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183-005
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop _1E-17 50-029-20793-00 182116_1E-17_IPROF_16Jan2023 _1E-20 50-029-20895-00 183005_1E-20_LDL_10Jan2023 183005_1E- 20_PlugSettingRecord_20Aug2023 183005_1E-20_PPROF_29Sep2022 183008_1E-20_RBP_25Feb2023 1F-06 50-029-20820-00 182145_1F-06_Perf_11Jul2022 182145_1F-06_TubingCut_20Feb2022 1G-09 50-029-21001-00 183124_1G-09_IPROF_01Jun2022 1G-103 50-029-20824-00 219110_1G-103_RSTWFL_09Nov2022 1G-11 50-029-21008-00 183131_1G-11_LDL_31May2022 1G-13 50-029-21016-00 183140_1G-13_LDL_09Jul2022 1H-102 50-029-23580-00 217097_1H-102_PPROF_02May2022 1H-103 50-029-23593-00 218003_1H-103_PPROF_06May2022 1H-109 50-029-23595-00 218013_1H-119_IPROF_02JUL2023 3of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38329 T38330 T38331 T38332 T38333 T38334 T38335 T38336 T38337 T38338 2/29/2024 _1E-20 50-029-20895-00 183005_1E-20_LDL_10Jan2023 183005_1E- 20_PlugSettingRecord_20Aug2023 183005_1E-20_PPROF_29Sep2022 183008_1E-20_RBP_25Feb2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:29:27 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1E-20 JBR 10/16/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test Test Results TEST DATA Rig Rep:Al HansenOperator:ConocoPhillips Alaska, Inc.Operator Rep:Dale Rowell Rig Owner/Rig No.:Nordic 3 PTD#:1830050 DATE:8/24/2023 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopRCN230825095311 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2241 Sundry No: 323-225 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8" x 5 1/2 P #2 Rams 1 Blinds P #3 Rams 1 7"P #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 none NA BOP Misc 2 2 1/16"P System Pressure P3050 Pressure After Closure P1700 200 PSI Attained P24 Full Pressure Attained P128 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @1937 ACC Misc NA P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P19 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8650'feet N/A feet true vertical 6756' feet 7977', 7979'feet Effective Depth measured 7948'feet 8130', 7778', 7662'feet true vertical 6212' feet 6353', 6081', 5990'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 J-55 7746' 7807' 6057' 6103' Packers and SSSV (type, measured and true vertical depth)7662' 7778' 8130' N/A 5990' 6081' 6353' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Contact Phone: 2380' 2172' Burst Collapse Tie-Back Production 1672' Casing 1646'1703' 8622' 6734' 2347' 110'Conductor Surface 16" 10-3/4" 76' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-005 50-029-20895-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025651 Kuparuk River Field/ Kuparuk Oil Pool KRU 1E-20 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 332 Gas-Mcf MD 700 Size 110' 720 1884678 0 6500 1286 323-479 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Blue Packer RH Max Baker HB Retrievable Baker FB-1 SSSV: N/A 7945-8094', 8349-8362', 8382-8410' 6210-6325', 6522-6532', 6547-6569' 8591' 7" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Shane Germann shane.germann@conocophillips.com (907) 263-4597 Authorized Name and Digital Signature with Date: Authorized Title: CTD Engineer ddd By Grace Christianson at 1:22 pm, Sep 26, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN= Shane Germann, E=shane.germann@ conocophillips.com Reason: I have reviewed this document Location: Date: 2023.09.25 14:38:41-08'00' Foxit PDF Editor Version: 12.1.2 Page 1/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/11/2023 05:00 8/11/2023 07:30 2.5 0 MIRU, MOVE MIRU MOB P Rig Release from 2T-203 @ 05:00. Prep rig to back off well. Place mats and build dance floor around rig for room to back off and turn. 8/11/2023 07:30 8/11/2023 10:45 3.2 5 MIRU, MOVE MIRU MOB P Back rig off 2T-203. Clean up around cellar and pad. Pad Op onsite to witness and sign Environmental Form. Vac Truck unloaded last fluid returns from tanks. Begin rig move from 2T to 2A. 8/11/2023 10:45 8/12/2023 00:00 13. 25 MIRU, MOVE MIRU MOB P Arrive at 2A. KDTH pull mats F/ 2T. Laying mats F/ 2A T/ 4 corners. Laying mats and rolled road in designated areas on spine T/ 2B. Rig performed maintenance. Replaced tugger line and install dutch riser lock-down flange. 8/12/2023 00:00 8/12/2023 02:00 2.0 0 MIRU, MOVE MIRU MOB P Continue prepping road to 2B with rig mats and rolled road in designated areas. 8/12/2023 02:00 8/12/2023 05:00 3.0 0 MIRU, MOVE MIRU MOB P Move sub from 2A to 2B. 8/12/2023 05:00 8/12/2023 19:00 14. 00 MIRU, MOVE MIRU MOB P Perform rig mat shuffle from 2A around rig to CPF-2. Begin rig move from 2B to CPF -2. Found soft spot in road before getting back up on mats. Laid mats for rig to back up onto. Inspected road from 2B to CPF-2. Wait on portable road at low spots to be laid down. Test Rig Gas Alarms. 8/12/2023 19:00 8/12/2023 20:00 1.0 0 MIRU, MOVE MIRU MOB P Continue rig move from 2B to CPF-2. 8/12/2023 20:00 8/12/2023 22:30 2.5 0 MIRU, MOVE MIRU MOB T Fell through road after coming off of rolled road on spine before CPF2. Crib under tires. Drive out of hole. Pull up onto mats. 8/12/2023 22:30 8/13/2023 00:00 1.5 0 MIRU, MOVE MIRU MOB P KDTH laying mats and rolled road in designated areas on spine to CPF2. 8/13/2023 00:00 8/13/2023 00:30 0.5 0 MIRU, MOVE MIRU MOB P KDTH continue laying mats and rolled road in designated areas on spine to CPF2. 8/13/2023 00:30 8/13/2023 02:00 1.5 0 MIRU, MOVE MIRU MOB P Move rig and stage at CPF 2. Finished installation of Dutch Riser lock-down flange. 8/13/2023 02:00 8/13/2023 10:00 8.0 0 MIRU, MOVE MIRU MOB P Perform rig mat shuffle from 2B around rig at CPF-2. KDTH laying mats and rolled road in designated areas to C pit on 1E access road. 8/13/2023 10:00 8/13/2023 13:30 3.5 0 MIRU, MOVE MIRU MOB P Move rig from CPF-2 to 2Z. Let traffic pass rig. Cont. to lay rig mats from the Y to 1E. Inspect saver sub and check top drive functions. 8/13/2023 13:30 8/13/2023 16:30 3.0 0 MIRU, MOVE MIRU MOB P Cont. rig move from 2Z to 1R access road. Stage rig and mat access road out to 1E pad. 8/13/2023 16:30 8/13/2023 19:00 2.5 0 MIRU, MOVE MIRU MOB P Perform rig mat shuffle from 2Z around rig. KDTH laying mats and rolled road in designated areas to C pit on 1E access road. Allow field crew change. Painting on rig floor. 8/13/2023 19:00 8/13/2023 22:00 3.0 0 MIRU, MOVE MIRU MOB P Move rig from 1R to C pit on 1E access road. Stage rig and mat access road out to 1E pad. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 2/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/13/2023 22:00 8/14/2023 00:00 2.0 0 MIRU, MOVE MIRU MOB P Perform rig mat shuffle from 1R around rig. KDTH laying mats from C pit to 1E. Painting on rig floor. 8/14/2023 00:00 8/15/2023 00:00 24. 00 MIRU, MOVE MIRU MOB P Perform rig mat shuffle from 1R around rig. KDTH laying mats from C pit to 1E. Set mats around well. Stage well head equipment. 8/15/2023 00:00 8/15/2023 04:00 4.0 0 MIRU, MOVE MIRU MOB P Move rig from C-Pit staging area to 1E Pad. 8/15/2023 04:00 8/15/2023 05:00 1.0 0 MIRU, MOVE MIRU MOB P Hang tree in cellar. Verify well head equipment is staged behind well. 8/15/2023 05:00 8/15/2023 06:00 1.0 0 MIRU, MOVE MIRU MOB P Spot sub over well 1E-20. 8/15/2023 06:00 8/15/2023 09:00 3.0 0 MIRU, MOVE MIRU MOB P R/U cuttings tank, tiger tank and hard line. Complete rig acceptance checklist. Rig accepted @ 09:00 Hrs. 8/15/2023 09:00 8/15/2023 11:30 2.5 0 MIRU, WELCTL MIRU RURD P R/U open top tank. Take on 9.4 PPG NaCl into pits. R/U circ manifold in cellar. 8/15/2023 11:30 8/15/2023 12:30 1.0 0 MIRU, WELCTL MIRU COND P Build 40 Bbls deep clean pill. 8/15/2023 12:30 8/15/2023 12:45 0.2 5 MIRU, WELCTL MIRU SFTY P PJSM on PT tiger tank lines. 8/15/2023 12:45 8/15/2023 13:00 0.2 5 MIRU, WELCTL MIRU PRTS P PT circ manifold & tiger tank lines T/ 2500 PSI. 8/15/2023 13:00 8/15/2023 13:30 0.5 0 MIRU, WELCTL MIRU SFTY P PJSM on well kill 8/15/2023 13:30 8/15/2023 16:00 2.5 0 MIRU, WELCTL MIRU KLWL P Take initial pressures T/I/O 770/770/15. Bleed free gas off of IA & tubing. Pump 40 Bbls deep clean pill followed by 473 Bbls 9.4 PPG NaCl @ 3 BPM, ICP=770, FCP=100 PSI. 425 Bbls returned to surface. Returns were visibly contaminated. 9.1 PPG return weight. Bleed OA F/ 750 T/ 250. 8/15/2023 16:00 8/15/2023 18:00 2.0 0 MIRU, WELCTL MIRU OWFF P OWFF- well flowing. Shut in 25 PSI on TBG, 30 PSI on IA. Consult with town. Decision made to oder out more 9.4 PPG fluid. Squeeze in HEC pill. Re-kill well. 8/15/2023 18:00 8/16/2023 00:00 6.0 0 MIRU, WELCTL MIRU OTHR P Order out more 9.4 PPG fluid. Get more duo vis to location.Build Hi Vis deep clean pill, 45 BBls. Empty returns tanks. Load and process drill pipe 8/16/2023 00:00 8/16/2023 01:30 1.5 0 MIRU, WELCTL MIRU OTHR P Complete High vis pill, 9.4 PPG fluid here. All tanks empty 8/16/2023 01:30 8/16/2023 02:00 0.5 0 MIRU, WELCTL MIRU SFTY P PJSM. Plan well kill pumping strategy. Roles and responsibilities. 8/16/2023 02:00 8/16/2023 02:45 0.7 5 MIRU, WELCTL MIRU KLWL P Initial T/IA/OA 35/50/40. Bleed gas off IA. Start Hi Vis deep clean down tubing @ 3 BPM 8/16/2023 02:45 8/16/2023 04:00 1.2 5 MIRU, WELCTL MIRU KLWL P Stop pumping @ 100 BBls pumped. Let pill soak at upper perf interval. Refill pits with 9.4 PPG fluid. Empty surface tanks 8/16/2023 04:00 8/16/2023 06:45 2.7 5 MIRU, WELCTL MIRU KLWL P Initial pressures 0/15/180, Start pumping 3 BPM @215 PSI. Pumped 487 BBls, 280 BBls returns 8/16/2023 06:45 8/16/2023 07:30 0.7 5 MIRU, WELCTL MIRU OWFF P OWFF- Flow diminished to no retuned at tank. 30 Min no flow out of TBG and IA. 8/16/2023 07:30 8/16/2023 08:15 0.7 5 MIRU, WELCTL MIRU MPSP P FMC set ISA BPV. 8/16/2023 08:15 8/16/2023 08:45 0.5 0 MIRU, WELCTL MIRU PRTS P Perform rolling BPV test @ 3 BPM for 10 Min. Took 4 Bbls to catch pressure. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 3/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/16/2023 08:45 8/16/2023 10:00 1.2 5 MIRU, WHDBOP MIRU RURD P B/D, R/D circ equipment. R/U circ hose T/ IA. 8/16/2023 10:00 8/16/2023 18:30 8.5 0 MIRU, WHDBOP MIRU NUND P N/D tree and adaptor spool. Trouble getting seized up bolts to break on adaptor flange. Attempt to pull tree to max of lift gear 42K. Wrap adaptor with herculite and apply steam heat. M/U landing joint to thread profile in Otis cap. Kelly up TD. Pull tree free @ 85K over. L/D tree. Inspect hanger neck threads - corrosion. Attempt to M/U 3 1/2" EUE XO into hanger neck, only able to get 7 turns. Function LDS - One LDS very hard to work. Replace LDS. Remove nuts from studs that backed out of adaptor spool. Install slip over blanking plug. 8/16/2023 18:30 8/17/2023 00:00 5.5 0 MIRU, WHDBOP MIRU NUND P N/U 7 1/16"DSA. N/U BOP, reconfigure gray locks on choke hoses multiple times 8/17/2023 00:00 8/17/2023 03:00 3.0 0 MIRU, WHDBOP MIRU NUND P Continue nipple up. Add choke 6' extension, N/U upper section trip nipple 8/17/2023 03:00 8/17/2023 05:30 2.5 0 MIRU, WHDBOP MIRU PRTS P Fill stack. Attempt to shell test. HCR kill leaking out of stem. Greased HCR's and manuals. Idenified leak on gray lock fitting. 8/17/2023 05:30 8/17/2023 11:00 5.5 0 MIRU, WHDBOP MIRU PRTS T Grey locks leaking on choke side. Replaced gaskets. Resume shell test on BOPE. Grey locks leaking on kill side. Replaced 2 gaskets. Achieved passing shell test. 8/17/2023 11:00 8/17/2023 20:15 9.2 5 MIRU, WHDBOP MIRU BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3075 PSI, after closure=1700 PSI, 200 PSI attained =19 sec, full recovery attained =119 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 19 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1987 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Austin McLeod. 8/17/2023 20:15 8/17/2023 20:30 0.2 5 MIRU, WHDBOP MIRU BOPE T Grease and function Choke HCR. Replaced CMV #1. Rebuilt CMV #13. All passed retest. 8/17/2023 20:30 8/17/2023 21:00 0.5 0 MIRU, WHDBOP MIRU RURD P Pull blanking plug. R/D test equipment. B/D choke. 8/17/2023 21:00 8/17/2023 21:30 0.5 0 MIRU, WHDBOP MIRU MPSP P Pull ISA BPV. 8/17/2023 21:30 8/17/2023 22:00 0.5 0 COMPZN, RPCOMP MIRU RURD P P/Y YJ spear, Stab mousehole. R/U Eckels, C/O elevators for DP 8/17/2023 22:00 8/17/2023 23:00 1.0 0 7,742.0 7,742.0 COMPZN, RPCOMP MIRU BHAH P PJSM, M/U BHA #1 Tubing spear, M/U to top drive, RIH to no go. PUH 15K, Spear latched up. BOLDS. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 4/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/17/2023 23:00 8/18/2023 00:00 1.0 0 7,742.0 7,710.0 COMPZN, RPCOMP MIRU PULD P PJSM, Pull tubing hanger to rig floor, Broke over @ 117K, PUW 117K to 110K. Release control line from hanger. Release spear. Break out hanger. Install FOSV. Lay down BHA #1 8/18/2023 00:00 8/18/2023 00:30 0.5 0 7,710.0 7,710.0 COMPZN, RPCOMP MIRU RURD P Blow down choke hose in cellar. R/U to circulate well. 8/18/2023 00:30 8/18/2023 01:30 1.0 0 7,710.0 7,710.0 COMPZN, RPCOMP MIRU CIRC P Circulate down Tubing 3 BPM. 17 BBls to get returns from annulas. Pump Pressure 215 PSI. Fluid loss pumping 85 BBls/HR. Line up across top. Fluid losses 36.5 BBls/Hr. Shut down pump. Let well relax 8/18/2023 01:30 8/18/2023 02:00 0.5 0 7,710.0 7,710.0 COMPZN, RPCOMP MIRU RURD P R/D circ hose. Pull FOSV 8/18/2023 02:00 8/18/2023 03:00 1.0 0 7,710.0 7,580.0 COMPZN, RPCOMP MIRU PULL P Pull 3 1/2" tubing F/ 7710 T/ 7580', PUW=90 - 100K. Filling hole every 1/2 hour, catching returns ~8-10 Bbls. 8/18/2023 03:00 8/18/2023 03:30 0.5 0 7,580.0 7,580.0 COMPZN, RPCOMP MIRU SFTY P Crew change out / Continue decomplete 8/18/2023 03:30 8/18/2023 06:30 3.0 0 7,580.0 5,905.0 COMPZN, RPCOMP MIRU PULL P Cont L/D completion F/ 7580' T/ 5905', PUW=105K. 8/18/2023 06:30 8/18/2023 07:00 0.5 0 5,905.0 5,905.0 COMPZN, RPCOMP MIRU RURD P Terminate control line. L/D SSSV. Recovered 27 of 34 SS bands. 8/18/2023 07:00 8/18/2023 15:00 8.0 0 5,905.0 0.0 COMPZN, RPCOMP MIRU PULL P Cont L/D completion F/ 5905' T/ Surface', PUW=90K. 14.95' cut joint. Clean cut. 20' of SS control line wrapped around lowest GLM. 8/18/2023 15:00 8/18/2023 16:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean and clear RF and pipeshed. R/D tubing handling equipment. R/U DP handling equipment. 8/18/2023 16:30 8/18/2023 18:00 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Mobilize BHA #2 equipment T/ RF and pipeshed. 8/18/2023 18:00 8/18/2023 19:30 1.5 0 0.0 44.3 COMPZN, RPCOMP MIRU BHAH P PJSM, M/U BHA #2 Dress off / Clean out BHA 8/18/2023 19:30 8/18/2023 20:30 1.0 0 44.3 44.3 COMPZN, RPCOMP MIRU RURD P Install wear ring 8/18/2023 20:30 8/19/2023 00:00 3.5 0 44.3 230.0 COMPZN, RPCOMP MIRU PULD P RIN, Start having problems @ 45' Made it down to 153'. P/U Kelley up and rotate / work pipe to 230'' pumping across the top. Stopped making forward progress, Trip out of well. No signs of hang up on tool string, All pick ups clean. PUW=46K. SOW 38-40K. 8/19/2023 00:00 8/19/2023 01:00 1.0 0 230.0 44.0 COMPZN, RPCOMP MIRU PULD P POOH on elevators from 230' to BHA, PUW=46K. No over pulls 8/19/2023 01:00 8/19/2023 02:00 1.0 0 44.0 0.0 COMPZN, RPCOMP MIRU BHAH P Pull bha from well, No marks on tools. Boot baskets empty 8/19/2023 02:00 8/19/2023 02:30 0.5 0 0.0 48.2 COMPZN, RPCOMP MIRU BHAH P Reconfigure BHa #2 to BHA 3. Drop 6 1/8" wash pipe bottom for 5.75" drag tooth. Lay down 6.125" string reamer. Install casing scraper 8/19/2023 02:30 8/19/2023 03:30 1.0 0 48.2 45.0 COMPZN, RPCOMP MIRU PULD P Attempt to run in hole. At 45' same issues as last BHA. POOH to reconfigure BHA 8/19/2023 03:30 8/19/2023 04:15 0.7 5 45.0 40.9 COMPZN, RPCOMP MIRU BHAH P Crew change out / Reconfigure BHA to casing scraper BHA #4 8/19/2023 04:15 8/19/2023 04:30 0.2 5 40.9 220.9 COMPZN, RPCOMP MIRU PULD P Trip in hole. Ratty at 100', Set Down @ 220.85 8/19/2023 04:30 8/19/2023 04:45 0.2 5 220.9 40.9 COMPZN, RPCOMP MIRU PULD P Pull out of well. 8/19/2023 04:45 8/19/2023 06:00 1.2 5 40.9 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #4 Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 5/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/19/2023 06:00 8/19/2023 06:30 0.5 0 0.0 12.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #5, 6.125" sting mill on DP. Call out E-line for caliper and CBL. 8/19/2023 06:30 8/19/2023 09:30 3.0 0 12.0 1,205.0 COMPZN, RPCOMP MIRU PULD P RIH F/ 12.5' T/ 1205'. SOW=47K. Took weight @ 149', 230', 670'. Push through @ 670' w/ 10K SOW. 8/19/2023 09:30 8/19/2023 10:15 0.7 5 1,205.0 12.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 1205' T/ 12.5', PUW=67K 8/19/2023 10:15 8/19/2023 10:30 0.2 5 12.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #5 8/19/2023 10:30 8/19/2023 11:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SFTY P PJSM w/ AK E-line and rig crew on rigging up E-line. 8/19/2023 11:00 8/19/2023 11:45 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P R/U AK E-line w/ Read 40 arm caliper. 8/19/2023 11:45 8/19/2023 13:00 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU ELNE P RIH w/ 40 arm caliper T/ 1840'. Lost communication w/ toll. Trouble shoot. POOH. Swap to back up 40 arm caliper. 8/19/2023 13:00 8/19/2023 14:15 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU ELNE P RIH w/ 40 arm caliper T/ 2550'. Log up T/ surface. R/D tool string. Send data in for processing. 8/19/2023 14:15 8/19/2023 17:45 3.5 0 0.0 0.0 COMPZN, RPCOMP MIRU ELNE P M/U CBL & CCL / Gamma tool string. RIH T/ 2550'. Log up T/ surface. TOC identified at 1788'. Rig down AK E-line 8/19/2023 17:45 8/19/2023 19:00 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Mobilize yello jacket / Service rig, Lubricate blocks and top drive. Change gear oil in spinners 8/19/2023 19:00 8/19/2023 19:30 0.5 0 0.0 12.1 COMPZN, RPCOMP MIRU BHAH P PJSM, M/U BHA 6 dummy packer run 8/19/2023 19:30 8/19/2023 20:00 0.5 0 12.1 220.0 COMPZN, RPCOMP MIRU TRIP P RIN T/220'. Set down, work pipe. K/U work through 8/19/2023 20:00 8/19/2023 23:30 3.5 0 220.0 660.0 COMPZN, RPCOMP MIRU TRIP P Continue in to 660' area. Work pipe, KU, Work/ push pipe. No go. PUH rotate pipe in 90° increments try to work through multiple orientations. No Go. Line up down drill pipepump 4 BPM while working pipe down. No Go. Consult town. Set down lightly and try to rotate through multiple times. No Go past 665' 8/19/2023 23:30 8/20/2023 00:00 0.5 0 660.0 285.0 COMPZN, RPCOMP MIRU TRIP P POOH BHA #6, PUW=51K 8/20/2023 00:00 8/20/2023 00:30 0.5 0 285.0 12.0 COMPZN, RPCOMP MIRU TRIP P Continue out of well to BHA #6 8/20/2023 00:30 8/20/2023 01:00 0.5 0 12.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down BHA #6. Dummy packer run 6.125 string reamer and 5.75 string mill 8/20/2023 01:00 8/20/2023 01:30 0.5 0 0.0 3.9 COMPZN, RPCOMP MIRU BHAH P M/U BHA #7 4.75 bull nose. Drift for IBP past deviated casing 8/20/2023 01:30 8/20/2023 03:24 1.9 0 3.9 2,237.0 COMPZN, RPCOMP MIRU TRIP P RIH on stands to 1200'. clean past problem areas 220-235 and 660-665. Start singles in 8/20/2023 03:24 8/20/2023 04:30 1.1 0 2,237.0 0.0 COMPZN, RPCOMP MIRU TRIP P Trip out of hole, Standing back, PUW=85, SOW=51K 8/20/2023 04:30 8/20/2023 05:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P On surface, Lay down drift. Prep rig for E- line Rig up 8/20/2023 05:00 8/20/2023 06:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Ak E-line rigging up to set IBP 8/20/2023 06:30 8/20/2023 10:00 3.5 0 0.0 0.0 COMPZN, RPCOMP MIRU ELNE P RIH w/ 3 3/8' OD IBP for 7". Locate tubing stub @ 7738' E-line depth. Set IBP @ 7715' COE. Top of IBP @ 7710'. Set and release from plug POOH. Stand back E- line. 8/20/2023 10:00 8/20/2023 10:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU PRTS P PT 7" & IBP T/ 1000 PSI for 15 MIn - Good test. .8 Bbls to build pressure. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 6/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/20/2023 10:30 8/20/2023 11:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P R/D E-line 8/20/2023 11:00 8/20/2023 14:30 3.5 0 0.0 3,620.0 COMPZN, RPCOMP MIRU PULD P M/U mule shoe. PUDP T/ 3620', SOW=64K. 8/20/2023 14:30 8/20/2023 16:30 2.0 0 3,620.0 0.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 3620' T/ surface. PUW=106K. 8/20/2023 16:30 8/20/2023 17:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service rig. Grease draw work, TD, corwn and blocks. 8/20/2023 17:00 8/20/2023 19:00 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P PJSM w/ SLB and rig crew on rigging up E-Line 8/20/2023 19:00 8/20/2023 22:00 3.0 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P R/U E-line. 2300', Run CCL. Identify collars @ 2205 and 2244', Set mid element @ 2225'. Top of plug 2218' run setting sequence. POOH 8/20/2023 22:00 8/20/2023 23:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P Line up to pressure test IBP to 1000 PSI for 15 minutes. .4 BBls / 6 strokes to pressure up. Leaking IA valve on tree. Call out grease crew to service it. 8/20/2023 23:00 8/20/2023 23:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig down SLB E-line ser vices 8/20/2023 23:30 8/21/2023 00:00 0.5 0 0.0 180.0 COMPZN, RPCOMP MIRU PUTB P PJSM, Single in DP to ~ 2100' Midnight depth 365' SOW=38K, PUW=40K 8/21/2023 00:00 8/21/2023 02:00 2.0 0 180.0 2,102.5 COMPZN, RPCOMP MIRU PUTB P Continue in w/ DP to 2102.5 8/21/2023 02:00 8/21/2023 03:00 1.0 0 2,102.5 2,102.5 COMPZN, RPCOMP MIRU RURD P Rig up hoses to dump sanddown DP. 8/21/2023 03:00 8/21/2023 09:00 6.0 0 2,102.5 2,102.0 COMPZN, RPCOMP MIRU OTHR P Dump 22ea 60# sacks of sand down drill pipe / 15 minutes 8/21/2023 09:00 8/21/2023 09:30 0.5 0 2,102.0 2,102.0 COMPZN, RPCOMP MIRU RURD P R/D hoses and hopper for sand dump. 8/21/2023 09:30 8/21/2023 10:00 0.5 0 2,102.0 2,102.0 COMPZN, RPCOMP MIRU SVRG P Allow sand to settle. Servic rig. Grease equipment. 8/21/2023 10:00 8/21/2023 12:00 2.0 0 2,102.0 2,102.0 COMPZN, RPCOMP MIRU SLPC P Allow sand to settle. Slip and cut 60' of dril line. 8/21/2023 12:00 8/21/2023 12:30 0.5 0 2,102.0 2,102.0 COMPZN, RPCOMP MIRU SVRG P Top drive gripper foot would not extend down. Troubleshoot. Re-wired control. 8/21/2023 12:30 8/21/2023 13:00 0.5 0 2,102.0 2,167.0 COMPZN, RPCOMP MIRU TRIP P P/U single. RIH F/ 2100' tag sand top @ 2167'. PUW=85K, SOW=48K. 8/21/2023 13:00 8/21/2023 14:00 1.0 0 3,167.0 0.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 2167' T/ surface. L/D mule shoe. PUW=85K. 8/21/2023 14:00 8/21/2023 15:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P Suck out stack. Pull wear bushing. Set 7" test plug. 8/21/2023 15:00 8/21/2023 16:15 1.2 5 0.0 0.0 COMPZN, RPCOMP MIRU NUND P C/O LPR F/ 2 7/8" x 5 1/2" VBR T/ 7" fixed. 8/21/2023 16:15 8/21/2023 19:00 2.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P R/U testing equipment. Fill BOPE w/ fresh water. Purge air, Door seals leaking, C/O door seals. refill stack and purge air 8/21/2023 19:00 8/21/2023 19:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BOPE P Test LPR 250 / 2500 PSI 8/21/2023 19:30 8/21/2023 20:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RUNL P R/D test equipment, Pull test plug, Drain stack, R/D choke and kill lines 8/21/2023 20:30 8/21/2023 23:00 2.5 0 0.0 0.0 COMPZN, RPCOMP MIRU NUND P PJSM, Nipple down upper section of trip nipple. Nipple down stack, ND DSA, ND IA valves, Remove tubing head LDS 8/21/2023 23:00 8/21/2023 23:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU NUND P PJSM w/ FMC & Hydratight. Discuss plan forward, hazzards, and mitigations 8/21/2023 23:30 8/22/2023 00:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CUTP P Try lockdown screws in casing head No go 8/22/2023 00:00 8/22/2023 01:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P PJSM Rig up Hydratight on casing head. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 7/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/22/2023 01:00 8/22/2023 02:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CUTP P Apply downward force to head. ~ 400K Able to Back out lock down screws 8/22/2023 02:30 8/22/2023 04:30 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU CUTP P All lock down screws backed out. Start growing 7" casing with Hydratight 8/22/2023 04:30 8/22/2023 05:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P 7" stop growing, Relax for 30 minutes. Initial growth 24.75". R/D Hydratight. 8/22/2023 05:30 8/22/2023 07:30 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU WWWH P Remove damaged LDS. Chase threads in casing head for LDS. Install new LDS. M/U 7" spear on RF. 8/22/2023 07:30 8/22/2023 09:30 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU CUTP P Engage 7" spear P/U 146K tension = 15.5" of stretch.. Collar below hanger at top of casing head. No room to set emergency slips. Consult with town. Slack back of T/ neureal weak. Decision made to release spear and cut without tension. Release from spear and L/D same. 8/22/2023 09:30 8/22/2023 17:00 7.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P PJSM. Nipple Up BOPE, Choke & Kill Lines. C/O Choke and Kill HCR Valves. Install Riser and Bell nipple. Remove 9.4 PPG NaCl from pits. Replace with seawater. Vis up seawater system. 8/22/2023 17:00 8/22/2023 17:30 0.5 0 0.0 6.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #9, mechanical cutter. T/ 6' 8/22/2023 17:30 8/22/2023 18:00 0.5 0 6.0 100.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 6' T/ 100'. Idenified leak on casing head. 8/22/2023 18:00 8/22/2023 19:30 1.5 0 100.0 100.0 COMPZN, RPCOMP MIRU NUND P Call out FMC chance out IC test port. Hydrostac the choke & kill and flow nipple. 8/22/2023 19:30 8/22/2023 21:00 1.5 0 100.0 1,675.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 100' T/ 1675''. PUW= 59K, SOW=55K. 8/22/2023 21:00 8/23/2023 00:00 3.0 0 1,675.0 1,718.0 COMPZN, RPCOMP MIRU CUTP P RIH T/ 1743 Pump @ 2 BPM, 180 PSI. RIH T/ 1770' No collar location. P/U T/ 1733' increase pump rate T/ 3 BPM, 230 PSI. S/O lactate collar @ 1758' set 3K down. P/U 1705' Pump @ 3 BPM, 230 PSI. S/O locate collar @ 1718'. P/U T/ 1698'. Rot @ 70 RPM, 5.2K Free Tq ROT=58K. Sage pumps up T/ make cut F/ 3 BPM, 230 PSI T/ 8 BPM, 900 PSI. Tq 5.5K-9K. Once cut was made flow increased. Shut in annular to divert flow T/ open top tank 8/23/2023 00:00 8/23/2023 00:30 0.5 0 1,698.0 1,698.0 COMPZN, RPCOMP MIRU SFTY P PJSM w/ rig crew on circ out arctic pack. Notified DSO and CT unit of gas venting. Reposition vac tucks to opposite side of rig. 8/23/2023 00:30 8/23/2023 02:45 2.2 5 1,698.0 1,698.0 COMPZN, RPCOMP MIRU CIRC P SICP=75 PSI. Circ 225 Bbls of 138* hot seawater @ 2 BPM, 175 PSI. Tanking returns to open top tank. Holding 100 PSI w/ super choke. Getting seawater back w/ gas. Shut off pump. Bleed pressure off of choke. 8/23/2023 02:45 8/23/2023 03:00 0.2 5 1,698.0 1,698.0 COMPZN, RPCOMP MIRU OWFF P Bleed choke pressure down T/ 0 PSI. Shut choke in allow gas to migrate for 15 min. SICP came up T/ 50 PSI. 8/23/2023 03:00 8/23/2023 05:00 2.0 0 1,698.0 1,698.0 COMPZN, RPCOMP MIRU OWFF P OWFF. 8/23/2023 05:00 8/23/2023 05:30 0.5 0 1,698.0 1,673.0 COMPZN, RPCOMP MIRU TRIP P Blow down top drive, rack back working joint. 8/23/2023 05:30 8/23/2023 09:00 3.5 0 1,673.0 1,673.0 COMPZN, RPCOMP MIRU RGRP T Assist Electrician Troubleshoot Top Drive. Found Parted ground wire. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 8/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/23/2023 09:00 8/23/2023 10:00 1.0 0 1,673.0 6.0 COMPZN, RPCOMP MIRU TRIP P Continue TOOH f/1673' Up Wt 65K. 8/23/2023 10:00 8/23/2023 10:15 0.2 5 6.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #9. Mechanical cutter. 8/23/2023 10:15 8/23/2023 11:00 0.7 5 0.0 13.0 COMPZN, RPCOMP MIRU BHAH P Load 7" CSG Spear and MU Same to one joint of 3.5" Drill Pipe with No-Go Stop and Packoffs. BHA #10 8/23/2023 11:00 8/23/2023 11:30 0.5 0 13.0 26.0 COMPZN, RPCOMP MIRU FISH P TIH 26' w/ BHA #10 and Engage 7" CSG PUH 5' with 80K Up Wt. 8/23/2023 11:30 8/23/2023 11:45 0.2 5 26.0 21.0 COMPZN, RPCOMP MIRU SFTY P PJSM on Circulating Seawater down 7" taking returns up the OA to the open top tank. Discussed SIm-Ops with CT Operator. 8/23/2023 11:45 8/23/2023 12:45 1.0 0 21.0 21.0 COMPZN, RPCOMP MIRU CIRC P Circulate 290 bbls of 80* Seawater @ 6 BPM, 370 PSI. 8/23/2023 12:45 8/23/2023 13:15 0.5 0 21.0 21.0 COMPZN, RPCOMP MIRU OWFF P Monitor well for flow for 30 mins. 8/23/2023 13:15 8/23/2023 14:15 1.0 0 1,698.0 1,676.0 COMPZN, RPCOMP MIRU PULD P Pulled CSG Hanger to Rig floor. L/D 7" Spear and Hanger. Blow down Top Drive. C/O Handling Equipment. 8/23/2023 14:15 8/23/2023 18:30 4.2 5 1,676.0 0.0 COMPZN, RPCOMP MIRU PULL P Continue to TOOH laying down 7" CSG. Up Wt 85K. Joint #17 indicated severe buckling. Each joint had some form of buckling. Layed down total of 43 joints and 18.55' cut joint. Cut was flared out T/ 8 1/4". Pulled out 16 straigh bladed centralizes w/ 9 7/16" OD, 4" long ribs. No centralize on cut joint. 8/23/2023 18:30 8/23/2023 20:00 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean and clear RF and pipe shed. R/D GBR casing equipment. 8/23/2023 20:00 8/23/2023 22:00 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Flush and suck out stack. Install test plug. Grease HCR and manual valves in cellar. R/U test joints and testing equipment. 8/23/2023 22:00 8/23/2023 22:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU PRTS P Shell test BOP. Call out AOGCC rep Bob Noble. 8/23/2023 22:30 8/24/2023 00:00 1.5 0 0.0 COMPZN, RPCOMP MIRU BOPE P Weekly BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" test joints. Choke valves #3, #4,#7, #9 - #12. Upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 2" rig floor Demco kill valve MM #13. Perform accumulator test. Initial pressure=3050 PSI, after closure=1700 PSI, 200 PSI attained =24 sec, full recovery attained =128 sec. UVBR's= 5 sec, Simulated LVBRs= 5 sec. Annular= 24 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1937 PSI. Witnessed by AOGCC rep Bob Noble. 8/24/2023 00:00 8/24/2023 04:00 4.0 0 0.0 0.0 COMPZN, RPCOMP MIRU BOPE P Weekly BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested LPR w/ 7" test joint. Test blinds rams. Choke valves #1, #2, #5, #6, #8, #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test gas detectors, PVT and flow show. Witnessed by AOGCC rep Bob Noble. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 9/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/24/2023 04:00 8/24/2023 08:00 4.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P B/D. R/D testing equipment. Pull Test Plug. Install wear bushing. L/D 4-3/4" Drill Collars. Load Yellow Jacket tools and 6- 1/4" Drill Collars to pipe shed. 8/24/2023 08:00 8/24/2023 10:30 2.5 0 0.0 225.0 COMPZN, RPCOMP MIRU BHAH P PJSM. MU BHA #11. 8-1/2" String Mill w/Bullnose, Oil jars, Bumper sub and Drill Collars. 8/24/2023 10:30 8/24/2023 11:45 1.2 5 225.0 1,697.4 COMPZN, RPCOMP MIRU TRIP P TIH with BHA #11 f/225' to top of 7" stub at ~1697.38' with 5K down weight. Up/Dn Wt 73K. PUH 5' and circulate. 8/24/2023 11:45 8/24/2023 12:45 1.0 0 1,697.4 1,691.0 COMPZN, RPCOMP MIRU CIRC P Circulate 150 bbls @ 6 bpm, 155 psi, taking returns to the outside open top. 8/24/2023 12:45 8/24/2023 13:30 0.7 5 1,691.0 225.0 COMPZN, RPCOMP MIRU TRIP P OWFF. Blow down top drive . TOOH standing back DP. 8/24/2023 13:30 8/24/2023 14:30 1.0 0 225.0 217.0 COMPZN, RPCOMP MIRU BHAH P Break out 8-1/2" String Mill and Bull Nose. 8/24/2023 14:30 8/24/2023 15:45 1.2 5 217.0 235.5 COMPZN, RPCOMP MIRU BHAH P MU 8-3/8" Pilot Mill, 8-3/4" String Mill and Pony Collar. 8/24/2023 15:45 8/24/2023 16:45 1.0 0 235.5 1,684.0 COMPZN, RPCOMP MIRU TRIP P TIH w/BHA #13, PUW=75K, SOW=70K. 8/24/2023 16:45 8/24/2023 19:15 2.5 0 1,684.0 1,699.5 COMPZN, RPCOMP MIRU MILL P Tagged top of 7" Stub @ 1698' with bumper sub closed. PUH 20' and set parameters. Up Wt 75K / Dn Wt 70K. Pumping at 7.5 BPM, 200 psi, 70 RPM, 5.5K Free Tq. ROT= 75K, ROT P/U =75K, ROT S/O=72. Locate and dress off top of 7" stub T/ 1699,5', 4-5K WOB. Tq =6- 7.5K metal shaving seen at shakers. Allow WOB to drill off. 8/24/2023 19:15 8/24/2023 20:00 0.7 5 1,699.5 1,689.0 COMPZN, RPCOMP MIRU CIRC P Circ 30 Bbls hi vis pill out of bit P/U 10', Chased out of hole @ 10 BPM, 300 PSI. 8/24/2023 20:00 8/24/2023 20:30 0.5 0 1,689.0 1,626.0 COMPZN, RPCOMP MIRU RURD P Rack back stand T/ 1626'. B/D top drive. OWFF - No flow. 8/24/2023 20:30 8/24/2023 21:30 1.0 0 1,626.0 245.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 1626' T/ 235', PUW=74K. 8/24/2023 21:30 8/24/2023 22:30 1.0 0 245.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA # 12 F/ 245' T/ surface. Inspect pilot mill. 7" wear pattern on mill. 8/24/2023 22:30 8/24/2023 23:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean and clear RF. 8/24/2023 23:00 8/25/2023 00:00 1.0 0 0.0 150.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #13, dress off shoe T/ 150' 8/25/2023 00:00 8/25/2023 01:30 1.5 0 150.0 256.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #13, dress off shoe, 8.75" string mill, magnet and boot baskets T/ 256', SOW=53K. 8/25/2023 01:30 8/25/2023 02:15 0.7 5 256.0 1,647.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 256' T/ 1647', PUW=74K, SOW=70K. 8/25/2023 02:15 8/25/2023 03:45 1.5 0 1,647.0 1,696.0 COMPZN, RPCOMP MIRU MILL P Obtain parameters, pump @ 7.5 BPM, 230 PSI. Rot 15 RPM, 2.1K Free Tq. Rot @ 50 RPM, 4.2K Free Tq. ROT=72K. Kill Rot. S/O swallow 7' casing stub @ 1698.5', PSI increase T/ 260. Fully locate @ 1702'. PSI increase T/ 320. P/U T/ 1700'. ROT @ 50 RPM, 4.4K Tq. Rot down T/ 1702'. Set 4K down. Drilled off T/ 2K down. Rot up off of stump. PSI decrease T/ 230 PSI. Rot down over stump @ 15 RPM. PSI increase T/ 260. Increase RPM to 50. Rot down T/ 1702'. Rot up off stump. PSI drop. S/O swallow stump no Rot PSI increase T/ 260. Rot down @ 50 RPM. PSI increase T/ 320. Rot up off of stump. PSI drop. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 10/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/25/2023 03:45 8/25/2023 04:30 0.7 5 1,696.0 1,696.0 COMPZN, RPCOMP MIRU CIRC P Pump 45 Bbls hi vis sweep. Chase out of hole @ 10 BPM, 370 PSI. 8/25/2023 04:30 8/25/2023 06:00 1.5 0 1,696.0 1,675.0 COMPZN, RPCOMP MIRU COND P Suck out trip tank. Fill trip tank w/ non vis seawater. Drain & Rise Stack. 8/25/2023 06:00 8/25/2023 07:30 1.5 0 1,675.0 1,675.0 COMPZN, RPCOMP MIRU CIRC P FIll tank with clean seawater. Displace well to seawater @ 6 bpm, 520 psi, total of 250 bbls. 8/25/2023 07:30 8/25/2023 08:00 0.5 0 1,675.0 1,675.0 COMPZN, RPCOMP MIRU OWFF P Monitor well for flow. 8/25/2023 08:00 8/25/2023 09:15 1.2 5 1,675.0 256.0 COMPZN, RPCOMP MIRU TRIP P TOOH with BHA #13 f/ 1675' to 256' 8/25/2023 09:15 8/25/2023 12:00 2.7 5 256.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down 6-1/4" Drill Collars and BHA #13. 8/25/2023 12:00 8/25/2023 13:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU PULD P Unload Yellowjacket tools from Rig floor and Pipe Shed. C/O Handing Equipment. Pull Wear Bushing. 8/25/2023 13:30 8/25/2023 14:15 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P RU GBR Equipment. 8/25/2023 14:15 8/25/2023 14:30 0.2 5 0.0 0.0 COMPZN, RPCOMP MIRU SFTY P PJSM. Discussed Hazards associated with making up running 7" CSG tie-back string. 8/25/2023 14:30 8/25/2023 16:30 2.0 0 0.0 1,665.0 COMPZN, RPCOMP MIRU PUTB P MU 7" x 8.370" External Casing Patch w/ 3' Swallow and 7" ES Cementer on 7" 26#, L-80, HYD563 Casing. MU Torque 9400 Ft-Lbs. Best O' Life 2000 AG Dope used. Installed Centralizers on the Joint #1 and then every other joint after that. 8/25/2023 16:30 8/25/2023 16:45 0.2 5 1,665.0 1,703.0 COMPZN, RPCOMP MIRU PUTB P Up Wt 75K / Dn Wt 75K. Lower Tie-Back String an engaged top of 7" CSG Stub at 1698' and No-Go out at 1703' with 20K down. Pulled 50K over string weight to 125K. Good set. 8/25/2023 16:45 8/25/2023 17:30 0.7 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P Kelly up and Rig up testing equipment to fluid pack and PT 7" CSG to 2000 psi. 8/25/2023 17:30 8/25/2023 17:45 0.2 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU PRTS P Step up pressure to 1800 psi to test 7" Casing for 5 mins. Good test. 8/25/2023 17:45 8/25/2023 18:45 1.0 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P Kelly down. Remove XO from casing top. B/D TD. Remove CSG tong from rig floor. 8/25/2023 18:45 8/25/2023 19:30 0.7 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU NUND P N/D choke and kill lines. Split BOP stack and lift. 8/25/2023 19:30 8/25/2023 20:00 0.5 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU WWSP P Set 10.380" x 7" emergency slips w/ 50K tensiion. 8/25/2023 20:00 8/25/2023 21:15 1.2 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU NUND P N/U BOP, choke and kill lines. Load contamination pill in cuttings tank, open top tank and pill pit for upcoming cement job. 8/25/2023 21:15 8/25/2023 22:00 0.7 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P Rig up circ hose to cement line and fluid pack. 8/25/2023 22:00 8/26/2023 00:00 2.0 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P R/U HES cement unit. Spot vac tucks. Load cement head with closing plug. R/U cement head. 8/26/2023 00:00 8/26/2023 00:15 0.2 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU SFTY P PJSM w/ HES cement crew and rig crew on cementing 7" 8/26/2023 00:15 8/26/2023 00:30 0.2 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU PRTS P HES flood line w/ water. Shut in and PT cement line T/ 4500 PSI. 8/26/2023 00:30 8/26/2023 01:15 0.7 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU CIRC P Close LPR. Open up HES and pressure up and open ES cementer @ 3000 PSI. verified returns to surface. Pump 203 Bbls 140* fresh water @ 5 BPM, 570 PSI. Good returns to surface. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 11/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/26/2023 01:15 8/26/2023 02:30 1.2 5 1,703.0 1,703.0 COMPZN, RPCOMP MIRU CMNT P HES batch up & pump 20 Bbls 10.0 PPG spacer @ 2.5 BPM, 100 PSI, Batch up and pump 122 Bbls 15.3 PPG cement @ 3 BPM, 330 PSI Cement wet @ 01:35 Hrs. Drop closing plug. Chase w/ 10 Bbls of fresh water. 8/26/2023 02:30 8/26/2023 02:50 0.3 4 1,703.0 1,703.0 COMPZN, RPCOMP MIRU CMNT P Displace w/ rig @ 5 BPM, 3 Bbls to catch plug ICP=750 PSI FCP=1310. 45.5 Bbls away slowed pumps T/ 3 BPM ICP=890, FCP=930. Bump plug on time w/ 56.9 Bbls. Pressure up T/ 2100 PSI and held for 3 MIn. 15.3 PPG cement back to surface @ 51.9 Bbls pumped. Cement in place @ 02:50Hrs. 5 Bbls cement to surface. 8/26/2023 02:50 8/26/2023 03:00 0.1 6 1,703.0 1,703.0 COMPZN, RPCOMP MIRU OWFF P Bleed of PSI. OWFF - no flow. 8/26/2023 03:00 8/26/2023 03:30 0.5 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU CLEN P Close annular. Open LPR. Pump contamination pill through OA valve and all tiger tank lines. 8/26/2023 03:30 8/26/2023 05:00 1.5 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P B/D cement circ lines and tiger tank lines to all tanks. R/D cement head. Suck out 7" casing and BOP stack. 8/26/2023 05:00 8/26/2023 07:00 2.0 0 1,703.0 1,703.0 COMPZN, RPCOMP MIRU RURD P Pull Riser, disconnect trip tank lines. ND BOP Stack and lift same. 8/26/2023 07:00 8/26/2023 10:30 3.5 0 1,703.0 0.0 COMPZN, RPCOMP MIRU CPBO P Clean casing head bowl. R/U WHACKS cutter. Cut 7". Retrieve 31.88'. joint #41. 8/26/2023 10:30 8/26/2023 12:00 1.5 0 COMPZN, RPCOMP MIRU NUND P Remove flow Nipple for Annular,Remove DSA from BOPE. Rack back BOPE. 8/26/2023 12:00 8/26/2023 15:00 3.0 0 COMPZN, RPCOMP MIRU WWSP P Install 7" Packoffs. N/U new 7 1/16" 5K x 11" 3K tubing head. RU 11" x 7" DSA. PT 7" casing void. 3000 PSI/10 minutes. Install 7" Test Plug. 8/26/2023 15:00 8/26/2023 18:30 3.5 0 COMPZN, RPCOMP MIRU NUND P NU BOPE. NU Choke & Kill Lines. 8/26/2023 18:30 8/26/2023 19:15 0.7 5 COMPZN, RPCOMP MIRU RURD P Fill BOPE w/ fresh water. R/U testing equipment. 8/26/2023 19:15 8/26/2023 20:30 1.2 5 COMPZN, RPCOMP MIRU PRTS P PT BOP breaks, choke and kill breaks against blinds 250/2500 PSI for 5 Min each. 8/26/2023 20:30 8/26/2023 21:00 0.5 0 COMPZN, RPCOMP MIRU RURD P B/D, R/D testing equipment. Suck out BOP stack. 8/26/2023 21:00 8/26/2023 21:30 0.5 0 COMPZN, RPCOMP MIRU MPSP P Pull test plug. Install wear bushing. 8/26/2023 21:30 8/26/2023 22:15 0.7 5 COMPZN, RPCOMP MIRU RURD P Mobilize BHA #14 to RF and pipe shed. 8/26/2023 22:15 8/27/2023 00:00 1.7 5 0.0 182.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #14 6 1/8" roller cone bit & 6 1/8" sting mill T/ 182', SOW=44K. 8/27/2023 00:00 8/27/2023 01:00 1.0 0 182.0 1,618.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 182' tag cement stringer @ 1638' S/O 4K, PUW=65K, SOW=62. P/U T/ 1618'. 8/27/2023 01:00 8/27/2023 01:30 0.5 0 1,618.0 1,618.0 COMPZN, RPCOMP MIRU DISP P Circ hole over to viscous seawater @ 5 BPM, 260 PSI. 8/27/2023 01:30 8/27/2023 05:45 4.2 5 1,618.0 1,700.0 COMPZN, RPCOMP MIRU DRLG P Obtain parameters, pump @ 6 BPM, 365 PSI. 65 RPM, Free Tq= 4.6K. ROT=65K. Wash & ream through green cement F/1638' tag plug @ 1680, WOB 3-5K, Tq 5K. Drill F/ 1680' T/ 1683, WOB = 5-11K, Tq = 4.5-8K 8/27/2023 05:45 8/27/2023 06:15 0.5 0 1,700.0 1,610.0 COMPZN, RPCOMP MIRU SVRG P Service Top Drive. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 12/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/27/2023 06:15 8/27/2023 11:30 5.2 5 1,610.0 2,170.0 COMPZN, RPCOMP MIRU DRLG P Obtain parameters, pump @ 6 BPM, 410 PSI. 50 RPM, Free Tq= 4-6K. ROT=68K. Drill and wash down F/ 1700' T/ 2170, WOB = 5-7K, Tq = 4.5-8K.Pumping Sweeps as every stand drilled down. Seen good cement in sweeps and trace of sand once bit was top sand. 8/27/2023 11:30 8/27/2023 12:30 1.0 0 2,170.0 2,175.0 COMPZN, RPCOMP MIRU CIRC P Circulate 20 bbl Hi-Vis Sweep x 2 around after Dry drilling on top of sand. Seen trace of sand in sweeps. Dry tag sand top @ 2 8/27/2023 12:30 8/27/2023 13:30 1.0 0 2,175.0 182.0 COMPZN, RPCOMP MIRU TRIP P Blow down top drive. TOOH w/BHA #14. Up Wt 71K. 8/27/2023 13:30 8/27/2023 14:30 1.0 0 182.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand Back Drill Collars and L/D BHA #14 8/27/2023 14:30 8/27/2023 15:30 1.0 0 0.0 232.0 COMPZN, RPCOMP MIRU BHAH P PJSM. P/U BHA #15 ( 5-3/4" RCJB w/6- 1/16" Head) boot basket, string magnet and Jars. 8/27/2023 15:30 8/27/2023 16:45 1.2 5 232.0 2,120.0 COMPZN, RPCOMP MIRU TRIP P TIH w/ BHA #15. 8/27/2023 16:45 8/27/2023 17:15 0.5 0 2,120.0 2,176.0 COMPZN, RPCOMP MIRU WASH P PU Working Joint. Start Washing down w/ RCJB from 2120'to 2186'. 75K PUW, 65K SOW, Pumping at 9 bpm, 1700 psi, 50 RPM, 4-5K Torque. P/U 10'. 8/27/2023 17:15 8/27/2023 17:45 0.5 0 2,176.0 2,190.0 COMPZN, RPCOMP MIRU CIRC P Circ hi vis sweep around @ 7 BPM 1200 PSI. Dry tag sand top @ 2190'. 8/27/2023 17:45 8/27/2023 19:15 1.5 0 2,190.0 182.0 COMPZN, RPCOMP MIRU TRIP P Rack back stand, L/D working single. B/D top drive. Crew change out. POOH F/ 2114' T/ 182', PUW=75K. 8/27/2023 19:15 8/27/2023 20:45 1.5 0 182.0 0.0 COMPZN, RPCOMP MIRU BHAH P Rack back DC's. break down BHA #15 F/ 182' T/ surface. PUW=44K. Metal shavings on magnets. Debris in RCJB & junk baskets. 8/27/2023 20:45 8/27/2023 22:00 1.2 5 0.0 182.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA # 16 RCJB #2 T/ 182, SOW=45K. 8/27/2023 22:00 8/27/2023 23:15 1.2 5 182.0 2,176.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 182' T/ 2176', PUW=72K, SOW=65K 8/27/2023 23:15 8/27/2023 23:30 0.2 5 2,176.0 2,180.0 COMPZN, RPCOMP MIRU WASH P Drop ball. Start Washing down w/ RCJB F/ 2176 T/ 2200'. 75K PUW, 65K SOW, Pumping at 9 bpm, 1700 psi, 55 RPM, 4.5K Free Tq. P/U T/ 2180'. 8/27/2023 23:30 8/28/2023 00:00 0.5 0 2,180.0 2,180.0 COMPZN, RPCOMP MIRU CIRC P Pump 20 Bbls hi vis sweep @ 9 BPM, 1675 PSI. Overoad sweep at surface. 8/28/2023 00:00 8/28/2023 01:30 1.5 0 2,202.0 182.0 COMPZN, RPCOMP MIRU TRIP P RIH dry tag sand top @ 2202'. Rack stand backT/ 2177'. B/D TD. POOH T/ 182', PUW=75K. 8/28/2023 01:30 8/28/2023 02:45 1.2 5 182.0 0.0 COMPZN, RPCOMP MIRU BHAH P Rack back DC's. break down BHA #16 F/ 182' T/ surface. PUW=44K. Reduction of metal shavings on magnets. Reduction of debris in RCJB & boot baskets. 8/28/2023 02:45 8/28/2023 03:30 0.7 5 0.0 182.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA # 17 RCJB #3 T/ 182, SOW=45K. 8/28/2023 03:30 8/28/2023 04:30 1.0 0 182.0 2,176.0 COMPZN, RPCOMP MIRU TRIP P RIH T/2176', PUW=72K, SOW=65K. 8/28/2023 04:30 8/28/2023 06:00 1.5 0 2,176.0 2,210.0 COMPZN, RPCOMP MIRU WASH P Drop ball. Start Washing down w/ RCJB F/ 2176 T/ 2210'. 75K PUW, 65K SOW, Pumping at 9 bpm, 1700 psi, 55 RPM, 4.5K Free Tq. P/U T/ 2180'. Pump Hi-Vis sweep around. 8/28/2023 06:00 8/28/2023 07:30 1.5 0 2,210.0 182.0 COMPZN, RPCOMP MIRU TRIP P Blow down top drive. OWFF. TOOH w/BHA #17. Up Wt 68K. 8/28/2023 07:30 8/28/2023 08:30 1.0 0 182.0 0.0 COMPZN, RPCOMP MIRU BHAH P Rack Back drill collars. Clean Magnets. Clean and Inspect RCJB. L/D BHA #17. Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 13/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/28/2023 08:30 8/28/2023 09:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Rig Service. 8/28/2023 09:00 8/28/2023 10:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean & Clear Rig Floor. 8/28/2023 10:00 8/28/2023 10:30 0.5 0 0.0 13.0 COMPZN, RPCOMP MIRU BHAH P PJSM. Load Baker tools to pipe shed. PU/MU Baker BHA #1, IBP Retrieval Assy. 8/28/2023 10:30 8/28/2023 11:30 1.0 0 13.0 2,200.0 COMPZN, RPCOMP MIRU TRIP P TIH w/ Baker BHA #1. 1.375'' JDC RET HEAD for IBP 8/28/2023 11:30 8/28/2023 12:30 1.0 0 2,200.0 2,217.0 COMPZN, RPCOMP MIRU WASH P Wash down to top of IBP at 3.5 bpm, 870 psi,up wt 65K, sow 60K. Pump 20 bbl sweep around to surface 8/28/2023 12:30 8/28/2023 13:00 0.5 0 2,217.0 2,217.0 COMPZN, RPCOMP MIRU MPSP P Engaged IBP at 2217'. Pulled up to 75K and seen pins shear. Allow elements to relax. Blow down top drive. 8/28/2023 13:00 8/28/2023 14:30 1.5 0 2,217.0 13.0 COMPZN, RPCOMP MIRU TRIP P TOOH w/BHA #1 8/28/2023 14:30 8/28/2023 15:00 0.5 0 13.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D IBP and Inspect Retrieval head. Everything looks good. IBP was not missing any elements of parts. 8/28/2023 15:00 8/28/2023 20:00 5.0 0 13.0 7,680.0 COMPZN, RPCOMP MIRU TRIP P TIH w/ Baker BHA #2. 1.375'' JDC RET HEAD for IBP F/ 13' T/ 7680', PUW=153K, SOW=98K. 8/28/2023 20:00 8/28/2023 20:30 0.5 0 7,680.0 7,680.0 COMPZN, RPCOMP MIRU SVRG P Service rig, top drive handle lock. 8/28/2023 20:30 8/28/2023 21:00 0.5 0 7,680.0 7,695.0 COMPZN, RPCOMP MIRU RURD P B/D through choke T/ open top tank for circulation. RIH T/ 7695'. Close UPR to divert returns to open top tank. 8/28/2023 21:00 8/28/2023 22:00 1.0 0 7,695.0 7,695.0 COMPZN, RPCOMP MIRU DISP P Pump 15 Bbls hi vis sweep. Displace well to 9.4 PPG NaCl w/ 1.25% safe lube @ 6 BPM, IP=2240. FCP=290. Pumped total of 314 Bbls. Clean 9.4 PPG back to surface. 8/28/2023 22:00 8/28/2023 22:15 0.2 5 7,695.0 7,695.0 COMPZN, RPCOMP MIRU RURD P Open up LPR. B/D choke and tiger tank lines. 8/28/2023 22:15 8/28/2023 22:30 0.2 5 7,695.0 1,980.0 COMPZN, RPCOMP MIRU PULD P P/U T/ 6980' M/U working single. 8/28/2023 22:30 8/28/2023 23:15 0.7 5 6,980.0 7,711.0 COMPZN, RPCOMP MIRU MPSP P Wash down F/ 6980' T/ xx' PUW=138K, SOW=106K. Circ @ 2 BPM, 200 PSI. T/ 7700'. Pressure increase T/ 470 PSI. Set 5K down. P/U saw pins on IBP shear 8K. P/U 2K. Allow IBP element to relax for 15 Min. Fluid level falling in BOP. P/U T/ 7690, PUW-138K, S/O T/ 7711', SOW=106K. 8/28/2023 23:15 8/28/2023 23:30 0.2 5 7,711.0 7,622.0 COMPZN, RPCOMP MIRU PULD P L/D 4 singles F/ 7711' T/ 7622', PUW=138K. B/D TD. 8/28/2023 23:30 8/29/2023 00:00 0.5 0 7,622.0 6,971.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 7622' T/ 6971', PUW=137K. Filling hole evey 30 Min. 8/29/2023 00:00 8/29/2023 04:00 4.0 0 6,971.0 12.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6970' T/ 12', PUW=129K Filling hole every 30 Min ~ 9 Bbls. 8/29/2023 04:00 8/29/2023 05:00 1.0 0 12.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D Baker BHA #2 & IBP. All parts and pieces recovered. 8/29/2023 05:00 8/29/2023 08:15 3.2 5 0.0 232.0 COMPZN, RPCOMP MIRU BHAH P PU/MU BHA #18. 3-1/2" Dress off Assy. 8/29/2023 08:15 8/29/2023 10:45 2.5 0 232.0 7,600.0 COMPZN, RPCOMP MIRU TRIP P TIH w/BHA #18 to top of 3.5" TBG Stub. 8/29/2023 10:45 8/29/2023 11:45 1.0 0 7,600.0 7,695.0 COMPZN, RPCOMP MIRU REAM P Rotate down f/7590' to 7695' 6-1/8" w/ String mill across Packer setting area @ 4 bpm, 620 psi, 50 RPM, SOW 106K, PUW 143K. Reciprocate across packer setting area x 3 Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 14/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/29/2023 11:45 8/29/2023 12:45 1.0 0 7,727.0 7,735.0 COMPZN, RPCOMP MIRU MILL P TIH and Tagged top of 3.5" TBG Stub @ 7727' rotate 1/4 turn and dress shoe went over stub, continue down and no-go with dress Assy. to 7733'. PUH and set parameters at 2 bpm, 1260 psi at 50 RPM, 3-5K Torque. Rotate down dressing top of tubing stub. Seen good 50 psi increase once shoe was completely located. Able to slide over tubing stub multiple times without pumping or rotating with no issues, no-go out each time @ 7735'. PUH and blow down top drive. 8/29/2023 12:45 8/29/2023 13:00 0.2 5 7,680.0 7,680.0 COMPZN, RPCOMP MIRU TRIP P PUH 60' and blow down top drive. 8/29/2023 13:00 8/29/2023 14:45 1.7 5 7,680.0 7,680.0 COMPZN, RPCOMP MIRU SLPC P Slip & Cut 48' of Drilling Line. 8/29/2023 14:45 8/30/2023 00:00 9.2 5 7,680.0 507.0 COMPZN, RPCOMP MIRU PULD P TOOH laying down Drill Pipe from 7680' T/507' Filling hole with ~9 BBLS every 30 min 8/30/2023 00:00 8/30/2023 00:30 0.5 0 507.0 231.0 COMPZN, RPCOMP MIRU PULD P POOH lay down DP F/507' T/231' Filling hole with ~9 BBLS every 30 min 8/30/2023 00:30 8/30/2023 03:00 2.5 0 231.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #18 - Clean and clear rig floor of BHA components 8/30/2023 03:00 8/30/2023 03:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Pull wear ring 8/30/2023 03:30 8/30/2023 04:15 0.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig up to run 3 1/2" tubing, load tubing components in pipe shed, prep pipe shed for running tubing 8/30/2023 04:15 8/30/2023 09:00 4.7 5 0.0 1,742.0 COMPZN, RPCOMP MIRU PUTB P PJSM - Run 3 1/2" tubing as per detail 8/30/2023 09:00 8/30/2023 09:15 0.2 5 1,742.0 1,742.0 COMPZN, RPCOMP MIRU OTHR P Set down while running completion at 1742', rotate tubing 1/4 turn. 8/30/2023 09:15 8/30/2023 09:30 0.2 5 1,742.0 1,886.0 COMPZN, RPCOMP MIRU PUTB P Continue running in hole with 3.5' completion f/1742' 8/30/2023 09:30 8/30/2023 10:00 0.5 0 1,886.0 1,886.0 COMPZN, RPCOMP MIRU CIRC P Set down with completion again @ 1886'. Install FOSV in TBG. Bullhead 20 bls down backside at 2 bpm, 95 psi. 8/30/2023 10:00 8/30/2023 10:30 0.5 0 1,886.0 2,008.0 COMPZN, RPCOMP MIRU PUTB P Able to work 3.5" completion pass tag depth at 1886' down to 2008' and tagged again. 8/30/2023 10:30 8/30/2023 12:30 2.0 0 2,008.0 0.0 COMPZN, RPCOMP MIRU PULL P Pull OOH standing back 3.5" TBG and L/D Jewelry. PU WT 54K SOW 54K. 8/30/2023 12:30 8/30/2023 13:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU PULD P L/D Overshot, GLM, X Nipple and Packer. 8/30/2023 13:00 8/30/2023 15:45 2.7 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Start loading Drill Pipe in shed. Load Yellowjacket tools back to the pipe shed. C/O Handling equipment. Swap pits from 9.4 ppg NaCL to Vis-fluid. Install wear bushing. 8/30/2023 15:45 8/30/2023 17:00 1.2 5 0.0 147.8 COMPZN, RPCOMP MIRU BHAH P PU/MU Clean Out BHA. 5-3/4" RCJB w/6- 1/16" Head, 7" 26# Casing Scraper, 6-1/8" String Mill, Boot Baskets x2 and String Magnets x2. 8/30/2023 17:00 8/30/2023 21:00 4.0 0 147.8 2,300.0 COMPZN, RPCOMP MIRU PULD P TIH w/BHA #19. Clean Out Assy. RIH T/2,300' 65K up and down Work casing scraper and string mill across spots at 1,742', 1,886', 2,008'- clean up and down, pull up 35' - 45' above them ad put 1/4 turn into pipe and work thru spot, clean up and down Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 15/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/30/2023 21:00 8/30/2023 23:00 2.0 0 2,300.0 2,300.0 COMPZN, RPCOMP MIRU CIRC P Circulate at 5 BPM 380 PSI - 10 BPM 1170 PSI Pump 30 BBLS Hi Vis sweep, chase with 9.4 PPG vis up brine Est loss rate @ 5 BPM @ 33% Pump 30 BBL Hi Vis sweep chase with 300 BBLS 9.4 PPG brine Lose rate @ 10 BPM @ 30% 8/30/2023 23:00 8/31/2023 00:00 1.0 0 2,300.0 1,634.0 COMPZN, RPCOMP MIRU PULD P POOH laying down DP to pipe shed F/2,300' T/1,634' 66K UP 8/31/2023 00:00 8/31/2023 01:45 1.7 5 1,634.0 147.0 COMPZN, RPCOMP MIRU PULD P POOH laying down DP to pipe shed F/1,634' T/147' 8/31/2023 01:45 8/31/2023 03:30 1.7 5 147.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #19, inspect boot baskets and clean magnet Clean clear rig floor 8/31/2023 03:30 8/31/2023 04:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Pull wear ring 8/31/2023 04:00 8/31/2023 06:30 2.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Rig up to run 3 1/2" tubing 8/31/2023 06:30 8/31/2023 15:30 9.0 0 0.0 7,670.0 COMPZN, RPCOMP MIRU PUTB P PJSM run 3 1/2" completion as per detail. Seen slight bobble at 1975' & 2006'. Continue running completion to joint 241 to 7669' PUW 96K, SOW 75K. 8/31/2023 15:30 8/31/2023 16:15 0.7 5 7,670.0 7,742.0 COMPZN, RPCOMP MIRU HOSO P Picked up Joint 243 & Joint 244. No-Go out 10' in on Joint 244 @ 7742' w/8.34' swallow on the overshot, top of tubing stub at 7733.66' while pumping at 2 bpm,170 psi, seen spear pins on overshot shear and seals during the no-go process, seen pressure increase after no-go. Pick up 2' and marked pipe for space out leaving the end of overshot at 7740'. 8/31/2023 16:15 8/31/2023 17:00 0.7 5 7,742.0 7,709.0 COMPZN, RPCOMP MIRU THGR P L/D Joint 243 & Joint 244. Add 8.24'space out pup below joint 242. P/U Hanger & Pup with landing. Top of Tubing Stub at 7733' and bottom of overshot shoe 7740'. Drop Ball & Rod. 8/31/2023 17:00 8/31/2023 19:00 2.0 0 7,709.0 7,709.0 COMPZN, RPCOMP MIRU CIRC P Circulate 168 bbls of CI Brine down backside and chase with 55 bls of Brine water @ 2 bpm, 175 psi. 8/31/2023 19:00 8/31/2023 19:30 0.5 0 7,709.0 7,709.0 COMPZN, RPCOMP MIRU RURD P Drain stack, blow down lines Sim Ops - start cleaning pits 8/31/2023 19:30 8/31/2023 21:00 1.5 0 7,709.0 7,738.0 COMPZN, RPCOMP MIRU THGR P Slack off land hanger in wellhead 96K UP 75K DN Flow check - slight flow from bull heading in fluid RILDS 8/31/2023 21:00 8/31/2023 22:00 1.0 0 7,738.0 7,738.0 COMPZN, RPCOMP MIRU PRTS P Rig up to set packer PSI up to 3500 PSI set packer 8/31/2023 22:00 8/31/2023 23:45 1.7 5 7,738.0 0.0 COMPZN, RPCOMP MIRU PRTS P Test tubing to 3500 PSI F/30 Min Bleed TBG to 1500 PSI Test IA to 2500 F/30 Min Dump TBG pressure - shear out SOV Pump at 2 BPM 200 PSI to insure flow path 8/31/2023 23:45 9/1/2023 00:00 0.2 5 0.0 0.0 COMPZN, WHDBOP MIRU OWFF P Flow check Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Page 16/16 1E-20 Report Printed: 9/25/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 9/1/2023 00:00 9/1/2023 01:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU MPSP P Flow check - static Lay down landing joint Install H-BPV test from below to 1000 PSI F/10 Min Blow down lines and rig down 9/1/2023 01:00 9/1/2023 02:30 1.5 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P C/O lower rams to 2 7/8" x 5 1/2" 9/1/2023 02:30 9/1/2023 05:30 3.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Remove bell nipple,disconnect kill & choke lines, pull mouse hole. ND BOPE, remove DSA and Rack back BOPE. 9/1/2023 05:30 9/1/2023 10:00 4.5 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/U tubing head adaptor and tree. PT Void to 250/ 5000 psi for 5 mins. 9/1/2023 10:00 9/1/2023 10:45 0.7 5 0.0 0.0 COMPZN, WHDBOP MIRU PRTS P RU Testing Equipment. Test tree and TBG adaptor T/250/5000 PSI 9/1/2023 10:45 9/1/2023 12:45 2.0 0 0.0 0.0 COMPZN, WHDBOP MIRU FRZP P Pull H-BPV. Pump 75 BBLS to freeze protect TBG and IA @ 2 BPM 950 PSI Rig down LRS. RU Hose and allow well to U-Tube for one hour. 9/1/2023 12:45 9/1/2023 14:00 1.2 5 0.0 0.0 COMPZN, WHDBOP MIRU RURD P Blow down and rig down lines. Secure well, obtain final pressures. FTP: 250 / FIAP: 250 / FOAP: 10 psi. Secure Wellhead. 9/1/2023 14:00 9/2/2023 00:00 10. 00 0.0 0.0 DEMOB, MOVE MIRU MOB P Prep for RDMO Rig. Clean Location and Cellar. Change out tire on rig, Inspect suction rubbers on valves in pits and change out as needed Rig Name: NORDIC 3 Rig Accept : 8/15/2023 Rig Release : 9/2/2023 Well Name: 1E-20 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,948.0 1E-20 12/20/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed post rig GLD. Set LTP assembly. 1E-20 9/10/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: TOL at 7751' 2/4/2020 spilch Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 34.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 33.0 2,380.0 2,172.4 45.50 K-55 BTC Tie-Back String 7 6.28 31.2 1,703.0 1,646.1 26.00 L-80 HYD563 WINDOW 7 6.28 7,949.0 7,953.0 6,216.3 WINDOW 7 6.28 7,961.0 7,965.0 6,225.5 PRODUCTION 7 6.28 31.2 8,621.7 6,733.7 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.7 Set Depth 7,746.0 Set Depth 6,055.7 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.7 27.7 0.06 Hanger 6.980 3.5" x 7 1/16" FMC Tubing Hanger Gen 4. Control Line Ports: PLUGGED FMC Gen4 2.920 485.5 485.5 0.05 Nipple - X 4.504 3.5" x 2.813" X-Nipple, SN: 0004890017-08 Halliburt on 2.813" X Nipple 2.813 2,774.7 2,456.6 45.10 Mandrel GAS LIFT 5.963 3.5" x 1.5" MMG (Dummy) w/ RK Latch, EUE-M BxP, SN: 24135-17 SLB MMG RK Latch 2.920 3,551.2 3,004.6 45.20 Mandrel GAS LIFT 5.927 3.5" x 1.5" MMG (Dummy) w/ RK Latch, EUE-M BxP, SN: 24135-18 SLB MMG RK Latch 2.920 4,481.2 3,644.3 45.20 Mandrel GAS LIFT 5.950 3.5" x 1.5" MMG (Dummy) w/ RK Latch, EUE-M BxP, SN: 24135-19 SLB MMG RK Latch 2.920 7,570.7 5,918.8 38.68 Mandrel GAS LIFT 5.949 3.5" x 1.5" MMG (2,000 psi SOV), RKP Latch, EUE-M BxP, SN: 24135- 20 SLB MMG RKP Latch 2.920 7,661.7 5,989.7 38.57 Packer 6.010 3.5" x 7" BluePack RH Max VAMTOP BxP, HNBR, SN: C23P- 0277 SLB BluePac k 2.894 7,687.8 6,010.2 38.47 Nipple - X 4.504 3.5" x 2.813" X-Nipple w/ RHC-M Plug, SN: 0004890017-04 Halliburt on 2.813" X Nipple 2.813 7,736.9 6,048.6 38.64 Overshot 6.000 3 1/2" PB Overshot w/ 8.50' of swallow (5.49' to shear pins, 2' space out) Baker Poorboy Oversho t 3.630 Top (ftKB) 7,742.0 Set Depth 7,807.0 Set Depth 6,103.2 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,764.6 6,070.2 38.81 PBR 5.125 BAKER PBR w/ 10' STROKE 3.000 7,778.3 6,080.9 38.89 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 7,794.6 6,093.6 38.99 NIPPLE 4.540 CAMCO D NIPPLE NO GO(MILLED 3/17/2017) 2.800 7,806.3 6,102.6 39.04 SOS 4.570 BAKER SHEAR OUT SUB 3.015 Top (ftKB) 8,098.0 Set Depth 8,160.0 Set Depth 6,375.8 String Ma 3 1/2 Tubing Description TUBING ABANDONED Wt (lb/ft) 9.30 Grade J-55 Top Connection BTCMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,098.0 6,328.0 39.57 BLAST JT 4.500 SHATTERED 1' OF BLAST JOINT LEFT ON TOP OF ABANDONED TUBING COMPLETION 2.992 8,110.1 6,337.3 39.57 GAS LIFT 5.940 CAMCO 2.907 8,129.7 6,352.4 39.58 LOCATOR 6.000 BAKER LOCATOR 4.000 8,130.3 6,352.8 39.58 PACKER 6.156 BAKER FB-1 PACKER 4.000 8,132.8 6,354.8 39.58 SBE 4.000 BAKER SEAL BORE EXTENSION 3.500 8,147.8 6,366.4 39.58 NIPPLE 4.520 CAMCO 'D' NIPPLE 2.906 8,159.3 6,375.2 39.59 SOS 3.500 BAKER SHEAROUT SUB 2.938 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 31.2 31.2 0.07 EMERGENCY SLIPS 10.380 x 7" emergency slips 8/25/2023 7.000 7,718.0 6,033.8 38.53 PACKER - PATCH - UPR 350-272 Mono Pak packer (5.65' x 1.81" ID) Note: One piece assembly Packer, spacer pipe & PTSA (OAL 35.8') NSAK Mono- Pak NSP0 28 9/10/2023 1.810 7,721.0 6,036.2 38.55 SPACER PIPE 2 3/8" spacer pipe (17.01' x 1.92" ID ) CPAI 9/10/2023 1.920 1E-20, 9/25/2023 1:22:39 PM Vertical schematic (actual) PRODUCTION; 1,700.0-8,621.7 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 HEW; 7,938.0 PACKER; 7,778.3 OTHER; 7,738.0 SPACER PIPE; 7,721.0 PACKER - PATCH - UPR; 7,718.0 Nipple - X; 7,687.8 Packer; 7,661.7 Mandrel GAS LIFT; 7,570.7 Mandrel GAS LIFT; 4,481.2 Mandrel GAS LIFT; 3,551.2 Mandrel GAS LIFT; 2,774.7 SURFACE; 33.0-2,380.0 Tie-Back String; 31.2-1,703.0 Production String 1 Cement; 31.2 ftKB Nipple - X; 485.5 CONDUCTOR; 34.0-110.0 EMERGENCY SLIPS; 31.2 Hanger; 27.7 KUP PROD KB-Grd (ft) 39.00 RR Date 2/3/1983 Other Elev 1E-20 ... TD Act Btm (ftKB) 8,650.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089500 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,200.00 WELLNAME WELLBORE1E-20 Annotation Last WO: End Date 7/23/1990 H2S (ppm) 90 Date 9/4/2017 Comment SSSV: LOCKED OUT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,738.0 6,049.5 38.65 OTHER 350-225 PTSA Assembly (3.75' x 1.781" ID) w/ 1.781 R NIPPLE. NSAK PTSA 9/10/2023 1.781 7,977.0 6,234.8 39.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/28/2017 2.500 7,979.0 6,236.3 39.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/31/2017 2.500 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,774.7 2,456.6 45.10 1 GAS LIFT GLV RK 5.96 3 1,202.0 9/8/2023 Schlumb erger MMG 0.250 3,551.2 3,004.6 45.20 2 GAS LIFT DMY RK 5.92 7 8/31/2023 Schlumb erger MMG 4,481.2 3,644.3 45.20 3 GAS LIFT OV RK 5.95 0.0 9/8/2023 Schlumb erger MMG 0.250 7,570.7 5,918.8 38.68 4 GAS LIFT DMY RK 5.94 9 0.0 9/8/2023 Schlumb erger MMG 0.000 8,110.1 6,337.3 39.57 9 GAS LIFT DMY BK 0.0 2/3/1983 In Tubin g Aband on 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,681.3 1,627.2 29.38 Collar - Stage 8.300 7" ES Cementer (SN#: 102463867) Halliburto n HES Cementer 6.171 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,945.0 8,094.0 6,210.1 6,324.9 C-4, C-3, C-2, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,349.0 8,362.0 6,521.5 6,531.6 A-5, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,382.0 8,410.0 6,547.1 6,568.8 A-4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 1E-20, 9/25/2023 1:22:40 PM Vertical schematic (actual) PRODUCTION; 1,700.0-8,621.7 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 HEW; 7,938.0 PACKER; 7,778.3 OTHER; 7,738.0 SPACER PIPE; 7,721.0 PACKER - PATCH - UPR; 7,718.0 Nipple - X; 7,687.8 Packer; 7,661.7 Mandrel GAS LIFT; 7,570.7 Mandrel GAS LIFT; 4,481.2 Mandrel GAS LIFT; 3,551.2 Mandrel GAS LIFT; 2,774.7 SURFACE; 33.0-2,380.0 Tie-Back String; 31.2-1,703.0 Production String 1 Cement; 31.2 ftKB Nipple - X; 485.5 CONDUCTOR; 34.0-110.0 EMERGENCY SLIPS; 31.2 Hanger; 27.7 KUP PROD 1E-20 ... WELLNAME WELLBORE1E-20 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-19_22114_KRU_1E-20_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22114 KRU 1E-20 50-029-20895-00 Caliper Survey w/ Log Data 19-Aug-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 183-005 T37951 8/23/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.23 10:34:09 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KRU 1E-20 Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8650'2241 None 7977' 7979' Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:James Ohlinger Contact Email: Contact Phone: 907-265-1102 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Replace Tubing N/A Kuparuk River Field james.j.ohlinger@conocophillips.com CTD/RWO Drilling Engineer Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoin g is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 8130'MD/6353'TVD Packer: 7778'MD/6081'TVD SSSV: 1822'MD/1748'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025651 183-005 P.O. Box 100360, Anchorage, AK 99510 50-029-20895-00-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: Kuparuk River Oil Pool 6756' Plugs (MD): J-55 TVD Burst 7807' MD 110' 2172' 110' 2380' 16" 10-3/4" 76' 2347' 7945-8094' 8349-8362' 8382-8410'' 7156-7182' 8591' 6210-6325' 6522-6532' 6547-6569' 6112-6134' 6734'7" 7948' 6212' 9/15/2023 3-1/2" Packer: Baker FB-1 Packer: Baker HB Retrievable SSSV: CAMCO TRDP 8622' Perforation Depth MD (ft): Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:38 pm, Aug 22, 2023 323-479 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2023.08.22 12:43:57-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger X X DSR-8/23/23VTL 9/15/2023 BOP test to 2500 psig Annular preventer test to 2500 psig MDG 8/24/2023*&: 09/15/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.15 13:33:24 -08'00' 404 RBDMS JSB 091823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 21, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1E- 20 (PTD# 183-005). Well 1E-20 was drilled and completed in February of 1983 by Rowan Rig #34 as a Kuparuk A/C sand producer. The well was worked over in 1990 to repair a leaking packer. In 2020, two CTD laterals were drilled targeting the C-sand out of the well. In late 2022, the well failed a TIFL and subsequent diagnostics revealed a probable production packer leak at 7778' RKB. If you have any questions or require any further information, please contact me at 406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to perform subsidence repair on the 7" casing. Then replace the tubing and stack a new production packer above the leak currently identified at the existing production packer. 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 1 of 4 Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests. 2. Pull catcher and RBP at 7738’ RKB. Pull CTD liner top packer at 7751’ MD. 3. Measure SBHP. 4. Pull all GLVs and install DVs. Leave lowest GLM open for circulation point. 5. Cut tubing at ~7,742’ RKB. 6. Install BPV and prepare well within 48-96 hrs of rig arrival. Confirm no gas in OA, IA, or tubing. Rig Work MIRU 1. MIRU Nordic 3 on 1E-20. Pull BPV if needed to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig tubing cut. Production Casing Test 6. PU DP, MU casing scraper w/ cleanout BHA, and RIH to scraper/cleanout to the tubing stub. Was unable to RIH past ~650’. POOH. 7. MU test packer and confirm casing integrity at planned packer set depth. Locate additional leaks as necessary. 8. POOH laying down DP. 9. RU eline for Caliper and CBL logs, log from 2500’ up IBP set at 7710’ MD 2nd IBP 2225’ MD 10. Place 50’ sand on top of 2nd IBP 11. Modify BOP stack for future 7” casing work Install 7” RAMS run test plug & pressure test to 2500 psi per Sundry requirements 12. Nipple down BOP for tubing head removal Begin grow & stretch operations of 7” Production Casing (PC) NOTES: 7” production casing on mandrel hanger 13. RU Hydratight System, control growth pull 7” casing 14. If successful on stretching enough 7” to expose below the mandrel hanger install slips Cut excess 7” casing set packoffs 15. Nipple up BOP 16. Set g-plug shallow for BOP test (2500 psi) 17. RIH w/ drift run If successful, fish added barriers, return to original approved sundry work 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 2 of 4 If Grow & Stretch Operations ae not Successful NOTES: Can’t get enough stretch to get to cut point below the hanger mandrel Can’t test BOP at this point 18. Nipple up BOP on casing flange BOP can be tested once the 7” casing has been retrieved 19. RIH w/ MSC for cut ~ 1700’, cut mid-joint above the TOC diesel will U-tube 20. Spear 7” PC with packoffs, PU on mandrel Circulate out Arctic Pack w/ heated seawater Pull 7” casing out from cut 21. Pressure test the BOPE flange break after casing is pulled. Use a BOPE test plug in the mandrel hanger profile 22. RIH with undersized 10 ¾” Drift assembly, drift or make drift for new 7” tie back. 23. RIH with 7” Tie back with external casing patch and cementer. Test casing to 2500psi. 24. Continue to pressure up and open cementer, Cement Annulus of 7” x 9 5/8” Casing. 25. Perform 30 minute no flow test, Split stack and land slips, cut excess casing and install PC packoffs. 26. Land stack and MU to casing flange. Test Flange break to 250psi/3000psi 27. Mill Cement/ plugs in cementer 28. Pull Plugs (barriers), return to previously approved sundry work Install New Tubing 29. MU 3-1/2” completion with poorboy overshot, packer, nipples, and GLMs. RIH to tubing stub. 30. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 31. Pressure test tubing to 3,000 psig for 5 minutes. 32. Pressure test inner annulus to 2,500 psig for 30 minutes on chart. ND BOP, NU Tree 33. Confirm pressure tests, then shear out SOV with pressure differential. 34. Install BPV. 35. ND BOPE. NU tree. 36. Pull BPV, freeze protect well, and set BPV if necessary. 37. RDMO. Post-Rig Work 38. Pull BPV 39. Pull B&R and RHC plug 40. Run LTP for CTD liner 41. Install gas lift design 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 3 of 4 General Well info: Wellhead type/pressure rating: FMC Gen I, 5M psi top flange x 3M bottom flange Production Engineer: Adam Becia Reservoir Development Engineer: Cody Keith Estimated Start Date: 6/1/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing tubing from a cut above the upper production packer, confirm leak depth at 7778’ RKB, stack new production packer with poorboy overshot above the leak. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / DSA (as needed) 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 4 of 4 Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed (Down to RBP at 7738’ RKB, 2500 psig, 3/8/2023) CMIT-TxIA Failed (likely leak point identified via LDL at 7778’ RKB, production packer depth) MIT-OA Passed (1800 psig, 5/3/23) IC POT &PPPOT PASSED – 1/14/2020 TBG POT &PPPOT PASSED – 1/14/2020 MPSP: 2241 psi using 0.1 psi/ft gradient Static BHP: 2847 psi / 6065’ TVD measured on 3/29/2023 PROPOSED COMPLETION FMC Gen I Tubing Hanger 3-1/2" 9.3# L-80 EUE-Mod 8RD 3-1/2" x 2.813" 'X' Nipple ~500ft MD 3-1/2" x 1.5" MMG GLMs (TBD) 3-1/2" x 7" SLB BluePack RH Max (Cut to Release) OR Equivalent 3-1/2" x 2.813" 'X' Nipple Poor Boy Overshot (sized for 3-1/2" tubing stub) REMAINING COMPLETION LEFT IN HOLE 3-1/2" 9.2# J-55 BTC-Mod cut tubing stub (cut @ 7742' RKB) Baker 3-1/2" PBR @ 7764' MD (3" ID) Baker HB retrievable packer @ 7778' MD (2.89" ID) 3-1/2" Camco DS landing nipple @ 7795' MD (2.75" min ID, no-go) 10-3/4" 45# K-55 shoe @ 2380' MD 7" 26# K-55 shoe @ 8622' MD 16" 65# H-40 shoe @ 110' MD A-sand perfs 8349' - 8410' MD KOP @ 7938' MD C-sand perfs 7945' - 8094' MD Failed HEW set attempts from 2017 Swell packer at ~8422' MD 1E-20L1 TD=11,337' MD TOL= 8531' MD BOL= 11,337' MD 2-3/8" slotted liner w/ billet 1E-20L1-01 TD= 10,913' MD TOL= 7751' MD BOL= 10,913' MD QCLL= 8442' MD, 9905' MD 2-3/8" slotted liner w/ LTP Suspected Packer Leak 7778' RKB 3-1/2" tubing cut ~7742' IBP ~7710' IBP ~2225' 50' sand 1E-20 Current Schematic 1E-20 Proposed RWO Completion PROPOSED COMPLETION FMC Gen I Tubing Hanger 3-1/2" 9.3# L-80 EUE-Mod 8RD 3-1/2" x 2.813" 'X' Nipple ~500ft MD 3-1/2" x 1.5" MMG GLMs (TBD) 3-1/2" x 7" SLB BluePack RH Max (Cut to Release) OR Equivalent 3-1/2" x 2.813" 'X' Nipple Poor Boy Overshot (sized for 3-1/2" tubing stub) REMAINING COMPLETION LEFT IN HOLE 3-1/2" 9.2# J-55 BTC-Mod cut tubing stub (cut @ 7742' RKB) Baker 3-1/2" PBR @ 7764' MD (3" ID) Baker HB retrievable packer @ 7778' MD (2.89" ID) 3-1/2" Camco DS landing nipple @ 7795' MD (2.75" min ID, no-go) 10-3/4" 45# K-55 shoe @ 2380' MD 7" 26# K-55 shoe @ 8622' MD 16" 65# H-40 shoe @ 110' MD A-sand perfs 8349' - 8410' MD KOP @ 7938' MD C-sand perfs 7945' - 8094' MD Failed HEW set attempts from 2017 Swell packer at ~8422' MD 1E-20L1 TD=11,337' MD TOL= 8531' MD BOL= 11,337' MD 2-3/8" slotted liner w/ billet 1E-20L1-01 TD= 10,913' MD TOL= 7751' MD BOL= 10,913' MD QCLL= 8442' MD, 9905' MD 2-3/8" slotted liner w/ LTP Suspected Packer Leak 7778' RKB 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull LTP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8650'feet None feet true vertical 6756'feet 7977', 7979'feet Effective Depth measured 8650'feet 7778', 8130'feet true vertical 6756'feet 6081', 6353'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7807' MD 6103' TVD Packers and SSSV (type, measured and true vertical depth) 7778' MD 8130' MD 1822' MD 6081' TVD 6353' TVD 1747' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2380' 2172' Burst Collapse Production Liner 8590' Casing 6734'8622' 2347' 110'Conductor Surface Intermediate 16" 10-3/4" 76' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-005 50-029-20895-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025651 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1E-20 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 110' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker HB Retrvbl Packer Packer: Baker FB-1 Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer 7945-8094', 8349-8362', 8382-8410' 6210-6325', 6521-6532', 6547- 6569' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 10:08 am, Apr 28, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.04.27 14:22:41-08'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 3/28/2023 SUPPORT OTHER OPERATIONS PULLED DV @ 7714' RKB; PULLED 3 1/2" CATCHER & 3 1/2" RBP @ 7733' RKB; ATTEMPT TO PULL 1.78" RX PLUG IN LTP @ 7760' RKB (UNABLE TO GET INTO TOP OF LTP @ 7751' RKB). IN PROGRESS. 3/29/2023 SUPPORT OTHER OPERATIONS BAIL ELEMENT DEBRIS INSIDE LTP @ 7751' RKB & STILL UNABLE TO GET INSIDE TO PULL 1.78" RX PLUG; PULLED 2.72" NS LTP & RECOVER 1.78" RX PLUG; DRIFT W/ 2.5" BAILER DOWN TO LINER TOP @ 7759' RKB; DRIFT W/ GAUGES AND UNABLE TO MAKE IT PAST 7759' RKB (MEASURED BHP 2846 PSI @ DEPTH); DRIFT W/ 1 3/4" BAILER SAT DOWN @ 7759', WORKED THRU, AND DRIFTED DOWN TO 8015' RKB. READY FOR E-LINE. 1E-20 Pull Liner Top Packer Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,948.0 1E-20 12/20/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tubing 1E-20 4/10/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TOL at 7751'2/4/2020 spilch Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.25 34.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 33.0 2,380.0 2,172.4 45.50 K-55 BTC WINDOW 7 6.28 7,949.0 7,953.0 6,216.3 WINDOW 7 6.28 7,961.0 7,965.0 6,225.5 PRODUCTION 7 6.28 31.2 8,621.7 6,733.7 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.6 Set Depth 7,807.0 Set Depth 6,103.2 String Ma 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.6 27.6 0.06 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,822.0 1,747.5 33.55 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE - LOCKED OUT 6/19/2000 (FLOW TUBE ONLY) 2.812 2,209.7 2,046.0 42.20 GAS LIFT 5.390 CAMCO KBUG 2.920 3,447.9 2,931.7 45.00 GAS LIFT 5.390 CAMCO KBUG 2.920 4,314.1 3,526.7 47.89 GAS LIFT 5.390 CAMCO KBUG 2.920 5,056.0 4,044.2 45.27 GAS LIFT 5.390 CAMCO KBUG 2.920 5,740.1 4,530.6 43.59 GAS LIFT 5.390 CAMCO KBUG 2.920 6,453.2 5,055.7 42.12 GAS LIFT 5.390 CAMCO KBUG 2.920 7,114.1 5,562.3 38.84 GAS LIFT 5.390 CAMCO KBUG 2.920 7,714.8 6,031.3 38.51 GAS LIFT 5.750 CAMCO MMG-2 2.920 7,764.6 6,070.2 38.81 PBR 5.125 BAKER PBR w/ 10' STROKE 3.000 7,778.3 6,080.9 38.89 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 7,794.6 6,093.6 38.99 NIPPLE 4.540 CAMCO D NIPPLE NO GO(MILLED 3/17/2017) 2.800 7,806.3 6,102.6 39.04 SOS 4.570 BAKER SHEAR OUT SUB 3.015 Top (ftKB) 8,098.0 Set Depth 8,160.0 Set Depth 6,375.8 String Ma 3 1/2 Tubing Description TUBING ABANDONED Wt (lb/ft) 9.30 Grade J-55 Top Connection BTCMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,098.0 6,328.0 39.57 BLAST JT 4.500 SHATTERED 1' OF BLAST JOINT LEFT ON TOP OF ABANDONED TUBING COMPLETION 2.992 8,110.1 6,337.3 39.57 GAS LIFT 5.940 CAMCO 2.907 8,129.7 6,352.4 39.58 LOCATOR 6.000 BAKER LOCATOR 4.000 8,130.3 6,352.8 39.58 PACKER 6.156 BAKER FB-1 PACKER 4.000 8,132.8 6,354.8 39.58 SBE 4.000 BAKER SEAL BORE EXTENSION 3.500 8,147.8 6,366.4 39.58 NIPPLE 4.520 CAMCO 'D' NIPPLE 2.906 8,159.3 6,375.2 39.59 SOS 3.500 BAKER SHEAROUT SUB 2.938 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,742.0 6,052.6 38.67 CUT 2-3/8" WELLTEC MECHANICAL TBG CUT AT 7742' RKB 4/10/2023 2.992 7,977.0 6,234.8 39.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/28/2017 2.500 7,979.0 6,236.3 39.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/31/2017 2.500 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,209.7 2,046.0 42.20 1 GAS LIFT DMY BK 1 0.0 3/8/2023 0.000 3,447.9 2,931.7 45.00 2 GAS LIFT DMY BK 1 0.0 3/8/2023 0.000 4,314.1 3,526.7 47.89 3 GAS LIFT DMY BK 1 0.0 3/8/2023 0.000 5,056.0 4,044.2 45.27 4 GAS LIFT Ext Pk DMY BK 1 0.0 3/2/2023 0.000 5,740.1 4,530.6 43.59 5 GAS LIFT DMY BK 1 0.0 3/7/2017 0.000 6,453.2 5,055.7 42.12 6 GAS LIFT DMY BK 1 0.0 9/26/2007 0.000 7,114.1 5,562.3 38.84 7 GAS LIFT DMY BK 1 0.0 7/23/1990 0.000 7,714.8 6,031.3 38.51 8 GAS LIFT OPEN OPEN 1 1/2 0.0 4/7/2023 0.000 8,110.1 6,337.3 39.57 9 GAS LIFT DMY BK 0.0 2/3/1983 In Tubin g Aband on 0.000 1E-20, 4/26/2023 6:39:37 AM Vertical schematic (actual) PRODUCTION; 31.2-8,621.7 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 HEW; 7,938.0 PACKER; 7,778.3 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 KUP PROD KB-Grd (ft) 39.00 RR Date 2/3/1983 Other Elev 1E-20 ... TD Act Btm (ftKB) 8,650.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089500 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,200.00 WELLNAME WELLBORE Annotation Last WO: End Date 7/23/1990 H2S (ppm) 90 Date 9/4/2017 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,945.0 8,094.0 6,210.1 6,324.9 C-4, C-3, C-2, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,349.0 8,362.0 6,521.5 6,531.6 A-5, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,382.0 8,410.0 6,547.1 6,568.8 A-4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 1E-20, 4/26/2023 6:39:39 AM Vertical schematic (actual) PRODUCTION; 31.2-8,621.7 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 HEW; 7,938.0 PACKER; 7,778.3 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 KUP PROD 1E-20 ... WELLNAME WELLBORE Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread SLOTTED LINER L1- 01 2 3/8 1.99 7,751.1 10,913.0 4.60 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,751.1 6,059.7 38.73 DEPLOYMENT SLEEVE 0.000 NSAK 225 Seal Bore Deployment Sleeve, L-80, (3.00" GS profile) 0.000 8,415.3 6,314.2 89.86 XO Threads 2.375 XO 2-3/8" STL box X 2-3/8" 511 pin, 4.7#, L-80 na na 1.992 8,417.1 6,314.3 89.94 XO Threads 2.375 XO 2-3/8" 511 box X 2-3/8" 511 pin, 4.7#, L-80 na na 1.992 8,421.9 6,314.2 90.16 XO Threads 2.060 XO 2-3/8" 511 box to 2-1/16" 511 pin, 4.7#, L-80 na na 1.992 8,422.8 6,314.2 90.20 SWELL PACKER 2.700 Swell Packer - Halliburton, (SP,WS, LT, 0C, NTE, 2.063, B-P, 2.7X1.5M, WLD) Halliburto n Swell Pkr.1.686 8,437.7 6,314.1 90.88 XO Threads 2.060 XO 2-16" 511 box X 2-3/8" 511 box, 4.7#, L-80 na na 1.992 8,438.7 6,314.1 90.93 XO Threads 2.375 XO 2-3/8" 511 pin X 2-3/8" 511 pin, 4.7#, L-80 na na 1.992 8,442.8 6,314.0 91.11 DEPLOYMENT SLEEVE 2.375 NSAK 350-238 OH Permanent QCLL, L-80 Baker 1.920 9,905.7 6,169.2 89.75 DEPLOYMENT SLEEVE 2.375 NSAK 350-238 OH Permanent QCLL, L-80 Baker 1.920 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,442.0 10,913.0 6,314.0 C-4, C-3, C-2, 1E-20 2/4/2020 SLOTS Slotted Liner 8442'-10913' 1E-20L1-01, 4/26/2023 6:39:42 AM Vertical schematic (actual) SLOTTED LINER L1-01; 7,751.1 -10,913.0 SLOTS; 8,442.0-10,913.0 PRODUCTION; 31.2-8,621.7 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 KUP PROD KB-Grd (ft) 39.00 RR Date 2/3/1983 Other Elev 1E-20L1-01 ... TD Act Btm (ftKB) 10,913.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089565 Wellbore Status PROD Max Angle & MD Incl (°) 104.27 MD (ftKB) 8,832.19 WELLNAME WELLBORE Annotation End DateH2S (ppm) 90 Date 9/4/2017 Comment Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread SLOTTED LINER L1 2 3/8 1.99 8,536.7 11,337.0 6,186.4 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,329.8 6,208.1 87.97 DEPLOYMENT SLEEVE 2.375 Shorty deployment sleeve Baker 1.920 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,537.0 11,337.0 6,309.6 6,186.4 C-4, C-3, C-2, 1E-20 1/30/2020 SLOTS Slotted Liner 8,537'-11,337' 1E-20L1, 4/26/2023 6:39:44 AM Vertical schematic (actual) SLOTTED LINER L1; 8,536.7- 11,337.0 SLOTS; 8,537.0-11,337.0 PRODUCTION; 31.2-8,621.7 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 HEW; 7,938.0 PACKER; 7,778.3 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 KUP PROD KB-Grd (ft) 39.00 RR Date 2/3/1983 Other Elev 1E-20L1 ... TD Act Btm (ftKB) 11,337.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089564 Wellbore Status PROD Max Angle & MD Incl (°) 100.18 MD (ftKB) 8,871.78 WELLNAME WELLBORE Annotation End DateH2S (ppm) 90 Date 9/4/2017 Comment 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8650'7977' 7979' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7945-8094', 8349-8362', 8382-8410' 8591' 6210-6325', 6522-6532, 6547-6569'3-1/2" 7" 16" 10-3/4" 76' 2347' Perforation Depth MD (ft): MD 110' 2172' 110' 2380' 6734'8622' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6756' 7948' 6212' 2241 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025651 183-005 P.O. Box 100360, Anchorage, AK 99510 50-029-20895-00-00 ConocoPhillips Alaska, Inc. KRU 1E-20 Kuparuk River Oil PoolKuparuk Oil PoolKuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 8130'MD/6353'TVD Packer: 7778'MD/6081'TVD SSSV: 1822' MD/1748'TVD Perforation Depth TVD (ft):Tubing Size: J-55 7807' 6/1/2023 Packer: Baker FB-1 Packer: Baker HB Retrievable SSSV: CAMCO TRDP-1A-SSA 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 RWO/CTD Engineer n P s 66 t c Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-225 By Kayla Junke at 3:28 pm, Apr 13, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.13 13:52:00-08'00' Foxit PDF Editor Version: 12.0.1 BOP test to 2500 psig Annular preventer test to 2500 psig VTL 5/17/2023 X MDG 4/28/2023 X 10-404 DSR-4/13/23GCW 05/17/23JLC 5/17/2023 5/17/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.17 10:59:26 -08'00' RBDMS JSB 051823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1E-20 (PTD# 183-005). Well 1E-20 was drilled and completed in February of 1983 by Rowan Rig #34 as a Kuparuk A/C sand producer. The well was worked over in 1990 to repair a leaking packer. In 2020, two CTD laterals were drilled targeting the C-sand out of the well. In late 2022, the well failed a TIFL and subsequent diagnostics revealed a probable production packer leak at 7778' RKB. If you have any questions or require any further information, please contact me at 406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to replace the tubing and stack a new production packer above the leak currently identified at the existing production packer. Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann @conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.13 14:18:34-08'00' Foxit PDF Editor Version: 12.0.1 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 1 of 3 Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests. 2. Pull catcher and RBP at 7738’ RKB. Pull CTD liner top packer at 7751’ MD. 3. Measure SBHP. 4. Pull all GLVs and install DVs. Leave lowest GLM open for circulation point. 5. Cut tubing at ~7,742’ RKB. 6. Install BPV and prepare well within 48-96 hrs of rig arrival. Confirm no gas in OA, IA, or tubing. Rig Work MIRU 1. MIRU Nordic 3 on 1E-20. Pull BPV if needed to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig tubing cut. Production Casing Test 6. PU DP, MU casing scraper w/ cleanout BHA, and RIH to scraper/cleanout to the tubing stub. POOH. 7. MU test packer and confirm casing integrity at planned packer set depth. Locate additional leaks as necessary. 8. POOH laying down DP. Install New Tubing 9. MU 3-1/2” completion with poorboy overshot, packer, nipples, and GLMs. RIH to tubing stub. 10. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 11. Pressure test tubing to 3,000 psig for 5 minutes. 12. Pressure test inner annulus to 2,500 psig for 30 minutes on chart. ND BOP, NU Tree 13. Confirm pressure tests, then shear out SOV with pressure differential. 14. Install BPV. 15. ND BOPE. NU tree. 16. Pull BPV, freeze protect well, and set BPV if necessary. 17. RDMO. Post-Rig Work 18. Pull BPV 19. Pull B&R and RHC plug 20. Run LTP for CTD liner 21. Install gas lift design 30 min 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 2 of 3 General Well info: Wellhead type/pressure rating: FMC Gen II, 5M psi top flange x 3M bottom flange Production Engineer: Adam Becia Reservoir Development Engineer: Cody Keith Estimated Start Date: 6/1/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing tubing from a cut above the upper production packer, confirm leak depth at 7778’ RKB, stack new production packer with poorboy overshot above the leak. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / DSA (as needed) 1E-20 RWO Procedure Kuparuk Producer P&R Tubing PTD #183-005 Page 3 of 3 Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed (Down to RBP at 7738’ RKB, 2500 psig, 3/8/2023) CMIT-TxIA Failed (likely leak point identified via LDL at 7778’ RKB, production packer depth) MIT-OA Passed (1800 psig, 1/14/2020) IC POT &PPPOT PASSED – 1/14/2020 TBG POT &PPPOT PASSED – 1/14/2020 MPSP: 2241 psi using 0.1 psi/ft gradient Static BHP: 2847 psi / 6065’ TVD measured on 3/29/2023 1E-20 Current SchematicLTP @ 7751' RKB3-1/2" Camco TRDP-1A-SSA SSSV @ 1822' MD (2.812" min ID)3-1/2" 9.2# J-55 Tubing to surface3-1/2" Camco gas lift mandrels @ 2210' MD, 3448' MD, 4314' MD, 5056' MD, 5740' MD, 6453' MD, 7114' MD, 7715' MDBaker 3-1/2" PBR @ 7764' MD (3" ID)Baker HB retrievable packer @ 7778' MD (2.89" ID)3-1/2" Camco DS landing nipple @ 7795' MD (2.75" min ID, no-go)Baker SOS @ 7806' MD (7802' PDC)_________________Baker FB-1 packer @ 8130' MD (4.0" ID)Baker SBE @ 8132' MD 3-1/2" Camco D landing nipple @ 8148' MD (2.90" min ID)3-1/2" tubing tail @ 8160' MD10-3/4" 45# K-55 shoe @ 2380' MD7" 26# K-55 shoe @ 8622' MD16" 65# H-40 shoe @ 110' MDA-sand perfs 8349' - 8410' MDKOP @ 7938' MDC-sand perfs 7945' - 8094' MDFailed HEW set attempts from 2017Swell packer at ~8422' MD1E-20L1 TD=11,337' MDTOL=8531' MD BOL= 11,337' MD2-3/8" slotted liner w/ billet1E-20L1-01TD= 10,913' MDTOL= 7751' MD BOL= 10,913' MDQCLL= 8442' MD, 9905' MD2-3/8" slotted liner w/ LTPSuspected Packer Leak 7778' RKB 1E-20 Proposed RWO CompletionPROPOSED COMPLETIONFMC Gen II Tubing Hanger3-1/2" 9.3# L-80 EUE-Mod 8RD3-1/2" x 2.813" 'X' Nipple ~500ft MD3-1/2" x 1.5" MMG GLMs (TBD)3-1/2" x 7" SLB BluePack RH Max (Cut to Release) OR Equivalent3-1/2" x 2.813" 'X' Nipple Poor Boy Overshot (sized for 3-1/2" tubing stub)REMAINING COMPLETION LEFT IN HOLE3-1/2" 9.2# J-55 BTC-Mod cut tubing stubBaker 3-1/2" PBR @ 7764' MD (3" ID)Baker HB retrievable packer @ 7778' MD (2.89" ID)3-1/2" Camco DS landing nipple @ 7795' MD (2.75" min ID, no-go)10-3/4" 45# K-55 shoe @ 2380' MD7" 26# K-55 shoe @ 8622' MD16" 65# H-40 shoe @ 110' MDA-sand perfs 8349' - 8410' MDKOP @ 7938' MDC-sand perfs 7945' - 8094' MDFailed HEW set attempts from 2017Swell packer at ~8422' MD1E-20L1 TD= 11,337' MDTOL=8531' MD BOL= 11,337' MD2-3/8" slotted liner w/ billet1E-20L1-01TD= 10,913' MDTOL= 7751' MD BOL= 10,913' MDQCLL= 8442' MD, 9905' MD2-3/8" slotted liner w/ LTPSuspected Packer Leak 7778' RKB Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,948.0 1E-20 12/20/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tubing1E-20 4/10/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: TOL at 7751'2/4/2020 spilch Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.2534.0 110.0 110.065.00 H-40 WELDED SURFACE 10 3/4 9.95 33.0 2,380.0 2,172.4 45.50 K-55 BTC WINDOW 7 6.28 7,949.0 7,953.0 6,216.3 WINDOW 7 6.28 7,961.0 7,965.0 6,225.5 PRODUCTION 7 6.28 31.2 8,621.7 6,733.7 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 27.6 Set Depth … 7,807.0 Set Depth… 6,103.2 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.627.60.06 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,822.0 1,747.5 33.55 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE - LOCKED OUT 6/19/2000 (FLOW TUBE ONLY) 2.812 2,209.7 2,046.0 42.20 GAS LIFT 5.390 CAMCO KBUG2.920 3,447.92,931.7 45.00 GAS LIFT 5.390 CAMCO KBUG2.920 4,314.13,526.7 47.89 GAS LIFT 5.390 CAMCO KBUG2.920 5,056.0 4,044.2 45.27 GAS LIFT 5.390 CAMCO KBUG 2.920 5,740.1 4,530.6 43.59 GAS LIFT 5.390 CAMCO KBUG 2.920 6,453.2 5,055.7 42.12 GAS LIFT 5.390 CAMCO KBUG 2.920 7,114.1 5,562.3 38.84 GAS LIFT 5.390 CAMCO KBUG 2.920 7,714.86,031.338.51GAS LIFT 5.750CAMCOMMG-22.920 7,764.66,070.238.81 PBR 5.125 BAKER PBR w/ 10' STROKE 3.000 7,778.36,080.938.89 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 7,794.66,093.638.99 NIPPLE 4.540CAMCO D NIPPLE NO GO(MILLED 3/17/2017) 2.800 7,806.36,102.639.04 SOS 4.570 BAKER SHEAR OUT SUB 3.015 Top (ftKB) 8,098.0 Set Depth … 8,160.0 Set Depth… 6,375.8 String Ma… 3 1/2 Tubing Description TUBING ABANDONED Wt (lb/ft) 9.30 Grade J-55 Top Connection BTCMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,098.0 6,328.0 39.57 BLAST JT 4.500 SHATTERED 1' OF BLAST JOINT LEFT ON TOP OF ABANDONED TUBING COMPLETION 2.992 8,110.16,337.339.57 GAS LIFT 5.940CAMCO 2.907 8,129.7 6,352.4 39.58 LOCATOR 6.000 BAKER LOCATOR 4.000 8,130.3 6,352.8 39.58 PACKER 6.156 BAKER FB-1 PACKER 4.000 8,132.8 6,354.8 39.58 SBE 4.000 BAKER SEAL BORE EXTENSION 3.500 8,147.86,366.4 39.58 NIPPLE 4.520 CAMCO 'D' NIPPLE 2.906 8,159.36,375.239.59SOS 3.500 BAKER SHEAROUT SUB 2.938 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,742.0 6,052.6 38.67 CUT 2-3/8" WELLTEC MECHANICAL TBG CUT AT 7742' RKB 4/10/2023 2.992 7,977.0 6,234.8 39.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/28/2017 2.500 7,979.06,236.339.59 FISH 3-1/2" by 7" high expansion wedge whipstock. Depth below 7977' 3/31/2017 2.500 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,209.7 2,046.0 42.20 1 GAS LIFT DMY BK 1 0.03/8/20230.000 3,447.9 2,931.7 45.00 2 GAS LIFT DMY BK 1 0.03/8/20230.000 4,314.1 3,526.7 47.89 3 GAS LIFT DMY BK 1 0.03/8/20230.000 5,056.0 4,044.2 45.27 4 GAS LIFT Ext Pk DMY BK 1 0.03/2/20230.000 5,740.1 4,530.6 43.59 5 GAS LIFT DMY BK 1 0.03/7/2017 0.000 6,453.2 5,055.7 42.12 6 GAS LIFT DMY BK 1 0.09/26/2007 0.000 7,114.1 5,562.3 38.84 7 GAS LIFT DMY BK 1 0.0 7/23/1990 0.000 7,714.86,031.338.51 8 GAS LIFT OPEN OPEN 1 1/20.0 4/7/2023 0.000 8,110.16,337.339.57 9 GAS LIFT DMY BK 0.02/3/1983 In Tubin g Aband on 0.000 1E-20, 4/10/2023 2:27:19 PM Vertical schematic (actual) PRODUCTION; 31.2-8,621.7 FLOAT SHOE; 8,619.9-8,621.7 FLOAT COLLAR; 8,537.7- 8,539.4 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 NIPPLE; 8,147.8 SBE; 8,132.8 PACKER; 8,130.3 LOCATOR; 8,129.7 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 Window; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 Window; 7,949.0-7,953.0 HEW; 7,938.0 SOS; 7,806.3 NIPPLE; 7,794.6 PACKER; 7,778.3 PBR; 7,764.6 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 FLOAT SHOE; 2,378.1-2,380.0 FLOAT COLLAR; 2,295.4- 2,296.9 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 HANGER; 31.2-34.5 HANGER; 27.6 KUP PROD KB-Grd (ft) 39.00 RR Date 2/3/1983 Other Elev… 1E-20 ... TD Act Btm (ftKB) 8,650.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292089500 Wellbore Status PROD Max Angle & MD Incl (°) 48.52 MD (ftKB) 4,200.00 WELLNAME WELLBORE Annotation Last WO: End Date 7/23/1990 H2S (ppm) 90 Date 9/4/2017 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,945.0 8,094.0 6,210.1 6,324.9 C-4, C-3, C-2, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,349.0 8,362.0 6,521.5 6,531.6 A-5, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 8,382.0 8,410.0 6,547.1 6,568.8 A-4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns 1E-20, 4/10/2023 2:27:22 PM Vertical schematic (actual) PRODUCTION; 31.2-8,621.7 FLOAT SHOE; 8,619.9-8,621.7 FLOAT COLLAR; 8,537.7- 8,539.4 IPERF; 8,382.0-8,410.0 IPERF; 8,349.0-8,362.0 NIPPLE; 8,147.8 SBE; 8,132.8 PACKER; 8,130.3 LOCATOR; 8,129.7 GAS LIFT; 8,110.1 IPERF; 7,945.0-8,094.0 FISH; 7,979.0 FISH; 7,977.0 WINDOW; 7,961.0-7,965.0 Window; 7,961.0-7,965.0 WINDOW; 7,949.0-7,953.0 Window; 7,949.0-7,953.0 HEW; 7,938.0 SOS; 7,806.3 NIPPLE; 7,794.6 PACKER; 7,778.3 PBR; 7,764.6 CUT; 7,742.0 GAS LIFT; 7,714.8 GAS LIFT; 7,114.1 GAS LIFT; 6,453.2 GAS LIFT; 5,740.1 GAS LIFT; 5,056.0 GAS LIFT; 4,314.1 GAS LIFT; 3,447.9 SURFACE; 33.0-2,380.0 FLOAT SHOE; 2,378.1-2,380.0 FLOAT COLLAR; 2,295.4- 2,296.9 GAS LIFT; 2,209.7 SAFETY VLV; 1,822.0 CONDUCTOR; 34.0-110.0 HANGER; 31.2-34.5 HANGER; 27.6 KUP PROD 1E-20 ... WELLNAME WELLBORE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-13_22086_KRU_1E-20_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API # Log Description Log Date 22086 KRU 1E-20 50-029-20895-00 Archer Vivid Acoustic LDL 13-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 AOGCC 183005 32809 13 -Mar -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 1E-20 50-029-20895-00 906260886 Kuparuk Multi Finger Caliper Field&Proc 23 -Jan -20 0 1 2 1E-12 50-029-20736-00 906207895 Kuparuk Leak Detect with ACX Processed 30 -Dec -19 3 1E-12 50-029-20736-00 906190298 Kuparuk Plug Setting Record Final -Field 19 -Dec -19 0 1 4 1F-05 50-029-20807-00 906223186 Kuparuk Injection Profile Log Field&Proc 8 -Jan -20 0 1 5 1R -23A 50-029-22200-01 906228630 Kuparuk Mufti Finger Caliper Field&Proc 7 -Jan -20 0 1 6 WSW -11 50-029-20882-00 906310488 Shallow Sand Plug Setting Record Final -Field 12 -Feb -20 0 1 7 3G-05 50-029-20132-00 906174377 Kuparuk Packer Setting Record Final -Field 26 -Dec -19 0 1 8 3M-17 50-029-21729-00 906210841 Kuparuk Leak Detect Log Final -Field 29 -Dec -19 0 1 9 TN 02A 50-029-21527-01 906192001 Kuparuk Leak Detect Log Final -Field 23 -Dec -19 0 1 10,30-01 50-029-21836-00 906193765 Kuparuk Plug Setting Record Final -Field 20 -Dec -19 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS _ANC/ f ��@hhallibbuurrtton.com Date: t/ /Xyo Signed: DSR-4/9/2020 VTL 4/10/20 THE STATE 01ALASKA MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-20 Permit to Drill Number: 183-005 Sundry Number: 320-003 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the 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, VJ re . Price Chair DATED this day of January, 2020. RBDMS 9dJAN 13 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑' Pull Tubing ❑ Change Approved Program Ll Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casin _ 9 ❑ Other: Whipstock_❑-' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska Inc Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 183-005 3. Address: 6. API Number; PO Box 1003fi0, Anchorage AK 99510 50-029-20895 00 — O® 7. If perforating: 8. Well Name and Number: llrn What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No KRU 1E-20 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25651 Kupawk River Field / Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): V / Plugs (MD): Junk (MD): 8650' 6756' 8538' 6668' 2413 psi N/A 7980'/Abandoned lower completion Casing Length Size MO TVD Burst Collapse Structural Conductor 110' 16" 110' 110' 1640 psi 670 psi Surface 2380' 10-3/4" 2380' 2172' 3580 psi 2090 psi Production 8622' 7" 8622' 6734' 4980 psi 4320 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7945'- 8094' 6210' - 6325' 8349' - 8362' 6521' - 6532' 3-1/2" 9.3# J-55 7807' 8382'- 8410' 6547'- 6569' Packers and SSSV Type: Cameo TROP Locked Out Packers and SSSV MD (ft) and TVD (ft): SSSV: 1822' MD / 1747' TVD Baker HB Retrievable Packer: 7778' MD / 6081' TVD Baker FB -?.Permanent (Abandoned) Packer: 8130' MD / 6353' TVD 12. Attachments: Proposal Summary O Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/20/2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ` Authorized Name: James Ohlinger�"An' -.•--�� Contac[ Na Tde'James Hayes Authorized Title: Staff CTD Engineer Contact Email:.James.C.Ha eS CO .COM Contact Phone: 265-6927 Authorized Signature: Date: �O0/J/0"91 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 00 Plug Integrity ❑ BOP Test Q/ Mechanical Integrity Test ❑ Location Clearance E] .} Other: 7�oi7 Uf�vir�vla/ pi tv��iY✓ trsfi 1 v�G� �s y RBDMS � JAN 13 2020 Post Initial Injection MIT Req'd? Yes ❑ No 2 Spacing Exception Required? Yes No Subsequent Form Required: /&7 — 40 7 APPROVED Approved by: � COMMISSIONER � v THEHE COMMISSION Date: • J Form 10-403 evis d 201 A provy d9 pp p ication is Ii r 2 hfr m h ate of approval. Submit Form and Attachments in Duplicate 5V 0404v V_' ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 19, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to set a whipstock in KRU 1 E-20 (183-005) on rig to allow CTD operations to drill a dual -lateral out of the KRU 1 E-20 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached for KRU 1 E-20 to allow a whipstock to be set in order for these laterals to be drilled. Attached to this application are the following documents: — 10-403 Sundry Application to for KRU 1 E-20 — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6927. Sincerely, James Hayes ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1 E-20 CTD Summary for Setting Whipstock Sundry (10-4031 Summary of Operations: KRU well 1 E-20 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sand to the south of 1 E-20. The laterals will improve regional C -sand resource recovery. This well was attempted to be sidetracked back in 2017 but was unable to get a whipstock to stay in place. Nabors CDR3-AC will move onto location and rig up over 1 E-20. The rig will then run in and pull the 2-3/8" slotted liner so that a clean out run and caliper can be dropped. Next a whipstock can be oriented and set at the appropriate setting depth. Using the maximum formation pressure in the area of 3034 psi in 1 D-03, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2413 psi. CTD Drill and Complete 1E-20 Laterals: January 2020 Pre -CTD Work 1. No pre -rig will be required. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Pull 5 joints of 2-3/8" liner 3. Run in hole, clean out the well & tag fish top 4. Run a caliper 5. Set whipstock @ 7,938' MD 6. 1 E-201_1 Sidetrack (C sand - South) a. Drill 2.80" high -side pilot hole through cement to 7965' MD b. Caliper pilot hole c. Set top of whip -stock at 7938' MD d. Mill 2.80" window at 7938' MD. e. Drill 3" bi-center lateral to TD of 11400' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 9590' MD. 7. 1 E -20L1-01 Lateral (C sand - South) a. Kick off of the aluminum billet at 9590' MD. b. Drill 3" bi-center lateral to TD of 11300' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 91 00'MD. 8. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Pull BPV 2. Return to production Page 1 of 1 12/19/2019 KUP PROD WELLNAME 1E-20 WELLBORE 1E-20 ', Well Attributes Mex.Angle,&MD TD.. _ (onoeOPllillips JJJ Hela Name W 11 ra PPgn W lora Statue MDInKB) pelgtm ffom) Q(&Svl. In KUPARIMRIVER UNIT SOOJA.Oggsnn Comment H33 (ppm) sSGV: LOCKED OUT 90 Oate MActedon no Dale KB-Grd IX) Ry Ratease Data 91412017 LastWO'. ]12311990 39.00 2'3/1983 1E30. 1y11..Ii125991M Last Tag Venice' mnemalic Deep, Anwlallam Depth(XKBI End Dale .1Nwre Iasi Motl Dy Las(Tag: SUM 7,948.0 1 heam's 10 1E-20 Imasbor Last Rev Reason M,wtatlon Ena DEN Wellb,e Iasi Motl Dy Rev Reason_ Ch8nge Out GLV's 612412019 1E-20 J,humhmg Ing Strings CO'iDUCT0R; 714110.4 tesla, --apron OD(im Rahn' Top(pon at Depth hoKo sat Depth Too) ("I wu U n g... Graae Top rnreaa CONDUCTOR 16 15.25 34.0 110.0 110.0 65.no H-40 WELDED Casing Deehir IS on OD (in) to(ia) Tap SURFACE 10314 9.95 33.0 MKa) Set Depth 111KB) SN DepM nVDI 1... NNLen R Great Top Thaved 2,380.0 2,172.4 45 so K-55 STC BAFSTIVLV. Lena Casing Description Do (in) to (in) Top WINDOW 7 6.28 71949.0 lnKB) Sex Depth MR.) Sat Depth RVA) 1... WVLen ll... Grade Top Tbread 7,953.0 6216.3 Cee ing Descnpron CD (in) IDlin) Tap WINDOW ] 8.28 7,961.0 IPo(B) Set Depth INKS) Set Depth Bonn 1... Wa-en ll... Gratle Top Thread 7,965.0 6,225.5 GFS LIFT: 2.2W.J Cas Ing Descopnon Do (in) 10(in) TOP(NKB) PRODUCTION J 6.28 31.2 Se[DePmot B) Sit Cape lrvDl l... WULenGraae Tap TMeaa 8.621] 6,733.7 26.00 K-55 BTC Tubing Strings Tubing Description 6lring Max.. to (in) Tap (flKD) TUBING WO 31/2 2.99 27.6 Sel Oepe X... Setup hiNDI IN. W[Dblh) Gratle Top Connection 7,80].0 fi,103.2 9.20 J-55 BTGMOD SURFACE, Sao-?3mD Completion Details LIFT 3,41]9 ToptlVDl Tap(XK1g (nlcDl Tap Inu l-1 IRm Des Bea une)GAB Com Rale) 27.6 228 0.06 HANGER FMC GEN III TUBING HANGER 3.500 Gas LIFT: 4.314.1 1,822.0 1,]4].5 33.55 SAFETY VLV CAMCG TROP -IA -SSA SAFETY VALVE- LOCKED OUT WJW2000 2.812 (FLOW TUBE ONLY) GAS LIFTi Shoe. 7,764.6 6,070.2 38.81 PBR BAKER PSR wl10'STROKE 3.000 7,778.3 6,080.9 38.89 PACKER BAKER He RETRIEVABLE PACKER gg90 GAS LIFT, 7794.6 6,093.6 38.99 NIPPLE CANSO D NIPPLE NO GO(MILLED 3/1 712 01 1) VRISI GAS UFT, 6,4532 ],8 06.3 5,102.6 39.04 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT. 7,,114.1 Tubing Deaciiptien 6eng Mex.. IO (in) Tap IflKD) Sat Dep h IX... Set Depth Boom (N., pot lb Gratle TaP Conn .M TUBING ABANDONED 312 2.99 8,098.0 8,1600 6,3>5.8 9.30 J-55 BTCMOO Cdpapletion Details Tap (NDI Top(flKR (ft KD) Top Incl l-) Itam Des corn IO pal NO GAS LIFT, 7,714.8- 8.098.0 6,328.0 39.5] BLAST JT SHATTERED I'OF SLAST JOINT LEFT ON TOP OF ABANDONED 2.992 1 TUBING COMPLETION 8,129.7 6,352.4 39.58 LOCATOR BAKER LOCATOR 4.000 8,130.3 6,352.8 1 39.58 1 PACKER BAKER FBA PACKER 4.000 8,1328 6,354.8 1 39.58 SBE BAKER SEAL BORE ERTENSION 3.500 8,1428 6,3664 39.58 NIPPLE CAMCO'D'NIPPLE 2.006 Padi777da 8,159.3 611,375.2 39.59 SOS BAKER SHEAROUT SUB 2938 Other In Mole (Wireline re plugs, valves, pumps, fish, OUT Top UVDl Top Incl Top(XKS) (DR., (-) nes Com Run Daro RaLI 7,980 fi,234.8 39.59 FISH 3-1)2' by 7'higM1 32&201] 2.500 expansion Wedge whipstock. Depth bodbe 7977' 7,9790 6,236.3 39.59 F 3112"by>°high 31312017 2.500 expansion evedgewfiipslack. Depth below 7977' WINDOW, 7,90.9,67,913.0 13eftratlons & Slots TOPR- Dtm lrVO) Dens WINNWI u.e Uner Pel:Snxe- 9 .0 sn11- Top (XKat Stm 11MB) (XpKD) IXKB) In. Zone Dam (abotsHl) ryp¢ Com 7,945.0 8,094.0 6,210.1 6.324.9 C -4,C 0 -3,C-2, 1E 2/211983 4.0 IPERF 90 deg. Pb; OA 4"ag guns JI Fla.V..77g 8,349.0 8,382.0 a_IB 6,531.8 A -6,1E-20 2Y1/1983 4A IPERF 90 deg. Phi DA A -can guns FmL7.oGd 8,382.0 8,410.0 6.547.1 GPWL8 A<, 1E-20 2'2/1983 1 4.0 1 IPERF 190 ae0, Ph; DA 4"csg guns IPERF: 7,9edut-6034.0 Mandrel Inserts SI an Top(Nn) No icp IXKE) INKB) Make It a[ wive Lafcb Pmt Size TRO Run ODlinl Sery Type Type (In) Ipsil Run Data Cam 1 2,209) 2,046.0 BANCO KBUG 1 GASLIFF IBK 0.313 1,250.0 61248019 2 3,447.9 I 2,931.7CAMCO KBUG I 1 ISAR NET GLV BK 0.188 1,231.0 6242019 GA61FTB,ttpt 3 4,314.Y 3,526] CAMCG KBUG 1 GAS LIFT GLV BK 0.188 1,283.0 W2312019 4 5,056.0 4,Od4.2 CAMCG KBUG 1 GAS LIFT OV BK 0.188 0.0 612312019 5 5,740.1 4,530.6 CAMCO KRUG 1 GA6LIFT DMV BK 0.000 0.0 301201] 6 6,4533 5,055.7 CAMCG KBUG 1 GAS LIFT OMI BK GOOD DO 91262007 7 7,114.1 5,562.3 CAMCG KBUG 1 GAS LIFT DMY BK 0.000 0.0 7,OSU990 - 8 ],]14.8 6,031.3 CAMCO MMG-2 11)2 GAS LIFT DMV BK 0.000 0.0 SSYNBRO - 9 8,110.1 6,337.3 CAMCG GAS LIFT DMV BK 0.000 0.0 2311983 In Tubing Abend on ales: General & Safety - 3/311201] NOTE: 2 sWINW SDluOans High Expansion Wedge Whipstock LEFT IN HOLE. 1111820111 NOTE: VIM Schematic W/ Alaska Schemmki IPERF; 8,34909,aGd0 IPERF:6.1920$410.0- PROCHON.312$621.7� W \} { ZD � )\ k ! - �# }2 cq \( � {\ \) § \ \ \\ } \ \ \} { \ � )\ k ! - �# }2 Loepp, Victoria T (CED) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Thursday, January 9, 2020 6:26 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 E-20(PTD 183-005, Sundry 320-003) Set Whipstock; BOP test pressure I would be requesting 3,500 psi for the high side of the BOPE test. v Thanks, James Hayes C: +1918.914.9609 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 8, 2020 11:03 AM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: [EXTERNAL]KRU 1E-20(PTD 183-005, Sundry 320-003) Set Whipstock; BOP test pressure James, What is the BOP test pressure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. Loepl)(5alas ka.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). it may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loeco@alaska aov RECEIVED STATE OF ALASKA • ALAS OIL AND GAS CONSERVATION COMMISSIO. APR 2 7 7017 REPORT OF SUNDRY WELL OPERATIONS A rCC 1.Operations Abandon CI Plug Perforations CI Fracture Stimulate CI Pull Tubing El Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Failed Add Lat'l 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑❑ 183-005 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-029-20895-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 KRU 1 E-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,650 feet Plugs measured None feet true vertical 6,756 feet Junk measured 7977 7979 feet Effective Depth measured 8,538 feet Packer measured 7778,8130 feet true vertical 6,668 feet true vertical 6081,6353 feet Casing Length Size MD TVD Burst Collapse Conductor 76 16 110 110 Surface 2,347 10 3/4 2,380 2172 Intermediate Production 8,591 7 8,622 6734 Liner Perforation depth Measured depth 7945-8094, 8349-8362,8382-8410 True Vertical depth 6210-6325,6521 -6532,6547-6569 Tubing(size,grade,measured and true vertical depth) 3.5 J-55 7807 6013 Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER HB RETRIEVABLE PACKER 7778 6081 PACKER-BAKER FB-1 PACKER 8130 6353 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY 1822 1747 VALVE-LOCKED OUT 6/19/2000(FLOW TUBE ONLY) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 270 331 1406 1277 224 Subsequent to operation: 294 205 1667 890 234 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ DevelopmentP Service D Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Name: Keith Herring Authorized Name:Keith Herring Contact Email: Keith.E.Herring@conocophillips.com Authorized Title: CTD Engineer Contact Phone: (907)263-4321 Authorized Signature: Date: i/i/ Z /, Form 10-404 Revised 4/2017 RBDI��S �/ MAY 101 ORIGINALbmit Original Only • Haggerty-Sherrod, Ann (Northland Staffing Services) • From: Herring, Keith E Sent: Thursday,April 13, 2017 9:01 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services);Conklin,Amy A(Swift Technical Services LLC); Kanady, Randall B Subject: FW: KRU 1E-20 CTD Sidetrack Please see below for what kind of form to submit to the State for the 1E-20 CTD Sidetrack. Thanks, Keith From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,April 12,2017 12:47 PM To: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]RE: KRU 1E-20 CTD Sidetrack Keith, A 10-404 for the work performed on the motherbore 1E-20 is all that is needed. Include a description of what occurred as outlined in your email below. Thanx, Victoria From: Herring, Keith E [mailto:Keith.E.Herring@conocophillips.com] Sent:Wednesday,April 12,2017 9:27 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com>;Conklin,Amy A(Swift Technical Services LLC)<Amy.A.Conklin@contractor.conocophillips.com> Subject: KRU 1E-20 CTD Sidetrack Good morning Victoria, I am inquiring as to what kind of form (10-407 or 10-404)the State of Alaska would like for me to submit for the KRU 1E-20 CTD Sidetrack? The following is a description of operations during the window milling process: The first whipstock was ran in hole and set at 7956' MD and a window was milled in the 7" production casing. When we went to drill the build section we were unable to exit the window due to the whipstock falling downhole in the parent wellbore. This was confirmed with a dedicated downhole camera run. A second whipstock was set at 7945' MD and a second window was milled in the 7" production casing. Again,we were unable to exit the window with our build BHA and confirmed that the 2"d whipstock fell downhole as well when a dedicated logging run was conducted. We then picked up and ran 2-3/8"tubing into the parent wellbore well leaving the bottom of tubing on top of the whipstocks that fell down hole in the parent wellbore at 7977' MD. The top of the 2-3/8" liner was left in the 3-1/2"tubing at 7776' MD. Below is an email from Baker Hughes stating that due to the whipstocks falling downhole we were unable to drill the 1E-20L1 lateral and obtain surveys. I have attached the CTD schematic for your viewing purposes. Thanks for your help on the matter and I look forward to your reply. Keith Herring 1 CTD Engineer • 907.263.4321(Office) 907.570.2410(Mobile) 700 G Street,ATO—664 Keith.E.Herring@conocophillips.com Collo Mips From:Soper, Michael K(Baker Hughes INTEQ) Sent:Tuesday,April 11,2017 4:10 PM To: Herring, Keith E<Keith.E.Herring lconocophillips.com> Cc: 'yosha.ragbirsingh@bakerhughes.com'<yosha.rakbirsingh@bakerhughes.com> Subject: 1E-20 CTD- No EOW Surveys Keith, Per our earlier conversation,due to the whipstock falling downhole we were unable to drill the 1E-20L1 lateral and obtain surveys. I do not plan to distribute any EOW surveys for the 1E-20 CTD laterals. Thanks, Michael Soper I Well Planner Baker Hughes I Drilling & Evaluation (INTEQ) I US Land I Alaska Office: 1.907.263.4794 I Fax: 1.918.886.6390 Cell: 1.907.242.3360 I michael.sopera,bakerhughes.com http://www.bakerhughes.com I Advancing Reservoir Performance 2 S Operations Summary (with Timelog Depths) 1E-20 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 3/22/2017 3/22/2017 6.00 MIRU MOVE RURD P Install horses head and CTES 0.0 0.0 00:00 06:00 counter.Remove 1 ft section of riser. Grease valves in preparation for upcoming BOP test. Service module:Arrived at 2L pad at 03:30.Refueled trucks and carried on, 0500 @ 2S pad 3/22/2017 3/22/2017 6.00 MIRU MOVE RURD P 06:24 @ 2M pad,crew change.Install 0.0 0.0 06:00 12:00 pressure bulkhead,Blow air through tiger tank line,adjust goose neck, install coil connector. 3/22/2017 3/22/2017 6.00 MIRU MOVE RURD P Exit spine and enter 1E-20 access 0.0 0.0 12:00 18:00 road @ 12:29. On pad and drop the jeep @ 14:00 Spotted pits @ 3:30,comms up. Crew change and town presentation. 3/22/2017 3/22/2017 2.50 MIRU WHDBOP CTOP P Finish town presentation.RU and pull 0.0 0.0 18:00 20:30 test CTC to 35KIbs.Head up UQC and test e-line.Good test. 3/22/2017 3/23/2017 3.50 MIRU WHDBOP CTOP P RU Hot Oil.PT line.Pump 5 bbl 0.0 0.0 20:30 00:00 methanol spear into coil at 0.25 BPM. Fluid pack stack and shell test to 3,500 psi. MU nozzle.Stab injector on well. Rig accept at midnight. 3/23/2017 3/23/2017 3.00 MIRU WHDBOP RURD P Fluid pack CT.Pumping slack forward 0.0 0.0 00:00 03:00 (50 bbls seawater at 2.0 bpm). Shut down.Test inner reel iron.Pick up injector.Move cart back. Install night cap. 3/23/2017 3/23/2017 10.00 MIRU WHDBOP BOPE P Begin state witness BOPE test. 0.0 0.0 03:00 13:00 Suspect master valve leaking,bypass testing continue to choke valves and call grease crew. Grease crew on location,service tree,still have leak. Troubleshoot,determine leak path to be R1,backward into the managed pressure line. Service valve.carry forward. Rig on High line power @ 10:00. 3/23/2017 3/23/2017 7.00 MIRU WHDBOP BOPE P Service tree valves.Try to test. 0.0 0.0 13:00 20:00 Service tree valves again. Good test. Post test greasing of BOPE.PT CT/UQC. 3/23/2017 3/23/2017 2.00 MIRU WHDBOP PRTS P Pressure test ODS and DS PDL. 0.0 0.0 20:00 22:00 Good test. 3/23/2017 3/24/2017 2.00 MIRU WHDBOP MPSP P PJSM with Valve Crew.RU lubricator. 0.0 0.0 22:00 00:00 Test to 2,000 psi.Pull BPV.RD lubricator and BPV. 3/24/2017 3/24/2017 2.10 MIRU WELLPR DISP P Pressure test UQC.Install nozzle and 0.0 0.0 00:00 02:06 stab on injector.Displace CT to seawtater. Pumped 50 bbls at 3.0 bpm while displacing for additional slack management. 3/24/2017 3/24/2017 4.10 PROD1 RPEQPT PULD P PU BHA#1 NS HEW whipstock. 0.0 54.0 02:06 06:12 Identified WS has a ball on seat configuration.Re configure BHA to PU a nozzle and RIH to roll hole to seawater and evaluate pore pressure. 3/24/2017 3/24/2017 0.40 PROD1 RPEQPT PULD P Surface pressure reading 1400 psi. 54.0 54.0 06:12 06:36 Bleed gas,Surface pressure 400. Page 1/8 Report Printed: 4/25/2017 •5 • Operations Summary (with Timelog Depths) Afthit,1714' ConocoPhiilips . v Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/24/2017 3/24/2017 0.40 PROD1 RPEQPT PULD P Tag up,Set depths,continue to bleed 54.0 54.0 06:36 07:00 off,all gas. 3/24/2017 3/24/2017 0.90 PROD1 RPEQPT TRIP P RIH 54.0 4,372.0 07:00 07:54 3/24/2017 3/24/2017 0.30 PROD1 RPEQPT TRIP P Notice the chain tensioning system on 4,372.0 4,200.0 07:54 08:12 the injector is bouncing more so on the reel side than the off reel side. Investigate/trouble shoot. Pull out of hole to observe pipe/ensure no damage. 3/24/2017 3/24/2017 0.90 PROD1 RPEQPT TRIP P Continue to RIH,pumping 0.5 bpm, 4,200.0 7,798.0 08:12 09:06 taking returns to the tiger tank. 3/24/2017 3/24/2017 0.50 PROD1 RPEQPT DLOG P Tie into tthe K1 for a-2'correction. 7,798.0 7,858.0 09:06 09:36 3/24/2017 3/24/2017 0.20 PROD1 RPEQPT DLOG P PUH to perform CCL log,close EDC. 7,858.0 7,725.0 09:36 09:48 3/24/2017 3/24/2017 0.40 PROD1 RPEQPT DLOG P Perform CCL log,SD @ 7983 CTMD. 7,725.0 7,983.0 09:48 10:12 3/24/2017 3/24/2017 0.40 PROD1 RPEQPT DISP P PUH slowly while displacing the well 7,983.0 7,925.0 10:12 10:36 to seawater taking returns to the tiger tank, PU wt,33.5k. 3/24/2017 3/24/2017 0.20 PROD1 RPEQPT DISP P Something amiss with the baker 7,925.0 7,925.0 10:36 10:48 depth,stop and start to troubleshoot/ fix. 3/24/2017 3/24/2017 0.80 PROD1 RPEQPT DISP P Continue to POOH displacing well to 7,925.0 7,766.0 10:48 11:36 seawater 3/24/2017 3/24/2017 0.90 PROD1 RPEQPT DISP P Lock out injector,mark and measure 7,766.0 7,683.0 11:36 12:30 chain sprocket to troublshoot bounce in chain tension/traction hydraulics. Verifyed blocks are all 2". Returns continue to be gas cut. roll injector to mark sproket. 3/24/2017 3/24/2017 0.30 PROD1 RPEQPT DISP P park,with 8.55 ppg in and out, 7,683.0 7,683.0 12:30 12:48 although the out MM hasnt been holding steady. BHP 2768 psi @ 7683 MD. WH stabilized at 70 psi. 3/24/2017 3/24/2017 3.00 PROD1 RPEQPT DISP P Circulate seawater @ 1.7 bpm,0.6 7,683.0 7,793.0 12:48 15:48 bpm returns until)MM out stabilized. run to tubing tail and bullheaded 38 bbl 100 k Cp LSR pill down the back side,under displaced with 36 bbls 6.6 ppg seawater. Left-5 bbls in the seven inch. Bleed IA from 1081 psi to 834 psi. 3/24/2017 3/24/2017 0.60 PROD1 RPEQPT DISP P S/I well and observe pressures. WH 7,793.0 7,793.0 15:48 16:24 153 psi,Baker 2911 psi. Well head fell and stabilized @ 90 psi Baker 2857 psi. 3/24/2017 3/24/2017 4.00 PROD1 RPEQPT DISP P Bring pumps online min rate,PUH 50', 7,793.0 7,793.0 16:24 20:24 ease choke open holding managed pressure,drop in out MM density and flow rate,suspwect gas,Shut in,wait for TT returns to be emptied. Pumping 1.4 bpm,WH 80 psi,crack choke,Ship returns outside. Page 2/8 Report Printed: 4/25/2017 • • s m Operations Summary (with Timelog Depths) tr Y e�=•-111,0o 1 E-20 CcoPhitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code', Time P-T-X Operation (ftKB) End Depth MKS)` 3/24/2017 3/24/2017 0.30 PROD1 RPEQPT DISP P PUH.Circulate well with seawater and 7,793.0 7,605.0 20:24 20:42 monitor returns.Varied rate in from 1.0 bpm to 1.8 bpm. Rate out consistent at 0.8 bpm. Perform second SBHP test.Close choke,pumps off.Surface pressure 100psi,MW=8.6 ppg,TVD of PWD =5055 ft TVD rkb.Pore pressure calculated at 9.0 ppgemw.PWD pressure calculated 9.2 ppgemw. 3/24/2017 3/24/2017 1.30 PROD1 RPEQPT TRIP P POOH with BHA#1. 7,605.0 53.0 20:42 22:00 3/24/2017 3/24/2017 1.50 PROD1 RPEQPT PULD P PJSM.PUD BHA#1. 53.0 0.0 22:00 23:30 3/24/2017 3/25/2017 0.50 PROD1 RPEQPT PULD P PJSM.PU Northen Solutions High 0.0 73.0 23:30 00:00 Expansion Wedge Whipstock.and PD BHA#2. 3/25/2017 3/25/2017 1.00 PROD1 RPEQPT PULD P Finish PD BHA#2 with Northen 73.0 73.0 00:00 01:00 Solutions High Expansion Wedge Whipstock. 3/25/2017 3/25/2017 2.50 PROD1 RPEQPT TRIP P RIH with BHA#2 at 80 fpm per 73.0 7,964.0 01:00 03:30 Northen Solutions.Tie-in to the K1 for a-1.5 foot correction.Continue in the hole to set depth.of 7964.78 ft(TOWS 7956 ft).PUW 34 Klbs.Orientation 0° HS.Close EDC. 3/25/2017 3/25/2017 1.00 PROD1 RPEQPT WPST P Attempt to set WS.Stage up rate to 7,964.0 7,964.0 03:30 04:30 1.9 bpm.Not able to achive setting differential.Open EDC flush and close again.Good indication of closing EDC. Bring rate back up to 1.9 bpm. Circulating pressure 4100 psi,diff pressure=768 psi.Need 2500 psi diff pressure to set. Made decsion to POOH and inspect BHA. 3/25/2017 3/25/2017 2.00 PROD1 RPEQPT TRIP T POOH with 3-1/2"x 7"WS. 7,964.0 52.0 04:30 06:30 3/25/2017 3/25/2017 1.00 PROD1 RPEQPT PULD T Pre job safty meeting,bump up,space 52.0 0.0 06:30 07:30 out,PUD BHA#2. 3/25/2017 3/25/2017 0.20 PROD1 RPEQPT PULD T Hang BHA in PDL,lay down 0.0 0.0 07:30 07:42 Whipstock and Al setting tool. 3/25/2017 3/25/2017 2.20 PROD1 RPEQPT PULD T Break Whipstock at setting tool,whip 0.0 0.0 07:42 09:54 stock guide arms tried to extend a small amount,+/-0.25". Air tested setting tool,leak. Disassembled found tool to be assembled incorrectly,o- ring sub inserted upside down. Hot shot new o-rings from Y pad shop, rebuild setting tool. Clean and reset Whipstock. 3/25/2017 3/25/2017 1.40 PROD1 RPEQPT PULD T PJSM,PU setting tool and WS,PD 0.0 52.0 09:54 11:18 BHA#3 3/25/2017 3/25/2017 2.00 PROD1 RPEQPT TRIP T RIH w/BHA#3, EDC open,pumping 52.0 7,800.0 11:18 13:18 min rate at 80 fpm per Northen Solutions. 3/25/2017 3/25/2017 0.20 PROD1 RPEQPT TRIP T Tie-in to the K1 for a-2.0 foot 7,800.0 7,874.0 13:18 13:30 correction. Page 3/8 Report Printed: 4/25/2017 0 0 00 Operations Summary (with Timelog Depths) ,,a 1E-20 Ph�ff,ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/25/2017 3/25/2017 0.30 PROD1 RPEQPT TRIP T Wt check 32.5 k lbs,Continue in the 7,874.0 7,964.0 13:30 13:48 hole to set depth.of 7964.66ft(TOWS 7956 ft).Orientation 0°HS. PUW 30 Klbs. Close EDC. Online w the pumps,0.5 bpm,stage up to 100, 1500,200',sheared at-2600 lbs. 3/25/2017 3/25/2017 1.00 PROD1 RPEQPT CIRC P PUH to tubing tail,open EDC,swap 7,964.0 7,783.0 13:48 14:48 coil/welbore to viscosified seawater. 3/25/2017 3/25/2017 1.70 PROD1 RPEQPT TRIP P Start pulling out of hole. 1.35 bpm in 7,783.0 68.0 14:48 16:30 0.60 bpm out,milling fluid at surface, 15:23,6271' @ 2000'pulling 110 ft/min, 1.36 bpm in,0.83 bpm out,0.4 bpm pipe voidage. 3/25/2017 3/25/2017 1.50 PROD1 RPEQPT PULD P PJSM,bump up,PUD BHA#3. LD 68.0 0.0 16:30 18:00 running tools. 3/25/2017 3/25/2017 2.00 PROD1 WHPST PULD P Crew change.PJSM PU/PD BHA#4, 0.0 76.0 18:00 20:00 milling assembly with 1°Weatherford fixed bend motor and 2.80"mill and string reamer. 3/25/2017 3/25/2017 1.50 PROD1 WHPST TRIP P RIH with BHA#4.Tie-in to the K1 for a 76.0 7,962.0 20:00 21:30 -2.5 ft correction.Continue running in the hole.Close EDC.Check weight, 34 Klbs.Dry tag pinch point at 7960.7 ft.(TOWS=7456 ft) 3/25/2017 3/26/2017 2.50 PROD1 WHPST WPST P PU, start pump 1.7 BPM.Free spin 7,962.0 7,963.0 21:30 00:00 509 psi.Confirm HS orientation.RIH and begin milling. Mill first 2 feet with 500lbs WOB.Differential pressure= 645 psi.Continue milling autodrill at 1 fpm.Continue milling per Northern Solutions Rep.Return rate 0.65 bpm. 3/26/2017 3/26/2017 4.20 PROD1 WHPST WPST P Continue milling window per Northern 7,963.0 7,966.0 00:00 04:12 Solutions rep and Weatherford rep. Pumping 1.7 bpm at 3580 psi.Return rate 0.7 bpm.Near stall @ 7964.7, WOB drilled off. 3/26/2017 3/26/2017 1.40 PROD1 WHPST MPSP P Milling rat hole,increase weight on bit 7,966.0 7,985.0 04:12 05:36 to 4-3k lbs. two stalls,7975'& 7979.8'. BOW 7964.7' 3/26/2017 3/26/2017 0.50 PROD1 WHPST REAM P Backream up,down,up @ highside, 7,966.0 7,970.0 05:36 06:06 dry drift,clean. 3/26/2017 3/26/2017 1.60 PROD1 WHPST TRIP P Open EDC,POOH 7,970.0 81.0 06:06 07:42 3/26/2017 3/26/2017 1.30 PROD1 WHPST PULD P PJSM,tag up,space out,PUD,BHA* 81.0 0.0 07:42 09:00 4,LD. 3/26/2017 3/26/2017 0.70 PROD1 DRILL PULD P Change out tools 0.0 0.0 09:00 09:42 *Speed mill 2.80"No Go String Mill 2.79"No Go 3/26/2017 3/26/2017 0.70 PROD1 DRILL CIRC P Make up nozzle and jet stack. 0.0 0.0 09:42 10:24 3/26/2017 3/26/2017 1.50 PROD1 DRILL PULD P PJSM,PD BHA#5 0.0 72.0 10:24 11:54 3/26/2017 3/26/2017 1.70 PROD1 DRILL TRIP P Bump up,set depth,RIH. 72.0 7,800.0 11:54 13:36 3/26/2017 3/26/2017 0.20 PROD1 DRILL DLOG P Tie into K1 for-2'correction. 7,800.0 7,850.0 13:36 13:48 Page 4/8 Report Printed: 4/25/2017 • • Operations Summary (with Timelog Depths) ,, 1E-20 ConocoPhithhp Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (W6); End.Depth(ftKS)'. 3/26/2017 3/26/2017 0.20 PROD1 DRILL TRIP P Continue to RIH,Stop,Close EDC, 7,800.0 7,973.0 13:48 14:00 run through window at 10'/min, pass through window,clean. S/D @ 7973' 5.7k,PU 32k lbs, PUH,RBIH 3/26/2017 3/26/2017 4.00 PROD1 DRILL DRLG P Set drilling rate at 1.4 bpm,0.27 bpm 7,973.0 7,983.0 14:00 18:00 out,CT 2168 psi,259 diff. pass easily by 7973'w little motor work. Stage up to 1.47 bpm,0.35 bpm out,CT 2340 psi,295 psi diff, 13.6 k lbs RIHWt. Tag up 7982'stall,PU,33k lbs.adjust rate to 1.5/0.42 bpm out. stall 7982.69',Drill slowly to 7983.29 with multiple stalls. Pump rate 1.81 bpm, 0.64 bpm out. 3/26/2017 3/26/2017 0.70 PROD1 DRILL DRLG P Crew change.Continue to try and 7,983.0 7,983.0 18:00 18:42 work BHA down and drill ahead.Could not get past 7983 ft. 3/26/2017 3/26/2017 1.00 PROD1 DRILL TRIP P PUH to 7840 ft.Log the K1 and 7,983.0 7,983.0 18:42 19:42 confirm previous tie-in.+0.5 ft. RBIH. Stack out at 7973 ft.PU to 7953 ft, orient 180°ROHS. RBIH slowly and tag up at 7965 ft with 1.1 Klbs WOB. Discuss plan forward.Made decision to POOH and inspect BHA. 3/26/2017 3/26/2017 1.50 PROD1 DRILL TRIP P POOH with BHA#5.Clean trip up 7,983.0 72.0 19:42 21:12 through the window.No bobbles. 3/26/2017 3/26/2017 1.50 PROD1 DRILL PULD P PJSM. PUD BHA#5.Bit grade 4-6-BT 72.0 0.0 21:12 22:42 -A-X-I-CT-HP.Reamer blade cutters chipped.Nose area of the bit beginning to ring out. 3/26/2017 3/27/2017 1.30 PROD1 DRILL PULD P PJSM. PU and PD BHA#6 with a 2" 0.0 42.0 22:42 00:00 nozzle and DGS. 3/27/2017 3/27/2017 0.50 PROD1 DRILL RURD P Continue PD BHA#6. 42.0 42.0 00:00 00:30 3/27/2017 3/27/2017 1.50 PROD1 DRILL TRIP T RIH with nozzle BHA#6.Tie-in to K1 42.0 7,950.0 00:30 02:00 for a-3 foot correction.Close EDC. Continue in the hole. 3/27/2017 3/27/2017 0.90 PROD1 DRILL DLOG T Log RA on whipstock 9 feet deeper 7,950.0 7,983.0 02:00 02:54 than planned at 7972 ft.New top of WS is 7965 ft.Hard tag at 7983 ft.No issues though window area. 3/27/2017 3/27/2017 2.10 PROD1 DRILL TRIP T POOH with BHA#6.Clean pull 7,983.0 42.0 02:54 05:00 through window. 3/27/2017 3/27/2017 1.50 PROD1 DRILL TRIP T PUD,BHA#6,Nozzle/DGS run 42.0 0.0 05:00 06:30 3/27/2017 3/27/2017 1.50 PROD1 DRILL WAIT T Discuss plan forward w town 0.0 0.0 06:30 08:00 engineering. 3/27/2017 3/27/2017 11.50 PROD1 DRILL WAIT T Gearing up for camera run. Wait on 0.0 0.0 08:00 19:30 EVO operator and equipment. 3/27/2017 3/27/2017 1.50 PROD1 DRILL PULD T LRS,on location w filter pots(3 0.0 0.0 19:30 21:00 micron)spotting up/rigging up.2x290 lake water in ultra clean vac trucks staged up. EVO testing tools in the pipe shed. 3/27/2017 3/27/2017 2.00 PROD1 DRILL PULD T EVO continues to test tools and 0.0 0.0 21:00 23:00 modify shroud to cover camera. 3/27/2017 3/28/2017 1.00 PROD1 DRILL PULD T PJSM,PU BHA#7 camera BHA,PD. 0.0 0.0 23:00 00:00 Page 5/8 Report Printed: 4/25/2017 • # ° ' ? F Operations Summary (with Timelog Depths) 10 3 1E-20 Co v cod't itihps . Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/28/2017 3/28/2017 3.50 PROD1 DRILL PULD T Lost communication with camera. 0.0 0.0 00:00 03:30 Unstab injector.LD camera BHA and troubleshoot. Reconfigured BHA several times with backup camera adaptor,LOC,and back up camera several times.Found combination that worked. 3/28/2017 3/28/2017 0.50 PROD1 DRILL PULD T MU BHA#7 with comera.Confirm 17.0 17.0 03:30 04:00 operational.PJSM with LRS and vac truck drivers. Displace CT to filtered lake water. 3/28/2017 3/28/2017 3.00 PROD1 DRILL TRIP T Pump filtered lake water ahead of the 17.0 7,845.0 04:00 07:00 camera. RIH bullheading clear fluid ahead of the BHA.Tie-in to tubing tail for a-0.75 ft correction.Continue in the hole to area of interest. 3/28/2017 3/28/2017 2.50 PROD1 DRILL DLOG T Record camera images around 7,845.0 7,975.0 07:00 09:30 window/whipstock setting area. Footage indicates body lock ring failure caused the whipstock to fall downhole at some point after cutting the window. Camera data in well file. 3/28/2017 3/28/2017 2.50 PROD1 DRILL TRIP T Offline with LRS and lake water.Bring 7,975.0 17.0 09:30 12:00 up rig pump and begin pumping viscosified seawater.POOH with camera BHA. 3/28/2017 3/28/2017 1.50 PROD1 DRILL PULD T Tag up.Close master and swab.Lay 17.0 0.0 12:00 13:30 down camera BHA. 3/28/2017 3/28/2017 4.50 PROD1 DRILL WAIT T Begin rigging down.Conference call 0.0 0.0 13:30 18:00 with town on plan forward. 3/28/2017 3/29/2017 6.00 PROD1 DRILL WAIT T Prep for possible rig move-Rig work 0.0 0.0 18:00 00:00 orders-PM's 3/29/2017 3/29/2017 6.00 PROD1 DRILL WAIT T Continue to wait on orders/whipstock 0.0 0.0 00:00 06:00 modifications.Continue on rig PM's and inspections. 3/29/2017 3/29/2017 6.00 PROD1 DRILL WAIT T Continue to wait on orders/whipstock 0.0 0.0 06:00 12:00 modifications.Service blocks. Housekeeping in halfway house and shop. Adjust tilt indicator on mast. 3/29/2017 3/29/2017 5.00 PROD1 DRILL WAIT T Continue to wait on orders/whipstock 0.0 0.0 12:00 17:00 modifications.Update Epoch system in pits.Continue reviewing and updating procedures. 3/29/2017 3/30/2017 7.00 PROD1 DRILL BOPE T Start full BOPE Test,Test witnes 0.0 0.0 17:00 00:00 waived by Guy Cook,AOGCC 3/30/2017 3/30/2017 1.00 PROD1 DRILL BOPE T Complete BOPE test, Perform draw 0.0 0.0 00:00 01:00 down test 3/30/2017 3/30/2017 2.50 PROD1 'RPEQPT PULD T PJSM,Prep floor for CT ops.M/U 0.0 73.5 01:00 03:30 BHA#8 NES 3 1/2 X 7"whipstock and pressure deploy.Make up coiltrak to coil and surface test.Inspect pack offs 3/30/2017 3/30/2017 2.50 PROD1 RPEQPT TRIP T RIH,EDC open,pumping min rate,80 73.5 7,894.0 03:30 06:00 FPM max,tracking high side.Stop and close EDC.Tie in to the K1 for a- 1 ft correction. Page 6/8 Report Printed: 4/25/2017 ! ! tit 0 Operations Summary (with Timelog Depths) 1E-20 sono r"[liips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/30/2017 3/30/2017 0.10 PROD1 RPEQPT WPST T Position whipstock on depth.PU to 7,894.0 7,948.0 06:00 06:06 30KIbs.Bring up pump and set whipstock per Northern Solutions rep. Whipstock set at 3100 psi. 3/30/2017 3/30/2017 1.60 PROD1 RPEQPT TRIP T POOH with wedge running tools,BHA 7,948.0 75.0 06:06 07:42 #8. 3/30/2017 3/30/2017 1.00 PROD1 RPEQPT PULD T PUD BHA#8. Running tools in good 75.0 0.0 07:42 08:42 condition. 3/30/2017 3/30/2017 1.70 PROD1 WHPST PULD T PU and PD BHA#9,window milling 0.0 76.0 08:42 10:24 BHA with Weatherford 1°fixed bend motor,2.79"no-go string reamer and new 2.80 window mill. 3/30/2017 3/30/2017 2.50 PROD1 WHPST TRIP T RIH with BHA#9.Tie-in to the K1 for a 76.0 7,949.0 10:24 12:54 -2.5 ft correction.Dry tag whipstock at 7950 ft. 3/30/2017 3/30/2017 6.00 PROD1 WHPST WPST T PUH. Bring pumps up to 1.7 bpm. 7,949.0 7,955.1 12:54 18:54 Free spin differential 500 psi. RBIH and begin milling per program.Call initial pinch point 7949.5,BOW @ 7952.7.Continue time milling to get string reamer out.Geo has confirmed formation in two seperate samples 3/30/2017 3/30/2017 2.60 PROD1 WHPST WPST T Mill rat hole, Increase ROP, 1.7 BPM 7,952.7 7,974.0 18:54 21:30 @ 2820 PSI FS 3/30/2017 3/31/2017 2.50 PROD1 WHPST REAM T Begin reaming passes Haveing 7,974.0 7,974.0 21:30 00:00 stalling and stacking issues @- 7953',Continue to remove suspected lip at bottom of window.Able to dry drift but not go through with pumps on. Continue reaming and cleaning up window 3/31/2017 3/31/2017 2.10 PROD1 WHPST REAM T Continue to clean up bottom of 7,974.0 7,974.0 00:00 02:06 window,Still having stack out issues at 7553. Unable to run through with pumps.Get to bottom with pumps off. Make two passes pulling up hole @ 180°tool face to 7552',Below tray wings.Able to run clean to bottom with pumps on at 0°tool face.Looks good 3/31/2017 3/31/2017 0.40 PROD1 WHPST TRIP P Start trip out,stop to fix reel pillow 7,974.0 7,881.0 02:06 02:30 blocks, 1 Hr NAD NPT 3/31/2017 3/31/2017 1.00 PROD1 WHPST TRIP T Replace pillow block bolts 7,881.0 7,881.0 02:30 03:30 3/31/2017 3/31/2017 1.50 PROD1 WHPST TRIP P Open EDC,Continue out of hole. 7,881.0 72.0 03:30 05:00 3/31/2017 3/31/2017 1.50 PROD1 WHPST PULD P At surface.Bump up.Space out. 72.0 0.0 05:00 06:30 PJSM. PUD BHA#9.LD motor/mills. String reamer gauged 2.79"no-go,the same as it went in.The 2.80"mill gauged 2.79"no-go. 3/31/2017 3/31/2017 3.00 PROD1 DRILL RGRP T While at surface,shim and re-tighten 0.0 0.0 06:30 09:30 reel hub bolts to compensate for spool hub plate tolerance. 3/31/2017 3/31/2017 1.50 PROD1 DRILL PULD P PJSM.PU and PD BHA#10.with 2.2° 0.0 72.2 09:30 11:00 +AKO motor and HCC RB bit. 3/31/2017 3/31/2017 2.00 PROD1 DRILL TRIP P RIH with BHA#10.Tie-in to the K1 for 72.2 7,974.0 11:00 13:00 a+2.5 ft correction.Continue in the hole. Page 7/8 Report Printed: 4/25/2017 fi 0 0 4 + Operations Summary (with Timelog Depths) NO 'tk 0 ::4,t4�t 1E-20 Philiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log '.- Start Depth Start Tirne End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation : (ftKB) End Depth(ftKD)` 3/31/2017 3/31/2017 4.10 PROD1 DRILL DRLG P BOBD. Pumping 1.7 bpm at 2930 psi 7,974.0 7,977.0 13:00 17:06 Multiple stalls and PU's required to keep drilling.Unable to drill ahead, made it to 7976.3 3/31/2017 3/31/2017 1.50 PROD1 DRILL TRIP T Trip out of hole to inspect BHA, 7,977.0 65.0 17:06 18:36 PUW=26K 3/31/2017 3/31/2017 1.50 PROD1 DRILL PULD T PJSM,PUD BHA#10.Bi center bit out 65.0 0.0 18:36 20:06 at 6-4 3/31/2017 3/31/2017 1.80 PROD1 DRILL PULD T PJSM,PD BHA#11 Nozzle with DGS, 0.0 42.8 20:06 21:54 M/U to coil and surface test 3/31/2017 3/31/2017 1.50 PROD1 DRILL TRIP T Trip in hole,EDC open 42.8 7,820.0 21:54 23:24 3/31/2017 3/31/2017 0.20 PROD1 DRILL DLOG T Log K1 for-.5',Close EDC, PUW=35K 7,820.0 7,840.0 23:24 23:36 3/31/2017 4/1/2017 0.40 PROD1 DRILL TRIP T Continue in well,start logging at 7940, 7,840.0 7,976.0 23:36 00:00 Set down at 7976'. Bit to gamma 4.8'. Did not see any pip tags 4/1/2017 4/1/2017 1.00 PROD1 DRILL CIRC T Open EDC,Prep pits,line up on 7,976.0 7,950.0 00:00 01:00 1 OPPG KWF circ down coil 4/1/2017 4/1/2017 3.50 PROD1 DRILL TRIP T Start OOH,taking losses,reduce 7,950.0 40.0 01:00 04:30 speed rate to conserve KWF. 4/1/2017 4/1/2017 1.00 PROD1 DRILL PULD T Well on static losses. Unstab injector. 40.0 0.0 04:30 05:30 LD Nozzle BHA. 4/1/2017 4/1/2017 2.40 COMPZ1 CASING PUTB T Crew change.Prep floor.RU and PU 0.0 200.0 05:30 07:54 5 joints slotted liner. MU running tools. 4/1/2017 4/1/2017 2.00 COMPZ1 CASING RUNL T RIH with liner BHA#12.Tie in to EOP 200.0 7,977.0 07:54 09:54 flag for a+1 ft correction.Continue running in the hole.Tag up at 7977 ft. Pump off of GS. 4/1/2017 4/1/2017 2.90 COMPZ1 MOVE DISP T Displace 9.6ppg brine to 8.6ppg 7,977.0 2,500.0 09:54 12:48 seawater.POOH. RU LRS for diesel FP. 4/1/2017 4/1/2017 1.20 COMPZ1 MOVE DISP T Continue out of hole pumping diesel 2,500.0 44.0 12:48 14:00 FP. 4/1/2017 4/1/2017 1.00 COMPZ1 MOVE PULD T PUD BHA#12.Confirm liner released. 44.0 0.0 14:00 15:00 4/1/2017 4/1/2017 1.00 DEMOB WHDBOP RURD T Move cart.MU nozzle.Stab injector 0.0 0.0 15:00 16:00 and flush stack. 4/1/2017 4/1/2017 2.00 DEMOB WHDBOP MPSP T RU Valve crew lubricator. Pressure 0.0 0.0 16:00 18:00 test to 1000 psi.RIH and set BPV. R/D lubricator 4/1/2017 4/2/2017 6.00 DEMOB MOVE MOB P Start working rig down check list- 0.0 0.0 18:00 00:00 Flush rig and blow down,Empty and clean pits,R/D PUTZ,R/D cellar.Blow down steam,RIG RELEASE 00:00 4/2 Page 8/8 Report Printed: 4/25/2017 • • 1E-20 Final CTD Schematic I++` 3-1/2"Camco TRDP-1A-SSA SSSV @ 1822'MD(2.812"min ID) 3-1/2"9.2#J-55 Tubing to surface 3-1/2"Camco gas lift mandrels @ 2210'MD,3448'MD,4314'MD,5056' V' 16"65#H-40 MD,5740'MD,6453'MD,7114'MD,7715'MD shoe @ 110'MD Baker 3-1/2"PBR @ 7764'MD(3"ID) Baker HB retrievable packer @ 7778'MD(2.89"ID)( .74'PDC) Willagl- 3-1/2"Camco DS landing nipple @ 7794'MD( JO'PDC) 10-3/4"45#K-55 (Milled to 2.80"prior to CTD) shoe @ 2380'MD 1""""""""' Baker SOS @ 7806'MD( ) ................. C-sand perfs IIII 7945'-8094'MD MIN Baker FB-1 packer @ 8130'MD(4.0"ID) Baker SBE @ 8132'MD I � 1 3-1/2"Camco D landing nipple @ 8148'MD(2.90"min ID) 3-1/2"by 7"high I I 3-1/2"tubing tail @ 8160'MD expansion wedge tt 1 III.\ whipstock ‘t Top Top of window=7949'MD \‘,,,,,,\ Bottom of window=7953'MD 3-1/2"by 7"high Whipstock fell down hole and window was left open expansion wedge whipstock Top of window=7961'MD Bottom of window=7965'MD Loa Whipstock fell down hole and window was left open ,71111D1l111' 2-3/8" slotted liner with deployment sleeve placed on I;�;I top of whipstocks that fell down hole iiii TOL=7776'MD 1.11 BOL=7977'MD A-sand perfs 8349'-8410'MD = 1 - 7"26#K-55 shoe @ 8622'MD ` Y ( KUP PROD • 1E-20 ConocoPhillips o Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore APBUWI Field Name Wellbore Statue eel(') MD(888) -Act 0tm(ft58) r ,- aptyMry. 500292089500 KUPAR UK RIVER UNIT PROD 48.52 4,200.00 8,650.0 --- Comment 1/25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-20.4/26/2017 10:23:13 AM SSSV:LOCKED OUT 140 8/12/2016 Last WO: 7/23/1990 39.00 2/3/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _. Last Tag:SLM 7.948.0 12/20/2010 Rev Reason:SIDETRACK(FAILED),2 FISH IN pproven 4724/2017 HANGER:2y 6 1 HOLE-SEE NOTES - '\f Casing Strings hCasing i-; CONDUCTOR Descripton OD(In) ID(In) Top(ftKB) Set Depth(MKS) Set Depth(TVD)...WHLen(1...Grade Top Thread 16 15.250 34.0 110.0 110.0 65.00 H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 103/4 9.950 33.0 2,380.0 2,172.4 45.50 K-55 BTC "' ■■ ' a1147 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...eWLen II...Grade Top Thread - ' CONDUCTOR:31.0-110.0•• " MN ._,-..WINDOW 7 6.276 7,949.0 7,953.0 6,216.3 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(#88) Set Depth(TVD)...WULen(I...Grade Top Thread WINDOW 7 6.276 7.961.0 7,965.0 6,225.5 Casing Description OD(In) ID lin) Top(ftKB) Set Depth(1tK8) Set Depth(TVD)...WULen(I...Grade Top Thread SAFETYVW,1,8220 _ PRODUCTION 7 6.276 31.2 8.621.7 6,733.7 26.00 K-55 BTC Tubing Strings Tubing Description (String Ma...I ID(.n) (Top(ftKB) I Set Depth(ft..lSet Depth(TVD)(...I Wt(10111) I Grade !Top Connection GAS LIFT,2,209.7 TUBING WO 31/21 2.992 27.6 7.807.0 6,103.2 9.20 J-55 BTC-MOD ge Completion Details o( ) ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des In) 27.6 1,822,0 Com 27.6 0.06 HANGER HANGER 3.500 FMC GEN III TUBING (1,747.5 33.55 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE-LOCKED OUT 2.812 SURFACE;33.0-2,360.0 6/19/2000(FLOW TUBE ONLY) NIn GAS LIFT,3,447.9 7,764.6 6,070.2 38.81 PBR BAKER PBR w/10'STROKE 3.000 7,778.3 6,080.9 38.89 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT:4,314.1 - 7,794.6 6,093.6 38.99 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,806.3 6,102.6 39.04 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT;5,056.0- Tubing Description String Ma. ID(In) Top(ftKB) Set Depth(ft..JSet Depth(TVD)(...WI(Ibfft) Grade Top Connection TUBING 31/2 2.992 8.098.0 8.160.0 6,375.8 9.30 J-55 BTCMOD I ABANDONED GAS LIFT:5.740.1 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT:6.453.2 8,098.0 6,328.0 39.57'BLASTJT SHATTERED 1'OF BLAST JOINT LEFT ON TOP OF 2.992 ABANDONED TUBING COMPLETION GAS LIFT:7,111.1 8,129.7 6,352.4 39.58 LOCATOR BAKER LOCATOR 4.000 IF 8,130.3 6,352.8 39.58 PACKER BAKER FB-1 PACKER 4.000 8,132.8 6,354.8 39.58 SBE BAKER SEAL BORE EXTENSION 3.500 GAS LIFT:7.714.9 8,147.8 6,366.4 39.58 NIPPLE CAMCO'D'NIPPLE 2.906 8,159.3 6,375.2 39.59 SOS BAKER SHEAROUT SUB 2.938 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Tap Incl PBR:7,764.6 Top(ftKB) MKS) (°J Des Com Run Date ID(in) 7.977.0 6,234.8 39.59 FISH3-12"by T'high 328/2017 2.500 illi expansion wedge whipstock.Depth below 7977' 7.979.0 6,236.3 39.59 FISH 3-12"by 7'high 3/312017 2.500 PACKER:7.778 3 expansion wedge whipstock.Depth below 7977' Perforations&Slots NIPPLE:7,794.6 Shot Dena SOS.7.806.3 Top(TVD) Bim(TVD) (shoes% Top(ftKB) Ste,(988) MB) MEI) Zone Date t) Type Com 7.945.0 8,094.0 6,210.1 6,324.9 C-4.C-3,C-2, 22/1983 4.0 IPERF 90 deg.Ph:DA 4"csg - - 1E-20 guns ` 8.349.0 8,362.0 6,521.5 6,531.6 A-5,1E-20 2/2/1983 4.0 IPERF 90 deg.Ph:DA 4"cog WINDOW.7s49.0-7,953.0 y guns 8.382.0 8,410.0 6,547.1 6,568.8 A-4,1E-20 2/2/1983 4.0 IPERF 90 deg.Ph;DA4"csg WINDOW.7.961.0-7,985.0 7 guns Mandrel Inserts Slotted Liner P61;7,775.8- St 7.977.0 all FISH,7.577.0 on Top(TVD( Valve Latch Port Size TRO Run FISH.7,979.0 N Top(ftKB) (HKB) Make Model OD(In) Sery Type Type (In) (poll Run Date Com 1 2,209.7 2,046.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,266.0 3/7/2017 IPERF.7.945.0-8,094.0 2 3,447.9 2,931.7 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 3/6/2017 3 4,314.1 3,526.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 376/2017 4 5,056.0 4,044.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/7/2017 5 5,740.1 4,530.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.0)0 0.0 3/7/2017 6 6,453.2 5,055.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/262007 GAS LIFT OTIS;8,110.1 I I7 7,114.1 5,562.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 723/1990 8 7,714.8 6,031.3 CAMCO MMG-2 1 12 GAS LIFT DMY BK 0.000 0.0 8/2/1990 LOCATOR:B.1297 9 Notes:General&Safety PACKER.8.130.3 er-.s. End Date Annotation II SBE;6,1328- 11/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 II 3/31/2017 NOTE:2 Northen Solutions High Expansion Wedge Whipstock LEFT IN HOLE. NIPPLE;6,147.9 I I a' -4 IPERF'8.349a-8.362.0 1 IPERF,8,382.0-8,110 0 PRODUCTION,31.2-8.821.7 1.'0* ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED FEB 21 2017 February 16, 2017 AOGCC Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ,AHHED MAR 2 8 2017, Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad-lateral out of the KRU 1E-20 (PTD# 183-005) using the coiled tubing drilling rig, Nabors CDR3-AC.J The scope of the window exit for KRU 1 E-20 has been modified from a cement pilot-hole casing exit to utilizing a 3-1/2"x 7" high expansion wedge exit. For this reason, please cancel the previously issued sundry (316-630). To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The CTD objective will be to drill four laterals (1E-20L1, 1E-20L1-01, 1E-20L1-02, & 1E-20L1-03), targeting the Kuparuk C-sand intervals. The work is scheduled to begin March 2017. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 1E-20L1, 1E-20L1-01, 1E-20L1-02 & 1E-20L1-03 — Detailed Summary of Operations — Directional Plans for 1E-20L1, 1E-20L1-01, 1E-20L1-02 & 1E-20L1-03 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, i i K-ith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska RBD1J1S 2 3 2017 • 1ST • O oJ OctrH l I/r — (3 N Z _ ~ C V W O v m `^ C 0 m Q O r a Y CD L Q 0 c� 0 Q ODy@ > C h O _. m �.- O ro _ Q L N V o v E > p .�- rt, y O N v 6- ,..3 a a c c c CD °y' C 'C -0 Fa C -0 a Q x v 0 (0 O CO4.9 r r r r L C 0a 6 CO J ,-.1 . - N y__, ) U t In < Ire ° U U C C C C E +� -6 r G W M E @ u L V1. H pp N M r N M V O }' r- LA Z Z ¢ 0 a1 > -0 41 gO C H f m v -0 , O G r i 4 G C G O O O p a J J J J J J J C +- 0 O F W W W W W W W In N LL LL LL LL LL LL LL aJ -0 © v Q J J J J J J J a +•^ N `H oar) ozzzzzz z � � v as LL LL LL LL LL LL LL cc — .Q c > y N ,r3O _o ai u (;) P:I 0.o � = i OFTit, • • ♦. evi' I// - THE STATE Alaska Oil and Gas ofZLZ V rConservation Commission � r£x_ 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 107\77; Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Keith Herring CTD Engineer 0 a ConocoPhillips Alaska, Inc. �� �� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-20 Permit to Drill Number: 183-005 Sundry Number: 316-630 Dear Mr. Herring: 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, Cathy P. oerster Chair DATED thisy of January, 2017. R D 5 LL )F04 2e11 • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 19 20 6 APPLICATION FOR SUNDRY APPROVALS gl- 1 20 AAC 25.280 AO iu 1.Type of Request: Abandon ❑ Plug Perforations❑., " Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑✓ ' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑✓ 183-005 s 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ PO Box 100360,Anchorage AK 99510 50-029-20895 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes IIINo 0 f KRU 1E-20 9.Property Designation(Lease Number): '0.21 10.Field/Pool(s): ADL 25651 AIEi9 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8650' 6756' ' 8538' • • 6668' 2413 psi N/A 7980'/Abandoned lower completion Casing Length Size MD TVD Burst Collapse Conductor 110' 16" 110' 110' 1640 psi 670 psi Surface 2380' 10-3/4" 2380' 2172' 3580 psi 2090 psi Production 8622' 7" 8622' 6734' 4980 psi 4320 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7945'-8094' , 6210'-6325' 8349'-8362' - 6521'-6532' 3-1/2"9.3# J-55 7807' 8382'-8410' - 6547'-6569' Packers and SSSV Type: Cameo TRDP Locked Out Packers and SSSV MD(ft)and TVD(ft): .SSSV:1822'MD/1747'TVD Baker HB Retrievable •Packer: 7778'MD/6081'TVD Baker FB-1 Permanent(Abandoned) ' Packer: 8130'MD/6353'TVD 12.Attachments: Proposal Summary d✓ Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development 0 N Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/30/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended E' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Keith Herring©263-4321 Email Keith.E.Herrinq(c�conocophillips.com Printed Name Keith Herring Title CTD Engineer /2//0Signature Phone: 263-4321 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ElOther: orp /I-tJr f p r 2r j5 vr�G I c., 3 57)0 /)5 Z r-°SF ' 14 h t7.51-- to 2 0 D %'5` � a ✓t' ✓la ip re-17c- � , /i-l_yr_na�,, ptvp1acCwttz ,pp no Post Initial Injection MIT Req'd? Yes ❑ No `��� U��C 2 �' 1 L Spacing Exception Required? Yes Ei No Subsequent Form Required: / APPROVED BY RBDNS f �-• .i,,/L, i 'LU jl Approved by� �` COMMISSIONER THE COMMISSION Date: / — 7 -/ t)gil 441 t 111- ► /Lam!/ Giit4Av Submit Form and Form 10-403 Revised 11/2015 � lid for 12 months from the date of approval. Attachments in Duplicate .� i • • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 DEC 19 2016 December 19, 2016AOGC C Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to plug the KRU 1E-20 (183-005) by cementing up the perforation to allow CTD operations to drill a tri-lateral out of the KRU 1 E-20 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the KRU 1 E-20 perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C-sand perforations in this manner. Attached to this application are the following documents: — 10-403 Sundry Application to for KRU 1 E-20 — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • • KRU 1E-20 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1 E-20 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize three laterals to target the C-sand to the south of 1 E-20. The laterals will improve regional C-sand resource recovery. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 7786' MD and the "D" nipple at 7791' MD will be milled out to 2.80" ID. An inflatable cement retainer (ICR) will be set at 7969' MD. The existing C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in_place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to ✓ plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 7965' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 7945' MD. All the laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3- 1/2" tubing tail. Using the maximum formation pressure in the area of 3034 psi in 1 D-03, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2413 psi. CTD Drill and Complete 1E-20 Laterals: January 2016 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test 2. RU E-line: Punch 2' of holes in 3-1/2" tubing tail 3. RU Pumping: Perform injectivity test down the tubing 4. RU Service Coil: Mill out "D" nipple, set ICR, and cement squeeze C-sand perforations up to the holes in the tubing tail. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC and set BPV. Rig Work 1-111-5 �( /rl 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 E-20A Sidetrack (C sand - South) a. Drill 2.80" high-side pilot hole through cement to 7965' MD b. Caliper pilot hole c. Set top of whip-stock at 7945' MD - d. Mill 2.80" window at 7945' MD. e. Drill 3" bi-center lateral to TD of 11400' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 9590' MD. New 3. 1 E-20AL1 Lateral (C sand - South) PTP a. Kick off of the aluminum billet at 9590' MD. b. Drill 3" bi-center lateral to TD of 1.1400' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9100' MD. / 4. 1E-20AL2 Lateral (C sand - South) �� ��(r �'J �� Co� (���rr l� old ' (i(o re5e(veS (eve ew "eco56.-,. pie 1 Page l of 2 I re cocier e/ into ENS(�^) Mit 6°Ie c(�cf 745 '4) !7r 12/19/2016 rey �c, vs 4r cif Cvrfe/f r }e/ Trfr4 7/47 11) a. Kick oflthe aluminum billet at 9100' MD. b. Drill 3" bi-center lateral to TD of 11400' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 7786' MD. 5. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 12/19/2016 *. d KUP IE-20 ConocoPhillips o Well Attributes 0 Max Angle&MD TD Alaska.It Wellbore APVUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) amoachps y 500292089500 KUPARUK RIVER UNIT PROD 48.52 4,200.00 8,650.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Coflf:-1 E-20,5/3112012 a i3-oo nM --SSSV:LOCKED OUT 80 9/26/2011 Last WO: 7/23/1990 39.00 2/3/1983 Schematic- ....... Actual ."'--Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,948.0 12/20/2010 Rev Reason:WELL REVIEW osborl 5/31/2012 HANGER,ss- Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.250 34.0 110.0 110.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd • SURFACE 103/4 9.950 33.0 2,380.0 2,172.4 45.50 K-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 31.2 8,621.7 6,733.7 26.00 K-55 BTC Tubing Strings CONDUCTOR. Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd 34-110 ',, TUBING WO 3 1/2 2.992 27.6 7,807.0 6,102.9 9.20 J-55 BTC-MOD Completion Details V Top Depth SAFETY VLV. (ND) Top tel Nomi... 1,922 Top(ftKB) (ftKB) CI Item Description ption Comment ID(in) I 27.6 27.6 0.11 HANGER FMC GEN III TUBING HANGER 3.500 h- . 1,822.0 1,746.5 33.71 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE-LOCKED OUT 6/19/2000 2.812 GAS LIFT, (FLOW TUBE ONLY) 2'210 1 r< 7,764.6 6,070.1 38.81 PBR BAKER PBR w/10'STROKE 3.000 7,778.3 6,080.8 38.89 PACKER BAKER HE RETRIEVABLE PACKER 2.890 7,794.6 6,093.6 38.99 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,806.3 6,102.4 38.89 SOS BAKER SHEAR OUT SUB 3.015 SURFACE, - Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 33-2,380 TUBING 31/2 2.992 8,098.0 8,160.0 6,375.8 9.30 J-55 BTCMOD ( ABANDONED GAS LIFT. t 3,448 g = Completion Details Top Depth -" GAS LIFT, (TVD) Top Incl Nomi... 4,314 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) i" 8,098.0 6,328.0 39.57 BLAST JT SHATTERED 1'OF BLAST JOINT LEFT ON TOP OF ABANDONED 2.992 _ TUBING COMPLETION GAS LIFT, 8056 8,129.7 6,352.4 39.58 LOCATOR BAKER LOCATOR 4.000 8,130.3 6,352.8 39.58 PACKER BAKER FB-1 PACKER 4.000 GAS LIFT, --. 8,132.8 6,354.8 39.58 SBE BAKER SEAL BORE EXTENSION 3.500 5,740 F 8,147.8 6,366.4 39.58 NIPPLE CAMCO'D'NIPPLE 2.906 GAS LIFT. --- 8,159.3 6,375.2 39.59 SOS BAKER SHEAROUT SUB 2.938 6,453 Perforations&Slots GAS LIFT, _ Shot 7.114 Top(ND) Blm(TVD) Dense Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment -17,945.0 8,094.0 6,210.2 6,324.9 C-4,C-3,C-2, 2/2/1983 4.0 IPERF 90 deg.Ph;DA 4"csg guns 1E-20 GAS LIFT, 7,715 - 40 8,349.0 8,362.0 6,521.6 6,531.6 A-5,1E-20 2/2/1983 4.0 IPERF 90 deg.Ph;DA 4"csg guns 8,382.0 8,410.0 6,547.1 6,568.7 A-4,1E-20 22/1983 4.0 IPERF 90 deg.Ph;DA 4"cog guns Notes:General&Safety .J.4 End Date Annotation 11/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR,7,765 PACKER,7.778 NIPPLE,7,795 I I SOS,7,806 IPERF, 7,945$094 I ii_..... GAS UFT -� OTIS,8,110 111. LOCATOR, j`` 8130 11 T( PACKER,8,130 SBE,8,133 NIPPLE,8,148 ,-.-- a _j Mandrel Details `4 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) 1°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,209.7 2,047.4 43.65 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,244.0 5/12/2008 2 3,447.9 2,931.8 45.10 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,238.0 5/12/2008 8,3498. IPERF• .M- WE 3 4,314.1 3,523.4 42.79 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,258.0 5/11/2008 362 4 5,056.0 4,044.3 45.46 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,284.0 5/112008 (PERF, _ 5 5,740.1 4,530.7 43.57 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 5/11/2008 e,38z-8-810 - 6 6,453.2 5,055.8 42.20 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/26/2007 7 7,114.1 5,562.3 38.84 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990 8 7,714.8 6,031.3 38.51 CAMCO MMG-2 1 12 GAS LIFT DMY BK 0.000 0.0 8/2/1990 PRODUCTION. 31-8,622 TD,8850 • Ilk • 3-1/2"Camco TRDP SSSV @ 1822'RKB(locked out) 16"65#H-40 shoe 3-1/2"9.3#J-55 EUE 8rd Tubing to surface @110'MD 3-1/2"Camco gas lift mandrels @ 2210',3448',4314',5056', 5740',6453',7114',7715'RKB 10-3/4"45.5# K-55 shoe @ 2172'MD Baker 3-1/2"PBR @ 7765'RKB(3.00"ID) 2111110.—_ Baker HB Retrievable Packer @ 7778'RKB(2.89"ID) 3-1/2"Camco D nipple @ 7795'RKB(2.75"min ID,No-Go) 3-1/2"tubing tail @ 7806'RKB Abandoned Lower Completion: 3-1/2"tubing w/Carbide blast rings @ 7980'MD 3-1/2"Otis gas lift mandrel @ 8110'RKB Baker Locator @ 8130'RKB Baker FB-1 Packer @ 8130'RKB ;+ri`3 Baker Seal Bore Extension @ 8133'RKB Camco D nipple @ 8148'RKB Tubing tail @ 8159'RKB • C-sand perfs(sqz'd) j ICR @ 7969'MD 7945'-8094'MD �! 111111 A-sand perfs 8349'-8410'MD 7"26#K-55 shoe @ 6734'MD Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Tuesday,January 03,2017 10:50 AM To: Loepp,Victoria T(DOA);Callahan, Mike S Subject: RE:CRU CD2-39(PTD 201-160)and KRU 1E-20(PTD 183-005)Plug for Redrills Good morning Victoria, CRU CD2-39 BOP test pressure=4500 psi KRU 1E-20 BOP test pressure= 3500 psi Thanks, Keith Herring CTD Engineer 907.263.4321(Office) 907.570.2410(Mobile) 700 G Street,ATO—664 Keith.E.Herring@conocophillips.com Nov- ConocoPhillips Alaska From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,January 03,2017 10:21 AM To:Callahan, Mike S<Mike.Callahan@conocophillips.com>; Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]CRU CD2-39(PTD 201-160)and KRU 1E-20(PTD 183-005)Plug for Redrills Please provide BOP test pressures. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 03/20/07 Schlumbel'ger /I,V, 1 /. l {)j--~- NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth sCANNED APR 0 3 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I"! ,\ n ,~ 2. Z., 0 t"') -¡' , I-m <,-' Commif1r\io1'i 1~3 -Cf)S- Field: Kuparuk Well Job# Date CD BL Color Log Description 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03108107 1 1E-20 11638833 GLS 03109107 1 1E-168 11626470 PRODUCTION PROFILE 03112107 1 1E-117 11626471 INJECTION PROFILE 03114/07 1 1Q-09 11638839 INJECTION PROFILE 03/16107 1 3S-22 NIA INJECTION PROFILE 03116107 1 3M-23 11638840 LDL 03/17107 1 1 C-1 0 11638841 INJECTION PROFILE 03118107 1 2A-23 11628986 INJECTION PROFILE 03118107 1 1 H-21 11638842 GLS 03119/07 1 1 D-42 11638843 SBHP SURVEY 03119/07 1 2L-323 11628988 INJECTION PROFILE 03120107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¡'S' . . Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1Y-19 ~."~-'i<~"~ PRODUCTION PROFILE/DEFT 10109/03 3A-04 ~-~'~ INJECTION PROFILE 10111103 3B-03 ~ ~:;~7';O¢C~, IPRODUCTION PROFILE/DEFT 10113/03 3B-08 ,~.z~-~,'~ PRODUCTION PROFILE 10114/03 3A-05 l~C~-~ ~ PRODUCTION PROFILE 10/15103 38-06 ~ ~;~-)-(~'~ PRODUCTION PROFILE 10116/03 2T-21 ¥ C~Z~ ~--"~ LEAK DETECTION LOG 10117/03 38-04 Ic~;_-)--(~2~ PRODUCTION PROFILE/DEFT t0118103 1E-20 t~;~,'~ ~ SBHP SURVEY 10120103 31-11 )~cj-O~ LEAK DETECTION LOG 10125103 3G-09 ~qC)"(~o'-~' 'PRODUCTION PROFILE 10125/03 3G-11 j qC)"O¥~ PRODUCTION PROFILE 10127/03 18-20 c~-'~ PERF RECORD/STATIC SURVEY 10130/03 SIGNE ... . ,,._Q_C:::::::~_~%-......C'-mv""%_ DATE: l',¢u ~ . .AI~31';3 3]i & ~.-:3 r,~,.,., ..-, . . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. &..,~,- . MEMORANDUM TO: Julie Heusser, Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 4, 2001 THRU:' Tom Maunder, ~-~~~ P. I. Supervisor ~l~r,,-c)t FROM: SUBJECT: ChuCk Scheve; Petroleum Inspector Safety Valve Tests Kuparuk River Unit 1 E Pad Thursday, January 4, 2001' I traveled to the Kuparuk River Field and witnessed safety valve system testing on 1E Pad. As the attached AoGcc Safety Valve SyStem Test Report indicates I witnessed the testing of 9 wellS. 18 Components on 1E pad with 2 failures. The Pilot on well 1E-07 was froZen and the Surface Safety valve on well 1E-24A had a slow leak when. pressure tested. A portable..heater was brought to location and the above mentioned pilot was thawed out. I requested the portable heater remain on this well until repairs are made on the catalytic heater in the wellhouse. The failed safety valve will be serviced and retested when the grease crew becomes available Earnie Barndt Conducted the teSting today; he demonstrated good test procedures and was a pleasure to work with. I also inspeCted :the Well houSes on this pad while Witnessing SVS testing. All the wellhouses were clean and the equipment appeared to be in good condition. Summary: I witnesSed the iSVS testing at 1E Pad in the Kuparuk River Field. KRU 1E Pad, 9 Wells, 18 components, 2 failure, 11.1% failure rate 16 wellhouse inspections Attachment: SVS KRU 1E Pad 1-4-01 CS X Unclassified Confidential' Confidential (Unclassified if doc. removed ) SVS KRU 1E Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips- Submitted By: Chuck Scheve Date: 1/4/01 Operator ReP: Eamie Barndt Field/Unit/Pad: .Kupan~ / KRU / 1E Pad AOGCC Rep: Chuck Scheve Separator psi: LPS 85 HPS Well' Permit Separ 'Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i i 1E-02 1800500 85 70 60 P P OIL 1E-03 1800560 85 70 45 P P OIL! 1E-05 1800580 1E-06 1800780 1E-07 1800800 85 70! 0 2P OIL 1E-10 1820360 1E-11 1820510 1 E- 12 1820600 1E-14 1820790 1E-18 1830160 85 70 50 P P OIL , 1E-19 1830170 1E-20 1830050~ 85 70 50 P P OIL 1E-21 1830020 1E-23 1821840 - 1E-24A 1971870 85 70 . 70 P 4 OIL 1E-26 1821660 1E-28 1821580 ~ 1E-29 1821540 1E-31 19713801 85 70 65 P P OILI 1E-33 1971510 ,, 1E-34 1971660 85 70 50 P P OIL , 1E-36 1982130 . 85 70 60 P P OIL Wells: 9 Components: 18 FailUres: 2 Failure Rate: 11.1%~ 9o var Remarks: Pilot on 1E'07 frozen. Portable heater placed on pilot until catalytic repaired S_urface Safety on 1E-24A had slow leak, valve to be serviced and retested. t/o/al Paoe 1 ofl SVS KRU 1E Pad 1-4-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~.~..,q~ Commissioner DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor John H Spaulding~,/~'~ ---20. Petroleum Inspecto~r FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX 1E - 8 wells, 16 components, 1 failure; 9 % failure rate, 12 well house insp. ~2X~-tO-weils~ 120compnents, 1 failure;-5 % failure rate, 12 well house insp. AttaChment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kuparuk/Kupamk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip COde Code Code GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1E-10 1820360 1E-11 1820510 1 E- 12 1820600 SI 1 E- 14 1820790~ 1E-18 1830160 91 60 46 P P OIL 1E-19 ' 1830170 ~ 1830050 91 60 48 P P OIL 1E-21 1830020 1 E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [-] 90 Day Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Submitted By: John Spaulding Date: 22-Jul Operator Rep: E. Barndt Field/Unit/Pad: Kup~uparuk R./2X AOGCC Rep: John H. Spaulding Separator psi: LPS 96 HPS Well Permit Separ Set' L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2×-01 1830840 2X-02 1831030 2×-03 1831090 2×-04 1831180 3000 2000 2000 P P WAG 2×-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2×-09 1841620 96 70 60 P P OIL 2X- 10 1841630 96 70 65 P P OIL 2X- 11 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X-15 1841760 96 70 70 P P OIL 2X-16 1841720 2X-17 1951710~ 96! 60 50 P P OIL 12X-18 1951600 96 60 50 P P OIL] 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% ~] 9o Day Remarks: R/1 _5/00 Page 1 of 1 svs kuparuk kru 2x 7-22-OOjs.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS :1. Operations performed: Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well X Other __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 411' FSL, 224' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1E-20 9. Permit number/approval number 1979' FSL, 1273' FEL, Sec. 15, T11N, R10E, UM At effective depth 2146' FSL, 934' FEL, Sec. 15, T11N, R10E, UM At total depth 2175' FSL, 871' FEL, Sec. 15, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8650' 6756' 83-5/90-357 10. APl number 50-029-20895 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8538' true vertical 6668' feet Plugs (measured) None feet 0 [~ !,~or~e~Jco~mP~igtion feet Junk (measured) Lower portion ' feet left in hole. Casing Length Size Structural 8 0' 1 6" Conductor Surface 2345' 1 0-3/4" Intermediate Production 8 5 8 6' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 29O Sx AS II 115' md 115' tvd 235 sx AS I 2380' md 2172' tvd 1300 sx AS III 2800 sx Class G 8621' md 6733' tvd 7945' - 7974', 8004' - 8094', 8349' - 8362', 8382' - 8410' true vertical 6210' - 6232', 6255'- 6325', 6521' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 7807' MD Packers and SSSV (type and measured depth) Baker "HB" Pkr @ 7778' MD, Camco "TRDP-1A-SSA" SSSV @ 1822' - 6532', 6547' - 6569' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rf~, 05/17/89 Title Area Drilling Engineer Date SUBI~IIT I1~ DUPLICATE ARCO Oil a,,cl Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel)ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field Auth. or W.O. no. AK5008 Operator ARCO county, parish or borough NORTH SLOPE ILease or Unit ADL: 25651 ITitle WORKOVER ALK: 469 State AK Well no. 1E-20 Spudded or W.O. begun SPUD 1) JARCOW.,. 55. 8533 IDate 01/21/83 ]Hour 14:00 ]Prior status ,f a W.O. Date and depth as of 8:00 a.m. 07/08/90 ( TD: 8650 PB: 8538 SUPV:GB 07/09/90 ( TD: 8650 PB: 8538 SUPV:GB 07/10/90 ( TD: 8650 PB: 8538 SUPV:GB 07/11/90 { TD: 8650 PB: 8538 SUPV:DEB 2) 4) Complete record for each day reported NORDIC 1 MONITORING WELL PRESSURE MW:11.9 NaBr MOVE RIG FROM 1L-10 TO 1E-20, RU OTIS SLICK LINE, PULL BPV, PULL DV F/ GLM AT 7700', RD OTIS SL, BLEED GAS OFF TBG, DISPLACE WELL TO WATER, RU DOWELL TO PUMP BRIDGESAL PILL, PUMP 10 BBLS OF BRIDGESAL CIRC SYSTEM, PUMP 75 BBLS BRIDGESAL KILL PILL, RD DOWELL, DISP WELL TO 11.9 PPG BRIDGESAL CIRC SYS, ANNULUS RETURNS WERE VERY GAS CUT DAILY:S36,288 CUM:$36,288 ETD:S36,288 EFC:$690,000 CIRC AND MONITOR HOLE MW:ll.9 NaBr MONITOR TBG/CSG PRES, PUMP 16 BBLS DWON TBG, LOST 8 BBLS TO FORMATION, SET BPV, ND TREE, NU BOPE, BLEED GAS OFF TBG, MU LDG JT, TST BOPE, RU HLS E-LINE W/ CHEMICAL CUTTER, BOLDS, PU 100K ON STRING, RIH W/ CHEMICAL CUTTER, FIRE TO CUT TBG AT 7900', LOG TO VERIFY CUT, CCL SHOWS SMALL CUT AT 7900', POOH W/ TOOLS TO SSSV, WORK TOOLS THROUGH SSSV, CHEM CUTTER HAD HOLE BLOWN IN TUBE OF TOOL 5' ABOVE CUTTER HEAD, LAY DOWN WL TOOLS, PULL 115K ON TBG, TBG MOVED 3', TBG NOT PULLING FREE, RU HLS WL TOOLS, RIH W/ CHEM CUTTER/CCL, TROUBLE GETTING THROUGH SBR AT 7741', WORKED TOOLS TO 7850', TOOLS STICKING, PUMP DOWN TO FIRE AT 7901', LOG CUT W/ CCL, CAN NOT SEE PART IN TBG, POOH, CHEM CUTTER TOOL DID SAME AS BEFORE, STAND BACK TOOLS, PULL/WORK TBG STRING UP HOLE, LAY DOWN LDG JT, CIRC HOLE AND MONITOR FOR GAS BUBBLE DAILY:S28,337 CUM:$64,625 ETD:S64,625 EFC:$690,000 RUN HLS E-LINE CHEM CUT MW:11.9 NaBr CIRC DOWN TBG, GAS CUT RETURNS, MONITOR WELL (STATIC), POOH W/ 3-1/2" TBG, RU FLOOR AND TIH W/ 3-1/2" TBG, PU SBR THAT CAME OUT OF HOLE AND STAB OVER SLICK STICK, RU HLS E-LINE AND RIH W/ DUMMY CUTTER HEAD TO 7950', POOH, MU CHEMICAL CUTTER W/ CCL AND RIH TO 7950', LOG UP AND TIE IN, CUT TBG AT 7828', PULL UP HOLE TO 7730', RUN BACK DOWN TO VERIFY CUT, UNABLE TO GET BACK DOWN, POOH DAILY:S152,674 CUM:$217,299 ETD:S217,299 EFC:$690,000 RIH W/BAKER RETR TOOL-PU DP MW:11.9 NaBr PUMP DOWN TBG, & FREE CHEM CUTTER, POH W/WL-CUTTER FIRED & LEFT CUTTER IN HOLE RIH W/CCL-GOOD CUT @ 7970', CONTINUE RIH, CAN'T WORK PAST 7970', POH, RU FLOOR POH W/3-1/2" BTC TBG, LD 2 PUPS & 2 SINGLES, POH 2 STDS PIPE PULLING WET, RU CIRC HEAD, REVERSE OUT GAS CUT BRIDGESAL 'A'. I HOLE VOL, RETRIEVING TOOL, RIH, PU 3-1/2" DP~ CONTINUE RIH DAILY:S52,502 CUM:$269,801 ETD:S269,801 EFC:$690,000 Drilling, Pages 86 and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil an~, ,=as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Section will be reporled on '"Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but nol less frequently Ihan every 30 days, or {2) on Wednesday of the week in which oil slring is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState ARC_~ ~T.ARWA TNC. NORTH SLOPE AK Field ~'~]~[~ ILease or Unitl~._20 IWell no. Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. 07/12/90 (5) TD: 8650 PB: 8538 SUPV:DEB 07/13/90 ( 6) TD: 8650 PB: 8538 SUPV:DEB 07/14/90 (7) TD: 8650 PB: 8538 SUPV:DEB 07/15/90 (8) TD: 8650 PB: 8538 SUPV:DEB 07/16/90 ( 9 TD: 8650 PB: 8538 SUPV:DEB NORDIC The a~ov_e is correct CIRC BTMS UP MW:ll.9 NaBr SERVICE RIG, CONT RIH W/ BAKER RETRIEVING TOOL ON DP, WASH OVER SLICK STICK, LATCH J-TOOL, ROTATE PKR FREE, CIRC 1 HOLE VOLUME, POH 4 STDS, HOLE SWABBING, CIRC 20 BBLS, CONT POH, DID NOT RECOVER PKR, LD BAKER RETRIEVING TOOL, RIG UP TRI-STATE OVERSHOT ON 3-1/2" DP, TIH, TAG SLICK STICK AT 7748', LATCH, PACKER PULLED FREE, POH 2 STDS, HOLE SWABBING FIRST 40', OK AFTER THAT, SEEING DRAG AT CASING COLLARS DAILY:S52,320 CUM:$322,121 ETD:S322,121 EFC:$690,000 RIH W/ DRIVE DOWN BAILER MW:ll.9 NaBr CBU, POH W/ FHL PKR AND SBR, CHEM CUT MADE AT 7828' PARTED WHILE BREAKING DOWN JOINT IN MOUSEHOLE, CHEM CUT AT 7900' WAS 3/4 OF THE WAY THRU, CUT AT 7901' SHOWED A CLEAN CUT, MU TRI-STATE OVERSHOT, RIH ON 3-1/2" TBG TO 7885' CBU, WASH DOWN AND LATCH ON FISH AT 7905', WORK PIPE, NO MOVEMENT, RU OTIS SLICK LINE UNIT, RIH W/ IMPRSSION BLOCK TO 7997' POH, NO MARKS, RIH W/ DRIVE DOWN BAILER TO GET FILL OFF CHEM CUTTER DAILY:S28,147 CUM:$350,268 ETD:S350,268 EFC:$690,000 RU CTU MW:ll.9 NaBr SLICKLINE WORK ATTEMPTING TO RETRIEVE HLS CHEM CUTTER AND CLEAN OUT FILL IN TUBING, 8 BAILER RUNS (RECOVERED SALT AND SAND), NO RECOVERY OF CHEM CUTTER, RD OTIS SLICKLINE, RU D/S COILED TUBING UNIT DAILY:S36,275 CUM:$386,543 ETD:S386,543 EFC:$690,000 MILL ON JUNK W/ CTU MW:ll.9 NaBr CONT RU D/S CTU, SET BOPS ON FLOOR, NU COILED TUBING EQUIPMENT, DISPLACE DIESEL IN COIL TO BRIDGESAL, PREPARE TO RIH, RIH W/ 2" JET NOZZLE TO 7800', BREAK CIRC, CONT RIH, TAG AT 8007', WORK CTU, NO PROGRSS, REPEAT, NO PROGRESS, POH, MU 2-5/8" TRI-STATE JUNK MILL AND DRILEX MUD MOTOR, RIH, TAG JUNK AT 8005', WORK COIL AND PUMP TO KEEP MOTOR TURNING, MADE 6" PROGRESS AT 06:00 DAILY:S28,147 CUM:$414,690 ETD:S414,690 EFC:$690,000 CBU W/ CTU AT 8140' MW:11.9 NaBr CONT MILLING ON JUNK W/ CTU, MILL FROM 8005' TO 8007', PROGRESS STOPPED, POH TO CHECK TOOLS, REHEAD CTU CONNECTOR, MU CUSTOM BURNING SHOE, RIH W/ BURNING SHOE, TAG TOP AT 8000', BREAK CIRC, BURN OVER AND MILL ON JUNK FROM 8000' TO 8007', BROKE THRU JUNK, WASH DOWN THRU TAILPIPE TO BOTTOM OF TAIL AT 8160' AND OUT THRU TAILPIPE AT 8140' CTU MEASUREMENT, CIRC HOLE CLEAN, GETTING BACK SOME BRIDGESAL PILL AN~D SCALE AAqD DIRT AND ?AR, CIRCt POH TO 4000' W/ CTUt ~a~x~ al' 4UUU' W/ CTU ~'OR 4 HK~, RIH W/ {~[~ TO CHECK FOR FILL s,onatu~. OR BRI~ES ~'~ING, PULL ~ INTO T~ING AT 8140' . n~T.Y~2R:~47 C~:8442~837 E~:8442~837 EFC:S690.000 AR3B-459-2-B INumber all daily well hislory torres consecutively as they are prepared for each well. JPage no. ARCO Oil an~, .~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by' Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. I NQ~TH SLOPE I Lease or Unit I 1E-20 Complete record for each day while drilling or workover in progress 07/17/90 ( 101 TD: 8650 PB: 8538 SUPV:DEB 07/18/90 ( 11] TD: 8650 PB: 8538 SUPV:DEB 07/19/90 ( 12 TD: 8650 PB: 8538 SUPV:DEB 07/20/90 ( 131 TD: 8650 PB: 8538 SUPV:DEB NORDIC 1 IState RU HLS CHEM CUTTER MW:ll.9 NaBr CIRC, POH W/ CTU, RD CTU, SET INJECTOR HEADS AND BOPS AND HYDRAULIC LINES OFF FLOOR BACK ON CTU, RE-RIG FLOOR, PULL 120K# MAX PULL ON TBG, NO MOVEMENT, PU ll0K# AND SET SLIPS, RU HLS E-LINE, MU CHEM CUTTER, RIM, CUT TBG AT 8098', GOOD INDICATION OF CUT, PU W E-LINE AND SET BACK DOWN ON CUT, NO PIPE MOVEMENT AT SURFACE, POH AND RD HLS E-LINE, PU AND SO OF PIPE, NO MOVEMENT, RU CIRC HEAD CIRC, WORK PIPE, NO MOVEMENT, ATTEMPT TO WORK RH TORQUE DOWN STRING TO RELEASE OVERSHOT, NO GO, RU HLS E-LINE TO CUT TBG DAILY:S102,615 CUM:$545,452 ETD:S545,452 EFC:$690,000 RU W/ WASHOVER PIPE MW:ll.9 NaBr MU HLS CHEM CUTTER, RIH AND CUT TBG AT 7909' WLM, POH -- LEFT CHEM CUTTER IN MOLE, RD SHIEVE AND PU ON PIPE -- PIPE FREE AT CUT, RD HLS, CBU, POH W 3-1/2" TBG, PU AND MU FTA #4, RIM W/ FTA#4 AND 4-3/4" DC AN-D 3-1/2" DP DAILY:S30,593 CUM:$576,045 ETD:S576,045 EFC:$690,000 START RIH W PUMP BAILER MW:ll.9 NaBr CONT RIM W WASHOVER PIPE, WASH DOWN OVER TOP OF FISH AT 7909', WASHED OVER TO 7972', ROTARY STALLING OUT, LAST 5' FROM 7967'-7972' IS TIGHT, CBU, POH W/ ETA #4, FOUND RADIAL GROOVES CUT IN WASHOVER PIPE INDICATING BROKEN BLAST RINGS, HAVING 5-3/4" HYDRAULIC VIBRATOR TOOL BUILT (24-30 MRS), RD DP TOOLS, RU TO RUN TBG, MU OVERSHOT WITH PACKOFF (NO GRAPPLE), RIH W/ OVERSHOT AND PACKOFF, RU CIRC HEAD, TAG FISH AT 7909', SPACE OUT AND SET PACKOFF/OVERSHOT OVER STUB, RU OTIS SLICKLINE, RIH W/ 2' LIB, TAG UP 7968' SLM, POH (IMPRESSION OF END SEGMENT OF CHEM CUTTER) PU 2-1/2" PUMP BAILER, START IN MOLE AT 06:00 DAILY:S40,448 CUM:$616,493 ETD:S616,493 EFC:$690,000 TESTING BOPE MW:ll.9 NaBr RIH W/ PUMP BAILER TO 6200' KINKED LINE, POH, SPOOL OFF 6200' LINE, RIH W/ PUMP BAILER TO 7968', POH (RECOVERED 2 PIECES OF THIN METAL), RIH W/ MAGNET, POH (RECOVER 4 PIECES OF THIN METAL SPRING), RIH W/ MAGNET, POH (RECOVER 5 PIECES OF SPRING), RIH W/ ALLIGATOR GRAB, POH (NO RECOVERY), RD OTIS SLICK LINE (LEFT CHEM CUTTER AND SLIPS AT 7968'), CBU, PUMP SLUG, POH W/ TBG AND OVERSHOT, TRI STATE VIBRATOR ARRIVED AT 02:00, MU VIBRATOR TOOL, TEST BOPE. DAILY:S61,451 CUM:$677,944 ETD:S677,944 EFC:$690,000 no. The above is correct For form preparation and ~s~'~bution ~ see Procedures Manual SeL~t~Sn 10, ~ Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms conseculively as they are prepared for each well. IPage no. ARCO Oil an~, ~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lolerim" sheets when filled out but not less Irequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ unlil completion. District Field ~RTT Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. I NORTH SLOPE Lease or Unit la-20 Complete record for each day while drilling or workover in progress 07/21/90 (14) TD: 8650 PB: 8538 SUPV:DEB 07/22/90 (15) TD: 8650 PB: 8538 SUPV:DEB 07/23/90 (16) TD: 8650 PB: 8538 SUPV:DEB NORDIC IState AK RU HLS E-LINE MW:ll.9 NaBr FINISH BOPE TEST, MU FTA#5 (GUIDE, OVERSHOT, GRAPPLE, OIL JARS, 5-1/2" VIBRATOR SUB), RIH, PU KELLY AND LATCH FISH, PU 190K# AND BREAK CIRC, TRIED DIFFERNT PUMP RATES AND PU WEIGHTS, NO PROGRESS WITH FISH, SHUT DOWN PUMP AND BUMP DOWN AND ROTATE OFF FISH, POH W/ FTA#5 AND LD TRI-STATE TOOLS, MU FTA#6 (GUIDE, OVERSHOT W/ GRAPPLE, EXT, XO), RIH, LATCH FISH AT 7909', PULL 50K# OVERPULL AND SET SLIPS, RU HLS E-LINE TO RUN JET CUTTER DAILY:S30,147 CUM:$708,091 ETD:S708,091 EFC:$690,000 LD 4-3/4" DC MW:11.9 NaBr FINISH RU HLS E-LINE, MU AND RIH W/ JET CUTTER, CUT TBG AT 7979' WLM, POH, PULL 1 JT TBG, RD ELS E-LINE, POH W/ TBG AND FTA#6 A_ND FISH, BREAK OUT 7' OF TBG STUB FROM TOP OF FISH, LD TRI-STATE FTA#6, PULL REMAINDER OF FISH OUT OF HOLE (FOUND TBG FLARE TO 3-7/8" -- FLARE HOLDING RINGS ON TBG), TOTAL 69'+ FISH RECOVERED (7' TBG STUB, 2 JTS AND 2' STUB OF FL4S W/ 42' OF CBRS), REMOVE CBRS, PU BHA, MU Bi-L%.#1 (BIT, CASING SCRAPER, BS, BUMPER SUB, OIL JARS, AND DCS), RIH ON DP, TAG FISH AT 7977' MD, PU 10' ABOVE FISH, CBU TO CLEAN UP HOLE, PUMP SLUG, POH W/ DP DAILY:S42,241 CUM:$750,332 ETD:S750,332 EFC:$690,000 RUNNING 3-1/2" COMPLETION MW:ll.9 NaBr SERVICE RIG, FINISH POH W/ DP, MU HOWCO RBP, RIH W/ RBP AND SET AT 7851' MD, TST 7" CASING TO 2500 PSI FOR 30 MIN (LOST 70 PSI), UNSET B.BP AND POH, RUN 3-1/2" COMPLETION ASSEMBLY (34 STDS AT 06:00) DAILY:S55,396 CUM:$805,728 ETD:S805,728 EFC:$690,000 IWell no. The above is correct Slgnature~ ~ sF~; f~/~c ePdruerPeasr a tMia°~u ~ F?-.-S ed~ ~i~[~inb ~ t~.On ~ Drilling, Pages 86 and 87 AR3B-459-2-B lNumber all daily well history forms consecutively as they are prepared for each well. JPage no. ARCO (~ ,=nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted alee whell operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, District ARCO ALASKA INC. County or Parish NORTH SLOPE Lease or Unit ADL: 25652 Title WORKOVER IAccounling cost center code State AK Field Auth. or W.O. no. A-K5008 ALK: 469 Well no. 1E-20 Operator ARCO Spudded or W.O. begun SPUD A.R.Co. W.I. 55.8533 Date I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 14:00 01/21/83 Date and depth as of 8:00 a.m. 07/24/90 (17) TD: 8650 PB: 8538 SUPV:DEB Complete record for each day reported NORDIC I RIG RELEASED MW: 0.0 Diesel SERVICE RIG, FINISH RUNNING 3-1/2" COMP, TEST SS CONTROL LINE TO 5000 PSI WHEN MADE UP TO SSSV & HANGER, DROPPED BALL & LND HNGR, INSTALLED NEW SEAL RINGS & DRIFTED TBG W/2.850" PLASTIC RABBIT, TOP OF FISH/OLD COMP LEFT IN HOLE @ 7979' RILDS, PRESSURE TBG TO 2500 PSI & SET PKR, HELD TBG & PRESS ANNULUS TO 1000PSI TO COMPLETE PACKOFF, BLED OFF ANNULUS HELD 1500 PSI ON TBG, BOLDS, PU & SHEAR PBR @ 106K, RELAND HANGER & RILDS, TEST ANNULUS & TBG TO 2500 PSI--OK BLED TBG AND ANN TO 1000 PSI-CLOSE SSSV-BLED ABOVE SSSV TO 500 PSI FOR 10 MIN-SSSV TEST OK, EQUALIZE & OPEN SSSV, HOLD 1000 PSI ON ANNULUS, PRESSURE UP TBG & SHEAR SOS @ 3950 PSI, BLED OF PRESSURE, LDLJ, SET BPV, ND BOPE, NU TREE, PULL BPV, SET TP, TEST PACKOFFS TO 5000 PSI, TREE TO 250 & 5000 PSI, PULL TP, RU LINES DISPLACE 12 PPG BGIDGESAL FROM WELL, REV CIRC TAKING RETURNS THROUGH CHOKE, PUMP 10 PPG NACL SPACER FOLLOWED BY CLEAN DIESEL, CONTINUE REV CIRC TO CLEAN DIESEL RETURNS, SHUT DOWN & MONITOR PRESSURE, BLED OFF ANNULUS, TP--1800 PSI AP=.0 PSI, CP-1025 PSI, RD LINES, SET BPV, SECURE WELL RELEASE RIG 2100 7/23/90 DAILY: $75,939 CUM: $881,667 ETD: $881,667 EFC: $690,000 OIdTO J New TD IpB Depth Rel drig .... iDate iKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Inter. al Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Date sF~; f~r o~ e~rue. Pe~r at~ia°rnu aar~l. ~S-e c~: r~ n~Ult J0°.n' ~ 0 Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. DlvlIJon of Atlantld:llohfleldGompa~y OIL AND GAS CONSERVATION ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ ~ Plugging _ Time extension _ Stimulate _ Pull tubing X Variance _ Perforate _ 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 411' FSL, 224' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1979' FSL, 1273' FEL, Sec. 15, T11 N, R10E, UM At effective depth 2146' FSL, 934' FEL, Sec. 15, T11N, R10E, UM At total depth 2175' FSL, 871' FEL, Sec. 15, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8 6 5 0' feet 6756' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 106' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1E-20 9. Permit number 83-5 10. APl number 5o-029-20895 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 2 3 4 5' Intermediate Production 8 5 8 6' Liner Perforation depth: measured 7945'-7974', 8 5 3 8' feet 6 6 6 8' feet Size 16" 10 3/4" 7" 8004 '-8094', Junk (measured) Cemented 1 6 1990 ~,.~Jaska 0il & Gas Cons. C0mmlsslo Measured depth ~'rde ~a~'~pth 290 Sx AS II 80' 80' 235 Sx AS I& 2380' 21 72' 1300 Sx ASIII 2800 Sx Self Stress 8 621 ' 6 733' 8349'-8362', 8382'-8410' MD true vertical 6210'-6232', 6255'-6325', 6521'-6532', 6547'-6569' TVD Tubing (size, grade, and measured depth 3-1/2" J-55 set at 8160' Packers and SSSV (type and measured depth) Baker FHL @ 7769', Baker FB-1 @ 8130', Camco TRDP-1A-ENC @ 1892' 13. Attachments Description summary of proposal Repair leaking upper packer and tubing 14. Estimated date for commencing operation June 12, 1990 16. If proposal was verbally approved Detailed operation program X BOP sketch X 15. Status of well classification as: Oil X Gas __ Suspended Name of a~prover Date approved Service P r O d u c e r 17. I hereby/~/ertify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~ Title ,4R. rc4- O~T,L,C--r_~,- k._.../,,--/r-r~ ~..~ ~ FOR COMMISSION USE ONLY - Conditions of ap~oval: Notify Commis~n so representative may witness Date 5"-15"- ?0 Plug integrity __ BOP Test Mechanical Integrity Test_ Location clearance__ Subsequent form require 10-~~ IApproval No~2~...,.~.~; I Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNiE C. $~iTH Approved Copy Returned Commissioner Date 5- 1'7 SUBMIT IN TRIPLICATE Kuparuk River Unit Well 1 E-20 Preliminary Workover Procedure Pre-Rig Operations , . . Rig Operations 1. . Obtain surface pressure build-up to confirm BHP. RU slickline and pull dummies at 7699' and across "C" sand at 7808' and 8110'. Confirm dummies above 7699' are in place. RU E-line and cut tubing below retrievable pkr and below blast rings. MIRU Nordic #1. . . . . . o , 10. Pump kill pill and circulate 11.0 ppg brine. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. Pull 3-1/2" tubing above upper packer. Inspect GLMs. RIH with RTTS and pressure test 7" casing. POH with RTTS. S. If casing does not pressure test, locate leak by resetting RTTS uphole. Repair as required. if casing passes pressure test, continue with workover. RIH with drill pipe and retrieve Baker FHL packer at 7769'. Inspect packer. Retrieve tailpipe with carbide blast rings. Inspect blast rings and GLMs. Retrieve stub above lower packer. PU new GLMs, blast joints, and tubing as necessary. Rerun single-selective completion assembly same as before with new retrievable upper packer and tailpipe stabbed into original Baker FB-1 lower packer at 8130'. RD, release rig. ~ /-~-~ 1 5000 PSI BOP STACK 1. 9 5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSSOVER SPOOL 4. 11" - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 2. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRILLING SUPERVISOR. 1 5. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORD~ SRE ~89 sssv / GLM DV or GLV KUPARUK FLUID LEVEL REPORT CC: DS Engr. NSK Files OP Engrg. Files Prod. Forema~ Well Fluid Level Shot Down' i~ Casing Tubing CSG Press During Shot =,,20(~O # TBG Press During Shot = ~# Reason For Shooting FL: To Determine Operating Valve Well Status: Fluid Level Fourtd @. /~,¢~ ! Ft On Continuous GL Operating CSG Press= ~ # GL Rate (If Available)= MCFD On Intermittent GL On Time--~ Min. Off Time -- Hr. Min. Delta Time From End Of On Cycle--~ No GL __ Comments: Min, RECEIVED JUL ! 0:1989 011 & Gas'Cons. Commfss~or~ ,.j}chora!.le sssv GLM / ~..~.~ DV or GLV oV Fluid Level Found @ 'Tq'gl tFt KUPARUK FLUID LEVEL REPORT CC' DS Engr. NSK Files OP Engrg. Files Prod. Foreman /'~'~.~..~ Fluid Level Shot Down: Date Casing /,'~ubing CSG Press During Shot = # TBG Press During Shot = '~ I 0 (:3 # Reason For Shooting FL: To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press = ~ GL Rate (If Available)= ~ On Intermittent GL On Time = Min. Off Time-- Hr. Min. Delta Time From End Of On Cycle--~ No'GL _ .~ comments: # MCFD Min. ARCO Alaska, Inc. Date: July 7, 1989 Transmittal #: 7505 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3H-02 30-04 3J-06 3A-05 1E-20 1E-20 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Fluid Level Report 6-21 -89 6-21 -89 6-21 -89 6-21 -89 6-28-89 6-28-89 Casing Casing Casing Casing Tubing Casing _ Receipt Acknowledged: Oil & Gas Cons. Comm~s=Jon ........................... Date' - ........... DISTRIBUTION: BP Chevron State of Alaska Unocal D&M Mobil Attachment ! ! Page 2 Drill Site 1H Wel 1 No. lH-3 ~1H-4 · ,~,{.. '~'~lH-6 ~lH-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA xi)/19/81 1E-2 '-8/17/81"7 _"1/17/84/ 1E-3 '"10/18/81~, '11/7/81/ ',,8/4/80"x, ..~., 1E-5 ~10/27/81~ 1E-6 ~10/21/81~ ~11/12/82/ ~1E-7 ~/28/81~ ~o/28/e~// 1E-8 ~11/1/81/~ 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 E-2e 0/27/82) ~6/13/83 1E-29 ~10/18/8~ ~7/~8/83 / / 1E-30 ~0/16/82 Drill Site 1G Wel 1 No. '%1G-1 '~1G-3 ~1G-4 '~ 1G-8 Log Date 9/7/82 ' 9/25/82%~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Dri 11 Si te Wel 1 No. L.o9 Date 1F '~1F-1 2/19/83 %1F-2 2/3/83 ~IF-3 1/31/83 "lF-4 5/29/83 ~1F-5 10/25/82 '~1F-6 10/28/82~ '~ 1F-7 11/19/82x,~ 5/7/83 RECEiVi ''/''';- FEB 2 1 1986 AJaska 011 & Gas Oons. Commission Anchorage ARCO Alaska, inc ...... Post Officex~ 00360 ..Anchorage, ~daska 99510-0360 Telephone 907 276 1215 FT:~,.T.V:., ,r', 2A~';!D .,..: % ,..- , i ;.., .... ..':' I'q :;. ~ 't FF:AC 2T ]; HUL_ A T I C)N.-/F'O.5']" F'F:tAr.; OH'PL.£TE F:'O.~T F,r;..'¢~L'.;· LOG TA'f'iC BHF'/DHT ?UF.:VEY R r':-F' F;.'.,.".~ C/F:',_ , T' . 'TI I i.iL]: f'J [~... , 'T,::',TI'C ):-.'HP/~:HT .'.'-;'L.!!:,'VE"~' ..... .;,, .... , , i~',]· RE-I" I ', l--i ,_: ;' F', ,"T ., 7'... :.., . A ' Y A N I) F' F;.'. ~-':'., "": F;:SCE i F'T :fi --'. ;:: : ~ i' -" .'.) L_' L. E ..D (; ED ' I) ]1 Z-']' i': ].' '....:."f' *' f"~:-' ' -- ,: .... T" r.'...' ~ , ,' ~,,- I:J~ "' ,.,'." ~: ..... ;,~, .. F' r-'-': ~ ..... ; n', ..... ]" ";" ' E: )::: ?." · ...... li'J.LJ: ;,! "" ~ ;; ;.:. ' r"~ ..-: i f :" F'i'I -r, , I '"' '''? :-': -' :": ,:. ~.:.. · .L ' I.., , ,~.,. -_ .... ,~ · :-, ! "'* I." -" I ~ I", I.~ ,:,., .-, J_: ~_. ~:.. ~ x . I ";( '~ '""" !~' '"'"' :,:' . ~. ' i"l I ~, i-~. L.._ :-:. ," .. ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. on Well Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reper f 1E-7 Fracture 3/1/85 1E-8 Reper f 1/28/85 1E-11 Reperf 2 / 1 / 85 1E-11 Fracture 2/7/85 1E-1 8 Fracture 3/1 3/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3 / 23 / 85 1E-22 Fracture 3 / 22 / 85 1 E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/1 8/85 1Q-1 0 Fracture 3/5/85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conver s i on 3 / 12 / 85 2A-5 Convers i on 3 / 12 / 85 2A-6 Convers i on 3 / 1 2 / 85 2A-7 Conve rs i on 3 ! 12 / 85 2C-4 Reper f 2 / 23 / 85 2D-4 Reper f 2 / 2 / 85 2V-8A Convers i 2X-8 Perforation 1/27/85 If you have any questions, please call me at 263-4253. Mike L.. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-5 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20895 4. Location of Well SURFACE LOCATION' 411' FSL, 224' FEL, SEC. 16, T11N, RIOE, UM BOTTOM HOLE LOCATION' 2175' FSL, 871' FEL, SEC. 15, T11N, RIO.E,6 UM 5. Elevation in feet (indicate KB, DF, etc.)/ . Lease Designation and Serial No. 106' (RKB) ADL 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER UNTT 10. Well Number 1E-20 1 1, Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL P00I Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 March 23, 1985, the "A" sands of Kuparuk well 1E-20 were hydraulically fractured and propped to improve production. treatment consisted of 300 BBLS of gelled water as pad and fluid and 13,230 LBS of 20/40 sand as proppant. 35 BBLS of diesel was used as a flush. The carrying gelled Prior to pumping, equipment and lines were tested to 5900 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS The space below for Commission use 3/27/85 COORDINATOR D~te Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev_ 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Co.mmission 3001 Porcupine Drive Anchorage, AK 99501 Oear Mr. Chatterton' Attached in duplicate are subsequent following wells at the Kuparuk River Field Wel ! Action Date Pe 1E-6 Fracture 1/26 1E-7 Reper f 1E-7 Fracture 3 / 1 / 1E-8 Reper f 1 /28 1E-11 Reperf 2 / 1 / 1E-11 Fracture 2/7/ 1E-18 Fracture 3/13 1E-20 Stress Frac 3/19 1E-20 Fracture 3/23 1E-22 Fracture 3/22 1E-24 Fracture 3/22 1 L-6 Fracture 2 / 2 / 1L-7 Fracture 1/30 1Q-9 Fracture 3/1 8 1Q-1 0 Fracture 3/5/ 1Q-12 Fracture 3/5/ 2A-3 Conversion 3/21 2A-4 Conversion 3/12 2A-5 Convers i on 3 / 1 2 2A-6 Convers i on 3 / 12 2A-7 Convers i on 3 / 12 2C-4 Reper f 2/23 2D-4 Reper f 2 / 2 / 2V-8A Convers i on 2X-8 Per fora t i on 1 / 27 If you have any questions, please Mike L. Laue Kuparuk Operations Coordinator call me at 2 MLL/kmc Attachment (Duplicate) notices rformed /85 85 /85 85 85 /85 /85 185 /85 /85 85 185 /85 85 85 /85 /85 /85 /85 /85 /85 85 /85 63-q253. on the ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-5 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20895 224' 4. Location of Well SURFACE LOCATION. 411' FSL, FEL, SEC. 16, TllN, RIOE, UM BOTTOM HOLE LOCATION' 2175' FSL, 871' FEL, SEC. 15, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ]06' (RKB) I ADL 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1E-20 11. Field and Pool KUPARUK RIVER KUPARUK RIVER POOL Check Ap~)ropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 March 19, 1985, the "A" sands of Kuparuk well 1E-20 were stress frac'd. The treatment consisted of two runs with the frac tools. stress Prior to starting the job, equipment was tested to 2500 psi. The stress frac was done to enhance an upcoming hydraulic fracture. It was done in lieu of the re-perforation proposed on January 25, 1985. RECEIVED Alaska Oil & Gas Cons. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARU K Signed Title 0 P E R A T I 0 N S The space below for Commission use 3/27/85 COORDINATOR Date Conditions of Approval, if any' Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Submit "Intentions" in Triplicate ARCO-Alaska, Inc. Post Offic Anchorage, ,.,laska 99510 Telephone 9137 277 5637 TransmittAl No: 4842 RETUR~ TO: .. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the foil%wing items. Please acknowledge receipt and return one signed copy of this transmittal. PL FI~I,DS Dresser /2 11/o5/s Run 1 G-13 Collar Log '4" Perf" /,/?_,-15-° " " ' 11/06184_ " ~8 " " "~/G Ring/Set P~er" 10/30/~ ~ 1 /2V-6 Spinner Log 8/31/0Z..: tkm 1 Schl~m~o_.erger f' 22f-5 Dua~ Spacing Thermal Neutron Decay Time "TDT" 7550 - 7746 6550 - 6750 6844 -.7221 5900- 64OO 11/02/84 Run 1 8210- 8658 2D-lO Temperature ' qmrefrac" T, Tamp "Spinner Log" "HP/FD" " " " ' ~Fluid Density" 11/09/84 Run I 8130- 8500 11/09/84 Run 1 7160- 7450 11/06/84 Run 1 3620- 6620 11/08/84_ Run 1 6800 - 7080 /cat Receipt Acknowledged: B. Currier BPAE Chevron D & M DISTRIBUTION Drilling Geology Mobil NSK Ops. W. Pasher State of AK G. Phillips Sohio Phillips Oil Union J. Rathmell Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 · Dear Mr. Chatterton: Attached is our notice of intention to perform a Stressfrac treatment on Kuparuk Field well 1E-20. If you have any questions, please call me at 263-4253. ~r ~ ~;~erations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED FEB t ~ 19~5 AlaSka ~',; & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (alL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-IX 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-5 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20895 OTHER [] 4. Location of Well SURFACE LOCATION: 411' FSL, 224' FEL, SEC. 16, TllN, R10E, UM BOTTOM HOLE LOCATION: 2175' FSL, 871' FEL, SEC. 15, TllN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' (RKB) 12. 6. Lease Designation and Serial No. ADL 25651, ALK 469 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-20 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: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). It is proposed that the "A" sand in Kuparuk well stress frac'd to optimize stimulation. Proposed Intervals (MD): 8349'-8362' 8382'-8410' (4 SPF) 1E-20 be ANTICIPATED START DATE: February 16, 1985 RECEIVED F E 1 4 1985 Alasi~a O~i & Gas Cons. Commission Anchora[la KUPARUK 14. I hereby certify that the foregoing is true and correct to the best of my kgol~W~j~gk. COORDINATOR Sign ed ~L~~~-~. ~-' ~/~i ~' The space below for Commission use 2/14/85 Date Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER /kpproVe41 Cc~7 By Order of ~ ~ the Commission Date Submit "lntent~ns" in Triplicate and "Subsequent R~orts" in Duplicate ARCO Alaska, Inc. Post OfficeBr ~d0360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 7, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports and Workover Well Histories for the following wells' 1E-22 1E-24 If you have any questions, please call me at 263-4944. Sincerely, d~Gruber Associate Engineer JG/tw GRU4/L135 Enclosures RECEIVED FEB 0 B 1 B$ Alaska 0i~ & Gas Cons. CommiSslom Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~--. ALASKA" AND GAS CONSERVATION IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-5 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20895 4. Location of well at surface 9. Unit or Lease Name 411' FSL, 224' FEL, Sec.16, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1979' FSL, 1273' FEL, Sec.15, T11N, R10E, UM 1E-20 At Total Depth 11. Field and Pool 2175' FSL, 871' FEL, See.15, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBI ADL 25651 ALK 469 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 01/21/83 01/30/83 02/03/83J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8650'MD,6756'TVD 8538'MD,6668'TVD YES [] NO []I 1892 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DI L/GR, CBL 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 80' 24" 290 sx AS II 10-3/4" 45.5# K-55 Surf 2380' 13-1/2" 1300 sx AS Ill & 235 s; AS I 7" 26.0# K-55 Surf 8621' 8-3/4" 1050 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) 8382' - 8410' 3-1/2" 8160'' 7769' & ~130' 8349' - 8362' w/4 spf, 90° phasing 8004, - 8094, 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. ,~" 7945' - 7974' DEPTH INTERVAL (MD) AMOUNT& KIND OF/MATERIAL USED N/A -, 27. N/A 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 CHOKE SIZE IGAS-OILRATIO TEST PERIOD I1~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED F E 0 8 1985 Alaska OJ~ & ~aS Cons. Commission Anchorage Form 10-407 GRU2/WC25 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 6208' 6361' 6509' 6618' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 7943' 8141' 8333' 8474' 31. LIST OF ATTACHMENTS Workove, r Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engr. Date 2-4-~g INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF~ KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field Kuparuk River Auth. or W.O. no. AFE Exp 304930 County or Parish Lease or Unit Title North Slope Borough ADL 25651 Recomplete State Alaska JWoII no. 1E-20 Operator WWS #1 ARCO Alaska, Inc. Spudded or W.O. begun Workover Date and depth Complete record for each day reported as of 8:00 a.m. 2400 hrs. 11/02/84 Old TD Released rig Classifications (oil, gas, etc.) Oil API 50-029-20895 A.R.Co. W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and 56.24% Jabandonment of this well I Date IHour I Prior status if a W.O. 10/27/84 ! 0630 Hrs. NU Tst pack-off to 5000 psi. Pull BPV, set tst plug, tst tree to 5000 Pulled tst plug. Displ well w/30 bbls diesel, followed by crude Set BPV. Secured well. RR @ 2400 hrs, 11/1/84. 7" @ 8621' 8538' PBTD, RR Crude & diesel in well to GLM @ 7699' Fin PU 3½" compl BHA, RIH w/3½" compl string to Camco SSSV. PU Camco SSSV, RIH w/3½" tbg holding 3000 psi on contrl In, stabbed into Bkr FB-1 pkr @ 8130'. Press tbg to 400 psi to verify position. Spaced out. MU hgr & lnd'g it. RU contrl in to hgr. Dropped setting ball, lnd tbg. Rn in lockdn screws. Press tbg to 2500 psi to set pkr; press dropped to 1500 psi. Sheared off of Bkr SBR w/40,000# over. Reconnect 1/4" contrl In, opened SSSV. Re-lnd tbg. Press back up on tbg to 1500 psi w/press bleeding dn to 600 psi. BO & LD lnd'g jt. Set FMC BPV. ND stack. tree. psi. oil. ECEIVED F E 0 8 1 85 Choran~ Co~rnlssln~ PB Depth o,-, 8538 ' PBTD 11/01/84 Knd of rg Rotary Type completion (single, dual, etc.) Single INew TD Date Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data !Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct For form preparation and~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Well History - Initial Report - Dally Inatruetlon~: Prepare and submit the "initial Rel~rt" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE Exp 304930 wws #1 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25651 Title Recomplete IState Alaska IWell no. 1E-20 W/O API: 50-029-20895 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover JDate ]Hour 10/27/84 Date and depth as of 8:00 a.m. 10/29/84 10130184 10/31/84 11/01/84 Complete record for each day reported ^Rco w.~. 56.24% Pr or status If s W.O. 0630 Hrs. 7" @ 8621' 8538' PBTD, Circ 11.0+ NaC1/NaBr Move rig f/1E-18 to 1E-20. Accept rig @ 0630 hrs, 10/27/84. RU to kill well. Pull BPV. RU Camco S/L, tst. RIH to GLM @ 7768', pull dummy vlv, POH, RD Camco. Bleed off tbg press 2600 psi to 1500 psi. Fluid to surf. Kill well dn tbg w/55 bbl BridgeSal pill w/ll.1 ppg brine, placing top of pill below btm GLM. Displ ann w/ll.1 ppg brine. C&C brine, observe well. Set BPV. ND tree. NU BOPE, tst all BOPE to 3000 psi. PU lnd'g jt, POOH w/tbg. SBR was sheared. POOH w/3½" CA, chg'g all colrs to AB Modified. PU Bkr SBR retrv'g tl & RIH. PU DP. RIH, PU DP to pkr @ 7833'. Wsh over slick it, latch onto pkr & rotate loose. CBU. 7" @ 8621' 8538' PBTD, RIH to Ret Bridge 11.1NaC1/NaBr, PH 7.5 Circ out gas, observe well. POOH w/pkr. PU ret bridge plug, RIH. Set bridge plug @ 7800'. Tst to 1500 psi, POOH. ND BOPE, chg out 11" 3000# tbg hd, instl 7-1/16" 5000# tbg hd. Tst BOPE to 5000 psi. Pull tst plug. RIH w/ret tool to pull bridge plug. 7" @ 8621' 8538' PBTD, POOH w/bit & scrpr 11.1NaC1/NaBr RIH w/retrv'g tl to BP @ 7800', rel BP & POOH. PU RAM pkr, RIH, set pkr @ 7500'. Tst csg to 3000 psi. Rel pkr, RIH, bridge @ 7945', POOH w/pkr. PU bit & 2 csg scrprs, RIH, wsh & rm 7945'-8538', circ hole cln, POOH. 7" @ 8621' 8538' PBTD, PU carbide blast ]ts 11.1NaC1/NaBr Fin TOH. RIH w/Bkr retrv pkr to 7500', set pkr @ 7500'. Press tst 7" cs§ to 3000 psi f/15 min. RIH to 8254', set Bkr pkr. Press "A" sands to 1500 psi f/comm tst; no comm. RIH, tag PBTD @ 8540', POH, LD 3½" DP. RIH w/6.0" OD gage ring/JB to 8450', POH. PU Bkr FB-1WL pkr & tailpipe assy. Set pkr @ 8130', RD DA. PU tbg completion BHA. rec q The above ia correct Signature o p p o d I~rstribution, ~ For f I ~'""~"~ see Procedures Manual, S§ctlon 10, Drilling, Pages 86 and 87. Date 11/19/84 {Title Drilling Superintendent ARCO Alaska, Inc.~ ~' Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached are our notices of intention Field well 1E-7 and re-perforate wells 1E-20. to fracture Kuparuk 1E-7, 1E-8, 1E-11 and If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) I £CEI v£D JA IV 2 ~ ]985 Alaska Oil &.Gas Cons. Commission ~nChorage ARCO Alaska, Inc. Is ast, bsidiary ol AllanticRichfieldCompany '~ ' STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-5 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 029-20895 OTHER [] 4. Location of Well SURFACE LOCATION' 411' T11N, RIOE, UM FSL, 224' FEL, SEC. 16, BOTTOM HOLE LOCATION' 2175' FSL, 871' FEL, SEC. 15, T11N, RlOi, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' (RKB) ADL 25651, ALK 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-20 1 1. Field and Pool KUPARUK RIVER KUPARUK RIVER 469 P001. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data FIELD OIL NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate []X] 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). It is proposed that the "A" sand in Kuparuk well 1E-20 be re-perforated to enhance subsequent stimulation. Procedures call the well to be perforated with a wireline conveyed gun under a lubricator. for Proposed Intervals (MD)- 8349'-8362' (4 SPF) 8382 '-8410' ANTICIPATED START DATE' January 28, 1985 RECEIVED .JAN 2 5 1985 Gas Cons. C0mmis Anchorage 14. I hereby certify that the foregoing i true nd correct to the best of my knowledge. Signed .... Title OPERATIONS The space below for Commission use COORDINATOR 1/25/85 Date Conditions of Approval, if any: Approved by COMMISSIONER Approved Cop7' Returned By Order of the Commission ;ion Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 4, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-20 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L118 Enclosures If RECEIVED /Uaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CON, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLxI~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 411' FSL, 224' FEL, Sec.16, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' 12. 6. Lease Designation and Serial No. APl ?~;651 Al K ~_69 7. Permit No. 83-5 8. APl Number 50-- 029-20895 9. Unit or Lease Name K.n~r,,k I~v~r I_1~_ , 10. Well Number 1E-?0 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: SUBSEQUENT REPORT OF' (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.) (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). Accepted rig ~ 0630 hrs, 10/27/84. Killed well. ND tree. NU BOPE and tstd to 3000 psi - ok. Pulled tubing & pkr. RIH and set retrievable pkr @ 7500'; tstd csg to 3000 psi - ok. Released pkr & POH. Washed and reamed to PBTD. RIH w/retrievable pkr & set ~ 7500'; tstd 7" csg to 3000 psi - ok. RIH & set pkr 8254'; pressured "A" Sands to 1500 psi -- no communication with "C" Sands. Tested lubricator to 1000 psi - ok. Ran gauge ring/JB to 8450'. RIH & set FB-1W/L pkr ~ 8130'. Ran 3-1/2" completion assembly w/tail @ 8160', FHL pkr @ 7769' & SSSV ~ 1892'. Dropped ball & set pkr. Set BPV. ND BOPE. NU tree & tstd - ok. Disp well w/diesel & crude. Secured well & released rig @ 2400 hrs, 11/02/84. RECEIVED Alaska 0il & Gas Cons. C0mmissi0r~ Anchorage 14. I hereby//~ that the foregoing is true and correct to the best of my knowledge. Signed ~ /,~'~--~~~" ,~-~' Title Area Dril ling Engineer The space ~'l/~w ,~r ~/~ission use Conditions of Appr~l, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 GRU2/SN42 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In?~- "'--" Posl Offic ,X ~. _ Anchorage, Alaska 99510 Telephone 907 277 5637 November 13, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to fracture the following Kuparuk Field wells: 1E-5, 1E-8, 1E-11, 1E-18, 1E-20 y questions, please call me at 263-4253. /~Mi L Laue Mik~ L. Laue _ _ Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED Nov Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany ~"' ' STATE OF ALASKA ALASIxA OiL AND GAS CONSERVATION ~;Ch~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-5 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20895 4. Location of Well SURFACE LOCATION- 411' T11N, R10E, UM FSL, 224' FEL, SEC. 16, BOTTOM HOLE LOCATION. 2175' FSL, 871' FEL, SEC. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' (RKB) ADL 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-20 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). It is proposed that the "A" sand in Kuparuk well 1E-20 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid' Gelled Water 363 BBLS Gelled Diesel 61 BBLS Proppant- 12/20 Sand 14,910 LBS RECEIVED NOV ANTICIPATED START DATE- November 18, 1984 Alaska Oil & Gas Cons. commission Anchorage 14. I h~c~fy that th~ fIll, / g is true and correct to the best of my knowledge. o~j.. KUPARUK 11 / 1 3 / 84 ~~' I¢~1~,.. I~1., I,~ ~t~f~ Title OPERAT IONS COORD I NATOR Signed Date The space bel~)w for Commission use Conditions of Approval, if any: Approved by ,~pproved Ccpy t~.turned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir' Post Offic. Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-20 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-20 to a selective single, completion. Since we expect to start this work on October 28, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kew in Area Dril ling Engineer JBK/JG/tw GRU2/L13 Enclosures RECEIVED OCT 1 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLxI~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 411' FSL, 224' FEL, Sec.16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' 12. 6. Lease Designation and Serial No. ADL ?c,F,c, 1 Al K 469 7. Permit No. 83-5 8. APl Number 50-- 029-20895 9. Unit or Lease Name 10. Well Number 1F-?O 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: SUBSEQUENT REPORT OF' (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.) (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 convert well 1E-20 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. A squeeze will be performed, if required. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 500~psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 28, 1984 d correct to the best of my knowledge. 14. I hereby certify that ~ foregoing i~ ~.~/~,stru'/~ Title Area Drilling Engineer Signed , . The space below for Commission use RECEIVED Alaska 0il & Gas Cons. Commission Anchor~? Conditions of Approval, if any: Approved by ^pproved C,~py Return~ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 GRU2/SN17 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address Po O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 411' FSL, T11N, R10E, UM ' 224' FEL, SEC. 16, BOTTOM HOLE LOCATION' 2175' FSL, 871' FEL, SEC. 15, T11N., R10Et UM 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 106' (RKB) ~ ADL 25651, ALK 12. 7. Permit No. 83-5 8. APl Number 50- 029-20895 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1E-20 11. Field and Pool KUPARUK RIVER KUPARUK 469 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 April 16, 1983, Kuparuk River Unit Well 1E-20 was stimulated with 12% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was - ~ psig and the maximum wellhead pressure was ~ psig. Diesel was used to displace the acid. Nitrogen was injected bia the coiled tubing and circulated intermittently with diesel to aid in cleanup. Following the cleanup period, the well was switched to the CPF. TOTAL AMOUNT USED' Acid 178 BBLS Nitrogen Volume not available Diesel 82 BBLS 14. I hereby certify, that th~ foregoing is true and correct to the best of my knowledge. Signed ~~ ~~ TitleKUPARUK The space below for Commission use OPERAT IONS COORD I NATOR Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission · 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are subsequent reports of stimulations performed on the following Kuparuk River Unit Wells: 1E-20 1E-21 1E-22 1E-23 1E-24 1E-26 1F-7 1F-8 1G-4 1Y-14 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Duplicate) cc: W. Crandall/T. Best R. Ruedrich R. May ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany - I,,qJPARUK EI',~ 1 NEF. R I NG TO: ~ .t-~~ FR~: D, ~¥. BoselShelby J. ~tthews'' Transmitted herewith are the fol Iowincj' PLEASE IA)TE: BL - BLUELINE, S SEPIA, F - FILM, T - TAPE, IF_--- ?__o ~r~~o:~ F-T~ED: - ~P/LEASE P.E-I1JP~I RECE 1 PT TO: K1JP~< ENG I NEER! TRANSMITTAL TO: Will iam VanAlen FR(~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the fol lowing- PLEASE NOTE: ~'2~~F - F! ~4, T - TAPE, PC - PHOT~PY · PLEASE RERJRN RECE! PT TO: ARCD ALASKA, I bt:. AT1-N- SHELBY J. ~/ATI'HB,~S - ATO/1115-B P. O, BOX 100360 AhID-E)RAGE, AK. RECEIVED J U N ~ 0 1883 99510 Alaska Oil & (j,-ts *. ~,~;~ ~.,~H,ilIIlS$iOo Anchorage KUPARUK ENGINEERING TO' Wil'liam V-~-n Alen~ DATE- ,.'~)---',~,,,~- ~'~..~ TRANSMlrTTAL ~ FROM- D.W. Bose/Shelby J. Matthews WEEk NAME- ~~. Transmitted herewith are the following' PLEASE NOTE'~E, ~A, F - FILM, T - TAPE, PC - PHOTOCOPY C( R~-~ ACKNOWLEDGED: - ~.,/~LEASE RETURN RECEIPT · Alaska 011 & ~as Corm. L, ommissiorl DATE· Anr:.hnr;me . ARCO AEASKA, INC. ' A'TTN' SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office B6x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 14, 1983 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Attached are notices of our Wells 1E-20, 1E-22, 1E-24 tubing. If you have any 263-4527. intent to stimulate Kuparuk Unit and 1E-26 with acid via coiled questions, please call me at Kuparuk Operations Coordinator CKH/kj¢ Attachment (In Triplicate) xc' W. L. Crandal 1/M. D. Schall R. A. Ruedrich - ANO 332 H. C. Vickers - AFA 326 - Kuparuk, North Slope ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COIvIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, :INC. 83-5 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20895 OTHER 4. Location of Well SURFACE LOCAT:ION' 411' FSL, 224' FEL, SEC. 16, T11N, R10E, UN BOTTOM HOLE LOCATION' 2175' FSL, 871' FEL, SEC. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (RKB) I ADL 25651, ALK 469 12. 9. unit or Lease Name KUPARUK RIVER UN:IT 10. Well Number 1E-20 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ]~ Abandon [] Stimulation [] Aba ndonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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 acidize Kuparuk River Unit Well 1E-20 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. The treatment will consist of 7480 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to 4000 psig and the tubing pressure will be limited to 1500 psig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. · During cleanup the well will be produced to tanks on location. Following the cleanup the well Expected start date' will be produced to CPF1. April 15, 1983 _'_~!~i. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed d~/~ ~----¢~1~"/ ~,/d~Title The space belovC/for Commission ~se Conditions of Approval, if any: O l i,qAL SIGNE[J ,Returned I~¥ LO~l[ C. SMIT~ By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate William VanAlen Transmitted herewith are the following: PLFASE NOTE:~ F - F~I, T - TAPE~ PC - PHOTOCOPY ~ AT. ASKA, :mC. MAR 1 ATTN: ~ - ~311 ..... 0ohs. Commissiorl P. O. ~X 360 ~X, ~2~;.~~ 0il & Gas . I '~ ,,~ Anchprage ~O~, ~. 99516 ~AF'CO/~laska, Inc. ~ Post Office B( .,0 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19' 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well Ravik State #1 #1 A1 so enclosed are well completion reports for' 1-24 1E-21 2-8. '1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 1'3-9. ARCO Alaska, Inc. is a subsidiary of-AtlanlicRichfieldCompany ~,? ' ...... STATEOF ALASKA ,.-- - ALASK,-.. ,_AND GAS CONSERVATION MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY[~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-5 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20895 4. Location of well at surface ~~S,T 9. Unit or Lease Name 411' FSL, 224' FEL, Sec. 16, T11N, R10E, UH Kuparuk River Unit At Top Producing Interval I '¢'ER,~ED / 10. Well Number 1979' FSL, 1273' FEL, Sec. 15, T11N, R10E, UM ISurf'~-~ 1E-20 At Total Depth ?-~--J 11. Field and Pool 2175' FSL, 871' FEL, Sec. 15, T11N, R10E, UH Kuparuk River Fie]d 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 106' RKB ADL 25651 ALK 469 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 01/21/83 01/30/83 02/03/83 N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8650'MD,6756'TVD 8538'MD,6668'TVD YES I~ NO [] 1909 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run FDC/CNL/DI L/GR, CBL 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 80' 24" 290 sx AS I I 10-3/4" 45.5# K-55 Surf 2380' 13-1/2" 1300 sx AS Ill & 235 sx f5 I 7" 26.0# K-55 Surf 8621' 8-3/4" 1050 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) 8382' -8410' 3-1/2" 7862' 7833 ' 8349'-8362' 4 spf, 90° phasing 8004'-8094' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7945' -7974' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure . CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core,c, hi.p.s~ None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 6208' 6361' 6509' 6618' 30. FORMATION TESTS Include interval tested, pressure (]a~a, all ,~lu~(ls ,ecovered and !lr~lvlt¥, GOR,and time of each phase 7943' 8141' 8333' 8474' 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 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water-In jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 1E-20 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1400 hrs, 01/21/83. Drld 13-1/2" hole to 2410'. Ran 57 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2380'. Cmtd 10-3/4" csg w/1300 sx AS III & 235 sx AS I. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 8400'. Ran FDC/CNL/DIL/GR. Cont. drlg 8-3/4" hole to 8600'. Ran DIL/FDC/CNL/GR. Cont. drlg to 8650' TD (01/30/83). Ran 217 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 8621'. Cmtd 7" csg w/1050 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro and CBL. (PBTD = 8538'). Perforated the following intervals w/4 spf, 90° phasing: 8382'-8410' 8349'-8362' 8004'-8094' 7945'-7974' Ran 3-1/2" completion assy w/tail @ 7862', pkr @ 7833' & SSSV @ 1909'. Tstd tbg hanger and packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Secured well & released rig @ 1000 hrs, 02/03/83. JG2DH15.sm 03/09/83 0 ARCO AL-ASKA, INC, GYROSCOPIC DIRECTIOHAL SURVEY , RADIUS OF CURVATURE HEYHOD OF COHPUTATION SURVEY RAN BY CHRPPELL COHPUTED FOR SDI BY OCERNTECH(FH LINDSEY & RSSOC,) RECORD OF SURVEY TRUE M'~o DRIFT VERTICAL SUB DRIFT DE .H ANGLE DEPTH SEA DIREC D M DEG, 0 '0 0 1.00 0 13 200 0 22 3.0 O 0 11 40'0. 0 t'O 5O0 0 2 6 O0 0 5 7'00 ,0 12 8.0.0 1 35 900 5 29 'lO00 9 5 tl.00 13 18 12.00 .f6 57 , 0 21 37 O0 '26 0 15.00 28 '44 1600 28 20 17:00 29 37 1800 32 44 190.0 36'27 2000 39 58 21,,00 42 44 2200 42 I1 23.00 42 23 .00 1'00.00 200,00 300 O0 400 O0 500 O0 6O0 O0 7OO O0 799 98 899 77 998 95 1097 03 '1193 54 1287 91 1379 38 1468.18 1556,03 1643.51 1729,06 1811.37 1889,93 1964.99 2038.77 2112,75 -106,00 N ,OOE -6,00 H82.25E 94,00 $29,3.8E 194,00 S 8,98E 294,00 'S14.90W' 394,00 N22,75E 494,80. N54,28E .594,00' N27.43E 693,98 H55.S3E 793,77 H61.98E 892,95' N64.08E 991,03 N64,25E I087,54 t{63,t8E 1181,91 N62,82E 1273,38 t464,98E 1362,18 t466,58E 1450, O~ t,165.47E 1537,51 H66.605 t623.06 t167,~0E 1705.37 H67 , 45E 1783,93 H67,63E 1858,99 N67,?OE 1932,77. H68,07E 2006,75 H67,83E 0 JOB t,lO 1360 KUPRRUK E-20 KB ELEV 106,00 FT. SURVEY DATE 02..,'01/83 TOTAL COORDINATES 36 14 E 59 53 E ' 88 95 E 125 19 E 1'67 t 0 E 210 75 E 255 01 E 302 64 E 355. 03 E "412 19 E 473 29 E 535 83 E 598,19 E 40,30 66,39 99,40 139.76 185,69 233,44 281 ,87 333.59 39 O, 32 452,13 518. t5 585.62 652.88 17,84 H 29,39 N 44,38 N 62,13 N 80,98 N J00,39 N 120.07 H 140,34 162. 1'7. N 185,80 H 210,90 N 236,31 N 261.57 'N DOG LEG SEVERITY DEG/IOOFT D H S 90 0 82 15 .0 E 73 3 8 E 5026 49 E 38 49 39 E. 41 32 41 E" 45 5'5 54 E . 56 44 37 E ?8 15 '2 E 63 4~' 40 E 63 19 34 .E 63 43 51E 63 43 31 E 63 29 3 E 63 36 15 E 64 8 36 E 64 31 42 E 64 47'13 E 65, 7 21E 65 27 0 E 65 44 9 E 65 58 55 E 66 12 4 E 66 22 53 E .000 ,217 ,150 .183 ,017 ,133 .050 ,117 1,383 3. 900 3,600 4,217 3,651 ,4o3 , ,17'3 I .31.3 3,123 3.717 3,518 2,767 ,574 ,226 SECT I ON I STANCE O0 50 37 46 55 76 2,1.3 8,19 20,79 40,12 66,09 98.91 1.39.10 184.98 232.68 281 . 05 332.77 389,50 451 51.7,3~ 584.84 652.11 © ARCO KOP, ARUK 'E-20 · SURFACE LOCATION .. . 411'NSL 224 WEL SE .6,'.T!IH,RIOE :. SURVEYE'D- 0'1 FEB 83 KB EL. EV 1 06,00 FT, HENS. DEPTH AHGLE 2500 26.00 2708 ,~...'..200.0 "29.0.0 3000 3i O0 32 O0 33100 340'0 35:00 36~00 37'0'0 38.0O ". 3.~ 'nO ":::':,,d, ,o ,4108 4200 - 43:00 .448.0 45:00 4600 47 O0 4880 ' 4900 50O0 51,0'.0 ;' ' 'TRUE DRIFT VERTICAL." ~U.B DEPTH "'.~,: ~'~EA D . 4:0' 43 44 4 45 45 44 44 . · · 58 2187,~4 59 ' 22'61',19. 44 .2332,69' 44 :.34 03, ;'3 13 2474,47 .4. 2545,~01 33 ':'. 2615,95 22. 2607;33 45 2'.'0 '275.8 46' 23 ' 2827,07 44 52 '2897,80 ,'9 2968,50 15 3038 ;96 47 '3109,'03 20 3t79,05 2 59 42. 31 31 2 28 56 '4 28 12 16 16 3248,28 '3316,47 3384,23 3451, O1 ' 35 ! 7,25' 3586 ,'35 3657,3.7 3.727,2 ! 3796,67 3065,00 3934.,05 4004,65 4075,03 45 45. 45 47 46 47 40 48 44 45 46 46 45 45 RECORD OF SURVEY. ' · ; ., . . · DRIFT TOTAL.COOR~,I~TES'. DIREC "' DEG, · ~08i',44 N68.18E '? ::.31'55,19' N68,82E. 2226,69' N68,6'OE 2297,73 N68,92E ~:2368,47." NTO,67E '.'.8439',01 "N?'O,93E ,~50~,95 .'N71,77E 250to.33 N72,.OSE 2652,'22:='H?2072E 2731',87 .N74~32E 2791,80 N75,47E 2862,50 N75,82E' '.2932,96 N76o53E 3.003,03 NTZ,43E 3073,05 NTe,55E 3142,28 N79,55E 321'0,47 NOO,58E 3278",23 NO1~57E 3345,0! NOO.45E 3411,25 N76,37E 3480,35 N69,38E 3551,37 N65,40E '3621,21 N64,13E 3690,67 N64,65E 3759,80 N65,37E "3028,05 N65,73E 3890,65 N65,90E 3969,.03 N66,7OE ' CLOSURES DISTANCE ANGLE D I'1 206,4,? H 659,0'4 E 3'11,22 N' 722,66 E 336,60 H'' ?e?,80 E' 362,~'a ~. 853,4.0 E 306~52.N :.919,.73 E 4'09-,03 N"":"'~86,67 E ~....,.'i;053;44 E .. 7'!9,34 H 66 31 54 E 78.6.,82 N 66 42 2 E 056,70 N 66 51 52 E 927,04 N 67 0'29 E 99?°64 N 67 12 19 E 1'068,40 N 67 26 37 E 432,' 454 475~ 514, 531, 548,9~ 565, .O 1', · . 579,06 H 160!,80 E 593,57 N 1672.,64 E 6'06,19 N 1:~44,69 E 617,6'0 N 181.7,34 E 629,23 N ~890.o86 E 644,28 t4 1964..,23 E 665,54 N 2:033.24 E 692,6'0 N 2098,21 E 723,11N 2162,95 E .754,2'0 H 2227°82 E 784,73 N 2293.31E 814,67 N 2359,16 E 844o~00 N. 2424,48 E 872,.56 H 24~9,53 E ., 1703o53 N 70 5 57 E 1774,84 N 7.0 27 42 E 1847,00 N 70.50 25 E 1919,'41 N 71. 13 49 E ~!992,81 N 71 2067°20 N 71 2139,39 N 71 2209°57 N 71 2280,62 N 7! 2352,02 N 71 2423°'85 N 71 2495,06 N 70 56 56 E 2567,19 N 70 48 22 E 2638;~1'H 70 41 5 E 35 38 E 50 24 E 52 30 E 43 56 E 30 5! E 17 49 E 6 36 E DOG LEG SEVER I TY DEG?I t3 OFT 1 ,425 3,032 ,758 ,223 .I , 005 ,201 660 230 I 024 I 34.'1 I 621 .33.3 ,.375 ,706 ,722 I ,702 ,555 ,896 1 , 029 3,059 5,611 2 480 8'0,.7 2")9 549 · .328 93;" .568 S E {;: 1' I C, H D I S T R I'.t C.: E 71:9 ~:'~' 786 1 0 :356 01 9 :-2. 6 :?; 9 997 0 i 0 E, 7' 92 i i :3 F3 :'3,1 .... l '..2 ,.' ?3 71 i 3 ~::; 0 26 -.~ ¢~ 14.31 ... ~3 ~:. . i491 '!35 ..,~2 07 i 6:32 75 '17'0.3..30 I 7'74 .38 I 8 46 2, 0 ~918 16 1991 01 '" i :3,3 2.1': 0 / 34 .:i:','i' ;.,.., ':~ 7 0 '" 5 ":" {'i .'3 '2.i 22 ,15 2,566, 13 ::.'.'637,08 ,. ARCO KUPARUK E-20 · SURFACE LOCATIOH TRUE HERS, DRIFT VERTICAL DEPTH RHGLE DEPTH. D FI- t~ .0 44 50 5300 .44 .34 5400 44 54 550'0 44 2.? 5600 44' 56 "570~0 43 46 58'0O 43 ;20 59.00 42 56 60O0 42 32 · 6'1.0..0 42 3'0 6200 42 3 630.0 42 23 ,64~00 42 16 ~.500 41 59 66.0.0 41 30 67'00 4.0 23 6~ ~0 39 42 ~O::O 38 44 700'0 39 2 710.0 38 50 7200 38 56 73.0'0 38 48 74'.00 30 32 75.0.0 38 21 ?60'0 38 49 ,7.700 38 25 7800 39 1 79.00 39 i6 GYROSCOPIC SURVEY .JOB HO '1360 4'1 I 'HSL, 224 ' WEL, SEC 16:,"T l"1 H, R I'.OE , f · ,, , SURVEYED- O1 FEB :33 KB ELEV i06.00 FT. RECORD OF SURVEY DRIFT D. IREC DEG, . : --TOTRL COORP!:H~tTE$ o, H66,85E ~00,46, H ' H6?.87E .: 927,54 H H6?,77E 954,12 H H67,32E 980:,97 H'.L'2749,63 E ,. N68o20E 1:0:07;59 N '281.4,73 E 4501,50: 4~95~'50' H67,95E'-IO~3,?O H 2879,58 E 4573;98 4646,96 4720, 1' 4794,~2 4868,11' 4942.17 50 ! 6; l,O 5090 5164 5240.42 5316,98 5394,46 5472,84 5551018 5629,02 57'06,88 5784,96 5863,28 5941,45 ~0~9o59 6'097o6t 617501? 2554,57 E ~6'19'; 49 E 2684-. 66 E :CCOSURES D I STAHCE .AHGLE D H 27.08,63 'H''7'O 2778,86 H 7o 2849,16 H 70 2919,38 H 70 2989,64 H 70 3.059,49 H 70 ~4467,90 H69,08E t.058,1~ H !'~.2943,69 E 3128,36 · 4540,,o. 96 1'16.8,55£ .1 qe3, i~ H ::,30.07 , 44 E 3196 ;.7 I 4762; 1'~i H69 "~ 20E ~156; ; ., 36 4'836 17 H69,92E '1,18'0, i"~~~,'~lJJ~g. ~[}.55 4984,27 ,N?O.O6E 1225~52 H~:~86,,~00 E 3600~96 5058,89 H69,50E 1248,52 H 3448048 E 5134,42 H68,72E t271,89 H 3509,70 E 5210,98 H68,.?TE I295,21 N 3569.65 E 5288,46 i!68,62E 1318,19 N. 3628,56 E 5366,84 t,166,.43E 1340,92 H' 3686.34 E 5445, t8 H68,57E 1363,7.0 N 3744,17 E 5523,02 H68,I2E ,t386~87 H 3802.5t E . . 5600,88 H67.97E' 1410,34 H .3860,71 E 5678,96 H68.37E ~433,57 N 3918,71 E 5757,.28 H67,SOE 1456,88 N 3976,35 E 5835,'45 N66,87E ~481~'0~ N' '4033,85 E 5913~59 H66.60E ~505,66 H 4091 ,19 E. 599t,61 N66,22E ~530,70 N 4148,51 E '6069~17 H64.97E ~556~78 N 42.05.99 E 3667,53 3733,05 3797.37 3860,58 3922,65 3984,79 4047,53 41 I'0,25 4172 ,.FO 4234084 4297.13 4359,46 4421,89 4484,85 .S 34 58 E 30 4 E 26 5 E 21 55 E 18 14 E 1511E t,4 7.0 12 53 E H ?0 I1 5 E HTO 90E HTO 729E H 70 6 26 E H 70 ~48 E HTO 55~E N?O. 6 tOE HTO 549E N 70 4 47 ,E N ?O 3 25 E N70 2 5E N70 039 E H 69 59 ~4 E N 69 57 42 E H 69 55 57 E N 69 54 21 E H 69 52 40 E H 69 50 22 E H 69 47 42 E N 69 44 49 E' H69 41 19 E DOG LEG SEVERITY DEG/IOOFT .440 ,567 .337 .501 ,654 1 .173 ,689 ,470 .402 · 389 .453 ,466 ,295 .343 .547 t,164 .684 .968 ,703 · 902 ,204 ,146 .347 ,548 ,413 ..619 .560 SECTION blSTANCE 2707,79 2778,09 2848.45 2918,73 2989.04 3058,93 3127.82 3196.19 32~4.05 3331 3398,99 34 66.09 3533.41 3600,47' 3667,04 3732,57 3796.90 3860.12 3922.21 3984,37 ,1047.14 41 09,97 41 72,34 4,234.50 4296,83 4359.19 4421 4494.66 KUP IRUK E-.20 SURFACE LOCAT'I ON HAS. DRIFT EPTH nHGLE D H 80~ 39 41 81~0 39 34 8200 39 36 8300 39 32 84.00 39 5 GYROSCOPIC SURVEY JOB HO 4! 1 'HSL,2.24 'A!EL,SECl'6 'T.I IH,R! OE 'RECORD OF- SURVEY TRUE ... ', . · . VERTICRL.. .. SUB . DRIFT DEPTH -,. SE~ DIREC, .. .... .DEG. 6252,.3~~, 6'I'46,36.,-.,H64,22E 6329,38. 62~3,.38. H62,.73E 6406,q$.'.,:~300,45 H62.93E 6483.54 ;6377:54 H63,35E 6560,92 ?$454,92 H6H,'ISE 85i00 38 '49 ' 6~38.697 "6532'69'"'H65.',60E 8650 38 49 6755'.56'.,ii~649',56 "N65,60E ,, OTTOM 'HOLE CLOSURE .,"'~t957.;??'FEET RT H · . . .... , ; , · '}584,~06 H ,4263.41 E t61~,54 N 4320,47 E t64!';63 H 4377,16 E 16'.70,.41 N 44~,99. E 360 1698,4! H .,4'49'0,01 E "!725o.09 H '4547:74'E SCientific.. '. .~ ~,~,,.. Drilling: , "~..,.,.:,~ ,International · C L-O S U R E ~ D'ISTRNCE .ANGLE 'D H: S 4~38,·20 H 69 21·25 E 4863.,93 N 69 13 36 E 69 9 29 E © SURVEYED- O1 FE~ KB ELEV !06,00 FT, DOG LEG SEVERITY DEG/I OOFT ,517 ,613 · 088 ,559 ,617 ,000 83 SECT/OH 4548,03 4611,49 4674.83 473~.17 4801.24 4863,93 4957.77 IR'CO KUPARUK E-20 GYROSCOPIC SURVEY .dOB HO '1360 SURFACE LOC. ATIOH' 411'HSL,.224'WEL,SEc16,T~lH,RlOE IEASURED DEPTH AND OTHER 'DATA FOR EVERY EVEN 100 FEETm OF SUB SEA DEPTH. SURVEYED- 01 KB ELEV 106,00 F'E~3 8-3 FT . MEASURED DEPTH 2 06 306 406 506 6'06 7 06 806 906 1 O07 1109 1213 1320 1430 1.543 1657 1773 1893 2021 2156 2291 2425 2563 2703 2845 2986 3f26 3268 3412 3553 3696 3839 3985 4132 4283 · ,. TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFEREHC~ 206., 3: 0.6. 4.06. 5.06. 606. 706 .. 806. 906. 1 006. 1106. 1206. 1306, 1406. 1506. 1606, 1706. 1806, 1906, 2 :O 06 21 06 2206 2306 2406 2506 606 2706 2886 2906 3006 3106 3206 3306 3406 3506 -..'106 .0 · .1 O0 0 200' , o 300 0 400 0 500 :0 6 '0 '0 0 700 0 800 0 900 1,000 1100 7 1200 13 1300 23 1400 37 1500 50 1600 66. 1700 87 1800 115 1900 149 2000 184 2100 2lA 2200 256 2300 297 '"40 O 338 25 O 8 38 2600 420 2700 462 2800 5 05 '29 [, 0 5 47 3000 589 3i O0 632 3200 678 .. aC, O 726 3 4 O O 777 VERTICAL. m iCORREOT I OH · . ,0 :0 0 0 0 0 O, 0 1 21'. 8 41 42 40 42 42 42 43 46 TOTAL COORDINATE8 .00 S ,66 .96 8 ,98 S ,89 8 ,69 S .54 t,I 3,92 H 9.88 [,I 18.77 H 31.14 H ,z~i=47.70 N . Sclen[i...~ ~7 H Drilling 6 t4 160.66 H 190.97 H 225.14 N 259.25 H 292.5~ N 327.02 H 362,91 N 396.98 N 429,27 H 459,74 N 489.55 t1 516.50 N 541.11 N 564.33 H 585.25 N 60~, 33 N 621 .20 H 6,11.36 N 7 62 95 !37 186 235 289 351 424 508 592 675 763 855 949 I 044 1137 1234 1332 1430 1528 1628 1733 1841 1951 ,00 °78 ,75 °87 ,94 I.IO 2,26 .92 ,71 °.07 ,48 .01 ,70 .20 ,77 ,00 .29 ,51 ,66 ,09 ,4'8 .Il ,19 .94 W E. E E E E E E E E E E E ' E E E E E' E E E E E E E E E E E E E E E E E RCO ' KUPARUK E-20 GYROSCCiPIC, SURVEY JOB NO 1360 SURFACE. LOC~IT. ION 41 i 'NSL, ,-.... "~":' 4 'kIEL , ..gEC16, T 11N , R 10E EASURED DEPTH AND OTttER DATA Fu,~ , , A~ L--.VER? EVEN' 100 FEET OF SUE SER DEPTH f:: t.:'. B '83 i':: T , TRUE HERSURED VERT!C~L q, UB" HI)-TVL) ?ER.. TIC:Rt. DEPTH DEPTH SE~ DIF'i'~ERENCE CORRECTIOI't TOTAL COORD I HATE:S 4427 3606, 4570 '3r 4713 3006. 't 4858 39 06, ./, 50'02 4006, 5144 41 06. 5285 4206, 5426 4306. ,5566, 4406, 57 06 45 5844 4606, 5980 4706. 6116 4806, 6251 4906, 6386 5006. 6521 51 06 ' "'-' 5206 . 6786 5306. 6915 5406 7 042 5506 ) 7170 5606 7299 5706 7427 5806 7555 5906 7683 6006 78811 6106 7940 6206 801'0 6.-306 8199 6406 8329 6506 8458 6606 . 85'86 6706. 8650 6756. 3500 882 '1 3600 863 3700 9 07 3800 95'2 39 00 995 .~ .-~ ,.~ ,IOOO i 4100 i 07:3 4~00 11 i9 4~08 1160 't400 1~00 4500 1~.~'7; ~ ~', 4600 i 274 4700 i~t 0 4800 i '¢' = 4900 i 380 5000 ~415 51 00 I ,I ,4 ~ 5200 1 ~ 79 ~, ~ 00 ! 5 n F: 5qO0 1536 · _ c, 00 159 ~ 5800 '16,4 E~ 6 000 17 04 61 00 t 73 62 00 1 763 6 S 00 i 79 :S 6400 i ::a 2 '5 6500 i 85 2 6668 i" .... 6650 I :394 2051 2143 2236 233 1 242,'5 25i8 2609 0:-] E '" t-', E 66 E 65 E 2701 .4i E 2792 59 E · 2883 55 E 2971.8; 0 E 3058 23 E 3143 76 E 3228 66 E' 3314 I9 E 3399 24 E 3482 14 E 3561. I I E 3637.13 E 3'."1 O, 6! E 37885.27 E 3:360,06 E 3934,25 E 4007,69 E 408881.26 E 415,1 ,1228 4303 ,1376 4450 4523 7'4 E 8.7 E 24 E 83 E 54 E' 77 E 4597,05 E ' ,t633,36 E ;~CO I<UP~RLII< E-2 0 SURF'~CE L. OCRI'IOH © G.'k,U,~L.O~ :[C '.-~IIRYEV JOB NO 1,~60. ,I 1 I "HSL, 22,I "bJEL, SEC 16, T I 1 tt, R 1 OE SURVEYED- 01 FEB E~S KB ELEV i06.00 FT, '~TERPCL~TED VF4I..UE<., FOR EVEH 1 000 FEEl' OF' I'iE~SURE£ DEPTH I'IE~ISURED DEPTH 0 1.0 O0 2000 3,000 4000 5000 600'0 700"0 8'000 ~GSO TRUE VERTICRL, DEPTH 999, 26,16, 3316, 4,005 ;. 4720, 547~, 6756. SUB SEt~ TOI'KiL COORD IH~TES -106. ,00 S 1 ? 84, 185, 251 0 , 4~2. 3210. 606,19 N ' 3899, L~44,00 N 4614. 1108,49 H 5367, 1 $40,92 6i 46. 1584 , 06 6650, 1763,9~ H ,O0 412 ,, 19 1.053,4'4 1,744.69 2424;48 3 070.58 3/,86,34 42'6~, 4 ! E E E E E E 'E E ~RCO ' 0 K U'P i~R U K E- 2 O SURFACE LOCRTIOH IHTERPOLRTED TRUE :ODE HEASURED ,lAME DEPTH GYROSCOPIC SURVEY ,JOB t40 136.0 sURVEYED- O1 FEEs 8:3 411 'HSL,224'[JEL,SEC16,TI1N,[-<lOE KB ELEV 106.00 FT. VERTICAL DEPTHS, COORDIN~%TES ~'~HD CLOSURES FOR ~IVEN DEPTHS TRUE VERTICRL DEPTH TOTAL COORDINATE~ CL,OSURE DIST~HCE ~HGLE SU~ SER f,UP SAND 7943 3.UP ~AHD 8141 [:.LO SAHD 8333 3.. ~ SAND 8474 rD 8650 62 08.42 636 0 o 99 65 09.02 6618.44 6660,29 6755.56 1568,39 N 4230,66 E 1624,49 H 4343..7,0 E 1679.77 N 44~2..76 E 1710,30 H 4532,9! E 17~4o93 H 4$69~43 E 1763.93 H 46~3'o36 E 4512,02 H 69 39 33 E 4B~7,53 N 69 29 41 4759,06 N 69 ,19 52 E 4047,66 H 69 14 22 E 4807..70 H 69 ~2 ~3 E 49~?,77 N 69 9 29 E Scientific Drilling Ir ternational ,slO2,42 6254,99 6403,02 6512,44 6562.29 6649,56 ......... -i '" i ..... ]'~'!'-'"': .... :'i'~' -~ ........ ,--..--- - - ; ........ . : '--:. ....... ! ".;-;i-+: ...... ; i 7 :'! i'i .-'--~']-'i' i-i ! · I ~. : ~ i i t :.i 1_ ...... 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LL I.'.J.L.~'!'I; I t I ~ I [.-] [ '1~.! 2 _,I ' ' !.~ .i i.l ;;i ~ i _; ; ! :.~ ; ;-.; !..'. ; '- ; . % -. -'. i; i'::' ', , :-~= :',''-~ ~: ~ , '- i . ' L:__i ! ~ , i.i ;.'_ · ':. I : ! ~ : ..... : . -- -.- .... ' ~ [ , . , . i_,I:. i ; l ,'_: ; ', : i i ' I.; ' ..... ' ,; -. __.;..i_ t..i.: _..i;:i_i _*_E:L.L'.J-!::i :L-i_ [:i51.- i':i.--',=-~. : , i_i i i i i:; ;-;:I h.l.'.!- .i..i ~ !'i- i-I ] ~ ::;I. !/: .{'--7!'- [..I:i i ; ~_i ? I ii i.i i-[ : , ; : i i i i :; .' : i ! : i. ! ; ~ ...;. ' ': .L_~..'-:' i :.L_; , .i, !.L=t. i ; j. !'~ i-L'i-I=~ ' f' ". ~:'i iT.t.=i ..;,.L-L [ ' L.~:..~ __i i '= : _ ........ ! , : , ;.~ ' _.1 .... ;. ._J_.5 ] I : '_, :-.- · · .... :. k.:;..'..~._L::;;2- 'i~i-:I'i_%i..i. 21:!.~;J [ ~, i_.L - .-' ............. '. ' _i..i i~ ! .~.p i ; ." 't'.--~ _-' ff:.i ~: -;:-, ~,,. r ..-- ~':i:' '_iTr:.r":~'i: 'i .7 L2:i .......... ~ ! :_ - ~, ~:," . : : ~ ! ; 1.;-~_ ;. ' ! L .'"' !i .5-1 L..;' ! [ ~-., ,.., ' i-1 ' . , i,,~:L~i';-?-~- i i i i I !_.~..i.' i ~_, ;..L_.. ,., 'i.. , ':.} i }.~-' - i i '- , - - : i i ! ; ! ; : ~ i'~ ~ ~ ; , i I i ; i ' I:~ .!.i_.i } : ,LZ , i.' ! I i i..L : .:.'._:. : '_L' ~ ' ' L . :_.:.:.'..<..~ ~,. _ ;..' 1 ~:, · ' .._.. , 0 ;RCO ALASKA, I ;YROSCOPIC DIRECTIOHAL SURVEY IRDIUS OF CURVATURE ME'THOD OF COHPUT¢~'TION :URVEY RAN BY CHAPPELL OI'IPUTED FOR SD I BY OCEANTECH(FH L II~DSEY ~' AS~OL;q '.) RECORD OF © JOB t`10 1360 KUPRRUK E-20 ,. KB ELEV lO6,00 FT, SURVEY DATE 02/01 , .i'; . TOTAL COORDINATES C L 0 S U'R E S D I STANCE . ,ANGLE ,, ,,oo s ,oo w ' ,00 s 9o o ,'o3 N ,19 E ,19 N 82 15 ,19 S .62 E ,64 $ 73 3 ,~d S ,77 E l,OO S 50 26 49 E ,~ S ,76 E I 21 S 38 '49 39 E F~,'f . ' '"' ' ~ ' ,~.~,.~' '.,-'.'. ,~I~F= i,31 S 41 32 41 E ' ' xi -'d'ific 1 29 S 45 55 54 E ,,~~~I',. ' 1 30 S 56 44 3 E 9 38 N '~> 18 67 E 20,90 N 63 19 34 .E · TRUE I'E~S, DRIFT VERTICAL SUB DRIFT !L )HANGLE DEPTH SEA DIREC · D H DEG, 0 .0 0 l'.OO 0 13 200 0 22 3.00 0 I1 40'0. 0 1'0 500 0 2 600 0 5 7'00 .0 12 8.00 1 35 900 5 29 1000 9 5 11,00 13 18 1200 f6 57 I .'00 '26 0 1500 28 44 1600 28 20 1700 29 37 1800 32 44 1900 36 27 2000 39 58 21 O0 42 44 2200 42 I I 23:00 42 23 ,00 1'00,00 200,00 300.00 400.00 5.00.00 600 O0 700 O0 799 98 899 77 998 95 1097 83 '1193 54 1287 91 1379 38 1468.18 1556.03 1643,51 1729.06 1811,37 1889,93 1964.99 2038,77 2112,75 -I06,00 -6,00 94,00 194,00 294,00 394,00 494,00 594,00 693,98 793,77 892.95 991,03 1087,54 1181,91 1273,38 1362,18 1450,03 I537,51 1623,06 1705.37 178`3,93 1858.99 1932,77 2006,75 N , OOE tt82,25E S29,38E S 8,98E 'S 14,90t..r N22.75E N54.28E H27.4:3E t,155,53E N61 98E tt64 08E N64 25E t,163 t 8E N62 82E N64 98E t,166 58E H65 47E tt66,6 OE t.16,7, .% OE N67, ,1SE N67,63E t,167.70E t,168,07E H67,83E .0 E 8 E' 17,84 N 36 14 E 40,30 N 63 43 51 E 29,59 N 59 53 E 66.39 N 6;3 43 31 E ,14,38 N 88 95 E 99,4'0 N 63 29 `3 E 62,1.3 N 125 19 E 1,39.76 H 63 36 15 E 80,98 ti 167,10 E 185.69 H 64 89 36 E 100,39 N 21 0,75 E 2`33,44 H 64 31 42 E 120.07 tt 255,01 E 281.87 H 64 47' 13 E 140,34 N 302,64 E '333,59 N 65 7 21 E 162, 17 N 355,03 E 390,32 I,I65 27 0 E 185,80 It 412,19 E 452,1,3 N 65 44 9 E 210,90 tl 473.29 E 518. 15 t,i65 58 55 E 236,31 N 535.83 E 585.62 t,I66 12 4 E 261.57'N 59B.19 E 652.88 N 66 22 53 E DOG LEG SEVERITY DEG/IOOFT .0'00 ,217 ,150 , ,017 ,133 .050 ,117 1 ,383 3 900 `3 600 4 217 3 651 4 667 ~ 403 2 758 .473 ! .313 3,123 3.717 3,518 2,767 .5.'4 ,226 SECTION DISTANCE .00 .18 ,51' ,50 ,37 ,46 ,55 ,76 2.1.3 8,19 20,79 40,12 66.09 98.91 139.10 184.98 232 68 281 05 332 77 389 50 451 32 517 36 584 84 652 11 O. iRCO KUPARUK E-20 SURFACE LOCAT.! Oil 0 t,ISL 224 WEL,SEC!6,..T!I:N,R!OE 1360 SURVE'rE£,- 0t FEB u3 KB EL. EV 106, nO FT, ~ERS. ).EPTH 2500 26.00 27:0.0 ...28"0.0 '29.08 3000 3'1 ~).0 3200 33-00 3400 35'.00 36i00 37.00 38.0.0 3~00 lo 4 ! :00 42'.00 - 43:00 44:00 4500 4600 47 '0.0 48'00 4900 500'0 5100 OR]ET AXGLE .D. H 4'0' 58 43 59 44 44 44 44 45 13 45 4 44 33 44 22 45 20 46 23 44 52 45 9 45 15 45 4.7, 45 20 47 2 46 59 47 42 48 31 .48. 3 I 44 2 45 28 45 56 46 4 46 28 46 12 45 16 45 16 RECORD OF TRUE -" .. DEPTH · ,, · . · ,. 2187, 4 208i'.,' 4 Nee 2403,73 Nee 2474,47 -2368,4'?' :NTO 2545,:01.' ~39}'01 HTO 2615,95 .:'..350~, 95 2687;'33. ' 2581,33 2758,22 2827,8? 2897.~.80 2968,50 3038;96 3 ! 09.03 3179,05 3248,28 3316,47 3384,23 3451,01 3517,25" 3586,35 3657,37 2652°22 a721',87 ~79'1,80 2862o50.. ~932.96 3003, '03 3073,05 3142.28 321'0,47 32?8,23 3345.01 34tl,25 NT1 N72 H72 N74 N75 N75 N76 N77 N78 N79 HBO N81 xeo N76 3480.35 H69 3551,37' N65 D~IFT D~REC DEG, · .1SE ,82E ,60E .92E ,67E .93E . ,77E ,0SE ,72E ,32E ,47E ,82E · 53E .43E ,55E ,55E ,58E ~57E ,45E .37E ,36E .4OE 3727,21' 3796,67 3865,80 3934.,85 4004,65 4075,03 3621,21 3690,67 3759.80 '3828,85 3898;65 3969,03 N64,13E N64.,65E H65.37E N65.73E H65,90E N66.7OE .. .. . CLOS-URES DISTANCE ANGLE D I'1 286,47 H ,;: 6,59',8'4 E 3'I'1,22 N 722.;66 E 336,60 N "78?.80 E' 362,',~'0 !.4'853,4.0 E 38.6 ~ 52. N .',9'! 9 ~.73 E 409', 83 H' ''"'986,67 E '" 278 531,91 m[lll 19 ~49~ 548,9.4%~ .: ~2 ,W~atic~,s~2 565,.8I N 53. 1,97 E !632 579,86 N 160t.80 E I703 593,57 H !672.64 E 1774 ~ ,. 617,60 N 1817.34 E 629.23 H 1890.86 E 644.28 N 1964.23 E 665.54 N 2:033.24 E 692.60 14 2098,21 E 723,11 H 2162,95 E 754,20 N 2227,82 E 784,73 N 2293.31 E 814,67 N 2359,16 E 844,:00 N. 2424,48 E S72,.56 N 2'489,53 E , ,i . . '.. 7'19,34 H 66 31 54 E 786.82 H 66 42 2 E 856.70 N 66 51 52 E 927,04 N 67 0'29 E 997,64 N 67 12 19 E 1'068,40 N 67 26 37 E 1138.72 H 67 41 . 6 E ,58 N 67 55 47 E ,90 H 68 10 30 E .36 N 68 27 30 E ,41H 68 46 52 E ,65 H 69 6 21 E ,09 N 69 25 34 E .84 N 69 45 19 E .53 N 70 5:57 E ,84 N 7'0 27 42 E ,OO N 70.50.25 E 1919,41 N 71. 13 49 E ~!992.81 N 71'35 38 E 2067 2139 2209 2280 2352 2423 2495 .20 N 71 50 24 E ,39 N 71 52 30 E ,57 N 71 43 56 E ,62 N 7! 30 51 E ,02 N 71 17 49 E ,'85 N 71 6 36 E .86 N 70 56 56 E 2.~567,19 t,I 70 48 22 E 2638;01 'N 70 41 5 E DOG LEG SEVER I TY DE;(;/I OOFT 1 ,425 3,032 ,758 ,223 ,I, 005 201 660 230 1 024 I 34,1 1 621 33:3 722 I 782 ,555 ,896 1 ,,'029 3,059 5,611 2,480 .8'03 ,299 .549 · .328 ,937 ,568 C'E C: T I 0 H D I S 'r R t",l C: E ?'86 1 0 856 01 926 99,-'" 06 i 06;;' i 138 3,1 120;3 30 127'8 71 1:350 26 I 4; ~ 1 "~.... 8 i 49 l 65 ~.:; ~, 2 07 ....... ~ ';.:' 0:'.~ 30 ",'? 7 ,i 38 :346 20 918 991 01 ,'; i 36 99 ,..i 22,45 2566, S~,37,08 , IRCO KUPARUK E-20 .SURFACE L'OCATION !? IERS, .DRIFT .)EPTH ANGLE 'D. H f~,...dtO 44 .50 53'00 .44 ,,~4 54,00 44 54 55'00 44 2.7. 5600 44 56 "5709 43 46 580:0 43 20 5900 42 56 6000 42 32 , 61.0,0 42 3'0 62:00 42 3 630:0 42 23 ..6400 42. 16 ~,.5.004 ! 5'9 66.00 41 30 6700 4'0 23 ~ )039 4~. 6900 38 44 ?000 39' 2 It 0.0 38 50 7200 38 56 7300 38 48 7400 38 32 ,75.0.0 38 21 7600 38 49 ..,,7700 38 25 7800 39 1 79.00 39 '16 . . ,, TRUE "~':*" ' GYROSCOPIC SURVEY .JOB NO '~360 4'1 ! "NSL, 224 'WEL, SEC i 6.)'T l"!. H, R I'.OE · . RECORD DRIFT D. IREC pE~. 4216,','76 ~4~.'!.0,76' 'Nfi,8?E " 827,54 N '~6'19","49 E 4287;80 ~..tet.,'eo- N6?,77E 954'12'H 2684',66 E 4358,9'!- ~25'2;9'1 "X67,32E 980,97 N"2749,63 E '4430,:o0 -~'324,.00 N6e,2OE "i:0:07;59 H '28~4,73 E 45o1.o 50 :'...4~s~, 50 4646 4794. ! 2 4868,1 ' 4~42,1 ? 5.016,10 50'90.2? 5164,89 5240.42 5316, 5394,46 5472 5551, 5629.02 5706,88 5784,96 5863,28 5941 6019,59 6'0~7,61 6175,17 4.54 O. 4614,4t 4~88.12 4762, ! I 4836, ! 7 4910~10 4'984,27 5058,89 5134.42 521 O, 98 5288.46 5366.84 5445,1 5523,02 · 5~oo, ee 5678,96 5757 5835 ,'45 5913,59 59'91.61 '6 069, 17 ,. , C L' 0 S .U R E S DX STANC'E m RflGLE D !'1 .s 27.:08,. 63 'H' '70.3.4 58 2778,86 N 70 30 4 2849,16 H 70 26, 5 291'9.38 N 70 21 55 2989,64 N 70 18 14 3059° 49 N 70 15 11 H6?.95E" 1033,70 N 2879,58 E N69oOSE ' 1.058',~ 14 i"',:2943.69'E 3128,36 N 7.0 12 53 N68,55E :!~83,1 N".::~,~,O:O?,44'E 3t 6;71 N 70 11 5 . o '1'!3~-';"~ ' ''''" ...... ']' ''. .... :-': ...... 333,'I0 N ?0 ? 28 1.156',6 , f tfff 399,36 N 70 6 26 i70,52~ ~,~ ',le~mati~~. ee H 7o ~ 5~ .HTO,OeE 1225,52 H"'.~86;oo E 3600,96 N 70 6 lO N69,50E 1248,52 N ,3448,48 E N68,?2E t271°89 N 3509,70 E H68,.?7E I295,2l H 3569,65 E · , N68,62E 1318.19 H. 3628.56 E N68,43E ~,92 H' 3686.34 E N68,STE J363.70 H 3.744,17 E' N68,12E .I386.87 N 3802,5l E 3667,53 N 70 5. 49 3733.05 H 70 4 47 3797.37 N 70 3 25 3860,58 H 70 2 5 3922,65 H 70 0 39 3904,79 N 69 59 14 4047.53 H 69 57 42 4110,25 H 69 55 57 4172,70 N 69 54 21 4234,84 N 69 52 40 4297,13 N 69 50 22 4359.46 H 69 47 42 4421 .89 I,I69 44 49 4484,85 N 69 41 19 N67.97E' ' 141 0,34 N .3860.71 E 'H68,37E 1433.57 H 3918,71 E 1,167,60E 1456.88 N 3976.35 E t166,87E 1481,01 N '4033,85 E N66,60E 1505,66 N' 4091.19 E. NSS,22E 1530o70 N 4148,51 E N64.97E 1556,78 H 42.05,99 E SURVEYED- 01 FEB R3 KB ELEV 'i06,00 FT, DOG LEG SEVERITY DEG?I.OOFT SECTION b I STANCE E E E E E E E E E E E E E E E E E E E E E E EE E E E E ,,440, ,567 ,3.37 ,501 ,654 ,173 .688 ,470 .402 .389 45~ I ,466 '"95 .343 ,547 ,164 ,684 .968 ,703 ,802 2 04 146 3O9 347 413 ,.619 ,560 2707,79 2778.09 2848,45 2918,73 2989:04 3058,93 3127,82' 3196.1.9 3264.05 3331 3398,89 3466.09 3533.41 3600,47 3667,04 3732,57 3796,90 386 O, 12 3922,25 3984,37 4047.14 41 09,87 4172,34 4234.50 4296,83 4~59.19 442! .66 4484 CO KUPARUK E-,20 SURFACE LOCATION TRUE AS..DRIFT VERTICAL PTH ANGLE DEPTH . .. · D H 1-.00 39 34 2:00 3,'3 36 3.00 39 32. 4.0.0 39 500 38 ~650 38 49 SUB ITTOH HOLE GYROSCOP!C SURVEY JOB NO 411 'NSL,224'WEL~SECI'6,'T,11H,RiOE - ,. . . .. .RECORD OF- SURVEY:· · . . : DRIFT ' DIREC, .DEG, . .6329o3S "6223,38 N62o73E :6'300,...~5 H62.93E 6405',45",I ., . 6560,92 6638,69::, . 6755'056.', 6649',56".~:,~N65.60E ,,', : . , . CLOSURE :'~957,;?? FEET AT H 69 36'0 TOTAL · ,, , .. .. -. '1763~ 'H ~633,,36 E'. 4957',.?~ H 69 Ai~F Scientific Drilling ,International © SURVEYED- O1 FEE~ 83' KB' ELEV 106,00 FT, DOG LEG SEVERITY DEG/I OOFT SECTION DIST~HCE ,613 · 088 ,559 o617 .000 '4540,03 4611,49 4674,83 4730,!7 4801.24 4863,93 4957.77 0 " O iR'CO KUPARUK E-20 GYROSCOPIC.. ,gURVE¥ dOB NO 1360 SURFACE LOCATION' 4!!'HSL,224'WEL,SEC16,TI1N,RIOE IEASURED DEPTH AHD OTHER 'DATR FOR EVERY EVEH I00 FEET OF SUB SEA DEPTH. .:,URVEYED- O1 FEB 83 KB ELEV 106.OO FT. · TRUE HEASURED VERT,ICIqL SUB HD'-TVD .,.:.., ,VERTICAL DEPTH DEPTH "'SEIq DIFFEREHC~E :.CORRECTIOH TOTAL COORDINATE$ .0 206 306 406 5O6 8O6 9O6 1 O0 ? 1109 1213 1320 1430 1543 1657 1773 1893 2021 2156 2291 2425 2563 270,3 2845 2986 3f26 :3268 3412 3553 3696 3839 3985 4132 4283 · ,. 206, ' 3.06, . 4~6 ,. 506, 606. 706 o, 806, 906. 1 006. 1106 1206 1306 1406 1506 1606 1706. 1806 1906 2006 2106 2206 2306 2406 2506 2606. 2706. 2806, 2906. 3006, 3106. 3206, J306, 3406, .7506. -,, 1 '06 1 O0 200 300 400 500 6 0'0 700 800 900 I ,000 tlOO 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 o~,00 2300 2400 250~ 2600 2700 '-',=,.q 0 O 29(,0 3000 .'3t O0 3200 ,33 O0 3400 '0 0 0 0 0 0 0 0 O' 1 ? 1.3 23 50 66. 115 149 218 292' 338 420 462 505 547 589 632 678 726 :0 ,0 0 0 0 '0 '0. 0 0 1 ,00 ,96 ,54 3,92 9.88 S $ S S N N N N N N H N N 2 18.77 4 ': ,~ 31,14 ~.': :'"'i,> Ai~,,I 747.70 F")Sclerltl .',~. 27 Drilling 11.61 .Intern~lB,~ ~,~!8 ~ 21' 160,66 H 28 190,97 H 34 225, 14 N 35 259.25 H 34 292,52 N 38 327.02 f,I 41 362,91 t4 41 396.98 N 42 429.27 H 40 459.7,1 ti 42 489,55 N 43 516.5.0 H 42 541.11 N 42 564. ~3 N 43 585,25 H 46 604,33 N 48 621 ,20 H 51 641,36 N e 87 ~o10 2,26 ?.92 19,71 38;07 62,98 95,48 !37,19 186,01 235 289.20 351 ..39 424,77 508.18 592,49 675.0 763.29 855.5 949,66 ! 044.09 1137,48 ; 234, 1332.97 ~430.19 1528.94 1628,85 1733.61 1841 . I 1951 ,86 W E E E E E E E E E E E E E E E E' E E E E E E E E E E E E E E E E E C) 0 ~C:.O ' I<[IPARUK E-20 I]"r'ROSCC~PIC SURVEY JOB t,lO 1360 SURFACE LOCAI'ION 41i HSL ',d~:'4 kiEl.._t-L. 16 TI 1N RIOE · ""nr ff',/ERY ,. EH DEPTit EASURED DEPTH AND OTHER DATR r~,,~ EVEH' 1.00. FEET OF SIJB q" , ., $ tJR ~,, E' "~" E' ['). .... fi. 'i I< [~ E: L E',/ i 06. l.., (., 83 TRUE ,. U 8 I'1D .- T V [) R T I C: A L. HEASURED VERTICAL q ' VE D E P T H D E P T H S E A D I F F E R E H C E f,:: 0 R R E C T I 0 H T 0 T A i. COORDiHATES 4427 4570 4717 ) 4858 .- 50'02 5144 5426 5566 5706 5844 59eo 6116 6251 6655 6786 6915 7'042 ,} 7170 ¢299 7427 7"555 7683 7:31 1 7940 8070 8199 8329 8458 8506 8650 3606, 7706, 3806, .3906, 4006, 4106, 4206, 4306, 4406, 4506, 460~, 4706, 4806. 4906, 5006, 51 06, 5206. 5306. 5406. 5506. 5606, ' 5706 5806 5906 6006 6106 6206 6.306 6406. 6506, 6606. 6;"'06 · 67~ 3500 82 '1 ..7600 863 ,. ," O0 907 3800 95'2 3900 9:' .''~; 4 000 1 0 .S 7 4 1 ;', 0 i 0 4'200 i 4300 4400 1200 4500 1'2S7 4600 127'4 ,t700 i 3 1 0 4':800 13,t.=,.. 4900 i 38 0 5000 i415 51 O0 i ,t,16 5200 14?'3. · ..~ ,. 0 0 1 5 0 .:. 4. O 0I "" '~, "' 5500 1 "{ ' 5600 i 592 5~' 00 i 6 :.? 0 ! 58 00 i 64 E'-; ::, ~ O 0 i 67 ,S 6 000 i 7 i.)4 .~ ...) . ,':, ~. 00 i 6 S 00 i ';'? ':~ :'~ 64 00 'l :~ 2 :'${ 65 00 i 6650 1 :'.'394 44 44 45 4"~ 42 4 i 4, i 41 4. 0 7.56 '~'", 'i:.':¢::' ;,,: '¥ ~,,, 35 :35 ,7 5 '".' '.?' '" ';' ,,, S .'3 . ~., 28 "} 0 -%, C~ S 0 :S 0 ,S 72 "5 ,4... N ';:" i :3.64 750, .'.:; 5 t't 002 22 N 5'5 H 86 N 98 t,! 67 H 30 f'.l 7'4 H 63 H 66 H 74. N '1'i'9'9,8,I N I !iii't.:230,34 N ii ~..Itl. 261:i'2.'5 t4 i;.29i,89 t4 '1:3.-_'-' 1 '1350 i :37'9 1,t10 14 S '9 1469 55 H 50 N 97 N O? H 77 N i501,37 53:~ .,I5 H 567,5'1 H 603,7'I t,I 6,1 i , ,I 6 H 67,9.67' t4 ;;'i4,07 t4 747,4' 6 ;'~63,52{ I,i 2051,08 E 2143,25 E 2236,6 i E 233 t , ~ii!. 6 E 2,125,7:S E 25i8, 16 E 26 09,65 E 270't ,41 E 2792 59 E · 2883 55 E 297~, 80 E 3058 23 E 3t 47 '76 E 3228 66 E 3314 19 E 3399 ;:4 E 3482 i 4 E 3561 I 'iE 3637 13 E. ~71 0 61. E 3785 27 E 3860 06 E :"3934 25 E 4007 69 E 4081 26 E 4154 74 E ,:1.22887 E 4303 24 E 4376 8.3 E 4450 54 E' 45'2,.37'2'E 4597,05 E 4633.36 E KLIP ~R UK' E-20 SURFI~CE L. OCF-~T!OH 0 GYI~U~,cuI.~[C SURVEY dOB NO HE;L, '22.i 'WEL, SEC 16, Ti it,I, R t OE 1360 ~ . SURVEYEb- 01 FEB,::,'"'._'~" 'KB ELEV i06.00 FT, t;tTERPOLATED VALUES FOR EVEi,I I000 FEET OF' I'iE~tSURED DEPTH, MEAsuRED D.EPTX 0 1.000 2000 4000 5000 6000 700"0 8'000 8650 TRUE VE R T ! C~IL. tS DEPTH " ~. IE~..I T O'l' F:iL CO 0 P,[,, I t'l~ TES 0,, -106. . O0 999, 89.~, " 9,~8 18~0, 1784, 185.80 , "'~ 36 2616 251 O, 4~., 3316, 3210. 606,19 4.'005' ~"'" - , . , ,~ 844 O0 4720, 4614, 1108,49 547~, 5~6,7, 1 ~40,92 6252, 6146 , 1584,06 6756. 6650, 1763,93 412., !053, I,?,t4. 2424 ', 3070, 3686, 4263, 4.633, O0 W 67 E 19 E 4'4 E 69 E 48 E 58 E 34 E 41 E 36 E Drilling "© "- 0 , t~.LrPARLitc', E-2i:I 6YROSC:OPIC SURVEY dOB HO 1360 sURt,'EYED- O1 FED 83 SURFACE I..£C~TIOH ,4il HSL,:.?24 i,.IEL $EC. 16 TI1H RJOE KB ELEV 106 OCt FT It. ITERPOL~:i't'ED TRUE 9ERTICt'~L DEP' '~ . I'Ho, COORDIt,tATES At,ID CLOSURES FOR C~IVEN DEPTHS TRUE ODE HEASURED VERTICAL TOTAL COORDIHATES C L',O S U R E . SUB AHE DEPTH I::,EPTH DISTAHCi~ ANI~LE .' SEA D, H S .UP SAND 7947 6208.42 1.568.39 N 42:30,66 E 4512:,02 H 69 39 33 'E .UP SAND 8J41 63~0,99 1624.49 H 4S43.,F0 E 4637,53 N 69 29 4! E .LO SRHD ~3 6509,02 1679,77 'N 4452,76 E 4759,06 H 69 j9 5~ E ,' )SRND 8474 6618,44 17i8,BO t't 4532,9J E ,4847,66 N 69 1'4 2~ E B',¢ 8538 6668,29 J734.93 H 4569,43 E 4887.70 N 69 j.2 33 E D 8650 6?55.56 1763,93 N 4633,36 E 4957,.77 H 69 9 29 E 6102,42 6254.99 64 03 ,' 02 65~2,44 -6562,29 6649.56 'Ar~ F: ,..,Clelltl[iC: Drilling International Suggested form to be inserted in each "Active" well folder to ckeck' for timely compliance with our regulations. ·" i ~p~ratof, W~ 1 N~me- ~na Reports and Materials to be received by: Date Required Date Received R.emarks Completion Report.' Yes , Well .History' Yes . · · · Core Chips ' ' ~~ - ...... , " d " , , .,RegiStered Survey Plat. :F~'~''%'. ~ - 3 0'"'" (~"~ .. ~: ,, InClination Survey · . , /4~ ~ , ...... Drill Stem Test Reports , . · Production. Test Reports , Digitized Data y e,~ ~--/~ ~_~,. '~~ . ' ' ' TO: William VanAlen FRCM: · Transmitted herewith are the following: Pr.wAgE NOTE: BL- BI/3EL]AIE, S- SEPIA, F-_ PC- PHOTOCO~ ARCO ~, iNC. AT/~: ~ - AFA/311 p. o. ~ox ~o ~-/~/. ~~ ~RAGE, AK. 99510- : Anchorage. o A.RCO Al,~ska, Inc. Post Office. -~60 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission ., 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for January on these drill sites- 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 . WSW-iO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are well completion reports for: 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska Inc. is, a subsidi.3ry of AllanlicRichlieldCompany . .. _., STATE OF ALASKA ALASKA (. AND GAS CONSERVATION CO fISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~] Workover operation [] 2. Name of operator ARCO A1 asEa, Inc. 3. Address P.O. Box 360 Anchoraqe, AK 99510 4. Location of Well at surface 411' FSL, 224' FEL, Sec. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No· 106' RKBI ADL 25651 ElK 469 7. Permit No. 83-5 8. APl Number so-029-20895 9. Unit or Lease Name Kuparuk I~!ver Unit 10. Well No. 1E-20 11. Field and Pool Kuparuk River Field K,_!paruk River Oil Pool For the Month of January ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1400 hrs, 01/21/83. Drld 13-1/2" hole to 2410'; ran, cmtd & tstd 10-3/4" csg. Drld 8-3/4" hole to 8600~ ran logs. Continued drlg 8-3/4" hole to 8650' TD; ran and cmtd 7" csg. Preparing to run Gyro as of 01/31/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 80'. Cmtd w/290 sx AS II. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2380'. Cmtd w/1300 sx AS III and 235 sx AS I. 7"j26.0#/ft, K-55, BTC csg w/shoe @ 8621'. Cmtd w/1050 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run FDC/CNL/DIL/GR 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED (/~~~./~~-]/' T,TLE Area Drillinq Enqineer DATE ~yT/L~--9 NOTE--Re on th~s ~o . rm ~s required for each calendar month, regardless of the status of operat.ons, and must be filed in duplicate with the Alaska Oil and Ga/s/Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate "-" 1E 20 .. ---', DRILLING HI STORY NU Hydril & diverter. Spudded well @ 1400 hrs, 01/21/83. Drld 13-1/2" hole to 2410'. Ran 57 its 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe @ 2380'. Cmtd 10-3/4" csg w/1300 sx AS III & 235 sx AS I. Instld 10'3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 8400'. Ran FDC/C~/DIL/GR. Cont. drlg 8-3/4" hole to 8600'. Ran DIL/FDC/CNL/GR. Cont. drlg to 8650' TI) (01/30/83). Ran 217 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 8621'. Cmtd 7" Csg w/1050 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Preparing to run Gyro as of 01/31/83. JG: llm o2/03/83 MEMORANDUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION TO: C.~~,,,~' '~.t~erton DATE: THRU: Lonnie C. Smith Commissioner ~.~ TELEPHONE NO: FROM: ~eD LeNo~an Petroleum Inspector January 2~, 1963 SUBJECT: Witness B.O.P.E. Tests on ARCO- ' s Kuparuk 1E-20, Sec. 16, TllN, R10E, Kuparuk River Unit ~unday, Janua_ry 23: I departed mv home at 12:20 p.m. for a 12:50 p.m. showup and 1:50 p.m. departure via Alaska Airlines flight ~61 for Deadhorse arriving at 3:30 p.m. ~eather -19°F, clear, light wind_. t~;onday, January. 24: P..O.P.E. tests on ARCO's Kuparuk 1E-20 · began at 3:30 a.m. and. were completed at 5:10 a.m. B.O.P.E. inspect ion report is attached. Tuesday,. January, 25: B.O.P.E. tests on Sohio's N-17 were Completed, the subject of a separate report. Testing of SSV's SSSV's and~ low pilots began at ~_rco's ~uparuk field --- Wednesday, Janua~z 26: and continued --- Thursday,_. January 27: --- until 8:30 a.m., the subject of a separate report. Bench testing of "K" valve for Sohio's well G-2 was complete~, the subject of a separate report. I departed Dead~herse via Alaska Airlines flight #56 at 4:10 p.m. arriving in Anchorage at 5:50 p.m. and at my ho~.~ at 6:20 p.m. In summary, I witnessed, successful B.O.P.E. test on ARCO's Kuparuk 1E-20. 4/81 .~ STATE OF ALASKA ALASKA OIL & GAS ODNSERVATION CQV6fLSSION B .O.P.E. Inspection Report Operator ~ ~ Representative Well .~_ ~;~_ ,_] ~ _/~--~ ~ ~ Permit # ~ ~ Location: Sec 7~ T//JR/5~M ~Fg~' ~/o~asing Set Drillinq'Contractor -~~~ Rig #~ Represe~ntatiVe~D,~x¥ Location, General~ Wel 1· Sign Ceneral ~eserve pit Rig ACCUML~ATOR sYSTEM Ful 1 charge Pressure ~ Pressure After Closure Pump incr. clos. pres. 200 psig. min..~ sec. Full Charge Pressure Attained: -~ min/~ sec. BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves- Check Valve Test Pres ~/re psig psig Controls: Master Remote ___w~_~L'_ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lo%~r Kelly Ball Type.. . Inside BOP Choke Manifold Test Pressure Test Pres sure-- Test Pressure Test Pres sure~ Test Pressure No. flanges_ A~justable Chokes~ Hydrauically operated choke Test Results: Failures O Test Time'/~/~ hrs.. Repair or Replacement of failed equipment to be made within · days and / . Inspector/ . .Q~m~sion office notified. Di str ibut ion orig. - AO&GIC cc - Operator cc - Supervisor January 11, 19'°~ '~?r. Jeffrey B. Kewin Senior Drilling En?~ineer ARCO ~.laska, Inc. P. O. Box 360.. Anchorage, Alaska 99510 Re: Kuparuk Rivmr Unit ~,.-- ARCO Alaska, Inc. Permit No. 83-5 S~:r. Loc. 411'p-eT~,o~,~, 224'F~, c~ec. 16, , ~ ° TI Btrehole ~c. 1626'FSL, !03~'FEL, oec. 15, , .~a, .... Dear rjr. t~nclosed is the approved application for.permit to drill the above referenced well. If coring~ is conductad, a one cubic inch chip from each +~oo~f ~ of recovered core is required oan~pies of well cuttings and a mud log arc not required. A continuous directional survey is required as per 20 AAC 25 050(b)(5). . ~ available, a tape contain~n~,~. ,.~ the digitized log~ information shall be submitted on all 1~o~,~ for copying_ _. except experimental ~ogs,~ velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been- classified as important for the spabmtng or migration of anadronous fish. Operations in these are-as are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to co~encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Came. Pollution of any waters of the State is proI~bitea by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution 'Control Act, as amended. Prior to com~;encing operations you mav be contacted by a representatx e of the Department of Environ~ental Conservation. To aid us in scheduling._ field ~ork, pteas~ notif¥~ this oz~zce==' 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Ke~zn Kuparuk River Unit 1E-20 -2- January 11, 1983 prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission r~ay witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandor~ment, please give this office adequate advance notification so that we may have a ~itnes s present. Very~_~ truly yours, ~ ..... / ./~ ~.~z..-, ~.~'7.~.//~-~,~ ~ C. V. dh-~tert°n ~'~airmmn of ~Y ORDSR ~ IMM Alaska Oil and Gas Conservation Co~isston Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!, Department of Environmental Conservation w/o encl. CVC~be ARCO Alaska, Inc. Post Office B~__ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 3, 1983 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk 1E-20 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1E-20, along with a $100 application fee. ° A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map. _ ° A well crossing analysis. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on January 24, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, dBK:d~-ltc Inclosures RE£E VED J A N 0 7 i983 Alaska 0il & Gas Cons. Cc-remission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION COWrr~lSSlON PERMIT TO DRILL 2O 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, Inc. 3. Address P, 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 411' FSL, 224' FEL, Sec. 16, T11N, R10E, UM At top of proposed producing interval 1550' FSL, 1320' FEL, Sec. 15, TllN, R10E, UM At total depth 1626' FSL, 1039' FEL, Sec. 15, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. PAD 72' RKB 106' I ADL 25651 ALK 469 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 1E-20 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 1E-21well 60' @ surface feet 18. Approximate spud date 01/24/83 2620 psig@ 80oF Surface 2974 psig@6186 ft. TD (TVD) 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 Miles NW of Deadhorse miles 1039' FEL @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8391' MD, 6685' TVD fec. t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 800 feet. MAXIMUM HOLEANGLE42 oi(see20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program SIZE , Hole ~4" 3-1/2" 8-3/4" Casing Weight 16" 65# 10-3/4" 45.5# CASING AND LINER Grade Coupling H-40 Welded K-55 BTC 7" 26# K-55 22. Describeproposed program: BTC Length SETTING DEPTH 2331' MD TOP TVD 80' 35' I 35' I 33' 33' I I I 31' I 31' 8360' MD BOTTOM TVD 115' 115' 2364'I 2200' I 8391'16685' I I QUANTITY OF CEMENT (include stage data) 250 cf ± 1100 SX AS III + 250 sx AS i 407 sx Class G + 344 sx Class G extended Estimated T0C = 3565' MD ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8391' MD, (6685' 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 (1800 psi for annular). Expected maximum surface pressure will be 2620 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals ~j~¢ ¢~l~e~r~i;ed within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will ~e~i~s~c~lfe~nd tested upon completion of the job. See attached analysis of well crossings. J AN 0 7 1983. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Senior Drilling Engineer .The space CONDITIONS OF APPROVAL Samples required F1YES eNO Form 10-401 GRU1/PD8 Rc.v. 7-1-80 Approval date Mud log required I Directional Survey required APl number [-]YES ~]'NO [ /~-YES [~NO 50-- OL¢~-'~.c SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 3-~m'¥ !!, 1983 by order of the Commission Submit in triplicate ANALYSIS OF 1E-20/1E-21 WELL CROSSING NOTE: Refer to the attached Proximity Map. 1E-20/1E-21 Wells 1E-20 and 1E-21 will be 60' from one another from surface to a depth of 800', which is the kick-off point of 1E-20. This distance corresponds to the suface well spacing. Both wells 1E-20 and 1E-21 will have cones of uncertainty of 6' in diameter at a depth of 800'. The areas of uncertainty for the two wells will, therefore, not intersect. Since the cones of uncertainty are so small, no well intersection problems are expected. 12/30/82 EDP/A1 RECE VE JAN 0 ? 1983 Alaska Oil & Gas Cons. (;ommissior~ Anchorage, o00 j 00o .. .>0001 Surface Dive'~_~r Ssstem L 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi dri.lling spool w/lO" side outlets. / 4. lO" bail valves, hyraul ically acluated, w/lO" lines to reserve pit. Valves to open automatio cally upon closure of annular preventer-.' 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. -_ _ 16" Conductor JAN 0 7 i,983 · A!ask~ Oil & Ga$.Cori$. Cc~nmls.a.on Close annular preventer in the event that gas or fluid flow to surface is 'detected. If necessary, manually over: ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. 1' 5/8" 5000 PSt ~SRRA BOP STA'CK · 2. 3. 4. SI J ) .-. 8' .( . . ._ _. ... -FJ PIPE RRMS " ·. . C > _[.' . ~DR.iLLit,i~' ' ' C ) ) .... PrPEi-RR~S 16" 8radenhead 16" 2000 PSI x i0' S-~S.O FSI casing head 10" 3000 PSI tubing he~_d 10" 3000 PSI x 13-5/$* 5gO0 PSI .. adapter spool 13-5/8" 5000 PSI pipe ra:s 13-5/8" 5000 PSI drilling s-pool w/choke and kill lines .13-5/8" 5000 PS! pi~'ra~s- -' 13-5/8" 5000 PST_blind r-~ 13-5/8" 5000. PSI an~=lar · _ . . _ _ . 1. ~'h~EC)C 'Aha-- FItL ACCI~Lr~%QR ~'~ WI~ HTDPJULIC 2. ~S~ ~T A~.~JT~ WI~ l=S~ PSI 3. ~S~,VE TIRE Th~ C~E ~ ~ITS S~~- ~L) AqD RECOPJ T~ T~ ~ P~ ~AI~ ' ~ OFF. . L~IT IS 45 SE~(~ ~I~ T~Z ~ l~ PSI ):"s ( " 'C ) '' TBG "' " '" · ~ .~'-~ .,.......~ . ~, ? .:"..-..-:'--: 7 -. - .... -'->i;~ Oil ~ G~s'oon~' Commission Is. · ~ ':'%' _ ..-. ..:~ ~- 13-5/$" ~.O? STAY-( TF._~ ,'ILL SEAT ARB SEAT h't I/~E PR~S~Z TO D lO HI,~ES."""' B~ED TO~~[. PIPE ~'~. TO ~ PSI. - _ ~t TOP S~ OF PIPE S~ ~ PIPE ~. IN~E PP. ESSUPZ T0 3~ ~ ~,g H~ ~R l0 HIIST~. B~ED TO Z~ PSI. ~"~ ~O TEST T0 3~ B~D TO ZERO PSI. ' ~ ~'IIFOLD ~JD LI~ OI~ ~;D ~L ,~L~ ~ ~ ~A ~I~ - YI~ ~TI~LY OP~ ~ ~jLT. ~-' I~¢ 3~' ~.~" Lo~.: l~°~5'd~.~' ' ' ' x: ~c ~ ~= ~o~ ~,~.~q~, ~o' ~ 2~ ~'= ~9~700-~~' , ~'- E , ~-~..k ARCO Alaska. Inc. ' "~ 'igC& )l''~ ..... ', ". . ~J'~Anonorago/, .~ --. ...... .' ,, u !~ cHECK LIST FOR NEW WELL PERMITS company Lease & Well No. ITEM APPROVE DATE (1) Fee /'~'"1~'~.~ (2) Loc ~ r~ ~"~ (.,2 thru 8) (,9 thru 11) (4) Casg / 6"'~'' 1~!.I --'(12 thru 20) (5> BOPE ,,,~,~.~/-/~ (21 thru 24) Is the permit fee attached ..,~ ........................... ........... ,. 2. Is well to be located in 'a defined pool ............................ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ...~ ...... . ......... 5. Is suffiCient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... 9· 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO · " Does operator have a bond in force ................................ order needed Is a conservation ...................................... Is administrative approval eded ne ®eel il ice·eel·iii·Ieee'e· ·····eeeeee Is conductor string provided .............. '.... ...................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is' this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~gf Are necessary diagrams of diverter and BOP equipment attached~.~.~..~ .~ ~ Does BOPE have sufficient pressure rating -Test to .~OCPg; ps pi / ( ) ' Does the choke manifold corn y w AP1 RP-53 Feb.78 .................. Additional requirements ............................................. ~ REMARKS Geology: Engineer ing: ~WK ~ LCS ./~Y ~EW ~ WVA ~ JKT --- HJH --- rev: 12/06/82 INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE ' i ;,' ~ 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 FAT * C ~) u 0 0 U U I:) 16 0 t:, 5 Ot) O 0 O0 OOb 065 OuO OOO 008 0~5 ()00 riot) 004 uUO COO 004: 065 000 (200 002 065 ,)UO UUU 008 065 t.) u () 0 O 0 0 {) 6 0 ~ 5 = 3.570 {~ 72,0 Ii) F -- 3.023 (~ 72,0 DF = 2. 990 10 5~ 273 2 5 '7 3 5 32 2162 3 2 I 0 'I 1!1 3 ,73 t) 5 1, b Pt · 4, 375 t',, p H 1' ,3 I 2 b 1. b , ~; 313 t',~ P :ti [ , (, ,') ~; 0~'C ix, L 2.1992 42,8:223 474:.75(;,() 3.~694 2 b211 4:5: ' 459o g56.75ul~ 4.29O 5 1.0.6250 20.1172 093. O0 On 2.6 .i 0 ,g 4. a U e~ 3 32. J. 289 59'!, 3.5 c:~ 93 5.91.41 29.~2~ 826. 3.2751. 5.B98~ 23.925a 1031.. OOC;O 2. 28.5469 35.83q~ 3.5883 2.1~75 44.4824 453.5u00 4.2836 ~1.0:15~ 500,5C:g0 3.9929 I 0 k H C A l,, I I L, U C ,a L, I I t,, D C h b I I bD 0 R H 0 C A L,, I l DR.ft CAI'.,[ t, 1,,,, I) L'}' P, H 0 C ab I: .t I, l., C .a L I 1 L', F.'. tq .o C.~bl I ]., P U R r.~ 0 CAhi 1,9199 0,133~ 8,7500 2,5762 0'09L91 12,781.3 14.,6953 0;0459 10, ~203 0.0791. 5.7852 0.0337 12,@359 ~,O0'IB 0,0063 12,'1266 32,3750 0,0239 1.0.671q 2.3379 0,0400 12,1096 2.5723 0.0459 11.351~ ! a. 2,7 5 0 () f,;P tq :I -99¥? zbUt ~C, - 0 !}g ' 2.. ~ o 0 .k :,,! i; a - b W ~J. 2.5 G i) }:' C ~;, I. --gq?.2b{',~, i:, lk:~ - 999. 5 00 .IL)9¢' '" ~ ~, .'.'..~ 250:,, "'999' , 250{) -999. 250O -999.25 u o -999.25U0 3.906N -999.2500 -999.250n -999.2500 2,2500 '999, -999,2.500 .-999 . 2500 2,203', -999,2500 -999,2 -~99,2500 -999,25~U -999,2500 2.3~27 -999.25o0 -999.25uo -999,25UU 2.U859 -999.2500 -999.2bOU -999.25U0 1.71.78 -999.25UU -999.25U0 -999.25U{~ 2 , 5%q5 -999.2500 -999.2bU9 -999,2500 I, t.,, I0 D. R H ,I L.D c A L I 1) R H f.] C A b 1 I b l.) Ca I.., I CALl 2. , 6'766 999 '2500 11,8125 2. --999,2500 1/.7969 2.'724:6 -999,2500 12,4453 ,9766-99 ,~500 11' 4:53 -999, 500 11.4706 2.0664 1,1.0391 2,9746 -999.250O 2.2109 -999,2500 11,71{')9 2,20"10 -999,2500 Iu.6953 1.6~65 -999.2500 11,1797 2,~203 -999.2500 10.4297 I'-~ I'~ i! l iil iI:~ ii! [:~ I ..... 2 H, 0 () 5~. 12~9 ~2,9375 -999,2500 - 9 ;:) 9,250 t) -,' 7 ~. 6 ~ 75 - 999,250 I": R ": R A 2. :1934 -999, -a6q 2r'''', -gqq, -999. 2500 -999,2500 2.3867 -999. 2500 -99<.). 2500 -999. 2500 2,179't -999. 251}c) -999.250o -9q9.25(10 2. I i~21. -999,250O -q9g, 2500 -999.25O0 2.3711, -999.25f~0 -999.25u0 - 9 99.2 5 o 0 2.4].F~n -999. 2500 - 9 99.2500 -999,2500 2,7793 -999,2500 -999,25U0 -999 · 2500 4.2q22 -q99.25U0 -999. 250() I. b L) L) R ttu C' A L, I ,L b D 1) R Pi t.'] C/:,~, b I I b t AL l i. I,, D DR C A [, 1 i L, P. R H [) 1 C.a. I, I 2.2871. -99~ 25U0 :3594 2,0938 -9q9.2500 1.2.4531 2,441.4 -999,2500 11,3359 2,2363 -999.250O ll,601b 2.2]87 -999,2500 11,5234 2,4688 -999.2500 11,6094 2.515b -999.2500 11,4141 2,8984 '999,2500 11,1250 3.1504 -9~9,2500 11.1406 3,t980 -999.2500 10,7969 .4,507~ -999.2500 11,000() P ~) :.1. 0. ;.~ 0 2 v El, 14 [ P' J tj ,:.., ["] i..;i ~, L t S '1; I .k (:; P & G E'. 7 3 · (:89~ -999.25(~g FCml., 3. 3125 · - 999.2'i-] C r.t ~ C'. N I.. - 9 9 9,25 (J ',) 71. i:, i 25 ,',~ P iq l -99q.2bOu -99 9.25C:0 R:,~P A · ,:. 1 0 q i -999,25o0 F(]i'~ b 1. U, q. 219 l, J., N,. - 2. ,) L 0 5,023a -999' 250{) ~,999 3,3 43 :q -999 2500 - g 9 9 ' 250 · -999.25 u 0 -~99,25u0 '999,2500 -999 ' 2500 4,0195 -999,2500 909,250() -999:. 2 5 (,I 0 2,5005 -999 ' 250n -999,2500 -999,215u0 3,2539 -999.2500 -999.2500 -999.250t~ -999,250f) 3,1699 -999,2500 .amg. 250r: -999,2500 -999,'25Uu -999,250',) -999,25U0 5,9297 -999.250t.', -999.25~0 -999.2500 ll,!.Ugq- 38.2'324 1 L D ;..~ R 1,4 i] C A bi, ] [.,D L) R H {J CALl I bO CALl .1. I',~ D D R b tJ C a, b I 1 b L) 1.) R H o C A i,, I i I..,D OIRH 1t C A L, I .1. b C~Li II,D I) H ~.t CJ CALl l t,.., [., C A 1..~ I f, R H C A L, 1 i bi) i) R ti () 5,1641 -999,.250() 1:1.,1562 3,3()66 -9~9,250~ 2,8359 -999'2500 12,80g7 4. 2695 -999,12.500 i2. 719 2,7852 -999.2500 .12,57ul 3,!727 -999,2500 ]1.2,1719 .3,3242 -999.2500 3,4922 -999.2500 13,6094 4,2422 -999,2500 12,9609 ~,3281 -999.2500 12.9922 0.0n24 i~,? i~ I I I I i 1 ,I:-I i[! [:-11 ::: -57.2 ? t 3 ~': ..',i : a 7. ':; 3 7:3 4. A 'i' ... 0 t') O 0 ~453 3,4. :: :...'.' 3.4453 7 2. z .:: ,, '.2292. u, 00 u 3, 2422 7 ~ 13 u 000 5352 61.~375 .I 7Ub,t.;Ut)(3 3. f.,75~ 66,93'.]5 !.79!5.0 0 f... (! 3.57.12 I 76. 'l . (.: i'.~ {; 0 3.~7223 12,.3125 FC hi F C ~ b I:?,'. 3,: R~ t:-: II.,v 500{) 61 '5751 4:. 96 [{ 7 37,9~.3 [.413 !., 50 t'~ 0 3 , 738 '? 1. 3,8b.'2%t 35. 6934: 60~, 50o0 3,6296 I7.5625 3e3.9629 3. 5398 1,1250 '1 · 3 (.: 47 5~5.5t)O0 3.9615 59,406 :{ 3b, 9629 b 19,500() 3.6931 12,6641 37,4512 593,00(.~ :.) 3,7151 7.~05~ 43,3105 435,7500 :3.9547 ~4 .bl "12 41.5039 4 ;5 6, b t~ (.) .q 5,5~7 .~ 45,.~543 ~.34.0t;00 C A L [ .'1 L L:t~ R P; U (7 ,~. t., J i 1.,~ D 1.) R F"t {) CAb [ ,l L i3 u }~ H [J Cnl.,I I l., i} .-.' R i"t 0 I [., D i) :~t H b C~b :1 i, L, L) C t~f.,I U ~ ,H t J C A b l: lbo 1: R h 0 CALI [ I., D '10.4375 5,73O5 0,0630 3 · .~609 1~,9531 u,0518 '1.2,9531 1.~,,9531 o,1250 1.1,6953 12,~078 O, 239 i4.~359 51,5313 -0,0039 14.0391 1~,0313 0,0552 13,U391 1.2.bOl, b -0,0098 11,1016 8.7578 10,9531 10.0938 0.0400 .10.9297 ~.6922 0.0317 11,5234 ~,7344 24, ~ 45:7 L b l~,! 13,414! I !.,,P' 46.9667 3,44:92 144:. 0.172 I il, ~< 41. 093~ 5.97 t ',5 ]. [, 52. b t) {'., 0 f.,, P ~ I j 77!.(:(':0(i Ft:,~! 585.5O00 3.~917 400 00 d 0 4 ,4033 6,41 t30 50,04t.~ ~ 45'.') !, 2500 4 32, 2(, 4,8,2422 16, ? 500 4.2917 10. 1.797 <~:~, ~ 340 60 2, t., 00 4!. t; 9 47 11,7500 33 · 6 ~. 67 709,000 o 49, ] b99 45~.'15¢)0 15,2344 38.1.348 051., 5000 3,8106 1.4,8594 39,257~ 3.~140 9,6250 50,~.348 446,- .... 7.085~ 354,000') ~,7355 C ~h I 'I1,D C k b 1, [./.., I'> 1..,.~ R H [3 C A L I .[ L D C a..IL., 1,' ,~'l .U :1 11 D 1~ R t4 O C A L, l t b D ,[ L f) Ct, L! i b l) D N !-] ii,[' CAb I u,0~161 .i I., 219 t', 23t~3 0,0493 10.3594 7,5313 0093 4609 O,519:5 0,0298 11,0391 '10.7969 -U,0029 11.6094 !2,9297 010049 12,65~3 I.O,632g u,034'7 11.,t141 15,8984 13,1953 t5,3594 -U,0073 12.0075 ll,b~B4 -0.0034 12.359~ 9.7813 0.021(.) 19.2031 . 125O ,.5317 0..07~1
