Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
196-116
ON OR BEF oRE W C..LOI~dI~ILM-D°c PL'JGGI~-,~ & LOCATION CLEAk~.NCE R~PORT State of Alaska .ALASKA 0IL & GAS CONS~RVATION COM~ISSION Aeview the well file, and-comment on plugging, well head suatus, a~d location c!ear~ce - provide loc. clear, code. Well head cut off: ,~L~,~_~)'- Loca=ion Clears.nc~: . . _ Code ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2D-06A (Permit No. 96-116/398-235) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent abandonment of KRU 2D-06A. This well was sidetracked and re-drilled to an alternate bottom hole location and renamed 2D-06B. If there are any questions, please call 263-4107. Sincerely, D. Hembling CTU Drilling Engineer AAI Drilling DH/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS E~] SUSPENDED E~] ABANDONEI~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-116, 398-235 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21168-01 4 Location of well at surface 9 Unit or Lease Name 124' FSL, 510' FEE, Sec. 23, T11 N, R9E, UM~I ~"'~'~'.~'~'~'~ ~ Kuparuk River Unit At Top Producing Interval ii '¢'~:~ : 10 Well Number 1279' FNL, 2195' FEL, Sec. 24, T11N, R gE, UM i~~ 2D-06A At Total Depth " ! ~, 11 Field and Pool 893' FNL, 2272' FEL, Sec. 24, T1.1N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial Ne. Kuparuk River Oil Pool RKB 121'I ADL 25653 ALK 2579 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 18-Aug-96 20-Aug-96 13-Sep-98 P&A NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9080' MD & 6284' TVD 8688' MD & 6020' TVD YES U NO M N/A feet MD 1465 APPROX 22 Type Electric or Other Logs Run GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE-1-FING DEPTH MD CASING SIZE Wf GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 110' 24" 224 sx CS I 9.625" 36.0# J-55 SURF. 4104' 12.25" 1070 sx AS III, 765 sx Class G 7" 26.0# J-55 SURF. 7185' 8.5" 560 sx Class G & 41 bbls AS I 3.5" 9.2# L-80 7024' 9080' 6.125" 396 sx Class G cement plug @ 8688' 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) all perfs down squeezed 26 ACID, FRACTURE, CEMEf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4.7 bbls cement 27 PRODUCTION TEST Date First Production Method of Operation (FIowing,N/A gas lift, etc.) Date of Test Hours Tested PRODUCTION FO] OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~- .,.,. .~. :~ ,. ' ' ': .:...' t.~"i N/A ?:i?,;i,r,~.., i~t'i: . /;;'.': f":: . . ': ...... , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8553' 5934' Bottom Kuparuk C 8598' 5963' Top Kuparuk A 8765' 6072' Bottom Kuparuk A 8936' 6186' Annulus left open - freeze protected with diesel. 31. LIST OF A1ZACHMENTS Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name~Number Sharon AIIsup-D~ake~263-46'12 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 ARCO Alaska, Inc. WELL 2D-06A DATE 09/13/98 DAY 2 '~ KUPARUK RIVER UNll vCELL SERVICE REPORq KI(D-06A(W4-6)) JOB SCOPE JOB NUMBER RIG SIDETRACK, SIDETRACK SUPT 0906981629.4 DAILY WORK UNIT NUMBER PRE-CTD MILLOUT D NIPPLE / PUMP CEMENT PLUG UNIT #3 OPERATION COMPLETE I SUCCESSFUL I KEY PERSON SUPERVISOR (~) Yes O No _1.. (~ Yes O NoI_ DS-BASS NAUGHT InitialTbgPress IFinalTbgPress IlnitiallnnerAnn11250Psl 1875PSI350PSI Final Outer Ann 2OO PSI DAILY SUMMARY MILL THROUGH D NIPPLE WITH 2.80" MILL. PUMP AND SQUEEZE CEMENT PLUG. 4.7 BBLS CEMENT BEHIND, CLEANED OUT DOWN TO 8690' (10' FROM TARGET OF 8700% COULD NOT JET DOWN ANY FURTHER AFTER SQUEEZING CEMENT. FREEZE PROTECT WELL WITH DIESEL TO 2500' . WELL SHUT IN WITH 1875 PSI AT WELLHEAD. TIME LOG ENTRY 06:00 MIRU. RIG UP RADIUS COIL CONNECTOR. PULL TEST TO18000 PSI. PRESSURE TEST TO 4000 PSI. OK. RIG UP RADIUS MOTOR AND MILL. 07:45 P/T COILED TUBING, INJECTOR HEAD/BOP STACK, HARDLINE TO 4000 PSI. OK. TGSM. DISCUSSED MUSTER POINT, JOB DETAILS. 08:00 STANDBY FOR COMPUTER TECH. CTU COMPUTER IS LOCKED UP. FOUND BAD KEYBOARD CONNECTION. 08:55 RIH W/1.75" COILED TUBING, RADIUS COIL CONNECTOR, DUAL CHECKS, DISCONNECT, XO, 2 3/8 TANDEM MOTOR, XO, 2.80" CARBIDE MILL. PUMPING .4 BPM SLICK SEAWATER. 09:45 AT 4800' CTM. NOISE FROM INJECTOR HEAD, APPEARS TO BE LOCKED UP GOOSENECK ROLLER. SCRATCH MARKS ON COILED TUBING. STANDBY FOR MANLIFT. FOUND BAD GOOSENECK ROLLER AND REPLACED. 11:25 WEIGHT CHECK AT 5000'. 7000#. RIH. 11:50 TAGGED D NIPPLE AT 7000' CTM. PAINT FLAG ON COIL. BRNG ON PUMP AT 1.5 BPM. BEGIN MILLING THROUGH NIPPLE. 15:20 MILLED THROUGH NIPPLE. RIHTO7030'CTM. BACKREAM THROUGH NIPPLE. SHUT DOWN PUMP AND RIH THROUGH NIPPLE. PULL BACK THROUGH NIPPLE. 15:30 POOH. 16:30 OOH. RD RADIUS TOOLS. RU COLD ROLL, XO, 2.2" CEMENTING NOZZLE. 17:05 PFF COIL, INJECTOR/BOP STACK, HARDLINE TO 4000 PSI. OK. 17:15 RIH W/1.75" COILED TUBING, COLD ROLL, XO, 2.2" BALL DROP CEMENTING NOZZLE. PUMPING 150 DEGREE SLICK SEAWATER AT .4 BPM. 19:00 TAG BOTTOM AT 8893' CTM, CORRECT TO 8915' (22' CORRECTION). PULL UP 10' AND FLAG PIPE. PUMP SEAWATER DOWN COIL ANNUL. AT 2-3 BPM. (150 BBLS TOTAL). START MIXING CEMENT. CONT PUMPING SEAWATER DOWN WELL. 19:45 20:00 PUMPED 150 BBLS SEAWATER DOWN WELL. SHUT DOWN PUMP AND TAKE SIP, LINED OUT AT 1370 PSI. 20:30 PT CEMENT LINES AND BEGIN PUMPING CEMENT AS PER PROC. 1 BPM. DOWN COIL. SWAP TO BIOZAN TIME 21:00 22:00 22:30 22:50 23:05 23:25 23:55 02:00 03:30 05:00 LOG ENTRY AFTER CEMENT PUMPED. CEMENT AT NOZZLE, RETURN 1 BBL ABOVE NOZZEL, LAY CEMENT IN AT .5 BPM TO 8820'. PUMP 500 PSI OVER ISIP.PUMP 1 BBL ABOVE NOZZLE( 2 TOTAL) LAY REST OF CEMENT IN TARGETING 1:1 RETURNS AND WELLHEAD PRESSURE OF 1850 PSI. PULL UP TO SAFETY. CALC. TOP OF CEMENT AT 8295'. CALC 4.7 BBLS CEMENT BEHIND PIPE. AT 7500'. WAIT 30 MIN. 1450 PSI PUMP HESITATION .1 BBL, WELLHEAD 1450 UP TO 1775 PSI PUMP HEST. STEP .1 BBL 1750 PSI TO 2000 PSI. PUMP HEST. STEP .1 BBL 1975 UP TO 2150 PSI . PUMP .1 BBLS PRESS AT 2375 ( 1000 PSI OVER SIWHP OF 1370 PSI). HOLD PRESS FOR 30 MIN. DROP BALL IN COIL. CLEANOUT WITH BIOZAN.SEE TOP OF CEMENT AT 8300'. TAG HARD AND UNABLE TO CLEAN BELOW 8690' 3 RECIPS FROM 8000' TO 8690' WITH WELL HEAD AT 1875 PSI OR HIGHER. AT 8690' POOH AT 55 FPM RECIPING AT TUBULARS TO CLEAN. AT 4200' COMING OUT OF HOLE, SWAP FROM BIOZAN TO DIESEL.PUMPING 1 BPM AND MOVING 55 FPM. TARGET SPOTTING 2500' DIESEL CAP FOR FREEZE PROTECTIONIN WELL BORE. AT SURFACE WITH COIL. SHUT IN WELL LEAVING 1875 PSI ONB TBG. RDMO ARCO Alaska, Inc. · KUPARUK RIVER UNIT WELL 2D-06A DATE 09/18/98 DAY 4 ~vELL SERVICE REPORT KI(D-06A(W4-6)) JOB SCOPE RIG SIDETRACK, SIDETRACK SUPT JOB NUMBER 0906981629.4 DAILY WORK UNIT NUMBER CORRELATE & TAG CEMENT PLUG 2128 OPERATION COMPLETE I SUCCESSFUL (~) Yes O No (~) Yes O No KEY PERSON SWS-VETROMILE ._ Initial Tbg Press I Final Tbg Press 1800 PSII 1800 PSI SUPERVISOR JONES Initial Inner Ann 125 PSI Final Inner Ann [ 125 PSI I ii Initial Outer100AnnpsI Final Outer Ann 100 PSI DAILY SUMMARY SWS RAN GR/CCL, CORR & TAGGED CEMENT PLUG @ 8688'. [Tag] TIME LOG ENTRY 07:45 SWS MIRU, HELD TGSM. MU TOOLS & PT LUB TO 3000#. 09:00 MIH W/1 11/16" CPLT, 2 WB. CORR TO SPERRY SUN DGPJROP/EWR4 LOG 8-17-96. TAGGED CEMENT PLUG @ 8688'. 11:00 POH & LD TOOLS. 12:00 RIG DOWN. 12:30 RELEASE SWS. Date: 10/12/98 Page: 1 well_summary_CTU2D06B.txt ARCO ALASKA INC. WELL SUMMARY REPORT COILED TUBING UNIT OPERATIONS WELL:2D-06B WELL_ID: STATE:ALASKA 168-02 FIELD: KUPARUK RIVER UNIT SPUD: START COMP: FINAL: RIG: NABORS4ES BLOCK: API NUMBER: 50-029-21 9/26/98 RDMO f/2K to 2D. Accept rig at 0300 hrs. NU BOPs. 9/27/98 RU CTU. RU remote check. Spot and clean tanks. BOP test. BPV. RIH. UR cement f/8420' 9/28/98 Underream cement to 8785' POOH. RU e-line. RIH with whipstock anchor. Stuck anchor. Work free & POOH. 9/29/98 E-line PBTD tag. Run & set whipstock anchor. Verify anchor orientation 9/30/98 MU & run TIW whipstock assy on coil, planned maintenance to rewire BOP control panel in ops cab, RIH w/window milling assy, milling window. 10/1/98 Mill window, POOH, RIH w/BHA #15, stalling on top of whipstock, POOH t o check mill and discuss options, RIH w/MWD and 2.5° motor w/flat bttm metal muncher mi 11, being time drilling procedure. 10/2/98 Start time drilling, out casing and drilled 6' open hole, log GR tie i n (6+' corr), POOH, C/O motor & mill, RIH w/polishing mill, orient, dress window FIT, POOH, pr essure imploy BHA #7. Page 1 well_summary_CTU2D06B.txt 10/3/98 PU BHA #3, build section, drilling from 8788'-8895', finish curve, PO0 H, PU BHA #9, RIH, drill horizontal form 8895'-9120'. 10/4/98 Drilling from 9120'-9250', ST drill to 9372', ST, difficulty drilling at 9372' for a few ft, drill to 9461', St, drill to 9559', ST, drill to 9720', POH for motor change. 10/5/98 POH, LD BHA %9, BOPE test, PU BHA #10, RIH to 235' SHT failed, no puls es, POH C/O MWD, swap old mud for new, RIH tie in RA tag (+8' corr.) Drill from 9720' to 987 0' 10/6/98 Drill from 9870'-10,010, ST, POOH for MWD, RIH w/BHA #11, Drill from 1 0,010' to 10276' 10/7/98 Drill from 10276' to 10657' Short trip & orient as required. 10/8/98 Drill from 10657' to 10830' Unable to drill ahead. Replace mud system Drill from 10830'-10973'. Orient and short trip as required. 10/9/98 Complete short trip. Drill from 10973' to 11075'. Change BHA. Drill fr om 11074' to 11198' Short trip & orient as required. 10/10/98 Complete short trip. Drill from 11198' to 11260' (TD). Short trip & lo g tie-in. Displace well to 12.5 mud & brine. POOH & LD BHA. MU liner. 10/11/98 RIH w/liner. Displace well to seawater. POOH & freeze protect well. Se t BPV. NDNU. Clean pits. Release rig & CT unit. Prep to move. Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~.~_.! 1. Type of Request: Abandon _~X 2. Name of Operator Alter casing _ Change approved program _ ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 124' FSL, 510' FEL, Sec.23, T11N, R9E, UM At top of productive interval 1279' FNL, 2195' FEL, Sec. 24, T11N, R9E, UM At effective depth At total depth 893' FNL, 2272' FEL, Sec 24, T11 N, R9E, UM Suspend_ Operation Shutdown __ Repair well _ Plugging __ Pull tubinq 5. Type of Well: Development Exploratory _ Stratigraphic _ Service -- Re-enter suspended well _ Time extension_ Stimulate_ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 121' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-06A 9. Permit number 96-116 10. APl number 50-029-21168-01 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured true vertical 9080 feet 6284 feet Plugs (measured) None feet Effective depth: measured true vertical 8982 6217 feet Junk (measured) None feet Casing Length Size Structural Conductor 110' 16" Surface 4104' 9.625" Intermediate Production 7185' 7" Liner 2056' 3.5" Cemented 224 sx CS I 1070 sx AS III & 765 sx Class G 560 sx Class G & 41 bbls AS I 396 sx Class G Measured depth 110' 4104' 7185' 9080' True vertical depth 110' 3160' 5016' 6284' Perforation depth: measured 8820'-8850' true vertical 6107'-6127' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7032' Packers and SSSV (type and measured depth) Baker C2 ZXP Liner Pkr @ 4361' MD, No SSSV ORi®INAL RECEIVED SEP 0 2. 1998 Naska 0il & Oon . Commission Anchorage 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation September 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. s igned~'~,.,.-~,~_,,c~ ~:: ;~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so represe~ntative may witness Plug integrity_,/ BOP Test ~ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- A'0 7' 15. Status of well classification as: Gas _ Suspended _ Date ~)",/'.~///2 ~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Orioln ,l 5 gned By Oavid W. Johnston SUBMIT IN TRIPLICATE Kuparuk 2D-06A Intended P&A Procedure Objective: P&A existing interval in preparation for CT sidetracking operations. Intended Procedure · RU SL. Tag bottom. · RU coiled tubing unit, load and kill well. · Pump 10 bbls Class 'G', 17 ppg cement, squeeze up to 7 bbp. · Clean cement top to -8735' md (KOP for CTU drilling at 8765') · WOC, Tag top of cement. RECEIVED klagka 0il & gas Cons. 60mmisslor, &nchorage August 25, 1998 C T Drilling Wellhead Deta , Methanol Injection Otis 7" WLA Quick Connect - ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Man--- Kelly Hose to Dual HCR Choke Manifold Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus I13-3/8" Annulus PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 08/12/98 RUN RECVD 96-116 MWD SRVY 96-116 GR/RES-MD 96-116 GR/RES-TVD 96-116 7921 96-116 DIR SRVY R SPERRY 7205-9080 ~SPERRY GR/RES ~205-9080 11/25/96 FINAL 01/29/97 FINAL 01/29/97 1,2 03/12/97 04/29/97 10-407 ~COMPLETION DATE ~/ 3 / gL/ DAILY WELL OPS R ~'[/ 3~/~/ TO ~1 ~ Iq~l Are dry ditch samples required? yes ~And received? Was the well cored? yes ~~alysis & description received? ~--y~-s~_~ Are well tests required? yes /~ Received? Well is in compliance /7~ Initial COMMENTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2D-06A (Permit No. 96-116) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 2D-06. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-116 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at surface 124' FSL, 510' FEL, Sec. 23, T11N, R9E, UM ~ ~';~'~.,.r, ..... ,.~' ; ''J' ~ i" At top of pro du cti vein te rval ~ ~.Z~'~L~' ~~--~__ ' 1279' FNL, 2195' FEL, Sec. 24, T11 N, R9E, UM :. . At total depth 893' FNL, 2272' FEL, Sec 24, T11 N, RgE, UM .... ~_~__~.~ 8. APl Number 50~029-21168-01 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2D-06A 11. Field and Pool ....... Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) JG. Lease Designation and Serial No. Rig Nordic #2 RKB 121, Pad 89' J ADL 25653, ALK 2579 ~'2. Date Spudded j13. Date T.D. Reaches j 14. bate Comp., Susp., or Aband.j15. Water depth, if offshore J16. No. of Completions 8/16/96 j 8/20/96 j 9/3/96 J N/A MSLJ One i'7. Total Depth (MD'+TVi~) j 18. i:'lug Back DePth (MD+TVD)J19. DireCtional SUrveyj20. Depth where sssv se't~21, Thickness of Permafrosl 9080 6284 FT~ 8982 6217 F~ I~Yes ~No j UA MDJ 1465' (Approx.) 22. Type Electric or Other Logs Run GR/Resistivity 23. CASING, LINER AND CASING SIZE 16" 9-5/8" VVT. PER FT. GRADE SETTING DEPTH I HOLE TOP BO-FFOM ii ....._S_!FF- 62.5# H-40 Surf. J-55 36.0# Surf. 7" 26# J-55 Surf. L-80 9.2# 7024' 110' I 24" 4104' [_1_ 2_:_251'__ 7185' / 9080' j 6.i25" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD 8820'-8850' 6107'-6127' (4 spf) MD TVD CEMENTING RECORD CEMENTING RECORD AMOUNT PULLED 224 sx CS I 1070 sx AS III & 765 sx Class G 560 sx Class G & 41 bbls AS I 396 sx Class G 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7032' 7032' 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8820-8850' 118000# proppant behind pipe and 20,468# proppant left in wellbore. Used 13,880# of 20/40 and 124,588# 12/18 proppant. 27. PRODUCTION TEST Date First Production ~k;jeth~d of Operation (Flowing, gas lift, etc.) 9/26/96 Gas Lift _ Date of Test iHours Tested I PRODUCTION FO~ 11/1/96 ! 20.2 !~_E__S__T__P___E__R_}_.O__D__~. F'f6~ T-dGi-~-~ica~i-H~- 'Pi--~ u repALCULATED · Press. 15~ 773 ~24-HOuR RATE OIL~BBL 88 OIL-BBL 1 O5 GAS-MCF 130 GAS-MCF 154 WATER-BBL 95 WATER-BBL 113 -CHOKE SIZE ! GAS-OIL I 176 I RATIO 65O7 ]'C~i[ ~-~/,V'if~'-APi (-~i i =24° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. APR 29 1997 Oil & Form 10-407 Rev. 07-01-80 Anchorage Submit In Duplicate ORIGINAL 29. Geologic Mark .... 30. ' Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 8553' 5934' Bottom Kuparuk C 8598' 5963' Top Kuparuk A 8765' 6072' Bottom Kuparuk A 8936' 6186' Annulus left open - freeze protected with diesel 3i~ List of Attachmer~'ts ...................... Summary of Daily Drilling Reports, Surveys t ............................. ;' ................................... ; ..... ; .................................................................................................................................................... 132. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 11/5/96 ARCO ALASKA INC. WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS Page: 1 WELL:2D-06A RIG:NORDIC WELL ID: AK8581 TYPE: -- AFC: AK8581 AFC EST/UL:$ 909M/ 1145M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:08/08/96 START COMP:08/05/96 FINAL: WI: 55% SECURITY:0 API NUMBER: 50-029-21168-01 08/05/96 (C 1) TD: 0' PB: 0' SUPV: JT DAILY: $ 08/06/96 (C 2) TD: 0' PB: 9041' SUPV: JT DAILY: $ 08/07/96 (C 3) TD: 0' PB: 9041' SUPV:DLW DAILY:$ 08/08/96 (C TD: 8439' PB: 9041' SUPV:DLW 4) DAILY:$ 08/09/96 (C TD: 8370' PB: 9041' SUPV:DLW 5) DAILY:$ 08/10/96 (C 6) TD: 8370' PB: O' SUPV:DLW DAILY:$ 08/11/96 (C TD: 7390 ' PB: 7385 ' SUPV: DLW 7) DAILY:$ MOVING RIG, CURRENT LOCAT Moving rig from 2M pad to 2D pad. MW: 0.0 52,932 CUM:$ 105,864 ETD:$ MOVING RIG, 1 MILE FROM 2 Moving rig from 2M pad to 2D pad. 0 EFC:$ 1,014,864 MW: 0.0 32,932 CUM:$ 171,728 ETD:$ 0 EFC:$ 1,080,728 FILL MUD TANKS W/ll.2+ PP MW: 8.5 SW Move rig over 2D-06. Accept rig @ 1800 hrs 8/7/96. Start operations to kill well. 31,700 CUM:$ 235,128 ETD:$ 0 EFC:$ 1,144,128 CBU, TBG PULLED UP 16' ST MW:ll.2 MUD Continue to pump down annulus through GLM @ 8387' to kill well. Shut down open well and observe well. Annulus dead. Pump pill down tubing. Well dead. N/D tree and N/U BOPs. Test BOPE. 38,539 CUM:$ 312,206 ETD:$ 0 EFC:$ 1,221,206 POOH CHANGE 3.5" COLLARS MW:ll.2 MUD Continue to circulate and work 3.5" tubing, stuck after moving 9'. Run 2.7" jet cutter to 8370' cut tubing. POOH. Tubing cut in middle of joint # 277 above GLM #6. POOH Change 3.5" EUE 8rd collars to EUE 8rd Mod. 52,171 CUM:$ 416,548 ETD:$ 0 EFC:$ 1,325,548 RIH W/7" CEMENT RETAINER MW:ll.2 MUD Continue to pull tubing. Test blind rams 250/3500 psi and set wear ring. Run 7" cement retainer. 43,054 CUM:$ 502, 656 ETD:$ 0 EFC:$ 1,411,656 M/U 7" SECTION MILL BHA MW: 9.8 MUD Continue RIH w/7" cement retainer to 7390'. Set retainer. Unsting from retainer test 7" casing to 3500 psi for 15 min. Stab into retainer inject into formation. Pump cement. CIP @ 1400 hrs. 8/10/96. Spot pill from 7390' to 7120' 67,192 CUM:$ 637,040 ETD:$ 0 EFC:$ 1,546,040 Date: 11/5/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/12/96 (C TD: 7206' PB: 7385' SUPV:DLW DAILY:$ 8) PULLING PIPE TO BREAK UP MW: 9.5 MUD Continue to RIH w/7" section mill BHA #1 to 7185'. Cutting 7" section at 7185'. Cut 13' hole started packing off and taking fluid lost 125 bbls. Work pipe slow pump rate down. Continue to pack off and loose fluid. Cutting section from 7198'. Hole took 40 bbls and then stabilized. Milled to 7206'. Started packing off and pump pressure coming up. 51,539 CUM:$ 740,118 ETD:$ 0 EFC:$ 1,649,118 08/13/96 (C 9) TD: 7235' PB: 7385' SUPV:DLW DAILY:$ L/D BHA & M/U 3.5" MULE S MW: 9.5 MUD Ream out section from 7185' to 7227'. Hole started to pack. Work pipe and CBU, iron recovery 40-50%. Ream section from 7185' to 7235' 39,173 CUM:$ 818,464 ETD:$ 0 EFC:$ 1,727,464 08/14/96 (C 10) TD: 7085' PB: 7085 ' SUPV: DLW DAILY: $ LD DP W/CMT MW: 9.5 MUD RIH with 3.5" mule shoe. Pump cement. CIP @ 1445 hrs. Down squeeze cement. 65,283 CUM:$ 949,030 ETD:$ 0 EFC:$ 1,858,030 08/15/96 (D 11) TD: 7215'(130) SUPV: DLW DAILY:$ MW: 9.5 VISC: 45 PV/YP: 15/17 APIWL: 7.7 SLIDING OUT OF WINDOW Bleed off 7" x 9-5/8" annulus. N/D BOP's. Test to 3000 psi for 10 min. N/U BOP's. Test BOP's. RIH on 3.5" DP with BHA #1. Clean out cement from 7015' to 7185'. Slide out of section from 7190' - 7215' 37,393 CUM:$ 511,908 ETD:$ 0 EFC:$ 1,420,908 08/16/96 (D 12) TD: 7709' (494) SUPV: DLW DAILY:$ MW: 9.5 VISC: 42 PV/YP: 10/20 APIWL: 6.7 DIRECTIONAL DRILL Continue to slide and directional drill 6-1/8" hole for direction from 7215' to 7246'. FIT @ 7246' to 12.5 ppg EMW. Continue to slide for direction from 7246' to 7709' 53,010 CUM:$ 564,918 ETD:$ 0 EFC:$ 1,473,918 08/17/96 (D 13) TD: 8401' (692) SUPV: D LW DAILY:$ MW: 9.7 VISC: 46 PV/YP: 13/22 APIWL: 5.5 TRIP FOR SPERRY-SUN MWD TOOL Continue to directional drill 6.125" hole, sliding for direction from 7709'- 7775'. Survey and unable to rotate torque to high. Circulate bottoms up and getting a lotof sand. Drill ahead rotating torque from 7775'-7868'. Short trip to 7" casing shoe @ 7185'. Hole in good condition. Continue to directional drill ahead from 7868' to 8401'. Trouble with Sperry-Sun MWD tool direction not repeating surveys. POOH to 7" shoe @ 7185'. Monitor hole. Well dead. 57,465 CUM:$ 622,383 ETD:$ 0 EFC:$ 1,531,383 08/18/96 (D 14) TD: 8700' (299) SUPV: DLW DAILY:$ MW: 10.9 VISC: 49 PV/YP: 17/26 APIWL: 4.8 DRILLING AHEAD @ 8700' Continue to POOH Sperry-Sun MWD-RLL tool. Test MW]). RIH to 7556' Take MWD check shots. Continue directional drilling 6.125" hole from 8401' having to slide about 1/3 of the time due to building angle while rotating. 65,340 CUM:$ 687,723 ETD:$ 0 EFC:$ 1,596,723 08/19/96 (D 15~ ~ ~ ~ ~ ~ MW: 11.6 VISC: 49 PV/YP: 15/20 APIWL: 4 5 TD: 8806'( 10~: ~' ~ "~ ~-~ ~ ' ' ~ ~ ~9~N~. '~ ELECTRICAL SYSTEM SUPV:DLW %~ ~ontin~ to directional drill 6.125" hole from 8700'-8734' Gas to ~urface. Circulate gas out of well. Drill from 8734' ~p~ g~8~. Gas to surface. Circulate to remove gas from well Date: 11/5/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DAILY:$ bore. Gas and oil continue to enter wellbore w/mud weight @ 10.9 ppg and ECD at 12.0 ppg. Shut in well and weight up mud to 11.5 ppg. Well dead but started to flow. Drill ahead from 8764' to 8806'. Lost %3 generator SCR unit. Continue to circulate with reduced pump pressure while working on %3 SCR. Unable to drill ahead due to overloading the other two generators, work pipe and circulate. 66,533 CUM:$ 754,256 ETD:$ 0 EFC:$ 1,663,256 08/20/96 (D 16) TD: 9080'(274) SUPV:DLW DAILY:$ MW: 11.9 VISC: 43 PV/YP: 15/18 APIWL: 4.3 POOH TO RUN 3.5" LINER Continue drilling 6.125" hole from 8806' to 9080' TD. RIH to 9080' hole in good condition. POOH to run 3.5" liner. 78,035 CUM:$ 832,291 ETD:$ 0 EFC:$ 1,741,291 08/21/96 (D 17) TD: 9080'( 0) SUPV:DEB DAILY:$ MW: 12.0 VISC: 49 PV/YP: 17/18 APIWL: 4.5 POOH LDDP RIH w/3.5" liner. Circulate and reciprocate pipe to condition mud and hole for cementing. Pump cement. CIP @ 2400 hrs. 8/20/96. POH LD 3.5" DP. 111,064 CUM:$ 943,355 ETD:$ 0 EFC:$ 1,852,355 08/22/96 (D 18) TD: 9080' ( 0) SUPV: DEB DAILY:$ MW: 12.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DISPLACE WELL TO SEAWATER POH LDDP. Run 3.5" completion assembly. Test casing & liner to 3500 psi for 30 minutes, lost 50 psi. OK. 33,432 CUM:$ 976,787 ETD:$ 0 EFC:$ 1,885,787 08/23/96 (D 19) TD: 9080'( 0) SUPV: DEB DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Reverse circulate and displace annulus & tubing to clean seawater. Freeze protect well. Test tubing to 3500 psi, OK. Test annulus to 3500 psi, OK. ND BOPE. NU tree. Set TP. Test packoff to 5000 psi, OK. Test tree to 250 psi & 5000 psi. OK. Secure well. Release rig @ 1930 hrs. 8/22/96. 81,159 CUM:$ 1,057,946 ETD:$ 0 EFC:$ 1,966,946 End of WellSummary for Well:AK8581 ~' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-79181 Sidetrack No. 1 Page 1 Company ARCO ALASKA, INC. Rig Contractor & No. Nordic Well Service - Rig: #2 Field KUPARUK RIVER UNIT ',, Well Name & No. PAD 2D/6A Survey Section Name Sperry Sun MWD BHI Rep. KIRT CHRISTENSEN _ ~lilrJl"~l~ WELL DATA Target TVD (F3) Target Coord. N/S Slot Coord. N/S 124.00 Grid Correction 0.0(X) Depths Measured From: RKB ~ MSL[-] SSD Target Description Target Coord. E/W Slot Coord. E/W -510.00 Magn. Declination 27.740 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ff~ 30m~] 10m[-] Vert. Sec. Azim. 353.01 Magn. to Map Corr. 27.740 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'P/ (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) RGMS 7205.00 48.72 42.62 5027.52 2466.37 2926.02 3602.28 TIE IN POINT 15-AUG-96 MWD 7420.00 46.76 23.90 215.00 5172.81 2586.03 3057.72 3689.14 6.49 43.91 -8.71 4 3/4" M 1/XL 1.2 Deg AKO 15-AUG-96 MWD 7515.00 46.04 14.90 95.00 5238.39 2647.52 3122.47 3711.98 6.90 -0.76 -9.47 16-AUG-96 MWD 7609.00 46.90 7.40 94.00 5303.18 2712.20 3189.24 3725.11 5.85 0.91 -7.98 16-AUG-96 MWD 7702.00 46.00 358.47 93,00 5367.32 2778.46 3256.42 3728.59 7.02 -0.97 -9.60 16-AUG-96 MWD 7795.00 46.28 351.81 93.00 5431.80 2845.40 3323.16 3722.91 5.17 0.30 -7.16 16-AUG-96 MWD 7889.00 47.96 350.16 94.00 5495.76 2914.23 3391.18 3712.10 2.20 1.79 -1.76 16-AUG-96 MWD 7984.00 47.94 348.20 95.00 5559.40 2984.61 3460.47 3698.86 1.53 -0.02 -2.06 16-AUG-96 MWD 8078.00 48,66 349.42 94.00 5621,93 3054.60 3529.32 3685.24 1.24 0.76 1.30 16-AUG-96 MWD 8172.00 49.21 350.50 94.00 5683.68 3125.37 3599.10 3672.89 1.04 0.58 1.1 5 17-AUG-96 MWD 8266.00 48.80 345.79 94.00 5745.38 3196.02 3668.50 3658.33 3.81 43.44 -5.01 17-AUG-96 MWD 8359.00 48.95 345,60 93.00 5806.53 3265.51 3736.38 3641.02 0.22 0.16 43.20 -- 17-AUG-96 MWD 8453.00 49.61 345.30 94.00 5867.85 3336.14 3805.34 3623.12 0.74 0.70 43.32 18-AUG-96 MWD 8548.00 49.44 346.50 95.00 5929.52 3407.64 3875.43 3605.52 0.98 -0.18 1.26 18-AU G-96 MWD 8642.00 49.97 347.38 94.00 5990.31 3479.13 3945.26 3589.31 0.90 0.56 0.91 18-AUG-96 MWD 8737.00 49.03 350.30 95.00 6052.01 3551.16 4016.12 3575.30 2.55 43.99 3.09 18-AU G-96 MWD 8831.00 48.25 353.00 94.00 6114.13 3621.68 4085.91 3565,05 2.31 43.83 2.87 18-AUG-96 MWD 8926.00 46.72 347.00 95.00 6178.36 3691.55 41 54.81 3552.94 4.92 -1.61 -6.32 18-AUG-96 MWD 9006.00 47.55 347.60 80.00 6232.79 3749.90 4212.02 3540.06 1.17 1.04 0.75 18-AUG-96 MWD 9080.00 47.55 347.60 74.00 6282.73 3804.25 4265.35 3528.33 0.00 0.00 0.00 Projected Data - NO SURVEY ...................................... ~---~ ......... I ...... L.___I IIIIII!_l.lJ__ . II I ......... J KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(2D-06A(W4-6)) 2D -06A DATE O9/03/96 DAY 2 JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0826961951.6 DAILY WORK UNIT NUMB ER PERFORATE A SANDS OPERATION COMPLErE SUCCESSFUL KEY PERSON SUPERVISOR YES YES SWS-SCHWARTZ GOLDEN Initial Tbg Press I 800 PSI I Final Tbg Press I 0 PSI I Initial Inner Ann 450 PSI Final Inner Ann 100 PSI Initial Outer Ann [ I 0 PSI Final Outer Ann 0 PSI DAILY SUM MARY PERFORATED A SAND F/8820'-8850' (4 SPF, 180 DEG PHASING, 0 DEG CCW, BIG HOLE CHARGES). I TIME LOG ENTRY 09:30 MIRU SWS E-LINE. TGSM-PERFORATING. 11:00 PT LUBRICATOR TO 3000 PSI - GOOD.RIH W/CCL/GR/10' - 2 1/2" HOLLOW CASE CARRIER (4 SPF, 180 DEG PHASING, 0 DEG CCW, BIG HOLE CHARGES). 12:00 14:30 16:00 · TIED INTO MWD LOG DATED 8/17/96.PERFORMED JEWERLY LOG F/6800'-8960'.PERFORATED 8840'-8850.WHP (BEFORE) = 1300 PSI, WHP (AFTER)= 1200 PSI. POOH. ASF.WHP DROPPED TO 0 PSI WHILE POOH W/GUN RIH W/CCL/WB/20' 2 1/2" HOLLOW CASE CARRIER (4 SPF, 180 DEG PHASING 0 DEG CCW, BIG HOLE O-L~GES).ATmMPTED TO PRESSURE UP WELL BEFORE SHOOTING- WHP WOULD SLOWLY BLEED OFF.PERFORATED 8820'-8840.WHP (BEFORE) = 500 PSI, WHP/AFTER) = 300 PSI. POOH. ^SF. RDMO SWS E-LINE.NOTE: NO PROBLEMS POOH W/2-1/2" GUNS IN 3-1/2" LINER ON E1THER GUN RUN. SWS 35B- UP CHARGES USED ON BOTH GUNS. 0 I~ I I--I_11M G S ~ I~t~JI C ~:: S WELL LOG TRANSMITTAL To: State of Alaska ~ Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ Lo RE: MWD Formation Evaluation Logs DS 2D-06A, AK-MM-60101 March 12, 1997 The technical data-listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21168-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:t I I--I--I IM G SEFt~/I r- E S WELL LOG TRANSM1Tr~ To: State of Alaska January 29,1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 2D-6A, AK-MM-60101 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-21168-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21168-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I I--I--I ~ G SE FIL/I C I:= S November 19, 1996 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 2D-06A Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2D-06A Tie in point 7,205.00', window point 7,205.00', interpolated depth at 9,080.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Ino. Company SPt '-SUN DRILLING SERVICES ANCHOR_AGE ALASKA ARCO ALASKA INC KUPARUK/DS 2D-6A 500292116801 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 081996 MWD SURVEY JOB NUMBER: AK-MM-60101 KELLY BUSHING ELEV. = 121.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7205.00 5027.52 4906.52 48 43 N 42.62 E .00 2926.02N 3602.28E 7420.00 5172.90 5051.90 46 45 N 22.72 E 6.89 3058.44N 3687.71E 7515.00 5238.48 5117.48 46 2 N 13.67 E 6.94 3123.66N 3709.18E 7609.00 5303.24 5182.24 46 57 N 6.02 E 5.98 3190.74N 3720.78E 7702.00 5367.38 5246.38 45 57 N 2.91 W 7.04 3257.99N 3722.65E 2465.89 2586.93 2649.05 2714.22 2780.74 7795.00 5431.91 5310.91 46 16 N 11.60 W 6.74 3324.36N 3714.19E 7889.00 5495.88 5374.88 47 57 N 14.39 W 2.81 3391.46N 3698.68E 7984.00 5559.52 5438.52 47 56 N 10.63 W 2.94 3460.30N 3683.40E 8078.00 5622.05 5501.05 48 39 N 12.44 W 1.63 3529.06N 3669.37E 8172.00 5683.84 5562.84 49 12 N 5.54 W 5.56 3598.98N 3658.32E 2847.65 2916.13 2986.33 3056.28 3127.03 8266.00 5745.53 5624.53 48 47 N 10.52 W 4.02 3669.19N 3648.43E 8359.00 5806.71 5685.71 48 57 N 15.57 W 4.09 3737.40N 3632.62E 8453.00 5868.04 5747.04 49 36 N 15.42 W .71 3806.05N 3613.59E 8548.00 5929.70 5808.70 49 26 N 14.11 W 1.06 3875.93N 3595.17E 8642.00 5990.51 5869.51 49 58 N 10.42 W 3.05 3945.97N 3579.95E 3197.92 3267.54 3338.00 3409.60 3480.97 8737.00 6052.18 5931.18 49 4 N 9.09 W 1.43 4017.17N 3567.70E 8831.00 6114.26 5993.26 48 15 N 10.75 W 1.59 4086.69N 3555.55E 8926.00 6178.46 6057.46 46 43 N 12.07 W 1.91 4155.32N 3541.71E 9006.00 6232.88 6111.88 47 32 N 12.86 W 1.26 4212.57N 3529.05E 9080.00 6282.82 6161.82 47 32 N 12.86 W .00 4265.80N 3516.90E 3553.14 3623.61 3693.42 3751.78 3806.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5528.62 FEET AT NORTH 39 DEG. 30 MIN. EAST AT MD = 9080 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 353.01 DEG. TIE-IN SURVEY AT 7,205.00' MD WINDOW POINT AT 7,205.00' MD PROJECTED SURVEY AT 9,080.00' MD SPI f-SUN DRILLING SERVICES A/~CHOKAGE ALASKA PAGE 2 ARCO ALASICA INC KUPARUK/DS 2D-6A 500292116801 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 081996 JOB NI/MBER: AK-MM-60101 KELLY BUSHING ELEV. = 121.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7205.00 5027.52 8205.00 5705.44 9080.00 6282.82 4906.52 2926.02 N 3602.28 E 2177.48 5584.44 3623.78 N 3655.54 E 2499.56 322.08 6161.82 4265.80 N 3516.90 E 2797.18 297.61 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPt I-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK/DS 2D-6A 500292116801 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7~96 DATE OF SURVEY: 081996 JOB NUMBER: AK-MM-60101 KELLY BUSHING ELEV. = 121.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 72 73 74 76 05.00 5027.52 4906.52 2926.02 N 3602.28 E 2177.48 44.09 5121.00 5000.00 3008.82 N 3663.16 E 2223.09 89.79 5221.00 5100.00 3106.11 N 3704.47 E 2268.79 34.91 5321.00 5200.00 3209.55 N 3722.30 E 2313.91 45.61 45.70 45.13 77 79 8O 82 83 79.24 5421.00 5300.00 3313.18 N 3716.29 E 2358.24 26.51 5521.00 5400.00 3418.52 N 3692.11 E 2405.51 76.42 5621.00 5500.00 3527.90 N 3669.63 E 2455.42 28.71 5721.00 5600.00 3641.50 N 3653.05 E 2507.71 80.75 5821.00 5700.00 3753.20 N 3628.22 E 2559.75 44.32 47.27 49.91 52.30 52.04 85 86 88 89 9O 34.62 5921.00 5800.00 3866.07 N 3597.65 E 2613.62 89.35 6021.00 5900.00 3981.60 N 3573.46 E 2668.35 41.12 6121.00 6000.00 4094.10 N 3554.15 E 2720.12 88.40 6221.00 6100.00 4199.91 N 3531.94 E 2767.40 80.00 6282.83 6161.83 4265.80 N 3516.90 E 2797.17 53.87 54.73 51.77 47.28 29.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVERNOR ALASKA OIL A~ GA~ 3001 PORCUPINE DRIVE &.",I'C.u. OPAGE, A.I_ASKA 99501-3! ~2 Pi~ONE: (907) 279-1433 F,,D(: (907) 276-7542 June 21, 1996 Michael Zanghi, Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2D-06A ARCO Alaska, Inc. 96-116 124'FSL, 510'FEL, Sec 23, T11N. R9E, UM 864'FNL, 2207'FEL, Sec 24, T11N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by la~v from other governmental agencies, and does not authorize conducting re-drilling operations m~til all other required permitting determinations are made. Blowout prevention equipment (B OPE) must be tested in accordance with 20 .~-XC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to w/mess a test of BOPE installed prior to drilling a new hole. Notice mav be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659- 3607. · David W Jo Chairman BY ORDER OF THE COM2VIISSION dlf/encl c: Dept ofFish & Game, Habitat Section.- w/o encl Dept of Envh'onmental Conservation - w/o encl STATE OF ALASKA ALASNA OILAND GAS CCNSERVATICN COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon ~ Suspend Alter casing _ Repair weii_ Change approved program _ 2. Name of Operator ARCO Alaska, Ipc, 3. Address P. O. Box 100360, Anchorage, AK: 99510 Operation Shutdown _ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other X Plugback for redrill j5. Type of Well: Development Exploratory Stratigraphic ] Service 4. Location of well at surface 124' FSL, 510' FEL, Sec. 23, T11N, RgE, UM At top of productive interval 1461' FNL, 1502' FEL, Sec 24, T11N, RgE, UM At effective depth 1181' FNL, 1255' FEL, Sec. 24, Tl lN, R9E, UM At total depth 1131' FNL, 1205' F-WL, Sec. 24, TI1N, R9E, UM 6. Datum elevation (DF or KB) RKB 126'. Pad Elev. 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2_D-06 9. Permit number 8-607 10. APl number 50-029-21 11. Field/Pool Kupurak River Field/ KuDaruk River Oil Pool 12. Present well condition summary Total Depth: measured (approx) true vertical 9140' feet Plugs (measured) 6269' feet Effective depth: measured (approx) true vertical 9038' feet Junk (measured) 62 1 6' feet Casing Length Size Cemented Structural Conductor 11 O' 1 6' 224 Sx CSII Surface 4104' 9-5/8' 1070 sx ASIil Intermediate 765 sx Class G Production 91 20' 7' 560 sx Class G Liner 41 bbls ASI Perforation depth: measured 8746'-8802', 8712'-8727', 8608'-8632' MD true vertical 6058'-6090', 6037'-6047', 5973'-5988' TVD Tubing (size, grade, and measured depth) 3-1/2', 9.3#, J-55, EUE, 8673' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1932' Packers: Baker FHL 8439', Baker FB-1 8656' ~ . Measured depth 110' 4104' 9120' True vertical depth 110' 3160' 6259' RECEIVED ,JLtl, I ! ~t t996 Anc?..o:zg¢ / 13. Attaci~mems Oescnption summary of proposal ~ Detailed operation program BOP sketch _ Estima~ecl date for commencing operation 14. June 26. 19~{ 16..-If proposal was verbally approved 15. Status of well classification as: Oil , Gas __ Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best · .,.. Title Drillinc~ Encjineer FOR COMMISSION USE ONLY Service of my knowledge. Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- IApproval , Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill Re-Entry DeepenI Service Development Gas Single Zone _~_ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 121'. Pad 89' feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25653 ALK 2579 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AA(; 25.025) 124' FSL, 510' FEL, Sec. 23, T11N, RgE, UM KuDaruk River Unit Statewide At top of productive interval 8. Well number Number 1259' FNL, 2159' FEL, Sec. 24, T11N, R9E, UM 2D-06A #U630610 At total depth 9. Approximate spud date Amount 864' FNL, 2207' FEL, Sec 24, T11N, R9E, UM 7/1/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2D-07 9115' MD 2207' @ TD feet 60' at surface feet 2560 6325' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 7 2 0 5 feet Maximum hole anc~le 49° Maximum surface 2705 pslg At total depth (TVD) 3375 pslg 18. Casing program Setting Depth size Specification Top Bcttom Quantitl/of cement Hole Casin~l Weight Grade Coupling Len~h MD 'I-VD MD TVD tinoiude statue data;l 6-1/8' 3-1/2" 9.3# L-80 B'rc 2080' 7035' 4917' 9115' 6325' 337 sxs Class G 19. To be completed for Redrill, Re. entry, and Deepen Operations. Present well condition summary Tolal depth: measured 9140 feet Plugs (measured) true vertical 6269 feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True V~ijio~ ~!~', I ~ / ~.~ r~ Structural l~,E L. L I v L L/ Conductor 1 1 0' I 6" 224 sx CSll I 10' 1 1 0' Surface 4104' 9-5/8" 1070 sx ASIII & Intermediate 765 sx Class 'G" 4104' 3160' JUN 1 4 ]996 Production 9120' 7" 560 sx Class "G" 91 20' 6259' Uner 41 bbls AS I Alaska 011 & Gas Cons. Commis$ior~ Perforation depth: measured 8746'-8802', 8712'-8727', 8608'-8632' MD true vertical 6058'-6090', 6037'-6047', 5973'-5988' TVD 20. Attachments Filing fee .~_ Property plat . BOP Sketch ~ Diverter Sketch ~ Drilling program X Drilling fluid program X Time vs depth plot 21. I hereby certify that the foregoing is true and correct to the best of my knowledge / / q , ,.,..- r~le Drillincj Encjineer Dale -- _ Commission Use Only/ Po~t~ u mT~~ IAPl number I Approval date.~ ~/~:~ ISee c°vor letter f°r '- 50- ~ :Z. ~'" .~//~ ~;r.., c3 {' ~'~ ,,.-- c:~ / ~ other requirements Conditions of approval Samples required .~Y e s ~ N o Mud log required ~ Y e s ~ N o Hydrogen sulfide measures ~ Y e s N o Directional survey required z~Yes Required working pressure for BOPE ~ 2M; ..~ 3 M; ~ 5 M; ~ 1 0 M; ~ 1 5 M Other: Original Signed By David W. Johnston by orde, of Approved by Commissioner the commission Date ._ Form 10-401 Rev. 7-24-89 ttriplicate REDRILL PLAN SUMMARY Well 2D-06A Type of well (producer/injector): Surface Location: Target Location- Bottom Hole Location' MD: TVD' Rig: Estimated Start Date: Operation Days to Complete- Producer 124' FSL, 510' FEL, SEC 23, T11N, R9E, UM 1259' FNL, 2159' FEL, SEC 24, T11N, R9E, UM 864' FNL, 2207' FEL, SEC 24, T11N, R9E, UM 9115' 6325' Nordic Rig 2 6-28-96 14 Drill FIuidE PrQ_aram: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casin~l 9.4 >25 15-35 85-95 20-30 30-40 8.5-9.5 Kick off to weicjht up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 REDRILL PLAN SUMMARY Well 2D-06A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig- Estimated Start Date: Operation Days to Complete: Producer 124' FSL, 510' FEL, SEC 23, T11 N, R9E, UM 1259' FNL, 2159' FEL, SEC 24, T11N, R9E, UM 864' FNL, 2207' Fl:L, SEC 24, T11N, R9E, UM 9115' 6325' Nordic Rig 2 6-28-96 14 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casin~ 9.4 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns RECEIVED Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Program: Hole size Csgrrbg Length Top (MD/'I'VD) Btm (MD/TVD 6-1/8" 3-1/2", 9.3#, L-80, BTC 2080' 7035'/4917' 9115'/6325' Tubing 3-1/2", 9.3#, J-55, EUE 5052' 29'/29' Cement Calculations: Casino to be cemented: 3-1/2" in 6-1/8" open hole /,~ct~r~e Volume - 377 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 50%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,705 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 13.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3375 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,705 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressu red Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 2D-06A, will kick off out of the 7" casing with-in the K-5 interval and +/-1,294' TVD below the K-10. The casing around the kick-off window will be squeezed with cement prior to ddlling out, which should isolate the K-10 from sidetrack operations. The K-5 interval will not be isolated, but should be able to handle the expected mud weights to be used for this sidetrack. Off-set drilling data shows that several wells in the area of 2D-06 were drilled to TD through the K-5 and K-10 intervals with 11.4 ppg mud and no loses. The kick-off point in 2D-06A is below any zones which would be of pressure concem pdor to weighting up for the Kuparuk interval. None Directional- KOP: Max hole angle: Close approach: 7210' MD / 5030' TVD 48.7° (in sidetrack portion) No Hazards 56.6° (in original well at 3000' MD) Page 2 Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes: All ddll solidsgenerated from the 2D-06A sidetrack will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. If the Kuparuk River bridge outage will not allow trucking of these solids to Prudhoe, they will be stored and later processed or disposed of in a permitted solids disposal area. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 2D-06A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU pump truck. Establish injection rate into perfs to confirm injectivity for cement down-squeeze. 2. RU slickline unit. RIH tag fill. Dummy off all GLMs, leave deepest GLM open. Leave circulation valves in all C Sand mandrels. 3. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. 3. NDtree. NU and test BOPE. 4. Screw in landing joint. POOH changing out tubing couplings to a modified thread and stand tubing back in derrick. Lay down all jewelry. PU DP and RIH with cement retainer. Set retainer at 7390' MD. Down-squeeze 55 bbls cement below retainer into perfs filling 7" casing across the C Sand with excess cement to squeeze down past the A Sand perfs if possible. Unsting from retainer and circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. POOH standing back DP. RIH w/section mill. Cut a 50' section in the 7" casing from 7190' - 7240'. POOH w/mill. RIH w/open ended DP. Wash down through section and circulate any metal shavings f/well. Mix and pump balanced cement kick-off plug f/100' below base to 200' above top of section. POOH. RIH w/6-1/8" bit, mud motor, MWD/LWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. Run 3-1/2" liner to TD w/150' of overlap to top of milled section. Cement liner. Set liner hanger and liner top packer. POOH w/DP. Pressure test casing and liner lap to 3500 psi for state test. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. Clean out well to PBTD w/coiled tubing. Perforate through tubing. . . al . 10. 11. 12. 13. 14. Lower Limit:. 12 days Expected Case: 14 days Upper Limit: 20 days No problems milling section, drilling new hole, or running completion. Difficulties encountered milling section, or drilling new hole. WSI 6/13/96 Page 4 ARCO ALASKA, Inc.i Structure : Pad 2D Well : 6A Field : Kuparuk River Unit Location : Horth Slope, Alaska l ~--- Point .... iKOP !End 1st Turn iEnd of Build iTorget iEnd of Hold !End of Hold WELL PROFILE DATA MD Inc Dir ~ North East Deg/lO0 7205 48.72 42.62 5028 2926 3602 0.00 7300 46.73 32.70 5092 2981 5645 8.0< 7712 47.54 353.01 5378 3264 3709 7.0< 8576 47.5~ 353.O1 5961 5897 3631 0.0< 8915 47.54 353.OI 6190 4145 3601 0.0< 9115 47.34 353.01 6325 4292 358~ O.Oq 'iD LOCATION: J 864' FNL, 2207' F-EL SEC. 24, T11N, RgE -6 4950. c) _ 5100_ .iI _ ~ 5250_ 54oo_ (D 5700_ -.~ L- - I'-- 5850_ I - I 6000_ V - 6150_ TARGET LOCATION: 1259' FILL, 2159' FEL SEC. 24. TllN, R9E Sidetrack Point (Depth Shifted) ~.o, Eoc AVERAGE ANGLE 47.54 DEG Interval N 6.99 DEG W 3824' (TO TD) East --> Scale 1 : 75.00 3150 5500 5450 3600 3750 3900 4050 4200 4550 4500 I.,I I I I I I I I I I I I I I I I I p~l> · TO ~"~ Interval A4 Interval A5 interval B lntar~c~ TA.~OEr - C4 TARGET- C4 / Sidetrack Point (Depth Shifted) , 4500 _4550 _4200 _4050 -3750 I i -- _5500 ~" _5150 _ ~ Q _3OO0 ~ .. _2850 ~ o _ o A5 Interval A4 Interval ntervo op Mi uv~ach 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 Scale 1 ' 75.00 Vertical Section on $53.01 azimuth with reference 0.00 N, 0.00 £ from slot #6A Crec~ecl ~ : jon~ For:, B ISAACSON Dote ~ottsd : 2B-&or-96 Plot Reference ii ~ V~"~t ~5. Coordir~es ore in feet refe~lr~e I, Iot ~ rme Ved~al ~t~ om ~ RKB (~d~ II). 7-1/16" 5000 PS! BOP STACK ANNULAR PREVENTER 7 I 1 ] I ' PIPE RAM I 5 BUND MUD -- CROSS 4 3 PIPE RAM > I ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE UNE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL lINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOI-I'OM PIPE RAMS. TEST BO'FI'OM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BUND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2. 11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4. 7-1/16" - 5000 PSI DRLG SPOOL W/CHOKE & KILL lINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6. 7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER NORDIC RIG ~2 LEVEL 1 z ~ ~ 12._¢o -- 28'-6" EMSCO F-800 (~ TRIPLEX MUD PUMP SPIRAL STAIRS CONTROL'~CONSO,LE ! 25'-0" 40--57 - .u-.ur -- m JU EtVED LEVEL 3 I UNE I !SPOOL I ~ ~ : · LISTER AIR HE.A'rER MUD TANK 750 B81.S SPIRAL STNR$ CHO OFFICE WATER TANK /GLYCOL TANK H'YORAUUC , V~rr~L P-----_i"~li i ~,,,,'-ir'~,.~i%.i_~O i COMPANY ~ WELLNAME 2_.~-'~ PROGRAM: FIELD & POOL ~'(~/¢~ INIT CLASS /"~¢_.z/ ?/, ~-~2'//' GEOL AREA ?"?'C) ......... ADMINISTRATION APPR DATE 1. Permit fee attached ...................... 2. Lease number appropriate .................. 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from drlg unit boundary .... 6. Well located proper distance from other wells ........ 7. Sufficient screage available in drilling unit .......... ~. If deviated, is wellbore plat included ............. 9. Ouerator only affected party .................. 0. Operator has appropriate bond in force ........... 1. Permit can be issued without conservation order ..... 2. Permit can be issued without administrative approval .... 3. Can permit be approved before 15-day wait ......... exp [] dev [] reddl~/serv [] wellbore seg _~ ann. disposal pars req -~ UNIT# /'/,,/'//'~",~ ,, ON/OFFSHORE C~) REMARKS 14. Conductor string provided ................... N 15. Surface casing protects ail known USDWs ......... N 16. CMT vol adequate to circulate on conductor & surf csg . . . ' Y N 17. C MT vol adequate to tie-in long sluing to surf csg ...... N 18. CMT will cover ail known productive horizons ......... N 19. Casing designs adequate for C, T, B & permafrost. ..... N 20. Adequate tankage or reserve pit ................ N 21. If a re--drill, has a 10403 for abndnmnt been approved .... Y.~ N 22. Adequate wellbore separation proposed ............ ~ N 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... 25. BOPEs adequate ........................ "''Y~ N 26. BOPE press rating adequate; test to ,¢ O dO psig. ,.~ N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~ N 28. Work will occur without operation shutdown .......... ~ N 29. Is presence of H2S gas probable ............... ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Da~ presented on potential overpressure zones ....... 32. Seismic a~alysis of shallow gas zones ........... ../ 33. Seabed condition survey (if off-shore) .......... ./Z.. Y N 34. Confact name/phone for weeKl~ progress reports . . . /'... Y N Jexptoratory only] GEOLOGY: ENGINEERING: COMMISSION: Commen[~ins[rucdons: HoW/1."n- A'?C. RMSV-~c, kI~ rev 4,/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0'0806 SgI'9 0'S8I£ 000'£ (£,~) HLdZG (MI) ZZIg (MI) ,qZI$ SEZ~I~IIEG ©NIStfD Z~IOH NZdO Z60 HZLSZM '~ EZLSZM ' G XZ~iO,~ · .g I 0109-Pq~q-)t%f NIlE GMN L6-SZ~-LE SZDIAEZS ©NI~IE~ N_~S-XEEZdS '0MI 'tf){St~f OOY~f I089II~6~00S ~9-GE ©NIE£S ©NIELS ©MIENS DNIELS ~EODZE ©NIS~D :EOO~ MDIEEZG :DNIHS~ (0 ~SM MOE~ L~)NOIL~AZqZ :~M~ :qZ~ :~S~ :Z©krk~ :dIHSNMOL :NOILDZS NOI£~DOq :SSZNLIM :EZZNI©NZ :EZ~PqflM flOD ' :adX~ sT ~ aTT~qAs adeL · ~ S,"','4,T,X'8: 866 ( 0 #,','gcI.Z.J..,) fI'8:OD,"cr'8: Y,T,Y(Z .~ 8~ 66 566 06 ~ 66 ~66 06 ~ 66 S66 06 ~ 66 ~66 O6 ~ 66 0~9 06 ~ 66 ~66 06 ~ TO 0I£ 06 ~ poM sIO clKi cIXi q~6usq ~zys A~D AxO Boq s~Tu~ ssIdm~s spoo IOO& smeM : ssA~no L ~¢-ZS~ffI~ : Zd0%S HLHON : HZAIH M~%~fd~M : ~9-GE : '0MI '~Q{S~I~ 0O~%f : Nfl0O N~ NM ND 'SS~d NI~ ~Z©MZM 0'E806 0'I0P8 0'I0P8 0'S8IL I ZS~S Z©~ZN dOi Z©MZM ON N_fig HLdZ~ CZL~IHSNi1 LMZq~fAI~Z ss~Aq 866 :q~6u~I p~oo~ mnm~xeM ss~Aq E9 :q~BusI p~oo~ mnmTuTM · ''sp~oos~ 0IE E :sIT~qns sdeL smn~ep 600~£ 89 :~poD dsH :J~emmns 5uipoosp ~poo uoI~e~usss~ds~ SIq q~ = SqTU~ qqda~ aiT~ ~d~ 00000~'0 = 6u~o~dS T~ ~T~ ~d~i 000000'00I£ = q~d~ puZ ST[~ ~d~i 000000'0016 = qqd~ q~qS sIT~ ~d~i Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SLIMMARY VENDOR TOOL CODE START DEPTH GR 7125.0 EWR4 7182.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION:. DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMI/M ANGLE: STOP DEPTH 8343.0 8350.0 17-AUG-96 ISC 4.54 DEPII 2.17R MEMORY 8401.0 7185.0 8401.0 0 46.0 49.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 7185.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: WEIGHTED LSND 9.70 46.0 10.0 80O 5.5 1.600 66.0 .880 125.6 .900 66.0 1.200 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 s~Xq 866 :q~Su~I pxoo~x mnmixeM s~Xq ~9 :q~6u~I p~oo~ smn~ep 6080~ 89 :~poD :J~mmns 6u~poo~p ~poo mo~e~u~s~d~ SI~ 00000S'0 = 5uTo~dS I~@q ~IT~ 000000'00IL = Mqd~Q puz aITA 866 (0 #Z~XL) GHOOZH ~L~G ~ 8~ 66 966 06 f 66 ~66 06 ~ 66 ~66 06 f 66 ~66 06 ~ 66 0~9 06 ~ 66 S66 06 9 66 ~66 06 ~ poM sIO dXL dXi qq6u~q szTs SqTUQ s~IdmeS spoD IOOL ~meM :ssA~no £ YMS~ : ZdOrIS H,T,%tON : HZLAI~ MflH~fdflM : %f9 -(I~ : · 0MI '~OtS~ftf OO%{tf : NiiOD NM MD : S)t~Z%t 0 O' : (ZH) XDNaD. O,w'~tet : (NIT) ~,40(:IN'~Vr, S q:OOZ 000 ' 00' : (NI) NOIIDa~OD aqOH :XZISNH~ XI~Z~ qOOZ 0'99 00l'I 0'89 008' 0'~51 01£' 0'89 00S'l O58 0'6 0'~ 09'II G,%T,HD I aM 0'SSIA 000'9 : (HI) HZIS ,l,I~t ,~IOH ~f,T,~f~ ONIS~fO ELKI~ ZqOHH%{O~{ ad.AZ q:O0,1', E(/OD qOO,T, (HO,T,,T,O~E 0,I, cIO,L) DN:I~ZS qO0,1', 6'6f /.'9~ 0 S'I806 0'I0~8 9'I806 fS'f DSI 96-D~-05 0'0506 0'£E06 HZdZ~ dOZS · seil} eqe~des uT un~ qTq qo~e xo} ~qep xep~eq 6oi pu~ seA-nD £ : HZ~IHflN ZqI,~ %tZGtfZH aq I,~ SIq :eclAq sT ~ SiT~qnS edmz s~Xq 866 :M~Bu@I p~oo~z mnmTxeM s~Xq ~9 :M~Bu~I p~oo~ mnmTuTM · ''sp~oo~ £II ~ :~IT~qns smn~p 818~ 89 :~poD d~ :A~mmns 6uTpoo~p ~poo UOTq~qu~s~d~ SI~ 00000~'0 = 5UTO~dS I~q ~IT~ 000000'00£8 = ~d~G P~Z ~IT~ 000000'0016 = ~2d~G 2~m2g ~I~ . SZLX~ 866 (0 #ZdXL) G~OOZH ~fL~gG ~ 8~ 66 ~66 06 ~ 66 ~66 06 f 66 S66 06 ~ 66 966 06 ~ 66 Of 9 06 f 66 966 06 ~ 66 g66 06 ~ pOX sIO dX£ cL~L M~6u~ ~zTs s~Tug s~Idme$ ~poo IOOL ~meM (~9 #ZdXL) GHOOZH L~O~ ~ ~M$~ : ZdO~IS HLHON : HZAIE Mfl~aflX : ~f9 -GE : 'OMI 'YM$~f~ OO~ : N. GOD N~ NO Tape S~bfi[e 5 is type: LIS 97/ 2/27 O1 **** REEL TRAILER **** 97/ 2/27 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 27 FEB 97 4:26p Elapsed execution time = 2.03 seconds. SYSTEM RETURN CODE = 0
