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Home My WebLink About200-050v : et. F EZ IV Mu STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG AN 15 2019 la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 11b. 20AAC 25.105 20AAC 25.110 Well Class: � Developmen t0(ys GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., SUSP., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/23/2018 200-050 318-372 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-8812 4/272000 50-029-22180-60-00 48. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 5/1/2000 PBU P -04L1 9 Re( Elevations KB 91.64 17. Field/Pool(s)'. Surface'. 2564' FSL, 2001'M. Sec. 31, TI IN, R13E, UM Top of Productive Interval: 415' FSL, 3129' FWL. Sec. 32, T11N, R13E, UM GL 54.19 BF 53.80 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 223' FSL, 4491'M, Sac. 32, T1 IN, R13E, UM 11519' / 8905' ADL 028288 41b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 631284 y- 5947292 Zone - ASP 4 13097'19051' 88-016 12. SSSV Depth(MD/TVD): 20, Thickness of Permafrost MDOVD: TPI: x- 637461 y- 5945253 Zone - ASP Total Depth: x- 638827 y- 5945085 Zone - ASP 4 None 1970' 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13, Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDrrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 11549'18926' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formafion tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary OR, RES, ROP 23' CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULL FT' TOP BOTTOM TOP BOTTOM 20" 42' 122' 42' 122' 30" 260 ax Arctic Set (Approx.) 10-3/4" 45.5# NT -s0 41' 2734' 41' 2691' 13-1/7' 2622 cu 8 Permafrost 7-5/8" 29.7# W-95HS 38' 11541' 38' 8920' 9-7/8" 1742 ou O Ciass'G' 5-1/2" 17# 130,60 11284' 11549' 8738' 8926' 6-3/4" 170 cu It Class G' 2-7/8" 6.16# 11549' 13097' 8926' 9051' 3-3/4" Uncemented Slotted Liner 18' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/ry If Yes, list each interval open (MDTVO of Top and Bottom; Perforation 4-1/7' 12,6# 13CrB0 11288' 11232-18701- 1232'/8701'26. Size and Number; Date Perfd): 7TYJw'^u.aa..¢-R 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed 1uL3/!li information DEPTH INTERVAL (MO) AMOUNT AND KIND OF MATERIAL USED 11519' Set Whipstock "161 11526' 49.2 Bble Class'G' 27 PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift. etc.): Date of Test:::: Hours Tested:: Production for Oil -Bbl- Gas -MCF: Water -Bbl: Choke Sire- Gas -Oil Ratio Test Period Flux Tubing Casino Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API loom: Press 24 Hour Rate --► Form 10407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only a6A?Aty►+ff,1J-r REDMsO ^,r,1 6 2019 vo 28., CORE DATA Conventional Cores) Yes ❑ No Q Sidewall Cores Yes ❑ No Q If Yes to either question, list formations and intervals wred (MD+TVD of top and bottom of each), and summarize lilhology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, wre chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MID TVD Permafrost - Top Well Tested? Yes ❑ No Q 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 11894' 9004' AAC 25.071. Eileen 11687' 9002' Saclerochil-Zone 4 11694' 9004' Formation at total depth: Zone 4 11694' 9004' 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, wre analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and comect to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: SIM cialist Contact Email: Tmvor.Hyatt@bp.com Authorized Signature: Date: 5 /' Contact Phone: +1 907 564 4627 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a welt producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (fop 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 lop and base of permafrost in Box 29. 20 AAC 25.071 and, to AS 31.05.030, submit all electronic data and printed logs within 90 days of Item 22. Review the reporting requirements of pursuant 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: Flouring, 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 wresponding 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: wre analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 bUDMi1 UKIWIVNL Univ Daily Report of Well Operations P -04L1 RI IMMARY ***WELL S/I UPON ARRIVAL*** (ctd) DRIFTED TO DEVIATION W/ 2.25" CENT, 1.75" SAMPLE BAILER @ 11,664' SLM / 11,705' MD (no sample) TAGGED TOP OF CLEAN DEPLOYMENT SLEEVE W/ 3.69" CENT, 3.50" LIB @ 11,490' SLM / 11,531' MD (41' corr) 9/24/2018 ***CONT WSR ON 9/25/18*** ***CONT WSR FROM 9/24/18*** (ctd) LATCHED TOP OF DEPLOYMENT SLEEVE W/ 4 1/2" GR @ 11,490' SLM TO VERIFY F.NECK INTACT 9/25/2018 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***WELL FLOWING ON ARRIVAL— INITIAL T/I/O = 300/1750/0. MIRU & BEGIN PT. 9/28/2018 ***JOB CONTINUED ON 29 -SEP -2018*** ***WELL FLOWING ON ARRIVAL*** R/U LRS & FP THE FLOWLINE. RUN 1: CUT 2-718"" LINER WITH 2.125" O.D. POWER JET CUTTER AT 11550.4' (-19' BELOW TOL). ALL LOGS CORRELATED TO LNR TALLY DATED 02 -MAY -2000. RDMO. WELL S/I ON DEPARTURE. FINAL TWO = 1440/1450/0. 9/29/2018 ***JOB COMPLETE ON 29 -SEP -2018*** T/1/0=SSV/1500/0 temp=Sl (LRS Unit 46 - Assist Eline: Freeze Protect Flowline) Pumped 5 bbls 60/40 MW down FL to freeze protect. E -line in control of well upon LRS departure. CV= OTG Tags hung 9/29/2018 Final WHP's SSV/ 1500/0 ***WELL S/I ON ARRIVAL*** (ctd) RIG UP SWCP 4518 10/1/2018 ***JOB CONTINUED ON 10/2/18*** ***WSR CONTINUED FROM 10/1/18*** (ctd) PULLED 18' OF CUT 2-7/8" LINER FROM 11,501' SLM. (11531' MD) NEW TOP OF CUT LINER IS 11549' MD SET 4-1/2" X -CATCHER @ 11,220' MD. PULLED BK -ORIFICE FROM ST# 1 @ 11,204' MD. PULLED BK -GLV FROM ST# 3 @ 9,225' MD. PULLED BK -GLV FROM ST# 4 @ 6,765' MD. PULLED BK -GLV FROM ST# 5 @ 3,110' MD. SET BK-DGLV IN ST# 5 @ 3,110' MD. SET BK-DGLV IN ST# 4 @ 6,765' MD. SET BK-DGLV IN ST# 3 @ 9,225' MD. 10/2/2018 ***WSR CONTINUED ON 10/3/18*** T/I/O= 1360/1423/Vac Temp= S/I (LRS Unit 72 - Assist Slickline: Load & Test) Arrive on location, Sign in with SSL, Sign onto RAP, RU to IA and start PT of surface line **"WSR 1012/2018 Continued on 10-03-18*** ***WSR CONTINUED FROM 10/2/18*** (ctd) LRS LOADED TBG w/ 350 bbls CRUDE. SET BK-DGLV IN ST# 1 @ 11,204' MD. LRS OBTAINED PASSING 2,500 psi MIT -IA. PULLED 4-1/2" X -CATCHER FROM 11,220' MD. RAN 20'x 3.70" WHIPSTOCK DRIFT, 3.50" LIB TO TAG TOL @ 11,517' SLM. (Impression of liner) RAN PDS 40 ARM CALIPER FROM 11,517' SLM TO SURFACE. (Good Data) 10/3/2018 ***JOB COMPLETE, WELL LEFT S/I*** Daily Report of Well Operations P-04L1 ***WSR Continued from 10-02-18**' T/I/0= 1360/1423/Vac Temp= S/I (LRS Unit 72 - Assist Slickline: Load & Test) Pumped 2 bbls 60/40 spear followed with 350 bbls 120* crude dawn IA to load, Pumped 5 bbis crude down IA to reach test pressure, Pressures wouldnt stabilize, Bleed IAP, Bled back 5 bbls. MIT-IA PASSED to 2627 psi, Max Applied Pressure= 2750 psi, Target Pressure= 2500 psi. Pumped 4.8 bbis crude down IA to reach test pressure, IA lost 24 psi in 1st 15 min and 0 psi in 2nd 15 min for a total loss of 24 psi in 30 min test, Bleed IAP, Bled back 4.9 bbls, AFE sign and tags hung on well, SSL in control of well at departure- 10/3/2018 IFWHP= 1592/220/-5. ***JOB STARTED ON 24-OCTOBER-2018*** (SLB ELINE: D&T/SET WHIPSTOCK) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 1500/50/0 RU. PT. RUN 1: RIH W/ 3.70" CENTRALIZER. TAGGED THE TOP OF 2-7/8" CUT LINER @ 11543'. 10/24/2018 ***JOB CONTINUED ON 25-OCTOBER-2018*** ***JOB CONTINUED FROM 24-OCTOBER-2018*** (SLB ELINE SET WHIPSTOCK) RUN 2- RIH W/ BKR 5-1/2" DELTA WHIPSTOCK. SET TOWS @ 11521'. WS ORIENTED TO 3.25 DEG LOHS. CCL TO TOP OF WHIPSTOCK = 14.1', CCL STOP DEPTH= 11506.9'. LOG CORRELATED TO SLB JEWELRY LOG 12-27-13. WELL SHUT IN ON DEPARTURE. FINAL TWO = 1500/0/0 10/25/2018 ***JOB COMPLETE ON 25-OCTOBER-2018*** CTU #9 2.375" coil 0.190 WT Objective: cement sqz pers/whipstock Pre CTD MIRU. Complete BOP test. Make up cementing BHA with 2.50" BDJSN and RIH. Load well with 1 % KCI and Diesel to underbalance. Pump 15.8ppg cement as per program and begin hesitation sqz. See log for details. 11/10/2018 **In progress" CTU #9 2.375" coil 0.190 WT Objective: cement sqz pers/whipstock Pre CTD. Perform Hesitate squeeze. Unable to achieve squeeze pressure as per program however, when the contamination began we were unable to bullhead and had to take returns. Allowed the WHP to get up to 1000psi before opening the choke, holding-600psi during the entire cleanout. Clean out from WCTOC to whipstock pinch point 11526' ELM D. Chase out at 80% washing all jewelry and bops with minimal losses. Well FP. Apply pressure at surface to confirm squeeze and able to maintain the equivalent of 700 psi over initial static WHP. 11/11/2018 ***Job Complete*** T/1/0= TWC/0/0 PRE CDR2. Continued from day shift. PT'd tree down against TWC & against WV Blind, High 5000psi. (PASSED). PT'd against 3" FMC OA VR plug low 300psi, High 3500psi. (PASSED). Evacuaed fluid from tree down to MV gate. RDMO ***Job 11/19/2018 Complete*** FWHP=TWC/0/0. TWO = 0/0/0. PRE CDR 2, Set TWC #292 @123" with CIW 840 Lubricator, Performed LTT on TWC (PASS). Install CDR Kill Line #2, to companion flange, PTd against TWC 300 PSI (PASS) Charted and Retained. Verified VR Plug in companion OA flange, Installed Alemite fitting in blind flange, installed Nordic Platform. RDMO. ***Job Incomplete***. FINAL 11/19/2018 T/1/0= 0/0/0. Daily Report of Well Operations P -04L1 T/I/O = TWC/60/10. Temp = SI. WHPs (pre rig). Nowell house, flowline or scaffolding. Bled IAP to 0 psi in 10 min(gas), bled OAP to 0 psi in 5 min (gas). Monitored 30 min. IAP & OAP increased 1 psi. Bled both to 0 psi on departure. FWHP's = TWC/0/0. 12/7/2018 SV, WV, SSV = C. MV=O. IA, OA = OTG. 15 00: T/I/O = TWC/0/0. Temp = Sl. WHP's. ((Pre -Rig). Nowell house, flow line or WH scaffold. No change in WHP's in 3 days. 12/10/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:50 North America - ALASKA - BP Operation Summary Report Page 1 Common Well Name. P-04 - Bra AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/15/2018 End Date: 1/3/2019 X3 -0197J -C: (2,351,407.00 ) Project: PBU Site: P -_--- Rig Name/No.: CDR -2 Spud Date/Time: 6/11/1991 12.00.00AM Rig Release: Rig Contractor. NABORS ALASKA DRILLING INC. 12/15/2018 11:00 BPUOI: USA00001646_ Active datum: KB @91.64usR (above Mean Sea Level) Date From -To - Bra Task Code NPT Total DepthPhase Description of Operations --__Susfl) 12/15/2018 11:00 - 18:00 7.00 RIGU P PRE ACCEPT RIG AT 11:00. BEGIN SAFE OUT CHECKLISTS AND RIGGING UP. j SPOTAUXILIARY EQUIPMENT. HOOK UP STEAM LINESAND INTERCONNECT - ,LINES. PREP ADAPTER FLANGE FOR TREE. 18:00 - 00:00 6.00 RIGU P I PRE PERFORM LTT BETWEEN MASTER VALVE AND SAAB TO 3500u. GOOD TEST NIPPLE DOWN TREE CAP. WORK ON GETTING MPD LINE HOOKED UP. LAND BOP STACK. NIPPLE UP STACK - LOADER SPOTTING CONTAINMENT AND ANY ANCILLARY EQUIPMENT 12/16/2018 00:00 - 02:00 2.00 RIGU P PRE FINISH NIPPLE UP. SECURE STACK TURNBUCKLES. 02:00 - 05:30 3.50 RIGU P PRE INSPECT TUGGERS. RUN ROPE THROUGH !. INJECTOR. PULL GRAPPLE CABLE THROUGH. PJSM, REVIEW PROCEDURE AND DISCUSS ROLES ! ! AND RESPONSIBILITIES. INSTALL GRAPPLE. PULLTEST 05:30 - 11:30 6.00 RIGU P PRE PULL CT ACROSS PIPE SHED AND INTO !I INJECTOR. INSTALL HORSEHEAD. REPLACE HOSE ON INJECTOR THAT WAS - LEAKING. !i INSTALL HOSE IN REEL FOR PUMPING SLACK 'BACKWARDS. —_- 11 30 - 14:30 3.00 RIGU P _ PRE VALVE CHECKLIST AND RIG CHECKS WITH ONCOMING CREW. ENERGIZE BOPACCUMULATOR UNITAND - INSPECT. MAKE UP INJECTOR TO WELL. 1430 - 15:00 0.50 RIGU P � PRE INSTALL QUICK CONNECT TEST FITTINGS. 15:00 - 15:30 0.50—'!� RIGU P PRE CONDUCT PJSM FOR REVERSE CIRCULATING. SPOT AND HOOKUP MEOH. LINE UP VALVES FOR REVERSE CIRCULATING. 115:30 - 19:00 3.50 RIGU P PRE RECONFIGURE VALVES GOING TO TIGER TANK TO MATCH HAZOP DRAWING PRESSURE TEST TIGER TANK LINE TO 250 / 3500 PSI, GOOD. _- 1900 - 0000 5.00 RIGU P PRE PJSM FOR FILLING REEL AND PUMPING SLACK BACK TO REEL. REVERSE CIRCULATE FRESH WATER INTO REEL. LEAK DEVELOPED ON RISER. BLOW DOWN AND INSPECT O-RING. REPLACED O-RING. PUMP SLACK BACK !, FOR BULKHEAD. RIG UP BIG BOY COMPRESSOR TO BLOW JNNERREELDOWN. Printed 1111/2019 10:26:57AM Common Well Name: P-04 Event Type: RE-ENTER- ONSHORE (R( North America - ALASKA - BP Operation Summary Report Start Date: 12/15/2018 Project: PBU Site: P Rig Name/No.: CDR -2 Spud Data/Time: 6/11/1991 Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @91.64usft (above Mean Sea Level) Date From - To Him Task Code NPT (hf)._. 12/17/2018 00:00 - 01:00 1.00 RIGU P Date: 1/3/2019 AFE No X3 -0197J -C:(2,351,407.00) Rig Release: Page 2 Total Depth Phase Description of Operations (U-511)--7— ..._" PRE BRING AIR ONLINE. FLOOR SUMPS N0T DRAINING. CREW MOBILIZED VACUUM SYSTEM. FRESHWATER TO CONTAINMENT INCELLAR. CALL SPILL HOTLINE, CALL SUPERINTENDENT. FLOW LINE FROZE. HEAT TRACE NOT WORKING VERIFY TEST JOINT LENGTHS. TORQUE CONNECTIONS TO 1000# WHILE CLEANING 01:00 - 04:00 04:00 - 0530 3.00 1.50 RIGU RIGU P P PRE PRE UP. CONTINUE BLOWING REEL DOWN. BLEED PRESSURE OFF. BREAK LINE OFF. TE -UNE FOR BULKHEAD. RACK BACK INJECTOR._ _ BREAK OFF DOWN TO TEST RISERS. INSTALL TEST CAP WITH JOINT GREASED UP 0530 - 08:30 3.00 RIGU P PRE CHECK BOP ADAPTER FLANGE BOLTS FOR PROPER TORQUE. WITH SWEENEY. MAKE UP PRESSURE BULKHEAD AND J -BOX INSIDE REEL. L MAKE UP INNER REEL HARDLINE. 08:30 - 11:00 1 2.50 RIGU P PRE PJSM FOR CUTTING CT. HOOK UP HYDRAULIC CUTTER AND CUT 280' OF CT. 11:00 - 14:00 3.00 j RIGU P * PRE INSTALL CT CONNECTOR, PULL TEST TO SOK, ' GOOD. COMPLETE VALVE CHECKLIST SHEET. - LINE UP TO FILL REEL FORWARD. FILL REEL FORWARD. 1400 1500 1.00 RIGU p j PRE PRESSURE TEST CT CONNECTOR AND PRESSURE BULKHEAD TO 4,700 PSI, SLIGHT LEAK OBSERVED. PERFORM LOTTO ON REELAND TIGHTEN BULKHEAD PACKING. PRESSURE TEST TO 4,700 PSI, GOOD. 15.00 - 1600 100 RIGU P PRE RIG UP LITTLE JERKS FOR CALIBRATION. INSTALL CORRECT SIZE DIES. TORQUE UP STINGER AND NOZZLE WITH LITTLE JERKS AND TEST TORQUE VALUES. MAKE UP INJECTOR TO WELL. 1600 - 16:30 0.50 RIGU P _ PRE TEST QTS TO 250 / 3,500 PSI, GOOD. PUMP SLACK FORWARD AT 4,100 PSI 13.65 BPM. CABLE IS HEARD MOVING. J 16:30 - 18:00 1.50 RIGU P PRE MOVE INJECTOR OFF WELL. CALIBRATE LITTLE JERKS, GOOD 1800 - 20:00 2.00 RIGU P PRE TEST WIRE CONTINUITY GOOD. MEG TEST LOW. POSSIBLE MOISTURE CUT 20' COIL / 20'E -LINE. RETEST. SAME ISSUE. _ 2000 - 22:30 2.50 RIGU P PRE PREP FOR SHELL TEST. WORK ON SHELL TEST TO MAKE SURE WE ARE READY FOR A.M TEST PUMP ISSUES. CALL MECHANIC. 22:30 - 00.00 150 RIGU P _ PRE CALLAND DISCUSS E -LINE ISSUES WITH ETL. CUT MORE COIL / E -LINE. Printed 1/11/2019 10:26:57AM Common Well Name P-04 Event Type: RE-ENTER- ONSHORE (RON) PBU North America -ALASKA - BP Operation Summary Report AFE No Start Date. 12/15/2018 End Date: 113/2019 X3 -0197J -C'. (2,351,407.00 ) Site: P ( Hg Narnelrvo.: GUH-2 i Spud Date/Time: 6/11/1991 12:00:00AM Rig Release: Page 3 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00001646 Active datum: KB @91.64usR (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (usft) 12f1812018 00:00 - 02:30 2.50 RIGU P PRE CONTINUE TO TROUBLESHOOTE-LINE. OPEN JUNCTION BOX, GOOD TEST ON E -LINE. NARROW DOWN TO COLLECTOR OR !COLLECTOR PIGTAIL. MECHANIC TORE DOWN TEST PUMP. SCALE PARTICLES HOLDING VALVES OFF SEAT. _ SERVICE TEST PUMP. 02:30 - 03:30 1.00 RIGU P PRE -PJSM, REVIEW CROSSCHECK. STAGE UP PRESSURE TO ADJUST POPOFF AT 55009. 6000# BURST DISK INSTALLED. PERFORM A PASSING 51000 SHELL TEST. BLOW DOWN TEST PUMP. 03:30 - 06:00 2.50 RIGU P PRE INSTALL COIL TUBING CONNECTOR _ PULLTESTEDTO SOK BHI INSTALL LOC. TEST LINE FROM J -BOX TO UOC. TESTED GOOD. INSTALL TEST SUB. PRESSURE TEST UOC AND CTC TO 4500#. GOOD. 0800 - 0800 2.00 0800 - 12:00 4.00 BOPSUR P PRE MOVE CART BACK. BOPSUR P 12:00 - 14:00 2.00 BOPSUR P 1400 - 1630 2.50 BOPSUR P PREP FOR BOP TEST#1. CONDUCT PJSM FOR BOP TESTING. DRILLER AND WSL REVIEW PRESSURE XCHECK VERIFICATION. SIMOPS: REPLACE COLLECTOR THAT WAS THE SOURCE OF THE ELINE TROUBLE EARLIER. ! PRE TEST BOPS TO 250/ 5000 PSI AS PER BP AND AOGCC REGULATIONS. TEST IS WITNESSED BY AOGCC REP JEFF JONES. TEST is BLINDS FAIL, CYCLE AND REPEAT, FAILAGAIN. FLUID IS OBSERVED PASSING BLINDS. CONTINUE ON WITH TEST 1. SIMOPS: CONTINUE WITH GAS ALARM TESTING, ALL GAS ALARMS PASS. PRESSURE STILL BLEEDING OFF, SUSPECT LEAKING PAST MASTER AND TWC. PRE CALL OUT GREASE CREW. TEST NEW COLLECTOR, GOOD. MOVE FLUID AROUND PITS, CHECK PVT LO! HI LEVEL ALARMS ON ALL THE PITS. GREASE CREW COMES OUT AND CLOSES SSV, SERVICES MASTER VALVE. PRE 'RE -START TEST#1 TO 25015000 PSI. VALVE B4 IS LEAKING BY AT HIGH PRESSURE, GREASE AND CYCLE, RE -TEST. GET GOOD TEST ON BI, BL1. FAIL/ PASS ON R1. FAIL ON B4 AND BLINDS. 16:30 - 18:00 1.50 BOPSUR P PRE TEST #2: ANNULAR (2-3/8"), TIW #2, 63, B2, BL7 PASS 250 13500 PSI. 18:00 - 20:00 2.00 BOPSUR N PRE TEST#3 TO 250/ 5000 PSI. UPPER 2318" PIPE/SLIP RAMS, TIW 11112, BL2, T2 AND C 15, HIGH PRESSURE LEAK OFF TROUBLE SHOOT BY ISOLATION, REFLUSH TEST LINES AND RETEST. Printed 1/11/2019 10:2657AM North America - ALASKA - BP Operation Summary Report Common Well Name. P-04 - — -- -- -- - Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/15/2018 End Date: 1/3/2019 Project: PBU --__ - _ Site: P.. AFE No X3 -0197J -C:(2,361,407.00) Page 4 ghffi ) Rig Name/No.: CDR -2 Spud Date/Time: 6/11/1991 12:00:00AM Ric Release: I INC. BPUOI: USA00001646 Active datum: KB @91.64usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hO_--_ (usft)_ 20:00 - 23:00 3.00 BOPSUR N PRE RE -START TEST#3 TO 250/5000 PSI. UPPER 2 3/8" PIPE/SUP RAMS, TIW #2, BL2, T2 AND C 15. ISOLATE LEAK PATHS ONE ATA TIME DOUBLE iBLOCKING-PRESSURE STILL FALLING. CLOSE LOWER 2 3/8" PIPEISLIP RAMS -PRESSURE STILL FALLING. TEST TEST EQUIPMENT -GOOD DISCUSS ISSUES WITH TOWN WHILE WAITING ON GREASE CREW TO 'ARRIVE -SUSPECT PRESSURE BLEEDING _ iPAST SSV 23:00 23:30 0.50 BOPSUR N PRE HOLD TOOLBOX TALK WITH GREASE CREW 23:30 - 00:00 ' a50 12/19/2018 00:00 - 01:00 1.00 01:00 - 02:30 1.50 02'30 - 08:00 5.50 08:00 - 10:00 2.00 10:00 - 12:30 2.50 1230 - 1800 1 5.50 Printed 1/112019 1036:57AM `N' depths Masked iA PkileFs Deaths` AND RIG CREW. 'CLOSE SWAB VALVE OPEN MASTER VALVE OPEN SSV -OBSERVED 200 PSI TRAPPED PRESSURE WHEN SSV OPENED. GREASE SWAB, SSV, MPD VALVES AND !MASTER. - BOPSUR N', PRE HOLD TOOLBOX TALK PRESSURE TEST TO 250/5000 PSI. AGAINST MASTER, LOWER 3r8" PIPE/SLIP RAMS, Tl -PRESSURE STILL iBLEEDING OFF. NOTE -STATE INSPECTOR HOURED OUT WILL BE BACK IN 8 HOURS. BOPSUR N PRE DISCUSS PLAN FORWARD WITH TOWN TEAM. HOLD TOOL BOX TALK WITH CREW PRESSURE TEST AGAINST TWC, LOWER2 3/8" PIPE/SLIP RAMS, T1 TO 5000 PSI -PRESSURE STILL BLEEDING OFF AT 500 PSI IN 10 MINUTES PRESSURE TEST AGAINST TWC, LOWER 3/8" PIPEISLIP RAMS, T1 TO 3500 PSI -PRESSURE STILL BLEEDING OFF 150 PSI IN 10 MINUTES DISCUSS RESULTS WITH TOWN TEAM AFTER REACHING AGREED UPON STOP POINT. BOPSUR N PRE HOLD TOOLBOX TALK WITH CREW PRESSURE TEST VOID BETWEEN SSV AND SWAB VALVE USING THE MPD LINE TO 250/3500 PSI.GOOD TEST DISCUSS RESULTS AND PLAN FORWARD WITH TOWN TEAM BOPSUR N PRE HOLD TOOLBOX TALK WITH CREW REMOVE TEST JOINT DE ENERGIZE AND LOCK OUT ACCUMULATOR VAC OUT BOP STACK TO REMOVE FLUID. _ CHANGE OUT BLIND RAMS ELEMENTS. BOPSUR N PRE CHANGE OUT CHOKE HCR. BOPSUR P PRE REPLACEMENT COMPLETED. ! ENERGIZE ACCUMULATOR. - COMPLETE VALVE CHECKLIST SHEET. CONDUCT SHELL TEST ON BOPS, SWAB, - j ! CHOKE AND KILL HCCRS TO 25015000 PSI, GOOD BOPSUR N� PRE WAIT ONAOGCC INSPECTOR TOARRIVE. AMIM RFFI Printed 1/112019 1036:57AM `N' depths Masked iA PkileFs Deaths` North America - ALASKA- BP Page 5 Operation Summary Report --_— -- -- Common Well Name: P-04 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date' 12/15/2018 End Date: 1/3/2019 X3 -0197J -C: (2,351.407 00 ) Project. PBU -- -- -- _ Site: P ng nana,rvo.: wn-e epu0 Uate/lime: 6/11/1991 12.00100AM Rig Release: Rig Contractor. NABORS ALASKA DRILLING INC. BPU01: USA00001646 Active datum: KB @91.64usft (above Mean Sea Level) Date From- To Hrs Task Code NPT Total Depth Phase Descnpbon of Operations (hr) _. _ (usft) 118:00 - 19:00 1.00 BOPSUR P PRE TEST BOPS TO 250/5000 PSIAS PER BRAND AOGCC REGULATIONS. TEST IS WITNESSED BY AOGCC REP MATT HERRERA. TEST 1: BLINDS FAIL, CYCLE AND REPEAT, FAILAGAIN. FLUID IS OBSERVED PASSING B_LINDS. 19:00 - 19:30 0.50 BOPSUR P I PRE TEST #2' ANNULAR (2-3/8"), TIW #1 , B3, B2, PASS 250 13500 PSI. 19:30 - 20:00 0.50 BOPSUR P PRE TEST #3 TO 250 / 5000 PSI. UPPER 2 3/8" 20:00 - 21:00 1.00 21:00 - 23:00 23:00 - 00:00 12/20/2018 00:00 - 01:30 2.00 1.00 PIPE/SLIP RAMS, TIW #1 , B3, B2. -TO OBTAIN 5000 PSI TEST ON TIW #1 B3 B2 _ BOPSUR P PRE ' TEST #4 TO 250/5000 PSI. UPPER 2 3/8" ,PIPE/SLIP RAMS, TIW #2, B2 AND C 15. R2 FAILED -ISOLATED WITH B2 BOPSUR N PRE TEST#5 T0250/5000 PSI. UPPER 23/8" PIPEISLIP RAMS, TIW #2, BL2 R2 AND B4. B4 APPEARS TO BE LEAKING, FUNCTION, GREASE AND RETEST UPPER 2 318" PIPE/SLIP RAMS, TIW #2, B1 AND 84 AND R2 NOT HOLDING.84 FAIL. NOTE: WENT BACK TO LAST GOOD TEST ALLIGNMENT, NOTABLE TO OBTAIN PASSING TEST. SUSPECT PRODUCTION TREE VALVES NOT HOLDING, CALL VALVE CREW TO COME SERVICE TREE VALVES. NOTE: AOGCC REP MATT HERRERA TIMED OUT AND LEFT LOCATION WITH PERMISSION TO CARRY ON WITH TESTING ONCE TROUBLE SHOOTING IS DONE WITHOUT WITNESS. BOPSUR N PRE TEST CHOKE MANIFOLD TO 250/5000 PSI WHILE WAITING ON VALVE CREW TO ARRIVE ON LOCATION. TEST CHOKE VALVE C11 AGAINST C15 1.50 BOPSUR N PRE TEST CHOKE MANIFOLD 70250/5000 PSI WHILE WAITING ON VALVE CREW TO ARRIVE ON LOCATION, TEST CHOKE VALVE C9,C7 AND C10 AGAINST C15 -FOUND TEST HOSE QUICK CONNECT TO BE LEAKING. -NO TEST -REPAIR HOSE 01:30 - 02:00 0.50 BOPSUR 02'00 - 03:30 1.50 03:30 - 04:00 BOPSUR N PRE N_. PRE 0.50 BOPSUR N Printed 1/11/2019 10:26:57AM PRE GREASE PRODUCTION TREE VALVES HOLD TOOL BOX TALK WITH GREASE CREW OPEN MASTER, OPEN SSV, OPEN MPD LINE TO BLEED ANY TRAPPED PRESSURE, OPEN SWAB. SERVICES TREE VALVES CLOSE TREE VALVES. FLUSH LINES AND TEST AGAINST SWAB VALVE TO 250 / 5000 PSI. AGAINST UPPER 2 3/8" PIPE/SLIP RAMS, TIW #1 , B3, 132 -NOT ABLE TO MAINTAIN A GOOD TEST SUSPECT FLUID PASSING BY PRODUCTION TREE VALVES. DISCUSS OPTIONS AND PLAN FORWARD WITH CTD SUPTAND ETL North America - ALASKA - BP Pape 6 Operation Summary Report Common Well Name: P-04 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/15/2018 End Date: 1/3/2019 X3 -0197J -C: (2,351,407,00) Project: PBU ---- -- - Site: P - Rig Name/No.: CDR -2 Spud Datelfime'. 6/11/1991 12.00.O0AM Rig Release: Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00001646 Active datum: KB @91.64usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04:00 - 06:30 2.50 BOPSUR N PRE RIG UP TO PUMP PREMIUM GREASE INTO MASTER, SWAB AND SSV, EXPEDITE ADDITIONAL DRUM OF PREMIUM GREASE TO -. RIG SITE. DISCUSS PLAN FORWARD WITH NABORS SUPERINTENDENT, PREPARE LOCK OUTAND PRE JOB FOR TESTING BOPS WITH 3500 PSI TRAPPED PRESSURE BETWEEN SWAB AND . SSV.PUMP PREMIUM GREASE INTO MASTER, SWABANDSSV 06:30 - 08:30 2.00 BOPSUR N PRE PJSM FOR NEW SHELL TEST. PUT 3500 PSI ON THE WELL IN BETWEEN THE SWABAND SSV. PRESSURE BLEEDING OFF, REPLACE 2 VALVES AND TRY AGAIN. STILL BLEEDING OFF, FLUID IS OBSERVED PASSING THE SWAB. 08:30 - 12:00 I 3.50 BOPSUR N _ PRE REGREASE SWAB VALVE. PRESSURE UP BETWEEN SWAB AND CLOSED SSV, MASTER. PRESSURE IS BLEEDING OFF. PRESSURE UP BETWEEN SWAB AND TWO. 'PRESSURE IS BLEEDING OFF, SAME RATEAS BEFORE. `CLOSE MASTER VALVE AND SEE IF LINE `- _ FLATTENS OUT. STILL BLEEDING OFF. _.-__... 12:00 12:00 - 16:00 4.00 I BOPSUR N PRE DISCUSS PLAN FORWARD WITH ODE, CTD SUPT AND ETL. DECISION IS MADE TO USE BOP TEST PLUG THAT SITS IN A SPOOL ON THE BOTTOM OF THE BOPS. --- ._ —CHANGE OUT SEALS ON BLIND RAMS. 16:00 - 19:30 - 3.50 BOPSUR N PRE PJSM THEN BREAK APART STACK TO INSTALL BOP TEST SPOOL. BREAK FLANGE AND REMOVE BOPS FROM PRODUCTION TREE INSTALL TESTING SPOOL WITH PRE LOADED TEST PLUG ON TOP OF PRODUCTION TREE RE INSTALL BOP ONTO TESTING SPOOL.. GREASE CHOKE VALVES AND B VALVE ....OFFLINE 19:30 - 20:00 0.50 BOPSUR N PRE FUNCTION BLINDS, FLUID PACK TEST LINES. 2000 - 2145 1.75 BOPSUR N PRE HOLD PJSM AND SHELL TEST BOPS TO 250/5000 PSI -FAIL LEAKING THROUGH I BLINDS, RIG UP TEST JOINT WITH CAPAND RE ATTEMPT SHELL TEST TO 250/5000 PSI AGAINST TEST CAP, R2, TIW 2, TEST PLUG, TP2, C15 AND BE 2 -GOOD TEST. CALL MATT HERRERAAOGCC REPAND RECIEVE PERMISSION TO START BOB TEST. 21:45 - 22:15 0.50 BOPSUR P PRE TEST BOPS TO 250 15000 PSI AS PER BPAND AOGCC REGULATIONS. . TEST IS WITNESSED BY AOGCC REP MATT HERRERA. TEST 1i ANNULAR (2-3/8"), TIW#2, B3, B2, 25013500 PSI. -PASS 22:15 - 23:00 0.75 BOPSUR P Y PRE TEST#2: UPR 2 3/8 PIPE/SLIP RAMS, TIW #2, B3, 82, 250/5000 PSI -PASS 23:00 - 23:30 0.50 SOPSUR P PRE TEST#3 UPR 23/8 PIPE/SLIP RAMS, TIW #2, Printed 1/11/1019 10:26:57AM North America - ALASKA - BP Operation Summary Report Page 7dSK Common Well Name: P-04 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/5/2018 End Date: 1/3/2019 X3 -0197J -C: (2,351,407.00) - 00:30 Site: P - —_---- BOPSUR P Project: PBU Rg Name/No.: CDR -2 Spud DateTme: 6/11/1991 120000AM Rig Release'. Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001646 Active datum: KB @91.64usft (at)ove Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) -_ (usft)_-__ 23:30 - 00:00 0.50 BOPSUR P PRE TEST #4 UPR 2 3/8 PIPEISLIP RAMS, TIW #2 , Printed 1/11/2019 10:26:57AM _C16_C11,B1 250/5000PSI-PASS 12/21/2018 00:00 - 00:30 0.50 BOPSUR P PRE TEST BOPST0250/5000 PSIAS PER BRAND AOGCC REGULATIONS. TEST IS WITNESSED BY AOGCC REP MATT HERRERA. TEST #5 TEST 2 3/8 X 3 1/2 VBR, C7, C9, C10, _TB2 TO 250/5000 PSI -PASS 00:30 - 01:00 0.50 BOPSUR P PRE TEST #6 TEST LOWER 2 3/8 PIPE SLIP RAMS, C5, C6, C8, TVI -PASS 01:00 - 01:30 0.50 BOPSUR P PRE TEST# 7SUPER AND MANUAL CHOKES. 2500 PSI DRAWDOWN -CHOKE IN GOOD OPERATION .01:30 - 02:00 0.50 BOPSUR P PRE ACCUMULATOR DRAWDOWN TEST CLOSING PRESSURE 2375, TIME TO GAIN 200 PSI 17 SECONDS, FULL PRESSURE 64 SECONDS. AVERAGE NITROGEN 10 BOTTLES AT 2100 PSI. GOOD TEST. 02:00 - 02:30 0.50 BOPSUR P PRE 'RIG UP TO TEST VARIABLES AND ANNULAR WITH 3 1/2" PIPE -HAD TO REMOVE BOTTOM OF TEST JOINT FOR SPACE OUT AGAINST .THE TEST PLUG 02:30 - 03:00 0.50 BOPSUR P PRE TEST #8 ANNULAR WITH 31/2 PIPE, Ci, C4, C6, TIW 2 TO 250/3500 PSI -PASS , _ OFFLINE TEST PVT SYSTEM AND ALARMS. 0300 - 03:30 0.50 BOPSUR P PRE TEST #9 VERS WITH 31/2 PIPE C1, C4, C6 TIW 270250/5000 PSI -PASS 03:30 - 04:00 0.50 BOPSUR P PRE TEST #10 C2, C3, B3, TO 250/5000 PSI -PASS 04:00 - 04:45 0.75 BOPSUR'. P PRE TEST #11 84, 9L1T0 250/5000 PSI SUSPECT CHECK VALVE LEAKING. ISOLATEAND TEST B4 TO 250/5000 PSI -PASS 04:45 - 05:15 0.50 BOPSUR P PRE TEST #12 BL1A, R1 TO 250/5000 PSI -PASS 0515 - 0600 0.75 BOPSUR P PRE RIG DOWN TEST JOINT AND TEST EQUIPMENT 06:00 - 09:00 3.00 BOPSUR P PRE PJSM THEN RIG UP FOR TESTING IRV AND STRIPPER. INSTALL NOZZLE, MAKE UP RISER TO WELL. PUMP 1 REEL VOLUME FORWARD. 0900 - 11.00 2.00 BOPSUR P PRE CREW CHANGE. RIG CHECKS AND VALVE CHECKLIST WITH NEW CREW. PJSM FOR PT INNER REEL VALVE. PRESSURE TEST INNER REEL VALVE, . STRIPPER TO 250 / 3,500 PSI. 1100 - 1200 1.00 BOPSUR N PRE VALVE R3 IS SEEN LEAKING FROM THE FACE FLANGE. BLEED OFF PRESSURE AND TIGHTEN, SAME RESULT. CHANGE OUT VALVE R3. Printed 1/11/2019 10:26:57AM North America - ALASKA - BP Operation Summary Report Common Well Name: P-04 22:00 - 00:00 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 12/152018 End Date. 1/3/2019 X3 -0197J-0:(2,351,407.00) Project: PBU Site P OBSERVED FROM BEHIND C9, C70, Rig Name/No.: CDR -2 Spud DateTme: 6/11/1991 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. AGAIN. BPUOI: USA00001646 Active datum. KB Q91.64usft (above Mean Sea Level) STILL BLEEDING, ISOLATE IRVAND Date From - To Him Task Code NPT Total Depth Phase Description of Operations GOOD TEST TO 250 / 3500 PSI ON IRV AND _ (usft) _ --_ -(hr) 12:00 - 15:00 3.00 BOPSUR P PRE LINE UP TO PRESSURE C9, C10 FROM 15.00 - 19:45 4.75 19:45 - 20:45 -1.00 20:45 - 21:45 1.00 21:45 - 22:00 0.25 01:00 - 01:30 e50 01:30 03:00 1 1.50 22:00 - 00:00 2.00 12/22/2018 00:00 - 01:00 1.00 01:00 - 01:30 e50 01:30 03:00 1 1.50 BOPSUR P 0300 - 04.00 1.00 BOPSUR P Printed 1/11/2019 10P 26 57AM PRE PURGE AND FLUSH SURFACE LINES FOR TESTING LINE UP TO TEST BL1 TO 250/3500 PSI -PASS LINE UP TO TEST T2 TO 250/3500 PSI -PASS LINE UP TO TEST T1 TO 250/3500 PSI -PASS NOTE RISER WAS TESTED WITH EACH OF THE ABOVE TESTS PRE LINE UP TO PRESSURE Ce, C10 FROM DOWNSTREAM SIDE. PRESSURE 25013,500 PSI. UNABLE TO MEET DOWNSTREAM SIDE. PRESSURE 25013,500 PSI. PRESSURE IS BLEEDING OFF, DRIP OBSERVED FROM BEHIND C9, C70, GREASE AND CYCLE THESE 2 VALVES, TRY AGAIN. STILL BLEEDING, ISOLATE IRVAND STRIPPERAND TESTTHOSE. GOOD TEST TO 250 / 3500 PSI ON IRV AND STRIPPER. 1 VALVE C9 NOT HOLDING PRESSURE FROM THE DOWNSTREAM SIDE. BOPSUR N PRE PJSM FOR CHANGING OUT BLIND RAM SEALS. PERFORM LEAK TIGHT TEST ON SWAB AND SSV, GOOD. CHANGE OUT SEALS ON BLIND RAM BLOCKS, CHANGE OUT EQUALIZER VALVE ON BLIND RAM OPERATORS.. PRE TEST BLINDS TO 250/5000 PSI -GOOD PERFORM SHELL TEST TO TEST BLIND RAM — DOOR SEALS TO 25015000 PSI -GOOD _T BOPSUR � P � B PRE—__ TEST BOPS TO 25015000 PSI AS PER BP AND TEST 'AOGCC REGULATIONS. I TEST IS WITNESSED BY AOGCC REP MATT HERRERA. TEST #14 BLINDS, B1, B2, 03 TO 250/5000 PSI -PASS _ BOPSUR t P PRE TEST # 15 B2, BLINDS, C9 C10, C16, CQ TPI, TP 2 250/5000 PSI -FAIL C9 LEAKING SERVICE AND CYCLE C9, RESTEST 250/5000 PSI BOPSUR P r PRE TEST#16 CHOKE TEST CHOKE A AND CHOKE C PRESSURE UP TO 5000 PSI HOLD, OPEN CHOKES BLEED TO 2500 PSI AND HOLD. -GOOD TEST BOPSUR P PRE LINE UP TO PRESSURE C9, C10 FROM DOWNSTREAM SIDE. FLUSH AND FILL LINES PRESSURE 25013,500 PSI. DID NOT PASS SIMOPS CREW CHANGE SIM OPS RIG UP GREASE CREW TO GREASE PRODUCTION TREE VALVES. BOPSUR P PRE RIG DOWN RISER AND FLANGE FROM TOP OF ANNULAR WITH PJSM REMOVE TEST PLUG FROM TESTING SPOOL BOPSUR P PRE 'RIG UP RISER TO TOP OFANNULAR AND MU BOPSUR P 0300 - 04.00 1.00 BOPSUR P Printed 1/11/2019 10P 26 57AM PRE PURGE AND FLUSH SURFACE LINES FOR TESTING LINE UP TO TEST BL1 TO 250/3500 PSI -PASS LINE UP TO TEST T2 TO 250/3500 PSI -PASS LINE UP TO TEST T1 TO 250/3500 PSI -PASS NOTE RISER WAS TESTED WITH EACH OF THE ABOVE TESTS PRE LINE UP TO PRESSURE Ce, C10 FROM DOWNSTREAM SIDE. PRESSURE 25013,500 PSI. UNABLE TO MEET North America - ALASKA -BP Operation Summary Report Common Well Name: P-04 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/15/2018 End Date: 1/3/2019 Project: PBU Site: P Rig Name/No.: CDR -2 Spud DateTme: 6/11/1991 12:00.00AM Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB ®91.64usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase _ _. — (usft)_ _ 04:00 - 04:30 0.50 BOPSUR N PRE 04:30 - 08:30 2.00 BOPSUR P PRE Page good AFE No X3 -0197J -C:(2,351,407.001 BPUOI: USA00001646 Description of Operations REBUILD VALVE C13 FLUSH/PURGE LINES LINE UP FOR TEST OF VALVES C9 AND C10 LINE UP TO PRESSURE C9, C10 C13 FROM DOWNSTREAM SIDE. PRESSURE 250 / 3,500 PSI.UNABLE TO MEET PASSING CRITERIA. TROUBLE SHOOT LEAK PATH. _ _ REPLACE SEAT ON C1 3. 06:30 - 07:30 1.00 BOPSUR P PRE PRESSURE UP ON DOWNSTREAM SIDE OF C9, CIO. GOOD TEST. BOP TESTING COMPLETE. 07:30 - 09:30 2.00 BOPSUR N PRE DURING TESTING C14 WAS PASSING FLUID. Pnnted 1/11/2019 10:26:57AM PJSM THEN CHANGE OUT C14. TRY TO TEST C14, NOTABLE TO. SUSPECT C13 AND CHOKE PASSING FLUID. GOOD. PJSM THEN CHANGE OUT C13. - 15:30 TEST C13, C14 AFTER CHANGEOUT, GOOD. .09:30 - 10:00 0.50 BOPSUR P PRE RIG EVAC EXERCISE WITH MICAH'S CREW. PRE ALLPERSONS MUSTER AND ACCOUNTED FOR IN 3 MIN. CONDUCTAAR. 10:00 - 12:30 2.50 BOPSUR P PRE 'GREASE CHOKE AND FUNCTION. CHECK TREE BOLTS FOR TORQUE. INSTALL BHI FLOATS. GREASE ALL CHOKE VALVES POST BOP TEST. PUMP THROUGH MPD CHOKE AND VERIFY RIG CHECKS AND VALVE CHECKLIST WITH ONCOMING CREW. 12:30 - 14:00 1.50 BOPSUR P PRE PRESSURE TEST UOC TO 250 / 4700 PSI, PLC CONTROLLER IS WORKING. GOOD, - 16:00 PRESSURE TEST FLOATS 7O 3,500 PSI, Pnnted 1/11/2019 10:26:57AM GOOD. 14:00 - 15:30 1.50 BOPSUR P PRE MAKE UP INJECTOR TO WELL. CHECK TREE BOLTS FOR TORQUE. PUMP THROUGH MPD CHOKE AND VERIFY PLC CONTROLLER IS WORKING. 1530 - 16:00 0.50 BOPSUR P PRE RIG EVAC EXERCISE WITH RICK ROY CREW. ALL PERSONS MUSTER AND ACCOUNTED FOR IN 4 MIN. CONDUCTAAR. 16:00 - 18:00 2.00 WHSUR P PRE GET NEW RKBS WITH NABORS CREWAND VALVE SHOP CREW. HOOK UP BPV LUBRICATOR AND PULLING RODS. HOOK UP HYDRAULICS. 18:00 19:30 1.50 WHSUR P PRE HOLD PJSM WITH RIG CREWAND VALVE SHOP CREW FOR TESTING LUBRICATOR AND PULLING BPV. WALKALL LINES AND VERIFY VALVE ALLIGNMENT FLUSH LINES TO CLEARAIR FOR TEST. PRESSURE TEST VALVE LUBRICATOR TO 250/5000 PSI FOR 5 MINUTES EACH -GOOD TEST. Pnnted 1/11/2019 10:26:57AM Common Well Name: P-04 Event Type: RE-ENTER- ONSHORE(RON) North America - ALASKA - BP Operation Summary Report Stan Date: 12/15/2016 End Date. 1/3/2019 SRC_P Rig Name/No.: CDR -2 Spud Date(Tme: 6/11/1991 12:00:00AM Rig Contractor: NABORSALASKA DRILLING INC. Active datum: KB @91.64usft (above Mean Sea Level) Data From - To Hrs Task Code NPT Total Depth Phase (hr) (usft) Pape 10 ABS AFE No X3 -0197J -C: (2,351,407.00) R:g Release: 19:30 - 20'45 1.25 WHSUR P PRE PULLTWC 20:45 - 21:00 0.25 WHSUR P 21:00 - 21:30 0.50 WHSUR P 21.30 - 23:00 23:00 - 00:00 Description of Operations HOLD PJSM I'RIG DOWN TEST LINE, RIG UP LUBRICATOR HYDRAULIC LINE. OPEN MASTER VALVE OPEN SSV OPEN SWAB AND MONITOR FOR TRAPPED PRESSURE -0 PSI VERIFY LINE UP PER NABORS PROCEDURE USING COMMAND AND CONTROL CHECKLIST. ENGAGE AND PULL TWC. WELL ON SLIGHT VAC -ALLOW METHANOL TO DRAIN. CLOSE MASTER AND SWAB VALVE NOTE: FUSABLE CAP INSTALLED AND HYD FLUID DRAINED FOR SSV. PRE PERFORM LEAK TIGHT TEST 703500 PSI BETWEEN MASTER AND SWAB -GOOD TEST WITNESSED BY RIG MANAGER ANDWSL. PRE RIG DOWN LUBRICATOR HOLD PJSM OPEN NEEDLE VALVE ON LUBRICATOR AND VERIFY NO METHANOL PRESENT. BREAK OTIS CAP AND PULL LUBRICATOR WITH TWC. LAY DOWN AND RIG DOWN LUBRICATOR. BLOW DOWN LINE TO TIGER TANK 1.50 KILLW P PRE MAKEUP BHA#1 FOR BOTTOM KILL 1.00 -- KILLW- P - 12/23/2018 00:00 - 00:30 0.50 Printed 1/11/2019 10:26:57AM KILLW P OPERATION HOLD PJSM WITH CREW. MAKE UP STINGER, NOZZLE WITH FLOAT INSTALL QUICK TEST CONNECTOR TO LUBRICATOR STAB INJECTOR TEST QUICK TEST CONNECTOR AND LUBRICATOR TO 3500 PSI LEAK TIGHT TEST. GOOD TEST PRE LOAD COIL TUBING WITH METHANOLAND HEATED 1% KCL PUMP 15 BELS OF METHANOL FOLLOWED BY HEATED 1% KCL TAKING RETURNS TO TIGER TANK UNTIL METHANOL IS DETECTED AT OUT '.MICROMOTION. _ PRE LOAD COIL TUBING WITH METHANOLAND HEATED I% KCL 8.5 PPG PUMP 15 BBLS OF METHANOL FOLLOWED BY HEATED 1% KCL TAKING RETURNS TO TIGER TANK UNTIL METHANOL IS DETECTED AT OUT North America -ALASKA - B P Operation Summary Report Common Well Name: P-04 AFE No Event Type: RE-ENTER- ONSHORE (RON) Stan Date: 12/15/2018 End Date: 13/2019 X3 -0197J -C: (2,351,407.00 ) ---Site: Rig Nanre/No.: CDR -2 I Spud Date/Time: 6/11/1991 12:00 00AM Rig Release: Page 11 Rig Contractor: NABORSALASKA DRILLING INC. - 14:20 3PL101: USA00001646 - Active datum: KB @91.64usft (above Mean Sea Level) P 1420 Date From - To Him Task Code NET Total Depth Phase Description of Operations hr) (usft) 00:30 - 08:00 5.50 KILLW P 11,491.00 PRE RIH FROM SURFACE TO 11491' HOLD PJSM WITH RIG CREW -ALSO COVER PRE SPUD SLIDE PACK WITH CREW. OPEN WELL TO CLOSED CHOKE -0 PSI ON WELLHEAD SET OPERATING PRESSURE ON CHOKE TO MAINTAIN 100 PSI WELL HEAD PRESSURE. RIH AT 50 FPM PUMPING AT 0.25 BPM WITH HEATED I%KCL8.5 PPG UNTILPASSING ''. PERMAFROST AT 2300', NO WELL HEAD PRESSURE INCREASE ,OBSERVED WHILE RIH AND PUMPING. FILL • DOWN BACKSIDE. APPROXIMATELY 5 BBLS TO FILL. - ! INCREASE RUNNING SPEED TO 80 FPM CONTINUING TO HOLD 100 PSI ON CHOKE. NOTE: PULL BACK TO SURFACE FROM 100' TO RE CALIBRATE BHI DEPTH COUNTER. STOPAGAIN AT 10000' TO FINISH CALIBRATION. NOTE: STOP AT 200 BELS SHIPPED OUT TO TIGER TANKAND CONFIRM WITH MANUAL STRAP. TT SENSOR MATCHES MANUAL (STRAP. 06:00 - 07:40 1.67 KILLW P 11,491.00 PRE 'LIGHT TAG ON WHIPSTOCKAT 11,491' UNCORRECTED. PICK UP WAND INCREASE PUMP RATE TO 4 PICK BPM. PUMP ALL KCL WATER THEN SHUT DOWN. HAVEN'T GOT A BOTTOMS UP YET SO SM WELL AT CHOKE WHILE TT IS EMPTIED OUT. RESUME PUMPING A FULL B/U_ 07'.40 - 08.20 067 KILLW P 0.00 PRE AFTER B/U SUIT DOWN PUMP. PJSM AND REVIEW NABORS PROCEDURE TO PURGE ANY TRAPPED GAS OUT OF CT RISER. HOOK UP BLEED HOSE FROM RISER OUT TO TT, PUMP FLUID OUT TO TT. UNHOOK HOSE AND PURGE WITH AIR FROM RIG FLOOR. 08.20 - 10:30 2.17 KILLW P 10:30 - 14:20 3.83 KILLW P 1420 - 15:30 1.17 KILLW P Printed 1/11/2019 10:26:57AM 11,491.00 PRE CONTINUE CIRCULATING MUD TO NOZZLE. AFTER MUD AROUND NOZZLE, START POOH. AFTER MUD GETS TO SURFACE, BRING RETURNS INSIDE, PURGE TIGER TANK LINE WITH AIR. FLOW CHECK WELL. RETURN FLOW DIMINISHING SLOWLY. USE 16 OZ CONTAINER TO FINGERPRINT WELL. IST 16 OZ -2.5 MIN TO FILL 2ND -5 MIN 3RD -15 MIN FLOW HAS STOPPED AFTER 15 MORE MIN. 10 MIN FLOWCHECK IS GOOD. 11,491.00 PRE (CONTINUE POOH. TAG STRIPPER AND RUN BACK IN 500' TO GET CORRECT DEPTH COEFFICIENT FOR BHI. 11,491.00 PRE TAG STRIPPER. PJSM WITH NABORSAND BHI CREW FOR I BHA. LJD NOZZLE BHA. MAKE UP TIW TO SAFETY JOINT, Printed 1/1112019 10:26:57AM North America - ALASKA - BP Page 12 CO Operation Summary Report Common Well Name: P-04 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/15/2018 End Date: 1/3/2019 X3 -0197J -C: (2,351,407.00) Project: PBU - -- - - - Site: P Rig Name/Nc.: CDR -2 Spud Date/Time: 6/11/1991 12:00:00AM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. SPUOI: USA00001646 Active datum: KB @91.64usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations 1530 - 1730 2.00 STWHIP P 11,491.00 WEXIT PJSM THEN MN BHA #2, WINDOW MILL. WHILE PICKING UP BHA WALK THROUGH SAFETY JOINT PROCEDURE WITH NEW CREW MEMBERS. MILLAND REAMER BOTH 3.80 GO, 3.79" NO-GO _ 1730 2000 2.50 STWHIP P 11,491.00 '., WEXIT RIH WITH BHA#2 TO 11390' PERFORM GAMMA RAV TIE IN -10' CORRECTION CONTINUE TO RIH FROM 11390' AND DRV TAG WHIPSTOCK 20:00 - 20:30 0.50 STWHIP P 11,519.00 WEXIT _ 'CONTINUE RIH AND DRV TAG 11518.5' WITH 12.8K DOWN. 20:30 - 00:00 3.50 STWHIP P 11,521.00 WEXIT MILL 3.80" WINDOW IN 5-1/2"X75/8" DUAL STRING PER BAKER REP FROM 11518.5' b '- RATE: 2.85 BPM IN, 2.85 BPM OUT -MUD WEIGHT: 8.6 PPG IN, 8.58 PPG OUT -SEE MOTOR WORKAT 11518.5 SUSPECTED CEMENT -START MILLING WINDOWAT 11519.3'TO .11521.5 - DWOB. O- 3.2KLBS - CIRC PRESSURE'. 2480-2550PSI1- 12/24/2018 00:00 - 06:00 6.00 STWHIP P 11,52650 WEXIT MILL 3.80" WINDOW IN 5-1/2"X 7 5/8" DUAL STRING PER BAKER REP - RATE: 2.8 BPM IN, 2.8 BPM OUT - MUD WEIGHT: 8.59 PPG IN, 8.54 PPG OUT SEE MOTOR WORKAT 11518.5 SUSPECTED CEMENT -START MILLING WINDOW AT 11521.5' TO 11526.5' - DWOB: 3- 3.5KLBS -_ -CIRC PRESSURE:2480-2550 PSI 06:00 - 12:00 6.00 STWHIP P 11,526.50 WEXIT MILL 3.80" WINDOW IN 5-1/2"X75/8" DUAL STRING PER BAKER REP FROM 11525.3' MD TO 11526.9' MD - RATE: 2.74 BPM IN, 2.73 BPM OUT - MUD WEIGHT: 8.58 PPG IN, 8.54 PPG OUT - DWOB'. 3.4 - 3 8 KLBS - CIRC PRESSURE: 2500 - 2650 PSI - GETTING GOOD AMOUNT OF METAL ACROSS SHAKER. 12.00 - 16:30 4.50 STWHIP P 11,528.60 WEXIT MILL 3.80" WINDOW IN 5-1/2"X 7 5/8" DUAL STRING PER BAKER REP FROM 11526.9' MD TO 11 529'BOW MD - RATE: 2.76 BPM IN, 2.77 BPM OUT - MUD WEIGHT: 8.58 PPG IN, 8.54 PPG OUT -DWOB: 3.4-3.8 KLBS - CIRC PRESSURE: 2500-2650 PSI AT 11527.5 PUMP 10 BBLS LO / HI VIS SWEEPS AROUND. -APPEAR TO HAVE EXITED CASING AT 11529' BASED ON MILLING PARAMETERS. PUMP UP A SAMPLE FROM THAT DEPTH. -SAMPLE AT 11529' CONFIRMED TO HAVE SHUBLIK 'FORMATION Printed 1/1112019 10:26:57AM TREE= 4-1/16" FLS CNV V1B-LF£Ab= ACTUATOR= CIVY BAKERC INITIAL KB. ELE 91.64' BF. ELEV =_ 53.9 KO—P= 1700' Max Angle = Dehm M)= 98' @ 1305Y 11501' Gahm TVD= 8800 SS D=ts.tza- ly —rIe = 9.950' 2734' Minimum ID = 2.38"@11537' 2-7/8" LINER CONNECTIONS 1.4-1/2' TBG, 12.6", NT-13CRTDS, 11288' 0152 bpf, D = 3.958' DE -TA Wi-PSTOCKw/2 RA PPTAGS 11519' D = 6.875" OF 2-7/8' LNR P-04 L1 2-7/8' SLTD SAFETYNOT6: WELLANGLE>70o@ 11694"" CHROME TBG & LNR — r.AS 1 FT MA WAR S ST PERFORATION SUMMARY I TVD I DEV REF LOG: AWS BHCA ON 06/26/91 VLV I LATCHI PORT ANGLE AT TOP PERF: 45" @ 11509' 5 Nobe: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I OpNSgz I SHOT I SOZ DW P-04 10/03/18 3-318-1 6 11509-11537 S 05/18/93 11/11/18 3-318" 611662-11692 3 S 07/16/91 11/11/18 3-3/8" 4 11692-11712 S 07/16/91 11/11/18 3-318' 4 11722-11768 S 07/12/91 11/11/18 1 P -04L1 8680 2" 4 11750-12420 S 06/26/02 11/11/16 2-71W 1 SLTD 11748-13097 S 05/02/00 11/11/18 P-04 L1 2-7/8' SLTD SAFETYNOT6: WELLANGLE>70o@ 11694"" CHROME TBG & LNR — r.AS 1 FT MA WAR S ST MD I TVD I DEV I TYPEI VLV I LATCHI PORT DATE 5 3110 3010 37 CA DW BK 0 10/03/18 4 6765 5456 50 CA OM1' BK 0 10/03/18 3 9225 7163 41 CA OW BK 0 10/03/18 2 10593 8211 39 CA 'DMY BK 0 10/17/13 1 11204 8680 44 CA DMY BK 010/03118 ' STA 9 2 = WAY HAS EXTENDED PACKING 11— 2� 4-1Y1" PKR SM NIP. D = 3.81 1 17-5/8- X 4-1/2' TW HBBP PKR, D = 4.0' 5-1/2' MLLOLFr EXTBJSDN, D = 4.865' 4-112' PKR SM NP, D = 3.813' MILLED D = 3.80' { 11288'—�4-12'WLEG,D=3.958' 11285' ELMD TT LOGGED 07/12/91 OFCMT. 2.50' PITCH POM OF MLLOL)TVVNDOW(P-041.1) 11549'-11555' D=7 PRUDHOE BAY UNIT VVELL: R04 / L1 PERMTNo: 2000500 AR No: 50-029-22180-60 SEE 31, T71 N, RI 3F, 2564' FSL & 2001' FWL DATE REV BY COMETS DATE REV BY COMMENTS I 07/12/91 AL 1112 INITIAL COMPLETION 10/08/18 GJB/JMJ RAL -18' DEPLY SLV & CUT LNR 05103100 NORDIC 1 SIDETRACKCOMPLETON 10/08/18 JMGIJMJ GLV C/O (10102118) 1 06/16/13 PJC P-04 & P -04L1 LATERAL C1UP 10/31/18 BTNJM) SET VN-PSTOCK w /2 RA PP TA 07/17117 CJNJM) GLV CrO (07/13117) 11/15/18 JCF/JM) CMT WS & PRE -RIG CMT 08/27/18 JN fJMJ EDITED BF ELEV & 5-1/2" LNR DEPTH BP Exploration (Alaska) 10/01/18 MS/JMD JETCUTLNR(09/29/18) 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. Well History File Identifier Organization (done) [] Two-Sided RESCAN ~/,,,~lor items: ~ Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA V'"~'Diskettes, No./ [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES' ,~~-~ NOTES: ORGANIZED BY: BEVERLY BR~HERYL MARIA LOWELL [] Other DATE:,~"" ~ y Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BRE~HERYL MARIA LOWELL PAGES: Lc-~-~ (at the time of scanning) SCANNED BY; BEVERLY BREN VlNC~ARIA LOWELL RESCANNEDBY: BEVERLY BRE~_.c~'HERYL MARIA LOWELL DATE: ¢~/ ~,~ General Notes or Comments about this file: PAGES: +~_____ Quality Checked (done) Rev1 NOTScanned.wpd ~~. . "" ". "\;\ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Permit to Drill No. 2000500 Well Name/No. PRUDHOE BAY UNIT P-04L1 Operator BP EXPLORATION (ALASKA) [NC AP1 No. 50-029~22180-60-00 MD 13097 TVD 9051 Completion Date 5/2/2000 / Completion Status I-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__~o Samples N___9o Directional Survey ~ ~/.~ ..... / __ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital DiGital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments l ED D Ver Rpt Ver 1 11532 13050 Ope 1/24/2002 10524 I 11532 13050 Ope 1/24/2002 Well Cores/Samples Information: Name Start Interval Dataset Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis Received? __Y. LI:~I~-~ Daily History Received? ~ Formation Tops Receuived? ~) / N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs P-04 L1, 1 LDWG formatted Disc with verification listing. API#: 50-029-22180-60 January 21, 2002 AK-MW-00030 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TIlE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Gal~Sn 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED Jkfq £ '; 2002_. STATE OF ALASKA ALAS~ ,L AND GAS CONSERVATION COM~ SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service I~Oil I-I Gas I-! Suspended I-I Abandoned ~J~Service 2. Name of Operator,,~.~-'~5 ~,~'~'~/ ~-'~'~ 7. Permit Number BP Exploration (Alaska) Inc. 200-050 3. Address~'~"~ q~ ~'~'~'~'~ ~8. APl Number i" ~!:: :'. .:,. ' ,' P.O. Box 196612, Anchorage, Alaska 99519-6612 ' 50-029-22 80-60 4. Location of well at surface 9. Unit or Lease Name; 2564' NSL, 2001' EWL, SEC. 31, T11N, R13E, UMAt top of productive interval ~ ~ ~,~'~ Prudh°e Bay Unit i "~:~ 414' NSL, 3128' EWL, SEC. 32, T11N, R13E, UM At total depth,,~,~,~ 10. Well Number 222' NSL, 4490' EWL, SEC. 32, T11N, R13E, UM P-04L1 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation~'d Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 91.64' ADL 028286 12. Date Spudded 113. DateT. D. Reached .14. Date Comp., Susp., or Aband. 115. Water depth, if offshore .16. Ho. of Completions 4~27/2000 I 15/1/2°°° .5/3/2000 f?' Z'/~"~"~t N/A MSL] One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 13097 9051 FTI 13097 9051 FTI [] Yes [] NoI (Nipple) 2182' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, RES, ROP 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" Surface 100' 30" 10-3/4" 45.5# L-80 Surface 2734' 13-1/2" 2622 cuft Permafrost 7-5/8" 29.7# NT95HS Surface 11541' 9-7/8" 1742 cu ft Class 'G' 5-1/2" 17# NT13Cr80 11284' 11549' 6-3/4" 170 cu ft Class 'G' 2-7/8" 6.16# L-80 11531' 13097' 3-3/4" Uncemented Slotted Liner 24. Perforations open to, Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, NT13Cr80 11287' 11232' MD TVD MD TVD 11748'- 13082' 9017'-9053' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11546' Set Flow-Through Whipstock 2000' Freeze Protect with 25 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 15, 2000 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER'BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Eileen 11687' 9002' Top Sadlerochit 11694' 9004' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble /'~/1~ ~ Title Technical Assistantlll Date P-04L1 200-050 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: P -04 L 1 Acce pt: 04~25/00 Field: Prudhoe Bay Spud: 04~27/00 AP I: 50-029- 22180-60 Release: 05/03/00 Permit: 200-050 CTD Unit: Nordic #1 PRE-RIG WORK 04/15/00 Miru SWS #2150. RIH w/5 ½" Baker Permanent Whipstock. Tie-in to GR / CCL Tie in Log (12-Jul-91), set whipstock top at 11,546', 18.5 degrees right of high side looking down. RIH and tagged whipstock at same depth. POOH. RDMO. COIL TUBING DRILLING 04/26/00 1 Accept rig 20:30 hrs. NU and test BOPE. Attempt BH kill. Locked-up immediately (history of hydrates). MU 3.25" nozzle and lubricate into well. RIH. Jet on choke w/500 psi back pressure. Stack-out and broke thru at 4072'. WHP jumped to 800 psi. SI choke. Switch to kill line and bullhead kill well with 220 bbls FIo-Pro while POOH slowly. Park at 300' to replace cotter pins in chains and monitor well. Well still flowing. Didn't get clean sweep of gas on bullhead kill. RIH to circulated out residual gas. 04/27/00 2 TIH to 5000', circulate out gas. Stage in hole to 11500', circulating out gas and crude oil. POOH, PU Window Milling BHA. TIH. Tag on XN, correct depth, mill. RIH to whipstock. Could not maintain enough rate for milling due to gas buster limitations. Circulate out gas and crude. RU HB&R. BH kill well down kill line and coil with 245 bbls SW. SI and monitor pressures. Determine mud wt increase and call for 10 ppg mud. Circulate new mud to bit at constant WHP. Circulate BU on choke schedule. SI well. No flow. Well drinking a little. Start milling window at 11,549'. 04/28/00 3 Finish milling window to 11,555'. Mill 10' of formation. POOH. LD window milling BHA. MU drilling BHA (1.7 deg motor; M09 bit). RIH. Drill build section to 11820'. Landed. POOH. LD BHA. PU drilling BHA #3 (resistivity tool; 1.1 deg motor; DS49 bit). RIH. O4/29/OO 4 RIH with drilling BHA #3. Drill horizontal 11820' - 11934'. Pin-hole in HP mud line between mud manifold and coil. PUH above window. Cut and remove mud line; bypass with temporary DS hard line. Drill 11934' - 12420'. 04/30/00 5 Drill 12435' - 12730'. Lost circulation started at 12684', increased to 75% losses at 12705'. Mix and pump 29 bbls Form-a-Set LCM pill. Lay in from TD, holding 200 psi squeeze pressure. PUH. Circulate on choke w/100 psi WHP while LCM sets-up. Full returns. Wash into hole. Started seeing losses at 12684'. Drill to 12775' with 50% losses. POOH. LD drilling BHA. Download resistivity data. MU and RIH with nozzle for bentonite cement LCM. XXX, Coil Tubing Drilling Page 2 05/01/00 6 TIH w/nozzle. Correct depth at flag (-26'). TIH to 12550', pump 28 bb113.8 ppg cement w/8% bentonite (5 bbl neat, 10 bbl w/15 ppb aggregate, 13 bbl neat). Close choke and pump 13 bbl into formation, squeezing to 1200 psi. Open choke, put out 1 bbl and pull uphole laying in at 1:1 while holding 500 psi squeeze pressure. Pull to safety and squeeze to 950 psi (open Sag perfs taking fluid?). Wash back in hole to 12300', POOH while circulating out cement. LD Cement BHA, PU Drilling BHA. RIH. Ran Tie-in log. RIH. Cleaned out to 12700'. Wiper trip to window. Cleaned out to 12780'. Drilled to 12787' w/Wt transfer problems. Wiper trip to 12600'. Working back to btm. 05/02/00 7 Drilled to 12938' losing 0.5-1.0 bpm. Wiper trip to window. Drilled to 13006'. Mad pass to window while WO mud. Drilled to 13077'. Loss rate increased to 1.5 bpm. Wiper trip to 13000'. MAD pass f/13077- 13000'. Wiper trip to window. Ran tie-in log (+23' correction). TD @ 13097'. POH. Download MWD sub. 05/03/00 8 Downloaded Sperry Resistivity Data. LD BHA. Held Safety meeting. PU Slotted liner assy (OAL:1565.59'). Ran 1-1/4" CSH wash string inside liner. MU Baker CT liner running tool. MU injector. RIH w/liner to TD at 13,097'. Disconnect from liner. POOH. Lay out CSH workstring in singles. M/U nozzle BHA and RIH to 11,500 ft. Displace well to seawater and recover 10 PPG FIoPro. Freeze protect tubing from 2000' to surface with MEOH. SIWHP = 800 psi. Close master valve and pressure test. Blow down CT with N2. Close Swab valve. Clean rig pits and green tank. Pull CT stub to reel and secure it. Remove gooseneck. Set injector head in pipe bay and nipple down BOPE. 05/04/00 9 ND Stack. NU tree Cap. Tested to 3500 psi, Rig released 5/3/00 @ 0700 hrs. Moved off well. Had 1 pint hydraulic leak. Contacted PBU spill tech. Cleaned up leak. LD derrick & moved off P-pad. North Slope Alaska Alaska State Plane 4 PBU_ WOA P Pad P-O4L 7 Surveyed: 2 May, 2000 SURVEY REPORT 7 June, 2000 Your Ref: API-500292218060 Surface Coordinates: 5947292.00 N, 631284.00 E (70° 15' 50.7547" N, Kelly Bushing: 91.64ft above Mean Sea Level 148°56'18.8088"W) Survey Reft s vy9788 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for P-O4L 1 Your Ref: AP1-$00292218060 Surveyed: 2 May, 2000 Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11487.49 44.980 124.710 8790.66 8882.30 2060.14 S 6001.33 E 11546.00 44.950 123.869 8832.06 8923.70 2083.44 S 6035.49 E 11578.93 49.390 122.539 8854.44 8946.08 2096.65 S 6055.70 E 11611.73 55.020 121.419 8874.53 8966.17 2110.36 S 6077.68 E 11641.13 60.030 120.519 8890.31 8981.95 2123.12 S 6098.94 E 11673.73 66.420 119.629 8904.99 8996.63 2137.69 S 6124.12 E 11714.33 74.350 115.209 8918.62 9010.26 2155.25 S 6158,04 E 11744.93 80.160 112.039 8925.37 9017.01 2167.19 S 6185.38 E 11775.33 84.990 108.879 8929.30 9020.94 2177.72 S 6213.61 E 11809,39 87.220 106.609 8931.61 9023.25 2188.07 S 6245.97 E 11836.79 86.700 102.639 8933.06 9024.70 2194.98 S 6272.44 E 11866.79 86.520 99.389 8934.84 9026.48 2200.70 S 6301.83 E 11895.19 87.580 95~859 8936.30 9027.94 2204.46 S 6329.94 E 11927.19 87.580 92.689 8937.65 9029.29 2206.85 S 6361.82 E 11957.79 87.220 88.109 8939.04 9030.68 2207.06 S 6392.38 E 11988.79 86.430 84.229 8940.76 9032.40 2204.99 S 6423.25 E 12024.39 84.670 89.699 8943.52 9035.16 2203.11 S 6458.68 E 12055.59 83.790 92.869 8946.66 9038.30 2203.81 S 6489.71 E 1'2090.39 83.350 97.979 8950.56 9042.20 2207.07 S 6524.13 E 12120.99 85.090 103.959 8953.64 9045.28 2212.86 S 6554.00 E 12156.19 86.960 107.319 8956.08 9047.72 2222.33 S 6587.81 E 12185.59 87.220 112.079 8957.58 9049.22 2232.23 S 6615.44 E 12218.99 88.280 115.779 8958.89 9050.53 2245.76 S 6645.94 E 12249.79 88.810 119.119 8959.67 9051.31 2259.95 S 6673.26 E 12280.59 88.370 118.239 8960.43 9052.07 2274.73 S 6700.28 E 5945336.81N 637320.34 E 5945314.12 N 637354.90 E 5945301.26 N 637375.33 E 5945287.93 N 637397.55 E 5945275.55 N 637419.03 E 5945261.42 N 637444.46 E 5945244.46 N 637478.69 E 5945232.99 N 637506.23 E 5945222.96 N 637534.64 E 5945213.17 N 637567.17 E 5945206.72 N 637593.76 E 5945201.52 N 637623.25 E 5945198.25 N 637651.42 E 5945196.42 N 637683.33 E 5945196.74 N 637713.89 E 5945199.34 N 637744.73 E 5945201.84 N 637780.12 E 5945201.69 N 637811.15 E 5945199.02 N 637845.62 E 5945193.75 N 637875.59 E 5945184.88 N 637909.56 E 5945175.47 N 637937.36 E 5945162.47 N 637968.09 E 5945148.75 N 637995.65 E 5945134.45 N 638022.92 E Dogleg Rate (°/'~OOtt) 1.017 13.804 17,375 17.235 19.752 22.055 21.506 18.937 9.331 14.593 10.831 12.962 9.897 14.998 12.754 16.096 10.495 14.646 20.257 10.904 16.194 11.515 10.976 3.194 Alaska State Plane 4 PBU_WOA P Pad Vertical Section (ft) Comment 6267.55 6305.23 6327.42 6351.45 6374.60 6401.92 6438.38 6467.37 6497.0O 6530.66 6557.93 6587.87 6616.20 6648.01 6678.14 6708.19 6742.76 6773.44 6807.90 6838.33 6873.26 6902.19 6934.58 6963.94 6993.11 Tie-on Survey Window Point MWD Magnetic Continued... 7 June, 2000 - 13:19 - 2 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. 12313.59 12343.79 12378.39 12411.99 12444.39 12480.59 12516.99 12561.39 12593.79 12618.19 1265O.39 12678.59 12702,79 12736.09 12764.64 12796.84 12826,44 12854.44 12881.44 12922.44 12958.54 12995.34 13026.54 13049,74 13097.00 88.460 86.430 86.780 86.960 86.080 83.260 83.000 82.910 82.290 84.320 89.070 92.160 94.270 95.070 95.330 93.740 91.450 90.040 90.930 93.570 93.850 95.770 96.650 97.710 97.710 Azim. 114.719 110.489 106.789 102.739 99.039 96.739 92.689 87.759 84.939 82.469 85.289 86.699 88.109 93.219 96.569 94.979 92,339 91,809 90.579 90.579 90.689 90.929 91.279 92.339 92.339 Sperry-Sun Drilling Services Survey Report for P-O4L 1 Your Ref: API.500292218060 Surveyed: 2 May, 2000 Sub-Sea Depth (ft) 8961.34 8962.69 8964.74 8966.57 8968.54 8971.90 8976.26 8981.71 8985.88 8988.73 8990.58 8990.28 8988.92 8986.21 8983.62 8981.08 8979.74 8979.37 8979.14 8977.53 8975.20 8972.11 8968.74 8965.84 8959.50 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9052.98 2289,43 S 6729.80 E 5945120.26 N 638052.70 E 9054.33 2301.03 S 6757.64 E 5945109.16 N 638080.74 E 9056.38 2312.06 S 6790.36 E 5945098.69 N 638113.65 E 9058.21 2320.61 S 6822.80 E 5945090.71N 638146.23 E 9060.18 2326.72 S 6854.55 E 5945085.16 N 638178.08 E 9063.54 2331.67 S 6890.25 E 5945080.83 N 638213.86 E 9067,90 2334.64 S 6926.26 E 5945078.49 N 638249.91 E 9073.35 2334.81S 6970.31 E 5945079.09 N 638293.96 E 9077.52 2332.76 S 7002,37 E 5945081.69 N 638325.98 E 9080.37 2330.11S 7026.45 E 5945084,77 N 638350.01 E 9082,22 2326.68 S 7058.40 E 5945088.75 N 638381.90 E 9081.92 2324.71S 7086.53 E 5945091,21 N 638409.99 E 9080.56 2323.62 S 7110.66 E 5945092.72 N 638434.10 E 9077,85 2324.00 S 7143,84 E 5945092.92 N 638467.28 E 9075.26 2326.43 S 7172.16 E 5945090.99 N 638495.64 E 9072.72 2329.65 S 7204.10 E 5945088.32 N 638527.63 E 9071.38 2331.54 S 7233,60 E 5945086.94 N 638557.16 E 9071,01 2332.55 S 7261.58 E 5945086,42 N 638585.15 E 9070.78 2333.12 S 7288.57 E 5945086.33 N 638612.15 E 9069.17 2333.53 S 7329.54 E 5945086.63 N 638653.11 E 9066.84 2333.93 S 7365.56 E 5945086.86 N 638689.14 E 9063.75 2334.45 S 7402.22 E 5945086.98 N 638725.80 E 9060.38 2335.04 S 7433.24 E 5945086.92 N 638756.82 E 9057.48 2335,77 S 7456.24 E 5945086,60 N 638779.84 E 9051,14 2337,68 S 7503.03 E 5945085.50 N 638826,66 E Dogleg Rate (o/-~ooft) 10.666 15.523 10.723 12.047 11.718 10.035 11.070 11.022 8.841 13.049 17.147 12.044 10.481 15,482 11.721 6.972 11.799 5.380 5.623 6.439 0.833 5.258 3.033 6.436 0.000 Alaska State Plane 4 PBU_WOA P Pad Vertical Section (ft) Comment 7024.73 7054.17 7088.31 7121.73 7154.06 7190.07 7226.O5 7269.47 7300.69 7323.95 7354.82 7382.18 7405.76 7438.50 7466,82 7498.83 7528.21 7555.94 7582.63 7623.04 7658.59 7694.79 7725.43 7748.21 7794.63 Projected Survey Continued... DrillQuest 1.05.05 7 June, 2000 - 13:19 - 3 - North Slope Alaska Sperry-Sun Drilling Services Survey Report for P-O4L 1 Your Ref: API.500292218060 Surveyed: 2 May, 2000 Alaska State Plane 4 PBU_WOA P Pad .All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.965° (26-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 99.980° (True). Based upon Minimum Curvature type calculations,' at a Measured Depth of 13097.00ft., The Bottom Hole Displacement is 7858.77ft., in the Direction of 107.305° (True). Comments MeaSured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11487.49 8882.30 2060.14 S 6001.33 E Tie-on Survey 11546.00 8923.70 2083.44 S 6035.49 E Window Point 13097.00 9051.14 2337.68 S 7503.03 E Projected Survey Continued... DrillQuest 1.05. 05 7 June, 2000 - 13:19 - 4 - North Slope Alaska Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 11546.00 8923.70 To Measured Depth (ft) 11546.00 13097.00 Sperry-Sun Drilling Services Survey Report for P-O4L 1 Your Ref: AP1-$00292218060 Surveyed: 2 May, 2000 Vertical Depth 8923.70 9051.14 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic Alaska State Plane 4 PBU_WOA P Pad 7 June, 2000 - 13:19 - 5 - DriliQuest 1.05.05 RE: PBU P-04A Subject: RE: PBU P-04A Date: Thu, 25 May 2000 12:48:54 -0500 From: "Hubble, Terrie L (NANA)" <HubbleTL~BP.com> To: "'McMains, Steve (AOGCC)'" <Steve_McMains~admin.state.ak.us> Hi Steve, I have just re-read this message and I still think we don't have the well name quite right. I don't know why I didn't catch it the last time around, but here we go... We did not abandon P-04. It has a flow-through whipstock in place and will continue to produce through the existing perfs. The new lateral in our opinion should be called P-04L1, not P-04AL1, since the original hole is not abandoned. Do you agree? Terrie From: Steve McMains[SMTP:steve mcmainsOadmin.state.ak.us] -- Sent: Thursday, May 04, 2000 9:15 AM To: Terri Hubble Cc: Sharmine Copeland; Gary Benson Subject: PBU P-O4A Terri, After reviewing the approved form 10-403 for this well, Bob Crandall agreed with us that this well should be a "LATERAL WELL". Make sure all appropriate people know of this change, Ted and i.e ........ I am going to put this in the weekly report next week. I am changing the well name/number and api number now to correct this error to the following: Old data: Prudhoe Bay Unit P-O4A and API number 029-22180-01 New data: Prudhoe Bay Unit P-O4AL1 and API number 029-22180-60 Steve McMains 1 of 1 5/25/00 11:34 AM PBU P-04A Subject: PBU P-04A Date: Thu, 04 May 2000 09:15:11 -0800 From: Steve McMains <steve_mcmains~admin. state.ak.us> To: Terri Hubble <hubbletl~bp.com> CC: Sharmine Copeland <copelasv~bp.com>, Gary Benson <BensonGA~bp.com> Terri, After reviewing the approved form 10-403 for this well, Bob Crandall agreed with us that this well should be a "LATERAL WELL" Make sure all appropriate people know of this change, Ted and i.e ........ I am going to put this in the weekly report next week. I am changing the well name/number and apl number now to correct this error to the following: Old data: Prudhoe Bay Unit P-04A and API number 029-22180-01 New data: Prudhoe Bay Unit P-04AL1 and API number 029-22180-60 Steve McMains 1 of 1 5/4/00 9:15 AM ALASi~A OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re' Prudhoe Bay Unit P-04ALI BP Exploration (Alaska), Inc. Permit No: 200-050 Sur Loc: 2564' NSL, 2001' EWL, Sec. 31, TllN, R13E, UM Btmhole Loc. 225' NSL, 4625' EWL, Sec. 32, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THE COMMISSION DATED this { ~'L~ day of April, 2000 dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: ~1 Abandon [] Suspend .r.. Plugging [] Time Extension [] Pedorate ~] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2564' NSL, 2001' EWL, SEC. 31, T11N, R13E, UM At top of productive interval 434' NSL, 3088' EWL, SEC. 32, T11N, R13E, UM At effective depth 331' NSL, 3229' EWL, SEC. 32, T11N, R13E, UM At total depth 294' NSL, 3277' EWL, SEC. 32, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 91.64' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number P-04 9. Permit Number 191-076 10. APl Number 50- 029-22180-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: Casing true vertical measured true vertical 12010 feet 9265 feet 11921 feet 9200 feet Length Size Structural Conductor 100' 20" Surface 2698' 10-3/4" Intermediate 11505' 7-5/8" Production Liner 709' 5-1/2" Plugs (measured) Junk (measured) ", ,'~:: ;'-i: Fish: CT Connector, Check Valves and Nozzle (8/96) Cemented MD TVD 2622 cu ft Permafrost 1742 cuft Class 'G' 170 cu ft Class 'G' 100' 100' 2734' 2652' 11541' 8920' 11284'-12005' 8738'-9262' Perforation depth: measured 11509'- 11537', 11662'- 11692', 11692'- 11712', 11722'- 11768' true vertical 8898'-8917', 9007'-9030', 9030'- 9045', 9052'-9087' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NT13Cr-80 at 11287' Packers and SSSV (type and measured depth) 7-5/8" TIW packer at 11232'; Otis SSSV Landing Nipple at 2182' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation April 11, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Ted Stagg, 564-4694 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: []Oil []Gas []Suspended Service Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the forego~g is true and correct to the best of my knowledge Signed Ted Stagg Title CT Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integ~ ~ BOP Test ~ Location clearance ~ Mechanical Integd~ Test ~ Subsequent fo~ required 1 o- Approv~ by order of the Commi~ion ORIGINAL SIGNED' BYA~v~,t~,, Form 10-403 Rev. 06/15/88 ~OOe~ N' Oi"~O¢~ ']~~ Submit In Tdpli~te STATE OF ALASKA ALASK/=~'~'L AND GAS CONSERVATION COMr'~"SION PERMIT TO DRILL 20 AAC 25.005 1al Type of work [] Drill [] Redrili 1 lb. Type of well [] ExploratorY [] StratigraPhic Test [] Development Oil [] Re-EntrY [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 91.64' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028286 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2564' NSL, 2001' EWL, SEC. 31, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 434' NSL, 3088' EWL, SEC. 32, T11N, R13E, UM P-04A L, ~ ~ Number 2S100302630-277 At total depth 9. Approximate spud date 225' NSL, 4625' EWL, SEC. 32, T11N, R13E, UM 04/20/00 Amount $200,000.00 12. Distance to nearest property line !13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028289, 225' MD! ... No..Close. A. ppr~oach ... 2560 13222' MD / 8936' TVD ::i"6. TO' be co~plete~'"for d~viate'd wells ........... 17. ~ntici'pated pressure {s~'e 20' AAC 35.035 (e) (2)} Kick off Depth 11535' Maximum Hole .A. ngle ........... 96 o . ....... Maximum surface 2490 psig, At total depth (TVD) 8800' / 3545 psi.g. 18. Casing Program I ....... Specifications S~tting '~)epth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Couplin,q Length MD TVD MD TVD (include sta.qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1727' 11495' 8796' 13222' 8936' Uncemented Slotted Liner ... ... ... .... ..... ................ . ..... ......... .. ...... ............ 19. "re be completed for F{edrill, F{e-entry, and Deepen OperationSOpresent well condition summary Total depth: measured 12010 feet Plugs (measured) true vertical 9265 feet Effective depth: measured 11921 feet Junk (measured) Fish: CT Connector, Check Valves and Nozzle (8/96) true vertical 9200 feet Casing Length Size Cemented MD TVD Structural Conductor 100' 20" 100' 100' Surface 2698' 10-3/4" 2622 cuft Permafrost 2734' 2652' Intermediate 11505' 7-5/8" 1742 cuft Class 'G' 11541' 8920' Production Liner 709' 5-1/2" 170 cu ft Class 'G' 11284'.~-12005' ~. ~. ,~738~.~ 9262' . Perforation depth: measured 11509' - 11537', 11662' - 11692', 11692' - 11712', 11722' - 11768' true vertical 8898' - 8917', 9007' - 9030', 9030' - 9045', 9052' - 9087' , 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements contact Engineer Name/Number: Ted stagg; 564;4694: Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the forego~g/~,tr_ue and correct to the best of my knowledge / / Signed Ted Stagg -- Title CT Drilling Engineer Date --~ ...... P';:~:~i:~:~:~':~:~::~:~:;:~® ............................ :":':':' ..................................... ':'¥:":~'~'i'*"~'U~'i~';'~'"'""'~" ............... ' ...... ' ........... " ................. "' .................... I" Approval Date I See cover letter , 04-) for other re u~rements oo- 150-029-22180-~o ~ I <)//~/~ ] q ' Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes j~'No Hydrogen Sulfide Measures 1RI Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2K; [] 3K; [] 4K; [] 5K; [] 10K; [] 15K Other: ORIGINAL SIGNED. BY by order of Approved By Robert N. ChrJsten.~n.n. Commissioner the commission Date ............. Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX P-04a Sidetrack Summary of Operations: P-04 is being sidetracked to target Zone 4 reserves. This sidetrack will be conducted in two phases. Phase 1: Set retainer, punch and squeeze straddle annulus, set whipstock: Planned for April 11-14, 2000. · A Mechanical Integrity Test will be performed. · A whipstock drift was run on 3/24/00. · E-Line will be used to set a retrievable, flow-through whipstock at approx. 11,525'. · Service coil will be used to mill the window. Phase 2: Drill and Complete sidetrack: Planned for April 20, 2000. Drilling coil will be used to drill, log and complete the directional hole as per attached plan. Mud Program: · Phase 1' Seawater with FIo-Pro sweeps · Phase 2: FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L slotted liner will be run from TD to approx. 11,495' MD. A small length of solid liner will be used across the Shublik B interval with the remainder of the liner slotted. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction log will be run in the open hole. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3545 @ 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2490 psi. P-04 Vertical Section 8750 8800 8850 8900 -T-SAD ~ 8,935 8950 9O00 9050 9100 - 500 Path Distance (Feet) 1,000 1,500 2,000 t I top perf Angle @ K.O.= 45 deg MD:11535 P-04a case 103 designed to KO @ TSHU. Slotted liner set 30 ft above 1the window. Whipstock will If ICL through. 2,500 Tot Drld: 1687 ft 13222 TD Marker Depths ~)ri~l Wellbore ,SAG I 8,8061,~VD TSHU I 8,8261f, TVD 8,9851 8,9851fl TVD TSAD I 8,9141fl TVD IKick Off 8,8241ft TVD 11,5351ft MD IDeprtr @KO 6,393 ft MD KO Pt 11,535I MD New Hole 1687I I Total MD 13,222I TVD TD 8,9361 DLS de~l/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 18 -30 262 Curve 3 8 -90 150 Curve 4 8, 90 280 Curve 5 8 -90 265 Curve 6 8 90 185 Curve 7 8 0 110 Curve 8 6 -90 415 1,687 Drawn: 3/27/2000 16:00 Plan Name: Case 103 P-04 5, 6,500 7,000 7,500 35 935 X distance from Sfc Loc -1,500 8,( -: 000 ~ 5OO -3,000 -3,500 -4,000 Well Name P-04 J CLOSURE I Distance 7,988 ft Az 106 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 6,064 - 1,974 TD 7,679 -2,201 State Plane 638,962 5,945,091 Surface Loc 631,284 5,947,292 DLS de~l/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 18 -30 262 Curve 3 8 -90 150 Curve 4 8 90 280 Curve 5 8 -90 265 Curve 6 8 90 185 Curve 7 8 0 110 Curve 8 6 -90 415 1,687 Drawn: 3/27/2000 16:00 Plan Name: Case 103 TREE: 4 1/16" - 5M CIW KB. ELEV = 91 WELLHEAD: 11 "- 5M FMC P-(~ 1 Proposed Completion BF. ELEV = 55.26' SSSV LANDING NIPPLE I 21 ~ (OTIS)(3.813" ID) CMT'd-- [] [] 10 3/4". 45.5#/ft. ~ ,~ ~. GAS LIFT MANDREL NT-80 BTRSl--.v. ~ CAMCOw/I" BKLATCH NO. MDtBKB) TVDss DEV. KOP: 1700' 5 3110' 2918' MAX ANGLE: 50~ @ 6200' 4 6765' 5364' 3 9225' 7072' 2 10,593' 8120' 1 11,204' 8588' 4 1/2", 12.6#/ft, 13CR, TDS CHROME TUBtNG ~ ~ 4 1/2" "SWS" NIPPLE I (PARKER) (3.813" ID) I 11,220' TUBING 3,958" CAPACITY: 0.0152 BBL/FT ~ Right-hand release btch ~ 7 5/8" TIW PACKER I 1 1,232' X E X (HR-BP) (4.00" ID) 4 1/2", 12.6fi/~, 13Ct TAILPIPE ~ (PARKER) (3.813" ID) I 1 1,253' ! I h 4 1/2" "SWN" NIPPLE TOP OF TIW ~ t~ (PARKER) (3.725" ID) 1 1,275' 5 1/2" LINER ~ ~ ELMD 11,285'i top slotted linerS0 ft above whipstock ~; ~,,:o1~:~ I:~ leaving room in Sag R. for future sdtrk ~ .~.~ ~, REF LOG: AWS BHCA (6-26-91) ~; ~ ,~_ N ~ ,.~ SIZE SPF INTERVAL OPEN/SQZ'D 3-3/8" 6 11509-11537' Open 5/18/93 Sag ::~;~: ~ ~:~ Lows[ perfs available for 33/8" 4 11692-11712' OPEN/7qC-91 whipstock lO,O0O psi Pack-Off P-04a CT Drilling & Completion BOP 36" 22,5"I 7 1/16" Annular Blind/Shear 7 1/16" Pipe/Slip 2 3/8" 38, Slips 7 1/16" Pipe -- ~ 27/8" __ '~ 2 3/8" SWAB OR MASTER VALVE Alaska hare. d ervlces rilling To: Date: March 27, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re: Well P-04a Prep for CT Sidetrack Well P-04 is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prepare P-04 for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. Note: Existing perfs of P-04 will not be abandoned. Production from the original completion will continue via a flow-through whipstock. The slotted liner to be installed in the sidetrack will not impede flow from the existing perforations. 1. A Tubing Integrity Test will be performed. 2. A whipstock drift was run on 3/24/00. $. The well will be killed with seawater and E-Line will set a retrievable, flow-through whipstock at approx. 11,525'. 4. Service coil will mill the window using seawater and Flo-Pro sweeps. Step 3 is scheduled for April 11, and step 4 is scheduled for April 13, 2000. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Dam Center E~LEL..H 4 1/16" - 5M CIW EAD: 11" - 5M FMC A f'~.TI I ~,TAD- NT-80 BTRS KOP: 1700' MAX ANGLE: 50° @ 6200' Proposed Completion KB. ELEV = 91.64' BF. ELEV = 55.26' CMT'd-- SSSV LANDING NIPPLE (OTIS)(3.813" ID) 2182' I GAS LIFT MANDREL 3AMCO w/l" BK LATCH ,NO. MD(BKB)i TVDss DEV. 5 3110' 2918' 4 6765' 5364' 3 9225' 7072' 2 10,593' 8120' 1 11,204' 8588' 4 1/2", 12.6#/ft, 13CR, TDS CHROME TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT i' I TOP OF TiW"11,284' 5 1/2" LINER 7 5/8., 29.7#~, 1 11,541'I NT-95HS NSCC Flow-Thru Whipstock at TSHU with top slotted liner 30 ft above whipstock leaving room in Sag R. for future PERFORATION SUMMARY REF LOG: AWS BHCA (6-26-91) SIZE SPF INTERVAL OPEN/SQZ'D 3-3/8' 6 11509-11537' Open 5/18/93 Sag 3 3/8" 6 11662-11692' OPEN/7-16-91 3 3/8" 4 11692-11712' OPEN/7-16-91 3 3/8" 4 11722-11768' OPEN/7-12-91 TIE-IN LOG: SWS GPJCCL (7-12-91) ON DEPTH TO BHCA $ 1/2" 17# 13CHROME FL4S LINER. PBTD !,11,922 4 1/2 ....SWS" NIPPLE (PARKER) (3.813" ID) I 11,220' Right-hand release latch 111,231 7 5/8" tlW PACKER I (HB-BP) (4.00" ID) , 1 1,232' 4 1/2", 12.6#/ft, 13Cr TAILPIPE I (PARKER) (3.813" ID) 1 1 ,253! 4 1/2 ....SWN" NIPPLE (PARKER) (3.725" ID) ELMD 11,275' 11,285' 4 1/2" WLEG 11,287' 2 7/8" slotted liner wi solid liner in Shublik B Lower perfs available for production through whipstock _ ~ATE H 1 62395 io_~,o~,..~_ VENDOR ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 3;20300 CKO;203OOD 100. O0 100. O0 HANDLINQ INST' S/H TERRIE HUBBLE IE A]'rACHED CHECK IS IN PAYU[NT FOR ITEMS DESCRIBED ABOVE.iZl]l:lII ! OO. CO ! OO. CO BP EXPLORATION (ALASKA), INC. P.O, BOX 196612 ANCHORAGE, ALASKA 99519-6612 .,.-,.,,,-,o.,,,....,,o.,,s.,...,, No. H 1 62395. AN AFFILIATE OF " CITY BANK CONSOL]DATED COMMERCIAL:'ACCQ'U:NT :: NATIONAL CLEVELAND, OHIO ::: .: :..:: ::. .... 56-389 i00 t &2395 :: ' 412 PAY To The ORDER O'.F ONE HUNDRED & O:O/iOO~~~~.~~~~~~ US DOLLAR ALASKA STATE DEPT OF REVENUE AO~C:C: 300.1 PORCUPINE DR ANCHORAGE AK ~9501-3120 DATE AMOUNT 02/04/00 15100. O0 I NO'F::VALID AFTER 120 DAYS Il' ;~ F= a ~ q S,' ~:0 t., it,, a[I ~,,o, ~ 5': OCR L, L, ]. el,' WELL PERMIT CHECKLIST COMPANY _,L~.~ WELL NAME~/~,,~ ~,~),~PROGRAM: exp __ dev__ redrll ~ serv__ wellbore seg __ann. disposal para req __ FIELD & POOL "~_~_5'~ INIT CLASS .~)~././ .j-,-:)~ ~ GEOL AREA ~'.xd UNIT# .//~',5"4~ ON/OFF SHORE C~ N Y N N N N N =N N N N N N N ADMINISTRATION DATE . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. ENGINEERING GEOLOGY Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~OO~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~)N (~)N ~3oo -oo"'(.-Z' (~U 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. ; 34. Contact name/phone for weekly progress reports [exploratory on, l~] Y N ANNULAR_ DISPOSAL35. With proper cementing records, t_his plan (A) will contain waste in a suit/ab~ receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or_._C, aLtse-d~ waste... Y N to surface; /~ ~ (C) will not impair,,,~A~ical integrity of,,th~ well used for disposal; Y N (D) will not d~e producing formatio/~or impair recovery from a Y N pool;~' ( (E) will not circumvent 20 AAC 25.252'-or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O Z Z --I -!- c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jan 15 16:45:38 2002 Reel Header Service name ............. LISTPE Date ............. ........ 02/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 02/01/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-00030 B. JAHN PARKER/ MCMU P-04L1 500292218060 BP Exploration (Alaska) Sperry Sun 15-JAN-02 MWD RUN 2 AK-MW-00030 B. JAHN C. PARKER/ J MWD RUN 3 AK-MW-00030 B. JAHN PARKER / MCM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MAD RUN 3 AK-MW-00030 B. JAHN PARKER / MCM 31 lin 13E 2564 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 2001 91.64 .00 .00 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 5.500 11546.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL TRUE VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. P-04L1 KICKS OFF FROM P-04 AT A FLOWTHROUGH WHIPSTOCK, WITH TOP SET AT 11546' MD, 8832.8' TVDSS. 4. MWD RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUN 2-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MULLER DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. RESISTIVITY DATA IN THE INTERVAL 11548.5' MD / 8834.2' TVDSS TO 13097' MD / 8959.8' TVDSS WERE ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE AFTER MWD RUN 3 AND ARE PRESENTED SEPARATELY. 7. DEPTH SHIFTING WAIVED PER THE E-MAIL OF 8/8/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. 8. MWD RUNS 1-3 REPRESENT THE MWD DATA FOR WELL P-04L1 WITH API# 50-029-22180-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13097' MD, 8959.8' TVDSS. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY - SCINTILLATION DETECTORS SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11532 0 FET 11545 0 RPD 11548 5 RPX 11548 5 RPM 11548 5 RPS 11548 5 ROP 11566 0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: STOP DEPTH 13050 0 13062 0 13062 0 13062 0 13062 0 13062 0 13097 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11532.0 11820.5 2 11821.0 12779.5 3 12780.0 13097.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD FPH 4 1 68 GR MWD API 4 1 68 RPX MWD OHMS 4 1 68 RPS MWD OHMS 4 1 68 RPM MWD OHMS 4 1 68 RPD MWD OHMS 4 1 68 FET MWD HRS 4 1 68 0 4 8 12 16 2O 24 28 Last Name Service Unit Min Max Reading DEPT FT 11532 13097 13097 ROP MWD FPH 0 814.11 13097 GR MWD API 24.49 739.01 13050 RPX MWD OHMS 0.4 2000 13062 RPS MWD OHMS 0.49 2000 13062 RPM MWD OHMS 0.51 2000 13062 RPD MWD OHMS 0.45 2000 13062 FET MWD HRS 0.347 100.48 13062 Mean 12314.5 85.6988 67.7408 13.304 14.5087 14.179 22.7094 17.5158 Nsam 3131 3063 3037 3028 3028 3028 3028 3035 First Reading 11532 11566 11532 11548.5 11548.5 11548.5 11548.5 11545 First Reading For Entire File .......... 11532 Last Reading For Entire File ........... 13097 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 11548.5 13072.0 11548.5 13072.0 11548.5 13072.0 11548.5 13072.0 11548.5 13072.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 3 1 11548.5 13097.0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MAD OHMS 4 1 68 4 2 RPS MAD OHMS 4 1 68 8 3 RPM MAD OHMS 4 1 68 12 4 RPD MAD OHMS 4 1 68 16 5 FET MAD HRS 4 1 68 20 6 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 11548.5 13072 12310.3 3048 13072 RPX MAD OHMS 0.4 2000 10.3544 3048 13072 RPS MAD OHMS 0.44 2000 13.6256 3048 13072 RPM MAD OHMS 0.44 2000 15.3057 3048 13072 RPD MAD OHMS 0.47 2000 22.0644 3048 13072 FET MAD HRS 1.42283 100.484 58.3176 3048 13072 First Reading 11548 5 11548 5 11548 5 11548 5 11548 5 11548 5 First Reading For Entire File .......... 11548.5 Last Reading For Entire File ........... 13072 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11532.0 11790.5 ROP 11566.0 11820.5 $ LOG HEADER DATA DATE LOGGED: 28-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11821.0 TOP LOG INTERVAL (FT): 11532.0 BOTTOM LOG INTERVAL (FT) : 11821.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 49.4 MAXIMUM ANGLE: 85.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER PB02100HWRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (P?M) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.750 Flo Pro 9.95 65.0 8.5 185000 6.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FPH 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 150.1 .0 .0 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 11532 11820.5 11676.3 578 11820.5 ROP MWD010 FPH 0.29 148.64 60.5662 510 11820.5 GR MWD010 API 31.64 739.01 148.755 518 11790.5 First Reading 11532 11566 11532 First Reading For Entire File .......... 11532 Last Reading For Entire File ........... 11820.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPX RPS RPM RPD GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11545 0 11548 5 11548 5 11548 5 11548 5 11791 0 11821 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12740 12732 12779 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 STOP DEPTH 12740 0 12740 0 12740 0 12740 0 0 0 5 29-APR-00 Insite 66.16 Memory 12780.0 11821.0 12780.0 82.9 95.1 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY /LB/G) : MUD VISCOSITY {S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM?ERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.750 Flo Pro 10.00 65.0 9.0 183000 4.6 .175 .000 .020 .020 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMS 4 1 68 12 4 RPS MWD020 OHMS 4 1 68 16 5 RPM MWD020 OHMS 4 1 68 20 6 RPD MWD020 OHMS 4 1 68 24 7 FET MWD020 HRS 4 1 68 28 8 65.0 161.8 65.0 65.0 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 11545 12779.5 12162.3 2470 12779.5 ROP MWD020 FPH 0 814.11 101.24 1918 First Reading 11545 11821 12779.5 GR HWD020 AP1 12732 RPX MWD020 OHMS 12740 RPS MWD020 OHMS 12740 RPM MWD020 OHMS 12740 RPD HWD020 OHMS 12740 FET MWD020 HRS 12740 24.49 192.63 0.4 2000 0.49 2000 0.51 2000 0.45 2000 0.347 100.48 52 2451 1883 14 9401 2384 16 2956 2384 15 8116 2384 26 4643 2384 20 7119 2391 11791 11548.5 11548.5 11548.5 11548.5 11545 First Reading For Entire File .......... 11545 Last Reading For Entire File ........... 12779.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 12732 5 12740 5 12740 5 12740 5 12740 5 12740 5 12780 0 LOG HEADER DATA STOP DEPTH 13050.0 13062 0 13062 0 13062 0 13062 0 13062 0 13097 0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 01-MAY-00 Insite 66.16 Memory 13097.0 12780.0 13097.0 90.0 97.7 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 3.750 Flo-Pro 10.00 65.0 10.0 182000 5.2 .020 .000 .040 .045 65.0 147.1 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMS 4 1 68 RPS MWD030 OHMS 4 1 68 RPM MWD030 OHMS 4 1 68 RPD MWD030 OHMS 4 1 68 FET MWD030 HRS 4 1 68 4 8 12 16 20 24 28 Last Name Service Unit Min Max Reading DEPT FT 12732.5 13097 13097 ROP MWD030 FPH 0 266.19 13097 GR MWD030 API 28.51 141.01 13050 RPX MWD030 OHMS 1.39 16.24 13062 RPS MWD030 OHMS 1.77 16.04 13062 RPM MWD030 OHMS 1.88 15.38 13062 RPD MWD030 OHMS 2.72 13.83 13062 FET MWD030 HRS 0.471833 31.0212 13062 Mean 12914.8 58.9432 47.6352 7.24711 7.89394 8.13497 8.80952 5.64916 Nsam 730 635 636 644 644 644 644 644 First Reading 12732.5 12780 12732.5 12740.5 12740.5 12740.5 12740.5 12740.5 First Reading For Entire File .......... 12732.5 Last Reading For Entire File ........... 13097 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 3 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 11548.5 13072.0 RPX 11548.5 13072.0 RPS 11548.5 13072.0 RPM 11548.5 13072.0 RPD 11548.5 13072.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 01-MAY-00 Insite 66.16 Memory 13097.0 11548.0 13097.0 90.0 97.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB02100HWRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 10.00 65.0 10.0 182000 5.2 .O2O .000 .040 .045 65.0 147.1 65.0 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MAD031 OHMS 4 1 68 4 2 RPS MAD031 OHMS 4 1 68 8 3 RPM MAD031 OHMS 4 1 68 12 4 RPD MAD031 OHMS 4 1 68 16 5 FET MAD031 HRS 4 1 68 20 6 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 11548.5 13072 12310.3 3048 13072 RPX MAD031 OHMS 0.4 2000 10.3544 3048 13072 RPS MAD031 OHMS 0.44 2000 13.6256 3048 13072 RPH MAD031 OHMS 0.44 2000 15.3057 3048 13072 RPD MAD031 OHMS 0.47 2000 22.0644 3048 13072 FET MAD031 HRS 1.42283 100.484 58.3176 3048 13072 First Reading 11548 5 11548 5 11548 5 11548 5 11548 5 11548 5 First Reading For Entire File .......... 11548.5 Last Reading For Entire File ........... 13072 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/01/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 02/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File