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Home My WebLink About187-035MEMORANDUM TO: Jim Regg P.L Supervisor ` � 71S41,& I� ,& 7 FROM: Austin McLeod Petroleum Inspector NON-CONFIDENTLA,L State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, July 21, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhdlips Alaska, Inc. 3M-]0 KUPARUK RIV UNIT 3M-10 Src: Inspector Reviewed By: P.L Supry Comm Well Name KUPARUK RN UNIT 3M-10 API Well Number 50-029-21715-00-00 Inspector Name: Austin McLeod Permit Number: 187-035-0 Inspection Date: 7/18/2020 IBsp Num: mitSAM200719090956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Miu 60 Min Well 3M-10 Type Inj W' TVD 6155 - Tubing 2800 - 2800 2800 2800 , PTD I 1870350 Type Test SPT Test psi 1539 IA 940 1810 1750 1740 ' BBL Pumped: BBL Returned: I - OA 640 680. 680 680 - Interval 4YRTST P/F P Notes: Mfr -IA Tuesday, July 21, 2020 Page 1 of 1 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,July 20,2016 Jim Regg P.I.Supervisor e44,. 7(Zz It(p SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-10 FROM: Matt Herrera KUPARUK RIV UNIT 3M-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 7—)R--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3M-10 API Well Number 50-029-21715-00-00 Inspector Name: Matt Herrera Permit Number: 187-035-0 Inspection Date: 7/14/2016 Insp Num: mitMFH160716160929 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3M-10 ' Type Inj W,TVD 6155 - Tubing 2780 . 2780 2780 . 2780 ' PTD 1870350 - ;Type Test SPT Test psi 1539 , IA 1280 2010, 1970 - 1965 - Interval 4YRTST P/F P ✓ OA 460 540 , 540 540 - I Notes: Test Pressure 2000 PSI per Operator ''', ) MAYI9 @P Wednesday,July 20,2016 Page 1 of 1 1VIEIVI®RAI~TDUM r To: Jim Regg + P.I. Supervisor I~~C/C ~~ f i;ROM: Bob Noble Petroleum Inspector State ®f Alaska Alaska OiI and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-10 KUPARUK RIV UNIT 3M-10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~J,r~ Comm Well Name• KUPARUK RN UNIT 3M-10 Insp Num: mitRCN080708053020 Rel Insp Num: API Well Number 50-029-21715-00-00 Permit Number: 187-035-0 Inspector Name: Bob Noble Inspection Date: 7/6/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-10 TYPe Inj. ~' TVD ~ 6IS6 IA ' Iz7s ~ 2lso ~ ; ztzo 2IIo p•T• 1870350 TypeTest ' SPT ~ Test psi ztso pA I6o z6o zw 260 Interval 4YRTST p~F P / Tubing 2760 I 2760 ~ 2760 ~ 2760 Notes: ~T~~ AUG C t~ Z~G$ Tuesday, July 08, 2008 Page 1 of MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~~1' q{u it)}- DATE: Monday, September 20,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-IO KUPARUK RIV UNIT 3M-IO FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RlV UNIT 3M-IO API Well Number: 50-029-21715-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS04080320163 1 Permit Number: 187-035-0 Inspection Date 8/3/2004 Rei Insp Num: MITOPOOOOO0389 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-IO Type Inj. S TVD 2850 IA 0 2275 2225 2225 P.T.D 1870350 TypeTest SPT Test psi 712,5 OA 600 880 880 880 Interval Four Year Cycle PIF Pass Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity, Monday, September 20, 2004 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg í) Q{ I P.I. Supervisor ~'11 ¿) Ii ,04 DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-IO KUPARUK RIV UNIT 3M-IO FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5ßf2.- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3M-IO API Well Number: 50-029-21715-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO4080320 1631 Permit Number: 187-035-0 Inspection Date: 8/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-IO Type Inj. S TVD 6479 IA 0 2275 2225 2225 P.T. 1870350 TypeTest SPT Test psi 712.5 OA 600 880 880 880 Interval 4YRTST P/F P Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, August 04, 2004 Pagel of I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed Please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on August 24, 2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Problem Well Supervisor Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field WELLS PTD# TOC VOLUME TYPE SACKS ft BBLS Cement 1H-01 1930060 18.0 3.74 Prod 22.6 1 H-21 1930460 21.0 3.66 Prod 22.1 2K-08 1890830 6.0 1.8 Prod 10.9 3M-09 1870290 46.0 8.32 Prod 50.2 -~3M-10 1870350 52.0 10.1 Inj 61.0 3Q-03 1911260 14.5 3.44 Prod 20.8 ADDENDUM WELL' 8/4/87 8/11/87 3M-10 Arctic pack w/175 sx CS I & 60 bbls Arctic pack; test good. Pressure tested 9-5/8" x 7" Arctic pack to 1000 psi. Pressure tested 7" casing to 3500 psi for 30 min, ok. No communication between 7" and 9-5/8" casing. D r~l~i ng Supe~or DEC Alaska Oil & ,S3,,~ Anchor"age STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Pull tubing Other 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 1042' FNL, 1636' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1351' FNL, 1765' FWL, Sec. 25, T13N, R9E, UM At effective depth 1377' FNL, 1638' FWL, Sec. 25, T13N, R9E, UM At total depth 1392' FNL, 1567' FWL, Sec. 25, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7222' 6479' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-10 9. Permit number/approval number 10. APl number 50-029-21715 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7084' true vertical 6371 ' feet Junk (measured) feet Casing Length Structural Conductor 1 1 5' Surface 3 3 8 4' Intermediate Production 71 76' Liner Perforation depth: measured 691 0'-6942' true vertical 6235'-6260' Size 16" 9 5/8" 7" MD TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, EUE, IPC 6837' MD Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA 1787', Packer: Cemented 203 Sx CS II 1200 Sx CS III & 260 Sx Class "G" 300 Sx Class "G" 175 Sx CS I Measured depth 115' 3384' 7176' Camco HRP-I-SP 6807' True vertical depth 115' 3384' 6444' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re0resentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 660 610 - 0 - 450 200 - 0 - 0 - 6000 1000 2000 16. Status of well classification as: Water Injector X Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~igned .//~¢zi..,~Rev~06~,~.-.<---¢.~'~¢O Title ~'~' ~f..,O.J~ Form 10-404 Date SUBMIT IN DUPLICATE · -' WELL SERVICE REPORT ARCO Alaska, In~--~,~ Subsidiary of Atlantic Richfield Compa, WELL iPBDT CONTRACTOR , ,EMARKS FIELD - DISTRICT- STATE /<',,e' ~ OPERATION AT REPORT TIME DAYS ID~TE o~$o I~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ] Temp' [ Chill Fact°r Visibility IWind Vel'Report °F °F miles I Signed knotsI :--- --'" Drillsite Morning Report ARCO Ala Inc. {~ CPF 3 Date ~-/'~-°~<:~ __ Time_ c~- ~OO Drillsite ~/~ Gas Lift Status '. Shut-h,~ ~ Status - TP Production Well Status ~ ~Well] P.T. or ~Choke Temp ~ Last H2S CSG Pressure PSI Gas ~ Inj. Rate ~ SI Zone PSi Bean OF WC% PPM 7" 10" ~ Temp Meter Total MSCFD Hrs~Reason ..... .... Total S Ltus Shut-In ~atus t inJ~ctlUll ¥¥1:~11 OL'"'JLUO PW nject. Pressure PSI ~ Choke CSG Pressure~ Meter Injection Rate ~ ~or SW Zone~Allowable Actual- Bean 7" 10" Total BBLS/Day MMSCFD Hrs. Total SWl Total /(~ PWI Total Drillsite Coil Temperature °F Coil Pressure PSI Bath Blanket Heater Prod Test " Prod [ Test Temp. Gas PSi Run Time Headers Production Water Injection Gaslnjection Gas Lift Drain _ Pressure .~/ /z~'t:3<0 1-8: .... 9-16: Temperature -- /1 Comments Chemicals Type Gal/Day Level Operater's Signature/,~,_~' ~ 3A.024(05/27/87) ARCO Alaska, Inc. "~ Post Office B~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 17, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are on Kuparuk wells. The wells Well 2G-9 2D-16 2F-10 3M-21 2E-11 2H-15 2H-13 3M-1 3M-2 3M-10 3M-15 3M-16 3J-4 3J-9 3J-13 If you have any q Sincerely, Commi ss i on multiple Applications for are listed below. Action Fracture Perforate & Stimulate Perforate & Stimulate Perforate & Stimulate Stimulate Perforate Perforate Perforate & Stimulate Conversion Conversion Conversion Conversion Perforate Perforate Perforate uestions, please call me at Anticipated Sundry Approvals Start Date February, 1988 March 4, 1988 March, 1988 February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 March, 1988 March, 1988 March, 1988 265-6840. G. B. Sma llwood Senior Operations Engineer GBS'pg-0154 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ~" ALASK,..OIL AND GAS CONSERVATION COMM.,.,SION APPLICATION FOR SUNDRY APPROVALS ., 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate L] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360? Anchorage: AK 99510 4. Location of well at surface 1042' FNL. 1636' FEL Sec 25 T13N, R8E, UM At top of productive interval' ' ' 1351' FNL, 1765' FWL, Sec. 25, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 63 6. Unit or Property name Ku~aruk River Unit , 7. Well number 3M-10 8. Permit number Permit #87-35 9. APl number 50-- 029-2171500 feet At effective depth 1377' FNL, 1638' At total depth 1392' FNL, 1567' 11. Present well condition summary Total depth: measured 7222' HD true vertical 6479' TVD FWL, Sec.25, T13N, R9E, UM FWL, Sec. 25: T13N: R9E_. UM 10. Pool Ku~aruk Riwr Oil Pnnl ! feet feet Plugs (measured)None Effective depth: measured 7084' MD feet true vertical feet 6371' TVD Casing Length Size Structural 115' 16" Cgnductor Surface 3384' 9-5/8" xx x~f~mX~Xd~c[te Production 7176' 7" xxxE. Fr~XXXX Perforation depth: measured 6910'-6942' ND Junk (measured) None Cemented 203 SX CSII 1200 SX CSIII & 260 SX Class G 300 SX Class G & 175 SX CSI Measured depth 115' MD 3384' MD 7176' MD True Vertical depth 115' TVD 3384' TVD 6444' TVD true vertical 6235'-6260' TVD Tubing (size, grade and measured depth) 2-7/8", 6.5 lb/ft, EUE, IPC, 6837' MD ¢¢Sc~ers and SSSV ltype and measured depth) · Camco TRDP-1A-SSA, 1787'. Packer' Camco HRP-I-SP, 6807' 12.Attachments Description summary of proposal [] Convert well to water injection. 13. Estimated date for commencing operation February, 1988 Detailed operations program [] BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and¢orrect to the best of my knowledge Signed ,/~,/'¢'2/"c~f y~ ¢-~'~'~ ¢'-~-'7--/~~' ' Title Sr. Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness _1 Approval No. [] Plug integrity [] BOP Test [] Locati~_no~,l~(2aqp¥ Approved by Date2/17/88 ORI61NAL SIGNED BY LONNIE O. SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate~ "'1[''' STATE OF ALASKA ALAS:I~-- OIL AND GAS CONSERVATION' ~OM MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG · , 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-35 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21715 4. Location of well at surface 9. Unit or Lease Name 1042' FNL, 1636' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit .., At Top Producing Interval 10. Well Number 1351' FNL, 1765' FWL, Sec.25, T13N, R8E, UM 3M-10 At Total Depth 11. Field and Pool 1392' FNL, 1567' FWL, Sec.25, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 63'I ADL 25523 ALK 2559 , 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. ~ 15. Water Depth, if offshore I'16. No. of Completions 04/01/87 04/06/87 11/1 6/87*I N/A feet MSLI 1 "i7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7222'MD, 6479'TVD 7084'MD, 6371 'TVD YEs,Il NO [] 1787' feet MDI 1600' (approx) ~22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL, Ca1, CBL, Gyro "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 ' 115"' ' 24" 203 sx CS II 9-5/8" 36.0# J-55 Surf 3384' 12-1/4" 1200 sx CS Ill & 260 st Class G _ 7" 26.0# J-55 Surf 7176' 8-1/2" 300 sx Class G & 175 sx CS 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) _ Perforated w/12 spf, 120° phasing 2-7/8" 6837' 6807' , , 6910' -6942 'MD 6235 '-6260 'TVD "~6. ACI D, FRAcTuRE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL'USED _ _ See attached Addendum~ dated 11/1.8/87, for fr. acture data. 27. N/A PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) , , Date of Test Hours Tested pRoDuCTION FOR OII'-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD , Flow Tubing Casing'Pressure c'ALCULATED OIL-BB'L GAS-M(~F WA-I:ER-BBL OIL GRA~/ITY-API (corr) Press. 24-HOUR RATE I~ 28. CORE DATA BriefNonedescription of lithology, porosity, fractures, apparent dip's and presence of oil, gas or water. Submit core chips. DEC 1 'A~a$~ 0ii & Gas 6o~s. *Note: Drilled RR 4/6/87. Perforated well & ran tubing 9/7/87. Fractured well 11/16/87. r , Form 10-407 Rev. 7-1-80 WC4/10:DANI CONTINUED ON REVERSE SIDE Submit in duplicate~ ' 30. 29. GEOLOGIC MARKERS F'oHMATION TESTS .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6897' 6225' N/A Base Kuparuk C 6913' 6238' Top Kuparuk A 6913' 6238' Base Kupar'uk A 6976' 6287' 1 31. LIST OF ATTACHMENTS Addendum (dated 11/18/87) "'32. I hereby certi,fy that the foregoing is true and correct to the best of my knowledge Signed (~ ~/7'/~ J ~ l/~ ~A.~ Title Ass°ci ate EngTM 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 ADDENDUM WELL: 3M-lO 5111187 RU CTU, RIH, tag ice bridge @ ±70'. Circ 10~ brine, wsh bridges. RIH to 1500', circ until 9-5/8" x 7" ann freed up. Pmp 2bbls methanol @ 180°. POOH to 150', displ w/diesel, RD CTU. RU Hot Oiler & pmp 55 bbls brine & 25 bbls diesl, RD Hot Oiler. Secure well. 8/04/87 Arctic Pak w/175 sx CS I & 60 bbls Arctic Pak. 11/16/87 Frac Kuparuk A1 and A2 sand perfs 6910'-6942' in ten stages per revised procedure dated 11/07/87 as follows: Stage I: Pad "A" - I00 bbls gelled diesel @ 10-20 BPM, 4600-3850 psi Stage 2: Pad "B" - 455 bbls gelled diesel @ 20 BPM, 3875-3850 psi Stage 3: 40 bbls 2 .ppg gelled diesel @ 20 BPM, 3830-3807 psi Stage 4: 50 bbls 4 ppg gelled diesel @ 19.9 BPM, 3830-3850 psi Stage 5: 50 bbls 6 ppg gelled diesel @ 19.7 BPM, 3880-4000 psi Stage 6: 50 bbls 7 ppg gelled diesel @ 20 BPM, 3875-3950 psi Stage 7: 50 bbls 8 ppg gelled diesel @ 19.7 BPM, 4058-4000 psi Stage 8: 40 bbls 9 ppg gelled diesel @ 20 BPM, 4100 psi Stage 9: 30 bbls 10 ppg gelled diesel @ 19.9 BPM, 4200 psi Stage 10:40.4 bbls flush @ 4400-4200 psi Underflush top perf by 1.4 bbls. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: ' 850 bbls strap 61,200# (computer) 390~~. ooo ARCO ALASKA? 3M-10 KUPARUK ALASKA .............................................. A.qchoYng8 ............ VERT ]: CAL F-:;'i~-L:.'"i" i'i'",N '"(_'!P.,L..Ci_ILATED AL. liNG (.':LO::;L!F;ilJ .............................. .. At'4 C HOR GE ~" '. · ' :vt.'e; : ' ' '~' ;~'~, ",, '"'~"'~ ,..:...,,:.. -..-., .i~- - .-, -,- · - '.; "~'.;~¢:~:~a~ ...... ' '~' ~"~'~.'?~::;}'T.,.k"",~'''?'~ ,"',L~GL.i:ii;:-r' l 1 ... 19,'97 dOD NUMBER ~K-DO_-.2'O052 .... ....................... , ........... --- '... KELLY BUSHING ELEV%.'-...~-__ '.63,00 OPERA T OR-M¢:Gt~ ,1Rl~'~,'!"¢;ik: :, %.'i \%,, · ";;' '~ .:: ~ ° '~' ~ ' ' ' '~ ":""" ....... .,¥.:~' :.~i¢.'.', :~,~'.:.. '. S U B---SE A Li:O L CF;: S¢i:' E'O U R'.--;E D~ ,'".;:;2,:;;.~...:.:.c'~~ ..... ............................................................. 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'::':'.'"':,,~:¢~ .............................................................. ,::,~,',:, ::;..--':: :,.,,.': <*,~:;:..: ,,.'_.'...:~,.~.<:::~.,;:,<'~,.<,:,¢~..,,,.':...::...~=<~-' ~.: ............... . : ~, .',,:.. '- ,~ ..,,?., ........................................................................................................................................................................... . . .: ~ ................................................................................................................................................................................ : . .:, .,..~..,,,.~:.,.,.:.:..:~,,~..,,,...,:,,~:~:¢:<..,., :,::;,.,:.,,:: :,.:;. <:,,:,':.:..:....:::::::::::::::::::::::::::::::::::::::::::::: ?.:.,::.: .?-:...,.:" ....... ?":::":,'-" :."-.:<.:. ,.:., ...... :: :"~ :: .:...,.:, ......... .... ,',', ~,;_~.~;. ....... - .... ~o,,~ .,' .- :4;~., ...... ~"~ .............. ',:; ................ ';:'.'~,,"~ - ., , ,,~,.. . !:.:~, ~ ,,. ,. ~, , . ~ ~ ,~, ..~, · , ..... , ,,.. , ... < ......... . ,~., .. · ' '..':' ,. ...,, :,:.,..:..:..... ,.: ,<.,,,.,.,,:<~,~,~: .',... ............ · ........ ~ ........ ~,~,.~,~,~,,,,,..e,~,~.~,~ ..... . -- - - -- ..... --~'~..~.?,'~,~,',~',~<,,f,,~..~';.;,., .... ,:u,,:.:~, ..;.~..: ..... .~:,,.,..,..~.,.,/,i.,%~ ARRO ALASKA 3M- 10 KUPARUK ALA'.S4(A "i"F;OE D E F' T H 'r) E; F' T i-! ;' :'; 3764 5: 7',':, :':: ,, (} 0 . ': : ,_'!~ ~, / :.T:u_:?, d:, ::i;. (.)0 ?] 5';'/:,'q f-~ '] .................... ' ,:,,r:,:::;<,. -¢,~ ,..,.:. '.'~'-;,,-,...~~'. · "'. I" I"' : ........ '::,I_,B--.:,Ei-~ l i, i :"'~ L.. ' (?'F~'i~'?"~ i~!-~L~'i2' ............ i~'~iE i~! T A'I,..t i} t .f i.../'fi:;: C o oi::;':D i NA TE'._=; MD-TVD ' VERTICAL DEF'TFI NOFiTH/S~;c)t.i T'i.i iF A:.:;]" / WE'.:;T DIFFERENCE CORRECTION .............................................. · .? ? ':':~'.';'*:.~,.'~%~., .~:;~:,?,:¢',~tte]~ ?~? :'~!~ %'77':!"7"~': ....... :.' .'; ': ,.:?'i/'.:'z',.?.';:r~;.;.;"L,','.~?,¢i:?;,t;:'*.}s':'r,'; '::' :::~."./'."?'"V"" ' · '. %/" ..¢ '.)., ':)0 :;ii: :?,,, !i:.'i,:~.' .... i"..! J. '.:,, 77W 't"...i'."' 1,'", .... "t~..!':,.;~ ""~'"'"".: '"...' :" ' ':'* 'J,, 24;;" ............................ . ............ ' ':"".....:'.'.::2.,;. a':'.'¢ ~" · '--,':::,',,": (::,.':: ::i: ::.::: ., .i:;:-.-: ~,.~ .':..:. ,--,9 w ...:"".,:~,:;,."..,~:.,'~.~':')},:~ .'.. .. · .... · ... 4... - -'-:' , .m:i--, ;: ,-:.- .................... T.5:'i'""-',' ' :: ........ .2' .:} (_: ~...~ · ..." '-':. ,2, .... 5767 · q ?:, O o. 0 C) 4.q.~ ,:'i. 70(_~ ':..:, 0 !:::;::::~ ,, ....... 4 .::::*.';i 0 ...""~ 0 ':.-:' '.ii: ,..2 'i::" ri::: 5 ':::": ,'.': :' ,, 0 t]'.,8 '7 ,. 5' 6 :5; ':.: :':, '.":.). O () j. ():;,, '7 .......................................... '": '; '...'""., ':)O 'i i :.-':' .. ,:!:.'5' '-':: "' ,..., . ~' "'~i"~ 'i :'.:', ':d 5:1 '7'" · ,o ,.,. ,, ............ !i:; ":i' ,.} ,3, (-:,,:") ! '.5 ""', '.::54.'.'~C','"i'5'i5.. ............................. :.f ,'_'..i i~ii ':' 4' 1 ;~:::'...., '.5 5 ()~"'~ ,, C) 0 I :!""',,.'!:,., '.q'7' :ii!; ARCO ALA'..:.;K[:~ ? :1: ?..! ..: .. :3M- 10 b:LIF'ARLI,k' ALASKA MEASLIREI3 ..... i:)EP ~r'iLi I<ELLY BLoHINI_, ELEV, = 6:3. OC~ FT. ........... OPERATOR-MC:t3Li I RE ' ',.,~ "' ', ....... ' .....~..~,~'~L": ~':~ · .'.~,;;~.i~,."~ '- .,. · . ,:~ ?,..¥, x~-,,~.,:~.~ ~. ,;.:~..- ~.:'~,'... ,.~..,~:~,,. ~,:.. :~:....:~.. , ~ ............................................. · ' ~', :;: 'd:' .... . .. ~; :::?'.,!' :".. :::'.,: "..' '''~' .' :,!.'~:! !=i';~( J'..'.'. ,, (".*('~ :22:3 .::,:::. :::i, 'I .-.":l.'Pt'f.: 67 W ~_~o' ~a.',~:: ..... · .............. :":'~'~ ........................... ..'. -..' --.' ............ :~'.:2~: ..~ .. · , ............ · ' ; '.' . . -'::.F',.,'...,.'I. ":'"'~ I,,J 7'-d7. ".-"):"4 -T~'7 -?'/'- .......... ~...... ........................... · ~ · .~,~... ~'.,~ :,, , ~. %,~ =.. ~., '~:~,~,,i:,,;i.,~,~ '..., '......... · :~..~ ~.' ¥.,., · .... ~ ~,,, '~' · ,, ~ ~: · · '~ ..... ~ ~.~ ~,,.,.;' a* ~, x. ,, .~ · .:.:.., Z:,z.;'" ':/:Z'~' f!i; 7 ,,.:..>.',,, ()0 ......................... z~c:,._, ...., ,_, ~:;'":" ~': ..... ::~:: ,, ()C~ 6817 6 J. e: :3 ,, 00 6945 6:2(:,:2,, ()0 707:3 F o~.--:, ('~c~ ARCO ALASKA) 3M- 10 I<LIF'ARI_IK ALASKA MEASUREF_; DEPTH 6897 6. 13 6976 7000 7t),.. 4 7222 i N'T'ERF:'OLATED 'v.-'ALLIES F: ]'tF:i: S; F:' IZ F;,~ t: :,' ,~ ..... :~-i:i.i?..! i...JF_'i'~ !. 'Z:URVEYING COMPANY F'AGE. '..;' ::,.. "~:.' ALASKA ..... ~':'~'"~ ':'" ' ~""~="'""'""'""=';:'" ;'~'~''-~':'-':'~:''¥': ................................ :' '" : .~ . ,,~.'.~:~:,,.. ~.~..,~,~, ..... ,.,. ,~ ~,;,,,. ,, .,.. ,,..... ,,:.., ~ ,*.',,, ...... ~,...... ..:. ....... ;~i.i~$,,,.,,,.~¢.':~ .......... ., ..... ~ ............ , .... -7:..':.'i:;-: ';---:.- ..:.:....;;~i · .. ' ~ .. ~." ' .7 ')' '~.'/.:' :':ir],~,.~'J~'~..Y~,.~2,~:..~.; ',(~'~..X;>.2~"~'~' 'J.'~.J...i'~ J_~"[~. ~.:'.".. · ..;.' . .~ C"N D~TI~,, ;'" ¥ :~ ~ ':" ': '" :" !~' ~? ':~' ¢;,..r~:l".w.5~..!i;,.,.',.~ ~"~? '.'::':??"!?' "~ ' .., ................. i, i '.-;,87 dOB NUMBER -.:.. --~. i<g.I,-LY Bt..~HINu ELEV 63.~_EY ....... ~ ~ OPERATOR-MCGUI RE .ii": ~i .. ~ . . ...... ~. · ~" ,' '": ~' '~ ..... ~' ..... i~!.)'::,~A~' :";,'4¢}'~?''~'~ $~'~' %?'?'"':'::J~ 2' '" , ,. '??' ............ , .'~.: ,",,.,.;.-:.7,.r.l.}.i:.~ ..~'._.:!:':.:!~' 7~¢~l&~,~:~a:..'.!'>"': .~ '..::':' .:~.~'~,~:., ' !,;.:~ ,:,.;:',.'....~..'/ .... '~,:i~:, . "i':~)"!"Ai.. ' ':" :' ,':-, i. 7 4 3 J. ,:"i 6,'7 2 3.9 4' .... :}.'i ]. :3 ,. 7' :I ,'..'-:. 2':'I-2. '7 :Z.:.:3 21., '7 2 ...... ,% :':-~ (..:': -; . 4 L-'i; :.i!~ Z::;.,:i.: .. ~::' :.:': ,..., .]. ~. ,r:.,., 4."i;:" :'::: 4':-:.', !:::,,:"¢ 'iii, NATES / W E S T ! ;:!i:"?'P. 06 W 'J 8',B:B. 8'3 W MARKER .. · . ..;,<..: ..,,, .:,, ...,...,,. · .~.' ~ t:',.i f.' BASE KI.!PA..RUK C t8!3'2,. 8:3 W TOP KUPARUK A t .-....:. ,' . ..../:...','.'-."iiii.·..2 .......................................................... W BA:,E'.% ......... kLFARUK2!_: .......... L..:' .A ............................................... 194i.8'P W SURVEY DEPTH ................... · '. i';::'.;>:3, 10 W PLiJG BA~I4 TD. -'°'. -". '""~ '-'-' -"'~ --I . · .' .,::::., ,.'/, z.-'-', W TO~AL'i:i DEP..TH. ·DRILLER '. ": '.. ,' : .,~.. ·. ,. _ ~ .. . ...... ...... ..~ ' ~' '-. '"~¢: 7,4 K ;'~'~;:. ;?;i-~";;;,'~';-q::',27t'~%::r.'",'.,"~,':":'?~L,'' '. .2 ...,! .... .:... ~..:...~ ............. , ...... .;, .,, .... ., ......:.i';'.''~. ..... ~':,;;"~'~: :;~,',¢:~t '.%~ ?.'.'".,]'A".~'~,:"L, :, .. , '~ h!,. ' ..,~r.:, · . 7, ,';¢;;'~, ' .. · ".. ,~.:'~ ,,~f~ ? ~:';]~, ,; ~. '.'.,,: :: ft]¢~.' 'j 'r-'/ ,' '. ' · .. i.:.]'?' .:.. ;.~. ::. :.: ¢;?,,;r:. ~:~;.::;,..: .:,',?:..;? ..:.,..., . . . . .."'i,!~ ,, .:...x, · :~ ¢..L& ...,.¢.¢-~ ..{.-~ >. ,'.'., :'"/ ,...',' ~.,' ' · · .~.].~ · ~ .'. · ,% ~ ,' ::* ~ ..,?' ',;.G[.t ':'¢:~,~";,~i".¢~;?,..":: ,"7.":' :,' ..... ~,, · · · ..... · .................................. ;: :;;-~_ ....... ~,,_~-- ~ ...................................................................................................... ' ~¢:'. :.~,: ""%;:4" ' ' : - ' '" ' " ~ :..: ~A,,,%., :~..,.:~'?.:.':~,,?.f.::?:,.,;¢ .:.' ':...' ..,:,:..~:,~~ "':i.':'i~?~i"" " .... ~(?'?"'.?';:'"':' "':'?."? :'"':'. · ...., : ..... :.%'7 ,".:~:':";:'" .;?"~':"i~".'"":'~ 'r}i::.>..77. ....... ~ "'::., · ."?"'.:~,. · ,:' ...... .,,¢.,,.~.,.,.,~,~,.¢,~'~,¢,&o,,,,'~':A,.,~4~',~..~,,,%,,,"-~, ,., · ~ . . " · ' "' ~'.°' · :'. · ,,,.,,.,,,,,,.,.~.,~ ........ ~,~...:~¢,..,-~.,.,.?,.-=~. ....... · ....... . ........ .:. ........ ..:'"'.'..,:..:::'.".., . .....,,~.::~ · .. ,.:, .~,.,...., .,.,? 4, ,., .,, ... ,,. .... · ...... .. · ~,....,.., .., : ..... k, ,:.~':'::, ."~,,.~,,,.:.,' '~: {¢".,,. ,.~'.'.";..: i~ i.,':<., ~:. '%.¢-,.',-.' ¢i.. ';i~,;, ,: ,,~' J c:.A-. ~ )¢~.4~:~,(.~i4:'~,, .'.."..',i >:. ~' ,<':'. .' lr:.)E;F.: ]; VED i..i'ii:; )' r,.¢,.;i~ E, i:1 .OEF'-!'H:--; AND SPERRY SUN SURVEY DATA , , . .... · ~. _~,%.-.%.' . . CO( BIB,l; NATES --Mt~'I~KEF~ ..........: ............ M E A S U R ~'~i' '"'~i,~¥[::;): H ..... · ............ -'.-:.-- ]'VD--;,-=~~ ........... "*"*"" ....... ' ..... ' ...... .................................... .............................. Ti_qP'" 1-::'1 ............. iF'AF:Ut-:'; *-: "r:,',::'?'? ................ A';;-~';:' !-.q .1. 4- .5. I/-:, .-'-' · 14 ' 30. 8.7~:~___ ' '' ".-q 1~: 7'.--~. Cj ¢" --- ................................. Ei'~':~'i'E"'KLtF'AI:?LiI.::; .Z; ' ..... ;L,",t:/~"!~.i' ............................................... ~i:,23'?~ ,'"-..5, &174 66 , 310.78S' . '~'"'18:E:E.:. ':": · l~t~F I-,UF ~.~RLf~,. A .......................................... '-' ,"!:, .}:.:!i',''7 ...... ,'"'/-, ~_.! 74: .~,~""~" ?:"~'~';.,'.. ~.t~:'*'~-,'~ ',~g:~;:.;;,}~,,.i:t j...t.~:'t.,,::¢,~.;;:;Er.:':,,' :' '~' ' '~:~'~%-'-~"~::'::"~'*':~'":~;':~':";;"" !~:~,~.~"~',~, ~',, ,i"~' "'~,F"7 ........ ':~':, ':., ":[ I~t~.' ' - -"% BASE t<'t tF'ARi t~::' r:':-~ ,'.":,'.-.;'7,:5 ,.':::, ':.'."'.::,":, ':7;4 /-,":-"--¢':' ~"* '""~¢-*':~ *;:"°'~';~-¢g':':*~m~:t¢":'~'~'"~"' "':"""'"~';"¢'"~ '* '* ..... ....... ,.: ,,:~¢. ~,.~.,,.::t,~,'.:.::~.~:.".x!,:,,'.~..:;~¢~;%~,?:.¢s"" :.',,'"!'~g:,:',:',¢,,,.',...."'., ...., ,'...~:~)~ "7,":i18,: 1927 '"' ' '"':~ ' " ! '" ........ "~ '~'~': ,',"' .~!.;',.'.';'~.:~',,,-~..;c'~'.~".'.:;¢.'.~; ~, .: ~i..'.:, "';'.':~'.": .' ';' ':' "~ · ": ' · . PLJu BACK 't"D ';:."-OF:;~ ,'_.:~..:~/t, 4S 6308. ~8' .,i::?:iS*,.j¢'i!¢,.ii!i!~'X:.~;'~;i?t.',.;~,::';///,:,,,::.%"c.:,~,:t::X:,;' .v.: .~:~I~?~;,."2L~S. ! 993, ..... TOTAL DEF'TH E~F;ZL.i...EF: 7;.:::~-~-- ............................................ ,'_":,>-1-'7'.:}", 4'F: /_-,415.49 34..<'. DOS 2077.23W ......... .................................... ?'::.-": .... ' .... :: !~,'.:::%-; .' :,'-:, ' '.;'c,, ~:.'" '~:.....:: ,. ,.. ..'.: . ' '..'." "~'"' .... :" .... :'"' ...... ' :,. ' . '.' ,... .... .; .... . , ., .:, . ., ' . ............ :'. :" ....... · .;.." ' ' " ........................................... ., ......................................................................................... 4:'; ':?'? .... .~.~,.`..:(~.~t~;`.~:::~;`5;~..~?..`~¢~`~.~.`z~`~%f%`~`:~;;~4~`:~..~.::~4~d~. ':'~';:":;' "'"'": ·, .'c":¢:%'~,~i' -~ ......................... ~ .......... **~: .... ,,. ....... .., ....... ...;.<~ · :.... ',..'., .:.,~.,,.' ..~. `~.``:~°`:~%`Q.~>2~?~`~,.e?~.~.:F~1~4~;~t~.:~:;.;~;~?;...~5;~;~., . · · ........ . ..... ~, :.,.:,, ;,,,~: ~¢.~.87~.~,~,.;.~..,~.~,,.~..~',...~.~.~.'~,¢,~: ,,',;.~:,:.,.., ,:.:. '.,. ;i.: !'.'::..;:;i... ~'.':.": ,,<.,,,:~ ,, ,?,;:, ,. :.,'.,.**.'.,;,.,.:., ,~,.',~,.,.,'~, ,.' .**;i.'~ ;.,~.':.'. ';' ...:.'. ':: ,,~::i..':I~.,~.*,'. ,,',,~'., '*. ? "&'*.:'t,t', ,, ~.,2'~'.,,'. ;' · ' ' .7 ..:: .... · · · , ~ · ~' ~. ·, ~,~.,,,.:~ ......... ',%'.*, %".",¢'" ~ '*x~".'~ "': .... ..... ,,., ..... ,,.,.,,,,.~ .. ........ ,~ ... :~,, .,, .~; ,..,,, .... ., ;~... .... , . ......................................................................... .... .......... .~,,;,,,,,**~**..:,_,.,,,.~,.,,,.. .... .,..,.,~.**.**.,,,~.,~,.,~;......,**, ...... ,,~..,. ........ ~;,,~.,,..,,,,..~..-:',.-'.'.,' ....... : ............ ............. ., ... ,... ................................................................................................................ -,.~,,,~$~~,~.**,,,~.~--- .................... ~" -,--r~. '~_--';Tq',-,~--r-- ..... -' ;, '-'7" ~-": ...... :.....; ..:,. ....... ' ........ ~"=,'---: ....... =.:--.-;"'z:':.: .ir ::.':: r ~.: .'::: - :-~- - ,---.----..,. , - ?,::.,,: ..x:~¢,-:.~. r:',,:; .-.,,.,~,~...??~,,'..:: ! ,./~$,¢;.' · ~:} FRuI,1 L. INE.¢-,[, [::.x~'~.,,..,F....il_:.g.i'fZON }_'._',ELU~,I IJE. E¢'[.ur .':.:;IW~I. uN. :.~j r~,;r,,-..':,:~..:,:¢.?.t..';.',..'"";"".:..**:¢~~ ·" 2 ) 'COffiPUTER F'F;:()E~RAI'i ..... :ii!;I:::'EF;RY SUN THR'EE .1"~ I IqEN:.-.'/; I ONAL RgD':~' ';i!~"'!:i'i'"'"'!~i*. ,z ;' :,' ' ":'::':":' ' 'Z'"'.::"i¥,¢~~~ .............................................................. ".: ~;-,,,¢ ' ' ' *" .;-~.~" ~.~,~,~ ~,..::',,'.,',~*'"'. '.' :.".' .: .: ,2'"?,'' DATg L:A[ ~ :l Ii f-:: I ] ~ ~l',l ¢.-'.,!',L~ ~ I N I ~.-!--,:F'~ ~! Al' I t~N f..¢¥ I..<Ai~] I It-; ~ d-. ~ :11RVA]' U~~," ,.~,:?:w~t';,'.;::'.:" .'. v. . '"..'i¢~ ............................................................................................................................................................................... ........................................ ,SPERRY -..SUN 5CRLE :- 1 INCH TO 500, OO / 500.0 KUPRRUK 3H-lO RK-80-70052 TRUE NORTH · ~,~.~,.~ . . , -2s[o. oo ' :2~o. oo" .-:s~o. oo --~c[o. oo .......... ~~ .... HOBIZO~TflL P~OJECTION RRCO RLRSKR, INC. RUGUST lO, 1987 "1500,. O0 3000.00 SPERRT -SUN 4500.00 .6000. 'l:ro ,' : !!:~' , .'i::; 64,?9.49. 7500. O0 $CR'LE :- 1 INCH TO KUPRRUK RK.BO-?O-O:52' .- .... -7222 VERT I CCq-L I 1500.00 3000. O0 PROJECTION ARCO Alaska, Inc. I Post Office B..... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 28, 1987 Transmittal '#: 6098 RETURN TO: ARCO Alaska, Inc. Attn: 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. ~'2X-16 '-3M-lO -3M-11 --lq-12 ---3C-1 ~-'3F-5 -'-'3F-5 '--3C-15 ~ 3C-16 ~ 3C-14 ~'3C-14 Kuparuk Well Pressure Report(Otis) 10-3-87 PBU 'A' Sand Kuparuk Well Pressure Report(Otis) 10-2-87 Static 'A' Sand Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand Kuparuk Operations Engineering Pressure Falloff Analysisl 3-15-87''A' Kuparuk Well Pressure Report(Otis) 8-15/18-87 PBU 'A' Sand Bottom-Hole Pressure Survey 'C' Dual-Zone PBU 10-13-87 50-029-21460 Bottom-Hole Pressure Survey 'A' Dual-Zone PBU 10-13-87 50-029-21460 Kuparuk Well Pressure Report(Otis) 8-28-87 Static 'C' Sand Kupaurk Well Pressure Report(Otis) 8-30-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-19-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-16/19-87 PBU 'A' Sand · ,,-, REOEI D / Naska O. ~, ~as Cons. Commlssi0ri Anchorage Receipt Acknowledged: DISTRIBUTION: Date: D&M BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRIchfleldCompany ARCO Alaska, I~/'~ Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 RETURN TO: ARCO Alaska, Inc. Attn: 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 s~gned copy of this transmittal. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M,22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement Bond Log 8-21-87 7689-8410 3M-14 Cement.Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement BOnd Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond.Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt'Acknowledged: DISTRIBUTION: NSK ~fault(film) ARCO Alaska, Inc. Is a Subsidiary of AllanlicRichfleldCompany STATE OF ALASKA ALA,.,KA OIL AND GAS CONSERVATION CO .... ,'IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate)~ Pull tubing [] Alter Casing [] Other~] COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 63' Feet 3. Address 6. Unit or~roperty name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk Niver Unit 4. Location of well at surface 1042' FNL, 1636' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1351' FNL, 1765' FWL, Sec.25, T13N, R8E, UM At effective depth 1374' FNL, 1651' FWL, Sec.25, T13N, R8E, UM At total depth 1392' FNL~ 1567' FWL~ Sec.25~ T13N~ R8E~ UN 7. Well number 3M-10 8. Approval number 7-273 9. APl number 50-- 029-21715 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 7222 'MD 6479 ' TVD measured 7084 'MD true vertical 6371 'TVD Length Size 80 ' 16" 3347 ' 9-5/8" Casing Conductor Surface Producti on 7141 ' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 203 sx CS II 1200 sx CS III & 260 sx Class G 300 sx Class G & 175 sx CS I Measured depth 115'MD 3384'MD 7176'MD ~ue Vertical depth 115'TVD 3384'TVD 6443'TVD Perforation depth: measured true vertical 6910 ' -6942 'MD 6235 ' -6260 ' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 6837' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 6807' & TRDP-1A-SSA SSSV ~ 1787' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure I CEIVED Gas Cons. Commisslo~ A~c~ralTe 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf' Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Histgry w/Addendum, dated 5/16/87) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW02/83 Date Submit in Duplicate)~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Accounting cost center code ICounty or Parish Slate Alaska North Slope Borough Lease or Unit ~Well no. ADL 25523 J 3M-10 Irma Completion API 50-029-21715 Field Kuparuk River Auth. or W.O. no. AFE AK2106 Nordic # 1 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 9/6/87 Date and depth Complete record for each day reported as of 8:00 a.m. 9~08~87 I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well our l Prlor status if a W.O. 0900 hrs. I 7" @ 7176' 7084' PBTD, RR 7.0 ppg Diesel Acce?t rig @ 0900 hrs, 9/6/87. Tst 9-5/8" X 7" ann to 1000 psi - ok. Tst 7" csg to 3500 psi - ok. ND tree, NU & tst BOPE. Perf well f/6910'-6942' @ 12 SPF. RU & rn 206 its, 2-7/8", 6.5#, J-55 EUE 8RD AB Mod tbg w/SSSV @ 1787', HRP-1-SP Pkr @ 6807', TT @ 6837'. Set pkr. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/diesel. R_~R @ 0330 hfs, 9/7/87. Old TD New TD Released rig Date 0330 hrs, Classifications (oil, gas, etc.) Oil I PB Depth 9/7/87 JKind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7084' PBTD Rotary Welt no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pumr~ size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abo~,~correct ~-Jz~-~, ~O (' ."2 Drilling Superintendent For forth see Procedures M~m3'~l, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvllion of AtllntlcRIchfleldCompany ADDENDUM WELL: 3M-10 5/11/87 RU CTU, RIH, tag ice bridge @ ±70'. Circ 10# brine, wsh bridges. RIH to 1500', circ until 9-5/8" x 7" ann freed up. Pmp 2bbls methanol @ 180°. POOH to 150', displ w/diesel, RD CTU. RU Hot Oiler & pmp 55 bbls brine & 25 bbls diesl, RD Hot Oiler. Secure well. Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure A~ask..3 0il & Oas Cons. Comm[ss[or~ Anchomrj9 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfi'~ldCompany VICINITY MAP SCALE 1",2MILES NOTES: I. ALL COORDINATES ARE A.$.R, ZONE 4. 2.&L.L DISTANCES SHOWN ARE TRUE. ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. ASPs 'X' 6,202.17 506,t26.'9 ,225.10 ,248.21 506,145.98 16,271.E4 506,155.57 016,294.28 506,165.07 016,317.4~ 6,016,~40.48 6,016,~6~.49 5~,193.52 ,~86.92 506,20~.14 ,456.13 506~52.0Z ,479.22 506,~41.52 6,016,50~.~6 5~,~51.07 6,016,525.51 506,260.~ 6,016,548.62 5~,270.~0 6,016,571.4~ 5~,279.77 6,016,59 4.T~ 5~289.40 6,016,617~9 6~016,~ 1.02 5~08.76 I HE~Y CERTIFY T~TI AM PROPERLY ~GIS~ER~ AND LICENSED TO ~AC- TICE L~D ~RVEYING IN ~E STATE OF ~KA AND T~T THIS PLAT REPRESENTS A ~ATION SURV~ MADE BY ~ ~ UNDER MY S~[RVISI~, AND THAT ALL DIM~SIONS AND O~ER ARE ~REECT ~S OF 5/8/87 LATITUDE $.ELEVATIONS ARE B.RM.$.L. 4.RER FIELD BOOK L87-3, PBL 7-I~; LIT-I, R 7; L87-3,P 51 - 53; $.0.G.ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON SM ~~i';L ['~: '",'.'!: i) MONUMENTS PER LHD & ASSOCIATES. , ~ 1 ~ ~') "; [ ~3'7 LONGITUDE 27'18 149°5 :7'20.0 .7'Z0.2 :7'20.459 20.91 $ 7'2: I .I 149036',5B.$I~ 7'21. ~6~ 149e~ 149056~ 149°56, ~9°56 70o2~ 149°56',56 7~2~ 149°5~ 5S 70°27', 23, I ~ 70°27 23.4 I0 7~27' 23.639 55.21T 70°27'23.868 54.933 Dist. F.N.L. Dist. F.E.L. ~ 1296' t273' 1250: 1227' 1204; Iltl 1158: 1135 IIIZ' 1042', 1019 996', 9?$ 927, 904 88l' 858' 635 ' ,~/Z' / :~4..3 ' 1741 1732 1722 1713 1703 1694 1684 1675 1665 1636 16 26 1617 1607 1598 1586 1578 1569 1559' /7~/' /7/.,~' 23.1' 23.2' 23.$', 25.4 23.4', 23.3 23.2* 23.1' 21.7. 21.5 21.1~ 20.9, 20.9, 20.9 ~:0.8' ARCO Alaska Inc. ,..~d 26.6' 26.6' 26.91 26.8 1:6.B*, 1:6.7 26.6' 26.6* 26.4** 26.5, 26.5 26.4~ 26.3 E6.4~ 26.4, 26.5, 26.5 26.6' Z&.Z ' z r,,, 9 ' D.S. 3M 9th WELL CONDUCTOR AS-BUILT ; CRAIG L. SAVAGE · 4538-S DWN BY: GLL CHK BY: AJR &iRK G_~l~-d2 ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 30, 1987 Transmittal #: 5970 RETURN TO: ARCO Alaska, Inc. Attn: 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. 3M-8 3M-10 3M-7 OH LIS Tape + Listing 4-15-87 OH LIS Tape + Listing 4-5-87 OH'LIS Tape + Listing 3-30-87 ^laska Oil & 6as cons. Comm[ssfor~ Receipt'Acknowledged: DISTRIBUTION: D. Wetherell Date: ARCO Alaska, lnc, is a Subsidiary ol AtlanlicRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Transmittal # 5968 Return to: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-lil9 P.O. Box 100360 Anchorage~ AK 99510-0360 Transmitted herewith are the £oilowing items. Please acknowledge receipt and return one signed copy of this transmittal. OP£N HOLE FINAL PRINTS: 3M-10 2" FDC Porosity 4-5-87 3389-7119 Cyberlook 4-5-8? 3389-7144 5" FDC Porosity 4-5-87 3389-7119 2" FDC Raw Data 4-5-87 3389-7119 5" FDC Raw Data 4-5-87 3389-7119 2" DIL 4-5-B? 3389-714~ 5" DIL 4-5-87 3389-7144 3M-6 2" FDC Porosity 4-21-87 4450-7300 Cyberlook 4-21-87 6900-7280 2" DIL 4-21-87 1000-7326 5" FDC Raw Data 4-21-87 4450-7300 5" FDC Porosity 4-21-87 4450-7300 2" FDC Raw Data 4-21-87 4450-7300 5" DIL 4-21-87 1000-7326 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Rathmell D & M Vault (film) Date: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK...ILL AND GAS CONSERVATION COMM~ .,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing Time extension ~ Change approved program ~ Plugging [] Stimulate I~ Pull tubing ~ Amend order [] Perforate ~ Other l~ ~,'/ 2. Na~ri0fl..of.qper~tor 5. Datum elevation (DF or KB) t~t~t.u ~lasKa, Inc RKB 63' feet 3. A(i[tJ. re ~s' Box 100360 Anchorage, AK 99510-0360 6'uUpnaitr °rK ak Pr...operty~ ver nuanr~et' 4. Location of well at surface 1043' FNL, 163.6' FEL, Sec.25, T13N, R8E, UN At top of productive interval 1313' FNL, 1894' FWL, 5ec.25, T13N, R8E, UM At effective depth 1349' FNL, 1653' FWL, Sec.25, T13N, R8E, UM At total depth 1365' FNL, 1566' FWL, Sec.25, T13N, R8E, UM 11. Present well condition summary Total depth: measured 7222 'MD feet true vertical 6483 'TVD feet (approx.) (approx.) (approx.) Plugs(measured) 7. Well number 3M-10 8. Permit number 87 -35 9. APl number 50_029-21 71 5 10. Pool Ku'paruk River Oil Pool None Effective depth: measured 7084'MD true vertical 6377'TVD Casing Length Size Conductor 80' 16" Surface 3347' 9-5/8" Production 7141 ' 7" feet Junk (measured) feet None Cemented 203 sx CS II 1200 sx CS il I 260 sx Class G 300 sx Class G Measured depth 115'MD 3384'MD 7176'MD True Vertical depth 115'TVD 3384 ' TVD 6447'TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Alaska 0it & Gas Cons. OOI'Ili'P,!SS[OI't Am, hor,~ue 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the for,egoing is true and correct to the best of my knowledge Signed / ?~i'~(., .~/.~,-..(.t~J~J\.v TitleASS°ciate Engineer Date - ' - Commission Use Only (DS) SA2/44 Conditions of approval Notify commission so representative may witness I Approval No. __ [] Plug integrity [] BOP Test [] Location~clearar~l '~,~- Approved by ~ _'~ --~/ ,. {~ '~'~~~ Commi;S~ioner the commission Date /'//~ Form 10-403 Rev 12-1-85 ~' ! / ' Submit~in tril~licate ARCO Oil and Gas Company ~, Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily worl( prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska Kuparuk River County, parish or borough North Slope Borough ILease o_r Unit ADL 25523 ITitle Drill IState Alaska IWell no. 3M-lO Auth. or W.O, no, AFE AK2106 Doyon #9 API 50-029-21715 Operator ARCO Alaska, Inc. Spudded or W.O. begun ARCO w,I. jHour · jPrior status if a W.O. 1130 hrs Spudded Date and depth as of 8:00 a.m. 4/02/87 4/03/87 4/04/87 thru 4/06/87 4/1/87 Complete record for each day reported 56.24% 16" @ 115' 2475', (2360'), Drlg Wt. 9.1, PV 12, YP 13, PH 9.0, WL 11, Sol 6 Accept ri$ @ 0900 hfs, 4/1/87. NU diverter sys. Spud well @ 1130 hrs, 4/1/87. Drl to 2475'. 502', .1°, S37.1W, 502.00 TVD, .31 VS, - .35, -.26 1514', .1°, S7.9°E, 1514.00 TVD, .07 VS, - .06, -.07 1987', 1.1°, S7.3E, 1986.97 TVD, .17 VS, -4.91, .59 9-5/8" @ 3384' 3405', (930'), Tst BOPE Wt. 9.3, PV 15, YP 14, PH 9.0, WL 9.0, Sol 7 Drl to 3405', CBU, short trip, C&C, POH. RU & rn 86 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 3301', FS @ 3384'. Cmt w/1200 sx CS III & 260 sx C1 "G". Displ using rig pmp, bump plug. Tst csg to 2000 psi. ND diverter. NU & tst BOPE. 2517', .5°, N49.3E, 2516.92 TVD, - 6.25 VS, -7.56, 7.50 2989', .8°, N50.1E, 2988.89 TVD, -10.81VS, -4.10, 11.58 3355', .4°, N28.8E, 3354.87 TVD, -13.67 VS, -1.14, 14.02 9-5/8" @ 3384' 7222', (3817'), Prep to rn 7" Wt. 10.0, PV 14, YP 7, PH 8.5, WL 4.8, Sol 12 RIH, DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 7152', short trip, CBU, POH. RU Schl, rnOHL, RD Schl. RIH, drl to 7222', POH, LD DP. 3423', .3°, 3802', 12.5°, 4369', 36.1°, 4747', 41.2°, 5248', 41.8°, 6665', 40.2°, 7152', 39.1°, N 0.3E, 3422.87 TVD, - 13.83 S88.3W, 3799.85 TVD, 16.23 S80.0W, 4308.69 TVD, 256.29 S82.6W, 4600.85 TVD, 495.97 S82.0W, 4976.08 TVD, 827.88 S78.9W, 6053.67 TVD, 1747.48 S79.5W, 6428.64 TVD, 2058.04 VS, .74S, 14.12E VS, 4.72N, 17.13W VS, 7.47S, 258.15W VS, 42.63S, 495.23W VS, 87.11S, 824.23W VS, 255.83S,1728.68W VS, 314.06S,2033.93W The above is correct Signature ~::~,~, For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowabte 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 lor reporting the entire operation if space is available. J Accounting District ICounty or Parish 1 Slate Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25523 Auth. or W,O, no. ~Title AFE AK2106 I Drill Doyon 9 API 50-029-21715 Operator A.R.Co. W.I. rTotal number of wells (active or inactive) on this, Icost center prior to plugging and A~CO A'laska, Thc. 56.24~ labandonment of this well Spudded or W,O. begun Date IHour I Prlor status if a W.O, Spudded 4/1/87 ~ 1130 hrs I cost center code Alaska Well no. 3M-10 Date and depth as of 8:00 a.m. 4/07/87 Complete record for each day reported 7" @ 7176' 7222', (0'), Rig Released Wt. 10.0 ppg Brine POH, LDDP. Run 166 Jts 26# J-55 BTC csg. FS @ 7176', FC @ 7084'. Cmt w/100 sxs 'G' w/2% A-2, 1% R-7 & 200 sxs 'G' w/l% FL 19, 0.5% CD-31 & 0.3% A2. Displace w/269 bbls 10.0 ppg brine. CIP @ 16.28 hrs 4/6/87. Test csg to 3500 psi. OK. Floats OK. ND BOP, set slip. Install pack off, test to 3000 psi. Release Rig @ 2000 hrs 4/6/87. Alaska Old TD New TD PB Depth Released rig Date Kind of rig 2000 hrs. Classifications (oil, gas,- etc.) O-tl Producing method Flowing Potential test data 4/6/87 Type completion (single, dual, etc.) Single IOfficial reserve'ir name(s) Kuparuk Sands Rotary Well no. ~Date Reservoir Producing 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 Signature ' For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. r-'o.~t Office Box 100360 Anchorage, Alaska 99510-0360 lelephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton' Enclosed is an as-built location'plat for the subject wells. If you have any questions, pleaSe call me at 263-4944. Sincerely, ;]. Gruber Associate Engineer JG/db GRU1/31 Enclosure RECEIVED MAR 0il & Gas [;ons,. Commission Alaska, Inc, is a Subsidiary of AllanlictlichfiehtCom[;,'my ALL WELLS LOCATED IN SEC.;:)5, TISN, R8~E~, ~A,I~ERIDIAN. ASPs 'X' 4,016,202.17 6,016,225. I0 6,016,248.21 6~016,271 · 24 6,016,294.28 6,016,:517.42 6,016 ,:540.48 6,016 6,016,:586.92 6,016,456.15 6,016,479.22 ,016,502.26 ,016,525.51 6,016,548.62 6,016,571.4:5 6,016,594.75 6,016,6 I 7.99 6,016,641 506,126.~J9 506,156.45 506,145.98 506,155.57 506,165.07 506,174.6:5 506,184.1:5 506,19:5.52 506,205.14 506,232.02 506,241.52 506,25 i.07 506,260.73 506,270.30 506,279.77 506,289.40 506,299.05 5 06,308.76 LATITUDE 7~27't g.TeO" 70° 27'20.005 70°27'20.2:~2 70°27' 20.459 70°27' 20.685 70°27' 20.9 ! :5 70°27'21.14C 70°27'2 I. ~66 7~27 22.5~ ~oo=~',zz.~o',', 7~27 22.959 70o27'23,1 70°27'2~.4 I0" 70°27' 2~.639" 70o27'2~.868'' 7~ 27'24.094" ?_4 19 25 30 [, _ OLIKTOK RT. ~ LAGOON -,. ~SURV~ ' %UI r VICINITY MAP SCALE 1"=2MILES NOTES: I. ALL COORDINATES ARE A.S.P., ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. 3.ELEVATIONS ARE B.P.M.S.L. 4.REF. FIELDBOOK LST-$,Pg$.7-17.; L87-1,RT;LST-3,PSI-53; 5.0.G. ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON 3M CONTROL MONUMENTS PER LHD & ASSOCIATES. LONGITUDE Dist. FN.L. Dist. FE.L. O,6,Elev. Pod Elev. 149°57'00.OOO'' 1296' 149°56' 59.720" 1273' 149°56159.459 12501 149<)56 59.157 1227 149056' 58.877 1204' 149°56' 58.596 I 181 ' 149°56'58.$ lG~J Il Ii 58' 149°56' 58.040'] 149°56' 57.756"1 II I?.' o ' 69 " ,49 56,5 . o~'.:1 ,o~2: ,,~o~6 ~.~-~ ,o,~ 149° 56',56.345~,~ 996', 149°56 56D6 I'1 973 149° 56'55 779" 950' 149 56 55.217 904' 149056'54.935" 881 ' 149°56'54.647'' 8 58' 1741' 1722', 1713 1703°, 1694 1684' 1675' 1665', 1636, 16 26 1617' 1607' 1598' 1586' 1578' 1569' 1559' 25.1' 23.2' 23,$', 25.4 2~:I', [3.0', 1.7, 2t.5 11.4' 2' 21.1' 20.9' 20.9' 20.9' 20.8' 26.6' 26.6' 26. 26.8', 26.7 6o6' 6.6' 26.4' 5' 26'5, 26. 26.4~ 26.3 26.4' 26.4: 26.5, 26.5 26.6' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MAD[ BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/87 ARCO Alosko Inc. D.S. 3M WELL CONDUCTOR AS-BUILT DW. ~¥: 0L. CH~ ~Y: %. DATE: :5/8/87 NSKG',3i3-d2 March 31, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360~ Anchorage, Alaska 99510-0360 Telecopy.. (907) 276-7542 Re: Kuparuk River Unit 3M-10 ARCO Alaska, Inc. Permit No. 87-35 Sur. Loc. 1043'FNL, 1636'FEL, Sec. 25, T13N, RSE, UM. Btmhole'Loc. 1348'FNL, 1668'F~,fL, Sec. 25, T13N, R8E, L~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation' so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ t r~~~ur s ,~ ~ C. Vi ChatCe~toh Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ~-" STATE OF ALASKA "~- ALASKA O~ AND GAS CONSERVATION CON. .,ISSION PERMIT TO DRILL 20 AAC 25.0O5 I la. Type of work Drill [~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development O,1 Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone F~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 63' PAD 27' ' , feet Kuparuk River Field p3 Address 6. Property Designation Kuparuk River 0il Poo ~0. Box 100360 Anchorage, AK 99510-0360 ADL 25523 ALK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 104_~'FNL, 1636'FEL, 5ec.25, T13N, R8E, UM Kuparuk River Unit Statewide 3At, top of productive interval 8. Well nu ,mber Number 131 FNL, 1894'FWL, Sec.25, T13N, R8E, UM 3H-10 #8088-26-27 At total depth 9. Approximate spud date Amount 1348'FNL, 1668'FWL, Sec.25, T13N, R8E, UM '~2~,~-g~-¢'8"7" ~/'~///~"? $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property' 15. Proposed depth(MD and TVD property line 3M-7 71 30 'MD 1042'~ Surface feet 125' ~ Surface feet 2560 (6420'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth3500 feet Maximum hole angle 43 '8 Maximum surface 1 994 psig At total depth (TVD) 3 065 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 12-1/4 9-5/8" 36.0# J-55 BTC 3333' 35' 35' 3368' 3368' 875 sx AS I I I & HF-EI',W 260 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC "70C)~' 34' 34' 7130' 6420' 200 sx Class G(minimurf HF-EI;~W T0C 500' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production "'~ .i i'i.';; ¢ Liner Perforation depth: measured : ::;::,:c..-, L;h ,'~. '. .... :/:.:::;;. 6 , true vertical /:~i~:;;~u~ 20. Attachments Filing fee ~ Property plat [] BOP Sketch J~ Diverter Sketch I~ Drilling program ~ Drilling fluid pr~ ~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby cc/eftify t at the forego' i tr and correct to the best of my knowledge Signed ; ,,,¢," ,..,f.¢~,. / Title Regional Drilling Engineer gate~ .¢/~"'*¢~E/'/'r .... '7 % ' ¢~- Commission Use Only (JFB) PD2/11 Perm it N u.m'ber,~ ?- .3,~I APl number I Approve, date I See cover letter 50--O~)-.~.-%t 7 ~" 5- ~1 -~"7 for other requirements Conditions of approval Samples required [] Yes ~L, No Mud Icg required Lq Yes ,~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~Yes [] No Required ~¢ P,,~~_ .,L~/~i~J,~y ; Other: working pr for PE ; ~ ; [] 5M [] 10M; [] 15M -. by order of ~...~ ( ~~.~ Commissioner the commission Date Approved by ,.. ,. Form 10-401 Rev. 12-1-85 in triplicate . . . · , · · I I KUPARUK RIVER UNIT :20' D IVERTER SCHEMATIC DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS S. 1 O" HCR BALL VALVES W/1 O' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSi ANNULAR PREVENTER ARCO ALASKA, INC., RE(~UESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROH 20AAC25.03S(b) MAINTENANCE & OP[,RATION I I 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLONd AIR THROUGH DIVERTER LINES EVERY 12 HOURS. .3, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE, FLUIDs OR GAS IS DETECTED, OPEN APPROPRIATE VALUE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY C ! RCUMST ANCE S JG 11-~-86 ~r h 4 3 2 - DIAGRAM #1 J3-5/8'. 5C03 PSI RSRRA BCP STACK I. 16" - 2000 PSI TAN(CO S'rARTIM3 HEAD 2. II · - ~(XX) PSI CA$IN~ ~EAD 3. II" - 3(X)O PS] X 13-.5/8" - ~ P~Z SPACER SPO~L 4. 13--5/8" - 5000 PSI PIPE RNVlB 5. 13'-5/8" - 5000 PSI CRIll ING 6P(:~L N/~ AN3 Kill LI~ G. 13'-5/6" - ~ PSI [XXJSLE RAM W/PIPE RAMB CN TCP '7. 13'-5/6" - 5000 PSI AI~LLAR A~TC~ CAPACZTY TEST I. Q-ECl( At~ FILL N333aJ. ATGR REEtERVOZR TO ~ LEVEL WITH HYI:RN~]C FLUID. 2, AS~tJRE THAT N::CLM. A.ATCR ~ IS ~ PSI WZlt 3. ~ T]]~E. 'rl-EN CLOSE ALL tedIT8 SIM.LT~~ ALL LI~TS ~ CI..OS[~ WITH ~INO PkJ~ CFF. 4. RECC:I~ ~ N~DC RE]3(3RT, THE ACCEPTABLE LCWE~ LIMT IS 45 E;E~ CLClSlNO TZb[ AN3 1200 PSI RtgiIAININ[ le 0 . Se 1 12. 13-5/8" BCP STACK TEST FILL B(:P STACX AN:) C:HC:KE MN~IF~ WITH ARCTIC DIF. SELo C~EQ( THAT ALL LOCI( ~ SCRE~ IN ~ ARE FLLLY RETRACTED. SEAT TEb~ PLUG IN ~8.LJ-EAD WITH RULING JT AN) RM~ IN L(X]<I:X:I~ LI~E VALVES ADJAQg~ TO ~ 8TAC~ ALL ~ LP TO 250 PSI ~ HeLD FC~ I0 MIN. IN-- ~ ~ TO 3000 PSI A/~ H~LD FCR I0 MIN. BLEED ~ TO 0 PSI. LI~E VALVES. CLCJSE__ TC~ PIPE ~ AN3 HC~ VALVES Clq KILL ~ (]-t(]<E LII~:S. TEST TO 250 PSI A]~) 3000 PSI A8 IN STEP 4. CCNTI~ TESTING ALL VALVES. LII~:So AN:) WITH A 250 PSI LC~ AI~ _3riO0__ I:~I HIGH. TEST AS IN NOT A FULL CLOSIN~ POSITIVE SEAL Q.K]<E, CN.Y ~ICN TEST Q-K]~$ THAT DO ~ FLLLY CLOSE. CPEN TCP PIPE RAMS At~ CLOSE BOTTC]~I PIPE RNv~. TEST BOTTCM PIPE RAMB TO 250 PSI AN:) 3C03 PSI. CLOSE BLIP) RAt~ AN3 TEST TO 250 PSI A~D PSI. MANIFCLD AN) LI~E$ ARE FULL OF ~ING FLUID. SET ALL VALVES IN gRILLING POSITICI~L TEST STAN:~IPE VALVES° KELLY,. KELLY CCX]<So [;RILL PIPE SAFETY VALVE, A~) INSIDE 8433 TO 250 PSI AN3 3OO0 PSI. RECCI~ TEST It~C~TIC~ CN BL~ R~m/ENTI~ TEST ~(3~o SIGN.: ~A~D~:. ~ TO C~ILLING SUPS~ISCR. P8~ C3]~R. ETE~8(]:~ TEST AFTER NIPPLING ~Y ~ER ~IClqALLY CI~5~RTE BCPE DAILY 510084001 REV. MAY 15, 198 · Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 ~eight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. There are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. ~ The annulus will be sealed with 175 sx of cement followed by ~arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCgDURF- KUPARUK RIVER FIELD D EVELOPItENT lqELLS I. Movs-~ in rig. 2. Ins. tail Tankco diverter system. 3. Drill 12~" hole to 9-5/8" surface casing point according co directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing co 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8%" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plus back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psis. 11. Dovnsqueeze Azctic Pack and ce~n~ la 7" x 9-5/8" a~ulus. 12. Nipple d~ blow ou~ p~eventer and install ce~ora~ ~a erie. 13. Secure ~11 and release rii. 14. ~n ~aed hole logs. 1~. Hove ~ wor~ver ~i~. Nipple up bl~ out preventer. 16. Pick up 7" casin~ scraper ~d tubing, trip in hole to plu~ back total depth. Circulitt hol~ ~th clean brine and trip out of hole sc~d~ C~in~ back. 17. Perforate ~d ~n co~leciou asse~ly~ set ~d test pacer. 18. Nipple do~ bl~ ouc preventer and install ~ tree. 19. OMnis over Co diesel. 20. Flw yell to ca~s. ShuC 21. Secure yell and release 22. Fracture sC~laCe. SHALE _ SHAKERS STIR ~.-w, STIR _ *w. STIR ? ..... ..... TYPICAL HUD SYSTEH SCHEHATIC LWK4/ih CHECK LIST FOR NEW WCr z. PERMITS (1) Fee (2) Loc ,, (2 thru 8) (3) Admin (9 thru 13) (10 and (4) Casg (14 ~ 22) "' (5) BOPE ~..~.~/. 3-.2'7o~ 7' ~23 thru 28) Company 1. Is the permit fee attached .......................................... Lease & Well No. YES NO 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 ..... ~ "' 51 Is sufficient undedicated acreage available in ~ ~i'~. ~. ~.. ~11~~ ',',' 6~ Is well to be deviated and is wellbore plat included Is operator the only affected party ....................... Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number .......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ IS old wellbore aban~t procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ (6) OTHER (~ thru 31) (6) Add: e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 26. 27. 28. Is a diverter system required .......................... - ............. Is the drilling fluid program sch~tic and list of equipnmmt adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ,~o psig .. Does the choke nmnifold comply w/API RP-53 fMay 84) .................. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... If an offshore loc., are survey results of seabed conditions {:):~;~l~:;d '"'"'~,~ 32. Additional requirements ............................................. Geology: Enginee~ring: rev: 01/28/87 6.011 INITLAL GEO. UNIT 3N/OFF POOL CLASS STATUS AREA NO. SHORE Yqo u I-OIL f I 16o 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. LIS VERIFiC~TIDN LiSTinG LVP OlO.H02 VERIFICATION LISTING PAGE i SRRVlCE N~MF-_ :ED~'~.T O,,,% T E :~7/04/I1 ORIGIN : RE~L N~ME :72261 CGNTINUA'TION ~ :01 PREVIOUS RE~L : C~MM~NTS :LiS TAPE, ARCO KUPaRUK 3M-lO~ APi 50-029-21715 ~:~ TAPE, . HEAD~R_ , ~:~'" SERVICE NAME :EDIT DATE :87/04/I1 ORIGIN :F$1A TAPE NAME : CONTiNUATiON # :01 PREVIOUS TAPE : COMMENTS :LIS TAP~ ARGO KUP~RUK 3M--10~ -..,. FILE HzaDER "'~' FILE N~,ME :EDIT .00t SERVICE N,~ME : VERSION m : ~TE : RAXIMUM LENGTH : ~024 ~ILE TYPE : PR~V'I~U$ FiL~ : iNFORMATION RECORDS MNEM CONTENTS CN : WN : FN : ~&NG: TOWN: SECT: COUN: STAT: ~RCO ALASKa~ INC. 3M-lO KUP~RUK T13N NORTH SLOP2 ~L~SK~ CONTENTS PRES: E UNIT TYP~5 CATE SIZE COGE 000 000 0i7 000 000 008 000 000 008 055 000 000 003 000 000 00~ 0~5 000 000 003 085 000 OOO 012 055 000 O00 005 0~5 UNIT TYPE C~TE SiZE COOE 000 COO OOl 365 VP OiO.HOI VSRIFIC~T'ISN LIS%iNG P~GE 2 ~.: ~LASK.~ COMPUT~ , ~NG CENTER COMPANY : ARCU ALASK~ iNC. WELL = 3~q-10 ~IELD = KUPARUK COUNTY = NORTH SLOPE ~OROUGH STATE = ALASKA JC3 NUMBER AT ACC: 72261 RUN ~1, DATE :LOGGED: 5 A~R 8'7 LOP: JIM KOHRZNG CASING = 9.525" 2- 3385' - BlT SiZ~ : 8.5" TC 7153" TYPE FL:diD : LSND-FOLYF~ER DENSITY : I0.0 L~/G ~H : 4.05 VISCOSITY : 37.0 S RMF : 3.,35 PH : ~ 5 · ~MC : 3,~8 ,~ 72 DF FLUID LOSS = &.6 C3 RM AT ~mT = 2.11 ;'qATR! X SANOSTCN5 -,--,--.--,--.- THIS .DATa HAS NOT 85~N~ D~PTH_ SH'IFT~D. - ~VERLAYS FIELD LVP OIO.H02 VERIFiCaTION LISTING ~GE 3 * SCHLUMSERGER LCGS INCLUgEO WITH ~THIS H~GN~T'''~ z~ T~PE: v~ ~'x= DU~L iNDUCTZON SFHERiC~LLY FOCUSED LOG (DIL) ~ =,~ DATA AV~ZLABLE: 7160' TO 337~' X~. ~',~ GAMMA RA~ IN C~S~NG (GR) x: -,- DATA ~VAILABLEI- 3401 T~ 1693 ~' "' DORM~TI~N DENSITY C~MPENq,~TED LOG (FDN) :'~: -~ DATA AVAILABLE'. 7160' TC 6=51' ..'~ ~;~ AND 5410' TO 5285' '4: ',' AN~ 4310' TO 4153' "~ '-~ ~.N~ 3:510' TO 3377' $ -,-~. DaTA FORM6T RECORD -,.~. ENTRY BLOCKS TYP~ SIZE REPR C~DE ~N'TRY i 1 66 0 4 1 66 t B 4 73 50 9 4 65 .lin 16 1 66 LVm 010.H02 VERIFiCATZSN LISTING F~GE 4 DATUM SPECIFICATION 8LOCKS MNEM SERVICE SERVICE UNIT 4PZ API IO CRDER # LOG TYPE CLCSS DERT PT O0 000 O0 SFLU D!L OHMM O0 220 Ol iLO OIL OdMM O0 lZO 46 !LM OIL OHMs! O0 1ZO 44 SP OiL NV O0 010 O1 GR DIL OARi O0 310 GR FON GAFf O0 310 Ol CALl FON IN O0 280 RHOB FON 6/63 O0 330 02 DRHO FDN G/C3 O0 356 01 NRAT FON O0 420 01 RNRA FDN O0 000 O0 NPHI FDN PU O0 890 O0 OPHI FDN PU O0 890 O0 NCNL FON CPS O0 330 3I :CNL FDN CPS ~* , ~0 ~30 30 gR CNL GAFi O0 310 01 DEPT 7150.0000 SFLU 4.5532 SP -19.4531 GR 97.12S0 RH05 2.4551 ORhg 0.0269 NPHI 37.5488 g~Hi 11.8135 GR -999.2500 DEPT 7100.0000 SFLU 3,2336 SP -20.8750 GR 94.5000 RHOB 2.4551 DRHO 0.0186 NPHI 39.1113 DRHI 11.3135 GR -999.2500 DSPT 7000.0000 SFLU 4.5463 SP -23.5625 GR 96.1250 Rags 2.4160 OR~C 0.0210 NPHi ~1.6504 DFHi 14.1809 3R -999.2500 DF:PT 6900.0000 S¢-LU 0.5013 SP -31. 1250 GR 86. 1875 ~HC~ Z.7207 ORHO -0.0146 NPHi 35.6887 O?Hi -4.2850 GR - 999. Z 500 DEPT 6800.0000 SFLU 2.0917 SP -21.3594 GR 111.8750 ~CB 2.30~6 DRHC 0,002~ NPHI 47.7051 DPHi 20.5913 Sq -999.2500 ~ P I MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ILD NRAT NCNL iLrJ NRAT NCNL iLO GR NRAT NCNL IL,* NR~T NCNL ILO NR & T NCNL FILE N 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ZE SPL 3.4221 97.1250 3.2051 2004.0000 2.7725 94.5000 3.2971 2035.0000 3.399~ 95.1250 3.4043 1905.0000 7.7388 36.1875 3.0996 2330.0000 1.6991 1!1.:~3750 3.7773 16OO.OOCO REPR PROCESS CODE (OCTAL) 68 O000000000OO00 68 O0000000000OO0 68 00000000000000 68 00000000000000 68 O0000000OO00OO 68 00000000000000 1 i i I 1 1 I 68 O0000000000CO0 ! 68 00000000000000 1 68 00000000000000 I 68 00,000000000000 1 68 OOOO000000000O I 68 00000000000000 I 68 O00OO000000000 I 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ILM 4.1758 CALl 8.6712 RNRA 3.4043 FCNL 588.5000 ILM 2,8306 CALl 8.6484 RNRA 3,5020 FCNL 58!.0000 ILM 3.4930 C~LI 8..3672 RNRA 3.5742 FCNL 533.0000 iLM 6.9329 CALl 8.4844 RNRA 3.1699 ¢CNL 735.0000 ILm 1.7785 C~Li 8.8984 RNR$ 3.8516 FCNL ~!5.2500 LVP OIO.H02 VER!FiC~'TICN LISTING PAGE 5 SP RHO5 NPHI GR SP RHDB NPHI GR NPH i DEPT SP RHO5 NPHI G~ OEPT SP DEPT SP NPHI GR DeFT SP NPHZ DEPT SP NPHi SP NPHi GR 6700.0000 SFLU -29,0313 GR 2,3633 DRH2 45,1~25 DPHi -999.2500 6600.0000 SFLU -27,6405 GR -999,2500 DRHO -999.2500 DPHi -999.2500 6500,0000 SPLU -22,3438 GR -999,2500 DRHO -999,2500 DPMi -999,2500 6400,0000 SFLU -34,7813 GR -999,2500 DRHO -999,2~00.~ DPHi -999.2500 $300,0000 S~LU -35,0938 GR -999,2500 DRHO -999,2500 OPHi -999.2500 6200,0000 SFLU -40,8437 GR -999,2500 DRHO -999.2500 D~H:I -999,2500 8100o0000 SFLO -33.8123 GR -999.2500 DRdO -999.2500 GPHi -999,2500 6000,0000 SFLU -43,1250 GR -999,2500 DR.eS -999,2 300 CPMI -999.2500 3900.0000 SFLU -43.5625 OR -999,2500 ZRHG -999,2500 DShI -999.2500 3,4133 iLD 111,6250 GR 0.0239 NRAT i7.3769 NCNL 4,7835 ILD 147,0000 GR -999,2500 NRAT -999,2500 NCNL 4,6564 ILO 229,0000 GR -999.2500 NR&T -999,2500 NCNL 4,7720 ILD 130,6250 GR -999,2500 NRAT -999,2500 NCNL 4,6025 ILO 108.5000 . GR -999.2500 NR~T -999,2500 NCNL 5,1785 ILO 108,8125 GR -999,2500 NRAT -999,2500 NCNL 2,6253 iLO 122.2500 GR -999.2500 NR~T -999,2500 NCNL 4.7116 iLD 94.0000 GR -999.2300 NRAT -999.2500 NCNL 4.1707 ILD 97.9375 GR -999.2500 NR~T -959.2500 NCNL 2.3354 111.6250 3.6992 1733.0000 3.4412 -999.2300 -999.2500 3,5058 -999,2500 -999,2500 -999,2500 4.0272 -9~9.2300 -999.2300 -999.2500 4.3558 -999.2500 -999.2500 -999.2500 4.5351 -999.2500 -999.2500 -~99.2500 2.4556 -999.2500 -999.2500 -999.2500 4.3472 -999.2500 -999.2500 -999.25C0 4.1~6 -9'~9.2500 -999.2500 -999.2500 ILM CALl RNRA FCNL iLM CALI RNR~ FCNL ILM C~L,i RNRA FCNL ILM C~LI RNR~ FCNL ILM CALI RNR~ FCNL ILM CALi RNRA ;CNL iLM C.aLI RNRA FCNL ILM CALI RNR& FCNL iLM C AL I RNRA FCNL 2.4215 8.9609 3.9375 440,0000 3.5398 -999.2500 -999.2500 -999.2500 3,6088 -999.2500 -999.2500 -999.Z500 4.1006 -999.2500 -999.2500 -999.2500 4.4876 -999.2500 -999.2500 -999.2500 4.6191 -999.2500 -999.2500 -999.2500 2,5042 -999,2500 -999,2500 -999,2500 4.3616 -999.2500 -999.2500 -999.2500 4.1417 -'999.2500 -999.2500 -999.2500 LVP OlO,H02 VERiFIC_AT!ON LISTING DEPT SP NPHZ GR SP NPHI GR DEPT SP RHOB NP H l GR DEPT SP GR DEPT S? RH08 NPHI GR DEPT SP RHO8 NPHi GR ~S E P T NPHI GR DEPT SP NPHI GR DEPT SP NPHI 5~00.0000 SFLU -59,8125 GR -999,2500 DRHO -999,2500 DPHI -999,2500 5700,0000 SFLU -43,3125 JR -999,2500 DRHO -999,2500 DPHI -999,2500 5600,0000 SFLU -45,2813 GR -999,2500 ORHO -999,2500 DPHI -999.2500 5500,0000 SFLU -45,0935 GR -999,2500 DRHO -999,2500 DPHI -999.,2500 5~00,0000 SFLU -40,0625 GR 2,3379 DRHO 35,1074 DPHI -999.2500 5300,0000 SFLU -48,1250 GR 2,3750 D~HO 40,2632 DP~i -999.2500 5200,0000 SFLU -51,3435 d~ -999.2500 ORMG -999.2500 n ~PHI -999.2500 5100.0000 SFLU -43.8125 GR -999.2500 DR~C -999.2500 DPHI -999.2500 5000,0000 SFLU -53,0625 SR -999,2500 DRHO -999,2500 CP~I -999.2500 5.8842 ILD 78,3750 GR -999.2500 NRAT -999.2500 NCNL 4'0107 !LD 26,5625 GR -999,2500 NRaT -999,2500 NCNL 3.9892 ILO 105.5000 GR -999.2500 NRAT -999.2500 NCNL 3.6994 iLD 105,9375 GR -999,2500 NRAT -999,2500 NCNL 3,2872 iLD 90,2500 GR -0,0059 NRAT 18,9157 NCNL 3,5265 ILD 104,3125 GR 0,0083 NR~'T 16.6657 NCNL 4.18=4. iLn~. 101,3125 GR -999,2500 NRAT -999,2500 NCNL 3.6474 iLD 111.1875 GR -999.2500 NRAT -999.2500 NCNL 3.8131 iLr~ 107,1875 GQ -999,2500 NR~T -999,2500 NCNL 3.8454 -999.2:500 -99~.2500 -999.2500 4.1309 -999,2500 -999,2500 -999.2500 4.2635 -999.2500 -999.2500 -999.2.500 3.7277 -999.2500 -999.2500 -999.2500 3,1761 93,5525 3,1602 1897,0000 5607 . 1;00,8750 3,~570 1866.0000 4.0704 -999.2500 -999.2500 -999.2500 3.3120 -999.2500 -999.2500 -999.2500 3.7902 -999.2500 -99~,2500 -999.2500 iLM CALi RNR:~ FCNL ILM CALI RNR A FCNL ILM CALi RNRA FCNL ILM CALI RNRA FCNL ILM C~Li RNRA FCNL ILM CALI RNR~ FCNL LM C/~LI RNRA FCNL iLM CALI RNRA FCNL iLM C&LI RNRA FCNL 4.16~9 -999.2500 -999.2500 -999.2500 4.1556 -999.2500 -999.2500 -999.2500 4,2537 -999.2500 -999,2500 -999,2500 3.6'732 -999.2500 -999.2500 -999.2500 3.2189 9,7500 3.6094 525,5000 3,5522 9,9062 3.8164 488,7500 4.0426 -999.2500 -999.2500 -999.2500 3.3005 -999.2500 -999,2500 -999.2500 3.7349 -999.2500 -999.2500 -999.2500 LVP 010.H02 VERIFICATION LISTING PAGE DiEPT ~900.0000 SFLU SP -43.5313 GR RHO~ -999.2500 DRMO NPHi -999.2500 OPHi GR -999.2500 OEPT 4800.0000 SFLU SP -50.8125 GR RH06 -999.2500 NRHI -999.2500 OPH! GR -999.2500 DEPT 4700.0000 SFLU SP -:53.8125 GR RH03 -999.2500 DRHO N~HI -9'99.2500 DPHI GR -999.2500 OEPT 4600.0000 SFLU SP -45.0625 GR RHOB -999.2500 DRHD NPHI -999.2500 DPHi GR -999.2500 OEPT 4500.0000 SFLU SP -45.8437 GR RHOB -999.2500 DRH~ NPNI -999.2500 OPHI GR -999.2500 DEPT 4400.0000 SFLU SP -50.8125 GR RHGS -!999.1500 CRH~ NPHI -999.2500 OPHI GR -999.2500 J;PT 4300.000C SFLU SP -50.8750 GR RH05 2.2754 DRffO NPHi 45.0195 OPH.I GR -999.2500 9EPT 4200.0000 SFLU S? -58.8125 GR RNC5 2.2578 DRHS NP~i 35.2539 DPHi GR -999.2500 DEPT 4100.0000 SFLU S° -55.093~ GR ~08 -999.2500 ORH6 NPHI -999.2500 UPHI G~ -99'9.2500 2.6126 ILO 92.8125 GR -:999. 2500 NRAT -999. 2500 NCNL 3.4893 ILO 116.0000 GR -999.2500 NRAT -999.2500 NCNL 4.3632 iLD 132.5000 GR -999.2500 NRAT -999.2500 NCNL 2.2096 91.2500 GR -999.2500 NRAT -999.2500 NCNL 2.7513 IL9 78.5000 GR -999.2500 NR4'T -999.2500 NCNL 3.9866 ILD 1i5.8750 GR -999.2500 NRAT -999.2500 NCNL 3.2495 ILO 96.5000 GR -0.0127 NRAT 22.7036 NCNL 5.3844 iLO 89.6875 GR 0.0156 NRAT 23. 7589 NCNL 3.3900 iLg 93.7500 GR -999.£500 NRAT -999.2500 h!CNL 2.384~ -999.2500 '-999.2500 -999.2500 3.1184 -99:9.2500 -999.2500 - 999.2 500 3.7149 -999.2500 -999.2500 -999.2500 2.2051 -999.2500 -999.2500 -999.2500 2.7653 -999.2500 -999.2500 -999.2500 4.0723 -999.2500 -999.2500 -999.2500 3.4473 100.1250 3.5605 1819.0000 5.5315 87.6875 1~34.0000 3.5055 -999.2500 -999.2500 -999.2500 ILM C~Li RNRA FCNL ILM C A L 'I RNRA FC NL ILM CALI RNRA FCNL ILM CALI R NR ~,~ FCNL ILM C~LI RNRA FCNL CALi RNRA FCNL ILM C~Li RNRA FCNL iLM CALl RNR A FCNL !LM CALl RNR~ FCNL 2.3515 -999.2500 -999.2500 -999.2500 3.0577 -999.2500 -999.2500 -999.2500 3.6829 -999.2500 -999.2500 -999.2500 2.1629 -999.2500 -999.2500 -999.2500 2.7307 -999.2500 -999.2500 -999.2500 3. :9426 -9'99.2500 -999.2500 -999.2500 3.3104 3.9355 4.9496 8.2556 3.3281 581.0000 3.4040 -99~.2500 -999.2500 -'999.2500 LVP OlO.H02 V~RIFICAT'iON LiSTIN~ P.aG~ 8 SP NPHI GR D~PT SP NPHI DEPT SP RHOB NPHi GR DEP'T SP NPHI GR u, EPT SP NPHZ 9~PT SP NPMI GR DEPT SP eH08 NPHi GR OEPT SP DEPT SP NPHi GR 4000.0000 SFLU -55.5938 GR -999.2500 DRH2 -999.2500 DPHi -999.2500 .3900.0000 SFLU -27,7344 GR -999.2500 ~RH~ '-999.2500 DPHI -999.2500 3500.0000 SFLU -28.0000 GR -999.2500 DRHg -999.2500 DPHI -999.2500 3'700.0000 SFLU -28.7959 gR -999.2500 DRHS -999.2500 OPHI -999.2500 3600.0000 SFLU -30.7656 GR -'999.2500 DRH8 -999.2500 OPHI -999.2500 3500.0000 SFLU -36.0313 GR 1.9873 ORHO 65.4297 ~PHI -999.2500 3400.0000 SFLU -39.5313 GR 1.7295 D.RHC 49.5605 DPHi 75.7500 3300.000C SFLU -999.2500 G2 -999.2500 DRm3 -999.2500 DPHI 52.4375 3200.0000 SFLU -999.2500 GR -999.2500 ORmO -999.2500 DPHI 5~.15c2 3.2006 ILD 99.8750 GR -999.2500 NRAT -999.2500 NCNL 3.3538 ILD 82.1250 GR -9!29. 2500 NRAT -999. 2500 NCNL 3.6164 Itg 90.312 5, GR -999. 2500 NRAT -999.2500 NCNL 4.7*92 ILO 89.7500 GR -999.2500 NRAT -999.2500 NCNL 1.5702 ILO 99.6875 GR -999.2500 NRAT -999.2500 NCNL 2.7809 ILD 85.3750 GR 0.0569 NRAT ~0.1634 NCNL 3.7864 iLO 76.6250 GR 0.0498 NRA'T 55.7884 NCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -~99.2500 NCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -9~9.Z500 NCNL '3.2930 -999.2500 -999.2500 -999.25C0 3.4817 -999.2500 -999.2500 -999.2500 3.7010 -999.2500 -999.2500 -999.2500 4.8033 -999.2500 -9'99.2500 -999.2500 1.3943 -999.2500 -999.2500 -999.2500 3.4865 94.0625 4.9062 1478.0000 4.4373 78.0000 4.1367 1244.0000 -999.2500 -999.25~0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.Z500 ILM CALl RNR~ FCNL iLM C~L! RNR4 FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNR:a FCNL ILM C~LI RNR4 FCNL iLM CALI RNR~ FCNL ILM CALl RNRA FCNL C~Li RNRA FCNL 3.1412 -999.2500 -999.2500 -999.2500 ~.33'73 -999.2500 -999.2500 -999.2500 3.5602 -99'9.2~00 -999.2500 -999.2500 4.5258 -999.2500' -999.2500 -999.2500 1.4756 -999.2500 -999.2500 -999.2500 3.1527 11.2187 4.63~'? 318.7500 e.ooo6 14.9531 4.6758 266.0000 -999.2500 -999.£500 -999.2500 -999.2500 -999.2500 -99~.Z500 -999.2500 -999.2500 LVP 010.H02 VERiFICATIgN LISTING P~GE 9 SP SP RHOB N?'HI DEPT SP RH05 N?H l GR DEPT S? NPH! GR OEPT SP NPHI GR SP NPHi GR SP NPHI GR CEPT SP NPHi CE~T S? RH8~ NPHI GR 3100.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 DPHI 5~.2500 3000,0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPM! 59.3125 2900,0000 SFLU --999,2500 GR -999.2500 ORHO -999.2500 DFHI 50.5000 2800,0000 SFLU -999,2500 GR -9'99.2500 DRHO -999.2500 OPHI 40.0313 2700.0000 SFLU -999.2500 GR -999.2500 GRHO '-999.2500 DPHI 39.2~I3 2600,0000 SFLU -999.2500 GR -999,2500 ORH8 -999,2500 DPHi 41.9687 2500.0000 SFLU -'999.2500 GR -999,2500 ~RHO -999.2500 DPHI 35.0000 2400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 25.3438 2300.0000 SFLU -999,2500 GR -999.2500 DRHg -'999.2500 OPHi 31.8125 -999,2~00 iLD -999,2500 GR -999,2500 NRAT -999.2500 NCNL -999,2500 ILO -999.2300 GR -S9'9.2500 NR~T -999.2500 NCNL -999,2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILO -$~9..2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 iLO -999.2500 GR -999.2500 NR~T -999.2500 NCNL -999.2500 ILD -999.2500 GR -999,2500 NRAT -999,2500 NCNL -999,2500 ILD -9'99,2500 GR -999,2500 NR~T -999.2500 NCNL -999.2500 ILD -999,2500 GR -999,2500 NRAT -i99,2500 NCNL -999.2500 ILS -999,2500 GR -999.2500 NR~T -999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 - ..2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -:999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'~9.2500 iLM CALi RNRA FCN~L ILM CALl RNRA FCNL ! L M CALl RNRA FC NL iLM CAL.i RNRA FCNL i LM CALl RNRA FCNL iLM CALl RNRA FCNL ILM CALI RNRA FCNL tLM C~Li RNRA FCNL iLM C~Li RNRa FCNL -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -999.2500 -99~.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.£500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 LVP OlO.M02 VERiFiCATiQN LISTING P~G5 10 DEPT 2200.0000 SFLU SP -999.2500 GR RH08 -999,2500 DRM~ NPHZ -999,2300 OPHZ GR 43,8i25 OEPT 2100,0000 SFLU SF -999,2500 GR RH08 -999,2500 DRHO NPHI -999,2500 OPHI GR 28 DEPT 2000,0000 SFLU SP -999,2500 GR ~H08 -999.2500 ORHC NRHi -999.2500 DPHI GR 37.6250 DEPT 1900,00C0 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHi -999,2500 DPHI GR 25.8906 DEPT 1800,0000 SFLU SP -999,2500 GR RHOB -999.2500 ORHO NPHI -999.2500 OPHI GR 28,0313 DEPT 1700,0000 SFLU S? -999.2500 GR 2H06 -999,2500 ORHO NPHI -999,2500 DPHI GR 37.9062 CSPT 1695.0000 SFLU SP -999,2500 GR RHO~ -999,2500 DRHJ NPHI -999.2500 DP~I GR 32.8750 -999,2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILO -999,2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999,2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999,2500 NCNL -999.2500 ILD -999,2500 GR -999.2500 NR~T -999,2500 NCNL -999,2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999,2500 ILO -999,2500 GR -999,2500 NR~T -999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -9'99.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 iLM CALI RNR4. FCNL ILM CALi RNRA FCNL ILM C~LI RNRA F C N L ILM CALl RNRA FCNL ILM CALl RNR~ FCNL ILM C~LI RNRA FCNL ILM CALI RNRA FCNL -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 :;:N~ FILE TRAILER N;~ FiLE NAME :EDi'T .001 S~RVICE N,~ME : VERSICN ~ : ~.~TE : M~XIMUM L~NGTH : 1024 ~iLE TYPE : N~XT 'ILE NAME : _VP OIO.HOZ VSR!~ICATION LISTING PAGE 11 ¢:~ TAP£ TRAILER ~SRVICE NAME DATE :87/0~/11 3RIG!N :FS1A ~AP~ NAME : 2CNTINUATION ~ :01 ~EXT TAPE NA~ : :O~ENT$ :LIS 'TAPS~ ARCO KUP~RUA 3M-lO, API 50-029.-Z1715 ,,-,. RE::L,. TRAILER .,-,,. SERVICE NAME :EOZT ~AT~ :87/0~/11 .~R ~EEL NAME :72261 SSNTiNUATiON ~ N~XT R~EL NANE : COMM~ENTS :LIS TAPE~ ARCS KUPARUK 3~-10~ ARZ 50-029-21717~