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187-010
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS WELL COMPLETION OR RECOMPLETION REPO AND LOG 1a. Well Status: Oil 0 Gas ❑ SPLUG 0 Other 0 Abandoned 0 • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 8/8/2016 187-010 ' 316-006 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 1/30/1987 50-029-21694-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/24/1987 PBU L5-12% Surface: 1668'FSL,15'FWL,Sec.01,T11N,R15E,UM • 9 Ref Elevations KB 60 ' 17. Field/Pool(s): Top of Productive Interval: 1427'FNL,3930'FWL,Sec.12,T11N,R15E,UM GL 21.75 ' BF 22.25 . PRUDHOE BAY,LISBURNE OIL* Total Depth: 1580'FNL,4072'FWL,Sec.12,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 8944'/7223' • ADL 028320 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 717446- y- 5974800 - Zone - ASP 4 - • 11242'/9267' - 84-62 TPI: x- 721451 y- 5971822 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 721598 y- 5971673 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary DIL/Spectralog,Z-Den/CN/GR/Cal,Acoustilog/WF/GR,FMT/GR,Temp/Diff.Temp/GR/BHP,CBL,Gyro,CCL SCANNED [EE 7 2017, 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT, PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-4o 42' 121' 42' 121' 30" 1860#Poleset 13-3/8" 72# K-55/L-e0 41' 4208' 41' 4001' 17-1/2" 2450 sx AS III,600 sx Class'G',115 sx AS I 9-5/8" 47# L-80 38' 10646' 38' 8709' 12-1/4" 585 sx Class'G',300 sx AS I 7" 29# L-80 10425' 11242' 8505' 9267' 8-1/2" 332 sx Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 2-7/8"6.5#L-80 9057'-10723' 10368'/8452' 10706'/8765' y_ h gri p42,44,o dN � 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. $ e t.,47'Let. °. .lime r, _. Was hydraulic fracturing used during completion? Yes 0 No 0 • i }„);:: Per 20 AFC 25.283(i)(2)attach electronic and printed A U G 3 1 1 2'1 15 information 10 (Ll, ( ti;r; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AOG CC L-lr See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �► • Flow Tubing Casing Press: Calculated Oil-Bbl: • Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate "'Oil' Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only i/'TL ft o / - / 14, RBDMS /-L- SEP - 1 2016 ,00e/o4% -.\ /c.,i/./, \76 • 28. CORE DATA • Conventional Core(s) Yes 0 No 0 ' Sidewall Cores Yes 0 No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encoun tered ) 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No El • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10644' 8707 separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Wahoo Zone 6 10644' 8707' Wahoo Zone 5 10717' 8775' Wahoo Zone 4 10818' 8870' Wahoo Zone 3 11018' 9057' Wahoo Zone 2 11084' 9119' Wahoo Zone 1 11135' 9167' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sperry,Nathan Email: Nathan.Sperry@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: 1` V Phone: +1 907 564 4091 Date: f.f3o/, 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 la Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 MC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 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 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only WELL NAME: L5-12 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 10325' Set CIBP 9262' Set Cement Retainer -9282' 64.9 Bbls Class 'G' 9057' Cut and Pull Tubing 8969' Set EZSV 8944' Set Whipstock • • L5-12 Well History (Pre-Rig Sidetrack) CTIVITYD u SUM. T/I/O = SSV/0/0, Temp: SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre RWO PPPOT-T: Stung into test void, (0+ psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 350 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (0+ psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 350 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 50 psi in 15 4/29/2016 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. ***WELL S/I UPON ARRIVAL*** (new well post) 5/7/2016 R/U SWCP 4516 SLICKLINE UNIT RAN FLAPPER CHECK DOWN TO TRSSSV @ 2,205' MD (open). SET 2 7/8" SS CATCHER @ 2,463' SLM. PULLED BK-DGLV FROM STA#1 @2,296' MD (purged line w/ diesel). SET BK-DGLV IN STA 1 CHEM INJECTION MANDREL.PULLED EMPTY SLIP STOP CATCHER. TAGGED RESTRICTION W/2.25" CENTRAILIZER 1.75" LIB @ 10354' SLM.(lib had small marks on side, cent probably nogo'd). CALIPER TUBING FROM 10354' SLM TO 9000' SLM. good data. BRUSH AND FLUSH TUBING TO 10354' SLM W/ CRUDE.=LRS FLUSHED TUBING WITH AN ADDITIONAL 92 BBL OF CRUDE. RAN 2.25" CENT, 2.25" LIB TO RESTRICTION @ 10,354' SLM (imprssion of possible collapsed 5/8/2016 tubing) T/I/O=2170/50/vac Temp=SI Assist Slickline (PRE RWO) MIT-T to 2500 psi Pumped 1 bbl of meth followed by 63 bbls of 90*F crude down Tbg to assist Slickline with brush. Pumped 5/8/2016 93 bbls of 90*F crude down Tbg to flush and load. ***CONT WSR FROM 5/8/16*** (new well post) SET 2 7/8" CIBP @ 10,325'MD (10,305' SLM) LRS PERFORMED PASSING MIT-T TO 2500psi (see log for details) SET 2 7/8" KEYLESS X-CATCHER ON CIBP @ 10,325' MD (10305' SLM). PULLED RK-DGLV FROM STA6 © 10259' MD PULLED EMPTY KEYLESS X-CATCHER SUB. ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** 5/9/2016 **********STA#6 LEFT OPEN POCKET********** ***job continued rom 5/8/2016 Assist SlickLine (Load &Test) MIT-T 2500 psi ***PASSED*** Pumped 5 bbls of ambient diesel to reach a test pressure of 2747 psi. 1st 15 min TBG lost 180 psi. 2nd 15 min TBG lost 60 psi for a total loss of 240 psi in a 30 min test. bled back—.07 bbls diesel. Tags hung on well. SlickLine on well upon departure. FWHP= 5/9/2016 390/127/-2 swab, wing, ssv= SlickLine CTU#6 1.75" HS-110 Job Scope: Cmt Tbg/IA- Pre Rig MIRU CTU. RIH w/2.25" JSN. Confirm with Slickline the CIBP is set at 10275' MD. Tag CIBP at 10324' down / 10321' up. Shift EIM to 10325' (plug depth). Puh and flag pipe at 9210.4'. Pooh. MU & RIH w/WFT 2-7/8" Cement Retainer. Corr Depth © Red Flag to 9210.25' MD - RIH Set Cmt Retainer @ 9262' MD - pumped IA to 1500 psi verify Cmt Retainer is holding - POOH - BD Wfd Setting Tools MHA, ball recovered - MU Wfd MHA w/o 5/10/2016 DHCV- MU Stinger Assembley- MIRU HES Cementers- RIH L5-12 Well History (Pre-Rig Sidetrack) CTU#6 1.75" HS-110 Job Scope: Cmt Tbg/IA- Pre Rig RIH w/WFT Stinger BHA. Sting into Cmt Retainer at 9266' ctm. Verify cement retainer integrity by pressuring up down backside. Batch Cement. Pump 64.9 bbls (Coil Micromotion Count/70 bbls HES Displacement Tank Volume pumped) of 15.8ppg Class G Cement up IA. Micromotion may not be accurate due to heavy cavitating with HES pump during cement pumping. Unsting and lay in 0.5 bbls. Reverse out down to 9240', leaving 20' of cement above cement retainer. Pooh while reverse circulating. TOC in IA— 9282' (Pumped 0.5 bbls above retainer/5.8bbls below retainer/63.7 bbls up IA). Was rough pumping cement, HES had a difficult time keeping pumps prime. FP well w/50/50 Methanol to 2500' tvd. At surface pump Gel sweep & 1.125" drift ball . FP Coil.. Perform Weekly BOP Test. Rig 5/11/2016 Down CTU. ***WELL S/I ON ARRIVAL*** TAGGED TOC @ 9,232' SLM W/2.21" CENT & 1-3/4" SAMPLE BAILER (recovered ltsp cement) 5/14/2016 BRUSHED BPV PROFILE W/ BRUSH FOR 30 MINUTES ***WELL SHUT IN UPON ARRIVAL*** ( SLB ELINE -JET CUTTER) INITIAL T/I/O = 0/374/0 MIRU. PT. RIH W/2.125" CUTTER. CUT TUBING AT9057', CCL TO CUT= 14.46', CCL STOP DEPTH = 9042.54'. LOG CORRELATED TO TUBING TALLY. DATED 06-05-1987. T/I/O =480/380/0 BEFORE CUT, T/I/O = 100/450/0 AFTER CUT POOH. RDMO. FINAL T/I/O = 80/420/0 5/15/2016 ***WELL SHUT IN UPON DEPARTURE*** ***CONT FROM 05/14/16 WSR*** PERFORMED PASSING MIT-T TO 3500psi PERFORMED PASSING MIT-IA TO 3500psi 5/15/2016 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/I/0=23/286/0 (SIDE TRACK) CMIT-TxIA to 3500 psi ***PASSED*** MIT-OA to 1200 psi ***IN PROGRESS*** Pumped 11.9 bbls of 50/50 meth to achieve test pressure. 1st 15 min TBGxIA lost 32/31 psi. 2nd 15 min TBGxIA lost 16/16 psi. Bled back 11 bbls. Pumped 4 bbls 50/50 meth followed with 604 bbls Inhibited 1% KCL and 180 bbls diesel down IA taking returns up TBG out FL, U tubed for 1 hour to put FP in place, Pumped 10 bbls diesel up FL for FP, MIT-OA- Pumped 1.4 bbls diesel down OA to reach test pressure, OA lost 76 psi in 5/17/2016 1st 15 min and 47 psi in 2nd 15 min fora total loss of 123 psi in 30 min test ***WSR Continued from 05-17-16*** Temp= S/I MIT-OA to 1200 psi ***PASSED*** 5th attempt(SIDETRACK) Pumped .6 bbls diesel down OA to reach test pressure, OA lost 20 psi in 1st 15 min and 19 psi in 2nd 15 min for a total loss of 39 psi in 30 min test, Bleed OAP, Bleed back —1.5 bbls, AFE sign and tags hung on well, Valve position @ departure-WV, SV, 5/18/2016 SSV= Closed MV= Open IA& OA= OTG, FWHP= 0/0/0 ***WELL S/I ON ARRIVAL*** (Pre Rig) TAGGED TRSV @ 2,205' MD W/2.35" GAUGE RING SET HOLD OPEN SLEEVE IN TRSV @ 2.205' MD 5/20/2016 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED** T/I/O = 20/VACNAC. Temp = SI. WHPs (pre RIG). No AL. 6/27/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 13:00 T/I/O = 20NACNAC. Temp = SI. T& IA FL (TRP request). No AL. Wellhouse, flowline, and grating disconnected. T& IA FL near surface. 7/15/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 16:00. T/I/O= 22/-11/-12. Installed IA Temp#43 OA Temp#95 . Piggyback GV. Torqued and PT'd 7/15/2016 to API specs. (PASS). RDMO. ***Job Incomplete*** FWHP=27/27/-12. I L5-12 Well History (Pre-Rig Sidetrack) T/I/0=300/300/0 Set 2 9/16" FMC IS-A BPV#503. N/D upper tree, N/U dryhole tree Temp #34 Pre Parker 272. FWP's BPV/0/0. Removed WH handrails on WH #08 and removed WH 7/16/2016 ladder on WH #16. see log for details. T/I/O = BPV/8/0. Temp = SI. WHPs (pre RIG). No flowline or AL. No SSV or WV installed. BPV installed in hole. 7/18/2016 SV, = C. MV= 0. IA, OA= OTG. 03:30 T/I/O=BPV/0/0 Installed 2 9/16" Temp. ASV#09. Pulled FMC IS-A BPV#503 through tree. 7/22/2016 FWP's 0/0/0 see log for details T/I/0= 0/0/0. RD ASV#09. Installed tree cap assembly, PT'd (Passed). RDMO. Final T/I/0= 7/28/2016 0/0/0. ***Job Incomplete**". See log for details. T/I/0 = 0/0/0 RU lubricator. Set 2 9/16 FMC ISA BPV#503. LLT (PASSED). FWP = 7/29/2016 BPV/0/0. ***JOB COMPLETE***see log for details. T/I/0 = BPV/O+Nac. Temp = SI. WHP's. (Pre-Rig). Well house, flow line, SSV&WH Scaffold removed. No access to tree cap for TP. IA& OA have double casing valves installed. 7/31/2016 SV, WV= C. MV= 0. IA, OA= OTG. 20:45 111) I North America-ALASKA-BP Page 1 CO— Operation —Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:LisburneII Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)©67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase i Description of Operations I (hr) (usft) 7/29/2016 12:00 - 19:00 7.00 MOB P PRE BEGIN RON EVENT AT 12:00 WITH PARKER RIG 272 i GENERAL RIG DOWN OPERATIONS ON i DS02-14A 1-SECURE TOP DRIVE AND BRIDLE UP , I -PERFORM DERRICK INSPECTION ' -RIG DOWN RIG FLOOR AND SECURE FORUM CRANE i -LOWER PIPE SKATE -MAINTENANCE AROUND RIG: MUD PUMP #1,CHANGEOUT ANNULAR PREVENTER ELEMENT,CHANGEOUT ST-80 HEAD 19:00 - 20:00 1.00 MOB P PRE SKID CATTLE CHUTE AND RIG FLOOR INTO _ `RIG MOVE POSITION 20:00 - 20:30 0.50 MOB P PRE LOWER MAST -380 KLBS HOOKLOAD PRIOR TO LANDING ON STAND 20:30 - 21:30 1.00 MOB P I PRE DISCONNECT ELECTRICAL INTERCONNECTS. MAKE FINAL PREPARATIONS FOR MOVING RIG. 21:30 - 22:30 1.00 MOB P PRE PULL OFF DS02-14 WITH MUD MOUDLE, 1 UTILITY MODULE AND DRILL MODULE. STAGE MODULES ON DRILLSITE 22:30 - 00:00 1.50 MOB N WAIT ' -1.75 PRE WAIT FOR RIG MATS TO BE LAID ON DRILLSITE 2 ACCESS ROAD. -MODULES LINED UP ON DS02 7/30/2016 00:00 - 01:00 1.00 MOB N WAIT -1.75 PRE WAIT FOR RIG MATS TO BE LAID ON DRILLSITE 2 ACCESS ROAD. 1 -MODULES LINED UP ON DS02 01:00 - 04:00 3.00 MOB P PRE MOVE RIG FROM DRILLSITE 2 TO MCC STAGING AREA 04:00 - 12:00 8.00 MOB N WAIT -1.75 PRE WAITING ON EAST DOCK ROAD RIG MAT I PLACEMENT DUE TO POOR SUMMER ROAD ii CONDITIONS: -WAITING AT MCC STAGING AREA#1 UNTIL j NORDIC FINISHES WELL ON D PAD AND MOVES TO MCC STAGING AREA#1 FOR JOINT RIG MOVE. j-SPOT RIG ON MCC STAGING AREA. MAKEUP UTILITY MOD AND MUD MOD TO !DRILL MODULE. SHIM TO LEVEL MODULES ON SOFT GRAVEL PAD -CHANGE UPPER RAMS TO 7"FIXED. CHANGE LOWER RAMS TO 2-7/8"X 5"VBRS. CHANGE PUMP LINERS TO 5-3/4". -GENERAL RIG MAINTENANCE AND HOUSEKEEPING Printed 8/22/2016 11:01:21AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 2 Cps Operation - Operation Summary Report Common Wet Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisbume Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 MOB N WAIT -1.75 PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: WAITING AT MCC STAGING AREA#1 UNTIL NORDIC FINISHES WELL ON D PAD AND MOVES TO MCC STAGING AREA#1 FOR JOINT RIG MOVE. -GENERAL RIG MAINTENANCE AND HOUSEKEEPING -CHANGEOUT MUD MODULE BOOSTER TRUNION -COMPLETE WELDING REPAIRS ON MUD PALLET ELEVATOR(WITH APPROVAL OF MCC AREA AUTHORITY) 7/31/2016 00:00 - 12:00 12.00 MOB N WAIT -1.75 PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT MCC STAGING AREA#1 UNTIL NORDIC FINISHES WELL ON D PAD AND MOVES TO MCC STAGING AREA#1 FOR i JOINT RIG MOVE. -GENERAL RIG MAINTENANCE AND HOUSEKEEPING INSTALL NEW FIRE-RATED QUICK-CONNECTS ON BOP STACK FITTINGS NOTES FOR RIG MOVE TO L5: PRE-CUT DUNNAGE IS STAGED ALONG THE L5 ROAD,READILY AVAILABLE SHOULD P272 OR NORDIC 2 PUNCH THROUGH A RIG MAT AT SOFT SPOT IN ROAD. -D-10 DOZER IS STAGED AT L5 AS CONTINGENCY IN CASEA MODULE GETS STUCK IN ROAD -PARKER HAS PLACED A SPARE TIRE ON L5 PAD 12:00 - 00:00 12.00 MOB N WAIT -1.75 PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD !CONDITIONS: -WAITING AT MCC STAGING AREA#1 UNTIL NORDIC FINISHES WELL ON D PAD AND MOVES TO MCC STAGING AREA#1 FOR JOINT RIG MOVE. -GENERAL RIG MAINTENANCE AND HOUSEKEEPING Printed 8/22/2016 11.01:21AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 3 Q62_ Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 1X3-017WQ-C:(6,616,817.00) Project:Lisburne Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)©67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 8/1/2016 00:00 - 21:00 21.00 MOB N WAIT -1.75 PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT MCC STAGING AREA UNTIL NORDIC FINISHES WELL ON D PAD AND !MOVES TOWARDS MCC STAGING AREA#1 FOR JOINT RIG MOVE. -01:00: LIFT MODULES,SEPARATE AND I TURN TO PREP FOR MOVE TO STAGING AREA #2 AT G&I. -ABLE TO MOVE MUD MODULE AND LINEUP AT MCC STAGING PAD ENTRANCE. -DRILL MODULE(3.7 MILLION LBS)HAS SUNK INTO SOFT GRAVEL STAGING PAD AFTER 2 DAYS OF WAITING. RIG TEAM SPENDS-12 HOURS GETTING THE DRILL MODULE OUT OF ITS TIRE RUTS AND UP ONTO SOLID MAT SURFACE. -18:45: PLANNED START OF P272 RIG MOVE FROM MCC STAGING PAD TO G&I STAGING AREA-MUD MODULE MOVES FROM STAGING PAD UP ONTO EAST DOCK ROAD. DRILL MODULE DRIVES OFF OF RIG MATS AT SAME LOCATION AS MUD MODULE AND 'SINKS INTO SOFT GRAVEL PAD IMMEDIATELY. DRILL MODULE BECOMES STUCK. -18:45 TO 21:00: ATTEMPT TO EXTRACT DRILL MODULE DURING NON-CRITICAL PATH TIME WHILE NORDIC 2 MOVES FROM D PAD TO MCC STAGING AREA. P272 REQUESTS NORDIC 2 TO MOVE TO PAD 10 AND THEN HOLD UNTIL DRILL MODULE IS EXTRACTED. 21:00 - 00:00 3.00 MOB N SEAL -1.75 PRE EXTRACT STUCK DRILL MODULE FROM MCC STAGING AREA. -MUD MODULE IS SITTING ON EAST DOCK ROAD AND UTILITY MODULE IS SITTING ON RIG MATS ON MCC STAGING PAD -NORDIC 2 RIG IS WAITING AT PAD 10 AND READY TO MOVE TO G&I STAGING AREA#2 AS PART OF JOINT RIG MOVE OUT L5 'ACCESS ROAD. EXTRACTION NOW TAKING PLACE DURING CRITICAL PATH OF RIG MOVE TO L5. -DRILL MODULE UNABLE TO MOVE UP SLIGHT INCLINE FROM MCC STAGING AREA ONTO EAST DOCK ROAD WITHOUT BREAKING THROUGH SOFT GRAVEL PAD. i-CALLOUT(2)PEAK D8 CATERPILLAR DOZERS FOR ASSISTANCE WITH PULLING RIG UP INCLINE AND OUT OF RUTS. -RIG TEAM WORKING ITERATIVE PROCESS OF JACKING UP RIG AND ADDING LAYERS OF CRIBBING TO BUILD SOLID FOUNDATION FOR RIG TIRES TO PUSH ON. -RIG EXTRACTED FROM PRIMARY TIRE RUTS 11 AT MIDNIGHT. NEED TO CLEANUP DUNNAGE, BUILDUP/SMOOTH GRAVEL PAD AND REPLACE DAMAGED RIG MATS BEFORE MOVING DRILL MODULE UP TO EAST DOCK ROAD. EXTRACTION COMPLETED ON 8/2/16. Printed 8/22/2016 11.01:21AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 gt28. Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne I Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)©67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) • (usft) 8/2/2016 00:00 - 02:30 2.50 MOB N SFAL -1.75 PRE EXTRACT STUCK DRILL MODULE FROM MCC STAGING AREA. -MUD MODULE IS SITTING ON EAST DOCK ROAD AND UTILITY MODULE IS SITTING ON RIG MATS ON MCC STAGING PAD -NORDIC 2 RIG IS WAITING AT PAD 10 AND i READY TO MOVE TO G&I STAGING AREA#2 AS PART OF JOINT RIG MOVE OUT L5 j I ACCESS ROAD. -PICKUP DUNNAGE,FILL-IN GRAVEL RUTS, LAY NEW RIG MATS. -WITH NEW SOLID MATTING BOARD SURFACE,ABLE TO MOVE DRILL MODULE UP INCLINE FROM MCC STAGING PAD TO EAST DOCK ROAD WITH ASSISTANCE FROM(2)D8 CATERPILLAR DOZERS. 02:30 - 03:30 1.00 MOB P PRE MOVE UTILITY MODULE UP TO EAST DOCK ROAD FROM MCC STAGING PAD. LINES UP THREE P272 MODULES WITH NORDIC 2 AND PREPARE TO MOVE. 03:30 - 08:00 4.50 MOB P PRE MOVE MUD MODULE,DRILL MODULE AND UTILITY MODULE+NORDIC 2 RIG FROM MCC ON EAST DOCK ROAD TO STAGING AREA#2 AT G&I TURNOFF. -RIG MATS LAID ON ENTIRE ROADWAY FROM PBOC TO G&I TURNOFF. -STAGING AREA IS TO ALLOW FOR RIGS MATS TO BE SHUFFLED FROM PBOC AREA UP TOWARDS EAST DOCK. -2200 RIG MATS RENTED FOR RIG MOVE (ALL AVAILABLE ON SLOPE). 08:00 - 00:00 16.00 MOB N PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT G&I TURNOFF(STAGING AREA #2)WITH NORDIC 2 WHILE RIG MATS ARE PLACED -GENERAL RIG MAINTENANCE AND HOUSEKEEPING 8/3/2016 00:00 - 02:30 2.50 MOB N PRE WAITING ON EAST DOCK ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT G&I TURNOFF(STAGING AREA #2)WITH NORDIC 2 WHILE RIG MATS ARE PLACED -GENERAL RIG MAINTENANCE AND HOUSEKEEPING 02:30 - 04:30 2.00 MOB P PRE MOVE MUD MODULE,DRILL MODULE AND UTILITY MODULE+NORDIC 2 RIG FROM G&I TURNOFF ON EAST DOCK ROAD TO STAGING !AREA#3 AT EAST DOCK. -RIG MATS LAID ON ENTIRE ROADWAY FROM G&I TURNOFF TO EAST DOCK. -STAGING AREA IS TO ALLOW FOR RIGS MATS TO BE SHUFFLED FROM EAST DOCK TO L5. Printed 8/22/2016 11 01.21AM *All depths reported in Drillers Depths* S • North America-ALASKA-BP Page 5 6P311 Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne Site:Lis DS 05 H Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. [UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 00:00 19.50 MOB N PRE WAITING ON L5/NIAKUK ACCESS ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT EAST DOCK(STAGING AREA#3) WITH NORDIC 2 WHILE RIG MATS ARE PLACED -GENERAL RIG MAINTENANCE AND HOUSEKEEPING 8/4/2016 00:00 - 03:00 3.00 MOB N PRE WAITING ON L5/NIAKUK ACCESS ROAD RIG MAT PLACEMENT DUE TO POOR SUMMER ROAD CONDITIONS: -WAITING AT EAST DOCK(STAGING AREA#3) WITH NORDIC 2 WHILE RIG MATS ARE PLACED GENERAL RIG MAINTENANCE AND HOUSEKEEPING 03:00 - 05:30 2.50 MOB P PRE MOVE MUD MODULE,DRILL MODULE AND UTILITY MODULE+NORDIC 2 RIG FROM I EAST DOCK DOWN THE L5/NIAKUK ACCESS RD TO L5 -RIG MATS LAID ON ENTIRE ROADWAY FROM EAST DOCK TO L5. 05:30 - 08:00 2.50 MOB P PRE SPOT DRILL MODULE OVER WELL CENTER. MARRY UP UTILITY MODULE AND MUD MODULE TO DRILL MODULE AND SHIM UP ALL MODULES. 08:00 - 10:00 2.00 RIGU P PRE RIG UP ALL MODULES. HOOK UP INTERCONNECTS AND INSTALL IWALKWAYS AND TRANSITIONS BETWEEN 10:00 11:30 1.50 RIGU P MODULES. - PRE i RAISE MAST AND SKID RIG FLOOR TO DRILL 1 POSITION -MAST OFF RACK AT 540K LBS -RAISE PIPE CAT I-INSTALL ROOFTOP WALKWAYS 11:30 - 15:30 4.00 RIGU P PRE RIG UP RIG FLOOR EQUIPMENT -CONNECT MUD,BLEEDER AND CEMENT LINES -HANG RIG TONGS,INSTALL MOUSE HOLES AND TIGHTEN KELLY HOSE 1-FUNCTION TEST EMERGENCY SHUT DOWN -BRIDAL DOWN AND HANG LINES IN DERRICKAND SECURE 1-PERFORM DERRICK INSPECTION -CALIBRATE BLOCKS 15:30 - 18:00 2.50 RIGU P PRE TAKE ON 8.5 PPG SEAWATER TO PITS AND CALIBRATE SENSORS RIG UP HARD LINE AND VALVES TO FLOW BACK TANK FOR CIRCULATING OUT DIESEL FREEZE PROTECT SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 18:00 - 18:30 0.50 RIGU P PRE 'ACCEPT RIG AT 18:00 HRS AND HOLD PRE SPUD MEETING WITH RIG CREW 18:30 - 19:30 1.00 RIGU P PRE CONTINUE TAKING ON HEATED SEAWATER IN PITS LOAD AND STRAP DRILL PIPE IN PIPE SHED 19:30 - 20:00 0.50 RIGU P PRE RIG EVACUATION DRILLANDAAR. ALL PARTIES EVACUATED RIG AND MUSTER AT THE DESIGNATED POINT.TIME FOR EVACUATION DRILL-5 MIN. Printed 8/22/2016 11:01:21AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 6 itafi Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisbume Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. 'UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ! (usft) 20:00 - 22:00 2.00 DHB P PRE ATTEMPT TO PULL BPV THROUGH TREE RIG UP AND TEST DSM LUBRICATOR, 250/3500 PSI FOR 5 MIN EACH. -ATTEMPT TO ENGAGE AND PULL BPV -UNABLE TO GET RETRIEVAL TOOL DOWN FAR ENOUGH TO ENGAGE BPV -BREAK AT QUICK TEST SUB AND SUCK OUT TREE TO VERIFY NO OBSTRUCTIONS INSTALL LUBRICATOR AND RE-TEST QUICK TEST SUB 250/3500 PSI FOR 5 MIN -ATTEMPT TO ENGAGE AND PULL BPV ONE MORE TIME -PULL LUBRICATOR AND EXAMINE TREE AND LUBRICATOR 22:00 - 00:00 2.00 DHB N SFAL -1.75 PRE DRILL SITE MAINTENANCE REPRESENTATIVES DETERMINED THAT OD ON CROSS-OVER FOR RETRIEVAL TOOL IS SLIGHTLY OVERSIZE AND WON'T GO THROUGH SWAB VALVE.COULD NOT BREAK OFF THE CROSS OVER ON THE LUBRICATOR !ON THE RIG FLOOR. LAY DOWN LUBRICATOR AND WAIT FOR DSM TO MOBILIZE THE SAME LUBRICATOR AND CROSS OVER THAT WAS USED TO SET PLUG 8/5/2016 00:00 - 01:30 1.50 DHB N SFAL -1.75 PRE NIPPLE UP NEW LUBRICATOR ON TREE AND TEST TO 250/32500 PSI FOR 5 MIN EACH ENGAGE BPV WITH RETRIEVAL TOOL AND PULL. -STAND BACK LUBRICATOR AND BPV ON RIG FLOOR. 01:30 - 03:30 2.00 PULL P -1.75 DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT -VERIFY CIRCULATING LINE UP -PRESSURE TEST SURFACE LINES AND EQUIPMENT TO 1700 PSI AND VERIFY LEAK TIGHT. -PUMP 16 BBL DOWN IA,TAKING DIESEL RETURNS FROM TUBING TO FLOW BACK TANK -3 BPM,800 PSI -PUMP 170 BBLS DOWN TUBING,TAKING DIESEL RETURNS FROM IA TO FLOW BACK •TANK -5 BPM,1700 PSI -VERIFY BBL IN/BBL OUT BY STRAPPING FLOW BACK TANK EVERY 20 BBL -SENT DIESEL TO FLOW 1 FOR r HYDROCARBON RECYCLE -SHUT DOWN AND MONITOR WELL FOR 15 MIN;STATIC BLOW DOWN LINES 03:30 - 04:30 1.00 DHB P -1.75 DECOMP 1NIPPLE UP AND TEST DSM LUBRICATOR 250/3500 PSI FOR 5 MIN EACH -INSTALL BPV AND RIG DOWN LUBRICATOR. Printed 8/22/2016 11 01:21AM *All depths reported in Drillers Depths` .-.-......- • North America-ALASKA-BP Page 7 Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)(q167.35usft(above Mean Sea Level) Date From-To Hrs Task ! Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 DHB N F SFAL -1.75 DECOMP ATTEMPT TO PRESSURE TEST BPV FROM BELOW THROUGH IA TO 250/3500 PSI FOR 5 MIN EACH GOOD LOW PRESSURE TEST I-DURING HIGH PRESSURE TEST,BPV FAILED. -SEAWATER OBSERVED MISTING OUT OF LUBRICATOR TEST PORT IN WELL HOUSE CAMERA -BLEED OFF PRESSURE AND ASSESS SITUATION -NOTIFIED 5700 AND WOS,JAY MURPHY,OF SITUATION -2 GAL SEAWATER IN CONTAINMENT AND 0.5 GAL MISTED OVER CELLAR WALLS -CLEAN UP CELLAR AND INITIATED !TRACTION REPORT 2016-IR-5315339 'DSM PULLED BPV WITH LUBRICATOR. INSPECTED BPVAND DETERMINED THAT !THE SEAL FAILED DSM REBUILT BPV ON SITE INSTALLED REBUILT BPV WITH DSM LUBRICATOR 06:00 - 06:30 0.50 DHB P -1.75 DECOMP PRESSURE TEST BPV FROM BELOW THROUGH IA TO 250/3500 PSI FOR 5 MIN EACH -GOOD TEST -BLOW DOWN AND RIG DOWN TEST EQUIPMENT 06:30 - 10:00 3.50 WHSUR P -1.75 DECOMP NIPPLE DOWN TREE AND ADAPTER FLANGE -VERIFY NO PRESSURE ON TUBING AND IA -FMC REPRESENTATIVE BLEED OFF !HANGER VOID i-NIPPLE DOWN TREE AND ADAPTER FLANGE -INSPECT HANGER THREADS AND REPAIR BURR ON THREADS -MAKE UP XO TO HANGER-5 TURNS TO MAKE UP • -INSTALL BLANKING PLUG ON BPV PER FMC REPRESENTATIVE-8 TURNS TO MAKE UP 10:00 - 15:00 5.00 BOPSUR P -1.75 DECOMP NIPPLE UP HIGH PRESSURE RISERS AND BOPE STACK -INSTALL TURNBUCKLES ON STACK •-INSTALL LOW PRESSURE RISER ON TOP OF j BOP STACK -AIR UP AIR BOOTS ON LOW PRESSURE RISER -ENERGIZE ACCUMULATOR AND TAKE RKB !MEASUREMENTS 15:00 - 16:30 1.50 BOPSUR P i -1.75 DECOMP RIG UP TO TEST BOPE -MAKE UP TEST JOINTS -FILL STACKAND LINES WITH WATER 1-PURGE AIR FROM SYSTEM 16:30 - 18:00 1.50 BOPSUR P -1.75 DECOMP PERFORM SHELL TEST 250/3500 PSI FOR 5 MIN EACH -FLANGE LEAKING ON HIGH PRESSURE RISER -RE-TORQUE STUDS ON FLANGE -RETEST-NO LEAKS NOTIFY AOGCC REPRESENTATIVE JEFF JONES OF SUCCESSFUL SHELL TEST Printed 8/22/2016 11:01:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 8 Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne I Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. •UWI:500292169400 Active datum:L5-12A(actual)©67.35usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 18:00 - 19:00 , 1.00 BOPSUR P -1.75 DECOMP SERVICE TOP DRIVE AND RIG EQUIPMENT 'WHILE WAITING FOR AOGCC REPRESENTATIVE TO ARRIVE ON SITE 19:00 - 00:00 5.00 BOPSUR P -1.75 DECOMP TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST WITH 7",4"AND 2-7/8"TEST JOINTS -TESTED ALL ALARMS,PVT AND FLOW SHOW I.-FUNCTIONBOPE FROM BOTH REMOTE PANELS -PERFORM DRAWDOWN TEST -ALL TESTS WITNESSED BY WSL, TOOLPUSHERANDAOGCC REPRESENTATIVE,JEFF JONES 8/6/2016 00:00 - 03:30 3.50 BOPSUR P DECOMP ±CONTINUE TESTING BOPE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -FINISH TEST WITH 4"TEST JOINT CHOKE MANIFOLD VALVE#10 FAILED -REBUILD AND RE-TEST VALVE#10 -BLOW DOWN AND RIG DOWN TEST EQUIPMENT -SEE ATTACHED TEST CHARTS PERFORM H2S/RIG EVACUATION DRILL AND AAR. ALL PERSONNEL RESPONDED APPROPRIATELY AND MUSTER AT CORRECT 'LOCATION.CREW RESPONSE TIME=3 MIN 40 SEC. — 03:30 - 06:30 3.00 DHB P DECOMP RIG UP DUTCH RISER AND DSM LUBRICATOR TO PULL BLANKING PLUG AND BPV � 4 -PRESSURE TEST LUBRICATOR 250/3500 PSI FOR5MINEACH -PULL LUBRICATOR AND DUTCH RISER ASSEMBLY -ENGAGE BLANKING PLUG AND PULL FROM WELLHEAD -RE-INSTALL DUTCH RISER AND LUBRICATOR ASSEMBLY -PULL BPV PER DSM CREW -RIG DOWN LUBRICATOR AND DITCH RISER (ASSEMBLY 06:30 - 08:00 1.50 PULL P DECOMP I RIG UP TO PULL 2-7/8"TUBING WITH CONTROL LINE 1-RIG UP DOYON CASING -RIG UP SCHLUMBERGER SPOOLING UNIT 08:00 09:30 1.50 PULL P DECOMP ENGAGE HANGER WITH LANDING JOINT AND PULL -MAKE UP 5 TURNS WITH LANDING JOINT INTO HANGER PER FMC PULL HANGER FREE WITH 90K AND PULL TO FLOOR -MONITOR WELL FOR 10 MIN-STATIC -LAY DOWN HANGER AND LANDING JOINT 09:30 - 12:00 2.50 PULL P DECOMP 'CIRCULATE A 60 BBL BARAKLEAN PILL SURFACE TO SURFACE -6.5 BPM;1935 PSI -MONITOR WELL FOR 10 MIN-STATIC Printed 8/22/2016 11.01:21AM *All depths reported in Drillers Depths" • • North America-ALASKA-BP Page 9 Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817 00) Project:Lisbume Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To j Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 22:00 10.00 PULL P DECOMP PULL AND LAY DOWN 2-7/8",6.5#/FT,EUE 8RD IPC TUBING FROM 9057'MD -PU 81K,SO 77K AT 9030'MD -MONITOR DISPLACEMENT WITH TRIP TANK WHILE LAYING DOWN TUBING -RECOVERED: 76 STAINLESS STEEL BANDS 283 FULL JOINTS OF 2-7/8"TUBING 4 GAS LIFT MANDRELS 1 SUBSURFACE SAFETY VALVE 1 CUT OFF JOINT 2.5'LONG. ALL ITEMS PULLED FROM WELL CHECKED FOR NORM AND WITHIN LIMITS. 22:00 - 22:30 0.50 PULL P DECOMP RIG DOWN DOYON CASING EQUIPMENT 22:30 - 23:00 0.50 PULL P DECOMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 23:00 - 23:30 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR 23:30 - 00:00 0.50 EVAL P WEXIT RIG UP E-LINE. 8/7/2016 00:00 - 01:00 1.00 EVAL P VVEXIT CONTINUE TO RIG UP SCHLUMBERGER I E-LINE 01:00 - 04:00 3.00 EVAL P WEXIT RUN IN THE HOLE WITH 8.5"GAUGE RING TO -DRIFT 9-5/8"CASING FOR RUNNING EZSV ON SLB E-LINE -RUN IN THE HOLE AND TAG TOP OF TUBING ISTUB -PULL OUT OF THE HOLE WITH E-LINE AND LAY DOWN GAUGE RING SIMOPS:BUILD STANDS OF 4"DRILL PIPE OFFLINE 04.00 08:00 4.00 EVAL P WEXIT MAKE UP AND RUN IN THE HOLE WITH 9-5/8" EZSV(7.75"MAX OD)AND GR/CCL ON SLB E-LINE -LOG WELL -CONFIRM WITH WELLSITE GEO AND WSL AND SET EZSVAT 8964'WLMD SIMOPS:BUILD STANDS OF 4"DRILL PIPE OFFLINE 08:00 - 09:00 1.00 EVAL P WEXIT RIG DOWN SCHLUMBERGER E-LINE AND CLEAR RIG FLOOR. Printed 8/22/2016 11.01:21AM `AII depths reported in Drillers Depths* • North America ALASKA-BP Page to 0" Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:00 1.00 DHB P WEXIT PRESSURE TEST 9-5/8"CASING AND EZSV SET AT 8964'WLMD -REVIEW PRESSURE TEST CROSS CHECK CHECKLIST -250 PSI LOW FOR 5 CHARTED MIN-GOOD ,TEST -3500 PSI HIGH FOR 30 CHARTED MINUTES- GOOD TEST -LOST 12 PSI IN FIRST 15 MIN -LOST 5 PSI IN SECOND 15 MIN -PUMPED 9.4 BBLS,BLED BACK 9.4 BBLS -TEST MET BP WELLBORE TESTING CRITERIA -DISCUSSED RESULTS WITH WOS AND RECEIVED ATP -TEST CRITERIA CALCULATOR AND TEST CHART ATTACHED SIMOPS:BUILD STANDS OF 4"DRILL PIPE OFFLINE 10:00 - 12:00 2.00 STWHIP P WEXIT MOBILIZE SCHLUMBERGER WHIPSTOCK AND MILLS TO RIG FLOOR. LOAD TOOLS IN SHED AND INSPECT REVIEW WHIPSTOCK AND RUNNING PROCEDURE WITH SLB,BAKER DIRECTIONAL TEAM,AND RIG TEAM. -CHECK LOCK-DOWNS ON TUBING SPOOL WITH FMC -DECISION MADE TO PERFORM WELLHEAD WORK WITH MILLING ASSY HUNG OFF. 12:00 - 15:30 3.50 STWHIP P WEXIT PICK UP AND RUN IN THE HOLE WITH 9-5/8" SCHLUMBERGER TRAKMASTER PLUS WHIPSTOCK ASSY TO 655'MD 15:30 - 2230 7.00 STWHIP P WEXIT RUN IN THE HOLE WITH 9-5/8"WHIPSTOCK ASSY ON 4"DRILL PIPE -FROM 655'MD TO 8963'MD -RUN IN THE HOLE PICKING UP 96 SINGLE JOINTS OF DRILL PIPE FROM SHED CONTINUE RUNNING IN ON STANDS OF 4" DRILL PIPE OUT OF DERRICK -FILL PIPE EVERY 20 STANDS -SHALLOW TEST MWD AT 1600'MD-GOOD TEST -RUNNING SPEED 90 FPM -UTLIIZE TRIP TO MONITOR DISPLACEMENT WHILE RUNNING IN THE HOLE 22:30 - 23:00 0.50 STWHIP P WEXIT SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT ..____.-... 23:00 - 00:00 1.00 STWHIP P WEXIT ORIENT AND SET WHIPSTOCK -ORIENT WHIPSTOCK PER BAKER DD;46° LOHS -SET WHIPSTOCK PER SCHLUMBERGER REPRESENTATIVES -TAG EZSV AT 8969'MD WITH 5K DOWN -PICK UP 3'OFF EZSV WITH WHIPSTOCK TO 8966'MD -SLACK OFF IN 10K INCREMENTS TO 60K AND OBSERVE WHIPSTOCK SHEAR -BOTTOM OF WHIPSTOCK SET AT 8966'MD -BOTTOM OF SLIDE ON WHIPSTOCK AT 8958' MD -TOP OF SLIDE ON WHIPSTOCK AT 8944'MD. Printed 8/22/2016 11:01:21AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisbume Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 8/8/2016 00:00 - 01:30 1.50 STWHIP P WEXIT 'HANG OFF MILLING ASSEMBLY PRIOR TO REPLACING TUBING SPOOL AND PACK-OFF -PULLAND STAND BACK 2 STANDS OF DRILL PIPE -MAKE UP HES HANG OFF TOOL PER HES REPRESENTATIVE !-RUN IN THE HOLE 1 STAND TO 8850'MD;PU l.-170K,170K,SO 140K SET HANG OFF TOOL PER HES REPRESENTATIVE -PULLAND LAY DOWN RUNNING TOOL. 01:30 - 03:30 2.00 WHSUR P WEXIT NIPPLE DOWN BOPE STACK AND RISERS TO .CHANGE OUT TUBING SPOOL AND PACK-OFF DRAIN STACK -DE-ENERGIZE ACCUMULATOR AND ND •BOPE STACK -BREAK TUBING SPOOL FROM WELL HEAD -RACK BACK STACK AND STORE ON STUMP j ( -PULL HIGH,PRESSURE RISERS TO RIG !FLOOR I I � 1 H2S/MAN DOWN DRILL:CRT H2S=3 MIN 10 SEC. 03:30 - 04:30 1.00 WHSUR P WEXIT NIPPLE DOWN TUBING SPOOL -PULL 9-5/8"CASING PACK-OFF -CLEAN AND INSPECT CASING SPOOL 04:30 - 05:30 1.00 WHSUR P WEXIT INSTALL 9-5/8"CASING PACK-OFF AND NIPPLE UP NEW TUBING SPOOL -INSTALL NEW 9-5/8"CASING PACK-OFF PER FMC PROCEDURE -NIPPLE UP NEW TUBING SPOOL 05:30 - 06:30 1.00 WHSUR P WEXIT I PRESSURE TEST PACK-OFF SEALS AND FLANGE -250 PSI LOW FOR 5 MIN -3500 PSI HIGH FOR 15 MIN -DISCUSSED RESULTS WITH WOS AND RECEIVED ATP -SEE ATTACHED TEST CHART 06:30 - 08:30 2.00 WHSUR P WEXIT NIPPLE UP HIGH PRESSURE RISERS AND I BOPE STACK -INSTALL TURNBUCKLES ON STACK -INSTALL LOW PRESSURE RISER ON TOP OF BOP STACK !-AIR UP AIR BOOTS ON LOW PRESSURE i RISER -ENERGIZE ACCUMULATOR AND TAKE RKB MEASUREMENTS 08:30 - 09:30 1.00 WHSUR P WEXIT TMAKE UP HES RUNNING TOOL AND PULL HANG OFF TOOL -RUN IN THE HOLE WITH RUNNING TOOL AND ENGAGE HANG OFF TOOL -RELEASE HANG OFF TOOL •-PU 170K,SO 140K -PULLAND LAY DOWN HANG OFF TOOL 09:30 - 10:30 1.00 WHSUR P WEXIT PRESSURE TEST BOPE BREAKS AND NEW WELL HEAD COMPONENTS 250/3500 PSI FOR 5 CHARTED MIN I-GOOD TEST -SEE ATTACHED TEST CHART Printed 8/22/2016 11:01:21AM "All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 12 Operation Summary Report Common Well Name:L5-12 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2016 End Date:8/22/2016 X3-017WQ-C:(6,616,817.00) Project:Lisburne Site:Lis DS 05 Rig Name/No.:PARKER 272 Spud Date/Time:1/30/1987 12:00:OOAM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292169400 Active datum:L5-12A(actual)@67.35usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 STWHIP P WEXIT DISPLACE WELL FROM 8.5 PPG SEAWATER TO 10.5 PPG LSND MILLING FLUID -10 BPM'1750 PSI IP ` r i, 12:00 - 20:00 8.00 STWHIP P WEXIT MILL 8-1/2"WINDOW PER SCHLUMBERGER )��'� FISHING REPRESENTATIVE -TAKE SPR:MW=10.5 PPG IN/OUT 8942'MD 1M�P (7223'TVD) -MP#1:30/40 SPM;420/525 PSI -MP#2:30/40 SPM;410/525 PSI -400 GPM;1790 PSI ON,1700 PSI OFF -90 RPM;8K FT-LBS TORQUE ON,6K FT-LBS TORQUE OFF -1-5K WOB TOW:8940'MD(7221'TVD) BOW:8958'MD(7235'TVD) WORK MILLS THROUGH WINDOW WITH AND WITHOUT ROTARY AND PUMPS WITH NO DRAG NOTED PERFORM D2 WITH HIGH GAS TO PITS DRILL AND AAR:CRT 90 SEC TO CLOSE IN WELL;10 MIN FOR ALL PERSONNEL TO MUSTER.DO TO WINDS AND WORK LOCATIONS, PERSONNEL MUSTERED AT BOTH MUSTER LOCATIONS.ACCURATE PERSONNEL COUNT WAS CONFIRMED. 20:00 - 00:00 4.00 STWHIP P WEXIT CONTINUE TO MILL 40'OF RATHOLE FOR NEXT RSS ASSEMBLY IN NEW FORMATION -FROM 8958'MD TO 8998'MD(7267'TVD) -400 GPM;1800 PSI ON,1720 PSI OFF -110 RPM;9-10K FT-LBS TORQUE ON,8K TORQUE OFF -12-14K WOB -PU 172K,SO 140K,ROT 152K -PUMP 40 BBL HIGH VIS SWEEP AT 8995'MD. 8/9/2016 00:00 - 01:00 1.00 STWHIP P WEXIT CIRCULATE THE HOLE CLEAN BEFORE PERFORM LOT -PULL UP INTO 9-5/8"CASING ABOVE WINDOW. -500 GPM;2545 PSI -MODERATE INCREASE IN RETURNS WITH SWEEP. -MW IN/OUT=10.5 PPG 01:00 - 03:00 2.00 STWHIP P WEXIT RIG UP AND PERFORM LOT -MUD WEIGHT:10.5 PPG,7221'TVD,8940'MD -PUMP 2.8 BBLS TO 620 PSI,BLEED BACK 2.6 BBLS -LOT EMW=12.15 PPG -DISCUSS RESULTS WITH ODE AND RECEIVE ATP -MONITOR WELL FOR 10 MIN-STATIC -BLOW DOWN LINES AND RIG DOWN TEST EQUIPMENT Printed 8/22/2016 11:01:21AM *All depths reported in Drillers Depths* TREE= 59116"CM/ _ 1. 0. O0'ON 06/24199 69ERPOF SLHOT-FROM 978/80'- WELLFfAD= FMC ACTUATOR= BAKER C OKB.ELEV= 60' TAILPIPE ON BTM"'" lit BF.BF.ELEV= 22.25' KOP= 2800' 20"COND, H 119' LMax Angle= 55"@ 7400' 91 5#,H-40, Datum MD= 10915' D=19.124' Datum TVD= 8900'SS 13-3/8"CSG,72#/68#,L-801 K-55,D=12.347' H 4206' 8944' -{9-5/8"WHPSTOCK(08/07/16) p„ ', 8969' -1H9-5/8"EZSV(08/07/16) 905T ELMD HJET CUT TBG(05/15/16) Minimum ID = 1.75" @ 10357'SLM MCMURRY GAS LEI MANDRELS COLLAPSED TBG ST M) TVD DEV TYPE VLV LATCH PORI DATE '•'•'•' 2 2826 2823 11 FM-10 DMY BK-2 0 11/22/90 TOC ABOVE CMT RETAINER(05/11/16) — -9240' !dd ■ 3 5722 5064 44 FMHO OMY BK-2 0 03/10/91 4441 /141 2-7/8'WFT CMT RETAINER(05/10/16) H 9262' i44444� 144441 4 4 8317 6756 46 FM JO DMY BK-2 0 06/05/87 .4. 14 4 5 9823 7960 27 FM-JO "DMY BK-2 0 06/05/87 2-7/8"TOP OF I CMT(05/11/16) -9282' 044444r ►44444 6 10259 8352 24 FMHO 'OPEN OPEN - 05/08/16 A.1).� /.4�4� STA#5=CEIVENTED OFF(05/11/16) 2-718"VVFT CBP(05109/76) -) 10325' �4; ►a4i41 2-7/8'COLLAPSED TBG(10/12/15) 1 10357'SLM i 10367' -{9-5/8"X 2-7/8"BROWN HB PKR,D=3.00" TOP OF 7"LNR -4 10425' MCMURRY PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 10575 8653 22 FIA-10 EKED BK-2 16 03/14/92 9-518"CSG,47#,L-80 NSCC/BTC,D=8.681" -I 10644' I---A Illi 10654' H2-7/8"AVA BPL NP,ID=2.259" 111 10662'-10702' H 2-7/8'CAMCO BLAST JOINTS,ID=2.438" 2-7/8"TBG-PC,6.5#,L-80,.0058 bpf,D=2.441" H 10723'ELMD I PERFORATION S1 NSAARY 71 10705'J-17.X 2-7/8'BROWN 4 B PKR,D=3.25" REF LOG:ZDUCMJGR DA ON 02/24/87 BMD ANGLE AT TOP PERF:21"@ 10668' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 4" 2 10668-10682 0 06/05/87 10723'ELMD -{CUT OFF TBG TAL,ID=2.568" 4" 2 10688-10698 0 06/05/87 2-1/8" 1 10735-10739 0 10/15/87 2-1/8" 1 10750-10755 0 10/15/87 , 2-1/8" 1 10757-10763 0 10/15/87 I 2-1/8" 1 10771-10773 0 10/15/87 2-1/8" 1 10775-10777 0 10/15/87 ' 2-1/8" 1 10783-10788 0 10/15/87 I 2-1/8" 1 10794-10798 0 10/15/87 4" 2 10856-10878 0 06/05/87 I 4" 2 10898-10922 0 06/05/87 PBTD -j 11197' ? FISH- 2-7/8"TA LPFE w/AVA NIP-69' .44444444444444 ON BOTTOM(06/08/87) 7"LNR 29#,L-80 BTC,.0371 bpf,D=6.184" -{ 11242' 444444444444444 DATE REV BY CONVENTS DATE REV BY CONVENTS LISBURTE UNIT 03/02/87 ORIGINAL COMPLETION 05/25/16 M.W/JMI7\SET HOLD OFE N SLEEVE(05/20/16) WELL: L5-12 12/29/01 0-1/TP CORRECTIONS PERMIT No: 1870100 05/13/16 MACRO SET CUP(05/09/16) API No: 50-029-21694-00 05/13/16 JI JIVD GLV GO(05/08/16) SEC 1,T11N,R15E,1668'FSL&16'FWL 05/13/16 TFA/JMD SET CMT RET/FU PED CMT(05/11/16) 05/16/16 JUJU) TBG CUT(05/15/16) BP Exploration(Alaska) Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Thursday,July 28, 2016 8:59 AM To: 'Sperry, Nathan' Cc: Lastufka,Joseph N (Joseph.Lastufka@bp.com) Subject: L5-12(PTD 187-010, Sundry 316-006, Plug for Redrill) L5-12A(PTD 216-002 Drill) BOP Test Pressure Change Follow Up Flag: Follow up Flag Status: Completed Nathan, Approval is granted to test the BOPs to 3500 psig instead of the 4000 psig outlined on the approved Permit(L5-12A Lateral PTD 216-002)) and Sundry(L5-12 Plug for Redrill, PTD 187-010,Sundry 316-006)). The MPSP is 2711 psig. This approval should be placed with your approved copies of the PTD/Sundry and available for the AOGCC inspector to review. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission ,.. y 333 W.7th Aver Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoeoo@alaska.gov From: Sperry, Nathan [mailto:Nathan.Sperry@ bp.com] Sent:Thursday,July 28, 2016 8:26 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: L5-12A BOP Test Pressure Hi Victoria, On L5-12A,our MASP is 2,711 psi. We submitted the Sundry and Permit with the intent to perform our BOPE tests to 4,000 psi and our tubular tests to 4,000 psi (casing, LTP,TWC). The driver for testing to 4,000 psi was that our post-rig work team believed they needed up to 4,000 psi to pump their acid and stimulation. They have revised their estimate and believe that they will only need 3,000 psi. Do we have your approval to drop our test pressure for our BOPE to 3,500 psi? We also are requesting to change our integrity tests from 4,000 psi to 3,500 psi. Regards, Nathan Sperry Drilling Engineer Cell:907-268-8416 Office:907-564-4258 2 PTO /8 7 - O U • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,July 28,2016 8:59 AM To: 'Sperry, Nathan' Cc: Lastufka,Joseph N (Joseph.Lastufka@bp.com) Subject: L5-12(PTD 187-010,Sundry 316-006, Plug for Redrill) L5-12A(PTD 216-002 Drill) BOP Test Pressure Change Nathan, Approval is granted to test the BOPs to 3500 psig instead of the 4000 psig outlined on the approved Permit(L5-12A Lateral PTD 216-002)) and Sundry(L5-12 Plug for Redrill, PTD 187-010,Sundry 316-006)). The MPSP is 2711 psig. This approval should be placed with your approved copies of the PTD/Sundry and available for the AOGCC inspector to review. Thanx, Victoria Victoria Loepp OCT Senior Petroleum Engineer SCANNED 3 120j6 State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From: Sperry, Nathan [mailto:Nathan.Sperry@)bp.com] Sent:Thursday,July 28, 2016 8:26 AM To: Loepp, Victoria T(DOA) Cc: Lastufka,Joseph N Subject: L5-12A BOP Test Pressure Hi Victoria, On L5-12A,our MASP is 2,711 psi. We submitted the Sundry and Permit with the intent to perform our BOPE tests to 4,000 psi and our tubular tests to 4,000 psi (casing, LTP,TWC). The driver for testing to 4,000 psi was that our post-rig work team believed they needed up to 4,000 psi to pump their acid and stimulation. They have revised their estimate and believe that they will only need 3,000 psi. Do we have your approval to drop our test pressure for our BOPE to 3,500 psi? We also are requesting to change our integrity tests from 4,000 psi to 3,500 psi. Regards, 1 ti OF r� THE STATE Alaska Oil and Gas • �w��\ I%%%�, as a� 4", ir��- o Conservati®n Commissi®n ALAsKA ` 1 } ===- 333 West Seventh Avenue \T��r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALA91°' Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen Engineering Team Lead SCANNED 14. BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-12 Permit to Drill Number: 187-010 Sundry Number: 316-006 Dear Mr. Allen: 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, A , P° Cathy Foerster Chair DATED this 22 day of January, 2016. RBDMS L JAN L 5 2016 ' RECEIVED STATE OF ALASKA -ALASKA OIL AND GAS CONSERVATION COMMI N JAN 0 5 20?6 • i APPLICATION FOR SUNDRY APPRO S 2O1 20 AAC 25.280 /3 7 /I( ���+++ 2_24/ 6 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ )P&[Arutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing ❑ Change Approved Program ❑ Plug for Redrill p• Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: - 5. Permit to Drill Number: 187-010 Exploratory ❑ Development p 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-21694-00-00 99519-6612 Stratigraphic ❑ Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? No PBU L5-12 Will planned perforations require a spacing exception? Yes ❑ 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028320 ' PRUDHOE BAY,LISBURNE 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): 11242 - 9267 11197 9225 2711 None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 42-121 42-121 1490 470 Surface 4167 13-3/8" 41 -4208 41 -4001 3700/4930 2230/2670 Intermediate 10609 9-5/8" 38-10646 38-8709 6870 4760 Production Liner 817 7" 10425-11242 8505-9267 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10668-10922 8729-8967 2-7/8"6.5# L-80 36-10723 Packers and SSSV Type: 2-7/8"Brown HB Packer Packers and SSSV MD(ft)and TVD(ft): 10368/8452 2-7/8"IB Packer 10706/8765 12.Attachments: Proposal Summary WI Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ll Service ❑ 14.Estimated Date for Commencing Operations: February 1,2016 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended El - 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Niedermeyer,James be deviated from without prior written approval. Email James.Niedermeyer@bp.com Printed Name Ken Allen Title Engineering Team Lead Signature :,�--} Phone +1 907 564 4366 Date L. b COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test IN Mechanical Integrity Test ❑ Location Clearance ❑ Other:Bop �--e-�f -o 40OD pS i ( A-tip5P .1 S ,2�/1 p5; ,�trloir��/�e6v Kent?' pi"a G ��tr -c) rt4-C z 5-' tt Z CL f16t-c� friu P �/ p Post Initial Injection MIT Req'd? Yes L No ❑ Spacing Exception Required? Yes 0 No 121" Subsequent Form Required: 1 0 4 0 7 APPROVED BYTHE / Approved by:it:egeil.t,9COMMISSIONER COMMISSION Date:7,ZZ_! o A- //2/ !, f ORIGINAL g/76 RBDMS L'- JAN 2 5 2016 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. • . 0 bp GP6p eiferfirdi oelfirL5-12 Sundry Application Well Type: Producer Current Status: The well is currently shut-in. Request:Approval for the P&A of Lisburne well L5-12 to sidetrack and complete L5-12A. MIT-T Passed to 1,000 psi (7/30/2014) MIT-IA Passed to 3,000 psi (10/12/2015), 1,000 psi after indication of collapsed tubing (10/25/2015) MIT-OA Passed to 1,200 psi (10/25/2015) PPPOT-T Passed to 5,000 psi (9/27/2015) PPPOT-IC Passed to 3,500 psi (9/27/2015) Well History: L5-12 was drilled in 1987 and continuously cored through the Wahoo. An acid frac was completed in the W6,W5, &W4 zones. The well is completed with 2-7/8"tubing with a straddle across the W6 perfs. The well came on at 2,000 BOPD. A test of the W5/W4 only in 7/90 indicated low productivity in these intervals. A CFA was pumped in 11/90 and resulted in 350 BOPD incremental production from these zones. The W5/W4 were produced alone until 3/92 when the BPI was pulled and a BPC was run in the straddle allowing the W6 to produce. The well's GOR was 10,000 to 30,000 and the well was shut in. The well has been produced only intermittently since 1993 due to high GOR and the need for frequent hot oilings. Most recently, it is suspected the tubing collapsed above the production packer during an MIT-IA and subsequent drift runs have been unable to pass the obstruction. Scope of Work: The sidetrack plan for the L5-12A well includes the following operations. Pre-rig, the horizontal lateral will be P&A'd with cement. Work is to include setting a plug in the tubing at—10,300', pulling the GLV from station 6 at 10,259' MD, and cement plug will be circulated into the tubing and IA. Top of cement is planned for 9,275' MD. Once the cement has setup, the final top of cement will be determined with a drift run followed by an integrity test of the tubing and inner annulus. Last, the 2-7/8" tubing will be jet cut at 9,030' MD in preparation for the rig. The rig will move over the well, pull the 2-7/8" tubing, and perform a clean out run. Last, an EZSV bridge plug will be set in preparation for the whipstock exit at—8,950' MD. The 7" intermediate casing will be set at the top of the Lisburne formation and the 6-1/8" production hole will be drilled in WH6, WH5, and WH4 of the Lisburne reservoir. The production liner will be a cementless sliding sleeve and swell packer completion. 4-1/2"tubing will then be run to the top of the production liner. MASP: 2,711 psi Estimated Start Date: February 1, 2016 , 1 cur. l4t Weir ygro1vcPs w r'/�i c GOR 25% "Ver rti4n 14e tqad a✓e to fre- a'? Mu" r6►vh pfovAte TG4or Of 1'4e 0,9vod f too/,u€"f 0,1 is Arte,191-.5 ar 9,c//,,.. ge, we// lave /tittle ei n0 ben ef,'/ f 1k— • lel L5-12 Sundry_p / 1 // 12/30/2015 lNCll for <e Rr,L( 54ovfcl q// - c (/►ffOP/ f�cover 6DM% N3 fOMp�' or Pie �QVI• . • • Pre-Rig Prep Work: Step Service Line Description of Work 1 S Set CIBP. Pull GLV from station 6. Flush chemical injection line. Set DMY in chemical injection mandrel. 2 F A/SL. Load TBG. MIT-T 3 C Circulate cement plug into TBG&IA with 71 bbls 15.8 ppg Class G. Planned TOC at 9,275' MD. 4 S D&T TOC. Drift for jet cut. 5 F MIT-T 3,500 psi. MIT-IA 3,500 psi. 6 E Jet cut tubing at 9,030' MD. 7 F Circ Out. CMIT-TxIA 3,500 psi. MIT-OA 1,200 psi. 8 S Set hold open sleeve. 9 W PPPOT-T. PPPOT-IC. Function LDS. 10 V Set TWC. Install Dry Hole Tree. Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test TWC from above and below to 4,000 psi psi for 5 minutes each. 3. Nipple down tree. Nipple up BOPE and test to 4,000 psi. (Configured from top to bottom: 13- 5/8" annular preventer, 2-7/8" x 5-1/2"VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5-1/2"VBRs in the lower cavity). a. Test rams and annular to 250 psi/4,000 psi with 4"test joint. b. Notify AOGCC 24 hrs in advance of full test. 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection and displace well to clean seawater. 6. Pull 2-7/8"tubing from the pre-rig cut. 7. Perform 9-5/8" cleanout run to 2-7/8"tubing stub. 8. Rig up e-line. Run and set EZSV at —8,972' MD. Pressure test to 250 psi for 5 minutes and 4,000 psi for 30 charted minutes each. Change 9-5/8"packoff and tubing spool 9. PU 9-5/8" whipstock, bottom trip anchor, and 8-1/2" window milling assembly (to include full gauge string mills). RIH to top of EZSV, orient, and set whipstock. 10. Swap wellbore over to 10.5 ppg LSND milling fluid. End of Sundry: Start of Permit to Drill Drill 8-1/2" Intermediate Hole 11. Mill window in 9-5/8" casing plus 20-50' of new formation. 12. Pull into the window and perform LOT. Minimum LOT required is 11.37 ppg EMW for 25 bbl kick tolerance. 13. POOH for drilling BHA#1. 14. MU 8-1/2"drilling RSS BHA#1 w/MWD/GR/RES/PWD/near-bit GR and RIH. 15. Kick off and drill 8-1/2" intermediate interval per the directional plan to TLSB TD of—10,914' MD. 16. At TD, CBU a minimum of 2x, or until wellbore is clean. 17. Perform short trip to the window. 18. RIH to TD, circulate the wellbore clean and POOH on elevators. L5-12 Sundry 2 12/30/2015 • S Run&Cement 7" Intermediate Liner 19. Change upper 2-7/8"x 5-1/2"VBRs to 7" casing rams and test to 250 psi low/4,000 psi high. 20. Run 7", 26#L-80, VamTop HC liner to TD,with 150' liner lap into 9-5/8"window. 21. Cement liner to TOL with 11.5 ppg LiteCrete lead and 15.8 ppg Class G tail cement. Circulate excess cement above TOL. 22. Set liner top packer and liner hanger. POOH and LD liner running tool. 23. Change upper 7"casing rams to 2-7/8"x 5-1/2"VBRs and test to 250 psi low/4,000 psi high. 24. Test 7"liner to 250 psi for 5 minutes/4,000 psi for 30 minutes after cement has reached a minimum 500 psi compressive strength. Drill 6-1/8" Production Hole Section 25. MU 6-1/8"drilling BHA with MWD/GR/RES/NPHI/PEF and RIH. 26. RIH and tag landing collar. 27. Displace wellbore to 8.5 ppg QuikDril-N. 28. Perform a negative pressure test on 7" liner(no flow test). 29. Drill shoe track and 20-50 ft of new formation. Pull above shoe and perform FIT. Minimum FIT required is 8.78 ppg EMW for infinite kick tolerance. 30. Drill 6-1/8" production interval per the directional plan to TD of-13,996' MD. 31. At TD, CBU a minimum of 2x, or until wellbore is clean. 32. Perform short trip to the shoe. 33. RIH to TD, circulate the wellbore clean and POOH on elevators. 34. LD excess 4" DP and BHA. Run 4-1/2" Production Liner 35. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 swell packer/sliding sleeve production liner to TD,with 150 ft liner lap into 7"casing. 36. Drop ball and shift liner circulation valve closed. 37. Set liner hanger and liner top packer. 38. Displace wellbore to clean seawater above TOL. 39. POOH and LD liner running tool. 40. Pressure test 9-5/8"casing x 7" liner x 4-1/2" liner envelop to 250 psi low minutes/4,000 psi high. Run 4-1/2"Completion 41. RU and run 4-1/2", 12.6# 13Cr-85 VamTop completion per the tally. Tag up in PBR, space out, and land tubing hanger. RILDS. 42. Displace tubing and IA to clean seawater. 43. Reverse circulate in heated seawater and inhibited seawater to IA and tubing (surface to surface). 44. Drop ball &rod and set production packer. Individually test tubing and IA to 250 psi low/4,000 psi high. 45. Shear DCR valve. 46. Reverse circulate in diesel freeze protect down IA using rig's injection pump to freeze protect IA and tubing to 2050' MD/ 1,981'TVDss. 47. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. L5-12 Sundry 3 12/30/2015 ND/NU 48. Install TWC and test from above and below to 250 psi low/4,000 psi high for 5 minutes each. 49. N/D BOPE. NU adapter flange and double master valves. Test to 250 psi/5,000 psi for 5 minutes each with diesel. 50. Ensure Heet is left on top of TWC and only diesel is left in the tree. 51. Install all annulus valves and secure the well. Release Rig 52. Rig down Parker 272. 53. Move rig off location. Planned Post-Rig Operations: 1. Change out dry hole tree for production tree. 2. Pull TWC, ball and rod, and RHC plug. Pull shear valve and install dummy GLV. 3. Negative pressure test on 7" liner top. 4. Perform acid stimulation. 5. Pull dummy GLVs. Install GLVs. 6. Flowback, per ASRC. 7. Modify S-riser as required. 8. Install flow lines and well house. Drilling Engineer: James Niedermeyer (907) 564-4874 Production Engineer: Joleen Oshiro (907) 564-4606 Geologist: Ashley Siks (907) 564-5246 L5-12 Sundry 4 12/30/2015 TREE= 5-9/16"aW • NOTES:HIGH OVERFILLS FROM 9800'- _ WELLHEAD= FMC �L5 12 10600'ON 06!24199*"'69'OF SHOT-OFF 2-7/8" ACTUATOR= BAKER—0 TAILPIPE ON BTM"* OKB.6LEV= 60' 1 1 BE ELEV= NA KOP 2800' Max Angle 55'@ 7400 „� 2205' -{2-718"CAMCO TRDP 1A TRSSSV,ID=2.312" Iv1 Datum MD= 10915' Datum TVD= 8900'SS CAW()Ct-IEMCAL MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE CONDUCTOR #/, D La 1 2296 2296 1 KBMG-L DV BK-2 0 1373/8"CSG,72#/68#,L-80/K-55,D=12.347" H 3987 _-A , MCMl1RRY GAS LFT MANDRE S — lST MD TVD DEV TYPE VLV LATCH PORT DATE ' 2 2826 2823 11 FMHO DV BK-2 0 3 5722 5064 44 FM-IO DV BK-2 0 03/10/91 Minimum ID = 2.259" @ 10654' 4 8317 6756 46 ,FM-10 DV BK-2 0 AVA BPL NIPPLE 5 9823 7960 27 FMHO DV BK-2 0 6 10259 8352 24 FMHO SO RK 20 03/10/91 .5{ 10367' H 9-5/8"X 2-7/8"BROWN I-U PKR,ID=3.00" TOP OF 7"LINER -+ 10425' L MCMURRY PRODUCTION MANDRELS L ,ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 10575 8653 22 FM-0 B<ED BK-2 16 03/14/92 9-5/8"CSG,47#,L-80,D=8.681" 10644' • 10654' —12-7/8"AVA BPL M?ID=2.259" 2-7/8"TBG-PC,6.5#,L-80,.0058 bpf,D=2.441" —I 10723'ELMD I 0 I 10662'-10702' - (2-7/8"CAMCO BLAST JOINTS,ID=2.438" 10705' —r X 2-7/8"BROWN I-B PKR PERFORATION SUMMARY I3MD REF LOG:ZDL/CNJGR DA ON 02/24/87 ANGLE AT TOP PERF:21°@ 10668' Note;Refer to Production DB for historical pert data SIZE SW INTERVAL Opn/Sqz SI-0T SOZ 4" 2 10668-10682 0 06/05/87 10723'ELMD --f CUT OFF TBG TAR.,ID=2.568" 4" 2 10688-10698 0 06/05/87 2-1/8" 1 10735- 10739 0 10/15/87 2-1/8" 1 10750- 10755 0 10/15/87 2-1/8" 1 10757-10763 0 10/15/87 2-1/8" 1 10771-10773 0 10/15/87 2-1/8" 1 10775-10777 0 10/15/87 2-1/8" 1 10783- 10788 0 10/15/87 2-1/8" 1 10794- 10798 0 10/15/87 4" 2 10856-10878 0 06/05/87 4" 2 10898- 10922 0 06/05/87 MID 11197' ? FISH- 2-7/8"TALPPE w/AVA NP-69' 4�4�44444�4�41• 1 ON BOTTOM(XX/XX/XX/)? 7"LNR,29#,L-80,.0371 bpf,D=6.184" -{ 11242' 1�4A4�vA•AvA4A4il DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURN=MT 03/02/87 ORIGINAL COMPLETION 08/18/14 PJC REFORMAT WBS-CLEANUP WELL: L5-12 12/29/01 CHrTP CORRECTIONS PERMIT No:1870100 06/11/04 PMI-I/KAK 13-3/8"CSG CORRECTION AH No' 50-029-21694-00 03/03/07 RL DATUM MD SEC 1,T11N,R15E, 1668'FSL&16'RM.. 07/09/14 JRPIJMD PULLED BPC SLV(07/08/14) 08/04/14 DIY PJC TREEC/O BP Exploration(Alaska) • • Victoria, Per AOGCC regulation 20 AAC 25.112(i), BPXA is requesting a variance to regulation 20 AAC 25.112(c)to plug the well L5-12. During the P&A planning stages in preparation to sidetrack Lisburne L5-12,there were some changes that have impacted our initial plan to P&A the well as normally done per 20 AAC 25.112. Provided below is the information leading to the current state of the well. • There are indications that the tubing has partially collapsed above the production packer at 10,367' MD. • Neither a 1.9"swedge nor 1.75"OD centralizer were able to pass 10,357'MD on subsequent drift runs. • The well passed an MIT-IA to 3,500 psi on 10/12/15 and 1,000 psi on 10/28/15 (after suspect of tubing collapse),which indicates the production packer integrity has not been compromised. To abandon the perforations behind the straddle packers and tubing,the original plan would have been to pull the valve from the production mandrel at 10,575' MD and squeeze cement into those perforations.Without being able to get past the tubing collapse,this method is no Ion&er possible and would require milling up the packer in order to o achieve full access.There also is the risk of additional collapse points between the known collapse and the production packer,further jeopardizing recovery. In regards to hydrocarbon bearing zones, please find the following information: • Due to the LCU truncation,the Put River and Ivishak reservoirs are absent,leaving the Lisburne as the only hydrocarbon bearing zone. • TLSB in L5-12 is 10,643' MD(8,646'TVDss). • Original cement records from L5-12 construction indicate 146.26 bbl of cement were pumped in the 12-14"OH x 9-5/8"casing annulus.Assuming an open hole volume increase/ washout of 40%(13.15"effective ID),this places TOC at 8,771'MD(7,020'TVDss). BPXA is proposing the following alternative plan to P&A the parent L5-12 wellbore: • Set a plug in the tubing at 10,300'MD. • Pull GLV#6 at 10,259' MD • Pump 78.8 bbls of 15.8 ppg Class G cement down tubing and squeeze 72.8 bbls into the IA, leaving 6 bbls in the tubing. • Drift and tag through tubing after cement has set up to confirm TOC. This will provide a 1000' MD cement plug in both the tubing and IA,put TOC at 9,300' MD (7,430'TVDss),ensure all hydrocarbons are confined to their indigenous strata and prevented from migrating,and satisfy the AOGCC's requirement of having cement 500'above the hydrocarbon bearing zone. If you have questions or there is any additional information needed to process this variance request,please let me know. Thank you, James Niedermeyer Drilling Engineer BP Exploration,Alaska Desk:907-564-4874 Cell:907-205-2357 James.Niedermever@bp.com M I KEL= 5-9/16"CNV L 5 12 ON 0 6124 99"69,,0E SLHOT--OFF 2 7/80• vVaLHEAD: FMC Pre-ri A ACTUATOR= BAKER TAILPIPE ON BTM"` OKB.ELEV= 60' 1 1 BE BEV= NA KOP= 2800' Max Angle= 55"@ 7400' 2205' -12-7/8"CAMCO TRDP 1A TRSSSV,D=2.312" Datum MD= 10915' v I Datum TVD= 8900'SS VIK ALNDREL ST MD DEVCAMCO CHETYPE VLV LATCHS PORT DATE "CONDUCTOR, #,_ ,D= H 1 2296 2296 1 KBMG-L DV BK-2 0 13-3/8"CSG,72#/68#,L-80/K-55,ID=12.347" H 3982' Minimum ID = 2.259" @ 10654' MCMURRY GAS LIFT MANDRELS AVA BPL NIPPLE ST MD DEV TYPE VLV LATCH FORT DATE 2 2826 2823 11 FM-IC) DV BK-2 0 3 5722 5064 44 FM-I0 DV BK-2 0 03/10/91 Suspected tubing collapse @ 10,357'MD—.. 4 8317 6756 46 RANO DV BK-2 0 5 9823 7960 27 FM-IO DV BK-2 0 E-line: Set CIBP @-10,300'MD 6 10259 8352 24 FM-10 SO RK 20 03/10/91 Pull GLV from ST#6 at 10,259'MD g >< 10367' H9-5/8"X 2-7/8"BROWN HB PKR,D=3.00" CT: Pump 78.8 bbl cement plug into tubing and IA TOP OF 7"LNR --{ 10425' E-line: Jet cut tubing at 9,030'MD MCMURRY PRODUCTION MANDRELS ST MD DEV TYPE VLV LATCH FORT DATE �— 7 10575 8653 22 FMHO EKED BK-2 16 03/14/92 9-5/8"CSG,47#,L-80,D=8.681" H 10644' 1----4 ' I 10654' -2-7/8"AVA BPL NP,D=2.259" 10662' -10702' --I2-7/8"CAMCO BLAST JOINTS,D=2.438" 2-7/8"TBG-PC,6.5#,L-80,.0058 bpf,D=2.441" -i 10723' ELMD I I 0 PERFORATION SUMMARY 10705' 7"X 2-7/8"BROWN I-B PKR REF LOG:ZDL/CNJGR DA ON 02/24/87 ELMD ANGLE AT TOP PERF:21°@ 10668' Note:Refer to Production DB for historical perf data SIZE SPF NTB2VAL Opn/Sqz SHOT SQZ 4" 2 10668-10682 0 06/05/87 10723' ELMD --�CUT OFF TBG TAL,D=2.568" 4" 2 10688-10698 0 06/05/87 2-1/8" 1 10735-10739 0 10/15/87 2-1/8" 1 10750-10755 0 10/15/87 j r7 2-1/8" 1 10757-10763 0 10/15/87 2-1/8" 1 10771-10773 0 10/15/87 2-1/8" 1 10775-10777 0 10/15/87 2-1/8" 1 10783-10788 0 10/15/87 2-1/8" 1 10794-10798 0 10/15/87 4" 2 10856-10878 0 06/05/87 4" 2 10898-10922 0 06/05/87 PBTD 11197' ? FISH- 2-7/8"TA LPPE w/AVA NP-69' .�1�.�1.11.. 1 ON BOTTOM()X/XX/XX/)? 7"LNR,29#,L-80,.0371 bpf,D=6.184" -� 11242' 14Att'A'A'�i DATE REV BY COMMENTS DATE REV BY COMV®'ITS LISBURNE UNIT 03/02/87 ORIGINAL COMPLETION 08/18/14 PJC REFORMAT WBS-CLEANUP WELL: L5-12 12/29/01 CH/TP CORRECTIONS PERMIT No: 1870100 06/11/04 RIR-/KAK 13-3/8"CSG CORRECTION API No: 50-029-21694-00 03/03/07 RL DATUM MD SEC 1,T11 N,R15E,1668'FSL&16'FVVL 07/09/14 JRP/JMD PULLED BPC SLV(07/08/14) 08/04/14 DU/PJC TREE C/O BP Exploration(Alaska) TREE= 5-9/16"CNV S> Y NOTES:HIGH OVERPULLS FROM 9800'- WELLHEAD= FMC Pre-rig P&A L5-12 10600'ON 06/24/99""69'OF SHOT-OFF 2-7/8" ACTUATOR= BAKERC TAILPIPE ON BTM "" OKB.ELEV= 60' I 1 BF.ELEV= NA /KOP= 2800' Max Angle= 55°@ 7400' 0 2205' H2-7/8"CA MCO TRDP-1A TRSSSV,D=2.312" Datum MD= 10915' Datum TVD= 8900'SS CA MCO CHEMICAL MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE "CONDUCTOR #, ,D= • HLd 1 2296 2296 1 KBMG-L DV BK-2 0 13-3/8"CSG,72#/68#,L-80/K-55,ID=12.347" --I 3982' Minimum ID = 2.259" @ 10654' '-4111 MCMURRY GAS LFT MANDRELS AVA BPL NIPPLE gei? -' , ,' ST MD TVD DEV TYPE VLV LATCH PORT DATE / 4- -- 2 2826 2823 11 FMHO DV BK-2 0 qo?JD ;, 3 5722 5064 44 FMHO DV BK-2 0 03/10/91 lI l' ^ — 1 ,.$ 4 8317 6756 46 FM-IC) DV BK-2 0 5 9823 7960 27 FMHO DV BK-2 0 E-line: Set CIBP @-10,300'MD 6 10259 8352 24 FM-IO SO RK 20 03/10/91 Pull GLV from ST#6 at 10,259'MD /03U� / ___�� 10367' --I 9-5/8"X 2-7/8"BROWN HB FKR,D=3.00" CT: Pump 71 bbl cement plug into • tubing and IA ---I TOP OF 7"LNR H 10425' E-line: Jet cut tubing at 9,000'MD MCMURRY PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE L 7 10575 8653' 22 FMHO EKED BK-2 16 '03/14/92 9-5/8"CSG,47#,L-80,D=8.681" - 10644' - k ' I 10654' H2-7/8"AVA BPL NP,D=2.259" 10662'-10702' H2-7/8"CAMCO BLAST JOMS,D=2.438" 2-7/8"TBG-PC,6.5#,L-80,.0058 bpf,ID=2.441" H 10723' ELMD I 10,0665 ' PERFORATION SUMMARY 10705' 17"X 2-7/8"BROWN I-B FKR REF LOG:ZDL/CNL/GR DA ON 02/24/87 ELMD ANGLE AT TOP PERF:21°@ 10668' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4" 2 10668-10682 0 06/05/87 10723' ELM D H CUT OFF TBG TA L,D=2.568" 4" 2 10688-10698 0 06/05/87 2-1/8" 1 10735-10739 0 10/15/87 2-1/8" 1 10750-10755 0 10/15/87 'S- 2-1/8" S2-1/8" 1 10757-10763 0 10/15/87 it, 7.35"/ 2-1/8" 1 10771 -10773 0 10/15/87 2-1/8" 1 10775-10777 0 10/15/87 2-1/8" 1 10783-10788 0 10/15/87 2-1/8" 1 10794-10798 0 10/15/87 4" 2 10856-10878 0 06/05/87 4" 2 10898-10922 0 06/05/87 d _.---- 1b9Z4'.- FBTD —I 11197' 4..1... ? FISH- 2-7/8"TALPPEw/AVA NP-69' $1$1$$$1$$$$$1 ON BOTTOM pOUXX/XX/)? 7"LNR 29#,L-80,.0371 bpf,D=6.184" H 11242' ,.i.........i0. DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNEUNIT 03/02/87 ORIGINAL COMPLETION 08/18/14 PJC REFORMAT WBS-CLEANUP WELL: L5-12 12/29/01 CH/TP CORRECTIONS PERMIT No: '1870100 06/11/04 PM-L/KAK 13-3/8"CSG CORRECTION AR No: 50-029-21694-00 03/03/07 RL DATUM MD SEC 1,T11N,R15E, 1668'FSL&16'FWL 07/09/14 JRP/JND PULLED BFC SLV(07/08/14) 08/04/14 DU/PJC TREE C/O BP Exploration(Alaska) • • Victoria, During the P&A planning stages in preparation to sidetrack Lisburne L5-12A,there were some changes that have impacted our initial plan to P&A the well as normally done. Because of this, I wanted to provide you the information leading to the changes. • There are indications that the tubing has partially collapsed above the production packer at 10,367' MD. • Neither a 1.9"swedge nor 1.75"OD centralizer were able to pass 10,357' MD on following drift runs. • The well passed an MIT-IA to 3,500 psi on 10/12/15 and 1,000 psi on 10/28/15 (after suspect of tubing collapse),which indicates the production packer integrity has not been compromised. To abandon the perforations behind the straddle packers and tubing,the original plan would have been to pull the production mandrel at 10,575' MD and squeeze cement into those perforations.Without being able to get past the tubing collapse,this method is no longer possible and would require milling up the packer in order to achieve full access.There also is the risk of additional collapse points between the known collapse and the production packer,thus jeopardizing recovery. In regards to hydrocarbon bearing zones, please find the following information: • Due to truncation from the LCU,the Put River and Ivishak reservoirs are absent,leaving the Lisburne as the only hydrocarbon bearing zone. • TLSB in this well is 10,643' MD(8,646'TVDss) • Original cement records from L5-12 construction indicate 146.26 bbl of cement were pumped in the 12-14"OH x 9-5/8"casing annulus.Assuming an open hole volume increase/ washout of 40%(13.15"effective ID),this places TOC at 8,771' MD(7,020'TVDss). At this time,we are proposing an alternative plan to P&A the parent L5-12 wellbore as follows: • Set a plug in the tubing at 10,300' MD. • Pull GLV#6 at 10,259' MD • Punch holes in the tubing at 10,275' MD • Pump 78.8 bbls of 15.8 ppg Class G cement down tubing and squeeze 72.8 bbls into the IA, leaving 6 bbls in the tubing. • Drift and tag through tubing after cement has set up to confirm TOC. • This will provide a 1000' MD cement plug in both the tubing and IA, put TOC at 9,300' MD (7,430'TVDss),and satisfy the AOGCC's requirement of having cement 500'above the hydrocarbon bearing zone. I want to make sure you have enough information to evaluate this proposal,so I apologize in advance for the lengthy email. If there is any other information you need from me,please don't hesitate to contact me. I look forward to hearing your response. Thank you, James Niedermeyer Drilling Engineer BP Exploration,Alaska Desk:907-564-4874 Cell:907-205-2357 James.Niedermeyer@bp.com • • • -Loepp, Victoria T (DOA) From: Niedermeyer,James <James.Niedermeyer@bp.com> Sent: Monday,January 18, 2016 9:40 AM To: Loepp, Victoria T (DOA) Cc: Lastufka,Joseph N; Roach, Frank Subject: Variance Request: PBU L5-12(PTD 187-010, Sundry 316-006) Plug for Redrill Attachments: L5-12 P&A Variance Request.docx; L5-12 P&A AOGCC.pdf Victoria, Please see attached Variance Request for well L5-12. Feel free to contact me with any questions or concerns. Thanks, James Niedermeyer Drilling Engineer BP Exploration,Alaska Desk:907-564-4874 Cell:907-205-2357 James.Niedermever@bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.Ioepp(a alaska.gov] Sent: Thursday, January 07, 2016 9:27 AM To: Niedermeyer, James Subject: PBU L5-12(PTD 187-010, Sundry 316-006) Plug for Redrill James, regulations The proposed plug does not meet regulation. Please reference 20 AAC 25.112. Any deviation from the eg ations would require a variance. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.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 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 work) the initial reviewer will cross out that erroneous entry and initial the ,/ 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 Kv The drilling engineers will serve as quality control for steps 1 and 2. (QC) \i 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. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scan ned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Origi hals: [] Other: DIGITAL DATA Diskettes, No. [] Other, No/Type -ro.,,,,..,,,,,,.s..lOI ORGANIZED BY; BEVERLY NOTES: BREN VINCENT SHERYL MARIA LOWELL Project Proofing [3 OVERSIZED (Scannable) ,., D Ma ps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) , Logs of various kinds [] Other DATE; Is~ [] Staff Proof By: Date: PROOFED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ SCANNED BY.' ~REN VINCENT SHERYL MARIA LOWELL Is~ RESCANNED BY: BEVERLY BREN VINCEN S~"~Y~ARIA LOWELL General Notes or Comments about this file: PAG ES: Quality Checked {done) Rev1 NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 44 \ NW JL :t.. 1 8 ZU1l1 July 6, 2011 Mr. Tom Maunder D ° Alaska Oil and Gas Conservation Commission �j 1 333 West 7 Avenue Anchorage, Alaska 99501t� Subject: Corrosion Inhibitor Treatments of GPMA L5 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L5 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Lisburne 05 Date: 05/30/11 T Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date 15-01 1890090 500292190800 0.4 NA 0.4 na 1.7 5/23/2011 15-04 1861910 500292167900 Sealed conductor NA NA NA NA NA 15-05 1870690 500292174200 Sealed conductor NA NA NA NA NA L5-08 1870300 500292171100 Sealed conductor NA NA NA NA NA 15-09 1901240 500292208600 Sealed conductor NA NA NA NA NA L5-12 1870100 500292169400 Sealed conductor NA NA NA NA NA L5-13 1831840 500292105900 0.6 NA 0.6 NA 1.7 5/24/2011 L5-15 1881090 500292186800 Sealed conductor NA NA NA NA NA L5-16 2060830 500292170001 Sealed conductor NA NA NA NA NA 15-17 2042230 500292188901 0.1 NA 0.1 NA .85 5/30/2011 15-18 1900830 500292206000 2.7 NA 2.7 NA 11.9 5/30/2011 L5-19 1900680 500292205200 P&A 9/24 NA NA NA NA NA 15-21 1870570 500292173200 Sealed conductor NA NA NA NA NA L5-23 1900500 500292203900 Sealed conductor NA NA NA NA NA L5-24 1850860 500292132700 0.1 NA 0.1 NA .85 5/30/2011 L5-25 1881350 500292188600 Sealed conductor NA NA NA NA NA 15-26 1901100 500292207900 1 NA 1 NA 3.4 5/30/2011 15-28 2060700 500292171701 Sealed conductor NA NA NA NA NA L5-29 , 1870450 500292172400 Sealed conductor NA NA NA NA NA L5-31 1901300 500292209100 0.8 NA 0.8 NA 3.4 5/28/2011 L5-32 1881020 500292186100 0.3 NA 0.3 NA .85 5/28/2011 L5-33 1890470 500292194300 0.3 NA 0.3 NA .85 5/28/2011 L5-34 1980850 500292288300 0.3 NA 0.3 NA .85 5/28/2011 15-36 1890380 500292193300 0.6 NA 0.6 NA 1.7 5/28/2011 1 MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ARCO Alaska, Inc. Post Office Box 100360 '~ Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 30, 1993 'Ms. Joan Miller AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RE: Delinquent Subsequent Sundry Notices Dear Madam: Enclosed are delinquent subsequent sundry notices for the Lisburne Oil Pool. Please refer to the list below. Form 10-404 W¢l Permit Approval Date Description Comment L1-15 89-132 90-314 5/8/90 Stimulate Completed L1-30 90-18 90-798 11/1/90 Pe rf/Stimu late " L2-06 83-47 9-928 10/20/89 Install Kinley Buttons " L2-10 87-85 90-850 12/3/90 Stimulate " L2-16 87-97 90-865 12/13/90 Stimulate Job Canceled L2-18 87-118 90-851 12/13/93 Pe rf/Stimulate Completed L2-30 85-9 9-955 11/1/89 Install GLVs " L3-01 86-161 90-779 10/16/90 Acid Wash " L3-28 89-66 90-807 11/9/90 Perf/Stimulate " L4-03 88-67 91-248 8/27/91 Perf/Stimulate " L4-15 83-71 91-308 10/16/91 Stimulate " L4-30 88-101 90-800 10/24/90 Stimulate " L5-12 87~10 90-781 10/16/90 Stimulate " L5-21 87-57 90-609 8/9/90 Stimulate " .~ // /¢.>~, ~'~"' ;-.-.~ ~,' :', .? ~-,' "/'" ~",? ' .? i~'? / '- ;?~" ~:"~'~ ~- ~'~' Sincerely, George K. Phillips Engineering Supervisor Lisburne/Point Mclntyre Engineering GKP:LSL:jb R ECE \IE D Enclosures cc: R.G.M. Oba, ARCO Alaska, Inc. (Without Enclosures) A U G - ,B Alaska OiJ & Ga:~, Coils. Corl~l"nissiorl Anch0ra§e ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMMb,ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Pull tubing Alter casing . Repair well 2. Name of Operator AR(;:;O Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 4. Location of well at surface 1668' FSL, 15' FWL, Sec. 1, T11N,R15E, UM At top of productive interval 1426' FNL, 1347' FEL, Sec.12, T11N,R15E, UM At effective depth 1567' FNL, 1215' FEL, Sec.12, T11N,R15E, UM At total depth 1579' FNL, 1205' FEL, Sec.12, T11N,R15E UM 12. Present well condition summary Total Depth: measured 1 1 242 true vertical 9 2 6 6 feet feet Plugging Perforate Pull tubing Other 6. Datum elevation (DF or KB) RKB 60' 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L5-12 9. Permit number/approval number · 87-1 0/90-781 10. APl number 50-029-21694 11. Field/Pool LISBURNE OIL POOL Plugs (measured) NONE feet Effective depth: measured 111 97' feet true vertical 9224' feet Junk (measured) NONE Casing Length Size Structural Conductor 8 0' 2 0" Surface 83 7 3' 1 33/8" Intermediate Production 1 0 6 0 9' 95/8" Cemented Measured depth 1860# Poleset 119' 2450 sx ASIII & 4206' 600 sx Qa~sG Tcpj dow/115 sx ASI 585 sx Qa~sG& 300 sx ASI 1 0 64 5' True vertical depth 119' 3999' 8707' Liner 8 1 7' 7" 332 sxQassG 1 0425'- 1 1 242' 8503'-9224' Perforation depth: measured 10668'-10682', 10688'-10698', 10856'-10878', 10898'-10992' true vertical 8723'-8741', 8747'-8756', 8904'-8825', 8943'-9031 2205' Tubing (size, grade, and measured depth) 7 ,, , /8, L-80, tbg w/tail @ 10792 Packers and SSSV (type and measured depth) 10705' 10367' & SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo zones 5 & 4. Treatment description including volumes used and final pressure Please refer to the attached 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 100 1819 0 50 . . 1 92 ~"' 465 1 1 5 0 481 495 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the for_egoing is true and correct to the best of my knowledge. ned George K. Phillips Title Engineering Supervisor-Lisb/Pt Mc Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE Lisburne Well L5-12 Stimulation Procedure 11/22/90 Rigged up slickline. (8900' SS). Ran static pressure survey , 3229 psi at 10700' MD 12/06190 Shut in well for stimulation. 12/09/90 Rigged up service company to pump CFA stimulation. Acidized Wahoo 5 and 4 with the following stimulation fluids: · 100 BBL 15% Gelled HC1 · 900 BBL 40 PPTG Gelled Water · 1200 BBL Emulsified Acid · 1100 BBL Crude · 75 BBL Diesel Released service company. production valves). 12/13/90 Opened well to flow. (Well control was provided by surface chokes and SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 !-2175 OCT ! ? 1990 ~$E REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger Gentlemen: ~-~f~ ~ Enclosed are~BL_printsof the Injection Profile Spinner Survey, run 1; 10/14/~. Company .CONOCO, Inc, . , Well CFP-2 Field Milne Point Additional prints are being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: .. George Lamb - OF 2016 PER Counly North State Alaska _L_BL_prints, 1RF Sepia CONOCO_ Thc: · 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. _6___D_e s t a Drive Midlan. d,. TX 79710 Attn: John Carro] *(915/685-5600) _l_JlL_prints, 1 RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 ~ttn: Priscilla MacLeroy *(415/842-1000) /AlaS~ Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, ~, ~9501 ' ' '/ ~~ John Boyle The film is_~eturned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Received by: Date: f~rT O~ ~ tQQa 'AJaBk8 Oil J Gas ~. ~mmi~iofl Ve~ truly yours, ~e SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SWS-- 1327-F STATE OF ALASKA ALASKA el L AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ~ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimula-~-X Pull tubing __ Variance __ .Perforate _._ Other .__ 2. NameofOperator ARCO Alaska~ Inc. 3. Address 99510- P. O. Bo× 100360 Anchorage, AK 0360 4. ~cationCwellatsudace 1668' FSL, 15' FWL, Sec, 1, TllN, ~topofproductiveinterval 1426' FNL, 1347' FEL, Sec. 12, ~ectivedepth 1567' FNL, 1215' FEL, Sec. 12, ~totaldepth 1579' FNL, 1205' FEL, ,Sec. 12, 5. Type of Well: Development Exploratory Stratigraphic Service R15E, UM Ri5E~ UM R15E, UM R15E, UM 12. Present well condition summary Total depth: measured 11242 ' MI) true vertical 9266 ' %'1/'I) feet Plugs (measured) None feet 6. Datum elevation (DF or KB) RKB 60~ feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Welt number L5-12 9. Permit number 7-248 10. APl number 50-- 0259-21694 TllN, TllN, TllN, 11. Field/Pool Lisburne Oil Pool R CEIVED feet Junk(measured) None feet Effective depth: measured 1'1197 ' MD true vertical 9224'TVD ,,~,a 0it & Gas Cons. O0mmis~i., Casing Length Size Cemented Measured depth ~l~'~¢f.~.ical depth Structural - - ' Conductor 80' 20" 1860¢ Poleset 119' MD 119' TVD Suflace 8373' 13-3/8" 2450 sx AS III & 4206~ MD 3999' TVD Intermediate 600 sx Class G, Top job w/l15 sx AS I Production 10609' 9-5/8" 585 sx Class G & 10645' MD 8707' TVD Liner 817' 7" ~ sx ~ sI sx a s G 10425'-11242' MD 8503'-9224'TV; Perforation depth: measured 10668'-10682'MD, 10688'-10698'~, 10856'-10878'MD, 10898'-10992'MD true vertical 8723'-8741' TVD, 8747'-8756'TVD, 8904 '-8825'TVD, 8943 '-9031'TVD Tubing (size, grade, and measured depth) 2-7/8", L-80, tbg w/tail @ 10792' Packers and SSSV (type and measured depth) 18 ~kr ¢ 10705'. ~g pkr ¢ 10367'. & SSSV 13. Attact~ments DescriPtion summ~ry pf_ proposal X_,~ · - . @ 2205' Det_ai.led~operati0ns pro_gram _..., B.OP ,,-ketchX~X 14. Estimated date for commencing operation 10-16-90 16. If proposal was verbally approved Name of approver 17. I hereby certi~ythat the fo_.regC'~g,j~true / ~/ '-"-- \,- 15. Status of well classification as: OilXX Gas Date approved Service Suspended __ and correct to the best of my knowledge. Title Senior Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ z~<~L~ Mechanical Integrity Test __ Subsequent form reqUired 10- Date 10/9/90 ORIGINAL $16NBI I¥ LONNIE C. SMITH , Approved by order of the Commission I Approva, No, ¢ ¢ _ 7~/ Approved Copy Returned lc I/ $ommi~sioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Proposed Stimulation Lisburne - Well L5-12 2e ge 4~ Shut in well. Rig up service company to pump stimulation fluids. Well control provided by surface chokes and production valves. Closed Fracture Acidize Wahoo 4 and 5 with the following stimulation fluids: · 100 BBL 15% gelled HC1. · 800 BBL 40 pptg gelled water. · 75 BBL 15% slick HC1. · 1,200 BBL emulsified acid 30:70 mixture [15,120 gallons (360 BBL) crude/35,280 gallons (840 BBL) 10% HC1] (visc.=150-180 cp). · 1,100 BBL) crude. · 375 BBL diesel. (Maximum treating pressure: 6500 psi) Release service company and open well to flow. ADDENDUM WELL: 3/09/87 4/2:z/87 5/22/87 5/24~87 5/25/87 L5-12 ND big bore vlv, tst tbg spool & csg head flange. Leak between outside of 9-5/8" packoff & tbg spool. Remove tbg spool, pull packoff. Instl new packoff. NU tbg spool & tst to 5000 psi; OK. NU tree. Instl hsr. Arctic Pak w/300 sx AS I & 120 bbls Arctic Pak. Tst OK. Pull BPV. Pull dummy GLV. Displ tbg w/diesel. Re-rn dummy GLV. Tst ann to 1000 psi; OK. Secure well & wait on frac. Frac Wahoo 4 zone perfs 10,856'-10,878' and 10,898'- 10,922' in seven stages per procedure dated May 22, 1987, as follows: Stage 1: 10 bbls diesel w/10% Musol @ 8 BPM, 2310 psi Stage 2: 5 bbls 15% gelled acid @ 8 BPM, 2310 psi Stage 3: 60 bbls 15% gelled acid w/100 balls @ 8 BPM, 2310-1800 psi Stage 4: 5 bbls 15% gelled acid @ 8 BPM, 1800 psi Stage 5: 100 bbls slick diesel w/RA mat @ 8 - 10 BPM, 1800 - 2150 psi Stage 6: 60 bbls slick diesel w/RA mat @ 8-10 BPM, 1800-2150 psi Stage 7: 180 bbls slick diesel @ 8 BPM, 2250-2360 psi (RA Material: 7Mc Gold-198 2.5 Day Half Life) Fluid to Recover: 350 bbls diesel; 70 bbls acid. Average Pressure: 2100 psi Sand in Casing: 0 Job com~.~ete @ 1340 hrs, 5/24/87. Open well f/6 hrs; no flow. RU DA E-Ln, rn temp/Diff Temp/GR/BHP f/11,076'-10,600'. Acidize Wahoo 4 as per Frac/Stim Summary, RD Dowell. RIH w/E-Ln 1 hr after acid job & rn Temp/Diff Temp/GR; main fluid entry thru perfs. Lower perfs tak'g more fluid than upper perfs. Drop to 11,000', take static BHP of 4552 psi. Open well up on choke; steady surf decline to 0 psi; well died. Leave well open; started flowing after 1 hr. Cont to flow Wahoo 4 perfs on open choke. ADDENDUM WELL: L5-12 5/26/87 5/27/87 5/28/87 5/29/87 thru 5/30/87 6/01/87 6/08/87 Cont flowing Wahoo 4 perfs. Cont flowing Wahoo 4 perfs. RU CTU, RIH to 2000', start N_. Unload 153 bbls fluid. RIH to 10,650', jet 4.5 hrs &Zrec'd 67 bbls fluid, POOH. POOH w/CTU & RD. Open well to flow on open choke. Flow tst well. RU Otis WL. RIH w/BNP blanking plug, att to set @ 10,780' w/o success, POH. Redress rn'g tl. RIH & set blanking plug in BNG nipple @ 10,780', POOH. RIH, retrv equalizing prong f/dummy vlv. Retrv dummy vlv f/GLM @ 10,350'. Set BPV. RD Otis. RU Otis, tst lubr; OK. RIH, tag BPI slv@ 10,632', wrk loose, POH, RD lubr. RIH, log CCL f/10,750'-10,650'. Fire cutter @ 10,723'. RIH w/expended cutter to 11,112', recorded 7" csg colrs, POH, RD Gearhart. RU Otis, retrv orifice ck vlv @ 10,234'; tbg press dropped to 500 psi, POH. RIH W/RKED vlv, set @ 10,234', POH, RD Otis. Release well to Production. Drilling Supervisor Date ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage~ A~ask~ 99510-0360 Telephone 907 276 1215 SAMPLE TRANSMITTAL TO: STATE OF ALASKA OIL & GAS CONSERVATION COMM. 3001 PORCUPINE DR. ATTN:JOHN BOYLE DATE:2- 16-89 HAND-CARRIED OPERATOR: ARCO NAME:L5- 12 SAMPLE TYPE: STATE CORE CHIPS SAMPLES SENT: 10761' 10765' 10762' 10826' 10763' 10844' 10764' 11018' NUMBER OF BOXES:I SENT BY: d. L. COLLINS UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: BAYVlEW GEOLOGIC FACILITY ABV-IO0 RECEIVED ARCO Alaska, Inc. is a Subsidiary of Atlanii~tRici~fieidC~:i~ ~- ;!, ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage, A~aska 995:10-03~0 Telephone 907 276 !215 SAMPLE TRANSMITTAL TO: STATE OF ALASKA OIL AND GAS CONSERVATION COMM. 3001 PORCUPINE DR. ANCH., AK 99501 ATTN: JOHN BOYLE DATE: 2-7-89 AIRBILL #: AFT#: CHARGE CODE# HAND-CARRIED OPERATOR: ARCO SAMPLE TYPE: CORE CHIPS SAMPLES SENT: NAME: Lisburne L5-12 NUMBER OF BOXES: 16 10686-10712 10827-10832 10713-10749 10750-10760 10766-10775 10776-10793 10794-10812 10813-10825 10827-10832 1083,3-10843 10845-10860 AT ONE FOOT INTERVALS THESE SAMPLES WILL BE SENT LATER: 10861-10886 10887-10910 10911-10935 I 9 711 0 1 1 0 0 1 "1 10 1 5~"~~ I I 0 1 9 I I 0 5 11050 1107 11076 11100 11100 I I I 1~:,~,. 10761 10765 10762 10826 10763 10844 10764 11018 SENT BY: TERESA GORUP UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED ARCO ALASKA, INC. P. O. BOX ~00360 ANCHORAGE, AK. 99510 ATTN: ABV-100 ~ DATE' c~~ ~'~'~_~. ARCO Alaska, Inc, is a Subsidiary of Atla~icRic?ifi-,!d;; ~ r:: ~,¢' DATE' FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Finals ~. L2-10 Collar Log 9-29-87 Run I 5" WAI L2-10 Collar Log 12-11-87 Run I 5" WAI L2-10 Injection Profile 3-16-88 Run I 5" Sch L2-16 Collar Log 11-23-87 Run I 5" WAI L2-21 Collar Log 10-9-87 Run I 5" DA L3'-12 Production Profi'le 3-~-88 run 2 5" Camco Collar Log 10-15-87 'Run I 5" DA L5-29 Collar Log 10-2-87 Run I 5" WAI , as a I as Cons. Commission PLEASE SIGN AND RETURN TO~r~,~-~MBERT ^,co ^L,S,, NC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON TRANSMITTIAL # --4Q4.--- STANDARD STATE OF ALASKA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~MMISSION ~ 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. 87-10 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21694 4. Location of well at surface 9. Unit or Lease Name 1668' FSL, 15' FWL, Sec. 1, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1426' FNL, 1347' FEL, Sec.12, TllN, R15E" UM L5-12 At Total Depth 11. Field and Pool 1579' FNL, 1205' FEL, Sec.12, T11N, R15E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.} 16.Lease Designation and Serial No. Li sburne 0i 1 Pool RKB 60' I ADL 28320 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. i 15. Water Depth, if offshore 116. No. of Completions 01/30/87 02/24/87 05/24/87* I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back DePth (MD+I-VD) i9. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 11242'MD, 9266'TVD 11197'MD, 9224'TVD YEsX~ NO[] 2205' feetMDI 1900' (approx) 22. Type Electric or Other Logs Run DIL/Spectralog, Z-Den/CN/CR/Cal, Acoustilog/WF/CR, FMT/GR, Temp/Diff. temp/GR/BHP, CBL, Gyro, CCT~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2U" 91.5# H-40 Surf 119' 30" 1860# Poleset 13-3/8" 72.0# K-55/L-80 Surf 4206' 17-1/2" 2450 sx AS Ill & 600 sx Class G Top job w/ll5 sx AS I 9-5/8" 47.0# L-80 Surf 10645' 12-1/4" 585 sx Class G & 300 sx AS i 7" 29.0# L-80 10425' 11242' 8-1/2" 332 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) 2-7/8" 10792' 10705' (WLM) & 10367' 10668'-10682'MD 8728'-8741 'TVD 10688'-10698'MD 8747'-8756'TVD 26. ACID, FRACTURE, CEMENT SQUE'I~'ZE, ETC. **10856'-10878'MD 8904'-8825'TVD SL~P 0 ? ]~l~l DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED *'10898'-10992'MD 8943'-9031'TVD See attached Addend im~ dated 7/21/87 for fracture dal;a, PerfOrated w/0.5 spf Alaska Oil & Gas Cons. Con'-' **Perforated w/1 spf /[nchorago ... 27N/A PRODUCTION TEST ' Date First Production Method of Operation {Flowing, §as lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Description. *Note: Drilled RR 3/2/87. Perforated well & ran tubing 5/21/87. Perforated well & workover performed 6/6/87. Fractured well 5/24/87. Form 10-407 WCS/.50 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 291 : -i:~:.':: 30. !,., ',. '. GEOLOGIC MARKERS FORMATION TESTS ~:: NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wahoo Zone 6 106/+/+' 8706' N/A Top Wahoo Zone 5 10717' 8774' . . Top Wahoo Zone 4 10818' 8868' Top Wahoo Zone 3 11018' 9056' Top Wahoo Zone 2 11084' 9118' Top. Wahoo Zone 1 11135 ' 9166 ' i '. 31. LIST OF ATTACHMENTS Core Description, Addendum (dated 7/21/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~//~/7~ J ~~ Title Associate Engineer 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- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Well L5-12 Lisburne Core Description Core #1 10,685-10,707 Cut 22' Recovered 22' 2/15/87 4.6' Interlayered chert and dolomitic skeletal grain- stone 17.4' Cherty limestone, skeletal §rainstone Core #2 10,707-10,740 Cut 33' Recovered 31' 2/16/87 14.4' Interbedded dolomitic limestone and dolomite; skeletal and non-skeletal grainstone interbedded wi th dolomitic mudstone 4.2~ Olive-gray shale 13.4' Dolomite limestone and limestone; skeletal and non-skeletal grainstones 2. O' No Recovery Core #3 10,740-10,765 Cut 25' Recovered 24' 2/16/87 24.0' Interbedded dolomitic limestone and limestone; skeletal and non-skeletal wackestone to grainstone 1.0' No Recovery Core #4 10,765-10,825 1.6t 6.6' 4.4' Chert Limestone; Limestone; Cut 60' Recovered 60' ~~2~~7 SEP o 2'. non-skeletal §rainstone Alaska Oil & Gas Cons. Commisslor~ skeletal 9rainstone Anchorage ll .2' Shaly dolomite; interbedded skeletal wackestone, packstones and §rainstones 4.1w Limestone; non-skeletal grainstone 5.31 Dolomite; interbedded undifferentiated mudstones to packstones 1.1' Chert 9o91 Dolomitic limestone; interbedded skeletal and non-skeletal grainstones 5.3I 1.4' 7.6' 1.4' Dolomite; skeletal grainstone Shale; ol ive-green Interbedded limestone and dolomite; mudstone to skeletal grainstones; shaly at base O1 ive-green shale Core #5 10,825-10, 1.3' 1.7' 7.0' 835 Cut 10' Recovered 10' Limy, cherty, olive-green shale Silty dolomite; mudstone Cherty limestone; non-skeletal feet is rubblized 2/18/87 grainstone; last 4 Core #6 10,835-10,897 4.5' 6.0' 13.0' Cut 60' Recovered 62' Limestone; non-skeletal grainstone 1 .0' 5.1' ll .2' 0.7a 1.5' 0.4' ll.3' 2.2' 1.2' 2.6' 1.3' 2/19/87 Limestone; mudstone Dolomitic limestone and limestone; non-skeletal grainstone O1 ive-green shale Interbedded Silty, shaly dolomite, shale and chert Interbedded non-skeletal and dolomitic limestone and dolomite Green shale Dolomitic limestone; skeletal grainstone Green shale Dolomitic limestone; skeletal grainstone Shaly dolomitic; mudstone to wackestone Green shale Dolomite; mudstone I E. EIVED Limestone; skeletal grainstone SEP o ?. ib l /klask~. 0il & Gas Cons. Commissior~ Anr~horage Core #7 10,897-10,957 Cut 60' Recovered 2/20/87 14.6' Limestone; skeletal and non-skeletal grainstone 4.3' Dolomite; interbedded mudstone to skeletal packstone 20.2' Limestone; interbedded skeletal and non-skeletal grainstone to wackestone 6.2' Light greenish-gray shale 8.8' Limestone; non-skeletal grainstone 1.2' Dolomitic limestone; skeletal grainstone 3.7' Interlaminated calcareous siltstone and lime mudstone Core #8 10,957-11,046 Cut 89' Recovered 89' 2/22/87 3.3' Calcareous siltstone interbedded with greenish-gray shale and lime mudstone 6.1' Limestone; skeletal grainstone 6.0' Interbedded chert, dark gray shale, lime mudstone and lime skeletal grainstones 4.1' Dolomitic limestone; non-skeletal grainstone 1.5' Dark greenish-gray shale 0.6' Chert 8.4' Limestone; skeletal and non-skeletal grainstones 5.0' Dark-gray shale 15.0' Dolomitic limestone and limestone; interbedded non-skeletal and skeletal wackestone to grainstone 11.0' Silty, Dark-gray shale 11.3' Limestone; interbedded skeletal and non-skeletal grainstones 2.9' Dark greenish-gray shale 5.3' Cherty, lime grainstone and_s~t~; last 3 feet rubble Core #9 ll ,046-11,113 20.9' 5.4 8.5 5.4 8.3 7.5 1.1 10.5' Cut 67' Recovered 67.9' 2/23/87 Limestone; interbedded skeletal and non-skeletal grainstones Dark gray shale Limestone; non-skeletal grainstone Interbedded shale, lime packstone and chert Dark greenish-gray shale Limestone; skeletal grainstone Interlaminated lime grainstone and shale Limestone; skeletal grainstone; several thin layers of dark gray shale near base $ UB.$ URFA CE DIRECTIONAL SURVEY F~IUIDANCE [~ONTINUOUS r-fi OOL Company _ Well NameL5-12(1668' Field/Location PRUDHOE ARCO ALASKA~ INC. FSL,15' FWL,SEC 1 ,T11N,R1 5E,UM) BAY/LISBURNE POOL, RECEIVED NORTH SLOPE, ALASKA Job Reference No. 72218 LogGed BT RUBENSTEIN JUL- 2:1987 Oil & Gas Cons. Commissio~ Anchorage Date _ 07-MAR-87 Computed By: KRUWELL GcT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. L$-12 METHODS OF ~OMPUTATION PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,~LASKA SURVEY DATE: 07-MAR-BT ENGINEER: RUBENSTEIN TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTIDN: HORIZo DIST. PROJECTED ONTO A TARGET AZIMUTH DE SOUTH 52 DEG 52 MIN EAST COMPUTATION DATE: 17-MAR-87 PAGE ARCO ALASKA, INC. L5-12 PRUOHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF S'URVEY: 07-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT,, ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH OEPTM DEPTH DEG MIN OEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE_ SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMDT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 100.00 40.00 0 7 N 81 17 W 200.00 200.00 140.00 0 11 S 64 39 W 300.00 300.00 240.00 0 13 S 44 50 W 400.00 400.00 340.00 0 12 S 38 40 W 500.00 500.00 440.00 0 13 S 37 47 W 600.00 600.00 540.00 0 13 S 39 32 W 700.00 700.00 640.00 0 16 S 32 18 W 800.00 799.99 739.99 0 16 S 27 57 W 900.00 899.99 839.99 0 16 S 22 0 W 0.00 0.00 0.00 N 0.00 E -0.14 0.00 0.07 N 0.13 W -0.29 0.00 0.01 N 0.36 W -0.40 0.00 0.20 S 0.66 W -0.42 0.00 0.48 S 0.90 W -0.43 0.00 0.76 S 1.11 ~ -0.43 0.06 1.07 S 1.35 W -0.42 0.00 1.42 S 1.61 W -0.36 0.00 1.85 S 1.86 W -0.26 0.00 2.27 S 2.05 W 0.00 N 0 0 E 0.15 N 62 44 ~ 0.36 N 89 2 W O. 69 S 72 52 1.02 S 61 41 I~ 1.35 S 55 38 W 1.73 S 51 40 W 2.15 S 48 29 W 2.62 S 45 5 W 3.06 S 42 3 W 1000.00 999.99 939.99 1100.00 1099.99 1039.99 1200.00 1199.99 1139.99 1300.00 1299.99 1239.99 1400.00 1399.99 1339.99 1500.00 1499.99 1439.99 1600,00 1599.99 1539.99 1700.00 1699.99 1639.99 1800.00 1799.99 1739.99 1900.00 1899.98 1839.98 0 12 S 17 34 W 0 11 S 8 51 W 0 7 S 2 44 E 0 6 S 20 44 E 0 11 S 51 9 E 0 16 S 75 26 E 0 18 S 87 57 E 0 17 N 86 ~,6 E 0 14 N 84 52 E 0 23 N 83 16 E -0.13 0.13 2.68 S 2.20 W 0.01 0.00 3.02 S 2.28 W 0.14 0.05 3.26 S 2.29 W 0.31 0.01 3.49 S 2.25 W 0.56 0.05 3.70 S 2.09 W 0.95 0.15 3.86 S 1.74 W 1.40 0.00 3.93 S 1.22 W 1.80 0.00 3.92 S 0.71 W 2.14 0.00 3.88 S 0.26 W 2.48 0.47 3.83 S 0.21 E 3.47 S 39 Z1 W 3.78 S 37 2 W 3.98 S 35 6 W 4.15 S 32 49 W 4.25 S 29 30 W 4.23 S 24 12 W 4.11 S 17 17 W 3.98 S 10 12 W 3.89 S 3 48 W 3.84 S 3 7 E 2000.00 1999.98 1939.98 2100.00 2099.97 2039.97 2200.00 2199.97 2139.97 2300.00 2299.96 2239.96 2400.00 2399,95 2339.95 2500.00 2499.88 2439.88 2600.00 2599.58 2539.58 2700.00 2698.88 2638.88 0 38 N 80 26 E 039 N 72 48 E 0 36 N 50 52 E 0 47 N 35 40 E 1 24 S 79 31 E 2 57 S 40 54 E 5 47 S 55 31 E 7 46 S 56 ~,6 E S 54 16 E S 56 I5 E 2800.00 2797.65 2737.65 10 6 2900.00 2895.71 2835.71 12 37 3.15 0.17 3.71 S 1.15 E 3.85 0.00 3.43 S 2.24 E 4.36 0.40 2.99 S 3.21 E 4.41 0.00 2.03 S 3.99 E 5.24 1.98 1.45 S 5.47 E 8.81 2.21 3.69 S 8.26 E 16.39 2.62 8.61 S 14.04 E 28.05 2.48 14.96 S 23.86 E 43.61 2.31 23.87 S 36.63 E 63.18 3.27 35.09 S 52.68 E 3.88 S 17 I1 E 4.09 S 33 9 E 4.39 S 47 6 E 4.48 S 63 0 E 5.66 S 75 7 E ] 9.04 S 65 55 E 16.47 S 58 29 E 28.16 S 57 54 E 43.72 S 56 54 E 63.30 S 56 19 E 3000.00 2992.66 2932.66 15 37 3100.00 3088.24 3028.24 18 27 3200.00 3182.32 3122.32 21 9 3300.00 3274.54 3214.54 24 21 3400.00 3364.55 3304.55 27 16 3500.00 3452.06 3392.06 30 30 3600.00 3536.96 3476.96 33 10 3700.00 3619.53 3559.53 35 28 3800.00 3699.82 3639,82 37 50 3900.00 3777.22 3717.22 40 42 S 58 23 E 87.54 2.56 S 57 29 E 116.77 2.96 S 55 29 E 150.57 2.95 S 54 36 E 189.15 2.74 S 54 43 E 232.68 2.85 S 54 27 E 281.01 3.06 S 53 51 E 333.82 2.46 S 56 15 E 390.16 2.68 S 57 55 E 449.58 2.65 S 57 31 E 512.64 3.23 48.14 S 73.36 E 87.74 S 56 43 E 63.64 S 98.28 E 117.09 S 57 4 E 82.37 S 126.50 E 150.95 S 56 55 E 104.55 S 158.10 E 189.54 S 56 31 E 129.75 S 193.62 E 233.07 S 56 10 E 157.71 S 233,06 E 281.41 S 55 54 E 188.72 S 275.82 E 334.20 S 55 37 E 221.17 S 321.92 E 390.58 S 55 30 E 253.40 S 372.05 E 450.15 S 55 44 E 287.12 S 425.61 E 513.40 S 55 59 6 COMPUTATION DATE: 17-MAR-87 PAGE 2 ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURVEY: 07-MAR-ST KELLY BUSHING ELEVATION: 60.00 ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGD~LAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3851.90 3791.90 42 20 4100.00 3924.68 3864.68 44 32 4200.00 3994.79 3934.79 46 9 4300.00 4064.01 4004.01 46 7 ~400.00 4133.71 4073.71 45 28 4500.00 4204.13 4144.13 45 6 4600.00 4274.81 4214.81 44 52 4700.00 4345.7'7 4285.77 44 47 4800.00 4416.53 4356.53 45 15 4900.00 4486.55 4426.55 45 51 S 56 9 E 578.98 S 55 46 E 647.44 S 56 2 E 718.65 S 55 52 E 790.71 S 55 36 E 862.33 S 55 16 E 933.25 S 54 55 E 1003.94 S 54 49 E 1074.36 S 54 31 E 1144.98 S 53 55 E 1216,35 1.46 2.63 0.49 0.51 0.82 0.14 0.53 0.23 0.72 0.55 323.47 S 481.30 E 579.89 $ 56 5 E 361.95 S 538.04 E 648.46 S 56 4 E 401.90 S 597.10 E 719.76 S 56 3 E 442.27 S 656.91 E 791.92 $ 56 2 ~- 482.64 S 716.19 E 863.63 S 56 1 522.90 S 774,66 E 934.63 S 55 58 E 563.36 S 832.70 E 1005.37 ~ 55 55 ~ 603.92 S 890.31 E 1075.81 S 55 50 f 644.75 S 947.98 E 1146.46 S 55 46 E 686.47 S 1005.92 E 1217.83 S 55 41 E 5000.00 4556.06 4496.06 46 2 5100.00 4525.27 4565.27 46 17 5200.00 4694.78 4634.78 45 31 5300,00 4764.89 4704.89 45 29 5400.00 4835.21 4775.21 45 11 5500,00 4905.82 4845.82 44 59 5600,00 4976.54 4916.54 44 58 5700.00 5047.63 4987.63 44 30 5800'00 5119.03 5059.03 44 18 5900.00 5190.91 5130.91 43 52 S 53 32 E 1288.24 S 53 7 E 1360.41 S 53 0 E 1432.31 S 53 4 E 1503.62 S 52 59 E 1574.71 S 52 56 E 1645.52 S 52 44 E 1716.22 S 52 42 E 1786.55 S 52 54 E 1856.57 S 52 47 E 1926.08 0.34 0.47 0.95 0.56 0.25 0.13 O.Wl 0.21 0.55 0.51 729.02 S 1063.86 E 1289.68 S 55 34 E 772.11 S 1121.76 E 1361.80 S 55 27 E 815.36 S 1179.20 E 1433.64 S 55 20 E 858.23 S 1236.18 E 1504.89 S 55 13 E 900.97 S 1292.99 E 1575.94 S 55 7 E 943.63 S 1349.51 E 1646.70 S 55 2 E 986.32 S 1405.87 E 1717.35 S 54 56 E 1028.94 S 1461.81 E 1787.63 S 54 51 E 1071.28 S 1517.58 E 1857.60 S 54 46 E 1113.22 S 1573.02 E 1927.08 S 54 42 E 6000.00 5262.83 5202.83 44 3 6100.00 5334.35 5274.35 44 43 6200.00 5405.08 5345.08 45 4 6300.00 5475.83 5415.83 45 2 6400.00 5546.08 5486.08 45 47 6500.00 5615.27 5555.27 46 39 6600.00 5683.45 5623.45 47 25 6700.00 5750.67 5690.67 47 59 6800.00 5817.46 5757.46 48 17 6900.00 5883,34 5823.34 49 14 S 52 ~2 E 1995.56 S 51 57 E 2065.45 S 51 45 E 2136.14 S 51 21E 2206.?9 S 50 32 E 2277.91 S 50 4 E 2350.04 S 49 21 E 2423.08 S 49 12 E 1496.97 S 48 45 E 2571.23 S 48 39 E 2646.25 0.66 0 · 7 ? 1.03 0.65 1.08 0.85 1.28 0.36 1.08 0.87 1155.27 S 1628.33 E 1996.52 S 54 38 E 1197.98 S 1683.66 E 2066.36 S 54 34 E 1241.67 S 1739.23 E 2136.98 S 54 28 E 1285.58 S 1794.60 E 2207.56 S 54 23 E 1330.40 S 1849.87 E 2278.60 S 54 16 E 1376.54 S 1905.41 E 2350.63 S 54 9 1423.78 S 1961.27 E 2423.57 S 54 1 E 1472.17 S 2017.30 E 2497.35 S 53 52 E 1520.95 S 2073.51 E 2571.53 S 53 44 E 1570.65 S 2129.99 E 1646.46 S 53 35 E 7000.00 5948.05 5888.05 50 8 7100.00 6011.23 5951.23 51 31 7200.00 6072.75 6012.75 52 27 7300.00 6132.84 6072.84 53 47 7400.00 6191.14 6131.14 54 39 7500.00 6248.85 6188.85 54 48 7600.00 6306.58 6246.58 54 42 7700.00 6364.86 6304.86 53 46 7800.00 6424.52 6364.52 53 6 7900.00 6484.54 6424.54 52 51 S 48 44 E 2722.29 S 48 48 E 2799.60 S 48 47 E 2878.24 S 48 35 E 2957.96 S 48 16 E 3038.96 S 48 26 E 3120.36 S 48 26 E 3201.78 S 49 40 E 3282.84 S 50 33 E 3363.00 S 50 17 ~ 3442.92 0.83 1.47 0.98 1.66 0.27 0.04 0.51 2.03 0.42 1.63 1620.95 S 2187.27 E 2722.43 S 53 27 E 1672.01 S 2245.59 E 2799.69 S 53 19 E 1723.95 S 2304.89 E 2878.29 S 53 12 E 1776.69 S 2364.95 E 2957.98 S 53 5 E 1830.o3 S 2425.71 E 3038.96 S 52 57 E 1884.90 S 2486.73 E 3120.36 S 52 50 E 1939.06 S 2547.85 E 3201.79 $ 52 43 E 1992.50 S 2609.05 E 3282.87 S 52 37 E 2043.84 S 2670.73 E 3363.05 S 52 34 E 2094.77 S 2732.41 E 3442.98 S 52 31 E · COMPUTATION DATE: iT-MAR-B7 PAGE 3 ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURVEY: 07-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT · ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6546.35 6486.35 50 36 8100.00 6610.69 6550.69 49 36 8200.00 6675.77 6615.77 48 55 8300.00 6742.89 6682.89 46 37 8400.00 6812.37 6752.37 45 27 8500.00 6883.60 6823.60 43 25 8600.00 6957.14 6897.14 42 10 8700.00 7032.12 6972.12 40 36 8800.00 7108.67 7048.67 39 28 8900.00 7186.71 7126.71 37 51 S 50 22 E 3521.44 S 49 56 E 3597.90 S 50 22 E 3673.75 S 51 28 E 3747.81 S 52 26 E 3819.72 S 52 15 E 3889.89 S 51 47 E 3957.64 S 51 30 E 4023.78 S 51 15 E 4088.11 S 51 6 E 4150.60 2.02 0.50 1.49 2.22 1.49 3.11 1.36 1.77 1.64 1.50 2144.92 S 2792.93 E 3521.52 S 52 28 E 2194.07 S 2851.61 E 3598.01 S 52 25 E 2242.69 S 2909.94 E 3673.88 S 52 22 E 2289.46 S 2967.42 E 3747.96 S 52 20 F 2333.71 S 3024.12 E 3819.88 S 52 20 ~ 2376.48 S 3079.75 E 3890.05 S 52 20 E 2418.21 S 3133.13 E 3957.81 S 52 20 E 2459.29 S 3185.00 E 4023.97 S 52 19 E 2499.37 S 3235.33 E 4088.30 S 52 18 E 2538.61 S 3284.01 E 4150.81 S 52 17 E 9000.00 7266.29 7206.29 36 49 9100.00 7346.80 7286.80 35 51 9200.00 7428.39 7368.39 34 51 9300.00 7510.88 7450.88 33 54 9400.00 7594.33 7534.33 32 58 9500.00 7678.69 7618.69 31 56 9600.00 7764.05 7704.05 30 49 9700.00 7850.61 7790.61 29 9 9800.00 7938.58 7878.58 27 41 9900.00 8027.51 7967.51 26 49 S 51 11 E 4211.13 S 51 9 E 4270.42 S 50 51 E 4328.21 S 50 47 E 4384.69 S 50 29 E 4439.76 S 50 4 E 4493.40 S 49 22 E 4545.42 S 48 43 E 4595.36 S 47 49 E 4642,73 S 47 58 E W688.26 0.73 1.11 0.82 0.92 1.00 1.02 1.45 1.97 1.37 0.51 2576.57 S 3331.19 E 4211.36 S 52 16 E 2613.75 S 3377.40 E 4270.66 S 52 15 E 2650.13 S 3422.34 E 4328.47 S 52 14 E 2685.85 S 3466.14 E 4384.97 S 52 13 E 2720.76 S 3508.78 E 4440.05 S 52 12 E 2755.09 S 3550.07 E 4493.72 S 52 11 E 2788.72 S 3589.85 E 4545.77 S 52 9 E 2821.53 S 3627.65 E 4595.75 S 52 7 E 2853.20 S 3663.10 E 4643.17 S 52 5 E 2883.87 S 3697.01 E 4688.77 S 52 2 E 10000.00 8116.95 8056.95 26 18 10100.00 8206.85 8146.85 25 36 10200.00 8297.30 8237.30 24 51 10300.00 8388.33 8328.33 23 59 10400.00 8480.02 8420.02 23 2 10500.00 8572.30 8512.30 22 24 10600.00 8664.95 8604.95 21 43 10700.00 8758.11 8698.11 20 57 10800.00 8851.60 8791.60 20 42 10900.00 8945.16 8885.16 lO 33 S 48 0 E 4732.87 S 47 34 E 4776.48 S 46 43 E 4818.92 S 46 0 6 4860.03 S 45 40 E 4899.65 S 45 4 E 4937.87 S 45 3 E 4975.13 S 44 14 E 5011.14 S 43 18 E 5046.17 S 42 52 E 5080.93 0.77 0.73 0.95 0.93 1.17 0.47 0.87 0.87 0.30 0.25 2913.80 S 3730.27 E 4733.41 S 52 0 E 2943.21 S 3762.70 E 4777.07 S 51 58 E 2972.24 S 3793.96 E 4819.58 S 51 55 E 3000.79 S 3823.90 E 4860.76 S 51 52 E 3028.58 S 3852.56 E 4900.46 S 51 49 E 3055.67 S 3879.98 ~ 4938.76 S 51 46 E 3082.23 S 3906.61 E 4976.12 S 51 43 E 3108.06 S 3932.22 E 5012.23 S 51 40 E 3133.71 S 3956.74 E 5047.37 S 51 37 E 3159.48 S 3980.83 E 5082.26 S 51 33 E 11000.00 9038.87 8978.87 20 16 11100.00 9132.78 9072.78 19 37 11200.00 9226.80 9166.80 20 0 11242.00 9266.26 9206.26 ZO 0 S 42 23 E 5115.31 S 42 14 E 5149.08 S 42 3 E 5182.57 S 42 3 E 51~6.69 0.55 0.37 0.00 0.00 3185.17 S 4004.50 E 5116.77 S 51 30 E 3210.60 S 4027.61 E 5150.69 S 51 26 E 3235.87 S 4050.48 E 5184.33 S 51 22 E 3246.55 S 4060.10 E 5198.51 S 51 21 E ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE~ALASKA COMPUTATION DATE: 17-MAR-87 PAGE 4'* DATE OF SURVEY: 07-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT. ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 1000 FEE~ OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE S'ECT'IaN SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0o00 -60.00 0 0 1000.00 999.99 939.99 0 12 2000.00 1999.98 1939.98 0 38 3000.00 2992.66 2932.66 15 37 4000.00 3851.90 3791.90 42 20 5000.00 4556.06 4496.06 -46 2 6000°00 5262.83 5202.83 44 3 7000.00 5948.05 5888.05 50 8 8000.00 6546.35 6486.35 50 36 9000.00 7266.29 7206.29 36 49 N 0 0 E 0.00 S 17 34 W -0.13 N 80 26 E 3.15 S 58 23 E 87,54 S 56 9 E 578.98 S 53 32 E 1288.24 S 52 42 E 1995.56 S 48 44 f 2722.29 S 50 22 E 3521.44 S 51 11 E ~211.13 0.00 0.13 0.17 2.56 1.46 0.34 0.66 0.83 2.02 0.73 0.00 N 0.00 E 0.00 N 0 0 E 2.68 S 2.20 W 3.47 S 39 21 W 3.71 S 1.15 E 3.88 S 17 11 E 48.14 S 73.36 E 87.74 S 56 43 F 323.47 S 481.30 E 579.89 S 56 5 729.02 S 1063.86 E 1289.68 S 55 34 1155.27 S 1628.33 E 1996.52 S 54 38 E 1620.95 S 2187.27 E 2722.43 S 53 27 E 2144.92 S 2792.93 E 3521.52 S 52 28 E 2576.57 S 3331.19 E ~,211.36 S 52 16 E 10000.00 8116.95 8056.95 26 18 11000.00 9038.87 8978.87 20 16 11242.00 9266.26 9206.26 20 0 S 48 0 E 4732.87 S 42 23 E 5115.31 S 42 3 E 5196.69 0.77 0.55 0.00 2913.80 S 3730.27 E 4733.41 S 52 0 E 3155.17 S 4004.50 E 5116.77 S 51 30 E 3246.55 S 4060.10 6 5198.51 S 51 21 E COMPUTATION DATE: 17-MAR-87 PAGE ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURV'EY: O7-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT · ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 60.00 60.00 0.00 0 14 N 53 59 W 160.00 160,00 100.00 0 8 S 70 11 W 260.00 260.00 200.00 0 13 S 54 10 W 360.00 360.00 300.00 0 12 S 39 17 W 460.00 460.00 400.00 0 11 S 38 7 W 560.00 560.00 500.00 0 13 S 37 35 W 660.00 660.00 600.00 0 15 S 34 32 W 760.01 760.00 700.00 0 17 S 30 33 W 860.01 860.00 800.00 0 15 S 24 23 W 0.00 0'00 0.00 N 0.00 E -0.04 1.04 0.03 N 0.03 W -0.23 0.00 0.05 N 0.26 W -0.37 0.00 0.10 S 0.54 W -0.42 0,00 0.37 S 0.81 W -0.43 0.00 0.65 S 1.02 W -0.43 0.00 0.95 S 1.26 W -0,44 0.00 1.26 S 1.50 W -0.39 0.00 1.68 S 1,76 W -0.31 0.00 2.10 S 1.98 W O. O0 N 0 0 E 0.04 N 52 13 N' 0.26 N 79 12 W 0.55 S 79 23 W 0.89 S 65 21 ~ t 1.21 S 57 44 W ' 1.57 S 52 54 W 1.97 S 49 56 W 2.43 S 46 21 W 2.89 S 43 13 W 960.01 960.00 900.00 1060.0! 1060.00 1000,00 1160.0! 1160.00 1100.00 1260.01 1260.00 1200o00 1360.01 1360.00 1300.00 1460.01 1460.00 1400.00 1560.01 1560.00 1500.00 1660.01 1660.00 1600.00 1760.01 1760.00 1700.00 1860.01 1860.00 1800.00 0 14 S 20 14 W 0 11 S 13 4 W 0 6 S 1 21W 0 8 S 10 31 E 0 9 S 37 55 E 0 14 S 68 23 E 0 17 S 84 29 E 0 17 N 88 17 E 0 14 h 84 56 E 0 15 N 83 55 E -0.18 0.21 2.54 S 2.15 W -0.06 0.00 2.88 S 2.25 W 0.09 0.00 3.18 S 2.29 W 0.24 0.01 3.41 S 2.27 W 0.44 0.00 3.61 S 2.18 w 0.78 0.10 3.81 S 1.91 W 1.22 0.06 3.91 S 1.43 W 1.64 0.00 3.93 S 0.91 W 2.01 0.00 3.90 S 0.43 W 2.32 0.07 3.86 S 0.01 W 3.33 S 40 17 W 3.66 S 38 0 W 3.92 S 35 49 W 4.10 S 33 43 W 4.22 S 31 5 W 4.26 S 28 35 W 4.17 S 20 6 W 4.03 S 13 5 ~ 3.92 S 6 14 W 3.86 S 0 10 W 1960,02 1960.00 1900.00 2060.02 2060.00 2000.00 2160.03 2160.00 ZlO0.O0 2260,04 2260.00 2200.00 2360.05 2360.00 2300.00 2460.08 2460.00 2400.00 2560.26 2560.00 2500.00 2660.80 2660.00 2600.00 2761.80 2760.00 2700.00 0 34 N 82 39 E 038 N 74 9 E 0 35 N 65 23 E 0 44 N 35 30 E 0 58 N 70 23 E 2 12 546 5 E 4 38 S 50 35 E 6 51 S 57 36 E 9 15 S 54 35 E S 55 4 E 2863.48 2860.00 2800.00 11 33 2.86 0.14 3.77 S 0.73 E 3.59 0.00 3.56 S 1.80 E 4.21 0.27 3.20 S 2.86 E 4.42 0.21 2.47 S 3.68 E 4.61 1.64 1.48 S 4.67 E 7.06 2.17 2.37 S 7.06 E 12.76 3.28 6.45 S 11.12 E 23.09 2.05 12.26 S 19.67 E 37.19 2.34 20.13 S 31.41 E 55.54 2.75 30.78 S 46.35 E 3.84 S 10 57 E 3.99 S 26 53 E 4.29 S 41 47 E 4.43 S 56 10 E 4.90 S 72 26 E 7.45 S 71 25 E 12.85 S 59 53 E 23.18 S 58 3 E 37.31 S 57 ZO E 55.64 S 56 25 E 2966.16 2960.00 2900.00 14 37 3070.28 3060.00 3000.00 17 36 3176.11 3160.00 3100.00 20 30 3284.11 3260.00 3200.00 23 51 3394.86 3360.00 3300.00 27 6 3509.23 3460.00 3400.00 30 46 3627.62 3560.00 3500.00 33 50 3750.01 3660.00 3600.00 36 33 3877.36 3760.00 3700.00 40 1 4010.95 3860.00 3800.00 42 26 S 58 15 E 78.74 2.76 S 58 4 E 107.56 2.98 S 55 53 E 142.05 2.57 S 54 39 E 182.75 3.10 S 54 42 E 230.29 2.75 S 54 22 E 285.72 2.99 S 54 8 E 349.04 2.56 S 57 26 E 419.47 2.63 S 57 43 E 498.00 3.49 S 56 0 E 586.34 1.50 43.51 S 65.83 E 78.91 S 56 32 E 56.70 S 90.47 E 107.85 S 57 1 E 77.56 S 119.45 E 142.42 S 57 0 E 100.84 S 152.87 E 183.14 S 56 35 E 128.37 S 191.66 E 230.68 S 56 11 E 160.46 S 236.89 E 286.12 S 55 53 E 197.65 S 288.14 E 349.42 S 55 33 E 237.25 S 346.51 E 419.95 S 55 36 E 279.25 S 413.21 E 498.72 S 55 56 E 327.57 S 487.43 E 587.27 S 56 5 E COMPUTATION DATE: 17-MAR-87 PAGE ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POQL NORTH SLOPE,ALASKA DATE OF SURVEY: 07-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 4149.99 3960.00 3900.00 45 38 4294.21 4060.00 4000.00 46 8 4437.41 4160.00 4100.00 45 14 4579.08 4260.00 4200.00 44 57 4720.04 4360.00 4300.00 44 47 4861.95 4460.00 4400.00 45 38 5005.67 4560.00 4500.00 46 3 5150.13 4660.00 4600.00 46 0 5293.04 4760.00 4700.00 45 31 5435.16 4860.00 4800.00 45 6 S 55 56 E 682.78 S 55 53 E 786.54 S 55 29 E 888.91 S 55 0 E 989.18 S 54 47 E 1088.47 S 54 10 E 1189.11 S 53 31 E 1292.32 S 52 59 E 1396.57 S 53 4 E 1498.66 S 52 57 E 1599.64 1.73 0.43 0.70 0.53 0.23 0.93 0.42 0.95 0.59 0.36 381.81 S 567.32 E 683.83 S' 56 3 E 439.93 S 653.46 E 787.75 S 56 3 E 497.69 S 738.13 E 890.25 S 56 0 E 554.88 S 820.59 E 990.59 S 55 56 E 612.06 S 901.85 E 1089.93 S 55 50 E 670.47 S 983.85 E 1190.59 S 55 43 E 731.45 S 1067.15 E 1293.76 S 55 34 E 793.84 S 1150.66 E 1397.93 S 55 23 E 855.25 S 1232.22 E 1499.94 S 55 14 E 915.99 S 1312.90 E 1600.85 S 55 5 E 5576.62 4960.00 4900.00 44 59 5717.34 5060.00 5000.00 44 29 5857.09 5160.00 5100.00 43 56 5996.06 5260.00 5200.00 44 2 6136.18 5360.00 5300.00 44 59 6277.60 5460.00 5400.00 44 57 6419.99 5560.00 5500.00 45 58 6565.44 5660.00 5600.00 47 6 6713.94 5760.00 5700.00 48 0 6864.36 5860.00 5800.00 48 55 S 52 47 E 1699.69 S 52 43 E 1798.71 S 52 54 E 1896.32 S 52 43 E 1992.82 S 51 49 E 2090.97 S 51 29 E 2190.94 S 50 24 E 2292.24 S 49 41 E 2397-.74 S 49 12 E 2507.30 S 48 36 E 2619.39 0.32 0.18 0.85 0.60 0.77 0.56 0.98 1.15 0.40 0.87 9'76.32 S 1392.70 E 1700.83 S 54 58 E 1036.31 S 1471.49 E 1799.78 S 54 50 E 1095.25 S 1549.29 E 1897.54 S 54 44 E 1153.61 S 1626.14 E 1993.78 S 54 38 E 1213.73 S 1703.74 E 2091.86 S 54 32 E 1275.69 S 1782.22 ~ 2191.73 S 54 Z4 E 1339.52 S 1860.94 E 2292.91 S 54 15 E 1407.30 S 1941.96 E 2398.27 S 54 4 ~ 1478.93 S 2025.14 E 2507.67 S 53 51 E 1552.85 S 2109.77 E 2619.63 S 53 38 E 7018.73 5960.00 5900.00 50 21 7179.11 6060.00 6000.00 52 17 7346.33 6160.00 6100.00 54 22 7519.33 6260.00 6200.00 54 47 7691.76 6360.00 6300.00 53 53 7859.20 6460.00 6400.00 53 12 8021.39 6560.00 6500.00 50 14 8175.94 6660.00 6600.00 49 16 8324.83 6760.00 6700.00 46 13 8467.24 6860.00 6800.00 44 14 S 48 46 E 2736.68 S 48 47 E 2861.73 S 48 24 E 2995.38 S 48 27 E 3136.11 S 49 29 E 3276.19 S 50 26 E 3410.36 S 50 12 E 3537.88 3 50 17 E 3655.58 S 51 48 E 3765.80 S 52 26 E 3867.17 1.10 0.68 1.03 0.14 2.25 1.05 1.79 1.58 1.58 2.30 1630.46 S 2198.12 E 2736.81 S 53 26 E 1713.05 S 2292.45 E 2861.79 S 53 13 E 1801.57 S 2393.06 E 2995.39 S 53 1 E 1895.38 S 2498.54 E 3136.11 S 52 48 E 1988.18 S 2603.99 E 3276.22 S 52 38 E 2073.98 S 2707.31 E 3410.41 S 52 32 E 2155.45 5 2805.58 E 3537.97 S 52 27 E 2231.09 S 2895.94 E 3655.71 S 52 23 E 2300.63 S 2981,53 E 3765.96 S 52 20 E 2362.61 S 3061.75 E 3867.33 S 52 20 E 8603.86 6960.00 6900.00 42 7 8736.61 7060.00 7000.00 40 13 8866.04 7160.00 7100.00 38 25 8992.15 7260.00 7200.00 36 53 9116.25 7360.00 7300.00 35 40 9238.46 7460.00 7400.00 34 31 9358.99 7560.00 7500.00 33 21 9477.94 7660.00 7600.00 32 10 9595.29 7760.00 7700.00 30 53 9710.75 7860.00 7800.00 28 58 S 51 46 E 3960.23 S 51 34 E 4047.50 S 51 4 E 4129.64 S 51 12 E 4206.43 $ 51 7 E 4279.90 S 50 48 E 4350.09 S 50 41 E 4417.33 S 50 8 E 4481.69 S 49 25 E 4543.01 S 48 37 E 4600.56 1.56 0.44 1.85 0.68 1.1i 0.90 0.94 1.07 1.38 1.90 2419.81 S 3135.17 E 3960.~0 S 52 ZO E 2474.04 S 3203.58 E 4047.69 S 52 19 E 2525.44 S 3267.69 E 4129.85 S 52 18 f 2573.62 S 3327.53 E 4206.66 S 52 16 E 2619.71 S 3384.78 E 4280.14 S 52 15 E 2663.96 S 3439.31 E 4350.35 S 52 14 E 2706.52 S 3491.44 E 4417.62 S 52 13 E 2747.57 S 3541.07 E 4482.00 S 52 I1 E 2787.15 S 3588.02 E 4543.36 S 52 9 E 2824.97 S 3631.57 E 4600.95 S 52 7 E COMPUTATION DATE: 17-MAR-87 PAGE 7 ARCO ALASKA~ INC. L5-12 PRUDMOE BAY/LISBURNE POOL NORTH SLOPE~ALASKA DATE OF SURVEY: 07-MAR-87 KELLY BUSHING ELEVATION: 60.00 ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 9824.17 7960.00 7900.00 27 23 9936.38 8060.00 8000.00 26 40 10047.96 8160.00 BIO0.O0 25 57 10158.83 8260.00 8200.00 25 12 10268.95 8360.00 8300.00 24 15 10378.23 8460.00 8400.00 23 16 10486.70 8560.00 8500.00 22 28 10594.67 8660.00 8600.00 21 46 iOT02.03 8760.00 8?00.00 20 5? 10808.98 8860.00 8800.00 20 42 S 47 46 E 4653.90 S 47 59 E 4704.59 S 47 47 E 4753.92 S 47 1 E 4801.59 S 46 12 E 4847.41 S 45 48 E 4891.17 S 45 6 E 4932.84 S 45 4 E 4973.17 S 44 12 E 5011.86 S 43 15 E 5049.30 1.15 0.38 0.71 0.89 0.90 1.05 0.39 0.84 0.86 0.27 2860.72 S 3671.41 E 4654.35 S 52 4 E 2894.82 S 3709.17 E 4705.10 S 52 1 E 2927.96 S 3745.95 E 4754.48 S 51 59 E 2960.33 S 3781.24 E 4802.22 S' 51 56 E 2991.98 S 3814.74 E 4848.11 S 51 53 3022.61 S 3846.44 f 4891.96 S 51 50 3052.09 S 3876.39 E 4933.73 S' 51 47 E 3080.83 S 3905.21 a 4974.15 S 51 43 E 3108.58 S 3932.73 E 5012.94 S 51 40 3136.02 S 3958.92 E 5050.51 S 51 36 E 10915.85 8960.00 8900.00 20 31 11022.52 9060.00 9000.00 ZO 11 11128.95 9160.00 9100.00 19 50 11235.34 9260.00 9200.00 ZO 0 112~2.00 9266.26 9206.26 20 0 S 42 50 E 5086.42 S 42 19 E 5122.96 S 42 10 E 5158.76 S 42 3 E 5194.45 S 42 3 E 5196.69 0.17 0.23 0.86 0.00 0.00 3163.56 S 3984.62 E 5087.76 S 51 33 E 3190.92 S 4009.74 E 5124.45 S 51 29 E 3217.89 S 4034.23 E 5160.41 S 51 25 E 3244.85 S 4058,58 E 5196.26 S 51 21 E 3246.55 S 4060.10 E 5198.51 S 51 21 E ARCO ALASKA, INC. L5-12 PRUDMOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA HARKER TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE PBTD TO COMPUTATION DATE: 1T-MAR-87 PAGE DATE OF SURVEY: 07-MAR-8? KELLY BUSHING ELEVATION: 60.00 ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1668 FSL, 15 FWL~ SEC 1~ TI1N, R15E, TVO RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 10644.00 10717.00 10818.00 11018.00 11084.00 11135.00 11197.00 112~2.00 8705.88 86~5.88 3093.67 S 3918.05 E 8773.98 8713.98 3112.42 S 3936.46 E 8868.44 8808.44 3138.35 S 3961.10 E ) 9055.76 8995.76 3189.77 S 4008.69 E 9117.75 9057.75 3206.55 S 4023.94 f 9165.69 9105.69 3219.41 S 4035.61 E 9223.98 9163.98 3235.11 S 4049.79 E 9266.26 9206.26 3246.55 S 4060.10 E COMPUTATION DATE: 17-MAR-87 PAGE g ARCO ALASKA, INC. L5-12 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURVEY: 07-MAR-B7 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN ~***~*~*~* STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 1668 FSL, 15 FWL, SEC 1, TllN, R15E, dM TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST TOP WAHOO ZONE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAHOO ZONE 2 TOP WAHOO ZONE 1 PBTD TD 10644.00 10717.00 lOB1B.O0 llO1B.O0 11084.00 11135.00 11197.00 11242.00 6705.88 8645.88 3093.67 S 3918.05 E ~773.98 8713.98 3112.42 S 3936.46 E 8868.44 8808.44 3138.35 S 3961.10 E 9055.76 8995.76 3189.77 S 4008.69 E 9117.75 9057.75 3£06.55 S 4023.94 E 9165.69 9105.69 3219.41 S 4035.61 E 9223.98 9163.98 3235.11 $ 4049.79 E 9266.26 9206.26 3246.55 S 4060.10 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 11242.00 9266.26 9206.26 5198.51 S 51 21 E SCHLUFIE}F-IRC-ER [3 ~ RECT; ONfqL SURVF-Y COI"IPP, N',¥' aRCO ~L~SKP, ~ NC NELL LS- 1 2 PRUDHOE E}~Y-LzSE',_, ,,,_ POOL COUNTRY US~q RUN 1 DIqTE LOOOEQ O? - rdF:tR - 8,7 REFEREN£E 72219 RECEIVED JUL- 2 1987 0il & Gas Cons. 6ommission Anchorage ~--WELL' L5-12 (1668' FSL, 15' F , SEC 1, TllN, R15E, UM) HORIZONTAL PROJECTION NORTH 5000 REF ?22 J 8 SCALE : !/]000 IN/FT 2000 1000 - ! 000 -2000 -~000 -qOOO SOUTH NEST , I ....... L_ ..... t ...... !. _. ~ ....... I EI~ST -WELL' (1668' L5'- 12 <--~-, VERTICAL PROJECT. ION FSL, 15' F , SEC l, TllN, R15E, UM) BO7. ARCO AL~KA INC. LISBURNE ENG INggRING Date: 8-13-87 From: Pam Lambert Enclosed are the following: CH Finals for Lisburne Wells Li-10 PDK-iO0 11-23-85 Run 1 5" DA L5-8 PDK-IO0 5.-17~-87 Run 1 5" DA [~F~ L5-12 PFC Log 6-4-87 Run 1 5" DA Z~ L5-16 PDK-iO0 5-18-87 Run 1 5" DA ~ L5-28 PDK-iO0 5~-18.-87 Run 1 5': DA ~ L5-28 Flowmeter Fluid Density Temp Log 7.-27,-87 Run ! 5" Camco2%~z~. L5-29 GCT Directional Survey 6-21.-87 Run 1 5" Sch Received by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 291 ARCO ALASKA INC. LISBURNE ENGINEERING Date: July 16, 1987 From: Para Lambert Enclosed are the following: CH Finals for L5 L5-8 Perf Record/GR 7-8-87 Run 2 5" Sch L5-12 Diff Temp /GR Log 5-24-87 Run 1 5" DA L5-12 Collar Log 5-19-87 Run 1 5" DA Received by: mECEIV aska Oil & Gas Cons. Commission Ancl~orage Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 265 ALASKA INC. LISBURNE ENGINEEKING Date: July 7, 1987 From: Pam Lambert Enclosed are the following: CH Finals for Lisburne Wells ~L5-12 Collar Log Chemical Cutter 6-7-87 Run 1 5" GO ~ ~ L5-16 Collar and Perf Log 5-30-87 Run 1 5" GO -L5-16 Temperature Survey 6-10-87 Run 1 5" Otis -~ L5-28 Temperature Log 6-18-87 Run 3 5" Sch Received by: Alaska Oil & Gas Cons Please sign and return tolPamLambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # STATE OF ALASKA ALAS~-,,, OIL AND GAS CONSERVATION COMk...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1668' FSL, 15' FWL, Sec. 1, T11N, R15E, UM At top of productive interval 1320' FNL, 1320' FEL, Sec.12, T11N, R15E, UM (approx.) At effective depth 1547' FNL, 1174' FEL, Sec.12, T11N, R15E, UM (approx.) At total depth 1559' FNL, 1162' FEL, Sec.12, T11N, R1.SE~ UM .(approx.) 5. Datum elevation (DF or KB) I~KI~ 60' 6. Unit or Property name Prudhoe Bay Unit 7. Well number L5-12 8. Permit number 87-10 9. APl number 50_029-21 694 10. Pool P'rudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11 ,242 'MD feet true vertical 9256 ' TVD feet Effective depth: measured 11,1 97 ' MD true vertical 9214'TVD Casing Length Size Conductor 80 ' 20" Surface 8373 ' 13-3/8" Production 10,609' 9-5/8" Li net 81 7 ' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None feet feet Plugs (measured) N o n e Junk (measured) None Cemented Measured depth 1 860# Pol eset 11 9 ' MD 2450 sx AS II I & 4206 'MD 600 sx Class G Top job w/l15 sx AS I 585 sx Class G 10,645'MD 332 sx Class G 10,425'-11,242'MD ~ue Verticaldepth 119'TVD 3998'TVD 8703'TVD 8500'-9256'T) 12.Attachments Description summary ofproposal [] Well History & Addendum (dated 3/20/87) 13. Estimated dateforcommencing operation June, 1987 Detailed operations program [] BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ('"~ t ~ /7~2~./ :~: j.~/)Jjl...~ Title Associate Engineer Commission Use Only (Dani) SA2/20 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test E3.Loc. ation clearance[ ~,~rove~! ~-..~ Approved by ~ [~,~I~ ~', ~l~l Form 10-403 Rev 12-1-85 Commissioner by order of - the commission Date-.~ Submit in triplicate ~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. AL0389 ICounty. parish or borough North Slope Borough JLease ADL #28320 or Unit ITitle Drill State Alaska Rowan #41 AP1 50-029-21694 Operator ARCO Alaska, Inc. Spudded OrSpUdW.O. begun IDate 1/30/87 IHOur Date and depth as of 8:00 a.m. 1/30/87 thru 2/02/87 2/03/87 2/04/87 2/05/87 2/06/87 Complete record for each day reported The above is correct see Procedures Manual, Section 10. Drilling, Pages 86 and 87. 1930 Hrs. 20" @ 119' 3929', (3810'), Drl surf hole Wt. 9.6, PV 7, YP 42, PH 9.3, WL 20, Sol 9 Accept ri~ @ 1330 hfs, 1/30/87. NU diverter sys. 1/30/87. Drl to 2302' KOP, drl & surv to 3929'. 2501', 3.3°, S42E, 2500 TVD, 5 VS, 4S, 3E 2899', 12.9°, S57.6E, 2894 TVD, 59 VS, 35S, 48E 3331', 25.2°, S54.aE, 3302 TVD, 200 VS, l12S, 165E JARCO W.I. Prior status 50% if a W.O. Spud well @ 1930 hrs, 13-3/8" @ 4206' 4220', (291'), Prep f/top job Wt. 9.5, PV 4, YP 36, PH 9.5, WL 17.4, Sol 8 Drl to 4220', short trip, C&C, POOH. RU & rn 105 its, 13-3/8", 72# BTC csg w/FC @ 4119', FS @ 4206' & cmt w/2450 sx AS III & 600 sx C1 "G" w/2% CaC12. Displ cmt using rig pmps, bump plug. Prep to pmp top job. 3951', 42.2°, S57.3E, 3815 TVD, 543 VS, 303S, 452E 4150', 45.6°, S55.5E, 3958 TVD, 681VS, 379S, 567E PU 12¼" BHA. 13-3/8" @ 4206' 4220', (0'), PU 12¼" BHA 8.3 ppg wtr ND diverter. NU & tst BOPE to 5000 psi. 13-3/8" @ 4206' 5532', (1312'), MU new bit Wt. 9.1, PV 3, YP 8, PH 11.8, WL 50, Sol 94.5 RIH, displ mud to wtr. Tst csg to 2500 psi. hole. Conduct formation tst to 14.5 ppg EMW. 5532'. 4473', 45°, S55.2E, 4186.06 TVD, 910.73 VS, 510.22S, 756.02E 4783', 45.2°, S55.2E, 4404.88 TVD, 1130.13 VS, 635.53S, 936.33E 5154', 46.1°, S53.4E, 4664.23 TVD, 1395.33 VS, 790.33S, 1151.76E 5462', 45.3°, S52.4E, 4879.34 TVD, 1615.76 VS, 923.30S, 1327.57E DO cmt & flt equip + 10' new Drl & surv 12¼" hole to Date Title 3/12/87 I Drilling Supervisor 13-3/8" @ 4206' 6574', (1042'), Drlg Wt. 9.2, FV 3, YP 6, PH 10.6, WL 68, Sol 6.5 TIH, hit bridge @ 4395', wsh & rm to 5532', drl to 6574'. 5727', 44.6°, S53.1E, 5066.88 TVD, 1802.97 VS, 1036.62S, 1476.60E 6217', 45°, S52.4E, 5416.37 TVD, 2146.41VS, 1243.66S, 1750.61E 6462', 46.5°, S51E, 5587.33 TVD, 2321.86 VS, 1352.42S, 1888.33E 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 formation name in describing work performed. Number all 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 ICounty or Parish I State Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Prudhoe Bay ADL #28320 I L5-12 Date and deptrt Complete record for each day while drilling or workover in progress as of 8:00 a.m, 2/07/87 thru 2/09/87 2/10/87 2/11/87 2/12/87 2/13/87 2/14187 thru 2/17/87 13-3/8" @ 4206' 8637', (562'), DD Wt. 9.2, PV 8, YP 6, PH 9.8, WL 14, Sol 7 Drl & surv 12¼" hole to 8637'. 6709', 48.1°, S50.3E, 5755 TVD, 2503 VS, 1467S, 2029E 7310', 54.1°, S48.9E,.6135 TVD, 2967 VS, 1772S, 2380E 8082', 49.5°, S52.7E, 6596 TVD, 3585 VS, 2168S, 2856E 8449', 44.9°, S53.1E, 6846 TVD, 3855 VS, 2331S, 3070E 13-3/8" @ 4206' 9217', (580'), Drlg Wt. 9.3, PV 7, YP 5, PH 9.4, WL 10.5, Sol 7 Drl & surv 12¼" hole to 9217'. 8603', 42.4°, S53.8E, 6957 TVD, 3961VS, 2394S, 3156E 9095', 35.9°, S50.6E, 7339 TVD, 4270 VS, 2585S, 3399E 13-3/8" @ 4206' 9865', (648'), Drlg Wt. 9.4, PV 9, YP 10, PH 11.4, WL 7.2, Sol 8 Drl & surv 12¼" hole to 9865'. 9340', 33.5°, S51E, 7541TVD, 4409 VS, 2673S, 3507E 9772', 27.8°, S47.8E, 7911TVD, 4631VS, 2816S, 3677E 13-3/8" @ 4206' 10,602', (737'), Drlg Wt. 10.0, PV 9, YP 8, PH --, WL 6.7, Sol 11 Drl & surv 12¼" hole to 10,602'. 10,015', 26.2°, S48.5E, 8127 TVD, 4741VS, 2889S, 3759E 10,540', 22.6°, S45.7E, 8605 TVD, 4956 VS, 3038S, 3915E 13-3/8" @ 4206' 10,674', (72'), Rn 9-5/8" csg Wt. 10.1, PV 8, YP 7, PH 11.1, WL 6.4, Sol 11 Drl to 10,674', 15 std short trip, circ, POOH. BTC csg. RU & rn 9-5/8" 9-5/8" @ 10,645' 10,765', (54'), Coring Wt. 9.4, PV 16, YP 12, PH --, WL 7.5, Sol 11 RU & rn 264 its, 47#, L-80 NS-CC csg w/FC 10,558', FS @ 10,645'. Cmt w/150 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46, followed by 435 sx C1 "G" w/.85% D-60 & .06 GHS D-135. Displ using rig pmps, bump plug. RIH w/BHA, DO cmt to 10,638', tst csg to 3000 psi. Displ well to OilFaze. RU & cut core #1 f/10,685'-10,707', rec'd 22'. Core #2 f/10,707'-10,740', rec'd 32'. Core #3 f/10,740'-10,765', rec'd 25'. RIH w/core #4. The above is correct Signatm~n ~.~~,,, For for and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate ITitle 3/12/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructioos: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all 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 JCounty or Parish } Stats Alaska North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL #28320 Date and deptl~ as of 8;00 a.m, 2/18/87 2/19/87 2/20/87 2/21/87 thru 2/23/87 2/24/87 2/25/87 2/26/87 2/27/87 The above is correct Signa~e~ '~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 9-5/8" @ 10,825', Wt. 9.3, Cut core 10,645' (60'), Coring PV 14, YP 11, PH --, WL 7, Sol 11 #4 f/10,765'-10,825', rec'd 60'. 9-5/8" @ 10,860', Wt. 9.3, Retrieve Cut core 10,645' (60'), Coring PV 12, YP 10, PH --, WL 7.8, Sol 11 core, TIH, cut core #5 f/10,825'-10,835' #6, incompl. ; rec'd 10' 9-5/8" @ 10,931', Wt. 9.3, Fin core core #7, 10,645' (71'), Coring PV 12, YP 10, PH --, WL 8.0, Sol 12 #6 10,835;-10,895', rec'd 60'. TIH, wash & ream. incompl. 9-5/8" @ 11,036', Wt. 9.3, Cut core f/10,955 10,645' (168'), Coring PV 14, YP 12, PH --, WL 8.0, Sol 12.5 #7 f/10,895'-10,955'; rec'd 60'. Cut core #8 '-11,044'; rec'd 89'. Cut core #9, incompl. 9-5/8" @ 11,225', Wt. 9.3, Cut core 11,225'. 10,645' (126'), Drlg PV 15, YP 12, PH 9.0, WL 8.0, Sol 12.5 #9 f/11,044'-11,111'; rec'd 67'. ?U BHA, TIH, drl to Alaska Well no. L5-12 Cut IDate ITitle 3/12/87 Drilling Supervisor 9-5/8" @ 10,645' 11,242' TD, (0'), RIH w/bit & scrpr Wt. 9.5, PV 17, YP 13, PH --, WL 7.4, Sol 11 POOH. RU & rn 18 its, 7", 29#, L-80 BTC lnr w/LC @ 11,072', FC @ 11,197' FS @ 11,242', TOL @ 10,425'. Cmt w/332 sx C1 "G" w/.85% D-60, .06 gal/sx D-135 & D-47. Displ cmt w/OilFaze mud, bump plug. POOH. PU 9-5/8" cs~ scrpr & 8½" bit & RIH. 9-5/8" @ 10,645' 11,242', (0'), POH Wt. 9.5, PV 15, YP 12, PH --, WL 7.4, Sol 12 Log FMT/GR to 10,950', RD DA. Make cond'g rn, POOH f/7" lnr. 9-5/8" @ 10,645' 11,242', (17'), Logging Wt. 9.3, PV 16, YP 12, PH --, WL --, Sol 12.5 Drl to 11,242', 7 std short trip, C&C, POH. RU DA, rn DIL/Spectra-log/SD, Density/CNL/GR/CAL & Acoustilog/WF/GR. 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 County! or Parish I State i Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Prudhoe Bay ADL #28320 I L5-12 Auth. or W.O. no. ITitle AL0389 I Drill Rowan #41 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spud Date and depth as of 8:00 a.m. Old TD API 50-029-21694 cost center prior to plugging and 50~ abandonment of this well Date Hour Prior status if a W.O. 1/30/87 1930 Hfs, Complete record for each day reported 7" f/10,425'-11,242' 11,242' TD, 11,197' PBTD, Instl tree 9.3 ppg NaC1 CO to LC, tst csg to 3000 psi. Fin CO 7" lnr to 11,197'. Circ, displ well w/ 9.3 ppg NaC1, tst csg to 3000 psi. POOH, LD DP. ND BOPE, NU tree. Released rig 2/28/87 thru 3/02/87 3/03/87 i000 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowin$ Potential test data 7" f/10,425'-11,242' 11,242' TD, 11,197' PBTD, RR 9.3 ppg NaC1 Displ 13-3/8" x 9-5/8" w/crude/diesel f/freeze protection. @ 1000 hrs, 3/2/87. New TD I PB Depth 11~242' 11,197' Kind of rig 3/02/87 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Lisburne Date 3/12/87 Drillin~ Supervisor Well no. Date Reservoir Producing Interval Oil or gas Test time Productiol3 Oil on test Gas"per day .. Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 3/09/87 L5-12 ND big bore vlv, tst tbg spool & csg head flange. Leak between outside of 9-5/8" packoff & tbg spool. Remove tbg spool, pull packoff. Instl new packoff. NU tbg spool & tst to 5000 psi; OK. NU tree. Instl hgr. Drilling Supervisor Date Date: 3-26-87 From: Para Lamber Enclosed are the following: Magnetic Tape for L5-12 GCT LIS 3-7-87 Run 1 Tape Number 72218 Sch Magnetic Tape for L5-16 EDIT LIS Unshifted 3-14-87 Run 1 Tape Number 72226 Sc~ ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 191 A~CO AL~A INC. LI SBUP. N~ ~Glh~gRING Date: 3-26-87 From: ?am Lambert Enclosed are the following: Magnetic Tape for L5-12 GCT LIS 3-7-87 Run 1 Tape Number 72218 Sch Magnetic Tape for L5-16 EDIT LIS Unshifted 3-14-87 Run 1 Tape Number 72226 Sc~ ign and return roi pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 191 ARCO ALAS~ INC. LISBUI~.N~ ENGINEERING Da~e: 3-19-87 From: Pam Lambert Enclosed are the following: CH Final for L5-12 3-7-87 Run 1 5" Sch CBL(CBT) Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 188 Date: 3-19-87 ? From: Para Lambert Enclosed are the following: FMT Pressure Data 2-25-87 DA fo~,A~ L5-12 Please sign and return roi Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE FILE ROOM EXXON STANDARD CENTRAL FILES TRANSMITTAL # 186 ARCO Alaska, h Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 13, 1987 Mr. Brad Fristoe Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99707 Dear Mr. FrisJx~e: ~/~. RE: ARCO Alaska, Inc. Lisburne Annular Injection ADEC General permit t/85#0-DB001 In follow up to our March 6, 1987 telephone conversation, this letter provides the requested written confirmation of my verbal request and your approval for ARCO to use Lisburne Well t/L5-12 for annular injection use. The well was included in my January 26, 1987 notification but final ADEC approval was delayed pending resubmittal of the information required by the permit. During our conversation we agreed that it was important for me to provide the information requested by condition I,B of the general permit. I believe my March 11, 1987 letter fulfills this requirements. Also, the existing general permit will expire April 30, 1987. It is requested that ADEC either finalize the MOU with AOGCC to remove this permitting duplication or that ADEC issue a new general permit prior to expiration of the existing permit. I understand that ADEC and AOGCC have been working on the MOU and it could be finalized shortly. Because this would minimize the notifications and administrative requirement to both ARCO and the state, I hope that the MOU is final~ized prior to the April 30 deadline. Again, thank you for the verbal approval for using L5-12. If you desire .......... ~ ........ ,,v,, ~-,~ or u,e o~a,,datu notizication ir, formation provided by my March 11~ 1987 letter~ please let me know. Sincerely, Peter N. Hellstrom Sr. Environmental Coordinator PNH/khh:O l I CC: Bob Martin, ADEC Anchorage Keith Kelton, ADEC Juneau Bill Barnwell, AOGCC Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A~GO AI, A~k INC. LI SBUP,~ ENGi'N~gRING Da~e: 3-9-87 From: Pam Lambert Enclosed are the following: Magnetic Tape for L5-12 OH LIS Unshifted 2-24-87 Run 1 DA ~~~- OH LIS Shifted 2-24-87 Run 1 DA 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 179 January 28, 1987 ~fr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit L5-12 ARCO Alaska, Inc. Permit No. 87-10 Sur. Loc. 1668'FSL, 15'FWL, Sec. 1, TllN, R15E, UM. Btmhole Loc. 1401'FNL, 12!4'FEL, Sec. 12, TllN, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~. tru-~ty<~, ~ zf Chairman of '~ Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION C ,,'1MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory ~ Stratigraphic Test [] , Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone~ Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A1 aska, I nc. RKB 60 ' , PAD 21 ' feet Prudhoe Bay Fi el d Lisburne Oil Pool Address 6. p.[ro, p~t..y~ D~ e~s i g n at i o n 31¢.0. Box 100360 Anchorage, AK 99510 AIJL ZUSZU -. · 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1668'FSL, 15'FWL, 5dC. 1, T11N, R15E, UN Prudhoe Bay Unit/Lisb rne 5tatewide At top of productive interval ~ Target 8. Well number Number 1320'FNL, 1320'FEL, Sec.12, T11N, R15E, UN L5-12 ' #8088-26-27 , At total depth 9. Approximate spud date Amount 1401'FNL, 1214'FEL, 5ec.12, T11N, R15E, UN 01/30/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD anU Tva) property line 1 I 158 'ND 1214' ~ 9258'TVD feet 177' From L5-13 feet 2560 (9258'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2300 feet Maximum hole angle 47 0 Maximum surface 3438 psig At total depth (TVD) 4490 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 2.0" 91.5# H-40 Weld 79' 40' 40' 119 119' 2000# Poleset 17.1/2'13-3/8" 68.0# K-55 BTC 70' 39' 39' 109' 109' 2250 sx AS ill 17-1/2'13-3/8" 72.0# L-80 BTC 4106' 109' 109' 4215 4000' 600 sx Class G 12-1/4'9-5/8" 47.0# L-80 BTC 10574' 38' 38' 10612 8730' ~80sxCl assG&3OOsxAS I &A 8-1/2" 7" 29.0# L-80 BTC 746' 0412' 8538' 11158 9258' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~ ~,~ ~,9 ~C~'~I~ ~'~ 1 tI 7 Surface Intermediate ,~J~N '~ 3 Production Liner .~$Y'~ 0~'~ & Perforation depth: measured true vertical , 20. Attachments Filing fee 1~ Property plat [] BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge " Signed '- ~" T~ Title Regional Drilling Engineer Date L;,ommission Use Only (FPG) PD2/02 Permit Number I API number I~)a.~ ~t~ t See cover letter ~:~- ~ O 50-- O',2.~ - ~ i ~'~f 'Appro__ /87 for other requirements Conditions of approval Samples r~quired [] Yes i~ No Mud log required ~ Yes ~ No Hydrogen sulfide measures F!.. Yes ~ No Directional survey required ~ Yes [] No Required working surefo[ OP ~2 · [] M; ~ 5M; [] 10M; ~ 15M Other: ~'~~~ e ~~,~~~ = by order of Approved by Commissioner the commission Dat . . 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'" ~' " ' :::: ':'::t:::. 3::::~'.: ~o:.!: aooo booo ~ooo ~ooo': sooo ~~~ ~j ' ~ .......... ~ ....... ~ .... .~. ~- ' ~ - ~ .... ', -' --~T-~~ ...... ~ .................. , ............................. ~' ............................... ~ .............................. ~ ............. ~ .......... ~ ......... ~ ...... i ..... ~ ~ ~ , i I ......... I ....... i .... ~ ' ; ; . ~ . . . _.,,. . ~ .... ~ ..... ~ ,~ ~ ~~ --~ ...........~ ~ .... ............ ~ . . ~ ~ '-L:__:_; .... :_::__-~_: ...... ~ ............... ~ ........... L ............ ~ ............ ~ I [ : ' L5-12 DRILLING & CORING PROGRAM 1. Set 20" conductor. A 20", 2000 psi annular diverter will be installed per attached schematic. This is variance from-2~ACC25.025. 2. MIRU Rowan 41. Install 10" diverter lines and function test. 3. Drill 17-1/2" hole to KOP. Build 2.5°/100'MD to 46o41' oriented S52°52'E. Hold angle and direction, drill 17-1/2" hole to 4215'MD (4000'TVD). 4. Set 13-3/8" casing and cement to surface. Do top job if cement does not return to surface. Test casing to 2000 psi. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi, annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform l eakoff test. 6. Drill 12-1/4' hole to 8500'MD (6939'TVD) maintaining angle and direction. 7. Begin dropping angle at 8500'MD (6939'TVD) at 1.5°/100'MD. Drop angle to 9-5/8" casing point (10612'MD/8730'TVD), planned final angle is 15°. (NOTE: There is no Sadlerochit pmesent in the L5-12 well path.) 8. Run 9-5/8" casing and cement. Test casing to 3000 psi. 9. Drill out 9-5/8" shoe and 10' of formation. Test casing shoe to 12.5 ppg EMW. 10. Change mud system to oil base mud for coring. 11. Drill 8-1/2" hole to the Top of the Lisburne (10643'MD/8760'TVD). 12. Cut 4" core with 8-1/2" x 4" corehead from 10643'MD/8760'TVD to 11109'MD/9210'TVD (466' of core). 14. Run open hole logs. JAN 2 ~ 1~B7 15. Run and cement 7" liner. Test to 3000 psi. ~k~a~Oi~&G~Go~s.~oimm~m°~ 16. Clean out cement and change mud out to brine with 400' diesel cap. 17. Secure well and release drilling rig. 18. Run cased hole logs. 19. MIRU completion rig. 20. Run production tubing string with subsurface safety valve. PD2/O2a 1-20-87 Page Two L5-12 Drilling Program 21. NU tree and test to 5000 psi. 22. Secure well and release completion rig. 23. perforate and stimulate. NOTE: a. In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level in the reserve pit, will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The an- nulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi @ 8960'TVD, less an oil column to 8660' less a gas column to the surface d. The only well within 200' of L5-~is L5-13 (177' From L5-/4~' at surface). There are no closer intersections downhole. PD/O2a 1-20-87 Density Depth (TVD) #/gal L5-12 MUD PROGRAM Plas Yield Visc. Point Initial 1OM FL % % (CP) #/100 ft2 Gel Gel CC/30M Oil Solids 40-60 20+ 40+ 20+ 0 8-10 Surf 8.8 Funnel to to 100- 13-3/8" 9.7 300 Csg Point pH and Type of Mud Spud Mud 13-3/8" Csg Shoe 8.3 Minimum 6 2 5 25 0 3 to to Possible to to to to to to K-lO 9.4 20 10 30 10 2 7 Low Sol ids Non-dispersed K-lO 9.2 10 4 4 8 8 2 4 to to to to to to to to to 9-5/8"Csg. Pt. 10.2 20 10 8 20 4 5 15 pH 9-10 Low Sol ids/Low Lime Non-dispersed 9-5/8" Csg. Shoe 9.2 15 18 12 10 5 88 9 to to to to to TD 9.6 20 89 10 NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. Oil base mud 1. Degasser 2. Shakers 4. EQUIPMENT - DRILLING FLUID SYSTEM Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Desilter 9. Centrifuge PD2/O2b 1-20-87 well i i i / I ! i I Fillup line i 10" ball I Conductor Note: Only one valve opens automatically when the diverter closes. The second valve will remain closed unless conditions require the use of the second vent line, The second vent line valve can be opened using controls located at the accumulator. This is a variance from 20 AAC 2.5.035 ARCO ALASKA INC. ROWAN 41 DIVERTER 13-5/8" 5000 PSI BOP STACK DIAGRAM ACCLIMULATOR CAPACITY TEST ANNULAR / 4. PR£Y£NT£R~. PI PE RAMS (-~-1 I 2. I t~]. BLIND RAMS PI PE RAMS 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Z. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOL.,D DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTIONALLY TEST CHOKES. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF 3 MINUTES, THEN TEST AT THE HIGH PRESSURE. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF SMINUTES. BLEED PRESSURE TO ZERO. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :~MINUTES. BLEED PRESSURE TO ZERO. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST ~SMINUTES. BLEED PRESSURE TO ZERO. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3 MINUTES. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH SO00 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEE~D PRESSUR'E TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST 3 MINUTES. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL YALYES ARE SET IN DRILLING POSITION. ~.. lqR3~. TEST STANDPIPE VALVES TO 5000 PSI. ~'~ -(- ~'"'-'15 ~ I ALL BOP EQUIPMEN'~ . T.E_~$[~<E,LY COCKS AND NSI DE BOP TO 5000 PSI . 5000 PSI RA~ED OgGGasGo~'[~'~~OPER~TIONOF DEGAsSER' ~S~a .~~7. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SENDTO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26- 85 ROWAN 41 MUD SYSTEM II mixing pit ~1-145 bbls mixing pit ~2-1 45 bbls pill pit 60 bbls pit ~4 115 bbls pit #5 trip tank 145 bbls pit ~3 suction 11 $ bbls 'njection pit 1 45 bbls pit #6 -90 bbls pit#7- 90 bbls pit ~8 40 bbls Brandt Doub 1 e-Deck er Sha 1 e Shak ers-(3 ) Demco Desander with 3-12" diam. cones Demco Desilter with 14-6" diam. cones Dri lco Degasser Pioneer Centrifuge Main Pumps: National 12-P-160, (2) Gasbuster SEC. 2 III SEC. I NS ?25, oo L-5 NOR T H .( L-5 N4~$.00 SOUTH O- PROPOSE D e- EXISTING N 3452.74 A.S.P. GEODET lC SEC. LIllE. DS-L-5 CZON~ 4) (CAT.-L0~G.) OFFSETS 1(.4&T3.18 Y~5,F/'4,4TO.82 TO* II~'M.,I4Z' 1,543 F,I;L ~l~C [.4812,a4 X- TIT,ZTI,27 14~ 14014.,S22~ I?O ~ K. 4584. M Y~$,~l'4,.SG0.42 TO' 1O'M.Se0' 1443 Irl. [.48lZ.47 X- Tl?,2Tl.~ 14~14'14.Zii' IN FLrl. H. 4TI$.05 Y~5,.~r4,TIO.S0 TO' Ill3 Ifil [.4812.45 X,, YlT,,ZTJ,~Z 14rJ4'j4,118' i~IrEL. K. 48~S.GS Y-,S,~4,IG0.4T T0"ZQ*OZ.I 17t3 FR.. [.4812.42 X~ TIT,2TI.BI 14r 14"l&.t~84' iH7 ~[L N.5074. i0 Y"'.5,~75.070.~,.~ 7'0' IB4Z Ir~l. flOC [.4812.55 X" ~ 144' 14' 18~ ~ £.481Z. 4T X-, TI?.2'TI.B4 14~14'11.7'12' llO l"[L K. S515.14 YmS,.~r$,~10.~,8 ZIILT FIL [.41~.~ X,- TIT,3F/'I,ZT 148" 14'Il. Ill' 145 ret. N.d~6S.00 N,~74,540.4~ TO" It'N.tlr 18 IrE [.~OlT.M X~ TIT.4.48.M 1484 14'08. 8 ~ g.,m~.oe Y-,.s,~4,Mo.$! 1,0"20*oo.~ee* J~,4e FII. aec [..qo~,.s7 x~ T17,4.4~.4~ 14~ I4'Oe.l~lt 12 J'IIL I K. S044.05 Y~5,g1'8,G4Q.~0 I~Q4 Ir,l. 8KC [.S04T.S2 X~ TIT.M. dl 14r 14'08.~J~' 1:2 ~ I [.so~7.s4 xu 7JT,4aS. 4.5 Jd~ I4*00.S24' 29 r~ I ii i' i .L~ I lB i ii ii · · i · m i i III I II I I II I I ARCO Drill Site L-5 I HEREBY CERTIFY TI~T lAM PROPER£~ R[mSTER[D AN~ L, CC.S~ TO L~D SURVEYING IN THE ~A~ OF ALASKA AND ~AT THIS PLAT REPRESENTS AN AS-BUILT SU~Y MA~ ~ ME ~ UNDER MY DIRECT SU~VISION AND ~AT ALL DIME~NS AND OTHER ~TAI~ ARE COR~CT. DATE Well As- Built Location LOCATED IN, SECTIONS I 6 2 PREPARED BY: PREI~RED FOR: .v£co, DATE, SHEET: I~- 19' 86 I of I DRAWN.* CHECKED, JSP GMS FIELD BOOK, ~K)B NO. L86-95 86052 ARCO Alaska, Inc. Post Office l~ox 1~. ~0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 23, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - L5 Pad (Wells 1, 4, 5, 8, 9, 12, 15, 16, 20, 21, 23, 28,29 ) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/dmr GRU1/44 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany CHECK LIST FOR NEW W~J. PERMITS ITEM APPROVE DATE (1) Fee ~z~7 t/~F~ (2 thru 8) (3) Admin (8) (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~~ 7-=~- r? (14 thru 22) (5) BOPE ~¥,~/. /- =~ ~ ,,gz (23 thru 28) (6) 01}{ER A/, 7% (29 thru 31) (6) Add: "/¢~'-,~ ~- ~z- 77 Geology: Erisa/leering: JAL ~ r~: 07/18/86 6.011 P~ ,~,c~,~. ?,~ Lease & Well No. Company /t ?- ' [> i~';:~ YES NO 1. Is the permit fee attached .......................................... v~g 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .............. 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. W~ Is a conservation order needed ...................................... Is administrative approval needed ' Is the lease number appropriate ..................................... ~.~. Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. · 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore , ............ Is old wellbore aband~t procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~o psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? .......... 30. Are seismic analysis data presented on shallow gas z~g~'... 1... ~ . 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. . .... / INITIAL GEO. UNiT ON/O~' POOL CLASS STATUS AREA NO. SHORE Additional R~marks: 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. 'LIS TAPE VERIFICATION LISTING' .VP 010.H02 VERIFICATION LISTING PAGE ~, REEL HEADER ** ~ERVICE NAME =GCT )ATE =87/03/17 ]RIGIN : ~EEL NAME :302501H ]ONTINUATION ~ :01 ~REVIOUS REEL : ~OMMENTS :GCT LIS,ARCO PRUDHOE BAY/LISBURNE POOL ~H TAPE HEADER ~* SERVICE NAME :GCT ]ATE :87/03/17 3RIGIN :7221 rAPE NAME : ~ONTINUATION # :0! PREVIOUS TAPE : COMMENTS :GCT LIS~ARCO PRUDHOE BAY/LtSBURNE POOL LS-lZ,API LS-12~API 50-02g-Z1694 50-0Z9'-21694 ~* FI~LE HEAOER FILE NAME :GCT SERVICE NAME VERSION ~ : DATE : MAXIMUM.'!LENGTH FILE TYPE. : PREVIOUS FILE .001 : 1024 ** INFORMATION RECORDS ** MNEM CONTENTS UNIT' TYPE CATE SIZE COOE CN : ARCO ALASKA INC 000 000 015 065 WN : L5-12 000 000 005 065 FN : PR~DMOE BAY-LISB~R'NE POOL 000 000 025 065 RANG: [SE 000 000 004 065 TOWN: llN 000 000 004 : 065 SECT: 1 000 000 002 COUN: NORTH SLOPE 000 000 O1Z 065 STAT: ALASKA 000 000, 006 065 CTRY: USA 000 000 O0~ 065 MNEM CONTENTS U. NIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 LVP 010~H02 VERIFICATION LISTING PAGE 2 SCHLUMBER'GER ALASKA COMPUTING CENTER COMPANY = ARCO ALASKA~ INC. WELL = L5-12 FIELD = PRUDHOE BAY/LISBURNE POOL COUNTY = NORTH SLOPE ALASKA = ALASKA JOB NUMBER AT AKCC: 72218 RUN ~ONE, DATE LOGGED: 07-MAR-87 LOP: RICK KRUWELL CASING CASING = 9.625" @ 10644' - BIT SIZE = 12.25" TO 10644' = 7.000" @ 11242' - BlT. SIZE = 8.5" TO 11242' AZIMUTH OF PLANNED VERTICAL PLANE: 127.13 DEGREES SURFACE LOCATION: 1668' FSL~ 15' ~WL~ SEC l~ TllN, R15E, UM .VP 010.H02 VERIFICATION LISTING PAGE 3 DEFINITIONS: HLAZ= AZIMUTH DEVI: DEVIATION GDEP= GYRO DEPTH V:DEP= TRUE VERTICAL DEPTH NSDR= NORTH OR SOUTH DEPARTURE EWDR= EAST OR WEST DEPARTURE DGL : DOG LEG (CURVATURE DF THE WELL) ¢-~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE 2 8 4 9 4 16 0 REPR CODE ENTRY 66 0 73 60' 65 .tin 66 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API A:PI API API FILE SIZE SPL REPR ID ORDER m DEPT FT'~; GDEP GCT FT VDEP GCT FT HLAZ GCT DEG DEVI GCT DEG NSDR GCT FT; EWDR GCT FT: DGL GCT. FT PROCESS LOG TYPE CLASS MOD NO. O0 000 O0 0 99 000 O0 0 O0 000~ O0 0 O0 000 O0 0 99 620 11 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 0 4 · 0 4 0 4 0 4 0 4 0 4 0 4 0 4 CODE (OCT:AL) t 68 O00000OO000000 1 68 00000000000000 1~ 68 000~00000~000000 t 6B 00000000000000 1 68 000000000000'00 ~ 68 00000000000000 t. 68 OOO00000000000 1 68 00000000000000 ~ DATA :~'~ ~VP OlO.HO2 VERIFICATION LISTING PAGE 4 )EPT' 8192.0000 GDEP )EVI 0.3102 NSDR )EPT 8100.0000 GDEP )EVI 31.3517 NSDR )EPT 8000.0000 GDEP )EVI 20.~559 NSDR )EPT 7996.5000 GOEP )EVI 20.0155 NSOR 50.0000 VDEP 0.0000 EWDR 3528.4985 VDEP -166.1823 EWOR 11031.8457 VOEP -3193.3066 EWDR 11169.9941 VDEP -3228.2450 EWiDR' 50.0000 HLAZ 0.0000 DGL 3476.5679 HLAZ 244.8804 DGL 9068.7480 HLAZ 4011'9131 DGL 9198.5957 HLAZ 4043.5947 DGL 307.0847 0.0000 125.8111 2.8393 137.7006 0.1036 137,9455 2.7074 ~, FILE TRAILER ~ILE NAME :GCT .001 SERVICE NAME : ~:ERSION # : DATE : MAXIMUM LENGTH :. 1024 FILE TYPE : NEXT FILE NAME : ** TAPE TRAILER SERVICE NAME :GCT. DATE :87/03/17 ORIGIN :7221 TAPE NAME : CONTINUATION ~ :01 NEXT TAPE NAME :. COMMENTS :GCT LISgARCO PRUDHOE BAY/LISBURNE POOL LS-12,API 50-029-21694 ~ REEL TRAILER ~ SERVICE NAME. :GCT DATE :87/03/17 ORIGIN : REEL~NAME :302501H CONTINUATION # :01 NEXT REELiNAME : COMMENTS :G:CT LIS,ARCO PRUDMOE BAY/LISSURNE POOL LS-12,~Pi 50-029-21694 EOF =~=~~ INC. ~tat: AlASkA LCC : -150.00 ~* PORMAT *~ ENTRY'" BLOCKS TrPE ENTZ.~ O~aCR£P¥iON. ~. -1: u~PIHS' DmCx:AS: ~ 6U.O ~RAME SPACING ,, 11 1'6 · ~AX~NUN F~ANESiRECO~D -0.~00 LEVEL ~Ai-um S~'~-CiFZCATiON BLOCKS ' .- · - CURVE 2E:R, CURVE' 2:PR.~ =. ~' Mvc=' .,. UN~:~S . '. ..... NAME C.OQ~, S~2:E, SAMPLE 1 MMHO SP ' 6-8: 4 1' M.V t CAL 68 4 1 iN CHMM OmMM CuRvE ::~: REPR : . , . CURVE . REPR Illl~lIII IIIt IIIlI IIIIii lIII! I ..... I CZLD 68 4 1 MMMG SP 66 4 I . TTEN 68 4 1 LSF SP3 6S 4 1 G~ 68 4 I ~Fi ~H 68 4 1 ~i~ :::,,~ 68 ~ -i ~i RFOC 68 4 1 RiLM 66 . 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I II I I 68 4 1 68 4 I UNITS MMHO CURVE REPR NAME CODE SIZE SP 68 ~ CAL 68 4 TH ~8 4 S~MPLE UNITS 1 MV I IN 1 ~/MN I ~ i C ~ M M G~MM FORMAT :LOCKS TYPE ENTRY B-SCRi?TiON 4 1' D~PTHS - .."S r~ - .-.--,: -- -C-~'~ 9 .iZN FRAME SF~C'i'NG UNITS - 11 ..... ~6~ ~q4. XiMUH ~E~AHES-/RECORD - D.A T UM.. S-.P E CZ,F iC AT iON; ...-S LOCKS i ;,J c · CUR¥.~ ~EPR S~MFLE UNITS I ! ! II I I ! ! I I I M V 1 iN CHMM C- TT U LD 0 ~ , , .,~O0 S~ 0.0C3 ~'EM C.CCC EN .,, . O.CO0 ., SPO O..GOO GR C.OGC O .CO0 K " '0'. COO KTH C. OCC LM 0.000 RZLD . 0.000 C~L C 0n~ Tm O.OOO qFOC O.OOJ -OEFTH 1,1200.0GC FT S413.7~ - i I i i i i i I I I I i iI i i II I I I I ! I I ! I -CZL TTE 'U - _ _ O ... : 28.503 SP -3.227 TEM C.,0CG C'~L N 3'95-i .Z74 S-~O i0.G85 GR ~u.607 Tm .. :: 0.7~1 ~-,- K : 0.Z15 KTH . . 14.7'85 : RFOC m a3.1 r4 RiL5 35.084 0.458 i .435 iGOOO.O00. 2, EPTH 11100.CC,,S F.T 3383.287C M . :. 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