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182-028
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-09 KUPARUK RIV UNIT 1E-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-09 50-029-20720-00-00 182-028-0 W SPT 6015 1820280 1504 2396 2397 2396 2397 152 233 188 172 4YRTST P Austin McLeod 6/5/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-09 Inspection Date: Tubing OA Packer Depth 510 1810 1745 1745IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605185248 BBL Pumped:1 BBL Returned:1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:34:16 -08'00' MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg P.I.Supervisor ( 1 51 g SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-09 FROM: Adam Earl KUPARUK RIV UNIT 1E-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv37312— NON-CONFIDENTIAL ) 312NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-09 API Well Number 50-029-20720-00-00 Inspector Name: Adam Earl Permit Number: 182-028-0 Inspection Date: 6/10/2018 Insp Num: mitAGEl80611091032 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well f 1E-09 "Type Inj G -rTVD 6015 Tubing 2500 2500 - 2500 - 2500 PTD] 1820280 Type Test SPT Test psi 1504 IA 40 1900 1820 - 1815 BBL Pumped: J 2 BBL Returned: 1.5 ' OA 150 265 - 185 160 Interval --- 4YRTST P F P Notes: MIT-IA - JUN 2 2 Lull), SCOW Tuesday,June 12,2018 Page I of 1 Ima ect Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) · Ia Logs of various kinds [] Other BY: BEVERLY ROBIN VINCEN~MARIA WINDY Project Proofing BY: ~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation ~ x 30 = ~ + -_'~ = TOTAL PAGES Production Scanning ~ ~ Stage 1 PAGE COUNT FROM SCANNED FILE: x~OUNT MATCHES NUMBER IN SCANNING PREPARATION: /'_ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES DATE · ' / (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NO NO RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS ' f Convert from 1.Operations Performed: Abandon Repair w ell ! Rug Perforations Perforate Other WIND to MWAG Alter Casing fl Pull Tubing r Stimulate-Frac r Waiver fl Time Extension Change Approved Program rOperat. Shutdown f Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182-028 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20720-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 • 1 E-09 ' ...," 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): RCT,CCL Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 7000 feet Plugs(measured) none true vertical 6674 feet Junk(measured) none Effective Depth measured 6878 feet Packer(measured) 6233,6308,6315 true vertical 6556 feet (true vertical) 5945,6015,6021 Casing Length Size MD ND Burst Collapse CONDUCTOR 49 16 80 80 SURFACE 2432 10.75 2463 2463 PRODUCTION 6931 7 6962 ® ,`V `ijt. . i °•�' � 4, , 1 NOV 052013 Perforation depth: Measured depth: 6664-6673,6688-6708,6712-6718 CC True Vertical Depth: 6352-6360,6375-6394,6398-6403 Tubing(size,grade,MD,and ND) 3.5, L-80, 6283 MD, 5991 TVD Packers&SSSV(type,MD,and ND) PACKER-FHL RETRIEVABLE PACKER @ 6233 MD and 5945 TVD PACKER-OTIS HYDRAULIC PERMANENT PACKER @ 6308 MD and 6015 ND PACKER-OTIS PACKER PLUCKER(PART OF PACKER ASSEMBLY)@ 6315 MD and 6021 TVD NIPPLE-CAMCO DS NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 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 shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run_ Exploratory r Development r Service F- Stratigraphic fl 16.Well Status after work: Oil r" Gas r WDSPL Daily Report of Well Operations XXX GSTOR WIND r WAG 17- GINJ r SUSP r SPLUG r 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: 313-460 Contact Jake Voss(a,265-6935 Email Jake.VossCc�conocophillips.com Printed Name J e Voss Title Wells Engineer ///// Signature Phone:265-6935 Date i l/4I f 3 , 7- 13 RBDMS NOV - 5 Form 10-404 Revised 10/2012 76-' Submit Original Only .40 (24°,.> KUP INJ • IE-09 ConocoPhdIips a Well Attributes Max Angle&MD TD Alaska(� Wellbore APIIUWI Field Name Wellbore Status ilncl(°) MD(ftKB) Act Btm(ftKB) it t f,v,rx:Wrvmin ;'` 500292072000 KUPARUK RIVER UNIT INJ 29.82 5,400.00 7,000.0 ..• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-09,10/24/2013 2.17.56 PM SSSV:NIPPLE Last WO: 10/17/2013 4231 4/8/1982 Vertical schematic{actual) Annotation Depth(ftKB) I End Date Annotation Last Mod By 'End Date Last Tag RKB 6,764.0 10/28/2012 Rev Reason:WORKOVER osborl 10/24/2013 HANGER,25.0 ?m)",. 1,1 asing rings Casing Description OD On) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 31.4 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len II...Grade Top Thread SURFACE 103/4 9.950 31.4 2,463.3 2,462.9 45.50 K-55 BUTT lij,7 1# I Casing Description -OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.2 6,962.3 6,637.9 26.00 K-55 BUTT � I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 31/2 2.992 25.0 6,2829 5,991.1 9.30 L-80 EUE 8RD Completion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 25.0 25.0 0.07 HANGER FMC TUBING HANGER 2.992 CONDUCTOR,314-80.0 515.3 515.3 0.34 NIPPLE CAMCO 2.875"DS NIPPLE 2.875 6,209.9 5,922.8 21.24 LOCATOR BAKER LOCATOR 2.990 NIPPLE;515.3 6,210.2 5,923.1 2124 PBR BAKER 80-40 POLISHED BORE RECEPTACLE 2.990 i 6,233.3 5,944.6 20.86 PACKER FHL RETRIEVABLE PACKER 2.910 g 6,257.0 5,966.8 20.48 NIPPLE CAMCO DS LANDING NIPPLE w/RHC PLUG 2.812 S INSTALLED 6,274.6 5,983.3 20.19 OVERSHOT POORBOY OVERSHOT w/7.85'SWALLOW 3.610 Tubing Description String Ma...ID lint Top(ftKB) -Set Depth(ft..Set Depth(ND)(...!Wt(IWft) !Grade Top Connection SURFACE;31.4-2,4633 TUBING Original 3 1/2 2.992 6,268.5 6,385.2 6,087.4 9 20 J-55 BTC IPC Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 6,283.9 5,992.0 20.04 SBR OTIS SBR 3.813 6,307.9 6,014.6 19.77 PACKER OTIS HYDRAULIC PERMANENT PACKER 4.000 6,314.8 6,021.1 19.76 PACKER OTIS PACKER PLUCKER(PART OF PACKER 4.000 ASSEMBLY) 6,353.9 6,057.9 19.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT,6,149.8 6,384.6 6,086.8 19.63 SOS BAKER SHEAR OUT SUB 2.992 0 Perforations&Slots Shot Den Top(ND) Bite(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,484.0 6,544.0 6,180.7 6,237.6 C-4,C-3,C-2, 6/17/1988 4.0 Squeezed off 4/30/97 C-1,1E-09 6,664.0 6,673.0 6,351.7 6,360.3 A-5,1E-09 4/7/1982 4.0 PBR,6,210.2 6,688.0 6,708.0 6,374.6 6,393.7 A-4,1E-09 4/7/1982 4.0 PACKER;6,233.3 6.712.0 6,718.0 6,397.5 6,403.3 A-4,1E-09 4/7/1982 4.0 Cement Squeezes NIPPLE,6.2570 Top(ND) Btm(ND) ... Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com I 6,484.0 6,544.0 6,180.7 6,237.6 Cement Squeeze 4/30/1997 Mandrel Inserts OVERSHOT.6274.6 4'1 St ati C " on Top(ND) Valve Latch Port Size TRO Run o INo Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date m 1 6,149.8 5,866.9 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 10/17/2013 SBR;6283.9 DCR-1 PACKER,6,307.9 - Notes:General&Safety M �• End Date Annotation 8/24/2010 NOTE View Schematic w/Alaska Schematic9 0 PACKER;6314.8 i i/ 1 NIPPLE;6353.9 t: I SOS,6,384.6 - Port;6.484.06.544.0 7/ Cement;6.484.0 57 Pert 6664.0-6673.0 Pert,6688.06 708 0- Pert;6.71206718.0 I 1 PRODUCTION,31 2-6962.3 1 E-09 Pre and Post Rig Well Work • Pre-Rig Well Work . DATE SUMMARY 8/12/2013 ASSIST VALVE CREW PULLING BPV. TAGGED @ 6775'SLM, EST. 50' RATHOLE. IN PROGRESS. 8/13/2013 MEASURE BHP @ 6700' RKB (2875 PSIA, 152 DEGF), GRADIENT STOP AT 6595' (2791 PSIA, 135 DEGF). , SET 2.75"CA-2 PLUG @ 6354' RKB, SET 2.74"x 123"JUNK CATCHER @ 6364' SLM, PULL 1" DV @ 6246' RKB, CONDUCT CMIT(PASS) 8/15/2013 (RWO): MITOA-FAILED: ESTABLISHED LLR OF 3.9 GPM; T POT-PASSED;T PPPOT-PASSED; IC POT-PASSED; IC PPPOT-PASSED; OC POT-FAILED: UNABLE TO BLEED TO 0 PSI (OA TRACKING); OC PPPOT-FAILED: UNABLE TO PRESSURIZE; ALL LDS'S: T PO, IC PO&OC PO, FUNCTIONED PROPERLY. 8/17/2013 (RWO): SCLD-IN PROGRESS. 8/20/2013 (PRE-RWO): SCLD-PASSED @ 1000 PSI; IA DDT-PASSED. 10/3/2013 (RWO) : OA BLEED FOR BUR. • Post-Rig Well Work 10/25/2013 Circ out w/ 170 bbl's Inhibited Sea Water w/(75 bbl's) U-tube Diesel FP; Pulled Ball & Rod @ 6229' SLM; Replace Soy @ 6147' RKB w/DV; Acquire Passing MIT-IA. In Progress. 10/26/2013 Pulled RHC Plug Body @ 6257' RKB; Bail Fill, Pull Catcher& 2.75" CA-2 Plug @ 6354' RKB; Tagged TD @ 6748' SLM ( Est 67' Rat Hole). Job Complete. • • ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1 E-09 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 10/11/2013 4:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/10/2013 24 hr Summary Move rig off 1A-26 well and staged on 1A-pad for repairs. Remove paint from hub with cracked welds and GBR air arc out the cracked welds, Continue with other rig maintenance activity's, replace faulty dry lock connection on Top Drive service loop, repair weather stripping in cellar, Repair Derrick climber while Derrick is laid over. Patch rear cellar door, Housekeeping on rig. 00:00 03:30 3.50 MIRU MOVE MOB P Finish cleaning pits and remove berming from around rig and cuttings tank, Pull out cutting tank from rig and spot down pad. Blow down steam and water in pit complex and disconnect all lines. Set Top Drive in rotary table and prep rig floor and Derrick to lay over. 03:30 04:30 1.00 MIRU MOVE MOB P Bridle up and lay Derrick over and secure. Disconnect Mud shack and stage down pad. 04:30 10:30 6.00 MIRU MOVE MOB P Pull pit complex out and stage down on pad. Move sub off 1A-26 well and staged on the pad to repair cracked welds on back hub. Pull hurculite up and mats. Clean up around cellar area. 10:30 12:00 1.50 MIRU MOVE RGRP T Remove drip pan from Dead Axle on rear of sub. 12:00 21:00 9.00 MIRU MOVE RGRP T Remove paint from Welds on tires# 5,Air Arc welds out, Repair Derrick climber, Organize items on pad for move to 1E-09, Housekeeping in the mezzanine and install patch on rear cellar door. 21:00 00:00 3.00 MIRU MOVE RGRP T Continue removing paint from welds on hubs, Repair weather stripping on ODS of cellar, Replace faulty dry lock on Top Drive servics loop. 10/11/2013 Finish repair's on rear hub and MPI welds, Passed inspection, Resumed mobilization to 1E-09 pad, Install jeep on pit module, Remove berming from around Downey cam,Air rig tires back up, Patch hole in pit#4, Install drip pan back on dead axle, Move sub to begining of pad to get Downey camp and truck shop out first. 00:00 12:00 12.00 MIRU MOVE RGRP T Continue repairs on cracked hub on rear of sub, Replace faulty submersible brine pump winches.Continue with housekeeping around the rig. 12:00 18:00 6.00 MIRU MOVE RGRP T Continue repairing cracked Hub on rear sub dead axle, MPI inspection after completing welding procedure, (Passed inspection) Page 1of10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 MIRU MOVE MOB P Resume Mobilization for move to 1 E-09, Install jeep on pits, Remove berming around Downey camp,Air up rig tires, Patch hole in pit#4, Install drip pans on dead axle. 21:00 00:00 3.00 MIRU MOVE MOB P Move and stage sub at begining of pad to get camp and truck shop around and moved out first to 1 E-Pad. 10/12/2013 Move Pit complex, truck shop, Downey camp, and parts house's from 1A-Pad to 1 E-Pad, set camp herculite and mats for camp,truck shop and spot Pit complex. Move sub from 1A-Pad to 1 E-Pad and spot over well, spot mats and hercuilte for sub, Spot pits and raise derrick,take on brine and Accepted Rig© 16:00 hrs 10/12/2013, Berm sub, raise cattle chute, install service loop, hook up all interconnects remove and secure bridle line, Rig up hard line and choke house to tiger tanks. 00:00 01:45 1.75 MIRU MOVE MOB P Peak arrived, load truck shop and tied on to Downey camp, pulled herculite and mats from under camp and truck shop, load parts house up and mats on trucks. 01:45 03:00 1.25 MIRU MOVE MOB P Move pit complex, Downey camp and truck shop to 1E-Pad from 1A-Pad. 03:00 03:30 0.50 MIRU MOVE MOB P Stage pit complex and remove jeep and move pit complex down past 1 E-09 well. 03:30 07:30 4.00 MIRU MOVE MOB P Move camp into place and lay herculite and mats under camp, spot parts house in place,set in truck shop. Berm around camp. 07:30 10:30 3.00 MIRU MOVE MOB P Move Sub from 1A-Pad to 1E-Pad. 10:30 11:30 1.00 MIRU MOVE MOB P Spot rig mats and herculite for sub base. 11:30 12:00 0.50 MIRU MOVE MOB P Spot sub over the 1E-09 well and level up same. 12:00 16:00 4.00 MIRU MOVE RURD P Spot Pit complex, Raise Derrick. Berm around pit module&began taking on 9.6 ppg brine.Accept rig @ 16:00 hrs 10/12/2013 16:00 22:30 6.50 MIRU MOVE RURD P Berm sub module, Raise cattle chute, install hydraulic service loop, Hook up steam lines,water and air, Remove and secure Bridle lines. 22:30 00:00 1.50 MIRU MOVE RURD P Spot choke house and rig up circ lines and equipment in cellar. 10/13/2013 Pull BPV, Rig up and kill well with 260 bbls of 9.6 ppg seawater, Monitor well 30 min(Good), Install BPV, N/D tree, Install blanking plug, N/U BOP stack, Rig up and test BOPE 250 low/3000 high,Test Good, (AOGCC State Rep. John Crisp waived witness of test) 00:00 01:00 1.00 MIRU MOVE KLWL P Continue rigging up lines to kill well, air test lines. 01:00 03:00 2.00 MIRU WELCTL KLWL P P/U lubricator and test to 500 psi, Good, Pull BPV,Tubing on a vac. L/D lubricator. 03:00 03:30 0.50 MIRU WELCTL KLWL P Rig up lines and valves to tree to kill well. Page 2 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 MIRU WELCTL SFTY P PJSM with crew and walk all lines and double check valves.Test hard line to 1600 psi, 04:00 05:30 1.50 MIRU WELCTL KLWL P Start kill operations, pumping 9.6 ppg brine down tbg taking returns out IA to tanks with 2 bpm 40 psi, 3 bpm 95 psi, 4 bpm 400 psi,and 5 bpm 720 psi. FCP= 1,195 psi, Pumped 260 bbls of 9.6 ppg. 05:30 06:00 0.50 MIRU WELCTL KLWL P Blow down lines and rigging up on the secondary choke to circ one complete volume.. 06:00 07:00 1.00 MIRU WELCTL KLWL P Pump down the 3 1/2"Tubing and take returns from the 7"x 3 1/2" Annulus to the Pits at 6.0 bpm/1,260 psi. 07:00 07:30 0.50 MIRU WELCTL KLWL P Monitor Well, static. Blow down all lines. 07:30 08:00 0.50 MIRU WHDBO PRTS P Set BPV. Test same from below at 500 psi. Good test. 08:00 10:30 2.50 MIRU WHDBO NUND P Nipple down Tree. Remove same from the Cellar. 10:30 11:00 0.50 MIRU WHDBO NUND P Clean Hanger threads and inspect same. Install Blanking Plug(11 turn left hand). Install XO(9 turns right hand). 11:00 12:00 1.00 MIRU WHDBO NUND P Change out studs in the Double Stud Adaptor. 12:00 17:00 5.00 MIRU WHDBO NUND P Nipple up DSA and BOP Stack, turnbuckles and riser. 17:00 19:00 2.00 MIRU WHDBO BOPE P P/U test joint, dart,TIW and x-overs, Fill stack and choke manifold with water. 19:00 19:30 0.50 MIRU WHDBO BOPE P Perform shell test 250 low/3000 high, (Good) 19:30 20:00 0.50 MIRU WHDBO BOPE P Contact State AOGCC Rep. after full body test,Test waived by State Inspector John Crisp. 20:00 23:00 3.00 MIRU WELLPF BOPE P Test BOP with 3.5"test joint, UVBR, LVBR,Annular,Air IBOP, Lower kell valve, HT-38 FOSV, &IBOP, Kill stand pipe, CHoke 1-11, 14-16, HCR &Manual&Kill 250 low/3000 high for 5 min each,All test Good. 23:00 23:30 0.50 MIRU WHDBO BOPE P Koomey draw down test: Start= 3000,After closing= 1800,200 psi Build up= 16 sec, Full rec=91 sec, 5 bottles @ 2000 psi avg. Pump Efficiency one Pipe ram &Hcr, Electric=22 sec,Air pumps=60 sec, Closing times:Ann= 16 sec, UVBR&sim LPR, Blinds=6 sec, Hcr ch&kill= 1 sec each. Good. 23:30 00:00 0.50 MIRU WHDBO BOPE P L/D 3.5"test joint, FOSV, and IBOP. Page 3 c +t�= Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/14/2013 24 hr Summary Kill Well. Nipple down Tree. Nipple up BOPE. Perform the initial BOPE and Koomey tests per ConocoPhillips/AOGCC requirements. Good tests. R/D test equipment, Pull blanking plug abd BPV, C/O to long bails, M/U dp pups and x-overs to tbg hanger, BOLDS,Attempt to pull tbg free to 144K max, No-Go, Call out Halliburton e-line, spot truck and unit, bring tools to rig floor and rig up, RIH with string shot to 6268' MD and fire same, M/U 2" RCT assembly and RIH locate depth and make cut, Good, POOH and R/D Halliburton e-line, Pull hanger to rig floor and R/U GBR, L/D 45 joints of 3.5"tbg with control line. 00:00 00:30 0.50 COMPZ WHDBO BOPE P Test Blind rams, Choke valves 12& 13, inner&outer spool valves 250 low/3000 high all test good. 00:30 01:30 1.00 COMPZ WHDBO BOPE P R/U and Pull test plug, Blow down all lines and choke manifold. 01:30 02:00 0.50 COMPZ RPCOM PULD P Pull Blanking plug and dry rod BPV out. 02:00 03:00 1.00 COMPZ RPCOM OTHR P Change out to long bails. 03:00 05:30 2.50 COMPZ RPCOM PULD P Make up drill pipe pups(1-10' 1-5' 1-10')and x-overs to hanger with TIW valve on top of pups. 05:30 06:00 0.50 COMPZ RPCOM THGR P FMC BOLDS on TBG hanger. Pull Tubing Hanger off seat at 95K. 06:00 06:30 0.50 COMPZ RPCOM PULL P Attempt to shear the SBR. Worked up to the maximum allowance surface pull(114K)plus Block weigh (30K)t at 144K several times with no luck. 06:30 09:00 2.50 COMPZ RPEQP1 ELOG P Call out HES E-Line Unit. Pull Tubing in tension(68K)set slips and prep floor for E-Line ops. Wait for Unit to arrive on location. 09:00 09:30 0.50 COMPZ RPEQP1 SFTY P PJSM with All. Spot E-Line Unit. 09:30 12:00 2.50 COMPZ RPEQP1 ELOG P Bring E-Line Tools to the Floor. Rig up Eline tools. 12:00 16:30 4.50 COMPZ RPEQP1 ELOG P Make-up Tool string with a 5-ft/160 grain String Shot. Run in 6,300-ft and record a jewelry pass and tie into the completion tally dated 04/06/1982. Make a 2-ft(+) correction to the top of the GLM at 6,246-ft tbg md. Drop back down and make a repeat pass. Park the CCL at 6,263-ft. Position of the center of the String Shot at is at 6,268-ft Top shot at 6,265.5-ft and the bottom shot at 6,270.5-ft. Fire String Shot. Good. POOH. Lay down String Shot. Make up the 2" RCT. Run in to 6,300-ft Record tie-in pass and made a 2-ft(+) correction again. Park the CCL at 6,258.7-ft. Position the RCT at 6,268.0-ft. Set Anchor. Fire Cutter. Good. Made several attempts to release anchor arms. Had to pull tight one time and allow the Jars to unload. Now free. POOH. Tool String recovered complete. Page 4of10 � Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 COMPZ RPEQP1 ELOG P Break out and lay down Tool String. Tubing free. String weight plus Blocks=80K. Complete Rig down E-Line. 17:30 19:30 2.00 COMPZ RPCOM RURD P Pull the Tubing Hanger to the Floor. Rig up GBR tubing handling equipment. Rig up Spooling Unit. Lay down Landing Joint and XOs. Lay down Tubing Hanger. 19:30 20:00 0.50 COMPZ RPCOM PULD P L/D pups and TBG hanger. 20:00 21:00 1.00 COMPZ RPCOM CIRC P Circ surface to surface with 6 bpm 740 psi. 21:00 00:00 3.00 COMPZ RPCOM PULL P L/D 45 joints of 3.5"tbg while pulling control line for SSSV with Camco. PUW=67 K. 10/15/2013 Continue POOH, breakout&lay down 3 1/2"tubing. Laid down 120 jnts, recovered 37 SS Bands and a SSSV. Make up Baker Model L Retrievamatic Storm valve and crossovers to tubing. Note:20K weight under packer. RIH and set packer with center element at 111'. Top- 100'. Release form packer, and test packer and casing to 2000 PSI- 10 minutes on chart. Nipple down BOP stack, and tubing spool. Nipple up Hydratite bolt system. Observed OA still spitting Arctic Pac after 12 hrs bleed time. Shut in pressure= 18 PSI. Bull head 40 BBLS 9.6 Brine down OA with FCP-720 PSI. Monitor OA 30 minutes-dead, no flow. Utilize Hydratite system to put 5000 ft lbs on casing packoff. BOLDS. Control release Hydratite jacks,with no movement observed in the 7"casing, no growth, bolts free-no pressure. RD Hydratite. Remove 7"packoff, and install new packoff as per FMC rep. Test same. Install new 11"3M x 7 1/16"3M Tubing head.Test same. Nipple up BOP's. 00:00 05:30 5.50 COMPZ RPCOM PULL P Continue laying down 3.5"9.2#J-55 BTC tbg. Recovered 37 SS bands, 1 -SSSSV, and 120 total jnts laid down. SIMOPS: Bleed OA down from 60 PSI. 05:30 08:30 3.00 COMPZ WELLPF PLUG P Make up Baker Model L Retrievematic Storm packer on stand of drill pipe and set centaer element at 111'MD.Top- 100'. Observed DP chattering while RIH, allowing DP to slightly turn to the left setting the packer.We pulled out of hole and observed packer in set position, and set it in neutral. Run back in hole to set with no issues. UP WT 50K, SO WT-50K. NOTE: Rig not centered over hole very well, and we had to work packer assembly through the wellhead area. 08:30 09:30 1.00 COMPZ WHDBO PRTS P POOH with setting tool. Fill hole with 9.6 ppg brine. Close blind rams, and pressure test casing and storm packer to 2000 PSI- 10 minutes on chart. Good test. Continue to bleed OA down from 30 PSI. Bleed pressure form casing test, and monitor well for negative test-30 minutes. No Flow observed. Page 5 of 10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 09:45 0.25 COMPZ WHDBO SFTY P Held PJSM with crew, and PESI rep. Discuss safety&hazard recognition issues. Discuss procedure to nipple down BOP stack, and tubing spool. 09:45 12:00 2.25 COMPZ WHDBO NUND P Nipple down BOP stack and lines. Crew Change. Continue bleed OA-0 PSI. 12:00 13:00 1.00 COMPZ WHDBO NUND P Continue Nipple down BOP's . Break bolts and nipple down tubing head as per FMC rep. 13:00 14:00 1.00 COMPZ WHDBO NUND P Nipple up Hydratite bolt system on casing head, installing a dummy spool for casing growth. Pressure 5000 ft lbs. Observed OA spitting Arctic Pac and not dead. Shut in= 18 PSI 14:00 16:00 2.00 COMPZ WHDBO KLWL P Discuss options with town engineer. Decision to bullhead 9.6 Brine down OA. Rig up lines to pump down OA at 1 BPM with pressure building to 800 PSI after 13 BBLS pumped away and staying steady at 800 PSI until 21 BBLS away, observing pressure dropping to FCP at 40 BBLS away- 720 PSI. Shut in, pressure=0 PSI. Monitor OA for 30 minutes with no flow. Blow down all lines. 16:00 16:30 0.50 COMPZ WHDBO OWFF P Monitor OA for 30 for flow--Static. 16:30 17:00 0.50 COMPZ WHDBO NUND P With Hydratite rigged up still, pressure to 5000 FT lbs, and release lock sdown screws on 7"casing. Observed no growth when pressure released. Rig down Hydratite bolt system, and discuss options with town engineer. Decision to change out packoff and install new tubing head. 17:00 20:00 3.00 COMPZ WHDBO NUND P Rig up pulling tool on DP, and engage packoff. Pull pack off. Install new pack off and test same. Install new tubing spool. 20:00 21:30 1.50 COMPZ WHDBO NUND P NU tubing head and test pack-off void to 250/3000 psi for 10 minutes; Good. 21:30 00:00 2.50 COMPZ WHDBO NUND P Install adapter spool, pick stack and set on well. Install bolts and tighten flange. Crew change. 10/16/2013 NU BOP, install test plug and test body 250/3000 psi on chart. Pull and RD test equipment. MU puller for Storm packer. Retrieve packer and LD same as per Baker rep. RU casing handling equipment and LD 3.5" 9.2#J-55 tubing. PU=45K, SO=45K. Total of 201 joints and cut joint(16.25'), 1-SSSV, 1-GLM and 37 SS bands. MU Dress-off Scraper assembly and RIH on 3.5"9.3#L-80 EUE-MOD tubing to joint 200. Page 6 of 10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment • 00:00 03:00 3.00 COMPZ WHDBO NUND P NU BOP;tighten and torque all connections, install secondary annulusl valve, install riser, hang and secure stack with turnbuckles. Measure RKB. Clean and clear floor. 03:00 03:30 0.50 COMPZ WHDBO PULD P PU test tools and plug. 03:30 05:00 1.50 COMPZ WHDBO PRTS P Install test plug and attempt PT on body of BOP. Test plug not seating, pulled and inspected and cleaned. Re-installed test plug and tested body breaks to 250/3000 psi on chart; Good test. 05:00 05:30 0.50 COMPZ WELLPF PULD P BD and LD test tools and blow down all surface lines. 05:30 07:00 1.50 COMPZ WELLPF PULL P MU packer retrieval assembly, RIH and release packer. Monitor well; Static. Lay down 3 joints DP and retrieval tool and storm packer per Baker rep. 07:00 08:00 1.00 COMPZ WELLPF PULD P PJSM for laying down tubing and RU GBR tubing handling equipment. 08:00 12:00 4.00 COMPZ WELLPF PULL P Pull and LD 3.5"9.2#J-55 BTC IPC tubing. PU=45K, SO=45K. Total 201 joints, Cut joint(16.25), 1 SSSV, 1 GLM and 37 SS bands recovered. Crew change. 12:00 13:00 1.00 COMPZ WELLPF PULD P Complete tubing LD, clear floor of GLM, SSV and cut joint. Clean and clear rigfloor. 13:00 14:00 1.00 COMPZ WELLPF PULD P PU and stage Baker BHA components and tools in pipeshed. 14:00 15:00 1.00 0 128 COMPZ WELLPF PULD P MU BHA#1; Dress-off/scraper assembly as per Baker rep. RIH to 128'. 15:00 20:45 5.75 128 3,755 COMPZ WELLPF TRIP P Trip in hole with assembly on 3.5" L-80 9.3#EUE-MOD tubing. 20:45 21:15 0.50 3,755 3,755 COMPZ WELLPF SFTY P Perform unannouced BOP WC drill; well secure 85 sec, CRT= 140 sec. Perform AAR to discuss and assess. Acceptable drill with good crew performance and responce. 21:15 00:00 2.75 3,755 6,273 COMPZ WELLPF TRIP P Trip in hole to joint 200 at 6273'. Wash down from 6242'to 6273'at 6 BPM with 645 psi. PU=83K, S0= 70K, Rot=75K Free torque at 12 RPM was 1.3K. Crew change. 10/17/2013 PU joint 201 and tag tubing stump at 6276'. Circulate 1.5 BU until clean returns. POOH with tubing standing back in derrick and LD DO/Scraper assembly. Service top drive and drawworks. Stage and verify completion string equipment. PJSM for running tubing. MU completion assembly; PBOS, Packer assembly, and RIH as per running order. Tag tubing stump at 6277'and shear overshot pins. Tag No-Go at 6285' (mule shoe depth). PU and circulate in corrosion inhibited brine; 220 BBI. Tag up, space up 1'and drop ball and rod. Set packer with 1800 psi and inflate with 2500 psi. Test IA and packer to 1000 psi for 10 minutes-Good. PU and space out with tubing hanger and land. Confirmed seal assembly with pumps and pressure increase when engaged. RILDS. Tested and charted IA and tubing to 3500 psi. Opened SOV with 2200 psi and confirmed with 3 BPM flow reverse and forward. RD circulation equipment. Page 7of10 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment • 00:00 00:30 0.50 6,273 6,276 COMPZ WELLPF WASH P Wash over stump at 6276' (6285'-9' swallow on shoe)with 6 BPM at 645 psi and tag with 5K down weight and pressure increase. Shut down pumps and tag stump 2X with 5-8K down weight. Pull up 10'for circulation. 00:30 01:30 1.00 6,266 6,266 COMPZ WELLPF CIRC P Circulate 1.5 BU; at 1 BU Arctic Pac was stringing out and cleaned up shortly after 1 BU. Circulated at 9 BPM with 1350 psi. Circulated clean. SPRs at 6270'with 9.6 ppg. SPR#1 35 strk/70 psi, 52 strk/160 psi. SPR#2 35 strk/70 psi, 52 strk/160 psi. Monitor well; Static. 01:30 05:30 4.00 6,266 128 COMPZ WELLPF TRIP P Trip out of the hole from 6266'tp 128' with 3.5"tubing standing back in the derrick. PU=83K, S0=70K. Change out seal rings on the trip out. 05:30 06:30 1.00 128 0 COMPZ WELLPF PULD P LD DO/Scraper Assembly per Baker rep. Clean and clear rigfloor. 06:30 07:00 0.50 0 0 COMPZ WELLPF SVRG P Service rig and topdrive, drawworks. 07:00 08:30 1.50 COMPZ WELLPF PULD P Load and stage completion equipment and review running order as per WP. 08:30 08:45 0.25 COMPZ RPCOM SFTY P PJSM for running completion; review running order and operations. 08:45 12:00 3.25 COMPZ RPCOM RCST P MU and trip in with completion string as per running order. Run 3.5"9.3# L80 EUE 8rnd tubing as per Baker rep and running order with make-up torque of 2200 ft/lb. PU=40K, SO= 40K. Run to 1700'at crew change. 12:00 16:00 4.00 COMPZ RPCOM RCST P Trip in with 3.5"tubing to 6277'; PU= 77K, S0=70K, shear pins in overshot @ 6277'with 8K down weight. Tag No-Go at 6283' Muleshoe depth with 5K down weight. Pick up to 6274'. 16:00 17:00 1.00 COMPZ RPCOM CRIH P RU to circulate corrosion inhibited brine. PJSM. 17:00 18:30 1.50 COMPZ RPCOM CRIH P Circulate corrosion inhibitor at 4 BPM with 460 psi. Pump 220 BBL 9.6 brine and chase with 8 BBL brine to clear surface equipment. 18:30 19:30 1.00 COMPZ RPCOM PACK P Drop ball and Rod, check seals with 500 psi-Good. Stage pumps to 1800 psi and set packer, stage to 2500 psi to inflate packer and slack down 10K for induced pressure relief. Test packer; IA and packer to 1000 psi for 10 minutes-Good. Pressure up tubing to 1500 psi and PU string to 30K over to shear PBR pins. Page 8 of 10 1 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 COMPZ RPCOM RCST P Pull and LD tubing joints 201, 200, and 199. MU space out pups; 10.17' 8.07, 8.06', MU 199 and tubing hanger with 2.67'pup. 21:00 21:30 0.50 COMPZ RPCOM RCST P Slack off and engage seals with PBR while pumping 0.5 BPM with 15 psi. Observe pressure increase to 60 psi as seals engaged. Bleed off pressure and land tubing hanger. Final PU=77K, SO=72K. RILDS. 21:30 23:30 2.00 COMPZ RPCOM PRTS P Pressure test tubing to 3500 psi for 15 minutes-Good. Bleed tubing to 2500 psi and pressure IA to 3500 psi for 30 minutes-Good. Bleed off pressures. Pressure up to 2200 psi to open SOV. Check flow paths reverse; 3 BPM with 160 psi, and forward; 3 BPM with 425 psi to confirm SOV open-Confirmed. 23:30 00:00 0.50 COMPZ RPCOM RURD P RD circulating equipment. Crew change. 10/18/2013 ND stack and NU tree. Test tree Freeze protect tubing, IA and OA. MU tree, oriented with FMC, Company rep and DSO. RDMO. Rig release 10/18/2013 23:59. 1E-09 Final pressures; IA and Tbg=0 psi, OA= 195 psi at 21:30. 00:00 01:00 1.00 COMPZ WHDBO PULD P PUII and LD landing joint. 01:00 01:30 0.50 COMPZ WHDBO PRTS P Install and test BPV; 1000 psi for 10 minutes-Good. 01:30 03:00 1.50 COMPZ WHDBO WWWH P Pull rotary table recover and wash out BOP stack. 03:00 05:00 2.00 COMPZ WHDBO NUND P ND riser and ND BOP stack. 05:00 07:30 2.50 COMPZ WHDBO NUND P Nipple up adapter flange and FMC 3 1/8"x 5M Tree. 07:30 08:00 0.50 COMPZ WHDBO PRTS P Rig up, and Pull BPV. Install Test plug. 08:00 09:00 1.00 COMPZ WHDBO PRTS P Rig up lines and pressure test tree 250/5000 psi and chart good test. 09:00 14:30 5.50 COMPZ WHDBO PRTS T Observed tree filled with water. Drain tree, and fill with diesel.Attempt re-test. Troubleshoot leaks. Observed test plug leaked. Pull test plug install new plug and re-test. Cycle valves on tree to allow diesel into the body of all valves.Test tree with diesel 250/5000 with diesel on chart-good test 5 minutes each. 14:30 16:00 1.50 COMPZ WHDBO FRZP P Little Red Services rigged up. Held PJSM. Line up valves and pressure test lines to 2500 PSI. Pump 75 BBLS freeze protect diesel down IA at 2 BPM-1000 PSI max. Shut down; IA=400 psi. Page 9of10 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 COMPZ WHDBO FRZP P Line up valves to U-tube diesel back to tubing until dead. Simops: Rig up Litte Red Services to OA, and pump 50 BBLS of freeze protect diesel at 1 BPM-1000 PSI. Shut down; OA= 400 psi. 17:30 18:30 1.00 COMPZ WHDBO RURD P Rig down circulating equipment, remove flange from OA and replace with gauge. Continue U-Tube. 18:30 19:30 1.00 COMPZ WHDBO RURD P Blow down all lines and RD same. Remove U-Tube lines. Pressures Tbg=o psi, IA=0 psi, OA=320 psi. 19:30 21:30 2.00 COMPZ WHDBO RURD P Remove auxiliary OA gate valve, install flange with gauge; install gauges on IA and Tbg. Pick up, clean up. Prep cellar for move. Final pressures; IA and Tbg=0 psi, OA= 195 psi at 21:30. 21:30 22:30 1.00 DEMOB MOVE RURD P BD Handi-Berm and prep cuttings tank for move. Disconnect pit module inter-tie and rig for move. 22:30 00:00 1.50 DEMOB MOVE RURD P Move cuttings tank and pull pit module back from rig. Rig release 23:59 10/18/2013 Page 10 01 10 • WELL LOG TRANSMITTAL DATA2�L�2 ED \�/lA1013 M K BENDER To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender October 15, 2013 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 L}�- L v 2Uy4 RE: String Shot Record, Tubing Cut Record: 1E-09 Run Date: 10/14/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook @halliburton.corn 1E-09 Digital Data in LAS format, Digital Log Image file 50-029-20720-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Hailiburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook @halliburton.corn Date: Signed: ■.ra . • • w �\��%%i�s� THE STATE Alaska Oil and Gas �� _ � OfALAS]�� Conservation Commission 4. *h GOVERNOR SEAN PARNELL 333 West Seventh Avenue Oj +mr p, Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 r sir Jake Voss Wells Engineer 1 q X— Q ConocoPhillips Alaska, Inc. [ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-09 Sundry Number: 313-460 Dear Mr. Voss: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, O Daniel T. Seamount, Jr. Commissioner DATED this 1� day of September, 2013. Encl. I ■a aw y STATE OF ALASKA AUG 2 3 2013 AlikA OIL AND GAS CONSERVATION COMAION 7 APPLICATION FOR SUNDRY APPROVALS ,\V ' C 20 AAC 25.280 ®� 1.Type of Request: Abandon r Rug for Redrill f Perf orate New Pool n Repair w ell 17• Change Approved Program Suspend f' Rug Perforations fl FFrforate f Pull Tubing Fy. Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Convert from WINJ t017 016- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182-028 3.Address: Stratigraphic Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20720-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 E-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651, Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7000 . 6674 - 6878'- 6556' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 49 16 80' 80' SURFACE 2432 10.75 2463' 2463' PRODUCTION 6931 7 6962' 6638' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6664-6673,6688-6708,6712-6718. 6352-6360,6375-6394,6398-6403 3.5 J-55 6385 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-OTIS HYDRAULIC PERMANENT PACKER MD=6308 TVD=6015. PACKER-OTIS PACKER PLUCKER(PART OF PACKER ASSEMBL MD=6315 TVD=6021 SSSV-CAMCO TRDP-1AE SSSV MD=1905 TVD=1905 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service For 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/30/2013 Oil r' Gas r WDSPL r Suspended 16.Verbal Approval: Date: WINJ I, ' GINJ r WAG V Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jake Voss @ 265-6935 Email: Jake.Vossaconocophillips.com Printed Name J e Vfoy Title: Wells Engineer Signature V.^------ Phone:265-6935 Date '/LE./13 Commission Use Only Sundry Number: 3i3....(j�,,/� � ) Conditions of approval: Notify Commission so that a representative may witness t/ w Plug Integrity r BOP Test Mechanical Integrity Test Location Clearance r ` M OCT 1 0 2 Other: /J 'P e-,5 to et, p S ` • 1--ct t z4--, h7 r$ r� Al IT" //� rc I, /`✓rl/ A rt-Cr 1-f-/1a Vi ///3Tcf / J7cti . Spacing Exception Required? Yes 0 No [ Subsequent Form Required: j, . Yeti�an� Afp - v _ ci v (lre �� ,4 c .)5.4/2 -(b) a^r vppr;� ac1rr-K1� I rrhiril. APPROVED BY �2` C$b tom` �� Approved by: COMMISSIONER THE COMMISSION Date,.c`� /!1 }/ -_ Approved application is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) PP PP 0 R � � I ppubmm and Attach nts i uplicate N A L ,�� 3�3 • RECEIVED lory AUG 23 2013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 21, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1E-09 (PTD 182-028). 1E-09 was originally completed in April of 1982 as an 'A' & 'C' Sand water injector. The'C' sand perforations were cemented in April of 1997, but the squeeze job appears ineffective. As per the latest (PROF recorded on 3/24/2011, at an injection rate of 5550 BWPD & 1300 psi wellhead pressure 100% of the injection fluid (water)was going into the 'C' sand. 1 E-09 has only been injecting water, gas injection never been applied to this well. It is desired to convert this well to an MWAG injector to provide injection support to an area that has seen minimal waterflood and MI support. The purpose of this workover is to set it up for MWAG injection./This sundry application is to document the change of service for this well./MWAG injection requires a tubing head rating of 5K psi which it currently does not have. During this workover, the objectives are to pull & replace the tubing with an overshot/stack packer, as well as replace the IC packoffs and upgrade the tubing head. Due to the stacked packer completion, the upper packer will be approximately 240' above the top perforation. We re test a variance for AOGCC 0 25$412 for this well. Attached is the CBL for 1E-0 showing compe en cement 500' above the proposed packer depth and behind the packer. If you have any questions or require any further information, please contact me at 265-6935. Sincerely Jaco oss Wells Engineer CPAI Drilling and Wells • • 1E-09 Rig Workover Pull & Replace Tbg, Upgrade Wellhead (PTD #: 182-028) Current Status: This well is currently online. Scope of Work: Pull&replace the tubing w/po-boy overshot and stack packer,upgrade the wellhead and replace the IC packoffs. General Well info: ✓ MASP: 2,190 psi Reservoir pressure/TVD: 2,829 psi/6386' TVD(8.52 ppg) Wellhead type/pressure rating: FMC Gen 1, 11"3K psi top x btm BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Variable Pipe Rams CMIT and DDT results: CMIT-passed on 8/13/13,MITOA—IAxDDT–passed on 8/20/13 Well Type:Injector Earliest Estimated Start Date: September 30,2013 Production Engineer: Dana Parker/David Lagerlef Workover Engineer: Jacob Voss(265-6935/jake.voss @conocophillips.com) Pre-Rig Work Request: 1. Set BPV Proposed Procedure 1. MIRU Nabors 7ES. Pull BPV. Circulate 8.6 ppg seawater. Verify well is dead. Set BPV. ND tree. Install blanking plug. NU BOP. Pressure test BOP including annular to 250/35815 psi. 2. Pull blanking plug and BPV. POOH laying down tubing. 3CC'e P 3. PU&RIH w/po-boy overshot and stack packer assembly. 4. With 2500'RIH,install storm packer&PT. 5. ND BOP stack,ND tubing head,change IC packoffs,install new FMC Gen 4, 11"-3K x 7-1/16"-5K tubing spool. NU BOP stack,test wellhead breaks and shell test BOP stack to,,3s$0 psi. 6. Retrieve storm packer and continue RIH w/3 '/2"completion. �'�'C� S 7. Locate tubing stub,circulate in corrosion inhibited fluid. Drop ball&rod and set packer. Shear PBR,space out tubing and land hanger. PT tubing and IA to 3500 psi. Shear SOV. 8. Set 2-way check. ND BOP. NU tree and pressure test. 9. Pull 2-way check. Freeze protect well. Set BPV. RDMO Nabors 7ES. Post-Rig Work request: 1. Pull ball&rod. Pull SOV and install DV. Pull RHC plug body. Pull catcher sub&plug from D nipple. 2. Complete facilities tie-in to the MI header. 3. Return well to injection. ■ . 0] - _ 1 E-09 — Injector ConocoPhillips r Overshot/Stack Packer Wellhead Swap Planned Schematic -4—Casing– 10-3/4"45#, K-55 BTC @ 2,463' Tubing–3-1/2" 9.3#, L-80, EUE-Mod f— MMG Mandrel @ approximately 6,210' � PBR approximately 6,240' ' -41----41--- @ a pp J .• f-- Baker FH Packer @ approximately 6,250' �?34-' Gc.bc✓C d 2.313"X-Nipple @ approximately 6,260' -10 f— SBE/Seal Assy @ 6,284' _ J Otis Hydraulic Permanent Packer @ 6,308' Otis Packer Plucker 6,315' ',4 bd Ve -c i -4--Otis @ a s I 2.25" D-Nipple @ 6,354' fv p pi"rF Il 1 1 2.992" Shear Out Sub @ 6,385' C-4,C-3, C-2, C-1 Perfs @ 61484-6,544' _° __ (Failed Cement Squeeze) .7.-.---z– , = A-5 Perf @ 6,664-6,673' —•' I I A-4 Perf @ 6,688'-6,708' —► I I A-4 Perf @ 6,712'-6,718' f--Casing–7" 26#, K-55 BTC @ 6,962' Date: August 13,2013 I Drawn By: Jake Voss CI ) ---Ws----_,..„ i °"42 -- '+Wa . ." ., .:.< w+w.++ af.wwr 9 A N Pd s=c .a —a- .. ._ s . 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' t Una '1 :' , INFZU 11101 MOW . ,., gar.1111==a AMMO,1•1111111.111111•1111111.4111111 ............. - WS ars 1:14m,10.5== ',.. ; i I . liga-4 WOW•■••••• MOW 1111■11111*IL •IR .. 611.011MONSL1101,01. ' .M. 4* . , t ' PI III = =:=NrassarAmosgunk ANWIMMIIMMAIOr..1.... vim ■ IMINININNIMMINNIFINNI ''''+'"iraligEn " , . . . „,,' ifflii #01111RM 1111P11..10 000111torr*mil . -t * 1 ....modiamosio.,AND • „„. t • • Ferguson, Victoria L (DOA) From: Voss,Jake <Jake.Voss @conocophillips.com> Sent: Monday, September 09, 2013 9:35 AM To: Ferguson,Victoria L(DOA) Subject: RE: [EXTERNAL]1E-09(PTD 182-028, Sundry 313-460) Follow Up Flag: Follow up Flag Status: Flagged Victoria, You are right, I had overlooked that top flange rating. Good catch,we will test the BOP to 3,000 psi. Thanks, Jake Original Message From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday,September 06, 2013 2:05 PM To:Voss,Jake Subject: RE: [EXTERNAL]1E-09(PTD 182-028,Sundry 313-460) Jake, You note the FMC Gen 1, 11"3K top and bottom. Why are you pressure testing the BOP to 3500 psi? Thanx, Victoria Original Message From:Voss,Jake [mailto:Jake.Voss @conocophillips.com] Sent: Friday,September 06, 2013 12:08 PM To: Ferguson,Victoria L(DOA) Subject: Fwd: [EXTERNAL]1E-09(PTD 182-028,Sundry 313-460) Victoria, Attached are the wellhead schematics of the FMC Gen 1 and Gen 4. If you need more information please let me know. Thanks, Jake Sent from my iPhone Begin forwarded message: From: "Hite, Kevin (FMCTI)"<kevin.hite@ fmcti.com<mailto:kevin.hite@fmcti.com» 1 • Date:September 6,2013, 10:52:17 AM AKDT To: "Voss,Jake"<Jake.Voss @conocophillips.com<mailto:Jake.Voss @conocophillips.com» Subject: RE: [EXTERNAL]1E-09(PTD 182-028,Sundry 313-460) The Gen 1 schematic is from 1978.....The Gen 4 one is much more detailed... Kevin E. Hite Base Manager E: kevin.hite @fmcti.com<mailto:kevin.hite @fmcti.com>I P:907 563 3990 I M:907 529 0106 From:Voss,Jake [mailto:Jake.Voss @conocophillips.com] Sent: Friday,September 06, 2013 10:32 AM To: Hite, Kevin Subject: Fwd: [EXTERNAL]1E-09(PTD 182-028,Sundry 313-460) Kevin, Can you help me out with the wellhead schematics for the state? Thanks, Jake Sent from my iPhone Begin forwarded message: From: "Ferguson,Victoria L(DOA)"<victoria.ferguson @alaska.gov<mailto:victoria.ferguson @alaska.gov» Date:September 6, 2013,9:55:48 AM AKDT To: "Voss,Jake"<Jake.Voss @conocophillips.com<mailto:Jake.Voss @conocophillips.com>> Subject: [EXTERNAL]1E-09(PTD 182-028,Sundry 313-460)Jake, Please provide wellhead schematics for the current wellhead(FMC Gen 1) and the new wellhead(FMC Gen 4). Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil &Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson @alaska.gov<mailto:victoria.ferguson @alaska.gov> 2 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1E-09 Run Date: 3/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20720 -00 Injection Profile Log 1 Color Log 50- 029 - 20720 -00 'YAA API tY tl PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. / Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 - 273 -3535 an64 klinton.wood @halliburton.com 1 0 Date: Signed: • • ConocoPhillips 1 µ Alaska f P.O. BOX 100360 - -- ANCHORAGE, ALASKA 99510 -0360 AN ti 4 ;rrkca P:' 2 V vor.& 1'' • : sion December 30 2010 ` U ;ne00 Commissioner Dan Seamount Alaska Oil & Gas Commission � 333 West 7 Avenue, Suite 100 NQ 4 JAN 201 � Anchorage, AK 99501 1 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23 24 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 12/30/2010 1C, 1 E, 1F, 1 G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1C-07A 50029205690100 2090290 3'2" n/a 3'2" Na 4.3 12/23/2010 °1 E -09 • 50029207200000 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" Na 3'9" n/a 11.6 12/22/2010 1E-16 50029207770000 1821100 4' Na 4' n/a 13.7 12/22/2010 1E -17 50029207930000 1821160 3'11" n/a 3'11" n/a 8.5 12/24/2010 1F-13 50029210200000 1831440 6" n/a 6" n/a 3 12/23/2010 1F-17 50029226570000 1960470 SF Na 18" n/a 7.65 12/23/2010 1 F -20 50029226610000 1960530 6" n/a 20" Na 6.1 12/23/2010 1 1G -13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y-01 50029209330000 1830500 SF n/a 6" n/a 1.9 12/21 /2010 1Y-03 i 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF n/a 6" Na 1.7 12/21/2010 1Y-11 50029209260000 1830410 9" n/a 9" n/a 2.6 12/21/2010 1Y-12 50029209130000 1830260 4' n/a 4' n/a 8 12/21 /2010 1Y-13 50029209030000 1830150 15" n/a 15" n/a 1.7 12/21 /2010 1Y-14 50029209100000 1830230 24" n/a 24" n/a 1.7 12/21/2010 1Y-16 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21/2010 Page 1 of 3 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Wednesday, October 27, 2010 2:44 PM To: Maunder, Thomas E (DOA) Subject: FW: LPP /SSV put back in service for 1 E -09 on 10 -18 -2010 Hi again Tom, I don't have your phone number, but the LPP on 1 E -09 was placed back into service 10/18/10. 1 just checked, and the LPP is in service and the wellhead injection pressure is 946 psig while injecting 3,500 bwpd. Give me a call if you have any questions, 1 S D Daniel Bearden /David Lloyd Lagerlef CPF1 Production Engineers n1269@conocophi[lips.com 659 -7493 pager 659 -7000 765 From: CPF1 Prod Engr Sent: Monday, October 18, 2010 3:56 PM To: 'Maunder, Thomas E (DOA)' Cc: NSK Prod Engr & Optimization Supv; CPF1 DS Lead Techs; CPF1 Ops Supv Subject: RE: LPP /SSV put back in service for 1E -09 on 10 -18 -2010 Tom /Jim, The low pressure pilot (LPP) on injection well 1 E -09 was returned to service on 10/18/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. The low pressure pilot had been defeated as the initial well head injection pressure was low from due the well being shut in an extended period of time for a corroded well line. The well was put back on injection at a reduced rate to avoid tubing and casing damage from thermal expansion. Current wellhead injection pressure is 1300 psig; injection rate is 4,400 BWPD. Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 From: NSK Prod Engr & Optimization Supv Sent: Sunday, October 17, 2010 8:57 PM To: 'Maunder, Thomas E (DOA)' 11/29/2010 Page 2 of 3 Cc: CPF1 Prod Engr Subject: RE: LPP /SSV defeated for 1E -09 on 10 -12 -2010 Tom, the well is pressuring up nicely currently at 122 psi wellhead pressure. It's gained -100 psi in the last 5 days and should increase faster when we get more PWI to add to it. Gary From: NSK Prod Engr & Optimization Supv Sent: Wednesday, October 13, 2010 11:36 AM To: Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPFi&2 Ops Supt Subject: RE: LPP /SSV defeated for 1E -09 on 10 -12 -2010 Thanks Tom. I'm checking w/ the person responsible for the well line upgrades to see how many more could fall into this category. Gary Gary Targac /Denise Titus NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 12, 2010 10:42 PM To: NSK Prod Engr & Optimization Supv Subject: RE: LPP /SSV defeated for 1E -09 on 10 -12 -2010 Gary, Sorry I did not get back to you sooner. It is acceptable to keep the well on. I need to look into the conservation order. It is probably appropriate to write an AA regarding the protocol to handle this. Will there be other wells that have not been active for long intervals? Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 @conocophillips.com] Sent: Tue 10/12/2010 1:48 PM To: Maunder, Thomas E (DOA) Cc: CPF1 Prod Engr; CPH DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; Wu, Jianbing; Seitz, Brian; Rodgers, James T Subject: LPP /SSV defeated for 1E -09 on 10 -12 -2010 Tom, ConocoPhillips requests administrative approval under CO 432D to operate a Kuparuk water injection well with a defeated safety valve system. This request is similar to CO 4068 administrative approval granted to the West Sak Pool. 11/29/2010 Page 3 of 3 The LPP for injection well 1 E -09 has been defeated due to low injection pressure as the well has been shut -in since February 2001. The well line was recently repaired and was brought back online today. We expect injection pressure to increase sufficiently in the next few weeks as the reservoir pressure increases. This will allow us to re- engage the SVS system and return the well to normal operations. The well is currently injecting 600 bwpd at pressures below the minimum LPP set point. A MITIA was performed on 6/24/10 with the outcome listed below. Thanks in advance for your time on this matter and call or email me with any questions. Regards, Gary 06/24/10 STATE WITNESSED ( Bob Noble) MIT -IA ( passed ), T /1 /0= 320/480/120. Pressured up IA with 2.0 bbls diesel, T /1 /0= 345/2420/260. 15 min T /1 /0= 345/2370/180. 30 min T /1 /0= 345/2360/170. Bled IA, T /1 /0= 320/450/120. Gary Targac /Denise Titus NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 11/29/2010 • MEMORANDUM To: Jim Regg ~~ ~ -~z~~ ~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-09 KUPARUK RIV UNIT 1E-09 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV UNIT 1E-09 API Well Number: 50-029-20720-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100627074812 Permit Number: 182-028-0 Inspection Date: 6/24/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ]E-09 ~- ~ -/ 6 Well ~ Type InJ. ~ N TVD 015 '~ IA 480 2420 ~ 2370 2360 P.T.DI 182o2so TYPeTest~PT j Test psi 2420 ~ OA 12o z6o Iso 170 IntervalaYRTST per' / Tabin P g 320 345 i 345 _ 345 _ Notes: }~liVl~ ~'eq~c~ -~~d- cJO~p _ si r k ~ 5f Wednesday, June 30, 2010 Page ] of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ,-;-::> P.I. Supervisor N:Y1' (,,( q ~G. DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASK.i\ INC lE-09 KUPARUK RIV UNIT lE-09 8rc: Inspector {)~ \ 4;¡?T FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv5íší2-- Comm Well Name: KUPARUK RIV UNIT IE-09 API Well Number 50-029-20720-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605094909 Permit Number: 182-028-0 Inspection Date: 6/4/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ¡Type Inj. ¡ N ! TVD ! I , I -- Well 1E-09 6019 IA I 500 2250 2225 2225 P.T. : 1820280 : : I ! ---+--+ ITypeTest I SPT i Test psi 1504.75 OA ! 120 280 200 200 I I ~ -- Interval 4YRTST PIF P Tubing! 0 i 0 ! 0 0 Notes Well temporarily shut in for common line repair. 'fP-;VNJ::: ;~'\tt't'J,':~ -.,~i)" Wednesday, June 07, 2006 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (j~"\ Chair DATE: July 11, 2002 THRU: Tom Maunder P.I. Supervisor FROM: John Crisp PetrOleum Inspector SUBJECT: Mechanical Integrity Tests Phillips Alaska 1 E Pad 1E-01,1 E-04,1E-08,1E-09 Kuparuk River Field Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1E-01I Type,nj.IsI I'Tubingl 0 11750 11750 [IntervalI 4 P.T.D.I 1800390 ITypetest} P }TestpsiJ 1500 I CasingI 1650I 2450 ~ }, .. 2425 J-: 2425 ],.. P/F J P Notes: 1 bbl. pumped for test pressure. WellI 1E-04 I Typelnj. I S I T.v.D. 15845 I Tubing 12064 I~0~, I~0~, I~0~" J lntervalI 4 P.T.D.I 1800570 TypetestI P .ITestpsiI 1500 lC.usingI 1700 12s00 I. 2725 I2700 I P/F I P Notes: 1 1/2 bbls. Pumped for test pressure. WellI 1E-08IT ,.,ni.IN I,.v.~.l I Tubing[ 150 I 175 J 175 I175 Ilntervall 4 P.T.D.I 1800810 ITypetestl 'P ITestpsil 1504 I Casingl 380 I 1750 I '1725I 1,725I P/F I P Notes: 2 1/2 bbls. PUmped for test pressure. WellI 1E-09 I Type,nj.I , I T.V.D. 10015 I Tubingl'250 ]300 1300 ! 300 I lntervall 4 P,T.D.I 1820280 ITypetestl 'P ITestPsiI so4 ICasing l .... 0I, sso I e2s, ! 1600 I P/F I --P Notes: 5 bbl. pumped for test psi. Observed,test ;pressurefor-additiOna115 minUtes,' final pressure,1590 psi. WellI I Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER IN J. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test 4 MIT's:performed, no failures Witnessed. Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: _4 cc: MIT report form 5/12/00 L.G. MIT PAl 1Ea 07-11-02jc.xls 7/24/2OO2 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1163' FSL, 809' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2518' FSL, 1276' FEL, Sec. 16, T11N, R10E, UM At effective depth 2666' FSL, 1299' FEL, Sec. 16, T11N, R10E, UM At total depth 2666' FSL, 1299' FWL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7000 feet Plugs (measured) 6674 feet 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-~) / ~/-~ ~C/~ 9. Permit number/approval number 82-28 / 8-509 10. APl number 5o-029-20720 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 6 8 7 8 feet Junk (measured) true vertical 6557 feet Casing Length Size Cemented Structural Conductor 78' 1 6" 250 Sx AS II Surface 2463' 10 3/4" 1050 Sx AS III & Intermediate 250 Sx AS I Production 6962' 7" 620 Sx Class "G" Liner Perforation depth: measured Measured depth True vertical depth 78' 78' 2463' 2463' 6962' 6638' 6484'-6544', 6664'-6673', 6688'-6708', 6712'-6718' true vertical 6181'-6238', 6352'-6360', 6375'-6394', 6398'-6403' Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 6386' MD RKB Packers and SSSV (type and measured depth) Camco TRDP-1AE SSSV @ 1905'; Otis HSP Packer @ 6308' MD TVD 13. Stimulation or cement squeeze summary Well 1E-9 was perforated in the C Sands from 6484'-5444' MD on 6-17-88 (see attached). Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 200 1 000 245O Subsequent to operation (WI) 0 0 1300 1 0 00 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , Sig ned ,//~¢..~,/f.~ ~? ~',~ ' Title Form '-10-404 Re/(/ '06)15/88 ' 1350 Service water inj. Date ~--~ ~P,,,~ -~/3 SUBMIT IN DUPLICATE .ARCO Alaska, Inc~,~.. Subsidiary of Atlantic Richfield Company, WELL IPBDT _ CONTRACTOR ,EMARKS ..... I ........ FIELD- DISTRICT- STATE OI~ERATI~)N AT REPdR~ TIM~: WELL SERVICE REPORT ]DAYS ]DjTE 1~3C) //.. ~)~ I-"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ;~a~ , ~ ~.-~,- 2 ~ ' ' ~ .... ' ~/J - --~~~~ - ~ - ~s ~ ~ ~ - ~,~ ~ ,~ ,7 ' ' S~ ~~ ~ &~o~ ~ /ds~ ......... ~ ' --- ~ d Slgn~ knot. REMARKS CONTINUED: DESC RI PTION DAILY ACCU M. TOTAL · OTIS ' S'CH{.UMBERGER '" I ' "DRESSER.ATLA~ " DOWELL HALLIBURTON ARCTIC COIL TUBING " '" FRA'~MASTER B. J. HUGHES "Roustabouts '3--. ~)~'~-~-~S LDieSel J . " MethanOl Supervision ,, Pre-Job' Safety Meeting ..... ...... -- ,, TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMk,,ISSlON APPLICATION FOR SUNDRY APPROVALS Abandon Suspend . ' Operation Shutdown 1. Type of Request: T~me extension Change approved program Plugging "'; Stimulate -] Pull tubing 2 Name of Op,erator~ ARCO AlasKa, znc. 3 Address PO Box 100360, Anchorage, AK 995:10 4. Location of well at surface :1163' FSL, 809' FEL, Sec.:16, T].IN, R:10E, UN At top of productive ~nterval 2518' FSL, 1276' ~ g f~ ?c ~'~eLd, e ~.tL~ 99, At total depth 2666' FSL~ 1299' Present well condition summary Total depth: measured 7000' MD true vertical6674' TVD FEL, Sec.16, T11N, RIOE, UM FEL, Sec.16, T11N, RIOE, UM FEL~ Sec.16~ T11N~ RiOE~ UM feet feet Re-enter suspended well 71 Alter cas.ng El Amend order .r Perforate ,r)( Other R~BD~. flevation (DF or KB) 11. feet 6. Unit or Property name Kuparuk River' Unit 7. Well number 1E-9 8. P~rmit.oumber Perml t #82-28 9. APl number 5o-- 029-20720 10. Pool Kuparuk River 0il Pool Plugs (measured) None Effective depth: measured 6878' MD feet true vertical6557, TVD feet Casing XXX,~ZCaX;ZQ¢~IKX X XX Conductor Surface X X x,l~j~Nl,[e~d~.at e Production xxxk&~y, xxxx Perforation depth: Junk (measured) None Length Size Cemented 78' 16" 250 SX ASII 2463' 10-3/4" 1050 SX ASIII & 250 SX ASI 6962' 7" 620 SX Class G Measured depth True Vertical depth 78' 78' 2463' 2463' 6962' 6638' measured 6664'-6673' 6688'-6708' 6712'-6718' MD true vertical6352,-6360' , 6375'-6394' , 6398'-6403' , TVD R E £ E IV E D Tubing (size, grade and measured depth) 3½" J-55 @ 6386' MD JUN Packers and SSSV (type and measured depth) ~_]a$~ 0il & Gas Cons. Camco TRDP-1AE SSSV (a ]905' MD: Otis Packer ~ 6308' MD ..... , Anchnr~ 12.Attachments Description summary of proposal ~ Detailed operations program [; BoP- Perforate C Sands' 6484'-6544' MD-RKB. 13. Estimated date for commencing operation 6-17-88 Sulo~u2~.,;,t .~,__.,_ ~, ~....~ 14. If proposal was verbally approved tTorm No.--------- Dat~d__/--/-- Name of approver Z, Si~i'i1~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~ ~ /7)/~:[~,~.~~ Title Sr. Operations Engineer " t~ '- Commission Use Only Conditions of approval Approved by N~otify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test E~ Location clearancel Approved Copy Returned OttlGINAL $18NEO - BY LONNIE C. SM~ Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date ~,-~ - ~' Submit in triplicate WELL 1E-9 PERFORATING PROCEDURE 1) MIRU Wireline for gauge ring run. PT lubricator to 3000 psi. 2) RIH. Tag fill (last tag at 6870'MD-RKB on 10/23/827). 3) POOH. RDMO Wireline unit. 4) MIRU E-line perforating unit. PT lubricator to 3000 psi. 5) With well shut-in, RIH with CCL/perf guns/magnetic decentralizer. 6) Tie in depth using Schlumberger CBL dated 4/6/82 (short joints at + 6550'-6600° MD-RKB) 7) Perforate the following interval: Depth (MD-RKB) ~g Shot Density 6484'-6544' CBL 4/6/82 4 SPF or DIL 4/3/82 8) After last gun run, POOH, RDMO E-line unit. 9) Return well to injection. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 3 1. 50C)C) PSI ?" WELLHF. A~ CONNECTOR FLANGE 2.~ 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 RECEIVED Gas Cons. Commission Anchorage H ] REL ] NE BOP E,OU ! pMENT I I Mr. C.~V. Chat*'~rtOn May 27, 1986 Page 2 KUPARUK · ATTACHMENT ~ ~;~."'J 7 C, RIVER UNIT INJECTION LOGS -,_ ............... &. k.'- ..... ~,-- '- INJECTION PROFILES .... Well Number Date of Initial Injection Date of Injection Profile 1A-7 1A-9 1A-11 1A-12 1A-13 1A-14 1A-15 1A-16 3/21/83 3/25/83 3/1/83 3/22/83 3/7/83 3/21/83 3/1/83 3/6/83 2/4/83 10/17/83 2/22/83 4/11/83 3/1/83 3/18/83 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 -. · 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 '1E-23 1E-27 1E-30 1 Number 1F-lO 1F-11 1F-13 1F-15 Date Date 1 Number Wel Wel 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 of Initial Injection Date of Injection Profile 8/!3/84 10/30/84 8/12/84 9/24/84 8/16/84': 9/25/84 8/16/84 9/26/84 - of Initial Injection Date of Injection Profile 1G-3 10/25/85 12/20/85 1G-6 7/28/84 9/23/84 1G-9 9/15/84 9/23/84 IG- i4 8/24/84 9/22/84 1G- 16 8/24/84 9/22/84 ARCO Alaska, Inc. Post Office B~. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:!0-02-85 TRANSMITTAL N0:5376 ETUi%N TO: ARCO ALASKA, iNC. KUPARUK OPEK'ATiONS i.'NGINLERING RE CO.~S CLERK A?O-!il5B P.O. bOX 100360 ANCHORAGE, AK 99510 ~=-.:,~..~=~u HE~Lb H ARS · '~ FOLLOWING iTEMS. PLLASL AC~NO,~LEDGE -= AND RL~U~x ONE SIGNLD COPY OF THiS TRANS~ITTAL _ . ~--- ', ~Qb~NC~ OF ~V~. A ~_,b P~h~SU.~ BUILD-UP 0~-2 u~i~:~u=, ~¥~h~ Pz~SSuH~ R~_'~= E~'~VELOPE FACES-ON u~-z~-c~ ~.~ .. SAND OTIS vc-zo-o~ ~z~..~ .. SAND . ~-u~-oo ~z.~_ ~ ~ S~2~D OTIS PSU £-9 09-07-~5 X-il 08-28-85 ]-12 09-04-85 F-5 08-17-85 F-5 08-17-35 3-5 08-17-85 'A' SAND O?IS 'A' SAND OTiS ' C' S!~D CAHCO PBU 'A' SAND BAKER/LYNES PBU 'C' SA_ND BAKER/LYNES PBU :A&C' SAND B~KER/LYNES 2VRO N' ~ DiST-<iSOT!ON: DRILLING t,t. PASiiER L. JOiihSTON EXXON [,lOBi L* PHILLIPS OIL* NSK CLERK J. RATHMELL* DATE _~__.._!_..:._, :' '"" "'" ' ' ,, .n', ~' STATE OF ~.r~e~~'* ~ SOHIO* U NI ON* K'. TULIN/VAULT ARCO Alaska. Inc. is a ,Subsidiary of AtJanticRichfieldComoanv KUPARUK ENGINEERING TRANSMITTAL # ~/~ TO' ~ FROM- .~ D. Fay Allison / -- DATE: ~_ '-,~/$,, ! ¢o°'z// Transmitted herewith are the following- WELL NAME- PLEASE NOTE!~)- BLUELINE, S - SEPIA, F - FILM, T - TAPE, _~ PHOTOCOPY Alaska Oil & *'Gas Cons. Comrni~slor~ PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. Anchorage ATTN' D. FAY ALLISON- ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 j~g['"~'~ACKNOWLEDGED: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] cOMPLETED WELL [] OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 1163' FSL, 809' TllN, R10E. BOTTOH HOLE LOCATION: SEC. 16, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 105 CKB} -- 12. FEL, SEC. 16, 2666' FSL, 1299' FEL, 6. Lease Designation and Serial No. ADL 2565] 7. Permit No. 82-28 8. APl Number 50-029-20720-00 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-9 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 26, 1982 a step rate performed on Kuparuk River Unit times, rates and pressures during test/unpropped fracture Well 1E-9. Following the test. treatment was is a table of Time Surface Pressure Injection Rate 1127 1750 psig 170 BOPD 1210 1800 240 1230 1900 312 1300 2300 486 1340 2800 2250 1430 3000 3072 Following the injectivity test the tubing was displaced with 35 bbls of diesel and the well was left shut in. RECEIVED MAY 0 6 1983 14.1 hereby c,~ti~ that t,~ forego;ng ~ true and correct to the best of my knowledge. KUPARUK Alaska 0il & Gas Cons, 60mmissi0~ Anchorage ,,/ )('/ ,,. ~ The space below for Commission use Title OPERATIONS COORDINATOR Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM- D. W. Bose/Shelby J. Matthews DATE' ~-/Z/~_?~C~- ~:>~ WELL NAME' Transmitted herewith are the following- PLEASE NOTE: BL- BLUELINE, S- SEPIA, F- FILM, T- TAPE, C~-- PH~ RECEI PT AC'KNOWLEDGED' '; ' EA'SE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: SHELBY O. HATTHE~S - AFA/3~sk~011 & Gas Gons~ Commissio~ - . P~O BOX 360 A~chorage ANCHORAGE, AK. 99510 AYE ARCO Alaska, Inc. ~ Post Office Box ,..,0 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager October 21, 1982 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Attached is a notice of ARCO Alaska, Inc.'s intent to .run injectivity tests/un-propped fracture treatments on Kuparuk wells 1E-10, 1E-9, and 1E-13. These wells are low rate producers that wi l 1 be converted to water injection for the Increment I Waterflood later this year. We feel that these wells need to be stimulated to ensure sufficient injection rates 'to prevent freezing problems. Based on our previous experience, we anticipate that creating short, unpropped fractures by injecting water at pressures above the formation parting pressure will result in improved injectivity at pressures below the fracture pressure. Notice of our intent to clean out well 1A-11 is also attached. Please call me at 263-4528-if you have any questions. L. Stramp Kuparuk Operations Coordinator ' RLS/b Attachments xc' L. K. Blacker - AFA 330 L. M. Sellers - ANO 332 E. A.' Simonsen - AFA 331 · H. C. Vickers - AFA 326 ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichf. ieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO,eMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA., INC, 3. Address P. O. BOX 360, ANCHORAGE,, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1163' FSL, 809' FEL, SEC. 1'6, T11N, R10Eo BOTTOH HOLE LOCATION' 2666' FSL, 1299' FEL, SEC. 16, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 105 (KB) 6. Lease Designation and Serial No. ADL 25651 7. Permit No. 82-28 8. APl Number 50-029-20720-00 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-9 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice. Report. or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or ComPleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a combination step rate/unpropped fracture treatment on Kuparuk well 1E-9 to gain further reservoir data and to improve the injectivity of the well. The test wil 1 consist of injecting heated water from our water source well. testing program into the well for approximately thirty minutes at each of the fol lowing surface injection pressures: 1800 psig, 2100 psig, 2400 psig, 2500 psig, 2600 psig, and 2700 psig. The anticipated fracture pressure at the surface is 2425 psig. After the test, the well will either be produced to tanks, produced to the CPF, or shut-in, depending on the results. Expected start date' 10/26/82 · 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Sign ed'-~~r,,l~ L. ~ Title OPERAT T ON.C; The space b/0bw for Commission use COORDTNATOR Date (~'"Zl-~z- Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER Approved Copy Returned By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK E~GINEERING TO: DATE: TRANSMITTAL ~~/~ ~ELL NA~E: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI,EASE NOTE: - S F - FILM, T - TAPE ... RE.CELVED Alaska Oil & Gas Cons. Commission Anchorage -~PT ACKNOWLEDGED: E RETURN RECEIPT TO: -. DATE: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office .;?c .)0 Anchorage. Af~ska 99510 Telephone 907 277 5637 May 26, 1982 Mr. C. V. Chatterton Commissionec State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Repozts - Kuparuk Dear Mr. Chatterton: Enclosed are well completion reports For the following dtillsites: 1A-16A (Sidetrack) 1E-9 · 1E-10 Also enclosed are monthly reports For April on these wells: 1E-11 1H-5 Sincerely, P.A. Van Dusen Regional Drilling Engineec PAV/JG:llm Enclosures GRU6/B4 STATE OF ALASKA ~ ALASKA.,_ .t. AND GAS CONSERVATION Cq ~. ~,M ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Tnc. 82-28 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20720 , 4. Location of well at surface 9. Unit or Lease Name 1163'FSL, 809'FEL, Sec. 16, T11N, R10E, UN ~' Kuparuk River Field At Top Producing Interval I VERIFIED 10. Well Number " 2518'FSL, 1272'FEL, Sec. 16, T11N, R10E, UM Surf. ,_.~___ 1E-9 At Total Depth B.H.~' 11. Field and Pool 2666'FSL, 1299'FEL, Sec. 16, T11N, R10E, UM ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0';1 Pool 105.7' RKB 'I ADL 25651 ALK 469 12. Date Spudded0 3/26/82 13. Date T. D. Reached04/03/82 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116" N°' of C°mple~i°n~04/08/82 N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set 1 21. Thickness of Permafrost 7OO0'MD 6674' TVD 6878'MD 6556' TVD YES [] NO [] 1905' feetMDJ 1450' .. 22. Type Electric or Other Logs Run CBL/VDL/GR, Gyro/CCL :~ DILI~,PJGRIEP'L.~ FDC.../~I~LJ 0.,AL. 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 78' 24" 250 sx AS II 10-3/4" 45.5# K-55 Surf 2463' 13-1/2" 1050 AS III & 250 sx AS II 7" 26.0# K-55 Surf 6962' 8-3/4" 620 sx Class G 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) 6712' -6718' 4spf 3-1/2" 6385' 6308' 6664'-6673' 4spf 6688' -6708' 4spf 26. ACID, FRACTURE, CEMENT sQuEEzE, ETC. ~ ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A r . .... 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift: etc.) Date of Test . Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I1~ I , Flow Tubing Casing Pressure CALCULATED OIL*BBL GAS-MCF WATER-BBL O1~ GRAVITY-APl (corr) Press. - 24-HO'UR RATE I~ . . 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEIVED . MAY 2 6 1982 .... A!ask~ 0it & Gas Cons. Commission /mch0rage Form 10-407 Submit in duplicate Rev. 74-80 GRUE/B25/26/27 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 6484' 6543' 6652' 6780' TRUE VERT. DEPTH 6180' 6236' 6340' 6462' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~----~-~ ~ ,, Title Senior Drlg Engr 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- iection, Gas I niection Shut-in, Other-exp!ain~ DS 1E-9 Drilling History NU Hydril & diverter. Spudded well ~ 2200 hfs, 03/26/82. Drld 13-1/2" hole to 2480'. Ran 60 its 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe ~ 2463'. Cmtd 10-3/4" csg w/1050 sx AS III & 250 sx AS II. ND Hydril & diverter. Set 10-3/4" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 3000 psi - ok. Tstd csg ~ 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new formation. Tstd formation to 423 psi - ok. Disp1 to polymer. Drld 8-3/4" hole to 7000'. Ran DIL/SR/GR/SFL & FDC/CNL/Cal. Ran 173 its, 7", 26#/ft, K-55, BTC csg w/shoe ~ 6962'. Cmtd 7" csg w/620 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Tstd csg to 2000 psi - ok. Arctic packed 7" x 10-3/4" annulus. Disp well to NaC1/NaBr. Tstd csg to 2000 psi - ok. 'Drld cmt to 6878' PBTD. Ran CBL/VDL/GR f/6878'-2000'; Ran Gyro/CCL f/6878' to surface. Perf'd 6712'-6718' & 6664'-6673' w/4 SRF. Perf'd 6688'-6708' w/4 spf. Ran 3-1/2" completion assembly w/tail ~ 6385' & pkr ~ 6308' Tstd tbg hanger & packoff to 3000 psi - ok. ND BORE. NU tree & tstd to 3000 psi - ok. Dropped ball & set pkr. Tstd tbg to 3500 psi & ann to 200 psi - ok. Disp tbg w/diesel. Closed SSSV. Secured well & released 6g 0200 hfs, 04/08/82. 3G:llm 05/14/82 GRUS/B28 MAY 2 5 J982 A~aska Oil & Gas Cons. Co~nm/ssior~ Anchorag9 ~1 E-9 KUPARUK :~ ~ APRIL 8~ 1982 (SEC 16 TllN RIOE) po ~ rri COMPUTATION DATE ' % BOSS GYROSCOPIC SURVEY JOB NUMBER BOSS-16999 KFLL'Y BUSHI'NG ELIEV. : 105.70 Fl". MEASURED 'VERTICAL VERT ICAL~. INCLINATION DIRECTION SEVERITY, RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH ~' DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 300 300.00 194.:30 0 12 N 5.29 W .lq .70 N .52 E .50 400 ~00,00 29A.30 0 33 N ~8.20 E .~6 1.20 N .86 E .88 ~nn ~9,~9 ~9~.P~ ,, O P3 N ~.e9 F .16 1.7~'N ~.~6 E ....!~ .......,,..,.... · 900 899,99 79~,29 0 9 S ~7,60 W ,12 1,99 N 2.16 ~ 1,23 1000 999,99 89~,29 0 6 'N ~,79 W ,23 1,99 N ~,05 E 1,25 11 88 ] 89~ .99 ' 99~.29 8. ~ S ~. 0 E .68 1,57 N ' 2.06 E · 1500 1~99.96 139fl.26 0 ~1 S 19.69 E .08 3.03 S 3.05 E -~.82 1600 1599.95 1~9~.25 0 ~7 S 15.19 ~ .~5 ~.26 S 3.07 E -5.00 1700 1699.94 159~.2~ 0 ~. S 13.39 ~ ~16 5~ ~ 2.76 ~ -6.05 2100 2099.93 1994.23 0 34 N 56.20 E .43 6.86 S 2.92 E -7.~3 2200 2199.90 2094.20 ] ~3 N 59,~0 E 1.16 5.82 S 4.64 E -6.97 2300 2299.8~ 219~.14 2 10 . N 67~ 9 E .51 ~.3! S 7.68 E 27O0 280~ 2699.18 2593.q8 3 2A N 32. 9 E 3.07 ,~6 N 25.18 E -8.60 2798,80 2693.10 6 q8 N 6,89 W 4,67 8,86 N 30.04 E -,89 2897.60 2791.90 10 50 N 17. 0 W ~.31 25.75' N 26,58 [ 1~.33 __ ~tl E-9 (SEC 16 TllN RIOE) COMPUTATION DATE BOSS GYROSCOPIC SURVEY KUPARUK APRIL 8~ 1982 JOB NUMBER BOSS-16999 A~ASKA .......... KELLY BUSHING ELEV. = 105.70 F~, : :~!~?::.:~%?~;:~!:i%:~:~i::~:~;?.~:.:~.i~:i:~:.;~:~:!:.:~:::~:S.~::~..~::.~:.::<~i~:.~i?.:~::.:~:i~......:~}~;:;.~:~:~:.::.!:.:...~.:~.......:~.::....:~?..:?..?.....:::S~.~::~. :,:$.~c.~:~.'.'.:~::.?/.:~ :::::::~::~S.~.~:?:~:~.~:~:ci::::x~:<:::~t.x;?:.'<~~;~/'.: :cL?:~;:;,:::<,:::!:!:~!~L!~.~ ::?:'~.:,~:.':~ t~:::tc.c~...::< :~.:~.:.:? ::::.:,~::::~ :%.::'/~:::?::~ cb>:~:'? ~.:~.~::~.:~:::~:~:.~.~:~.~:~:..F:~::~:~.~:~..~..~.~:~;~.i;~::~::~:~.:.~.~,~:.:,~;~:~:~;:~::.~.~`~..~..~.~:.~:~:~.~.~:~:.:.~:;~:~:~.,:~.:~:..~.~~:;':~':::~:~:'::~:'~'~::~':~:~':'':'''~'~'':'~''~':~:~''~:~:'~.' :::<,,;~:.~.;,.?u~,?:.. ~:::.<.t:/u~:.c.:~:>.!.?::. MEASURED VERTICAL VERTICAL INCLiNATiON DiRECTiON SEVERITY RECTANGULAR COORD[NATES VERTICAL DEPTH DEPTH DEPTH DEG H[N DEGREES DEG/]O0 NORTH/SOUTH ~ EAST/~EST SECT]ON $400 3369,72 326q,02 24 '0 N 22,20 W 1.69 3500 3q60.68 3354,98 25 'q' N 23,79 ta 1,25 I 3600 3551.15 3445.45 25 21 N 4000 3914.51 3808.81 4100 4005.76 3900,06 23 57 N 2'4,60 Ia ,41 171,71 N 37,40 Ia 174,85 209,93 N 53,64 Ia 216,22 248,84'N 71.00 W 258,59 · 401,08 N . 140.18 W q24'77 438,22 N 157.34 W 465,40 4200 ~097.23 3991.53 23. 42 N 25,39 W ,41 47~+,84 N 17q,zt2 W 505,51 ~600 ~465.97 ~360.27 21 3~ N 22.79 W 1.00 616.~2 N 237.36 W 659.63 ~700 ~559.17 ~53.~7 20. 55 N 2~.70 W .7~ 6~9.72 N 251.66 W 695.72 ~800 4652.60 ~546.90 20 52 N 22.10 W .57 682.57 N 265.5~ W 731,25 : ::C ':~:'::.i: :] ,:?~: ~]"~'.' '" "'"~ :"~'::';' :;:': "]' ]~' ;]:?/]] ':'~ 5200 5018,~0 ~912.70 26 ~7 N 20.20 W 1.37 8~,~0 N .522.56 ~ 892.35 5300 5107.13 5001,4~ 28 7 N 17,89 ~ 1,70 876,98 N ~37,58 W 9~8,42 5qO0 519q.61 5088,91 29 ~9 N 16.29 W 1,87 925.27 N ~51,81 W 986,8~ 5800 55~7.35 5q41,65 25 55 N 1~.2.9 U 1,03 1105,06 N ~01.09 U 117~.96 5900 5637,62 5531.92 25 2 N 15,79 VI 1,08 11~6,61 N ~12.26 ~J 1217.92 6000 5728.63 5622.93 23 5~ N 15.39 ~ 1,15 1186,52 N ~23.q0 ~ 1259,32 htl E-9 (SEC 16 TllN RiOE) KUPARUK MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COMPUTATION DATE BOSS GYROSCOPIC SURVEY APRIL 8~ 1982 JOB NUMBER BOSS'16999 ~__~~ ...... ' ....... KELL'¥ BUSHING ELEV, : 10S,7~ DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEGREES DEG/iO0 NORTH/SOUTH EAST/blEST SECTION 6500 6195.~+8 6089.78 18 52 6GO0 6290,4~+ 618~,7'~ 18 0 N 12,50 W 1,06 1560.26 N ~6~,08 W 1~7'11 N 12,20 W ,56 1390,89 N ~+70,78 bi 1q68.31 29 bi .85 : 1~+20.69 N 476.72 W 1~+ _ HORIZONTAL DISPLACEMENT= 1581,28 FEET AT NORTH~ 18 DEG, 2 )4INo. WEST AT M~ : 7000 ~1 [-9 (SEC .16 TllN RIOE) COMPUTATION DATE KUPARUK APRIL 8, 1982 dOB NUMBER BOSS-16999 ,AkASKA ......... KELLY BUSHING ELEV, : 105,70 FT, TRUE SUB-SEA TOTAL M[ASL~B[p y[RTICAL VERTICAL RECTANGULAR COORDINATE~ MD-TVD ~ERTIC~,L, .................... 1000 999,99 89~,29 1,99 N 2,05 E ,01 ,01 2000 1999,93 189~,23 7,3~ S 2,~7 [ ,07 ,06 3000 299~,93 2889,23 ~7 N 19~6~ ,[ , 5,07 ' 5,~0 7000 6675,7q 6568,0q 1503,~8 N' q89,90 W 326,26 5q,89 THE CALCULATION PROCE'DURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVt~TUR-- METHOD, t~l E-9 (SEC 16 T11N KUPARUK · RiOE) COMPUTATION DATE APRIL 8, 1982 dOB NUMBER BOSS-16999 _ ~..,.. _ ....... KELLY BUSHING FLEV, : 105,70 FT, TRUE SUB -SEA MFA.~I~RFn Vr R T T I":/i |~ V F ..~..,l...l.,.~.;...~..!.~ ............................ ~...~..~ 5 5.70 -100.00 105 105.70 0..00 n .'Tn nn.o n , 605 605.70 500.00 705 705.70 600.00 TOTAL TANGHLA O,OO .16 R COORIDTNATFS~ 0.00 N ,21 .TVD 0,00 ,00 0.00 .00 2.01 N 1,82· E ,01 ,00 2-1z! N 2,11 E ,01 .00 805 805.70' 700.00 . j.~l,~ N 2~6 E . ..... 1205 1205.70 1100.00 .3A N 2,19 E 1305 1305,70 1200,00 ,92 S 2,36 E ~1 E-9 (SEC 16 TllN RiOE) COMPUTATION DATE KUPARUK APRIL 8~ 1982 dOB NUMBER BOSS-16999 ....A.~.ASKA KELLY BUSHING ELEV, = 105,70 Fl', TRUE SUB-SEA TOTAL ,~4EASUR~D VERTICAL VERTICAL ~ECTANGULAR COORDI NA.TES 1905 1905.70 1800.00 7.12 S 2,2~' E .07 .00 2005 2005.70 1900'00 7.32 S 2,~'? E .07 ,00 2105 2105.70 2000.00 6.85 ~, ,~ 2~7 E t,..D. 7 ' .00 2506 2505.70 2~'00.00 3.17 S 18.13 E .~' ,17 2606 2605,70 2500,00 2,~+7 S 2z+,65 E ,65 ,22 2706 2705.,..70 26.,0,....0, t 00 . 3115 3105,70 3000,00 76,56 N 6,07 5 10,17 ~,68 3222 3205,70 3100,00 109,11 N 9,86 W 16,56 6,39 33:~0 3305,70 3200.00 1~5,9~ N 26.62 | '}:. ' !!i{~i'!!i!{~ii~iii~]{~{}i~il .:'.'..:...:c: ::.:.::<~:.::~!<.:}<:.:.::~:~'~'~::::'!~{~:.::~':':: ?<'~{:.<:<~/:.~<':??/:.::~.':~:~,:':~<:<~: ~':t'~:{::'%~'..':.:/.:i:!':~:{':~i{{ ~:.?~:~::~<:i~:~:.;..?:.::<~<.~>:::}`~:~<.~:??:~.:.:<?~:~?~ii!~! ~1 E-9 (SEC 16 TllN RIOE) KUPARUK ~ A~ ~. ..................................................................................... COMPUTATION DATE APRIL 8~ 1982 dOB NUMBER BOSS-16999 ........... KELL'Y BUSHING ELEV, : ~.0.5.,..7.~ .~, ..... TRUE SUB-SEA TOTAL .~r,o,R~n rn VFRTTCAI VFRTTCAI RFI:TANGIILAR cnnR D'[ ~dA,,Trs . : M:.I')..~ T:] r) ........ 3880 3805,70 3700,00 35~,21 N 119,65 U 7q,82 10,06 3990 3905,70 3800,00 397,~6 N 138,~9 ~ 8~,63 9,80 4N99 4Nn5.70 39flfl.nn 4~fl,]9.._N !57-33 ~ . 9~.23 ' ~{~1 ~555 ~05,70 ~00,00 59~,~9 N 227,99 ~ 129,~8 ~6~2 ~505,70 ~00,00 6~0,89 N 2~3,~5 W 1~7,02 ~749 4G~5, ?O. ~SO0,OO ............ ~ ~,~.~..~... ~ ,.. ~..~..~...~. ~..~... ~:~ .......................... ~.~..~..~..~.~ ............................................................. .~...~.,..~..~ 5185 5005,70 ~BO0,O0 827,38 N 320,3~ W 180,07 11,1~ 5298 5105,70 5000,00 876,25 N 337,35 W 192,67 12.60 . . 5~12 5205.70 51~0.g0 929.~ N 553.59 W 207.08 lq.~1 J~'~::~:,.:'~;/L'~.L~:L:~'~Li,:~.iL~-:L:L~?~S:~:~?:~i:L(<:~:~]<~<~;]?? ~~ ~S~:~:~S?:~:::~:g~S~S~S~:~?::~?:S~S~.~:~.:~?:~:~:?~.~<~:`~:::~S?.~:~:::~:~<~?~::<~:~~:~?~<]~]]~.~]~ ~]~:~L~]]~]~?~`~:~]~]~]~.~~]~]~~ <'<:'%L,2'~SiC?: :::,S'T.~:/,JS ~< ~::~'.?A:'h~,'::~ :~<'<<:::SSC,, ~<~',~: lcd-2/:~:::~'q<~':<,::':C:?X':?~qL:~<>q<{i?< :?. :~LLS<i-~XS<<::>:< S~'<:::2~ <'~::<:S'<L?S : ~1 E-9 (SEC 16 TllN RiOE) COMPUTATION DATE JOB NUMBER BOSS-16999 KELLY BUSHING ELEV, : 105.70 FTo · '~!!.~:~i.;i:::i~!:-,..'.7'!~i~'~!;:'::i!~.' !:7:::'i:!:" '~.'.'i:.!~!!:i!~.ii:~ ii::: :i;!;iti~::~:;!; i~::i? ~? :':.:~:.;~ :.:??; .i' :: .i'~'~. :' :.~i~.].~:~ i~ ~ '.-~ TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COOR[~INATES MD-. TVD VERTICAL 5974. 5705,70 5600,00 1176,72 N A. 20,70 W 269,22 10,16 6083 5805.70 5700.00 1218.75 N ~31,71 W 278,26 9.0~ 6191 590},,]~0 580(~., O0 !258.3~J ~40.93 U 286.20 ' 7.94 6616 6305.70 6200.00 1395.74, N 471,83 g .'310.35 5,27 6720 64,05,70 6300,00 1~26.85 N 4,77.84, W 315,25 A.,90 . 6t]25 6505.70~ 6400.00 1~+56.37 N ~,82o92 W 319.6~, I THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS (SEC 1G T11N RIOE) ~'," , '~, "..~i/~: , "'"' ~ i,,,~ ~' '~,.'i ~ . ;'i .~7,' ,~ ,~'. "~","~' '~,"~;,i~i~;,,!i,~i-; "!~ '~i~:i ': ,!i~i!ii~il;i ii,~ii" i', ~'i, . COMPUTATION DATE KUPARUK APRIL 8e lc)82 dOB NUMBER BOSS-1£9C)9 TRUE NF4~IIRF~ VFRTT~AI 65~3 6236.25 6652 6339.90 SUB-SEA TOTAL R F C T ~, N I !,.!..!.!::.~..R,.· ................ ~.D..O..,,R,..D...T...~,~.,T,...[..~ VFRTTCAI 6130.55 1373.62 N ~67,0~ ~ BAS~ UPPER SAND 623~.20 1~06.58 N &7~'16 B TOP LO~ER SAND © ii/i:..i~:i::~ ;:i'?:.:!~'i.! :i:: .:::::i.:i:i.i~; :..5: i' ...::' L ~L:. :i.i~: i:': ;'7: :..: i:= .:"' ": :::~;.i~ F~',i ::~: "' !~:':' :7i.:': ";:' ":' i~: :. 5:?./::, ':;~i:>. ~,.:. ~:i: ?: i':: T:'/: ~:.::i;~ :~::~ ;:' i:!:~i:~ii:L?i:¢~:::i !::i!i~i~:!!:i;ii!~. :iiii:~i!~:iiii~:iii:iii:~i~i~!~:ii:ii~i:ili!iii.lii~!}i~ii:~!i;i:i STRATIGRAPHIC SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA SEC 16 T11N RIOE DATA CALCULATION AND INTERPOLATION BY RADIUS OF CURVATURE mmmmmm mm ~ m ~mm~mmmmmmmmmmmmmm m~ m ~mmm~ m 4m m m ~m~ m m m m m m mm m m mmm m mm m m m ~mmm m m m m m m m m m m m m m ~m~ KELLY BUSHING ELEV. : 105.70 FT. ARCO Alaska, Inc. Our Boss GYroscopic Survey Job No. Boss-16999 Well: ~1 E-9 (SECl6 TllN R10E) Kuparuk Field North Slope, Alaska' Survey Date: April 6, 1982 Operator: Tom McGuire Scale: 1" = 500' ¢.. 7000 · ~ · TRUE NORTH ~L -1 sO0. OO -1000. OO -500. QO Surface Location ~..1.16~.3NSL 809WEL) l_500.00 -sob, oo_ HORIZONTRL PROJECTION ARCO Alaska, Inc. Our .~Boss Gyroscopic survey Job No. Boss-16999 Well: #1 E-9 (S~C16 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: April 6, 1982 Operator: Tom McGuire Scale: 1''' = 1500' O. O0 1500,00 8000.00 4500.00 6000.00 7500.00 N18° 02'W ~ 7000 15~0.00 30bO. O0 VERTICRL PROJECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator; ~e~l Na~e ah~ Number Reports and Materials to be received by: ~-'- (~ Date : Required Date Received Remarks Completion Report Yes Well History Yes _Samples . / Mud Lo9 · Core Chips ~. ' ,, ///,~/,¢ ~ ---- C~/~- ' Core DescriptiOn __ Registered SurVey Plat 7 ~<~ . InclinatiOn. Survey ./~}' ~.,-"~'A"?', ',, Directional Survey x~ ~p{ , Drill Stem Test Reports ~s "~--- Y es KUPARUK ENGINEERING TO: TRANSMITTAL # ~ ~//~ /~/~ FROM: D. W. Bose/Ann Simonsen DATE WELL NAME Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T~ TAPE PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ~,n~oO. oo~, ' ANCHORAGE , .' AK 9 9 510 Apr il 30, 1982 Mr...C.V. Chatterton State of Alaska Alaska Oil & G-as Conservation Commission 3001 Porcupine Drive 9 Anchorage, Alaska Subject: State Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following drill sites: 11-6 11-7 14-29 15-2 1A-15 (Revised) Also enclosed are monthly reports For March on these drill sites: 2-19 15-4 2-20 Ei[een #1 13-17 West Sak 24 13-23A 1A-16A (Sidetrack) 14-9B It-9 14-28 Oliktok Pt. #1 14-30 West Sak 25 15-3 We ar.e also including plug and abandonment subsequent sundry reports on Eileen #1 and 1A-16. The reports on Eileen #1, Oliktok Pt. t/1, and the two West Sak Wells are of a confidential nature. We would appreciate it if you could store information concerning these wells in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:pb enc. GRU4/84 ~'-~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-28 3. Address ; 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20720 9. Unit or Lease Name Kuparuk River Field 4. Location of Well at surface 809' FEL, 1163' FSL, Sec. 16, T11N, RiOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 105.7' RKB ) ADL 25651, ALK 469 10. Well No. 1E-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. Marc h ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2200 hfs, 03/26/82. Drld 13-1/2" hole to 2480'; ran & cmtd 10-3/4" csg. Drld 8-3/4" hole to 3438' as of 03/31/82. See Drilling History. 13. Casing or liner run and quantities of cement, results of p~essur9 tests 16", 62.5 #/ft, H-40 conductor set @ 78'. Cmtd w/250 sx AS II. 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe @ 2463'. Cmtd w/1050 sx AS III & 250 sx AS II. See 'Drilling History 14. Coring resume and brief description N/A. 15· Logs run and depth where run None to date. 6. DST data, perforating data, shows of H2S, miscellaneous data N/A. APR ) 0 J982 0il & Gas Cons. Commission Ar~chora~-e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE Senior Drilling Engineer DATE NOTE--Report on this 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. DS 1E-9 Drilling History Nu Hydril & diverter. Spudded well ~ 2200 hfs, 03/26/82. Drld 13-1/2" hole to 2480'. Ran 60 jts 10-3/~", 45.5 #/ft, K-55, BTC csg w/shoe ~ 2463'. Cmtd 10-3/4" csg w/1050 sx AS III & 250 sx AS Il. ND Hydril & diverter. Set 10-3/~" paekoff & tstd to 2000 psi - ok. NU BORE & tstd to 3000 psi - ok. Tstd esg ~ 1500 psi - ok. Drld FC &emt. Drld FS & 10' new formation. Tstd formation to 423 psi - ok. Displ to polymer. Drld 8-3/4" hole to 3438' as of 03/31/82. 3G:hrl 0b,/17/82 GRU3/B19 APR o Oil & Gas Cons. Commission KUPARUK ENGINEERING TRANSMITTAL D. W. Bose/Ann Simonsen WELL NAME: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVED ...~- Oil & Gas Cons. Co~ ~~s~ ~~ ~c~ ~o: ~co ~s~, ~c. ~hor~o P. O. ~OX 360 ~H~O~G~ ~ ~ 99510 MEMORA' DUM state of Alaska DATE': FILE NO: TELEPHONE NO: SUBJECT: April 29, 1982 Subject: Witness _ BOPE test on Sohio% E-12 Well, Sec 6. Tll~ ~14~ UP~, ~r~t_ ~. - 82~6, on grl~erhoff ~g ~. 1 ThOr .~sday, A. pril 2.2~_ 19.82: A~ter vitnessins the tagging of the 9 5/8" cement plug on A~C°ts W. ink 25 yell, I traveled to Brt_nkerhoff Rig 1 to vitness the BOPE test. The BOPE test commenced at 1:00 p.m. and was concluded at 9:00 p,m, ~aile pressuring up on the blind rams I found a hydraulic leak at the lower pipe rams door hinge pin. The hin~ pin seals ~ere replaced and the test resumed. This repair ~rk caused the lonEer t,han average test time. I filled out an A.O.G.,C.C. BOPE test-report which is attached. In summary I vitnessed the BOPE test on $ohio~s E-i2 yell. ~The longer than average test time was a result of the. repairs to the lo, ar rams doer hinge pin seals.. I filled out an A.O.G.C*C..BOP~ test report ~hich is attached. O&G #4 4/80 STATE OF' ALASKA ALASKA OIL & GAS CO~,iJi;~¥ATION COHMISSION B.O.P.E. ~nspe¢.t'ion Report Date Inspector Opera~tor Well Location: Sec %/~:~ ,Ttl Drilling Contractor Representative ~-~V'C'~J {_c~-e~q'7__e_.~ 1 Permit # ~-~ Rig # I . Representative- ~_'~.. ~!~.~' Location', General ~).k-~ ACCUMULATOR SYSTEM Well Sign O.k-. Full Charge Pressure ~)oO psig General Housekeeping , d)~ Pressure After Closure ~00 pszg Reserve pit ~ 200 psig Above Precharge Attained: min~ Rig ~ Full Charge Pressure Attained: ~ minO~ sec Controls: Master O~ Remote O~ Blinds switch cover Test Pressmre KellZ and Floor Safety Valves '~,OOO Upper Kelly ~J Test Pressure ~).0OO Lower Kelly~ ~ Test Pressure ~' Ball Type ~ ~ Test Pressure ~ Inside BOP ' ] Test Pres sure ~; t~ Choke Manifold ~ ~Test Pressure ~ NO. Valves ~ {I NO. flanges ~7 Adjustable Chokes ~ Hydrauically operated ch6ke ~ t./' .... ~----.::: _ : ....................................... Test Results: Failures I. Test Time ~ hrs. Repair or Replacement of failed equipment to be made within days and ~ ~~ Ins~ctor/Com~ssion office notified. I I ..... J ' ' .... ~ ''' - "- , BOPE Stack Annular Preventer Pipe Rams u~ Blind Rams ~' Choke Line Valves w/ .~, , H.C.R. Valve '/ } Kill Line Valves W/u/~ . Check Valve Distribution orig.-- AO&GCC cc - Operator cc - Supervisor Inspector . __ _ ALASKA OIL AND GAS CONSERVATION COMMISSION ' Thru~ Apr il 9, 19 82 108/D Witness BOPE Test on ARCO ~ s Kuparuk 1E-9 Wel 1 Sec. 16, T11N, R10E, U.M. Permit No. 82-28 on Rowan Rig No. 34 NOh~aV~.~a~chh~9_&~9.8_2- I traveled this date from Brinkerhoff .~aig No..~ tO Kowan Krug NO. -34 tO witness the BOPE test. The t. est com~nce~ at 6~0 p.m. and was concluded at 3~00 a.m. The longer than average test time was due to two ruptured bladders in the accumulator system. These bladders were replaced and the accumulator reteste~ successfully. I fille~ out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test on ARCO~s Kuparuk XE-9 well on Rowan Rig No.' 34. The longer than average test time was a result of two defective accumulator bottle bladders. The bladders were replaced and the accumulator retested successfully. I fill~ out an A.O.G..C.C. BOFE test report which is attached. O&G 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COHMISSION B.O.P.E. Inspection Report Inspector OOEM ~ ~'~/~.~ ......... ?_el__l_~Z _~__ .--_ ._~. _ Operator . ,/~, _r~'~3 Representative Well ~p ,/~'~ Permit ~ Location: Sec /¢ ~/~R/[3~ M ~/~ ./~&sing Set Drilling Contractorg~~ Rig ~ *¢ Representative. Location, General Well Sign.. General Housekeeping Reserve pit . Rig i.':, ~ .'.':: -;::,-'::< · i:5:~-':': .:.>'::';. BopE Stack :..' :;.>-'. Annul~.~., ..pr eve nt e r ~/ ~. ~ / Pipe. Rams .-" -::- -." Blind R~s.~ H.C.R. Valve Kil~ Line Valves Check Valve Test Results: Failures Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure .~Od)O Pressure After Closure. .... //Od) . 200 psig Above Precharge Attained: min_~_~ sec Full Charge Presgure Attained: ¢ mill ~/.sec Controls: Master ~ :, Rem~_te. ~ Blinds switch Cover ~ Kelly and Floor Safety Valves Upper Kelly / /~Test Pressure ~, Oa(3 Lower Kelly / ~est Pressure Ball Type / Test Pressure Inside BOP _/____Test Pressure Choke Manifold ' Test Pressure No. Valves ./¢- Adjustable Chokes / Hydrauically operated choke / Test Time /? Repair or Replacement of failed equipment to be made within.. . days and Inspector/Commission office notified. , / . orig,' - AO&~C cc - Operator cc - Supervisor Inspector t// //// /// ARCO Alaska, Inc. ~"~, Post Office B,._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 19, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Kuparuk 1E-9 Dear Sir- Enclosed please find the following' . . 5, . The application for Permit to Drill Kuparuk 1E-9 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projec- tion of the wellbore. An as-built drawing of "E" pad indicating the proposed surface location. A proximity map indicating the relative location of Kuparuk well 1E-8. A determination of maximum pressure, to which BOP equipment could be subjected. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. If you should have any questions, please do not hesitate to contact me at 263-4970. Sincerely yours, win Sr. Drilling Engineer JBK'AAC'ltc Enclosures FEB 2 0il & Gas Cons. Commission /'~chorag~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieidCompany March 2, 1982 ~Ir. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O, Box 360 Anchorage, Alaska 99515 Re: Kuparuk River Field 1E-9 ARCO Alaska, Inc. Permit No. 82-28 Sur. Loc. 809'FEL, l163'FSL, Sec 15, TIlN, R10E, U~i. Bottomhole Loc: 1429'FEL, 2954'FSL, Sec Dear Mr. Kewinz Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~ifany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 18.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to co~r~encing operations you_ may be contacted by the Habitat C~ordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~a. ter Pollution Control Act, as amended. Prior to eomr~encing operations you may be contacted by a representative of the Department of ~nvironmental Conservation. ~ir. Jeffrey B. E in Euparuk River Field iB-9 M~rch 2, 1982 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would al so like to be notified so that a representative of the Commission.may be present to witness testing of blowout preventer equilmuent before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairn~an of BY ORDER OF THE CO~,~,~ .... Alaska Oil and Gas Conservation Con~s~ sure cc'~ Department of Fish & Game, Babitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC ~ be ~"~ STATE OF ALASKA ~ ALASKA",~,L AND GAS CONSERVATION CC.,,'MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL {~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Znc. 3. Address P 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 809'FEL, l163'FSL, Sec. 16, TllN, RiOE UM At top of propo?~r-/j~'b-'~ing interval 1296'FELAttotaldept~' ~'72'~SL' Sec. 16, TllN, R10E, UM 1429'FEL~,~2954~SL, Sec. 16, TllN, RIOE, UM 5. Elevation in feet, i~(j_D~ficate KB, DF etc.) I 6. Lease designation and serial no. 66.7 GL, 71.7 PD, 105.7 RKBI ADL25651 · ALK 469 , ~Umt or lease name Kuparuk River Field ~)10. Well number 1E-9 1., Field and pool ...... ~'Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/Or numbeFecl, o Ins Co. #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 miles NW Deadhorse miles 16. Proposed depth (MD & TVD) 7394' MD 6977'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT feet. feet 14. Distance to nearest property or lease line AT TD 2326' feet 17. Number of acres in lease 2560 MAXIMUM HOLE ANGLE 20. Anticipated pressures o (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 1E-8yen @ 18. Approximate spud date 3/22/82 2'644 ' psig@ bU F surface 3155 _psig@-6136', ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole I Casing Weight Grade / C°Upli g Length MD TOP TVD MD BOTTOM TVD (include stage data) _2_4'~. 116" 65# ~-40 ~elde~ 80' Pad I Pad 115" 1115' t ' ~ Pad1500' ~500' ~3-I/2"i0-3/4 '45.5¢f 1~-55 TC _~465 Pad ~ 8-3/4" 7" 26# ~-55 TC 7359' Pad , Pad '394' 6977' .173sx of Class" I I ~ I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River 0il Pool devel- opment well to approximately 7394'MD, 6977'TVD. Selected intervals will be logged. 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. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2644 pSig based on cooling of a gas bubble rising at constant volume, The well will be completed with 3-1/2" 9.2#:' J-55 buttress tubing. Non-freezing fluids will be left in uncemented annuli thru the permafrost interval. Selected 'intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. ~200CF L O5Osx AS III + 250sx S II 23. I hereby certify that the foregoing is true and correct to the best of my knowledge S,GNED T,TLE Sr. Drilling En ~E ,~J~q;~ 2/255/82 The space be/~v~ f¢1¢ C~om/iss~on usef CONDITIONS OF APPROVAL Samples required Mud log required []YES ~]..N O []YES Permit number Approval date /- Form 10q01 Rev. 7-1-80 Directional Survey required . / ~PI numhc, r SEE COVER LETTER FOR OTHER REQUIREMENTS · ,COMMISSIONER by order of the Commission DATE Submi't in triplicate - 1 ?-fi---t- . .~ T1~=6666 TliD=6994~ DE .wELL ~8 Y :- . -_ c I,rELL ~7 1.tELL ~ . · -. o - - o 1,1ELL ~ VELL ~3 '- Y X L~T LOtqG '~ELL ~5 Y =' - - X -=' ' .5q9':' ~89.039 -- L~T = ZO°lS~OT..7~q'' LO~G = I &~g°35s'~5..278'' .....-- .. -. -. ::: X = 5q3,lE89.818 - LRT ' 70°18~O.E~.SG]" LOnG = . = 5~,~89.5o~ = 7oo18~i~5o38G,, . -. : - :. " '"' T T Lt...:. THE STATE OF A~S~ AND HA -'~;"' :x~' ' ' ' --:~ ~ .:' '~ ................ -.---~ ~..- ,.~ --~ . -~.. ..... ~;~E;~-y~.?.-;-~ .- ....., THAT ALL.Dlfl~NSIONS AND OTHER . : DETAILS ARE CORRECT, AS OF: '--'"-DATE :7 . .- - ' ..... . ' - - '.-- . - ' - ' - : =- ' ' ' --'.. -- -- ' ..... '' - D-~'. ~ WELL5 }.--~ LOo^TIoN,c-; A~-'F~,.,L.tILT~ ..... j aA',V -' 'AtlanticRichfiel. dCompany ~ IDAT~:I ALASKA DISTRICT-- ,. __1KUPARUK ' I II I iii · · ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3155 psig from RFT & pressure buildup data. This pressure E) 6030'SS = 6136'TVD will be balanced by 9.89 ppg mud wt. Normal drilling practice calls for 10.4 ppg wt. prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 163 psi over-balance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2644 psi during drilling oeprations. Derivation assumes a gas kick at reservoir temperature and pressure {160°F, 3155 psi), gas migration to the surface w/o expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial {reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final {surface) Pivi = PfVf l~i Tf · since vi : Vf'i.e. no expansion .. Pi': Pf Then Pf = PiTf = (3170 psia) (60°F + 460) T~ Tf Ti~ (160°F + 460) Pf 2659 psia = 2644 psig Surface Dive,_ir System _ -® 1. 16" Bradenhead. 2. 16" x-20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. diverter line. Do not. shut in well under any circumstanc'es." 16" Conductor Q. , Maintenance & Operation ( 1. Upon initial installation close annular J preventer and verify that ball valves ) _ have opened properly. ' . i 2., Close annular preventer and blow air ~_.~ · through diver't~r lines every 12 hours. 3. Close annular preventer in the event that gas or flui(i flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind -<, J ' ! , RNNULRR PREVENT OR ) ( 13-5/8" 5000 PSI RSRRA BOP STACK BLIND RRHS 8 PIPE RRHS ) 7 DRILLING SPOOL -.o · 2. 3. 4. Se e . o . . PIPE RRHS 5 . -. .o 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" .5000 PSI drilling spool w/choke and ki 11. 1 i nes 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular . · .. ACCU~,IULATOR CAPACITY TEST . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL Will4 HYDRAULIC FLUID. ASSURE THAT-ACCL~.IULATOR PRESSURE ES 3000 PSI · WITH 1500 PSI DOWNSTRE~4 OF THE REGULATOR. OBSERVE TIME THEN CLOSE ALL UNITS SII4ULTANE- OUSLY AJ4D RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED W'Illi CHARGING PUMP OFF. RECORD ON IADC REPORT. THE ACCEPTABL~ L~4ER LIMIT IS 4S SECONDS CLOSING TIME ~ 1200 PSI REMAINING PRESSURE. - 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITi4 ARCTIC DIESEL. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELl. HEAD. i~ IN LOCK DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKE~ J&llD BYPASS VALVES ON MANIFOLD. TEST ALL CO(.IPONENTS TO 250 PSI AND HOI. D FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND' HI)LO FOR lO MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE ll)P SET OF . PIPE RAMS. INCREASE PRESSURE TO 3000. PSI AND )lOLl) FOR 10 MI~rdTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DCT~NSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINIJiG UNTESTED I~IFOLO VALVES, IF ANY, WITH ~000 PSI UP'SI~ OF ' VALVE AND ZERO PSI D(T&NSTREAM.. BLEEO SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS AND CLOSE SET OF PIPE RAMS. ' INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 ltINUTES. BLEED TO ZERO PSI. OPEN BOTTOm4 SET OF PIPE RAMS. BAOC OFF RUN- NING ,,)OINT AND PULL OUT OF HOLE. CI. OSE BLINO RAMS AND TEST TO 3000 PSI FOR 10 HIRUTES. ' BLEED TO ZERO PSI. . OPEN BLIIID RAILS AiiO RECOVER TEST PLUG.. HAKE SURE HA~IIFOLO ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN IiP~ILLIt~G"' . POSITION. TEST STANDPIPE VALVES TO 3000 PSE. · TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI -. 14ITN KOO~EY PUMP. ,. RECORD TEST INFORMATION ON BLOWOUT ?REVENTER . TEST F'OR)'! SIGN ATID SEltO TO DRILLI~4G SUPER- VISOR. ' ' PERFORI-I COI1PLETE BOPE TEST OltCE R UEEK A:ID FUNCTIONALLY OPERATE BOPE DAILY. ' CHECK LIST EOR NEW WELL PERMITS ITeM APPROVE DATE (1) Fee ~-z~--~vZ_~__ ~[ ~, &~-~ (2-) Loc/ ~~~ L-Z~-6~ " .~thru 8) ' (3) Admin ~(~ ~hru 11) · · 3. 4. 5. 6. 7o 8. e 10. 11. (4) Casg ~l~ thru 2'0) 13,. 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~2~ 2---A6'~~'' 21. ~'2'1 thru 24) 22. 23. 24. (6) Add: Company Lease & Well No. YES NO Is the permit fee attached ...................... · .................... Is well to be located in a defined pool, Is well located proper distance' from from other propertY wellsi~"gg'[[[[[['''''''''''"~'~'~ Is well located proper distance Is sufficient .undediCated acreage available in this poOl Is well to be deviated and is well bore plat included ............... Is operator the only affected party .... Can permit be approved before' ten-day'~il. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is ad inistrative approval needed m ·eeeee eeeee·eeeeeeee·eeeeeeeee·ee·e Is conductor string provided ....................... ................ Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizon's ......... Will surface casing protect fresh water zones .....,... Will all casing give adequate safety in collapse, ;g~i;~ and'g~ Is this well to be kicked off from an existing wellbore ....... .--- Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... Is a d±verter system required Are necessary diagrams of diverter and BOP equipment attached . Does BOPE have sufficient pressure rating.- Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. · Additional requirement S · e e e i · e e e e I e e e · e · e e · · · · · · · · · · · · e e · · · · e · · · · · · · REMARKS Additional Remarks: 0 Geology: Engining: WVA JKT~AD / rev: 01/13/82 INITIAL GEO. 'UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ ,. No 'special'effort has been made to chronologically organize this category of information. ' .o r~: : I<UP AU!< ....... .... 00~'0 ..... 0'00 '008: 065 ............. ..... RANG 210E COMPANY FIELD = KUPARUK STATE = ALASKA DATA DEPT RH~ SP 8P RHOB RHOB 0~0 CA:b:! -99.9 - 2500 C A'b I 2,2559 ILD 999,2500 D R H 0 ..9'99 ' 250'0 CALI 2500 DRHO 99,2500 CALI 1,7822 -99~:: 340~8 67,1'9 2,2070 , -99~, 99~' 4434 - ,2500 9,4219 SP R m~ RHOB DEPT RHOB - DEPT 4 RHOB '~ ;P R DEPT GR DEPT HOB R DEPT HOB GR DEPT ,. 4200,0000 SFLU 2 '49,50OO ,GR::: '999,2500 NCNL - 999 · I. 04,5374. ~ ' RN R ;% "999 99g, -999.2:50.~0 CAb I 2,9824 )3: ~74 N~M.I: ' 2:50-0: :DRHO SO0 F'CNL '999 ' 2'500 CALX /:25.0 0 4100.49.4688.0000 ' SFLUGR 9],204!,2930 I.b~NpH! -9993':1348 !IbD, 250.0 DRHO '999,2'500 NCNb :999,12500 FCNL .-99:9,:~5:00 CAbX 92,2041 RNRA ' 999;2500 40.00.0000 SFLU 2,7988 Ib~ 5~.2813 GR.: 75.0999 ,2813 NCNb 226'8,0000 FCN ?S.0999 RNRA .3.7764 2'227 I LD 3900.0000 SFLU 2.7598 IbM 2,9102 IbD 6'i;7'2 3, , .9~ !'0 6172 3~ 539t 3,0762 SP SP ., SP SP '81'2500 GR 76,i098 R"OB 2'3008' NCNb ~-~-198~'~QQ0 DBPT ]000 RHOB GR 65 0000 SFLU 6640 RNRA .0000 FCNL · 4, .00 30 DEPT SP RG HOB R 29.0.0 0000 SFbU 8. 218.7. lbfl 74:2500 GR 75; 7'643 'NPHI 7~,2207 NCNb 1865,0000 FCNL ,7643 RNRA 4;2184 11,04'69 II~D ,~43,~2023, DRHO: 504 ;7500 CALl 451 0 CAbl 2656 · 8359 4.06 .) ~EPT SP - )EP" DEPT TAPE TRAILER COMMENT~ ITRPE' COMMENT~ ** REEL TRAILER ** BERVI~E NAME =$ERVlC DATE :'83/O2/18 ORIGIN : REEL NAME :REEb ID CONTINUA ION # .O!
