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186-175
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG AUG 0 6 7 19 la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned D • Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ El WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Class �` p �� Developm 'Ex t0mt IService ❑ Stratigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., Aband.: 7/11/2019 . 14. Permit to Drill Number/Sundry 186-175 • 318.045 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7, Date Spudded: 11/4/1986 15. API Number: 50-029.21663-00-00 ' 4a. Location of Well (Governmental Section): Surface: 812' FNL, 833' FWL, Sec.22, Tl lN, R15E, UM Top of Productive Interval: 141 1'FNL, 4361' FWL, Sec. 22, T11 N. R1 5E, UM Total Depth: 1479FNL, 4473' FWL, Sec. 22, T1 IN, R15E, UM 8. Date TO Reached: 11/20/1986 16. Well Name and Number: PBU L3-22 9 Rat Elevations KB 60 GL 22.38 BF 23.44 17. Field/Pod(s): PRUDHOE BAY, LISBURNE OIL 10. Plug Back Depth(MD/TVD): . 9526'/ 8481' 18. Property Designation. ADL 028322 ' 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 708096 - y- 5961492 Zone - ASP 4 TPI: x- 711640 y- 5960991 Zone - ASP Total Depth: x- 711755 y- 5960926 Zone - ASP 4 11. Total Depth (MD/TVD): . 10480'19399' - 19. DNR Approval Number: 84-82 12, SSSV Depth(MD/TVD): None 20 Thickness of Permafrost MD/TVD: 1900' (Approx.) 5. Directional or Inclination Survey Yes ❑ (attached) No 0 Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (R MSL) 21. Re-dell/Lateral Top Window MD/TVD: 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 my, 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 NOT /DLL,GR/CNL/LOT I EPT/ Cal, CBT, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# 1+40 39' 119' 39' 119' 30" 1725# Poleset 13-3/8" 68#!72# K-WLau 38' 4110' 38' 4014' 17-1/2" 2350 sx AS III, 600 sx Class'G', 150 sx AS 1 9-5/8" 47# L-80 36' 9869' 36' 8808' 12-1/4" 790 sx Class'G', 300 sx AS I, 175 sx Clasw'G' 7" 29# L -m 9618' 10480' 8568' 9399' 8-1/2" 300 ax Class 'G' 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 1�. 'V4A DATEPer VE IFIED LILs. / «-�=---- 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TV 2-718" 6.5# L-80 9527' - 9668' 9582't 8534' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): WA Data of Test: Hour: Tested: Production for Test Perm y Oil -Bbl: Gas -MCF: Waler-Bbl: Choke Slue Gas -011 Ratio: Flow Tubing Press Casing Press: Calwlaled 24 Hour Rate .. 11, Oil -Bbl: Gas -MCF: Water -Bbl: Oil GraWN- API(com: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RSDMS±-1' AUG 0 9 2019 11-L 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes ❑ 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 ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 Top of Productive Interval 9923' 8858• AAC 25.071. Lisburne - Wahoo Zone 7 9923' 8858' Wahoo Zone 6 10008' 8940' Wahoo Zone 5 10140' 9068' Wahoo Zone 4 10242' 9167' Formation at total depth: Wahoo Zone? 10242' 9167' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby Certify that the foregoing is true and Correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Thompson, Jacob Authorized Title: SI Sp list I Contact Email: Jacob.Thompson@BP.com Authorized Signature: Contact Phone: +1 907 564 5579 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 wail 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 Is. 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 11b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage Cementing and the location of the Cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the Corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Forth 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: L3-22 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9853' Set Plug 9825' 44 Gal Class'H' 9708' Set Plug 9650 44 Gal Class'H' 9639' Set Plug 9527' Cut & Pull Tubing 9526' Set Whipstock Daily Report of Well Operations PBU L3-22 TWO = SSV/1750/0 TEMP = SI, PPPOT-T (PASS) PPPOT-IC (PAS) Pre Rig PPPOT-T: Stung into test void 20 psi, bled to 0 psi. Monitored for 10 min, no change in pressure. Function all (LDS), all moved freely. Unable to get torque wrench on one (LDS) pin at the 4 O'clock. Marked with red tape. Torque all (LDS) to 550 ft/lbs. Unable to pump through test void and take returns of fluid.Pressure test void to 5,000 psi for 30 min test. Lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bleed to 0 psi. PPPOT-IC: Stung into test void 50 psi on void, bleed to 0 psi. Monitored for 15 min, no change in pressure. Function all (LDS), all moved freely. Torque all (LDS) to 550 ft/lbs. Unable to pump through test void to take returns. Pressure to 3,500 psi for 30 min test. Lost 100 psi in 5 min, 2/23/2019 1 lost 0 psi in second 15 min (PASS). Bleed to 0 psi . ****WELL S/I ON ARRIVAL****(sidetrack) RIG UP SLICKLINE 5/28/2019 ****CONT WSR ON 5-29-19**** ****CONT WSR FROM 5-28-18****(sidetrack) P/T CONTROL LINE TO 4500 psi (holding) RUN 2.35" NO-GO CENT TO 950' SLM (unable to pass, paraffin on tools) ATTEMP TO BRUSH & FLUSH TUBING (well pressuring up) RUN KJ, 2'x 1-1/2" STEM, 1-3/4" S -BAILER TO 1,162' SLM (hydrates in bailer) MAKE MULTIPLE RUNS WITH GAUGE RINGS TO CLEAR UP HYDRATES & PARAFFIN FROM 950' SLM TO 3,500' SLM (see log for details) 5/29/2019 1 ****CONT WSR ON 5-30-19**** T/1/0=1300/1740/0 Temp=Sl Assist SLine w/ B&F and Tbg Load (SIDE TRACK) Pumped 2.2 bls crude down Tbg and Tbg pressured up to 2500 psi. SLine ran bailer and got back hydrates. Pumped 225 bbls of 100* F crude into the IA. TBG pressure came up to 2850 psi. Bled TBG to 2700 psi but could not bleed it any lower, started to get fluid back. Pumped 5 bbls of 50/50 McOH and 50 bbls of 180* F crude into the TBG. Pumped another 84 bbls of 180* F 5/29/2019 crude into the TBG while SL brushed. ***Job Continued to 05-30-2019 WSR**** ***Job Cont from 05-29-2019 WSR*** Pumped 31 bbls (50 bbls total) 180* crude down Tbg while Sline brushed. Pumped 50 bbls 90* crude down Tbg to flush Tbg. SB for SLine to change out gas lift valves. ***Job Cont 05-31- 5/30/2019 2019 WSR*** ****CONT WSR FROM 5-29-19****(sidetrack) BRUSH & FLUSH TUBING W/ KJ, 2-7/8" BRUSH, 2.15" GAUGE RING DOWN TO 9700' SLM. LRS FLUSH TUBING W/ 50 BBLS CRUDE. SET 2-7/8" KEYLESS X -CATCHER (XN-51, OAL 66.5") @ 9629' SLM. PULL BK-DGLV FROM STA #5 (8944' MD) PULL BK-LGLV FROM STA#4 (7531' MD). STA#3 (5390' MD) & STA #2 (281 VMD) SET BK-DGLV IN STA #2 (2811' SLM), STA #3 ( 5390' MD), DROPPED BK-DGLV FOR STA #4. ATTEMPT TO FISH BK-DGLV PULL RKP-PRONG FROM STA #6 (9475' MD) 5/30/2019 ****CONT WSR ON 5-31-19**** Daily Report of Well Operations PBU L3-22 ****CONT WSR FROM 5-30-19****(sidetrack) RUN 3' 1-1/4" STEM, 2.30" CENT, 2.25" LIB TO 9627' SLM (impression of PCT) VERIFY STA #4 (7531' MD) EMPTY WITH PINNED JK RUNNING TOOL. VERIFY STA #5 (8944' MD) EMPTY W/ 1.25" LIB. BAIL PCT FROM 2-7/8" KEYLESS X CATCHER AT 9627' SLM W 10'x2.25" PUMP BAILER PULL 2-7/8" KEYLESS X CATCHER FROM 9627' SLM (sta#4 bk-dgly recovered). SET 2-7/8" KEYLESS X- CATCHER @ 9627' SLM. ATTEMPT TO SET BK-DGLV IN STA #4 (7531' MD) 5/31/2019 ****CONT WSR ON 6-1-19**** 5/31/2019 ***Job Cont from 05-30-2019 WSR**** LRS 72, Assist Slickline with MIT -IA Oob postponed) T/I/0= 680/1505/12 ***Assist SLB/SL with Load & Test** (SIDETRACK) Pumped 3 bbls Methanol (50/50) spear followed by 630 bbls of 180* Crude down the IA through station #6 for 6/1/2019 IA load, Continue WSR to 06/02/19, ***See log for details*** ****CONT WSR FROM 5-31-19****(sidetrack) SET BK-DGLV IN STA #4 (7531' MD). SET BK-DGLV IN STA #5 (8944' MD). PULL RKP-RKED VALVE FROM STA#6 (9475' MD). CURRENTLY LRS LOAD IA W/ 700 BBLS CRUDE (see LRS log for details) 6/1/2019 ****CONT WSR ON 6-2-19**** ****CONT WSR DROM 6-1-19****(sidetrack) SET RK-DGLV IN STA #6 (9,475'md) LRS MIT -IA TO 2,500 PSI (pass). PULL STA#1 BK-DGLV. PURGE CHEM INJ LINE W/ 6 GAL OF HYDRAULIC FLUID. SET STA#1 BK-DGLV. PRESSURE TEST CHEM INJ LINE TO 3,000 PSI (pass). PULL EMPTY 2-7/8" CATCHER FROM 9,654' MD 6/2/2019 ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** ***Continued WSR from 06/01/19*** Continued pumping 70 bbls of 80* Crude down IA to station #6, MIT -IA ***PASSED*** at 2666 psi, Pumped 29 bbls Crude to reach max applied of 2750 psi, target pressure 2500 psi, 1 st 15 min TBG lost 20 psi, 2nd 15 min TBG lost 17 psi for a total loss of 37 psi in 30 min. Bled back 11.7 bbls Crude. FP TBG with 15 bbls crude. FP FL 6/2/2019 with 5 bbl 50/50. SSL in control of well @ departure. FWHP= 1300/-16/16 ***HES RELAY UNIT JOB PREP IN HES SHOP*** ***WELL S/I ON ARRIVAL*** (sidetrack) RIGUP HES 046 RELAY UNIT 6/8/2019 ***CONT.TO 6/9/19 WSR*** ***CONT. FROM 6/9/19 WSR*** (sidetrack) DRIFT W/ 40'x 2.16 DMY GUNS, 5'x 2" BAILER, TAG STICKY BOTTOM AT 9832' SLM ATTEMPT TO SET HES TTBP, CURRENTLY STUCK AT 8744' SLM 6/9/2019 ***CONT. TO 6/10/19 WSR*** T/I/0= 9/194/12. Assist Slickline (SIDETRACK) ***SEE LOG FOR DETAILS*** Pumped 74 bbls Crude down TBG, total TBG volume to Assist HES relay, Pumped 40 bbls of 180* Crude 6/9/2019 down TBG, ***WSR CONTINUED TO 06/10/19*** T/1/0=570/175/5 Temp=S/I (LRS -76 Assist HES) Loaded TBG with 2 bbls 50/50 meth and 80 bbls 1 % KCL. Freeze protected TBG with 15 bbls crude. RDMO. Hung tag on WV. HES in 6/9/2019 control of well upon LRS departure. IA/OA=OTG. FWHP=800/110/10 WSR continued from 06/09/19 ***ASSIST HES RELAY*** (SIDE TRACK) Continued pumping 259 bbis of 180* Crude down TBG. Pumped 50 bbls of 1% kcl w/safelube, followed by 25 bbls crude for freeze protection. Slickline still on well at LRS departure. FWHP= 131/391/26 **Tbg load tag hung on MV** 6/10/2019 1**Tbg FP tag on MV** Daily Report of Well Operations PBU L3-22 ***CONT. FROM 6/9/19 WSR*** (sidetrack) PUMPED 50 BBLS SAFE LUBE SLICK KCL & 25 BBLS CRUDE JARRED ON STUCK TOOL @ 9,023' SLM, ABLE MOVE DOWNHOLE TO 9,327' SLM BUT UNABLE TO COME FREE DROPPED KINLEY CUTTER, CUT WIRE, ALL WIRE RECOVERED W/ KINLEY CUTTER RELAY TS LEFT IN WELL @ 9326' SLM, OAL = 43.13' 6/10/2019 ***CONT. TO 6/11/19 WSR*** T/I/0=vac/340/20 Temp=S/I (LRS Unit 42 Assist Relay Unit- Sidetrack) Pumped 50 bbls 6/10/2019 crude down TBG to assist HES. **Continued on 06-11-19 WSR** ***CONT. FROM 6/10/19 WSR*** (sidetrack) RAN 2-7/8" GR, 2.22" BAIT SUB,XO, & 2" GUTTED SPLIT SKIRT JD TO 9420' SLM UNABLE TO LATCH FISH, RECOVERED PIECES OF RUBBER ELEMENT AND BRASS RAN 2-7/8" GR, 2.22" BAIT SUB,XO, & 2" GUTTED SPLIT SKIRT JD TO 9420' SLM UNABLE TO LATCH FISH, JD SKIRT EGGED OUT LATCH & SET GUTTED 2" JD W/ 2-7/8" BAIT SUB ON FISH @ 9420' SLM ATTEMPT TO FISH TS W/ 2-7/8" GS, MOVE FROM 9409'- 9401' SLM, FISH FELL TO 9468' SLM ATTEMPT TO FISH TS W/ 2-7/8" GS, MOVE FISH FROM 9489' SLM TO 9439' SLM ***CONT.TO 6/12/19 WSR*** 6/11/2019 ***Continued from 06-10-19 WSR** (LRS Unit 42- Assist HES Relay: Sidetrack) Rigged down. Did not pump any fluids. HES in control of well upon departure. IA OA= OTG. Final 6/11/2019 Whp's=200/200/20 T/I/O= 7/ 164/3. (Assist Wire line.). Pumped 112 bbls crude down TBG while HSL ran brush. 6/12/2019 Job cancelled. FWHP's 67/82/5. HSL on well upon departure. ***CONT. FROM 6/11/19 WSR*** (sidetrack) RIH W/ 2-7/8" GR, LATCH FISH @ 9447' SLM MOVE TO 9404' SLM RIH W/ 2-7/8" GS, LATCH FISH @ 9404' SLM, RECOVER RELAY TS (MISSING SLIPS & BOW SPRINGS) RAN 2.29" MAGNET TO MASTER VALVE, DID NOT RECOVER ANY MISSING PARTS. RAN KJ, BRUSH,DOUBLE KJ,BRUSH, & 2.05" G-RING TO 9507' SLM UNABLE TO PASS (RECOVERED PIECE OF BOW SPRING) 6/12/2019 ***JOB POSTPONED FOR PRIORITY JOB*** ***CONT. FROM 6/12/19 WSR, WELL SHUT IN ON ARRIVAL*** (sidetrack) RIGUP HES RELAY UNIT 046 RIH W/ 2.29" G-RING, SD @ 9524' SLM, NOTHING RECOVERED 6/13/2019 ***CONT. TO 6/14/19 WSR*** T/l/O = 0/150/0 Set TWC. RU Gray lubricator with 2-9/16" CIW 'H' TWC #353. PT to 350/3500psi (PASS). Run down and set at 102" LTT (PASS) RD lubricator and install tree cap. PT to 500psi (PASS) RDMO ***Job in Progress*** SEE LOG FOR DETAILS Final T/I/O 6/14/2019 = TWC/150/0. ***CONT. FROM 6/13/19 WSR*** (sidetrack) SSV LEAKING, GREASE CREW UNABLE TO FIX, MASTER/SSV/SWAB S/1 RIGDOWN & GO INTO MAINTENANCE 6/14/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** Daily Report of Well Operations PBU L3-22 ***CONT. FROM 6/14/19 WSR, WELL S/I ON ARRIVAL' (sidetrack) RIGUP HES RELAY UNIT 046 RAN SWORD MAGNET TO 9524' SLM (no recovery) RAN BAITED 1 PRONG WIRE GRAB TO 9524' SLM WORKED TO 9540' SLM (no recovery) RAN 2.12" MAGNET TO 9524' SLM (no recovery) RAN 2.29" BELL GUIDE WITH INTERNAL THREADS, & 1.84" MAGNET SAT DOWN @ 9527' AND WORKED DOWN TO 9542' SLM UNABLE TO PASS, POOH (no recovery) RIH W/ 2-7/8" GR, 2.22" BAIT SUB, & 1 PRONG WIRE SPEAR, GRAB FISH 9545' SLM, FISH FELL OUT TBG TAIL, SHEARED OFF AND LEFT BAIT SUB W/ PRONG ATTEMPT TO RECOVER 2-7/8" BAIT SUB,XO, 1 PRONG WIRE GRAB (CAL = 47") UNSUCCESFUL DRIFT W/ 2.0" G- RING, TAG FISH @ 9832' SLM *****FISH LEFT IN HOLE****** 6/15/2019 ***CONT. TO 6/16/19 WSR*** T/I/O=TWC/200/0.Pre rig. Remove 2 9/16" Cameron upper tree. Install 2 9/16" ASV #9 and SV #34. Torqued to API spec. PT to low 300psi and high 5000psi for 5min ea. Passed. Pulled 2 6/15/2019 9/16" TWC #353 @ 78". PT tree cap to 500psi. Passed. Job Complete. See log. Final WHP's T/1/0=0/165/0 Assist HES relay (SIDETRACK) Road unit to location/ spotted equipment. 6/15/2019 *** WSR continued on 06/16/19*** ***WSR continued from 06/15/19*** Pumped 3 bbls of 50/50 MW followed by 90 bbls of 120* crude down TBG to load and flush. Pumped 3 bbls 50/50, followed by 87 bbls of 11% kcl. Flush surface lines with 1 bbl 50/50. Freeze protect tbg with 25 bbls crude. Standby as contingency. 6/16/2019 *** WSR continued on 06/17/19*** ***CONT. FROM 6/15/19 WSR*** (sidetrack) LRS PUMP 90 BBLS OF CRUDE, SEE LRS LOG DRIFT W/ 2.0" G -RING TAG BTM @ 9819' SLM DRIFTED TBG. WITH 40'x 1.75" BAILER TO 9835' SLM PUMPED 90 BBLS I% KCL & 25 BBLS CRUDE RIH w/ 1.69" E DPU TO TEST TOOLS, STOP @ 9800' RLM, ENCOUNTER WIRE ISSUES WIRE STUCK IN S.BOX, UNABLE TO POOH @ 9529' RLM, STANDBY FOR PLAN FOWARD 6/16/2019 ***CONT. TO 6/17/19 WSR*** *** WSR continued from 06/16/19*** Standby as contingency/ Rigged down for scheduled maintenance,( LRS unit 70 to take over). HES in control of well upon departure. FWHP's 6/17/2019 vac/210/15. T/1/0=vac/215/5 Temp= S/I (LRS unit 70: Assist HES Relay/Sidetrack) Took over job for Unit 46 (Scheduled Maintenance) Pumped 3 bbls of 50/50, followed by 75 bbls of 1% KCL, along with a 15 bbl Crude FP down TBG to load. Slickline in control of well upon LRS departure. 6/17/2019 Tags hung. FWHP's vac/245/vac ***CONT. FROM 6/16/19 WSR*** (sidetrack) LRS L&K W/ 75 BBLS OF KCL, 15 BBLS CRUDE, SEE LRS LOG BRING RELAY TS TO SURFACE PER APPROVED PROCEDURE, RECOVERED ALL TOOLS FROM WELL RIGDOWN RELAY UNIT 046 6/17/2019 *** WELL S/I ON DEPARTURE, DSO NOTIFIED*** Daily Report of Well Operations PBU L3-22 T/1/0=vac/171/vac Temp=Sl (LRS Unit 70 -Assist Slickline) Spear in to TBG with 3 bbls of 60* 50/50 meth H2o followed by 75 bbls of of 120* 1 % kcl, cap with 15 bbls of 50/50. Pumped 78 bbls 120* 1% kcl followed by 15 bbls 70/30 meth. Slickline in control of well upon LRS departure. 6/21/2019 FWHP's vac/230/2 ***WELL S/I ON ARRIVAL*** (Sidetrack) HES RELAY UNIT #46 DRIFT W/ 2.21" G. RING TO TAG AT 9827' SLM (hard btm). DRIFT W/ 2.16" x 48' DUMMY GUNS TO TAG @ 9827' SLM (hard btm, tools pick up freely). 6/21/2019 ***JOB CONTINUED ON 22-JUN-2019*** T/I/O= 8/180/0 Temp=Sl (LRS Unit 70 Assist Relay: Stuck in Hole) Pumped 2 bbls meth 6/22/2019 followed by 16 bbls crude down TBG as freeze protect. ***WSR continued on 06-23-19*** ***JOB CONTINUED FROM 21-JUN-2019*** HES RELAY UNIT #46 RAN 1.69" DPU SETTING TOOL FOR TEST RUN, UNABLE TO PASS 9518' SLM DUE TO POSSIBLE DEBRIS. PU & STROKE TOOL AT 9400' SLM. RAN 2.211"G. RING, PUSHED DEBRIS FROM 9518' SLM TO TOC @ 9827' SLM. RAN 48'x 2.16" (max od) DUMMY GUNS, TAG STICKY BTM @ 9731' SLM. RAN 1.69" TTBP, LOST COMMUNICATION WITH TOOLS @ 9,500'. TROUBLESHOOT SURFACE EQUIPMENT, COULD NOT RECEIVE DATA FROM TOOL (NO CCL). RIH TO 9530' STILL NO COMMUNICATION, PULL UP HOLE TO SEE IF CCL WILL COME BACK. WHILE POOH TRYING TO GET DATA BACK WE BECAME STUCK IN GLM @ 9475' MID ... CURRENTLY STUCK IN HOLE. 6/22/2019 ***JOB CONTINUED ON 23-JUN-2019*** ***WSR continued from 06-22-19*** (LRS Unit 70 - Assist Relay: Stuck in Hole) Pumped 50 bbls 105*F 1 % Kcl w/ safelube down TBG followed by 15 bbls crude as freeze protect. Pumped 4.3 bbls crude down TBG to aid in plug removal out tubing tail. E-line on well on dep wing shut swab shut ssv shut master open casing valves open to gauges 6/23/2019 Final Whp's=vac/216/vac ***JOB CONTINUED FROM 22-JUN-2019*** (Sidetrack) HES RELAY UNIT #46 SET 1.69" HES TTBP @ 9827' SLM (no ccl data, zeroed @ middle of element on ttb . DRIFT W/ 48'x 2.16" (max od) DUMMY GUNS, 2.227" GAUGE RING (s/d in nipple @ 9654' md). DRIFT & TAG TTBP @ 9827' SLM W/ 48'x 2.16" (max od) DUMMY GUNS. 6/23/2019 ***JOB INCOMPLETE, SWAP OVER FROM RELAY TO ELINE*** ***WELL S/1 ON ARRIVAL*** (sidetrack) RIG UP HES ELINE UNIT 4863 6/23/2019 ***JOB CONTINUED ON 24-JUN-2019*** ***JOB CONTINUED FROM 23-JUN-2019*** (Sidetrack) TAG TOP OF 1.69" HES TTBP AT 9853' ELM. MAKE 5 RUNS W/ 40'x 2" POSITIVE DISPLACEMENT DUMP BAILER (DUMP - 27.5 GAL OF 17 PPG CLASS "H" CEMENT, EST. TOP OF CEMENT AT - 9835' ELM) 6/24/2019 ***JOB CONTINUED ON 25-JUN-2019*** ***JOB CONTINUED FROM 23-JUN-2016***HES ELINE UNIT #4863 MAKE 3 RUNS W/ 40'x 2" POSITIVE DISPLACEMENT DUMP BAILER (8 total runs) (DUMP - 16.5 GALLONS OF 17 PPG CLASS "H" CEMENT, EST. TOP OF CEMENT - 9825') 6/25/2019 ***JOB COMPLETE ON 25-JUN-2019*** Daily Report of Well Operations PBU L3-22 ***WELL S/I UPON ARRIVAL*** (Sidetrack) HES RELAY UNIT #46 STATE WITNESSED (Matt Herrerra) DRIFT & TAG TO TOP OF CEMENT @ 9792' SLM w/ 1.75" SAMPLE BAILER (recovered 1 cup of cement) SET 1.69" HES TTBP @ 9708' RLMD MID-ELEMENT. 6/28/2019 ***JOB CONTINUED ON 29-JUN-2019*** ***JOB CONTINUED FROM 28-JUN-2019*** (Sidetrack) HES RELAY UNIT #46 MAKE 3 RUNS W/ 40'x 2" POSITIVE DISPLACEMENT DUMP BAILER. DUMP — 16.5 GALLONS OF 17 PPG CLASS "H" CEMENT, EST. TOP OF CEMENT — 9698' ELMD 6/29/2019 ***JOB CONTINUED ON 30-JUN-2019*** ***JOB CONTINUED FROM 29-JN-2019*** (Sidetrack) HES RELAY UNIT #46 MAKE 3 RUNS W/ 40'x 2" POSITIVE DISPLACEMENT DUMP BAILER (6 total runs) DUMP — 16.5 GALLONS OF 17 PPG CLASS "H" CEMENT, EST. TOP OF CEMENT — 9687' ELMD. 6/30/2019 ***JOB CONTINUED ON 01-JUL-2019*** ***JOB CONTINUED FROM 30-JUN-2019*** (sidetrack) HES RELAY UNIT #46 MAKE 2 RUNS W/ 40'x 2" POSITIVE DISPLACEMENT DUMP BAILER (8 total runs) DUMP — 11 GALLONS OF 17 PPG CLASS "H" CEMENT, EST. TOP OF CEMENT — 9680' ELMD 7/1/2019 ***JOB COMPLETE 01-JUL-2019*** T/I/O=SSV/150/0, Temp=Sl. PPPOT-T (PASS), function remaining LDS on TBG hanger. PPPOT-T: Stung into test port (0 psi). Monitored for 10 min, no change in pressure. Function flagged LDS on TBG head, functioned good. Pressured test void to 5000 psi, lost 50 psi in 15 7/1/2019 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. T/1/0= 0/180/0. (LRS Unit 72 - Assist Slickline: AOGCC MITs) MIT-T to 2500 psi PASSED 3rd Attempt at 2639 psi (2750 psi max applied pressure). Pumped 6 bbls of 60* F diesel to achieve test pressure. Bleed back 0.3 bbls to 2200 psi. Pre AOGCC MIT-IA ***PASSED*** Pumped 14.4 bbls DSL down IA to 3751 psi. IA lost 81 psi in 1st 15 mins and 36 psi in 2nd 15 mins for a total loss of 117 psi in 30 min test. Bled IA to psi and got back —14 bbls. AOGCC MIT-T to 3500 psi ***FAIL*** Pumped 3.47 bbls DSL down Tbg to take Tbg pressure to 3767 psi. Tbg lost 224 psi in 1 st 15 mins and lost 174 psi in 2nd 15 mins for a total loss of 398 psi in 30 min test. AOGCC CMIT-TxIA to 3500 psi. ***FAIL*** Pumped 13.78 bbls DSL down IA and Tbg to bring Tbg/IA pressures to 3765/3761 psi. Tbg/IA lost 248/73 psi in 1st 15 mins and 201/29 psi in 2nd 15 mins for a total loss of 449/102 psi in 30 min test. ***FAIL*** Bled down Tbg/IA and got back —15 bbls. 7/2/2019 ***Job Cont to 07-03-2019 WSR*** ***WELL S/I ON ARRIVAL*** (Sidetrack) TAG TOC AT 9,653' SLM W/ 2.00" DUMMY GUN (2.16" swell rings), 1-3/4" S-BLR (Sample of cement). NOTE: SWELL RINGS ON DUMMY GUN COVER DRIFT FOR JET CUTTER (2.125"). RAN READ CASED HOLE MTT FROM 9,650' TO 8,800' SLM (Two passes, Bad data). LRS PERFORMED SUCCESSFUL MIT-T TO 2,639 PSI (Pre AOGCC test). LRS PERFORMED SUCCESSFUL MIT-IA TO 3,670 PSI (Pre AOGCC test). LRS PERFORMED UNSUCCESSFUL AOGCC MIT-T TO 3,500 PSI (Witness Matt Herrera). LRS PERFORMED UNSUCCESSFUL AOGCC CMIT-T x IA TO 3,500 PSI (Witness Matt Herrera). TAG TOC AT 9,650' SLIM W/ 2.00" CENT, 1-3/4" S-BLR (Witnessed by Matt Herrera, sample of cement . 7/2/2019 ***JOB IN PROGRESS, CONTINUED ON 7/3/19 WSR*** Daily Report of Well Operations PBU L3-22 ***Job Cont from 07-02-2019 WSR*** (LRS Unit 72 - Assist Slickline: AOGCC MITs) Continue Rig Down from IA/PAS. SLine in control of well per LRS departure. IA,OA=OTG. **Tags hung on IA and MV** / ***AFE Sign already on well 7/3/2019 FWHP's=65/220/-4 ***CONTINUED FROM 7/2/19 WSR*** (Sidetrack) RAN READ CASED HOLE MTT FROM 9,650' TO 8,850' SLM (Two passes, Good data). 7/3/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** TWO = 0/354/0. Temp = SI. AOGCC MIT -T FAILED. (Pre -Rig). Dry hole tree, well house & scaffold removed. TBG FL @ Near surface. State witness on location is Austin McLeod. Used 1.8 bbl of diesel to achieve test pressure of 2698 psi. TP lost 194 psi in the first 15 minutes, TP lost 91 psi in the second 15 minutes for a total loss of 285 psi in 30 minutes. Bled TP to 0 psi in 10 minutes, 1.5 bbl of fluid returned. Rig down. No change in WHP's during 30 minute monitor. MIT tag hung. Final WHP's = 0/369/0. 7/4/2019 SV, SSV = C. MV=O. IA, OA = OTG. 10:00 ***WELL SHUT IN ON ARRIVAL*** SET BAKER CIBP WITH MID ELEMENT AT 9639' 7/4/2019 ***JOB CONTINUES ON 05-JUL-19*** Assist Eline (SIDETRACK) Arrive on location. SU/PJSM/ SB for E -Line ***Job Cont to 07-05- 7/4/2019 2019 WSR*** ***Job Cont from 07-04-2019 WSR*** CMIT-TxIA to 2710 psi ****PASSED*** Target = 2500 psi Max Applied= 2750 psi Pumped 1.85 bbls DSL down Tbg for MIT -T to 2500 psi ***FAILED*** Pressured up Tbg to 2743 psi. Tbg lost 164 psi in the 1 st 15 mins and 99 psi in the 2nd 15 mins for a total loss of 263 psi in 30 min test. Pumped 10.56 bbls on 2 CMIT-TxIA tests. On last test took Tbg/IA pressure to 2744/2438 psi. Tbg/IA lost 16/17 psi in 1st 15 mins and 11/11 psi in 2nd 15 mins for a total loss of 27/28 psi in 30 min test. PASS Test was performed with jumper open per WSL. Bled Tbg/IA to 500 psi and got back —7 bbls. Pumped 3 bbls of diesel at 2 bpm into the TBG to verify successful cut. IA tracked up with the TBG. Bled back 3 bbls to Final T/I/0= 20/390/0 7/5/2019 1 HES E/L had control of the well and DSO notified of status upon departure. ***CONTINUED FROM 04-JUL-19 WSR*** PERFORM PASSING 2500 PSI CMIT- TAA see Irs wsr for details CUT TUBING @ 9527', CONFIRM COMMUNICATION TEL LOGS CORROLATED TO TUBING TALLEY DATED 11-24-86 7/5/2019 ***JOB COMPLETE DSO NOTIFIED*** T/1/0=50/415/-3 CMIT-TxIA (SIDETRACK) Post Cut CMIT-TxIA to 2682 psi PASS Target = 2500 psi Max Applied = 2750 psi Pumped 9.9 bbls 50/50 meth down Tbg for CMIT-TxIA. Pressured up Tbg/IA to 2450/2754 psi. Tbg/IA lost 54/56 psi in 1st 15 mins and 16/16 psi in 2nd 15 mins for a total loss of 70/72 psi in 30 min test. Start down Tbg, up IA and out to open top tanks for circ out. Pumped 35 bbls 120* fresh water 7/5/2019 ***Job Cont to 07-06-2019 WSR*** TWO = TWC/ VAC/ VAC. Temp = SI. WHPs (pre RIG). No wellhouse, flowline, or scaffoling. Dryhole tree. 7/6/2019 SV, SSV = C. MV = O. IA, OA = OTG. 19:30 ***WELL S/I UPON ARRIVAL*** (sidetrack) DRIFTED W/ 2.35" GAUGE RING TO TRSV AT 2,196' MD SET 2 7/8" CA HOLD OPEN SLEEVE IN TRSV AT 2,196' MD 7/6/2019 ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU L3-22 T/1/0=0/0/25. Pre Parker 272. Set 2 9/16 CIW "H" TWC #204 @ 90". With CIW lubricator #840. LTT (PASSED) PT'd tree cap to 500 psi. (PASSED). ***JOB INCOMPLETE*** See log 7/6/2019 for details. Final WHP's 0/0/25 ***Job Cont from 07-05-2019 WSR**** Pumped 1022 bbls (1057 bbls total) 120* fresh water down Tbg, up IA and out to open top tanks for circ out. Pumped 6 bbls of 50/50 meth down Tbg for TAA pressure test to 2000 psi. Passed. PASSED OA Integrity test. Lost 17 psi during the 5 minute test. Pumped 2.6 bbls of 50/50 Meoh to achieve test pressure. bled back 2.7 bbls to FWHP. Final T/I/0= 0/0/0. All valves on the hardline and choke skid are bled to 0 psi and closed, SV and SSV are closed. MV is open. IA and OA are open to gauges. DSO notified of well status 7/6/2019 jupon departure. T/I/O=TWC/0/0 Removed ASV #9 from Dryhole tree #34. Torqued to specs. PT'd tree through lubricator against TWC... pass. see "Field Charted Tests" Pulled 2 9/16" CIW "H" TWC #204 through tree. Set VR plug in front side OA. Removed front side OA valve and installed on back side. Installed blind on front side OA with bleeder plug. Torqued to specs. PT'd through bleeder plug against VR plug 300/low..3500/high..pass. see "Field Charted Tests" PT'd back side OA valve against VR plug.. pass. Pulled back side VR plug. Installed piggybacks on IA & OA valves, Temp #43 & #12. Torqued to specs. PT'd 300/low/3500/high. see "Field Charted 7/8/2019 Tests" FWP's 0/0/0 see log for details. Common Well Name: L3-22 Event Type: RE-ENTER- ONSHORE (RON) Proiect: Lisburne North America - ALASKA - BP Operation Summary Report AFE No Start Date: 7/7/2019 End Dale: 7/23/2019 X3-019CC-C. (5,907,796.00 j Site: L3 Page 1 Rig Contractor: PARKER DRILLING CO. BPUOL USA00001272 Active datum: ACTUAL KB P272 068.31 usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft) 7!7/2019 17:30 - 19:30 2.00 MOB P -1.02 PRE RIG DOWN OFF OF PWDW3-2 AND STAGE Printed 8/52019 12:08:03PM **Ali depths reported in Drillers Depths" MODULE FOR MOVE TO L3 -22A -COMPLETE PRE MOVE INSPECTIONS - SPLIT MODULES AND STAGE FOR MOVE AT PAD ENTRANCE - REMOVE DUMMY WELL HOUSE AND RE -INSTALL GAUGES ON WELLHEAD 19:30 - 23.00 3.50 MOB P -1.02 PRE MOVE RIG MODULE FROM FLOW 3 ALONG 09:30 - 10'00 0.50 MOB P -1.02 PRE OXBOW ROAD TO INTERSECTION WITH WEST DOCK ROAD. _ 23:00 - 00:00 1.00 MOB P -1.02 PRE CONTINUE MOVING RIG MODULES ALONG WEST DOCK ROAD 7/8/2019 00:00 - 01:30 1.50 MOB P -1.02 PRE MOVE RIG ALONG EAST DOCK ROAD TO .TARMAC CAMP 01:30 - 06:00 4.50 MOB P -1.02 PRE MOVE RIG ALONG EAST DOCK ROAD FROM TARMAC CAMP TO L3 ACCESS ROAD AND ON _ TO L3. 12:00 - 17:30 5.50 WHSUR P -1.02 PRE RIG ON LOCATION AT 06:00 HRS 06:00 - 09:30 3.50 MOB P - -1.02 PRE 'SET DUMMY WELL HOUSE AND SPOT DRILL Printed 8/52019 12:08:03PM **Ali depths reported in Drillers Depths" MODULE OVER 1.3-22 MATE UTILITY MODULE AND MUD MODULE TO DRILL MODULE INSTALL ROOF COVERS, TRANSITIONSAND FLOOR PLATES MAKE UP ELECTRICAL CONNECTIONS IN INNER -CONNECTS 09:30 - 10'00 0.50 MOB P -1.02 PRE RAISE MAST OFF DERRICK WITH 525 KLBS OFF THE RACK 10:00 - 11:00 1.00 MOB P -1.02 PRE SKID RIG FLOOR TO DRILL POSITION SKID HAUNCH INTO POSITION RAISE PIPE CAT INSTALL FLOW LINE 11:00 - 1200 1.00 MOB P -1.02 PRE SPOT CUTTINGS BOX MAKE UP LINES IN INNER -CONNECTS _ ACCEPT RIG AT 12:00 HRS. 12:00 - 17:30 5.50 WHSUR P -1.02 PRE NIPPLE DOWN TREE PER CAMERON REP - BLEED OFF CONTROL LINE AND REMOVE CAP -BEGIN MONITORING WELL THROUGH IA -SUCK OUT TREE - NIPPLE DOWN TREE - FUNCTION AND MEASURE LOCK DOWN SCREWS - VERIFY HANGER THREADS 2-7/8" EUE AND INSTALL HP BPV - 9-1/4 TURNS FOR XO, 6 TURNS FOR HP LUG, 7-1/4 TURNS (1" GAP) FOR DART SIMOPS: - RIG UP HARDLINE FROM IA -COMPLETE RIGGING UP RIG FLOOR EQUIPMENT - INSTALL OFF-LINE MOUSEHOLES - CALIBRATE PITS AND GAS WATCH Printed 8/52019 12:08:03PM **Ali depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 1-3-22 -1.02 PRE AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date'. 7/7/2019 Eno Date7/23/2019 X3-019CC-C: (5,907,796.00 ) Project: Lisburne Site: L3 PULLTEST DARTAND HP BPV FROM WELL Rig Name/No.: PARKER 272 Spud DateTme: 11/4/1986 12:00:OOAM Rig Release: 7/27/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001272 Active datum: ACTUAL KB P272 @68 31 usft (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 BOPSUR P -1.02 PRE NIPPLE UP DSA, HIGH PRESSURE RISERS 20:30 - 22:30 2.00 BOPSUR P 2230 - 2330 23:30 - 00:00 7/9/2019 00:00 - 05:00 1.00 BOPSUR P AND BOP STACK - NIPPLE UP STACK AND TORQUE ALL BOLTS -CONNECT FLOW LINE, DRAINS AND FILL UP LINE -OBTAIN IRKS MEASUREMENT - INSTALL MOUSEHOLE _ -1.02 PRE CHANGE UPPER AND LOWER PIPE RAMS TO 2-7/8" x 5" VBR - OPEN DOORS AND INSPECT CAVITIES - INSTALL 2-7/8" x 5" VBR IN UPPER AND LOWER RAMS SIMOPS: _ - CHANGE SAVER SUB FROM NC50 TO HT38 -1.02 PRE RIG UP TO TEST ROPE - PURGE AIR FROM STACKAND LINES MAKE UP TEST JOINTS AND TEST MANIFOLDS 0.50 BOPSUR P -1.02 PRE TEST BORE TEST FIRE AND GAS ALARMS 5.00 BOPSUR P -1.02 PRE TEST BOPE PER AOGCC AND BP TEST RAMS AND ANNULAR WITH 2-7/8" AND 4" TEST JOINTS - TEST UPPER AND LOWER 2-7/8" x 5" VBR WITH 250/5000 PSI FOR 5 CHARTED MIN - TEST ANNULAR 70 250/3500 PSI - TEST BLIND SHEARS AND CHOKE MANIFOLD VALVES 250/5000 PSI - TEST FIRE AND GAS ALARMS - PERFORM ACCUMULATOR DRAW -DOWN TESTAND FUNCTION HIGH/LOW BYPASS -PERFORM BLACKOUT TEST TEST WITNESS WAIVED BYAOGCC REP BOB NOBLE SIMOPS: - LOAD 4-1/2" VAM TOP TUBING IN PIPE SHED AND PREP FOR INSPECTION 05:00 - 05:30 0.50 BOPSUR P -1.02 PRE RIG DOWN AND BLOW DOWN BOP TEST _ _EQUIPMENT 0530 - 0700 1.50 WHSUR P -1.02 PRE PULLTEST DARTAND HP BPV FROM WELL PER CAMERON WELLHEAD REP - MAKE UP T -BAR AND ATTEMPT TO PULL TEST DART: UNABLE TO GET ON DART WITH BEND IN T -BAR - PUMP OUT STACK - ENGAGE AND PULLTEST DART WITH T -BAR - ENGAGE AND PULL HP BPV FROM WELLHEAD -RIG DOWN T -BAR _ 07.00 - 07:30 0.50 WHSUR P -1.02 DECOMP RIG EVACUATION/ 12S DRILLAND AAR WITH RIG CREW WBS'DECOMP Printed 8/5/2019 12:08:03PM "AII depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 3 Common Well Name. 1-3-22 23:30 - 00:00 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 7/7/2019 End Date: 7/23/2019 X3-019CC-C (5,907,796 00 ) Project. Lisburne Site: L3 LINE FROM 9575' MD (9564' + 10.57' RKB Rig Name/No.: PARKER 272 Spud Date/Time: 11!4/1986 12:00:OOAM Rig Release: 7/27/2019 Rig Contractor: PARKER DRILLING CO. - RECOVERED: 296 FULL JOINTS OF 2-7/8" BPUOI: USA00001272 Active datum: ACTUAL KB P272 Q68.31 usft (above Mean Sea Level) MANDREL, 2 FLOW COUPLINGS, 75 SS Date From - To Him Task Code NPT Total Depth Phase Description of Operations SIMOPS: (usft) -1.02 DECOMP 07:30 - 09:00 1.50 WHSUR P -1.02 DECOMP _ RIG UPAND CIRCULATE OUT TOP OF WELL - PUMP 20 BBLS DOWN THE TUBING TAKING RETURNS FROM THE IA TO THE OPEN TOP TANK: 4 BPM, 1190 PSI - PUMP 40 BBLS DOWN THE IA TAKING RETURNS UP THE TUBING TO THE OPEN TOP TANK: 4 BPM - 8.3 PPG IN/OUT ---MONITOR WELL FOR 10 MIN: STATIC 09:00 - 11:00 2.00 WHSUR P -1.02 DECOMP PULL TUBING HANGER TO FLOOR AND LAY DOWN - MAKEUP LANDING JOINT AND XO -ENGAGE HANGER WITH B TURNS - BACK OUT LOCK DOWN SCREWS PULL HANGER TO RIG FLOOR 80 KLBS TO COME OFF SEAT - PU 86 KLBS, SO 86 KLBS RIG DOWN LANDING JOINT - RIG UP TO PULL AND LAY DOWN 2-7/8" TUBING WITH CONTROL LINE 11:00 - 21:00 10.00 CASING P 21:00 - 21:30 0.50 CASING P 21:30 - 23:30 2.00 BOPSUR P Printed 8/5/2019 12,08:03PM **All depths reported in Drillers Depths" 23:30 - 00:00 0.50 WHSUR P 7/10/2019 00:00 - 01:00 1.00 WHSUR P Printed 8/5/2019 12,08:03PM **All depths reported in Drillers Depths" SIMOPS: -RIG UP OA TO TIGER TANKAND BEGIN MONITORING FOR PACK -OFF CHANGE OUT -1.02 DECOMP PULLAND LAY DOWN 2-7/8" TUBING WITH CONTROL LINE AND CHEMICAL INJECTION LINE FROM 9575' MD (9564' + 10.57' RKB DIFFERENCE) - PRE -RIG JET CUT WAS A PARTIAL CUT - RECOVERED: 296 FULL JOINTS OF 2-7/8" TUBING, 5 GLM'S, 1 CHEMICAL INJECTION MANDREL, 2 FLOW COUPLINGS, 75 SS BANDS -1.02 DECOMP RIG DOWN 2-7/8" HANDLING EQUIPMENT SIMOPS: - DRAIN STACKAND LAY DOWN MOUSEHOLE -1.02 DECOMP NIPPLE DOWN BOP STACKAND HIGH PRESSURE RISERS FOR TUBING SPOOLAND PACK -OFF CHANGE OUT - NIPPLE DOWN BOP STACKAND SECURE ON STUMP - PULL HIGH PRESSURE RISER AND DSA SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT -1.02 DECOMP NIPPLE DOWN 13-3/8"x 11" TUBING SPOOL - FUNCTION LOCK DOWN SCREWS AND _ CONFIRM NO CASING GROWTH -1.02 DECOMP CONTINUE TO NIPPLE DOWN 13-3/8" x it" TUBING SPOOL PER CAMERON WELLHEAD REP - CLEAN AND INSECT 9-5/8" CASING PACK -OFF - BACK OUT LOCK DOWN SCREWS SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT Printed 8/5/2019 12,08:03PM **All depths reported in Drillers Depths" Common Well Name. L3-22 Event Type. RE-ENTER- ONSHORE (RON) I'miect: Lisburne North America - ALASKA - BP Operation Summary Report Start Date. 7/7/2019 End Date. 7/23/2019 Site: L3 Spud DateRime: 11/4/1986 12:00 OOAM AFE No K3-019CC-C: (5,907,796.00 ) Page Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00001272 Active datum: ACTUAL KB P272 @88.31 usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr)_. _ (usft) 01:00 - 02:30 1.50 WHSUR N -1.02 DECOMP WAIT FOR CAMERON WELLHEAD REP TO LOCATE AND GET TOOLS TO PULL 9-5/8" CASING PACK -OFF -PACK-OFF IN WELL IS THREADED AND DOES NOT HAVE THE "J" SLOTS FOR RUNNING/RETRIEVING - CAMERON HAND WENT TO TOOL SERVICE iWAREHOUSE TO RETRIEVE THREADED PACK -OFF PULLING TOOL SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING .OFF-LINE STAND BUILDING EQUIPMENT - LOAD PIPE SHED WITH REMAINDER OF 4Al2" TUBING _-NORM 2-7/8" TUBING AND JEWELRY 02:30 - 03:00 0.50 WHSUR P -1.02 DECOMP PULL 9-5/8" CASING PACK -OFF --MAKEUP THREADED PULLING TOOL -PULL 9-5/8" CASING PACK -OFF WITH (TUGGER !-CLEAN AND INSPECT WELLHEAD SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING 'OFF-LINE STAND BUILDING EQUIPMENT 03:00 - 06:00 3.00 WHSUR P -1.02 DECOMP INSTALL NEW 9-5/8" CASING PACK -OFF AND NIPPLE UP NEW 13-3/8" TUBING SPOOL PER CAMERON WELLHEAD REP - INSTALL SECONDARY ANNULUS VALVES SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT 06:00 - 07:00 1.00 WHSUR P _ -1.02 DECOMP PRESSURE TEST HANGER SEALS TO 3500 PSI FOR 15 CHARTED MIN - GOOD TEST: MET TEST CRITERIA PER BP PRACTICE 100218 TABLE 2 TYPE 3A - TEST APPROVED BY BP WSUP -SEE ATTACHED 07:00 - 09:00 2.00 BOPSUR P -1.02 DECOMP NIPPLE UP HIGH PRESSURE RISER AND BOP STACK - TORQUE ALL BOLTS TO SPEC - INSTALL TURNBUCKLES AND FILL UP / CIRCULATING LINES -INSTALL FLOW BOXAND LOW PRESSURE RISER -AIR UPALLAIR BOOTS -OBTAIN NEW RKB MEASUREMENT SIMOPS: - BUILD STANDS OF 4" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT 09:00 - 10:00 1.00 BOPSUR P -1.02 OECOMP INSTALL TEST PLUG AND PRESSURE TEST BREAKS TO 250/3500 PSI FOR 5 MIN - INSTALL TEST PLUG AND FILL STACK - PURGE LINES AND TEST BREAKS: GOOD TEST 10:00 - 11:00 1.00 WHSUR P -1.02 DECOMP PULL TEST PLUG AND INSTALL 9, 125" IS WEAR RING - LAY DOWN RUNNING TOOL Printed 8/5/2019 12:08:03PM **All depths reported in Drillers Depths" North America - ALASKA- BP Operation Summary Report Page 5 Common Well Name: 1-3-22 WHIPSTOCK PER SLB FISHING REPAND AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 717/2019 End Date. 7/232019 X3-019CC-C: (5,907,796.00) Project: Lisburne Site: L3 FLOOR Rig Name/No.: PARKER 272 Spud Date/Time: 11/4/1986 12:00 OOAM Rig Release: 727/2019 Rig Contractor: PARKER DRILLING CO. _ AND SCRIBE BPUOI: USA00001272 Active datum: ACTUAL KB P272 @68.31 usft (above Mean Sea Level) - SHALLOW HOLE TEST MWD: GOOD Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) .. _(us8) - MAKE UP AND RUN IN THE HOLE WITH THE 11:00 - 17:00 6.00 STWHIP P 9,572.98 WEXIT MAKE UP MILLING ASSEMBLYAND 9-5/8" Printed 8/5/2019 12:08:03PM ••All depths reported in Drillers Depths" WHIPSTOCK PER SLB FISHING REPAND BAKER MWD - MOBILIZE BHA COMPONENTS TO RIG FLOOR - MAKE UP TRI -MILL, FLOATAND MWD TOOS AND SCRIBE - SHALLOW HOLE TEST MWD: GOOD - PICK UP AND MAKE UP WHIPSTOCK TO TRI -MILL - MAKE UP AND RUN IN THE HOLE WITH THE REMAINDER OF THE MILLING ASSEMBLY: FILTER SUB, (9) 6-1/2" DRILL COLLARS AND (21) JTS OF 5" HWDP WBS: WEXIT 17:00 - 2230 5.50 STWHIP P 9,572.98 _ WEXIT RUN IN THE HOLE WITH 9-5/8" WHIPSTOCK AND WINDOW MILLING ASSEMBLY FROM 1046' MD TO 4828' MD, PICKING UP 4" DRILL PIPE FROM THE PIPE SHED. '- RUN IN THE HOLE AT 45 FT/MIN PER SLB FISHING REP - PU 140 KLBS, SO 126 KLBS AT 4828' MD -MUD WEIGHT IN/OUT =8.3 PPG - MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT 22'.30 - 0000 1.50 STWHIP P 9,57298 WEXIT CONTINUE TO RUN IN THE HOLE WITH 9-5/6" WHIPSTOCK AND WINDOW MILLING ASSEMBLY FROM 4828' MD TO 6255' MD, ON STANDS 4" DRILL PIPE FROM THE DERRICK. - RUN IN THE HOLE AT 45 FT/MIN PER SLB FISHING REP - FILL PIPE EVERY 2000' - PU 157 KLBS, SO 133 KLBS AT 6030' MD - MUD WEIGHT IN/OUT = 8.3 PPG - MONITOR WELL WITH TRIP TANK AND HOLE _ FILL: GOOD DISPLACEMENT 7/11/2019 00:00 - 02:00 2.00 STWHIP P 9,572.98 WEXIT CONTINUE TO RUN IN THE HOLE WITH 9-5/8" WHIPSTOCKAND WINDOW MILLING ASSEMBLY FROM 6255' MD TO 9477' MD, ON STANDS 4" DRILL PIPE FROM THE DERRICK. - RUN IN THE HOLEAT 45 FT/MIN PER SLB FISHING REP - FILL PIPE EVERY 2800' - PU 225 KLBS, SO 165 KLBS AT 9477' MD - MUD WEIGHT IN/OUT = 8.3 PPG -MONITOR WELL WITH TRIP TANK AND HOLE FILL: GOOD DISPLACEMENT Printed 8/5/2019 12:08:03PM ••All depths reported in Drillers Depths" Printed 8/5/2019 12:08:03PM "All depths reported 10 Drillers Depths' North America - ALASKA - BP Page 6 pf1a. Operation Summary Report Common Well Name: 1-3-22 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 7/7/2019 End Date: 7/23/2019 X3-019CC-C:(5,907,796.00) Project: Lisburne Site: L3 --- Rig Name/No.: PARKER 272 Spud DateRme: 11/4/1986 12:00:OOAM Rig Release: 7/27/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001272 _ _ Active datum: ACTUAL KB P272 @68.31 usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 02:00 - 03:30 1.50 STWHIP P 9,572.98 WEXIT ORIENT AND SET SLB WHIPSTOCK - MAKE UP TOP DRIVE AND BREAK CIRCULATION: 120 GPM, 2280 PSI -ORIENT WHIPSTOCK WITH MWD: 10° ROHS AS PER BAKER MWD/DD - RUN IN THE HOLE AND TAG AT 9559' MD WITH 3-4 KLBS - TAGGED 15' HIGHER THAN EXPECTED - PICKED UP TO 9553' MD AND SLACKED OFF AND TOOK 4 KLBS. - PICKED UP TO 9551' SLACKED OFF, BEGAN TAKING WEIGHT IMMEDIATELY. STOPPED AND DISCUSSED WITH ODE, WSUP AND_ETL. 03:30 - 05:00 1.50 STWHIP P 9,55600 WEXIT DISPLACE WELL FROM 8.3 PPG FRESHWATER TO 9.9 PPG LSND MILLING FLUID WHILE DISCUSSING WHIPSTOCK SETTING DEPTH WITH ANCHORAGE TEAM. 600 GPM, ICP 2895 PSI 05:00 - 05:30 0.50 STWHIP P �., 9,556.00 WEXIT SET WHIPSTOCK AT 9555' MID (BOTTOM OF WHIPSTOCK ANCHOR) PER SLB FISHING REP - SET DOWN AND OBSERVE SHEAR AT 45 KLBS 05'.30 - 20:00 14.50 STWHIP P 9,556.00 WEXIT MILL WINDOW IN 9-5/8" CASINGAND -16'OF NEW FORMATION FROM 9526' MD TO 9556' �l L3 2Lf MD, 8509- TVD -400-265 GPM, 1800-1180 PSI, 130 RPM, 12-16 KFT-LBS TORQUE ON BOTTOM, 8 KFT-LBS TORQUE OFF BOTTOM, 5-17 KLBS WOB - PU 203 KLBS, SO 165 KLBS, ROT 182 KLBS AT 9526' MD - WORK MILLS THROUGH WINDOW: 80 RPM - 2 KFT-LBS INCREASE IN TORQUE EACH TIME WITH PUMPS ON - WORK MILLS THROUGH WINDOW WITH NO PUMPS / NO ROTATION: -3-5 K FT -LBS INCREASE IN DRAG AS UPPER MILL WENT THROUGH WINDOW TOP OF WINDOW: 9526' MD, 8481' TVD BOTTOM OF WINDOW: 9540' MD, 8495' TVD SIMOPS: - LOAD PIPE SHED WITH 7" LINER AND INSPECT. - LOAD PIPE SHED WITH REMAINDER OF 4-1/2" TUBING AND LINER AND INSPECT - RIG UP CONTINGENCY TANKS AND LINE FROM TANKS TO PUMP AND TO RIG. 20:00 - 21:00 1.00 STWHIP P 9,556.00 WEXIT CIRCULATE A HIGH VIS SWEEP AND CLEAN UP HOLE - 650 GPM, 3700 PSI - RECIPROCATE PIPE 15' AT SURFACE, NO ROTATION Printed 8/5/2019 12:08:03PM "All depths reported 10 Drillers Depths' I TREE= CIw WELLHEAD = MCEVOY ACTUATOR= BAKER !B_ ELEV = 60 BF. B -EV = 23.44' KOP= 3100' Max Angle = 39" @ 7200' Oatum ND= 10028' Datum TVD = 89W SS. 133/8' CSG, 68#, , -[M- K-55 BTC, D = 12.415' 20' CONDUCTOR 91.5#, 11-40, D = 19.124" 119• Minimum ID = 1.12" @ 2196' 2-7/8' TRDP HOLD OPEN SLEEVE 13-3/8' CSG, 72#. L-80. D = 12.347" -4 ARi--�_ 19-5/B" CSG, 47#, L-80 NSCC XO TO L-80 BTC I JET CUT TBG (07N5/19) 9627' 7' LNR 2-7/8- TBG -PC, 6.5#, L-80 9JE BIRD, .0058 bpf, D = 2.441' L3-22 SAFETY NOTES 19-5/8" WHIPSTOCK MV11/19) I X 7- TACK, D 2-7/8' CAMCO D NP, D = 225' FOR POSSIBLE PIECES OF TTBP PLUG N TBG (PIECES OF RUBBER SUPS AND BOWSPRNC) 1.69" HES TTBP (0828/19) I—L 9708' I— Toc(osrz5119) 9825' 9847 7 MARKH2JONr(2o') 1.69' HES TTBP (0623/19) 9663' 98&1' FISH: 2.22"BAIT SUB, WIRE SPEAR(47'OAL), MOST TTBP PLUG PIECES PUSHED TO BOT, 9-5/8' CSG, 47#, L-80 BTC, D = 8.681' 9869' PERFORATION SU MINRY Rff LOG: LDT/CT•L ON 11/20/06 ANGLEAT TOP FES: 18" @ 9718' Note: Refer to Production DB for historical pert data S17E SPF INTERVAL OpNSgz %W SOZ 2-1/8" O 9718-9742 O 09/13/18 2-1/8" 5 9942 - 10002 C 03r23/87 BTN/JMD 2' 6 10043 - 10063 C 0525/15 2-1/8" `S 10043-10126 C 03123/87 7 6 10092-10127 C 05/25/15 2-1/8" 'S 10141-10219 C 03/23/87 7 6 10158- 10173 C 05/2915 7 6 10196-10221 C 0925x15 - SeiectNe Shofs PBTD 10436' 7' LNR, 29#, L-80 BTC, .0371 bpf, D = 6.184" 10 BW— Cy_1:Ir7 FISH - 2-1/2' JU DOG SPR14G (05111/08) 1 DATE REV BYI COMMENTS DATE REV BY COMMENTS 7124166 I-ITIIILCOYPLE710N 07/18M9 EPD/JMD SETCIBPBJETCUTTBG 09/28M8 DDUMD ADDED BF ELEV 8 COND INFO 07118/19 EPD/JMD SET HOLD OPEN SLEEVE 12/18118 2V/JMD GLV C/O 12M7/18 0611SMS LG/JM GLV C/O 06102/19) 0627/19 BTN/JMD SETPLUGBCMT-2 FISH 07/18/19 MS/JMD SETPLUGBCMT LISBURNE UNIT WELL: 1-322 PERMIT No: 1861750 API No: 50-029-21663-00 SP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UN LIS L3-22 Insp Num: mitSAM190705173810 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 15, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. L3-22 PRUDHOE BAY UN LIS 1-3-22 API Well Number 50-029-21663-00-00 Permit Number: 186-175-0 Sre: Inspector Reviewed By: P.I. Suprv'-I Comm Inspector Name: Austin McLeod Inspection Date: 7/4/2019 Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min Well L3-22 Type In,j �' TVD Tubing 0 '('98 )s11 zaia 1 PTD 1861750 T) pe est SPT Test psi IA =- .78 379 38, BBL Pumped: BBL Returned: i.; OA 0 o 0 n Interval OTHER - P/p - P Notes: Well is arn oducer. This Ml7'=1 was part of the plug for redrill ( Sundry 186-175). Plug verification report was sent to Jim Regg but he requested I submit this report with the remarks from the other report attached. Remarks as follows: On 7/3/191 received a call from BPYA rep Josh Prowant requesting that we add another well to the already scheduled Mechanical Integrity Tests (MIT's) to be performed on 7/4/19. Not knowing the wells recent history, I arrived on site on 7/4/19 expecting to perform an MIT on a online injection well. I was then informed that the well could not eet a passing AOGCC witnessed MIT -T to n,n f, a redrill after n,ao.. anP..•,.m Annrr ;,.,,. xn.,.. ue....., �.o.,..,...1. •••••�_+�•• •wuFM muu.g rvu i - i a, agmna a IJ cancer pug roar was dump Dollen. JOsn toll me a non -witnessed passing test was completed ton ire attempt) after me many witnessed fading tests. I was shown an email from AOGCC engineer Mel Rixse, wanting to confirm the integrity of the plug to 2500 psi. It was at the operators discretion to attempt another test or move on to the other scheduled MIT's for the day. Monday, July 15, 2019 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Section: 22 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Eric Dickerman Casing/Tubing Data (depths are MD) Conductor: 20" O.D. Shoe@ Surface: 13 3/8" O.D. Shoe@ Intermediate: 9 5/8" O.D. Shoe@ Production: Cut@ O.D. Shoe@ Liner: 7" O.D. Shoe@ Tubing: 2 7/8" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 2, 2019 SUBJECT: Well Bore Plug & Abandonment PBU L3-22 BPXA PTD 1861750; Sundry 319-207 11N Range: 15E Meridian: Umiat NA Total Depth: 10480 ft MD Lease No.: ADL 028322 ' Suspend: P&A: X 119 Feet 4110 - Feet 9870 Feet Csg Feet 10480 Feet 9668 Feet Tvpe Pluq Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Tvpe Pluq Founded on De th Btm De th To MW Above Verified Fullbore - Bridge plug 9708 ft MD. 9650 ft MD Wireline tag OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 3767 - 3523 - 3349 - IA 312 314 316 F OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 3765 3517 3316 IA 3761 3688 3659 F OA 0 0 0 Remarks: i PBU L3-22 is slated to be redrilled (L3 -22A; PTD 2190510). 2nd plug verification inspection (see report 6/28/19): this one for isolating the Ivishak reservoir perforations. I witnessed Haliburton Slickline unit rigged up on well to tag top of isolation cement plug inside the 7 -inch liner on 7/2/2019. Multiple attempts at MIT -T and CMIT TAA - both failed due to pressure loss from the ✓ tubing. Attachments: none rev. 11-28-18 2019-0702_Plug_Verification_PBU L3-22_mh MEMORANDUM TO: Jim Regg !l` P.I. Supervisor �� FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 28, 2019 SUBJECT: Well Bore Plug & Abandonment PBU L3-22 BPXA PTD 1861750; Sundry 319-207 Section: 22 Depth Btm Township: 11N Range: 15E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 10480 ft MD 'Lease No.: ADL 028322 " Operator Rep: Nathan Williams Suspend: P&A: X - Casing/Tubing Data (depths are MD): Casino Removal: Conductor: 20" O.D. Shoe@ 119 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 4110 Feet Csg Cut@ Feet Intermediate: 9 5/8" - O.D. Shoe@ 9870 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7 O.D. Shoe@ 10480 Feet Csg Cut@ Feet Tubing: 2 7/8" O.D. Tail@ 9668 Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore - Bridge plug 9864 ft MD 9815 ft MD Wireline tag Test Data: Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: PBU L3-22 is slated to be redrilled (1-3-22A; PTD 2190510). Well Operations isolating Lisburne reservoir from Ivishak reservoir. I witnessed Haliburton Slickline unit rigged up on well to tag top of isolation cement plug inside the 7 -inch liner on 6/28/2019. � Attachments: none rev. 11-28-18 2019-0628_Plug_Verification_PBU L3-22_mh Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 1, 2019 2:59 PM To: Thompson, Jacob Subject: RE: L3-22 (RTS4-975) Sundry Amendment Sundry# 318-045 �� Ir Jacob, Thanks for the updated plan for isolating Ivishak associated with plug for redrill. NOTE: Also make sure you include the PTD # in all email correspondence. i Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 1 or (Guv.schwartz@alaska.cLov). From: Thompson, Jacob <Jacob.Thompson@BP.com> Sent: Monday, April 1, 2019 12:54 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Allen, Kenneth W <Kenneth.Allen@bp.com>; Allely, Josh <Josh.Allely@bp.com> Subject: RE: L3 -22A Sundry Amendment Sundry# 318-045 Mel / Guy, As per your below request we will plan on setting an IBP above the existing cement plug and dump bail 25' of cement on top of it to isolate the Lisburne from the Ivishak. I've attached a schematic to illustrate the approved plan. I've also amended the Pre -rig Operational summary below to reflect the plan. Pre Rig Summary 1. Run flapper checker. Dummy gas lift valves. MIT -IA to verify valves set. Pull chemical injection valve, flush chemical line, set dummy, test line. Pressure test control lines. 2. A/SL.Load IA. MIT -IA. Load TBG, obtain step rate test. 3. RIH with TTBT plug and set at 9,864' MD 4. Dump Bail 25' of cement on top of TTBT plug TOC --9,839' MD. 5. D&T TOC. RIH with TTBT plug and set at 9,707 MD 6. Dump bail 25' of cement on top of the TTBT plug. TOC 9,682' MD. 7. D&T TOC. Drift for jet cut. 8. MIT -T 3,500 psi. CMIT-TxIA 3,500 psi. Negative pressure test 9. Jet cut tubing at 9,520' MD. 10. Circ out. CMIT-TxIA 3,500 psi. MIT -OA 1,100 psi. 11. Set TRSSSV hold open sleeve. 12. Cement control/chemical lines that fail PT. 13. PPPOT-T. PPPOT-IC. Function LDS. 14. Set BPV. Install Dry Hole Tree. Configure annular valves. Let me know if you have any questions. Jacob From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.Bov> Sent: Thursday, March 28, 2019 2:42 PM To: Thompson, Jacob <Jacob.Thompson@BP.com> Subject: RE: L3 -22A Sundry Amendment Sundry# 318-045 Jacob, I have talked to the commissioners. An IBP with 25' of bailed cement will be considered an adequate barrier between the Lisburne and Ivishak pools. No additional variance explanation will be required. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melon Rixseealaska.Rov). From: Rixse, Melvin G (DOA) Sent: Monday, March 25, 2019 4:33 PM To:'Thompson, Jacob' <Jacob Thompson@BP.com> Subject: RE: L3 -22A Sundry Amendment Sundry# 318-045 Jacob, AOGCC is now aware that the 10' cement plug is, at this time, isolating the Ivishak from the Lisburne. I see a note on the AOGCC internal paperwork for Sundry (317-062) that the sand back was "a temporary recompletion to evaluate the Ivishak in this area before returning to Lisburne production". Furthermore, AOGCC recognizes that a "sand back" is a common method utilized by the industry for temporary isolation or protection. For permanent abandonment/isolation AOGCC will require BPXA to isolate the Lisburne from the Ivishak pools per AOGCC 20AAC 25.112(c) or submit a written variance request that provides at least equally effective means of satisfying AOGCC 20AAC 25.112(c). As stated previously a 10' cement plug followed by a 15' cement plug does not meet regulation. BPXA is welcome to provide a written variance request for presentation to the AOGCC Commissioners for their review and final judgement. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin, Rixse@alaska.Rov). From: Thompson, Jacob <Jacob.Thompson@BP.com> Sent: Monday, March 25, 2019 12:49 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Subject: L3 -22A Sundry Amendment Sundry# 318-045 Mel, I would like to clarity the direction given below as well as the intent of the AOGCC regulation 20 AAC 25.112(c) (1)(E). First, I would like to provide an explanation as to why a pressure test cannot be performed on the cement plug above the perforations at 9,942' MD. As per the approved Sundry Number #317-602 sand was placed across the Lisburne perforations, a 10' cement plug added via dump bailing (TOC 9,874'), and perforations added in the Ivishak. The cement plug was not pressure tested prior to perforating the Ivishak above it. This prevents us from pressure testing the existing or future cement plugs or retainers that are below the Ivishak perforations at 9,718'— 9,742' MD. Although a positive pressure test was not performed on the 10' dump bailed cement plug, the change in the well's production profile shows substantial evidence of the Lisburne being isolated, and the Ivishak producing. Prior to the sand and cement plug being placed the well was producing —1,391 bbls of total fluid per day, —50 bbls of oil per day, at 1,340 bbls of water per day from the Lisburne. After the plug was placed and Ivishak perforations added oil production increased and water production reduced giving a production profile with 637 —160 bbls of total fluids per day, 337 — 61 bbls of oil per day, and 360 —1 bbls of water per day. The drastic change in the production profile cannot replace the assurance a positive pressure test would have provided, but does offer evidence that the Lisburne has been isolated from the Ivishak. 20 AAC 25.112(c) (1)(E) states "(E) if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer;." It is my understanding that the intent of the mechanical bridge plug is to act as a hard bottom to aid in placing a permanent cement plug on, in which, the cement will act as the permanent barrier preventing hydrocarbon flow and pressure migration. It is BP's request that we utilize the existing 10' cement plug, as a hard bottom to place additional cement on top of. The plan outlined in the previous email recommended placing an additional 15' of cement on top of the already established 10' cement plug to give a total of 25' of cement to isolate the Lisburne perforations from the Ivishak perforations. I am happy to discuss my interpretation of the regulation, or addition of more cement, or the benefits of adding a mechanical bridge plug over the phone if you would like to give me a call. Below is the recommended complete pre -rig prep work description for approval. Steps that have changed from the approved sundry are in red font. Pre Rig Summary 1. Run flapper checker. Dummy gas lift valves. MIT -IA to verify valves set. Pull chemical injection valve, flush chemical line, set dummy, test line. Pressure test control lines. 2. A/SL.Load IA. MIT -IA. Load TBG, obtain step rate test. 3. Dump Bail 15' additional cement on top of the existing plug at 9,874' MD. 4. D&T TOC. RIH with TTBT plug and set at 9,707 MD 5. Dump bail 25' of cement on top of the TTBT plug. TOC —9,682' MD. 6. D&T TOC. Drift for jet cut. 7. MIT -T 3,500 psi. CMIT-TxIA 3,500 psi. Negative pressure test 8. Jet cut tubing at 9,520' MD. 9. Circ out. CMIT-TxIA 3,500 psi. MIT -OA 1,100 psi. 10. Set TRSSSV hold open sleeve. 11. Cement control/chemical lines that fail PT. 12. PPPOT-T. PPPOT-IC. Function LDS. 13. Set BPV. Install Dry Hole Tree. Configure annular valves. Thanks, Jacob Thompson BP Alaska Rotary Drilling Engineer Cell. (907) 854-4377 Office: (907) 564-5579 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Friday, March 22, 2019 9:06 AM To: Thompson, Jacob <Jacob.Thompson@BP.com> Subject: RE: L3 -22A Sundry Amendment Sundry# 318-045 Jacob, AOGCC will approve a mechanical bridge plug be set and a minimum of 25' cement be dump bailed above your top of perfs at 9942' MD per AOGCC regulation 20 AAC 25.112(c) (1)(E). AOGCC will require BPXA to provide a written justification why AOGCC should approve a variance to 20 AAC 25.112(g)(2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing AOGCC will approve a mechanical bridge plug be set and a minimum of 25' cement be dump bailed above your top of perfs at 9718' MD per AOGCC regulation 20 AAC 25.112(c) (1)(E). AOGCC will require a 24 hour notification as per 20 AAC 25.112(g)(2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location, however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing Please resubmit a complete pre -rig prep work description for approval. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Me _Ivw Rixse@alaska gov). From: Thompson, Jacob <Jacob.Thomoson@BP.com> Sent: Thursday, March 21, 2019 2:26 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: L3 -22A Sundry Amendment Sundry# 318-045 Hello Mel, It has been a while since I ran into you last. I think FFFFF. I have taken over the planning for the L3 -22A well. As I understand it you had some questions on the changes to the abandonment plan so I created a new schematic to illustrate what we are trying to achieve. Below is a brief outline of the operational steps for the modified pre -rig work. 1. Dump bail a minimum of 15' of cement on top of the existing cement plug at 9874'. 2. Wait for cement to set. 3. RIH tag TOC #1. 4. Run TTBT plug at —9,707' 5. Dump bail 25' of cement on top of the TTBT plug. 6. Drift and tag TOC #2. 7. Continue with operations per the approved sundry at step 5 on pg. 2 (see below) Pre -Rig Prep Work: Step Service Line Description of Work Run flapper checker Dummy gas lift valves- MIT -IA to verify valves set. Pull chemica iniection ya-_ Ivey flush chemical line, set dummy, test line. Pressure test control lines. A/SL.Load IA, M1 -IA. Load TBG, obtain step rate test I S 2 F 3 F Cement plug. Target TOC 9680'md. 4 5 S F D8T TOC. Drift for jet cut. C MIT -T 3,500 psi. CMIT-TxIA 3,500 psi. r 6 E Jet cut tubing at 9,520' MD. 7 F Circ out. CMIT-TxIA 3,500 psi. MIT -OA 1,100 psi. 8 S Set TRSSSV hold open sleeve. 9 O Cement controllchemical linea that fail PT. 10 At PPPOT-T. AP -POT -IC -Function LDS. 11 V Set BPV. install DryHole Tree. Configure annular valves I'll give you a call to discuss. Thanks, Jacob Thompson BP Alaska Rotary Drilling Engineer Cell: (907) 854-4377 Office: (907) 564-5579 • VOF T� • � THE STATE Alaska Oil and Gas ice='� Conservation CommissionofALAS ( \ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Kenneth W. Allen BP Exploration(Alaska)Inc. P.O Box 196612 i Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-22 Permit to Drill Number: 186-175 Sundry Number: 318-045 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French t Chair DATED this day of March,2018. RE E D STATE OF ALASKA 'v •ALASKA OIL AND GAS CONSERVATION COMAON • APPLICATION FOR SUNDRY APPROVALS �� /// , 20 AAC 25.280 FED 0 1 2018 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 0.-rations ashutdown 0 Suspend 0 Perforate o Other Stimulate 0 Pull Tubing 0 Chan.:'- P .i 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 186-175 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0• 99519-66126. API Number 50-029-21663-00-00 • Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 ' PBU L3-22 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028322 • PRUDHOE BAY.LISBURNE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10480 ' 9399 • 10435 9355 2585 7 None 9858 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 39-119 39-119 1490 470 Surface 4072 13-3/8" 38-4110 38-4014 3450/4930 1950/2670 Intermediate 9834 9-5/8" 37-9870 37-8808 6870 4760 Production Liner 862 7" 9618-10480 8568-9399 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9942-10221 8877-9147 2-7/8"6.5# L-80 34-9668 Packers and SSSV Type: 2-7/8"Baker FI-B Hydro Set Ret Packer Packers and SSSV MD(ft)and ND(ft): 9582/8534 2-7/8"Camco TRDP-1A SSV 2197/2197 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: May 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL ❑ 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 foy4going is true and the procedure approved herein will not Contact Name: Gorham,Bradley M be deviated from without prior written approval. Contact Email: Bradley.Gorhamc bp.com Authorized Name: Allen,Kenneth W Contact Phone: 907-564-4649 Authorized Title: Engineering Team Lead Authorized Signature: r'.'"' „) G Date: f /E. COMMISSION U ONLY Conditions of approval:Notify Commission so�that a representative may witness Sundry Number: /�J/ Plug Integrity BOP Test L9taMechanical Integrity Test 0 Location Clearance 0 3' J O Other /3 op F U 3C571 25-00075t, A-kzv1 vda r pre. V7'.v' 4�k r-Si Post Initial Injection MIT Req'd? Yes 0 No L9' REIT Li_ s,., `rig Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: )0— 4-0 7 (CaLCf.- APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: �` 103 PTI-I- z/2.e/i8 CSC CO ., Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 0 bP Gp 61)3 aterRitlillifie Sly r L3-22 Sundry Application Well Type: Producer Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of Lisburne well L3-22 to sidetrack and complete L3- 22A. MIT-IA Passed to 2400 psi ((9/28/2017) MIT-OA Passed to 1172 psi (9/28/2017) PPPOT-T Passed to 5000 psi (8/25/2017) PPPOT-IC Passed to 3500 psi (8/31/2017) Well History: L3-22 was originally drilled and completed in 1986. After a high GOR additional perforations were added in 2016. Since the well had suffered from low productivity and has been shut-in since August , 2017. L3-22 has no remaining value as all reasonable attempts to restore performance have been exhausted. Scope of Work: The sidetrack plan for the L3-22A well includes the following operations. Pre-rig, a cement plug will be , pumped into the existing casing leaving the TOC around —9,680' MD. Once the cement has setup, the final top of cement will be determined with a drift run followed by an integrity test of the tubing and inner annulus. Next, the 2-7/8" tubing will be jet cut. The rig will then move over the well and pull the 2-7/8" tubing.A clean out run will then be performed if deemed necessary, followed by the setting of an EZSV bridge plug in preparation of the whipstock exit at—9,470' MD. The 7" intermediate casing will be set at the top of the Lisburne formation and the 6-1/8" production hole will be drilled in the Wahoo reservoir. The production liner will be a cemented and perforated. 4- 1/2"tubing will then be run to the top of the production liner. MASP: 2,585 psi Estimated Start Date: May 15, 2018 iG!e v-e1 A4j ..Pn ' 'treyG°by /10/�'li%1911 less i4 'n /. '6' Ari �Or jkG �Gs9 (i(ptr /ld o/ ,,0O r ✓P 7,/e vv,' 1 I -cw-c' CV,— RCuri ii ��/0, flvj f4J wtlf fOr iadi'IP ci6vd a/JOw for irnf1-pve, recover/ fro* �1,0 prh,Cr+ or TL+e 1Oo1 i 2/7/4 L3-22 Sundry 1 1/31/2018 • Pre-Rig Prep Work: Step Service Line Description of Work 1 S Run flapper checker. Dummy gas lift valves. MIT-IA to verify valves set. Pull chemical injection valve,flush chemical line, set dummy,test line. Pressure test control lines. 2 F A/SL.Load IA. MIT-IA. Load TBG, obtain step rate test. 3 F Cement plug. Target TOC 9680'md. 4 S D&T TOC. Drift for jet cut. J Arm f 4-i; he(iC 2 l i s 5 F MIT-T 3,500 psi. CMIT-TxIA 3,500 psi. a p r 6 E Jet cut tubing at 9,520' MD. 7 F Circ out. CMIT-TxIA 3,500 psi. MIT-OA 1,100 psi. 8 S Set TRSSSV hold open sleeve. 9 0 Cement control/chemical lines that fail PT. 10 W PPPOT-T. PPPOT-IC. Function LDS. 11 V Set BPV. Install Dry Hole Tree. Configure annular valves. Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test BPV from below to 3,500 psi psi for 5 minutes. 3. Nipple down tree, install blanking plug and nipple up BOPE and test to 3,500 psi. (Configured from top to bottom: 13-5/8"annular preventer 2-7/8"x 5"VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5"VBRs in the lower cavity). a. Test both 2-7/8"x 5"VBR's with a 4"test joint. b. Test annular to 250 psi/3,500 psi with 4"and 4-1/2"test joint. c. Notify AOGCC 24 hrs in advance of full test. 4. Rig up and pressure test lubricator and dutch riser against blanking plug. 5. Break lubricator at the quick test sub (QTS) and pull blanking plug on drill pipe. 6. RU lubicrator and test QTS and lubricate out BPV. 7. RU hard lines to BOP. Circulate out diesel freeze protection and displace well to clean seawater. 8. Pull 2-7/8"tubing with control/chemical lines from the pre-rig cut. 9. Perform 9-5/8"cleanout run to tubing stub. Perform only if deemed necessary. 10. Rig up e-line. Run and set EZSV at—9,486' MD. Pressure test to 250 psi low for 5 min/3,500 • psi high for 30 charted min each. 11. Change 9-5/8"pack-offs and tubing spool and pressure test. 12. PU 9-5/8" whipstock, bottom trip anchor, and 8-1/2" window milling assembly (to include full gauge string mills). RIH to top of EZSV, orient, and set whipstock. TOWS at 9,470' MD. 13. Swap wellbore over to 10.3 ppg LSND milling fluid. End of Sundry: Start of Permit to Drill Drill 8-1/2" Intermediate Hole 14. Mill window in 9-5/8"casing plus 20' of new formation. 15. Pull into the window and perform LOT. Minimum LOT required is 11.4 ppg EMW for 25 bbl kick tolerance. 16. POOH for drilling BHA#1. 17. MU 8-1/2"drilling motor BHA#1 w/MWD/GR/RES/PWD and RIH. 18. Kick off and drill 8-1/2" intermediate interval per the directional plan to TLSB TD of—9,984' MD. 19. At TD, CBU a minimum of 2x, or until wellbore is clean. 20. Perform short trip to the window. L3-22 Sundry 2 1/31/2018 • • 21. RIH to TD, circulate the wellbore clean and POOH on elevators. Run & Cement 7" Intermediate Liner 22. Change upper 2-7/8"x 5"VBRs to 7"casing rams and test to 250 psi low/3,500 psi high for 5 min each. 23. Run 7", 26# L-80, VamTop HC liner to TD, with 150' liner lap into 9-5/8"window. 24. Cement liner to TOL with 15.8 ppg Class G tail cement. Circulate excess cement above TOL. 25. Set liner top packer and liner hanger. POOH and LD liner running tool. 26. Change upper 7" casing rams to 2-7/8"x 5" VBRs and test to 250 psi low/3,500 psi high for 5 min each. 27. Test 7" liner to 250 psi low for 5 min/3,500 psi high for 30 min after cement has reached a minimum 500 psi compressive strength. Drill 6-1/8" Production Hole Section 28. MU 6-1/8"drilling BHA with MWD/GR/RES/DEN/NEU/PEF/IMAGE and RIH. 29. RIH and tag landing collar. 30. Displace wellbore to 8.5 ppg QuikDril-N. 31. Perform an extended flow check on 7" liner(no flow test). 32. Drill shoe track and 20 ft of new formation. Pull above shoe and perform FIT. Minimum FIT required is 9.7 ppg EMW for infinite kick tolerance. However, a higher EMW will be targeted based on planned ECD's. 33. Drill 6-1/8" production interval per the directional plan to TD of 13,849' MD. 34. At TD, CBU until wellbore is clean. 35. Perform short trip to the shoe. 36. RIH to TD, circulate the wellbore clean and POOH on elevators. 37. LD excess 4" DP and BHA. Run and cement 4-1/2" Production Liner 38. Run 4-1/2", 12.6 ppf, 13Cr-85, VamTop production liner to TD,with 150 ft liner lap into 7" casing. 39. Cement production liner with 15.8 Class G cement. Note: If losses are present then the 8.6 ppg lightweight slurry will be utilized. 40. Set liner hanger and liner top packer(WFT). Circulate out the excess cement off the top of liner. 41. Displace wellbore to clean seawater. 42. POOH and LD liner running tool. 43. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner envelop to 250 psi low for 5 min/3,500 psi high for 30 min. Wait for cement to reach 500 psi prior to conducting pressure test. 44. RU and run pert guns as per TCP. Space out and shoot-2,500' of perforations. 45. POOH while keeping the hole full of sea water Run 4-1/2" Completion 46. RU and run 4-1/2", 12.6# 13Cr-85 VamTop completion per the tally. Tag up in PBR, space out, and land tubing hanger. RILDS. 47. Displace tubing and IA to clean seawater. 48. Reverse circulate in heated seawater and inhibited seawater to IA and tubing (surface to surface). L3-22 Sundry 3 1/31/2018 • • 49. Drop ball &rod and set production packer. Individually test tubing and IA to 250 psi low for 5 min/ 3,500 psi high for 30 min. 50. Hold pressure on the IA and slowly bleed tubing pressure down to 1,500 psi to shear the DCR valve. Pump both ways to confirm circulation ability. 51. Reverse circulate in diesel freeze protect down IA using rig's injection pump to freeze protect IA and tubing to 200' below base permafrost. 52. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. ND/NU 53. Install TWC and test from above and below to 250 psi low/3,500 psi high for 5 minutes each. 54. N/D BOPE. NU adapter flange and double master valves. Test to 250 psi/4,500 psi for 5 minutes each with diesel. 55. Ensure Heet is left on top of TWC and only diesel is left in the tree. 56. Install all annulus valves and secure the well. 57. Rig down Parker 272. 58. Move rig off location. Post-Rig Operations 1. V: tree work/Pull BPV 2. SL: DGLVs 3. C: Set retainers/acid job/mill retainers(assumes 4 acid stimulation stages) 4. SL: LGLVs 5. T: Flowback(while coil mills, acid clean up, and obtain test) Drilling Engineer: Brad Gorham (907) 564-4649 Production Engineer: Kirsty Schultz (907) 564-5105 Geologist: Mark Swanson (907) 564-5931 L3-22 Sundry 4 1/31/2018 TREE= CAN L3-22 22 SAFETY NOTES: Wfl.LHEAD= MCEVOY P&P ACTUATOR= BAKER KB.HSV= 60 13-3/8"CSG,68#,, —1 70' 4. x I _BF.E-EV= KOP= _3100' K-55 BTC, Max Angle= 9*7200' D=12.415" Datum MD= 10028' 2196' I--I2-7/8"CAM TROPIA-SSA TRSSSV,D=2.312" ()gum TVD= 8900'SS O CHEMICAL MANDRELS -)] I,i ( 1 ;I ST MD TVD DEV TYPE VLV LATCH PORT DATE 11 1 2284 2284 0 KBMG-L DMY BK-2 0 03/31/87 Minimum ID = 2.250" @ 9654' GAS LFT 2-7/8" CAMCO D NIPPLE ST M) SND DEV TYPE MAN VLNV�LATCH FORT DATE 2 2811 2811 4 MIGFM-D DM' BK 0 03/31/87 13-3/8"CSG,72#,L-80,D=12.347" H 4110' 3 5390 5063 36 MI -FM-0 DOME BK 16 09/30/17 9-5/8"CSG,47#,L-80 NSCCXO TO L-80 BTC H 4.517• 4 7531 6754 38 A/C-F1/1-10 DONE BK 16 09/30/17 5 8944 7942 24 MC-FM-O SO BK 20 09/30/17 Base DPZ 1 - CM3 7,760' MD (6,874' TVDss) 6 9475 8433 20 MIGFMHO RKED RKP 0 03/31/87 ,. TOC at 7 550' MD from 11-25-86 VBL 1•` . AI IF 9582' 9-5/8"X 2-7/8"BRWN HB PKR DPZ3 - LOU - 9,504' MD (8,400' TVDss) 1'�— OM r 1 Pre-rig jet cut at 9,520' MD - 0 ►. 9618' —19-5/8"X 7"TEBACK,D=?' •TOP OF 7"LNR 9631' ,A l ®I it 9631' —I9-5/8"X 7"BOT SHORTY HYD HGR,10=?' 1 �. 1•4 • 1• 41 ►1 /' 9654' H2-7/8"CAMCO D NP,D=2.25" 1.144 IH 14.111 2-7/8"TBG-IPC,6.5#,L-80 BJE 8RD, 9666' 1�k1. V 1, 9666' —2-7/8"WLEG,D=2.441" .0058 bpf,D=2.441" ,1 11 ♦ .�♦ r►1 . . Top of Cement Plug —9,680' MD e,�I�ili12�I�I�ilii1 III ii DPZ 3 - BSAD 9,749' MD (8,632' TVDss) 1�o/i/...�1.1./44A r 9847' }-7'MARKER JO(1r(20") 111111/ ����11 ? HASH SPRING 05/11/08 .1141•.;•'•"."• � ( > II . ►.1 �♦ ►111.4.111 11 ► /.11111♦1♦1.111♦1♦/� . 9868' 7'MARKER JOINT(20") 9-5/8"CSG,47#,L-80 BTC,D=8.681" }— 9869' 11 .******... 4 ♦11..411111 11 ****11. ♦ .11..1.1 1 ►1(1.•...1.4*1*1*'11 DPZ 4 - Lisburne 9,922' MD (8,797' TVDss) PERFORATION SUMMARY EF ►1•♦♦111♦♦1•♦11 111 I,/41.♦*♦♦♦1♦1♦1' RLOG:LDT/CN ON 11/20/86 .1......11........4 1 ANGLE AT TOP PERF_16"@ 9942' ♦1.11♦11111) 11 1.11/1♦ ► Note:Refer to Production DB for historicalpert data 1�/♦♦114♦� 1 11 1111111'► 11.11111 1 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 11'....1.94 2-1/8" "S 9942-10002 - 0 03/23/87 ►41 11.1.♦.♦41.1. ►1 2" 6 10043-10083 0 05/25/15 111�41♦1.1.1♦4♦11 11 2-1/8" "S 10043-10126 0 03/23/87 ►1'..44444 1 ►11.•�♦4♦411•••••'11 2" 6 10092-10127 - 0 05/25/15 11111.1111♦11111♦�,/1 2-1/8" *S 10141-10219 - 0 03/23/87 1 .4'4'4'4 1 2" 6 10158-10173 ' 0 05/25/15 11114..♦..'11 11,•♦♦♦1♦. / 2" 6 10196-10221 • 0 05/25/15 1.11�.�♦♦1♦.�/♦/11/1 . 1•.11..4 1 1'11..411 ♦ 1111♦1� * Selective Shots ►111 4.4.41/1�♦11. PBTD --I 10435' 11 ••••••• 111•.♦1♦11./11*♦*•111 7"LNR,29#,L-80 BTC,.0371 bpf,ID=6.184" — 10480' 1,4 444.4•••••1•♦•♦ 1 DATE REV BY COMMENTS DATE REV BY COMMENTS LISBLIRNE UNIT 11/24/86 IMTIAL COMPLETION 02/02/14 GFJ/PJC SSSV CORRECTION WELL: L3-22 05/28/06 RCT/PJC GLV GO 02/22/14 PJC REFORMAT DRAWING PERMIT No:"1861750 03/04/07 RL DATUM MD 06/22/15 DHS/JMD ADPERFS(05/25/15) API No: 50-029-21663-00 05/04/07 BSE/PAG GLV GO&CORRECTIONS 10/16/17 GJB/JND GLV GO(09/30/17) SEC 22,T11 N,R15E,812'FNL&833' 05/07/08 DK/PJC TREE REPLACEMENT 05/31/08 BSE/PJC FISH(05/11/08) BP Exploration(Alaska) WELLHEAD= MCEVOY • L3-22 SAFETY NOTES: ACTUATOR= BAKER KB.ELEV- 60' 13-3/8'CSG,68#,, --{ 70' 4. 1 I BF.ELEy = K-55 BTC, KOP= 3100 Max Angle= 9 @ 7200' D=12.415" A2196' H 2-7/8"Datum MD= 10028' CAM TRDP1 A-SSA TRSSSV,D=2.312" Datum TVD= 8900'SS CF CAL MANDRELS ®"CONDUCTOR - ? ST MD ND DEV TYPE VLV LATCH FORT DATE C L ' 1 2284 2284 0 KBMG-L DMY BK-2 0 03/31/87 Minimum ID = 2.250" @ 9654' GAS LFTANDS 2-7/8" CAMCO D NIPPLE ST MD ND DEV TYPE MAN VLLVRELLATCH FORT DATE 2 2811 2811 4 MC-FMI-D MY BK 0 03/31/87 13-3/8'CSG,72#,L-80,D=12.347" —{ 4110' 3 5390 5063 36 MC-FM-0 DOME BK 16 05/04/07 9-5/8"CSG,47#,L-80 NSCC XO TO L-80 BTC H 4517' 1--K x 4 7531 6754 38 MC-FMD DOME BK 16 05/04!07 5 8944 7942 24 MC-FM-0 SO BK 20 05/04/07 6 9475 8433 20 MGFMHD RKE) RKP 0 03/31/87 (>< 9582' —19-5/8'X 2-7/8"BRWN 113 FKR 9618' —19-5/8"X 7"TEBACK,D=?' TOP OF 7"LNR H 9631' 4 9631' —I9-5/8''X 7'BOT SHORTY HY D HGR D=V ' 9654' H2-718"CAMCO DMP,D=2.25" 2-7l8'TBG FC,6.5#,L-80 QIE 8RD, --I 9666' II 9666' —�2-7/8"WLEG,D=2.441" .0058 bpf,ID=2.441" 9847' F_7'MARKER JOINT(20") 4III ? HASH-2-1/2"JU DOG SPRPIG(05/11/08) 19-5/8"CSG,47#,L-80 BTC,D=8.681" }— 9869' .1—, I, 9868' F-7'MARKER JONT(20") I PERFORATION SUMMARY FRE I LOG:LDT/CNL ON 11/20/86 ANGLE AT TOP PERF: 16"@ 9942' ' Note:Refer to Production DB for historical perf data SIZE SPF NTER'VAL Opn/Sqz SHOT SOZ 2-1/8" 'S 9942-10002 0 03/23/87 I 2" 6 10043-10083 0 05/25/15 2-1/8" 'S 10043-10126 0 03/23/87 I 2" 6 10092-10127 0 05/25/15 2-1/8" 'S 10141-10219 0 03/23/87 ' 2" 6 10158-10173 0 05/25/15 2" 6 10196- 10221 0 05/25/15 ' * Selective Shots P6TD 10435' +1.1.1. 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" 1—fi 10480' • DATE REV BY COMMENTS DATE REV BY CONI ENI S LISBURNE unirr 11/24/86 INITIAL COMPLETION 02/02/14 GFJ/PJC SSSV CORRECTION WELL: L3-22 05/28/06 RCT/PJC GLV CIO 02/22/14 PJC REFORMAT DRAWING PERMIT No: 1861750 03/04/07 RL DATUM MD 06/22/15 OHS/JMD ADPE2FS(05/25/15) AR No: 50-029-21663-00 05/04/07 BSEIPAG GLV GO&CORRECMONS SEC 22,T11N,R15E,812'FT&&833' 05/07/08 DK/PJC TREE RE'LACENENT 05/31/08 BSE/PJC FISH(05/11/08) BP Exploration(Alaska) • • • • 2 ( ) • 3 ¢ J m s § W' E5 >w 80 ALI oems �Nxfi� �coz `^`' .8°... ie ,2,0 228g $ !!, -G wdd`` R §R!I !m xg ! =mff, a3�F, amens• iy�mm\ zzs�a jj '-a7nr . anvLm\ ain --aa s� � . _ ,m,- •.•.•.• oao2\ � -..--.--. \\ \\i i.\�1010 .. . onwu' vnn inm � \\ i � W� . ire ,,,,,,,--ii- QnINn nh• -- � -- m ]C ��� I 1 o O CY Y as oa0. o J os } n 8 8 BK .aG ma w I i 4.1:,q-- , : _____ !! !! i 1 i I - - , Wmm �mm inn P.Sa yna zn, H---- 1 i .B/L f-,I z Mn— uu,--mn S-- cZ�� c7_ 0 I I } 6 IF■ II•V ill it SI"i -'! 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' ossr, m ■1111111 'AIIF �1■I , �_111■IIII1I11 _ 44. O 1 ■IIIIUI�'■II' UI1ii,lil����■ , 1 II■IIIIIIII 73 X j ■Illllll��d1�I11�111nh �.. �.... unman UJ ■IIIIIIII■IIOUil IIIIIIII■IIIIIIII 1■11111111■ 0. ■�111I 1111111/1 1111111 1■1011111■ a s8 o 0 0 0 0 0 s sr 0 0 0 0 0 ri 0 0 0 0 r 0 0 0 a-I 0 0 e-I 0 yfuow aad Ja4eM;o siaiiie8 Jo yWo j Jed POO spine S 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 j / in the upper left corner of Form 10-403 is checked. If the "Abandon"or V "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, 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. V or T� w���\I%%, THE STATE Alaska Oil and Gas ®f LAsKA. Conservation Commission ui 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o ,,,. Q, Main: 907.279.1433 ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE SCANNED JAN 1 $ ?U13 BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-22 Permit to Drill Number: 186-175 Sundry Number: 317-602 Dear Mr. Stechauner: • 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, d:62( Hollis S. French Chair 11 DATED this LI day of January, 2018. • 17471-':::r3 S *ALASKA OIL AND GAS CONSELRAVS N COMM) 7 • APPLICATION FOR SUNDRY APPROVALS DEC 2 2 201 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations m Fracture Stimulate 0 Repair Well 0 AGe 2-GTtdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool p 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: 186-175 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21663-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I! PBU L3-22 • 9. Property Designation(Lease Number): 10. Field/Pools: it 0t,+45 ? "�f'�'4=C ' -e-1 `l76"'-4' ADL 0028322 ' PRUDHOE BAY,LISBURNE OIL 11. PRESENT WELL CONDITION SUMMARY A (.9,if,' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10480 . 9399 ' 10435 9355 9858 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 39-119 39-119 1490 470 Surface 33 13-3/8" 38-71 38-71 3450 1950 Surface 4040 13-3/8" 71-4111 17-4015 4930 2670 Intermediate 9834 9-5/8" 37-9870 37-8808 6870 4760 Production Liner 862 7 9618-10480 8568-9399 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9942-10221 8876-9147 2-7/8" L-80 34-9668 Packers and SSSV Type: 2-7/8"Baker H-B Hydro Set Ret Packer Packers and SSSV MD(ft)and ND(ft): 9582, 8534 2-7/8"Camco TRDP-1A SSSV 2197,2197 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q • Service 0 14.Estimated Date for Commencing Operations: 1/15/18 15. Well Status after proposed work: Oil I . 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 Name: Stechauner,Bernhard be deviated from without prior written approval. Contact Email: Bernhard.Stechaunert bp.com Authorized Name: Stechauner,Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2 PE Authorized Signature: Date: (Z/ (/C7- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31--)—(40 2 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No l3/ Subsequent Form Required: is_ /c Approved by: COMMISSIONER APPROVED BYTHE COMMISSION Date:( Jt 61') IA ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. AttaAp nts in Duplicate 12.• 2;-.17 • • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) December 21, 2017 To Whom it May Concern: Attached please find the Sundry Application for Sand Back with Cement Cap to Plug the Perforations in the Lisburne Formation and Addition of Perforations in the New Pool of the Ivishak Formation for Well L3-22, PTD # 186-175. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD,EAZ, BPG 10/12/15) General Information Well Name: L3-22 Well Type: Gas Lift Producer API Number: 50-029-21663-00 Well Activity Conventional 4 Classification: Activity Description: Plug Lisbourne, Perf Ivishak Cost Code/AFE: APBNRWOS Field/Reservoir: LISBURNE 12 Month Avg IOR, 50 bopd: Job Type: Add Perf+ Prof Mod Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory Convert from Lisburne to Ivishak pool requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Required? Secondary Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907) 360-7485 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Mark Sauve Contact numbers: (907)564-4660 (907)748-2865 Date Created: November 14, 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Choke SettingPressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 8/21/2017 51 1340_4 bwpd, 99 1,940 176 2,382 546 WC 96.31% Current Status: Operable Shut In Inclination >70°at Depth (ft) NA Recent H2S date, m 5/28/2015 70 Maximum Deviation(Angle and ( pp ) ppm / Depth) 39° 6,800'MD Datum depth,ft TVDss 8,900'TVDss Dogleg Severity(Angle and Depth) 4° 3,700' MD Reservoir pressure(date, psig) 9/27/2017 2.768 psi Minimum ID and Depth 2.250" 9,654' MD Reservoir Temp, F 181° F Shut-in Wellhead Pressure 1.200 psi Known mech. integrity problems(specifics) None Last downhole operation(date,operation) 9/30/2017 DrIg screen, GLV work, set/pulled catcher from 9,621'SLM Most recent TD tag (date,depth, toolstring OD) 9/26/2017 10,306' MD 2.15"cent, TEL. s. bailer Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Rotary SOR on backlog for this well most likely not happening until 2019. Minimal on-time over the last background information, years and barely competitive. etc: Would like to test Ivishak in this area to understand if Z1 is swept and to potentially identify a drilling target (from DS-04). ppSe rt,) ,f likely a teiVm1y cecom//ef/ fo eva(v. moi• tr.-s� i, COACar• 021‘ n� `✓�Dc+4✓ch}�i, O Ate before return'''. rd t;rY�+K • Well Intervention Details • • Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sites/gwo2/GlobalLibrary/100220.pdf Suspected Well Problem: Low IOR Lisburne well, sidetrack not scheduled until 2019 Specific Intervention or Well Objectives: 1 Isolate Lisburne and perforate Ivishak 2 Prove up a future Ivishak sidetrack in the area,depending on Ivishak production results 3 Key risks,critical issues: Mitigation plan: 1 Perforating through two strings,small tubing Perform SPAN analysis to identify best gun Sand back with coil and dump cement on EL will give 2 Isolate Lisburne in a way that's easily reversible us minimal amounts of cement to underream should we elect to re-access Lisburne. 3 Summary Service Line Activity Step# 1 S Drift to TD 2 C Sand back. Top of sand-9,850 MD 3 E Drift to top sand, dump-10ft of cement perforate Ivishak Z1 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 100 MMSCFD: 6 BWPD: 50 Expected Production Rates: FTP(psi): 200 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POP to LP with AL and test. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • PENDING PERFORATING PROCEDURE Well: L3-22 API#:50-029-21663-00 Date: 11/1412017 Prod Engr Bernhard Stechauner Office Ph: (907)564-4594 H2S Level: 11 __... Home Ph: I�.. 70 ppm _.�I Cell/Pager: (907)360-7485 CC or AFE: APBNRWOS _...... _... _... _.._... _... . WBL Entries IOR Type Work Description See Procedure Well Objectives and Perforating Notes: See Procedure. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 0 feet Log: LDT/CNL to the tie-in log to be on Date: 11/20/1986 depth with the reference log. Company: Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 9.718' 9,742' Z1 Add Requested Gun Size: Charge: Min Wellbore ID: 2.25 Max Swell in Liquid: Max Swell in Gas: Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Drift: 10,306 ft MD on 9/26/2017 Est Res.Pres.l 8,900'TVDss MD is 2768 psi Perforation Summary Summary Dist Well: -22 Town: Date: API/k: 50-029-21663-00 Prod Engr: Anch Prod Engr ..._............ ................. P.D.Center P8TD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/8/U 0/B/U • Well : 13-22 Nip c TVDSS `1:250'FT) (FEET" ' i GR_N • i , , 1 :250 1:25 . . . x Annotation schematic 23N 9600 , 22N 85500 r 9625 ..... s 650 r a f 8550 9675 #' " P 1 8575 ihr ; 'a: 9700 14P i 1 1 i1 8600 9725 13P 862",x ; 3 f 8650 I 0 • TREE= OWN VI.ELLHEAC7.• TACEVOY' L 3-22 SAFETY NO rES.. ACTUATOR= BAK1321 '_ = 13-3/1 03G 090, ri 7041 7 K-55 EITC I KOP= 3100 i AlioL AVE= 9 a 7207 [ 211n. 7-11 fie"CA41 MOEN* GSA TRSSSV,I)'1 312' j 0111111114D= 100201 , Ca8unt1V0. 89017 SS, — CHEMICAL MAM:RELS -ST ACM FT-VC/10E1f TY FE VW1LA 101 PORT GATE 1 2217234, , 0 103144G-L DMY I 8K-2 0 '03/317E7 Minimum ID il 2250"a 9664' GAS LFT IAAM1RELS 2-7/9"CAMCO D NIPPLE ,I gi — ,......., [1.3-,309'( G,12 8:L-1130,_83.._12.3vir H 4110 1-4 I, 2 2311 2511 hIG FR4-10 Cliff BK 0 ;03/31137 , , _ -.. 3 5390 50331 38 AGRI410 COI& ex 16 .ofiv3o/17 [0,54.1"CI3G,4/e,L,,00 nc4-1;)50 TO L-d0 E1111; [---- asir I-- — 4 7531 6754 38 PAC-FMHC/ DOW BK 18 09/30117 5 6944 79421 24 4C-RATO SO BK 20 ,09030117 6 9475 34331, 20 AC-FM-102 Re033 RKP 0 03131167 1552' ...::,. L 111552' j-;19-Srtir X 2-118-194WN HO PKR 1 [T-OP OF l-r11411r--14 90.18' -1-1-9-5/3"X 7^TIEBACK,D="A'I 1-- aill' J-in-50r X 7"1301 91,ORTY 1-4.;IT t MR 10, ; I lir!DOM,B 5w,L 60 10 t1111, -- 91165` [7_915‘,...ji---V---mr.cokmeo 0 NP, 1 I .4441-=-1-fTri7-HIL,EG,L2-2 44 1. 1 1_0069 Dpf,CI,2.441' I 0047 j-17'MARKER JONI'20-) I likr i 7 -1-{FlOt I•2,,177'.70 OrX3 SPRDNIG(05111006)_I -5'11*CS 414,Leo OTC,11)=e&Iv-1-r 9949' 1--4 ilk I 1166er FLT MARKER JOINT(20') 1 _ , _ ,, I PERFORATION SLOO/ARr RFF 100 LOT/04 ON 112666 I AP F AT TOP PERK 1E",::,;9942 Note:Rater to Roduction C13 for istorical part data I :..-rzE SPF INTERVAL 1 Opri/STiz SHOT 1 902 7-1/8" 5 9942-10302 0 03123/87. II 7 6 10043-10083 0 05/25115, 2 1/8' 5 10043-10126 0 03/23/871 I 2' 6 10092 10127 0 05/25/151 2•1/9 5 10141-10219 0 03/23/87 I 2' 6 10158-10173 0 05/25/15, r 6 10196-10221 0 ;osI7si15j , .... I ' Selective Shots ' 9999999, ••••••• ri,il-4i,i9.'•' ,1:40 EITE..0371 biA.ID'0 tea' H 1°our DATE REV BY REV BY COMMENTS ; LIS81ljeE ul‘iT 11/24/511 MTIAL Call PLETTON 02/02/14 GF.1 RIC Ss-SV CORRECTION WELL: L3-22 0520006 RCT/PJG (&V CIO 0222/14 RIG REFOOMAT 13144)ANG PETIPAT ND. 1861/5(7 ; 03104/07 FL DATUM MD 05722/15 CHS/MD ACPEFFS(0525/15) AR No: 50629.21663,770 05/04707 8S&10 Gi_V(20&CORRECTIONS 10/16/1 I GJIBIJIND.GLV DO(09/30717) SEC 22,T1114.R15E,812 RC&833' 05707708 OK/RE TREE REP_ACELENT I 05/31108 BSEPPJC RSH(05/11030) ___. BP Exploration tAlaska) • • Roby, David S (DOA) From: Richards, Meredyth <Meredyth.Richards@bp.com> Sent: Wednesday, December 27, 2017 8:24 AM To: Roby, David S(DOA);Stechauner, Bernhard Subject RE:Sundry application for PBU L3-22 (PTD 186-175 Hi Dave, In reading notes on this well and the proposed recompletion,it seems to me that we are looking for sidetrack potential in the Ivishak. If results of this plug set suggest a viable Z1 play in the Ivishak,the idea is to proceed with a sidetrack targeting the Ivishak only.If we are unable to identify such a drilling target,the well will continue producing out of the Lisburne. Future well plans may include a sidetrack to elsewhere in the Lisburne,although I'm not aware of any plans to do that as of yet. Does this help any? Hope you had a nice Christmas. Please get in touch if I just confused things even more! Best, Meredyth From:Roby,David S(DOA)[mailto:dave.roby@alaska.gov] Sent:Tuesday,December 26,2017 1:14 PM To:Stechauner, Bernhard<Bernhard.Stechauner@bp.com> Subject:Sundry application for PBU L3-22 (PTD 186-175 Bernhard, In reviewing the application to plug the subject well and recomplete it in the Ivishak formation it appears that the intent would be for this recompletion to just be temporary to determine if there's a viable Ivishak target to be drilled from DS-04 and that the option of recompleting the well in the Lisburne or utilizing the wellbore for a possible future Lisburne sidetrack would be maintained. Is this correct? Thank you, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.if you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@ataska.gov. 1 STATE OF ALASKA J U IVB 2 4 '' ALASKA OIL AND GAS CONSERVATION COMMS .JN ��I" REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed {1.,�- ,�-'.. Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 186-175 3. Address: P.O.Box 196612 Anchorage, Development I21 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6 API Number: 50-029-21663-00-00 7. Property Designation(Lease Number): ADL 0028322 8. Well Name and Number: LISB L3-22 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 10480 feet Plugs measured feet true vertical 9399 feet Junk measured 9858 feet Effective Depth: measured 10435 feet Packer measured 9583 feet true vertical 9355 feet Packer true vertical 8535 feet Casing: Length Size: MD: TVD. Burst: Collapse: Structural Conductor 80 20"Conductor 38-118 38-118 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9834 9-5/8"47#L-80 37-9870 37-8808 6870 4760 Production Liner 862 7"29#L-80 9620-10482 8570-9401 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet 1 2-7/8"6.5#L-80 36-9669 36-8616 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and 2-7/8"Baker H-B Hydro Set Ret Packer 9583 8535 true vertical depth) 12.Stimulation or cement squeeze summary. Intervals treated(measured): Treatment descriptions including volumes used and final pressure' SCANNED : I i " % 2131 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 1890 1986 537 Subsequent to operation: 426 638 1871 2048 517 14 Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations (i Exploratory ❑ Development 10 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhay,, : M( -O Technologies) Title Data Manager • / Signatur /�—� ' / Phone +1 907 564-4035 Date 06/23/2015 v t`� / 9 / S rel . RBDMSu JUL - 1 2015 Form 10-404 Revised 5/2015 ! 0 /!/ �� Ir"�- Submi ginal Only Daily Report of Well Operations ADL0028322 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL SWCP 4521***(perforating) RAN 2.34" NO-GO CENTRALIZER TO TRSV @ 2160'SLM. RAN FLAPPER CHECKER TO TRSV @ 2160'SLM.TRSV OPEN. RIH W/ 30' X 2" DUMMY GUN, T.E.L., S.BAILER, TAGGED T.T. @ 9618'SLM./9666'MD. 48'CORRECTION, TAGGED TD @ 10,268'SLM/ 10,316'MD, RDMO. 2/19/2015 LEFT WELL SHUT IN, TURNED WELL OVER TO PAD OPER**** T/I/O=2000/1700/210. Temp= SI. T FL(E line request). AL open @ casing valve. TBG FL @ 6940' (591'above sta#4 DOME, 40 bbls). 2/27/2015 SV, WV, SSV= C. MV= O. IA, OA=OTG. 19:50. ***WELL SHUT-IN UPON ARRIVAL***(SLB ELINE- PERF) INITIAL T/I/O= 1700/1780/220 PSI MIRU. VALVE CREW GREASE SWAB AND SSV. RUN 1: RIH, PERFORATE FROM 10196'-10221'/CCL TO TOP SHOT= 3.3'/ CCL STOP DEPTH = 10192.7' RUN 2: RIH, PERFORATE FROM 10158'-10173'/CCL TO TOP SHOT= 8.25'/CCL STOP DEPTH = 10149.75' RUN 3: RIH, PERFORATE FROM 10107'-10127'/CCL TO TOP SHOT= 3.25'/CCL STOP DEPTH = 10103.75' RUN 4: RIH, PERFORATE FROM 10092'-10107'/CCL TO TOP SHOT=8.25'/CCL STOP DEPTH = 10083.75' RUN 5: RIH, PERFORATE FROM 10063'-10083'/CCL TO TOP SHOT= 3.3'/CCL STOP DEPTH = 10059.7' RUN 6: RIH, PERFORATE FROM 10043'-10063'/CCL TO TOP SHOT= 3.3'/CCL STOP DEPTH = 10029.7' ALL RUNS CORRELATED TO DRESSER ATLAS ACOUSTIC CEMENT BOND LOG DATED 25- NOV-1986. 5/25/2015 ***JOB CONTINUED ON 26-MAY-2015*** ***JOB CONTINUED FROM 25-MAY-2015***(SLB ELINE-PERF) ALL PERF RUNS COMPLETE. RDMO. FINAL T/I/O= 1710/1760/0 PSI 5/26/2015 ***JOB COMPLETE. WELL SHUT-IN UPON DEPARTURE*** Fluids Summary Bbls Type 2 DIESEL 1 METH 3 • Perforation Attachment ADL0028322 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base L3-22 3/23/1987 PER 9941.5 9942.5 887617 887714 _ L3-22 3/23/1987 PER 9943.5 9944.5 8878.1 8879.06 L3-22 3/23/1987 PER 9945 5 9946 5 8880.03 8880 99 L3-22 3/23/1987 PER 9947.5 9948.5 8881.95 8882.92 L3-22 3/23/1987 PER 9949.5 9950 5 8883 88 8884.84 L3-22 3/23/1987 _ PER 9951.5 - 9952 5 8885 81 8886.77 L3-22 3/23/1987 PER 9953 5 9954 5 8887.73 8888.7 L3-22 3/23/1987 PER 9955 5 9956 5 8889 66 8890.63 L3-22 3/23/1987 PER 9957.5 _ 9958.5 8891.59 8892 55 L3-22 3/23/1987 PER 9959.5 _ 9960.5 8893.52 8894.48 L3-22 3/23/1987 PER 9961 5 9962 5 8895.45 8896.41 L3-22 3/23/1987 PER 9963 5 9964 5 8897.37 8898.34 L3-22 3/23/1987 PER 9965 5 9966 5 8899.3 8900.27 L3-22 3/23/1987 PER 9967 5 9968 5 8901.23 8902.2 L3-22 3/23/1987 PER 9969 5 9970 5 8903.16 8904.12 L3-22 3/23/1987 PER 9971 5 9972 5 8905.09 8906.05 L3-22 3/23/1987 PER 9973 5 9974 5 8907.02 8907.98 L3-22 3/23/1987 PER 9975 5 9976 5 8908.95 8909.91 L3-22 3/23/1987 PER 9977 5 _ 9978 5 8910.88 8911.84 L3-22 3/23/1987 PER 9979 5 _ 9980 5 8912.81 8913.77 L3-22 3/23/1987 PER 9981 5 _ 9982 5 8914.74 8915 7 L3-22 3/23/1987 PER 9983 5 _ 9984 5 8916.67 8917.63 L3-22 3/23/1987 PER 9985 5 _ 9986 5 8918.6 8919.56 L3-22 3/23/1987 PER 9987 5 - 9988 5 8920.53 8921.49 L3-22 3/23/1987 PER 9989 5 9990 5 8922.46 8923.42 L3-22 3/23/1987 PER 9991 5 9992 5 8924.39 8925.35 L3-22 3/23/1987 PER 9993 5 - 9994 5 8926.32 8927.29 L3-22 3/23/1987 _ PER 9995.5 9996 5 8928.25 8929.22 L3-22 3/23/1987 PER 9997 5 9998 5 8930.18 8931.15 L3-22 3/23/1987 PER 9999.5 10000.5 8932.11 8933.08 L3-22 3/23/1987 PER 10001.5 10002.5 8934.05 8935.01 L3-22 5/25/2015 PER 10042.5 10043 8973.67 8974.16 L3-22 5/25/2015 APF 10043 10043.5 897416 8974.64 ' L3-22 5/25/2015 APF 10043 5 10044.5 8974.64 8975.61 L3-22 5/25/2015 APF 10044.5 _ 10045.5 8975.61 8976.58 L3-22 5/25/2015 APF 10045.5 10046.5 8976.58 8977.54 L3-22 5/25/2015 APF 10046.5 10047.5 8977.54 8978.51 ' L3-22 5/25/2015 APF 10047.5 _ 10048.5 8978.51 8979.48 1 L3-22 5/25/2015 _ APF 10048.5 _ 10049.5 8979.48 8980.44 L3-22 5/25/2015 APF 10049.5 _ 10050.5 8980.44 8981.41 _ L3-22 5/25/2015 APF 10050.5 10051.5 8981.41 8982.38 L3-22 5/25/2015 APF 10051.5 _ 10052.5 8982.38 8983.35 L3-22 5/25/2015 APF 10052.5 10053.5 8983 35 8984.31 L3-22 5/25/2015 APF 10053.5 10054.5 8984.31 8985.28 L3-22 5/25/2015 APF 10054.5 _ 10055.5 8985.28 8986.25 L3-22 5/25/2015 APF 10055.5 _ 10056.5 8986.25 8987.22 L3-22 5/25/2015 APF 10056.5 _ 10057.5 8987.22 8988.18 L3-22 5/25/2015 APF 10057.5 10058.5 8988.18 8989.15 L3-22 5/25/2015 APF 10058.5 10059.5 898915 8990.12 L3-22 5/25/2015 APF 10059 5 _ 10060.5 8990.12 8991.09 L3-22 5/25/2015 APF 10060.5 10061.5 8991.09 8992.05 L3-22 5/25/2015 APF 10061.5 10062.5 8992.05 8993.02 L3-22 5/25/2015 APF 10062.5 10063 8993.02 8993 5 L3-22 5/25/2015 _ APF 10063 _ 10063.5 8993.5 8993.99 L3-22 5/25/2015 APF 10063.5 _ 10064.5 8993 99 8994.96 L3-22 5/25/2015 APF 10064.5 10065.5 8994.96 8995.92 L3-22 5/25/2015 APF 10065.5 10066.5 8995 92 8996.89 L3-22 5/25/2015 APF _ 10066.5 10067.5 8996.89 8997.86 AL3-22 5/25/2015 APF 10067.5 10068.5 • 8997.86 8998.83 L3-22 5/25/2015 APF 10068.5 10069 5 8998 83 8999.8 L3-22 5/25/2015 APF 10069 5 10070 5 8999.8 9000.76 L3-22 5/25/2015 APF 10070.5 10071.5 9000.76 900173 L3-22 5/25/2015 APF 10071.5 10072 5 9001.73 9002.7 L3-22 _ 5/25/2015 APF 10072 5 10073.5 9002.7 9003.67 L3-22 5/25/2015 APF 10073 5 10074 5 9003.67 9004.63 L3-22 5/25/2015 APF 10074 5 10075 5 9004.63 9005.6 L3-22 5/25/2015 APF 10075.5 10076 5 9005 6 9006.57 L3-22 5/25/2015 APF 10076 5 10077 5 9006 57 9007.54 L3-22 5/25/2015 APF 10077 5 10078.5 9007.54 9008 51 L3-22 5/25/2015 APF 10078.5 10079.5 9008 51 9009 47 L3-22 5/25/2015 APF 10079 5 10080.5 9009.47 9010.44 L3-22 5/25/2015 APF 10080.5 10081.5 9010.44 901141 L3-22 5/25/2015 APF 10081.5 10082.5 _ 9011.41 9012 38 L3-22 5/25/2015 APF _ 10082.5 10083 9012.38 9012.86 L3-22 5/25/2015 PER 10083 10083 5 ▪ 9012.86 9013.35 L3-22 5/25/2015 PER 10091.5 10092 9021.09 9021.58 L3-22 5/25/2015 APF 10092 10092.5 _ 9021.58 9022.06 L3-22 5/25/2015 APF 10092 5 10093.5 9022.06 9023 03 L3-22 5/25/2015 APF 10093.5 10094 5 9023.03 9024 L3-22 5/25/2015 APF 10094.5 10095.5 9024 9024.97 L3-22 _ 5/25/2015 APF 10095.5 10096 5 9024.97 9025.94 L3-22 _ 5/25/2015 APF 10096.5 10097.5 9025.94 9026.91 L3-22 _ 5/25/2015 APF 10097.5 10098.5 _ 9026.91 9027.87 L3-22 5/25/2015 APF 10098.5 10099 5 _ 9027.87 9028.84 L3-22 5/25/2015 APF 10099.5 10100 5 9028.84 9029.81 L3-22 5/25/2015 APF 10100.5 10101.5 9029.81 9030.78 L3-22 5/25/2015 APF 10101.5 10102.5 9030.78 9031.75 L3-22 5/25/2015 APF 10102.5 10103 5 9031.75 9032.72 L3-22 5/25/2015 APF 10103.5 10104.5 9032.72 9033.69 L3-225/25/2015 APF 10104.5 10105 5 9033.69 9034.66 L3-22 _- 5/25/2015 APF 10105.5 10106.5 9034.66 9035.63 13-22 5/25/2015 APF 10106.5 10107 9035.63 9036.11 L3-22 5/25/2015 APF 10107 10107.5 9036.11 9036.6 L3-22 5/25/2015 APF 10107.5 10108.5 9036.6 9037.57 L3-22 _ 5/25/2015 APF 10108.5 10109.5 9037.57 9038.53 1 L3-22 5/25/2015 APF 10109.5 10110.5 9038.53 9039.5 L3-22 5/25/2015 APF 10110.5 10111.5 9039.5 9040.47 L3-22 5/25/2015 APF 10111.5 10112.5 9040.47 9041.44 _ L3-22 5/25/2015 APF 10112.5 10115.5 9041.44 9044.35 L3-22 5/25/2015 APF 10115.5 10116.5 9044.35 9045.32 L3-22 5/25/2015 APF 10116.5 10117 5 9045.32 9046.29 L3-22 5/25/2015 APF 10117.5 10118 5 • 9046.29 9047.26 L3-22 _ 5/25/2015 APF 10118.5 10119.5 • 9047.26 9048.23 L3-22 5/25/2015 APF 10119.5 10120.5 9048.23 9049 2 L3-22 5/25/2015 APF 10120.5 10121.5 9049.2 9050.17 L3-22 5/25/2015 APF 10121.5 10122.5 9050.17 9051.13 _ L3-22 5/25/2015 APF 10122.5 10123.5 • 9051.13 90521 L3-22 5/25/2015 APF 10123.5 10124.5 9052 1 9053 07 L3-22 5/25/2015 APF 10124.5 10125.5 9053 07 9054.04 L3-22 5/25/2015 APF 10125.5 10126.5 9054.04 9055.01 L3-22 5/25/2015 APF 10126.5 10127 9055.01 9055.5 AB ABANDONED MIR ISOLATED REMOVED APF ADD PERF MIS ISOLATED BPP PULLED MLK MECHANICAL LEAK BPS SET OH OPEN HOLE FCO FILL CLEAN OUT STC CLOSED FIL FILL STO OPEN SQF FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR REMOVED RPF REPERF Casing / Tubing Attachment ADL0028322 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"Conductor _ 38 - 118 38 - 118 SURFACE 4040 13-3/8"72#L-80 71 - 4112 71 - 4015 4930 2670 SURFACE 33 13-3/8"68#K-55 39 - 71 39 - 71 _ 3450 1950 INTERMEDIATE 9834 9-5/8"47#L-80 37 - 9870 37 - 8808 6870 4760 LINER 862 _ 7"29#L-80 9620 - 10482 8570 - 9401 8160 7020 TUBING 9633 2-7/8"6.5#L-80 36 - 9669 36 - 8616 10570 11160 Tom= ' L3-22 FE D= MC�I/OY OY lY NOTES: ACTUATOR= BAKER KB.ELEV= 60' 13-3/8'CSG,68*,, H 70' I--1-x BF'ELEV= K-55 BTC, KOP= 3100' Mix Angle= 9 0 7200' D=12.415' Datum MD- 10028 2196' H2-7/8"CAM TRDP1 A-SSA TRSSSV,D=2.312' I ri Datum ND= 8900'SS 11 CHBAC.AL MANDRELS _•CONDUCTOR ? ST MD ND DEV TY FE VLV LATCH FORT DATE ' 1 2284 2284 0 KBMG-L DMI BK-2 0 03/31/87 Minimum ID = 2.250" @ 9654' GAA - 2-718" CAMCO D NIPPLE VLV LATCH� MD ND DEV N PEE MAN AN V LV LATCH FORT DATE ,I 2 2811 2811 4 IC-FM-0 DMY BK 0 03/31/87 13-3/8"CSG,72*,L-80,D=12.347" H4110' 3 5390 5063 36 MC-F7&0 DOME BK 16 05/04/07 9-5/8-CSG,47*,L-80 NSCC XO TO L-80 BTC H 4517' 1---w 4 7531 6754 38 MGFM10 DOME BK 16 05/04/07 5 8944 7942 24 MC-FM-0 SO BK 20 105/04/07 6 9475 8433 20 AC-FM-ID RKED tfRKP 0 03/31/87 6 - - 9582' —i9-5/8"X 2-7/8-BRW4 HB FKR 961rI9-5/8'X 7"TIEBACK,0=V TOP OF 7"LNR F— 9631' 4 —9631' --I9-5/8-X 7"8OT SHORTY HYD HGF,D=?' I - 9654' —12-7/8-CA MCO D NP,0=2.25' 2-7/8-TBG-PC,6.5*,L-80 BJE 8RD, 9666' 1-- 9666' H 2-7/8-YUIEC�D=2.441' .0058 bpf,D=2.441' I ' 9847' H7'MARKER JOIYT(20") Illif ? —I FISH-2-1/2'JU DOG SPRING(05/11/08) 9-5/8"CSG,47*,L-80 BTC,D=8.681" H 9869' I1 9868' '-7'MARKER JOINT(20') I PERFORATION SUMMARY REF LOG:LOT/Cf_ON 11/20/86 ANGLE AT TOP PERF:16' r,9942' Note:Refer to Production DB for historical perf dataI SIZE SPF MBRVAL Opn/Sqz SHOT SQZ 2-1/8' 'S 9942-10002 0 03/23/87 I 2' 6 10043-10083 0 05/25/15 2-1/8' 'S 10043-10126 0 03/23/87 I 2' 6 10092-10127 0 05/25/15 2-1/8' 'S 10141-10219 0 03/23/87 2' 6 10158-10173 0 05/25/15 2' 6 10196-10221 0 05/25/15 • Selective Shots FBTD 10436' 404444 ••�•�4�4�4.4 7'LMR,29*,L-80 BTC,-0371 bpf,ID=6.184- H 10480- 1 • DATE REV BY COMMENTS DATE REV BY COMMENTS LSBURrEUNIT 11/24/86 INITIAL COMPLETION 02/02/14 GFJ/PJC SSSV CORFECTION WELL: L3-22 05/28/06 RCT/PJC GLV CO 02/22/14 PJC REFORMAT DRAWING PERMIT No: 1861750 03/04/07 RL DATUM MD 06/22/15 DHS/JMD ADPERFS(05/25/15) AR Ib: 50-029-21663-00 05/04/07 BSE/PAG GLV G/O& I1ONS SEC 22,T11N,R15E,812'FNL&833' 05/07/08 DK/PJC TREE REPLACEMENT 05/31/08 BSEIPJC RSH(05/11/08) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies thOse items that were not scanned during the initial production scanning... They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ! ~ ~2- / ~ Well History File Identifier Organization (done) X Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Co/lor items: Gorayscale items: or Quality Originals: TOTAL PAGES: I~)(~ NOTES: ORGANIZED BY:OREN VINCENT SHERYL MARI~ [] Diskettes, No. [] Other, No/Type LOWELL DATE: [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) of various kinds Logs [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: BEVERLY BREN VIN~RIA LOWELL ReScanned {done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAGES: Quality Checked {done) RevlNOTScanned,wpd • • bp 0 BP Exploration (Alaska) Inc. Attn: well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 5i.ANNED AUG 3 2O1 v( Mr. Jim Regg -( Alaska Oil and Gas Conservation Commission ✓ 333 West 7 Avenue to`f5 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Lisburne 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 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) GPMA Lisburne 3 Date: 0308/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD 4' API # cement pumped cement date inhibitor sealant date L3-01 1890750 50029219590000 0.0 N/A 0.0 N/A 10.20 11/29/2011 1_3-02 1861540 50029216440000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-08 1831430 50029210190000 3.0 N/A 3.0 N/A 27.20 11/29/2011 L3-11 1852310 50029214520000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-12 1861610 50029216510000 Dust Cover N/A 0.0 N/A N/A 3/8/2012 L3-15 1852660 50029214760000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-18 1861670 50029216570000 0.0 N/A 0.0 N/A 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 .__.ji L3-22 1861750 50029216830000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-24 1861820 50029216700000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 PM 12/93 NA NA NA NA NA L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-31 1860340 50029215440000 0.0 N/A 0.0 N/A 8.50 11/29/2011 • Schlumberger NO. 4024 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ,- /~0 - I~S Field: Prudhoe Bay Well Job# Log Description Date BL Color CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 1 L3-30 11637115 PRODUCTION PROFILE 03/19/07 1 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 L3-12 11686732 PRODUCTION PROFILE 04/08/07 1 02·29C N/A EMIT & CALIPER IMAGE 04/17/07 1 OS 02-36 11637141 MULTI-FINGER CALlPE 03/14/07 1 F-16A N/A SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20/07 1 A-30A 11628762 MEM CBL 03/13/07 1 03·36A 11637326 USIT (CORROSION) 04112107 1 03-36A 11637326 USIT (CEMENT) 04/12/07 1 OS 17-05 11594492 USIT 04124/07 1 OS 03-01 11630462 USIT 03111107 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1 7 2007 BP Exploration (Alaska) Inc. 5(;ANNED MAY Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth --- Date Delivered: Received by: ~1Þ\Y .1\ 6 'IuU7 \~ 05/15/07 . . , . I""""'- ~ . . ¡/'r~'¡ t.:;'r:-' ,r¡, \ :::,-'¡:j f'r' ,\.. ¡ ¡ ;; '; ¡ i L_. ',', " ! " " ,... rÙ) ¡ \ I c..;'. \ ¡ 'lL ~--' L ..nj u -." ,,"', ,'_.., rr \ I r' WJlf ;';", i'! (;': (';;~'ìr'{ì !';'I 1;'.\ I ¡ !hi \..U I .',' If!: I'/jlll, (i"'\\."'L',¡ 11\: . I ". " ,\ Ii" LrJ Lb U\j ciD '~Lf\i ¡ ! FRANK H. MURKOWSKI, GOVERNOR I AI,J\SKA OIL AND GAS CONSERVATION COMMISSION / 333 W. 7'" 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 Anchorage, AK 99519-6612 I ~&-17 S- 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 of SVS 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 L1, 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 w.t th SVS test. Sincerely, 2J~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) /'""'-, ~ '/ t Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/27/2004 Unit/Field/Pad: Greater Pt McIntyre/Lisburne/L3 Separator psi: LPS 450 HPS 450 1181l1l.lJ)J818 _11- ... 1'II1I1lL11l1Jrl8J!AlIIJlJIJ -- Well 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 L3-01 1890750 12/4/1993 SI L3-02 1861540 450 350 350 P 6 P OIL L3-05 1851950 1/14/2003 SI L3-08 1831430 7/2/1994 SI L3-11 1852310 9/9/2003 SI L3-12 1861610 4/19/1997 SI L3-15 1852660 12/22/1996 SI L3-18 1861670 2/16/1997 SI L3-19 1852860 11/17/2001 SI L3-22 1861750 6/4/2003 SI L3-23 1853060 6/26/1995 SI L3-24 1861820 5/12/1997 SI L3-28 1890660 9/7/1993 SI L3-30 1861850 11/25/1996 SI L3-31 1860340 7/28/2003 SI Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service SSV Page 1 of 1 SVS PBU LIS L3 04-27-04.xls MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-175 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21663 4. Location of well at surface 812' FNL, 833' FWL, 5ec.22, T11N, R15E, UM At Top Producing Interval 1411' FNL, 917' FEL, Sec.22, TllN, R15E, UM At Total Depth 1479' FNL, 804' FEL, Sec.22, T11N, R15E, UN 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well Number L3-22 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 60' I ADL 28322 ALK 2320 12. Date Spudded 113.Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/04/86 I 11/20/86 03/30/87* 17. Total Depth (MD+TVD)Ii18'Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 10,480'MD, 9399'TVDI 10,435'MD, 9355'TVD YES [~ NO [] I2197' feet MD 22. Type Electric or Other Logs Run NGT/DLL, GR/CNL/LDT/EPT/Cal, CBT, CBL, Gyro 11. Field and Pool Prudhoe Bay Field Lisburne Bay Oil Pool 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL 1 21. Thickness of Permafrost 1900' (approx.) HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 1725# Poleset CASING SIZE WT. PER FT. GRADE TOP BOTTOM 20" 91.5# H-40 Surf 120' 13-3/8" 6 Surf 10,480' 8-1/2" 2350 sx AS III & 600 sx Top job performed w/150 790 sx Class G, 300 sx 300 sx Class G 3.0#/72.0# (-55/L-80 4110' 17-1/2" 9-5/8" 47.0# L-80 Surf 9869' 1 2-1/4" 7" 29.0# L-80 9631 ' 2-7/8" i 9668' C1 ass G sxAS I IS I & sqz w/175 Sx C] TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 9582' 25. SIZE 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9942'-10,002'MD 8876' -8934 'TVD 10,043' -10,-083'MD 8974'-9013'TVD 10,092'-1 0,11 2'MD 9021 '-9041 'TVD 10,116'-10,1 26'MD 9045'-9054'TVD 10,144'-10,172'MD 9072 '-9099'TVD 10,196'-10,206'MD 9122'-9132'TVD 10,211 '-1 0,219'MD 9137 '-9144 'TVD Perforated w/5 spf, 0° phasing DEPTH INTERVAL (MD) /AMOUNT& KIND OF MATERIAL USED See Well History dpl;e¢ 04/14/87. for Stimulation dataI, 27. ~1/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested. PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-AP (corr) Press. 24-HOUR RATE I~ 28. CORE DATA ass Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , ..... 0il & Gas Cons. Coi'".~.i';~!:'~:.:. :, , . (,'~..C', - * NOTE: Drilled RR 11/24/86. Perforated, stimulated & ran tubing 03/30/87. Form 10-407 Rev. 7-1-80 WC248 .'DAN I CONTINUED ON REVERSE SIDE Submit in duplicat, e~, 29. Top Zone 7 Top Zone 6 Top Zone 5 Top Zone 4 GEOLOGIC MARKERS NAME 30. ~ORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH 9925' 10,008' 11,142' 10,242' 8860' 8940' 9069' 9166' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion 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 ADDENDUM WELL: 12/21/86 3/12/87 L3-22 Arctic Pak w/300 sx AS I & 128 bbls Arctic Pak; tst OK. RU pmp to tbg head vlv, start press'g up; master vlv leaking. Instl cap & master vlv. Press up to 3000 psi; tst good (7 bbls diesel pmp'd). Drilling Supervisor '\ Dhle ~' December 18., 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60093 Well: L3-22 Field: Lisburne North Slope, Alaska Survey Date: November 26, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures Ni. Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 SF'ERRY-SUN WEI_L SLIRVEYING CF-~MF'ANY F'AGE 1 ANCHORAGE ALAF;KA ARCO ALASKA, INC. DATE OF SLIRVEY NOVEMBER 26, 1986 L:3-22 COMPLITATION DATE BOSS GYROSCOPIC SURVEY LISBURNE DECEMBER 01, 1':7'86. .JOB NLIMBER AK-BO-6OF)'F,:]: ALASKA ~i~E'Eg'"'" :B'[ii_E~"j~"iq'i.~?'""E:_"E'E'o': ........ ::: .......... EY~'F~'"~'~'~F:"'j:'~-' ................. L, iF:E R~.Yi?.RL.Hif!i5 EFj:-F;:E .................................................. : .............................. VERT-I-~_.'~-E '.=;ECT IL-IN F:ALCLILATED ALONG CLOSURE --IflE~i_-91.]RED TRUE SLIB-SEA COURSE COLIRSE DOG-LEG TOTAL VERT I CAL VERT I I-:AL I NCL I NAT I ON D I REE:T I ON '._:;EVER I TY REI_-:T~NGULAR L-:OORD I NA-I'ES VER'r I C:AL D[ 'H DEPTH DEPTH .......... DEG ...... Iq"i N .......... [)EOREES ....... DEG/i' (ii') ............ NCiRT'H':/SOI-iTi:~ ....................... E'~'iBT'/i~E'F-iT .......................... E;ECT I oiq ..... c) L~.-O0 -6c). O0 0 0 N O. 0 E O. O0 c). c)O O. O0 O. O0 100 200 -- 4(:)0 500 10o.00 40.00 0 5 N 51.19 E 0.09 0.05 N 0. o6, E 0.05 20o.o0 1.40.o_0 0 5 N ~..~9, o W O. 12 c), 17 N 0. (.],:,'-' E 0.05 'L'-iL"fO]_Si_5 :.~4:T.'i-:]]R) 0 10 S 13. :E:9 W O. 25 o. OE: N 0, 01 E -0.01 600 700 :_::00 ................ 900 .=;,:¢,:) o,'-, P;'7'", 99 0 .=; S 65.19 W 0 17 0 81 S c) 75 E 0 ':,'::' · -- .' .' · .' .' '-- ".- .. # · · '~ . · , ~ · mm ~-~ ~.-~ I-,':,':, '--;':;,/-,:::'-? '-?':'; 0 24 F; 4. c). "-'o 1 11 L--.; 0 45 E 6) 64 ................. c,_ W (3 ":-'"' 79':?. 99 739, 9'...-~ 0 19 S :_--:0.6c) W 0. i c) 1.61 S 0.08 E 0.37 -F:.F~',~'--:-.';'~.~ ,-'.~'-:,:-"F-~:/.~:~, O'" ':, c-27 80 W c.'.) 1/-, 1 '-'-,',:: S c') 13 W (') 2::: -- . . ~ . . m_~ ._m .. · .. ,. .- ." "-~ · · - · - m .- - .. m .. · 1000 'F, 9'?. '?'? 'iF,:'-:'.-'.>'. 'i)9 0 ........... :2:'il.' ................. S'" 45.10 ' 1100 .............. 1099.99 .............. 1"03 '? ~ "99 ................................... L)~ ............ .::~'" 4 ...................... .-,~'"'I'"':-'._-, ............ 4. c_)' N c_)' ........ c..)~' ,._>... ......................................... ~<'~''' ?'. ,:..a = ..i..?.:. ........................................... O' ....... ,:,;~' ._, = .................................................... W - ¢)'..:.'-' :-'~ ...... 'I-2i')'C~ '~]"~'~-:]~ ~-,'~:F-:.~-.c. ' .- -- __ ,.~..:,;, :~. 0 ~'0 S 20.1'-? W o. l'S' .~: 4:3 S 1 15 W -0 ="'" .'- - · .~. o.':, 3 9'~ '" 1 :_--:Oc') .......... 12'F'9. ':;:::' 123'F; .9~ cZ) '~C) ':'~, 1E:, 19 E C). ~.~ ..... o 1 16 W -0 43 14 ¢') 0 1399 ': ':' ':::::';~ 9 EF o ,-, ,-, - . .;~, 1-. _. · 0 11 ~, o, o¢.) E O. 15 4.. 44- L~ 1 . 04 W -0. ~.z.'-"-' -i-SKFO 1Zl:'---;~-~)--':"i-~,; 14:--:'F; ':>,¢,4":' 7" C~.:,,,: 11-, ':' 14.60 ld 0 12_' 4 84 S 1 c')::: W -cZ) 1 ':) . .... ~ ..._ · .. ~ .... ~', ,, - ._m . · ~ m . - m .. 16 cZ) (') ............. 1 ~ ........ '-? 9 ' 98 ................ 1 F; ::: ':,". ' ':,.. ,:,'~"'~ ........... : ~.':: .......... (]?':ii '" 1 '~' ................. :--:" ":361" 6' 9'-' W .......................... P '~" 1 o'-' ....................................... ._,='"'"'~" i~. ._-, _) ....... .:,~'~ ................................................ 1.._-:0~-'' ...................................................... W -c.)'"/33 .......... · _ ....................................... ~, £::~ ............. ;:',j ............................................................................................................ .. ........................................................................ ~,.,..~ ................................................................ .................. 1. 700 ........................ 1'~"99"~ gE: 1 &:--:9. ~:~!'~ . . ¢~F:' 20 .......... S ....... 18.89 1900 1R,:,o ~ '-"~"~ ~'"::' 0:'::::;;'.:~20 : ' S 17 ~'- ' . ~9 W 0 05 ,' 7 O0 :~ 1 ¢*.~ W -0.66 ~ :..~ 97 <.:.: :;::: . . , ....... . 'i:'':~'''''~ :' ': ..'5...0::~ 2c)00 19':~9.97 1Q"~'~ '..'~7i:~"<:->C.~":.. 11 ._, . .... ' "'-"--~'-L'5--: ~-'...Z .,i 7_'-l"~"ii"F y.._q~:Ti:~. '.-~-.'...'_'0:.::':.. ';'/:.:::j 0 11 E; 4.5. 0 ES O. 16 7.73 S 1. ':?L"] W --0.5::: ' ' ':, '? 00 .............. '.--' 1' 99"' 97 .................... 2 i :3 ?'""9 %~?' ......................... "'0 ............. t 'S ........................ '.:-; '"'"(:;4 "i' 9 '"' [-- ................................. 0"""i 4 ......................................... 7' ."'? ./:; '"' F.; .......................................... i ':'60 "'W ..................................... ""h ~" 1' 4 .......... 2:300 ............ :::: L.'.: 9':T/':'"? ~_; ....................... '-::.' 2 :_--: :.-.'~ ""9/-'(:.i!:',"' ............................ Ci ............ 5'1 .......................... N'""'7~'"i"'~:9"'"'E .................................... (i 'i'"~' g ........................................... 7' :" Ei 7 '""'S ......................................... iii' ';"'~; 4'"" W ............................................... /}" :'" :7' ;.:~ ............. 2'500 ;-,-'.600 270'U 28C) 0 2':?0() 4':/':" 5'4 .:,z~.:,c, 94 0 45 S 65 60 E O. 1'-' ':4 =' 2 12 E .....,..-._, .. ~ ~.. 4._,S., ,:,'-'. 6,1 2 .=i'-,, 9 94 ~" =' '-"--, ":" '? 4 4. 8 ....... ,:._,._-,; 94 c) 16 ".F_; 64 10 E 0 49 '" "q'-'':' .... :,. ,:...: .... ... E 4. SPERRY-:--;UN WELL SURVEYING C:OMF'ANY F'AGE '--' ANCHORAGE ALASKA ARCO ALASKA, INF:. DATE OF SLIRVEY NOVEMBER 26, 198/_-. L3-22 COMF'LITATION DATE BOSS GYRF~SE:OPIC SLIRVEY L ISBLIRNE ¢~ DEC:EMBER 01 ,' 1986 ,_lOB NUMBER AK-BO-/:,OC)9:3 ALAE;KA i;!i'~i'::'Eg"""'~ili'i~i'Fi'l"~iS"'"'~E'~9] ........ ~.- ..... ~5'""'~5'i5'"-~:"~"] ................. CIF'ERA TOR-MC:Cd_I I RE · . VERTICAL '.:-;EF:TION CALCULATED ALONG CLO'.::LIRE "'MEA'._:;LIRED TRLIE SLIB-SEA COLIR::';E COLIRL--;E DOG-LEG TOTAL VERT I CAL VER]' I C:AL_ I NCL I NAT I ON D I RECT I ON :_--;EVER I ]'Y RECTANGUI_AR COORD I NATES VERT I CAL [,' "I'H ..... DEF'TI-] ...... DEF"TH ........................ iSE'G ....... M'iN .............. I]EGRE'E_:; ................. hEi~'?"~iS'O ............ NiSR'¥iqTE;CiilITH ....................... E~iTT'w'i~i~i'Y ............................ E;Ei~::i:I ON ......... ............ =, I ._, 74 30 E .... o .-._. 10 :' '-"-' 2¢'~ 31 c~O .'::o 97 42 '-" '-' .... . -' . . . ...... · .,0o7,42 10 ~:.4 ::, 75 69 E '2,34 23.7/_-, t:, 41 02 E' 44. 62 · ':: 200 :319.=; 27 ':-' 1 '-'"' '--' '-'" ::::=: z c,. · _-,._, ~.7 13 1 ',.--.: 76 10 E '-"-' 75 E: /-,0,91 :; 6.5 09 · -- # ..' mm _ ~ · :}E~.ffPO :.:.:'29'--...'. 01 :_--:2:32.01 16. 14 S 76. ::-:'?, E :--:. 22 .'_:.:4.6:]-: S :--:5.4',3 'E '.-.-,Ci. :_--:2 :]: 4. 0 C~ ..... 5:387 '-' =' ......... ""'-'"' "' ............................ .... : ..... :,.:,...7 .::.:, 1 E: ............. 5'1 ....................... S-7:::,'"69'"'E .......................... 2'-'-'6'Z ................................... 40,"P.;j;-E; ............................... 'j.'"i"4"~"';?-'] ....... E .................................... :2:5o0 :2:4:--:1.29 :.:.:421. '2'.:.> ........ '21 ..... 10 .......... E; 7'P ./:,9 E ....... 2. :,35 ................. 47. :36' E; ................ 148'. :56 ......... O/.""" -;'~i='''''~ .................. :~'Pi'""'; ..... "~'~--':,F,-- -- ?;.-, ,:,/. c. · _, :, 00 .... ,7._',. 74 .:, .. 1 .--,. 74 .... .., .. S 80.60 E .-.':' 4 E: ...:,... ..... -, 186.0 :::,'.. · _',7OO 3/--,/_',4. 10 :3604 .10 27 4 :--; 80 . .=lO_. E .-': .49 /-',0. o'-'"',:, S .-..,_'""~'q. 2:--: ._7._,..' 09 '--"P '-' '-' 3 S 00 'q ='-'. .-,'-'/>':~...:'-'. 6~9., .... '"_.,=,'" .:, o 1 .... 5:'-.-¢ E ..'.-' 61 /-, ..... ::' 'q 4 .q .... 275 2 ('~ L~i'p00 40C) 0 4100 ...... 4300 4400 '.'.-:'. 17 74.90 ' S :--:25.60 2. '.:.)8 79.0::3 '.F; 3'79.31 1..,'"" 4. .6,/_-. !E 192.7:3 -- ":":'?i E :2 E: :3.00 4005 44 .................. :-:; 94:5 ~'"44 .......................... 34 ................... i ........................ :.--.;'"" E; 8 '-' ..... 0"'" E ............................ 0'~' 48 ................................... lei 51. "'56'"'"Ei .............................. 4:3 E;'~"01 ...... E ................................ 44. 2! · --;~"~ "'%-"~' ~ ' ' ')'" '-, ' " C: ~ 40~b. :::6 41..',:, :_--:6 '-"~' 56 S 87 3~, E 0 34 '-"--' · ._-,o .... --,..:,. 61 "" . _. o 4 ..' 0 86 E 4'? 7 · :::9 '" -' ,-.F, 5C~ E 1 24 o ,~ 4171.01' 4111.01 :--:4 o4 b ~ ....... . ,..,7. 10 =, .547.04 E ~._,~. 79 4 .~._,,:,. 41 41 '-~ 3 41 ,:, 4 '-'/' 84 o._-., ,],", ,=. /-, 0 ::: 48 E /-, I 0.20 .... -...- :, S . :3'P E 0, 64 ...~, ,. ,=, ........ 77 ..,~-! %.1 1:2' ~ 4500 4:2::_::5.70 4275· 70 34 46 E; 84, F:9 E O. '3'3 97, 6,3 S /_-,60.02 E 6 66, 81 ...............4.600 4417. o.--,; ..:, ........................ 4..:,'-"=-._, 7, '9:::. _ .......................... :q 4. ._,...":'Pi ................ ...,':' F:'4" '3':;'~'.. , . E ....................... c~'.. i9 ..... .............................. ~"i5')'--: .... · i' ib-:""'::!i .... .............................. 712~;'"'./-,'~-('"' ..... E.-' .................................. 7'.:;'--':'""...... · "--;"';'_ .,.. 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' 5:E:c~0 ..... 5394.':-..-':_:: ......... 5:3!--:4~'2:3 ............................ !3~ ........... !L::'~ ...................... :F;'"':--'::3~'19' E .................... 0.46 1A:.E:. 19 S 141 i. 2:2: E 141:q. 44 ................5900 5474./.:,4 .... ':",414.../.-,4 ................................. .:,6'"' ............. .~:._,:~' ~? ...................... .:,;~'"" "-"c:,._-,..-, ;'-'" "-';~ .................................... E 0.' ............................................................. 1/.:, 175. 12.' .S 1470.' '. 5:'/',. _ E' ............ ........... 1477 · 76 SPERRY-:F.;LIN WELL SI_IRVEYING COMF'ANY F'AGE ':' ARCO ALASKA L3-22 L I '._--;BURNE I NC. ANCHORAGE ALASKA COMF'UTATION DATE DATE OF SURVEY NOVEMBER 26, BOSS GYROSCOPIC SLIRVEY DECEMBER 01, 1986 ,_lOB NUMBER AK-BO-6OO'P:--: 19:_::6. -VER'T-I'~/tYL---.'_=TE~YTOg-i'T'A-Ei'_-TL]E'LAWED ALONG E:LdSL1RE TRUE SUB-SEA COLIRSE COLIRSE DOG-LEG TOTAL -"HEASUREI]-----~ERTICAE ' ' VERT I CAL 'INCL INATI'ON D I"RECT I'i.-.IN" :_--;E~E'r~Y ....... REC'TA'NG[ii_AR COORD I NATES VER]' IC:AL_ "TH DEF'TH DEPTH 'DEG M I N ......... DEGREE:--; .......... DEG/1'0'0 ............. NORTH/SOLI'FH .................... E;A.E;T 7I.~JE'S T .............................. '-':-;E L-.~T I ON .... 6000 6,1 O0 6,200 ,/_-: :_--: r30 6400 /:.,._,L)O ........... '6; E; O'O~---Z-';i]-27 ]'77 .... 59'E;'7".-77 --~'"' :._4 :.-: 36, ~-i~,W'-E 0 ~ 1 ":":' 1 -- . .,., ._, 6.7c)o 6,105 76, &oqF, 76 :_::8 :53: F; 81 69 E O. '-'= 240 . . · _ . - · ,_ · .", ~..! · 6,800 61 ""° 29 ' --. ,..-~ · 54 6,1 ''':"':' 54 0 :--'; 81 5 f"~ E 0.17 .,c 4 :: . - ,Z! ..., ~ · .. , · ..'_ .=., · ........ /-,'-.'~OC) ......... /-:f2/_-:'i '/"!?~: '?_~:2'('f1'-77:-: ....... ._,"s~-"',"~.'ql,..,. ... '---' E: 1 '~';YF'-E c), 14 '-'""'-' ....... ~., · ..... ." .J r-:, · 7000 /-,::::--:9 ......, 14 .... 6279, 14. :38 ...... 5-7 .......... t--.; 81; 10 E 0 .27 ........... 26:E:. 71 O0 ....... 641/_';. '? 1 ............... 6:_--:56'"".:.> ........................ """ .......... ':; .................... '-:'""'"'~ ......... ~-;' E (., 1 .:, ,':. 77, i .:,,:, ._ E, .:, c, 1..:,0 ..................................... ") ..... :-; .......................... :~"- - · :, 1 b:y5.49 E 1 '-7(')a 13 .'_--:7 '-' '-'='"" ':'9 E 19/-,::: 6:.--.: · ::., 1 ;..i,. ,_, .... · 'q'=" ':' 2019 57 E :20:31.5 () ._ ,..I ._{, . I E: 4 S 20 .:: 1.72 E 5:_' O'P 4.31 7 :::(') ¢) /:,._ 7 ..'S '-' ._7 =;I 6' '--~1 c, '";._ 7 ':-":' '-"-' - .r-l". .... 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I ............. --'----w'i ........... .~;.~ .. . - ......... ._ ,::, 1 O0 72i]7'.T0 7]-z[7-.. ,'~0'..... 1 ':' :BI'' I b:1 1 r')lll E 0 ~ :7--'i/';i::. 1. 2 E; 281 O" ':; 1 .-- 2::::31 ' 2--'(:' L----": 20 ("-) ......... 7 :'"'' ? 0' '~'' ':''"': ~'; .................... 7 ':2 :--:lO''';'" ::--I '55 ............................ ...... ;':'' ':: ........... ..'--'~ .......... ':; ...................... 0'''''''0''0'' ............ · i O' ....... E" ............................................. 1 ......... '0 ~:'' .............................. ::''77 ...... ...... '--'~ :'';"'--' ''''';<':' ...................... '''':--~';~';C' ........... 6 /--' .... =" 7 ................................ E 'a'''' ':' '~' C':--'''7' ...... e" 7 .... ::i: :300 ................ 737 ''5 '/'0 ':2'''': ............... 731 '=5 ..... ?' .............................. "'':'' .............. ~'~':"'~ ........................ '--;--''' .......... .... 0''' O0 '--'':' ':' 77' '''(/'''''[4: .................................... 'f':~70''';~ .............................. 5~i'(~i?''i'''i~:'5~f''''''i~; ........................ ~9'i''Ei'['72''--''E ............................. 2'9'~077--:5 .............. --"~'400 746'1" ''"''C--) '--~--~i)--i--Y:~'i5 3'0. ....... ' ..... ~"'--'' S '''TE'';'''?~'O E .0 · '~O'q'--' :::99__ ' ' "41 ':"'' 29/'':'q. . --" 09 --E 2o':~.'" 1 · 50-- ~----:5¢}0-- -- 7547"94 74E:7 "94 29, '--":'9 '--':; 76 ' ,.qO,... E 0"41 410'8i S '.'2016. · 5:'5:' E :]:041"21 ~ t"'¢'~¢'~ 76'>'--'''"--'" 21 ----'='''5 ':' 1 '--'':' 47 C; ''R ' /'J/'-- 421 S 3064 10 l--7 ..... ~''' 77 10 E 0 ''''':' ..... '-- CJ " 3¢'):--'':'~ · '::"':::: .... · .~- ' 0"', . .. ................. E:70'0 77'zi_'-:-Tf~i~ ..... 7-~T~_-2_'::.'10 2:~:' 10 ~F-' _~..._',R~ E 0.6,7 4:_::2.6,9 .'_--; :_--:110...=:.14· E 31:37../:.1 :--: L--.: 00 7L-': 11' '.'84 .............. 7751 ...... ,:,Zl. .......................... ~-":' 6'- ............. 4.:,:-' ..................... .:,'-; ...... 74. ~"~~,:, ::~ .... I.-_- 1.64 444.0" =-'"..., "'".:, ................... .:,'~' 1" "'~_, ...,. 20'"' E ............................ 3.18:3.5 8900 ........ 790i' ,'76~ .................... 7i--:4 i' ~" 7/_-,' .............................. 25 ................. i]--i ....................... E;-'72'~" fO'""E ..................................... J]"'799' .............................. 4.56'~'"2~4'"7S ....................... !~.i'i'~)'7'['"i"S[""E~ .............................. !~[L.--:27 ~" 0/--,' ........................ SF'ERRY-SUN WEt_I_ SURVEYING COMF'ANY F'AGE 4- ARC:O ALA'.--;KA, L3-22 L I '.:;BURNE ANC'HORAGE ALASKA INC, DATE OF SURVEY NOVEMBER 26, 1986 BFm,:'c' GYROSCOF'IC SURVEY COMF'LITATION DATE DECEMBER 01 ,JOB NI_IMBER AK-BO-/_-,C)09:.3 VERTICAL .=,E_.TION CALCULATED ALONG CLOE:LIRE TRUE SLIB-SEA COURSE COLIRSE DOG-LEG TOTAL ME~'.--;LIRED VER T--i-iZ:AL VERT I CAL I NL-:L I NAT I ON D I RECT I ON SEVER I TV RECTANGULAR I-:I-II_-;R O I NATES VERT I C:AL Dr' TH DEF']'FI DEF:'TH BEG M I N DEGREES DEG/1 c~O NORTH/g;OUTH EA'.:-..;T/WE:E;T '.--;EF:T I L')I4 ......... 9/_", 0 (] ................... 8 5 5 0 -' 16' .................. i3"4'?"Ci';"' 1'/.:. .... o._,o4 79 '-7,'7C)C} c,'",44 79 . 9:::("~("} 8739 79 ":'/',~'-"~ '79 ':.-,"F,'O0 --?-:F.:35.4.6 ::.'::775. 46 . . i ri 0 (] (3 :z:,:~ .-:: .1. '::'":' 8 :::: 71 8:2 ..... - .._ . ~_..'_ · 1 '.:~}-'=]'}¢') 7x.P'7.~782 ...... 79:~ :32 ..m.:., 37 S 70.'-" ,~) E I 61 469 =' '.q '-""'-' ........~ ._, ....... ,m :, z .:, 6 , z :~ E 326 ¢ . ,z~.....'z: 4~,~, ~:~ ~' .:,z7o 74 33c)7.30 .'910C) 8084.48 8024 42: '7,'R 31 S 68 30 E 1 01 ,z,.:, .-,.-,-, - 92 (-) c) 8176 37 8116 37 z 2 55 S 67 ':"z 4'z¢; ,:,,-, 24 '=' :3:345 - ~,7 E (3 62 .., 3:310 ':' 'z' - ,:~ :s: (-) (-).. ......... :::2A::: .79 :q2C)::: ..... .79 ~.~c:"s'0 S 67 . (').. E (')_. '?7 Pi12_ .8:3 S 3:34~:'._, . 61 .... "' 338:3 .2'-'c, ':~ ..... ~ 00 :3:361.9:3 .............. 8:301 ~ 9 "":, ........................... .:(.)'-'" ............ ..:, c,'~ ;''' .................... "".:, ..... 6._,~-". ''~-',:,'''r~:: ..... E" ................................. 1. Zr.~:'~ ............................. ._,.~ 7 .~- '-~ .............. 41 "':,::, ...................... .:,.:,;~;'"=;'~7c,.'~; '"""~s ........... 6 ::':' ............................. o4;:' ' ..... 1 c,."-' ........ 7t.)' ....... 19 :s:/., ...... ' ....S 64 6C)' EE 1 Z 3 .......... Pl... 41 . E:O .......... S :34 i 0. 21 .. _---' ................. 3452 . ('):'::: 19 7 ':::--2~'~" (') E 0 ~1 ~~=~ -'-' S :344-C) 21 " :3484 0':? _ o._, ::,65 60 E 0 ~ :' '- o :, .-,E, ;;. 4 "' . , c, S :34/-,9 57 - 17 46 S 64 ~(') E 0 '-"-' ~'-"~ ~'T~ '~ 3497 87 16 0 S 6,2 10 E 1.9(') 59~; 6,1 S .:,~;s,-:, 84 :z .-,, ..... , .. .................. _ ..... ..... 15 1 S 61. 0 E 1.02 6, C) 8.:35 S :3547.:37 :Z 35 0 ..... 100 .......9C12:E: Pq 4 ............. 8968' ............... 'Y;4 ............................. i"a ............ :~;:~: .................. ::;' '"'~;9 :' ~;~]"" E ........................ C)', 74 .......................... A2(). 95 "'-:3 ...................... .:,'-'~._, 6 '''~;~. ........... 41 E- ...................... .:,'-'6 ~:.'-"-'z .... 6 .... _,. 40 '-' 0200 91oS ~ '- ' : 1 :30 ~o q.-, · .., ;~ ;~ 06._,. ~i':~ '~ q 19 E 0 9 ~ 3590.04 E 3645 41 030c~ ,r;o.$,.-, ~=. 9162 95 c; ~l 89 ~ 3609.40 E 3666 63 . .. ~=~./~, . . 12 52 ..... 7. E O. 6,2 6,4._. 48 S . r14(30. . '- '-"-' 's~.z,.~ O.._,~'0 c~.s,/-,cl ........ SC} 1'"~ ._,.:,o~ o'-' 57 .19. E 0.37 6._S 7. z"'-'o S 2A27.97 ....... E 3A87 i 0 4 Et 0 'F':2:'F'E:. 59 ':7,,:':-::3:2:. 5'.:;' 1 '2 :2:2 S 57. 19 E cl. cZ}O 66,6 69 E; .:, :,4...'...:,7 E :.370:_--.:. 08 THE CALCULATION '~ .... " PRJE. EDURE..~ ARE BASED ON THE' USE ElF THREE 'DIMENSIONAL RADIUS OF CLIRVATLIRE METHOD. SPERRY-'.:-;I._IN WELL '.--;LIRVEYINC~ COMF'ANY F'AGE 5 ARCO ALASKA, ANCHORAGE ALASKA INC. DATE OF SURVEY NOVEMBER 26, 1986 COMPUTATION DATE L I SBI_IRNE A L A'._:;KA DEC:EMBER 01, 1986 ,JOB NUMBER Ak'.'-BO-600'.;c_:: F-.:.'E[['?' BU'Ei'i:iI Ni:<" E'[Ev, ..... & ........... -E]'i:'["i'~}'~i-]~9"~' ......... OPERA TOR-MF:GU I RE c-i INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEA._,LRED DEF'TH M. SI_IRED 1] E h' T H ]'RUE ::-;LIB-SEA TOTAL_ .. VER T I C:AI_ VERT I CAL ' REC:T~NGLii'"'AR E:OOR[~ I'N'A TES .......... N[i""'~'~"[i .......................................... (?'~'~"'~"ii~!'~'[ ........ : ........................................................................................................ .......... I]E F'TH ......... DEPTH ................... Nr~RTH/%--:OU'TFi ............... EAST/WE Si]' ......... D':f F'F ER"E Ni~!'~ ........................ i]!i]i'R ~ ~'i~.! T 'i-i~i'~j .................................................................................................................... :3000 2 '.-} '.-.-/8.80 fi: 9 '_-'-: ::-.-:. ::i: 0 4 ('~,(")0 '.-::9 :...-."2.4:2: :>': 86,:2.42 ....... 5000 ............... 4745 :-' '.;"1 ................ 4:6 :::'::5' :. 9'1 6, o 0 o 5554.59 54'P 4.5'P 7000 63:2: S/. 14 .6'279. 14 ............ 8000--71'2/_4;-Y6]1.' ............. 70 90C)0 7'.:.)'72. 82 79:_::2.82 10000 :.'::'? :2:1. :L:: 2 .... :38 '71. E: 2 ..... 1"04'8'0 ....... ':-Y;:~'¢~ ~-~'-=:°,.--/;-.:-~;-;'--~:-~.-~ 0.00 O. 01 O. 01 O. 0 :_3 0. (] 2_' ................... 1 ,'20 ................................................ 1"'." 1 7 ........ '77....~ ,_,':" 76" :38 ' ....... HE CALF:LILATIC. IN F'ROC:EI]IJF;~ES ARE BA'.::;ED ON THE IJSE OF THREE DIMENSIONAL RADIIJS OF CI.JRVATUI;tE METHf]D. ~=:PERRY-.SLIN WELL SI_IRVEYINI3 COMF'ANY F'AGE 6. ANCHORAGE ALASKA ARCO ALA~--;KA, INC:. DATE OF SURVEY NOVEMBER 26, 1986 LO-C,.:, ..... COMPUTATION DATE I_ISBLIRNE DECEMBER 01, 1'.-78E. ._lOB NLIMBER AK-BO-6(.')09::-: A L A°...E.;?¢iA.. .............................................................................................................................................................................................................................................. ?i~..E...L...;..-......Y_.B...!=!.!..---.!.~...!...N.E.~_.E....L.. [....V.._.__.= ...... ../--.:.¢.-'!_._ f.! .!_:!_. _F...T_.., OF'ERATOR-MCGLI I RE I NTERPRLATED VALUE:=; FF[R EVEN 10(:) FEET OF SUB-SEA DEPTH TRUE E:UB-SEA TOTAL Mr :.;URED VER T I rZ:AL VER T I C:AL .............. ~'E'i~!']=~'i~i~'i:)[:'~A R'' COi?'RD i NA'T'¢:"i.-:: .................... i~i'D'2'~r'~i] .......................................... O'.F:'R'~'~"i~!~'[~ ............................................................................................................................... DEr'TH .................... i]EF'TH .................... ]] E'i~":fi-~ ........................ ~'ifi'E'9'P ?"ifi'~?i?r H ....................... E~i~iT/WE'i~;':r ............ ~Ff'PP~E~:'i~E~ ......................... ;:.:.'!'6'~i ~'~ E:;~i'E"i"5~' ...................................................................................................................... ... 0 ('.). 00 - 6 C). C) O C). C)(:) 6C) 6 (). ()C) O. 00 0 · 01 16,0 1 ~f:q?.) 100.00 0. 1 I N 26C) ' 260. ()0 .......... 2C)(:). C)O ............................................... :.:.:6,(:) :::60. ()(.'.) :_--:C)0.00 (:)'11" ,.--; ..... ..... 46(:) ................... 460 :-' (:)0 ...................... ~'(:)0]' O0 O. 48 S 5/_-,0 5/:,0.00 500. (:)C.) 0.79 66 () /_-,/_-,0.00 6 C) 0 · 00 (:). 90 S ......... 760 76C). 0 C) 7()0.00 1.4:,-2 S (;). N 0. C) · 0. 860 9/_..,0 E:6. C.), (:)0 ......... E:()() ,0() ................................................. 1 ~ ........ :=:8 S ()(z) 0.0 C) (_') 1 7 0. O0 (.'.). 00 11 -_ 0.00 O. 0(:) 04 "E ........................................... 0'"~"'()'(~ ............................................................ i]~"'-"'il;~'(i (:)6 E (:). :=,z E 0. :::(') E 0.63 _ O. 19 - 0 ;'08"' ...... (:); 00 ...................... 0'0() ...................................... C). 01 O. O0 C.). (:)1 0.00 0 · C)1 O. O0 O. 01 0.00 ............ --[-i.'i-~:O 1060.00 1000. O0 2.6,2 ,.5; O. 69 W O. C) 1 0.0(:) i 1/-,0 116(:) · ()0' i 100 (:)0 ~ ':' '::' ~., ~.1 1.07 W 0.01 0.00 -- . · · 12/-,c) J. 26(') · (')0 1200 00 c,'" 76 S 1.24 W 0 (.~)'" 0 . C) 0 136, C) 1 :_--:6,0 · 00 130C). OC) 4.30 '.:: 1.07 W 0.02 0.0() .... 1460 ............... 1460:. '0(:) ...... , ............. 14'(:)(i ';' O0 ................................................... 2~"_""/:; 6; '"'E; ....................................... i ;' (:)::-:'""'W ............................................... '(5 ~'"02' ............................................................ ~i :-'(:i~:i .................... i ..c:;/~:'(.~J ........................ l' .~ '/-;'i'J: "'~'i 'i'i' ......................... i'~'Ci'i%'"~ Ci ................................................. ~,'7"i".::E'"'"'i:i ....................................... 'i'":""f"7"""~ ....................................... 'i'i':'"i:i': ........................................................... ~'-"E"'i':i'i"'-i .............................................................................................................................. ............ I'E:'~:'() ' ' 16/_-,C) (~'0f~.~E-.Ob ~,: ~, ..... ,~. .... 1 49 W 0 (:)2 O. O0 1760 17/.:,0 .... 00 1700 O0 ' 6"14 .c; , · 1.68 W O.t.:)'~'.c 0.00 · L:;F'ERRY-SLIN WELL SLIRVEYINI] Iz:OMPANY ANC~EF~-AGE ALASKA F'AGE 7 ARCO ALASKA. INE:. DATE OF SLIRVEY NOVEMBER 26, 19:_-:6 L3-22 ,,~OMPUTATION DATE L I SBURNE DECEMBER F) 1, 1 'PE:/_-. .JOB NI_IMBER AI-::.'-BO-/_-.<'.]~'.-.-,3 ALASKA I_-IF'ERA TI_-IR-MI_-:GI_I I RE INTERPOLATED VALLIEL:; FOR EVEN 100 FEET OF SLIB-SEA DEPTH TRUE SLIB-SEA TOTAL ME' "t_IRED VERI- I CAL VERI-I E:AI_' .... R'E DEl-. FH ................ DEF'TH ............... F..iEF'TH ...................... 1:3/:1 <:) 1860. 00 I :$: 00. 00 1 ?/_".1<:) I ? 60. 00 1. 900. 00 '2160 '2160.00 2100 ' 00 ";2E.C) ".'_.' 2/_-. c)C~C)220C. i ,' . _ ,,, _ _ . . _ _ .......... '2360 ................ 2 :'-i'E:()' ',"00 ................ 2>. L'-.' 00':"00 '2460 246 c). 00 2400, 00 z.._,60 '256C~. 00 2500. O0 2'-/::/:; o -- :2-&7/_-;L"F:'].]'i]i-- 6.77 S 1 '-"- . . .o~¢ W 0 0:3 O. OF) 7. :31 '.-., 2. £)4 W O. ¢ .:, O. 0£) 7.63 '.i:; :---:. ~ W O. 0:3 0. O0 .............. :_:: ,' 0:.-:: ' S I. ';':..'2 "W ...................... 0" (_'):3 ................................... O, 0(".) .................................................................... ~Y?'~F-!L--: 0 "':~ ..... ' I · .,:...:, E 0.04 0.01 ~:..., S 1.64 E 0.05 0.C) 1 e" 74 :--: '-" 77 E 0 06 C~.O:l. 'P.<.'.)4 S 3.31 E 0.06 0.00 ........... 29/_-;(i ............ 2'-.'~ ~; i'i-;:]')i'f--:" '.,::.;"'"~-'~ (.)<. TM 'i ........ 0¢)" ..... ~'7'.---"W._,'~"'--~"':¢:, ~-(i~-~i~--E 0 q4 0 ....... ~:.::'" .'2:061 :2:06, C), 00 ' .'7.-: 0 <7.) 0.00 22.02 S 2: 4, 20 E 1. 'P:3 1,09 -. :2:16:2: ,2:16, 0.00 :2:100 . O. 0 2'./-,_. 79 c.,'-' ..,'= ..:'-'. '-y.9 E o.'" 80 1. ,:,'-' 7 ..... ...... ::: 2/-, 6, ::: 260 (] 0 :::'2 ¢] <'~ 0 c) '-"-, F, - · :,...... 7 S 76, 74 E 6, 75 ':' 'P.=-i .... # ..... · . · # ~ .'_· .... 3371. 3:_--:/:,0, 00 .... :}.':300 ,~' 00 3477 ::-':4/_-,<_') '"00 ........... :2400 :"00 ........... ~585 ............. 35/_-;'0':'-00 ............... 3/-_,95 3660 · O0 3600, O0 .......................... :39 14' ".'E; .................. ;I/06 '. 02""E ................................... ~i 1"~'"17 .......................................................... 4'".'"4::;'r .................................................................................................................. ...................................... 45 "' ~-,,:-F"",-..' ......................... . ,=,,.:, .::, 140':'45'""E ...................................... 17":'"i'Z:; ......................................................... · - ~- ..... ~, .., 1 o .~ · 16 E- '.." ~, · 01 7 · ~:5 60 ~4 S '-"-,A '-~ · ~-_ 24 E . :.~._. 40 10 . .:,'""':~ SF'ERRY-SLIN WELL F;LIRVEYING C:OMF'ANY PAGE :F.: ARCFj ALASKA -:, ~ .':, .-) l_ I L:;BLIRNE ANCHORAGE ALASKA INC. DATE OF SURVEY NOVEMBER 26, 1986 COMPLITATION DATE DEF_:EMBER 01 · 1':786 ,_lOB NI_IMBER ALAF;KA KELLY BLI'._--;HINA ELEV. = /-, (D . (') ,FD FT. OPERATOR-MCGLI I RE ,- I NTERF'OLATED VALLIES FOR EVEN 100 FEET OF SUB-SEA DEF'TH -I'RUE F;I_IB-SEA TOTAL ME ' '--;LIRED ' VER'F I F:AI, {/ER T I CAL ................. REi]'!'T'A'~'(".~'[li'[]'~R .... C!i"i'~.~)RD'i"NA"~Ei~i ....................... ~'~i'::"i=i~'~i ......................................... (~)'E'~'~F'~"i~!'~'i~ ::::--,' A,-'-,, :376 A. 00 :3700.00 69.01 ':' 279./-, =' · _, _ ._, E 49.10 13.70 · _-,; .-.._,:_:.:86(~. oO :::SFDF) O0 76 '"/-, /- '= ...... ..<. _ S 32_ 9. · A. 6 E ..... ,. 6 7 15. .., ':' 7 4045 3'.:'..' 60. 00 4 ;t 65 4 ('I, 60. (:DO, 4286 41/:, O. 00 ............ '4407'- 42?_:;0 ?iO .~, .-,,.--~ . _ _ 4._ .-' .-. 4360 AA 4651 4460.00 ......... --477'2-- 4.57_-T0. O0 4500. 00 112.00 S 814. ::: 4 E :2:1:2. '.-? 2 21. :::() 4:::94 4,660. 5017 ..... 4 '7 d, 0. .......... 5'i'4'0 ..........· _,o,:,~'~'" '" "z ...... '5'Z~/_:; F~ ....... '1115 O------F,'21'A'Ff:]5i'f17.., .- -"~..~'~5,..,,:~ S1459 .._,~='" E 421 . 8 A. ~:4"' .40 6006 5 F, 6 A 00 5 ~ 0 F). 00 1 '"'-' - '-, F, ......... _~.26 S 1534.07 E 446.~1 ~.~.01 E;F'ERRY-E;UN WELl_ '.:;URVEYING C:OMF'ANY F'AGE '? ARCO ALASKA, L:=:-22 i'"'I]=;BURNE ANCHORAGE ALASKA INC. DATE OF SURVEY NOVEMBER 26, 1986 COMPLITATION DATE DECEMBER 01, 1986 ,_lOB NUMBER At.'.'.'-BO-6OF)'?F: I NTERF'OLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T R LIE S U B- E; E'A T ii T A L ME -'I_IRED VERT I CAL VERTICAL .......... RECTANG'IZIE'AR .... C:O'ORrii N~T'ES ................ MD'"'"T~'D .......................................... '~'T'~"i]i'~'i'" ................................................................................................................................... DE, fH ................. i.]EF'I'H ................... I]EP]'Fi ..................... NCiRTHT!--i-.aJTH ....................... E~q':--;TT~Ei_--;T ........... 'fFf'F'F'~EE'~i]!'~ ......................... i]!'O'E'K~'~ifi'¥'fifi~j ................................................................................................................... 6132 5/=,60. O0 5/=,00. O0 6258 5760. O0 5700.00 6513 5960. O0 5900.. O0 6,64.1 606 ~"~. 00 /=,000.00 ...... 67'/_-.9 .............. /.-.', 1'/=;'0 .' 00 ................ /_-, 8 98 6 '260.00 6, 200. ()('~ 702/=, /=,360.00 6300. O0 ......... 71'55 ...... 72;=:3 74. t 1 ........... 7539 7666 7792 656 C). 00 .6,500 ' 00 190 R'-'' . .,~,:, .3 1610 1/=, 200.51 S 1686.5:=: ::..' 1 i" 5'5 S 1764.09 ......................... ;-]:2:'=:';"'15'"'S ....................... 1842 15 .... ........... '-' :-"~' '" 02'S ............ ' 19'2 0 9':: ' a:' ..7., ._! . · . .~. :,::~ '_',. 74 E: --'2'~'i'i16';"7:'_:: ..... '-:'.=;:~. 68 'S 2(')80.6/_-, 270.95:3 2160.47 '."~-~" 21 c. '--"'.-"4(3 :::9 E 472 77 '-'= ~ .~.._1 · . ,. E 4,99. OC)_ 26 . .~'-"-'.z, E 5'.--26.0 0 :.27.0 0 · :. ._, c, 1.2:4 27. E: 6, E 6(F9 7 1-- ~"E.'''-T'' 47 · .. ~_~ · '- 666. ':":' ' :'- ...... 28.54 6660.00 6,60() OF) .............................. :_::Ci/:;';'"2'1 ..... S :.---': ::: 'P 9 . 1 ,::, :. 7._ '1~'8'4 ................................................................................................................................................ ................ ?-,7'E;Fi:'Fii.'i .......... ........ 7:;7('il'i";"i')'C! 317 .61 F; 2477 .5'P.._. E 779.41 27. F,':'.. ,_, b, IR b, (') 0 () b, :~l(') (') (')C) :'::2 ~ · ("l 3 '-' '-' = ~' '~/- ":' '=' · , .:, = ._,._, 4 :E: 4 E ::: C) _/:,. 2 9 · _ 7 S " ..... /-,9/-,F) ......... · 00 /-.'vC~(]._ .. . . O0 340, ~ ' 2/-,F=F~ :36 E :,.:.= · 44 ... ~,.o/. 14 ~ _ · . i_, ._ _ # ._, ,_, # ~ ..j ~-' ' - .. · ..... .'% ! / / n ..-'. J. [~. ,", ,.~, ~t n .", .-', ..' ._-,. ..._1 c,L)41 71/-.(] F)(] .... 71 (')0'. F)F) 3/:,2~" E:7-'S .............. ~'~-~-~~r~'~-"4 ....... = ............................... ,-,-."4 ~-,.-, ................................................... ...;w...l.O= .........,-,"]' 1/=, .Z,'-' ................... -~ ."/', ( ) .'-' ............................. ' ' ()()"" ......................... 7~( )( ) .'"'"" ...... ()()"" ........................................... .', 7-', .~-/' ':~0'"'",'~,_, ,_,~F' "" ,".._, ........................ ." ,-, 4/~,.'%'~; .................. ,-,/',J~ .................................................. E ~" ~":~. ( ).',. ......................................................................./',~ :%':%"-":~;'..' ~.. ,] o-:,,-,.-, 7~iT:i(i~ii:i----'?-~ii.~i(iT-(-i-(~ ;~F.=;,'','''~'r'~' '=' 2'Pry-.', .... 87 E q22,46 1~,E:1-' ;.., dr. ,_-~ d:% ~"2' .- n '-' 'r %-, , . ':'""- '-' ':, 9'~ 24 "' '93 ,.:,.:,.:4--,_ 7460 , O0 7400, 00 ,.,. ... .:, 2967 ,41 E . _, 61 I 6 . 1 ..., =' :=:F'ERRY-L=;UN WELL SLIRVEYING L-.:OMF'ANY F'AGE 1 0 ANCHORAGE ALASKA ARCO ALASKA, INC:. DATE OF SURVEY NOVEMBER 26., 19:--:6. L3-22 COMPLITATION DATE [-ISBURNE DECEMBER 01, 198/=. ,_lOB NLIMBER AK-BO-6OO'P3 ALA:S:XA ............................................................................................................................................................................................................................................................................................................................ i;!:EEE"2'"'"'BiJ'L~iFi"~"iGi~?"'"EE~'9": ........... --= 6i:~3t-F-F% OF'ERA TL-~R-MC:Ed_I I RE Ii-. I NTERF'OLATED VALLE.=, FOR EVEN 100 FEET OF SUB-SEA DEPTH MI ]I._IRED DE r' -i"H TRI_IE SLIB--SEA TOTAL "VER T I cAI, .... VER T I CAL ........... ~'~-~'i~!'~'~'i~i'~-~i'-i'i"'"AIR iE!'i~i'i~.i'~'~i"~["~i'~'~'i~i ........................ ~i'~i']~';~'i~'~i ........................................... ~'~";'~"~"~}'~'[' ................................................................................................................................. [IEF'I"FI DEF'TH NI]RTH / Si]I...I'FH EAST/WEST Ii I FFERENCE CIDRRECT I ON 75/-,0_ _. O0 7.:;00_ _, O0 412. :37 S :':-:(]2:--:,_. _, 22 E '-;~..,'='-" .,:, ?R'=,_ ..., 15, 27 76/=,0. O0 7600. O0 424, :--:4 S 3077..'_=:9 E 96E:. 29 14.41 %~'-~Ti] C)(') '7 7 (:)C) C)0 4 3 7. ":' 1 :.--.'::31 2'--* 7:3 E ") ::: 1 '-' ~"- ...... =,.._, 1:3. ~/- -/:_--: 60. 0 0 ........ -/:=: 0 0': '0 () .................................. 4 5 0"':'"4 5"' ' 'S; ................. .31 7 8 ~' :36:"" F ......................... 9 9'3 '"8:2: ...................................................... i'"JJ":' 9 iS: 7'?~,(') . (-)¢-) 7700. O0 4/-',4': :.E:4 "._--; ...... :_--:222. 71 "' [.=- ....... i004' 1 7 l'O': !_=:41 L--;F'ERRY-SLIN WELL ~--;LIRVEYING ROMF'ANY F'AGE ]. 1 ANCHORAGE ALASk'.A ARC'O ALASKA, INC. DATE OF SURVEY NOVEMBER~°~_,, 1¢¢'~.. ~._, L3-22 COMPUTATION DATE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ' '~: : TRUE SLIB"'"SEA TOTAL MF --.:LIRED ..... VER T I CAL ........ VERT I L':AL ............... R'EC~'TANiSLIE'AR ..... Iz:O'OR'D'I'N'P~'TE'.'_-'~ ..................... PI'I'i'""'T'9'£i ......................................... '9~R'T'~i"i]'~'i""' ..................... ' ....................................................................................................... FIE,. r H ................................. FIE F"I"FI ...................................... D'~'i~;T'i::i ........................ N'i:iR'T:H?'!~i'i:iij'.i'~i::i ....................... E ~'!Si'T'7'~'l~'i~:'~ ............ '~l-'t"~"~'~.'~'E'~'i]!'E .................... i~!'i~i'~'~'[~i~!'~"~"i:ii~' ............................................................................................................... I C')4,'_--:<] 73;:-~8. ='" ,.~.~,.::o .=,¢~ . . - .-, ;~ ;,.: .... -, ..... ' 666 6'~ S :3642.57 E 1081.41 0.9;5 ---TIqE i2AL]C'[.ILATI'ON F'ROCEDIiRES'""LISE' 'A" LINEAR' I'NTERF'OL..AT I'ON"BI~'T'IqE'EN THE 'NEAREST '20' "'FOOT"'MD ........ (FRr'iPI'"'RA'DII.':IS-OF"'"i]:I:-IRVATEIRE) ....... PO'I'IqT!--~ ...................................................................................................................................................................................................................................................... SF'ERRY-SLIN WELL SURVEYING COMF'ANY F'~GE 12 ARC:O ALASKA, INC. L :'::- 22 L I .'E;BI_IRNE ANCHORAGE ALASKA COMPUTATION DATE ' ~IEE:EMBER 01 -, 19:E:6 DATE OF SURVEY NOVEMBER ,_.lOB NLIMBER AK-BC~-6'OC)':.-,'3 ALASKA ....................................................................................................................................................................................................................................................................................... !?;.E....L:....L_Y._.B..!._..!.!:.-.!~.~N.!.._-.!__E.._L:..E_V__... = ,/.-,c). o0 FT. . OF"E RA TOF:;t-MF:GLI I RE ... INTERPOLATED VALLE._~ FOR SPECIAL SLIRVEY F'OINTS TRUE SUB-SEA TOTAL ME' --;HRED ..... VERT I C~'E ................ VERTIi~':AL .................. ~'R'iE'¥'~"i~ji].iOE-AR ...... Ci'=ii~i'~'D'i"i'Ei~'~Ei~i ............................................................................................................................................................................................................................................................................... DE, ,'H ............................... DE F,T H .................................. D~is'~ iq ....................... i~i~i'~'i:i:i'7'i:~i'i~ii2i'?'iq ....................... E P~i~i i:]WE'}S'~ ............................. 'i~'~:~';![~'~' ................................................................................................................. 7 ..................................................................... · . ~-- ~ ._'~._1..' ~ ~ ..._ 10 (')(')::: ,-,,- .-,c~ .-, . - _ ,:, "Y.:, :.. 54 8879.54 Z-,r)'9_.. . .:,6'E', ,:, ,., ..,.-, ~. ,,, c~.. . 1 ,_':: T'~_)]-;.-1-'-E' 9 (i E, 9 ............ 22: 9 C.)0':."',' :22 /-, '2/-, 24 ':' '-':, ._.=;, 7 c,.'-' .4.1 1 ~') ......... '..74. '2 ....... 91/-,/. · 4- 3 .............. 91 O, A" 'Zl. 3 ....................................... ?-, ._,":-' ,..,'=" ""Pi.._. _7'"'"":"._, ................. .._":: ._.=; ,:,,.. :::_ ,' :E: 7 .... 104 (")(-) '? :32(:~'. !50 '.::."" 26,(:i'. 5 ('-) 6.57 -' "'?F:"""S ........ :36. 27. 97 ': ...... "' r~v'''''¢'~''':'''''''~"*- *.:,.-, .': .:,.Z,* ..... 0:""':'-0 9294 · /-,/",_ - /:,61. 40 S 2:6,34. '36 1 ('} 4 :::'F) 9 '-" C,,,-, 59 9 ::: ::: :-q 59 ..... : .... : ........ 6'6'6 6'~" '.F..; '"" '-, '-' 57 ..... · -,E 4z.. =' TOP ZONE 7 _-. TOF' ZONE 6' .E TOP Z 0 NE 5 .E TF, F; ZFdqE 4 ............................................................................... 7_ .......SliR~EY [~EF'TFi F'i._LIG BAC:K I'D TOTAL DEPTH DRILLER STRATI GRAPHIC. SUMMARY. · DERIVED USING [;IL DEF'THS AND SPERRY '.SUN :SURVEY DATA COORD I NATES MARKER ....... MEASURED DEPTH TVD THICKNESS WITH REF. TO WELLHEAB BKB . . BKB ._,L B-.,EA VERT I CAL ( OR I G I N- 812FNL 833FWL · SEC 22 T 11N R 15E .... --T'OP~Z L-~Ell~_._, 10142 ~-~06'-2.22 900.9.22 626.24S'- 3578.41E TOF' ZONE 4 10242 .~ ~166.43 'P106.43 638.57S 35~8.37E PLUG BACK TD 10435 ~354.66 72t~4.66 661.40S 3634.36E ~A~~iR"ILE'R 104'80 'P:3'F~8.59 w::::::::, ~? 666.6'PS :3642 ~:- 2) COMPUTER F'ROGRAM - SPERRY SUN THREE DIMENSIONAL RADILIS OF CURVATURE,' DATA CALCULATION AND INTERPOLATION BY RADILIS OF CURVATURE ~PIPOTA-TIT3AI '"DA'TE " I' ' "el" DEC:EMBER 01, 1'~86 ,_lOB NUMBER AK-BJ-6OO.~ c, KELLY BLI.:,HIN.., ELEV. = 60 00 FT. I -500.00 TRUE NORIH 5CRLE LISBURNE L3-22 RK-BO-60093 INCH TO 500.00 / 500.0 RRCO RLRSKR, ]NC. NOVEHSER 26, 1986 ......... ~ ~.00 --500.00 I ~5oo. oo ~oo1~. oo~sol~. oo~oo1~. oo~o1~. oo 10480 --1000. O0 HOB 7[ ZONTAL. PAOJEiCT I ON' 0.00 5CRLE :- LISBURNE L3-22 RK-80-6009~ INCH TO 2000.00 / 2000.0 RRCO RLRSKR, !NC. NQYEHBER 26. [986 2000.00 4000,00 6000.00 8000.00 ~0000.00~ 9398. 59 10480 I 20C0. O0 4000. O0 VERT ~' C~aL PBOJ_FCT ~ ON LISBURRE ENGINEERING Date: 7-31-87 From: Pam Lambert Enclosed are the following: CH Finals for L3 Wells -'"'L3-18 Post Minor Breakdown Log 7-17-87 Run 1 5" Camco~F/c~ ~'~L3-18 Post Major Breakdown Log 6-27-87 Run 3 5" Camco "~L3-22 Production Profile Log 7-17-87 Run 1 5" Camco~ '"-L3-18 Collar Log 6-20-87 Run 1 5" DA CH Final for L1-21 ~-._3 Flowmeter Fluid Density Temp Log 6-24-87 Run 1 5" Camco CH Final for L2-30 ~ PDK~IO0 6-20-87 Run 1 5" DA -~~'~ CH Finals for L5 ~ L5-8 Temp GR Log 7-14-87 Run 1 5" Camco ~ "'L5-28 Post Stimulation GR Temp Log 7~13-87 Run ! 5"~Camco~~/~ ~ L5-28 Flowmeter Temp Survey 6-26~87 Run 1 5" Camco~/l Received by: Pleaae sign and return to~ P~ L~bert ~CO ~ INC~ ~' ~ 700 G Street ATO 477 Anchorage, ~. 99510 TRANSMITTAL # 283 LISBURNE ENGINEERING Date: 7-29-87 From: Para Lambert Enclosed are the following: CH Final for L3-22 Production Profile 7-17-87 Run 1 5" Scj Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M ~//{,~// EXXON _ STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 279 A~CO ALASKA INC. Date: 5-7-87 , , From: Para Lamber Enclosed are the followir~: CH Finals for Lisburne Wells Li-10 Temp Fluid Density Survey 3-23-87 Run 1 5" Camco L3-18 Collar Log 4-11-87 Run 1 5" DA L3-22 Prod. Logging Svs (H P Survey) 3-23-87 Run 1 DA L3-22 Collar Log 3-29-87 Run 1 5" DA L3-22 Collar Log 3-27-87 Run 1 5" DA L3-22 Collar Log 3-22-87 Run 1 5" DA L3-30 Collar Log 4-15-87 Run 1 5" DA L3-22 Temp/Fluid Density Flowmeter Log 4-23-87 Run 1 5" Camco AiJs~,a oH ~, uas coils, commissiorm Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 233 STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION COM. ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ,~ Plugging © Perforate~ Pull tubing COMPLETE Alter Casing ~ Other 2~ 2. Name of Operator ARCO Alaska, Inc. 3. Address Po0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 812' FNL, 833' At top of productive 1411' FNL, 917' At effective depth 1473' FNL, 813' At total depth 1479' FNL, 804' 11. Present well c°ndit Total depth: FWL, Sec.22, T11N, R15E, UM interval FEL, Sec.22, T11N, R15E, UM FEL, Sec.22, T11N, R15E, UM FEL¢ Sec.22~ T11N~ R15Et UM ion summary measured 10,480 'MD true vertical 9399'TVD 5. Datum elevation (DF or KB) RKB 60 ' 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L3-22 8. Approval number 7-~0 9. APl number 50-- fl79-71 10. Pool Lisburne 0il Pool feet Plugs (measured) None feet Feet Effective depth: measured 10,435'MD feet Junk (measured) None true vertical 9355 'TVD feet 12. Casing Conductor Surface Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 80' 20" 1725# Pol eset 120'MD 120'TVD 4073' 13-3/8" 2350 sx AS Ill & 4110'MD 4018'TVD 600 sx Class G Top job w/150 sx AS I 790 sx Class G, 9869'MD 8820'TVD 300 sx AS I & Squeezed shoe w/175 sx Class G 300 sx (;lass G 9631'-10,480'MD 8594'-9400'TVD 9834' 9-5/8" 849' measured , 7" true vertical 9942'-10,002', 10,043'-10,083', 10,092'-10,112', 10,116'-10,126', 10,144'-10,1 10,196'-10,206', 10,211 '-10,219' 8876'-8934', 8974'-9013', 9021 '-9041' 9122'-9132', 9137'-9144' Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 9668' Packers and SSSV (type and measured depth) HB pkr t~ 9582', & TROP-1A-SSA SSSV (~ 2197' Stimulation or cement squeeze summary iSn~e Co.mpletion Well History for stimulation data. erva~s treated (measured) , 9045'-9054', 9072'-9099' Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Wel 1 Hi story) Daily Report of Well Operations ,~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associ ate Engineer Date 4-t4¢~7 Form 10-404 Rev. 12-1-85 (Dani) SW02/22 Submit in Duplicate ARCO Oil and Gas Company '~ ,~' Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is scudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska lSlate Alaska I County. parish or borough North Slope Borough Field ILease or Unit IWell no. Prudhoe Bay I ' ADL #28322 I L3-22 Auth, or W,O. no. /Title AL0257 J Completion WWS #1 API 50-029-21663 Operator ARCO Alaska, Inc. Spudded or W.O. begun ~Date Complete/P erf/S t imulat e J 3 / 22 / 87 Cate and depth Complete record for each day reported as of 8:00 a.m. 3/22/87 7" @ ~0,480' thru 10,435' PBTD, Rn'g static BHP 3/23/87 3/24/87 I ARCO W.I. 50% JHour IPrior status if a W.O. 0130 Hrs. 3/25/87 3/26/87 3/27/87 A~cept rig @ 0130 hrs, 3/22/87. ND tree, NU & tst BOPE. RIH w/3½" tbg, displ diesel cap, POOH. RU DA, perf 10,211'-10,219' & 10,196'-10,206', 10,144'-10,172', 10,116'-10,126' & 10,092'-10,112', 10,083'-10,063', 10,043'-10,063', 9972'-10,072' & 9942'-9972' (no fluid loss). Make 3 GR/JB rns, POOH. RIH ~/HP/Temp/CCL to determine BHP. 7" @ ~0,480' 10,435' PBTD, Acidizing perfs Fin rn'g HP/Temp BHP, RD DA. MU PIP pkr, Hydrospring & RTTS w/bypass, RIH w/3½" tbg to 10,258'. RU BJ & Howco, tst lns to 4000 psi. Isolate perfs & stimulate same w/~0% HCL. /~i' 7" @ ~0,480' 10,435' PBTD, Load tbg w/nitrogen Ein stimulating perfs. Tbg flowing. Rev tbg capacity & set pkr. Tst ann to 2500 psi; OK. RU Otis, att to pull std'g vlv. Set dn @ 9605', POH & WL broke. Fsh WL & pull std'g vlv. RU swivel & flow viv's, tst ins; hydrospring failed. Re-tst backside to 2500 psi. Load tbg w/nitrogen. 7" @~0,480' 10,435' PBTD, Kill well Flow well un~il cln'd up. Prep to kill well w/brine. 7" @ ~0,480' 10,435' PBTD, Cln vlv's in pmp Bullhead 90 bbls brine dn tbg, open bypass &circ up gas bubble. SI tbg = 0 psi, SI ann = 30 psi. Circ w/9.2 ppg brine w/9.0 ppg rtns. SI w/50 psi on tbg & 150 psi on ann. Circ 9.4 ppg brine @ 3 BPM; losing 75 BPH w/9.1 ppg rtns. Bullhead 50 bbls LiteSal pill to perfs; did not bump. Pmp 25 more bbls LiteSal; pmp quit. Close by-pass & cln pmp. (Total fluid loss = 200 bbls) The above is correct IOate 4/14/87 For form preparation and distribution, 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 a!lowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data }n blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL #28322 Auth. or W.O. no. T t e AL0257 Completion WWS #1 API 50-029-21663 Operator A.R.Co. W.I. Accounting cost center code State Alaska IWell no. ~3-22 Spudded or W.O. begun Complete/Perf / S t imulat e Date 3/22/87 Iotal number of wells (active or inactive} on this~ Dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0130 Hrs. Date and depth as of 8:00 a.m. 3/28/87 thru 3/30/87 3/31/87 Complete record for each day reported 7" @~'i0,480' 10,435' PBTD, Displ well to diesel Pmp 75 bbls LiteSal pill; bypass & hydrospring plugged off. RI to 9945' w/pkr. RU DA, RIH w/perf gun, perf tbg w/6 shots @ 9604'-9607'. Att to POH; pkr hung up @ 9945'. RIH to 10,290', C&C hole; hole losing fluid @ .5 BPM. POH to 20' above TeL. Pmp 60 bbls LiteSal pill, sqz 24 bbls into perfs @ 1.5 BPM, 1000 psi. Stop pmp, hold 700 psi f/10 min. C&C brine, TOH, LD 3½" tbg. RU DA, make GR/JB rn. Chg & tat rams to 2-7/8". RU & rn 2-7/8" prod string. SSSV @ 2197', HB Pkr @ 9582', TT @ 9668'. Set pkr. Tat tbg to 2500 psi, tat ann to 1500 psi. ND BOPE, NU & tat tree to 5000 psi. Displ well w/diesel. 7"' @r10,480' 10,435' PBTD, RR Fin displ'g well w/diesel, tst SSSV. RR @ 1200 hrs, 3/30/87. Old TD New TD PB Oepth 10,480' 10,435' Released rig Date Kind of rig 1200 Hrs. 3/30/87 Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature q~~._ Date 4/14/87 ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO ALASKA INC. LISBURNE ENGINEERING Date: 2-9-87 From: Pam Lambert Enclosed are the following: OH Finals for Lisburne Wells "'- L1-2 Mudlog 9-2-85 NL Baroid ~Ll-14 Mudlog 7-13-85 Westlog ~L2-3 Mudlog 11-4-85 NL Baroid ~ L2-21 Mudlog 11-26-85 NL Baroid ~L2-25 Mudlog 1-30-86 NL Baroid ~L2-33 Mudlog 2-28-86 NL Baroid ~ L3-2 Mudlog 9-9-86 Westlog ~L3-5 Mudlog 9-18-85 Westlog ~ L3-11 Mudlog 10-25-85 Westlog ~ L3-22 Mudlog 11-18-86 Westlog ~ L3-19 Mudlog 12-19-85 Westlog ~ L3-30 Mudlog 12-31-86 Westlog '~ L5-4 Mudlog 1-20-87 Westlog '"'"'~,LGI-2 Mudlog 8-7-86 Westlog LGI-6 Mudlog 6-20-86 Westlog ~LGI-8 Mudlog 5-19-86 Westlog West og Please sign and return to~Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM TRANSMITTAL # 167 CENTRAL FILES Gas Cons. commission Anchorage ARCO ALASKA LISBURN]~ gNGINgF, RING Date: 2-5-87 From: Para Lamber Enclosed are the following: CH Finals for Lisburne Wells ~L3-2 Collar Log (to set packer) 12-16-86 Run 1 5" DA ~"'"L3-2 Collar Log (for perforating) 12-16-86 Run 1 5" DA ~L3-19 CET 3-11-86 Run 1 5" Sch ~ L3-19 CBL 3-10-86 Run 1 5" Sch (CBT) ~"'~L3-22 Acoustic CBL 11-25-86 Run 1 5" DA '~L3-24 Acoustic CBL 12-24-86 Run 1 5" DA LGI-6 7-9-86 Run 1 5" Sch (CBT) '~LGI-6 Completion Record 10-28-86 Run 1 5" Sch LGI-~ GCT Directional Survey 7-9-86 Run 1 5" Sch (recomputed) Received by: ka 011 & Gas ns. Commission Anchorage Please sign and return tot Pam~ambert~/ ARCO 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 162 STATE OF ALASKA ALASKa, ,.)IL AND GAS CONSERVATION COMM.,.,,clON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abapdon _ Suspend - Operation Shutdown X Re-enter suspended well -' Alter casing Time extension- Change approved program _- Plugging- Stimulate- Pull tubing- Amend order ' Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0o Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 812' FNL, 833' FWL, Sec. At top of productive interval 1320' FNL, 1000' FEL, Sec. At effective depth 1387' FNL, 782' FEL, Sec. At total depth 1393' FNL, 769' FEL, Sec. 22, TllN, R15E, 22, TllN, R15E, 22, T11N, R15E, 22, T11N, R15E, UM UM(Approx) UM(Approx) UM(Approx) 5. Datum elevation(DF or KB) 60'RKB 6. Unit or Property name Prudhoe Bay Uni t/Li sburne 7. Well number L3-22 8. Permit number 86-175 9. APl number 50-- 029-21 663 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4073' Production 9834' Liner 849 ' Perforation depth: measured 10. Pool Lisburne Oil Pool 1 0480 'MD feet Plugs (measured) None 9400'TVD feet 1 0435 'MD feet Junk (measured) None 9357'TVD feet Size Cemented Measured depth 20" 1725// Poleset 120'MD 13-3/8" 2350 sx AS I II & 4110'MD 600 sx Class G True Vertical depth 1 20 ' TVD 401 8 ' TVD 8820'TVD 9631 '-10480'MD 8594'-9400' None true vertical None Top job w/150 sx AS I 9-5/8" 790 sx Class G & 9869'MD squeezed shoe w/175 sx Class G 7" 300 sx Class G Tubing (size, grade and measured depth) None None Packers and SSSV (type and measured depth) Description summary of proposal WELL HISTORY Detailed operations program _ BOP sketch - 12.Attachments 13. Estimated date for commencing operation June, 1987 Date approved 14. If proposal was verbally approved Name of approver SA/186 Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &//~/'~,/y,_Y ~I/_/J/A_~ Title A sso c i ate Engin der ~/' Commission Use Only (DAM) Notify commission so representative may witness / Approval No. -- Location clearance t on Form No. Commissioner the commission ua[e /.: .. Conditions of approval __% Plug integrity - BOP Test ~%.,¢V~roved f_r~y ~eturn~d . Approved by ~ [8~[ ~' ~ VD Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company ~, Well History - Initial Report - Daily Alaska Slope Borough Alaska I'-ea~e °~ ~': ADL ~28322 Prudhoe Bay I !T~t!e Auth. or W.O aD AL0257 Drill Rowan #41 AP1 50-029-21663 Opera[or ARCO Alaska, Inc. Spudded or W.O. begun Spud *~co ~ 50% Oale IHour P?i°~ stalus ii a &/ O 11/04/86 I 1200 Hrs Oate and depth as of 8:00 a.m. 11/05/86 11/06/86 11/07/86 11/08/86 thru 11/10/86 Complete record for each day reported 20" @ 120' 1600', (1480'), Drlg Wt. 9.1, PV 7, YP 36, PH 9.0, Sol 5 Accept rig @ 0900 hfs, 11/4/86. NU diverter syl. Spud well ~1200 hfs, 11/4/86. Drl 17%" hole to 1600'. '~ 20" @ 120' . 3146', (1546'), RIH Wt. 9.4, P~ 8, YP 23, PM 8.9, WL 2.5 SO]C~'~.'~- Drl, DD & surv to 3146'. 2712', Assumed vertical 2858', 4.1°, S60.Sg, 2858 TVD, 4.87 V~,-2.57S, 4.5&~ 3015', 8.3~, S74.2E, 3013.92 TVD, 21.26 rS, 9.08S, 20" @ 120' 4120', (974'), Rn'g 13-3/8" csg Wt. 9.2, PV 9, YP 18, PM 8.9, WL 2,5, Sol 6 Drl f/3146'-4120', 15 std short trip, CBU, POOB. RU & begin rn'g 13-3/8" csg. 3229', 13.3~, S78E, 3224 TVD, 61.15 rS, 18.71S, 59.06E 3f~l', 23~, S81.6E, 3576 TVD, 178.85 VS, 38.625, 175.09E ; 33.8~, S89.6E, 3968 TVD, 395.40 rS, 59.23S, 390.94E 411o' ~~ (z~59'), ~ w/~it ~t. 9. I', PV 7, YP 14, PM 9.9, WL 14.2 Sol 6 Fie rn'g 99 its, 13-3/8", 68#, K-55 BTC csg w/FC @ 4026', FS @ 4110'. Cmo w/2350 sx AS III & 600 sx C1 "G" w/2% CaCi?. Displ using rig pmps, bump plug. Perform 150 sx AS I top Jo§. ND dtverter. NU & tat BOPE. PIE, DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 12¼" hole to 6279', DP twisted off. TIE w/fsh'g tls, engage fsh @ 2615', POOH & LD fsh. Chg out BRA& RIH. 4331', 34.4°, S86.5E, 4201TVD, 552 VS, 65S, 548E 4954', 35.2~, S86.1E, 4713 TVD, 906 VS, 91S, 902E 5293', 35.3~, S85.4E, 4990 TV]), 1101VS, 106S, 1098E 5908', 36.4~, S84E, 5489 TVD, 1462 VS, 138S, 1457E The,/~l~ve ia correct For form preJ~'~tion ~-d dist--, see Procedul, l~'Menual, Section 10, Drilling. Pages 86 an(3 87. Date ITitle Drilling Supervisor AR3B-459-1-D Number all daily will hlltory forml consecutively II Ihly Itl I~rlOirld for alch wi . Pag~ no. ARCO Oil and Gas Company (> Daily Well History--Interim Alaska North Slope Borough Lease ~ ',Jn,~ .CDL ,.?28322 Alaska Prudhoe Bay Da.'.e aha deoln as of 8:00 a.m. 11/11/86 [Com~ie[e recom for each Jay while cr;;;,ng or .~'Or,~over ,n orogress 13-3/8" @ 4Il0' thru 11/12/86 11/13/86 11/14/86 11/15/86 thru 11/17/86 11/18/86 8110', (1831'), Chg BHA Wt. 9.5, PV 9, YP 7, PH 12.7, WL 6.8, Sol 8 Drl & surv 12¼" hole to 8110'. 6185', 37°, S86.3E, 5711 TV]), 1626 VS, 152S, 1621E 6979', 38.7°, S81.9E, 6335 TVD, 2117 VS, 205S, 2110E 7164', 38.8°, S82.3E, 6479 TVD, 2233 VS, 221S, 2224E 7472', 38.3°, S82.6E, 6719 TVD, 2425 VS, 246S, 2415E 7842', 36.8°, S81.6E, 7013 TVD, 2651VS, 277S, 2638E 8055', 35.7°, S83.3E, 7184 TVD, 2777 VS, 293S, 2763E 13-3/8" @ 4110' 8930', (820'), Drlg Wt. 9.5, PV 9, YP 9, PH 12.6, WL 5.6, Sol 8 Drl, DD & surv to 8930'. 8306', 30.8°, S77.7E, 7394.05 TVD, 2914.18VS, 316.06S, 3899.07E 8794', 27.1°, S78.0E, 7820.90 TVD, 3150.05VS, 365.51S, 3130.20E 13-3/8" @ 4110' 9447', (517'), Rm to btm Wt. 9.7, PV 8, YP 4, PH 11.9, WL 6.0, Sol 9 Drl, DD & surv to 9447', POOH. RIH, rm 120' to btm. 9070', 23.2°, S71.OE, 8070.68 TVD, 3266.34VS, 396.83S, 3243.14E 9377', 21.1°, S67.8E, 8355.01TVD, 3379.45VS, 437.55S, 3351.46E 9-5/8" @ 9869' 9886', (439'), DO FS Wt. 9.4+, PV 5, YP 3, PH 11.9, WL 6.6, Sol 8 Drl & surv Co 9886', short trip, CBU, POOH. RU & rn 237 jts, 9-5/8", 47#, L-80 BTC& NS-CC csg. Lnd on hgr, unable to energize pack-off. Cmt w/150 sx 50/50 pozz CL"G" & 640 sx CL"G". CIP @ 0145 hrs, 11/16/86. Att to pull pack-off w/o success. ND BOPE. Chg 9-5/8" hgr pack-off. NU & tst BOPE to 5000 psi. RIH w/8½" BHA to FC, press tst csg to 3000 psi; bled to 1200 psi in l0 min. Drl plugs & FC. Drl FS. (FC @ 9781', FS @ 9869') 9621', 19.1°, S67.5E, 8584.14 TVD, 3460.82VS, 469.43S, 3429.01E 9821'. 17.9°, S65.4E, 8773.80 TVD, 3522.06VS, 494.79S, 3487.19E 9-5/8" @ 9869' 9886', (0'), LD 5" DP Wt. 9.4+, PV 6, YP 4, PH 7.2, WL 12.2, Sol 8 Drl FS. Conduct formation tst to 12.7 ppg EMW. RIH w/3½" DP, sqz 9-5/8' shoe w/36 bbls (175 sx) 15.8 ppg C1 "G" w/.8% D-60 & .06 gal/sx E-2009 cmt w/final press of 2080 psi, POOH. PU drlg BHA, RIH to 9425', LD 5" DP. Thea,~ve is correct Drilling. Pages 86 and 87 · : Date ITitle AR3B-459-2-B Drilling Supervisor Number all dally well hlalory ~orms consecutively as they are prepared lot each well. [Page2~o ARCO Oil and Gas Company (> Daily Well History--Interim ~orth Slope Borough ] Alaska ILease or Unit !.'.e ADL ~28322 ] L3_2~ Alaska C:e:d ?rudhoe Ba' as of 3:C'.C a.m. 11/19/86 11/20/86 11/21/86 11/22/86 thru 11/24/86 Comoiete recoro for each cay ,~nl;e ~rq]mg or .',or.~o.er m =rog'ess 9-5/8" @ 9869' 10,242', (356'), Drlg Wt. 9.3, PV 5, YP 14, PH 12.4, WL 21.8, Sol 9 Tag cmt @ 9540', drl hard cmt to 9812', CBU, tst csg to 3000 psi. Drl hard cmt to 9886' + 10' new formaton to 9896'. Conduct formation tst to 12.5 ppg EMW. Drl to 10,242'. 9-5/8" @ 9869' 10,480', (238'), POOH Wt. 9.3, PV 5, YP 4, PR 11.8, WL 14.8, Sol 5 Drl 8½" hole to 10,480', short trip, CBU, POOH f/logs. 9-5/8" @ 9869' 10,480', (0'), Prep to rn lnr Wt. 9.3+, PV 5, YP 7, PH 11.4, WL 13.4, Sol 5 Fin POOH. RU Schl, rn NGT/DLL/GR/CNL/LDT/EPT/CAL f/10,475'-9869', rn CBT f/9869' to 100' above Sadlerochit. RD Schl. Make wiper trip. 7" @ 10,480' 10,480' TD, 10,435' PBTD, ND BOPE 9.4 ppg NaCl Brine RU & rn 21 jts, 7", 29#, L-80 BTC csg w/Tieback slv@ 9618', TOL @ 9631', LC @ 10,311', FC @ 10,436', FS @ 10,480'. Cmt w/300 sx C1 "G" w/.6% D-79, .8% D-112, .25% D-65, .06% gal/sx E-2009', .05% gal/$x M-45 & .15% D-13. Displ using rig pmp, bump plug. RIH w/8½" bit, drl cmt f/9252'-9618', circ, POOH. RIH w/6" bit, CO inside lnr to LC. Circ, tst csg to 3000 psi. DO LC & cmt to FC, cite, tst csg & lnr to 3000 psi. Displ to brine, POOH, LD DP. ND BOPE. The above is correct Drillin~ Supervisor Drilling, Pages 86 and 87 AR3B-459-2-B las hey ate preparec~ for each well. ARCO Oil and Gas Company,r'~' Daily Well History- Final Report =~str2: !z:.- ! :- z-_.. ~- : ... Alaska , :;or~h Slope Borough i .R:aska Prudhoe Bay i ADL ;;28322 ! 23-22 Auth. orWO :~o Ir.~ AL0257 Drill Rowan #41 API 50-029-21663 Operator ! A R Co W i ARCO Alaska, Inc. i! 50% Spudded or W.O. begun I Date Spud I 11/04/86 c Otal number of ,veils ~ac:lve pst cenler Dnor tO pluggmg and abandonment of !his well Hour Pr,or t200 Hrs. Date and depth as of 8:00 a.m. tt/25/86 Complete record for each day reported 7" @ 10,480' 10,480' TD, 10,435' PBTD, RR 9.4 ppg NaC1 Brine NU & tat tree to 5000 psi. Pull BPV. Pmp 90 bbls crude f/freeze protection. RR @ 1200 hfs, 11/24/86. Old TD New TO PB Depth 10,480 ' Kind 10,435 ' Released rig Date pi rig 1200 Hrs. 1/24/86 Rotary Classifications (oil. gas, etc.l Type comple.on (single. dual. etc.) Oil Single Producing method Oflicial reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day ,. Pump size, SPM X length Choke size T.P. C.P. Water % GOR Grswty Allowable Elfective date corrected ?e~j~ve is correct Dam [Title see Procedures Manual, Section 10, Orilling, Pages 86 and 87. AR3B-459-3-C Number afl daily well history forms conllcullvely as they are prepared for each well. iPage no. Ohrl~o~ 04 A~llh~l'dle~cl~l~ff'ty LISBURNB ENGINEEKING Date: 12-19-86 From: Para Lambert Enclosed are the following: Magnetic Tapes for Lisburne Wells ~--~ L3-12 OH LIS Unshifted 10-8-86 Run 1 Tape Number 72108 Sch "' L3-12 OH LIS Shifted 10-8-86 Run 1 Tape Number 72108 Sch ~ L3-22 OH LIS Shifted 11-20-86 Run 1 Tape Number 72091 Sch Received by: & Gas Cons. Commission Please sign and return to~Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 125 ARCO ALASKA INC. LISBURNE ENGINEERING Date: 12-18-86 From: Pam Lamber~~~x.~k Enclosed are the following: OH Finals for L3-22 CBL/CBT 11-20-86 Run 1 5" Sch Cyberlook 11-20-86 Run 1 5" Sch DLL/SGR 11-20-86 Run 1 2"&5" Sch EPT/GR 11-20-86 Run 1 2"&5" Sch Natural GR Spectroscopy 11-20-86 Run 1 2"&5" Sch LDT/CNL (Raw) 11-20-86 Run 1 2"&5" Sch LDT/CNL (Poro) 11-20-86 Run 1 2"&5" Sch Oil & Gas Cons. Commission Anchorage Received by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D &M STATE- EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 122 AKCO ALASKA INC. LISBURNE ENGINEERING Date: 12-1-86 From: Para Lambert Enclosed are the following: Magnetic Tape for L3-22 OH LIS Unshifted Run 1 11-20-86 S. ch ~o 3 ~c~c/- .~ -~e ~ ~ ? ~~ ~/~ ~~ Received b _ i.i~ ~, ~1 ems ~ "r!t~_~. ~~ L%/amb~r t0 ~ ....... /'¥";;~'~'~'00 G Street ATO 477 ~chorage, ~. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 110 .,=MORAIV-qUM THRU: FROM' Statr of Alaska OI~ ~ GAS CONSERVATION COMiMISg~ON C] hatterton DATE: November 20, C~a~an. ~ ~ RLENO.: D.ADA.61 Lonnie C. Smith ~ q" Co~issioner / ~ ~'~ TELEPHONE NO.: Doug Amos Petroleum. InspeCtor 1986 SUBJECT: BOP Test ARCO PBU L3-22 Permit No. 86-175 Lisburne Oil Pool Friday,_ November 7~.j1986: After witnessing the safety valve retest at ARCO PBU, I traveled 'to ARCO's PBU L3-22 location to stand by for the BOP test. Satu~rday, November 8, 1986: The test con~nenced at 6:30 a.m. and w-~ conc-----luded ~'t 8':30 a.m. There were no failures, and I filled out an AOGCC BOP inspection report which is attached. In sugary, I witnessed the successful BOP test at ARCO PBU L3-22 Lisburne well. Attachment 02-001 A ( Rev 10-84) -. -'i:;i?} .:\~L STATE. OF ALASKA ': ALASKA 0~i&:'GAS CONSERVATION COMMISSION '~W~B.:'~'~'~.E. Inspection Report Operator '/~--~-C~ ~, '. c ,-5 - z z ~' ' ' "1! IJ 'R- '"' .... Location: Sec~T ]~M M,~, Driliin~ Contractor ~~ ~ Ri Location, General ~ Well Sign D~. General Housekeeping ~ ~ Rig Date. / pre en a ve 7' Set ' ACC~ATOR SYST~ Full Charge Pressure Reserve Pit Mud Systems TriP Tank Pit Gauge F1Ow Monitor .. /- i ,~-~: . .: -: ;/./:'~i . ~...: . ~nular Preventer. Choke LSne Valve~"~ ~ Check Valve Visual Test Results: Failures Test Pressure 5;, ~00 ,? psig Pressure After Closure Pump incr. clos. pres. 200 psig psig min ~ sec. Full Charge Pressure Attained: ~ min %~-sec. Controls: Master psig Remote O~ Blinds switch cover Kelly and Floor Safety Valves. .:'.~,,~..:...,.. Upper Kelly / ~Test Pressure ~, ~_~ Lower Kelly I ~Test Pressure tt Ball Type / ~Test Pressure ~t Inside BOP / ~Test Pressure Choke Manifold ~ ~est Pressure No. Valves / No. flanges Adjustable Chokes Hvdrauically operated choke Test Time ~ hrs. Repair or Replacement of failed equiPment ~O be made within Commission office'notified' If days and Inspector/ Remarks: :.. .. Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector October 30, !986 ~-'~r. T. P Oostermoyer Regional Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 _Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit L3-22 ARCO Alaska, inc. Permit No. 86-175 Sur. Loc. 8!2:FNL, 833'F~, Sec. 22, TllN, R15E, Btm~hote Loc. !369'FNL, 664'FEL, Sec. 22, TI]N, R]5E, Dear Mr. Oostermoyer: Enclosed is the approved application for permit to drill the above referenced well. The oermit to drill does not indemnify you from the probable need to o~tain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to' witness testing of the equipment before the surface casing shoe is drilled. ~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~r ~=]~ tru~ ~. V~ C~at:ter'ton Chai~an o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF ' '~ ~0~ dlf Enclosure cc: Department of Fish & ~ , . ~a~ne l{abitat Section w/o encl Department of Environmental Conservation ?~/o encl. Mr. Doug L. Lo~wery STATE OF ALASKA ALASKA _~IL AND GAS CONSERVATION C ,¢IMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill ~. Redrill F11 lb. Type of well. Exploratory [] Stratigraphic Test E3 Development Oil Re-Entry [] Deepen []1 Service [] Developement Gas [] Single Zone Q Multiple Zone © 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60', PAD 21' feet Prudhoe Bay Field 3. Address 6. Property Designation Li sburne Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 28322 ALK 2320 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 812'FNL, 833'FWL, Sec.22, T11N, R15E, UM Prudhoe Bay Unit/Lisburne Statewide At top of productive interval ~. Target 8. VVell nu.mber Number 1320'FNL, 1000'FEL, Sec.22, T11N, R15E, UN L3-22 #8088-26-27 At total depth 9. Approximate spud date Amount 1369'FNL, 664'FEL, Sec.22, T11N, R15E, UN 11/03/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 10,484'MD 664,~ 9402'TVD Cj''~l) feet 120' from L3-18 L~est rface 2560 (9402'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2750 feet Maximum hole angle32, t~ ~Maximum surface 3560 psig At total depth CrVD) 4490 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 17-1/2"13-3/8" 68.0# K-55 BTC 70' 39' 39' 109' 109' 2100 sx AS I I I & 17-1/2"13-3/8" 72.0# L-80 BTC 3963' 109' 109' 4072' 4000' 600 sx Cla~ 12-1/4"9-5/8" 47.0# L-80 BTC 9779' 38' 38' 9817' 8840' 530sxC1 assG&3OOsxAS I &A 8-1/2" 7" 29.0# L-80 BTC 867' 9617' 8672'10484' 9402' 190sx65%C1 as sG/35%POZ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor R[C~!VED Surface Intermediate (_}C-[ 9;_ ,'~ ~..~uulo'qr4 Production Liner Alaska 0il & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee '~ Property plat ~ BOP Sketch ,'~ Diverter Sketch ,~ Drilling program Drilling fluid program ~ Timevs depth plot r~ Refraction analysis ~ Seabed report ~ 20 AAC25.050 requirements ~. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge . .,--'~--~~ Regional Drilling Engineer S~gned ~/ / Title Date/~p/ Commission Use Only ( FPC ) PD/01 4 Permit Number. _ I APl number I Appr9v,~l,~l,a~e,,., [ See cover letter ~'~ ~ ( 7~ J 50-- O -~ c/,_~/~ ~,.~ I ± U/.,1U / ~ 6I for other requirements Conditions of approval Samples required~ Yes ~No Mud Icg requi.red ~ Yes ~No Hydrogen sulfide measures [] Yes [] No Directional,survey~quired ~Yes [] No Required working.~;~ure/fcr~//~2M,~ ._~3M; ~' 5M; ,~ 10M; © 15M Other: / ~//~~/ /,~~~--'~/' by order of Approved b , [ /~/~ Commissioner comm ¢( ~" ,,./. [_ _, ~,~.~~_.~ the ission Dat Form 10-401 I~ev.~-l-8b~ Submit in' riplicate L3-22 DRILLING PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annul ar diverter will be installed per the attached schematic. This is a variance from 20 AAC 25.035. 2. MIRU Rowan 41. Install 10" diverter lines and function test. 3. Drill 17-1/2" hole to 2750'MD(2750'TVD). Build 2-1/2° per 100' to 32%5' oriented S81°36'E to 4072'MD(4000'TVD). 4o Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. Do top job if cement does not surface. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi, annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform leakoff test. 6. Hold angle and drill 12-1/4" hole to 9817'MD(8840'TVD). 7. Set 9-5/8" casing and cement. Test casing to 3000 psi. 8. Drill 10' of new formation and perform leakoff test to 12.5 ppg EMW. 9. Drill 8-1/2" hole to approximately lO,484'MD(9402'TVD). 10. Run open hole logs. 11. Run and cement 7" liner. 12. Clean out cement and change mud out to brine with 400' diesel cap. 13. Secure well and release rig. 14. Run cased hole logs. 15. MIRU completion rig. 16. Run production tubing string with packer and subsurface safety valve. 17. NU tree and test to 5000 psi. 18. Secure well and release completion rig. 19. Perforate and stimulate well. NOTE: a. In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level in the reserve pit, will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The an- nulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi ~ 8960'TVD, less an oil column to the GOC ~ 8660', less a gas column to the surface. d. The existing wells within 200' of the proposed well are: L3-18, 120' at surface L3-19, 178' at surface There are no closer approaches downhole. PD/014a :dmr 10-22-86 DS 4-21 passes 1084' from L3-22 ~ 8517'MD/7745'TVD (L3-22 Depths) DS 4-22 passes 858' from L3-22 ~ 10,350'MD/9290'TVD (L3-22 Depths) Ar chora, ge Depth (TVD) Plas Density Visco #/gal (CP) Surf 8.8 Funnel to to 100- 13-3/8" 9.7 300 Csg Point 13-3/8" Csg Shoe 8.3 Minimum to to Possible K-lO 9.4 L3-22 MUD PROGRAM Yield Point Initial 1OM FL % % pH and #/100 ft2 Gel Gel CC/30M Oil Solids Type of Mud 40-60 20+ 40+ 20+ 0 8-10 Spud Mud 6 2 5 25 0 3 Low Solids to to to to to to Non-dispersed 20 10 30 10 2 7 K-lO 9.2 10 4 4 8 8 2 4 pH 9-10 to to to to to to to to to Low Sol ids/Low Lime 9-5/8"Csg. Pt. 10.2 20 10 8 20 4 5 15 Non-dispersed 9-5/8" Csg. Shoe 9.2 4 6 2 8 10 2 4 Low Solids/ to to to to to to to to to Non-Dispersed TD 9.6 10 10 8 20 4 8 8 Salt 15,000 - 30,000 ppm NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser L// 2. Shakers , 4. Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Desilter 9. Centrifuge RE,..EiV . ,, PD/014b :dmr 10-20-86 Alaska Oil & ~a~; Cons. Crmil-rlbsior~ Ancfi!)rage ROWAN 41 MUD SYSTEM mixing pit ~1-145 bbls mixing pit ~2-145 bbls pill pit 60 bbls i pit ~5 trip tank 1 45 bbls pit ~4 115 bbls pit ~6 -90 bbls pit~7- 90 bbls pit ~3 suction 115 bbls 'njection pit 145 bbls pit ~8 40 bbls Brandt Doub 1 e-Deck er Shale Shakers-(3) Demco Desander with 3- 12" diam. cones Demco Desilter with 14-6" diam. cones Drilco Degasser Pioneer Centrifuge Main Pumps: National 12-P-160, (2) Gasbuster 1.3-22 0 1000 2000 3000 4000 bO00 8000 1000 2000 3000 4000 50CC 6000 7000 800O TOP SAD TOP 8-6 TOP TD 10000 11000 70DO 0 , , , , , [ [ f , , , , , , , 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 tO' CONDUCT¢)FI TVD -' 110 ARC ) AL/ ,SKA, INC. i ;CALl= I IN = lttl~tt F'r. SHL: 812'1;NL, 833' FWL, SEC 22, "11N, R15E, U VI (OP TVD - 271 i0 THL: 1320' FNL, 1000' FI:.L, 2.5 t 7.5 ~_F~ ~_~: "!1N~ RIRI=: il:vi 12.5 17.5 22.~ 27.5 J'~ ~;2.5 EOC TVD "3984 MD - t054 DEl= -- 81~1 ~ /.~~ 13"8/8' EURFACE TVD= ``'.000 MD--4072 DEP--371 S 8L DEG 36 MIN E 3484 FT(TO %ARGE]7) AVERAGE ANGLE = 32 DEG 35 MIN ..] K-10 TYD -- 7810 MD ~, 8001 DEl= -- 487 1(.-5. TVD -- 7760 I~ ID - 8535 DEF - 2776 r!'D--8410 MD =9306 DEl='---3180 ~ LCU TVD'" 410 MD-83(~6 DEP--3180 Ir,. TVD - 8705 b D - 9666 DEP '- 3379 G TVD '"' 8840 ID "" 9817 DEl= = 3``'.`'.65 O 3 TVD = 8870 MD -- 9852 DE:P ~ 3484 ,, .. , ., ;-.:~); [ [, , i i i , i , , , i i i i , , , i , , i i i , i , , i , , i i i , , , T i , , , I , I , I , I , I , , I I , ~ , I , 1000 2000 0 1000 2000 3000 4000 5000 6000 VERTICBL SECTION 30OO 4000 SO00 6000 7000 8OOO 9000 10000 11000 7000 O'OI WqSSSIO OOSSI ' N~tOOWq-80P 98BI '£30 O~ P. - N COOROINFtTES ,._.) o o W Z I ~000 0 lO00 ~000 $000 ~000 5000 BO00 - ! 000 0 ! 000 2000 3000 9000 5000 6000 E - W COORDINR~'ES CO CE~o 7~ F. - N OOORDINBTES -400 -300 -200 I I I I I I I I I I I I I I t I ' ~ [ ~597 69o Z 0 o o I I 0 -400 -300 -200 -1 )0 0 E - N COORDINRTES 1 O0 200 300 (:3 o 0 Z C~ E - N COORBINFITES - 1000 0 1000 2000 3000 dO00 5000 6000 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 L3-1~ 334X21 U54- 22 B27~ ~495 0850 5112 -'326843 1o~/u ~[ 602~ ~:q ~:' ~ .... ~ ~ ~ ,.~:.. :.., 562 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~1/ i~ - 1000 0 1000 2000 3000 dO00 5000 6000 E - N COORDINPITES well ARCO ALASKA INC. ROWAN 41 DIVERTER I I Riser Fillupline J Flowline 10" ball. ball vlv I Conductor Note: Only one valve opens automatically when the diverter closes. The second valve will remain closed unless conditions require the use of the second vent line. The second vent line valve can be opened using controls located at the accumulator. This is a variance from 20 AAC 2.5.035 1:3-5/8" 5000 PSI BOP STACK DIAGRAM ACCI_IMLILATOR CAPACITY TEST i l PREYENTE PI PE RAMS i ¢ I BLIND RAMS C DRILLING SPOOL PI PE RAMS 1 ~ ~ ~-~ ¥ SPOOL ~ ALL BOP EQUIPMENT 5000 PSI RATED :!'-:. ,.. ~._~ ._~ ;. ~ :_: ~-' 1. CHECK AND FILL ACCUMULATOR RESERYOIRTO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ONIADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TI ME AND 1200 PSI REMAINING PRESSURE. . . . 9 10. 11. 12. 13. 14. 15 16 17 18 !3-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON- FREEZING LIQUID. CHECK THAT ALL HOL ~D DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUO ON DRILL PIPE AND SEAT I N WELLHEAD. STREAM. BLEE~D PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST 3 MINUTES. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLINDRAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVE5 TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERAT. ION OF DEGASSER. " RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLINGSUPERYISOR PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JO 8-26-85 ~tECK LIST FOR NEW WI~.I, PERMITS ITEM APPROVE DATE (1) Fee ' (2) (2 thru 8~ ;- --' (8) _ (9. ~hru 13) '~ (10 and i3') ' (3) Admin (4) Casg .~.~.~../O'27-8g (14 thru 22) (23 thru 28) (29 thru 31) . 10. 11. 12. 13. Company_ Lease & Well No ~/~-~ 1. Is the permit fee attached ............ ~ ............................. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .... 4, Is well located proper distance from other wells ..... 5. Is sufficient undedicated acreage available in this pool 6, Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force ................................... Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES NO Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandormmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~, Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrauns and descriptions of diverter and BOPE attached. Does BOPE tmve sufficient pressure rating - Test to ,5-'ODro psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data .presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- 32. Additional requirements ............................................. Geo logy~ Engineering ~'~,~ ',,,,..?,~ LCS ~7~ ~W WVA ~ MTM HZH JAL ' rev: 07/18/86 6.01] INITIAL GEO. UNIT oN/OFF POOL CI_AS S STATUS AREA NO. SHORE Additional Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. .... :. "~ ". $ C,X.I , ']'" ! ~",. C '~ L .., L L .{~ -,.'. ?: - 'i, i .2 T' :.} ?: :'"'~ .3 L .,.2', 2 ::" '~ L. :iL.: /::' .... L 2 < :- "; ~ C 'T '? :::i" L21 ': 'i" :,L: :' ! L i" ...:, .~. - ,..,:., , , !- g'. ;'.,i "i ,:' 'l '-, "; :._.. "? "-:' _, ,"~ ,~ i ,,i' l, ,',; ':; '.i .31 .. .,,' _~ .'~, :3 "..' i: "~.' :' -~" .~ ;',5 T .--. . ~', ' ~ i L i :': :''~ -' ,,.., '~ .~ ~; "i' ,: ~ :.. :; -~- .... : ,L '~',. ~"~' ,.~ -,. , ~.~.. ,i ,..: '::~' ! i ..3 ..., .c. .{ .~ · .., :'..} ,4. ..... , ,~, :,,, ~,~. 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