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Home My WebLink About192-005Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'192-0053R-1750-029-22242-00 910433126Kuparuk RiverPacker Setting RecordField- Final11-Nov-2501 Originated: Delivered to:5-Nov-25Alaska Oil & Gas Conservation Commiss05Nov25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-730 50-103-20907-00-00 225-010 Kuparuk River WL TTiX-IPROF FINAL FIELD 6-Oct-253J-03 50-029-21399-00-00 185-164 Kuparuk River WL PPROF FINAL FIELD 7-Oct-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL IPROF FINAL FIELD 10-Oct-252Z-07 50-029-20946-00-00 183-064 Kuparuk River WL CBP FINAL FIELD 11-Oct-252Z-03 50-029-20964-00-00 183-085 Kuparuk River WL IPROF FINAL FIELD 14-Oct-253R-17 50-029-22242-00-00 192-005 Kuparuk River WL LDL FINAL FIELD 16-Oct-253S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-IPROF FINAL FIELD 20-Oct-252U-06 50-029-21282-00-00 185-019 Kuparuk River WL RBP FINAL FIELD 25-Oct-253T-731 50-103-20905-00-00 224-156 Kuparuk River WL Cutter FINAL FIELD 2-Nov-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41052T41053T41054T41055T41056T41057T41058T41059T410603R-1750-029-22242-00-00192-005Kuparuk RiverWLLDLFINAL FIELD16-Oct-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.05 12:45:23 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\0O55OAKD\2025-10-16_22239_KRU_3R-17_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22239 KRU 3R-17 50-029-22242-00 Caliper Survey w/ Log Data 16-Oct-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 192-005 T41021 10/22/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.22 11:31:01 -08'00' Operations Performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon Plug PerforationsFracture Stimulate Pull Tubing Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re air Well P ❑ Re-enter Susp Well El ConocoPhillips Alaska, Inc. 4. Well Class Before Work:5. Per Development Q Exploratory ❑ 192-005 P -0 -Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service ❑ Ib. API Number: 50-029-22242-00-00 KRU 3R-17 ECELIVE® JUN U 5 2019 Change Approved Program ❑ Other: _ Tubina patch rl ADLO355023 and Iesenl vven condition Summary Total Depth measured 7,171 feet 4086' true vertical 6,917 feet Effective Depth measured 6,929 feet Packer true vertical 6,704 feet Casing Length Size Conductor 79' 16" Surface 4044' 9.625" Production 7132' 7„ Perforation depth Measured depth 6887-6947 f eet True Vertical depth 6667-6719 feet (size, grade, measured and true vertical depth) s and SSSV (type, measured and true vertical depth) I4. oumma0on or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: N, Subsequent to operation: N fta Jirenl5(requlrea per 20AAC25.010,25.071, a 25.283) Report of Well Operations 21 !s of Logs and Surveys Run ❑ :d and Electronic Fracture Stimulation Data ❑ hereby certify that the foregoing is true and ci Name: Rachel Kautz Title: Well lntearity V77- 6l Form 10-404 Revised 4/2017 Plugs Junk Packer MD TVD 121' 121' 4086' 4086' 7171' 6917' measured feet measured feet measured feet true vertical feet Burst 3.5" L-80 9842' SSSV CAMCO TRDP-4A 1826' Upper Patch Packer Paragon II Packer 6323' Lower Patch Packer Paragon II Packer 6348' Packer Baker HB 6773' or Collapse 6109' 1826' 6173' 6195' 6567' ry NA NA NA NA aner VIR. I ------------------ ❑ Development 0 Service ❑ Stratigraphic ❑ after work: Oil 0 Gas ❑ WDSPL WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ iwledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Rachel Kautz/Sara Carlisle /' Contact Email: n2549(o�conocoohillios com 6 Date: j - I y Contact Phone: 659-7126 RBDMS 6_!,1 JUN 0 5 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 3, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 3R-17 (PTD 192-005). Please contact Sara Carlisle or me at 659-7126 if you have any questions. Sincerely, Rachel Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary 05/25/19 05/31/19 06/03/19 Kuparuk producer 3R-17 required a tubing patch to repair a tubing leak located at 6331'. The tubing patch was set across the leak site and subsequent testing passed to confirm tubing integrity was restored. MIRU E -line, PT lubricator to 3200 PSI. RIH and Set 3-1/2" Paragon II Packer at 6348'. CCL to Mid Element = 9.7', CCL Stop Depth = 6338.3'. RDMO Eline, ready for Slickline. CMIT TO 2500 (PASS) WITH TEST TOOL SET IN P2P @ 6348' RKB. SET 2.72" P2P (#CPP35046), SPACER PIPE, ANCHOR LATCH (#CPAL35079) MID-ELEM @ 6323' RKB. MITT TO 2500 (PASS). CMIT IA x T TO 2500 (PASS). READY TO RE-TIFL. (AC-EVAL) POST PATCH TIFL (PASSED) Initial T/I/O = 250/1100/607, IA FL @ 5121' (ST #3, OV) SI wellhead @ WV & double block AL Stacked WHP's to T/I/O = 960/970/607 in 35 min. IA FL @ same location Bled AL line Bled IA from 970 psi to 460 psi in T/I/O = SI 1000/460/607, IA FL @ same loaction, Monitor for 1 hour 15 min T/I/O = 1025/460/607 30 min T/I/O = 1025/460/607, IA FL @ same location 45 min T/I/O = 1060/460/607 60 min T/I/O = 1060/460/607, IA FL @ same location Final T/I/O = SI 1060/460/607 �1 KUP PROD WELLNAME 311-17 WELLBORE 3R-17 ConoeoPhillips Well Attributes Max Angle &MD TD Alaska. INC. wellbn,e Aruuw wnieo,e slaw: nal r) m0 hone) Act elm (rtes) KUPARUK RIVER UNIT 500292224200 PROD O.66 5,700.00 ITO0 Comment HIS lapel -sue Apnopnon EM Date xe1111 RIp RM ease Gale SBSV: TRDP Last WO: 41 01 1311992 1 3R- 11, RaRKA 2:33:as PM Last Tag VAlce lenemallc ptlwl Announce Depth lace) onema"MIIWre Last Matl By East Tag: I. 6,9290 4119/20193M7 nights Last Rev Reason - - ----- - rvarvcER. 316 Annoti Entl none weHOore Last Mntl ey Rev Reason Set Patch 5/31/2019 3R-1] lamaj Casing Strings cazlna Dezcnptlon ODpn) man) Tovlaxel set Oepu@xe) Sel Depin noon... en ll_. Grade roprmea4 CONDUCTOR 16 1506 420 121.0 121.0 62.50 H40 WELDED Casing Dezc,Isn' OD le) ID len) Top men) tel Oepm take) eel 0eptn I"ToTen ll.. Gn.ea Tu;TM1,eao SURFACE 990 8.92 42D 4.686.3 4,085.8 3600 J-55 BTC COmucHaR: QTCOI0 Casing Descne-OD(11) UTA Topinto) Depth TheSIT DepIM1 ITVO)... Widen ll.. G,aoe Top TM1take PRODUCTION ] 628 39.5 71]1.2 6.916.6 2. 0, J-55 BTC -MOD Tubing Strings Them, a ... The.101n1 ToplakBl 3e13epm la-Senl)2-to TVDT I...WI(INn) Gtatle Top Connecllon TUBING 31/2 2.99 3].] 68022 6,5926 930 J-55 ITSFILE SPfEttVLV:19268 Completion Details Isr1o0) Top Incl 'somal NID Top RKB) (nxe) V) em es, (Ip) GIS LIFT, 250],5 3J.] 3].J 0.15 HANGER WKM GEN IV TUBING HANGER 31500 3566 1.826.8 1,826.8 108 SAFETY VLV CAMEO TROP 4A SAFETY VALVE 2.812 6,]59.] 6,5554 2873 PBR BAKER PER I0' STROKE 3.WD ,73.4 6,5674 28.72 PACKER BAKER He RETRI EVABLE PACKER 2890 6,]89.] 6,501.] 28.70 NIPPLE CAMCO D NIPPLE 2750 6,801.3 6,591.9 28.69 SOS BAKER SHEAR OUT SUB 2992 BURFACE42Gaaes.6- Other In Hole (Winellite retrievable plugs, valves, pumps, fish, etc.) . LIF)., 4Ish2 T., (a..) T. (T.) malo I Topincl M Gez Com Run Dale tonne 6,3230 6,1]34 2938 PATCH -UPR P2P PACKER(CPP35046) W/ SPACER PIPE AND 513112019 162D PKR ANCHOR LATCH (CPAU5079). GAL 26' MAX 00 2.MT GA6 GFS', SIII 6.3220 6,176.9 29.38 PATCH- P -1102 -1/16 -SPACER PIPE SPACER PIPE 5/31=9 1.610 6,331.0 6.180.4 29.38 TUBING LEAK TUBING LEAK IDENTIFIED WITH RELAY L0L 919119 9198019-199198019_2992 GAS LIFE; S.]9L.5 6,3480 6,195.2 29.36 PATCH -LWR 2]30D P2P PACKER, CPP35180, DAL= 4.01 5'292019 1.620 PKR (ME) PATCH -uPR PKR: 6.323.0 6,923.0 6,698.6 20.69 FISH 11/2"OV Fell to Racide, 7m 19-9 5 0060 6,949.0 6.7214 28.61 FISH 2.6"NON-MAGNETIC RING FROM D&D HOLEFINDER 6rb8013 0.000 0 2 SMALL NON-MAGNETIC LUG 2'x 25" IN RATING "Pun. LEAK 8,5310 PATCH . SPACER PIPE Perforations & Slots 6321.0 "no GAB LIFT: 8.31.1 Dens Top I'Ve BhA .) (sM1maln PATCHMRPRRIME): a31eo Pap (IRS) Blm lacBl (aka, (nkB) LInMtl Zane GSA 1 Type Cons 6,88].0 6.9420 666]0 6,]19.6 A -2,A-1, 3R -D &1311932 4.0 IPERF 4.5"Csg GUM1180Eeg.pe Frac Summary San Dale Piopwnt GetlgnM(:Ie):Proppant l n Fwmallon Da) 9/2b1992 GPS LIFE: 6.]1.6 Slgtl Statl Gale Top GepN(aK0) BMhos.) Lhol(WHIJIMI PRAT V., Chain 1 1) VasluRy@b0 1 9122/1992 6,887,0 6,947.0 Mandrel Inserts at AT! N Top DVD) wive Top(aKB) Mha) Make Mosel DDIIe) Ser, Type "Act un Type Run Dale ComPBR 4]55.] 1 2,508.5 2,5084 MACCO SPM -1A 1GASUFT GLV BK .0 7/&12018PACKER 9,7]6.4 2 4,131.2 4,130.6 MACCO SPM -1A 1 GAS LIFT GLV JwQR.A BK .0 71IN20183 5,121.0 5,188.4 MACCO SPM -1A 1 GASLIFT OV SK .0 71IN2018NIPPLE6]699 4 5,]92.5 5,]13.9 MACCO SPM-tA 1 GAS LIFT DMY INT .0 ]/12/20185 6.338.1 6,1866 MACCO SP 1A 1 GAS LIFT DMY EK -2 .0 DM007CAMCO MMG-2 1111 GAS LIFT DMY RK .0 5/15/2019 III; e..1 a Notes: General & Safety Ena Dee Anhommn 8/31/2005 N.TE.WAIVEREOWELL'. IAx OA COMMUNICATION 122201D NOTE: View Sc0ematic w/ Alaska Schematic9.0 IPERF. 6.86)6891]0 FRAC: 6.86]0 FIBH: 8..o FI.H; S.a PRODUCTION: IS A-71]1.1 WELL LOG TRANSMITTAL #905707899 To: Alaska Oil and Gas Conservation Comm. Attn,: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 192005 30 93 5 May 23, 2019 JUN 2 7 2019 RE: Leak Detect Log and Patch Setting Record: 3R-17 AOGCC Run Date: 5/19/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS-ANC@halliburton.com 3R-17 Digital Data in LAS format, Digital Log file 50-029-22242-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: ao/Z-V/� Signed: • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • eon ~~~-1~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped starting March 13, 2008 and the corrosion inhibitor/sealant was pumped starting November 10, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~°''~~ ,,~~~~ ~~ M.J. oveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11 /12/08 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 36-10 185-114 >25' 6.00 6'6" 10/30/2008 7.65 11/12/2008 3K-32 197-076 11' 1.80 12" 10/3/2008 2.00 11/12/2008 3R-11D 192-016 6" 1.00 11/10/2008 3R-12RD 192-014 16' 1.90 18" 10/6/2008 4.25 11/10/2008 3R-14 192-045 20" 4.50 11/10/2008 3R-17 192-005 20" 4.25 11/12/2008 3R-18 192-017 14' 2.10 20" 10/6!2008 4.25 11/12/2008 3R-20 192-022 9'4" 1.50 16" 9/11/2008 2.80 11/12/2008 3R-21 192-043 SF 1.70 11/12/2008 3R-22 192-039 14" 1.70 11 /12/2008 3R-26 195-187 13' 1" 2.25 11" 3/13/2008 2.25 11/10/2008 ON OR BEFORE E A_ _E_E . a RK ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Pull tubing _ Alter casing _ 2. Name of Operator: 15. Type of Well: ARCO Alaska. Inc, I Development _X, 3. Address: Exploratory P,O, Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service _~, Plugging _ Perforate _ Repair well _ Other _ 6. Datum of elavation (DF or KB feet): 52' RKE 7. Unit or Property: Kuparuk River Unit 4. Location of well at surface: 1943' FNL, 2427' FWL, Sec 9, T13N, R9E, UM Af fop of productive interval: 1306' FNL, 1769' FEL, Sec 9, T13N, R9E, UM At effective depth: 1211' FNL, 1665' FEL, Sec 9, T13N, R9E, UM Af fatal depth: 1178' FNL, 1628' FEL, Sec 9, T13N, R9E, UM 12. Present well condition summary 8. Well number: 3R-17 9. Permit number/approval number: 92-05 10. APl number: 50-029-22242-00 11. Field/Pool: Kuparuk River Field / Oil Pool Total Depth: measured true vertical 7810 feet Plugs (measured) None 7478 feet Effective Deptt measured true vertical 7082 feet Junk (measured) None 6838 feet Casing Length Conductor 80' Surface 4034' Production 7113' Size 16" 9-5/8" 7" Cemented Measured depth 225 PF 2 121' 950 Sx PF E & 4086 4375 Sx Class G 200 Sx Class G 7168 True vertical depth 121' 4085' 6914' Liner Perforation Depth measured 6887'-6947' true vertical 6667'-6720' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 6802' Packers and SSSV (type and measured depth) Packer: Baker HB @ 6773'; SSSV: Camco TRDP-4A @ 1827' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/10/98, Intervals treated (measured) 6887 '-6947' Treatment description including volumes used and final pressure Pumped 234,819 lbs of 16/20. & 12/18 ceramic proppant into formation, fp was 5850 psi, 14. Prior to well operation Subsequent to operation Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1078 461 300 1037 160 1473 638 516 1173 147 15. Attachments MITform Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Production Engineering Supervisor Date Form 10-404 Ro/~ 06/15/88 DUPLIC 't~A~l~ SUBMIT IN Alaska, Inc. ~"~ KUPARUK RIVER UNIT ./ELL SERVICE REPORT 3R-17(4-1)) WELL JOB SCOPE JOB NUMBER ' 3R-17 FRAC, FRAC SUPPORT 0601980829.1 UNIT NUMBER DATE 06/10/98 DAY 2 FIELD ESTIMATE DALLY WORK PUMP "A" SAND REFRAC OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~'~ Yes O No ~ Yes ~,~ No DS-YOKUM AFC# ICC# ] DAILY COST ACCUM COST KD2391 23ODS36RL $141,570 $149,534 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 1015PSlI 2500PSII 615PSl 700PSI 0PSI 0PSI 0.000 " SUPERVISOR SCHWENDERMAN Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY PUMPED "A" SAND REFRAC. PUMPED TOTAL OF 234,300 LBS PROPANT IN FORMATION AND 603 LBS LEFT IN TUBING. I I [Frac-Refrac] TIME LOG ENTRY 08:00 MIRU DS (YOAKUM, APC, LRS) TGSM, PT 9000 PSI, OK. 10:00 PUMPED BREAKDOWN AND CONDITIONING STAGES FOLLOWING PROCEDURE, PERFORM STEPDOWN TES, DOWN AND OBTAIN ISIP 2185 PSI. 11:30 PUMPED DATA FRAC, SHUT DOWN AND OBTAIN ISIP 2184 PSI. ADJUST PAD. 13:00 PUMPED MAIN FRAC PER PROCEDURE. FLUSHED WITH 25 BBLS WATER AND 35 BBLS OF DIESEL. TO MAXIMUM PRESSURE OF 5850 PSI. TOTAL PROPANT PUMPED= 234,300 LBS IN FORMATION AND 603 LBS IN TUBING. 15:00 BLED TUBING TO 2500 PSI AND ANNULS TO 700 PSI. 16:00 RDMO DS FRAC UNIT. WELL RETURNED TO PRODUCTION TO FLOW BACK. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $554.40 APC $7,800.00 $9,000.00 ARCO $400.00 $400.00 DOWELL $130,770.00 $130,770.00 HALLI BURTON $0.00 $4,460.00 LITTLE RED $2,600.00 $4,350.00 TOTAL FIELD ESTIMATE $141,570.00 $149,534.40 ' ' STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMioo,~ REPORT OF SUNDRY WELL OPERATIONS ORIGINA 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1943' FNL, 2427' FWL, SEC. 9, T13N, R9E, UM At top of productive interval 1306' FNL, 1769' FWL, SEC. 9, T13N, R9E, UM At effective depth 1211' FNL, 1665 FWL, SEC. 9, T13N, R9E, UM At total depth 1178' FNL~ 1628' FWL~ SEC. 9~ T13N, R9E, UM 12. Present well condition summary TOtal Depth: measured true vertical 7180' 6924' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 52' 7. Unit or Property name Kuparuk River Unit 8. Well number 3R-17 9. Permit number/approval number 92-05 10. APl number 50-029-2224200 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 0 8 2' true vertical 6 83 8' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' I 6" 4045' 9-5/8" 7145' 7" measured 6887'-6947' true vertical 6667'-6719' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 6802' Packers and SSSV (type and measured depth) BAKER 'HB' @ 6773~ CAMCO TRDP-4A @ 1827' 13. Stimulation or cement squeeze summary 14. Cemented Measured depth True vertical depth 225 PF 2 CMT 121' 121' 9505X PF E CMT, 4086' 4085' 4375 SX CLASS G 200 SX CLASS G CMT 7168' 6914' 'A' SAND FRACTURE TREATMENT Intervals treated (measured) 6887'-6947' Treatment description including volumes used and final pressure SEE A'I-I'ACHED WELL SERVICE REPORT SUMMARY D ~-C Reoresentative Daily Average Production:or, I~.,~_ -~ OiI-Bbl Gas-Mcf A~al~tr'~F'~l~Ch0~g Pressure Prior to well operation 0 0 0 0 Tubing Pressure 0 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1779 1466 9 1140 16. 144 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. C.tO. Form 10-404 Rev 09/12/90 Title Petroleum Engineer Date SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 09/22/92 TO 09/22/92 CPF-3 DS-3R 3R-17 09/22/92 PUMPED INITIAL FRACTURE TREATMENT WITH DS YF140D. PUMPED 210 BBL BREAKDOWN STAGE AT 30 BPM. LAST WHTP=3982 PSI, ISIP=1643 PSI, FG=0.69 PSI/FT, EXCESS FRIC=0 PSI. PUMPED 100 BBL PAD (8.5% PAD/TOTAL SLURRY RATIO) @ 30 BPM, LAST WHTP=4440 PSI. PUMPED 16.0 MLBS 16/20 CARBOLITE IN 2 PPA STAGE & 220.0 MLBS 12/18 CARBOLITE IN 4 TO 12 PPA STAGES (WENT 60 BBLS LONG IN 12 PPA STAGE). FLUSHED JOB TO COMPLETION 2 BBLS SHORT OF TOP PERF. TOT PROPPANT: DESIGNED 225.0 MLBS, IN FORM 233.0 MLBS WITH 12.0 PPA @ PERFS. TOT FLUIDS: WATER 1100 BRAS, DIESEL 45 BBLS (FLA+FLUSH). (LENZ/CORBELL/WALKER) DEC 1 6 199~, Alaska, 0il & Gas Cons. Anchorage STATE OF ALASKA ALA:sKA OIL AND GAS CONSERVATION COIv, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~ GAS [~] SUSPENDED r'~ ABANDONED r'~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-05 3 Address 8 APl Number P.O. Box 100360, Ancho ramie, AK 99510-0360 50-029-22242 4 Location of well at surface 9 Unit or Lease Name 1943' FNL, 2427' FWL, SEC 9, T13N, R9E, UM ~ '~~ ' KUPARUK RIVER At Top Producing Interval~ ,,~ ~/~,j~; /__ ~~ D.,3,~"~" I YE~F~ ! 10 Well Number 11 Field and Pool 1178' FNL, 1628' FWL, SEC 9, T13N, R9E, UM [ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 52', PAD 11' GL ADL 355023, ALK 3573 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 03/28/92. 04/01/92. 08/13/92.I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost I 7180' MD ,6924' TVD 7082' MD, 6838' TVD YES X~ NO L_J 1827' feet MD APPROX 1700' 22 Type Electric or Other Logs Run CDR/CDN/CBL/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 121' 24" 225 PF 2 CMT 9-5/8" 36# J-55 SURF 4086' 12-1/4" 950 SX PF "E" CMT, 375 SX CLASS G 7" 26# J-55 SURF 7168' 8-1/2" 200 SX CLASS G CMT 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) 6887' - 6907' W/4-1/2" CSG GUN @ 4 SPF MD 6667'-6684' TVD 3-1/2"", 9.3# J-55 6802' 6773' 6907' - 6947' W/4-1/2" CSG GUN @ 4 SPF MD 6684'-6719' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 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 ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE · 28 CORE DATA S P - 41992 Alaska Oil & Ga,.~ Cons. uom~,ss-on Anchora(]e :orm 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOEOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA TOP KUPARUK C 6782' ~6575' ]ASE KUPARUK C 6886' 16666' TOP KUPARUK A 6886' 6666' BASE KUPARUK A 6967' 6737' 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, GCT SURVEY 32. t hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~__~~___~ Title AREA .RILLING 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. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3R-17 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-029-22242 92-05 ACCEPT: 03/28/92 08:03 SPUD: 03/28/92 02:03 RELEASE: 08/13/92 04:08 OPERATION: DC + P DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 03/29/92 ( 1) TD: 2283' (2283) 03/30/92 ( 2) TD: 4110' (1827) 03/31/92 ( 3) TD: 4110' ( 0) 04/01/92 ( 4) TD: 6345' (2235) 04/02/92 ( 5) TD: 7180'( 835) 04/03/92 (6) TD: 7180' ( 0) DRILLING MW: 9.0 VIS: 90 MVOED RIG FR. 3R-iOA TO 3R-17. TEST DIVERTER. TEST WITNESSED BY AOGCC REP LOIUS GRIMALDI. DRILL AND SURVEY FROM 97' TO 2283' CIRC 9-5/8"@ 4086' MW: 9.4 VIS: 46 DRLD 2283'-4110'. CIRC. WIPER TRIP TO HWDP. WORK THRU TIGHT SPOTS 3045'-2750'. HOLE SWABBING 1950'-1775'. RIH. REAM BRIDGES AT 1925', 2865', 3150'. NO FILL ON BTM. CIRC FOR 9-5/8" CSG. TSTG BOP 9-5/8"@ 4086' MW: 9.4 VIS: 42 POH. RAN 101 JTS 9-5/8" 36# J-55 BTC CSG. FS @ 4086'. CMTD W/ 950 SX PERMA FROST E W/ 1/4 PPS FLOCELE AND 375 SX G W/ 2% CACL, 1/4 PPS FLOCELE. 60 BBL CMT TO SURFACE. ND DIVERTER. INSTALL CSG HEAD. NU BOP & TEST. DRLG 9-5/8"@ 4086' MW: 9.1 VIS: 38 SET WEAR BUSHING. RIH W/BIT. CIRC. DRLD CMT 3955'-3971' TESTED CSG. DRLD OUT CMT & PLUGS AND 10' NEW HOLE. TESTED FORMATION TO 12.5 PPG EMW. DRLD 4120'- 6345'. REPAIRING STABBING BEND "@ 7167' MW:10.2 VIS: 47 DRILL AND SURVEY 6345' TO 7180' (TD). SHORT TRIP TO 9-5/8" SHOE. TIH. WASH F/ 7130' TO 7180'. 13' FILL ON BOTTOM. CIRC AND CONDITION HOLE. POOH L/D BHA. R/U TO RUN 7" CASING. RUN 7" CASING. REPAIR STABBING BOARD. RIG RELEASED "@ 7167' MW: 0.0 VIS: 0 RECEIVED S P - 4 992 Alaska Oil & Gas Cons. Commissior~ WELL : 3R-17 OPERATION: RIG : NORDIC 1 PAGE: 2 08/13/92 ( 7) TD: 7180 PB: 7082 RUNNING COMP STRING "@ 7167' MW:10.3 NaCl/Br MVE TO 3R-17. ACCEPT RIG @ 14:30 HRS 08/12/92. PLACE PIT LINER AROUND WELLHEAD & MAT BOARDS-MVE OVER WELL & LEVEL RIG. ND DRY HOLE TREE. NU BOP STACK. COMPLETED TEST ON BOPE. WITNESSED BY AOGCC REP HAROLD HAWKINS. TEST 7" CSG TO 3500 PSI.-TST GOOD. RELEASE PRESS-RU SWS. PERF W/4-1/2" CSG GUNS, BIG HOLE CHARGES, 24 GM ORIENTED 125 DEGREES CCW F/HI-SIDE AS FOLLOW: RUN # 1-PERF F/6927'-6947' ASF RUN #2-PERF F/6907'-6927' ASF RUN #3-PERF F/6887'-6907' ASF RD SWS. RU TO RUN COMP STRING. RUNNING 3-1/2" 9.3# J-55 EUE 8RD AB-MOD IPC COMP ASSEMBLY W/JEWELRY. 08/14/92 ( 8) TD: 7180 PB: 7082 RIG RELEASED "@ 7167' MW:10.3 NaCl/Br RUN 3-1/2" 9.3# J-55 EUE 8RD AB-MOD IPC TBG. (TBG TAIL @ 6802'). BAKER RETRV PKR @ 6773'. PBR SHEARED, SOS SHEARED. MU WKM TBG HGR. MU C-LINE & TEST TO 5000 PSI. LAND TBG ON HANGERS, DROP BALL & SET PKR, SHEAR PBR, RELAND TBG, TEST SSSV. TEST ANN TO 2500 PSI-OK. SHEAR OUT SOS. BLEED OFF PRESS. CLOSE SSSV. RD LNG JT, SET BPV. ND BOP STACK. NU UPPER WKM TREE. PULL BPV. SET TP & TEST TREE 250/5000 PSI. PULL TP. RU LINES & CIRC 12 BBLS DIESEL DOWN ANN & BULLHEAD 4 BBLS DIESEL DOWN TBG FOR FREEZE PROTECTION-CV HOLDING. SECURE WELL. RELEASE RIG @ 16:30 HRS 08/13/92. SIGNATURE: DATE: RECEJVEt g!as _ka .Oil .& Gas Co s. Anchorag~ SUB- SURFACE DIRECTIONAL SURVEY ~-~1 UIDANCE r~ ONTINUOUS I-~ OOL RECEIVED MAY 11 1992. Alaska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 3R-17(1943' FNL, 2427' FWL, SEC 9, T13N, RgE, UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA i Job Reference No. 92253 Loqcled By: MCBRIDE Date 6-APR-92 Computed By: DEES · SCHLUIdBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3R-17 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE' 06-APR-lg92 ENGINEER* M.MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 44 DEG 16 MIN WEST COMPUTATION DATE' 28-APR-92 PAGE ARCO ALASKA, INC. 3R-17 KUPARLJK NORTH SLOPE, ALASKA DATE OF SURVEY' 06-APR-1992 KELLY BUSHING ELEVATION' 52.00 FT ENGINEER * M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -52.00 0 0 N 0 0 E 100.00 100.00 48.00 0 23 S 42 48 W 200.00 200.00 148.00 0 17 S 43 29 W 300.00 300.00 248.00 0 18 S 10 27 W 400.00 400.00 348.00 0 11 S 9 40 W 500.00 500.00 448.00 0 9 S 40 19 W 600.00 600.00 548.00 0 9 S 73 48 W 700.00 699.99 647.99 0 10 S 59 10 W 800.00 799.99 747.99 0 9 S 50 25 W 900.00 899.99 847.99 0 8 S 15 9 W 0 O0 0 O0 -0 15 -0 17 -0 21 -0 31 -0 41 -0 53 -0 68 -0 84 0 O0 2 O0 I 10 I 14 i 31 I 45 I 09 0 77 0 46 0 21 O00N 0045 043S 0 73 S 0 97S I 26S I 55S I 83S 2 11S 239S O00E O03W 022W 050W 070W 085W 101W I 12W 119W I 25W 0.00 N 0 0 E 0.05 S 44 19 W .48 S 27 24 W .89 S 34 37 W .20 S 35 52 W 1.52 S 34 6 W .85 S 32 56 W 2.15 S 31 22 W .42 S 29 24 W .70 S 27 34 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 99 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 947 99 99 1047 99 99 1147 99 98 1247 98 98 1347 98 97 1447 97 96 1547.96 95 1647.95 O0 1799.93 1747.93 O0 1899.92 1847.92 0 16 S 6 26 W O27 S 8 3W 034 S 12 2W 0 3O S 11 27 W 0 40 S 8 50 W 0 44 S 19 12 W 0 51 S 19 33 W 0 56 S 24 42 W I 4 S 24 7W I 9 S 25 33 W -1 O8 -1 46 -1 92 -2 46 -3 04 -3 67 -4 30 -4 93 -5 55 -6 26 0 O7 0 10 0 07 0 28 0 01 0 32 0 O0 0 51 0 04 O. 27 2 79 S 3 455 4 23 S 5 13S 6 16S 7 30 S 8 64 S 10 06 S 11 69 S 13 43 S I 32W I 44 W 159 W I 73W I 96W 2 24W 2 71W 3 26W 404 W 4 81W 3.09 S 25 16 W 3.74 S 22 42 W 4.52 S 20 39 W 5.41 S 18 39 W 6.46 S 17 41 W 7.64 S 17 I W 9.06 S 17 25 W 10.57 S 17 56 W 12.37 S 19 S W 14.26 S 19 43 W 2000.00 1999.89 1947.89 2100.00 2099.88 2047.88 2200.00 2199.88 2147.88 2300.00 2299.87 2247.87 2400 O0 2399.87 2347.87 2500 O0 2499.86 2447.86 2600 O0 2599.86 2547.86 2700 O0 2699.86 2647.86 2800 O0 2799.86 2747.86 2900 O0 2899.83 2847.83 I 6 S24 OW 0 39 S 18 56 W 0 45 S 10 55 E 0 38 S 23 19 E 015 S 9 lW 0 16 S 17 49 E 0 22 S 23 17 W 0 29 S 18 50 W 0 44 N 53 52 W I 24 N 27 40 W -6 98 -7 52 -8 40 -9 52 -10 09 -10 45 -10 77 -11 08 -11 O0 -8 90 0.10 0.71 O. 37 0.34 0. O0 O. 14 O. O0 O. O0 I. 94 0.34 15 27 S 16 58 S 17 85 S 19 02 S 19 70 S 20 13 S 20 62 S 21 33 S 21 64 S 19 93 S 5.67 W 6.24 W 6.28 W 5.88 W 5.75 W 5.69 W 5.74 W 6.02 W 6.45 W 7.71 W 16 29 S 20 23 W 17 18 19 20 20 21 22 22 21 72 S 20 37 W 92 S 19 23 W 91 S 17 11W 52 S 16 17 W 92 S 15 47 W 41 S 15 33 W 17 S 15 46 W 58 S 16 35 W 37 S 21 8 W 3000.00 2999 80 2947.80 3100.00 3099 77 3047.77 3200.00 3199 73 3147.73 3300.00 3299 70 3247.70 3400.00 3399 66 3347.66 3500.00 3499 63 3447.63 3600.00 3599.60 3547.60 3700.00 3699.58 3647.58 3800.00 3799.55 3747.55 3900.00 3899.53 3847.53 1 31 N 22 39 W 1 31 N 2O 40 W I 30 N 15 57 W I 31 N 15 41 W 1 3O N 12 37 W 1 26 N 11 16 W 1 13 N 8 16 W I 14 N 5 51 W 115 N 5 1W 1 27 N 0 59 W -6 5O -4 08 -1 73 0 58 2 84 5 05 6 96 8 63 10 35 12 11 0 O0 0 O0 0 22 0 O0 0 02 0 29 0 02 0 37 0 O0 0 18 17 58 S 15 14 S 12 67 S 10 13 S 7 59 S 5 04S 2 73S 0 67S 1 56 N 3 87 N 8 73 W 9 69 W 10 53 W 11 22 W 11 85 W 12 40 W 12 78 W 13 05 W 13 23 W 13 38 W 19.63 S 26 25 W 17.97 S 32 37 W 16.48 S 39 44 W 15.12 S 47 56 W 14.07 $ 57 23 W 13.39 S 67 53 W 13.07 S 77 56 W 13.07 S 87 4 W 13.32 N 83 18 W 13.93 N 73 52 W COMPUTATION DATE: 28-APR-g2 PAGE 2 ARCO ALASKA, INC. 3R-17 KUPARU~ NORTH SLDPE, ALASKA DATE OF SURVEY: 06-APR-1992 KELLY BLJSHING ELEVATION: 52.00 FT ENGINEER: M.MCBRIDE TNTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MF.~SURED VERTICAL VERTICAL DEVIATION AZIkIUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3999.49 3947 49 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 4099 45 4047 O0 4199 39 4147 O0 4299 33 4247 O0 4399 25 4347 O0 4499 04 4447 O0 4598 54 4546 O0 4697 67 4545 I 38 N 4 i E 45 I 47 N 6 59 E 39 2 2 N 7 18 E 33 2 14 N 33 44 W 25 2 25 N 41 53 W 04 4 45 N 53 13 W 54 6 42 N 56 2 W 67 8 3 N 57 44 W 44 10 17 N 58 10 W 48 11 58 N 57 5 W O0 4796 44 4744 O0 4894 48 4842 13 99 15 89 17 91 20 89 24 82 31 09 40 89 53 69 68 86 87 98 0 O0 0 19 0 63 0 61 i 26 I 61 2 32 0 83 2 88 I 34 6.53 N 13.34 W 9.48 N 13.03 W 12.73 N 12.60 W 16.12 N 13.40 W 19.23 N 15.83 W 23.38 N 20.56 W 29.10 N 28.73 W 36.27 N 39.72 W 44.50 N 53.00 W 55.05 N 69.57 W 14.85 N 63 55 W 16.12 N 53 58 W 17.91 N 44 41W 20.96 N 39 44 W 24.91 N 39 28 W 31.14 N 41 19 W 40.89 N 44 38 W 53.78 N 47 36 W 69.20 N 49 59 W 88.71 N 51 39 W 5000.00 4991.87 4939.87 14 21 5100.00 5088.21 5036 21 16 40 5200.00 5183.36 5131 5300.00 5277.09 5226 5400.00 5369.19 5317 5500.00 5459.75 5407 5600.00 5547.90 5495 5700.00 5634.38 5582 5800.00 5720.48 5668 5900.00 5806.72 5754 36 19 14 09 21 36 19 24 9 75 26 28 90 29 40 38 30 40 48 30 31 72 30 22 N 52 57 W N 47 13 W N 45 26 W N44 6W N 44 34 W N 43 32 W N 42 48 W N43 3W N 43 14 W N 43 40 W 110 22 136 89 167 58 202 43 241 37 283 75 330 94 381 13 431 97 482 S9 3 09 3 08 3 67 3 47 2 38 4 45 I 71 0 58 0 57 0 29 67 90 N 85 106 131 159 189 224 260 297 334 88 26 W 111 35 N 52 26 W 38 N 108 61N 130 35 N 155 20 N 182 58 N 212 09 N 244 84 N 278 97 N 313 75 N 347 54 W 138 71W 168 26 W 203 47 W 242 02 W 284 22 W 331 43 W 381 17 W 432 97 W 482 09 N 51 49 W 68 N 50 48 W 37 N 49 46 W 16 N 48 54 W 42 N 48 12 W 45 N 47 28 W 53 N 46 52 W 28 N 46 25 W 84 N. 46 7 W 6000.00 5893.08 5841 08 30 7 6100 O0 S979.62 5927 6200 6300 6400 6500 6600 6700 6800 6900 O0 6066.38 6014 O0 6153.43 6101 O0 6240.62 6188 O0 6327.93 6275 O0 6415.47 6363 O0 8503.07 6451 O0 6590.77 6538 O0 6678.45 6626 N 44 6 W 533.00 62 29 58 N 44 38 W 583.12 38 29 37 N 45 22 W 632.84 43 29 24 N 45 55 W 682.04 62 29 19 N 46 15 W 730.99 93 29 I N 46 33 W 779.70 47 28 50 N 46 56 W 828.00 07 28 47 N 47 6 W 876.18 77 28 42 N 47 18 W 924.16 45 28 45 N 47 32 W 972.18 0 42 0 30 0 43 0 53 0 57 0 32 0 14 0 30 0.21 I. 39 371 08 N 382 91 W 533 22 N 45 54 W 406 92 N 417 442 11N 453 476 53 N 488 510 50 N 523 544 10 N 558 577.23 N 594 610.13 N 629 542.76 N 664 675.33 N 699 94 W 583 07 W 633 26 W 682 53 W 731 84 W 779 05 W 828 32 W 876 58 W 924 98 W 972 32 N 45 46 W 04 N 45 42 W 26 N 45 42 W 23 N 45 43 W 97 N 45 46 W 31 N 45 49 W 53 N 45 53 W 56 N 45 57 W 65 N 46 2 W 7000.00 6766.23 6714.23 28 28 7100.00 6854.12 6802.12 28 32 7180.00 6924.41 6872.41 28 32 N 47 38 W 1020.00 N 47 43 W 1067.67 N 47 43 W 1105.81 O. 60 O. O0 O. O0 707.64 N 735.33 W 1020.52 N 46 6 W 739.63 N 770.81 W 1068.27 N 46 11 W 765.34 N 799.08 W 1106.46 N 46 14 W COMPUTATION DATE: 28-APR-92 PAGE ARCO ALASKA, INC. 3R-17 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-APR-1992 KFII y BUSHING ELEVATION: 52.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN FEET DEG/iO0 FEET FEET FEET DEG MIN 0,00 0.00 N 1000 20OO 3000 4000 $000 6000 7000 7180 O0 999 O0 1999 O0 2999 O0 3999 O0 4991 O0 5893 O0 6766 O0 6924 99 947.99 0 16 S 6 26 W -1 89 1947.89 1 6 S 24 0 W -6 80 2947.80 I 31 N 22 39 W -6 49 3947.49 I 38 N 4 I E 13 87 4939.87 14 21 N 52 57 W 110 08 5841.08 30 7 N 44 6 W 533 23 6714.23 28 28 N 47 38 W 1020 41 6872.41 28 32 N 47 43 W 1105 0 O0 -52.00 0 0 N 0 0 E 0 O0 08 98 50 99 22 O0 O0 81 0 O0 0 07 0 10 0 O0 0 O0 3 09 0 42 0 60 0 O0 2.79 S 1 15.27 S 6 17.58 S 8 6.53 N 13 67.90 N 88 371.08 N 382 707.64 N 735 765.34 N 799 32 W 3 67 W 16 73 W 19 34 W 14 26 W 111 91W 533 33 W 1020 08 W 1106 0 O0 E 0 O0 N 0 0 E 09 S 25 16 W 29 S 20 23 W 63 S 26 25 W 85 N 63 55 W 35 N 52 26 W 22 N 45 54 W 52 N 46 6 W 46 N 46 14 W COMPUTATION DATE' 28-APR-92 PAGE 4 ARCO ALASKA, INC. 3R-17 KUPARU~ NORTH SLOPE, ALASKA DATE OF SURVEY' 06-APR-1992 KELLY BUSHING ELEVATION' 52.00 FT ENGINEER' M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FF__ET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIWI~TH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -52.00 0 0 N 0 0 E 52.00 52.00 0.00 0 11 N 67 51 W 152.00 152.00 100.00 0 11 S 22 22 W 252.00 252.00 200.00 0 11 S 71 29 W 352.00 352.00 300.00 0 16 S 80 52 W 452.00 452.00 400,00 0 20 S 31 32 W 552.00 552.00 500.00 0 21 S 2 42 W 652.01 652.00 600.00 0 16 S 16 11 E 752.01 752.00 700.00 0 12 S 14 30 E 852.01 852.00 800.00 0 12 S 0 39 W 0 O0 0 O0 -0 16 -0 19 -0 14 -0 18 -0 30 -0 46 -0 63 -0 76 0. O0 0 O0 0 96 1 13 1 77 1 57 I 26 1 02 0 48 0 29 0 O0 N 000N 0 325 0 59 S 0 79 S I 075 139 S I 72 S 2 01. S 2265 O00E 000 E 0 lOW 033W 0 62W 084W I OOW 1.10 W 1.16 W 1.24 W 000 N 0 0 E O0 N 0 0 E 33 S 16 43 W 68 S 29 17 W O1 S 38 2 W 36 S 38 5 W 71 S 35 41W 04 S 32 34 W 32 S 30 0 W 58 S 28 43 W 952.01 1052 O1 1052 1152 1252 1352 1452 1552 1652 1752 1852 01 1152 01 1252 02 1352 03 1452 03 1552 04 1652 06 1752 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 08 1852.00 1800 952 O0 900 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 16 S 8 46 W 0 24 S 13 I W 025 S 11 34W 0 31 S 6 38 W 0 37 S 14 21 W 0 39 S 12 36 W 0 50 S 19 39 W 0 52 S 20 28 W 1 3 S 26 23 W I 5 S 23 23 W -0 93 -1 25 -1 69 -2 22 -2 74 -3 39 -3 99 -4 64 -5 24 -5 92 0.17 0.19 O. 33 O. 07 O. O0 O. O0 O. 06 O. 05 0. O0 O. O0 2565 3085 3 825 4 725 5 635 6 755 7 98 S 9 37S 10 89 S 12.58 S 1 30W 1 38 W I 50W 1 67W 1 8SW 207W 2.48 W 2.97 W 3.66 W 4.43 W 2 87 S 26 49 W 3 4 5 5 7 8 9 11 13 38 S 24 5 W 11 S 21 28 W 01 S 19 28 W 93 S 18 14 W 07 S 17 5 W 36 S 17 14 W 83 S 17 37 W 48 S 18 35 W 34 S 19 25 W 1952 10 1952 O0 1900.00 2052 2152 2252 2352 2452 2552 2652 2752 2852 11 2052 12 2152 13 2252 13 2352 14 2452 14 2552 14 2652 14 2752 15 2852 O0 2000.00 O0 2100.00 O0 2200.00 O0 2300 O0 O0 2400 O0 O0 2500 O0 O0 2600 O0 O0 270O O0 O0 2800 O0 I 12 S 24 55 W 0 45 S 22 23 W 044 S 026W 0 43 S 20 8 E 0 22 S 3 33 E 0 16 S 13 45 E 0 16 S 6 11 W 0 28 S 21 58 W 0 18 S 33 44 W 1 19 N 36 17 W -6 62 -7 30 -7 90 -8 99 -9 93 -10 25 -10 65 -10 91 -11 25 -10 O0 0 29 0 80 0 65 0 O0 0 0 0 0 0 0 94 21 S2 14 83 58 14.40 S 16.06 S 17.21 S 18.49 S 19.47 S 19.93 S 20.38 S 20.96 S 21.68 S 20.90 S 5 28 W 6 02 W 6 35 W 6 09 W 5 74 W 5 76 W 5 65 W 5 88 W 6 14 W 7 11W 15.34 S 20 9 W 17.15 S 20 33 W 18.34 S 20 14 W 19.47 S 18 14 W 20.29 S 16 26 W 20.74 S 16 7 W 21.15 S 15 30 W 21.77 S 15 41W 22.53 S 15 48 W 22.08 S 18 48 W 2952.18 2952.00 2900 O0 3052.22 3052.00 3000 O0 3152.25 3152.00 3100 O0 3252.29 3252.00 3200 O0 3352.32 3352.00 3300 O0 3452.36 3452.00 3400 O0 3552.39 3552.00 3500 O0 3652.41 3652.00 3600 O0 3752.43 3752.00 3700 O0 3852.46 3852.00 3800.00 I 29 N 21 56 W I 29 N 2O 37 W I 29 N 19 8W 1 30 N 15 16 W 1 30 N 13 37 W 1 30 N 11 55 W I 21 N 9 38 W 1 10 N 725W 1 18 N 3 56 W I 21 N 4 15 W -7.67 -5.23 -2.84 -0.53 I 78 4 O1 6 11 7 85 9 53 11 25 0 39 0 21 0 12 0 09 0 06 0 O0 0 48 0 08 0 15 0 15 18 74 S 16 31 S 13 85 S 11 34 S 8 805 6245 3 77 S 1 655 O50N 272N 825W 9 24W 10 15 W 10 88 W 11 57 W 12 15 W 12 62 W 12 94 W 13 15 W 13 33 W 20 48 S 23 45 W 18 17 15 14 13 13 13 13 13 74 S 29 32 W 18 S 36 14 W 72 S 43 49 W 54 S 52 46 W 66 S 62 49 W 17 S 73 22 W 04 S 82 43 W 16 N 87 50 W 61 N 78 28 W COMPUTATION DATE: 28-APR-92 PAGE 5 ARCO ALASKA, INC. 3R-17 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 06-APR-1992 KELLY BUSHING ELEVATION: 52.00 FT ENGINEEE: M.MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZli~.rr~ DEPTH DEPTH DEPTH DEG WIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 3952.49 3952.00 3900.00 4052.53 4052.00 4000.00 4152.58 4152.00 4100.00 4252.6,4 4252.00 4200.00 4352.71 4352.00 4300.00 4452,82 4452.00 4400.00 4553.18 4552.00 4500.00 4653.89 4652.00 4600.00 4754.93 4752.00 4700.00 I 30 N 0 35 E 142 N 6 6E I 52 N 7 38 E 2 I N 14 36 W 2 15 N 38 32 W 3 47 N 48 36 W 5 48 N 55 14 W 7 42 N 56 53 W 9 3 N 58 23 W N 57 26 W 4856.60 4852.00 4800.00 11 34 13 09 14 98 16 92 19 24 22 95 27 56 35 91 47 53 61 56 79 35 O. 52 0.41 O. 24 2.40 0.47 3.52 1.85 I. 26 2.61 O. 85 522N 804N 11 14 N 14 56 N 17 80 N 21 16 N 26 23 N 32 85 N 40 55 N SO 26 N 13.40 W 13.21 W 12.82 W 12 63 W 14 62 W 17 78 W 24 54 W 34 40 W 46 60 W 62 13 W 14 38 N 68 44 W 15 47 N 58 41W 16 98 N 49 I W 19 27 N 40 55 W 23 03 N 39 24 W 27 63 N 40 3 W 35 92 N 43 5 W 47.56 N 46 19 W 61.77 N 48 58 W 79.91 N 51 2 W 4958 94 4952.00 4900.00 13 22 5062 5166 5273 5381 S491 5604 5720 5836 5952.46 5862 29 5052 O0 5000 O0 15 49 87 5152 09 5252 20 5352 37 5452 72 S552 48 5652 57 5752 O0 5100 O0 5200 O0 S300 O0 5400 O0 SSO0 O0 5600 O0 5700 O0 6800 O0 18 11 O0 20 49 O0 23 42 O0 26 7 O0 29 44 O0 30 38 O0 30 24 O0 30 17 N 55 32 W N 48 18 W N46 OW N 44 34 W N 44 34 W N 43 42 W N 42 49 W N43 OW N 43 20 W N 43 56 W 100 55 126 38 156 93 192 69 233 75 279 96 333.27 391.57 450.51 509.09 2 96 2 11 2 47 2 55 2 79 4 14 I 25 0 73 0 38 0 33 62 17 N 78 29 N 100 99 17 N 123 124 38 N 148 153 78 N 177 186 85 N 209 225 81N 245 268 48 N 285 311 48 N 325 353.88 N 366 80 28 W 101.54 N 52 15 W 74 W 127 58 N 52 9 W 09 W 158 46 W 193 12 W 234 40 W 280 81W 333 55 W 391 87 W 450 30 W 509 07 N 51 9 W 68 N 50 3 W 56 N 49 2 W 64 N 48 15 W 78 N 47 26 W 94 N 46 46 W 79 N 46 18 W 32 N 45 59 W 6068 10 5952 O0 5900 O0 30 4 6183 45 6052 O0 6000 O0 29 41 6298 36 6152 O0 6100 O0 29 24 6413 06 6252 O0 6200 O0 29 18 6527 51 6352 O0 6300 O0 28 57 6641 71 6452 O0 6400 O0 28 52 6755.80 6552.00 6500.00 28 42 6869.83 6652.00 6600.00 28 48 6983.81 6752.00 6700.00 28 29 7097.58 6852.00 6800.00 28 32 N 44 26 W N45 13 W N 45 54 W N 46 2O W N 46 41 W N 46 56 W N 47 16W N 47 28 W N 47 36 W 1012 N 47 43 W 1066 567.16 624.65 681.24 737.38 793 01 848 10 902 96 957 69 29 52 0 58 0 61 0 51 0 82 0 37 0 39 0 10 0 64 0 36 0 O0 395.55 N 406 75 W 567 37 N 45 48 W 436.35 N 447 475.97 N 487 514 92 N 528 553 25 N 568 590 97 N 608 628 36 N 648 665 82 N 689 702 44 N 729 738 85 N 769 25 W 624 68 W 681 15 W 737 53 W 793 75 W 848 99 W 903 28 W 958 62 W 1012 96 W 1067 85 N 45 42 W 45 N 45 42 W 62 N 45 44 W 29 N 45 47 W 43 N 45 51 W 34 N 45 56 W 13 N 46 0 W 80 N 46 5 W 12 N 46 11 W 7180.00 6924.41 6872.41 28 32 N 47 43 W 1105.81 0.00 765.34 N 799.08 W 1106.46 N 46 14 W ARCO ALASKA, INC. 3R-17 KUPARUK NORTH SLOPE, ALASKA MARKER BOTTO~ 9 5/8" CASIN~ TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD BOTTOM 7" CASING COMPUTATION DATE: 28-APR-92 PAGE DATE OF SURVEY: 06-APR-1992 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1943' FNL & 2427' FWL, SEC9 T13N R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4086.00 6782.00 6886.00 6886.00 6967.00 7051.49 7082.00 7168.00 7180.00 4085 45 6574 98 6666 17 6666 17 6737 23 6811 50 6838 31 6913 87 6924 41 4033 45 6522 98 6614 17 6614 17 6685 23 6759 50 6786.31 6861.87 6872.41 9 05 N 636 90 N 670 78 N 670 78 N 697 03 N 724 16 N 733 84 N 761 48 N 765 34 N 13.09 W 658 23 W 695 01W 696 01W 723 71W 753 45 W 764 45 W 794 84 W 799 08 W ARCO ALASKA, INC. 3R-17 KUPARLJK NORTH SLOPE, ALASKA COMPUTATION DATE: 28-APR-92 PAGE 7 DATE OF SURVEY: 06-APR-1992 K~LI Y BUSHING ELEVATION: 62.00 FT ENGINEER: M.MCBRIDE ************ STRATIGRAPHIC SUD~ARY ************ MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD SURFACE LOCATION = 1943' FNL & 2427' FWL, SEC9 T13N R9E BELOWKB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6782 O0 5886 O0 6886 O0 6967 O0 7082 O0 7180 O0 6574.98 6522.98 6666.17 6614.17 6666.17 6614.17 6737.23 6685.23 6838.31 6786.31 6924.41 6872.41 636 90 N 670 78 N 670 78 N 697 03 N 733 84 N 765 34 N 658.23 W 695.01W 695.01W 723.71W 764.45 W 799.08 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7180.00 6924.41 6872.41 1106.46 N 46 14 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FI=U~ KUPARUK WELL 3R-17 COUNTRY USA RUN ONE DATE LO~KaED O~ - APR - 92 DEPTH UNiT FEET REFERENCE 92253 WELL: 3R-17 (1943' FNL, 2427' FWL, SEC 9, T13N, RgE, UM) HORIZONTAL PROJECTION 1200 IOO0 200 ~N~rr WELL: 3R-17 (1943' FNL, 2427' FWL, SEC 9, T13N, R9E, UM) VERTICAL PROJECTION 200 400 600 800 1000 1200 1400 .............. AoGCC GEOLOGICAL MATEnl~LS INYENTOn¥ LIST '" .... i, che..,ck off or list data as it is received ~ cored inte~als, , core ,analysis iJ i~.. dh/ditch inter~ais ,., digital data ...... JllJ lll i i i i i i ii i i ii 1111 111 J i iii ii , I ,.,,,,, ,,I , ,, , , , ,, I , , ...... £6'G TYPE ' nUN INTEI:~/ALS .... scALE .............. .o. {~ ~,+) ,, , .............. ~~- dD~ ....... / ~o~o- q179 ,, ~] c ~,~ ..... ...... i /, ~ ~ L z~ s~, ~,, ~ II ........ ............. 7) , , , , , ...... 9] - 10) .... 14) ,, , ~ .... , ,, ..... , .................. ~ .... .... 1~) , ,, , ..... ..... ,,, ,, ~9] ii il ii i J I II J I I TO: THRU: FROM: Sta e of Alaska CONSERVATION COMMISSION David W Johnston-. ommlssloner~ DATE: FILE NO: August 19, 1992 hhS19-1.doc Blair Wondzell P. I. Supervisor ~rold R Hawkins Petr Inspector TELEPHONE NO: SUBJECT: BOP Test~Nordic 1 AAI KRU '3R-17 Permit No. 92-05 Kuparuk Rv Field ~ednesda¥, .Auq.ust 12, 1997 I witnessed the BOP test at AAI KRU 3R-17 on Nordic Rig '~. There were no failures. I fJ. lled out an AOGCC field report which is attached. In summary, the BOP test on Nordic #1 on AAI KRU 3R-17 was satisfactorily performed. Attachment 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA 01 L AND GAS CONSERVAT I ON COMM I SS I ON BOP Test Report OPERATION: Drlg Wkvr Operator A,,~-/ Well 3 /~'//7 Drlg contrctr ~/'~/~ p [(~ ~ . - - TEST: Initial__ Permit #, ?,~ ' ~j~ ,, Rig// / Weekly.__ Other Ri g phone Location: Sec /q2 T,13~ R Location (general) Housekeeping (general) MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Vi sual / I Rig .,~ ll"/4j ~ v · ! Audio BOPE STACK: Annular preventer Test Pressure Pipe rams Blind rams Choke line valves':?~.~.~ HCR valve - Kill line ~lves Check valve TEST RESULTS: ACCUMULATOR SYSTEM: Full charge pressure 7/~'~ pstg Press after closure ~ ~/.~4~(~r psig Pump tncr clos press 200 pstg - min~ J~'" sec Full charge press attained ,------ min~_~' sec Controls, Haster m6'AV Remote ~'A% Blind switch cover ~X'~/ Remarks: KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves ~g~. Number, flanges ~ ~ Adjustable chokes ~ Hydraulically operated choke Fail,ures '"~,,/>~ Tes~ time /'Y hrs · Repair or replacement of failed equipment to be made within days. · .-_ Test pressure ~//~ Test pressure Test pressure ~,~ Test pressure Test pressure Notify the Inspector, fnd follow with written~FAXed [276-7542] verification to Commission office. '7'~ ~ ~ ~' I , ,:;! Distribution: orig - AOGCC c - Operator' c - Supervisor C.004 (rev 07/92) STATE W I TNESS/REQU I RED? yes V no 24-HR NOTI ~. IVEN? yes - no ., . Waived by: AOGCC phone 279-1433 - FAX 276-7542 ARCO Alaska, Inc. Date: May 8, 1992 Transmittal #: 8426 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 R- 1 7 Sub-Surface Directional 4 - 6 - 9 2 Survey Receipt Acknowledged' ~ .... D at e: D&M State of Alaska (2 copies) 92253 .... RECEIVED MAY 111992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: April 24, 1992 Transmittal #: 8412 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. R-10A Receipt Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Acknowledge: Please acknowledge receipt and 4-6-92 4-6-92 4-6-92 4-6-92 4-13-92 4-13-92 5695-7053 5695-7O77 6495-7936 6495-7957 7500-8487 7500-8464 Drilling State of Alaska(+sepia) NSK ARCO Alaska, Inc. Date: April 24, 1992 Transmittal #: 8411 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy pf th_i~ transmittal. S Tape and Listing 3 - 2 5 - 9 2 ~j3,,. ~" 3 R - lei~pt~g'~)/-LIS Tape and Listingo 4~1 - 9 2 Rec Acknowledged' - .... --. ...... Please acknowledge receipt and return 92235 92250 Date: .......... DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED APR 2 9 997. Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. Date: April 10, 1992 Transmittal #' 8404 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmiltal. Please acknowledge receipt 3R-17 C[~ ~ 3-31/4-1-92 3R 17 CDR 3-31/4-1-92 3 R- 10A Array Induction Log 3 - 2 5 - 9 2 (5"/100' Presentation) 3 R- 10A Array Induction Log 3 - 2 5- 9 2 (2"/100' Presentation) 3 R- 10A Dipole Sonic Log 3 - 2 5 - 9 2 (2" &5" Delta T) 3 R- 10A Dipole Sonic Log 3 - 2 5 - 9 2 (Coherence Log) 3 R- 10A Litho Density-Neutron Porosity 3 - 2 5 - 9 2 (2" &5") 3 R- 1 0A Litho Density-Neutron Raw Data 3 - 2 5 - 9 2 (2" &5") Receipt Acknowledged: DISTRIBUTION: 4090-7179 4090-7179 :4790-8044 4790-8044 4794-8027 4794-8027 4790-8044 4790-8044 RECEIVE Date- - ......... APR 1 4 1992 Alaska 0il & Gas Cons. Commission Anchorage D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) TO: THRU: FROM: MEMORANDUM Alaska ALASKA OIL AND GAS CONSERVAT~ Lonnie C Sm~. Commissioner DATE: FILE NO: March 31~ 1992 lq331-4, doc P. I. Supervisor Louis R Grimald~ Petr Inspector TELEPHONE NO: SUBJECT: Diverter Inspection Parker 245 ARCO 3R-17 Permit 92-05 Kuparuk River Field Sat~.dav, .March 28, 1992 I traveled to CPF-3 in the Kuparuk River Field to perform a diverter inspection and witness the function test of Parker Rig 245 diverter system. Don Breden (ARCO representative) has always called and given the inspectors plenty of advance notice (24 hours) and then another call when he is approximately 2 hours from test time. This makes it easy for us to schedule a visit to his rig. The diverter system functioned quite well and I was impressed with the operation of the 10"demco ball type diverter valves. Unlike the paddle type valve which usually operates slowly, these valves when, actuated, completed their cycle within one second~ I found all items to be in compliance with the exception of a targeted tee at the end of the starboard diverter line which would direct the flow towards a production shack 35' away. It should be noted that this pad is not on line and this building is not powered or manned as of yet. The tee was removed at my request. In summary, I witnessed the diverter test on Parker Rig 245 Drilling Well # 3R-i7 for ARCO in the Kuparuk River Field. Attachment 02-00lA (Rev. 6/89) 20/11/MEMOl.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report OPERATION: Drlg ~ Compl~ Wkvr UIC Operator /~ j~_.c_~ Permit # ~-- E)_i-- Location: Sec ~ T /~ R ~ M ~ D~lg contr ~~~ Rig~ ~~ Location (gen'l) ~~ Well sign ~ IN COMPLIANCE; xes no n/a A. DIVERTER 2.(~ () s () ~.CX) () s.O<) () 7. (r'/-.). ( ) 8.() () 9.() () 10. ( ) ( ) 11. ( ) ( ) 12. ( ) ( ) 13. ( ) ( ) 14. ( ) ( ) 15.() () 16.() () 17. () () i8.() () 19. ( ) ( ) 20.() () 2'1. ( ) () 22. ( ) ( ) 23. ()<) ( ) 24. (~X) ( ) 25. (x~) ( ) 26. ~) ( ) 27. (X) ( ) 28.. ()0 ( ) 3o ( ) 3~. (~ ( ) 32. (~)- () ( ) line sz & length ( ) line corm & anchored ( ) bifurcated & dwn wind ( ) 90° targeted turns ( ) vlvs: auto & simultaneous ( ) annular pack-off ( ) condition B. BOP STACK (~) wellhead flg wkg press (~) stack wkg press ()0 annular preventer (~) pipe rams (70 blind rams (~)~) stack anchored (~) chke/kill line sz (70 90° turns targeted (chke & kill In) (j)Q HCR vlvs (chke & kill) (~ manual vlvs (chke & kill) (X) connections (flgd, whd, clmpd) (~(~ drl spool (X) fl ow ni pp 1 e (~ flow monitor (~X~ control lines fire protected C. CLOSING UNITS ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ( ) remote control panel Representative Well name Representative IN COMPLIANCE; yes n._~o n/a 3:3. 34. ss. 38. (~') 39. (/~ 40. (,~ 42. 47. (30 48.() 49. 0<) 5o.() 5~.() 52. ( ) 53.() 54.() 55. ~ 56. (~ 57. () 58. (~ ( ) ( ) firewall ( ) ( ) nitrogen power source (back-up; ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ) ( ) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) ( ) chke In conn ( ) ( ) trip tank E. RIG FLOOR ( ) ( ) kelly cocks (upper,lower, IBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) ( ) driller's console (flow monitor flow rate indicator, pit leve indicators, gauges) ( ) (/3~ kill sheet up-to-date ( ) ~ ) gas ~etection monitors (H S & methane) ( ) (~ hydr chke panel ( ) Q~ chke manifold F. MISC EQUIPMENT ( ) (j~O flare/vent line ( ) (~X) 90° turns targeted (dwn strm choke lns) ( ) (~ reserve pit tankage ( ) ( ) personnel protective equip avai' ( ) ( ) all drl site suprvs trained 2for procedures ( ) ~ H S probes ( ) ( ) rig housekeeping RECORDS: Date of last BOP inspection: Resulting non-compliance: Non-compliances not corrected & why: Date corrections will be completed: ~ BOP test & results properly entered on daily record? ~'~ Date of last BOP test: Kill sheet current? ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 27, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3R-17 Rev. ARCO Alaska, Inc. Permit No. 92-05 Sur Loc 1943'FNL, 2427'FWL, Sec. 9, T13N, R9E, UM Btmhole Loc 1182'FNL, 1686'FWL, Sec. 9, T13N, R9E, UM Dear Mr. McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated January 17, 1992, are in effect for this revision. Sincerely, Chairman ~ ' Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 1 a. Type of Work Drill X Redrill r'~ 1 b Type of Well Exploratory D Stratigraphic Test r'~ Development Oil X Re-Entry [~ Deeoen r'~ Service D Development Gas D Sin~lleZone X Multiple Zone D 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 52', Pad 11' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 355023, ALK 3573 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1943' FNL, 2427' FWL, Sec. 9, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1315' FNL, 1815' FWL, Sec. 9, T13N, RDE, UM 3R-17 #UG30610 At total depth 9. Approximate spud date Amount 1182' FNL, 1686' FWL, Sec. 9, T13N, RDE, UM 3/26/92 $200,000 '"i 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3R-18 7,059' MD 1686' ~ TD feet 25' ~ surface feet 5175 6,805' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 4400md feet Maximum hole angle 29° Maximum surface 2411 Data At total deoth ~TVD~ 3283 18. Casing program Setting Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length MD 'TVD MD 'rVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BT(3 4,031' 41' 41' 4,072' 4,072' 545 Sx Permafrost E & HF-ERW 375 Sx Class G 8.5" 7" 26.0# J-55 BTC 7,018' 41' 41' 7,059' 6,805' 160SxClassG HF-ERW Top 500' above Kuparuk 1 9. 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 Structural Length Size Cemented~j~ ECE! vl~al~ed depth True Vertical depth Conductor Surface Intermediate Production M A R ~ 5 199~ Liner Alaska 0ii & Gas Cons. Commission Perforation depth: measured true vertical Anchorage '~0. Attachments Filing fee D Property plat r'l BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis r'l Seabed report D 20 AAC 25.050 requirements X '"~ 1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _//~//~~~' Title Area Drillincj Encjineer Date / Commission Use Only Permit Number I APl number I Approval date I See cover letter for ~'"~-~ -~I 50-O..~ ~ -- ~ :~--~. ~"~-"I /'~-' / ~',- ~;;;~¢=,~] othe,r requirements Conditions of al313roval Samples re(tuired r-1 Yes ~' No Mud Io~ recluired r"l Yes/'~ No Hydrogen sulfide measures r'l Yes ~ No Directional survey required '~ Yes r'l No Required working pressure for BOPE D 2M ~ 3M r'l 5M D 1OM r"l 15M Other: --~ ......... by order of ~.~/~ Appr Commissioner the commission Ddt Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 25, 1992 Mr. David W. Johnston, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 3R- 14 APl 50-029-22241 Permit Number 92-04 Kuparuk River Unit Well 3R-17 APl 50-029-22242 Permit Number 92-05 Dear Mr. Johnston: ARCO requests cancellation of approved permit to drill for Kuparuk River Unit 3R-14, and requests approval of revised application for permit to drill 3R-17 to bottom hole location change. 3R-17 will now be drilled to the bottom hole target permitted in 3R-14. Ddlling operations have not yet sta~ed. We appreciate your patience in this matter. If you have any questions, please contact Ellen Fitzpatrick at 263-4638. Sincerely yours, A. Wayne McBride Area Drilling Engineer RECEIVED MAR 2 5 1992 Alaska 0il & Gas Cons. commission Anchorage DRILLING FLUID PROGRAM Well 3R-17 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.2 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% 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 and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2411 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3R-17 is 3R-18. As designed, the minimum distance between the two wells would be 25' @ surface. The wells would diverge from that point. InCidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVED MAR 2 5 1,992 Alaska Oil & Gas Cons. Cornmission Anchorage IARCO ALASKA, I Structure · Pod 5R Well · 1 7 Field · Kuparuk River Unit Location ' North Slope, Alaska 3reoted by ' jones For: E FITZPATRICK )ate plotted ; 25-Mar-92 Plot Reference is 17 Version #5. Coordinates ere in feet reference slot //17. True Verticsl Depths ore reference wellhead. J]EASTMAN IJCHRISTENSEN A {ok,w H~,l~ N 44.26 DEG W 8?7, (?o ?Ai~CET) 4OO - o 4o0 800 1200 5600- 7200- TD LOCATION: ] 1182' F'NL, 1686' F'WL{ SEC. g, T15N, RgE J RKB EL['VATION: 52' 900 800 700 600 500 400 t : ! { { I { I I I I T~GET LOCATION: 1515' F'NL, 1815' FWL SEC. 9, f13N, RgE TARGET 'ND=6472 TMD=6678 DEP=877 NORTH 628 WEST 612 B/ PERMAFROST 'R/D=1692 West T/ UONU SNDS TVD=27¢2 Scale I ' 50.00 300 200 1 O0 0 1 O0 I I { I { I I I I - 900 8OO SURFACE LOCATION; 1945' FNL, 2427' FWL SEC. 9, T15N, RgE 7OO T~ W SA)< SNDSTVD=5482 B/ W SAK SNDS TVD=3872 K-lO TVD=3927 9 5/8"CS0 PT TVD=4072 KOP 'FVD=4400 TMD=4400 DEP=O 3.00 9.00 BUILD 3 OEG / lOO' 15.00 21.00 TARGET - T/ KUP SNDS TVD=6472 TbID=6678 DEP=877 T/ ZONE A T'VD=6553 TMD=6771 0EP=922 '------~c--~ B/ KUP SNDS WD=6630 TMO=68§9 DEP=965 ~ TD / LOGGI]~G PT TVD=6805 TMD=7059 DEP=IO82 AVERAGE ANGLE 29.08 DEG RECEIVED MAR 2 5 !992 Alaska 0il & 6as Cons, Commissior, Anchora.qe West Scale 1 50.00 250 200 I I I 54OO 150 I 100 5O 0 5O 100 11000 520O 1400 150 I I I 2OO 350 300 250 2OO 150 /X 1600 100 RECEIVED MAR 2 5 1992 Alaska Oil & Gas Cons. CommisSiOn 'Anchorage 50 0 50 tARCO ALASKA~ Inc. ~oo Stru~'l'urw ~ Pad ;SR ....~'.,I 1'~-"--'~- l mid'-' Kuraruk i~lver' Unl! Loc .¢~lr,on: North Slope. Aleeko " -.': " 150 _ _ I _ GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3R-17 , , , , , , , , , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker Rig 245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,072') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (7,059') according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED MAR 2 5 1992 Alaska Oil & Gas Cons. Col~mJss~on Anchorage .I ,6 , 13 5/8" 5000 F 51 BOP STACK ACQUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 4 BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALLOTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST 8. ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5(X)O PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5(X)O PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED MAR 2 5 1992 Alaska Oil & Gas Cons. Commission Anchorage KJPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 I 5 4 HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. RECEIVED . MAR 2 5 ~992 Alaska OJJ & Gas Cons. Commission Anchorage 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20"- 2000 PSI ANNULAR PREVENTER EDF 3/10/92 ALASKA OIL AND GAS CONSERVATION COMMISSION January 17, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well Name: Kuparuk River Unit 3R-17 Company ARCO Alaska, Inc. Permit No: 92-05 Sur. Loc. 1943'FNL, 2427'FWL, Sec. 9, T13N, R9E UM Btmhole Loc. 1264'FSL, 790'FEL, Sec. 9, T13N, R9E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. Sincere David W... Joh~ton, Chairman Alaska O~1~.~_~ Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL....,KA OIL AND GAS CONSERVATION C, OIVlMIoolON PERMIT TO DRILL 2O AAC 25.005 1 a. Type of Work Drill X Redrill D 1 b Type of Well Exploratory D Stratioraphic Test ri Development Oil X Re-Entry D Deepen D Service 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 52', Pad Elev: 11' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 355023, ALK 3573 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 .a. AC 25.025) 1943' FNL, 2427' FWL, Sec. 9, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1475' FSL, 1000' FEL, Sec. 9, T13N, R9E, UM 3R-17 #UG30610 At total depth 9. Approximate spud date Amount 1264' FSL, 790' FEL, Sec. 9, T13N, R9E, UM 1/27/92 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3R-18 (proposed) 7,862' MD 1264 (~ TD feet 22' (~ 1700' MD feet 51 75 6~819' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A.~C 25.035(e)(2)) Kickoff depth 2787 feet Maximum hole angle 41 ° Maximum surface 2400 psig At total depth (]'VD) 3300 pslg 18. Casing program Settir~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couptin~l Length MD 'I'VD MD TVD (include stage data! 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4129' 41' 41' 4,170' 4,052' 595 Sx Permafrost E & HF-ERW 405 Sx Class G 8.5" 7" 26.0# J-55 BTC 7821' 41' 41' 7,862' 6,819' 170Sx ClassG HF-ERW Top 500' above Kuparuk 1 9. 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 sCuD='o' R E C E IV £ D Intermediate Production Liner - t992 Perforation depth: measured Alaska 0il & Gas Cons. C0mmJss~0n true vertical Anchorage 20. Attachments Filing fee X Property plat r'! BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D - Refraction analysis D Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~3 ~.~ ./~,~,~~/~~ Title Area Drilling Engineer Date - '' /' "~" ' Commission UseOnl)f /- -- ~'~ -~,~ 50- ~>~_ ~- Z. ~_-;~, ~77.~., /"-/*~ ~' ~',~'~ other requirements Con'ditions of approval Samples required r-i Yes ~ No Mud log required r'! Yes,~ No Hydrogen sulfide measures r"l Yes ~ No Directional survey required ~ Yes r=l No Requirod working pressure for BOPE D 2M OM O 5M O 10M O 15M Other: Appr Commissioner the commission Date //I,. ~' <~_ Form 10-401 Rev. 7 _~'89~ Submit in triplicate _)RILLING FLUID PROGRAM WELL 3R-17 Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 9.0-10.0 9.0-9.3 10.0 PV 15-35 5-15. 10-18 YP 15-35 5-8 8-12 ViscOsity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 API Filtrate 10-12 8-10 4-5 pH 9-10 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Triple Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaner, Centrifuges, Degasser - Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2400 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3R-17 will be proposed Well 3R-18. As designed, the minimum distance between the two wells would be 22' at 1700' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. Spud mud should be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. RECEIVED Alaska Oil & 6as Cons. Anchorago ARCO ALASKA, Inc. Structure · Pad 5R Well · 17 Field · Kuparuk River Unit Location ' North Slope, Alaska 3reared by ' j°neSror: B~,x~u~¥ / FITZPATRICK Date plotted : 27-Dec-91 Plot Reference is 17 Version #4. Coordinates ore in feet reference slot #17. True Vertical Depths are reference wellhead. z~J~EASTMAN ~CHRISTENSEN A Baker Hughe~ ~ompony 0 0 0 0 · ' 400 -6 soo 1200 - 1600- 2000- (D ~ 2400- _ ~ 2800- 0 - · q--- 3200- (D - 3600- _ 4000- - 4400- _ 4800- - V 5200- _ 5600- 60004 _ 6400- _ 6800- _ 7200- S 44.86 DEG E 2627' (TO TARGET) RKB ELEVATION: 52' B/ PERMAFROST TVD=1697 Scale1 ',00.00 East --> 0 200 400 600800 1000 1200 1400 1600 1800 2000 I I I I I I I I I I I I I I I I I I I I I I I 0 SURFACE LOCATION: ~ 1943' FNL, 2427' F'WL .. SEC. 9, T15N, R9E 200 o o 400 g V ® / ~ ~X~~°°° ~=6482 ~D=7413 DEP=2627 SOUTH 1862 ~SI 1853 T/ UGNU SNDS 7VD=2742 5.00 KOP T'VD=2787 TMD=2787 DEP=O 9.00 BUILD 3 DEG/ 100' 15.00 21.00 T/ W SAK SNDS TVD=3472 TMD=3488 DEP=127 , 27.00 k, 33.00 @/ W SAN SNDS TVD=3852 TMD=3917 DEP=324 ~\ 3~ r~^ K--lO TVD=3942 TMD=4027 DEP=389 ~]OC/ 9 5/8"CSG PT TVD=4052 TMD=4170 DEP=¢79 ~ AVERAGE ANGLE 41.47 DEG ~ TARGET - T/ KUP SNDS TVD=6482 TMD=7413 DEP=2627 ~x, ~, ~ T/ ZONE a TX/D=6576 TMD=7538 0EP=2710 ' ~ B/ KUP SNDS TVD=6669 TMD=7662 DEP=2792 ~ TI) / LOGGING PT TVD=6819 TMD=7868 DEP=2925 I I I I I I I I I I I I I I I I 400 800 1200 1600 2000 2400 2800 5200 Vertical Section on 136.1~- azimuth with reference O.O0 N, O.OO £ from slot 1~17 TO LOCATION: I 1264' FSL, 790' FEL SEC. 9, T13N, R9E RECEIVED Alaska Oil A Gas Cons. c0mmiS~'t0~ ,.Anchorage. Scale 1 ' 50,00 East ~200 2250 2300 2350 2400 2450 ARC 0 ALASKA, Inc. Structure: Pad 3R field: Kuparuk River Unit Location: North Slope, Alaska 2500 2550 2600 I I I I I I 2200 2650 I ~ 550 1600 1650 5400 8O0 O0 ~800'~ 4riO0 18OO 2000 \2787 '~,3200 RECEIVED Alaska Oil & Gas Cons. Anchorage 1700 - 1 750 -1800 -1850 -1900 -1950 -2000 -2050 I I V 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3R-17 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 7 , 6 5 I I 13 5/8" 5000 P. I BOP STACK A(~CUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3(X)0 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST 8. ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 30(X) PSI. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR RECEIVED JAN - 3 1992 Alaska Oil & Gas Cons. Commission Anchorage ~.dPARUK RIVER UNI'~ 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" 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 RECEIVED JAN - 5 1992 Alaska .Oil & Gas Cons. Commission ,. ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ,oc [10 S 13] (4) Casg ~'~'~ [14 thru 22] [23 thru 28] Other /~,,'~ . [29 thr~ ~'1 Company /-J ~C__(-D . YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. /~ 3. Is well located proper distance from property line ................... ~C~ 4 Is well located proper distance from other wells ..................... 5 Is sufficient undedicated acreage avai..lable in this pool ............. 6 Is well to be deviated & is wellbore 'Plat included ................... 7 Is operator the only affected party .................................. 8 Can permit be approved before 15-day wait ............................ (6) Addl . 10 11 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Does Operator have a bond in force ................................... .~. Is a conservation order needed .... Is administrative approval needed ................ Is lease nunber appropriate .......................................... Does well have a unique name & nunber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Wi.ll all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation, proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... y NO REMARKS Additional requirements ............................................. Z geology' DWJ_]~ RPC~'/~d~ en9ineering: MTM~K-f LCS ,//C; BEW. rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ** CHECK LIST FOR NEW WELL PERMITS ** Company Lease & Well ITEM APPROVE ,D/ATE Fee ,~.//E),x'~ Loc ~ , [2 thru 8~ E9 thru 13]' ' [10 & 13] [14 thru 22] [23 thru 28] (6) Other /~ /Z~~ [ 29 thru "~ 1 ] 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Does operator have a bond in force .................. ' ................. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~OOo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. REMARKS 0 -rZ ~0 u~--I geo 1 ogy: eng i nee r i ng,: DWJ~ MTPLg?~' LCS ,,/~."]~ RPzC.~ BEW /' RAD~ ~-~-,~. rev 03/29/91 jo/6.011 INITIAL GEO1 "UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional rema r ks' Well History File APPENDIX Information of detailed nature that is not padiculady 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 APPENDIXl .. No special 'effort has been made to chronologically organize this category of information. RECEIVED APR 2 9 199~ Alaska 011 & Gas Cons, Commission Anchorage MICROFILMED center 9"AP~'5~-1992 r~I~:06 ........ ', . FIN(l!< 7!17" Cblu. mhergor Al. asKa Cot~i.;t.~t.!nr:~ C F ? D g F ~ T Y P g Co V Wield Nome ee]l, AP1 Serial ~,~umber Field Locat' Section T own s h j p County St:ate o~ Prov!nce N <~ t i o Latlt~,de l~onoi tude ~itness~ 549009 Service ~rder FT O. ~:l, evatlo~ oi:' Per,~, ~,':',a b':q' 52, Ai3OVF P~jR ~,~ A N E?,~T VT 52. Elevatio~ of Kelly ~"l: 52, E:!ovat:lon o~ Derrick FT' 11. t~:leva'tlon o~ Ground ~;".[' 7179, Total. DePth - Driller ~'T 7!79. Total. bePth - Loaa'er PT 7!79, ~:~ottom Loa Interval FT 4090, ToD Loo Intervol C~.:.I~/[..~!(L~ Pr'il!i. na F1uj,.d Type c~IC.'3 ~(.'.2 Drll!lno Fluid Oensit ~ (' Pr i 11 i, ~n ~" l U ~ d P h CF' 40. [:)rilli. mo Fluid VI. sCOS P3 ~.2 [:'ri. Iii. hq F'luid~ boss [lii;.~': 2,5! P~sist!vitv of ~?ud Sa [>EGF 67. ~':LJrl Samf.:le Temperatu [')qb? 2,33 Pesistivity of: mud fi [':CGF ~.{7, r-it.id ~i, ltrete Sample U~x;', Peslstlvitv of t:ud Ca O~:(;F' ~,UO Cake san;ole l:em~e I.S T~ne Ve?if~cat.lon i istin.'.i~ T N. p t~ I3FPT , 9 C a b. L :* t.:; - q 99.250 D P F: !. L V :) - 999.250 D P 0 P. f, :;:~ D -999.250 -999 250 98:904 :999 250 999'250 100,877 -o 015 .!.19 1.53.856 ' f'J , 0 3 6 0.22! 82.194 0.012 0. O46 51.294 0. OO7 0 140 0, !. 2 4 9 P R I. 'b ~? !. 2 0 !, 79 7 2. 459 2,190 2,534 0, Ci 7 0 2,!01 2. 386 0,1 O o !...270 2. 451 o.:121 ('? 97 C 'I · ' 2.457 C',1:!7 :1.545 2.452 0,1. 2 0 1.53e, 2.419 i~. 14(? 1.q35 2.422 0. I ~} ~ 3,515 2.42° 0,134 2.R72 ri.il4 2.44! D P [3 R ROPE :,RHD Li~:P D P C'J R. ! i~! P R i,:)pF~, bV',D DR i'- 0, L i~; D D P C! P. L ~ D D P r; P. b i,~ D R 0 P ~.:. L. ,,' 9 DR ~C! L' D t3 P 0 R. [.., ?: D R(!PF:. D R I-': Q, L ,~ I :, P A :G.E: 0,000 0,170 60 998 0.002 0,1!6 !89,!59 0,001 0 070 20i'' -0,0t4 0.160 141,730 0,01 3 0.121. 4(:). 652 0,003 0,117 222.223 -O,OOl 0.120 22!..204 -0,005 0,140 2~0,581 u. 00 3 0,118 255.1~4 0,002 9.134 372,219 0.019 0.1!4 254.391 T ~,! P !4. l, w !) 33 ,, .309 a T P.. l~ u; L' (;'o. L !:; 0 ~:: i. ' 33 t, £i, e, 0 e D P H 15. L W I. ~ ,:it 2 P S F!'. L w i) 2,427 P S ~?,. I.., :'~ !2 ,'"'. 028 !) F t-4 i. !.., '.*' b ? 764 F-',qO, t ~,i!) 1 , 2 2 ? P S :q., b ~'.' D .... r,~ I . t-~,36 F=,q[:,:, · r ."i3 377 1. ':' 6 382 2.394: 4 t 6 . :1.42 1:30 2.3a2 !62 2,289 ,., , ~, i.q 2.534 2..371 0,169 2.09.3 ?. 374 0. i 67 2..352 O. lSl 2,42 (.) ('. I 4O 2.399 c,. ~ 52 2.6'74 2.3'7.'1 I. 537 D P .H O. !.. v.t b l:::' 0 p F. L W () D P O P, L W O I) P Ci R. [.,, ? D ROPE i') P O ~. b w t') R .r', p f..;, L V:- D ? P f) P', I., ':, P i< (.') P E:. f., '.~. ti, -0,01, 4 O, 166 263,.662 -0.017 0,}55 230, 79 '0,002 0,142 ta9,47! -0,009 0,162 185.460 -0.033 0.2!9 304.66:1 -tO, 004 0 169 267:571 -0,014 0,167 38'1,129 u.001, 0.181 139.53! 0.065 0.!40 486.07i 0.028 0.152 457,60l -0,002 0.I69 353.222 2.4 t:, 8 R ~:i 0 i:~. , ?. o 0.563 D P H !, b ~'~ P - t'..} 99,250 R 1:4 O F!,. b W ') - 999.250 D P ?1 !,. L ~4 D -999,250 PSg', 2,2~4 0.222 3,!!.l 2.299 0.213 2, ~.375 ?.167 3.024 1.622 !, 62,3 .761 t10 342 -q99,250 -99g,250 D P 0 R. b w i> ,R 0 P E. !., w ~, D k t~.i 0. :j., !,.4 D R 0 P E. b 9 R ~r! 0. b i~ D R 0 P E. L ~ O -o.02i 0'222 546.~27 -0.012 0.2!3 0.041 0,167 5S0'004 0.035 0.623 302'664 -0,266 0,!10 -999,250 ~999 250 99: 2so -999,250 50-~i29-22242