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185-297
STATE OF ALASKA • LASKA OIL AND GAS CONSERVATION COMMI WELL COMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 • Suspended 0 lb.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 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 7/30/2017 185-297 • 317-110 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/4/1985 50-029-21505-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 1/6/1986 PBU L2-29 ' Surface: 1961'FSL,1010'FWL,Sec.18,T11N,R15E,UM 9 Ref Elevations KB 52 17. Field/Pool(s): Top of Productive Interval: 3824'FSL,1176'FEL,Sec.13,T11N,R14E,UM GL 14.08 ' BF 15.17 • PRUDHOE BAY,LISBURNE OIL • Total Depth: 4074'FSL,1379'FEL,Sec.13,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9332'/8446' ADL 028321 &028307 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 692695• y- 5963855• Zone - ASP 4 • 10490'/9441' • 84-62 TPI: x- 690463 y- 5965661 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 690253 y- 5965906 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/I-VD: 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 Gyro,DLL/MSFL/NGT,MEST/TCC/GR,LDT/CNL/EPT/PCD/GR,LSS/Waveforms/GR,RFT/GR,CET/GR,GCT,GR/CCL 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-40 40' 120' 40' 120' 30" 1800#Poleset 13-3/8" 72# K-55/L-80 39' 3988' 39' 3981' 17-1/2" 1950 sx AS III,600 sx Class'G',40 sx AS I 9-5/8" 47# L-80 38' 9736' 38' 8788' 12-1/4" 1085 sx Class'G',300 sx AS I 7" 29# L-80 9533' 10489' 8616' 9440' 8-1/2" 435 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): 4-1/2"12.6#13Cr85 9366' 8878'/Q 8064' sag�� / �\I x 2-7/8"6.5#L-80 9518'-9738' 9653'/8718' 9� ;1'21-'23,f[1-00.J'v ;-1y 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVED i?ATE Was hydraulic fracturing used during completion? Yes 0 No 0 . Per 20 AAC 25.283(i)(2)attach electronic and printed j 3 a 111- information AUG 2 2 2017 Vt-(SIF I E U DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached AC 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 ...or Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate •...... Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only V`a e/a/i RBDMS ►,��- AUG 2� 2017 , \VI//GI Arr K � ter • 28. CORE DATA Conventional Core(s) Yes 0 No 0 • Sidewall Cores Yes 0 No 0 • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No 0 • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9839' 8876' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Wahoo Zone 6 9839' 8876' Wahoo Zone 5 9960' 8979' Wahoo Zone 4 10072' 9075' Wahoo Zone 3 10288' 9262' Wahoo Zone 2 10357' 9323' Wahoo Zone 1 10419' 9378' Formation at total depth: Wahoo Zone 1 10419' 9378' 31. List of Attachments: Summary of RWO,Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Ciolkosz,Ryan R Authorized Title: Informa' nd Data C . Iler Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: Date: 512.211 Contact Phone: +1 907 564 5977 • `aJ 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and IVO for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • S WELL NAME: L2-29 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9815' Set Posiset Plug 9805' 16 Gal Cement 9664' - 9665' Tubing Punch 9569' 7 Bbls Class 'G' 9518' Cut & Pull 2-7/8" Tubing 9348' RHC Plug w/ hole 9332' Set Whipstock • • Daily Report of Well Operations L2-29 ACTIVITYDATE SUMMARY T/I/O = SSV/0/0 TEMP = SI PPPOT-T(PASS) PPPOT-IC (PASS) Pre RIG PPPOT-T: Stung into test void, 100 psi on void. Bled test void to 0 psi. Monitored for 10 min, no change in pressure. Function all LDS full in and out(difficult to function). Torque all LDS to 450 ft/lb. Unable to pump through void. Pressure void to 5,000 psi for 30 min test. Lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC Stung into test void, 0 psi on void. Bled test void to 0 psi. Monitored to 10 min, no change in pressure. Function all LDS full in and out(difficult to function). Torque all LDS to 450 ft/lb. Unable to pump through void. Pressure void to 3,500 psi for 30 min test. Lost 4/30/2017 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. ****WELL S/I UPON ARRIVAL**** (RWO capital) RAN 2.34" NO-GO & FLAPPER CHECKER TO TRDP-1A TRSV©2,199' MD (Functioned properly) MADE 2 RUNS W/ 10' x 2.25" PUMP BAILER TO CA-2 BLANKING @ 9,702' MD (Recovered 2 gallons of pct) MADE 1 RUN W/ 15'x 2" PUMP BAILER TO CA-2 BLANKING @ 9,702' MD (Recovered 1/4 gallon of pct) PULLED CA-2 BLANKING PLUG PRONG & PLUG BODY FROM 9,702' MD DRIFTED W/23' x 2" DUMMY GUNS &2.19" CENT TO 9,950' SLM PERFORMED PASSING PRESSURE TEST OF CHEMICAL INJECTION LINE ****WELL LEFT S/I & & DSO NOTIFIED OF STATUS UPON DEPARTURE**** 5/5/2017 **NOTE : TRSV CONTOL LINE LOCATED ON REAR OF TREE** ***WELL SHUT IN UPON ARRIVAL***(SLB E-LINE POSISET) PJSM, RIG UP, PT. 5/13/2017 ***JOB CONTINUED ON 14-MAY-2017*** ***JOB CONTINUED FROM 13-MAY-2017***(SLB E-LINE POSISET PLUG) RUN 1: RIH W/ HEAD - MPSU - MPEX. OAL= 33', OAW= 190LBS, MAX OD = 2.125. LOG CORRELATED TO SLB CBL DATED 1/21/86. SET 7" POSISET PLUG @ 9815' ME RUNS 2 -4: RIH W/ HEAD/ERS/DBA 40' BAILER. OAW= 300LBS MAX OD = 2.125 OAL = 51'. DUMP BAIL 10' OF CEMENT(16 GAL) IN 3 RUNS WITH 40' OF BAILER PER RUN. ESTIMATED TOC @ 9,805' MD. RUN 5- RIH W/ HEAD/ERS/EQF X2/CCL/MPD/PUNCHER/ILE OAL= 28' OAW= 250LBS MAX OD = 1.69". CORRELATED TO PDS LEAK POINT SURVEY DATED 02-OCT-2015. PUNCH TUBING WITH MEDIUM SIZED CHARGE-9664'-9665'. 5/14/2017 RDMO. CTU#14 1.75" CT Job Scope: Depth log/Cement plug **Continued on 05/26/17** 5/25/2017 MIRU CT. MU WFD ctc/MHA CTU#14 1.75" CT Job Scope: Depth log/Cement plug **Continue on 05-27-17** MU WFD MHA& HES GR/CCL logging tools with 2" DJN & RIH. Tag TD at 9791' ctm. Circulate bottoms up with 74 bbls of 50/50 meoh and get 1:1 returns. Log up at 50fpm to 9400, paint yellow flag. Log up to 9000'. POOH pumping pipe displacement. Tie into PDS Leakpoint survey dated 02-October-2015, +18.5' correction. MU SLB 2" BDJSN. RIH to yellow flag and correct depth to 9418.5'.Tag PBTD @ 9813' get WT back @ 9809' Park coil @ 9802'. Begin to pump 5 bbl FW spacer, Class G 15.8 ppg cement into coil, chase 5/26/2017 w/ 10 bbls of FW and 1 % slick KCL. • • Daily Report of Well Operations L2-29 CTU#14 1.75" CT Job Scope: Depth log/Cement plug Lay in 7 bbls of 15.8 class G cement from 9802' to 9290'. Drop 5/8" ball and pump powervis. Contaminate down to 9630'. Chase ooh @ 80%w/ 1% slick KCL. Jet GLM and jewelry on the way out. Est top of cement is 9630'. Lay in 50/50 Freeze protect from 2500'. Jet BOP's. RDMOL 5/27/2017 **Job Complete** ****WELL S/I ON ARRIVAL*** (pre-rwo/drift for jet cut)** TAG TOP OF CEMENT AT 9568' SLM W/2.25"CENT& 1.75" S.BAILER (2 cup sample of cement). RE-TAG TOP OF CEMENT AT 9569' SLM W/ 1.75" S.BAILER (2 cup sample of 5/29/2017 cement). T/I/O = 10/460/0. Temp = SI. T, IA& OA FL's. (for FB). Flowline removed, wing valve locked out. TBG FL= Near surface, IA FL=42', (<3 bbl), OA FL @ Surface. 5/30/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 23:20 T/I/O = 0/200/0 *Well has no flowline*. Test#1 CMIT TxIA**Inconclusive**(see log) CMIT TxIA**PASSED to 3571/3543. Max applied psi= 3730/3639. Target psi = 3500/3500. Pumped 13.5 bbls dsl down tbg to reach test pressure. 15 min TxIA lost 43/46. 30 min TxIA lost 19/21. Total TxIA loss in 30 mins =62/68. Bled TxIA back to 0/10. Bled back 11 bbls to unit. MIT OA**PASSED**to 1114 psi. Max applied = 1200 psi. Target= 1000 psi. Pumped 1.5 bbls diesel down OA to reach test pressure. 15 min OA lost 21 psi. 30 min OA lost 9 psi. Total loss in 30 mins= 30 psi. Bled OAP back to 16 psi. Bled back 1 bbl. Dso notified of well status and tree valve positions as follows: SV,WV,SSV= closed. 5/31/2017 MV=open. IA and OA open to gauges. FWHP= 0/30/16 ***WELL SHUT-IN ON ARRIVAL*** (SLB E-LINE TUBING CUT) INITIAL T/I/O = 0/0/0 PSI RIH W/ HEAD/CCL/2.125" POWER CUTTER. CUTTING DEPTH = 9518'. CCL TO MID CUTTER = 8.5'. CCL STOP DEPTH = 9509.5'. TIE INTO BP TUBING DETAIL DATED 25-APR-1986. 6/1/2017 FINAL T/I/O = 0/0/0 T/I/0=60/66/31 (RWO CAPITAL) CMIT-TxIA Max applied 3700 psi Target pressure 3500 psi. **PASSED**2nd attempt. Pumped 12.3 bbls of amb to achieve test pressure. 1st 15 min TBG/IA lost 19/15 psi, 2nd 15 min TBG/IA lost 12/13 psi. For a total loss of TBG/IA 31/28 psi in a 30 min test. Bled TBG/IA pressure down hard line to L2-21. Pumped 5 bbls meth spear followed by 870 bbls of fresh water going down the TBG taking returns up the IA down hard line to L2-21 flow line. Pumped 177 bbls diesel down the IA then let TBG & IA U-tube for 1 hr to freeze protect TBG & IA. Pumped 4 bbls of meth followed by 10 bbls of diesel to freeze protect hard line and L2-21 flow line. FWHP=1793/1787/8 Caution tags 6/3/2017 &AFE sign hung on well. SV,SSV,WV=Closed WV=Open IA,OA= Open to Gauge ***WELL S/I ON ARRIVAL*** (pre-rig). DRIFTED TO 9,450' SLM W/2.25" CENT, 20'x 1-3/4" BAILER (no issues) 6/5/2017 ***CONTINUED ON 06-06-15 WSR*** • Daily Report of Well Operations L2-29 ***CONTINUED FROM 06-05-17 WSR*** RAN PDS GR/CCL/MTT LOG PER PROGRAM (good data) RAN FLAPPER CHECKER TO TRSV (confirmed trsv is functioning) SET 2-7/8" SLIP STOP UNDER 2-7/8" CA. TRDP1A-SSATRSV @ 2,199' MD. DEPLOY 2-7/8"Z-5 LOCK OUT TOOL IN 2-7/8"CA. TRDP1A-SSA TRSV @ 2,199' MD. RAN 2.25" BLIND BOX TO 2-7/8" CA. TRDP1A-SSA @ 2,199' MD (Locked out trsv). PULL 2-7/8"Z-5 LOCK TOOL FROM 2-7/8" CA. TRDP1A-SSA TRSV @ 2,199' MD. RAN FLAPPER CHECKER TO 2-7/8" CA. TRDP1A-SSA TRSV @ 2,199' MD. (Confirmed trsv is locked out). PULL 2-7/8" SLIP STOP CATCHER FROM 2,175' SLM (All intact). 6/6/2017 ***WELL S/I ON DEPARTURE*** (pad op notified=job complete, well &well head status). T/I/O = 20/20/0. (PRE-Parker). Set 2 9/16" ISA BPV#504 @ 103". RD upper tree & RU Temp valve#34 to MV. RU piggy back I/A#72 &0/A#30. RDMO. ***JOB 6/6/2017 COMPLETE***. FWHP's= BPV/20/0. T/I/O = BPV/50Nac. Temp = SI. WHPs (Pre-rig). Flowline removed and tree removed. Has well house. Heavy Equipment doing dirt work for well pad prep. IA FL @ surface. 6/9/2017 Crown valve= C. MV= O. IA, OA= OTG. 21:00 T/I/O = BPV/50Nac. Temp = SI. Bleed WHPs to 0 psi (pre rig). Has no wellhouse, flowline or scaffolding. OA FL near surface. Bled IAP from 50 psi to 0+ psi in 1.5 hours. Rig down due to Tie-In crew needing over the well to install rig well house. 6/11/2017 SV, MV= ?. IA, OA= OTG. 10:50 • i S North America-ALASKA-BP Page l of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM 'Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs I Task Code ' NPT Total Depth Phase Description of Operations (hr) + (usft) 6/11/2017 06:00 - 07:00 1.00 MOB P PRE SKID RIG FLOOR TO TRAVEL POSITION. LAY OVER DERRICK;390K ON RACK 07:00 - 09:00 2.00 MOB P PRE ,DISCONNECT FROM HI-LINE POWER. 'DISCONNECT SERVICE LINES AND ELECTRICAL LINES IN INNER CONNECTS. I REMOVE ROOF CAPS AND FLOOR PLATES. 'TURN TIRES AND INSTALL TIE RODS. 09:00 - 12:00 3.00 MOB P PRE SPLIT MODULES AND MOVE OFF OF L3-25. STAGE ALL THREE MODULES AT ENTRANCE TO THE PAD FOR MOVE. 12:00 - 19:30 7.50 MOB P PRE MOVE MODULES FROM L3 TO L2. 19:30 - 20:30 1.00 MOB N PRE STAGE MODULES AND MOBILIZE ADDITIONAL 6"MATS TO DEAL WITH SOFT PAD CONDITIONS FROM THE RECENT PAD PREP. 118"GRAVEL LIFT ON MUD MOD SIDE OF WELL IS VERY SOFT AND ADDITIONAL MATS ARE REQUIRED TO STAGE MUD MOD FAR 1 ENOUGH OUT SO THAT DRILL MOD CAN BE SPOTTED OVER WELL. — 20:30 - 00:00 3.50 MOB P PRE SPOT DRILL MOD OVER L2-29AAND SHIM. 'MOVE UTILITY MOD AND MUD MOD INTO POSITION. 6/12/2017 00:00 - 01:30 1.50 MOB- P PRE II CONTINUE TO RIG UP MODULES.TURN I TIRES AND INSTALL TIERODS ON UTILITY MOD AND MUD MOD.CLOSE CARRIER BAY , I DOORS AND RAISE DRIVERS CABS.PLUG IN MODULES AND MAKE UP SERVICE LINES. INSTALL ROOF CAPS,PIPESHED FLOOR i PLATES AND DOOR TRANSITIONS. 01:30 - 02:00 0.50 R1GU P PRE i RAISE DERRICK-525K OFF THE RACK. 02:00 - 03:00 1.00 RIGU P PRE SKID RIG FLOOR TO WELL CENTER 03:00 - 05:00 2.00 RIGU P PRE BRIDAL DOWN,UNTIE SERVICE LOOPS AND INSTALL OFFLINE MOUSEHOLES. RIG UP RIG FLOOR EQUIPMENT. **RIG ACCEPT AT 04:00 HRS 06/12/2017** I TAKE ON SEAWATER TO THE PITS 05:00 - 05:30 0.50 RIGU P PRE HELD PRE-SPUD MEETING WITH FISCHER'S CREW. 05:30 - 06:00 0.50 RIGU P PRE CONTINUE RIGGING UP.CALIBRATE PVT SYSTEM 06:00 - 07:00 1.00 RIGU P PRE CONTINUE GENERAL RIG UP OPERATIONS. PRESSURE TEST SURFACE LINES TO 4000 PSI. 07:00 - 08:00 1.00 RIGU P I PRE PRESSURE TEST BPV FROM BELOW 250/3000 PSI FOR 5 CHARTED MIN EACH-GOOD TEST. 08:00 - 08:30 0.50 RIGU P PRE HELD H2S/RIG EVACUATION DRILL AND AAR WITH FISCHER'S CREW 08:30 - 14:30 6.00 BOPSUR P PRE I NIPPLE DOWN TREE AND ADAPTER FLANGE -BLEED OF CONTROL LINES I NIPPLE DOWN TREE AND ADAPTER FLANGE INSTALL ISA BLANKING PLUG —_- —_ I I VERIFY CROSS OVER;5-3/4 TURNS Printed 8/14/2017 9:47:48AM *All depths reported in Drillers Depths* r S North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) I Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) usft 114:30 - 18:00 3.50 BOPSUR P PRE NIPPLE UP HIGH PRESSURE RISERS AND BOPE STACK -NIPPLE UP DSA AND HIGH PRESSURE RISERS TO WELLHEAD AND TORQUE TO SPEC -NIPPLE UP BOPE STACK AND TORQUE TO SPEC I-INSTALL TURNBUCKLES AND INSERT BELL ;NIPPLE -AIR UP ALL AIR BOOTS -OBTAIN RKBS -INSTALL MOUSEHOLE ENERGIZE ACCUMULATOR 18:00 - 19:00 1.00 BOPSUR P PRE FILL STACK AND PERFORM BODY TEST ON BOPE AND RE-TORQUE ALL STUDS AFTER TESTING. 19:00 - 20:00 1.00 BOPSUB P PRE I HELD H2S/RIG EVACUATION DRILLANDAAR !WITH HUNDLEY'S CREW 20:00 - 00:00 4.00 BOPSUR P PRE TEST BOPE 250/3500 PSI FOR 5/5 CHARTED 'MIN EACH -TEST ALL RAMS AND ANNULAR WITH 2-7/8" AND 4-1/2"TEST JOINTS -TEST GAS ALARMS TEST WITNESSED BY RIG MANAGER,WSL AND AOGCC REPRESENTATIVE BRIAN BIXBY 6/13/2017 00:00 - 01:00 1.00 BOPSUR P PRE �CONTINUE TO TEST BOPE PERFORM DRAWDOWN TEST AND BLACKOUT TEST -TEST WITNESSED BY RIG MANAGER,WSL AND AOGCC REPRESENTATIVE BRIAN BIXBY 01:00 - 01:30 0.50 BOPSUR P PRE RIG DOWN BOPE TEST EQUIPMENT 01:30 - 04:00 2.50 WHSUR P DECOMP INSTALL AND TEST DUTCH RISER,QUICK TEST SUB AND LUBRICATOR -DRAIN STACK,INSTALL DUTCH RISER AND I RUN IN LOCK DOWNS -MAKE UP QUICK TEST SUB AND LUBRICATOR -PRESSURE TEST LUBRICATOR TO 250/3500 PSI FOR 5/5 CHARTED MIN;GOOD TEST BREAK OFF LUBRICATOR AND STAND BACK PULL DUTCH RISER AND QUICK TEST SUB AND STAND BACK MAKE UP TEST JOINT AND XO AND PULL ISA BLANKING PLUG PER FMC REPRESENTATIVE. RE-INSTALL DUTCH RISER AND QUICK TEST 11 SUB.MAKE UP LUBRICATOR TO DUTCH RISER.TEST QUICK TEST SUB. ATTEMPT TO PULL BPV WITH LUBRICATOR.PICK UP AND BREAK OFF LUBRICATOR- NO BPV AND THE RETRIEVAL TOOL IS BENT. Printed 8/14/2017 9:47:48AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 104:00 - 07:00 3.00 WHSUR N SFAL DECOMP ATTEMPT TO PULL BPV —MAKE UPA NEW RETRIEVAL TOOL AND RUN IN THE HOLE -ATTEMPT TO RETRIEVE THE BPV -PICK UP,BREAK OFF LUBRICATOR-NO BPV AND RUNNING TOOL IS BROKEN SUCK OUT THE STACK AND ATTEMPT TO FISH OUT BROKEN BPV RUNNING TOOL WITH MAGNETS-NO SUCCESS. 07:00 - 08:30 1.50 BOPSUR N SFAL DECOMP RIG DOWN THE LUBRICATOR AND DUTCH RISER ASSEMBLY AND SPLIT THE STACK TO RETRIEVE THE BROKEN RUNNING TOOL -REMOVE TURNBUCKLES AND BELL NIPPLE -BREAK STACK FROM WELLHEAD AND LIFT -RETRIEVE THE BROKEN RUNNING TOOL PIECES AND INSPECT THE TOP OF THE BPV -RE-INSTALL THE BLANKING PLUG TO TEST 'THE BREAKS 08:30 - 09:30 1.00 BOPSUR N SFAL DECOMP NIPPLE UP THE STACK AND RE-TORQUE ALL BOLTS -RE-INSTALL TURNBUCKLES,BELL NIPPLE IAND AIR UP AIR BOOTS 09:30 - 10:30 1.00 BOPSUR N SFAL DECOMP !PRESSURE TEST BREAK AT THE WELLHEAD AND RISER AGAINST THE BLANKING PLUG I AND THE BLIND/SHEAR RAMS -250/3500 PSI FOR 5 MIN EACH;GOOD TEST -RIG DOWN TEST EQUIPMENT 10:30 - 13:30 3.00 WHSUR N ' SFAL DECOMP DISCUSS WITH ODE,WSUP AND ANCHORAGE TEAM TO DEVELOP A PLAN FORWARD SIMOPS: -BUILD LANDING JOINT -LAY DOWN DSM TOOLS -BUILD 60 BBL 9.8 PPG BRINE PILL -MAKE UP T-BAR ASSEMBLY -RIG UP CIRCULATING LINES AND EQUIPMENT 13:30 - 15:00 1.50 WHSUR N SFAL DECOMP MAKE UP BPV SETTING TOOL WITH INDICATOR TO T-BAR ASSEMBLY AND ENGAGE BPV TO ACTIVATE POPPET TO CHECK FOR TRAPPED PRESSURE BELOW BPV. -DIFFICULTY GETTING SETTING TOOL TO ENGAGE BPV -ABLE TO ENGAGE BPV AND DEPRESS POPPET -VERIFIED NO PRESSURE IN TUBING AND NO GAS BELOW POPPET BY OBSERVING FLUID I IN STACK -DISENGAGE SETTING TOOL FROM BPV AND PULL TO FLOOR -VERIFY INDICATOR ON SETTING TOOL TO ENSURE THAT BPV WAS FULLY ENGAGED NOTIFY ODE OF WELL STATUS Printed 8/14/2017 9:47:48AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 of E Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 j Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth j Phase Description of Operations (hr) (usft) 15:00 - 16:00 1.00 PULL P DECOMP PULL AND LAY DOWN TUBING HANGER -MAKE UP LANDING JOINT AND XO TO TUBING HANGER PER FMC REPRESENTATIVE,5-3/4 TURNS -BACK OUT LOCK DOWN SCREWS -MAKE UP TOP DRIVE -UNSEAT HANGER WITH 100K TO PULL FREE -PULL HANGER TO FLOOR WITH 95K, EXPECTED 88K. -LAY DOWN HANGER AND LANDING JOINT -FLOWCHECK WELL FOR 10 MIN;STATIC. 16:00 - 18:00 2.00 PULL N DPRB 9,518.00 DECOMP !ATTEMPT TO CIRCULATE THE WELL TO CLEAN SEAWATER -RIG UP HEAD PIN TO LANDING JOINT -CLOSE ANNULAR PREVENTER AND LINE UP j TO TAKE ALL RETURNS TO THE TIGER TANK ATTEMPT TO PUMP DOWN THE IA,TAKING RETURNS UP THE TUBING -PRESSURE UP TO 500 PSI,UNABLE TO MOVE FLUID -RE-VERIFY LINE UP LINE UP TO PUMP DOWN THE TUBING, TAKING RETURNS TO THE TIGER TANK -PUMP DOWN THE TUBING AT 1 BPM;75 PSI -PUMP 3 BBLS. UNSUCESSFULLY RE-ATTEMPT TO PUMP DOWN THE IA WITH SAME RESULT 18:00 - 21:30 3.50 PULL P 9,518.00 DECOMP PUMP DOWN THE TUBING,TAKING RETURNS TO THE TIGER TANK -STAGE UP PUMPS TO 7 BPM WITH INITIAL PRESSURES OF UP TO 2300 PSI AND INTERMITTENT PACK-OFFS ABLE TO ACHIEVE 7 BPM AND 2600 PSI WITH NO PACK-OFFS -PUMP BARA-KLEAN PILLAND CIRCULATE A SURFACE TO SURFACE VOLUME AT 7 BPM TO DISPLACE DIESEL FROM TUBING AND ANNULUS -VERIFY SOAP AT TIGER TANK AND CLEAN RETURNS. -OPEN WELLAND MONITOR FOR 10 MIN; STATIC 21:30 - 00:00 2.50 PULL P 9,518.00 DECOMP PULL AND LAY DOWN 2-7/8"TUBING WITH SINGLE CONTROL LINE AND CHEMICAL INJECTION LINE FROM CUT AT 9518'MD TO 8150'MD -PU 80K;SO 70K -MONITOR HOLE FILL WITH TRIP TANK 6/14/2017 J 00:00 - 09:00 9.00 PULL P 9,518.00 DECOMP PULL AND LAY DOWN 2-7/8"TUBING WITH SINGLE CONTROL LINE AND CHEMICAL INJECTION LINE FROM 8150'MD TO SURFACE -MONITOR HOLE FILL WITH TRIP TANK; DISPLACEMENTS MORE THAN CALCULATED. FLOW CHECK WELL MULTIPLE TIMES; STATIC. -RECOVERED 74 SS BANDS(EXPECTED 76); 1 CHEMICAL INJECTION MANDREL;5 GLMS;1 SSSV;301 FULL JOINTS,3 PUP JOINTS AND 1 CUT JOINT 15.79' Printed 8/14/2017 9:47:48AM *AII depths reported in Drillers Depths* • i ! North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:00 - 09:30 0.50 PULL P 9,518.00 DECOMP RIG DOWN DOYON CASING AND CLEAR RIG FLOOR. 09:30 - 11:00 1.50 CLEAN P 9,518.00 DECOMP DRAIN STACK AND INSTALL 9"ID WEAR RING. FUNCTION RAMS LOOKING FOR MISSING SS BANDS-DID NOT FIND ANY IN THE STACK. SIMOPS: TALLY 4"DRILL PIPE IN SHED FOR UNPLANNED CLEAN OUT RUN -MOBILIZE SLB FISHING TOOLS FOR CLEAN OUT RUN 11:00 12:00 1.00 CLEAN P 9,518.00 DECOMP PICKUP AND RUN IN THE HOLE WITH 8-1/2" CLEAN OUT/DRIFT ASSY TO 50'MD FOR I UNPLANNED CLEAN OUT/DRIFT RUN -8-1/2"OD MILL TOOTH BIT,BIT SUB W/ PORTED FLOAT,8-1/2"OD STRING MILL,1 JT 5"HWDP,8-1/2"OD STRING MILL,XO BACK TO 4"HT38 DRILL PIPE '-MONITOR WELL WITH TRIP TANK;GOOD DISPLACEMENT 12:00 - 00:00 12.00 CLEAN P 9,518.00 DECOMP PICK UP 4"DRILL PIPE AND SINGLE IN THE HOLE WITH 8-1/2"CLEAN OUT/DRIFT ASSY i FROM 50'MD TO 8267'MD -FILL PIPE EVERY 2500'MD -PU 137K;SO 129KAT 7800'MD RUNNING SPEED 150 FPM -MONITOR WELL WITH TRIP TANK;GOOD DISPLACEMENT 6/15/2017 '00:00 - 02:00 2.00 CLEAN P 9,518.00 DECOMP CONTINUE TO PICK UP 4"DRILL PIPE AND SINGLE IN THE HOLE WITH 8-1/2"CLEAN OUT /DRIFT ASSY FROM 8267'MD TO 9518'MD -FILL PIPE EVERY 2500'MD -PU 165K;SO 145K AT 9500'MD -TAG TUBING STUB WITH 10K ON DEPTH AT 9518'MD i-MONITOR WELL WITH TRIP TANK;GOOD DISPLACEMENT 02:00 - 03:00 1.00 CLEAN P 9,518.00 DECOMP CIRCULATE HOLE CLEAN,1.5 X HOLE VOLUME(850 BBLS) -PUMP TWO 35 BBL HIGH-VIS SWEEPS -15.5 BPM;2960 PSI -RECIPROCATE PIPE 90'AT 13 FPM. -NOTHING NOTED IN RETURNS MONITOR WELL FOR 10 MIN;STATIC 03:00 - 06:00 3.00 CLEAN P 9,518.00 DECOMP PULL OUT OF THE HOLE WITH 8-1/2"CLEAN OUT/DRIFT ASSEMBLY FROM 9518'MD TO 50'MD -265 FPM PULLING SPEED -STAND BACK 4"DRILL PIPE AND LAY DOWN 'DURING TRIP OUT OF HOLE,WILL LAY DOWN REMAINDER OF PIPE OFFLINE -MONITOR WELL WITH TRIP TANK;GOOD DISPLACEMENT -MONITOR WELL FOR 10 MIN;STATIC 06:00 - 06:30 0.50 CLEAN P 9,518.00 DECOMP LAY DOWN 8-1/2"CLEAN OUT/DRIFT ASSEMBLY Printed 8/14/2017 9:47:48AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 6 of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:30 - 09:30 3.00 CASING P 9,518.00 RUNCMP RIG UP TO RUN 4-1/2"COMPLETION RIG UP DOYON DOUBLE STACK 4-1/2" ECKEL CASING TONGS WITH TORQUE TURN EQUIPMENT 1-CHANGE OUT ELEVATORS AND SLIPS -LAY OUT COMPLETION JEWELRY IN PIPE SHED AND VERIFY RUNNING ORDER(ODE VERIFY PIPE TALLY) 09:30 - 22:30 13.00 CASING P 9,518.00 RUNCMP RUN 4-1/2",12.6#,13CR85 VAMTOP 1 COMPLETION WITH(2)CTD CASING KICK-OFF WEDGES TO PLANNED SET DEPTH OF 9373'MD(-145'ABOVE 2-7/8"TUBING STUB) 1-BAKER-LOK ALL CONNECTIONS BELOW THE PRODUCTION PACKER -USE JET LUBE SEAL GUARD PIPE DOPE ON ALL VAMTOP CONNECTIONS&TORQUE ALL CONNECTIONS TO OPTIMUM MAKE UP TORQUE;4440 FT-LBS -VAM REP ON LOCATION TO INSPECT ALL THREADS AND WITNESS MAKE UP -RUN IN THE HOLE AT 40-80 FPM(SYRINGE FORCING FLUID OUT TOP OF PIPE ON EVERY JOINT DUE TO LARGE OD CASING WEDGES) -NO ISSUES RUNNING IN HOLE THROUGH 9-5/8"CASING -FINAL PU 141K;SO 122KAT 9325'MD(P272 TOP DRIVE+BLOCKS=35 KLBS) CASING WEDGE DEPTHS FOR FUTURE CTD KICKOFF(P272 42.5'RKB TO ULDS) TOP OF WEDGE 1 APPROXIMATELY AT 9334' MD(CASING COLLARS 12'ABOVE AND 13' BELOW WEDGE) TOP OF WEDGE 2 APPROXIMATELY AT 9286' MD(CASING COLLARS 5'ABOVE AND 13' I BELOW WEDGE) SIMOPS: -LAY DOWN 52 STANDS OF 4"DRILL PIPE OFFLINE WHILE RUNNING COMPLETION 22:30 - 00:00 1.50 CASING P 9,518.00 RUNCMP MAKE UP AND LAND TUBING HANGER PER FMC REPRESENTATIVE -RUN IN LOCK DOWN SCREWS AND TORQUE GLAND NUTS 6/16/2017 00:00 - 03:00 3.00 CASING P 9,518.00 RUNCMP DISPLACE WELL TO NEW SEAWATER AS FOLLOWS: 1-PUMP 53 BBLS OF CLEAN 120°F 8.5PPG SEAWATER AT4 BPM;700 PSI -PUMP 405 BBLS OF CORROSION INHIBITED 120°F 8.5PPG SEAWATER AT 4 BPM;700 PSI PUMP 192 BBLS OF CLEAN 120°F 8.5PPG SEAWATER AT4 BPM;700 PSI -CLEAN SEAWATER SPACED OUT TO BE 'ABOVE UPPER GLM IN BOTH TUBING AND IA, INHIBITED SEAWATER BELOW GLM IN TUBING AND IA. OVERDISPLACE BY 5 BBLS AND THEN LINE UP DOWN TUBING TO PUMP 5 BBLS DOWN THE TUBING TO WASH THE FACE OF THE RHC AND CIRC FLUIDS BACK INTO PLANNED PLACE. Printed 8/14/2017 9:47:48AM *All depths reported in Drillers Depths* S North America-ALASKA-SP Page 7 of 8 Operation Summary Report Common Well Name:L2-29 ;AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations L (hr) (usft) 03:00 - 06:00 3.00 CASING P 9,518.00 RUNCMP SET PACKER AND TEST COMPLETION AS FOLLOWS: MAKEUP LANDING JOINT AND DROP THE BALLAND ROD -SET THE 9-5/8"x 4-1/2"HES'TNT'PACKER DURING PRESSURE UP -CONTINUE TO PRESSURE UP AND TEST I THE TUBING 250/3500 PSI FOR 5/30 CHARTED MIN LOST 50 PSI IN FIRST 15 MIN AND 10 PSI IN THE SECOND 15 MIN,TEST MET BP I PRESSURE TESTING CRITERIA FOR WBE -BLED PRESSURE ON THE TUBING TO 2100 PSI -PRESSURE TEST THE PACKER AND IA !250/3500 PSI FOR 5/30 CHARTED MIN -LOST 10 PSI IN THE FIRST 15 MIN AND 5 PSI ; IN THE SECOND 15 MIN,TEST MET BP ,PRESSURE TESTING CRITERIA FOR WBE i ' -9.5 BBLS PUMPED AND 9.5 BBLS BLED BACK I HOLD PRESSURE ON IAAND PACKER AND NOTIFY WSUP PER HOLD POINT IN WELL PROGRAM FOR ATP. DISCUSS PRESSURE TEST RESULTS WITH 1 WSUP AND RECIEVE ATP. BLEED OFF PRESSURE ON TUBING AND !SHEAR DCR VALVE.PUMP BOTH WAYS AND VERIFY CIRCULATION BOTH WAYS. 06:00 - 09:00 3.00 CASING P 1 9,518.00 RUNCMP FREEZE PROTECT WELL WITH 171 BBLS OF DIESEL 1-REVERSE CIRCULATE 171 BBLS OF DIESEL ALLOW THE WELL TO U-TUBE FOR 1 HOUR MONITOR WELL FOR 10 MINUTES AFTER U- !TUBE:STATIC SIMOPS:CONTINUE PREPARING RIG FOR ' — — i. RIG MOVE 09:00 - 10:00 1.00 INTLVT P 9,518.00 RUNCMP DRY ROD TWC PER FMC REPRESENTATIVE AND PRESSURE TEST -TEST FROM BELOW;250 PSI LOW 3500 PSI HIGH FOR 5 CHARTED MINUTES GOOD TEST 10:00 - 13:00 3.00 BOPSUR P 9,518.00 RUNCMP NIPPLE DOWN BOPE AND HIGH PRESSURE , ,RISER -PUMP OUT STACK AND CLEAN DRIP PANS DE-ENERGIZE ACCUMULATOR -LET AIR OUT OF AIR BOOTS AND PULL BELL NIPPLE ' -RE-DRESS UPPER RAM CAVITIES WITH 4-1/2"X 7"VBR'S FOR NEXT WELL BREAK STACK AND RACK BACK ON STUMP NIPPLE DOWN HIGH PRESSURE RISERS AND LAY DOWN TO PIPE SHED SIMOPS: -BLOW DOWN ALL SURFACE LINES AND EQUIPMENT -BREAK DOWN RIG FLOOR INTERCONNECTS I CONTINUE TO PREP MUD MODULE FOR RIG 'MOVE Printed 8/14/2017 9:47:48AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 8 of 8 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:WORKOVER(WO) Start Date:6/11/2017 End Date:6/16/2017 X3-018G0-C:(2,215,033.00) Project:Lisbume Site:Lis DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:12/4/1985 12:00:00AM 'Rig Release:6/16/2017 Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001091 Active datum:KB©52.Oousft(above Mean Sea Level) Date From-To I Hrs Task Code NPT Total Depth Phase I Description of Operations (hr) (usft) 13:00 - 16:00 3.00 RIGD P 9,518.00 RUNCMP INSTALL AND TEST ADAPTER FLANGE AND TREE -TORQUE ALL FLANGES TO SPEC -PRESSURE TEST HANGER VOID;250 PSI LOW,4500 PSI HIGH FOR 5/15 MIN -PRESSURE TEST TREE;250 PSI LOW,4500 PSI HIGH FOR 5 MIN VISUAL LEAK-TIGHT GOOD TESTS,NOTIFY WSUP AND RECEIVE ATP SIMOPS: -SECURE TOP DRIVE AND UNPIN BLOCKS -PIN BRIDAL LINES -CONTINUE TO PREP MUD MODULE AND DRILL MODULE FOR RIG MOVE 16:00 - 18:00 2.00 RIGD P 9,518.00 RUNCMP SECURE TREE AND CELLAR AND PREP DUMMY WELL HOUSE FOR RIG MOVE **RIG RELEASE FROM L2-29 AT 18:00 HRS ON 06/16/2017** NEXT EVENT=RON EVENT ON J-28A Printed 8/14/2017 9:47:48AM *AII depths reported in Drillers Depths* I S Daily Report of Well Operations L2-29 ACTIVITYDATE SUMMARY T/I/O= TWC/100/0. Removed tree cap assembly& installed ASV#02. Torqued ASV x SV to 886 ftlbs. (L7 NC). PT'd ASV down on SV. Low 300 psi, High 5000 psi. (Passed).Pulled 4" H TWC#292 @110". Installed tree cap& PT'd to 500 psi. (Passed). RDMO. ***Job 7/2/2017 Complete***See log for details. FWHP= 0/100/0. ***WELL S/I ON ARRIVAL*** (CTD) PULL BALL& ROD FROM 4-1/2" RHC PLUG BODY AT 9,348' MD. PULL RKP-DCR SHEAR VALVE FROM ST#4 (3,481' MD). SET RK-DGLV AT ST#4 (3,481' MD). PERFORMED SUCCESSFUL MIT-IA TO 2500 PSI.. DRIFT TO RHC-M PLUG BODY AT 9,348' MD W/3.70"x 10' DUMMY WHIPSTOCK. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 7/4/2017 4-1/2" RHC-M PLUG BODY LEFT IN HOLE FOR WHIPSTOCK SET DEPTH CONTROL. ***WELL SHUT IN UPON ARRIVAL***(SLB E-LINE WHIPSTOCK) PJSM, RU, PT. 7/6/2017 ***JOB CONTINUED ON 7-JULY-2017*** ***JOB CONTINUED FROM 6-JULY-2017***(SLB E-LINE WHIPSTOCK) RUN 1.RIH W/ HEAD/ERS/SWIVEL/CENTRALIZER/WPMOT/WPTET/WPGRT/WPST/BST#10/NORTHE RN SOLUTIONS WHIPSTOCK. OAL = 52' OAW= 650LBS, MAX OD = 3.625". LOG CORRELATED TO TUBING SUMMARY DATED 15-JUNE-2017. WHIPSTOCK SET ON RHC-M SET IN X NIPPLE AT 9348', RA TAGS @ 9339' TOWS = 9331.64', CCL TO TOWS = 14'. RDOM ***JOB COMPLETE*** 7/7/2017 T/I/0=50/300/0 Set 4" CIW"H" TWC#438 through dryhole tree Pre-CDR 2. FWP's 7/16/2017 TWC/300/0 see log for details. T/I/O=TWC/300/0. Pre CDR2. R/D Temp#84 ASV#02, N/U CDR Tree#3 and PT to 5000 psi. Pass. R/D Temp#72 and#30 from IA/OA and PT blinds to 2500 psi. Pass. ***Job 7/17/2017 Complete***See log. T/I/O = TWC/250Nac. Temp = SI. WHPs (Pre rig). No AL, flowling, wellhouse or grating. Drilling scaffold on well. Unable to bleed at this time due to pad prep in progress. 7/22/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:55. T/I/O = TWC/250NAC. Temp= SI. IA FL (pre CTD). No AL. Wellhouse, flowline, SSV removed. IA FL @ surface. 7/22/2017 MV= 0. IA, OA= OTG. 22:30 7/24/2017 Installed Nordic platform. Installed Super Floor. RDMO. ***JOB COMPLETE***. T/I/O = TWC/240Nac. Temp = SI. Bleed IAP to 0 psi. (Pre RIG). IA FL = Near surface. WH, scaffold, flow line removed, rig mats set. Bled IAP from 240 psi to 0 psi in 15 minutes (23 gallons of diesel returned), held open bleed for 30 minutes. Rig down & monitor for 30 minutes. No change in WHP's. Final WHP's =TWC/ONac. 7/25/2017 SV, WV= C. MV= 0. SSV= REMOVED. IA, OA= OTG. 02:45 T/I/O = TWC/9NAC. Temp = SI. WHPs (Post Bleed). WH, scaffolding, and flowline removed. IAP increased 9 psi over night. 7/26/2017 SV, WV= C. MV= 0. IA, OA= OTG. 16:45 Daily Report of Well Operations L2-29 T/I/O = TWC/9/VAC. Temp= SI. WHPs (pre rig). Well is disconnected from the system, no well house, flow line or scaffolding. SSV removed &a extra WV installed. WHPs unchanged since 07-26-2017. SV, WV= C. MV= O. IA, OA= OTG. 14:30 7/28/2017 • • • North America-ALASKA-BP Page 1 got, Operation Summary Report Common Well Name:L2-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2017 End Date:8/5/2017 X3-018G0-C:(1,972,531.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:12/4/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 7/29/2017 00:00 - 02:00 2.00 RIGU P PRE CONTINUE RIGGING DOWN ON 14-32A,PREP TO MOVE OFF WELL. '02:00 - 04:00 2.00 RIGU P PRE CONDUCT PRE-JOB SAFETY MEETING WITH PEAK CREW AND NABORS CREW FOR PULLING OFF WELL. DISCUSS USE OF CHOCK BLOCK,STOP COMMAND AND RADIO CHECKS. PULL PIT MODULE AWAY. PULL DRILLING SUB OFF WELL,WITNESSED BY TOURPUSHER AND WSL. PULL MODULES DOWN THE PAD,INSTALL JEEPS FOR ROAD TRAVEL. 04:00 - 07:00 3.00 RIGU P PRE MOVE RIG MODULES FROM DS 14 TO LISBURNE 2 -ROAD CONDITIONS GOOD -PRECAUTIONARY MATTING PLACED BY FIELD ENGINEER WERE KEY. NOTED THAT RIG HAD POTENTIAL TO GET STUCK IN SOFT SPOTS IF THE MATS WERE NOT THERE. MODULES SPOTTED ON LOCATION AND PREPARED FOR PJSM FOR PLACEMENT 07:00 - 08:00 1.00 RIGU P PRE PJSM FOR PULLING SUB MODULE OVER WELL. NOTIFY PAD OPERATOR THAT CLOSE !PROXIMITY WELL HAS BEEN SHUT IN AND FLAGGED FOR MOVING OVER WELL,GIVEN PERMISSION TO MOVE OVER WELL. -DISCUSS VISUALAND AUDIBLE COMMANDS FOR STOPPING THE JOB -PLACE 12"X 12"BLOCK IN FRONT OF WELL VERIFY COMMUNICATION WITH TRUCK PUSHER AND DRIVER ON WHEN TO STOP TO I JOB -WSL VERFIED THAT IA/OAARE 50 PSI,ALL VALVES CLOSED IN PROCEED WITH MOVING MODULE,OVER WELLAND SET DOWN AT 0800 HRS. RIG ACCEPT 0800 HRS. 08:00 - 11:30 3.50 RIGU P PRE 1SHIFT RIG MATS,ALIGN PITS MODULE AND BACK INTO POSITION. VERIFY LINE-UP, INSTALL INTERCONNECTS. CONTINUE WITH SITE PREPARATION FOR RIG OPS -CLOSE PROXIMITY WELL PLACED BACK INTO PRIOR CONFIGURATION,FLAGGING REMOVED -RECEIVED REPLY FROM AOGCC REP ADAM EARL THAT WITNESS IS WAIVED FOR BOP TEST 11:30 12:45 1.25 RIGU P PRE CONDUCT PRE-SPUD MEETING WITH BOTH !CREWS -DISCUSS H2S EVACUATION PROCEDURE, SOUND ALARM AND CONDUCT RIG EVACUATION DRILL -CONDUCT PRE-TOUR MEETING WITH NIGHT CREW Printed 8/14/2017 9:49:08AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 2 Operation Summary Report Common Well Name:L2-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2017 End Date:8/5/2017 X3-018G0-C:(1,972,531.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:12/4/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001091 Active datum:KB©52.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 12:45 19:00 6.25 RIGU P PRE CONTINUE WITH SITE PREPARATION FOR RIG OPS -NU BOP,STAGE SUPPORT EQUIPMENT, PREPARE AREA FOR TANK FARM -TEST ALL ALARMS PER AOGCC REQUREMENTS -CHECK TORQUE ON BOP TEST JOINT COMPONENTS. -REVIEW BOP TEST PROCEDURE WITH DRILLER AND TOURPUSHER. SHELL TEST BOPS,GOOD. 19:00 - 00:00 5.00 BOPSUR P PRE CONDUCT BOP TEST PER AOGCC,BP,AND [NABORS POLICIES -ALL TESTS TO 250 PSI LOW/3500 PSI HIGH -BOP CONFIGURATION:ANNULAR,BLIND SHEAR RAMS,2-3/8"COMBI RAMS,3"PIPE SLIP RAMS,2-3/8"X 3-1/2"VARIABLE RAMS, BLIND SHEAR RAMS,2-3/8"COMBI RAMS -TEST CONDUCTED WITH 2-3/8",3"AND 3-1/2"TEST JOINTS,RAM LOCKS TESTED CONCURRENTLY. 7/30/2017 00:00 - 08:30 8.50 BOPSUR P PRE CONTINUE TESTING BOPS. -HAVE TO RECONFIGURE THE BOP TEST JOINT SEVERAL TIMES TO TEST ALL RAMS AND ANNULAR. -CONDUCT ACCUMULATOR DRAWDOWN TEST:17 SECONDS FOR INITIAL 200 PSI AND 47 SECONDS TO REGAIN INITIAL SYSTEM PRESSURE. -TEST CHOKE VALVES 9 AND 10 FROM OPPOSITE DIRECTION -TEST INNER REEL VALVE AND PACKOFFS TO 250 PSI LOW/3500 PSI HIGH -TEST WITNESS IS WAIVED BY AOGCC ADAM EARL. -TREE HEIGHT VERIFIED BY LUBRICATOR CREW,TREE TORQUE CONFIRMED BY VALVE CREW. LUBRICATOR COMPONENTS HAVE BEEN MOBILIZED INTO PIPE SHED. 08:30 - 09:45 1.25 EVAL P PRE BREAK OFF,INSTALL BHI UQC WITH FLOATS. CONDUCT LEAK TIGHT TEST ON CONNECTION. PRESSURE TEST FLOATS TO 3500 PSI HIGH FOR 5 MINUTES,GOOD TEST. -INSTALL LUBRICATOR EXTENSION Printed 8/14/2017 9:49:08AM "All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 3 eat Operation Summary Report Common Well Name:L2-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/29/2017 End Date:8/5/2017 X3-018GO-C:(1,972,531.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:12/4/1985 12:0O:OOAM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001091 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:45 - 13:00 3.25 DHB P PRE PJSM FOR PULLING TWC. -DISCUSS PRESSURE CROSSCHECK FOR TEST PRESSURES,MITIGATION MEASURES FOR UNEXPECTED PRESSURE FROM WELLBORE. -RU LUBRICATOR,PRESSURE TEST CONNECTION TO LEAK TIGHT CRITERIA OF 3500 PSI,GOOD TEST. -RUN DOWN,TAG TWC AND ENGAGE. PULL TWC,NO PRESSURE FROM WELL. PULL ABOVE MASTER AND SWAB. CLOSE IN I MASTER,ATTEMPT TO CLOSE IN SWAB. CAN !ONLY GET 8 OF 23 TURNS. DISCUSS, RE-MEASURE SPACEOUT AND MAKE 'SECOND ATTEMPT AND AGAIN CANNOT CLOSE. CALL AND DISCUSS SCENARIO WITH SENIOR WELL SITE LEADER:WELL HAS I TESTED CEMENT PLUG,TESTED MASTER VALVE,KILL WEIGHT FLUID COLUMN TO SURFACE OVERBALANCED TO EXPECTED BOTTOM HOLE PRESSURE. -WITH MASTER CLOSED,PURGE 'LUBRICATOR PER PROCEDURE. FLOW II CHECK,NO PRESSURE. POP OFF,INSPECT TWC. NO VISIBLE MARKS THAT VALVE HAD TOUCHED IT. MOBILIZE LUBRICATOR OFF OF RIG, REMOVE LUBRICATOR EXTENSION 13:00 - 15:00 2.00 CONDI4L P PRE MAKE UP NOZZLE,STAB ON WITH INJECTOR AND PRESSURE TEST LUBRICATOR CONNECTION AGAINST CLOSED MASTER AND CLOSED CHOKE. OPEN UP MASTER TO CLOSED CHOKE,FLOW CHECK-NO PRESSURE. OPEN CHOKE,NO FLOW. -CIRCULATE TO CLEAN RIG LINES AND PURGE LUBRICATOR OF METHANOL FOR MAKING UP BHA -PJSM FOR MAKING UP 3.80"MILLING BHA -POP OFF,REMOVE NOZZLE. MAKE UP 3.80" MILLING BHA#1. STRING MILL 3.80"NO-GO, WINDOW MILL 3.79"NO-GO. MU TO 2 JTS PH6 AND BHI SMART TOOLS. -STAB ON AT 1500 HRS 15:00 - 17:30 2.50 STWHIP P WEXIT RIH WITH MILLING BHA -RIH,TAG AT 162'. -PUMP 18 BBLS NEAT MEOH TO MILL FOLLOWED BY HOT WATER. -TAKE RETURNS TO TIGER TANK,PARTIALLY OPEN CHOKE. -DISCUSS WITH DRILLER RISKS OF WASHING THROUGH ICE PLUGS WITH MILLING BHA. Printed 8/14/2017 9:49:08AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 off, Operation Summary Report - _ -- ----- ______ _-- -- - _ -- --- - --- ........--------- Common Well Name:L2-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:7/29/2017 End Date:8/5/2017 X3-018G0-C:(1,972,531.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:12/4/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001091 Active datum:KB©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 17:30 - 20:30 3.00 STWHIP P WEXIT ONCE MEOH AT THE MILL,START EASING I DOWN. CLEAN PICKUPS EACH TIME. PAST 200'NO MORE SETDOWNS. CONTINUE PUMPING NEAT MEOH THROUGH i THE MILL DOWN TO 1,700'. AT 1,700'PICK UP AND PUMP A B/U,NOTHING UNUSUAL SEEN. RIH TO 2,500'AND PUMP 1 B/U,NOTHING SEEN. AT 2,500'OPEN EDC,RIH. PUMP 0.50/0.94 BPM WHILE RIH. MUD WEIGHT IN: 8.36 PPG MUD WEIGHT OUT: 8.39 PPG 20:30 - 22:30 2.00 STWHIP P WEXIT LIGHT TAG ON WHIPSTOCK AT 9,330'. PICK UP AND CIRCULATE MUD TO MILL AND TO SURFACE. AFTER MUD IS AT MILL,SHUT DOWN AND VAC OUT TIGER TANK THEN CONTINUE CIRCULATING MUD TO SURFACE. ONCE MUD IS ALL THE WAY AROUND, PERFORM DYNAMIC FLOW CHECK FOR 10 I MIN,GOOD. _ &itI2T 22:30 - 00:00 1.50 STWHIP P 9,330.00 WEXIT CLOSE EDC AND BRING PUMPS UP TO 2.73 BPM. � MILL 3.80"WINDOW IN 4-1/2"X 9-5/8"" ���n� (I t CASING/LINER PER BAKER REP FROM 9,329.8'MD TO 9,330.2'MD -RATE:2.78 BPM IN,2.77 BPM OUT -MUD WEIGHT:8.96 PPG IN,9.04 PPG OUT -DWOB:1-2 KLBS -CIRC PRESSURE:3,800 PSI -BLEED IA ONCE FROM 990 PSI TO ZERO 7/31/2017 I 00:00 - 06:00 6.00 STWHIP P 9,332.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"X 9-5/8"" CASING/LINER PER BAKER REP AND WELL PLAN FROM 9,330.2'MD TO 9,331.9'MD UNCORRECTED DEPTH. -RATE:2.77 BPM IN,2.77 BPM OUT -MUD WEIGHT:8.97 PPG IN,9.02 PPG OUT -DWOB:2-3 KLBS -CIRC PRESSURE:3,800 PSI 06:00 - 12:00 6.00 STWHIP P 9,335.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"X 9-5/8"" CASING/LINER PER BAKER REP,NORTHERN SOLUTIONS REP AND WELL PLAN FROM 9,331.9'MD TO 9,335'MD UNCORRECTED DEPTH. MILLING OFF OF NORTHERN SOLUTIONS WHIPSTOCK TRAY SET INTO LOWER WEDGE OF TANDEM WEDGE HOUSING. -RATE:2.72 BPM IN,2.73 BPM OUT MUD WEIGHT:9.0 PPG IN,8.98 PPG OUT -DWOB:2-4.6 KLBS -CIRC PRESSURE:3,875 PSI -CALCULATE THAT THE WINDOW MILL HAS NOSED OUT OF THE 4-1/2"TUBING AT 9333' 12:00 - 20:30 8.50 STWHIP P 9,338.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"X 9-5/8"" CASING/LINER FROM 9,335'MD TO 9,338.2' MD UNCORRECTED DEPTH. -RATE:2.73 BPM IN,2.74 BPM OUT -MUD WEIGHT:9.0 PPG IN,8.95 PPG OUT -DWOB:3.40-4.3 KLBS -CIRC PRESSURE:3,800-3930 PSI Printed 8/14/2017 9:49:08AM *AII depths reported in Drillers Depths* TRS= 2-9/16"FMC • WELLHEAD= FMC `2-2 9 T NOTES:"`K-55 BURST 3450 PSI**CHROME ' ACTUATOR= — AXE SON 13-3/8"CSG, H 61' KB.ELEV= 52.0' 68#,K-55, REF t3B/- 52' ID=12.415" BF.ELEV= 15.17' ' 2106' -I 4-1/2"FES X NIP,D=3.813" KOP= - - 4700' 20"CONDUCTOR 110' - — GAS LFT MANDRELS Max Angle= 47"@ 7700' 91.5#,FI-40, Datum MD=- - 9928' ST WD TVD DEV TY PE VLV LATCH PORT DATE __._ -___ .w_._-_g--_ .. D=19.124" 4 3481 3478 6 MNG DMY RK 0 07/04/17 Datum TVD= 8900'SS 3 5794 5695 33 MMG DMY RK 0 06/15/17 13-3/8"CSG,72#,L-80 BTC R3,D=12.347" H 3984' 2 7657 7084 47 NAG DMY RK 0 06/15/17 J 1 8773 7976 33 MMG DMY RK 0 06/15/17 TOC -I -6634' 1, ' ., ' 1 L 8850' -4-1/2"HES X NP,ID=3.813" 1' 1 Minimum ID =0.875" @ 9348' 14 1 4-1/2" RHC PLUG w/HOLE �j 8878' s-s/s"x 4-1/2"HES TNT PKR D=3.903" I ' 8912' -+4-1/2"HESXNP,D=3.813" • 9278' -19-5/8"X 4-1/2"CT WS WEDGE,D=3.958" II : 19302' H4-1/2"FESXNP,D=3.813" `; 9326' H9-5/8"X 4-1/2"CT VVS WEDGE,D=3.958" NS WHPSTOCK w/2 RA TAGS @ 9339'(7/7/17) -I 9332' g 11 D �� 9348' -14-1/2"HES X NP, =3.813" 1; 1 9348' H4-1/2"RHC PLUG w/HOLE,ID=0.875"(7/4/17) 4-1/2"TBG, 12.6#,13CR-85 VAM TOP, -j 9366' �/ 4 9366' -14-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 1; 1 2-7/8"JET CUT TBG(P-272 TAG ON 06/14/17) --I • 9618' •i 1 1 TOP OF 7"LNR H 9533' �® ®4 9533' -9-5/8"X 7"BKR LNR HANGER ASSE BLY V 1; i1 14 w/TEBK SLV,ID=? t/ ►A 11 o/1' •- 9630' ELM ---17"X 2-7/8"BROWN EB PKR SL TAG TOC(05/29/17) H 9668' ��� ���1�11 111...00.4.1/11 111111 1 ///111/1 o 11.ii 9702' H 2-7/s"CAMCO D NE,D=2.25" 1 4.0.)1 1114 1 •�4, 11111//111/11 11 2-7/8"TBG-PC,6.5#,-0058 bpf,D=2.441" H 9716' l 1••••••••111110 9715' -I2-7/8"WLEG,ID=1.995" V I ••11111 • 1 9-5/8"CSG,47#,L-80 SMLS R3 BUTT,ID=8.681" --I 9736' 1�1111111111111111/1 9715' --I ELMD TT LOGGED ON XX/XX/XX C 11111111111111111►• 1�►..11111111.04 PERFORATION SUMMARY A 1.1.1 : , 9815' -17"POSLSEr PLUG(05/14/17) RLOG:LDT/CNL ON 01/06/86 �� 9848' --I 7"MARKER JOINT AT TOP PERF:31°@ 9840' / I � Note:Refer to Production DB for historical perf data t• 1) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ I 4" 4 9840-9944 C 04/09/86 t, 1 4" 4 9976-10058 C 04/09/86 �, �• ., 11� 10220' HASH-14',1-11/16"TEN/P/CCL/WTBAR �/ 14 PBTD --I 10444' 1 )t 1,1111111111111111111 7"LNR,29#,L-80 SMLS R3 BUTT, -1 10490' ,,1'1'1'1'1'1'1'1„ -0371 bpf,D=6.184" DATE REV BY COMMENTS . DATE REV BY COM/ENTS LISBURNE UNIT 04/12/86 ORIGINAL COMPLETION 07/11/17 NXW/JMD SET NS WS(07107/17) WELL: L2-29 06/16/17 P-272 RWO 07/25/17 RJWJMD CORRECTED WEDGE DEPTHS FERMI Nb: 1852970 06/20/17 JND DRLG HO CORRECTIONS AR No: 50-029-21505-00 07/05/17 RC/JMD F1'1AL ODE APPROVAL SEC 18,T11N,R15E, 1960'FSL&1010'FVVL 07/06/17 BSE/JMO GLV GO(07/04/17) 07/06/17 &B/JW RHC PLUG w/HOLE(07/04/17) BP Exploration(Alaska) 11111 • WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. July 20, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DATA LOGGED itoizo7-1 AUG 0 2 2017 (vi. K BENDER RE: Coil Flag Log: L2-29 Run Date:5/26/2017 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 L2-29 Digital Data(LAS),Digital Log file (Field Data) 1 CD Rom 50-029-21505-00 Coil Flag Log(Field Print) 1 Color Log 50-029-21505-00 SCANNED AUG 15 2017 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com&AKGDMINTERNAL@bp.com Date: Signed:,i/✓a/Z"" 6...esteat • • • of TA THE STATE Alaska Oil and Gas _ ��• 9a OfAT AConservation Commission sKA ZI 333 West Seventh Avenue � Anchorage, Alaska 99501-3572 �., GOVERNOR BILL WALKER .._.�.,..,,...--.---- g "'' Main: 907.279.1433 OFA SY'P' Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor ;SCANNED ''P" 2 f}1 1,BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool,PBU L2-29 Permit to Drill Number: 185-297 Sundry Number: 317-110 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy7JLJ7tks Foerster Chair DATED this /(day of March,2017. R D t 3 23 STATE OF ALASKA liONLASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROV S 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well IV V1 L" Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing I! Change Approved Program 0 Plug for Redrill 0 • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 185-297• Exploratory 0 Development El. 3, Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-21505-00-00 99519-6612 Stratigraphic 0 Service 0 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I3 PBU L2-29 ' 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED ADL 028321&028307 • LISBURNE OIL POOL ' MAR ® 9 2017 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): ✓ Plugs(MD): 10490 • 9441 • 9702 8759 2418 9702 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 40-120 40-120 1490 470 Surface 3949 13-3/8" 39-3988 39-3981 3700/4930 2230/2670 Intermediate 9698 9-5/8" 38-9736 38-8788 6870 4760 Production Liner 956 7" 9533-10489 8616-9440 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9840-10058 8877-9063 2-7/8"6.5# L-80 36-9738 Packers and SSSV Type: 2-7/8"Brown 1-B Packer Packers and SSSV MD(ft)and TVD(ft): 9653/8718 2-7/8"Camco TRDP1A-SSA TRSSV 2199/2199 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: April 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Ciolkosz,Ryan R be deviated from without prior written approval. Email Ryan.Ciolkosz@bp.com Printed Name John Egbejimrba+ Title Drilling Supervisor c./ Signature . / _ Phone +1 907 564 4139 Date 3/8/a.O/z O I 1 v COMMISSION USE ONLY ` O Conditions of approval:Notify Commission so that a representative may witness Sundry Number: e 31-1-1\U Plug Integrity ❑ BOP Test ISl Mechanical Integrity Test 0 Location Clearance 0 Other: t ittet-c5 ,j` fC)0 3C7 0 R S ' / i ce " t5 1 t hnvlarprc ►.VCv-)fc0— *r-5J+ 1c' ZSG� Ps'19 Post Initial Injection MIT Req'd? Yes 0 No 12 Spacing Exception Required? Yes 0 No M Subsequent Form Required: //6 4 0 Approved by: / (/ 67 1/2 3i 5 COMMISSIONER COMMISSION Date:3_K,_ / 1 APPROVED BYTHE I 7 ORIGINAL SDnIS W ' 9 3 2017 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Atchments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz CTD Engineer bP Date: March 7, 2017 Re: L2-29A Permit Approval Permit approval is requested to drill a L2-29A CTD Ivishak sidetrack. 1._t �'vrc �S 1'3'11 L2-29 was drilled in 1986 as a Zone 5&6 producer. The well was initially completed with a 4.5"frac string and a 35,000#frac pumped before the well was recompleted with a 2-7/8" tubing string (Everything above Brown production packer was replaced). Unfortunately L2-29 never lived up to expectations and suffered from low PI since day one, rarely achieving non-flush gross fluid rates over 150 bpd. By 1994 the well was designated LTSI - and the flowline removed. Proposed plan: Abandon the Lisburne Reservoir Pre-Rig. Parker 272 will move in and complete tubing swap to 4-1/2" tubing on or around June 21st, 2017. CDR 2 Coiled Tubing Drilling rig will drill a through tubing sidetrack with the on or around August 15st, 2017 targeting Zone 1 Ivishak. CDR2 will mill a 3.80" window in the 4-1/2" tubing tail and drill an Ivishak well. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. (orCvr, r „di filen t r{t 1 q or,'1-p p� Ij pfc a' ve 6'- prod, 1 Sys 1-11 n (DO a0 PP iq ; /qq`� ,4 cork or qmlr' ten. 'f(0 of a rFkr,Pts hAve_ n O'Neil*" dv/p",f rise fog)" 204- Grp/ 4j„r h4® d(3IVO ti'n re RI ; f I L it j 141f wef( dor c4;/1fin/kit C(fph, kr ,;y/- O ',r (eCOver, in it IN,� poitido of At 17'6l01� • • CTD Drill and Complete L2-29A program: Start Date: April 1st, 2017 Pre-Rig Work 1 S Pull CA-2 Blanking Plug. Drift for Posiset. PT Control Lines 2 E Set Posiset Plug. Dump Bail Cement. Punch Tubing Tail 3 F NEL: Load TBG. 4 C Lay in Cement inside 7" Casing 5 F MIT-T. MIT-IA 6 E Jet Cut Tubing 7 F CMIT-TxIA. Circ Out 8 S Set hold open sleeve across TRSSSV 9 V Set TWC. Install Dry Hole Tree. Configure Casing Valves. 10 D Bleed WHP to 0 psi. — - S — - utf-CA=2-BtartkingPlug. -Drift-forPo-s set: PT Control Lines --2-- E—____.Set-Pesiset-Ptug. Dump Bail Cement. Punch Tubing-Tail - Rig Workovers pa��s� 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,418 psi. 2. Pull 2-7/8" tubing from jet cut 3. Change out wellhead packoff 4. Run 4-1/2" 12.6# 13CR-80 tubing 5. Set Packer and Pressure test to 3500 psi. /3 6. Install Dryhole Tree and NDMO. SvhG� Pre-CTD Work: 1. E-line: Set Whipstock Wedge CTD Rig Work: - , 4 '" 1. MIRU and Test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,418 psi. • 2. Mill 3.80"window plus 10' of rathole. Swap the well to 8.5ppg PowerPro. 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD 5. Run 3-1/2"x 3-1/4"x 2-7/8" L-80 liner. 6. Pump primary cement bringing TOC to TOL, 23 bbls of 15.3 ppg liner cmt planned ® 7. Test liner lap to 2,400 psi. f yjc i/ PTO 8. Perforate liner 9. Freeze protect well, RDMO Post Rig: 1. S: Set GLV design. Run Memory RPM log. Install LTP if necessary. 2. F: Pressure test Liner top packer 3. T: Flowback to test separator 4. S: Obtain SBHP post flowback Mud Program: • Well kill: 8.4-8.6 ppg brine. • Milling/drilling: 8.4-9.8 ppg Power Pro for milling window and drilling (>419 psi over-balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" • • Liner Program: • See attached schematic • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property—22,000' • Distance to nearest well within pool 600' (18-18) Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • RPM log run post drilling rig Perforating: • SWS 2", 6 spf, perf guns • The primary barrier for this operation: a minimum EMW of 8.4 ppg. . • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • There are no wells that fail "Major Risk" with the L2-29A wellpath. ............ Hazards • LS-pad is an H2S pad • Medium Riskof-lost circulation • Up to 4 possible fault crossings Reservoir Pressure • The reservoir pressure on L2-29 is expected to be 3346 psi at 8650' TVDss. (7.44 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,481 psi. Managed Pressure Drilling • MPD techniques may be used to improve hole stability. • An automatic choke will maintain a target ECD at the window for the duration of drilling to improve hole stability. • A pressure schedule will be used for tripping In/Out of the hole. The purpose of the pressure schedule for tripping is to maintain the same bottom hole pressure at the window by applying surface pressure via the choke. • At all times, drilling fluid weight will be greater than equivalent pore pressure. MPD is only being used for hole stability. Ryan Ciolkosz CC: Well File CTD Engineer Joseph Lastufka -FREE= 2-9/16"FMC • SA NOTES:'*K-55 BURST 3450 PSI"* WELLHEAD= AMC L2-29 ACTUATOR= AXR SON 13-3/8"CSG, — 61' 68#,K-55, X� FEF EL—B7=7- 52' U=12.415" 2199' H 2-7/8"CAMCO TRDP1A-SSA TRSSV,U=2.312" BF.ELEV= 15.17' KOP= 4700' 20"CONDUCTOR 110' 0 CHEMICAL MANDRELS M3x Angle= 47°@7700' 91.5#,H-40, • ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum MD= D=19 .124" 1 2243 2243 1 KBMG-L DMY BK-2 0 04/25/12 -_-- Datum TVD= 8900'SS GAS LFT MANDRELS ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC R3,10=12.347" H 3984' 2 2774 2774 2 MC-FMHO DMY BK-2 0 04/12/86 3 5088 5061 18 MC-FMHO DMY BK-2 0 04/25/12 4 7144 6724 43 MC-FMHO DMY BK-2 0 04/12/86 5 8709 7923 33 MC-FM-IO DMY BK-2 0 04/12/86 Minimum ID =2.25" @ 9702' 6 9493 8582 32 MC-FM-IO DMY *RK 0 04/25/12 2-7/8" CAMCO D NIPPLE 'STA#5=DOME HAS A TURNED DOWN LATCH Note:MD DEPTHS ABOVE CORRECTED TO TOP DEPTH 2/1/12 TOP OF 7"LNR —1 9533' }---5 9533' —9-5/8"X 7"BKR Ll'siR HANGER ASSEMBLY w/TU3K SLV,ID=7 9653' H 7"X 2-7/8"BROWN I-B PKR 9702' -�2-7/8"CAMCO D NP;ID=2.25" 9702' HI2-1/4"CA-2 BLANKIdG PLUG(04/24/12) 2-7/8"TBG-PC,6.5#,.0058 bpf,ID=2.441" H 9738' / \ 9738' H2-7/8"WLEG,ID=1.995" L 9738' H ELMD TT LOGGED ON XX/XX/XX 9-5/8"CSG,47#,L-80 SMLS R3 BUTT,ID=8.681" —) 9736' L-A 9848' H7*MARKER JOINT PERFORATION SUMMARY REF LOG:LDT/C►sL ON 01/06/86 ANGLE AT TOP PERF:31°@ 9840' 1104 10220' -j FISH-14',1-11/16"TEM YCCUVVT BAR Note:Refer to Production DB for historical perf data SIZE SR= tITERVAL Opn/Sqz SHOT SQZ 4" 4 9840-9944 0 04/09/86 4" 4 9976-10058 0 04/09/86 PBTD --I 10444' 7"LNR,29#,L-80 SMLS R3 BUTT, — 10490' tit, �1���1�� .1...1...1.1....: 1.0371 bpf,D=6.184" DATE REV BY COM/ENTS DATE REV BY COMMENTS USBURNE UNIT 04/12/86 ORIGINAL COMPLETION 09/09/15 EPD'JMD SET BLANKING PLUG(4/24/12) WELL: 1_2-29 06/16/03 CMO/TLP KB ELEVATION CORRECTION 12/14/16 AMC ADDED CSG XO&SAFETY NOTE PERMT No: 1852970 03/04/07 RL DATUM MD 03/09/17 JNUJMD ADDED REF&BF ELEV AR No: 50-029-21505-00 02/01/12 PJC DRAWING CORRECTIONS 03/09/17 JNUJMD EDITS TO PKR&TBG TAE DEPTHS SEC 18,T11 N,R15E, 1960'FSL&1010'FWL 04/25/12 CJWJMD GLV GO(04/25/12) 02/02/14 GJF/PJC SSSV CORRECTION BP Exploration(Alaska) TREE 2-9/16"FMC • L 2��9 SAI II NOTES:"K-55 BURST 3450 PSI" WNELLHEAD= FMC L� ACTUATOR= AXELSON 13-3/8"CSG, -{ 61' KB.ELEV= 52.0' 684,K-55, I BF.ELEV= 2199' -42-7/8"CAMCO TROPIA-SSA TRSSV,D=2.312" KOP= 4700' ID=12.415" Max Angle= 47'@ 7700' 20'COPDl1CFOR 110' 0 CHHNICAL MANDRELS Datum M)= 9928' 91.5#,H_40, ST MD ND DEV TYPE VLV LATCH FORT DATE Datum ND= 8900'SS D=19.124" =I 1 2243 2243 1 KBMG L DMY BK-2 0 04/25/12 GAS LFT MANDRELS 11 ' ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC R3,0=12.347" - 3984' 2 2774 2774 2 MC-FMHO DMY BK-2 0 04/12/86 3 5088 5061 18 MC-FMHO DMY BK-2 0 04/25/12 4 7144 6724 43 MC-FMHO DMY BK-2 0 04/12/86 5 8709 7923 33 MC-FMHO DMY BK-2 0 04/12/86 Minimum ID =2.25" @ 9702' 6 9493 8582 32 MC-FMHO DMY "RK 0 04/25/12 2-7/8" CAMCO D NIPPLE *STA#5=DOME HAS A ThIU3 DOWN LATCH Note:MD DEPTHS ABOVE CORRECTED TO TOP DEPTH 2/1/12 TOP OF 7'LN R ,-{ 9533' .. k....„ 6-1 9533' -9-5/8"X 7"BKR LNC HANGER ASSEMBLY JetCut-9520'ELMD ',/ wlT1EBKSLV,ID=? TKVK -8644'TVDSS/9627'MD g 9630' -j7"X 2a/8-BROWN1-8 PKR ,,, , r . Tubing Punch iii ; ... 9702' 1-277/8"CAP O DNP,ID=2.25" * 2-718"TBG PC,6.5#,.0058 bpf,ID=2-441" -1-4715. */; } 9715' -12-7/8-WLEG,D=1.995' 1-9715'-1-J ELMD TT LOGGED ON XX/XX/XX I -5/8"CSG,47#.L-80 SMS R3 BUTT,D=8.681" -, 9736' ' TLSB -8824'TVDSS/9839'MD ' ----.-------- Posiset Plug -9840 8 ri84$' -H7"MARKER.WONT PERFORATION SUMMARY - REF LOG:LDT/CHL ON 01/06/86 ANGLE AT TOP PERF:31"@ 9840' - Note:Refer to Production DB for historical perf data 10220' -j FISH-14',1-11116"TEMI'tCX31WT BAR SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4" 4 9840-9944 0 04/09/86 4" 4 9976-10058 0 04/09/86 PBTD -{ 10444' 11111111/11111 111111111111111 1111/111 7"LHR,29#,L-80 SMS R3 Burr, 10490' 111111 . __.____ .1.1.1.1.1.1.1.1. .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE REV BY COMuU'TTS USBURNE UNIT 04/12/86 ORIGINAL COMPLETION 09/09/15 ERYJMD SET BLANKING PLUG(4/24/12) WELL: L2-29 06/16/03 CMOTTLP KB ELEVATION CORRECTION 12/14/16 JUJM) ADDED CSG XO&SAFETY NOTE_ PERMIT No:'1852970 03/04/07 RL DATUM M) AR No: 50-029-21505-00 02/01/12 PJC DRAWING CORRECTIONS SEC 18,T11N,R15E, 1960'FSL 8 1010'FlNL 04/25/12 CJNYJM) GLV GO(04/25/12) 02/02/14 GJF/PJC SSSV CORRECTION BP Exploration(Alaska) TREE= III WELLHEAD= 2-9/16"FFMD _� 9SA�NOTES:`"K-55 BURST 3450 PSI" ACTUATOR= AXELSON 13-3/8"CSG, H — 61' . KB,E-EV= 52.0' 68#,K-55, BF.BEV- D=12.415" 2199' 41/2 HES XNIP,0=3813 KOP= 4700' ' Max Angle= 47`©7700' 20"COPDUCTOR 110' Datum MD= 9928' 91.5#,11-40, Datum TVD= 8900'SS ID=19.124" GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTC R3,D=12.347' —1 3984' IL/ L ST MD TVD DEV TYPE VLV Lr` 1 MMG DMY kr, 2 MMG DMY RK i0 3 MMG DMY RK 0 4 MMG DMY RK , 0 5 I MMG DMY RK 0 ' 8870'-4 1/2"HES X N}ppe,ID=3.813" 8900'-9-5/$"x4-1/2"Bakers 3 PmductonPacker I ' 8930'-4-1/2"HES X NiopI,33=3.813" Ali 1116„.----9300'-4 1/2"x 9-5/8"CT whipstock wedge 9321 -4 1/2"HES X Niope,ID=3.813" dilli9340'-41/2"x9-5/8"CT whipstock wedge 9361'-4 1/2"HES X Nipph,ID=3.813" 9375'-W LEG 4-1/2"12.6# 13CR-80/$5 6. 1 9533' -19-5/8"X 7"BKR LNR HANGER ASSEMBLY w/TIEBKSLV,D=? JetCut %4 k. 9630' H 7"X 2-7/8"BROWN I-B FKR ',g ,"-' 9702' _-12-718"CAMOODNP,D=2.25" r ' ,` ' 9715' —12-7/8"VVLEG,D=1.995" 9-5/8"CSG,47#,L-80 SMS R3 BUTT,u=8.681" — 9736' . ,, ' 9715' ---1ELM)TT LOGGED ON XX/XX/XX 7\i' 9848' H7"MARKEZJOINT 10220' --{FISH-14',1-11/16"TE?*YC UWT BAR PBTD H 10444' •,s..,4..,.,. 7"LNR,29#,L-80 SMS R3 BUTT, — 10490' �����A�.1M., .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE REV BY COINvUJTS USBUR E 1*17 04/12/86 ORIGINAL COMPLETION 09/09/15 BRYJMO SET BLANKING PLUG(4/24/12) WELL: L2-29 06/16/03 CMO/TLP KB ELEVATION CORRECTION 12/14/16 JUJMO ADD®CSG XO&SAFETY NOTE REMIT No:'1852970 03/04/07 RL DATUM MD AR No: 50-029-21505-00 02/01/12 PJC CRAWTNG CORRECTIONS SEC 18,T11N,R15E,1960'FSL&1010'FIN_ 04/25/12 CJNJMD GLV CIO(04/25/12) 02/02/14 GJF/PJC SSSV CORRECTION BP Exploration(Alaska) TREE= 2-9116"FMC • L2-29A SA NOTES:"K-55 BURST 3450 PSI" WE1U-EAD= FMC ACTUAYOR= AXELSON 13-3/8"CSG, H 61' KB.BEV= 52.0' 68#,K-55, vil ! D=12.415" 2199' 1--4 112"FIf S XNIP,10=3.813 KOP= 4700' ' Max Angle= 47"©7700' 20"OOMJUCTOR 110' Datum M)= 9928' 91,5#.1-5-40, Datum TVD= 8900'SS D=19.124" GAS LET MANDRELS 13 318"CSG,72/1,L-80 BTC R3,ID=12-347" 3984' LI. STr MD TVD DEV TYPE VLV LATCH PORT 1 MMG DMY RK 0 2 MMG DMY RK 0 3 MMG DMY RK 0 4 MMG DMY RK 0 5 ,, MMG DMY RK 0 I I 8870'-4-1/2"HES X Nippb,D=3.813" 5 >< 8900'-93/$"x4 1/2"Bakers 3 PnnducttnPacker ' 8930'-4 1/2"HES X N}ppb,ID=3 813" l 9101'-3.70 BakerDepbymentSbeve CO 1.1.14 11# `11 4 !• 4k 9300'-4-1/2"x 9-5/8"CT whiostock wedge — 9321 -4-1/2"HES X Nippb,D=3813" X11 yI 1' '1111 '1411 O1�1S /, "1 9340'-41/2"x9-5/8"CTwhiostock wedge 9361'-4-1/2"HES X Ntopb,ID=3.813" 9533' —9-5/8"X 7"BKR LNR HANGER ASSEMBLY 11,340 -3-1/4"6A#TCIIL-80 9375'-W LEG L-80 JetCut9615'M D M ►,! . 9630' —{r X 2-7/8"BROWN I-B FKR „! .P 9702' _-12-7/8"CAMCO D NP,D=2.25" 9715' --12-7/8"WLEG,D=1.995" 9-5/8"CSG,47#,L-80 SMLS R3 BUTT,D=8.681" H 9736' 'L..-- 9715'ill24 ' H B_MD TT LOGGED ON XXDOUXX I 994$' —{7"MARKER JOINT ' k I 10220' H FISH-14', 1-11/16"TEMP/CCL/WT BAR PBTD —I 10444' ►1i11i1i1i**4 ►1:111:1:/:111:11 7"LMR,29#,L-8o SMLS R3 BUTT, 10490' ►1111111111111111 .1.1...1.1...1.1: .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE REV BY 1 COMMENTS LISBURNE UNIT 04/12/86 ORIGINAL COMPLETION 09/09/15 EFtYJMD SET BLANKING RUG(4/24/12) WELL: L2-29 06/16/03 CMO/TLP KB B-EVATION CORRECTION 12/14/16 JUJMD ADOE)CSG XO&SAFETY NOTE FERMT No:'1852970 03/04/07 RL DATUM MD AR No: 50-029-21505-00 02/01/12 PJC DRAWING COFI?ECTIONS SEC 18,T11N,R15E, 1960'FSL 8 1010'FVVL 04/25/12 CLYJMD GLV CIO(04/25/12) 02/02/14 GJF/PJC SSSV CORRECTION BP Exploration(Alaska) Well L2-29 •DR2AC BOP Schematic "fate _ Quick Test Sub to Otis I -1.1 ft — — — — — — — — — — — — Top of7"Otis 0.0 ft .—.—.—.—.—._._._ CDR2 Rig's Drip Pan I Distances from top of riser Excluding quick-test sub LTop of Annular I 0.0 ri . ►Ci. °I 7-1/16"5k Flange X 7"Otis Box ----- Hydril 7 1/16" C Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft Aire Blind/Shear CL Blind/Shears I 3.3 ft ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft B5 I B• , " • " B7 I B8 pm to 71/16" Deployment Line 4 t. li:4 4 5k Mud 0-iiirayAlt! l-i, NIII1 - ' mil.. lo Cross -��• ♦ �� �� u III p/." Iq Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft ► 2-3/8"x 3-1/2" CL 2-3/8"x3-1/2"VBRs 7.4 ft -► VBR B1 I B2 I Kill Line !rtilii rir , / r - m1 1=4� 1 �i wruwwlrtwMlM III Blind/Shear III CL Blind/Shears 10.0 ft Nell 2-3/8"Pipe/Slips Ii Cu_2-3/8"Combi's 10.7 ft iIP CL of Top Swab 13.3 ft 1 IN ----Swab 2 Test Pump Hose . ,/Swab 1 CL of Bottom Swab 14.8 ft *• ie T1 T2 Ar CL Flow Tee 16.2 ft •• : `°'. BOP2 CL of SSV 17.5 ft • _ 1 Master 2 } Fusable CL of Master Valve 19.0 ft BOP1 Master 1 LDS 205 ft ---_►,, _ 0,1A 1 1. .. .1 .. it II II.II II II Gound Level ROA fl I. u II-n II .mss .1 .. i • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist/ ✓ in the upper left corner of Form 10-403 is checked. If the "Abandon" or "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 ki> work)the initial reviewer will cross out that erroneous entry and initial them it on both copies of the Form 10-403 (AOGCC's and operator's copies). V Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code,they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • WELL LOG TRANSMITTAL 240 eS 2. PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 W. 7th Ave OCT 23 2©tS Suite 100 Anchorage, Alaska 99501 (907) 793-1225 .. ., � _:�rz::. RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 gancpdcabp.com and SCANNF1) ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 02-Oct-15 L2-29 BL/CD 50-029-21505-00 2) Signed : MA/2444024A.117) 6.-eitDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx � � • • (.1 M ,_0 ) Lo Win WO U (*. . ( wfl'QT � tN_c �C coo OY co 0 YO Q c O O 5 "O Q U Q. Y CO > 0- Q O Q l7 LC) LO In r c o ami E y CO F _ o d d a) U) 0 N y c F- N CO to Q p E co E u+ N cfl o) M -o Q CJ v) Z Q M 6 C N O Q > Z z ° -a E 0 T z f- L > a) 0 0 0 0 0 0 (0• v L Cr W J J J J J J } W W W W W W OOp O (0 O O — I— LL LL LL LL LL u a) E v) o Q J J J J J J E w co >i f" Q Q Q Q Q Q Q 0 0)cy) r_ 0 z z z z z z v C -O v LL LL LL LL LL LL 07 L _ u L) �z CG o G, E a 4J ° -D U i.:1 �: C O _0 O N = o _ H m N a) C. q a > > c t0 ti " ' Z 0.1 7 Q v t E C13 OU > o co ;: W F- y F' 1y 01 't' 0 m m 2 Q' pip ,y oa° u'l U U J N J .CI01 CO CO U .5 C d MI U a M W al 8 Fy co ^ J O CD W o s > coa 1 'Q I I o Lai esx dr z x c�yl ets C`» w o >- >- >- V 1 735 D W CL a4 3 t _ CC a L O 0 J O J J 1eil ijirlr— lir W Q 2 03 Cao Cao N < m www E w E z 0 0 0 = O O s I = 9 I -0 -J 0 0 0 N 0N v L" 0 0 0 J 0 J LL w CC a' Q a a a a am 1.1:.2c bll O K x y N 0 w N M N a CO O �„J 0 M CO 01 M O O 0- 111Mil cc '., 0 O O Q --... O O O O p 0 O CD O O O O O O Q LLII Ql O V O h CO (>' W •C I- > > X CO > LL (� Q LLI O W' U U U 0 0 co ai ,.0) no x > RI Ct S° C Q •,- 0 0 0 0 a m L o Ip 0 0 0 0 0 0 u N c r 4 ch a u7 +O+ c old t0 N 00 N O — Q m .- Cr M Cr, LO M I Y NCNICNINCANCN 4-, T O O E m N O) O) Q)N N N N N N V, 0 Q1 0 0 0 0 0 0 C N O O O O O O f` 0 of uM u LO ) ) u) N Com CO cY Y CO a7 K AQ d W II�[[1I N C O CO Lt Y QOQ1l p vUI C to .N O 01 00 M Z OO N N N N C cc N �p N ^ J N c6 1�/1 T. a N N J !i X z J z J E Z y i U T L �--I t ^ C +-, f0 0 I� k Q ` y C 0 COD a 10 a a 6 m Image Project Well History File 'Cover Page XHVZE This page identifies those items that were not scannedduring 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. j _0~_~- ~ ~/~' Well History File Identifier Organization {done) /~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scan'nable) [] Color items: D Diskettes, No. [] Maps: [] /~ayscale items: n Other, No/Type ~ Poor Quality Originals:/~ '~'/" D Other: Other items scannable by large scanner OVERSIZED (Non-Scannable) ID Logs of various kinds NOTES: BREN VINCENT SNERYL MARIA LOWELL DATE: [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: BEVERLY BREN VIN~ARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES Quality Checked {done) Rev1 NOTScenned.wpd Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] �� +AI / �3 Sent: Wednesday, April 03, 2013 7:28 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Sauve, Mark A; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P Subject: NOT OPERABLE: Producer L2 -29 (PTD #1852970) TxIA Communication All, Producer L2 -29 (PTD #1852970) failed a MIT -IA on 04/02/2013. The well is reclassified as Not Operable until the TxIA communication is repaired and integrity confirmed. A tubing tail plug has been set in the well. Plan forward: APE: Evaluate plan forward Please call with any questions. Thank you, scANNED JUL 1 0 2013 Jack Disbrow GW BP Alaska - Well grganizatior Integrity Coordinator Iobai i ' II Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator Pbp.com 1 • • bp BP Exploration (Alaska) Inc. RECEIVED' 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 AUG 31 Anchorage, Alaska 99519 -6612 Nib 4II & Gas C. Commission Astheraga August 22, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission \ g, 333 West 7 Avenue 1‘; Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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 02 Date: 7/7/2011 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 ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 L2 -13A 1980780 500292144001 Top Plate NA NA NA NA NA L2 -14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA ~ ,..-....., ,-¡;', :.:~ ";.:¡ r. '\ ¡::-r'j ~'r' ¡ \... ': If"! ! ','. !', ¡' , L rÌJ')\I'U\:' [ ~-=- .~ l"~j \! ,-~ ((ì rf:'¡ I I I , ! ",' ill) U~ ï", "! ¡~" ,,~~.\ r~/ï r¡\ ! ~,I 'I I ". I' ¡ ¡ o..J ! './ i n \ I ¡, , , ' 1\, ,. ,. , "\\:1 !i\\".,',-!!'I!\~ ¡J~~ L6 U\j æJ U\'J Lf\i í i FRANK H. MURKOWSKI, GOVERNOR / ! AI,ASKA OIL AND GAS CONSERVATI ON COMMISSION / 333 We "JT" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 J\nchorage,AJ( 99519-6612 -{~5-':l9 7 Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU Ll PBU L2 PBU L3 Date ofSVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \\JOt th SVS test. Sincerely, ÇJ/~ J . Norman, Chair C~missioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) ,""""" ,..-....., Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Ron Marquez Date: 04/26/2004 Operator Rep: Rob Endebroc1 Unit/Field/Pad: Greater Pt McIntyre/Lisbume/L2 AOGCC Rep: None Separator psi: LPS HPS 448 _Hll- -.m11- lir. ~Iil:l Ø!1R?1rtilG1I1Jfi8 _1llllmØ. Wen Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L2-06 1830470 448 350 280 P P P OIL L2-10 1870850 11 /9/1996 SI L2-14A 2032140 448 350 250 P 4 P 4/27/2004 OIL L2-16 1870970 5/16/1995 SI L2-20 1851340 6/29/1995 SI L2-21 1852750 448 350 320 P P P OIL L2-24 1850900 3/28/1995 SI L2-25 1860060 3/23/1996 SI L2-26 1851040 11/8/1996 SI L2-28 1850350 8/4/2000 SI L2-29 1852970 2/24/1994 SI L2-30 1850090 8/4/2000 SI L2-32 1871370 6/9/2003 SI L2-33 1860220 3/28/1995 SI Wens: 3 Components: 6 Failures: 1 Failure Rate: --- Remarks: Page 1 of 1 SVS PBU LIS L2 04-26-04oxls '~ ' .... STATE OF ALASKA - ~ ALASKA ..~L AND GAS CONSERVATION CL,,JMISSION ¢c~ W LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Serwce Well -;/, OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~ ' 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-297 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21505 4. Location of well at surface 9. Unit or Lease Name 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval iO~ Well Number 1456' FNL, 1176' FEL, Sec.13, TllN, R14E, UM L2-29 At Total Depth 11. F~eld and Pool 1205' FNL, 1379' FEL, Sec.13, T11N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lisbu~rne O±1_ ?ool RKB 52' ADL 28307, ALK 2317 ' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1 2/04/85 01/06/86 01/11/86'I N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. D.irectional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10,490'MD 9440'TVD 10,444'MD 9399'TVD YES~ NO []I 2199' feet MD 1900' (Approx) 22. Type Electric or Other Logs Run Gyro(f/2000'-4000'), DLL/MSFL/NGT, MEST/TCC/GR, LDT/CNL/EPT/PCD/GR, LSS/Waveforms/GR, LSS/Waveforms/GR, RFT/GR, GCT, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ... 20" 91.5# H-40 Surf 110' 30" 1800# Pol eset .. 13-3/8" 6~ .0#/72.0# K-55/L-80 Surf 3985' 17-1/2" 1950 sx AS III & 600 sx Cla,s~ G Performed top job w/40 ~x AS I 9-5/8" 47.0# L-80 Surf 9736' 12-1/4" 1085 sx Class G & 300 s~ AS I 7" 29.0# L-80 9533' 10,489' 8-1/2" 435 sx Class G. 24. Perforations open to Production (MD+TVD of Top and Bottom and 2B. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9840 ' -9944 'MD 2-7/8" 9738 ' 9653 ' 9976'-10,058'MD w/4 spf, 90° phasing 26. ACID, FRA'CTURE, CEMENTSOUEEZE, ETC. 8876'-8964'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8992'-9062'TVD See attached Addendum, dated 01/29/87; for fracture data. 27. N/A PRODUCTION TEST .... Date First Production I Method of Operation (Flowing, gas lift, etc.) 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~l~ 1 , ~ , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 0IL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~I~ ,, , , 28. CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch,ps. See core description attached to the Well completion Report dated 01/31/86. *Note: Tubing was run & well perforated 04/12/86. Well was recompleted 04/25/86. Form 10-407 Rev. 7-1-80 WC2:016:DAN I CONTINUED ON REVERSE SIDE Submit m duplica~ 29. NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 Top Wahoo Zone 1 GEOLOGIC MAR I~,ER~ TRUE VERT. DEPTH 31 I_IST OF ATTACHMENTS Addendum _~at___ed 01/29/87). 3~ MEAS. DEPTH Truncated 9839' 9960' 10,072' 10,288' 10,357' 10,419' 8875 8978 9074 9261 9322 9377 30. ?'ORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and t~me of each phase. DEPTH HYDRO. PRESSURE SHUT-IN PRESSURE 10,031' 4539 psi 4521.6 psi 9851' 4450.1 psi -- I hereby certify that the foregoing ~s true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (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 ADDENDUM WELL: 4/18/86 L2-29 Frac Lisburne perfs f/9840'-9944' & 9976'-10,058' in seven_stages. Pmp'd the following treatment @ 40 BPM, 4600 max pressure: Stage #1: 800 bbls YFGOII Stage #2: 250 bbls YFGOII 100 mesh (10,000#) Stage #3: 300 bbls YFGOII Stage #4: 74 bbls YFGOII 20/40 (5000#) Stage #5: 102 bbls YFGOII 20/40 (8000#) Stage #6: 137 bbls YFGOII 20/40 (20,000#) Stage #7: 149 bbls YFGOII 20/40 flush (20,000#) RU Camco, RIH, tag fill @ 10,352'. PU logging, stuck @ 10,250'. Pull out of rope socket; ti left @ 10,230' MD. POOH, RD WL unit. RU to tst well. (Note: Ti left in hole = 10' wt bar 1-11/16" OD, 1' rope socket 1-11/16" OD & 3" CCL/Temp 1-7/16". Total length = 14') rilliJ§ Supervisor ARCO Alaska, Inc. Post Office B 10360 Anchorage, Ala=,,<a 99510 Telephone 907 276 S.ANF LE TRANS.qlTFAL SHIPPED TO' State of Alaska Oil & Gas Consv..Comm. 3001 Porcupine Dr. Anchorage, Ak 99501 Hand-Carried DATE' Dec. 21, 1987 OPERATOR' ARCO S:%XlPLE TYPE' Core Chips S~\IP LES SENT' Kuparuk 2T-9 5965-5997 5998-6025 6026-6058 6059-6085 6086-6115 6116-6145 -~isburne~-L2-2~ 9849-9865 9865-9874 9880-9886 9887-9896 9897-9918 9918-9931 9929-9945 9946-9985 9986-10001 10001-10006 10008-10016 041-10048 ~k 10052-10061 l~/,..~..s,. /b'o~'~- ~ 0~ 10062-10080 ' { 10081-10090 ~'~ ~,'o~J, 10090-10093 SHIPPED BY'~~ NAa\IE' Kup. 2T-9, Lis. NbT. IBER OF BOXES' L2-29,L3-12 Lisburne L3-12 11130-11170 11170-11211 11211-11262 11262-11287 11287-11323 11323-11363 11368-11428 11429-11467 11468-11519 11520-11580 11581-11634 * * sample no. 11615-11616 could not be located. Paleo Lab Tech UPON RECEIPT OF THESE SkMPLES, PLEASE NOTE kqY DISCREP.%NCIES .~ND ~NIL A SIGNED COPY OF THIS FO~! TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/100 RECEIVED BY' DATE- ARCO Al".lka. Inc. II I Subsidiary of AllanllcRIchfleldCompan¥ ARCO Alaska, Inc Post Office .~.~,. J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 S.'~.',IP LE '['R~NS.~IITTAL Hand-Carried SHIPPED TO' State of Alaska Oil & Gas Consv. Comm. 3001 Porcupine Dr. Anchorage, Ak 99501 DATE' Dec. 21, 1987 OPERATOR: ARCO S:LXlPLE TYPE' Core Chips · N~\IE. Kup. 2T-9, Lis. L2-29,L3-12 9 NUMBER OF BOXES' S~\IP LES SENT: Kuparuk 2T-9 5965-5997 5998-6025 6026-6058 6059-6085 6086-6115 6116-6145 ' / Lisburne L2-29 9849-9865 9865-9874 9880-9886 9887-98~6 9897-9918 9918-9931 9929-9945 9946-9985 9986-10001 10001-10006 10008-10016 10041-10048 10052-10061 10062-10080 10081-10090 10090-10093 SHIPPED BY:~ .Lisburne L3-12 11130-11170 11170-11211 11211-11262 11262-11287 11287-11323 11323-11363 11368-11428 11429-11467 11468-11519 11520-11580 11581-11634 * * sample no. 11615-11616 could not be located. Paleo Lab Tech UPON RECEIPT OF THESE S~x, IPLES, PLEASE NOTE ~NY DISCREP.%WCIES .~ND ~IL A SIGNED COPY OF THIS FO~\I TO' ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/100 DATE: ARCO Alaska. Inc. Is a Subs,diary of AtlanticRichlieldComl~an¥ STATE OF ALASKA ALASI ~..~.~IL AND GAS CONSERVATION COMM.-..~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~[ Pluaain_a [] Perforate~ Pull tubing COMPLETE/WORKO"VER Alter Casing [] Other I~ Fee 2. N a~0ofA ~,~,tOrnc, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1961' FSL,1010' FWL, 5ec.18, TllN, R15E, UH At top of productive interval 1456' FNL, 1776' FEL, Sec.13, TllN, R14E, UM At effective depth 1222' FNL, 1366' FEL, Sec.13, T11N, R14E, UN At total depth 1205' FNL, 1379', FEL, Sec.13, T11N, R14E, UN 5. Datum elevation (DF or KB) RKB 52 ' 6. Unit or ProDertv name Prudhoe Bgy Uhit 7. Well number L2-29 8. Approval number 2 9. APl number 50-- 029-22505 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10490'MD true vertical 9440 ' TVD Effective depth: measured 10444 'MD true vertical 9399'TVD Casing Length Size Conductor 71 ' 20" Surface 3946' 1 3-3/8" Production 9699' 9-5/8" Perforation depth: measured 9840'-9944 'MD true vertical 9976'-10058'MD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 9738' Packers and SSSV (type and measured depth) lB pkr @ 9653' & TRDP-1A SSSV @ 2199' feet feet feet feet Plugs (measured) Junk (measured) Cemented 1800# Pal eset 1950 sx AS III & 600 sx Class G & Top job w/40 sx AS I 1085 sx Class G & 300 sx AS I 12. Stimulation or cement squeeze summary See attached Addemdum, dated 01/20/87, for Fracture data. Intervals treated (measured) Treatment description including volumes used and final pressure None None Measured depth True Vertical depth 110'MD 110'TVD 3985 'MD 3979 'TVD 9736'MD 8786'TVD RECEIVED r"F9 0 2 1987 ~laska 0ii & Gas CoO~, AnChorage Ce.m~i~siOl~ 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl etion/Workover Wel 1 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 TitleASsociate Engineer Date (DANI) SW0/174 Submit in Duplicate ADDENDUM WELL: 4/~8/86 L2-29 Frac perfs f/9840'-9944' & 9976'-10,058' in seven stages. Pmp'd the following treatment @ 40 BPM, 4600 max pressure: Stage #1: 800 bbls YFGOII Stage #2: 250 bbls YFGOII 100 mesh (10,000#) Stage #3: 300 bbls YFGOII Stage #4: 74 bbls YFGOII 20/40 (5000#) Stage #5: 102 bbls YFGOII 20/40 (8000#) Stage #6: 137 bbls YFGOII 20/40 (20,000#) Stage #7: 149 bbls YFGOII 20/40 flush (20,000#) RU Camco, RIH, tag fill @ 10,352'. PU logging, stuck @ 10,250'. Pull out of rope socket; tl left @ 10,230' MD. POOH, RD WL unit. RU to tst well. (Note: Ti left in hole = 10' wt bar 1-11/16" OD, 1' rope socket 1-11/16" OD & 3" CCL/Temp 1-7/16". Total length m 14') Drilling Supervisor Atlar ~ichfieldCompany A Daily Well History-Final Report Instructions: Prepare and submit the "Final Relse~t" on the first Wednesday aner allowable has been assigned Or well la Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations ere 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 Repolt" form may be used for reporting the entire operation if space ie available. District ~County or Parish AZaska [ North Slope Borough Field ]Lease or Unit Prudhoe Bay [ ADL ~28307 Auth. or W.O. no. [Title AFE 803570 I Completion Pool 102 AP1 50-029-21505 rAocountlng cost center code State Alaska Well no L2-29 Operator [ A.R.~. W I. ARCO Alaska, Inc. J JDate 50% Spudded or W.O. b~un Complete [ 4/08/86 fcOtalnumber of wells (active or mactwe) on this st center prior to plugging and [ andonment of this well our ]Prior status if a W.O. 1700 Hrs. Date and depth as of 8.00 a.m. 3/09/86 4/09/86 4/10/86 4/11/86 4/12/86 thru 4/14/86 Old TD Released rig Complete record for each day reported Arctic Pak w/300 sx AS I, followed by 122 bbls Arctic Pak. 7" f/9533'-10,489' 9.4 ppg NaCl Accept rig @ 1700 hfs, 4/8/86. ND tree, NU &tst BOPE. tbg hgr. RU to rn 4" tbg conveyed perf gun. Pull 7" f/9533'-10,489' 9.4 ppg NaC1 Ck 4½" tbg w/Tuboscope. string. Rev circ diesel cap. Rn 4½" frac 7" f/9533'-10,489' 10,458' PBTD, RIH w/perm pkr 9.4 ppg NaC1 Fin RIH, RU DA, rn GR/CCL f/10,190'-9050'. Perf f/9976'- 10,058' & 9840'-9944' w/4", 4 SFP, 90° phasing, POOH. Make gage ring rn to 10,190'. RIH w/perm pkr. 7" f/9533'-10,489' 10,458' PBTD, RR 9.4 ppg NaC1 RIH, set pkr @ 9630'. RIH w/4½" frac string; unable to sting into pkr, POOH. Add 2 its tbg below GLM, RIH, sting into pkr @ 9630', lnd tbg. ND BOPE, NU tree. Tst ann to 2000 psi, tbg to 2500 psi. Tat tree to 250/5000 psi. Shear out ball. RR @ HC1. ....... Fli~-geil.""~ ........... =--r ....... 11~ .............. 10,458' 2000 Hrs. 4/12/86 Rotary Ciaselflcstlons {oil, gas, etc.) Oil [ Single Producing method I Official re~olr name(s) Flowing I Llsburne Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test t~me Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. c.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87 Drilling Supervisor AR3B-459-3-B Number all daily well history forms consecutively Pa~e no I as they are prepared for each well. ARC(' il and Gas Company Daily Well History-Final Report Inatructiona: Prepare and submit the *'Final Report" on the first Wednesday after allowable has been ess;gned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations ere suspended for an indeflmte or appreciable length of time On workovers when an Official test I~ I~ot required upon completion, report completion end representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation If apace is available District Field Alaska ICounty or Parish North Slope Borough Lease or Unit ADL #28307 Title Recompletion Prudhoe Bay IAcc0unting cost center code State Alaska Well no ].2-29 W/O Auth or W O no. AFE 803570 Pool 102 Operator ARCO Alaska, Inc. Spudded or W O begun Workover Complete record for each day reporled AP1 50-029-21505 Date and depth as of 8 00 a m 4/23/66 4/24/86 4/25/86 4~26~86 Old TD Released rig 1000 Hrs. Classdications (oil, gas, etc ) Oil Producing method Flowing Potential teat data IARCo WI 50% JOate 4/22/86 Iotal number of wells (active or reactive) on this oat center prior to plugging and bandonment of this well our IPnor status If a W.O I 0630 Hrs. 7:; ~ i0,489: 9.5 ppg Brine 10,444' PBTD, Tst'g BOPE Accept. rig @ 0630 hrs, 4/22/86. Displ well w/9.4 ppg brine dn ann. Blanking plug leaking f/btm. Displ well w/9.5 ppg brine. Set BPV. ND tree, NU BOPE & tst. 7" @ 10,489' 10,444' PBTD, RIH w/2-7/8" prod tbg 9.5 ppg Brine Fin tst'g BOPE. POH, LD 4½" tbg & seal assy. Chg rams to 2-7/8" & tst. RIH w/redressed seal assy & 2-7/8" tbg to approx 1200'. 7" @ 10,489' 10,444' PBTD, Displ'g well to diesel FIH w/304 its, 2-7/8", EUE 8RD L-80, 6.5# tbg & lnd w/SSSV @ 2199'. Press tbg to 2500 psi & ann to 1500 psi. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. 7" @ 10,489' I0,444' PBTD, RR Fin displ'g well w/diesel. Press tbg to 1000 psi, bleed ann to 0 psi. Ck vlv OK. Close SSSV. Set BPV. RR @ 1000 hrs, 4/25/86. RU Camco, RIH w/retrv'g tl to pull equalizing sub, POOH. RIH w/retrv'g il, jar on plug, POH, left tl string in hole. RIH w/impression block, POH; rope socket lk'g up. RIH & fsh tl string, POH; indication that piece of wire beside fsh'g neck. ~ JNSwTD 'r---r--° ]Fg~p~ .... 10,444' JOate JK,nd of rig 4/25/86 [ota~¥ Type complehon (single, dual, etc ) Single J Ofhcml rese~mr name(s) Lisburne WeJl no 3ate Rese~,olr Producing Interval Oil or gas Test time Production O~1 on test Gas per day Pump sue, SPM X length Choke size T.P C.P Water % GOR Grawty Allowable Effective date corrected *he above Is correct 5/09/86 Drilling Supervisor For form preparation and dlstmbutlon, see Procedures Manual, Section 10, Drilhng, Pages 86 and 87 AR3B-459-3-C Number all dady well history forms consecutively as they are prepared for each well P;ge no. Division of AtlenflcRIchfleldCompany Telecopy No. (907) 276-7542 October 10, 1986 Teresa Gorup - ABV 100. ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Ms. Gorup: In an effort to make our data current, it has been found that the following materials have not been submitted to the Commission as required by 20 AAC 25.071(b) of our regulations. Please submit the following materials: (. 2) SAMPLES Well Name Completion Date Permit Number Hemi Springs Unit ~3 Winter Trails #1 4/6/85 85-22 3/7/86 86-8 ( . 3) CORE CHIPS PBU DS 3-32 4/12/86 84-107 PBU DS 16-21 9/2/86 85-312 PBU L1-9 11/19/86 85-1 PBU L~-29 4/12/86 85-297 PBU L~-23 2/28/86 85-306 PBU LGI-12 5/2/86 86-54 KRU lQ-16 6/10/85 85-47 KRU 3B-14 5/22/85 85-24 Teresa Gorup October 9, 1986 Page 2 (.3) LITHOLOGIC DESCRIPTION Well Name Completion Date PBU DS 3-32 PBU DS 16-21 PBU L1-9 PBU LGI- 12 Hemi Springs Unit #3 4/12/86 9/2/86 1/19/86 5/2/86 4/6/85 We appreciate your attention to this matter. S~ncerel~, John F. Boyle - Petroleum Engineer Assistant jo/A.JFB.4 Permit Number 84-]07 85-312 85-1 86-54 85-22 ARCO Alaska Inc. Lisburne Engineering To: State of Alaska John Boyle Date: Pam Lambert 8-4-86 Traasmitted herewith are the following: CH Finals for Lisburne Well L2-29 Gamma Ray 4-10-86 Run 1 DA Collar Log 4-11-86 Run 1 DA Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No:~ RECEIVED AUG 1986 Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM WELL: 1/13/86 4/17/86 6/01/86 L2-29 Instl ~" j~ tbg hgr, tbg head adapter, lower master vlv & tree cap. Pull circ vlv. Rn & set dummy vlv. RIH w/std'g vlv, press tst tbg to 3000 psi, POOH, RD WL. Press tbg/ann to 1500 psi. Load sand, pre-heat diesel & start gelling tanks. Att to inject; well Arctic Pak'd. Suspend operations. Drilling Supervisor Lisburne Ens~neerin~ To: State of Alaska John Boyle ~'rom: Pam Lambert Da~e: 6-2-86 are the follovir~: CH Final for Lisburne Wells ~L2-21 CET 1-8-86 Run 2 5" Sch ~L2-25 CET 2-6-86 Run 1 5" Sch '~L2-29 CET 1-21-86 Run 2 5" Sch ~'--L3-23 CET 2-18-86 Run 1 5" Sch Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lamber: AT0 477 PO Box 100360 Anchorage, Alaska 9~510 To: State of Alaska Lisburne Engineering John Boyle DaCe: Pam Lambert June 3, 1986 Traaemlcced herewith are the ~ollovir~: CH Final for Lisburne Well L2-29 Gamma Ray Log 4-20-86 Run 1 5" GO TransmicCal No: 7~/~ STATE OF ALASKA ALASKA~DIL AND GAS CONSERVATION CmVlWllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-297 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21505 4 Location of well at surface 9. Unit or Lease Name 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1456' FNL, 1176' FEL, Sec.13, T11N, R14E, UM L2-29 At Total Depth 11. Field and Pool 1205' FNL, 1379' FEL, Sec.13, T11N, R14E, UM Prudhoe Bay Field 5. Elevation ~n feet (~nd~cate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 52' RKB ADL 28307 ALK 2317 12. Date Spudded 13 DateT.D. Reached 14. Date Comp.,Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/04/85 01/06/86 01/11/86* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Direct~onaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 10490'MD,9440'TVD 10444'MD,9399'TVD YES [~X NO []I 2199 feet MD 1900' (approx) 22 Type Electric or Other Logs Run Gyro(f/2000'-4000'), DLL/MSFL/NGT, MEST/TCC/GR, LDT/CNL/EPT/PCD/GR, LSS/Waveforms/GR, RFT/GR, CET/GR, GCT, GR/( 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD IAMOUNTPULLED 20" 91.5# H-40 Surf 110' 30" 1800# Poleset 13-3/8" 68.0#/72. )# K-55/L-~;0 Surf 3985' 17-1/2" 1950 sx AS Ill & 600 sx Class G Performed top job w/40 sx AS I 9-5/8" 47.0# L-80 Surf 9736' 12-1/4" 1085 sx Class G & 300 sx AS I 7" 29.0# L-80 9533' 10489' 8-1/2" 435 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9840 ' - 9944 ' 2-7/8" 9738' 9653' 9976' - 10,058' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Acidized w/190 bt1, 15% HC1 27 N/A PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR !OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL !OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of IIthology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See core description attached to the Well Completion Report dated 01/31/86. RECEIVED MAY 2 t 1986 Commbol~. Alaska Oil & Gas Cons, '~'~ A~chom§e Form 10-40~f NOTE: Tubing was run & well perforated 4/12/86. Well was recomplet~-4/25/86, WCl/00~ubm.t in dupl.cate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 Top Wahoo Zone 1 GEOLOGIC MARKERS MEAS DEPTH TRUE VERT. DEPTH 31 LIST OF ATTACHMENTS Truncated 9839' 9960' 10,072' 10,288' 10,357' 10,419' 8875' 8978' 9074' 9261' 9322' 9377' 30. FORMATION TESTS Include ~nterval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase DEPTH HYDRO. PRESSURE SHUT-IN PRESSURE ,, , 10031' 4539 psi 4521.6 psi 9851' 4450.1 psi -- Well History (completion details & workover), Addendum (dated 4/28/86) 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge ~_~ ~~ Associate Engineer Signed Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27. Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10~407 AtlanticRichfieldCompany" 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 Rel~orr' should be submitted also when operations are suspended for an mdeflmte or appreciable length of t~me 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 enhre operation if space is available Spudded or W.O. begun Complete 4/08/86 Accounting cost center code D~stnct ICounty or Parish State Alaska I North Slope Borough Alaska Field ~Lease or Unit IWell no Prudhoe Bay I ADL 1128307 I L2-29 Auth. or W.O. no. ~Tlfle AFE 803570 [ Completion Pool 102 API 50-029-21505 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 50% I Date Date and delhi1 a~ of 8,'00 a.m. 2000 Hrs. Old TD Releaand rig 3/09/86 4/09/86 4/10/86 4/11/86 4/12/86 thru 4/14/86 Claulflcatlone (oil, ga, etc.) Oil Producing method Flowing Complete record for each day mpe~ted Iotal number of wells (active or inactive) on th~st cst center prior to plugging and I bandonment of this well our I Prior status if · W.O. I 1700 Hrs. A~ctic Pak w/300 sxAS I, followed by 122 bbls Arctic Pak. 7" f/9533'-10,489' 9.4 ppg NaC1 Accept ri& @ 1700 hfs, 4/8/86. ND tree, NU a Cst BOPE. tbs hgt. RU to rn 4" tbg conveyed perf gun. Rev circ diesel cap. 7" f/9533'-10,489' 9.4 ppg Nat1 Ck 4½" tbs w/Tuboscope. string. Rn 4½" frac 7" f/9533'-10,489' 10,458' PBTD, RIH w/perm pkr 9.4 ppg NaC1 ---- Fin RIH, RU DA, rn GR/CCL f/10,190'-9050'. Perf f/9976~.~ 10,058' & 9840'-9944' w/4", 4 SFP, 90° phasing, ~OOH. a~ gage ring rn to 10,190'. RIH w/perm pkr. ~.~ 7" f/9533'-10,489' ~ 10,458' PBTD, RI[ 9.4 ppg NaC1 RIH, set pkr @ 9630'. RIH w/4½" frac string; unable to sting into pkr, POOH. Add 2 its tbg below GLM, RIH, sting into pkr @ 9630', lnd tbg. ND BOPE, NU tree. Tat ann to 2000 psi, tbg to 2500 psi. Tst tree to 250/5000 psi. Shear out ball. RI[ @ ....... -~--r ....... '[Fa ff~ / 10,458' Kind of rig 4/12/86 Rotary Type completion (single, duel, etc.) Single Official reservoir name(e) Lisburne Potential test data Well no. Date Reservoir Producing Inten~el Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % iGOR Gravity Allowable Effective date corrected The above is correct Date [Title 4/26/86 For form preparation and d~stnbution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor 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 submdted also when operations are suspended for an md.hate or appremable length of time On workovers when an offrmal test ~s 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 Spudded or W O. begun Workover I Accountmg cost center code D~str~ct JCounty or Parish J State Alaska j North Slope Borough J Alaska F~eld [Lease orUnit IWeII no Prudhoe Bay ADL #28307 L2-29 W/O Auth. or W O. no ~ Tdle AFE 803570 I Recompletion Pool 102 API 50-029-21505 OperatorARCO Alaska, Inc. IA R C° w .50% IabandOnmentlcOstrr°tal number °f wells (act've °r 'nact've) °n th'sIcenter pr,Orof thist° pluggingwell and 4/22/86 ! 0630 Hrs. Date and depth as of 8:00 a.m. 41zsls6 4/24/86 4/25/86 4/26/86 Complete record for each day reported 7" ~ 10,489: 9.5 ppg Brine 10,444' PBTD, Tst'g BOPE Accept rig @ 0630 hfs, 4/22/86. Displ well w/9.4 ppg brine dn ann. Blanking plug leaking f/btm. Displ well w/9.5 ppg brine. Set BPV. ND tree, ND BOPE &tst. 7" @ 10,489' 10,444' PBTD, RIE w/2-7/8" prod tbg 9.5 ppg Brine Fin tst'g BOPg. POE, LD 4~" tbg & seal easy. Chg rams to 2-7/8" & tat. RIH w/redressed seal assy & 2-7/8" tbg to approx 1200 '. 7" @ 10,489' 10,444' PBTD, Displ'g well to diesel FIR w/304 its, 2-7/8", EUE 8RD L-80, 6.5# tbg & lnd w/SSSV 2199'. Press tbg to 2500 psi & ann to 1500 psi. ND BOPE, tst tree to 5000 psi. Displ well w/diesel. 7" @ 10,489' 10,444' PBTD RR gl.J ' Fin displ'g well w/diesel. Press tbg to 1000 psi, bleed an~-~ 0 psi. Ck vlv OK. Close SSSV. Set BPV. RR @ 1000 hrs,LJ.J 4/25/86. RU Camco, RIH w/retrv'g ti to pull equalizing sub, POOH. RIH w/retrv'g il, Jar on plug, POH, left tl string in hole. RIH w/impression block, POH; rope socket lk'g up. RIH & fsh ti string, POH; indication that piece of wire beside fsh'g neck. Old TD Released rig 1000 Hrs. Classifications (oil. gas, etc.) Oil J N~w TO I JDate Producing method Flowing - ~---- ~---o- --]F~ep~ .... / 4/25/86 IK,.~ of rig 10,444' Rotary IType completion (stogie, dual, etc ) Single Official rese~oir name(s) Lisburne Potential test data Well no. Date Reservoir Producing Interval Od or gas Test time Production Oil on test Gal per day Pump size. SPM X length Choke raze T P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Supervisor For form preparation and distrlbuhon, see Procedures Manual, Section 10, Drilhng, Pages 86 and 87. ADDENDUM WELL: 1/13/86 4/17/86 L2-29 Instl 5½" tbg hgr, tbg head adapter, lower master vlv & tree cap. Pull circ vlv. Rn & set dummy vlv. RIH w/std'g vlv, press tst tbg to 3000 psi, POOH, RD WL. Press tbg/ann to 1500 psi. Load sand, pre-heat diesel & start gelling tanks. MAY 2 1 1986 .... · .~ .,, ~ ,.;,~.s Cons. Commis$!' Drilling Supervisor Date STATE OF ALASKA ALASKf, .~L AND GAS CONSERVATION COMMI,_ ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Reques[: Abandon ~ Suspend ~ Operation Shutdown ~/7'~:~e-enter suspended well ~ Alter casing Time extension ~ Change approved program ~ Plugging ~ Stimulate ~,, Pull tubing ~ Amend order ~3 Perforate ~,~Other~ 2. Name of Operator ARCO Alaska, Inc 3. Address P, 0, Box I 00360 Anehorng~. _ AK qgR1 ¢) 4. Location of well at surface 1961'FSL,. 1010'FWL, Seco18, T11N, R15E, UM At top of productive interval 1456'FNL, 1176'FEL, Sec.13, T11N, R14E, UM At effective depth 1222'FNL, 1366'FEL, Seco13, T11N, R14E, UM At total depth 1205'FNL, 1379'FEL, Sec.13, T11N, R14E, UM 5. Datum elevation (DF or KB) 52 ' RKB feet 6. Unit or Property name Prudhee _~>' Un'.'t/L!sburnc 7. Well number 1.2 -?9 8. Permit number 85-297 9. APl number 50-- 029-21505 10. Pool Lisburne 0i] Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 71 ' Surface 3946' 1 0,490 ' feet feet 9440 ' 10,444' feet 9399 ' feet Size 20" 13-3/8" 9 -5/8" 7" Producti on 9699 ' Liner 956 ' Perforation depth: measured None true vertical N o ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal~j~,,. Plugs (measured) Junk (measured) Cemented Poleset 1950sx AS II I & 600sxClass"G" & 40sx AS I top job 1085 sx Class "G" 435sx Class G Measured depth 110'MD 3984'ND 9736'MD 9533 'MD- 10489'MD True Vertical depth 110'TVD 3979 'TVD 8786'TVD 8613'TVD- 9440'TVD RECEIVED APR 1 0 1986 Alaska 0ii & Gas go.qs. Co~mission Detailed opetAar~¥g~[~(::~ogram C BOP sketch 13. Estimated date for commencing operation April 12, 1986 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 &~ ~ Title Associate Engineer Commission Use Only ( JJG ) SA/004 Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Location clearance I Approved by ,~pproved Copy ~®turned . Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate L2-29 SUNDRY APPROVAL STIMULATION PROCEDURE 1. MIRU Pool 102. 2. NU BOPE and test. 3. Perforate 9840' - 9944' and 9976' - 10,058'. 4. Run 4-1/2", 12.75#, BTC frac string and 7" permanent packer to approximately 9695'MD. 5. ND BOPE. Install 4-1/2" tree. 6. RDMO. 7. Acidize well with approximately 8,000 gals 15% inhibited HC1 and flow test well. 8. Fracture stimulate with approximately 81,000 gals gelled diesel and 77,000 lbs intermediate strength proppant. 9. M I RU Pool 102. 10. Kill well. Install BOPE. 11. Pull 4-1/2" frac string. 12. Run 2-7/8" completion assembly with mandrel s. SSSV below permafrost and gas lift 13. Remove BOPE. Install production tree. SA/OO4a:tw RECE!V D To: ARCO Alaska Inc. ~- Lisburne Engineering State of Alaska }~'ro~: Pam Lambert ~'-~ ~/~ John Boyle Date: March 21~ 1986 Transmitted herewith are the following: Final Print for Lisburne Well L2-29 Stratigraphic HIGH-Res. Dipmeter Run 1 Sch Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: (~1 To: ~t=te oF _A_!as~=_ ~ Lisburne Engineering ~-~_ From: Para Lamb er t ~'x(~'~~~3 ~¢ 7ohn Boyle Date: February 27, 1986 Transmitted herewith are the following: Magnetic Tapes for Lisburne Wells L2-29 OH LIS Shifted Run 1 Tape Number 71151 Sch 1-6-86 L3-23 OH LIS Unshifted Run 2 2-6-86 Tape Number 71255 Sch PO Box 100360 Anchorage, Alas~ 99510 ARCO Alaska, Inc. Post Office b"~ 100360 Anchorage~ Alaska 99510-0360 Telephone 907 276 1215 February 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- L2-29 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for L2-29. Tubing details will be submitted when the well is completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L129 Enclosures Alaska 0il & Gas Cons." ARCO Alaska, Inc is a Subsidiary of AtlanhcR~chf~eldCompany STATE OF ALASKA ALASK/~OfL AND GAS CONSERVATION C-O1~i~ ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL [] GAS [] SUSPENDED--[~X ABANDONED [] SERVICE [] 2 Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-297 3 Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5o- 029-21505 4. Location of well at surface L")~;,",-"JL-31~$1 9. Unit or Lease Name 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UNik ,VZ2',PIED il Prudhoe Bay Unit/Lisburne At Top Producing Interval Sur~._.__l~ 10. Well Number 1456' FNL, 1176' FEL, Sec.13, TllN, R14E, UN IB.H.-I,~r/ L2-29 At Total Depth 11. F~eld and Pool 1205' FNL, 1379' FEL, Sec.13, T11N, R14E, UM Prudhoe Bay Field 5 Elevation ~n feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 52' RKB ADL 28307 ALK 2317 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. 115. Water Depth, ~f offshore 116. No. of Complet~ons 1 2/04/85 01/06/86 01/11/86I N/A feet MSLI N/A 17 Total Depth (MDFTVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Th~ckness of Permafrost 10490 'MD ,9440 'TVD 10444'MD,9399'TVD YES [Z~x NO []I N/A feet MD 1900' (approx) 22. Type Electric or Other Logs Run Gy to( f/2000' -4000 ' ), DLL/MSFL/NGT, MEST/TCC/GR, LDT/CNL/EPT/PCD/GR, LSS/Waveforms/GR, RFT/GR, CET/GR, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 1800# Poleset 13-3/8" 68.0#/72.,)# K-55/L-iO Surf 3985' 17-1/2" 1950 sx AS Ill & 600 sx Class G Performed top job w/40 sx AS I 9-5/8" 47.0# L-80 Surf 9736' 12-1/4" 1085 sx Class G 7" 29.0# L-80 9533' 10489' 8-1/2" 435 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ~nterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A -_ ,. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27 N/A PRODUCTION TEST Date F~rst Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I FIowTub~ng CasmgPressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of I~thology, porosity, fractures, apparent dips and presence of o~1, gas or water. Submit core chips. See attached core description. Form 10-407 DAI~'~/WC05 Submit ~n dupl,cate Rev. 7~1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 Top Wahoo Zone 1 GEOLOGIC MARKERS MEAS DEPTH Truncated 9839 ' 9960 ' 1 0,072 ' 10,288' 1 0,357 ' 10,419' TRUE VERT DEF~.TH. 8875' 8978' 9074' 9261' 9322' 9377' 30. FORMATION TESTS ~ Ipc~lu ~e ~'~ter¥~L'tCsl[ed~ pressure data, all fluids recovered and gravity, 'GOR, ~ni:ljt~r~t~ 0~,~.'acJ~i phase. RFT data to be submitted when received. 31 LIST OF ATTACHMENT/S Gyroscopic Su 7v~e 32 I he,eby certify that the foregoing ~s true and correct to the best of my knowledge _~_ ~ Associate Engineer S,gned _~ _ ~ T,tte Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1. Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28. If no cores taken, indicate "none". Form 10407 ARCO Oil and Gas Company '~' Well History - Initial Report- Daily Inatructlona: Prepare and submit the "Initial Report" on the hrst 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 CONFIDENTIAL District Alaska F~eld Prudhoe Bay Auth, or W 0 no AFE 803570 Rowan 41 ICounty, parish or borough North Slope Borough ILease or Unit ADL #28307 IT,tie Drill IState Alaska Well no L2-29 API 50-029-21505 Operator ARCO Alaska, Inc. Spudded or W O begun Spudded Data and depth as of 8 00 a m 12/o5/85 12/06/85 12/07/85 thru 12/09/85 12/10/85 12/4/85 IH°ur 2230 Hrs. Complete record for each day reported 20" @ 110' 711', (601'), Drlg Wt. 8.7, PV 9, YP 50, PH 9.6, WL 15, Sol 3 NU diverter sys. Accept rig @ 1700 hrs, 12/4/85. 2230 hrs, 12/4/85. Drl 17~" hole to 711'. 20" @ 110' 3330', (2619'), Drlg Wt. 9.6, PV 11, YP 48, PH 8.5, WL 32, Sol 9 Drl 17½" hole to 3330'. IARCO W l 50% Prior status ~f a W O Spud well @ 13-3/8" @ 3985' 4568', (1238'), POH Wt. 8.5, PV 3, YP 4, PH 12.7, WL 100, Sol 1.5 Drl to 4000', 27 std short trip, C&C, POOH. RU & rn 100 its, 13-3/8", 72#, L-80 BTC csg w/FS @ 3985', FC @ 3900'. Cmt w/1950 sx AS III, followed by 600 sx C1 "G" w/2% CaC13 Displ using rig pmps, bump plug. CIP @ 0500 hrs, 12/07/85."'ND diverter. Perform 40 sx AS I top job. NU & tst BOPE. TIH to FC, tst csg to 2500 psi. DO FC, cmt, FS + 10' new formation. Rn gyro f/2000'-4000'. Conduct formation tst to 16.2 ppg EMW. Drl, DD & surv 12¼" hole to 4568'. 4143', 9.9°, S52.4W, 4133.83 TVD, -46.78 VS, 4513', 21.9°, NS1.2W, 4484.32 TVD, 33.02 VS, -125.22S, - 44.74W -156.84S, -152.70W 13-3/8" @ 3985' 4124', Sidetrack Wt. 8.7, PV 3, YP 7, PH 12.7, WL 70, Sol 2.5 POH, LD DD. RIH w/DP open ended, PU 49 its DP, tag btm @ 4568'. Spot cmt plug @ 4568' w/455 sx C1 "G" w/.75% D-65 & .2% D-46. Displ using rig pmps. CIP @ 1148 hrs, 12/9/85. POH 10 stds, circ hole cln, LD 35 its "E" DP & 24 its "G" DP. RIH w/HWDP & drlg assy, tag cmt @ 4089', circ hole cln, POH. PU DD, RIH, att sidetrack f/4104'-4124'. The above is correct Signatur~.)Z For form preparation and d*s~lbutlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87 IDato 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form ~s used during drilling or workover operations If testing, coring, or perforahng, show formation name in describing work performed Number afl drill stem tests sequentially Attach description of all cores Work performed by Producing Section wdl be reported on "Interim" sheets untd final complehon Report ofhc~al or representative test on "Final" form 1) Submd "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oH string ~$ set Submit weekly for workovers and following setting of oll string until completion District jCounty or Parish J State Alaska North Slope Borough F~eld ~Lease or Umt Prudhoe Bay I ADL #28307 Date and depth as of 800 am, 12/11/85 12/12/85 12/13/85 12/14/85 thru 12/16/85 12/17/85 Alaska Well no L2-29 Complete record for each day while drdhng or workover In progress 13-3/8" @ 3985' 5553', (1429'), Drlg Wt. 8.6 Frsh wtr DD, drl & surv 12¼" hole to 5553'. 4141', 6.9°, S52W, 4132.38 TVD, -47.71VS, 122.73S, 41.63W 4388', 7.1°, N86.5W, 4377.40 TVD, -27.79 VS, 132.64S, 70.46W 4669', 10.0°, N58.3W, 4655.43 TVD, 12.29 VS, 115.82S, 106.76W 4914', 14.7°, N51.7W, 4894.41 TVD, 65.90 VS, 84.22S, 150.13W 5374', 24.9°, N47.4W, 5327.30 TVD, 219.60 VS, 15.15N, 267.41W 13-3/8" @ 3985' 6720', (1167'), Drlg Wt. 9.2+, PV 5, YP 14, PH 10.7, WL 19, Sol 7 Drl & surv 12¼" hole to 6720'. 5620', 30.0°, N46.7W, 5545,53 TVD, 332.84 VS, 92.39N, 350.39W 6019', 40.0°, N46.0W, 5872.29 TVD, 553.79 VS, 250.25N, 515.03W 6661', 40.6°, N45.0W, 6357.65 TVD, 972.78 VS, 546.39N, 813.14W 13-3/8" @ 3985' 7227', (507'), Drlg Wt. 9.4, PV 9, YP 19, PH 9.6, WL 8.2, Sol 10 Drl & surv 12¼" hole to 7227'. 6816', 40.1°, N45.0W, 6475.77 TVD, 1072.85 VS, 617.35N, 884.10W 7077', 42.0°, N45.0W, 6672.59 TVD, 1243.75 VS, 738.54N, 1005.29W 13-3/8" @ 3985' 9160', (1933'), Surv'g Wt. 10.1, PV 12, YP 13, PH 10.3, WL 5.8, Sol 12 Drl, DD & surv 12¼" hole to 9160'. 7310', 44.5°, N44.6W, 6842.15 TVD, 1402.97 VS, 851.92N, 1117.88W 7871', 44.4°, N44.6W, 7232.28 TVD, 1803.79 VS, 1144.63N, 1394.92W 8303', 32.2°, N50.6W, 7576.83 TVD, 2063.02 VS, 13t5.62N, 1589.64W 8730', 33.2°, N47.4W, 7937.08 TVD, 2292.17 VS, 1466.44N, 1762.21W 8878', 33.9°, N48.2W, 8060.43 TVD, 2373.94 VS, 1521.38N, 1822.80W 13-3/8" @ 3985' 9408', (248'), POH Wt. 10.2, PV 10, YP 9, PH 10.6, WL 6.0, Sol 13 Drl & surv to 9408', pmp hi-vis sweep, raise mud wt to 10.2 ppg, POH, lost 3 cones on bit. RIH w/mill & JB to 9324', rm to 9408'. Mill on junk @ 9408', circ gas cut mud, mill on junk, POH. 9135', 32-1/2°, N42-3/4W, 8275.47 TVD, 2513.73 VS, 1620.02N, 1923.09W 9353', 32°, N40-3/4W, 8460.34 TVD, 2628.93 VS, 1706.46N, 2000.22W The above is correct Signature For form preparation and dq~nbuhon see Procedures Manual Section 10, Drdhng, Pages 86 and 87 Date [T~tle 2/07/86 Drilling Superintendent ARCO Oil and Gas Company ~"Daily Well History--Interim Instructions: Th~s form is used dumng drdhng or workover operations If teshng, coring, or perforabng, show formation name In descmblng work performed. Number alt drdl stem tests sequentially Attach description of all cores Work performed by Producing Secbon wdl be reported on "Interim" sheets unbl final complehon Report offlcml 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 ~n which oH string ~s set Submit weekly for workovers and fotlowmg setting of OlJ strong until complehon Dmtr,ct ]County or Par,sh IState Alaska ILease or Un,t North Slope Borough ADL #28307 Complete record for each day whde drdhng or workover ~n progress F~eld Prudhoe Bay Date and deptll as of 800 am 12/18/85 12/19/85 12/20/85 12/21/85 thru 12/23/85 12/24/85 Alaska Well no ]_,2-29 13-3/8" @ 3985' 9415', (7'), Drlg Wt. 10.2, PV 10, YP 8, PH 10.6, WL 5.6, Sol 13 POH, chg BHA. TIH to 9356', rm to 9409', mill on junk to 9409' TOH. TIH w/new BHA, rm to 9409', drl to 9415'. 13-3/8" @ 3985' 9647', (232'), Drlg Wt. 10.2, PV 11, YP 10, PH 10.0, WL 6.0, Sol 13 Drl f/9415'-9430', POH, chg bit. RIH w/bit & JB, wsh 108' to btm, CBU, drl to 9514', POH, rec'd junk. RIH w/new bit, rm 80' to 9514', drl to 9647'. 13-3/8" @ 3985' 9760', (117'), Circ Wt. 10.2, PV 12, YP 10, PH 10.6, WL 5.6· Sol 13 Drl to 9760', 10 std wiper trip, CBU, POH. Chg rams to 9-5/8" & tst. RU & rn 141 ]ts, 9-5/8", 47#, L-80 BTC csg, well started flowing. SI & circ thru choke. 9710', 31.5°, N42.75W, 8763.91TVD, 2815.84 VS, 1846.61N, 2125.30W 9-5/8" @ 9736' 9861', (101'), Coring Wt. 9.4, PV 12, YP 11, PH 8.6, WL 4.0, Sol 4.5 Circ csg on choke, raise mud wt to 10.5 ppg. RU & rn 71 more ]ts, 9-5/8", 47#, L-80 csg; well flowing. Circ csg on choke @ 8603', balance mud wt. Rn 27 more ]ts 9-5/8" csg; unable to lnd on 9-5/8" hgr. Tag btm @ 9735', circ, att to wsh dn. Cmt w/1085 sx C1 "G" while circ'g. Displ using rig pmps. Did not bump plug. CIP @ 2030 hrs, 12/20/85. NU & tst BOPE. RIH w/8½" BHA, tag cmt to 9546', DO cmt to 9636', tst csg to 3500 psi. DO FC @ 9645', FS @ 9736', new formation to 9770'. Conduct formation tst to 12.5 ppg EMW. Build vol of bland mud & displ hole. Drl 8½" hole to 9849', CBU, POH. PU core bbl, RIH, cut core #1 f/9849'-9861', incompl. 9-5/8" @ 9736' 9880', (19'), LD Core #2 Wt. 9.4, PV 13, YP 8, PH 8.4· WL 4.4, Sol 4.5 Fin core #1 to 9865', POH, rec'd 15' Core · POH The above is correct For lorm preparation and dlstrlbut~)n see Procedures Manual Section 107 Drilhng, Pages 86 and 87 Date IT,Ue 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: Th~s form ~s used during drdhng or workover operations If testing, coring, or perforahng, show formation name tn descmbmg work performed Number aH drdl stem tests sequenhally Attach description of all cores Work performed by Producing Sechon wdl be reported on "Interim" sheets untd hnal completion Report ofhc~al or represenfat~ve test on "Final" form 1) Submit "Interim" sheets when hlled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oll string is set SubmH weekly for workovers and following setting of oH string until complehon Distr~ct F~eld Alaska County or Parish ]State North Slope Borough IL ADL #28307 ...... Umt Prudhoe Bay Alaska Well no L2-29 Date and deptl~ as of 800 am 12/25/85 thru 12/26/85 12/27/85 12/28/85 thru 12/30/85 12/31/85 1/01/86 thru 1/02/86 1/03/86 1/04/86 thru 1/06/86 Complete record for each day while drdhng or workover In progress 9-5/8" @ 9736' 9916', (36'), Coring Wt. 9.4, PV 10, YP 8, PH 8.2, WL 4.0, Sol 5 Rec'd 9' f/core #2. Core #3, 9880'-98878', rec'd 6'. 9887'-9897', rec 9'. Core #5 f/9897'-9916', incompl. Core #4, 9-5/8" @ 9736' 9928', (12'), Coring Wt. 9.4, PV 8, YP 6, PH 8.2, WL 4.0, Sol 5 Fin core #5 to 9917', rec'd 20'. Core #6, 9917'-9924' 7'. Core #7 f/9924'-9928', incompl. , rec'd 9-5/8" @ 9736' 9928', (12'), Coring Wt. 9.4, PV 8, YP 6, PH 8.2, WL 4.0, Sol 5 Fin core #7 to 9929', rec'd 5'. Core #8 f/9929'-9946', rec'd 17'. Core #9 f/9946'-9951', rec'd 3'. TIH, drl f/9951'-9971' CBU, POH. Core #10, 9971'-9986', rec'd 14'. Core #11 f/9986'-9991', TOH. 9-5/8" @ 9736' 10,001', (10'), Coring Wt. 9.4, PV 8, YP 10, PH 7.9, WL 5.0, Sol 5 Rec'd 4' f/core #11. Core #12, 9991'-10,001' w/core #13. , rec'd 10'. TIH 9-5/8" @ 9736' 10,041', (40'), POH w/bit Wt. 9.4, PV 9, YP 10, PH 7.9, WL 5.2, Sol 5 Core #13 f/10,O01'-10,008', rec'd 5'. Core #14 f/10,008'-10,010', rec'd 1'. Core #15 f/lO,O10'-10,040', rec'd 5'. RIH w/8½" bit, wsh 50' to btm, drl 10,040'-10,041', CBU, POH. 9-5/8" @ 9736' 10,060', (19'), Coring Wt. 9.4, PV 9, YP 7, PH 7.9, WL 5.2, Sol 5 Core #16 f/10,041'-10,052', rec'd 7'. Core #17 f/10,052'-10,060', incompl. 9736' (429'), Wiper trip PV 9, YP 13, PH 7.7, WL 5.6, Sol 5 9-5/8" @ 10,489', Wt. 9.4+, Fin core #17 to 10,063', rec'd 10'. Core #18 f/10,063'-10,088' rec'd 25'. Core #19 f/10,088'-10,094', rec'd 3'. LD core equip, PU 8½" BHA. RIH, rm 50' to btm, drl f/10,094'-10,489'. The above is correct Signature For form preparation and dl~l[rlbuhon see Procedures Manual Section 10, Drdhng, Pages 86 and 87 IOate ITitle 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form ~s used dunng drilling or workover operahons If testing, coring, or perforahng, show formahon name m describing work performed Number all drill stem leers sequerHlatly Attach clescr~phon of all cores Work performed by Producing Sechon wdl be reported on "Interim" sheets until final complehon Report official or representahve test on "Fmat" 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 oll string is set Submit weekly for workovere and following sethng of o~1 string until completion D~strlct Alaska North Slope Borough County or Parish Fmld Lease or Unit Prudhoe Bay ADL #28307 Date and depth Complete record for each day whde drdhng or workover ~n progress as of 800 am State Alaska Well no L2-29 1/07/86 1/08/86 1/09/86 1/10/86 9-5/8" @ 9736' 10,490', (1' correction), Logging Wt. 9.4+, PV 12, YP 13, PH 7.6, WL 5.4, Sol 5 Make 8 std short trip, CBU, POH. RU SOS, run #1DLL/MSFL/NGT 0,485'-9728' Rn LDT/f/1/CNL/EPT/PCD'GR' #2, MEST/TCC/GR logs. Rn #3, Rn #4, LSS w/waveforms/GR. 9-5/8" @ 9736' 10,490', (0'), Prep to rn 7" lnr Wt. 9.4+, PV 12, YP 14, PH 7.8, WL 5.6, Sol 5 Rn #5, RFT/GR. Rn #6, CET/GR f/9726'-6997', RD Schl. RIH, had 10' fill, C&C, POH. RU to rn 7" lnr. Tst BOPE. 7" f/9533'-10,489' 10,490' TD, 10,318' PBTD, PU 3½" DP Wt. 9.4, PV 12, YP 14, PH 8.1, WL 5.4, Sol 5 Rn 22 jts, 7", 29#, L-80 BTC lnr w/FC @ 10,445', FS @ 10,489', Tie-Back Slv@ 9546'. Cmt w/435 sx cmt slurry of C1 "G" w/Flyash, .2% D-20, .8% D-112 & .2% D-46. Displ using rig pmp. Recip lnr. CIP @ 2030 hrs, 1/8/86. POH, LD 8½" BHA, PU 3½" DP. 7" 9533'-10,489' 10,490' TD, 10,443' PBTD, Drlg cmt Wt. 9.3, PV 10, YP 10, PH 11.2, WL 5.8, Sol 5 TIH, tag soft cmt @ 8939', drl to 9533' TOL, circ, TOH w/9-5/8" scrpr. TIH w/7" csg scrpr to TOL, no cmt. TIH to 10,223', rm 95' cmt to LC @ 10,318'. Tst csg & lnr lap to 3000 psi. DO LC & cmt to FC @ 10,444'. The above is correct Signature For form preparation and dlstrlbutlll~n see Procedures Manual Sec.on 10,' Dnlhng, Pages 86 and 87 IDate IT~tle 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well-History-Final Report Instructions- Prepare and submH Ihe "Final Reporl" on the hrst Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold "Final Rel~ort" should be submdted also when operations are suspended for an ~ndeflmte or appreciable length of time On workovers when an official test is not required upon completion, report completion and representative test data m blocks prowded The "Final Report" form may be used for reportrng the entire operahon ~f space ~s avadable Accountmg cost center code District Alaska F~eld Prudhoe Bay Auth or W O no AYF. 803570 County or Palish Lease or Unit Title North Slope Borough ADL #28307 Drill State Alaska Iwe" L29 Rowan 41 Operator ARCO Alaska, Inc. ARCo WI 50% Spudded or W O begun Date Spudded 12/4/85 Date and depth Complete record for each day reported as of 8 00 a m Old TD Released r~g 1/11/86 API 50-029-21505 I otal number of wells (achve or ~nachve) on th~s pst center prior to plugging and bandonment of th~s well our I Prlor status if a W.O. 2230 Hrs. 7" f/9533'-10,489' 10,490' TD, 10,444' PBTD, RR 9.4 ppg NaC1 brine Circ, tst csg & lnr to 3000 psi. Displ mud w/9.4 ppg NaC1 brine, POOH, LD DP. Place 400' diesel cap in well. ND BOPE, NU tbg head & lower master vlv & tst; OK. Spot 80 bbl crude/diesel cap in 13-3/8" x 9-5/8" ann. RR @ 0600 hrs, 1/11/86. INew TD Date 10,490' PB Depth Kind of mg 10,444' 0600 Hrs. 1/11/86 Rotary Classd~cahons (od, gas, etc ) Type complehon (single, dual, etc ) Oil Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Well no Dale Reservmr Producing Interval Oil or gas Test time Produchon Oil on test Gas per day Pump size. SPM X length Choke size T P C P Water % GOR Grawty Allowable Effective date corrected The above Is correct Signature I Date I Title ~,..)~,/ ~.___~_~._...,j 2/07/86 For form preparat,on a~ d,strlbutioZ ~' see Procedures Manual, Section 10, Drdhng, Pages 86 and 87 Drilling Superintendent ARCO OII and Gas Company Well History - Initial Report - Daily Ir~slruclJolll; Prepare and suDm~t the "Initial RaDort" on Ihe hrst Wednesday alter a well is spudded or worKover operations are star, ed DadyworkprlortoSPuddlng should b ..... a d on .... the,o,., .... ..... .... ', CONFIDENTIAL DiStriCt F~eld I County par,eh or Oorough IState Alaska North Slope Borough Alaska I L ...... Uo.t #28307 ADL Drill Prudhoe Bay Auth. or W O no AFE 803570 Rowan 41 Well no L2-29 API 50-029-21505 Operator JAMCO W I ARCO Alaska, Inc. J 50% SpuddedorWO begun Ioa,e IHour P ..... tatusdaWO Spudded 12/4/85 2230 Hrs. Date and depth as of 8 (30 a m 12/05/85 12/06/85 12/07/85 thru 12/09/85 12/10/85 Complete record for each day reporled 20" @ 110' 711', (601'), Drlg Wt. 8.7, PV 9, YP 50, PH 9.6, WL 15, Sol 3 NU diverter sys. Accept ri~ @ 1700 hrs, 12/4/85. 2230 hrs, 12/4/85. Drl 17~" hole to 711'. 20" @ 110' 3330', (2619'), Drlg Wt. 9.6, PV 11, YP 48, PH 8.5, WL 32, Sol 9 Drl 17½" hole to 3330'. Spud well @ 13-3/8" @ 3985' 4568', (1238'), POH Wt. 8.5, PV 3, YP 4, PH 12.7, WL 100, Sol 1.5 Drl to 4000', 27 std short trip, C&C, POOH. RU & rn 100 jts, 13-3/8", 72#, L-80 BTC csg w/FS @ 3985', FC @ 3900'. Cml w/1950 sx AS III, followed by 600 sx C1 "G" w/2% CaCi~. Displ using rig pmps, bump plug. CIP @ 0500 hrs, 12/07/85.~ ND diverter. Perform 40 sx AS I top job. NU & tst BOPE. TIH to FC, tst csg to 2500 psi. DO FC, cmt, FS + 10' new formation. Rn gyro f/2000'-4000'. Conduct formation tst to 16.2 ppg EMW. Drl, DD & surv 12¼" hole to 4568'. 4143', 9.9°, S52.4W, 4133.83 TVD, -46.78 VS, -125.22S, - 44.74W 4513', 21.9°, N81.2W, 4484.32 TVD, 33.02 VS, -156.84S, -152.70W 13-3/8" @ 3985' 4124', Sidetrack Wt. 8.7, PV 3, YP 7, PH 12.7, WL 70, Sol 2.5 POH, LD DD. RIH w/DP open ended, PU 49 jts DP, tag btm @ 4568'. Spot cml plug @ 4568' w/455 sx Cl "G" w/.75% D-65 & .2% D-46. Displ using rig pmps. CIP @ 1148 hrs, 12/9/85. POH 10 stds, circ hole cln, LD 35 jts "E" DP & 24 jts "G" DP. RIH w/HWDP & drlg assy, tag cml @ 4089', circ hole cln, POH. PU DD, RIH, att sidetrack f/4104'-4124'. Oil & Gas Cons, The above ~s correct Slgn8ture For form preparation and disl~butlon, see Procedures Manual. Section 10. DrHhng, Pages 86 and 87. Joat. 2/07/86 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim In,,Iructlon- This form ~s used during drHhng or workover operations If testing, coring or perforating show formation name ~n describing work performed Number ail drdl stem lesls sequenha/~y Atlach desc,pl~on of all cores Work performed by Produong Sechon wdl be reported on "lnlertm' sheets untd hnal com!Dlehon Report offloal or representahve test on "Final" form 1) Submit "Interim" sheets when fdled out but not less frequently than every 30 days. or (2/ on Wednesday of [he week in wl~lcn Oll string is set Submit weekly for workovers and following setting of Oll strm~ until completion District ICounty orParish IState Alaska North Slope Borough Alaska F~eld ~Lease or Umt Well no Prudhoe Bay I ADL #28307 L2-29 12/11/85 12/12/85 Date and depth as of 800 am. 12/13/85 12/14/85 thru 12/16/85 12/17/85 Complete record for each day whde drHhng or workover in progress 13-3/8" @ 3985' 5553', (1429'), Drlg Wt. 8.6 Frsh wtr DD, drl & surv 12¼" hole to 5553'. 4141', 6.9°, S52W, 4132.38 TVD, -47.71VS, 122.73S, 41.63W 4388', 7.1°, N86.5W, 4377.40 TVD, -27.79 VS, 132.64S, 70.46W 4669', 10.0°, N58.3W, 4655.43 TVD, 12.29 VS, 115.82S, 106.76W 4914', 14.7°, N51.7W, 4894.41TVD, 65.90 VS, 84.22S, 150.13W 5374', 24.9°, N47.4W, 5327.30 TVD, 219.60 VS, 15.15N, 267.41W 13-3/8" @ 3985' 6720', (1167'), Drlg Wt. 9.2+, PV 5, YP 14, PH 10.7, WL 19, Sol 7 Drl & surv 12¼" hole to 6720'. 5620', 30.0°, N46.7W, 5545,53 TVD, 332.84 VS, 92.39N, 350.39W 6019', 40.0°, N46.0W, 5872.29 TVD, 553.79 VS, 250.25N, 515.03W 6661', 40.6°, N45.0W, 6357.65 TVD, 972.78 VS, 546.39N, 813.14W 13-3/8" @ 3985' 7227', (507'), Drlg Wt. 9.4, PV 9, YP 19, PH 9.6, WL 8.2, Sol 10 Drl & surv 12¼" hole to 7227'. 6816', 40.1°, N45.0W, 6475.77 TVD, 1072.85 VS, 617.35N, 884.10W 7077', 42.0°, N45.0W, 6672.59 TVD, 1243.75 VS, 738.54N, 1005.29W 13-3/8" @ 3985' 9160', (1933'), Surv'g Wt. 10.1, PV 12, YP 13, PH 10.3, WL 5.8, Sol 12 Drl, DD & surv 12¼" hole to 9160'. 7310', 44.5°, N44.6W, 6842.15 TVD, 1402.97 VS, 85i.92N, 1117.88W 7871', 44.4°, N44.6W, 7232.28 TVD, 1803.79 VS, 1144.63N, 1394.92W 8303', 32.2°, N50.6W, 7576.83 TVD, 2063.02 VS, 1315.62N, 1589.64W 8730', 33.2°, N47.4W, 7937.08 TVD, 2292.17 VS, 1466.44N, 1762.21W 8878', 33.9°, N48.2W, 8060.43 TVD, 2373.94 VS, 1521.38N, 1822.80W 13-3/8" @ 3985' 9408', (248'), POH Wt. 10.2, PV 10, YP 9, PH 10.6, WL 6.0, Sol 13 Drl & surv to 9408', pmp hi-vis sweep, raise mud wt to 10.2 ppg, POH, lost 3 cones on bit. RIH w/mill & JB to 9324', rm to 9408'. Mill on junk @ 9408', circ gas cut mud, mill on junk, POH. 9135', 32-1/2°, N42-3/4W, 8275.47 TVD, 2513.73 VS, 1620.02N, 1923.09W 9353', 32°, N40-3/4W, 8460.34 TVD, 2628.93 VS, 1706.46N, 2000.22W The above ~s correct S,gnature [Date T,tle , ~'~i ~,l~;~,~, )- ~ ~J~,,~ ~G.__ _...,,~_~_...¢.j 2/07/86 ['~ ~¥i ~a~{rintendent For form prepara.on and d~mbuhon see Proco~uros Manual Soc~on ~0, ~ ~ ~ Drdhng. Pages 86 anO 87 . ~ "~ . ~ ~ ~J 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 descmblng ~vork performed Number ad drd/ stem tests sequentially Atlach descr~pl~on of all cores Work performed by Producing Section wdl be reported on ' In,erin1" sheets until final complebon Report ofhc~al or represenlahve test on Final" form 1~ Submit "llltertm" sheets when filled out but nol less frequently than every ;30 days, or (2) on Wednesday of the week ~n which oH string ~s set Submit weekly for workovers and following setting of oll strmCg; until completion Distr,ct ICountyorP .... h lState Alaska North Slope Borough Alaska F,eld ILease or Umt lWell no Prudhoe Bay I ADL #28307 J L2-29 12/18/85 12/19/85 12/20/85 Date and depth asof8OO am 12/21/85 thru 12/23/85 12/24/85 Complete record for each day while drdhng or workover m progress 13-3/8" @ 3985' 9415', (7'), Drlg Wt. 10.2, PV 10, YP 8, PH 10.6, WL 5.6, Sol 13 POH, chg BHA. TIH to 9356', rm to 9409', mill on junk to 9409' TOH. TIH w/new BHA, rm to 9409', drl to 9415'. 13-3/8" @ 3985' 9647', (232'), Drlg Wt. 10.2, PV 11, YP 10, PH 10.0, WL 6.0, Sol 13 Drl f/9415'-9430', POH, chg bit. RIH w/bit & JB, wsh 108' to btm, CBU, drl to 9514', POH, rec'd junk. RIH w/new bit, rm 80' to 9514', drl to 9647'. 13-3/8" @ 3985' 9760', (117'), Circ Wt. 10.2, PV 12, YP 10, PH 10.6, WL 5.6, Sol 13 Drl to 9760', 10 std wiper trip, CBU, POH. Chg rams to 9-5/8" & ts,. RU & rn 141 jts, 9-5/8", 47#, L-80 BTC csg, well started flowing. SI & circ thru choke. 9710', 31.5°, N42.75W, 8763.91TVD, 2815.84 VS, 1846.61N, 2125.30W 9-5/8" @ 9736' 9861', (101'), Coring Wt. 9.4, PV 12, YP 11, PH 8.6, WL 4.0, Sol 4.5 Circ csg on choke, raise mud wt to 10.5 ppg. RU & rn 71 more its, 9-5/8", 47#, L-80 csg; well flowing. Circ csg on choke @ 8603', balance mud wt. Rn 27 more jts 9-5/8" csg; unable to lnd on 9-5/8" hgr. Tag btm @ 9735', circ, att to wsh dn. Cmt w/1085 sx C1 "G" while circ'g. Displ using rig pmps. Did not bump plug. CIP @ 2030 hfs, 12/20/85. NU & ts, BOPE. RIH w/8½" BHA, tag cmt to 9546', DO cmt to 9636', ts, csg to 3500 psi. DO FC @ 9645', FS @ 9736', new formation to 9770'. Conduct formation ,st to 12.5 ppg EMW. Build vol of bland mud & displ hole. Drl 8½" hole to 9849', CBU, POH. PU core bbl, RIH, cut core #1 f/9849'-9861', incompl. 9-5/8" @ 9736' 9880' ' , (19), LD Core #2 Wt. 9.4, PV 13, YP 8, PH 8.4, WL 4.4, Sol 4.5 Fin core #1 to 9865', POH, rec'd 15'. Core #2 f/9865"-.9880', . POH. --'~- '-- ~ ~ The a~)ove is correct S~gnature For form preparation and d~str~Out~n see Procedures Manual Secbon 107 Dmlhng, Pages 86 and 87 Date [Title 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim [rllltr~JCtiO~ll, Ttll3 form ~s used during drHhng or workover operat;ons If testing, coring or perforahng, show format[on name in descmblng 'work performed Number ail drill stem tests seQuenhally .Attach descr~phon of 3il cores Work 0@rfp,reed by Producing Section wdl be reported on "lilt@rim" sheets untd hnal completion Report ofhc~at or representahve test on 'FiIlml" form 11 Submit "Interim" sheets when filled out but not hess frequently than every 30 days or {2) on Wednesday of ~he week ~n which oH string ~s set Submit weekly for workovers and following setting of Oll strln(~ until completion Dlstr~ct Alaska JCounty or Parish J State North Slope Borough ADL #28307 F~eld Alaska Prudhoe Bay Well no L2-29 Date and depth as of 8 O0 a.m. 12/25/85 thru 12/26/85 12/27/85 12/28/85 thru 12/30/85 12/31/85 1/01/86 thru 1/02/86 1/03/86 1/04/86 thru 1/06/86 Complete record for each day whde drllhng or workover ~n progress 9-5/8" @ 9736' 9916', (36'), Coring Wt. 9.4, PV 10, YP 8, PH 8.2, WL 4.0, Sol 5 Rec'd 9' f/core #2. Core #3, 9880'-98878', rec'd 6'. 9887'-9897', rec 9'. Core #5 f/9897'-9916', incompl. Core #4, 9-5/8" @ 9736' 9928', (12'), Coring Wt. 9.4, PV 8, YP 6, PH 8.2, WL 4.0, Sol 5 Fin core #5 to 9917', rec'd 20'. Core #6, 9917'-9924' 7'. Core #7 f/9924'-9928', incompl. , rec'd 9-5/8" @ 9736' 9928', (12'), Coring Wt. 9.4, PV 8, YP 6, PH 8.2, WL 4.0, Sol 5 Fin core #7 to 9929', rec'd 5'. Core #8 f/9929'-9946', rec'd 17'. Core #9 f/9946'-9951', rec'd 3' TIH, drl f/9951'-9971' CBU, POH. Core #10, 9971'-9986', rec;d 14'. Core #11 f/9986'-9991', TOH. 9-5/8" @ 10,001', Wt. 9.4, Rec'd 4' w/core # 9736' (10'), Coring ' PV 8, YP 10, PH 7.9, WL 5.0, Sol 5 f/core #11. Core #12, 9991'-10,001' 3. , rec'd 10'. TIH 9-5/8" @ 10,041', Wt. 9.4, Core #13 f/10,008 5' RIH POH. 9736' (40'), POH w/bit PV 9, YP 10, PH 7.9, WL 5.2, Sol 5 f/10,O01'-lO,O08', rec'd 5'. Core #14 '-10,010', rec'd 1'. Core #15 f/10,010'-10,040', rec'd w/8½" bit, wsh 50' to btm, drl 10,040'-10,041', CBU, 9-5/8" @ 10,060', Wt. 9.4, Core #16 f/10,052' 9736' (19'), Coring PV 9, YP 7, PH 7.9, WL 5.2, Sol 5 f/10,041'-10,052', rec'd 7'. Core #17 -10,060', incompl. 9-5/8" @ 9736' 10,489', (429'), Wiper trip Wt. 9.4+, PV 9, YP 13, PH 7.7, WL 5.6, Sol 5 Fin core #17 to 10,063', rec'd 10'. Core #18 f/10,063'-10,088' rec'd 25'. Core #19 f/10,088'-10,094', rec'd 3'. LD core equip, PU 8½" BHA. RIH, rm 50' to btm, drl f/10,094'-10,489'. The above is correct S~gnature For form preparation and d~l~r~buhon see Procedures Manual Section t0, Drdhng, Pages 86 and 87 IOate ]THle 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions Th~s form Is used during drlihng or workover ooeratlons If testing, coring or perforating show formation name in describing work performed Number ail drill stem tests sequenhally Attac~ descnphon of all cores Work performed by Producing Sectfon wdl be reported on "Interim" sheets untd hnal completion Report ofhc~al or reoresen~ahve ~est on 'Final' form 1) Submit "lnlerlm" sheets when hiled out but not less frequently than every 30 days, or (2) on Wednesday of the week m which oH string is set Submit weel<ly for workovers and following Setting Of pti strln(:; until completion D~strlct ICounty or Parish IState Alaska North Slope Borough easeADL #28307 or Unit Complete record for each day while drilling or workover ~n progress Prudhoe Bay 1/07/86 F~eld 1/08/86 Date and deot~ as of 8 O0 am. 1/09/86 1/10/86 9-5/8" @ 9736' 10,490', (1' correction), Logging Wt. 9.4+, PV 12, YP 13, PH 7.6, WL 5.4, Sol 5 Make 8 std short trip, CBU, POH. RU SOS, run #1DLL/MSFL/NGT f/10,485'-9728'. Rn #2, MEST/TCC/GR logs. Rn #3, LDT/CNL/EPT/PCD/GR. Rn #4, LSS w/waveforms/GR. 9-5/8" @ 9736' 10,490', (0'), Prep to rn 7" lnr Wt. 9.4+, PV 12, YP 14, PH 7.8, WL 5.6, Sol 5 Rn #5, RFT/GR. Rn #6, CET/GR f/9726'-6997', RD Schl. RIH, had 10' fill, C&C, POH. RU to rn 7" lnr. Tst BOPE. 7" f/9533'-10,489' 10,490' TD, 10,318' PBTD, PU 3½" DP Wt. 9.4, PV 12, YP 14, PH 8.1, WL 5.4, Sol 5 Rn 22 its, 7", 29#, L-80 BTC lnr w/FC @ 10,445', FS @ 10,489', Tie-Back Slv@ 9546'. Cmt w/435 sx cmt slurry of C1 "G" w/Flyash, .2% D-20, .8% D-112 & .2% D-46. Displ using rig pmp. Recip lnr. CIP @ 2030 hrs, 1/8/86. POH, LD 8½" BHA, PU 3½" DP. 7" 9533'-10,489' 10,490' TD, 10,443' PBTD, Drlg cmt Wt. 9.3, PV 10, YP 10, PH 11.2, WL 5.8, Sol 5 TIH, tag soft cmt @ 8939', drl to 9533' TOL, circ, TOH w/9-5/8" scrpr. TIH w/7" csg scrpr to TOL, no cmt. TIH to 10,223', rm 95' cmt to LC @ 10,318'. Tst csg & lnr lap to 3000 psi. DO LC & cmt to FC @ 10,444'. Alaska Well no L2-29 The above is correct see DrHhng, Pages 86 and 87 Date [Title 2/07/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Initrucflons' Prepare and sul)m~t the "Final Report" on the hrst Wednesday attar allowable has been assigned or well is Plugged, Abandoned or Sold "Final Report" should be submdted also when oPerahons are suspended for an indefinite or appreciable length of lime On worKovers when an official test ~s not required upon completion report completton and representative test <data rn blocks provided The "Final Report" form may Ue used for reporting the entire operahon ~f space ~s available D~strlct ICounty or Pamsh Alaska F~etd ~Lease or Unit I Prudhoe Bay Auth or W O no ]T~tle AFE 803570 I Drill Rowan 41 API 50-029-21505 Operator IA R Co W I ~ ARCO Alaska, Inc. 50% Spudded or W O begun ~Date Spudded J 12/4/85 Date and depth Complete record for each day reported as of 8 00 a m 1/11/86 Accounting cost center code State North Slope Borough Alaska Well no ADL #28307 L2-29 I otal number of wells (achve or mact~ve) on th~s pst center pmor to plugging and bandonment of th~s well I otJr l Prior status ~f a W O 2230 Hrs. I 7" f/9533'-10,489' 10,490' TD, 10,444' PBTD, RR 9.4 ppg NaC1 brine Circ, tst csg & lnr to 3000 psi. Displ mud w/9.4 ppg NaC1 brine, POOH, LD DP. Place 400' diesel cap in well. ND BOPE, NU tbg head & lower master vlv & tst; OK. Spot 80 bbl crude/diesel cap in 13-3/8" x 9-5/8" ann. RR @ 0600 hrs, 1/11/86. Old TD New TD 10,490' Released r~g 0600 Hrs. Date 1/11/86 I PB Depth , 10 444 ' I K,nd o~ r,g Rotary Classlftcat~ons (o111 gas, etc ) Oil Type complehon (single, dual, etc ) Single Producing method Official reservoir name(s) Flowing Lisburne Potenhal les~ dale Well no Date Reservoir Producing Interval Od or gas Test time Production Od on test Gas per day Pump size, SPM X length Choke s~ze T P C P Water % GOR Grawty Allowable Effechve date corrected The above is correct Signature I Date I Title . ~'J--'¢ _~,,~~_ 2/07/86 For turin preparation and distribution, see Procedures Manual, Section 10, DrHhng, Pages 86 and 87 Drilling Superintendent ARCO Alaska Inc. Lisburne Engineering To: State of Alaska John Boyle From: Date: Para Lambert February 7, 1986 Traasmitted herewith are the following: OH Final Prints-for Lisburne Well L2-29 RFT 1-7-86 Run 1 5" Sch Natural GR Spectroscopy 1-7-86 Run i 2"&5" Sch DLL/MSFL-GR 1-6-86 Run 1 2"&5" Sch LDT/CNL (Raw) 1-6-86 Run 1 2"&5" Sch Electromagnetic Prop °1-7-86 Run 1 2"&5" Sch LSS 1-7-86 Run 1 2"&5" Sch LSS/WF 1-6-86 Run 1 5~' Sch LDT/CNL (Poro) i-6-86 Run 1 2"&5" Sch Microlog 1-7-86 Run 1 2"&5" Sch CET 1-7-86 Run 1 5" Sch GR-Neutron in casing 1-6-86 Run 1 2"&5" Sch Receipt Acknowledgement: /~__~.~~~,~ Return Receipt to: ARCO Alask~~"~.' ~laska Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal N°:~7 ~ ARCO Alaska, Inc. ~- Post Office Bc )0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCompany RECEIVED FEB 1 3 1986 Alaska 0il & bus C~ms. Cuu,~nission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 6, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' L2-29 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L69 Enclosure ARCO Alaska, Inc, ~s a Subsidiary of AtlanhcRichheldCompany - -~- STATE OF ALASKA ...... ALASK, ,~,_ AND GAS CONSERVATION L .IISSION WELL COMPLETION OR REPORT AND LOG 1. Status of Well ~,~L ~ "~!l ~ I If'~L Classificat,on of Serv,ce Well OIL [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-297 3. Address 8. APl Number P. 0. Box 100360, Anchorage~ AK 99510 50- 029-21505 4. Location of well at surface 9. Unit or Lease Name 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Wetl Number To be submitted when gyro is run. L2-29 At Total Depth 11. F~eld and Pool To be submitted when gyro is run. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and SerIal No. Prudhoe Bay 0i 1 Pool 52' RKBJ ADL 28307 ALK 2317 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1 2/04/85 01/06/86 01/11/86I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10490'MD 10444'MD YES [] NO ~X N/A feet MD 1900' (approx) 22. Type Electric or Other Logs Run Gyro(f/2000'-4000'), DLL/MSFL/NGT, MEST/TCC/GR, LDT/CNL/EPT/PCD/GR, LSS/Waveforms/GR, RFT/GR, CET/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 1800# Poleset 13-3/8" 68.0#/72.0# K-55/L-8O Surf 3985' 17-1/2" 1950 sx AS Ill & 600 s~ Class G Performed top job w/40 sx AS I 9-5/8" 47.0# L-80 Surf 9736' 12-1/4" 1085 sx Class G 7" 29.0# L-80 9533' 10489' 8-1/2" 435 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (Corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch~ps. See attached core description. Form 10-407 TEMP3/WC66 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOIGIC MARKERS NAME MEAS. DEPTH 30. Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH IGOR, and time of each phase. RFT data to be submitted when received. 31. LIST OF ATTACHMENTS Core Description 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~ ~ ~]~L~I-~J T,tle 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- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Well Core 0.2' 2.8' 2.1' 1.5' 0.3' 7.1' 1.0' 1.0' L2-29 #1 Lisburne Well-Site Description CONFIDENTIAL 9849=9865 Cut 16' Recovered 15 12/23/85 Siltstone; dark gray, pyritic, calcareous. Dolomite, mudstone. Dolomitic limestone; non-skeletal grainstone. Limestone; non-skeletal grainstone; 3 thin layers of shaly siltstone. Shaly siltstone; dark gray. Limestone; non-skeletal grainstone, slightly dolomitic. Limy dolomite; skeletal wacke/packstone. No Recovery. Core 3.4' 5.6' #2 9865-9880 Cut 15' Interbedded dolomite and dolomitic packs tone/grai ns tone. Limestone; non-skeletal grainstone. No Recovery. Recovered 9' 12/24/85 limestone; skeletal Core #3 9880-9887 Cut 7' 6.0' Limestone; skeletal grainstone 1.0' No Recovery. Recovered 6' 12/25/85 Core #4 9887-9897 Cut lO' 2.6' Limestone; cherty skeletal 6.4' Interbedded dolomite, limy muds tone/wackes tone. 1.0' No Recovery. Recovered 9' grainstone. dolomite and chert; 12/25/85 Core 1.1 1.9 0.4 1.6 4.8 4.5 4.41 #5 Core #6 0.6' 6.4' Core #7 4.5' 0.5' Core #8 17.0' 9897-9917 Cut Dolomite; skeletal Limestone; skeletal Chert. 20' Recovered 20' wacke/packstone. packstone/grai nstone. Dolomite; mudstone. Limestone; skeletal grainstone. Interbedded dolomitic limestone wacke/packstone. Dolomite; mudstone. Limestone; mud/wackestone. and dolomite; skeletal 9917-9924 Cut 7' Recovered 7' 12/26/85 Siltstone; medium gray, shaly. Limestone; interbedded mudstone and wackestone. CONFIDENTIAL 12/26/85 9924-9929 Cut 5' Recovered 4.5' 12/27/85 Dolomitic limestone; skeletal pack/grainstone. No Recovery. 9929-9946 Cut 17' Recovered 17' Dolomitic limestone; Interbedded skeletal and grainstone. Core #9 9946-9951 Cut 5' 1.O' Dolomite; mudstone. 2.0' Dolomitic limestone; grainstone. 2.0' No Recovery. From 9951-9971 No core; drilled out formation. 12/28/85 non-skeletal Recovered 3' 12/28/85 mixed skeletal and non-skeletal CONFIDENTIAL Cut ]5' Recovered ]4' ]2/~9/85 L~mestone; m~xed skeletal and non-skeletal 9ra~nstone. Shale; calcareous, s~lt.v. L~mestone; m~xed skeletal and non-skeletal 9ra~nstone. Do]om~t~c ]~mestone; skeletal 9ra~nstone. Chert. No Recovery. Core #10 9971-9986' 22' 0.2' 6.6' 3.0' 1.0' 1.0' Core #11 9986-9991 Cut ll' Recovered 4' Core mostly rubble. 1.0' Banded Chert. 3.0' Dolomitic limestone; grainstone. 7.0' No Recovery. 12/30/85 Core #12 9991-10001 Cut 10' Recovered 10' 12/31/85 8.0' Limestone and dolomitic limestone; skeletal grainstone. 2.0' Limestone; non-skeletal grainstone. Core #13 lO,O00-10,O08' Cut 7' Recovered 5' 12/31/85 5.0' Interbedded chert limestone and dolomitic limestone; skeletal and non-skeletal grainstone. 2.0' No Recovery. Core #14 10,008-10,010 Cut 2' Recovered 1.8' 1/1/86 1.8' Limestone; skeletal grainstone, mostly rubble. 0.2' No Recovery. Core #15 10,010-10,040 Cut 30' Recovered 6' 1.O' Interbedded chert and lime grainstone. 1/1/86 4.7I 0.3' 24.0' Limestone; skeletal grainstone. Siltstone; shaly, dark gray. No Recovery. CONFID mAL Core #16' 10,040-10,052 Cut 12' Recovered 7' 7.0' Limestone; skeletal grainstone. 4.0' No Recovery. 1/2/86 Core #17 10,052-10,063 Cut Il' 4.5 0.5 2.0 0.5 2.5 1.0 Recovered 10' 1/3/86 Limestone; skeletal grainstone. Interbedded chert and siltstone. Chert and limestone; mudstone/wackestone. Limestone; skeletal grainstone. Dolomite; mud/wackestone. No Recovery. Core #18 10,063-10,090 Cut 27.5 3.8' ll.l' 12.1' Recovered 27.5' 1/4/86 Dolomite; interbedded mudstone, wackestone and packstone. Interbedded siltstone and silty claystone; olive gray, pyritic. Limestone; mixed skeletal and non-skeletal grainstone. Core #19 10,0903 Cut 3' Recovered 3' 3.0' Limestone; skeletal grainstone. 1/4/86 NFi ENTI L SUB-~URFACE DIRECTIONAL ~URVEY I~UIDANCE ~'IONTINUOUS I-~"100L Company Well Name ARCO ALASKA INCORPORATED L2-29 (1961' FSL, 1010' FWL, S18, TllN, R15E) Field/Location PRUDHOE BAY/LISBURNE POO,L, NORTH SLOPEI ALASKA Job Reference No. 71194 SALAZAR Date , =, ~ 29-JAN-1986 Computed By: OGDEN GCT DIRECTI]NAL SURVEY 'USTDMER LISTIN~ FOR ARC3 4LASK~, IN'. LISBURNE L2-29 PRU'3HDE BAYFLISBURN5 PgOL NORTH SLOPE,~L~SKA DATE: 22-JA~-$6 ENGINEER: S~L&Z~R METHODS OF C34PUT~TIOq TOOL LOCATION: TANSENTIAL- AVERAGED DEVIATION AND aZIMJTM I~TE~P~L~TIDN: LINEAR VERTICAL SECTION: ~ORIZo DIS?. PROJECTED D~TO ~ TARGET AZIM~'TH OF NgRTH ~9 O~ 22 ~IN ~EST COMPUTATION DATE: 29-J~N-B5 P~3E I LISBU~NE L2-29 P~JDHOE BAY/LISBURNE N]RTH SLOPE,ALASKA P30L £NTE~POLATED VALJES FOR EYEN 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTI:AL 3EPTH DEPTH DEmTH 0,00 0,00 -5~,00 lDO,DO lO0,O0 48,00 200,00 200,00 168,00 300.00 300.00 248.00 O0.O0 400.00 349.00 00.00 500.00 ¢¢8.00 $00.00 599.99 547.99 700,00 699.98 647.98 800.00 799.37 747.97 900.00 899.~6 947.96 1000.00 999.95 947.95 1100.00 1099.95 10~7.95 1200.00 1199.95 1147.95 1300.00 1299,~4 12¢7,94 1~00.00 1399.94 1347.94 1500.00 1&99.34 1~7.94 1500.00 1599,94 1547.94 1700.00 1699.94 16¢7.94 1800.00 1799.94 1747.9~ 1900.00 1899.94 1847.9~ 2000.00 1999.94 2100.00 2099.93 2200.00 2199.92 2300.00 2299.89 ~ ~o.oo 23~9.~7 ~O.OO 2~99,84 2500.00 2 82 2700.00" 80 2800.00 76 29~0.00 ~3 1947.94 20~7.93 21~7.92 22¢7.89 23~7.87 2&47.84 25~7,82 26~?,80 2747,76 28¢7.63 DATE DF SURVEY: 2Z-J~N-8$ KELLY_aUSHIN,3 =L~V~TZ]N:_ 5"~_..33 ; =NSZNE:R' SALA~AR 3000.0~ 0 2947.k0 3100.0 ' 9 30~S.99 3200.00 ~6 31¢6.~6 3300.00 .75 32~5.75 3~00.00 31,97.17 33~5.17 3500.00 3~96.52 344~.62 3600.00 3595.99 35¢3.99 3700.00 3695.21 3643.21 3800.00 3794.35 3742.35 3~00.00 3893.~0 3841,~0 MEASURED 3EPTH COURSE VERTICAL D03LEG RECTANGULAR CODRSI~ATES H]RIZ. DEPARTURE 2E¥~ATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH DEG MIN DEG MIN FEET DES/10g FEET FEET FE:T 0 0 N 0 0 E 0,00 O.O0 0 8 N 60 41 W 0,12 0,19 0 $ S O 45 W 0.19 3,21 . 0 I S 58 35 W 0.13 0.07 0 8 S 59 23 W 0.15 0 ii S 19 Z3 W 0.13 0.71 0 51 S 5 7 E -0.62 0.18 0 52 S 9 33 E -1.77 D,17 0 ~6 S 16 ~.5 E -2.9~ 0.06 0 ~4 S 17 20 E -4.06 0.19 0 35 S 24 0 E -5.08 0.1~ 0 27 S 26 28 E -5,91 0,40 0 16 S ~Z 8 E -6.49 0.12 0 12 5 52 21 E -5.92 0.09 0 9 S 67 57 E -7.23 0.12 0 7 S 73 42 E -7.46 0.08 0 Z1 S 77 53 E -7.88 O.1Z 0 Z1 S 7~ 5~ E -8.44 0,13 0 21 S 70 25 E -9.03 0.07 0 13 S 79 31 E -9.55 0,18 0 12 N 81 0 E -9,82 0,43 0 3'2 N ¢~ 26 E -9,97 0,09 1 16 N 66 9 E -10,04 1,05 1 Z1 N 45 52 E -10.39 0.21 1 14 N 56 35 E -10.75 0.38 1 Il N 85 19 E -11.74 1,04 I lO S 67 12 E -13,52 0.40 1 13 S 40 19 E -15,54 0,65 2 7 $ 14 55 E -18.06 1.39 3 Z7 S 3 31 E -21.68 0.96 4 37 S 1 15 E -26.35 1.4~ 5 29 S 0 6 W -32.24 0.43 6 32 S ~+ 44 W -38.69 2.33 6 37 $ 6 41 W -45.37 0,81 5 58 S 7 ~0 W -51.38 0.53 6 10 $ 15 55 W -56.58 0,92 6 ~8 S 27 57 W -60.16 1,20 7 22 S 38 19 W -61,86 1,71 7 ~.1 S ~. .57 N -61.39 D.39 8 0 S 48 2¢ W -60.02 3.47 3.00 N 0,09 N 0,03 ~ 0,35 S 0,09 S 0.46 S 1,71 S 3.22 S 4.57 S 5.93 S 0.0 0.0 0.2 O.Z 0.2 0.$ 0.6 0.4 0.1 0.2. 0.00 0.12 0.23 0.21 0.29 0.73 1.82 3.25 4.57 5.94 q O 0 E q 41 19 W q 2,2 29 R S 77 3 W S 72 14 W S ZO 37 W S 7 35 W S 1 31 W S Z 32 E 7.03 7.85 8.32 8.61 8.78 8.86 8.96 9.12 9.31 9.49 0,6 1.0 1.4 1.T 1.9 2.2 2.7 3.3 3.9 4.4 6 E 7.06 6 E 7.92 I E 3 E 3.78 9 E g. O0 2 : 9.14 0 : 9.36 0 E 9.70 I E 10,09 4 E 10,4~ 5 7 11 15 19 ZZ 25 21 37 21 47 3 44 54 47 9.59 9.13 8.09 6.45 4.98 4.10 4.50 5.68 8.16 12.98 ~.71 E 5.31 E 6,29 E 3.15 E 9,89 E 11,95 E 13,95 E 15,60 E 16.79 E 17.42 E 10.59 10.56 10.24 10.40 ll.OT 12.54 14.55 16.60 18.67 21.73 25 37 51 63 71 72 69 53 9 11 51 39 17 5 8 59 4 18 19.90 28.85 39.10 50.91 61.52 71.93 82.31 92.70 102.36 111.94 17.65 17.73 17.43 1,5.10 14.82 12.83 8.64 1.97 6.93 15,87 26.60 33.86 42.81 53.39 63.38 73.05 82.77 92.72 102.59 113.11 41 31 24 17 13 10 5 1 3 33 34 1 32 31 6 59 13 52 34 ARCO ALASKA~ INC. LI$BURNE 12-29 PRUDH3E BAY/LISBURNE NORTH SLOPE,ALASK~ POOL COflPUTATI34 INTERPOLATED VALUES FOR TRUE SJB-SEA MEASURED VERTICAL VERTISAL DEPTH DEPT9 DEPTH 4000.00 3992.~6 4100.00 ¢091.59 42O0.00 ¢190.34 6300.00 6290.07 '600.00 ¢389.27 ~630.00 4587.39 4700.00 6685,94 4800.00 6783.$8 4900.00 4880.55 5000.00~ ¢977.01 5100.00 5072.32 5200.00 5166.68 5300.00 5259.26 5400.00 5350.78 5500.00 54¢0.75 5500.00 5529.08 5700.00 5615.66 5300.00 5700.33 5900.00 5782.38 6000.00 5861.39 6100.00 5937.53 6200.00 $012.78 6300.00 5037.79 '?-00.00 6162.B¢ 00.00. $233.04 ,~,,,00. O0 6313.$3 6700.00 $389,44 6800-00,~ 6~65.74 ~oo.oo: 7~00. : ' 50 7~0.00 6906.88 7500.00 ~975.99 7SOO.gO 70~.50 T7OO.O0 7~2.75 7800,00 7180.38 7gO0.O0 7251.50 CDJRSE DEVIaTIDN AZIMUTH 3EG 4IN DES 414 3943.46 ¢039.59 ¢138.8¢ ¢238.07 6337.27 ¢436.42 ¢535.39 ¢$33.94 ¢731.68 ¢828.65 7 38 S ¢7 59 W 7 18 S 48 3 W 6 57 S 57 ¢1 W 7 21 S 73 ¢1 W 7 11 N 85 38 W 746 N 67 8 W 8 ¢g N 58 9 W 10 51 N 57 O W 13 16 N 53 ¢8 W 14 ¢1 N 52 15 W 6925.01 5020.32 5114.48 5207.26 5298.78 5388.75 5471.08 5563.66 5648.33 5730.38 16 26 N 50 ¢8 W lB ~1 N 69 53 W 20 51 N 49-28 W 24 41 N ¢8 56 W 26 54 N 48 45 W 29 0 N 48 1 ~ 30 59 N ¢7 15 W 33 gO N 46 33 W 36 ~8 N ¢6 5 W 5809.39 5885.63 5960,78 6035.79 5110.84 5185.04 5261.63 $413.74 6490.11 5565.49 $639.86 $712.82 5784.50 $85~.88 5923,99 6992.60 7060.75 7128.38 719~.50 DATE: EVEN VERTIC SECTI FEE 29-J~N-86 100 FEET AL DO$LEG ON SEVERITY T DEG/IO0 -58.00 -56.43 -48.65 -40.31 -28.61 -14.65 2.11 23.07 47,43 74. 104. 138. 175. 215. 259. 305. 356. 409. 465. 527. 592. 657. 723. 789. 855. 920. 985. 1050. 111¢. 1180. 1246. 1315. 138~. 1455. 1527. 1599. 1672. 1745. 1815. 17 40 02 34 60 24 10 10 25 31 03 86 82 74 48 76 80 28 68 21 85 01 51 28 64 47 80 86 0.77 2.23 2.32 1.08 2.80 2.03 1.4~ 2.65 2.07 1.35 1.89 1.52 2.44 1.84 2.61 2.01 2.12 2.55 3.08 0.71 0.31 0.40 0.32 3.84 0.53 0.3¢ 1.43 }.8~ 1.30 !.05 1.20 1.15 0.35 ~.3~ 3.55 DaTE OF SURVEY: 22-J~N-D5 K~LLY SUSqlN$ ELEVATIDN: ENGINEER: S&L&Z&~ 2 52.00 MEASURE3 DEPTH R:STANStJL&R CDORDI4~T:S HDRIZ. NDRTH/SOUTH EAST/WEST DIST. FEET FEET FE:T 120.78 S 27.20 W 123.80 129.70 S 36.93 W 134.86 137.27 S 46.42 W 144.91 142.11 S 57.83 W 153.43 143.73 S 70.22 W 159.97 140.39 S 82.75 W 162.)5 133.57 S 95.29 W 16~.07 124.55 S 109.65 W 165.95 112.59 S 127.00 ~ 169.72 97.~5 S 146.46 W 176.14 DEPARTURE AZIMUTH DE3 MIN S 1Z 41 4 S 15 53 W S 18 40 4 S 22 8 W S 25 2 J S 30 31 ~ S 35 30 .t S 41 Z1 W S 4~ 26 ~ S 56 15 W 81.15 S 167.35 W 186.00 S 61.88 S 190.66 W Z00.45 S 40.13 S 216.29 W 219.99 S 15.77 S 244.57 W 245.08 S 10.55 q 274.9¢ W 275.15 N 39.29 N 307.88 W 310.38 ~ 70.~3 ~ 342.91 W 350.05 q lO~.lZ N 379.88 W 393.89 N 140,44 q 418.75 W ~41.67 N 179.86 N 460.11 W ¢94.02 ~ 222.52 N 504.09 W 551.02 267.74 N 550.36 W 512.03 313.97 N 597.43 W 574.91 360.47 N 644.45 ~ 73~.~Z 406,96 N 691.42 W ~OZ.Z} ~53.45 N 738.15 W ~56.30 ~99.68 N 784.50 W 930.12 545.54 N 830.75 ~ 993.93 591.08 N 876.74 W 1057.38 535.52 N 922.60 W 1120.87 582.90 N 9~9.16 W 1185.59 730.21 N 1016.37 W 1251.49 778.78 N 1066.52 W 1318.97 923.37 N 1113.53 W 1387.85 ~79.35 N 1163.31 W 1¢53.08 ~30.~6 N 1213.59 W 1529.54 983.50 N 1263.93 W 1501.¢8 1336.¢7 N 1314.42 W 1573.91 1389o43 N 1~65.60 W 1745.92 1138.91 N 1415.45 W 1916.77 64 7 72 1 79 294 8618 87 46 82 43 78 23 74 40 71 27 68 38 $$ 10 64 3 $Z 16 SD 46 59 31 53 26 57 30 55 42 56 0 55 23 54 18 53 48 53 21 52-55 52 30 52 6 51 44 51 25 51 lO CO~PUTATI3N DATE: 29-JAN-85 ~,S;_ 3 ARCO ALASKA, INC. LISBURNE L2-29 P~JDHDE BAY/LISBURNE NORTH SLOPE,ALaSKA TRUE MEASUREO VERTICAL DEPTH DEPTH 8330.00 7328.12 8100.00 7408.72 8200.00 7491.57 ~300.33 7576.Z6 30.00 7661.50 ,00.00 77¢6.26 8600.00 7830.64 8700.00 7914.55 8800.00 7998.16 8900.08 8081,06 9000.00 8164.12 9100.00 8248.21 gZOO.OO 8332.87 9300.00 8417.57 9400.00 8502.50 9500.00 8587.19 9580.00 8671.71 9700.08 8756.35 9800.00 8841.75 9900.00 8926.92 POOL 10000.00 9012.35 10100.00 9098.94 10200.00 9184.45 10300.00 9271,74 30.0g 9360.03 ~0.00 9439.84 INTERPOLATED VALJE$ FOR EVEN 103 giB-SEA COURSE VERTICAL VERTI:AL DEVIATION AZIMUTH SECTION DEPTH 3EG MIN DES Mit FEET 7275,12 7355.72 7439.67 7524.26 7609.50 7694.25 7778.64 7862.65 7945.16 8029.06 37 54 N 47 55 W 1879.98 34 50 N 51 55 W 1939.11 32 53 N 51 59 W 1994.89 31 47 N 49 51 W Z048.17 31 37 N 48 4~ W 2100.48 32 20 N 48 25 W 2153.54 32 39 N 48 18 W 2207.19 33 8 N 47 41 W 2261.42 33 37 N 4T 23 W 2316,40 34 17 N 47 lB W 2372.29 8112.12 8196.21 8280.87 8355.$7 8450.50 8519.71 8704.35 8789.75 8874.92 33 10 N 46 B W 2427.92 32 24 N 45 19 W 2481.91 31 59 N 45 35 W 2535.01 32 0 N 44 58 W 2587.89 31 58 q 44 15 W 2540.65 32 12 N 44 13 W 2693.60 32 18 N 44 3 W 2746.84 31 49 N 43 33 W 2799.83 31 ~1 N 40 25 W 2851.41 31 13 N 39 48 W 2903.12 8960.35 9046.04 3132.45 9219.74 9308.03 9387.84 31 17 N 39 45 W 2954.35 30 42 N 39 25 W 3005.15 29 ~4 N 39 O W 305¢.~3 28 36 N 38 25 W 3102.68 27 31 N 37 52 W 3148.73 27 31 N 37 52 ~ 3189.49 FEET OF DOGLEG SEVERITY DEG/IO0 3.94 2.31 2.33 1.97 0.6~ 0.17 0.37 0.79 0.72 0.34 1.76 0.43 0.31 0.94. 0.43 0.46 0.50 1.8':) 1.59 0,21 0.51 3.81 0.95 1.I~ 0.03 O.O0 ]~TE 2: SJ~FEY: ZZ-JA~-~5 KELLY BUSHINg ~LEV~TI3N: 52.00 F ENGINEER: S&LAZAR MEASURED DEPTH RECTANGULAR COORDINATES flORIZ. 3EPqRTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FE:T FEET F=:T DEG 1183.32 1221.37 1255.4.9 1288.96 1 323.23 1358.31 1393.)6 14.30.22 1 A. 67. ~3 1505.24 1461. 1507. 1551. 1592. 1632. 1572. 1712. 1752. 1793. 1834. 8~ W 1~80.75 N 51 0 d 10 W 1939.87 N 50 58 W 33 W 1995.72 N 51 1 ~ 82 W 2349.02 N 51 1 W 33 W 2101.30 ~ 53 58 ~ 15 W 2154.32 N 53 54 ~ 25 N 2207.93 q 53 51 N 60 W 2262.11 q 50 47 N 12 W 2317.03 N 50 42 ~ 32 W 237~.85 q 50 37 ~ 1543.22 1581.21 1518.53 1555.58 1593.42 1731.56 1769.97 1808.28 1846.97 1887.10 1875. 1913. 1951. 1989. 2026. 2063. 2100. 2137. 2172. 2205. 03 W 2~2.3.43 N 50 32 W 58 W 2~82.34 q 50 25 W 53 W 2535.37 q 50 19 W 33 W 2588.19 q 50 13 ~ 47 W 2640.88 q 50 6 d 50 W 2593.75 ~ ~9 59 ~ 70 W 2746.95 q 49 53 d 66 W 2799.90 q 4~ 46 ~ 42 W 2851.44 q 4~ 37 ~ 12 W 2903.13 q 49 ZT ~ 1927.02 N 2239.38 W 295~.35 q 49 17 ~ 1966.72 N 2272.25 W 3305.18 q 4~ 7 ~ 2005.75 N 2304.09 W 3954.31 ~ 4~ 57 ~ 2343.80 N 2334.53 W 3102.~3 N 43 4.~ W 2380.71 N 2363.63 W J148.)} q 43 3~ ~ Zl13.55 ~ 238}.17 W ~i89.d6 q 4~ 30 J COMPUTATION DATE= 29-J~N-85 =~= 4 ARCO ~LASK~, INC. LISBURNE L2-29 PR~DHOE B~Y/LI$BUR~E N]RTH SLDPE~AL~SKA PDOL TRUE 4E&SURED VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 999.95 2000.00 1999.9¢ 3000.00 2999.¢0 ' ~.00 3992.~5 J.OO ¢977.01 6000.00 5861.39 7000.00 5517.~9 BO00.O0 7328.12 9000.00 8164.12 10000,00 9012.35 10~90.00 9~39.~4 INTERPOLATED V~LUES FOR EVEN lOOD SUB-SEA CDJRSE VERTICAL VERTICAL 2EVIATID4 AZIMUTH SECTION DEPTH )EG 4IN DEG MIq FEET -52.00 947.95 1947.94 2947.40 3940.46 ~925.01 5809.39 5555.49 7275.12 BllZ.12 N 39 45 W N 37 52 W 8963.35 31 17 9387.84 27 31 0.00 -5,08 -9.82 -26.35 -58.00 74.17 527.47 1180.21 1879.98 2427.92 3189.49 FEET DF DOSLEG SEVERITY DEg/IOO 0.00 O.l~ 0,43 1.4~ 0.77 1.89 2,84 0.84 3.94 1.76 0.51 O.OD D~Tr_- 3~ SURVEY: ZZ-J&N-55 K:LLY 3USHIN$ ELEV'~TZ]9: 52.00 FT ENGI4EER: S~L~Z~R 4E6SURE] DEmT RE~T&NDUL~R CDJRDIq&TES H]2IZ. DEPARTURE NORTH/SOUTH E~ST/WEST DIST. ~ZIqUTH F=ET FEET FE:T DE~ MIN 0.00 N 3.30 E O.DO 4 3 0 E 7.03 S 0.65 E 7.06 S 5 21 E 9.59 S ~.71 E 10.69 S 25 9 E 19.~0 S 17.65 E 25.60 S 41 33 E 120.78 S 27.20 W 123,80 S 12 41 J 81.15 S 167.36 W 186.33 S 64 7 W 222.52 N 504,09 W 551.02 N 65 10 W 582.90 N 969,16 W 1185.59 N 5~ 49 W 1183.32 N 1451.84 W 1~80.75 4 51 0 W 1543.22 N 1875.03 W 2~2~.43 N 53 32 W 1927.02 4 2239.38 W 2954.35 q 4~ 17 W 2113.55 q 2389,17 W 3189.85 q ~8 30 4 A~CO ALASKA, INC. LISBURNE L2-29 PRgDHDE B~Y/LISBUR~E N3RTH SL3PE~ALASKA PDOL COMPUTATION DATE: INTERPOLATED VALgES FOR EVEN 100 TRUE SJB-SEA MEASURED VERTICAL VERTICAL 9EPTH DEPTH DEPTH COJRSE VERTICAL DEVI~TIgN AZIMUTH SECTION lEG qIN OEG MIN FEET 0.00 0.00 -52.00 52.00 52.00 0.00 %52.00 152.00 100.00 252.00 252.00 200.00 '2.00 352.00 300.00 2.00 452.00 4.00.00 ~52.00 552.00 500.00 652.02 652.00 600.00 752.03 752.00 700.00 852.04. 852.00 800.00 0 0 N 0 0 E 0.00 0 16 N 38 43 W 0.00 0 6 S 63 55 W 0.21 0 2 S 41 19 E 0.13 0 2 S 63 57 W 0.14 0 14. S 38 53 W 0.19 0 65 S 3 42 W -0.16 0 .52 S 8 $ E -1.21 0 52 S 11 21 E -2.39 0 ~5 S 16 48 E -3.53 952.05 952.00 900.00 1052.05 1052.00 1000.00 1152.05 1152.00 1100.00 1252.06 1252.00 1200.00 1352.05 1352.00 1300.00 1652.06 1452.00 14.00.00 1552.06 1552.00 1500.00 1652.05 1652.00 1600.00 1752.06 1752.00 1700.00 1952.05 1852.00 1800.00 0 39 S 20 23 E -6.61 0 30 $ 28 B E -5.54 0 19 S 39 39 E -5.26 0 14 S ¢7 52 E -6.73 0 10 S 53 16 E -7.09 0 8 S 69 35 E -7.35 0 ZO S 79 44. E -7.63 0 go $ 77 50 E -8.17 0 Z1 S 73 48 E -8.74 0 ZO S 69 ~ E -9.33 1952.05 1952.00 1900.00 2052.06 2052.00 2000.00 2152.07 2152.00 2100.00 2252.10 2252.00 Z20D,O0 ''2.12 2352.00 2300.00 Z.15 2~52.00 Z¢O0,O0 Zb~2.1? 2552.00 2500.00 2652.19 Z6SZ,O0 2600.00 2752.22 Z'?$2,00 2700.00 2852.29 >~8S:Z~O0 2800.00 i ,oo.oo a t.oo 32oo.oo 4.55.13 3452.00 34.00.00 sss. z 3ssz.oo 3500.00 556.4.3 3 52.00 3600;00 s757.27 3752.00 3700.00 3858.19 3852.00 3800.00 0 8 S 39 ¢5 E -9.72 0 29 N 51 $ E -9.93 0 ~7 N ~2 55 E -10.00 1 27 N 51 16 E -10.21 1 18 N ~8 58 E -10.52 1 20 N 65 32 E -11.14 I 11 S 77 39 E -12.60 I 9 S 54. 15 E -14.56 1 33 S 25 ~ E -16.73 2 ~+9 S 7 2 E -19.80 3 57 S I 35 E -23.97 5 11 S 0 21 E -29.37 5 52 S 1 27 W -35.62 6 55 S 6 38 W -4.Z.32 6 6 S $ 4.2 W -~8.75 6 0 S 10 49 W -54.39 6 28 S 22 28 W -58.82 7 9 S 33 ~ W -61.38 7 35 S 43 38 W -61.78 7 58 S 45 30 W -60.72 29-J&N-86 D&TE ~ SUqVEY: £2-J~q-~5 ~LLY BUSHING ELEV&TI]N: ENSIqEER: S6L~Z~ 5 5Z.OO =T FEET OF SUB-SE~ DOGLEG REST~N SEVERITY NORTH/ DES/IOO FEE 0.00 O. 0.70 O. 0.32 O. 0.11 O. 0.16 O. 0.35 O. 0.50 1. 0.12 Z. 0.13 ~. 0.05 5. 0.34. 0.17 0.36 0,10 0.11 0.06 0.30 0.12 0.05 0.05 0.63 0.40 0.97 0.39 0.78 1.39 1.3Z 1.39 0.80 1.09 0.26 I.OB 1.0¢ 1.53 1.66 D.82 0.99 DEPTH GUL~R CDORDINATES H6RIZ. SOUTH EAST/WEST DIST. T FEET FE:T O0 N 0.00 E 0.00 O0 q 0.00 E 10 q 0.19 W 0.21 03 3 D.ZO W 0.21 06 S 0.26 W 0.24 21 S 0.43 W 0.67 DZ S 0.55 W 1.21 49 S 0.55 W 2.55 O0 S 0.28 W 4.01 33 S 0.08 E 5.33 5.55 S 0.46 E 6.56 7.~7 S O.B8 E 7.53 8.14 S 1.26 E 8.24 8.49 S 1.58 E 8.54 8.71 S 1.85 E 8.91 8.83 S 2.11 E 9.08 8.30 S 2.41 E 9.22 9.04 S 3.01 E 9.53 ~.21 S 3,62 E 9.89 9.~2 S 4.21 E 10.32 . 8. 7. 5. 4. 4. 5. 6. 10. 16. 24. 34. 45. 56. 67. 77. ,~8. 98. 107. 56 S 6.60 E i0.51 43 S 4.9) E 10,67 72 S 5.70 E 10.¢1 21 S 7.27 E 10.24 62 S 9.04 E 10.55 38 S 10.92 E 11.76 19 S 13.01 E 13.67 32 S 14,87 E 15.70 7Z S 16.28 E 17.61 37 S 17.19 E 20.08 35 S 17.56 E 23.99 ~5 $ 17.73 E 30.20 39 S 17.68 E 38.60 ~9 S 16.73 E 48.47 92 S 15.39 E 58.97 29 S 13.93 E 6~3.72 69 S 10.84 E 78.44 22 S 5.19 E 88.37 31 S 2.95 W 98.35 90 S 12.57 W 108.53 DEPARTURE ~ZI~IUTH DES MIN q 3 0 = N 61 3 w S 75 55 W S 63 59 ~ S 33 S 12 21 ~ $ ~ i W S 0 52 E S % 0 E S 6 43 E S 8465 S 10 33 E S 1Z 4 E S 13 28 ~= S 15 8 E S 13 25 E S 21 27 E S 2~ 4 E S 47 2 E S 35 56 E S 27 24 : S 20 11 E S 15 8 ~ S 11 41 E S 7 56 E S 3 21E S 1 43 R S $ 38 W COmPUTaTION DATE: 29-J~N-85 =&BE 5 ,~RCO ALASKa, INC. LISBURNE L2-29 PRUDHOE B~Y/LISBURNE N]RTH SLOPE,ALaSKA PDOL INTERPOLATED VALUES FOR EVEN 100 FEET TRUE SJB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPT4 DEPTH 3959.17 3952.00 4060.07 ¢052.00 4160.87 4251.$2 4252.00 62.43 4352.00 53.2/+ ¢452.00 4564.21 4552.00 4555.49 4652.00 4767.49 4752.00 48?0.40 4852.00 4973.96 4952.00 5378.57 5052.00 5184.53 5152,00 5292.13 5252.00 5401.34 5352.00 5512,63 5452.00 5526.28 5552.00 5742.57 5652.00 5862.49 5752.00 5987.90 5852.00 6119.10 5952.00 6252.31 6052.00 6385.57 $152.00 65t8.54 6252.00 ~ ~0o78 5352.00 ( J2.O0 6~52,00 6~13,05 .6552,00 7046.24 7182.29 O0 73z1.85 in OD 7465.1~" 0 7510.8 400 7758.12 7900.67 !52.00 8030,08 7352.00 8152.¢4 8271.38 7552.00 8388.85 7652.00 8506.79 7752.00 8525.39 7852.00 C]JRSE VERTICAL DOGLEG DEVIITION AZIMJTM SECTION SEVERITY DEG MIN DEG Miq FEET 0E$/100 3900.00 4000.00 4100.00 /+300.00 ~400.00 4600.00 4800.00 7 50 S 49 31 W -58.80 0.5/+ 7 35 S 47 38 ~ -57.08 1,05 6 54 S 51 48 W -55.28 1.32 7 12 S 69 31 W -51.17 1.85 7 11 S 85 3q. W -43.86 2.95 7 34 N 72 /+ W -33.23 2.02 8 22 N 59 38 W -19.92 1,4/+ 10 3 N 58 11 W -4.07 2.20 12 37 N 54 55 W 15.82 2.26 14 21 N 52 38 W 40.03 0.97 4900.00 5000.00 5100.00 5203.00 5300.00 5500.00 5600.00 5700.00 5800.00 15 57 N 51 0 W 65.91 1.74 18 17 N 50 5 W 97.59 1.9/+ 20 28 N 49 33 W 132.57 2.55 22 /+4 N 69 5 W 172.30 I.$7 24 63 N 48 56 W 216.16 2.62 27 9 N 48 ¢0 W 265.00 2.04 29 33 N 4? 51 W 318.96 Z.09 31 58 N 47 0 W 378.26 2.52 35 15 N 45 19 W 444,35 3,45 38 ~2 N 45 49 W 519.85 2.72 5900.00 5000.00 6100.00 6300.00 $403.00 6500.00 5600.00 6700.00 $800,00 41 11 N 45 33 W $06.59 0.24 41 23 N 45 19 W 692.38 0.25 41 18 N 45 15 W 783.24 0.21 41 0 N 45 /+ W 867.64 1.21 40 /+1 N 45 11 W 953.93 1.05 40 IZ N 45 21 W 1038.69 0.25 40 /+1 N 45 11 W 1123.17 1.22 41 53 N 44 57 W 1210.88 0.89 43 33 N /+6 42 W 1302.84 1.15 44 56 N 44 3~ W 1399,87 1,01 6900 7000 7100 7200 7300 740O 7500 7600 7700 7800 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 46 Z& N ~/+ 0 W 1502,05 0,79 46 53 N 43 43 W 1607,50 0,42 47 33 N 44 5 W 1715,12 1,74 ~2 15 N 45 23 W 1816.31 ~.83 36 55 N 49 S W 1898.26 4.15 33 56 N 52 25 W /968.68 1.93 32 I N 50 38 W 2033.00 1.47 31 34 N 48 50 W 2094.65 0.49 32 20 N 49 25 W 2157.17 0.17 32 ~4 N ¢8 12 W 2220.90 0.42 DaTE DF SJqv'EY: 22-J~N-95 KELLY BUSHIN3 ELE¢~TiON: 51.03 ~ ENGI~SEq: S~LAZ&q SUB-SEA DEPTH RECTANG~JLAR COORDINATES H]RIZ. DE~AeTURE NDRTH/SOU'TH EAST/NEST DIST. ~ZIMUTH FEET FEET FEET gEG MIN 117.18 S 23.05 W 119.43 S 11 8 ~ 125.20 S 33.07 W 130.46 S 14 41 ~ 134.53 S 42.60 W 141.12 S 17 34 W 140.50 S 53.21 W 150.33 S Z~ 43 W 143.74 S 65.54 W 157.98 S 2~ 30 W 142.10 S 78.13 W 162.15 S Z~ 48 ~ 136.34 S 90.74 W 163.77 S 33 38 W 127.90 S 104.37 W 165.08 S 39 12 W 116.83 S 121.08 W 168.26 S 45 1 W 102.35 S 1~0.58 W 173.~0 S 53 56 ~ 85.75 S 161.73 W 183.05 S 62 4 W 66.26 S 185.45 W 195.93 S 70 20 ~ 43.57 S 212.15 W 216.60 S 7~ 22 W 17.77 S 242.27 W 242.92 S 85 48 ~ 11.02 N 275.36 W 275.58 ~ 87 42 ~ 43.08 N 312.21 W 315.17 ~ 82 8 ~ 79.04 N 352.45 W 361.21 q 77 21 a 119.21 N 396.1~ W ~13.58 q 73 15 ~ 164.64 N 444.23 W 473.75 q 69 39 ~ Z17.20 N 498.62 W 543.87 N 65 27 ~ 276.56 N 559.3~ W 523.97 q 63 41 ~ 335.31 N 622.04 W 708.39 ~ 51 27 ~ ~00.25 q 584.55 W 7~3,07 ~ 59 41 ~ ~62.07 N 746.78 W 878.17 ~ 58 15 N 523.15 N 803.07 N 962.53 q 57 4 ~ 582.92 N 868.~7 W 1345.96 N 55 7 ~ 542.52 N 928.64 W 1129.25 N 55 19 W 704.56 N 990.91 W 1215.91 N 54 34 ~ 770.10 q 1055.92 W 1306.91 ~ 53 53 ~ 839.34 N 1124.36 W 1~03,10 N 53 15 ~ 912.73 ~ 1196,04 W 1504.52 ~ 52 39 ~ 989.20 N 1269.36 W 1509.29 N 52 4 ~ 1367.47 N 1344.02 W 1716.35 ~ 51 32 ~ 1139.23 N 1415.78 W 1817.22 N 51 10 ~ 1195.43 N 1475.54 W 1899.02 N 50 59 ~ 1239.~5 N 1530.55 W 1363.48 N 50 59 W 1279.27 N 1581.15 W 2033.85 ~ 51 1 ~ 1319.40 N 1627.94 W 2095.47 N 50 58 W 1360.72 N 1674.87 W 2157.95 N 50 54 ~ 1~03.08 N 1722.49 W 2221.63 N 50 50 W A~O ALAS~A~ IqC. LISBURNE 12-29 PRUDHOE BAY/LISBUR~E ~]OL N2RTH SLOPE,ALaSKA CDqPUTATI]N DATE: 29-J~N-85 DATE DF SJRCEY: ZZ-JIN-35 (ELLY BgSHIN3 ELECATI]N: ENSINEER: S&:~Z~ 52,00 = INTERPOLATED VALUES FOR EVEN 100 :EET O: SJB-SEA DEPTH TRUE SUB-SEA CDJRSE ME*SURED VERTICAL VERTICAL 2EVI&TIDN AZIMUTH ~EPTH DEPTq DEPTH 3EG 8764.67 7952,00 7900.00 33 20 8B54.85 8052.00 BO00.O0 34 7 8985.52 8152.00 8100.00 33 ZO 9104.69 $252.00 8203.00 32 23 22,55 8352.00 8300.00 31 58 (60.50 8452,00 8400,00 31 58 9658°63 8552,00 8500,00 32 9 9576.67 8652.00 8600.00 32 ZO 9594.87 8752.00 8703,00 31 54 9812.05 8852.00 8803.00 31 9929.32 8952.00 8900.00 31 15 100~6.33 9052.00 9000.00 31 Z 10152.57 ~152.00 ~lOO.O0 30 6 10277.48 9252,00 9200.00 28 10390.95 9352.00 9300.00 27 31 10490.00 9439.84 9387,84 27 31 VERTICAL DOGLEG REST4N.SULAR CODROZN~T~S H]eIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZST. AZIqUTH FEET OEG/IO0 F~ET FEET F£~T ]E~ MIN N 67 25 W 2285.91 N 67 29 W 2352.52 N 45 28 W 2419.99 N 45 20 W 2484,31 N 65 37 W !546.95 N 44 32 W 2609.28 N 46 ~ W 2671.56 N 44 2 W 2734.40 N 43 35 W 2797.13 0.40 3.79 1.94 0.45 0.50 0.33 0.42 1.52 1.19 1445.76 N 1770.68 W 2285,57 N 50 44 ~ 1~91.55 N 1819.75 W 2553.12 ~ 53 39 ~ 1537.7T N 1869,25 W 2~20.51 N 53 33 N 1582.90 N 1915.28 W 2484.73 ~ 50 2~ ,,,I 1526.90 N 1960.07 ~/ 2547.29 N 50 18 ~ 1570.94 N 2004.~2 W 2509.55 .~ 50 11 ~ 1715,59 N 2048.08 W 2571.75 N 50 2 ,/ 1760.99 N 2092,02 W 2734.53 I 49 54 ~ 1.~06.31 N 2135.78 W 2797,20 ~ 49 46 N 1~51.81 N 2175.53 W 2~57.71 N 49 35 N N 39 45 W 2918.10 N 39 3~ W 2978,01 N 39 '8 W 3036.36 N 38 35 W 3092.04 N 37 52 W ~16~.63 N 37 52 W 318~.49 0.32 0.62 1.OS 1.24 5.92 0,00 1896.77 N 2215.8~ W 291~.10 ~ 49 24 W 1945,~8 N 2254.71 W 2978.02 N 49 12 ~ 1991.25 q 2292.32 W 3036.41 N 4~ 1 ~ 2035.32 N 2327.88 W 3392.18 N 48 50 N 2077.41 ~ 2361.06 N 3144.88 ~ 48 39 ~ 2113.55 N 2389.17 W 3189.36 N 48 30 ~ A~O ALASKA, IRC. LISBURNE L2-29 P~JDHOE B~Y/LISBURqE NORTH SLOmE,aL~SK~ MARKER TOP NA,930 ZONE TOP ~A,900 Z3;IE "OP ,QAH30 ZONE _OP ~gDO ZDqE T DP N~q~O ZD~ TOP ~900 Z34E TOP NAHDO ZONE PBTD TD COqPUTaTIDN INT:RPOL~TED V~LOES F3R 4EASJRED DE~TH $SLO~ K~ TRJNCATED gB39.DO 9~60.00 10372.00 LOZBB.O0 10357.00 10619.00 106¢4.30 10~90.00 DATE: 'HOSEN 29-JAN-85 H3RIZSNS ORi$Iq: TVD PROM KB 8978.21 907~.00 ~261.21 9321.93 9376.87 9399.0~ 9439.84 DaTE 3: SJqVEY: 22-J&~-85 (:LLY 5USHI'JG ELC¢&TZ~N:~ 57_.00 5NGIqEER: S&LaZA~ 1961' mSL, 8925.21 ~022.00 9209.21 9Z69.~3 9~24.87 9347.04 1010° SJR:ASE -3C&TION ~T FNL, SEC 18, Tllq~ RISE, RECT&NGJLAq COORDiN&TES NORTH/SSUT9 EaST/NEST 1852.73 N 2185.71 1911.02 N 2226.0~ 1955.65 N 2253.13 2039.2~ N 2331.0~ 2054.9~ N 2351.35 20B7.5~ N 235'9.02 2396.77 N 2375.11 211~.5S N 23~9.17 ~T AR&O ALASKA, INC. LISBURNE L2-29 P~JDHgE BAY/LISBURNE N]RTH SLOPE,ALASKA POOL COMPUT~TI34 DATE: 2g-JAN-85 D~TE OF SURVEY: 22-J~N-~5 KELLY BUSqlNG ELEVATION: ENGINEER: S~LAZ&R 9 .52.00 M~RKER TOP WAH30 ZONE TOP WA9OD ZONE TOP WAHOO ZONE 'DP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP ~AH20 Z3~E PBTD TD OqIGIq: 1951' FSL, ~EASURED DEPTH TVD BELOW KB FROM KB SJB-SEA TRUNCATED 9839.00 ~874.85 ~22.36 9960.00 8978.21 8926.21 10072.00 9074.00 9322.00 10288.00 9261.21 gZO9.21 10357.00 9321.93 9269.93 10419.00 9375,87 9324.87 10~44.00 9399.04 9347.04 10~90o00 9439.84 9387.84 1010 ' SJRFA'E _OCATION ~T FWL~ SEC 1~, TllN, R15E, RECT~NGJ.AR CDOq]INAT'-S N3RTH/S]UTH EAST/NEST 1852.73 '~ 2185.71 W 1911.02 N 2225.0~ W 1955.65 N 2253.13 W 2039.29 'q 2331.0~+ W 205~.98 N 2351.35 W 2057.6~ N 2359.02 W 20~6.77 N 237~.11 W 2113.55 N 2389.17 W FINAL WELL LOCATION ~T TO: TROE S~B-S~A ~EASJRE3 ~ERTICAL VERTICAL DEPTH DEPTH DEPTH 10490.00 9439.84 9387.84 HORIZONTAL 3EPARTUR5 DISTANCE AZt~UTH FEET ]EG MI~ 3189.85 ~ 48 30 W ~T U~ SCHLUMBERGER 0 ~ REC T I ONAL SUR V E Y COMPANY ARCO ALASKA INC WELL LI SBURNE L2-29 FIELD COUNTRY L I SBURNE USA POOL/PRUDHOE BAY RUN TWO DATE LOOOED REFERENCE 000071t94 WELL L2-29 (1961' FSL, 1010' FWL,S18, TllN, R15E) HORIZONTAL PROJECTION I~IOR'I'H :~000 REF 000071 ~94 2501:1 2OOO ! soo 1 ooo SOO · -SOO SOUTH -]000 -3000 NEST SCALE = !/SOO IN/FT -2000 -ISO0 -I000 -SO0 0 SO0 1000 EAST WELL L2-29 (1961' FSI,, lQ10' FWL, S18, TllN, R15E) VERTICAL PROJECTION 130. -MO00 - ! 000 0 0 ! __000 2000 PROJECTION ON VERTICAL PLANE 310, - 130. SCALED IN VERTICAL OEP'THS HORIZ SCALE = 1/1000 IN/FT ~;000 310. Suggested form to be i~,serted in each "Active" well folder to check for timely compi~ance with our regulations. Date Required Da~:e Received Remarks ,, ,,. Inclination Survey 1 ' ' -" '"' ,,~ .. ~__~.~ , ~ ~ ...... Production Test Reports . ~' .... - ...... : ~ , , , ,/., ,: ,~1~ .... D~g~t~d Data ', .... ~.. ,, ~ V(7 '/ , , L. FJ. 04 STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX ARCO Alaska Inc. Lisburne Engineering To: ~tmt~ mf .'i'nhn Rnvl ~ From: Pam Lambert Date: February 4~ 1986 Transmitted herewith are :he following: Magnetic Tapes for Lisburne Wells L2-29 OH LIS Unshifted 1-6-86 Run 1 Tape Number 71151 Sch L3-19 OH LIS Unshifted 12-23-85 Run 1 Tape Number 71115 Sch Receipt Acknowledgement: Return Receipt to:~o Alaska Inc. Pam Lambert ATO 477 PO, Box 100360 AnChorage, Alaska 99510 Transmittal No: ~/ ARCO Alaska Inc. Lisburne Engineering To: State of Alaska From: Pam Lambert John Boyle Date: February 4, 1986 Traasmitted herewith are the following: Magnetic Tape for Lisburne Well L2-29 GCT LIS 1-22-86 Run 2 Tape Number 71194 Sch ~-~ ~ ~-/- ~-~ ~d- ~-/~ ~d Receipt Acknowledgement: Return Receipt ~'~~CO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: ~' ~2 STATE OF ALASKA - ALASKA C._ AND GAS CONSERVATION CO~, AISSION dlONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well :~( Workover operation [] 2 Name of operator 7 Permit No. ARCO Alaska, Inc. 85-297 3 Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21505 9. Unit or Lease Name 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 52 ' RKB 6. Lease Designation and Serial No. ADL 28307 ALK 2317 10. Well No. L2-29 11. F~eld and Pool Prudhoe Bay Field Lisburne 0il Pool For the Month of. January ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2230 hrs, 12/04/85. Drld 17-1/2" hole to 4000'. Ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 4010'. Ran gyro. Cont'd drlg 12-1/4" hole to 4568'. Pumped plug w/455 sx Class G. Sidetracked @ 4104'. Drld 12-1/4" hole to 9760'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9849'. Cored f/9849' - 9951'. Cont'd drlg 8-1/2" hole to 9971'. Cored f/9971' - 10,040'. Drld 8-1/2" hole 1'. Cored f/10,041' - 10,094'. Cont'd drlg 8-1/2" hole to lO,490'TD (1/6/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 10,444'. Secured well & RR ~ 0600 hrs, 1/11/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set 6~ 110'. Installed w/1800# Poleset. 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe (~ 3985'. Cmtd w/1950 sx AS III & 600 sx Class G. Top job performed w/40 sx AS I. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe @ 9736'. Cmtd w/1085 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/9533' - 10,489'. Cmtd w/435 sx Class G. 14. Coringresumeand brlefdescription Core #1 f/9849' - 9865'; cut 16', recovered 15' Core #2 f/9865' - 9880'; cut 15', recovered 9' Core #3 f/9880' - 9887'; cut 7', recovered 6' Core #4 f/9887' - 9897'; cut 10', recovered 9' Core #5 f/9897' - 9917'; cut 20', recovered 20' (cont'd on attached sheet) 15 Logs run and depth where run Gyro f/2000' - 4000' DLL/MSFL/NGT f/10,485' - 9728' CET/GR f/9726' - 6997' MEST/TCC/GR ~ LDT/CNL/EPT/PCD/GRL LSS/Waveforms/GR ( RFT/GR oJ depths not available 6 DST data, perforating data, shows of H2S, m~scellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report ~/~ th~s form is required for each calendar month, Associate Engineer DATE regardless of the status of operations, and must be fded in duplicate w~th the Alaska and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ~nrm ~ n-~n~ TEMP3/MR42 Submit in duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS L2-29 January 1986 Item #14: Core #6 f/9917' - 9924'; cut 7', recovered 7' Core #7 f/9924' - 9929'; cut 5', recovered 5' Core #8 f/9929' - 9946'; cut 17', recovered 17' Core #9 f/9946' - 9951'; cut 5', recovered 3' Core #10 f/9971' - 9986'; cut 15', recovered 14' Core #11 f/9986' - 9991'; cut 5', recovered 4' Core #12 f/9991 ' - 10,001'; cut 10', recovered 10' Core #13 f/10,001 Core #14 f/10,008 Core #15 f/10,010 Core #16 f/10,041 Core #17 f/10,052 Core #18 f/10,063 - 10,008 - 10,010 - 10,040 - 10,052 - 10,063 - 10,088 ; cut 7', recovered 5' ; cut 2', recovered 1' ; cut 30', recovered 5' ; cut 11', recovered 7' ; cut 11, recovered 10' ; cut 25', recovered 25' Core #19 f/10,088 - 10,094 ; cut 6', recovered 3' ARCO Alaska, Inc. Post Office Bc,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12'15 January 14, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the December monthly reports for the following wells: 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 tH-4 2H-9 3A-16 3F-15 4-24 16-20 LS-/5 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 1986 Olt & Gas ~s. ~omm/s~o~ ARCO Alaska In~ ~, f' Su[}.'. d~art, o! Alh, rli~cRIchflclc:Company STATE OF ALASKA ALASKA--..-~AND GAS CONSERVATION Cb-~._~,lSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 17. Or~il~ng well ~J~ Workover operation [] 2 Name of operator 7. Permit No. ARCO Alaska, Inc. 85-297 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21505 4 Location of Well a.t surface 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UM 6. Lease Designation and Serial No ADL 28307 ALK 2317 For the Month of. December , 19 85 5 Elevation in feet (~nd~cate KB, DF, etc.) 52 ' RKB 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10, Well No. L2-29 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2230 hfs, 12/04/85. Drld 17-1/2" hole to 4000'. Ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 4010'. Ran gyro. Cont'd drlg 12-1/4" hole to 4568'. Pumped plug w/455 sx Class G. Sidetracked ~ 4104'. Drld 12-1/4" hole to 9760'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9849'. Cored f/9849' - 9951'. Cont'd drlg 8-1/2" hole to 9971'. Cont'd coring f/9971' - 10,010' as of 12/31/85. 13. Casing o~-[i-~r-[u-~ and qua~t-it~es of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set ~ 110'. Installed w/1800# Poleset. 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe @ 3985'. Cmtd w/1950 sx AS III & 600 sx Class "G". Top job performed w/40 sx AS I. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe 8 9736'. Cmtd w/1085 sx Class G. 14 Con Core Core Core Core Core ng resume and ~rlef description #1 f/9849' - 9865'; cut 16', recovered 15' #2 f/9865' - 9880'; cut 15', recovered 9' #3 f/9880' - 9887'; cut 7', recovered 6' #4 f/9887' - 9897'; cut 10', recovered 9' #5 f/9897' - 9917'; cut 20', recovered 20' (cont'd on attached sheet) 15 Logs ru~-~-~h where run Gyro f/2000' - 4000' 16 DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN ! 4 1986 Oil & Gas Conm, Oommk,mton Anchor30~ 17. I ~h-e~eby certl-~-~l~-t ~l~e-f-orego,ng ,s true and correct to the best of my knowledge. SIGNED_: ___~_ _L,(J/' L/Y,...,, ~/,,~ ~'¢~ ~,_____ TITLE Associ ate Engi neet DATE 1-14-Z~b NOTE Report~n th~s form ~s required for each calendar month, regardless of the status of operations, and must be filed m dupl~cate with the Alaska O~l and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR14 Submit in duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS L2-29 December 1985 Item #14: Core #6 f/9917' - 9924'; cut 7', recovered 7' Core #7 f/9924' - 9929'; cut 5', recovered 5' Core #8 f/9929' - 9946'; cut 17', recovered 17' Core #9 f/9946' - 9951'; cut 5', recovered 3' Core #10 f/9971' - 9986'; cut 15', recovered 14' Core #11 f/9986' - 9991'; cut 5', recovered 4' Core #12 f/9991' - 10,001'; cut 10', recovered 10' Core #13 f/lO,O01' - 10,008'; cut 7', recovered 5' Core #14 f/10,008' - 10,010'; cut 2', recovered 1' RECEIVED JAN 1 4 1986 Aladra Oil & Gas Cons. Commission Anchorage TEMP3/MR14a MEMORANDUM TO' TH RU' FROM: State of Alaska ALASKA OIL ~.~.-O GAS CONSERVATION COMMISS.-~N C V/.~tterton · Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector FILE NO.: TELEPHONE NO.: SUBJECT: December 10, 1985 D.BDF.26 BOP Test ARCO - P.B.U. L2-29 Permit #85-297 Lisburne Oil Pool SundaY,, December, 8., 1985: The BOP test began at 12:00 AM and was concluded a't 6: oo -A/,~, As the attached BOP test report shows, there were four failures, all of which are to be repaired/replaced before drilling out shoe. In summary, I witnessed the BOP test on ARCO's L2-29. Attachment 02-001 A (Rev 10-84) o&~ tt4 5184 . STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report O er or c at on: S Drilltns Sontractor~AO/~/~ w Location, General ~/~ Well SignO/C General Housekeeping~Rtg~ Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Representative ~. ~33/leasing Set ~ ~ ~ ~Z ft. Rig (/d/ Representative ~;~ / ACC~LATOR SYST~ Full Charge Pressure ~/~ psig Pressure After Closure /~~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ~% ~ min:~ / sec. mind'sec. Remote ~ ~ Blinds switch cover ~'...~ Kelly and Floor Safety Valves ', Upper Kelly / Test Pressure ,_~. ~ Lower Kelly / Test Pressure ~'~0 Ball Type / Test Pressure Inside BOP ; Test Pressure Choke Manifold ?~ Test Pressure NO. Valves /~ Test Results: Failures Repair or Replacement of failed equipment to be made within No. flanges ~ Adjustable Chokes / Hydrauicall¥ operated choke Test Time ~ hrs. day~ and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor L~over~ber 29, 1985 ~r. Don E. Breeden Sr. Drilling Engineer ARC() Alsska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit 1,2-29 ARCO Alaska, Inc. Permit No. 85-29.7 Sur. Loc. 1961'FSL, iO10'_F~IL, Sec. 18, TllN, R15E, UM Btmhole Loc. 1085'~/.~L, 159~'FEL, Sec. 13, TltI~, R14E, . Dear Plr. Breeden: Enclosed is the approved application for permit to drill the above reference well. The permit to drill does not indemnify you fro~ the probable need to obtain additional permits required by law fro[~ other governmental agencies prior to commencing operations at the ~e 11 site. To aid us in scheduling field work, please notify this office 2~ hours prior to commencing installation of the blowout pre- vention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~here a diverter system is required, please also notify this office 24 hours prior to com~encin~ equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman Alaska Oil and Cas Conservation Commission BY ORDER OF TIlE COMblISSION b~ Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environ~mntal Conservation w/o encl. l~. Doug L. Lowery ARCO Alaska, Inc. Post Office E,~ 100360 Anchorage_.. Aiaska 995 Telephone .~07 276 !2!5 November 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Lisburne L2-29 Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Lisburne L2-29, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Diagrams showing the proximity to other wells in the area. There are three wells passing within 200' of L2-2S, as discussed in the application. A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment ° A copy of the certified "As-Built" conductor survey We estimate spudding this well on December 1, 1985. If you have any questions, please call me 263-4963. Sincerely, D. E. Breeden Senior Drilling Engineer DEB/tw PD2/LIO Enclosures RECEIVED AlaSka ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chf~eldCompany STATE OF ALASKA ALASKA O,-~.AN D GAS CONSERVATION corv,.~.c~SSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DR ILL I~x REDRILL [] DEEPEN [] lb Type of well EXPLORATORY [] DEVELOPMENT OIL ~(X DEVELOPMENT GAS [] SERVICE [] STRATI ~(~..AP4~. SINGLE ZONE [--IXX MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3 Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location o-f Well at surface 1961' FSL, 1010' FWL, Sec.18, T11N, R15E, UN At top of proposed producing interval 1364'FNL,1269'FEL, Sec.13,T11N,R14E,UH At Target. @ 8952'TVD:1320'FNL, 1320' FEL, Sec.13, T11N, R14E, UN At total depth 1085' FNL, 1594' FEL, Sec.13, T11N, R14E, UN 5. Elevation in feet (indicate KB, DF etc ) 6. Lease designation and serial no. RKB 52', PAD 13' ADL 28307 ALK 2317 1~2- Bond reformation (see 20 AAC 25 025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. D~stance and d~rectlon from nearest town 7-1/2 mi, N of Deadhorse mdes 16 Proposed depth (IVld& TVI~) 10524'MD, 9432' TVD 14. D~stance to nearest property or lease line 1010' 8 surface feet 9. Unit or lease name Prudhoe Bay Unit/Lisbu¢~e 10. Well number L2-29 11. F~eld and pool Prudhoe Bay Field Lisburne Oil Pool Amount $500,000 15. D~stance to nearest drilling or completed L2-28wel1172' @ 1084'MD feet 17. Number of acres ~n lease feet 2560 19 If dewated (see 20 AAC 25.050) 120. Anticipated pressures 3420 KICK OFF POINT 4100 feet. MAXIMUM HOLE ANGLE 37 Ol (see 20 AAC 25.035 (c) (2) 4490 _ 21 17-1/2"~ 13-3/8" 68.0# 17-1/2"I 13-3/8" 72.0# -5/8" 47.0# 8-1/2"I 7_'./ ..... 29.0# 18. Approximate spud date 12/01/85 psig@__ 40°F. Surface ps,g@ 8952..ft. TD (TVD) Proposed Casing, iner and Cementing Program SIZE ..... :ASING AND LINER SETTING DEPTH Grade Coupling/ Length MD TOP TVD MD BOTTOM TVD (include stage data) H-40 Wel~ 80' 39' I 39' 119' 119' 2000# Poleset K-55 BTC/ 70' 39' Ii 39' 109'I 109' L-80 BTC/ 3891' 109' ~ 109' 4000']4000' L-80 BTC/ 9736' 37' II 37' 9773' I 88~2' L-80 BTC/ 951 ' 9573' I 8672' 10524' II 9432' 300SX65%"G"-35%Poz 22. Describe proposed pr~ram. ARCO Alaska, Inc., proposes to drill this Lisburne development well to approximately 10,524'MD (9432'TVD). is planned as a Wahoo production well. Approximately 465' of the Top of the Wahoo will be cored. QUANTITY OF CEMENT 3000 sx AS !11 Lead & 400 sx Class G Tail 750"G"/300AS I &ArcPack A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged. A string of 2-7/8", 6.5#, L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) 23. I ~re~-~-~-e~t[f~/;~hat the forego,ng Is true and correct to the best of my knowledge The-;~p;-~; ~)eiow for co-mm,ss,on u;; CONDITIONS OF APPROVAL Samples required Mud log required DYES '(~NO DYES ~NO _ _ -P-e-~m t~ ~q~J-mber- Approval date ~ APP~:EDBY ~~/~ ' Form 10-401 (PEB) PD2/PD10 D~rectionaI Survey required '~ES I--INO APl number 50- 0 Z Q - ~/~o,~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission November 29, 198 Submit in triplicate PERMIT TO DRILL L2-29 (cont'd) Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Arctic Set I cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig ~ 40°F was calculated from the Wahoo datum pressure of 4490 psig @ 8952'TVD and 183°F. It assumes a 300' oil column to 8652'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and original reservoir pressure in the Put River sand ~ 8084'TVD, yields a maximum surface pressure of 3320 psig @ 40°F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set ~ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history, for surface pipe set at similar depth, shows a 11.5 to 13.7 ppg EMW pump-in gradient just below the casing shoe. Well L2-29 is within 200' of wells L2-26, L2-28, and L2-30. Respectively, those wells are 197', 178'~ and 178' from L2-29 at the surface. The wells run parallel to the various kick-off points. Wells L2-26, L2-28, and L2-30 were drilled to the Northeast from kick-off points at 2500', 1008', and 2416', respectively. The calculated minimum distance between L2-29 and L2-28 is 172' at 1084'MD. The proximity of L2-29 to the other two wells is minimum at surface. Well L2-29 will head Northwest below its kickoff point at 4100'. There are no other wells within 200' of L2-29. /.,N$~~ 0 1000 2000 3000 4000 5000 6000 7000 0 '''Iii''' ' ' ' ' ' ' ' ' ' ''''''''' ' ' I I I I I I I I I I I I i I ] i I ' ' ' ' ' ' ' ' ' ' ' I I I I I 0 ~ [O' CONDUCT~)R TVD - 119 ooo ooo ARC13 ALA,SKA, INC. 2000 I~CAL~ I IN. = 1888 FT. 2000 SHL: 1961' FSL, 1010'F~ L, SEC.18,' '11N, R15E, Ula THL: 1320 FNL, 1320'Ff L, 3000 RFC 1~. ;'11N: R!4F: Il ~ 3000 ~0 - ~ (OP TVD = 41~30 2.5 7.5 ~ 12.5 17.5 K-1E TVD ' ~840 MD -- 481;4 DEP -- 123 5000 22.~ 5000 22.5 36.9 EOC TVl) - 6476 MD - BET8 DEP - N 49 DiG 22 MIN W a070 F'rITO TARGET) AVERAGE ANGLE 6000 ~ - 6000 7000 7000 ~ I-5 TVD--747' MD--8079 [ EP--1862 8000 Pu~ .,v ;,w - uu.~ ~ ~ - .u~u ~--z4~u 8000 LCU TV[I -- 8124 MD 8888 DEP -- 2 SAG RI'~ER TVD-81)8 MD-898~ DEP-2504 SHUBLIK TVD - 8262 MD - 9060 D EP -- 2552 SADLi;ROCHIT TVD = 8302 MD -- 8110 DEP -- 258. K~VlK TVD -- 8~;27 MD -- 9642 DEP = 2901 TVD - ~832 MD -- 9773 DEP - 298( ~ ~ WAHOO ~D ,,8882 MD-- 8811 DEP - 300 9000 TD-7'LINER. ~D ~ 9432 MI) -- 10624 DEP ~ 3431 loooo loooo Alaska 0~t & Gas Corm, C o~ri~o~s~or~ 1000 ................................................................ 11000 0 1000 2000 3000 ~000 5000 6000 7000 VERTICAL SECTION -r- O_ W ED __] CD W W F. - W o -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 W i I I I I I i ! I I I I ! i i i i i i I I I I I I I I I I ] ~HI- 1R~ I'F~I . 1~1~'F WI. . SEC.18, T11N, R16E, IM THL: 1320'FNL, 1320' :EL, SEC.13, T11N, R14E, ~ M TAR ~FT TVD -- TMD -- 9923' DEP - 3070' N 1~ W ~U ................................... (D -6000 -5000 -4000 -3000 -2000 .~m;bo~.~ 0 0 ! 000 ~ - W COORDIN~TP.S C] CD CD C3 o I Z o o L~ I Z P. - W O00ROIN~P.S -6000 -5000 -4000 -3000 -2000 I i i ! i i i I i I I I I ! I I i i i i i i i i ; I ! I ! I I I I I I i J ! ~2-2~ 0 - 0 i i i i i i i i I i i * i i i i i i i i i i i i i i i i i i i i i i i i i i -6000 -5000 - ~000 -3000 -2000 E - N COORDINRTES 76 ,2-26 0 -~00 £ - N COORDINR~S -300 -200 - 1 O0 0 100 ;200 300 400 -300 -200 - O0 0 1 O0 200 300 'tOO E - W OOOROINFITES SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC'. ~ IO" HYD. OPR. BALL VALVE /~...---WE,L,L BORE (SEE DETAIL) / /~ I0 HY?. OPR. BALL VALVE /'~ /'/'"' J ALL 90 TURNS ARE "TEE" ~ J CUSHION I lhELL RESERVE PIT AREA NOTE · FLOWL INE F DRILLING RISER L 20" 2000 PSI WP ANNULAR PREVENTOR lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 2026010203 IRNNUL,~:I - PRE""VENTOR PIPE RAHS BLIND RAMS ILLING SPOOL P[-PE RAMS 11. 12. 13. 14. 15. 16. 17. / 13-5/8" BOP STACK DIAGRAM / Accumulator Capacity Test 1. Check and fill acctmulator reservoir to proper level with hydraulic fluid. 2. Assure that acct~ulator 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 tmits are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressmre. 15-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. ' 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. 6. -In each of the following tests, first hold a 250 psi low pressure test for a ~ of 5 minutes, then test at the high pressu_~F_~x 6. Increase pressure t6.5000 PS~% and hold for a mimJ.mum of 5 mznutes. Bleed pressure to zero. 7. Open annular preventer and _~p. set of pipe rams. Increase pressure t ~f~0-0O_pfi and hold for at least 5 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe r~ms and hold for at least 5 min- utes. 10. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe r~. Back off running joint and pull out of hole. Close blind r~ms and test to 5000 psi for at least minutes. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. 18. Perform complete BOPE test once a week and func- tionally operate BOP~ daily. Revised 2/21/84 o31 30o 240 o~.3 ~'o · H o~ o~ 3 PLAN T RTN Grid Nortlt il 13°North / TIIH VIClNITY MAP ASP ZONE 4 Y = 5 963 094.70 X= 69E 67'0. 6~. 7 Y= 5 963 37'0. 88 X= 692 807. 03 17 Y= 5 963 503.78 X= 692 776. 54 21 Y=5963620.77 X= 692 749.45 25 Y= 5 963 7,:7,7. 69 X= 692 722. 59 29 Y=5965 854.62 X= 692 695.43 Y=5963 971.60 X: 692 668.46 SECTION 18 OFFSET WLO ~,.0 LAT= 70°18' 13.0931" 1166 1197 ~ z 1480E6' 15.1423 ' ~T= ~ ~8',15.8~46 ~ I1~ ~475 LO~= 148°~ 16. 78~ ' LAT= 70°18~1Z 1391 ~ 1082 1609 LO~= 148°~1Z 590~ LAT: 70°lS~,le. Z96~ lOSe 17~6 LAT= 70°18~ 19.45~7 ~ i0~4 1843 LONG~ 148°~6'18 9879" 0 ~ 6 ' LAT=70 18,EO. 091 I010 1961 LONG ~ 148°~ 19 6866" LAT= 70°18'E1.~11" 986 20~9 LONG = 148°E6'19.80~5'' NOTES I. COORDINZ~TES ARE"FLUOR" ASP ZONE 4 PER F. R. EELL DWNG DRILL SITE I..--2, 9 -21- 85 LEGEND WLO: WEST UNE OFFSET SLO_'SOU1~ LINE OFFSET __ .THIS ~JRVE~. CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I 'AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESEI~TS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVlSlON,,,;, AND ALL DIMENSIONS AND OTHER DETAILS It.RE CORRECT. DATE ' SURVEYOR ARCO Alaska , Inc. DRILL SITE L- 2 CONDUCTORS LOCATED IN PROTRACTED SECTION 18, TIIN, RIBE U.M. PREPARED BY LOUNSBURY ~t ASSOCIATES, INC. 725 WGth AVE~ ANCHORAGE,ALASKA OATE:IO/29~5 ._ SCALE: 1",:~30~ - CHKD. BY' GEL , FLIt, BK.= U'IDI~-IOI _ ___ ITEM APPROVE DATE (2.) (2 thru 8) ® me 3. 4. 5. 6. 7, (8) (3) Admin-"~K 1/'Z7~' 9. (9 thru 12) 10. (~0 ~ ~) ~. (4) ~a~ .~. ~. ~ (13 thru 21) (5) BOP E~/~~. (22 thru 26) (6) Add:/~y~, //-f7-~f~c' 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO Is the permit fee attached Is well to be located in a defined pool ............ Is well located proper distance from property li~;°'ii.i.il i~i[ii .i /~K . Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ /~ pl - Is well to be deviated and is wellbore at included ................ Is operator the only affected party ........... '~ ...... Can permit be approved before ten-day ~;i; Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... ~ _ Will cement tie in surface and intermediate or production strings ... /~/ Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ - Is adequate wellbore separation proposed ............................ ~ " Is a diverter system required ............................. ........ .. Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~-'~o psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. -- Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS o H o Additional Remarks: Geo !~: _Engi~gering: HWK LCS ~ BE';;~ WVA ---- MTM H Jif JAL .--.. rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF 'II P_O. OL CLASS STATUS AREA NO. SII0RE 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 APPENDIXl No special effort has been made to chronologically organize this category of information. . . FMS Composite Sepia's 185-297 Are in special storage due to . overSIze. Please ask the Liberian to retrieve them for you in the storage upstairs. ';3 ,.., .~ .., . ...... 0~0;., i i ? .& ! ? ? 1 7 ;. ? ;;5 "; O0 2;, 5, i:5 55 '~ , , .. _; :,} .;, ? 5 ,'~ .- 5.3123 2¢7.551: ~ . 50c';',: - ~ ~ 9.2500 -939 253'~ !973.5093 - e ~'). 250'3 3~3. 5405 ~ .,525 ' !.2595 : 3 '¢:. 50 } ' 2v1!.33:33 -9'~ 9. 72. ?77. ~ ', - v 50 -".3' 12 152.2115 -5 ~5.25'? 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SEAVICES CJSTOqEq =i:L3 TAP= S;q¥IC=_ N&qE DATE :3~/01/23 3R[OIN T~5 N~ :1151 SS~TiNJ~TZ]N ~ :01 ~RE¢iOJS T&PE : '3~ENTS :SCHLJqSE~ER N£L_ SERVICES CJSTOMEq =IELD TAo~ :IL= :I.E NAME :EDIT SEqVICE NAqE : VERSION ~ : MAXI~U~ LEngTH : =ZLE TY~E mREV!OJS FILE : iOZ¢ ¢:',-' IN~DR~qATION qECO~DS ,~:¢ ~fq~M CD,TENTS J~IT 'TYP: '~TE SIZE CDOE SN : ~R'O ALASKA INC. 000 300 015 055 ,~N : LIS6URNE L2-29 033 300 01~ 055 =N : mRJDqDE 8~Y/LiS~UA~E Pg]L 000 JO0 025 955 qAq3: lEE 03} 303 00~ 065 TO~: 11~ ODD 300 00~ 055 SECT: 1~ 000 000 002 055 COJ~: NSqTH S~CP~ 003 300 012 055 STAT: ALASKA OOO 300 905 065 'TRY: US~ OOO 900 003 055 ~N~M CONTENTS ,JNIT TY~E SATE SIZE C30E PRES: E 003 300 031 065 '~:~ :~ COMMENTS .,. ::~ .,. ......... =~= ~NY = ~C] ~SK~ iNC. ~ = _IS3]~= L2-29 LD = ~RJ]t3= ~Y/.iSSJ~E ~])L ~TY = ~2RTi 5_]P~ ]2R]JSfl J3~ "4d'43E~ ~T &'C: 71151 ~Jq mSNf, ]ATE _,DSS=D: ]6-J~N-~5 '~: C. ~ILKIE SiZ= RM= RMS RM ~T = 8.5" TO = .~357 = .0307 = .0599 = .0149 54.9 167. 3F DF ~'~ f ~ i X ...! 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FILE SIZE S~ REPR PR3CESS ID ORPER ~ L3G TYP~ CL&$S ~2~ N2, C$3E (JCT&L) 35~T :~- DO 003 33 O 0 ~ 1 SB O000000OOOOO00 ~T~ SNR _5 O0 000 OD O 0 4 1 53 OOgO000OOOOO00 LV~ OlO.q02 VEqIFIC~TISN LZSTZN} ~A3E 33 00S 003 3E~T 10543.957) HTEq -99.7352 ~£~T 10500.2910 ]E~T 10~00.2913 DE:T lOZOO.2~l~ ~T~ ~TE~ 1272.5~75 35~T 10100.2913 qTE~ 1285.5B75 35~T 10)00.2910 HTE~ 3E~T 9900.291D HT~N 1283.5375 DE~T 9800.2910 ~TE~ 1333.5~75 ~TE~ -999.2500 -)9.7352 -137.~132 1337.5~75 13%0.5875 1272.6675 1255.6575 1327,5~75 !2~3.5575 1B~3,5875 -999.2530 HTE~ HTEq HTEN HTE~ HTE~ ~ FILE TRAILER ~¢ :Z.E N~E :EDIT .DO1 SERVICE NA~E : VERSIO~ ~ : MAXIMUM LEngTH : 1~2~ SE~¢!CE N4~E :E31T ]4TE :~5/01/23 ]Ri$1N :OOOO -lO7.~lOZ 1337.5375 iB~0.6~75 1272.5375 1185.5~75 13Z7.5375 1Z~3.SB?5 1333.5~75 -999.2500 1 $~ 03300930000300 i $~ 33300333003003 1 5~ 0003C333333003 HTSq -99.7~52 HT£~ -137.~102 HTS~ 1307.5875 ~TS~ 13~0.5875 ~T~q 1272.5375 HTE~ 12~5.6375 HTE~ 1327.5875 HT~ 128~.5875 HTE~ 13~3.5375 HTE~ -~99.Z500 TriP5 N~£ :1151 5D~TINJ~TIDN ~ :01 RELL SER~IS=S CJSTS~E~ :i=L~ T~m5 ~EL, SE2¢ISES CJST]~=~ T~oE TAPE LVP 010.H02 VERIFICATION LISTING PAGE I ORIGIN I REEL NAME IR DEPTH CONTINUATION # i01 PREVIOUS REEL I COMMENTS ISCHDUMBERGER WEbb SERVICES PROPRIETARY FIEbD TAPE $* TAPE HEADER SERVICE NAME IGCT DATE 186/01/29 ORIGTN TAPE NA~E 11194 CONTINUATION # PREVIOUS TAPE COMMENTS 15CHbUMBERGER YELL SERVICE5 PROPRIETARY rI£bD TAPE EOF ********** ERViCE N VERSION # MAXIMUP LENGTH I 1024 FiLE TYPE PREVIOUS ** INFORMATION RECORDS ** ; ARCO ALASKA INC 000 000 015 065 .... 0!00 000 014 065 R:ANG~ IB:~ 003 065 ,o,.. ti" OOOo oo 0 0 3 o65 8ECTi 000 000 002 0'6~ $ COU~ N. 5LOPE 000 000 008 065 $~A?~ 0,65 A~ASKA 000 O00 ~RY~ tiaa ~0~ 00~ 003 0~5 MNEM CONTENTS UNIT TYPE CATE SIZE CODE LVP 010,H02 VERIEICATIOt~ I,ISTING PAGE 2 SCHLUMBERGER AhASKA COMPUTING CENTER FIELD - PRUDHOE 5A¥/LISBURNE POOL COUNTY m NORTH 8LOPE ~bASKA = A~$KA dOB NUMBER AT ACCl 7[~94 RUN #?~Ot DATE bOGGEDI22edAN~86 LDPI ~, OGDEN CASING = 7,00" ~ 10434,0' - BIT SIZE = 8,5" TO 10434,0' GYRO CONTINUOUS TOOL CGCT) * LVP 010,H02 VFRIFICATION LISTING PAGE 3 * DEFINITIONS: * HLAZ= AZIMUTH * OEVIm DEVIATION * GDEP= GYRO DEPTH * VDEP~ TRUE VERTICAL DEPTH * NSDR= NORTH OR SOUTH DEPARTURE * EWDR~ EAST OR WEST DEPARTURE * DGb = DOG bEG (CURVATURE OF THE , ****************************** ** DATA FORMAT RECORD ** ENTRY BLOCKS TYP~ $IZEt REPR ~v~DE ENTR¥o 4 I 66 8 4 73 60 9 4 65 ,lin 16 1 66 0 1 66 0 DATUMs~t~ICATION BLOCKS MNE~ SERVICE UNIT APl API AP1 AP1 FILE SIZE SPL REPR PROCESS CODE 0 A ~°~ "~ ~~ "°~ "' ~ oooooo~o~o~ ~EP Los vo~. ~,o~. oo ooo ooo o , , ~ oooooooooooooo ~ ~g~ ~ oo ooo ooo o , ~ ~ oooooooooooooo ooooooo~ooooooo .s~. ,o, ~ oo ooo ooo o , , ,. oooooooooooooo ~,~'. ~o~ oo ooo ooo o , , ~, oooooooooooooo o~ ~o~ ~Too ooo ooo o ~ , ~ oooooooooooooo 65534,0000 GDEP 60,0000 YDEP 60,0000 ~'bAZ LVP OiO.H02 VERIFICA?IO;~ LISTING PAG£ 4 D£¥! 0.30gO N~DR 0.0000 BWDR 0.0000 DGL 897 2496 VDEP ~g7,2086 HLAZ -5:900! EWDR 0,2529 DGL 3317,8984 VDgP 33t5,5391 HbAZ -52,9384 EWDR 15.8588 DG[. 7161,6963 VDEP 6?3?,0654 HLAZ 760.0209 EWDR -I045,9448 DGL 10391,0449 VDEP 9352 0820 20?? ,4429 DEPT DEVI ,0000 GDEP 6550~,7359 NSDR 65400,0000 GDEP 6,4610 NSDR 43, 28 NSDR 65240,5000 GDEP 27,5306 NSDR DEPT OgVI DEPT OEV! DEPT DEV! ** FILE TRAILER riLE NAME IGCT cOO1 8 R ICE NAME VIRIION , ~AXINUM LENGTH ' 1024 LB TYPE 1 NEXT FILE NAME ~* TAPE TRA~IbER ** SERV! NAME ,GCT CONTINUATION ~ 10! N EX T T APE N A ~:E COMMENT6 ISCHLU~BERGER WELL &ERVICE8 PROPRIETARY FIELD TAPE D:ATE ORIGIN l REEL NAME tR DEP~:H CONTINUATION # t01 N~XT :REEL NAM~ : COMMENTS ISCHI~UMBERGER WELL SERVICES PROPRIETARY FIgLD TAPE 0,81.22 162,7352 0,1146 18b,6687 1,0527 3i5,2~73 1,2268 ,13~9 $2~,9779 RECEIVED q739.~3 ~.2 57 23.n, .t17 1~;.3 17,3 ~74],~6 74,2 i49 2b.~ 330 17,9 17.1 9743,~ 22.5 1.~4 30.2 327 20,0 20,0 ~7a5.~ 15.! 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A 0 C C 9, O 16081.~8 28,2 I0083.8~ 33.0 1008b,8~ 10087,88 i 0089,88 100'91,88 1(~093 1 O095 10097 10099 10103,88 10~07,88 0 lol I 3 ln~ 15 4,9 6,3 1,9 4,2 t 0, 4,9 5,2 1'!,2 ! 7,0 6,7 t4,4 I4,1 19 · 7 9, ~ o3 ~l,B 324 ~.~ 71 31,7 32~ ~,0 55 31.7 324 353 31,7 ½24 9,~ 213 31.5 J24 10.1 104 ~1.6 32q 9,4 25 31.7 324 9,2 323 31.7 324 72 ]1,7 324 *~R 31,8 ~24 8,8 22 31,8 524 8,8 117 31,8 t24 185 31,8 324 8,9 29~ 31,9 324 ?1 ~l,g 324 ~,8 69 32,0 324 ~,9 BO 32.0 324 8,8 319 31,9 324 ~,9 254 31,8 324 8,9 255 31,7 324 8,9 ,'38 3!,7 324 8,9 !lO 31 6, 324 8,9 121 31,5 324 9.0 69 31 .5 32~ 7~ ,5 324 9,0 324 8 9 95 31,5 3~4 8,9 !23 3],5 324 8,9 t13 31,4 324 8,9 lOq 31,4 ]24 9,0 5~ 31,3 324 74 31,3 324 g,O 85 31, 24 8,9 55 31,3 32.4 209 31.2 324 8.9 9,3 9.3 9,7 9.9 9,9 10,1 9,2 9,3 9 1 ~ 2 i) b D 0 0 L) A C C c C 2 C 2 C 1 l~t.:l'i.a~ 11..~ 213 31.2 324 IPI39.U~ ~t,6 13ti 31,2 324 8,9 I0143,S~ ].b 152 31,2 324 ~,9 l 01 ~4. b, 8~ 3,4 159 31,2 324 10147,8a 10,2 262 31,2 324 1l)1.i9,~i~ 12.4 270 31,2 .~24 I 01'.)7, ~ 5,~ 25t ti,1 t2t 8,9 1;)159,~8 7,3 2]B ]1,0 ~24 9,0 J0161,88 10.~ 262 tI,U 324 9,2 10163,~8 b.O 12 31.0 ~24 1016b,8~ 4,5 40 30.9 324 ~.3 10167.88 1.8 21 30.9 324 9.2 10169,~ 1,9 .~20 30,9 32~ 10171,88 5,6 t45 30.9 324 9,4 1017,t,8~3 4,t} 3~ 30 6 325 ~ 3 10175,88 2,9 21 3018 325 9 7 10177,88 !,~" 327 ~0,8 325 9 10179,88 6,4 07 30,8 325 9 2 tOj87,~8 0,9 I O, 3 8,8 10 1,88 1,2 253 ~0, 324 8,8 10193,88 2,9 175 39,7 ]24 I0,95.88 '.1 !77 ,0.7 ,24 ~.9 * 1<'19; a~ !(.).~ ~70 30,~ ~2~ 8,8 1019. 88 0,9 03 30, 24 8,9 .... } 7 ~3~ 30 7 324 10203 ~a 3,U 96 30,7 32~ ~,~ 102t, 5 8~ 4.6 92 30,65 ~ 8,9 C'""~ 7 125 30 4 324 [~,9 1021i 88 I6.4 i19 30,4 324 8,9 1<)213 89 ll.b 288 30,q. 32b ~,[) 10215.1 88 12;I ~08 30,4 324 ~,9. *************************************** 9,2 9,1, 9,1 ~,1 9,1 9,1 9,1 9,1 9,0. 9,0 9,1 9,1 9 2 9 2 9 2 9 i 9 2 9 C 9 1 9 2 9 t A A A L~, A C B a A A A A I 10219.~B 6.9 1 30,4 324 1()221.8L~ }Z.3 81 ~0.4 ~2~ iq22b.88 9,o 121 30,4 10227,8~ lO,b 275 30,4 324 t(~229.~ '~,~ 2lu .~0,4 324 102tb,Bh 4.b lb9 ~0.3 324 I (~237.B8 4.b 1~3 3U,3 1.02~9.8E 9.b 301 30,3 325 10241,88 1.1 20,i 30,2 325 10~43.88 1.2 i80 30.2 ~25 10245,88 ~,9 22 30,1 325 10247.~8 11,3 50 30,1 325 10249,~8 10.1 34] 30,0 325 10251,88 11.7 329 30.0 ]25 10253,88 ~,1 175 30,~ 10255,88 4,0 319 30,0 325 10257,88 3,2 29 30,0 325 1,0259' 88 3,3 35 30.0 325 !02b!,~ 2,0 5~ 30,0 1/~20 ,88 10.9 7t 29. ,2:5 102 .88 12,5 145 30. 4 10273.8~ 9,9 101 30,0 324 10275,~8 2.0 2~ 30.0 325 I0283;88 20.0 130 29.6 325 i0287,B8 11,~ 118 10289,88 t0,9 ]00 29,6 325 I0295;88 t.7 3~0 29 ~,9 8,9 8°9 9,0 9,3 9,2 9.2 9,2 8.9 8.9 8~9 ~ 0 ~25 525 q, 1 9,2 9,2 9.1 9.2 9,1 9,2 9.2 9.2 9,1 9.3 9,4 9,2 9,2 9.I 9 1 9 2 9 3 9 4 9 4 9 5 9 4 9,5 9,5 9,5 9'4 9,3 9 I 4.{~ 3!! 29,5 325 ~.~ 2,7 ~5 29,5 t25 u.7 i16 29,5 ]2b 8,~ 5,7 40 29,5 ]25 5,'t 49 29,5 325 4,~ tOu 29,6 325 ~,~ 5,2 2~ 29,6 325 ~.2 32 29,5 325 8,9 i0.5 101 29.4 325 8,9 3.o 39 29.3 325 8.9 3..~ bO 29,3 325 ~,9 4,0 53 29.2 ]25 g.9 4,t 89 29,2 325 ~,9 5.1 41 29,2 325 ~,9 7,4 14 29,~ t25 8,9 6,~ 11129.1 325 8.9 5,b 111 29,1 325 8,9 3.~ 58 29.1 325 2,~ o6 29,1 325 ~,9 2.9 78 29,1 325 8,9 4,b 57 29,0 325 9,0 6.6 232~ 9. 325 ~,9 . 325 8,8 b 6 106 28.~ 325 4 b 88 2a,7 325 8,9 12,t 11128. 325 b. 2 . 325 9 2~ 2~* 32b , 325 , * * 103u5,~ * 10311 ~ 103i3.~8 * t0319,8M * Iu321 * , 1033t,88 * 10335.88 ~ i. 0337,88 * 10339.88 * 1U34~,88 , t0.34 * i034b,8~ * t03,t7,88 * 10349,88 * 10351 * 10353 * 1O355 * 10357 88 * 10359 * I05~1 * I0365,88 * 1036~,~8 * t036 * 1. u309, ~g 4 , t0~71.8~ 20 * 1 ~)37,~, 88 * t0375 ;~8 6 79 28'I ],~ 8;37'9 50 28, 8,5 *********************** 9.1 9,I 9,1 9,U 9,1 9,0 9,1 9,~ 9,0 9,2 9,2 9, 9 5 9 7 9 4 8 9 O 0 9 0 9,3 10379,~8 10381.b8 1~,383.~ I f~'385..{{ 10399,88 lo401,88 1C4{39,88 1041I,B$ 1041.5 88 I0423'88 1042b,8@ i0427,88 1.04~,8~ 10433,88 10435.88 1043'!, ~ 8 I04~9,88 10441 88 10443 ~8 1044~ ~ 1044 4.5 3,7 7.3 9 b 7 ! 7 8 7 7 C b2'29 ********************* DiP OEg DE~V O]AM AZ~ AZ~ 1-3 g9 2~.'~ 325 9b 28.7 32o 80 28.6 326 43 28.5 326 154 28.4 .~26 146 28.4 325 8 148 2a,4 325 298 28.3 325 176 28.3 325 183 28.3 325 82 28,3 325 170 28,3' 325 132 28,2 326 31 28.1 325 171 2~,1 326 125 28,1 32~ 118 2a.(~ 326 8 123 28.0 326 60 27.~ t26 59 27,g 326 112 2~,~ 326 lOb 2'1.9 326 8 94 27.9 325 53 27,9 325 8 37 9 0 2t,~ 325 8 ~29 27,8 8 143 27~8 J25 258 27'7 ~25 8 53 , 325 121 27.0 325 131 27 5:~. 3~5 a 9,2 A g.1 h 9.1 C 9,(: C 9,i C 9,0 C 9, () C 9,0 C 9,0 A 9,6 A 9,0 A 9.U D 8,9 C 9,0 A 8,9 A 8,9 A 8,8 A 8.7 A , 8,6 A * 8,J A 8,3 A 8,0 g 8,0 A 8,0 6 8,0 B 8,0 C ~' 4 C * 8~b O ~,2 C :8,0 C 8, i B ************************************** L) 21.4 32.5 21.~, 325 21,4 325 2 I, .~ ~25 2'1.~ 326 27,2 2 1o 1 1 2 2 I 1 2 2 I 2 1 2 2 i 1 1 I 1 1 150 1 2 2 1 1 21 0 1 2 1 240 1 1 2 3 2 4 2 6 q 2 7 1 5 120 i5(3 $ 210 240 7 b 4 2 ~ 1 6 B 14 2 3 1 13 7 2 2 2 5 5 5 5 6 2 2 6 o 7 4 4 ? 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