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192-141
RE• STATE OF ALASKA C E I V D 0 ALASKA OIL AND GAS CONSERVATION COM*N WELL COMPLETION OR RECOMPLETION REI AND LOG FEB 1 4 7l1R la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 1b.Well Class: 2OAAC 25.105 20AAC 25.110 Develo mj t ,Jr% , GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero p t Service m Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,.or Aband: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 1/19/2018 192-141 • 317-517 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/29/1992 50-029-22320-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 1/17/1993 PBU 09-51 • Surface: 1023'FSL,143'FWL,Sec.01,T1ON,R15E,UM • 9 Ref Elevations KB 54.80 • 17. Field/Pool(s): Top of Productive Interval: 2612'FSL,5082'FWL,Sec.12,T1ON,R15E,UM GL 20.00 • BF 23.19 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 2342'FSL,4969'FEL,Sec.07,T1ON,R16E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 5489'/4765' ADL 028327&028345 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface: x- 718534 5942495 Zone - ASP 4 • 11990'/9299' . 74-017 y-TPI: x- 723580 5938951 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: y-Total Depth: x- 723867 5938690 Zone - ASP 4 None 1900'(Approx.) t Directional or Inclination Survey: Yes 0 (attached) No m 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, I suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,calipen, 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 GR/CNL/LDT/DLL/MSFL 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNif FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 36' 116' 36' 116' 30" 27 cu ft Arctic Set 13-3/8" 68# L-80 35' 3925' 35' 3701' 16" 2936 cu ft CS II,466 cu ft Class'G' 9-5/8" 47# L-80 32' 11417' 32' 8864' 12-1/4" 1104 cu ft Class'G',507 cu ft Class'G' 7" 29# 13Cr80 11247' 11990' 8735' 9299' 8-1/2" 217 cu ft Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD 11 If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 5-1/2"17#13Cr80 5515'-11297' 11219'/8714' A-13fi 1 tOO Cb x4-1/2"12.6#13Cr80 ---7 ,i. 'L ,',.)N 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. • -,.'r Was hydraulic fracturing used during completion? Yes 0 No Ei • I 11041$- Per 20 AAC 25.283(i)(2)attach electronic and printed information Fc E.I SCANNEDgIUN 1 ,8 2018 �k.- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED iill�� See Attached Y7. PRODUCTION TEST Date First Production: Not on Injection Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size. Gas-Oil Ratio: Test Period +..► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate •••41.' Form 10-407 Revised 5/2017 CONT��D��GE 2 Submit ORIGINAL only �� 6 /`Z/` b � RBDMS LL FE U18 A.,3i G • 28. CORE DATA • Conventional Core(s) Yes 0 No 0 Sidewall Cores Yes 0 No 0 k If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 11394' 8847' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 11394' 8847' CGL-Zone 3 11420' 8867' Base of CGL-Zone 2 11459' 8896' Base Sadlerochit-Kavik 11791' 9149' Formation at total depth: Kavik • 11791' 9149' 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: Sperry,Nathan Authorized Title: Inform- and Data C t r Contact Email: Nathan.Sperry@bp.com Authorized Signature: 21141)Q4 Contact Phone: 907-564-4258 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 WELL NAME: 09-51 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount& Kind of Material Used 11279' Pull 4-1/2" PXN Plug 11162' 10 Bbls Class'G' 9500'- 10933' 96 Bbls Class'G' 5515' Cut& Pull 7"x 5-1/2"Tubing 5489' Set Whipstock • Daily Report of Well Operations 09-51 ACTIVITYDATE SUMMARY T/I/O = SSV/500/150 TEMP = SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre Rig PPPOT-T: Stung into test port 100 psi, bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned all LDS, all moved freely. Pumped through void, good returns. Pressured void to 5,000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port 50 psi, bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned all LDS, all moved freely. Pumped through void, good returns. Pressured void to 3,500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min 11/29/2017 (PASS). Bled void to 0 psi. ***WELL SHUT IN ON ARRIVAL*** (side track) PULLED 4 1/2" PXN PRONG AND PLUG BODY FROM 11279' MD. 12/22/2017 ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTUE*** Assist with cement job (side track). Heat CH2 tanker#30019, 225 bbls of diesel from 10* F 12/29/2017 to 80* F. Heat vac truck#86056, 160 bbls from 23* F to 40* F. ***Well S/I upon arrival*** SLB Cementing Services. Job Scope: Fullbore Reservoir P&A(Pre-Rig) Initial T/1/O: 210/517/300 Pumped Down TBG: 5 bbls meOH spear 351 bbls 1% KCL, 29 bbls FW (380 bbls total) for L&K 10.0 bbls 15.8 PPG Class G CMT 7.0 bbls FW spacer 302.8 bbl DSL displacement(309.8 total displacement) Estimated TOC = 11192' MD. FWHP: 250/423/250 12/29/2017 ***Well S/I upon departure, Pad Op notified of well status*** ***WELL SHUT IN ON ARRIVAL***(sidetrack) BRUSH BPV PROFILE W/ DBL 7" BRUSH & 3.50" G. RING PULL TGE PRONG &T2-DGLV FROM ST#10 @ 10933' MD 1/4/2018 ***CONT. ON 01/05/18 WSR*** T/I/0=536/376/14. (LRS Unit 42 -Assist Slickline: State Witnessed (Bob Noble) CMIT- TxIA) CMIT TxIA to 4125 psi **PASSED** (max applied of 4400 psi) T/IA lost 36/41 psi in 1st 15 min. and lost 17/19 psi in 2nd 15 min. for ttl losses of T/IA 53/60 psi in a 30 minute test. Pass per Brad Elias. Pumped 3 bbls 60/40 methanol followed by 14.36 bbls diesel to reach test pressure. Bled back —17.2 bbls SL in control of well at LRS departure. IA/OA=OTG. Caution tags and AFE sign on well. 1/5/2018 FWHP=523/397/12 ***CONT. FROM 01/04/18 WSR*** (sidetrack) ATTEMPT TO PURGE CONTROL LINES BUT UNSUCCESSFUL PT CONTROL& BALANCE LINES TO 3000 PSI RUN PDS MTT LOG FROM 6000'TO SURFACE AS PER PROGRAM (GOOD DATA) PERFORM STATE WITNESSED TAG OF CEMENT AT 11,162' SLM WITH 3.25" CENT AND 3.0" SAMPLE BLR (cement smpl rec). LRS PERFORMS PASSING CMIT TxIA TO 4000 PSI. ***WELL TURNED OVER TO DSO*** 1/5/2018 *****STATION #10 LEFT OPEN POCKET***** • Daily Report of Well Operations 09-51 (SLB Unit 03548 - Balance Plug Attempt) Rig up SLB Cementers. Computer issues trying to connect pickup computer to cement van computer. After PT, discover frozen hardline. Due to several issues and daylight crew, 1/7/2018 decision made to postpone job. 1/7/2018 LRS Unit 70 Heated 260 bbls diesel to 80*F on CH2 tanker. 1/8/2018 LRS Unit 70 Heated 200 bbls diesel to 90*F on CH2 tanker. ***Continued on 01-09-18 Initial T/I/O =416/308/0 Temp = S/I. (SLB Unit 03548 - Balance Plug) Flow Path down the Tubing, thru STA# 10 Open Pocket at 10933' MD, up the IA to Return Tanks: Fluids Calculated in BOTH Tubing & IA: Diesel Freeze Protect= Surface to 3000' MD/2965' TVD Freshwater= 3000' MD to 9500' MD/7389' TVD 15.8 ppg Class G Cement= 9500' MD to 10933' MD/8497' TVD ***NOTE: 100221 (10-60) compliance information in "Fluids Tab". *** Cement in place at 18:00. 2000 psi compressive strength in 15 hrs. Tags hung on SV and IA CSG Valve. Valve crew contacted to service tree valves upon departure. 1/9/2018 Final T/I/O = 191/-9/550 ***Continued from 01-08-18 WSR*** LRS Unit 70 Heated 200 bbls diesel to 90*F on CH2 1/9/2018 tanker. ***WELL S/I ON ARRIVAL*** (Sidetrack) TAG TOC AT 9,382' SLM W/2.50" SAMPLE BAILER (Sample of dry cement, State witnessed). LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 4000 PSI (Jeff Jones witnessed).. DRIFT TO 6,868' SLM W/4.25" CENT (Target depth 6,000' md, Target od 4.15"). 1/11/2018 ***LRS IN CONTROL OF WELL ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** ***JOB STARTED ON 11-JANUARY-2018*** (SLB ELINE TUBING CUT) RU. STANDBY FOR LR TO CONTINUE NEGATIVE PT ON IA. 1/11/2018 ***JOB CONTINUED ON 12-JANUARY-2017*** T/I/O 0/0/30 Assist Slickline/CMIT TxIA**PASSED**to 4231/4322. State witnessed by Jeff Jones. Pumped 6.48 bbls dsl down tbg, jumpering TP to IA in order to bring TxIA to 463/424 as per slickline PE to prime up TxIA. Pumped 11.61 bbls down tbg,jumpering TP to IA in order to bring TxIA to test pressure. Max applied pressure = 4400 psi. Target pressure =4000 psi. Test#1 15 min TxIA lost 64/164. 30 min TxIA lost 33/61 psi. Total loss of 97/225 psi in 30 mins. Run test out another 15 min. 45 min TxIA lost 20/22. **FAIL** Pumped an additional .6 bbl dsl to reach test pressures. **Total bbls pumped = 18.7** Max applied pressure = 4400 psi. Target pressure = 4000 psi. Test#2 15 min TxIA lost 17/27. 30 mins TxIA lost 7/8. Total loss of 24/35 in 30 mins. Bleed TxIA back to 0 psi. Blead back 14.6 bbls dsl total. Monitor IA for no flow for 30 min to a bleed trailer. ***WSR continued on 1/11/2018 01/12/2018*** ***WSR continued from 01/11/2018*** Rig down. Valve positions= SV,WV,SSV=closed. 1/12/2018 IA/OA=OTG. MV= Open. FWHP=2/0/23 T/I/O= 129/VAC/24 Temp=amb CMIT-TxIA, MIT-OA(Post E-Line Jet Cut) ***WSR 1/12/2018 continued to 1/23/2018 r Daily Report of Well Operations 09-51 ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE TUBING CUT) INITIAL T/I/O = 0/0/0 RUN 1 RIH W/4.15" JET CUTTER. CUT TUBING AT 5500'. CCL TO CUTTER = 16.35'. CCL STOP DEPTH = 5483.65'. VERIFIED TxIA COMMUNICATION WITH TRIPLEX. CORRELATED TO MAGNETIC THICKNESS TOOL LOG JANUARY 5 2018. FINAL T/I/O = 125/0/0 1/12/2018 ***WELL SHUT IN ON DEPARTURE, DSO NOTIFIED*** ***WSR continued from 1/12/2018 (Post Coil Jet Cut) CMIT-TxIA to 4385 psi TBG, 4343 psi IA, target 4000 psi, ***PASSED***. MIT-OA to 1146 psi, target 1080 psi ***PASSED*** Attempted two CMIT-TxIA with passing results on the second. Pumped 11.5 bbls of ambient diesel the first test and an additional .25 bbls for the second test to reach a test pressure of 4385 TBG, 4343 IA. 1st 15min TBG lost 48 psi, IA lost 46 psi. 2nd 15min TBG lost 17 psi, IA lost 17 psi. Bled back —11.5 bbls diesel. Left—250 psi on TBG for valve crew to install a BPV. BPV in tree, monitor IA psi during MIT-OA for TBG psi. Pumped 2.27 bbls diesel down OA to reach test pressure. Loss of 25 psi 1st 15 min. Loss of 09 psi 2nd 15 min. Bled down all pressures to 0 psi. FWHP=BPV/0/0 SV,WV,SSV shut MV,IA,OA Open. Tags hung, AFE sign 1/13/2018 hung on wing. T/I/O= 250/250/0 SET BPV. R/U Red CIW Lubricator. PT'd Lubricator Low 300psi, High 3500psi. Set 6" J-BPV#422 @ 160". Good Set. RDMO. ***Job Complete*** FWHP 1/13/2018 250/250/0 See Log For Details. • • North America-ALASKA-BP Page 1 erifer Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:1/13/2018 End Date: X3-018R0-C:(7,472,361 00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud DateTme:12/29/1992 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A l§68.97usft(above Mean Sea Level) Date From-To Hrs I Task Code I NPT Total Depth Phase Description of Operations (hr) (usft) 1/13/2018 16:00 - 20:00 4.00 RIGD P PRE RDMO OF X-11A GENERAL RIG DOWN OPERATIONS -SKID RIG FLOOR -LAY OVER DERRICK -SEPARATE MODULES AND STAGE IN PREPARATION FOR MOVE -PRE RIG MOVE MEETING, -SECURITY ON SITE AT 20:00 20:00 - 00:00 4.00 MOB P PRE MOBIZE RIG FROM X-PAD TO DEAD HORSE MOVE ALL THREE MODULES ON X-PAD ACCESS ROAD TO THE SPINE. -MOVE EAST ON SPINE TO EAST GUARD SHACK. 1/14/2018 00:00 - 06:00 6.00 MOB P PRE MOBILIZE ALL THREE RIG MODULES FROM EAST GUARD SHACK TO CH2 YARD IN DEAD HORSE. STAGE MODULES AT JACOB PAD AT CH2 YARD IN DEAD HORSE 06:00 - 13:00 7.00 MOB N PRE WAIT ON PERMISSION TO CROSS THE ICE ROAD. -WAIT FOR PAD PREP COMPLETION. SIM OPS:DOUBLE STACK CHANGE OUT: REMOVE NOV 6012 DOUBLE STACK -PULL RAMS FROM STACK BREAK FLANGES AT THE ANNULAR AND DOUBLE STACKS -REMOVE DOUBLE STACKS AND LAY DOWN TO GROUND -PICK UP NEW NOV 6012 STACK AND INSTALL. -MAKE UP AND TORQUE ALL FLANGES, RE-INSTALL HOSES AND FITTINGS -SECURE STACK IN BOP DECK 13:00 - 16:00 3.00 MOB N PRE MOBILIZE RIG MODULES FROM JACOB PAD IN DEAD HORSE TO DS 17 -RECEIVED PERMISSION TO CROSS THE ICE ROAD AND STAGE ON DS 17. -UNABLETOGOTODS9DUETO UNFINISHED WELL WORKAND PAD PREP. 16:00 - 00:00 8.00 MOB N PRE WAIT FOR WELL WORK AND PAD PREP COMPLETION. -RIG MODULES STAGED ON DS17 -CREW PERFORMING PREVENTATIVE MAINTENANCE ON VARIOUS EQUIPMENT. 1/15/2018 00:00 - 06:00 6.00 MOB N PRE WAIT FOR WELL WORK AND PAD PREP COMPLETION. -RIG MODULES STAGED AT DS17 -CREW PERFORMING PREVENTATIVE MAINTENANCE ON VARIOUS EQUIPMENT. 06:00 - 12:00 6.00 MOB N PRE WAIT FOR WELL WORK AND PAD PREP COMPLETION. -RIG MODULES STAGED AT DS17 -CREW PERFORMING PREVENTATIVE MAINTENANCE ON VARIOUS EQUIPMENT. "TURN RIG MODULE SO 7"CASING CAN BE L LOADED. Printed 1/30/2018 5.22:49PM 'All depths reported in Drillers Depths* . 0 Page 2448^North America ALASKA-BP ,. q. F Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/13/2018 End Date: I X3-018R0-C:(7,472,361.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. LBPUOI:USA00001198 Active datum:09-51A @66.97usft(above Mean Sea Level) Date From-To Hrs Task ! Code NPT Total Depth Phase 1 Description of Operations (hr) (usft) I 1 12:00 - 00:00 12.00 MOB N j PRE WAIT FOR WELL WORK AND PAD PREP i COMPLETION. -RIG MODULES STAGED AT DS17 -CREW PERFORMING PREVENTATIVE IVARIOUSE UIPMENT. MAINTENANCE ON Q 1-PRE-SPUD MEETING WITH HUNDLEY CREW. 1**SIMP OPS:LOAD 50 JOINT OF 7"CASING IN THE PIPE SHED. 1WEEKLYSAFETY MEETING: -TOPIC FOR THE MEETING,CREW HANDOVER AND HOW TO MAKE IT BETTER. 4-REVIEW UPSTREAM SAFETY LEADERSHIP PRINCIPALS VIDEO WITH CREW. 1/18/2018 00:00 - 05:00 5.00 MOB N -0.18 PRE I WAIT FOR WELL WORK AND PAD PREP I COMPLETION. 1-RIG MODULES STAGED AT DS17 1-CREW PERFORMING PREVENTATIVE 1 MAINTENANCE ON VARIOUS EQUIPMENT. 1-PRE-SPUD`MEETING WITH YEAROUT CREW **I I PREP MOVING GEAR FOR MOVE TO DS9, PRE-CHECKS FOR TIRES AND MOVING SYSTEM. -NOTIFY SECURITY AND DRILL SITE 1 OPERATOR FOR RIG MOVE AT-07:00 05.00 - 06:30 1.50 MOB N -0.18 PRE 'MOBILIZE RIG MODULES TO THE OTHER SIDE OF DS17. -LINE UP MODULES FOR MOVE TO DS9. 06:30 - 10:00 3.50 MOB P -0.18 PRE I MOVE RIG MODULES FROM DS17 TO DS9 10:00 - 12:00 2.00 MOB P -0.18 PRE STAGE MODULES ON DS9 AND PLACE MATS 12:00 - 14:00 2.00 � MOB P I -0.18 PRE 1 SPOT DRILL MODULE OVER WELL CENTER. MATE UP UTILITY MODULE AND MUD 1 MODULE TO DRILL MODULE 114:00 - 16:00 2.00 RIGU P -0.18 PRE GENERAL RIG UP OPERATIONS THROUGHOUT RIG -HOOK UP SERVICE AND UTILITY LINES -INSTALL ROOF TOP TRANSISTIONS AND WALKWAYS. _-_.-...-. 16:00 - 19:00 3.00 RIGU P -0.18 PRE CONTINUE WITH GENERAL RIG UP OPERATIONS THROUGHOUT RIG -RAISE DERRICK:545 KLBS OFF THE RACK -SKID RIG FLOOR TO WELL CENTER -SKID HAUNCH AND RAISE PIPE CAT -CONTINUE RIGGING UP LINES THROUGHOUT RIG -TAKE ON CALIBRATION FLUID TO MUD PITS. "'ACCEPT RIG AT 16:00 HRS"' 19:00 - 21:30 2.50 WHSUR P -0.18 PRE NIPPLE DOWN TREE AND ADAPTER FLANGE -FMC REPRESENATIVE TERMINATED CONTROL LINES -CLEAN AND INSPECT HANGER THREADS; IILOOK GOOD -INSTALL HANGER XO,9.5 TURNS TO MAKE IUP -INSTALL BLANKING PLUG Printed 1/30/2018 5:22.49PM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP • Page 3t' Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:1/13/2018 End Date: X3-018R0-C:(7,472,361.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A @66.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase I Description of Operations 00:00 2.50 WHSUR I I -0.18 (hr) I (usft) 21:30 P ~ 1 -0.18 PRE NIPPLE UP HIGH PRESSURE RISERS AND BOP STACK -INSTALL HIGH PRESSURE RISERS AND I TORQUE ALL BOLTS -INSTALL BOP STACK AND TORQUE ALL i BOLTS -INSTALL TURN BUCKLES AND AND PITCHER -I NIPPLE I I-AIR UP AIR BOOTS AND INSTALL FLOW LINE IAND JET LINES. -ENGERGIZE ACCUMULATOR 1/17/2018 00:00 - 01:00 , 1.00 WHSUR P -0.18 PRE I PRESSURE TEST HIGH PRESSURE MUD I j LINES I -REPLACE 0-RING ON STAND PIPE AND RE-TEST MUD LINES. 01:00 - 02:00 1.00 BOPSUR P -0.18 PRE MAKE UP TEST JOINTS AND TEST ASSEMBLIES 02:00 - 03:30 1.50 BOPSUR , N -0.18 .- PRE ATTEMPT TO PERFORM SHELL TEST I I-PURGE AIR FROM SYSTEM I-PERFORM SHELL TEST ON SYSTEM AND (OBSERVE PRESSURE BLEED OFF I - i-OBSERVE CORRESPONDING PRESSURE ON =- IIA GAUGE. 03:30 - 08:30 5.00 WHSUR- N -0.18 PRE TROUBLESHOOT LEAKING BLANKING PLUG -PULL BLANKING PLUG -PRESSURE UP ON BPV FROM BELOW TO RE-SEAT BALL -TEST BPV FROM BELOW TO 2700 PSI FOR 5 I I MIN:GOOD TEST , -RE-INSTALL BLANKING PLUG 08:30 - 09:30 1.00 BOPSUR I P -0.18 PRE PERFORM SHELL TEST ON BOP AND HIGH PRESSURE RISERS -4000 PSI;GOOD TEST -RE-TORQUE ALL FLANGES 09:30 - 15:30 6.00 BOPSUR I P -0.18 PRE TEST BODE PER AOGCC AND BP 250/4000 PSI FOR 5 CHARTED MIN EACH -TEST ANNULAR WITH 7"AND 4"TEST JOINTS TO 250/3500 PSI -TEST UPPER VBRS WITH 7"AND 5"TEST JOINTS -TEST LOWER VBRS WITH 5"AND 4"TEST JOINTS -TEST RAM LOCKS,HIGH/LOW BYPASS AND BLACKOUT -TEST GAS ALARMS,PVT AND FLOW SHOW I -PERFORM ACCUMULATOR DRAW-DOWN ITEST I I ALL TEST WITNESSED BY BP WSL AND PARKER RIG MANAGER SEE ATTACHED TEST CHARTS AOGCC REPRESENTATIVE JEFF JONES WAIVED WITNESS ON 01/16/2018 AT 12:10 15:30 - 16:00 0.50 BOPSUR P -0.18 DECOMP RIG EVACUATION DRILL AND AAR WITH I HUNDLEY'S CREW 16:00 - 16:30 0.50 BOPSUR P -0.18 DECOMP I RIG DOWN AND BLOW DOWN ALL TEST -I i EQUIPMENT Printed 1/30/2018 5:22:49PM *All depths reported in Drillers Depths* • 410 North America ALASKA BP010 Page Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/13/2018 End Date: X3-018R0-C:(7,472,361.00) Project:Prudhoe BaySite:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A @66.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) L (usft) L 16:30 - 19:30 3.00 WHSUR P -0.18 DECOMP RIG UP AND PULL BLANKING PLUG AND BPV I -INSTALL DUTCH RISER,QUICK-TEST SUB AND LUBRICATOR -PRESSURE TEST LUBRICATOR TO 250/3500 I I PSI FOR 5 MIN -STAND BACK LUBRICATOR -PULL BLANKING PLUG THROUGH DUTCH ' •RISER AND QUICK-TEST SUB WITH TEST JOINT ' -RE-INSTALL LUBRICATOR WITH BPV I RUNNING TOOL I 1-TEST QUICK-TEST SUB BREAK TO 250/3500 I PSI -ENGAGE BPV AND PULL -LAY DOWN BPV,LUBRICATOR AND DUTCH L RISER/QUICK TEST SUB. 19:30 - 21:30 2.00 WHSUR P 1 -0.18 DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT ,TO FLOW BACK TANK -CLOSE BLIND/SHEAR RAMS AND VERIFY II LINE-UP TO FLOW BACK TANK I '-STAGE UP PUMPS TO 8 BPM,1010 PSI AND 'CIRCULATE DOWN THE TUBING TAKING RETURNS FROM THE IA TO THE FLOW BACK ;TANK -MONITOR BBL IN/OUT WHILE DISPLACING TO FREEZE PROTECT WITH CLEAN SEAWATER -FLOW CHECK WELL FOR 10 MIN AFTER DISPLACEMENT;WELL STATIC BLOW DOWN LINES. 121:30 - 23:30 2.00 WHSUR N -0.18 DECOMP I MAKE UP HANGER CROSS-OVER AND I I LANDING JOINT TO TOP DRIVE AND BACK j OUT LOCK DOWNS PER FMC I REPRESENTATIVE -UNABLE TO BACK OUT 1 LOCK DOWN SCREW I NOTIFIED ODE AND WSUP OF DIFFICULTY BACKING OUT 1 LOCK DOWN -FMC REPRESENTATIVE DISCUSSED WITH CAMERON WELLHEAD REPRESENTATIVE WITH REGARDS TO PRE-RIG WORK -WELLHEAD REPRESENTATIVES ABLE TO PULL AND REPLACE DAMAGED AND CORRODED LOCK DOWN SCREW 23:30 - 00:00 0.50 1 WHSUR P i -0.18 I DECOMP I PULL 7"TUBING HANGER TO RIG FLOOR I , PULL TUBING HANGER OFF SEAT WITH 175 KLBS(30 KLBS OVER ESTIMATED HOOK , ' LOAD) -PU 145 KLBS i -SIGNIFICANT AMOUNT OF PARAFFIN AND CORROSION ON TOP OF TUBING HANGER - - 1/18/2018 00:00 - 01:00 1.00 I CASING P I 5,499.82 DECOMP CIRCULATE A SOAP PILL SURFACE TO SURFACE THROUGH TUBING CUT AT-5500' MD -STAGE PUMPS UP TO 18 BPM;650 PSI -MONITOR WELL FOR 10 MIN:STATIC , l i SIMOPS: -RIG UP SPOOLING UNIT ON RIG FLOOR Printed 1/30/2018 5:22:49PM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 5 • Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/13/2018 End Date: X3-018R0-C:(7,472,361 00) Project Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A @66.97usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 01:00 - 08:30 7.50 CASING P 5,499.82 DECOMP !PULL AND LAY DOWN 7'x 5-1/2"NSCC TUBING WITH CONTROL LINES FROM CUT AT -5500'MD l-RECOVERED 75 JTS OF 7"TUBING,(1)2' j I PUP JT,(1)SSSV AND 50 SS BANDS RECOVERED 57 JTS OF 5-1/2"TUBING,(1) PUP JT,(2)GLM ASSEMBLIES AND(1)4.6'CUT !JT !-CUT LOOKED GOOD WITH 6.6"OD FLARE 1-DISCREPANCY NOTED WITH XO FROM 7"TO 5-1/2",ORIGINAL TALLY LENGTH=6.81', RECOVERED XO LENGTH 1.5' PU 143 KLBS,SO 133 KLBS WITH HANGER !AT RIG FLOOR SIMOPS: -BUILD STANDS OF WIRED 5"DRILL PIPE OFF-LINE 08:30 - 09:00 0.50 CASING P 5,499.82 DECOMP RIG DOWN DOYON CASING TONGS AND SCHLUMBERGER SPOOLING UNIT 09:00 - 09:30 0.50 CASING P 5,499.82 DECOMP CLEAN AND CLEAR RIG FLOOR --- MOBILIZE CLEAN OUT BHA TO RIG FLOOR 09:30 - 12:00 2.50 WHSUR N 5,499.82 DECOMP PERFORM OPERATIONAL ASSURANCE PRESSURE TEST ON LOCK DOWN SCREWS -SUCK OUT STACK AND INSTALL TEST PLUG CLOSE BLIND/SHEAR RAMS AND TEST LOCK DOWNS TO 4000 PSI FOR 15 CHARTED MIN; GOOD TEST -TEST APPROVED BY WSUP -PULL TEST PLUG 1-INSTALL 9-1/8"ID WEAR RING 12:00 - 14:30 2.50 CLEAN P 5,499.82 DECOMP MAKE UP AND RUN IN THE HOLE WITH 9-5/8" CLEAN OUT ASSEMBLY -8-1/2"MILL TOOTH BIT,BIT SUB W/FLOAT, SMOOTH OD WATERMELON MILL,PONY COLLAR,AND STABILIZER -SINGLE IN,PICKING UP SIX STANDS OF 5" 1HWDPTO575'MD -PU 65 KLBS,SO 65 KLBS -MONITOR DISPLACEMENT WITH TRIP TANK; GOOD DISPLACEMENT 14:30 - 17:30 3.00 CLEAN P 5,499.82 DECOMP RUN IN THE HOLE WITH 9-5/8"CLEAN OUT ASSEMBLY,PICKING UP 5"WIRED DRILL PIPE FROM THE PIPE SHED -FROM 575'TO 3230'MD -PU 120 KLBS,SO 120 KLBS MONITOR DISPLACEMENT WITH TRIP TANK; GOOD DISPLACEMENT 17:30 - 19:30 2.00 CLEAN P 5,499.82 DECOMP I CONTINUE RUNNING IN THE HOLE WITH THE CLEAN OUT ASSEMBLY ON STANDS OF 5" DRILL PIPE OUT OF THE DERRICK -FROM 3230'MD TO 5500'MD -PU 165 KLBS,SO 150 KLBS -MONITOR DISPLACEMENT WITH TRIP TANK; 1 1 GOOD DISPLACEMENT Printed 1/30/2018 5:22:49PM *AII depths reported in Drillers Depths* • 4110 North America-ALASKA-BP Page 6cr. Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/13/2018 I End Date: X3-018R0-C.(7,472,361 00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A©66.97usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT I Total Depth Phase 1, Description of Operations (hr) 1 (usft) 19:30 - 21:00 1.50 CLEAN P 5,514.82 DECOMP CIRCULATE AND CLEAN OUT WELLBORE -WASH DOWN AND TAG TOP OF TUBING STUB AT 5515 MD , -PUMPED A 35 BBL BARAKLEAN SOAP PILL AND HIGH VIS SWEEP • -16 BPM,1245 PSI,40 RPM,3 KFT-LBS TORQUE - RECIPROCATE PIPE 30'STAYING 5'OFF ! 'TUBING STUB -PARAFFIN,CEMENT SCALE,PIPE SCALE AND CEMENT WIPER BALL DEBRIS CIRCULATED UP 21:00 - 22:30 ! 1.50 CLEAN P 5,514.82 ' DECOMP PULL OUT OF THE HOLE WITH 9-5/8"CLEAN OUT ASSEMBLY -FROM 5515'MD TO 580'MD � j 1 MONITOR WELL FOR 10 MIN PRIOR TO I PULLING OFF BOTTOM:STATIC 1-MONITOR HOLE FILL WITH TRIP TANK, ILL 1 22:30 - 23:00 0.50 I CLEAN P ' 5,514.82 DECOMP ,PULL AND LAY DOWN 9-5/8"CLEAN OUT ! GOOD ASSEMBLY 1 -FROM 580'MD MONITOR WELL FOR 10 MIN PRIOR TO -PULLING BHA:STATIC 23:00 - 23:30 I 0.50 CLEAN P 5,514.82 DECOMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT SIMOPS: 1 -LAY OUT WHIPSTOCK AND MILLING BHA IN I I PIPE SHED 23:30 - 00:00 0.50 WHIP P 5,514.82 WEXIT MAKE UP 9-5/8"WHIPSTOCK AND WINDOW MILLING ASSEMBLY- 1/19/2018 00:00 - 02:00 2.00 WHIP P 5,514.82 WEXIT CONTINUE TO MAKE UP 9-5/8"WHIPSTOCK AND WINDOW MILLING ASSEMBLY PER SLB FISHING REPRESENTATIVE AND BAKER DD/MWD -MAKE UP WHIPSTOCK AND TRI-MILL I I ASSEMBLY;VERIFY 45 KLB SHEAR BOLT -PICK UP(9)6-1/2"SPIRAL DRILL COLLARS -RUN IN WITH 6 STANDS OF 5"HWDP TO 633' MD 02:00 - 06:30 4.50 WHIP P I 5,514.82 I WEXIT RUN IN THE HOLE WITH THE 9-5/8" WHIPSTOCK AND WINDOW MILLING 1 ASSEMBLY ON 5"WDP i -FROM 633'MD TO 5500'MD 1 -SHALLOW HOLE TEST TOOLS AT 633'MD; GOOD TEST -FILL PIPE EVERY 2000'MD -MONITOR DISPLACEMENT WITH TRIP TANK; GOOD DISPLACEMENT Printed 1/30/2018 5:22:49PM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 7 sf ' Operation Summary Report Common Well Name:09-51 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/13/2018 End Date: X3-018R0-C:(7,472,361.00) L. Project:Prudhoe Bay 1 Site:PB DS 09 - - Rig Name/No..PARKER 272 Spud Date/Time:12/29/1992 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. BPUOI:USA00001198 Active datum:09-51A©66.97usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT Total Depth Phase I Description of Operations I 06:30 - 07:00 i 0h50 WHIP P 1 5,514.82 1 WEXIT I ORIENT AND SET WHIPSTOCK 60°RIGHT OF HIGH SIDE -600 GPM,1250 PSI I -ORIENT WHIPSTOCK TO 60°RIGHT OF HIGH 1 I SIDE I-SET DOWN AND TAG TUBING STUB AT 5515' 'MD WITH 10 KLBS I-PICK UP 3'AND SLACK OFF TO SET WHIPSTOCK,BOLT SHEARED WITH 37 KLBS !'DOWN I-PICKUP AND VERIFY WHIPSTOCK SET. -TOP OF WHIPSTOCK AT 5489'MD(4768'TVD -BOTTOM OF WHIPSTOCK SLIDE AT 5503'MD (4778'TVD) I 1 GPB IN PHASE 2 WEATHER CONDITIONS I FIELD WIDE 07:00 - 08:00 1.00 WHIP P 5,502.82 WEXIT DISPLACE WELL FROM SEAWATER TO 9.4 PPG MILLING FLUID 1-600 GPM,1400 PSI [-MONITOR WELL FOR 10 MIN:STATIC•. r I MW IN/OUT=9.4 PPG III fy� 08:00 12:00 4.00 STWHIP P 5,502 82 WEXIT MILL 9-5/8"CASING WINDOW FROM 5489'MP Chi � TO 5496'MD l 5 1Ar I I -450 GPM,1100 PSI,90 RPM,6-12 KFT-LBS I I TORQUE,5-7 KLBS WOB -PU 177 KLBS,SO 156 KLBS,ROT 161 KLBS -MUD WEIGHT IN/OUT 9.4 PPG I AFTER MILLING-0.5'MILL BECOMES STUCK WITH 30 KLBS DRAG TO PULL UP THE HOLE. WORK MILLS WITH AND WITHOUT ROTATION j I I AND CONFIRM WHIPSTOCK IS NOT BEING PULLED UP THE HOLE--ABLE TO GO BACK I DOWN TO PREVIOUS TAG DEPTH.WORK AREA WITH AND WITHOUT ROTATION UNTIL I OVERPULL IS NO LONGER OBSERVED ON THE UPSTROKE. 1 1 SIMOPS: j-BUILD STANDS OF 5"WDP OFFLINE I-BLEED OA FROM 860 PSI TO 360 PSI(-1 BBL) 12:00 - 18:00 6.00 STWHIP N 5,502.82 WEXIT WAIT ON WEATHER-GPB IN PHASE 3 WEATHER CONDITIONS -STOP MILLING OPERATIONS AND PULL MILLS UP INSIDE CASING WINDOW -FLOW CHECK WELL FOR 10 MIN:STATIC -MONITOR WELL WITH CONTINUOUS HOLE FILL I I AT 17:15 GPB WEATHER CONDITIONS IMPROVED TO PHASE 2 Printed 1/30/2018 5:22:49PM *AII depths reported in Drillers Depths* TREE= . CNV •WELLHEAD= FMC NOTES:H2S READINGS AVERAGE 125 MI.WELL REQUIRES A SSSV ACTUATOR BAKER C 09-51 IrHEN WHEN ON ML ***CHROME TBG&LNR*** BF.REV= 23.19' I L KOP= 2388' ----; Max Angle= 51°@ 8048' 20"GOND, H ? Datum MD= 11405' Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80,D=12.415" H 3919' GAS LIFT MANDRELS 9-5/8"WHIPSTOCK(01/19/18) H 5489' ST MD ND DEV TYPE VLV LATCH FORT DATE 1 3409 3314 34 MERLA DMY RA 07/07/03 JET CUT TBG(01/12/18) H 5515'ELM 2 5477 4757 48 OTIS LB-1 DMY RA 0 01/22/93 3 6600 5501 48 MERLA DMY RA 07/07/03 4 7352 5993 48 MERLA DMY RA 07/07/03 CEMENT BALANCE PLUG(01/09/18) —1 -9500'-10933' 5 8144 6503 49 OTIS LB-1 DMY RA 0 01/22/93 Minimum ID = 3.725" @ 11279' ��►�T$171. 6 8946 7013 48 OTIS LB-1 DMY RA 0 10/02/93 .4414.4�4�4�•�•��6. 7 9665 7510 49 OTIS LB-1 DMY RA 0 01/22/93 4-1/2" OTIS XN NIPPLE 8 10307 8014 51 o-ns LB-1 DMY RA 0 01/22/93 EST TOC(12/29/17) H 11162'SLM 9 10643 8273 51 OTIS LB-1 DMY RA 0 01/22/93 10 10933 8497 51 OTIS LB-1 9IPTY - - 01/04/18 5-1/2"TBG,17#,13CR-80, — 11203' _ _ 11193' _H5-1/2"OTIS XN NI',D=4.455" .0232 bpf,ID=4.892" '� 11213' 19-5/8"X 5-1/2"BAKER SB-3A TOP OF 7"LNR 11235' HYDROSET PKR D=4.875 11228' H?MLLOUT DCT w/5-1/2"X 4-1/2"XO,ID=3.958" 11261' —+4-1/2"OTIS X NIP,ID=3.813" 01)","4•11 I '4: 11279' —14 1/2"OTIS XN NIP,ID=3.725" &IIP 4:114449 4-1/2"TBG,12.6#,13CR 80, H 11290' - 1 .0152 bpf,ID=3.958" • 41P.1**y 11291' H 4-1/2"WLEG,ID=3.958" e e if if 11278' --I EMD TT LOGGED 03/19/97 e iv lbeN, 9-5/8"CSG,47#,MN-80,ID=8.681" H 11411' IP"if if if PERFORATION SUMMARY RE=LOG: DLUMSFL ON 01/18/93 ANGLE AT TOP PERF: 40"@ 11498' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11394-11414 S 06/28/07 2-7/8" 6 11498-11518 S 12/29/17 3-3/8" 4 11538-11558 S 06/28/07 3-3/8" 4 11620-11626 S 06/28/07 3-3/8" 4 11654-11664 S 06/28/07 PBTD H 11910' tiMMA 7"LNR,26#,13CR-80,.0383 bpf,ID=6.276" H 11990' .•.•.•., ,,,,,,,, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/22/93_ ORIGINAL COMPLETION 01/16/18 BSE/JMD GLV GO(01/04/18) WaL: 09-51 10/06/01 RN/KAK CORRECTIONS 01/16/18 MRD'JMD SET CMT BALANCE PLUG PERMIT No: 1921410 01/11/12 TMN/JMD ADDS)H2S SAFETY NOTE 01/16/18 BTN/JMD JET CUT TBG(01/12/18) API No: 50-029-22320-00 07/31/15 TJWJMD SET PXN RUG(07/14/15) SEC 1,T10N,R15E,1023'FSL&122'RAIL 12/27/17 ZV/JMD PULLED PXN RUG(12/22/17) 01/02/18 JJUJMD RES PA REDLINE(12/29/17) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 06,2018 TO: Jim Regg Tele4116 P.I.Supervisor 1\ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-51 FROM: Jeff Jones PRUDHOE BAY UNIT 09-51 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-51 API Well Number 50-029-22320-00-00 Inspector Name: Jeff Jones Permit Number: 192-141-0 Inspection Date: 1/11/2018 Insp Num: mitJJ180111162522 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-51 Type Inj N ^ TVD 8709 - Tubing 500 4229 ' 4165 4132- PTD 1921410 - Type Test SPT Test psi 2177 IA 352 4327 - 4163 4102 _ BBL Pumped: 13 BBL Returned: 13 ✓ OA 39 407 . 387 381 Interval ! OTHER P/F P Notes: Combo MIT;Tubing x IA to 4000 psi following placement of second permanent abandonment cement plug.Sundry 317-517 V' • SCANNED ivi-1.1-? ' Tuesday,February 06,2018 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 18,2018 TO: Jim Regg � 1k2i(t 6 P.I.Supervisor3� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-51 FROM: Jeff Jones PRUDHOE BAY UNIT 09-51 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-51 API Well Number 50-029-22320-00-00 Inspector Name: Jeff Jones Permit Number: 192-141-0 Inspection Date: 1/11/2018 Insp Num: mitJJ180111162522 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-51 Type Inj N TVD 8709 ' Tubing 500 4229 • 4165 - 4132 PTD ! 1921410 Type Test SPT Test psi 2177 - IA 352 4327 - 4163- 4102- BBL Pumped: 18 BBL Returned: 13 • OA 39 407 . 387- 381 Intervals OTHER PIF P Notes: Combo MIT;Tubing x IA to 4000 psi following placement of second permanent abandonment cement plug.Sundry 317-517 it Wjit Sirtivt; .1—o;t (�race) %AWNED 6..• ik Thursday,January 18,2018 Page 1 of 1 MEMORANDUM State of A aska Alaska Oil and Gas Conservation Commission TO: Jim Regg .PR�`l 1/16(ie DATE: January 11, 2018 P.I. Supervisor ` SUBJECT: Well Bore Plug &Abandonment PBU 09-51 FROM: Jeff Jones BPXA Petroleum Inspector Prudhoe Bay Unit - PTD 192-141 - Sundry 317-517 Section: 1 Township: 10N Range: 15E — Meridian: Umiat Drilling Rig: N/A Rig Elevation: 19 ft(W/L) Total Depth: 11990 ft MD Lease No.: 028327(surf) 028345(B/H) Operator Rep: Chuck Nardini • Casing/Tubing Data(Depths in MD): Casing Removal: Conductor: 20" O.D. Shoe@ 80 Feet Casing Cut@ Feet Surface: 13 3/8" - O.D. Shoe@ 3890 Feet Casing Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 11385 Feet Casing Cut@ Feet Production: O.D. Shoe@ Feet Casing Cut@ Feet Liner: 7" • O.D. Shoe@ 11990 Feet Casing Cut@ Feet Tubing: 5.5"x 4.5" - O.D. Tail@ 11297 Feet Casing Cut@ Feet Plugging Data: Type Plug Founded on Bottom of T.O.C. Depth T.O.C. Mud Weight Pressure (bottom up) Cement Verified? above plug Test Cased hole •1 Bottom - 11181 ft MD 9401 ft MD W/L Tag 7.1 ppg Pass Type Pluq Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag $CANHE ` N Annulus Balanced C.T.Tag Casing Stub Retainer No Surface January 11,2018: I travelled to BPXA's Prudhoe Bay Field(PBF)well 09-51 to witness a wireline tag and pressure test to verify proper placement and integrity of the second permanent abandonment cement plug placed in this well. On arrival I met with BPXA representative Chuck Nardini and we discussed the verification procedures.A 450#weight assembly with jars and a sample catcher was then run in the hole and tagged the top of cement solidly at 9401 ft MD.The sample returned in the catcher was hardened cement.A passing combo jr- Tubing Tubing x IA pressure test(CMIT)was then performed to 4229/4327 psi, indicating that this plug meets AOGCC requirements. cc: Attachments: none rev.4-20-16 2018-0111_Plug_Verification_PBU_09-51 Jj prp 192 -/f1 • Loepp, Victoria T (DOA) From: Sperry, Nathan <Nathan.Sperry@bp.com> Sent: Wednesday,January 03, 2018 3:47 PM To: Loepp,Victoria T(DOA) Cr: Lastufka,Joseph N Subject: RE: PBU 09-51(PTD 192-141, Sundry 317-517) Plug for Redrill: Follow Up Flag: Follow up Flag Status: Flagged Thank you! Nathan Sperry Drilling Engineer C: (907)268-8416 0: (907)564-4258 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,January 3,2018 3:39 PM To:Sperry, Nathan<Nathan.Sperry@bp.com> Subject: Re: PBU 09-51(PTD 192-141,Sundry 317-517) Plug for Redrill: Nathan, Change is approved as written. AINNED Thanx, Victoria Sent from my iPhone On Jan 3,2018,at 3:09 PM,Sperry, Nathan<Nathan.Sperry@bp.com>wrote: Hi Victoria, The target pressure is 4,000 psi. On our production cement job,we wrote in our permit application that we would pump 13.6ppg cement. We have since optimized the slurry and would prefer to pump a 15.0ppg slurry. The volume would not change neither would the TOC. We would pump 122.7 bbls,689 cu ft,547 sacks of 15.0ppg Class G (yield is 1.26 cuft/sk). Please let me know if this change is approved. Regards, Nathan Sperry Drilling Engineer 1 • C: (907)268-8416 • • 0: (907)564-4258 From:Raese,J. Kyle • Sent:Wednesday,January 3,2018 11:56 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Sperry, Nathan<Nathan.Sperry@bp.com> Subject: RE: PBU 09-51(PTD 192-141,Sundry 317-517) Plug for Redrill: Victoria, Nathan Sperry(cc'd)will be the drilling engineer for 09-51 going forward. Nathan, Could you address Victoria's question below? • Thanks, Kyle Raese Drilling Engineer BP Exploration (Alaska) o:907-564-4629 c:907-301-6405 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,January 3,2018 11:19 AM To: Raese,J. Kyle<john.raese@bp.com> Subject: PBU 09-51(PTD 192-141,Sundry 317-517) Plug for Redrill: Kyle, For the CMIT-TxIA in step 6, pre-rig,what pressure will you test to? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loego@alaska.gov 2 VOF T� • • g ����yyy�s� THE STATE Alaska Oil and Gas �� �-s���-_'�► oConservation Commission fALASI<;A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Kenneth Allenc# `1 1 Engineering Team LeaderSCANNED BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU 09-51 Permit to Drill Number: 192-141 Sundry Number: 317-517 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French {` Chair DATED this CI day of November, 2017. RBDi s L" re- 1 7 2017 STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVIIII NOV 1 2017 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ 06 t 0•wn 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill H• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 192-141 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service H 6. API Number 50-029-22320-00-00 ' 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 H PBU 09-51 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327&028345• 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): V/Plugs(MD): Junk(MD): 11990 ' 9299 • 11279 8759 2504 11279 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36-116 1490 470 Surface 3890 13-3/8" 35-3925 35-3701 5020 2260 Intermediate 11385 9-5/8" 32-11417 32-8864 6870 4760 Production Liner 743 7" 11247-11990 8735-9299 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11498-11518 8926-8941 7"26#x5-112"17#x4-112"12.6# 13Cr80 29-11297 Packers and SSSV Type: 5-112"Baker SB-3A Packer Packers and SSSV MD(ft)and TVD(ft): 11219/8714 7"Camco BALO SSSV 2099/2098 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch H Exploratory 0 Stratigraphic 0 Development 0 Service H • 14.Estimated Date for Commencing Operations: November 10,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended H • 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Raese,J.Kyle be deviated from without prior written approval. Contact Email: john.raese@bp.com Authorized Name: Allen,Kenneth W Contact Phone: +1 9075644629 Authorized Title: Engineering Team Lead f Authorized Signature: t,. L'/ Date: r//)/// COMMISSION USE ONLY/ Conditions of approval:Notify Commission so that a representative may witness Sundry Number 31151 Plug Integrity fErr BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: e"p f,-�c,-/ j o 4 U vcJ r> G nviKiviol r /J/-C/fvv f----/:v" ft5 to Z✓OD �]Sr Post Initial Injection MIT Req'd? Yes 0 No C`1,/ Spacing Exception Required? Yes 0 No yr Subsequent Form Required: `c — L APPROVED BYTHE I Approved by: tr2SEr— COMMISSIONER COMMISSION Date: 4i its 11 LCL h/'7—J 1 4,x,`1 ���` ORIGINAL R8� Iii � ��-� a} 26�7 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachment m Duplicate • • bP GPopeifechrldhaelif 09-51 Sundry Application Well Type: Injector Current Status: Shut-in Request: P&A for rotary rig sidetrack Planned Pre-Rig Work Start Date: November 10, 2017 Planned Rig Start Date: January 10, 2018 11/5/2016 MIT-T to 4000 psi PASS 12/6/2016 MIT-IA to 4000 psi PASS 11/5/2016 MIT-OA to 1200 psi PASS 10/31/2016 PPPOT-IC to 3500 psi PASS 10/31/2016 PPPOT-T to 5000 psi PASS MASP: 2,504 psi (7.29 ppg EMW at 8,973'TVDss with 0.1 psi/ft gas gradient) Well History: Well 09-51 was completed in 1993 and later converted to a side pattern injector. This well has no value in its current configuration and is shut-in. It is in the pattern selected for the next MIST well in the program and has been released for rotary rig sidetrack. Scope of Work: Prior to rig arrival, the 09-51 perfs will be abandoned via fullbore cement. Top of cement will be tagged and pressure tested. A cement plug will then be circulated into the tubing and IA with top of cement at 9600' MD. Final top of cement will be tagged followed by an integrity test of the tubing and IA. The 7"x 5-1/2"tubing will be cut at—5500' MD. Wellbore integrity will again be verified. The rig will then move over the well and pull the 7" x 5-1/2" tubing. A 9-5/8"whipstock will be used to mill a window out of the existing production casing at —5500' MD. The proposed 09-51A sidetrack will be a horizontal injector targeting the "Victor" package. The planned well is a two string, ultra-slimhole design using 7" intermediate liner and 4-1/2" production liner. The intermediate liner will be set at the top of the Sadlerochit and the injection interval will be completed with a cemented liner using sliding sleeves. Cose 1 /itaT wells hare fl oven -to /yro'a ecv rex, P rer Co4 ve r'©+4l i n j eCto if ('a CerT q, ' Si ph'dif Recpraiy r4 (vett AS q /11151 Inaectbr JA odd ;y►9ic (ecorFr, 74j F7rr/'a+ a f foal, (//67/17 09-51 Sundry 1 11/1/2017 • Proposed Pre-Rig Work: 1 S Pull TTP. MTT log. 2 F P&A perfs. TOC 11200' MD. 3 S D&T TOC. Pull GLV. dV6'hey 4D(z-GG it))/5 I F') a c 4 F CMIT-TxIA. Circ Cement Plug. TOe—9600' MD. �►'fia6/ 5 S D&T TOC. Drift for Jet Cut. /v> fit fj �,�'�06,eG 7 4 "4 `�� 6 F CMIT-TxIA 7 E Jet Cut tubing at 5500' MD. 8 F Circ out. CMIT-TxIA. MIT-OA. 9 W PPPOT-T. PPPOT-IC. Function LDS. 10 0 Cement Control Line & PT. 11 V Install Dry Hole Tree. Install BPV. Proposed Drilling Operations: 1. MIRU Parker 272. 2. Test BPV from below to 2,750 psi. 3. Nipple down dry hole tree. Nipple up BOPE and test to 4,000 psi (annular to 3,500 psi). 4. Pull BPV. Circulate out freeze protect with 8.5 ppg seawater. 5. Pull 7"x 5-1/2"tubing from the pre-rig cut at 5,500' MD. 6. Run 9-5/8" mechanical whipstock and 8-1/2" window milling assembly. Orient and set the whipstock on the tubing stub. End of Sundry/Start of Permit to Drill 7. Mill window in the 9-5/8" casing at 5,500' MD plus 20'of new formation. Perform LOT. POOH. ............ 8. Run 8-1/2" motor drilling assembly on 5" DP. Include DIR/GR/RES/PWD. Drill to 6,000' MD. POOH. 9. Run 8-1/2"x 9-7/8" RSS drilling assembly with 9-7/8" under-reamer on 5" DP. Include DIR/GR/RES/PWD. Drill to 7"casing point at TSAD (11,000' MD). 10. Circulate well clean,wiper trip to window, run back to TD, circulate wellbore clean and POOH. 11. Run 7" liner to TD and cement. 12. POOH and LD liner running tool. 13. Pressure test the liner to 4,000 psi. 14. Run 6-1/8" motor drilling assembly on tapered 5" x 4" DP. Include DIR/GR/RES and Cement Evaluation LWD. • If Cement Evaluation LWD unavailable, run dedicated E-line cement evaluation log. 15. Log 7" liner annular cement to satisfy AOGCC injector requirements. 16. Drill out the 7" shoe plus 20' of new formation. Perform FIT. 17. Drill the 6-1/8" production build to 11,500' MD. POOH. 18. Run 6-1/8" RSS drilling assembly on tapered 5"x 4" DP. Include DIR/GR/RES. 19. Drill the 6-1/8" production lateral to TD at 16,236' MD. Circulate well clean, wiper trip as needed and POOH. 20. Run 4-1/2" liner to TD and cement with—13.6 ppg acid soluble cement. Include—20 NCS Sleeves for future injection stages. Set liner hanger and packer. 21. Displace wellbore to clean seawater and POOH. 22. Pressure test 4-1/2" liner top packer to 4,000 psi. 23. Run and land 4-1/2"completion. 24. Reverse circulate diesel freeze protection.Allow diesel to U-tube so that T x IA is freeze protected down to—2,000' TVD. 25. Set TWC. 26. Nipple down BOPE. Nipple up adapter flange and dry hole tree and test to 4,500 psi. 09-51 Sundry 2 11/1/2017 • • 27. RDMO Parker 272. Proposed Post-Rig Work: 1 V Pull TWC. Tree work as necessary. 2 F Circulate completion fluid. Drop ball & rod. Set production packer. MIT-T. MIT-IA. 3 S Pull ball &rod. 4 C Cleanout to PBTD. Shift open toe sleeves. Perform acid treatment. N2 lift to flowback if necessary. 5 T Portable test unit flowback assist. 6 S SBHPS. Set MCX. 7 F MIT-IA. Drilling Engineer: Kyle Raese (907) 564-4629 john.raese@bp.com Production Engineer: Kirsten Schultz (907) 564-5105 Geologist: Cheryl Hartbauer (907) 564-4159 09-51 Sundry 3 11/1/2017 TREE= CNV • = FMCACTUATO S NOTES:H2S READINGS AVERAGE 125 VVELLFEAACTUATOR= BAKER 09-51 ppm WHEN ON MI.WELL REQUIRES A SSSV OKB.TiEV= 54.8' WHEN ON Ml. ***CHROME TBG&LNR*** BF.ELEV= KOP= 2388' 2099' —7"CAM BAL-0 SSSV NP,D=5.937' Max Angle= 51° 7 8048' Datum MD= 11405' Datum TVD= 8800'SS L3284' 7"X 5-1/2^XO,D=4.892" GAS LET MANDRELS 20"CONDUCTORST MD TVD DEV TYPE VLV LATCH FORT DATE 7"TBG,26#,13CR-80,.0383 bpf,D=6.276" — 328?4' 1 3409 3314 34 NE2LA DMY RA 07/07/03 2 5477 4757 48 OTIS LB-1 DMY RA 0 01/22/93 13-318"CSG,68#,L-80,ID=12.415" 3919' 3 6600 5501 48 ME LA DMY RA 07/07/03 4 7352 5993 48 NERLA DMY RA 07/07/03 Minimum ID =3.725" 11279' 5 8144 6503 49 OTIS LB-1 O Y RA 0 01/22/93 6 8946 7013 48 OTIS LB-1 DMY RA 0 10/02/93 4-1/2" OTIS XN NIPPLE 7 9665 7510 49 OTIS LB-1 DMY RA 0 01/22/93 8 10307 8014 51 OTIS LB-1 DMY RA 0 01/22/93 9 10643 8273 51 OTIS LB-1 DMY RA 0 01/22/93 I 10 10933 8497 51 OTIS LB-1 EQUAL RA 0 01/22/93 5-1/2"TBG,17#,13CR-80, — 11203' 11193' —5-1/2"OTIS XN NP,ID=4.455" .0232 bpf,D=4.892" _ 11213' —9-5/8"X 5-1/2"BAKER SB-3A TOP OF 7"LNR H 11236` FIY DROSET PKR ID=4.875" 11228' —?MLLOIJT EXT w/5-1/2"X 4-1/2"X0,D=3.958" 11261' —I4-1/2-OTIS X IVF',D=3.813" � 11279' —4-1/2"OTIS XN NP,O=3.725" 11279' H 4-112"PXN PLUG(07/14/15) 4-1/2"TBG,12.6#,13CR-80, H 11290` .0152 bpf,D=3.958" 11291' --I4-112"\LEG,ID=3.958" 11278* —I ELMD TT LOGGED 03/19/97 9-5/8"CSG,47#,MN-80,113=8.681" —I 11411' 1. F RFORATION SUMMARY I REF LOG: DLL/MSFL ON 01/18!93 ANGLE AT TOP PERE: 40'@ 11498' Note:Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11394-11414 S 06/28/07 2-7/8" 6 11498-11518 0 08/05/07 3-318" 4 11538-11558 S 06/28/07 3-3/8" 4 11620-11626 S 06/28/07 3-3/8" 4 11654-11664 S 06/28/07 PBTD —I 11910' (r 11111111111114 7"LNR,26#,13CR-80,.0383 bpf,ID=6.276" --I 11990' t•1.t1.1.1.1�.4 DATE REV BY COMMENTS DATE REV BY COMMUVTS PRUDHOE BAY LUT 01(22/93 ORIGINAL COMPLETION 07/31/15 TJH/JMD SET PXN PLUG(07/14/15) WELL:1)9-51 10/06/01 RN/KAK CORRECTIONS PERMIT No:'1921410 08/27/11 SLAC/RIC SET PXN PLUG(8/27/11) API No: 50-029-22320-00 09/18/11 RNR/RIC TREE GO(09/04/11) SEC 1,T10N,R15E,1023'FSL&122'FVVL 09/18/11 MSS/PJC RLL PXN(09/08/11) 01/11/12 TMV/JMD ADDED I-12S SAI-EIY NOTE BP Exploration(Alaska) TREE= CNV WELLHEAD= F1vC • 0. SfeTY NOTES:I-12S READINGS AVERAGE 125 ACTUATOR= BARER CMI. WELL OKB.ELEV= 54.8' 09-51 WHEN ON **CHROMEETBGB LNR***SSSV _ PRE-RIG BF.ELEV= _KOP= 2388' 20"COND I ? ' O 2099' I—7"CAM BAL-O SSSV NIP,D=5.937" Max Angie= 51'@ 8048' Datum MD= 11405' Datum TVD= 8800'SS 3284' -{7"X 5-1/2"XO,D=4.892" 7"TBG,26#,13CR 80,.0383 bpf,D=6.276" —I 3284' GAS LFT MANDRELS 13318"CSG,68#,L-80,0=12.415" — 3919' ` ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3409 3314 34 M3&A DMY RA 07/07/03 2 5477 4757 48 OTIS LB-1 DMY RA 0 01/22/93 TBG CUT(_ / !_._}I-1 —5544' 3 6600 5501 48 MERLA DMY RA 07/07/03 Minimum ID =3.725" @ 11279' 4 7352 5993 48 MERLA DMY RA 07/07/03 4-1/2" OTIS XN NIPPLE 5 8144 6503 49 OTIS LB-1 DMY RA 0 01/22/93 6 8946 7013 48 OTIS LB-1 DMY RA 0 10/02/93 EST ANNULAR TOC(40%WASHOUT) — —7813' 7 9665 7510 49 OTIS LB-1 DMY RA 0 01/22/93 • I EST TOC(i/_/-__,) —I —9600' "-:- 8 10307 8014 51 OTIS L 8 1 DMY RA 0 01/22/93 /• o ••'••''`` .$ 9 10643 8273 51 OTIS LB-1 DMY RA 0 01!22/93 ♦ 44 )••••••,. g1.,41,,,�,,, 10 10933 8497 51 OTIS LB-1 EQUAL RA 0 01/22/93 5-1/2"TBG, 17#,13CR-80, — 11203' R-�'►••••• . i 11193` --15-1/2'OTIS XN NP,10=4.455' 1♦41••••••••4!r4 .0232 bpf,ID=4.892" 1: �or 0 •0 8 4 is4, • p$•*•4 'Ai 11213' -19-5/8-X 5-1/2"BAKER SB-3A 4. #visHY DROSET R<R ID=4.875' TOP OF 7"LNR — 11235' 1 ..•••••4 *40 . ■; 11228' —{7 MLLOUT EXT w/5-1/2"X 4-1/2"XO,13=3.958" •••4 *4#•' ,'. 11261' —4-1/2'OTIS X NP,D=3.813" . 4 ee0,,v 1 ••4 .+ 4 I**•ja : 11279' 4-1/2'OTIS XN NP,D=3.725' •4-1/2"TBG,12.6#,13CR-80, 11290' ►a �i•#•!•••�410 ''0 l •••••4 0152 bpf,OD=3.958" ,• ►•*•*•*4*• �- 11291' -I4-112"WL EG,D=3.958" •, ••••4 X11 0.004. 4, •♦••0000 11278' HELMD TT LOGGED 03/19/97 • 0141‘000•• AN c 1+ •••••i• �' 9-5/8"CSG,47#,NUJ-80,D=8.681" H 11411' ,, `+—►••41,•*j ,/ 4410•41,4140- PERFORATION SUMMARY V•••'►•••#• P••••• •*'► FIB=LOG: DLUMSFL ON 01/18/93 ►•••••0••4.• ANGLE AT TOP PERF-: 40'@ 11498' "•me" t•••�►•••••+l Note:Refer to Roducbon DB for historical perf data 4000••,••*• SIZE SPF INTERVAL Opn/Sqz DATE ►••••••4#•4�'• 3-3/8" 4 11394-11414 S 06/28/07 ••4 •* 2-718" 6 11498-11518 0 08/05/07 •••4••♦ 3-3/8" 4 11538-11558 S 06/28/07 ••'►••••••• • 4#000•41 +► 3-3/8" 4 11620-11626 S 06/28/07 **1041••4••4� + 3-3/8' 4 11654-11664 S 06/28/07 •••+►+►•4. � 1(►•••••• *4 ►••••#••4`4 ►•*••••••••4 1PBTD —{" 11910' "44%/14$ 1044 44414I444t•4 7"LNR 26#,13CR-80, .0383 bpf,D=6.276" —I 11990' 0•4A.'.fik DATE REV BY COMuBYTS DATE REV BY COMENTS PRUDHOE BAY UNIT 01/22/93 ORIGINAL COMPLETION 07/31/15 TJI-YJM) SET PXN PLUG(07/14/15) WILL: 09-51 W 10/06/01 RKAK CORRECTIONS tI-4',/I€I KRIJM) CPRE-RIG _ PEWIT No: 1921410 08/27/11 SWC/PJC SET PXN PLUG(8/27/11) AR No. 50-029-22320-00 09/18/11 W1 R/PJC TREE C/O(09/04/11) SEC 1,T1ON,R15E, 1023'FSL&122'FWL 09/18/11 MSS/PJC PULL PXN(09/08/11) _____ 01/11/12 TMyJM) ADDED H2S SAFETY NOTE BP Exploration(Alaska) TREE= CIV1/ • S NOTES:H2S READINGS AVERAGE 125 WELLFEAD= FMC ACTUATOR= BAKE3RC PROPOSED 0951 ;' ppm WHEN ON MI.WELL REQUIRESASSSV WHEN ON MI. ***CHROME TBG&LNR***WELL OKBRE LE�V= 54.8' REV 3 I ANGLE>70°@ . BF.KOP= 2388' 20"GOND, 110° Max Angle= @ I I 2100' H4-112"HES X NP,D=3.813" Datum MD= Datum ND= 8800'SS 13-3/8"CSG,68#,L-80 BTC,D=12.415" H 3919' / -5350" 19-5/8"X 7"WFD LTP w/TIEBACK SLEEVE& WFD HGR,ID= TOP OF 7"LNR H -5360' f74 Minimum ID 7 I' @ ___ ) NDHES WX(NPD A3530 -5516'MLHLOUT 4-1/2W 9-5/8"SLB W-IPSTOCK(_/__Li — -6600' [9±-5/8"CSG,47#,L-80 NSCC,ID=8.681" -I -6600' `,'r) ;';;)' H7"X 4-1/2"HES TNT PKR,D= " --I 4-1/2"HES X NP,D=3.813" TOC XX/XX/XX -9401;' A X F E�1 eH4-1/2"HES X NP,D=3.813" tai „....5 10850W ]-l7"X 5" FD LTPw!BACKSLEEVE& WFD HGR,ID= " TOP OF 4-1/2"LNR —I ^'10860' I if; -10866' —14-1/2"WLEG,ID=3.958" k. • H ELND TT LOGGED_/_/ 4-1/2"TBG,12.6#,13CR 85,VAM TOP H ^-10855' �j: J' 0152 bpf,ID=3.958" -15"X 4-112"XO,D= " Yri'I w NCS FRACPORT SLVS,ID=3.860" 4 NO DEPTH SEAT SZ ACTUAL SZ 0/C DATE 1XX ►4 20 J I,X 7"LNR,26#,L-80 VAM TOP HC, --I •-11000' ► f 1 S 0383 bpf,ID=6.276" —e 17 mmeii► 16 6.62I ►a�m 15 14 4 mi6 13 12 � um 11 I iI. 10 ► 9 to_ __ I 8 4c....; 7 ► 6 .11,045 es ► 4 PBTD H -16156' 3 X19.941"1► 2 4-1/2"LNR,12.6#,13CR 85,VAM TOP --I -16236' i'I.A.-..�-1► 1 0152 bpf,D=3.958" O=OPEN C=CLOSES DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/22/93 ORIGINAL COMPLETION 1AELL: 09-51' / 1_ SIDETRACK(09-51A) PERMIT o: 12/21/16 JMD BOLT PROPOSAL API No: 50-029-22320-0 i 12/27/16 KR/J16121 B&.LT PROPOSAL REV 1 SEC 1,T10N,R15E,1023'FSL&122'FW_ 91/19/17 KR/11H BULT PROPOSAL REV 2 10/09/17 KR BUT PROPOSAL REV 3 BP Exploration(Alaska) I 0 - ig ( ) 2 X ; m E o� w m0a Ng o' Jm .-i- s '..1-S' s 9 $ � has go2� a e o� `c,,, 7- g m gni PP s. sw`c g ,::, s\wx .$ij • . I rr Lon0Nanr S 2 ..\ laa mm m,, ,n n i : ' oaca-W *---!.,,z,..:a ne7 °" .. eo mom Sc :WiNx Nn i�,r, i ��� .>� z . � _ ��� ,,,n-i.- �nn CO n�L,Jn � 0 t. - I Q I a J o Y � a \ s• ���N/._ m' m ---- ..---- '3 J «< aia 00 00 $ !SOS W O 11 : __iiii- W � �� � S 0•J W mm 14Z !!1.-_5 s 3 I �� �� m�N N ::1, N � � --—li- z �" Pr .9/L t..lvai:-" °uS�^ g"r'� \ / s it it � I\lip =�:11l jdd'=�1!�1111�1'dl�9al ----- _ ( elsoi l Qf I.1 - II Q 1 i L BI —'�=s'=L I oP Wit'° W .9-.9 8 s vad orc \ \ 1739 N URO wrm rvl I9HUM1 O --JA9-.9—* .Ll-•Ll •Z/L 9L-,1Z O O .Z/l 9-.LY LO 0 O, (34N1 17W939) ow • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist // in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist k 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 m N N MCF per Day MCF per Day o o ,I c o 0 0 8 8 1 g . N o oo g ti ti g ri-1 ri � ,I m a ..._ i. 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IO.,Ql WI I E E co o a o al 0 0 0 o 0 0 0 � ; g o o o 4 Aea Jad slauee Aea aad siaiiee u 0 0 a Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, February 04, 2015 4:28 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OIL;AK, OPS PCC EOC IL; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr;Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; Regg,James B (DOA) Subject: NOT OPERABLE:Injector 09-51 (PTD#1921410) Due For AOGCC MIT-IA Attachments: image001.png All, Injector 09-51 (PTD# 1921410) is due for an AOGCC MIT-IA on 02/20/2015. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection, and will be added to the Quarterly Not Operable Injector Report. Thank you, Kevin Parks Aire c Lc II"IF ) SCANNEDi t -. 1; di BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegntyCoordinator@bp.com -.•- z 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 D FEB X012 Ft 0. I / 2 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 0 9f-61 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) 1 DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09-01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09 - 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sued conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09 -09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09 -15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sued conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09 -24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09 -30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09 -34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 1.2 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 '"'"�' , 09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 23, 2011 TO: Jim Regg V '1 �l I( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09 -51 FROM: John Crisp PRUDHOE BAY UNIT 09 -51 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry \ AC-- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 09 -51 API Well Number: 50 -029- 22320 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110221071918 Permit Number: 192 -141 -0 Inspection Date: 2/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -51 ' Type Inj. G - TVD 8709 IA 893 2695 - 2645 2630 P.T.D i 1921410 - TypeTest I SPT , Test psi 2177 ' I OA 152 247 244 242 Interval 4YRTST P/F P , Tubing 2200 2200 2200 2200 Notes: 7.8 bbls pumped for test. - 1 3 V ' I I Wednesday, February 23, 2011 Page 1 of 1 • • Page 1 of 1 Maunder, Thomas E (QOA) From: Prebfe, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Wednesday, December 05, 2007 8:00 AM To: Maunder, Thomas E (DOA} Subject: RE: DS 09-51 (132-141} Tom, I talked with Patti Phillips and both of our databases show 09-51 was changed over on 10/17/07. 6vey P~eb/e Petro%um Doto Manogement Engineer SA3'C ~7--564-4944 preb/egbC~bp, com From: Maunder, Thomas E (DOA) [mailtoaom.maunder@afaska.gov) Sent: Tuesday, December 04, 2007 4:03 PM To: Prebfe, Gary B (SAIC} Subject: DS 09-51 (192-141} Gary, We have received the 404 for changing this well from 1WINJ to WAG. When was gas first injected in to the well? According to our report, it looks like about October 4. Thanks, Tom Maunder, PE AOGCC 12/5/2007 STATE OF ALASKA ~~ ~; ; ALA~A OIL AND GAS CONSERVATION COMMISSION ~10V 2 ~ ~? f, REPORT OF SUNDRY WELL OPERATION~-iaska Qil & Gas Ccros.;~trlt~is~itani 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other (1 ~~ WAG Performed: Alter Casing ~ Pul1 Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ' 192-1410- 3. Address: P.O. Box 196612 Stratigraphic SerVICe 6. API Number: Anchorage, AK 99519-6612 50-029-22320-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54.8 KB PBU 09-51' 8. Property Designation: 10. Field/Pool(s): ADLO-028345 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11990 ~ feet Plugs (measured) None true vertical 9298.94 feet Junk (measured) None Effective Depth measured 11910 feet true vertical 9238.52 feet Casing Length Size MD TVD Burst Collapse Conductor 78 20" 91.5# H-40 32 - 110 32 - 110 1490 470 Surface 3887 13-3/8" 68# L-80 32 - 3919 32 - 3696.44 4930 2270 Production 11380 7" 26# 13CR80 31 - 11411 31 - 8859.94 7240 5410 Liner 755 7" 26# 13CR80 11235 - 11990 8725.9 - 9298.94 7240 5410 Perforation depth: Measured depth: 11394 - 11414 11538 - 11558 11620 - 11626 11654 - 11664 11498 - 11518 True Vertical depth: 8846.99 - 8862.23 8956.58 - 8971.78 9018.87 - 9023.42 9044.67 - 9052.26 8926 - 8941 Tubing: (size, grade, and measured depth) 7" 26# 13CR80 23 - 3284 5-1/2" 17# 13CR80 3284 - 11233 4-1/2" 12.6# 13CR80 11233 - 11290 Packers and SSSV (type and measured depth) 5-1/2" Baker SB-3 Packer 11213 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ ~ 1,. ,,~-~. ~~ ~~ zoa~ 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: 9363 80 3370 Subsequent to operation: 9994 3122 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ WINJ WDSPL ' 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 Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature Phone 564-4944 Date 11/26/2007 . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27,20074:43 PM To: 'Preble, Gary B (SAIC)' Subject: RE: OS 09-51 (192-141) C"\ ~) --0 \ ~c...<t\ ~~ J d <6 , ~~ I: -0' _ ~~'-\ ~~ ~(¿\ ~__ øé) From: Preble, Gary B (SAle) [mailto:Gary.Preble@bp.com] 'èt..~\~J sent: Monday, August 27,20073:23 PM '. ~4'Wì-f...;"1t To: Maunder, Thomas E (DOA) · , I R ,,\J , Subject: RE: DS 09-51 (192-141) We'll look forward to the corrected sundry. Tom I have corrected this 10-404 to show only open perfs 11498-11518 Gary Preble Petroleum Data Management Engineer SAIC 907-564-4944 preblegb@bp. com SCANNED SEP 1 1 2007 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] sent: Friday, August 24,20072:14 PM To: Preble, Gary B (SAle) Subject: OS 09-51 (192-141) Gary, This is another one of those 404s. You submitted a 404 detailing some squeeze work done per 307-244. It appears based on the operations summary that all perforations were squeezed and then the perfs from 11498 - 11518 shot. It would seem appropriate to either remove the other perfs listed on the 404 or somehow show them squeezed. Thanks, Tom Maunder, PE AOGCC 8/27/2007 . . STATE OF ALASKA . AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~ P.7-Ø 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 CEMENT SQUEEZE Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 192-1410 3. Address: P.O. Box 196612 Stratigraphic Service P 6. API Number: Anchorage, AK 99519-6612 50-029-22320-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 54.8 KB PBU 09-51 8. Property Designation: 10. Field/Pool(s): '. =::: :I» ADLO-028345 . Prudhoe Bay Field/Prudhoe Oil Poo~ 11. Present Well Condition Summary: e ;0 ~ J> m 5"'s c:: Total Depth measured 11990 feet Plugs (measured) None G). 0 o. ,:J¡D, true vertical 9298.94 feet Junk (measured) None ::f::t-~ ~ m Q' In· -. o. OI::¡. $I)' - \c. :::> < Effective Depth measured 11910 feet 10.. ~. f"'<.J n <:::J' m true vertical 9238.52 feet 4;:1' c:J> 3 --.. 0 Casing Length Size MD TVD Burst ~ollapse tI'> Conductor 78 20" 91.5# H-40 32 - 110 32 - 110 1490 õ' 470 :::J Surface 3887 13-3/8" 68# L-80 32 - 3919 32 - 3696.44 4930 2270 Production 11380 7" 26# 13CR80 31 - 11411 31 - 8859.94 7240 5410 Liner 755 7" 26# 13CR80 11235 - 11990 8725.9 - 9298.94 7240 5410 Perforation depth: Measured depth: 11498 - 11518 True Vertical depth: 8926 - 8941 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 11233' - 11290' Packers and SSSV (type and measured depth) 5-1/2" Baker SB-3 Packer 11213 0 0 0 0 0 0 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: 0 0 11307 1050 1689 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service P Daily Report of Well Operations X > 16. Well Status after proposed work: Oil Gas WAG r GINJ r WINJ p W OS Pl 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: 307-244 Contact Gary Preble Printed Name Gary Prebl~ /ÎA// Title Data Management Engineer ~- ,/~~ Phone 564-4944 Date 8/15/2007 Signature ../ ~ /' /' Form 10-404 Revised 04/200Û R , GIN A L RBDMS 8Fl SEP 1 0 Z~"~ Submit Original Only " . . 09-51 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***Heat Fluids*** [Cement Squeeze] Circulated 545 bbls (2 uprights) of 2% KCL bringing temperature up to 180* CTU #5*** Acid/Cement Squeeze*** MIRU CTU. Bullhead 10 bbl 50/50 meth, 270 bbls 1 % KCI w/0.6% SafeLube and 10 bbl 50/50 meth tail. RIH with CTU. *** Job continued on WSR 06/27/2007 *** 6/27 uprights of 1 % KCL to 180*f for CTU #5 6/27/2007 CTU #5 Cement Squeeze *** Continued from 06/26/2007 *** InterACT publishing during job. Tag bottom at 11815' ctm. Flag CT 10' off bottom. POOH. Heat 1 % KCL up to 180* F in UR tanks. Cement system sensitive to temp. *** Continue job on 6/28/2007 *** 6/28/2007 CTU #5 Cement ***Continue job from 6/27/2007*** InterACT publishing during job. Load and pressure up IA to 1500 psi w/ diesel. RIH w/ 3" BDN. ~ 11815' CTM. PU to confirm flag on CT. Wash across perfs from 11,394'- 11,664' w/30 bbls NH4CL, 9 bbls 12% HCL, 8 bbls 9:1 Mud Acid, 31 bbls NH4CL. Flush across perfs and rathole w/ 1 % KCL. Perform cement squeeze. Pump 15 bbl fresh water spacer, 20 bbl neat LARC cmt, 50 bbl LARC cmt w/ agg, 26 bbl of neat LARC cmt. 96 bbls of cement total. Pull to safety. Calculated cement top at 10,032'. 47 bbls of cement behind pipe. Attempt to PT to 1500 psi. After 4 attempts held 1500 psi. After 6 1/2 hours on cement attempt to PT to 2000 psi. Broke at 1985 psi and fell to 1000 psi. Attempt to PT to 1500 psi and failed. Lost additional 9 bbls of water during PTs. 56 bbls of cement behind pipe. After 7 hours on cement forced leave a cement plug. Clean out to 11,320' with biozan. Chase biozan OOH at 80%. Recip across all jewelry. Freeze protect tubing from 2500' w. 50/50 Methanol. ***Continue job on 6/29/2007*** 6/29/2007 CTU #5 Cement Sqz ***Continue job from 6/28/2007*** InterACT publishing during job. Bleed IA down to 200 psi. RD CTU *** Job Complete*** Need to come back and underream cement ***WELL IN ON ARRIV*** DRIFT TUBING WITH 3.50" CENT, TEL, SAMPLE BAILER LOCATED END OF TUBING @ 11285' SLM (ELMD @ 11278') NEG 8' CORRECTION CORRECTED DEPTH, CEMENT BACK IN SAMPLE ***TURN WELL BACK TO DSO*** 7/10/2007 MIRU CTU #5. *** Job scope: Under-ream cement from liner*** InterAct not publishing. MU MHA w/ 3.5" underreamer (6.276" open). Tag cement top at 11326 CTM & correct depth to 11314' Start under reaming process using recirculation system from return tanks. ***Continue job on 7/11/2007*** " . . 7/11/2007 CTU #5 ***Continue job from 7/10/2007*** InterAct not publishing. Underream cement from 11314' corrrected depth. using sweeps of 3# Biozan w. 3 Ibs/bbl citric acid. Launch 3/4" ball and shift Circ sub in MHA POOH @ 80%. Redress Underreamer with bottom blades measured at 6" and RBIH. Underream from 11412' to 11488' *** Job Continued on 7/12/07*** 7/1 CTU #5***Job from 7/11/07***lnteract Not Publishing. Continue Underreaming cement. Underream to 11560' ctmd. Drop 3/4" ball to open circ sub and POOH at 80%. Freeze protect to 2500'. Blades look good on Underreamer, minimal wear on blades. R/D Job Complete ***Notify DSO of well status*** 7/1 ***WELL S/I ON ARRIVAL*** (rate) DRIFT W/ 33/8" DUMMY GUN, TEL, & S-BAILER TO TD @ 11,563' ELMD. (btm perf @ 11,664', 101' OF FILL). RECOVERED SAMPLE OF WHAT APPEARS TO BE MUD. ***WELL LEFT S/I, DSO NOTIFIED*** .. FLUIDS PUMPED BBLS 1295 1% XS KCL W/0.6% SAFE LUBE 105 3# BIOZAN W/PPB CITRIC 130 50/50 METH 1530 TOTAL , . . SARAH PALIN, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Patti Phillips PE BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, 09-51 Sundry Number: 307-244 , 3 2007 SCANNE.D JUL ~ Dear Ms. Phillips: \ q g...-14-1 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Commissioner DATED this (D day of July, 2007 Enc!. · 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate LV A1t~fWaiVe~"Ui d'J'.; Other L:¿ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Cement Squeeze Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developm ent 0 Exploratory 0 192-1410 / 3. Address: P.O. Box 196612 Stratigraphic 0 Service ø 6. API Number: Anchorage, AK 99519-6612 I 50-029-22320-00-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-51 , Spacing Exception Required? Yes 0 No 0 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028345 - 54.8 KB ~ Prudhoe Bay Field / Prudhoe Bay Pool ~ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rotal Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): JUnk (measured): 11990 /' 11910 . 9298.94 9238.52 None None Casing Length Size MD TVD Burst Collapse Conductor 78 20" 91.5# H-40 32 110 32 110 1490 470 Surface 3887 13-3/8" 68# L-80 32 3919 32 3696 4930 2270 Production 11380 7" 26# 13CR80 31 11411 31 8860 7240 5410 Liner 755 7" 26# 13CR80 11235 11990 8725.9 9299 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11394 - 11664 8846.99 - 9052 7" 26# 13CR80 23' - 3284' - - 5-1/2" 17# 13CR80 3284' - 11233' - - 4-1/2" 12.6# 13CR80 11233' - 11290' Packers and SSSV Type: 5-1/2" Baker SB-3 Packer Packers and SSSV MD (ft): 11213 0 0 0 0 0 0 12. Attachments: Descriptive Summary of Proposal ø 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Developm ent 0 Service ø 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/15/2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 W1NJ0 WDSPL 0 Commission Representative: Prepared by uäry ,..r~ule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name / ...patti Phillips Title PE Signature ;?r¿z¡:;:c::;a~~ Phone 564-4578 Date 7/17/2007 ; COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ~'7. t5J~LL/J ~-rT Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: II U RBDMS 8Fl JUl 2 3 20D7 Apprn".~ø y#? APPROVED BY 7 (20/7 COMMISSIONER THE COMMISSION Date: , Fe./' 10 ,~ Kt::.lA::IVt:U _ STATE ðfÄL'Þ:sKÁol '¡'/IÍ.iJ?~, A~A OIL AND GAS CONSERVATION COM_ION ¡:;d;. JUL 1 9 2007 APPLICATION ~~A~CS2~~~RV APPROV A~!ask~)ðì1 & Gas Cons. Commission Form 10-403 Revised 06/2006 0 R t G \ N A L L $tØ? Submit in Duplicate ·õ To: . . Clark Olsen I Jerry Bixby, GPB Well Ops TL Date: February 8, 2007 From: Abraham Zambrano, Wells Engineer Subject: 09-51 i CT Saueeze and AdPerf (Chrome) AFE: PBD09WL51-C Est. Cost: $250M Est. lOR: 250 Th' d 'I d th f II t IS P roce ure mc u es e 0 oWlnq malor s eps: Step Type Procedure 1. 0 MIT-IA (probably just requires triplex) 2 S Drift & tag. 3. C Acidize & squeeze. 4. S Drift wi DG (post squeeze) WOC 3 Days 5 E Adperf (post squeeze) Current Status: Last injection rate: Max Deviation: Min. 10: Angle at Top Perf: Deep TO tag: Last Downhole Ops: H2S Level: PWI 9044 bwpd PWI @ 1801 psi WHIP, 1/4/2007 51 deg @ 8,048' 3.725" @ 11,279',4-1/2" Otis XN nipple 40 deg @ 11 ,394' Drift & Tag 11,799' ELM, 10/20/2006-no problems IPROF 11,800' (did not tag TO), 11/06/2006 153 ppm, 3/2012003 Well History: OS 09-51 was converted to a WAG (water alternate gas) well May 2006 and is presently on PWI. Before the start of MI injection, the uppermost perforations will be squeezed, eliminating the MI from flooding the upper most part of the Zone 3. Currently, these upper perfs are taking 69% of the total water injection. The SCMT bond log run 10107/2003 indicates that two zones showed poor cement at 11390'· 11450' and 11550-11575'. A caliper was run across the tubing on 06/07/2003. The tubing was in good condition. The objective of this procedure is to squeeze off all of the uppermost open perf interval. After waiting on cement, adperfs will be shot, and the well will be put on MI. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663(W), 240-8037(C), 274-0929 (H). Jennifer's cell phone may not work from the CTU's phone, so it may be necessary to call her from the truck phone. . . Objective The primary goal is to squeeze all open perforations in the uppermost perf interval so that MI can be injected in the lowermost part of the interval. Primary squeeze target: 11394'-11414'. All perfs will be squeezed off. Current injectivity is 9200 BWPD @ 1800 psi. Procedure/Risk Discussion · Please call Jennifer prior to pumping this cement job to discuss objectives. · Based on ¡PROF on 11/06/2006, injectivity into the upper zone (11394'-11414') is - 4 to 6 bpm at 280 psi. Expect huge injectivity. Likely will require leaving a plug to mill out. Should be similar to recent 13-23i. · The bottom hole static pressure and temperature on 4/12/2006 was 3266 psi and 190°F @ 8855' TVD; 300 bbls of diesel (down to 10804' MD or 8398' TVD) will be needed to have 100 psi on wellhead during the cement job. · The static BHT on 4/12/06 was 188°F. Later, with well on injection (9,200 BWPD), the BHT was 137.7°F. Ensure that fluids used to load the well are 180°F Please note that the cement design will have to change if the load temperatures are different. · The wellbore volume is 331 bbls to 11,799' ELM (Last Tag). · NOTE: 09-51 has chrome tubing and chrome liner. MIT-IA was pressure tested to 4000 psi on OS/23/2006, and passed. Pre-Squeeze FB: 1. MIT-IA to 2500 psi if desired (last MIT IA was done on 5/23/06). Pre-Squeeze SL: 2. RU SL unit and drift & tag PBTD. Important to obtain an accurate eline measured tag. CTU Acid wash. and Cement Squeeze: 3. RU 1.75" CTU. Fluid pack well with -500 bbl 180°F KCI water (-1.5 x well bore volume) at max rate. After -500 bbls of water have been pumped, reduce the rate to -1 bpm in order to maintain BHCT. Well will be on a vacuum with a full column of seawater. Note: Do not pump J313 (slick water) into the perfs ahead of the cement, as it will clabber up cement. Well bore volume = 331 bbl to 11,799' PBTD 4. Run in hole w/cement nozzle (no check valves). . . 5. While pumping down backside only (coiled tubing by tubing annulus), tag PBTD with nozzle. Pull up 10 feet and flag pipe. Pull up hole above 11,394' (top perf.) Note tubing tail at 11278'. 6. RU cementing equipment and pump the following down the coiled tubing, reciprocating across target squeeze interval 11 ,394'-11 ,414' MD. a) 840 gallons (20 bbl) 3% NH4CI b) 420 gallons (10 bbl) 12% HCI c) 420 gallons (10 bbl) 9: 1 MUD acid d) 840 gallons (20 bbl) 3% NH4CI e) Coil volume of spacer water * Additives and concentration can be determined as per current best practice based on 188°F and 13Cr. 7. Run down to as deep as possible. If tag is deeper after pumping acid, pull up 10' from new PBTD and reflag pipe. Pump flush to ensure all acid is removed from wellbore (acid is an accelerator to cement). Once the wellbore is flushed, pull nozzle above 11 ,394' (top perf) and park. 8. Pump diesel down backside as necessary to achieve positive wellhead pressure under static conditions (not while pumping into the formation). This will be about 145 bbl of diesel (based on estimated from most recent hydrostatics and a positive pressure differential of 100 psi.) Do not proceed with squeeze unless the tubing is liquid packed and gas free. 9. Batch mix 90 pumpable bbl LARC cement to meet the following specifications. Use old Arco ramp for lab testing. Temperature should be approximately 180°F. Please note that the cement design will have to change if the water used to load the well is not 180°F due to temperature's affect on cement thickening time. Volume to Pump Cement Type Filter Cake Thickening Time Fluid Loss Target Acceptable Range Rheology 90 bbl total Liquid Latex Acid Resistant w/D-176, 3% BWOC w/aggregate 8.5" firm cake ± 0.15" in lab 6-8 hours at 180°F SBHT 75 cc/30-minutes at 180°F SBHT 50 - 90 cc/30-minutes at 180°F SBHT YP>5 with no settling or gelation in fluid loss cell. 10. Catch a sample of the cement for QC testing. Line up cementers to the coil. 11. Pressure up IA to 1500 psi. 12. Pump the following down the coil: . . a) 10 bbl spacer water Do NOT use friction reducer J313 as it will clabber up cement b) 20 bbl bbls neat LARC (to fill the rathole so if we leave a plug we won't be drilling out LARC wI aggregate c) 65 bbl bbls LARC cement wI aggregate d) 5 bbl bbls neat LARC e) displace with spacer water 13. RIH with coil to flag depth as cement reaches the nozzle. Open choke to take returns up the backside. 14. Do not pull uphole until -4 bbl of cement are out the nozzle. (Ideally, this will place the cement top -100' above nozzle in order to prevent dilution of cement while pulling uphole). After 4 bbl cement are out the nozzle, pull uphole and lay in cement 1 :1. 15. Pull up to just above top perf of 11,394' (to prevent cement dilution if perfs are taking cement). 16. Close the choke and reciprocate just above the top perf at 11,394' until wellhead pressure rises 1000 psi. Do not build squeeze pressure while coil is below perfs to prevent getting "noded" in. 17. Once 1 000 psi pressure bump is observed, open choke to take returns at 1 000 psi and begin pulling up, laying in remaining cement at 1 : 1 . 18. Position nozzle at cement top just as last barrel of cement reaches nozzle. 19. Pull up hole at maximum speed to safety at 9301'. Note: 90 barrels of cement would extend up the tubing to 9401' MD if the perfs take no cement before squeeze pressure develops (assuming PBTD at 11,799' MD). 20. With coil at safety, close choke, and slowly walk squeeze pressure up to a target of 2.500 psi DP at the perfs in 500 psi increments, holding each increment for 15 minutes. Maintain 2,500 psi for 1 hour. Note: Account for methanol, diesel, and cement densities when calculating DP at perfs (SBHP = 3266 psi at 8800 TVD). Note: Assuming PBTD = 11,799' and 90 bbl of cement pumped, approximately 71 bbl of cement can be sQueezed behind pipe before the cement top in the casing falls to -11 ,287' ELM (within -1 DO' of the top perf at 11,394'). Note: If unable to achieve at least 1500 psi DP squeeze pressure at perfs, contact Jennifer and plan on leaving a plug and coming back to drill out after woe 3 days. . . 21. After one hour at 2500 psi, slowly bleed WHP down over 15 minutes to 500 psi WHP. Minimize surges while bleeding down WHP and during cleanout to prevent nodes from getting displaced. 22. Swap to 1 112# biozan and launch ball. Chase ball to nozzle then RIH at 1: 1 jetting at max CT pressure and clean out to 11 ,800'. Pump rate at 1 bpm across perfs to avoid node damage. 23. Take barrel count to ensure 1:1 returns. 24. Switch to friction reduced water. Make 3 down and 2 up passes from PBTD' to IT. 25. Jet uphole at 80% running speed and max CT pressure. Slow down across all jewelry. 26. Freeze protect the top 2,500' of well bore. 27. RD CTU, leaving well secured with -500 psi on tree. Post-SQueeze CT Operations (if cement plu~ is left ) 28. After 3 days WOC, RU CT with milling BHA. Mill to 11,530' as per PE manual. Post-SQueeze Slickline 29. RU slick line; tag PBTD wi 3-3/8" dummy gun. Post-SQueeze Perforatin~ 30. Tie in with SWS IPROF (11/06/2006). Perforate the interval 11,500'-11520' with 3-3/8" 3406 PowerJET 60° phasing 6 spf. See separate perforating procedure, 8/21/06. . . . . . . ... 1J:E::: I'M: I I WB.U£o\D ::: 6-3.'S'(;M 09-51 SAfETY NOTES: CHROME 18G & LNR ::: OTIS KB. 8.Bf ::: 55 SF. 8.Bf = K(F::: 2388' 2099' H7' CAM BAl-O SSSV Np, D::: 5.937" , KAI'g ::: . um ::: 141101 um u::: !III UI1~1 IT' TBG, 26#, 13-Cß.BO, .1m3 b t, I)::: 6276' I 3284' L 3284' ~7" X5-1/2"XO TCPCF 5-1Q'1BG! 3284' r 1'3.318" (Sa. 6&¥. bBD. Ð= 12.415" { 3919' i---.j ~ GASlFTw.NæELS Sf r.Ð 1VD IDeJ iYFE VlV LA II."" I"VI'(I [}t,1C 1 341» 3314 34 M:RLA (Jd( RA D7iD71U3 MininUmID=3,725"@11279' L- 2 :·477 4757 4S om L8-1 (Jd( RA 0 01122193 3 66ID 5!i11 4B M:RLA (Jd( RA D7iD71U3 4-112" OTIS XN NPPLE 4 7352 51»3 48 M:RLA (Jd( RA D7iD71U3 5 8144 6!i13 49 om Lß.1 (Jd( RA 0 01122193 ð 8M! 7013 4B omLß.1 (Jd( RA 0 1D1D2J93 1 ¡I6a; 7510 49 omLß.1 (Jd( RA 0 01 i22I93 8 103D1 SOt4 51 omLß.1 (Jd( RA 0 01122193 9 10643 8273 51 omLß.1 (Jd( RA 0 01122193 10 10033 8491 51 OTlSlß.1 ECLIAl RA 0 01.'22193 15-1I2'TBG,l1#,13-Cß.80. .D232b t.1D=4.B92' ! 11203' 1-- . 11193' H5-1/2" OTISXNNP,ID:::4.455' I 11233' I- ~ 11213' 1~5'S" x 5-1/"Z BAKER SB-3A ITCPCF4-ta"TBG ¡.o HYDROSEr R<R, D::: 4.815" TOPOFT LNR I 11235' l- I 11228' (-15-112" X 4-1/"Z MLLOOTEXT ( I . 11261' H4-1I2"OTJSXNP.ID::: 3.813" I I 11279' H4-1I2"OTISXNNP,ID:::3.725' I 14.,lZ·TBG. 12.6ìíí,13-Cß.80. .0152 bpf.ID::: 3.958' [; 11290' I- 11291' H4-1,12"wtm I 11218' [-t8.MJTTLOOOEDCG/I9191 I 9-MI" CSG, 47#, J.m0. D::: B.æl" [ 11411' .. PEFFæA mNSl.MIf\ RI' I ÆFLOO: DllJM5FL 000 1/18/93 ANa.EAT1DP~: 400 113*4' ( I ( I NcH: Refer " FlDdœtilJ1 œ fer histoiciil perf dilta SIZE S~ tmRVAl q,nJSqz DATE I I 3-3.6" 4 11304· 11414 0 02IœI93 3.3.6" 4 11538" 115$ 0 02IIMG 3.3.6" 4 11620 - 11626 0 02IœI93 3.3.6" 4 11654" 11ð64 0 02fŒ,'Q3 f'STD 1191 0' .~ I T 1M. 26t 13-CR-80. .0383 ¡,pt. Ð =6.276" 11990' Cl\TE I RI:V BY I D\TE RBlrrt COMBlTS FR.OŒ6' y Uffi 1ftl7LJ![I W8.L: 09-51 10Jœ101 FERI.fT NIx 1921410 !I5JœJ'In A TDKK av t.s APlNIx 51HJ:i9-:!2331-ID 0l1Ul103 JJffi.p a. v 0'0 £1. T10~ R15E 4964.67'F8.& 2935.38' FN.. BP&pIoRtìon ¡A ilShJ . . Page 1 of å. Maunder, Thomas E (DOA) ------~ From: Phillips, Patti J [PattLPhillips@bp.com] Sent: Tuesday, July 17, 2007 11 :00 AM To: Maunder, Thomas E (DOA) Subject: RE: 09-51 Cement Squeeze 10-403 Sundry Tom, The purpose of the sqz is to eliminate the perfs in the upper Zone 3, which were taking 69% of the total water injected. After the sqz job, additional perfs will be added in Zone 2, 27P and the well will be put on MI. The complete program will be included with the sundry. Thanks, Patti ,~,.~___~_.o__,~__.~.__..______._.___~~_~_"_..______.._____,___,__._~._" From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 17, 2007 10:08 AM To: Phillips, Patti J Cc: Preble, Gary B (SAle); Engel, Harry R Subject: RE: 09-51 Cement Squeeze 10-403 Sundry Patti, Thanks for the information. What was the purpose of the squeeze? A document has been prepared to guide making the determination of when a sundry is needed. It is called "The Matrix". I have attached a copy. This is a document that should be available to the engineers preparing well work programs. If you or your colleagues have questions, Harry should be able to help you. Call or message with any questions. Tom Maunder, PE AOGCC ._....'---~----~ From: Phil/ips, Patti J [mailto:Patti.Phil/ips@bp.com] Sent: Tuesday, July 17, 20079:50 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAle) Subject: 09-51 Cement Squeeze 10-403 Sundry Mr. Maunder, I just found out yesterday that I should have initiated a sundry for the cement squeeze for 09-51. The work was completed, 7/12/07, before we got the sundry out to you. I want to apologize for not knowing the process required for these sundries. I am fairly new in my job, so many of us have moved around and we currently do not have a good system to alert us when a sundry is needed. Our more complicated programs that might require a sundry (patches, squeezes, acid and frac jobs) do not have a built-in method to help notify everyone that a sundry is needed. Thanks to Gary Preble, who reviewed the Well Service Reports and caught the oversight. I sincerely apologize for not getting the sundry form initiated and will work on a process that will help me know when to begin the 10-403 and 10-404 forms. We now have the form for 09-51 ready to send to you at the AOGCC. If you have any questions, please call or email. Thank you, 7/20/2007 Sc~lnIbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth US~ 11/28/06 lqg -[L.{/ NO. 4058 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD H·34 11477963 LDURST 11/07/06 1 y.o1B 11485468 MPPROF W/DEFT & GHOST 11/07/06 1 2-08/K-16 11487771 LDL 11/12/06 1 X.o3A 11485772 MPPROF WIDEFT & GHOST 11/09/06 1 DS 09·51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1 N-07A 11296715 PROD PROFILE W/GHOST 09/10/06 1 DS 09-31C 11483591 INJECTION PROFILE 11/20/06 1 G-06A 11422979 SCMT 11/01/06 1 P2-59A 11414775 SCMT 11/05/06 1 NGI-06 11414773 USIT 11/01/06 1 A-43 11414774 USIT 11/03/06 1 01-26A 11001225 RST-SIGMA OS/24/05 1 1 I~ . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: NO" 9. 9 70m) Alaska Data & Consulting Services 2525 Gambell S,_ S.iæ gO A~""'.... AK "50~! ATTN: Beth Q Received by: I / f\---- A STATE OF ALASKA _ ALA'" OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate 0 Other [] Convert to Inj Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver 0 Time Extension D f?þ..' J oJ¡.. Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 192-1410 3. Address: P.O. Box 196612 Stratigraphic 0 Service R1 6. API Number: Anchorage, AK 99519-6612 50-029-22320-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54.8 KB 09-51 8. Property Designation: 10. Field/Pool{s): ADL-028345 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11990 feet Plugs (measured) None true vertical 9298.94 feet Junk (measured) None ~~-'~'ÞJ\'~~.~-~::~;'- ì ;-,~ (">r:~I;- \,;\¡¡,.\, i--o. . '.. tli..,/ ),:~' '".. " Effective Depth measured 11910 feet true vertical 9238.52 feet Casing Length Size MD TVD Burst Collapse Conductor 78 20" 91.5# H-40 32 - 110 32 - 110 1490 470 Surface 3887 13-3/8" 68# L-80 32 - 3919 32 - 3696.44 4930 2270 Production 11380 7" 26# 13CR80 31 - 11411 31 - 8859.94 7240 5410 Liner 755 7" 26# 13CR80 11235 - 11990 8725.9 - 9298.94 7240 5410 Perforation depth: Measured depth: 11394 -11414 11538 - 11558 11620 - 11626 11654 - 11664 True Vertical depth: 8846.99 - 8862.23 8956.58 - 8971.78 9018.87 - 9023.42 9044.67 - 9052.26 Tubing: (size, grade, and measured depth) 7"26# 13CR80 23 - 3284 5-1/2" 17# 13CR80 3284 - 11233 4-1/2" 12.6# 13CR80 11233 - 11290 Packers and SSSV (type and measured depth) 5-1/2" Baker S8-3 Packer 11213 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS 8Fl JUL 2 7 2006 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: 0 0 0 0 0 Subsequent to operation: 0 0 4553 200 1764 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development 0 Service R1 Daily Report of Well Operations 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ R1 WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 305-327 Contact Sharmaine Vestal P'oled N,me Sh',",."", V..tal , ~ Title Data Mgmt Engr Signatu~ ~ Phone 564-4424 Date 7/27/2006 Form 10-404 Revised 04/2004 Submit Original Only MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg \(e/.- ,«/0«- P.I. Supervisor'(i I - DATE: Wednesday, May 24,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-51 PRUDHOE BAY UNIT 09-51 ~ ,Ù\ \ \ C\'?r FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed B~~ P.I. Suprv ..J - ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-51 API Well Number 50-029-22320-00-00 Inspector Name: John Crisp Insp Num: mitlCr060524043949 Permit Number: 192-141-0 Inspection Date: 5/23/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ! I , I I ---- Well 09-51 IType Inj. i W TVD : 8694 IA 180 I 4000 I 3940 3920 i :TypeTest i SPT I Test psi [ 'OA I ! I -- P.T. 1921410 2173.5 160 560 560 , 560 Tubing i I -- I I Interval INITAL PIF P 400 400 400 i 400 - Notes MIT IA 4000 psi. post initial injection. 9 bbl's pumped to for test pressure. ·-r~~I,\,.¡¡;;'¡L ~'",j\.l;¡ ''';>Ì .w.-- r; ,'""" t) Wednesday, May 24,2006 Page 1 of 1 ~,' ~ ',S.:J ,/A' '\" [9 Œï ' \ Ii I I ,I \ I, I " '\ :: /j \ I, II I, r ',ì\ I' ! i \ . i ,! ~ ~ I LJ ¡(', 10n ì i? ~ i i I I L~,'::1J , '1' I J" I : ! I ' \~I; ) t:~~ ~nl ~\ (n'~ :~ '7' œ' , ,I i, !! ¡'i¡ \ ¡ !\.~ 11/ ,,' J, ¡ ,,/8', ilb! ; 8\ \''\ ! i~< i~/ \ (,;""" ¡ I[ l / '~ :ru,'\ 'i ;'J" \ I " " '\ I I: ' ,'"l ~ ',' "â .. 1\ (I I 1\' ¡ .' I Wi '" . ~ '~~.i... ~ ) ALASKA OIL AND GAS CONSERVATION COMMISSION / I ¡ FRANK H. MURKOWSK', GOVERNOR Victoria Imeh Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \ C\:f.... \ \{ I Re: PBU 09-51 Sundry Number: 305-327 ~~NEt) O[;<lI' $ 1 200~1 Dear Ms. Imeh: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this -rb day of October, 2005 Enc!. 1, Type of Request: CIí /(), "bb -0) STATE OF ALASKA " All k Oil AND GAS CONSERVATION COMMk lON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool 0 4. Current Well Class: , Development ~ / Exploratory D D 6. API Number: Stratigraphic 0 Service 50-029-22320-00-00 / \d6,fR It(l;61i\1ce D OCT 2 4 2005 Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend U Repair well D Pull Tubing D Alaska Oil & Gas Cons. Commissiol Perforate U Waiver U AodnJ~~ U Stimulate D Time Extension D Re-enter Suspended Well D Convert to Injector 5. Permit to Drill Number: 192-1410 / 9. Well Name and Number: 54.8 KB 09-51 /' Casing Conductor Surface Production Liner Total Depth TVD (ft): 9298.94 Length 78 3887 11380 755 10. Field/Pools(s): PRUDHOE BAY Field / PRUDHOE Oil Pool / PRESENT WELL CONDITION SUMMARY Effective D~, e, ~D (ft): Effective Depth TVD (ft): Plugs (measured): ~~:,~ 9238.52 None Size MD TVD Burst Junk (measured): None Collapse 470 2270 4760 5410 8. Property Designation: ADl-028345 11. Total Depth MD (ft): 11990 20" 91.5# H-40 32 110 32 110 1490 13-3/8" 68# l-80 32 3919 32 3696 4930 9-5/8" 47# MN-80 31 11411 31 8860 6870 7" 26# 13CR80 11235 11990 8725.9 9299 7240 Perforation Depth MD (ft): 11394-11414 11538 - 11558 11620 - 11626 11654 - 11664 Packers and SSSV Type: Perforation Depth TVD (ft): 8846.99 - 8862.23 8956.58 - 8971.78 9018.87 - 9023.42 9044.67 - 9052.26 5-1/2" Baker SB-3 Packer Tubing Size: 7" 26# 5-1/2" 17# 4-1/2" 12.6# Tubing Grade: 13CR80 13CR80 13CR80 Tubing MD (ft): 30 - 3284 3284 - 11233 11233 - 11291 Packers and SSSV MD (ft): 11213 12. Attachments: Descriptive Sum m ary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for /1 Commencing Operations: 1 (2J005 16. Verbal Approval: . Date: Com m issi on Representative: 17. I hereby certify th~t the foregoing is true and correct to the best of my knowledge. Contact Printed Name \ ~ctoria Imeh Title Production Engineer Signature 0" \~' Phone 564-5233 Date I, \. . COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory 0 Development D Service ~/' 15. Well Status after proposed work: Oil D Gas D Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ ~ / WDSPL 0 Prepared by ;:)IIè:lrll1é::1l11e Vestal 564-44:¿4 Victoria Imeh 10/13/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: W5 - ~ I Plug Integrity D BOP Test D Mechanical Integrity Test ~ location Clearance D Other M : T >. I),~ s-l - i '~i., nT(~.~ will ben,.: tevV¡~~,,:~~t IA "-C S L-thL.¡'\..~ l' { r ~ Vv"- M:! W t U v~ "'- 3 v c\e'1 S C' r ~ It .. t I h,;/ ~ L t, --p,- . Approved by: ' COMMISSIONER THE COMMISSION Date: /ð ORIGINAL Submit in Duplicate V" Form 10-403 Revised 11/2004 n 111I I rs n 1 9- ') ') .../"'" / ,\ SchlumbePllP . ......,....... ' : . . .' ....._...,.., Company: BP EXPLORATION (ALASKA), INC. " 1/ " ""~ , Well:,' , Field: \ ( , Boroug h: . D.S. 09-'51 PRUDHOE BAY NORTH SLOPE ! State: ALASKA ~ ü ~ ..J Q' 5: ~ LL Z >- ~ 0 W -<::t ç: û... <t: <x:: 0 co oð IT: ..J W 0 Z (f) 0 ..J IJ") 0 (f) ..J I I LL m 0... ¡::: t- o M 0 >< <x:: a:: ::> 0 w Ü 0 C\J ([ 0 a.. 0 z a.. 0 co ..J SLIM CEMENT MAPPING TOOL GAMMA RAY / eel 7 -OCTOBER-2003 .....,. -.,' ..... ,I..,.J ,;: ~ ~ ~ ¿", ~-;.; '.' ~;.:' ~ :;., ..c c c OJ 0 (1: ð ü .~ ~ E- o ã) () "" 0 co ü: .3 ~ ü ~_ LOiL9!!!g.J?at~______,__ Run Number ...___ Dept~~-º~~~e!.~____._, ___~ Schlumberg~~~E~h_ _,~ottom Logi~!~~~~. ~ Top Log Int~~~~__ __._Ca~ìng£!~~2YP~ Sali n ~l....__.,_ ,_ _.._~p_e.!l_~~ty______ ~____ Fluid Level BIT /CASING/ruSING"STRï'NG- -- - '".--------."--..---- ""-..-- --.------.--------,------..-.. -.-.-"-_. ~ -- ~ --_.-._---._-.".. Bit Size 8.500 in ___._.___,.____,__.___ _ __._.".,~.__,___.." __ ,__.___ .._," __._ ____._._~__.___._"..M.___ _.. .__......,._...._'_.____ ___.... ....._._ _. _ .__..__.,_.._____._n__._,______,,____. ,_ _.___ "_'___ __,__ . ., From 11411 ft .~~~: =-ï- ~_~.--~~~~-=~_._.." _~._'~~.., ~:-:_~=~_~__1~~~QI~~'.-.~: .~~. , ,;,,~;~) CasinglTubing Size 7.000 in ! ~~~~~~-- - .... . ...._=.~:~~l;o --.-- '--"---"~---~" '--."-- .---.-.--- -~.....-. -.-,---.. From 11235 ft --.----,----,--..- "--~- .,-----. -_..._-_.__.._---_.~.-_. ... To 11990ft "Maximum Recorded Temperatures ¡ Ii! -LOgg-eron'Bi~~_='I··~:.~]:~~~~i~=~Oct-2003----~~~_~_~:~J ~1?~_~q.~~_~ _~:'_ ,:~ --'1 _____~__~.__~_._____J ~!!_~l}!'.~~~r 'u ~ u__ ~C?c:ati<?{~ __ ___~~ 58 J_~~~'::!9HOE B~ ,!" _ ______~_ j_..____~___.._~_h_ Recor_~e~_._ B.H.BOEHME _.____~.____,._ ~_~___ __ ~~____~_ Witnessed By M.AIVANO Log Measured From: Drilling Measured From: "J0.:§_:~c,..__ _ ~_.R-tSJ?·..__~ ,J3JSJ2:_ Elev.: K.B, 54,8 tt G.L. 25.3tt OF 53,8 tt Elev.: _ __9_.h.. r 1',1, po ;. !i I 1023' FSL & 144' FWL SURFACE LOCATION Permanent Datum: 54,8 tt above Perm, Datum API Serial No, 50-029-22320-00 7 -Oct -2003 ".-.-,---,----.---.-..........-- . ONE .'" .--.,---...--..-.. -.~--_. 11805 ft --- .------..-.-.-. '" . 11803 ft --_..__._..._--_._-_.__...~'''- .- 11 790 ft _, ....,_. .__......_.~n.____· ...._ 11240 ft _._ .__._,___._______,_.....___.__._~,.u,._....__ .. ._.._ ,._ KCL WATER Section 1 Township iON Range 15E . ...,.- '-,.--..----..-- -.. -""-'-'. .,,,-. ,,-_._~- .,. . . .. _..-. ~-- -'-',. .-....--,,-. '.-'--'...-" .. ..____.. ....~..._.. .._____..._.n.__,"..._._._.~..,_._.. ...'---_.._-~ . .-,-, '.' "...--- ..,_. ,-..' . .. .--.- ._..-----._-_._..~-- '-.-.. . .-. -. -. _ ....... ,...__..... ,." _.___...... __...,.,_......_.u..._.__._,,_...,_."._._..·_·___ .... -'-"""'-" ".-_._"....~ . .".-.., ----_._,-,._'''._",,--"- . ,,---.--.--..,-----..- ... ...--"..--.-..-- . - +'.. _ ·..'"_''_'n___''._'''_h~._....,__.~_'_''_''' -,_... ...--....-,-...--- .- . ---_.. '-"-..'- ,.-..-.-.-....--..-.-- ..- -....- -,_._~_.._._."'-_..".....,.- . . .-'-'.-. .~-.. .- ----,~..... --..----.---.--"---,. Input DLIS Files DEFAULT SCMT _PSP _ 009lUP FN:8 PRODUCER 07-0ct-2003 17:03 11815.0 FT 11036.5 FT Output DLIS Files DEFAULT SCMT_PSP _013PUP FN:12 PRODUCER 07-0ct-2003 17:40 OP System Version: 11 CO-305 MCM SCMT-BB SKK-2319-SCMT _b PSPT -A/B 11 CO-305 PIP SUMMARY ~ ~~~-~~~~,-~~-~!.y-~-~, ~-,-_.~_.~--- Maximum MAP Transit Time - - - - J~X!!)_ - - ----0 100 (US) 3001 I '""'. ,,'-'-'-" -"'--~'-"'-"-"- . .., "..-...-..., .,--" ,..-... CBl Amplitude (CBL) (MV) 100 .._-._._."._-_.~_._- ._"_ .___".____,__ ._. 'M ..~__~......_,....... . ,--.... --.- -.-~...--"---.---_....-".-"..--,-,.-.-.,,.._.~"."_"-- Minimum ~~iri;ansit Time L. _ _ _ç~~ .~~P!i~~~~ .t~~~)' . _. _ -----------;jO (MV) 10 ,100 (US) 3001 ---.--.,.-.---------.... ,.--..,--------........------.----..---.- ----.---.-.-- Computed I Average MAP Amplitude CCl Cbl 3.ft Transit Time (IT) I JAVMAL (CClC) 200 (US) 4OOrö" - - - - - - - -- 11I-5 (V) 13 !I_t!I!'_t!~~ _~~e~r~i~i,,-. -!,~.~., '~~" ~~,-.-n, '-,-JL,~-,M~Xi~~~~;;:LmPlitud~OO o (DEG) 36010 - - - ..l: (MY) - - 100 ---------.. - .-- .--- .~ ---- ---+--- ---------- I - ----------_.--~._--------_.._-- -.-- ---._------ OPEN PERFS o Gamma Ray (GR) (GAPI) Minimum MAP Amplitude Min Amplitude Max JMIMAL I I I I I I!~;'" 100Õ - - - "M- - -1"00 VOL VariableDensity (VOL) ! ( V) 200 (US) 1200 2.5000 5.0000 7.5000 10.0000 12.5000 15.0000 17.5000 20.0000 22.5000 25.0000 27.5000 30.0000 32.5000 35.??oo 37.5000 40.0000 42.5000 45.??oo 47.5000 50.0000 52.5000 It, 55.0000 - 57.5000 - 60.0000 - 62.5000 - 65.??oo - A7 <;""" ~~ Ï:~, "-. :, ~ \' ",. (~c-:: I,L .. ... - . v,S : . ' '<. ... I, '" -. '''-- , ~Il c_ ( \~ -= -- :... - '- ,..,- ., ' - , '-""-- (' .. - - ~ r- - - - - - _ __ _ ~~ ~r~ I . -- ::w- :J1- " ".~? : ~1: 1'" '~) ,~ ....¡. ,< ~þ :. I , ( '> . ~ ~I~I - ." - ~ -::. ~ tf _~~ _... ,,_._.~_ ~... --.. " " " --~ "", \<'--, J._____ . .) J~--.-..~ t, :=:= -<,j . I ~ ¡ f ., ',~ '1 \. '-' ----. \ '\ :.-- -- . < <.. < ( ( : J .-::> ~) ,__ i-- 1 _ "\ ( .~ ~J? }~~ : I I,/} =: i) .-' ' -.- 1 ,.r '-r- <.. I> 04/:, _ ~~ ~ m 1/ ,.' _ -....:=- /" --- ~ ".-. '':':==-~- - - - ~, " .' · L ~~ _. __"-.- --:.. -j~_::--:- --~ ~-. '.' -:=~ ---: ~~~ -=- . - ~'------ - ~-~~---- - 1\ <:. ~ .._ ~=:? - - -- ......,;:. 11400 · -....Ll.,. ,- _ ____,_ _ '~-. _,) =='!=:.~ \[ ·==~'-"-~~:2~ ' -'>..-, -- "- -'-~. -- -~... ---._- ..... .... ~'--, ,~ '~ (, "',-~- '--' ~ - '----== .~- - .-t-- ---, --~--- ____\ _ _..- ;' ') -=-- c---- .. -:==_==_.~== . ') <:: - ---':.._- " ) ........... --- - f" . - r -,- : --1'--(7- .~ "\ _ --..' :.. ':: . : -..." )-- / ±~~, :' I --=---__ :þ--,.-,....:'.). ==~-£ ::~=:_:::-:-..-::.' :::..- -. -- - ,.. I 'tl < . ~. ',' I' '. ;~ I, ~ ~ . t Ii ·1, ,j~ ~ ,1 1 :.. I " I ~! ;~; ~, 'X:~' ''''-wI _... ._..J .\ C.f .' . þ" .. - ~_:~-=- ~- - ... - - - - I" . _ * _ _ . ---'-- .._ .~.:..:..:-:: L- , w ._,___-. __.___.._.___ , I ~_._. ._-.A.-__.. t, -, . . - - --:-.....:: - - --" - --,. - - ~ - -'- - -:-- -:: :, .....-:.1. " ,'\ l-~J I I I I I 1_lIIlIIa..' Ilj 'nq i MAIN PAS~ SCMT - lOGGED UP 1 BOO ~PH ,~rl1:~ç, .:::, ""'-.- ~ - ~ -1{" ~" ';>~':~f.~'~'¡!, ~rf~~~~ """- ~' " ,:' I ,~~~ ___-=-~ - - . ' \ I .\ " I 1\' .... , ,,..-.,~.. _--;___...- ' t I I (MPWF) (MV) .-- $ \ j ¡ of -t t 11300 t ..# ~~ ~..iL ~F 0+:\ ~ bp .,. ..\ll.'''. -..,~ ~...~ ~..- ~..~ ...~ ~..... ·'i'~'\· ". ) ') To: J. Bixby/D. Cismoski Date: October 24,2005 GPB Well Ops Team Leaders PECT: PBD09WL51-M From: Vickie Imeh Production Engineer lOR: 300 Subject: 9-51 - Conversion to Injection Est. Cost: $1.75M 1 2 S F Dummy GL Vs AOGCC to witness MIT-IA to 2500 psi (" Current Status: Max Deviation: Min. ID: Last TD Tag: Last Downhole OP: Latest H2S Value: L TSI, Converting to injection 51 degrees @ 8048' md 3.725" XN Nipple @ 11279' md 09/28/2003 10/07/2003 - SCMT Log 151 ppm - 3/20/2003 Well 9-51 was drilled January 1993 as a Victor and Tango producer. Initial production was 2000 bopd at 500/0 water cut. A PPROF in February 1993 showed that the Victor perfs were not contributing, so a ROPE stimulation of the interval was performed. The stimulation increased the water rate by 3000 bwpd without much of a change in oil rate. The last PPROF run 3/97 showed 75% of production from the Victor perforations and 25% from the top Tango perforation interval. A SCMT in October 2003 showed poor .p' cement at 11390-11450' md and 11550-11575' md; however injection will be contained in the desired zones. It was shut-in in October 2003. 9-51 is currently being converted to a water injector pending completion of surface conversion. It is hoped that the actual surface conversion will be completed by 4Q of this year. This program requests well preparation and MITIA to confirm integrity in inner , annulus. 9-51 is ready for injection as soon as the IA test is completed, and appropriate state approval has been obtained. Contacts Victoria I meh cc: w/a: Well File Victoria Imeh Office 564-5233 Home 748-4961 Cell 748-4961 ,) TREE = RMC W8..LHEAD = 6-3/8" CrN A CTUA TOR = OTIS KB. ELEV = 55' BF. ELEV = KOP = 2388' Max Ange = 51 @ 8048' Datum MO = 11405' Datum TVD = 8800' SS 17" TBG, 26#, 13-CR-80, .0383 bpf, 10= 6.276" I~ 3284' I TOP OF 5-1(.2" lEG I~ 3284' 113-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 3919' I I ~ Minimum ID = 3.725" @ 11279' 4-1/2" OTIS XN NIP PLE 09-51 ~","",:i"',",'¡" ~ \ ~ ST 1 2 L--3 4 5 6 7 8 9 10 I 5-1/2" TOO, 17#, 1:¡..C R-80, .0232 bpt, [) = 4.892" H 1120 3';zl ~ 1 TOP OF 4-1t.2" lEG I~ 11233' 1 )z' 1 TOP OF 7" LNR 1-1 11235' r- w 14-1/2"TBG, 12.6#, 13-CR-80, .0152 bpf, 10= 3.958" 1-1 11290' 1 19-518" CSG, 47#, 1VN-80, 10 =8.681" 1-1 11411' PERF ORA 1l0N SUMI\t\A. RY REF LOG: OLUMSFL ON 01/18/93 ANGLE AT TOP PERF: 40 @ 11394' Note: Refer to Production œ for historical perf data SIZE SA= INTERVAL Opn/Sqz DATE 3-3/8" 4 11394 - 11414 0 02/08/93 3-318" 4 11538 - 11558 0 02/06/93 3-318" 4 11620 - 11626 0 02/08/93 3-318" 4 11654 - 11664 0 02/08/93 PBTDH 1& I 1 7" LNR, 26#, 13-CR-80, .0383 bpf. 10 = 6.276" 1-1 11990' I DATE 01/22/93 10/06/01 05/06/03 07/07/03 REV BY REV BY OOMv1ENfS ORIGINAL COM PLETION RNtKA K CDRRECTIONS A TD'KK GL V CORREC1l0NS JJffLP GL V C/O DA.TE ;."'¡~¡I f , .. ... r: J!I!II£. COMv1ENTS ) SAFETY NOTES: CHROME TBG & LNR 2099' 1-17" CA M BAL-O SSSV NIP, 10 = 5.937" 1 3284' 1--17" X 5-1/2" XO I GAS LIFT MANDRELS MO TVO OEV TY PE VL V LA TD-i 3409 3314 34 MERLA OMY RA 5477 4757 48 OTIS LB-1 OMY RA 6600 5501 48 MERLA OMY RA 7352 5993 48 MERLA OMY RA 8144 6503 49 OTIS LB-1 OMY RA 8946 7013 48 OTIS LB-1 OMY RA 9665 7510 49 OTIS LB-1 OMY RA 10307 8014 51 OTIS LB-1 OMY RA 10643 8273 51 OTIS LB-1 OMY RA 10933 8497 51 OTIS LB-1 EQUAL RA 11193' 1-15-1/2" OTIS XN NP, 10 = 4.455" 1 11213' 1- 9-5/8" X 5-1/2" BAKER SB-3A HYOROSEr A<R, 10 = 4.875" 11228' 1-15-1/2" X 4-1/2" MLLOUTEXT I 11261' 1--14-1/2" OTIS X NIP, 10 = 3.813" 1 11279' 1--14-1/2" OTIS XN NP, 10 = 3.725" 1 11291' 1-14-1/2" WLEG I 11278' 1-1 ELMO TT LOGGBJ 03/19/97 PORr DATE 07/07/03 o 01/22/93 07/07/03 07/07/03 01/22/93 10/02/93 01/22/93 01/22/93 01/22/93 01/22/93 o o o o o o FRUæOE SAY UNIT W8..L: 09-51 PE~ITNo: 1921410 A PI No: 50-029-22320-00 SEC 1, T10N, R15E. 4964.67' FEL & 2935.38' FI\l. BP Exploration (Alas k a) ) ) bp o BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 24, 2005 Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for conversion to injection service: DS 9-51 Dear Mr Aubert: Enclosed is an Application for Sundry Approval to convert DS producer 9-51 to injection service. The following supporting documentation is included for your review: · Application for Sundry Approval · Map showing wells within % mile radius · Cement bond log (SCMT) · Well bore schematic · Conversion procedure Please do not hesitate to call if you require additional information. S'1cerely, ~J Victoria I meh East Waterflood Production Engineer 564-5233 I to water no a PRUDHOE BAY, RUDHOE OIL 09-51 90 011 Rate (CD) (M bblld ) -- Water Rate (CD) (M bbl/d ) Gas Rate (CD) (MMcl/d) PPT,PRESS Cum OilPrQd(MMbbl) _ Gas I Oil Ratio (Mel/bbl) Water ut 50 10 0,05 (\,02 É 6000 5000 PRÐŒOL ~ 01 Case NaTe ' Case1 b ,Q o cj tí te 81d Ráe Fae::æt Date 1000 09-51 2) ~ ~ 00 00 W . æ ~ ~ œ œ ~ œ œ œ œ ;g .0 ""_ &x) Ô £ !!< '" a:: a 100 50 ) ) MECHANICAL INTEGRITY REPORT' , ?- I G R E ~ ~ ;.. S ~ : OPER & FIELD -ß P - P~tA.. ~LL NUMBER oq-S\ /92-141 = ? U D D .~. ;:::: : ~rl ~ LL D AT A TD : I ( 0/ q 0 . till.. 92 q c¡ TVD; ? B TD: I! q I 0 MD 7 2 "5 9 TVD Cë.si~g: 9~ Ç/3" Shoe: 11411 HI) ~-8(p() TVD¡ DV: MD ·TVD II :-:':ìe~: 7 Shoe: IlqqD ill) /I '/ \\'t4Þ'/~1I ~\.joi:;g: 7 1..'5'" l Packe:= IlïQ/, HI) : - . ") I ,.1 " f) '/- I .-.01 e S:...z e ¡ (.,. - 1 anå Q. 2 9 l q 9 !VD i :CF: 1/2 ~ ~ HD ~7 zto Set ê.t: /12/~ ;:"'TD T"VO í Perfs II ")q4 to 1I{¿;,{P4 :-S CF..ANI C;'..L INTEGRITY - ? .tŒ.T ¡ 1 Annulus Press Test: :P 15 û1lTI 3 0 min COIITI:rrents: MIT y eb~~ d· ~ :ŒCHJÜqICÞ-L INTEGRITY - PART /2 Cement: Volumes:' .A.ll1t. Liner If'~~ t",,~ ; Csg qt?O ~·tL ; DV C¡:¡jt: 701 to cove:!:" per::s ¡Ç1 ('..{¿ t ÇDÙ' (? ~O'P./', el.te~<;. Iheo:!:"e cical TOe 10 &CC f- I tAl I SO%? rÞ{..uc,,<;. Cement Bond Log (Yes or No) '~ ; In AOGCC File ../ CEL E:valuation, ::one ë.oove perfs µ'" I:> 1 QI./, ~ q. ç I ~" cell' vJf,'[ l b.ß V\J¿ 1;uAA.;~)' Sf) Ii -,1 eU\ ~ {i lA.-{' \A--f J t JO Production Log: Type : Evaluation CONÇLUSIONS: ? art t 1: J1f.-r' '('It;' ~ ,,{ j.. - . ? ar:: ;Z: vJt[!lw~ t.t~LLP' ÇU v\!Ó\ (po (i -/11 J .,,~ vJ,¡J J. þ~ úL, I\. ~v; '1"- d) ("þ cI ~ CM., ,-"""",t N.t 4 ~ d rß.- & Â'.? r¿ ¡)µ.i I . - ,..):1. d- . I , I ~ A I ^ 1)' I) "r ~- "'I./v-...\.o"'-. ~"'~'\..,.\...t , '-..'\.'" , r' t ¡~. '! .., , . \ /. I 6 /~'1A../!)I.{A sr- I ./~ ;/ ;. l''' ) ',) ,,'j/,",'" V'1 . '.''''''''- \ ¡ v I \,. .,-' ¡' ,..' ',.' -. ',,"' , oN oR BEFORE CF MBF R 000 C :LOP. lkl~ IL-~vI'DOC GeoQuest 500 w. International Airport Road Anchorage, AK99518-11~J-9~ ATTN: Sherrie , cCEIVED NO. 9264 Company: 2/22/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 ~J~J~ 0ii & [~a~ G011$, ~;0~l~JS~ Field: Prudhoe Bay Alll;horag.~ Floppy Well Job # LOg Description Date BL RF Sepia Mylar Disk ~ 7q- 75' ,7G.70 D.S. i-25 PATCH SE'l-riNG RECORD 020495 I 1 D.S. 1-22A DUAL BURSTTDT-P 020395 I 1 D.S. 11-11 PERF RECORD 020395 I 1 D.S. 9-38 INJEC PROFILE 020495 1 1 D.S. 9-45 DUAL BURST TDT-P 020595 I 1 D.S. 9-45 RST 020495 I 1 D.S. 9-51 I PROD PROFILE 020595 I I ,, , D.S. 16-4A RST 020295 I 1 D.S. 18-14 TUBING CUT'I'ER RECORD 020595 1 1 D.S. 5-26 PROD PROFILE 020695 I 1 D.S. 5-28 PROD PROFILE 020695 I 1 ,, D.S. 6-10 DUAL BURSTTDT-P 020795 I 1 D.S. 9-8 PERF RECORD 020695 I 1 .... D.S. 11-16 ~. PERF RECORD 0203951 I 1 D.S. 14-34 PERF RECORD 020795 I I SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. PERMIT DATA AOGCC Individual. Well Geological Materials Inventory T DATA_PLUS 92-141 5514 92-141 SURVEY 92-141 SURVEY 92-141 DWOP 92-141 407 92-141 T 11190-12011 DLL/SDN/CNTH R 0-11327 MWD E TELECO R 0-11327 MWD E TELECO R 12/30-01/23/93 R COMP DATE:02/08/93 PROD/SPIN/TEMP/P L 0-11820 92-141 PROD 92-141 PERF 92-141 PERF 92-!41 LD/NEUTRON 92-141 LD/NEUTRON 92-141 GR/CL 92-141 DLL/MSFL/GR L 11330-11700 L 11150-11750 L 10850-11872 L 11406-11948 RAW DATA L 11406-11948 POROSITY L 11330-11700 L 11406-11865 Page' 1 Date' 01/09/95 RUN DATE_RECVD 1 02/01/93 08/31/93 03/17/93 03/17/93 03/17/93 1 01/14/94 1 03/26/93 1 04/19/93 1 04/19/93 1 03/09/93 1 03/09/93 1 03/26/93 1 03/09/93 yes ~And received? Are dry ditch samples required? Was the well cored? yes ~no~ Analysis & description received? Are well tests require~.~/~,,,~_~ yes ~Received? yes ~ Well is in complianc~~-'- Initial COMMENTS yes ~ ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360, ,chorage, AK Transmittal #: 94021 99510.~ ~, Subject: From/Location: BHP Report John Degrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date~ Tool Type Run, Scalej Contractor Nurr~er (M-D-Y) 1-9 12-17-92 t BHP - Camco 1-14 8-11-92t BHP - 1 Camco 1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP - Camco 2-13 2-12-93 BHP Camco 2-35 5-21-92 BHP Camco 3-15A 3-20-93 BH P Camco 3-20 12-18-92 BHP Camco 4-7ST 5-17-92, 1 BHP Camco 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BH P - Camco 4-42 4-27-92 BHP I ' Camco 5-9 2-21-93 BHP - Camco 5-16 2-21-93 BHP i Camco 5-25 2-21-93 BHP Camco 5-31 2-21-93 BHP Camco 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 1 2-15-93 BHP - Camco 9-40 1-25-93 BHP - Camco 9-51 3-20-93 BHP Camco 12-7A 12-6-92 BHP Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BHP - Camco 13-20 7-4-92 BHP - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BHP - Camco 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP Camco 16-21 10-19-92 BHP - Can'K~ 16-30 9-28-92 BHP - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP - Camco 17-21 12-21-92 BHP t ' 1Carnc° 18-15 t 6-14-92 BHP - Camco ARCO ~ inc. Is · Subsh~ar~ of Allanllc~ch~l~,omgeny RECEIVED FE~ I {, 1994 Alaska Oil ~ ~as Cons. ~nchorage C°rr~i$$lon ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ?-~ -.~-~.1 - 11 12-18-93 q-~" 2-cl__l - 18 12-12-93 ~~-22 12-03-93 ~ 7_~_-7-0 ~__1-25 12-17-93 ~T.~-6 12-05-93 ~-- ~Lt 2-22 10-22-93 · ~ 3-4 12-20-93 ~~-36 12-11-93 4 t)~-t/7~ 4-1 12-06-93 -1 lA 12-13-93 e~- 1~,? _4-23A 12-14-93 ** ~-Tu 4-31 12-11-93 _ 'P~- ;%:, 4-41 12-14-93 "?t-'.~i,~ 5-28 12-10-93 '~ ?-_-7.'-~ __6-2 12-20-93 [~'~7 ~-"-'~ 6-16 12-15-93 ;'~. ~c...-9-1 12-5-93 ~- .-~. --'~9-1 12-9-93 -,~ !-- z .... 9-20 12-19-93 ~:ZL2c~ .... 9-29 12-13-93 ~-36A 12-17-93 X9-36A 12-17-93 ~?2-Ttq't 9-51 12-07-93 ~?~?__~_. 11-12 12-06-93 C~ ~_<LL¢_I 1-13A 12-14-93 4-1 12-5-93 5-9A 12-9-93 ~-~Zo 16-17 12-4-93 q~ -4~ 16-23 12-10-93 qZ ~-~--. 16-29A 12-18-93 ~7~..~.~~18-29 A 10-19-93 1-3-94 ARCO CASED HOLE FINAL~ CNL (£tl) lc2.-z.c--ic~O Run Leak Detect )~.?(',',,/Tenp/~re~r' Rrm Perf Record q?~O-lO5~o Run Prod Profile1_,'< ~(n. i%~'a*10!~hcs'6, l a~Rtm Perf Record ~0~,'5% -I/qu, c Run TDTP (depth corrected) Run InJ Prome i~;n }7¢~p?e% Run Perf Record I Zc~o - (ZZ~i O Run Perf Record ~l~e -fi$~C Rrm Perf Record 3 ~0 c o - ~[¼OO Rrm Dual Burst TDT-P (¢~. Run Prod Profile ~!?.,' ' ~C v"c :'2!~:';'<. RLtn Perf Record :-; 7'; :. -'-'~:~ ;; E' Run Dual Burst TDT-P .,ti;-~ : Run Production !;~ ' -. ', ,: :'~'.;-".. ~::;..; %Run Prod Profile ,'~.:~ Leak Dete ct.' ? ~i:~.',',',,,.> :U, ..~c/:.:-,-!~: ':-'-Run Leak Detect;';:' :'~ MI Inj Proflle:'~"-.'" ."q '" ?: C:' .: -: ~ ,:. ,- Run Leak Detect[?;. , ,;-'" :?~ .-,~c ;,,.,,..; >C Rim Dual Burst TDT-P~GR ,. ~.Run Prod Profile ~V,~ Prod Profile/Se,n TBG Cutt.e.r ~_,~o ~-q--/~t/ Run GR/CCL (~ q~c0 "-q ~r~0 Leak Detection Leak Detection I faS/'r~.mt~ b'cc.o Run Perf Record I ~'~0o-iLZtZ_ Rrm TDTP (depth corrected) Run , 5" 1, 5" ¥:70o - qzcc 1,5" 1.5" citgo .-teo'zo 15" 1, 5" I tOOo ~tX%Ho 1,5" 1,5" 1,5" 1,5" 1, 5" ;~::'-':'- -:6': "; ~ 1, 5" c'i,.CL' .--~,', ~.: ~_ 1, 1, ' .... :~ 1, 1, 1, 5' Seh 1, 5" *1050--q~. q.~ Seh 1, l'&5'' O~ i[~ Sch 1, 5" I~50~ ~ ~ Seh 1, 5" cl~%O- I0~M Seh 1, 5" Seh 1, 5" Seh 1,~&5"~ itc'he sch 1, 5" Seh 1,5" Please sign and return t~e atta~he~ cppy ~,~ x, ceipt of ~. EeEIVE Jo~ E. DeGrey ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF _ALASKA APPROVED Trans# 94002. Sch Sch Sch Sch Sch Sch Sch Sch $ch Sch Sch Sch Sch Sch Sch Sch 2"&5"(-..' ?'"-- "c --- I,:Sch l"&5". '-:'. _- - ' ~z'.--~'Sch 5"':i','" --';-~ '~. ' Sch 5" ?z.,.';~'. ' - · ' ~-i :':,' c;. Sch The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct well name is 18-29A and the corrected API# is 50-029-22316-01 STATE OF ALASKA ALASKA~'-''' AND GAS CONSERVATION C( vllSSION t..,/'.,-. RE'PORT',JI5 SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X ~'~' I I Pull tubing Alter casing Repair well Other '~'~,~-, I 5. Type o__f W. ell _ . 6. Datum of elevation(DF or KB) '~. 2. Name of Operator ARCO Alaska, Inc. 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1023' NSL, 5136' WEL, Sec. 1, T10N, R15E, UM At top of productive interval 2612' NSL, 194' WEL, Sec. 12, T10N, R15E, UM At effective depth At total depth 2350' NSL, 86' EWL, Sec. 7, T10N, R16E, UM Service Prudhoe Bay Unit 8. Well number 9-51 9. Permit number/approval number 92-141 10. APl number 50 - 029-22320 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11990 feet Plugs(measured) true vertical 9303 feet Effective depth: measured 11910 feet true vertical 9242 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78' 20" 27 cuft AS 110' 110' Surface 3887' 13-3/8" 2936 cu ft CS 11/466 cu ft CL 'G' 3919' 3919' Production 11383' 9-5/8" 1104 cu ft CL 'G'/507 cu ft CL 'G' 11411' 8859' Liner 755' 7" 217 cu ft CI 'G' 11235-11990' 8725-9300' Perforation depth: measured 11394-11414';11538-11558';11620-11626';11654-11664' true vertical 8846-8861 ';8956-8971 ';9018-9023';9044-9052' Tubing (size, grade, and measured depth) 7",26#,13CR-80 @ 3284' MD;7" x 5-1/2" xover @ 3277'MD;5-1/2",17#,13CR-80 @ 11203' MD;4-1/2",12.6#,13CR-80 w/tail @ 11291' MD Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker SB-3A Hydroset pkr @ 11213' MD,7" Camco BaI-O SSSV @ 2099' MD 13. Stimulation or cement squeeze summary l\ L ~ [~ ~ '~ [~. ~ Intervals treated(measured) ,~ ~ P - .~ 'Jg~)~ Treatment description including volumes used and final pressure Alaska 0ii & Gas Co~ls. Corrlrnissiol'~ 14. Representative Daily Averaqe Production or Injection Data AJ~u, ayu Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 0 0 0 2242 3621 2326 Casing Pressure Tubing Pressure 0 311 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 ,,.] _ (~qL_¢..~ ,...~ Title FS-2 Senior Engineer Form 10-404 Rev 06/15/88 ' Date SUBMIT IN DUPLICATE · ILy REPORT OF WELL OPER. IONS DS 9-51 Perforating Operations: ARCO Alaska, Inc. perforated DS 9-51 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 2/6/93 and 2/8/93. The intervals perforated were the following: 11394' - 11414', 11538' - 11558', 11620' - 11626' and 11654' - 11664' MD (Reference Log: SWS-DLL/MSFL dated 1/18/93). Completion 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 2/6/93. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, okay. RIH and perforated 11538'-11558' MD at 4 SPF, POOH, and confirmed all shots fired. Attempted to RIH, could not get down (surface equipment freezing problems), POOH. (ref: SWS-DLL/MSFL of 1/18/93). Rigged down and secured well. Continued perforating operations on 2/8/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 11654'-11664' MD at 4 SPF, Logged up and perforated 11620'-11626' MD~ POOH, and confirmed all shots fired. RIH and perforated 11389'-11412' MD at 4 SPF, POOH, and confirmed all shots fired. (ref: SWS-DLL/MSFL of 1/18/93). Rigged down and secured well. RECEIVED alaska Oil & Gas Cons. r3ornrnission Anchorage RDC: 9~3/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/03 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MIND Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Please sign and return the attached copy as RECEIVED BY_~~ Have A Nice Day! Sonya Wallace ATO-1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL Job#AKEI30010 Sperry Job#1209 BHI Ana Aha Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job# 1192 Teleco Job#AKFA30012 Sperry Job#1202 BHI Aha Ana Ana Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Teleco Job#AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job# 1168 Teleco Job#1172 Teleco Teleco Job//1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job//1195-450 Teleco Job#1205 BHI APPROVED Trans# 93059 receipt of data. # PB WELL FILES # BPX # ST. OF AK. (2 COPIES) # LUCILLE JOHNSTON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-19 2-7-93 ~~~'1-24A 2-20-93 ~'--zr~~l'30 1--24--93 ~l~ "' 2-14 7-27-91 .~-- 3-9 12-19-92 ~ ~.~[L~-~3.3-24 1-25-93 ' 3-32 3-32 4-25-92 4-25-92 q.~_i~-32 2-10-93 -.~--~'~3-34A 2-19-93 · 4-35 8-16-92 8-18-92 3-2-93 3-1-92 X9-27 3-1-92 1 2-8-93 1-1 4-21-92 1-13A 3 -8 -93 1-18 4-14-9~- 1-18 4-14-92 ---12-4A 2-11-93 ~\q%~12-19 2-11-93 ~L~ 12-29 12-22-92 ~12-32 12-26-92 /14-5A 2-20-93 -~14-12 4-24-92 ~ ~ I~.~~N~4-12 4-24-02 _ 4-37 4-13-92 4-37 4-13-92 6-21 7-23-02 6-21 7-23-92 _-~-~.-~--~16-27 8-23-92 ~16-30 2-12-93 RECEIVED 'A/aska Oil &~,,~_~_(h$ Cons. Pe~ Record n~~, H~ Pe~ Record R~ 1, ~' Pe~ Record R~ 1. ~' Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ T~ R~ 1. ~' Pe~ Record R~ 1, ~' Pe~ Record R~ 1, ~' H~ PGST Computed Resets R~ 1, ~' PSGT R~ 1, ~' Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ T~ R~ 1, ~' DSN R~ 1, ~' T~ Boron ~Jection R~ 1, ~' H~ Peri Record R~ 1, ~' Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ ~GT 5 ~/M~ R~ 1, ~' H~ ~ 10 ~/~ R~ 1. ~' H~ Pe~ Record R~ 1. ~' Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1. ~' Pe~ Record R~ 1. ~' H~ PSGT Com~uted Rea~s P.~ 1. ~' HL~ PSGT R~ 1. ~' Pe~ Record R~ 1, ~' Pe~ Reco~ R~ 1, ~' H~ Pe~ Record R~ 1. ~' Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' PSGT Computed Resets R~ 1. ~' H~ PSGT R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' PSGT R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' PSGT R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ l. ~' H~ R~ 1, ~' H~ i~.~ 7-21 12-20-92 Perf Record Please sign and return tahe attached co, py as receipt of data. RECEIVED BY ~_~__~__~ . , APPROVED So~ya Wallace ATO-1529 Trans# 930 CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON PHILLIPS MOBIL BPX STATE OF ALASKA * The correct apl# for 3-32 is 50-029-21141-00. ARCO ,~l-ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ~I ~_~1-~ 2-9-93 Prod Profile Run 1, 2-21-93 Prod Profile l~_m 1, ~~ ~3-20 1-22-93 Leak Detect Run 1, :~'Sd~' ~~~/3-20 2-22-93 Leak Detect/Noise/Temp Run 1, :~'&l~' 2-23-93 Prod Profile Run 1, 1-24-93 Alpha Patch CCI, l~_m 1, 2-21-93 GR/Collar Run 1, 2-21-93 InJ Profile ' l~m 1, [~' 1-25-93 Static Temp Run 1, 2-20-93 GR/Collar Run 1, 2-20-93 Prod Profile Run 1, 4ST 2-11-93 Prod Profile Run 1, ~~'~/~,~-22A 2-19-93 Prod Profile Run 1,~' PI e sign and return the attached copy as receipt of data. .,C l Have A Nice Day! APPROVED SOAT~-Y-1529 Trans# 9304i'-~ '-- Camco Camco Camco Camco C~__mco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO The correct weU name for this log is l-lB. RECEIVED MAR 2 6 ]99~ Alaska 011 & Gas Cons. Commission Anchorage check off or list data as it is received.*list received date for 407. if not required list as NR dolt i* ~)l'TlC/~' drillin~ hi'sto~ V~ surve¥!'~! well tests ~ I core descripti°~J~L ,cored intervals , core anaiys, is ~ d~ ditch intervals digital data LOG TYPE RUN INTERVALS SCALE NO. (to the nearest footJ [inchl100'J STATE OF ALASKA WELL COMPLETION OR REOOMP LETIO REPORT 1. Status of Well Classification of Service Well OIL [] GAS [] StJSPEt,[)ED [] ABAN[:X:)NED [] SERVICE [] 12. Name ol Operator 7. Permit Number ARCO Alaska,/nc. 92-141 3. Address !~. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22320 4. Location of well at surface i9. Unit or Lease Name 1023' NSL, 5136' WEL, SEC. 01, TION, R15~-:"_,;;;ii~i:~i'.~i~;:.i"~! ~' Prudhoe Bay Unit ~ ~.~-~-. ; [,O(-A]tON$ i 10. Well Number ~ V~:~ ,-~-~ i 1 1 Fiald and Pool At Total Depth - ~-.. ; ; Prudhoe Bay Field/Prudhoe Bay Pool 2350'NSL, 80" EWL, SEC. 07, TION, R16E ~ ~ .................. ; 5. Elevation in feet (indicate KB, DF, etc.} 16. Lease Designation and Serial No. KBE -- 54. 7' I ADL 28345 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/29/92 1/17/93 2/8/93I N/A leet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11990'MD/9303' 11910'MD/9242' TVD YES [] NC) []! 2099'feet MD ! 1900'(Approx.) 22. Type Electric or Other Lo-3s Run GR/CNL/LD T/DLL/MSFL 123. CASING, LINER AND CEMENTING ~ SE'CFI,,IG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'croM HOLE SIZE CEMENTI,,IG RECORD AMOLI, CT PULLED 20" 91.5~ H-40 32' 110' 30" 27 cuft Arcticset 13.3/8" 68# L-80 32' 3919' 16" 2936 cu ft CS !1/466 cu ft Class "G" 9-5/8" 47# L-80 28' 11411' 12-1/4" 1104 cu ft "G"/507 cu ft "G" 7" 29# 13CR80 11265' 11990' 8-1/2" 217 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBI',IG RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MDI Gun DiameterMD3-3/8" ~/s~f 7"x5-1/2" 11291' 11213' 11394'-11414' 8791'-8806' w/4-1/2" tail 11538'- 11558' 8899'8914' ~ 26. ACID, FRACTURE, CEMENT SQUFFTE~ ETC. 11620'-11626' 8961'-8966' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11654'- 11664' · 8987-8994' Freeze protected 13-3/8" x 9-5/8" with 150 BBL dry crude 127. PRODUCTION TEST =Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/8/93 I Fiowing Dale of Test Hours TeSted PRODI. JCTIONFOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~' I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RF E V[D MAR 7 t995 Alask~ OJJ & Gas Oons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ~OGIC MARKER~ ..)RMATION 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 11394' 8791' Zone 3 11420' 8811' Zone 2 11459' 8841' Base Sadlerochit 11791' 9125' 31. [JST OF ATTACHMENTS 32. ~ hereby ced~y that the foregoing is true and correct to the best of my hnow~edge Signed ~'~ TitleDrillin¢EngineerSuoervisor Date'~' / ~''~''' ?~ INSTRUCTIONS General: This form is designed for .submitting. a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 ~ If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 / ,. BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-51 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/29/92 10:00 SPUD: 12/30/92 10:00 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 12/30/92 ( 1) TD: 110'( 0) 12/31/92 (2) TD: 1450'(1340) 01/01/93 (3) TD: 2800' (1350) 01/02/93 ( 4) TD: 3975' (1175) MIX SPUD MUD. MW: 8.5 VIS: 0 MOVE RIG F/ DS 9-49 TO DS 9-51. RIG ACCEPTED @ 22:00 HRS, 12/29/92. N/U DIVERTER. MIX SPUD MUD. M/U BHA. DRLG. MW: 9.2 VIS:325 MIX SPUD MUD. SPUD WELL @ 10:00 HRS, 12/30/92. DRLG F/ 110'-900' SHORT TRIP TO 110' DRLG F/ 900'-1450' DRILLING SURF HOLE MW: 9.1 VIS:ll5 DRILL TO 1800. POH, PU DYDADRIL MTR & ORIENT W/TELECO MWD, SURF CHECK. RIH W/BHA %2. DRILL TO 2800. SHORT TRIP TRIPPING. DRILL TO 3975. MW: 9.8 VIS: 85 01/03/93 ( 5) TD: 3975' ( 0) 01/04/93 ( 6) TD: 3975' ( 0) 01/05/93 (7) TD: 5820' (1845) 01/06/93 (8) TD: 6860' (1040) 01/07/93 (9) TD: 7618' ( 758) PERF TOP JOB MW: 9.7 VIS: 78 DRILL FOR REAMING. REAM TO 3975, COND HOLE. CBU, DROP SURV & PUMP DRY JOB. POH, RU CSG EQUIP. RIH W/13-3/8" CSG. CIRC. TEST LINE. UNABLE TO RECIP PIPE. PLUG DID NOT BUMP, FLOAT HELD. RD CMT CMT HEAD & CLEAR FLOOR. DRILL OUT FLOAT EQUIP MW: 8.6 VIS: 38 ND, PERF TOP JOB. INSTL EMERG SLIPS & CUT OFF CSG. ND RISER. WELD ON ADAPTER FLANGE & TEST. NU & TEST BOPE. SET WEAR RING. RIH W/BHA #3 & TAG FIRM CMT @ 3826. TEST CSG. DRILL OUT CMT~& FLOAT EQUIP. DRLG. MW: 9.3 VIS: 40 DRLG CMT, FS, 10' NEW HOLE TO 3985' CBU. FIT (13.6 PPG EMW). DRLG F/ 3985'-4918' SHORT TRIP TO 3915' DRLG F/ 4918'-5820' DRLG. DRLG TOI 5950'. SHORT TRIP TO 5910' -- POOH. CHANGE BHA. RIH. DRLG TO 6860' MW: 9.6 VIS: 39 DRLG TO 6517' DRLG. MW: 9.6 VIS: 39 DRLG TO 7460' SHORT TRIP TO 6380'. DRLG TO 7618' MTR FAILURE. POOH. CHANGE BIT. RIH. REAM 100' TO BTM. WORK PAST JUNK. Anchorage WELL : DS 9-51 OPERATION: RIG : NABORS 18E PAGE: 2 01/08/93 (10) TD: 8164' ( 546) 01/09/93 (11) TD: 8700'( 536) REPAIR ECR CHAIN MW: 9.7 VIS: 38 REAM & WORK BY JUNK. DRAG TO 814. DRO SURV, POH. REPAIR ECR CHAIN. DRLG W/BIT #6 PU MOTOR & BIT #6. DRAG W/BIT #6. MW: 9.7 VIS: 39 01/10/93 (12) TD: 9100' ( 400) 01/11/93 (13) TD:10014' ( 914) 01/12/93 (14) TD:10325' ( 311) 01/13/93 (15) TD:10707' ( 382) 01/14/93 (16) TD:ll125' ( 418) DRAG W/BIT #7 MW: 9.7 VIS: 38 REPLACE SWIVEL WASH PIPE. DRLG TO 8995. POH, CUT DRAG LINE. POH, LD JTS, TEST BOPE. PLUG LEAKED, CHT OUT & TEST. PU NEW JARS & BHA & RIH. REAM TO 8995. DRAG W/BIT #7. DRAG W/BIT #8 MW: 9.8 VIS: 41 DRAG TO 10014. DRY JOB & POH. CHG BIT & STAB BLADE & RIH. DRAG W/BIT #8. DRAG W/BIT #9 MW: 9.8 VIS: 42 DRAG TO 10111. REPLC KELLY BUSHING. DRAG TO 10156. DRY JOB & POH. PU NEW MTR & RIH W/BIT #9. SURV. RIH. DRLG TO 10325. RIH W/ND & BHA MW: 9.8 VIS: 41 DRLGW/BIT #9. POH, REAM TO 10250, POH. SERV WEAR RING. CHG BIT & BHA & RIH. DRAG 12 1/4" HOLE MW: 9.7 VIS: 39 FINISH RIH, BENCH MARK @ 6530. DRAG & SURV, SLIDING. 01/15/93 (17) TD:l1417' ( 292) 01/16/93 (18) TD:l1417' ( 0) 01/17/93 (19) TD:11675' ( 258) 01/18/93 (20) TD:l1990'( 315) 01/19/93 (21) TD:l1990' ( 0) RU TO RUN 9-5/8 CSG MW: 9.8 VIS: 46 DRAG TO 11189. CHG SWIVEL PKG, DRIL TO 11417. CIRC PUMP HI-LO SWEEP AROUND. SHORT TRIP, CIRC COND MUD. POH TO RUN 9-5/8 CSG. CHG TOP RAMS, LD BHA. CHANGE RAMS TO 5" MW: 9.8 VIS: 40 PULL WEAR RINg & CLEAN FLOOR. RU & RUN 9-5/8 CASG. CIRC COND HOLE, TEST LINES. MIX & PUMP CMT. LD LNDG JT. INSTALL PKOFF. CHG TOP RAMS. DRAG 8-1/2 HOLD MW: 8.9 VIS: 42 TEST BOPE. RU BHA, CHG BLADES. RIH, BREAK CIRC. TEST 9-5/8 CSG. DRAG FLOAT EQUIP & NEW HOLE TO 11427. CIRC & CHG MUD. DRLG TO 11675. RUNNING WL LOGS MW: 9.5 VIS: 43 DRAG TO 11990. CIRC BTTM UP FOR WL LOGS. DROP SURV, POH. RU & RIH W/LOGS. RIH W/7" LINER MW: 9.6 VIS: 57 POH W/LOGS & RD. RIH W/BHA, C IRC & COND MUD. POH. CHG TOP RAMS. RU CSG, PU 7" LINER & HGR & CIRC. RIH W/7" LINER. Gas Cor~s. Corril'nissio~ _P, cn~'~rage WELL : DS 9-51 OPERATION: RIG : NABORS 18E PAGE: 3 01/20/93 (22) TD:l1990 PB:ll910 01/21/93 (23) TD:l1990 PB:ll910 CHG OVER TO BRINE MW: 0.0 NaC1 CIRC PIPE VOL. WASH TO BTTM. CMT LINER & DISPL W/RIG PUMP. BUMP PLUG, CIP. POH, CHG TOP RAMS. PU BIT, BHA & RIH. CBU. TEST CSG. REV CIRC, DISPL MUD W/BRINE. RUN PROD TBG MW: 0.0 NaC1 POH LDDP, CUT & SLIP DRL LINE. CHG TOP RAMS. LD BHA, PULL WEAR RING. RU & RUN 5-1/2 PROD TBG. 01/22/93 (24) TD:l1990 PB:ll910 SET PKR & TEST TBG MW: 0.0 NaCl RUN 5-1/2 TBG. PU HGR & LAND. RD CSG TOOLS, CHG RAMS, DN BOPE. NU FLANGE & TREE & TEST. SET PKR, TEST TBG. 01/23/93 (25) TD:11990 PB:ll910 RELEASED RIG MW: 0.0 NaC1 DISP DIESEL IN ANN & U-TUBE TO TBG. SET PPV. PREPARE TO MOVE RIG. RELEASED 1-22-93 @ 12:00 HRS. SIGNATURE: (drilling superintendent) DATE: ,-~', ,... ' Anchorage TEi.EFIBTMFIN ECl3 Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 /G INAL EASTMAN TELECO MWD SURVEY DS 9-51 PRUDHOE BAY Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · MWD Survey Listing · Composite 100' MD Interpolated · Composite 100' TVD Interpolated Oil & Gas Cons. Anchorage MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation Date Dec 30-Jan 15, 92 Filename : 1167 Plane of Vertical Section : 126.6° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.00Oft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0' ' (T) Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 120 120 0.0 340.7 226 106 0.1 340.7 318 92 0.2 254.5 411 93 0.3 263.7 TVD ft 0 120 226 318 411 VS ft 0 0 0 -0 -1 LAT ft 0 0 0 0 0 Page 1 of 4 Date Dec 30-Jan Filename : 1167 15, 92 DEP D ' LEG BUILD TURN o ft °/100 °/100 /100 0 0.0 0.0 0.0 0 0.0 0.0 -16.1 -0 0.1 0.1 0.0 -0 0 . 2 0 . 1 -93 . 7 -1 0.1 0.1 9.9 503 92 0.6 219.0 597 94 0.4 203.2 689 92 0.3 148.0 781 92 0.1 137.8 874 93 0.2 152.9 5O3 597 689 781 874 -1 -1 -0 0 0 -0 -1 -2 -2 -2 -1 0.5 0.3 -2 0.3 -0.2 -2 0.4 -0.1 -1 0.2 -0.2 -1 0.1 0.1 -48.6 -16.8 -60.0 -11.1 16.2 965 91 0.3 196.2 1067 102 0.3 150.5 1150 83 0.2 152.6 1242 92 0.4 151.9 1336 94 0.2 144.1 965 1067 1150 1242 1336 -2 -3 -3 -4 -4 -1 0.2 0.1 -1 0.2 0.0 -1 0.1 -0.1 -1 0.2 0.2 -1 0.2 -0.2 47.6 -44.8 2.5 -0.8 -8.3 1430 94 0.4 173.3 1524 94 0.6 165.2 1617 93 1.2 207.1 1719 102 1.6 232.0 1826 107 1.3 238.0 1430 1524 1617 1719 1826 -4 -5 -7 -8 -10 -0 0.3 0.2 31.1 -0 0.2 0.2 -8.6 -1 0.9 0.6 45.1 -2 0.7 0.4 24.4 -4 0.3 -0 . 3 5.6 1920 94 1.6 132.5 2015 95 4.4 120.9 2108 93 5.6 107.9 2202 94 6.0 116.7 2294 92 7.4 123.4 1920 3 -11 -4 2.5 0.3 2015 8 -14 -0 3.0 2.9 2107 16 -17 7 1.8 1.3 2201 25 -21 16 1.0 0.4 2292 36 -27 25 1.7 1.5 -99.0 -12.2 -14.0 9.4 7.3 2388 94 9.6 122.3 2481 93 12.4 115.0 2574 93 15.1 117.1 2667 93 17.4 118.5 2759 92 19.8 118.8 2385 2477 2567 2656 2743 5O 67 89 115 144 -34 37 2.3 2.3 -1.2 -42 52 3.4 3.0 -7.8 -52 72 3.0 2.9 2.3 -.64 95 2.5 2.5 1.5 -78 121 2.6 2.6 0.3 2853 94 22.1 119.9 2948 95 24.8 120.2 3040 92 27.1 120.2 3134 94 29.3 119.9 3227 93 32.1 119.9 2831 177 -95 150 2.5 2.4 1.2 2918 215 -114 183 2.8 2.8 0.3 3001 255 -134 218 2.5 2.5 0.0 3084 299 -156 256 2.3 2.3 -0.3 3164 346 -180 297 3.0 3.0 0.0 3322 95 34.5 120.6 3415 93 35.7 119.9 3508 93 37.4 120.2 3601 93 40.0 121.6 3695 94 42.5 120.2 3243 398 -206 342 2.6 2.5 0.7 3319 451 -233 389 1.4 1.3 -0.8 3394 506 -261 437 1.8 1.8 0.3 3467 564 -291 486 2.9 2.8 1.5 3537 626 -323 540 2.8 2.7 -1.5 Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation Page 2 of 4 Date Dec 30-Jan Filename : 1167 15, 92 MD CkL INC DIR TVD ft ft deg deg ft 3789 94 44.6 120.2 3605 3895 106 46.2 120.2 3680 4007 112 45.5 121.6 3758 4100 93 45.4 123.4 3823 4194 94 46.3 125.2 3888 VS ft 690 765 845 911 978 LAT ft -355 -393 -434 -4'70 -508 DEP ft 596 661 730 786 841 D'LEG °/100 2.2 1.5 1.1 1.4 1.7 BUILD °/100 2.2 1.5 -0.6 -0.1 1.0 TURN °/loo 0.0 0.0 1.3 1.9 1.9 4289 95 47.0 125.9 3954 4381 92 46.7 125.2 4017 4473 92 47.4 125.2 4079 4568 95 47.5 125.9 4144 4661 93 46.8 125.9 4207 1047 1115 1182 1252 1320 -548 -587 -626 -667 -707 898 952 1007 1064 1119 0.9 0.6 0.8 0.6 0.8 0.7 -0.3 0.8 0.1 -0.8 0.7 -0.8 0.0 0.7 0.0 4755 94 47.7 125.2 4271 4848 93 47.4 125.9 4333 4940 92 47.8 125.9 4395 5034 94 47.9 125.9 4458 5128 94 47.2 125.9 4522 1389 1458 1526 1595 1665 -747 -787 -827 -867 -908 1176 1231 1286 1343 1399 1.1 0.6 0.4 0.1 0.7 1.0 -0.3 0.4 0.1 -0.7 -0.7 0.8 0.0 0.0 0.0 5222 94 48.2 125.5 4585 5316 94 48.0 125.5 4648. 5411 95 47.2 125.2 4712 5503 92 48.0 125.5 4774 5597 94 48.0 124.8 4837 1734 1804 1874 1942 2012 -949 -989 -1030 -1069 -1109 1456 1513 1570 1625 1682 1.1 0.2 0.9 0.9 0.6 1.1 -0.2 -0.8 0.9 0.0 -0.4 0.0 -0.3 0.3 -0.7 5690 93 47.6 124.8 4899 5784 94 46.8 125.2 4963 5880 96 48.9 125.5 5028 5974 94 47.8 125.5 5090 6069 95 49.3 126.9 5153 2081 2150 2221 2291 2362 -1149 -11~88 -1229 -1270 -1312 1739 1795 1853 1911 1968 0.4 0.9 2.2 1.2 1.9 -0.4 -0.9 2.2 -1.2 1.6 0.0 0.4 0.3 0.0 1.5 6164 95 49.7 128.0 5215 6259 95 49.2 127.6 5277 6353 94 48.3 128.0 5339 6447 94 48.8 126.9 5401 6542 95 49.5 124.8 5463 2435 2507 2577 2648 2720 -1356 -1400 -1444 -1487 -1529 2025 2082 2138 2194 2252 1.0 0.6 1.0 1.0 1.8 0.4 -0.5 -1.0 0.5 0.7 1.2 -0.4 0.4 -1.2 -2.2 6636 94 48.6 126.9 5524 6730 94 48.1 125.9 5587 6825 95 48.9 127.6 5650 6919 94 49.7 127.6 5711 7013 94 48.3 128.0 5773 2791 2861 2932 3003 3074 -1570 -1612 -1654 -1698 -1741 2310 2366 2423 2480 2536 1.9 1.0 1.6 0.9 1.5 -1.0 -0.5 0.8 0.9 -1.5 2.2 -1.1 1.8 0.0 0.4 7106 93 49.7 127.6 5834 7200 94 49.9 128.0 5895 7295 95 49.8 128.7 5956 7390 95 48.4 130.1 6018 7484 94 49.1 129.7 6080 3144 3216 3289 3360 3431 -1784 -1828 -1874 -1919 -1964 2591 2648 2705 2761 2815 1.5 0.4 0.6 1.8 0.8 1.5 0.2 -0.1 -1.5 0.7 -0.4 0.4 0.7 1.5 -0.4 Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation MD CkL INC DIR TVD ft ft deg deg ft 7577 93 49.0 126.2 6141 7671 94 49.7 126.9 6202 7765 94 50.1 127.6 6263 7858 93 50.3 128.7 6322 7953 95 50.8 129.0 6383 VS ft 3501 3573 3644 3716 3789 LAT ft -2008 -2050 -2094 -2138 -2184 Page 3 of 4 Date Dec 30-Jan 15, Filename : 1167 92 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 2870 2.8 -0.1 -3.8 2927 0.9 0.7 0.7 2985 0.7 0.4 0.7 3041 0.9 0.2 1.2 3098 0.6 0.5 0.3 8048 95 51.2 128.7 6442 8143 95 51.2 130.4 6502 8238 95 51.1 130.4 6562 8333 95 50.8 130.1 6621 8426 93 50.6 130.1 6680 3863 3937 4011 4084 4156 -2230 3156 0.5 0.4 -0.3 -2277 3213 1.4 0.0 1.8 -2325 3269 0.1 -0.1 0.0 -2373 3325 0.4 -0.3 -0.3 -2419 3380 0.2 -0.2 0.0 8519 93 50.5 130.8 6739 8615 96 50.3 129.4 6801 8708 93 50.0 129.0 6860 8802 94 50.4 126.9 6920 8894 92 49.9 127.3 6979 4228 4302 4373 4445 4516 -2466 3435 0.6 -0.1 0.8 -2513 3492 1.1 -0.2 -1.5 -2559 3547 0.5 -0.3 -0.4 -2603 3604 1.8 0.4 -2.2 -2646 3660 0.6 -0.5 0.4 8998 104 49.3 127.6 7047 9093 95 48.7 127.6 7109. 9186 93 47.7 126.6 7171 9282 96 46.7 126.2 7236 9376 94 45.6 126.2 7301 4595 4667 4736 4806 4874 -2694 3723 0.6 -0.6 0.3 -2737 3780 0.6 -0.6 0.0 -2779 3835 1.3 -1.1 -1.1 -2821 3892 1.1 -1.0 -0.4 -2861 3947 1.2 -1.2 0.0 9471 95 44.6 126.2 7368 9567 96 43.1 127.3 7438 9662 95 41.9 126.6 7508 9758 96 40.6 126.6 7580 9850 92 39.3 125.5 7650 4941 5008 5072 5135 5195 -2901 4001 1.1 -1.1 0.0 -2941 4054 1.8 -1.6 1.1 -2979 4105 1.4 -1.3 -0.7 -3017 4156 1.4 -1.4 0.0 -3052 4204 1.6 -1.4 -1.2 9944 94 38.1 126.2 7724 10041 97 35.9 126.6 7801 10132 91 34.4 128.3 7876 10227 95 39.1 130.4 7952 10321 94 38.6 131.1 8025 5253 5312 5364 5421 5480 -3086 4252 1.4 -1.3 0.7 -3121 4299 2.3 -2.3 0.4 -3153 4340 2.0 -1.6 1.9 -3189 4384 5.1 4.9 2.2 -3227 4429 0.7 -0.5 0.7 10415 94 39.3 131.1 8098 10510 95 40.2 131.1 8171 10606 96 40.1 130.4 8244 10700 94 38.3 130.8 8317 10795 95 39.3 131.5 8391 5539 5599 5661 5720 5779 -3266 4473 0.7 0.7 0.0 -3306 4519 0.9 0.9 0.0 -3346 4566 0.5 -0.1 -0.7 -33.85 4611 1.9 -1.9 0.4 -3424 4656 1.1 1.1 0.7 10888 93 40.4 131.5 8463 10979 91 40.6 132.5 8532 11073 94 40.8 132.9 8603 11165 92 40.9 133.6 8673 11259 94 40.5 132.9 8744 5839 5898 5959 6018 6079 -3464 4701 1.2 1.2 0.0 -3503 4744 0.7 0.2 1.1 -3545 4789 0.3 0.2 0.4 -3586 4833 0.5 0.1 0.8 -3628 4878 0.6 -0.4 -0.7 Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation MD ft 11327 CkL INC DIR TVD ft deg deg ft 68 40.3 134.0 8796 VS ft 6123 LAT ft -3658 Page 4 of 4 Date Dec 30-Jan 15, 92 Filename : 1167 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 4910 1.1 -0.3 1.6 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6123 ft 126.7° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Well Name Location Date Surveyed Survey Performed By : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope : Dec 30-Jan 15, 93 : : Craig E. Tomayer This survey is correct to the best of my knowledge and is supported by actual field data. ........ COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope Date Dec 30-Jan 15, 93 Filename : 1167 Interpolated 100 ft of MD Plane of Vertical Section : 126.6° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0' ' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 1 Date Dec Filename Interpolated of 3 30-Jan 15, 93 : 1167 100 ft of MD MD ft 0 100 200 3OO 400 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 38O0 3900 CkL INC DIR ft deg deg 0 0.0 0.0 100 0.0 283.9 100 0.1 340.7 100 0.2 271.4 100 0.3 262.6 100 0.6 220.5 100 0.4 201.4 100 0.3 146.8 100 0.1 140.9 100 0.2 165.3 100 0.3 180.5 100 0.3 151.3 100 0.3 152.2 100 0.3 147.1 100 0.3 164.0 100 0.5 167.3 100 1.1 199.4 100 1.5 227.4 100 1.4 236.5 100 1.5 154.9 100 4.0 122.7 100 5.5 109.0 100 6.0 116.5 100 7.5 123.3 100 10.0 121.4 100 13.0 115.4 100 15.7 117.5 100 18.3 118.6 100 20.8 119.3 100 23.4 120.0 100 26.1 120.2 100 28.5 120.0 100 31.3 119.9 100 33.9 120.4 100 35.5 120.0 100 37.3 120.2 100 40.0 121.6 100 42.6 120.2 100 44.8 120.2 100 46.2 120.3 TVD ft 0 100 200 3OO 400 VS ft 0 0 0 -0 -0 LAT ft 0 0 0 0 0 DEP D ' LEG ft °/100 0 0.0 0 0.0 -0 0.1 -0 0.2 -1 0.1 500 -1 -0 -1 0.4 600 -1 -1 -2 0.3 700 -0 -2 -2 0.3 800 0 -2 -1 0.2 900 0 -2 -1 0.1 1 -3 -1 0.1 1 -3 -1 0.1 1 -3 -1 0.0 2 -4 -1 0.0 2 -4 -0 0.1 3 -5 -0 0.2 3 -6 -1 0.7 3 -8 -2 0.8 3 -10 -4 0.3 3 -11 -4 1.9 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 8 -14 -1 2.8 2099 15 -17 7 1.9 2199 25 -21 16 0.9 2298 37 -'27 26 1.7 2397 52 -35 39 2.4 BU I LD TURN o /100 /100 0.0 0.0 0.0 -76.1 0.1 56.8 0.1 -69.3 0.1 -8.8 0.3 -42.2 -0.2 -19.1 -0.1 -54.6 -0.2 -5.9 0.1 24.4 0.1 15.2 -0.0 -29.2 0.0 0.9 -0.0 -5.1 0.1 16.9 0.2 3.3 0.5 32.2 0.4 27.9 -0.2 9.2 0.2 -81.6 2.4 -32.2 1.5 -13.7 0.5 7.5 1.5 6.8 2.4 -2.0 2495 72 -44 56 3.2 3.0 -5.9 2592 96 -56 79 2.8 2.8 2.1 2687 125 -69 105 2.5 2.5 1.1 2782 158 -86 134 2.6 2.5 0.7 2874 196 -104 166 2.6 2.6 0.8 2965 237 -125 203 2.7 3054 283 -148 242 2.4 3141 332 -173 285 2.8 3225 386 -200 332 2.7 3307 442 -229 381 1.6 501 563 629 698 768 3388 3466 3541 3613 3683 2.7 0.2 2.4 -0.2 2.8 -0.1 2.7 0.5 1.6 -0.4 -258 432 1.7 1.7 0.2 -290 486 2.9 2.7 1.4 -324 543 2.8 2.6 -1.4 -359 602 2.2 2.2 0.0 -395 664 1.4 1.4 0.1 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 2 of 3 Date Dec 30-Jan 15, Filename : 1167 93 Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 45O0 4600 4700 4800 4900 5OO0 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6OOO 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD ft deg deg ft 100 45.5 121.5 3753 100 45.4 123.4 3823 100 46.3 125.2 3893 100 47.0 125.8 3961 100 46.8 125.2 4030 100 47.4 125.4 4098 100 47.3 125.9 4165 100 47.2 125.6 4233 100 47.6 125.5 4301 100 47.6 125.9 4368 100 47.9 125.9 4436 100 47.4 125.9 4503 100 48.0 125.6 4570 100 48.0 125.5 4637 100 47.3 125.2 4705 100 48.0 125.5 4772 100 48.0 124.8 4839. 100 47.5 124.8 4906 100 47.2 125.3 4974 100 48.7 125.5 5041 100 48.2 125.9 5107 100 49.4 127.3 5173 100 49.5 127.8 5238 100 48.8 127.8 5304 100 48.5 127.4 5370 100 49.2 125.7 5435 100 48.9 126.1 5501 100 48.3 126.2 5567 100 48.7 127.2 5633 100 49.5 127.6 5699 100 48.5 127.9 5764 100 49.6 127.6 5830 100 49.9 128.0 5895 100 49.7 128.8 5959 100 48.5 130.1 6025 100 49.1 129.1 6090 100 49.2 126.4 6156 100 49.8 127.1 6221 100 50.2 128.0 6285 100 50.5 128.8 6349 VS ft 84O 911 983 1055 1128 1202 1275 1349 1422 1496 1570 1644 1718 1792 1866 1940 2014 2088 2162 2236 2311 2386 2462 2538 2613 2688 2763 2838 2913 2989 3064 3140 3216 3292 3368 3443 3519 3595 3671 3748 LAT ft -432 -470 -511 -553 -595 -638 -680 -723 -766 -809 -853 -896 -939 -982 -1025 -1068 -11'11 -1153 -1195 -1238 -1282 -1327 -1373 -1419 -1465 -1510 -1554 -1599 -1643 -1689 -1735 -1782 -1828 -1876 -1924 -1972 -2018 -2064 -2110 -2158 DEP D'LEG BUILD TURN o o o ft /100 /100 /100 726 1.1 -0.6 1.2 786 1.4 -0.1 1.9 845 1.6 0.9 1.8 904 0.7 0.6 0.6 964 0.5 -0.1 -0.6 1023 0.6 0.6 0.2 '1083 0.4 -0.2 0.5 1143 0.2 -0.1 -0.3 1203 0.4 0.4 -0.1 1263 0.3 0.1 0.4 1322 0.2 0.2 0.0 1382 0.5 -0.5 0.0 1442 0.6 0.6 -0.3 1503 0.1 0.1 -0.1 1563 0.8 -0.7 -0.3 1623 0.7 0.7 0.3 1684 0.5 0.0 -0.7 1745 0.5 -0.5 0.0 1805 0.5 -0.4 0.4 1866 1.5 1.5 0.2 1926 0.5 -0.5 0.4 1987 1.6 1.2 1.4 2047 0.5 0.1 0.6 2107 0.7 -0.7 -0.1 2166 0.4 -0.3 -0.3 2227 1.4 0.6 -1.7 2288 0.4 -0.2 0.4 2348 0.7 -0.7 0.1 2408 0.8 0.4 0.9 2469 0.9 0.8 0.4 2528 1.1 -1.0 0.3 2588 1.1 1.1 -0.3 2648 0.4 0.3 0.4 2708 0.6 -0.2 0.8 2766 1.6 -1.3 1.3 2824 0.9 0.6 -1.0 2884 2.1 0.1 -2.7 2945 0.9 0.7 0.7 3006 0.8 0.4 0.9 3066 0.7 0.3 0.8 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 3 of 3 Date Dec 30-Jan Filename · 1167 Interpolated 100 15, 93 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 51.0 128.9 6412 8100 100 51.2 129.6 6475 8200 100 51.1 130.4 6538 8300 100 50.9 130.2 6601 8400 100 50.7 130.1 6664 8500 100 50.5 130.7 6727 8600 100 50.3 129.6 6791 8700 100 50.0 129.0 6855 8800 100 50.4 126.9 6919 8900 100 49.9 127.3 6983 9000 100 49.3 127.6 7048 9100 100 48.6 127.5 7114 9200 100 47.6 126.5 7181 9300 100 46.5 126.2 7249 9400 100 45.3 126.2 7318 9500 100 44.1 126.5 7389 9600 100 42.7 127.1 7462 9700 100 41.4 126.6 7536 9800 100 40.0 126.1 7612 9900 100 38.7 125.9 7689 10000 100 36.8 126.4 7768 10100 100 34.9 127.7 7849 10200 100 37.8 129.8 7930 10300 100 38.7 130.9 8009 10400 100 39.2 131.1 8086 10500 100 40.1 131.1 8163 10600 100 40.1 130.4 8240 10700 100 38.3 130.8 8317 10800 100 39.4 131.5 8395 10900 100 40.4 131.6 8472 11000 100 40.6 132.6 8548 11100 100 40.8 133.1 8624 11200 100 40.8 133.3 8699 11300 100 40.4 133.6 8775 11327 27 40.3 134.0 8796 ! r q,c, C-; Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6123 ft 126.7 ° VS ft 3826 3903 3981 4059 4136 4213 4290 4367 4444 4520 4596 4672 4746 4819 4891 4962 5030 5097 5162 5226 5287 5346 5405 5466 5529 5593 5657 5720 5783 5847 5911 5976 6041 6106 6123 LAT ft -2207 -2256 -2306 -2356 -2406 -2456 -2506 -2555 -2602 -2648 -2695 -2741 -2785 -2829 -2871 -2913 -2954 -2994 -3033 -3070 -3106 -3141 -3178 -3219 -3260 -3302 -3344 -3385 -34'26 -3469 -3513 -3557 -3602 -3646 ~-3658 .. DEP D ' LEG BUILD ft °/100 °/100 3126 0.5 0.5 3187 0.6 0.2 3246 0.6 -0.1 3306 0.3 -0.2 3365 0.3 -0.2 TU~ °/100 0.0 0.8 0.8 -0.2 -0.1 3724 0.6 -0.6 0.3 3784 0.7 -0.7 -0.1 3843 1.3 -1.1 -1.0 3902 1.1 -1.1 -0.3 3960 1.1 -1.1 0.0 4017 1.2 -1.2 0.3 4072 1.5 -1.5 0.5 4126 1.3 -1.3 -0.5 4178 1.4 -1.4 -0.5 4229 1.4 -1.3 -0.2 4279 1.9 -1.8 0.6 4326 2.0 -1.9 1.3 4372 3.1 2.8 2.1 4419 1.2 0.9 1.1 4466 0.5 0.5 0.2 4514 0.9 0.9 0.0 4563 0.4 0.0 -0.7 4611 1.8 -1.8 0.4 4658 1.1 1.1 0.7 4706 1.1 1.1 0.1 4755 4802 4850 4897 ~4910 0.7 0.2 1.0 0.4 0.2 0.5 0.2 -0.1 0.2 0.4 -0.4 0.2 0.6 -0.5 0.7 3424 0.5 -0.1 0.6 3483 0.8 -0.2 -1.0 3542 0.5 -0.3 -0.6 3603 1.6 0.4 -2.1 3664 0.6 -0.5 0.4 TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drillin'g Well Name Location Date Surveyed Survey Performed By : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope : Dec 30-Jan 15, 93 : : Craig E. Tomayer This survey is correct to the best of my knowledge and is supported by actual field data. Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-51 Location : Drill Site 9 : Prudhoe Bay : North Slope Date Dec 30-Jan 15, 93 Filename : 1167 Interpolated 100 ft of TVD Plane of Vertical Section : 126.6° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0' ' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 1 of 3 Date Dec 30-Jan 15, Filename : 1167 93 Interpolated 100 ft of TVD MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 100 100 0.0 283.9 200 100 0.1 340.7 300 100 0.2 271.4 400 100 0.3 262.6 500 100 0.6 220.5 600 100 0.4 201.4 700 100 0.3 146.8 800 100 0.1 140.9 900 100 0.2 165.3 1000 100 0.3 180.5 1100 100 0.3 151.3 1200 100 0.3 152.2 1300 100 0.3 147.1 1400 100 0.3 164.0 1500 1600 1700 1800 1900 2000 2101 2201 2302 2403 2505 2609 2713 2820 2928 3039 3153 3270 3391 3516 100 0.5 167.3 100 1.1 199.5 100 1.5 227.4 100 1.4 236.5 100 1.5 154.8 100 4.0 122.7 100 5.5 108.9 101 6.0 116.6 101 7.6 123.3 101 10.1 121.1 102 13.1 115.5 103 16.0 117.6 105 18.6 118.7 106 21.3 119.5 108 24.2 120.1 111 27.1 120.2 114 29.9 119.9 118 33.2 120.2 121 35.4 120.1 124 37.6 120.3 3646 130 41.2 120.9 3782 136 44.4 120.2 3924 142 46.0 120.6 4067 143 45.4 122.8 4211 144 46.4 125.3 TVD ft 0 100 200 3OO 400 5OO 6OO 700 80O 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 VS ft 0 0 0 -0 -0 -1 -1 -0 0 0 8 16 25 37 53 LAT ft 0 0 0 0 0 -0 -1 -2 -2 -2 -3 -3 -3 '--4 -4 -5. -6 -8 -10 -11 -14 -17 -21 -27 -35 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 -76.1 -0 0.1 0.1 56.8 -0 0.2 0.1 -69.3 -1 0.1 0.1 -8.8 -1 0.4 0.3 -42.2 -2 0.3 -0.2 -19 . 1 -2 0.3 -0.1 -54.6 -1 0.2 -0.2 -5.9 -1 0.1 0.1 24.4 -1 0. 1 0.1 15.2 -1 0. 1 -0.0 -29.2 -1 0.0 0.0 0.9 -1 0.0 -0.0 -5. 1 -0 0.1 0.1 16.9 -0 0.2 0.2 3.3 -1 0.7 0.5 32.2 -2 0.8 0.4 27.9 -4 0.3 -0.2 9.2 -4 1.9 0.2 -81.7 -1 2.8 2.4 -32. 1 7 1.9 1.5 -13.7 16 0.9 0.5 7.6 26 1.8 1.6 6.6 39 2.5 2.4 -2.2 2500 73 -45 58 3.2 3.0 -5.5 2600 99 -57 81 2.8 2.8 2.0 2700 129 -71 108 2.5 2.5 1.0 2800 165 -89 140 2.5 2.5 0.8 2900 207 -110 176 2.7 2.7 0.6 -134 -1,61 -192 -226 -263 3000 3100 3200 3300 3400 254 308 370 438 511 593 685 786 888 991 3500 3600 3700 3800 3900 -306 -353 -404 -457 -515 217 2.6 2.6 0.1 265 2.5 2.5 -0.3 318 2.8 2.8 0.3 377 1.8 1.8 -0.1 441 1.8 1.8 0.2 512 2.8 2.7 0.5 591 2.4 2.4 -0.5 679 1.1 1.1 0.3 766 1.2 -0.4 1.5 851 1.5 0.7 1.8 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 2 of 3 Date Dec 30-Jan 15, 93 Filename : 1167 Interpolated 100 ft of TVD MD ft 4357 4504 4651 4799 4947 5095 5244 5393 5542 5691 5839 5989 6141 6295 6446 6599 6750 6902 7054 7208 7362 7515 7668 7823 7981 8140 8299 8457 8614 8770 8926 9079 9229 9374 9515 9652 9784 9914 10039 10162' CkL INC DIR TVD ft deg deg ft 146 46.8 125.4 4000 147 47.4 125.4 4100 147 46.9 125.9 4200 148 47.6 125.5 4300 148 47.8 125.9 4400 149 47.4 125.9 4500 149 48.2 125.5 4600 149 47.4 125.3 4700 149 48.0 125.2 4800 149 47.6 124.8 4900 148 48.0 125.4 5000 150 48.0 125.7 5100 152 49.6 127.7 5200 153 48.9 127.8 5300 151 48.8 126.9 5400 153 49.0 126.1 5500 151 48.3 126.3 5600 152 49.6 127.6 5700 153 48.9 127.8 5800 154 49.9 128.1 5900 154 48.8 129.7 6000 152 49.1 128.6 6100 153 49.7 126.9 6200 156 50.2 128.3 6300 157 50.9 128.9 6400 159 51.2 130.3 6500 159 50.9 130.2 6600 158 50.6 130.3 6700 157 50.3 129.4 6800 156 50.3 127.6 6900 156 49.7 127.4 7000 153 48.8 127.6 7100 149 47.3 126.4 7200 145 45.6 126.2 7300 141 43.9 126.7 7400 137 42.0 126.7 7500 133 40.2 126.3 7600 129 38.5 126.0 7700 126 35.9 126.6 7800 123 35.9 129.0 7900 VS LAT DEP D'LEG BUILD TURN o o ft ft ft °/100 /100 /100 1097 -577 938 0.2 0.2 0.0 1204 -639 1026 0.4 0.4 0.0 1313 -702 1113 0.4 -0.4 0.3 1421 -765 1202 0.5 0.5 -0.3 1531 -829 1291 0.2 0.2 0.3 1641 1751 1861 1971 2081 2190 2302 2417 2533 2647 2762 2876 2990 3105 3223 3340 3454 3570 3689 3811 3934 4058 4180 4301 4421 4540 4656 4767 4873 4972 5O65 5152 5234 5311 5382 -894 1380 0.2 -0.2 0.0 -9'58 1469 0.5 0.5 -0.3 -1022 1559 0.6 -0.5 -0.2 -1086 1649 0.4 0.4 -0.0 -1149 1739 0.3 -0.3 -0.3 -1212 1828 0.4 0.3 0.4 -1277 1920 0.2 0.0 0.2 -1346 2012 1.4 1.0 1.3 -1417 2104 0.5 -0.5 0.0 -1486 2193 0.4 -0.0 -0.6 -1554 2287 0.4 0.1 -0.6 -1621 2378 0.5 -0.5 0.1 -1690 2470 1.1 0.8 0.9 -1761 2561 0.4 -0.4 0.1 -1832 2653 0.6 0.6 0.2 -1906 2745 1.1 -0.7 1.1 -1979 2833 0.6 0.2 -0.8 -2049 2925 0.9 0.4 -1.1 -2121 3020 0.8 0.4 0.9 -2197 3115 0.5 0.4 0.4 -2276 3211 0.7 0.2 0.9 -2356 3305 0.2 -0.2 -0.1 -2435 3399 0.2 -0.2 0.1 -2513 3491 0.5 -0.2 -0.6 -2588 3585 0.9 -0.0 -1.2 -2660 3679 0.4 -0.4 -0.1 -2731 3772 0.6 -0.6 0.1 -2798 3860 1.2 -1.0 -0.8 -2860 3945 1.1 -1.1 -0.2 -2919 4025 1.2 -1.2 0.4 -2975 4100 1.4 -1.4 -0.0 -3027 4170 1.4 -1.4 -0.3 -3075 4236 1.4 -1.3 -0.2 -3120 4298 2.1 -2.0 0.5 -3164 4354 1.1 -0.0 1.9 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling · DS 9-51 : Drill Site 9 : Prudhoe Bay : North Slope Page 3 of 3 Date Dec 30-Jan 15, 93 Filename : 1167 Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 10289 127 38.8 130.9 8000 10418 129 39.3 131.1 8100 10548 130 40.2 130.8 8200 10678 130 38.7 130.7 8300 10806 129 39.4 131.5 8400 10937 131 40.5 132.0 8500 11069 132 40.8 132.9 8600 11201 132 40.7 133.3 8700 11327 126 40.3 134.0 8796 VS ft 5460 5540 5623 5706 5787 5870 5956 6042 6123 LAT 'ft -3214 -3267 -3322 -3376 -3429 -3485 -3543 -3602 -3658 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 4414 2.4 2.3 1.5 4475 0.4 0.4 0.2 4538 0.7 0.6 -0.2 4600 1.1 -1.1 -0.1 4661 0.7 0.5 0.6 4724 0.9 0.8 0.4 4787 0.5 0.2 0.6 4850 0.2 -0.0 0.3 4910 0.7 -0.4 0.8 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6123 ft 126.7° ARCO ~_ln_~ka, Inc. P.O.Box 100360 Anchorage, Alaska 09510 DATE: 3-2-93 REFERENCE: ARCO OPEN HOLE FINALS 2-25-93 DLL (Simultaneous) Run 1, 2'&$" 2-25-93 B H C]S t..-- Run 1, 2-25-93 CNL Run 1, 2'&$ 2-9-93 DLL/MSFL/GR Color Run 1, 2"&~ 2-9-93 LD/GR/CNL (Raw) Color Run 1, 2"&5" 2-9-93 LD/GR/CNL (Poro) Color Run 1, 1-18-93 DLL/MSFL/GR Color Run 1, 1-18-93 LD/Neutron (Raw) Color Run 1, 2"&5" 1-18-93 LD/Neutron (Poro) Color Run 1, 2"&5" 2-19-93 DLL/MLL/GR Run 1, 2"&$" 2-19-93 BHCA/GR 1/26-2/12/93 DGR/EWR/FXE 1/26-2/12/93 DGR/CNP/DSFD/CAL 1/26.2/12/93 DGR/Near-Far Ave4~' 1/26-2/12/93 DGR/EWR/FXE 1/26.2/12/93 DGR/CNP/DSFD/CAL Runs 4-16, 2"&S"TVD 1/26-2/12/93 DGR/Near-Far Ave .~ Runs 4-16, 2"&5"TVD Pleue sign and return~ttac~efll copy as receipt of data. #D&M R&D # CL]XT CHAPMAN ~.. # BPX # EXXON -'~ # STATE OF ALAS~ M&RATHON # TEXACO # MOBIL Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Run 1, 2"&5" Atlas Runs 4-16, 2"&5"MD Sperry Runs 4-16, 2"&5"MD Sperry Runs 4-16, 2"&S"MD Sperry Runs 4-16, 2"&5"TVD Sperry Sperry Sperry Alaska, Inc. P.O.Box 100360 Auchorage. Alaska 99510 DA~: J~xy 25.1993 I~EFEHENCE: 1-24A 12-22-92 7-18-92 /~RCO MAGNETIC TAPE{S) WITH LISTINGS ~.~,IZ~CiCrtlGR D~-,/~Y-,~ I,~C l CN I GR ~C~iD~i~ DLL/SDN/CNTH DI~,/~IAClCNIGI~ l~m I Job~5822 Run I Job~5578 1~nl J~37 R~n I Job~93033 Run 1 Job~5605 Please sign and return~ tl~ attac~h/~ copy as receipt of data. IIave A Nice Day! · ! C~)nya Wallace APPROVED_~E~f__ ATO-1529 Trans# 93016 C~NTr~ ~m~S (CH) CHEVRON D&M # ~OB ~A~ (OH/GCT) # EXXON ~THON MOBIL ~CO ~o, The correct well na~e for tht~ 1-24A not 1-24ST. This i~ a revised tape. please replace previous tape. The correct API# for 14-22A is 50-029-20747-01. Atlas Atlas Sch Atlas MEMORANDUM TO: THRU: Leigh Griffin~, ' Commissioner Blair Wondzell, P. I. Supervisor Stale of Alaska Alaska Oil and Gas Conservation Commission DATE: January 25, 1993 FILENO: jph-rep6.doc, Rev. 1 TELE. NO: 279-1433 , FROM: Jerry Herring, ~f~ SUBJECT: Petroleum Inspector B.O.P. Test, Nabors 18E ARCO PBU DS 9-51 PTD 92-141 Saturday, January 16,1993: ! witnessed a B.O.P. test on Nabors rig 18E on Prudhoe Drill Site 9, well 51. The 9-5/8" casing was installed to 11,410 feet. The B.O.P. Test Report is attached. Summary: The B.O.P. test on Nabors :18E started at 7:00 a.m. and lasted for 2-1/2 hours. No failures were encountered. Attachment OPERATION: Drlg X// Compl~ 0 p~r ~ ~0 r ~ O~ ll~ ~: ~ }~ /{ Location: Se,c , ,f-,, } T /mhJ Drlg contr ~i~%"~m~q~ ~ Location (geAF1) 0~{' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report Representative d - Wel 1 name Representative ~J~, 1N COMPL 1ANCE ~ yes no ~_~/ A. DIVERTER -- ' ~ [ ne s-~ ~-ength ~. () () 2. ( ) ( ) (¢~ ~-line conn& anchored 3. ()() l~bifurcated & dwn wind 4. ( ) ( ) _- 90° targeted turns 5. ( ) ( ) ¢/)] vlvs: auto & simultaneous 6. ( ) ( ) (¢O~./annular pack-off 7. ( ) ( ) (~ condition B. BOP STACK wellhead flg wkg press stack wkg press annular preventer pipe rams blind rams stack anchored chke/kill line sz 90° turns targeted (chke & kill ln) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd, whd, clmpd) drl spool flow nipple flow monitor.' control lines fire protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs- regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote pontroI panel .. 8- I~))- ( ) ( ) 9. () () 10. (VIi ( ) ( ) 11 · ~/~., ( ) ( ) ~2. (,/~-/ ( ) ( ) '~3. (~,. ( ) ( ) · ~4..(~. ( ) ( ) ~5. ('¥~ () ~. (-/)~ ( ) ( ) ~. () () 22. () ()~ 24. ( ) ( ) 25. () () 26. ( ) ( ) 28. () () zs. (~, ( ) ( ) Bo. (-~ () () ]~.(~)/ ( ) ( ) 32. (¢'). ( ) (,-) I N COMPL I ANCE :. ~ no n/a 34 (~..() ( ) 35 (~T~ ( ) () 36. (v~() 37 ( ,,/)' ( ) 38. (,,'F' ( ) 39. (~<~ ( ) 40 (~ ( ) ~2 ( ) ~3. (,-I"' () 44. ~ ( ) ~.s. ('-')'~. () 46 (v~'~ ( ) ~?. (~'r~ ( ) 48. ( ) (v)'/ 49. ('v~'"" ( ) s~. ( ) 52. ( ) ss. ( ) 54. ( )/ ( ) 55.~ ( ) 56. ( ) 57. ((~() 58. ( ) firewail nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In copn trip tank E. RIG FLOOR kelly cocks (upper,lower,lBOP) floor vlvs (dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor flow rate indicator, pit leve' indicators, gauges)' kill sheet up-to-date gas ~etection monitors {H S & methane) hydr chke panel ch~e manifold F. MISC EQUIPMENT flare/vent line 90~ turns targeted ~ (dwn strm choke lns) (v~)reserve pit tankage personnel protective equip avail all drl site suprvs trained 2for procedures. H S probes rig housekeeping REMARKS: RECORDS: Date of last BOP inspection: (..~ Resul ting non-compli ance: /%/IL_~ ~ 1~1~,~'7"' Non-compliances not corrected & vCny: Date corrections will be completed: BOP test & results properly entered on daily record? Date of last BOP test: Kill sheet current? InspectorJ/~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg v Operator Wkvr q ?/b" csg set II, ft .. Location (general) /' · Housekeeping (general) TEST: Initial Rep ]~)/ ~ ~ J4 -----------------------------------~l ~ Rig# l~ Well sign Rig Weekly t~ Other Rig phone # Location: Sec T R M ACCUMULATOR SYSTEM: Full charge pressure ~Otgd~) psig Rsrve pi t ~.4UD SYSTEMS: Vi sua 1 A~i o Trip tank / / Pi t gauge Flow monitor Gas detectors BOPE STACK: Test Pressure Annular preventer ~ ~d~ /'~' -' -' -' -' -' -' -' -' -~ 0 Pipe rams r,',~ ~)/"~'00"~ B1 i nd rams Choke line valves HCR valve Kill line valves Check va1 ve .~\l//~' Pump incr clos press 200 psig ~ min Full charge press attained J min 2 Controls: Master Remote/ ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: J ~ sec sec I%oo Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges Adjustable chokes Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test .pressure TEST RESULTS: Failures ~ Test time ~/~- hrs Repair or replacement of failed equipment to be made within ~ days. Notify the Inspector~ and follow ~ith ~ritten/FAXed [27G-7542] verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor 004 (rev 07/92) ' J 24-HR NOTI~IVEN? yes ... no . Waived by: Witnessed AOGCC phone 279-1433 FAX 276-7542 ALASKA OIL AND GAS CONSERVATION COMMISSION December 23, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 Michael Zanghi ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 9-51 ARCO Alaska, Inc. Permit No: 92-141 Sur. Loc. 1023'NSL, 5136'WEL, Sec. 01, TiON, R15E, UM Btmhole Loc. 2361'NSL, 4715'WEL, Sec. 07, T10N, R16E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI'-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE -= 54.8'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoragg, Alask~ 9951~-6612 ADL ~1345 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.o25 1023' NSL, 5136' WEL, SEC. 01, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2610' NSL, O' WEL, SEC. 12, TION, R15E DS 9-51 U-630610 At total depth 9. Approximate spud date Amount 2361' NSL, 4715' WEL, SEC. 07, TION, R16E 12/25/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line . . ADL 28327/-342'1ee[ DS 9-46/90' @ 103'MD feet 2560 12086' MD/9257' TV/]eet 16. To be completed for deviated wells 17. Anticipated pressure (se,, 20 AAc 25.035 (e)(2)) Kickoff depth ~9oofeet Maximum hole angle 47.1 o Maximum surface 3330psig At total depth (TVD) ~800'/4390psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5~ H-40 Weld 80' 32' 32' 110' 110' 11 yds Arcticset (Approx.) 16" 13-3/8" 68# L-80 B TC 3959' 31' 31' 3990' 3750' 153o sx CS 111/400 sx "G"/250 sx CS II 12-1/4" 9-5/8" 47# L-80 NSCC 11487' 30' 30' 11517' 8870' 900 sx Class "G" 8-1/2" 7" 26# 13CR8O NSCC 719' 11367' 8768' 12086' 9257' 185 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production DEC 1 1 1992 Liner Alaska 0il & Gas Cons. t;ommisSion Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time/.vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby cert!fylthatJ, he tforegoing is true and correct to the best of my knowledge Signed/~ ~. Title Drilling Engineer Supervisor Date ! ~'' I r~-¢ ' ' -~ ,-"k,,, Commission Use Only Permit Number -LM iAPi number IApproval date _ _ See cover letter ~.~__-/'~// 150-cz- ?.-, z ~_ ~ ~ M Id' for other requirements Conditions of'approval Samples required [] Yes /~'NO u Icg required []Yes J~ No Hydrogen sulfide measures [] Yes ~. No Directional survey required ~ Yes [] NO Required working pressure for BOPE CI2M; 1-13M; ~5M; I-]10M; I-I15 Other: Origina! Signed By by order of Approved by David ~.,V. ,Jc~hn~l'c~r~ Commissioner [ne comm,ssion Date Form 10-401 Rev. 12-1-85 Submit in triplicate State; Alaska Borough: Well: D$9-51 Fie{d: Prudhoe Bay St. Perm ~ 92-141 Date 1'4/15/92 Engr: M. Minder DS9-51 .XLS Casing intervs{ Interval $~ze Bofforn Top lA 13.375 151 31 ~A, 13.375 3750 120 3/3. 9,625 8870 30 4A 7 9;)57 8768 5A 0 0 0 GA 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Descriptionescriptionescription Tension 11487 719 0 0 0 0 0 0 Lbs Grade Thread Lbs 68 K-55 BTC 0 68 L-80 BTC 269212 47 L-80 NSCC 0 26 13CRB0 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/ft ! B 9.5 0.494 2B 9.5 0.494 3b I 0.0 0.520 4B 10.0 0.520 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 9B 0.0 0.000 1 OB 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF 3330 3450 1.0 3330 5020 1.5 3330 ~ 1.4 3330 7240 2.2 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #OiVlO! 0 0 #DIVIO! 0 0 #DIVIO! 0 0 #DIVIO! Tension Strength K/Lbs !C 277.372 2C 269.212 3C 539.889 4C 18.694 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 1069 3.85 ~ 20.6~5 1086 2.01 604 0 #DIV/0! 0 #DIV/O! 0 #DrWO.I 0 # DIV..~! 0 #DiV/O! 0 #DIV/O! Collapse Collapse Pr-Dot-Psi Resist, CDF 75 195O 21~, 142 1853 2260 1.220 4612 5140 1.114 4814 5410 1.124 0 0 tlDIVIO! 0 0 #DlVl0.1 0 0 #DIViO! 0 0 # DIVIO.I 0 0 #DIVIO.I 0 0 #DIVlO.I $-51CI4T.XLS Si:ate: Well: Field: State Permit DS,9.51 PRLI,..'~t-IO£ $2.14! Engineer: Work S heat: Date: C. emeni Vok,,me £'alc~#alion,~ 12115182 Casing Type Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement-Sacks 111 Cement- Yield 111 Cement- Cubic ft Cement- Cubic Irt 111 Cement- Sacks 1:I2 Cement-Yield Cement- Cubic Irt :1:t2 Cement- Cubic it ~2 Cement-Sacks 113 Cement- Yield :!:13 Cement- Cubic ti ~I3 Cement- C,.,¢~4c tt 1:t3 Cement- Cubic tt/'Vol Cement- Fill Factor Casing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sa~s111 Cement- Yietd 111 Cement- Cubic tt 111 Cement- Cubic tt 111 Cement- Sacks :1:12 Cement- Yield 1:12 Cement- Cubic t't 1~2 Cement- Cubic tt 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic ft :I:13 Cement- Cubic tt 113 Cerr~nt - Cubic tt / Vol Cement-lnte[val ft Top of Cement- Feet Conducto~ 20.000 80.080 30.000 0.000 0.000 O.000 297.000 0.000 0.000 0.000 0.000 297.080 1.381 !nte~mediate 0. O00 0.000 0.000 0.0O 0.00 0.00 Et:lO O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~DIV/0! ~DIV/0! Surface 13.375 3,959.000 16.000 1,530.000 1.920 2,937.600 2,937.600 400.000 1.150 460.000 460. OO0 O. OOO 0.000 0.000 0.000 3,397.600 2.041 Liner 7.000 719.000 8.500 185.000 1.180 218.300 218.300 0.000 0.000 0.000 0.000 218.300 2.394 inte~mediate II2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 0.00 IIDIV/O! I:IDIV/O! Production 9.625 11,51 7. 000 12.250 4B'O. O0 2.40 1,104.00 1,104.00 440.00 1.14 501.60 501.60 0.00 0.00 0.00 0.00 1,605.60 5,126.74 6,390.3 M ec-tsured Depl'h 115'/'1/ WELL PLAN WELL: LOCATION: 9-51 Surface: Target: T.D.: Producer 1023' FSL, 5136' FEL, Sec.' 01, T10N, R15E 2610' FSL, 0' FEL, Sec. 12, T1 ON, R15E 2361' FSL, 4715' FEL, Sec. 07, T10N, R16E ESTIMATED START: Dec 25, 1992 OPR. DAYS TO COMPLETE: 23 (19 days drilling, 4 days completion) CONT~TC~: Nabors 18E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEp: 47.1 deg/S53.4E/1900'/2.5/6743' Estimated Ground level elevation is 25.3' AMSL. KB to ground level elevation is 29.5'. Item TVD(BKB) MDfBKB) Mud Wt. 20" CONDUCTOR 8 0 8 0 8.5 13-3/8" SHOE -' 3750 3990 9.0-9.5 TOP UGNU SANDS 5 9 94 72 89 9.0 - 9.5 K12 7022 8801 9.5-10.0 K10 7555 9584 9.5-10.0 K5 8135 10436 9.5-10.0 9-5/8" SHOE 8870 11517 9.5-10.0 SAG/PUT/SH UB Absent TOP SADLEROCHIT 8 8 7 0 11 51 7 9.2 - 9.5 TARGET 8870 11 51 7 9.2-9.5 TOTAL DEPTH 925 7 1 2086 9.2- 9.5 CASING PROGRAM: Hole Csg wt Grade Conn Lenqth Tgp 30" 20" 91.5# H-40 WELD 80 32 16" 13-3/8" 68# L-80 BTC 3959 31 12-1/4" 9-5/8" 47# L-80 N930 11487 30 8-1/2" 7" 26# 13Cr NSCC 719 11367 Btm 110 3990 11517 12086 COMPLETION: Tubing: Gl_Ms: Packer: 7x5-1/2 26#/17# 13Cr Fox 3300/8017 29 11317 10-5-1/2" x 1-1/2" with 9 dummies and 1 RP shear(2800 psi) ir, top station and 1 equalizing dummy in deepest station. 9-5/8" x 5-1/2" perm latched set at +/- 50' above top of liner with 4-1/2" tail pipe. LOGGING PFE~RAM: Open Hole- 12-1/4" Hole: 8-1/2" Hole: DS 9-51 None DLL/CNL/LDT/GR +/- MSFL Conventional 14:37 December 10, 1992 REEEIVED Page 5 DEC 11 !992 Alaska 0ii & Gas Cons. 6omnl~ss~o~ Anchorage Cased Hole Atlas SBT or SWS USIT cement evaluation logs after rig moves off. No gyro planned. RE6EIVED DEC 1 1 1992. Alaska Oil & 6~s Cons, Anchorage DS 9-51 Conventional 14:37 December 10, 1992 Psge 6 PROPOSED DRILLING AND COMPLETION DS 9-51 Procedure PROGRAM , , . , . . , . , MIRU drilling rig. N/U diverter and function test same. Drill 16" hole to surface casing point. Run and cement surface casing. function test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. perform leak off test. Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. mud. RIH and drill 8-1/2" hole through reservoir to TD. RU and run e-line logs. MU 7" liner on 5" DP. RIH to TD. Cement same. excess cement from wellbore. POOH. MU casing scraper & clean out 7" liner. Run 7" x 5-1/2", 13Cr tubing and packer assembly with SSSV. Test tubing and casing to 3500 psi. NU tree and test to 5000 psi. ° Anticipated BHP: o Maximum Anticipated Surface Pressure: o Planned Completion Fluid: Notes: a. Nipple up BOPE and Drill 10' of new hole and Bump cementing plug with Set liner hanger and packer. Circulate Freeze protect with diesel. Release drilling rig. 3600 psi @ 8800' TVD SS 2800 psi 8.6 ppg filtered sea water The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). Ce Based on previous logs on DS 9, no potential productive zones are anticipated above the Sadlerochit target do No potential hazardous levels of H2S are anticipated in this well. RE EIV£D DEC 1 1 1992 Alaska 0ii & Gas Cons. Anchorage g-51 Conventional Producer DdlUn.g__P_roblema & Copper.os: DS 9.51 I;a slant convenflorlal well ( 80 acre ir]fill produoer ) with a 13.3/8" x 9.7/8" x 7" daslno program. A a3py of the D~ [:1 dat~, sheet ha; been dellvered to 18E. The Ugnu/Creta=eous is likely overpreseured by' 1P. 5 Io 150 poi. A mud weight of 9.0 ppg or grealer should be used through this Interval to prever]t salt water in~.urslon=. The top of the Cretaeeoue/Ugnu ts at 7289' md/5994' tvd. No elgnlfl=ant drilling problems are antlolpatecl. No Klngak, Sag River, or Put River will be The 9-51 well targel Is progno~ed for ttm lop of Sadloroohlt ( ZULU flowunll ). There I~ no expected g~s e~p Ir~ the well, Faulting In the near tergot area is not a oon~rn end a 201)' target radiu~ will be used. The oompIotlon will inolude 7" x 5-1/2" 130r Fox tubing with 8 dummled GLMs, one equalizing dummy, and one RP shear valve AlitTE FLUIDS The ~-42 and 4T9 surface annulus i~t ~¥atlable ~or pumping al pre,ont. Fluids can also be transported Io the oentral 00.2 injection facility, The AOGOO has Informed PB Drilling thai only assoolaled fluld~ from drilling operations can be pumped down the surface x Intermedlale annulus-lo: completion fluids cannot be pumped. CUTTINGS...D.!BP__O_9_ ,,, Plan Io wash and store gurface gravel In bormed pit on pad. Grind and tnJeot all non-gravel ~urfeoe, intermediate, and produoilon interval material using the gun Unit. FREEZE .PRO.TECTIq. The tubing along with the tubing ~: caging annulus will b~ free~:e protected using cllesel. Tile 13- 3/8" x 9-$/8" annulus mu6l be fully displaced with dry crude after the welt is completed. CLOSE APPROAqUS_& NOte near well proximity (less than I00') of other D$-9 wells, Produotlon has been requested to pedorrn the following:, 9.15 (i,lector) casing is set, 9-48 (producer) Is 6et. 30' to 100' down to 2678' md, 30' to 100' down to 1548. Close SS@V until drilling well m~rf~ce Close S~SV unlil drilling well surface easing DS 9-61 Conventional 13'.38 December 15, 199£ Page 7 PRUM ~N~HI LHI~W WiN U~ILLII~ ~u ~R~AT L~D DIRECTIONAL DRILLINC~ INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 E6EIVED DEC 1 1 1992 Alaska Oil & Gas Cons, commiSSiot~ Anchorage DIPd~CTiONAL WELL PLAN for PRUDHOE BAY DRILLING Wall ......... : DS 9-51 (P3) Fie%d ........ : PRUDHOE BAY DRILL $IT~ 9 Computation..: MINI~U~ CURVATURE LEGAL DESCRIPTION Surface ...... : 1023 FSL 5136 FEL $01T10N R15E UM Target ....... : 2610 FSL 0 FEL S12 T!0N R15E UM BHL .......... ; 2361 FSL 4715 F~L $07 T10N R16E U~ Prepared ..... : 12/10/92 Section at...: 126.63 KB elevation.: 55.00 X ASP ZONE 4 Y 718534.64 5942495.42 723777.96 5938955.15 724119.84 5938716.38 PROPOSED WELL PROFILE STATION YDENTIPICATION KB KOP BUILD 2.5/100 BUILD & TURN 2.5/100 MEAS INCLN DEPTH ANGLE 0 0.00 1900 0.00 2000 2.50 2100 5.00 2200 ?.50 V~RT-DEPTHS $~CT BKB ~UB-$ DIST 0 -55 1900 1845 2000 1945 2100 2045 2199 2144 DIP~ECTION REL-COORDINATES AZIMUTH FROM-WELLHEAD DL/ 100 0 0.00 0 N 0 E 0.0 0 78.00 0 N 0 E 0.0 1 78.00 0 N 2 E 2.5 6 78.00 2 N 9 E 2.5 13 78.00 4 N 19 E 2.5 2300 9.18 2400 11.16 2500 i3.32 2600 15.5S 2700 2298 2243 2397 2342 2494 2439 2591 2536 2587 2632 24 90.88 5 N 34 E 2-5 39 99.51 4 N 51 E 2.5 58 105.48 1 S 72 E 2.5 82 109.78 9 S 95 E 2.5 110 113.00 19 S 122 ~ 2.5 2800 20.27 2900 22.66 3000 25.07 3100 27.50 32OO 29.94 2781 2726 2874 2819 2966 2911 3055 3000 3143 3088 142 115.49 33 S 252 ~ 2.5 178 117.49 49 $ 185 E 2.5 218 119.11 68 S 220 E 2.5 262 120.47 90 S 259 E 2.5 309 121.63 115 S 300 E 2.5 3300 32.38 3400 34.84 3500 37.30 3600 39.76 3700 42.23 3229 3174 3312 3257 3393 3338 3471 3416 3547 3492 361 122.62 143 S 34~ E 2.5 416 123.49 173 S 390 E 2.5 '475 124.26 206 S 439 E 2.5 537 124.94 241 $ 490 ~ 2.5 603 125.56 279 $ 544E 2.5 ~ND OF CURV~ SURFAC~ CASING UGNU K-12 3800 44.70 3899 47.14 3990 47.14 7289 47.14 8801 47.14 36!9 3564 3688 3633 3750 3695 5994 5939 7023 6968 672 126.12 319 S 600 E 2.5 742 126.63 361 S 657 E 2.5 810 126.63 401 S 710 E 0.0 3227 126.63 1~44 S 2651 E 0.0 4336 126.63 2505 $ 3540 E 0.0 K-10 K-5 T~LRGET TOP S3~LEROG~IT HEAVY OIL TAR 9584 47.14 10436 47.14 11517 47.14 11517 47.14 11818 47.14 7555 7500 8135 8080 8a70 8815 8870 SS!5 9075 9020 4909 126.63 2847 S 4000 E 0.0 5534 126.63 3220 S 4502 E 0.0 6326 126.63 3693 $ 5137 E 0.0 6326 126.63 3693 S 5137 E 0.0 6547 126.63 3825 S 5315 E 0.0 CGLDD (c)92 DS951P Sl.36 9:14 AM ~) lU 12/10/92 Page 2 PROPOEED WELL PROFILE STATION IDENTIFICATION owe BOTTOM SADLEROCHIT TD MEAS INCLN VERT-DEPTH$ SECT DIP~CTION REL-COORDINATES DL/ DEPTH ANGLE B~B SUB-$ DIST AZIMUTH FROM-WELLHEAJ3 t00 11877 47.14 9115 9060' 6590 11936 47.14 9155 9100 6633 12080 47.14 9253 9198 6739 12086 47.14 9257 9202 6743 126.63 3850 S 5349 E 0.0 126.63 3876 S 5384 E 0.0 126.63 3939 S 5469 E 0.0 126.63 3942 S 5472 E 0.0 (GLDD (c)9~ D$951P B1.56 9:14 ~M 2) REEEIVED DEC 1 1 1992 Alaska Oil & Gas Cons. CommisSiOr~ Anchorage D~C-10-1992 10:21 ~P(~H I LHFIU L/1 I-~ .L/I% i I_L ! I'tLl I u PR HOE BAY DRIL'f'"ING A} KR ,, :.o ,,oo o o.oo IVERTICAL SECT , N VIEW £) ~ILO & ~N ~_5~00 ~200 2]9g C3 7.50 ,, , ~ - ._ E) ~RFACE CASING 3990 3750 8~0 47,~4 F) 7AReET t~517 8870 53~ 47,J4 TVO Sc8)e.' J ~nch = ~200 feet ~o ~2086 9857 6743 d7,14 Oep Sca le .' ~ inch = 1200 f ~EC ~ ] , ~ ~ , , ....... !?-~ .Oil & 6as Cons. , i i i ~ ~ ~ t { l ~']"- ~ i ~ ' -- ~ r " ~ r'~~..... 1~, ~ ~ ',~'~_i... , .,.. , .... ~L ~ ~ ~ { I,I ...... i11 ~',1 ~ ~-':"" ~ i i i I I i I I .... ~ I ~ ~ I i .. ~ t l , _._ , .._1 ~-r ...... ~'l..& ~ ~ [ ~ t ~ i~ ....... F'~ ~ t ~ ~ ~ . , -~ , ' ...... l-ll 'T= ~,,~ , t l ..... ~,, ~ j ..... ~ ..... I ~ T' ~ ~ _ . , . ~,l, ~ ~ ~ ~,,~ ~ .~ ..... ~:~'~~ ~'~ :.-!.l.-.~[ "~' ,, ~ "' , iii l~ .... L ' I , I ,. I f .,I ........... I-, I I ~ 'J-[ I t I I I U"'.'' ...... , i--1, 1,1 I , , i ,., , .... ' l..1- ' ' iT ...... T.- ~ ~ ~ , , .... ..-.~ , -i ...... 4 t , . --,.,-P-. ' ........ i' ~ ~; ..... "" , , r'-r',-"r- I I I ' ; I ...... I I I ' I I ., ~ ,~,, ,,i,,,,.::I'-_. '~; , :,".,, ' ' ' ' ' ' '-' I ~ ..... I I , .... , , ~ t , ~ I t ~ ' I !l'-~ i I ~1 I I / I~ '-'F'~I' I t , I ,,,, ,, ,,,:,,.,.,,,,, .... .... ...., ._, ' ~ " ~{ ~! "'['~--. ~ !~ :'~" ~' 'i ' ~ ' ~ . --. , --,, .,, ,, .-~ , :, ~_ ," ,: ~,, i , '-[ ' ] ~ I ~ ~ ~ L I ~'"! , I ~ ~ ~ ~ ' i, .......... ! ~ ~' t_..' I _/_L?]'Z_l._r,, i'~_,_L .upM j s~-1 I i I'- L.'.. --- I [, I i ' N - Jr -~--i F'~ ]'I I I . , , ,, ,, .,...,_,,, ,,,,.... ,, , , ~ , '-,, , . -,.~p,~-t:z -~...~-~;' .~ .... ~ ......... · ": .~.,,, . ,," ,'~-': ,,"i,..~.-,, ," ,, ','.~ ,,"-. .,-"~~~,,,, -~ ~-, ',, I~ , ~,, I~ ,, ' ~ ~ I~ ~;": ~ " ~ ~' ~ -' ...... · -.,, ., , "'' ' ' L~t-T .... _ ...... ~_ ,,. ..... i .-. I, ~*-'"' '* "~--'-~ "" ,.,'"" .... ' Tii -'~', ..... ' * -~' ........ -.' ',, I..~ ~ I i I i I '*'1 ~ I, : i I I I I /, i T-~. i : I ] ' l-1 _l !~ I i ..... ;.j , , ~'1 ~ ~ '...} I i ~' i ~,,,,.,.., ,, ,,,~,., ..... ,,.. ~--~ .,.-,-' .., ~¢',~¢- ~"'. ~- . ~ .,,,;%'1:~ ,"-hF,~ ...... -.."i--',, i--c'~'~''-~'~''':;''~'''*''-~-:'; l.~ I ~ I I1 ' ' i ~ I , I "- -'"I .... ' " ' ' , , ,,,',' ,, "- t--~¢' l~i ~ ,., ' I ~ I ¢ ' ~ ~ ' ' I I- , , I 0 600 i200 ~$00 P400 3000 ~3600 4200 4BO0 5400 6000 6600 7200 7800 Sect ~on DepartuPe (GLOB I¢)g2 '~_~SJP 1~.36 9:,~0 AN ~) ..... DEC-10-1992 i0:22 P'-R-U'DHOE IU Marker fd8ntif &cation ND N/S A] KB 0 0 N B) KOP BUILD 2.5/100 t900 0 N C) ~ILO & TURN 2.5/~00 2200 4 N D) ENO ~ C~VE ~8gg 26~ S E) ~RFACE CASING ~990 40t S F) TARGET ~1517 3693 S G) TO ~2086 39~ S BAY £/~ lg ~57 ~ 710 E 5237 E 5472 E RECEIVED DEC 1 1 1992 Alaska 0ii & Gas Cons, CommissiOn 'b'R-ILLI N6 DS 9-5 (PS) PLAN VIEW i i ,i~ ......... CLOSURE · 6744 ft at Azimuth 125.77 DECLINATION.' 30.24 E SCALE · ! inch = lO00 fe~t DRAWN ' 12/10/92 iiii illll, i ....l ...... Great Land Directional Drj]]jng ii j. i ~ ........ 500 0 500 <- NEST ' EAST -> I000 t500 2000 2500 3000 2500 4000 4500 5000 5500 6000 6500 Great Land Directional Drilling, Inc. Collision Avoidance Analysis Client.: Field..: Pad .... : Well...: PRUDHOE BAY DRILLING NSLOPE Drill Site 9 DS0951P Method..: Date .... : WellHd X: WellHd Y: Normal Plane 12/10/92 71s534.64 5942495.42 Comment: DS 9-51 1900 KOP (P3) Wells with minimum separation ~reater than 200 ft not reported. Ail depths are relatlve to the Dlanned well. Existing Well .... 100~ ........ 25, ..... Band Occurs at Warning-Band Serious-Band Closest Depths Enter Leave Enter Leave Point BKD MD MD MD MD MD D$0913G DS0914G DS0915G DS0916G DS0946G DS0947G DS0948G 189 5979 7266 85 2175 2176 1 2416 30 1 1 1 2678 148 2636 2647 90 103 103 3 1002 144 777 777 30 3 3 3 1548 E EIVED DEO 1 1 1992 Alaska 0il & (~as Cons. Commission Anchorage TOTAL P. 06 MUD PROGRAM- Well 9-51 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.5 Funnel Viscosity sec/qt ,-.300 <1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH 8.5- 10 8.5- 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/100ft2 10 rain Gel Ibs/100ft2 APl Fluid Loss mi/30 min pH -- Hardness m g/I 9.5-10.0 10 - 15 5-10 10 - 2O <15 through Kuparuk (6800' tvd) <6 in Jurassic Shales below 6950' tvd 8.5 - 10.0 NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAL' Swap out mud after drilling out intermediate cement. Baroid to mix 2-3% KCL blend (same as used for sidetracks) at plant and transport to rig. Return mud to Baroid upon completion of well. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel Ibs/100ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH 9.0-9.5 8-13 5-10 7-15 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales R[C[IVED 8.O - 9.O DS 9-51 Conventional 14:37 December 10, 1992 DEC I 1 1992 Alaska 0ii & 6as 0OHS. [,ommissir~,~ Anchorage Page 9 13-3/8" SURFACE CASING CEMENT PROGRAM - BJ Services CASING SIZE: 13-3/8", 68# CIRC. TEMP 40°F LEAD CEMENT TYPE: Cold Set III ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX #SACKS: 1530 YIELD:1.92 ft3/sx THICKENING TIME: 4:30 hrs MIX WATER: 10.5 gps TAIL CEMENT TYPE: Class G + 2% A-7, CaCI + I gphs FP-6L ADDITIVES: as required WEIGHT: 15.8 ppg APPROX #SACKS: 400 YIELD: 1.15 ft3/sx THICKENING TIME: 3 hrs MIX WATER: 4.95 gps. TOP JOB CEMENT TYPE: Cold Set II ADDITIVES: retarder WEIGHT: 14.9 ppg YIELD:0.96 ft3/sx MIX WATER: 3.89 gps APPROX #SACKS: 250 SPACER: 75 bbls fresh water ahead of lead slurry. CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two bow type centralizers spaced 10" and 20' above conductor shoe 4. Do not run cement baskets. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume 250 sx. EEEIVED DEC 1 1 1992 Alaska 0/1 & 6as Cons. Commissio~ Anchorage DS 9-51 Conventional 14:42 December 10, 1992 Page 13 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ Services CIRC. TEMP: 130oF SPACER: 50 bbls Arco Spacer, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2.0% A-2 + 0.5% Gel + 0.7% R-18 + 1 GPHS FP-6L WEIGHT: 12.0 ppg YIELD: 2.40ft3/sx APPROX #SACKS: 460 THICKENING TIME: 5hrs TAIL CEMENT TYPE: CLASS G MIX WATER: 14.2 gps ADDITIVES: .3% FL~52 + 0.5% CD-32 + 0.1% A-2 + 1 GHS FP-6L for 3-4 hrs thickening time. WEIGHT: 15.8ppg APPROX #SACKS: 440 YIELD: 1.14ft3/sx THICKENING TIME: 4 hrs MIX WATER: 4.84 gps CENTRALIZER PLACEMENT: 1. 1 turbulator centralizer per joint on shoe joints (2 required) 2. 1 turbolator per joint on every third joint to 500' above shoe(4 required) 3. 1 straight blade rigid centralizer every third joint from 300' below to 300' above Ugnu/Cretaceous (7289' md to 8801'md + 600' = 18 required) 4. 2 turbolators spaced out 100' and 200' above surface shoe (2 required) OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. CEMENT VOLUME: 1. Tail G slurry to 1000' md above casing point with 50% excess. 2. Lead slurry from 1000' above shoe to 300' md above Ugnu/Cretaceousr~,SJ;~)~ ~ ~ 2. 80' md 9-5/8", 47# capacity for float joints. ED DEC 11 1992 Alaska 0il & Gas Cons. Commission ~chorage DS 9-51 Conventional 15:05 December 10, 1992 Page 17 7" PRODUCTION LINER CEMENT PROGRAM- BJ Services CIRC. TEMP 140o F PREFLUSH: 75 bbls Arco preflush + 1% S-400 . CEMENT TYPE: CLASS G ADDITIVES: 0.8% BA-10 + 0.6% FL-32 + 0.2% CD-30 + 0.3% A-2 + 0.35% R-1 + 0.35% R-1 + 1 ghs FP-6L WEIGHT: 15.7 ppg YIELD:I .18 ft3/sx MIX WATER: 5.03 gps APPROX #SACKS: 185 THICKENING TIME: 4:15 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe (35 needed). OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME: , . 3. 4. 5. Open hole + 30% excess + excess for surface volume lost (adjust if a caliper log is run and it indicates severe washouts). 7", 26# casing capacity below landing collar. 150' liner lap 200' of cement on top of the liner in the 9-5/8" casing. Modify volume if caliper shows washout in 8-1/2" hole. RE. EIVED DEC 1 1 1992 Alaska Oil & Gas Cons. Commission Anchorage DS 9-51 Conventional 15:15 December 10, 1992 Page 22 DS 9-51 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRESSURE 1 4 3750 2730 Burst S.F. 1.26 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3750 1853 Collapse S.F. 1.22 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 3990 PBYS Tension S.F. 4.61 Mud Wt. 9.5 ppg TJYS 5.61 String Wt. (#) 231924 RE EIVED DEC 1 1 1992 Alaska Oil & Gas Cons. Commission Anchorage DS 9-51 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SrTP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8870 0.1 3818 Collapse S.F. 1.24 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 11517 PBYS Tension S.F. 2.38 Mud Wt. 10.2 TJYS 2.54 String Wt. (#) 456910 DEC 1 1 lgg Alaska Oil & Gas Cons. Commission Anchorage DS 9-51 Casing Design PRODUCTION LINER 7", 26#, 13Cr, NSCC Casing GRADE BURST 13Cr 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3512 3420 2,06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 9257 0.1 3984 1.36 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 719 Mud Wt. String Wt. (#) 10.0 15780 Tension S.F. PBYS TJYS 38.28 42.27 RECEIVED DEC 1 1 1992 Alaska Oil & Gas Cons. Anchorage I'~UD I - Choke Manifold - Poor Boy Degasser . - Brandt VacuumrType Degasser - Brandt Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge I'OIAL. ,¢C.'rlVEz Svs/',Eh': q', 'TO "~-- pIT . · rr~p/'" k I/I / w,-~[ r~ / --' I .I ~ -~ ' o o 2~0 8~c VI I t'1 , ', / / / ," /" " /'MUD DISTRIBOTION OlrC / ,' / t' / ~UD .. , ~ :. ~ ' . TO SrA~D p~,o~- PIT ,~,UD Kill __. .. · ! - Ree°rd±ng dr±lltng fluid, pit 'level ~Lndtcat0r with both ~tsual and audio warn±ng devices at dr±Zler's console ' ! - Trip Tank (75 BBL.) 1 - DrtZl±ng fluid flow sensor with readout at drtller~s console Il - 5 Hp Agitators NABORS 18 E 13 $/8" 5,000 psi Stack .5O 4.75 4.73 3.98 1 3.66 1.49 2.37 I I 2.21 I 0.55 KR TO RF RIG FI OOR 11.41 HYDRIL GROUND LEVEL PiPE RAM BLIND RAM MUD CROSS PIPE RAM l EMUD CROSS I SPOOL I l, k~ASE FLG/ 15.66 ~r 17.93 I ,f 22.96 ,f RECEIVED 26.45 28.25 3O.25 DEC 1 1 !992 Alaska Oil & Gas Oo~s. 6ommissiu,' Anchorage SL1F, "' HOLE DIVEFtTER SYSTEM Two lines venting 90 deg. ap::~rt in directions that ensure safe down wind venting, and ex- tending to a point at least. 100' Item any source of ignilion. 10' Full Opening Valves '35' or as required Dresser Sleeve 1. All pipe connections i 50¢. ANSi Flanges or welded conned, ions and secured to prevent movemenL 2_ Manual 10" full opening valves mechanically' r_~nnected to ensure that one valve is failosaie open at all limes. 10' Diveder Une 3. Ail tums ;~re g0 deg. and targeted. 1 O' Full opening ball valve w/Hydraulic Actuator 20' D[verter Spool w/10' Side Ou[le[ DE0 11 !992 Alaska Oil & 6as Cons, fJommisslo Anchorage MEM I/3/90 .¢ ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) L~ ~ (3) Admin E~¢] £9 -thru' 1~]" [10 & 13] [14 thru 22] (5) BOPE ~¢.~,'.~>'~r. [23 thru 28] Lease S Wel 1 ~ ¢z7~ YES 1. Is 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 & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is 1 ease n~mber appropriate .......................................... Does well have a unique name & nL~ber ................................ Is conductor st ring prov i ded ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor $ surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~Ooo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (8) Addl geology' enqineering: RPCz~ BEW LAG rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditiom~ ~sented... Name, and phone nLmber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE rema'r ks' ,/ 0 -I "rz Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special'effort has been made to chronologically organize this category of information. FIEbD ~,.~A~E : PRUD~()~ BAY BO~Ol.lg~ I NORT~ SLOPE AP1 ~UM~,ER : 50-029-223~0-00 ~FFEPENCE NO : 93033 IS ?erie Verif. tcat!on List~no chl.~ber(4et ~l, aska Computln~ Center 23-0;~N-1 q93 1D:05 ***:* REEf., })E,~DER **** DAT~ ~' 93/0J OPIGI~ : FL, lC ~E[, MAME., ~ 93033 P~EVIOUS RE~:L CO~MENT : ~RC0 ,AbASKA IMC.,PP[JDHf)E 8~Y,9 - 51,50-029-22320-00 TAPK NAME : 93033 C~KNT : ARCO ALASKA INC,,P~iDHO~ BAY,9 - 51',50-029-22320-00 PPUDHOE B~Y' U~IT wELL N~F,: TaPE CRE~T'ION 6~TE: JOB DATA OP~RATO~ WI"~ ' !.ESS: SURFACE SECTIOM: TOWNSMIP! ~LEV~TION{FT FR~< KELLY BtISHIMG: DERRICK FLOOR! GROTJ~9 [,EVIL: ~wbI., CASTMG RKCO~D 1ST STRING PND STmING G. $~RBER 15F., 1023 5136 54,80 53,80 25,30 OPEN HOLE C A S I ~.iC, DRILLERS [~.IT SlZ!:: i:I~:) S:IZE (Ir,l) t.~.K. PTH (FT) '~'~. 0 ..........:-,_ ;~.''''5 ;~';;:~'''4... PAGE: cblum~erger Al. aSK Computim.. Center 993 12: 05 ~. ~,.~,,,~ ~., , DLL TOOL CENT[~,~[,IZED WITH 4 1.5" TEFLO~'~ BO~EHOLE SALINITY : 26,500 PP~ CHbORtDES. CNL ~4~.T~.IX SANDSTONE, ~{OI.,.E CORRECTION : LOT C,ALIPE~. D:,.,NSITY ~..A].:RIX : 2 65 G/ C.,- FLUID DE~SII. Y - 1,0 G/CC, TENSION PULr,$ 0N ~IN ~N'~ RE'>' · PASS SO}.~E FLAT SPOTS O~:~. THE LOG FRO~'~ TOOL STICKING, $ FIb~;~ NA~E : EDIT ,001 SERVIC~ ~ FLtC VERSION : 00!A07 DhTE : 93/0~./23 ~X ~IC: SIZE : 1024. FIL~ TYPE : LO L ~ $ T F I L E ~ P A G E: EDITED CURVES .~11 t°ol strinos~ Depth shifted and clip~e~] curves~ al! runs meroed: no cased bole data. DMmTH INCREMENT 0.5000 FILM PBU,TOOL CODE ~',~SFL DI. S D N CMTM B-~sELINE CURVE. FOR SHIFTS: GR CUPVE SMIFT DAT~ (MEASURE~ DEDT~) ~SELINE DEPTH MSF'L 11936.0 11936.5 ~,!917,0 ~.. 1907,5 119n~,5 ! 1~B9 ~ !879,5 ?187~,5 ~ 1872.0 11B72,5 START DEPTH STOP DEPTH 11966,0 11407,5 11950,0 11406,0 11935,0 11406',0 .... -- .... E(,)II I V AI.,[~;N T U '~: ..... N,-~H I FTEI) DEPTH .......... SDN 1 ~.937.0 11880.0 CN T ~ !191.9.0 11S90,5 11885,5 115~0,0 11869,5 IS Tape Ver!~].Cat~on Listinq chlumberger ~!aska ¢omput!nc~ Center ~,I ..~ .0 11~00,0 t 1786. ,5 .~. 1786,0 .I: 1786,0 ! 1777,5: 11760'0 !. 1753.5 1 I754,0 i 1748,5 I t 749 , 5 17a7,5 1738,5 11738,0 11733,0 1. 1732.5 }i 720.5 11720.5 . 719.5 11700.0 }. 1693.0 1. 1684,5 11684.0 11673.0 ~. ~..649.5 t~ 16 4 0 ,. 0 ~'i' 1638,5 11638,0 !61.5.5 !1606.5 11595,0 I 1595,0 ~. 1583,5 11560,0 11531,0 11528.5 11527 0 11527..0 1 4 ,l: o !. 1. a60 5 .1 1404.5 11404,0 1 ~ 32~ O I ~.00.o 99,5 P~t; TOO!, COD~ PUN .11865.5 11788,0 1.1762,5 11749.5 1. t72~.0 1170 1169~ 11673.0 116~0,0 t1615,5 I1613.0 I 1561,0 I1527,5 11 ~ 71,0 1296 too'. 1177~.5 694.5 11651.0 1:1 115 .~ 158 ,¢. 0 11530,0 .04. , 113~o0 112 ~9.5 THE DEPTH ADJUST}~ENTS SHO~{~.! ADOVE ~EFLECT ~SFL TO GR (CARRYING ALI., OTHER DLL CURVES). ~HOF T~ GR (CARRYING ALL SDi4 CURVES) & ~P~I TO G~ (CARRYI~G Ab[, OTHER CUR VF. 8 ), 'lis Tape YerilJ,.catlon Listing chlumberOer laska Computt.nO Center ,, PAGE: ** DATA. FfD;:~aAT SE. ECIFICATION RECO;4D ** ** SET TYPE - 64E.B ** TYPE ~P:P~ CnDF VALUE I 66 0 ~ 66 0 3 73 84 4 66 5 66 6 73 7 65 9 65 11 66 12 13 66 0 1~ 65 F'~ I5 66 16 66 0 66 0 ** SET TYPE.- I D DEPT FT 590459 LL~ DLL OH~ 599459 LLD DLL OFM~ 599459 SD DLL ~¥ 599~59 G~ DLL GAPI 599459 TENS DLL L~ 599459 HTE~ DLL LB 599459 ~FI, DLL OFMM 599459 PUCF SDN G/C3 599459 D~Wn SDN G/C3 599459 OEP SDN BN/E 599459 C~aL1 SD~ IN 599459 ~TE~4 SDN DEGF 599459 ~ES SD~ OHM~ 599459 5!P~T CNTH PU-S 599459 C~aY C~T~ 590459 M~AT CNT~ 59945~ NCNT C~v~q CPS 599459 FCN? C~'TH CPg 59945~ CMTC CNTw CPM 599459 CWTC CWTq CPS 59945~ CH~ ** # LOG TYPE C O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 OOO O0 000 O0 000 O0 000 O0 000 CO 000 O0 000 O0 000 O0 000 O0 00o O0 O00 O0 000 mmmmm~m~m AP!: .APl I..,ASS MOD (,"~n 0 O0 0 O0 0 O0 0 O0 0 OO 0 O0 0 O0 0 O0 0 00 0 O0 0 OC O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 nO 0 O0 0 ~fB .$AMP ~[,F~ CODE. (HEX) 1 4 68 OOOO000000 ! 4 68 0000000000 1 4 68 0000000000 1 a 6~ 0000000000 ! 4 6~ 0000000000 .! 4 68 0000000000 ! 4 6° 000000o000 1 a 68 00o0000000 1 4 6~ O00000000O 1 4 68 0000000000 1 4 68 0000000000 ~ 4 68 000o000000 1 4 6~ 0o00000000 1 ~ 68 O0000000oo 1 4 68 O0000OO000 I 4 68 O00OO00000 1 d 68 O000000OO0 1 4 68 0000000000 1 ~ 68 0000000000 ! 4. 68 O0000000OO 1 4 68 0000000000 ;chlumbercter A.lssl~a Computi~q Center 2~-JAN-~ 993 ,1:2 ~ 05 G~.Dt,~,,, ' ,z999 50 T~,~S.~t.lt, ~25.000 ~,~T~'~,Dbb ~e9~.~lS' R~OB SON -99Q,~50 D~Mfl SDN '999,~50 PFfF,~'~'' - · ......... . ~.~.)~q 999.250 CALl SDN MT~.$.DN 164.454 :~RES,. SDN' 0.067 NPHI,. CNT~ -999.~50 CRAT.C~TH N~AT.CNTH -999.250 NCNT,CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNT~ CFTC, CS!T~ -999. 250 D~PT. 11900.0~0 ~)L~~ DLL 5.377 I,,LD.DLL 5 410 SP.DI,,L G~.,DLL ~22'006 TENS~DLL 6330.000 HTEN.DLb ~175~2.10 ~SFL.DLI, R~f3~ S[)~ 2.656 DR}"~.~'DN 0.063 PFF,SDN 3 676 CALl SDN ~RAT. C[~TH 3.0~8 NCNT.CNTH 2177.750 FCk~T.CNT8 704.625 CNTC.C~;T~ D E pT. 11800.000 ~.~ L ~. D 6 L 7 ~ 26 L I,,, D. D [,, i., 7.883 $ P. D L I,,, C~.D[,,~, 1,09.422 TENS. DLh 6210:000 HT~I. DLG 912.70~ ~0~' SDN: 2.571 [)P~O. SDN 0.0!4 P r. SDN 3.400 C~LI.SD~ )~TE:~.~ SD),~ I6~,1,92 ~ ~,, .... ,~.SDN 0.065 NPHI.CNTH~ 27.454 CRAT.CNTH · ~ ~ ~ ' ,, ~ ~,:~,[T.CNTH 2.702 NCNT.CNT}~' 2779 500 $CNT.C~,..,'H 1035 500 CN~,C C~TC.CYT~ 1021.875 .... ' ' DB~PT. X1700.O00 LL~.D[,[,, 8.088 [,LD :[)t,[~ 8033 SP C~ DLr,, 105 ~02 T~,,~,,~S.DLL 6175 000 ¢~TEU.DI,,L 845:942 ~SFL:DLL RHOB.SDt~ 2. 729 DR~O.SDN -0. Ol 1 ~TEU.SD~[[ 163.507 ~.~$. SDN 0,065 Npu'I D{ 4.215 CALl SDN ,. C~.~ ~ H ~6 719 CRAT ~ C~.~TH NRAT.CNI ~.t 2.811 NCNT. CNT~ 2330.264 FC~JT. C[~TH 770~241 C.~TC.~NTH CmTC. C~'~T~ 944,~94 ....... ~.DbL 93..307 TE~S,.DL~' 5905:0 0 HTE),I..DLL 830 11.6 ~FL DBl., PNOB,SDN 2,628 DRH[).SDe; 0,0C)6 P....,~.SDN 3 505 CALl SDN %~TE~. S[)N !63,408 ~RES.. SDF~ 0.065 NPNI,.C~TH 25 089 CRAT.CNTH [~'P ~T. CNTH 2.47~ NC~T.CNTB 2827.542 FCNT.C[*TH [074~413 C[ITC. C~IT~ C~'TC.CNT~ D~PT. 1,15oo 000 4L~.DLL 2.907 [,LD.DLL 4 265 "~P DLL 32:~5~ TENS.DLL 6085 000 HTEN.DL' 89~'774 NSFL DLL h'~O~.SDN 2.255 DRFO.SDN -0.005 PEF.SDN' ~.571 CAI.,1.SDN ~TF~'.SD~ 163.195 ~RES.SDN 0.065 NPHI.CNTH 27.002 CRAT.C~TH NPAT.CNTH ~.670 NCNT.CNT}I 2891.500 FCNT.CNTN ~069.0Q0 C?TC.CNTM CWTC.C~TM !151.375 DEPT. 11406.000 LL". DI.,[~ '999.~50 I.,I,D. DLI~ -999.250 SP.DLL GP, DL[., 43.305 TENS.DLL 5970.000 MTEN.DLL ~78.030 MSFL.DLL ~HO~.SDN 2.2~0 DRF~O. SDN 0.049 PEF.SDN 6.875 CALl .SDN ~TE~. SD~ 161.120 URFS. SDt~ 0.065 NPHI.CNTH 27.725 CRAT. C~,~TH N;~T.CNTM 2.9~fi [~CNT. CNTI'{ ~737.438 PCNT.CNTg 556.625 CNTC.C~Tg C~TC. C~,~Tg 571.563 q99,~50 · ~g9. 50 999,250 :990.250 999,250 -24,36:7 5'584 8,625. ~,867 2122,285 -18.78.! 6,672 :s9 7 '~,676 ,974 8,596 ~.572 2424,743 I. .627 8.537 2 46 '1~:439702 8.419 2.534 2833.250 -35.511 1.941 9.590 2.773 1629.125 IS Tare Verification [,i, stJ,,ng cblumberoer Alaska Computin~ Center 23-JAM-!993 12:05 PAGE: **** FII, E TRAibEP SF~VICE VF~SION ~ 001~07 D,~T~ : 93/01/~3 ~,~X REC SIZE FI}5~ TYPE LAST FII, E **** FIL .... }~EA[,')~ **** F!L~ NAME : EDIT .002 SERVICE : rhIC D~T~ ~ 93/01,/~3 ~ ,,, , ,~ , FIb~ TYPE : L.O LAST FILE : FI[.,~ HEdgER FILE NUMBER 2 RA!~ OPeN HOLE MAIN P,~SS Curves and log hea~er data,~or e~ch ,run and tool strino in, seDarate ~iles; Tool,Strino ~1 ~o ~$adl. erochIt ru~ nresented ~irst (primary depth control strino used to depth Shift the 6adler interval) followed by files for other main DOSS strings Der run. TOOL STPIaG NUMBER: D~P~M IMCRE~EMT: 0,5000 FIbF SUa~i!~.RY UENDO~ TOO[, CODE START DEPTM 1.!920, 11935.0 1!947,0 I,.DT DLL $ # OATE LOGGED: SOFTWARE VERSION! wI~E CTRCIIL~TION ENDED: TI~ I,OGGER gU BOTTOm: WD D~ILLKR (FI): TD LOGgED(FI): STOP DEPTH 11406,0 11406°0 11405,0 la-JAN-9) 5C0-423 ~300 17-JAN-93 510 18-JAN-93 ~1990,0 11982.0 chlllmber~'er Alaska Comp,]tfnO Center .. 23-dAN-lgg3 1.2:05 LOG '!NTERV,AI, (VT)- T 0 ? ..... BOPTOI,~ LOG I~'tTE~VA5 q'OOL STRING (~.OP VENDOR TOi3b CODE TOOL 1 I406.0 1.!965..0 TCC T~iLE~,~'ETR Y CARTRIDGE C~(I, CO~PENSATEO LDT ~UCLEAR SOURCE LOT DE~S/PESISTIV D 1, I., D U a L L A T g R 0 L 0 G DLL DUAL Ot, L DUAL DRILLERS CASING D~PTH (FT)I LOGGERS CASING DEPTM BORE~OLE CONDITIOM'8 },'~UD TYPE: ~'UD DEMSITY (t,B/G): vUD VISCOSITY ($): ~'UD Ft'U:~D ness ec~): RESISTIVITY (0~) AT TE~'IPER.~'TURE ~!]D AT NIE, ASER~} T'E~iP~ATURE '~UD AT BOTTO~I HOL~ TE~!PERATURE uUD FILT~AT~ AT ~UD VILTRATE AT (BWT): uUD CAKE AT ~[..ID CAKE AT ~:~ EUTRO~,~ TOOL TOOL ~YPE (F',PITHERMAI~ OR THERMAL): U~TRIX: ',~ATR IX DENSITY: ~OL~ CORRECTION (IN): TOOL STAX~'DOFF (l~~): B S P E A TCC-B 281 SGC-SA 50 C~..;C-HA 398 ~ISC- g 801 DRS-C 4908 DI.,S-,D 761 S~ E'-F 975 8~8-D ~35 8,500 111417 1404; S,90 42,00 1:0.90 5.20 165.0 O,le7 0,1.6.3 0.323 THERMAL SANDSTONE 9.,65 66'.0 66.0 66,0 SP CURVE RECOPDE[.',, ALIT blOT PR.F..SEt!TED AT CLIEt4TS REQUgST BLL TOO!, CENTm,~LIZED WIT~ 4 1.5" TEFLON STAM~0FFS, ?,ORM~OI, F SALINITY = 26,500 PP~ CHLORIDES. CNL MfiTRIX SANDSTON%~, HOI.,~ CORRECTION = LDT CALIPER, DF~M!TY HATRIY = 2 65 G/CC FLUID DEM$ITY = 1.0 G/CC. TE~!$IOH PULLS ON ~!N ANn ~PET~T PASKES REsuLTED !N S[I~qE FI,AT SPOTS O~! TNE LOG FPOt~i TOOL STICKING. ,IS ?ane Yerification !,istin~ ch,!u~her~er Ala...,~'~a Comp,~tinQ Center # LIS FORMAT DATA 23 -' d A .N - 1993 12:o5 ** DAT_~ F[1R~AT. SPECIFiCATIqN~, RECORD ** ** SET TYPE - 64F. B ** 1, 66 0 2 66 0 3 73 ~:20 4 66 5 66 7 65 ~I 66 4 !) 66 0 14 65 FT 15 6S ~6 66 0 66 ~.. ** SET TYPE -~CN~N ** ........... . . ID ORDER ~ bOG TYPE ~L DF:PT FT 599~59 O0 000 O0 LLS Obi, OHMM 599459 O0 OOO OO LT.D DLb OHM~ 599459 O0 OOO OO C~LS ~[..,[, lin 5994.59 O0 000 O0 CaLl ?)LL iN 599459 O0 O00 OO CALt Db!, IN 599459 O0 000 O0 SP DLL ~V 59~99 O0 000 O0 G~ ~L[, C~P! 5g0159 O0 OOO OC T~NS ~b!, LB 500459 O0 000 O0 ~T~ 9L~, D~GF 599~59 OO 000 O0 ~DF~ DLL OH~4~ 599459 O0 OOO O0 ~T~ 95[: L~ 599459 O0 000 00 ~S~l, DLL r)~, 590~5q O0 000 O0 S~I~ DLL OgPU 5994S0 O0 000 O0 SU~O DI,[., OPuu 599459 09 OOO O0 ODHT bDT PU 59945o O0 000 O0 ~0~ [.,UT G/C3 590459 O0 000 O0 DPnn bDT G/C3 599459 90 OOO O0 pFw ~,PT 599{59 O0 009 O0 0 2 I 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 ! ~ 4 68 0000000090 0 2 1 1 4 69 0000000000 0 2 1 1 4 68 0000000000 0 2 1 t 4 68 0000000000 0 2 I 1 4 68 000000000o 0 ? 1 1 4 6~ o0000000o0 o 2 ! [ 4 6a oooooooooo 0 2 I I. 4 68 9000000000 0 2 ! 1 4 68 oo0oono000 0 2 I 1 4 6~ 0000000000 0 2 ~ ! 4 68 O000OO00OO 0 2 { 1 4 68 0000000000 0 2 1 ! 4 68 O000900000 0 2 1. 1 4 68 O00000000O O 2 1 1 4 68 OOO0000000 0 2 ! ! 4 68 000o000000 0 2 1 1 4 6~ O0000OOOOO ,IS Tape Verification Listing ~cblU~beroer Alaska Comptltin~ Center 23-JAN-1993 12:05 PAGE: ORDER ~ I.,OG TYP O1,$ LDT 5994~9 O0 0.$S LD? 599/.1.59 00 LS LDT CPS 599459 00 I,U LDT CPS 599459 O0 LL LDT CPS 599459 O0 LITH L~T CPS 599,4.59 O0 SS2 LDT CPS 599459 O0 [$~tV LDT V 599459 O0 SS~:{V LDT V 59~459 00 $!RR LDT G/C] 599459 O0 LSR~ BDT G/C3 599459 O0 LI!RF LDT G/C3 599459 O0 C.[ [;T LDT I'N 599459 90 CAL~. bDT IN 599459 O0 TENS LDT LB 599459 00 b~TEE LDT DEGF 599459 O0 MRES bDT OHg~l 599459 O0 ~TE~:~ LDT LB 590459 00 ~,~PH ! C~L P[,I 599459 O0 R T ~.:;~ P CNL 599~,59 TNP~ CNL PU 599~%59 ,v~,~, a C, NL 599459 O0 N~O~ CNL PU 599459 O0 RC%~T CNL, CPS 590459 O0 ~CFT C~"L CPS 599~59 O0 C%~TC CNL CPS 599459 O0 C~TC C?~ [,, CPS 599459 OO GP C~L GAP'[ 509459 O0 C~L! CNL I~'t 599459 90 C5 !.,S C :'~ L IN 599459 O0 TENS C~,'L LB 599459 O0 ~REg CNL OHMM 599459 O0 ~TE~' CNL I_,B 599459 O0 ~II~iI~ 000 O0 0 2 000 O0 0 2 000 O0 0 000 O0 0 2 000 O0 0 000 O0 0 OOO O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 000 O0 0 2 000 O0 0 000 O0 0 000 OO 0 2 OeO O0 0 2 000 O0 0 2 000 O0 0 000 OO 0 2 009 O0 o 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 000 O0 0 000 O0 0 2 000 O0 0 2 000 O0 0 2 O00 00 0 2 O00 O0 0 2 000 O0 0 000 O0 0 2 000 O0 0 2 000 O0 0 000 00 0 2 1 1 1 1 1. 1 1 ~,, 1 1 1 1 1 1 ! .,-,. ., t 4 68 O000000OO0 I 4 68 OOOO0000OO 1 4 6~ 0000000000 1 4 68 0000000000 ! 4 68 O000OO0000 I 4 68 0000000000 1 4 68 CO00000000 1, 4 68 0000000000 1, 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 oeo0000000 t 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 ! 4 69 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 6~ 0000000000 1 4 68 0000000000 1 ~ 68 0000000000 1 4 65 0000000000 1 4 68 O00000OO00 1 4 68 0000000000 ~ 4 68 O00OO00000 1 4 68 OOOOO00000 17010.000 9.679 2390. 000 7.324 2.7Ol 0.064 3~, 1.50 1.332.895 R.679 ]64.4.54 3.892 !.,Lb. D[,L 3.881 CALS.DLt, 7.123 SP.DLL -20.000 G~.DBI, 164.454: FtRES. DLL 0.067 HT~IN. DLI, 0.824 $ ~, t.l O. D.t,., L ! .739 DPHI. I.,DT 0.066 PEF. BDT 28.938 OI.,S. 1,9T 164.141 [.,l~. LDT 1.48.5o9 LL.LDT ~84.409 SS2.LDT ~30.~5~ LSHV.LDT 2.577 b,~R H. [,,DT ~.7~5 LUE~.[,DT 7.123 ~. [,,CT 77.829 0.067 ~TEW. [,.9T -130.520 NvNI.C~I, 8.146 77.820 -130.520 -8.532 0.277 89.887 1454.367 2,831 2390,000 31,659 I$ T~v~ Veri, fJ-¢atlon Ltst:i.n~J chlumber~er AlasKa Comvutin~ Center RC'NT.CNL 3367.507 RCFT.CNL <; ~. C N' L 77,8 ~ 0 C o ? p T. 12 O 0 O. 0 o 0 t, L g. D L b C aLI. DL~I,.~ 8.679 C~L,I.DLL T~ts~8. ~bL 4070. 000 M~F'L, DJ.,5 7.459 R~'t[I¢. LDT 2.79!, DRHO. LDT OSS.LDT 0.06~ 5S.LDT LITR. LDT ~6.150 SSI. LDT SSHV.LDT 1332.895 SIRH-bDT CAL!.[,DT ~.679 CAI,.,1. L~T MT~),~. LDT I64.454 MRES..LDT R T N ~, C 5) ~, 3.000 RCNT,CNL 3367.507 RCFT,.C~L G P. C ~ h 77.8 ~ O C ,a L I. C ~.~ L M~E~.CNL 0.067 ~TE~.CNL E ' n ' D,..~PT 11900. Oa bLS DLL ~ I ~ ~ ~ ' ' ~ C ,~ L . D b [,,, 8., 14 C A ,[,, 1. D h L TENS, DI;.,L 6330,000 MTEM,DLL ~,SFt,' OLL 4,.804 RHOB.LDT 2 654 D~HO.LDT OSS. 5, DT 0 ' .039 hS. LBT I., T T~, LDT 47 · 296 SS 1 , LDT SSHV.LDT 1,332,583 SIRH.LDT CALI.LDT 8.914 C,~I~ 1 .LDT f4TE~. LDT ]6.4.355 MRES.LDT ~TNP.CN5 2.967 TNPH.CNL RCNT.CN5 2206.965 RCFT.CNL G~.CNL, 12~.006 C[LI.CNb ~PE~. CN5 .067 DEPT. 1 ! 809.000 BLS.DLL C~,LI.DLL 9.70,I C~Li.OLh TENS.DLL 6210.000 ~4TE~I. !)LL MSFT,.DLL 5.655 ~HOB.LDT 2.651 D~HO. I,,DT OSS.LDT 0 013 LS.LDT LIT~. BDT 45: 793 SSi .LBT SSHV.I,DT ~333.416 CgLT.LDT ~.794 CALI.LBT ~TE~. LDT ~ 64.19~ ~RES. ~T'~.CN[~ 2.970 TN~H.CNL ~CNT.CNL ~510.247 RCWT.CN5 GR.CN[, 109.422 C~[,I.C~L ~$.CNL 0.065 ~4TEi~. CHL DEPT. ! 1700.000 LI.,& Ol.,I., CaLI.DLL ~.520 CALI:DLL TFNS.DI, L 6175.000 ~qTE{-I. l>I,L ~SFL.DLL 7.5~9 St~IN.DLb ~HOg. I.DT 2. 491 02.4,55 CNTC.C~L 8.679 CALS.CNL ~64. 454 ~TEN 3.~92 LLD.DLL 7 12] 164:454 MRES.DL5 0.835 SMNO.DbL 0. 066 PEF*LDT 164.1. 41 LU.LDT 184.409 'SS2.LDT 2.577 hS~H.LDT .7,123 G~.SDT 0 067 HTE:q, LOT 102 4 ~ 5 C 8:6,9 CALg,C~tL I64'454 ~,!TEN,C~{L ~.I~3 LLb,DLL . 5 164. 355 ~RES. DLL ,D L L 2 0 ~ 59 L ~,]. b D T 192.656 SS2.bDT 2.442 I.,S¢~.BDT 30.740 TN~.CNL 729.603 C~TC. CNL 8.914 C~LS.CNL 164.355 HTE~,t. CtvL 7. ~ 15 8 625 S~.DLh 164:192 ~RES.DbL 3,96~ S~NO,DLL 0,041 PEF,~DT ]. 93.903 LU. LDT 186.O87 SS2.LDT 9.505 LS~H.SDT 8.625 G~.BDT 0.065 ~TE~.LDT 30.~59 TNRg. CNL 805.426 CNTC.CNL 8.794 CAL, S.C~L i64.19~ HTF~'. CNL 8.065 LLD.DLL ~. 504 SP. DLL 163.507 2,906 SHNO.DLL 0.01~ PEW.LDT 2,864 3234,589 ~ :146 3 -2o2ooo 0.067 1,.766 3.979 ~48.509 230. ~.725 77.82O - 136.043 2. g 64 3234. 589 ~.146 -136.043 5 099 0 067 3,828 198.746 ~55 122.006 ~75.210 2. 907 21~6.798 8.708 1175.210 7. ~ 47 -18.438 0.065 6.249 191.475 255..4,86 ~.6]o lo9.422 2.70] 912.644 2476.650 8.72~ 912.703 -2.500 0. O65 5.~46 4.238 CFT'C.C~L TE?~'$. Cat, S. DLL GR. DLL DPHI.LDT QLS. LDT L5. LDT t, SHV. LDT TE~S. LDT PJ P H I. C ~ L CFTC.C~JL H T ~:~. DLL DPH I., LDT OLS. 5L. LDT h 8 ~'t V. L, D T LURH. LDT TENS. bDT NPOR. CNI,, CFTC. CNL TENS. C~{L C~bS. GR. PhL ~TE~'. DLL DPHI.LDT O!,,S. LDT LL. LbT LSHV .LDT btJ~. LDT TEUS.LDT NPHI.CNL CFTC. C~ L Tgh~S.CNL CaI,S.DLL GR.DLL HTYh7. OLL DDH I. QLS. LDT PAGE: 10 1139.250 2390.000 8 146 77i820 -1360~3 -8.532 0.277 89 887 1454:367 2 831 40]01000 1.659 32.197 1139.250 4070.000 8.708 122.006 :t175.210 -0.236 '0,012 100.886 1454.946 2,597 6330,000 32,016 30.700 767.89~ 6330.000 8.728 109.422 912,703 -0,091 0.005 98.~66 1456.2~6 2.6~0 6210.o00 28.209 31.185 912.761 6~10.000 8.716 105.402 ~45,942 9,6~3 0.005 Veri, icati. o cblumberqer ComputIno Center OS$. LDT 0,058 LITH.LDT 54,33I S SHV.LDT 1333,.902 CAL~ .LDT 8,,520 MT~,. bDT 16~. 507 RTN~. CNL 2. 256 RC~.C~L 33~8.013 ~PES. C~ b 0. 065 D~T. 1 {. 600.000 T ~ ~ 8, D b b 5905.00 () ~';,~ FY, ,. ~ L b 11., 945 HO~.LDT 2. 624 POSS. LDT O. 002 b :Y T H. L D T 47.060 $~I-{V.LDT 1333.717 R ~. CNL 2.478 RC~'T.CNb 2822..5~2 G~.CNb 93. 307 ~I~ES.CNL 0. 065 DEPT. 11500,. 000 C,~L,!. DLL 8,424 TENS.D[,,L 6085.000 gWOB. LDT 2.233 OSS.LDT 0.013 LTTP.LDT 109.:122 SSHV, LDT l 333,638 ~T~ ~,,. t, DT 163.195 RT~.CNI, 2. 823 ~CNT. CNL 2869,.933 G~,CNL 32,351 MRE~. CN!., 0. 065 DFPT 1140,). 000 CaLI: DI.,[., ' ~ .636 ~HOg.LDT t.950 css. -o.135 [,IT~.LDT 14.197 SSHV.LDT ~334.614 C~LI .L~T ~ .636 ~T~.LDT 160.641 32. L, $. L D $ S 1 :. I,,D T S i RH, bDT TNPH. CUL, RCFT.CML LbS. DLL CAE~. DLb ~TE~. DLL S ~' I N. D L b DPHO. LOT LS, bDT SSi.LDT S 1, ~ H, t, D T ~RES, bDT TMPH. CNL RCFT CALl C~L .~TEM CNL L 5 S, D L b C ,t L 1 ,. D b L ~MTEM. DLL DRH, O, LDT I..$, 'LDT S81 . LDT S~RM.LDT CALl .bDT ~ES.. LDT TNPtq. C N I,,, CAI,,I.CNL !,LS. DLL CAL 1 . [>LL ~"CE~. DLL SMI N. DLL DRHO. LDT LS.LDT SS ~. LDT S~RH.LUT CALl .bDT '~RFS. LDT TNPH . CML RCFT. CML CALI .CNL 23-JAN-!99? I2:05 ~ 3:6 . 508 b U . [., D T 186.678 2.430 t,, $ R ~{ ,, b D T 8,504 GR... LDT 0.065 MTEN.LDT 180t.24,1 CMTC.C~'L 8.520 C A L $ · C N L 163.507 ~T E~. CN; L 14.63 ~ L L D. D l,,, L 8.537 SP. DLL 1~3 408 NRES.DLL 0 ?06 PEF.,LD~q,T 8.537 0.065 HTEN,LDT 1,074.41 ] CNTC,CML 8.924 CALS.CNL 1.63,408 HTEN.CNL 2. 850 LLD. ~.419 SP.DL5 163.I95= 8. 059 $~NO'DLL '0.0~5 PEF'LDT 5 190 75 SS2.bDT 2.,~50 bSRH bDT 0. 065 L ~... 27.~33 Ttiaa. C~Ib 1114.412 CNTC.CML 8.424 C,ALS.CNL 163.~95 HTEN.CNL 0.!55 LLD.OLL 8.602 SP. DLL 160.641 NRES,~LL 0.236 8'.~NO. DLL '0.922 PEF.LDT 130. 463 [~U. bDT 51.590 SS~.LDT 4.80~ bSmH.LDT 8.60~ GR.bDT 0.065 HTEN.LDT 31.612 TC:~ ~.CC~L 569.130 C~',TC.CNL ~.636 CALS.CNL !60.641 227.175 248.792 2.479 105 .aO 2 845.942 2 . 18,4 3125.284 8.7 t 6 845.942 la.149 -7. :563 0 065 15,'552 3.541. 192.788 245753 2i618 93 3O7 8 30.1. '16 2.:446 2698. 355 8.736 830.116 4 1.84 -14 56.3 0 O65 7 392 2 950 33:6.605 283.669 2 .23 ~ 32.351, R99.774 9.567 2753 180 ' 8:539 899.774 0.431 -85.125 0.065 0,. 183 23.224 t. 37.738 8a.276 2.872 32.603 907. 686 2,9~2 1587.807 8.820 907.686 bi... bDT LSHV. LDT LURH. LDT TE~$. LDT NPOR: CNL CFTC.CNY TEN $. C ~L C,ALS DLI., DPH I. LDT OLS. bDT LL.LDT LSHV. LDT L U R H. L D T T~ ~. LOT ~IP?I I. C~L NPOR. CML CFTC.CNL T Ei<~ $. CN'L CALS.DbL GR.DLL HTEN. Dbb DPHI. LDT Qi.,S. LDT Lb. LDT LS~V. LDT bURH. TENS.LDT NPOR.CNL CFTC.CNL T~NS. CNL CALS DLL ETE~.DLL ~PhI .LOT OLS.LgT LL. LgT LSHV .LDT LURH. TE~S.LOT NPHI.CNL CFTC .CNL TENS.CNL PAGE: 122.920 1457.103 2.496 6175.000 21,656 17.381 1651,034 6175.000 8.736 93.307 830.1,16 .I,597 0.023 95.767 985 5905.000 25.089 24.981 ~1~8.822 5905.000 8 32! 51 899 74 25.258 -0.027 190.79~ 1456.477 2.243 6085.000 27 509 2721 8 1097.485 6085.000 8.820 32,603 907,686 42.444 -0.035 61.594 1457.60~ 2.903 6075.000 3~.4~.9 32.513 567.052 6075.000 ,IS Taoe~ Vertf!cation :chlumberqer i%.laska ComputlnO Center 576 CAL1.DLL 6015, :000 ~ T E ~'i" D L b !.122 SM'IM,DLL 2,036 0RHO,LDT '0,093 LS.LDT 14.238 SS1.LDT 1334.873 $1RH.LD~ 8,576 CAL1.LDT 1 58. ~5~ ~ ~".8 .bDT 4.190 T~aPH, C~L J341 944 RCFT. C~7;, 1. 120 o. 00 o [, L $' ~ L b 8.573 C ~ I~.' 1 .. D L L 5775.000 ~ T E ~. D L b 0,700 SMIN,DLL 2. 079 DRHO, bDT '0,095 LS'LDT t, 1 . 8S2 SS LDT 8.573 C A t., 1. L P t 156.721 ~ES,LDT 3,975 TNPH,CNL 1351.37,4, ~CFT, C~'t.~ !08.061 CA, I.,I. C~L I 1190. 500 LbS. DLL ~.575 CALI.DLb 5~5.000 -999,P50 SMIN.OLL 2,155 D~HO.LDT -0,112 LS,LDT 13,577 SS1 .LDT 1335,167 SI~.LDT ~,575 CALl ,LDT !56,510 S~ES,LDT 4.410 TN~q. CNL 1335,9.29 RCWT,CNL ~ 2~,:1.64 C~LI.CNL 0,067 ~tT~M, C~"L ** END OF DATA ** .; 23-JAN-I993 12;05 0.152 l.., L D..D L L 9 '~04 SP.DLL 158::~53 :~RF$.DLL 7.536 L U. D T 55.807 S82. bDT 4.653 bSRF{, bDT ~. 604 G~. bDT 0.066 53,:~98 TN~,CNL 282.,454 CNTC.CNL 8,576 CA.LS,CNL O. 1,46 LbD DLL ~. 6 o $ s 156 721 ~R~:S.DbL T 0.862 P E'F ,':b D T ~. 19,594 !, U, h D T 54.744 SS~.LDT 4.713 8.605 G R. [, D T 0.067 HTEN.LDT 333 [ 453 CNTC. CNL 156. 21 HTEN. NL O. 150 LLD.DLb ~.596 156.510 MRES. DI.,L =999,250 '0,~13 PEF,LDT 123 ~40 I,,{.I. bDT 4.670 LSat,bDT 8,596 GR, bDT CNTC.C , .57s 156.5 o 0 6637 0.066 0,,179 20. 348 1,34 0218 86.' 54 2.892 105.537 845.328 4,084 1267,298 8. 831 845' 328 0 658 0.067 0.184 41..:041, 126,698 8 3.680 2.94! I08.06~. 8'1~ .gO6 3.790 13 ~. O, 490 8 820 878:90,6 0.680 -120.188 0.067 -999.250 1,9.917 130.~47 87.896 2.969 128.16q 903.799 3.~7~ 1296.613 8.820 903.799 CALS.DbL G ~: · HTEN . DLL DPHI .bDT O.LS, bDT LL. LDT L $ t'{ V, L D T TENS. bDT N 9 ~ I. C N L CFTC. TENS.CN'L C A I., S. D b, L GP. Dbb ~'TEN DLL ,DPHI ;:bDT Q[.,8, bDT LL. LDT LSHV. bDT LU~H . LOT TENS. bDT N'PH l. CN'L NPOR.CNL, CFTC. C ~ b TENS.CNL Ch[,,S.DbL GR.DLL HTEN.DDI,. DPHI,LDT OLS.LDT Li,,.LDT LMHV.!.,DT LURH,LDT TENS.bDT NPHI.CML NPnR,C~'~L CFTC.CNL TE~$.C~5 PA6E: 12 8,831 1,05537 37o185 427 1459.476 2,929 601.5,000 53~791 52.339 306,812 6015,000 8,820 108.061 878,906 34,604 0.003 56.:245 1459,855 2-990 5775,000 48.411 ~8.841 3~0,755 5775.000 8.820 128.164 903.799 29.971 -0.060 58.267 1460.163 2.982 5885.000 49.941 48.533 349.537 5885.00O , . c~!umi, er~er laska Con, out. ino Cemter' 23-JAl'~-1993 12:05 PAGE: **** FILE TRAIBEP **** SERVICE : rt, IC [.).~ TE I 93/01/23 **** FILE HEADER **** F'ILF NA~E : EDIT ~ ~::~SlON : oo1Ao7 DaTF : 9~t0~I~ F'i'LE TYPE : LO FISE ~EADER Ra~i OPE~ 8OL, E REPEAT PASSES Curves and log header data for each pass, tool stri. nO, amd run in separate ~lles. RUN ~UNBER: TOOL STRING D~PTH ~NCR~NENT: 0,:5000 FILE Stl~aRY VENDOR.TOOL CODE START DEPT~ C~ 1,~920,0 C~L 119~5,0 !.,PT 11947,0 DL[, 11964.5 HEADER DATA DATE LOGOED; SOFTWAPE VERSION: T!~E CIRCUI, ATIOM ENDED: TI~E LO~GE~ ON BOTTO~: "'D DRILLER (FT): TD LOGGEq(FT): TOP LOG INTEPVAL (ET): POTTO~ LnG INTERVAL [ET): r,OGGING SPEED [EPHP): $ T.O P D E 11406,0 11406.0 !1.406.0 11406.0 TOOL, STRING fTOP TO BOTT051) VENDOR TOO!,, Cf~DE TOOL TYPE ' ................. SP gD N ~'~0 U S PO'I' E I~' T I A [., 1P-JAN-g3 5C0-423 2300 11990.0 1.1992,0 1~4~06.0 ~!965.0 1800.0 17-dAN-g3 18-JA~-93 TOOL NUMBER -.;:;-;, .... ~tS .P A. ,]cs ?a,~e veri,~iication l,,istin~ ;e,hlumber~er A,!ask~a ComputinO Center 2~-JAN-II. 993 12:05 q"CC G~ Lr>T D L L $ G.a,~.~ A ]RAY GA~A RAY COMPENSATED N U CL~,'B f~ SOURCE D~'t;$,/~ESiSTIVITY DU.~L LATE.~OLOG DUAL I,,ATEROLO~ DUAL LATE~OI, O~ SGC-$A 50 CNC-~A 398 ~SC-E 801 DRS-C 4908 ULS-9 761 SRE-F 975 OPF~!' H'f')LE BiT' SIZE (I,N):' , ','c . ] ' ' ,' D~II,,,L%R,;~ C.aSI~G DEPTH (FT): LOGGERS CASING D~PTH (FT): B['~pEHOLE CONDITIONS MUD TYPE: ~UD DE~SlT'Y (LB/G)1 r~UD vISCSS~TY ($): ~UD NAXI~UM RECORDKD TE~pERATURE ~ES.!STiVITY (OH~N) ~T TEMPERATURF~ ' '~UD AT ~EASU'RED, ~E~:PEBATU~7 (~T.):, ~UD AT BOTTO~ t~Ob,E TE~PERATORE. (BHT): ~UD FILTRATE AT (~T):, ~UD FILTRATE AT (BHT): ~UD C~K~ AT NEUTRO'N TOOl,, TO[iT,, TYPE (EPITHERMAL OR THER~AI.,~)~ MATRIX DENSITY~ HOLE CORRECTIU~; (IN): TOOL STA~,IDOFF fIN): 8,500 11417.0 1~.404,0 8~90 42.00 10'90 5.20 165,0 0 , :{, 87 0,!.63 0,323 SANDSTONE 66.0 66.0 66.0 PE;,~ARM'S: SD CURVE RECORDED, BUT NOT PRESENTED AT CLIENTS ~EOUEST DbL TOOL C~NTP~.LI~ED WIT[~ 4 1.5" TEFLO~ STANDOFFS. BOREHOLE SALINITY = 26,500 PP~ CHLORID~TS CNL ~AT~IX SAWDSTflNE, HOLE DENSITY MATRIX ; 2 65 G/CC FLUID DE~SITY : ~.0 G/CC. TENSION PU[,LS ON ~IN ,aND ~PEAT PASSES RESULTED S~E FLAT SPOTS ON TM~ [,,0~ FRO~ TOOl, STICKI~G. LIS FOR~.~T DAT~ chlumberqer'A,laska Computin~ center 23-JAN-ID93:12:05 1.5 ** DATA F[)Ri':~AT SPE'CIFIC~TION RECORD SET TYPE - 64EB ** TYPE REPR CtlPE V~LUE: 2 66 0 ~ 73 22O 4 66 ! 5 66 6 73 7 65 S 68 0.5 9 65 ~T 11 66 4 12~ 6~ !3 66 0 ~5 66 6~ 16 66 !, ** s~:? TYP~ - CU~ ** , N~E SERV UNIT SEPVTCE ~PT ~pl' ~Pt AP~ FI'bE NtI~ ~g'~ SIZE REPR PROCESS 'ID ORDER # LOG TYPE CLASS MOD NUmB $~MP, ELEM .CODE , (MEX) DFPT FT 599459 O0 000 O0 0 3 ! ! 4 68 0000000000 LL8 DL9 OHg~ 599459 O0 000 O0 0 3 1 l 4 68 0000000000 Lt, D Db~ e .... ' ~, ' .... ,,,~MN 599459 O0 000 O0 0 3 1 I 4 68 0000000000 CAL8 D[,,~ IN 59945g O0 000 O0 0 3 ! I 4 68 0000000000 CALl DLP IN 599459 O0 000 O0 0 3 ~ ! 4 68 0009000000 CaL! DL~ IN 599450 O0 000 O0 0 3 ~, ! ~ 68 OOOO000000 SP DL~ MV 599459 OO OOO O0 0 3 1 I 4 68 O000OO0000 GR DL~ GAPI 599459 O0 000 O0 0 3 ~ 1 4 68 0000000000 TENS DLR LB 599459 O0 000 O0 0 3 ! I 4 68 gOO0000000 ~TE~ DLR DEGF 599459 O0 OOO O0 0 3 1 1 4 68 O000000OO0 M~E$ Db~ ON~ 599459 O0 000 O0 0 3' ~ 1 4 68 gO00000000 HTE~ DL~ LB 599459 O0 OOO O0 0 3 I 1 4 68 O000000OO0 ~SFI., DDR ONM~ 599459 OO 000 O0 O 3 ! 1 4 68 CO00000000 S~IN 9LR 0~ 59945Q O0 000 O0 0 3 ! 1 4 68 0000000000 SNNO DLP O~MN 599459 O0 000 O0 0 3 ! 1 4 68 0000000000 DDMT LbR PU 599459 O0 000 O0 0 3 ! 1 4 68 0000000000 ~OB LDR G/C3 590450 O0 000 O0 0 3 1 1 g 68 O0000OO000 DPHn L,D~ G/C3 599459 O0 000 O0 0 3 ~ 1 4 6~ 0000000000 PEF LDR 599459 O0 OOO O0 0 3 ~ I 4 68 O000OO0000 gL$ LDq 5Q9459 OO 000 O0 0 3 ! 1 4 65 0000000000 Q$$ t,D~ 599459 O0 000 O0 0 3 ~ 1 a 68 OOO000OOOO [,$ LDR CPS 599459 O0 OOO OO 0 3 ! 1 4 68 O00OO00000 L[~ l,~R CPS 599459 O0 000 O0 0 3 1 ! 4 68 0000000000 LL LU~ CPS 599459 OO gOO O0 0 3 1 ! 4 6~ O0000OO000 L?T~ L~R CPS 599A59 O0 000 O0 0 3 ! 1 4 65 OOOOOOOO00 SSi [,DR CPS 599459 O0 000 O0 0 3 ! 1, 4 68 OOOO000OO0 .I~ Ta e Verifi. cat~on I..,.{s~Ina ~c~l, Ue~eroer AlasP, a Comr~u£ .rig Center 23-JAN-~993 12:05 i6 mmmmmMmmmmmmmmmmmmm~mmmmmmmmmm~mmmmmmm ID ORDER I.,D~ CPS 5994 9 O0 LDP V ~99459 O0 000 O0 LDR V 599459 O0 O00 O0 LDR G/C3 599459 O0 000 00 LOP G/C3 599459 O0 000 O0 bO~ G/C~ 59945~ O0 OOO O0 b[)~ IN 599~59 OO OOO 00 LD~ IN 599450 O0 000 O0 LDR G~PI 599459 O0 000 O0 I, DR bB 599~59 O0 OOO O0 bOR DgGF 599459 O0 000 00 LDR OM~M 599459 O0 000 O0 LDP L~ 599450 O0 OOO O0 CNR PU 599459 O0 O00 O0 R PU 599459 OD 000 O0 CNR 599459 O0 CNR PU 599459 O0 000 O0 C~ C~$ 599459 00 000 0¢ CN'~ CPS 59945~ 00 000 OO CN~ CPS 599459 O0 000 O0 CM~ CPS ~99459 O0 O00 O0 CN~ GAPI 599459 O0 OOO O0 C~ TN 599459 O0 000 O0 CN~ I~? 599459 O0 000 O0 CMR L~ 599459 OO OOO O0 CN~ O~M 599459 O0 000 O0 CNR DEGF 599459 O0 000 O0 CMR LB 599459 00. 000 O0 DATA ** DFPT. CALI. DLR TE%IS · DLP ~'SFL. ~WO~.I. DP OS8.hDR LIT~.LD~ SSNV.LDP C~LT.LDP ~TEN . LOP ~TNP · CNR GR.CNR 12011.500 LLS, DLR 5 7.2~7 CAL1.DLR 6 7295.000 ~T~M.DLR ~.59 6.100 SMIN.DLR 0 ~.2C4 9RHO.LD~ 0 0.090 LS.LDR 452 61.645 $S1..LD~ 237 132~.718 $IPH.LDR 7.237 CALI..LO~ 6 ~59.936 HRF$.I, DR 0 2.571 TNPH.CNR 25 2!.~9.778 RCWT.CN~ 842 109.512 CALI.CN9 7 0.069 ~TEM.CNP 159 .PI FILE NIt~B NUMB $I~E RF, PR PROC...,$$ OD NUMB SAMP El, EM COD..,;:' ~ (~]EX) 3 1. 1 6t 0000000000 1 4, 68 C!0O0000000 0000000000 3 l 1 4 68 0000000000 3 ! I 4 68 OOOO000000 3 1 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 ! 4 6~ 0000000000 3 1 1 4 68 0000000000 , ! ! 4 6~ 0000000000 3 1 I 4 68 0000000000 3 1 ! 4, 68 0000000000 3 1 I 4, 68 0000000000 3 1 i 4, 68 OOOO000000 3 , I 4 68 0000000000 3 i. 1 4 68 0000000000 3 ! I 4 68 O0000OOOO0 3 ,, I 4 68 0000000000 3 ,. 1 4 68 0000000000 3 I I 4 68 O000000OO0 3 I ! 4 68 O000000OO0 3 ! 1. 4 68 0000000000 3 ! ,, 4 68 0000000000 3 ! 1 4 68 0000000000 , i I 4 68 0000000000 ,3 ! I ~ 68 0000000000 3 1 I 4 68 O00OO00000 3 ! 1 4 68 0000000000 3 1 I 4 68 O00000OO00 ... .304 I.,LD..OLR 60,520 CAL$.DLR 416 SP,DLR -20.000 GR.DLP :936 M~ES,DL~ 0.069 HTEN,DLR .780 SNNO,DLR 1.625 DPHI.LDR .125 PEF,LD~ 0.000 OLS.I, DR .736 LU.LDR 43~.595 LL.LDR ,939 SS2.LDR 324.042 I, SHV,LOR ,4~6 G~.LDR 109.51~ TENS.LD~ ,069 HTE~.LD~ -160.635 ,020 TNR~,CNR 2.~55 .5S? ChtTC.C~'9 2103.~97 CFTC.C~ .237 CALS.CN~ 7.782 .936 NTE~.CN~ -160.635 7,782 109.512 -~60~635 97.026 -0.07~ 236.474 1438.503 2.096 2295,000 25.820 870.703 2295.000 ,ils Ter, e Veri~lcation L~stino ;ehlumheroerA!~ska Computi, no Center 4205.000 6,251. 2.20~ 0.090 7.237 1.59;936 ~.571 2189.:728 109,512 0.069 1~900'000 8,8~2 6,076 0 O31 45 .21, 8 1.330 3 ~ 123.229 0,069 11800"000 8,873 6175,000 7'047 2.618 0,020 54. ~331.595 ~.873 161.164 2.43a 2709.590 I~3.2~6 o.o67 ~7oo.ooo 8,5~ 624o,ooo 8,~35 ~.5~5 0.064 53,4~7 1331,959 g,58~ ~59,95b LLS'.DLR CAL1.DL~ ~ ~ I N.. DLR DRHO,LDR ' LS. LDR $S1.LDR $1RH.LD~ CAI, !. LD~ ~RES,. [,DR TBPH.C~R LbS;Dba CAI.I*DLR ~TEH-DLR LS:,LDR SSI.LDR S1RH-LD~ CAL1.LDR MRES.LDR TNPH.CN~ aCFT-CN9 ~TEM,CNR · b L $. D I, R ~TE~.DL~ SHIN.DL~ DRHO,LD~ L$.LDR $1RH.LDR CAL1.LDR ~RES.L, DR TNPH.CNR ~CFT.CNR C~f,I.C~R ~TEM.CMP LL$.DLR CALI.DLR ~TEM.ULR D~O.LD~ L~. LDR SS :LDP SI~H.bDR CALI.LDR 23-OAN-1993 12105 5.304 LLD~DL~ '!!416 SP.DL~ 15 ~36 ~RBS:.DLR 23 0,125 PEF, LD~ 452,736 LU.LDR 237.939 1.830 LSR~.LD~ 6,416 GR..LDR .25,820 TbRA:.,CNR 842,582 C~TC.C~ 7°237 CALS.CNR 159,936 MTEN.CNR .. 4,83'3 LLD,DLR 8.~66 SP'DLR 159. 22 ,3,156 S~4NO.,DLR 0.056 PEF, LDR 194.391, LLI,.bDR 189.4.11, SS2.,LDR 477 LSRH.LDR ~'566 GR LDR * . . 0,069 H T 31.~6~ TNRA, CNg 765 118 CNTC,CNR 159,52~ HTEN.C~R 6.139 LLD.DLR 8.625 SP,'DL~ O. 9 PEF..LDR ~01.587 LU.LD~ 2.5C5 LSR~.LDR 8.625 GR.LD~ 0.067 HTflN.LDR 25.396 TNRA.CNg 1071.~44 CNTC.CNR 8 ~7] CALS,CNR 161~164 HTEN.CN~ 7.~47 LLD,~LR ~ 506 SP.DLR ,.59!8~6 M~ES.DLR 3 I 9 S~O.DL~ 0.020 PEF.LDg ~27.]30 LU,LDR 187.693 SS2,LD9 8.506 G~.LDR 0.068 HTE~.bDR 60.52O -20,.000 0..069 1719 432.,525 04~ !09.51,2 -I22.5~2 ~ 455 2~03:297 7.823 -t22.522 -25~6~5 405 190,634 ~53,380 1121 805 - 2.'188 0.067 6.240 113,,~$6 1020.101 2.549 8.736 1020.101 7 908 0 068 5,660 4.020 ~21.155 ~46.880 2.505 96.450 835.g29 ,, CALS.DbR GR.:DLR DP:HI.LD~ OLS. I, DR LS~¥.LDR LURH.LDR TE~t$,.LDR NP~I.CNg ~{~O~.C~ CFTC.CNg TENS.C~g CALS.DLR HTEN. DL~ D P ~ I :, L D R 0 L $ * t, O ~ [,8HV', URH:*bDP NPOR.CNR CFTC*CNR TENS.CN~ CA~$.,DLR HT~N.DLR DPHI.LD~ QbS.LDR LSHVbDR LU~H:LD~ TENS*I..D~ NPM].CN~ NPO~,CNR CFTC.CNR T~NS.C~R C~LS,.DL~ HTEN.DLR DPHI.LD~ LI,.LD~ LSHV.LDR TE~S.LD~ NP~I.CNR PAGE ,It 7.823 109.5~,.2 '122,522 27.0~6 236.474 1439,503 4205,.000 870.8~0 4205.,000 123.229 i121'805 '0,848 0 018 99 0?4 1444 917 2 624 6~1~ 3 705 31 669 787.506 6415.000 ., 8,7 6 11'3,,'~86 1020.101 1.938 0.0;0 I03.445 403 6175.000 26,689 25.,619 6175,000 8.567 96.450 835,929 7,546 -0,008 116.752 1.450,778 2,5~5 6240.000 19.164 1,7 :,IS Tape V'eriflcatlom ListinQ ;chlumberqer ~laska ComDut~n~ Center RCNT'C?JR 259~ 7i. 8 RCFT CN~ (~;R, C,~ 96,4, 50 CALl. D E ~ T. 1 l 600.000 L L S. C~'L't Ob~ ~'952 C~L1.DLR ' ~ '..',, ,., . T[~S.DLR 5955.00P ~HOB.I,D~ 2.695 DRHO.LDR t, I TH. L9~ 5~.505 SSl. ~DR S S H V. L 0 ~ 13 t 2 · ~ ~ O $1 R H.. b C ~ b I · L D ~ 8.952 C A L '1 · L O R ~}TE~. I.~.D!~ 160.49~ '~RES, LDR G~.CN~ 93,1.~4 C~LI'CN~ ~IS, CNR 0,067 ~TF~,CNR t)~', PT . 1 1500 . 000 LbS' CALI.DL~ ~.431 CALl.Db9 TEN:S. DL~ 6115,000 ~TF~.DL }~SF[., ~ DL~ 2.805 SMI'N. DLR, ~HOB.LD~ 2,246 D~HO,LDR 088,BDR 0,0~ 3 LS.LDR LIT~,Lt'~P 1 6 196 SS1... CALl. [,.D~ 8.431 CALI.LDR ~TE~, LDR 160,081 ~RES,LDR ~TNP Ca~ ~,~6 TN~H,CNR ~CNT'~C~R 2800,].~5 RCFT,CNR GR,CUR 33.5~5 CALI,CNR ~ES.CMR 0.067 MTE~4.CNR DEPT. 11400'* 000 LLS.DL C~b!.DLR 8*636 CAbI...DLR TENS.DLR 6045,000 MTEM,DLR NSFL,DLR 0,~42 SWlN,DLR ~HOB.LDR ~.981 DRHO.LDR OSS. LDR -0. t25 LS.LDR LITH. L.DR 1.4,. 005 881. bOR SSHV.LD~ 1333,09.~ SI~H,LDR CAI..I. LDR ~,6B6 CALI..LQR ~TEM. LD~ ! 59,1 38 MRES. LDR ~TM~. CNR 3. 596 Tw~H. CNP ~CwT.CU~ 1.63~.253 ~CFT.CMR G~.CNR 24.3~4 CALI.CMR MP~fM. CNm 0. 066 ~!T~M. C.ILI :DLR 8.g37 CAL1.DLR MSFI..DL~ -999.259 SMIN.DI,~ 23-JAN-1993 12:05 r2. 159,856 1, i. 843 I., L D .. 8.509 $ 0.0 ~.. 75. 0 8S2. LDR 2,601 b 8 ~ H, b D R 8', 509 G 0 067 I064,7.4.~ CNTC,CSiR 160, 1. ~RES.DL~ 6.387 $ ·-0 0 882, :LDR ~ .~ 360 G R .. :b D R 0,067 HTEN:,:LDR 28.~1. TNRA.CN~ 954, 4 CMTC,CNR 160.0 ~ BT~N.CN~ 0.258 L L D. D I.,R 8. 649 SP, DLR 159.138 ~RES.DbR 0.201 -0.913 PEF.LDR 127 ~58 I.,U.. LD~ 4 7 3 [.,SB~.BDR B. 649 GR. 0 . 066 37,639 TNRA.CNR 507,646 CNTC.CNR 8.636 CALS,CN¢ 159. 138 HTEN,CNR 0.144 LLD.DL~ 158.558 MPES.DLR -999.~50 SMNO.DL~ -0.~71 PEF,LD~ 2.0 4 2835. 5247 8,567 835. 929 1 ~, 506 0..067 20,. 542 2 967 1, 85.' 927 242~ .009 93-i 14 884.. 975 884.975 -21,~ 360 67{ 2., 596 32! ,..e 88 28 ~. 75 3 . :~ 51 3 .525 8 sv : o9 8 539 878~246 0 -93. B75 O. !40 21 ..107 1 ~0.687 83.508 ~.894 24.. )24 885.786 3.240 1585.403 9.818 885.786 0.80~ -119.625 0.066 -999.250 28.938 1463-32 6240,000 88 ,975. 54 99 782 145! 892 2 64~ 5955 26'211 1094~187 5955.000 33.5~5 878.246 24.481 0,0~6 1451~,315 2.270 6!15.000 99,631 29~,423 1057.893 6115.000 8'818 24.324 885.786 40.549 0.046 61..914 1451.7~7 2.957 6045.000 38.240 38..132 497.754 6045.000 8.878 64..119 903.770 37.769 -0.088 chlumber_er .~lask:a ComPtit in0 Center 23-JAN'1, 993 !2:05 PAGE: 19 QSS. LD~ '0.1~.8 bITM.LDR l. 1.312 S8~V.LDR 1333.489 CtLI.LD~ ~.637 CA!,,1.. hDP ~T~.~. LD~ 158. 558 ~'IRgS, LDR ~.TN~ CN~ 3.696 TMPH CNR GP.CNR 64.1.1.9 Cll..,I. CNR NRKS,CMP 0.066 109.172 LU.;bDR 54.205 SS2.LgR 4.713 LSRH.LDR ~.643 G~.LDR 0.066 HTE~.LD~ 46.3~ T~R~,.C~R 355.692 C~TC,CNR 8.637 CALS:.CNR 158.55~ RTENoCNR 23'o l, 1 86,387 2.898 64:.~19 903,.770 3.535 1359.,905 S,.87, 903.770 47.666 1454,521 2.906 6055.000 43,656 43.1,67 6055.00 **** FII..,~ TRAILER **** FII.,E NA~E : EDIT .003 SKRVtCE : wi, lC V~RSIOM : 001~07 DAT~ :' 93/01/23 ~i× REC.SiZE ~ 1024 FILM TYPE L~ST FILE : **** TAPE TRAILER **** SERVICE' NAME : EDIT DATE : 93/01/P3 OPlCIN : FLIC TApE NAPE : 93033 CONT,I::NUATI~U # : I PREVIOUS TAPE C~MWEMT : ARCO A,..,.~AoKA I~IC , [ e . PRi,ID~')O~ BA, Y,9 - 51 50 0~9-2~320-00 **** RMEh TRAIl, ER SERVICE b,!A~M : EDIT D.AT~ : 93/0J./73 ORIGIN : FblC ~KEt., ~!A~.;E ~ 93033 C~NTIMU~T!U~ ~ : C~E~T : ARCO ALASKA INC.,PRUDMOE BAY,9 51,50-029-22320-00
