03 pill. Mix 2nd CaC03 pill. Pump 2nd pill. had returns. SID & monitor well well losing 73 BPH. Mix & pump 3rd CaC03 pill. Continue pumping after pill on bottom. hole stayed full @ 1 BPM. loss 60 BPH. Then slowly got returns. Mix & pump 4th 50 bbl pill. Now getting 85% returns. Had small amount of gas to surface. SID & FL slowly dropped. Losses 16 BPH. Mixed & pumped 5th 50 bbl pill. Losses dropped to 5 BPH. SID & monitor well. Finish circ after 5 th pill. Losses were 5 BPH. SID. FL dropping very slowly. Monitor well. Allow calcium carbonate to drop. Cut & slip 84' of drilling line. Fill hole took 8 bbls after 2 hrs. Circulate @ 3 BPM, 360 psi. Circulated 10 min, no losses. SID hole full. Close in annular & reverse circulate, 3 BPM @ 300 psi. losses 32 BPH. Reduced rate to 1 BPM, 200 psi. loss rate 16 BPH. SID Hole stayed full. POOH & stand back 3 1/2" DP. Continue POOH with 3 1/2" Drill Pipe and BHA #8. Stand back Drill Pipe and Drill Collars. Lay down Baker Fishing Tools. Empty Junk Baskets. Recovered one large piece of Packer Slip. Also recovered a piece of IBP band, Carb-O-Lite, and metal fines. Pull Wear Ring. Pick-up Test Jt. Install Test Plug. Perform weekly BOPE Test per BP/AOGCC requirements at 250/3500 psi. State's right to witness Test waived by C. Sheeve. Co Printed: 3/28/2005 8:05:49 AM ) ) BPEXPLORATION .()per~~.i.önssul11rr1aryR~þºrt . PäQè6of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/9/2005 Rig Release: 3/25/2005 Rig Number: Spud Date: 2/18/1985 End: 3/25/2005 Date From-To Hours .·.Task Code NPT· 3/23/2005 09:30 - 14:00 4.50 BOPSUP P DECOMP Rep and TP witnessed Test. 14:00 - 14:30 0.50 TA C SURE Pick-up Halco Running Tool and 7" RBP. 14:30 - 18:00 3.50 T A C SURE TIH with RBP, Drill Collars, and 31/2" Drill Pipe to 10750'. 18:00 - 19:00 1.00 T A C SURE Break circulation. Space out RBP to 10750'. Set packer wI 15K down wt. P/U 142K, SIO 120K. 19:00 - 19:30 0.50 T A C SURE Pressure test RBP to 1500 psi for 10 min. Tested OK. Charted test. 19:30 - 00:00 4.50 TA C SURE POOH & LID 243 jts of 31/2" DP. 3/24/2005 00:00 - 01 :00 1.00 T A C SURE POOH & stand back 29 stands of 31/2" DP & 3 stands of 4 3/4" DCs. 01 :00 - 02:00 1.00 TA C SURE LID 7" running tool. M/U 9 5/8" RBP & running tool. 02:00 - 03:00 1.00 T A C SURE RIH wI 29 stands of 3 1/2" DP & 3 stands of 4 3/4" DCs. 03:00 - 03:30 0.50 T A C SURE Attempt to set 95/8" packer. Set & took weight, 20K down. Turn to left & PIU for overpull.... no overpull. PIU single & RIH, Attempt to reset. No good. POOH to check tools. PIU & SIO 54K. 03:30 - 05:00 1.50 TA X DFAL SURE POOH & stand back 31/2" DP & 4 3/4" DCs. Inspect running tool. Looked Ok. RBP lost down hole below 3,030'. 05:00 - 07:00 2.00 TA X DFAL SURE P/U 2nd 9 5/8" RBP & running tool. RIH on 3 1/2" DP. Set RBP #2 at 3000'. Test at 1500 psi/10 min. Good. 07:00 - 09:30 2.50 TA C SURE POOH and Lay down 31/2" Drill Pipe, 43/4" Drill Collars, and Halco running Tool. 09:30 - 11 :00 1.50 TA C SURE Pull Wear Bushing. LID running tool. Clear & clean rig floor. 11 :00 - 11 :30 0.50 T A C SURE Service rig. 11 :30 - 12:00 0.50 T A C SURE RIU tools to handle 4 1/2" kill string. 12:00 - 15:30 3.50 T A C SURE RIH wI 65 jts 41/2" tubing. WLEG @ 2562'. "X" Nipple @ 2520'. 15:30 - 16:00 0.50 T A C SURE Set TWC. Test same. Drain BOP stack. Blow down lines. 16:00 - 17:00 1.00 T A C SURE ND BOPE. 17:00 - 19:30 2.50 T A C SURE N/U adapter flange & X-mas tree. 19:30 - 20:00 0.50 T A C SURE Test hanger void & tree to 5000 psi, OK. 20:00 - 00:00 4.00 TA X WAIT SURE Wait on DSM to pull TWC. R/U to pump diesel. 3/25/2005 00:00 - 00:30 0.50 T A P SURE P/U lubricator & pull TWC. LID same. 00:30 - 02:00 1.50 TA P SURE Displace well to bottom of kill string wI 180 bbls of diesel for freeze protection. Pumped @ 5 BPM, 500 psi. 02:00 - 02:30 0.50 T A P SURE Allow well to equalize. Flush & blow down lines. Set BPV & test. 02:30 - 04:00 1.50 TA P SURE Clean pits. Secure well. RELEASE RIG @ 0400 hrs. 04:00 - 06:00 2.00 TA P SURE RID Lower & scope down derrick. Printed: 3/28/2005 8:05:49 AM ) ) . BPEXPLORATION .. ··Qper¡¡~i:()n.s·SUI·'ltnarY··.~øpptt ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 4/8/2005 From.;To· Hours Task Code Npi .. Phase 06:00 - 10:00 4.00 RIGD P PRE 10:00 - 00:00 14.00 MOB P PRE 00:00 - 16:00 16.00 MOB P PRE 16:00 - 20:00 4.00 RIGU P PRE 4/9/2005 20:00 - 00:00 4.00 REST P DECOMP 4/10/2005 00:00 - 04:00 4.00 BOPSUP P DECOMP 04:00 - 09:00 5.00 BOPSUF P DECOMP 09:00 - 12:30 3.50 BOPSUR P DECOMP 12:30 - 13:00 0.50 BOPSUR P DECOMP 13:00 - 13:30 0.50 PULL P DECOMP 13:30 - 17:00 3.50 PULL P DECOMP 17:00 - 18:00 1.00 CLEAN P DECOMP 18:00 - 21 :00 3.00 CLEAN P DECOMP 21 :00 - 23:00 2.00 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 4/11/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 03:00 2.00 CLEAN P DECOMP 03:00 - 12:30 9.50 CLEAN P DECOMP 12:30 - 13:30 1.00 CLEAN P DECOMP 13:30 - 17:00 3.50 CLEAN P DECOMP 17:00 - 18:00 1.00 CLEAN P DECOMP 18:00 - 19:00 1.00 CLEAN P DECOMP 19:00 - 00:00 5.00 CLEAN P DECOMP 4/12/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 04:30 3.50 CLEAN P DECOMP 04:30 - 05:30 1.00 CLEAN P DECOMP 05:30 - 11 :00 5.50 CLEAN P DECOMP Start: 4/9/2005 Rig Release: 4/15/2005 Rig Number: Spud Date: 2/18/1985 End: 4/15/2005 . [}esdri ptiönöfOperatiQDS PJSM. Scope down & layover derrick. Prep rig components for move to DS 17.' PJSM. Move Rig from Badami to GPB DS 17-11,40 mile move. Continue moving from Badami to DS 17. On location @ 16:00 hrs. PJSM. Spot rig over well. Raise & scope up derrick. Rig up on 17-11. Touched base wI Nabors 2ES Company Man & Tool Pusher regarding simultaneous operations & close proximity of rigs. PJSM. R/U to circulate out diesel, Pull BPV Test 3500 psi. Circulate out freeze protection with sea water. Install TWC N/D Tree & Adpt flange PJSM. N/U 13 5/8" x 5M BOPE. PJSM. Conduct full test on BOPE. AOGCC State Rep Chuck Sheve waived witnessing test. Test witnessed by Nabors Tool Pusher & BP Company Man. No failures. PJSM. Pick up lubricator, pull two way check valve, LID lubricator. PJSM. BOLDs. Pull hanger to floor & UD same. Up wt = 37K. PJSM. POOH & UD 41/2" TCII kill string. PJSM RID 4.5" R/U 3.5" handling tools. Set wear ring. RII 2 LDS. Clear floor. M/U BHA #1 HES 9 5/8" RBP pulling tool TIH with BHA #1 on 31/2" DP to 3000' Latch and pull 9 5/8" RBP at 3000' POOH. UD packer. TIH with BHA #1 on 3 1/2" DP ContinueTIH with HES 9-5/8" pulling tool on 31/2" DP. Locate and latch 9 5/8" RBP packer at 4230' TOH with 9 5/8" RBP packer on 31/2" DP Lay down packer and running tool PJSM M/U 7" HES RBP pulling tool. RIH on 3 1/2" DP to 4200' running stands & continue in hole, singling in. Tag top of 7" liner 25' in on jt # 333 @ 10,541' DPM. PJSM. Establish parameters. 128K up wt, 112K down. Set 3 - 5K down on TOL. Set slips & rotate (5) turns to the right, see torque drop off. Continue in & tag again @ 10,547'. Repeat procedure as before 7 drop through OK. Conitinue in hole. Tag top of RBP 10' in on jt #340 @ 10,747' DPM. 135K up wt, 114K down. Set 20K on packer & pick up, verify latched w/5K overpull. Set down 20K, rotate to the right (3) turns & hold torque. Work torque down & repeat. Packer released. PJSM. POOH w/3 1/2" DP & RBP. UD 7" RBP packer and running tool. Clear rig floor PJSM P/U BHA # 2 Baker 6' flat bottom mill, boot baskets, bit sub, bumper sub, oil jar, drill collars, and pumpout sub. RIH BHA #2 on 31/2" DP. Continue RIH w/BHA #2 on 31/2" DP at 10,494 MD Clean out hole fluid wI Flo-Pro 8.5 Iblgal VIS=78 740 bbls Work through liner at 10,550'. Single in & tag @ 11,025'. PJSM. Kelly up. Establish parameters. 118K down wt, 140K up wt wI pumping @ 5 bpm I 1300 psi. 158K up wt wI pump off. 130K rotating wt. 3000 ft/lbs torque off bottom. Rotate @ 80 - 100 RPM & commence cleaning 7" liner. Tag @ 11,195', hard Printed: 4/18/2005 9:37:21 AM ) ) BPEXPLORATrON ..··...O·per.élti..q.I'1$·.·$.u·mrnª·ry.·.·.·Re·PQtt·. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/9/2005 Rig Release: 4/15/2005 Rig Number: Spud Date: 2/18/1985 End: 4/15/2005 .Date Frprn-·To· Höurs Task Code NPT . . Phase ·DescriptiÓnt?fOperations 4/12/2005 05:30 - 11 :00 5.50 CLEAN P DECOMP tag @ 11,216'. Opinion is Gunk) on top of sand wI very little cement. Continue down to 11,265', much sand back over shaker. No siginificant losses. pH level of fluid in 'pits after cleaning out to 11,280', 9.5. Climbed to 10.5 when @ 11,295'. NOTE: OIA climbed from 0 psi to 640 psi from 06:00 to 09:30.....bled off into slop trailer...all gas. Shut in to check for build up. 11 :00 - 14:30 3.50 CLEAN P DECOMP Continue clean up to 11,350' 14:30 - 18:30 4.00 CLEAN P DECOMP Condition well circulate 2x bottoms up 6.87 BPM/1600 psi. working pipe 18:30 - 19:00 0.50 CLEAN P DECOMP PJSM Stand back Kelly TOH with 3-1/2" DP viscous fluid not falling 19:00 - 20:00 1.00 CLEAN P DECOMP Drop circulating sub dart pump down to circulating sub and shear at 2600 psi. Slug pipe with 20 bbl 9.5 Ib/gal salt pill to clean pipe 20:00 - 00:00 4.00 CLEAN P DECOMP Continue TOH with 3-1/2" DP filling pipe displacement 4/13/2005 00:00 - 03:00 3.00 CLEAN P DECOMP Continue TOH lay down 3-1/2" DP Filling displacement (285 jts out). Stop to Cut and Slip Drilling Line. 03:00 - 04:30 1.50 CLEAN P DECOMP Cut and Slip Drilling Line (84'). Adjust Draw Works brakes 04:30 - 06:00 1.50 CLEAN P DECOMP Continue POOH and single down 3 1/2" Drill Pipe. 06:00 - 06:30 0.50 CLEAN P DECOMP Lub and Service Rig. 06:30 - 07:30 1.00 CLEAN P DECOMP Lay down Drill Collars and BHA. 07:30 - 08:00 0.50 CLEAN P DECOMP Clear and clean Rig Floor. 08:00 - 09:00 1.00 RUNCOMP RUNCMP Rig upTorque Turn Equipment and 41/2" handling equipment. 09:00 - 09:30 0.50 RUNCOMP RUNCMP PJSM with All. 09:30 - 10:30 1.00 RUNCOMP RUNCMP Baker Lock and make up assembly connections WLEG, XN nipple, Tbg., X nipple and Baker S-3 Ret. Pro. Packer 194-47 at Optimun torque 4280# RIH 10:30 - 00:00 13.50 RUNCOMP RUNCMP Make up and run completion using optimum torgue spacing assemblies as per procedure X-nipple, 5 Camco MMG GLM w/Dummie,1 upper Camco MMG GLM w/DCR-1SV, X-nipple 4/14/2005 00:00 - 01 :30 1.50 RUNCOMP RUNCMP Continue running completion sting 4-1/2" 12.6# 13Cr-85 Fox Tbg to space out 01 :30 - 03:00 1.50 RUNCOMP RUNCMP Drain the stack Make up Cameron McEvoy SSH 13" x 4-1/2" MS/CCL Tbg. Hanger Land and RILDS. Test Tubing Hanger packoff to 5000 psi. Set TWC 03:00 - 04:30 1.50 BOPSUR P RUNCMP Nipple Down BOP 04:30 - 07:00 2.50 WHSUR P RUNCMP Nipple up Adaptor Flange and Production Tree. 07:00 - 07:30 0.50 WHSUR P RUNCMP Pressure Test Production tree at 5,000 psi. Good test. 07:30 - 08:30 1.00 WHSUR P RUNCMP Pick-up Lubricator an pull TWC. Lay down same. 08:30 - 15:00 6.50 RUNCOM\J WAIT RUNCMP Wait on Vac Truck with 140 deg Sea Water. Truck were called out at 05:00 hrs. Also Dispatch was notified with a 12 hour "will call" for Vac tuck needs. 15:00 - 21 :00 6.00 RUNCOrvP RUNCMP Reverse in with 100 bbls of 140 degree 1 % KCL at 3 bbls/min with 600 psi. Continue to reverse in with -600 bbls, 140 deg 1% KCL w/Corrosion Inhibitor (added at 25 gal/100 bbls). 21 :00 - 23:30 2.50 RUNCOrvP RUNCMP Drop Packer setting BaIl/Rod.....on seat. Set Baker S-3 Packer with 3500 psi and held for 30 min charted. Bleed Tbg. to 1500 psi. Test CsgIPacker 3,500 psi I 30 min charted. Bleed Tbg. until DCR valve shears. Pump down annulus 5 BPM and pump down Tbg 5 BPM find DCR valve to be open 23:30 - 00:00 0.50 RUNCOrvP RUNCMP PJSM Held with all hands and Little Red Hot Oilers 4/15/2005 00:00 - 02:30 2.50 RUNCOrvP RUNCMP R/U L.ittle Red Hot Oilers Test to 4000 psi Reverse Circulate i Printed: 4/18/2005 9:37:21 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-11 17-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/9/2005 Rig Release: 4/15/2005 Rig Number: Spud Date: 2/18/1985 End: 4/15/2005 Date From~T() HöursTask CÖdé NPT··· Ptläse Qescription of Operations 4/15/2005 00:00 - 02:30 2.50 RUNCOMP RUNCMP with 145 bbls of Diesel to Freeze Protect Well. U tube diesel RID lines. RUNCMP R/U Cameron lubricator set BPV and test 1000 psi RUNCMP RID all lines Secure well Release Rig. 02:30 - 03:00 03:00 - 04:00 0.50 RUNCOMP 1.00 RUNCOMP Printed: 4/18/2005 9:37:21 AM ) ) Well: Field: API: Permit: 17-11 Rig Workover Prudhoe Bay Unit 50-029-21259-00-00 184-244 Accept: Spud: Release: Rig: 03/13/05 N/A 03/25/05 Nabors 4ES Accept: Spud: Release: Rig: 04/09/05 N/A 04/15/05 Nabors 4ES POST RIG WORK 04/17/05 PULL BPV. ATTEMPT TO PULL BALL AND ROD. TOOLS SAT DOWN AT 6829 SLM. RAN 3" PUMP BAILER TO 6832' SLM, WORKED DOWN TO 6989' SLM. RAN 3" DRIVE DOWN BAILER TO 6989' SLM, BROKE THROUGH AND SAT DOWN AT 7445' SLM. CONTINUE BAILING TRYING TO GET TO TOP OF BALL & ROD AT 10,464' MD. 04/18/05 ATTEMPTING TO PULL B+R. MADE 4 RUNS WITH 10' 3" D.D. BAILER TO 7374' SLM. RECOVERED FULL BAILERS OF SAND. RAN 2.25" DRIVE DOWN BAILER TO 10,347' SLM. RAN 3" PUMP BAILER TO 10,322' SLM. RAN 3" DRIVE DOWN BAILER TO 10357' SLM. 04/19/05 BAILING ON TOP OF RHC 2.2511 DRIVE DOWN BAILER. 04/20/05 BAIL APPROXIMATELY 18 GAL OF SANDS, DRILLING MUD AND RIG TRASH FROM 10,436' SLM; STILL NOT SEEING THE BALL AND ROD FISHING NECK. CONTINUE BAIL TO BAIL. 04/21/05 BAIL APPROXIMATELY 12 GAL OF SANDS, DRILLING MUD AND RIG TRASH FROM 10,436' SLM. WORK TOOLS DOW N TO 10,442' SLM. 04/22/05 BAILING SAND AND MUD ON TOP OF BALL AND ROD AT 10464' MD. ATTEMPT TO BAIL DRILLING MUD, FRAC SAND, AND WORK OVER JUNK FROM ON TOP OF THE BALL AND ROD AT 10,464' MD. 04/23/05 BAILING SAND AND MUD FROM TOP OF RHC & BALL & ROD. ATTEMPT TO BAIL WORK OVER JUNK FROM THE TOP OF THE RHC PLUG AT 10, 464' SLM, RAN A 3.25" LIB TO 10,442' SLM AND RETURNED TO SURFACE WITH AN IMPRESSION OF THE BALL AND ROD FISHING NECK. RAN D-CENTRALlZER WI 3.25" LIB TO 10441' SLM. IMPRESSION OF SAND ONLY. RUN 2.750" HYDROSTATIC BAILER. 04/24/05 SET CATCHER SUB ON TOP OF FILL. SET WHIDDON CS AT 10438' SLM. ATTEMPTING TO C/O GASLlFT VALVES. PULLED DUMMY VALVE W/ RK LATCH FROM STA#4 AT 5905' SLM. 04/25/05 PULL DCR VALVE FROM STATION #1 AT 3216' MD, PULL DUMMY VALVE FROM STATION #3 AT 5910' MD, PULL DUMMY VALVE FROM STATION #5 AT 8978' MD, PULL DUMMY VALVE FROM STATION #6 AT 10,242' MD. SET 1.5" DOME GAS LIFT VALVE 16/641633 TRO IN STATION #1 AT 3216' MD. 04/26/05 PULL AND SET GLV'S GAS LIFT PORTION COMPLETE. BALL & ROD I RHC STILL IN WELL, POP TO FLOW BACK SAND. TRI!E = " Me Ev oy G3 WELLHEAD = McEvoy ACTuAToR:; .' AXElSON ''''''''~''''''''''''^'''''''''''~'''''''~'''''''''''''''/''H'I'Jww'''' KB. ELEV = 71' Bþ:'Ël..Ë\/;; . . ... ·kÒÞ;·" ^MãxAngïe = Öatum MÖ= IÖï3iumTVÖ;'· . 4-1/2" TBG 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" 1-1 PERFORATION SUMrv1ARY REF LOG: BHCS ON 03/07/85 A NGLE AT TOP PERF: 33 @1 0893' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE ? 6 10893 - 10916 S 04/26/91 3-3/8" 13 10893 - 10916 0 02/28/92 3-3/8" 4 10905 - 10907 0 07/19/91 3-3/8" 4 10924 - 10930 0 04/30/92 4 10930 - 10935 0 04/30/92 8 10935 - 10952 0 04/30/92 4 10980 - 10993 0 04/30/92 1 11014 - 11054 S 04/26/91 5 11014 - 11054 0 07/19/91 1 11066 - 11118 S 04/26/91 5 11066 - 11118 S 04/26/91 4 11130 - 11150 0 07/19/91 1 11130 -- 11174 S 04/26/91 1/311198-11206 S 04/26/91 1/4 11208 - 11216 S 04/26/91 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3- 3/8" ) 17-11 ) FR DRL .. DRAFT l J 2099' 1-1 4-1/2" HES "X" NIP, ID= 3.813" 3700' 5(~-0!3~?,' 11027' ' . ääöÖ'ss GAS LIFT rv1ANDRELS \13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2508' I..J ~ ST MD 1VD DEV TY PE VLV LATCH PORT DATE 6 3217 3217 0 MMG DOME RK 16 04/25/05 L 5 4439 4385 31 MMG DMY RK 0 04/12/05 4 5911 5439 49 MMG DOME RK 16 04/25/05 Min. ID = 3.725" @ 10610' 3 7445 6386 54 MMG DMY RK 0 04/12/05 2 8979 7333 46 MMG DOME RK 16 04/25/05 4-1/2" HES XN Nipple 1 10233 8245 43 MMG SO RK 22 04/25/05 . ~ I 10419' 1-1 4-1/2" HES "X" NIP, ID= 3.813" :g -I 10440' 1-1 4-1/2" x 9-5/8" BKR S-3 , ID= 3.875" ,TOP OF 7" LNR 1-1 10550' . I 1 0464' 1-1 4-1/2" HES "X" NIP, ID= 3.813" I 10632' I-I L----, 10632' 1-1 4-1/2" WLEG I 10610' 1-1 4-1/2" HES XN NIP, ID = 3.725" I 9-5/8" CSG, 4,7#, L-80, ID = 8.681" 1-1 10861,'1~' .. LCN''JO .) ^JJ F'orfe;: 'I ¿jU: ! ¡ 2'00'- I PBTD 1-1 11449' , ~ [ -11350' 1-1 ASSORTED FISH & FILL [7" LNR, 29#, L-80, .0371 bpf,ID=6.184" 1-1 11488' DATE 03/11/85 02/16/86 04/12/05 04/26/05 04/28/05 REV BY COMMENTS ORIGINAL COM PLETION RWO RWO ITLH CORRECTIONS KSB/TLI- GLV C/O (04/25/05) DATE REV BY PRUDHOE BA Y UNIT WELL: 17-11 PERMIT No: "1842440 API No: 50-029-21259-00 SEC 22, T10N, R15E. 4700.31' FEL & 2682.68' FNL COMMENTS BP Exploration (Alas ka) RE: Cancel Waiver: 15-29 ) ) Subject: RE: Cancel Waiver: 15-29 From: "Anders, Joe L" <anders22@BP.com> f&l (7 -l ( Date: Fri, 04 Mar 2005 14:40:46 -0900 .)8-<t-a4lf To:": JamesRegg<jim_tegg@admin.state.ak.us> .',,1 CC: "NSU, ADWW ell Operations Sup~rvisor" <NSUADWW ellOperationsSupervisor@BP.com>, . W~nton GAubert <winton_aubert@admin.state.ak.us>, "Rossfuerg, R Steven" <RossheRS@BP.com>,' "Engel, HarryR" <EngeIHR@BP.com>,"Mielke,RobertL." <töbert.mielke@BP.com> Hi Jim. Both 15-29 and 17-11 have been S I. LJ....o5J\- CSf3i-- '3/4/0Ç w.-f15 had the production casing hanger seals replaced during a RWO conducted May 2004. Let me know if you have any additional questions. Joe -----Original Message----- From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, March 04, 2005 2: 19 PM To: Anders, Joe L Cc: Winton GAubert Subject: Re: Cancel Waiver: 15-29 Joe - re: 15 - 29 and 17-11; does this mean the wells have been SI? re: W-05; repairs done to eliminate SCP? Jim Regg AOGCC Anders, Joe L wrote: ! Hello all. Well 15-29 (PTD 2020160) has been reclassified from "Waiver" to "Trouble". The well has both TxlA and a PC leak. Please remove any copies of the waiver and any waiver signs from the well house. Call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator BP Exploration (Alaska), Inc 1-907 -659-5102 anders22<æbp.com .sG/~NNE-'~"~} ~R ,r~j") 'i' C,' 2001:' c.. ,~!d 1í ./ ~,I .,. J-l 1 of 1 3/4/2005 3: 18 PM Problem Well Notification: 17-11 (PTD #1842440) ) Subject: Problem Well Notification: 17-11 (PTD #1842440) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 15 Oct 2004 21:28:38 -0800 . .' . TO,:."GPB~'FS2 D~Ops Lead" <GPBFS2DSOpsLead@BP.com>/'GPB,Qps Mgr".:'.. '. "'. <GPBOpsMgr@BP.com>, "GPB,.FS2 TL"<GPBfS2TL@BP~:com>; "Hams,'MarvinL (CONOCO)'~: <håim11@BP .com>, HRossberg, R Steven'.' .<RossbeRS@BP.com>~'.'NSU,..:ADW~~W ell.Operätions.' '. Supervisor" <NSlJADW'WenOp~rationsSupervisor@]3,P~cQm>, "(}PB,; '\¥ells:0pt~ng'" '., .': : <.' .,' . <GPBW ellsOptEng@BP.com>, ttAOGCC Jiril Regg (E~mail)..<jitn~regg@adniill.st~te.ak.us::>. : : "AOGCC Winton Aubert (E-mail)" <winton ~ aub~rt@a<imin~state~ak~us>, i-,'NSU~ .i\DW.,WL '&:.' Cowpletion Supervisor" <NSUADWW~~Completio1i~uperyisor@BP~com?' .. .::;.: .'.':':...,:"...' . . , CC: "NSU, ADW Well Integrity Engineer":<NSUADWWeIlIntegritYEngi1ieer@BP~com>, "Reev~s,. Donald F" <Ree"esDf@BP.com> ... .".'. . ..... .. ...' .. .. '.. ') \ ~-;f.LfLt All, Well 17-11 (PTD #1842440) has sustained casing pressure on the OA and the well has been classified as a Problem well. The TIOls on 10/14/04 were 220/1300/1220. The plan forward for this well is as follows: 1. DHD: MITOA to 2400 psi - PASSED 2. DHD: NFT-IA - PASSED. 3. WAV: Revise waiver to TxIAxOA ¿/' Attached is a wellbore schematic. Please call if you have any questions. «17-11.pdf» Joe Anders, P.E. Well Integrity Coordinator, Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: BP Exploration, (Alaska) Inc. .com Content-Description: 17-11.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NO\! () 2 2004 1 of 1 10/20/2004 3: 14 PM 1)1\ TE RBI BY COIVMENTS 02108103 Jr./P/KK WAWER SAFETY NOTE 04/08103 DAC/KK PATCH CORRECll0N 07/11103 JBlKAK GLV ClO ') TREE = IIJk;EVOY GEN 3 WB.LHEAD = IIJk;EVOY ACfij\'TOR;'; '.'''''A"XELSÖN okS: EL~"'--""71î Bï=~näEV;;--- KOP ~. . 3700' _.~~-'" m,_, - -- ._~- ~~. A~g e..=':n.. ~..~.!~~g:, Datum MD = 11027' Datum ND = 8800' SS 113-3/8" CSG, 72#, L-80, D = 12.347" 1-1 2508' Minimum ID = 3.725" @ 10600' 41/2" OTIS NIPPLE 5-1/2"TBG-PC, 17#, L-80, .0232 bpf, D =4.892" 1-1 10514' 1 I TOP OF 4-1/2" TBG-PC 1-1 10514' 1 TOP OF 7" LNR 1-1 10550' 14-1/2" lBG-PC, 12.6#, L-80, .0152 bpf, D = 3.958" 1-1 10612' I 9-5/8"CSG, 47#, L-80, ID=8.681" 1-1 10861' ~ ÆRFORA TON SUIVMARY RB= LOG: BHCS ON 03/07/85 ANGLE AT TOP PERF: 33 @10893' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ? 6 10893-10916 S 04/26/91 3-3/8" 13 10893 - 10916 0 02/28/92 3-3/8" 4 10905 - 10907 0 07/19/91 3-3/8" 4 10924 - 10930 0 04/30/92 4 10930 - 10935 0 04/30/92 3-3/8" 8 10935 - 10952 0 04/30/92 3-3/8" 4 10980 - 10993 0 04/30/92 3-3/8" 1 11014 - 11054 S 04/26/91 3-3/8" 5 11014-11054 0 07/19/91 3-3/8" 1 11066-11118 S 04/26/91 3-3/8" 5 11066 - 11118 S 04/26/91 3-3/8" 4 11130-11150 0 07/19/91 3-3/8" 1 11130-11174 S 04/26/91 3-3/8" 1/3 11198-11206 S 04/26/91 3-3/8" 1/4 11208-11216 S 04/26/91 ~ 11449' 17" LNR, 29#, L-80, .0371 bpf, ID= 6.184" H 11488' I ~ 11505' DATE 03/11/85 02/16/86 12/10/00 02/02/01 07/15/01 10/27/01 COIVMENfS ORIGINAL COr./PLEfION LAST OORKOVER SIS-MWH COIWERTED TO CANVAS SIS-MD INITIAL REVISION RWTP CORRECTIONS CJlTP ÆRF STA lUS CHANGE REV BY 2181' H5-112" OTISRQM SSSV, D=4.562" I GAS LFT Mð. NDRELS ~ST I\¡[) lVD DBI lYÆ VLV LATCH FORT DATE 1 2986 2986 0 CAM/R-20 OOI'llE RK 16 07111/03 2 4569 4494 33 CAMIRD OOI'llE RK 16 07/11/03 L - - 3 6401 5751 51 CAM/R-20 OOIVE RK 16 07/11/03 4 7950 6684 54 CAMIRD DMY RK 0 5 8021 6726 54 CAMIRD DMY RK 0 6 9113 7428 44 CAM/R-20 SO RK 24 07/11/03 7 9183 7479 44 CAMIRD DMY RK 0 8 9910 8012 44 CAMIRD DMY RK 0 9 9980 8062 44 CAMIRD DMY RK 0 10 10338 8322 43 HESlNOVA SO RK 20 :g Z-- 11 10409 8375 41 CAM1 PATCH PATCH '-----t 10390' 1--5-1/2"TELEDYNEMERLA lBGPATCH :g Z COVERING GLM#11, ID= 3.75" l 1 I 10484' 1-1 5-1/2" BOT PBRASSY I Z z I 10504' 1-1 9-5/8" X 5-112" BAKER3H A<R I W} ~ - II 1100560140: HI., 5-1/2" X 4-112" XO ~ 4-1/2" 011S XN NIP NO GO, ID = 3.725" I --- 1 10611' H ~ 10612' 1-1 I 10591' 1-1 17 -11 8 r-J ~ i. ...... ~ ~ ~ ~ . 11163' I 11180' I 11142' I 11363' I 11178' 11248' 11344' ) SAFETY NOTES: ***WAlVEREDWB...L(02/08/03 WAlVER)*** TX IA COMMUNICATION, PASSES NFT. TB...EDYNEnVlERLA PATCH RAN ACROSS GLM#11. VERY DlFRCUL T TO PULL OGLV. 4-112" BAKER SHEA ROUT SUB I 4-1/2" TUBING TAIL 1 ELMDTTLOGGED 05/11/86 I H SAND I 1-1 CA- RKED - 04/21/91 I H 14 IBP STEEL BANDS - 06/19/92 1 H CA-ROO -10/011891 I- 4" TTL FINGER ON TOP OF BP & BKR BP RUBBER B.M\lT, 3-3I8"X10" & CAR-20 11/07/90 H CA-R-20 - 05120/891 H BAKER BP RUBBER ELEMENT - 11/13190 I FRLOHOE SA Y UNT \NELL: 17-11 PERMIT No: 1842440 AR No: 50-029-21259-00 SEC22, T10N, R15E, 4700.31' FB. &2682.68' FNL BP Exploration (Alas ka) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/13/03 Well Job # Log Description Date Blueline Color Prints CD NK-14 [ C{ l,C' O(~/,~ :SBHP SURVEY 04~20~03 1 NK-08A ~_C~ ~. O'Z.ci SBHp SURVEY 04/19/03 NK-20 T'C~'~ ~ i ~ J SBHP SURVEY 04120103 NK-21 [c~,G~~-~, SBHP SURVEY 04/19103 1 NK-07A ~ [, {~, ~ SBHP SURVEY 04121103 4-181S-30 i~. i ~ ~ PSP GLS 0411S/03 '1 1-33B/L-24 .'~Cl~. ~ .~.~' LDL 04/19103 3-45/M-29 i ~'~ - 0.~ i INJECTION PROFILE 03127/03 1 D.S. 15-47 IClr-A ~t'l ~- LDL 03121/03 1 D.S. 17-11 I ~ ~- - o~,~-~t-~ GLS 04~27~03 1 D.S. 18-14A l~C-~. OO"~ LDL 04~03~03 D.S. 13-29L1 ?-O'~- ' C~c~ PRODUCTION PROFILE 04~06~03 D.S. 18-03A t~Z~ -- [.~7 ~ LDL 03~27~03 D-05 t"tO, ~O ~, PRODUCTION PROFILE 04113/03 1 D.S. 9-20 %~'~. ~ ~ [ INJECTION PROFILE 04115/03 E-13A I cl"~ ' OO '7,.-, SBHP SURVEY 04~24~03 D.S. 1-28 i'~: O4~.z~ CHFR 03131/03 D.S. 4-18 i ~.r.~ ~ ~, _~-.~ FLOWING BHP & TEMP 04/13103 J-23 I~ ~ · O ~ ~ LDL 04~25~03 1 N-20A tq~ - t ~ ~-~ CHFR 04/10103 1 D.S. 1-34 ! ~ -- I t ~--{' CHFR 03/29/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T,O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FrN: Beth MEMORANDUM TO: THRU: FROM: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation CommisSion DATE: DeCember 15, 2000 Tom Maunder, P. I. Supervisor Chuck Scheve; SUBJECT: Petroleum Inspector Safety ValVe Tests PrUdhoe Bay Unit Drill Site 17 . . Friday, December 15, 2000: I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve system testing.. As the attached AOGCC Safety Valve System Test Report indicates I WitnesSed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on Well 17-4 Failed to close on its initial test. After this valve was serviced and the hyd lines flushed it operated properly and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the wellhouses on this locatiOn while witnessing SVS tests. All the wellhouses and associated equipment appeared clean and in good cOndition Summary: I witnessed SVS testing at BPX's PBU Drill Site 17. PBU DS17, 15 wells 30 components 1 failure 3.3% failure rate~ 19 Wellhouse inspections Attachment: SVS PBU DS17 12-15-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential Alaska Oil and Gas Conservation COmmission Safety Valve System Test Report Operator: BPX Submitted By: Chuck Scheve Date: 12/15/00 Operator Rep: Mark Womble FieldfUnit/Pad: Prudhoe / PBU / DS 17 AOGCC Rep: Chuck Scheve Separator psi: LPS 165 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gl-NJ, Number Number PSI PSI Trip Code Code Code Passed G^S orCYCLE 17-01 1800550 165 150 130 P P OIL 17-02 1800700 165 150 100 P P OIL 17-03A 1972160~ 165 150 110 P P OIL 17-04A 1960500 165 150 120 P 5 12/15/00 OIL 17-05 1800960 165 150 110 P P OIL 17-06 1801320 17-07 1810660 165 150! 140 P P OIL 17-08 1810740 17-09 1810900 165~ 150 100 P P OIL 17-10A 1991100 17-11 1842440 165 150 120 P P OIL 17-12 1842450 165 150 120 P P OIL 17-13 1841790 165 150 110 P P OIL 17-14 1841660 165 150 140 p P OIL 17-15A 1991310 17-16 1920910 165 150 130 p p OIL 17-19A 1970550 165 150 130 p P OIL 17-20 1921150 165 150 120 p P OIL 17-21 1921250 165 150 130~ p p OIL Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.3% [] 9o Day Remarks: Surface Safety on 17-4 failed to close, it was serviced and retested. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-rN: Sherrie NO. 9606 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/1/95 Well Job # Log Description Date Field: Prudhoe Bay Floppy BL RF Sepia DIR MWD Disk p.S. 7-3A .¢~"~,~' ~ ~ 'CNTG 95071 !. 1 1 D.S. 14-34 <~,~-~ \'~'~ PROD.P.ROFILE 950714 I 1 ... D.S. 16-.!3 v<~l r~.'~ INFLATABLE BRIDGE PLUG 950713 I 1 D.S.. 17-7 ~ ~' (^ ~,~" PROD PROFILE ~1 ~ 071 ~ 1 1 D.S. 17-11 ~ ~{ ~-~l-~-i~ ~RODpRORLE 950715 1" 1 ,, ,,, ..... ,, __ SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 7/7/95 NO. 9557 GeoQuest ~, 1~ 500 W. International Airport Road . .. ~)~)' ~ / Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 __,~ ~, ~..~// ..~. tk~ , ATTN: Sherrie . ~/'/?;;;~-- U~') _A'v"~ ('~ {) .~A Attn: Larry Grant /~ / ~.~| ,~q Uik,.,,~ 3001 Porcupine Drive ~) Anchorage, AK 99501 ~jo~ L~~sc ~0~ Field: Prudhoe Bay Floppy Well riPt Date BL RF Sepia DIR MWD Disk D.S. 4-24" /'95181 CNTG/ ~/' 950513 1 D.S. 5-6A ~ 95226 DUAL BURSTTDT-P/ 950630 1 D.S. 1-4 ") ~ ~_ (',,~ PR. OD PROFILE 95061 3 I '. 1 D.S. 1-15 ~/~' ~"7 POGLM SETTING RECORD 950617 1'. 1 D.S. 3-22 cA' '~~! ~-~'2 RSTA 950601 I 1 D.S. 9-40 ~(.5 PERF RECORD 950613 I 1 D.S. 11-31 q ~ I~.-"~' DUAL BURST TDT-P 950612 I'~. 1 D.S. 16-21 ~ %~l,--- PROD PROFILE 950612 I . 1 D.S. 17-3 ~ G ~"l ~ PERFRECORD 950614 I 1 D.S. 17-11 ~ ~ ~k[ GAS LIFTSURVEY 950611 I I RECEIVED JUL 0 7 1995 DATE: Alaska Oil & Gas ~o~s. uu.,,m~s~on A~chorage SIGNED _ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date: Subject: From/Location: P.O. Box 100360,__.,nchorage, AK Feb 1 1, 1994 Transmittal #: 94021 BHP Report '~ohn Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date Tool Type Run, Scale t Contractor Number (M-D-Y) 1-9 12-17-92 BHP - I Camco 1-14 8-11-92 BHP - I Camco 1-14 8-11-92 BHP Camco 2-2 1-10-93 BHP Camco 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP - i Camco 3-15A 3-20-93 BHP - t Camco 3-20 12-18-92 BHP 'I Camco 4-7ST 5-17-92 BHP - I . Camco 4-14 1-9-93 BHP -t Camco 4-29 12-28-92 BHP t Camco 4-42 4-27-92 BHP t Camco 5-9 2-21-93 BHP 't Camco 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Camco 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - t Camco 9-24 2-15-93 BHPI Camco 9-40 1-25-93 BHP - Camco 9-51 3-20-93 BH P - Camco 12-7A 12-6-92 BHP - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BHP - Camco 13-20 7-4-92 BHP - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BHP - Camco 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP Carn(~ 17-21 12-21-92 BHP Camco 18-15 6-14-92 BHP - Camco ARCO I ~ I, a I~ ~ A~nlcR~chflelclComlmnY RECEIVED FE~ I,: 199~ Alaska Oi/ & ~as Cons. '~nchorage C°rre~isSion ARCO ,~ls_~ks; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED HOLE FINALS Y/'~/~ 3-~ 7-31-93 InJ Profile 2~ -~ o ~-~-~3-17 7-31-92 InJ Profile Prod Profile ~ 1, 8-4-92 lnJ Profile Run 1, Prod Profile Run 1, ~od profil~ ~ l-ff~__* ie.-~.~i 7-31-92 Run 1, ~?-! 1. 8-3-92 Prod Profile ~ 1, C~mco Please sign and return tl~.e attach~l copy as receipt of data. RECEIVED B~~,~~ RE'CEIVED Sonya Wallace OCT 0 5 1991 APPROVED_,~~/I./~_ AT0-1529 Trans# 9220~ v - Alaska Oil & Gas Cons. Commission Anchorage # CENTRAL ~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF AI2~KA TEXACO * The correct well ~me is 16-29A not 16-29ST. ARCO b.l:n_q_ Ica, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO CASED HOLE FINALS 6-6-92 Prod Profile Run 1, 6-6-92 Inj Profile Run 1, 6-5-92 Prod Profile R~n 1 6-7-92 Prod Profile Run 1, 6-9-92 Prod Profile Run 1 6-7-92 Inj Profile Run 1, 6-8-92 Inj Profile Run 1, 6-12-92 Jewelry ~ Run 1, 6-12-92 Gas Entry ~/ Run 1 6-8-92 GR/CCL Run 1. 6-4-92 Inflatable Bridge Plug/CCL Run 1. 2' & $' Camco 5" Camco 5" C_~mco ~' Camco 5" Camco o 5" Camco 5" Camco 5" Camco 2' & ~' Camco 5" Camco 5" Camco Please sign and return the, attached copy as receipt of data. RECEIVED BY Have A Nice Day! ~ F C ~ i'~/E D ) jUL '1 ~-~99~- APPROVED_ ~/~/ Sonya Wallace AT0-1529 ~iaska 0il & aaa Con~. C,~nmissi0n Trans# 9214T A~choraga # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ALASKA .AND GAS CONSERVATION CC 'IlSSION REPORT OF SUNDRY WELL OPE' ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing 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 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2437' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number/approval number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11505 feet 9226 feet Plugs(measured) Bridge Plug @ 10998' MD (top). Effective depth: measured 11445 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2000# Poleset 110' 110' Sudace 2437' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 2508' Production 10790' 9-5/8" 500 sx CIG & 300 s× CS II 10861' 8731' Liner 937' 7" 340 sx CiG 11488' 9213' Perforation depth: measured 10893-10916'; 10924-10952'; 10980-10993'; (isolated below Bridge Plug: 11014-11054'; 11066-11118'; 11130-11150') true vertical 8757-8777'; 8784-8807'; 8831-8842'; (isolated below Bridge Plug: 8860-8892'; 8901-8942'; 8951-8975') Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10514' MD; 4-1/2% 12.6~, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 10504' MD; 5-1/2", Otis SSSV RQM @__2.'L81' MD 13. Stimulation or cement squeeze summary l\ L ~ L. ! v ~, ~ Intervals treated(measured) See attached, jU~,~t ~: ?_ l~joj~ Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons, C0t~fft[ss~o~ 14. Representative Daily Averaqe Production or Iniection Data r,,,~ ..... ~'- Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 616 654 2493 -- 355 1190~ 2629 3147 -- 271 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. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 847/9 DRR cc: SW, JWP 17-11 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG & SHUBLIK 4/23/92: MIRU & PT equipment to 4000 psi. RIH w/CT & loaded the wellbore w/seawater, then pumped 20 bbls slurry containing 2500 lbs 20/40 mesh sand, to isolate the Zone 4 perforations at: 11014 - 11054' MD (Z4) 11066 - 11118' MD (Z4) 11130 - 11150' MD (Z4) Ref. Log: BHCS 3/7/85. POOH w/CT. Rigged down. 4/24/92: RIH & tagged top of sand plug at 11041' MD. 4/25/92: RIH w/CT & pumped an additional 12.5 bbls of slurry containing 1300 lbs 20/40 mesh sand. Made final tag at 11043' MD. POOH w/CT. Rigged down. 4/26/92: RIH & tagged hard top of sand plug at 11042' MD. 4/27/92: RIH w/CT & pumped an additional 9 bbls of slurry containing 1250 lbs 20/40 mesh sand. Made final tag at 11005' MD. POOH w/CT. Rigged down. 4/28/92: MIRU & RIH to tag sand plug at 11001' MD. on top of the sand plug. POOH. Rigged down. RIH w/dump bailer & dumped 125 lbs of CaCO3 4/30/92: Added perforations: 10924 - 10952' MD (Shublik) 10980 - 10993' MD (Shublik) Ref. Log: BHCS 3/7/85. 5/2/92: MIRU & PT equipment to 8000 psi. Pumped a Hydraulic Fracture Treatment, using 12/20 mesh & resin coated proppants, through the perforations above the sand plug at: 10893 - 10916' MD (Sag) 10924 - 10952' MD (Shublik) 10980 - 10993' MD (Shublik) Ref. Log: BHCS 3/7/85. Pumped 574 bbls Gelled Pre Pad @ 30 bpm, followed by Shutdown. ISIP @ 1650. Resumed pumping 1060 bbls Pad @ 30 bpm, followed by 872 bbls Crosslinked Slurry at 1 - 10 ppg, followed by 251 bbls Flush, followed by Shutdo~n~...- w/proppant stages Placed a total of 152,000 lbs of proppant into the formation. 5/5/92 & 6/2/92: Performed proppant/sand plug fill cleanouts. 6/4/92: Rigged down. EIVED JUN 2 2 1992 Alaska 0il & Gas Cons. o0rnm[ss~.or~ Anchorage RIH w/CT mounted Inflatable Bridge Plug & set the plug at 10998' MD (top), to isolate the lower perforation intervals (listed above). POOH w/CT. Rigged down. Returned well to production w/gaslift & obtained a valid production test. STATE OF ALASKA ALASK,~ 'L AND GAS CONSERVATION C( MISSIOI~ REPORT" F SUNDRY WELL OP'ERATIO I 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 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 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 At top of productive interval 2437' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM Alaska 0il & Gas Cons. Com~tss'~°~ A~hOrage feet 9. Permit number/approval number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11505' feet Plugs(measured) 9226' feet Effective depth: measured 11095' feet true vertical 8924' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2000# Poleset 110' 110' Surface 2437' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 2508' Production 10790' 9-5/8" 500 sx CI 'G' & 300 sx CS II 10861' 8731' Liner 937' 7" 340 sx CI 'G' 11488' 9213' Perforation depth: measured 10893-10916';10924-10952';10980-10993';11014-11054';11066-11118';11130-11150' true vertical 8759-8779';8785-8809' ;8832-8843';8860-8892';8901-8942' ;8951-8967' Tubing (size, grade, and measured depth) 5-1/2",17#,L-80,PCT @ 10514' MD; 4-1/2",12.6#,L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BeT 3-H pkr @ 10504' MD; 5-1/2" Otis SSSV RQM @ 2181' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure 600 50O 25O0 1100 2000 3000 Tubing Pressure 35O 360 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. Signed ~~ ~ Title FS-2 Regional Operations Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DflJPLICATE ~.~.~ILY REPORT OF WELL OPE ~I~...~'IONS DS 17-11 Perforating Operations: ARCO Alaska, Inc. perforated DS 17-11 at selected intervals in the Shublik formation of the Prudhoe Bay Unit on 4/30/92. The intervals perforated were the following: 10924-10952' MD & 10980-10993' MD (Reference Log: SWS-CET dated 3/23/85). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 4/30/92. RU perforating unit, pressure tested BOP's 4000 psi and lubricator to 3500 psi, okay. S.I. well, RIH and perforated 10980'-10993' MD at 4 SPF, POOH, and confirmed all shots fired. RIH and perforated 10924'-10952' MD at 4 SPF, POOH, and confirmed all shots fired. (ref: SWS-CET of 3/23/85). Rigged down and secured well. RDC: 6/4/92 RECEIVED JUN - B t992 Alaska 0il & Gas Cons. L;o[fliBIS5~o ' Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-15-92 REFERENCE: ARCO CASED HOLE FINALS J~-/~ ? 2-26 7~--7s' 3-1 2.c--~? 4-30ST 2{/~// 12-26 4-28-92 CCL (Per/) R._- 1, 5" 5-4-92 Peri Record Run 1, 5" 4-26-92 Completion R,,- 1.5" 5-5-92 Completion Run 1.5" 4-28-92 CCL (Peri) R-n 1.5" 5-5-92 Peri Record R-n 1.5" 4-30-92 Peri Record R-n 1.5" Please sign and return the attached copy as receipt of data~ RECEIVED Have A Nice Day! Sonya Wallace APPROVED ATO- 1529 Trans# 9210~'-~ Atlas Sch Sch Sch Atlas Sch Sch # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIP~ PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO M~'f 2 ~ '1992 AlaSka Oi~ & 6a~ Cons. Gommlssio~ /0 ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 3-8 2-25-92 ~ 1- ~'~ 3-35 2-21-92 ?/-~' i 4-3 2-9-92 4-3 3-2-92 ?J'- ~ 4-7ST 3-2-92 ??-~ 5-14 2-11-92 ~Z~z ? 6-21 2-22-92 ?°~/~? 9-43 2-12-92 ~/~-z~, 11-3A 2-23-92 ~3~/zz~-14-32 2-28-92 2-28-92 GR/Perf R~m 1, 5" HLS Collar R~,n 1, 5" HLS CCL/Perf R,m 1, 5" HI~ Perf Record R-~ 1, 5" HIS Perf Record R~_m 1, 5" HLS Perf Record R~m 1, 5" HIS Perf Record R~m 1, 5" HLS CCL/Perf R~m 1, 5" HLS Perf R~_m 1, 5" HLS CCL/Perf R!m 1, 5" HLS Perf Record R~m 1, 5" HLS Perf Record R~_m 1, 5" Please sign and return the attached copy as receipt of data.l~,~ C,, ~ ~ ~'' O RECEIVED BY Have A Nice Day! Sonya Wallace AT0-1529 Alaska Oi~ & Gas Cous. Co~niss~on APPROVED ~ ~s~ 920 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 11-3A is 50-029-20666-01. ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOT.~- FINALS - j~12 ~2- ~ 12-29-91 Prod Profile Run 1, 5" ,~/~-/II ~/_~,.2~-S~2~ , 12-2~91 Temp S~ & T~ ~ ~-1, 2" ~ ~ ~ ~ -~/ 12-2~91 InJ ~offle ~ 1, 5' 9 ~ ~ 12-28-91 Peri Bre~do~/Temp/Sp~er ~ 1, 5" . ~~~ #1 12-~91 Peri Bre~do~ ~ 1, 5' ~~3 ~ ~ ~ Det~t ~ 1,5" ~ ~ ~ ~ ~/~ ~. 91 ~od Profile ~ 1, 5' ~~ ~ ~/~ 1-6-92 ~ Det~t ~ 1, 5" ' ~-~/ ~ 12-31-91 InJ Profile ~ 1, 5" ~ ~6~ ~ 1-3-92 PITS ~ 1, 5" ' /~ ~ >~12-~91 ~d ~offle ~ 1, 2"~" /~f~ ~ ~ / ~ 12-2~91 ~ Det~t ~m 1, 2'&5' )/ffi~ -- 12-2~91 ~ Det~t ~ 1, 2"&5" Pl~e s~ ~nd retm ~e a~ch~ c~ ~ receipt of ~n~ W~ce APPROVED ATO- 1529 ~ns# 9201 CalTIC0 Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL ~ # CHEVRON D&M ~ # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FH,F~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED Alaska 0il & (~ C~ns. STATE OF ALASKA ALASKA. .AND GAS CONSERVATION CC ,IlSSlON£~ :~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate X Plugging ~ Perforate ~ Pull tubing ~ Alter casing Repair well Other X 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22 T10N, R15E, UM At top of productive interval 2437' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N. R15E, UM 5. Type of Well Development X Exploratory StralJgraphic 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number/approval number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11505 feet 9226 feet Plugs(measured) 11180', w/sand cap to 11095' MD. Effective depth: measured 11095 feet true vertical 8924 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2000# Poleset 110' 110' Surface 2437' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 2508' Production 10790' 9-5/8" 500 sx Cl G & 300 sx CS II 10861' 8731' Liner 937' 7" 340 sx Cl G 11488' 9213' Perforation depth: measured 10905-10907'; 11014-11054'; 11066-11118'; 11130-11150' true vertical 8768-8769'; 8860-8892'; 8901-8942'; 8951-8967' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10514' M D; 4-1/2", 12.6~, L-80, PCT tail @ 10612'M D Packers and SSSV (type and measured depth) BeT 3-H packer @ 10504' MD; 5-1/2", Otis SSSV RQM @ 2181' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Averaoe Produ~ion or Ini~ion Da~'~¢''" Anch0rsge OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1041 2933 1576 -- 251 2718 '/ 3073 3809 -- 516 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. Signed Title Sr. Area Operations Engineer :orm 10-404 Rev 06/15/88 770/5 SLW/SRC cc: SW, JWP SUBMIT IN DUPLICATE DS 17-11 DESCRIPTION OF WORK COMPLETED TUBING PATCH, CTU CEMENT SQUEEZE, & FRACTURE TREATMENT OF SAG/Z4 4/21/91 4122/91: RIH & pulled Inflatable Bridge Plug @ 11185' MD (set 11/15/90) from the wellbore. Rigged down. 4/24/91: RIH w/Tubing Patch & set patch @ 10390' - 10412' MD over GLM #11 leak @ 10409' MD. POOH. RD. 4/26/91: An Acid Wash & CTU Cement Squeeze for profile modification, were performed as follows: MIRU & PT equipment to 4500 psi. Loaded wellbore w/seawater & RIH w/CT to wash the perforations at: 10893 - 10916' MD (Sag) 11014 - 11054' MD (Z4) 11066 - 11118' MD (Z4) 11130 - 11174' MD (Z4) 11198 - 11206' MD (Z3) 11208 - 11216' MD (Z3) Ref. Log: BHCS 3/7/85. Pumped 69 bbls of 15% HCl w/10% Xylene, followed by 70 bbls of 12% HCI - 3% HF, followed by 71 bbls of 2% NH4CI3. Proceeded pumping 20 bbls of PVA cement followed by 40 bbls of PVA cement w/aggregate, squeezing the perforations (listed above) at 2500 psi maximum squeeze pressure for one hour. Placed 11 bbls of cement behind pipe. Contaminated cement & jetted out contaminated cement from wellbore. POOH. Rigged down. 7/1 7/91: MIRU & RIH w/CT to bottom, then pumped 5 bbls of sand slurry (750 lbs of sand/silica flour) to spot a pre fracture treatment sand plug to cover the lower squeezed perforation intervals. Rigged down. 7/1 8/91: RIH & tagged top of sand plug at 11163' MD. 7/1 9/91: Reperforated: 10905- 10907' MD (Sag) 11014 - 11054' MD (Z4) 11066 - 11118' MD (Z4) 11130 - 11150' MD (Z4) Ref. Log: BHCS 3/7/85. 8/30/91: MIRU & PT equipment to 9500 psi. Pumped a Hydraulic Fracture Treatment, using 12/18 mesh proppant, through the open perforations (listed above). Pumped: a) 299 bbls Pre Pad, @ 50 bpm, followed by b) Shutdown. ISIP @ 2300. Resumed pumping: c) 1420 bbls Crosslinked Pad w/5% Diesel, @ 50 bpm, followed by d) 1121 bbls Cross Linked Slurry, w/proppant concentrations @ I - 12 ppg, followed by e) 254 bbls Flush, followed by Shutdown. Placed a total of 209,000 lbs of proppant into the formation. Rigged down. REEE!V~D 9/1/91 10/9/91: Performed wellbore proppant fill cleanouts to 11150' MD. I 0/26/91: Pumped a scale inhibition treatment. ::UV - 6~ Flowed well intermittently. ~,~laska Oii ,~o Gas Cons, Oom~f~ Ancho, age Placed well on production & obtained a valid production test. The last tag run of 10/23/91, tagged bottom at 11095' MD, indicating an additional fill cleanout may be required in the near future. F'~O~ BOX ~88~68 ANCHORAGE~ ALASKA DATE' 8-7-9i REFERENCE: ARCO CASED HOLE FINALS i-7' 7-t7-9t DIFFERENTIAL TEMP t-Tx 7-t 7-9t F'DK-t O0/GR/CCL t-22' 4-t4-9t PERF RECORD ** 2-3 t ?-2i -9t COLLAR/F'ERF ~1-~'7 4-37" 7-20-9t COLLAR _.~w,~_36 x 7- t 8-9 t GR-CCL ~J 'r-,'5-36- 7-t 9-9~ F'ERF-PACKER 6-4~ 6-7-9t PERF RECORD 6-7~ 4-t0-9~ PERF RECORD 7-33- 4-28-9i COLLAR/PERF 9-9"" ?-i 7-~i VERTILOG ~ 9-34- 7-6-9i F'ERF RECORD O' ~,~- 4 2, 7-3-9t F'ERF RECORD it-i' 5-i2-9i F'ERF RECORD it-3' 5-i8-9i F'ERF RECORD t t -5. - 7-t 2-9i F'ERF RECORD i 3-2~ 7- i 5-9 i JEWELRY-PERF i 6-24' 7-8-9i COI. LAR i7-3- 7-7-9i PERF RECORD i 7-i i- 4-24-9i COLLAR i 7-i i~ 7-i 9-9i COLLAR/PERF RUN i, 5" RUN i, 5' RUN i, 5' RUN RUN i, 5' RUN i, RUN i, RUN i, RUN t, 5" RUN RUN i, RUN i, RUN i, RUN i, RUN i, RUN i, 5' RUN RUN RUN RUN RUN i, RUN i, 5" HL$ ATLA~ A~LA$ HL$ ATLAS ATLAS $CH $CH HL$ HL$ HL$ ATLAS HLY HL$ HL$ HL$ HL$ HL$ ATLA~ HL$ HL$ ATLAS PLEASE SIGN AND RETURN THE ATTACHED RECEIVED By~~I~_~ HAVE A NICE DAY! SONYA WALLACE ATO-i529 DISTRIBUTION 'CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL COPY AS RECEIPT OF DA'FA. , uc. 7 2 mD? PHI L L I F'S ~nChorage' ~mmia~lba PB WELL FILES R & D BPX STATE OF ALASKA TEXACO , THE cORRECTED AF'I~ FOR i-lB IS 50-029-2i~)07-~)t ** THE CORRECTED AF'I~ FOR 2-3 IS 50-029-20077. F'. O. BOX i ANCHORAGE, ALASKA DATE: ?-~t-gi REFERENCE ' ARCO t -22 ~-24 6-27-9~ t -25 7-4-9t 2-9 6-29-9i 5-3 6-23-9i 9-2 ~-B-gf 9-35 ~-e-gf ~ f ~-f f 6-2~-9 f e-~ ~-5-9~ CASED HOLE FINALS PROD PROFILE PROD PROFILE F'ROD F'ROFILE PROD PROFILE F'ROD F'ROFILE LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT CASING INSPECTION CALIPER LEAK DETECT PROD F'ROFILE _- PROD PROFILE PROD F'ROFILE RUN RUN RUN RUN c~mmis,~N RUN RUN RUN RUN RUN RLIN RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY ___ HAVE A NICE DAY! $ONYA WALLACE AT0-~529 DISTRIBUTION AF'F'ROVEDi 2~~- TRAN$$ 9 .. $ CENTRAL FILES ~ PHILLIPS '- CHEVRON PB WELL FILES D & M R & D ~ EXTENSION EXPLORATION ~ BF'X - EXXON ~ STATE OF ALASKA MARATHON TEXACO - MOBIL ir * THE CORRECTED BOTTOM LOG INTERVAL IS 4,900 FEET CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO -CAMCO CAMCO CAMCO ARCO ALASKA, INC. P.O. BOX tO0360 ANCHORAGE, ALASKA 995--r-~ DATE: 7-t2-9t REFERENCE: ARCO CASE ~-J ~ 6-5-9t t-~ t 6-5-9~ ~ -2t 6-7-9J 2-4 6-30-9~ 4-~ 6-t ~-9~ ~P4-36 6-t 9-9i ~4-37 6-2t-9t ~'~'_ ~4-37 6-24-9t ~l~ -33 7-2-9~ ~/~ 5-35 6-39-9J 7-~5 6-3~-9~ . 9-6 6-~6-9~ 9-8 6-5-9~ ~-9 6-23-9~ ** 9-~ 4-~ 7-9~ 9-~8 6-~ 3-9~ 9-33 6-~ 4-9~ ~ 0 - If69-47 6-m-9~ ** t t-~ 4-t 7-9t ~ t -5 6-~ 2-9t t2-t2 6-~ 6-9t i3-iD 6-t7-9t **** ~-~6 6-t 7-9t ~6-~6 6-t3-9t t 7-t t 5-8-9t D HOLE FINALE PROD PROFILE-" GR-COLLAR J PROD PROFILE/ CCL-PERF/ GAS LIFT/ CBT/ CET~ F'FC-GR (F'ACKER SETTINGY CBTf CETJ F'FC-GR (PACKER SETTINGY GR-CCL~ COLLAR-F'ERFj PRODUCTION F'ACKER-- SBL/GR/CCL- CCL-PERF-- LEAK DETECTIONs' PERFORATION BREAKDOWN/ COLLAR-PERF~ INJ PROFILEJ JEWELRYJ LEAK DETECTION-~ INJ PROFILE~ DATA FRAC '[EMF'~ LEAK DETECTION--~ F'RO~ PROFILE~-- PDK--~6~/GR/CCL-BORAX~ LEAK DETECTION-- INJ F'ROFILE--- INJ PROFILE~ INJECTION/PRODUCTION-' PRISFf-- LEAK DETECTION-. PLEASE SIGN AND RETURN THE ATTACHED HAVE A 'NICE DAY] SONYA WALLACE AT0-i529 DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL RUN t, 5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' ATLAS RUN ~, 5' CAMCO RUN ~, 5" SCH RUN ~, 5' SCH RUN t, 5' ATLAS RUN ~, 2'&5' SCH RUN ~, 2'&5' $CH RUN ~, 5' ATLAS RUN ~, 5' ATLAS RUN t, 5' ATLAS RUN ~, 5" ATLAS RUN i, 5' ATLAS RUN ~, 5" ATLAS RUN ~o 2"&5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' ATLAS RUN ~, 5" CAMCO RUN ~, 5' CAMCO RUN ~, 2" CAMCO RUN ~, 5' CAMCO RUN t, 5" CAMCO RUN i, 5" CAMCO RUN ~, 5" CAMCO RUN ~, ~' ATLAS RUN ~, 2"&5' CAMCO RUN ~, 5' CAMCO RUN t, 5" CAMCO RUN ~, 5" CAMCO RUN ~, 5' ATLAS RUN ~, 2'&5' CAMCO COF'Y AS RECEIPT OF DATA. TRANS~ 9~ BPxF'B WELL FILES STATE OF ALASKA TEXACO . CORRECTED LOG INTERVAL FOR 9-6 IS 67e~-770~ ** REFERENCE MIX UF' ON TRANSMITTAL 9tt59 - POSSIBLE DUPLICATE LOGS *** CORRECTED LOGGED INTERVAL FOR 9-4~ IS t395t-t425~ **** CORRECTED AF'I~ FOR ~3-~6 IS 5e-~29-2~823 ARCO ALA$'KA, INC, - :~ ~;: · P,O, BOX ~00S60 .......... ,,.-- ANCHOF:A~E, ALASKA 995~0 · Z.:.-~-~ - - ~-:~... ........ - ....... ~..... .......... _R ECEI¥£_D: . .... ': JUN-1-1 1991 D A T E: 6- ~ 3 - 9 ~ · ' '-' ~::~ AlaSka Oil & Gas 8ons. Commission .......... REFER'ENCE' ARCO CASED HOLE FINALS · ~"9'53~- ...... ~-~-9~ COLLAR-F'ERF -.' RUN ~, 5" ATLA~ ~ S-2A .... 6-2-9 ~ --:ktr COLLAR-PERF~;~ ...... [ ...... '3~---'. ....RUN--4-, -5 ' A~LAS . ~ 4-~2" 5-~ 6-9~ .~'.:~ INJF'ROF .. '~,;~(~.= ' ~ ~-,.. .... "', RUN .~ ,' 5 CAHCO ~ 4-25 5-~ 6-9~ ' 1NJ F'ROF-GR' ' -~(_.:.-;';'-RUN ~ 5' CANCO ......... ~ 4'S6 ....... 5- ~ 6-9 ~ -~-'~,ZNJ -PROF .................. -' ~-~UN---~ .--5-"- --. .......... ~AHCO - 5- 7-9 F'ROF'' .': .- RUN '- · -CAHCO ~ 6.~.~ - 5-~ 9~ ....... ]NJ..PROK, .... ; ............................. RUN ' ' . RUN ~, 5 CAHCO ~J~-~6-22 5-23-9~ PROD F'ROF -'" -~':'~-%=~":' ~ 6-24 5-~ 9-9~=-- -~.= PROD-F'RO~ ~-~'- ~; .............. ~ ....... ... .... '. ,- ........... - ..... - .......... - .- UN ~. --,~ .... -.- ...... CAHCO .-~.~ 7~2 "' 5-8-9t ''~': ";::?LEAK..DETE~..~j?.:~;.--~:':; .... .:.. ~,%~:;=.?.?-_-:~..R -u~-?-?.- ~ 7~2, ~-5~.t 8-9 ~'.-.'~;J~;LEAK;~-DETEC~: .... ' ' :: ' . :'-~ ~v - ~¢T~n~'"'?-' ...... -- - ' .- -.'--~?;:~:~ ;' -'__--'-;- RUN ::NGI ~'~ ';.'." _ :;5~]~INJ PROF -':'-?~;;~;::;;:? '-''~' ,' '-' ;-c:)T ?~':~'- -;'] ?RUN ~:-~:;~,5._',--~'~]':~-CAMcO F'LEAS;E SIGN AND RETURN THE ATTACHED COPY AZ RECEIPT OF DATA -' : ' · - . · - RECEIVED BY ........ -~ _ . '." . .... j~-z.-" :._ .- ~, .'. . _--.` _. _ - . HAVE A NICE DAY~-._ '...-..._.~:...-~ .---?..:,~,':::.,-~-~'..::~--..',.. .----_::-~'¢-.~-m~-~,~:-:..--'~ '. - -'-.-- :- ..:. ~-~-.~_;' ~ . :_-?-'-:.',f _:::--:':-:~-,~5:,--x-:2Z:~_=_ ~ ]'~ , :~f:~._~~-~:~f~:~~~'tZ:'~r75~ .- . . . .... : . ..-::_.,:.' .... - .._ · ._ :._...t~.;:. :. ...... ·: -;~-.- , . . _-_~ _:~.~-__:.~:~ .DISTRIBUTION ..................... -'~ '-' . - -.. ~t~ -_ .- .. - . ... - . _ " ~ CHEVRON : -" .... ~': F'B WELL-:~FILE~ -~'-'-- ' .... D & M ........................ = .................. R &'--D .... :'.~ ......... ' . . ...... ~ EXTENSION EXPLORATION ' ~ BF'X . ' ' ':' ' ~ STATEs'F--ALASKA- - ...... '' -EXXON ............... ~ .... ~' --- MARATHON TEXACO ~ MOBIL ................... . .. ~ ~ .. : ' ' - ' ...... ' '._-.~ ~':.:~;6.-' - '. ~":~,~::;. - ---_ -:L'- >- · r ' - - - ' · '..' ...... _-. '~..' '.. -.::~-.~N;~,r'Y-', ~'" '~ ..... ..::~'~7~ ~--:~'~" -' :: -" ~' - .... ., . ......... ,.,-.~i~. · . ......... . . . . ~ .~- '..... - -.. ~ ~-_.'~-:_- .'_ .-_. -:?. _. - - --, - . .~_ . ~ ..-~,:~ ...... . ..... - ..::.:~. .:..- ._ ..... . .t;~-:...[- .. ~, ~.~..a~_. .- ........... . --.-_ . , .... .- . - . ..~. -: ~* _ ................ ~- ~ .- .~.. _ ........ . ..... ,.._ . ARCO ALASKA, INC P.O. BOX ~0836~) ' ANCHORAGE, ALASKA 995~0 ..... - ............. DATE' t -2i -9i REFERENCE' ARCO CASED HOLE FINALS ~i-6 i-7-9i F'DK-i,:),~/DIFF.CORR. S'IGMA & F'ORO RUN ~ t-29 i'2--t2-98 F'RODUCTION PROFILE RUN ~3--3 i 2-23-90 1' EMF'ERA'FUF~'.E RUN --4-3 t '~- t "~-of.] F'RODUCTION PROFILE RUN '"'-.6-24 t 2-i 7-90 F'RODUCI'ION F"ROF'ILE RUN ,- - .....' ....'E RUN '""?-8 i o i 2-9~') TEHPI.'.Rf4 fUR '~?-i& t~-'~3-9~, INJ PROFILE RUN '~7-28 t 2-t 7-90 FLOWMETER/TEMP' SUF,'VEY RUN "-,.. ?-34 i o t 9-9¢ F'I TS RUN '-,,~t 3--7 t 2-t &--9¢ PITS RUN --43-.24 t2-i2-9~) INJ PROFILE - .RUN '"4 3-25 t2-t2-9~'D INJ PROFILE RUN ""i 3-3° t ~-t 4-m¢ I'NJ PROFILE RUN .. .. · ----t 5-i 3 t -~_ .o'z-e~.-~ PF<ODUCTION PROFILE RUN --46-24 t 2-24-9e PRODUCTION PROFILE RUN -~-t7-tt i2-24-9¢ F'ROOUCTION F'F:OFILE RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY SHARON WIL~'ON ATO-t 52? APF'ROVED~ TRANS-$ 9i~2t ATLA.? C'AHCO CAMCO CA~"~CO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO C At'i C 0 CAMCO CAMCO CAMCO CAMCO DISTRIBUTION ' CENTRAl_ F ILE~' '" CHEVRON '~1' D & M '~. EXTENSION EXPLORATION ~ EXXON MARATHON ~ MOBIL ~r F'H!LLIF'$ PB WELL FILES' R & D BPX . STA1'E OF ALASKA TEXACO RECE VED dAN 2 9 1991 A!aska Oil & 6.*-s Cons. Commission ' '- Anchorage ARCO ALASKA, INC, F'~O~ BOX t~6'36() ANCHOF,'AE..E, ALASKA 995i REF'ERli-]NCE' ARCO CA;"CFD HOLE F'INAL£' i i i i F'WD S-''~''~'.~__;i i _q_or:;. ; ,. ,F-' F;' Fi F:,. _ .. F:'F.;'F)F l L_E,, _ RUN i , ,.~ ,- ' ,, ._ ~_lr.,' ~ : '~-'z'o i ~':"-.'Si -9':D PRC,'D PRi]F£LE r"l '~ ._, ..o i i -.--~a--o,:, ~']flL LAR/F'ERF RUN i , &--i ~'-; i i - ':"= - (;' ,':, F'DK-~ ¢,,:-}/6R/CCL RUN 6-2~ i i -26.-9,3, F'DK-I ¢¢/GR/CCL RUN i: '7-9 t i-S-9,:Z) F'Ii'$/£'F'.[N.N.F'R RUN i , 7.-25 i t-:34-.96, CO/.LAR/F'ERF' RUN i, t i-4 i t-4-96' F'I;.'OD F'ROF'.[L.E F:UN ~ , i i-6 i t-.3:--96, PROD PR,"-:~FII..E RUN i i--i i i i-5-9,'..} F'ROD PRUFZLE RUN I 5-6 i ,':',--Si _c;,-..., i'i]:Z':,'C GAS' TN. I PROFIL[-. RUN i 4---i 5 i i-5-9(-) F'F.:OD PF.'OFii_E RUN i i '2::-4 i i .-2"_:;.-.':.;'0 VERT]:L. OC; RUN i 6- i 9 i '..:;,--3 i - 9,'Z:, COL!_AF;.' RUN 7 .- 7 i i .- ''> - o ;'.'-, F:' r.', r', ~; ~ ,- .... '..,_, ,_, P R C) F" I L E R U f',! 7-°.: i i-:'~-'";':'-;_ , .. PROD F'F:OFTLE.. R'.Uxl,, i , ?-it t 1-''~ c¢,.':', PROf':' PROF]:LE. RUN 2 7-i'" i t-'S-9'~ F'ROD F'I;:OFILE RUN i I/j ~ '~ '" - ''~ "'-'-, ,, ,--.=~., i i .--.:: c;;:; COLLAR/PERF F'<LtN i F:'LE:'ASF .?iC-i".} AND RST.URN TI-iF ATi-ACFiiLO C. OPY AS Ri£CE..[F:'T OF DATA_. HAVE A NICE DAY'! SALLY HOFFECI<ER A T 0 '- i.,.~.":' '-' '";>. C A r'i C 0 (J R r-i C 0 RrL. AS A '[ L A :'--. A'f'L. AZ: C A f'-~ L: 0 ATLA:7 U A r~ r-: 0 C A f'i C O CAMCO C A M C 0 ........ UAtqUU R f'L. RS C A I"i C t_'! CAt'iL;O f-: .-,, .,4 ~-,-~ ~t ~,._.U CAMCO r'AMCO ATLAS i) ISTR]:BUTION CENTR~'aL F:[LE£ C H i!-" V R 0 N D * M EX]'ENSION E. XF'LORATION FXX(]N MARATHON MOBIL ,, F, HZLLiP? PB WELL FILES R & D ~ BPX £']"Ai E OF' ALASKA TEXACO u~, 7 1990 Aias,ka Oil & Gas · ~,uns. C0mmissi0r, Anchorage ALASKA '_AND GAS CONSERVATION C(' VIISSION REPORT 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. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2437' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stra~graphic 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number/approval number 84--244/9-1059 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2437' Production 10790' Liner 937' 11505 feet Plugs(measured) 9226 feet 11445 feet 9191 feet Junk(measured) Size Cemented Measured depth 20" 2000# Poleset 110' 13-3/8" 2400 sx CS III 2508' 9-5/8" 500 sx Cl G & 300 sx CS II 10861' 7" 340 sx CIG 11488' True vertical depth 110' 2508' 8731' 9213' Perforation depth: measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206'; 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951- 8986'; 9005-9011 '; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10514' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth)BeT 3-H packer@ 10504' MD; 5-1/2", Ot~S~~l(~l~l,~l' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached AUG ! ]9.90 Treatment description including volumes used and final pressure ~laS~.0~J .~ (~aS C0rIs, C0~[S$[0J~ ' .~ch0raEa 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1921 1956 4716 -- 247 2008 1686 3800 -- 243 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. Signed Title Sr. Area Operations Engineer Date ~/'/~ ~/~ Form 10-404 Rev 06/15/88 456 DLB cc: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE DS 17-11 DESCRIPTION OF WORK COMPLETED BRIDGE PLUG INSTALLATION FOR WATER SHUT-OFF 1/31/90: Installed an Inflatable Bridge Plug in the well as follows: MIRU, and PT equipment to 4000 psi. Loaded wellbore w/Crude & Meth-Water. RIH w/CT Bridge Plug and set at 11188' MD (middle). Pumped 1.5 bbls of Sand Slurry on top of plug. POOH. Rigged down. 2/2/90: RIH & tagged top of sand at 11180' MD. POOH. RD. Returned well to production and obtained a valid production test. Perforation Summary: Producina Perforations above Bridge Plug: 10893 - 10916' MD Ref. Log : BHCS 3/7/85. 11014 - 11054' MD 11066- 11118' MD 11130 - 11174' MD Isolated Open Perforations below Bridqe Plug: 11198 - 11206' MD Ref. Log : BHCS 3/7/85. 11208 - 11216' MD ARCO Alaska, Inc. Prudhoe BaY,~._.dineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 31, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11, Permit No. 84-244 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DB/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 17-11)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ,.~ I/A I I- UI- /~L/~I',,/~ ALASKA 'LAND GAS OONSERVATION C(~ ,VilSSION APPLICA-rlON FOR SUNDRY APPROVAL ! C ! 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Al£er casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-036O 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2437' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2437' Production 10790' Liner 937' 11505 feet Plugs(measured) RE~E~V~-'D 9226 feet 11445 feet DEC 1. Z i989 9191 feet Junk(measured) &las .0ii& 6as-c0ns" Size Cemented MeasdJ~J~ True vertical depth 20" 2000# Poleset 110' 110' 13-3/8" 24o0 sx cs ,~ 2508' 2508' 9-5/8" 500 sx CIG & 300 sx CS II 10861' 8731' 7" 340 sx CIG 11488' 9213' Perforation depth: measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206" 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951-8986'; 9005-9011 '; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10514' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 10504' MD; 5-1/2", Otis SSSV RQM @ 2181' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation November 1989 Oil x 16. If proposal was verbally approved I Name of approver Date approvedI Service 17. I hereb%certify that.the fo_rego'm_g is true and correct to the best of my knowledge. Signed ~/J~~~~ Title Operations Engineering Manager Date 15. Status of well classification as: Gas Suspended Approval No. ~;;2.. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commissioner Location clearance Subsequent form required 10- ~ ORIGINAL SIGNED BY LONNIE 6, SMITH Commissioner Date SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 225 D. Brown DR!LL SITE 17-11 '--.--- W'A'I'ER SHUT-OFF-INFLATABLE BRIDGE PLUG AFE AP1107 SUBCOMPONENT AFE KS1168 FIELD PROCEDURE , . . . o MIRU slickline unit and pull SSSV. Make gauge/dummy run through tubing and liner to fill at 11,248 ft. Minimum restriction is Otis XN Nipple @ 10,578 ft. MD (ID = 3.813"). Maximum OD of bridge plug is 3-3/8". POOH and RD slickline unit. MIRU coil tubing unit, test lubricator, and run in hOle with 3-3/8" 130 rib inflatable bridge plug. Locate tubing tail at 11,590 ft. MD and Otis XN nipple at 11,578 ft. MD for depth correlations. Set Baker bridge plug assembly with middle of sealing element at 11,188 ft. MD and release. Pump 61 gal of sand slurry (250 lbs sand) on top of bridge plug using 40#/1000gal HPG gellant. Lay sand in while pulling out of the hole with the coil tubing 40 ft. above the bridge plug. Wait 20-30 minutes for sand to settle and pull coil tubing up 30 additional ft. and pump 5 BBL of methanol water at maximum rate to ensure sand is on the packer and not on the liner. 6. POOH and RDMO coil tubing unit. 7. MIRU slickline unit and tag top of sand to verify depth of the bridge plug. 8. RDMO slickline unit. 9. Place well on production. WELL DATA DEC 1.. & Gas Cons, , c mge SBHP FBHP BHT Hole Angle Otis XN Nipple Tubing Tail 3880 psi 2000 psi 200° F 37-40° @ 11,190 ft. 11,578 ft. MD (Ref ELM 5-11-86) 11,590 ft. MD (Ref ELM 5-11-86) 5 4 3 2 COILED TUBING UNIT BOP E0U ! PMEN~ 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSi 4 1/16" STUFFING BOX 3 J 2 H]REL]NE BOP EOUIPMENT 1. 5000 PS! 7" W£LLHEH:) CONN£CIOR rLANG£ 2. 5000 PSI WIRELINE RAUS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC~ F'.O. BOX tO0360 ANCHORAGE, ALASKA DATE' 9-48-89 REFERENCE' ARCO CASED HOLE FINALS 4-? 8-23-89 PRODUCTION PROFILE 2-4 9-2-89 LEAK DETECTION SURVEY 2-t 9 8-24-89 PITS 3-t& 8-25-89 INJECTION PROFILE 4-.5 8-30-8? STATIC TEMP SURVEY 4-i9 8-29-89 STATIC TEMF' SURYEY 4-t 9 8-30-89 TEMP FM 6-t 4 9-t 0-89 COLLAR 7-i '~ 8-3t-89 LEAK DETECTION SURVEY t2-2t 8-30-89 TEMF' SURVEY i3-2:2 8-3i-89 INJECTION PROFILE i4-20 8-30-89 PRODUCTION PROFILE t4-24 8--3i-89 PRODUCTION PROFILE ~4-S4 8-S0-89 PRODUCTION F'ROFILE ~6-4 8-~3-89 LEAK DETECTION ~7-7 5-4 9-89 LEAK DETECTION ~?-~ 5-~9-89 LEAK DETECTION RUN ~, 5" RUN 4, 2" RUN ~, ~"&5' RUN ~, 5" RUN RUN RUN ~, 2' RUN RUN 4, 2"&5" RUN RUN RUN RUN ~, 5" RUN ~, 5" RUN RUNS RUNS ~-3, 5" PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO HR$ CAMCO CAMCO CAMCO CAMCO CAMCO OTIS OTIS RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 TRAN$~ 89~94 CENTRAL FILES PHILLIF'$ CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION -.-'~BPX '~ STATE OF ALA3'KA EXXON MARATHON ~ TEXACO MOBIL ARCO ALA,?I<A, INC,. F'.O. BOX t,3(.)36,3 ANCHORAGE, ALASKA 99518 Il DATE' 9-6-89 REFERENCE: ARCO CASED HOLE FINAI_£ t-.,._° 8-t6-89 TEMF'/FLLI. ID DENSII'Y RLIN t, _,~ · i.-i4 8-i7-89 F'I;:ODUC'FION F'ROFZLE RUN 1, 5' 2-2.'.5 8-':24-89 COLLAR/F'ERF RUN i , 5' S-6 8-o8-89,,._ COLLAR/F'ERF RI_IN t , ~.., · S-28 8-t9--89 F'RODUCTION F'ROFII..F RUN. t , :" 6-'~.,= 8-i 4--89 F'RODUCTIflN.. PROFILE RUN t , _,'=,' it-i¢ 8-t 8-89 INJECTION PROF-ILE/TEMP RUN t, 5' t t-i8 8-2t -89 PRODUC'FION F'ROFIt_E RUN i, 5' t2-28 8-tS--89 F'RODUCTION PROFILE RUN i, 5' i4-32 8-iS-89 LEAK DETECTION RUN t, 5' i5-25 8--:20-89 PITS RUN t, 5' iT-ti 8-t 8-89 PRODUCTION PROFILE RUN i , 5' PLEASE SIGN AND RFTURN THE ATTACHED COPY AS RECEIF'T OF DATA, CANE:O CAMCO ATLAS A FI_AS C. A M C 0 CAMCO CAMCO CAMCO CAMCO CAMCO (;AMC[) CAMCO RECEIVED BY HAVE A NICE DAY! ,':¢ AI.L Y HOF'FECKER A'FO- t 529 DISTRIBUTION CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO * THE CO~.RECTED AF'I~ FOR t-2 IS ARCO Alaska, Inc Prudhoe B =--~,,.-~. n g i n e e ri n g Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 13, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11, Approval No. 9-464 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 17-11) W1-3 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK. 'ILAND GAS CONSERVATION C. ]MISSION REPORT-OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing 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 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number/approval number 84-244/9-464 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2437' Production 10790' Liner 937' 11505 feet Plugs(measured) 9226 feet 11445 feet 9191 feet Junk(measured) Size Cemented Measured depth 20" 2000# Poleset 110' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 9-5/8" 500 sx CI 'G' & 300 sx CS II 10861' 7" 340 sx CI 'G' 11488' True vertical depth 110' 2508' 8731' 9213' Perforation depth: measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206'; 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951-8986'; 9005-9011 '; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10514' MD; 4-1/2", 12.64¢, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10504' MD; Otis SSSV @ 2181' MD 13. Stimulation or cement squeeze summary -~" ~ '~' L 14. Intervals treated(measured) See attachment Treatment description including volumes used and final pressure Representative Daily Average Produ~ion or Iniection Da~'~' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2471 6164 2646 -- 315 Subsequent to operation 2158 5129 3279 -- 300 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. Signed ,~c~//~~~ ~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 105 T. P. Allen. 263-4837 Date ~'/~.~/~ SUBMIT IN DUPLICATE TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: 10. Drill Site 17-11 Description of Work Performed Scale Inhibition Treatment To Scale Inhibit Sag River & Zone 4 Intervals 12. 11. A. B. C. D. E. 50 bbls of diesel 50 bbls of methanol 45 bbls of EDTA with additives and the solid and liquid diverter 236 bbls of scale inhibitor blend 550 bbls of 2% NaCI water w/1000 mg/I of DETPMP F. 50 bbls of diesel 255 bbls of dead crude 5 bbls of diesel RD and released equipment. well to production. Obtained a valid well test. Shut in well for 2 hrs. After this period of time returned 10893-10916, 1 1014-1 1054, 1 1066-1 11 18, 11 130-1 1 174 11198-11206 and 11208-11216' MD (ref. Long Spaced Sonic 3/7/85) June 15, 1989 1. Obtained a valid well test. 2. Performed a fluid level survey on the 5-1/2 x 9-5/8" annulus. Fluid packed the 5-1/2 x 9-5/8" annulus with 475 bbls of dead crude and 5 bbls of diesel. 3. Loaded 50 bbls. of filtered fresh water for blending the EDTA. Loaded 233 bbls of filtered 2% NaCI water for blending the scale inhibitor. 4. Mixed the remaining 2000 gals. of filtered fresh water with 1550# of EDTA and additives. Checked pH, iron content and EDTA content. 5. Flushed pumper with 2 bbls of filtered 2% NaCI water and mixed one of the current acceptable amine phosphonate inhibitor blends. 6. Loaded 350# of solid OSR diverter and 25 gals of liquid OSR diverter. 7. Loaded 50 bbls of methanol, 105 bbls of diesel, and 550 bbls of 2% NaCI water w/1000 mg/I of DETPMP. 8. Batch mixed the 48 bbls of EDTA with 350# of solid diverter and 25 gals of liquid diverter. 9. MIRU pump trucks and transports. Pumped the following fluids down the production tubing: ARCO Alaska, In< Prudhoe B~r~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 6, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11 Approval No. 9-348 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 17-11) W1-3 JUN o lg g ~iasl(a Oil & Gas Cons. Commission Anch0mge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASE )ILAND GAS CONSERVATION ( ~IMISSlON REPOR 'OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number/approval number 84-244/9-348 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2437' Production 10790' Liner 937' 11505 feet Plugs(measured) 9226 feet 11445 feet 9191 feet Junk(measured) Size Cemented Measured depth 20" 2000# Poleset 110' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 9-5/8" 500 sx Cl 'G' & 300 sx CS II 10861' 7" 340 sx CI 'G' 11487' True vertical depth 110' 2508' 8731' 9213' Perforation depth: measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206'; 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951-8986'; 9005-9011 '; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10514' MD; 4-1/2", 12.6~, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10504' MD; Otis SSSV @ 2181' MD 13. Stimulation or cement squeeze summary REC~IVED 14. Intervals treated(measured) See attached JIj Treatment description including volumes used and final pressure Representative Daily Average Produ~ion or Inj~tion Data Anch0raoe OiI-Bbl Gas-Md Water-Bbl Casing Pressure %ubing Pressure Prior to well operation 1496 3243 172 -- 237 Subsequent to operation 3607 4907 445 -- 288 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. Signed ~'//P-'~/~~),~~/~-~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 048 T. P. Allen. 263-4837 Date ,~ %~g~/~>'? SUBMIT IN DUPLICATE~,~ Treatment' Objective' Intervals Treated: Treatment Date: Drill Site 17-11 Description of Work Performed 12% HCI Perforation Breakdown Treatment With Ball Sealers To remove near wellbore damage in Zones 3,4, & Sag 10893-10916',11014-11054',11066-111 18',1 1130-11 174' 11198-11206';11208-11216' MD May 22, 1989 , Performed a tubing wash with 2500 gals of 15% HCL, 250 gals of xylene and 0.4% corrosion inhibitor. Pumped down the production tubing as follows: 2750 gals of 15% HCL/Xylene 165 bbls of crude 2. Flowed the well back to the system. . Obtained a wellhead fluid sample from Well 17-11 and performed emulsion and sludging tests with the acids and additives. 4. Obtained a valid well test. , MIRU wireline unit. Changed out the live GLVs to dummy GLV. Loaded the 5-1/2 x 9- 5/8" annulus with dead crude/diesel to surface. Pressure tested annulus to 2000 psi to ensure no communication exists. 6. Loaded 12000 gals of 12% HCL. 7. Loaded 1000 gals of xylene and 340 bbls of slick diesel. 8. MIRU pump trucks and transports. Placed 2400 psi on the 5-1/2 x 9-5/8" annulus. 9. Rolled all acid compartments on location before pumping fluids downhole. 10. 11. 12. Pumped the following fluids down the 5-1/2" tubing: A. 4 0 bbls Slick diesel to establish treating rate and pressure B. 500 gals Xylene C. 4000 gals 12% HCL acid w/additives and 200 ball sealers D. 500 gals xylene E. 6000 gals 12% HCL w/additives and 400 ball sealers F. 2000 gals 12% HCL acid w/additives G 300 bbls Slick Diesel Immediately following the treatment, unloaded the well. Obtained a valid well test. 'jUtl o t t9 hiaska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. Prudhoe Bay iE~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 2, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11 Permit No. 84-244 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/TPA/jp Attachment T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 17-11)W1-3 RECEIVED _Alaska_ .Oil.& Gas Cons. Corem/ss/on ' ~ ~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~51ATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC,_ ,vllSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Vadance Perforate Other 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FS, 567' FWL, Sec. 15, T10,N R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110 Sudace 2437' Production 10790' Liner 937' 11505 feet {ECEIVED 9226 feet JtlN 0 51989 11445 feet 9191 feet Junk(measured) J~flSl(a, 0il .& Gas Cons. Gommissior~ Size Cemented ~bs~~ True ve~ical depth 20" 2000~ Poleset 110' 110' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 2508' 9-5/8" 500 sx CI 'G' & 300 sx CS II 10861' 8731' 7" 340 sx CI 'G' 11487' 9213' Plugs(measured) Perforation depth: measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206'; 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951-8986'; 9005-9011'; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10514' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 10504' MD; Otis SSSV @ 2181' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation June 1989 16. If proposal was verbally approved Oil x Gas Name of approver Date approved Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. S ig n e d ~'~z~~J~.,u,~~''' Title Operations Engineering Manager FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH 15. Status of well classification as: Suspended Date ~'///~/~' Form 10-403 Rev 06/15/88 (11R T P AIIp. n_ 2R.ct-4B37 SUBMIT IN TRIPLICATE Drill Site 17-11 Scale Inhibition Treatment ARCO Alaska, Inc. proposes that a scale inhibition treatment be performed on Well 17-11. The treatment will be performed as follows: 1. Obtain a valid well test. 2. Perform a fluid level survey' on the 5 1/2" x 9 5/8" annulus. Fluid pack the 5 1/2 x 9 5/8" annulus with dead crude/diesel. . Load 50 bbls. of filtered fresh water for blending the EDTA. Load 233 bbls. of filtered 2% NaCI water for blending the scale inhibitor. 4. Flush pumper with 2 bbls of filtered fresh water. 5. Mix the remaining 2000 gals. (48 bbls) of filtered fresh water adding: . -1550 lbs of Na2EDTA -4 gals of F75N, NE-18 or Losurf 300 -2 gals of A186, CI-9 or MSA Flush pumper with 2 bbls of filtered 2% NaCI water and mix one of the current acceptable amine phosphonate inhibitor blends. 7. Load 350# of solid OSR diverter and 25 gals of liquid OSR diverter. . Load 50 bbls of methanol, 105 bbls of diesel, and 550 bbls of 2% NaCl water w/1000 gm/I of DETPMP. 9. Batch mix the 48 bbls of EDTA with 350# of solid diverter and 25 gals of liquid diverter. 10. MIRU pump trucks and transports. 1 1. Pump the following fluids down the production tubing' A. B. C, D. E. F. G H. 50 bbls of diesel 50 bbls of methanol 48 bbls of EDTA with additives and the solid and liquid diverter 236 bbls of scale inhibitor blend 550 bbls of 2% NaCI water w/1000 mg/I of DETPMP 50 bbls of diesel 255 bbls of dead crude 5 bbls of diesel 12. 13. RD and release equipment. production. Obtain a valid well test. Shut in well for 2 hrs. After this period of time return well to . Nas~ 0il & Gas Cons. /knchor?~ 5 4 2 COILED TUBINg UNIT BOP E0U 1 PI, lENt 1. ~K)00 PSI 7" WELLHEAD CONNECTOR IrLANGE! 2. 5000 PSI 4 1/16" PIPE RAkeS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 HIREL INE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELIN£ RAU5 (VARIABLE SIZE) ~. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc.. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 3, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11, Permit No.84-244 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/TPA/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 17-11)W1-3 RECEIVED ~ ~ ~2 £7-/'n ,. Ai~ska Oil.& ' ; ~chorago ARCO Alaska, Inc. is a Subsidiary o! AllanticRichfieldCompany AR3B--6132-C STATE Of ALASKA ALASKA .LAND GAS CONSERVATION CC ,VIlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Vadance Perforate Other 5. Type of Well 6. Datum of elevation(DF or KB) Development y/ 71 RKB feet Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, R15E, UM At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-11 9. Permit number 84-244 10. APl number 50 - 029-21259 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 11505 feet 9226 feet Plugs(measured) 11445 feet 9191 feet Junk(measured) Size Cemented REC'EIVED .~ ¥ .... ~ 2-;'~' ~asure8 d~t~O~e ve~ical depth 110' 20" 2000# Poleset 110' 110' 2437' 13-3/8" 2400 sx CS III & 400 sx CS II 2508' 2508' 10790' 9-5/8" 500 sx CI 'G' & 300 sx CS II 10861' 8731' 937' 7" 340 sx Cl 'G' 11487' 9213' measured 10893-10916'; 11014-11054'; 11066-11118'; 11130-11174'; 11198-11206'; 11208-11216' true vertical 8757-8777'; 8860-8892'; 8901-8942'; 8951-8986'; 9005-9011 '; 9013-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10514' MD; 4-1/2", 12.6~, L-80, PCT tail @ 10612' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10504' MD; Otis SSSV @ 2181' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Oil x Gas Name of apl)rover Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~J~~ ~~ Title Operations Engineering Manager FOR COMMI-~RION USI= {3NLY Conditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Suspended Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LO.N.~J!E e. SM)TH ApproVed CoPY Returned._ ~,- Date ,,~-' SUBMIT IN TRIPLICATE 018 T. P. Allen, 263-4837 Drill Site 17-11 HCL Perforation Breakdown Treatment ARCO Alaska, Inc. proposes that a perforation breakdown treatment using HCL be performed on Well 17-11. The treatment will be performed as follows: 1. Perform a tubing wash with 2500 gals of 15% HCL, 250 gals of xylene and 0.4% corrosion inhibitor. Pump down the production tubing as follows: 2750 gals of 15% HCL/Xylene 165 bbls of crude 2. Flow the well back to the system. 3. Obtain a wellhead fluid sample from Well 17-11 and perform emulsion and sludging tests with acid and additives. 4. Obtain a valid well test. . MIRU wireline unit. Tag bottom to ensure that fill is not covering the perfs. Change out the live GLVs to dummy GLVs. Load the 5-1/2 x 9-5/8" annulus with dead crude/diesel to surface. Pressure test annulus to 2000 psi to ensure no communication exists. 6. Load 12000 gals of 12% HCL. Friction reduction additives should be added to slick acid. 7. Load 1000 gals of xylene and 340 bbls of slick diesel. 8. MIRU pump trucks and transports. Ensure that 2500 psi is placed on the 5-1/2 x 9-5/8" annulus. 9. Roll all acid compartments on location before pumping fluids downhole. 10. Pump the following fluids down the 5-1/2" tubing: A. 4 0 bbls Slick diesel to establish treating rate and pressure B. 500 gals Xylene C. 4000 gals 12% HCL w/additives, friction reducer and 200 ball sealers D. 500 gals Xylene E. 6000 gals 12% HCL w/additives with friction reducer and 400 ball sealers F. 2000 gals 12% HCL w/additives with friction reducer G 300 bbls Slick Diesel 11. 12. Immediately following the treatment, unload the well. After all stimulation fluids have been recovered, obtain a valid well test. 5 4 3 2 COILED 1UBINt~ UNIT: BOP E~IIU 1 PHE N~, HIRELINE BOP EOUIPHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULI0 SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 1. 5000 PSI 7" WELLHEAD GONNECIOR FLANGE 2. 5000 PS! WlRELIN£ RAI~IS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 5000 PSI 4 1/G" BLIND RAMS 5000 PSi 4 1/16" STUFFING BOX STATE OF ALASKA . ,~ ALASI~.,--OIL AND GAS CONSERVATION COMM.-~-'~31ON , REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate ¢ Pull tubing [] Alter Casing [] Other [] 2. Name of Op_erator ARCO Alaska, Inc. 3. Address Post Office Box 100360~ Anchoraqe~ AK 99510 4. Location of well at surface 2710'FNL, 1029'FWL, Sec. 22, T10N, R15E, UN At top of productive interval 2267'FSL, 542'FWL, Sec. 15, T10N, R15E, UM At effective depth 2559'FSL, 567'FWL, Sec. 15, T10N, R15E, UM At total depth 2595'FSL~ 569'FWL, Sec. 15, TION, R15E, UM 11. Present well condition summary Total depth: measured 11505 feet true vertical 9226 feet Effective depth: measured 11445 feet true vertical 9191 feet Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) 71' RF, B Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 17-11 8. Approval number 84-244 9. APl number 50-- 029-21259 lO. POO~rudhoe Bay Oil Pool Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 110' 20" To Surface 110' 110' Surface 2508' 13-3/8" 2800 Sx 2508' 2508' Production 10861' 9-5/8" 500 Sx 10861' 8731' Liner 937' 7" 340 Sx 10550-11487' 8481-9213' Perforation depth: measured 10893-10916', 11014-11054', 11066-11118', 11130-11174', 11198-11206', 11208-11216' true vertical 8757-8777', 8860-8892', 8901-8942', 8951-8986', Tubing (size, grade and measured d ' ' 5½" 17# L-80 10484'MD & 4½" 12 6#, L-80, 10612'MD P~r~a~d ~SS,V (typ~ and measured depth) - FacKer e 10504'MD; Otis SSSV e 2181'MD ~E(]~%~4:;~ 12. Stimulation or cement squeeze summary Intervals treated (measured) NA Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 640 630 0 1200 7609 6096 0 1200 Tubing Pressure 235 253 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~,~~__~'~~ Title Operations Engineering Manager Form lO-40~,'~Rev. 12-1-85 17-11/STAT17 C. M. Baker (263-4643) Date Submit in Duplicate Summary of Operations Began perforating operations on 12/25/87. S/I well. RU perforating unit, pressure tested equipment· RIH w/gun #1, perforated 11154'-11174' POOH, all shots fired. RIH w/gun #2, perforated 11134-11154', POOH, all shots 'fired. RIH with gun #3, perforated 11130-11134' and 11106-11118', POOH, all shots fired. RIH w/gun #4, perforated 11086-11106', POOH, all shots fired. RIH w/gun #5, perforated 11066-11088', POOH, all shots fired. RIH w/gun #6, perforated 11034-11054', POOH, all shots fired. RIH w/gun #7, perforated 11014-11034', POOH all shots fired RIH w/gun #8 perforated 11208-11216' and 11198-11206' , · , , POOH, all shots fired· Secured well, RD, returned to production. STAT17'SN 4-29 ANCHORAC, E, A I... A.'~,' I(' A DATE' ~-27-R~ B'F'.FER-F-NCFT' ARCO CA,~ED 14F~! F:'- FTNAI_ I~'1 !i:J ~, I~1 li~J i . R'I N t . !;:! hi i, F,:I N t . F:I N ~ . I:;.'1 Ni . r~:l M 'i. r-;.'l.N i , F:I /'-J 'i . 'F) 11 :? 'T r.;., 'r T:{ I IT T ~'-~ N I .~ J'"Jl .1", F':,'~ M f~ P, F'.A H C. FI Ft. AMCI'] f".AHCR F':ANCFi F'.AMF:r'i ~" F: IE N 'T R A I I: 1~ I... F... ,? .... ~ .r.,, H ...... '[ ! I I' c:,, .::.,~ · ~ C 14 .F'. V I;.' O l"J F'T~: IJFII F'rl '() ,*. H I;: ,~ O ~u F:~TF'N."-,' T rli'.,J F'%F'!. f'lPAT 'r fii'-J :'~ ~ I!:' t:,' ':{ O lg 4'.: 5.' T A 'f' F R F A I -¢~, ."-.'.' !,..' A i':i ,.2, F.' A T 14 fi N ~ "F P- ¥ ,-.~ F.' fi -~ Fi f'i 'R T j ARCO A~_A~KA, INCo P.,O, BOX t¢¢~6A ANCHORAGE, ALASKA 99..%' ~ ~-, DATE- t-2~-R8 REFERENCE: ARCO £A~ED HnI..E FINAl... 6-t t2-t6-87 COI...I._AR/F'ERFORATION [_06 RUN -t.?-'i't'- I 2-22-87 COLL. AR/F'ERFORAT.TON LOG RUN 7-t 2 I 2-25-87 COI_.[..AR/F'ERFORATION [..01.., RUN F'L. EA~E ~IGN AND RETURN THE ATTACHED COPY AY RE~EIF'T OF DATA.. RECEIVED BY __ _ HAVE A NICE DAY! .988 F'E 6 rT., Y B E N N E T T ~Naska Oil & Gas Cons. Commi~lo~ n T O- ~ 5 2 9 ~chorage DI~TRTBIITTON TRAN$ $88G48 ~. AF'F'ROVED -_ GEAR GEAR CENTRAl._ F I I...E,S' $ F'H I I._1... I F',S' CHEVRON F'P, WEI.. t.. FII_ E~ D ~, M R * D .F. XTEi" ,: ]ON EXF'I...IgF-,,'AT.T. OK.I ...... _ . . -,-., ..... AF..C. ---= .......... .., ,,.~._ E×XON -~ '~:,.'F,--I;ATE ..OF- AI._A,~'KA . MARATHON $ TEXACO MOBIl_. i '7..-- ! i ARCO Alaska, In Prudhoe B'a"~E. ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 24, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11 Permit No. 84-244 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: Standard Alaska Production Company PI(DS 17-11)W1-3 RECEIVED AUG 2 ~ ~7 AI~I~ Oil & G~ C~,, ~i~ An~omge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA OIL AND GAS CONSERVATION COI,.....~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0- Rnx lflf136fl: AnchnragP: Al< qq.61fl 4. Location of well at surface 2710' FNL, 1029' FNL, Sec. 22, T10N, R15E, UH At top of productive interval 2267' FSL, 542' FNL, Sec. 15, T10N, R15E, UM At effective depth At total depth 2595' FSL, 569' FNL, Sec. 15, T10N, R15E, UN 5. Datum elevation (DF or KB) 71' RKB 6. Unit or Property name Prurlho¢_ Ray lin'ii-_ 8. Approval number 9. APl number 50-- 029-21259 10. Pool Feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured . true vertical 15055 feet 9226 feet Plugs (measured) Effective depth: measured true vertical 11455 feet 9191 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10893' - 10916 8760' - 8779' Tubing (size, grade Length 110' 2508' 10861' 937' measured ' (1 interval) true vertical (1 interval) and measured depth) Size 20" 13-3/8" 9-5/8" 7" Cemented Measured depth True Vertical depth 2000# PS 110' 110' 2400 Sx + 400 Sx 2508' 2507.9' 500 Sx + 300 Sx 10861' 340 Sx 10550'-11487' 5½" 17# L-80 PCT @ 10612'MD, 4½", 12.6#, L-80 @ 10612' Packers arid SSSV (type and measured depth) 0tis SSSV @ 2181 'MD, B0T 3-H packer 8730' 8480'-9213' 12. Stimulation or cement squeeze summary Intervals treated (measured)See attached Treatment description including volumes used and final pressure AUG 2 6 1561 Oi~ & 6a~ ¢o~s. 6ommi~ 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 727 1701 61 185 2826 0 Tubing Pressure 222 249 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 wF~! ~9/n_~ T_ P_ Al lPn. ATO 1516. 263-4837 Date ~¢//~7 Submit in Duplicate (~ DS 17-11 DESCRIPTION OF WORK PERFORMED Hydraulic Fracture Treatment Objective: Stimulate Sag River interval (10893-10916' MD, ref. LSS 3/7/85). Date Performed: 7/12/87 1. Loaded the 5-1/2" x 9-5/8" annulus with 9.2 lbs/gal brine/diesel. 2. MIRU wireline unit and replaced all live gas lift valves with dummy valves. 3. Tested 5-1/2" x 9-5/8" annulus and ensured isolation with the tubing. 4. MIRU conductor line unit. Ran spectralog tool from 11364-10500' MD. 5. RD conductor line unit. MIRU appropriate pumps, blenders, tanks, tree saver, hardline, etc. 6. Pumped the following fluids: a. 55,000 gals of pad stage @ 25 BPM w/Iodine-131 tracer b. 2,000 gals of 2 ppg of ISP (16-20 mesh) @ 25 BPM w/Gold-198 tracer c. 4,000 gals of 4 ppg of ISP (16-20 mesh) @ 25 BPM w/Gold-198 tracer d. 4,000 gals of 6 ppg of ISP (16-20 mesh) @ 25 BPM w/Gold-198 tracer e. 1,000 gals of 8 ppg of ISP (16-20 mesh) @ 25 BPM w/Gold-198 tracer Note: Early screen-out during treatment. 7. RD tree saver and hardline. MIRU CTU and cleaned out proppant in wellbore. 8. MIRU conductor line unit. Ran gamma ray log from 11076-10480' MD. 9. Rigged up wireline unit and re-installed active gas lift valves in the tubing string. 10. Placed well on production and tested. WELLS/683 .? c: h ,?, (: h c.h ,'.'?. c h :-:,' c: h ,'_',' c h ['~ '!' i '.-': o '1'" da!'a, ¢' F:'I'; i I. L i l-',~ :.": F: e I"~ t: i- a L F:' i L e s' ' :C: C h c-., v ~- c, ~"~ F:' [¢ kl E, I. L F i L ~..'..', ~; I) & H I:;-'. & I) · ~J:E x !' e n -'..' i o n E: ).'. P I. o r' a '~ i r'm'n ~ ,?;"..o h i o _ ~',: E x >.'. o ¥'~ ~~' H a r' a '.~ h o n ~: l"e x a c o $' i"i o I_'~ i L . ' 995~0 D A 1' Iii; · J u. I. y 2 8, i 98 '7 I';,' I!;; F' Ii;; I:;; Iii; N C Iii; · A R C 0 C a :.!: e d I.-I o ! e I::' i n a I. I::"r o d u c 't i o n L.. o g 1" ~L.t 1::, i n g C u. '1' T e r 6; a m m a I:;.'. n y L. o g ,..:. i.) ~-:i, c: '[' r' a I. 0 g 5' J::' J. r:, a ;~ e ':4' . I::.i e,c:: e i v e d I--lAVE!: A N and ¥' e '[ ,.:.'~" n :1'; e !C:E'' '"E:I~ c: o ..', y a '..': re c: e ip-I: D A ¥' ! x,~ska Oil & ~ O~n~. ~lon An~orage [;~ 0 .S' a I1D E.." e e E:~ J..'. A T ['i.. .... ~ '::"_,,,.. © o, TI:::AH3' ~. ,"'3 '? S 8 L"~: f::'l p P r' o V ect ................... ..!(~ ............................................................ [: ..... j.. ! :'i'il 3 iq o f d a -I: a, ~'- r;enTraL I::'i Les' '"' C h e v r c, 'n I) & M I:i: x t' e n.,.'~.' i o n F:: >,' I:) L o r a t i o n E x x o n M a r o T h c.', n "' Mob i L 'Il' F:'hi I. L i p~' F:'B WeLL Fi Lez,' I:;.'. & i) J~. 'U' - ' i · ,,. ,.:-ol~ ! C ............ ~'" ':.: ')" e X a c 0 '0 A T E · ..J u [ y .-. 4, t 9 8'7 REI:.-ERF;NCE' ARCO 12a_~ed Hole Final t 7 .... I t '7 --. 1 6 --. 8 '7 6.' a m m a R a y / C o [ [ 8 ¥ Re.c- e i ".,'ecl By. ................................................ .. I--IgVE A NICE bgY A'T'O .... i '~'2© ...¢ ... A p I:> 'r o v o d - ............................................................. DIS TI~-~ BUT IOlq. o I"' -~'"' f.";en + ~- a. L F-'i L ¢:_'-:;.. '"'.,~C h e v ~- n._ n I) & M · "' Iii x 't' e 'n s: i n n E x P L o'r' :':i t- i ,n -,."" E x x o n i'I ;:'~ 'r' ,'..~ '? h o n :,~: M c, i::, i I. I:' h i I. ~_ ii:, s' F:'9 Wel. L F'i Le~: R & D ;!i; ,:' :, l -., i o ..'.'i:±a!'e of Alaska 'T' (-.'..', x ;.-'~ c o DATE' June 25, t987 REFERENCE: ARCO Cased Hole Final . ::_'-i6 6-7-87 Collar & F'erf, . Run t, 5" 4-.26 6-8-87 Co[ Iai- & F'erf, Run i, 5" i'?--S 6-t2--87 CoLLar & F'erf. Run t, 5' ,..,~tT.~,ft. 6-t6-87 Leak De~, Temp, Survey ~ear (;eer Gear Ofi~ F:'Le.; .. sign and return ~he atkac:hed copy as receipt of data, HAVE A NICE DAY' JUlql3 0 1987 R o s a n ne F'ee k ~ Naska 011 & Gas Cons. Commission A 1'0-- t 5 2 9 An~0rage Appl-oved ............................................. DISI'RI BtJ'FIOH Central F'i Les $ F'hi l[ips Chevron F'B We[ l I) & H R & I) Ex'~ens'ion Exp[orat ion :$ Sohio Exxon .. ~,~ate of Harai'hon ~ Texaco Hob i [ Fi [es Alaska ARCO ALas:ka, Inc. F:'~O, Box ~00:360 Anchorage, ALaska 99510 DAI'E: June 25, t987 REFERENCE: ARCO Cas;ed HoLe Final 2-~6 5-7-87 CoLLar & F'erf, 4-26 5-8-87 ColLar & F'erf, t'7-3 6-t2-87 CoL La',' & F'erf, t7-t~ 6-t 6-87 Leak Der, Temp. Survey Run Run t , 5" Run t, 5" 5" Gear Gear Otis; F:'Le.:...' s:ign and return the attached copy as; receipt of data. Received By HAVE A NICE'.' DAY! Ros:anne Peek ATO- ~ 529 Approvecl ............................... Anchorage D I ~'lr' R I BUT I ON · " Central I:."i Les -Ir · $ Chevron I) & M · '~ Exten.s'ion Exploration ~ E x x o n Harathon :~ Mob i L · .."" F'hi [Lips: F'B WeLL Fi Les: R & D '" ,S'oh io "1~ ~ State of A La.ska · "- Texaco 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 20, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-11 Permit No. 84-244 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/TPA/jp Attachment cc: Standard Alaska Production Company PI(DS 17-11)W1-3 WELLS/68 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA;,,_,,,, OIL AND GAS CONSERVATION COIV,~.¥SSION 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 Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99210 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, TiON, R15E, UM At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM At effective depth At total depth 2595' FSi, 569' FWL, Sec. 15, TZON, R15E, UM 5. Datum elevation (DF or KB) 71 ' t~B feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 17-11 8. Permitnumber 84-244 9. APInumber 50-- 029-21259 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11505 feet 9226 feet Plugs (measured) Effective depth: measured 11455 feet true vertical 9191 feet Junk (measured) Casing Length Size Structural Conductor 110 ' 20" Surface 2508' 13-3/8" Intermediate Production 10861 ' 9-5/8" Liner 937 ' 7" Perforation depth: measured Cemented Measured depth True Vertical depth 2000# PS 110' 2400 Sx + 400 Sx 2508' 110' 2507.9' 500 Sx + 300 Sx 10861' 8730' 340 Sx 10550-11487' 8480-9213' 10893-10916' (1 interval) true vertical 8760-8779' (1 interval) ~bing(size, grade and measured depth) 5~" 17#, L-80 PCT @ 10612' MD, 4~" 12 6# L-80 @ 10612' ~ , ' · , Packers and SSSV(t~pe and measured depth) Otis SSSV @ 2181 MD, BOT 3-H packer 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I herebhcertify//~t ~ ~..g.%nT true and c°rrect t° the best °f mY kn°wledge Signed ~,/¢-~¢,,~,,~ .,4j ~,;,--~ Title Operations Engineering Manager Date Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by by order of Commissioner the commission Form 10-403 Rev 12-1-85 WELLS/68 T. P. Allen, ATO-1516, 263-4837 Submit in triplicate DS 17-11 DESCRIPTION OF PROPOSED WORK ARCO Alaska, Inc. intends to perform a propped fracture treatment on DS 17-11. The treatment will be performed as follows: 1. Ensure the 5-1/2" x 9-5/8" annulus is loaded with crude/diesel. 2. MIRU wireline unit and replace all live gas lift valves with dummy valves. 3. Test 5-1/2" x 9-5/8" annulus and ensure isolation with the tubing. 4. MIRU conductor line unit. Run a natural gamma ray spectrometry and a continuous temperature tool. Log 300' above and below the Sag River zone. 5. RD conductor line unit. MIRU appropriate pumps, blenders, tanks, tree saver, hardline, etc. 6. Pump the following fluids: a. 60,000 gals of pad stage @ 25 BPM* b. 2,000 gals of 2 ppg of ISP (12-20 mesh) @ 25 BPM* c. 4,000 gals of 4 ppg of ISP (12-20 mesh) @ 25 BPM* d. 4,000 gals of 6 ppg of ISP (12-20 mesh) @ 25 BPM* e. 3,500 gals of 8 ppg of ISP (12-20 mesh) @ 25 BPM* f. 180 bbls of flush @ 25 BPM g. 75 bbls of diesel @ 25 BPM * Add RA material to this stage. 7. RD tree saver and hardline. MIRU wireline unit, ensure wellbore is clear. 8. MIRU conductor line unit. Run a natural gamma ray spectrometry and continuous temperature log (this step may be performed after step 9) across the Sag River zone. 9. MIRU rig up coiled tubing unit and clean out proppant contained in the rathole. 10. MIRU rig up wireline unit and re-install active gas lift valves in the tubing string. WELLS/68 ARCO Alaska, F'.O. Box Anchorage, A I.a~ka. 995J0 DATE' February 2 5, 1987 REFERENCE' ARCO Cased Hol. e FJnaL 3-J4 8-23-86 CET Run ~, 5' $ch 4-'i7 6-6-86 F'erf. Record Run ~, 5' $ch 4-~8 6-6-86 F'erf. & CCL Run ~, 5' $ch 4-2~ 6-~-86 F'erf~ & CCL Run ~, 5' ,~ch 4-.2~ 6-5-86 Perf. Record Run ~, 5' Sch 4-~4~ 6-6-86 Perf. Record Run ~, 5' ~ch 4-27 6-4-86 Perf~ Record Ru~ ~ ~ 5' ~ch 4-28 6-4-86 Perf. Record Run J, 5' ~ch ~' Sch 9-~2 8-7-86 CET Ruo ~-, ~ ~4-4 8-~4-86 Reperf. Record Run ~, 5' Sch J6-24 8-~ -86 Perf. Record Run ~, 5' ~ch ~7-~ 5-~-86 Compte~ion Record Run ~, 5' ~ch ~7-t4 8-29-86 Add-F'erf. Record Run t, 5' ~ch F'Leam'e sign and ret'urn '~he at'-l'ached copy as receip't of dat'a. Received By. E HAVE A NICE DAY! --- Ro.sa nne Peek A T O- t _, .. 9 a Wa Oti & Oomm~ss~o ApproYed ......... , ..... ~ Central Fi Les ~ F'hi LLips · ~ Chevron F'B WeLL Fi les D & M R & D ~ Texaco Mara Shon ~ ~ Mob i L STATE Of ALASKA ALA~¢,~, OIL AND GAS CONSERVATION COM'r~',SSION 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 Alaska, Thc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T10N, R15E, UH At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UN 5. Datum elevation(DF orKB) 71' RKB 6. Uniter ~opqCy na~e vruenoe uay Unit 7. Well number DS 17-11 8. Permit number 84-244 9. APl number 50-- 029-21259 10. Pool At effective depth 2559' FSL, 567' At total depth 2595' FSL~ 569' 11. Present well condition summary Total depth: measured true vertical FWL, Sec. 15, TION, R15E, UM FWL, Sec. 15, TION, R15E, UM Prudhoe Bay Oil Pool 15505 feet 9226 feet Plugs (measured) feet, Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 11445 9191 Size feet feet 110' 2508' 10861' 937' measured 10893' true vertical 8757' 20" 13-3/8" 9-5/8" 7" - 10916' - 8777I Junk (measured) Cemented To surface 2800 SX Measured depth 500 SX 340 SX 110' 2508' Tubing (size, grade and measured depth) 54II 17// L-80 10484'MD & 4½" 12 6# L-80 10612'MD ~ ~ ~ · ~ ~ · Packers and SSSV (type and measured depth) BOT 3-H Packer ~ 10504'MD: Otis SSSV ¢ ?IRI'Mr) 12.Attachments 10861' 10550' - 11487' True Vertical depth 110' 2508' 8731' 8481' - 9213' Description summary of proposal ~q' Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hem. hv"hertifv that. the,,foreooing is true and correct to the best of my knowledge Signed ~"¢~,~~-d Z-,;'f/,z'~-~- Title Operations Enqineerin,q Manaqer Date ~/~_,//~? Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. [] BOP Test Approved by [] Plug integrity [] Location clearance J.' . ¢ .... Commissioner by order of the commission Date / Submit in triplicatu Form 10-403 Rev 12-1-85 GNF (265-6268) ARCO Alaska, Inc. Requests the following' 1. Permission to waive the production profile described in Conservation Order, Rule 11a. Only 23' of perforations were shot in 17-11. All of the perforations were shot in the Sag River thereby negating the need for a spinner survey. Additional perforations are planned as listed below. The timing of the perforations, however, is after the initial six month time period has passed. A production profile will be run following the addition of the Sadlerochit perforations listed below. 2. Sundry approvals for additional perforations on DS 17-11 for selected intervals within the Sadlerochit sand from the Prudhoe Bay Unit. 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. Ref' BHCS 3/7/85 Proposed Sadlerochit Perforation Intervals' 11014-11174'MD (160') 11198-11218'MD (20') RE£EIVE iai~} 2 6 1987 · . r,- 6orr~mission A~8,sk¢ Oil & bas- A~qchorage ARCO Oil and Gas Company ~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no. AYE 404349 County, parish or borough North Slope Borough Lease or Unit ADL 28331 Title Drill, Complete & Perforate IState Alaska Well no. 17-11 Rowan #35 API 50-029-21259 Operator ARCO Alaska, Inc. 0500 Hrs. IARCO W.I. Prior status If a W.O. · Spudded 2/17/85 21.66% Date and del~th as of 8;06 a~m~: - 2/20/85 2/21/85 2/23/85 thru 2/25/85 Complete record for each day reported 13-3/8" @ 2508' 2530', (2420'), Weld 13-3/8" csg head Wt. 9.4, PV 14, YP 20, PH 8.5, WL 14 Acce~t ri~ @ 2000 hfs, 2116185. NU diverter~aY's~i,~-'~U~.. 0500 hfs, 2/17/85. Drl 17~" hole to 25'30', ~C~O~C:~~~~' [3-3/8",~[-~ css w/~s ~ 2~08, ~c ~ ~428'. III w/.2% R-7, followed by 400 sx CS II w/. using rig pmp, b~p plug. 100 bbls cmt rtns~!' 2/18/85. ~ BOPE, set slips, cut off csg. .~ ~- 2530', (0'), Chg BHA 8.3 Fresh wtr Fin welding 13-3/8" csg head. NU & tst BOPE~ LD ~-~ 1 8 1~8~ 13-3/8" @ 2508' A!ask2Oi!& ~osCons. CornmJss[o~ 3835', (1304'), Drlg Wt. 8.9, PV 2, YP 5, PH 8.5, WL NC, Sol 3 TIH w/BHA to FC @ 2428', tst csg to 1500 psi, DO cmt & flt equipment, drl to 2541'. Conduct formation tst to 11.2 ppg EMW. Drl, Navi-Drl & surv 12¼" hole to 3835'. i':~; Assumed vertical ':; 8.6°, N23W, 3671.52 TVD, 1243 VS, 11.87N, 5.04W ~Y§'9', <1304'), TOH Wt. 9.2, PV 6, YP 7, PH 8.5, WL NC, Sol 4 Navi-Drl, drl & surv 12¼" hole to 5139'. 3796', 13.3°, N22W, 3671.52 TVD, 39.99 VS, 38.23, 15.96 4014', 19.25°, N17W, 4000.62 TVD, 102.24 VS, 98.23, 37.16 4432', 31°, N16W, 4377.52 TVD, 277.20 VS, 268.41, 85.04 4869', 41.6°, N14W, 4728.69 TVD, 534.58 VS, 519.49, 149.83 5077', 45.7°, N15W, 4879.19 TVD, 677.08 VS, 658.49, 185.78 13-3/8" @ 2508' 8435', (3296'), Drlg Wt. 9.7, PV 11, YP 11, PH 8.4~, WL 8.3, Sol 10 Drl & surv 12¼" hole f/5139'-8435'. 5521', 48.3°, N12W, 5182 TVD, 1000.02 VS, 974.23, 261.58 6048', 50°, N08W, 5526.70 TVD, 1398.27 VS, 1366.81, 330.81 6503', 51°, N7W, 5816.11TVD, 1749.36 VS, 1714.90, 376.63 7038', 53°, N6W, 6145.59 TVD, 2170.89 VS, 2133.78, 424.36 7525', 54°, N6W, 6435.17 TVD, 2562.23 VS, 2523.11, 465.28 8190', 53.5°, N05W, 6828.39 TVD, 3098.19 VS, 3056.93, 516.68 The above is correct - Signature /1 For form preparation and~listribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ! Title 4/1/85 Drilling Superintendent INumber all daily well history forms consecutively as they are prepared for each well. iP~ge no. ARCO Oil and Gas Company ~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Alaska Field ICounty or Parish North Slope Borough ' IState Lease or Unit Prudhoe Bay Date and dept. as of 8:00 a.m. 2/26/85 2/27/85 2/28/85 3/01/85 3/02/85 thru 3/04/85 3/05/85 ADL 28331 f;: > record for each day while drilling or workover in progress ~'' ~-.' ~.-?~? Complete . i3-3/8" ~ 2508' ~aska 0//,~."-~ ~bTM 9252', (817'), TIH Wt. 9.8, PV 15 YP 7 PH 8 4 ~ 5.~, ~o~ w .... 'c,'..~ .... '.o~;~...~ ..... Drl & surv 12¼" hole to 9252', TOH f/bit chg. 8546' 50 3°' N06W, 7048.06 TVD, 3378 17 VS, 3335 79, 543 53 , · , ' ' ' 8927' 47° N02W, 7299 77 TVD, 3663 66 VS, 3621 10, 563 48 , · · · · 9132' 43 {o N03W, 7444 60 TVD, 3808 19 VS, 3766 05, 569 81 · ·, . · · · 13-3/8" @ 2508' 10,105' (853') Drlg wt. 10. , Pv 19; YP 10, 8.0, 4.8, Sol 11 TIH, wsh & rm f/9190'-9252' drl & surv 12¼" hole to 10,105' , ' 9575', 43°, N01W, 7766.13 TVD, 4107.17 VS, 4066.22, 580.g9 9915', 43.5°, N01W, 8015 96 TVD, 4340 68 VS, 4301 20, 584 39 13-3/8" @ 2508' 10,470' (365'), Drlg Wt. 10.~, PV 12, YP 8, PH 8.5, WL 4.5, Sol 11 Drl & surv 12¼" hole to 10,470'. 10,087', 44°, N1W, 8140 TVD, 4458.86 VS, 4420.13N, 586.47W 13-3/8" @ 2508' 10,880', (410'), POOH to rn 9-5/8" Wt. 10.2, PV 16, YP 7, PH 8.5, WL 4.8, Sol 11 Drl & surv 12¼" hole to 10,880', C&C, POOH. 10,444', 40.7°, N3E, 8404.05 TVD, 4696.72 VS, 4660.59N, 582.27W 10,880', 34.3°, N7E, 8749.95 TVD, 4955.86 VS, 4925.00N, 559.14W 9-5/8" @ 10,861' 11,438' (558'), Wrk stuck pipe Wt. 10.{, PV 15, YP 10, PH 9.5, WL 4.6, Sol 10' RU & rn 275 jts, 9-5/8", 47#, L-80 butt csg & lnd w/FS @ 10,861', FC @ 10,774'. Cmt w/500 sx Cl "G" w/.75% D-31 & .15% R-5. Displ using rig pmps. CIP @ 0024 hrs, 3/2/85. RIH w/8½" BHA, DO cmt & flt equip + 10' new formation. Conduct formation tst to 11.22 ppg EMW. Drl 8½" hole to 11,438', start out of hole, pipe stuck w/bit @ 11,377'. Wrk & jar on stuck pipe. 9-5/8" @ 10,861' 11,438', (0'), PU fsh'g string Wt. 10.1+, PV 13, YP 7, PH 9.5, WL 4.2, Sol 10 Wrk pipe. RU DA, rn APRS; stopped @ 10,450', POOH, lost belly spring section. RIH w/OS, push fsh to btm, POOH; no rec'y. Rn freept; indicates differentially stuck on btm, POOH. Rn BO shot, BO @ 11,276', POOH. Alaska IWel~ no. 7-11 The above is correct Signature ~ For form preparation and d~tribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 4/01/85 Drilling Superintendent AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPa~e no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show [ormation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unlil completion. District Field Alaska Prudhoe Bay Date and deptl~ as of 8:00 a.m. 3/06/85 3/07/85 3/08/85 3/09/85 thru 3/11185 ICounty North Slope Borough or Parish Lease or Unit ADL 28331 Complete record for each day while drilling or workover in progress IState Alaska IWoI~ no. 7-11 9-5/8" @ 10,861' 11,438', (0'), Rn'g elec logs Wt. 10, PV 12, YP 8, PH 10, WL 3.8, Sol 10 RIH w/fsh'g tls, screw into fsh, jar, POOH w/fsh. wsh 11,300'-11,438', C&C f/logs, POOH. RU DA. RIH w/BHA, 9-5/8" 11,505 Wt. 10 Att to 11,438 @ 10,861' ', (67'), Prep to log , PV 10, YP 7, PH --, WL 2.8, Sol 10 log w/o success, RD loggers. RIH w/BHA, wsh 11,381'- ' drl to 11,505' circ~ POOH. , , 9-5/8" @ 10,861' 11,505', (0'), POOH Wt. 10+, PV 13, YP 9, PH 9.0, WL 3.3, Sol 10 POOH. RU Schl, rn DIL/LSS/SP/GR f/11,498'-10,861'. to 2508' POOH Make cond'g rn, POOH , · · Cont w/GR 9-5/8" @ 10,861' 11,505', (0'), ND BOPE 9.4 ppg Brine Rn 33 jts, 7", to 11,502'. Cmt w/340 sx Cl "G" w/5% KC1, .5% D-31, 1.2% D-19 & .05% R-5. Displ using rig pmps, lnr stuck w/FS @ 11,487', FC @ 11,455', LC @ 11,397'. Fin displ'g. CIP @ 1730 hrs, 3/8/85. POOH, chg to 8~" BHA, RIH, DO cmt f/10,247'- 10,550' (TOL), circ out mud, POOH. RIH w/6" bit, tag TOL, DO f/10,550'-10,572', RIH to 11,239', DO cmt f/11,239'-11,449', circ, tst 9-5/8" & 7" csg to 3000 psi. Displ hole mud w/brine. Displ brine w/diesel f/2000'-surf. ND BOPE. The above is correct Signature For form prel~aration and (~T's{'r[bu~on see Procedures Manual Section 1'0, Drilling, Pages 86 and 87 IDate ITitle 4/01/85 Drilling Superintendent AR3B-459-2-B I Number all daily well history forms consecutively as they are prepared for each well. IPa~e no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I State Al_~ska I Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 404349 County or Parish North Slope Borough Lease or Unit ADL 28331 Title Drill, Complete & Perforate J Wel~ no. 7-11 Rowan #35 Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. Date Spudded Date and depth as of 8:00 a.m. 3/12/85 Complete record for each day reported 9-5/8" @ 10,861' 11,505', (0'), RR Instl master vlv. Old TD New TD 11,505' Released rig Date 0900 Hrs. 3/11/85 Classifications (oil, gas, etc.) 011 Producing method FlOwing API 50-029-21259 W.I. [Total number of wells (active or inactive) on thisI Icost center prior to plugging and I 21.66% Jabandonment of this well IHour I Prlor status if a W.O. 2/17/8S J 0500 Hrs. I RR @ 0900 hrs, 3/11/85. J PB Depth (3/07/85) JKind.of rig Type completion (single, dual, etc.) Single Rotary Official rese~oir name(s) Sadlerochit Potential test data Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and distribul~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate JTi,e 4/01/85 Drilling Superintendent AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. Page no. Division of AtlantlcRIchfieldCompaaY STATE OF ALASKA ALAS~._~OIL AND GAS CONSERVATION COMI~.~_~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown r- Stimulate - Plugging ~ Pedorate ~ Pull tubing - Alter Casing ~ Other '--" 2. Name of Operator ARCO Alaska, ]:nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 2710' FNL, 1029' F~L, Sec. 22, T10N, R15E, UN At top of productive interval 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UN At effective depth 2559' FSL, 567' FWL,'Sec. 15, TION, R15E, UM -~ At total depth 2595' FSL, 569' FWL, S~¢, 15.TZON. R15E. UN 11. Present well condition summary Total depth: measured 1'[505 feet Plugs (measured) true vertical 9226 feet 5. Datum elevation (DF. or KB) 71' RKB 6. Unit or Pr..ope,rl[y nar~ ~'ruanoe t~ay Unit 7. Well number DS 17-11 8. Approval number 84-244 9. APl number 5o- 029-21259 10. ,Pool Prudhoe Bay Oil Pool Effective depth: measured .11445 feet Junk (measured) true vertical 9191 feet Casing Length Structural Conductor 110 ' Surface 2508 ' Intermediate Production 10861' Liner 937 ' Perforation depth: measured Size Cemented 20" To surface 13-3/8" 2800 SX 9-5/8" 500 SX 7" 340 SX Measured depth True Vertical depth 110' 110' 2508' 2508' 10861' 8731' 10550' - 11487' 8481' - 9213' 10893' - 10916' true vertical 8757' - 8777' Tubing (size, grade and measured depth) 5½", 17#, L-80 10484'MD & 4½", 12.6#, L-80, 10612'MD Packers and SSSV (type and measured depth) B0T 3-H Packer ¢a IC),.~O4'MD: (I.+~..~V (a ?!Rl'Mr) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED ~ ~,-.4. ~ -- ~OOO Oil & ~s ~ ~ uun~. Commission Anchors~a 13. Prior to well o:)eration Suh~secuent to operation Re~resent~ive Daily Average Pr~x:luction or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure N/A 200 180 0 950 231 14. Attachments -- Dailv Report of Well Operations _-- Copies of Logs and Surveys Run 15. ! nereDy certify that the foregoing is true and correct to the best of my knowledge Form 1040/. Rev. 12-I-85 GWF (6268) Date Submit in DuDl~cate Well 17-11 Began perforating operation 5/11/86. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10893'-10916' MD 6 spf (23' ref'. CET 3/23/85). All shots fired (except 1). Flow well back using gas lift, RD. ,, STATE OF ALASKA ;'-- 0 16 ~ W~l_l_ ALASKA'-~iL AND GAS CONSERVATION COMMISSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-2b~+ 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21259 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, T1ON, R15E, UM At Top Producing Interval 2267' FSL, 542' FWL, Sec. 15, TION, R15E, UM At Total Depth 2595' FSL, 569' FWL, Sec. 15, TiON, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKB I ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 02/18185 03107185 03111185 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set l1505'MD, 9226'TVD 11455'MD, 919Z'TVD YES ~X NO [] I 2181 feet MD 22. Type Electric or Other Logs Run DIL/LSS/SP/GR, FDC/CNL/Cal/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 17-11 11. Fieldand Pool Prudhoe Bay Field Prudhoe Bay Oil Pool I15. Water Depth, if offshore 116. No. of Completions N/A feet MSLI N/A 21. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" 13-3/8" 9-5/8" 7" A/T. PER FT. 91.5# 72,0# 47,0# 29.0# ~RADE H-40 L-80 L-80 L-80 TOP SETTING DEPTH MD BOTTOM Surf. 110'' Surf. 2508' Surf. 10861' 10550' 11487' 24. Perforations open to Production (MD+TVD of Top and BottOm and HOLE SIZE 30" CEMENTING RECORD 200~ Poleset 2400 sx CS 111 & 400 s: 500 sx Class "G" 340 sx Class "G" cmt AMOUNT PULLED CS 11 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) interval, size and number) Sag River 10893' - 10916' MD 6 spf 8757' - 8777' TVD Ref: LSS 3/7/85 5% 10484 10612 10504 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. Date [F'~r st:~P-r Oduc t i o n ",, 5/11/86'5 Date of'Test />~urs Tested Flow Tubing ~ Casing Pressure Press. 23~ ) 950 PRODUCTION TEST I 'Method of Operation (Flowing, gas lift, etc.) Gas lift PRODUCTION FOR TEST PERIOD I~ CALCULATED 24-HOUR RATE OIL-BBL 53 OIL-BBL 200 GAS-MCF 47 GAS-MCF 180 28. CDR E DATA WATER-BBL 0 WATER-BBL 0 CHOKE SIZE GAS-OIL RATIO 90 gDO OIL GRAVITY-APl (corr) 31.8 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AUG 1 8 1986 Alaska 0ii & Gas Cons. 0ommission Form 10-407 Rev. 7-~-80 a~F (6268) CONTINUED ON REVERSE SIDE Submit in duplicate 0RIGI.NA[ bo/ · GEOLOGIC MARKERS' NAME Top Sag Base Sag Top Sadlerochit O/W Contact Base Sadlerochit MEAS. OEPTH 10893' 10916' 11005' 11350' TRUE VERT. DEPTH .i'i~'~-i. :"'~'~'"" FoRMATiON-TESTS _. i: .: '; -' '-':"- .-;:"-; '- ;-~.'::: "'~ .. . Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 87574 8777' 8851' 9117' 31. LIST OF ATTACHMENTS 32. I hereby certify that the 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 rep, ort 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' Indical~e 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-ex-plain. Item 28' If no cores taken, indicate "none". Form 10-407 995f0 DAT~ . . ...... .,_ Augur+ ,s, I .oRA -" 2-_=:. 7-28-86 Static 'Gradien± Ca.mcc', 0 ~ -',_").q_OZ. ~"-i- + J C ~zl _. . --- ,:_-o , --,_. ~.,,., =-. ,a , '-'-ad i pi]'!', ~ t 7-t i 6-3£)-86 F'BU --" J 7-J ''~ -?-.-4-oz F'BII Ii~' i.-_-z -' / ,- ,..i I..I _. "-' ~ -~-t 3 6-~°-°'~-- , ~,~, PBU I P;ease =-=ign and re'l'urn $.he a+,~ached c. opy as receip¢ of da,'!:.a. Received By " , ~'~' r' ,, r'~ ICE DAY' ~ ' ': ~- [ p. / HAVE A N L inda H,J.L(~~B8~ ATO-~ 529 ........ ~,~,,~. Commission TRAN,S' ~86 , .r)ISTRT o, ,'rTON Cen+.raL Fi Les ~ F'hi II ip~. Chevron F'B Welt. Fi [es ~x~ensJon E'xp Lorat ;on ~ ~oh~o Exxon ~ J~a~ of ALa:zka _ . . ~. ~ ""~qk, ' I STATE OF ALASKA ALASKA o'O'iT_ AND GAS CONSERVATION C~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number . ARCO Alaska, Inc. 84-244 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21259 4. Location of well at surface 9. Unit or Lease Name 2710' FNL, 1029' FWL, Sec. 22, TiON, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2267' FSL, 542' FWL, Sec. 15, T10N, R15E, UM 17-11 At Total Depth 11. Field and Pool 2595' FSL, 569' FWL, Sec. 15, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBI ADL 28331 12. Date Spudded 13. DateY.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116- No. of Completions 02/18/85 03/07/85 03/11/85I N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost llS05'MD, 9226'TVD 11455'MD, 9191'TVD YES ~X NO [] 2181 feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/LSS/SP/GR, FDC/CNL/Cal/OR, 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" 91,5fA H-40 Surf. 110 ' ' 30" 2000~ Poleset 13-3/8" 72,0~ L-80 Surf. 2508' 17~" 2400 sx CS 111 & 400 s: CS 11 9-5/8" 47,0~ L-80 Surf. 10861' 12~" 500 sx Class "G" 7" 29.0~ L-80 10550' 11487' 8~" 340 sx Class "G" cat 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) Sag River 5~ 10484 10504 4~ 3.0612 3_0893' - 10916' ND 6 sp£ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8757' - 8777' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Ref: T.SS 3/7/85 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/11/86I Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 5/14/8~ 6.3 TEST PER IOD I~ 53 47 0 90 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 231 950 24-HOUR RATE ~ 200 180 0 31.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 1 2 Oil & Gas Cons. C0mmiss~/, Anct~0rage Form 10-407 Submit in duplicate Rev. 7-~-SO GWF (6268) CONTINUED ON REVERSE SIDE · ,, .... ~ 30. 29. ~-.i~,.' . GEOLOGIC MARKERS - ' FORMATION TEsTs . _. : .~ : ~.~., . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag ,. 10893' 8757' . Base Sag 10916' 8777 ~ . _;- - . Top Sadlerochit 11005 ' 8851' I O/W Contact 11350' 9117 ' . . . Base Sadlerochit .... · . . . . 31. LISTOF ATTACHMENTS .,. 32. I hereby certify that the foregoing is true and correct to th'e'best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion rep, ort a_nd.: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 (m~Jitiple 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 .s. upplemental records for this well should show the details of any multiple stage cement- ing and the lobation 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". Form 10~,07 STATE OF ALASKA ALAS' OIL AND GAS CONSERVATION COMI' SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 2710' FNL, 1029' FWL, Sec. 22, TION, R15E, UN At top of productive interval 2267' FSL, 542' FWL, Sec. 15, TION, At effective depth 2559' FSL, 567' FWL, Sec. 15, T10N, At total depth 2595' FSL, 569' FWL, Sec. 15, T10N, 11. Present well condition summary Total depth:' measured 1}505 true vertical 9226 R15E, UM R15E, UM R15E, UM feet Plugs (measured) feet 5. Datum elevation (DF or KB) 71' RKB Feet 6. Unit or Pr.,oper, t,y narQe vruanoe uay Unit 7. Well number DS 17-11 8. Approval number 84-244 9. APl number 50-- 029-21259 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 11445 feet true vertical 9191 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 110' 20" 2508' 13-3/8" 10861' 9-5/8" 937' 7" measured 10893' - 10916' true vertical 8757' - 8777' Junk (measured) Cemented Measured depth True Vertical depth To surface 110' 2800 SX 2508' 500 SX 10861' 340 SX 10550' - 11487' Tubing (size, grade and measured depth) 5½" 17# L-80 10484'MD & 4½" 12 6# L-80 10612'MD Packers and SSSV (type and measured depth) B0T 3-H Packer 0 lO.~4'Ml'); Clf. i~ ~.~V Ca ?IRI_'MFI 12. Stimulation or cement squeeze summary Intervals treated (measured) 110' 2508' 8731' 8481' - 9213' Treatment description 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 Subsequent to operation N/A 200 180 0 950 231 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 GWF (6268) Title Submit in Duplicat6 99S i e DATE' Ju.'ne 6. i986 A R C; 0 F:"r' e .-;i.' .?i: u. 'r' e C C)j:) y a .'..!: · r e,.':: e i !::' "r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v,~vllSSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-244 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21259 4. Location of well at surface 9. Unit or Lease Name 2710' FNL, 1029' FWL, Sec.22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2267 FSL, 542' FWL, Sec.15, T10N, R15E, UM 17-11 At Total Depth 11. Field and Pool 2595' FSL, 569' FWL, Sec.15, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 71' RKB ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/1 8/85 03/07/85 03/11/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MDFTYD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 11505'MD,9226'TVD 11455'MD,9191 'TVD YES [~X NO [] 2181 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run D I L/LSS/SP/GR, FDC/CNL/Cal/GR, 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 110' 30" 2000# Po] eset 13-3/8" 72.0# L-80 Surf 2508' 17-1/2" 2400 sx CS Ill & 400 sx CS II 9-5/8" 47.0# L-80 Surf 10861' 12-1/4" 500 sx Class G & 300 sx CS II 7" 29.0# L-80 10550' 11487' 8-1/2" 340 sx Class G 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" 10,612 ' 10,504' 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.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casin§Pressure CALCULATED.1~ 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. NONERECEIVED APR 0 8 1986 Alaska 0ii & Gas Cor~s. Anchorage Form 10-407 * NOTE: Tubing was run 2/16/86. DAM/WC97 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sag River Top Shubl i k A Top Shublik B Top Shubl i k C Top Sadlerochit HOT OWC GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 8751 8779 8796 8814 8851 9043 9117 . ...FORMATION TESTS . : 10,885' 10,918 ' 10,939' 1 0,960 ' 11,005 ' 11,250' 11,350 ' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify .that the foregoing, is true and correct to the best of my knowledge . Signed Title D ate 4 '4 "8~ 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: Meth'0d 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". Form 10~,07 AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on the first Wednesday attar allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District J County or Parish Alaska I North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL 28331 Auth. or W.O. no. ITitle ~ AFE 404349 mpletion Accounting cost center code State Alaska Well no. [7-1! W/O WWS #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Date and depth Complete r~'~ord as of 8:00 a.m. 2/14/86 2/15/86 thru 2/17/86 for each API 50-029-21259 IA.R.Co. W.I. 21.66% IDate 2/13/86 day reported I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our I Prlor status if a W.O. 2300 Hrs. 7" @ 11,505' 11,449' PBTD, ND BOPE 9.4 ppg NaC1 Accept ri~ @ 2300 hfs, 2/13/86. plug leaking, ND BOPE. ND tree, NU & tst BOPE; tst 7" @ 11,505' 11,449' PBTD, RR Diesel Chg out damaged 13-5/8" tbg spool. Tst BOPE. RU WL, rn gage ring/JB in 9-5/8" csg & 7" csg, RD WL. Rev out diesel cap. Rn 245 jts, 5½", 17#, L-80 AB MOD 8RD tbg & 2 its, 4½", 12.6#, L-80 BTC tbg & lnd w/SSSV @ 2181', PBR @ 10,484', Pkr @ 10,504', TT @ 10,612'. Drop ball, set pkr, shear PBR & re-lnd tbg. Tst tbg & ann. Instl BPV. ND BOPE, NU & tst tree to 5000 psi. RU WL, pull GLM dummy vlv @ 2986'. Displ tbg & ann to diesel. RIH w/GLM d,mmy vlv & reset. RD WL. Tst tbg to 2500 psi. Shear ball @ 3200 psi. Re-press tbg to 3000 psi. Set BPV. RR @ 2400 hrs, 2/16/86. R ECFIV~D Did TD J New TD I Released rig ~ Date I 2400 Hrs. Classifications (oil, gas, etc.) O±l 2/16/86 APR 0 8 1986 Alaska Oil & G~s Cons. Commission A~ch3r~rje 1,8 l 1,449 ' Depth Kind of rig Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test !Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Prudhoe Bay .,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 27, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-11 DS 17-12 DS 17-13 DS 16-7 DS 16-15 Permit No. 84-244 Permit No. 84-245 Permit No. 84-179 Permit No. 84-204 Permit No. 84-264 Enclosed is the "Subsequent" Sundry Notices detailing work completed on the above-mentioned we ls. Very truly yours, D. F. Scheve DFS/GWF/jj Enclosures CC: SOHIO Alaska Petroleum Co. kile PI(DS 17-11)W1-3 PI(DS 17-12)WI-3 PI(DS 17-13)W1-3 PI(DS 16-7)W1-3 Fl(DS 16-15)Wl-3 RECEIV APR0 AlaSka 0il & Gas C ....... - ARCO Alaska. Inc. ,s a SuDs;diary of Allar~ticl~fchl,,ei(~Ccmpany STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION cOI~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well SHL' 1029' FWL, 2710' FNL, Sec. BHL' 316' FWL, 2662' FSL, Sec. COMPLETED WELL [~X OTHER [] 22, TION, R15E, UM 15, TION, R15E, UM 7. Permit No. 84-244 8. APl Number 50- 029-21259 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-11 11, Field and Pool Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudh0e Bay 0i 1 Po01 RKB 71' PAD 36 4'I ADL 28331 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 [~X 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 Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 17-11 at selected intervals within the Sag River Sand and the Sadlerochit Sand of the Prudhoe Bay Unit. 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. Mef' BHCS 03-07-85 Proposed Perforation Intervals' 10894-1 11014-1 11198-1 0914'MU Sag River i174'MD Sadlerochit 1218'MD Sadlerochit RECEIVED APRO 1986 Alaska Oil & Gas Co~S. commi~io~ Anchorage 14. I hereby;qertify that t!~e fo~r~egoin~.is true and correct to the best of my knowledge. Signed ' u~4~, "~'"~' Title ,Operations Engineering Mgr_ Date .7, The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office E 100360 Anchorage. A~r-~ka 99510 Telephone 907 276 1215 Date: October 21, 1985 Reference: ARCO CH Finals 2-10~' CET Log 6-30-85 3-2/ CET 3-11-85 '~6-10 ~CET 3-6-85 7-2-' CET 3-8-85, 9-16 ~ Gamma Ray 4-27-85 11-12"CBL ' 12-13-~4 · 13-4 --CCL/Perf 5-8-85 13-25~EPL 4-13-85 13-98'CNL 8-14-85 13-98'CNL 8-14-85 14-2z CET 6-29-85 14-4-- CET 6-29-85 '~'14-7-- CCL 4-5-85 14-34 ~CET 3-'~0-85 ' 15-12'CET 3-9-85 '"~"~"~! 7-11-~CET 3-2 3-85 17-13-CET 3-4-85 17-14~CET 3-3-85 Run 1 1 5I! 5" Sch 'Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1~. 5" Sch 15 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5"' Sch t' 5" Sch 1 5" -' Sch . 1 5" Sch 1 5" Sch (Recomputed) (Epithermal-Recomputed) (Thermal-Recom'~uted) . . Please sign as receipt of da~a~ ,- Received by .~" ~'C.T ~ ~,. ~.._(~5~ COns-~,_ ' Pat. Lamber t aOChorage' ~'umn~iS$iorl · ATO 14 29C Trans 365 Chevro~ DAM Ex~l. Services" Ext. Exploration~ Exxon Marathon Mobil PhilliBs -~ PB Well Files R&D Sohio ~a=e~,of~-Ataska. Tmxaco - ALASKA OIL AJ/D ~,AS OO,~SERI/ATIO#.~,O/~,gI$$10/i · Lo o , -.S~: . L :. T I ~ .IV. ~ 15' ~ U, l~ . , ' . · __ '. 14e wish to brlf, g to your atteueton ehae the Co~te~on hag no~U . e~ U reee · ~l~tcl, ired the followtug required ttem~ on the oubJ e ~elI-. . . ,. Article 536(b) of Ttele 20, Chapter 2.5, Alaska Adminisera~ive Code, 8eipulatee ti, aC el,f8 maeertal shall be filed within 30 days a£~er compleeto,~ of a drtlled.~ell. Pleaoe oubmle the above Chairman lc,0.024 ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: July 16, 1985 Reference: ARCO OH Finals 9-34 Induction Resitivity 6-7-85 Run i 2"&5" Sch 17-11 Cyberlook 3-7-85 i 5" Sch 17-11 Long Spacing Sonic Waveforms 3-7-85 1 5" Sch 17-11 DIL 3-7-85 17-11 Litho Density Poro 3-7-85 17-11 Litho Density Raw 3-7-85 17-11 Long Spacing Sonic 3-7-85 1 2"&5" Sch i 2"&5" Sch i 2"&5" Sch i 2"&5" Sch 17-11 Gamma Ray through Casing 3-7-85 1 5" Sch Pam Lambert ATO 1429C Trans 211 Chevron Phi 11 ips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Mara t hon Tmxa co Mob i 1 ALASKA OIL AND ~A$ GONSERYATION-~,OM~I$$10N Bill ~heHief(/, Governor 300l PORCUPINE DRIVE ANCHORAGE,ALAOKA gg6ol~-31gz TELEPHONE(gO1) 2;0,...143:] RE.' Weli · Loc Permit No. ~ r attention that the Commission has We wish to bring t~o you A terns on the subject, well yet received the zollowing requireu .i . , ~-~ //_~:~z:-- ' which our records indicated was compiete~ ~/.3-/~ . ~u o~ ~L e 2 Alaska Admin Cha ter 5, Article 536(b) of Title 20, P shall be filed within 30 day~ that this material Code, stipulates after completion of a drilled.well. Please submit the above missing ~aterial. Chairman lc:C.024 ARCO Alaska, Inc. Post Office B'~"100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 17-11 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. Tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L43 Enclosures RECEIVED APR 2 5 1985 Alaska Oil & Gas Cons. 0o,'nmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfJeldCompany STATE OF ALASKA ALASKA"-.._- AND GAS CONSERVATION CL~..,VIlSSION W LL COMPLETION OR RECOMPLETION REPORT AND LOG iw i 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-244. 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21259 4. Location of well at surface T~,.~~-~T 9. unit or Lease Name .... -~ ~ Prudhoe Bay Unit 2710' FNL, 1029' FWL, Sec.22, T10N, R15E, UM ! \/~"~-~'~ i lO. WellNumber At Top, Producing Interval 2267 FSL, 542' FWL, Sec.15, T10N, R15E, UN ! 17-11 ?" ~'-[~-~ 11 Field and Pool At Total Depth 2595' FSL, 569' FWL, Sec.15, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKB ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/18/85 03/07/85 03/11/85 N/A feet MSLI N/A ~ 7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost l1505'MD,9226'TVD 11455'MD,9191'TVD YES [~X NO [] N/A feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run DIL/LSS/SP/GR, FDC/CNL/Cal/GR, 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 110' 30" 2000# Pol eset 13-3/8" 72.0# L-80 Surf 2508' 17-1/2" 2400 sx CS Ill & 400 sx CS Il 9-5/8" 47.0# L-80 Surf 10861' 12-1/4" 500 sx Cla~$ "G" 7" 29.0# L-80 10550' 11487' 8-1/2" 340 sx Class "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 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, 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.) I of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO Date TEST PERIOD I OIL-BBL GAS-MCF WATER-BBL rOIL GRAVITY-APl (corr) Flow Tubing Casing Pressure !CALCULATED Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porositv, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska 0ii & 8as Cons. C0~missi0~ Anchorage Form 10-407 TEMP/WC05 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate -~ ;. ,c-.~ ,, . .or-- '.., ?,, ';; .i~., -,~.,~'.. ~ .:,.,...,._~..0,;., .r.'.,;~c:.? $'d- ~.~*-,; -~,,- ~-~- ~.~'~ ~ ~::~:~' GEOLOGIC MARKERS ~.'r :..'< L~ ,. ,-; ';':i::';-:-:~ 4,::.,:'.'-~ ~;-':L.::~' ?~i~O~MATi'~N~TESTS'.:.;~ - ' · · . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH.· GOR, and time of each phase. N/A N/A .: · . ~ .:' . ,.~ ~: .- _- . :: . ,. · , ,.. ._ : [ :. J ':. .-.. .,-:;,- · · , .. . 31. LIST OF ATTACHMENTS Gyroscopic Sur,vey. (2 copies) ,. . 32. I hereby certify that the foregoing is true and correct to the best. of my knowledge . Associate Engineer Signed t~b ~ _~ Title Date /! INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion r~port and Icg 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". I::nrm I ~-4Fi7 ARCO Alaska, Inc. Post Office B'~....~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the March monthly reports for the following wells' 1Q-3 2U-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 1 6 Alaska Oil & Gas Cons. Commission Ancl~orago ARCO Alaska, inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASKA',,..~L AND GAS CONSERVATION C01~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well'Y~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-244 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21259 9. Unit or Lease Name 1029' Prudhoe Bay Unit 4. Location of Well at surface FWL, 2710' FNL, Sec.22, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. 71' RKB I ADL 28331 10. Well No. 17-11 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of March ,19. 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0500 hfs, 02/18/85. Drld 17-1/2" hole to 2530'. Ran & cmtd 13-3/8" csg. Drld 12-1/4" hole to 10,880'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,438'. While POH pipe stuck w/bit @ 11,377'. Worked to free pipe. Backed off ~ 11,276' (fish left in hole = 8-1/2" bit, 8-1/2" RWP, 3 DC's). Recovered fish. Drld to tl,505'TD (3/7/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 11,455'. Secured well and released rig 0900 hfs, 3/11/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 110'. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe @ 2508'. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe ~ 10,861'. 7", 29.0#/ft, L-80, BTC csg f/10,550' - 11,487'. Installed w/approx 2000# Poleset. Cmtd w/2400 sx CS !il & 400 sx CS II. Cmtd w/500 sx Class "G". Cmtd w/340 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/LSS/$P/GR f/11,498' - 10,842' FDC/CNL/Cal/GR f/11,498' - 10,842' (continued with GR to 2508') 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED N/A APR 1 6 985 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /7,~' ].- '~',/~-/ TITLE Assoc'.' ate Eng~ ..... DATE NOTE--Report:ion this form is required for each calendar month, regardless of the status of ~;e~a~i°ns, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TFMP/MI~I R Submit in duplicate ARCO Ala_s'ka F'~ O~ Box i A n c h o r a g e DATE: Apr i l 8, i985 REF'ERENCI:i]~ ARCO Magnetic -I'ape.s' w/I i -=,--I: i 'ng_s R u~3 t Sc:h · ~- "XXOiq & ~"'"h io t c,.':)py previr;u:!.-:'l.y .?en't L_~ ~"> L..I --- ... I::' i. _..', a .s' e '.-; i g 'n ..-..-~ 'n cl 'm" e t; u 'r' 'm-m f. h e a t; t: a c: h 6:, d c o p y by ,'.";'(:h !. umberger ~ a3: 'rec:eiF"f. c'.,f clat:a~ Received By ............................................................. HAVE] A NICE DAY! Kel. l.y McFar land ATO.-. t 429F' "FRANS., :,,":.C;06''z~, D :[ S 'T' R I B U 'i" ]: 0 N ( On l×_.OIJ ) CI"~ err on I) & M E]xp Lo'raj' io'n Se'm"vices- lii:xfermsion Exp I. ora'.~ ion E.' x x o n Marathon Mo b i l E & F' Phi llip_~ Prudhoe Bay We~.~. R & D Sohio State of Alaska I--i Les ARCO Alaska, Inc. Post Office BCh~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 17-11 Dear Mr. Chatterton: Enclosed is the Well Completion Report for DS 17-11. The bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU5/L46 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'-..~._. AND GAS CONSERVATION C(~...~vllSSION0 RIG IN A [ WELL COMPLETION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-244 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21259 4. Location of well at surface 9. Unit or Lease Name 2710' FNL, 1029' FWL, Sec.22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 17-11 At Total Depth 11. Field and Pool To be submitted when gyro is run. Prudhoe Bay Field 5, Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKBI ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/18/85 03/07/85 03/11/85I N/A feet MSLI N/A 17. Total Depth (M D+TV D) 11505' MD lB. Plug Back Depth (ME~TVD) 11455' MD YES19' Directional Survey[] NO ~ [ 20. Depth where SSSV setN/A feet MD I21' Thickness °f Permafr°st1900' (App fox ) 22. Type Electric or Other Logs Run D I L/LSS/SP/GR, FDC/CNL/Cal/GE 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# U-40 Surf 110' 30" 2000# Pol eset 13-3/8" 72.0# L-80 Surf 2508' 17-1/2" 2400 sx CS Ill & 400 sx CS II 9-5/8" 47.0# L-80 Surf 10861' 12-1/4" 500 sx Class "G" 7" 29.0# L-80 10550' 11487' 8-1/2" 340 sx Class "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 N/A 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED I~ 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.~ Form 10-407 Rev. 7-1-80 TEMP/WC01 Submit in duplicate CONTINUED ON REVERSE SIDE ' ': ~.':;/ GEOLO'~3'i'C:~I'A'I~KI~I~~' !:- : .":":i'.' :,i~_~?"":-" 'i;~;i "i~i~ :.'~'":-, -:' ~.' ~ '~FO'I~M~,Ti-~)N TE's-~s' F.-. ;' : ":, :'-.~:' "i.: · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEP.TH GOR, and.time of each phase. · N/A N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer .~' ~/-~"' Signed ~ t/~~ ~J-~' Title 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" Form 10407 $ UB-$ URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ONT~NUOUS r oo, Company_ A~L..&NTIC RICHFIELD COMPANY Well Name DRILLSITE 17-11 (2710'FNL,102~)'mCL,~;22,TlON.R15F, Field/Location PRU~.OE BAY, NORT~ SLOPE, ALASr, A Job Reference No. 70288 Lo~ed By: MCBRIDE RECEIVED 'Date APR 2 5 ]985 09-APRIL- 1985 Alaska 0ii & 6as Cons. Commissi~om.,ute,~,., ~, -' By.' Anchorage HALSTEAD GCT DIRECTT(3NAL SURVEY CUSTOMER LIS~IN~ FOR ~RCO ALASKa, I~C, DS 17-]1 BAY ~ORTH SLOPE,ALASKA SURVEY D~TE: 24-MAR-R5 ~NGI~!E~R: MCBRTD~ ~ETHOD$ OF COMPUTA?ION TOOL LOC~TION: TANGENTIAL- averaged deviation and azimuth TN~ERPOLATIO~ IJINE~R VERTiCA[, ~ECTIO~ IiOR~Z, DXST, PROJECTE~ nNTO A TARGET AZIMUTH OF NORTH, ? PEG 34 M~N WEST ARCO ALASKA, TNC. D5 ~7-11 PRUDHnE BAY NORTH SLOPE,ALASKR COMPUTATION DRTEI 9-~PR-fl5 KELLY BUSHING EbEVATIONI ENGINEERl MCBRIDE 71,00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF ME{~$URED DEPTH IEASURED VERTICAL YERTIC~b DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG'M~N DEG VERTICAb O~GbEG RECTANGUbAR COORDINATES HORZZ.: DEPARTURE ~ECTION SEVERITY NORTH/~OUTH EAST/~EST D~$T, AZIAUTH FRET DE~/tO0 FEET ~EET FEET DEG MXN 0.00 100.00 200 O0 300~00 40O O0 t ~00 ~00,00 900.no 0 O0 100 O0 2OO O0 300 O0 399 99 4q9 9q 599 9R 699 97 799 97 899 97 -71.00 0 0 ~ 0 0 E 29.00 011 N ~658 E 12..009 011 ~ 3544 W 229.00 0 26 S 204~ F 328,99 0 29 S 745~ ~ 42R.99 ' 0 34 S 65 45 E ~2R,08 0 4] S 4554 E 628.97 0 39 S 67 q E 728,97 0 29 $ 80 1E 828.97 0 30 S ~4 4] E i¥oooo.oo O0 1099 96 102 .96 1~00~00 tm 1109 1]0o.o0 12~9 140o O0 1309 1500'00 1499 1600:00 1509 1700.00 1699 1800.00 !799 1900.00 1899 96 112 95 1928.95 95 132~,05 95 1428,95 94 1528.94 94 1629,94 1828.9~ O.O0 0.00 0,00 N 0,00 E 0,00 N 0 0 E -o. 2 o.2 s o.o w o.2 s .0 ~5 0,66 0,24 S O,lO ~ 0,26 S 23 18 E '0:86 0,40 0.86 S 0.03 E 0,87 $ 159 g -1,30 0,26 1,22 S 0,63 E ~,38 $ 27 5 E -1.65 0.82 1.46 S 1,55 E 13 $ 4639 f -2.55 0,06 2,26 5 2,39 E ~i29 'S 4635 E . -~.46 0.81 3.05 5 3.35 ~ 53 $ 47 43 g -3.75 0.1~ 3,~! $ 4,29 E 5,36 S 53 il E -4.23 0.35 3,61 8 4,93 ~ 6,11 S 53 47 E -~ O6 =5i78 -6 31 -7.13 -7.97 -8.57 -9.39 -10.18 -11.79 o. ½ 0,2 0.27 0 12 0 25 0 88 0 32 0 16 0 57 0 31 4,42 .S 5,11 E 6,76 S 49 7 E 5.~? $ 5.38 ~ 7.42 S 46 23 E 5.0. 5 5,70 E 7,99 $ 45 28 E 6,42 S 5,81 E 8,66 $ 42 8 E 7,81S 6,30 ~ t 03 S 54 g 8,68 5 5,99 E 10,55 $ 37 E 9,49 $ 5,94 E 11.19 $ {2 4 1,05 $ 6,38 E 12,76 $30 .1 E 2000.00 1999 93 102~,93 2100.00 2099 9~ 2028.92 2~00.00 2199 92 2128,92 2300.00 2299 91 222,.91 2400.00 2399 9, 232,.01 ~ ~=- .00 2409 91 2428.91 .00 2599 90 2~2m.90 ~,00.00 2699 90 2628,90 2~00.00 ~799,~o 2720,90 2000.00 2899. q 2828.89 0 35 lq 94 40 E 0 32 N 73 17 E 0 25 N 73 29 E 0 3t 580 7 E 0 28 S 80 0 E 0 20 I~ 82 3] E 0 25 $ 68 41 E 0 2n s 55 54 E 029 S 2134 E 027 S 3541 E 3nO0.O0 ~999.80 2928.89 3100.00 3099.89 3028.89 3200.00 3199.88 3128.88 3300.00 3299,88 3~28.~8 3400,00 3399,88 3328.~8 3500.00 3499,87 342~.87 3600,00 3599,79 3528,79 3700.00 3698 3627,98 9 21 3800.00 3796.96 3725.°6 13 11 3900,00 3893.55 3822.55 1654 -12.12 -11.95 -11.69 2,32 -17.~2 -12.55 -12,96 -13.55 -14.45 -15.15 -16.03 -16.79 -17.47 -18.16 -15.99 -4.00 15.38 40.53 0 77 O' ,81 0,87 0.66 0,61 0,48 0.,66 0,38 0,66 0,55 0.38 0.34 0.68 0,70 0.81 1.90 6.12 4.27 2.17 3.11 11 ~6 lO 7 tO 62 1085 I Ol i~ 91 i! 05 1137 11,89 12,76 1343 S 14 27 S 15 O0 S 1565 S 1636 S 17,06 'S 14,44 S 3,03 S 15,59 N 39,78 N 7 28 ~ 8 282 E 8 7 E 9 76 E lO 66 E 11 39 E 12 07 E 12 80 E 13,43 E 13,69 E 13,95 E 14.33 ~ 14,60 E 14,82 E 14,75 E 14,48 E 12,70 E 7,62 E 0,58 E 8.35 W 1 70 $ E 13 84 S 39 52 E 14 59 $ 41 58 E 15 33 $ 44 3 E 15 77 $ 46 12 g 16,37 S 47 ~1E 17,12 6 4822 E 17,94 S 48 28 E 18.71 S 47 1E 1937 S 46 5 E 2022 S 45 8 E 2093 S 4413 E 2156 S 4325 E 2203 S 42 1E 22 37 S 4019 E 1923 S 4120 E 820 S 6820 E 15 60 N 2 6 E 40.65 N 11 51 ~ P~UDttOE B~¥ NORTH St. OPE,A£,ASKA T~U~ SUB2 BASURFD VERTICAL VBRTZCI6 DEVZAT~ON AZIMUTH ~EPTH DFPTH OEPTH D~G MXN D~G 4000 O0 3998,73 3917,73 18 36 420n 00 417408, 410],08 2514 4300~00 4263.30 419~.30 28 R 4RO0'O0 4436,03 4365:03 32 34 5000.00 4825 66 4754,66 43 58 5100.00 4896 44 4825,44 46 0 5200.00 4964 90 4893,~9 47 5300 O0 5032 5? 496i,57 47 36 5400:00 5099 93 5028,93 47 52 5500 O0 5~66 7~ 5095.72 ~8 11 5600:00 5.33 26 516~.26 48 5700 O0 5299 .35 522B,35 48 53 5800:00 5365 10 5~94.10 48 5~00.00 5430 70 535~,T0 49 6000 O0 54~5.24 5424,24 6100:00 5559.40 548~.40 49 6200.00 5623.30 555~.]0 50 41 6]00,00 5686.66 5615,66 50 43 640o.n0 5749.71 567~.71 50 55 6mO0.O0 5812.42 574t,42 ~! It ~)0.00 ~875,07 5R04,02 51 17 6, 0,00 5937,&~ 5866,42 51 27 6900.00 5909.41 5928,41 51 57 6~00,00 6060,87 598~.82 K2 24 7000,00 6121,17 6050.17 53 7100,00 61R0,67 6109.67 53 38 7200,00 6239,95 6168.95 53 44 7300 O0 6298,94 6227,04 ~4 q 7400 O0 6357,5R 6~86.58 54 1 7KO0 O0 6416,44 6345,44 53 52 7600 O0 6475.28 6404,~8 5] 48 7700 O0 6534.30 6463,]0 53 50 7800,00 6593.27 6529,27 5] 50 7900,00 6652,30 6581,]0 53 46 COMPUTATION DA~E{ g-APR-85 PAGE DATE OF S~RVEY: 24-MAR-SS KELLY BUSHING ~bEVATION~ E~G]NEER: MCBRIDE INTERPOLATED V~[,UES FOR EVEN 100 FEET OF MEASURED D~PTH , VERTTCAb DO,bEG RECTAnGULaR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FE~X FEET DEG ~IN . 17 a7 W 7n,57 3 04 N 15 51 w 104.01 3:20 102 N 1,5 36 w i44,59 3,44 140 N 1523 W 189.30 2,07 1~4 ~ 14 57 W 237.58 2,14 231 N 14 31 w 289,19 2,63 281 335 N !4 29 W ~44,~0 2.96 N 14 43 w 403,60 2,77 393 ~ 14 30 W 466,02 2,18 453 N 14 0 W 53~,25 1,8i 517 N 13 4 W 599,06 2,15 N 1229 W 669,41 2,06 N 1216 W 741,..60 1,13 N 1154 W ~15,43 0,48 V 1138 W 880,14 0,51 N 11 19 W 963,39 0,51. ~ 1053 W 1037,89 1,06 ~ 10 ] W li12,83 0,66 ~ 9 2~ W 118~,13 0,40 N 850 W 1263,58 0,94 . 8 11 W 1330.05 ~ 7 53 W 1416.65 ~! 7 35 W 1493.56 N 6 46 W 1570.94 ~ 6 1~ w 1648.54 ~ 5 43 W 1726,4! ~' 530 W 1804.]3 ~ 526 W 1~82,43 '~ 5 26 W 1060,f14 N 5 38 W 2039,72 ~ 5 34 W 2119.40 . 5 39 W 219q,73 ~ 5 58 w 2280.23 N 6 7 W 2360.95 N 5 5] W 2441.92 ~ 5 40 W 2522.72 ~ 5 45 W 2603.~3 N 5 45 W 2684,~2 N 5 16 W 2764,92 ~ 5 0 W 2845,57 O,7B 0,54 0,72 1,04 0,49 0,77 0,51 0,18 0,80 0 68 0 36 0 41 0 66 0 56 0,75 0,51 0,42 0,69 0,63 68 74 N 11 N 27 69 ~? 38 21 N 50 1 ~ 63 252 N 76 47 ~ 90 09 N 105 95 ~ 12 1 60 N 137 71,00 F'T 583 87 N 153,97 W 65~ 79 ~ 1~ 46 W 72~ 90 N 1~ 10 w 795 97 ~ 200 52 w 868 ]~ N 2~5, 56 W 941 26 N 2~0 39 W 1014 49 N 244 t088 28 N 258 1162 56 N 271 1237 09 ~ 283 603, 674, 747, 894, 969, 87 W 1043, 84 N 1446 W 43 N 1433 W 19 N 1420 W 84 N 14 8 W 69 N 1356 N 05 N 13 45 W 62 a 13 34 W 50 W 111.8,56 N 13 21 W 14 w 1103,76 N 13 7 W 15 W 1269,08 N 12 53 W 1312,62 N 294,43 W 134524 N 1238 W 1388,58 N 305,OR w 142170 k 1223 W 1464,78 ~ 315,54 W 149838 N 12 9 W 1542.,55 N 325,1~ W 157548 ~ 1154 , 161.8 67 ~ 333,99 W 1652 77 N 1139 W 1773 74 N 34975 W ~807,8" N [! 9 W 208756 N 379,95 W 2121,85 N 1018 W 216755 N 387,83 W 2201,97 N 10 8 W 2247 67 N 395,99 W 2282,28 N 9 59 W 2327 97 N 404.46 W 2362 84 N q 51 W 2408 52 N 412,98 W 2443 67 N ~ 43 W 2488 96 ~ 421 00 W 2524 32 N 9 ]6 W 2569 4! N 4~9 07 W 2604 99 N 9 28 W 2649 72 N 437 25 W 2685 56 N 9 22 W 27]0 10 ~ 445 04 W 2766 14 N ~ i5 W 2810 51N 452 19 W 2846 66 N 9 8 W 18 4] W 71,17 N 35 0 W 98 W I05,88 N15 19 W 91W 145,97 N 1527 W 92 w 191,1! N 15 27 W 69 W 239,82 N 15 24 W 91 ,W 291,84 N 1516 W 80 W 347,54 N 15 8 W 85 W 407,10 N 15 4 W 69 W 469,98 N 15 0 W 97 W 535,68 N 14 55 W ARCO AbASKA, TNt. DS 17~11 NORTH SLOPE,ALASKA CBNPUTATI. ON I')ATg= q-APR-85 DATE OF SURVE¥~ 24-HAR-85 KELbY BUSHING ~EV~TION= ENGIN~ER~ HCBRXDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH PAGE 71,00 FT TR~J~ SUB-SEA COURSE EASUR~D VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DFPTH DEPTH DEG MIN DEG MIN oo oo:oo 8400 nO 6951.87 6880,87' 51 44 ' .00 7078,21. 7007.21 49 58 $ - ,00 7143.04 7072.04 49 7 8800,00 7209,14 7139.14 48 10 8qO0.O0 7276.45 7205.45 47 O VERTTCAL DOGbEG REC?ANGUBAR CDORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, ~ZIMUTH FEET DE~/IO0 FEET FE~T FE~T DEG MIN 9000,00 7345.19 7274,19 45 37 9~00 O0 7416,33 7345,33 ~3 53 9~00:00 74~9.29 7419,29 42 18 9300.00 7563.84 749~,fl4 al 54 9400,00 76~7.86 7566,86 42 34 9~00 O0 7711.24 7640,24 42 54 9600:00 77~4 3~ 7713,)8 43 4 9700.00 7857':37 7786.37 43 10 9800.00 7930,15 7~59.~5 43 30 9900.00 8002,57 7931.57 43 ]2 N 5 q W2926. 16 N 5 34 W $086.76 N 5 ~4 W 3166.60 N 5 21 w 3245.57 N 5 7 W 3323,45 N 4 34 W 3400.45 N 3 55 W 3476.45 N 3 12 W 3551,31 N 2 44 W 3625.03 N 1 5~ W 3697,36 N 1 36 W 3767.24 N I 37 W 3835.26 N I 56 w 3901.59 ~ 147 W 3q68,50 ~ 1 29 W 4036,06 N 1 6 W 41.03.84 N 0 45 W 417,,75 N 0 14 w 4239,82 ~ 0 21 E 4308.17 O, 9 0,93 1o 0 Oo 7 0,31 1,16 0,84 1,36 2,60 1,46 I 73 0 89 0 79 0 3~ 0 25 0.34 0,63 0,65 2800 86 N 459. 30 Vt 2927 12 N 9 1 W 2971 01N 466 72 W 3007 45 N 8 55 W 3050 3130 3 09 3186 3363 3439 3514 3588 88 ~ 474 38 M 482 04 ~ 489 66 N 496 47 N 503 40 N 508 29 N 513 15 ~ 517 32 W 3087 13 W 3167 67 W 3246 82 w 3324 25 w 55 w 355 40 W 3621 53 N'8 50 W 29 N 8 45 W i9 N 8 40 W 00 N 8 35 W 91 N $ 30 W 84 N 824 W 62 N 8 18 W 26 N 8 t2 W 3660,7! ~ 3730,95 N 3799,30 N 520 40 W 3697 52 N 8 5 W 522 39 w 3767 34 N 7 58 W 524 34 W 3835 32 N 7 51 W 3865,94 N 5~6 3933,14 N 528 400~,03 ~ 530 406 ,20 ~ 532 4275,15 N 533 ,10 ~ 5~3 40 W 1901 60 W 3968 55 w 4036 09 W 4103 21 w 4171 85 W 4239 79 w 4308 61 N 7 45 W 50 N 7 39 W 6 N ~ 33 W 4 N 7 26 W 78 h 7 20 W 89 ~ .7 13 W 30 N 7 7 W 0000,o0 P074,80 8003,g0 43 5~ 010o.00 8146.76 8075.76 44 11 0200 ~0 ~2~8,48 8~47.48 43 46 0300 00' M291.36 0400 O0 93~6,05 8295,05 41 4 0td0.~0 9509.3. 8 2 0800.00 ~680,46 8609.46 34 51 0900,00 8763.64 869~.64 33 ~) 0 4~ E 4376.63 ~ 1 5 E 4445.31 ~ 1 35 ~ 4514,16 " 2 14 K 4581,69 ~ 3 3 ~ 4647.13 ~ 3 46 F 4710,86 . 5 7 ~ 477~.39 ~ 6 18 E 4831.42 W 7 25 E 4888.06 ~ 8 3~ E 4941,56 0,39 0,53 1.27 2.16 0,49 1,70 2,12 1,33 4344 25 N 533,14 w 4376,84 N 6 59 W 4483 36 N 530,38 W 4514,62 N 6 44 W 4551 78 N 528,10 W 4582,31 N 6 37 W 4618 19 N 525,02 w 4647.94 N 6 29 W 468299 N 521,22 W 4711,91 N 6 21W 4745 70 N 516.47 W 4773,72 N 6 12 W 4806 06 N 5i0,30 W 4833.08 N 6 3 W 4919 10 ~ 495,71 W 4944.02 N 5 45 W 1000.00 8846 76 8775,76 34 42 1100.00 fl9~7 77 8856,77 ~7 20 1200.00 0005 55 8034.55 40 21 1300.O0 9090 32 9000,32 42 48 .1400,00 0152 04 9081.04 45 .1500.00 9222 25 9151,25 45 24 1505.00 9225 76 9154.76 45 24 ~ 8 39 E 4994.90 ~ 7 11E 5051.36 ~ 5 41 ~ 5112,34 ~{ 3 47 E 517~,15 ~ 2 3 F 5245.69 ~) 1 59 F 5]15.91 ~ 1 58 B 5319,42 1,77 3,27 2,12 3,06 1,75 0,00 0,00 4974 03 N 487,22 w 4997,84 N 5 35 W 03208 N 479,03 W 5054,83 N 5 26 W 094 52" 472,05 w 5116,34 N 5 17 W 24 N 462,98 W 5250,69 N 5 3 W 5301 40 N 460,5t w 5321.36 N 4 57 ~ 5304 96 N 460,39 W 5324,90 N 4 57 W ,,, PAGE 4 ARCO AbA~KA, TNC, DS PPU~HnE NORTH TRU~ SUB-SEA COURSE IER$1)RFD VERTICAL VERTIC~b DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DFG MIN OATE OF SURVEY: 24-M~R-85 KEbbY BUSHTNG ~b~VATION: 71,00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN lO00 FEET OF MEASURED DEPT VERTICAb DOGbEG RECTANG'UbRR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~$T/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0,00 lO00.O0 000.00 1999 ~000,00 2999 4000 O0 3985 500~!00 4825 O0 5495 ,,: ~.00 61~1 8000,O0 6711 9000,O0 7345 0 00 -7i,00 0 0 999 96 928.96 0 28 93 192,.93 0 35 89 292,.89 0 34 '73 3017.73 18 36 66 4754,66 43 58 24 5424.24 50 13 17 6050,17 53 15 4] 6640.41 5345 19 7274.19 45 37 LO000 O0 8074.80 B003.80 43 52 [100o'00 9846.76 8775.76 14 42 [1505:00 0225.76 9154,76 45 24 ~ 0 0 E 0,00 S 5 q E N 84 40 E $ 6 48 E -15,15 ~ 17 47 W 70.57 N 13 4 W §99.06 N 8 lt. W 1339.95 ~ 5 34 W 2119.40 ~ 5 ~ W 2926.]6 N 1 51 W 3697.36 N 0 42 ~ 4376.63 ~ 8 39 E 4994.90 N I 58 E 5319.42 0 00 0 1I 0 77 0 38 3 04 2,15 0,78 0 65 0:59 2,60 0.39 I 77 0:00 0 O0 N 4 68 583 1312 2087 2890 3660 42 $ 5 26 S .7 43 S t3 74 N 62 ~ 2 56 N 3~9 86 N 459 71N 52O 11 E 6 28 E 13 95 E 19 43 W 71 97 w ,603 43 W 1345 95 w 212½ 30 w ?92 40 W ~697 0 O0 E 0 O0 N 0 0 E 76 S 49 7 E 41 S 32 52 E 37 $ 46 5 g 17 N 15 0 W 84 N 14 46 W 24 N 12 38 W 85 N 10'18 W 12 N 9 1W 52 N 8 5 W 4344.25 N ' 533.14 W 4376,B4 N 6 59 W 4974,03 N 487.22 w 4997,84 N 5 35 W 5304,96 N 460.39 W 5324,90 N 4 57 W ARCO ALASKA, ?NC. DS 17~11 iEASURED VERTICAL VE~TICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M~N DEG MIN 0.00 71,00 171.00 271.00 371 O1 o~i '°2 .o2 ~71.03 COMPUTATION DATE:, 9-APR-~5 PAGE DATE 'OF SURVE'~ 24-MAR-SS KEbbY BUSHZNG EbEVAT~UN: ENGINEER~ MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUSmSEA DEPTH VERTTCAb DO'bEG RECTANGUbAR COORDINATES HOR~Z, DEPARTURE SECTION SfVERiTY NORTH/SOUTH EAST/NEST DIST,. AZTRUTH FEET DEC/l, 00 FEET FEET FEET PEG MIN -Tt.O0 0 0 0,00 0,00 0,00 0 12 0,39 0,22 ~00 00 0 4 0 74 0,20 oo:oo o o:5 o.6 300.00 0 25 0,20 1,17 400.00 0 33 0.08 1,40 500.00 0 42 0.14 2,00 600.00 0 42 0.'36 2,86 0 30 0.09 3,17 0 27 0,91 3,39 0 O0 71 O0 171 O0 271 O0 371 On 471 O0 571 O0 671100 771 O0 700,00 871 O0 900.00 0 27 0 24 0 21 0 3l 0 28 0 21 0 33 0 2~ 0 34 0 26 0 33 0 32 0 2] 0 34 0 32 0 23 0 26 0 28 0 29 0 32 0 29 0 29 0 28 0 23 0 23 0 24 2 52 971.04 971.00 uO0.O0 1071.o4 1071.00 i000.00 1171.04 1171.00 1100.00 1~71.05 1271.00 1~00.00 137~..05 1371.00 1300.00 1471.o5 !.47~,00 1400.00 1~71.06 157 o00 1500.00 1671.o6 1671.00 1600.00 177i.06 1771.00 1700.00 1871.07 !871.00 1RO0.O0 1071.07 1971.00 2900.00 207t.08 2071.00 2000.00 2171,08 2171.00 21.00.00 2~71.08 ~271.00 2~00.00 2~71.09 2371.00 2300.00 .09 ~571.00 2~00.00 1.10 2671.00 2600.00 2771,10 2771,00 2700,00 2R7~.11 ~871.00 2RO0.O0 2071.11 2971.00 2900.00 3071.11 3071.00 3000.00 3171.12 3171.00 3100.00 271,12 3271.00 3200.00 ~371.12 3371.0n 3300.00 3471o12 3471.00 3400.00 3571.14 3571.00 3500.00 0.00 -0.~0 -0.22 -0.64 -1.~1 -3.55 -2.~7 -3.23 -3.68 -3,99 -4,R3 -5.63 -6.13 -6 85 -9.40 -9.i3 -9.96 "10.82 '11.68 -1~.07 "tl.97 - -12.~1 12.44 '12.78 -13.34 -14.20 -14.87 -15.~3 -16.55 -17.~7 -17.99 -19.64 -17.70 -8,~0 ~.60 33.98 0 24 0 50 0 22 0 44 0 10 0 58 0 16 0,74 0,29 0,27 ,20 S ,98 5,44 6,15 S 7,01 7'.64 8,40 9.2$ 10,14 S 10,96 S 0.48 11,25 0,55 11,02 0,15 10,72 0.11 10,75 0.55 10,93 1 10,97 68 11,22 0,62 11,69 0,51 12.52 0 68 0 51 0 47 0 47 0 29 0.69 6,38 ,42 .34 4.43 $ S 13 ~9 S 14 14 77 $ 15 45 S 16 19 S 16 88 S 10 '0] .05 N 33,48 N 0.00 O, 13 0,13 0.02 2,13 3,0.5 4,04 ,81 5 25 ~ 5 6~ E 5 74 F 5 99 ~ 6,28 6,07 6,00 5.86 6,18 7 O0 E ,95 78,71 9,49 I0 42 11 23 E 11 89 E 12 6! 13 30 13 57 13 93 14 16 14 54 ~4 80 14 75 14 49 13 64 9 30 r 2'/1 ~ 6 07 W 71,00 FT ,60 S 50 31E ~,24 S 46 29 E 7,8~ S 45 57 E 8,41 S 43 2 E 9,22 S 40 28 E 9,89 $ 39 24 E 10.36 S 35 50 E 11,0~ S 3~ 57 E 11'.71 S 30 1 E 12.58 $ 29 25 E 13.25 S 31 53 E 13.59 S 35 47 g 13.81 $ 39 6 E 14.34 S 41 '26 g i5 10 S 43 38 E 15 69 S 45 42 E 16 18 S 47 17 £ 16 8~ S 48 21 ~ 17 70 S 48 40 E 18 46 S 47 17 E 19.16 $ 46 39 E 19,9~ S 45 7 E 20,73 S 44 33 E 21,40 $ 43 45 g 21,90 S 42 20 E 22,25 S 40 39 E ~1,06 S 40 21 ~ 11.66 S 52 52 E 10.4' ' 15 5 g .02 N 10 17 W 3671.69 3671.00 3600.00 8 10 3T73.37 3771.00 3700.00 12 29 3876.48 3871.00 3800.00 16 I 0,00 N 0 0 E 0,26 S 30 18 W 0,24 $ 33 30 E 0,65 $ 1 53 1,24 S 19 17 E 1,89 S 42 19 E , 46 43 E 5 88 S Z : so ARCO AbASKA, INO, DS 17-11 PRUDHRE BAY NOR?H SLOPE,ALASKA COMPU?ATION DATE: g-APR-85 PAGE DATE DF ~URVg~! ~4'MAR-85 ~g~bY BUSHING ~h~VATZON~ ENGINEERI MCBRIDE I,TERPOLATED VALUES FOR EVEN 100 FEET OF 8UB-SER DEPTH TRU~ SOB-SEA COURSE tEASURED VERTICAL VERT~.CAL DEVIATION AZIMUTH DEPT. D~PTH DEPTH DEG 398~,]1 397~,00 3900,00 t8 l] N ~,8 4~ W 4087,6~ 407~.00 4~00,00 21 42 N ~5 47 W 4~96.59 4~71,00 4tO0,O0 25 6 4~0~.74 4271,00 4~00.00 ,4423.~3 4371.00 4300,00 ,0 41 541.~6 4471,00 4400.00 33 38 ~.28 4571,00 4BO0,O0 36 56 ~,9 ,03 4671,00 4600,00 39 47 4924.96 4771,00 4700,00 42 28 5063.66 4871,00 4800,00 45 5208,R7 497{,00 4900,00 47 5356,99 5071 O0 5000,00 47 37 5506.42 5171 O0 5i00,00 5~56.09 5271 O0 5?00,00 ~8 39 5~0,.97 ,371 O0 5300.00 48 53 5962.14 5471O0 5400,00 49 59 6118.05 5571 O0 5~00.00 50 3 6275.~2 5671 O0 5600,00 6433.78 5771 O0 5~00.00 5i 7 oo ooo:oo 8100,62. 6671,00 6600.00 53 45 44 6771,00 6~00,00 5~ 29 826~,61 6872.00 6800,00 52 55 8430.~5 6971.00 6000.00 51 21 8588.78 7071 O0 7000.00 50 3 874~.54 ~171 O0 7i00.00 48 42 8891,96 ~2~1 O0 7~00.00 9036,60 7371 O0 7300,00 44 50 9125.1.9 7471 O0 7400,00 ~2 44 9309.65 75~1 O0 7~00.00 9445.13 76~1 O0 7600.00 42 47 9581.68 7771 O0 7700.00 971R,70 7871,00 7RO0,O0 43 VERTICAL DOGbEG SECTION SEVERITY FEET DEG/IO0 64,77 100.32 i4]. 249.47 311.85 460,95 547.92 643,55 N ~.5 37 W N 15 23 W N i4 50 W M 14 25 W N i4 40 W N 14 30 W N 13 47 W N 12 33 W u 12 14 W 748,45 ~ 11 41 W 857,39 N 11 18 W 968,16 W lO 23 W 1080,53 M 9 2~ W 1194,88 ~ 8 25 W 1310,88 v 7 5~ W i430,47 ~ 6 56 W 1551,86 ~ 6 7 w 1674.76 ~ 5 32 W 1799,30 N 5 38 W 2052, N 5 38 W 2186. N 6 o w 2322.57 w 5 47 W 2460.42 N 5 45 W 2597.70 N 5 2q W 2734,43 N 5 0 W 2871,04 N 5 23 W 3006,94 N 5 37 W 3140,81 , N 5 16 W 3269.63 N 4 36 w 3391,87 ~ 3 36 W 3508.44 N 2 47 w 3619.,4 N 1 37 W 3723,17 ~ ! 37 W 381~,60 ~ I 55 W 3908.02 N 1 39 W 3998,97 N 1 q w 4091.4! N 0 4i W 4i84,45 1,84 3,36 3 39 2 O0 2 3~ 2 47 2 68 2 12 2 11 2 19 1,04 0,66 0,63 ! 02 0 6¢ 0 7O I 22 0 44 0 0 35 0 81 0 71 0 56 0 31 0 28 0 49 0 85 1,09 0,71 1,06 1,19 1,82 6 ~9 43 71,00 FT RECTANGULAR COC}~DINATES HORIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZ*~UTH FEET FEET FEET DEG 449 Ot N 42 W 464 88 ! W 5 0 533 88 , 142 O! W 552 44 N 14 53 627 45 N 163 85 W 648 49 N 14 38 730 26 N 186 49 W 753 70 N 09 13 W 62 88 N 14 837 16 N 2 8 945 95 N 23133 w 973 82 N 1.3 44 W t056 46 N 2 77 W 1086 28 N 13 27 ~~ i169 23 N 2 24 w t200 50 N 13 6 ~ t283 85 , 200 23 w 1316 25 N ~2 44 , 140~ 27 N 306 98 W 1435 48 N 12 20 ~ 152 61 N 3~2 90 W 1556 47 N 1i 58 , 1644 75 , 336 79 W 1678 88 N 11 3, ~ 1768 73 N 349 26 W 1802 88 N 11 i.O W ,893 56 ~ 361.14 W 19~7 69 N {~ 4~ ~ 2091 40 M 37~.,48 W 9055 61 N 2 W 2154 46 N 386,55 W 2188 87 N ~289 80 M 400,39 W ~324 54 N 9 55 24~6 94 ~ 414,87 w 2462 I4 N 9 42 2563 61M 428,48 W ~59917 N 9 29 W 2699 72 N 442,16 W 2735 69 N 9 18 W 2835 91N 454,42 W 2872 09 N 9 2971 36 N 466,75 w 3007 80 N 8 59 W 3104 70 ~ 479,59 W 3141 53 N 8 46 3233 O1N 491 90 w 3270 22 N 8 39 3354 91N 502 56 W 339234 N 3471 39 N 5110i W 3508 80 N 8 22 3582 25 N 517 1, w 36,9 38 N 8 12 3686 65 N 521 16 W 3723 31 N 8 2 3782 56'N 523 86 W 38,8 67 3872 40 N 526 6i W 3908 04 3963 75 , 529 54 W 3998 97 N 4056 70 N 531 84 w 4091 41 N 7 28 4150 36 N 533 38 w 4184 49 N 7 COMPUTATION DATE: g-APR-85 ARCQ abASwA, INC. DS 17-11 P~UDHOE BAY NORTH SLOPE,ALASK~ DATE OF SURVEY~ 24-MAR-85 KELLY BUSHING ELEVATION: ENGXNEER{ MCBRIDE 71,00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPT~ DEPTH nEPTH DKG M~N DKG MiN 9856 47 7971 O0 9994:73 B071:00 0272.77 82 0406.57 8371 oA37.42 ~471 ut 45 ~671 .090~ 77 8771 1029,57 8871 7900,00 43 37 8000,00 43 52 O0 8100,00 44 16 O0 8~00,00 42 57 O0 8300.00 41 0 O0 8400.00 ]9 O0 8~00.00 37 7 O0 8600,00 ]5 5 O0 8700.00 33 4 O0 8800.00 35 17 VERTICAL DOGLEG R~CTANGUbAR CO0~D2NATES HORXZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIRUTH FEET DEG/IO0 FE~T FEET FEET DE~ MIN 1155 02 897~.00 8900.00 ]9 7 1987']2 907~.00 9000.00 42 ]i 1427:00 9i71.00 9100.00 45 24 .1505'.00 q225.76 9154.76 45 24 N 0 4 E 427~.46 ~ 0 40 E 437].01 N I 1~ E 4468.66 ~ 2 4 ~ 456].14 N 3 5 E 4651.]7 N 4 It E 47~4.16 ~ 5 59 E 4810.70 N 7 21 E 4881.67 ~ 8 40 E 4946.14 ~ 8 21 E 5011.18 N 6 18 ~ 5084.34 N 4 5 E 5!68'72 N I 58 E 5264,64 1 58 E 5319.42 0,46 4437 1,51 45]2 i. O0 4622 .0~ 4706 . 4857 , 4990 3,27 2,95 0,00 0,00 11 N 533 91 W 4278,56 N 7 10 W 60 N 533:18 W 4373.22 N 7 0 W O2 N 649W ]0 ~ 531 51W 4469 97 ~ 528 8~ w 4563 50 N 524 80 w 4652 72 N 51.9 56.W 4735 85 , 512 58 W 4812 N 504 11 W 4883 81 N 494 99 W 4948 79 N 484 70 W 5014 71 N 6 39 W 20 N 6 28W 3t N 6 17 W 23 N 6 6 ~ 65 N 5 55 W 63 N 5 44 W 27 N 5 32 W 5065,.88 M 475.03 W 5088,~0 N 5 21 W 5249,45 ~ 462,31 W 5269.76 N 5 I w 5304,96 N 460,39 W 5324090 N 4 57 W ARC~ Ab~KA, DS 17-11 NORTH SLOP[,Ar, ASKA ~ARKER ToP 5~G RTV~R TOP SHU~[,TK TOP 5HURbTK TOP $~UBbTK TOP ZONE ~ HOT TOP ZnNE ~ O/W CONTACT P~T~ TP C~PUTA?[~N DATEI 9=APR-85 INTERPOLATED VAbUFS FOH CHO~BN HORIZONS MEASURED DEPTH BELOW KB 10BB5.00 10918,00 10939.00 10960.00 llOOS.0n 11246.00 11250.00 11313.00 1350.0n ~1455.00 11505,00 PAGE 8 DATE OF SURVEY! ~4-HAR-85 KEb~Y BUSHING ELEVITION{ ~1.00 F{ SURFACE LOCATXON ORIGIN= 2710' FNL.1029' F~L. SECR .TION RtSE,UM TVD RECTANGULA COORDTN}TES FROM KB SUB-SBA NORTH/SOUTH EI~T/~EST 8751.04 8778.74 8796.29 881].73 8~50.R7 9040.]1 904].]0 9089.83 9116.~1 ,9190.66 8680 04 8707 74 8742 8779 87 8969 31 8972 30 9018 83 q045 61 9119 66 491],04 N 496,93 4928.90 N 494.22 4951.73 N 490.66 4976.85 N 496.79 5124.S0 N 469,~0 5i27.14 N 46R,97 5169,49 N 465,P3 5194.99 N 464.45 5269.37 N 461.62 9225.7b 9154.76 5]04.96 N 460,39 W PRUDHOE MARKER ToP SaG RTV~R TOP SHIJBL[K A TOP SHURLIK B TOP SHUB~IK C OP ZON~ 3 HOT TOP ZONE 2 .O/W CONTACT TD COMPUTATION DATEI g-APR-85 MEASURED DEPTH BELOW KB PAGE DATE OF SUPVEY: 24-MAR-85 KELbY ~USHYNG EbEVATXONt 71,00 FT ENGXN~ERI ~CBRIDE SURFACE LOCATION ORIGIN= 27~0' F~b,t029' r~t,. SEC TVD RECTANGULAR COORDINATES F~OM KB SUB-SEA NORTH/SOUTH EAST/WEST 8680 04 8707 74 8725 29 8742 7~ 8779 87 8969 31 8972 30 9018 83 9045 6i 9119 66 10885 O0 8751,04 10918~00 8778.74 10939..00 8796.29 10960,00 8813.73 lt005.00 8850 87 ~1~4~.00 9040:3! ! ~ ,00 9043.30 11313,00 9089.83 11~,00 9116.61 1 ,00 9190.66 4928 80 4m4o i9 4951 73 4976 85 5124 50 5127.~ 5169. 5194.99 5269.]7 5304.96 N 494 490 66 W 486 79 W 469 20 W 468 97 W 465 83 W 464 45 W 461 62 W 460,39 W 11505,00 9225.76 9154,76 FINAL WELb bOCATYON AT TD: TRU~ StIR-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11505.00 9225.76 ~154.76 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FE~T DEG MIN 5324.90 q 4 57 W SCHLUMBERGER 0 1 RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 17- 1 1 FIELD PRUOHOE BAY COUNTRY USA RUN ONE DATE LOOOEO 24-MAR-SS REFERENCE 0000?0288 WELL: DRILLSITE 17-11 SURFACE LOCATION: 271C' FNL, 1029' FWL, S22, T10N, R15E, UM VERTICAL PROJECTION -'.000 O O ]0O0 2000 3000 4000 5000 SO00 7000 172. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:.~':.~:~.u.~.~ ...... ~...¢_.~...~..u_.~._;..~...r;..~..~_;..~..;..~..~...~_ ...~.._~_.~...?.~t.!.!._ ...:..~: ~...~:.~... .!..X...Lj. ~X...;...'./:...:...;...?...~...~..~..;...~...~...~..;..;.. 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', j -:. ?;:---r-~ -~ -~---[---- l---.:---;-,--- ]---~---f---~--~---r-.~--.-~..-$--~ ...... ;.1~.~.~?.f...*..?j...t."~..~..~...~...;...f...f..~.~1...~...?.~.t...~...?..~..~...?.~...~ ...... 1::~.:*:* .... ~' : i :;~* **~'~~ ~1:--:~. :~*~:.~.~.:~.~6~]..~;.~:?::W~:~::~:~F~::~.~::.~::~*~::~:.~:~F~:~:x:~:~]::~:~::6::j~::~::~:::~::.~:.~:~:~<:.~*::F:~::~:~:~?~F~--. ~ F~'"'~'":"'?r'~'"'?"~ ..... ~"~n'~n'~"'~"~'"'~'"r~ ....... ~'"~."~'"r~'"?"*"~"~?"~'~"'~'"~"'~ ....... ,'"~"';'"~'"?'"?-:"~:' ~?~''''~'';' '~ ....... :":'": ............... ': :': .... ~'~" ::~ ";": "' ~ ..... " ~ ?---;---?--,-'-~'--~ ....... :--'~ .... ~ ~.. ~ PROJECTION ON VERTICAL PLANE 3S2. - ]72. CJCALEO IN VERTICAL OEPTHS HORIZ SCALE = './ 1000 IN/FT WELL: DRILLSITE 17-11 SURFACE LOCATION: 2710' FNL, 1029' FWL, S22, T10N, R15E, UM HORIZONTAL PROJECTION NO~TH 7000 REF 000070288 sooo SO00 4000 9000 2OOO ] 000 SOUTH -i000 -4000 NEST ........ '-? ................................................. ~- ........................................................... ; ............. J. i ":'"; ....... : J'"; ........ : ';"T"':"~' ":"': ....... ~-~ ~.;.-=ff-..;....;-.~ ..... :-.;-.,~.-..~..?.f ...... .i } ............... : .... : ...... ; .................. :..~ ............ , .... ~ .... ~ .... : ............................. :. ........... ~ . . :. & ; .: : · . . . . . , . . - ': : : : ! ' -- : - : ! . -: . I . -- . i. .: '- .... : .' : ' · ". ' " ' ~'~]'~"-' [i!J ~/'f~";"~"]'i'~:-'~i~ i~';T'?.''' ~'~'~j?"~'~'~ .........J ~ ..... _/;'" ,il; ';'-; j '_ " . . ' 1. -,-' ...... Iv'. ........ , ..... ? .............. :''i ............ I ............. - ............. ~ .... - .... ;'1 ....... I ' 1 ' ' I _~ -3000 -2000 - J 000 0 ] 000 2000 3000 4000 ERST Suggested form to be in:.erted in each "Active" well folder to check for timely compliance with our regulations. 0PE~CATOR, WELL NAME ~J~ID NUMB~ER Reports and Materials to be received by: '"~'~-/'1 .. Date Required Date Received Remarks Completion Report Well History [? Samples ~ .- pi ..... ~/~ Core Ch~ps Core Description Registered Survey Pi~'~ Inclination Surveys,. Drill Stem Test Reports Production Test Reports Log Run,...__ .. ' ':~? Digitized Data ~ ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 t~arch 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2w-2 2w-3 2w-4 If Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L18 Enclosures you have any questions, please call me at 263-4944. RECEIVED 1 4 1985 Alask8 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION cO~/i'MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 11. Drilling wellX~ Workover operation [] 4. Location of Well at surface 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-244 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21259 9. Unit or Lease Name 1029' FWL, 2710' FNL, Sec.22, TION, R15E, UM Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 71' RKB ADL 28331 10. Well No. 17-11 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0500 hfs, 02/18/85. Drld 17-1/2" hole to 2530'. Drld 12-1/4" hole to 10,880' as of 2/28/85. Ran & cmtd 13-3/8" csg. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 110'. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe @ 2508'. Installed w/approx 2000# Poleset. Cmtd w/2400 sx CS III & 400 sx CS II. 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED N/A MAR 1 4 1985 Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (¢f~~~ TITLE A-~-~o~.i~-- Fno~n-er DATE .,~-'--~-8--~" NOTE--Reportl~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR1 2 Submit in duplicate MEMORANDUM TO: THRU: Lonnie C. Smith Commissioner State of Alaska FILE NO: D.BHL.14 TELEPHONE NO: FROM: Ben LeNorman Petroleum Inspector SUBJECT: Witness BOPE Tests on ARCO's DS 17-11, Sec. 22, T10N,R15E,UM, Prudhoe Bay Unit. Friday,..February 15, 1985: I departed my home at 1:50 pm for a ~20 pm 'ShOWUp and'~:20 ~m departure via Alaska Airlines, Flt. #57 for Deadhorse, arriving at 5:00 pm. Weather: -42°F, calm, ice fog. Saturday, Febru.~r~ 16, 1985: BOPE tests on ARCO's Kuparuk 2U-3 ~ere ¢omp'leted, the-SUbject of a separate report. Sunday, February 17, 1985: BOPE tests on ARCO's Kuparuk 2C-11 were ~ed~ th~""~ub~ect' 0~' a separate report. Monday, February 18, 1985: Setting of plug across 9 5/8" shoe on ~RC0's WeSt ~Ak:~-6~~ ~ompleted, the subject of a separate report. ~~ebruary 19, 1985: BOPE tests on ARCO's DS 17-11 began at - , and were completed at 4:00 am. We~~ay, February 20, 1985: . . · B--~ ~spe~t'i°n ~p0rt~s a~tached. i departed Deadhorse at 10:00 am via Alaska Airlines, Flt. #54 arriving in Amchorage at 11:40 am and at my home at 12:10 pm. In summary, i witnessed successful BOPE tests on ARCO's DS 17-11. Attachment O&G ~f4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator ~~ Well /7 Location: Sec ~_ T/o~R/~M ~/z~ Representative ~u~. ~-~~ Permit # ~/. ~ ~, /J~asing Set ~ ~m~p ft. Drilling Contractor ~~~ Location, General ~ Well SignOt~_ General Housekeeping ~_.Rig ~__ Reserve Pit .~?__ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Rig # ~&' Representative~f-f~~ ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full ~harge Pressure Attained: Controls: Master Remote ~ Blinds switch cover ~ Kelly and Floor Safety Valves Test Pressure Upper Kelly ~o0 Lower Kelly ,~-~ Ball Type ~'"~0~ Inside BOP ~"~~ Choke ManifOld ~-~ ~ No. Valves ~-~~ No. flanges Test Results: Failures Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: ~-~_~-~ ~-~~ psig 3 p s i g. m in_5-O sec. rain -- sec. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Adjustable Chokes / Hydrauically operated choke / Test Time ~" hrs. & days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc. Post Office B'C--x~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 24, 1985 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 17-11 Dear Mr. Chatterton' Enclosed is a sundry notice for the subject well. any questions, please call S. L. Massey at 263-4964. Sincerely, Gruber Associate Engineer JG/tw GRU3/L71 Enclosure If you have RECEIVED alaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA~'CTIL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well SHL: 1029' FWL, 2710' FNL, Sec.22, TION, R15E, UM BHL: 316' FWL, 2662' FSL, Sec.15, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 84-244 8. APl Number 50-- 029-21259 9. Unit or Lease Name Prudh~ B~y Iln~ 10. Well Number 17-11 11. Field and Pool Prudhoe Bay Field Pruhdoe Bay Oil Pool RKB 71', Pad 36.4' ADL 28331 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon ~,[] Stim u lation Repair Well [] Change Plans ~/ Repairs Made Pull Tubing [] Other ,J~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 12. SUBSEQUENT REPORT OF: (Submit ir~ 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). ARCO Alaska, Inc., will spud the DS 17-11 well around February 10, 1985. After reaching a surface casing point of 2500'TVD, a surface string of 13-3/8", 72.0#, L-80, BTC will be run with the top two (2) joints beinc 13-3/8", 68.0#, K-55, BTC. After casing is set and cemented, ARCO will weld on a 13-5/8", 5000# casing head. BOPs will be nippled up and tested then drilling will be resumed. Also, please be aware that ARCO will drill the 17-12 well prior to drilling 17-11. These wells will not cross each other but there could be a close proximity of 40' at a depth of 1209'TVD. We do not anticipate any problems with this proximity. RECEIVED JAN 2 4 igC5 A/aska Oil & Gas Cons. Commissi, Anchorage 14. I hereby certify that the forej~ng is true and correct to the best of my knowledge. Signed Z · -~!~-_ .- -- __~ Title Area Dril ling Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by SIGNED LOHHIE C, SMITtl (SLH) $Ni0i5 ~®turned By Order of COMMISSIONER the Commission Date /- Submit "1 ntentions" in Triplicate Form 10-403 Rev. 7-1 ~80 and "Subsequent Reports" in Duplicate December 28, 1984 Mr. T. L. Fithian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Amchorage, Alaska 995].0-036 Re: Prudhoe Bay Unit DS 17-11 ARCO Alaska, Inc. Permit No. 84-244 Sur. Loc. 1029'FWL, 2710'FNL, Sec. 22, T10N, R15E, UM. Btmhole Loc. 316'FWL, 2662'FSL, Sec. 15, T10N, R15E, Dear Mr. Fithian: 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 mud 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 submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the.spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by 'the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be Contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to com~encing installation of the blowout prevention Mr. T. L. Fithian .... Prudhoe Bay Unit DS 17-11 -2- 'D~cember 28, 1984 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 b~fore 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. Verw_.[ruly yp~rs, ~ C. V. Ch~ttert°n Chai~an o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION be EnClosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse.~vation w/o enc!. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B(~:.~-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 19, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 17-11, Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill DS 17-11, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on January 9, 1985. If you have any questions, please call me at 263-4610. Sincerely,/\ T. L. Fithian Area Dril 1 ing Engineer TLF/SLM/tw PD/L12 Enclosures RECEIVED DEC 2 l Lel Alaska. Oil & Gas Cons. Cmmmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA O"rE AND GAS CONSERVATION CO'i-~ISSION PERMIT TO DRILL lb. Type of well EXPLORATORY [] SERVICE [] STRA, TIGR DEVELOPMENT OIL [~X SINGLE ZO~t~E E~X DEVELOPMENT GAS [] MULTIPLE la. Type of work. 2. Name of operator ARCO Alaska, Inc. DRILL REDRILL DEEPEN 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1029' FWL, 2710' FNL, Sec.22, T10N, R15E, UH At top of proposed producing interval 350' FWL, 2400' FSL, Sec.15, T10N, R15E, UH ¢ Target At total depth 316' FWL, 2662' FSL, Sec.15, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 71', PAD 36.4' ADL 28331 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number 17-11 11. Field and pool Prudhoe Bay Field Prudhoe Bay Oil Pool , ~bF~ Amount $500,000 ~M'r'- 15. Distance to nearest drillir~Jr completed 13. Distance and direction from nearest town 30 mi. E of Deadhorse miles 16. Proposed depth (MD & TVD) 11560' MD, 9198' TVD feet 19. If deviated (see 20 AAC 25.050) 14. Distance to nearest property or lease line 316' ~ TD feet 17. Number of acres in lease 2560 17-8 well 22" ~jr7~52' TVD 18. Approximate spud date O1/09~85 2605 psig@ 80°F Surface feet KICK OFF POINT 21 SIZE Hole i30" ,17-1/2" lil 2-1/4" 8-1/2" Casing 20" 13-3/8" 9-5/8" 20. Anticipated pressures' 3500 feet. MAXIMUM HOLE ANGLE 49 Ol (see 20 AAC 25.035 (c) (2) Weight 3700 psig@ 9198 ft. TD (TVD) Proposed Casing, Liner and Cementing Program 91.5# 72. O# 47.0# L-80 29.0# L-80 7" 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld L-80 BTC BTC BTC Length SETTING DEPTH QUANTITY QF CEMENT MD TOP TVD 80' 32'1 32' 2468' 32'l 32' 0813' 30' 30'~ 10543'I 1017' 8535' M D BOTTOM TV D 112' 112' 2500'I 2500' 10843'I 8732' 11560' I 9198' I I (include stage data) 2000# Pol eset 2300sxCS 111&4OOsxCS II 500 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to directionally drill this Sadlerochit development well to 9198'MD (11,560'TVD). A 20", 2000 psi annular diverter will be installed and operationally tested prior to spud. The 13-5/8", 5000 psi RSRRA BOP stack will be installed and tested (rams 5000 psi, annular 3000 psi) upon installation, weekly and operationally tested each trip. After reaching TD, logs will be run across selected intervals. The well will be completed using a workover rig at a later date. A string of 5-1/2", 17#, L-80 tubing and packer will be run and set above the Sad]erochit. A downho]e safety valve will be installed and tested upon completion of the job. Non-freezing fluids will be left in all uncemented annuli within the permafrost interval. Selected intervals will be perforated in the Sadlerochit fromation and reported on subsequent reports. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process. DS 17-11 will also be 79' away from DS 17-10 at 3294'TVD. 23. I hereby certify that the fo~oing is true and correct to the best of my knowledge SIGNED I____,~_. ~ TITLE Area Drilling Engineer The space below for Commission use DATE Samples required [~YES J~NO Permit number APPROVED BY Form 10-401 PD/PD12 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number I--] YES ~LXIO [~-Y E S I--INO I 50-- O Z¢/ Approval date _ .t /'/~"~ ~ ,COMMISSIONER DATE ~'~__~ by order of the Commission SEE COVER LETTER FOR OTHER REQUIREMENTS December 28. lgga Submit in triplicate DS 17 11 1000 2000 3OOO 4000 5000 6000 70OO K- 8OOO 9000 10000 11000 1000 2000 3000 4000 5000 6000 7000 0 1000 2000 3O0O 4000 5000 6000 7000 8OOO 9000 10000 11000 i i i i i i I I I ~o/I CASING' ' ' ' ' TVI:' ' i1 112' ' ' i i i i i i i i i i i i i i i i i i i i i I ! I I ' ' ' ' i , 1 . AFIOO AI.J[$KA, IN0. 8GALE 111~ -1000 FT. SI-I- 1029' ?v& ~ 2710' Fh% o£ Sec. 13o3/8' CASING TVD -= 2600 T10N, RiSE,bM I ,n 'rz-E.- 2400' FSL & 350' Fi, fL. of I Sec. 15, T10N, RISE, + (OP TVD - 860{ 7.5 ~2.5 4-7.5 EO¢ TVD -- 6240 MI) -- 5478 DEP -- 01 N 7 BEG 84 MIN W ~1-~ F" (TO TARGET) A VERAi IE AN~LE 4~ DEG !i MIN '- 0 TVO i7321 M) i8674 OEP-- t:229 K. 6 ~vo=.111 M, =.sss bE.= ~lS, · LCU TVD =8681 MD 610~64 DEP=4STM g'6/RACA$1NG§ 5 TVD =87-92 MD610!4-9 DEp64"76 RIVER 'rvn-S742 MD--1036S DEP-48SS SHUBLIK TV 3 -- 8770 MD -- 1 lob1 DEP == 492( a i-bP &^DLSROC, HiT -¥D--88,i, 6 Mgm' iiOi8 g~F-P--50Du - TARG "T TVD = 6071 k D ' 11210 DEP" O/W CONT ACT TVD 1 9101 MD "' 11410 DEP i 5307 TD TVO=Olgrl MD=11660 DI,P =5419 Aiasl(a 0il & Gas Cons. t ommissior-, Anchorage , , , , ! , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 0 1000 :2.000 3000 't000 5000 6000 7000 VERTICFtL SECTION W DS 17-11 -5000 -4000 -3000 -2000 - 1000 0 1000 2000 I I I ..... ' I ..... I ! I I I I I i .... , , , I I I I I I i I I I I I I I I I I ........ I ......... SHL- 1029' FWL ~ 2710' FNL of ~c.22 T10N, ~- 2400' FSL ~ 350' ~ of ~c. 15, T10N, R15E, Target' ~7 [ 7- 1 1 . ~= 8971' ~= 11,210 ' DEP= 5155' ~73 o [las~ Oil & Gas Cons. Commissi~ o . And orage , , , i , i , , , , , f , i , i [ , , i , , , , i , , -5000 -~000 -3000 -2000 -1000 0 1000 2000 - H COOROIN T S CD Z SCALE 1 IN. - 1000 FT. - IA COOROINRTE5 ARCO ALASKA, INC. 0 0 I z Ill OEO SCALE 1 IN. --- 1000 FT. E - N COORDINFITES ARCO ALASKA, INC. DS 17-11 -5000 -4000 -3000 -2000 - 1000 0 1000 2000 , , , , , i i i i , i i I I I I I I I I I I I I I I I I I [ I ' ' ' i i i i ! i I i i i i I I I I I I I I i , , , , , ! i , I I 17-11 1 - B 17-7 0530 / OS 17-8 S~o~ f 8849 [702~ O~ RECEIVED DE 0 ~ I 1~ ~las~a Oil & 6as 6o~s. Anchorage ' ................................. ~ _'~ '.'~ ~ .................... -5000 -4000 -3000 -2000 - [~)ol 7- i E - ~ COOROINFITES 0 1000 2000 ~0 1/2 DEG ~-~ DS 17-11 E - N COOROINgTF. S ARCO ALASKA, INC. o -~00 -300 -200 - 100 0 lO0 200 300 0 CD 0 w ~- o I z I I I I I I I I I I I I I t I I I I I I I I I I I I I I OS 17-~ 4312 4229 OS 17-11 52'0 518~055 _ /~ 3395 ~d819~895 ~45c8 RECEiV ~ Oil ~ ~s ~ons. ~ommission 4'. ;77 Anchorage i i i ~ i i i i i i i i i i i t i i i i i i i i -400 -~00 -200 - i O0 0 lO0 200 ~ - N COORDINATES 0 0 O3 0 C3 0 p,,. g CD C) 0 0 0 DS 17-11 ~ - H OOOROINflI~S ARCO ALASKA, INC._ -300 -200 -100 0 ' 100 200 300 ~00 · I I / I '1 I I ! I I I I I I I . t711'~ OS 17-11 ,~o~7 · 5240 X5120 t8553 I50'~8 /6366 ~9~3 6177 4895t 5988 ~481 4 ~F95 ; Ec AI~~ Oi~ & G~s Cons. GommiCmn Anchorage I I I I I I I I I I I I I I I I I I I I I I I I -300 -200 - 1 O0 0 1 O0 200 300 ~00 co r,1 (]~ Z I DS 17-11 -~00 -300 30 1/2 DEG ",~,-./ SCALE I IN.--100 FT. ~~ -200 -100 0 100 200 300 I I I I I I I I I I I I I I I I I I I I I I I I I I I I OS 17-il 5189 120 5048 4973 731 ;77 3996 R,ECE!VE[ u EEC2 Alaska Oil i& Gas Cons. Co~ ~mission Anchorage __ I I I I I I I I I I [ I I I I I I I I I I I I I I I I --~00 -300 -200 - 1 O0 0 1 O0 200 300 - N COOROINRTES 0 0 0 0 CZ) 0 ~-, z I,,--.-I Q:::2 o Oo 0"-' © Z o o C~ DS 17-11 ARco ALASKA. INC, .. -z~O0 -300 -200 -100 0 100 -200 - 300 -300 -200 - i O0 0 l O0 200 300 - N COOROINRTES 0 ~ -~00 I I I I I I I I I I I I ~' I ! I I I I I I I I I I I ! I - i ' ~ - IlS 17-11 . ~4-973 73~ V~329~ 3996 71 8~9 RECElX!ED ]/ OSha?J-tO Ala~a Oil & Gas ~r ;. ~mmisslon Anchorag ' ' ' ' I .... I .... I ................ ~NULP~ . PRE'VENTOR PXPE SLINO ~ SPOOL 15-~/8" ~P STACK DIAGRAM A~cu~ulator Capacity Test Ch~ck and fill acct~ulator reservoir to level ~th ~lic ~d. ~s~e ~t ac~lator pressure is ~000 psi with 1500 psi ~t~ of t~ re~lator. Obse~e t~, t~n close all ~ts ~ r~or~ t~ t~ ~ pressure re~g after all ~:s a~ clos~ wi~ ~rg~g ~ off. ~o~ on ~ re~. ~e acceptable lower is 45 seco~ clos~g t~ ~d 1200 psi re~i~g press~. 13-5/8" ~P Sta~ Test Fill ~P s~a~ ~ ~fold with a ~-~r~z~g ~eck t~t all ~ld ~ screws are ~lly retracted. ~rk ~g joint with p~te~ plug seat~g ~pth. ~ test plug on drill pi~ ~ seat ~ wel~e~. ~ ~ lock d~ s~ws. 3. Close ~ar p~venter ~ ~stre~ valves. ~. F~io~lly test c~kes. · 5. -In ea~ of t~ ~o11~ tes~, first hold a 250 psi 1~ press~e test for a ~ of 3 ~tes, then test at t~ ~ 6. I~e press~ to 3000 psi ~ ~ld for a ~ of 3 ~es. BI~ ~ess~ to ze~. 7. ~n ~ar preventer ~ close top set of pipe r~. I~e~e pres~e to 5000 Psi ~ hold for le~t ~ ~tes. BI~ pres~e to zero. 8. ~ose valves directly ~st~ of ~okes ~ ~o~a. Inhere ~ess~ to 5000 psi ~ hold for at le~t 5 ~tes. BI~ press~e to 9. ~n top set of pi~ ~ t~n close ~tt~ set of pi~ r~. Inhere p~s~e to 5000 psi below the ~tt~ set of pipe r~ ~ hold for at le~t 3 m~- utes · 10. Test re~ ~tested ~fold valves (if with 5000 psi ~stre~ of valve ~ zero press~e 11. Bled pres~e to zero. ~n ~t~ set of r~. 12. ~ off ~g jolt ~ p~l o~ of hole. Close blind r~ ~ test to 5000 psi for at le~t ~tes. 13. Bled pressure off all e~nt. ~n bl~ r~. ~e s~e ~fold ~d l~s ~e ~1 of non- fr~z~g li~d ~ all v~ves are set ~ ~ill~g 14. Test st~pi~ valves to 5000 psi. 15. Test ~lly c~ ~ ~i~ ~P to 5000 ps{ with 16. ~k ~r~tion of ~g~ser. 17. ~cord test i~o~tion ~ blo~ut preventer test fo~. Si~ ~ se~ to Drill~g S~e~isor. 18. Per{o~ c~lete ~PE test once a week ~ ~c- tio~lly o~rate ~ ~ily. l, 1. RECEIVED DEC2 Alaska Oil & Gas Cons. Commission Anchorage "'" 4 Revised -- 1,-1/8 SURFACE HOLE D ~VERTER ARCO ALASKA SYSTEM INC. SCHEMAT ~C ~ IO" HYD. (3PR. BALL VALVE ../'~......---V~LL BORE ISEE DETAIL) / /~.~.---IO" HYD. OPR. BALL,VAL,,VE / //' I ALL 90' ,9'URNS ARE 'TEE .~,~ ~ I cus.~o. I _l --w RESERVE PIT AREA NOTE: FLO~ INE DR ILL lNG RISER F L 20" 2000 PSI ~P ANNULAR PREVENTOR i --,.~ ~ IO" HYDRAULIC _ ~~,,~.~.,.,~ ~'- OPERATED BALL VALVES ~ IO" DIVERTER LIN Valves on diverter lines open automati- cally when the annular oreventer is closed. 20" CONDUCTOR PIPE "DETAIL" 2026010203 AS-BUILT LOCATIONS j~.- Vl~ II,,lrl'X' HAP %" ~. 4-~;~=:~I .. _ ,- I HEREBY cERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED T.O PRACTICE LAND su,vEy~,~ ~, T., ST^T.~ O, '~,S~ ~,~ TH^T. TH~S ~^T REPRESENTS AN AS-BUILT SURVEY' MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER O~AILS ~.~ co...~T, ~s OF: ~/~/~ 1 oF . .,,, D.S. 17 - CONDUCTORS 7 THRU 11 X = ~09,175.53 · LAT = 70 12'27.701" LONG = 148°18'47.912'I 10. STATE PLANE LAT & LONG ~...~ Y = 5,928,051.78 x ~o~,~s~.s7 :~'~ ...... LAT 7O ),2 '24.248" LONG 148" 18' 45. 755" q ~,?,-.~$m~t ~.,,.~ 7. Y = 5,928,400.63 CELLAR BOX ELEV = 36.5' 8. Y = 5,928,284.55 X = ~09,203.60 LAT 70 12'26.552" LONG = 148°18'47.191'" CELLAR BOX ELEV = 36.5' 9. Y = 5,928,167.69 X = ~09,231.69 LAT 70 12'25. 395" .LONG = 148°18'46.471'' CELLAR BOX ELEV = 37.0' CELLAR BOX ELEV =. 37.1' 1]. Y = 5,927,935.32 x = ]o9,287,76 LAT = 70"12'23.095" ' LONG = 148°]8'45.03TM CELLAR BOX ELEV = 36.9' CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc {'2 thru 8) . me 3. 4. 5. 6. 7. (3) Admin ~ ~ ,Z ~' %>z'''~'~ 9. (~ thru 12) 10. (10 and 12) '~ 12. (13 thru 21)~ (22 thru' 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Company Lease & Well No. YES NO Is the permit fee attached ........................................ .~l~_~ / Is well to be located in a defined pool .......................... Is well located proper distance from property lin~ .i ...... ~<~??~_~ Is well located proper distance from other wells ................... <'7__ Is sufficient undedicated acreage available in this pool ..... './{ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party .................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed eeeeeeleeeeeeee~eeeeeeeeeeeeeeeeeee®e~ ,(~ ,. Is administrative approval needed .................................... Is the lease number appropriate ..................................... ..... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... .#~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ...' ................ Will surface casing protect fresh water zones ...... [1 ..... 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 wellbore separation proposed ............................ REMARKS Is a diverter system required ...... ' ................................ Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ Geology: ~ Engineering: WVA --- JKT~.-~ HJH ~ INITIAL GEO. UNIT ON/OFF rev: 10/29/84 6. CKLT POOL CLASS STATUS NO. SHORE mm 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 APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ..... S'CH~U~SERG~R ........ ~ VP glo HOZ V2RIF.~,.,~,T~.~N LiS'T~NG ~AGc i:-q,: iNFOR:.I,.,q,.TiON R'ECJRDS .... "-' ,1N" M CONTi£NTS 4N :M "ONT :NTS ONiT .JNZT TYPE OOO 000 OOC, 000 000 000 C ,~T c ,,~, OOO GOO CATE 000 005 0-J 3 007 C33 SI :E 0 O 1 CODE 0 ."-' 5 0 6 5 0 6,5 O .~ 5 ALASKA g,IV'ISIGN CJMPU'T.iNG C~=ZNT!E,~ : ,~ELL = 17-1i COUNTY = N.SLDP~ ST ~'T ~ = AL~:SK ,SECTION = :' ~ ~N~MFP = i0N :~ A N G ~Z = .I: .5 E TAPE D'ENSITY = 800 !~!PI jO6 ~ 70i?~8 LOG: DI~ , ~U'N :~ Z DATE LOG~E3 7 MAR 35 50TT3M L3G INTeRVaL TOP LC'~ iNTSRV,~L ,51 T S I Z Fj TYPE ~OL~ FLUID .V? OlD.HO~ .... V~"~Z~=ir~TZ~'''~,~ LZS'TI~%G P~S,E 3 2ENS ITY : 10. OO VISCSSIT¥ : 35.90 oH '= 9. O0 Fhhli3 LOSS = 2.i~O RM .~ M~S~. TE~qP. = 2.~30 RMF ~ M.E,~S. TEMP. = I. RMC ,~ ME&S. TEMP. : 3.230 LOP: T MALS'TEAO ;::~ DAT~ FaRM~T R~EC.SRO ~ :NTR ~' i~LgC ~,S )ATUM SPeCIFICATiON ~NiM SERVICE S:ERVZCE ~R 31L ~ R ~ DT )R,~G LOT ~R~T ~CT ~C~L :CNL LDT SR USS ST LSS 3TU ~S S TY~E SiZE ,qEPR CDDiE Z6 1 6,6 O i .65 5LOCXS iNiT APZ APl AP1 L3G TYPF~ CLASS FT ~0 OOO O0 OHMM O0 ~20 Ot 3~;4M O0 120 %o ~3H~M O0 120 44 MV gC glo 01 GAP~ 30 310 O! IN O0 28g O1 G/C.5 O0 35 '3 02 · G/C3 OO 356 O1 OO ~iO Oi O0 000 O0 PU OC ~90 O0 0 g 35~ Ol CPS O0 330 30 JAPI O0 310 US/F ~ 520 80 JS/F 30 ~ZO dO ENTRY O 1 O RzPR ~8 68 6.6 58 ~6 ~8 PROCESS (OCTAL) 0000000000000~ O000000000000O aOOOOOOOOOOOOJ ODO000000OO00O OOOOO000OO000J OOOgOOOOOgO00g O000000000000J OOOOOO0000000~ OOOOOOO000000~ O00OO00000000~ OgO00000000OO2 OOOO000000000~ OOOOO00000OO00 O00000000000OO 00000000000003 O0000OO0000000 OOO0000000000J 00000000000000 02000000000000 .V~ Oi,~.HO~ ¥~RI~iCATISN ~ISTING P~.'3~ 4 3A?I 0 0 ~i ~ )t 0 g 52 i. 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