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Home My WebLink About185-206Image Project Well History File Cover Page XHVZE This page identifies thOse items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J ~__-c~ 0 ~' Well History File Identifier Organization (done) X Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No, [] Other, No/Type TOTAL PAGES: /~' NOTES: ORGA.,ZED~Y: ~ BRE. V,.CENT S.ERY. MARIA LOWEL, Project Proofing OVERSIZED (Scannable) [3 Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: I t~) .~) (at the time of scanning) SCANNED SY: BEVE.LY I~ VINCENT SHERYL MARIA LOWELL RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) Rev1 NOTScanned.~od PLUGGING & LOCATION CLEAR~_NCE R~,PORT State of Alaska . ALA~K~ 0iL & GA~ CTNSERVATION CCMMISSION .~ev'lew the well file, a.n~-c=mmen= on plugging, well head oA'?, -~/,~, ~9-._----0 / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~v,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas I--'1 Suspended D Abandoned r~ Service Fl 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 185-206 3. Address 8. APl Number P. O. Box 10360 Anchorage, AK 99501-0360 50-029-21432 4. Location of well at surlace 9. Unit or Lease Name 4750' FNL, 748' FEL, Sec. 7, T12N, R9E, UM (asp's 507699, 5996908) i LO~T~OI~i. Kuparuk Unit At Top Producing Interval I V~__~,~ ! ! 10. Well Number 4520' FNL, 1165' FEL, Sec. 18, T12N, R9E, UM (asp's 507305, 5992244) ~ ~t~r~. 3A-03 At Total Depth ~.~! 11. Field and Pool 4518' FNL, 1238' FEL, Sec. 18, T12N, R9E, UM (asp's 507233, 5991861) Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 72 feetI ADL 25632 / ALK 2565 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 9, 1985 September 15, 1985 December 12, 2000 (P&A'd)I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8390' MD / 6378' TVD 7697' MD / 5847' TVD YES r~ No FII 513' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/SP/CAL, BHC/GR, CET, GOT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD AMOUNT PULLED CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORD 16" 62.5¢ H-40 Surface 106' 24" 187 SxAS II 9-5/8" 36¢ J-55 Surface 3888' 12-1/4" 1200 Sx AS III & 320 Sx Class G 7" 26# J-55 Surface 8370' 8-1/2" 425 Sx Class G & 250 Sx AS I 20u /-~iaska UII & U,;3S CORS. L;omrrlissl( 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) 3-1/2" 7715' 7680' * Plugged & Abandoned all open perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See P&A Summary) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I N/A Test Pedod > 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 pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-403 form approved November 29, 2000 (Approval fl300-290) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERb MEAS. DEPTH 7786' 7873' 7996' TRUE VERT. DEPTH 5914' 5980' 6073' 6197' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. 8158' GOR, and time of each phase. N/A JaN ~ o~ 2001 Alaska 0il & Gas Cons. Commissioli Anchorage 31. LIST OF ATTACHMENTS Summary of 3A-03 Pre Coil Tubing Sidetrack Plug & Abandonment Operations. 32. I hereby cedify that the following is true and correct to the best of my knowledge. Signedv/~.i~'~.../~_.- ~..~,~ Title Co Tubin.qDrillin.qEn,qineer Lamar Gantt Date Prepared by Paul Rauf 564-5799. 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 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 3A-03 DESCRIPTION OF WORK COMPLETED PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 11/25/2000: 11/13/2000: 12/03/2000: 12/08/2000: 12/09/2000: 12/10/2000: 12/11/2000: 12/12/2000: 1 2/13/2000: RIH w/slickline & tagged fill @ 8206' MD. Dummied GLV's. Displaced casing w/Diesel. PT'd casing to 2250 psi - passed. RIH & performed SBHP Survey @ 7874' & 7674' MD. MIRU CTU#4 & Nabors 3S. Rig accepted 0100 hrs. NU BOP Stack. Completed RU. PT'd BOPE. RIH w/CT. A CTU Cement Plug was pumped to Plug & Abandon the lower wellbore prior to ST operations as follows: Tagged PBTD @ 8206' MD. Killed well w/140° Seawater. Pumped 5 bbls of Neat 17 ppg Class G Cement, followed by 15 bbls of 17 ppg Class G Cement w/ aggregate, followed by 15 bbls of Neat 17 ppg Class G Cement to abandon the open perforation intervals located f/: 7790' - 7874' MD (Zone C-3, C-2, C-1, & B) 7882'- 7892' MD (Unit B) 8010' - 8034' MD (Zone A-3) 8050' - 8089' MD (Zone A-2) Layed in cement 1:1 until above perfs. Placed 14 bbls of Cement behind pipe @ a max squeeze press of 160 psi. Contaminated cement w/Biozan & cleaned out to the 7620'. POOH. WOC. PT'd cement plug to 2000 psi - bled to 1600 psi in 10 min. RIH & tagged TOC @ 7697'. PUH to 7400' & established injectivity of 1 bpm @ 1950 psi. POOH. RIH w/parabolic mill to 7820' w/no motor work. Slight motor work to 7844'. Hard tag @ 7845'. POOH w/mill. RIH w/UR & made pass to 7730'. Pumped Biozan sweep. POOH w/UR. RIH w/CT nozzle f/2nd cement plug. Pumped 2 bbls of Neat 17 ppg Class G Cement, followed by 10 bbls of 17 ppg Class G Cement w/20#/bbl aggregate, followed by 9.4 bbls of Neat 17 ppg Class G Cement. Bullheaded 2.4 bbls of cement behind pipe & achieved 1500 psi squeeze press. Bumped WHP to 2500 psi - held fine. Contaminated cement w/Biozan & jetted contaminated cement f/wellbore. POOH w/CT holding 1500 psi WHP. WOC. PT'd cement to 2500 psi for 30 min - held good. RIH w/BHA & logged tie-in. RIH & tagged TOC @ 7697'. Began milling pilot hole f/window. Continued w/3A-03A Sidetracking Operations. Alaska Oil & Gas Con:s. Comrnissiol~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 10360 Anchorage, AK 99501-0360 Location of well at surface ~' ,,/ ,j' 4750' FNL, 748' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 4520' FNL, 1165' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 4518' FNL, 1238' FEL, Sec. 18, T12N, R9E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 507699, 5996908) (asp's 507305, 5992244) (asp's 507233, 5991861) 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3A-03 9. Permit number/,,approval number 185-206 10. APl number ~ 50-029-21432 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 106' Surface 3816' Production 8298' Size 16" 9-5/8" 7" 839O 6378 8213 6240 feet``./' Plugs (measured) feet feet Junk (measu'red) feet Cemented Measured Depth 187 Sx AS II 106' 12oo sx AS III & 320 Sx Class G 3888' 425 Sx Class G & 250 Sx AS I 8370' Tagged PBTD @ 8213' MD on 5/12/1999. True vertical Depth 106' 3098' 6363' Perforation depth: measured 7790' - 7874'; 7882~ - 7892'; 8010' - 8034'; 8050' - 8089'. true vertical 5918' - 5981'; 5987' - 5995'; 6085' - 6103'; 6115' - 6152'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7715' MD. 3-1/2" x 7" BAKER SAB-3 Packer @ 7680' MD. 3-1/2" CAMCO D NIPPLE @ 513' MD. RECEIVE,. Alaska Oil & ~ Cons. Commi~ion Ancflorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation December 4, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed L~~/~.~ Title: Coil Tubing Drilling Engineer FOR COMMISSION USE ONLY Questions? Call Dan Venhaus @ 564-5273. Prepared by Paul Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _~ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission ,~ Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE KRU 3H-10 Intended P&A Procedure Objective: Pump 17 ppg cement to P&A existing interval and provide for a cement whipstock for window milling. Mill window in preparation for CT sidetracking operations. Intended Procedure RU slickline unit, RIH and tag bottom. Drift tubing to 2.80" to nipple at 7703' md. Replace live GLV's with dummy valves. MITIA RU CTU. Mill out 2.75" nipple with 2.80" mill. Load and kill well. RIH with coil, tag bottom. Lay 25 bbls Class 'G', 17 ppg cement in the 7" liner. Squeeze up to 5 bbls cement into open perfs. Wash cement to 7715'. WOC. Tag TOC and PT to 1500 psi November 15, 2000 KRU 3A-03~ ,-'ROPOSED CT .ORIZONTA~ SIDETRACK ~Camco D Nipple @ 513' 9-5/8" Shoe @ 3888' 3-1/2",9.3#, J-55 Production Tubing to Surface Top of 2-3/8" Liner @ 7130' (proposed) Tubing Tail @ 7715' 3-1/2" x 7" Baker SAB-3 Packer @ 7680' Cement Top 7715' Mill Window in 7" Casing @ 7760' ELM 3" Open hole 2-3/8" FL4S 4.6# Liner Cemented & Perforated TD @ 9178' 7" Liner & Perfs P&A'd with 17.0 ppg Cement 7" Shoe @ 8370' PCR11/17/2000 ARCO Alaska, Inc. (513-514, OD:3.500) Gas Lift ~ Mandrel/Valve 1 (3296-3297, OD:5.390) Gas Lift Mandrel/Valve 2 (48224823, 0D:5.390) Gas Lift Mandrel/Valve 3 (5349-5350, OD:5.390) PBR (7664-7665, 0D:3.500) SEAL A~ .i (7679-7!" I ..... ! OD:3"~ I I (7680-7~ ' OD:6.! (7703-7' ' OD:3.!.., SOS (7715-7716, OD:3.500) (7790-7874) Per[ (7882-7692) Ped (8010-8034) Peri (8050-8098) GKA 3A-03 3A-03 APl: 1500292143200 II Well Type: PRODI Angle @ TS: Il40 deg @ 7792 IWORKOVER SSSV Type: INone Last W/O: I Angle @ TD: 139 deg @ 8390 Annular Fluid: I Odg Completion: 19/16/85 Rev Reason: BY VG Reference Log: I Ref Log Date: I Last Update: 7/5/99 Last Tag: 18213 TD: 18390 ftKB Last Tag Date: ~5/5/99 Max Hole An~]le: 149 deg ~ 4000 Casing String - CONDUCTOR Size I Top I aottom I TVD I Wt I Grade I Thread 16.000 0 106 106 J 62.50 I H-40 I Welded Casing String - SURFACE Size I Top I Bottom TVD J Wt J Grade Thread 9.625 0 3888 3098 J 36.00 J J-55 RTC casing string ,PRODUCTION · Size J Top I Bottom TVD I Wt IGrade I Thread 7.000 0 8370 6363 I 26.00 I J-55 BTC TUbing:string:-TUBING:,: i ~:: :~:i : ::i':i :ii:i . = Size I Top I Bottom TVD Wt Grade I Thread 3.500 J I° 7715 5861 I 9.30 I J-55 J EUE-ABM Perfor~ti~inssumma~::::::i: : ::::: :'i::';:::: '~::. : ~: : ::::: :':. Interval TVD I Zone ~StatuslFeetlSPF~ Date! Type I Comment 7790-7874 5918-5981/UNIT/ I 64112~1/20/85~IPERF J5"CG, 120 deg phase 7882-7892 5987- 5995 UNIT B 10 1 1/20/8 IPERF 5"CG, 120deg phase 8010-8034 6085-6103 ! A-3 / I 24 4~11/20/85~IPERF 14"CG, 90 de~l phase 8050-8098 6115 6152 ! A-2 ! I 48 4~ll/20/8qPERF 14"CG, 9Odegphase Ga:s::Liff:Ma;ndr~iS:Nalves·. . . . StnI MD ITVOIManIMan IVMfr I VType IVOD'lLatchlPortl'TROI 'Date ! Vlv I I IMfr I TYPe I I I / I I I Run ~omment II 32961 27061CAMCOI KBMM I I GLV I 1.0 /aK 10.1881 12921 5/13/99 / 2 I 48221 37431 CAMCO I KBMM I I GLV I 1.0 !BK 10.2501 14031 5/13/99 / 3I53491 41141CAMCOI KBMMI I ov I 1.0 /BE 10.3131 015/13/99 ! 4I 63451 46421CAMC01 KSMM I I DMY I 1.0!BEI0.0001 01 5/13/99 / 5 I 70811 53881 CAMCO I KBMM I I DMY I 1.0 /BK 10.0001 01 5/13/99 ! 6I 76071 57791CAMCOI MMG I I DMY I 1.5 IRK 10.0001 01 5/13/99 / ;Other (plugs~eqdip;,:. etc:):~:JEWEER¥ :; :: .. ;. Depth ITvDI 'l:Yl~e DesCription I ID 5131 5131 NIPPLE IcAMCO D Nipple' Pulled cAT sv °n 7/23/98. I 2.812 76641 5822 PBR lEaker80-40 I 3.000 76791 583318EALASSY IaakerKBH-22 I 3.000 76801 58341 PKR IBakerSAB-3 I 3.250 77031 58521 NIP ICamco O Nipple I 2.750 77151 58611 SOS IBaker, pinned for 3500 psi I 1.750 6 2 I ' iii · COILED 'I'UBI. NI~ UHIT BOP E(;IU 1 PMENT 1. 5000 PSI ?" WELLH[.AD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. ~)000 PS1 4 1/16" STUFFING BOX H ! REL ] NE BOP EOU ! PHENT ii i i L_ 1. 5000 PSt ?" W£LLH[.AD CONNECIOR rLANI~£ 2. 5ODO PS! W~RELIN[ RAUS (VARIABLE SIZE) 3. 5000 PS~ 4 1/6" LUEIRICA~OR 4. 2000 PS~ 4 1/6" FLOW ZUB£ PACK-OFF ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 16, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3A-03 (Permit No. 85-206) Report of Sundry Operations Dear Mr. Commissioner: ORIGINAL Enclosed is report of Sundry Operations for the recent workover operations on KRU 3A-03. If there are any questions, please call 265-6120.. Sincerely, G. L. Alvord Drilling Engineering Supervisor Kupamk Drilling Anchora..r.y; GLA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing ~X Alter casing Repair well X Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 27' Rig RKI~ 3. Address: Exploratory__, 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service Kuparuk River Field 4. Location of well at surface: 8. Well number: 527' FSU 749' FEU Sec. 7, T12N, R9E, UN 3A-03 At top of productive interval: 9. Permit number/approval number: 1142' FSU 1165' FEU Sec. 18, T12N, R9E, UN 85-206/ At effective depth: 10. APl number:, 50-029-21432 At total depth: 11. Field/Pool: 759' FSI_, 1221' FEL, Sec. 18, T12N, R9E, UN Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 8390' Plugs (measured) true vertical 6377' Effective Deptt measured 8210' Junk (measured) true vertical 6239' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 187 sx AS 11 106' 106' Surface 3862' 9.625" 1200 sx AS I{I & 320 sx Class G 3888' 3098' Production 8345' 7" 425 sx class G & 250 sx AS I 8370' 6363' Liner Perforation Depth measured 7790'-7874', 7882'-7892', 8010'-8034', 8050'-80 true vedical 5918'-5981' 5987'-5995', 6085'-6103' 6115'-61~ Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7715' Packers and SSSV (type and measured depth) Baker SAB Perm Pkr @ 7680', No SSS~ 13. Stimulation or cement squeeze summary '~ ~'~ ~'~ 'I, ,_, ~(i~!i~.~,, _.. Intervals treated (measured~ N/A Anchora~ Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _X Oil _X Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Date Signed,/~.. ~ ~ ~_.~,~. ~.~ ~). ~'~.r~' . .................. Form 1~-40~, Rev 06/15/88 SUBMIT IN DUPLICATE WELL HISTORY HANDOVER FORM Well 3A-03 KRU Workover X APl # 50-029-21432-00 New Well PTD# N/A Completion Date 5/5/99 WELL INFORMATION SITP lAP OAP BHP /Depth / Date / Inst. 240 240 0 Description Weight(ppg) Packer fluid I Diesel/Brine 6.7 / 9.8 Tubing fluid I Diesel/Brine 6.7 / 9.8 To Production X To Drilling Rig Name Nordic Rig #3 Approx Depths 2150' 2150' DIRECTIONAL INFORMATION RKB 28.7 KOP 497' Avg Hole Angle 44 Max angle of 49 @ 2913' Hole Angle @ TD 38 NEWt ADDED OR RE-PERFED INTERVALS Top Bot SPF Gun Type Date All Original Perfs 7790' 7892 12 IPERF 11/20/85 7882' 7892' 12 IPERF 11/20/85 8010' 8034' 4 IPERF 11/20/85 8050' 8098' 4 IPERF 11/20/85 AFE Number '999339 Drillers TD 8390' DOWNHOLE INFORMATION PBTDFFop of fill or Junk: 8210' BPV Installed Way Check Downhole Plug Size Wt. Cond. 16" 62.58# Surf. 9 5/8" 36# Prod. 7" 26# Prod. Tubg. 3.5 9.3# KNOWN Communication Date Tagge¢ IA VR Plug OA VR Plug 5/3/99 CASING/'rUBING DATA Grade Conn. H-40 Welded J-55 BTC-MOD J-55 BTC-MOD Depth Top Bot 0' 106' 0' 3888' 0' 8370" L-80 EUE 8rd Mod 0' 7715' Tubing E~ lA ~ OA ~---~ SURFACE EQUIPMENT Tree 3 1/8" 5K FMC Gen IV Tree Cap Corm 7" Otis Acm (Type/Pressure Rating) Tbg Hgr Corm 3.5 EUE 8 rd COMPLETION INFORMATION Depth Item Mfgr Model Vlv Size OD ID Valve Latch 513 Nipple Camco DS 2.812 3296 GLM Camco KBMM 1" 5.390 2.920 DV BK-5 4822 GLM Camco KBMM 1" 5.390 2.920 DV BK-5 5349 GLM Camco KBMM 1" 5.390 2.920 DV BK-5 6345 GLM Camco KBMM 1" 5.390 2.920 DV BK-5 7081 GLM Camco KBMM 1" 5.390 2.920 DV BK-5 7607 GLM Camco MMG 1.5" 5.968 2.920 open RK 7664 PBR Baker 80-40 5" 3" 7679 Seal Assy Baker KBH-22 7680 PKR Baker SAB-3 5.9375 3.25 7703 Nipple Camco D 4.5" 2.75" 7715' BSSOS Baker Pinned for 3500psi 4.5" 1.75"/3" (Sheared out 5-6-99) Rig released subsequent to full well completion as required on State Drilling permit: Yes No If no, specify remaining operations: ENVIRONMENTAL SITE INSPECTION Location Clean/Cellar Clean GENERAL INFORMATION E~ Note: 5/8" Well head is crooked?? 9 extremely Appears to have been installed this way?? PBR pinned for 39,600wtpull - Is sheared Camco Note: These (5) KBMM were originally set up for lC-23 '¢~ GLM @ 7607 RP Valve Sheared BSSOS @ 7715 Sheared Drilling Dept. Rep. Dead W. Gladen Production/Oper Dept. Rep. Denise Petrash Title Drlg Supv Date 5/8/99 Title Prod Eng Date 5/8/99 TUBING DETAIL 3-1/2" Single Producer WE LL: 3A- 03 KRU ARCO Alaska, Inc. DATE: 5/6/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Nordic RKE 26.88 26.88 26.88 FMC 7 1/16" X 3 1/2" Gen IV Tubing Hanger 3.15 26.88 Spaceout Pup Jr. 3 1/2" L-80 EUE 8rd Mod Tbg (10.05+ 6.15 ) 16.20 30.03 Jts 225-239(15 Jts )3 1/2" 9.3# L-80 EUE 8rd Mod Tbg 467.10 46.23 Nipple Camco "DS" Nipple w/2.812" No-Go profile 1.21 513.33 Jts 136-224(89Jts)3 1/2" 9.3# L-80 EUE 8rd ModTbg 2771.64 514.54 Pup !Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.05 3286.18 GLM # 1 3 1/2" X 1" Camco "KBMM" w / DV installed, BK-5 Latch 6.83 3296.23 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 9.61 3303.06 Jts88-135 (48Jts)3 1/2" 9.3# L-80 EUE 8rd ModTbg 1500.30 3312.67 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.02 4812.97 GLM # 2 3 1/2" X 1" Camco "KBMM" w / DV installed, BK-5 Latch 6.83 4822.99 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 9.58 4829.82 Jts 72-87 (16 Jts)3 1/2" 9.3# L-80 EUE 8rd Mod Tbg 500.34 4839.40 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.04 5339.74 GLM # 3 3 1/2" X 1" Camco "KBMM" w / DV installed, BK-5 Latch 6.82 5349.78 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 9.54 5356.60 Jts41-71 (~31Jts)3 1/2" 9.3# L-80 EUE 8rd ModTbg 969.03 5366.14 Pup Pup Jr. 3 1/2" L-80 EUE 8rd Mod Tbg 10.03 6335.17 GLM # 4 3 1/2" X 1" Camco "KBMM" w / DV installed, BK-5 Latch 6.84 6345.20 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 9.55 6352.04 Jts 18-40 (23Jts)3 1/2" 9.3# L-80 EUE 8rd Mod Tbg 710.13 6361.59 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.10 7071.72 GLM # 5 , 3 1/2" X 1" Camco "KBMM" w / DV installed, BK-5 Latch 6.79 7081.82 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 9.56 7088.61 Jts2-17 (16Jt)3 1/2" 9.3# L-80 EUE 8rd ModTbg 499.26 7098.17 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.04 7597.43 GLM # 6 3 1/2" X 1 1/2" Camco "MMG" w/RP Shear Valve Installed 8.21 7607.47 (3000psi casing to tubing shear) . RK Latch 7615.68 Pup Pup Jt. 3 1/2" L-80 EUE 8rd Mod Tbg 10.01 7615.68 Jt#1 (~1Jt)3 1/2" 9.3# L-80 EUE 8rd ModTbg 31.32 7625.69 Remarks: String Weights with Blocks: 82K Up. 65K Dh. 25K Blocks& TD. Ran 239 oints of tubing. Drifted tubing & hanger with 2.867" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-coated. All tubing is new Nordic Rig #3 Drillin~l Supervisor: Dearl W. Gladden CASING / TUBING / LINER DETAIL 3-1/2" Single Producer WELL:3A-03 KRU ARCO Alaska, Inc. DATE: 5/6/99 Subsidiary of Atlantic Richfield Company 2 OF 2 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Pup Pup Jr. 3 1/2" L-80 EUE 8rd Mod Tbg 7,92 7657.01 Baker "80-40 PBR w / 10' eft. Stk (39K shear) 13.37 7664.93 Space out above PKR 1,00 7678,30 Seals Baker "KBH" Anchor Seal Assy w / 3" ID ,92 7679,30 PKR Baker "SAB - 3" PKR 7"X 3 1/2" Perm Pkr (5.968"OD X 3.25"1D) 4,91 7680.22 Pup Pup Jt, 3 1/2" L-80 EUE 8rd Mod Tbg 8,15 7685,13 Pup Pup Jt, 3 1/2" L-80 EUE 8rd Mod Tbg 10,05 7693,28 Nipple Camco "D" Nipple 3 1/2" w/2.75" No-Go profile 1,00 7703.33 Pup Pup Jr. 3 1/2" L-80 EUE 8rd Mod Tbg 10,13 7704,33 Baker 3 1/2" Shear Sub(Pinned (7) @ 3500psi) ,91 7714,46 B~M of Ass~ 7715.37 Remarks: Nordic Rig #3 Drilling Supervisor: Dead W. Gladden Date: 5/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS _ -- WELL:3A-03 WOE WELL_ID: 999339 TYPE: AFC: 999339 API NUMBER: 50-029-21432-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:05/01/99 START COMP:04/30/99 RIG:NORDIC 3 STATE:ALASKA BLOCK: FINAL: WI: 0% SECURITY:0 04/30/99 (C1 TD: 0' PB: 0' 05/01/99 (C2) TD: 8390' PB: 8280' 05/02/99 (C3) TD: 8390' PB: 8280' 05/03/99 (C4) TD: 8390 ' PB: 8280' 05/04/99 (C5) TD: 8390' PB: 8280' PULL VR PLUG & BPV. SITP MW: 0.0 SUPV:DONALD L. WESTER Turn key rig move from 3H pad to 3A pad. Accept rig e 1800 hrs. 4/30/99. UPCOMING OPERATIONS:PUMP KILL WEIGHT FLUID AROUND. N/D TREE & N/U 11" 5M DOUBLE GATE BOP STACK. PULL 3.5" ESP. FIRST PILL SLOWED LOSS. P MW: 0.0 SUPV:DONALD L. WESTER Hold safety meeting. Kill well pumping seawater down tubing. Pump kill weight brine. N/D tree. Nil BOPE and test to 300/3500 psi. Hole taking fluid 60 bph. Pump high vis pill spot at perfs. UPCOMING OPERATIONS:PULL TBG & ESP CABLE. RIH W/ BIT AND SCARPER TO PBTD 8280' P/U BIT & SCRAPER SPACED MW: 0.0 SUPV:DONALD L. WESTER Mix and pump 30 bbl high vis pill. Mix & pump pill #2. Pull 3.5" ESP completion. Pump Thixsal. UPCOMING OPERATIONS:RIH W/ DUMMY PUMP RIH SLOWLY W/ 5.62" OD DU MW: 0.0 SUPV:DONALD L. WESTER RIH w/scraper. Unable to reverse and clean hole. POOH w/scraper. Pump pulled from hole had large rocks & steel fillings causing pump failure. RIH w/sample bailer. POOH. Recover formation fine sand. RIH w/duramy pump. UPCOMING OPERATIONS:POOH RUN USIT LOG FINISH N/U BOPS ON NEW GE MW: 0.0 SUPV:DEARL W. GLADDEN TIH w/dummy pumps and drift to 7400' Change scope of well completion, well will be completed as single producer. Set storm packer and test to 3000 psi, OK. N/D BOPs to C/O tubing spool and tree to Gen IV for completion. UPCOMING OPERATIONS:TOH L/D DP - MAKE SL GUAGE RUN - RUN COMPLETION Date: 5/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/05/99 (C6 TD: 8390' PB: 8280' 05/06/99 (C7 TD: 8390' PB: 8280' 05/07/99 (C8 TD: 8390' PB: 8280' TIH W/ 3 1/2" TBG COMPLET MW: 0.0 SUPV:DEARL W. GLADDEN NU Gen 4 tbg spool and test packoff to 3000 psi, OK. N/U BOPs and test to 250/3000 psi. OK. Pull storm packer. Spill Response rollout. Safety meeting. Run completion assembly. UPCOMING OPERATIONS:FINISH TIH - LAND TBG - DROP BALL & SET PKR - SHEAR PBR - SPACE OUT & RE LAND -PRES TEST TBG N/D BOPS - N/U TREE - FRE MW: 0.0 SUPV:DEARL W. GLADDEN Finish running in hole with 3.5" completion assembly. Set packer ~ 7680'. Attempt to test annulus to 2500 psi, slow pressure loss. Check all surface equipment. Monitor well, well shows slight flow from tubing and annulus. Attempt to set BPV, no go. Well showing more flow. Shut in well. UPCOMING OPERATIONS:MOVE RIG FROM 3A PAD TO iL PAD ( 14.5 MILE MOVE ) MW: 0.0 SUPV:DEARL W. GLADDEN Pump brine, well still flowing. Circ 9.8 ppb brine surface to surface, well static. N/D BOPs. Nil tree and test to 250/5000 psi. Release rig ~ 1800 hrs 5/7/99. UPCOMING OPERATIONS:RIG RELEASED 6:00PM - MOVE TO 1L-03 ~'ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 4, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: KRU 3A-03 Completion Change from Electro-coil ESP to Gas Lift Dear Blair, KRU 3A-03 had been permitted as one of two KRU wells selected to install an electro-coil ESP completion in order to progress KRU lift technology. The scope of this workover included retrieval of the failed ESP completion prior to a wellbore clean-out and setting of the lower packer assembly by the drilling rig in preparation of a coil tubing unit to deploy the ESP on 2-3/8" electro-coil. Once the failed ESP was pulled from 3A-03 it was torn down for a preliminary failure analysis. The initial investigation revealed the ESP had a broken shaft, suffered from a high degree of sand erosion in two of the three sections and had the third fully packed off with formation sand. This initial investigation raised concerns as to the viability of an ESP completion (electro-coil or otherwise) in a well subject to high sand production rates. Due to concerns of ESP run life in this particular well ARCO Alaska, Inc. would like to request the completion technique be changed from electro-coil ESP to a single packer gas lift design (see Attachment). Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling Attachments: Completion Schematic 3A-03 (5/4/99) ltla ka Off a.Sas Cons. AnChorage 3A-0'3 Proposed Comp...don ( Scope Change ) 7" 26# J-55 @ 8,370' N. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down. M. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to the tubing hanger. L. 3-1/2" Camco 'DS' Nipple with 2.812" No-Go profile set @ +/- 500' MD. K. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBMM' mandrels w/DV's, spaced out as follows. GLM # MD TVD -- 1 3,287' 2,700' 2 4,825' 3,745' 3 5,365' 4,125' 4 6,342' 4,840' 5 7,097' 5,400' Note: Each GLM should have 10' L-80 handling pups installed. J. 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/RP Shear Valve installed (3000 psi casing to tubing shear). 10' L-80 handling pup installed on mandrel. D. Pup Joint 3-1/2" x 10' L-80 C. 3-1/2" Camco 'D' Nipple w/ B. Pup Joint 3-1/2" x 10' L-80 A. Baker 3-1/2" shear out sub C-Sand Perfs 7,790' - 7,874' 7,882' - 7,892' A-Sand Perfs 8,010' - 8,034' 8,050' - 8,098' PBTD @ 8,283' - Actual 7" Casing PBTD to LC. TD @ 8,390' I. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod tubing H. 3-1/27 Baker '80-40' PBR w/10' effective stroke (32K lb shear). 8' L-80 handling pup installed. G. Baker 'KBH' Anchor Seal Assembly w/3" ID. F. 3-1/2" x 7" Baker 'SAB3' Hydraulic Set Permanent Packer (5.968" OD x 3.25" ID). E. Pup Joint 3-1/2" x 8' L-80 EUE 8rd Mod tubing. EUE 8rd Mod tubing. 2.75" No-Go profile. EUE 8rd Mod tubing. (3500 psi shear). Tubing tail @ +/- 7,715 '. '" AJaska 0il & 6as Cons. Anchorage MAC 5/4/99 Workover for KRU 3A-03 Subject: Workover for KRU 3A-03 Date: Mon, 3 May 1999 09:25:25 -0900 From: "Chip Alvord" <CALVORD~rnail.aai.arco.corn> To: Blair_wondzell~admin.state.ak.us CC: "Mark A Chambers" <MCHAMBE2@rnail.aai.arco.corn> ..o.,e' Blair, As a follow up to our discussion this past weekend: I misinformed you on the two wells I thought had previously had sundrys approved for electrcoil recompletions - I told you the wells were 3H-11 and 3H-03 and they are actually 3H-11 and 3H-05. These recompletions are coil deployed ESP completions. The ESP cable is inside the 2-3/8" coil tubing and the well is produced via the 2-3/8" x 7" tbg/csg annulus. The scope of the rig preparation for these wells will be to kill the well, retrieve the existing completion and clean out to PBTD (3H-11 had a single selective completion and 3A-03 is a packerless ESP completion with a failed ESP). A USIT log will be run as a caliper to ensure the casing is of sufficient thickness where flow exits the crossover from the packer bore to the annulus, near the top of the packer assembly. The lower packer assembly contains dual flapper vavles, wellbore shut-off devices. The rig will finally install the proper wellhead equipment to for the ESP installation. After the rig is released the final ESP/electro-coil completion will be run with a coiled tbg unit 3A-03 was selected in lieu of 3H-05 due to the higher PI of the well and the increased oil production to be realised. Sorry for the confusion this past weekend and thanks for you help resolving the situation. Please call if you have any questions (265-6120). Regards, Chip Alvord 1 of 1 5/3/99 10:03 AM MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson'~ DATE: May 1, 1999 Chairman THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: Lawrence M Wade~~-~ SUBJECT: Petroleum Inspector ac2geagf. DOC BOP Test Nordic 3 KRU 3A-3 PTD 85-206 May 1~1999: I traveled to Kupurak to witness a BOP test on Nordic 3. They had forgotten to apply for a sundry notice and had to get a verbal from Blair Wondzell. The test went well once underway but we had a small leak at a nipple and hydraulic hose on a control line to the BOP stack. The rig was clean and orderly but in the process of being modified where they can handle a bigger reel for control lines on ESP completions. SUMMARY: Witnessed a BOP test on Nordic 3, 4 hours, 0 failures. Attachments: ac2geagf, xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Other Workover: X DATE: Nordic Rig No. 3 PTD # 85-206 Rig Ph.# ARCO Rep.: Don Wester 3A-3 Rig Rep.: Shane McGheehan Set @ 8,370 Location: Sec. T. R. Weekly 5/1/99 Meddian Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location verbal Standing Order Posted X Well Sign X Drl. Rig ok Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 250/3,00O P f 250/3,000 P I 250/3,000 P I 250/3,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/3,000 f 250/3,000 250/3,000 f 250/3,000 f 250/3,000 I 250/3,000 2 250/3,000 250/3,000 P/F P MUD SYSTEM: Visual Alarm Tdp Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 12 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 250/3,000 P 36 250/3,000 P 1 P Funcb~ned Func#oned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,050 2,100 minutes 12 I minutes 10 Remote: 2400-2250-2400-2300 Psig. sec. sec. X Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Replaced hydraulic nipple and hose to the BOP stack. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade Fi-021L (Rev. 12/94) ac2geagf.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __Stimulate_ Plugging_ Pull tubing Alter casing __ Repair well Perforate Other X Install ESP completion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic _ Service _ 4. Location of well at surface 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1142' FSL, 1165' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 759' FSL, 1221' FEL, Sec. 18, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8390' feet Plugs (measured) 6377" feet 6. Datum elevation (DF or KB) Rig RKB 32' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-03 9. Permit number/approval number 85-206/398-108 10. APl number 50-029-21432 11. Field/Pool (uparuk River Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3862' Intermediate Production 8345' Liner 8280' feet Junk (measured) 6294' feet Size Cemented 16" 187 sx AS II 9-5/8" 1200 sx AS III & 320 sx Class G 7" 425 sx Class G & 250 sx AS I Measureddepth Trueverticaldepth 106' 106' 3888' 3097' 8371' 6362' Perforation depth: measured true vertical 7790'-7874',7882'-7892',8010'-8034',8050'-8098' 5917'-5980',5986'-5994',6083'-6102',6114'-6151' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7709' Packers and SSSV (type and measured depth) RECEIVFO 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JUL 20 ]998 Alaska 0il & Gas C0[,:, Anch0ra~r~ 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~-~ / ~/~- -- _ Title Drilling Engineer Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE Date: 7/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3A-03 RIG:NORDIC # 2 WELL_ID: 999222 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:07/12/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21432-00 07/12/98 (C1) TD: 8390' PB: 8220' 07/13/98 (C2) TD: 8390' PB: 8220' 07/14/98 (C3) TD: 8390' PB: 8220' 07/15/98 (C4) TD: 8390' PB: 8220' 07/16/98 (C5) TD: 8390' PB: 8220' 07/17/98 (C6) TD: 8390' PB: 8220' 07/18/98 (C7) TD: 8390' PB: 8220' N/U 11" double gate stack MW: 0.0 SUPV:DLW Turn key rig move from 3K pad to 3A pad. Accept rig @ 1000 hrs. 7/12/98. Circulate seawater around pumping down tubing. Taking returns to production flowline. Pull tubing MW: 0.0 SUPV:DLW Set blanking plug, N/D tree. N/U BOPE and test to 250/3500 psi. Pull blanking plug. Pull tubing. Monitor well. Try to fill hole taking 60 bph. Mix hi-vis pill. Pump pill. Cut fluid loss. Spot hi-vis pill #2. Spot another pill. Continues to take fluid. Cut weight to 9.9 ppg. Loading pipe shed SUPV:MCH/RO Pull tubing and strap. MW: 0.0 Laying down fish (hole ta MW: 0.0 SUPV:MCH/RO Finish POH w/3.5" tubing. RIH and latch fish @ 7700', jar loose and CBU. Hole taking 40 bph while circ. Pump barocarb pill. Monitor well for losses, lost 8 bph while monitoring. POH w/fish MW: 0.0 SUPV:MCH/RO POH with retrievable packer. RIH with hollow mill. RIH W//BIT & SCRAPER MW: 0.0 SW SUPV:M.C. HEIM & RICK OVERSTREET Milling packer. Push packer down hole to 8180' top of packer. RUNNING PUMP MW: 0.0 SW SUPV:M.C. HEIM & RICK OVERSTREET POH w/fish. Recovered permanent packer. Clean out to 8280' Set and test storm packer to 3000#. NU BOPE and test to 3500#. Pull storm packer. Date: 7/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/19/98 (C8) TD: 8390' PB: 8220' DISPLACING SEA WATER W/DI SUPV:M.C. HEIM & RICK OVERSTREET Run ESP completion. MW: 0.0 SW 07/20/98 (C9) TD: 8390' PB: 8220' MOVE RIG MW: 0.0 SW SUPV:M.C. HEIM & RICK OVERSTREET ND BOPE, NU tree and test to 5000~. OK. Release rig @ 0900 hrs. 7/20/98. Move to 3A-01. End of WellSummary for We11:999222 Prepared by: S. ALLSUP-DRAKE 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operation Shutdown __ Re-enter suspended well Alter casing _ Repair well _ Change approved program _ Plugging __ Time extension _ Pull tubing ~ Variance _ Perforate _ Stim~ate _ Other X Install ESP -- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1142' FSL, 1165' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 759' FSL, 1221' FEL, Sec. 18, T12N, R9E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 72' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-03 9. Permit number 85-206 10. APl number 50-029-21432 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 8390' feet (approx) true vertical 6377' feet Plugs (measured) None Effective depth: measured 8283' feet Junk (measured) (approx) true vertical 6294' feet Casing Length Size Cemented Structural Conductor 80' 16" 187 sx AS II Surface 3862' 9.625" 1200 sx AS III Intermediate & 320 sx Class G Production 8345' 7" 425 sx Class G & Liner 250 sx AS I Measured depth 106' 3888' 8371' Truevedicaldepth 106' 3097' 6362' Perforation depth: measured 7790'-7874', 7882'-7892', 8010'-8034', 8050'-8098' true vertical 5917'-5980', 5986'-5994', 6083'-6102', 6114'-6151' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7959' i : -'.-'~ ~ ~ ~, Packers and SSSV (type and measured depth) Baker FHL Pkr @ 7719' MD, Baker FB-1 perm. Pkr @ 7940', Baker FVL SSSV @ 1780' 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions_. Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation June 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,/~_..__/..~ ~'. ~ Title: Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Date: Conditions of approval: Notify Commission so repres,~tative may witness Plug integrity _ BOP Test __~ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10- ~¢ ~r Approved by the order of the Commission Form 10-403 Rev 06/15/88 u~'~glnal Signed By 0a,f!d W..Johnston oo¢ Commissioner SUBMIT IN TRIPLICATE KRU 3A-03 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w/wireline. Pull valve from bottom GLM leaving an open pocket. Dummy off all other GLM's. 2. RU E-line unit. Chemical cut tubing above and below blast ring joints, adjacent to C Sand perfs. 3. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 11.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/3-1/2" tubing changing out couplings to modified thread. Stand back tubing and lay down all jewelry. 5. PU DP and RIH with spear. Latch into PBR barrel and pull retrievable packer free. POOH with packer and tubing down to cut above blast joints. 6. RIH w/overshot. Wash over tubing stub and fish blast ring joints. POOH and lay down fish. RIH w/overshot and fish remaining completion equipment down to bottom production packer. 7. RIH and mill permanent packer. POOH. RIH with spear and fish permanent packer. POOH w/fish. 8. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. 9. Set storm packer and change out tubing head for ESP completion compatibility. Pull storm packer and verify well is dead. POOH laying down DP. 10. RIH w/Electric Submersible Pump completion on 3-1/2" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 11. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 9.0 days Expected Case: 10.0 days Upper Limit: 12.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 04/17/98 3A-03 Proposed Completion L. 3-1/2" 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. 3-1/2" L-80 EUE 8rd tubing pup below hanger. Flat #1 power cable with tech wire in double armor wrap K. 3-1/2" L-80 EUE 8rd Mod tbg to surface with the bottom +/-1500' Rerun J-55 EUE 8rd Mod IPC. Space-out 3-1/2" x 1" Camco 'KBMM' mandrels (box x box) w/DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 10' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as procedure Cable splice from motor lead to flat #1 power cable adjacent to 10' pup above pump J. 3-1/2" X 1" Camco 'KBMM' mandrel (box x box) with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 3-1/2" x 10' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 10' and 20' pups. H. Pup jt, 3-1/2" x 20' L-80 EUE 8rd Mod tubing. G. Internal sensing Baker 'Sentry' gauge with special cplg to replace conventional cplg on full joint of tubing below gauge. Conductor Wire for gauges will be run to surface with-in the 2nd Armor wrap of ESP cable. F. 1 jt of Rerun 3-1/2" J-55 EUE 8rd Mod IPC tbg w/annulus sensing Baker 'Sentry' gauge clamped to tbg OD. E. 3-1/2" Camco 'D' landing nipple with 2.75" No-Go profile. Standing Valve to be set as nipple is made-up. D. Pup jt, 3-1/2" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. LaSalle Protectolizers at each flange of ESP assembl' C. Centrilift '182 GC8200' Series 513 Triple Taper Pump with bolt-on intake and bolt-on discharge head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift 'GST3 4B HL PFS' Tandem Seal Section. A. Centrilift '570 HP KMH 3560/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/-7701' MD RKB. C Sand Perfs 7790' - 7874' 7882' - 7892' A Sand Perfs 8010' - 8034' 8050' - 8098' 7" 26# J-55 @ 8371' PBTD @ 8283' WSI 3/31/98 ARCO ~ ~' A . .,a.~K¢, !nc. Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1 F-02 Perforate 74--;%:~ 1L-01 Perforate ,C-.'q---i'~-~- 2X-1 3Perforate '¢~,-1~1~ 2X-1 5 Perforate /3A-03 Stimulate 95-~,/,.. 3A-03 Perforate E:~-~-3~' 3A-1 0 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering R£CEiV£D DEC ~! 1 1993 oi~ & Gas Cons. Commission Anchorsge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1. Operations Performed: _.~ STATE OF ALASKA 3KA OIL AND GAS CONSERVATION COMk ON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing , Repair well 2. Name of Operator 15. Type of Well: Development X ARCO Alaska. Inc, Exploratory _ 3. Address Stratigraphic m P. O. Box 100360, Anchorage, AK 99510 . Service __ Other 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit feet%-, 4. Location of well at surface 527' FSL, 749' FEL, SEC.7, T12N, R9E, UM At top of productive interval 1142' FSL, 1165' FEL, SEC.18, T12N, R9E, UM At effective depth 825' FNL, 1226' FEL, SEC.18, T12N, R9E, UM At total depth 759' FSLr 1221' FEL, SEC.18, T12Nr R9E~ UM. 12. Present well condition summary Total Depth: measured 8 39 0' feet Plugs (measured) true vertical 6377' feet Norle Effective depth: measured 8283' feet Junk (measured) true vertical 6 2 9 4' feet Nort9 Casing Length Size Cemented Structural Conductor 7 6' 1 6" 187 Sx AS II surface 3858' 9 5/8" 1200 Sx AS III & Intermediate 320 Sx Class G Production 8 3 41' 7" 425 Sx Class G & Liner 250 Sx AS I Perforation depth: measured 7790'-7874', 7882'-7892', 8010'-8034', true vertical Tubing (size, grade, and measured depth) 8. Well number 3A-03 9. Permit number/Approval Number 85-206 10. APl number 5o-029-21432-00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ~asured depth True ve~ical depth 106' 106' 3888' 3098' 8371' 6364' 8050'-8098' RECEIVED 13. 3 1/2 9.3 lbs J-55 @ 7912', 2 7/8" 6.5 lbs J-55 @ 7938' Packers and SSSV (type and measured depth) SSSV: Baker FVL ~ 1759', PACKERS: Baker FHL ~ 7698', Baker FB-1 ~ 7919' Stimulation or cement squeeze summary REPERFORATE A3 SAND MEMBER Intervals treated (measured) 8010'-8034' 14. .... ji~u u,, & Ca,~ 06,,~. Cu,,mlsst( Anchorage Treatment description including volumes used and final pressure PERFED WITH SCHLUMBERGER 2-1/8" ENERJET "BIG HOLE" CHARGES. PERFED ~ 6 SPF~ 180° PHASING, ORIENTED 90° CCW FROM LOW SIDE OF HOLE. Re~resenlative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 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 I:~st of my knowledge. ,,S~ned f~~, ~/M/~ Title Sr. PetroleumEn,qineer Form 10-404 Rev 09/12/90 Date /Z-/"7---'~ ~ SUBMIT IN DUPLICATE ARCO Alaska, Sul~ldlary of Atlantic Richfield Coml, WELL PBDT 3A-03 ~'z ~'3 ' CONTRACTOR REMARKS TP' 500 f~:~; WELL SERVICE REPOR' ~ 3z~4 ~ FIELD- DISTRICT. STATE JOPER~TION AT REPORT TIME /~ F'c: q~ ~o4o DAYS i DATE £~4. c~'). $ %81, 0-/o o oqoo Oq4O IZI$ 14L5 w;+k Z%" E..,i¢ "'~' ";" ' DEC 2 1 I~o Gas Cons. Commissior~ Anchorage [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knota ~'. 0,,I. ~ REMARKS CONTINUED: DESCRIPTION DAILY ACCU M. TOTAL CAMCO OTIS SCHLUMBERGER '~q 500. DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING ~RACMASTER B. J. HUGHES Roustabouts - Diesel Methanol Supervision Pre-Job Safety Meeting AFE ,= ,. TOTAL FIELD ESTIMATE I Signed _ ,., ~ OIL ~ GAS ~VAT[~ C(~4N 3N REPORT OF SUNDRY WELL OPEl:CATIONS 1. Operations Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 '4. Location of well at surface 527' FSL, 749' FEL, SEC.7, T12N, RgE, UM At top of produ~Ive Interval 1142' FSL, 1165' FEL, SEC.18, T12N, R9E, UM At effective depth 825' FNL, 1226' FEL, SEC.18, T12N, R9E, UM At total depth 759' FSLf 1221' FELa SEC.18a T12N~ R9Ef UM 12. Present well condition summary Total Depth: measured 8 3 9 0' 5. Type of Well: Development Exploratory Stratigraphic Plugging Perforate ~ Other feet Plugs (measured) true vertical 6 3 77' feet None Effective depth: measured 8 2 8 3' feet Junk (measured) true vertical 6 2 9 4' feet Norle casing ~ Size Ceme~ Structural Conductor 7 6' 1 6" 187 Sx AS II surface 3858' 9 5/8" 1200 Sx AS III & Intermediate 320 Sx Class G Production 8 3 41' 7" 425 Sx Class G & Liner 250 SX AS I Perforation depth: measured 7790'-7874', 7882'-7892', 8010'-8034', true vertical 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-03 g. Permit number/Approval Number 8.5-206 10. APl number so-029-21432-00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth ~ue vertical depth 106' 106' 3888' 3098' 8371' 6364' 8050'-8098' 13. Tubing (size, grade, and measured depth) 3 1/2 9.3 lbs J-55 @ 7912', 2 7/8" 6.5 lbs J-55 @ 7938' Packers and SSSV (type and measured depth) SSSV: Baker FVL ~) 1759'~ PACKERS: Baker FHL @ 7698'~ Baker FB-1 @ 7919' Stimulation or cement squeeze summary A SAND FRAC'n. RE TREATMENT Intervals treated (measured) 8010'-8034', 8050'-8098' Treatmeflt description including volumes used and final pressure SEE ATI'ACHED WELL SERVICE REPORT SUMMARY RECEIVED DEC 2 1 199 .,, ~. 0as Cons. Commission Anchorage 14, pcoreseptative Dally Ayeraqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subseclue~t to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby cesti_ fy that the foregoing is true and correct to the best of my knowledge. Signed -~~J' ~'~ Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 150 311 533 . 483 ./' 763 36 16. Status of well classification as: Oil ~ Gas Suspended 118 150 750 157 SUBMIT IN DUPLICATE KUPARUK PETROLEUM ENGINEERING MORNING REPORT DATE: 11/29/93 CPF-3 3A-03 PUMPED A SAND DATAFRAC/REFRAC WITH DS YF140D. DATAFRAC RESULTS AS FOLLOWS: STAGE FLUID VOLUlUiE RATE FWHTP ISI~ FG EXCESS FRIC BD SLK WTR 200 40 6532 1318 .66 -- PI #1 SLK WTR 25 20 3218 1327 .66 462 PI #2 SLK WTR 25 20 3213 1345 .66 439 PI #3 SLK WTR 25 20 3275 1355 .67 418 FLUSH GLD WTR 68 20 3195 1428 .68 338 DF #1 GLD WTR 238 20 3480 1716 .73 335 DF #2 GLD WTR 208 20 3529 1721 .73 379 CALCULATED A FLUID EFFICIENCY OF 48% FROM DATAFRAC #2 BASED ON A CLOSURE PRESSURE OF 4220 PSI & A CLOSURE TIME OF 15.2 MINUTES. CUT PAD FROM 80 BBLS TO 20 BBLS. PUMPED 20 BBLS PAD, 7.0 MLBS 20/40 LWP IN 2 PPA STAGE, 45.3 M_LBS LWP IN 4 TO 8 PPA STAGES. PUMPED ENTIRE JOB @ 20 BPM & SCREENED OUT 61 BBLS INTO THE 8 PPA STAGE @ A MAXIMUM WHTP OF 6300 PSI. TOT PROPPANT: DESIGNED 136 MLBS, IN FORM 35.5 MLBS WITH 6.7 PPA @ PERFS. TOT FLUIDS: WATER 958 BBLS, DIESEL 20 BBLS, ADDITIVES 100 BBLS. RECEIVED DEC 2 3 i993 Anchorage ARCO Alaska, Sul~ldlary of Atlantic Richfield ~/~r~r~iy WELL ~-03 CONTRACTOR REMARKS IPBDT JFIELD - DISTRICT - ~TATE IOPERATION AT REPORT TIME WELL SERVICE REPOR' DAYS - i DATE ~ //-~8-q3 bFQ : qqgOqO/~cO~ : E~T. Co$7": a/og, CuM. Esr. Cost: 0 (~,~ o 0830 oq/o I000 ~qoo~ /$18m . /o3~/ /03'7 P~nZ~ s~l ~ ~o sa/~'* 33 q0~ /355e $5/la /"/,,11~ EFF. I$~5' [.p~b " ,' "IOO 030 8~00~* 1357 8 ~AA " " " I00 030 ,~3¥' 3~o0~ Anchorage [~CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wtltttel' I TlmP' i Chill Flclm' I VlIIbIIIly IwlIM VM'RepoIt 'F 'F mil. REMARKS CONTINUED: i' DESCRIPTION I DALLY ACCUM.ToTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel /,5'0 ~J$. ,~/~,30. OO Methanol · Supervision .. V~co b~P ~ Y~¢.7~uc.X ~3,~6'o.o0 Pre-Job Safety Meeting AFE qct$O~tO/ TOTAL FIELD ESTIMATE ,~/Oq.~q?~7. 08 #1,25',5¥7.08 ... ARCO Alaska, Inc. Date: November 13, 1989 Transmittal #: 7603 RETURN TO: ARCO Alaska, Inc. Atln: Jenny Gamage Kuparuk Operations File CLerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 C-08 Kuparuk Fluid Level Report 1 1 - 4 - 8 9 Casing, Tubing 3A-03 Kuparuk Fluid Level Report 1 1-3-89 Tubing 1C-08 Kuparuk Fluid Level Report 1 1 -2-8 9 Tubing 1 C- 08 Kuparuk Fluid Level Report 1 1 - 2 - 8 9 Casing 3 C, - 1 4 Kuparuk Fluid Level Report 1 1 - 5 - 8 9 Tubing Receipt Acknowledged: DISTRIBUTION: BP Chevron D&M Mobil State of Alaska Unocal CC: DS Engr. NSK Files Prod. Foreman KUPARUK FLUID LEVEL REPORT SSSV__ GLM DV or GLV Fluid Level Shot Down: Casing ~ Tubing CSG Press During Shot= # TBG Press During Shot = Reason For Shooting FL: To Determine Operating Valve Well Status: -~.,~_. ~.:, Found @ Ft Comments: On Continuous GL Operating CSG Press= ~ # GL Rate (If Available) MCFD On Intermittent GL On Time=__ Min. Off Time = Hr. Min. No GL .t /'~/--- ~ ,r.c~,~../z: Alas~ Oil & Gas Cons. Commi lQ ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal Ct: 7470 Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 o ~3A-03 ~'"3A-08 ~"'30-11 ~'"30-13 '~"30- 17 B-14 D 08 ~"3H-1 0 "~3A-08 '~ 30-12 '~30-18 2B 14 O2 16 6 02 O6 O7 25 EM Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Ku Please acknowledge receipt and return Sub-Surface Pressure Survey 2- 1 5 - 8 9 Ku 2aruk Fluid Level Report 4 - 2 3 - 8 9 2aruk Fluid Level Report 4 - 2 3 - 8 9 3aruk Fluid Level Report 4 ~ 2 2- 8 9 2aruk Fluid Level Report 4 - 2 2 - 8 9 2aruk Fluid Level Report 4 - 2 2 - 8 9 3aruk Fluid Level Report 4 - 2 4 - 8 9 2aruk Fluid Level Report 4- 2 4 - 8 9 3aruk Fluid Level Report 4 - 2 4- 8 9 ~aruk Fluid Level Report 4 - 2 4 - 8 9 2aruk Fluid Level Report 4 - 2 9 - 8 9 ~aruk Fluid Level Report 4- 2 9 - 8 9 2aruk Fluid Level Report 4 - 2 9 - 8 9 2aruk Fluid Level Report 4- 3 0- 8 9 2aruk Fluid Level Report 4 - 2 9 - 8 9 2aruk Fluid Level Report 5-03-89 2aruk Fluid Level Report 5 - 0 4 - 8 9 2aruk Fluid Level Report 5 - 0 3 - 8 9 2aruk Fluid Level Report 5 - 0 8 - 8 9 2aruk Fluid Level Report 5 - 0 7- 8 9 )aruk Well Presure Report 1 1 -07-8 #64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal ARCO Alaska, Inco Date: March 24, 1989 Transmittal #: 7447 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return "... 30-16 --- 30-10 · ---- 30-13 ..,,,,~ 3 O- 03 .I 30-15 .,~.. 2G- 14 ~ 2G-13 · ~ 2G-09 ~ 1 E-03 ',,,,,m 1 E-05 30-18 '"""'~ 3 H- 10 ~3A-03 '""~ 3 H-04 ~2B-14 ~30-13 mm-,30-10 "'~' 30- 16 ~'1 B-07 ""'"~1B-03 ~1B-05 "'"'"'"~1B-07 ~1B-07 '"'~ 1L-08 "~',,~1 L- 04 ~"~3 H- 1 0 "~',-3 M-01 Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report 1 -3 - 1 8 9 Sand 'A' 2 - 04 - 8 9 Sand 'A' 2 - 08 - 89 Sand 'A' I - 09 - 89 Sand 'A' 3-04-89 3-11-89 Tubing 3- 1 1 -89 Tubing 3- 1 1 -89 Tubing 3-09-89 Tubing 3-09-89 Tubing 3 - 09 - 89 Casing 3 o 09 - 8 9 Casing 3 - 09 - 8 9 Casing 3 - 04 - 89 Casing 3 - 1 3 - 89 Casing · '2-08-89 #72665 2-04-89 #72655 1 -31 -89 #72655 3 - 31 - 88 Casing 1 -27-88 Tubing 1 -27-88 Tubing 4-27-88 Tubing 1 -27-88 Tubing 2- 1 2- 88 Tubing 2- 1 2~88 Tubing Kuparuk Fluid Level Report 3 - 1 7- 8 9 Cas,10g Report 3-li'~ .~ Kuparuk Fluid Level . ~~as~,~ .... o~ co~s. Commission ~chorage ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '"'~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~O-18 Kuparuk Fluid Level Report 3~ 17- 89 Casing ~~.30-09 Kuparuk Fluid Level Report 3-1 7-89 Casing B 13 Kuparuk Fluid Level Report 3-1 7- 89 Casing Receipt Acknowledged: ........................... Date' - ........... DI,~TRIBUTION' D&M State of Alaska SAPC Chevron Unocal Mobil ~ A~¢horag~ ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report 1 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report I 2 - 1 8 - 8 7 3 F-0 1 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F - 0 9 Kupaurk Fluid Level Report 8-29-87 3 F - 0 6 Kupaurk Fluid Level Report 8-29-87 3F-1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 1 Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N - 1 0 Kupaurk Fluid Level Report 5-18-87 3 N-06 Kupaurk Fluid Level Report 5-22-87 3 N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report 4-24-87 3 N - 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level Report 4-13-87 3 F - 0 8 Kupaurk Fluid Level Report 4-1 4-87 3 N-0 1 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report I 2 - 0 4 ~ 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B - 0 5 Kuapruk Well Pressure Report 2-20-89 1 E- 2 5 Kuparuk Fluid Level Report 2-19-89 3 B-1 I Kupaurk Fluid Level Report 2-20-89 3 A - 0 3 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M-1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casinc~ Casino_ Casino. Casino. Casino. Casino. Casino. Tubing Sand 'C' Sand 'C' BHP Amerada C sin Casing Casing Casing Tubing Tubin~ Casin~ Casin~ 314-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17'-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H- 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DI,,,STRII~UTION: D&M State of Alaska SAPC Unocal Mobil Chevron ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7296 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 0 4 Kuparuk 3 B - 1 3 Kuparuk Kuparuk Kuparuk Kuparuk / I D - 08 Kuparuk - 03 Kuparuk Kuparuk Kuparuk ×/ 1E-06 ' Kuparuk , 1 E- 0 2 . Kuparuk Fluid Level Report 9 - 0 6 - 8 8 Fluid Level Report 9 - 0 5 - 8 8 Fluid Level Report 9 - 0 5 - 8 8 Fluid Level Report 9 - 0 5 - 8 8 Fluid Level Report 9 - 0 1 - 8 8 Fluid Level Report 9 - 0 1 - 8 8 Fluid Level Report 8 - 3 1 - 8 8 Fluid Level Report 8 - 3 1 - 8 8 Fluid Level Report 8 - 3 1 - 8 8 Fluid Level Report 9 - 1 7- 8 8 Fluid Level Report 9 - 1 7- 8 8 Receipt Acknowledged: Casing Casing Casing Casing Casing Tubing Casing Casing Casing Casing Casing ;EP 2 !988- · .~s,::AOil & Gas Co~s. Commiss:.on ............................. · -'rsate :A~,chor-~u~ .......... DISTRIBUTION: D&M State of Alask~ Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Post Office Bc )0360 Anchorage, AlaSka 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal =5806 Transmitted herewith are the follov~ing items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: --~/~R-14 gET/gEL ~J1R-14 gET/gEL 2A-14 gET/gEL ~u-~3A-1 gET/gEL -~3A-2 gET/gEL -uJ3A-3 gET/gEL -,.3A-15 gET/gEL -~3A-16 gET/gEL ~---3C-15 gET/gEL ~a~3C-16 gET/gEL '~J3F-1 gET/gEL ~_3F-10 ,gET/gEL -"-J~-3F~11 CET/CEL ~3J-4 CET/CEL ~3J-6 gET/gEL ~3J-9 gET/gEL 10-12-85 Run #2 8600 ~3 85.50 10-13-85 Run = 10-02-85 Run ~1 6795 10-01-85 Run #1 7550 10-01-85 Run #1 6680 10-01-85 Run #1 6080 12-30-85 Run =2 6400 12-30-85 Run =2 7300 10-!5-85 Run ~1 5887 10-15-85 Run ~1 3995 10-!7-85 Run #1 7000 12-19-85 Run ~1 5166 12-19-85 Run= #1 6950 10-05-85 Run #1 6860 10-19-85 Run ~1 7000 12-18-85 Run #1 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 36 - 6678 REC:IV · Receipt Acknowledged: ..,~---~.,Z/ '~"'~'(D{~i:Se~~Sb~'''/' - _.~~. "" -r' ' . // / ~ Alas.k~ Oil' & Gas Co,r~. OommJssJo,. K Drilling Vault(1 film) A~CO Alask2. Inc. is e Subsidiary of Aliant~cRichfieidCompeny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska, Inc. 85-206 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21432 Classification of Service Well 4. Location of well at surface 527' FSL, 749' FEL, Sec.7, T12N, RgE~ UH At Top Producing Interval 1142' FSL, 1165' FEL, Sec.18, T12N, R9E, UH At Total Depth 759' FSL, 1221' FEL, 5ec.18, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 72' RKB J ADL 25632 ALI< 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 09/09/85 09/15/85 09/16/85* 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8390 'MD ,6377 'TVD 8283 'MD ,6294 'TVD YES [~X NO [] 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-3 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL 1 20. Depth where SSSV set I 21. Thickness of Permafrost 1 780 feet MDI 1500 ' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/SP/CAL, BHC/GR, CET, (:CT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 9-5/8" WT. PER FT. 62.5# 36.0# GRADE H-40 J -55 SETTING DEPTH MD TOP BOTTOM Surf 106' Surf 3888 ' Surf 8371 ' HOLE SIZE 24" 12-1/4" CEMENTING RECORD 187 sx AS I I 1200 sx AS III & 320 s AMOUNT PULLED x Class "G" 7" 26.0# J~55 8-1/2" 425 sx Class "G" & 250 sx AS I 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8098' - 8050' w/4 spf, 90° phasing 8010' - 8034' 7882' - 7892' w/12 spf, 120° phasing 7874' - 7790' SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7959 ' 7719 ' & 7940 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE .pr 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R. FCE!VED APR 0 ]986 Aia~k~ 0it & t~aS C0115, Form 10-407 Rev. 7-1-80 NOTE: Tubing was run & well was pertorated CONTINUED ON REVERSE SIDE GRU1/we02 Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 5914' 5980' 6073' 6197' 30. FORMATION TESTS 7786' 7873' 7996' 8158' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed///_~1~ .~-~_/ Title Associate Engineer 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, a~r 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 aJpplemental records for this well should show the details of any multiple stage cement- ing and the io..~ation'of the cementing tool. Item 27: Method o,f.Op~ration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ,'~i;.' .":~;:,.. ..:' ~ ,..; ,~ ~ :- .. Item 28: If no ¢~.ores taken, indicate "none" Form 10-407 ADDENDUM WELL: 3A-3 Frac well w/319 bbls diesel, 1000# 100 mesh & 8490# 20/40 sand @ avg rate of 14 BPM, 2600 psi. Turn well over to Production. R CF JVED APRO Alask~ Oi! & Gas Oo~s, Anch3r39e Drilling ~uperintendent " Da%e ARCO Alaska, Inc. Post Office B,.... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-3 Dear Mr. Chatterton: Enclosed is a copy of the 3A-3 Well History (completion details) to include with the Well Completion Report, dated 12/4/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L136 Enclosure cc: 3A-3 Well File ARCO Alaska. Inc. is a Subsidiary ol AtlanticRichfieldCompany ARCO 011 and Gas Company Well History - Initial Report- Daily Inltructlona: Prepare and submit the "initial Rel~rt" on the first Wednesday after a well is spudded or workover operations are started. Dai}y work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0260 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25632 Title Completion IState Alaska IWell no. 3A-3 Nordic 1 A_PI 50-029-21432 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Complete 11 / 14/85 0030 hrs. Complete record for each day reported 7" @ 8370' 8283' PBTD, PU 3½" tbg 10.2 ppg NaC1/NaBr Accept rig @ 0030 hrs, 11/14/85. ND lower tree, NU & tst BOPE to 3000 psi. RIH w/6-1/8" bit & 7" csg scrpr, PU 3½" tbg. Date and depth as of 8:00 a.m. 11/14/85 11/15/85 phasing f/8050'-8098', & f/8010'-8034'. gun, 12 SPF, 120° phasing f/7882'-7892'. gun, 12 SPF, 120° phasing f/7790'-7874'. ring & JB to 8000'. RIH w/FB-1WL pkr. 7" @ 8370' 8283' PBTD, RIH w/FB-1 pkr 10.2 ppg NaC1/NaBr Fin RIH, PU 3½" tbg, tag PBTD. Rev circ & filter brine, POH w/BHA & 3½" tbg. RU SOS, perf "A" sand w/4" gun, 4 SPF, 90° Perf "B" sand w/5" Perf "C" sand w/5" RIH w/6-1/8" gage The above is correct Signature For ~orm pre~aration~and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate Title Drilling Superintendent ARCO Oil and Gas ComPany Daily WeII -History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ~Title AFE AK0260 I Completion COSt center code Alaska IWell no. 3A-3 Nordic 1 API 50-029-21432 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 11/14/85 Date and depth as of 8:00 a.m. 11/16/85 thru 11/18/85 Complete record for each day reported Old TD Released rig 1230 hrs. Classifications (oil, gas, etc.) DJ[ Producing method Flowing Potential test data I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prior status if a W.O. 0030 hrs. I 7" @ 8370' 8283' PBTD, RR 6.8 ppg diesel in tbg & ann Fin RIH w/FB-1 pkr, set w/top @ 7919', RD SOS. RIH w/3½" CA, stab into FB-1 pkr, space out & lnd tbg. Drop ball, set FHL pkr @ 7719'. Attempt to press tst tbg to 2500 psi--pmp in formation @ 1000 psi, indication of ball lodged in dn hole equip. Rev circ thru orifice vlv, attempt to press tst tbg w/o success. Drop 2nd ball, re-press up tbg & pmp in formation @ 1000 psi. Shear off PBR, relnd tbg. Attempt to jar 2nd ball free & pmp same dn tbg.w/o success. Indication of 2nd ball hanging up in dn hole equip. RU & RIH w/Bkr WL 2-1/4" std'g vlv, set same in "D" nipple @ 7953'. With std'g vlv in place, tst tbg to 2500 psi; OK. Tst ann & pkr to 2500 psi; OK. Pull std'g vlv. Press up ann & tst SSSV; OK. Shear out 2nd ball, RD WL. Set BPV. ND BOPE, NU & tst tree. Displ well to diesel. Tst tbg & orifice vlv; OK. Bled tbg to 900 psi. Set BPV. RR @ 1230 hrs, 11/16/85. SSSV @ 1780' - FHL - Pkr @ 7719' - FB-1Pkr @ 7940' - i'D" Nipple @ 7953' - TT @ 7959' New TD PB DePth 8283' PBTD Date K nd of r g 11 / 16/85 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test -!i. GA,~s per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable /" .~ Effective date ';' ~"-- L corrected i../ -, ?': - The above is correct ,-, L,'y,,._ . Signature Date Title -:~"¢/:,'!~-~-r~}~ !~'J''~ ~.~'~ t~}~.~ .... ~/~ ~~ /~'/3-~' Drilling Superintenddnt ~!4u~ For form preparatio~ and distribution, see Procedures Manual, Section 10, Drilling. Pages 86 and 87. ARCO Alaska, Inc. Post Office ~ox 100360 Ali(;l~,-m'age, P, iaska 99510-0360 Telephone 907 276 i215 December 4, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-3 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3A-3. ! have not received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L108 Enclosures ARCO Alaska, Inc. is a ~ubsidiary of AtlanlicRichfieldCompany '~"~ STATE OF ALASKA ALASKA L, ~_ AND GAS CONSERVATION CO.____ AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG · , 1. £tatus of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-206 · . 3. Address 8. APl Number P. 0. Box 100360,~, Anchorage, AK 99510 50- 029-21432 4. Location of well at surface ........ 9. Unit or Lease Name 527' FSL, 749' FEL, Sec.7, T12N, R9E, UI4 T[_~C,~.TIONSt Kuparuk River Unit At Top Producing Interval 't VET~[FIED, o !~ [ 10. Well Number 1142' FSL, 1165' FEL, Sec.18, T12N, RgE, UH )Surf,_J~,~ 3A-3 At Total Depth ,,~~l ~"~ ~' 11. Field and Pool 759' FSL, 1221' FEL, Sec.18, T12N, R9E, UH'--~'-"'""-"~ Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72' RKB ADL 25632 ALK 2565 , . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/09/85 09/15/85 09/16/85* N/A feet MSL 1 171'Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8390'MD,6377'TVD 8283'MD,6294'TVD YES I-~X NO []I 1780 feetMD 1500' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/SP/CAL, BHC/GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16~ 62.5# H-40 Surf 106' 24" 187 sx AS I! 9-5/8" 36.0# J-55 Surf 3888' 12-1/4" 1200 sx AS !11 & 320 s; Class "G" 7" 26.0# " J'-~5 Surf 8371' 8-1/2" 425 sx Class "G" & 250 sx AS I , 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) 8098' - 8050' w/4 spf, 90° phasing 3-1/2" 7959' 7719' & 7940' 8010' - 8034' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7882' - 7892' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7874' - 7790' N/A · . 27. N/A PRODUCTION TEST Date First Production / Method of Operation (Flowing, gas lift, etc.) / ' I Date of T~st Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ · Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ ..... 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0ii & ,,~- . Form 10-407 *NOTE: Tubing was run & well was perforated 11/16/85. TEJ, IP2/WC68 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :. :'": "" G'EOiO~i'C. MARKERS. ~:'~.~ '"'"'; i~ ~ -;'. ~.;i'-'-' i:{:;~-"' i.:. ~"'..:i;:'~i~,.~ ? :~.~i:! :..':iF'O~i~M-~TiON:.:~S~s . .. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . l'op Kuparuk C 7786' 5914' N/A Base Kuparuk C 7873' 5980' Top Kuparuk A 7996' 6073' Base Kuparuk A 8158' 6197' 31. LIST OF ATTACHMENTS W~_ll History. Gyroscopic Survey ~2 CoDies~ 32. I h'ereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ~ ~ .~~ Title Associate Engineer 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. !tem 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 Oil and Gas Cpmr ~y,~,'~ Well History - Initial Report - Daily Inatru{=tlons: Prepare and submit the "lnlti~, :port" on the first Wednesday after a well is spudded or workov, aratJons are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. - ~ District Field J County. parish or borough IStete I North Slope Alaska Alaska ~tease ~r unit APL ~56~2 Borough JTitle I Drill Kuparuk River Auth. of W.O. no. AYE AK0260 Parker 141 jWell no. 3A-3 API 50-029-21432 OperatorI I IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun [Date [Hour Prior status if a W.O. Spudded 9/9/85 0300 hrs. Date and depth as of 8:00 a.m. 9/09/85 9/10/85 9/11/85 9/12/85' Complete record for each day reported 16" @ 106' 400' (294'), Drl'g Wt. 9.3, PV 16, YP 23, PH 10.5, SL 17.2, Sol 7 Skid rig, Accept rig @ 2~30 hr.s,. 9-8~85. NU 20" annl, & diverter, PU BHA. DP, orient, Spud @ 0300 hrs, 9-9-85. 16" @ 106' 1901' (1501'), TIH Wt. 9.1, ?V 15, YP 26, PH 10, WL 16, Sol 7 Drl f/400'-497', DD to 647', POH, LD DP, PU 2nd DP, TIH, DD f/647'-1901'. Pmp pill, POOH, LD DP, PU new BHA, TIH. 766', 7.4°, S6.0W, 710.55 TVD, 13.81VS, S13.74, W1.40 1219'' 22.5°, S4.5W, 1147.71TVD, 127 93 VS, S126.82, W1755 1714', 36,8°, S6.6W, 1576.27 TVD, 373.55 VS, S370.79, W46.38 1901', 43.3°, S6.0W, 1719.42 TVD, 493.87 VS, S490.39, W59.58 9-5/8" @ 3888' 3900' (1999'), Circ& Cond f/9-5/8" Wt. 9.4, PV 15, YP 19, PH 9.0, WL 9.8, Sol 8 W&R f/1770'-1901', Drl to 3900'. Circ Hi-Vis sweep, drop surv, short trip. No correction, POOH. RU & rn 95 its 9-5/8", 36#, J-55, HFE RW, BTC csg. Set FS @ 3888', FC @ 3765'. Land on FMC hgr, RU Dowell, C&C mud f/cmt. 2225.10', 47°, Si.0W, 1962.03 TVD, 737.59 VS, S733.82,W74.47 2913.12',48.8°,S3.5W, 2427.36 TVD, 1243.69 VS, S1239.93,W99.08 3659.14',48.5°,S4.4W, 2920.46 TVD, 1803.45 VS, S1797.57,W148.12 3901', 48.8°,S7.0W, 3080.34 TVD, 1985.12 VS, S1978.34,W166.16 9-5/8" @ 3888' 4743' (843'), Turbine Drl'g Wt. 8.8, PV 7, YP 8, PH 10.5, WL 18.2, Sol 5 RU Dowell, tst ins to 3000#, pmp 45 bbls wtr spacer, drop plug. M&P 1200 sx AS III w/½ per sx Cellophane Flake @ 12.2 ppg. M&P 320 sx CL "G" w/2% SI,+ 0.2% D-46 , drop plug, displ w/rig pmp. Bmp plug w/1500#; floats OK. CIP @ 0845 hfs, 9-11-85. RD Dowell, flush ins, & annl. ND diverter & annl, MU wellhead,-NU 13-5/8" BOPE &tst. MU BHA, TIH to FC @ 3801', tst csg to 1500 psi. Drl FC, cmt, FS & made 10' new hole. C&C mud, perform leak-off tst to 630 psi = 12.5 ppg EMW. Pmp pill, TOH, MU Turbine &tst. TIH, tag btm, Turbine drl & surv f/3910'-4121'. Correction rn f/4057'-4121', drl f/4121'-4743'. 4169', 54.4°, S8.5W, 3286.60 TVD, 2206.92 VS, S2198.27, W196.09 4668', 46.1°, S7.3W, 3634.80 TVD, 2564.07 VS, S2552.31, W245.22 The above is correct Signature For'form preparafio~ ' see Procedures Manuah Set~tion 10, Drilling, Pages 86 and 87, IOate /0 ' f~ '~' [Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work perl'ormed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 3(3 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District ICounty or Parish Alaska I North Slope Borough Field ILease or Unit Kuparuk River I ADL 25632 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a,m. 9/13/85 IState 9-5/8" @ 3888' 7123' (2380'), Turbine Drl'g Wt. 9.3, PV 14, YP 8, PH 9.5, WL 9.6, Sol 7 Turbine drl f/4734'-7123'. Correction rn f/5117'-6489' 5042',46°, S7.9W, 3894.37 TVD, 2833.17 VS, S2819.20, W280.83 5575',43.2°,Sll.2W, 4237.88 TVD, 3206.53 VS, S3188.26, W342.92 6010',42.6°,S10.6W, 4592.54 TVD, 3501.38 VS, S3479.03, W398.91 6507',42.1°,S7.3W, 4959.84 TVD, 3835.62 VS, S3809.76, W451.00 7001',42.6°,S7.5W, 5324.92 TVD, 4168.24 VS, S4139.78, W493.86 Alaska IWell no. 3A-3 The above is correct S i g n a t u re ,~,~ ~=~ For form preparation and distribution see Procedures Manual Section--10, Drilling, Pages 86 and 87 IDate ITitle /o-2~ -~ Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWoII no. Kuparuk River ADL 25632 3A-3 Auth, or W.O, no. JTitle AFE AK0260 I Drill Parker 141 API 50-029-21432 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded A.R.Co. W.I. 56.24% Date 9/9/85 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0300 hrs. I Date and depth as of 8:00 a.m. 9/14/85 thru 9/16/85 9/17/85 9/23/85 Complete record for each day reported 7" @ 8371' 8280' (1267'), Rn'g 7" , Wt. 10.3, PV 13, YP 6, PH 8.5, WL 7.0, Sol 14 Turbine drl f/7123'-7776, POOH. PU BHA, TIH, drl & surv f/7776'-8280', 20 std short trip, C&C, POH. RU Schl. rn DIL/FDC/CNL/GR/SP/CAL f/8276'-3888'. Rn BHC/GR f/8274' WLM - 9-5/8" csg shoe. RD Schl. TIH, wsh & rm f/8217'-8280', drl to 8390', 20 std short trip, TOH. Chg rams to 7" & tst to 3000 psi. RU & begin rn'g 7" csg. 7500', 41.4°, S5.6W, 5695.76 TVD, 4502.09 VS, 4471.50S, 531.95W 7701', 41°, S8.3W, 5847.00 TVD, 4634.45 VS, 4602.92S, 547.97W 8005', 40.4°, S9.1W, 6077.47 TVD, 4832.92 VS, 4798.88S, 577.97W 8242', 38.8°, S12.6W, 6260.08 TVD, 4983.36 VS, 4947.25S, 606.41W 7" @ 8371' 8290' TD, 8283' PBTD, RR 10.2 ppg brine in 7" csg to FC @ 8283' Fin rn'g 200 its, 7", 26#, J-55 HF/ERW BTC csg w/FS @ 8371', FC @ 8283'. Cmt w/425 sx Cl "G" w/3% KCl, .8% D-60 & .2% D-46. Displ cmt using rig pmps, bump plug. CIP @ 1225 hrs, 9/16/85. Full rtns thru out job. Instl pack-off, NU wellhead, tst pack-off to 3000 psi. RR @ 1600 hrs, 9/16/85. Well was arctic packed w/250 sx AS I. Old TD I New TD IPB Depth 8283' PBTD I Released rig Date IKind of rig 1600 hrs. 9/16/85 I Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Prod0cing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Superintendent ARCO Alaska, Inc Post Office l:J~ix 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO' ALAS~,' INC. KUPARUK OPERATIONS .. RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5422 ENGINEERING TRANSMITTED HEREWITH ARE ThE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUR1W ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/SCHL OPEN HOLE (ONE * OF EACH) 3F-1 ~'5" DIL/SFL-GR ,~k2" DIL/SFL-GR ,~k~, 5" DEN/NEU PORO DEN / NEU PORO \~5" DEN/NEU kcAW "~2" 'DEN/NkU RAW · CYBERLOOK 3A-3 '"'~5" DIL/SFL-GR ~ 7'2: DIL/SFL-GR / ~5 DEN/NEU PORO ; ~2" DEN/NEU PORO '-5" DEN/NEU P, AW / '-2" DEN/NEU RAW ~ '- CYBEkLOOK --%~5 BHC SONIC-GR . ~2" BHC SONIC-GR / 1R-4 ~ %5" DIL/SFL-GR % 2" DIL/SFL-GR /~,~ 5" DEN/NEU PORO ~2" DEN/NEU PORO ~5" DEN/NkU RAW '2" DEN / NEU RAW ~ ~ CYBERLOOK 09-24-85 RUN 91 3966-8634 09-24-85 RUN $1 3966-8634 09-24-85 RUN #1 7850-8609 09-24-85 RUN #1 7850-8609 09-2~-85 RUN ~1 7850-8609 09-24-85 kUN #1 7850-8609 09-24-85 RUN #1 7850-8500 09-14-85 RUN %1 3890-8268 09-14-85 RUN #1 3890-~268 09-14-85 RUN ~1 3890-8242 09-14-85 RUN ~1 3890-~242 09-14-85 RUN #1 3890-8242 09-14-85 RUN #1 3890-~242 09-14-85 RUN ~1 7550-8219 09-15-85 RDN #1 3890-8270 09-15-85 RUN #1 3890-8270 09-17-85 i~UN #1 4297-~336 09-17-85 RUN #1 4297-8336 09-17-85 ~UN #1 4297-8310 09-17-85 RUN #1 4297-8310 09-17-85 t{UN #1 4297-8310 09-17-85 RUN #1 4297-8310 09-17-85 RUN #1 7600-8287 F~ECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M*BL D I STRIBUT ION: DkILLING*DL ~. PASHEt{ L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RAThMELL*BL STATE OF ALASK,~A*~B]~ SOHIO /bE UNION VAULT/ANO*FILMS ARCO Alaska. Inc. ~$ a Subsidiary o~ Allan~icRich~ieldCompany ARCO Alaska, Inc. Post Office Rox 100360 ..':-,~ct~ol'age, Alaska 99510-0360 'TeleF4-1one 907 276 1215 October 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-3 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3A-3. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. Also, I have not yet received the Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L45 Enclosure ,- -,,~, ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA t ._r- AND GAS CONSERVATION CC .... 41SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDEDX~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-206 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21432 4. Location of well at surface 9. Unit or Lease Name 527' FSL, 749' FEL, Sec.7, T12N, RgE, UM (Approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when Gyro is run. 3A-3 At Total Depth 11. Field and Pool To be submitted when Gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0ii Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband, 15. Water Depth, if offshore 116. No. of Completions 09/09/85 09/15/85 09/16/85 N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8390'MD 8283'MD YES [] NOjkl~I N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/SP/CAL, BHC/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 106' 24" 187 Sx AS II 9-5/8" 36.0# J-55 Surf 3888' 12-1/4" 1200 sx AS Ill & 320 s) C]¢ss "G" 7" 26.0# J-55 Surf 8371' 8-1/2" 425 Sx Class "O" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CQRE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 DRH/WC38 Rev. 7-1-80 CONTINUED ON REVERSE SIDE · ': -:"' '' GEoEOGic:MARKERS : .... .:'~ :':' :;.:': :%~':;'.={: i~i~'""::" : ':'-! :-'. ' ?'" i~'~:'i":'.'' ~:.:~ORM~,Ti~N:!~'~S:~--; ' -. "'-; ':- · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wh;n Gyro is run. N/A 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ _.~~ Title Associate Engi neet 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 $UB.~URFACE DIRECTIONAL ~URVEY I~UIDANCE [~'IONTINUOUS ~-IOOL Company Well Name Field/Location ARCO ALASKA INCORPORATED 3A-3 (527' FSL, 749' FEL, S7, T12N, R9E, UM) KUPARUK, NORTH SLOPE, ALgSKA Jo13 Reference No~. 70915 Loaaecl 8~. LESNIE Oat__._~e Com~ut~:l 8¥: BOL/~ OCT D]RMCTTUNAL SURVEY CHSTO~ER LISTING FOR ARoO A~,ASKAo INC, 3A -] KlJPARUK ~ORTH SLAPE,AbASKA SURVFY DATE: 02 OCT 85 deviation and azimuth APCrl ~,bASk'A, Ti, if'. KIIpA t.<llK NF~R'I"H Sr,(.~'r,i<, At,ASK COHPUTA~Iflr; i)ATM: 4,-NOV-85 DATE OF SURVEY~ 02 OCT 85 KELbY BUSHING EbEVAT~ON~ ENG~NEER~ IN'rFRPOI,ATED VAI,[JF5 F'rlR EVEN 100 FEET OF MEASURED DEPTH VERTTCRL DUCLEG RECTANGUL&R CODRDZNATE$ HORZ~. DEPARTURE SECTION SEVerITY NORTH/SOUTH ERST/WEST ~$~e AZIMUTH F~ET DE~/100 FEET FEET o. Ot) 0.00 100.O0 100.0n 28.O0 0 26 200.00 199.99 ~27,99 0 26 ]00.n0 2a9,90 227,99 0 16 400,00 399,9n ~27,99 '0 16 500,0(, 4~9.~q 427,99 0 30 600.0(; 599,9% 527,93 ] 20 700.~O 009.40 627.49 7 8 800.00 7q8,3~ 726,35 9 4~ ~00.00 896.25 824,95 13 21 1000.O0 9q3,02 o21 .02 16 llOn.n0 lo87,90 1o15,98 20 5 l?On,OO 1180,75 1108,75 23 4) 1~00.00 ~271.0~ tlgq.03 97 1400o00 1359,50 1787.50 ~8 3q 1500.00 ~44b,bl 1~73.61 ~2 5 1600,00 15~9,3& 1457,~6 ]4 3] ~700.00 1609,80 [~]7,~0 38 1800,00 ~6qt,,']8 1614,7~ 41 16 IO00,00 !759.9~ [687,90 a4 19 2nun.no ~u]o.5~ t. 75~.~5 45 2~ 2100,00 1900,J6 1R2~,')6 46 ~ 2200 00 ~969 24 1897.24 46 ~7 2400,00 9105 91 2d33,91 4~ 47 2500.o0 ~174~ 2107,]3 4~ 5~ 2600,00 ~242,4~ 2170.45 47 5 2700.00 2310,2() 273~,~0 ~7 47 2~00,00 9370,82 2~04,~2 4~ 30 2gO0.O0 9442,9~ 23'70.08 48 3'1. H 0 0 F 0.00 0,00 0.00 N 97 4 E -0.45 0,75 0,46 ~ 75 15 F -O.q7 0.39 0.91 S 71 47 E -1.04 0,14 0,92 S 52 5~ W -n.76 0,67 0,6] S 56 11 W '0,34 1,13 0,27 S I 4q F 2.43 4.22 2,49 S 133 W 11.&3 3,89 11,7] S 0 3 ? 26,58 2.41 26,74 S 2 lfl W 46.80 2.48 47,01 $ 3 10 W 71.96 $ ] 8 W 103.92 S 2 40 w 140.45 ~7 $ 3 50 W 22 6 S 2 32 W 280 72 $ I 31 W 335~23 ~ 145 ~ 394.46 S I 53 W 458,1.0 S 1 51 W 526,1.7 $ 1 23 W 596.77 $ 0 5~ W 668,15 ~ 0 50 W 740 39 S i 0 W 813:20 S 1 25 W 88504 S ! 50 W 958:70 S 2 9 w 1~3~.77 K 2 2~ W 1~05.19 S 2 30 w 1179.66 $ 2 4n W 1254,55 37 W 1329.33 4!. W 1404,17 47 ~ 147fl,97 4R W 155],93 54 W 1628,g~ 4 W 1703,86 6 W 1778.80 1~ W 185~,74 25 W 1928,56 10 W 2003,46 3000.00 2509.25 2437,25 48 30 3100,00 2575.,t6 2~03,46 48 29 3200,00 2041.'13 2560,73 48 34 3300 00 2707.81 26~.nl 48 38 3400:00 P773,~O 270i,89 48 35 3500 00 ?~40.0n 27b8.00 4~ 37 3~00:00 2906'13 2834,~3 48 36 ]700,00 ~972 26 2qOO,?b 48 32 3g00,00 3104,7~ .~037.73 d8 39 3.70 3 59 3 44 2 47 3 19 2 38 3,80 o17 1,89 0,66 0.81 0.65 0.09 0.54 0'50 0.23 1.1] 0.45 0.23 0 38 0 22 0 14 0 38 O, 8 O, 8 O, 2 l,: 0 7217 S 10338 $ 14063 S 1~3518 230 O1 $ 28072 S 33532 S 394 65 S 458 43 $ 526 59 S 597 33 8 668 91 $ 741 40 $ 814 44 S 887 39 $ 960 29 S 1033 45 8 1106 94 S 1 45 S 1331 17 $ 1406 03 S 1,480 838 155580 $ 163077 S 1705 69 S 1780 59 $ 1855 49 8 1930248 2005 07 S 0,00 E 0,02 W 0 68 E 128 E 1 34 E 0 74 E 0 48 E 0 48 E 0 33 E 0,14 W 72,00 FT I 35 W 3 5 7 10 13 15 17 19 21 39 W 103 02 W 140 52 W 75 W 281 43 W 335 29 W 395 07 W 458 44 W 527 7218 S I 4 W 44 S 152 W 72 $ 2 2 W {I°" 06 S 2 4 68 s 2 38 03 s 2 30 W 83 $ 2 22 w 03 $ 2 19 W 23 24 27 28 30 33 42 47 W 597 79 $ 2 15 W 88 W 669 38 S 27 W 89 W 741 12 W 814 56 W 887 71W 960 28 W 1.033 8t W ! 85 S ~ 5~ w 89 S w 78 $ I w 53 S ~ 11 $ 1 54 w 09 s t 57 w 46 26 W 1331 97 S ~. 59 W 49 53 56 6O 64 68 72 77 81 75 W 1406 31 W 1481 99 W 1556 72 W 1631 62 W 1706 66 W 1781 77 W 18~6 15 W 191 66 W 2006 90 $ W W 91 $2122,10 92 $ W 92 $ 2 !4 W 79 $ 2 t7 w 73 $ 2 19 w ARCFI AL, ASVA, I'NCo 3~.-3 ~'~ fl R T it 5t,[JPg ~ Al,ASK3 TRLIW SIJ~-$EA CnURSF: ~EASUAFD V~R'T'IQAI.. VEr~'I'TCAL, D£VTATInI',, AZI~"IJ"tH Cr~MPUTATInN DATF: 4-NOV-g5 DATE OF SURVEgl 02 OCT 85 KELbY RUSHING EbEVATIONI ENGTNEERI bESNIE INTFRPOI,ATFn VAf. UF$ FnR EVEN 100 FEET OF MEASURED DEPTH VERTTC~L DOGhEG SECTION SEVERITY DEPTN DEPTH nEPTH DEG FEET PE~/IOO PAGE 2 72,00 PT RECTANGULAR COORDINATES HO,RZ~, DEPARTURE NORTH/SOUTH ERST/WEST D~8~,. ~..AZIMUTH FEET FEET ~.~T,,. 0,25 2080.17 S , 0.2] 2225,76 S W 2~2 .' 2 21 0,22 2367,26 S 113,58 W 236~ 9~ $ 2 44 W 0.42 2438,35 S 121,94 W 244~ .40 0.2~ 2509,54 S 130,]0 W 25[~ ~2 ~ ~[ W 0,21 2580,68 S 138,58 W 2584 40 0,51 2651,82 $ 146,6! W 2655 87 8 3 9 W o,15 2722,58 $ 154,5t W 2726 97 $ 3 4000.00 ~170.57 ]098.67 48 42 410n.oo ~237.1~ 3165,18 47 2 4200.00 t307,1~ 3735,1~ 45 lO · 4O 3~05 49 45 2° 4~00,00 ~377, . , 4400.00 ~447.44 ]~75.44 45 ]9 4500.00 t517.27 3445,27 45 45 460~.00 ~b~7.0n 3515.00 45 4~ 4700,00 3686.7~ ]584.79 45 47 4800.00 3726.61 3654.61 45 33 4900.00 ~796.89 ~724.fi2 45 20 5000.00 ]867.07 3795.02 4.5 34 5100.00 ~936.8g 3n64,~8 45 36 5~0n.00 4007.47 3935.47 ~4 52 5300.00 4078.26 4006.26 45 5 5400.00 4148.71 't076.71. 45 20 5500.00 ~219.01 i147,01 45 g 560a.00 4200.66 421~.66 43 lP 57()0.00 4363.~1 4P91.41 43 1K 5800.00 4436.4:3 4304,43 42 52 5qO0.O0 4509.99 4437,02 42 36 6000 OO 45~3 52 ~511.52 42 28 6100~00 4657:'/~ 4585.71 41 40 6~00 O0 47~2i53 4660,53 41 3~ 6300~00 .48~7 27 4735.27 41 45 6400.00 4891.76 4809.75 41 56 6500.00 4956.27 4P84.77 ~1 45 6600 O0 5030.91 405~.91. 41 52 6700~00 5105..]1 5033.31 42 n 6800.00 5179.4! 5107.41 42 19 6q00.00 5253.23 5181.23 42 2R 7000.00 5377.12 5255.12 42 24 7100.00 5401.00 532o.00 42 26 7200 00 5474.b~ 540?.68 42 31 7300:00 5548.5~ 54'16,5~ 42 13 7400~00 5622.~? 5550.~2 41 54 7500 O0 5697'52 5625.52 4~ 17 7600:00 5772,85 5700,q5 ~!, 11 7700.00 5848.17 5776,17 40 57 7800.00 59?4.27 5~52.97 40 18 7900.00 6000.06 592fl,05 40 56 $ 2 21 W 2078.55 $ 4 24 W 2153.13 S 7 0 W 2224.56 $ 6 4~ u 2295. ...... S 6 43 W 2357.05 $ b 42 W 2438.61 S 6 40 W 2510.28 $ 6 33 W 2581.88 S b 2! w 2653.47 $ b 26 W 2724.67 S ~ 36 W 2795.~@ $ b 42 W 2867.41 $ 7 43 W 2938.22 S 7 55 w 3008.79 S 8 5 W 307a,70 $ 8 20 W 3150,75 R 8 14 W 3220,42 S 8 32 w 3~88.94 $ 8 57 W 3357,16 $ 9 17 W 3424.85 $ 9 39 W 3492.40 S 9 53 W 3559 27 S 9 59 W 3625141 S 10 3 w 3691'66 $ !0 14 W 3758,16 S b 5~ W 3824.73 $ b ~ W 3891.28 S 6 5 ~ 395n.!0 S 6 R w 4025'25 S 6 4 W 409~.70 S 6 8 W 4160.07 $ ~ 33 W 4227.46 S 6 36 W 429~.06 $ b 31 W 4362.44 S ~ 2~ W 4429.4~ S 6 28 w 4~95.88 $ 6 42 W 456~,64 s 7 43 w 4627.~9 S 8 49 W 4692,~9 $ 7 52 W 4757.35 0,38 0,91 2864 0,40 2934 0.63 3004 0,33 3074 0,70 3145 0,87 321.4 0.30 3282 0,61 3349 0,27 2793 34 $ 162 62 W 2798 07 S 3 19 W 68 S 1 65 $ 189 92 S 199 32 $ 209 33 S 2i9 20 $ 229 73 S 239 3416,69 S 250 0,63 0,78 0,06 36]4 0,33 3680 0,51 3745 2,09 381~ 0 73 387 O' ,Oq 3944 0.26 4011 0,45 4078 0.70 0 48 0119 0 4~ 0 2O 0,93 0~,64 1.:i'27 0 ·., 90 W 2869 81. W 2940 41 W 3010 34 W 3081 48 w 3152 58 W 3221 57 W 3290 96 ~ 3358 71 W 3425 50 $ 3 24 W 18 S 3 30 W 6, 8 I 16 W 38 $ 2 W 28 S 3 48 W 82 S 3 54 g 2 S 4 w I S 4 a W 87 $ 4 11W 3483 47 S 261 3549 54 S 273 96 32 S 98 S 308 85 S 318 02 $ 325 46 S 33 23 $ 33~ 29 S 347 84 W 3493 25 W 35 05 W 3758 37 W 3825 59 W 3891 66 W 3958 86 W 4025 O5 W 4093 4145 29 S 354 18 W 4160 40 $ 4 53 W 42 4346 4412 4479 4544 4609 4673 4738 · 27 $ 36 44 $ 36~ 38 34 $ 3. 60 $ 4O7 77 $ 417 32 S 426 64 W 4227 40 W 4295 0 W 4 78 W 4627 29 W 4692 72 W 4757 AIqC~ A[:A.SKA, 3A-~I NORTH cr)aP0TATi .nN DATF,: 4-NOV=~5 ~A~E OF SURVgYt 02 OCT 85 KELLY BUSHING .EbEVATIONJ ENG~N~ER ~ 'rR[J~ SUR-SE~ CnLI~SR VERT~ CA[, DUGL~G RECTANGULAR COORDZNATES H~JZ;~.' DEPARTUR~ . , D:ST -0 "- ~AB~IR~D V~RTI~A~ VErTiCAL DEVIATION AT.I~UTH S~cTInN SE~ERITY NnRTH/SOUTH EAST/WEST Z DEPI', DFPTm DEPTH" DEG ~IN DFG 1.1IN FEET DEG/IO0 FE~T FEET FELT...<..~.DEG 8oOO.~o 6075.7~ 6n03.79 40 ,O S 7 2, ~' 482~.61 0.34 4803.05 S 4]5 ,5 W 482~'"'~"" "'~..t~ 8100 no 6152.10 0080.10 t9 54 a 7 7 W 4~8~.21 1.01 4867 15 S 443 61 W 488 R200:O0 &2~9.47 ~157,47 ]8 53 .~ 9 2, w 4950.52 3.72 4929 9] S 452 12 W ~950',':.6~ 'S 514, 8300 O0 6307.25 6?35 25 38 56 S 9 29 W 5013.~3 O.OO 4991 92 S 462 48 W533001 ~'. 8~9n:00 6377.25 6305~25 3856 S 929 W 5069.66 0,00 504771 ~ 47181 W ~06907~ PAGE 4 KIIP~RIIK N~RTH SLOPE~AT,A5KA DATE OF SURVEYI 02 OCT 85 KELLY BUSHXNG ELEVATION{ ENG)NEER{ GESNIE 72,00 FT ].NT~RPO[,ATED VAI,LI~5 FOR EVEN 1.000 FEET Of' MEASURED DEPT T~!)~ SU~-SEA COURSE ME~SI.IRF9 VERTIPAI, VE~TTCAL DEVTATIrlN AZi)~UTH DEPTH DEPTH hEPTH DEG MTN DFG MTN 0.0~ 0.0o -77,00 .0 0 lO00,oO 9q3,09 o21,02 16 ~ nO0 n0 18]O.bS 175~,~5 45 2~ ]fl00'O0 2509 25 2437,25 48 30 4000'00 3170~§7 3n98.67 48 49 50OO'nu 38~7,07 3795,02 45 34 boO0'O0 45~3.57 4511',~2 42 2~ 7o00~00 ~3~7.17 5~55~2 42 2~ 8oO0.~o 6075.79 bO03,79 40 30 8390.00 6377.25 5]05,25 ~8 56 VgRTTCAL DOGLEG RFCTANGULAR COORDZNATES HORXZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DX$~ AZ2MUTH FEET DEG/1 00 FEET H 0 O ~ 0.00 S 3 19 w 71.96 $ 1 2~ W 596.77 $ 2 37 w 1320.33 ~ 2 21 w 207~.55 ~ 6 36 w 2795,~8 S 9 39 W 3497.40 S 6 q w 4~60.07 S 7 28 w 4827.61 S 9 29 w 506~.&6 0 On 3:?o 0.66 0,38. 0.25 0.38 0 63 0~70 0.34 0,00 0 O0 N 72 597 1331 2080 2793 3483 4145 48~ 504~ 0,00 £ 0~'0~i~,'-'~:~ 0 0 E 17 S 8S t4 w ~OnX'~t' S 2 ~ ~ 29 S W 4160'40 $ 4 5. d 71S 471 81W 5069,72 S 5 20 W KI'PAR~K C[INP!.ITATION OAT~: 4-NOV-85 DATE OF SURVEYI 02 OCT 85 ENGINEER~ LESNIE iNTERPOLATED VALLIFS F~R EVEN 100 FEFr OF SUB-SEA DEPTH ,~EASIIRFD VERTICAl, Vt:~RTTCAL DEVTATlmN A~i~UTH DEPTH DF. PT~ nEPTH DEG ~It,~ DFG .~IN 0.O0 0.~ -'1~,00 0 0 u ~) 0 F 7~.n0 72,0m 0,00 0 24 ~! 0 ~ E 172,~0 172,0n lOn.O0. 0 3~ ~ R:~ 52 F 272,01 272,~n 2UO,00 0 1~ ~ ~1 ! E ~72,01 372,00 30~,00 0 12 $ 22 ~ W 477,01 472.0n 400.00 0 27 S ~6 5~ W 572 O~ 572.Un 500,00 2. 17 ~ U 3~ W 672~3 672.~j0 60~,00 6 ? S ~ 7 W 77~,79 772,9n 7(30.00 9 11 S (,' 1 W R7K,11 872,00 ROn. O0 12 3~ $ 1 51 W q7R.17 972.00 °00.00 15 23 1~8].02 ~072.00 lO00.nO !9 3o 1190,47 1172,00 1100.~0 23 2~ 1301,n9 1272 O0 190n,o0 27 3 1414.77 1372 O0 lion.00 29 7 1531 96 1472 OO 1400.00 32 40 165~5 !572 on 150n. O0 ~6 3'~ 1780.45 ~672 00 1600,00 d0 36 1~16.~9 1772 00 170o.00 a4 37 2059,76 1872 00 l~0n.n0 45 4~ 2~04,02 1972.00 lmO0,O0 4. b 4~ 2350,45 2072,00 2000.00 46 51 2496.~9 2172,00 21Un. O0 4~ 57 2643.44 2272,00 2700,00 47 15 2792 72 2372.00 2~00.O0 ~8 2~ 2943'8! 7472,00 2~00,00 4~ 30 3094.~77 7572.00 2~00.00 ~8 30 3945.78 2672,00 2600.00 aa 3~ 3397.15 ~772.00 2700.o0 ~8 35 ]K48.4(') 7872.00 2~0o.00 aB 35 3699 61 ?972 uo 2~00,00 48 32 3R50:50 3072:0o 3000.00 48 33 4002.02 3172.00 3100,00 ~8 42 4150 ~ 3272 00 3900,00 45 27 4~9~:18 ~372:0~ ]300.00 ~5 27 443~.16 ]472,00 3400.00 45 q.~ .4578.K0 3572,00 ]500,00 ~5 45 4721,82 ~672.0n J&bO.O0 45 46 4864.~9 3772.00 ]700,00 .45 21 5007,12 3872,00 3800,00 45 36 PAGE 5 72,00 FT VEPTTCAL DOGLEG R~CTANGULAR COORDINATESHORZZ, DEPARTURE SECT[ON SEVERITY NDRTH/SnUTH EAST/WEnT DXST,; AZIMUTH FFET DEC/100 FEET FEET PE~ DEG MXN 0.00 0,00 N 0,00 '0,25 0,26 N 0.06 -0,87 0,8] N 0.46 -1.06 0,95 N 1,15 -o.~5 0,72 N 1,41 -0.47 0,38 N 0,94 !,04 1,09 S 0 46 ~.4b 8,56 $ 0,57 22.21 22,35 $ 0,3~ 4.].1.9 41,40 S 0,07 S 2 59 w 66.07 S 2 35 w ~36.68 $ 3 54 W 183.86 $ 3 44 W 236,83 ~ 1 57 W 297.45 S 1 52 w 365.52 $ 1 44 w 445.34 S 1 47 w 53R,07 $ I 4 W 638,g9 ~ 0 51 W 743.31 $ 1 6 W ~49.92 S 1 49 W 956.91 $ 2 15 W 1063,54 S 2 20 W 1174.21 S 2 3~ W 1287,32 S ? 41. 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L..i..$...L.~ : : ; : , : : : ; ~ : : : : : : : : : ""~"~"~"""~'"'~"'~" ¢" ~'" ~"?"?"'.~"?-?'-?"7'W't'?"T"T"?"?"?"T"7"? .................. ...... .:~-...~....[...¢..~...[....~._~..¥..~... ..¢..¢..¢.4..L.L..L..i...L.. ,.. ::.?: ...L..~...'L¢...~...;..-L. ~-+"+'"~'+".-'"f"'i"-~":j'-' .f'f 'T' "?"i" :+"? f'::' 4O0O Suggested form to be inserted .~.each "Active" well folder to check for timely compliance with our regulations. 'OPERATOR, ~EL~NA~E AND NUMBER Reports and Materials to be received by: )~-/~-- · Date . Required Date Received Remarks Completion Report Well History ' Cote Description Registered Survey Plat Drill Stem Iest Reports , ARCO Alaska, Inc. Post Office _ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the 'September monthly reports for the following wells' 3A-2 3C-3 3J-4 WSP-6I (workover) L3-5 9-29 3A-3 3C-16 3J-5 L1-2 4-21 11-8 3A-4 3F-1 3J-6 L1-14 (workover) 4-30 11-9 3C-1 3F-2 1R-3 L2-13 4-32 11-11 3C-2 3J-3 1R-4 L2-26 9-24 15-7 16-17 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUll/L62 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA C. _~ AND GAS CONSERVATION COld.MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-206 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21432 4. Location of Well atsurface 527' FSL, 749' FEL, Sec.7, T12N, R9E, UN (approx) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 73' RKB I ADL 25632 ALK 2565 For the Month of. September ,19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0300 hrs, 9/9/85. Drilled 12-1/4" hole to 3900'. Ran, cmtd, & tstd 9-5/8" csg. Drilled 8-1/2" hole to 8280'. Ran logs. Continued drlg 8-1/2" hole to 8390'TD (9/15/85). Ran, cmtd, & tstd 7" esg. PBTD = 8283'. Secured well & RR ~ 1600 hrs, 9/16/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set @ 106'. Cmtd w/187 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3888'. Cmtd w/1200 sx AS Ill & 320 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 8371'. Cmtd w/425 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/FDC/CNL/GR/SP/Cal f/8276' - 3888' BNC/GR f/8274' - 3888' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska, 0il & Ga~ Cons, Anoh0ra~e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on&is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRH/MR30 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. Posl Ollice Box Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 9/26/85 Transmittal No: 5371 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape and Verification Listing: ~'~lR-3j #70811 9/10/85 -~lR-4~' #70823 9/i7/85 ~3A-2/ #70808 9/7/85 3A-3 #708i4 9/14/85 3C-3/ #70807 9/6/85 ~3J-3/ #70812 9/9/85 Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Chevron Geolog~L.Johnston Exxon Sohio Mobil Phillips Oil Union D & M NSK Drill Clerk J. Rathmell K. Tulin/Vault MEMORANDUM State of Alaska TO: THRU: FROM' ALAo,.~A .JIL AND GAS CONSERS¢.¢IO~'~ ~ .,:' /' ! ~ / ,.( C. V. / ~¢a'tterton Lonnie C. Smith Co~i s s ioner ....... Bobby D. Foster Petroleum Inspector DATE: Septem?oer 16, 1985 FILE NO: D.BDF. 78 TELEPHONE NO: SUBJECT: BOPE Test ARCO - 3A-3 : Permit #85-206 Kuparuk River Field Wednesday, September 1!. 1985: The BOPE Test began at 12:45 PM and ~s COnCluded a-t-~:i5PM. As the attached BOPE Test Report shows, there were no failures. In summary, I witnessed the BOPE Test on ARCO's 3A-3. Attachment 02-001Af~ev. 10/79) O&G ~4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Inspect or l~---'~ ~p ~~ 0 er or o at on: 7 Drilling Contractor ~~~ Rig Location, General~Well sig~~~ General Hous ekeeping~Rig Reserve Pit ~~ .... Mud Systems Visual Trip Tank ~ Pit Gauge ~-~ Flow Monitor ~/ Gas Detectors Audio Date ACCUMULATOR SYSTEM Full Charge Pressure _~/~ psig Pressure After Closure /~-~ psig Pump incr. clos. pres. 200 psig. min~-~ec. BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Full Charge Pressure Attained: ~ min~_~_sec. Controls: Master Remote ~~Blinds switch cover~j~ · Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type ? Test Pressure ~ Inside BOP / Test Pressure ~6 Choke Manifold~~ Test Pressure~ / No.. Valves No. flanges Adjustable Chokes / HydrauiCally operated choke / Test Time hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: Distribution orig. - A0&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG 0 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany 7 8 .--.4 NOTES OJCRDINATES,-,RE A.S.R,ZONE 4 2. 'SECTION ~_,NE DISTANCES ARE TRUE. S HORfZONTAL POSITIONS BAOEDCN THE D.S.-OA WEST ~ 3AMID PER LHO &ASSOC. 4, VERTICAL POSITION BASED CN 3A EAST 3A MID PER LHO ~ ASSOC. 5.0.G. ELEVATIONS IN?ERPOLATED FROM S/C D'~G, CED- RIXX- 30~0 rev. H~BY~TIFYTHATI A ~C~ED T~ ~TIC~ ~ ~URVEYING I~ THE STATE MADE IJNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14,1985 LOCATED IN 12 AS BUILT--J' CONDUCTORS I- 16' _ 10- ll- 12- 13- 14- 1- Y=5,996,860.05 LAT= 70024'09.520" X: 507,712.01 LONG- 11,9°$6' 13 020" 478' FSL, 736' FEL, 36.8' OG, 40.8 PAD 2- Y=5,996,88/+. 17 LAT= ?0°7/,' 09. 758" X= 507,705.57 LONG= 159°56' 14 207" 503' FSL, 743' FEL, 3.5.8 O'S, :,0.9 P~O 3- Y=5,996,908.32 LAT= 70o24'09.-995'' X= 507,699.06 LONG= 14g°56' 14 j97" 527' rSL, 749'FEL, 33.700, 40.8 PAD 4- Y=5,996,932, Z2 LAT= 70°24' 10.235" X= 507,592.55 LONG= 1/+g°56' 14 587" 551' FSL, 756' FEL, 36.7 OG, 40.8 5- Y=s,ggG,g56.GI LAf= 70024, i0.470" X= 507,686.21 LONG= 149°56' 14 773" 575'FSL, 762'~EL, 36.50G, 40.9 PAD 6- Y=5,ggG,980.84 LAf= 70°2~' 10.709': X= 507,679.66 LONG= 14g°56' 14 963" 399' FSL, 768' FEL, 36.50G, 40.8 PAD 7- Y:5,gg7,004.90 LAT= 70o24' tO.gqS" X= 507,673.26 LONG= 149°56' i5 tSt" 623' FSL, 774'FEL, 36.5 0.1, &t, 1 8- ¥=5,gg7,029.03 LAF= 70°Z~' 1!. [~3" X-= 507,666.81 LONG= I49°56' 15 667' FSL, 781' FEL, 36.40G, 40.9 P.'AO Y=5,g97,101.24 LAT= 70°24' 11.893'' X= 507,647.70 LONG= 149o56' 15.896" 720 FSL, 800' FEL, 36.3 OG, 41.7 PAD Y=5,99~, 125.66 LAT= 70°24' i2. 134" X= 5d ',6~+0.8g LONG= 149°56' 16 OgS" ?44 C'L, 806.' FEL, 36.30G, ~1.6 Y=5,99'~, 149.8/+ LAf= 70o24' 12.371" X= 507,63/+.4/+ LONG: 149°56' 16 283" 768 FSL 813 FEL, 36.2 OG, 4L2 PAD Y=5,997, 73.97 LAT= 70024, 12.509" X= 507,627.96 LONG= I49°56'16 792 FSL 819 FEL, 36.10G, ~1.3 Y=5,997, 98.08 LAT= 70°2'~' X= 507,.521.48 L-ONG= [~9°56' 1.5 ~<'" 817 ~SL 825 FEL, 36.00G, 41.0 Y:5,ggT,222.2g LAT= 70°24' !3,38~." X= 507,615.0 LONG= i~.9°55' 16 8/+1 FSL 832 FEL, 35.80G, ~1.0 4 LAT= 70°24'I3.322'' 5 LONG= !4g°56' !;' 03?" FEL, 33.6 0G, ~,1. 5 LAT= 70°2~' 13.55," 0 tONG= 1¢.905.5' I 7 .... :EL, 35. 5 OG, ~, 1. ;' - Ft~-m., Y=5 997 246. PROTRACTED SEC.7,T. 12 N. R. 9~, ~.hj{~"r ! %/ ' ' ' .1 __ ~ v:5,997.270 ~ 4S~ 0" &lEas Cons. Commis~ol~'r~' 9.$,~ N 7 ' ON[ TI 9Anchorage BSSDG, fltl,lllll iI~ IIII Illl, l~lll ,. ARCO Alaska,. Inc. Kuporuk Pro;eot DRILL SITE 3A CONDUCTOR AS- 8 UI LT LOCATIONS Date AUG. 16, 1985 Scale: I"- 3~' - Drafted by :~___~,~ Owg. no.: NSK 85-16 I I ' II~ August 22, 1985 Mr. J. B. Kew in Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re.. KuparUk River Unit 3A-3 ARCO Alaska, Inc. Permit No. 85-206 Sur. Loc. 527'FSL, 749'FEL, Sec. 7, T!2N, R9E, Btmhole Loc. 962'FSL, 1223'FEL, Sec. 18, T!2N, RgE, !~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~zn Kuparuk River Unit 3A-3 '-2- August 22, t985 To aid us in scheduling 'field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. BY ORDER OF THE COb~{ISSION be Enclosure Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enct. Mr. Doug L. Lowery ARCO Alaska, Inc. Pos'~ Of[ice i'$~_, ,00360 ~Felephone 907 276 12i5 August 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-3 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3A-3, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system o Diagram and description of the' BOP equipment We estimate spudding this well on September 6, 1985. any questions, please call me at 263-4970. Sincerely, /Regional awning Engineer JBK/TEM/tw PD/L144 Enclosures If you have Alaska Oil & Gas Cons. Commis$ior~ '" uurage ARCO AlasRa, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL la. Type of work. DRILL REDRILL DEEPEN [] 20 AAC 25.005 ~, SERVICE [] STRATIGR~L~ S,NGLE ZONE ,. MULTIPLE ZONE~. ~;~O ff~?~ lb. Type of well EXPLORATORY [] DEVELOPMENT OIL []X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location -~-~11-at surface 527' FSL, 749' FEL, Sec.7, T12N, R9E, UN (Approx.) At top of proposed producing interval 1300' FSL, 1190' FEL, Sec.18, T12N, R9E, UM At total depth 962' FSL, 1223' FEL, Sec.18, T12N, R9E, UM I 5. Elevation in feet-lindicate KB, DF etc.) 6. Lease designation and serial no. ~ RKB 73', PAD 42' ADL 25632 ALK 2565 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-3 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 0' (~ 1830'TVD feet 16. Proposed depth (-M~D~ TVD) 17. Number of acres in lease 8178' MD, 6278' TVD fe~t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 44 oI (see 20 AAC 25.035 (c) (2) Amount $500,000 15. Distance to nearest drilling or completed 3A-2 well 25' ~ surface feet 18. Approximate spud date 09/06/85 2720 psig@ ROOF Surface ~,113 ..psig@ 6033 ft. TD (TVD) SIZE Hole ! Casing 24" 16" 12-1/4" 9-5/8" 8-1/2" I 7" Weight 62.5# 36. O# 26.0# 22. Describe proposed--program' Proposed Casing, CASING AND LINER Grade H-40 J-55 HF-ERW J-55 HF-ERW Coupling Weld I BTC BTc Length 80' 3745' 8150' iner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD (include stage data) 29' I 29' I 29' I 29' I 28' I 28' MD BOTTOM TVD 109~ 109' 3774'1 3122' 8178'1 6278' I ± 200 cf 850 sx AS III & 320 sx Class G 250 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8178' MD (6278' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3774' MD(3122' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2720 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 2-7/8", 6.7#, J-55, 8rd tbg. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby cer.bi~cf~hat the foregoing is true and correct to the best of my knowledge SIGNED _/_~ TITLE Regional Drilling Engr. us.? CONDITIONS OF APPROVAL SamPles req-uired --- ' ~ Mud Icg required I Directional Survey required ?erYE~nu _~_N~O~_ _. i []YES /~NO ~YES I--INO Form 10~01 (TEM) PD/PD144 / / Rev. 7-1-80 IAPI number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 22, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL (cont'd) 3A-3 installed and tested upon completion of the job. 3A-3 will be 25' away from 3A-2 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6692'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. On completion of disposal injection, the 9-5/8" x 7" annulus will be downsqueeze Arctic packed with approximately 200 sx of Class G cement and sufficient Arctic pack to place the cement/pack interface below the permafrost. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ALASKA'~ .... iNC. -' , PAD 3A. WELL NO, 3 PROPOSED SLOPE,____ALASKA- .... i .... KUP._ARUK...FIELD, .__NORTH__. ...... !-2.T T __ EASTM^N WH[PSTOCK. [NC. . . . _ _ .~ -- ' ~-'- 0 ......... ., _.SURFACE_. '--- '.__1000. _ ............ 2000 3000 _ ____.o._.4000. · -~ ...... ..... : .... 5000_ KOP . _ TVD=500 TMD=500 DEpIO .......... 9 15 27 33 39 BUILD'3'DEG ............................. PER I00 FT .... ~ . BASE PERMAFROST' -TVD=1552 TMD=1614 DEP=316 EOC TVD=1832 TMD=1974 DEP=541 ' -' TOP UGNU_SNDS_TVD=1982 TI'ID=2183 DEP=687- - ' - _ ToP W- S,~K- SNDS ..... TVD=2642--TMD=3104-DEp=13 K-12 TVD=2922 TMD=3495 DEP=1602 CSG PT 'TVD=3122 TMD=3774 DEP=1796 . __ K-5 AVERAGE ANGLE 44 DEG-'I'3 --MI'N TVD=4562 TMD=57'83 DEP:3198 TOP UPPR SNDS TOP LOWR SNDS TARGET CNTR TVD=5930 TMD=7692 DEP=4529 TVD=6010-TMD=7804 DEP=4607 -- TVD=6033 TMD=T836 DEP=4629 BASE KUP SNDS TVD=6135 TMD=7978 DEP=4728 TD (LOGGING PT) TVD=6275 THD=8178 DEP--4868 · --- _ - Anchorage · . . · ..... _ _ _ .. I I - 1 000 2000 :3000 . ....... VERT'[ CAL' -SECT I ON .:_: ......... :_ ..............--------'---HORIZONIAL .... PROJECTION SCALE IN. =:_1000 FEET .......... . ............... ':- ......... ..... : __: ........ ! ........ ~.~ ............. .......... , : ...... : .... .......................................... ARcO ALASKA. INC. : ........' PAD 3A. WELL NO, 3 PROPOSED .... KUPARUK FIELD.-NORTH' SLO.~E_?_~EASKA__L_ 3000 2000 ' 1000 '- ' 0 ......................... ] 000._ ~ - ~ - I ........ 8URFA~ · ' 527' FSL, _ '-_... ~' ;' -';' .SEC. . .................. .1000 ..... . .... ~ ...... ........... ~. 2000 ............. .................... 3000 .......... _ .......... : ................. . ............ TARGET CENTER TVD"6O~ :. : - ' ....................... 4000 ........... DEP"~2g ............... - ' SOUTH 4607 ...... .~ .... 1200 FSL, 1200 FEL : ~ ~ J sec. ~s, ~2,..~ · - ~- ............................................ : ..... .:'7 ............. .:'7*'T---. ..... _-.-:~-':-'=~::-~:. ..... SEC;- -- ';-' i"1'00 t 000 9rn -'-80.0 700 SO0 500 400 ~ - ~00 .......... l ....... l-'' ' ....... ! .... I-- -,~ ' i .... t'. .... 1227- -- ...... . . % 1355 -- ' ;- ; ';'."::--.;":;'; ;; :'- ;~4,0--; : ...... ; ; ;:' ~,r2~ __ ~:s2~ ;_.._. ;_ _ '" .:5.~ .... ~sr~-; L'_ ___ ;: - :' ;~1:7: ' . o . . LL '_ _ -' -: - -- -/,os2 -' "-- -- ' :-": I---~-': : :;"- ' ~X -~: -- '- ' ::" /_'Z~ -:' - :~i :-'-' -:: ::- "':;:' :-- k "' - ' ~- :/.,.~_.-.:;:.,::_:;' .... '--'i_'J:- - :.:.:;::_. --X: ' 400'' _;.''- 1 .' ._' ;T.-.- ;'_:; ;--LSd:-'; ;: 4 ~1~-5--~';~/'.';"~ - . '- ...~"1';;.-; ~:._L..{ t '-JJ/~N~TE,;:; ;;~;; - ;_"ELL: PATHS-ExTEND-;_ ' . BEYOND; _ _L-;_ x , KUPARUK RI VER UNIT 20" DI VEBTER $CHEMAT I C . ii DE S CR I P T l ON I. 16' CO~dCTOR. 2. TA~O STARTER HEAD. $. T ANKO SAVER SUB. 4. TANKO LOWER QU!CK-CON~CT ASSY, 5. TA~O UPPER QUIC~-CO~CT ASSY. 6. 20' 2CX)O PSI DRILLING SPOOL W/I O' OUTLETS. ?. 10" HCR BALL VALVES W/I O' ~' DIVERTER LINESo VALVES OPEN AUTOMAT I CALLY UPON CLOSURE CF AN~ULAR PREVENTER. 8. 20" 2000 PSI ANf~MLAR PREVENTER, 5 P, ECi:J V'ED MAI NTENANCE & OPERAT.] ON , ,i 1. UP-ON INITIAL INSTALLATIOf~ CLOSE PREVENTER AND VERIFY THAT VALVES -HAVE- OPENED PROPERLY, 2. CLOSE At~NULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, CLOSE Ah~ULAR PREVENTER IN TPtE EVENT THAT AN ih, FLUX OCr ~LL~. FLUIDS OR GAS IS DETECTED. IF NECESSARY; ~AhCJALLY OVERRIDE Ahl3 CLOSE - APPROF~ I ATE VALVE TO ACHIEVE DO~INWIh~ DIVERSION. DO NOT SHUT IN ~ELL AU,j.~;.-;'*~ UN6)ER ANY CIRCUMSTAh~ES Alaska Oil & Gas Cor~s.. Commission _ 7 ' DIAGRAM #1 13-5/8 S(X)O PSI RSRRA, BOp ~TA(>( 1. I G' - 21DDO PSI TAhKCO STARTING Hr. AD 2. I1' - 3000 PSI rASING kD. AD 3. I1' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL q. 13-5/8" - SO00 P~I PIP~ 5. 15-5/8" - 5000 PSI DRILLING SPODL W/O4CKE AND KILL LI~.S G. 15-5/8' - 5000 PSI DOJBLE RA~ W/PIPE RANIS ON ?. 15-5/8' - 5000 PSI AhNJ. AR · 6 , 4 ,] I3 2 A,C(%MJLATOR C, APAC];TY TEST 1. (DECK AND FILL ACO~TC~ RF_~OIR TO PRC~ LEVEL WITH HYDRALLIC FLUID. ~ ~T A~T~ ~ IS ~ ~I WI~ -3. ~ TI~. ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T. ~ A~~ L~ LIMIT 13-5/8" BOP STACK TEST I. FILL B6P STACK Af~ CHCKE M~NIFO. D WITH ACETIC DIESEL° ~ ~T ~ L~ ~ ~ IN ~ ~Y ~RA~. ~T ~ ~ IN ~~ ~I~ ~I~ ~ ~ ~ IN L~ LI~ V~VES ~ TO ~ STA~ ~ 4. ~~ ~ TO ~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO 3~ ~I ~ ~ F~ I0 MIN. ~ ~~ TO 0 ~I. LI~ V~VES. ~ T~ PI~ ~ ~ ~ V~VES T~T TO 2~ PSI ~ ~ ~I ~ IN S~ 4. 7. ~I~ TESTI~ ALL V~S, LI~, ~ ~S WITH A ~ PSI L~ ~ ~ PSI HI~. ~T AS IN ~T A ~L ~I~ P~IT~ ~ ~ ~Y ~ B~ PI~ R~ TO ~ ~I ~ ~ ~I. 9. ~ ~~ PIPE R~, ~ ~ ~I~ ~ ]0. ~ ~I~ ~ ~ ~ST TO ~ ~I ~ ~I. ~IF~ ~ LI~S ~ ~L. ~ ~~I~ ~UID. ~ ~ VALVES IN ~I~I~ P~ITI~ 12' TEST ST~I~ VALVe, ~Y, ~1 Y ~S, ~ILL PI~ S~ V~VE, ~ I~I~ ~ TO ~ ~I 5~ ~I. 15. RE~ TEST I~~TI~ ~ ~~ ~ F~, SI~, ~ ~ TO ~I~I~ 14. P~~ ~E B~ ~ST ~ NI~I~ ~ ~Y T~~ ~I~Y ~~ ~ ~ILY. 5 i 00840O I REV. · i~m~y 1 5o 198- CHECK LIST FOR NEW WELL PERMITS Oompan:,, Lease & Well No..,~/'/~ ~ -~ ~-~//~-3 ITEM APPROVE DATE YES NO REMARKS (2 thru 8) (8) (3) Admin ~¢/¢'>K ~J;~.-¢5:2.5~ 9. (9 thru 12) 10. (10 and 1'2).' 12. 1. Is the permit fee attached .......................................... ~0~ 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~. 4. Is well located proper distance from other wells .................... /~ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~/~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before ten-day wait .......................... ¢4df Does operator have a bond in force .................................. /=e~ Is a conservation order needed ...................................... ~1~ Is administrative approval needed ................................... .¢~( Is the lease number appropriate ..................................... ~-___ (4) (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ............ ........... Will all casing give adequate safety in collapse, tension and burst...~?~, Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~Z..f/ Does BOPE have sufficient pressure rating - Test to ~O~ psig ...//'~.. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: ~-] . Geology: HWK ~" ~',' WVA ............ JAL .'' ....... En6ineerin8: LCS ?: BEW ...... : .......... MTM ~,.~?'*..¢,~ HJH /,'~."' ,:, rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , , 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. [~ECEIVED o c'i-o z, 1985 Alaska U~l & Gas Cons, Commission Anchorage LyD 0lO.H02 VEnlFICATION LISTING PAGE ,~Er~ vi CF ~A~E ; F~DTT ORIGIN : CONTTNI~ATION ~ tn1 ** TaPF HEADER RERV!CF ~A~E :FDlT DATE ORIGIN :fi000 CONTINUATII~N PRFVTO~IS T~PE **~*~*~*** EOF' ** FIL~ ~II,E N~M~ ~EDTT SERV!C~ NA.E : VERSION DATE : ~AXI~Ij~ LENGTH : 1024 ~ILE TYPF ** INFORmAtION RECORDS ~N~M CONT~N?S ~N : ~RCo ALASKA INC RANG~ TOWN~ !2 SECTI 7 COUN: ~TAT: aLASKA CTDY: MNEM CONTENTS UNIT TYP~ CATE SXZ~ CODE 000 000 016 065 000 000 004 065 ooo ooo oo, ooo ooo oo o~ ooo ooo oot o~ 000 000 002 000 000 0t2 000 000 006 065 000 000 004 065 !)NIT TYPE CATE SIZE CODE 000 000 001 065 JO[% ~[J~BFR AT ~CC: 7nSf4 CA$I~'G TYPE F[,UID VISCnSITY ~ATR'[X = SANn = 9 6~5" ~ 3BBB.O' ' B~T SIZE = ~.5" Tn ~2BO,O' = lO.? t,B/G aM = 5,~00 ~ 66,0 DF : ~n,O S EMF · 5,230 e 66,0 DF : 8.5 R~C - 3.500 9 66;0 DF = 7,2 C3 R~ A~ BH? = 2.465 9 t44o DF ,SCHbU~RERGER LUGS TNCL~TDFD W~TH THIS ~AGNETIC n~JAb I~.lt)UCTfON SPHERICALt~Y F~CUSED ~OG * nOREHO[,,E CO~PENSA?~D L~G (BHC) * CO~PEN,~ATED NEUTRON Li:.,)G (F~N) * DATA AVAIbAPLPTI 389~,0' TO ~242,0' ~aTR¥ gbnCK$ 2 1 66 0 ~ 1 66 I LVP 01~.~407~ VEPIwlrATIF~?~ bISTI~!~; PA~E 4 ~ 4 73 6O 9 4 65 ,1TN 10 I 66 1 0 1 66 0 ID O~OER # OEPT ~R bib OT ~R CALl rDN RN~A ~PHI FDN ~CNb FDN ~pI APl IPI FILE LnG TYPE PLAS8 40D NO, mT O0 000 OH~M O0 920 OH~ O0 ~20 OH~ O0 120 ~V O0 010 CAP! ~0 310 US/? oO 520 GAPI nO GADI O0 310 ~N O0 ~0 ~0 ~20 O0 000 DU O0 CPS O0 CPS 00 0 0 4 1 O1 0 0 4 46 0 0 4 1 44 0 0 4 O1 0 0 4 01 0 0 4 1 80 0 0 4 01 0 0 4 1 Ol 0 0 4 1 Ol 0 0 4 1 O2 0 o 4 1 Ol 0 0 4 1 O1 0 o 4 oo 0 o 4 1 O0 0 0 4 1 31 0 0 4 30 0 0 4 PROCESS CODE (OCTmb) 68 00000000000000 68 O00OO000000000 68 00000000000000 6a 00000000000000 68 0000000000~ 68 0000000000 8~ 68 0000000000 ~0 68 00000000000 0 68 000000000 68 000000000 ~ 000000000 000000000 68 000000000 8 000000000 ~B 000o00000 68 000000000 68 000000000 0 O0 ~0000 )0000 }0000 )0000 )0000 )0000 ~R ~R~T 0000 0951 0625 SFbU ~R OEPT 5P qRAT ?CMb 8 ]00 0000 -3n 2451 4492 5~ 5491 SFLU CALl RNRA SP GR NR~T B~O0 0000 SFLU -26 2451 OR JO0 8308 CALl ] 73~5 mN~A 442 ~906 gEPT ~P 8100,O000 SFLU 8~.9 , CAGI 75g' 0495 ~N~A BO00.O000 SF'[U -101.34'77 ~R 4 i062 ibo 5020 ~HOB 3 8733 ~PHI 2 6995 -999 2500 OR 2 0530 DRHO 44 091.8 NCNb 4 t062 Y6~ 2,69'95 5t:4492 DT -999.2500 GR 7351 ~HOB 2,0530 DRHO ~ 8733 ~PHI 46,2891 NCNb 8.3379 Ib~ B2,96.48 DT 8.~29 nH00 ], 25 NPHI 6.7820 I60 84.71.48 DT 7.~742 I6~ 94, 648 GR 2,4045 DRHO 32.5684 HCN6 5,7195 IbM 92.65~3 GR 953, 125 0,00! 0 2503,5000 9~,B250 ,83~S 07R5 RH3B 9905 ~iP!4I DEOT 7900 SP ~R 77 NRRT ? 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NRAT -099 2500 ~N~A FCNL -qgO 2500 -999.2500 Tbn -999.2500 ~ -999,2500 RHOB '999,2500 NPHI ** FTLE TR~I[,E~ rILE NA~E IEDIT .001 $EPVICE NA~E VERSTOW # DATE ~ MAXI~U~ LENGTH : 1024 rILE TYPE EOF ********** ** TAPE TRAILER ** 2,2522 DRHO 46.1426 NCNb 112.]088 DRHO 38.9648 NCNb '7 3 GR 41 6 NCNL ilo OR 2 J6. 8 ORHO 42 87] 1 NCNL 2,2678 DSHO 40,9180 MCNL 164 NCNb -~99 2500 IbM 64!9023 GR -99~ 2500 DRHO-99! 2500 NCNb 0 0000 2033~6875 4,4070 9,8398 ti., ,0024 2032.6875 3.7346 10i.2148 0.0054 2042.6875 96, 14 O, 0024 2i 19,5000 ,7351 . ,2148 100.0083 21i?,5000 5,6570 ,0029 1690,6875 -999,2500 -9 ,2500 -9 ,2500 SEgVICF NA~E :FL)IT BATE J~5/Oq/23 ORIGIN · APE ~i~SF 1n@14 CONTINUATInN ~E×T t~PK NA~E : COmMeNTS Jt,I~R~Y TAP5 g~VTCK NA~B ~RIGTN ~ ~F 1!,40232 CONT~N~ATION # REEl., .A~E : EOF