Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout185-250Originated: Delivered to:1-Jan-26Alaska Oil & Gas Conservation Commiss01Jan26-NR        !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCD4-588 50-103-20853-00-00 223-029 Colville River WL IPROF-WFL FINAL FIELD 10-Dec-251F-10 50-029-20984-00-00 183-105 Kuparuk River WL IPROF-LEE FINAL FIELD 11-Dec-253J-10 50-029-21467-00-00 185-250 Kuparuk River WL PPROF FINAL FIELD 25-Dec-25Transmittal Receipt//////////////////////////////// 0/////////////////////////////////  +  !  1 Please 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!%  T41231T41232T412333J-1050-029-21467-00-00185-250Kuparuk RiverWLPPROFFINAL FIELD25-Dec-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.01.02 08:01:12 -09'00' By Anne Prysunka at 3:13 pm, Oct 26, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-15_22043_KRU_3J-10_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22043 KRU 3J-10 50-029-21467-00 Caliper Survey w/ Log Data 15-Aug-22 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 PTD:185-250 T36892 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.18 11:15:40 -08'00' A31TE OF ALASKA KRU 3J-10 OIL AND GAS CONSERVATION COMI ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate r Pull Tubing F Operations Shutdown Performed: Suspend Perforate Other Stimulate fl Alter Casing E Change Approved Program IT Plug for Redrill Perforate New Pool Repair Well F Re-enter Susp Well 3 r- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory IT 185-250 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21467-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25630 KRU 3J-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7344 feet Plugs(measured) None true vertical 6562 feet Junk(measured) 7100 Effective Depth measured 7321 feet Packer(measured) 6409 true vertical 6470 feet (true vertical) 5841 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110 110 0 0 SURFACE 2310 10.75 2342 2342 0 0 PRODUCTION 7285 7 7322 6544 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6854-6874,6994-7014, 7032-7040,7042-7056 True Vertical Depth: 6176-6191,6284-6299,6313-6320,6321-6332 RECEIVED Tubing(size,grade,MD,and TVD) 3.5, L-80,6467 MD, 5884 TVD = °~^- - DE 2 2015 Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER 6", FHL 3.5"W/60K SHEA @ 6409 MD and 5841 TV C C SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none MAR Treatment descriptions including volumes used and final pressure: s NNEC �.r d i? i' `d 3 l u 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut in Subsequent to operation waiting fac hookup_ 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F' Exploratory IT Development F Service IT Stratigraphic 1"— Copies Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas 1- WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR WINJ IT WAG IT GINJ SUSP TT SPLUG r.- 17. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Jonathan Coberlya265-1013 Email Jonathan.Coberly(a'�.conocophillips.com Printed Name Jonathan Coberly Title Sr. Wells Engineer Signature Phone:265-1013 Date /2.2z.../5" //s//L RBDMSU-DEC 2 8 2015 Form 10-404 Revised 5/2015 _doe , ///- Submit Original Only KUP PROD • 3J-10 Cot ocoPhi1p5 91 i Well Attributes Max Angle&MD TD r Alaska Inc 1 Wellbore APIIUWI Field Name Wellbore Statusncl(°) MD(ftKB) Act Btm(ftKB) CanocoPta®1{s /500292146700 KUPARUK RIVER UNIT PROD 1 44.55 5,800.00 7,344.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 31.10,12/22/2015840.09 AM SSSV:NONE 110 3/24/2014 Last WO: 11/28/2015 32.99 12/10/1985 vedlcal schematic tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,091.0 12/16/2015 Rev Reason WORKOVER,GLV C/O,H2S lehallf 12/21/2015 Hanger;30.0 l`U,'°"'' Casing Strings III p Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ll.�,w CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 H-40 Welded I +'. Cas ng Deser prion OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Writ..(I .Grade Top Thread SURFACE 10 3/4 9.950 32.3 2,342.3 2,342.2 45.40 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 36.7 7,321.8 6,544.4 illi Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection CONDUCTOR;33.0-110.0 TUBING-RWO- 31/2 2.992 30.0 6,403.0 5,836.9 9.30 L-80 EVE Srd 2015 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 30.0 30.0 0.08 Hanger Tubing Hanger 3.000 SURFACE;32.3-2,312.3 6,390.4- 5,827.5 42.00 LOCATOR Baker Locator Sub 2.940 6,391.1 5,828.1 42.00 SEAL ASSY Seal Assembly"space out"...3-ft 2.980 GAS LIFT;2,4946 - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 3 1/2 2.992 6,395.1 6,467 05,884.5 9.30 L-80 ABM EUE Completion Details PillNominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 6,395.1 5,831.0 41.99 I PBR PBR w/SPACEOUT @ 6372' 2.970 GAS LIFT:3,688.1 11- 6,408.8 5,841.2 41.99 PACKER BAKER FHL Packer 6",FHL 3.5"w/60K Shea 2.992 IF6,459.7 5,879.0 42.03 NIPPLE CAMCO DS Nipple wINO GO PROFILE 2.812 12 6,466.5 5,884.1 42.041/LEG BAKER WIRELINE ENTRY GUIDE 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) CAS LIFT.46966 Top(ND) Top Incl Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) it I 7,100.0 6,367.1 37.08 FISH PIECE OF D&D HOLEFINDER SLIP,2.5"L X 1.3"W 10/23/2013 0.000 X.2"THICK Perforations&Slots GAS LIFT;5,6722 Shot Dens Top(ND) eta(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 1111 6,854.0 6,874.0 6,175.6 6,190.9 C-1,UNIT B, 11/1/2007 6.0 APERF 2.5"PJ HSD,60 deg ph 3J-10 6,994.0 7,014.0 6,283.5 6,299.1 A-3,3J-10 7/23/1988 8.0 RPERF 30 deg.ph;2 1/8" GAS LIFT;6,333.1 EnerJet 7,004.0 7,005.0 6,291.3 6,292.0 A-3,3J-10 4/10/1986 1.0 (PERF 4"Csg Gun Ultrapak IS 7,008.0 7,009.0 6,294.4 6,295.2 A-3,3J-10 4/10/1986 1.0 (PERF 4"Csg Gun Ultrapak 7,032.0 7,040.0 6,313.2 6,319.5 A-2,3J-10 7/23/1988 8.0 RPERF 30 deg.ph;2 1/8" EnerJet LOCATOR;6,390.4111 7,036.0 7,037.0 6,316.4 6,317.2 A-2,3J-10 4/10/1986 1.0 (PERF 4"Csg Gun Ultrapak 7,042.0 7,056.0 6,321.1 6,332.1 A-2,3J-10 4/10/1986 4.0 (PERF 90 deg.ph;4"Csg Gun SEAL ASSY;6,391.1 (( M J HJ II PBR;6,395.1 Mandrel Inserts PACKER;8,408.8 St all . on Top(ND) Valve Latch Port Sire TRO Run N Top(ftKB) (ftKB) Make Modal OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,494.6 2,494.4 Camco 'MMG 1 1/2 GAS LIFT GLV RK 0.188 1,228.0 12/11/2015 2 3,688.1 3,686.9 Camco MMG 1 1/2 GAS LIFT GLV -RK 0.188 1,229.0 12/11/2015 NIPPLE;6459.7 3 4,696.6 4,593.3 Camco MMG 11/2 GAS LIFT OV RKP 0.250- 0.0 12/11/2015 WLEG:6,466.5 II>� 4 5,672.2 5,302.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/27/2015 APERF;6,854.0-8,874.0- ` - 5 6,333.4 5,7852 Carom I MMG 11/2 GAS LIFT DMY RK 0.0001 0.0 11/27/2015 Notes:General&Safety End Date Annotation 7/25/2005 NOTE WAIVERED WELL:IA x OA COMMUNICATION 1/30/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic 9.0 RPERF;6,994.0-7,014.0- (PERF;7,004.0-7,005.0--. IPERF:7,008.0-7,009.0 RPERF;7,032.0-7,040.0----. (PERF;7,036.0-7,037.0- (PERF;7,042.0-7,056.0 • FISH;7,100.0 1 PRODUCTION:36.7-7,321.8 L ,:,:i., • • Operations Summary (with Timelog Depths) ,0 1 3J-10 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr), Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 11/23/2015 11/23/2015 14.00 MIRU MOVE MOB P Mobilize equipment from 3Q pad to 3J 06:00 20:00 pad.Rig on pad at 20:O0hrs. 11/23/2015 11/24/2015 4.00 MIRU MOVE MOB P Spot rig over well.spot pits and rig up. 20:00 00:00 Berm up secondary containment. 11/24/2015 11/24/2015 3.00 MIRU MOVE RURD P Continue to spot equipment and rig 00:00 03:00 up. Raise Derrick. Hook up inter- connect. Berm fuel tanks and cuttings box. 11/24/2015 11/24/2015 3.00 MIRU WELCTL RURD P Rig accepted at 03:00 hrs.Take on 03:00 06:00 sea water and install secondary valve on well head.RU lines to well. (SIMOPS: Bridle down. Rig up floor). 11/24/2015 11/24/2015 3.00 MIRU WELCTL MPSP P Pick-up Lubricator. Pressure test 06:00 09:00 same at 1,000 psi. Good. Pull the BPV. Lay down Lubricator and BPV. Tbg=350 psi, IA=350 psi,OA=390 psi. 11/24/2015 11/24/2015 1.00 MIRU WELCTL RURD P Hook up lines to the tree and the kill 09:00 10:00 manifold. 11/24/2015 11/24/2015 0.25 MIRU WELCTL SEQP P Pressure test kill lines at 250/3,500 10:00 10:15 psi. Good. Blow down lines. 11/24/2015 11/24/2015 0.25 MIRU WELCTL SFTY P PJSM. Discuss the hazards 10:15 10:30 assoicated with the well kill operations. 11/24/2015 11/24/2015 2.00 MIRU WELCTL KLWL P Circulate Well with 70 deg F.Sea 10:30 12:30 Water at 3.0 bpm/415 psi. Increase rate to 4.0 bpm/562 psi. Observed clean returns at calculated hole volume(201 bbls). Route returns to Pits and pump an additional 50 bbls.. Shut down pump. 11/24/2015 11/24/2015 0.50 MIRU WELCTL OWFF P Monitor Well Static. (SIMOPS...blow 12:30 13:00 down kill lines and choke manifold). 11/24/2015 11/24/2015 0.25 MIRU WHDBOP MPSP P Set BPV. 13:00 13:15 11/24/2015 11/24/2015 0.50 MIRU WHDBOP MPSP P Pressure test from below at 1,000 psi 13:15 13:45 x 5 minutes. Good. Record on chart. 11/24/2015 11/24/2015 1.25 MIRU WHDBOP NUND P Nipple down the Tree. Inspect hanger 13:45 15:00 threads. Install blanking plug(10 turns). 11/24/2015 11/24/2015 2.00 MIRU WHDBOP NUND P Nipple up BOP's 15:00 17:00 11/24/2015 11/24/2015 4.00 MIRU WHDBOP BOPE P Start initial BOP test.Test BOP's, 17:00 21:00 Annular Preventer and Choke Manifold 250/3500 psi.CMV 7,9,and 14 failed initial test.Perform AOGCC Koomey test and CPAI draw down Koomey test.Test witnessed by Matt Herrera,AOGCC Rep. 11/24/2015 11/25/2015 3.00 MIRU WHDBOP RGRP T Repair Choke valves 7,9,and 14. 21:00 00:00 Rebuild valves,replace all seals. 11/25/2015 11/25/2015 0.50 MIRU WHDBOP BOPE T Retest CMV 7,9 and 14.Valves 00:00 00:30 tested 250/3500 psi,all valves passed.Witness of retest waived by Matt Herrera,AOGCC Rep. 11/25/2015 11/25/2015 1.50 MIRU WHDBOP MPSP P Pull Blanking plug and BPV. BOLDS. 00:30 02:00 Pick up landing joint and prepare to pull Hanger. Page 1/5 Report Printed: 12/18/2015 • Operations Summary (with Timelog Depths) 4 3J-10 ConocoPhilhps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 11/25/2015 11/25/2015 0.75 COMPZN RPCOMP PULL P Attempt to pull Seal assembly free 02:00 02:45 from the PBR.Max pull 125K,would not pull free.Leave string in tension for 5 minutes and then work string 50K SOW to 125K PUW. 11/25/2015 11/25/2015 6.75 COMPZN RPCOMP ELNE T Wait on Schlumberger DSL Unit. All 02:45 09:30 logging crews timed-out until 06:00 hrs. (SIMOPS load and process Drill Pipe. Order out fishing tools,Top Drive inspection,housekeeping). Set Slips with 20K over string weight...install 3 1/2"TIW Valve. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP ELNE P Schlumberger DSL arrive on location. 09:30 10:00 PJSM on rigging up. 11/25/2015 11/25/2015 3.75 COMPZN RPCOMP ELNE P Spot equipment and rig-up. PJSM on 10:00 13:45 picking up the lubricator and discuss special concerns with the String Shot and Chemical Cutter tools. Continue with rig up and picking up tool string. 11/25/2015 11/25/2015 2.75 COMPZN RPCOMP ELNE T Make-up 10-ft String Shot. Stab 13:45 16:30 Lubricator on Well. Pressure test at 500 psi. Good. Run in with String Shot(10-ft)Tool String. Drop down below the Tubing Patch(6,301'- 6,310')to 6,336-ft. Log back up across GLM#5 to 5,657-ft. No correction needed. Drop back down below the Tubing Patch. Re-log across the tubing Patch. Good. Continue up hole and straddle the cut target at 6,280-ft with the String Shot. Attempt to fire String Shot...however,unable to arm do to low signal. POOH to investigate. 11/25/2015 11/25/2015 1.50 COMPZN RPCOMP ELNE T Repair wire,cut 20'off and tie new 16:30 18:00 head on. 11/25/2015 11/25/2015 3.00 COMPZN RPCOMP ELNE P Run in the hole with string shot. Log 18:00 21:00 and correlate string shot 6,273'to 6,283'.CCL to top 11.6',CCL stop depth 6261.4'.String shot fired,POOH for Chem cutter. 11/25/2015 11/25/2015 2.50 COMPZN RPCOMP ELNE P Run in the hole with Chem cutter.Log 6,280.0 6,280.0 21:00 23:30 and correlate Chem cutter.Chem cut at 6,280'.CCL to cutter 27.6',CCL stop depth 6,252'4'.Chem cutter fired. String held in tension 20K.String bounced in the slips when Chem cutter fired,good cut.POOH 11/25/2015 11/26/2015 0.50 COMPZN RPCOMP ELNE P Rig down DSL and prepare to pull 6,280.0 6,280.0 23:30 00:00 Hanger to the floor. 11/26/2015 11/26/2015 1.00 COMPZN RPCOMP CIRC P Pull Hanger to the floor and circulate 6,280.0 6,280.0 00:00 01:00 surface to surface. 11/26/2015 11/26/2015 7.00 COMPZN RPCOMP PULL P Single down 3 1/2"GL completion. 6,280.0 0.0 01:00 08:00 Recovered 195 Jt 3 1/2"Tubing,5 GLM, 1 Nipple Assembly,3 1/2"cut- off stub OAL=14.36-ft). (the chemical cut was textbook perfect). Page 2/5 Report Printed: 12/18/2015 I g • • Operations Summary (with Timelog Depths) 3J-10 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P T-X Operation MKS) End Depth(ftKS) 11/26/2015 11/26/2015 1.25 COMPZN RPCOMP RURD P Rig down Weatherford tubing handling 0.0 0.0 08:00 09:15 equipment. Clear floor. Install Wear Bushing. Prep to run 3 1/2"Drill Plpe. 11/26/2015 11/26/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Discuss the hazards 0.0 0.0 09:15 09:30 associated with picking up Drill Collars and Drill Pipe. Review the make-up order of BHA#1. 11/26/2015 11/26/2015 1.25 COMPZN RPCOMP BHAH P Make-up BHA#1 as follows: Cutlip 0.0 226.0 09:30 10:45 Guide,5 3/4"Overshot,Extention,Top Sub,Bumper Sub,Oil Jar, Pump-Out- Sub,6 ea x 4 3/4"Drill Collars, Intensifier. 11/26/2015 11/26/2015 5.25 COMPZN RPCOMP PULD P Single in BHA#1 with 3 1/2"Drill Pipe 226.0 6,185.0 10:45 16:00 from the Pipe shed. Establish parameters as follows: Up weight, 130K. Down weight, 112K,SPR Pump#1 at 2.0 bpm/164 psi and at 3.0 bpm/292. SPR Pump#2 at 2.0 bpm/162 psi and at 3.0 bpm/298 psi. RTW at 15 rpms=120K. Blow down Top Drive. 11/26/2015 11/26/2015 0.50 COMPZN RPCOMP FISH P Continue in to the top of the 3 1/2"cut- 6,185.0 6,273.0 16:00 16:30 off tubing stump. Tag at 6,273-ft dpmd. Plant Overshot. Break out Top Drive. Install TIW Valve. Make-up Top Drive. 11/26/2015 11/26/2015 4.75 COMPZN RPCOMP JAR P Jar Seals free from the PBR at 6,395- 6,273.0 6,273.0 16:30 21:15 ft. Firing Jars at 160K(30K over). Straight pull up to 170K(40K over). Seals pulled free from PBR 170K straight pull weight.PUW 140K after pulling Seals free. 11/26/2015 11/26/2015 2.00 COMPZN RPCOMP CIRC P Circulate 2 surface to surface at 5 6,273.0 6,273.0 21:15 23:15 bpm to clean out top of PBR. Recovered a fair amount of formation sand...! 11/26/2015 11/27/2015 0.75 COMPZN RPCOMP PULD P POOH laying down 3 1/2"drill pipe 6,273.0 5,100.0 23:15 00:00 and fish(Seal assembly). 11/27/2015 11/27/2015 5.50 COMPZN RPCOMP PULD P POOH laying down 3 1/2"drill pipe 5,100.0 0.0 00:00 05:30 and fish Seal assembly. 11/27/2015 11/27/2015 6.00 COMPZN RPCOMP OTHR P Load and process new 3 1/2"GL 0.0 0.0 05:30 11:30 Completion into the pipe shed. Load Seal Assembly and GLMs in their proper running order. Perform the final jewelry inspection. 11/27/2015 11/27/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Discuss the hazards 0.0 0.0 11:30 11:45 associated with running the completion. Review the final completion running order. 11/27/2015 11/27/2015 7.25 COMPZN RPCOMP PUTB P Single in with the 3 1/2"Completion as 0.0 6,369.0 11:45 19:00 per the designed program. 11/27/2015 11/27/2015 1.00 COMPZN RPCOMP PUTB P Pick up joints#196, 197 and 198. 6,369.0 6,369.0 19:00 20:00 Make up circulating head on joint#98 for Space Out. 11/27/2015 11/27/2015 0.50 COMPZN RPCOMP HOSO P Tag Locator sub at 9'on joint#198, 6,369.0 20:00 20:30 6,391'.Tag bottom of PBR at 19.82' on joint#198 Space Out 3',6,403'. Lay down joints#198, 197,and 196. Pick up two 10'pup joints and Joint #196.Locate Seals in PBR at 6403'. Page 3/5 Report Printed: 12/18/2015 • • Operations Summary (with Timelog Depths) x„ 3J-10 CorcoPhititps , Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth, Start Time End Time Dur(hr.) Phase Op Code Activity Code Time P-T-X Operation MftKB)', End Depth MKS) 11/27/2015 11/27/2015 1.00 COMPZN RPCOMP THGR P Pick up GEN IV FMC Hanger and 20:30 21:30 Make up per FMC Rep. 11/27/2015 11/27/2015 1.25 COMPZN RPCOMP CRIH P Pump 225 bbls of Corrosion Inhibited 21:30 22:45 seawater down the backside taking returns to the pits.Pump 7 bbls of seawater from the pits to clear lines. 11/27/2015 11/28/2015 1.25 COMPZN RPCOMP THGR P Attempt to land Tubing Hanger,PBR 22:45 00:00 sanded off,start pumps and ease down slowly washing down.Wash down through sand and landed Hanger,RILDS.(will note Sand in the PBR on Handover form). 11/28/2015 11/28/2015 1.25 COMPZN RPCOMP PRTS P Pressure test the tubing to 3,000 psi 00:00 01:15 for 15 minutes,test good.Bleed tubing pressure to 1,500 psi and pressure IA to 2,500 psi for 30 minutes,test good. Shear open the SOV at 1,850 psi. 11/28/2015 11/28/2015 1.00 COMPZN WHDBOP MPSP P Lay down landing joint and install IS-A 01:15 02:15 BPV.Pressure test to 1,000 psi for 5 minutes,test good. 11/28/2015 11/28/2015 3.75 COMPZN WHDBOP NUND P Nipple down BOP's and set back on 02:15 06:00 stump. 11/28/2015 11/28/2015 2.00 COMPZN WHDBOP NUND P Nipple up Adaptor flange and Tree. 06:00 08:00 11/28/2015 11/28/2015 0.50 COMPZN WHDBOP PRTS P Pressure test Hanger void at 08:00 08:30 250/5,000 psi. Good. 11/28/2015 11/28/2015 1.50 COMPZN WHDBOP PRTS P Set test Plug. Pressire test tree at 08:30 10:00 250/5,000 psi. Good. Pull Test Plug. 11/28/2015 11/28/2015 0.25 COMPZN WHDBOP SFTY P PJSM with Lil'Red. 10:00 10:15 11/28/2015 11/28/2015 1.25 COMPZN WHDBOP FRZP T Bring Lil' Red on line with diesel down 10:15 11:30 the IA...taking returns up the tubing at 1.0 bpm. Pressure gradually climbed up and rate as rate decreased. 0.3 bpm at 2,100 psi.after 18 bbls away. (suspect SOV not sheared all the way open or trash?). Shut down and bleed off pressure. Swap manifold around and pump down the tubing...taking returns from the IA. 2.0 bpm/800 psi x 10 bbls pumped. Good returns. Swap back around to pump down the IA. 11/28/2015 11/28/2015 1.25 COMPZN WHDBOP FRZP P Bring Lil'Red pump on line at 1.5 11:30 12:45 bpm/400 psi. Good returns from the IA. Increase rate to 2.0 bpm. Continue pumping diesel freeze protect with no further problems. Final 2.0 bpm/1,400 psi x 75 bbls pumped down hole. 11/28/2015 11/28/2015 1.00 COMPZN WHDBOP FRZP P Rig down Lil'Red. U-Tube diesel 12:45 13:45 freeze protect. Page 4/5 Report Printed: 12/18/2015 • • Operations Summary (with Timelog Depths) : 3J-10 ConocoPhitliips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time ` End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS); 11/28/2015 11/28/2015 2.25 COMPZN WHDBOP MPSP T Attempt several times to set BPV. No- 13:45 16:00 Joy. Suck out the fluid from the Tree. Observe a piece of metal across the Tubing Hanger. Further investigation reviled that FMC Serviceman failed to pull the Tree Test Plug even though he thought he did. By attempting to set the BPV the Tree Test Plug was damaged and presently it can not be retrieved. Discuss a path forward with Anchorage Engineer and Supervisor. Secure Well and prep to move off. 11/28/2015 11/28/2015 2.00 DEMOB MOVE MOB P Prep to rig down and move. Rig 16:00 18:00 Released at 1800 hours. Page 5/5 Report Printed: 12/18/2015 tc5-25o hETEMVED 254 � 1 WELL LOG TRANSMITTAL FEB 13 2015 DATA LOGGED� AOGCC M.KK.0 BEND ER To: Alaska Oil and Gas Conservation Comm. February 11, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3J-10 SCANNED 1/14 4^ 1()1 Run Date: 2/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3J-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21467-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: l' Aiza-0?-0-0 6-emzeet Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_ (~,,.~'- ~~ Well History File Identifier Organization (done) /Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [3 Diskettes, No. [3 Maps: Grayscale items: [3 Other, No/Type [] Other items scannable by large scanner Poor Quality Originals: ~ OVERSIZED (Non-Scannable) Other: [] Logs of various kinds (~ D Other TOTAL PAGES: (~ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL~OWELL Project Proofing By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: lei ~ /~ (at the time of scanning) PAGES: SCANNED BY; BEVERLY BREN VINCE~ARIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; PAGES: (~** '~ .--J2~'"--" Quality Checked (done) RevlNOTScanned.wpd T ~c~~t~ergr Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Weil Job # /~ f/~--- 08/06/08 N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ~~• ~ ~ ~~ G ~~ _~ ~~(~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 1A-22 12097412 GLS - (p'~ 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23/08 1 1 1A-22 12097413 PROD PROFILE - '~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE ~ / 07/24/08 1 1 1A-25 11996648 PROD PROFILE - i 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26/08 1 1 1 E-112 12080408 INJECTION PROFILE .. 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE - 07/28/08 1 1 3J-10 12097408 SBHP SURVEY - 07!20/08 1 1 3M-28 12097411 SBHP SURVEY L .• Q 07/21/08 1 1 1 L-15 11982443 PROD PROFILE 07/06/08 1 1 30-08A 12080407 SBHP SURVEY ~Cr IOj~} -193 (lp~' 07/26/08 1 1 30-09 12080406 SBHP SURVEY /(p°~-~~ 07/26/08 1 1 1 L-24 11978468 PRODUCTION PROFILE 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -OV 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 iH~. `6 12100434 INJECTION PROFILE uZ.C.. / "~ {0 08/03/08 1 1 UGNU DS2-OBi 11996650 TEMPERATURE LOG ~ - 07/27/08 1 1 2X-14 12100432 LDL 6 - 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08!04/08 1 1 iH-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~~ }}yy ~y ~, ~-, 1s. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~ ~~~~ ~ ~ Z~Q~ Well Job # Log Description N0.4513 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken l ~~~ 333 West 7th Ave, Suite 100 ~„~ ~ Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2N-310 11839685 PERF RECORD/SBE1P_SURVEY.:,..~1r~ ~e~.r.~~a«.x..~^ 11/17/07 1 2Z-01A 11837536 PRODUCTION PROFILE ~~)~;j`;?_.-",,¢ = 11/16/07 1 3R-14 11839686 LDL d~=~. `~) ---~-ca~'~~'~~~ 11/18/07 1 2M-10 11839687 PRODUCTION PROFILE ~=~ "~~ ~ 11/19/07 1 3J-10 11837539 PRODUCTION PROFILE ~ ~'~ °~•`;t ~"~' 11/19/07 1 2A-20 11839688 INJECTION PROFILE -.,°.~'4 e~'+,-;~" .- `"~ ~ 11/24/07 1 11 /26/07 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907j 561-8317. Thank you. -,.~~~ ~ ~~~ STATE OF ALASKA RECEIVEQ Nav 2 s 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ska Oil & Gas Cons. Commission f ___l _. 1. Operations Pertormed: Abandon ^ Repair Wel{ ^ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended WeII ^ 2. Operator Name; 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 185-250 f 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21467-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 74' - 3J-10 8. Property Designation: 10. Field/Pool(s): ADL 25630 ALK 2563 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7344' ~ feet true vertical 6562' ~ feet Plugs (measured) Effective Depth measured 7134' feet Junk (measured) true vertical 6394' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 2268' 10-3/4" 2342' 2342' PROD. CASING 7248' 7" 7322' 6545' Pertoration depth: Measured depth: 6854'-6874', 6994'-7014', 7032'-7040', 7042'-7056' true vertical depth: 6176'-6191', 6283'-6299', 6313'-6320', 6321'-6332~!~~~~;) ~OV ~ g Z~~~ Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 6466' MD. Packers & SSSV (type & measured depth) Baker FHL Baker pkr @ 6408' Camco'DS' nkpple @ 485' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 605 1207 1140 -- 137 Subsequent to operation 360 780 1293 - 126 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run ~ Exploratory ^ Development ~ Service ^ Daily Report of Wefl Operations _X 16. Well Status after work: OiIO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Sch Title Wells Group Engineer Signature'' Phone Date jj,- Z1 ~~ ~- Pre a Sh ro Alls -Drake 2 3-461 Form 10-404 Revised 04/2006 ,~~~~~ i~~i}I c~j ~~~ ~~~~ •'" it(~~ Submit Original Only 3J-10 Weil Events Summa • ry DATE Summary 10/27/07 Perform N2 fill clean out, Cleaned out from fill tag of 7034 CTMD to hard tag of 7198 CTMD (150' below bottom perfs). Freeze protected well, Turned over to DSO. 10/28/07 GAUGE TBG TO 2.79" 8~ TAG FILL @ 7134' SLM. NO SAMPLE. DRIFTED TBG WITH 2.72" X 16.5' DMY DRIFT. ***NO OBSTRUCTION'S"**. JOB COMPLETE. 10/31/07 PRESSURE AT 6752' WAS 3024 PSI. PRESSURE AT 6619' WAS 2986 PSI 11/1/07 SHOT 2 1/2" POWERJET HSD GUN FROM 6854'-6874' • Y-~..,_ ~ KRU 3J-10 ~~n~cfl~'t~allips ~4i~s~~, lnc. 3-1,- ~ ---- _ -- _-. API 5t1U~J214670Q Well T e: PROD An le a~ TS: 40 de a) 6817 TUBING _ i SSSV Type: NIPPLE Orig 12/10/1985 Angle @ TD: 37 deg @ 7344 (a~sass' OD:3.500, f Com letion: iD:z.9sz) --m Annular Fluid: Last W/O: 7/20/2005 Rev Reason: TAG PERF ~ -~ Reference Lo Ref Lo Date: Last U dater i 1/6/2007 _ Last Tag: 7134' SLM TD: 7344 ftK6 -a Casing String -ALL STRINGS Descn Lion Size To _ _ _ __ B©ttom TVD VYt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 10.750 0 2342 2342 45.40 J-55 v ..~ '' ~' ~'' PR_ OD. CASING - .__ .Tubing String -TUBING Size Top 3 500 0 .Perforations Summary interval TVD 7.000 0 Bottom TVD 6-166 5881 Zone Status Ft 7322 PF 6545 26.00 J-55 _ Wt Grade Thread J '~_~0 ~ L 8p A6M EUE I Date T Comment --- ~ 6854 - 6874 6176 - 6191 C-1,UNIT B 20 6 11!112007 APERF 2.5" PJ HSD, 60 deg ph ;~ 6994 - 7004 6283 - 6291 A-3 10 8 7/23/1988 RPERF 30 de h• 21/8" EnerJet 7004- 7005 6291- 6292 A-3 1 9 7/23/1988 RPERF 30 de h' 2 1/8" EnerJet 7005 - 7008 6292 - 6294 A-3 3 8 7/23/1988 RPERF 30 de h' 21/8" EnerJet 7008 - 7009 6294 - 6295 A-3 1 9 7/23/1988 RPERF 30 de h' 2 1/8" EnerJet -_1 ,, 7009 - 7014 6295 - 6299 A-3 5 8 7/23/1988 RPERF 30 de h' 21/8" EnerJet 7032 - 7036 6313 - 6317 A-2 4 8 7/23/1988 RPERF 30 de h' 21/8" EnerJet ~,? 7036 - 7037 6317 - 6317 A-2 1 9 7/23/1988 RPERF 30 de h' 2 1!8" EnerJet 7037- 7040 6317- 6320 A-2 3 8 7/23!1988 RPERF 30 de h; 2118" EnerJet 7042 - 7056 6321 - 6332 Gas Lift MandrelsNalves St MD TVD Man Mfr A-2 Man Type Mfr 14 4 4/10/1986 (PERF 90 deg. ph; 4" Csg Gun HJ II _ _ V Type V OD Latch Port TRO Date Run VIv Cmnt 1 2401 2401 CAMCO MMG GLV 1.5 RK 0.188 1270 8/10/2005 2 3606 3605 CAMCO MMG GLV 1.5 RK 0.250 1305 8/10!2005 3 4291 4255 CAMCO MMG GLV 1.5 RK 0.250 1295 8/10/2005 4 4758 4641 CAMCO MMG OV 1.5 RK 0.250 0 8/10/2005 5 5720 5336 CAMCO MMG DMY 1.5 RK 0.000 0 7/20/2005 6 6336 5787 CAMCO MMG _ DMY 1 5 RK 0.000 0 7/31!2005 - , 1~ ~1 ~ ~ Perf (6994-7014) Perf (7004-7005) General Notes Pert (7032-7040) Pert (7036-7037) Pert Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~.. _~ . -... NO. 4482 n ,ti ,a j ~~ 1171)1 ~~~ N~~ ~ ~ 2007 Log Description -l ~ ~ ~~Date 11 /07/07 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk a~J ~~ ~~ v 3 BL Color CD 3J-10 11850465 SBHP SURVEY / ~ 10131/07 1 18-08A 11839682 INJECTION PROFILE Z, - 10131107 1 1D-01 11846458 LDL 11/01/07 1 2A-15 11846459 PRODUCTION PROFILE 5 - 'L (0 11102/07 1 1E-02 11850470 PRODUCTION PROFILE ff °t~s 11/04/07 1 2N-310 11745242 SCMT 11/04107 1 1E-119 10687772 OH LDWG EDIT d} ~f 04/08/04 1 1E-119 10687772 CMR ~pL - 04/08/04 1 1 E-119 10687772 MDT 04/08/04 1 C. • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ) ) Howard Gober Wells Engineer Drilling & Wells Conocó'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4220 September 9, 2005 '12'P"'~: ""':, (~, II.:.. ¢' ~, ~,;;-(:,,,,,,,, . ß::~, 1~ ~ ~1" J ~:: S£ ,," !¡,;>' ''',','''''''' P " H ' '"':>."" II:) 10 "" . .~ ¿ D5 011& Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3J-1 0 (185-250) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the Kuparuk well 3J-10. If you have any questions regarding this matter, please contact me at 263-4220. Sincerely, .~ Howard Gober Wells Engineer CPAI Drilling and Wells RBOMS Bf:L rl SEP 1 9 2005 HG/skad ,-, r' ¡ 'Ì\..' '\ i E- ¡~ (\ ED -1 c,¡ ';' 0 (J r '~v,¡"'d~." t).J r -~. (, --' .) ,(::;ElVED SEP 1 2 2005 REPORT OF SUNDRY WELL OPERA TION:§ildir,<,:;i nil i~~~ C:1~\~ C"m.71I;....~'.~,' D D ' ,.!~.!oJ! 1!i~r.;¡."II'!,Jf,I! Abandon Repair Well Plug Perforations 0 Stimulate D Other "t::,.:nc;J,ÇI¿UlG Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D "J, Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPh ill ips Alaska, Inc. Development 0 Exploratory D 185-250 1 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21467-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 74' 3J-10 1. Operations Performed: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 8. Property Designation: ADL 25630, ALK 2563 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 7344' feet true vertical 6562' feet measured 6772' feet true vertical feet Length Size MD 110' 16" 110' 2268' 1 0-3/4" 2342' 7248' 7" 7322' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 2342' 6545' Measured depth: 6994'-7014',7032'-7040',7042'-7056' true vertical depth: 6283'-6299',6313'·6320',6321'·6332' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6446' MD. Packers & SSSV (type & measured depth) Baker FHL Baker pkr @ 6388' Cameo 'OS' nipple @ 465' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 318 242 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 697 1695 624 2183 15. Well Class after proposed work: Exploratory D Development 0 Service D Tubinq Pressure 147 148 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C,O. Exempt: Contact Printed Name Signature WDSPL D Howard Gober @ 263-4220 Howard Gober Jl3vJæ¡ Title Phone Wells Group Engineer Date Preoared bv Sharon Allsuo-Drake 263-4612 Form 10-404 Revised 04/2004 Submit Original Only ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-10 3J-10 WORKOVER/RECOMP n3scm@conocoph¡llips.com Nabors 3S Frq.t6:~"'blTlòlJrs · ¡~qd~ ::¡~ô~bê 7/8/2005 13:00 - 16:00 16:00 - 18:00 18:00 - 00:00 7/9/2005 00:00 - 02:00 02:00 - 04:00 3.00 MOVE MOVE MOVE 2.00 MOVE RURD MOVE 6.00 MOVE RURD MOVE 2.00 MOVE RURD MOVE 2.00 MOVE RURD MOVE 04:00 - 06:00 2.00 WELLSR PLGM DECOMP 06:00 - 08:00 2.00 WELCTL KILL DECOMP 08:00 - 10:30 2.50 RIGMNT RGRP DECOMP 10:30 - 14:30 4.00 WELCTL KILL DECOMP 14:30 - 17:00 2.50 RIGMNT RGRP DECOMP 17:00 - 20:30 3.50 WELCTL KILL DECOMP 20:30 - 23:00 23:00 - 00:00 7/10/2005 00:00 - 14:00 14:00 - 16:30 16:30 - 18:00 7/11/2005 18:00 - 19:00 19:00 - 23:00 I 123:00 - 00:00 I ¡ 00:00 - 06:00 I 106:00 - 19:00 : 19:00 - 22:15 22:15 - 00:00 2.50 WELCTL KILL DECOMP 1.00 WELCTL KILL DECOMP 14.00 WELCTL KILL DECOMP 2.50 WELCTL KILL DECOMP 1.50 WELCTL OBSV DECOMP Start: 7/8/2005 Rig Release: 7/20/2005 Rig Number: Spud Date: 11/27/1985 End: 7/20/2005 Group: '."'.:. "'.."' :" :", "." "'::. ,"", ::: '"':.' :".:":,":: .:....::: :"::.: =.: , .... {þ~~ctjptiòhl()f··gAøré1~jþ,,~i· Begin moving from 3F-09 to to 3J-10. Arrive location. Begin spotting up equipment. Hot oil on location pumping last of hot seawater/surfactant well flush. 290 bbls circulated down tubing up IA. Layed herculite, spotted rig over well. Moved pits and pipe shed into place. Continued rigging up. Accepted rig @ 00:01 7/09/2005 Begin offloading 200 bbls 12.5# brine into pits; mixing 30 bbl viscous brine pill in pill pit. Rig up hardline to return tanks and rig up lines to tree to circulate well to kill. Move lubricator to rig floor, pull BPV through tree. PfT hardline to tanks to 1000 psi -- good. Begin pumping well kill Rig pump will not work properly waiting on repairs also one Cat engine is down. Pumped well kill with 30 bbls Vis. Pill followed by 12.5 ppg brine injected 30 bbls of brine to cover perfs. 12.1 ppg brine back to surface lost pump again. Shut down to repair problems. Working on rig mud pump Brine wgt coming up light, 11.8#. Salt falling out of brine, see Irg. amount in pit trough. Begin circulating at max rate 4 bpm, holding 30 psi backpressure. Circulating in 12.5# from pits, out consistent 11.8#. Salt plugging pump screens; shut down to clean, and install larger screens. Lost 8 bbls over 30 mins; open choke fully. Only dropped circ. press 10 psi. Drop pump rate to 3.5 bpm, rtns 1: 1. In 12.1 ppg, out 12.4 ppg. Continue to circulate. Have consistent 12.2# brine at the pits; shut down to monitor. Have 60 psi tubing and casing pressure. Come back online to circulate, discuss w/ mud engineer. Circulating well continue to lose brine weight. Order new Sodium Bromide brine 400 bbls to replace Formate Circulated in new 12.4 ppg; took returns to the pits and returning old brine to MI plant in Prudhoe to analyze problem with solids suspension. Quit circulating and monitor well. Well is stable, 0 psi on IA and tubing. 1.00 WELLSR PLGM DECOMP Install BPV 4.00 WELCTL BOPE DECOMP ND tree, install blanking plug and NU BOPE. NOTE: State witness of BOP test waived by John Crisp yesterday afternoon. Begin testing BOP stack - BOPE to 250/4000 psi Annular to 250/2500 psi DECOMP Tested BOPE to 250/4000 psi, annular 250/2500 psi. DECOMP i Could not pull blanking plug through stack because of offset hanger. . ND BOP stack and removed blanking plug. NU BOP stack again, pulled BPV, and ran tree test plug to test flange break. Pulled tree test plug. Tied in to Hanger with 2-7/8 EUE landing joint and pulled hanger I : free 60K up weight. 3.25' FISH : PULL DECOMP Rigging up ESP cable spooler; start pulling 2 7/8 completion. Fluid level stabilizing at roughly ground level. Work ESP cable to spooler. Begin : pulling pipe, monitoring fluid level. Small amount of gas breaking out of fluid. 1.75' WELCTL CIRC 'DECOMP' Shut down to thread/wrap cable into spool on unit. Substantial amount . of gas breaking out; take advantage of downtime to perform BOP drill 1.00 WELCTL BOPE DECOMP I 6.00 II WELCT~ BOPE 13.00 WELCTU, BOPE Printed: 8/29/2005 3:15:04 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . .:.' .": :":: . . :." ..: . :"." ::': ,". .... .. :':". ".". .: ....... ...... .... . .... ..' .... . ... ..... ... ...... .. ..... ...... .... . .. ..... ... ..... ... .... ....... ... . ,".. ...... . ...... ': ':":' .. .. ....... ........ .. .,',',',' ., ,. .'., .... ,.. .. . '.. ... .. ... '.", .. . .... .. ..' ",.. ..... ..... ....... .... . .... .. . .. ., .. ... ... ..,. .' . .. .. . .. .... .... .... .. ...... .. . . .. ....... .. ." ... .. .......... . .... ,". . ......... .. . . ... .., . .. ... ...". . , .. '.' .... .. .. .. . . . ..... . ... .. .... .. ... ",.,. '. ... . '. ..",. .. . .. ... ...... ..'....:.. :CQnôcppHiHipSA....::.lå... S.<i<. ê!'.' '.. ...... .... o. '..: ..:.:........... '. '.' ..' '. '.:. ..... ....,. '..: ." .... .. ....:: .. ....... . ... .. ... .. . . ," ... ...... . . .. . . ..... . .. . - . . .." ...... ... . ....... ". . .... .. ..' . ....... .. .... ......" . .. . ............ . .. . ...... .. ". . .... . . ..... ". .... .......... ... '.. .. ." .'. ..... ........ . ... ....... . ..... .... .. ...... ...". .. . . .. . .. . ... ." .... . ..". ... . . ... ..... ··9p~~~~iQ!Ø~i~ijmrn'~·rM·..~~pc)~·: 3J-10 3J-10 WORKOVER/RECOMP n 3scm@conocophillips.com Nabors 3S Start: 7/8/2005 Rig Release: 7/20/2005 Rig Number: Spud Date: 11/27/1985 End: 7/20/2005 Group: :.': :'.,. ":". :":":": ................. .. . .. . . . .... . . .. . . ,. ... ..... . .. .'. . .......... .. ...... .. . .... .. .".... .... ... pøsprm~iþn8fppêråtjpH§·. .. .. From;'Tp HOl.lrsCode·. 7/11/2005 7/12/2005 22:15 - 00:00 00:00 - 01 :30 01 :30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 08:30 08:30 - 18:00 18:00 - 00:00 7/13/2005 00:00 - 01 :00 01 :00 - 06:00 06:00 - 16:00 16:00 - 19:30 I i , 19:30 - 21 :00 ,21 :00 - 00:00 7/14/2005 00:00 - 01 :30 1.75 WELCTL CIRC DECOMP and circulate out gas. 1.50 WELCTL CIRC DECOMP Resume pulling completion. 6 jts out, well started flowing. Stab floor valve, rig lines to circulate, come online with pumps circulating bottoms up monitoring brine wgts. See light spots in brine (12.3-12.5 ppg). Shut down and check for flow. 2.50 WELCTL CIRC DECOMP Fluid swapping out of tubing, seems to have stabilized. Resume pulling pipe. Well still flowing slightly, 3 bbl gain in 15 mins, small amout of gas breaking out. Rig up to circulate again, close bag and bullhead 30 bbls into formation. Resume circulation @ 4bpm- cont. until brine wgt is consistent 12.5 ppg. 1.00 WELCTL OBSV DECOMP Shut down, check for flow. Well still wanting to flow. OA has 600 psi, begin bleeding off. No change in flowrate, approx. 16 bph. Possibly gas leaking from OA leaking into IA or insufficient brine wgt. 1.00 WELCTL CIRC DECOMP Circulating @ 3 bpm; OA has 250 psi- still bleeding. Rig hardline back up from OA to tiger tank to bleed quicker. 2.50 WELCTL OBSV DECOMP Casing pressure bled off; stop circulating and monitor well. Still flowing. Attempt to shut annular to get pressure, bag will not seal around cable. Pull pipe out of hole to next cable clamp. Cut cable and lower back below stack. Close annular and monitor well. 9.50 WELCTL OBSV DECOMP One hour shut-in. Well showing 20 psi SIDP, 20 psi on casing. Discuss options with M-I and Wells Engineer. Opened well up thru choke, checking for breathing, press bled down to 10 psi, flowed back 2 bbls in 20 min 4 bbls in 1 hr. Shut in, waiting of new fluid. Well showing 20 psi SIDP 40 psi on casing. 6.00 WELCTL CIRC DECOMP 100 bbls 2# biozan on location. Begin mixing into brine system while circulating. Once we had viscisified brine back to surface, shut down to monitor well for 10 mins. Well stabilized at 20 psi SIDP 1 20 psi on casing. Resume circulation @ 1.75 bpm (losing fluids at higher rates), adding calcium carbonate to bring wgt up to 12.7 ppg. 1.00 WELCTL OBSV DECOMP 4 bbls loss, drop rate to 1.5 bpm. Finish circulating/mixing viscosified 12.7 ppg brine. Stop pumping, begin monitoring for flow. Begin re-threading ESP cable over sheave to spooler while waiting. 5.00 FISH PULL DECOMP Well not flowing; fluid level has settled about mid-stack. Rig up to resume pulling completion. Begin pulling pipe, pumping hole fill every 10 jts. laying down 2-7/8" tubing and spooling up ESP cable. 10.00 FISH PULL DECOMP Continue pulling out of hole laying down the 2-7/8" tubing, pups and jewelry, and spooling up ESP cable. While pulling completion the fluid loses were approx. 1/2 bbl per 10 jts pulled. 3.50 WELCTL OBSV DECOMP When pulled and layed down last GLM checked hole fill and fluid level was slowly rising instead of losing fluid. Pulled one more jt and Baker I Century Guage and check well again. Well was flowing down flow line I very slow. Installed GLM with open pocket and ran back in hole below I surface and shut well in. Total pit gain was 8 bbls. in 45 min. SIDPP- i ! 20 psi SICP - 40 psi. 1.50 I WELCTLJ OBSV I DECOMP : Confer with Engineer/Wells Team Ldr.l State Reps. Flow back 15 bbls I (F/L volume 4 bbls) and monitor rtns. Flow Rate 1 bbl 1 3 mins, let flow ¡ for 15 bbls. ..no change, fluid consistent 12.7 ppg. Shut well back in to : monitor. 3.00 WELCTL KILL DECOMP SIDP press=50 spi, Casing press=70 psi. Chain down tbg at rig floor as . precaution, close upper pipe rams and bullhead 33 bbls 12.7# brine into I well ~t 0.8 bpm, 200 psi casing press. Shut down to let bleed off / mOnitor. 1.50 WELCTL KILL DECOMP Casing pressure 35 psi. Begin pumping 14.4 ppg biozan/calcium Printed: 8/29/2005 3:15:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') .. .. ...... . . ..... .. . ... .. . ".' . . .. .. .. . . .. . . '. ....... .... ..... .. ... .. . .. '. .... . . .. .. .' .. ..' ...... .." ....... .. . ." . .. "... ..... ". . "., : ..... ". ...... .::" :.......: . .. 0" ., ." . .. .... .. '. .. ..... . .. ...: : :... ...: ."::.:: ":.: .:.: . "., ..... ...' ... . ... ...,.. . .. ..' . . . ",. .... . .. ... . .. . .. .' ...... ......... ....... .... .,....,... ...... ..... ". ................. ....: . :". ".' . ..', , ,'.', "".: :........,. . ,.. .", ... . ." '". . . . . .:> · ...» '.. ····¢:Q!nþêoRhillipsÂI~$ké('<\/ .... :.... .'.. ..'.' .,." ..' ..' . .....,. ..' .,'., ..,", .,.........,... ........... .. ......,....,.., ....,. .". ...............,.. ., ...,.....,...... ...........,.., .. ......... .. 0.. .' .. . . . . . . . ... . . ......... . . . .. . . . . . . . . . . . . . ... ...... .. .: . '. '." . ....".. .... .. :.... ... ....... ":". :: :." . .'. . .'. ,'.,...'....'..,....,....,:..:, '.'. ....., :. ',':.'. '.'.....,'.:...:.".'....".:.: .'. ':,.:,....::.'.,'..,'. '.". .:'.':..'.: '.",..":,.:."':.",'::..,":. ':',.,',..:.',.,..'"...."...'...','.'".:.:......':...... .. ¡}:ºp~r:~~i9P~,$~mtJ1~rx¡'·,~~pöij\·· 3J-1 0 3J-1 0 WORKOVER/RECOMP n3scm@conocoph¡lIips.com Nabors 38 Start: 7/8/2005 Rig Release: 7/20/2005 Rig Number: Spud Date: 11/27/1985 End: 7/20/2005 Group: . ........... ................. ....... . .., .,.. . . "' . ..' . ...... "." .... . ... .. ..". .............. .. .. o . . . . ... .. ·:iPesçdpti(jnÒf:øper~W?ris . . r:: .. 'T' H', ,'0'·' U': :r' ·s'· .,...'. .., :..., r-.' '.', ·..·.0,· ,'d' "e" .. S.U.'·.b.·..·. .".:." ......,..p.. .',.' ,·:.'.h:.:'.·a:..· S:.'.· '.'.e· '......., rrOm:+lø \J.... . .. ·Códe' 7/14/2005 00:00 - 01 :30 01 :30 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 11 :30 11 :30 - 11 :45 11 :45 - 12:00 12:00 - 15:00 15:00 - 21 :00 21 :00 - 00:00 7/15/2005 00:00 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 11 :00 11 :00 - 15:00 , 15:00 - 17:00 1.50 WELCTL KILL DECOMP carbonate pill, 0.8 bpm @ 200 psi csg pressure. 10 bbls away, shut down and monitor. Perform fire drill. 1.00 WELCTL KILL DECOMP Casing pressure 25 psi, almost flattening out. Pump 10 more bbls of 14.4 ppg biozan/calcium carbonate. Shut down and monitor. Level at 10 psi csg and SIDP. PULL DECOMP Open up and bleed off. Open pipe rams and bag. Monitor well for flow. No flow. Conduct pre-job saftey meeting. Begin pulling remaining completion. Flat channel and bands corroded, some barely hanging on, some missing. Pick those out of the hole that we are able. OTHR DECOMP Out of hole with old 2-7/8 completion. Bands hung up in stack; close blinds so they won't fall ito well. Lay down old equipment in dike to be normed. Begin removing riser to get access to bands. 5.50 WELCTL EaRP DECOMP Retrieved bands from stack. Retrieved all 116 clamps, 9 Flat Guards and 39 bands. Potential of 18 bands lost in hole.Set test plug in wellhead. Installed 3-1/2" blocks in both pipe rams. Pressure test rams to 250/4000 psi. Witnessing of test waived by Lou Gramaldi (AOGCC). Pulled test plug. Monitor well for flow, well static 0.25 WELLSR TRIP WRKOVR Installed wear ring. Cleaned rig floor and pipe shed, preparing to pick up workstring with scraper. 0.25 FISH SFTY WRKOVR PJSM on running scraper and workstring. 3.00 WELLSR TRIP WRKOVR RU tools to pickup and NU BHA. Open blinds and observe well, static. MU and run BHA consisting of 6-1/8" bit, two boot baskets, 7" casing scraper, Bumper sub, jars. 6.00 WELLSR TRIP WRKOVR Pickup workstring (3-1/2" PH-6 P-110) run in hole. 3.00 WELCTL KILL WRKOVR Well appearing to flow again- have displaced most of our 14.4 ppg pill to pits. Circulate remainder of 14.4 ppg pill to bottom (16 bbls). Monitor well; dead. Cont. RIH with workstring. 20 more jts in the hole. Well flowing again. Stop running pipe, stab TIW valve and prep to circulate. Monitor flow. 2.00 WELCTL OBSV WRKOVR Open up to check flow; bleed if possible. Flow 3 bbl back to pits...good rate back, appears to be increasing. Shut back in. 2.00 WELCTL CIRC WRKOVR SICP=40 psi, SIDP=10. Attempt to bleed 3 more bbls. No change. Inconsistent brine wgts in pits due to displacing pill back (12.7 ppg and 13.1 ppg). Gun pits, equalize ouat 12.9 ppg. Begin circulating hole at 2.3 bpm. 2.00 WELCTL OBSV WRKOVR 140 bbls around back to pits, lost 17 bbls. 12.9 ppg back to surface. Shut down, let stabilize. 30 psi SICP, 20 SIDP; monitor. SICP dropped to 20 psi after 15 mins. Open up to bleed off. Still flowing, very low rate, Showing 10 psi SICP, return rate dropping off, slowin down to a trickle. WRKOVR Continue running in hole with scraper and workstring, with constant I monitoring of well conditions. With 204 jts ran in (6739') well starting to flow again. Shut in with SICP 40 psi SITP 0, Installed safety valve, I establish circulation with 12.9 ppg 2.5 bpm @ 160 psi. 4.00! wELcnJ CIRC WRKOVR ¡Installed safety valve, switched through choke and establish circulation I . with 12.9 ppg 2.5 BPM @ 160 psi getting 12.5 ppg returns. After ! pumping 155 bbls fluid returns were 10.1 ppg Continued toCirculated ·12.9 ppg in started getting FW back up and leveled off at 12.6 ppg out, 'circulated 361 bbl Shut down well was static, press O. No losses during I ! circulation. 2.00 WELLSR TRIP WRKOVR I Continued running in hole with scraper and workstring and tagged up i@ 7042'. Put weight down to push any loose bands etc down but only I made l' of progress, final tag 7043'. Fluid leve fell 12' down during tag i process then leveled out to static. 1.50 FISH 2.00 FISH 5.00 WELLS1 TRIP I I I I I I Printed: 8f29f2005 3:15:04 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-10 3J-10 WORKOVER/RECOMP n3scm@conocophillips.com Nabors 3S Start: 7/8/2005 Rig Release: 7/20/2005 Rig Number: Spud Date: 11/27/1985 End: 7/20/2005 Group: ... ........... ....... .... . ".' ...... '::"" .":: .. ... ....... . .......". . ".' .. .... ..' ... ". .. . ..,.,. ., '.. .,'.',. . .....:": "... ...... ... ... ..... · .. P~sçriptiòq!9f9?Pªt~ti9~~:: ;FrQ~HTOHour~ ·..i~Þd~· ~od~.Phas~;i; 1.00 WELLSR OTHR WRKOVR RU pumping equipment to reverse circulate and clean out 13' of covered perforation. 2.00 WELLSR CIRC WRKOVR Reverse circulated @ 2BPM with 230 psi. Lowered and tagged at 7043' solid. Set weight down (7k) to clean out but could not make any progress. Pumped 28 bbls total and lost 7 bbls. 2.75 WELLSR KILL WRKOVR Discuss options w/ Wells Eng. Decide to pump calcium carbonate to isolate perfs. Begin mixing 20 bbl pill per agreed M-I recipe (5Ib/bbl safecarb 2, 40 Ib/bbl safecarb 40, 20 Ib/bbl safecarb 10 --65 Ib/bbl tot.). Pulled 1 more jt (3 total) putting our depth at 6947'. Pill=150 vis/13.6 ppg 1.25 WELLSR KILL WRKOVR Finished mixing pill. Circulate 17 bbl pill to bottom, close bag and begin bullheading into formation @ 0.8 bpm, 450 psi SIDPP. 3 bbls displaced, begin seeing slow pressure increase. 15 bbls away, have worked up to 700 psi, drop rate to 0.4 bpm. 20 bbls away, have all of pill displaced. SIDPP=700 psi, 0.4 bpm. Shut down. Begin mixing new pill (M-I rep getting SC250 from Doy15). WRKOVR Batch up new perf-block pill, 26 bbls (15 Ibs/SC1 0, 45 Ibs SC40, 15 Ibs SC250); 200 vis/13.3 ppg. Wait on Safecarb 250 to arrive. WRKOVR Circulate high-visc pill (22 pumpable) around at 1 bpm. Pill away, shut down- difficulties getting swapped to 12.9 ppg brine due to plugged screens. Back online and circulate pill to bit. WRKOVR Close bag and bullhead, displacing into formation at 0.8 bpm, 450 psi initial DPP. Walk casing pressure up to 950 psi, rate down to min (0.2 bpm). Able to inject steady at that rate and pressure. WRKOVR Shut down, monitor pressure. Continuing to drop, still dropping approx 10 psi/30 secs at 380 psi. 22 bbl pill displaced. Begin prepping to pooh, racking back. Pulling wet, pump 20 bbl dry job. WRKOVR POOH standing back workstring and DC in derrick. WRKOVR Break out and lay down bit and scraper from BHA. Empty out two junk baskets. Recovered 2 more bands in pieces. Rig up tools to run back in hole. WRKOVR MU 6" x 5.75" Reverse Junk Basket, two boot baskets, jars, bumper sub and 6 collars. WRKOVR RIH on 3-1/2" PH-6 workstring. WRKOVR On bottom; begin rigging up power swivel. WRKOVR Perform Bop Drill. WRKOVR Rrigging up power swivel. WRKOVR Pick up and MU first jt in power swivel. Establish circulation 4BPM 870 psi Tagged up at 7042'. Cleaned out approximately 10' something hard like the metal bands, finally broke thru softened up as per sand. Dropped ball into reverse basket and continued to wash down and clean out to 7124' KB, circulating hole clean between connections. This puts us 68' below perfs. WRKOVR Circulate hole clean. Lots of frac sand back in returns. WRKOVR Set Power Swivel aside. Pull 5 jts to get above perfs. Disconnect and : rig down Power Swivel. WRKOVR I Begin pulling fishing string out of hole, laying down WRKOVR ¡ Pulling fishing string out of hole, laying pipe down sideways. . WRKOVR . Lay down drill collars and remaining BHA. Clean out debris from junk 'basket. Recovered two 16" twisted pieces of flat guard, several pieces I of bands and approx. 2 gals frac sand. CMPL TN . PJSM with Schlumberger on rigging up eline and running IBP. RU and RIH with Baker IBP (Retrievable Bridge Plug). On spot at in middle of 7/15/2005 17:00 - 18:00 18:00 - 20:00 20:00 - 22:45 22:45 - 00:00 7/16/2005 00:00 - 02:00 2.00 WELLSR KILL 02:00 - 03:30 1.50 WELLSR KILL 03:30 - 04:45 1.25 WELLSR KILL 04:45 - 06:00 1.25 WELLSR KILL 06:00 - 14:00 8.00 WELLSR TRIP 14:00 - 15:30 1.50 WELLSR TRIP 15:30 - 18:00 2.50 FISH TRIP 18:00 - 23:00 5.00 FISH TRIP 23:00 - 23:30 0.50 FISH RURD 23:30 - 00:00 0.50 WELCTL SFTY 7/17/2005 00:00 - 07:30 7.50 FISH RURD 07:30 - 14:30 7.00 FISH MILL I i '14:30 - 16:30 : 2.00 FISH iCIRC 116:30 - 20:30 , 4.00: FISH 'TRIP 20:30 - 00:00 3.50, FISH ,TRIP 7/18/2005 00:00 - 05:00 5.00 FISH TRIP 05:00 - 08:30 3.50' FISH TRIP , 08:30 - 15:30 7.00 LOG ELOG Printed: 8/29/2005 3:15:04 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3J-10 3J-10 WORKOVER/RECOMP n3scm@conocophillips.com Nabors 3S "D' ... ··t···'· .... .. .. F· . . T· H'· ......... ... ·r-··d···· ..·.·..·..·..,...8.·. ·...·.u.,··.....b.·.·...:,..·, .... p..·..,.h·.'.·, 8". ."s'·.e·. '.,.'.'....: .···..å~) ." ..·r'drn..:o ;,oÜrs ¡¡\;Joe ,Qc:>d~: ;. 7/18/2005 08:30 - 15:30 7.00 LOG ELOG CMPL TN 15:30 - 21 :00 5.50 LOG ELOG CMPL TN 21 :00 - 23:30 2.50 LOG PULD CMPL TN 23:30 - 00:00 0.50 WELCTL BOPE CMPL TN 7/19/2005 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 17:00 14.50 CMPLTN RUNT CMPL TN 17:00 - 19:00 2.00 CMPL TN CIRC CMPL TN 19:00 - 19:30 0.50 CMPL TN DEOT CMPL TN 19:30 - 21 :20 1.83 CMPL TN SOHO CMPL TN 21 :20 - 22:00 0.67 CMPL TN SOHO CMPL TN 22:00 - 00:00 2.00 CMPL TN DEOT CMPL TN 7/20/2005 00:00 - 05:15 5.25 WELCTL NUND CMPL TN 05:15 -12:00 6.75 CMPL TN SEOT CMPL TN 12:00 - 20:00 8.00 MOVE RURD MOVE Start: 7/8/2005 Rig Release: 7/20/2005 Rig Number: Spud Date: 11/27/1985 End: 7/20/2005 Group: first jt above top perf @6970'. Pumped on IBP for 2hrs. 40 min over, no pressure. POOH with eline and IBP. RU and run 40 arm casing caliper log from top of perfs 6994' to surface. SWS out of hole. Call Wells Engineer to review logs. Discuss options and form plan forward. Called state rep (Jeff Jones) at 23:35 to discuss weekly BOP test. Explained we would be running completion in approx 2 hrs (01 :30 7/19/05)- he stated weekly BOP was unnecessary - test waived. Prep to run completion. Call out Baker completions hand. Pulled out two rows of workstring from pipe shed. Prep to run new 3-1/2" completion. Conduct pre-job safety meeting. Begin running new completion per program/discussion w/ Wells Engineer. Packer to be set at +- 6680' orig. RKB. Packer on spot @ 6684'. Spotted 10 bbls corrosion inhibited brine on bottom in tubing X IA. Used 2% by volume of the Baker Petrolite CRW132. RU chart recorder, dropped ball and rod 1 3/8" FN X 2.25" cent X 6.10' long. Press up to 2500 psi and set FHL packer @ 6684'. Shear out PBR w/2,500 PSI in tubing. 60K up wt. 11.10' for space out ups. Prepare for tubing landing. Land tubing. Prepare for final PT. PT ia and tubing. Chart all pressure test. All test passed. 2,500# IA. o leak off. Prep to set BPV and pick stack. Nipple dwn BOPE. Clean pits. Install BPV. Prepare to pick up newly redressed production tree. Tear down of 7" BOPE for parts on 13 3/8" stact for next well. Install and orient tree and new tubing head adaptor. Pull BPV, set TIP test adapter and tree to 5000 psi. Clean cellar area and tree. Install BPV. Released rig @ 12:00 on 7/20/2005. Rig down, hook up to trucks, move rig from 3J-10 to 1G-13. Left location @ 18:00 hrs. Printed: 8/29/2005 3:15:04 PM Schlumbergep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well ../ 2N-305 1. 0 J. i )5- J .2N-308 I CCq "úit. .í2N-317 l q S· N} u 2G-06 1'3 ~(- ~~).. j 1 Y -04 ¡ 3~ - f¡ ~ l: \"/.3J-10 '~fi-J..Çè J 2U-10 IJ>- _ t )i:~ ....·1 C-178 ~O:J - (:-if SIGNED: Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 f ; /) I ,.,.1 j/ I k .. I / " /f:/.h'lf'tV't f.... St;j~_N... \."..1 E,¡.~.·.·..·.: ~.'.'.'~>_> f:'.=. ,'--,'.J f) . 'j nIl ¡;; - "-~ '~'.~ i} (] 2LJL¡~ Log Description Date 08/03/05 NO. 3443 I ~G"';)" 5b SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE V 'I {. MULTI-FINGER CALIPER LOG PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD --- .", ! , f'f.l í I l! / /Íit'¿t~l --' " 1 1 1 1 1 1 1 1 ---' DATE: ~...~ .~...~-- v Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ') ConocJP'hillips Alaska ) RECE'VE:'r~) AUG I 1 2005 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. CO¡~'h1~¡SS¡(H1 Anchorage August 8, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we1l3J-10 (PTD 185-250). The Sundry reports a Braidenhead welding repair. Please call me or Marie McConnell at 659-7224 if you have any questions. Sincerely, ~ ~f ~. Problem Well Supervisor 8C"",£.\.~\.¡~"it·:-r·'J nul.... .~ 1 <)onr ~ ",;"'.,\1 .I,-.r! .J "'- _ t_ uJ Attachments 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillipsAlaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 74' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 7344' feet true vertical 6562' feet measured 7344 feet true vertical 6276' feet length Size MD 110' 16" 110' 2268' 10-3/4" 2342' 7248' 7" 7322' ) ') ALASKA OIL AND ~~;~g~S~~~':ON COMMISSION RE C E IVE D REPORT OF SUNDRY WELL OPERATIONSUG 11 Z005 RepairWell 0 Pull Tubing D Operat. ShutdownD Stimulate 41aska Oil & ~NrCons. ~missjo 1 Waiver Lf TimA~~ D Re-enter Suspended Well D 5. Permit to Drill Number: 185-250 6. API Number: 50-029-21467 -00 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development _ 0 Stratigraphic D Exploratory Service D D 9. Well Name and Number: 3J-10 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 110' 2342' 6542' Measured depth: 6994-7014', 7032-1056' Intervals treated (measured) true vertical depth: 6283-6299',6313-6332' Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6446' MD. Packers & SSSV (type & measured depth) Baker Packer 6670' SSSV= NIP SSSV= 465' 12. Stimulation or cement squeeze summary: 13. Treatment descriptions including volumes used and final pressure: N/A Representative Daily Average Production or Injection Data Gas-Met Water-Bbl NA NA AN NA 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: _ oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Marie McConnell/MJ Loveland @ 659Y24 Printed Name MJ ~~d / /' Title Problem Wells Supervisor Signature $ // ~ Phone 907-659-7224 Date a:/ ~ ;;- 7 / R8DMS BFl AUG 1 5 2005 '1 : Form 10-404 Revised 04/2004 Submit Original Only Oil-Bbl NA NA Casing Pressure NA NA Tubing Pressure NA NA WDSPLD ) 3J-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Braiden Head Welding Event Summary 7/31/200S Secured well for BH welding with TPP 8/1/200S PuIlIA and OA VR plugs and prep for BH weld 8/6/200S Welded braiden head with 3 welding passes 8/7/200S well normaled up and MITOA passed to 1800 psi post BH weld ) [Fwd: Re: 3J-10 Influx] Hi Jim, Not too much to add to this other than Rick Overstreet (Foreman) kept in good contact with me throughout. Lou Content-Type: message/rfc822 3J-IO Influx Content-Encoding: 7bit C)' (I, t_, '1' 1 of 1 7/22/20054:14 PM Re: 3J-10 Influx ) ~~~je~t: R:~:~!-lP~~~~.·....i.'...'..''''''.''.' '. .. ........... .............. ...i.....·............. ............... ................................ . . ~:~~JÏ1:.. ·T~9~f\~·...~~'~7~·..ñt9m+~~ut1(l~r@~4$il1...st~t~:~ål<. µ~? D~~e:T1).µ,.. ¥4JuJg()05·~-():24-:.~.·~·~08Q.O.· . Howard, This acknowledges you call of last evening regarding the event at 3J-10. Thanks for supplying the chronology. Please keep us informed with regards to any further determinations. I think you are correct that with no gas evident, that the "source" was downhole. Tom Maunder, PE AOGCC Gober, Howard wrote: Tom, I wanted to follow up with you on the sequence of events on 3J-10 yesterday, our current status, and our plan forward. Below is yesterday's events: · Fluid in hole - 12.7 ppg viscosified sodium bromide brine with calcium carbonate for weight. · Pulled 2-7/8" tubing with ESP completion on bottom out of hole. Hole fill was -1/2 bbl over calculated for every 10 jts pulled. Everything looked good. · Pulled last gas lift mandrel out of the hole (-162' of completion left in the hole). Fluid level was slowly rising in the stack. · Pulled one more joint of tubing and removed the Baker Sentry gauge. · Observed the well. Brine was flowing down the flowline very slow. · Cut the ESP cable and installed the last GLM with an open pocket and 1 joint of tubing on top. · Ran in hole and closed in the annular. SITP=20 psi. SICP=40 psi. Pit gain=8 bbls. · Discuss situation with town engineer, Wells Team Leader, and AOGCC. · Flow back 15 bbls to the pits. Flow rate was consistent at 1 bbll3min. No gas in returns. · Close in well. SITP=50 psi. SICP=70 psi. · Bullhead 33 bbls 12.7 brine into well at .8 bpm and 200 psi to push most of influx back into the formation. · Shut down pumping. Casing pressure stabilized at 35 psi. · Pump 10 bbls 14.4 ppg brine. Shut down and monitor pressure. SICP=25 psi. · Pump 10 bbls 14.4 ppg brine. Shut down and monitor pressure. SITP and SICP=10 psi. · Bleed off well. Well dead. Open up BOP's. No flow. Well balanced with fluid level at -ground level. · Pull remainder of completion out of hole. · Clear broken ESP bands out of BOP stack. · Change both pipe rams to 3-1/2" Current status: Pressure testing 3-1/2" pipe rams. ÒCf:ìt:\~~~:~:J.. ~:: , ? C ?OC:J Here is our plan forward: · PT pipe rams · RIH with bit and scraper on 3-1/2" work string. Tag PBTD. · Circulate and condition brine. Check for flow. Weight up brine if necessary. 10f2 7/22/20054:15 PM Re: 3J-10 Influx · POOH. · RU E-Line. RIH and set IBP above perfs. · Run caliper log from IBP to surface. · LD workstring. · PU and run gas lift completion. ) ) PT I BP to 1500 psi. I appreciate your help yesterday. Your suggestion of gas in the ESP pump was a plausible theory. In fact, I thought that was our problem. When we bled off and saw no gas, though, we realized our flow must be coming from the reservoir. I cannot explain why we went from overbalance to underbalance so quickly. It does not make sense. There were no changes in injection on the pad to affect our BHP. We will continue to look for a reason. In the meantime, the well is stable. We will get in the hole with the scraper and be able to weight up if necessary. Please let me know if you have any questions, or if you would like to discuss this matter further. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocophillips.com 3J-IO Influx 20f2 7/22120054:15 PM ALASKA OIL AND GAS CONSERVATION COM~VHSSION 1 / / ,~' /' FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 should be allowed to continue production with no restrictions. , The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C~ 16 should be changed to be similar to the other failed ESP wells with the fluid entry OCT 2003 Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, R~and~Rued~rich~~ Commissioner STATE OF ALASKA ,, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend [] Operation Shutdown Repair well ~] Plug Perforations Pull Tubing ~] Perforate New Pool Perforate ~ Variance [~] Stimulate ~ Time Extension ~] Re-enter Suspended Well [] Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ [] Exploratory ~] Stratigraphic [] Service r-'] 5. Permit to Drill Number: 185-250 6. APl Number: 50-029-21467-00 7. KB Elevation (ft): RKB 74' 8. Property Designation: Kuparuk River Unit 11. 9. Well Name and Number: 3J-10 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7344' 6562' 7231' 6470' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' SUR. CASING 2268' 10-3/4" 2342' PROD. CASING 7248' 7" 7322' Perforation Depth MD ft): Perforation Depth TVD (ft): 6994'-7014', 7032'-7040', 7042'-7056' 6282'-6298', 6312'-6318', 6320'-6331' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal [~ Detailed Operations Program [-~ BOP Sketch 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: Packers and SSSV MD (ft) no packer no SSSV 110' 2342' 6543' Tubing Size: Tubing Grade: Tubing MD(fi): 2-7/8" L-80 6777' 13. Well Class after proposed work: Exploratory r'-] Development r'~ 15. Well Status after proposed work: Oil r'~ Gas ~] WAG ~ GINJ [] Plugged WINJ Service Abandoned WDSPL r"-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerxv Dethlefs Signature J~~/~ ~5~. ~ '/ Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date ~'.~'~.~ Conditions of approval: Notify Commission so that a representative may witness laundry Number: Plug Integrity r-~ BOP Test Other: Mechanical Integrity Test r-~ Location Clearance E] ECEtVED SEP'i $ 200;3 Subsequent Form Required: V",.O t',,,,~" ~;:i i"~:!' ",:.," iq;. ~,'.. i...i~.t;...,~,.. Approved by: ~ ~ Alaska Oil & Gas Cons. Commissio~ "-"O6)MMISSION ER BY ORDER OF THE COMMISSION Anchorage / / Date: ORIGINAL Form 10-403 Revised 2/2003 · SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3J-10 (PTD 1852500) September 11, 2003 This application for Sundry approval for well 3J-10 (PTD 1852500) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3J-10 was originally completed in December 1985 as a gas lifted producer. The well was re-completed with an ESP in~~.-.~he well produced via ESP until November 2002, at which time the pump failed. The AOGCC was notified of the pump failure on November 23, 2002. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing thr0~ugh~a gaslift mandrel at 6685'measured depth. From that point produced fluids flow up the tubing and out the wellhead t-o producti'on facilities. Gaslift is maintained on the well through gaslift valves at 2671' and 3807' to keep annular fluids to the lo~we.st possible~depth. The well is equipped with a wellhead Safety Valve System as per regulations. Recent well test data shows the following results: ,r~--~.----~.~. WELL TEST SUMMARY REPORT OTAL FORM TOTAL LIFT GAS IFT GAS DS WL LENGTH CHK FTP FTT OIL WATER~%WC IFLUID GAS GOR GLR RATE ~ PRES I I 3J 10 15:55 104 173 131 404 1360( 77 11764 203 502 483 650 } 1172 I I 3J 10 12:27 104 172 130 394 1289 ~) 77 ~1683 198 503 497 638 I 1177 3J 10 18:00 104 160 130 389 1361 \ 78 11750 204 524 482 640 ~ 1161 I / 3J 10 15:41 104 157 130 381 1325 [ 78 )1706 196 516 486 632 ~ 1166 3J 10 18:00 104 167 130 375 1390 t 79 /1765 192 512 506 702 I 1151 I / As per this request, ConocoPhillips intends to produce 3J-10 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. Gas Lff~ VlandrelNalvE 2 (2671-2672, 0D:4.750) Gas Lift VlandrelNalvE 4 (3807-3808, OD:4.750) Gas Lift VlandrelNalw 5 (6685-6686, 0D:4.750) GConocoPhillips Alaska, Inc, 3J-10 NIP (6761-6762, 0D:2.875) TUBING (0-6777, 0D:2.875, ID:2.441) PUMP (6777-6805, OD:2.875) SEAL (68O5-6825, OD:2.875) MOTOR (0825-6848, OD:5.620) Perf (6994-7014) Perf (7OO4-7OO4) Perf (7032-7040) KRU 3J-10 APl:1500292146700 SSSV Type: NONE Annular Fluid:I Reference Log:I Last Ta9:17231 Last Tag Date:111/10/1996 Well Type:I PROD Orig 112/10/1985 Completion:I Last W/O:111/10/1996 Ref Log Date:I TD:17344 ftKB Max Hole Angle:~45 deg (~ 5800 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 10.750 PROD. CASING 7,000 Top 0 Bottom TVD 110 110 0 2342 2342 0 7322 6545 Angle (~ TS:I40 deg ~ 6817 Angle @ TD:I37 deg @ 7344 I Rev Reason:I FTS WELL Last U pdate:[ 5/25/2003 I Wt Grade] Thread 62.501 H-40I 45.4oI J-55 I 26.00I J-55 I Tubin9 Strin9 - TUBING Size I Top IBottom 2,875 0 6777 Perforations Summary Interval TVD 6994-7004 6283-6291 7004-7004 6291-6291 7004-7008 6291-6294 7008-7008 6294-6294 7008-7014 6294-6299 7032-7036 6313-6317 7036-7036 6317-6317 7036-7040 6317-6320 7042-7056 6321-6332 TVD I Wt GradeI Thread 6117 I 6.50 L-80 I ABM EUE Zone Status Ft SPF Date Type Comment A-3 10 8 7/23/1988 RPERFI30 deg. ph; 2 1/8" EnerJet A-3 0 9 7/23/1988 RPERFI30 deg. ph; 2 1/8" EnerJet A-3 I 4 8 7/23/1988 RPERFI30 deg, Dh; 2 1/8" EnerJet A-3 I 1°19 17/23119881RPERF130deg'ph;2118"EnerJet A-3 I 1618 7/23/19881RPERFI30 deg' Ph; 2 1/8" EnerJet A-2 I 1418 17/23/19881RPERFI30 deg. ph;21/8"EnerJet A-2 I iol9 17/23/19881RPiRFI30deg. ph;2118"inerJet A-2 I 1418 17/23/19881RPERFI30deg. ph;2118"EnerJet A-2 I I 14 I 4 14/10/198611PERFI~0deg'ph;4''CsgGunHJ 'st l MDI'TVD'I Ma"'].. Man I V MfrIvTypeI VOD ]LatchI PortI TRolDate I Vlv Mfr Type Run 1 129 1291McMurra~ ~0 ~ [ ~.O I ~ Io.oool0 1~,~00~c~n' 2 2671 26711McMurray~ FMHO GLV I 1.0 I BK 10.156 11293~11/17/200~ 313762l 37601McMurra~ FMHO I I DMY I 1'0 I BK 10'0001 0 ~1/10/1996~ 4138071 38041McMurra~ FMHO I I OV I 1.0 I BK 10.2501 0 ~1/17/200;I 5166851 60471Cam0o/ FMHO I I OPEN I 1.0 I BK 10.0001 0 111/17/200~ :Other (plugSi::eq ui:p~i et~i; JEWELRY ;: :: :;;,:: : :::: ::;;: ::i ::: :i:;;; i i;!:i:: ;;;:,;: ::::: DePth/TVD I Type Description ID 6726 16078 I SENSOR Baker Sentryll P&T I 2.441 6761 16105 I NIP Camco'D' Nipple NO GO I 2,250 6777 16117 I PUMP CentriliftModel 'GPMT' Series513 Tandem Pump w/ integral intake & boltI 0.000 / I on head I 6805 16138 I SEAL Centrilift Model 'GSTB' Tandem Seal Section I 0.000 6825 /6154 I MOTOR Centrilift Model 'KMEGI' Series 562 w/Motor Lead Extension I 0.000 Date ] Note 11/23/200;I PACKERLESS COMPLETION: FLOW TO SURFACE WELL ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3J-10 (Permit No. 85-250 & 396-214) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of sundry well operations for the recent workover on KRU 3J-10. The workover was to pull the existing completion and to install an ESP. If there are any questions, please call 263-4622. Sincerely, ORIGINAL W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad R£CEIVED FEB 6 1997 STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COt~,'~IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Install ESP 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1015' FSL, 565' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1304' FSL, 1252' FEL, Sec 4, T12N, R9E, UM At effective depth At total depth 1379' FSL, 1577' FEL, Sec. 4, T12N, R9E, UM t5. Type of well: [] Development [] Exploratory [] Stratig raph ic [] Service 6. Datum Elevation (DF or KB) RKB 74' 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3J-10 9. Permit Number / Approval 85-250 396-214 10. APl Number 50-029-21467 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured 7344 feet Plugs (measured) true vertical 6561 feet Effective depth: measured 7231 feet Junk (measured) true vertical 6470 feet Casing Length Size Cemented Structural Conductor 80' 16" 171 sx AS II Surface 2312' 10.75" 1000 sx ASIII & 140 sx Class G Intermediate Production 7292' 7" 610 sx Class G & 250 sx AS I Liner MD TVD 115' 115' 2342' 2342' 7322' 6543' Perforation depth: measured 6994'-7014', 7032'-7040', 7042'-7056' true vertical 6282'-6298', 6312'-6318', 6320'-6331' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 @ 6848' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED I:EB 5 1997 Alaska 0il & ORIGINAL 14. Prior to well operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl 535 274 1 O29 Casing Pressure Tubing Pressure Subsequent to operation: 778 450 1599 15. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ .,~. ~[. ~',~ ,,. ,. , .___ Title O,~J. ZHt~ Prepared By Name/Number: 1250 1600 Date Form 10-404 Rev. 06/15/88 Submit In Duplicate Date: 1/28/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3J-10 RIG:NORDIC WI: 0% SECURITY:0 WELL ID: 998580 TYPE: AFC:--998580 AFC EST/UL:$ 560M/ OM STATE:ALASKA API NUMBER: 50-029-21467-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/05/96 START COMP:11/03/96 FINAL:il/12/96 11/03/96 (C1) TD: 7056' PB: 7231' SUPV:DLW DAILY:$ 11/04/96 (C2) TD: 7056' PB: 7231' SUPV:DLW DAILY:$ 11/05/96 (C3) TD: 7056' PB: 7231' SUPV:DLW DAILY:$ 11/06/96 (C4) TD: 7056' PB: 7231' SUPV:DLW DAILY:$ 11/07/96 (C5) TD: 7056' PB: 7231' SUPV:DLW DAILY:$ 11/08/96 (C6) TD: 7056' PB: 7231' SUPV: DLW DAILY: $ 11/09/96 (C7) TD: 7056' PB: 5331' SUPV:DLW DAILY: $ DERRICK WINDWALL MODIFICA Install derrick windwalls. MW: 0.0 17,000 CUM:$ 17,000 ETD:$ 0 EFC:$ DERRICK WINDWALL MODIFICA MW: 0.0 Continue modification of derrick windwalls. 577,000 17,000 CUM:$ 34,000 ETD:$ 0 EFC:$ 594,000 MOVE RIG FROM 3B TO 3J MW: 0.0 Wait on wind to drop below 10 mph to continue modification of derrick windwalls. Work on derrick windwalls. Move rig from 3B pad to 3J pad. 22,300 CUM:$ 56,300 ETD:$ 0 EFC:$ 616,300 TEST BOPE MW:ll.5 BRINE Pump brine down tubing to kill well. Well dead. Pump diesel to freeze protect hard lines and production line. ND tree. NU BOPE. Test BOPE 250/3500 psi. 78,082 CUM:$ 134,382 ETD:$ 0 EFC:$ 694,382 STRIP IN HOLE WHILE P/U D MW:ll.5 UNKN Pull 3.5" tubing. PU 3.5" DP. Well started to flow. Shut in well. R/U install inside BOP and start stripping in hole. 31,200 CUM:$ 165,582 ETD:$ 0 EFC:$ 725,582 CHANGING HYDRIL ELEMENT MW:12.0 UNKN Continue to strip in hole picking up 3.5" While stripping in hole to 6327' Hydril started to leak and annulus pressure coming up to 400 psi. Shut in w/pipe rams. 89,673 CUM:$ 255,255 ETD:$ 0 EFC:$ 815,255 RIH W/BIT & CSG SCRAPER MW:ll.8 UNKN Change pipe ram used for stripping, hook up kill line & flow nipple, test Hydril to 300/3000 psi, test rams to 300/3500 psi. OK. RIH from 6327' to 6692' top of Baker PBR and packer. Pull up to 190K shear pkr release. Circ surface to surface, lost 28 bbls while circ. 44,958 CUM:$ 300,213 ETD:$ 0 EFC:$ 860,213 Date: 1/28/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/10/96 (C8) TD: 7231' PB: 7231' SUPV: DLW DAILY: $ POOH L/D 3.5" DP TOTAL OF MW:ll.8 UNKN Continue RIH w/BHA %2 6.125" bit and casing scraper spaced out to stop @ 6900'. Clean out fill from 7061' to 7231'. There is junk on bottom. 81,982 CUM:$ 382,195 ETD:$ 0 EFC:$ 942,195 11/11/96 (C9) TD: 7231' PB: 7231' SUPV:DLW DAILY:$ RUNNING 2-7/8" 'ESP' COMP MW:ll.8 UNKN R/U to run 2-7/8" tubing 'ESP' and pump. RIH w/completion. 31,200 CUM:$ 413,395 ETD:$ 0 EFC:$ 973,395 11/12/96 (Cl0) TD: 7231' PB: 7231' SUPV:DLW DAILY:$ RELEASE RIG MW: 0.0 DOILSW Continue to run 2-7/8" ESP completion. Test tubing to 2500 psi for 30 min. OK. Release rig @ 0600 hrs. 11/12/96. 242,986 CUM:$ 656,381 ETD:$ 0 EFC:$ 1,216,381 End of WellSununary for We11:998580 STATE OF ALASKA -,.._~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend m Operation Shutdown __ Re-enter suspended well _ Alter casing_ Repair well Plugging_ Time extension Stimulate Change approved program _ Pull tubing X Variance _ Perforate _ Other X__ Install ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory _ RKB 74' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1015' FSL, 565' FWL, Sec. 3, T12N, R9E, UM 3J-1 0 At top of productive interval 9. Permit number 1304' FSL, 1252' FEL, Sec 4, T12N, R9E, UM 85-250 At effective depth 10. APl number 50-029-21487 At total depth 11. Field/Pool Kupurak River Field/ 1379' FSL, 1577' FEL, Sec. 4, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7344' feet Plugs (measured) (approx) true vertical 6561' feet Effective depth: measured 7231' feet Junk (measured) (approx) true vertical 6470' feet None Casing Length Size Cemented Measured depth True vertical depth Structural 80' 1 6 ' 171 Sx AS II 1 1 0' 1 1 0' Conductor Surface 2312' 10-3/4' 1000 sx ASIII 2342' 2342' Intermediate 140 sx Class G Production 7292' 7' 610 sx Class G & 7322' 6543' Liner 250 sx AS I Perforation depth: measured 7004', 7008', 7036', 7042'-7056' true vertical 6290', 6293', 6315', 6320'-6331' Tubing (size, grade, and measured depth) 3.5', 9.3#, J-55, 6775' Packers and SSSV (type and measured depth) Baker FH-L packer @ 6705', Camco TRDP-1A-SSA SSSV @ 1797' 13. Attachments Description summary of proposal ~ Detailed operation program __ BOP sketch _ Contact William Isaacson at 263-4622 with an)/ questions. 14. Estimated date for commencing operation 15. Status of well classification as: November 4. 1996 Oil X Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date Approved Service 17. I hereby certify/ :hat t/b/el~regoing is true and correct to the best of my knowledge. Signed - Title Drill Site Development Supervisor Date '~' ~o'~ FOR COMMISSION USE ONLY Conditions of approval: ommission so representative may witness IApproval.,L, Plug integrity_ BOP Test__ Location clearance__ I ~ t~-'_~ , Mechanical Integrity Test_ Subsequent form require Original SJgne(:l By Commissioner Date ////f/~ ~) Approved by' the order of the Commission .~.:.;;.._.~ :,,,.; :.,: ..... ;.. .... Form 10-403 Rev 06/15/88 0R~~i~~L SUBMITIN 'LICATE Approved Copy R~tur@ed KRU 3J-10 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline. Pull valve from bottom GLM leaving an open pocket. Dummy off all other GLM's. 2. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 11.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down 3-1/2" tubing and all jewelry. 5. PU DP and RIH with spear. Latch into PBR and pull retrievable packer free. POOH with packer and tail-pipe assembly. 6. PU bit and scraper and RIH cleaning out well to PBTD. Circulate hole clean. POOH standing back DP. . RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 8. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 10/29/96 Casing, 7", 26#, J-55 3J-10 Proposed Comi etion I. 2-7/8' x 7-1/16' 5M FMC Eccentric tubing hanger with EFT penetrator for ESP cable and port for downhole gauge conductor wire. 2-7/8' L-80 tubing pup on bottom. H. 2-7/8' L-80 EUE 8rd Mod fl0g to surface with the bottom +/-1500' Internally Plastic Coated. Space out 2-7/8' x 1 ' McMurry 'FMHO' mandrels w/DV's as follows: GLM# MD-RKB 2 4600' 3 3750' 4 2650' 5 100' NOTE: Install LaSalle cable proteCtors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM (except the one at 100') should be made up with a 6' pup below and a LaSalle cable proteCtor placed on cplg below pup. LaSalle ESP Cable spaced out as per procedure Cable splice from fiat to round cable adjacent to pup above pump LaSalle Protectolizers at each tan of ESP assembly G. 2-7/8' X 1 ' Camco 'KBMM' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). F. Pup jt, 2-7/8' x 6' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. E. 2 jts of 2-7/8' L-80 EUE 8rd Mod Internally Plastic Coated tubing with Baker 'Sentry' downhole pressure / temperature gauge clamped onto 1st jt of tubing. Conducter Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. Install one LaSalle cable protector on cplg between the two joints. D. 2-7/8' Camco 'D' landing nipple with 2.25' No-Go profile. Standing Valve to be set in landing nipple as completion is being made up. C. Centrilift Model 'GPMT' Series 513 Tandem Pump with integral intake and bolt on head. 2-7/8' x 10' L-80 handling pup on top. B. Centrilitt Model 'GSTB' Tandem Seal Section. A. Centrilift Model 'KMEGI' Series 562 Motor with Motor Lead Extension Cable. Bottom of motor set at +/-6900' MD RKB. A Sand A Sand Peds 6994'-7014' 7032'-7040' 7042'-7056' PBTD @ 7231' WSI 10/29/96 ~L~SKA 0IL A~II GAS C 0NSER¥~I ON TONY KNOWLE,.,o,, GOVERNOR · 3001 PORCUPINE IDRIVE ANCHORAGE. ALASKA @9501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18, 1996 Mr. Mike Zanghi Kuparuk Drill Site Dev. Supr. ARCO Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Waiver to the Packer Requirements of 25 AAC 25.200(d) to Allow- Effective Electric Submersible Pump Completions in 3 KRU Wells Dear Mr. Zanghi' Your November 12, 1996 letter to the Commission requested a Waiver to the packer requirement of 20 AAC 25.200(d) so that electric submersible pumps (ESPs) could be used safely and efficiently in the Kuparuk River Unit. This request is to allow ESP installations in KRU wells 3B-13, 3J-7, & 3J-10. Regulation 20 AAC 25.200(d) requires that "All wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless other,vise specifically approved by the commission." ESP wells are completed with the pump set just above the zone. During pumping operations, the fluid being pumped serves to cool the pump; if gas enters the pump, the pump becomes gas locked and it over heats which results in pump failure. When Kuparuk River crude enters the wellbore, pressure decreases and gas breaks out of solution; this gas tends to rise and accumulate. When sufficient gas has accumulated so that it is sucked into the pump, the pump becomes gas-locked and it overheats because it no longer pumps fluid which would cool it. Therefore, the goal is to find a way to produce the well safely so that gas does not accumulate where it can be sucked into the pump. One option is to set a packer high - 500' for example - this practice does not satisfy, the intent of 25.200(d); this is a not a safe completion. ESP wells have to be pulled at intervals from a few months to a few years to change the pumps, it is very difficult to kill a well that has a packer installed at 500' because it is difficult to displace the gas that has accumulated in the annulus; the gas trapped under the packer makes the operation risky. Mr. lVIike Zanghi Kuparuk Drill Site Dev. Supr. November 18, 1996 Page" ,_ A second option is to set a packer below the ESP. Again, this practice does not satisfv the intent of 25.200(d) and is an unnecessary, operation. SubJect wells are high water cut (60 to 70%) and possibly could not flow unassisted, at least not at economical rates; therefore its in the State's best interest to have these ,,,,'ells completed with some form of assisted lift. The operators have determined that ESP completions are effective in these high water volume Kuparuk wells. Your request for a general waiver for Kuparuk wells can only be accomplished by a conservation order; however, the Commission can issue specific approvals. The Commission hereby waives the requirement for a packer in Kuparuk ~ver Unit wells 3B- 13, 3J-7, and 3J-10. David W. Chairman cc: Blair Wondzell bew/espwells TONY KNOWLE$, GOVEFINOR ALASKA OIL AND GAS CONSERVATI ON COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18, 1996 Mr. Mike Zanghi Kuparuk Drill Site Dev. Supr. ARCO Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Waiver to the Packer Requirements of 25 AAC 25.200(d) to Allow Effective Electric Submersible Pump Completions in 3 KRU Wells Dear Mr. Zanghi: Your November 12, 1996 letter to the Commission requested a Waiver to the packer requirement of 20 AAC 25.200(d) so that electric submersible pumps (ESPs) could be used safely and efficiently in the Kuparuk River Unit. This request is to allow ESP installations in KR'U wells 3B-13, 3J-7, & ~ Regulation 20 AAC 25.200(d) requires that "All wells capable of unassisted flow must be completed with downhole prodUction equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless otherwise specifically approved by the commission." ESP wells are completed with the pump set just above the zone. During pumping operations, the fluid being pumped serves to cool the pump; if gas enters the pump, the pump becomes gas locked and it over heats which results in pump failure. When Kuparuk River crude enters the wellbore, pressure decreases and gas breaks out of solution; this gas tends to rise and accumulate. When sufficient gas has accumulated so that it is sucked into the pump, the pump becomes gas-locked and it overheats because it no longer pumps fluid which would cool it. Therefore, the goal is to find a way to produce the well safely so that gas does not accumulate where it can be sucked into the pump. One option is to set a packer high - 500' for example - this practice does not satisfy the intent of 25.200(d); this is a not a safe completion. ESP wells have to be pulled at intervals from a few months to a few years to change the pumps. It is very difficult to kill a well that has a packer installed at 500' because it is difficult to displace the gas that has accumulated in the annulus; the gas trapped under the packer makes the operation risky. Mr. Mike Zanghi Kuparuk Drill Site Dev. Supr. November 18, 1996 Page 2 A second option is to set a packer below the ESP. Again, this praCtice does not satisfy the intent of 25.200(d) and is an unnecessary operation. Subject wells are high water cut (60 to 70%) and possibly could not flow unassisted, at least not at economical rates; therefore its in the State's best interest to have these wells completed with some form of assisted lift. The operators have determined that ESP completions are effective in these high water volume Kuparuk wells. Your request for a general waiver for Kuparuk wells can only be accomplished by a conservation order; however, the Commission can issue specific approvals. The Commission hereby waives the requirement for a packer in Kuparuk River Unit wells 3B- 13, 3J-7, and 3J-10. David W. jo Chairman cc: Blair Wondzell bew/espwells 1. Type of Request: ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~N REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address 5. Type of Well: Development Exploratory Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1015' FSL, 565' FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1304' FSL, 1252' FEL, Sec. At effective depth 1364' FSL, 1151' FEL, Sec. At total depth 1379' FNL, 1577' FEL, Sec. 4, T11N, R9E, UM 4, T11N, R8E, UM 4, T11N, R9E, UM X 12. Present well condition summary Total Depth: measured true vertical 7344' feet 6 5 61 ' feet Plugs (measured) 6. Datum elevation (DF or KB) 74' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3J-10 9. Permit number/approval number ~-6o~ Verbal approv~ll from L. Smith 10. APl number 50-029-21467 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 7 2 31 ' true vertical 6470' feet Junk (measured) feet Casing Length Structural Conductor 8 0' Surface 231 0' Intermediate Production 7 3 2 2' Liner Perforation depth: measured 7004', 7008', true vertical 6290', 6293', Size Cemented 1 6" 171 Sx AS II 9 5/8" 1000 Sx AS III & 140 Sx Class "G" 7" 610 Sx Class "G" 250 Sx AS I 7036', 6315', Tubing (size, grade, and measured depth) 3 1/2", J-55 tbg w/tail @ 6775' Packers and SSSV (type and measured depth) 7042'-7056' MD 6320'-6331' TVD Measured depth 110' 2342' 7322' True vertical depth 110' 2342' 6543' FHL packer ~ 6705'~ TRDP 1A-SSA SSSV @ 1797' 13. Stimulation or cement squeeze summary A Sand refracture treatment. Intervals treated (measured) 6994'-7056' Treatment description including volumes used and final pressure 14. Pumped total of 1338 bbls gelled diesel, 144156 # of 16/20 mesh Carbo-Lite WHTP 5400. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1094 525 1100 150 1390 887 31 1160 205 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 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 Form { 0-404 R~v'-06/15/88 Title sDL~M, T~i N~D U~p ~11 C C'JAT ~E WELL ARCO Alaska, Subsidiary of Atlantic Richfield Company' iPBDT CONTRACTOR REMARKS JFIELD - DISTRICT- STATE '~ OPERATION AT REPORT TIME WELL SERVICE REPOR' IDAYS iDATE ~-~ %D Coq. ~5~P / o o ./GO ,~ -P~o ~ S 3430 .50 '75 I I 'Aooo I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather J Temp' J Chill Fact°r I Visibility ]WlndVel'Report *F *F miles J Signed t ARCO Alaska, Inc. Date: September 30, 1988 Transmittal #: 7307 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-11 Kuparuk Well Pressure Report 9-22-88 Amerada 1 E- 0 6 Kuparuk Fluid Level Report 9 - 2 5 - 8 8 Casing 3 J - 1 0 Kuparuk Fluid Level Report 9 - 2 5 - 8 8 Casing 3 C- 1 1 Kuparuk Well Pressure Report 8 - 1 3- 8 8 Amerada 3 C- 1 1 Bottom-Hole Pressure Survey 8 - 1 3 - 8 8 Receipt Acknowledged' DISTRIBUTION: D&M State of Alaska SAPC Unocal Chevron Mobil ARCO Alaska, Inc. Date: August 12, 1988 Transmittal Cf: 7257 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 31 - 1 2 Kuparuk Well Pressure Report 6 - 1 5 - 8 8 Amerada 1 G-04 Kuparuk Well Pressure Report 7 - 1 6 - 8 8 Amerada 2 T- 0 6 Post Frac Job Report 7 - 1 8 - 8 8 Allo Frac A-10 3Q-15 Kuparuk Stimulation Summary 8-07-88 Cf230DS36QL 3J-10 kuparuk Stimulaiton Summary 8-08-88 Cf230DS36JL 2V-11 Kuparuk Stimulation Summary 8-03-88 Cf230DS28VL I R- 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing 1 F - 0 7 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing 2 D - 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ARCO Alaska, Inc. ~ Posl Office Box I00360 Anchorage, Alaska 99510-0360 0 Telephone 907 276 1215 August 8, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2 D - 6 Refracture August, 1988 2 D- 1 5 Stimulate August, 1988 -~3J-.,4~.~_~ ~. Refracture August, 1988 2 Z- 2 Conversion May, 1988 2 Z- 8 Conversion May, 1988 2 Z- 1 1 Conversion October, 1988 2 Z- 1 4 Conversion September, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Srri~llwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 ARCO Alaska. Inc. is a Subsidiary of AllanllcRIchlleldCompany 1. Type of Request: STATE OF ALASKA ALAS'K'A OIL AND GAS CONSERVATION COMbl'rSSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend ' ' Operation Shutdown ii Re-enter suspended well [~ Alter casing [] Time extension Change approved program L! Plugging ~ Stimulate .,~ Pull tubing : ' Amend order·m. Perforate L_r' Other ~ ;'~ 2. Name of Operator &~rn al~:ka Inc 3. Address P.O. Bnx 100360. Anchoraoe. Alaska gg5]O 4. Location of well at surface 1015' FSL, 565' FWL, Sec. 3, T12N, ReE, UN At top of productive interval 1304' FSL, 1252' FEL, Sec. 4, TllN, ReE, UN At effective depth 1364' FSL, 1151' FEL Sec. 4 T11N ReE UM At total depth ' ' ' ' _~_~7q' F_qL~ !577' FF~ -~ec~ 4~ TI_I_Nj DeE, UM 11. Present well condition summary Total depth: measured 7344 ' feet true vertical 6561' feet Plugs (measured) 5. Datum elevation (DF or KB) ~R 74' 6. Unit or Property name K~paruk River Unit 7. Well number 3J-10 feet 8. Permit number 85-250 9. APl number 50-- 02921467 10. Pool Kuparuk River Oil Pool Effective depth: measured 7231 ' feet true vertical 6470 ' feet Junk (measured) Casing Length Structural Conductor 80' Surface 2310' Intermediate Production 7322' Liner Perforation depth: measured Size Cemented Measured depth 16" 171 Sx AS II 110' 10-3/4" 1000 Sx AS III & 2342' 140 Sx-Class' G 7" 610 Sx Class G & 7322' 250 Sx AS I 7004', 7008', 7036', 7042'-7056' MD True Vertical depth 110' 2342' 6543' true vertical 6290' 6293' 6315' 6320' -6331' TVD Tubing (size, grade and measured depth) 3 1/2", J-55 tbg w/tail Packers and SSSV (type and measured depth) '~ ; ........... - .... ~ ........ ~ ......... operations 12.Attachments D~scription summary of proposal~ Detailed~- .... program Refrarture A Sand with gelled diesel and !6/20 M Carbe-Lit~. 13. Estimated date for commencing operation 8/0~/88 14. If proposal was verbally approved Name of approver Z , ~ I1; 15. I hereby certify that the forgoing is true and correct to th~best of my knowledge Signed ,/~(~_///,,4f .j~ Z~~ '~c..~ Title " ' Commission Use ~nly Conditions of approval Notify commission so representative may witness Approved by [] Plug integrity [] BOP Test D Location clearanceI Approval No. Date '~/~/~ ~ ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy ~_,~,l~eturned Commissioner the commission Date<~ It / Submit in triplicate /-v/ Kuparuk Well 3J-10 Well 3J-10 is currently an A Sand only producer. The A Sand will be re-fractured to improve flow efficiency. A copy of the proposed procedure is attached. The fracture stimulation will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A 10,000 psi 'tree saver' will be used during the fracture stimulation. The average reservoir pressure of the A Sand is estimated to be 2600 psi as of 6/1/88. The C Sand has less than 1' of net pay and is separated from the A Sand by 110' of B Sand in this well. RECEIVED AUG 1 Aiaska Oil & Gas ~' .... -~,, ..... ,~,, ..... Treatment Procedure: 1. RU fracturing equipment. Install "Tree Saver". Pressure test all lines. 2. Pressure up annulus to prevent buckling the tubing. Set pressure to account for thermal effects, achieving a maximum of 3500 psi during the treatment. 3. Pump 100 bbl Pre-pad stage. Shut down for ISIP calculations. * Check tank straps against metered volume. Correct flush volume accordingly. 4. Set pumps to trip off at 7300 psi wellhead pressure. Rate should be reduced if pressure exceeds 7000 psi. 5. Pump fracture treatment per attached schedule: * All slurry stages should be mixed "on-the-fly". * Use silica flour in the PRE-PAD and PAD ONLY at 40 Ibs/Mgal. Slurry stages should contain NO silica flour. * Strap tanks "on-the-fly" during the pad stage to insure meter accuracy. * Ramp up slowly between slurry stages to avoid high density spikes. * Take gel samples during the slurry stages to monitor gel quality and to determine appropriate break times. * Call flush as the densimeter drops from 10 PPG. * Expected Wellhead Treating Pressure: WHTP 5575 psig Fracture Gradient 0.69 psi/ft TVD (6310' TVD) Tubing Friction 180 psi/1000 ft (6775' MD) 6. Bleed down annulus pressure after the treatment. 7. RD fracturing equipment. ARCO Alaska Inc. {~ a ~JI3lldlaty of At~antl~ Richfield Company AR3B.6001-A STAG~ FLUID DESCRIPTION KUPARUK WELL 3J-10 'A' SAND REFRACTURE PUMPING SCHEDULE 'A' *June 27, 1988' CLEAN VOLUME PUMP RATE PROP. ~C. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS ' 1 DIESEL/10% MUSOL 60.0 1 2 DIESEL FLUSH 60.0 1 .............................................. SHUT DOWN 3 GD PRE-PAD 100.0 2 5 ................................................... SHUT 4 GDPAD 800.0 2 5 5 GD w/2 PPG 45.9 2 5 6 GD w/4 PPG 42.5 2 5 7 GD w/6 PPG 59.3 2 5 8 GD w/8 PPG 73.9 2 5 9 GD w/9 PPG 71.6 2 5 1 0 GD w/10 PPG 69.4 2 5 1 0 GD w/12 PPG 13.1 2 5 1 1 GD FLUSH 59.0 +SV 2 5 0 - - 0 60/ 60 60 0 - - 0 60/ 1 20 1 20 OVERNIGHT TO SOAK ................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 1 00/ 1 00 60 DOWN FOR ISIP ...................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 800/ 900 1 60 2 16/20 M CARBO-LITE 3860 50/ 950 960 4 16/20 M CARBO-LITE 7141 50/ 1000 101 0 6 16/20 M CARBO-LITE 14947 75/ 1075 1060 8 16/20 M CARBO-LITE 24841 100/ 1175 1135 9 16/20 M CARBO-LITE 27065 100/ 1 275 1235 1 0 16/20 M CARBO-LITE 291 52 100/ 1375 1335 1 2 16/20 M CARBO-LITE 6593 20/ 1395 1435 0 - - 0 59/ 1434 1435 NOTES: TOTAL GELLED DIESEL= 1334.8 BBLS + SV TOTAL DIESEL = 114.0 BBLS TOTAL MUSOL = 6.0 BBLS ISTAGE SUFFICIENT SUPPLIES OF GELLED DIESEL AND PROPPANT TO SATISFY CONTINGENCY FOR AN ADDITIONAL 100 BBL OF 10 PPG. 1. All fluids should be maintained at 70 to 90 F on the surface. 2. Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. 3. Stages 5 through 10 are Gelled Diesel (8 hour break), WITHOUT SILICA FLOUR. 4. Stage 11 is Gelled Diesel with Iow temperature breaker ( 8 hour break). 5. Stage 11 should include a volume adjustment for surface equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 1.0 bbl. The blender tub should be bypassed at flush. 16/20 M CARBO-LITE = 113600 LBS SILICA FLOUR = 1 51 2 LBS ARCO Alaska, Inc.. · Posl Office Box 100360 Anchorage, Alaska 995i0-0360 Telephone 907 276 12i5 CONFIDENTIAL August 8, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3J-10 Core Description Dear Mr. Chatterton' Enclosed is a copy of the 3J-10 Core Description to include with the Well Completion Report. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG'hf Enclosures cc- 3J-10 Well File GRU14/O20b ARCO Alaska, !nc, is a Subsidiary of AtlanticRichfieldConlpany ARCO ALASKA, INC. KRU 3J-10 CORE CHIP DESCRIPTIONS DEPTH(MD) DESCRIPTION SEC. 3, T12N, R9E U.M. CONFIDENTIAL 2452 SILTSTONE, 2455 SILTSTONE, 2458 SANDSTONE, 2461 SANDSTONE, 2464 SILTSTONE, 2467 SILTSTONE, 2470 SILTSTONE, 2473 SANDSTONE, 2476 SANDSTONE, 2478 SANDSTONE, 2479 SANDSTONE, 2483 SANDSTONE, 2486 SANDSTONE, 2489 SANDSTONE, 2491 SANDSTONE, 2494.5 SILTSTONE, 2498 MUDSTONE, N 2501 SANDSTONE, 2504 SANDSTONE, 2507 SANDSTONE, 2510 SANDSTONE, 2513 SANDSTONE, 2516 SANDSTONE, 2519 SANDSTONE, 2535 SANDSTONE, 2538 SANDSTONE, 2541 SANDSTONE, 2544 SANDSTONE, 2547 SANDSTONE, 2550 SANDSTONE, 2553 SANDSTONE, 2555 SANDSTONE, 2562 SANDSTONE, 2566 SANDSTONE, 2570-2574 RECOVERED 2 LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN LITTLE POROSITY, NO OIL STAIN SOME POROSITY, SOME OIL STAIN POROUS, SOME OIL STAIN POROUS, SOME OIL STAIN POROUS, NO OIL STAIN POROUS, NO OIL STAIN SILTSTONE, LITTLE POROSITY, POROUS, NO OIL STAIN POROUS, LITTLE OIL STAIN LITTLE POROSITY, NO OIL 0 OIL STAIN SILTY, LITTLE POROSITY, POROUS, OIL STAIN POROUS, OIL STAIN POROUS, OIL STAIN POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL POROUS, OIL '(RUBBLE) 2574 SILTSTONE, LITTLE PO 2577 SANDSTONE, POROUS, 0 2580 SANDSTONE, POROUS, 0 2583 SILTSTONE, LITTLE PO 2586 SILTSTONE, LITTLE PO SANDSTONE, POROUS, 0 2589 SANDSTONE/SILTSTONE, 2592 SANDSTONE, POROUS, 0 2595 SANDSTONE, POROUS, 0 2598 SANDSTONE, POROUS, 0 2601 SANDSTONE, POROUS, 0 2603 SANDSTONE, POROUS, 0 STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN - SANDSTONE, SILTSTONE, ROSITY, IL STAIN IL STAIN ROSITY, ROSITY, IL STAIN LITTLE IL STAIN IL STAIN IL STAIN IL STAIN IL STAIN STAIN NO OIL NO. OIL STAIN STAIN POROUS, OIL STAIN LITTLE POROSITY, NO OIL STAIN NO OIL STAIN NO OIL STAIN POROSITY, NO OIL STAIN NO OIL STAIN 2606 2609 2612 2615 2618 2620 2623 2624 2627 2630 2633 2636 2639 2642 2645 2648 2652 2654 2657 2660 2663 2666 2669 2672 2675 2678 2680 2687 2690 2693 2696 2699 2702 2705 2708 2711 2714 SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, SOME OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL SANDSTONE, POROUS, OIL STAIN SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE/SANDSTONE, SOME POROSITY, OIL STAIN SANDSTONE/SILTSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN , SILTSTONE, LITTLE POROSITY, NO OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN CLAYSTONE, NO OIL STAIN SILTSONE, SOME POROSITY, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SANDSTONE, POROUS, OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL SILTSTONE, LITTLE POROSITY, NO OIL STAIN SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL SILTSTONE/SANDSTONE, LITTLE POROSITY, NO OIL STAIN STAIN STA:IN STAIN STAIN STAIN STATE OF ALASKA ALAS~'~ OIL AND GAS CONSERVATION COMIV~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown i l Re-enter suspended well ~ Alter casing [] Time extension Change approved program L! Plugging ~ Stimulate.~ Pull tubing ~ ' Amend order ['~ Perforate £'i Other [] 2. Name of Operator 3. Address P.O. Bnx 100360: Anchorage: Ala_~ka 99510 4. Location of well at surface 1015' FSL, 565' FWL, Sec, At top of productive interval 1304' FSL, 1252' FEL, Sec, 4, TllN At effective depth 1364' FSL, 1151' FEL, Sec, 4, T11N At total depth ]27q' F.SI ~ 1E77' FFI ; C,~r: 4; TI_IN 11. Present well condition summary Total depth: measured 7344 true vertical 6561 3, T12N, R9E, UM , R9E, UN · R9E. UN ~ 1~gF~ UM I feet ' feet Plugs (measured) 5. Datum elevation (DF or KB) ~R 74' 6. Unit or Property name Kuoaruk River Unit 7. Well number 3J-10 feet 8. Permit number 85-250 9. APl number 50-- 02921467 10. Pool Kuparuk River 0il Pool Effective depth: measured 7231' feet true vertical 6470' feet Junk(measured) Casing Length Size Structural ConduCtor 80' 16" Cemented Measured depth 171 Sx AS II 110' True Vertical depth 110' Surface 2310' Intermediate Production 7322' Liner Perforation depth: measured 10-3/4" 1000 Sx AS III & 2342' 140 Sx Class'G 7" 610 Sx Class G & 7322' 250 Sx AS I 7004' 7008' 7036' 7042'-7056' MD 2342' 6543' true vertical 6290' 6293' 6315' 6320'-6331' TVD Tubing (size, grade and measured depth) 3 1/2", J-55 tbg w/tail @ 6775' Packers and SSSV (type and measured depth) 12.Attachments Description summa~ ot proposam~ 'D~d~p~}a~Fons program G R~-actu,e A S~nd ~!th ~e!!ed diesel ~nd [6/20 H Ca,be-Lite. 13. Estimated date for commencing operation BOP sketch [] 8/o /88 14. If proposal was verbally approved Name of approver Z , .~ 11 ~ Date approved 15. I hereby certify that the foregoing is true and correct to th~)best of my knowledge Signed ~/~,~¢/~ j~ .Z/~b¢~-~-c~0~r-~ Title ~J~'/t ~~~~ ~j- ....'~' Commission Use ~nly ~ Conditions of approval Notify commission so representative may witness [ Approval No. D Plug integrity ~ BOP Test ~ ~cation clearanceI ORIGINAL SIGNED BY LONNIE C. SMITH Approved by ~,pproved Copy Retuj'ned Commissioner Form 10-403 Rev 12-1-85 Date -S~/~-/~ y the commission Date <~ ~t ~ Submit in triplicate Kuparuk Well 3J-10 Well 3J-10 is currently an A Sand only producer. The A Sand will be re-fractured to improve flow efficiency. A copy of the proposed procedure is attached. The fracture stimulation will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A 10,000 psi 'tree saver' will be used during the fracture stimulation. The average reservoir pressure of the A Sand is estimated to be 2600 psi as of 6/1/88. The C Sand has less than 1' of net pay and is separated from the A Sand by 110' of B Sand in this well. Treatment Procedure: I . . 1 . . RU fracturing equipment. Install "Tree Saver". Pressure test all lines. Pressure up annulus to prevent buckling the tubing. Set pressure to account for thermal effects, achieving a maximum of 3500 psi during the treatment. Pump 100 bbl Pre-pad stage. Shut down for ISIP calculations. * Check tank straps against metered volume. Correct flush volume accordingly. Set pumps to trip off at 7300 psi wellhead pressure. Rate should be reduced if pressure exceeds 7000 psi. Pump fracture treatment per attached schedule: * All slurry stages should be mixed "on-the-fly". * Use silica flour in the PRE-PAD and PAD ONLY at 40 Ibs/Mgal. Slurry stages should contain NO silica flour. * Strap tanks "on-the-fly" during the pad stage to insure meter accuracy. * Ramp up slowly between slurry stages to avoid high density spikes. * Take gel samples during the slurry stages to monitor gel quality and to determine appropriate break times. * Call flush as the densimeter drops from 10 PPG. * Expected Wellhead Treating Pressure: " WHTP 5575 psig Fracture Gradient 0.69 psi/ft TVD (6310' TVD) Tubing Friction 180 psi/1000 ft (6775' MD) Bleed down annulus pressure after the treatment. RD fracturing equipment. ARCO Alaska AR3~-e0Ot-A STAGE FLUID DESCRIPTION KUPARUK WELL 3J-10 'A' SAND REFRACTURE PUMPING SCHEDULE 'A' *June 27, 1988' CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 DIESEL/10% MUSOL 60.0 1 2 DIESEL FLUSH 60.0 1 .............................................. SHUT DOWN 3 GD PRE-PAD 100.0 2 5 ................................................... SHUT 4 GD PAD 800.0 2 5 5 GD w/2 PPG 45.9 2 5 6 GD w/4 PPG 42.5 2 5 7 GD w/6 PPG 59.3 2 5 8 GD w/8 PPG 73.9 2 5 9 GD w/9 PPG 71.6 2 5 1 0 GD w/lO PPG 69.4 25 1 0 GD w/12 PPG 13.1 2 5 1 1 GD FLUSH 59.0 +SV 25 0 - - 0 60/ 60 60 0 - - 0 60/ 1 20 1 20 OVERNIGHT TO SOAK ................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 1 00/ 1 O0 60 DOWN FOR ISIP ...................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 800/ 900 1 60 2 16/20 M CARBO-LITE 3860 50/ 950 960 4 16/20 M CARBO-LITE 7141 50/ 1000 101 0 6 16/20 M CARBO-LITE 14947 75/ 1075 1 060 8 16/20 M CARBO-LITE 24841 1 00/ 1175 1135 9 16/20 M CARBO-LITE 27065 1 00/ 1 275 1235 1 0 16/20 M CARBO~LITE 291 52 100/ 1375 1335 1 2 16/20 M CARBO-LITE 6593 20/ 1395 1435 0 - - 0 59/ 1434 1435 NOTES: TOTAL GELLED DIESEL = 1334.8 BBLS + SV TOTAL DIESEL = 114.0 BBLS TOTAL MUSOL = 6.0 BBLS STAGE SUFFICIENT SUPPLIES OF GELLED DIESEL AND PROPPANT TO SATISFY CONTINGENCY FOR AN ADDITIONAL 100 BBL OF 10 PPG. · 1. All fluids should be maintained at 70 to 90 F ~)n the surface. 16/20 M CARBO-LITE = SILICA FLOUR = 2. Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. 3. Stages 5 through 10 are Gelled Diesel (8 hour break), WITHOUT SILICA FLOUR. 4. Stage 11 is Gelled Diesel with Iow temperature breaker ( 8 hour break). 5. Stage 11 should include a volume adjustment for surface equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 1.0 bbl. The blender tub should be bypassed at flush. 113600 LBS 1512 LBS ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt=and return one signed copy of this transmittal. t30-15 Kuparuk Fluid Level Report 7- 1 I - 8 8 Tubing 30-10 Kuparuk Fluid Level Report 7- 1 I - 8 8 Tubing 2 D- 1 5 Kuparuk Fluid Level Report 7 - 1 2 - 8 8 Casing 2A-06 Kuparuk Fluid Level Report 7-1 2-88 Tubing 1 G-07 Kuparuk Fluid Level Report 7- 0 8 - 88 Casing 1 G- 08 Kuparuk Fluid Level Report 7- 0 8 - 8 8 Casing 1 G- 15 Kuparuk Fluid Level Report 7- 0 8 - 8 8 Casing 31 - 01 Kuparuk Fluid Level Report 7- 0 8 - 8 8 Tubing 31 - 1 2 Kuparuk Fluid Level Report 7- 0 8 - 8 8~- Tubing · 2A-03 Kuparuk Fluid Level Report 7-06088 Casing 3 H - 1 4 Post Frac Job Report 7- 0 9 - 8 8 AIIo Frac A-10 2 B - 1 6 Bollom Hole Pressure- Survey 7 - 03 - 8 8 PBU 3 J - 1 0 Kuparuk Well Pressure Report 3 - 0 8 - 88 Amerad Receipt Acknowledged: --'- ........................ Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ARCO Alaska, Inc. Post Office E,,_~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Hand-carried' SA$1P LE TRJLNSMITTAL · SHIPPED TO: State of Alaska Oil '& Gas Conservation Commission ' 3001 Porcupine Dr. . ' Anchorage, Ak. 99501 Attn: John Boyle ;.~. ... OPERATOR' Arco S:~'qPLE TYPE' core chips DATE- 6-20-88 SAMPLES SENT' 2457.05 - 2494.05-' 2496.05 - 2526.15 25.27.10 2527.95- 2529.05 - 2545.05 2547.15 - 2561.3 2562.'2 2562.9 2563.9 2565.05 - 2598.05 2600.05 - 2631.05 2633.05 - 2637.05 2639.05 - 2667.05 2668.95 2668.95 2670.05 2671.1 2673.1 - 2700.05 (one'sample per foot) l! II II .j UPON RECEIPT OF THESE SBZPLES, COPY OF THIS FOPdq TO' Bavview Facility CagrS~nator PLEASE NOTE ;uNY DISCREP;UNCIES AND bi, IL A SIGNED I ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 9'9510 ATTN' Paleo Lab ATE' RECEIVED ~'~ ~~'~ .-.- ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc?._. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5943 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3I-3 3I-4 3J-10 3J-11 3I-8 3I-7 3I-5 3N-2A CET 2-12-86 6100-7610 CET 2-12-86 6300-8280 CET 2-11-86 5686-7181 CET 2-11-86 6084-7520 CET 3-8-86 7400-9176 CET 3-8-86 4950-7238 CET 3-7-86 6100-9948 CET 2-15-86 7315-8761 RecJipt Acknowledged: DISTRIBUTION: Drilling Mobil NSK 0il & Gas Orals. BPAE Anch~lti~.ron SAPC Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary o! AllanilcRichlleldCompany ' ,_,.. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C0'~MISSION _~ " WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well /// //////// O1~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , . . 2. Name of Operator 7. Permit Number ARCO Alaska, I nc. 85-250 .~'~ 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21467 4. Location of well at surface 9. Unit or Lease Name 1015' FSL, 565' FWL, Sec.3~ T12N~ RgE~ UN Kuparuk River Unit 1'01 Well Number At Top Producing Interval 1304' FSL, 1252' FEL, Sec.4, T12N, RgE, UM 3J-10 At Total Depth 11. Field and Pool 1379' FSL, 1577' FEL, Sec.4, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 74' RKBI ADL 25630 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.,.Susp'~ or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/27/85 1 2/09/85 05/11/86* "~' ,) N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Dire~{~n~i~Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7344'MD,6561 'TVD 7231 'MD,6470'TVD YESX~~-] NO [] 1797 feetMDI 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR, DIL, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6~ hz.5# H-40 Surf 11'0' '' '2'4-" ' 171 sx AS II · 10-3/4" 45.5# J-55 Surf 2342' 13-1'/2" 1000 sx AS Ill & 140 sx ;lass G 7" 26.0# J-55 Surf 7322' 8-1/~" 610 sx Class G & 250 sx ~,S I r' -- . 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) . . 7004 ' 3-1/2" 6775 ' 6705 7008' w/1 spf, 90° phasing _ . 7036' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7042' - 7056' w/4 spf, 90° phasing See attached addendum for fracture data. . . 27. N/A PRODUCTION TEST . ~ - Date First Production Method of Operation (Flowing, gas lift, etc.) Dat; of Tes~' Hours Tested PRODUCTION FOR 01L-BBL ' -GAs-McF ' WA'I~ER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Fiow T;bing' Casing Pressur'e CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (corr) Press. 24-HOUR RATE i~ 28. CDR E DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. jun 2 4 /ktaska 0ii & G~s Cons. C0rn~'$s~0tl Anchorage Form 10~07 * NOTE: Drilled RR 12/10/85. Well perf'd & tubing run 4/10/86. WCl/064 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME -- Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6803' 6136' N/A Base Kuparuk C 6873' 6189' Top Kuparuk A 6980' $271' Base Kuparuk A 7132' $391' .. 31. LIST OF ATTACHMENTS -_ Addendum (dated 6/9/86) : 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~.~ j(~~_~ TitieASSociate 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- lng 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: 3J-10 12/30/85 Arctic Pak well w/250 sx AS I, followed by 87.5 bbls Arctic Pak. 1/31/86 RU DA, rn DIL f/2460'-2770' WLM, RD DA. 2/13/86 Rn CET/GR/CCL & 6.125" gage ring f/7185'-5684'. Rn GCT gyro f/7135'-surf. 5/8/86 Frac'd "A" sand perfs 7004', 7008', 7036' (1 spf) & 7042'-7056' (4 spf) in 7 stages per 4/30/86 procedure using 5% Musol/diesel/spear, YFGO II gelled diesel. Press'd ann to 2800 psi w/diesel. Tst ins to 9000 psi; OK. Stage 1: 20 bbls 5% Musol/diesel @ 2 BPM, 2600 psi. Stage 2: 68 bbls YFGO II @ 1.0/1.0 BPM, 2900/2700 psi. Stage 3: 11 bbls YFGO II @ 20 BPM, 4500 psi. Stage 4: 20 bbls YFGO II @ 20 BPM, 4300 psi. Stage 5: 18 bbls YFGO II @ 20 BPM, 4000 psi. Stage 6: 75 bbls YFGO II @ 20 BPM, 4000 psi. Stage 7: 9 bbls YFGO II @ 20 BPM, 4000 psi. Ail pmp'g equipment sanded up. Abort frac, SI well. 5/lO/86 Frac'd "A" sand perf (same as above) in 6 stages per 5/10/86 procedure using YFGO II gelled diesel w/40#/1000 gal Silica flour. Stage 1: 65 bbls YFGO II w/8 ppg 100 mesh @ 5 BPM, 3000/2700 psi. Stage 2: 8 bbls YFGO II @ 20 BPM, 4100/2700 psi. Stage 3: 74 bbls YFGO II @ 20 BPM, 3800/2800 psi. Stage 4: 19 bbls YFGO II w/3 ppg 20/40 @ 20 BPM, 3500/2900 psi. Stage 5: 25 bbls YFGO II w/8 ppg 20/40 @ 20 BPM, 3400/3000 psi. Stage 6: 65 bbls YFGO II @ 20 BPM, 4000/3000 psi. Pmp'd 33 bbls of 8 ppg stage in formation leaving 2.5 bbl stage containing 840# 20/40 sand (24' fill) in 7" csg. Load to recover 256 bbls of diesel. Job complete @ 1310 hrs, 5/11/86. 5/15/86 Drilling Superintendent Rn CTU cln out operations. Turn well over to Production. RECEIVED JUN 2 4 l~8~ate Alaska Oil & Gas Cons. Corem .... ~,~ STATE OF ALASKA ALASK'-,-,,cJIL AND GAS CONSERVATION COMM,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging Alter Casing ~ Other ,'Z~(~0r-r~¢~,..~-.¢,_~ 2. Name of Operator ARCO Alaska~ Inc. 3. Address P_O. Box 100360 Anchor=ge, AK 99510 4. Location of well at surface 1015'FSL~ 565'FWL~ Sec.3, T12N~ RgE~ UH At top of productive interval 1304' FSL~ 1252'FEL, Sec.#, T12N, R9E, UN At effective depth 1364'FSL, 1511 'FEL, Sec.4, T12N, R9E, UM At total depth 1379'FSL, 1577'FEL, Sec.4, T12N, R9E, UM Perforate ~ Pull tubing 5. Datum elevation (DF or KB) RKB 74 ' 6. Unit or Property name ,~. ....... ,. o- ,,'"r Un~. t 7'. ~e~l' r~t~'ml~r'v ~.,I - 1 r~ 8. Approval number Permit #85-250 9. APl number 50-- 029-21467 10. Pool Kuparuk River Oil Pool Feetz 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface feet 7344 feet 6561 Production 7231 6470 Length Size 80 ' I 6" 231 0 ' I O- 3/4" 7322 ' 7" feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 171 sx AS II 1lO'MD 1000 sx AS I I I & 2342 'MD 140 sx Class G 610 sx C1 ass G & 7322 'MD 250 sx AS I ~ueVerticaldepth 110'TVD 2342'TVD 6543'TVD Perforation depth: measured 7004 'MD 7008 'MD true vertical 6290 ' TVD 6293 'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail 8 6775'HD Packers and SSSV (type and measured depth) FHL pkr @ 6705' and TRDP-1A-SSA SSSV @ 1797' 7036 'MD 7042' - 7056'MD 631 5 'TVD 6320' - 6331 'TVD 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing PressUre 14. Attachments (Completion Wel 1 History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-8 Title A.~_~nni R~ Fnni n~r (DAM) SWO/020 Date ~'--1_~ ¢~/~ Submit in Duplicate ~ ~ AtlanticRichfieldCompan~''l '~' Daily Well History-Final Report Instructions: Prepare and submit the "Flnll 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 ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25630 Auth, or W.O. no. ITItle AFE AK0171 I Completion ! Nordic #1 API 50-029-21467 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun I Date Complete I 4/10/86 Complete record for each day reported IAccounting cost center code State Alaska Date and depth as of 8:00 a.m. 4110186 thru 4/11/86 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our I Prlor status if a W.O. 0045 hrs. 1715 hrs. 7" @ 732~' 7231' PBTD, RR Diesel Accept rig @ 0045 hrs, 4/10/86. ND tree, NU & tst BOPE. Perf w/4" gun, 4 SPF, 90° phasing @ 7004', 7008', 7036' & 7042'-7056' Rn 216 its, 3½", 9.3#, J-55 8RD AB MOD tbg w/TT @ 6775', SSSV'@ 1797', FHL Pkr @ 6705'. 'Set pkr @ 6705'. Tst tbg & ann, shear PBR, lnd tbg. ND BOPE. NU & tst tree. Displ well to diesel. RR @ 1715 hfs, 4/10/86. IWell no. 3J-10 Old TD New TD 7231' Relea~d rig Date Rotary Classifications (o11, ga~, etc.) 0il Producing method Flowing JPB Depth Kind of 4/10/86 Type completion (single, dual, etc.) Single Official rese~olr name(s) Kuparuk Sands Potential test data 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. IDate ITitle Drilling Superintendent ARCO Alaska. Inc. Post Office ~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewit~h are the following items. return one signed copy of this transmittal. Final Prints: Dresser Atlas: One * of each . 2H-2 2V-10 2V-13 3J-10 3J-15 Comp. Neu. Gamma Ray 12-03-85 Comp. Neu. Gamma Ray 12-02-85 Comp. Neu. Gamma Ray 12-02-85 Carbon/Oxygen Gamma Ray 01-29-86 Carbon/Oxygen Gamma Ray 01-30-86 04-15-86 ~"TU%NSMITTAL # 5629 Please acknowledge receipt and Run #3 7400-7655 R'.-'. n # 7000-7300 Run #3 8210-8314 Run #1 2460-2770 Run #1 2530-2980 Receipt Acknowledged: ~:~t~te of AK*bl/se ~. :.. :,.... .... ._. Vault*films NSK Cierk*bi Dri!iLnc*b! STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION cO,'~I'MIsSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED7~ ABANDONED [] SERVICE [] '~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-250 __ 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21467 -- 4. Location of well at surface 9. Unit or Lease Name 1015' FSL~ 565' FWL, Sec.3, T12N~ R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1304' FSL, 1252' FEL, Sec.4, T12N, RgE, UM 3J-10 At Total Depth 11. Field and Pool 1379' FSL, 1577' FEL, Sec.4, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 74' RKBJ ADL 25630 ALK 2563 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/27/85 1 2/09/85 1 2/1 0/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7344'MD,6561 'TVD 7231 'MD,6470'TVD YES [~X NO []I N/A feet MD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR, DIL, CET/GR/CCL, 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 110' 24" ~71 sx AS II 10-3/4" 45.5# J-55 Surf 2342' 13-1/2" 1000 sx AS Ill & 140 s~ Class G 7,, 26.0# J-55 Surf 7322' 8-1/2" 610 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD') None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A . 27. N/A PRODUCTION TEST ,.. Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description to be submitted when received. ~.~c~IVE APRO 4 1985 Form 10-407 DAM2/WC11 Submit in duplicate~) Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 6803' 6873' 6980' 7132' TRUEVERT. DEPTH 6136' 6189' 6271 ' 6391 ' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR. and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86), Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Oa'.e #-2 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". i Form 10407 ADDENDUM WELL: 12130/85 1/31/86 2/13/86 3J-10 Arctic Pak well w/250 sx AS I, followed by 87.5 bbls Arctic Pak. RU DA, rn DIL f/2460'-2770' WLM, RD DA. Rn CET/GR/CCL & 6.125" gage ring f/7185'-5684'. Rn GCT gyro f/7135'-surf. · Drilling ~Superintendent D~te 2~ _ 5~ 9 I0 NOTES I. COORDINATES ARE A.S.P.,ZONE 4 7- 2. SECTION LINE DISTANCES ARE TRUE. :3 HORIZONTAL POSITIONS BASED ON THE D.S.-$J NORTH- WEST 8 SOUTHWEST WINDOW CORNERS PER ER.B.&ASSOC. 4. VERTICAL POSITIONS BASED ON TBM 85-7-27-1 PER 8- LHD I~ ASSOC. 5. C.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- RlXX--3060 rev. _.¢ oF ~ '~. ~ F. ROBERT BELL I HEREBY CERTIFY THATIAM PROPERLY REGISTERED AND 13- LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY iMADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF JULY 30, 1985. 14- AS P' "LT Y= 6,002,42 X= 519,544. 563 FWL, 7 Y= 6,002,44 X= 519,544. 563 FWL, 7 Y= 6,0.02,47 X: 519,544. 563 FWL, 7 Y: 6,002,49 X= 519,544. 564 FWL, 8 Y- 6,002,52 X= 519,544. 564 FWL, 8 Y= 6,002,54 X= 519,544. 564 F~L, 8 Y= 6,002,57 X= 519,544. 564 FWL, 8 Y: 6,002,59 X= 519,544. 564 FWL, 9 Y= 6,002,67 X= 519,544. 564 FWL, 9 Y: 6,002,69 X= 519, 544. 565 -"~L, 1 Y= 6,002,72 X= 519.544. 565 F ,', L , 1 Y: 6,002,74 x= 519,544. 565 FW:, 1 Y= 6,0'.],77 X: 5.19. -'./,4. 565 r~. _, 1 Y= 6, O'L ~', 79 X= 519. 565 F~ __, 1 CONDUCTORS 1-16 - 2.64 6O 40' FSL, 7.64 66 65~ FSL, 2.59 60 90~ FSL, 7.59 63 15~ FSL, 2.57 65 40~ FSL, 7.61 65 65~ 2.61 67 90' 7.57 68 LAT. 70025 04.020" LONG. 149°50 26.870" OG. 41.3, PAD 45.3 LAT. 70o25 04.266" LONG. 149°50 26.866" 0G.41.0, PAD 45.6 LAT. 70°25 04.512" LONG. 149°50 26.866" OG. 40.9, PAD 45.4 LAT. 70°25 04.758" LOflG.' 149°50 26.863m OG. 40.8, PAD 45.5 LAT. 70o25 05.003" LONG. 149o50 26.861" OG. 40.9 PAD 45.4 LAT. 70o25 05.250" LONG. 149°50 26.859" FSL, OG. 41.0, PAD 45.4 LAT. 70°25 05.495" LONG. 149o50 26.856# FSL, OG. 41.1, PAD. LAT. 70025 05.741" LONG. 149°50 26.854a 15 FSL, OG. 41.2, 2.63 LAT. 74 LONG. 90' FSL, OG. 7.65 LAT. 74 LONG. 015~ FSL, OG. 2.64 LAT. 73 LONG. 040~ FSL, OG. 7.62 LAT. 78 LONG. 065~FSL, OG. 2.67 LAT. 78 LONG. 090' FSL, OG. 7.59 LAT. PAD. 45.3 70025 06~479" 149°50 26.846" 41.0, PAD 45.5 70o25 06.725' 149o50 26.845" 41.0 PAD 45.4 70o25 06.971" 149°50 26.843" 40.7 PAD 45.3 70o25 07.217" 149o50 26.840' 40.7, PAD 45.5 70o25 07.463" 149050 26.837m 40.4, PAD 45.4 70o25'07.708' 78 LONG.149°50'26.836' 115' FSL, OG 40.3, PAD 45.5 X= 519. S~4.80 LONG. 149°50'26.833" 565 6,002,847.58 LAT. 70°25'08.200'' X: 519.544.80 LONG. 149°50'26.831'' :;~ ! LOCATED IN PROTRACTED SEC. 3 TI2N, R9E,U. MER. 15- Y= 6,0L :,822.60 LAT. 70°25'07.954'' ARCO Alaska, Inc. Post Office Bo'"6~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are the Well Completion Report for the following wells: 3J-10 3J-11 The bottomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L126 Enclosures ARCO Alaska, Inc, is a Subsidiary ol AtlanticRichfieldCompany STATE OF ALASKA ALASKA OI~L AND GAS CONSERVATION cO,'~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDEDX[~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 85-250 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21467 4. Location of well at surface 9. Unit or Lease Name 1015' FSL, 565' FWL, Sec.3, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3J-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 74' RKB ADL 25630 ALK 2563 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of CompIetions 11/27/85 1 2/09/85 12/10/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7344'MD 7231 'MD YES [] NO ~XI N/A feet MD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 171 sx AS II 10-3/4" 45.5# J-55 Surf 2342' 13-1/2" 1000 sx AS Ill & 140 s: Class G 7" 26.0# J-55 Surf 7322' 8-1/2" 610 sx Class G & 250 s:~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description to be submitted when received. F:ECEiVED Alaska 0ii & Anchofaoe Form 10-407 TEMP3/WC88 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTF 30. FORMATION T [:STS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Title 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 AtlanticRichfieldCompany" DailY werll'-'History- Initial Report Inetm©tlone: Prepare and submit the "Initial Rep~W' on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to sPudding should be summarized on the form giving inclusive dates only. District I County or Parish, Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ~Title APE AK0171 North Slope Borough ADL 25630 Drill IState Alaska IWell no. 3J-10 Rowan 34 AP1 50-029-21467 O~mtor ARCO Alaska, Inc. 8~dd~ or W.O. be~n loots Spudded I Date I~d deplJl ii o! a:M] &m.. ~ 11/27/85 11/30/85 thz~ 12/02/85 12/03/85 12/04/85 t2/05/85 Complete record for each day reported I A.i. Co'$ W.I. - . I Hour . Pti r statue if a W.O. 11/27/85 1630 hrs. . 56.24% 16" @ 110' Wt. 9.0, PV 17, YP 30, PH 9.0', WL 9.8, Sol 5 Accept rig @ 2400 hfs, 11/26/85. NU diverter sYs, Prep to spud. 10-3/4" @ 2342' 2531', (2526'), Coring Wt. 9.0, PV 17, YP 19, PR 9.5, WL. 5.0, Sol 6 NU &tst diverter sys. Spud well @ 1630 hfs, 11/27/85. Drl 13½" hole to 2360', 9 std short trip, CBU, POH. RU & rn 58 its, 10-3/4", 45.5#, J-55 BTC csg w/FS @ 2342', FC @ 2258'. Cmt w/1000 sx, (390 bbls) AS III, followed by 140 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 1300 hfs, 11/29/85. ND diverter, NU &tst BOPE. RIH, tag FC, tst csg to 2000 psi. DO flt equip, cmt + 10' new formation. Conduct formation tst to 12.4 ppg EMW. Drl 9-7/8" hole to 2457', TOM. PU core bbl, RIH, core #1, 2457'-2487', rec'd 30'. 2487'-2501' ' ' , recd 14'. Core #3, 2501'-2531', rec'd 25 . 530', .3°, N76.1E, 530 TVD, -1.28VS, .33N, 1.35E 1500' 3° N15.5E, 1499.97 TVD, -4..26VS, 5.50N, 5.19E , · , - 2000', 1.0°, N08.6E, 1999.94 TVD, -7.37VS, 8.95N, 8.91E 2330' 9° N.5W, 2329.90 TV]), -6 88VS, 14.40N, 9.29E ! * , · 2425' 1° N16E, 2424.88 TVD, -6 84VS, 15.95N, 9.51E Core #2, 10-3/4" @ 2342' 2603', (72'), Coring Wt. 9.2, PV 25, YP 11, PH 10, WL 5.2, Sol 4 Core #4, 2531'-2559', rec'd 24.5'. Core #5, 2559'-2570', rec'd 11'. Core #6, 2570'-2574', rec'd 2'. Core #7, 2574'-2603', rec'd 31.5'. TIE w/core #8. 10-3/4" @ 2342' 2705', (102'), LD core bbl Wt. 9.1, PV 13, YP 12, PH 10, WL~.0, Sol 3 ~.. Core #8, 2603'-2617', rec'd 18'. Core #9, 2617'-2645', rec'd[~: 28' Core #10, 2645'-2675' 'd ' . , rec 31 . Core #11, 2675'-2705', rec'd 30', POOH w/core bbl & LD same. 10-3/4" @ 2342' 4238', (2705'), Turbine drl Wt. 9.3, PV 16, YP 6, PH 9.5, WL 6.4, Sol 6 Fin LD core bbl. PU turbine, RIH, drl to 4238'. 2930', 1.7°, N 3.7W, 2929.74 TVD, -6.21VS, 27.78N, 3507', 1.1°, N17.9E, 3506.57 TVD, -5.70 VS, 41.77N, 3898' Alaska ""- u~l & Gas C,,')r~s. 10.78E 12.52E , 16.5°, N52.6W, 3892.22 TVD, 42.59 VS, 79.29N, -30.32W The above is correct Signature For Iorm preparation and d0~trlbutlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company ~"-~Daily Well History--Interim Inatrucflone: This form ia used during drilling or workover operations. If testing, coring, or peHorating, show formation name in describing work performed. Number all drl stem tests sequent a y Attach descrip_t on.,,of, all co.r.e~: .Wo.r.k,p. er. fo.rm,e,d by .Prod. ucin..g, Sectio. n~will be reported on "Interim" sheets until final completion. Report official or representative test on ' rmal term. ]) ;:~uoml! 'interim sheets wnen mind DUi out not less frequently than every 30 days, or (2) on Wednesday of the week in which oil siring Is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska ICounty or Parish Lease or Unit North Slope Borough IState Alaska Kuparuk River Date and depth as of 8:00 a.m. 12/06/85 12/07/85 thru 12/09/85 12110185 ADL 25630 Complete record Ior each day while drilling or workover in progress IWell no. 3J-10 10-3/4" @ 2342' 6068', (1830'), Rotary drl Wt. 9.4, PV 16, YP 13, PH 9.5, WL 6.0, Sol 5 Turbine & rotary drl to 6068'. 4114', 23.1°, N66.9W, 4095.45 TVD, 110.84 VS, 116.15N, 4546', 36.6°, N86.SW, 4475.01TVD, 314.84 VS, 150.44N, '4982', 44.6°, N83.2W, 4812.44 TVD, 590.05 VS, 178.96N,- 93.52W 294.60W 568.78W 10-3/4" @ 2342' 7344', (1276'), Prep to rn 7" Wt. 10.2, PV 18, YP 7, PH 9.5, WL 5.8, Sol 7 Trip to 9-5/8" csg shoe, make rig elec repairs. TIH, drl & surv 8½" hole to 7333', CBU, short trip to 6000', TIH, C&C, POH. RU Schl, log w/DIL/GR/SP/SFL-f/7296'-2336', cont w/GR to surf. Log FDC/CNL f/7305'-6594', 5702'-5394' & 3503'-2325'. P,m CAL f/7296'-2336'. RD Schl. Chg rams, TIH & make cond'g trip. Prep to rn 7" csg. 5290', 44.3°, N83.2W, 5032.31TVD, 805.55VS, 204.50N, 782.95W 6070', 42.6°, N83.3W, 5591.69 TVD, 1348.88VS, 275.30N, 1321.89W 6378', 42.1°, N86.5W, 5819.32 TVD, 1555.84VS, 293.44N, 1528.56W 7333', 37-1/4°, N74-1/4W, 6554.36 TVD, 2165.53VS, 395.68N, 2129.68W 7" @ 7322' 7231' PBTD, Displ'g cmt Wt. 10.2, PV 18, YP 4, PH 9.0, WL 5.8, Sol 9 LD 5" & HWDP. RU & rn 169 its, 7", 26#, J-55 HF/ERW R-2 BTC csg w/FC @ 7231', FS @ 7322'. Cmt w/350 sx C1 "G" w/1.5% D-79, 1.2% D-112, .5% D-65, .2% D-46 & .25% D-13, followed by 260 sx C1 "G" w/3% KC1, .9% D-27, .3% D-13 & .2% D-46. Displ using rig pmps w/276 bbls 10.2 ppg brine. Hole packed off w/237 bbls displ'd. Fin displ'g last 40 bbls @ .5 BPM @ 2000-2500 psi. ,{.~,.~ uu ." .:,: !j O - The above Is correct Signature ~ For form preparation and dil~tribution see Procedures Manual Section 10, Drilling, Pages 86 end 87 Drilling Superintendent ARCO Oil and Gas Company Daily Wel' Histo Final Report Instruclions: 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 submifled 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 County or Parish Lease or Unil Tte operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0171 Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TD 12/11/85 2400 hrs· Released rig Classifications (oil, gas, etc.) 0il Producing method Flowing Potential test data North Slope Borough IAccounting cost center code State Alaska ADL 25630 Drill API 50-029-21467 56.24% IA.R.C.o. Date IWell no. 3J-10 11/27/85 Complete record for each day reported otal number of wells (active or inactive) on thisH est center prior to plugging and I bandonment of this well /- 1630 hrs,IH°ur IPri°rstatusifaw'O' 7" @ 7322' 7231' PBTD, RR Fin displ'g cmt, bump plug. ND BOPE, instl lower pack-off & tbg head. RR @ 2400 hrs, 12/10/85. A.a,~k,~ Oil & Gas Cons, New TO I PB Depth 7344' TD I 7231' PBTD Date I Kind of rig 12/10/85 I Rotary IType completion si.(~le, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke s~ze 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 Superintendent SUB.SURFACE DIRECTIONAL ~URVEY ~UIDANCE ~ONTINUOUS ~"~ COL RECEIVED APR 0 4 1986 Oil & G~,s Cons. Cornmi,ssio~ Company Well Name Field/Location ARCO ALASKA INCORPORATED ~LL 3J-10 (1015' FSL, 565' FWL, S3, T12N, R91g) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71311 Logaed By: WEST Date 01-MAR-1986 Computed By: OGDEN GCT DI~ECTI3N~L SURIE¥ 3USTOMER LISTINS FOR INO. 3J-lO KU~RJK N~TH SLOPE,aL~SK~ SdR~EY D~T;: 11-FE)-86 METHODS OF COIPUT~TIOI TOOL LDC~TIDN: Ta~3ENFIAL- I~TERPD~TIDN: LIN~R VERTICAL S~CTIDN: tORIZ. DIST. EN$INEER: T. WEST PRDJECT:D ]~TO ~ ~ZIMJTM ~ZIMUTH OF 80 05~ ~ ~IN JEST COMPUT~TIAI DATE: 1-M~R-8$ 3J-lO KJP~RUK N]RTH SLOPE,ALaSKA INT£~POLaTED VALUES FOR EVEN lOO FEET O: TRUE SJB-SE~ MEASURED VSRTICqL VSRTICAL DSPTH DEPTq DEPTH 0.00 0.00 -74.00 130.00 1DO.O0 25.00 Z30oOO 200.00 125.00 3DD.O0 300.00 226.00 .400.02 400.00 '325.00 3530.00 499.99 425.99 500.00 599.99 525.99 ?O0.OD 699.99 525.99 800.00 799.98 725.98 900.90 899.98 825.98 iOOO.gD 999.97 925.97 1100.00 1099.97 1225.97 1200.09 1199,97 1125.97 1300.00 1299.97 1225.97 1400.03 1399.96 1325.96 1500.02 1499.96 1425,96 1590.90 1599.96 1525.96 1700.00 1699.95 1525.95 1890.93 1799.~3 1725.93 1930.00 1899.91 1825.91 2000.00 1999.89 1925.89 2100.00 2099.37 2025.37 2ZDO.OD 2199.85 2125.85 2330.90 2299.~4 2225.84 ' '~0.00 2399.$3 Z325.83 30.00 2499.82 2¢25.82 2500.00 2599. B1 2525.81 2730.00 2699.79 2525.79 2BDO.DO 2?99.77 2725.77 2300.00 2899.?4 2825.74 3300.00 2999.?0 2925.70 3130.]3 3099.56 3025.65 3ZD0.30 3199.53 3125.63 3300,00 3299.$0 3225.$0 3400.93 3399.58 3325.58 3500.0D 3499.55 3425.55 3530.00 3599.~2 3525.42 3700.00 3698.53 3524.63 3330.00 3796.76 3722.76 3~30.00 3893.31 381~.31 DATE DF SURVEY: 11-=53-85 (ELLY BUSHING ELEVATION: 7~.00 FT ENGINEER: T. WEST DEPTH CDJRSE VERTICAL DOGLEG RE'T?N DEVI&TIDN &ZIMUTH SECTION SEVERITY NORTH! 3EG MIN DES MIN FEET DES/lO9 FEE 0 0 N 0 D E 0.00 0.00 0 16 N 19 $ W 0.25 0.21 0 15 N 13 ? E 0.32 2.14 0 17 N 28 ~, E 3.22 O.OB 0 17 N 5.2 23 E 0.02 0.1~ 0 lO S 38 50 E -0.37 3.55 0 Z1 N 10 9 ;~ -9.15 0.83 0 34 N 82 49 E -0.69 0.45 0 %1 N 50 29 E -1.57 0.10 0 )5 S 81 55 E -2.69 D.3S 0 24 N 35 2~ E -3.19 D.43 0 33 S 86 52 E -3.75 0.22 0 8 N 59 39 E -~.34 2.89 0 26 N 55 55 E -%.56 0.90 0 ~.8 S 31 35 E -5.30 0.38 0 16 S 55 45 E -5.75 2.61 0 37 N 8~ 3 E -5.58 0.13 0 55 S 74 32 E -7.96 2.25 1 8 N 57 11 E -l.60 1.4~ 1 9 N 3~ 33 E -10.87 9.42 1 1 5 12 17 1 3 N 22 20 E -11.54 0.33 1 8 N 14 49 r- -11.86 D.i) 0 55 N 2.9 15 E -12.13 0.33 0 ~1 N 1~ 30 E -12.35 3.3~ 0 50 N 3 39 E -12.29 0.63 0 %0 N 5 1~ E ,-12,31 1.30 0 54 N 3 37 '- -12.14 0.75 0 58 N 3 59 E_ -11.95 0.23 1 19 N 1 27 W -11.66 9.41 1 33 N 2 15 W -11.19 0.60 1 35 N 4 45 E -10.78 9.39 1 35 N Z 15 : -10.48 0.45 1 1~ N ~ 39 ~ -19.26 9.1~ 1 17 N 19 9 ~ -10.41 D.31 14 N i1 24 E -10.68 9.35 20 N 5 17 W -10.54 1.32 Z N 5$ 55 W -7.01 5.35 2 N 59 27 J 4.49 56 N 55 l& ~ 21.94 3.76 Z N 53 31 ~ 45.20 SULAR CDDRDIq.~TES H]RIZ. SOUTH EAST/WEST DIST. T FEET FE~T DEPARTURE AZIMUTH D:G~ . O. O. 1. 1. 1. 1. 2. 2. 2. 3. 3. 3. 3. 3. Z. 2o 2. 2. 3. O0 N 0.00 E O.DO 16 N 0.23 W 0.28 54 N 0.22 W 0.58 11 N 0.0~ W 1.11 52 N 0.26 E 1.55 50 ~ 0.5~ E 1.73 58 N 0.42 E 1.74 10 N 1.04 E 2.35 47 N 1.98 E 3.17 73 N 3,15 E 4.18 35 N 3.72 E ~.81 49 N 4.35 E 5.58 34 N 4.93 E 5.96 66 N 5.21 E 6.36 23 M 5.89 E 5.72 59 N 5.2~ E 6.76 ?4 N 7.11 E 7.62 ~4 N 8.45 E B.80 44 N lO.1Z E 10.41 91 N 11.$$ E 1Z.,Z8 . 10. 12. 13. 15. 16. 18. 21. 54 N 12.59 E, 13.?5 39 N 13.21 E 15.14 21 N 13.78 E 15.57 75 ~ 14.24 E 17.84 21 N 14.43 E 18.90 52 N 14.67 E ZO.O1 97 N 14.74 E 21,08 67 N 14.81 E 22.30 55 N 14.83 E 23.93 17 N 14.76 E 25.~0 N 65 15 E N 60 45 : N 55 13 c N 52 57 5 N 47 75 ~ 33 29 q 3~+ 52 24. 26. 29. 31. 33. 35. 39. 56. 71. 05 N 14.81 E 28.25 88 N 14.97 E 30.77 40 N 15.15 E 33.08 59 ~ 15.65 E 35.25 70 N 16.27 E 37.42 35 N 16.47 E 39.45 47 N 13.49 E 41.71 56 ~ 2.83 E 45.75 24 N 13.13 W 57.75 33 N 3~.15 W 79.13 N 31 36 E '~ 29 6 E I 27 15 E N 25 21 E '4 25 45 E N 24 4O 5 N 18 51 E ~ 333-'_ t 13 ~) ~ ~ 25 39 ~ aRS. ~LASKA, IqC. 33-10 KJPARJ~ NO~TH SLOPE,AL~S<~ COMPUT~TI3N DATE: £NTERPOL~TED VALJES FOR EVE.N TRUE SJB-SEA ,ME~SURE] VERTIC&L VERTISAL 3EPT,q DEPTq DEATH 4000,00 3987,36 3913.86 4130.00 %080,92 6005.92 %3~0.00 %252.74 DO 0 ¢43~.50 ~363.60 · ~0 ~ 6515.29 %%41.29 ~7}0,~ ~595.50 %521.50 4300.00 %67~.11 ~600.11 ~00.33 %747.27 %673.27 5330'33 %318,77 5100,03 6890,34 %815,34 5200,00 %962,10 ~888,10 5300,03 5033.)4 %959.9~ 56~0.00 5105.~2 5031.~2 5500.00 5177075 ~103.75 55~0.00 52%9.50 5175,60 5~00.09 5321.31 5~}0.~0 5392.55 5319.65 5)00.00 5¢63.9~ 5389.92 6000.00 5536.25 5462.25 6100.00 5610.59 5535.69 6200.00 56~5.13 5511.13 6300.00 5759.35 55~5.35 '~00.00 5833.50 5759.60 ~]O.~O 5907.88 ~833.88 o590.~ 5982.~1 5903.21 5700.00 5057.%5 5983.45 6300.00 5133. ~8 5059.28 69~0.~g $~09.60 5135.~0 7000.00 5286,?4 5212.74 7lO0.OD 5365.$5 5291.65 7200.00 54~5.$3 5371.63 7300.00 5525.51 5451.61 73%4.00 5560,B0 5%85.80 C]JRSE V=RTICAL 2EVICTION ~ZIM~TH SECTION 2EG ~IN DE~ MI~ ~EET 20 ZO 22 05 24 33 26 30 30 ~1 34 54 36 $0 36 40 36 44 7 44 2.1 44 13 44 4 44 1 43 57 44 9 44 19 &4 33 44 2.3 N 58 13 W 7%.34 N 6~ 47 W 109.22 N 78 52 W 1~g,14 N 93 42 W 192,06 N 36 ~1 W 239.55 N 86 28 W 293,67 N 85 ~9 W 352.40 N ~6 25 W 411,78 N 82 33 W. N 83 3 W 5~1.49 N 83 2% W 611.34 N 83 25 W 681.11 N 83 3~ W 750'68 N 83 40 W 320.16 N 83 43 W 989.60 N 83 52 W 958.97 N 8~ 12 ~ 1023.41 N 8~ 25 'W 1097.98 N 8% 33 W 1167.91 N 8~ 53 W 1237.90 42 41 41 ~Z 41 42 41 40 40 39 Z3 59 9 59 4 31 57 35 N 85 IB W 1305.74 N 85 21 ~ 1373.31 N 85 41 W 1439.86 N 35 55 W 1506.62 N 85 11 W 1573.33 N 85 53 W 1639.98 N 32 51 W 1705,71 N 7~ 28 W 1772.56 N 75 Z5 N 1837.64 N 76 29 N 1902.28 38 37 36 36 36 39 5 53 53 53 N 75 55 W 1955,51 N 77 27 W Z025.81 N 77 14 W Z086.72 N 77 15 W ~_145.53 .N 77 1% W Z!73.OO P~SE O~TE DF SURVEY: Il-FEB-85 KELLY 5USHIN$ ELEVATION: ENGINEER: T. WEST =EET O= ME~SURE] DEPTH DOGLEG RESTA~SUL&R CO SEVERITY N3RTH/SOUTH E4 DES/lDO FEET F 6.29 90.10 ~ 5 %.19 105.32 N 9 6.3% 117.%0 ~ 13 Z.85 123.10 ~ 17 ~.57 1Z8.00 ~ 22 3.95 132.16 N 27 0.13 135.%0 q 33 1.85 138.50 N 39 5.4% 144.50 ~ 45 1.08 153.20 q 52 D.15 161.39 N 59 3.23 169.37 N 66 0.28 177.31 N 73 0.2% 185.03 ~ 80 9.2Z 192.5'7 N 87 O.lg ZO0.17 N '~3 D.31 Z07,~l N 100 0.43 214,24 N 107 D.l~ 220.99 N 11% 0.7% 227.53 N 121 Z.15 233.39 N 128 0.31 238.86 4 135 0.31 Z~.lO N 141 0.2~ 248.95 N 148 0.4~ 253.57 N 155 1,20 257.93 N 161 2.8~ 254,03 N 168 2,63 Z74,19 N 175 1,11 ~88.03 N lB1 1.35 303.52 q 187 1.47 318.01 N 193 1.65 331.50 N 199 O.OO 344.72 N 205 g.00 357.97 N 211 0.03 363.~1 ~I 214 2 76.00 FT ORDINATES HORIZ. ST/WEST DIST. EET FEET 0,7% W 103,67 3,45 W 161,55 2,10 W 175,73 4,65 W 213,57 1.97 ~ 255.23 6,11 W 306.11 5,08 W 361,41 4.72 W 6,18 W %78.52 3.75 W 545.70 3.19 W 514.75 2.57 W 583.'88 1.77 W 752.94 0.89 W 321.99 O.OO W 391.08 9.05 W 3.23 W 1229.34 7.60 W 109'3.59 7,35 W 1163,%~ 7.19 W 1238.28 5.~7 W 1305.98 2.53 W 1373.%5 9.09 W 1639.93 5.93 W 1505.54 2.77 W 1573.33 9.57 W 1539.98 5.17 W 1706.73 1.25 W 1772.58 %.9% W 1337.55 ?.91 W 190!.28 9.61 W 1965.51 9.54 W 2026.83 8.08 W 2335.75 6.63 W 2146.59 2.39 :~ 2173.06 OE~RTL/'RE DEG MIN ~ 33 59 ,t 4 6~ 25 ~ N 67 59 W t 70 39 d N 7Z 25 J q 73 41 N ~ 74 46~ ~ 75 39 ~ ~ 75 22 W ~ 75 59 ~ 4 ~ 30 ~ q 77 58 4 78 22 W ~ 78 45 ~ q 7~ 24 ~ ~ 79 42 W N 79 59 W N BD 14 ~ N 80 29 ~ N 80 43 ~ ~ 80 57 ~ N 81 5 N 481 5 ~ q 30 58 ~ 83 35 W ~ 83 24 W ~Rr. CD ~L~S~H, INC. 3J-10 KJPaRJK NORTH SL. DOE~HL~SKH C]IPUT~TION D~TE: 1-M~R-85 P~'GE D~T5 DF SJRVEY: 11-F55-85 NELLY BUSHIN$ 5LEV~TIDN: ENGINEER: T. WEST 3 ?~+,00 ~T ~NTE~POL~TED V~LJES :OR TRUE SJB-SEA ME~SURE] VERTICAL VERTI~HL ]EPTH DEPTt DEPTH 0,09 O,DO -?~,O0 1DOD,OD 999,~7 925,97 2200,00 1999,39 1925,89 3300,30 2999.70 2925,70  330,00 3987,86 3913,86 :~330,33 $81~,77 ¢745,77 6000.,00 5536,25 5562,25 7000.23 5286.74 S21Z.T~ T3~4,0D 5550,30 $~85,80 COURSE ,'lEVI ~TI 3~ AZIMJTt ]EG vtlN DES MI~ 0 '0 N D 3 0 2~ N 35 2¢ I 3 N 22 ZO 1 36 N 4 4B 20 ~.0 N 5.~ 13 44 Z1 N 83 2~ 42 !3 N 35 19 38 39 N 76 55 36 53 N 77 1~. E'VEN lOOD FEET ]= ME&Sj'R V~RTICHL DOGLEG RECT~N SECTION SEVE~'ITY NO~TH! FEET DE~/IOO FE= O,O0 O,OO O. -3,19 3,43 3. -11.54 0,33 5, -10,78 D,39 24, ?~.34 ~,23 90, 611.34 0'15 161, 1305.7~ 2.15 Z33. ~965.51 1.'47 318, 2173.00 O.OD 363. ED DEPT SUL6R COORDINATES H]RIZ. SO~TH E&ST/WEST DIST. T FEET FE:T DO N 0,00 E 0.00 ~5 N 3.72 E 4.81 54 N 12.59 E 13.75 36 N 1~.81 E 23,25 10 N 5D.7~ W 108.57 39 N 593,19 W 51q.,75 39 N 1285.97 W 1306.98 OI N 1939.51 W 1~65.51 81 N Z142.39 W 2173,06 DEPARTURE AZIMUTH DES MIN D 0 N 50 38 E 65 15 31 36 3359 7¢ 46 80 41 80 21 ARCO 11Lll'S K~, 3J'lO NORTH SLOPE, fiL ~SK.a, INTERPOLATED V~LUES ;OR EVEN 100 FEET O= TRUE SJ3-S~& MEASURED V=RTIC~L VERTICAL )EPTH DEPT4 DEmTH 0,39 0.00 -74.00 ?4.33 74.00 0.00 174.03 17~.30 100.00 27~,30 27~.00 200,00 )374.~ 374.D0 300.00 '474.01 474,00 403.00 574.01 574.00 500.00 574.2! 674-00 $OD.O0 77~.01 774.00 700.00 874.0~ 87¢.00 ~00.00 ~74.03 974.D0 101~.03 1074.00 1003.00 1174.03 ll?~.DO 1100.00 1274,03 1274.00 1203.00 1374,0~ ,1374.D0 1300.00 1474.04 1474.30 140~,00 1574.04 1574.00 1500.00 1074.0~ 157~,30 1500.00 1774,07 1774,00 1700.00 1874.0~ 1874.00 1800.00 197~.11 197~.00 1903.00 2074.12 20~4,0'0 2000,00 217~.1~ 217~.00 2103.00 227~.15 2274,00 2200.00 -~74.17 2374.00 2300.00 ..74.18 247~.00 240~.00 ~'$74.19 2574,00 2300.00 25?4.20 2676.00 2503.00 2?74.22 2774,00 2700.00 2~74.25 287~,00 2803.00 2974.29 2974.00 2900.00 3074.33 307~.00 3000.00 3174.37 3174.00 3100,00 3274.39 327~,00 3200.00 3374.42 3374.00 3300.00 3~14.44 3474.00 3403.00 3574.51 3574.00 3500.00 3575.09 3674.00 3500.00 3776.58 3774.00 370D.00 33?9.9? 3574.00 3~09.00 CSJRSE VERTI:AL DD2LEG 2EVI~TISN ~ZIMJTq SECTION SEVEqlTY ]EG ~IN DE~ MIN FEET DE~/IOD 0 0 N 0 D E 0.00 0 15 N 31 45 ~ 0.18 0,54 0 16 N 7 2~ E 0.33 D.1D 0 17 ' N 23 [ E 0.25 9.10 0 18 N ~2 3 E 0,07 0.27 0 12 S ?4 53 ~ -3.29 0.41 0 16 N 45 10 W -0.23 0.80 0 32 N 71 29 E -0.45 0 39 N ~9 I : -1 36 0 41 0 ~2 S ~4 5~ : -2.40 1.03 0 22 N ~1 17 : -3.10 2.05 0 3~ N 81 3~ ~ -3.49 1.49 0 13 S 53 25 E -~.27 0'60 0 13 N 38 15 E -4.46 D.43 0 30 S 41 15 E -5.13 D.3~ 0 24 S 25 25 E '5.66 9.22 0 34 N 81 9 E -5.32 0.17 0 53 S 72 1! E -?.55 }.35 0 59 N 81 15 E -9.20 1.71 1 12 N 42 9 E -1~.59 ~.34 1 2 N 25 2~ E -11,42 0.34 1 8 N 1,5 30 E -11.80 0.17 1 2 N 22 lB r- -12,05 0 ~7 N 15 29 ~ -12.30 9.30 0 54 N ¢ 1~ E -12.34 0.69 0 57 N 3 ~Z E -12.32 1.45 0 50 N ~ 25 E -12.18 D.67 0 55 N 3 33 E -12.00 0.85 1 Il N 1 ~5 W -11.77 0.55 1 27 N 2 3~ :,~ -11.33 0.52 1 1 3 8 12 16 1 38 N 3 5 E -10.83 2.72 1 38 N 2 23 : -10.57 D.l~ 1 24 N 5 23 ~ -10.27 1,12 1 15 N 15 17 E -10.33 0.29 14 ~ 14 3 E -10.65 0,30 14 N 2 ~ E -10.52 0.14 ~4 N 45 35 ~1 -8.71 5.71 3 N 50 30 W 1.03 3.7~ 3 N 55 25 W 17.39 3.87 13 N ~3 55 ,~ 43.14 4.12 D~TE DF SUR~EY: Il-FEB-85 KELLY BUSHING ELEVATION: EN~I`4EER: T. WEST 7~.00 FT SU3-SE& DEPTH RECTAN NORTH/ FEE GULAR CO3RDINATES H]RIZ. SOUTq EaST/NEST DIST. T FEET FEET 0,00 N O.OO E 0.00 0.04 N 0,18 W 0.19 0,51 N 0.25 W 0.57 0,09 N 0.10 W 0.99 1,~4 N 0,16 E 1.55 ~4 0.55 E 1.74 1.56 N 0.49 E 1.53 2.04 ~ 0.79 E 2.19 2.27 N 1.75 E 2.87 2,76 N 2.88 E 3.~9 2.9Z ~ 3.61 E 4.54 3.50 N 4.10 E 5.39 3.35 N 4.87 E 5.92 3.56 ,~ 5.10 E 6.21 3.42 N 5.75 E 6.59 2.73 q 5.17 E 5,75 2.70 N 6.84 E 7.35 2.56 N 8.07 E 2.27 N ~.69 E 9.95 3.51 N 11.29 E 11.82 5.10 N 12.39 E 13.~0 6.90 N 13.07 E 14.78 8,80 N 13.53 E 16.22 10.35 N 14.14 E 17.52 11.~2 N 14.41 E 18.54 13.27 ~1 14.62 E 19,74 14.70 N 14.72 E 20.80 16.23 N 14.7~ E 21.95 18.08 N 14.85 E 23.~0 20.¢9 N 14.79 E 25.27 23.34 N 14,75 E 27.61 26.15 N 14,94 E 30.12 28,81 N 15.06 E 32.51 31.04 N 15.48 E 34.59 33.17 N 16.15 E 36.89 35.28 N 16.47 E 33.~4 38.25 N 15.01 E 41.39 43.82 N 6.04 E 44,23 53.37 N 8.99 W 54.12 67.9.5 N 29.58 W 7~.15 DE=~RTU~E ~ZI~UTH OEO MIN `4 D 0 E N'75 59 a ~ 25 37 ~ N 5 40 ,~ ~ 5 32 E '418535 N 17 24 E q 21 3 E `4 37 36 E q 45 11 F. `451 25 ~ 49 34 E N 55 27 E q 55 5 E `465 8 E ~ 68 26 E N 72 22 E ~ 75 50 E N 72 44 E `4 32 17 E `4 27 36 E t 25 3O E N 25 57 E `425 1E N Z1 25 5 x~ 7 51 E `4 9 33 ~ ~ 23 35 ~ ARCO ALAS(A, 3J -10 KJ~ARU~, N3RTH SLOPE, ~,L ~,SK ~, CO~PUTATI]`4 MEASURED 3EPTH D~rE: 1-M~R-85 iNTERPOLaTED V~LUES :OR EVE~ 100 FEET O: TRUE SJB-SSA VERTICAL VERTICAL DEPTq DEPTH 3985.21 3974,00 3900.00 4092,52 %074.00 ~OOD,O0 4231'71 %174.00 ~100,00 4312.57 %274.00 ~200,00 '~27,25 4374,00 4300,00 5~8.51 ~74.00 ~400.00 4573.Z0 4574.00 ~500.00 4?99.85 %674.00 ~500.00 4937.35 ¢774.00 5]77.Z0 ~87~.00 %803.00 6.55 4974.00 4900.00 5.75 5074.00 5000.00 4.79 5174.00 5100.00 4.00 5274.30 5200.00 3,83 5374,00 5300,00 4.11 5474,00 5400.00 0,75 5574.00 5500.00 5.32 5674,00 5500,00 9.78 5774.00 5700.00 4.~0 5874.00 3800.00 535 553 5?? 591 6O5 631 658 672 685 693 1 .,i! 3 73q. COJRSE V:RTICAL DOGLEG DEVI~TIDN ~ZIMUTH SECTION SEVERITY PEG ~IN DE~ MI~ FEET OE~/IOD ZO 0 N 55 43 W 69.60 %.00 22 34 N 58 ~ W 105.46 ~.33 24 35 N 79 Z W 149.86 ~.32 25 51 N 83 ~8 ~ 197.64 3.33 31 55 N 85 11 W 253.66 ~,56 36 17 N 85 5% W 321,90 1.57 36 39 N 86 57 W 395,86 0.15 40 35 N 82 3~ W 473.30 5.~% ~4 21 N 83 13 W 557.57 3,33 ~4 15 N ~3 25 W 665,22 0.21 44 4 N 83 34 W 752.!9 0,25 ~4 2 N 83 ~2 W 858.91 0,18 43 ~7 N 83 51 W 955,36 0,15 44 9 N 8~ 29 W t05Z,05 0,29 44 32 N $4 30 W 1149.59 O,ZO 44 18 ~ 84 55 W 1247.74 3.75 41 51 N 85 17 W 1340.56 3.09 41 57 N 95 37 W 1429.88 3.32 42 10 N 85 59 W 1519,86 42 0 N ~5 15 ~ 1609.60 0.45 41 38 N 83 15 W 1599,39 2.87 40 %~ N 79 33 ~ 1795.88 2,4? ~0 24 N 75 9 ~ 1872.39 0.~5 38 53 N T6 51 W 1955.32 1,Z~ 37 0 N ?? 25 W Z033,10 1.47 36 53 N 77 1~ ~ 2107.97 3.03 36 53 N 77 1~ R 2173.00 0.00 9.00 5974.20 5900.00 1,89 5074.00 SOOO,O0 3,51 5174.00 5100.00 3.57 5274,00 5200.00 '0.~5 $374.~0 5303.00 5.%? $47~,00 5400.00 4.00 5560.30 5~85,80 D~TE DF SJRCE¥: 11-FE5-85 KELLY BUSHING ELE~AT[DN: ?~.00 FT :NGI~EER: T. WEST SUB-SE~ DEPTH RE:T&N3UL~R CDDRDI`4ATES HDRIZ. DEPARTURE N3RTH/SOUT~ E4ST/WEST DIST. AZIMUTH FEET FEET FE~T DE~ MIN 87, 105, 117, 123, 129, 133. 137, 144o 156, 167, 34 kl 56,39 W 103,95 22 .~ gD,54 W 139,01 53 N 132,80 W 177.34 70 `4 190.21 W 21!3,58 27 N 235.05 W 269.13 70 ~ 304,45 W 332,53 ?5 N 378.73 W ~03,01 ~+'9 N 456.08 W %78.42 31 N 5~9.$7 W 571,46 55 ~ 646.77 W 568.12 178. 189. 199, Z09. 219, 228, 236, 243. 249, 255, $0 hi 743.21 W 764.37 29 N 839.~$ W 360.53 79 N 935.46 W 956,55 77 ~ 1031,30 W 1052.90 25 N 1129.07 W 1150.16 ~1 N 1227.02 W 1243.10 18 N 1319.78 W 1340.74 34 N 1409.10 W 1~29.96 90 g 1499.19 W 1519.88 95 N 1589.12 W 1509.60 Z63. 276. 296 · 315. 332. 349. 363 · 24 N 1678.90 88 N 1755.32 41 N 1848,19 59 N 1929.67 87 `4 2005.6~ 42 t 2078,85 81 ~ 2142,39 1599,~1 N 81 5 ~ 1785,90 `4 81 5 ~ 1372.40 `4 83 53 W 1955.32 ~ 80 42 N 2333.12 `4 83 34 W 2108.01 q 80 27 N 2173.06 ~ 83 Z1 R ALAS(A, IqC. 3J-10 KJ~AR~K N3~TH SLDPE,~L~S~A M~KER TOP ) TOP )aSE PBT3 TD KUP~RUK C KUP~RUK ~ KJ~ARJK A CDIPUT~TIDN [NT:RPOL~TED VALUES ;DR qEASJRED DEPTH 3ELO~ KB 5803.00 5373.00 6980.00 7132.00 7231.20 D~TE: 1-M~R-B5 H3RIZDNS ~RDM ]RISIN= 1015' TV9 KB SJB-SEA 5135.55 518cl. T6 5271.15 5391.25 6~.70.43 5560.80 5351.55 511~.76 $197.15 5317.25 53gE.B3 5~g6.80 P~SE 2~TE DF SdRVEY: ll-F:B-86 KELLY BUSHIN3 ELEVATI3N: ENGINEER: T. WEST 6 7~,.00 SJRF~CE LDCA ~T FSi, 565' FWL, SEC 3, T12 RECT~NSU,AR CDD NORTH/S3UT'~ E Z88.EO 315.17 335.71 3~8. ~ 3 353.81 TIDN RDIN~TES ~ST/~EST 815.$3 W 850.9g W 927.~Z W D18.27 W 076.23 W 1~Z.39 W FT S J-lO KJ:~RJK N3RTH SLDmE,AL~SK~ M~RKER TOP 5~SE TOP ) 3ASE ~5T3 l'D KUP~RUK C Kg~ARUK A CO~PdT~TI3N DARE: ~EASJRED DE~TH BELD~ KB 5~03.00 6B73.00 5~80.00 7132.00 7231.00 73~¢.00 1-M~R-85 SJ~M~RY 3R FROM K 5135.5 5188.7 6271.1 5391.2 5470.4 5550.8 I$IN: T~D P~$E DATE OF SURVEY: ll-F:B-85 KELLY 8USHINS ELE~ATIDN: ~N$INEER: T. WEST 7 ?~,.00 1015 ' SJ~-SEA 5361.55 511~+. 76 5197.15 5~17.25 5395.~3 5¢86.80 FSL, 555 ' FWL REC N3 SJRFASE ~OC~TION' ~T , SEC 3, T12~, RgE, T&NSULAR CODR3IN~TES RTH/S]UTW E~ST/~EST Z~8.52 N 1815.8~ W 2~9.4~ N 1850.)) W 315.17 N 19Z?.$Z W 335.71 N 231~.27 W 3~8.83 N 2376.Z~ W 353.81.~ 21~Z.3~ W FT JM MEASJRE] DE~TH 73~.0D WEL'. LD~T[]N~ TROE CERTIC~L ~EPTH 5550,80 TO: SJB-SE,~ ~RTI3~L DEPTH 6~6.~0 H3RIZONT~L 3EP~RTURE DISTANCE ~ZIMUTq FEET ]ES Mil 2173.05 N 83 21 SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3J-lO FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 0000713]! WELL 3J- 10 (1015'FSL, 565' FWL, S3, T12N, R9E) HORIZONTAL PROJECTION NI]I~TH 2000 REF 000071311 1SO0 lO00 soo -soo _~ooo SOUTH -2000 WEST SCALE = I/SO0 IN/FT --.',I-..( ': i ~ ~ ) i - , ~ ) ~ ! i i i -il i ! ! ( .-: '.: i-,i-l.~4-4Z-_M... ~ ~ ~ -:.: ~ ~ ~ i ~ -". ,.44-.:-b4---4.4~---Ht--.?:*~.i- --+.-~-.Hb-H.b+.+-4-.. * i ~ ~ ~ ~. :- ~ -~ ~ i : ! i :~ .-+-+,4-.4-~., i .iH.'-~.i ! ~i ! .~ ~ i -*~T.'--i-T?*r--t",-f'*t-'~.??~i'-~-'ff'"rm'?.'"'r- ~ ~ : li~_;~ ~ ~ b~-~ ~-~-~:-~-~-.-~.-~.4-~ ~-,.+++..~..-~+.,~.. : ; : : : : : ~ : : ' : : , : : ; : : , : : : : : ~ : , : ) i : : : ~ ~ : · ; : : : : ; : : ; : · : : [ ; : , : : : : ; k-i'-~ ~ ~ ~ ... ~-~.~-. ~..--m~.. ft , ~ .: -~- .~ ..-.~ .-..--,.m~..-~ [-.--H-~..t-~:-..,>-.~*.,--~ ..~.....-~..-.-T"r-T-T.' '-~r~- ...? .1.1~...:*.. --.:...,..,.....:..-- "fi J J , i~i' i ~ i i i i J i i i i ..--:-'h-~, ...:-H-; f-ff-[ ~ffj~--'--H--.:." T:.' r fT.} *....'~-'fi-..; ~ff ~ff4- i i i'f'!'"f"f-H- "~T' i ~-r'..*-x'3~4~,ii ~ [...-'t~~"t-.t--'-'.:-..*"~--t.:-.-'""-f'..'"t-.:~-ff-?~-~ j ..t f-f--k-} -~-?..-ff-..': : :4-4-- : : : -: -: .... : ~ ': ' :-i-:' :' -: -: .... ': -: ...... 4-~-: $-: ..... [_.~_ ...... ' : : :4- .................. ~ ~ .... k ...... ....~._? _..~_._~_~ ?.~.... : . . ii ~l-~-i4i i4H~Lbiii ~~ i i~~B-~~~!.~-[ b~-b---~.l-~.."Zi-'i--' -~-~--i--.b J-.~H.-H~-~-4-4...~-4-...~-~ .... ~-~ .~-H.4-~.~4_ 4-~-~...~-~4_~.4...~_ ~'1- ~-~--:..,-~--1 ~'---L'~-i-~ '~'~ittttli)'-!-~-~4- ,4..++.,~-.. *..~...~...~...;. j i! ! if fi i f"H"[q'iS-f"=ti'i"i-ff"k! ! i !'~-f--}-f-!-'t-' i ~ il !! i! ! i~.--H~i i I i--~.';-H-..':--i-.:4-¥ i i i ~---~i..:.-.b.:.b.~. 4-~4--.~-.b.-.b.:.b.$-.i-~.".H~t-~-b--.b~--H- , i i i i i i l-::'!--i i i i H'i..-:..-HH'-+-~-H'-' ~-i..-:.,F 4..-~- i ~i i i ;.'i--'-h~i f~ i i ½--H-fHa.. -H..-:..'i--+½'+--.-'H-F'H-'+.~--k-H-t-H -' , . Il ! ,*-i i i .'-'~--. ~'!'-- ,-'[--?'!', ~ ! ! ~ i ~"~-,i'-~,t ? ?.-~-"~"!;-~'~/- ,'l--l-m?---?'.'~'-~.-'~'---i~, ,i--?"'?'"'-'~"': :'~:· ~ ? *'"'~"-t"~,~'?°'?- ~ -: L.: .... : -1 -.' :. I -: -l' .:' ~ ~ : : ! [ : : : : .... ! -: .: ~: --' : : ! ! .... :.. :J~i_4- _: : I ' . .: $ '...L,. -~.l"t.-1-: 1~' ~l1-' ~I-I-: :~-Y: T~ ..--FT :-YT]-y: :~-~' i ] }~'YT-.. ' - .1-y-.,~ .l~-' -YI-'1-?. ~ : :~ :~-~--I-!-?-'I'" - :~-'~":*'"Y" -?--.,~-..~I-I ~ ~ ]'-?.- '"..*'"y"?-T- j il.':- ii ii i iiil-~~Tt'H~??i~.-.l:~'~! i ii H ii ii iff"~--?":.'-?-i'"~i~'"t-'-?'?i-t--?'lt''i'''''?''?~-r' i i i [ [ ii] i i [ i I i i i i I i i i i ! i i i i L_~i [ i i i_.': i i ] i i i i ~ i ~ i i ! I i i i i i ! i .! ; ! i .--H+i i l FiT['il i-liW X,GTF,+T- -. .:.L~ ~ ~ il )) i )][I ! ~ i ~ ~li i i ii i.) [ii i i i ii i i; i i i i I ii )__.-'- l i~)~ i i_~ !.~ iL~_i,_t..L.~__L.L4..'- I?--l~- : : : : : : : : : : : : : : : : .~---.~-! I ~ : : i -: '.. i : r ( ' : : ..' ~ ; .' : ! i : ~ ~ .: ; .? :*- Y : . . · , , : : , ii:: :- :- ! -': ~ ~ .,' i i-.'i!l :iii '.- = : : ll' : ~ -l' ~ ,,' ~ i ::'?: [ .-' = ~ ..' :r-~: -I--.. :--F: : : .... :: : ;: : · : : : [ ~ i --~-~-.~--b 4--~--~-¢- .--M,~-~4-.. 4--4-4--.~-. -.~-..b-4--~-- -4 ' ' .. -' -,s-i-.i-.~- -5+.+.P--H-H- .--~: .-i-:' i ~ i 5~.--~H:-.i--H;-,b~ ~-i i i ~ ~ ~ i i ~k-i-H~-F H.-+-H---,-FH-..i-. ,+-t'---H.-. %..,;'-H-- --..bH,-,~--. -!-,.F-½-- .~-~--~--~ ~ ~ -~-'.i--~ '-4.-4-4-, ..~-(--~-.; ~.---,b-i-4-~. = -: ~ i !-4-.4-.-.~-i-~-4-~.-4-~---.4-.~.4--~---4-.~-~--~ -~-+ ;-~- ..a..-*.-~-~ .... ~-4...a,.-+- : :' i !----i--~--;-4---4-4--b-~----i.-~-~--~-4..~.+-~J-;--~-~--~--,~-.~-i, $ ~ $ ..i i ; -: i-4-..,..~--~.~-~..--i-,-.;-4~--~-..-~--~--4--i--+---.~-i-.' .+--~-~--H,~ ...+-~..~.,,4- .~.*~.-+-+- .-+ .-+-t-; +- -t.-t--+>H --:.--HHt-%--+--+-+H--%t-+-+- ---~+-++- -+-+-++. -- ..-t-.~-4.-+.--H+m-.-+...--~-+--t---?- -+-+--t~.t-- -?.+-+-.t ....... t-++-.t-~ I i i [ I ! i i i J i i i _.-' I i !]~ i ] .'.' i I i ] ! i i i ! ! ~[.F'~.~ ~ F~ ~_?...:'FT... :~i T Ti T £: ~ : , ~ ~ ~ L..L.L.i....'_ -~000 -2~00 -2000 - 1500 - 1000 -500 0 500 1000 EP~T WELL 3J-10 (1015'FSL, 565' FWL, S3, T12N, R9E) VERTICAL PROJECTION PROJECTION ON VERTICRL PLRNE Z'7~). - Scl. SCALED IN VERTICAL DEPTHS HORIZ SCRLE = I/S00 IN/FT EXACT RAOIUS OF CURVATURE METHO0 TIE-IN LOCATION MEASURED DEPTH O. 0 FT TRUE VERTICAL DEPTH O,O FT 01 STANCE NORTH' O. O FT DISTANCE EAST O.O FT BOTTOM HOLE COURSE LENOTH COURSE AZ I MUTH MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DISTANCE WEST LOCAT I ON 2173.0 FT 279.6 OEO ?944,0 FT 6SSl.O FT 963.8 FT 2]42.3 FT REF 00007131! Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · ·. O~rA~O~, ~:I,~. ~' ~D '~U~~ . Reports and Haterials to be received by: Date .. L.FJ.04 ARCO Alaska, In Post Offic~"~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 01-28-86 TRANSMITTAL # 5541 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each ~'3F- 14 5" DIL/SFL-GR 12-24-85 Run 0i 1700-6966 2" DIL/SFL-GR 12-24-85 Run 0i 1700-6966 5" Den/Neu (poro) 12-24-85 R,~n 01 6100-6940 2" Den/Neu (poro) 12-24-85 Run #1 6100-6940 5" Den/Neu (raw) 12-24-85 Run 01 6100-6940 2" Den/Neu '(raw) 12-24-85 Run 01 6100-6940 Cyberlook 12-24-85 Run #1 6100-6900 3J-9 5" DIL/SFL-GR 11-24-85 Run #2 2" DIL/SFL-GR 11-24-85 Run 02 5" Den/Neu (poro) 11-24-85 Run 02 2" Den/Neu (poro) 11-24-85 Run #2 5" Den/Neu (raw) 11-24-85 Run #2 2" Den/Neu (raw) 11-24-85 Run #2 Cyberlook 11-24-85 Run #2 5" Dual Dipmeter-GR 11-23-85 Run #2 5" LSS-GR 11-23-85 Run #2 2" LSS-GR 11-23-85 Run 02 P~mT Log 11-24-85 Run #2 3448-6770 3448-6770 3448-6744 3448-6744 3448-6744 3448-6744 6100-6717 3448-6767 3448-6762 3448-6762 6361-6662 --~3J-10 5" D!L/SFL-GR 12-08-85 Run 0i 2" DIL/SFL-GR 12-08-85 Run 0I 5" Den/Neu (poro) -12-08-85 Run #1 2" Den/Neu (poro) 12-08-85 Run #1 5" Den/Neu (raw) 12-08-85 Run #1 2" Den/Neu (raw) 12-08-85 Run #1 Cyberlook 12-08-85 0100-7322 0100-7322 2336-7298 2336-7298 2336-7298 2336-7298 Run #1 2400-7275 *The API serial # is incorrect on all of these logs. It should read 50-029-21500. Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl Date: Dril!ing*bl ~ch0~ Rathmell*bl D & M*bl Vault*films ARCO Alalka. Inc. ,$ · SuD$,c~lar¥ of AllantlcRichfieldComlDan¥ ARCO Alaska, Inc, (' Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells- 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 !6-19 L3-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20. 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944~ Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Encl osures RECEIVED JAN ! 4 ]986 011 & Gas Cons. Ix~mmiss/or~ ARCO Alask,~. Inc. is a Subs~dier.v of AllanlicRichfJel(~Company STATE OF ALASKA ALASKA O~ AND GAS CONSERVATION CO~.911SSION MOIITHLY RI:PORT OI= DIIII-IlI iO _ .lID WOIIKOVI:lt 1. Drilling wellK~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-250 3. Address 8. APl Number ' P. 0. Box 100360, Anchorage, AK 99510 50- 029-21467 4. Location of Well at surface 1015' FSL, 565' FWL, Sec.3, T12N, R9E, UM (approx.) 5. Elevation in feet (indicate KB, DF, etc.) 74 ' RKB 6. Lease Designation and Serial No. ADL 25630 ALK 2563 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3J-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1630 hfs, 11/27/85. Drld 13-1/2" hole to 2360'. Ran, crntd, & tstd 10-3/4" csg. Drld 9-7/8" hole to 2457'. Coring f/2457' - 2705'. Drld 8-1/2" hole to 7333'. Ran ]ogs. Cont'd drlg 8-1/2" hole to 7344'TD (12/09/85). Ran, crntd, & tstd 7" csg. PBTD = 7231'. Secured well & RR @ 2400 hfs, 12/10/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/171 sx AS II. 10-3/4", 45.5#/ft, J-55, BTC csg w/shoe ~ 2342'. Crntd w/1000 sx AS III & 140 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/shoe @ 7322'. Crntd w/610 sx Class G & 250 sx AS I. 14. Coring resume and brief description Core #1 f/2457 Core #2 f/2487 Core #3 f/2501 Core #4 f/2531 Core #5 f/2559 Core #6 f/2570 - 2487'; cut 30', recovered 30' - 2501'; cut 14', recovered 14' - 2531'; cut 30', recovered 25' - 2559'; cut 28', recovered 24.5' - 2570'; cut 11', recovered 11' - 2574'; cut 4', recovered 2' Core #7 f/2574' - 2603'; cut 29', recovered 31.5' Core #8 f/2603' - 2617'j cut 14' recovered 18' Core #9 f/2617' - 2645'j cut 28', recovered 28' Core #10 f/2645' - 2675'; cut 30', recovered 31' Core #11 f/2675' - 2705'~ cut 30', recovered 30' 15. Logsrunanddepthwhererun DIL/GR/SP/SFL f/7296' - 2336' FDC/CNL f/7305' - 6594', 5702' - 5394' Cal f/7296' - 2336' GR f/7296' - surface , & 3503' - 2325' RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data None JAN I 4 1986 Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE /-'7-~__~ NOTE--ReporC,,/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oiland Gas Conservation Commission bythe15~ ofthesucceeding month, unlessotherwisedirected. TEMP/MR06 Form 10-404 Submit in duplicate ARCO Alaska, Inc. Post Office Bo-.._.00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE12-19-85. TRANSMITTAL ~ 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4// G3-18-85 Run #1 4570.0-9471.0 ~2H-9/~ 12-02-85 Run #1 1800.0-8113.0 ~2H-10 ~/ 11-23-85 Run #1 2856.0-7960.0 ~2H-12 /, 11-07-85 Run #1 2743.0-6829.0 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ~ 2V-16/! 06-03-85 Run #1 2973.0-7168.0 ~ 3A-10 J! 11-09-85 Run #1 3179.0-7014.0 ~3A-11/, 11-16-85 Run #1 3208.0-7330.0 3A- 12// 11-23-85 Run #1 3797.0-8006.0 '~3A-13;/ 12-01-85 Run #1 1800.0-7597.0 ~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 ~-3C-9/, 07-10-85 Run #1 3920.0-8332.5 3F-8 ~; 11-09-85 Run #1&2 0115.0-7040.0 ,,~ 3F- 9/~ 11-17-85 Run #1 3410.0-7770.0 3F-10~ 11-27-85 Run #1 1800.0-6631.0 3F-11 ~ 12-05-85 Run #1 0148.0-8618.5 3J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 3J-10'/ 12-08-85 Run #1 0096.5-7348.5 ref#' 70997 --;N~.~tf &~ ref# 71048 ref# 71002 ref# 70947 ref# 7095~CC~/d/D~ ~?/ ref# 70952'~~mr~ ref~ 70960 ref9 70989 ref9 71003 ref~ 71047 ref9 71073 ref9 70~6--~ ref~ ref~ 70~90 rof~ 71037 ref~ 71034 ref~ 7~074 Receipt Acknowledged: 'STATE OF ALASKA* 3D-II o F -3-ope _ 73 d ARCO Alaska, Inc. is a Subs,diary Of Alll~llcRichlieldComDl~y Date: ARCO Alaska, Inc. Post Office Bo. D360 Anchorage, Ala'~"~ 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED O£c 1 $1985 Alaska Ou ~ Gas Cons. Com~iss[ol7 Anchorage . - ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany. .. STATE OF ALASKA ALASKA O.,.....'AN D GAS CONSERVATION COl¥,..~.llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling we~Y~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-250 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-029-21467 4. Location of Well atsurface 1015' FSL, 565' FWL, Sec.3, T12N, R9E, UM (approx.) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74' RKBI ADL 25630 ALK 2563 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3J-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1630 hfs, 11/27/85. Drld 13-1/2" hole 1:o 2360'. Ran, cmtd, & 1:st:d 10-3/4" csg, as of 11/30/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/171 sx AS II. 10-3/4", 45.5#/ft, J-55, BTC csg w/shoe ~ 2342'. Cmtd w/1000 sx AS Ill & 140 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED d~th~ ~~II~ , TITLE Associate Engineer DATE NOTE--Report is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRH/MR60 Submit in duplicate M EMORAN-OUM TO: THRU: FROM: State-of Alaska ALASKA/~IL AND GAS CONSERVATION COM~ISSION C. V rton DA/E: December 9, 1985 Chai ~h~-~'' FILE NO: D.EWS.59 Lonnie C. Smith~~ ! Commis s ioner Edgar W. Sippl~_~. Petroleum Ins~j~r John F. Boylp~ Pet. Engineei~ Assistant TELEPHONE NO: SUBJECT: BOP Test ARCO KRU 3J-I0 Permit No. 85-250 Kuparuk River Field November 29, 1985: Ed Sipple and I traveled this date from Anchorage vi~ Alaska Airlines to Prudhoe Bay, ARCO Kuparuk, Rowan Rig 34, to witness a BOP test. The drilling contractor was in the process of nippling up. November 30, 1985:. The BOP test commenced at 3:00 PM and was con- ClUded at 8:00 PM. There were two failures. See remarks on A.O.G.C.C. BOP Inspection Report. Kim Tengberg, ARCO representative, notified us on December !, 1985, that all repairs had been and tested. We filled out the A.O.G.C.C. BOP inspection report which is attached to this report. In summary, Ed Sipple and I witnessed the BOP test on ARCO Kuparuk 3J-10, Rowan Rig 34. Attachment 02-001A,(Rev. 10t79,~ O&G I/4 · STATE OF ALASKA ALASKA OIL & 'GAS CONSERV~TION COMMISSION B,OoP,Eo Inspection RePort· inspector ~-~ ~/~ [ IC_' / ~~ '~5/-/~, . Operator t~ Well q ~-- lO ' " nocation: Drilling Contractor' Location, General.' General Housekeeping~ Reserve Pit. ~/~ Mud Systems Visual Audio 'Pit Gauge . (~(~ , Flow Monitor - Gas Detectors o'r' E n_. -'- Test Pressure Test Results: Failures Full charge Pressure pressure After Closure / Pump incro closo pres. 200 psi~ N2~/O~'Z~--' ~1~', ~ ~ ~ ~~, . psig. . Controls: Master /J, C~UE/ Remote ~ Btind~ z''~ -~'-- -- ~itch coV'er~ psig ,~ psig/~ ~ 0 min--~s e co Kell. y and Floor S UPper Kelly ~/Tes Lower Kelly ~ ~"Tes Ball Type ~_ ~Tes afety Valves t Pressure t Pressure t PresSure' Inside BOP ~P~ L-"~Test Pressure - ~4. O'~' .. Choke ManifOld ~/~f~est Press~ '~- ~ a ~ No.. Valves /~ No, flanges~ ' '~'~'- .: Adjustable Chokes Hvdrauicall¥ operated c~0[e Tes~ Time ~-hrs' Repair or Replacement of failed equipment to he'made within~- ~2- . days and Inspector/ Commission office notified. ~ _~ ~ _..~/~'?~-e ~_..i~.~-~"'..C ~'/~,..~,~, I-~V/.~/U(-~- ..... . , :. ~ ~ , ~ Distribution orig. - A0&GCC cc - Operator cc -'Supervisor October 22, ]985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3J-10 ARCO Alaska, Inc. Permit. No. 85-250 Sur. Loc. 565'-FWL, 1015'FSL, Sec. 3, T12N, R9E, t~. Btmhole Loc. 1516'FEL, 1352'FSL, Sec. 4, T12N, R9E, IN. 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. ~ere 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. Ver~v~trul'~vo~rs ~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSIOM be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~...~,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive ^nchorage, AK 99501 SUBJECT: Kuparuk 3J-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 3J-10, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on November 2, 1985. If you have any questions, please call me at 263-4970. ~gional Drilling Engineer JBK/HRE/lt PD/L12 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA O'rl:::: AND GAS CONSERVATION CO'i~YvllSSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] STRATI¢~A~PHIC I--] MULTIPLE .Z~=NE [] ~. / 9. Unit or lease name ~ ~Oz;2~;~.~' / Kuparuk River Unit 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 565' FWL, 1015' FSL, Sec.3, T12N, RgE, UN At top of proposed producing interval 1262' FEL, 1311' FSL, Sec.4, T12N, RgE, UM At total depth 1516' FEL, 1352' FSL, Sec.4, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 74', PAD 45' ADL 25630 ALK 2563 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 10. Well number 3J-10 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 3J-9 Well 257 ~ surface feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 3764 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7306' MD, 6521' TVD fee. t 2560 19. If deviated (see 20 AAC 25.050) I20. Anticipated pressures KICK OFF POINT 3600 feet. MAXIMUM HOLE ANGLE 44 oI (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 11/02/85 2860 psig@ 80°F Surface 3284 psig@ R37q ft. TD (TVD) SIZE Hole Casing 24" 16" il 3-1/2" 10-3/4" Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT '8-1/2" Weight 62.5# 45.5# 7" 26.0# Grade Coupling H-40 / Weld -55/HF-El~ BTC -55/HF-E1W BTC Length MD TOP TVD 80' 29' I 29' 2301' 29' I 29' I 7278' I 28' I 28' MD BOTTOM TVD 109¢, 109 2330'I 2330 I 7306'l 6521' St I (include stage data) ± 200 cf 900 sx AS I!1 & 140 sx Class G fficient Volume of Cement. I To co~ er exposed hydrocarbons~¢~ 22. Describe proposed program: /O/)r/8~z" ~. ~,~/~1~.~,~/, ,~0~1~,;.~'" ~.~o ~.g~V~- ARCO Alaska, Inc.~ proposes to drill a Kuparuk River Field development well to approximately 7306~ ND (6521' TVD). Selected intervals will be logged. The Ugnu interval will be cored. .A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2860 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3J-10 will be 25' away from 3J-9 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 10-3/4" annulus of this well. The 7" x 10-3/47, annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby,¢~fy that the foregoing is true and correct to the best of my knowledge i SIGNEE~/ //.,~"'~'~f./f~. ,~.,t.,,'~.,4~ TITLE Regional Dri ] 1 lng Engr. Th e spa~e~w--~/om/issi'o; use CONDITIONS OF APPROVAL Samples required I Mud log required ~-~e Y Erin um b~ .... I AESpYp ~OSval dat~eNee O Form 10-401 (LWK) PD/PD162 R~_v 7-1-RC) Directional Survey required APl number ~¥ES []NO 50-- O%¢- ''t'/ ~/~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Octobe]: 22, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3J-10 (cont'd) Upon completion of the disposal process, the 10-3/4" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. KUPARUK RI VER UNIT 20" -DI VE~TER SCHEMAT I C ii DE SCR ! PT I ON I. 16" COhC~CTOR. 2. TANKO STARTER HEAD. .. 3. TANKO SAVER SUB. 4. TANKO LOWER QU ! CK-COFa'~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6, 20' 2000 PS! DRILLING SPOOL Vi/I O' OUTLETS. 7. I0" HCR BALL VALVES W/lO' ~ DIVERTER LIliES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI AhX~ULAR PREVENTER. IVIAINTENANCE & OPERAT)ON. 4 I, UPON INITIAL INSTALLATION, CL'OSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY, 2. CLOSE. At~'~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Ah~JLAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DOV~NWlND DIVERSION. P,E.CEIVED DO NOT SHUT IN ¥~ELL 0Ci'! 5 ]985 UNC)ER ANY CIRCUMSTANCES. Alaska Oil & Gas Cons. Commissio~ Anchorage ' '3" u uY I, 7 G 5 4 L. 4. 13-5/8" - 5DOO PSI PIPE 5. 13--5/8" - 5C130 PSI DRILLZhI~ SP03_ W/O-O~-AND KILL LIhES 6. ID.-.5/8" - 5DDD PS! ~ RAM H/P~PE 7. 13~..5/8' - 5D~ PS! AtCC.LAR' ACII. lVUI. ATOR. CAPAC~ .Ti~$'I' 1, C3,-ECX AhD FZII AO~J,_ATI:~ ~OIR .'rD LEVEL W~TH HYERALLIC FLUID. ~ THAT AC'O_M.LATCR ~ IS _3COD__ PS! W~TH 15eX) PSZ 1~ CF TIE ~. ~ TZ~_, 13-EN O_ODE ALL LJNZTS SZMJ..'rANECLE~Y ALL LNI'r$ A~5 CL~ W~TH O4ARGIN3 ~ ~-F. 4. RECO:~ CIW NADC REPD~T, TI-E; ACI:::EF~ABLE LOhE~ LIMTT ~$ 45 ~CCN~ O..OSZNg TINGE AND 1200 J,;. OCT1 ~ !985 : : Alaska Oil & Gas Cons, Com~.,.JssJo~ ~'JJagO 5 i ~4~ I REV. 2 ~ ~Y 15, 1~5 ,..! .,., ...... , ·., ~ scALE 1 IN.:,, ,, , '1oo6 FEE't",. I . ! I -1 : : ~ , ' i ' ' '* ' · ~ : : I~ : I . ' ' ; , · ~' I ..I.. :_,~ ......: i 1 ~t'': ............ ~...¢, ........... ;..:...2..~ .... ; ....:" ~'t '" ; ....... t : ........ ' ' ~'':i L[.,~.;.~ ~.-~ ..... ~ ...... ' . ~ '~ ' ~ ' ~ '~ .... '" ' ' : ~ ~ , ~ I ' : : ..-t- ~ ~ r'' I ' ,,I ............. , · .,,, .... . , 1 .- ..... ~-[-.'-'-;--& '--[ ' -':---~ - --¢-~-;-~ ~ .... ~'-'¢-~ ...... ~-';--;-'~ '~ .... : ....... ~r ...... ~_ ~..~..;_.; ..... ~_: .... ~.__:~ 2 .... :...4.¢ .... t '~ ~, :~: ~: ~I~.'":I ~ ~-: PAD 3U,:~ELL:NO~iO~ t PROP~31 ~'~ .... i'~ ..... , , ' .... "-1, , ' ................... ~ . i ......... . . ~'. 'I'" ~-'?-~ ......... , ~ ...........~ i ' ' . : , : ~ ~ ~ ~ · ~ ", , ' ........... L~ ~ ~ ~ -. ~ .T", ·. ~,'.: ~ '. :'-: I: : :. ~. EASTMAN' HHI~S/O~K~:[~. ,-:-~, 't i T . ' I ; t ~ + i ' I I' ' ' ' ' ~ ~ ' .... ' * · : ...... I ' t ....... I l ......... ~ .... :., ......... ,..~-J.-'-' .... : .... :.:.,t ...... ~:-., ~., -., : ....... 4 .....:_.~: .... , -q', 1 ' ' ' : ; ' ~ ', .. .. ~ ; ~'~ ,, ~ ,, · ~ ~ · ~ ' ~ , . , ~ :. ~ ~' ; "' "1 ]'/"~ ~ ~~ ':'~ ~'~'i ' ' '. ~'' ~ ~ ~ ' ~ ~ ¢-,-[. -~- .4 ..... -4 ..... I.-.~ ....... 4.. - .... ' .... ; . . · ..'. ...... : ' '"~ ~ .... ?' . ,, t ~ ~ ~ ,~ , ,,-,....~ .-... .... ; ........ ~ ., ~ I ..... :' i ..... = ' ..I I'ARo£T' TVD-6320 i ', 4 IOl 5'. ' ...... ARCO iAL-ASKA.--.INC, i ~- ~ · ~:: -~,,/J .-L_-. 7-F' AD.. 3 a ~._.--WEL L-'-. N O ,';-.-1-' 0 '._-:-. pR O P.O $ ~D::':-'::_-_i::-.: .... = ..... KUPARUK--.Ft ELD,~- N OR TH. -SUOPE~-'.-ALA$~KA '~'~ _ ..... :_EASTH~N..~HI PSTOCIC. ~ :I N C.:--L----'~-:'.--/::-.-._-~-L-_::-. - - ! ~: : ......... ~ ~ : ' -i ..... -'--' !: :. :--- 40D. O - D-6320-'TMD"7023 ~DEP" t 9 t 0 :' 1 - -TfflI~7-306-DEP.' 2't'08 ! . , . i - , I I i ' ,.? , I T ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, A'~ska 99510-0360 Telephone 907 276 1215 August 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3J Pad Wells 1-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L07 Enclosure If RECEIVED AUG 2 19B5 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlanticRichtieldCompany 4 ~ g ~ IO NOTES i. COORDINATES ARE A.S.RtZONE 4 _ I I I r 2. SECTION LINE DISTANCES ARE TRUE. 3 HORIZONTAL POSITIONS BASED ON THE D.S.'-~J NORTH- WEST B SOUTHWEST WINDOW CORNERS PER 4. VERTICAL POSITIONS BASED ON TBM 85-7-Z?-I PER LHD & ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED - RlXX-- 5060 rev. ~ RECEIVED AS BU..~.~ CONDUC, TORSI - le i I _ _ [- Y. 6.002,*2Z.$e LAT. 70e25'O&.~20, , X- 519.5~.~0 L01G. t~oS0t2~.870 563' FYL. ?~0t FSL, 0G. ,1.3. PAD ~$.3-' 2- Y- 6,002,447.6& LAT. 70°25:04.266 Xl 519,S~*.66 LONG. 1~g°50'26.866" 563' rWL, ?65' ?$L, 0G.~I.0..PAD 3- Y= 6,002,472.5g LA~. ?0°25'04.512" X= 51g,$&a.60 LONG. 149°50'26.866 $63~ FWL, 790' ~$Lo 0G. ~0.9. ekd 4- Y- §,002,497.$9 LAT. 70°25.~04.758" X. 519,5*~.63 LONG, 1~9050~26.863 56~' F~L, 815' FSL..OG. ~0.8, P~D 5- Y- 6,002,522.57- LAT. ?0025'05.003" X. 519,5a4.65 LONG.,14g°-50'26.B61" 6- Yo 6,002,567'.61 LAI. 70°25:05.250" X. $]9,5~4.65 LONG. ~49°50~26.8S9 564' FYL, 865~ FSL, 0G. ~.0, PAD 7- Y. ~,002,572.6! LAT. 70°25'05.A95" Xo 5~9,5,~-,67 LO#G. [~9050~26.656" 566' F~L, 8gO* FSL, OG, ~[.[, PAD. BL Y. ~,002,597.57 LAT. 70o25~05.7&~ X. 519,5~.65 L0~G. 564, FYL, 915 rSL, OG. ',1.2, PAD. 9- ¥- ~,002,672.63 LAT. 70°25~Of.,79 56~ F~L. ge0' FSL, OG. 41.0, P&D ~5.5 ~0- T= 6,O02,697,6S LAT. ?OeZSt06,725 XI 519.5~,71 LO#i, $55' F~L, lOIS~ FSLo O&. &l.0, PAD 11- Y= 6,00g,722.6, LAT, 70°25'06.971 X- 519,5~*.73 L0#&. 1,9°50~26.8a3 565' F~L, 1010' FSL, 0G. ~0.?, PAD Alaska Oil & Gas Cons. Commission_ Anchorage I HEREBY CERTIFY THAT lAM PROPERLY REGISTERED AND LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA~THATTHIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF JULY 30! 1985. LOCATED IN PROTR.~TED SEC..3, TI2 N~ RgE~ U. MER. Y- 5,002,-7A1.'62 LAT. 70e25'07.217" X= 5-[9,5~a.78 LONG. 555' FWL, 106s'rSL, OG. ~0.?, PAD a5.5 13- Y= 5,002,772.67 LAT, ?0°25107.~53" X- 51.g,~4~.78 LONG. 149050'26.$37~ 5~§' FWL, 1090' FSL, OG. ~0.~, PAD 1~- Y= §,002.7g?.56 LAI. ?0025'07.?08'' X. 51g,56~.78 LONG.la~°50'2~.B36'' 565' FWL, I115' FSL, OG. I0,3, PAD 15- Y- 5,002,622.60 Lal, 70°25~07.~54'' X- 51g,5~a.80 LOMG. 1~9°$0'26.633" 565'FWL, 11~0~ FSL, OG, &0.1, PAD 45.0 16- ¥- 6,002,~7.58 LAI. 70025'08.200'' X. 51g,5~.80 LONG. l!g°50'ZG.831~' 565' ~WL, 1165'FSL, OG. ~0,0, P~D. ~5.~ ~THIS ARCO Aluska, In{;. Kupar~mk ProJ~f DRILL co ouc o LOCATIONS CHECK LIST FOR NEW WELL PERMITS Company ~~ Lease & Well No. ...ILI~< YO- I O ITEM APPROVE DATE (1) Fee , /o-vi- f 1. (2) Loc / 'l :-t':' 2. (~ thru 8) 3. 4. 5, 6. 7. 8. (3) Admin - / ~ - / f"/Y'~ 9. (.~, thru '12). 10. (10 and 12. (4) Casg ~..~.~_ /~-/Z-~ (13' thru 21) (5) . (22 th'~u 26) Geology: I~A Engineering: LCS ~ rev: 03/13/85 6.011 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO REMARKS Is the permit fee attached .......................................... Is well to'be located in a defined pool ............. Is well located, proper distance fr°m pr°perry line !i!i!!!!!!i!~!!-.~ Is. well located proper distance from other wells .... Is sufficient undedicated acreage available in this pool .. . Is well to be deviated and is wellbore plat included .... Is operator the only affected party ........................ Can permit be approved before ten-day wait ..~.~.~ i.~.~ i..~...i .... ~es operator have a bond in force ........... :::::::::::::::::::::::::::::::::::::::::::::. .:i!ii"iiiiiiiii!iii: ¢--. , Is the lease number appropriate ............................. - ........ I conductor string provided S .eeleeeeeemeeeeeeeeeeeeeeeemeeeeeeeeeee. Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ...~FF Will cement cover all known productive horizons ..................... _~.,:,~' .. " Will surface casing protect fresh water zones ....................... , Will all casing give adequate Safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ..... ~ ............... lil:~: a~tac~;~ :::. Are necessary diagrams of diverter and ~u~'equipmen~ Does BOPE have sufficient pressure rating - Test to .~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~/,~ .~h~4,~~ Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: ~_Z~---~.,-., v~rll o~,-~-~--I ~g~c~b~ ~,~ -~------~.~r~ .... .......... INITIAL OEO. ' Ult... IT .... ON/OFF POOL ] CLASS STATUS AREA NO. SHORE < 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. DEC .,$ o 19,~5 ^lasl<a Oil & Oas 6ohs. Gom~issio~ Anchorage SERVICE NA]viE :'FDIT ORIGIN CONTINUATI[IN CO,aM E~.~TS SERVICE DATE : ~'I bg DY PE PREVIOUS F.I, LE : 10,2 4 CN : ARCO A!i, ASK A S ~(] T: 3 COUN: ['~. SLOPF, STAT: AI,ASKA CTRY: USA .[ i,{ C PRE5: F ** C(').;:I,'it!:ki'I'$ ** TYPE 000 000 000 000 000 000 000 000 CATE o00 00O 000 000 000 O00 000 000 000 CATE i, im im ii 000 SIZE 019 006 008 002 004 002 012 006 003 001 C 0 D E ,1! iii il lm O65 065 065 065 065 065 065 065 O65 CODE 065 ~ S C H, L U C[:]HPANY = ARCO .AbASKA COU~,JTY = NOR'f?] SLOPE STATE = A[,A, SK A CA$Ii'~G = ,1,0,75" (a 233t,' - B, Iq.' SIZE: = 8,5" TO 7333,0' D~;NE,ITY = 10,2 LB/(; Rt~l : 2 600 Ii '12 DF VI,..(,OSi~ .... 40,n $ R~*.F "2 50 fa 72 DF Ft, l. lID .[,~i3SS = 6,0 C3 R~ AT RHT = 1 319 fa 1,42 DF ~4 A T R I X ~::~ A I..~ l) S T [.:,l N E ¥ ED '~ska Oil a ~as Cons. Co .... Anchorage I~',,{/)LiCTIt',3J~t SP!iF,[{ICAbLY FOCUSFD LOG (DIL) ILABbF:: '729~.()' TO 2136,o' * CASING {GR.CNL) AVAIhABLE~ 2450,0' TO 100,0' Gas Cons, Commissioi~ DATUm% SPEC[FICAT!(]N 6;L, OC, isS PROCESS ** DATA DEPT '7348.5(t00 SP ,,,.30 0~89 GR I0 R pi 0 [.3 2 ' ~ 01 (.,) 0 ~;,' j,l [3 . r~ ~.) HI 28,125 t.) a C N b 244 0 E P'T '72 (-i 0 ,:l ,'; 0 o S t;' I U SP - 15,607.4 GR ~ () l-i El j!!, 2,4377 D R [40 P ~'~ I 4:3,7 f) l. 2 NC N [.., 2 () 72 OEPT 700o..0000 SF"f:!J 2. SP -39.1133 GR 6 R H flor} 2,?(~g3 NPHi 32,2266 ~', Cr'~ L, 262 SP -37.1133 (;R 11 000 22O t 2O 12o 310 3.'1.0 28O 350 42O 890 ~30 330 2.,4' O. 2 9.5 3.6 0.2 3,5 2.2 0.5 9.3 0.0 5.5 .~. 0 7.2 0 · 0 9.5 7 4 0.0 !.5 3 ~ 7 5.1 O, 0 CbASS 00 O1 44 Ol 0 O1 0'2 01 0.1. 00 0 o 3o o I 749 b 23 432 00 o 448 523 () 00 698 273 e 64 (¢ 75 882 398 591 O00 049 '173 o 00 539 000 ;I. 31 523 8O6 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 G R NRAT i l,O GR FCNL, I ~iJD FCNt., NRAT F C P,t L ,T. f,..r). NRA? F C N b G~ FCNL. I' L, D G~ NP&T t',iO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5.1 108,1 2.6 3 '189.8 2,,1. 100,5 3.5 516.3 4.6 89.3 3.1 695.3 18.7 67.2 2.9 863.3 7 2 78:5 2.8 88! .8 3,4 115.1 3.1 882 523 155 125 '752 523 260 1.25 897 273 881. 125 804 395~ 526 !25 7O5 773 202 !25 507 89a 792 125 377 523 565 CO[)E 68 68 68 68 68 68 68 68 68 6P,, 68 68 CAbI RNRA GR 1 I.., M C A L I RNRA GR I b~'¢ C A b I RNRA GR R~'4RA IbM CAbI R ~,tRA GR C. ,~ L, I R N R A { OCTAb ) 00000000000000 00000000000000 ooooo00000000O 00000000000000 00000000000000 00000000000000 00000000000000 O00000()O000OO0 OuO00000000000 00000000000000 o00000000000OO 00000000000000 00000000000000 000000000O0000 00000000000000 O00000000000OO 2,7131 8 2;7678 -999,2500 3.4319 7 · 8093 3.0803 -999,2500 2.24.05 2 9, 441 3.9~41 '999,2500 4.8679 9.1191 3.3147 -999,2500 20.b768 8,8926 3.0452 -999.2500 7.3250 8,9785 3,1194 -999.2500 3.4221 10.0176 3.5432 DEPT SP R H 0 B NPHI D E P T SP DE] P T DE',P!? 8P N P H I DEPT $? R H 0 B NPHi S P R NOB NPHI 0 E P T SP N p H I 9YPT OEPT S° N p H I OYPT SP SP -3 7,3 3 2 0 (; P, - 9 9 9,2500 1".1 C,. L ~:, 40 0,00 ~:i 0 S F' 1.., U ,,44,36'33 GR 999,2 2999, 6200 0000 5820 (.; -55,2500 bRHO '999, . C -999,2500 N: 59n0. 000(.} SFLU -2 ] , 51 t;. 7 qR -999,2500 DRH 3 - 12.2 'l !. 5 ,G iR 2313 J oO -0 2337 2 0 1 1. ?o -999 -9q9 3 212 - 999 -999 2t. 2 13'1 -999 -999 3 ! ..!0 -999 -990 2 1. 32 -999 -999 4 96 -999 - 999 1..51 -999 -999 ,50 o o ,8946 2913 .fi12.~ * 687 5 ,789 t ,2 773 ,2500 .2500 3125 .2..Ou ,2500 .1960 ' ' 500 .5901 ,9375 .2500 ,7.483 .5273 ,250O .2500 78'14 1312b .2 !5 00 7820 7773 25O0 2509 .0530 ,bd75 .2500 °25O0 i.~047 95.7!48 652, 100. 5.41.. 2, 135, , '99 -999, -999, 3. -99g, -999, 3 '999 , -999, -999, 3, -999, -999, -999, 3, -999. -999, -999. 2, -999, -999, -999, 4 -9g9' -999. -999. 3, -999. -999. -999. 2. 95, 8125 3186 'l 5 2 0398 8125 1467 8125 7913 3906 9630 250n 2500 250o 3030 250o 2 ..':, (, 0 250O 2.4.24 2500 2500 250O 4377 2500 2500 2500 80 1 o 2500 2500 25 (.) 0 890':) 250.9 250O 2500 f~2 57 2500 2500 2500 1487 2500 250O 250O 033,i 714L~ (;, R C ;.'., LI R N R A G R i [., M CA h.£ R :~ .R A I L bl CAbI R~qRA GR I L M C~LI RNRA I I.,~ CALl CALl R N R A CAbI' RNRA t'; R CAD1 R ~.I R A I l.., ~ I I.., ~ CAbl R N R A G~ C a L, .I. -999,2500 2,1545 9'6035 4,1~1.32 -999. 500 2.1975 9.5020 4,2351 -999,2500 20Jr59 '999:2500 '999.25U0 '999,2500 3 3499 -999,2500 -999,2500 -999,2500 3,3381, -999.2500 -999,2500 -999,~500 3,4631 -999,2500 -999,2500 -999,2500 3,8635 -999,2500 -999,2500 -999,2500 2,9417 2999,2500 999,2500 -999,2500 4.5046 -999 2500 -999:2500 -999,2500 3.1096 -999,2500 -999.2500 -999.75oU 2.0413 9,~83~ D E P T R ,q 0 B DEPT SP R H 0 B N ? H I 0 F P T SP RHO.B 0 g P T S P RHOB DEPT SP N P H I D~PT R H 0 P, $..P OEPT S P NPH I OEPT Sp qPH i OEPT q900. OC, O9 $ - 32.515) 5 G .qgc) 2500 DENC, -050: 25o0 4800, OO(.)O -34.2695 GR -999,25(!0 DRHO -999,25C, 0 4700,0000 SFI.,U -34.99,~'3 -q99,250u -999,25n0 4600. C) <) (] O $ ~' [ t) 0,0132 I',: R A T 2:199,5000 FCN[., 2.32,25 ILO 773 G 8,~, i~ 151 NRA.' 225? 5000 2,26~B ILD 86.7773 GR -999,2500 NRAT -9~g.2500 FC~[, 2.531.5 IUD 7 '7.4023 G re -999. 2500 I~iRA'I' -9")9,2500 FCNb 2 5862 1LD g 8: 2773 G -9!)9~ 2500 -9~9. 250() FCN[, 2,9t.~65 IbD 113,4023 GR -999, ?.,5('I0 NRA~ - 9 9 9.2 50 0 r C i,~ !,, 3.0764 ob 65°3 -999,2500 NRAT -999,2500 FCIq[., 3, (':, 95 q I 1:, t) 106.839~4 GR -~o9 2500 I',! R A T ~9: 2soo 2,383i IL!) 9 ]., 9648 -999,250r,) FRAT -999,25o0 7.. 1370 'Tt.,O 3,2815 ~tNRA 6.,~1,81.25 GR 2,304.9 IL, M 85.08'98 CALl ] ~()~3 RNRA 67 ' 1 5 GR ,. 2. ,'~ 63 I. 1 L,.M 81.7173 CAI,,I 3'. 1741, R N R A 697,3125 GR .9gg,4'084 IbM .250o C.~l..,I -99~,2500 ~NRA -999.2500 GR 2,4475 Ib~ -999,2500 CALI -999.2500 RNRA -999.250o GA 2 8o10 -q99!2500 CALl -999 2500 HNRA -999,2500 GR 3.0803 IbM 99: 250(.', R~'R A -999.2500 3 3245 -999:2500 C~LI -999 2500 RNRA -999:2500 GR 3.1799 I[.,~ -999 2500 CALl -99912500 -999,2500 dR 2,5245 -999,2500 CALl -999.2500 i{NRA -999.2500 2.2366 -999. O0 4,7234 9,.[582 3'3557 -999,2500 2 3303 .], 39 -999,2500 2. ,4963 9, ~551. 3,2366 -999,2500 2,4182 -999,2500 999,2500 -'999,2500 2.4,612 '999,2500 '999.~500 '999.2500 2,7971 -999,2500 -999,2500 -999,2500 3,0413 -999.2500 -999,2500 -999,2500 3.3069 -999,2500 -999 2500 -999:2500 3.1252 -999,2500 -999,2500 -999.2500 2. 7405 -999,250o 999 2500 -'999:2500 2,2112 .... ': P A G E 7 SP R H 0 B N P H I t)EPT 8P OEPT $ P R I.-~ f3 [3 D EPT SP N P H I OgPT SP 0 E P T SP D E P 7' S Ii.' !) E P T $..P R H L) B ~'4 P H I OEP%' · "4 P H I OEPT SP NPH! 3EPT SP -c)99,250() 4200,0000 -44.,5195 -999. 2500 9~¢ f-{U '" 999,25 ¢} 0 i~] C N L 00 (.l 0 2695 25 C, 0 ,,.99 r'), 2500 3900.000 (.) $ ,~' !,,, U -999.25u0 [) !,'_ i4 i,) '999,2500 ~',]CNb 3700.00u0 -52.23~3 -999,2500 -999.2500 3600.00 C., .9 5 F f, U -50,7383 -q99.25C.'0 DRHC; - 9 q 9.2509 ~'~ C i;~ 1, :i, 2 - 999 - 999 2 99 ' - 9 9 9 b, "999, -999. 2~ I o5. -999. -999. 94 ,. 999. 3 t 0 0, - 9 g 9 -999' · it ' -999. -999, 1. 02° -999. -999. 102. -999. -999, , -999. -999. 1.11. -999. -999, 9(,48 25 o 0 3 s 57 O, 273 2500 2 ~, o u 457.3 4:64~ 2501~ 2500 539.3 4023 2500 25OO f~721 9648 250 o 250 () 1331, 5273 25OO 25o0 019~ 4(348 2500 25O0 6799 7148 25O0 2500 2620 2500 2500 0295 .1523 250U 2500 3760 5273 2500 250 o G R F C 1'4 L '.!7., [,, 13 IF' C N L, l' N R A 'P F C N L II,D G U FCNL I b D Ga NRAT F C b,l b I b D ~\~ k A T F' C N 15 I L D GR MRAT F C N I.,, I L,D GR NRAT FCN L [ b D 1 L, [) GP L, R A T GR NRAT FCa.I, -999,2500 CAbI -9~9 2500 -999.2500 GR 2.5901 IL~ -q99,2500 CALl -,999,2500 R. NRA -999. 2500 GR 2,4'124 -999.2500 CALl -999,250o ,RNRA -999,2500 , 0530 I ..,.~ k -99 ,2500 CAbI -999,2500 RNR& -999.25()0 GR 3 2444 IbM -999.250n CAE, I -999,2500 Ri,,!RA -999.250n GR 3,3616 I L ~. -999.2500 CALI -999. 2500 RN[~A -999,2500 GR 4,0437 -999.2500 CALl' -999,250o RN'RA -999.2500 GR 3.5120 IL~ -999.2500 CALl -999.2500 R~iRA -999,2500 GA 2.7366 1L~ -999,2500 CAb] -999.250(.) R!~RA -999,2500 GP 2,3969 -999,2500 CAbI -999.2500 -999.2500 GR - 999,2 500 -999. 2500 -999. 2500 2,5100 2999,2500 999,2500 -999,2500 2.53,15 -999,2500 -999,2500 -999.~500 2,38 t 1 -999. 2500 .-'~99. 2500 99. 2500 3.0159 -999.2500 -999.2500 -999.2500 3.1096 -999, 500 -999,2500 '999.2500 3,2112 :999,2500 999,2500 -999,2500 3.9065 -999.2500 -999 2500 -999:2500 3.3499 -999 2500 -999:2500 -999,2500 2,5959 -999.2500 -999.2500 =999,2500 2.1877 :999,2500 999,2500 -999.2500 0 g P T $ P N P H i 0 g P T SP D~]PT R !.! O B OMPT SP DBPT SP DFPT R H O 6 NPHI OEPT S P D E P T SP R H C.} B !~ P H I 0 F. P T SP R H 0 B NpH! OEPT SP N P h .1 DEPT Sp RHO~ N P H I 320,0 - 62 2 47 0 0 0 0 .$ F" 1, U 5 1 9 5 ,,; R 0 ? .2. 5 l') R H I'3 00,0000 3!68,9727 2900. 0000 SFL U -74.5352 GR 2,2502 [)kh() 45,9901, ~,t C ~".~ L 2800 -4,2 2 ~4 0000 832 C,' 1.950, 82'~2 S F L U G F: 0 R h () ',',Cb'f, 2700. -36, 2. q-g. () 0 (; <) 22 o 9 2600. 2. 40. 'I 07 9 6309 G R I.) R H (? 25O0. -32. 2. 0 t.; 0 () 0295 054 7 5 F [, Lt ¢; ..N ~t C N L, 1,9()63 1L, D ~: 5.7 '773 G R 0,0884 N~AT 1. 921. ¢; 875 FCNL 3,94 '15 I L, D 79.1523 CR o 1094 NRa'l,' ,17 't 7 ' 68 75 l;'C N I.., 4 o 9695 '[ f, r) 70.5273 G R 1. t,~ 3 g. 6 B 7 5 ti.' C i't I, 7.4, 343 (), 0435 1951.6875 7 571. o ILD 0,032? ~RAT 1955.6875 FCNL h.~835 93.0273 O, 1064 f~i R A!' 169~.6g75 FCNI., 135.8125 ILD 69,2148 GR O.030R NqAT 1.630.68'15 FCaL 2.7366 8 5 . 7773 3 6135 4'76: 6406 4,5 4 7 6 q !, 52 73 3 .758 '1 47 1. b406 4, '9460 79. 1523 3,81.67 414.390'6 4,6;I, 40 84,6523 3~8323 467.8906 8,1035 7:1. 0899 3,9006 427.8906 7,0~28 70.5273 3.754~ 459,8906 8,1270 8,t.464,9 46~ ,7053 ,1406 8,2363 68.5898 3.5823 514.8125 8.7129 83.0273 4.0085 403.3906 72.5273 69.2148 3,8440 401.6406 10,6582 80,4023 4,2~20 364,6406 '[ L Ni G R I L t C A 1,..,I R N R ~. GR CALI RNRA GR CAI~i R ti R ,A CA [.,I Rt~RA G~ CADI R~rRA GR CALl RNRA GR I 1., M CALl RNRA GR I L,v.': C~LI R ¢.} R A (; P II.,g CABI I LM CaLI GR 2 6448 9 7285 4 0,320 -999 2500 4.. 2078 9 ~ 494:1 '3.78 5 4 -999,2500 ¢. ,4265 9,673~ 4,~156 -999 , O0 4,3562 9,5879 4.1023 '999,2500 7 332~ 9 6816 4 3132 -999 2500 6,5320 8,3770 4,000'1 -999,2500 7,5789 9,1.191 4,1687 -999,2500 '1,8796 3'7991 -999.2500 7,7195 11.8535 ~,2117 -99 .250O 84.7148 10.3926 4.0750 -999.2500 9.0~88 9.~785 4.4695 -999.2500 OEPT 230u $? -999 R H 0 P - 9 g 9 :~PHI -999 DFPT 1700,0000 SPI.,U SP ' 99a 2500 GR R H 0 B 999,25 (,, 0 1.) P H 0 NPHI 2999,250(,' :'.~ C. ,~:~ T DEPT 15C, O,OOUO SP -999. 2500 RHOb -999.250d NPHI -999.2500 DEPT 140,0. n O (:, 0 SFLLI SP -999. 250u G R!.!Oa -~99,2500 -999 2500 -9q9 2500 GR -999 2500 NRAT -999 2500 -999. 2500 I[,D -999.2500 G.R 999.2500 N R A 'ir - 999.25 00 15 C ~'~t 1,., -999 · 2500 ILD -9qg, 2,~00 CJR -,999 2500 NRA'I - 9 *'49: 2500 V C b! l, -999.25oo ,l,r,,o 2999 2500 G~ 999 ' 2500 ~,1 R ~ T -999 2500 FCN[, -999. 2500 1 b -999.2500 GR -999. 2500 NRA1 -gg~. 2500 -99C~. 2500 ILO -999.2500 GR -999.2500 NRAT -999,2500 FCN[, -999 2500 iLD -~99:2500 Ga -999.2500 NRAT a'gq9.2500 FCN[: -999.2500 ZLD -999.2500 GR -999.2500 NRAT 1.5 9316 li,~ 6~:5898 CAI..,I .0 '398 R N R a 393,1406 GR -999 2500 IbM -999' .. ,2500 CALl -999,2500 RNRA -999,2500 GR -999 2500 I:bl~ -9.. 9.25ou CAI. I - 999.25 o o R N' R A -999.2500 GR -999 250O -999 2500 -999 2500 -999 2500 GR -g99,2500 IbM -999,2500 CALI -999,2500 ,R~!RA -999,250f) (JR - 999,2500 ,I .[., M -999.2500 CAb]: -999 2500 R f,iR A -999: 2500 GR -999 2500 I.LN -999,2500 CALl -999,2500 RNRA -999.2500 GR -999.2500 -g99.2500 C~LI :999 2500 ~NRA 999~250!.) ~. _- 99 2500 I r.,~4 999.2.500 R.NRA -999. 2500 GR -999 2500 -999:2500 CALl -999,2500 -999.2500 (;R -g99.2500 IbM -999,2500 CAbI -999.2500 R~iRA 13,6,1.13 9,6973 4,4,121 70,7773 -999 2500 -999 2500 -999 2500 37 5117 -999.25U0 -999,2500 -999.~500 q0.7930 -999,~500 -999. 500 '999,2500 50.0117 -999 250(} -999,2500 -999,2500 38.1367 -999 25OO -999' ,2500 -999,2500 38,6367 -999,2500 -999,2500 -999.2500 41,0742 999 2500 '-999:2500 -999,2500 42,4805 -999.2500 : 9 .2soo 99.2500 45,5742 -999,2500 -999,2500 -999,2500 28.2549 -999.2500 ~999,2500 999,2500 bVP 010,ho2 VERIFI'CATION LI~..IINfi PAGE 10 N P 141 - 999 , 2500 N' C t'J .b F "t C -9r9, 9 2500 I b :0 -, 999,2.5 (.'I 0 G R ,,999,~b00 NRAT -999, 5oo FCNL, -999 2500 - 9 9 9 * ,2500 G R -99q 2500 NRA'P -999. 2500 FCNI., -9q9 ~500 ' q 00 G R -999. 2500 NRAT -999 '2500 eLi~b -999,2500 I[,D -999. 2500 GR -999 2500 N{}AT -99q'25nO F Nb -999,2500 ILD -999.2500 Gig -999,2500 NR/~T -999,2500 FCNL O fi; P T 70 (,). 0000 $ SP -999' 2500 RHOB -999. 2500 NPHI -999.25o0 NCNb 999,2500 Il:aD . '999,2500 GR 999 2500 NRAT. :99~' 250t) FCNL - 9 . D E? P T 6 O O. () ,') 00 SP -999.2500 R [.{ C] B - 999.2500 NPl4I -999. 2500 -9q9. 2500 I L,D -999.2500 GR -999. 2500 NRAT -999.2500 [~'C, d L DEPT 500. 0000 SF L.~i SP -999° 2500 Gl..'. RgOF~ -999.2b00 DRHO NPHI, -999'2500 ,NCS, L 999.25 () (.) I b D : 9 99.2500 (]R -999.2500 NRAT -999. 2500 FCNL OEP? 400.0000 SFLt! 8P -999,2500 GR R H 0 P., . g ,a 9.25 (.! 0 NPHI -999,2500 -999.2500 II,i) -999. 2500 G~. -999.2500 NRAT -999.2500 FCplt., OEPT 3o0. 0900 SrbU S P - 999.25 ,.:) 0 (; ~< 2500 ILD -~99'2500 Gl< -999,2500 GR 999,2500 999,2500 CAbI -999,2500 R'NRA -999,250o GR -999.25~)0 -999,2500 CA[,I -999,~500 RNRA -999.2500 GR -999 250o IbM -gg9.2500 CALl -999,2500 RNRA -999.2500 GR -999 2._00 IL~ -999,2500 CALl -999.2500 RNRA '999,'2500 GR -999,2500 IL~ -999.2500 eAhI -999,~500 RNRA -q99, .500 GR -999 2500 IL, M -999:1~5()0 CAI, ii -999 500 ['{NRA -999 2500 Ga -999 2500 II.,M -999: 2500 CAI.,,'I -999,2500 RNRA -999 o 250(.) (JR -999,2500 ILM -999,2500 CALl -999,2500 Ri,iR~ -999.2500 GR -999.2500 -999.2500 CALl -999.2500 RhRA -999.2500 GR -q99.2500 '[L~ -999.2500 CALl -g99.2500 RNRA -999.2500 GR -999.2500 ILa -999,250('t CibI 39.6367 -999,250() -999.2500 -999,2500 43.7617 -999 2500 - 9 ,?;500 32 6992 -999,2500 '999,25'00 -999,2500 37,1680 -999,2500 -999,2500 -999,2500 50,793O -999.2500 -999.2500 -999,2500 24.9268 -999 2500 . -999,2500 '999,2500 6'7,5898 '999,2500 -999.2500 -999.2500 50.7617 -999.2500 :999,250O 999,2500 37,2617 -999,2500 -999.2500 -999,2500 39,9180 -999.2500 -999.2500 -999.2500 50,6680 -999.2500 -999.2500 II,-"I'"~ I~ Il I Iii 'I;t g._, [NZ -999,2500 i 1'.., D -999..2500 GR -' ' 2500 !'~iRA'I: ** FII,E TR,~ FlibE N A i:,~ g :EDIT ,001 ?ERSIOt,] ~ : DATE : ~IL~ TYPE NEXT F'IbF: NAME : 2.999. 2500 RNRA 9 q 9,250 ,"~ G R -999 2500 IL~,I 99: 250 (} C A L .I '~99,2500 RNR,% . -999,2500 GR. -999,2500 -999,2500 CAL.I .,-999,250() -999. 2500 (:iR -999 2.)I 0 ID~ -999,2500 CAbi - 999,2500 R i'.! R A -999,2500 GR I:;, A G E 11 -999.2500 29,9893 .~999.2500 999,2500 999,2500 -999 2500 -999 2500 -999 2500 23 .1893 999,2500 -99 ,2500 28. ** TAP[!; SERVICE Nt~,~iE : OATE :85t12/1,4 OR.I(.;Id :0000 T~PE] ~AHE :1074 CO{~TI ~lj AT! Dr,~ ¢ r~EXT TAPE NA~v~F: : C(]MMEr,~]'$ :L,I~.RAR¥