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185-072
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 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 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 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' 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 7182'feet 6777'feet true vertical 6940' feet None feet Effective Depth measured 6954'feet 6485', 6754'feet true vertical 6750' feet 6250', 6516'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 2-7/8" L-80 J-55 6761' 6790' 6523' 6552' Packers and SSSV (type, measured and true vertical depth)6485' 6754' 6250' 6516' 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-382 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 SLB Blue Max RH Baker DB SSSV: None Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013Staff RWO/CTD Engineer 6677-6703', 6846-6855', 6862-6889', 6941-6948' 6440-6466', 6607-6616', 6623-6650', 6701-6708' 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 MDSize 110' N/A measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-072 50-029-21332-00-00 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: ADL0025635 Kuparuk River Field/ Kuparuk Oil Pool KRU 1R-07 Plugs Junk measured Length 2836' 110'Conductor Surface 16" 10-3/4" 72' Production Casing 7125' 7" 7160' 6918' 2873' 2805' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:09 am, Nov 14, 2023 Page 1/9 1R-07 Report Printed: 11/8/2023 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 10/7/2023 12:00 10/7/2023 14:30 2.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P MOB to 1R-07, shuffle rig mats, spot T mats around 1R-07 cellar Spot well head equipment behind rig, spot tree in cellar 10/7/2023 14:30 10/7/2023 16:00 1.5 0 0.0 0.0 MIRU, MOVE MIRU MOB P Spot rig over 1R-07, shim and level rig 10/7/2023 16:00 10/7/2023 20:00 4.0 0 0.0 0.0 MIRU, MOVE MIRU RURD P Berm up cellar area, spot cuttings box, kill and open top tanks, work on rig acceptance check list Accept rig 20:00 HRS 10/7/2023 20:00 10/7/2023 23:45 3.7 5 0.0 0.0 MIRU, WELCTL MIRU RURD P Load pits with 8.6 PPG seawater, build deep clean pill, R/U circulating lines for well kill, contuine rigging up hard lines and hoses to open top and kill tank, spot mud shack, high line trailer, blow air thru lines to tanks, prime mud pumps, check all 1502 connections Obtain RKB's GL = 30.52', LDS = 27.70', ULDS = 25.80' 10/7/2023 23:45 10/8/2023 00:00 0.2 5 0.0 0.0 MIRU, WELCTL MIRU DISP P PJSM, on displacing well to 8.6 PPG seawater TBG = 745 PSI I/A = 645 PAI O/A = 240 PSI 10/8/2023 00:00 10/8/2023 00:30 0.5 0 0.0 0.0 MIRU, WELCTL MIRU DISP P Double check valve line up, flood lines with water, Test lines T/3,000 PSI 10/8/2023 00:30 10/8/2023 00:45 0.2 5 0.0 0.0 MIRU, WELCTL MIRU DISP P Line up bleed off gas cap TBG F/745 PSI T/730 PSI, I/A F/645 PSI T/600 PSI 10/8/2023 00:45 10/8/2023 02:15 1.5 0 0.0 0.0 MIRU, WELCTL MIRU DISP P TBG PSI = 750 I/A PSI = 635 PSI Pump 32 BBL warm deep clean pill, followed by 290 BBLS 8.6 PPG seawater holding 830 PSI on I/A until seawater turned corner At 1700 STKS shut down monitor TBG pressure bleed DN F/600 T/460 PSI, build to 480 PSI Cont. pumping 8.6 PPG seawater at 4 BPM holding 680 PSI on TBG 10/8/2023 02:15 10/8/2023 05:00 2.7 5 0.0 0.0 MIRU, WELCTL MIRU SIPB P Shut down montior pressure's, While off loading 10.4 PPG NaCl/NaBr to pits 460 PSI on TBG/IA Shut in well blow down all lines Open back up to montior pressure's 460 PSI on TBG/IA 10/8/2023 05:00 10/8/2023 07:30 2.5 0 0.0 0.0 MIRU, WELCTL MIRU KLWL P TBG/IA PSI = 460 PSI Pump 32 BBL Deep clean pill Followed by 390 BBLS 10.4 PPG NaCl/NaBr Holding 680 PSI on IA until KWF turn corner at open GLM, then hold 280 PSI on DP Pump at 3 BPM, taking returns to tiger tank Lost 121 BBl on circulation 10/8/2023 07:30 10/8/2023 09:30 2.0 0 0.0 0.0 MIRU, WELCTL MIRU OWFF P 10.3 PPG at surface, S/D pumps, casing and IA on vac. Flow check while loading 10.4 into pits. OA=200 PSI Getting F/P diesel coming out of IA. Flow check while combining fluids in pits 10/8/2023 09:30 10/8/2023 10:15 0.7 5 0.0 0.0 MIRU, WELCTL MIRU RURD P Loss rate 7 BBls/Hr. Plann to pump 5 BBls/30 minutes during nipple up/down ops. Load DP 10/8/2023 10:15 10/8/2023 11:00 0.7 5 0.0 0.0 MIRU, WELCTL MIRU RURD P Set BPV. R/U to test. Pumping 2 BPM straight injection @ 125 PSI. Pump away 25 BBls. Consult town. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 2/9 1R-07 Report Printed: 11/8/2023 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 10/8/2023 11:00 10/8/2023 14:00 3.0 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P N/D tree Load out / Load DP into shed 10/8/2023 14:00 10/8/2023 18:00 4.0 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P PJSM, Nipple up 13 5/8" BOPE pick stack up off BOP stand, set back down and remove flow nipple off top of bag due to clearance issues with rotary table beams. Pick stack up and set down on well head, N/U 7 1/16" 5K x 11" 5K adaptor flange on bottom of BOP Go to pick stack back up to install new ring gasket in the 13 5/8" x 11" DSA and notice DS bridge crane wasn't working correctly. Set stack back down on well head and secure with come a longs, remove bridge cranes from BOP lift plate. Fill down IA with 5 BBLS every 30 min 10/8/2023 18:00 10/8/2023 21:00 3.0 0 0.0 0.0 MIRU, WHDBOP MIRU RGRP T Trouble shoot driller side bridge crane, find that the bearing in the hook was bad. PJSM, rig up wire rope slings on BOP lift plate and to top drive. Pick stack up install API ring gasket, set stack back down. Fill down IA with 5 BBLS every 30 min 10/8/2023 21:00 10/9/2023 00:00 3.0 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P Cont. N/U BOP, make up 13 5/8" x 11" DSA, hook up kill line Contuine to load and process drill pipe in pipe shed Fill down IA with 5 BBLS every 30 min 10/9/2023 00:00 10/9/2023 07:00 7.0 0 0.0 0.0 MIRU, WHDBOP MIRU NUND P Contunie to N/U BOP equipment, hook up choke line, install flow box and install riser and air up boots Adjust trip tank fill nipple on flow box Contuine to load and process drill pipe in pipe shed Fill down IA with 5 BBLS every 30 min 10/9/2023 07:00 10/9/2023 12:00 5.0 0 0.0 0.0 MIRU, WHDBOP MIRU PRTS T Fill stack. Go to HP test. Grey locks leaking on choke line. Reconfigure multiple times. 10/9/2023 12:00 10/9/2023 12:30 0.5 0 0.0 0.0 MIRU, WHDBOP MIRU RURD P Rig up testing equipment, install 3 1/2" test joint Fill stack and lines with water, work air out of system Obtain good shell test Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 3/9 1R-07 Report Printed: 11/8/2023 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 10/9/2023 12:30 10/9/2023 19:00 6.5 0 0.0 0.0 MIRU, WHDBOP MIRU BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Fail/Pass on annular, UVBR/LVBR w/ 3 1/2" test joints. Fail/Fail on blind 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=3050 PSI, after closure=1750 PSI, 200 PSI attained =17 sec, full recovery attained =119 sec. UVBR's= 5 sec, Simulated LVBRs= 5 sec. Annular= 19 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1887 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. 10/9/2023 19:00 10/9/2023 19:45 0.7 5 0.0 0.0 MIRU, WHDBOP MIRU BOPE P Rig down testing equipment, blow down lines, drain stack Pump 5 BBLS/30 min down IA 10/9/2023 19:45 10/9/2023 22:00 2.2 5 0.0 0.0 MIRU, WHDBOP MIRU BOPE P Change out blind rams 10/9/2023 22:00 10/9/2023 22:30 0.5 0 0.0 0.0 MIRU, WHDBOP MIRU BOPE P Rig up fill stack and lines with water, Retest blind rams 250/3000 PSI 5 min each. 10/9/2023 22:30 10/9/2023 23:00 0.5 0 0.0 0.0 MIRU, WHDBOP MIRU BOPE T Test blind rams 250/3000 PSI F/5 min each 10/9/2023 23:00 10/9/2023 23:15 0.2 5 0.0 0.0 MIRU, WHDBOP MIRU RURD P R/D BOP test equipment 10/9/2023 23:15 10/10/2023 00:00 0.7 5 0.0 0.0 MIRU, WHDBOP MIRU MPSP P Pick up 3 1/2" test JT, pull FMC slip over blanking plug Put 10 BBLS down hole from TT when IS- A plug out of hole 10/10/2023 00:00 10/10/2023 00:15 0.2 5 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Blow down and rig down circulating line to IA 10/10/2023 00:15 10/10/2023 00:45 0.5 0 0.0 6,489.0 COMPZN, RPCOMP MIRU PULL P Make up landing joint to hanger 9 3/4 turns, make up top drive, set DN 10K BOLDS, pick up 105K hanger come off seat , 97K UP when seals out of PBR Pull hanger to floor T/6,489' 10/10/2023 00:45 10/10/2023 01:30 0.7 5 6,489.0 6,489.0 COMPZN, RPCOMP MIRU CIRC P Pump at 2 BPM while adding 15 BBLS F/trip tank across top take 27 BBLS to fill hole to top of stack Circulate establish loss rate @ 2 BPM 85 PSI Loss rate = 40% Pump 79 BBLS total lose 31 BBLS 10/10/2023 01:30 10/10/2023 02:00 0.5 0 6,489.0 6,489.0 COMPZN, RPCOMP MIRU OWFF P Flow check, dropping with small bubbles breaking out Line up trip tank establish static loss rate @ 42 BPH - monitor for 20 min 10/10/2023 02:00 10/10/2023 02:30 0.5 0 6,489.0 6,489.0 COMPZN, RPCOMP MIRU PULL P Break out landing JT, break out and lay down hanger 10/10/2023 02:30 10/10/2023 10:00 7.5 0 6,489.0 0.0 COMPZN, RPCOMP MIRU PULL P Pull out of hole laying down 3 1/2" tubing to pipe shed Adding 10 BBLS every 30 min plus double pipe displacement From 6,489' T/Surface, 204 Jts Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 4/9 1R-07 Report Printed: 11/8/2023 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 10/10/2023 10:00 10/10/2023 11:30 1.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P On surface with seal assembly. Lay down conpomnets. Clear floor, Set wear bushing. Bring BOT BHA #1 to rig floor 10/10/2023 11:30 10/10/2023 13:00 1.5 0 0.0 221.7 COMPZN, RPCOMP MIRU BHAH P PJSM, Make up BHA #1 in hole, Spear, Jars, DC's T/ 221' 10/10/2023 13:00 10/10/2023 19:15 6.2 5 221.7 6,407.0 COMPZN, RPCOMP MIRU PULD P PUDP F/ 221' T/ 6407' PUW=137K, SOW=115K. 10/10/2023 19:15 10/10/2023 21:45 2.5 0 6,407.0 6,407.0 COMPZN, RPCOMP MIRU SLPC P Slip and cut 66' of drill line. 10/10/2023 21:45 10/10/2023 22:30 0.7 5 6,407.0 6,407.0 COMPZN, RPCOMP MIRU CIRC P Circ 35 Bbls hi vis pill. Close UVBR's. Bullhead pill out into C sand @ 2 BPM, ICP=270, FCP=675. Open UVBR's. 10/10/2023 22:30 10/10/2023 23:00 0.5 0 6,407.0 6,407.0 COMPZN, RPCOMP MIRU OWFF P OWFF. B/D TD. 10/10/2023 23:00 10/10/2023 23:15 0.2 5 6,407.0 6,510.0 COMPZN, RPCOMP MIRU PULD P Cont PUDP F/ 6407'. Kelly up. Engage PBR @ 6510' w/ spear burried 5' T/ 6515'. PUW137K, SOW=116K. 10/10/2023 23:15 10/11/2023 00:00 0.7 5 6,510.0 6,505.0 COMPZN, RPCOMP MIRU FISH P Bleed jars. P/U pipe free @ 250K. Allow elements to relax for 15 Min. Stroke pipe up 50' and back down 50' T/ 6505'. No packer drag observed. 10/11/2023 00:00 10/11/2023 02:30 2.5 0 6,505.0 6,505.0 COMPZN, RPCOMP MIRU CIRC P Circ BU + losses @ 2 BPM, 230 PSI, 80% return rate. 10/11/2023 02:30 10/11/2023 03:00 0.5 0 6,505.0 6,505.0 COMPZN, RPCOMP MIRU OWFF P OWFF, B/D TD 10/11/2023 03:00 10/11/2023 07:00 4.0 0 6,505.0 221.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6505' T/ 221'. PUW=139K. 10/11/2023 07:00 10/11/2023 08:30 1.5 0 221.0 0.0 COMPZN, RPCOMP MIRU BHAH P Stand back drill collars, Lay down BHA #1. Recovered PBR to poorboy overshot. 49.03' 10/11/2023 08:30 10/11/2023 09:30 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU SVRG P Service crown, top drive, spinners, and draw works, Derrick inspection 10/11/2023 09:30 10/11/2023 12:00 2.5 0 0.0 225.0 COMPZN, RPCOMP MIRU BHAH P PJSM, P/U BHA #2 Overshot, P/U 15 singles 10/11/2023 12:00 10/11/2023 15:00 3.0 0 225.0 6,531.0 COMPZN, RPCOMP MIRU TRIP P Trip in out of derrick to 6531' 10/11/2023 15:00 10/11/2023 16:00 1.0 0 6,531.0 6,550.0 COMPZN, RPCOMP MIRU FISH P ,Get parameters, PUW=140K, SOW=117, P/U Working joint, Roll pumps 2 BBL/Min @ 170 PSI. Rotate 15 RPM w/3400 Ft/Lbs. Circulating PUW=130, SOW=123. RIH see pressure increase to 400 PSI @ 6553, Continue in to setdown @ 6560 w/10K down. PUH no latch. Repeat. PUH 40'. RBIH set down @ 6550. No latch. Run into it few times. No latch. 10/11/2023 16:00 10/11/2023 16:30 0.5 0 6,550.0 6,560.0 COMPZN, RPCOMP MIRU OWFF P PJSM, Lay down single working joint. Blow down top drive. Flow check well. 10/11/2023 16:30 10/11/2023 18:30 2.0 0 6,550.0 3,752.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6544' T/ 3752', PUW=140K. 10/11/2023 18:30 10/11/2023 19:00 0.5 0 3,752.0 3,752.0 COMPZN, RPCOMP MIRU SVRG P Rig service. Secure service loop on TD. 10/11/2023 19:00 10/11/2023 20:45 1.7 5 3,752.0 225.0 COMPZN, RPCOMP MIRU TRIP P Cont POOH F/ 3752' T/ 225', PUW=94K. 10/11/2023 20:45 10/11/2023 21:30 0.7 5 225.0 0.0 COMPZN, RPCOMP MIRU BHAH P Rack back 2 stands DC's. L/D BHA #2. Inspect overshot and grapple. Mill control looked good. Grapple was sharp. No obvious deficiencies noted on why it did not catch. 10/11/2023 21:30 10/11/2023 22:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean & clear RF. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 5/9 1R-07 Report Printed: 11/8/2023 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 10/11/2023 22:00 10/11/2023 22:45 0.7 5 0.0 227.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #3 overshot w/ 9' of extension and 3.44" spiral grapple T/ 227'. SOW=45K. 10/11/2023 22:45 10/12/2023 00:00 1.2 5 227.0 3,010.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 227' T/ 3010', PUW=85K, SOW=80K. 10/12/2023 00:00 10/12/2023 02:00 2.0 0 3,010.0 6,538.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 3010' T/ 6538', PUW=137K, SOW=117K. 10/12/2023 02:00 10/12/2023 02:30 0.5 0 6,538.0 6,623.0 COMPZN, RPCOMP MIRU FISH P Obtain parameters. Circ @ 2 BPM, 195 PSI. Rot @ 15 RPM, 3.4K Free Tq, ROT=125K. Wash and ream over tubing stub, pressure increase T/ 380 PSI @ 6551'. Cont in fully locate overshot over stub @ 6563' w/ 17K down. P/U T/ 150K, bleed jars. Straight pull T/ 250K, pipe free. P/U T/ 6534', packer drag seen T/ 155K. 10/12/2023 02:30 10/12/2023 08:30 6.0 0 6,623.0 6,623.0 COMPZN, RPCOMP MIRU CIRC P Circ @ 1 BPM, 110 PSI w/ 60% return rate. Circulate until no gas break out 10/12/2023 08:30 10/12/2023 09:00 0.5 0 6,623.0 6,623.0 COMPZN, RPCOMP MIRU OWFF P Flow check well. Good. Taking 7 BPH static. 10/12/2023 09:00 10/12/2023 12:00 3.0 0 6,623.0 5,878.0 COMPZN, RPCOMP MIRU TRIP P Trip out. First stand out of slips over pull to 200K. Not wanting to go back in hole. Get BOT to floor, Kelly up and pump out, 3 BPM @410 PSI, PUW 150 bouncing 10/12/2023 12:00 10/12/2023 13:00 1.0 0 5,878.0 5,607.0 COMPZN, RPCOMP MIRU TRIP P Go to tripping on elevators filling down back side 10/12/2023 13:00 10/12/2023 13:30 0.5 0 5,607.0 5,607.0 COMPZN, RPCOMP MIRU SFTY P Have safety shutdown w/Chuck Van Ray, Well HSE rep Jerry B. Crew and Newell. Discussed yesterdays event with fractured hand. Discussed mitigations going forward 10/12/2023 13:30 10/12/2023 19:15 5.7 5 5,607.0 227.0 COMPZN, RPCOMP MIRU TRIP P Continue out of well, watching displacement, Pumping 5 BBls every 30 minutes + displacement, PUW=130K 10/12/2023 19:15 10/12/2023 19:45 0.5 0 227.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #3 T/ fish top. 10/12/2023 19:45 10/12/2023 20:15 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU PULL P L/D 3 1/2" completion fish 13.45' cut, PBR, packer, 1 joint of tubing, GLM, Lower cut 15.28', clean cut no flare. OAL=91.01'. 10/12/2023 20:15 10/12/2023 21:15 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Recover upper cut out of overshot in BHA #3. 10/12/2023 21:15 10/12/2023 21:45 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean & clear RF. 10/12/2023 21:45 10/12/2023 22:45 1.0 0 0.0 230.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #4 overshot w/ 9' of extension and 3.5" spiral grapple T/ 230'. SOW=45K. 10/12/2023 22:45 10/13/2023 00:00 1.2 5 230.0 4,026.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 230' T/ 4026', SOW=90K. 10/13/2023 00:00 10/13/2023 01:15 1.2 5 4,026.0 6,633.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 4026' T/ 6633', PUW=141K, SOW=117K. 10/13/2023 01:15 10/13/2023 01:45 0.5 0 6,633.0 6,630.0 COMPZN, RPCOMP MIRU FISH P Obtain parameters. Circ @ 2 BPM, 205 PSI. Rot @ 15 RPM, 4K Free Tq, ROT=127K. Wash and ream over tubing stub, pressure increase T/ 240 PSI @ 6644'. Cont in fully locate overshot over stub @ 6656' w/ 10K down. P/U no over pull. PUW=142K. P/U 25'. S/O reconfirm tag on top of tubing stub w/ 10K down. 10/13/2023 01:45 10/13/2023 02:00 0.2 5 6,630.0 6,630.0 COMPZN, RPCOMP MIRU RURD P B/D TD. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 6/9 1R-07 Report Printed: 11/8/2023 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 10/13/2023 02:00 10/13/2023 03:45 1.7 5 6,630.0 3,855.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6630' T/ 3855', PUW=142K. 10/13/2023 03:45 10/13/2023 04:15 0.5 0 3,855.0 3,855.0 COMPZN, RPCOMP MIRU SVRG P Service rig. Clean draw works sump. 10/13/2023 04:15 10/13/2023 05:30 1.2 5 3,855.0 230.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 3855' T/ 230, PUW=95K. 10/13/2023 05:30 10/13/2023 06:30 1.0 0 230.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down BHA # 4, Have fish, Recover 15.28' upper cut joint, 2 blast joints, 26.9 & 30.81, 2.85' lower cut joint 10/13/2023 06:30 10/13/2023 08:30 2.0 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P PJSM with PESI to lay down blast joints, Bring PESI tools to floor. Prep floor for blast ring removal, Break rings loose. L/D joints. Lay down PESI false table and tools. 10/13/2023 08:30 10/13/2023 09:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU BHAH P Clean up carbide from rig floor 10/13/2023 09:00 10/13/2023 11:30 2.5 0 0.0 225.0 COMPZN, RPCOMP MIRU BHAH P P/U jar, bumper sub, and overshot. Disengage fish from overshot/ Redress grapple. Shorten wash pipe. Trip in hole with BHA 10/13/2023 11:30 10/13/2023 15:12 3.7 0 225.0 6,690.0 COMPZN, RPCOMP MIRU TRIP P Trip in with BHA #5 10/13/2023 15:12 10/13/2023 15:18 0.1 0 6,690.0 6,690.0 COMPZN, RPCOMP MIRU FISH P Kelly up, PUW=143K, SOW=117. Roll pump 2 BPM @ 215 PSI, Rotate 15 RPM @ 3300 Ft/Lbs, Wet rotating P/U=130K, SOW=127 10/13/2023 15:18 10/13/2023 15:24 0.1 0 6,690.0 6,722.0 COMPZN, RPCOMP MIRU FISH P RIH, see pressure increase @ 6715'to 400 PSI. S/D pump, continue in to 6722 with 15K down 10/13/2023 15:24 10/13/2023 15:30 0.1 0 6,722.0 6,718.0 COMPZN, RPCOMP MIRU FISH P PUH to 160K, 6718'. Let jars bleed off, Pull up to 241K. No movement 10/13/2023 15:30 10/13/2023 18:30 3.0 0 6,718.0 6,718.0 COMPZN, RPCOMP MIRU FISH P Start Jarring on fish, 50K over, straight pull T/ 100K over. Stage jar hits up T/ 100K over, straight pull T/ 100K over. 100 hits at 100K no movement. Consult w/ town, decision made to release from fish and wash over to top of packer. 10/13/2023 18:30 10/13/2023 20:15 1.7 5 6,718.0 6,718.0 COMPZN, RPCOMP MIRU SFTY P Post jarring derrick inspection. No deficiencies noted. 10/13/2023 20:15 10/13/2023 20:45 0.5 0 6,718.0 6,618.0 COMPZN, RPCOMP MIRU FISH P Circ 2 BPM, 200 PSI. S/O break friction bite. Rotate T/ right off of fish top @ 65 RPM, 6.5K Tq. P/U T/ 6688', PUW=141K. 10/13/2023 20:45 10/13/2023 21:15 0.5 0 6,618.0 6,618.0 COMPZN, RPCOMP MIRU RURD P OWFF. B/D TD. L/D working single. 10/13/2023 21:15 10/14/2023 00:00 2.7 5 6,618.0 2,639.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6618' T/ 2639', PUW=141K. 10/14/2023 00:00 10/14/2023 02:15 2.2 5 2,639.0 227.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 2639' T/ 227', PUW=80K. 10/14/2023 02:15 10/14/2023 03:00 0.7 5 227.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #5 F/ 227 T/ surface, PUW=45K. 10/14/2023 03:00 10/14/2023 03:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean and clear RF 10/14/2023 03:30 10/14/2023 04:45 1.2 5 0.0 253.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #6 wash pipe & shoe T/ 253', SOW=45K. 10/14/2023 04:45 10/14/2023 05:00 0.2 5 253.0 500.0 COMPZN, RPCOMP MIRU TRIP P RIH F? 253' T/ 500' 10/14/2023 05:00 10/14/2023 08:42 3.7 0 500.0 6,690.0 COMPZN, RPCOMP MIRU TRIP P Continue trip in 500' T / 6690, KU, Circ 2 BPM @ 215 PSI, Get returns, 15 RPM- 33900 Ft/Lbs, Circulating PUW=130, SOW=127 Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 7/9 1R-07 Report Printed: 11/8/2023 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 10/14/2023 08:42 10/14/2023 10:00 1.3 0 6,690.0 6,745.0 COMPZN, RPCOMP MIRU CIRC P Bring rate up to 5 BPM @ 1850. Wash down to TOF @ 6719. Slight pressure increase, . Recipe wash down to hard bottom @ 6745. and repeat 10/14/2023 10:00 10/14/2023 10:36 0.6 0 6,745.0 6,745.0 COMPZN, RPCOMP MIRU OWFF P Flow check well, Blow down top drive 10/14/2023 10:36 10/14/2023 14:00 3.4 0 6,745.0 253.0 COMPZN, RPCOMP MIRU TRIP P Trip out of well, PUW=140K 10/14/2023 14:00 10/14/2023 15:30 1.5 0 253.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down BHA #6, Wash over pipe. Boot basket had some scale in it 10/14/2023 15:30 10/14/2023 17:00 1.5 0 0.0 322.0 COMPZN, RPCOMP MIRU BHAH P Make up BHA #7, Overshot grapple T/ 227', SOW=45K. M/U 1 stand T/ 322' 10/14/2023 17:00 10/14/2023 19:30 2.5 0 322.0 322.0 COMPZN, RPCOMP MIRU SLPC P Slip and cut 66' of drill line. Check crown o matic. Set block height. 10/14/2023 19:30 10/14/2023 22:45 3.2 5 322.0 6,695.0 COMPZN, RPCOMP MIRU TRIP P RIH F/ 322' T/ 6695'. PUW=145K, SOW=119K. 10/14/2023 22:45 10/15/2023 00:00 1.2 5 6,695.0 6,725.0 COMPZN, RPCOMP MIRU FISH P Pump @ 2 BPM, 185 PSI, Rot @ 15 RPM, 3.6K Free Tq, ROT=130K. Wash and ream over tubing stub T/ 6725'. Stage up straight pull & jar hits T/ 100K over. 25 jar hits no pipe movement. 10/15/2023 00:00 10/15/2023 00:30 0.5 0 6,725.0 6,725.0 COMPZN, RPCOMP MIRU FISH P Cont straight pull & jar hits T/ 100K over. Total of 40 jar hits no pipe movement. Grapple slipped off fish top. Attempt to reengage fish top unsuccessfully. 10/15/2023 00:30 10/15/2023 01:00 0.5 0 6,725.0 6,695.0 COMPZN, RPCOMP MIRU RURD P L/D working single T/ 6695', PUW=145K. B/D TD. OWFF 10/15/2023 01:00 10/15/2023 02:00 1.0 0 6,695.0 6,695.0 COMPZN, RPCOMP MIRU SFTY P Perform post jarring derrick inspection. No deficiencies identified. 10/15/2023 02:00 10/15/2023 05:30 3.5 0 6,695.0 230.0 COMPZN, RPCOMP MIRU TRIP P POOH F/ 6695' T/ 230', PUW-145K. 10/15/2023 05:30 10/15/2023 08:00 2.5 0 230.0 0.0 COMPZN, RPCOMP MIRU BHAH P Lay down collars and fishing BHA #8. Recover seal assembly from PBR, Lay down and load out 10/15/2023 08:00 10/15/2023 09:30 1.5 0 0.0 251.0 COMPZN, RPCOMP MIRU BHAH P M/U BHA #9, 2 7/8" mule shoe, 2, 6.125 string reamers, boot backets, 2 stands Drill collars 10/15/2023 09:30 10/15/2023 12:30 3.0 0 251.0 6,376.0 COMPZN, RPCOMP MIRU TRIP P Trip in well to 6376', Stand 67. Kelly up. Displace to viscosified 10.3 PPG brine 10/15/2023 12:30 10/15/2023 15:30 3.0 0 6,376.0 6,755.0 COMPZN, RPCOMP MIRU DISP P Wash down to PBR @ 6755. Work packer setting area @ 6495 10/15/2023 15:30 10/15/2023 16:30 1.0 0 6,755.0 6,755.0 COMPZN, RPCOMP MIRU DISP P Recip PBR. Load on clear brine. Prep to pump Hi vis sweep followed with 10 BBl spacer Viscocified bring then clear 10.3 Brine 10/15/2023 16:30 10/15/2023 18:00 1.5 0 6,755.0 6,755.0 COMPZN, RPCOMP MIRU DISP P Pump Hi Vis sweep down DP, 26 BBls, Pump 10 BBl spacer. Chase with 10.3 PPG brine off truck. Recip PBR on hi vis sweep exiting drill pipe. Chase to surface. 5 BPM @ 700 PSI. B/D TD. 10/15/2023 18:00 10/15/2023 18:30 0.5 0 6,755.0 6,755.0 COMPZN, RPCOMP MIRU SVRG P Service rig. Add oil & service draw works. 10/15/2023 18:30 10/15/2023 23:15 4.7 5 6,755.0 251.0 COMPZN, RPCOMP MIRU PULD P LDDP F/ 6755' T/ 251', PUW=145K. 10/15/2023 23:15 10/16/2023 00:00 0.7 5 251.0 86.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #8 10/16/2023 00:00 10/16/2023 01:00 1.0 0 86.0 0.0 COMPZN, RPCOMP MIRU BHAH P L/D BHA #8, clean scale out boot baskets. 10/16/2023 01:00 10/16/2023 02:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU CLEN P Clean and clear RF and pipe shed. 10/16/2023 02:00 10/16/2023 02:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P Pull wear bushing. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 8/9 1R-07 Report Printed: 11/8/2023 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 10/16/2023 02:30 10/16/2023 03:00 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU WWWH P Jet BOP stack. 10/16/2023 03:00 10/16/2023 04:00 1.0 0 0.0 0.0 COMPZN, RPCOMP MIRU RURD P R/U tubing handling equipment. Verify joint count and jewelry running order. 10/16/2023 04:00 10/16/2023 04:30 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU SFTY P PJSM w/ SLB & rig crew on running 3 1/2" EUE-M completion. 10/16/2023 04:30 10/16/2023 05:00 0.5 0 0.0 236.0 COMPZN, RPCOMP MIRU PUTB P Run 3 1/2", 9.3#, L-80, EUE-M completion as per tally. Run-N-Seal dope used. EUE -M torque T/ 2250 Ft/lbs. T/ 326', 10/16/2023 05:00 10/16/2023 14:00 9.0 0 236.0 6,749.0 COMPZN, RPCOMP MIRU PUTB P Continue making up Tubing to Jt 212, 6742'. PUW=95, SOW=80K. Pump online .5 BPM @ 75 PSI. RIH see pressure spike @ 6743. S/d Pump 215 PSI. Set down 75K @ 6750. Pull up to PUW. 6749. Repeat to confirm marks. Lay down Jt 212,211, & 210. Space out = 4.68. Space out jt 4.1' swapping jt 210 for 212. Spaced out 4.53' Used Jt 212. 10/16/2023 14:00 10/16/2023 14:45 0.7 5 6,749.0 6,716.0 COMPZN, RPCOMP MIRU CRIH P Displace backside to CI 10.3 brine 10/16/2023 14:45 10/16/2023 15:15 0.5 0 6,716.0 6,747.0 COMPZN, RPCOMP MIRU THGR P Pumped 150 BBl's CI down backside. Drain stack, Kelly down to land hanger 10/16/2023 15:15 10/16/2023 16:30 1.2 5 6,747.0 6,747.0 COMPZN, RPCOMP MIRU THGR P Rig up manifolds / sensator for testing on floor and cellar, bleed off air, Low pressure test on seals - Good 10/16/2023 16:30 10/16/2023 16:45 0.2 5 6,747.0 6,747.0 COMPZN, RPCOMP MIRU OTHR P Break off hardline, Drop ball and rod, Let ball and rod fall. 10/16/2023 16:45 10/16/2023 17:15 0.5 0 6,747.0 6,747.0 COMPZN, RPCOMP MIRU PACK P Pressure up to 3800 PSI, test and chart tubing for 30 minutes 10/16/2023 17:15 10/16/2023 18:00 0.7 5 6,747.0 6,747.0 COMPZN, RPCOMP MIRU PRTS P Bleed tubing to 1500 PSI, Pressure up IA to 2500 PSI for 30 minutes - Good test 10/16/2023 18:00 10/16/2023 18:30 0.5 0 6,747.0 6,747.0 COMPZN, RPCOMP MIRU OTHR P Pressure IA up to 2800. Line up tubing to Blooie line. dump tubing to TT. See SOV shear at 1800 PSI 10/16/2023 18:30 10/16/2023 19:15 0.7 5 6,747.0 6,747.0 COMPZN, RPCOMP MIRU RURD P Rig down pumping / testing hardware 10/16/2023 19:15 10/16/2023 19:45 0.5 0 0.0 0.0 COMPZN, RPCOMP MIRU MPSP P Lay down landing joint, Set Type H, BPV, PT 1000 PSI for 10 minutes 10/16/2023 19:45 10/16/2023 20:45 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU RURD P B/D, R/D testing equipment. 10/16/2023 20:45 10/17/2023 00:00 3.2 5 0.0 0.0 COMPZN, WHDBOP MIRU NUND P PJSM, Nipple down BOP stack Remove flow riser. R/D choke & kill lines. 10/17/2023 00:00 10/17/2023 01:00 1.0 0 0.0 0.0 COMPZN, WHDBOP MIRU NUND P N/D BOP, rack back on pedestal. N//D DSA. 10/17/2023 01:00 10/17/2023 03:45 2.7 5 0.0 0.0 COMPZN, WHDBOP MIRU NUND P Install tree test dart. Nipple up adaptor spool and new tree. 10/17/2023 03:45 10/17/2023 04:00 0.2 5 0.0 COMPZN, WHDBOP MIRU PRTS P FMC PT tubing hanger void T/ 5000 PSI for 15 Min. 10/17/2023 04:00 10/17/2023 04:30 0.5 0 COMPZN, WHDBOP MIRU RURD P R/U testing equipment to tree 10/17/2023 04:30 10/17/2023 05:00 0.5 0 COMPZN, WHDBOP MIRU PRTS P PT tree T/ 5000 PSI for 5 Min. 10/17/2023 05:00 10/17/2023 05:30 0.5 0 COMPZN, WHDBOP MIRU RURD P B/D, R/D testing equipment. 10/17/2023 05:30 10/17/2023 06:00 0.5 0 COMPZN, WHDBOP MIRU MPSP P Pull tree test dart & HP BPV. 10/17/2023 06:00 10/17/2023 07:45 1.7 5 COMPZN, WHDBOP MIRU RURD P R/U LRS, & squeeze manifold. 10/17/2023 07:45 10/17/2023 08:15 0.5 0 COMPZN, WHDBOP MIRU PRTS P PT manifold and tiger tank lines T/ 3000 PSI. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Page 9/9 1R-07 Report Printed: 11/8/2023 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 10/17/2023 08:15 10/17/2023 10:00 1.7 5 COMPZN, WHDBOP MIRU FRZP P LRS pump71 Bbls diesel down IA @ 2 BPM, ICP=800, FCP=1400. U-tube well for 1 Hr. 10/17/2023 10:00 10/17/2023 11:00 1.0 0 COMPZN, WHDBOP MIRU RURD P B/D, R/D squeeze manifold & tiger tank line. Secure tree. Final pressures T/IA/OA= 50/200/200 10/17/2023 11:00 10/17/2023 12:00 1.0 0 DEMOB, MOVE MIRU DMOB P Move auxiliary equipment away from well. R/D tiger tank line and tanks. Rig Name: NORDIC 3 Rig Accept : 10/7/2023 Rig Release : 10/17/2023 Well Name: 1R-07 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 6' of Rathole) 6,954.0 1R-07 6/26/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed post rig GLD, pull ball & rod, RHC. Pulled catcher & ca2 eq prong. 1R-07 10/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3/16/2004 WV5.3 Conversio n 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 38.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 37.0 2,873.0 2,804.7 45.50 K-55 BTC PRODUCTION 7 6.28 34.8 7,159.9 6,917.7 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.1 Set Depth 6,761.4 String Max No 3 1/2 Set Depth 6,523.3 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) 33.1 33.1 0.09 Hanger 6.980 3.5" x 7 1/16" FMC Tubing Hanger Gen 4. Control Line Port: PLUGGED FMC Gen4 2.920 2,325.6 2,259.9 7.32 Mandrel GAS LIFT 5.920 3.5" x 1.5" MMG, GLM SLB MMG 2.920 4,531.0 4,432.3 25.09 Mandrel GAS LIFT 5.908 3.5" x 1.5" MMG, GLM SLB MMG 2.920 6,424.7 6,191.0 11.29 Mandrel GAS LIFT 5.923 3.5" x 1.5" MMG, GLM SLB MMG 2.920 6,484.8 6,250.0 10.16 Packer 6.280 3.5" x 7" BluePack RH Max Vam Top SLB BluePac k 2.894 6,542.4 6,306.7 9.38 Nipple - X 4.500 3.5" x 2.813" X-Nipple HES X Nipple 2.813 6,594.9 6,358.6 8.76 Mandrel GAS LIFT 5.902 3.5" x 1.5" MMG, GLM SLB MMG 2.920 6,751.0 6,512.9 8.30 Locator 3.480 Baker locator 3.46" OD Baker Locator 2.380 6,752.0 6,514.0 8.30 Seal Assembly 3.240 Baker 80-32 Seal Assembly (2' From Fully Located) Baker 80-32 Seal Assembl y 2.380 Top (ftKB) 6,754.0 Set Depth 6,790.1 String Max No 2 7/8 Set Depth 6,551.7 Tubing Description Tubing Completion Lower Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RDMOD ID (in) 2.44 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) 6,754.0 6,516.0 8.30 PACKER 6.156 BAKER DB PACKER 3.250 6,757.7 6,519.6 8.29 SBE 3.500 BAKER SEAL BORE EXTENSION 3.000 6,777.9 6,539.6 8.27 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,789.4 6,551.0 8.26 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 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) 6,775.0 6,536.7 8.28 OTHER Baited 2.5" JD latched to 2.25" CA2 plug. 2.5" JDC (5/16" steel) 2-7/8 B-SUB (1.813 G F/N) OAL=26" 10/29/2023 0.000 6,777.0 6,538.7 8.27 PLUG Set 2.25" CA-2 Plug (28" OAL) Note: EQ prong was pulled 10/27/23 but plug isn't equalized. 2/21/2023 0.000 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) 2,325.6 2,259.9 7.32 1 GAS LIFT GLV RK 1 1/2 1,235.0 10/25/2023 SLB MMG 0.188 4,531.0 4,432.3 25.09 2 GAS LIFT GLV RK 1 1/2 1,225.0 10/25/2023 SLB MMG 0.188 6,424.7 6,191.0 11.29 3 GAS LIFT OV RK 1 1/2 0.0 10/25/2023 SLB MMG 0.188 6,594.9 6,358.6 8.76 4 PROD DMY RK 1 1/2 0.0 10/16/2023 SLB MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,677.0 6,703.0 6,439.8 6,465.5 C-1, UNIT B, 1R- 07 7/2/1985 12.0 IPERF 120° phasing, 5 " HJ II Csg Gun 6,846.0 6,855.0 6,607.0 6,615.9 A-4, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 6,862.0 6,889.0 6,622.8 6,649.5 A-3, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 6,941.0 6,948.0 6,701.0 6,707.9 A-2, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 1R-07, 11/8/2023 8:59:47 AM Vertical schematic (actual) PRODUCTION; 34.8-7,159.9 IPERF; 6,941.0-6,948.0 IPERF; 6,862.0-6,889.0 IPERF; 6,846.0-6,855.0 PLUG; 6,777.0 OTHER; 6,775.0 Seal Assembly; 6,752.0 PACKER; 6,754.0 IPERF; 6,677.0-6,703.0 Mandrel GAS LIFT; 6,594.9 Nipple - X; 6,542.4 Packer; 6,484.8 Mandrel GAS LIFT; 6,424.7 Mandrel GAS LIFT; 4,531.0 SURFACE; 37.0-2,873.0 Mandrel GAS LIFT; 2,325.6 CONDUCTOR; 38.0-110.0 Hanger; 33.1 KUP PROD KB-Grd (ft) 37.51 RR Date 6/6/1985 Other Elev 1R-07 ... TD Act Btm (ftKB) 7,182.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292133200 Wellbore Status PROD Max Angle & MD Incl (°) 26.50 MD (ftKB) 4,600.00 WELLNAME WELLBORE1R-07 Annotation Last WO: End Date 10/17/2023 H2S (ppm) 130 Date 11/7/2014 Comment SSSV: NIPPLE Certificate Of Completion Envelope Id: 78FEE1FC5E7643C4AA40CAF6EF4CF2D4 Status: Completed Subject: Here is your signed document: KRU 1R-07 10-404 (323-382).pdf Source Envelope: Document Pages: 11 Signatures: 1 Envelope Originator: Certificate Pages: 5 Initials: 0 Jonathan Coberly AutoNav: Disabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 600 N Dairy Ashford Rd Houston, TX 77079-1100 Jonathan.Coberly@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 11/8/2023 5:21:00 PM Holder: Jonathan Coberly Jonathan.Coberly@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Jonathan Coberly Jonathan.Coberly@conocophillips.com Security Level: Email, Account Authentication (None) Signature Adoption: Pre-selected Style Using IP Address: 138.32.8.5 Sent: 11/8/2023 5:22:51 PM Viewed: 11/8/2023 5:23:15 PM Signed: 11/8/2023 5:24:25 PM Freeform Signing Electronic Record and Signature Disclosure: Accepted: 10/21/2021 1:38:44 PM ID: 816074ce-6cf9-4a8e-a803-d7ca1a5695a7 In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Jenna Taylor Jenna.L.Taylor@conocophillips.com ConocoPhillips Security Level: Email, Account Authentication (None) Sent: 11/8/2023 5:24:26 PM Viewed: 11/8/2023 7:32:08 PM Electronic Record and Signature Disclosure: Accepted: 10/16/2023 5:54:47 PM ID: 67551fd2-158e-440c-8245-f971ef8ee62c Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 11/8/2023 5:22:51 PM Certified Delivered Security Checked 11/8/2023 5:23:15 PM Signing Complete Security Checked 11/8/2023 5:24:25 PM Completed Security Checked 11/8/2023 5:24:26 PM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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By selecting the check-box next to I agree to use electronic records and signatures, you confirm that: You can access and read this Electronic Record and Signature Disclosure; and You can print on paper this Electronic Record and Signature Disclosure, or save or send this Electronic Record and Disclosure to a location where you can print it, for future reference and access; and Until or unless you notify ConocoPhillips as described above, you consent to receive exclusively through electronic means all notices, disclosures, authorizations, acknowledgements, and other documents that are required to be provided or made available to you by ConocoPhillips during the course of your relationship with ConocoPhillips. 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): 7182'N/A 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 6677-6703' 6846-6855' 6862-6889' 6941-6948' 7125' 6440-6466' 6607-6616' 6623-6650' 6701-6708' 3-1/2" & 2-7/8" 7" 16" 10-3/4" 72' 2836' Perforation Depth MD (ft): MD 110' 2805' 110' 2873' 6918'7160' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6940' 6954' 6750' 2721 6777' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025635 185-072 P.O. Box 100360, Anchorage, AK 99510 50-029-21332-00-00 ConocoPhillips Alaska, Inc. KRU 1R-07 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 6542'MD/6306'TVD Packer: 6594'MD/6357'TVD Packer: 6754'MD/6516'TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 & J-55 6535' & 6790' 9/11/2023 Packer: Baker Retrieveable Packer: Baker FHL Packer: Baker DB SSSV: None 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 Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Staff RWO/CTD Engineer By Grace Christianson at 10:54 am, Jul 11, 2023 323-382 BOP test to 3000 psig Annular preventer test to 2500 psig MDG 7/17/2023 X 10-404 X VTL 07/17//2023 DSR-7/12/23JLC 7/17/2023 07/18/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:08:22 -05'00' RBDMS JSB 071823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 6, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Jonathan Coberly Staff RWO/CTD Engineer ConocoPhillips Alaska, Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1R-07 (PTD# 185-072). The 1R-07 was completed into the Kuparuk A and C sand intervals in 1985. The well is configured as an A and C sand selective producer. In 2012 tubing leaks were identified above the upper packer after a failed TIFL and well was shut in. It was worked over in 2013 to repair tubing leaks. A stacked packer completion was installed. In 2019 a tubing leak was identified above the upper most packer and subsequently patched to bring back online. In 2022 the well was SI for high water cut and a leak in the C sand portion of the selective was supected. The tubing patch was pulled and the selective tubing leak was confirmed and located in 2023. The well is currently shut in with a plug in the lower packer tubing tail waiting a rig workover to replace the upper selective down to the lower packer. If you have any questions or require any further information, please contact me at (907) 538-8398. In order to bring the well back online a rig workover is requested to repair the tubing and regain selectivity/isolation between the Kuparuk A & C sands. 1R-07 RWO Procedure Kuparuk Producer P&R Upper Selective PTD #185-072 Page 1 of 3 Remaining Pre-Rig Work 1. Pull BPI sleeve, if able 2. Cut tubing above and below blast rings in selective. 3. Remove GLV’s, Install DV’s, and leave bottom GLM open. 4. Test wellhead pack offs. 5. Prep well for rig ~48 to 96 hours before rig arrival confirm no gas in OA, IA, or Tubing. MIRU 1. MIRU Nordic #3 on 1R-07. (No BPV set in pre-rig due to internal risk assessment on N3.) 2. Circulate KWF. 3. 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. Weight up and circulate KWF if needed. 4. Set BPV and confirm as barrier, ND Tree, NU BOPE and test to 250/3,000 psig. Test annular 250/3,000 psig. Retrieve Upper Completion 5. Pull BPV, MU landing joint, and BOLDS. 6. Pull 3-1/2” tubing from PBR. a. If tubing fails to pull from PBR, RU E-line and cut tubing above PBR to fish as needed. RDMO E-line. Fish additional tubing section(s) as needed. b. If pre-rig IC-PO tests failed. During POOH with tubing: set storm packer or RBP, PT to verify barrier, ND BOPE, ND tree, Re-land the production casing on slips, cut excess, install pack offs, NU tubing head, NU BOPE, shell test BOPE. Engage storm packer/RBP, Close annular on DP, release storm packer/RBP, circulate out any packer gas as needed, release annular. Lay down any remaining free tubing. 7. TIH and fish stacked packer/poor boy overshot completion. TOOH. 8. TIH and fish tubing stub from PBR. TOOH. 9. TIH and fish upper selective packer. TOOH. 10. TIH and fish blast ring section of tubing. TOOH. 11. TIH and fish tubing stub to lower packer. TOOH. 12. TIH and cleanout through lower packer SBE. POOH. 13. RIH with new 3-1/2” upper selective completion tubing. Engage SBE and space out completion. 14. Circulate corrosion inhibitor. Land hanger. Pressure up to set the packer. Drop ball and rod if necessary. a. If seals into lower packer are unable to provide integrity, TOOH and add a packer in the completion tubing design between the C sand perforations and the lower packer. 15. PT the tubing to 3000 psig for 30 minutes on chart. 16. PT the IA to 2500 psig for 30 minutes on chart. ND BOP, NU Tree 17. Shear the SOV. Install BPV and PT. ND BOPE. NU tree. 18. Pull BPV, freeze protect well, and set BPV if necessary. 19. RDMO. Post-Rig Work 20. Pull BPV, if needed. 21. Pull DV’s & SOV. 22. Install GLD. 23. Cleanout above Catcher if needed. 24. Pull Catcher & CA-2 Plug. 1R-07 RWO Procedure Kuparuk Producer P&R Upper Selective PTD #185-072 Page 2 of 3 General Well info: Wellhead type/rating: FMC Gen III / 5K (Tubing Head Upper); 3K (Tubing Head Lower) Production Engineer: Adam Becia Reservoir Engineer: Jennifer McLeod Estimated Start Date: 9/11/2023 Workover Engineer: Jonathan Coberly (265-1013/ Jonathan.Coberly@conocophillips.com) Current Operations: This well is currently shut in for rig workover Well Type: Producer Scope of Work: Pull tubing and upper selective completion, cleanout, run new upper selective completion. MIT results: MITOA: Passed to 1800 psig on 2/28/2023 T-POT/T-PPPOT: Test pre-rig IC-POT/IC-PPPOT: Test pre-rig CMIT-TxIA: Passed to 2500 psig on 7/4/2019 Waivers: Waivered for IAxOA Communication MPSP: 2721 psi using 0.1 psi/ft gradient Static BHP: 3367 psi / 6700’ TVD measured on 4/26/2023 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross/ Pipe Rams / Mud Cross / DSA as needed 1R-07 RWO Procedure Kuparuk Producer P&R Upper Selective PTD #185-072 Page 3 of 3 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 6' of Rathole) 6,954.0 1R-07 6/26/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Patch, Set CA-2 plug and catcher 1R-07 2/21/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3/16/2004 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By WAIVERED WELL: IA x OA COMMUNICATION 3/16/2004 Admin 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 38.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 37.0 2,873.0 2,804.7 45.50 K-55 BTC PRODUCTION 7 6.28 34.8 7,159.9 6,917.7 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.1 Set Depth … 6,534.8 Set Depth … 6,299.2 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd 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) 33.1 33.1 0.09 HANGER 8.000 TUBING HANGER 3.500 545.5 544.8 7.10 NIPPLE 4.500 CAMCO DS LANDING NIPPLE 2.875 2,588.4 2,521.1 5.46 GAS LIFT 5.968 Camco MMG GLM w/ Dummy, RK Latch SN: 235AD10 (2588) CAMCO MMG 2.867 3,790.4 3,720.0 3.96 GAS LIFT 5.968 Camco MMG GLM w/ Dummy, RK Latch SN: 227AD10 (3790') CAMCO MMG 2.867 4,802.3 4,675.6 26.37 GAS LIFT 5.968 Camco MMG GLM w/ Dummy, RK Latch SN: 244AD10 (4802) CAMCO MMG 2.867 5,569.3 5,367.3 22.76 GAS LIFT 5.968 Camco MMG GLM w/ Dummy, RK Latch SN: 249AD10 ( 5570') CAMCO MMG 2.867 6,150.2 5,923.3 13.45 GAS LIFT 5.968 Camco MMG GLM w/ Dummy, RK Latch SN: 246AD10 ( 6150') CAMCO MMG 2.867 6,456.4 6,222.0 10.70 GAS LIFT 5.968 Camco MMG GLM w/ DCR-1 w/ RKP Latch SN: 234AD10 ( 6456') CAMCO MMG 2.867 6,512.1 6,276.8 9.74 LOCATOR 4.510 BAKER LOCATOR Locator 2.992 6,513.1 6,277.8 9.73 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY 80-40 PBR Seal Assembl y 2.990 Top (ftKB) 6,519.2 Set Depth … 6,567.5 Set Depth … 6,331.5 String Ma… 5.02 Tubing Description STACKED PACKER Wt (lb/ft) Grade Top Connection 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) 6,519.2 6,283.9 9.65 PBR 5.020 BAKER 80-40 PBR 2.990 6,541.8 6,306.1 9.39 PACKER 5.980 BAKER RETRIEVEABLE PACKER Baker FHL 2.910 6,553.3 6,317.5 9.25 NIPPLE 4.000 HES X NIPPLE 2.812" HES " X " 2.812 6,560.9 6,325.0 9.16 OVERSHOT 6.010 POOR BOY OVERSHOT DRESSED FOR 3.5" TBG Baker Poorboy tbg os 3.720 Top (ftKB) 6,562.9 Set Depth … 6,790.1 Set Depth … 6,551.6 String Ma… 4 1/2 Tubing Description TUBING Original 3.5"x2.875" Wt (lb/ft) 9.30 Grade J-55 Top Connection FL4S 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) 6,580.0 6,343.8 8.94 PBR 5.125 BAKER PBR 3.000 6,593.7 6,357.3 8.77 PACKER 6.078 BAKER FHL PACKER 3.000 6,668.7 6,431.6 8.46 BLAST RINGS 4.500 CARBIDE BLAST RINGS (2) 2.992 6,736.5 6,498.7 8.31 NIPPLE 4.540 AVA BPL LANDING NIPPLE 2.320 6,739.2 6,501.3 8.31 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 6,753.0 6,514.9 8.30 LOCATOR 3.500 BAKER LOCATOR SUB 2.441 6,754.0 6,515.9 8.30 PACKER 6.156 BAKER DB PACKER 3.250 6,757.6 6,519.5 8.29 SBE 3.500 BAKER SEAL BORE EXTENSION 3.000 6,777.9 6,539.5 8.27 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 6,789.4 6,551.0 8.26 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 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) 6,492.0 6,257.1 10.03 LEAK Leak at 6492' 4/10/2019 2.992 6,731.0 6,493.2 8.32 LEAK LEAK IDENTIFIED BY EL PPROF LOG AT 6731' RKB 1/14/2023 2.992 6,736.0 6,498.1 8.31 SLEEVE-BPI 2.75" BPI. 29" OAL 4/1/2019 2.310 6,771.5 6,533.3 8.28 CATCHER Set 2.25" Catcher on top of plug (67" OAL) 2/21/2023 0.000 6,777.0 6,538.7 8.27 PLUG Set 2.25" CA-2 Plug (28" OAL) 2/21/2023 0.000 1R-07, 2/22/2023 5:35:33 AM Vertical schematic (actual) PRODUCTION; 34.8-7,159.9 FLOAT SHOE; 7,158.3-7,159.9 FLOAT COLLAR; 7,070.0- 7,071.5 IPERF; 6,941.0-6,948.0 IPERF; 6,862.0-6,889.0 IPERF; 6,846.0-6,855.0 SOS; 6,789.4 NIPPLE; 6,777.9 PLUG; 6,777.0 CATCHER; 6,771.5 SBE; 6,757.6 PACKER; 6,754.0 LOCATOR; 6,753.0 NIPPLE; 6,736.5 SLEEVE-BPI; 6,736.0 LEAK; 6,731.0 IPERF; 6,677.0-6,703.0 PRODUCTION; 6,631.5 PACKER; 6,593.6 PBR; 6,580.0 OVERSHOT; 6,560.9 NIPPLE; 6,553.3 PACKER; 6,541.8 PBR; 6,519.2 SEAL ASSY; 6,513.1 LOCATOR; 6,512.1 LEAK; 6,492.0 GAS LIFT; 6,456.4 GAS LIFT; 6,150.2 GAS LIFT; 5,569.3 GAS LIFT; 4,802.3 GAS LIFT; 3,790.4 SURFACE; 37.0-2,873.0 FLOAT SHOE; 2,871.2-2,873.0 FLOAT COLLAR; 2,786.5- 2,788.2 GAS LIFT; 2,588.4 NIPPLE; 545.5 CONDUCTOR; 38.0-110.0 HANGER; 37.0-41.2 HANGER; 33.1 KUP PROD KB-Grd (ft) 37.51 RR Date 6/6/1985 Other Elev… 1R-07 ... TD Act Btm (ftKB) 7,182.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292133200 Wellbore Status PROD Max Angle & MD Incl (°) 26.50 MD (ftKB) 4,600.00 WELLNAME WELLBORE1R-07 Annotation Last WO: End Date 2/19/2013 H2S (ppm) 130 Date 11/7/2014 Comment SSSV: NIPPLE 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) 2,588.4 2,521.1 5.46 1 GAS LIFT GLV RK 1 1/2 1,270.0 3/9/2013 0.188 3,790.4 3,720.0 3.96 2 GAS LIFT GLV RK 1 1/2 1,255.0 3/9/2013 0.188 4,802.3 4,675.6 26.37 3 GAS LIFT GLV RK 1 1/2 1,240.0 3/7/2013 0.188 5,569.3 5,367.3 22.76 4 GAS LIFT GLV RK 1 1/2 1,226.0 3/5/2013 0.188 6,150.2 5,923.3 13.45 5 GAS LIFT GLV RK 1 1/2 1,211.0 7/4/2019 0.188 6,456.4 6,222.0 10.70 6 GAS LIFT OV RK 1 1/2 0.0 7/2/2013 0.188 6,631.5 6,394.8 8.59 7 PROD DMY BK-2 1 0.0 5/24/1991 Close d 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,677.0 6,703.0 6,439.8 6,465.5 C-1, UNIT B, 1R- 07 7/2/1985 12.0 IPERF 120° phasing, 5 " HJ II Csg Gun 6,846.0 6,855.0 6,607.0 6,615.9 A-4, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 6,862.0 6,889.0 6,622.8 6,649.5 A-3, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 6,941.0 6,948.0 6,701.0 6,707.9 A-2, 1R-07 7/2/1985 4.0 IPERF 90° phasing, 4" HJ II Csg Gun 1R-07, 2/22/2023 5:35:34 AM Vertical schematic (actual) PRODUCTION; 34.8-7,159.9 FLOAT SHOE; 7,158.3-7,159.9 FLOAT COLLAR; 7,070.0- 7,071.5 IPERF; 6,941.0-6,948.0 IPERF; 6,862.0-6,889.0 IPERF; 6,846.0-6,855.0 SOS; 6,789.4 NIPPLE; 6,777.9 PLUG; 6,777.0 CATCHER; 6,771.5 SBE; 6,757.6 PACKER; 6,754.0 LOCATOR; 6,753.0 NIPPLE; 6,736.5 SLEEVE-BPI; 6,736.0 LEAK; 6,731.0 IPERF; 6,677.0-6,703.0 PRODUCTION; 6,631.5 PACKER; 6,593.6 PBR; 6,580.0 OVERSHOT; 6,560.9 NIPPLE; 6,553.3 PACKER; 6,541.8 PBR; 6,519.2 SEAL ASSY; 6,513.1 LOCATOR; 6,512.1 LEAK; 6,492.0 GAS LIFT; 6,456.4 GAS LIFT; 6,150.2 GAS LIFT; 5,569.3 GAS LIFT; 4,802.3 GAS LIFT; 3,790.4 SURFACE; 37.0-2,873.0 FLOAT SHOE; 2,871.2-2,873.0 FLOAT COLLAR; 2,786.5- 2,788.2 GAS LIFT; 2,588.4 NIPPLE; 545.5 CONDUCTOR; 38.0-110.0 HANGER; 37.0-41.2 HANGER; 33.1 KUP PROD 1R-07 ... WELLNAME WELLBORE1R-07 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread Conductor 110 110 16"15.25"65 H-40 WELDED Surface 2873 2804 10-3/4"9.95"45.5 K-55 BTC Production 7160 6917 7"6.28"26 J-55 BTC Upper Tubing (Old)6754 6516 3-1/2"2.99"9.3 L-80 EUE 8RD Lower Tubing 6789 6551 2-7/8"2.44"6.5 J-55 EUE 8RD Upper Tubing (New)6754 6516 3-1/2"2.99"9.3 L-80 EUE-Mod 8RD Created by: Jonathan Coberly 7.6.2023 P&R Upper Selective 1R-07 Proposed RWO Completion PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE-Mod Tubing 3-1/2" x 2.813" 'X' Nipple 3-1/2" x 1-1/2" CAMCO Gas Lift Mandrels (xTBD) 3-1/2" x 7" SLB BluePack RH Max Cut-to-Release Packer (or similar) 3-1/2" x 2.813" 'X' Nipple 3-1/2" x 1-1/2" CAMCO Gas Lift Mandrel (w/ DV) 3-1/2" EUE (box) x 2-7/8" EUE-Mod (pin) Crossover 2-7/8" Baker 80-32 Locating Seal Assembly (10') REMAINING COMPLETION LEFT IN HOLE 2-7/8" x 7" Baker 'DB' Permanent Packer Baker 'SBE' (3.25" ID) 4" ACME x 2-7/8" EUE 8RD Crossover 2-7/8" x 2.25" CAMCO 'D' Nipple Surface Casing Production Casing Conductor A-sand perfs 6846' - 6855' RKB 6862' - 6889' RKB 6941' - 6948' RKB C-sand Perfs 6677' - 6703' RKB D X FILL 6954' RKB 6/26/2022 X 18FE, 072 31127 WELL LOG TRANSMITTAL #905797925 To: Alaska Oil and Gas Conservation Comm. August 21, 2019 Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1R-07 Run Date: 7/3/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@hAiburton.com 1R-07 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-029-21332-00 AUG 2 7 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: 2 6 % Signed: STATE OF ALASKA a °° Ry *"n ALASKA OIL AND GAS CONSERVATION COMMISSION C �i REPORT OF SUNDRY WELL OPERATIONS JUL In �n1n 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 11 Operation% sllbTditn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change P,parrd p gym ❑ Plug for Redrill El'erforate New Pool ❑ Repair Well LDRe-enterSusp Well El�. tch 2 2. Operator Well Class Before Work: 5. Permit to Drill Number: CPhilll S Alaska, Inc.4. ConocoPhillips p Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 185-072 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21332-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1R-07 ADL0025635 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Poo fs): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,182 feet Plugs measured None feet true vertical 6,940 feet Junk measured None feet Effective Depth measured 6,990 feet Packer measured 6519, 6594, 6754 feet true vertical 6,750 feet true vertical 6284, 6357, 6516 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 feet 16 110' MD 110' TVD SURFACE 2,836 feet 10 3/4 " 2,873' MD 2,805' TVD PRODUCTION 7,125 feet 7 7,160' MD 6,918 TVD Perferation depth Measured depth 6677-6703,6846-6855,6862-6889,6941-6948 feet True Vertical depth 6440-6466,6607-6616,6623-6650,6701-6708 feet Tubing (size, grade, measured and true vertical depth) 3.5" & 2.875 L-80 & J-55 6,789' MD 6,551' TVD Packers and SSSV (type, measured and true vertical depth) PBR - BAKER 80-40 PBR 6,519' MD 6,284' TVD PACKER - BAKER FHL PACKER 6,594' MD 6,357' TVD PACKER - BAKER DB PACKER 6,754' MD 6,516' TVD NIPPLE - CAMCO DS LANDING NIPPL 546' MD 546' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: N/A N/A N/A N/A N/A Subsequent to operation: I N/A N/A N/A N/A N/A 14. Attachments (required Per 20 AAC 25.070, 25.071, & 25283) 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 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 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: Dusty Freeborn/Jan Byrne Authorized Name: Dusty Freeborn Contact Email: N1617@conocophillips.com Authorized Title: lWell Integrity and Compliance Specialist Contact Phone: 907-659-7224 Authorized Signature: Date: 5 July 19 Form 10-404 Revised 4/20170 9 �'�BDe„5 �--/JUL 10 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 9, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 1 R-07 (PTD 185-072). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Date Event Summary 07/04/1 07/03/1 I R-07 DESCRIPTION OF WORK COMPLETED SUMMARY IDENTIFY TBG LEAK BETWEEN 6150'- 6169' RKB W/ HOLEFINDER. SET TEST TOOL IN P2P @ 5483' RKB. PULLED GLV @ 6150' RKB (SCALE IN NOSE CONE, CHECK APPEARS FUNCTIONAL) & REPLACED IN KIND. MITT TO 2500 (PASS) & CMIT TO 2500 (PASS). PULLED TEST TOOL. JOB MITT TO 2500. PRE T/1/0= 450/225/200, PSI UP W/ 1.5 BBLS. START= 2525/300/200, 15 MIN= 2475/300/200, 30 MIN= 2475/300/200 **PASS** LRS RU TO IA. CMIT IA x TBG TO 2500. PRE T/1/0= 2475/300/200, PSI UP W/ 1.5 BBLS START= 2700/2525/230, 15 MIN= 2700/2450/230, 30 MIN= 2675/2450/230, 45 MIN= 2675/2450/230 **PASS** BLEED BACK TBG AND IA. PUMPED 5 BBLS DSL DOWN IA. SET 2.725" P2P (#CPP35189) MID-ELEM @ 6503' RKB. CORRELATED TO HES LDL 10 -APR -2019. CMIT TO 2500 (PASS) W/ TEST TOOL SET IN P2P. SET 2.725" P2P (#CPP35083), SPACER PIPE, ANCHOR LATCH (#CPAL35110) MID-ELEM @ 6483' RKB. SET TEST TOOL IN UPPER P2P; MITT FAILED (IA TRACKING). IN PROGRESS. 11T to 2500 psi (TOOL TO SET IN P2P @ 6465' SLM (6503' RKB)) :E T/1/0= 375/200/180, PSI UP w/ 2.8 BBLS ART= 2500/2300/220, MIN= 2450/2250/220, MIN= 2425/2250/220 **PASS** 04/101191 PERFORM LDL: IDENTIFY TBG LEAK @ APPROX 6492' RKB, PERFORM UP / DOWN PASS OVER LEAK. STATION STOPS @ 6496'& 6486' RKB. CORRELATE TO TBG DETAIL 2/17/2013. READY FOR CALIPER. 02/2311911C POT Passed, MITOA Passed to 1800 psi, T POT Passed, SI TIFL Failed. KUP PROD WELLNAME 1R-07 ConocoPhillips Ji ' F Well Attributes Maz Angle & MD JTD Flela rvame w<IIMre APIN1M wellhore slama Alaska, Inc, KUPARUN RIVER UNIT 50 02 9 2 133200 PROD Comment H2S(ppm) Ba,e gnnolaXan Eno SSSV: NIPPLE 130 iW12014 -krpm1 2/1912013 L. nCl1'1 MD InKBI hot BmHnKBI fi.50 6,600.00 ],182.0 Bale NBGN(X) flq Release BHe 3751 616/1985 Last Tag AK All Wellbores Schem anno,anon Bcpm lrcNel EUC Izx,Mm By weubare Less Tag: SLR fi.590.0 11/1312015 lehalll 1R -0J Last Rev Reason ,4kk Nn ven lsope,aa„e iwlau,emmm laclval gnnaa,lan Ena Dale �zl Moa Hy weneore " RNUGER Sal ad NIPPLE, sss GASUFT2599.a SURFACE: 31.G3.9]3A� GAB UFT:&]ea.9 cAs uFTa.W23 cqs OFF', SSW.3 GAS LIFT: fir 1.c GAS OFr: 44tea PACKER: 6,{93.4 LSI Castro- BPACERPIPE.fiOBas PACNERIaWa6 LGCMDR:a5121 BEALAssI.Ssat BR:a31A3 PALKER:6,A,.a NIPPLE6.653.a TKSASHOT:6,5W.a PER, ease - EB]6,7360 PACKER:4sa6E PRGDucnox: a,aau IPERF: 68P.Ga.SNE 6LEEkSaPCSTING MPPLE:aTaae LOCATOR: e,7ssp PACKER, 6, M.0 SEE S7576 - NIPPLE 6777.9- TPes, .75h.a- IPERF;aNaGfi.A55a- IPERF', S.SUCa,&bA� PRODUCPGN: 31.6 .158.9 Rev R.I. Set BPI, SAI Patch "412019 lama, 1R-0] Notes: General & Safety Em role Anlotld- wHI6L< 1011412010 NOT E View SclmmdtiC w/ Alaska SChema0Cs.0 1R -C7 Casing Strings s« Bep,n nvBl wl/L<n ng o<a CC(i'to (rnl Top lrcKel se, BepIn IX1B' trcHe Imm Graea Wre CONDUCTOR 16 1525 38.0 110.0 110.0 65.00 H-60 EL ED -07 WELDED 1R-0] SURFACE 103/4 9.95 3].0 2,8]3.0 281)4] 45.50 K-55 BTC 1R-0]7�82111NCa;39U PRODUCTION 71 6.28 1 34,81 7,159.9 fi9llJ 26.00 J-55 BTC 1R-0/ Tubing Strings Proper Mas Nominal s«Wp11 s«.,,ft, Bl Des oo gni le lin) Top@RBI "NB) InNel As pMp Grade Top TM<ea weu Wre TUBING WO 312 2.99 33.16,534.8 6.299.2 9.30 L-80 FUEBrd mK7 STACKED -PACKER 5.02 2099 6,519.2 8567.5 6.331.5 lR-07 TUBING Original 4112 2.99 6.5629 6,790.1 61551.6 9.30 J-55 FL4S 113-07 3.5"x2.873" Completion Details TUP(TVB) Top mtl Nomlml TIP PtoN DUKE) ('1 Item Des aam Inorg Wellbore 33.1 33.1 0.09 HANGER TUBIN HANGER 3SW UAT7 545.5 544.8 7.10 NIPPLE CAMCO OS IANDING NIPPLE 2.875 IR -07 6,512.1 6,276.8 9.74 LOCATOR BAKER LOCATOR 2.992 iR-07 6513.1 6,277.8 9.73 SEAL ASSY BAKER 8B40 SEAL ASSEMBLY 2.990 1R47 6519.2 6,283.9 9.65 PBR BAKER 8D40 PBT 2.990 1R-07 6.541.8 6,306.1 9.39 PACKER BAKER RETRIEVEABLE PACKER 2.910 1R-07 6,553.3 6,317.5 9.25 NIPPLE HEIS X NIPPLE 2.812" 2.8121R-07 6,560.9 6,325.0 9.16 OVERSHOT POOR BOY OVERSHOT ORESSEOFOR TYTBG 3.720 113-07 85800 6,343.8 8.94 PER BAKER PER 3.000 1Ro7 6,593.7 6,357.3 877 PACKER BAKER FHL PACKER 3.000 1114rJ 6669.7 6,431.6 8.46 BLAST RINGS CARBIDE BI -AST RINGS (2) 2.992 1R-07 6.736.5 6,498.7 8.31 NIPPLE AVA BPL LANDING NIPPLE 2.320 iR47 67392 6501.3 8.31 x28]5 2.875 1-- CROSBAKER LO ATORng LOCATOR 6.]53.0 6,5149 8.30 LOCATOR BAKER LOCATOR SUB 2.441 1R-0] 6,]Sdq 8.5159 8.30 PACKER BAKER DB PACKER 3.2 1R -OJ 6,]576 6,519.5 8.29 SBE BAKE H SEAL BORE EXTENSION 3.000 113-07 6777.9 6,539.5 827 NIPPLE CAMCO D NIPPLE NO GO 2.250 lR-D7 6,789.4 5,551.0 826 SOS CAMCO SIICAR OUT SUB 2441 1R-07 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top WD) Top EtMg HIKE) Tap Incl D') Dez Com Run 0. ID (in) Welllnre 6,483.0 6,248.2 111.20 PACKER P2P Packer (CPP35083) wl Sparer Pipe and 7/312019 1.625 lR-07 Anchor Latch (CPAL35110). OAL 20' Max OD 2 ]25" 6.487.0 6.252.1 10.12 SPACER PIPE 15.5'0(21116-P-110SP3cer Pipe. 7432019 1.630 113-07 6.492.0 6.20.1 10.03 LEAK Leak as 6492 6/102019 2.992 1R-07 6,503.0 6267.9 9.84 PACKER P2P Pa6er(CPP35189) OAL 4' Max OD 71312019 1.625 1R-07 2.725 6 73606,498.1 831 SLEEVEBPI 2.75 BPI. 29 GAL 4/112019 2.310 i11-07 Liner Details Top pv0l Nommnl0 TIp GtKB1 (oKB) iop Incl l') I,em Des CIm pnl kk Is e 3].0 9.0 0.10 HANGER 9650 1H-01 38.0 'LLI 010 CONDUCTOR ""qn. Perforations & Slots Top(RKB) BtnUftNI Top nV01 (See) BesjNBI (Hee) IJn4d Zone W. shot Den hh «srll I Type Co. We"Wore 6.677.0 6703.4 6.439.8 6,465.5 C-CUNITB.IR- 07 7211985 12.0 (PERE 120 deg. phasing, 5"HJ II Call Gun 1R-07 6,846.0 6,855.0 6.607.0 6,615.9 A4 1R-07 ]1211985 4A IPERF 90 deg.phasing, 4 NJ II Csg Gun 1R-07 6,862.0 6.8890 6,622.8 6.649.5 M3,1R-0J A211g85 4.0 IPERF 90 deg. phasing, VHJ 11 Csg Gun 1R-07 6,941.0 6948.0 6,701.0 6707.9 A -21R-07 7211985 4.0 IPERF 90 deg. phasing, 4-HJII Cap Gun iR-07 Mandrel Inerts I $I ar Pox onTop(NB) VNve L«cb Blxe TRO Run Madel OD lin) Swv T p< Type (in) (psi] Run Do,e Cqn wellhore No }op(XKBI INN.)dCAMCO 1 2,588.4 2521.1 MUG 112 -GAS LIFT GLV RK BAN 1,270.0 31912013 1R-07 2 3,)90.4 3,720.0 MMG 1112 GASLIFT GLV RK 0.188 1,255.0 3192013 1R-07 3 4,8023 4,675.6 MMG 112 GAS LIFT GLV RK 0.188 1,240.0 3012013 iR-07 4 5,569.3 5.36].3 MMG 112 GASLIFT GLV RK 0.188 1,226.0 3152013 1R-07 5 6,150.2 5,923.3 MMG 112 GAS LIFT GLV RK 0.188 1,211.0 JM2019 1R-0] 6 6456.4 6,2220 MMG112 GASLIFT OV RK 0.188 0.0 ]/112013 1R-0]> 6631.5 6,394.8 KBUG 1 PROD WAY SK -2 0.000 0.0 52411991 Close 1R-0 a WELL LOG TRANSMITTAL #905622367 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1 R-07 Run Date: 4/10/2019 i 30 92 5 June 26, 2019 JUN 2 7 2019 rArOGM The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1R-07 Digital Data in LAS format, Digital Log file 50-029-21332-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: -ov i l Signed: Originated: Schlumberger PTS-PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician II . = Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 --,y Anchorage, AK 99501 1pj0?2 i TRANSMITTALDATE TRANSMITTAL# Schlumberger -Private Imag'~Project Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~~- _~ 7_~--- Well History File Identifier Organizing (done) RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [] Maps: [] Grayscale items: [] Other, No/Type c] Poor Quality Originals: [] Other: ~ NOTES: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: Is~ Scanning Preparation ~ x30= 9~~1 + /~ '- TOTALPAGES /~.~~ · BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Production Scanning Stage BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INOIVlDUAL PAGE BASIS DUE TO QUALrFY, GRAYSCAI..E OR COLOR IMAGES) PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES BEVERLY BREN VINCE~ MARIA LOWELL DATE://///0,~/~---j, IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO III IIIIIIIIIII II III RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon J Repair w ell Id Plug Perforations Il Perforate E Other E Alter Casing ("' Rill Tubing Stimulate - Frac I Waiver j Time Extension Chan Approved Program )EOperat. Shutdow n i Stimulate - Other Il Re -enter Suspended Well °" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Id Exploratory r f 185 -072 3. Address: 6. API Number: Stratigraphic 1 Service E P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21332 - 00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25635 ` 1R-07 •-• 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): -% none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7182 feet Plugs (measured) 6778' true vertical 6940 feet Junk (measured) none Effective Depth measured 7070 feet Packer (measured) 6542, 6594, 6754 true vertical 6828 feet (true vertical) 6306, 6357, 6516 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 2836 10.75 2873 2805' PRODUCTION 7125 7 7160 6918' IA lc. °,x,�' ', v 1 "," ' ...� M.L:\R 1 _. :1 Perforation depth: Measured depth: 6677 -6703, 6846 -6855, 6862 -6889, 6941 -6948 AOG CC True Vertical Depth: 6440 -6466, 6607 -6616, 6623 -6650, 6701 -6708 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 6535 MD, 6299 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER RETRIEVEABLE PACKER @ 6542 MD and 6306 TVD PACKER - BAKER FHL PACKER @ 6594 MD and 6357 TVD PACKER - BAKER DB PACKER @ 6754 MD and 6516 TVD SSSV - CAMCO DS NIPPLE @ 546 MD and 545 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable NEO APR 192D13 Treatment descriptions including volumes used and final pressure: SCAN 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development 14 ,. Service [ Stratigraphic E 16. Well Status after work: pOil f Gas I WDSPL E Daily Report of Well Operations XXX GSTOR f' WINJ r WAG 1 GINJ E SUSP E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jonathan Coberly a. 265 -1013 Email Jonathan .Coberlvaconocophillips.com Printed Name Jonatha Coberl Title Wells Engineer Signature Phone: 265 -1013 Date 3. / /.. Z 0/3 -Ckn Form 10 -404 Revised 10 /201RB - -D 1/1- Submit Original Only MS MAR 1 � �1 4 )12-113 9"- KUP 1R-07 ConocoPhillips 0 $ Well Attributes Max Angle & MD TO Pktska, h1C Wel lbore APWWI Field Name Well Status Ind (°) MD (ftKS) Act Btm (R613) 500292133200 KUPARUK RIVER UNIT PROD 26.50 4,600.00 7,182.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date "' SSSV: NIPPLE 75 9/4/2011 Last WO: 2/19/2013 37.51 6/6/1985 Well Canna, -1R-07, 2,22/2013 12'17:02 PM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,003.0 4/13/2012 Rev Reason: WORKOVER osborl 2/22/2013 HANGER, 33- Casing Strings I Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 38.0 110.0 110.0 65.00 H -40 WELDED Casing Description Strin 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thrd SURFACE 103/4 9.950 37.0 2,873.0 2,804.7 45.50 K -55 BTC Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I PRODUCTION 7 6.276 34.8 7,159.9 6,917.7 26.00 J -55 ETC -- Tubing Strings 1 ll Tubing Description String 0... String ID ... Top (RKB) Bet Depth (f... Set Depth (ND) ... String Wt... I L -8 String 0 I ... String Top Thrtl TUBING WO 31/2 I 2.992 I 33.1 I 6 I 6 9.30 EUESrd CONDUCTOR, Completion Details Top Depth 36-1 Or (ND) Top Ind Noml... NIPPLE. 545 41 Top (MB) (RKB) (1 Rem Description Comment ID (In) 33.1 33.1 0.25 HANGER TUBING HANGER 3.500 , . 545.5 544.7 7.10 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,512.1 6,276.8 9.74 LOCATOR BAKER LOCATOR 2.992 GAS LIFT, 2,588 - 6,513.1 6,277.8 9.73 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd O Stacked packer I 5.02 I 2.990 I 6,519.2 I 6,567.5 6,331.5 - Completion Details 1 Top Depth SURFACE, / (ND) Top Intl Noml... 37 -2,873 Top (RKB) (RKB) (°) Rem Description Comment ID (in) 6,519.2 6,283.9 9.65 PBR BAKER 80-40 PBR 2.990 GAS LIFT, 6,541.8 6,3062 9.39 PACKER BAKER RETRIEVEABLE PACKER 2.910 3,790 IIIIF 6,553.3 6,317.5 9.25 NIPPLE HES X NIPPLE 2.817 w/RHC PLUG 2.812 MK 6,560.9 6,325.0 9.16 OVERSHOT POOR BOY OVERSHOT DRESSED FOR 3.5" TBG 3.720 if GAS LIFT, I: Tubing Description String 0... String ID ... Top ( RKB) Set Depth (f... Set Depth (ND)... String Wt... String... String Top Thrd 4802 - TUBING Original 4 1/2 2.992 6,562.9 6,790.1 6,551.6 9.30 J -55 FL4S MIL 3.5 "x2.875" OIL Completion Details G Top Depth AS s. so, LIFT - (TVD) Top Inc! Nomi... Top (RKB) (RKB) ( °) Item Description Comment ID (in) - 6,580.0 6,343.8 8.94 PBR BAKER PBR 3.000 6,593.7 6,357.3 8.77 PACKER BAKER FHL PACKER 3.000 GAS LIFT e / so - i 6,668.7 6,431.6 8.38 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 _ 6,736.5 6,498.7 8.31 NIPPLE AVA BPL LANDING NIPPLE 2.320 6,739.2 6,501.3 8.31 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS 61456 - 6,753.0 6,515.0 8.30 LOCATOR BAKER LOCATOR SUB 2.441 6,754.0 6,515.9 8.30 PACKER BAKER DB PACKER 3.250 IIIN 6,757.6 6,519.6 8.29 SBE BAKER SEAL BORE EXTENSION 3.000 NM LOCATOR. 6,777.9 6,539.5 8.27 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,512 SEAL ASSY. 6,789.4 6,551.0 8.26 SOS CAMCO SHEAR OUT SUB 2.441 6,513". - - -_ -_- - PM. 6.519 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth PACKER, 6,542 _ (ND) Top Ind Top (RKB) OM) ( °) Description Comment Run Date ID (In) NIPPLE, 6.553 iI, ' 6,736.5 6,498.6 8.31 SLEEVE -C 2.75" AVA BPI - 2.79" NO GO, 29' OAL - CLOSED 1/24/2013 2.313 1/24/2013 II 1 6,776.8 6,538.5 8.27 CATCHER 2.27 CATCHER SUB ON TOP OF PLUG 1/20/2013 0.000 OVERSHOT, 6,.561 6,777.8 6,539.5 8.27 PLUG 2.25 CA -2 PLUG (2.29" NO GO) 1/20/2013 0.000 I Perf 8 Slots PBR, 8,580 Shot Top(ND) Btm (TVD) Dens PACKER. 6.594 Top (RKB) Bi (RKB) ( (RKB) Zone Date (6t ,, Type Comme 6 6, 703.0 6, 6,465.5 C-1, UNIT B, 7/2/1985 12.0 IPERF 120 deg. phasing, 5" HJ II Csg Gun PRODUCTION. 1R -07 6,632 6,846.0 6,855.0 6, 607.0 6,615.9 A-4, 1R -07 7/2/1985 4.0 IPERF 90 deg. phasing, 4W II Csg Gun IPERF, t 6,862.0 6,889.0 6,622.8 6,649.5 A-3, 1R -07 7/2/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun 8,8778,703 - .._.1.i 6,941.0 6,948.0 6,701.0 6,707.9 A -2, 1R -07 7/2/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun SLEEVE-C. �� Notes: General & Safety NIPPLE. 6.737 N - 1 1 1 _ - End Date - Annotaton _ - -- 3/16/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 10/14/2010 NOTE: View Schematic w/ Alaska Schemalc9.0 LOCATOR. - 6,753 PACKER. 6754 SBE, 6,758 R+� CATCHER. 6,777 I, to_ I PLUG, 6,778- Mandrel Details NIPPLE, 6,778 t'�'!' ' Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run SOS, 6,789 { �-1 N... Top (RKB) (RKB) I Make Model (in) Sew Type Type (in) (psi) Run Date Corn... 1 2,588.4 2,521.1 5.46 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/172013 2 3,790.4 3,720.0 3.96 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/17/2013 IPERF, 3 4,802.3 4,675.7 26.39 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/172013 68488,855 4 5,569.3 5,367.4 22.76 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/17/2013 IPERF, 5 6,150.2 5,923.3 13.45 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/17/2013 6.662.0. 99 6 6,456.4 6,222.0 10.39 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 2/17/2013 DCR -1 8,9418, IPERF, _ I EI 7' 6,631.5 6,394.8 8.42 CAMCO KBUG 1 PROD DMY 'BK -2 0.000 0.0 5/24/1991 Closed 948 �! PRODUCTION. 357,180 TD, 7,182 + � ConocoPhillips Time Log & Summary Wetlwew Web Reporting Report Well Name: 1R-07 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 2/13/2013 5:00:00 PM Rig Release: 2/17/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/12/2013 24 hr Summary Move rig f/ 3K pad t/ 1 R -07, Move camp t/ 1R pad, Move rig complexes t/ 1R pad 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move Camp t/ 1R pad, Release Rig, blow down steam & H2O, split complexes & pipe sheds, move complexes & rockwasher t/ 1 R. 02/13/2013 Move sub & pipe sheds t/ 1R pad, spot sub over well, lay mats & spot pits motors & boiler complexes, lay mats & spot pipe sheds, work on rig acceptance, Rig accepted @ 1700 hrs, Rig up hard lines to well & tiger tank. Rig up to 'Dull BPV 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Move Sub off 3K -105. 02:00 05:30 3.50 0 0 MIRU MOVE MOB P Mob. pipe sheds & sub t/ 1R pad 05:30 07:00 1.50 0 0 MIRU MOVE MOB P Spot sub over well. 07:00 12:15 5.25 0 0 MIRU MOVE MOB P Lay mats and set pits motors & boiler complexes, lay mats f/ pipesheds 12:15 14:00 1.75 0 0 MIRU MOVE MOB P Spot & level pipesheds. 14:00 17:00 3.00 0 0 MIRU MOVE MOB P Work on rig acceptance check list rig accepted @ 1700 hrs ) 17:00 18:00 1.00 0 0 MIRU MOVE MOB P Take on 595 bbls of 8.6 ppg sea water t/ pits, hook up hard lines & double valves in cellar. 18:00 22:00 4.00 0 0 MIRU MOVE RURD P Rig up hard line to tiger tank. 22:00 23:00 1.00 0 0 MIRU MOVE RURD P Rig up scaffolding in cellar. SIMOPS, blow air through hard line, discovered ice plud in hard line. Cleared ice plug out of hard line. 23:00 00:00 1.00 0 0 MIRU WHDBO OTHR P PJSM, attempt to pull BPV, discovered 24 ppm H2S. Shut down. Locate bleed tank and rig up. 02/14/2013 Displace well to 8.6 ppg seawater and OWFF, slight flow. Rig up and circulate well. Tested down hole plug to 1500 psi, good. OWFF, static. Set BPV and nipple down tree. Install blanking plug and nipple up BOPE. Test BOPE to 250/3500 psi. Chuck Scheve of AOGCC waived witness if the test. 00:00 01:45 1.75 0 0 COMPZ WELCTI OTHR P Bleed off wellhead H2S gas t/ bleed tank. 01:45 02:30 0.75 0 0 COMPZ WHDBO OTHR P R/U & test FMC lubricator t/ 500 psi, cull BPV 200 psi on tubing, 0 on IA, shut in bleed off pressure, R/D Lubricator. 02:30 02:45 0.25 0 0 COMPZ WELCTI SFTY P Pre Job Safety Meeting on displacing freeze protect. 02:45 04:45 2.00 0 0 COMPZ WELCTL CIRC P Displace well to 8.6 pea seawater IeD 126 gpm holding back pressure on well following a pressure schedule FCP -527 psi, 270 bbls pumped. Page 1 of 5 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode _ T Comment 04:45 05:15 0.50 0 0 COMPZ WELCTL OWFF P Observe well f/ flow static. 05:15 06:00 0.75 0 0 MIRU WELCTL OTHR P Attempt U remove tree cap, observe pressure building below cap, bleed pressure to bleed tank pressure not bleeding off. 06:00 07:15 1.25 0 0 MIRU WELCTL CIRC P Circulate surface to surface down tubing Lakin _returns u IA @210 gpm 1475 psi. No gas or oil observed @ bottoms up. 07:15 07:45 0.50 0 0 MIRU WELCTL OWFF P Observe well f/ flow slight flow 07:45 08:15 0.50 0 0 MIRU WELCTLCIRC P Circulate bottoms up 210 gpm 1475 psi 08:15 09:00 0.75 0 0 MIRU WELCTL OWFF P Observe well f/ flow slight flow observed rate slowing down. 09:00 09:30 0.50 0 0 MIRU WELCTL PRTS P Pressure test tubing & ann t/ 1500 psi to verify down hole plug holding, test good. 09:30 11:00 1.50 0 0 MIRU WELCTL OWFF P Observe well for flow slight flow slowing to static. 11:00 12:00 1.00 0 0 MIRU WHDBOOWFF P Blow down lines and bled pressure of tree. Removed tree cap, OWFF, static. 12:00 14:00 2.00 0 0 MIRU WHDBO NUND P PJSM, Nipple down tree and install blanking plug. Inspect threads on hanger, good. 14:00 15:00 1.00 0 0 MIRU WHDBO RURD P Rig down scaffolding and circulating lines. Clean and clear work area. 15:00 17:00 2.00 0 0 MIRU WHDBO NUND P PJSM, Nipple up adapter flange and BOPE. 17:00 18:00 1.00 0 0 MIRU WHDBO NUND P Install riser and turn buckles. 18:00 19:00 1.00 0 0 MIRU WHDBO BOPE P PJSM, Rig up to test BOPE. 19:00 00:00 5.00 0 0 MIRU WHDBO BOPE P _Test BOPE to 250/35 PSI for 5 min. each, record on chart. Test #1: Top pipe rams, CV 1,12,13,14 & manul kill. Test #2: Upper IBOP, HCR kill, CV 9 &11. Test #3: Lower IBOP CV 5, 8 & 10. Test #4: Dart valve, CV 4,6 & 7. Test #5: Floor valve & CV 2. Test #6: HCR choke & Kill line demco. Test #7: Manual choke & HCR kill. Test #8: Annular preventer. Test #9: Blind rams & CV 3. System pressure= 3000 psi, pressure after closing= 1700 psi., 200 psi attained after 54 sec., full pressure attained after 227 sec. Nitrogen bottle average= 2000 psi. Witness of BOP test waived by AOGCC inspector Chuck Scheve. Note: Lower pipe rams will be tested after tubing is laid down due to blanking plug, verified by AOGCC via E -mail. Page 2 of 5 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/15/2013 24 hr Summary R/D BOP test equip, Attempt to pull on tubing, unable to break over, work string no go, R/U E -line RIH w/ string stot, & RCT cutter cut tubing @ 6561' R/D E -line Latch on to tubing and Pull to rig floor, Circ bottoms up Flow check well Static, R/U & Pull 3 -1/2" tubing completion. 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE P Pull test plug, drain stack, blow down lines. 01:00 02:00 1.00 0 0 MIRU WHDBOOTHR P Pull TWC 02:00 02:45 0.75 0 0 COMPZ RPCOM RURD P R/U t/ pull tubing. 02:45 03:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on pulling tubing. 03:00 03:15 0.25 0 0 COMPZ RPCOM OTHR P M/U top drive t/ X -Over and 1 jt. of tubing. 03:15 03:45 0.50 0 0 COMPZ RPCOM PULL P Attempt t/ pull hanger PUW 120 - 135 k work string several time no change. 03:45 08:00 4.25 0 0 COMPZ RPEQP1 ELNE P Wait on wireline unit, simops service rig, P/U subs, work orders, clean pits, R/U power tongs, break down landing jt. space out w/ pups w/ 30 k tension. 08:00 10:15 2.25 0 0 COMPZ RPEQPI ELNE P Spot wireline truck R/U tools & dress packoff. 10:15 10:30 0.25 0 0 COMPZ RPEQP1ELNE P Pre Job Safety Meeting on R/U E -line 10:30 11:15 0.75 0 0 COMPZ RPEQP1ELNE P R/U E -line string shot, M/U tool string. 11:15 13:30 2.25 0 0 COMPZ RPEQP1ELNE P _RIH w/ string shot corelate fire shot @ 6559', POOH UD tool string confirm shot. - 13:30 17:30 4.00 0 0 COMPZ RPEQP1ELNE P C/O tools M/U RCT cutter RIH w/ RCT tool t/ 6640' corelate depth make cut @ 6561', release anchors attempt t/ POOH take wt, work string unable to fire jars no progress w/ working string, Decision made t/ pull out of rope socket, pull up t/ 49001 bs wire line tension, string came free CCL locator working tools appear to be intact. POOH 17:30 18:30 1.00 0 0 COMPZ RPEQP1 ELNE P R/D tool string evidence of cut, anchors failed to release. Slag on tools, anchors possibly became welded to tubing. R/D HES E -Line 18:30 19:00 0.50 0 6,561 COMPZ RPCOM PULL P R/U & pull on tubing pull up to 100K tool string br over PUW - 95k pull han er t/ floor R/U t/ circ bottoms up. 19:00 20:15 1.25 6,561 6,561 COMPZ RPCOM CIRC P Circ. bottoms up X 2, 210 gpm 600 psi. Dumped dirty sea water returns to rock washer. 20:15 20:45 0.50 6,561 6,561 COMPZ RPCOM OWFF P Monitor well, static. Hold PJSM for laying down tubing. 20:45 21:15 0.50 6,561 6,502 COMPZ RPCOM THGR P Lay down landing joint and tubing hanger. 21:15 23:15 2.00 6,502 4,693 COMPZ RPCOM PULL P Lay down 3 -1/2" tubing, 1 pup, 60 joints and SSSV with 34 SS bands, 1867'. Page 3 of 5 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 23:15 00:00 0.75 4,693 4,693 COMPZ RPCOM RURD P Rig down SLB control line spooler and tools. 02/16/2013 Pull 3.5 completion UD, R/U and test lower rams t/ 250 low 3500 high, Run 3.5 Completion. Tag tubing stub , Displace well t/ corr Inhib. brine, space out drop ball & rod set packer Space out & land hanger 6.18' from fully located. R/U & test tubing t/ 3000 psi & ann. t/ 3500 psi Shear SOV. 00:00 05:00 5.00 4,963 0 COMPZ RPCOM PULL P UD 3.5 tubing 208 jts 8 glms, cut jt. 17.8' Correct 0611TE 05:00 06:00 1.00 0 0 COMPZ RPCOM RURD P R/D tubing equipment, clear floor. 06:00 07:00 1.00 0 0 COMPZ RPCOM BOPE P R/U test equipment, test lower rams 2 7/8 x 5" pipe rams w/ 3.5 test jt 250 low 3500 high. 07:00 09:00 2.00 0 0 COMPZ RPCOM RURD P R/U tubing equipment. 09:00 17:45 8.75 0 6,530 COMPZ RPCOM RCST P RIH w/ 3.5 completion string t/ 6530' Correct hole fill. 17:45 18:45 1.00 6,530 6,550 COMPZ RPCOM RURD P R/U Circulating equipment, RIH and tag up on tubing stub @ 6562.93', set 10K down wt on it P/U soft tag w/ 5K P/U t/ 6550' 18:45 20:15 1.50 6,550 6,550 COMPZ RPCOM CIRC P Displace well w/ 230 bbis of 8.6 ppg Inhibited Seawater. 126 gpm, 200 psi. 20:15 20:45 0.50 6,550 6,568 COMPZ RPCOM PACK P Break Connection drop ball & rod slack off engage overshot tubing stub, until fully located P/U 1' pressure up t/ 3500 psi on tubing set FHL and shear packer and hold pressure for 10 min. 20:45 22:00 1.25 6,568 6,519 COMPZ RPCOM HOSO P Tag PBR @ 6519' UD 3 jts. M/U space out pups a jt. of tubing & hanger land on hanger @ leaving 6.18' space out f/ fully Iocated.RILDS 22:00 22:30 0.50 6,519 6,519 COMPZ RPCOM RURD P R/U t/ pressure test tubing & ann. 22:30 23:30 1.00 6,519 6,519 COMPZ RPCOM PRTS P Test tubing U 3000 psi f/ 15 min. bleed off tubing t/ 2500 hold pressure on tubing pressure up on ann. to 3500 hold pressure f/ 30 min. bleed tubing off observe SOV shear. 23:30 00:00 0.50 6,519 6,519 COMPZ RPCOM RURD P Pull landing jt set BPV 02/17/2013 Set BPV test in direction of flow t/ 1000 psi, N/D BOP, nipple up & test tree, freeze protect well w/ 78 bbis diesel, allow t/ u -tube, set BPV test in direction of flow t/ 1000 psi secrure well head, rig released @ 1200 Hrs. 00:00 00:30 0.50 6,519 0 COMPZ RPCOM OTHR P Blow down lines suck out stack 00:30 01:30 1.00 0 0 COMPZ WHDBO OTHR P Set BPV test f/ direction of flow t/ 1000 psi, blow down lines 01:30 04:15 2.75 0 0 COMPZ WHDBO BOPE P N/D BOP's, N/U adaptor flange & tree, test adaptor flange void 250 low 5000 high f/ 10 min. 04:15 05:45 1.50 0 0 COMPZ WHDBO BOPE P Set tree test plug, test tree t/ 250 low 5000 high, pull test plug, & BPV. 05:45 06:15 0.50 0 0 COMPZ WHDBO RURD P R/U hard lines t/ circ. freeze protect Page 4of5 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 06:15 08:00 1.75 0 0 COMPZ WHDBO FRZP P Test lines t/ 2000 psi w/ little red, Freeze protect well w/ 78 bbls of diesel 08:00 09:00 1.00 0 0 COMPZ WHDBO FRZP P Allow well t/ u -tube, simops rig down scafolding in cellar. 09:00 11:00 2.00 0 0 COMPZ WHDBO PRTS P R/U Lubricator, test t/ 1000 psi f/ 10 min. Empty pits. 11:00 12:00 1.00 0 0 COMPZ WHDBO RURD P R/D little red, Blow down lines. Release rig @ 1200 Hrs Page 5 of 5 l`6b 072 WELL LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1R -07 Run Date: 9/26/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -07 • Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21332 -00 SCANNED APR 2 3 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com 411 Date: L) H ( Signed: f 'IJG, 64,t/p7 110 • r-05- 07 a - ZA2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: 1R-07 Run Date: 8/25/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -07 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21332 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood SCANNED APR 2 3 2013' 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Vlscll2 Signed: AL-4,- 621-4 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 1R-07 Run Date: 5/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -07 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21332 -00 SCANNED APR 2 3 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: .1 J 1 f 1 Z, Signed: • C65-072, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1R-07 Run Date: 5/8/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21332 -00 SCANNED APR 2 3 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OR-- •-- -- Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1'6/2_ Signed: y,� C~ Con ~ " ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • . I ~EP 0 2 2009 Al~~k~ Q~I ~ f~s C~ns, Commission A~~~o~ I `~'s ~ ~ a' ~~'o`~ ~ -~ . ~.'~" ~. ~ ~~ , '~~1~ ~,. . ,- -_ . Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~` and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;h and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ~ • ~ • ~~'T,~t~ ~~`~~ `lLl ~~ , l.=J... ° ~. _ .. t ~ .a ~+ ~,. • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8I29-09 1R PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 R-01 B 50029214040200 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8l27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' 5.00 24" 8l15/2009 4 8/28/2009 1 R-08 50029213330000 1850730 8' 1.00 21" S115/2009 13.7 8128i2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' S.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8l15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28J2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029229880000 1910870 9'4" 120 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8l1512009 5.1 8127i2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28l2009 1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 ~~~~~~~~ NO. 4914 <~~,r c_. c" Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # a~ a ~° ~ 5 n, F. n r 'r~; ~ <; ~'vvv ~a.+wu W .~ ~ ..~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 - 12097405 SBHP SURVEY 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /[- p p C 09/10/08 1 1 3G-25X 12080437 LDL ~ - '3 L/(o 09!21/08 1 1 2C-04 12100444 INJECTION PROFILE G C / 09/14/08 1 1 3M-13 12096541 LDL - C7L( ( b4 09/10/08 1 1 2Z-13A 12100446 LDL aQ(o- ( O ~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - ~ 5''~l 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE 't p 09/20/08 1 1 30-15 12100452 LDL - ~ SQ 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE c ~ 09/23/08 1 1 i R-i 1 11966277 SBHP SURVEY '- V 09/25/08 1 1 1R-35 11966279 SBHP SURVEY ~ _ p 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 1R-34 12080444 _ GLS G _ 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE ~~C/ 10/02/08 1 1 1D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~""': ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L/ 10/03/08 1 1 1B-16 12097426 GLS ~ - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE - 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE (~ 10/07/08 1 1 iB-04 12096552 INJECTION PROFILE ~ ~ 10!08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 16-16 12096554 PRODUCTION PROFILE G~C~ .~ G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ~'~~ :~ 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 R-07 (PTD 1850720) Report of failed TIFL Page 1 of 1 Re , James B DOA ~ • g9 ~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, April 20, 2008 5:04 PM ;~~~ ,~~2/^ 3 To: Maunder, Thomas E (DOA); Regg, James B (DOA) `\ Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1 R-07 (PTD 1850720~Report of failed TIFL Attachments: 1 R-07 schematic.pdf; 1 R-07 90 day TIO plot.jpg Tom & Jim, Kuparuk gas lifted producer 1 R-07 (PTD 1850720) failed a diagnostic TIFL on 04/19/08 and has been added to the weekly SCP report. The TIO prior to the test was 180/900/860. A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. «1R-07 schematic.pdf» «1R-07 90 day TIO plot.jpg» ~. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~N~ MAY ~ ~ 2008 5/2/2008 KRU 1 R-07 PTD 185-072 .-..~.~ ~ inn innnn • • f~' Cor~aca~'hillips Alas~Ca, tnc. - -_ - --_ 1 R-07 SSSV (1913-1914, ~_=.' OD:3.500) - ~: PBR (s5aass8l, OD:3.500) PKR (659a-65ss, 00:6.156) SLEEVE-0 (6737-6738, OD:2.750) PKR (6754-6755, OD:6.156) NIP (6778-6779, OD:2.875) ~. - _ . i , ~[ , 1 j~i ~ .! ' 1 i i KRU 1 R-07 API: 500292133200 Well T e: PRUD An fe TS: 9 d m 4623 SSSV T : TRDP Ori Com letion: 6!6/1985 An le TD: 8 d 7182 Annular Fluid: Last W/O: Rev Reason: TAG FILL, Set BPC Reference L Ref L Date: Last U date: 11/14/2006 Last Ta : 6899' TD: 7182 ftKB L ast Tag Date' 11/11/2006 Max Hole Angle: 27 deg 4700 Casl~String -ALL STRINGS --_ Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 SUR. CASING 10.750 0 2873 2805 45.50 K-55 PROD. CASING . - 7.000 0 7158 6916 26.00 J-55 _ ~ - Tubi~Stri~ -TUBING _ _ _ Size To Bottom TVD Wt Grade Thread 3.500 0 6739 6501 9.30 J-55 EUE 8RD 2.875 _ 6739 6790 6552 1.20 J-55 EUE 8RD °Perfoi•ations Summary ~ _ , _ Interval ND Zone Status Ft SPF Date T e Comment 6677 - 6703 6440 -6465 C-1,UNIT 26 12 7/2/1985 IPERF 120 deg. phasing, 5 " HJ II B Cs Gun 6846 - 6855 6607 - 6616 A-4 9 4 7/2/1985 IPERF 90 deg. phasing, 4" HJ II Cs Gun 6862 - 6889 6623 - 6650 A-3 27 4 7/2/1985 IPERF 90 deg. phasing, 4" HJ II Cs Gun 6941 - 6948 6701 - 6708 A-2 7 4 7/2/1985 IPERF 90 deg. phasing, 4" HJ II Csg Gun Gas tiff Mandrels/Valves _ - - - St ~ MD f TVD Man ~ Man Type ~ V Mfr ~ V Type ~ V OD ~ Latch ~ Port ~ TRO ~ Date Run ~ Vlv Production MandrelslValves - - -- - _- St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO ~ Date Run Vlv Mfr Gmnt 9 6632 6395 Camco MMG-2 DMY 1.0 RK 0.000 0 5/24/1991 Closed - Other . __ - _. _ --- I ~S, equi ., etc.).- COMPLETION De nth ND T ~e ,1 1913 1853 SSSV Camco TRDP-1A-SSA' - l 6580 6344 PBR Baker 6594 6358 PKR Baker'FHL' ~ 6737 6499 SLEEVE-O 2.75" AVA BPC set 11/1: 6737 6499 NIP AVA BPL LANDING NIP » 6754 6516 PKR Baker'DB' ~ ~ ,»~ 6778 6540 NIP Camco'D' Ni le NO GO 6789 6551 SOS Camco _... _ { __ ._6790_ . 6552 TTL - General Notes Date Note 3/1 6 /2 0 0 4 WAIVERED WELL: IA x OA COMMUNICA I F,1 I 1l I ~- Perf (6846-6855) Perf (6862-6889) 2. 2.441 2.441 Perf (6941-6948) 11/21/06 Scblunl~epgep NO. 4049 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 9 znoß Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1155-- (57 d Field: Kuparuk Well Date CD BL Color Job# Log Description 2U-09 11416231 SBHP SURVEY 10/29/06 1 3J-18· 11483494 GlS 11/13/06 1 3J-13 11483495 INJECTION PROFilE 11/14/06 1 1 R-07 11486070 SBHP SURVEY 11/11/06 1 2X-17 11486068 PRODUCTION PROFilE 11/09/06 1 1 D-36 - 11486077 SBHP SURVEY 11/19/06 1 1D-120 ~ 11486073 INJECTION PROFilE 11/14/06 1 1R-35 - 11486074 PROD PROFilE-INCOMPLETE OPERATION 11/15/06 1 ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. o /.It--... . . RECE\VED 06/13/06 dUN 1 4 2006 Schlunlbepgep ~. 01' 'd- I /' \1;'0 NO. 3850 Alaska Oil & Gas Cons, Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 . " <, F ')í1\"f) ,...,0 nl\~, , .Ji c..~. " .''0 ,,~\\}t:,) ""I." "" ;:?~l'\;\., "~'.' Field: Kuparuk Well Job# Log Description Date BL Color CD ¡ ,;;- 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1 R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 . 11213760 PRODUCTION PROFILE WfDEFT 05/31/06 1 1R-07 11249912 PRODUCTION PROFILE 06/07/06 1 1 F-12 11320981 PRODUCTION PROFILE W/DEFT 06/06/06 'I 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE WfDEFT 05/25/06 1 2A-22 11213756 LDL 05/27/06 1 1Y-04 11320980 LDL 06/03/06 1 2Z-02 (REDO) 11235362 INJECTION PROFILE 05/28/06 1 1 H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13 (REDO) 11320976 LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31106 1 1 F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06/11/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (!1 . ~ o ;! ^ L . V / j7t>,~,__,. (Ç) / I ~( ('ß e e RECL,¢ED STATE OF ~ ['I0V 2 8 199T ALASKA OiL AND ~ COIJSE~A~N COMMISSION I~c~ lmmpil~ Teel AJaska 0il & Gas Cons. Commission Anchorage _ FIELB fUNIT t PAD: . ~-KRU- C~p #t ... DATE: ..... 6,',28/e8 mi. ii ill _ IMENTS: PRETEST ~D. ESJAJRE OBSERVED FOR ~0 MtNkjrTE~ PRIORTO TrsST. , il i __ __ I i _ ii _ _ J_ - ~ -- __ · 11J~ltG ~ON PI.I/ID: PR~ WATER INa. ~;ALT WATER ~ MISCIBLE lng. SCANNED DEC 1 9 2002_ NOT INJECTING c. Tdl) R:pI FI~ ANNUl. AR FLUID: P.P,G. gamd, ulesec ~.z ~ o.~ GLYCOL .~ . ~ _ ~__ SALT WATER _ -.-, __ J 6~ ~lLLl~ ~ ~ 0.~ O~ _ 0.~ .,, tlq~LL 1EST: Initill 4 -Ye~ Other AOC.-.-.-.-.-.-.-.-.~C REP SIGNATURE ~ BI, III OPERATC~ REP SIGNATURE STATE OF ALASKA AL--~¢, OIL AND GAS CONSERVATION COMMi'~-_:,~-~DN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate_ Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 212' FNL, 222' FEL, Sec. 19, T12N, R1 At top of productive interval 1344' FNL, 1117' FEL, Sec. 19, T12N, At effective depth 1395' FNL, 1156' FEL, Sec. 19, T12N, At total depth 1408' FNL, 1166' FEL, Sec. 19, T12N, 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 0E, UM R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 71 8 2 true vertical 6 93 8 Effective depth: measured 7 0 7 0 true vertical 6828 6. Datum elevation (DF or KB) RKB 84 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 R-07 9. Permit number/approval number 85-72 10. APl number 50-029-21332-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Junk (measured) NoPe feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 2836' 1 0-3/4" Intermediate Production 7125' 7" Liner Perforation depth: measured Cemented Measured depth 200 Sx CS II 8 0' 1000 Sx PF E & 2873' 200Sx AS II w/ 50 Sx PF C top job 700 Sx Class G & 71 6 0' 250 Sx PFC 6677'-6703',6846'-6855',6862'-6889',6941'-6948' true vertical 6438'-6464',6606'-6614',6621'-6648',6700'-6707' True vertical depth 80' 2804' 6916' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6790' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 6577' & Baker DB @ 6737'; SSSV: Camco TRDP-1A-SSA @ 1896' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 9/21/97. Intervals treated (measured) 6846'-6855' ,6862'-6889',6941 '-6948' Treatment description including volumes used and final pressure Pumped 231 Mlbs of 16/20 and 12/18 ceramic proppant into the formation, fp was 4675 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 566 363 326 980 214 Subsequent to operation 996 812 546 985 218 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date R E E E 1 V P SU M ,N Naska 0il & Oas Cons. c0mmissi0r~ Anchorage ARCO Alaska, Inc. '~-~ '~'~'KUPARUK RIVER UNIT ---- WELL SERVICE REPORT K1(1R-07(W4-6)) WELL JOB SCOPE JOB NUMBER 1R-07 FRAC, FRAC SUPPORT 0916971714.2 DATE DAILY WORK UNIT NUMBER 09/21/97 PUMP 'A' SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 ~ Yes O NoI ® Yes O No DS-YOKUM JOHNS ESTIMATE KD1533 230DS10RL '$144,483 $153,666 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final ¢¢jAer Ann 489 PSI 3300 PSI 500 PSI 500 PSII 0 PSII - 190 PSI DALLY SUMMARY I PUMPED'A' SANDS REFRAC WITH 231'000# OF UP TO 12 PPA 12/18AT PERFS' LEFT 1153~ PROPPANT IN PIPE' PUMPED 15'000#'120/40, 217,153#- 12/18. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LITFLE RED PUMP AND APC VAC. TRUCK. 07:30 HELD ON JOB SAFETY MEETING. 08:35 PUMP BREAKDOWN 30 BPM AND 5900 TO 5000 PSI, PUMP 1 AND 2 PPA 20/40 PROPPANT SCOUR STAGES AND FLUSH 15BPM AND 3300 PSI. SHUT DOWN AND PUMP PULSE TESTS. 09:43 PUMP DATA FRAC AND FLUSH, 15 BPM AND 2925, SHUT DOWN FOR ISlP 1923 PSI.AND CLOSURE CALCULATION. 10:55 PUMP 250 BBLS PAD OF 50# X-LINKED GEL AT 5 TO 15 BPM AND 11:19 PUMP 2PPA STAGE WITH 20/40 PROPPANT, AT 15 BPM AND 3800 PSI. 11:25 PUMP RAMP UP OF 2PPA TO 10 PPA 12/18 PROPPANT AT 15 BPM AND 12:04 PUMP 10 PPA FLAT STAGE, 15 BPM AND 3525 PSI. 12:28 PUMPING AT MAX. PRESSURE, RAMP TO 12 PPA, CUT TO MINIMUM RATE, GO TO FLUSH, GOT PROPPANT FLUSHED TO PERFS. 12 PPA ,12/18 AT PERFS. SHUTDOWN. 12:36 RDMO SERVICE COMPANY - SERVICE' DAILY COST ACCUM TOTAL $0.00 $1,344.00 APC $7,100.00 $7,100.00 DOWELL $135,383.00 $135,383.00 HALLI BURTON $0.00 $4,585.00 LI~-I'LE RED $2,000.00 $5,255.00 TOTAL FIELD ESTIMATE $144,483.00 $153,667.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 212' FNL, 222' FEL, Sec. 19, T12N, R10E, UM At top of productive interval 1344' FNL, 1117' FEL, Sec. 19, T12N, R10E, UM At effective depth 1393' FNL, 1159' FEL, Sec. 19, T12N, R10E, UM At total depth 1408' FNL, 1166' FEL, Sec.19, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 71 8 2' feet Plugs (measured) true vertical 6940' feet 6. Datum elevation (DF or KB) .. RKB 84 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-07 9. Permit number/approval number 85-72/~)-437 10. APl number 5o-029-21 332-00 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7 0 7 0' feet Junk (meaSured) true vertical 6828' feet Casing Length Size Cemented' Measured depth True vertical depth Structural Conductor I 1 0' 1 6" 200 Sx CS II I 1 0' I 1 0' Surface 2873' 10 3/4" 1000 Sx PF"E" III & 2873' 2807' Intermediate 250 Sx PF"C" Production 71 6 0' 7" 700 Sx Class G & 71 6 0' 6 6 7 8' Liner 250 Sx PF"C" ~ Perforation depth' measured ~ 6677'-6703', 6846'-6855', 6862'-6889,' 6941 '-6948' MD-RKB true vertical 6440'-6466', 6607'-6616', 6623'-6650', 6701 '-6708' TVD-RKB Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 6773' MD-RKB Packers and SSSV (type and measured depth) RE6 Baker FHL @ 6577, Baker DB @ 6737, Camco TRDP-1A SSSV @ 1896 F 13. Stimulation or cement squeeze summary Gelled deisel fracture with 20/40 Carbolite was pumped into the A Sand. r~- ~.~,... Intervals treated (measured) ~'~'E~ 6846'-6855' 6862'-6889 ' 6941 '-6948' AIa$!(~ OJj & Gas Corls, ' ' ' Treatment description including volumes used and final pressure Pumped 44,500 lbs of 20/40 Carbolite into the A Sand. Maximum treating pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 712 851 0 = 684 141 1158 1212 I ' 15 515 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~¢'~,~.,~/,~,/x~t~-~--~-~~ Title Sr. Operations Engineer Form '10-40~/Rev 06/15/88 Service , ARCO Alaska, Ir~, ¢) Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL rNTRACTO~.~;~ U/~7~ - h PSDT ,..,-- I FIELD- DISTRICT- STATE IDAYS/ _ _~ ~o-~-~TT6-~ ~ ~-- !13o /diP. z/. H/~/~o~ ,0' r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report 'F ' '. , 'F -'" '~:i;~ii: knot' 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator . 0 co s .v,. ON oo ,ss,o. APPLICATION FOR SUNDRY APPROVALS AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing_ Variance _ Perforate _ Other Type of Well: Development X Exploratory _ Stratigraphic _ 4. Location of well at surface 212' FNL, 222' FEL, Sec. 19, T12N, R10E, UM At top of productive interval 1344' FNL, 1117' FEL, Sec. 19, T12N, R10E, UM At effective depth 1393' FNL, 1159' FEL, Sec. 19, T12N, R10E, 'UM At total depth 1408' FNLI 1166' FEL, Sec. 19, T12N, R10E~ UM Present well condition summary Total Depth: 6. Datum elevation (DF or KB) measured 7182' feet Plugs ' (measured) true vertical 6940' feet Effective depth' measured 7070' feet Junk (measured) true vertical 6828' feet None Casing Length Size Cemented Structural Conductor I 1 0' 1 6" 200 Sx CS II Surface 2873' 10 3/4" 1000 Sx PF"E" III & Intermediate 250 Sx PF"C" Production 71 60' 7" 700 Sx Class G & Liner 250 Sx PF"C" RKB ~4 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 R-07 9. Permit number 85-72 10. APl number 50-029-21 332-00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVED MAY 2 6 1989 Nasl~ 011 & Gas Cons: Comrn'mion Measured depth 'l'~ll~"~l"vel"'l~r~'lcal depth 110' 110' 2873' 2807' 7160' 6678' 12. Perforation depth: measured 6677'-6703', 6846'-6855', 6862'-6889,' 6941'-6948' MD-RKB true vertical 6440'-6466', 6607'-6616', 6623'-6650', 6701'-6708' TVD-RKB Tubing (size, grade, and measured depth 3 1/2" J-55 9.3 #/FT @ 6773' MD-RKB . Packers and SSSV (type and measured depth) Baker FHL @ 6577, Baker DB @ 6737, Camco TRDP-1A SSSV @ 1896 Attachments Description summary of proposal_ Detailed operation program Refracture Pump Schedule 13. 14. Estimated date for commencing operation Mav 18. 1989 16. If proposal was verbally approved Name of approver j~, j~, ~) ~. ~ ~. Date approved BOP sketch 15. Status of well classification as: Oil ~ Gas M Suspended Service Oil Producer I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSI(~ USE ONLY Date ~'~- ~)~/C_~,~t:,~ 17. Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test M Subsequent form require 10-"~-~ OR!GINA! SIGNED BY LONNIE C. SMITH Approved Copy Returned - ~3~mmissioner IApproval Approved by the order of the Commission Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE ~'-~ Well 1 R-07 Application for Sundry Approval May 23, 1989 It is proposed to refracture Well 1R-07's A Sand. The well will be refractured with gelled diesel and 20/40 Carbolite pumped at 20 BPM, and no workover fluid will be used. No BOP is required. A surface manifold with tanks will be present and used to produce the well for the first few days. The expected bottom hole pressure of the A sand is 2500 psi. RECEIVED MAY 2 6 1989 ~ 0il & Gas Cons. Commissi01~ Anchorage KUPARUK WELL 1R-07 'A° SAND REFRACTURE PUMP SCHEDULE 5/9/89 ST/EE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BB .L.S BPM . PPG DESCRIPTION LBS STG/CUM BBLS 1 GD PRE-PAD 150.0 20 0 NOI:q:I(::)PPANT 0 '1 50/ 150 61 ............................................... SHUT DOWN FOR ISIP 2 GDPAD 330.0 20 0 NOPI:IOPP~ 0 3301 480 21 1 3 GD w/2 PPG 23.0 20 2 20/40 M CARBO-LITE 1930 25/ 505 541 4 GDw/4 PPG 29.8 20 4 20/40 M CARBO-LITE 4999 351 540 566 5 GD w/6 PPG 39.5 20 6 20/40 M CARBO-LITE 9965 501 590 601 6 GDw/8 PPG 44.4 20 8 20/40 M CARBO-LITE 14905 60/ 650 651 7 GD wllO PPG 34.7 20 1 0 20/40 M CARBO-LITE 14576 501 700 711 9 . GDFLLISH 60.0 +SV 2,0 0 , NO~AN~,. ,, 0 60/ 760 761 TOTALGELJ.ED DIESEL= 711.3 BBLS +SV 20/40 M CARBO-LITE = 46374 LBS NOTES: Stages I and 9 am Gelled Diesel. Stage 2 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 3 through 7 are Gelled Diesel with 6 hour breaker and without silica flour. Stage 9 should Include a volume adjustment for surface equipment between the wellhead and den~. This job is intentionally underflushed by I bbl. The blender tub should be bypassed at flush. All fluids should be mai ~n~ at 70 to 90 F on the surface. ARCO Alaska, Ir~ Post O ffic~.~ /J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO:STATE OF ALASKA DATE: AK, OIL & GAS CONSERVATION.coMMIsSION 3001 PORCUPINE DR. -. ATTN: JOHN BOYLE APRIL 15~ 1986 OPERATOR: ARCO NAME: KUP 1R-7 SAMPLE TYPE: CORE CHIPS NUMBER OF BOXES: 30 BORES @ 1·' Intervals 6695-6722 6728-6775 6782-6832 6842-6890 6892-6980 SHIPPED BY: ~ '\~3,~>,~, PEG WEISSER mEC~ ATD~ FOR T.A. G©RUP UPON RECEIPT OF~ THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC' P.O. BOX 100360 ._ ANCHORAGE, ALASKA 99510 ABV-100 DATE: ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany ARCO Alaska, In( Post office~0360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA DATE: APRIL 15, 1986 AK, OIL & GAS cONSERVATION COMMISSION 3001 PORCUPINE DR. ANCHORAGE, AK 99510 ATTN: JOHN BOYLE OPERATOR: ARCO SAMPLE TYPE: PLUGENDS-. SEE ATTACHED:. NAME: UG~U 1R- 7 NUMBE~ OF BOXES: 4 BOXES~._ SHIPPED BY: . Xs,~.~,.~-~.~ PEG WEISSER TECH ATD~ ~ T~A_ GORUP UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 -. ANCHORAGE, ALASKA 99510 ATTN: PALEO LAB, ABV-100 RECEIVED BY: / ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Ir~ Post Offic,~5'~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA DATE: APRIL 15, 1986 AK. OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR. ANCHORAGE, AK 99510 ATTN: JOHN BOYLE OPERATOR: SAMPLE TYPE: ARCO PLUG ENDS NAME: W.S. 1R-7 NUMBER OF BOXES: 22 BOXES @ 1' Intervals 3440.9-3448.7 3745.7-3754.7 NO CORE #7 '~756=3761 3451.6 3762.7-3784.7 3463.7-3474.7 3476.7-3517.7 3519.7-3525.7 3527.7-3551.2 3553.7-3643.2 3646.7-3725.2 3727.7-3742.7 3743-3744 --~'~ SHIPPED BY: ~,f ~3.~j~ PEG WEISSER TECH AIDE FOR / UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: PALEO LAB, ABV-100 RECEIVED BY: DATE ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Date: March 11, 1986 Internal Corresponde""e / Subject:Documentation Request-Plugends For T.he State Of Alaska F~im 1R~nu Interval) From/Location: T.A. Gorup-100 ABV To/Location: Barb Durfee ATO-1090 @ 1' Intervals DEPTHS COMMENTS DEPTHS COMMENTS 30ii.i-3037.i o o- o 3.1 NO CORE #4 3096.3-3136.1 THIS LIST EXCEPT AS NOTED IN COMMENTS AND CORRECTIONS COLUMN, IS A COMPLETE LIST OF SAMPLES DUE THE STATE OF ALASKA. PLEASE SIGN AND RETURN THIS FORM TO: T.A. GORUP, ABV-100 NAME DATE ARCO Alaska, Inc. Is a Subsidiary of AllanflcRIchfleldCompany ARCO Alaska, Inc. Post Office ,L~...,_.,J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 31, 1985 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 acidize Kuparuk field wells 1R-1, 1R-2, 1R-7, 1R-11, and 1R-16. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD:ps:Fi le Attachment (In Triplicate) RECEIVED JAN 0 2 1986 Oil & Gas Um'~. ,,~,,ml~lon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OFALASKA , , ALASKA 0'TL AND GAS CONSERVATION CO~MI~{[~ I V E D SUNDRY NOTICES AND REPORTS ON WELLS JAN 0 2 DRILLING WELL [] COMPLETED WELL I~ _OTHEF] [] Alaska 0il & Gas Cons. uornmiss~on 2. Name of Operator ARCO ALASKA, INC. 7. Permit No. 85-72 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21332 9. Unit or Lease Name KUPARUK RIVER UNIT 212' FNL, 222' FEL, SEC. 19, UM 4. Location of Well SURFACE LOCATION: T12N, R10E, 5. Elevation in feet (indicate KB, DF, etc.) 84' (RKB) I 6 . Lease Designation and Serial No. ADL 25635, ALK 2568 12. 10. Well Number 1R-7 11. Field and Pool KUPARUK RIVER FIELD KtJPARUK 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 improve production. The HCL with MSR-100. "C" sand in Kuparuk well treatment will consist 1R-7 be acidized to of 26 bbls of 12 % The acid is to be pumped by coil tubing unit and displaced with nitrogen to aid well cleanup. Prior to starting work, equipment will be pressure tested to 4000 psi. Fluid Requirements' 26 bbls 100 bbls 12 % HCL Diesel ANTICIPATED START DATE' January 3, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~, /~ ~,~,~--,,~,¢~- The space below for Commission use KU PARU K Title Date OPERATI ONS COORD I NATOR 12/31/85 Conditions of Approval, if any: Approved by BRI&IIAL Sl'ltJl[i "-. Iff f,O,lll[ l, SIITI' .~ Approved Returned COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Offic(_~.._~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ... · · DAT~= 10-22-85 TPJ%NSMITTAL i~O: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLEkK ATO-1115B . --. P.O. BOX 100360. · · '' ANCHORAGE, AK 99510 TRANSMITTED HER/,.WITH AK~ T~ FOLLOWING ITmlS. RECEIPT AND RETURN ON~ SIGNED COPY OF THIS FINAL PRINTS/ SCHL/ ON~ * OF EACH CEMENT. BOND LOG/ VARIABLE DENSITY "~3B- 8 06-06-8-5- .RUN %1 5850-8369 ~ 42X-15 11-07-.84 RUN ~1 5900-8258 "~2X-13 .11-17-84 RUN #1 5896-8410 '~ 2X- 12 12-08-84 RUN %1 3050-7215 ~2X-ll 12-08-84 RUN #1 3100-6370 -%2X-10 12-21-84 RUN #1 3350-6973 ~2X-9 12-20-84 PUN ~1 5100-8338 2W-6 11-25-85 RUN ~1 5700-7290 '~2V-16 06-06-85 · RUN ~1 4550-710~ 2V-15 06-07-85. · RUN #1 4650-6428 ~2V-13' 06-03-85-' RUN #1 . 6590-8553 · ~20-8'~ ' 04-02-85 . RUN.#i:..' .4970-6938' ~'~2U-7-~'. -. 04-01-~5' ,{UN ~1:". 0070-~122 'J20-6 i-;' 03-31-85 ' RUN ~1'.~ -'w2U- 5'f.'~ 04-01-85 · ~UN #1 ~2D-16 ' 12-19-84· RUN 2D-15 ' 12-18-84 RUN ~2D-l' 11-03-84 - RUN . -~lR-8 ' 06-17-85 kUN ' ~lR-7 .. 06-08-~5 RUN '~R-5 . 06-08-85 aUN ~iL-15 11-05-84 RUN %1 WlQ-15 05-27-85 RUN '~1~3 04-17-85 ,. kUN %CPF-1A 12-21-84 ~UN C~ENT EV~UATION TOOL LUGS/ ~ 1F-'16 . 03-12-85 RUN ~k-5 ff~ 06-26-85 - RUN' vla-5 ..??~.' 06-27-85-.~ RUN ~20-2'~'~.~~' '03-25-85 ~'~ RUN '~20-15 03-87-85 RUN "~3B-9 ~-.~-'- 06-30-85 RUN %1. . '~3C-11"' 06-29-85 ~ RUN '~3C~12".''''. 06-29-85. RUN . . . ~CEIPT : · BPAE- "' -' - DRILLIN~*BL B. CUVIER . L. JOHNSTON, CHEVRON. · ... D & M. · · - . · ~ PLL.'A$~ ACKNO~4LEDGE TRANSMITTAL. 5600-8107 .... 5994__9161· 6284-7850' 5200-7459- 3285-6454" 5693-6652 5987-8324 4302-7028 6950-8628 4883-660U'- , - 6490-7566- " 897~-10744 2200~3856 _ Ck/~ENT ~VALUATION LOGS 8269-8712 6974-8644 8254-8532 5790-9450' 6400-7002 6000-8246 6500-8726 5400-7457 ~ . . W. mOB I L - NSK CLEt~K*=L ' ' ' ' ' J~ RATHmELL'' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ARCO Alaska, Inc...~ Post Office B~"~1~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-7 Dear Mr. Chatterton: Enclosed is a copy of the 1R-7 Well History to include with Well Completion Report, dated 7/29/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L149 Enclosure the Alaska 0it & Gas Cons. ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ARCO O-and Gas Company Daily Well History-Final Report Instructions: Prepare and suomd 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 tor an indet~mte or appreciable length of time. On workovers when an official test is not required upon completion, rel:)Ort completion and representative test data in blocks provided. The "Final Report" form may be used Ior reporting the entire operalion if space is avadable. District ICounty or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. AFE 604577 North Slope Borough APL 25635 Completion IAccounfing coat center code State Alaska IWell no 1R-7 Nordic I! 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete AP1 50-029-21332 I A.R.Co. W.I. rrotal number of wells (active or inactive) on this 56,24:[ Icost center prior lo plugging and J abandonment of this well I°ale711185 I I Z. oO ~,-t-t-t-5--tn-~. IH°ur IPriOr status if a w'O' Date and depth Complete record for each day reported as of 8:00 a.m. 7/02/85 7/03/85 7070' PBTD, RIM w/3½" Compl String .: Accept Ri~ @o~o--h~-s, 7-1-85. NU w/4" csg guns, 4 SPF, 90° &perf f~', 6889'-6862', 6855'-6846'. RIH w/5½" csg guns, 12 SPF, 120° & perf f/6703'-6677'. RIH w/pkr & tail pipe assy. Set @ 6737~. RIH w/3½" compl string. 7" @ 7158' 7070' PBTD, RR Crude RIH w/3½" compl. Set retr pkr, shear ?BR, ND BOPE, NU tree & tst. Displ well to crude. Tst SSSV, set BPV. RR @ 1700 hfs, 7-2-85. Ran 211 its 3½", 9.3#, J-55 EUE, 8rd IPC tbg. Set SSSV @ 1913', retr pkr @ 6594' perm pkr @ 6754', "D" nipl @ 6778~. Move to 1R-8 FT Old TD I New TD I Released rig ~ Date I 1700 hrs. Classifications (oil. gas, etc. I 0il Producing method Flowing Potential test data I PB Depth Kind of rig 7/2/85 Type completion Ising!e. dual. etc.) Single Official reservoir name(s) Kuparuk Sands 7070' PBTD Rot'ary Well no. Dale Reservoir Producing Interval 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 l~he above is correct -- CON(A~ - For form preparation and distributionT. see Procedures Manual, Section, I~ · · Drilling. Pages 86 and 87 AR3B-459-3-C Date Titl Drilling Superintendent OCT 0 1985 Alaska Oil & Gas Cons. Commission Anchoraga as they are prepared for each well. ]. Dlvi'~on of AflantlcRlehfleldCompany ARCO Alaska, Inc. Post Office B~"~T'00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-7 Dear Mr. Chatterton: Enclosed is a copy of the 1R-7 Well Completion Report, dated please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L30 Enclosure Well Hi story to include wi th the 7/16/85. If you have any questions, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History - Initial Report - Daily Inatructlonr- Prepare and submit the "lnlUel Re~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to slxldding should be summarized on the form giving inclusive dates only. District I~unW. ~d~ or ~rough I State Alaska I North Slope Borough I Alaska Field I Lease or Unit . Well no. Kuparuk River I~itle ADL 25635 1R-7 I Drill Auth. or W.O. no, AFE 604577 Doyon 9 API 50-029-21332 Operator ARCO W.L ARCO Alaska, Inc. 56.24% Spudded ' 5/15/85 1400 hrs. Date and depth as o! 8:00 a.m. 5116185 5/17/85 5/18/85 thru 5/20/85 5/21/85 5/22/85 The above is correct For form preparation and dilrlributi~n, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Complete record for each day reported 16" @ 110' 1329', (1219'), Trip Wt. 9.6, PV 20, YP 18, PH 9.0, WL 15.6, Sol 8 Accept rig @ 0900 hfs, 5/15/85. NU diverter sys. Spud well @ ' 1400 hrs, 5/15/85. Drl 13%" hole to 1329'. 431', 3.8°, S39.9W, 430.90 TVD, 4.34VS, 3.33S, 2.79W 857', 15.0°, S33.0W, 850.61TVD, 73.20VS, 57.51S, 45.46W 1250', 22.8°, S42.3W, 1222.0 TVD, 200.67VS, 156.35S, 126.11W 16" @ 110' 2887', (1628'), Rn OHL Wt. 9.9, PV 16, YP 16, PH 9.0, WL 14.4, Sol 10 TIH, drl 1329'-2887', circ, POH. RU & att to log; unable to get below 1580', POH. PU bit, RIH, C&C mud, POH. RU & rn OHL. 1410', 21.4°, S42.8W, 1370.24, 260.86, 200.70S, 166.51W 1923', 11.4°, S57.5W, 1864.39, 394.53, 288.05S, 269.85W 2549', 5.6°, S64.3W, 2483.34, 480.12, 330.21S, 351.42W 2857', 4.2°, S71.0W, 2790.17, 504.09, 340.39S, 376.11W 10-3/4" @ 2873' 3106', (219'), RIH Wt. 9.9, PV 26, YP 30, PH --, WL 5.6, Sol 30 Log DIL/SFL/SP/GR/CAL/LDT/CNL & GR/LSS f/2888'-surf. GIH, C&C, POOH. RU & rn 70 its, 10-3/4", 45.5#, J-55 BTC csg to 2873' & cmt w/1000 sx PF "E" @ 12.3 ppg & 200 sx PF "C" @ 15.6 ppg. Displ w/262 bbls mud, bump plug w/1500 psi. CIP @ 0200 hrs, 5/18/85. ND diverter. Perform 50 sx top job. NU & tst BOPE. RIH w/BHA, tst csg to 1500 psi. DO shoe it, conduct LOT to 12.5 ppg EMW. Chg over to oil base mud. Drl f/2897'-3005', trip f/core assy. RIH, core #1, 3005'-3033', rec'd 100%. Core #2 f/3033'-3063', rec'd 100%. Core #3 f/3063'-3093', rec'd 100%. Core #4, 3093'-3105', rec'd 97%. 10-3/4" @ 2873' 3449', (343'), RIH Wt. 9.1, PV 25, YP 31, PH --, WL 4.2, Sol 29.5 Core #5, 3106'-3136', rec'd 100%. TIH w/drlg assy, drl 3136'-3440', TOH. PU 9-7/8" core assy, TIH, core #6 (West Sak) f/3440'-3449', rec'd 100%. 10-3/4" @ 2873' 3523', (74'), POOH w/core Wt. 9.6, PV 20, YP 28, PH --, WL 4.2, Sol 29 Att to core @ 3449' on hard streak, TOH, PU bit, RIH & drl to 3451', POOH. PU core assy, RIH, core #7,~4~9~', rec'd J~. Core #8,~M~i~~:~ rec'd 1'. Core rec'd,~l ' Core #10~3~3~~ ~t-e~- 29'. Cor~ ~ll, ~Z5~-mS~'~ PO~, Date I Title 6/20/85 Drilling Superintendent R. ECEiVED AR3B-459-1-D . = Alaska 0il & Gas Cons. Commlss~on Anchnr~.r~e Number all daily well history forms consecutively as they are prepared for each well. iP~.ge no. ARCO Oil and Gas 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 performed. Number ali 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 "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 strin§ until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25635 Complete record for each day while drilling or workover in progress 5/23/85 5/24/85 5/25/85 thru 5/27/85 5/28/85 5/29~85 State Alaska Well no. IR-7 10-3/4" @ 2873' 3755', (232'), POOH w/core #18 Wt. 9.8, PV 23, YP 29, PH --, WL 3.8, Sol 31 Rec'd 28' f/core #11. Core #12, 3553'-3582', rec'd 30'. Core #13, 3582'-3613', rec'd 31'. Core #14, 3613'-3644', rec'd 31' . Core #15, 3644'-3G~4', rec'd 28'. Core #16, 3674'-3702', rec'd 30'. Core #17, 3702'-3725', rec'd 24'. Core #18, 3725'-3755', TOH. 10-3/4" @ 2873' 3885', (130'), RU to rn VSP Wt. 9.7, PV 22, YP 27, PH --, WL 3.8, Sol 30 TOH w/core #18, rec'd 28'. Core #19, 3755'-3785', rec'd 31' LD core equip. TIH, drl 9-7/8" hole f/3785'-3885', TOH. RU Schl, log DIL/GR f/3874'-2868', LDT/CNL/NGT f/3874'-2668'. RU f/VSP. 10-3/4" @ 2873' 5987', ~2i0Z'), Drlg Wt. 9.4, PV 11, YP 13, PH 9.5, WL 7.0, Sol 9 Rn VSP f/3830'-1750' WLM & 1590'-310' WLM. RIH, fire SWC w/28 shots f/3462.7 - 3448.9' WLM, 1 shot @ 3424' & 1 shot @ 3422.9'; rec'd 26 shots. RIH w/BHA, CBU, chg over to polymer mud, POOH, RU & tst BOPE. RIH w/BHA, Navi-Drl & surv 8%" hole to f/3885'-5987'. 3840', 3.5°, S59.9W, 3770.95 TVD, 565.06 VS, 369.38S, 435.41W 4184', 15.2°, S42.8W, 4109.89 TVD, 620.04 VS, 402.60S, 480.86W 4401', 22.1°, S41.1W, 4315.50 TVD, 689.43 VS, 454.21S, 527.25W 4621', 26.7°, S32.0W, 4515.85 TVD, 779.98 VS, 527.22S, 581.37W 5438', 25.5°, S34.1W, 5250.61TVD, 1133.85 VS, 824.70S, 779.09W 5928', 14.9°, S15.7W, 5712.82 TVD, 1288.67 rS, 969.01S, 849.55W 10-3/4" @ 2873' 6607', (620'), Prep to core Wt. 10.0, PV 16, YP 13, PH 9.0, WL 6.8, Sol 13 Drl 8½" hole to 6607', POOH, LD BHA. PU core bbl, RIH to 6447', wsh to 6607'. 6211', 13.7°, S19.5W, 5987.05 TVD, 1352.61VS, 1035.64S, 870.69W 6582', 8.8°, S34.1W, 6350.51TVD, 1423.57 VS, 1102.39S, 902.29W 10-3/4" @ 2873' 6667', (60'), Coring Wt. 10.0, PV 17, YP 15, PH 9.0, WL 7.0, Sol 14 Core #20~ 6607'-6637', TOH, rec'd 25.5'. Core #21, 6637'-6667' prep to TOH. The above is correct For form preparation and dist~'~ution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent AR3B-459-2-B J Number all daily well history forms consecutively as they are prepared for each well. Aiaska Oil & Gas Cons. IPa~e no. ARCO Oil and Gas Company ,~, Daily Well History--Interim Inslruclions: This form is used during drilling or workover operations, if testing, coring, or perforating, 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. RePorl official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less trequently than every 30 days, er (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil stdn§ until completion. District Field Alaska J County or Parish '~ tState - North Slope Borough JL ADL 25635 Unit Alaska Kuparuk River Date and depth as of 8:00 a,m. 5/30/85 5/31/85 6/01185 thru 6/03/85 6104185 6/05/85 6/06/85 JWell no. iR-7 CompJete record for each day while drilling or workover in progress 10-3/4" @ 2873' 6728', (43'), Core #23 Wt. 10.0, PV 17, YP 15, PH 9.5, WL 7.0, Sol 14 Core #21, 6667'-6695', rec'd 60.5'. Core #22, 6695'-6728', rec'd 27.5' RIH f/core #23. 10-3/4" @ 2873' 6782', (54'), Core #24 Wt. 10.0, PV 17, YP 16, PH 9.5, WL 7.4, Sol 14 Core #23, 6728'-6782', rec'd 47' RIH w/core #24. 10-3/4" @ 2873' 6979', (197'), Core #27 Wt. 10.0, PV 18, YP 10, PH 8.9, WL 7.1~ Sol 13 ~ore .#24 f/6782'-6842', rec'd 50'. Core #25 f/6842'-6892' ec'd 48'. Core #26, 6892'-6952', rec'd 60.5'. Core #27, 952'-6979', incompl. 10-3/4" @ 2873' 7182', (203'), RU to log Wt. 10.1, PV 16, YP 13, PH 9.0, WL 5.9, Sol 15 Fin core #27 f/6979'-6982', rec'd 27.5' Drl 8½" hole f/6982'-7182', C&C, 10 std short trip, POH. RU Schl. 10-3/4" @ 2873' 7182', (0'), Rn'g DLL Wt. 10.1+, PV 20, YP 11, PH 9.0, WL 6.5, Sol 15 RU & GIH w/LDT/CNL/SP/DIL/Micro log; microlog not wrk'g, POH. Log w/LDT/Micro Log/GR/CAL f/7166'-2866'. Log DIL/SFL/LSS/GR f/7100'-2866' Log SHDT; tl not wrk'g. Att to log w/DLL/GR. 10-3/4" @ 2873' 7182' TD,(0'), RU to rn 7" Wt. 10.2, PV 20, YP 8, PH 9.0, WL 6.0, Sol 15 Log DIL/GR f/3950'-2866', SHDT f/7100'-2864'. Re-rn DIL/GR f/3950'-2866'. RIH, wsh fill 7123'-7182', CBU, short trip to 6237', CBU, POH, LD DP. RU to rn 7" csg. The above is correct For form preparation and dist~:)ution see Procedures Manual Seclio'h t0. Drilling. Pages 86 and 87 AR3B-459-2-B Date J Title 6/20/8~ Drilling Superintendent At&sKa 011 8, G&s ConS, Oomm',,s¢or~ J N umber all daily well history forms consecutively as they are prepared for each well. IPage no. 3 ARCO 0~'and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday attar 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. I Accounting cost center code District ICounty or Parish I State Alaska North Slope Borough - Alaska Field IL ...... Unil IWell no. Kuparuk River ADL #25635 iR-7 Aulh. or W.O. no. ~Title AFE 604577 I Drill Doyon 9 AP1 50-029-21332 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 5/15/85 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. 1400 hrs. [ Dale and depth as of 8:00 a.m. Did TD Released rig Complete record for each day reported 7" @ 7160' 7182' TD, 7070' PBTD, RR 10.0 ppg NaC1/NaBr Rn 163 its, 7", 26#, J-55 BTC csg w/FC @ 7070', FS @ 7160'. Cmt w/300 sx C1 "G w/l% CFR-2, 1.25% Halad-24.$ Displ w/brine & bump plug. CIP @ 1715 hrs, 6/6/85. Lnd csg. ND BOPE. NU & tst tree. RR @ 2115 hrs, 6/6/85. 2115 hrs. 6/07/85 Classilications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD 7182' (6/4/85) IPSoepth Kind of rig 6/6/85 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7070' PBTD Rotary Well no. Date Reservoir Producing Interval 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 Signature For form preparation ~nd distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Date ITitle 6/20/85 Drilling Superintendent & Gas Coas, fimi~'a~.,we.. ~,~,o~,........... tively Pagano. , . las they are prepared for each well. k~Ch0 rS.g~0 Oivi"on of Aflanti~Ehlleld~m~y ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-85 TRANSMITTAL NO: 5313 RETURN TO: aRCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECOkDS CLERK - ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND <~LE FINALS/SCHL/OHE * OF EACH PLEASE NOTE-- THIS LOG IS A "TWO IN ONE". ONLY THE ~ ~_ WE USED FUR TRANSMITTING. HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ~TURN ONE bIGNED COPY OF THIS TRANSMITTAL. ~ THIRD INTERVAL WILL ----7/ ~-q5" DIL/SFL 06-04-85 I{UN #3 2864-7090 "",o-x,3 2" DIL/SFL 06-04-85 RUN #3 2864-7090 5" COMP.NEU/LIT~zO.DE~--PORO 06-04-85 RUN #3 2866-7162 'xo-'-J2" Ct)MP.NEU/LITHO.DEN-PORO 06-04-85 RUN #3 2866-7162 ~ ~-'"~ 5" CO[.iP NEU/LITho DEN-RAW 06-04-85 ztUN #3 2866-7162 ~ 2" CO[.~P.NLU/LITHo. D~N-RAW 06-04-85 RUN #3 2866-7162 "/ Il ,, ~,,.j/ ~'~5 LONG SPACING SONIC-GR 06-04-85 RUN #3 2864-7057 '~ 2" LOI]G SPACING SONIC-GR 06-04-85 RuN #3 2864-7057 ~ CPTR PRuCLb~LD LOG U6-04-85 RUN #3 2866-7049 '~ 5" DUAL DIPidETER 06-04-85 RUN #3 2864-7100 'x'~'~',g5" &25" HICROLOG-GR 06-04-85 RUN #3 2864-7059 5" DIL/SFL-GR 06-28-85 RUN #1 ~" DIL/SFL-GR 06-28-85 kUN #1 ~" DEN/NEU PORO 06-28-U5 RUN #1 '"~2" DEN/NEU PORO 06-28-85 RUN #1 5" DEN/NEU RAW 06-28-85 RUN #1 2" DEN/NEU RAW 06-28-85 RUN ~1 CY~E~LOUK 06-28-85 i!UN #1 3876-8285 3876-8285 4000-8259 4000-8259 4000-S259 4000-8259 7400-8236 RLCEIFT aCKNOwLEDGED: commission STATE OF ALASKA*BL SOHIO /SE UNION RATi~IELL*BL K .TULIN/VAULT*FILM ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichIieldCompany ARCO Alaska, In(~_ Post Office ~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 'TRANSMITTAL NO:5292 RETUPd1 TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED k~CEIPT AND KUPARUK WELL PRESSU lB-1. 05-30-~5 lB-2. 05-30-85 ~lB-4~ 05-16-85 1C-4 07-24-85 1C-6-~ 07-25-85 1D-8-~ 07-30-85 --1H-3 07-30-85 l'Q-13/ 06-24-85 "lQ-14j~ 06-23-85 XlQ-15' ' 06-21-85 ~'iQ- 16~ 06-21-85 1R-5? 07-05-85 1R-6-~ 07-06-85 ~lR-7/ 07-06-85 -1R-8 ~ 07-08-85 ~2A- 2-' ' 07-04-85 ~2W-7--' 07-26-85 '-2V- 3 07-11-85 ~2W- 15" 08-04-85 3B-l- 06-14-85 3B-2~--~' 06-14-85 -3B-3'- 06-28-~5 ~3B-3' 06-15-85 ~3B-4- 06-15-85 ~3B-5 --- 06-26-85 - 3B-6"- 06-26-85 ~-3B- 7' 06-28-85 3B-7~ 06-27-85 3B-8~ 06-28-85 ~3B-9~ 07-18-85 ~3B-10-~ 07-20-85 ~3B-11 -- 07-20-85 3B-12-.- 07-21-85 ' 3B-13- 05-29-85 ~3B-14 05-29-85 RECEIPT ACKNO~LEDGED: BPAE* B. CURRIER CHEVRON* D & H* HERE%$ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNO~LEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. RE REPORT--ENVELQ. PE FACE DATA CAMCO '~3B-15 CAMCO 3B-16~-~ CAMCO ~ 3C- 11~' CAMCO CAMCO CAMCO C~CO CAMCO CAMCO CAMCO C~ICO CAMCO CAMCO CAMCO CAMCO OTIS DRESSEI{ OTIS OTIS CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CA/~]CO CAMCO CAMCO OTIS OTIS DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON b~BIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of AllanlicRichlieldCompany ARCO Alaska, Inc~.. Post Office E~o~'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-20-85 TRANSMITTAL NO: 5294 RETURI~ TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND FINAL PRINTS / SCHLUMBERGER CET/CEMENT EVALUATIONS (ONE * OF EACH) --m2Z-8 ~ CET LOG 04-26-85 '--2V-9'"' CET LOG 04-25-85 '~2H-14--'CET LOG 04-0 5-85 ~iR-7/CEHENT EVALUATION 06-19-85 RETUKN ONE SIGNED COPY OF THIS HEREWIYH ARE THE FOLLOWING ITL~4S. PLEASE ACKNOWLEDGE TRANSMITTAL. FINAL'" PRINTS / SCHLUMBERGER CBL'S (ONE * OF EACH) 3~-1/' 05-06-85 RUN #1 ~2U-11~05-03-85 }{UN #1 2U-10/05-03-85 RUN #1 '~2U-9 ~ 05-02-85 RUN #i -~lQ-16/05-27-85 ~{UN #1 5040-7563 ..... 8423 5500-6963 5850-8089 4290-7018 KUN #1 8400-9208 RUN #1' 7000-7893 RUN #1 7-400-8700 RUN #1 4500-7033 :<ECEIPT ACKNOWLEDGED: JPAE CURRIER :HEVRON ) & M DISTk(IBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLEF, K*BL J. RATHMELL ., ,.,.,~ 6ons. OommJssio, , STATE OF ALASKA*BL SOHIO /SE UNION K. TU LIN/VAU LT* FI LMS ARCO Alaska. I.c i~ R .c:;,thcirli~rv *"f f, ll~.~,;~--;-~.':~'-'"' ....... ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TRAN$SIITTAL NO: 5285 ~ETUR/~ TO: ARCO ALASKA, INC. KUPAI~UK OPERATIONS ENGINEEkING ~ECOKD~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 fKANSMITTED HEREWITH ARE THE FOLLOWING ITkX~S. ~'PLEASE ACKNO~LEDGE qECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. BOX 1 OF 2: 3PEN ~OLE LIS TAPES PL US LISTINGS (ONE COPY OF ~C-11 06-23.-85 RUN 91 4427.5-8881.5 REF 3C-10" 07-02-85 RUN ~1 1785.0-8987.5 I~EF 3C-9-' 07-10-85 RUN #1 3920.0-8332.5 REF -.~C- 7~ 07-31-85 RUN #1 4617.5-8747.5 REF ~B-14-- 03-20-85 RUN #2 3280.0-6~03.5 REF 3B-12' 07-03-85 RUN 91 4021.5-8261.5 REF 3B-11~ 06-26-85 RUN #1 2190.5-9257.0 REF 3B-10~ 06-17-85' RUN #1 3273.0-7270.5 REF 3B-9'-~ 06-10-85 RUN #1 2092.0-8415.0 REF 2Z-15" 06-19-85 RUN #1 2658.0-6620.0 REF 2Z-14~ 06-28-85 RUN #1 3876.0-8334.0 REF /Z-13' 07-05-85 RUN #1 4180.0-8538.5 REF 2Z-12~ 07-20-85 RUN #1 4409.0-9412.5 REF !Z-11~ 07-27-85 RUN #1 3531.5-7534.0 REF EACH) #70597 #70620 #70642 #70706 #70229 #70641 #70598 #70555 #70634 #70562 #70600 #70639 #70661 #70704 .N BOX 2 OF 2: ~P~iN~HOLE LIS TAPES PLUS LISTINGS (ONE COPY OF w-16~/ 01-28-85 RUN #1 3116.0-7038.5 REF -V-14'/ 05-16-85 I~UN #1 3047.0-7086.5 REF V-12~/ 04-22-85 RUN 91 3960.0-9265.0 REF U-10~// 04-11-85 RUN #1 2972.0-7063.0 REF U-7~'-~ 03-1.9-85 RUN #1 3594.5-8179.5 REF A-13/~ 07-16-85 RUN #1 7649.5-8160.0 R-13'/ 07-27-85 RUN #1 3940.0-8578.0 REF R-12~ 07-20-85 RUN #1 3935.0-8277.5 REF .R-11'~'' 07-13-85 RUN 91 3810.0-7213.5 REF _R-10~''~ 07-06-~5 RUN #1 2991.0-8738.0 REF .R-9'~./ 06-28-85 RUN #1 399'1.5-8131.0 REF R-7// 06-04-~b RUN #1&3 0045.5-7103.0 kEF EACH) # 70436---REVISED ~ 70614---REVISED # 70613---REVISED # 70612---kEVI SED # 70505---RE-'VISED #70645 #70702 #70660 #70643 #70640 #70601 #70509 ECEIPT ACKNO%~LEDGED: DIS%'KIBUTION: ?AE D~I LLING W. PASHER · CURRIER L. JOHNSTON EXXON _/EVRON NOBIL PHILLIPS OIL & ~4 NSK CLEKK J. RATHMELL DATE: ~J~-~ ~i ........ iS ..... ~ ~--~,~ Cor~s. Corn~ sion STATE OF ALASKA*' SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Alaska Oil and Gas Conrervation Commission 3001 Porctm!~m Drive Anc]mrage, Alaska o~-~.~:):~1 RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy YES sent to sender ., No ~ STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~SSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Sta~e oE ,~daska Alas?~ Oil and G2z Conservation Comm~sion 3001 Porcupine Drive Anchorage, Alaska §9501 Receipt of the following material which was transmitted via ,,/~/~ / / is hereby acknowledged: ~UANTITY DESCRIPTION ~VI ~ ~ ~ ~ I- RECEIVED: DATED: Copy sent to sender YES NO ~ ARCO Alaska, Inc. Post Office Bb-x--l~0360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 6, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1R-7 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. not yet received the Well History (Completion Details). I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRUIO/LI05 Enclosure I have When I do, RFCE!VED 0 91985 Aiaska Oil & Gas Cons. Oommission Anchora. c:~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA '~_ AND GAS CONSERVATION CC~_~,~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , , 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :~. Name of operator 7. Permit Number ARCO Alaska, Inc, 85-72 : 3. Address 8. APl Number ' ~ P, 0, Box 100360, Anchorage, AK 99510 50- 029-21332 4. Location of well at surface 9. Unit or Lease Name 212' FNL, 222' FEL, Sec.19, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1344' FNL, 1117' FEL, See.19, T12N, R10E, UM 1R-7 At Total Depth 11. Field and Pool 1408' FNL, 1166' FEL, Sec.19, T12N, R10E, UM Kuparuk River Field · 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 84' RKBI ADL 25635 ALK 2568 i2. Date Spudded05/15/85 13. Date T.D. Reached06/04/85 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re ] 16' N°' °f C°mpleti°ns06/06/85* N/A feet MSL t 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ! 20. Depth where SSSV set [ 21. Thickness of Permafrost 7182'MD,6938'TVD 7070'MD,6828'TVD YES I~ NO [] 1913 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/$P/GR/Cal/LDT/CNL, GR/LSS, SHDT/GR, LDT/CNL/NGT, LDT/Mierolog/CR/Cal, DIL/SFL/LSS/GR, SHDT, DLL/GR, CBL/GR, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H~40 Surf 110' 24" 200 sx CS II 10-3/4" 45.5# K-55 Surf 2873' 13-1/2" 1000sx PP'E"& 200sx PF"C"&.50 sx PF "C"(top 7" 26.0# J~55 Surf 7160' 8-1/2" 700 sx Class "G" & 250 sx PF "C" ,, 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) 6846' - 6855' 3-1/2" 6790' 6594' & 6754' 6862' - 6889' w/4 spf, 90° phasing 6941' - 6948' 26. ACID, FRACTURE, CEMENTsOUEEZE,ETc. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6677' - 6703' w/12 spf, 120° phasing N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) " I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~i~ ... 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 chips. See Core Description attached to the Well Completion Report, dated 6/28/85. RECEIVED Alaska 0il & Gas Cons. Commission ob) Form 10-407 * NOTE: Tubing was run and well perforated 7/2/85. TEMP/WC68 Aliuhurage Submit in duplicate L Rev. 7-1-80 CONTINUED ON REVERSE SIDE ........ . .. . ~ - . .... . . ~_:. ~: ;: . .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . . . . Top Upper Sand 6622' 6384' N/A Base Upper Sand 6700' 6461' Top Lower Sand 6834' 6594, : Base Lower Sand 6947' 6706' · . . . · . . . 31. LIST OF ATTACHMENTS ' None · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item I' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ corhbustion. Item. 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).. Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUB. SURFACE DIRECTIONAL SURVEY F~UIDANCE F~ONTINUOUS F'~]OOL Company Well Name ATLANTIC RICHFIELD COMPANY 1R-7 (21~2' FNL, .22.2' FEL,_ S19~ T.%2N~ R10E_~ UM). Field/Location K,UPARU~, NORTH SLOP, E, ALASKA Job Reference No_, 70566 Lo~¢3ed By: KOKUSKA JUL 16 Alaska Oil & Gas Cons. Comm~'ssior' Anchorage Date · 23-JUNE-1985 Computed BY: CUDNE¥ GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, [NC, IR-7 KUPARUK SURVEY DATEt 6 d!IN 85 £NGINEERI D. KOZUSKA ~ETHODS OF COMPUTATION TOOL LOCATIONI TANGENTIAL- averaged deviation and a~lmuth INTERPOLAT~ONI LINEAR VERTICAL SECT~ONt HOR~Z, DXST, PROdECTED ONTO k TARGET AZIMUTH OF SOUTH 41DEG: 26 MIN WEST ARCO AbASKA~ TNC, NORTH SLOPE,ALASKA ' C~MPU?ATION DATE; 22"dUN-85 DATE DF SURVEy! $ dUN 85 KELbY BUSHING £bEVATIDN{ ENGINEER{ D, KOZUSKA INTERPOLATED VALUES FOR EVEN 100 FEET DF HEA~URED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION DEPTH DEPTH DEPTH DEG ~IN DEG 0 O0 100 O0 2O0 O0 300 O0 399 92 4q9 59 697 32 795 O? 891 62 '84.00 0 0 16.00 0 16 116.00 0 19 216 O0 0 47 ]15 92 3 21 41559 553 ~14 81 8 34 6 71311 ~2 11 O? 13 29 $07 62 16 3? 0 O0 100.00 200.00 300,00 400.00 ~00 nO 600~00 700,00 800.00 900,00 986 85 90~ 85 18 28 $ 36 42' W ~0 99730 ~0 4 ~ 39 21 W ~ 1090 59 22 ~ $ 4i 6 W 127483 2136' S 43 16 W 136~.55 18 58' S 44 55 W 3 1464,03 15 4] S 49 0 W ~ 1860.02 '3 9 S '2 2~ . ~3~ 165~,52 12 13 $ 55. 13 W 1756.32 1147 S 57 33 W lo00.00 1100.00 1081 1200.00 1174 1~00 00 1266 1400~00 1358 1500 00 1452 1600:00 1548 700.00 1,64~ ~800,00 174 1000.00 1840 2000 00 1938 2100 00 20]6 2200 O0 2135 2300 00 2400 00 2~00 00 2600 00 2700 00 2~00 00 2900 00 ]6 1854.36 10 59 $ 60 3]. w 66 1052.66 10 ll S 62 52 W 21 2n51.~1 9 9 S 64 8 W 14 2150.1.4 7 3~ S 63 51 W 40 2~49.40 6 34 ~ 64 8 W 80 234~.80 5 57 $ 66 1~ W 88 .~.,88 5 6 8 68 46 W 3 2647,53 4 2!, S 70 15 W 9 2747,29 3 48 S 65 41 W 06 2847.06 4 0 S 66 g W 82 2946.82 3 53 8 66 ? W 59 3046,59 3 55 S 66 10 W 36 3146.36 I 54 S 66 50 W 17 3~46,,.2 57 S 65 2' W ]345,88 3 56 S 641~ W 3445,66 3 47 S 63 4 W 43 3 49 ~ 62 ] W 2O 3 58 S 61 59 W 4 59 S 60 57 W ~234 ~333 2432 ~532 27~1 2831 3000.00 293~ 3100.00 303 3200.00 3130 3300.00 3230 3500 00 34 3600 O0 3529 3?0O O0 36~9 3900 O0 38?8 92 3744,92 PAGE 84.00 VERTICAL DOGbEG RECTANGULAR COORDINATES XORZZ, ADEPARTURB SECTION SEVERITY NORTH/~OUTH EAST/WEST DIST,, F~ET DEG/I00 FEET FEET FEET OEO n.00 -0.10 ,41 11,97 24.35 41.49 62.28 88.05 118.37 151,16 187,16 226 08 264 91 ~99 76 ]29 25 353 64 374 89 395 02 413 ~8 431 01 445 72 460 481 41 49 33 49~ 64 505,94 512.09 51~ 35 52463 53O 77 ~36 94 54314 549 56 555 2 562 ~0 568 32 ~75 44 0 00 0 23 0 18 2 0~ 3 38 2 18 2 3'/ ! 67 0 ti2 tm 2 ? 0 0 I O0 0 o 0 $9 I 39 0 89 081 I 04 1 O0 0 3] 0 26 0 ~6 0 44 0 41 0 32' 0 4S 0,00 N s 0 116 $ 4255 10 33 $ 19 33 S 32 93 S 50 36 S 72 06 $ 0.00 0.29 E 0,60 E 0.70 1.20 W 4 6.38 W 12 14.89 W 24 25.61 W 41 37,06 W 62 51,41W 88 96 67 S 122 66 S t49 268 69,36 W 89,45 W 80 S 113.10 W 187 60 S 139 30 W 226 5 8 63 w 265 S 230 5~ W 353 395 3'02 68 S 2n2 S 31 62 $ 33 25 S 34~ 16 $ 356 83 8 365 6O ~ 373 15 S 379 325 330 335 339 342. 345 348 368 3'/? O0 N 0 0 E 2'/ $ 69 38 E 74 $ 53 8 E 36 S 30 57 E 42 S 15 49 IN $ 31 42 W 40 $ 37 ~' W 56 S 38L . 63 $ 36 20 IN 52 S 35 30 W 118 98 S 35 39 w 151 536 6 W 90 S 37 3 W $3?5 W 97 S 39 15 W :37 ~ 39 55 W 67 S 40 40 W 89 $ 41 26 W 06 $ 42 13 W 22 S 404 O0 S 410 0l S 416 01S 423 6 S' 428 ~6 S 434 92 S 441 6W 413 :$ w 43! ,98 W 447 .83 W 461 W 71 w 49 11W 500 O1 W 508 42 W 514 385 66W 521 95 W 528 42 W 540 65 w 547 93 W 554 O0 W 560 88 W 567 82 w 573 42 W 581 94 $ 43 0 W 38 $ 4347 W $8 $ 44 32 W 13 S 45~ W 59 S 45 36 W 97 S 46 84 S 46 4t 50 S 4? If 94 ~ 4727 W 47 ~ 47 41 W 02 S 47 55 W 44 S 48 9 W S 48 ,'W ] S 48 47 W 68 S 4858 W ~2 S 4" 8 W ~0 S 49 16 W ~0 S 49 25 W ARCO ALASKA, INC. K~IPRRUK N~R?H SLOPE,ALASKa TRUE SUB-SEA ~OURSE MEASUR£D VER?ICAL VERTTCAb DEVTA? ON AZZMUTH DEPTH DEPTH DEPTH DEG H~N DEG MZN COMPUTATION DATE: 22-JUN-85 PAGE DATE OF SURVEY= 8 JUN. 85 KELLY BUSHING ELEVRTZONI ENGINEERI D. KOZUSKR INTERPOLATED VALUES FOR EVEN ~00 FEET Or NERSURED DEPTH VERTICAL DOGLEG AEC?ANGULAR COORDINATES HORI~. DEPARTURE 5~CTION SEVERiTy NORTH/SOUTH EAST/WEST DIS?',: AZIMUTH FEET DEG/IO0 FEET FEET FEET 4000 O0 3928 09 3844 09 9 52 4i00:00 4025 81 3941 81 1.4 9 3~ 4n3~ ~9 15 32 25 4134 25 18 23 78 422? 98 22 9 76 4319 76 24 29 76 440q,76 26 30 0 4a99.20 26 3~ 4 458~.74 26 23 40 467~.40 26 9 4200 O0 4122 4300:00 4218 4400 O0 4311 4~00:00 4403 4600 O0 ~493 4700:00 4583 4800.00 4692 4900.00 4762 24 32 25 41 48 ~5 35 85 24 31 90 21 50 50 18 36 79 16 59 66 15 35 5000.00 48.52 26 4768.~6 25 54 5100 O0 4942 25 485~.~5 95 5200 O0 5032 494~,24 ~5 48 5~00 O0 5122 503R,32 5400 O0 5212 5128 5~00 O0 ~302 521~,85 5600 O0 5394 531o,9o oo ~000 O0 5796 32 5692 ~2 14 11 6100 O0 5893 4? 598O:.9 13 20 6~00 00 5970 76 5886.76 13 34 6~00 O0 6067 97 5983,97 13 ~ 6400 O0 6165 64 6081.64 11 4~ 6263 84 6179.~4 O0 O0 6362 46 O0 656~ O0 6 O0 6659 9 53 54 627R.54 8 45 6377.45 8 21. 42 6476.42 8 15 36 6575.36 8 10 6500 6600 6900 6800 6900 8 12. B 12 $ 59 46 w 587.28 S 46 21 w 609.90 S 42 49 w 633.Rt $ 41 21W 662.22 ~ 38 20 W 697.~0 $ 35 28 W 736,60 $ 31 2~ W 779.69 S 31 10 W 823.?0 S 31 19 W 867.53 S 31 26 W 911.15 S 31 24 W 954.35 S 31 19 W 997 28 8 31 24 W 1040 23 S 31 29 w 108~ 97 $ ]1 34 W 1125 60 S ]1 14 W 1~69 ?9 S 28 33 W 1206 S ~6 ~8 W 1240 15 $ 22 16 W 1269 27 $ 18 47 W 1~95 $ *6 0 W 1319 ] 2 $ 15 33 W 1340 46 S 17 15 W 1361 37 S..~0 39 W 1383 02 $ 24 46 W 140, 29 $ 29 54 W 1421 52 S 35 12 W 1437 43 $ 36 19 W 1452.08' S 3~ ~g W 1466.37 $ 3 7.W 1480.72 S 39 19 W 1494.92 S ~9 19 W 1520,88 7000.00 6758,35 6674,35 7100.00 685~.33 6773,33 7182.00 69~ ,49 6854.49 5,37 4,00 0,96 5,24 1,94 4 18 0 52 0 32 o 0 o 1~ 1 41 86 0 8, 7O O6 ? 0 34 0,00 0,00 383 99 S 452 44 W 593 306 415 436 463 494 531 569 6O7 645 79 S 469 57 S 486 59 S 506 76 S 528 97 S 552 55 8 576 79 S 599 84 $ 6?2 65 $ 645 09 W 614 96 W 640 09 W 668 69 W 703 35 W 741 02 W 783 19 W 826 32 W 869 40 W 912 2 84,00 r~ 683 0B 8 668 28 W 955 61 $ 44 22 W 720 757 33 $ 690 58 $ 713 61 8 736 0 S 758 , S 781 85 S 800 90 $ 817 ~t S 829 96 $ 840 95 W 998 65 W 1040 28 W 1083 90 W 1125 9 W 1167 5 W 1206 {, W 1240 ~6 W 1269 07 W 1296 14 S 43 48 W S 43 17 W 29 S 42 49 W 76 $ 42 23 N 85 S 41 59 W 04' S 41 36 W t6 S 41 12 W 4 S .40, 49 W 07 S 40 24 W 10'11 103 105~ 1078 1098 1115 I 28 1~40 1152 1164 48 8 847 43 W 1319 56 S 39 57 N 33 $ 853 79 W 1341 19 S 39 32 W 860 w t3a~'~ 6 38 48 W 4 13 4 S S 867 51 8 876 32 S 884 84 S 893 72 S 901 8 S 910 2 S 918 w 02 W 1405 53 w 1423 24 w 1439 93 w 1454 W 1468 44 S 39 9 W 04 S 38 34W 49 S 38 25 W 50 S 38 2~ ' 20 $ 38 tL 96 S 6 W 1175,44 S 1186,48 S 1195,5) 927,33 W W 943, 1497,19 S 38 16 W 1511,47 S 38 16 W 1523,17 S 38 17 W 42 $ 49 40 W 40 $ 49 46 W 8 $ 49 31 W 9 S .49 12 W 21 S 48 44 W 68 S 48~ W 8O S 4? ~ 92 S'45 40 W 91 S 44 59 W TRUE SU~-SEA COURSE MEASURED VERTICAL V£RTICAb DEVIATION A~IMU?H DEPTH DEPTH DEPTH DEG MIN D£G 0.00 1000.00 986 2000 O0 1938 3nO0:O0 29~1 4000,00 39?8 5000.00 4852 6000.00 5776 7000.00 6758 718~,00 6938 CDMPUTATION DATE: 22-JUN-g5 PAGE DATE OF SURVEY1 8 JUN 85 KELbY BUSHTNG EbEVATIDNI ENGTNEERI D. KOZUSKA. INTERPObATED VAbUE$ FOR EVEN 1000 FEET OF MEASURED DEPT VERTTCAb DOGbEG RECTANGULAR COOrDiNATES HORlZ. DEPARTURE SECTION SEVERXTY NORTH/~OUTH EAST/WEST DIST,:AZ~AUTH FEET DEG/iO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 36 4? W 118,37 $ 60 33 W 413,78 S 66 9 W 518,15 $ 59 46 W 587.25 S ~1 24 W 954.35 ~ ~6 0 W 1319.12 ~ 39 19 W 1494.92 S 39 19 W 1520.88 0 O0 '84.00 0 85 90~,85 18 28 36 1954.'6 10 59 06 2847.06 4 0 O9 3844,09 9 5~ 26 4768,26 25 54 32 569~,~2 14 11 35 6674,~5 8 12 49 6854,49 8 0 O0 0 93 0 82 0 33' 5 37 012 1 56 0 91 0 O0 0 O0 N 96 302 35 10~! 1175 1195 0 O0 E 67 $ 69 36 W 118 68 $ 282 36 W 413 O0 S 395 W 66 52! 99 8 452 44 W 593 08 S 668,28 W 955 48 $ 847 ~3 W 1319 44 $ 927 33 W 1497 53 S 943 79 W 1523 84, O0 FT 0 O0 N 0 0 g ARCO ALASKA, INC, KUPRRUK NORTH SLOPE,ALASKA TRUE SUB-SE& COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MTN DKG MIN 0,00 84,00 184,00 284,OO 3B4 06 484,34 585.03 686,44 788,63 892,06 0 O0 84 O0 184 O0 284 O0 384 O0 484 O0 584 O0 684 O0 784 O0 884 O0 COHPUTATZON DATK: 22-jUN-85 PAGE DATE' OF 8URV£¥: 8 JUN: 85 KELLY BUSHXNG EbEVATIDNI ENGIN~ERI D, KOZUSKA: INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTAHGULAR COORDINATES HORIZ, DEPARTURE SFCTION SEVERITY NORTH/SOUTH ERST/WEST DIST,. AZIMUTH FEET DEG/{O0 FE£T · FEET FEET DEG MIN N 0 0 E 0.00 ~ 60 51 ~ -0.09 S 28 1. E -0,09 $ 0 16 W 0,~7 $ 35 42 w , 309 S 41 5~ W 10,41. S 43 16 W 2~,20 S 35 4~ w 38.92 w S 34 4? W 85,83 12 1637 1740 1842 1044 996.99 1802.87 lOR4 16 1184 87 12~4 O0 1384 15 1484 ~8 m584 09 1684 43 1784 59 1884 -84,00 '0 0 0,00 0 15 100 O0 0 17 2O0 O0 0 35 100 O0 2 59 400 O0 5 2O 0 0 O0 8 4 O0 O0 10 46 70O O0 13 7 800 O0 16 2) S 36 42 w S 39 27 W S 42 12 W S 34 w S461 1W S ~0 23 W 853 46 W S 55 1~ w S 58 59 W 2046 2i48 2249 2]50 2450 2551 2651 2752 2852 2952 984 O0 900,00 18 26 O0 1000,00 20 8 O0 1100,00 22 1~ O0 1200.00 73 25 O0 l]O0,O0 ~0 58 O0 1400.00 17 46 O0 1500.00 14 38 O0 1600.00 i2 37 O0 1700.00 12 ~ O0 1800,00 11 2~ O0 tqO0 O0 lO ]" ~ 6 44 W oo 2000:00 s 61 w . , 6 50 S 63 ] W O0 O0 8 O0 ~I~: 6 1 S 65 16 W 00 5 30 8 66 35 w O0 -;2500 O0 5 i? S 65 32 w O0 2600.00 4 48 S 7 15 W O0 0,00 3 5 S O0 ~I° 3' 6~ 50 W 00,00 3 56' ~ 65 41 W 47 1984 08 2084 ]8 2184 ~6 2284 2484 91 25~4 31 2684 60 ~?~4 83 2884 3 57 S 65 42 W 3 52 $ 66 8 W 3 54 S 67 32 W 3 55 S 65 34 W 4 I S 64 11W 3 53 S 63 30 W 3 49 $ 62 41 W 3 5~2 S 61 34 W 4 20 S 60 4~ W 7 30 S 61 20 W 3053 07 29~4 O0 2900.00 3153 30 3084 O0 3000,00 3253 53 31~4 O0 3100,00 3353 77 ]284 O0 3200 O0 3454 O0 3384 O0 3300:00 3554,94 3484,00 3400 O0 3654.47 358!!00 3500:00 3754,69 368 O0 3600,00 3854,93 378 O0 3700,00 3955,39 388 O0 3800,00 117 42 152 13 190 98 233 62 17 338,95 36],38 38 ,52 403,60 421'02 43 ,82 47~,57 ,04 515.34 52! 70 89 540,26 546.62 552,98 559,17 565 580.00 0,00 0,28 0 25 1 14 223 2 73 3 6 2 3 O! 3 O8 0 95 2 36 I 67 0 92 4 $ 28 0 6! 1 O0 0 2'/ 0 18 0 5 0 ?~ 0 5~ 0 8 0 24 0 6 o 0'21 3 0,00 N 0058 0378 0995 3535 9188 17 75S ~0 61 ~ 48 70 23 S 95 90 S ooor, 0 19 E 0 56 E 0q. 1£ 067 W 5 34 W i3 42 W 24 13 w 35 66 w 50 ,14 W 59 86 · 84,00 r~ 123 152 184 214 239 258 297 306 315 322 35 366 369 372 376 380 42 $ 90 64 $ 69. $ 197 92 $ 21.8. 59 S 237 S 273 91 S 168 O7 w 439 332 49 w 467 .05 S 342 S 361 $ 369 94 ~ 376 63 S 382 84 W 47~ 39 w 48 09 W 496 40 W 505 53 W 51'2 65 W 518 06 W 152 78 S 36 7 W 67 W 191 51 S 37 9 W 37 W 234 O' S38 5 W 35 W 274.97 $ 38 48 W 24 W 3t0 35 S 39 27 W 85 W 339.;02 S 40 1,2 W ,65 W 362,39 S 40 58 W 4 8 W 383,53 S 4'1 46 W 09 W 403,68 8 42 34 W i $ 43 22 W $ 44 9 W $ 44'51 W 09 $ 45. 23 W 98 $ 45 49 W S 46 3~ 02 S 47 2 W O0 S 47 33 $ 47 ~4 W 50 S 389 02 W 524 97 $ 47 49 W 26 S 395 23 W '5~ 99 S 401 50 W 5 71 943~ 8 48 t6 W 70 S 407 63 $ 414 64 S 420 66 S 426 80 S 432 17 $ 438 ~i S 446 77 W 544 O5 W 551 25 W 557 18 W 564 09 W 570 30 W 577 5i W 586 $ 48 2 W 41 S 48 30 W 06 S 48 42 W 71 $ 48 53 W 16' 8 49 3 W 69 S 49 12 59 S 49 21 W ~8 $ 49 32 ~ 68 79 W 1t8 02 S 35 39 W K~P~RUK COMPUTATION DATE= 22-JUN-g5 DA?£ Or SURVey: 8 JUN_, 85 KEbI.Y BUSHZNG EbF, VATIONI ENGINEERS P. KOZUSKA. INTERPOLATED VA[,UE~ F~R EVEN !00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTTCAb DEV)ATION A~IMUTH DEPTH DEPTH DEPTH DEG M)N D£G MIN O0 3900.00 12 24 O0 4000.00 15 10 O0 4100.00 16 49 O0 4200.00 21 29 OO 430o,00 23 43 O0 4400.00 26 2~ O0 4500,00 26 30 00 4600,00 2621 O0 4700.00 26 5 O0 4800,00 25 51 057 O0 398i 40,: 4264 09 4184 4370:04 4284 447g 4384 448 4?00 89 4584 4812 57 4684 492406 4784 503528 48m4 5146 40 4984 O0 4900.00 25 51 5257 46 5084 O0 5000.00 25 42 O0 5100.00 25 37 O0 5200,00 25 0 O0 5)00.00 22 9 O0 5400.00 18 47 O0 5500 O0 '6 59 0000 55~v-!00 14 6 ~ O0 1530 O0 5800 O0 13 17 5368 41 5184 5479 20 52~4 5588 24 5384 5695 24 5484 5800 22 5584 5q04.50 5684 6007,91 57~4 6110.82 5884 O0 590000 O06000i00 O0 0 O0 oo° 00.00 O0 6100.00 O0 6400.00 O0 6500.00 O0 6600.00 O0 6700.00 O0 6800.00 6R13 5984 18 75 61R4 65,20 45 6284 6621 ~0 6384 6?22 8 6~84 6823 84 6524 6q24~9 66m4 7025.81 6784 7126,95 6884 7182.00 6938.49 6854.49 S 5t 4 W S 4 8 W S 42 9 w 839 2 w $363! w 831 32 w S 3 lOW 8 31 20 W $ 3 6 w S 1741 w 1364 $ ~118 W 1386 $ 25 32 W 1406 S 31 15 w 1424 $ 35 51w 1440 8 16 S 36 4 w 14 59 8 16, $ 35 15 W 1469 8 16 8 36 56 W 1484 8 1~ S 39 19 W 1498 8 12 $ 39 19 W 1513 VERTTCAT.., r)OC;L,~G R~C?ANGUbAR COORI:)INA?E$ HORZZ. DEPARTURE nEC,/ O0 597.97 5 6~ 390 15 S 461 61 W 604 40 $ 49 47 W 623,27 ! O1 407 85 $ 4?9.'78 W 629 ~l S 49 37 W 651,44 3 54 428 56 S 498 ~0 W 65~ !70 S 49 20 W 686.32 2 96 4'55 O1 $ 5~1: 4,u W 69 20 S 48 54 W ?2?,?7 3 4? 48? ~8 IS 547 14 W 733 O1 S 48 i6 W ??4,89 0 '.?~ 5~? )8 $ 5?349 W ??9 ii S 4? 23 W 824.09 0 32 5?0 13 8 599 40 W 827 24 S 46 7' W 873.03 0 18 612 62 $ 625 22 W 875 33 $ 451~ W 92,..59 028 65469 ,q 65092 W 923 21 $ 4450 W 969.53 0 22 696 24 S 676 30 W 970 63 $ 44 10 W 026 ~164 S 70148 W 101793 $ 4333 W 0 2'1 8? $ 726 6S W 1065 2! $ 4:{ 0 W 0 64 10 8129 088 11~)'~91602, 8. $~8~6i .,,6 wW 136541 8383946 W 76 0 62 1155 %4 8 912 30 W 1471 8 ., w, ,,, s . 0.00 1295,5] S 94~,~9 W 1523.~7 8 12 $ 39 19 W 1520.88 PAGE 5 84,00 Fl S ti 22 W lO1~.23 S 3t I~ w 1064.80 S 3 W 1112,14 8 31 35 W 1159 13 $ 28 43 W 1201 S 26 45 W 12 8 $ 31 W 1 296 94 8 15 53 W 1320 85 S ~5 36 W 1342 68 ARCO AbASKA, TNC, KUPARUK NORTH SLOPE,ALASKA MARKER ToP UPPER SAND BASE UPPER SAND TOP b~R SAND BASE LOWER SAND P~TD TD C~MPUTATION DATEI 22-dUN-85 INTERPOLATED VALUeS,FOR CHOSEN HORIZONS MEASURED DEPTH BEt, OW KB FRO~ KB 6622 On 6384,29 6700!00 6461.45 6834 O0 6594,06 6947 O0 6705,88 7070,00 6827,63 7182.00 6938.49 PAGE 6 DATE OF' SURVE¥~ 8 JUN. 85 KELLY BUSHTNG EbEVAT~DNI 84,00 F~ ENG~N~ER$ D, KOZUSKA SURFACE LOCATION AT ORIGIN-- 212' FNE,222' rE[, SEC 19,TI2N.RlOE.UM TVD RECTANGULAR COORDTNATE$ SUB-SEA NORTH/SOUTH' EAST/WEST 6300 6377 6510 6621 6743 6854 29 895 , 901 06 1~56,34 $ 91~ 88 11.69.54 $ 922 63 1183.~7 $93 9433 49 1~95.53 $ i5 W 93 W 15 W 73 **( ARCO AbASKA, THC, 1R-7 NORTH SLOPE,ALASKA ~AR~ER TAP UPPER SAND BASF UPPER SAND TOP bOWeR SAND BASF t, OWER SAND COMPUTATION DATE; 22-jUN-S5 MEASURED OEPTH BEEOW KB 66?2 O0 6700 O0 6834 O0 6947 O0 7070 O0 7182 O0 PAGE DATE OF BURVE¥~ 8 JUN 85 KEEEY BUSHING EEEVATIONI ENGINEERI De KOZUSKA SUMMARY *$$**~*$~* ORIGIN~ 212" FNb,222~ TVD FROM KB SUB-SEA 6384.29 6300.2g 6461.45 6377.45 6594.06 65~0.06 6705.:~ 6621.88 6827. 6743,~3 6938.49 6854. 9 84.00 1131.51 1140.72 $ 1156.34 $' 1169.54 1183.i7 $ 1195.53 89.5,15 901..93 W 913,15 W 922,73 W 933,66 (' 943,79 FINAL WELb LOCATION AT TD~ TRUE SUB-SEA M~ASURED VERTICAL VERTICAb DEPTH DEPTH DEPTH 7182.00 ~938.49 6854.40 HOR)ZONTAb DEPARTURE DISTANCE' AZIMUTH FEET DEG MIN 1523..~7 S 38 17 W , WELL NAME: 1 R- 7 SURFACE LOC~TION: ~ ' FNL, 222' FEL, S19, T12N, RI£~_~UM VERTICAL PROJECTION - ] 000 -SOO 0 0 SOO ' 1000 !.c;O0 ~000 2S00 @000 4I .... ~...,;....: ...... 1-4_~...,....~....4_4-.-,-.;...]--~...~....~...;.-~.;~~ ~ ~].:::: ~1-~4~-~ _~J._~_._~..~.~_.L.~..~ ...~-~.~-~.. 221 :.;...;-;-~..L~...~4...~_,~.~..~-L~..~.~4 ....... ;-~.~~- ~ ~ ~ ~.~.~--~..~-,~..~.4...~-L.~.;-~..~-...;-~.4-~-~- .~.i~~- ~.4-~...~..-k.;--4-;..-~.--+4-~..-M-~..k~4.-.. kk~..~.4-4-~ ~4+.~4~+.-.-++.~.+.+-~-~ ~ ~..4...~ ~4-..~.~4-,-~-~.~..M4.~-. ~-4-~.~-4.-~..44.~ -f--f:f--f-i---?-f-h~ ..... f'~-'-f~--~-f-h: :'~-~-~-~d'- ~-~ hhh~'h-~d-f"h?'-H-h-~f--?"'h"~'~'~-"f+-hf-f'f-d'~"~"f'f'h~5 ~...~,..~-~.f..?..~..?..., ..... ?..~...?_?.~...,r~...,,.~ ....... ~..?..?,.. ..... t..~...??......T..?,...t.....~...?..?..?... ,-~-.~.-?.t..~..~-?-.~ ,.~.~-t-~.?--~-.??-.~.-: ...?~-~.?-}...~.~.?.- ~.,~.~..?..?.. ~...~-.~..4.. 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(-'7'"; -*'-T"~-T" "'?T'-r"7-'~""~"T'U'*"I'"'("-%~Y-T-'?'?'''t~'-s '?'I" :' :"?-:'T"?'":'"~'":".'-?r'~7'-:"T'-~"7-T-':' ' m"-:":'":"-r~":'v': ~ ..... :". - ~ ": - ~ - :..:...~...~.2 ~ . . ~ i :_:.._i...}..L.:..:...:..~...:..:....:...:..:...; .; ..... "','"','"','"','",'"','"','",'", ....... ,"',"",'",'",'"','",'"','"', ....... :'":": ~ ~":": : {:: ~ ~ ~ ~ : ~ ~ t ' ' · - · ~ i . '; ....... '"';" ~' '~ ...... ~ ; * ; ; ; ": I ; ~.~...;..4...~...; ........... { .................................. ~-.~.~....-~-.~.... ............... PROJECTION ON VERTICAL PLANE 221. - 41. SCPJ-EO IN VERTICAL OEPTH$ HORIZ SCALE = I/SO0 IN/FT · I"q "-t n rrl I! WELL NAME: 1 R- 7 SURFACE LOCATION: ' FNL, 222' FEL, S19, Ti'2N, Ri, ~, UM HORIZONT_~ PROJECTION 400 2OO -200 -600 -8OO -Iooo SOUTH - ! 200 · R£F O00070S6~ $C~£ = 1/~00 IN/FT - 1200 - 1000 -800 -800 -400 -200 0 200 400 NEST ERST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~E~IATOR, WELn N~fg J[ND NUMBER Reports and Materials to be received by: ~-- ~ Date Required Date ReceiVed Remarks Completion Report Samples" /.s _~., _, Registered Survey Plat [~', ,~'X ~r''~*~' dK ,nc~,na,~on Surve~ ,~. Directional Survey~ Dr~'ll Stem 'Test Reports P roduction?~---. Test Reports ~ __~~. , ,. ~ - Digitized Data yes ARCO Alaska, Inc. Post Office F..~,..J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 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 following wells at the Kuparuk River Field: Well Action Date Performed 1G-2 Acidize 7/12/85 1 R-5 Fracture 7/16/85 1 R-6 Fractu re 7 / 19 / 85 1R-7 Fracture 7/17/85 1R-8 Fracture 7/17/85 2D-7 Acidize 6/21/85 2D-8 Acidize 6/21/85 2H-3 Acidize 6/21/85 2H-13 Fracture 7/23/85 2 X-5 Perforate 7 / 23 / 85 3B-1 Acidize 7/22/85 notices on the )' / .? ? If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. RECEIVED o Z985 ~la~a On .. ~,Gas Cons. Commission '~nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany O~ STATE OF ALASKA O~ ALASKA AND GAS CONSERVATION C ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, I NC. 85-72 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 332 4. Location of Well SURFACE LOCAT I ON: 212 ' T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 84 ' ( RKB ) FNL, 222' FEL, SEC. 19, 6. Lease Designati~n and Serial No. ADL 25635, ALK 2568 12. 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1R-7 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER O I L 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 [] Stimu [etlon ~ 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 July 17, 1985, the "A" sands of Kuparuk well 1R-7 were hydraulically fractured and propped to improve production. treatment consisted of 271 BBLS of gelled diesel as pad and fluid and 1000 LBS of 100 mesh and 14,280 LBS of 20/40 sand proppant. 58 BBLS of gelled diesel was used as a flush. The carrying as Prior to pumping, equipment and lines were tested to 6500 psi. t ECEI VED 41aska 0~ Co.,. 'Chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~4~4. ~ Tit~e KUPARUK The space below for Commission use OPERATIONS COORD I NATOR Conditions of Approval, if any: 7 I~185 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 '"NE~ PROJ~TS E~INEERL~ TRANSMITTED EEtEMITN ARE TEE FOLLOWINg: PT-FASE NOTE: BL - BLUELINE, S - SEPIA, F - FTtM, T - ~A,~E, PC - ?EOTOC0,.~f RECEIPT ACKNO%rLEDGED: PLEASE P~ETURN RECEIPT TO: ~//ARCO ALASKA, INC. -.~',-'_, .,-~ P. 0. BOX 100360 ~:NCP, ORAGE, AK 995.10 · '-.~.~ ~' TO: FP,.O14: L. K. S-~"ZT~/~. $. '~~ TKAN$1¢~:~ EEP~~ AKE TEE FOI~O~rING: NOTE: BL - BLAINE, $ - EEPI.A, PILE, T - TAPE, ?¢ - PEOTOCOF~ '"':~a 0ii & Gas Cons. Comrnissior,, AtTch, Orann AT0/507 '~'~ ARCO Alaska, Inc. Post Office B6~"'~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1R-7 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for 1R-7. The tubing details will be submitted when the well is completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L56 Enclosures RECEIVED ._ ~-~ ,-~. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALASKI,~_~tL AND GAS CONSERVATION C{._/MlSSiON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [-I SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-72 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21332 , 4. Location of well at surface - 'T-~---'" -LIONS~.[, A[ 9. Unit or Lease Name 212' FNL, 222' FEL, Sec.19, T12N, R10E, UN ' . Kuparuk River Unft At Top Producing Interval i VERIFIable:) 10. Well Number 13M+' FNL, 1117' FEL, Sec.19, T12N, R10E, UN J[urf---J;/ 1R-7 At Total Depth j J)~._.~ _ 11. Field and Pool 1~,08' FNL, 1166' FEL, Sec.19, T12N, R10E, UN Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 8~.' RKBJ ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 05/15/85 06/04/85 06/06/85J N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7182'MD,6938'TVD 7070'HD,6828'TVD YES I~X NO []I N/A feet MD 1600' (Approx) 22. Type Electric or Other Logs Run LDT/CNL/SP/DIL/Hicrolog, DIL/SFL/LSS/GR~ SHDT~ DLL/CR (see attached sheet) Gyro ((;CT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 16" 62.5# H-40 Surf 110' 24,, 200 sx CS Il ~ 10-3/4" 45.5# K-SS Surf 2873' 13-1/2" 1000sx PF"E"& 200sz PF"C~'& 50 sx PF~"C"(top 7" 26.0# J-55 Surf 7160' 8-1/2" 700 sx Class "G" & 250 sx PF "C" __ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing' gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD m~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA - , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips See Core Description attached to the Well Completion Report, dated 6/28/85.RI .EIVED J U'k 1 6 1985 .~l~s?.a Oh & Gas Cons. Commission Anchorage ob, Form 10~107 GRU10/WC17 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30.' .... GEOLOGIC MARK, ERS ' FORMATION TESTS ' NAME -- Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper 5and 6622' 6384' N/A Base Upper Sand 6700' 6461' Top Lower 5and 6834' 6594' Base Lower Sand 6947' 6706' . 31. LIST OF ATTACHMENTS 1~ Gyroscopic Survey (2 conies} - 32. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed & (~ ~ Title Associate Engineer Date '7-/~°~5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item:21: Indicate Whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ATTACHMENT Well Completion or Recompletion Report and Log 1R-7 (cont'd) Item #22: DIL/SFL/$P/GR/Cal/LDT/CNL GR/LSS SHDT/GR DIL/GR LDT/CNL/NGT HRP SAT/VSP (shot VSP intervals every 40' f/3830' - 1750') Ran sidewall cores ~ 26 points f/3463' - 3449'WLM JMM2/WC49b:tw 06/24/85 , STATE OF ALASKA ALASKA Crrr_ AND GAS CONSERVATION CO'~_.vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-72 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21332 212' UM 4. Location of Well at surface FNL, 222' FEL, Sec.19, T12N, RIOE, 6. Lease Designation and Serial No. ADL 25635 ALK 2568 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 9· Unit or Lease Name Kuparuk River Unit 10. Well No. 1R-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. June ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1400 hrs, 5/15/85. Drld 13-1/2" hole to 2887'. Ran logs. Ran, cmtd, & tstd 10-3/4" csg. Drld 8-1/2" hole to 3005'. Cored f/3005'-3136'. Continued drlg 8-1/2" hole f/3136'-3440' . Cored f/3440'-3785'. Continued drlg 8-1/2" hole f/3785'-3885'. Ran logs. Continued drlg 8-1/2" hole to 6607'. Cored 6607' - 6982'. Continued drlg 8-1/2" hole to 7182'TD (6/4/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7070'. Secured well & RR ~ 2115 hrs, 6/6/85. Arctic packed on 6/15/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 110' Cmtd w/200 sx CS' II 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe ~ 2873'. Cmtd w/1000 sx PF "E" & 200 sx PF "C". Performed top job w/50 sx Permafrost C. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 7160'. Cmtd w/700 sx Class "G" & 250 sx PF "C". 14. Coring resume and brief description Core #1 f/3005' - 3033'; cut 28', Core #2 f/3033' - 3063'; cut 30', Core #3 f/3063' - 3093'; cut 30', Core #4 f/3093' - 3105'; cut 12', Core #5 f/3106' - 3136'; cut 30', recovered 28' recovered 30' recovered 30' recovered 11.6' recovered 30' (cont'd on attached sheet) 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/LDT/CNL f/2888'WLH - surface GR/LSS f/2888'WLN - surface SHDT/GR f/2888'WLN - surface LDT/Nicrolog/GR/Cal f/7166' - 2866' DIL/SFL/LSS/CR f/7100' - 2866' SHDT f/7100' - 2864'WLM DLL/GR f/3950' - 2866'WLM (cont'd on attached sheet) 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED $ ~ ~ TITLE Associate Engineer DATE '7~/~' NOTE--Report~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 GRU1 0/MR02 Submit in duplicate Monthly Report of Drilling and Workover Operations June, 1985 1R-7 (cont'd) Item 14: Core #6 f/3440' - 3449'; cut 9', recovered 9' Core #7 f/3449' - 3451'; cut 2', Core #8 f/3451' - 3463'; cut 17', recovered 1' Core #9 f/3463' - 3493'; cut 30', recovered 31' Core #10 f/9493' - 3523'; cut 30', recovered 29' Core #11 f/3523' - 3553'; out 30 Core #12 f/3553 - 3582'; cut 29 Core #13 f/3582 - 3613'; cut 31 Core #14 f/3613 - 3644'; cut 31 Core #15 f/3644 - 3674'; cut 30 Core #16 f/3674 - 3702'; cut 28 , recovered 28' , recovered 30' , recovered 31' , recovered 31' , recovered 28' , recovered 30' Core #17 f/3702 Core #18 f/3725 Core #19 f/3755 Core #20 f/6607 Core #21 f/6637 Core #22 f/6695 Core #23 f/6728 Core #24 f/6782 Core #25 f/6842 Core #26 f/6892 - 3725'; cut 23 , recovered 24' - 3755'; cut 30', recovered 28' - 3785'; cut 30', recovered 31' - 6637'; cut 30', recovered 25.5' - 6695'; cut 58', recovered 60.5' - 6728'; cut 33', recovered 27.5' - 6782'; cut 54', .... - 6842'; cut 60', recovered 50' - 6892'; cut 50', recovered 48' - 6952'; cut 60', recovered 60.5' Core #27 f/6952 - 6982'; cut 30', recovered 27.5' Item 15: DIL/GR f/3874'WLM - 2868'WLM LDT/CNL/NGT f/3874'WLM - 2668'WLM HRP f/3874'WLM - 2868'WLM SAT/VSP shoot VSP intervals every 40' f/3830' - 1750' (Ran sidewall core ~ 26 points f/3463' - 3449'WLM) Alaska Oil & [~as Cons. Commission Anchorage ARCO Alaska, Inc. Post Office BoxY0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 3, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-7 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1R-7. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted When the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L51 Enclosure 'EIVED JUL 0 8 1985 -Ji~ ~ ;~a.~ Coils. COffll'QiSS|Ol'l Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK~_~.,.~ AND GAS CONSERVATION '~(~.~AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-72 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21332 4. Location of well at surface 9. Unit or Lease Name 212' FNL, 222' FEL, Sec.19, T12N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1R-7 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 84' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/15/85 06/04/85 06/06/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+IR/D) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7182'MD 7070'ND YES [] NO I-~XI N/A feet MD 1600' (Approx) 22. Type Electric or Other Logs Run LDT/CNL/SP/DI L/Nicrolog, D I L/SFL/LSS/GR, SHDT, DLL/GR (see attached sheet) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD . CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" 62.5# H-40 Surf 110' 24" 200 sx CS II 10-3/4" 45.5# K-55 Surf 2873' 13-1/2" 1000sx PF"E"& 200sx PF'~C''& 50 sx PF "C"(top 7" 26.0# J-55 Surf 7160' 8-1/2" 700 sx Class "G" & 250 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Description. RECEIVED J U L 0 8 aias~,,a 0JJ & Gas Cons. Commission Anchorage Form 10407 JMM2/WC49 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '" '"'- ':'"'(~EOLOGiOMARKERS"' '~' :' ~ .i:" ~' ,::~-.: i '--i~ ':.; :.: -i-' i_i';' '? '~' ":: :!:: ._" ~.;.~ :'"'-~FORMAT. i0N:~i:ST~'" .... ' ¢"' :--' '"", :...?:'i. :-~ ::~:: . . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted w~n gyro is run. N/A - · · .: : · : 31. LIST OF ATTACHMENTS Attachment to Item #22; Core Description · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~J ~ ~ Title- Associate Engineer Date INSTRUCTIONS General' This form is designed-for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ATTACHMENT Well Completion or Recompletion Report and Log 1R-7 (¢ont'd) Item #22: DIL/SFL/SP/GR/Cal/LDT/CNL GR/LSS SHDT/GR DIL/GR LDT/CNL/NGT HRP SAT/VSP (shot VSP intervals every 40' f/3830' - 1750') Ran sidewall cores ~ 26 points f/346~' - 3449'WLM JMM2/WC49b:tw 06/24/85 RECEIVED J U L 0 8 1985 Alaska Oil & Gas Cons. Commission Anchorage 1R-7 CORE DESCRIPTION Core 20 6607' - 6637' Core 21 6637' - 6695' Core 22 6695 - 6728 Core 23 6728 - 6782 Core 24 6782 - 6842 Core 25 6842 - 6892 Core 26 6892 - 6952 Core 27 6952 - 6982 cut 30', rec. 25-1/2' cut 58', rec. 60-1/2' cut 32', rec. 27-1/2' cut 55, rec. 47' cut 60', rec. 50' cut 50', rec. 48-1/2' cut 60', rec. 60-1/2' cut 30', rec. 27-1/2' Shale & siltstone Siltstone, shale, sandstone Sandstone, siltstone Siltstone & sandstone Siltstone & shale Sandstone & shale Sandstone & shale Sandstone & shale GRU9/CD01: tw 06/13/85 TO: DATE: krZLL PgCEIFT ACK]~OkTEDG~ · PL=_ASE R=--'Tb-PO~ RECr~'v ~0 0 J~J~_ ~C ATTN' PATSY S. ~ BtZ~ m~, ATO/50? P. O. BOX 100360 ~O~GE, ~ 995!0 ARCO Alaska, Inc. Post Office B~.....J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the following wells: 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L56 Enclosures RECEIVED JUN 1 ]g/]5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .. - , · STATE OFALASKA - ALASKA C~r¢_ AND GAS CONSERVATION CO~.wllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well ~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-72 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21332 9. Unit or Lease Na~e 212' 4. Location of Well at surface FNL, 222' FEL, Sec.19, T12N, RIOE, UM 6. Lease Designation and Serial No. ADL 25635 ALK 2568 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB Kuparuk River Unit 10. Well No. 1R-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1400 hrs, 5/15/85. Drld 13-1/2" hole to 2887'. Ran logs. Ran· cmtd· & tstd 10-3/4" csg. Drld 8-1/2" hole to 3005'. Cored f/3005'-3136'. Continued drlg 8-1/2" hole f/3136'-3440'. Cored f/3440'-3785'. Continued drlg 8-1/2" hole f/3785'-3885'. Ran logs. Continued drlg 8-1/2" hole to 6607'° Cored 6607'-6842' as of 5/31/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set @ 110' Cmtd w/200 sx CS !1 · · · · 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe ~ 2873'. Cmtd w/lO00 sx PF "E" & 200 sx Performed top job w/50 sx Permafrost C. PF "C" . 14. Coring resume and brief description Core #1 f/3005' - 3033'; cut 28', recovered 28' Core #2 f/3033' - 3063'; cut 30', recovered 30' Core #3 f/3063' - 3093'; cut 30', recovered 30' Core #4 f/3093' - 3105'; cut 12', recovered 11.6' Core #5 f/3106' - 3136'; cut 30', recovered 30' (cont'd on attached sheet) 15. Logs DIL/ 'GR/L SHDT run and depth where run SFL/SP/GR/Cal/LDT/CNL f/2888'WLM - surface SS f/2888'WLM - surface /GR f/2888'WLM - surface (cont'd on attached sheet) 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report ~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 TEMP/MR58 Submit in duplicate Monthly Report of Drilling and Workover operations 1R-7 (cont'd) Item 14: Core #6 f/3440' - 3449'; cut 9', recovered 9' Core #7 f/3449' - 3451'; cut 2', .... Core #8 f/3451' - 3463'; cut 17', recovered 1' Core #9 f/3463' - 3493'; cut 30', recovered 31' Core #10 f/9493' - 3523~; cut 30', recovered 29' Core #11 f/3523' - 3553'; cut 30', recovered 28' Core #12 f/3553' - 3582'; cut 29', recovered 30' Core #13 f/3582' - 3613'; cut 31', recovered 31' Core #14 f/3613' - 3644'; cut 31', recovered 31' Core #15 f/3644' - 3674'; cut 30', recovered 28' Core #16 f/3674' - 3702'; cut 28', recovered 30' Core #17 f/3702' - 3725'; cut 23', recovered 24' Core #18 f/3725' - 3755'; cut 30', recovered 28' Core #19 f/3755' - 3785'; cut 30', recovered 31' Core #20 f/6607' - 6637'; cut 30', recovered 25.5' Core #21 f/6637' - 6695'; cut 58', recovered 60.5' Core #22 f/6695' - 6728'; cut 33', recovered 27.5' Core #23 f/6728' - 6782'; cut 54', .... Core #24 f/6782' - 6842'; cut 60', .... Item 15: DIL/GR f/3874'WLM - 2868'WLM LDT/CNL/NGT f/3874'WLM - 2668'WLM HRP f/3874'WLM - 2868'WLM SAT/VSP shoot VSP intervals every 40' f/3830' - 1750' (Ran sidewall core @ 26 points f/3463' - 3449'WLM) ARCO Alaska, In~r Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 1R Pad Wells 1-16 _ Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L115 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' WELL I Y-- 5,99t,050.09 Lot. - 70°2:3'11.370" X = 539,829.76 Long.= 149040'33.808" ~ SEC. 20-- 154'FNL 139'FWL N O R T H ' I- WELL 2 Y= 5,990,990.16 L~l. = 70°23'10.7el" i x = 539,829.82 Long. = 149°40'$3.816 '0 SEC. 20-- 214'FNL, 138'FWL I~ .._._ I WELL 3 Y= 5,990,930.24 Lot = 70°25'10.192'' I IX = 539,829.78 Long. = 149o40'33.826" i . SEC. 20-- 274'FNL, 138~FWL ~ '~ i WELL 4 Y= 5,990,870.26 Lot. = 70°23'09.602'' [ c~::~11--12 = ~3',~? [ X = 539,829.77 Long. = 149°40'$3.836" : , ! ~,-~,' i SEC. 20-- 334' FNL, 137'FWL , ~,c ' i'~ WELL 5 Y= 5,990,870.21 Let. = 70023'09.620" S i~s-'~-: X: 539,469.75 Long.= 149040'44.377' ! I SEC. 19- :3:32'FNL, 223'FEL [ , ~ ' WELL 6 Y= 5,990,930.21 Lot. = 70°23'10.210" I ' i X= 539,469.74 Long. = 149°40'44.368" · "'.__..,~ SEC. 19 -- 272' FNL, 222'FEL ! WELL 7 Y= 5,990,990.23 Lot..= 70°23'10.800'' i,I X = 539,469.76 Long. = 149°40'44.358" I I SEC. 19 -- 212' FNL, 222'FEL I ~ I~ WELL 8 Y: 5,991,050.20 Lot. : 70°23'11.390" t' SZ01'i I X= 559,4692.' 73 L~ng. = 149°40'44.350" I' ' ! .~. SEC. 19-- 15 FNL, 22 FEL ,%~, ' ,~ - - WELL 9 Y= 5,991,600.16 Lat. = 70°23'16.800" ~7 ~ 2-~/~, ' X = 559,469.91 Long. = 149°40'44.259" ' SEC. 18 ~ 398' FSL~ 216'FEL ' ~_V.;. ~ il4_+~ WELL 10 y= 5,991,660.11 Lot. = 70°25'17.389" i x = 5:39,469.82 Long.= 149o40'44.25:3'' I ' SEC. 18 -- 458' FSL, 216'FEL I,.L_. ~ WELL II ~=5,991,720.17 Lot. = 70°25'17.980" '~ '--"-'- , X = 5:39,469.81 Long.-- 149°40'44.2z~4" i I ~ SEC. 18 -- 518' FSL, 215'FEL ', WELL 12: Y= 5,991,780.16 Let. = 70°25'18.570'' - I X= 5:39,469.78 Long. = 149°40'44.235" I SEC. 18 -- 578' FSL, 215'FEL DRILL SITE R,"= 3oo' WELL 1:3 Y= 5,991,780.16 Lot. = 70°23'i8.551" - X = 539,829.75 Long. = 1~9°40'33.695" AS-BUILT CONDUCTOR LOCATIONS SEC. 17 -- 576'FSL, 145'FWL WITHIN SECTIONS 17,18~I91~20~TIP. N~RIOE~U.M. WELL IZ~ Y=5,991,720.13 Lot. = 70°25'17.961 X= 559,829.71 Long.= 149°40'33.705"' NOTE: SEC.17 -- 516' FSL, 145'FWL COORDINATES ARE ALASKA STATE PLANE~ ZONE: 4. WELL 15 Y: 5,991,660.19 Lot. = 70°25'17.$71" SECTION LINE DISTANCES ARE TRUE. X= 559,829.71 Long. =. 149°40'3:3.715" HORIZONTAL 6 VERTICAL POSITIONS PER L.H.D. SURVEYORS~ SEC. 17 -- 456'FSL, 144'FWL DOCUMENT NO. 129: N 19+69 N 17+25 WELL 16Y: 5,991,600.20 Lot. = 70023'16.781" E 9+56 8 E 15+25 X = 539,829.77 Long.= 149°40'$3.722'' EL.50.39 EL.38.75 SEC. 17-- 396~ FSL, 144'FWL CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ~. , THAT ALL DIMENSIONS AND OTHER DETAILS ~' "~"'"'"'"'"'~ · ' ' :" ' CHECKED J HERMAN ..... ....-, 3340 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 ]C~ __ ~ / .... ' ..... April 29, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 1R-7 ARCO Alaska, Inc. Permit Mo. 85-72 Sur. Loc. 212'F~L, 222'FEL, Sec. 19, T12N, R10E, Btmhole Loc. 1326'F~FL, t237'FEL, Sec. 19, T12N, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a or, e-cubic linch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawo_ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation] Mr Jeffrey B Kewzn Kuparuk River Unit !R-7 -2- April 29, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to wi~aess testing of the equipment before the surface Easing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~4ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower7 ARCO Alaska, Inc. "--'-', Post Office L 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1R-7 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 1R-7, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on May 11, 1985. If you have any questions, please call me at 263-4970. Sincerely, JBK/HRE/tw PD/L69 Attachments RECEIVED APR 2 21 85 Alaska OH & Gas Cons. Commission Anr. Amrage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA "'-' ALASKA ~J,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE E~X 2. Name of operator ^,co 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 AP,~,, 4, Location of well at surface r,, ~' ~Oll~'~ 212' FNL, 222' FEL, Sec. 19, T12N, R10E, UM A~$ka 011 & Gas Co~ At top of proposed producing interval 1302' FNL, 1184' FEL, Sec.19, T12N, R10E, UM AJ1ch0[age At total depth . 1362' FNL, 1237' FEL, Sec.19, T12N, R10E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 84', PAD 47' I ADL 25635 ALK 2568 9. Unit or lease name Kuparuk River Unit 10. Well number 1R-7 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 14. Distance to nearest property or lease line 3918' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7214' MD~ 6882' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2316 feet. MAXIMUM HOLE ANGLE 39 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed R-6 well 60' ~ surface feet 18. Approximate spud date 05/1 1/85 28_~_5 psig@ ROoF Surface 3278 psig@ 6568 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 124" 16" 62.5# 13-1/2" 10-3/4"! 45.5# 8-1/2" 7" 26.0# 22. Describe proposed program: Weight CASING AND LINER Grade CouplingI H-40 Wel~ J-55 BTC/ HF-ERW J-55 BTC~ HF-ERW Length 80' 35' 3248' 35' 35' I 7180' MD TOP TVD I 35' I 34' 134' MD BOTTOM TVD 115' 115' 3283' I 3272' 7214' I 6882' I I (include stage data) m 200 cf Poleset 1285 sx Permafrost "E" 200 sx Permafrost "C" 500 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7214'MD (6882'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 10-3/4" casing will be set through the Ugnu Sands at approximately 3283'MD (3272'TVD). 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 (3000 psi for annular). The West Sak interval will be cored with oil based mud. Expected maximum surface pressure is 2855 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6/5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) -23. I hereby~at the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer The spacet~w f~t~/~o~u~use Samples re,~red t Mud log required ~]YES ,,,,,~NO [ []YES ,,~0 Permit number Approval date APPROVED BY Form lOqO1 (HRE) PD/PD69 D ~,, '~ I on CONDITIONS OF APPROVAL Directional Survey required ,~YES r-]NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER. DATE Ap~i I 29, 1 985 by order of the Commission Submit in triplicate APl number PERMIT TO DRILL 1R-7 installed and tested upon completion of the job. 1R-7 will be the third well drilled on the pad. It is ±60' away from 1R-6 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at the 10-3/4" casing shoe in order to cover the West Sak Sands. Reserve pit fluids will be disposed of down the 10-3/4" x 7" annulus. The 10-3/4" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. . . I - i i_ . . nnn: ! ~000~ >.000 i 000 000: , p~l%~l' Ii ~ .... ' R£C£1¥ APR2 2 !Anc~ra! ; ED ~ ~ ~ -' : ~ ' ! ' - ! ' ~ ~ ' · i ~ ! ' ' ' ' i , ~ , - ' L':"-% ' ...... '. ' ' [ ; ~ ~ 7 ~ . ; ~ i i ? :' ' ~ i; : , ' , ~ .... ~ ' '. ; .... . , . , .... ~ ~ i [ ~ ~ ; ~ I i '. i i i : : i_i f ~ ~ '. ] 7 ~ ~ ~ _ . i : ~.. i ~ ~ . ~ i 5 i :~ i ] - : : : - ~ : : E ~, ~,~-- ~ ~:~:,,~:-,,;,,'~,~:-., ~, ~: ,., ~.' ,. : : ~i~!"::~ ......... . i i - ' ; : 7 : - . - - : ; , - : ~ ~ ~ ~ ' - 7 : ~ t ~ , ~ ~ , ~ : ..... ' ' : ' ' . · - · ~ j ~ j ,, , ,, i il; :- ~ T : ~ ' .: ~ ' ~ ' ~ ~ ' '-- ' - ~ ~!~ ~ i! ~: :~ ~' '_:~ ; ~ ~:'~ 9~ ~~ ~ri~ ~ ~,~ ~i i ~ i ;,i,~.1.~;~. []; :. ~ ~ i~ ~ i ;~ ' ~ ' .5 ~ i ; ?~:'~nn~-- ~'W'f ' - ]'~'~t '~G~i- Ke~¥G~fb-~, ,~ i~ ~--8~-~ ...... F~ - 7'r--- .... ~-'-~--, ........... ............ r~ ~ ~ ~, ~ [ - ~ ..i i[[ · . ~ , '7"'.- . : i ~ i , ~ 7~ ~'__~ , !~ 1~ ,. i ;~ ~ ~ ~ } :~ ~ ' : ' . , , _ ~ : . . iiit : .................... :' ' '- ;~!~ ..... ~i~ ' ' Surface Diverter Sys:em_ i. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. I6" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling, spool w/[O" side curl ets. ' b// 5. [0" ball valves, hydraulically actuated, w/lO' lines to resem~e pit. Valves to open automat'ically upon closure of annular preventer. 6. 20" 2000 psi annular'preventer. · "7. 20' bell nipple. · h Maintenance & Opera.rich. Upon initial installation close annular preventer and verify that ball valves have opene~ properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event, that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to u~wind diverter line. Do not shut in well under any circumstances. 16" Conductor 219B5 Oil & Gas ConS. Gommissio~ Anchorage 7 6 5 4 2 12. 13. £CEIV£D ACC~ATOR CAPACITY TEST 13-5/8' BOP STACK TEST FILL ~ S'FAO( AN:) ~ M~rIFCLD W~TH DIESEL. Q-I~ THAT ALL LO~X ~ SO~ IN FLI_LY ~"rRACTED. SF_AT TEST PLUG IN W~TH I~Ih~ JT ~ ~U~ IN L~ SC~E~ 3. CLOSE ~ ~~ ~ ~ K~LL LI~ V~ ~~ %0 ~ ST~ 4, ~~ ~ %0 ~ ~I ~ ~D F~ I0 ~ ~~ TO ~ ~I ~ ~D F~ I0 ~D ~_~ TO 0 ~I. LI~ V~ ~ T~ PI~ ~ ~ ~ TO ~ ~I ~ ~ ~I ~ IN ~ 4. ~ A ~ ~ L~ ~ ~ ~1 HI~, ~T ~ IN ~P 4, ~ ~T ~~ T~ ~ ~ A ~L ~~ ~ITI~ ~ ~. ~Y 9. ~N ~TT~PI~ ~ ~ ~ ~~ I0, ~ ~I~ ~ ~ T~T TO ~ ~I. ~l, ~N ~I~ ~ ~ ~~ ~T ~IF~D ~ LI~ ~ F~ ~ ~~I~ ~UI~ ~T ~ V~ IN ~ILLI~ ~ITI~ ~ ~I. ~~ ~ I~~TI~ ~ ~~ ~~ ~ST F~ SI~ ~ ~ TO ~ILLI~ ~EVI~. ~E~Y ~~ F~I~Y ~TE ~ ~ILY. Alaska 0il & Gas Gons. Commissm" Anchomg~ 5~ 008400~ (2) Loc 2.; "" '.'... ':: (2 ~' thru :.,8.) ?-" ;-~: '-- ' ' ' · ;,~'" ";~ ' ' '~ ~ ~: .' ,,tO ~, '.,:,' ,.,.'.' ,-. , - ' ' '.' '- ~..',..'.~~?:.-'.~-:.~.'..-... .... . 7-, · .:.:...:~~~~.?~....~ ,~...~ ?..L.:...~. (lO :~;~nd..,.~'~ 2). ' ~ 2. (I3 ~h~U 21) (22-th~u 26) (6) ,Add.: Geology: EnF~neerin~: HW~ ~. LCS~ SEW ~ J rev: 03/13/85 6.011 13 o ].4. 15. 16. 17. !8. 19. 20. ~'~2, 23. 24. 25. 26. 27. · 'iq.~t i. : '-" %-.' ~,~:.!' , ?':~ - ' '~ ';" '": . . ..... ~.~ .. - .. : ::.,..'.: . -, .......... I~' welI-loCgted proper dista~ce"from property line ..' ........... /~ Is ~eli located proper distance from other:wells . ' .................. ~ , is sufficien: undedicated acreage available~in this poo~ ............ Is ~ell to be deviated 'and is Wellbore plat included ......... ~ ....... %~d~ ' isoPerator .... the Only affected party - . Can permit be approved before ten-day wait .......................... Does operato~ have bond in force ~ . a .................................. Is a conservation order'.needed ...................................... ~f administrative approval needed ~, Is eeeeeeeeoeeeeeeeeeeeeeeee®ee®eeeeee IS the lease'number appropriate ..................................... ~~ Is conductor string provided ............................. i ....... ........ 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 01d wellbore abandonment procedure included on '10-403 ............ Is adequate wellbore separation proposed ............................ .Is a diverter system required .................................... '.. ~ Are necessary·diagrams of diverter and BOP equipment attached ....... .~ Does, BOPE have sufficient pressure rating - Test t° ~0 psig .. Does the choke manifold comply w/AFI RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No special 'effort has been made to chronologically organize this category of information. :* .... 5CHLUMB ERSER ..... ~ .L,I$ T~,P~ V~FIC~Ti~O,~ LISTZNG LVP OlOoHOZ VERIFICATION LISTING PAaE i · ~:* REE.L HEADER ** SERVICE NAME :EDIT DATE :85/05/Z9 ORIGIN : REEL N~ME : CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS : · -~ TAPE HEADER SERVICE NAME :EDIT · 'EATE :85/05/29 2RIGIN :00~0 TAPE NAME :0509 CONTINUATION # PREVIOUS T~P~ : ~ FILE HEADER FILE NAME ,:EDIT .001 SERVICE NAME VERSION ~ OATE : MAXIMUM LENGTH : 1~2~ FILE TYPE PREVIO~S ~ILE : ~:~ IN,FERMATION REC,~RiD$ M N ,E M C 0 N TiE N 'T S MNEM CO~TENTS PR,ES: E ~NLT TYPE CATE SIZE 000 000 015 055 000 00.0 00.4 065 000 000 007 000 000 003 055 000 '000 0,~'3 000 000 002 065 000. OOO 0~,7 06'5 000 000 006 0,6,5 000 000 003 ~.NIT 'TYPE CATE SIZE ~O'DE ..000 000 001 06.5 LVP OlO.HOZ V,ERI,FICATION LIS'TING -,- SCH':.LJMBER ~ER ~ ALASKA COMPUTING CENTER COMPANY : ATLANTIC RICHFIELD COMPANY WELL = 1R-7 FIEL~ : UPPER UGNU COUNTY = NORTH SLDPE ~OR~UGH ST,~TE = ALASKA JOB NUMBER AT ,~CC: 70433 RUN ~1., gATE LOGGED: 17 MAY 85 LDP: L. ~. CUDNEY CASING TYPE :FLUID DENSITY VISCOSITY PH FLUID LOSS : 16.000" i~ 110' - BIT SZZ~Z = 13.5" TO 2885" : SP'UD MUg = 9.8 L~/~ RM : ~),.'~O ~ 67.0 OF : 60.0 S RMF = ~.620 ~ 67.0 DF = 8.5 RMC : 3.980 ~ aT,O D'P : 15.6 C3 RM AT BHT = 5-¢0:5 ~ 58.0 DF MATRIX SANDSTONE LVP OIO.HOZ VERIFICATIi2N LISTING PAA,E S THIS DAT.6 ~AS NOT SEEN DEPTH SHIFTED - DVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC 'TAPE:' DUAL INDU:CTION SPHERICALLY F)CUSED LOG (!)IL) DATA AVAILA3LE: 1/6' TO 2~80' LONG SPACED SONIC LOG (LSS) O~IA AV~ILASLE: 11~m ~O Z~" LITHO OENStT~ COMPENSATED LO2 (LOT) COMPENSATED NEUTRON LOG (LOI) DATA 4VAIL~SLE: 116' TO 2~5~" LSS MERG:O 4T ,1890' SCHLUMBERGER ALASKA DIVISION COMPUTI'NG CENTER COMPANY '= ARCO ALASKA INC WELL : 1R,-7 FIEL2 : KUPARUK LVP OlO.H02 VERIFICATION LISTING COUNTY = N.SLOPE STATE = SECTION = TOWNSHIP = 12N RANGE = 10E J 0 ~ ~ 7050 ~ BASE LOG: OIL , RUN ~ ) 2ATF... LOG~EO ~ JUN 8:5 ~OTTOM L2G INTERVAL : TOP LOG INTERVAL CA SI NG-L 3GGER BIT SIZE TYPE HOLE FLUID 2ENS ITY VISCgSIT¥ PH FLUID LOSS RM ~ MERS. TEMP. RMF ~ ME~S. TEMP. RMC @ MEAS' 'TEMP. RM ~ ~SH T LOP: T ~ALSTE&D ?OgO FT. 2864 FT. 10.750 ~N. @ 286~ FT. 8. 500 IN. G~L 10.10 ~'3. O0 9.0.0 5. '90 2.5'~0 @ 65 F 2.300 ~ 55 F 1.680 @ 55 ,F 1.211 @ 1~/+ F LVP 0!O.HOZ VERIFICATION LISTING PAGE *~* NOTE ~* LOGS MERGED TOGETHER AT THESE POINTS: DIL - 2878°0 LDT - 2852.0 kCS - 28~5.0 · -* DATA FORMAT REC3RD ENTRY 5LOC(S 'TYPE SiZE REPR C 3'2,E ENTRY 2 1 6,5 0 9 6 65 .lin 16 i 6~ 1 0 1 66 0 DATUM SPE.CIFIC&TION ~LOCKS MNEM SERVICE SERVICE ONiT API APl API ,~P][ FILE SIZE SPL RiEPR ORDER LOG TYPE CLASS MOO NO,. P R D,C ~E S S C g, D E (0 C'T i L ) FT O0 OOg O0 0 O ~ OHMM O0 220 O1 0 0 ~ OHMM O0 120 ,~6 0 0 ~ MV O0 010 O1 0 0 ~ GAPI :00 310 O1 0 0 ~ OAP[ O0 310 O1 ~ 0 ,~ ,IN 0,0 ZSO O1 0 O ,~ G/C3 O0 350 02 0 0 :~ G/C3 O0 35:$ OX 0 0 ~ 0,0 420 O1 0 0 :~ O0 000 O0 0 0 ~ PU O0 ~90 O0 O 0 .~ O0 358 O1 0 0 .~ ~PS O0 330 3i 0 0 ~ CPS O0 330 30 :0 0 ,¢ ~API 0.0 310 O~ 0 0 ~ i 58 00000000000000 1 68 00000000000000 .1 68 0000000000000.0 I 68 00,00000000000~ I ,68 00000000000000 I 68. 0000.00.0000000'~ I 58 0'0000000000000 I ~8 0000,0000000000 1 5B :O0000O'OOO0000'O 1 '5:8:0000:0:00000000~ 1 68 00:000'000000000 1 b8 0000:0000000000 I ,68 0000000000,0000 I 68 0:00000:0000:000~: i 68 00:00000000000~ i 6:8 000,~:0'00000000~' 1 68 'OOO00'O0000000~ LVP O1D.HOZ VERIFICATION LISTING OTL ;SS US/F O0 MI ¼V MLL OHMM MN2R MLL 2HMM HD MLL IN SR MLL ~APi SZO 80 0 520 ~0 0 252 O0 280 01 0 310 DATA 7[03°0000 SFLU -~,3.,5758 GR -999.2500 DRNO -999. 2500 PE:F -108.1602 9T -~99.2500 HO 7100.0000 5FLU -43.~8~3 GR 3.7014 ORHO 40.38 O 9 P E F 2.369~ HD 7~00.0000 5FLU -ih. 5~07 GR 2.3987 ORHO 4~. 33,~0 PEF 10,~. 3328 gT 1.75 g 8 ~ D 6200.. 0'000 SF~U -16.7607 '~R 2. ~ I 0 ~ ~ R H O 3~' 1309 PEF 87.08 g 8 0 Z' 5237 HO 6~00. 000:0 SFLU -ZZ. 3857 GR Z, ~0~5 ORH.O 32.32.~2 PEF 88- Z773 OT 3.. ~ 057' 6700 0000 SFLU -35. '70 70 GR Z. 578~ DR HO .28' 6 ~ 3 ~ P E.F 6 ~. 0898 O 'T 5.3328 6500. go00 SFLU - ~ g.. g 170 G R 3.7b20 ILD -L08.1602 ER -999,2500 NRRT -999.2500 NC~L 101.2773 DTL -999.2500 ~R 3. '762 0 [ L 2 -108.1602 SR 2. ~70£ NR AT ,¢o2351 NC~L /01..2773 DTL .8 .. 5173 $.R ~' 1414 iLO 8'7. O 898 5 R 0.03.3 Z ,4 R A T ,3.06 Z 7 NC N L 93. g 023 D T L 9.0 2,.~, 2 ,~'R 8 0 i 8 Z L .D 0:89:8 ~ R -0. O0,ZO I"iR AT .0 ,1,64. N,C N L,, 6523 OT L 0 82. 8 G R Z. 969:0 i L D 0 .q,. 0 ~ 17.0205 -999.2500 -999.2500 -999.Z500 102.0273 -999°2500 1'7.00~9 1362.6875 3.0530 i0:Z.0273 1362,6875 1.9776 Ii~. 0898 '720 . 5875 110. ? 77'3 114.0898 3. 7854 9,~ 1523 3. ~ 100 02 ~:' 6875: 9,~. Z 773 .~... O 1:6'4 g.~. 0Z73 05 ~ 5000 '9 ~': Z 7 ~'3 zz'o oZ Z. 5526 153-5 0 O0 8 0.7 77.3 79.5523 Z. 7 01 ~ 1 ~8 OOO000000000OO I 68 00000000000000 i 58 O000000OO0000O 1 ~8 O000000000000~ 1 58 O00000000OO00~ 1 68 OOOO000000000O ILM 3.3059 CALI -999.2500 RNRA --999.2500 FCNL -999.2500 MINV -999.2500 ILM 3.3069 CALZ RNRA 3.2366 FCNL 6323.2500 MINV 3.1936 CALi 8.8223 RNRA 3.703~ FCNL ~6.~..3906 MINV ,.Z..:~,319 iLM 3.8957 CALI 8.5566, RNR:A 3.:Z639 FC, NL ~20.,3125 MiNV 3..1.252 ILM ~.,:2:507 CALl 8.9315 RNRA 3'0706 FCNL 66~ 3~25 M,IN¥ CALI ;'a-, 5566 R N R A ,Z,. 66 53 :; MC NL S 0 '? ', 3125! MINV ,5. g 7'73 CALi I0. ~535 LVP OIO.HOZ VERIFICATION LISTING RA&E 7 RH28 2.$803 DRHO NPMI 35. 4492 ~R ll~..~OZ3 DT MNOR 1'7.3486 MD DEPT 6500.0000 SP -25.6065 GR RH28 2. 3616 ORHO NP~I ~. 9219 PEF GR 95.02~3 MN~R 1. 0997 DEPT 6~00. 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