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Home My WebLink About184-079 - DIE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ON W OMPLETION OR RECOMPLETION RE T AND LOG APR 0 5 2018 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned m• Suspended 0 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Developm t GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp., •rAband 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc -03/5/2018 184-079 • 317-603 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 6/5/1984 50-029-21118-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 6/17/1984 PBU 03-29 • Surface: 545'FSL,71'FWL,Sec.11,T1ON,R15E,UM • 9 Ref Elevations KB 6200 17. Field/Pool(s): Top of Productive Interval: 2233'FSL,2227'FEL,Sec.10,T1ON,R15E,UM GL 28.3 BF 32.32 PRUDHOE BAY,PRUDHOE OIL • Total Depth: 2741'FSL,2655'FEL,Sec.10,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9604'/8745' ADL 028327&028328 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 713355• y- 5936587 . Zone - ASP 4 • 10283'/9196' • 74-017 TPI: x- 711008 y- 5938211 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 710565 y- 5938706 Zone - ASP 4 None 1900'(Appreox) 5. Directional or Inclination Survey: Yes 0 (attached) No IZI 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Wndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary Du_/BHCS/GR/SP,LDT/CNL/GR/Cal,CBL/CET/GR,Gyro 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 33' 113' 33' 113' 30" 1875#Poleset 13-3/8" 72# L-80 32' 2501' 32' 2501' 17-1/2" 2000 sx CS III,400 sx CS II 9-5/8" 47# L-80 31' 9499' 31' 8669' 12-1/4" 500 sx Class'G',300 sx CS I,552 sx Class'G' 7" 29# L-80 9181' 10283' 8421' 9196' 8-1/2" 325sxClass'G' 5-1/2"x4-1/2" 17#/12.6# L-80 9047' 9220' 8309' 8452' 3-1/2" 9.3# 13Cr80 8959' 9994' 8223' 9014' Scab liner 51 sx Class'G',156 sx Class'G' 24. Open to production or injection? Yes 0 No Il 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 8971' 8849'/8137' �/�1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ?J iSj tS Was hydraulic fracturing used during completion? Yes 0 No IT Per 20 AAC 25.283(i)(2)attach electronic and printed /^y^�,(A- scots JUN 1 .9 2•131 information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9604' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bhl: Gas-MCF: Water-Bbl: Choke Size Gas-Oil Ratio: Test Period ....► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press 24 Hour Rate •1• /r Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only vr- 6/4 /1 q ,oe-,6 RF,TZ)4►ak" k, i t,18,A 5./y CI 28. CORE DATA • Conventional Core(s) Yes 0 No Q • Sidewall Cores Yes 0 No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No Q Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9368' 8570' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 9368' 8570' Shublik 9413' 8604' Sadlerochit-Zone 4 9506' 8674' CGL-Zone 3 9740' 8842' Base of CGL-Zone 2 9783' 8872' Zone 1B 10169' 9125' Formation at total depth: Zone 1B 10169' 9125' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Leemhuis,Jacob Authorized Title: SIM Sp is t Contact Email: Jacob.Leemhuis@bp.com Authorized Signature: Date: 4(d,I $ Contact Phone: +1 907 564 4989 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only i i Daily Report of Well Operations 3/29/2018 ACTIVITYDATE SUMMARY 2/9/2018 Assist CTU with heating upright of 1% KCL. Heat 2 uprights of 1% kcl to 135* CTU#8 1.75" CT. Job Scope: Pull TTP/MILL CIBP MOL RU. MU RIW/w BKR CTC 2.0", DBOV 2.13", JAR 2.13", DISCO 2.13" (5/8" ball), X- over 3.10", 4" GS SPEAR w/PRONG 3.50", OAL=12.52' (MAX OD=3.50"). Set down at 8952' ctm, WHP dropped off, let pressures equalize. OOH recovered XXN PLUG @ 8954' MD. MU BKR CTC 2.0", DBPV 2.13", JAR 2.13", DISCO 2.13" (5/8" ball), CIRC SUB 2.13" (1/2" ball) MOTOR 2.13", 5 BLADED JUNK MILL 2.85", OAL=19.21', (MAX OD=2.85"). 2/9/2018 ***Job in progress** CTU#8 1.75" CT. Job Scope: Pull TTP/MILL CIBP MOL RU. MU RIW/w BKR CTC 2.0", DBOV 2.13", JAR 2.13", DISCO 2.13" (5/8" ball), X- over 3.10", 4" GS SPEAR w/PRONG 3.50", OAL=12.52' (MAX OD=3.50"). Set down at 8952' ctm, WHP dropped off, let pressures equalize. OOH recovered XXN PLUG @ 8954' MD. MU BKR CTC 2.0", DBPV 2.13", JAR 2.13", DISCO 2.13" (5/8" ball), CIRC SUB 2.13" (1/2" ball) MOTOR 2.13", 5 BLADED JUNK MILL 2.85", OAL=19.21', (MAX OD=2.85"). Mill CIBP at 9508' & push to bottom. Dry tag at 9958'. POH. MU & RIH w/drift. 2/9/2018 ***Job in progress** CTU#8 1.75" CT. Job Scope: Pull TTP/MILL CIBP Continue to RIH w/2.62" drift. Dry tag at 9960'. POH. RDMO. 2/10/2018 ***Job Complete* ***WELL S/I ON ARRIVAL*** (Pre CTD) DRIFT TO 9,800' SLM W/2.70" x 20' DUMMY WHIPSTOCK, S-BLR (No sample or 2/15/2018 issues). ***WELL S/I ON ARRIVAL*** (SLB ELINE SET WHIPSTOCK) INITIAL T/I/O = 200/0/NA. MIRU, LPT/HPT= PASS. RIH W/ BAKER 3-1/2"XL MONOBORE WHIPSTOCK, OAL =47', OAW = 355 LB, MAX OD = 2.625". SET WHIPSTOCK AT 9,605' TOWS, 179 DEGREES ROHS, 2 RA TAGS 6.3' FROM TOWS, OAL LIH = 10.5'. TAG WS, POOH. LOG CORRELATED TO SLB RST DATED 12-MAY-2014. RDMO. WELL S/I ON DEPARTURE. FINAL T/I/O = 255/0/NA. 2/16/2018 ***JOB COMPLETE ON 16-FEBRUARY-2018*** T/I = SSV/50. Temp = SI. Bleed IAP to 0 psi (Pre Rig). ALP = 1900 psi, SI @ CV. IA FL near surface. SSV disconnected from pannel & DMY off unable to open to get TP. Bled IAP to BT from 50 psi to 0+ psi in 5 min (all gas). Monitored for 30 min. IAP increased 10 psi. FWHPs = SSV/10. 2/19/2018 SV, WV, SSV= C. MV= O. IA= OTG. 16:00 T/I = SSV/60. Temp = SI. Bleed IAP to 0 psi. ALP = 60 psi SI © manifold &AL casing valve. IA FL near surface. No wellhouse or ladder to swab platform. Bled IA&AL line to 0 psi in 1 hr& held open for 30 mins. Monitored for 30 mins, IAP increased 1 psi. Final WHPs = SSV/1. 2/28/2018 SV, WV= ?. SSV= C. MV= O. IA= OTG. 14:00 T/I = 400/0. PRE-CDR2 Tree work. Set 4" CIW TWC#429 at 125"with CIW Lubricator#68- 840. Removed Tapped Blind Flange off FC Companion side and replaced with Kill Line#2. Torqued to API specs and PT to 350 psi low and 5000 psi high for 5min. each. (PASS). RDMO ***Job Complete***SEE LOG FOR DETAILS. Final T/I = TWC/0. Note: TWC sign 3/1/2018 hung on wellhead. T/I = TWC/25. Temp = SI. WHPs (Post Bleed). No AL, Wellhouse, flowline, and scaffolding. IAP increased 24 psi since 02/28/18. 3/2/2018 SV= ?. WV, SSV= C. MV= O. IA= OTG. 15:30 • • North America-ALASKA B' Operation Summary Report Common Well Name:03-29 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI.USA00001406 Active datum.KB @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 3/1/2018 11:00 - 12:15 1.25 RIGD P PRE START OPS FOR CONVERSION TO 2"COIL STACK JETTED CLEAN,HES HAVING TROUBLE TESTING ONE OF THEIR VALVES BEFORE THEY CAN TEST AGAINST THE RIG VALVE TO TEST THEIR LINE 12:15 - 12:20 0.08 RIGD P PRE I CUSTOMER VALVE AND TREATING LINE TESTED 12:20 - 12:40 0.33 RIGD P PRE HOLD A PJSM TO BLOW DOWN REEL 112:40 - 14:00 1.33 P PRE BLOW DOWN REEL,VERIFY PUMP LINE UP {WITH THE PCCL CARD I APPLY 300 PSI ON OUTSIDE REEL VALVE TO PREVENT FLUIDS FROM BACK FLOWING INTO THE N2 LINE OPEN VALVE AND BRING RATE UP TO 1800 SCFM 20K SCF OF N2 PUMPED,SHUT DOWN N2 - AND ALLOW N2 TO BLEED OFF 14:00 - 16:00 2.00 RIGD P PRE PU INJECTOR AND REMOVE NOZZLE BHA I MU GRAPPLE CONNECTOR AND PREP TO UNSTAB PIPE 16:00 - 18:30 2.50 RIGD P PRE UNSTABPIPEANDSECUREATTHEREEL 18:30 - 19:45 1.25 RIGD P PRE PRE JOB MEETING WITH CRANE OPERATOR, RIGGER, AND RIG CREW. -REVIEW LIFTING PLAN WITH RIG CREW. -EMPHASIS ON COMMUNICATION AND STOP THE JOB. -AFTER REVIEWING LIFTING PLAN,SOME CONCERNS ABOUT TYPE OF PICK. -CALL BP HSE AND DISCUSS.L2RA REQUIRED IF PICK IS DONE WHILE RIG IS ON WELL. -STOP OPS AND ADJUST OPERATIONS PLAN FORWARD TO DO PICK AFTER MOVING OFF OF WELL. -SUPERINTENDENT NOTIFIED OF CHANGE OF PLAN. 19:45 - 00:00 4.25 RIGU P PRE PJSM W/ALL PARTIES INVOLVED.EMPHASIS ON BODY PLACEMENT AND COMMUNICATION. -CHANGE OUT REELS F/2 3/8"TO 2"COIL. -REMOVE GRIPPER BLOCKS ON INJECTOR AND INSPECT INJECTOR. 3/2/2018 00:00 - 05:00 5.00 RIGU P PRE PJSM.SECURE REEL IN REEL HOUSE. -INSTALL SADDLE CLAMPS AND CHAIN OFF REEL. -CHANGE OUT BRASS ON INJECTOR STRIPPER -INSTALL 2"GRIPPER BLOCKS ON INJECTOR. -PERFORM LTT ON SWAB VALVE.PREP TO CHANGE RAMS IN BOPE. Printed 3/19/2018 10.14.31AM *AII depths reported in Drillers Depths" • North America-ALASKA-BP • Page 2 d Operation Summary Report Common Well Name:03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI:USA00001406 Active datum:KB @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:00 - 17:00 12.00 RIGU P PRE -CHANGE OUT BOP 2-3/8"RAMS FOR 2" RAMS -REVIEWED AND WALKED THROUGH LIFT PLAN FOR SWAPPING OUT GOOSENECKS WITH BP HSE REP T.HUNT,LIFT DOES NOT REQUIRE A L2RAAS WE ARE NOT LIFTING OVER THE WELL OR LIVE PROCESS LINES AND THERE ARE NO ADJACENT WELL ' HOUSES/WELLS -CALL OUT CRANE CREW -RU CRANE AND SWAP GOOSENECKS -PREP TO STAB PIPE 17:00 - 21:30 4.50 RIGU P PRE PJSM.PULL COIL OVER GOOSENECK. -INSTALL GRAPPLE AND PULL TEST,OK. STAB COIL AND RUN THRU INJECTOR,NO ISSUES. 21:30 - 23:00 1.50 RIGU P ' PRE PJSM.INSTALLING INNER REEL IRON. -EMPHASIS ON TIGHT QUARTERS,BODY POSITIONING,PINCH POINTS. I -INSTALL INNER REEL IRON. 23:00 - 00:00 1.00 RIGU P PREPJSM.N/D BOPE. �-NIPPLE DOWN BOPE. 3/3/2018 i 00:00 - 02:00 2.00 RIGU P PRE INSTALL 4 1/16"ADAPTER FLANGE ON BOTTOM OF BOP. -SECURE CELLAR.INSTALL TREE CAP AND LTT,GOOD TEST. -NABORS RELEASED RIG OFF OF 03-10 02:00 HRS,03/03/2018. 02:00 - 02:30 0.50 RIGU P PRE PJSM W/CREW AND TRUCK DRIVERS. -EMPHASIS ON USING GOOD COMMUNICATION TECHNIQUES. -STOP COMMAND AGREED UPON.STOP BLOCK IN PLACE ON SUB. -ANNULUS PRESSURES CHECKED.0 PSI ON ANNULI.WELL SECURE WITH VALVES SHUT IN. -DRILL SITE OPERATOR NOTIFIED,WAIVED WITNESSING. 02:30 - 04:30 2.00 RIGU P PRE COMMENCE RIG MOVE OPERATIONS. -JACK UP PIT MODULE AND SPOT OFF TO SIDE. -JACK UP SUB AND PULL OFF OF WELL. -NABORS TOOLPUSHER AND BP WSL WITNESSED SUB PULLING OFF OF WELL. -MOVE AROUND THE PAD TO 03-29. 04:30 - 05:00 0.50 RIGU P PRE SPOT MAIN SUB OVER 3-29 -EMPHASIS ON USING GOOD COMMUNICATION TECHNIQUES. -STOP COMMAND AGREED UPON.STOP BLOCK IN PLACE ON SUB. -ANNULUS PRESSURES CHECKED.0 PSI ON ANNULI.WELL SECURE WITH VALVES SHUT IN. -DRILL SITE OPERATOR NOTIFIED, WITNESSED RIG SPOTTING OVER WELL. -NABORS TOOLPUSHER AND BP WSL ALSO WITNESSED SUB SPOTTING ON WELL. 05:00 - 05:30 0.50 RIGU P PRE MAIN SUB SPOTTED Printed 3/19/2018 10.14:31AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP S Page 3 6PI4 Operation Summary Report Common Well Name:03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001406 Active datum:KB @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:30 - 14:00 8.50 RIGU P PRE PIT SUB SPOTTED, ACCEPT RIG @ 05:30 HRS.START RIG UP OPS -LTT MASTER&SWAB -MU MP LINE WHILE INSTALLING THE REST OF THE REEL IRON -MU THE PRESSURE BULKHEAD -SHIM REEL 14:00 - 15:00 1.00 BOPSUR P PRE FUNCTION TEST BOPE HYDRAULIC LEAK ON ONE OF THE RAMS REAM COIL FOR CTC 15:00 - 16:00 ' 1.00 BOPSUR i P PRE FUNCTION TEST RAMS I GOT ANOTHER HYDRAULIC LEAK 16:00 - 16:15 0.25 , BOPSUR P PRE FUNCTION TEST RAMS AGAIN I 1 GOOD TEST,ALLOW GREASE CREW TO i 'SERVICE VALVES SHELL TEST,UPPER 2"DOOR SEAL FAILED, CHANGE OUT SAME. t, THIS 2-HRS WILL GO AGAINST THEIR 10-HR TEST TIME I 16:15 - 18:00 1.75 BOPSUR P PRE FLUID PACK STACK TO SHELL TEST -ACHIEVE GOOD SHELL TEST. -TEST GAS ALARMS,OK. 18:00 - 23:00 5.00 BOPSUR 1 P PRE PRESSURE TEST 7 1/16"X 5M BOPE. -FROM TOP DOWN: ANNULAR PREVENTOR, BLIND SHEAR RAMS, -2"PIPE/SLIPS,MUD CROSS,2 3/8" PIPE/SLIPS,2"PIPE SLIPS. -TESTING ALL VALVES AND RAMS @ 250- 3500 PSI AS PER BP AND AOGCC REQUIREMENTS. -AOGCC REP MATT HERRERA WAIVED WITNESSING,24 HR NOTICE GIVEN. 1-ATTEMPT TO TEST LOWER 2"PIPE/SLIPS, NOT HOLDING AT ALL. I-OPEN DOORS AND INSPECT,2 3/8"PIPE/ SLIP RAMS ARE WHERE 2"SHOULD BE. 23:00 - 00:00 1.00 BOPSUR N PRE PJSM.OPEN DOORS AND CHANGE RAMS TO COMPLY WITH REQUIRED CONFIGURATION. 3/4/2018 00:00 - 02:30 2.50 BOPSUR N PRE I PJSM.CONTINUE TO RECONFIGURE RAMS IN BOPE. -INSTALL 2"PIPE/SLIP RAMS IN LOWERMOST RAM BODY. -INSTALL 2 3/8"PIPE/SLIP RAMS ABOVE 2" PIPE/SLIPS. -INSPECT DOOR SEALS ON RAM DOORS. -FUNCTION TEST RAM FUNCTIONS,GOOD. -PERFORM BODY TEST ON BOPE,250/3500 PSI,GOOD TEST. 02:30 - 07:00 4.50 BOPSUR P PRE RESUME TESTING BOPE AS PER BP AND AOGCC REQUIREMENTS. -TESTING ALL COMPONENTS @ 250/3500 PSI/5 MIN EACH/CHARTED. 07:00 - 10:00 3.00 BOPSUR P PRE BOP TEST COMPLETED,RD TEST EQUIPMENT AND PREP TO MU THE CTC&BHI UQC 10:00 - 11:30 1.50 WHSUR P PRE PULL TEST CTC TO 50K GOOD PULL TEST,MU THE BHI UQC Printed 3/19/2018 10.14:31AM *AII depths reported in Drillers Depths* 411 North America-ALASKA-BP • Page 4 at*- Operation Summary Report` ffu f Common Well Name:03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001406 Active datum:KB©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 11:30 - 13:00 1.50 WHSUR P PRE FILL COIL TO PT IRV AND PACKOFFS -TABLE TOP H2S DRILL W/CREW COMING ON TOUR. -REVIEWED SOP FOR H2S DURING DRILLING OPERATIONS. -REINFORCED NOT TO GO IN ANY WELLHOUSES ON THIS PAD. -ALL GASEOUS RETURNS TO BE TAKEN TO THE TIGER TANK. 13:00 - 13:30 0.50 WHSUR P PRE CHECK TREE BOLTS 13:30 - 13:50 0.33 WHSUR P PRE TREE BOLTS ARE GOOD 'PT IRV&PACKOFFS 13:50 - 14:05 0.25 WHSUR P PRE PT IRV&PACKOFFS 14:05 GOOD LOW PT,GO TO HIGH 14:05 - 14:20 0.25 WHSUR P PRE I BLEED OFF,WE HAVE A LEAK ON A HOSE THAT IS PART OF THE TEST EQUIPMENT 14.20 - 14:55 0.58 I WHSUR P PRE PT THE IRV AND PACKOFFS GOOD LOW,GO TO HIGH LOOKS LIKE WE MIGHT HAVE SOME AIR IN THE SYSTEM,HAD TO BUMP IT UP A COUPLE TIMES AND IS HOLDING 14:55 - 15:40 0.75 WHSUR I P PRE GOOD TEST,BLEED OFF,LOAD 30 BBLS OF 'MUD INTO THE COIL 15:40 - 16:05 0.42 WHSUR P PRE SHUT DOWN PUMP,PU INJECTOR AND INSTALL BHI DHCVS 16:05 - 16:10 0.08 WHSUR P PRE PRESSURE TEST CTC&UQC TO 3500 PSI 16:10 - 16:25 0.25 WHSUR- P" - PRE GOOD,PT,BLEED OFF AND PT THE DHCV'S FROM THE DOWNHOLE END • 16:25 - 16:40 0.25 WHSUR P PRE GOOD PT ON CVS,RD TEST HOSE,MOVE INJECTOR OUT OF THE WAY HOLD A PJSM WITH VALVE CREW TO RU 'THEIR LUBRICATOR,PT AND PULL THE TWC 16.40 - 18:15 1.58 WHSUR P 7 PRE ,PU LUBRICATOR. -PRESSURE TEST LUBRICATOR @ 3500 PSI, GOOD TEST. -PULL TWO WAY CHECK VALVE,NO ISSUES. -430 PSI STP.CLOSE MASTER VALVE,23 TURNS. 18:15 - 19:30 1.25 WHSUR P PRE PJSM.LINE UP AND PUMP METHANOL ACROSS TREE. -CLOSE SWAB AND PERFORM LTT ON SWAB AND MASTER VALVES,GOOD. -RETRIEVED TWC VALVE,LAY DOWN LUBRICATOR. 19:30 - 20:30 1.00 WHSUR P PRE PJSM.MOVE INJECTOR OVER WELL AND STAB ON. -TEST UQC©3500 PSI/5 MIN/CHARTED. BLEED ALL PRESSURE. Printed 3/19/2018 10 14 31AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 56>P7 Operation Summary Report Common Well Name.03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001406 Active datum:KB @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 20:30 - 22:30 2.00 KILLW P PRE PJSM.WELL KILL(BULLHEAD).SITP 430 PSI, I/A 0 PSI,0/A 0 PSI. -EMPHASIS ON GOOD COMMUNICATION TECHNIQUE. -DOUBLE CHECK VALVE ALIGNMENTS& CALL OUT. -REVIEW PRESSURE CROSS CHECK LIST AND ESTABLISH PARAMETERS. -LINE UP AND BULLHEAD(10)BBLS METH AHEAD. -BULLHEAD 290 BBLS HEATED SLICK KCL. ICP=640 PSI @ 5 BPM. -W/70 BBLS KCL AWAY,225 PSI©5 BPM. -W/130 BBLS KCLAWAY,5 BPM/100 PSI. - WI 200 BBLS AWAY.5 BPM @ 100 PSI.. - W/290 AWAY,FCP 100 PSI,SHUT DOWN AND LINE UP ON HI VIS PILL. -BULLHEAD 25 BBLS HI VIS PILL W/H2S SCAVENGER @ 4.5 BPM/100 PSI. -CHASE HI VIS PILL W/130 BBLS DRILLING 'MUD. BPM/100 PSI. 22:30 - 00:00 1.50 KILLW P I PRE 'PJSM.LINE UP TO FLUSH ABOVE SWAB VALVE TO TIGER TANK. -PUMP DOWN COIL,(DRILLING MUD),AND 'FLUSH EXCESS METH TO TIGER TANK -PUMP ACROSS THE TOP TO DETERMINE LOSS RATE. -INCREASE RATE TO 5 BPM,SEE RETURNS AND ESTABLISH LOSS RATE©210 BPH. -NOTIFY ODE AND FORMULATE PLAN TO I PUMP DIAMOND SEAL PILL W/MUD ENGINEER. -ORDER MORE MUD AND WATER BACK 50 BBLS OF KILL WT AS ACTIVE SYSTEM IS GETTING LOW. -CONTINUE TO FILLACROSS THE TOP AND OBSERVE LOSS RATE SUBSIDE TO 165 BPH. -NOT SEEING ANY INDICATION OF LOSSES HEALING UP. 3/5/2018 00:00 - 00:45 0.75 KILLW N PRE CONTINUE FILLING ACROSS THE TOP, PUMPING DOWN KILL LINE. -PUMPING WATERED DOWN KILL WT MUD UNTIL NEW MUD ARRIVES. 00:45 - 03:15 2.50 KILLW N PRE NEW MUD ARRIVES.INCREASE RATE TO 4 1/2 BPM/40 PSI. -ESTIMATED LOSS RATE 140 BPH.LOOKED LIKE LOSSES SLOWED DOWN AFTER 160 BBLS PUMPED. -DETERMINED FALSE READING...VAC TRUCK WAS PUSHING FLUID THRU MUD PUMP,(WELL ON VACUUM). -REESTABLISHED TRUE LOSS RATE...140 BPH.PREPPING TO MIX/PUMP DIAMOND SEAL LCM PILL. 03'15 05:20 2.08 KILLW N PRE PRE JOB WITH RIG CREW. -SENT PUMPING PLAN TO TOWN AND CALLED ODE,PLAN OK'D. -STILL PUMPING ACROSS THE TOP THRU KILL LINE.LOSS RATE NOW 100 BPH. Printed 3/19/2018 10:14:31AM *All depths reported in Drillers Depths* iNorth America-ALASKA-BP • Pages Operation Summary Report Common Well Name:03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:00AM Rig Release:3/13/2018 Rig Contractor:NABORS ALASKA DRILLING INC. 'BPUOI:USA00001406 Active datum:KB©62.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:20 - 05:40 0.33 KILLW N PRE WELL PLAN CALLS FOR 10.5PPG&20 PPB CONCETRATION,BAROID PROCEDURE CALLS FOR 16PPB CONCENTRATION.CALL ODE AND VERIFY CORRECT PPB TO USE, FOLLOW BAROID PROCEDURE AND USE 16 PPB PJSM TO PUMP DIAMOND SEAL FOR LOSSES CURRENT LOSS RATE=102 BPH 05:40 - 06:25 0.75 KILLW N PRE START CUTTING SACKS AGITATE FOR 1 MIN CLOSE CHOKE AND PUMP DOWN HOLE AT 3.5 BPM PUMP 50.4 BBLS OF DIAMOND SEAL PUMP20 BBLS OF FRESH WATER CHASE WITH DRILLING MUD WHP=343 PSI 106:25 - 06:35 0.17 KILLW N • PRE 120'BBLS FROM TOP PERF REDUCE RATE TO 2.0 BPM WHP=199 PSI 06:35 - 07:30 0.92 KILLW N PRE DIAMOND SEAL AT THE PERFS,SHUT DOWN PUMP AND LINE UP DOWN THE COIL TO CIRC ACROSS THE TOP AND MONITOR RETURNS TO ESTABLISH A LOSS RATE INITIALLY HAD 12 BPH LOSS RATE THEN HEALED UP AND ONLY SEEING SEEPAGE i LOSSES 107:30 - 07:40 0.17 KILLW. N PRE DIAMOND SEAL IS MIGRATING AND WE ARE • STARTING TO SEE IT AT THE SHAKER 07.40 - 08:05 0.42 KILLW N • PRE CLOSE CHOKE AND APPLY 400 PSI SQUEEZE PRESSURE 400 PSI ACHEIVED FAIRLY QUICK,CALL ODE AND DISCUSS BRING PRESSURE UPA LITTLE HIGHER ODE WANTS TO BRING IT UP TO THE 'EQUIVELENT WE WOULD SEE WHILE MILLING THE WINDOW,735 PSI IS EQUIVELENT TO 10.2 PPG 08:05 - 08:15 0.17 KILLW N PRE ACHIEVED 735 PSI,TOOK 4.4 BBLS TO BRING TO ACHEIVE THEN SLOWLY STARTED BLEED OFF ON ITS OWN IN 10 MIN PRESSURE BLED OFF 430 PSI 08:15 - 08:45 0.50 KILLW N PRE HOLD A PJSM TO FLOW CHECK WELL AND DEPLOY THE MILLING BHA SLOWLY BLEED OF THE REST OF THE WHP TO FLOW CHECK THE WELL 08:45 - 09:45 1.00 KILLW P , PRE ,GOOD NO FLOW,PU THE INJECTOR AND DEPLOY THE ALREADY MU MILLING BHA 09:45 - 12:40 2.92 STWHIP P WEXIT BHA MU,RIH PUMPING SLACK FORWARD AT - 1.6 BPM 12:40 - 13:00 0.33 STWHIP P 8,950.00 WEXIT CLOSE THE EDC AND RIH PUMP DOWN THROUGH THE MOTOR WHILE RIH THROUGH THE 3-1/2"LINER TO MAKE SURE WE DON'T PLUG UP WITH LCM WHILE LOGGING TIE IN 13:00 - 13:20 0.33 STWHIP P 9,582.00 WEXIT RIH CLEAN TO THE TOWS-170'PAST THE BOTTOM PERF AND NO LOSSES,PUH ABOVE TIE IN DEPTH TO LOG DOWN OPEN EDC Printed 3/19/2018 10:14:31AM *All depths reported in Drillers Depths' • North America-ALASKA-BP • Page 7 Operation Summary Report Common Well Name:03-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/1/2018 End Date:3/11/2018 X3-018R2-C:(1,937,700.00) Project:PBU Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:6/5/1984 12:00:OOAM Rig Release:3/13/2018 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI:USA00001406 Active datum:KB @62.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:20 - 13:45 0.42 STWHIP P 9,582.00 WEXIT LOG TIE IN RETURNS CAME UP THNE WE LOST ALL RETURNS,MONITOR TO SEE IF IT COMES BACK 1.8 BPM IN AND ONLY 0.23 BPM BACK,STOP LOGGING AND PULL OUT OF THE 3-1/2 LINER AND INTO THE 4-1/2"TUBING 13:45 - 15:10 1.42 STWHIP P 9,582.00 WEXIT PULLED BHA INTO THE 4-1/2,LINE UP ACROSS THE TOP TO REDUCE LOSSES CALL ODE AND DISCUSS A PLAN FORWARD DECISION MADE TO SWAP OVER TO MILLING WITH 1%SLICK KCL SECURE TRUCKS TO HAUL FLUIDS BEFORE CONTINUING OPS HOT WATER PLANT IS DOWN,MIGHT BE A DELAY IN GETTING FLUIDS 15:10 - 15:35 0.42 STWHIP P 9,582.00 WEXIT TRUCKS ARE LOADING,RIH TO LOG TIE IN 15:35 - 15:55 0.33 STWHIP P 9,602.00 WEXIT LOG TIE IN F/9560'-9602'. • 15:55 - 17:00 1.08 STWHIP P i' 9,602.00 WEXIT CORRECT DEPTH-20' e _ , 17:00 - 18:15 1.25 STWHIP P 9,603.60 WEXIT CONSULT ODE AND AGREE WE CAN GO ON J 1 DOWN AND MILL BIT AND SEE IF LOSSES lY?-2-61k SUBSIDE. DRY TAG PINCH POINT @ 9603.6'.26K DOWN WT,42K UP WT. -PICK UP,BRING ON PUMP @ 1.60 BPM/ 3200 PSI FREE SPIN. -ANNULAR BHP=3925 PSI.8.41 PPG IN/NO • RETURNS. -OPEN LINE THAT FILLS HOLE ACROSS KILL LINE,IMMEDIATE RETURNS. -MILL FOR 45 MINUTES,F/9603.5'-9603.6'. NO INDICATION OF LOSSES SUBSIDING, ADVISE ODE. • 18:15 - 20:15 2.00 STWHIP P 9,603.60 WEXIT PICK BACK UP TO 9350 AND CIRCULATE • ACROSS THE TOP OF THE WELL. -BUILD VOLUME AND HAVE SOME EXTRA KCL ON HAND,(2)TRUCKS. • -START KCL DOWN HOLE AND RIH CIRCULATING MIN RATE. 20:15 - 00:00 3.75 STWHIP P 9,604.70 WEXIT KCL OUT AT THE BIT.RESUME WINDOW MILLING OPERATIONS. -MILL ON 3 1/2"9.2 PPF 13-CR TUBING,F/ 9603.6-9604.7'. -1.64 BPM IN/1.17 BPM OUT,(PUMPING DOWN KILL LINE W/CHARGE PUMP TO KEEP HOLE FULL). -TAKE PIT STRAPS REGULARLY,DETERMINE LOSS RATE IS 95 BPH WHILE MILLING. -2150 PSI FREE SPIN W/KCL.1-3K WOB. AVERAGING.3 FPH.(1)STALL AND P/U RESTART. -THIS TUBING IS CHROME AND WAS RUN IN 2014,SO IS FAIRLY NEW AND HARD DRILLING. Printed 3/19/2018 10.14:31AM *All depths reported in Drillers Depths* TREE=. McEVOY GEN 3 FETY NOTES: "'CHROME TBG&LNR*"`SEE PG.3 'ACTUATOR =_ _--_-_- SMCEVONY III 03-29 �R PREVIOUS WELLBORE""` OKB.ELEV= sz44 BF.BEV= 32-32' 20"GOND H 120' i % I 1616' H9-5/8"HES ES CEMENTER KOP= 3650' �41 Max Angle= 52°@ 102_0_0' . 1537' 9-518"BKR ECP Datum MD= 9768' _ _ ; Datum TVD= 8800'SS ' 2146' —I4-112"HES X NP,D=3-813" 9-5/8"CSG,47#,L-80 HYD 563,D=8-861" —I 1668' GAS LFT MANDRB S 9-5/8"BOWR'1 CSG PATCH,D=9.05" —I 1668'-1662' ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347' H 2600' , I 5 3750 3745 13 WIG DMY RK 0 05/17/17 'L,II 4 6230 5889 33 WAG DMY RK 0 05/17/17 3 7674 7118 30 MMG DMY RK 0 02/07/14 Minimum ID =2.970" @ 8979' 2 8457 7792 30 M?v1G DMY RK 0 02/(}7/14 1 8742 8042 27 MIG DMY RK 0 02/07/14 9-5/8" X 7" HMC HGR w13.5" PIN 8821' —I4-1/2"HES X NP,13=3.813" 8849' —)9-5/8"X 4-1/2"TNT PKR,D=3.903" r----H 8883' H4-112"HES X NP,D=3-813" 8954" ---I4-112"OTIS XN NP,D=3.725" 8959' —I9-5/8"X 7`ERH ZXPw/HD LTP(BOT),D=6.190" 74 `�.�• 8971' H4-1/2"WLEG,D=3.958" 4-1/2"TBG, 12.6#,13CR-85, H 8971' .0152 bpf,®=3-958" jjr .' 8979' H 9-5/8"X 7"HMC HGR w /3.5"STL P,D=2.97" 5-1/2"TBG STUB(01/16/14) —+ 9047" !4./i' 9064° j---I TIW LATCH ASSY,D=4.76" i ' E9066' —{9-5/8"X 5-1/2"TM/HBBP PERM PKR,D=4.75" 1 9090' -I5-1/2"PKR SWS LANDNG NP,D=4.56" NA k 9106' —15-1/2"HES XN NP,D=4.45" ii ' BEHIND •i k 9118' ---15-1/2"BKR WLEG(BEVELED),D=4.89" SCAB HOLES N TBG(PER CALFER 10/21/06) -I 9120'-9178' :a NI :►� C. 9142' HI9-5/8"X 5-1/2"OTIS PKR LNR 1 i- 9149' —H5-1/2"X 4-1/2"XO,D=3.958" %TOP OF 7"LNR —I 9181' w ,.F ; � �, 9181' H12'BOT TIEBACK SLV,D=? 4-112'TBG, 12.6#,L-80,.0152 bpf,D=3.958' — 9020" :• If 9193' —I9-5/8"X 7"BOT SHORTY HYDRA HGR,D=? 4 ii Ilk 9-5/8"CSG,47#,L-80 BUTT,D=8.681" - I 9500' 4 14 9208' —I4 1/2"HES XN NP,D=3-725" BEHIND 9219' —14-1/2"OT SHEAROUT SUB SCAB Illk. 111 3-1/2"MONOBOREVIS w/2 RA PP TAGS(2/16/18) H 9604' y y # , 9220' —14-1/2"TBG TA L,D=3.958" LNR ', _ PERFORATION A SUMMARY 9480" H 7"MARKER JOINT REF LOG:BHCS on 06/17/84 t1 4 ANGLE AT TOP PERF:40°@9371' i Z# t Note:Refer to Production DB for historical pertdata ,410 ! 9958' H FISH:MLLED&PUSHED CEP DH(02/09/18) SEE SPF NTERVAL Opn/Sqz SHOT SQZ - .,� —SEE PAGE 2 FOR R3FFORATION DETALS— '1 1,-+ 9976"ctm --I TOC(ME LED ON 3/27/14) ' I 1. 1, 1w► - 10000' --I PBTD(TAGGED 04/27/00) 3-1/2"SCAB LNR,9.2#,13-CR STL, — 9994' r$efeem1 •�•�•�•�•�••�•1 D 1.....1.•/ .0087 bpf, =2.992" 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" --I 10283' DATE REV BY COMIulOYTS DATE REV BY COtv?vU%(TS PRt1DHOE BAY UNTT 06/24/84 ORIGINAL COMPLETION 11/19/15 GC/JMD ADDED SPF TO PERF SUMMARY VVELL: 03-29 10/25/94 RWO 10/27/16 MGS/JMD SET XXN PLUG/CORRECTED MN D PERMIT No:'1840790 02/08/14 DOYONI4 RWO 05/22/17 GJB/JMD GLV/CO&RESET PLUG(05/18/17) AR No: 50-029-21118-00 04/24/14 CDR/PJC SCAB LNR CMT CORRECTIONS 02/12/18 JGUJMD FULLED PLUGJINLLED CEP(02/09/18) SEC 11,T1ON,R15E,545'FSL&71'FVVL 06/04/14 JCMIJMD ADPERFS(06/02/14) 02/19/18 KFM+JMD SET WHIPSTOCK w/2 RA TAGS(2/16/18) 11/18/15 CJS/AD SET R_UG/ADR3 FS(10/20/15) IBP Exploration(Alaska) I 03-29 • ,,- N . At �A 111A 1 I I I c+,? Ok A.,, • Ole II r PERFORATION SUNMARY 4 REF LOG: ON / / .::! L ANGLE AT TOP PERF:40°@ 9371' I -i Note: Note:Refer to Production DB for historical pert data t % o SIZE SPF INTERVAL Opn/Sqz SHOT SQZ P Iti.� yilfr 4111 2-1/2" 6 9371-9415 0 10/20/15 ... 3-3/8" 4 9510-9640 S 05/05/91 02/04/14 ei 40 viiioi LAIIIIIIIIIMOMMIMIMINIEW i..._, 74. 3-3/8" 4 9678-9690 S 10/06/93 02/04/14 4 2-1/2" 6 9775-9795 C 06/02/14 h. MI 2-1/2" 6 9848-9868 C 03/31/14i• 44 ", 2-1/2" 6 9929-9938 C 06/02/14 3-3/8" 4 9974-9978 S 03/18/95 2/4/2014 !kill ilk, 3-3/8" 8 9978-10004 S 03/18/95 02/04/14 3-3/8" 4 10001-10008 S 03/18/95 02/04/14 4 9978- 10008 DATE REV BY CO vTv1f3'ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24/84 ORIGINAL COMPLETION 11/19/15 GC/JMD ADDED SPF TO PERF SUMMARY WELL: 03-29 10/25/94 RWO 10/27/16 MGS/JMD SET XXN PLUG/CORRECTED WPI ID PERMIT No: 1840790 02/08114 DOYONI4 RWO 05/22/17 GJB/JWD GLV/CO&REBET PLUG(05/18/17) AR No: 50-029-21118-00 04/24/14 CDR/PJC SCAB LNIR CMT CORRECTIONS 02/12/18 JGUJMD RILED PLUGJMILLED CSP(02/09/18) SEC 11,T10N,R15E,545 FSL&71'FWL 06/04/14 JCNI/JMD ADPERFS(06/02/14) 02/19/18 KFNUJ A) SET WI-FSTOCK w/2 RA TAGS(2/16/18) 11/18/15 CJS/JMD SET PLUG/ADPERFS(10/20/15)_ I BP Exploration(Alaska) • yOF T� • • \�� THE STATE Alaska Oil and Gas Of/0 L /�Ac Conservation Commission 1� s x = a= KA. 7. Witt333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 oFwh Main: 907.279.1433 ALAs� Fax: 907.276.7542 www.aogcc.alaska.gov Garrett Staudinger SCANNED JAN 7 2018 Senior Drilling Engineer BP Exploration(Alaska), Inc. PO Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-29 Permit to Drill Number: 184-079 Sundry Number: 317-603 Dear Mr. Satudinger: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of January, 2018. t'BDE is �(, 'P rt� b �' RECEIVED STATE OF ALASKA •ALASKAOIL AND GAS CONSERVATION COMM11IN DEC 2 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A i / 7 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 down 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill O• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 184-079 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development I I• 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21118-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU 03-29 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327&028328' PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): / Plugs(MD): Junk(MD): 10283 • 9196 • 8954 8229 2495 ✓ 8954.9500 None Casing Length Size MD TVD Burst Collapse Conductor 78 20" 34-112 34-112 1490 470 Surface 2469 13-3/8" 33-2502 33-2502 4930 2670 Intermediate 9468 9-5/8" 31-9499 31-8669 4930 2670 Liner 1102 7" 9181-10283 8421-9196 8160 7020 Liner 173 5-1/2"x 4-1/2" 9057-9220 8309-8452 7740/8430 6280/7500 Scab Liner 1035 3-1/2" 8959-9994 8233-9014 10160 10530 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9371-9938 8572-8977 4-1/2"12.6# 13Cr80 29-8971 Packers and SSSV Type: 4-1/2"HES TNT Packer Packers and SSSV MD(ft)and ND(ft): 8849/8137 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary I1 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch m Exploratory 0 Stratigraphic 0 Development II Service 0 14.Estimated Date for Commencing Operations: January 15,2018 15. Well Status after proposed work: . Oil 0 WINJ 0 WDSPL 0 Suspended Q • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Leemhuis,Jacob be deviated from without prior written approval. Contact Email: Jacob.Leemhuis©bp.com Authorized Name: Staudinger,Garret Contact Phone: +1 907 564 4989 Authorized Title: Senior Drilling Engineer giineer Authorized Signature: 45v \, Date: 12,/2„0/ii COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 317- c461o3 Plug Integrity 0 BOP Test le. Mechanical Integrity Test ❑ Location Clearance ❑ Other: L30P 1-t5 f *Y-0 35-6° P 5 '1 . -i-a 2_5-1) 0 1 5 ` 5 f},try/a�- rt v/�, tt,,'rsS , Gi r� Ad-Ite-rna is pl,(7 placr" 1 1— 't Ph�sof►° c�ZS. 6/ZC�� / l-7 r r a • Post Initial Injection MIT Req'd? Yes 0 No L� Spacing Exception Required? Yes❑ No Subsequent Form Required: IC -- 4 D APPROVED BYTHE Approved by: Cper....r.... ., COMMISSIONER COMMISSION Date: ( y lie) colt ORIGINAL � ,e.,, — � t.;� \' Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,if/�(;'57 /! - /L Z -, e7 •• To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis b CTD Engineer Date: December 19, 2017 Re: 03-29A Sundry Approval Request Sundry approval is requested to plug the 03-29 perforations as part of the preparation, drilling and completing the proposed 03-29A coiled tubing sidetrack. History of 03-29: , 03-29 is a Rotary Zone 4/3/2 horizontal sidetrack which was initially put on production in June 1984. A couple RWOs were performed in October 1994 and February 2014. The RWO in 1994 repaired tubing leaks and a packer leak. The RWO in 2014 ran and cemented a scab liner to shut off the Zone 4 perfs. - Zone 3 and Zone 2 were reperforated. Proposed plan for 03-29A: Drill a through tubing sidetrack with the Nabors CDR2 Drilling rig on or around March 1st, 2018. The 03-29A sidetrack will be a dual string exit from the existing 3W x 7" production liner. A 3W Whipstock will be set pre-rig. 03-29A will kickoff from 3W x 7" production liner drilling a horizontal well targeting Zone 4A/4B. Well design involves kicking off a 3W whipstock, drilling build section with 40 DLS, drilling lateral with 12 DLS geosteering in the Zone 4, run 2%" 13Cr-85 production liner, cemented and perforated. This Sundry covers plugging the existing 03-29 perforations via the production liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin January 15, 2018) 1. S Pull XXN Plug 2. C Mill CIBP 3. S Drift for WS 4. E Set WS 5. V Pre-CTD Tree Work Rig Work(scheduled to begin March 1, 2018) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,495 psi). 2. Mill 2.80"window and 10'of rathole. 3. Drill Build: 3.25" OH, -234' (40 deg DLS planned). 4. Drill Lateral: 3.25" OH, 1,246' (12 deg DLS planned). 5. Run 2%" 13Cr-85 liner leaving TOL at-8,939' MD. 6. Pump primary cement job: 13.4 bbls, 15.3 ppg Class G, TOC at-8,939' MD. 7. Perform cleanout run if needed 8. Perform liner lap test*. 9. Perforate -650' 10. Freeze protect well to a min 2,000' TVDss. 11. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Ct'Ac".. Welt his ,,tgre'Cd our reiti",frod1iO oEer i % v�'4W�/'"f- 6e-''feempot/l/LgrC4 2006. Aret� To restorl Cj`MGP /4 ,', �4„e Qro,cl J�/95GeSTvI y Irl '1 ,b '►� prod i 6 4 o 0A0(.S 0I ins t '4Arre-e( Fred in A2.1 W ,-t� no o� vmr .'r P 0. rr �C� vT' Qer y. Pfv,p IA, 7J�c &veff ffq(r/1/ 540144 Q/iOw /c ,"n f0''€ ' leavar, -i'd'/A 744 P er ri-On pF (hL Poor . l(2_01/-7 • S Post-Rig Work: 1. Pull TWC. Tree work as necessary. 2. Set liner top packer if liner lap test fails.* 3. Pressure Test LTP (if necessary) 4. PTS New Well Kickoff if perf>500' Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 TRH== McEVOY GHV 3 WH LFEAD= MCEVOY • 3—2 FOR PREVIsilky OUS WELLBORE E T8G S LNR"'SEE PG.3 ACTUATOR= AXH.SON OKB BEV= 62' I `J BE BEV= ? *I 1515' -19-518"HES ES CEMENTER KOP= 365(7 20"COPD --I 120' ' 4 Max Angle= 52 ©10200' �, 1537 i-1 9 518"BKR ECP Datum MD= 9768' Datum TVD= 8800'SS / ' 2145' -14-1/2"HES X NP,D=3.813" 9-5/8"CSG,47#,L-80 HY D 563,D=8.861" H 1558' GAS LIFT MANDRELS 9-518"BOWEN CSG PATCH,ID=9.05' H 1558'-1562' ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2500' 5 3750 3745 13 WAG DOME RK 16 '03/04/14 4 6230 5889 33 WIG SO RK 20 03/04/14 3 7674 7118 30 MNG DMY RK 0 02/07/14 Minimum ID =2.970" 8959' 2 8457 7792 30 MAG [)Mt RK 0 02/07/14 1 8742 8042 27 MAG DMY RK 0 02/07/14 9-5/8" X 7" HMC HGR w13.5" PIN I1 8821' H4-1/2"FES X NP,D=3.813" oF..174 8849' H9-518"X 4-1/2"TNT PKR,D=3.903" ' 8883' H4-1/2"FES X NP,D=3.813" ' ( 8964' 1-14-112"OTIS XN NP,D=3 725'/ 8954' H4-1/2"XXN PLUG(10/26/16) 1 8959' H9-5/8"X 7"ERH ZXPW/HD LTP(BOT),D=6.190' - 4-1/2"TBG,12.6#,13CR-85, - 8971' 2 ' 8971' H4-112"WLEG,D=3.958" k .0152 f,D=3.958" Cry 1 A♦ 8979' -9-5/8"X 7"MAC HGR w /3.5"STL P,D=2.97" f`�, 'It" 9064' -1TNV POSITIVE LATCH ASSY,D=4.76" 5-1/2"TBG STUB(01/16/14) 9047' ,;~'�'1i ,ems, e N1►.1 9055' H9-5/8"X 5-1/2"11W HBBP PERM PKR,D=4.75" ik9090k IM ' -15-1/2"PKR SWS LANDING NP,D=4.56" ilt , 9106' H5-1/2"HES XN NIP,D=4.45" BEI-IND HOLES N TBG(PER CALDER 10/21/06) - 9124'-9178' , 9118' -�5-t/2"BKR WLEG{BEVEL),D=4.89" SCAB �� ;,I., ►_1 9142'll --19-5/8"X 5-1/2"OTIS PKR LNR 9149' -15-1/2"X 4-112'XO,D=3.958' TOP OF 7"LNR 9181' �I,A s c �M 10.•-' 9181' -112'BOT TIEBACK SLV,D=? 1 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 9020' 4 J ►�• :�,, 9193' I9-5/8^X 7"BOT SHORTY HYDRA HGI�ID=? '''•" ,I4t 9208' H4-1/2"HES XN NP,D=3.725" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" -f 9500' %, BEHIND 9219' H4-1/2-OT SI-EAROUf SUB SCAB !1iii it 1 tf LAR PERFORATION SIIVLV�RY 1+ 9220' �4 112^TBG TAL,ID=3.958" Alt _ REF LOG:BHCS on 06/17/84Slti N" Sit S 9480' --17"MARKER JONT ANGLE AT TOP FEW:40°@ 9371' 4.. %. Nate:Refer to Production DB for historical perf data �I 9500' H 3-1/2"BKR CEP(10/20/15) SIZE SPF f NTB21/AL Opn/Sqz SHOT SQZ -SEEI PAGE 2 FOR PERFORATION DETALS- ' ■ I I I ( I Y„I 9976'atm HTOC(AALLED ON 3/27/14) 10000' H PBTD(TAGGED 04/27/00) 3-1/2"SCAB LW,9.2#,13-CR STL, -1 9994' 1�1'11�1�1�1�1�1�� .0087 bpf,13=2.992" 0•+•.•4++•4•4•i•• 01�1.1.1�1�141e1 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" H 10283' DATE REV BY COWMEN'S DATE REV BY COMAB'tTS FRUDHOE BAY INT 06/24/84 ORIGINAL COMPLETION 11/19/15 GC/MD ADDED SPF TO PERF SUMMARY WELL: 03-29 10/25194 MO 10/27/16 MGS/JtiD SET XXN PLUG/CORRECTED MV D FE RMT No:'1840790 02/08114 DOYONI4 IMO AA No: 50-029-21118-00 04/24/14 CDR/PJC SCAB LNR CM'CORRECTIONS SEC 11,T10N,RI 5E,545'FSL&71'FWL 06/04/14 JCWYJMD ADPERFS(06/02/14) 11/18/15 CJS/JMD SET FLUG/ADFERFS(10120/15) BP Exploration(Alaska) 03 29 III 110ci ' I ' I 8 11 0 ► j I'I' 'I~I "tie.% •e Ap N.siti. 14, Ili ! FERFORA11ON SUMvtARY REF LOG: ON_/_/_ —1_°16.- ►-� ANGLE AT TOP PERE.40°@ 9371' `�+/`. ill Note:Refer to Production DB for historical pert data ►. SIZE SPF KTERVAL Opn/Sqz SHOT SOZ II ! S 2-1/2" 6 9371 -9415 0 10/20/15 ■ li 3 I 3-3'8" 4 9510- 640 S 35/05191 02/04/14 4 1 '., .� `: )312..es�1 041291914i29t91 w v 4Min( ,e,,,.0 t3' 04/29,/91 4 3-3/8" 4 9678-9690 S 10/06/93 02/04/14 2-12" 9775-9795 _. • MI 2-1/2" 6 9848-9868 C 03/31/14 2-112" 6 9929-9938 C 36/02/14 3-3/8" 4 9974-9978 S 03/18/95 2/4/2014 3-3/8" 8 9978-10004 S 33/18/95 02/04/14 3-3/8" 4 10001-10008 S 03/18/95 02/04/14 4 9978- 10008 32/16/93 11111111111111111 11111111111111114 1114.41.44 DATE REV BY COIVIV NTS DATE REV BY COMMENTS RZIJDHDE BAY UNIT 06/24184 ORIGINAL COMPLETION 11/19/15 GC/JM? ADDED SR=TO FERE SUIVIVIARY WELL: 03-29 10/25/94 RANO 10/27/16 M3S/JID SET XXN PLUG/CORRECTED MN D FfRMT No:'1840790 02/08/14 DOYON14 MO AR No: 50-029-21118-00 04/24/14 CDR/PJC SCAB LNR CMT CORRECTIONS SEC 11,T10N, R15E,545'FSL&71'FWL 06/04/14 JCMJM7 ADPERFS(06/02/14) 11/18/15 CJS/JM) SET R_UG/ADRERFS(10/20/15) BP Exploration(Alaska) WB-LFEAD= MrEVOY PROP(D 03-29A SY NOTES: "—CHROME TBG&LNR"' ACTUATOR= OIB.ELEV= 62 ) Z I: 1 = 20•COND H 120' i►-V 1616' J-19-5/8"HES ES CEMENTER KOP= 3650' '�, = •� I• 1637' I-19-5/8"BKR ECP Max Angle@ �,` Datum ND= _- Datum TVD= 8800'SS ' , [ 2146' 1-14-1/2-HES X NP,D=3.813" 19-5/8"CSG,474,L-80 HYD 563,D=8.861" H 1668' GAS LFT MANDRELS 9-5/8"BOWEN CSG PATCH,ID=9.05" N 1668'-1662' ST M) TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.34r H 2600' 1 ( ' I 5 3750 3745 13 MING DMY RK 0 05/17/17 LI 4 6230 5889 33 MMG DMY RK 0 05/17/17 3 7674 7118 30 MNG DMY RK 0 02/07/14 2 8457 7792 30 MNG DMY RK 0 02(07/14 Minimum ID = " ' 1 8742 8042 27 MNG DMY RK 0 02/07/14 ' 8821' 141/2 FES X NP,D=3.813"1 TOP OF LNR'CMT —{ 8939' N2 8849' -1-19-519•X 4112'TNT PKR D=3.903" PERFORATION SUMMARY 8883' —1\,I 41/2HES XNP,D=3.813" REF LOG:BHCS on 06/17/84 ANGLE AT TOP PERF:40°@ 9371' _�� 8939' —I •DEPLOY SLV,D= • Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sg2 SHOT SQZ ' ■ 8964' —141/2.OTIS XN NP,D=3.725" -SEE PAGE 2 FOR PERFORATION DETAILS- ' 1 I I I I 8969' —19-5/8"X 7'ERH ZXPw/FD LIP(BOT),D=6.190' 4-1/2"TBG,126#,13CR 85, —I 8971' 2 ' ��• 8971' Hr WD 4-11LEG, =3.958" • 0152 bpf,D=3.958' i•Ilii �/� 8979' —19-5/8"X 7"HMC HGR w /3.5'STL P,D=2.97" I'd". Vi‘ II• 5 1/2'TBG STUB(01/16/14) 9047• ,�`li ��lii ,� V%1 �� 9064' —IINV POSITNE LATCH ASSY,D=4.76" II `+*J \ 9066' --I9-5/8'X 5-1/2"TNV HBBP PERM PKR,D=4.75" �9 9090' 1-15-1/2"PKR SWS LANDING NP,D=4.56" .4! 9106' —15-1/2"FES XN NP,D=4.45" BEHIND HOLES N TBG(PER CALIPER 10/21/06) —{ 9120'-9178' _7-* - 9118' —15-1/2"BKR WLEG(BEVELED),D=4.89" SCAB ='t ►•, LNR -1r1i 9142' -19-5/8"X 5-1/2"OTIS PKR I TOP OF 7"LHRH 9181' 1!i1 1 9149' —15-1/2"X 41/2"XO,D=3.958" t i4-1/2•TBG,12.6#,L-80,.0152 bpf,D=3.958" 9020' 11 9181' —117 BOT TACK SLV,D=? ' 9193' —i 9-5/8'X 7'BOT SHORTY HYDRA HGR,D=? 1 9208' H4-1/2"FES XN NP,D=3.725" g BE 9M) 9-5/8"CSG,47#,L-80 BUTT,D=8.681' —1 9600' 9219' J-14112"OT SHEAROUT SUB SCAB 3-1/2"VVHFSTOCK(_/ /_J —{ 9602' I L 9220' H4-1/2"TBG TAI..,D=3.958" LNR TOC(MILLED ON 03/27/14) 9976'CTM 111 „,„",........... 3-1/7 SCAB LNR,924,13-CR STL, —I 9994' .RIS- .0087 bpf,D=2.992 ►1�111t►1/111/111I a., ►1111 N11 •.•. PBTD(TAGGED 04/27/00) 10000' ►.1+1./.1.+•1�� — `- r LNR,294,L-80 BTC,.0371 bpf.D=8.184• 10283' 2-3/8"LNR,_#,13-CR_,. bpf,D= 11132' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY IST 06/24/84 ORIGINAL COMPLETION WELL: 03-29A 10/25/94 RWO PEWIT No: 02/08/14 DOYON14 RWO AR No: 50-029-21118-01 / CTD SIDETRACK(03-29A) SEC 11,T1 ON,R15E,545'FSL&71'PM.. 06/07/17 .MO BULT PROPOSE BP Exploration(Alaska) ! • Well Slimhole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis -1.1 ft Top of7"Otis 4CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub •4 7-1/16"5k Flange X 7"Otis Box Top of Annular I 6.0 ft f] • H dril71/16•' Top of Annular Element 6,7 ft Annular 2 Bottom Annular 8.0 ft J ► mmm•,, CL Blind/Shears 9.3 ft ► » .`ar O 00 jo 2"Pipe/Slips Cu 2"Pipe/Slips 10.1 ft 61 B2 111 B3 1.,B4 511 • Cross 24/8"x 3-1/2"VBRs III CL 2-3/8"x 3-1/2"VBRs 12.6 ft ► ink to 2"Pipe/Slips CL 2"Pipe/Slips 13.4 ft ► �� ON CL of Top Swab 16.0ft 1` Swab Test Pump Hose • • T1 #T2 CL of Flow Cross 17.4 ft � = Master CL of Master 18.8 ft •.� L LDS 11:4 111: IA n:n: Stu 0:4 = OA i it nl I!r1 LDS 1.1311:1311 Ground Level • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist'` / in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist /1- work) the initial reviewer will cross out that erroneous entry and initial then/ ,/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug Stat Tech for Redrill" box, they will enter the Typ_Work code"IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code,they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. x ,, N ,, Thousand Cubic Feet of Gas ("MCF") per Month o; o N kip O N O O O O O O o O O 0 O N O O O of OO O Ol r.4- O O . ei >1 Eri mmIIII11 '11111 Il INS °eO�o� 1 1. sll!1111®IIII111IrIIIu1 - 1111 I I ' 1111111t o ILII 111UIIII11111U111111 ' L 1111! 1 I 11 4 UIII1111INNIII111I1111PI! a IIi1111 w ! I ' 1I IOIIIUIIHIIIIIIIIIIIII .S a -0 V/ o d . j°�4�� m =I N UII11111 UI11111111UIIII11 '� ( ' 3 w ■11111111ai111111u.iiu11 VIII! I 1111 _ c 111Ii1llUII niiiNiiEiii 11111 ammo o 111111U11H1U1111111111 °rO�4P a c, N z ■IIII1111.II111111.Imn } < _. II Miii I .. ,i, Iwiti . IPIPilh iQ I ,iiiiIIII S°W70 4 s = q lo o ■III11111111111IIIII��t1111111 0. Ao ..- 11111111111111111111111111111111111 o !9_.1111 ill I 11111111111111111111111111111111111 � ' - : � : < < IIIIIHIUIIIIII �e4 a m Ilei ' COo0 8%0 ;' MIN 1111111•1u111�111111 8 3 Z LjjQ O _ �q��►o 1 a: nIP 1 a a li 64 sti -- -- 0 .11111�111111111r111 r a 111111111 Q a a� a o ° o o , .. 'I1 ',. y e_ I�111 .11/ ... m 0 CC 0 J O '2o. .� .1 �-i 86r 4Nn X 0 11111_ _ c W m s 0 . � Po o 0 o , 0 0 0 O O O O O O O i uow aad aaleM}o siaiaea Jo LOUOIAI aad tip}o stains STATE OF ALASKA • RECEWED •ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 19 2Db REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed �p�) ��' Abandon 0 Plug Perforations I3 Fracture Stimulate 0 Pull Tubing 0 Opera 's1Tu�yt7e r ❑ Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:5;t7 C I3l' b7 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 184-079 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21118-00-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number: PBU 03-29 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10283 feet Plugs measured 9500 feet true vertical 9196 feet Junk measured 9986 feet Effective Depth: measured 9600 feet Packer measured See Attachment feet true vertical 8742 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 2469 13-3/8"72#L-80 32-2501 32-2501 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCANNED JAN 2 9 201Li Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 30-8972 30-8245 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 5467 1734 272 Subsequent to operation: Shut-In 920 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature )1j], Phone +1 907 564 4424 Date 11/19/15 Form 10-404 Revised 5/2015 V 17- x/714`5 RBDMS, ri 2 0 2015 Submit Original Only • • Packers and SSV's Attachment PBU 03-29 SW Name Type MD TVD Depscription 03-29 PACKER 1537.94 1537.89 9-5/8" Baker ECL Packer 03-29 TBG PACKER 8850.17 8137.91 4-1/2" HES TNT Perm Packer 03-29 PACKER 8959.91 8234.12 7" Baker ZXP Packer 03-29 TBG PACKER 9055 8315.68 5-1/2" TIW HBBP Packer • • d .o 0 o O M o 0 co r N- co co ( (NI O O N- N O LO 0 • N I"- N- U NOOoo °) oo L O CO f— N- CO CO CO (.0 CoE) COCO M Ln LO LO LC) O co Cr co co Cc) O N N N— CO C)) CA CO i I ONr M N N O M ,— O M M M lf) N V M Co CO 4-0 w M C N • O O CO C)) O r- lC) (0 t C1) N C)) - N r 0) CA c- M C.) Q N CO N N O CO CD O C)M CO CO CO LO CA CO Co CO C)) CO I_ 0- o 0 0o °O O co O o COCOOoO Q� = J J J M 00 • 61)N # N J 1 •� _ M(/) CO O Cb COO O N U - -• CO O CA N N M t O O M O Co V LC) 0) O C) G) N N— co J W W Q Q c� LLJ00 W W LL Z Z W W LL.I UJ m O D ~ ~ Z Z D 0 Z Z J J � . II II ± 0 % a ± \ k , 0 , 0 I I � � 2 © 0 � / CU) 2 2 CC < 0 \ / $ \ O Z A2 ¢ \ / 7 / § 0 0 0 O �� 0 �� \ -1 \ 0 / I / I n G2 L < H < I- g 2E, u O b 0 ƒ \ Li_ % CO O 0 CO -6 _JO FF_ HH � / 0 0 H 0 \ 0 \ C © /a OM 0 / O MO o » ± $ 1-1-1 ,. 0 / / / / E 2 \ / 0 < ® n / - /L w / _2 0 ii 0 \ % o_ cia) D - < E H & uOH 0 E 0 E \ O / / '- 1-1 < 0a-± z - : O o / R I H / / _ Z I / 7 d ? : MCD CC 0 \ / / / \ : LI R o E \ O § R ƒ \ \ r / O 2 O �� r o M 2 H D O /< 2 CC 8 6 2 b / Z 0 0 00 / / t � Aƒ 2 \ ± / R \ HOLD Ez / \ I \ < 0 o t © ® mow ® �m / ƒ ca \ Z R O G O Z_ O 2 < cc < $ / / : •a / f < O < i / i / ui / > w e R H > / I Z E 0 Z O ƒ O r 2 \ / Z \ \ (Ni < \ / / 2 O ± ± s o k \ A d / A O CU 0 z / % ƒ / ƒ � EEE � \ F_ / D0)I N— < rf / \ \ 2f/ / 2 / k / E � � � � 0) 0) � = ± 2O / mo " QR \ . HODwODOOO _ < H _ m O O G Z Z = ± ± 0 R Z O p Z Z ¥ I 12 a E m 7, m O 0 I R 2 2 m < O I < O O o -1 c o a % \ 6 Z 0 O ¥ L = CC ¥ ± p ¥ p _ U 'Iu L "j \ -1 - E 3 - ® m < - O < - O < CDE ® o 0 ± % >. < R O O • / % i ƒ 2 % ƒ @ \ 0 $ / / $ / a \ fF ? / � 130 � ± z ± o3 ± c2 « o : G R - 6 CO t - e : : E I a_ I cC I � ce I $ : b 2 r r m \ / / / \ m \ r w * / / m 0 / \ / 0 < IFdEE= McEVOY GEN 3 0 ,,.{/0/� 29 SAI-t 1Y NOTES: '"'"CHROME TBG&LNR'""SEE PG.3 • WEI LHEAD= MCEVOY FOR PREVIOUS WELLBORE"" ACTUATOR= AXELSON OKB.ELEV= 62 BF,ELEV= 7 I F . I 1515' H9-5/8"HES ES CEMENTER KOP= 3650' 20"COND -{ 120' r fi ti Max Angle= 52°@ 10200' 6::*0. * 1537' H9-5/8"BKR ECP Datum RC= 9768' Ng I. . Datum TVD- 8800'SS {__.2145' 1----E4-1/2" tomD �4-1/2"HES X , =3.813"i 9-5/8"CSG,47#,L-80 HYD 563,D=8.861" -{ 1558' / , GAS LFT MANDRELS 9-5/8"BOWBV CSG PATCH,ID=9.05" -{ 1558'-1562' ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2500' 5 3750 3745 13 IVMG DOME RK 16 03/04/14 4 6230 5889 33 MIG SO RK 20 03/04/14 1 LI 3 7674 7118 30 MMG DMY RK 0 02/07/14 Minimum ID =2.970" @ 8959' 28457 7792 30 MMG DMY RK 0 02/07/14 1 8742 8042 27 MMG DMY RK 0 02/07/14 9-5/8" X 7" HMC HGR w13.5" PIN - ' 8821' 4-1/2"HES X NP,D=3.813" $ 8849' -I9-518"X 4-1/2"TNT PKR,D=3.903" I I [ 8883' H4-112"HES X NP,D=3.813" 8954' -14-112"OTIS XN NIP D=3.750" 8959' -19-5/8"X 7"ERH ZXPw/HD LTP(BOT),D=6.190" 4-1/2"TBG,12.6#,13CR-85, -{ 8971 `�� 8971' -14-112"WLEG,D=3.958" .0152 bpf,D=3.958" 8979' H 9-5/8"X 7"HMC HGR w /3.5"STL P,D=2.97" 4` C►;' tib' *' 9054' TPOSNE LATCH ASSY,D=4.76" 5 112'TBG STLB(01116114) - 9047' + ► M! TT 9055• --{9-5/8"X 5-1/2"TIW I-BBP PERM PKR,D=4.75" 9090' H5-1/2"PKR SWS LANDING NP,D=4.56" ''. k 9106' H5-1/2"HES XN NP,ID=4.45" BEHNro i 9118' H 5-112"BKR WLEG(BEV BLED),D=4.89" SCAB HOLES IV TBG(PER CALPER 10/21/06) - 9120'-9178' =4 11:4, E 9142' H9-5/8"X 5-1/2"OTB PKR LPR v.. tleAr 9149' H5-1/2"X 4-1/2"Xo,D=3.958" TOP OF 7"LNR 9181' *• '} p op S9181' --11Z BOT TIEBACK SLV,D=? LI 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 9020' 9193' H9-5/8"X T BOT SHORTY HYDRA HGR,D=? 9 5/8"CSG,47#,L-80 BUTT,D=8.681" �' \ 9208' JH4-1/2"HES XN NP,D=3.725" H 9500' BEHIND 9219' 1-4-1/2"OT SHEAROUr SUB I SCAB PERFORATION SUMMARY 4 9220' --{4-112"TBG TAIL,D=3.958" INR REF LOG:BRCS on 06/17/84 ANGLE AT TOP FERE:40"a 9371' `9 9480' H 7"MARKER JOINT Note:Refer to Ptoduction DB for historical pert data 9500' H 3-1/2"BKR CBP(10/20/15) SIZE SPF INTERVALOpn/Sqz SHOT SQZ `Vill -SEE PAGE 2 FOR PERFORATION DETA LS- ar ■- I [ I 1 I 'P 9976'ctm HTOC(MILLED ON 3/27/14) if.8.16,79.7e7i1 —_ AA:45s�, 10000' -PBTD(TAGGED 04/27/00) 3-1/2"SCAB LNR,9.2#,13-CR STL, H9994' ►4444444444444441 .0087 bpf,D=2.992" ►4444444444444441 1444444*4,0) 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" -{ 10283" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24184 ORIGINAL COMPLETION 04/24/14 CDR/PJC SCAB LNR CMT CORRECTIONS WELL: 03-29 10/25/94 RWO 06/04/14 JCMJMD ADFERFS(06/02/14) 1UMT No:x1840790 02/08114 DOYONI4 RWO 11/18/15 CJS/JMD SET PLUG/AMINES(10/20/15) AR No: 50-029-21118-00 04/08/14 I I W PJC PERFORATION(3/31/14) 11/19/15 GC/JM) ADDED SPF TO PEFF SUMMARY SEC 11,T10N,R15E,545'FSL&71'FWL 04/08/14 TTR/PJC MILL CMT(03/27/14) 04/15/14 PJC RWO CORRECTIONS BP Exploration(Alaska) 411 ! 03-29 .. t * + !."i ►. 4 * ►.4 4 II 11 I I I t 0 I,4 4 4 4 4 4 `'4 4 ~4* ~I 4 k FERFORATION SUMMARY .' REF LOG: ON_/_/ + ►�� ANGLE AT TOP PERF:40°C 9371' 11. Note:Refer to Production DB for historical pert r. data r.. SIZE SW MER/AL Opn/Sqz SHOT ,O7 y • S 2-1/2' 6 9371-9415 0 10/20/15 3-3/8" 4 9510-9640 S 05/05/91?02/04/14 P 4 4 3-3/8 4 9678 9690 S 10106/93 02/04/14 2-1,2" 6 97775-9795 C 06,02;'14 '<�� M 2-1/2" 6 9848-9868 C 03/31/14 . 2-1I2" 6 9929-9938 C 06/0214 . 3-3/8" 4 9974-9978 S 03/18/95 2/4/2014 •,. 3-3/8" 8 9978-10004 S 03/18195 02/04/14 • . 3-3/8" 4 10001- 10008 S 03/18/95 02/04/14 ibi 4 9.978- 111008 02116/93 Nitii$ 11+.....*.+1 14�`�+1. 44.8.4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRU DHOE BAY UNIT 06/24/84 ORIGINAL COMPLETION 04/24/14 CDR/PJC SCAB LW CMI CATIONS WELL: 03-29 10/25/94 FMO 06/04/14 JCMJM)ADFERFS(06/02/14) PERMIT No: 1840790 02/08/14 DOYONI4 FMO 11/18/15 CJS/JM) SET PLUG/ADFERFS(10/20/15) AR No: 50-029-21118-00 04/08/14 TTR/PJC PERFORATION(3/31/14) 11/19/15 GC/J1/3 ADDED SW TO KM SUMMIARY SEC 11,T10N,R15E,545'FSL&71'FWL 04/08/14 TTR/PJC MAL CMT(03/27/14) 04/15/14 PJC RWM)CORRECTIONS BP Exploration(Alaska) ` yw1 j/j,6, THE STATE Alaska Oil and Gas �'�'7►:-s��.�'�l of//�A�j\ T■®■■ q�Ir' /A\ t //� (�'� �?y�1 jo('� Com.) t o (�y®; , _ __4-? i ai./ �.�`' �� i `..,G111112eli �Y(ililiiil�m �L o ��i) f fission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA; S16"' Anchorage, Alaska 99501-3572 ALA Main: 907.279.1433 Fax: 907.276.7542 Dave Bjork SCANNED AUG 1 8 2014 Engineering Team Leader p-� D BP Exploration (Alaska), Inc. ` 0 'T P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-29 Sundry Number: 314-002 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. • cerely, • Daniel T. Seamount Commissioner DATED this 9 day of January, 2014. Encl. STATE OF ALASKA 44L., RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION �,6;\ APPLICATION FOR SUNDRY APPROVAL JAN 0 3 2014 20 AAC 25.280 �®�� 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool ®Repair Well ' 0 Change Approved Program ❑Suspend ®Plug Perforations• ®Perforate • ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate IN Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 184-079 3. Address: ❑Exploratory 0 Stratigraphic Alaska 99519-6612 ®Development 0 Service P.O. Box 196612,Anchorage, 6. API Number: 50.029-21118-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 341 D PBU 03-29 • Will planned perforations require a Spacing Exception? 0 Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 028327&028328• Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10283' • 9196' . 10000' 9018' 9080', 9208' 9986' (2) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32'- 110' 32'- 110' 1490 470 Surface 2469' 13-3/8" 31'-2500' 31'-2500' 4930 2670 Intermediate 9470' 9-5/8" 30'-9500' 30'-8669' 6870 4760 Production Liner 1102' 7" 9181'- 10283' 8421'-9196' 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9510'- 10008' 8677'-9023' 5-1/2", 17#x 4-1/2", 12.6# L-80 9220' Packers and SSSV Type: 9-5/8"x 5-1/2"TIW HBBP Packer; Packers and SSSV 9055'/8316'; 9-5/8"x 5-1/2"OTIS Packer MD(ft)and TVD(ft): 9142'/8389' 12. Attachments: 13.Well Class after proposed work: ® Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic IS Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 5,2014 ' •®Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Rymut,564-4398 R Printed Name: Dave Bjork) �eo,r /A�p,,J��r Cod mut b Title: Engineering Team Leader Email: Y Y @ Pcom Signature: /� ,, co Phone: 564-5683 Date: / L/f CVL v Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry �\L _ C C)-L^ Sund Number: _ ❑Plug Integrity'"BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: V r1©P rest- to 3560 1::::,5 + RBDMS MAY 1 0 2014 Spacing Exception Required? 0 Yes liNo Subsequent Form Required: /0 '''i 0 APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: 6 I (/! 9-- Form 10-403 Revised 1./2012 Approv(d�, ti i ` i f 't 1#months from the date of approval Submit In Duplicate $ \� by 0 Sundry Request for Casing Repair and Scab Liner Well: 03-29 Date: 12/31/2013 Engineer: Cody Rymut. MASP: 2366 psi .. ' Well Type: Producer Estimated Start date: February 5th, 2014 History: 03-29 was completed in July 1984 in zone 43P. In March 1991 zone 45P perforations did not add significant gas. The well is currently has open perforations in zones 46, 44, 43, 42, 24P. E-line lost 6 springs off of bowspring centralizer in 6th of May 2000 while attempting to fish out IBP and hyd disco @ 9,970' SLM. The IBP was fished out but the well has e-line tool string stuck in hole @ 9,986' SLM. v In March 2006 the well was SI since DSO was unable to maintain OA pressure under MAASP. Well was de-pressured and freeze protected. The 21st of October 2006 caliper recordings indicate that the 4.5" Tubing Tail is in poor condition with penetrations ranging from 51%to 100%wall thickness. A Hole with 49%wall thickness is recorded @ 9178'. No significant ID restrictions are recorded throughout the tubing tail. Starting head leak was confirmed on 25th of February 2008, and IA and OA gas samples came back showing different compositions in September 2008. There are parts of the TIO plot that look suspicious (IA and OA not equalizing). Considering the evidence this well may not have IAxOA communication but instead it's experiencing high OAP from an external gas source similar to 03-08. 28th of April 2011 gas sample shows 10.6% CO2 and 81.4% methane. SL went to do a D&T and SBHPS in 23rd of June 2011 and got hung up at 9623' SLM and had to pump hot oil to get loose. Possible liner damage @ 9,623' MD was also notified on the 23rd of June 2011. In late June 2012 it was necessary to secure the well for upcoming wellhead weld repair. There were numerous attempts to get a successful MIT on the tubing during the pre-wellhead repair in early July 2012 but they failed. In addition, we could not get plugs to hold pressure in any of the profiles (-5) in the tailpipe, so had to set an 5-1/2" Baker RBP @ 9,080' MD above the tailpipe. Eventually; the well passed a CMIT-TxIA to 2500 psi on 6th July 2012 and passed a PPPOT. This allowed to progress with the bradenhead weld job. The starting head welding was completed on 18th of September of 2012 and no surface-breaking defects were found. The well passed the Dye Penetrant test"PT" on 25th of September 2012; however, the pack-off seal assembly was damaged during testing; therefore, a PPPOT was successfully performed post SH weld on 27th September 2012.The procedure called for Non Destructive Test"NDT" post SH weld, but the Radiographic Test"RT" done was not acceptable due to IQ wire issues; so an Ultrasonic Test"UT"was to be performed instead. The planned UT was never performed but subsequent required pressure testing was, and the well passed the MIT-OA to 1,200 psi in 3'd of October 2012. Prior to installing the flow sleeve in station#7, the well failed an MIT-T on 02nd of July 2012 indicating that a TxIA leak. In addition to the flow sleeve in station#7, the well had a generic design with an unloading valve in station#1 (top) and an orifice valve in station#2. Subsequently; all live valves were dummied and the well was re-tested for a passing MIT-T. However; after setting the dummy gas lift valves in all the stations we were unable to get a passing MIT-T on 13th of November 2012. 03-29 failed CMIT-TxIA with a calculated LLR of 0.044 bpm @ 2500 psi on 16th of November 2012. TecWel Leak Detect Log was performed on 5th March 2013 and elevated signals were present at 9,056'MD indicating a leak at the 9- 5/8"X 5-1/2"TIW HBBP Packer. Elevated signals were also present at 7,293' MD indicating a leak at GLM#3. The proposed RWO will be to repair the leaks mentioned above as well as performing casing repair to take care of the historical IAxOA communication to gas. Seal-tite was also considered but it has a less- than-stellar record in repairing casing leaks to gas on sustained gas-lift and having any sort of longevity. The plan is to shut off upper Zone 4 and perforated lower Zone 4 and Zone 2. There is remaining oil trapped in 41 P/42P below the 42N. In addition; there has not been off take in Zone 2 from 03-29 and we expect the water injected into Zone 2 would be slumping to the bottom and closer to 03-02 leaving oil behind. Upper Zone 4 has lower oil saturations than initial oil saturations but is still a target that can be , pursued with CTD in 2014 if necessary. Scope of Work: Pull 2-7/8" 13Cr-85 tubing (pre rig cut), Mill and fish 9-5/8" x 5-1/2"TIW Permanent Packer, Mill and fish 9- 5/8" x 5-1/2" Otis Packer, Cleanout 7" LNR to PBTD, Install 4.5" scab LNR, USIT log 9-5/8" CSG to determine cement top in 9-5/8" x 13-3/8" annulus, Mechanically cut 9-5/8" CSG, Pull 9-5/8" CSG, Run and fully cement 9-5/8" tieback, Run 4-1/2" 13Cr-85 completion tubing. Pre Rig Prep Work: Task S Pull 5-1/2" Baker RBP @ 9080'MD. S Pull PXN from 9208'md. Drift and Tag PBTD with 2.5" gauge ring. E Baker RPM-C PNC3D and Carbon Oxygen Log S Set 4-1/2" PXN plug @ 9208'MD, Set 5-1/2" Baker RBP @ 9080'MD S Drift down to —9060'MD with 5-1/2" gauge ring. E Jet cut 5-1/2" tubing in top 10' of 1st full joint above TIW packer (-8995'MD) F Circulate well to clean seawater, freeze protect ✓ Set BPV O Pull well-house, flow-line, prep pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6"VBRs, blind shears, mud cross and 3-1/2"x 6"VBRs). Test the V6BRs to 3500 psi and the annular to 3500-psi. 2. Pull 5-1/2" L-80 tubing from pre-RWO cut—8995' MD. 3. Rotate out latch from the top of the TIW packer 4. Pressure test 9-5/8" CSG to 3000psi 5. Mill and fish TIW packer and tail pipe assembly @ 9055'MD 6. Mill and fish the Otis packer and original 4-1/2"tail pipe 7. Cleanout 7" LNR to PBTD 8. Run 4-1/2" scab liner down to PBTD and cement in place. 9. RIH with USIT logging tools and determine top of cement in 13-3/8"x 9-5/8" annulus. 10. Run a 95/8" RBP, set—100' below logged TOC, and stack 50ft of sand on RBP. PT RBP to 1000psi 11. Change the upper pipe rams to 95/8" solid pipe ram and test. 12. Mechanically cut the 95/8" casing in 1st full jt above logged TOC. 13. Circulate out Arctic Pack in 133/8" x 95/8" annulus. 14. Pull 9-5/8" casing down to the cut. 15. Dress-off 95/8" casing stub and scrape 13-3/8" casing. 16. Run and fully cement 95/8"tie-back casing. 17. Drill out 95/8" shoe-track, PT casing to 3500 psi. 18. Retrieve 95/8" RBP. 19. Run 4-Y2" 12.6#/ft 13Cr-85 VamTop tubing with HES TNT packer, set the packer at—8908' MD. 20. Displace the IA to packer fluid and set the packer. 21. Test tubing and IA to 3,500-psi. Freeze protect to 2,200' MD. 22. Set BPV. ND BOPE. NU and test tree. RDMO. Post rig Work ✓ Pull BPV S Pull ball and Rod, Pull RHC seat, E Perforate S Run GL Design GEN 3 LO= �O IMY MCEVOY 03-29 SA NOTES: ""CH2OMETBG*'* POSSIBLE7"LNR ACTUATOR AXaSON DAMAGE(SEE 06122/11 AWGRS).HOLES IN 5-1/2"TBG KB.BEV= 62 (PER 10/21/06 CALIPER). BF.ELEV= ? I rk KOP= 3650' Max Angle= 52°@ 10283' 2118' 5-1/2"CAM TRDP SSSV NIP,D=4.562" Datum MD= 9 �. 1�. 7 LOCKED OUT(11/11/12) Datum ND= 8800'7: GAS LFT MAMJRES ST' MD NEV D DTYPE VLV LATCH PORT DATE 1 '3757 3752 13 OT DMY RM 0 11/12/12 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2500' ' 2 6290 5940 33 OT DMY RM 0 11/12/12 3 7288 6785 31 OT DMY F21 0 09/20/11 4 7883 7298 31 OT DMY T-2 0 01/03/95 5 8474 7807 30 OT DMY T-2 0 10/24/94 Minimum ID = 3.725" @ 9208' 6 8781 8077 27 OT DMY T-2 0 10/24/94 4-1/2" OTIS XN NIPPLE 7 8927 8206 29 OT DMY T-2 0 11/12/12 I I 9033' —15-1/2"PKR SWS LANDING NP,D=4.56" 9054' ---11-Mr POSITNE LATCH ASSY,D=4.76" 9055' —+9-5/8"X 5-1/2"TNY HBBP PERM PKR,D=4.75" 9080' H 5-1/2'BKR REP(07/02/12) I I 9090' -j5-1/2"PKR SWS LANDING NP,D=4.56" 5-1/2"TBG, 17#,13CR-80 NSCC, --I 9118' .0232 bpi,D=4.892" `I I 9106' H5-1/2'HES XN MP,D=4.45" 9118' —15-1/2'BKR LEG(BEVELED),D=4.89' HOLES IN TBG(PER CALIPER 10/21/06) —19120'-9178' IL WEL — , 9142' —19-5/8"X 5-1/2"OTIS PKR 9149' H5-1/2"X 4-1/2'XO,D=3.958" 5-1/2"TBG,17#,L-80 AB-M,.0232 bpi,0=4.892' —1 9149' 9181' —112'BOT TEBACK SLV,0=? TOP OF 7"LNR 9181' 9193' —19-5/8"X 7"BOT SHORTY HYDRA HGR,D=? HI: I 9208' H4-1/2"OTIS XN NP,N3=3.725' 9208' —14-1/2'PXN PLUG(06!30/12) 4-1/2"TBG, 12.6#,L-80,.0152 bpi,D=3.958" H 9220' 9219' H4-1/2"OT SHEAROUT SW 9-5/8"CSG,47#,L-80 BUTT,D=8.681" —{ 9500' A L. 9220' _—{4-1/2"TBG TA L,ID=3.958" 9194' —I E-ND TT LOGGED 08/09/85 PERFORATION SUNvIARY 9478' H7"MARKE2JONT REF LOG:EWES ON 06/17/84 J ANGLE AT TOP PEW:42°@ 9510' ) 41 9623' - I POSSIBLE UNER DAMAGE(06/22/11) Note:Refer to Production DB for historical perf data SIZE SFE NTBRVAL Opn/Sqz DATE I 3-3/8" 4 9510-9640 0 05/05/91 3-3/8" 4 9678-9690 0 10/06/93 3-3/8" 4 9974-9978 0 03/18/95 I 3-3/8" 8 9978- 10004 0 03/18/95 ' 1 3-3/8" 4 10004-10008 0 02/16/93 9986' 6 BOWSPRNG SPRNGS .06"X.50"X 22"ON 05/07/00 9986' —ICCL,SET TOOL(PUMP),F1 ESS BU& PBTD(TAGGED 04/27/00) —1 10000' Pl1LL DISC.CAL 15.06'ON 05/07/00 .......I 7"LNR,29#,L-80 BTC,.0371 bpi,D=6.184" --1 10283' •,v,•,•,•,•,v,. c".".1.,.1.x! DATE REV BYCOMMENTS DATE REV BY COMMENTS PRUIDHOE BAY UNIT 06/24/84 +ORIGINAL COMPLETION 07/09/12 GJF/.NAD SET 5-1/2"&4-1/2"PLUGS(06/30-07h WELL: 03-29 10/25194 LAST WORKOVER 07/09/12 GJF/JM) HOLES IN TBG(10/21/06) FERMT Na: 1840790 12/19/07 CMC/PJC DRAWING CORRECTFDNS 07/09/12 BSFJJMD GLV C/O(07/03/12) AR No: 50-029-21118-00 06/23/11 WE/SV-LINF.R DAMAGE(06/22/11) 11/16/12'SWC/JMD LOCK OUT TRDFYGLV C/O(11/11-12/12) SEC 11,T1ON,R15E,545'FSL&71'FWL 09/21/11 CDJ/PJC GLV C/O(09/20/11) 11/08/11 PJC PERE CORRECTION(ALL OPEN) BP Exploration(Alaska) TREE= McEVOY GEN 3 SA NOTES: **'CHROME TBG'" .WELLHEAD= MCEVOY 03-29 ACTUATOR= AXELSON KB.ELEV= 62' E r se i R H . G BF.aEV= ? I — I KOP= 3650' Max Angle= 520 @ 10283' Datum MD= 9768' 20"COND 120' Datum TVD= 8800'SS 9-5/8" HES ES Cementer —I -229°'- I I I — 2,200' 14-1/2"HES'X'NP,D=3.813" 9-5/8" BKR ECP — l 2300 I 9-5/8" Bowen Casing Patch — l 2320' I ip — I 2350' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" —I 2500' — 1 3757 2 6243 L 3 7654 4 8466 5 8797 4-1/2"TBG,12.6#,13Cr-85,.0152 bpf,ID=3.9582-I 8908' ' I I 8,877' —14-1/2"HES X NIP,ID=3.813" 8,908' —19-5/8"X 4-1/2"HES'TNT F I — I 8,942' -14-1/2"HES'X'NP,D=3.813" Minimum ID = 3.725" @ 9208' I — 4-1/2" OTIS XN NIPPLE 9014' —14-1/2"OTIS XN NIP,ID=3.725" III 9,043' —9-5/8"X 4-1/2"LINERTOP TOP OF r LNR H 9181' I _ - 9191 -0-58'X7'W9-CRIY RD 1›? 9-5/8"CSG,47#,L-80 BUTT,D=8.881" H 9500' j , , v. 4 PERFORATION SUMMARY m REF LOG:BRCS ON 06/17/84 ANGLE AT TOP PERF:42°@ 9510' Note:Refer to Production DB for historical pert data SIZE SPF_ INTERVAL Opn/Sgz DATE x 3-3/8" 4 9510-9640 0 05/05/91 3-3/8" 4 9678-9690 0 10/06/93 3-3/8" 4 9974-9978 0 03/18/95 3-3/8" 8 9978-10004 0 03/18/95 3-3/8" 4 10004-10008 0 02/16/93 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 9220' PBTD(TAGGED 04/27/00) — 10000' •1111111•..11111 . 7"LNR,29#,L-80 BTC,.0371 bpf,ID=6.184" H 10283' Wm/•1.1•� 4.•.4.4.4.IAw. DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24/84 _ORIGINAL COMPLETION 07/09/12 GJF/JMD SET 5-1/2"&4-1/2"RUGS(06/30-07 WELL: 03-29 10/25194 LAST WORKOVER 07/09/12 GJF/JMD HOLES IN TBG(10/21/06) PERMT No: 1840790 12/19/07 CMC/PJC DRAWING CORRECTIONS 07/09/12 BSE/JMD GLV C/O(07/03/12) AR No: 50-029-21118-00 06/23/11 WEC/SV LINER DAMAGE(06122/11) 11/16/12 SWGJMD LOCK OUT TRDP/GLV GO(11/11-12/12) SEC 11,T10N, R15E,545'FSL&71'FWL 09/21/11 CDJ/PJC GLV C/O(09/20/11) _ 11/08/165/8'PaG,d ?E� l ($18$1 it ) 9500' I 8P Exploration(Alaska) • I Ig g 6 . 0 r pa g G: ' l IF ib .pg O I N NOY z H 3 8hp OZ 7 W O 2 li ma 6 6 N W a 2 1 It > -, 2 0 7 13_ 2 d w ZZ m Y U m H m o pp■ N M IA CO n $ W €tl Z 0R • _ _ h 3-( i 11111 atiki [ si Mill G❑ tO o W r U2 Z N e L N a rn - 0 r, J S 8 c N]2 //pp q/ _o 21i 11 /I '- \ d ,C MW Y CD- I- a m as 11 L( m z x� a a If - tIP el FAR s 1 .- 1 nII ---- 110-11-- lÀ; Ill .A. i Qa ,.. 2 - p < Ki E 1 11 6 l � I _ g jI .1 ..,,,, ,I--- A 11\ e ii j SI i • Ferguson, Victoria L (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday,January 07, 2014 8:02 AM To: Rymut, Cody D Cc: Fer Victoria L(DOA), Subject: RE: PBU 03-29 RWO r Cody, I'll pass this application along for engineering review, but as you can understand, I'm reluctant to sign off on an application before all details of the planned operation are known. Please submit a list of planned perforations via email as soon as practical to add to AOGCC's file on the well. Thanks, Steve Davies AOGCC From: Rymut, Cody D [mailto:Cody.Rymut@bp.com] Sent: Monday, January 06, 2014 5:29 PM To: Davies, Stephen F(DOA) Subject: RE: PBU 03-29 RWO Steve, I can definitely do that, but unfortunately this afternoon the 03-29 well was accelerated on our schedule and should be going in about 2 weeks which might make things fairly tight on timing. We are currently trying to get a Halliburton RMT log ready to run the job as soon as possible but my best guess is still a week or so before we have the log. I'm not sure if that changes things on your end, but keep in mind the perforations won't be occurring in a separate hydraulic unit just at a deeper depth than the current perfs. Cody From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, January 06, 2014 5:20 PM To: Rymut, Cody D Subject: RE: PBU 03-29 RWO Cody, Since we have some time available, could you please provide the list of proposed perforation depths soon after you run the log? Thanks, Steve Davies AOGCC From: Rymut, Cody D [mailto:Cody.Rymut@bp.com] Sent: Monday,January 06, 2014 5:16 PM To: Davies, Stephen F (DOA) Subject: RE: PBU 03-29 RWO Steve, 1 r The proposed perforation depths are currently based on a log we are going to be running in the next week or so. I don't have the depths of the perforations currently but they have listed the desired zones to perforate as below 8736'TVDss (9678' MD).The plan is to perforate upper zone 2 first and flow the well followed by perforations in lower zone 4, but no depths are currently listed. I could talk with the PE and get them to estimate where these zones should come in depth wise if you would like? Cody Rymut RWO Engineer 907-564-4398 From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Monday,January 06, 2014 4:38 PM To: Rymut, Cody D Subject: PBU 03-29 RWO Cody, I'm reviewing the Application for Sundry Approval for BP's planned RWO for PBU 03-29,and I don't see a list of proposed perforations in either the Proposed RWO Procedure or the Post-Rig Work sections of the application,or on the proposed wellbore schematic drawing. Have I overlooked something? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission(AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 2 riCtoCI V CLJ • STATE OF ALASKA OCT 1 0 2012 A KA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well [J Plug Perforations U Perforate U Other t'Arti� If erui Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ t.sci d Change Approved Program ❑ Operat. Shutdown': Stimulate - Other ❑ Re -enter Suspended Weft❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development is Exploratory ❑ 184 -079 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21118 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ,. ADL0028328 PBU 03 -29 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,., To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10283 feet Plugs measured See Attachment feet true vertical 9195.52 feet Junk measured 9986 feet Effective Depth measured 9080 feet Packer measured See Attachment feet true vertical 8336.79 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 32 - 112 32 - 112 0 0 Surface 2469 13 -3/8" 72# L -80 31 - 2500 31 - 2499.58 4930 2670 Intermediate None None None None None None Production 9470 9 -5/8" 47# L -80 30 - 9500 30 - 8669.28 6870 4760 Liner 1102 7" 29# L -80 9181 - 10283 8420.67 - 9195.52 8160 7020 Perforation depth Measured depth 9510 - 9525 feet 9525 - 9572 feet 9572 - 9640 feet 9678 - 9690 feet 9974 - 9978 feet 9978 - 10004 feet 10004 -10008 feet True Vertical depth 8676.66 - 8687.71 feet 8687.71 - 8722.09 feet 8722.09 - 8771.23 feet 8798.43 - 8806.98 feet 9001.15 - 9003.77 feet 9003.77 - 9020.72 feet 9020.72 - 9023.32 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): R RCMS OCT 11 2012 SCANNED JAN 10 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 11 0 8289 1678 266 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Ei - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil (J Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG'❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email GarfY.CBtront BP.Com Printed Name Garry Catron Title PDC PE Signature jj w - C - Phone 564 -4424 Date 10/10/2012 A f V� v HAAS OCT 1 1 �►' ■' v �" i /* //.- Form 10-404 Revised 10/2012 Submit Original Only • • 03 -29 184 -079-0 Plugs Attachement SW Name Date MD Description 03 -29 7/2/2012 9080 5 -1/2" Baker RB Plug 03 -29 6/30/2012 9208 4 -1/2" Otis X Plug 1 Packers and SSV's Attachment ADL0028328 SW Name Type MD TVD Depscription 03 -29 PACKER 9055 8253.68 5 -1/2" TIW HBBP Packer 03 -29 PACKER 9142 8326.55 5 -1/2" Otis Packer • Casing / Tubing Attachment ADL0028328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" Conductor 32 - 112 32 - 112 LINER 1102 7" 29# L -80 9181 - 10283 8420.67 - 9195.52 8160 7020 PRODUCTION 9470 9 -5/8" 47# L -80 30 - 9500 30 - 8669.28 6870 4760 SURFACE 2469 13 -3/8" 72# L -80 31 - 2500 31 - 2499.58 4930 2670 TUBING 9089 5 -1/2" 17# 13Cr80 29 - 9118 29 - 8368.61 7740 6280 TUBING 31 5 -1/2" 17# L -80 9118 - 9149 8368.61 - 8394.34 7740 6280 TUBING 71 4 -1/2" 12.6# L -80 9149 - 9220 8394.34 - 8452.44 8430 7500 • Ill • Daily Report of Well Operations Y p p ADL0028328 ACTIVITYDATE SUMMARY • = 1 0 +10 +. Temp = SI. WHP's ' YVe • • rep pos • ee•. 'ressures unchanged overnight. Hardline has 20 psi. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. Block valves on hardline SI. 7/17/2012 NOVP 17:15 T /I /O = 0/5/0 +. Temp I. WHP's (SH Weld Prep) post bleed. IAP increased —5 psi overnight. Hardline has 25 psi. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. Block valves on hardline SI. 7/18/2012 NOVP. 15:15 ? /110 = 0/38/4. Temp = SI. Bleed WHPs to 0 psi, Depress T & IA w /N2 (Prep for welding). AL spool disconnected, ALP = 340 psi. Flowline pressure = 20 psi. Hardline rigged up from IA to tree cap of well 28. Bleed IAP from 38 psi to 0 psi < 1 min to slop tank. Bled OAP from 4 psi to 0 psi < 1 min. Pumped 3 bottles of N2 down TBG taking returns up the IA to depress T FL from near surface to 300' (6.5 bbls fluid returned to slop tank). U -tube T /IAP to 140/120 psi. Monitored for 30 minutes, TP, IAP & IA FL unchanged. Increased IAP from 120 psi to 700 psi w/ N2. Monitored for 2 hrs, IA FL @ 54'. Bled IAP from 700 psi to 100 psi for N2 cap. IA FL rose to 30'. Increased OAP from 4 psi to 50 psi w /N2 3 times trying to purging OA (all gas returned during purge). N2 cap left on OA FL @ 42'. Job Incomplete. Final WHPs = 130/100/50. 9/5/2012 SC, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 1730. T /I /O = 105/100/50. Temp = SI. Check FL's (Prep for welding). AL spool dropped. ALP = 300 psi. T FL @ —300', IA FL @ near surface, OA FL @ —36'. Bled TP from 105 psi to 0 psi in 20 min to slop trailer (all gas). Bled IAP from 100 psi to 0 psi in < 5 min to slop trailer (gas & fluid). IA FL @ surface. OA purged three times with 70 psi N2. OA FL @ —36'. Bled ALP from 300 psi to 0 psi, SI AL @ lateral. Job incomplete. Final WHPs = 0 +/0/0. 9/6/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 1500 T /I /0= 0/8/0. Temp= SI. Circ -out IA w /brine, Surface casing leak depth determination & install N2 cap on T, IA & OA (Pre SH welding). AL spool disconnected, ALP= 15 psi. TP & T FL unchanged, OAP & OA FL unchanged, IAP increased 8 psi & IA FL dropped to 46' overnight. Bled IAP from 8 psi to 0 psi in 1 minute (all gas). Pumped 7 bbls 9.8 brine into tubing taking returns up the IA (2.3 bbls clean brine returned to slop tank). Pumped 3 bottles N2 into tubing taking returns up the IA trying to purge fluid from T & IA (6.87 bbls fluid returned during N2 purge). Rigged up from T to IA allowing well to U -tube for 1 hour. T FL © 390', IA FL @ 40'. N2 cap on T /IAP= 220/220 psi. Maintained open bleed on OA companion valve. Strapped OA w /plumb bob, OA FL @ 39'. N2 cap on OAP= 50 psi. Monitored for 30 minutes, T, IA & OAP unchanged. Final WHPs= 220/220/50. Job completed. 9/7/2012 SV,WV= closed. SSV,MV =open. IA,OA =open to gauge. NOVP. 17:25 Daily Report of Well Operations ADL0028328 T /I /0= 220/220/50. Temp= SI. Circ out IA fluid and collect sample (Pre SH weld). AL spool disconnected. TP & T FL unchanged, IAP unchanged, IA FL rose to near surface, OAP & OA FL unchanged overnight. Pumped 2 bottles N2 into tubing taking returns up IA (2 bbls fluid returned to slop tank). Collected fluid sample for lab test. Monitored for 3 hrs, IAP & IA Fl unchanged. Bled off TP from 200 psi to 10 psi (all gas). Pumped 1 bottle of N2 into IA to increase IAP from 50 psi to 700 psi, no changes in TP & T FL during IAP increase. Rigged up to U -Tube T & IA to 100 psi. Monitored for 30 minutes, T & IA pressure unchanged. FWP's = 100/100/48. Job incomplete. 9/8/2012 SV, WV= closed. SSV,MV =open. IA,OA =open to gauge. NOVP. 1700 hrs. T /I /0= 100/100/48. Temp = SI. WHP's. FL's & IA gas sample. (pre -SH Weld). No change in WHP's overnight. TBG FL @ 468' (10.9 bbl), IA FL @ 36' (1.6 bbl). Gas sample taken for testing. 9/9/2012 SV & WV = C. MV &SSV = O. IA & OA = OTG. NOVP. 0833. T/I/0 = 94/100/48. Temp = SI. WHPs. FL's & LEL's (Pre SH Weld). AL spool disconnected. IA has integral installed = inspection not current. TP decreased 6 psi, IAP & OAP unchanged overnight. Tubing FL @ 480' (11.1 bbl). IA FL @ 48' (2.1 bbl). IA & OA 02 = 1.6 %, LEL's over range. 9/10/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 1630 T /I /0= 94/110/50. Temp = SI. Prep for SH Weld. (Pre -SH weld). No change in TP, IAP increased 10 psi & OAP increased 2 psi in 3 days. T FL = 468', IA FL = 36' & OA FL = 90'. Bled OAP to 0 psi, pressured OAP from 0 psi to 160 psi with N2, monitored for 1 hour, no change in OAP. Bled OAP to 0 psi & repressured OAP w /N2 to 152 psi. Bled TP to 0 psi & pressured IAP to 400 psi to increase IA FL, monitored for 1 hour, no change in IA FL. Found tag on control line valve stating SSSV is not locked out (closed). Tried to open SSSV w/ pump & control line would not hold pressure. Installed 50 psi N2 cap on TBG. Rig down for end of shift. Final WHP's = 50/400/152. 9/15/2012 SV & WV = C. MV & SSV = 0. IA & OA = OTG. NOVP. T /I /0= 30/390/152. Temp = SI. WHP's. (Eval for SH Leak). TP decreased 20 psi, IAP decreased 10 psi & No change in OAP overnight. 9/16/2012 SV & WV = C. MV & SSV = O. IA & OA = OTG. NOVP. 1400 T /I /0= 30/400/152. Temp = SI. Prep for SH Weld. (SH weld). No change in WHP's overnight. TBG FL @ 438', IA FL @ 18' & OA FL @ 90'. Bled IAP to 50 psi as per procedure. Bled OAP to 0 psi and started N2 purge across OA for prep grinding in SH. Grinding finished & OK'ed by QC. Rig down & monitor for 30 minutes. Final WHP's = 30/50 & 0 +. SV & WV = C. MV & SSV = O. IA & OA = OTG. NOVP. 1750. 9/17/2012 Established OA purge with N2 ground off threads for start head weld 9/17/2012 ***Job in Progess * ** T /I /0= 36/78/5. Temp= SI. Purge OA w/ N2 (SH weld). AL spool removed. Increased IAP w/ N2 to 100 psi. Increased TP w/ N2 to 75 psi. Purged OA w/ N2 @ 5 psi during weld pre -heat & starting head weld. 9/18/2012 ** *Continued on 09 -19 -12 WSR * ** 9/18/2012 Starting head welding completed per welding procedure T/I/0= 75/180/8. Temp= SI. Purge OA w/ N2 (SH weld). AL spool removed. Maintained purge on OA w/ N2 until wellhead temp cooled to < 180° F. Monitored for 30 min. OAP decreased 1 psi. See log for details. Job complete. Final WHPs = 73/120/5. 9/19/2012 SV, WV = C. SSV, MV = 0. IA & OA = OTG. NOVP. 11:50 • Daily Report of Well Operations ADL0028328 T /I /O = 50/110/0. Temp = SI. Pull Spill containment, Ladder, anything else in cellar ( Post SH Weld). Re Installed Grating. AL spool removed. IA has integral installed = inspection not current. TP decreased 25 psi, IAP decreased 70 psi and OAP decreased 8 psi since 09 -19 -2012. Job complete. 9/27/2012 SV, WV = C. SSV, MV = 0. IA &OA = OTG. NOVP. 09:30. T /I /0 = 0/20/0. Conduct PJSM. Barriers= IA and OA 18 -1/2 turns. Pressure locked through grease fittings to 5000 psi for 5 min. (passed). Charted and documented. Shut in OA valve on other side (18 -1/2 turns) and bled to zero to RU lubricator. LTT passed. PT'd lubricator to 200 -300 psi. for 5 min. (passed) and 3500 psi. for 5 min. (passed). Set VR plug and PT'd to 200- 300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Charted and documented. SI valve and bled off pressure to perform LTT on valve (passed). Rigged down lubricator and installed tapped blind flange. Torqued to API specs. PT'd flange to 2500 psi. for 5 min. (passed) . Job 9/27/2012 complete. T /I /0= 120/110/0 Temp =SI PPPOT-IC (PASS) Post SH Weld PPPOT -IC: Test void has Hokie valve installed. Stung into test void (0+ psi.) Bled void to 0 psi. Pumped through void, good returns. Pressured test void to 3500 psi. Lost 700 psi. in 15 min. Torqued LDS to 600 ft/Ibs. Pressured test void to 3500 psi. for 30 min. 9/27/2012 test. Lost 100 psi. in 15 min. Lost 0 psi. in second 15 min. (PASS). Bled void to 0 psi. T /I /0 = 30/50/3. Temp = SI. IA & OA FLs (Pre MITOA/IA). AL spool piece dropped. Integral installed on IA = inspection not current. IA & OA FLs near surface. 9/30/2012 SV, WV = C. SSV, MV = 0. IA, OA = OTG. 08:00 T /I /0 = 36/61/2. Temp = SI. MIT -OA to 1200 psi- PASSED (Post SH Weld). AL spool disconnected. Integral installed on IA = inspection not current. Pumped 4.8 bbls of diesel to increase OAP from 2 psi to 1200 psi. OAP decreased 44 psi in 1st 15 mins and 16 psi in 2nd 15 mins for a total of 60 psi loss in 30 min test. Bled OAP from 1140 psi to 104 psi in 5 min. (3 bbls). Tags hung on casing valves. Flooring grating removed for subsidence crew to backfill cellar gravel. Job Complete. Final WHPs = 35/65/104. 10/3/2012 SV,WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 1600 hrs. T /I /0 = 35/65/104. Temp = SI . MIT -T to 2500 psi w/ Diesel - XXX. (Eval TxIA comm). Al spool dropped. Integral installed on IA = inspection not current. Used x bbls of xxx to pressure T from 35 psi to 2500 psi. XXP decreased xx psi in 1st 15 min and xx psi in 2nd 15 min. for a total loss of xx psi in 30 min. Bled xxP from xxx to xxx psi in 30 min. (xx bbls). Job Complete. Final WHPs = xxx/xxx /xxx. 10/3/2012 SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP T /I /0 = 320/250/90. Temp =SI. Install Grating in cellar (Post SH Weld). AL spool is dropped. Installed floor grating and removed chain from door. 10/6/2012 SV,WV= Closed. SSV,MV =Open. IA,OA =OTG. NOVP. (1900 hrs) TREE= Mc EVOY GEN 3 • WELLHEAD = MCEVOY sR�tl Y NOTES: """CHROME TBG"" POSSIBLE 7" LNR ACTUATOR = AXELSON 03 DAMAGE (SEE 06/22/11 AWGRS). HOLES IN 5 -112" TBG (PER 10/21/06 CALIPER). KB ELEV = 62' BF ELEV = 7 KOP = 3650' Max Angle = 52° @ 10283' L 2118' J--{5 -1 /2" CA M TRDP SSSV NIP, ID = 4562 Dtum MD = 9768' O zo° coNO — 120 Dtum TVD = 8800' SS GAS LIFT MANDRELS MD D DEV TYPE VLV LATCH PORT ATE 3757 3752 13 OT ' DOME RM 16 10/28/11 13 -3/8" CSG 72#, L -80 BTC, ID = 12 347" —1 2500' 2 6290 59 3 OT SO RM 26 10/28/11 3 7288 6785 31 OT DMY RM 0 09/20/11 4 7883 7298 31 OT DMY T -2 0 01/03/95 5 8474 7807 30 OT DMY T -2 0 10/24/94 1 ^ Minimum ID = 3.725" @ 9208' 6 8781 8077 27 OT DMY T -2 0 10/24/94 4-1/2" OTIS XN NIPPLE 7 8927 8206 29 OT FLWSLV _ T -2 0 07/03/12 9033' H5 PKR SWS LANDING NIP, ID = 4 56" 9054' --iTNV POSITIVE LATCH ASSY, ID = 476" 9055' H9 -5/8" X 5-1/2" TMU HBBP PERM PKR, ID = 4 75" 9080' — 5-1/2' BKR RBP (07 /02/12) 9090' H5 -1/2" PKR SWS LANDING NIP, ID = 4.56" 5 -1/2" TBG 17 #. 13CR - NSCC. H 9118' 0232 bpf, ID = 4 892" r 9106' H5-1/2" HES XN NIP, ID = 4.45" 9118' — {5 - 1 /2 " BKR WLEG(BEVELED) 10 =489" HOLES IN TBG (PER CALIPER 10/21 /06) — 9120' - 917 N „ 9142' — 19 -518" X 5 -1/2" OTIS PKR 1 9149' — 5 - 1/2" X 4 -1/2" X0, ID = 3 958" 5 -1/2" TBG,17 #, L -80 AB -M 0232 bpf, ID = 4 892" H 9149' 9181' I 12' BOT TIEBACK SLV ID = 2 TOP OF 7" LNR H 9181' i • ■ 9193' — 19 -5/8" X 7" BOT SHORTY HYDRA HGR, ID = 2 rt il 9208' _ — 4-1/2" OTIS XN NIP, ID = 3 725" J ' 9208' —14-1/2" PXN PLUG (06/30/12) 4-1/2" TBG. 12 6#. L -80 0152 bpf, ID = 3 958" — 9220' 9219' — 14 -1/2" OT SHEA ROUT SUB 9 -5/8" CSG. 47 #, L -80 BUTT ID = 8 681" —1 9500' 9220' 4-1/2" TBG TAIL, ID = 3 95$" 9194' —1 ELMD TT LOGGED 08/09/85 PERFORATION SUMMARY 9478' —17" MARKER JOINT REF LOG BHCS ON 06/17/84 ANGLE AT TOP PERF 42° @ 9510' 9623' HPOSSIBLE LINER DAMAGE (06/22/11) Note Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9510 - 9640 0 05/05/91 3 -3/8" 4 9678 - 9690 0 10/06/93 3 -3/8" 4 9974 - 9978 0 03/18/95 1 3 -3/8" 8 9978 - 10004 0 03/18/95 9986' — 6 BOWSPRING SPRINGS 3 -3/8" 4 10004 - 10008 0 02/16/93 06' X 50" X 22" ON 05/07/00 ilk 9986' — CC'_, SET TOOL (PUMP) PRESS EXT & PBTD TAGGED 04/27/00 —{ 10000' PULL DISC OAL 15 06' ON 05107!00 WAWA 7" LNR. 29 #, L - 80 BTC 0371 bpf, ID = 6.184" — 1 10283' IWOWO .6.41.4.41.6.6.6.1.4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24184 ORIGINAL COMPLETION 11 /07/11 SET/ PJC GLV 0/0 (10/28/11) WELL 03 -29 10125194 LAST WORKOVER 11/08/11 PJC PERF CORRECTION (ALL OPEN) PERMIT No '1840790 12/19/07 CMC/PJC DRAWING CORRECTIONS 07 /09/12 GJF /JMD SET 5-1/2" & 4 -1/2" PLUGS (06/30 - 07) API No 50-029-21118-00 09/20/08 BSE/SV SET PX PLUG (11/29 /07) 07 /09/12 GJF /JMD HOLES IN TBG (10/21 /06) SEC 11, T1ON, R15E 545' FSL & 71' FWL 06/23/11 WEC/SV LINER DAMAGE (06/22/11) 07 /09/12 BSE/JMD GLV C/0 (07 /03/12) 09/21/11 CDJ/ PJC GLV C/0 (09/20/11) BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 - 6612 December 30, 2011 X11 ?_ 0 Sit Mr. Tom Maunder Alaska Oil and Gas Conservation Commission O 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -03 0 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator Y ..p ^rt >oa.,.,,... + � , }.9:e+nav avmaRlY+' p F!°iawc _. _r - - 4„�r. u+�,• %A.....'^".,^.�Tp` '�v' r s- • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS -03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date ft bbls ft gal 03-01 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03-02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03-03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03-06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03 -07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03 -08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03 -10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03 -11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03 -12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03 -14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03 -15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03 -16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03 -17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03-19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03 -20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03 -21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03 -22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03 -24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/12/2011 13.6 7/17/2011 03 -26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03 -27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03-28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 ---->. 03 -29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 03-338 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03 -34B 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03-35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 03 -37 2091390 50029234210000 2.5 NA 2.5 NA 16.2 8/2/2010 • TEOF ALASKA °' 1VD ALASKA OIL ANDIrS CONSERVATION COMMISSION 1 0 2011 REPORT OF SUNDRY WELL OPERATIONS ammjjgggg 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate i9i88ka Oiltt ' ' ' I'L RNfAN1T Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extens&) + rage Change Approved Program Operat. Shutdown Perforate Re -enter Suspended Well 9 PP 9 ❑ P ❑ ❑ P ❑ 2. Op a o BP er t r Exploration AI k 4. Well Class Before Work: 5. Permit to Drill Number: (Alaska), a), Inc. In c Name: Development 0 Exploratory ❑ - 184 -0790 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21118 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028328 , PBU 03 -29 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10283 feet Plugs (measured) 10000 (FILL) feet true vertical 9195.52 feet Junk (measured) 9986 feet Effective Depth measured 10236 feet Packer (measured) 9055 9142 feet true vertical 9166.58 feet (true vertical) 8316 8389 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32 - 112 32 - 112 Surface 2469' 13 -3/8" 72# L -80 31 - 2500 31 - 2500 4930 2670 Production 9470' 9 -5/8" 47# L -80 30 - 9500 30 - 8669 6870 4760 Liner 1102' 7" 29# L -80 9181 - 10283 8421 - 9196 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# 13Cr80 29 - 9118 29 - 8369 5 -1/2" 17# L -80 9118 - 9149 8369 - 8394 4 -1/2" 12.6# L -80 9149 - 9220 8394 - 8452 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" TIW HBBP Packer 9055 8316 5 -1/2" Otis Packer 9142 8389 12. Stimulation or cement squeeze summary: Intervals treated (measured): r "n Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 82 1,207 14,529 295 Subsequent to operation: 24 0 6,915 258 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El Service p Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ' El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam e Lastufk Title Petrotechnical Data Technologist Signatu e Phone 564 -4091 Date 11/9/2011 0' 'EIDM�7 NOV 1 4 6 // /y /( Form 10-404 Revised 10/201 Submi Original y i ��t/ (! !`I / � 9�nal Onl 03 -29 . 184 -079 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -29 8/9/85 PER 9,572. 9,640. 8,722.09 8,771.23 03 -29 3/28/91 APF 9,510. 9,525. 8,676.66 8,687.71 03 -29 4/29/91 SQZ 9,510. 9,640. 8,676.66 8,771.23 03 -29 5/5/91 APF 9,525. 9,572. 8,687.71 8,722.09 03 -29 5/5/91 RPF 9,510. 9,525. 8,676.66 8,687.71 03 -29 5/5/91 RPF 9,572. 9,640. 8,722.09 8,771.23 03 -29 2/16/93 APF 9,978. 10,008. 9,003.77 9,023.32 03 -29 10/6/93 APF 9,678. 9,690. 8,798.43 8,806.98 03 -29 3/18/95 APF 9,974. 9,978. 9,001.15 9,003.77 03 -29 3/18/95 RPF 9,978. 10,004. 9,003.77 9,020.72 03 -29 4/27/00 FIL 10,000. 10,236. 9,018.12 9,166.58 03 -29 11/29/01 BPS 9,090. 10,000. 8,345.2 9,018.12 03 -29 3/30/11 BPP 9,090. 10,000. 8,345.2 9,018.12 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 03 -29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/12/2011 T /I /O = SSV /230/10. Temp = SI. Remove grating (Pre - Furmanite). AL is 'disconected. IA has integal installed. Removed grating. Installed heater and bled above SSV to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 10/13/2011T/I/O = SSV /230/10. Install clamp on starting head. Furmanite crew installed clamp ;around starting head for trial fit. Placed heater in well house and will return tomorrow to pump teflon sealant. 10/14/2011171/0 = SSV /230/10. Install clamp on starting head. Furmanite crew injected teflon ;sealant into clamp. Injected sealant behind upper rope packing, then lower rope ; packing. Filled void in between packing. Will return tomorrow to pressure up sealant and then MIT -OA. 10/16/2011 T/I/O= SSV/235/11. Temp =SI. MIT -OA to 1200 psi. FAIL (post Furmanite clamp). 'AL spool dropped. IA has integral installed. IA FL @ surface. OA FL near surface. =Pumped 22 bbl to reach test pressure. OAP lost 42 psi in the 1st 15 min and 14 psi in the second 15 min for a total loss of 56 psi. Diesel started leaking around top of clamp. Bled OA to 490 psi. Fumanite crew repacked clamp. Pressured up OA to 1200 psi for 15 min, no signs of leak around clamp. Bled OAP to 25 psi in 20 min. !Final WHPs= SSV/275/25. 'Job complete. SV, WV, SSV =C. MV =O. IA &OA =OTG. NOVP. 10/26/2011 !T /I /0= 700/1250/140. Temp =SI. WHP's (eval leaking Furmanite). ALP = Online. OAP increased 115 psi since 10/16/11. Furmanite clamp appears to have leaked recently, no current activity visible. Cleaned clamp & removed heater trunk from blowing directly on clamp; clamp too hot to touch. ** TP was read from tree gauge, no scaffold gate on Swab platform. SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. 10/27/2011'T/I/O =SSV /190/50. Temp =SI. WHP's (eval Furmanite clamp). ALP =SI @ lateral valve, no IA companion. IAP decreased 1060 psi, OAP decreased 90 psi overnight. ,There is no SC activity currently visible. ** There is no surface containment installed. ISV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 10/28/2011T/I/0= 600/200/50. Temp= SI. WHPs (Eval leaking Furmanite). No IA companion. ALP shut in @ lateral valve. 'SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP. 10/29/2011; T/I/0= 600/190/50. Temp =SI. Install spill containment (SH leak). ALP =Open @ casing valve, SI @ lateral. Installed 37" spill containment on SC. SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. • • i 11/1/2011! T/I/0= 280/1690/330. Temp= Hot. Monitor SH for signs of leak (Eval leaking SH). ` ;AL online w/ no companion. Heater installed in wellhouse. SH has Furmanite clamp I E `installed. Clamp has thick resin /diesel mix 360° on top. Bubbling visible at top of :clamp at 9 o'clock position. There is water in flutes to within 1/2" of top of conductor. Spill containment installed on SC. Cleaned top of clamp for later evaluation. Tree I cap bled to 0 psi. Note: DSO reported that he had just bled OAP from 800 psi to 3001 I !psi because resin was bubbling up around top of clamp and water bubbling up in I flutes. i ;SV =C. WV, SSV & MV =O. IA & OA =OTG. NOVP. I 11/2/2011!T/I/0=260/1553/175. Temp = Hot. OART (eval IA x OA comm). OA FL @ Surface. -, Bled OAP from 175 psi to 50 psi in 2 minutes. Monitor for 1 hour. No change in TP ' or IAP, OAP increased 15 psi to 65 psi during 1 hour monitor. Final WHP's= 260/1553/65. * ** treecap bled to 0 psi due to heater in wellhouse*** !Job Complete. E !SV = C. WV, MV & SSV = O. IA & OA = OTG. NOVP. 11/2/2011 T/I/0= 260/1553/549. Temp = Hot. MIT -OA to 1200 psi PASSED / OART. (Post E :Furmanite Clamp). ALP @ 1660 psi & no companion valve. OA FL @ Surface. !Pressured OAP from 549 psi to 1200 psi w/52 gallons of diesel. OAP lost 22 psi the ; 1st 15 minutes & 4 psi the second 15 minutes for a total Toss of 26 psi. No visible :leaks. Bled OAP from 1174 psi to 93 psi in 10 minutes (88 gallons of fluid returned), :monitor OAP BUR for 1 hour as per WIE. No change in TP or IAP during test or monitor, OAP increased 82 psi during 1 hour monitor. Final WHP's = 260/1553/175. !Job Complete. ' SV = C. WV, MV & SSV = 0 IA & OA = OTG. NOVP r 11/5/2011,T/1/0= 300/1770/830. Temp= Hot. WHPs (Eval leaking SH). ALP= 1660 psi open @ casing valve. No companion valve. TBG pressure increased 40 psi, IAP ;increased 217 psi, & the OAP increased 655 psi since 11/02/11. Slight bubbling noticed @ the 4 -5 & 9 o'clock positions of the Furmanite clamp. Fluid dripping off !clamp @ the 6 o'clock position. iSV= C. WV, SSV, MV= 0. IA, OA= OTG. NOVP. 11/6/2011; T/I/0= 300/1750/930. Temp =138 °. Monitor SH for signs of le (Ev Leaking SH). 1AL online. IAP decreased 20 psi, OAP increased 100 psi overnight. OA is fluid ' packed with clean diesel. Top of the Furmanite Clamp is bubbling @ the 4 - 5 & 8 iO'Clock positions. Collect a sample of diesel dripping from the clamp @ the 6 / !O'clock position, diesel leak is dripping into the conductor @ —1/4 oz of fluid every 5 ; ,/ mins. 'SV =C. WV, SSV, MV =0. IA, OA =OTG. I 11/7/2011:T/I/O= 600/1570/860. Temp= SI. Bleed OA to 100 psi (Secure). AL online w/ no • ;companion. Bubbling visible on top of Furmanite clamp at 8 o'clock position. OA FL ,@ surface. Sucked out —1 gal fluid from conductor. Bled OA from 860 to 100 psi (30 gals diesel) to slop tank in 10 mins. Monitored for 30 mins. OAP unchanged. Bubbling continues. OART tags removed. Job complete. Final WHPs= 600/1570/100. SV & WV =C. SSV & MV =O. IA & OA =OTG. NOVP. FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL . TREE= McEVOY GEN 3 WELLHEAD = MCEVOY SAFETY NOTES: M E TBG*** POSSIBLE 7" LNR ACTUATOR = AXELSON --- 3-29 DAM AGE (SEE 06/22/ AWGRS) 11111) KB. ELEV = 62' BF. ELEV= ? 1 KOP = 3650' Max Angie = 52 @ 10283' I 2118' H 5 -1/2" CAM TRDP SSSV NIP, ID = 4.562" I Datum MD = 9768' 120" CONDUCTOR 120' TV D Datum =- 8800' SS GAS LIFT MANDRELS ST MD T V D D E T Y P E VLV LATCH PORT DATE 13 -318" CSG, 72 #, L -80 BTC, ID = 12.347" H 2500' I—, 1 3757 3752 13 OT DOME RM 16 10/28/11 2 6290 5940 33 OT SO RM 26 10/28/11 3 7288 6785 31 OT DMY RM 0 09/20/11 4 7883 7298 31 OT DMY T -2 0 01/03/95 Minimum ID = 3.725" 9208' 5 8474 7807 30 OT DMY T -2 0 10/24/94 6 8781 8077 27 OT DMY T -2 0 10/24/94 4 -1/2" OTIS XN NIPPLE 7 8927 8206 29 OT DMY T -2 0 10/24/94 1 I 9033' I 1 5 -1/2" PKR SWS LANDING NIP, ID = 4.56" I 9054' I—I TIW POSITIVE LATCH ASSY, ID = 4.76" I 9055' H 9 -5/8" X 5 -1/2" TW HBBP PERM PKR, ID = 4.75" I ►I ►/ 9090' H 5 -1/2" PKR SWS LANDING NIP, ID = 4.56" 9106' 1-15-1/2" HES XN NIP, ID = 4.45" I 5 -1/2" TBG, 17 #, 13CR -80 NSCC, 9118' 9118' I- {5 -1/2" BKR WLEG (BEVELED), ID = 4.89" I .0232 bpf, ID = 4.892" ∎∎. ∎I/ 9142' H 9-518"x5-112" OT PKR I I5 -112" TBG,17 #, L -80 AB -M, .0232 bpf, ID = 4.892" H 9149' 9149' H 5-1/2" X 4-1/2" XO, ID = 3.958" I 9181' H 12' BOT TIEBACK SLV, ID = ? 1 I TOP OF 7" LNR 9 181' ! 9193' H9 -5/8" X 7" BOT SHORTY HYDRA HGR, ID = ? I M 9208' I- 1 41/2" OT XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9220' 1 I 9219' I-I 41 /2" OT SHEAROUT SUB I 9220' _I—I 4-1/2" TBG TAIL, ID = 3.958" I 19 -5/8" CSG, 47 #, L -80 BUTT, ID = 8.681" H 9500' 1 9194' 1-1 ELMD TT LOGGED 08/09/85 I PERFORATION SUMMARY 1 94.7$' H7" MARKER JOINT I REF LOG: BHCS ON 06/17/84 ANGLE AT TOP PERF: 42° @9510' 1 1 9623' J—I POSSIBLE LINER DAMAGE (06/22/11) I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz 1 DATE 1 3 -3/8" 4 9510 - 9640 0 . 05/05/91 3 -3/8" 4 9678 - 9690 0 10/06/93 3 -3/8" 4 9974 - 9978 0 03/18/95 3 -3/8" 8 9978 - 10004 0 03/18/95 3 -3/8" 4 10004 - 10008 0 02/16/93 9986' I 6 BOW5PRING SPRINGS 1 .06" X .50" X 22" ON 05/07/00 ' illy 1 9986' I-- CCL, SET TOOL (PUMP), PRESS OCT & PULL DISC. OAL 15.06' ON 05/07/00 PBTD (TAGGED 04/27/00) . 1-1 10000' i f MAYT ♦N 000.f 4 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" 10283' �r�ri'r #r +r } w 4. #.4.41.1.4 .4.4.+ DATE REV BY COMMENTS DATE REV BY - COMMENTS PRUDHOE BAY UNIT 06/24/84 ORIGINAL COMPLETION 06 /23/11 WEC/SV LINER DAMAGE (06/22/11) WELL: 03 -29 10/25/94 LAST WORKOVER 09 /21/11 CDJ/ PJC GLV C/O (09/20/11) PERMIT No: 1840790 12/13/07 TFA /PJC GLV C/0 11/07/11 SET/ PJC GLV C/O (10/28/11) API No: 50- 029 - 21118 -00 12/19/07 CMC /PJC DRAWING CORRECTIONS 11/08/11 ' PJC PERF CORRECTION (ALL OPEN) SEC 11, T1ON, R15E, 545' FSL & 71' FWL 09/20/08 BSE/SV SET PX PLUG (11/29/07) 04/01/11 SWC /PJC GLV C/0/ PULL PX (03/30 - 31/11) BP Exploration (Alaska) 1 Schlumberger NO. 3748 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay J fc.l ~\:) Well Job# Loa Description Date BL Color CD 06-02 10715379 MEMORY PRODUCTION PROFILE 01/26/04 1 04-06 10672293 INJECTION PROFILE 08/07/03 1 03-31 9153242 PRODUCTION PROFILE 02/05/03 1 ,-,q 03-29 10866560 PRODUCTION PROFILE 07/30/04 1 02-29A 10563072 LDL 06/22/03 1 01-34 10563167 SBHP SURVEY 06/05/03 1 01-25 10889226 LDL 04/07/05 1 01-24A 10772257 SCMT 05/11/04 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ': 't'A¡¡'~~·~.J) \~V- ~:"f. ~,f;,¡o, i g {.DDS .2'~ v 03/27/06 e e Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/30/O3 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 4 00 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 5-168 I q q --[ ~ LDL 09110/03 P2-60 I q ~ -('""~ '\ PROD PROFILE W/DEFT 09/13103 H-26 ~' ,<~:~ -~0'-~'~' PROD PROFILE 09117/03 E-21A ~ ~ ~ SBHP SURVEY 09/16/03 NK-29 ' PROD PROFILE W/DEFT 09~09~03 D.S. 3-29 '~ ~ ~ ~ ~q PROD PROFILE W/DEFT 09/19/03 D.S. 15-18 ~ ~'O(O~ SBHP SURVEY 09/19103 U-08A ~ ~- ~~ SBHP SURVEY 09/20103 W-24., ! ~ ~~ ~ / LDL 09/23/03 D.S. 9-06 ~ ~ I~~ ~ PROD PROFILE W/DEF~ 09~20~03 D.S. 2-088 'lq~ ~'~ 23375 CH EDIT MCNL 05/31103 W-23A~ ' . 23373 OH EDIT LWD IMPULSE DATA 04/30103 W-23A ~~~~ 23373 MD VISION RESISTIVI~ 04/30/03 W-23A ~ -- 23373 ~D VISION RESISTIVI~ 04/30103 ~-23A ~ '23373 MD BOREHOLE PROFILE 04/30103 MPSO~~/' 23435 SCMT 08~09~03 MPS-~8~, ~,~ 10559235 CH EDIT SCMT GR (PDC) 03~03~03 MPS-18/~ ~ ~ 10559235 SCMT 03103103 ~l ~A~ A~ ..... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Camille O. Taylor, ~ ~' Chair DATE: Tom Maunder, P. I, Supervisor John Crisp, SUBJECT: Petroleum Inspector September 13 thru17, 2002 Waivered Wells Put on Production PBU DS 03-29 PBU DS 04-18 PBU DS 04-29 PBU DS 18-21 PBU DS 12-08 September 12, 2002; I traveled to BP's Prudhoe Bay Field to witness waivered wells Put on Production. I witneSsed a number of wells POP in the Eastern Operating area of Prudhoe Bay. No ~ivered~well~ 'were POP in Re Western Operating. area of Prudhoe Bay during O9:t3 thru~ 17,02' that AOGCC Field Inspector was given a. chance to witnessi Ail:wells ~'phad notice of waiVered well sign in the well house. No abnormal pressures~were ~:tnessed. BP Pr°~dures were followed while AOGCC Inspector was Onsite. summary; I witnessed PBU EOA wells POP. A~a,c. hment: none NON-CONFIDENTIAL Waivered Well POP 09-13 thru l 7-02jc.doc MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor State of Alaska ~,~ Alaska Oil and Gas Conservation Commission DATE: January 15, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site'03 January 15, 2001- I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble waS BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-14-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC test report is attached for reference. 21 wellhouses were inspeCted during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15-00jc CC; NON-CONFIDENTIAL . SVS PBU DS 03 1-15-.01jc.doc Alaska Oil and Gas Conservation CommisSion Safety valve System'Test RepOrt Operator: BPX Operator Rep: Mark Womblc AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field DS 03 Separator psi: LPS 185 I-IPS 1/15/01 690 Well Permit Separ Set L~ Test Test Test Date Oii, WAG, amJ, NUmber Number PSI , PSI .Tdp Code Code Code Passed GASorCYCLE 03-01 1750750 185 150 100 P P ' OIL 03-02 1760240 185 150 120' P P OIL 03-03 1760390' 185 150 110 P P OIL 03-04 1760510 · , , , 03-05 1760570 . 03-06 1760600 , 03-07 1760530 03-08 1760730 ' 185' 150 130 P P OIL 03-09 1790220 185~ 150 100 P P OIL 03-10 1790210 · 03-11 1790470 , 03-12 1790580 03-13 1790710 ~ 03-14 1790820 185' 150 100 -.P P OIL 03-15A 1930150 185 150 100 P P OIL 03-16A '1970330 . 03-17 1791020 . 03-18A 1930420 03-19 18'30920 185 150 90 P P OIL 03-20A. 1930470 185 ' 150 100 P P OIL 03-21 1831120 185 150 100 P P OIL , 03-22 1831230 690 600 420 P P OIL , 03-23 1831270 185 150 0 1 P OIL 03-24A 1980060 690 600 530i P P OIL ,,,, 03-25A 1930230 , 03-26 1831510 185 ' 150 I10 P P OIL ,, 03-27 1840620 185 150 100 P P OIL 03-28 1840720 03-29 1840790 185 150 110 P P OIL , 03-30 18408301' 185 150 90 P P OIL ,, 03-31 1840920 185 150 140 P P OIL 03-32A 1940540 185 150i 110 P P OIL 03-33A 1970390 · 03-34B 2000110 185 150 0 1 P OIL 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15-01c.xls Well permit Separ Set L/P Test Test Test Date oi;, WAG, G~, Number Number PSI PSI ' Trip C,,ode Code Code' Passed GAS o,r CYCLE 03-35 1910800 185 150 90 P P OIL 03-36 1930190 · Wells: 21 Components: 42 Failures: 2 Failure Rate: 4.8% Clg0 Remarks: ' '~ °'^' Paoe 2 of 2 SVS PBU DS 03 1-15-01c.xls GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie NO. 9923 Company: 12/12/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Prudhoe Bay Floppy RF Sepia DIR MWD Disk D.S. 3-29~_,~ 2~z(~ PROD LOG 951 1 01 I 1 D.S. 15-5A 77'1~vt.. PRODPRORLE 951103 I 1 D.S. 15-8A /'~ i PROD LOG 951101 I 1 D.S. 15-8A ~ PRODLOG 951101 1 1 D.S. 15-38-' ~ (-/ /~) PROD PROFILE 9511 04 I 1 .... ., Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: RFCEIVED i~aska Oil & G~s Cons. Anchorage STATE OF ALASKA ~ ALALZ'~.-~ OIL AND GAS CONSERVATION _.OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 545' FSL, 71' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2301' FSL, 2290' FEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 2742' FSL, 2658' FEL, Sec. 10, T10N, R15E, UM 12. Present well condition summary Total depth: 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED APR 12 1995 Alaska 0il & Gas Cons. Commission 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-29 9. Permit number/approval number 84-79 10. APl number 50 - 029-21118 11. Field/Pool Prudhoe Bay Oil Pool measured 10283 feet true vertical 9195 feet Plugs(measured) PBTD Tagged @ 10004' MD (3-18-95) Effective depth: measured 10004 feet true vertical 9020 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1875# Poleset 80' 80' Surface 2438' 13-3/8" 2000 sx CS III & 400 sx CS II 2500' 2500' Production 9438' 9-5/8" 500 sx CL 'G' 9500' 8669' Liner 1055' 7" 325 sx CL 'G' 10236' 9166' Perforation depth: measured 9510-9640'; 9678-9690'; 9974-10008' true vertical 8676-8771'; 8798-8807'; 9001-9023' Tubing (size, grade, and measured depth) 5-1/2"; 17# 13CR-80 Tbg @ 9118' MD; 5-1/2", 17#, L-80, PCT @ 9142-9149' MD; 4-1/2", 12.6g, L-80, PCT tail @ 9220' MD. Packers and SSSV (type and measured depth) TIW HBBP Packer @ 9055' MD; 5-1/2" Camco TRDP SSSV @ 2118' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representatiye I~ailv Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 545 1512 8405 551 293 7863 Tubing Pressure 361 356 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Engineering Supervisor Date ~-~. ' 7~~'- Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE cc: KZ, JWP. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 Al'TN: Sherrie NO. 9521 Company: 6/19/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-22 DUAL BURST TDT-P 950603 I 1 D.S. 3-29 PROD PROFILE 950530 I 1 D.S. 3-32A PERF RECORD 950609 I 1 D.S. 4-2A DUAL BURST TDT-P 950529 I 1 D.S. 4-35 PERF RECORD 950529 I 1 "D.S. 6-19 DUAL BURST TDT-P 950530 I 1 ·D.S. 9-3 BRIDGE PLUG RECORD 950531 I 1 .D.S. 9-39 PERFRECORD 950604 I 1 D.S. 9-50 ~PROD PROFILE 950602 I 1 D.S. 12-15 GAS LIFT SURVEY 950606 I 1 D.S. 12-17 GAS LIFT SURVEY 950607 I 1 ~D.S. 14-02B DUAL BURSTTDT-P 950531 'i 1 .' D.S. 15-36 DUAL BURST TDT-P 950602 I 1 D.S. 16-11 MI INJECT PROFILE 950605 1 1 D.S. 15-15 951 82 CNT-D 950509 1 'D.S. 14-33 95170 CNT-D 950427 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. REC£1¥ D DATE: JUN 1 9 1995 Alaska 0il & (~as Cons. Commission Anchorage 3-29 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/1 8/95: MIRU & PT equipment. 30' of perforations as follows: Added perforations: 9974 - 9978' MD (Z2) Reperforated: RIH w/perforating gun & tagged PBTD at 10004' MD, then PU & shot 9978 - 1OO04' MD (Z2) Ref. Log: BHCS 6/17/84. Ref. Log: BHCS 6/17/84. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED APR 3 2 3995 N~ska Oil & Gas Cons. Commission ~ohor~go STATE OF ALASKA ~-.,.: ALASI?'~OIL AND GAS CONSERVATION , '~MMISSION REPOR' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate ~ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 545' FSL, 71' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2301' FSL, 2290' FEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 2742' FSL, 2658' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 62' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-29 RECEIVED APR 1 2 1995 Alaska 0il & Gas Cons. C0mmissl0n ~cflorage feet 9. Permit number/approval number 84-79 10. APl number 50 - 029-21118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10283 feet Plugs(measured) PBTD Tagged @ 10004' MD (3-18-95) true vertical 9195 feet Effective depth: measured 10004 feet true vertical 9020 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1875# Poleset 80' 80' Sudace 2438' 13-3/8" 2000 sx CS III & 400 sx CS II 2500' 2500' Production 9438' 9-5/8" 500 sx CL 'G' 9500' 8669' Liner 1055' 7" 325 sx CL 'G' 10236' 9166' Perforation depth: measured 9510-9640'; 9678-9690'; 9974-10008' true vertical 8676-8771 '; 8798-8807'; 9001-9023' Tubing (size, grade, and measured depth) 5-1/2"; 17# 13CR-80 Tbg @ 9118' MD; 5-1/2", 17#, L-80, PCT @ 9142-9149' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9220' MD. Packers and SSSV (type and measured depth) TIW HBBP Packer @ 9055' MD; 5-1/2" Camco TRDP SSSV @ 2118' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 545 1512 8405 Tubing Pressure 361 Subsequent to operation 551 293 7863 15. Attachments I 16. Status of well classification as: Copies of Logs and SurVeys run I Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 356 Signed -'~/¢vl,~ ~0. Form 10-404¢'1~ev 06/15/88 Title Engineering Supervisor SUBMIT IN DUPLIcATE- ' 3-29 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/1 8/95: MIRU & PT equipment. 30' of perforations as follows: Added perforations: 9974 - 9978' MD (Z2) Reperforated: RIH w/perforating gun & tagged PBTD at 10004' MD, then PU & shot 9978 - 10004' MD (Z2) Ref. Log: BHCS 6/17/84. Ref. Log: BHCS 6/17/84. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED APR 1 2 lg9 ~aska 0il & Gas Cons, Commission ~cfl0rage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9366 Company: 3/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 ~ Field: Prudhoe Bay Floppy .. Well Job # Log Description Date BL RF Sepia DIR MWD Disk 4~I/DW 2-1 STATIC TEMP-INJ PROF 031795 I 1 O.S. 02-13 POGLM SETTING RECORD 031095 I 1 D.S. 03-09 PERFRECORD 031095 I 1 D.S. 3-29 PERFRECORD 031895 I 1 D.S. 4-12 TUBG PUNCHER RECORD 030395 I 1 D.S. 4-38 TUBG CUTTER RECORD 031695 I 1 D.S. 7-18 PROD PRORLE ' 030495 I 1 iD.S. 11-27 BASELINE TEMP 031795 I 1 ID.S. 12-14 ST1 PERFRECORD 030495 I 1 D.S. 12-34 ROPE PERF REC/FLD DET 030795= I 1 D.S. 16-13 PROD PRORLE 030695 I 1 D.S. 16-27 PERFRECORD 031895 I 1 D.S. 1-22A 95049 DUAL BURSTTDT-P 020395 1 D.S. 4-37 95037 CNTD 012095 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: b 1 1995 . - Alaska 0il & Gas Cons. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing x Stimulate Plugging Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 545' NSL, 71' EWL, SEC. 11, TION, R15E At top of productive interval 2301' NSL, 2290' WEL, SEC. 10, TION, R15E At effective depth 5. Type of Well: Development X Exploratory Stratigraphic Service At total depth 2742' NSL, 2658' WEL, SEC. 10, TION, R15E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10283 feet Plugs (measured) 9195 feet 10236 feet Junk (measured) 9166 feet Perforate Other 6. Datum elevation (DF or KB) KBE - 62' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 3-29 9. Permit number/approval number 84-79/conservation order #258 10. APl number 50- 029-21118 11. Field/Pool Prudhoe Bay Field/Oil Pool ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth RECEIVED ~OV 1 6 5-1/2", 13CR80 tubing to 9118' MD ~CflO[; ~ : Packers and SSSV (type and measured depth) 9-5/8" TIW 'HBBP' Packer @ 9055' MD; 5-12", Camco 'TRDP ' SSSV @ 2118' MD feet 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Sicjned Form 10-404 Rev 06/15/88 to the best of my knowledge. Title Drilling Engineer Supervisor Service Date SUBMIT IN DUPLICA1'E BP/AAI SHARED SERVICE WELL: DS 3-29 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 10/09/94 06:00 SPUD: RELEASE: 10/24/94 06:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 10/09/94 ( 1) TD:10236 PB:10236 10/10/94 ( 2) TD:10283 PB:10236 ACCEPT WELL @ 06:00 HRS. MW: 0.0 MOVED RIG F/3-31. SPOTTED & LEVELED. SPOT SEAWATER & SLOP TANKS. BERM TANKS AS REQ. TAKE ON SW & ACCEPT THE WELL @ 06:00 HRS ON 10/9. SETTING STORM PKR. MW: 8.5 Seawater COMP. RU F/W/O. RU LUBR. PULL BPV. RD LUBR. TBG ON SLIGHT VACUUM. BLED OFF 400 PSI F/ANNUL. HELD 5 MIN SFTY MTG ON WORK W/LUBR. CIRC OUT DIESEL F/TBG ANNUL. REV CIRC COMPLETE THRU CHOKE. REASONABLE AMT OF GAS & CRUDE ON BU. MONITOR WELL-STATIC. SET BAKER 5.5" RET BP @24' RT ON 2-7/8" DP. TEST T/1000. SET BPV. ND ADPTR FLNG. XMAS TREE. NU BOP STCK. HELD 5 MIN SFTY MTG. RAN BRIDGE PLUG RET TOOL ON 2-7/8" DP W/SFTY VALVE. ENGAGED BP. 0 PSI UNDER PLUG. RETRIEVE/LD PLUG. FILL HOLE. AIR BREAKING OUT IN BELL NIPPLE. CIRC T/BAL SYST. MONITOR WELL - STATIC. SET BPV THEN CHK. VALVE SUB. TEST BLIND RAMS T/250/2500. TEST WITNESS WAS WAIVED B/AOGCC REP L. GRIMALDI. PULL BPV THRU LUBR. MU LNDG JT. BOLDS. PULLED TBG HNGR LOOSE W/175K. CBU. AIR GAS & OIL EVIDENT ON BU. CIRC REMAINDER THRU CHK. MONITOR WELL. STATIC. WHILE CIRC RU TBG PULLING EQUIP. (OTIS). PULL TBF HNGR T/FLOOR REMOVE. LD SAME. MU 9-5/8" STORM PKR T/5.5" COMP STRING. RIH. SETTING STORM PKR F/PACKOFF CHANGE OUT. HELD 10 MIN SFTY MTG PRIOR T/POOH W/COMP. STRING. RECEIVED !?:"V 1 6 !994 Gas Cons. Commisslort WELL : DS 3-29 OPERATION: RIG : DOYON 16 PAGE: 2 10/11/94 ( 3) TD:10283 PB:10236 10/12/94 ( 4) TD:10283 PB:10236 10/13/94 ( 5) TD:10283 PB:10236 RIH W/O'SHOT & PU 5" DP. MW: 8.5 Seawater COMP. SETTING STORM PKR @27'.RELEASE STAND BACK RT. TEST PKR T/1000. HOLD SFTY MTG. MU PACK OFF RETRIEVING TOOL. RIH ENGAGE PO. BOLDS. PU & WORK PO FREE. POOH RAN & SET NEW PO. TEST T/5000. OK. RECOVERED STORM PKR/COMPLETION STRING. LD PKR. CONT'D POOH LD 5.5" COMPLETION STRING T/CHEM CUT. RECOVERED ALL TUBULARS & COMPLETION COMPONENTS T/CHEM CUT @9087. (217 JTS OF 5.5" TBG, SSSV; 10 GLM'S; 18.7' OF 5.5" TBG CUTOFF SECTION.) TBG WAS CORRODED ON THE ID. SUBTANTIALLY WORSE CORROSION W/DEPTH WAS EVIDENT. PINS WERE CORRODED THE SAME. RD TBG EQUIP. CLEAN UP. RAN TEST PLUG. TESTED BTTM PIPE RAMS T/250/5000. RECOVERED TEST PLUG. RAN WEAR BUSHING. PU 8-1/8" OS W/5.5" GRAPPLE. MU BHA & RIH PU 5" DP. POOH W/SHORT CATCH O'SHOT MW: 8.5 Seawater CON'T RIH PU DP. MU KELLY. WASH DOWN T/TOF @ 9070. ENGAGE FISH. PU 50K O/P T/FREE FISH. HELD 10 MIN SFTY MTG. CBU GAS & OIL WERE EVIDENT ON RETURNS THRU CHOKE. POOH W/O'SHOT. RECOVER 5.5" TBG CUT OFF SECTION, PUP JT; & SBR. XO F/BTTM SBR T/4.5" PUP JT. PIN PULLED OUT OF BOX ON XO. FISH LEFT IN HOLE= 4.5" PUP JT W/PIN UP. RET PKR; 4.5" TAILPIPE ASSY. TOP OF FISH @9122. LD THE RECOVERED FISH. MU OS W/4.5" GRAPPLE. MU BHA & RIH T/9092. MU KELLY & WASH DOWN T/TOP OF FISH -DPM- ENGAGE FISH. PU 3000# O'PULL/FISH CAME LOOSE. SUSPECT 4.5" PJ PULLED OUT OF COLLAR ON TOP OF PKR. CBU & HOLD 10 MIN SFTY MTG. POOH W/O'SHOT. NO RECOVERY. GRAPPLE SHOWED TUBULAR MAKINGS. MU SHORT CATCH O/S W/5.125" GRAPPLE. RIH T/8327. SLIP & CUT DL. CON'T T/RIH T/TOF. MU KELLY. COULDN'T RIH T/TOF. MU KELLY. COULDN'T ENGAGE FISH. MONITOR WELL. OK. POOH W/O'SHOT. JARRING ON PKR MW: 8.5 Seawater COMP POOH W/SHORT CATCH O/S. NO RECOVERY OR MARKINGS ON O/S. GRAPPLE. LD OS. HELD 5 MIN. SFTY MTG. PU 8.5" BURN SHOE, EXTENSION. RIH T/9097. MU KELLY. WASH DN T/9122. ROTATE DN 9122-9123. SOLID @ 9123. CBU. POOH W/B'SHOE ASSY. PU 8-1/8" SHORT CATCH O/S W/5.5" GRAPPLE. MU BHA. RIH T/9099. MU KELLY. WASH DN T/9023. ENGAGE FISH. TOP SUB ON PKR. PU T/310K (90K O'PULL) PKR STRAIGHT PULL RELEASE. PINNED @ 70K. POOH W/PKR 1.5'. COULDN'T GO FURTHER. JARRED UP/DN ON PKR, PRESS ON TOP. NO GO. TRY T/RELEASE O/S F/FISH. WOULDN'T. COULDN'T ROTATE T/RIGHT. CONT'D JAR'G. NO GO. PRESS ON ANNUL--NO GO. CON'T JARRING ON PKR. RECEIVED A~s'ka UAl & Gas Cons. Commission WELL : DS 3-29 OPE{RATION: RIG : DOYON 16 PAGE: 3 10/14/94 (6) TD:10283 PB:10236 10/15/94 ( 7) TD:10283 PB:10236 10/16/94 (8) TD:10283 PB:10236 POOH W/E-LINE MW: 8.5 Seawater CON'T JARRING UP ON PKR. FIRING JARS @350K, 130K O/P. PU AFTER JARRING T/MAX OF 400K. WORKED STRING UP/DN. W/RIGHT HAND TRQ IN PLUS PRESS ANNUL WHILE HOLD MAX PU WT OR SLACKED POSITION. NO GO. HELD SFTY MTG. RU SCHLMBRGR. RAN CHISEL WL JARS, CCL TOOL STRING IN HOLE. ON MONO LINE. T/TOP OF SAND PLUG @9375. LOGGED THRU BHA T/END OF TAIL PIPE. POOH W/TOOL STRING. MU 350 GR. S'SHOT, CCL STRING & RIH T/708. WORKED IN LH TRQ. FIRED SHOT. BO @ COLLAR @708. POOH W/E-LINE. RACKED BACK KELLY. PU JT DP. SCREW BACK INTO COLLAR @708. TRQ STRING. MU TIW VALVE, WL STRIP'G HD T/DP. RIH W/CCL.& 700 GR. S'SHOT. LAY SHOT ACROSS PKR 9132 T/9137(WLM) PU STRING T/350K. FIRE. NO GO. S/O O/P. POOH W/E-LINE. JAR ON PKR W/MAX PU WT WHILE PREPARING B/O S'SHOT. NO PKR MOVEMENT. RIH W/CCL, 350 GR. B/O S'SHOT & LAY ACROSS TOP OF COLLAR O'SHOT 9129 T/9134(WLM). WORK 9 ROUNDS LH TRQ INTO STRING FIRE. NO GO. POOH W/E-LINE. RIH W/CCL, 700 GR. S'SHOT LAY ARCROSS TOP SUB O/S ON PKR. WHILE WORKING 10TH ROUND LH TRQ INTO STRING IT BACKED OFF. POOH W/ELINE. S'SHOT/CCL. SCHLUMBERGER CONFIRMED THEIR STRING INTACT. HELD 10 MIN SFTY MTG ON EXPLOSIVES. POH W/BURNING SHOE MW: 8.5 Seawater COMPLETED POH W/E-LINE. ON TRIP OUT NOTED STRING BACKED OUT AT 780'. SCREWED BACK INTO STRING. TORQUED UP. RIH W/700 GRAIN STRING SHOT, CCL TO TOP OF 4-1/2" TBG PUP JT AT 9119' COULD NOT GET INSIDE TBG. STRING SHOT OVER INT 9121-~116', COVERING 2 CONNECTIONS: TOP SUB O/S EXT, O/S EXT-XO BUSHING. WORKED LH TORQUE. SHOT STRING WHOT. HAD INDICATION BACKED OFF DEEP. POH W/E-LINE. R/D. CIRC B/U. SLIPPED AND CUT DRL LINE. POH W/FISHING STRING. FOUND STRING BACKED-OFF AT BUMPER SUB. O/S ASSY LEFT INHOLE - TOP SUB, O/S EXT, XO BUSHING, O/S BOWL. L/D BS, JARS. P/U BHA. M/U 8-1/2" X 6-1/2" BURN SHOE ASSY. RIH TO 9094'. M/U KELLY. WASHED DN TO TOP OF TOP SUB. MILLED 9112-'9113.5'. PUMPED HI VIS SWEEP. CIRC OUT. POH W/BURN SHOE TO P/u O/S. RIH W/3-1/2" MILL MW: 8.5 Seawater COMPLETED POH W/BURN SHOE ASSY. RECOVERED 15 LB METAL/SCALE FROM BOOT BASKETS. P/U OVERSHOT 2/6-3/8" GRAPPLE. M/U BHA W/ACCELERATOR. RIH TO 9095'. M/U KELLY. WASHED DOWN TO TOF AT 9110'. REVERSE CIRC HOLE CLEAN. LOWERED STRING TO 9112. ENGAGED FISH. MONITORED WELL - STATIC. POH W/L/S. RECOVERED TOP SUB FROM ORIGINAL O/S ASSY - 100% REC. L/D FISH, O/S, ACCELERATOR. WELL : DS 3-29 OPE~RATI ON: RIG : DOYON 16 PAGE: 4 10/17/94 ( 9) TD:10283 PB:10236 10/18/94 (10) TD:10283 PB:10236 10/19/94 (11) TD:10283 PB:10236 TESTING BOPE MW: 8.5 Seawater COMPLETED RIH W/3-1/2" MILL TO 9102'. M/U KELLY. WASHED DOWN TO TOP OF O/S EXT AT 9112'. WORKED MILL INSIDE. WASHED DOWN TO TOP OF PKR AT 9117'. DRESSED OFF TOP SUB ON PKR. CONT'D WASHING DOWN/ROTATING THRU 4-1/2" TAILPIPE ASSY TO 9205' - 10' OUT OF END OF TAILPIPE AT 9195' (DPM). CIRC B/U. MONITORED WELL - STATIC. POH W/MILL. L/D MILL, 3-1/8" DC, 3-1/2" DP. P/U 9-5/8" CSG SCRAPPER, 8-1/2" RR BIT. M/U BHA. RIH TO 9090' REV CIRC WELL OVER TO INHIBITED SEAWATER. MONITORED WELL-STATIC. SLIPPED AND CUT DRILL LINE. POH W/BIT AND SCRAPPER. L/D SAME. PULLED WEAR BUSHING. WOULD NOT PASS THRU WORN HYDRIL ELEMENT. CHANGED OUT HYDRIL ELEMENT. PULLED WEAR BUSHING. RAN TEST PLUG. TESTED BOPE. RUNNING 5.5" COMPLETION STRING MW: 8.5 Seawater COMPLETED TESTING BOPE AS PER PROGRAM. RERAN WEAR BUSHING. P/U 9-5/8" RTTS. RIH ON 5" DP TO 9080'. SET RTTS TEST PKR AT 9080'. TESTED CSG AGAINST PIPE RAMS TO 3500 PSI FOR 30 MIN - GOOD TEST, PRESS BLED OFF 25 PSI OVER PERIOD. RELEASED PKR. ALLOWED ELEMENTS TO RELAX. MONITORED WELL - STATIC. POH W/RTTS PKR LD 5" DP. L/D PKR. R/U TO RUN 5.5" 13CR80 COMPLETION STRING. PULLED WEAR BUSHING. RAN COMPLETION STRING AS PER PROGRAM. AT REPORT TIME HAVE 11 JTS TBG. TBG TO RUN PRIOR TO REACHING SSSV. RUNNING MOD BOW SPRING WL TOOL MW: 8.5 Seawater CONT'D RIH 5.5" CR80 COMPLETION STRING TO SSSV. M/U CAMCO TRDP SV. INSTALLED CONTROL LINE. TESTED TO 5000 PSI. CONT'D RIH COMPLETION STRING. TAGGED TOP OF EXISTING PKR AT 9117'. SPACED OUT FOR WLEG TO BE AT 9116'. M/U HGR, CONTROL LINE. TESTED CONTROL LINE CONNECTIONS TO 5000 PSI. M/U LANDING JT. LANDED HGR IN TBG SPOOL. R/D TBG RUNNING EQUIP. RILDS. H/U CONTROL LINE. PRESS TO 5000 PSI TO OPEN SSSV. L/D LANDING JT. R/U LUBRICATOR. R/U HES SLICKLINE. MADE GAUGE RUN W/3.5" CENTRALIZER. COULD NOT PASS TOP OF EXISTING PKR. RAN 3.48" IB. SHOWED PIPE/COLLAR OD PROFILE CENTERED ON BLOCK BOLDS. PULLED HGR TO FLOOR. L/D HGR. CHECKED SPACE OUT - OK. R/U STUFFING BOX TO TBG STRING. RAN 3.5", 3.2", 3.0" CENTRALIZERS - COULD NOT PASS TOP OF EXISTING PKR. RAN VARIOUS TOOL STRING CONFIGURATIONS W/TBG 5' THEN 35' ABOVE EXISTING PKR. ON FINAL RUN W/FOLLOWING TOOL STRING MADE INTO PKR: KNUCKLE JT, 1-7/8" X 1' WEIGHT BAR, ADJUSTABLE BOW SPRING CENT, 3" TAPERED SWADGE, JARS. ON FIRST RUN IT WENT INTO PKR WITH NO PROBLEM. IT WAS RUN OUT OF THE TAILPIPE TO 9270'. HAD HES P/U TO 100' ABOVE EXISTING PKR AND RERUN. ON THIS ATTEMPT IT TOOK SEVERAL TRIES TO ENTER BUT IT DID ENTER. POH W/TOOL STRING. WELL : DS 3-29 OPE~RATION: RIG : DOYON 16 PAGE: 5 10/20/94 (12) TD:10283 PB:10236 10/21/94 (13) TD:10283 PB:10236 10/22/94 (14) TD:10283 PB:10236 PULL & LD 5.5" COMP STRING MW: 8.5 Seawater RAN 3" SWEDGE TO 9270' TAG TOP OF OLD PKR. R/D HALIB WIRELINE. RU W/1 JT 5.5" TBG. RUN IN & TAG TOP OF OLD PKR. R/U & PUMP 2 TBG VOLUMES 440 BBLS. FILTERED SEAWATER. R/U HALIB. DOWN HOLE VIDIO. TRIP IN GOOD PICTURE TO SN @ 9103' RUN IN TO 9118' POOR PICTURE. OBSTRUCTION SEEMS TO BE LOOSE PIECE OF METAL. TRIP OUT F/CAMERA CHG & PUMP IN SUB. RU PUMP IN SUB. CHG. CAMERA. TRIP IN TO 9116' ENTRY GUIDE CIRC. TO CLEAR PICTURE. MOVE DOWN HOLE. GOOD PICTURE OF ENTRY TO TOP SUB ON PKR. SLIVER OF LOOSE METAL IN HOLE & OBSTRUCTION APPROX. 1' ABOVE ENTRY TO TOP SUB. PICTURE OF THIS UNCLEAR. POH RIG DOWN OTIS PUMP IS ASSY. ATTEMPT TO LOWER PIPE IN OVERSHOT EXTENTION WOULD NOT GO. RIG DOWN OTIS. RIG UP TO PULL COMPLETION STRING. (5 MIN SAFETY MEETING). CIRC @ 9080' & PREPARE TO REV MW: 8.5 Seawater PULL & L/D 5.5" COMPLETION STRING. L/D TO SSSV. LOST 8-STAINLESS STEEL BANDS OFF CONTROL LINE. RD OTIS. L/D 5.5" COMPLETION STRING. R/D TBG TONGS. LOAD PIPE SHED & SET WEAR RING. M/U 6-5/8" REVERSING BASKET ASSY & P/U 5" DP TO 9080'. P/U KELLEY & REVERSE CIRC DOWN TO TOP SUB ON OLD PKR. W/REVERSE CIRC. BASKET. TOOH W/MILL MW: 8.5 Seawater HANDED OUT 4 STOP CARDS. HELD SFTY MTGS. REV CIRC DN T/OS EXT. TOP @9112. WORK INSIDE EXT & REV CIRC. T/9116. TOP OF OLD PKR. REV CBU. WORK BSKT. TOOH T/CHK BSKT & PU MILLING ASSY. EMPTY REV BSKT & RECOVER 2-PCS OF RUBBER & ONE COMP. SS BAND. LD BSKT & PU TAPERED MILL ASSY. TIH W/ASSY. PU KELLY & BREAK CIRC. TAG TOP EXT @9112, DRESS TOP ON PKR W/MILL. CBU. TOOH LD 4 6.25" DC'S. & MILLING ASSY. EMPTY BOOT BSKTS. RECOVER 1 BAND & 4 LBS OF JUNKS. PU 3.556" MILL & 3-1/8" DC. & TIH. SLIP & CUT DL. RUN MILL THRU PKR & TAIL PIPE. TAG EXT @9112 & TOP OF EXISTING PKR. @9117. CBU. SET BACK KELLY & DROP 3.25" DRIFT W/SLICK LINE TATTLE TAIL. TOOH W/3.25". DRIFT WOULD NOT GO THROUGH. 2 JTS OUT OF 7 PULLED WERE OFF GRADE G-105 5" 19.50# DP. PIN END CHG T/3" DRIFT. TOOH. WELL : DS 3-29 OPERATION: RIG : DOYON 16 PAGE: 6 10/23/94 (15) TD:10283 PB:10236 10/24/94 (16) TD:10283 PB:10236 10/25/94 (17) TD:10283 PB:10236 RUNNING COMPLETION MW: 8.5 Seawater HANDED OUT 3 STOP CARDS. HELD SFTY MTGS. TOOH DROP 3" DRIFT THRU 5" DP. LD 3-1/8" DC'S & 3.556" MILL. PU TAIL PIPE ASSY ON 5" DP. TIH T9112. RU HES SL UNIT & TIH T/9130. REV CBU. RU LUBR. & HALIB. SL. TIH W/SL T/9140. PULLED BACK THRU PKR. HUNG UP-WORK THRU. RUN IN. PULLED BACK. HUNG AGAIN - WORK THRU RAN THRU SAME PLACE SEVERAL TIMES W/NO PROBLEM. POOH RD SL UNIT. REV. CBU POOH LD 5" DP, & TAIL ASSY. PULL WEAR RING. RU T/RUN 5.5" 13 CR80 COMPLETION STRING. NU ADPTR & TREE MW: 8.5 Seawater 6 STOP CARDS HANDED OUT. HELD SFTY MTG. RUN 5.5" 17# 13 CR 80 COMP STRING. RU HES CONNECT CONTROL LINE T/SSSV. & TEST T/5000. CON'T RUNNING COMP. STRING. KEEP 5000# ON CL. SPACE OUT. LAND TBG. RILDS. HOOK UP CL. RU HES. SLICK LINE W/3.275" DRIFT. RIH W/SL STOPPED @9130'. WLM. TOP OF 4.5". RIH W/3.5" DUMMY GUN RUN T/9200. OK. RIH W/RHC PLUG & SET IN XN NIPPLE. RD WL. LD CASG TOOLS & SET BPV. ND BOPE. NU ADAPTER & TREE. RIG RELEASED MW: 8.5 Seawater HANDED OUT 2 STOP CARDS. HELD SFTY MTG. PREPARE RIG F/MOVE. NU TREE, TEST ADPTR FLNG T/5000. INSTL TEST PLUG. TEST TREE T/5000. REMOVE TEST PLUG. INHIBIT WELL FLUID W/COREEXIT@ 4BPM. DROP BALL/PRESS UP ON TBG T/4000. SET PKR. PRES BLED T/3500 IN 5 MIN NO SURFACE OR ANNUL LEAKS. BLED OFF PRESS. CHK ALL SURFACE EQUIP. PRESS TBG T/3500 BLEED OFF. 500 PSI F/5 MIN. NO LEAK ON ANNUL OR SURF. EQUIP. HOLD 2000 PSI ON TBG PRESS ANNUL T/3500/30 MIN. OK. BLEED OFF PRESS. PRESS ANNUL T/2900 SHEAR RP. PUMP 5620 GALLON DIESEL T/ANNUL & U-TUBE T/TBG. INSTALL BPV. SECURE WELL & MOVE OFF. RIG RELEASED @ 18:00 HRS ON 10/24/94. SIGNATURE: (drilling superintendent) DATE: GeoQuest 600 W. International Aiq:~orl Road Anohorage, AK 99518-1199 ATTN: ,She~e NO. 9023 10/21/94 Company: Alaska Oil & Ga~ Cons Oomm , Atln: Larry Grant I 3001 Porcupine Dflve Anohorage, AK 99501 Field: Prudhoe Bay Well Log Deeoription 'BL RR Sepia RF Sepia Mylar D.S. 02.31 , LEAK DEIECTION (10-16-94) 1 1 iD.S. 03-21 ~,'~ '-//Z.-- TUBG CUTTER RECORD (10-15-94) 1 1 D.S. 03-29 ~' ~_-"~'~ BACK-OFF SHOT RECORD & JEWELRY LOG (110-13.94) 1 1 'D.S. 4-SA Y-'~'~ -J"/~ PERF RECORD(10-14-94) 1 1 D.S. 4-29 ~ ~ ? ~ ~ PERF RECORD (11012-94) I 1 D.S. 4-29 ~ ,,/. ~. ' ~,-,'~ :GCT (10-15.94) 1 1 D.S. 9-26~,/~ 3 7 AVA POGLM SETilNG RECORD (10-16-94) 1 I D.S. 9-26 u I ~-- ALPHA soFT SET PATCH RECORD (10-15-94) 1 ! D.S. 16-19 ~'"~..--/:2~,~' PROD LOG & GAS LIFT SURVEY (10-12-94) 1 1 D.S. 15-38 ~ ~--~0 ~ STATIC PRESSURE SURVEY & PRIMARY DEPTH CONTROL (10-15-94) 1 1 D.S. 16-28 ~' ~ -' ~ ~ PROD PROFILE (10-13-94) , 1 1 .OCi 1994 /IJaska Oil & Gas Cons. C0mmissi0~l SlG ~~gn red. mol ~///~ _.. · A.ch0rage ' PI and copy of ~is transmiffal to Sherle ~ the above addre~. ~ank you. DATE: MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johns~ Chairman~-~r Blair Wondzell, ~,-~- ' P. I. SUpervisor FROM: Bobby Foste~'~~ SUBJECT: Petroleum Inspector DATE: October 17, 1994 FILE NO: AFIIJQBD.doc BOPE Test - Doyon 16 ARCO - PBU - DS3-29 PTD # 84-0079 Prudhoe Bay Field Monday, October 17, !994: I traveled this date to ARCO's DS3-29 being worked over by Doyon rig 16 and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows there were 2 failures of the equipment. The full opening floor safety valve leaked and 1 of the 3 air pumps on the accumulator would not work. Both of these items are to be repaired and I will be notified with-in 24 hours.. The location was clean and there was good access to all areas of the rig. The rig was clean and all of the equipment seemed to be in good working order. Summary: I witnessed the BOPE test on Doyon rig 16 - test time 2.5 hour~- 2 failures. " Attachment: AFIlJQBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Ddg Contractor: Operator: Well Name: Casing Size: 7 5/8 Test: Initial X Workover: X DOYON Rig No. 16 PTD # ARCO Rep.: DS f6-23 Rig Rep.: Set {~ 9,398 Location: Sec. Weekly Other DATE: 10/16/94 84-0079 Rig Ph 659-46fO/461f BRUCE CAMPBELL WA YNE S TO TTS I f T. fON R. fSE Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: 'OK' (Gen) Reserve Pit N lA Well Sign OK Drl. Rig. OK.'. BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower ~Pipe Rams r 1 Blind Rams I Choke Ln. Valves 1 HCR Valves Kill Une Valves 1 Check ValVe N/A ,, , Test :Pressure P/F 300/3,000 P 500/5,000 500/5,000 P P P P P P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YE~ Flow Indicator ' 'YEg YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 Pressure P/F 500/5000 P 500/5000 P ' 500/5,000 P CHOKE MANIFOLD: No. Valves f4 No. Flanges ,35 Manual Chokes 1 Hydraulic Chokes 1 , , Test Pressure Functioned Func~oned PIF ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btrs: 6 ~. 2200 3,050 I P f,550 P minutes 3f sec. minutes 58 sec. YES Remote: YES Psig. :Number of Failures: 2 ,TestTime: 2.5 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned 'by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failure: I of the 3 .air PUmps would not work- to be repaired and the inspector notified. The floor safe~ valve leaked - to be repaired, tested and the inspector no,lied. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED?" YES X NO 24 HOUR NOTICE GIVEN YES X NO ,, I I Waived By: W~nessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) AFIlJQBD.XLS Drill Site: 3 Well: 29 Fri Aug 26 13:10:34 1994 K-VALVE DESIGN DOME SET PRESSURE: 380 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 295 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: Redesign~of KVLV due to dumping problems of current Well operating pressure has dropped to 270 psi, so clesure pressure has been reduced. This may require well 'to bechoked~'back. ",To. test,..open choke apd~or dum~ CC: ENGINEERING FILE / COORDINATOR PRB 24 '- (WITH:.ATTACHMENTS.) · i ~. . . ..- . . J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT "ATTACHMENTS ) ~ R.A. WELLS / K.L. BLACKBURN PRB 14 ( COVER ONLY) ...... .~ .} .. T.W. CAHALANE ATO 1586 ( WITHOUT .ATTACHMENTS ) STATE 'OF,:AL.-~~: (~COVER ~O~Y) DESIGNED BY: R. T. Burno Drill Site: 3 Well: 29 Tue May 31 13:09~18 1994 K-VALVE DESIGN DOME SET PRESSURE: 380 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 305 PSIG K-VALVE CLASS (A,B,C): A .. COMMENTS-. Redesigned to allow testing of k-valve in the well.(~ The well will have to be choked back during normal' operation. To aid in dumping, the well could be sw~e~ to the lower pressure of the LP CL's. CC: ENGINEERIN~ FILE / COORD'IRATOR~RB24 (WITH ATTACHMENTS) - :, -'. J.C. SMART / M.~. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) R.A. WELLS / K.L. BLACKBURN PRB 14 (COVER ONLY) Drill Site: 3 Well: 29 K-VALVE DES I GN SSSV DEPTH ( MEAS ): 2162 FTP @ CLOSE (PSIG): 305 PRESS ADJUSTMENT: T,W. CAHALANE ATO 1586 (WITHOUT ATTACHMENTS ) NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK ~L~R FTP OIL %WTR 87 3003 362 583 92.9 3148 CONDITIONS AT CLOSURE: 87 3003 305 614 92.9 3148 WELL TEST TEMPERATURE @ SSSV: 174 PRESSURE @ SSSV: 677 GOR ~GLR LIQ PWF .586 8255 2542 SEP COML PI TEMP PRES DATE SEL 7.38 151 0 03/16/94 Y 567 8702 2466 7 . 38 151 @CLOSE 176 614 DOME SET PRESSURE: 38O PRIOR DESIGNS: DATE: 09/25/93 06/02/93 11/01/92 SET PRESSURE 290 FTP @ CLOSURE: 230 290 155 295 190 TEMP: LINEAR LINEAR LINEAR ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; FS=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= . . 81358e-2 N= 1. 000000 NEW C= . . 18773e-2 ENTERED N= 1. 000000 Drill Site: 3 Well: 29 K-VALVE DESIGN Sat Jan 22 11:15:12 1994 D~4E SET PRESSURE: 390 PSIG @ 60 DEG F FTP @ CLOSE (PSiG): 303 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: Redesigned to allow' testing of k-valve in well. This will require the well be choked back to keep from dumping. To aid in dumping, the LGR can be raised up, and if ok, open the drain system also. CC: ENGINEERING FILE / COO~INATOR PR 24 (WITH ATTAC~.~NTS) J.C. S~aART / M.G. SHOEFaAKE P~ 20 (WITHOUT A~AC~.~S) R.A. ~LLS / K.L. BLAC~URN P~ 14 (COVER ONLY) T.W. CAHALANE ATO 1586 (WITHOUT ATTACFR4ENTS ) STATE OF AI~SKA (COVER ONLY ) DESIGNED BY: MM~4 Drill Site: 3 Well: 29 CE LGR FTP OIL %WTR 87 3003 304 87 3004 313 87 3029 315 87 3000 320 87 3004 316 87 2965 322 87 2943 333 87 2598 313 87 2966 315 87 3004 321 87 3002 324 WELL TEST DATA GOR GLR LIQ 619 93.4 3246 747 91.8 3751 759 91.7 3743 767 91.6 3709 767 91.6 3803 746 91.7 3007 774 91.8 3594 683 91.7 3533 818 91.3 3164 854 91.2 3216 856 91.4 3078 87 3009 330 ,741 91.8 3313 Sat Jan 22 11:15:15 i994 PW~ PI SEPARATOR DATE SEL TEMP PRES 533 9390 2534 8.34 155 251 01/13/94 Y 629 9217 0 0.00 153 233 12/19/93 639 9178 0 0.00 154 240 12/14./93 638 9155 0 0.00 154 246 12/09/93 644 9194 2340 0.00 154 244 12/06/93 575 9050 605 9458 605 8274 585 9490 591 9721 56O 10050 600 91'01 0 0.00 153 251 12/04/93 0 0.00 155 264 11/22/93 0 0.00 155 251 11/18/93 0 0.00 154 251 11/15/93 0 0.00 155 262 11/08/93 0 0.00 156 268 11/07/93 0 0.00 156 269 11/01/93 ESC=EXIT; Fl=HELP; F3=DESiGN; F4=DISTRiBUTiON LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEP~ (MEAS): 2162 FTP @ CLOSE (PSIG): 303 PRESS ADJUSTMENT: I TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEF~, PI PROF USES BH TEMP AND WELL PI WPS C= 3.266944 N= 0.500000 NEW C= 3.557552 ENTERED N= 0.500000 ARCO Alaska, Inc. Date: May 24, 1994 P.O. Box 100360, .~ ~orage, AK Transmittal #: 94040 99510~ ~ Subject: From/Location: Telephone: To/Location: ,;/% ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 5-14-94 5-7-94 5-11-94 5-11-94 5-7-94 5-7-94 5-8-94 4-30-94 5-13-94 4-4-94 i 5-3-94 i Well iLog Date1 Number (M-D-Y) , OWDW- 4-29-94 SW 1-9A 1-20 2-4 2-4 2-5 2-5 2-18 2-20 2-20 3-19 3-29 3-32A 5-9-94 & 3-32A 5-12-94 Perf Rec 4-5A j 5-17-944 v/ PerfRec 4-5A 5-17-94 USIT 5-6 4-30-94 Prod Prof 5-35 5-3-94 TDT-P 6-10 4-5-94 Leak Detect 6-11 5-14-94 ',-Packer Set Rec 6-22A 5-14-94 Perf Rec 7-3 5-8-94 Prod Prof 7-3 5-7-04 Perf Rec 7-23 5-10-94 Set Rec 7-23 5-15-94 Rec 9-13 5-16-94 9-26 4-6-94 Perf Rec. 9-42 5-15-94 Leak Detect 9-47 5-16-94 Packer Set Rec 11-36 5-18-94 USIT 12-8B 5-4-94 ,/' Prod Prof 13-8 5-2-94 Pmf 13-31 5-2-94 v/ USIT 13-35 14-7 14-15 14-41' 16-26 17-19 18-1 ARCO Alaska, Inc. Is a l~b~ldla~y o! AtlantlcFIlchfleldCompany Tool Type v// PITS Rec Perf Rec v~ Prod Prof CNL ,~ Prod Prof CNL Prod Prof Prof CNL 5-10-94 USIT I 5-13-94 Patch Rec 5-17-94 CNL 5-8-94 Burst TDT-P 5-6-94 ~ PerfRec 5-12-94 Perf Rec 5-16-94 v~ PerfRec Run, Scale 1, 5" 1, 5" ! 5II 1 5" 1 5" 1 5" 1 5" I 5" I 5" 1 5" 1 5" 1, 5" 1, 5" 1, 1" 2" 5" 1,1" 5" 1,5" 1, 5" 1 511 1 5" 1, 5" ! 5II 1,5" 1,5" 1,5" t,c~ t~ SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH i SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH $CH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH I SCH SCH SCH 5cH- ARCO Alaska, inc. Date: Subject: Fro m/Lo cat ion' Telephone: To/Location: May 10, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution P.O. Box 100360, Anchorage, AK Transmittal #: 94037 99510~ ~ R'F-c"EI'VED 0il& Gas Cons. Anchorage Number (M-D-Y) __{_~~ OWDW-i 04-30-94i Pump-JnTemp (:~- 2~q 0 NW f Pump-in Temp c~- 2.:~cl --. S E ; -'¢o-%t~----------~ 1-4 I 04-20-94I f TDT-P -¢~-cc[---------~ 1-i7 ~ 04-07-94~ f TDT-P ~ 2.-1'57_ ~ 1-24A i 04-08-94I -- Perf Record i 04-16-94 i" Perf Record 2-18 2-19 2-25 2-34 2-35 3-17 3-17 3-21 3-29 4-33 4-44 ~ 4-44 j 4-45 4-45 4-46 5-10 5-15A, 5- 5A 5-35 6-6 6-14 6-14A 6-22A 04-17-94 !~ Prod Profile 04-18-94 l/ Bridge Plug 04-19-94 i"' Prod Log 04-12-94 t~" Prod Profile 04-27-94 i/Iniection Profile 04-19-94 l/ Peff Record 04-20-94i ,-' Perf Record i.04-14'94 1.~ Leak Detect 04-29-94 i~lnjection Profile 04-12-94 1~ USIT 04-14-941 ~ TDT-P Run, 5" 1,5" 1,5" Contractor i Sch Sob i Sch Sch Sch i '1, 5" Sch { 1, 5" Sch j 1, 5" i 1,5" 1' &2 &5 I 1,5" ~ 1,5" $ch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch ! 07-23 07-23 7-24 i 7-24 '~5-~L~ , 9-1 ~, 9-9 ~-~E) 9-19 04-14-94 ~" CNTG 04-24-94 / CNTG ~ TDT-P 04-22-94 ~' Perf Record 04-13-94 Leak Detect 04-25-94 ~ CTU Prod 04-26-94 / TDT-P 04-16-94 ~' Leak Detect 04-17-94 Com 04-08-94 .~ TDT-P j 04-19-94 i~-" Completion 04-27-94 I ~'Perf Record 04-13-94 ! -----Patch Record 04-16-94 I .~'Leak Detect 1,5" 1, 5" 1, 5" 1, 5" 1,5" 1,5" 1, 5" 1 5" 1 5" , ~- TDT-P =. 1 5" i 12-09-93 I = , Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 04-18-94 j ---' In: Profile '.' 1 5" 04-12-94 i~' Patch j 1, 5" 04-23-94 ,-'Patch Record 1, 5" 04-20-94 -'-Inject Profile ~ 1, 5" Sch Sch Sch Sch Sch ARCO Alaska, Inc. I$ a Subsl~llary of AtlantlcRIch/laldCompany ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360, ,...¢horage, AK Transmittal #: 94034 99510,~ ~ Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution ~ Well Log Date !Number (M-D-Y) c~..~,_~.' 01,09A 04-02-94 ?7-54 01-11~ 03-25-94 ~-17~ 01-33 103-28-94 75--~5i 03-01 i 03-27-94 71~-2..q!03-02 i 03-22-94 03-19 i 03-22-94 03-29 j 03-18-94 ...~ 03'29 i 03-27-94 03-31 i 03-27-94 Tool Type i Run, Perf Record i 1 5" ] TDT-P TDT- P Perf Record Leak Detection ~- Bridge Plug ?Leak Detection !./ Bridge Plu9 ]~' Bridge Plu9 TDT-P CNTG USIT !/04-43 ¢ 03-29-94 t~ q.-'t5 !~' 04-43 i 03-29-94 i'X,04-43~' 03-10-94 04-44 i 03-13-94 ~-Scf! 04-45 ~03-29-94 ~77-Z~{ 05-08 i03-14-94 ~-~l~! 06-19 ¢03-18-94 I~i 07-08 ~04-03-94 -~ 07-23 ~03-21-94 ~75'-7G~ 09-01 ~03-30-94 hw- o{ USIT ]~- USIT Cement Prod Profile Perf Record Perf Record Bridge Plug Prod Profile 09 -02 09-03 09-19 09-27 11-04 11-17 11-24A 12-06A 13-20 14-O3 14-23 .,~/14-28 .~'1 4-28 '~'i~14-28 14-35 03-17-94 i J Prod Profile 03-29-94 i/ Prod Log 04-01-94 i,~' Perf Record 03-16-94 i/' Prod Log 03-22-94 ] ~' Perf Record 03-16-94!," Patch setting 03-29-94 11 Perf Record 03-18-94 Prod Profile 03-15-94 i." Leak Detection 03-28-94 i -- CNL 03-19-94 ! -~ Prod Profile 03-15-94 !./Leak Detection 03-28-94 !v~ Patch Setting 03-21-94 !/ Bridge Plug 03-17-94 i ¢ CNL ;~2..-t5~ 16-04A i 03-15-94 i,,'- Perf Record ~-~_q~ 16-18 i 03-14-94 i~'Leak Detection ~7.- ~7.. i 16-28 i 03-14-94 i v- Perf Record ~--/:5 i 18-08 i 03-20-94 i,/ TDT-P 1 5" 1 5" 1 2" 1 5" 1 5" 15" 1 5" 15" 1 5" 1 5" 1 5" 5~, 1 15" i 1,5" !' 1,5" ! 1,5" 1, 1"&5" i I 1"&5" 1,5" 1,5" 1,5" 1,5" I 1, 1"&5" I 1,5" Contractor ~'~ ~bez~.~ Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch .~ Number of Records: 38 ARCO AlasKa, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 REFERENCE: g£C£1v£b DEC 0 ? Ala,ka 0il & Sas Cons. ~CO ~ED HO~ ~ -16A 9-25-93 16A 9-26-93 3-29 9-19-93 4-1 9-23-93 4-4 9-17-93 4-78T 9-19-93 4-8 9-23-93 63~qa 4-16 9-13-93 ~f~,-2~ 9-5A 9-16-93 9-29 9-15-93 /9-35A 9-17-93 ~9-35A 9-18-93 \9-35A 9-!9-93 . 9-42 9-14-93 ~b 9-44 9-15-93 /12-22 9'25-93 \12-22 9-26-93 12-30 9-22-93 /~-53 14-4 9-24-93 14-31 9-20-93 15-2 9-14-93 ~-~0 15-18 9-21-93 ¢Z-¢a 16-29A 9-24-93 ~¢-~¥~ 17-12 9-22-93 ~55 18-25 9-20-93 Collar ¢CTc') lo$flO-lO~I Production ~qoo Perf Record Run 1, 5" Atlas Run 1, 5" Arks Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch 1, 5" Sch 1, 5" ~uo~ Perf Record ~o-Sz~ Run Leak ~tectm~Vl~/~ ~ R~ ~ucflon/sa~ ~)~ R~ ~ Detect~ ~]~,~,~ R~ Pe~Record ~l~ll~ R~ Pe~ Record %~a-~lo ~ R~ ~od ~offie ~ ~*~/~ ~ ~od ~offieif~~~ R~ Jewe~ i~alcea R~ Pe~Record 2q00-~%o R~ ~~ ~t/~G ~~ R~ Pe~Record [~i~5~ R~ ~oducflon ~~0 Rim ~od ~o~e [~i~l~ R~ B~er ~~ble ~cker R~ ~oducfloni~/~~ R~ ~uc~on ~ ~od ~offie u~0~zv~o R~ 1, 2" ~-lo~[5 Sch 1, l"&5" Sch 1, l"&5" Sch 1, 5" Sch 1, 5" . Sch 1, 1"&5" . Sch 1, 5" fl~-~/8ch 1, 5"l~'(~6-'Itl~R Sch 1, 5'~a~o-W~- 8ch 1, 5" Sch 1, 5" 1, 5" Sch 1, 5" Sch 1, 5" t~--I~ Sch 1, 5" I ~;taz~o Sch 1, 5"~-'~z~z 8ch 1, 5" ~lcO.-It77~ Sch 1, 5" Sch Have A Nice Day! Sonya Wallace ATO- 1529 Please sign and return the attached copy as receipt of data. RECEIVED BY__ / APPROVED .... Trans# 93118 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # LILLIAN TIULANA # EXXON # MOBIL 1. Operations performed: STATE OF ALASKA ALASKA~ ~'.AND GAS CONSERVATION CC~ISSION RI:PORT OF SUNDRY WELL OPI-- ATIONS Operation shutdown.--.- Stimulate Plugging . Pedorate X . ,~ ~,~/)/~ Pull tubing ~ Alter casing .--..- Repair well ~ ~ .,, / ~,~.,~ ~ 6. Datum of X 62 RKB ' / ~/~'/~ feet 7. Unit or prOperty i;'~// 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 545' FSL, 71' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2301' FSL, 2290' FEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 2742' FSL, 2658' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service Prudhoe Bay Unit 8. Well number 3-29 9. Permit number/approval number 84-79 10. APl number 50 - 029-21118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10283 feet Plugs(measured) 9195 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2438' Production 9438' Liner 1055' 10236 feet 9166 feet Junk(measured) Size Cemented 20" 1875f¢ Poleset 13-3/8" 2000 sx CS III & 400 sx CS II 9-5/8" 500 sx CL 'G' 7" 325 sx CL 'G' Measured depth True vertical depth 80' 80' 2500' 2500' 9500' 8669' 10236' 9166' RECEIVED Perforation depth: measured 9510-9640' ;9678-9690' ;9978-10008' true vertical 8676-8771 ';8798-8807' ;9004-9023' NOV 1 6 ~99~ A~aska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2";17#'L-80;PCT @ 9149' MD;4-1/2";12.64t;L-80;PCT tail @ 9220' MD Packers and SSSV (type and measured depth) Otis pkr @ 9142' MD;5-1/2" Camco BaI-O SSSV @ 2162' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 690 1101 8854 - Subsequent to operation 763 1405 8589 Tubing Pressure 327 368 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rc=~/06/15/88 Title FS-2 Senoir Engineer SUBMIT IN DUPLICATE ~..'~ { .... .lILY REPORT OF WELL OPERiI 'ONS DS 3-29 Perforating Operations: ARCO Alaska, Inc. perforated DS 3-29 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 10/6/93. The interval perforated was the following: 9678' - 9690' MD (Reference Log: AWS-BHCS dated 6/17/84). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 3/12/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 9678'- 9690' MD at 4 SPF, S.I. well, POOH and confirmed all shots fired. (reft AWS- BHCS of 6/17/84). Rigged down and secured well. R£CF..IVED i40¥ I 6 ~99b Gas Cons. Commission Anchorage RDC: 11/4/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS gX- \~-5 1-19 ~10-1-93 * 1-22 ~;l- I-It /10-1-93 ~-t~ 1-29 J 10-8-93 2-16A c~5-1~/9-29-93 4-24 ~- ~O! ~'10-10-93 _/c~ ~t~2~-~. 9-30-93 - 10-1-93 6-12A q~- ~q ~9-29-93 ~ 6-13 10-1-93 7-5 ~-~ 10-6-93 -28 10-~-~3 -28 10-9-93 9-119~-~ /10-4-93 9-13 /10-3-93 9-20 97-q ~ - 10-7-93 ~ ~11-168T ~10-1-93 12-22 ~q'~ /9-28-93 /13-20 ~0-2-93 ~13-20 / 10-10-93 14-3~ ~-~ ~ ~-25-93 14-3~ ~-28-93 ~t~ 14-32 ~10-2-93 15-22 ~1~ ~9-30-93 ~O 16-17 ~ 10-8-93 16-22 ~0~ ~10-10-93 ~-1~ 17-15 ' ~ 10-8-93 17-16 ~ ~0-3-93 17-21~Z~ ~10-4-93 Perf Record Run Rer~_Rar~zd Run Prod Profile 1~ ~e~ ~~ Run Perf Record lU~-~I~7 R~ Perf Record ~ ~ - ~ ~ R~ Completion R~ Peri Record R~ lnj ~offie }~~l~t~ R~ Pe~ Record ~ / ~0~ - I ~1~ R~ 1, 1, 1, 1, 1, Perf Depth Control/~,[cc~ Run 1, Completion Run 1, Leak Detect / ~ Vr~r~el ~b-~ R~ 1, ~od ~offie/~ I~1~ ~ R~ 1, /Completion R~ 1, /~od ~offie/~l~~/~ R~ 1, ~D~ Bmr T~P R~ 1, ~ ~tect~N~t~/~a R~ 1. ~d ~tect~lc~ ~[ 6 a R~ 1, InJ ~o~e I~t~el~e~/~a R~ 1, n~ Brat TDTP R~ 1, D~/~I~?I~?~~ R~ 1, ~tch ~tt!~g I~o-~ R~ 1, CNTG/GR/CCL R~ 1, HLnT/~t[cc~ R~ 1, ~od ~offie/~e~ai~f~i~a R~ 1, Completion Completion R~ 1, 5" 10Zoc)-~.o'5;z.o Sch I~' IocO-.olz~ 8ch B" 8ch 5" 8ch 5"~So- ~5~ Sch :3"adS" I~-'~ ~ 0 Sch I~' q~oo.-- tco~5o Sch 5' 9ch 5" '::1o~-~o-.--'::1~5o $ch 2'* O""c~ ~ % $ch 1"&5" q%~0 -a~%CSch ~,, ~t'~oo- I O~O0 Sch Please sign and return tho attached copy as r~.ceipt of data. RECEIVED BY ~ Have A Nice Day! Sonya Wallace ATO-1529 i II III # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA The correct APl# for 1-22 is 50-029-20848-00. The correct API# for 11-168T is 50-029-215814)0. The correct API# for 17-16 is 50-029-22286-00. Drill Site: 3 Well: 29 K-VALVE DESIUN Thu May 27 16:23:36 1993 DOME SET PRESSURE: FTP @ BOSE K-VALVE CLASS .(A,B, C) 290 PSI~ @ 60 DE~ F 155 PSIC C COMMENTS K-valve will have to be bench tested. Design will account for increasing water cut., PI and LUR. Design shoUld not interfere with ~roduction during normal o~eration. ~oz~rmo F~E / COORDZNATO~ 24 (WITH ATTACHMENTs.) J.C. SMART / M.~. SHOEMAKE PRE 20 (WITHOUT ATTACHMENTS) ~.A. W~LL'S / K.L. ~LAcK~uRN PRE 14 STATE OF ALASKA ALASKA ~AND GAS CONSERVATION C¢ ~AISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown Stimulate Plugging , Pull tubing Alter casing Repair well 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 545' FSL, 71' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2301' FSL, 2290' FEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 2742' FSL, 2658' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service Perforate X Other 6. Datum of elevation(DF 62' RKB et 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-29 ~ 9. Permit number/approval number 84-79 10. APl number 50 - 029-21118 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 10283 feet Plugs(measured) 9195 feet Effective depth' measured 10236 feet true vertical 9166 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1875# Poleset 80' 80' Sudace 2438' 13-3/8" 2000 sx CS III & 400 sx CS II 2500' 2500' Production 9438' 9-5/8" 500 sx CL 'G' 9500' 8669' Liner 1055' 7" 325 sx CL 'G' 10236' 9166' Perforation depth: measured 9510-9640';9978-10008' true vertical 8676-8771 ';9004-9023' Tubing (size, grade, and measured depth) 5-1/2";17#'L-80;PCT @ 9149' MD;4-1/2";12.6#;L-80;PCT tail @ 9220' MD Packers and SSSV (type and measured depth) Otis pkr @ 9142' MD;5-1/2" Camco BaI-O SSSV @ 2162' MD _ _.~ 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation RE£ .lvcu Representative Daily Average Production or Injection Data "-" .......~lt~Q_f.~g~ OiI-Bbl ? Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2035 7254 4628 - 320 Subsequent to operation 2770~'' 6790 5890 323 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~b ~'t~ Title FS-2 Senoir Engineer Form 10-404'~ev 06/15/88 Date SUBMIT IN DUPLICATE t, _ilLY REPORT OF WELL OPERi iONS DS 3-29 Perforating Operations: ARCO Alaska, Inc. perforated DS 3-29 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 2/16/93. The interval perforated was the following: 9978'-10008' MD (Reference Log: AWS-BHCS dated 6/17/84). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 2/16/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 9998'-10008' MD at 4 SPF, Logged up and perforated 9978'-9998' MD at 4 SPF, S.I well, POOH, OOH, left 30' perf gun fish in hole. (ref: AWS-BHCS of 6/17/84). Rigged down and secured well. Fished perf gun on 2/19/93. RDC: 5/'.111./93 Alaska Oit .&. Gas C;ons,. ~1ore-Isis* ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOfF- FINALS 7S-G ~ 6-4 ~7 *__14-23 ... ~2 /16-14 ~ ~~~-~6-14 10-17-92 PSGT - Computed Results R~m 1, 5" 10-17-92 PSGT Run 1, 5" 1-25-93 PSGT - Computed Results Run 1, 5" 1-25-93 PSGT R~_m 1, 5" 2-19-93 PSGT - Computed Results R~_m 1, 5" 2-19-93 PSGT Run 1, 5" 7-24-93 PSGT - Computed Results R~_m 1, 5" 7-24-92 PSGT R~_m 1, 5" 2-18-93 PSGT - Computed Results Run 1, 5" 2-18-93 PSGT . R~_m 1, 5" 2-21-93 PSGT - Computed Results R~m 1, 5" 2-21-93 PSGT R~_m 1, 5" 1-24-93 PSGT - Computed Results R~_m 1, 5" 1-24-9,3 PSGT Run 1, 5" 8-2-92 TMD Run 1, 5" 12-28-92 TMD Run 1, 5" 12-9-91 TMD Run 1, 5" 8-1-92 TMD Run 1, 5" 9-17-92 PSGT - Computed Results Run 1, 5" 9-17-92 PSGT Run 1, 5" 8-17-92 TMD R~_m 1, 5" Please sign And return th~ attached copy as receipt of data. RECEIVED BY__~; _/'~ ~~~.. Have A Nice Day! Sonya W-11.ce ATO-1529 CLOT mON MOB~ # pI4~.Lrps PB WELL FILES # BPX # STATE OF ALASKA * The coreect APl# for 14-23 is 50-029-20757-00. *ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-7-93 REFE~RENCE: _ ~ARCO MAGNETIC TAPE(S) WITH LISTINGS ~" '~ 3-~~~0-17-92 PSGT Run1 Job#L84611-X 3-29 5/olt 1-25-93 3-31 ~lq 2-19-93 ~3-32 5~o 4-25-93 ~o~-33 ~ 7-24-92 9o~~4-2 ~ 2-18-93 ~4-4 ~o 2-21-93 ~--4-9 ~~ 1-24-93 ~~11-1 5~ 4-21-92 1~11-18~9 4-14-92 ~~4-12 ~~4-24-92 · 4-23 12-9- ~14-37 ~ 4~ 13-92 ~16-14 ~zg- 17-92 ~16-21~ 7-23-92 PSGT Run I Job#L92001-8 PSGT Run 1 PSGT Run 1 PSGT ' Run 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 PSGT R!ln 1 PSGT · Run 1 TMD Run 1 PSGT Run 1 PSGT Run 1 PSGT Run I Job#L92012-8 Job#L66798-6 Job#I2~4725-3 Job #L92011-7 Job#L92013-9 Job#L83200-7 Job#L66796-4 Job#L66795-3 Job#L66797-5 Job#L73961-8 Job#L667942 Job#L84609-8 Job#L84724-2 Please sign and return the attach~ed Copy as of data. RECEIVED BY__~_~receipt Have A Nice Day! R E C E IV E D ~ Sonya Wallace APPROVED ATO-1529 Ip~ ] 9 199}' Trans# 9304~ Alask~Oit'& Gas'Cons. C0m~ # CENTRAL FIL]~°~ CHEVRON D&M BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL # PHILIAPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOI~ FINALS 2-7-93 Dual Burst TDTP lam 2-26-93 Dual Burst TDTP (Borax) 2-23-93 CNL 28-93 Dual Burnt TDTP l~_~m 2-16-93 Peri Record Run 2.8-93 Production Log 1-31-93 CNL Run 2-1-93 CNL l~__m 2-22-93 Tubing Punch/POGI~ Setting l~_m 2-14-93 CNL l~_m 2-21-93 Peri/GR/CCL/Jewelry l~_m 2-17-93 CBT Color 2-17-93 USIT(¢ement & Corrosion) Color Run 26-93 PFC/GR/~ (Correlation) Run 2-6-93 Vertllog Please sign and return the attached copy ap receipt of data. RECEIVED B¥__~.~I Have A Nice Day! Sonya Wallace APPROVED__ _~__ ~ ATO-1529 Trans# 93038 8ch 8ch 8ch 8ch Sch Sch Sch 8ch Sch Sch Seh Seh Sch 8ch Sch Atlas Atlas Atlas # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHH,LIP8 PB WELL FILE~ R&D # BPX # STATE OF ALASKA TEXACO The correct API# for 2-12 is 50-029-20277-00. The correct API# for 6-14A is 50-029-20458-01. Drill Site= 3 Well= 29 K-VALVE DESIGN Sat O¢'h., 31 08=52=04 1992 DOME SET PRESSURE: 295 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 190 K-VALVE CLASS (A, B, COMMENTS: This K-valve will most likely have to be pulled to be tested. Depending on the PI, it may dump around 230 - 240 psi. If this occurrs it may have to be pulled and redesigned. CC: J.C. SMART / M.G. SHOEMAKE C.L. CLARK / K.L. BLACKBURN ENGINEERING WELL FILE PRB 24 PRB 20 PRB 14 ~~.NENSING ATO 1586 DESIGNED BY: MMM RECEIVED 0 Alaaka 011 & Gas Cons, Commission Anchorage STATE OF ALASKA ~... ALASK/~/-'"L AND GAS CONSERVATION C( VllSSION REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate X Plugging Perforate X Pull tubing Alter casing ~ Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 545' FSL, 71' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2301' FSL, 2290' FEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 2742' FSL, 2658' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-29 9. Permit number/approval number 84-79 10. APl number 50 - 029-21118 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10283 feet Plugs(measured) 9195 feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2438' Production 9438' Liner 1055' 10236 feet 9166 feet Junk(measured) Size Cemented 20" 1875# Poleset 13-3/8" 2000 sx CS III & 400 sx CS II 9-5/8" 500 sx Cl 'G' 7" 325 sx Cl 'G' Measured depth 80' 2500' 9500' RE¢' I ED True vertical depth 80' 2500' 8669' 9166' Perforation depth: measured 9510-9525'; 9525-9572'; 9572-9640' true vertical 8676-8687'; 8687-8721'; 8721-8771' J U L 1 5 t99t Alaska 0il & 6as Cons. C0mmissi0t~ Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9149' MD; 4-1/2", 12.6g, L-80, PCT tail @ 9220' MD Packers and SSSV (type and measured depth) Otis packer @ 9142' MD; 5-1/2", Camco Bal-0 SSSV @ 2162' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1438 . -. 3630 1323 3982 -~ 12670 2895 Tubing Pressure 276 822 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE DS 3-2g DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & ZONE 4 FRACTURE TREATMENT 4/29/91: A Pre Frac Acid Wash/CTU Squeeze was performed as follows: MIRU & PT equipment then RIH w/CT & loaded wellbore w/seawater. Tagged bottom w/CT then washed perforations at: 9510 - 9525' MD (Z4) 9572 - 9640' MD (Z4) Ref. Log: BHCS 6/17/84. Pumped: a) 39 bbls 12% HCL w/10% Xylene, followed by b) 44 bbls 12% HCL- 3% HF, followed by c) 39 bbls 3% NH4CL Flush. Displaced fluids away w/Seawater & Meth/Water, then pumped 66 bbls of cement, squeezing the perforations (listed above). Placed 12 bbls of cement behind pipe at 3500 psi maximum squeeze pressure. Contaminated cement & cleaned out contaminated cement from wellbore. POOH. RD. 5/5/91: Reperforated: 9510 - 9525' MD (Z4) 9572 - 9640' MD (Z4) Ref. Log: BHCS 6/17/84. Added perforations: 9525- 9572' MD (Z4) Ref. Log: BHCS 6/17/84. 5/1 9/91: MIRU & PT equipment to 9400 psi, then pumped a Propped Fracture Treatment, using 12/18 intermediate strength proppant, through perforations (listed above). Pumped: a) 374 bbls Pre Pad, followed by b) Shutdown. ISIP @ 2102. Resumed pumping: c) 2262 bbls Pad, @ 45 bpm, followed by d) 1367 bbls Cross Linked Slurry, at 2 - 12 ppg of proppant, followed by e) 211 bbls 40# Gelled Flush, followed by f) Shutdown. Placed a total of 309,000 lbs of proppant into the formation. Rigged down. 5/25/91: Performed a proppant fill cleanout. 6/21/91: Pumped a scale inhibition treatment. Returned well to production & obtained a valid welltest. .... P~ 0'. BOX t 00S60 .................. "~"' ......... - ......... =-}'~ ............ ="--' ".=~'."-~ ANCHORAGE, ALASKA .995f~3 . ..... : ............. ;~: ....... ._ .................... DATE' 5-i6-9~ . . REFERENCE' ARCO CASED ~.HOLE FINALS . ""-:':::~ '~"'29 :"=':-'4-i ~=9i :':<:'.:;' F'ERF"?RECORD"~:'~:J.~' '~d;': :.. -, -=., ...... RUN ,'i ..... '" .. , ..... ,,,'-',~.'.,'..'~-.] --- ~ ¢. , 3-f8 4~5~9~ " .... ' INJECTION ...:-'~r ' "¥ .... 'RUN'4, . ..... ........ "- . . . . . .,.~ ~-.- ~,.... ~ . ; ~.-.. . · 3-29 S-29-9f -~ ' PERF 'CO~ :..y-T.'-'.-'- · ...... .-. - RUN t, 5' -. '~;E-~ HL~ ........... ~q29 -"- 5=5'=9 ~ "77' COL[ARTpE~:~'T'T~':Z}7-"}'~'T'"~-'.--~;.=':~":?7- : ...... ~UN='t s-s az s-e '- -:'LEAK". ETECTZ"'ON''?''-: .... "' nUN "6-6 4~ ~-9~ ..... GAHMA'R~YTCOU T~G ...................... 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"..".. . ' .~'~"."~''~," ~.'s~.~zz'~'] v .' · ¢. ' ' · ; · ' : ........ · .... .'. ~, '. ," . ' ' '., ~ '.~.'.' . r.,z s:..' ", : ............ ~'.z~'%,~.:'.~;'O.,.:~ ......... ~~ ........ ................. - "." '. ..... ~ '='. '7'v. .... ~ .......... == ...... =7-.'.'t-.:T~'.'~ ~:, .. '~.; ' -. . , ,:: ...... '. · .~:.'"...~.'. ' · · :,'~.2' "'..: x'. . .. '.4 .... ~.~.'..~.... ;~:: · .... . . · .'. ' ...... '.,' '.. . ":...':.'..,,.'.;;,~,. ~.~...':... '6- - ; . ': ' ~," .". .....' ' .- - . ' :L')'~',~. ~.' . '~- ' }....~Lr,.. / .~',,:..'...' :,. ~ ~ · ............ A R C 0 A !... A ;!~' K A, I N C., I::',. C), BOX ANCHOIR(:'~E;IE, ALA,S'I< A DATE: 4-.4- 9 i , F;~IiF. F"'FRENC;E' Al:;:(](] CASED HOLE F'INAL. S i -5 t -S ',2-1 'S "z, .... .'.~ .... 2 2 · ,. ' t:-'- ..~ ".';, .... ~"~ 5....S i i .... 28 i2-i t ':> .... '~ i i i4-Si i '.5.-4 i 5-4 iS-ii t b-,~. i i6-? i '?-2 i ,3 - i ..'5 - 90F:' r..:: F;,' F:' R E:. C t. R D i '2-i 6-90 I::'IER'F I:;..'ECOi;:D i (.)-:27-90 PERF REC~ORI) S..-'.3 i -9 t COL. L. AR/F'IiEI;~F · 3 - :5 ,:)..- 9 i C 0 L.. I... A R /F:' E R F 3-'''c' -9 ,.:. ! i C 0 !.. L A !;.'. / t':' E R !'--' S -... 2 '7 - 9 i C 0 L. L. A R / P E R F' S.... 3 r:',- 9 t (]CJ L I_ A I;~ / F:' E: F< F' :'-~, '... 2. 8 - 9 i C 0 I... L. A R/' F:' E F:. F' i ~, '-,=. :~ '7, -,:~,,,n P E R F:R' iiE C 0 R D t <')- 8 -" 9 () P Iii: R F' R E: C [) R D i :2-'29-9~ F' [~ F,' F kEC. Olxl9 .. .... · .. ~,,. ]... · i i "~,... q,.., -.. o, n,, P E R F R E. L, .~ F,' D i ¢9-25-90 F'L~iRF F,'FZCORD · o. ,. :5-"25-~ i F:'ERF F(E:.CORD i 2-2-9() (;AHHA RAY i '2-~-90 PERF REECOF;,'I) t ()-2S-90 F'EF~F..RECOI;~I) i (')-29-?~ F'ERF RECORI) S--'27-9 t. CCL .............. : .................................... 3-'28-9i COLLAR/F'ERF ..... RUN i ,.., RUN "-, RUN' t, ':" R LJ N'1 , I';:I..JN i , RI..J N i , ..,.' NUN t, .., R U i'..l, i, I;,'U N t, 5 R U N i, '5 RI. JNt, '.5 R LJ N .... , RUN t, .5 RLJN t , '5 RUN t ,..5 · RLJN t., 5 RLJN t, .5 RUN t , 5 F;.'.UN t , 5 PI_EASE SIGN. AND RETJRN 'THE ATTACHED' COPY AS RECEIPT OF' DATA, /- RECEIVED BY HAVE A NICE DAY! . · SHARON WILSON ............................................................ AF F ROV AT[]-i 529 ' 'FRANS$- 9t 093 ..... .a-., ~T~.~.. ~ .~T~~:~": ;'"' "' '" ~'' ~ ...... ., C Fi ~ R ON. -~r~,.~.~.~. ~ ~'~'~., D & M:,.~:~:-~-,,,~,":~"T~-,~(~~":' . R & D EXTENSION E i.6 TXON. BP.X .... RECEIVED · .lA EXXON ~ STATE OF- ALASKA, PR 9 19~1 MARATHON .............................................. :I:.EXACO., .................... :41aska Oil & Gas Cons. , M O B I L. C°tamission ....... : ' Anchorage ARCO ALA~gKA~ INCo~ P .~ 0 ~ B 0 X ~ C) () ::'~ 6 ~.~ ANCHOF~:A(}E, AI.A,'.gKA 9??Di ,a R Iii] F:' Iii] R E N C. E ' A R C 0 M A (~ iH IE T I C T A P E ( :_:i.' ) W I T H L. _I S 'i" I N G ( ~: ) '$....'29 i ~).---29-89 D~.;N ,.JOB:~S673 t 2 6 .... i t (-)....29--89 (};AMMA DSN JOB:~:S67:323 '?-2t i 0..-.'..'~ 0..- 8 i;' DS"N .JOB:,":. '~6 '?:3S4 t :.'..'; .-. 98 i 2 .... i 4 .-- 89 D I L.. / I..t R I ..J 0 B ~ :3678:3 X ..,, t .3 i 0 -') 8 o,.- ,.. c.,'y C,.A M M A DS'N .jO B:~S6'? S¢.:) t t'" ""'" ' D ;" · - t._ E. ~:.~..-, I::. 5' I G N A N i:L' E't" U R N T H E A 'l" T A C I.-i E D C: 0 P Y A ,2, R E C E I P 'i" 0 F' D A 'T' A~ A RECEIVED SAI...LY HOFFECK[-.:F( /4. 9~0 APi::~ROYEI) ........ ATO .... i529 JAN2 1,, ._[{'~::.'ANS'.: '~'o Alaska Oil'& Gas Cons. Com~Ssto. ' '" 2 Anchorage D I S T R I B LJ T I 0 N .L CENTRAL F=ILE$ (C1'1) CHEVRON D & M 'i"AMMAS BROWN (OH) IEXXON MARATHON NOB I i_ P I"11 I... L. I F:' S F:'B W E: L.. L.. F' I L. E ~; R & D · ..'"' BP:x: · '" ;:,."TA't"E OF AI..A.?I<A "1" tjij X A C .O Ali'.(](] ALASKA, INC~ 1:'~ 0., BOX i (-)(-)36~ ANCHORAGE, ALA,S'K A 995'1 DATE' i-i 8-9~ I,I.-.I--I.-.F~I::.r.~.,E AR[;(] CASED HOI..E FINAI...S' 3-29 i (.)-29-89 6 .... i i()-29-89 7-2 i i ,3- :~'"3- 8 9 i 3-98 i 2'-i 4"-89 i 1i~"'-98 i 2-i 4-89 i S .... i :::.: i '::.;,-28'-"89 [;AMMA I)S"N GAMMA DS.'N C;AMMA I)SN DII.. HZ-RES. INDUCTION GAMMA DSN RUN i , ..~ R U N i, '.:S" RLJN t , '5" RI...IN i, '5" RUN t, .~;" RLIN i , ~" F:'I...['." A S E S I G N A N I) F;,' E l' U R N T I'-ili:.: A T T A C I-'iE D C 0 F:' Y A.S' R E C E I P T 0 f:' D A T A~ RECEIVED BY .... ~_~ .......... FIAVE A NICE DAY, RECEIVED SAL. LY HOFF:'ECi< ER A'rO .... '29 _ JAN Z 1990 ~- CENTRAL FILF$ '"'.,,. C I"t E V R 0 N · '" EEXTE..'.NS I ON EXF:'LORAT ION ~11' . EX×ON MARATHON ~ MOB I L A F:' F:' I:;: CJ V E~ I) ..~__ TRANS¢- 9 ~ (':/2 L5 P H I L L I P ,S' PB WELL FILE.$ · "' B P X -!1' :~ -$TAI'E OF ALA.'::I<A · ~: TEXACO ARCO ALASKA, :[NC. F:'., 0 .,. BOX i (.")6'360 ANCHORAGE, ALA~'KA 995i -- DATE: 7-26-89 REFERENCE' ARCO CASED HOLE FINALS t-25 7-2(:)-89 ACBL/VDL-GAMMA RUN i, 5" S-29 7-t 5-89 'JR ~'PEC. 'FOOL F,'UN 4-26, ~-~.i-89 COLLAR/PERF RUN i , 4--'~'~ ~-'~, ~ i -89 COLLAR/PERF RUN 9-4 7-t 9-89 COLLAR/PERF RUN t t-3 ~_,~o._oo ...... , '', ..... ,- , ~ .. COLL~R/FEkF RUN i 6-4 7-22-89 COLLAR/PERF RUN i , t 8-24 7-20-89 CBT RUN i 8-24 7-20-89 CE'f' RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 ...DISTRIBUTION $ CENTRAL FILES ~~ CHEVRON D & M '"' EXTENSION EXPLORATION · "' EXXON ....... MARATHON "" MOBIL_. ~ PHILLIPS PB WELL FILES m_ · ,r BF'X $'I'A'¥E Ob-. ALA~'KA I'EXA~O A'FLA~' A f' C. A.'-:~' Ai LA;~' A'f' L r:~.':¢ A'f' i_A,"~ A ~'Cl4 ~'CH ARCO ALASKA, IN(]. F'. O. BOX ANCI4ORAGE, AL. ASKA 995 i 0 -- DATE- 6-9-89 REFEF,'ENCE · ARCO CASED HOLE FINALS 3-9 ~-o~-no_ _~ _, F'RODUCTION F'ROFiLE RUN 3-24 5-22-89 GR SPEC .TOOL KUN 3-2? 5-26-89 GR SPEC TOOL RUN 4-t5 5-t7,i9-89 TEMF' RUN 4-26 5-i9-89 PRODUCTION PROFILE RUN 4-~ 5-t8-89 PRODUCTION PROFILE RUN 5-t3 5-2~,2t-89 [EMF' RUN 5-i7 5-2e-89 PRODUCTION PROFILE RUN ~7-7A 5-28-89 PERF RECORD RUN 9-t4 5-22-89 INJECTION PROFILE RUN --'"t2-it 5-2t-89 PITS RUN '~'i2-t9 5-2i-89 INJECTION PROFILE RUN ~'-t4-i~ 5-27-89 COLLAR/F:'ERF RUN ~t8-2~ 5-22-89 CBT RUN --~OWDW-NW 5-24,25-89 PITS RUN --OWDW-$E 5-25-89 PITS RUN OWDW-$W ~- ~' ¢-~4-89 PITS RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, DISTRIBUTION · CENTRAL FILES ~- F'HILLIF'S CHEVRON'"':::_~ ';~!:' ~'~-;- PB WELL FILES D &. M.. '" ~. ; R & D EXTENStOW" EXPLORATION ~ ~ BPX EXXON "' ~ ~ STATE OF ALASKA MARATHOn. ' - -~ ~ TEXACO MOBIL CAMCO ,S'C!4 ,.?CFI CAMCO CAMCO C A H C 0 CA~"ICO C ~ M C 0 SCH CAt.~CO CAMCO CAMCO A'I"L.A,2' SCH CAMCO CAMCO CAMCO I:,'I=FI:RFENf':~: ~R'f'llTJ .C.~SFD I-.IF~i.I: FTi'-.Jt:~I.. :]'-2('-) 4 -- .':-.: ~.' -' ;q F'l CR! I..¢,R ¢~N13 PF-RI=[1R~T!'NK I_F1K RIIN t, ~:~:: ::~:_ '~:., - '=',. ",.:.. -.- ,'-~..,:,, P ','.,. '~, ..,:" I:;' ~..~ ~, ,:;" 4-- t "-'-- '~ '~-F~,'-,' Pl:~'[1F:,l r, .... !,,TTf'IN F'~:FIFI'! F I~t..IN i , ';' . .~ ~ . · 4'--t i b-.>-?t--RR 'rN..IF'f".TTrliq i::'I?i]i:'TI.F Rl.liq i . ~..-? 4-'.')....P,P, [:f!! I ,-:':',!:? t..5~.,!,¥) I:'I--!;.'t=F'IF;.'t~TTN[7., t..Iq.[:, I;.'I. INi. ~,.'." o · = ~.: - :? ,:':) ---. ,q '~:), F:' R Fl f'.': ~ I f': T T Fl i'4 F:' F;.' f'! I=' t' ~ F" R' I.I iq.~ ~" ~-- .:. .. . , . . , . i'i-'i:? 4-'?--Rf=: 1.7, ¢, M M ;:'.; F:¢;y/.?PT,,',..!NFI;,',/'IdYD~S:F) !flF; R'!..IN t, i '.'::' .- :.-'.~ 'R "'.'; --- t :!--- :::~ ,"-:~, i'.'- ~:'.', T ;~, 1::' R' ¢,,"".' / '!" F' M P F:' R' ¢~ TI I R' r" I. FI F; I;.' I ! N '~ : ~" i d'-,- i ~. , 'T.-- i ''~:.. _. ,.;,.,c:.., o --f-C-Mi:,,. , . /F't f'!tdMI:'TF"R/1 F-;.5. K..DFTF:~T T Fliq R! iiq t : ~." i f---: -- :'~ % -- :.', :~ .-- :::t ~:~ ' I::' T -c .::, R ! ! iq i :;;" .... ~ ! .~ . · i. ,q - i i. ~;', -- ''~.: '~, _. c:,,.,,c,, c:,, IN,,. Fi 'F',..I I f".' '1" '", ['1 iq. F' F,.' 13 F- T 1 F' R I I iq t . r.~,, iq t77 'r -. ~:: ' 5.-- '..:.-' 4 .- ,.c -.,, ,,.. !-.,, T N. t F' f": T T ~"~ iq F:' R rt F !' ! I::' R' lJ N i . ~" I': A H F: f'l I'IAH C.f'l [',~M f:fq ir'; f.: ~ [.'. ¢, i,,i f": FI f': th i'q i'": F1 F: t."~ ivi f".' F1 F;,' F: ~ E[ 1: V F' T) 1=.-,' Y ............................................................ Ft,'~,Vi:' ¢'~ NI'f":F D¢;Y! ][)ATE: JuLy 23, t987 REFEF:ENCE: ARCO F're~ure Data F'Lowing/Prem's'ure 'FaLLoff Test Shut in BHF' Log Run t Shut in I?.HF' Log Run i Shu'f in BHI:'. L. og Run t $ch $ch $ch S c h I::'l. ease sign and re'l:urn '?~e ,attac:hed copy as receipt Received B'/ .... HAVE A NICE D~~aOil & Gas Cons. Commission R o.s a n ne F' e e k~~~" Anchorage ATO-t 529 'f'I:;~ANS' .$8'7J75 /~ , Ap p roved_, .......... ;~ DISTRIBUTION of data, ~ F'hi llips Central Fi les' .. Chevron F'B Well Fi les :'-': D .t.. M ~'~. R & D Extenxion Exploration :~ Sohio " ~tate of Alaska · ~'~E X X 0 I~ -.. ~ H a r' a 'f h o n ~'~ T e x a c o · .-'"' M o b i L ARCO Alaska, Inc F',.O ~ Box Anc:horage, A£a~ka 995~ DATEi' February 2 REFERENCE: ARCO Pres:~ure ~-29 i/~t-2/~/8 "? ~atic Gradient' ~-~ 2-i-87 S~a'~'ic Gradien'~ C a ~ c o F:'i. ease sign and re~urn ~he atiac:hed copy as receip~ of data~ Received By HAVE A NICE: DAY! Rosanne Peek ATO- i 529 TRAN$ ~.87t t9 Ap p roved DISTRIBUTION Cen~ra L F i Chevron D & M Ex'~ension ExpLora'~ion · ..'~' E x x o ~ Marathon ~ Mob i I. ~'..-F'hi F'B We£L Fi i. es ~ R & D ¢ Soh i o ... $~a'l.'e of ALaska :~ Texaco Anchorage ARCO Alaska, Inc, F'. O. Box i Anchorage, Ai-aska 99.'5:i G, DATE' March ~, i986 REF'ERENCE' ARCO Ca sed Hoi-e Final. ~D.~ :~-29 t0-:~0-85 I'DT Run t 5" ~D$ 4-8 t-3t-86 ~pinner ~'urvey ~ D~ 4-t~ 2-3-86 ~'pinoer Run ~ D~ 4-2t ~ 2-38-85 ACBL/VDL/,~ig/GR Run D.~ 6-4 t t-22-84 TDI' Run t 5' ~ D3' 6-5 1-9-85 Co~,~p. Record Run ~D~' 6-9 tl-3-85 PDK t e~ Run ~D,~ 6-~ te-t2-85 CNL MuL~i-~pace Run 2 5" DS' 6-tY~ t~-12-85 Epi Log LAC AnaLy~i~ Run ~ D~ 9-7 t -23-86 ~p i nner/GR Run t 5" ,5.'c h Ot i~" Camco DA $'ch $c h DA C a f~ c o F'l. ea~e .s'ign and re'fu'rn the att'ached copy a.s receipt of data. Received By ~~~ I..IAYE A NICE Irma CarLin AI'O--t 429F TRAN$ $86t96 DISTRIBUTION $ Ce',",tra I. F i les · ,,."" Cl'levr on D & M · ,,."" Ex'l:en.~ion E:xpLo','a'~io',", · .. E× ×on Mara t;hon $ Mob i l .,,-p .,,- hi l l i p.s' F:'B Well F'i le.s' R & D · ,."" ~'ohio ARCO Ala~.'ka: Inc. P.O. Box i GGS6G Anchorage, A i.a~ka DATE)' Jar~u, arv 7, i°86 REF'ERENCE ' ARCO Pr e.s's' ur e Pre~.~u'r'e Bui [d-up F're~.ure Bui I.d-up F:'re~:sure Bu.i /d-up C 8 fliC 0 C ~..) hi C 0 Ca file 0 F'Lea~e s'ign and re'.l:t.',.rn 't'he .~.~l'"t'ached copy a.s: receip-'.r c',f ,.':ls't'a., 'F.'.ecei red By HAYE A NICE .DAY! I<eL Ly McF:ar La'nd ATO-i 429F TRAN~. . ~8z¢~6~.~ DISTRIBUTION Cen±ra [ F.i l.e.s [.'.' h e v r o 'n D & M "" I~'- ,v I. 4. ' ,,.. ):: 4.,. £.;, ti 2..: i 0 i'i ~ .... p £) i' 8 : I 0 i"i Ex xo'n 71 a i" 8 4.: h o. i'i Mob i 1. Phi [Lip~ PB WeL L'F'i Lez,' ""oh i 0 · ~ $'tate of Afa,.s-I..',a Texaco ARCO Alaska, Inc. ~ Post Office L 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: November 4, 1985 Reference: ARCO CH Finals ~X/~c~3~-~9 Spinner 10-13-85 Run 2 5"' Camco -,~ x,~182 SpinnEr 10-26-85 1 5" Camco - Spinner,,.. 10-25-85 1 5" Camco ~ ~ ~1-4 Spinner .... -10/17-18/85 1 5" Camco ~~~-23 spinner 10-24-85 1 5" Camco Please sign as rece&pt of data. Received by Pam Lambert ATO 14 29C Trans 396 ~r'l~/l:~ Anchorage Chevron PhilliDs D & M ' PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Tmxaco Mobil ARCO Alaska, Inc,~',, Post Office .... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 10, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation-Commission 3001 Porcupine Drive Anchorage,~AK 99501 Dear Mr. Chatterton: Re: DS 3-2 DS 3-27 DS 3-28 DS 3-29 DS 3-30 Permit No. 76-24 Permit No. 84-62 Permit No. 84-72 Permit No. 84-79 Permit No. 84-83 Enclosed is the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, . D. F. Scheve DFS/JEB/cb Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 3-2)Wl-3 Pi(DS 3-27)Wl-3 Pi(DS 3-28)Wl-3 Pi(DS 3-29)Wl-3 PI(DS 3-30)Wl-3 RECEIVED Alaska Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . -' /~',, STATE OF ALASKA .---,~ ALASKA(. 'AND GAS CONSERVATION cO AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-79 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21118 4. Location of well at surface 9. Unit or Lease Name 545'FSL, 71'FWL, Sec. 11, TION, R15E, UM PrUdhoe Bay Unit At Top Producing Interval 101 Well Number 2301'FSL, 2290'FEL, Sec. 10, T10N, R15E, UM 3-29 At Total Depth :,, , 11. Field land Pool 2742'FSL, 2658'FEL, Sec. 10 T10N, R15R, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool 62' RKBJ ADL 28328 ALK 2326 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore ]16. No. of Completions 6/05/8/+ 6/17/8z~ 7/17/8z~I N/A feet MSLI 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10283' MD 9195' TVD 10236' MD 9166' TV]) YESJ~ NO [] 2161' feet MDI 1900' 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, LDT/CNL/GR/Cal~ CBL/CET/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZEiWT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 80' 30" 1R754} Pm1 13-3/8" 72.0#- L-80 Surf. 2500' 17~" 20~ .~w C.R ITT + ~nn _~x IS II .9-5/8" 47.0# L-80 Surf. 9500' 12~'''' 500 sw ~1~, ('. CR I 7" 29.0# L-80 9181' 10236' 8~" 325 mx Class C, 24. Perforations open to Production (MD+TvD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9572-96~+0' MD 5½ 9220' ~1~2! 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perfed on 8-9-85 w/6 SPF DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED TVD of perfs: 8721-8770' I~/A ,, 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8/09/85 Flowing , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE SIZE IGAs-oILRATIO 8-21-85. 4.1 TEST PERIOD ~ 728- 1613 0 410I 2.218 Flow Tubing Casing Pressure CALCULATED.~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1141 -- 24-HOUR RATE "~' 425-9 9445 ,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED SEP 19:85 AlasKa Oil & Gas Corm, Commission Anchorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , Top Sadlerochit 9506 ' 8673' None GOC 9688 ' 8801+ ' Top Zone 3 971~0' 881~1' Top Zone 2 9783' 8871' HOT 10052 ' 9051' OWC 10107 ' 9085 ' Top' Zone lB 10169,'- 9121~, PBTD 10236 ~ 9166 ' TD 10283 ' 9195 ' 31. UST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This. form is designed for submitting a complete and correct well completion 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 a.~d i'n any attachments. ':'. . Item 16 and 24: If this well is completed for separate production from more than one interval (multiple co~mpletion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- iection, Gas lniection, Shut-in, Other~e×p.~ip~ Form 10-407 ARCO Alaska, Inc~'-~ Post Office · -~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 10, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 3-2 DS 3-27 DS 3-28 DS 3-29 DS 3-30 Permit No. 76-24 Permit No. 84-62 Permit No. 84-72 Permit No. 84-79 Permit No. 84-83 Enclosed is the Completion Report for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/cb Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 3-2)W4-3 P1 (DS 3-27) W4-3 P1 (DS 3-28)W4-3 P1 (DS 3-29)W4-3 P1 (DS 3-30)W4-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARco Alaska, inc. ~ Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 3, 1985 Reference: ARCO Pressure Data 3-27 Static Gradient 3'-29 Static Gradient 3-30 Static Gradient 11-2 PBU 8-4-85 DA 8-10-85 Otis 8-12-85 Otis 5-27-85 Camco Please sign as Received by Pam Lambert ATO 1429C Trans 297 receipt of data. ~~.V~~ Alaska Oil & G~$ C¢m$. Commission Anchorage Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Texaco M ob i 1 ARCO Alaska Inc ~s a Subsidiary of AllanticRichfieldCemo~-v ARCO Alaska, In~'-''~''~. Post Office =~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 3-29 Completion Dear Mr. Chatterton: Enclosed is the Completion Report, Daily Drilling History, and two copies of the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4610. Sincerely/~ T. L. Fithian Area Drilling Engineer TLF/JMM/tw JMM/L09 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEiVEb ocr o4 Alaska Oil &.Gas Cons. Commission ~nChorage · ' ' ' ~"-~- STATE OF ALASKA ALASK' .. ~AND GAS CONSERVATION C ~IISSION"~ WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL I~(× GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator~ 7. Permit Number ARCO A1 aska, Inc. 84-79 3. Address 8. APl Number P. 0. BOx 100360, Anchorage, AK 99510 50- 029-21118 4. Location of well at surface 9. Unit or Lease Name 545' FSL, 71' FWL, Sec.11, T10N, ELSE, UN !LOCATIONS Prudhoe Bay Unit , ,. At Top Producing Interval VERIFIED 10. Well Number 2301' FSL, 2290' FEL, SeC.lO, TION, R15E, UM i Surf.~ 3-29 At Total DepthJ .B.H. ~ 11. Field and Pool 2742' FSL, 2658' FEL, Sec.lO, TION,' R15E, UM '--~---~ Prudhoe Bay Field 5. ElevatiOn in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 62' RKB! ADL 28328 ALK 2326 12. Date Spudded 13. Date T.D.~Reached. , 14. Date Comp., Susp. or Aband. i 15. Water Depth, if offshore 116. No. of Completions 06/05/84 06/17/84 ~ ' 07/17/84 I N/A feet MSL I 1 i7. Total Depth (MD+TVD) 18.Plug Back DePth'(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of'PermafrOst 10283'MD,9195'TVD 10236'MD, 9166'TVD YES [] NO [] 2161 feel MD J 1900' (App~ox) ~2. Type Electric or Other Logs Run " D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, CBL/CET/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD " SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" 1875# Poleset ' 13-3/8" 72.0# L-80 Surf 2500' 17-1/2" 2000 sx CS Ill + 400 sx CS II 9-5/8" 47.0# L-80 Surf 9500' 12-1/4" 500 sx Class G + 300 sx CS I 7" 29.0# L-80 9181' 10236' 8-1/2" 325 sx Class G 24. Perforations open to prOductiOn (MD+TvD of Top and Bottom and 25. TUBING RECORD interval, 'size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 9220 ' 9142 ' I 26. ACIDi FRACTURE, CEMENT sQuEEzE, ETC. ,, DEPTH INTERVAL {MD) AMOUNT& KIND OF MATERIAL uSED ,,, N/A 27. N/A PRODUCTION TEST i " Date First Production Method of Operation {Flowing, gas lift, etc.} Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED , OIL-BBL GAS-MCF WATER-BBL elL'GRAVITY-APl (corr) Press. 24-HOUR RATE ~ ~ 28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent 'dips and presence of oil, gas or water. Submit Core chips. None RECEIVED OCT o 81984 Alaska 0il & Gas Cons. Cornmission Anchorage ..... Form 10-407 Submit in duplicate Rev. 7-1-80 JMM/WC16 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and graviiy, NAME MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochi t 9506' 8673' NONE G0C 9688 ' 8804 ' Top Zone 3 9740' 8841' Top Zone 2 9783' 8871' H. O. T. 10052 ' 9051 ' OWC 10107' 9085' Top Zone lB 10169' 9124' PBTD 10236' 9166 ' TD 10283' 9195' 31. LIST OF ATTACHMENTS Drillinn Hi_~nrv_ C, vrn_~nni~..~lrv~.v ~? ~nni~.~l 32. I hereby certif~y'tha~ the for oing is tru~ and correct to the best of my knowledge Area Drilling Engr. Signed'1'-~, ~-" Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ' Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depl~h measurements given in other spaces on this form and in any attachments. .~ Item 16 and 24: If this well is cOmpleted for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jectiOn, Gas Iniection, Shut-in, Other-explain, Form 10-407 ARCO Oil and Gas Company Well History - Initial Report- Dally tnetru~tione: Prepare and submit the "lnit~l Rel~' on the fl~t Wednesday after a well Is spudded or worKover operetlonB are stifled. Dally work prior to sPuddlell Ii~ould' be mrmmldzed on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 203408 ICounty. pariah or borough North Slope Borough Leale or Unit Title ADL #28328 Drill, Complete & Perforate Istete Alaska ell ~o. -29 Operator IARCO W.L Prior elalUl if 21,66% ARCO Alaska~ Inc. Spudded or W.O. begun loafs IHour Spudded 6/05/84 1630 Hrs. Date end depth Complete record for each day reported as of 8:00 a.m. 6/06/84 6/07/84 6/08/84 6/09/84 thru 6/11/84 6/12/84 13-3/8" @ 2500' 751', (751'), Drlg Wt. 8.8, PV 32, YP 54, PH 8.5, WL --, Sol 3 Accept rig @ 1100 hfs, 6/5/84. NU diverter system & 20" Hydrl. Spud well @ 1630 hfs, 6/5/64. Drl 17½" hole to 751'. 13-3/8" @ 2500' 2538'', (1787'), Prep to ND Wt. 9.2, PV 24, YP 52, PH 8.5, WL 9.6, Sol 4 Drl 17½" hole to 2538'. RU & rn 66 its, 13-3/8", 72#, L-80 BTC csg w/FS @ 2500', FC @ 2421'. M&P 2000 sx CS III @ 12.2 ppg, followed w/400 sx CS II @ 15.0 ppg. Displ using rig pmps. CIP @ 0600 hrs, 6/7/84. Bump plug. Tst csg to 1500 psi. a W.O. 13-3/8" @ 2500' 3201', (663'), TOH Wt. 8.6, PV 3, YP 1, PH 11.5, WL NC, Sol 2 ND Hydrl & diverter sys. NU & tst BOPE to 3000 psi. TIH w/12¼" bit to FC @ 2421', DO FC & cmt, tst csg to 1500 psi. DO cmt + 10' new hole. Conduct formation tst to 11.2 ppg EMW; OK. Drl to 3201', TOH to PU Navi-Drl. 13-3/8" @ 2500' 6635', (3434'), Drlg Wt.. 9.2, PV 6, YP 4, PH 8, WL NC, Sol 6 TIH, Navi-Drl, drl & surv 12¼" hole to 6635'. 3308', 1.7°, N87W, 3307 TVD, 1.27 VS~'- .0SS, 1.59W 3674' 11.2° N56W, 3671TVD, 40.17 VS, 24 95N, 31.64W 4054' 19.3° N69W, 4037 TVD, 141.22 VS, 70.21N, 122.88W , , 4693' 33.9° N61W, 4606 TVD, 425.72 VS, 193.41N, 382.46W , , 6445' 33.2° N56W, 6065 TVD, 1394.87 VS, 712.38N, 1201.15W , , 13-3/8" @ 2500' 7714', (1079'), TIH w/bit Wt. 9.2, PV 3, YP 3, PH 7.5, WL NC, Sol 6 Drl & surv 12¼" hole to 7714'. 6897' 31.9° N56W, 6446 TVD, 1638.06 VS, 848.37N, 1402.76W 7332' 31° N54W, 6817 TVD, 1864.25 VS, 978.55N, 1588.67W 7641' 29.9° N56W, 7083 TVD, 2021.41VS, 1068.37N, 1716.95W · , RECE \/ED The above Is correct Signature For form preparation and(~letribution, see Procedure- ManUal, ~ectlon 10, Drilling, Pages 86 and 87. IDate I Title 6/28/84 OCT 0 8 ]984 Arlch()r.~ ~ e Drilling Superintendent AR3B-459-1-D I Number all dally well history forms consecutively they are prepared for each well, {P;ge no. ARCO Oil and Gas Company Dally Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I Stale Alaska North Slope Borough Field ILease or Unit Prudhoe Bay I ADL ##28328 Date and depth as of 8:00 a.m. 6/13/84 6/14/84 6/15/84 6/16/84 thru 6/18/84 6/19/84 6/20/84 Complete record for each day while drilling or workover in progress 13-3/8" @ 2500' 8814', (1100'), TOH f/bit chg Wt. 9.5+, PV 10, YP 7, PH 8.5, WL 9.5, Sol 9 Drl & surv 12¼" hole to 8814'. 7943', 30.5°, N53W, 7344 TVD, 2173.25 VS, 1156.59N, 1840.62W 8319', 30.7°, N5OW, 7668 TVD, 2364,06 VS, 1275.74N, 1990.41W 8750', 27.2°, N44W, 8043 TVD, 2572.27 VS, 1421.08N, 2143.52W 13-3/8" @ 2500' 9200', (386'), Drlg ahead Wt. 9.9+, PV 22, YP 18, PH 8, WL 9.5, Sol 11 Fin POH. RIH, rm 8424'-8734', pipe stuck @ 8734'. Jar & wrk pipe loose, rm 8734'-8814'. Drl 12¼" hole to 9200'. 9063', 31.7°, N42W, 8318 TVD, 2720 VS, 1532N, 2247W 13-3/8" @ 2500' 9530', (330'), POH f/csg Wt. lO, PV 9, YP 5, PH 8, WL 10.2, Sol 11 Drl & surv 12¼" hole to 9530', cond f/csg. 9217'. 35.6°, N42W, 8446 TVD, 2802 VS, 1595N, 2304W 9-5/8" @ 9500' 10,264', (734'), Fsh'g Wt. 9.5+, PV 11, YP 7, PH 10.5, WL 9.8, Sol 9 RU & rn 227 its + 1 pup, 9-5/8", L-80, 47#, BTC csg w/FC @ 9414', FS @ 9500'. Cmt w/500 sx C1 "G" w/.25% D-31 & .15% R-5. ~im~l w/mud using rig pmp. Bump plug. CIP @ 2230 hfs, 6/16/84. Chg rams &tst to 5000 psi. RIH w/8½" BHA, DO FC, cml, FS + 13' new hole. Conduct formation tst to 13 ppg EMW. Drl to 10,264', POH. RU & rn DIL/SP/BHCS/GR f/9490'-10,264'. Rn LDT/CNL/CAL/GR f/9490'-10,264', GR to 2500'. Rn LDT/CNL/CAL/GR, log stuck @ ±9740'. Prep to strip over WL. RIH to ±9701' WLM, set dn on bridge, att to WO or latch onto fsh w/o success. (TOF @ ±9705'-9715' WLM). 9-5/8" @ 9500' 10,264', (0'), Drl Wt. 9.5, PV 10, YP 6, PH 10, WL 10.1, Sol 9 Att to wsh thru ledge or key seat @ 9701' WLM. Rotate pipe, wrk thru & wsh over fsh. Strip out of hole w/WL, retrv compl fsh w/o damage to logging tls. RIH, prep to drl. 9-5/8" @ 9500' 10,283', (19'), Prep to cml lnr Wt. 9.5, PV 10, YP 8, PH 10, WL 9.9, Sol 10 Drl 8½" hole to 10,283', cond f/logs. RU & rn GR/CN. Chg top rams to 7" &tst. RU & rn 26 jts, 7", 29#, L-80 BTC lnr. Alaska The above is correct S,gneture //j~~_ ~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B IDate ITitle 6/28/84 Drilling Superintendent RECEIVED OCT 0 8198/t Alaska Oil & Gas Cons. Commission Anchorage I Number all daily well history forma consecullvely es they are prepared for each well. no, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space ~s available. I Accounting cost center code District County or Parish ~State Alaska North Slope Borough I Alaska Field Lease or Unit ] Well no. Prudhoe Bay ADL #28328 [ 3-29 Auth. or W.O. no. Title AFE 203408 Drill, Complete & Perforate Operator ITotal number of wells (active or inactive) on this ~cost center prior to plugging and labandonment of this well I J Hour Prior status if a W.O, ! 1630 Hrs. I A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun ~ Date Spudded I 6/05/84 Date and depth as of 8:00 a.m. 6/21/84 6/22/84 6/23/84 Complete record for each day reported 9~5/8'' @ 9500' 9092', (0'), Drlg cmt Wt. 9.6, PV 11, YP 5, PH 11.5, WL 11.8, Sol 10 Cmt lnr w/325 sx Cl "G" w/5% KC1, .5% D-31, 1.2% R-5 & .2% D-6. CIP @ 0800 hrs, 6/20/84. Chg rams to 3%", Cst to 3500 psi. TIH w/BHA, tag cmt @ 8721', DO cmt. 9-5/8" @ 9500' 10,128', (0'), Modifying OS Wt. 9.6, PV 13, YP 15, PH 12, WL 14.9, Sol i0 DO to 10,128', TOH, leaving fsh in hole. PU OS, TIH, wsh over fsh, TOH. Prep to PU new OS. TOF @ 9066' - TOL @ 9181' - FC @ 10,236' 9-5/8" @ 9500' 10,236' FC, (0'), RR 8.6 Brine TIH w/OS, wsh over fsh, TOH, full rec'y. TIH w/bit & 9-5/8" scrpr, drl cmt to TOL @ 9181'. PU 6" bit, TIH, drl cmt ~-f/~,128'-10236' FC, tat lnr to 3000 psi; OK. Displ well to brine & retst lnr; OK. Chg rams to 5%" & tat to 5000 psi. RU & rn CBL/CET f/10,236'-9081'; good bond. Rn 218 its, 5%" tbg & lnd w/pkr @ 9142', tbg tail @ 9220'. ND BOPE, NU & tat tree to 5000 psi. RR @ 1500 hfs, 6/24/84. Old TD I New TD I PB Depth I 10,283' ] 10,236' Re, drig .... IDato JKtnd of rig ~ 1500 Hrs. 6/24/84 Rotary Classifications (oil, gas, etc.) J Type completion (single, dual, etc.) Oil ] Single Producing method t Official reservoir name(s) Flowing J Sadlerochit Potential test data Well no. Date Reservoir Producing Interval OII or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Alloweble Effective date corrected The above ia correct Signature I Date Title Drilling, Pages 86 and 87. AR3B-459~3-C Alaska Oil & Gas Cons. Ce;:~rn;ssm~ Number all daily well ] P e no. for e'aMY~,Zell~t ~ ~ as they are prepared hlst~~,cutlvely Dlvldofl of AtllmtlcRiehfleldCompony spepr .,-sun August 20, 1984 Mr. Randy Ruedrich ARCO AlaSka, Inc. P.O. Box Anchorage~ AK 99510 Our Boss Gyroscopic Survey Job No. AK-BO-4OO&O Well: DS 5-29 (SEC 11TiON R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: July 17, 1984 Operator: McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Muitishot Directional Survey on the above wel 1. Thank yod for giving us this opportunity to be of service. Si ncerel y, NL SPERRY-SUN, I NC. Kirk Afl lerbach District Supervi sot ka/AK Enclosures R£CE VEO oct o Alaska Oil & Gas Cons. commission Anchorage PRUDHOE", BAY ALA.,:,KA ' ................................................................................. S;F..'.E R R Y---.:~..:; L-IN.-W E-l.=b..-~tJR.'v'E.¥ .I NG-C.;0 HF"AN¥ ................................ A N C:I-..t O R A (:i [CA L.. i.."-~ S; !< A DA"I"f_:~ Of::' :i!i;IJl::,;'v'lE'Y JLII_¥ 1 '7, .1. ]L£O.N_I.'-';;$-~ .".~)l::lf.':'-U. :I:A/T-'.i-C::~N--[.~A:T:E ...... ~?.O:iii::i.::~.¥1:.~g~GOP I C. SL!RVEV .... ItJLY .t '.:;', .1. 984 ,_.IOJE;~ NUHBER AK--'BO-40060 KEI_LY F.~LISHING ELEV. = 62.00 Fl', ................................................................................................................... OF-'E[~.7:OR .... 1:.,---NGGM~IRE VERTICAL SECI"ION C:ALC:LILYATED ALONG MEASURED DEPTH VERI'ICAL % SEC::T 101', J 0 0.0 (') -- 6:;2:. 00 () (:) iq O. 0 E (). 00 0.00 C). 0() C). 0 () 1 O0 .1. ()0, O0 :E::E:, O0 () 13 ._ . 7'c.'~ 7c)o. ~ ........ ~~ O0 .O. . ~ 3 _ .%.~:i.~.:~S~_.E O.~..OZ .0..54._.S ........ O=~&~ ....... =O~SO ..... ' :BO0.. .· :900.0() .~ .z, o .'-"-' ""' O0 O. 5 S "~,. 0 W (). 17 ()..'77 S O. 31 E -0.7:3 50~, .......... 500..-00 ................ .4 .... ;.,. O0 ................. 0 ....... Z.3 ................ 1 .,,':1 600 C, 00 00 r~':":' ,:"~ 0 (] 18 f'.i ':" ";' .......... :,, :'::(] [: O..t/', (') '79 :E; 1 0:2 E '-1 ':"::~ 700 7cm. .................... (]c~ 6:38, o('~ o '?o I'.,I t::'~'~;' ,. :1.? E o, .... lA () . A2 .... E; 1 . f~:'::_ _ E -t . ....":~'-'::, .......... ':;":? . .~Z 8.00 75;:?-,..?.'~ .............. :Z~ ..................... 0 ................ . . ' ........ . b~O0 A99 99 """-' ,:,.:,7, 9"P () :,,::b~ N :94, J O E (), J () O =;'::' S '-' 99 E -2,66 ~000 'q":':'~ ?8 '~¢37,':'~:::: 0 44 S 80 ~::;0 E 0.:3~ 0 ':~;'=' '"" -':' ......................... :::, 4.04 E ...... t ............... ~O0 ............ 10'¢;'.'.:;~....'P8 ........ ~ 0~.. ?8 ................. O ........ 4.:~ .............. ~; · '72, ::;:0. E: .................. ~z, .1.1 ....................... O,-E~'7- .E;. = '"'' .... t ':'c~O~.. ~ J ':~':¢..... ':~7... '1. t3'7 . '77 A ....50 '.:~; ,I.P; , ("~ .... E o , :':::":~ ..... 1 . P;7_ '.:~; 6. ':":'...,,.., E --f=;_. 75.. 1300 1 '2';;"P. 9'6 .1. 2:37, 'P6 () ~ 500 14'P?. ""=; 0 S I '",~"~ I:{ 0 L/-, 4 :'~0 S ._, : ._, 1800 l r:'::*9 ........ ':),I 1=''''''',:,.:./, ':)., 40. :31 .:"" ................. ............ J ~"J- - - i,:.9&~-'74--- 1~7.94 __O .~.;¢ ..... '"' .. ~..?;0 E ...... '"' ........ ~,-G:4 ~:~ ~55--~ ............. 4~.,~ - . .... - ...... . ........... . -.. .-',-'- . .............. ~.~.~ ......... ... 18C)C) J. '77'P, 'P4. 17:37, 'P4 0 26 1 ?00 .1. '..:::?'..::'. ?4 183'7, ?4 2000 -- ~,9:~'~?-..:~l ........... 1-9~?-..'R t- 2100 20?9.84 20:37. :=:4 2200 21 '.-?':?, 74 21:37.74 ~--- 22.'R~2 ../~,5- ........ ~ 2400 2:3'?':?. 5? :::2:'-::7, 5? 2500 2477.55 2437,5;5 2~0D--___259i. -54- ...... 25:~--, 54.-. 2700 2/=,'.:x'? · 52 2/_',:E;7 · 52 2800 27'.'?'.'?. 5! 27:37. 51 '?~-00 .......... 28 S?'F'..-50- ........ 2837-. 50. 0 ':.::7 1'4 88. 1 C) E: 0.55 ,,-.,.~----f~ ............ 1 ....... 4~ ........N-4>:2 ....' ........ '~:' ARCO ALASKA INC. laS_ ii_B-2'~_2o:~ CiA__.Y.I.O iq .~f:~: 15EJ ...... PRUDHOE iBAY ALASKA .......................................................... ~P. ERR¥-~ -L~..-- WE.L-L --.S .l=i. 1::;~ VE:'¢ IN.G- -~] ~IF-.'.AN¥ ............................. A N C:I...I 0 R A G E A L A :!!i; I< A DA"I-E OF SI. JF?VEEY ,..It.lL.Y 1'7, · . ' .... .~'"' '"'" / '" "J-'-i-'.l'"lr~, · '"- ,'°'. ", "' ~_II..ILY J.':~ :I.'YF:4 ,J(.][~ NI_IHBER AK-BO--'40060 KELLY DUSHZNG ELEV. = .............................................................................................................. OR.BRA T O[~----:I:-,-.- J~U Z RE- VERTZC~L SEC:'r]:oN CAL.r:UL~'fED AL..ONG CL.K~SURF 62.00 F T, MEASURED DEPTH..' £OLI~. . COLLIi';:SE ........ I NCL I NAT I ON B I REC:T I ON SEVEF41 T'Y D E G bi I N D E; 0 R E E S I;) E O / 1 C) 0 :3000 "2 S~'.:?'?. 48 ,.,"::' ! OC) :'::(") ...... ':.";':."; .4-'7 · 7' 9:3'7, 48 I () :i.:.'; (!:. 5, :39 E:' 0 · .l '7 :'::03'7 .... , 4'7 I 6 ::S ,::....., ..... . ,::.'.', 9 E 0.. .11 RECTANGLII..,.AR C:OORD I NATES' :- NC RTH/F~F, rrH EAST/WEST VERTICAL. SECTIOI ) (). :.':': :1, S.'; :2:4.44 [= - :2'7. :34 1 ,, .'.!57 S :2:6. 12 E -.. 29. 12 · .:,._00 :F.:4'PC';.'.?2 ..:,4._::,.'P2 /., '-""" N 4. () ":::':> W 2,7/-, F; 61 I',1 · :, .:, .~ ¢)'-' = '=" ., ..... .=,Sz]:,:,'-'-=" '-' "='-' '-"~'-'~ =Y'" __'7_ .... 4Z .N._..,l. 5 1.?_..L4 ................... 3,.0.6 ............... 1Z).._.12"'..N __.__ ,, _ ,.-L.~ .............:.~._~t .,:.~ (:', .,~ .~..,.- ', ............ :3600 "'"'="':' , =,::: 9 :=4 N ':" · :,._,: 7 "" - ':' 5':' ~ ".? ::: ·., .1. '=,":~ 14 :3.."2:A 14 '=:' ::: I',i ...., ,_ ..! ._ # ..... # .. .... m, . :3650 '::A47.27 .---,5o~. '-. '-(" 2. · _ _ .: .... =,...27 10 12 N 52: ,:, _) W 1 'i.:' 2C). 1-4 N ___£__.~:700 "a/-,9/=,, 34 '="'=' ':" ......... _1-1 ....... 50. N .r..~,= .... ,,-> .-, .-, .-,=- ,'-,'-- ...... ~:,.; ...... W ............... ~._.~& .............. .,~o. Y.-, ..N ..................... ~_,=-,~ 4_._ ,~. 4 ............. · :.,::,t)O :3793.79 :37:'-':1. '7':.=* 14 1 N P,!"',. :::::':>_ .. W ..-:'"'. :32 ..."::":'.. . (")(").. . N 3:~'~(3C) :':i;:i3'?C). 24 :3:=:2:_=i:, 24 :1./',_ :=:,'=, Iq ,:'::,..':1. . 1.(").. W .::,', :=:/-, '::'"'"....,.~.. (_')4 I',1 4000 _.__3'~2~.5L. ,"-,:'-~ ........... 3'?':;':=',..d,:'"', ....... 1;3 ....1 -F_~.____N_...6'i:2.._.I_'::2 W_ "::'.. 26 ....... ,S2...~/=. lq 410CJ 407:=;'..'F'4 4C) 1 '7, ?.?4 20 '28 N /=,:3. :39 W '2,5"'(:~ 75.72 Iq 4200 4172.91 4110. 91 2:2 4:;"' N 66, 6'P W :,7.'. :37 :3'=?. 6/=, lq .............. _430L~ ........ .42,S_q~.40 ...... 4 20'.'-:' ..4,0 ............. 24 .....51 .........b~. 64 '. ~9_. W .......... 2.2'?- ................ 106.2Z Iq 4400 4:::!-=;4. ()7 ,12'P2. C)'7 '27 4-() I',1 .:!:.::~:. ::'_';(.:, [.i 2. :.:.-:'7 12'.!'_';. 62 N 4500 4441.6L=.': 4:37'F'. ,'-'-,;:: 2'? 5./:, N 6'2..l ':;' W 2, 36 14'7.6':? N · ::.' 7.26 [--- · --, ."~ "I:.':' -- 17 ._4 E 10. ':."1E 3...32-E__ ,~ '-"J W :37.75 W -:=.a') ,_ 6'-'-Z .... -- 30.4. :3 -2.&.-33 ...... -- 22.5 :!ii: -t7,71 -4.27 4. 1":' 13~:,::: __. 3/:.. 02 62. (.')4 5'-O-,.B;? ) .... · .' ..'. ~6 15'Z. 72 ...... i 6-Y--..-.O':-J-..W ............. J, 96...'.Z5 ........ 2C),:'"_-,. ::.? 1 L-J :2':'::'i~'~. 87 24'P. 67 W 2:87. C) 5; 4600 4700 4800 ........ 4900 5000 5100 5200 5300 O. 16 , 0.4.,'.-, .!'7"'..:'. 4:'=": N '_.--:'95_- 22 W 199.6:3 N 342.71 W 2:27, :=:9 Iq 390.7'7 W '256._',~CL1~1 .... 43::." = 52. W 2::36. C)7 Iq 485. :=.,' 1 W :Z:15.67 N 533.18 g :::;4~. f=;:F:._l',/ "'-;:~:0_ :7'7, W 375.5'5; N 626. 'PO W 4.0..:,. 59 N /_-,73 2/.-., W 338_- !.2 · --, ~ .'% .:,.-. ,:. IF.._ 447.30 502= 69 _ --. ._l .._1 / i . /_-. 1 :=:. 28 F-./-,:~-/-,:=: ...... 723, o.-, 778, 79 aRCO ALaSKa INC. PRUDHOE:BAY ALASKA ...................... ::;F'E:RR.Y,-:.SUN .W[i:I..-.,.L=....E:URVE:¥ I. NG--~;~MF'AN¥ ........................... A NC t.-i 0 R A (} E A L A S I< A ~ DA'T'E OF:: SI...lt;:VE:Y ,JULY 17, pn,:::.,::, j'~' ,j:',[~::.~ '::, T SURVEY JI...ILY 1'2, I':4h34 ,JOB Nt..IHBER AK-BO-40060 I<ELLY BLISFilNG ELEV. = VE"RT I C:AL .:,E ...T I (iN CAI_.CI...il....ATED A l_ CI lq (:.i (::L.O::~;I_IF:~E 1984 62. O0 FT. MEA~,L RED DEPTFI TRUE .................SUB= SF,:A ................. C OUF.~SE ............... E.£:l LI F~ ~ ..................... DCI G:::~ LEO VERT I C:AI_ VERT I CAL I NCL I NAT I ON D I REC'i" I ON SEVER I TV I:;;EC:T'(qqGI...IL. AR I)EF"/H DEPTH BEG M I N DE2 f'gRIE E S DEG/1 O0 NORT'H/SCILI'T'H 5700 54.4:3.76 ='-"-'...,. :,,::, 1 ,76 ~a¢]O ,::.:=:..?-7 ..;,--, ,:,;ii/-.,:.: "7,.-, 5900 '=; ':':~=-" '-' 67 .... 611,67 ..... 600 cl. =" ' ":~": =' '-"---' o 1 · ._, c, .~ ._~, 81 .J 6.z, o, "" ............. 6100 ........... 5779..75 5.7-1.7,, 75 ............... 6200 ~i:~/-, :':.',' ........... .::) ,:", ( ! 1 ..... · -~ ' ") , .4:,..:, 0 t 5':;47 .... ::,,:,...,, 4:3 .~,400 ........ ~,03..1 ,.Z.:'~ .........5':?, '~....,-.,~. ":/ "':'E',. I",l !:'~7. ::i::C) W C), J.() 46,.':I.,, :3::.:.': N I',1 57. () W (),, :::::1 4'F'4.4C)I",1 !&-~.. 60_-}~ 0.~':.:"? . .....5~l-&_ N N Y':/',. ICJ W O. '2'::? ....,._,4..,a.:, N ....... ::,4.66 N N ~=:::" 7':) .... · ,.. W c) 45 . ...... ,. IO.-W ................. 0..69- ......... 615.64 N N 54.6':::' W C). 38 6 '..I 7. C, 5 N iq 54, '..-::~0 W 0.06 67 :::~. 4..<'t I',1 .......... ~.~ ...... .4 .............. 14-.~:,4 .... 00. W ............... 0.- 13 .......... 70 ? ...:~5-. N ............. I- 124...~.0 .... C:O01RB I NATES VERT I C:AI_ EA / WE.::,T oEL. l I '7 6 !1.3. 1 '7 W ::::::'7.5 (3 810. '.:.;' 7 W ':941.75 ::356:46 W ~~ ....... '.::)01./_-,5 14 104':.:,'. :-?2 946. :..:.::2 W 110:3.7:::: · 990 .- 98'.- W ...... 115:3.00 10::35.66 W 1212. '5() 10(::0. (.)GI W 1 2Z::,./:,. 71:: W .............. 4:..--;21. I ,s ...... =~_ (' - ..-:,.::, 6,.. JO 6,11 '= .... :23 /**-., 0 f5 :':: . .o .... ~ ,% ,,..~ 6600 6199. :Z'::2: 6137. :3:3 .......... --&~]O .... 621~3. 57 .............. ~.1.. 57 ..... i'* (' ' 6,:, .) .6 ,.-'.200 d-. .- 7-QO.O_ =""-' --6..,,~.,. '::' '~:' &475,.'?~ ................ ,~ ..,.. ~ .......... 7100 /'./-,2::: :?5 ' ~" ....... (:, .'] 7200 67o8.75 6646, 75 ........... -Z"-~ .........~ 79':.'t .42~ - &,,_..:,.,~._4 ~'~'-"-' "" 7400 6::::8C). 27 ,'-'-. ::: 1 .'::-::, 27 7500 ,.':,':766. 4.1 6'?04.41 ::.:::2 45 Iq 5.4.. 19 W (). 4. 6 741.4 :32 45 N 54. 1 () W 0.0A 77:3.0'.-:;' 32 ....26, ...... :--.J~...54 .. 39'. W ................. O-....3& ............. 804~56. 7:2 '-? N 5:; ,lI .l (") W (i ":"":' ,-,.'-,,:::' '7::::: .... · .... . -_, ~:,. ,7) -_') ....I · · ... :':.': 1 5 ? . ...... .,.--. i',1 54. 1'? H ()., ':.:'o (366 :::'; · .... :::9'7.- _' ........ 31 --2~ .... N..,. ,.1, ("i. W 0., ' ...... ' .......... . _ _ ........... ,.=.1...-:., .... ::.31 2:3 N 5,1. 1 ':? W O, 12 'F,'28.2.'::.. :-41 6 N 5 4. 10 W O. 30 '?.5::.:.:,/-,'-i ............ :'31 .... ............ 0 ............. 1',1. 5.'-1., O. 14 ........ (),-.1 1 ..... ,--,c,c,; 30 49 N .54. 0 W 0.2:3 10.'1.9.07 30 19 I',! 54. 1 '.:-;' b,i O. 41. .1· 0.4:3. .......... _7--6~0 7 700 71:3 '.--.,'. 8:3 7800 72:2:6,. 51 ........... ~00- ....... 7:_-.--' 1 .'2.-7-1 ..... 8000 7 :::: 'P ::-:: . 6<5 8100 7484./..:::: ;Z_..~,._O. :.'.-.-~ 2: .... '~:~ : 4- .... c,. 1--, ~00 '~ ~-' = 8400 77~:2, 41 ............ ~0.0 ........ '782:'--..04 ....... --.7052... 9-7 ............. &?'-?~.-':A7- 2 ~ ...... 4~ .......... N--~., .:1-.-~U -- W .......... 0 .. 57 1.070 7077 :::::: '::'9 .:,c, N 54 1() W 0 24 ll(-)A, 9~ '7164.51 :30 I0 N 5:3.60 W 0.59 11:36,:36 7-'~c). . ...... .~_ 71 ...... 30 .4~ .... N-.-5'~;,50-N ............... 0,79 ....... 1166,84. 7:3:36, 66 :30 4,1 N 51. :30 W O. 61 I :1.':?:::~. :3:::: 7422.6:2: :90 4 1 N 5(:). :::::<'.~ W O. 51 1. '2'::::0.66 hi 11/'-' 84 :,,:,, W 1 :.'-: 75.40 N 121"'.~.70. W 1429.44 N ....... 1-".~;4.-42--- W- ':"-' ":'-' ......... 1.~:b~.~,..~.a- .... IL%' .--~ I:.=' ,'" N 1'?'::~'::) '7'? W 1. ,.-,/', N 1:34- ::-2.82 i,4 15 :_:.':'.? · t-. 1 ..<,.~ ..... .-4,.,. N ...... 1 '-"-'~"" ' .14 ............ I',1 ~ 4.27.6:3 14 ! 6:-?4. 1 (:. N 146'!:). 67 W 1745. Iq .......-;I .511.. 42-W ............... 17:.-? 7.-48 ...... N 1· ,. ,.,.- .55':'.' '.-72 W I (:..:4::_: · 71 I',1 15 '.:;' 4. O 6 W 1:3 '.:;"?. 4 :.3 N ....... -1 ~:4-.-74--Id --,[-5'.4-':-2-, 4&'.' ." ' lq 1674. '-?':' W.. ,_, N 1715,24 W '204:::. 70 N .......... .:!..-7 ~ ,-75 - 14 .......~O'.Z,~', bi 17?5, '?7 W '2.'.[ ~t-.~, 47 N 1'-''-'~'~ .~:;~ W 7-"2'c~1 '.-':":-- ,--:,. -:,...! · ........ · ._.~ --7--~01~Ir3-7 ............ 31 ..... ]..r-~, ........ N-- 4'::;'-. A~. .... -- W ......... (~.&7 ....... 126:3,77- 7~94.._. 15 90 :::7 N 4.:::. :3'? W O. oc.""'~ 12':;'7.4'F' 7680.41 :30 8 N 47.60 W O. 6:2 1:3:31. :3:3 .77~7..04 ......... 5?9. -. 4:3 ........N. 4,S, 09' .W ................ 0, .4~ ...... $.365, :25 .lq ........ 4074.-.'-.:;:4-.14 .........22 5:;~,.-'.::z,i:;, ..... I',1 1913 · 74 W 2:304, :.-::6 N 1951. :3:3 W :..'.'::::54. :.-3<.':, N ........1 ~:E::.'.-:-:.,-02-W ........... 2-'404.7.1: ..... -z:.F:E-'.Rf',~-¥- ..-.:_,...IN-..-L~. z-:L_.I.::-,~:I.:JF~ Ib.:¢ INt...:-.-~..~. l..k~z~N-Y.. .................................. ~:~.-.-,iE ..... -4-- ...... A N C H O R A G E A L. A ::2; K ~ ARf":Cl ALASKA I NIL'.:. D(-tTE OF:' St. JRVEY JI. JLY ! 7, ! '..T,' :7.-.': 4 F'RUDHOE BAY ,_ilJLV I9, 1';,'84 dOB NLIMBER AK-'BO-4006C) ALASKA KELI_Y BLISHING ELEV, = 62. O0 FT. ......................................................................................................................................................................... OF'ERATOR-- -T. .MCGU!RE" ' ' VERT' I CAL SE)-:T I (iN r".:AL.(i;:I...ILATED ALFJNC; CI....(]:i3LIl:i'[.i:'. MEASI,.!RED DEPTH ' - :I'EiLIE ............ ~--_' "SF_.~-~ VERT ! CAL VERT I CAL DEF'I'H DEPTH . ,:,F.:: k, ER I 'f'Y I NC:L. I NA"r I FiN D I F,'ECT I EII',I '- .... , .. , DEG M Z N DE:r..~F;:EES I]EC.;/10() 'i '. :i ..::' VER'f I C:AL, : SEC:T I 0 245:3, 71 25; 0 J.. ('):2 · -i t~'. · 2642.07 2/~9-4..44 ...... 2750.20 ':7809.22 ...... 10000 1O1O0 10200 - ~,-,.~ 'T,"4 (')(') .z,.,.,.:.,_.~_.._5_4: ............... ,-:: ~.o1.. .._,. _t .............. .40 ..... L,.~ .............. N__.4..1. EI.O_W ............... '2..._4~ ......... _17_Q.~_...6;'-] ...N_ · ~ . . .... --.-,,~,,~,. ~ ~_J~ IAI _ ........ ,:.::; -'", 9500 ::::/-,/-,:::. d,,'_:. 86C)/:, 66 42 21 N 42 1'::;' W 2 15; 17 .... _-, .,.:,..:., Iq ,:~ .... ,_,. lC) W 9600 8741,7:3 :3679, 7:.:-': 43 40 N 40, :=:0 W 1,64 97].fLO_-- .....E::31 ''"' ' ' . -. .:,,.4(:,_ ........... 8ZSJ[_,~.&ri ............... .... .". L--_I '--~' 9800 8:38:3. A:.-.: ,-..,,:.,....1.. 6:.'-_': 46 '7 hi .............................. ::--, 4.4. 0 1 '::*¢'¢'~0 ::::':~5; 1 ,S0 ,_,'::":":'c;',_,,.., .../.,¢"~ ,I 8 .1. :3 1'4 40, :1. ('~ W "::' ~"~'~.:' 19,::.,:::::. OA N '""": '"' · .. N ':-:;'O:S; 1,4/_-, '::;'019.46 50 ~"18 N :.":;:'ii;'..5C) W 1,5'7 2(:)::::4. '.:.;':3 iq 2637, 24 W 914:3. '7-.-:.. ? c) 81 7'.7: '='- '-' ....... .- .......... "-.?1~.4_,.:3 L ....... S'.'.~.81 52 .... O ........ bl_ .~, ,z,'"" '-' ..... 60.. W ........ :. EL._~ .........~..L5'.6..~ F'-:7. N-- ....... _2:'~9_._'F,7.L4_ W 2871-._4-J ...... · -., ,D .'D/. :300:3.7:'"": 30-1~ .... 3 ! 42.27 :3214-. :25 c, .':, /. .':, 3 L ._, ._, _t ._~ · :.7::439, 80 '35Q2~,.A.4 HORIZONTAL DIS.;PL. ACEMENT = :350:3. c"',4 FEET (",'T NoR'rI-I 51 [)ECi. .1. C) MIN. WES"F A"r MD = 10283 THE CALCULATION F'ROCEDURES ARE BASED ON THE LISE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. . . ,. ...................................................................................... SF'ERRY=SLIN.- WEI.....L~-. SUR VE Y-I-NG -(-}E~f,~:.AN.Y ANCHORAGE .Al_ At:.i;KA DATE.: OF SURVEY ,..IUL. Y 17, 1 '..'.:h:-:;4 T 10N._I~ 5E ) ,.IULY 19: .1. '?::':':4 d()B NUI'IBEI:;: AK-BO-400/_-.O KELI_Y BUSHING ELEV. '= /_-.2, OC~ FT. 4)t;;:ERA::I:' ARCO ALASKA INC. _ f]F;_t 3=29(SFC£1 PRUDHOE BAY ALASKA IN]"[-'.'.RF'OLATE[~ VALUES F:'OF:( EVEN :1.('~O() FF/ET ElF MEA:..::';I..IRE[:) DE}:'TH MEASURED ] R LIE SI IB-F;EA TOTAL VERT I CAL VERT I CAL F, EL. YANbL I....AF~ f' F,"iRD I NAT F'.::; MD-,TVD VERT I CAL " "' - ' ~_ ¢"' ...... ~-" : "' '-' .......... ' ..... ' ...... ' '1 -' ' - '" ' "' .DEPT_H ................ _.EiEE_T. FL ........ _J~.OR:EI:L-oL~UI.H ............. ELA~I-/.WE&I _.D.I.E.':I::EJ:,.EIt.,IL:E ....... L:L t.~,I:',:E:L::LILJN 0C) 0.0() 0.00 0.0() ,:;,c, _Q.,.~._.S_ ,4.,,_0-4- E 0..,~ .0 c'~";, 91 6.19 S 10.94 E: (). O'F.' 0.0'7 48 0.81 '..::-.'; 34.44 E (), 52 0, 4.:3 63 .................... 6.3...8/.-, -..N .................. &,5...2' 7.-- W ................. 1~ 4..,~'7 ............................... 1-:~: ,. :'_-:: ~.- .................................................... 5000 4:359.89 4797.89 286.07 N 4.:---:5.91 W 14(:). i I 125.74 6000 56'i;'5.81 56::::::. 81 584.66 h.I '.:;' 4. (.":. . ::.:.:2 W ::.:.:()4. 1 ':."'~ 164.07 .............. --ZOO(') __&53'Z.._~22 ........... &4.7-5. 8000 7:3'F~8.66 7:3:36.6/_", 11 'F/8. :38 N 1 '7'.~5. ?.;'7 W ./:,0 .t, :34 1 ::-:'.-.-/. 26 9000 8268. 17.;' 8206.19 1534..51 N 2156.4.7 W 731.81 .t30.47 ............. _.[O0_O-O ..... : .... 9017-...44 .... ................... ~.u.~..~-._ ./..;l.. _ N '""~-"? ....'"'" ...... ,.::,o =. o .... ,:.~: W .............. :i'):~2,-5& ............... 250..7~ 10282: 9'19'4.8;I. 9'132. :-:-:1 21'.:;'6.87 N 2729. :_::,l W lC~::.-_.::.:.i:. 19 105./_-.3 ........... ~:EIF~ULCLT..:D3N_F:.'.iRQCEDUI~E~.- A~2E-._Bgg:gEO ON ~:H:~g--LI$B-~E-~:l~HRE~-D.~.~`44g~IQNAL~-~:~D~J:ii.:~-~F-~-CL~4.~/AT.URF~-.~z~T~.~.~D. .---- .) i. ~PERR. Y,---~L~N WELl= E;URVEY t NG F;OtqF'ANY ARE:O ALASKA INC. DATE OF- St...IRVE¥ JULY 1'7, 1'.-784 F'RUBHOE BAY ,_IULY 19, 1984 ._lAB NUMBER AK-.BO-40060 ALASKA KELI_Y BUSHING ELEV. = 62.00 FT. INTERFULAIE[ VALUES FOR EVEN 100 FEE'1" (]F' SI_IB--.'.-::EA DEF']'H 'T'RI_bl- MEASURED VERT I CAL .DEB.TH .... DEE'..TH ...-,UE -.:,EA TOTAL I.,.I.]L RD I VERT I C:AL VERT I CAL RECTANbL L. AR NATES MD-TVD ..... I3 ER.TH ........... J_x. lu R T H/_~.u LI :tH ............ E~S.T/_WEST ..... D.IEr~RENCE ......... %ORREC.~N 0 0 · O0 --62 · O0 0. O0 O. O0 i,2 ____ 62_,,_OJ:! ............... i62 162.00 100.00 0.41 5; O..t:3 E 262 ,.6.~.0C) 2F)O 00 0 7:3 S 0:31 E .................... o6~ .............. o6,~..00 .. ~,O.U. O0 ........................ ' '""> '~' 4_,~ 462.00 400.00 1 00:5; 0, 4m7 E 562 562. O0 500.0 () O. 8() S (). 8:2 E ........ &A2 . ..... 662._00 .......... ~0._.~__. 762 7 A_ 2.00 700.00 0, 48 S 1 . '=',_,,_.c' E O. O0 O_~O0 0_._00 O. O0 O. O0 O. O0 O· O0 .................... 0..00 ................0..00 ................... O. O0 O. O0 0. O0 O. O0 O-.--OO- ...................... O-.-OO O. 01 0 · O0 0.01 O. O0 ........ .:~62 ............ ~62. O0 ................ ::~.0. O0 ...... 062 i r'-) A 2.00 I 000. 00 O. '7.'2: ::2; 4 · 8:2: E 162 11/-._,,_?. O0 11 O0. (')("~_. 1 . 18 S .,.':"_. '::~:::::..._ E 2&~ ~ 7_'6'2. CLO_ ...... 1_ '..-:'('~0.. OO. 2 ':._21_S_ ......... · -- ' .-f~..-I # , ~ # :.462 1 ._-, =,~. 00 1:300 O0 :.4 20 S 7 · 4? E 4~2 1462.00 1400.00 4.00 S 7. ?5 E 1~ 1~/-,'? Or) 15tOA~O0 .... 4._~B "-' ':' ....... ~..~l ........................ ~l ................ ........ . .................... 1662 1662.00 1600.00 5.58 S 8.54 E 1762 1762. O0 1700. O0 A._ 27 :::; 8.._,'='"):, E ARCO ALASKA INC. .../3':..L_.~ PRUDHOE BAY ALASKA .:J N---W E L-l=-~ U R VE. Y-t-NC4--~ 0 MF' A N Y ........................................................................... F' A GE A N C I"'10 R A G E A L A f:i: K ~ DA]"IF' OF:' SURVEY ,_.II._ILY 17, 1'784 COiqF'I~£TA.'T:Ii 0 N_ DA~i~]~ ............. ,JULY ].'.-.-/, :1.'.:.;'::'-:4 ,_lOB NUMBEF:;: KFZ[.LY BLISHINC; ELEV. = 62,00 FT. ..................................................................................................................... OF;'fEI;:;; MEASURED ..DER. TH I N'I"ERPOLATE[~ VALU[-.":S FOI:? EVEN .tO(_'~ I:::EET' OF:' F.;I...IB-Sli.::A DEEF:'T'H 1" RUE .'::-;LIB-. :SEA TO TA L VERT I CAL VERT I CAL RECTANGULAR C(:,],RD I NATES MD--TVD VERT I CAl._ .) .. I3 E E' T. H ..................... DE RI:H ............. I',10 R TH / S 0 UT H .......... E: A ~; '[ /W E $ .Y ....... D. l F; F; E R E N C: E .......... i:: [ :l I:;:R [~ C:].:-,1:0 N .............................................................. ,_, 6 .. 1 :::/., 2. o 0 1 ::.: o 0.00 ...... 1 '-?A ? __i:~D_O ......... I_?E~O_..O0 2062 206'-'z., 00 2000 , ()0. "2 i '62' 2162,, O0 2100,00 .......... 2262 ........ 2262. O0 .. 2200. O0 '":"--'/- '-" 2:::/-,2, O0 '-"-' ' ] .... ..-.._:, ¢.l (. ,.. ,.., _l ,,~ u ... 2462 2462. ()0 2400. (':)0 2.40 S ............. (). 02 N 1.71 N 2.24 i".~ 2662 2662. O0 2600. O0 2762 2762.00 2700. O0 ........... 28 -/;,2.' ........ 2862 ..00 ..... 2800, O0 :2'F.,62 :,?.76';:'. 00 2900. ()0 3062 :3062.00 :3 C) O O. O0 .......... :~A~,2 ....... 5l ,$2.,-00 ..... J~.~ 00 ..00 ::<262 :_::;.--:,'-,2, O0 :3200. O0 :3362 ::::362.00 :3300.00 .............. '-P.~4&2 ..... 3462 .. O0 ........ ~400. O0 356:3 :3:'::;/_-.2. (lO ::::.500. O0 3664 :'::,,'-,/-,2.0() :13600. C)(') 1.76 N 1.O:q N .................... iD, -2'7. -N .......... (':~. 54 :::i; .1.. 2'7 S ....................... -~..-14- .... ~3 ............. '-' NO '.:-] · .%... '-" '.;'2 S ":' ~j; N ......... .,h,-~ ..... :l 1.4 :,.:.' N 21.76 N ,::,. ,:.,.::, E O. 06 r) O0 ':;'_.::;'_].__':EL .................. 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Ja ........ )-- 1 ) F:ROH I_ ZNEAI:R li:~X'f'i'~Af'-'Eil_.~:'~'l'I Obi [-:diiilL...ClN I~d2EF:'['{:S'T S. ' I" i:', '[' 101',1,, :2) COMPUTER F'ROC4R(~P'I .... ... DATA CALCLIL~~'~D_.._~4TERF~Z!L~r~'L1 K:OMF'LII"AT'I' r-)l'-,l DATE .... ~LILY 19, 19;34 D~C[~Z_f_'iF '.K,;IIR'~'E.Y ,___ILILY ._10[-;~ NUMBE'R ~:~t::.'--[¢--~---400Z:,O t::'lr:! i Y RI I::;MI'NI~_ [::1 F~/_ := d.,'.:'-¢')(3 F:'T . TRUE NORTH ARCO Alaska, Inc. ~'~ Our BOSS Gyroscopic Survey ~ Job No. AK-BO-40060 ~ Well: DS 3-29 (SEC 11 T10N R15E) ~ Prudhoe Bay Field ~' North Slope, Alaska '~'"'-, Survey Date: JUly 17, 1984 Operator: McGuire Scale: !" = 500' 3503.64 ' @ N 51© 10' W · · -~obo. oo -~bo. oo -~obo. oo -,~bo. oo -,oho. oo -,. -50~. O0 HORIZONTRL PROJECTION 2000,00 -1500.00 -1000.00 ~00.00 Surface Location 545 FSL 7! FWL -500.00 0.00 2000.00 4000.00 6000.00 8000.00 10000.00~ 3503.64' @ N 20bO. O0 ARCO Alaska, Inc. Our BOSS Gyroscopic Survey Job No. AK-BO-40060 Well: DS 3-29 (SEC 11 T10N R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: July 17, 1984 Operator: McGuire Scale: 1" = 2000 * 10282 51° 10' W '~&o. oo VERT I Ct:::IL PROJECT I ON Suggested~ fo~ to be inserted in each "Active" well folder to d~,eck for timely ccmpliance with our regulations. ' ' ' Operator," well N'am~ and Number Reports and Materials to be received by: Date .Required Date Received Remarks . · Ccmpletion Report Yes /~ _~ .~..~_ ~ '. · __Well. History Yes ,. Core Chips -' /~/~"q/~-': ------"--- ~ K\ Core Description ~Z~ ~ ' ...... ---' d '~ Registered Survey Plat yC~ Inclination Survey ~d Drill sero Test Reports ~/~~. · Digitized Data j~'r ARCO ALas'ka, Inc, F',(:)~ Box J00360 Anchorage, A £a~'l<a DAl"E: S'epTember JS~ J984 Rli:'F'EFiE:.i'.I~,E:. AF;".CO C.'.a.sed 1"1o ke F:'ina I..s D.S'~ J3-6-~ 6-23-84 D ,. ,S' ~ i S -98-~' 7 - 8- 84 D~S~ t:3-'9~ 7-8-84 D,.S~ t 4-.i 0~-- 8-.4..--84 D S I 4'"'28 ....", .... .", ", .._ o ,~ D S' t~; t6~ ~ ~ ., .... 6-'27-84 D ~ S ,.i 5-t 6~ 6-28'"'84 D~S'., t5-t6~ 6-28"84 D S t ':~ t'7~ ~ "~' .... ~ ~ .~'" , "-,,..4 D,. S' . i ~ .... t 7" "', -' ~,. '~ ~,. '~ -' ,.,° ..~, D,.S'. t'5 .... 1'7 ~ 8"-2-84 D ~ ~~ 't.., ':~' .... i F ~ , ,.~. ~.. ",_,.,. D~S~ t 5'-J'7~- '7"-2t -84 D~S',. t5 .... t'~ 7--2t .... 84 CBI_/VD EPL. DIL. Mon i to'," C.N L.. C H ( E !::' i t' h e r m a L ) CNL CH ('Fhermai.) CCL./F:'er f Record CCLtI:"er 'f: Record [;CT [;yro I.,JeLL S'u.*"ve':,., CBL./VD C:CL/Per f Fiec o.*" d CCL/Per'f: Record CBI.../VD GCT Gyro WeLL S'urv'e'>.' C E T L o g C E T L o g ~ CBL./VI) "~--J :sign and re'l.'tirn '~he at't'mched copy a:; r'eceip'~ Recei red i-IAVF.': A NICE DAY! !< e L L y M c: F' a r L a n d P, ta~ O~i & ~as Cons. commission A T 0-- i 4 2 9 F' Anchorsge TI:iANS. :~.367 o f d a 't' a ~ I) I $ l' R I B LJ T I 0 N Chevron ExpLoration Ser¥ice~' ExTens'ion ExpLoration Ex xon Getty Marathon Mob i L Mob i L E & F' Phi LLip~ F:'ruclhoe Bay WeLL R & D S'oh i o State of ALaska Fri Le.s' ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 9, 1984 Re fercnce.: ARCO Open Hole Finals D.S. 3-29 6-19-84 Prolog 6-17-84 BHC/Acoustilog/GR 6-17-84 DIFL/GR 6-17-84 CDL/GR 6-17-84 CDL/CNL/GR 6-17-84 GR 5" DA Run 1 2" & 5" run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 5" D.S. 3-2~~'~ 6-1-84 6-1-84 ~,~ 6-1-84 ~ 6-1-84 6-1-84 6-1-84 6-1-84 CPL/Cyberlook BHCS Borehole Profile DIL/SFL LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) CH GR Run 1 5" Sch Run 1 2" & 5" Run 1 5" Sch Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" D.S. 12-22 5-30-84 ~L Log 5-30-84 BHCS 5-30-84 DILL .... ~-~u-~ CDL 5-30-84 CDL/CNL 5-30-84 GR 5" GO Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5~; Run 1 2" & 5" Run 1 5" ~~Please sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO-1429F Trans. #248 DISTRIBUTION :>~evron D &~M Drilling Exp. sez'~ic-e~ Ext. ~ploration Exxon ~tty' Mob i 1 . Oil & , ~Sas COns. Commission M0bil E & P nchorage Phillips Prudhoe Bay Well Files R&D Carolyn Smith S~ io ARCO Alaska, Ih.. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 10, .1984 Reference: ARCO Magnetic Tapes /'~~____~2-3--84-- TDT-M--~swer--~s_ting Run 1 Sch ~z D.~-14/ 4-23-8~ ~%-M LIS ~6919! w/listing Run 1 Sch ~ D.S. 12-27~ 3-3-84 OH ~69243 w/listing Run 1 Sch ~ D.S. 12-27~ 3-3-84 ~T ~69243 w/listing Run 1 Sch ~ase sign and return the attached copy as receipt of data. Have A Nice Day! Kelly McFar land ATO- 1429F Trans. ~264 r '., DISTRIBUT ION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon' Getty Marathon Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith ~'"-'" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address p.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell At surface: 545' FSL & 71' FWL, Sec. 11, T10N, R15E, OM At top Producing Interval: 2301' FSL & 2290' FEL, Sec 10, T10N, R15E, UM At total depth: 2742' FSL & 2658' FEL, Sec 10, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc~) 62'RKB ADL 28328 ALK 2326 12. 7. Permit No. 84-79 8. APl Number 50- 029-21118 9, Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-29 11. Field and Pool Prudhoe Bay Field 6. Lease Designatiorl and Serial No. Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 8-9-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 9620'-9640'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun #2, shot interval 9600'-9620'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun #3, shot interval 9572'-9600'MD (6 SPF). Shut in well, POOH, all shots fired. Secured well, RD. Ref: BHC Acoustilog 6-17-84 RECEIVED SEP 1 3 .~,nch0rage 14. i hereby/eprtify that the foregoing is true and correct to the best of my knowledge. . Regional Operations Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ..... '"'~ STATE OF ALASKA ~ ~=r~ ALASKA L,.,-: AND GAS CONSERVATION CO~·.MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of Well at surface 545' FSL, 71' 99510 5. Elevation in feet (indicate KB, DF, etc.) 62' RKB, Pad 28' FWL, Sec.11, T10N, R15E, UN 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 84-79 8. APl Number 50-- 029-21118 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 3-29 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of. June ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 1630 hrs, 06/05/84. Drld 17-1/2" hole to 2500'. Ran, cmt, & tstd 13-3/8" csg. Drld 12-1/4" hole to 9530'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 10,236'. Ran 0HL. Ran, cmtd, & tstd 7" lnr. Displace to brine· Ran CBL. Secured well & ER @ 1500 hrs, 06/24/84. Displace to diesel. Ran 5-1/2" compl· ass3/. Leave 9-5/8" x 13-3/8" annulus open for injection w/non-freezing fluid for protection· 13· Casing or liner ru.n and quantities of cement, results of pressur9 tests , 20" 91 5#/ft, H-40, weld conductor set ~ 80' Instld w/1875# Poleset , · · · 13-3/8", 72.0#/ft, L-80, BTC csg w/FS ~ 2500'· CIP w/2000 sx CS II1 +400 9-5/8" 47.0#/ft, L-80, BTC csg w/FS ~ 9500'. CIP w/500 sx Class "G" cmt. 7" 29,0#/ft, L-80, BTC csg f/9181' - 10,236'. CIP w/325 sx Class "G" cmt. sxs CS II. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/GR/SP f/9490' LDT/CNL/GR/Cal f/9490' CBL f/10,236' - 9081'. Gyroscopic Survey. - 10,264'. - 10,264' (GR to 2580'). 16. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED JUL2 6 L984 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge.. SIGNED T L."~~ T,T,E Area Drillinq Engi neet DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· r-~.~ ~n_An~ .IMM/MR1.5 Submit in duplicate DS 3-29 DRILLING HISTORY NU 20" diverter. Spudded well @ 1630 hrs, 06/05/84. Drld 17-1/2" hole to 2538' Ran 66 jts 13-3/8" 72#/ft, w/FS @ 2500'. Cmtd 13-3/8" csg w/2000 sx CS II~ + 400 sx CS II. ND 20" diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000~-psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.2 ppg EMW - ok. Drld 12-1/4" hole to 9530'. Ran 228 jts 9-5/8" 47#/ft,w/FS @ 9500'. Cmtd "G" cmt. 9-5/8" csg w/500 sx Class Tstd csg to 3000 ' ok Drld FC & Psi . cmt. Drld 8-1/2" hole to 10,236'. Ran DIL/BHCS/GR/SP f/9490'- 10,264'. Stuck LDT/CNL @ 9713' Stripped over wireline with DP.PUlled tools free Finish running OHL. I'DT/CNL/GR/Cal f/9490' - 10,264', GR to 2580'. Ran 26 jts 7" 29#/ft f/9181' - 10,236' Cmtd 7" lnr w/325 sx Class "G" cmt. Drld cmt to 10,128' Twisted off BH~. Fished and recovered all BHA. Drld cmt to 10,236'PBTD~ Tstd lnr lap to 3000 psi - ok. Displaced well to brine. Ran CBL f/10,236' - 9081' Ran 5-1/2" completion assy w/tail @ 9220', pkr @ 9142', & SSSV @ 2161'. 'Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 1500 hrs, 06/24/84. Displaced well to diesel. Dropped ball & set pkr. Leave 9-5/8" x 13-3/8" annulus open for reserve pit fluid injection and a non-freezing fluid cap for protection. JMM/DH15: tw RECEIVED JUL261 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM Stale of Alaska ALASKA OIL A2~D GAS CONSERVATION COMMISSION TO: C o - ter n THRU: Lonnte C. Smith'r ,,~ Commissioner FROM: Doug Amos~ Petroleum Inspector DATE: June 12, 1984 FILE NO: D. 41.23 TELEPHONE NO: SUBJECT: Witness the BOP Test on ARCO's DS 3-29 Well Sec. 10, T10N,R15E,UM, Permit No. 84-79 on Rowan Rig No. 35. Wednesday, June .6, 1984: After witnessing the safety valve test at SOhiO', I traveled't°' ARCO's DS 3-29 well to witness the BOP test there. Thursday, June.7,~.!98~4: The BOP test commenced at 6:45 pm and was hohcluded at 9:15 pm. There were no failures and I filled out an 'AOGCC BOP test report which is attached. In summa~, I witnessed the successful BOP test at ARCO's DS 3-29 well. AttaChment . OiL & GAS ~NSERVAT_~ON COMMISSION B.O.P.E. Insl~?c'&ion Report Well Sign ...................... General Housekeeping Reserve pit Rig '~ '~ · . ACCUMULATOR SYSTEM Full Charge Pressure___~,Od90 psig Pressure After Closur%.~~ psig 200 psig A~ve Precharge Attained: min_~_Sec Full Cha~ge Pressure Attained~.~ ..... min~7 sec Cont~-ols; Master ~:~*'" .-~ '-~t:ind Rams~P Choke Line Valves~ H.C.R. Valve Check Valve t! Il // Upper Kelly ....... ~____/Test Pressure__.~Q~k ..J~ Lower Kel! y ~est sure _ . ..... ~___ . Pres i~Ba]l ,Cy.p~ ]_..~est Pressure ........ , inside BOP ~...~st Pressure Ir Choke Manlfold__~_~est Pressure " No. Valves .................... ~NO. f!anges ~ ,, Ad ju.stakle C-hoke~_ ...................... L !i Hydrauically operated choke ....... Test Results: Failures Repair or Replacement of failed equipment to be r,~de witt~in ........ .~ays and Inspector/Commission office notifierS. Remarks: Distributi~ or ig. -/A~O&GCC cc ~- Operator cc - Supervisor :k ,."~ '. //// 1984 Mr. T. L. Fi thian Area Drilling Enginee~ ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 3-29 ARCO Alaska, Inc. Permit No. 84-79 Sur. Loc. 54§'FSL, 71'FWL, Sec. 11, T10N, R15E, UM. Btmhole Loc. 2588'FSL, 2294'FWL, Sec. 10, T10N, R15E, UM. Dear Mr.' Fithian: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inCh chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as par 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter su~veys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, ' e Chapter 3, Artxcle 7 and the regulations promulgated thereu~d r (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal WAter Pollution Control Act,. as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. T. L. Fithla. Prudhoe Bay Unit DS 3-29 May 24, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment Before the surface casing shoe is drilled. Where a diverter system is required, please also notify this o£ftce 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this off,ce adequate advance notification so that we may have a witness present. Very truly yours, · ~. ~. Ch~t[~r~on~ -ay o.o~. o~ T,~ CO~M~SS~O, Chairman of Alaska 0il and Gas Conservation Comnisston be Enclosure Department of Fish & Came. Habitat Section w/o encl. Depart~nent of Envirorunental Conservation w/o encl. ARCO Alaska, Inc. /~ Post Office BI.. , 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 3-29, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 3-29 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; proximity plats showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on June 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Sincerely,ff T. L. Fithian Area Drilling Engineer TLF/JG:tw GRU7/L53 Enclosures Alaska Oil & G~,~ Cons. Commission Ancl~orage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany · z~, STATE OF ALASKA r~, ALASKA (.,,- AND GAS CONSERVATION COIv, MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [~X lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL E~X SINGLE ZONE ~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator t ECEIVED ARCO Alaska, Inc. ,,. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 MI/~Y 2 4. Location of well at surface 9. Uni~,(~J~ase_name 545' FSL, 71' FWL, Sec.11, T10N, R15E, UN Prudhoe ,ay-um-~ Corls. At top of proposed producing interval 10. Well number ~llch0J'ag6 2384' FSL, 2598' FWL, Sec. 10, T10N, R15E, UR (~ Target) 3-29 At total depth 11. Field and pool 2588' FSL, 2294' FWL, Sec.10, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Prudhoe Bay 0i 1 Pool RKB 62', PAD 28' ADL 28328 ALK 2326 12. Bond information (see ~0 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 3 mi. NE of Deadhorse miles 71' ~ surface feet 3-28well 120' ~ surface f~t. 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10326' MD, 9220' TVD feet 2560 06/15/84 "' 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~61 psig@__ Surface KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLE 35 Ol(see2OAAC25.035(c) (2) :~850 psig@ 9770 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing prOgram SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 33' I 33' 113 ~ 113' 2000# Pol 17-1/2" 13-3/8" 72.0# L-80 BTC 2467' 33' 33' 2500'1 2500' 2300sx CS II 1+400sx CSI 12-1/4" 9-5/8" 47.0# L-80 BTC 9639' 32' ~ 32' 9671'1 8682' 500 sx Class 8-1/2" 7" 29.0# L-80 BTC 955' 9371' Ii 8423' 10326'1 9220' 400 sx Class I I ~ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill this well to 10,326' MD (9220' TVD) to produce from the Sadlerochit zone. Logs will be run across selected intervals. A surface diverter will be installed and operationally tested prior to spud. A.13-3/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing and packer will be run. The packer will be set above the Sadlerochit. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A Sundry Notice will be submitted when the well is to be perforated. DS 3-29 will be 200' away from DS 3-15 @ 4721'TVD. It is also 120' away from DS 3-28 at the surface. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process (i.e., rig move, shutdown of disposal process for an extended period of time). · 23. I hereby certify t nd correct to the best of my knowledge SIGNED ~, / TITLE Area Drilling Engineer DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number [ Permit number _. _ ~, ApproVal date ,--'-"X 0~'~/ SEE COVER LETTER FOR OTHER REQUIREMENTS _ I ~ '//'k ~'~'~~~'~ by order of the Commission ' Form 10-401 GRU7/PD 19 / Submit in triplicate DS329 0 1000 - 2000 3000 4000 SOOO 6OD0 7000 ~ r- CASING TVn I 1000 A i SI-IL- 71' FWL & 545' FS~ of J ~' 'lI~~ Sec. 11, T10N, R15]~, U~ ./ / ~ THL- 2780' FEL & 2450' FSL of // I ~- .~:t~ ~' N8K~ II~. 3-3/8' CASING TVD -2600 3000 2.5 7.5 ' ~ 12.5 17.5 4000 -f- "~ --1--~ TVD · 4608 MD -- 46; lg DEP -- 408 o 5000 ~4E.% IDpI:m 18 MIN W ~(TO '1' AReBT) > 6000 W , 7000 '-1'-- K-10 TVD ' 7342 MD - 80~,1 OEP - 2376 r,8~C~F:' - ".-"22 ..~.= - __.~::: =_=." - 2."~! 8000 SAG RIV. :R TVD -- 8682 I~ D - 8682 DEP -3242 IL.,~ LJ TVD-8682 N D-8562 DEP--3242 .\ SHUB ;IK TVD --8822 I ID "'9688 DEP -, 8262 8-6/8° CASI dG TVD -- 8882 I lid --8671 DEP ''33138041 TOP 8.a~J~OI :HIT TVD '--880'2 MD -' 0883 DEP ""'"' '"""" ""-"" \ c -u ooo OIW CI ~NTACT TVD-- 8 )87 MD- 10178 06P -- 3882 BASE SAIDI EROCHIT TVD - )187 MD.- 1028! DEP - 3840 TD TVD-' 220 MD 10321 DEP--3677 M^¥ 2 10000 Alaska Oi & 6as Cons. Commission Anchorage 11000 '1 ............................................................... 11000 7000 1000 2000 0 1000 2000 3000 4000 5000 6000 VERT I CFIL SECT I ON 30OO 4000 5000 6OOO 7000 10000 0._ W __] DS3-29 E - N COOROINBTKS o -6000 -5000 -4000 -3000 -2000 - 1000 0 ! DO0 0 ' ' ' ' ' I I I ' ' ' IIII II '' ''' ' ''' I I I'' '''' ~' ,,,, ,,,,I,, ,,, , , , ~- I I II SI-IL-31 FI~rL & 545 FSL of Sec.ll, ~_ & · · T10N, R15E, UM ~'~~/~ ~ THL- 2780 FEL & 2450 FSL of ~ ,, /'~ ~ ~ Sec. 10,'T10N, R1SE, UM N /// ° ~ ~CO AL ~,$KA, I1~ C. C:) ° - CD Target' c2 TVD- 8862 ' o 1~- 9890 ' 03 ~ DEP-3429' " RECE VED' o MAY 2 > 1984 ' 1 laska Oil & Gas ;OHS. Commiss I ' ' ' ' ' ' ' ' * ' ' ' ' ' ' ~ ' ' ' ' ' ' ' ' ' ' ' ' '' ' ! ' ' ' ' ' ' ' ' ! ' ' -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 - N O00ROIN~tTES c:) DS3-29 -700 -600 -500 E - N OOOROINB~F.S ~ -400 -300 -20G -]00 0 ]00 CD CD- CD CD CD CD CD CD j i I ! i i i I I I I I I I & I ! .I & ! I I I I I I I I I I I I I I I I I ! ! I I ! ! I I I I I I I i I I ! ! I I i I ! ! I ! I I I I I I I I / · .589 ROC ALAE;KA;. INC. " -" '": ' S~ ,LEI IN. = 100 i~'. .- - : ~z~4z 3 DS3-15 ii i i ii i '" ~@7 ~...~~~ 6 ~''3U / . 958 X, 'Z;q R O ~258 , , , x,~. ,, ~0 RECI IVE'D '-< 889 MAY' 2 2 !984 DS$-29 ~ 6,.., ~;'~-~',~ ¢. ~ ~as Cons. Commbs[ol u Anch( rage i iII i i i I i i i i i i i i I I Il lIli i i i i i I i , I i iI i i i i i I i I i i i i i i i I i i i i i i i i i i ! i Ii I i! i i i ! i i i , i i cnn _Ann -~nn -;nn -inn 0 18 -4000 o I ! I DS$-29 o -6000 -5000 E - N OOOROINR~ES -3000 -2000 -1000 ]000 'AR O0 Al_Al IKA, INC, 13S 5 2 -6000 -5000 -4000 -3000 -2000 -1000 0 lOOO E - N COOROINRTES DS3-29 ~-~'E - N OOOROINRTES -5000 -4000 -3000 -2000 - 1000 0 -6000 0 0 L~ 0 w I -6000 1000 i i ! i ! ! · ~ ! i i ~ I I I I 00 RECEI ED Oil & Gas ~s. commission Ancho~e -5000 -4000 -3000 -2000 - 1000 0 F - N COORDINRTP. S 1000 DS$-29 z~'x', tS. - hi COOROINFi~F.S ,'-~,, -6000 -5000 -4000 -3000 -2000 -iO00 0 1000 ,,,' AI:RC. X2) A~~ ~ INC. . co ~ .... ~ 5-i7 ~ - -- .?.',~ ~--,~-,' 99 , I o ~ 8 !~~2058~ 2 II ' ~~2 o.O ~~s RECEIVED _ a ;ka Oil & Cao C{ ns. Commission~ · 15 t. ^nchor~ ~ I i i i i i i i i i i i i1 i i 11 i Ii i i i I i i i i i i i i i i i i i i II i i i i i i i i i i i i i ' i i i i i I i i i -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 E - IA COORDINFITES RNNULRR PREVENTOR PIPE RRMS BLIND RRM$ DRILLING SPOOL P['PE RRMS i ii~ ii iii 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Tes..t 1. Check and fill .accunulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1S00 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the tim~ and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and .manifold with a non-freezing liquid. 2. Check that all 'hold down screws are fully retracted. Mark running joint with predetermined plug se.a.ting depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Fundtionally test chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 minutes. Bleed pressure to zero. 7. Open annular Preventer and close top set of pipe rams. Increase pressure to $000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase p~essure to $000 psi and hold for at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to $000 psi below the bottom set of pipe rams and hold. for at least 3 min- utes. Test reamining untested manifold valves (if any) with SO00 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe Back off rurming joint and pull out of hole. Close blind rams and test to $000 psi for at least 5 minutes. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to $000 psi. Test Kelly cocks and inside BOP to SO00 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOPB test once a week and func- tionally operate BOI~ daily. 10. 11. 12. 13. 14. 1S. 16. 17. 18. RECEIVED MAY 2 2 1984 Alaska Oil & Gas Cons. Commission Anchorage Revised 2/21/84 SURFACE HOLE D iVERTER ARCO ALASKA _. ' / ~ EL B E DETAIL) / /~ I0" HY~. ~R. BALL VAL~ ~ ~ ~ I ALL ~ TURNS ARE "TEE" I~LL RESERVE PIT AREA NOTE' SYSTEM INC. SCHEMATIC FLOWL INE DR ILL lNG R I SER _F LI 20" 2000 PSI WP 'Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 20260102 ARCO Alaska, Ir?'''''~ Post Offic,. vox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 11, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS.3 Wells 27-34 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU7/L41'tw Enclosure If A~aska 0ti & Gas ConS. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~UILT WELL LOCATIONS . ~.-~-L No. 27 EL. 28.72 Lon~. )~o 16' 41.390" 713,298~2 ~t. 70°13' 48.188" Y 5,936,703.4[ ~ Long. 148°16' 40.664" X 713,3~6.61 Long. 148016'39.937" X 715~ 354.96 Lot. 70° 13' 45.881" Y 5~ 936~ 470.52 Long. 148°!6 39.2~" X 713~ 385.55 WE~ No. ,I EL. 27.20 L~t. 7~ 15' 46.095" Y 5,956,511.24 Lon~. 148016. 19.589" X 714,057.70 Well 27 .WELL No. 52 EL. 27.65 21'~ · Lot. 7~ 15' 44.94[" Y Lon~. 148°16' 18~865" X 714,086.01 Well 28 Gyro WE~ No. 55 , __,,- EL. 27.89 71'~ ~ _ Lon~. 148°!6 18.156 714~114.58 WELL No. 54 EL. 27.75 Well 51 Lot. 7~ 15[ 42.65~" _ ~. 1~16 17.411 X 714~14Z.62 Y 5~ 956,161.57 - 771' ~= - Well 50 Well ~ ~ . 796' .. GYRO LOCATIONS Let. 70° 15' 45.467" ~ 5~ 956,225.55 a46' ~ EA~ ~Y~O t0 Lon~ 148°16 20.756 X714, 012.22 ~ Pr~ocI~ S~fion Line RECEIVED , - .Alaska ~o~[s '~ ~'~r~ H. Lounsbu~ · "~ ~S COn3 ~ ' Elevations ore ARCO datum M.L.L.W. ~'~'., 872.S .Z A~chor3._' All distances are ~rid. ~~:,..,,,.~,~ ~ X,Y coordinates are Alaska State Plane, Zone 4. ' I LHD OCIATE$. ~ / ~,~RU~~R~ORS ! A! ka I ARCO. as , nc. ~ P;~STICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT T~'.S ;LAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER ASBUILT ~7 S~=EAvISION AND ALL DIMENSIONS AND OTHER DETAILS ARE ::~, ~ ' s~e~oF / LOCATED IN PROTRACTED ~ _ SECTION I1~ TION~ R 15E~ U.M. . - I" DATE: 4 24 84 SCALE= =500' ~ CK'D: LMH ~D. BK. ~-I0, 84-11 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (z2 thru 8) (3) Admin ~ [~-'~'u"~f ('~ thru 11) (10'and 11) (4) Cas~ /~' ~--~ -f~ (~12 thru 20)~ (21 thru 24) (6) Add: le YES NO Is the permit fee attached .......................................... ~,~-.~.: 2. Is well to be'located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... REMARKS Is conductor string provided ..................................... . Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ............. Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation proposed ......................... Is a diverter system required .................................... and'BOP ' ;ttached ~ Are necessary diagrams of diverter equipment . Does BOPE have sufficient pressure rating - Test to ~D'~ psig . Does the choke manifold comply w/API R?-53 (Feb.78) .................. Additional requirements ............................................. ~ , ~ Additional Remarks: f~. P/~o,~.c# 0 HO Geology: Engi~. e~ing: WVA ~ JKT~HJH~ rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the fiie under APPENDIXl No 'special*effort has been made to chronologically organize this category of information. o. S~.O. ~/ 63153 ~,.~ -. ~.:' ECC# 2003 Company LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. Well D.S. # 3-29 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date 6-17-84 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC RESISTIVITY FOCUSED DIFL .2 - 2000 RILM RESISTIVITY MEDIUM " .2 - 2000 , RILD RESISTIVITY DEEP " .2 - 2000 GR1 GAMMA RAY 1 DIFL - BHC/AC 0-100, 100-200 SP SPONTANEOUS POTENTIAL " " 0-100, 100-200 AC ACOUSTIC BHC/AC 150 - 50 DEN DENSITY CDL 2 - 3 ,, , cORR CORRECTION " -.5 - .5 DENP DENSITY POROSITY CD/CN 60 - 0 · CN COMPENSATED NEUTRON " 60 - 0 GR GAMMA RAY CDL-CD/CN 0-100, 100-200 · CAL CALIPER " " 6 - 16 , , GR2 GAMMA RAY 2 GRL 0-100, 100-200 ~ , . 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' ,.. , ... ........... v.,. ....~ u ~ ?. 1& ~ ~d ~7, '~,f. ~ '~ ~'~ 001~'~ ~0 n .~ . ~ .,~ HA££1BURTON L. O ~ ~IN~ $~R VIC~S, /NC. OA Halliburton Company LIS TAPE VERIFICATION LISTING LDWG FORMAT Page i REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/03/20 --- ANCH --- 920018 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/03/20 --- ANCH --~ 0 COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: 03-29 API NUMBER: 500292111800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 20-MAR-93 JOB NUMBER: L92001-8 LOGGING ENGINEER: McCARTER OPERATOR WITNESS: T. ALLEN SURFACE LOCATION SECTION: 11 TOWNSHIP: i0N RANGE: 15E FNL: FSL: 545 FEL: FWL: 71 ELEVATION(FT FROM MSL 0) KELLY BUSHING: 62.00 DERRICK FLOOR: 61.00 GROUND LEVEL: 28.00 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2500.0 72.00 2ND STRING 12.250 9.625 9500.0 47.00 3RD STRING 8.500 7.000 10236.0 29.00 PRODUCTION STRING 8.500 5.500 9149.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BCS PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... PSGT 9637.5 9634.5 9686.0 9683.0 9714.5 9712.0 9770.5 9768.0 9843.5 9841.0 9926.5 9926.0 9988.5 9988.0 10014.5 10014.0 $ REMARKS: TIED INTO SWS BHC DATED 17-JUN-84. FILE ORGANIZATION: FILE 1: EDITED PASS 1 DATA ( .50 FT DEPTH INCREMENT ) FILE 2: EDITED PASS 2 DATA ( .50 FT DEPTH INCREMENT ) FILE 3: EDITED PASS 3 DATA ( .50 FT DEPTH INCREMENT ) FILE 4: EDITED PASS 4 DATA ( .50 FT DEPTH INCREMENT ) FILE 5: EDITED PASS 5 DATA ( .50 FT DEPTH INCREMENT ) FILE 6: AVERAGED PASS 1-5 ( .50 FT DEPTH INCREMENT ) FILE 7: RAW DATA OF PASS 1 ( .25 FT DEPTH INCREMENT ) FILE 8: RAW DATA OF PASS 2 ( .25 FT DEPTH INCREMENT ) FILE 9: RAW DATA OF PASS 3 ( .25 FT DEPTH INCREMENT ) FILE 10: RAW DATA OF PASS 4 ( .25 FT DEPTH INCREMENT ) FILE 11: RAW DATA OF PASS 5 ( .25 FT DEPTH INCREMENT ) FILE 12: COMPUTED DATA FILE ( .25 FT DEPTH INCREMENT ) $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 93/03/20 --- 1024 --- LO Page 3 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 10012.5 9642.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 920018 GAPI LIRI PSGT 920018 COIR PSGT 920018 API CODE FILE# 00000000 0 00000000 0 00000000 0 00000000 0 SIZE 4 4 4 4 #SAMP REPR. 1 68 1 68 1 68 1 68 Page 4 STUN PSGT 920018 00000000 0 4 i 68 ITCR PSGT 920018 00000000 0 4 i 68 HPLI PSGT 920018 00000000 0 4 i 68 TCCR PSGT 920018 00000000 0 4 i 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 I 68 RIC PSGT 920018 00000000 0 4 i 68 KIC PSGT 920018 00000000 0 4 i 68 HIC PSGT 920018 00000000 0 4 i 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 i 68 CAIC PSGT 920018 00000000 0 4 I 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 I 68 FERC PSGT 920018 00000000 0 4 i 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 i 68 TEMP PSGT 920018 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10012.500 GRCH = 18.782 LIRI = 1.404 COIR = .487 STUN = .007 ITCR = 6078.736 HPLI = 1.276 TCCR = 9668.736 OAI = 2.785 SIAI = 4.132 RIC = .629 KIC = .392 HIC = .061 SIIC = .061 CLIC = .015 CAIC = .003 FEIC = .093 SIC = .101 FERC = 2.451 TMDS = 23.084 TENS = 1520.976 TEMP = 20.900 DEPT = 9912.500 GRCH = 27.541 LIRI = 1.344 COIR = .496 STUN = .007 ITCR = 5693.250 HPLI = 1.343 TCCR = 8826.131 OAI = 4.246 SIAI = 3.852 RIC = .645 KIC = .401 HIC = .076 SIIC = .071 CLIC = .019 CAIC = .002 FEIC = .083 SIC = .095 FERC = 2.414 TMDS = 17.779 TENS = 1663.562 TEMP = 21.300 DEPT = 9812.500 GRCH = 16.331 LIRI = 1.323 COIR = .473 STUN = .007 ITCR = 5263.406 HPLI = 1.324 TCCR = 9289.418 OAI = 3.683 SIAI = 3.026 RIC = .567 KIC = .397 HIC = .067 SIIC = .070 CLIC = .016 CAIC = .002 FEIC = .087 SIC = .098 FERC = 2.493 TMDS = 14.773 TENS = 1713.887 TEMP = 21.500 DEPT = 9712.500 GRCH = 23.125 LIRI = 1.373 COIR = .477 STUN = .007 ITCR = 5508.421 HPLI = 1.314 TCCR = 9470.736 OAI = 2.481 SIAI= 3.714 RIC = .582 KIC = .396 HIC = .066 SIIC = .066 CLIC = .017 Page 5 CAIC = .002 FEIC = .089 SIC = .099 FERC = 2.435 TMDS = 15.987 TENS = 1739.049 TEMP = 21.900 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 93/03/20 --- 1024 --- LO --- COMCEN.002 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 --- 93/03/20 --- 1024 --- LO --- COMCEN.001 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 10013.5 9650.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 --EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 9647.0 9648.0 9683.0 9684.0 9712.0 9713.0 9768.0 9769.0 9841.0 9841.5 Page 6 9926.0 9988.0 10013.0 $ REMARKS: 9926.0 9988.0 10012.0 THIS FILE CONTAINS EDITED DATA FOR PASS #2. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 920018 GAPI 00000000 0 4 i 68 LIRI PSGT 920018 00000000 0 4 i 68 COIR PSGT 920018 00000000 0 4 1 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 I 68 HPLI PSGT 920018 00000000 0 4 I 68 TCCR PSGT 920018 00000000 0 4 I 68 OAI PSGT 920018 00000000 0 4 I 68 SIAI PSGT 920018 00000000 0 4 I 68 RIC PSGT 920018 00000000 0 4 i 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 I 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 i 68 FEIC PSGT 920018 00000000 0 4 i 68 SIC PSGT 920018 00000000 0 4 i 68 FERC PSGT 920018 00000000 0 4 I 68 TM. DS PSGT 920018 CU 00000000 0 4 i 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 Page 7 DEPT = 10013.500 GRCH = 47.259 LIRI = 1.375 COIR = .476 STUN = .007 ITCR = 5372.602 HPLI = 1.302 TCCR = 8953.941 OAI = 5.971 SIAI = 8.476 RIC = .600 KIC = .391 HIC = .062 SIIC = .059 CLIC = .014 CAIC = .004 FEIC = .096 SIC = .099 FERC = 2.370 TMDS = 22.466 TENS = 1697.112 TEMP = 22.500 DEPT = 9913.500 GRCH = 41.250 LIRI = 1.353 COIR = .482 STUN = .007 ITCR = 5192.734 HPLI = 1.358 TCCR = 8486.568 OAI = 3.463 SIAI = 3.882 RIC = .612 KIC = .397 HIC = .077 SIIC = .071 CLIC = .015 CAIC = .003 FEIC = .083 SIC = .092 FERC = 2.451 TMDS = 18.026 TENS = 1722.274 TEMP = 23.200 DEPT = 9813.500 GRCH = 37.243 LIRI = 1.330 COIR = .472 STUN = .007 ITCR = 5529.750 HPLI = 1.324 TCCR = 9397.072 OAI = 2.684 SIAI = 4.035 RIC = .588 KIC = .394 HIC = .066 SIIC = .069 CLIC = .013 CAIC = .004 FEIC = .088 SIC = .096 FERC = 2.444 TMDS = 15.252 TENS = 1697.112 TEMP = 23.700 DEPT = 9713.500 GRCH = 43.199 LIRI = 1.370 COIR = .474 STUN = .006 ITCR = 5583.642 HPLI = 1.282 TCCR = 9591.666 OAI = 3.347 SIAI = 4.552 RIC = .582 KIC = .390 HIC = .064 SIIC = .061 CLIC = .015 CAIC = .001 FEIC = .096 SIC = .100 FERC = 2.432 TMDS = 18.512 TENS = 1638.400 TEMP = 24.400 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 93/03/20 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.003 Page 8 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ------ 5 --- 93/03/20 --- 1024 --- LO --- COMCEN. 002 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 10014.0 9637.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT 9634.5 9635.5 9683.0 9684.0 9712.0 9712.5 9768.0 9768.5 9841.0 9841.5 9926.0 9926.0 9988.0 9988.0 10013.5 10012.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 Page 9 8 4 73 60 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 920018 GAPI 00000000 0 4 1 68 LIRI PSGT 920018 00000000 0 4 i 68 COIR PSGT 920018 00000000 0 4 I 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 1 68 HPLI PSGT 920018 00000000 0 4 i 68 TCCR PSGT 920018 00000000 0 4 1 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 i 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 i 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10014.000 GRCH = 65.978 LIRI = 1.416 COIR = .487 STUN = .007 ITCR = 5301.763 HPLI = 1.303 TCCR = 8544.197 OAI = 6.680 SIAI = 8.489 RIC = .621 KIC = .396 HIC = .064 SIIC = .058 CLIC = .017 CAIC = .002 FEIC = .094 SIC = .099 FERC = 2.385 TMDS = 22.614 TENS = 1604.850 TEMP = 25.300 DEPT = 9914.000 GRCH = 61.559 LIRI = 1.361 COIR = .488 STUN = .007 ITCR = 5474.681 HPLI = 1.314 TCCR = 8786.432 OAI = 3.149 SIAI = 5.127 RIC = .623 KIC = .396 HIC = .074 SIIC = .070 CLIC = .015 CAIC = .002 FEIC = .087 SIC = .095 FERC = 2.341 TMDS = 16.594 TENS = 1646.787 TEMP = 26.000 Page 10 DEPT = 9814.000 GRCH = 55.027 LIRI = 1.383 COIR = .479 STUN = .007 ITCR = 5328.860 HPLI = 1.312 TCCR = 9392.770 OAI = 2.629 SIAI = 4.488 RIC = .567 KIC = .394 HIC = .068 SIIC = .072 CLIC = .016 CAIC = .002 FEIC = .087 SIC = .097 FERC = 2.395 TMDS = 15.004 TENS = 1671.949 TEMP = 26.700 DEPT = 9714.000 GRCH = 58.771 LIRI = 1.402 COIR = .497 STUN = .007 ITCR = 5468.595 HPLI = 1.296 TCCR = 9397.244 OAI = 2.140 SIAI = 4.340 RIC = .582 KIC = .394 HIC = .061 SIIC = .058 CLIC = .015 CAIC = .002 FEIC = .096 SIC = .101 FERC = 2.411 TMDS = 18.700 TENS = 1655.175 TEMP = 27.500 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 ------ 0 --- 93/03/20 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 ----~ 0 --- 93/03/20 --- 1024 --- LO --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH Page 11 PSGT 10014.0 9651.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 9648.0 9648.5 9683.0 9683.5 9712.0 9712.5 9768.0 9768.5 9841.0 9841.5 9926.0 9926.0 9988.0 9988.0 10013.5 10012.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #4. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT P GRCH PSGT 920018 LIRI PSGT 920018 COIR PSGT 920018 STUN PSGT 920018 ITCR PSGT 920018 HPLI PSGT 920018 TCCR PSGT 920018 OAI PSGT 920018 GAPI API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. i 68 1 68 i 68 i 68 i 68 1 68 1 68 1 68 1 68 Page 12 SIAI PSOT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 10014.000 GRCH = 81.471 LIRI = 1.380 COIR = .485 STUN = .007 ITCR = 5273.491 HPLI = 1.318 TCCR = 8517.574 OAI = 5.880 SIAI = 9.455 RIC = .619 KIC = .391 HIC = .061 SIIC = .058 CLIC = .013 CAIC = .004 FEIC = .097 SIC = .099 FERC = 2.379 TMDS = 21.621 TENS = 1789.374 TEMP = 28.600 DEPT = 9914.000 GRCH = 68.986 LIRI = 1.393 COIR = .478 STUN = .007 ITCR = 5195.109 HPLI = 1.363 TCCR = 8510.357 OAI = 2.860 SIAI = 4.693 RIC = .610 KIC = .397 HIC = .075 SIIC = .070 CLIC = .015 CAIC = .003 FEIC = .085 SIC = .092 FERC = 2.439 TMDS = 17.402 TENS = 1814.536 TEMP = 29.500 DEPT = 9814.000 GRCH = 59.734 LIRI = 1.351 COIR = .449 STUN = .006 ITCR = 5454.624 HPLI = 1.343 TCCR = 9327.461 OAI = 3.593 SIAI = 4.833 RIC = .585 KIC = .396 HIC = .067 SIIC = .069 CLIC = .013 CAIC = .005 FEIC = .087 SIC = .097 FERC = 2.411 TMDS = 15.362 TENS = 1881.635 TEMP = 30.200 DEPT = 9714.000 GRCH = 69.871 LIRI = 1.391 COIR = .473 STUN = .007 ITCR = 5223.673 HPLI = 1.280 TCCR = 9239.492 OAI = 3.314 SIAI = 4.677 RIC = .565 KIC = .392 HIC = .063 SIIC = .057 CLIC = .012 CAIC = .003 FEIC = .097 SIC = .101 FERC = 2.435 TMDS = 20.357 TENS = 1881.635 TEMP = 30.900 Page 13 FILE TRAILER RECORD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 --- 93/03/20 --- 1024 --- LO --- COMCEN.005 TYPE 129 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 --- 93/03/20 --- 1024 --- LO --- COMCEN.004 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 10014.5 9653.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 .......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 9650.0 9650.0 9683.0 9683.0 9712.0 9712.0 9768.0 9768.0 9841.0 9841.0 9926.0 9926.0 9988.0 9987.0 10014.0 10012.0 $ Page 14 REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS S5. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 I 66 0 3 2 79 88 4 I 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS API CODE FILES SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 GRCH PSGT 920018 GAPI 00000000 0 4 1 68 LIRI PSGT 920018 00000000 0 4 1 68 COIR PSGT 920018 00000000 0 4 1 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 1 68 HPLI PSGT 920018 00000000 0 4 i 68 TCCR PSGT 920018 00000000 0 4 1 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 i 68 FEIC PSGT 920018 00000000 0 4 i 68 SIC PSGT 920018 00000000 0 4 i 68 FERC PSGT 920018 00000000 0 4 I 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 i 68 TEMP PSGT 920018 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10014.500 GRCH = 111.364 LIRI = 1.376 COIR = .484 STUN = .007 ITCR = 5352.419 HPLI = 1.308 TCCR = 8351.061 OAI = 8.570 Page 15 SIAI = 10.256 RIC = .641 KIC = .392 HIC = .064 SIIC = .061 CLIC = .015 CAIC = .002 FEIC = .094 SIC = .098 FERC = 2.392 TMDS = 21.789 TENS = 1940.347 TEMP = 31.700 DEPT = 9914.500 GRCH = 75.645 LIRI = 1.395 COIR = .484 STUN = .007 ITCR = 5361.103 HPLI = 1.300 TCCR = 8686.498 OAI = 2.634 SIAI = 4.344 RIC = .617 KIC = .396 HIC = .072 SIIC = .066 CLIC = .015 CAIC = .002 FEIC = .090 SIC = .097 FERC = 2.380 TMDS = 17.700 TENS = 1873.248 TEMP = 32.400 DEPT = 9814.500 GRCH = 66.277 LIRI = 1.346 COIR = .472 STUN = .007 ITCR = 5151.751 HPLI = 1.350 TCCR = 9218.711 OAI = 3.056 SIAI = 4.898 RIC = .559 KIC = .396 HIC = .069 SIIC = .071 CLIC = .015 CAIC = .002 FEIC = .087 SIC = .095 FERC = 2.444 TMDS = 14.670 TENS = 1881.635 TEMP = 33.100 DEPT = 9714.500 GRCH = 78.585 LIRI = 1.379 COIR = .483 STUN = .007 ITCR = 5356.253 HPLI = 1.329 TCCR = 9264.451 OAI = 3.328 SIAI = 6.355 RIC = .578 KIC = .391 HIC = .062 SIIC = .059 CLIC = .015 CAIC = .001 FEIC = .097 SIC = .098 FERC = 2.491 TMDS = 19.606 TENS = 1898.410 TEMP = 33.600 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 m~-- 0 --- 93/03/20 --- 1024 --- LO --- COMCEN.006 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --~ 0 --- 93/03/20 --- 1024 --- LO --- COMCEN.O05 Page 16 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PSGT $ REMARKS: 01,02,03,04,05 GRCH, OAI AND SIAI ARE TAKEN FROM PASS #1. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS DEPT F GRCH PGAV 920018 LIRI PGAV 920018 COIR PGAV 920018 STUN PGAV 920018 ITCR PGAV 920018 HPLI PGAV 920018 TCCR PGAV 920018 GAPI API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 Page 17 OAI PGAV 920018 00000000 0 4 i 68 SIAI PGAV 920018 00000000 0 4 i 68 RIC PGAV 920018 00000000 0 4 i 68 KIC PGAV 920018 00000000 0 4 i 68 HIC PGAV 920018 00000000 0 4 i 68 SIIC PGAV 920018 00000000 0 4 1 68 CLIC PGAV 920018 00000000 0 4 1 68 CAIC PGAV 920018 00000000 0 4 1 68 FEIC PGAV 920018 00000000 0 4 1 68 SIC PGAV 920018 00000000 0 4 i 68 FERC PGAV 920018 00000000 0 4 1 68 TMDS PGAV 920018 CU 00000000 0 4 1 68 TEMP PGAV 920018 DEG 00000000 0 4 I 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10012.500 GRCH = 18.782 LIRI = 1.403 COIR = .483 STUN = .007 ITCR = 5489.245 HPLI = 1.304 TCCR = 8985.494 OAI = 2.785 SIAI = 4.132 RIC = .606 KIC = .394 HIC = .062 SIIC = .061 CLIC = .016 CAIC = .003 FEIC = .092 SIC = .099 FERC = 2.408 TMDS = 22.910 TEMP = 25.820 DEPT = 9912.500 GRCH = 27.541 LIRI = 1.363 COIR = .480 STUN = .007 ITCR = 5395.817 HPLI = 1.360 TCCR = 8484.609 OAI = 4.246 SIAI = 3.852 RIC = .632 KIC = .399 HIC = .077 SIIC = .072 CLIC = .016 CAIC = .002 FEIC = .083 SIC = .093 FERC = 2.422 TMDS = 17.274 TEMP = 26.480 DEPT = 9812.500 GRCH = 16.331 LIRI = 1.331 COIR = .471 STUN = .007 ITCR = 5271.214 HPLI = 1.332 TCCR = 9223.943 OAI = 3.683 SIAI = 3.026 RIC = .570 KIC = .395 HIC = .067 SIIC = .070 CLIC = .014 CAIC = .003 FEIC = .088 SIC = .097 FERC = 2.436 TMDS = 14.910 TEMP = 27.080 DEPT = 9712.500 GRCH = 23.125 LIRI = 1.375 COIR = .481 STUN = .007 ITCR = 5442.257 HPLI = 1.302 TCCR = 9336.945 OAI = 2.481 SIAI = 3.714 RIC = .580 KIC = .395 HIC = .067 SIIC = .066 CLIC = .016 CAIC = .002 FEIC = .090 SIC = .099 FERC = 2.424 TMDS = 16.634 TEMP = 27.700 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.006 Page 18 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------ 5 --- 93/03/20 --- 1024 --- LO --- COMCEN. 007 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 93/03/20 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 10032.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9639.0 25-JAN-93 2.23 1015 25-JAN-93 10036.0 10030.0 9660.0 10020.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 114434S OO5 8.500 10236.0 Page 19 LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): WATER 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOw SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 I 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 20 MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 CCL PSGT 920018 MV 00000000 0 4 1 68 GR PSGT 920018 GAPI 00000000 0 4 i 68 LIRI PSGT 920018 00000000 0 4 i 68 COIR PSGT 920018 00000000 0 4 1 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 1 68 HPLI PSGT 920018 00000000 0 4 1 68 TCCR PSGT 920018 00000000 0 4 i 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 i 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10032.500 CCL = 10923.000 GR = 18.807 LIRI = 1.431 COIR = .465 STUN = .006 ITCR = 5725.477 HPLI = 1.298 TCCR = 7868.139 OAI = 11.538 SIAI = 11.216 RIC = .728 KIC = .406 HIC = .073 SIIC = .060 CLIC = .023 CAIC = .003 FEIC = .084 SIC = .097 FERC = 2.436 TMDS = 30.731 TENS = 1026.118 TEMP = 20.700 DEPT = 9982.500 CCL = 10923.000 GR = 29.713 LIRI = 1.377 COIR = .495 STUN = .007 ITCR = 5621.134 HPLI = 1.318 TCCR = 9104.703 OAI = 4.043 SIAI = 3.223 RIC = .617 KIC = .398 HIC = .074 SIIC = .072 CLIC = .016 CAIC = .002 FEIC = .084 SIC = .096 FERC = 2.384 TMDS = 16.418 TENS = 1638.400 TEMP = 21.000 DEPT = 9932.500 CCL = 10923.000 GR = 18.964 LIRI = 1.367 COIR = .468 STUN = .007 ITCR = 5580.857 HPLI = 1.302 TCCR = 9503.250 OAI = 3.083 SIAI = 3.466 RIC = .587 KIC = .396 HIC = .071 SIIC = .070 CLIC = .015 CAIC = .003 FEIC = .085 SIC = .097 FERC = 2.429 TMDS = 15.337 TENS = 1671.949 TEMP = 21.200 Page 21 DEPT = 9882.500 CCL = 10923.000 GR = 19.245 LIRI = 1.390 COIR = .474 STUN = .007 ITCR = 5702.393 HPLI = 1.330 TCCR = 9099.096 OAI = 3.780 SIAI = 2.704 RIC = .627 KIC = .399 HIC = .077 SIIC = .069 CLIC = .020 CAIC = .001 FEIC = .084 SIC = .095 FERC = 2.387 TMDS = 16.262 TENS = 1713.887 TEMP = 21.300 DEPT = 9832.500 CCL = 10923.000 GR = 22.494 LIRI = 1.371 COIR = .466 STUN = .006 ITCR = 5816.774 HPLI = 1.348 TCCR = 9587.844 OAI = 3.233 SIAI = 3.657 RIC = .607 KIC = .399 HIC = .073 SIIC = .072 CLIC = .020 CAIC = .002 FEIC = .082 SIC = .095 FERC = 2.406 TMDS = 15.620 TENS = 1730.662 TEMP = 21.400 DEPT = 9782.500 CCL = 10923.000 GR = 17.650 LIRI = 1.353 COIR = .475 STUN = .007 ITCR = 5423.678 HPLI = 1.321 TCCR = 9991.037 OAI = 4.512 SIAI = 3.339 RIC = .543 KIC = .400 HIC = .071 SIIC = .075 CLIC = .019 CAIC = .002 FEIC = .082 SIC = .098 FERC = 2.403 TMDS = 13.699 TENS = 1722.274 TEMP = 21.600 DEPT = 9732.500 CCL = 5461.000 GR = 20.774 LIRI = 1.365 COIR = .480 STUN = .007 ITCR = 5648.818 HPLI = 1.299 TCCR = 9985.787 OAI = 2.925 SIAI = 3.143 RIC = .566 KIC = .395 HIC = .066 SIIC = .071 CLIC = .016 CAIC = .002 FEIC = .089 SIC = .099 FERC = 2.370 TMDS = 16.184 TENS = 1730.662 TEMP = 21.800 DEPT = 9682.500 CCL = 10923.000 GR = 39.510 LIRI = 1.324 COIR = .477 STUN = .007 ITCR = 5517.274 HPLI = 1.392 TCCR = 8752.330 OAI = 2.983 SIAI = 3.999 RIC = .630 KIC = .399 HIC = .071 SIIC = .070 CLIC = .018 CAIC = .002 FEIC = .084 SIC = .094 FERC = 2.434 TMDS = 17.803 TENS = 1705.499 TEMP = 22.000 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 007 --- 93/03/20 Page 22 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 1024 --- LO --- COMCEN.008 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 ~-- 0 --- 93/03/20 --- 1024 --- LO --- COMCEN.007 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 10035.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9648.0 25-JAN-93 2.23 1015 25-JAN-93 10036.0 10030.0 9660.0 10020.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 114434S OO5 8.500 10236.0 Page 23 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): WATER 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. Page 24 DEPT F 00000000 0 4 i 68 CCL PSGT 920018 MV 00000000 0 4 1 68 GR PSGT 920018 GAPI 00000000 0 4 i 68 LIRI PSGT 920018 00000000 0 4 i 68 COIR PSGT 920018 00000000 0 4 i 68 STUN PSGT 920018 00000000 0 4 i 68 ITCR PSGT 920018 00000000 0 4 I 68 HPLI PSGT 920018 00000000 0 4 1 68 TCCR PSGT 920018 00000000 0 4 i 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 I 68 RIC PSGT 920018 00000000 0 4 i 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 I 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 i 68 FEIC PSGT 920018 00000000 0 4 i 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10035.000 CCL = 10923.000 GR = 51.995 LIRI = 1.438 COIR = .463 STUN = .006 ITCR = 5401.341 HPLI = 1.366 TCCR = 7611.026 OAI = 8.009 SIAI = 10.337 RIC = .710 KIC = .402 HIC = .070 SIIC = .062 CLIC = .021 CAIC = .003 FEIC = .086 SIC = .095 FERC = 2.468 TMDS = 41.016 TENS = 1009.343 TEMP = 22.400 DEPT = 9985.000 CCL = 10923.000 GR = 43.811 LIRI = 1.331 COIR = .475 STUN = .007 ITCR = 5548.317 HPLI = 1.334 TCCR = 8929.645 OAI = 3.924 SIAI = 4.648 RIC = .621 KIC = .394 HIC = .077 SIIC = .069 CLIC = .013 CAIC = .002 FEIC = .087 SIC = .093 FERC = 2.409 TMDS = 15.577 TENS = 1739.049 TEMP = 22.700 DEPT = 9935.000 CCL = 10923.000 GR = 40.723 LIRI = 1.337 COIR = .464 STUN = .007 ITCR = 5508.146 HPLI = 1.333 TCCR = 9329.422 OAI = 4.033 SIAI = 4.637 RIC = .590 KIC = .395 HIC = .072 SIIC = .071 CLIC = .015 CAIC = .003 FEIC = .085 SIC = .095 FERC = 2.457 TMDS = 15.632 TENS = 1722.274 TEMP = 23.000 Page 25 DEPT = 9885.000 CCL = 10923.000 GR = 40.418 LIRI = 1.351 COIR = .474 STUN = .006 ITCR = 5632.869 HPLI = 1.368 TCCR = 9302.100 OAI = 4.716 SIAI = 4.137 RIC = .606 KIC = .400 HIC = .075 SIIC = .070 CLIC = .014 CAIC = .003 FEIC = .085 SIC = .093 FERC = 2.419 TMDS = 16.199 TENS = 1688.724 TEMP = 23.200 DEPT = 9835.000 CCL = 10923.000 GR = 43.496 LIRI = 1.364 COIR = .477 STUN = .007 ITCR = 5442.879 HPLI = 1.311 TCCR = 9088.949 OAI = 3.857 SIAI = 4.054 RIC = .599 KIC = .397 HIC = .072 SIIC = .071 CLIC = .015 CAIC = .003 FEIC = .084 SIC = .096 FERC = 2.457 TMDS = 16.493 TENS = 1730.662 TEMP = 23.600 DEPT = 9785.000 CCL = 10923.000 GR = 36.788 LIRI = 1.337 COIR = .473 STUN = .006 ITCR = 5879.286 HPLI = 1.309 TCCR = 10126.490 OAI = 4.260 SIAI = 4.367 RIC = .581 KIC = .398 HIC = .070 SIIC = .074 CLIC = .018 CAIC = .001 FEIC = .084 SIC = .099 FERC = 2.446 TMDS = 14.110 TENS = 1705.499 TEMP = 23.800 DEPT = 9735.000 CCL = 10923.000 GR = 40.801 LIRI = 1.322 COIR = .474 STUN = .006 ITCR = 5569.004 HPLI = 1.332 TCCR = 10059.190 OAI = 2.497 SIAI = 4.279 RIC = .554 KIC = .397 HIC = .066 SIIC = .072 CLIC = .016 CAIC = .003 FEIC = .086 SIC = .097 FERC = 2.436 TMDS = 15.849 TENS = 1646.787 TEMP = 24.300 DEPT = 9685.000 CCL = 10923.000 GR = 51.434 LIRI = 1.361 COIR = .483 STUN = .008 ITCR = 5360.875 HPLI = 1.317 TCCR = 8605.363 OAI = 3.958 SIAI = 4.890 RIC = .623 KIC = .396 HIC = .068 SIIC = .067 CLIC = .014 CAIC = .004 FEIC = .087 SIC = .098 FERC = 2.494 TMDS = 19.380 TENS = 1646.787 TEMP = 24.700 FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.008 SERVICE SUB LEVEL NAME --- 0 VERSION NUMBER --- 5 DATE OF GENERATION --- 93/03/20 MAX. PHYSICAL RECORD LENGTH --- 1024 FILE TYPE --- LO Page 26 OPTIONAL NEXT FILE NAME --- COMCEN.009 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 --- 93/03/20 --- 1024 --- LO --- COMCEN.008 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 10033.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9635.5 25-JAN-93 2.23 1015 10036.0 10030.0 9660.0 10020.0 300.0 NO 25-JAN-93 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ 114434S OO5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 10236.0 BOREHOLE CONDITIONS FLUID TYPE: WATER Page 27 FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY I 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F CCL PSGT 920018 MV API CODE FILE# 00000000 0 00000000 0 SIZE #SAMP REPR. 4 i 68 4 1 68 Page 28 GR PSGT 920018 GAPI 00000000 0 4 1 68 LIRI PSGT 920018 00000000 0 4 1 68 COIR PSGT 920018 00000000 0 4 1 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 1 68 HPLI PSGT 920018 00000000 0 4 1 68 TCCR PSGT 920018 00000000 0 4 1 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 10033.500 CCL = 10923.000 GR = 69.142 LIRI = 1.426 COIR = .476 STUN = .007 ITCR = 5028.046 HPLI = 1.313 TCCR = 7104.632 OAI = 7.601 SIAI = 11.906 RIC = .708 KIC = .402 HIC = .068 SIIC = .060 CLIC = .021 CAIC = .003 FEIC = .088 SIC = .099 FERC = 2.384 TMDS = 22.791 TENS = 1042.893 TEMP = 25.200 DEPT = 9983.500 CCL = 10923.000 GR = 61.137 LIRI = 1.371 COIR = .519 STUN = .008 ITCR = 5179.037 HPLI = 1.320 TCCR = 8539.305 OAI = 3.177 SIAI = 4.416 RIC = .606 KIC = .396 HIC = .075 SIIC = .068 CLIC = .015 CAIC = .002 FEIC = .086 SIC = .095 FERC = 2.417 TMDS = 15.722 TENS = 1646.787 TEMP = 25.500 DEPT = 9933.500 CCL = 10923.000 GR = 52.415 LIRI = 1.344 COIR = .490 STUN = .007 ITCR = 5538.182 HPLI = 1.312 TCCR = 9402.021 OAI = 3.413 SIAI = 4.174 RIC = .589 KIC = .397 HIC = .071 SIIC = .069 CLIC = .017 CAIC = .003 FEIC = .086 SIC = .097 FERC = 2.445 TMDS = 16.625 TENS = 1663.562 TEMP = 25.800 DEPT = 9883.500 CCL = 10923.000 GR = 56.572 LIRI = 1.350 COIR = .481 STUN = .007 Page 29 ITCR = 5454.274 HPLI = 1.316 TCCR = 8935.117 OAI = 3.771 SIAI = 4.836 RIC = .610 KIC = .397 NIC = .075 SIIC = .070 CLIC = .016 CAIC = .003 FEIC = .085 SIC = .095 FERC = 2.377 TMDS = 17.251 TENS = 1646.787 TEMP = 26.100 DEPT = 9833.500 CCL = 10923.000 GR = 57.192 LIRI = 1.373 COIR = .466 STUN = .007 ITCR = 5355.922 HPLI = 1.372 TCCR = 9124.143 OAI = 2.706 SIAI = 4.451 RIC = .587 KIC = .398 HIC = .073 SIIC = .075 CLIC = .018 CAIC = .002 FEIC = .081 SIC = .094 FERC = 2.462 TMDS = 15.866 TENS = 1663.562 TEMP = 26.600 DEPT = 9783.500 CCL = 10923.000 GR = 51.988 LIRI = 1.368 COIR = .469 STUN = .007 ITCR = 5498.751 HPLI = 1.310 TCCR = 9876.662 OAI = 3.571 SIAI = 4.034 RIC = .557 KIC = .399 HIC = .069 SIIC = .078 CLIC = .018 CAIC = .003 FEIC = .081 SIC = .098 FERC = 2.346 TMDS = 13.496 TENS = 1671.949 TEMP = 27.000 DEPT = 9733.500 CCL = 10923.000 GR = 60.909 LIRI = 1.352 COIR = .468 STUN = .006 ITCR = 5657.165 HPLI = 1.315 TCCR = 9962.412 OAI = 3.069 SIAI = 4.789 RIC = .568 KIC = .397 HIC = .068 SIIC = .072 CLIC = .017 CAIC = .002 FEIC = .086 SIC = .099 FERC = 2.396 TMDS = 16.344 TENS = 1680.337 TEMP = 27.300 DEPT = 9683.500 CCL = 10923.000 GR = 68.268 LIRI = 1.344 COIR = .486 STUN = .007 ITCR = 5583.518 HPLI = 1.343 TCCR = 8838.172 OAI = 3.640 SIAI = 4.921 RIC = .632 KIC = .398 HIC = .071 SIIC = .068 CLIC = .017 CAIC = .003 FEIC = .086 SIC = .096 FERC = 2.376 TMDS = 17.499 TENS = 1646.787 TEMP = 27.700 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.009 SERVICE SUB LEVEL NAME --- 0 VERSION NUMBER --- 5 DATE OF GENERATION --- 93/03/20 MAX. PHYSICAL RECORD LENGTH --- 1024 FILE TYPE --- LO OPTIONAL NEXT FILE NAME --- COMCEN.010 Page 30 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 --- 93/03/20 --- 1024 --- LO --- COMCEN.O09 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 10034.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9648.5 25-JAN-93 2.23 1015 25-JAN-93 10036.0 10030.0 9660.0 10020.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): 114434S 0O5 8.500 10236.0 WATER Page 31 BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #4. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F CCL PSGT 920018 MV GR PSGT 920018 GAPI LIRI PSGT 920018 API CODE FILE~ SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 1 68 i 68 1 68 Page 32 COIR PSGT 920018 00000000 0 4 1 68 STUN PSGT 920018 00000000 0 4 1 68 ITCR PSGT 920018 00000000 0 4 1 68 HPLI PSGT 920018 00000000 0 4 1 68 TCCR PSGT 920018 00000000 0 4 1 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 1 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 ! 68 SIIC PSGT 920018 00000000 0 4 1 68 CLIC PSGT 920018 00000000 0 4 1 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 1 68 TEMP PSGT 920018 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 10034.500 CCL = 10923.000 GR = 87.949 LIRI = 1.428 COIR = .470 STUN = .006 ITCR = 5126.496 HPLI = 1.315 TCCR = 7322.815 OAI = 10.594 SIAI = 14.498 RIC = .700 KIC = .399 HIC = .066 SIIC = .062 CLIC = .017 CAIC .003 FEIC = .090 SIC = .098 FERC = 2.369 TMDS = 28.961 TENS = 1219.029 TEMP = 28.500 DEPT = 9984.500 CCL. = 10923.000 GR = 69.494 LIRI = 1.356 COIR = .522 STUN = .007 ITCR = 5347.208 HPLI = 1.347 TCCR = 8638.861 OAI = 3.702 SIAI = 5.224 RIC = .619 KIC = .395 HIC = .075 SIIC = .069 CLIC = .010 CAIC = .003 FEIC = .088 SIC = .093 FERC = 2.385 TMDS = 15.597 TENS = 1814.536 TEMP = 28.900 DEPT = 9934.500 CCL = 10923.000 GR = 60.574 LIRI = 1.373 COIR = .474 STUN = .007 ITCR = 5479.230 HPLI = 1.329 TCCR = 9179.922 OAI = 3.912 SIAI = 5.068 RIC = .597 KIC = .397 HIC = .069 SIIC = .071 CLIC = .015 CAIC = .002 F~IC = .087 SIC = .096 FERC = 2.368 TMDS = 15.485 TENS = 1831.311 TEMP = 29.300 DEPT = 9884.500 CCL = 10923.000 GR = 62.954 LIRI = 1.371 COIR = .481 STUN = .007 ITCR = 5270.390 HPLI = 1.381 TCCR = 8656.756 OAI = 3.656 SIAI= 4.884 RIC = .609 Page 33 KIC = .396 HIC = .074 SIIC = .073 CLIC = .013 CAIC = .004 FEIC = .083 SIC = .091 FERC = 2.508 TMDS = 16.417 TENS = 1839.698 TEMP = 29.800 DEPT = 9834.500 CCL = 10923.000 GR = 64.587 LIRI = 1.351 COIR = .467 STUN = .007 ITCR = 5339.331 HPLI = 1.318 TCCR = 8980.346 OAI = 3.820 SIAI = 5.630 RIC = .595 KIC = .397 HIC = .071 SIIC = .071 CLIC = .018 CAIC = .003 FEIC = .084 SIC = .096 FERC = 2.411 TMDS = 15.971 TENS = 1873.248 TEMP = 30.100 DEPT = 9784.500 CCL = 10923.000 GR = 61.527 LIRI = 1.337 COIR = .464 STUN = .006 ITCR = 5616.474 HPLI = 1.286 TCCR = 9929.377 OAI = 3.306 SIAI = 5.207 RIC = .566 KIC = .399 HIC = .069 SIIC = .073 CLIC = .018 CAIC = .002 FEIC = .084 SIC = .100 FERC = 2.388 TMDS = 13.235 TENS = 1881.635 TEMP = 30.500 DEPT = 9734.500 CCL = 10923.000 GR = 64.272 LIRI = 1.329 COIR = .466 STUN = .007 ITCR = 5436.791 HPLI = 1.347 TCCR = 9837.002 OAI = 2.352 SIAI = 4.476 RIC = .553 KIC = .397 HIC = .066 SIIC = .072 CLIC = .017 CAIC = .002 FEIC = .086 SIC = .097 FERC = 2.462 TMDS = 14.702 TENS = 1873.248 TEMP = 30.800 DEPT = 9684.500 CCL = 10923.000 GR = 79.645 LIRI = 1.335 COIR = .502 STUN = .007 ITCR = 5106.437 HPLI = 1.333 TCCR = 8482.063 OAI = 3.121 SIAI = 5.560 RIC = .602 KIC = .397 HIC = .068 SIIC = .070 CLIC = .016 CAIC = .003 FEIC = .086 SIC = .097 FERC = 2.377 TMDS = 19.587 TENS = 1881.635 TEMP = 31.200 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.010 SERVICE SUB LEVEL NAME --- 0 VERSION NUMBER --- 5 DATE OF GENERATION --- 93/03/20 MAX. PHYSICAL RECORD LENGTH --- 1024 FILE TYPE --- LO OPTIONAL NEXT FILE NAME --- COMCEN.011 ****************************************************************************** Page 34 FILE HEADER RECORD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 --- 93/03/20 --- 1024 --- LO --- COMCEN.010 TYPE 128 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 10034.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9650.0 25-JAN-93 2.23 1015 25-JAN-93 10036.0 10030.0 9660.0 10020.0 300.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ 114434S OO5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 10236.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): WATER Page 35 FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #5. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F CCL PSGT 920018 MV GR PSGT 920018 GAPI LIRI PSGT 920018 COIR PSGT 920018 STUN PSGT 920018 API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 Page 36 ITCR PSGT 920018 00000000 0 4 i 68 HPLI PSGT 920018 00000000 0 4 1 68 TCCR PSGT 920018 00000000 0 4 1 68 OAI PSGT 920018 00000000 0 4 1 68 SIAI PSGT 920018 00000000 0 4 1 68 RIC PSGT 920018 00000000 0 4 i 68 KIC PSGT 920018 00000000 0 4 1 68 HIC PSGT 920018 00000000 0 4 1 68 SIIC PSGT 920018 00000000 0 4 I 68 CLIC PSGT 920018 00000000 0 4 i 68 CAIC PSGT 920018 00000000 0 4 1 68 FEIC PSGT 920018 00000000 0 4 1 68 SIC PSGT 920018 00000000 0 4 1 68 FERC PSGT 920018 00000000 0 4 1 68 TMDS PSGT 920018 CU 00000000 0 4 1 68 TENS PSGT 920018 LB 00000000 0 4 i 68 TEMP PSGT 920018 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10034.000 CCL = 10923.000 GR = 154.879 LIRI = 1.449 COIR = .477 STUN = .007 ITCR = 5234.813 HPLI = 1.342 TCCR = 7344.382 OAI = 9.655 SIAI = 9.815 RIC = .713 KIC = .397 HIC = .066 SIIC = .061 CLIC = .017 CAIC = .003 FEIC = .090 SIC = .095 FERC = 2.422 TMDS = 25.932 TENS = 1101.604 TEMP = 31.600 DEPT = 9984.000 CCL = 10923.000 GR = 82.525 LIRI = 1.385 COIR = .501 STUN = .007 ITCR = 5218.566 HPLI = 1.344 TCCR = 8571.082 OAI = 3.129 SIAI = 6.411 RIC = .609 KIC = .394 HIC = .076 SIIC = .069 CLIC = .014 CAIC = .001 FEIC = .088 SIC = .093 FERC = 2.427 TMDS = 16.328 TENS = 1898.410 TEMP = 31.900 DEPT = 9934.000 CCL = 10683.000 GR = 73.374 LIRI = 1.364 COIR = .471 STUN = .007 ITCR = 5249.831 HPLI = 1.318 TCCR = 9071.627 OAI = 3.372 SIAI = 5.272 RIC = .579 KIC = .395 HIC = .070 SIIC = .071 CLIC = .014 CAIC = .003 FEIC = .086 SIC = .097 FERC = 2.400 TMDS = 15.744 TENS = 1881.635 TEMP = 32.300 DEPT = 9884.000 CCL = 10923.000 GR = 74.482 LIRI = 1.326 COIR = .468 STUN = .006 ITCR = 5370.872 HPLI = 1.298 TCCR = 8753.111 OAI = 3.111 SIAI = 5.113 RIC = .614 KIC = .399 HIC = .074 SIIC = .070 CLIC = .016 CAIC = .003 FEIC = .084 Page 37 SIC = .096 FERC = 2.416 TMDS = 16.137 TENS = 1881.635 TEMP = 32.600 DEPT = 9834.000 CCL = 10923.000 GR = 71.989 LIRI = 1.389 COIR = .475 STUN = .007 ITCR = 5400.441 HPLI = 1.331 TCCR = 9000.682 OAI = 3.479 SIAI = 5.738 RIC = .600 KIC = .399 HIC = .073 SIIC = .070 CLIC = .019 CAIC = .002 FEIC = .084 SIC = .096 FERC = 2.371 TMDS = 16.187 TENS = 1856.473 TEMP = 32.900 DEPT = 9784.000 CCL = 10923.000 GR = 66.795 LIRI = 1.344 COIR = .470 STUN = .007 ITCR = 5308.436 HPLI = 1.334 TCCR = 9673.879 OAI = 2.486 SIAI = 4.856 RIC = .549 KIC = .397 HIC = .071 SIIC = .075 CLIC = .017 CAIC = .003 FEIC = .083 SIC = .096 FERC = 2.402 TMDS = 14.546 TENS = 1856.473 TEMP = 33.300 DEPT = 9734.000 CCL = 10923.000 GR = 74.439 LIRI = 1.338 COIR = .479 STUN = .007 ITCR = 5378.833 HPLI = 1.321 TCCR = 9790.941 OAI = 2.912 SIAI = 5.184 RIC = .549 KIC .= .397 HIC = .066 SIIC = .072 CLIC = .017 CAIC = .002 FEIC = .087 SIC = .097 FERC = 2.312 TMDS = 15.389 TENS = 1873.248 TEMP = 33.500 DEPT = 9684.000 CCL = 10923.000 GR = 92.205 LIRI = 1.340 COIR = .502 STUN = .007 ITCR = 5180.866 HPLI = 1.342 TCCR = 8477.906 OAI = 3.042 SIAI = 5.848 RIC = .611 KIC = .394 HIC = .070 SIIC = .068 CLIC = .015 CAIC = .002 FEIC = .088 SIC = .097 FERC = 2.460 TMDS = 20.620 TENS = 1890.023 TEMP = 33.800 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.011 SERVICE SUB LEVEL NAME --- 0 VERSION NUMBER --- 5 DATE OF GENERATION --- 93/03/20 MAX. PHYSICAL RECORD LENGTH --- 1024 FILE TYPE --- LO OPTIONAL NEXT FILE NAME --- COMCEN.012 ****************************************************************************** FILE HEADER RECORD ............ TYPE 128 Page 38 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.012 --- 93~03~20 --- 1024 --- LO --- COMCEN.011 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 12 STATIONS & COMPUTED RESULTS DEPTH INCREMENT 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ REMARKS: 10030.0 9655.0 THIS FILE CONTAINS COMPUTED RESULTS FOR: VSH - SHALE VOLUME SOIL - CASED HOLE OIL SATURATION PHSO - CASED HOLE BULK VOUME OIL PHSW - OPEN HOLE BULK VOLUME WATER PHIE - EFFECTIVE POROSITY = SPHI * (1.0-VSH) ALSO INCLUDED IS OPEN HOLE DATA PROVIDED BY ARCO: OHGR - OPEN HOLE GAMMA RAY OHDT - OPEN HOLE DELTA T OHSW - OPEN HOLE WATER SATURATION RHOB - OPEN HOLE BULK DENSITY SPHI - OPEN HOLE SONIC POROSITY AVERAGE OF PASS #1 - #5 USED FOR COMPUTATIONS. OPEN HOLE GAMMA RAY & SONIC POROSITY USED TO COMPUTE VSH & PHIE. OPEN HOLE DATA HAS BEEN INTERPOLATED FROM 1 SAMPLE/FT. TO 4 SAMPLES/FT. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 72 4 1 66 1 5 1 66 1 8 4 73 30 Page 39 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILES SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 OHGR OH 920018 GAPI 00000000 0 4 i 68 OHDT OH 920018 US/F 00000000 0 4 1 68 OHSW OH 920018 % 00000000 0 4 1 68 RHOB' OH 920018 G/C3 00000000 0 4 i 68 SPHI OH 920018 % 00000000 0 4 1 68 VSH CHARM 920018 % 00000000 0 4 i 68 SOIL CHARM 920018 % 00000000 0 4 1 68 PHSO CHARM 920018 % 00000000 0 4 1 68 PHSW CHARM 920018 % 00000000 0 4 i 68 PHIE CHARM 920018 % 00000000 0 4 1 68 GR PSGT 920018 GAPI 00000000 0 4 I 68 LIRI PSGT 920018 00000000 0 4 1 68 COIR PSGT 920018 00000000 0 4 i 68 STUN PSGT 920018 00000000 0 4 i 68 RIC PSGT 920018 00000000 0 4 i 68 SIIC PSGT 920018 00000000 0 4 I 68 CAIC PSGT 920018 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10030.000 OHGR = 101.901 OHDT = 72.838 OHSW = .822 RHOB = 2.606 SPHI = .133 VSH = .990 SOIL = .000 PHSO = .001 PNSW = .001 PHIE = .001 GR = 18.807 LIRI = 1.430 COIR = .471 STUN = .007 RIC = .716 SIIC = .061 CAIC = .003 DEPT = 9980.000 OHGR = 29.472 OHDT = 87.702 OHSW = .397 RHOB = 2.278 SPHI = .219 VSH = .094 SOIL = .713 PHSO = .057 PHSW = .057 PHIE = .198 GR = 24.801 LIRI = 1.360 COIR = .500 STUN = .007 RIC = .604 SIIC = .068 CAIC = .003 DEPT = 9930.000 OHGR = 18.152 OHDT = 89.468 OHSW = .351 RHOB = 2.252 SPHI = .229 VSH = .019 SOIL = .331 PHSO = .150 PHSW = .079 PHIE = .225 GR = 21.065 LIRI = 1.358 COIR = .475 STUN = .007 RIC = .595 SIIC = .073 CAIC = .002 Page 40 DEPT = 9880.000 OHGR = 17.809 OHDT = 102.904 ONSW = .321 RHOB = 2.219 SPHI = .303 VSH = .016 SOIL = .349 PHSO = .194 PHSW = .096 PHIE = .298 GR = 18.519 LIRI = 1.357 COIR = .477 STUN = .007 RIC = .625 SIIC = .071 CAIC = .003 DEPT = 9830.000 OHGR = 20.481 OHDT = 87.619 OHSW = .358 RHOB = 2.281 SPNI = .234 VSH = .033 SOIL = .264 PHSO = .167 PHSW = .081 PHIE = .226 GR = 19.193 LIRI = 1.350 COIR = .468 STUN = .006 RIC = .586 SIIC = .076 CAIC = .002 DEPT = 9780.000 OHGR = 22.610 OHDT = 83.543 OHSW = .250 RHOB = 2.356 SPHI = .212 VSH = .047 SOIL = .484 PHSO = .104 PHSW = .051 PHIE = .202 GR = 16.995 LIRI = 1.330 COIR = .478 STUN = .007 RIC = .552 SIIC = .074 CAIC = .003 DEPT = 9730.000 OHGR = 23.923 OHDT = 91.220 OHSW = .271 RHOB = 2.289 SPHI = .244 VSH = .055 SOIL = .324 PHSO = .156 PHSW = .063 PHIE = .231 GR = 19.201 LIRI = 1.350 COIR = .473 STUN = .006 RIC = .580 SIIC = .069 CAIC = .002 DEPT = 9680.000 OHGR = 33.620 OHDT = 91.192 OHSW = .289 RHOB = 2.325 SPHI = .244 VSH = .126 SOIL = .697 PHSO = .065 PHSW = .062 PHIE = .213 GR = 24.679 LIRI = 1.344 COIR = .499 STUN = .007 RIC = .568 SIIC = .067 CAIC = .003 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.012 --- 93/03/20 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME --- COMCEN DATE --- 93/03/20 ORIGIN OF DATA --- ANCN TAPE NAME --- 0 Page 41 TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: ------ i ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 93/03/20 --- ANCH --- 920018 ****************************************************************************** END OF TAPE ENCOUNTERED Page 42 DJREC'T D-JGiTA[ ..... LOGGING PROCESSED U U U U U U ij ij U tJ U U U U U ij U U ij U i.j U U U M M M M U U F:! F't !:i PI l"l Pt nii ..... P1 i"i !'q M U Lt ,. i'~ l:l [1 ......... - ........... u u r,1N r'l rq rq F-'] N p~ U U i,i bi H H i,i i',ii,i i ii i ~i i'i i:i ;?,i M i',i J t J ) Fq t'fl M U U H M H H U U i'i t-'i, hi M M H H H M M ~-'i F' i::' F' F'P P F' P P F'i ? 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PF;:UDHOE B~Y DATE LU~4L:.L~: i0-29-~'~ ................ NORTH SLOPE .................................... f4 L. Ft ~5 K. ~ .................................... 2iii8,000 ............................................... 0 n~q, 0 Min 0 0 Sec: N 0 Dag, 0 blin, O, 0 S~, kt ........................ i ON ..................................................... 62, 00'0 .................................................. F T 6i , 000 .................................................. FT 28,0 O0 .................................................. FT H S ....................................................... KE; ...................................................... 90 c, 0 00 29/~ 0/89 ................................................ NOR'TH SLOPE NORTH SLOPE ..................................... R 0 E D E R ..................... , .............. LOkiTHER/HORRIS i 0236,000 ............................................... FT 0, 000 ................................................... F T 0,000 ' , .......................... F T O, 000 ........................................... , ....... HR 827,000 ................................................. HR 0., 00 0 ................................................... O, 0 0 0 ....................................... ............ DE~]F C R L! D E ..................................... 0 ~ 0 O 0 ................................................... C P 0,00 0 ................................................... 0,0 0 0 .................................................... O, 0 0 0 ................................................... - O0 0 ' 000 O, 000 ................................................... LI !q PI i~1 0 H i'! H 0 H H H S C 0 E:: E E R¢.,_,'"" '-' '"'n M C S T i!CSS CS rS: 0 ~-~ T E N 7' 8 U N i T T Y F' El ,-~ nr~n DEGF 7 ~ P 0 .............................. 8:500 C A T K-i S i Z E C 0 [;..' E .S~ R R 0 R 8 ~_'":' 4 6 8 () 2 i 2 6 5 0 2-.: '-!- 6 8 COMMENT RE:CORDS ........... ~.-..ion Comment t :, t:;f. JRFF:iCE: ...... ~ o,-af.~,on Cornme~,~. ,,,.. 2~ Loc.~tion L]om~',~+ ~ Loc.stion Comment 4: ,~ii~s. C:ommen~-. ~:. L.O~:; CORRELATE~'~... Fiie Comment 2: CRUDE ~ 20 8BL ci1~. Comment z,: ,.~tEL. L, r ..... :::< b 45 F S L :+::+:L:'[S +ape.., wr. itten b,..'- :... i~NC:HORK4GE COMPiJT:Nr':;, . _ ;...=N'-'~-"~: ER ~* ,,':.~! 1 cur. ye and 'gool mr,.emonics u:e:d ar'e those .whi::zh · ** Hsi]. ibu~:ton cur-ve and tool ,~nemc, nic:., mo~t c io~ei,,~ match ,- - -~- -+: -, .... :e- -,. H< :e. :+; :'k. :~,:': :+: :+: :~;: :+: :~ :+: :~: :+: :~': :~,: :+: :,~: :e. :%: :e. :~: :e. :+: :~ :+: :.~: :+: :.f: ~i': :~: :~. HALL I BURTON. TO S C:H LU.~,JB ERG E R TOP E',O T TO!'4, DEPTH J .0250, O0 0232 00 F,~2~'-' ,', i"~ 0232 O0 0232 0 0 0232 00 0232 00 0232:: '00 E N T R Y TY'PE ::; i z:h_ C 0 [:, E 'i 6 i 66 0 i 6 6 I 6,..r': a ,.. :...im .~ p e: t.. i ¢ i c a t i o r',. b I c, c k s u b ,.- t,.,, ~.,.~ ,=.,. 0 'T'e;r-r~.~inator. ( no mor, a ant,,"ie~ ;:, DATA .~'ORMAT '~ _ .~ · : oP~'~C 1 F I RAT I ON© SERV!CE SERVICE H N E i"] i D 0 R [:: E R ~. P RC: ~ :SIZE LVL SHPL RC F'F.'.OCESS i?..iDi.C:ATORS 02 32 . 0 00 0':200, 000 0! 00, 000 n n 00 r, 00 'PgO0, 000 9800. 000 9600:000 o.... 500, n_ 00 9400, 000 0,000 45 .'~ n 0 24,600 22 0 00 27" 4.00 SO 500 23 300 84- 700 O~ 400 ;-qH O00 7:00 ?..,.'~ ,..u 5 9 00 492 700 49:3 i O0 431 500 462 800 5i4 700 46:5 :.-'ZOO 370 '~00 $56 rl :": 0 6OO lj...:.: 000 ~00 E. O0 2.52'3 24.240 24 65 0 2,4 ._'3;30 27 910 ~5 560 2i 860 26 ~ ~' '"' '"e 660 ~0 890 Maximur;': length; !024. V.e,:-s i or,, ~; £'.,ate: H a x i m ~...! !.r, i e n g t.h: t 0 2 4 F i i e t !...., p e; L 0 P r. e v i o :..i s .F' i i e; C H W N F H COi. JN STAT C T R Y APl' N L¢'~T I L 0 N 6 SECT C". !..-.1N El,:: D EDF EGL LMF r.:, rd F RUN T i ME [:,ATE L C: C ._-,ON L U i-~ FL LUL E N G i D D DL CBD i CSL.~ TC:S TLAE: B H T MRT M T MSS DFD M u. ;' ,'" D F P H DF'L RM RMF MFST MFSS R M C ARCOr4LR.=~..R"' 'q'"' iNC, ................ [::,S, 3'-29 APi NUM; 50-029-2~ii~.~ ................ PRUDHOE BAY DATE LOGGED: i NORTH SLOPE · ~ ..... 0 D~q, 0 Min, O, 0 Smc, N 0 De~, 0 Min, O, 0 Sec, W ........................ i ON !5E 6 2, 0 0 0 , .............................................. F T 6 ~ , 0 O0 .................................................... FT 2 ~, 0 0 '0 ....................... ............................ F T MS 9 0 8,0 0 8 29 / i 0 / 89 NORTH Si.._ OPE .................................... NORTH ~' =uOPE ROEDER .................................... ~_~ OWTHER/MORR IS 'i 02i 3. OOO ................................................ 0, '000 ................................................... 0, O 00 lO 2 ~ i , 0 0 O ................................. 0 0~¢' ....... n0c~ 0, 000 0, 000 CRUDE FT FT kl FT HR HR [;,E GF DFGF L i:3 / G U !'-' 0 H M M ..,',~-'i,._ ~ I [_oc.(~tion C,:,mmci'",~:. i :. SURFACE; ;'-'i" :-~-.,'.,iL. ~ 545" (Jeii L. oc.~t, ion C:ommr~nt 2: l,t~i ]. LOC.~, ior~ CorDmc~n't ~ ~.¢e~ J Loc~tion Com~r'~t 4', " I C: ~ L_O~S CnRPELATED TO BrS, ~OG Ri i~4 AFTEp ..~,i~ii ...... Fi l,~ Com~snt 2: CRUDE ~., 20 8BL METHP~40i , D[:,L~, '-"'¢'"T¢'~-'.:,~.::,.=~-~ t. Je:ii Fit~:: C:oament ;3: WELL. PiJMPING 443 BSL DEAD AND TOOLS USED TO L~S t..?.-...pe wr. it.t~n b,..,~ ANCHORAGE Cr'""~'~t"rING C~'NT~: Ali curve and t. ool mnmmonics used are t. ho,~e which ~ost clos~i~ H.~i i :ibur-(;on curve and ,,.ou i mne:~¢onics H~LL ZBURTOH TO SCHLUMBERGER TOP BOTTOM t t,:,,.~t SERVICE UNYT MNEM iCE U. 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