The URL can be used to link to this page

Home My WebLink About184-2341. 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 9535'feet 9021'feet true vertical 6937' feet 8803'feet Effective Depth measured 9366'feet 7309', 8478', 8951'feet true vertical 6820'feet 5317', 6173', 6526'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 L-80 8555' 9023' 6231' 6579' Packers and SSSV (type, measured and true vertical depth)7309' 8478' 8951' 5317' 6173' 6526' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: 8709-8719', 8722-8726', 8735-8740', 8742-8753', 8756-8764' 8771-8777', 8834-8881', 8914-8928' 6347-6355', 6357-6360', 6367-6370', 6372-6380', 6382-6388', 6393-6398', 6440-6475', 6499-6509' 4622'3571' 16" 9.625" Burst Collapse 11936' Casing 6920'9511' 7882' 103'Conductor Surface Production 117' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-234 50-029-21250-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025641, ADL0025634 Kuparuk River Field/ Kuparuk Oil Pool KRU 1Q-04 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 103' Well Shut-In 325-223 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB Blue Pack Max RH Packer: SLB Blue Pack Max RH Packer: Packer FB-1 SSSV: None Brian Glasheen brian.glasheen@conocophillips.com (907) 545-1144RWO Engineer Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:53 am, Jun 30, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.30 10:16:39-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen JJL 7/21/25 RBDMS JSB 070325 DSR-7/21/25 Page 1/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/20/2025 12:00 5/20/2025 13:00 1.00 MIRU, MOVE MOB P MOB to 1Q-04 0.0 0.0 5/20/2025 13:00 5/20/2025 15:30 2.50 MIRU, MOVE MOB P Large snow wall at entrance of pad from recent Phase 3 weather conditions prevented rig from being able to exit pad. Call out snow removal 0.0 0.0 5/20/2025 15:30 5/20/2025 17:00 1.50 MIRU, MOVE MOB P Continue toward spine road. 0.0 0.0 5/20/2025 17:00 5/20/2025 19:00 2.00 MIRU, MOVE MOB P Hold for field change out. 0.0 0.0 5/20/2025 19:00 5/21/2025 00:00 5.00 MIRU, MOVE MOB P Continue MOB towards 1Q. 0.0 0.0 5/21/2025 00:00 5/21/2025 01:30 1.50 MIRU, MOVE MOB P Stage sub on 1Q pad. 0.0 0.0 5/21/2025 01:30 5/21/2025 06:00 4.50 MIRU, MOVE MOB P Hang tree in cellar. Stage wellhead equipment behind cellar. Lay herculite & spread mats. Spot sub over well. Shim rig. Berm in rig. 0.0 0.0 5/21/2025 06:00 5/21/2025 10:00 4.00 MIRU, MOVE RURD P MIRU Tiger and open top tank. Set cuttings box. R/U hardline to kill tanks. Obtain well pressures. Get RKB's. Rig up well kill plumbing. Bring on 500 BBls 10.4PPG fluid. Complete acceptance check list 0.0 0.0 5/21/2025 10:00 5/21/2025 11:30 1.50 MIRU, WELCTL RURD P Complete fluid loading, Rig up bleed trailer to OA 0.0 0.0 5/21/2025 11:30 5/21/2025 12:00 0.50 MIRU, WELCTL SEQP P Pressure test circulation lines in cellar, PT lines to kill tanks manifold to 2500 PSI 0.0 0.0 5/21/2025 12:00 5/21/2025 15:30 3.50 MIRU, WELCTL KLWL P Attempt to bleed off free gas. Initial tubing pressure 900 Initial IA=1000 PSI. Cycled down to 700 PSI three times. Came right back up. Start pumping 30 BBl deep clean pill followed by 460 BBls 10.4 PPG NaBr. 3.5 BBl/Min ICP=1075, FCP=422. Getting 10.4 PPG fluid back at surface with oil sheen on top. Shut down Monitor wellBleed off in step wise manor. 140 psi TO 60 psi 0.0 0.0 5/21/2025 15:30 5/21/2025 16:45 1.25 MIRU, WELCTL KLWL P Line up and pump 100 BBls, 3.5 BBls/Min ICP=825, FCP=925, Shut down T & IA balanced @ 45 PSI. Consult town. Slowly bleeding off together 0.0 0.0 5/21/2025 16:45 5/21/2025 19:30 2.75 MIRU, WELCTL OWFF P OWFF. TBG died quickly. OA sputtered gas, oil & brine for 1Hr. Diminishing to no flow. Gas migrating up IA. Bleed OA down T/ 20 PSI. Closed in IA on gauge, pressure up T/ 6 PSI of 15 Min. Repeat. 0.0 0.0 5/21/2025 19:30 5/21/2025 20:45 1.25 MIRU, WELCTL KLWL P Line up and pump additional 142 Bbls, 10.4# brine @ 2 BPM, 265 PSI w/ open choke. Initial returns 50/50 crude/brine. Started to clean up towards end of circ. 10.4 PPG returns at surface. 0.0 0.0 5/21/2025 20:45 5/21/2025 22:30 1.75 MIRU, WELCTL OWFF P Allow well to relax for 15 min. Flow reducing at tank. Shut well in for 30 Min, 0 PSI TBG/IA. Open up both sides initially on slight vac. OWFF, 30 MIn no flow. 0.0 0.0 5/21/2025 22:30 5/21/2025 22:45 0.25 MIRU, WELCTL RURD P B/D, R/D TBG circ equipment. 0.0 0.0 5/21/2025 22:45 5/21/2025 23:15 0.50 MIRU, WELCTL MPSP P Set H BPV. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 2/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/21/2025 23:15 5/21/2025 23:30 0.25 MIRU, WELCTL PRTS P Rolling PT on BPV from below for 10 Min @ 2 BPM, 600 PSI. 0.0 0.0 5/21/2025 23:30 5/22/2025 00:00 0.50 MIRU, WHDBOP RURD P B/D, R/D IA circ equipment. 0.0 0.0 5/22/2025 00:00 5/22/2025 02:30 2.50 MIRU, WHDBOP NUND P Function LDS. N/D tree & adaptor spool. Inspect lift threads. Install tree test dart. 0.0 0.0 5/22/2025 02:30 5/22/2025 05:30 3.00 MIRU, WHDBOP NUND P N/U DSA & BOP. Install flow nipple. R/U trip hose. 0.0 0.0 5/22/2025 05:30 5/22/2025 07:00 1.50 MIRU, WHDBOP RURD P Grease choke. R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 5/22/2025 07:00 5/22/2025 16:45 9.75 MIRU, WHDBOP BOPE P Initial BOPE test to 250/3000 PSI for 5 Min each, Tested UVBR's, LVBR's & annular on 3 1/2" X 5 1/2 test joints. Test blind rams, .Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV & IBOP. Test 3 1/2" & 4 1/2" EUE FOSV. Test 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 = 2950 PSI, after closure = 1600 PSI, 200 PSI attained = 21 sec, full recovery attained = 124 sec. UVBR's = 5 sec, LVBR's = 5 sec. Annular = 24 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 1980 PSI. Witness waived by AOGCC rep Guy Cook. 0.0 0.0 5/22/2025 16:45 5/22/2025 17:00 0.25 MIRU, WHDBOP BOPE T Door seal on LPR's failed initial test. Replaced door seal. Passed retest. 0.0 0.0 5/22/2025 17:00 5/22/2025 18:00 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. 0.0 0.0 5/22/2025 18:00 5/22/2025 18:30 0.50 MIRU, WHDBOP MPSP P Pull dart & BPV. 0.0 0.0 5/22/2025 18:30 5/22/2025 18:45 0.25 MIRU, WHDBOP PULD P R/U landing joint. K/U set 10K down. BOLDS. 0.0 0.0 5/22/2025 18:45 5/22/2025 19:00 0.25 COMPZN, RPCOMP PULL P Pull hanger off seat @ 80K. Pipe free @ 105K. PUW=92K. Pull hanger T/ RF, Pull cut F/ 8378' T/ 8348'. 8,378.0 8,348.0 5/22/2025 19:00 5/22/2025 21:00 2.00 COMPZN, RPCOMP CIRC P Circ well @ 3 BPM, 180 PSI. Over Boarding contaminated fluid. Circulating loss rate @ 3 BPM = 30 BPH. Cont circ @ 4 BPM, 320 PSI. Circulating loss rate @ 4 BPM = 30 BPH. 8,348.0 8,348.0 5/22/2025 21:00 5/22/2025 21:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Fix leak in trip hose. 8,348.0 8,348.0 5/22/2025 21:30 5/22/2025 22:00 0.50 COMPZN, RPCOMP PULD P L/D hanger & landing joint. B/D TD. Put well on TT. Static loss rate = 12 BPH. Well out of balance flowing from TBG. 8,348.0 8,348.0 5/22/2025 22:00 5/22/2025 22:45 0.75 COMPZN, RPCOMP RURD P R/U head pin & circ hose. Blend 100 Bbls 10.4+ PPG brine. 8,348.0 8,348.0 5/22/2025 22:45 5/22/2025 23:15 0.50 COMPZN, RPCOMP CIRC P Circ STB @ 4 BPM, 380 PSI. 8,348.0 8,348.0 5/22/2025 23:15 5/23/2025 00:00 0.75 COMPZN, RPCOMP PULL P L/D 3 1/2" completion F/ 8348' T/ 7857. PUW=92K. 8,348.0 7,857.0 5/23/2025 00:00 5/23/2025 06:30 6.50 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" completion F/ 7857' T/ Surface. PUW=85K. 7,857.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 3/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/23/2025 06:30 5/23/2025 07:30 1.00 COMPZN, RPCOMP BHAH P Clean and clear rig floor. Unload 3 1/2 EUE completion. Line up on trip tank. Static fluid loss 13 BBls 0.0 0.0 5/23/2025 07:30 5/23/2025 08:00 0.50 COMPZN, RPCOMP RURD P M/U wear ring, ID=6.875 0.0 0.0 5/23/2025 08:00 5/23/2025 09:00 1.00 COMPZN, RPCOMP RURD P R/D tubing tongs. R/U Tongs and spinners 0.0 0.0 5/23/2025 09:00 5/23/2025 09:30 0.50 COMPZN, RPCOMP BHAH P Load BHA #1 into shed. Load cut joint down slide. P/U BHA #1 test packer 0.0 17.5 5/23/2025 09:30 5/23/2025 17:30 8.00 COMPZN, RPCOMP PULD P PUDP T/ 6120'. PUW=100K, SOW=92K 17.5 6,120.0 5/23/2025 17:30 5/23/2025 17:45 0.25 COMPZN, RPCOMP MPSP P P/U set 7" test packer @ 6095' COE. 6,120.0 6,103.0 5/23/2025 17:45 5/23/2025 18:15 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Purge kill line. Close UPR. 6,103.0 6,103.0 5/23/2025 18:15 5/23/2025 19:00 0.75 COMPZN, RPCOMP PRTS P PT 7" CSG T/ 2500 PSI for 15 Min. 6,103.0 6,103.0 5/23/2025 19:00 5/23/2025 19:15 0.25 COMPZN, RPCOMP RURD P Open UPR. B/D, R/D testing equipment. 6,103.0 6,103.0 5/23/2025 19:15 5/23/2025 19:30 0.25 COMPZN, RPCOMP MPSP P Release test packer. 6,103.0 6,103.0 5/23/2025 19:30 5/23/2025 20:30 1.00 COMPZN, RPCOMP PULD P PUDP F/ 6103' T/ 7424'. PUW=115K, SOW=95K. 6,103.0 7,424.0 5/23/2025 20:30 5/23/2025 20:45 0.25 COMPZN, RPCOMP MPSP P P/U set 7" test packer @ 7400' COE. 7,424.0 7,410.0 5/23/2025 20:45 5/23/2025 21:00 0.25 COMPZN, RPCOMP PRTS P PT 7" CSG @ 7400'. Fail. Pump 2 Bbls 160 PSI. Bled off T/ 80 PSI. 7,410.0 7,410.0 5/23/2025 21:00 5/23/2025 21:15 0.25 COMPZN, RPCOMP TRIP P Rack back stand of DP 7339'. 7,410.0 7,339.0 5/23/2025 21:15 5/23/2025 21:30 0.25 COMPZN, RPCOMP MPSP P Fill DP. Set 7" test packer @ 7326 COE. 7,339.0 7,335.0 5/23/2025 21:30 5/23/2025 21:45 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. Purge kill line. Close UPR. 7,335.0 7,335.0 5/23/2025 21:45 5/23/2025 22:15 0.50 COMPZN, RPCOMP PRTS P PT 7" CSG @ 7326' T/ 2500 PSI for 15 MIn. Pass. 7,335.0 7,335.0 5/23/2025 22:15 5/23/2025 22:30 0.25 COMPZN, RPCOMP RURD P Open UPR. B/D, R/D testing equipment. 7,335.0 7,335.0 5/23/2025 22:30 5/23/2025 22:45 0.25 COMPZN, RPCOMP MPSP P Release test packer. P/U T/ 7331' 7,335.0 7,331.0 5/23/2025 22:45 5/24/2025 00:00 1.25 COMPZN, RPCOMP CIRC P Circ STS @ 4 BPM, 825 PSI. 7,331.0 7,331.0 5/24/2025 00:00 5/24/2025 00:30 0.50 COMPZN, RPCOMP OWFF P B/D TD. OWFF 7,331.0 7,331.0 5/24/2025 00:30 5/24/2025 03:15 2.75 COMPZN, RPCOMP SLPC P K/U. Slip & cut 66' of drill line. Calibrate block height & hook load. 7,331.0 7,337.0 5/24/2025 03:15 5/24/2025 06:00 2.75 COMPZN, RPCOMP TRIP P TOOH F/ 7337' T/ 17'. PUW=115K. 7,337.0 17.0 5/24/2025 06:00 5/24/2025 08:30 2.50 COMPZN, RPCOMP BHAH P At surface, Lay down test packer. Clean and clear rig floor. Lay out BHA #2, M/U BHA #2 Overshot 17.0 223.5 5/24/2025 08:30 5/24/2025 10:30 2.00 COMPZN, RPCOMP PULD P P/U singles from shed 223.5 1,986.0 5/24/2025 10:30 5/24/2025 13:00 2.50 COMPZN, RPCOMP TRIP P Trip in well to 8288 On High Line 12:30 1,986.0 8,288.0 5/24/2025 13:00 5/24/2025 14:15 1.25 COMPZN, RPCOMP FISH P KU Stand & 88, PUW=137, SOW=95, Online 2 BPM @ 275 PSI. Find TOF @ 8366. Added stand. Set down 20 K. Pull up to 40 K over See jars fire. Fish appears to be free. 150 K PUW, 136 dragging. 8,288.0 8,366.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 4/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/24/2025 14:15 5/24/2025 15:15 1.00 COMPZN, RPCOMP CIRC P Circ BU 4 BPM @ 910 PSI 8,366.0 8,366.0 5/24/2025 15:15 5/24/2025 15:45 0.50 COMPZN, RPCOMP OWFF P OWFF. Gas break out. 1 BBl gain. 8,366.0 8,307.0 5/24/2025 15:45 5/24/2025 16:00 0.25 COMPZN, RPCOMP CIRC P Circ 100 BBls, 4 BPM @ 910 PSI, Lost three BBls 8,307.0 8,307.0 5/24/2025 16:00 5/24/2025 16:30 0.50 COMPZN, RPCOMP OWFF P Monitor well. 8,307.0 8,307.0 5/24/2025 16:30 5/24/2025 21:00 4.50 COMPZN, RPCOMP TRIP P TOOH F/ 8307' T/ 223'l, PUW=134K 8,307.0 223.0 5/24/2025 21:00 5/24/2025 22:45 1.75 COMPZN, RPCOMP BHAH P Rack back DC's L/D BHA #2. PUW=38K. & Fish. 23.55' cut joint, clean cut. OAL of fish w/ seals 42.44'. 223.0 0.0 5/24/2025 22:45 5/24/2025 23:15 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 5/24/2025 23:15 5/25/2025 00:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #3 4" spear T/ 225'. SOW=35K. 0.0 225.0 5/25/2025 00:00 5/25/2025 04:00 4.00 COMPZN, RPCOMP TRIP P TIH F/ 225' T/ 8382'. PUW=135K, SOW=95K. 225.0 8,382.0 5/25/2025 04:00 5/25/2025 05:15 1.25 COMPZN, RPCOMP FISH P Wash into PBR @ 1.5 BPM, 230 PSI. PSI increase as entered PBR top @ 8394' T/ 260 PSI. Set 10K down @ 8401'. P/U bleed jars. Straight pull T/ 250K pipe free. PUW 140K-150K. Worked stand up back down F/ 8390' T/ 8330', five times to wear element down. 8,382.0 8,379.0 5/25/2025 05:15 5/25/2025 07:45 2.50 COMPZN, RPCOMP CIRC P Circ well @ 2.5 BPM, ICP= 640 PSI. Through gas buster. 280 BBls 8,379.0 8,379.0 5/25/2025 07:45 5/25/2025 08:15 0.50 COMPZN, RPCOMP OWFF P .Monitor well. Gas breaking out at surface 8,379.0 8,379.0 5/25/2025 08:15 5/25/2025 09:00 0.75 COMPZN, RPCOMP CIRC P Line up. Circ 100 BBls, 8,379.0 8,379.0 5/25/2025 09:00 5/25/2025 09:30 0.50 COMPZN, RPCOMP OWFF P Open well and monitor, Well static, Blow down top drive 8,379.0 8,379.0 5/25/2025 09:30 5/25/2025 14:00 4.50 COMPZN, RPCOMP TRIP P Trip out from 8379, PUW=144K 8,379.0 225.0 5/25/2025 14:00 5/25/2025 15:30 1.50 COMPZN, RPCOMP BHAH P At intensifier. Lay down BHA #3, Rack back two stands of collars. Attempt to release spear from fish. Unable to release fish. Hot shot spear in PBR to BOT for removal. Recover 89.97' fish with Poor boy overshot, X nipple and packer 225.0 0.0 5/25/2025 15:30 5/25/2025 17:00 1.50 COMPZN, RPCOMP BHAH P Clear and clear floor. M/U BHA #4 5 3/4" with 3 1/2" grapple Overshot 0.0 223.5 5/25/2025 17:00 5/25/2025 20:30 3.50 COMPZN, RPCOMP TRIP P TIH F/ 223' T/ 8472', PUW=134K, SOW=98K. 223.5 8,472.0 5/25/2025 20:30 5/26/2025 00:00 3.50 COMPZN, RPCOMP FISH P Circ @ 3 BPM, 550 PSI, 2 BPM, 240 PSI. Rot @ 10 RPM, 3.6K Free Tq. ROT=1115. Wash & ream over fish top, saw PSI increase T/ 530 PSI @ 8481'. Shut down pump, PSI held. Set 10K down @ 8484'. Kill rotary. P/U bleed jars. Straight pull T? 250K. Pressure up T/ 2500 PSI. Pressure holding. Bleed PSI off. Warm up jars, hit jars 50x @ 100K over. Straight pull T/ 270K. Pump down DP pressure up T/ 2000 PSI. Hit jars 1x @ 115K over. Pipe free. PUW =140K. P/U T/ 8469'. Circ @ 2 BPM, 240 PSI. TIH saw PSI increase T/ 600 PSI @ 8479'. 8,472.0 8,479.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 5/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/26/2025 00:00 5/26/2025 02:00 2.00 COMPZN, RPCOMP CIRC P P/U T/ 8469'. Circ @ 3 BPM. 570 PSI. Overboard contaminated fluid at BU. Perform post jarring derrick inspection. B/D TD. 8,484.0 8,469.0 5/26/2025 02:00 5/26/2025 06:00 4.00 COMPZN, RPCOMP TRIP P TOOH F/ 8469' T/ 233' 8,469.0 223.0 5/26/2025 06:00 5/26/2025 07:30 1.50 COMPZN, RPCOMP BHAH P At collars, Lay down BHA # 4, Recovered Seals, PBR, and inner packer mandrel, OAL-27.64 223.0 0.0 5/26/2025 07:30 5/26/2025 08:00 0.50 COMPZN, RPCOMP BHAH P Clear and clean rig floor. Load BHA #5 spear. Break down spear for incoming spear extension 0.0 0.0 5/26/2025 08:00 5/26/2025 08:30 0.50 COMPZN, RPCOMP SVRG P Lubricate crown, draw works, blocks, and top drive 0.0 0.0 5/26/2025 08:30 5/26/2025 10:00 1.50 COMPZN, RPCOMP WAIT P Consult town, Formulate plan forward. Need to get spear extension to spear remaining inner mandrel in packer #2 0.0 0.0 5/26/2025 10:00 5/26/2025 12:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #5, 3.001 grapple with 7.15' extension 0.0 229.2 5/26/2025 12:00 5/26/2025 14:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #5 229.2 8,508.0 5/26/2025 14:30 5/26/2025 15:30 1.00 COMPZN, RPCOMP PULD P P/U Single, Obtain parameters PUW=144K, SOW=95K, 1 BPM=205 PSI, 2 BPM =695 PSI, 3 BPM=1352 PSI. Pump 2 BPM continue in hole 8508 see pressure increase. S/D pump Bottom out @ 8513 8,508.0 8,513.0 5/26/2025 15:30 5/26/2025 18:00 2.50 COMPZN, RPCOMP FISH P 8513. PUH to 155K fish on. Start jarring @ 100K over. Straight pull to 260 Work on establishing circulation. Total of 80 jar licks.. Consult town. Work BHA. Able to circulate 2.5 BBl/Min @ 1080 PSI 8,513.0 8,513.0 5/26/2025 18:00 5/26/2025 18:30 0.50 COMPZN, RPCOMP FISH P Crew change out, PJSM for jarring operations 8,513.0 8,513.0 5/26/2025 18:30 5/26/2025 19:30 1.00 COMPZN, RPCOMP FISH P Continue to work fish 8,513.0 8,513.0 5/26/2025 19:30 5/26/2025 21:30 2.00 COMPZN, RPCOMP CIRC P Getting gas break out at surface. Circulate BU 2 BPM @ 1198 8,513.0 8,513.0 5/26/2025 21:30 5/26/2025 22:30 1.00 COMPZN, RPCOMP FISH P Resume fishing. Jar @ 130K over. Straight pull T/ 320K. 44 jar licks. For total of 124 hits. 8,513.0 8,513.0 5/26/2025 22:30 5/26/2025 23:00 0.50 COMPZN, RPCOMP SVRG P Perform derrick inspection post jarring 8,513.0 8,513.0 5/26/2025 23:00 5/27/2025 00:00 1.00 COMPZN, RPCOMP FISH P Resume fishing. Jar #@ 130K over. Straight pull T/ 350K. 33 jar licks. On hit 177 P/U T/ 350K. Pipe free. 8,513.0 8,513.0 5/27/2025 00:00 5/27/2025 00:30 0.50 COMPZN, RPCOMP PULD P L/D 2 working singles F/ 8513' T/ 8469'. PUW=14K. 8,513.0 8,469.0 5/27/2025 00:30 5/27/2025 02:15 1.75 COMPZN, RPCOMP CIRC P Circ STS @ 3 BPM, 580 PSI. Perform post jarring derrick inspection. Replace broken tie wire on guard bold. B/D TD. 8,469.0 8,469.0 5/27/2025 02:15 5/27/2025 06:30 4.25 COMPZN, RPCOMP TRIP P TOOH F/ 8469' T/ 229'. PUW=148K. 8,469.0 229.0 5/27/2025 06:30 5/27/2025 07:45 1.25 COMPZN, RPCOMP BHAH P L/D BHA #5. PUW=38K. Spear broke off. Stuck in packer. 229.0 0.0 5/27/2025 07:45 5/27/2025 09:45 2.00 COMPZN, RPCOMP SLPC P Slip & cut 66' of drill line. Mobilize fishing tools from Deadhorse. 0.0 0.0 5/27/2025 09:45 5/27/2025 10:45 1.00 COMPZN, RPCOMP WAIT P Wait on fishing tools to be mobilized from Deadhorse. 0.0 5/27/2025 10:45 5/27/2025 11:45 1.00 COMPZN, RPCOMP SVRG P Work on top drive link tilt. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 6/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/27/2025 11:45 5/27/2025 12:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6 Spear w/ no grapple T/ 224'. SOW=38K. 0.0 224.0 5/27/2025 12:15 5/27/2025 14:45 2.50 COMPZN, RPCOMP TRIP P RIH F/ 224/ T/ 8381' 224.0 8,381.0 5/27/2025 14:45 5/27/2025 16:00 1.25 COMPZN, RPCOMP WASH P Wash in @ 1.5 BPM, 470 PSI. F/ 8381' T/ 8505' PSI increase T/ 620 PSI taking weight. Push down T/ 8508' w/ 5K. 8,381.0 8,508.0 5/27/2025 16:00 5/27/2025 16:30 0.50 COMPZN, RPCOMP OWFF P P/U T/ 8470'. OWFF. B/D TD. 8,508.0 8,470.0 5/27/2025 16:30 5/27/2025 20:30 4.00 COMPZN, RPCOMP TRIP P TOOH F/ 8470' T/ 224', PUW=140K. 8,470.0 150.0 5/27/2025 20:30 5/27/2025 21:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA# 6 150.0 0.0 5/27/2025 21:30 5/27/2025 22:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor prep tools for BHA 0.0 0.0 5/27/2025 22:00 5/27/2025 23:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 7 , burn over shoe w/ wash pipe 0.0 285.0 5/27/2025 23:00 5/28/2025 00:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole with burn over BHA T/ 1500' 285.0 1,500.0 5/28/2025 00:00 5/28/2025 03:00 3.00 COMPZN, RPCOMP TRIP P Continue in hole with burn shoe T/ 8,507' 1,500.0 8,507.0 5/28/2025 03:00 5/28/2025 08:00 5.00 COMPZN, RPCOMP MILL P Obtain perameters // Up Wt=135 Dn Wt=95 // Rot 65 rpm @ 4,300 tq free // Pump 4 bpm @ 993 psi // Dry tag top of packer @ 8,507' w/ 10K WOB, bring on pumps pumping viscosified seawater 42 vis Mill F/ 8,507.5' T/ 8509'', TQ 7,300 ft/lbs, PP= 733 psi, 8,507.0 8,509.0 5/28/2025 08:00 5/28/2025 10:00 2.00 COMPZN, RPCOMP CIRC P Pump hi-vis pill around @ 4 BPM, 680 PSI. P/U T/ 8437'. B/D TD. 8,509.0 8,437.0 5/28/2025 10:00 5/28/2025 13:15 3.25 COMPZN, RPCOMP TRIP P TOOH F/ 8437' T/ 285'. PUW=135K. 8,437.0 285.0 5/28/2025 13:15 5/28/2025 15:00 1.75 COMPZN, RPCOMP BHAH P L/D BHA #7. PUW=39K. 285.0 0.0 5/28/2025 15:00 5/28/2025 15:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipeshed. 0.0 0.0 5/28/2025 15:30 5/28/2025 16:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #8 Spear T/ 226'. SOW=38K. 0.0 226.0 5/28/2025 16:00 5/28/2025 19:15 3.25 COMPZN, RPCOMP TRIP P TIH w/ BHA# 8 spear, T/ 8475' make up TD to string 226.0 8,475.0 5/28/2025 19:15 5/28/2025 20:45 1.50 COMPZN, RPCOMP FISH P Pu Wt 160K Dn Wt 90K // Pump 1 bpm @ 230 psi, 1.5 bpm @ 291 psi, 2 bpm @ 386 psi, 3 bpm @ 589 psi Work spear into fish @ 8,508.5', posative indicator 200 psi pump increase, continue to work spear into fish pump 1 bpm @ 444 psi Work spear into fish T/ 8,509' ( 1.5' ) Pick up 180k bleed off jars Straight pull 225k fish moving up hole 8,475.0 8,509.0 5/28/2025 20:45 5/28/2025 21:30 0.75 COMPZN, RPCOMP CIRC P Pump 3 bpm @ 660 psi ( Circulate B/U ) 8,509.0 8,472.0 5/28/2025 21:30 5/28/2025 22:00 0.50 COMPZN, RPCOMP OWFF P Flow check well 8,472.0 8,472.0 5/28/2025 22:00 5/29/2025 00:00 2.00 COMPZN, RPCOMP TRIP P TOOH w/ fish // showing drag and tendency to swab, slow trip speed to 45'/min 8,472.0 7,100.0 5/29/2025 00:00 5/29/2025 04:30 4.50 COMPZN, RPCOMP TRIP P TOOH w/ fish, swabbing tendencies slow trip rate to maintain hole fill 7,100.0 226.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 7/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/29/2025 04:30 5/29/2025 05:45 1.25 COMPZN, RPCOMP BHAH P Lay down BHA# 8 along with fish // Packer body, OAL=4.35'. Mobilize grapples for up coming runs from Baker Deadhorse. 226.0 0.0 5/29/2025 05:45 5/29/2025 06:15 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & Pipe Shed. 0.0 0.0 5/29/2025 06:15 5/29/2025 06:45 0.50 COMPZN, RPCOMP SVRG P Service rig. Change out link tilt valve bank. 0.0 5/29/2025 06:45 5/29/2025 09:45 3.00 COMPZN, RPCOMP WAIT P Wait on fishing tools. 0.0 0.0 5/29/2025 09:45 5/29/2025 10:15 0.50 COMPZN, RPCOMP BOPE P Weekly BOPE function test. 0.0 0.0 5/29/2025 10:15 5/29/2025 11:00 0.75 COMPZN, RPCOMP BHAH P Pick up BHA# 9 Overshot T/ 223'. SOW=37K. 0.0 223.0 5/29/2025 11:00 5/29/2025 14:15 3.25 COMPZN, RPCOMP TRIP P TIH F/ 223' T/ 8472'. PUW=165K, SOW=89K 223.0 8,472.0 5/29/2025 14:15 5/29/2025 15:00 0.75 COMPZN, RPCOMP FISH P K/U circ @ 1 BPM, 242 PSI. 2 BPM, 325 PSI. 3 BPM, 468 PSI. Rot @ 20 RPM, 6.5K Free Tq. Kill rotary, wash over fish @ 1 BPM, 224 PSI. Saw PSI increase @ 8509'. Swallow T/ 8511' w/ 20K SO. P/U pipe moving @ 185K. L/D working singles T/ 8469' PUW=165-170K. 8,472.0 8,469.0 5/29/2025 15:00 5/29/2025 15:15 0.25 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 8,469.0 8,469.0 5/29/2025 15:15 5/29/2025 20:00 4.75 COMPZN, RPCOMP TRIP P TOOH F/ 8469'. T/ 223', PUW=168K. 8,469.0 150.0 5/29/2025 20:00 5/29/2025 22:00 2.00 COMPZN, RPCOMP BHAH P Rack back collars , lay down overshot and broken spear // PJSM talk about plan of laying down double fishing tools Lay down spear and overshot 150.0 150.0 5/29/2025 22:00 5/30/2025 00:00 2.00 COMPZN, RPCOMP PULL P Lay down GLM and blast jts // WRBP found in lowest GLM 150.0 100.0 5/30/2025 00:00 5/30/2025 02:30 2.50 COMPZN, RPCOMP PULL P Continue laying down lower completion // found 3rd jt of blast rings parted estimated @ 8,800', estimate ~ 540 blast rings left in hole Blast ring jts recovered 31.11' & 29.71' 100.0 0.0 5/30/2025 02:30 5/30/2025 05:30 3.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor. Wait on orders. 0.0 0.0 5/30/2025 05:30 5/30/2025 07:30 2.00 COMPZN, RPCOMP SLPC P Slip & cut 66' of drill line. 0.0 0.0 5/30/2025 07:30 5/30/2025 08:00 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 5/30/2025 08:00 5/30/2025 09:30 1.50 COMPZN, RPCOMP CLEN P Clear pipe shed. Mobilize tools for BHA #10 0.0 0.0 5/30/2025 09:30 5/30/2025 11:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #10 clean out assemvbly T/ 271'. SOW=45K. 0.0 271.0 5/30/2025 11:00 5/30/2025 13:30 2.50 COMPZN, RPCOMP TRIP P TIH F/ 271' T/ 7131'. PUW=145K, SOW=80K. 271.0 7,131.0 5/30/2025 13:30 5/30/2025 15:00 1.50 COMPZN, RPCOMP REAM P Wash & ream in hole through upper packer set depth. F/ 7131' T/ 7493'. Pump @ 4 BPM, 750 PSI. Rot @ 65 RPM, 6K Free Tq. ROT=107K. 7,131.0 7,493.0 5/30/2025 15:00 5/30/2025 15:30 0.50 COMPZN, RPCOMP TRIP P TIH F/ 7493' T/ 8335. PUW=170K, SOW=91K. 7,493.0 8,335.0 5/30/2025 15:30 5/30/2025 18:00 2.50 COMPZN, RPCOMP REAM P Wash & ream in hole through lower packer set depth & perfs. F/ 8335' T/8,808'. Pump @ 4 BPM, 800 PSI. Rot @ 65 RPM, 8K Free Tq. ROT=120K. 8,335.0 8,808.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 8/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/30/2025 18:00 5/30/2025 20:00 2.00 COMPZN, RPCOMP CIRC P Circulate sweeps 35 bbls 250 vis 8,808.0 8,700.0 5/30/2025 20:00 5/30/2025 22:30 2.50 COMPZN, RPCOMP MPSP P TOOH 2 stands // Pick up storm packer // Set @ 89' COE // Test from above 1000 psi 10 min 8,700.0 8,621.0 5/30/2025 22:30 5/31/2025 00:00 1.50 COMPZN, RPCOMP NUND P Suck out stack and remove riser // ND BOPs 8,621.0 8,621.0 5/31/2025 00:00 5/31/2025 05:00 5.00 COMPZN, RPCOMP CUTP P Grow casing .25" let stand 30 min remove tubing head, spear casing pull 100k up on casing // Pull 100k over and set slips 11 in stretch 11.25" total OAG. Cut excess 7" of with WHACKS saw. 8,621.0 8,621.0 5/31/2025 05:00 5/31/2025 07:45 2.75 COMPZN, RPCOMP NUND P Install packoffs // Nipple up C-Bowl Tubing Head. 8,621.0 8,621.0 5/31/2025 07:45 5/31/2025 08:00 0.25 COMPZN, RPCOMP PRTS P PT pack off T/ 3000 PSI for 10 Min. 8,621.0 8,621.0 5/31/2025 08:00 5/31/2025 10:30 2.50 COMPZN, RPCOMP NUND P Install secondary IA valve. Install test plug. N/U BOP. 8,621.0 8,621.0 5/31/2025 10:30 5/31/2025 11:00 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. 8,621.0 8,621.0 5/31/2025 11:00 5/31/2025 11:30 0.50 COMPZN, RPCOMP PRTS P PT stack breaks 250/3000 PSI for 5 Min each. 8,621.0 8,621.0 5/31/2025 11:30 5/31/2025 12:30 1.00 COMPZN, RPCOMP RURD P R/D, B/D testing equipment. Drain stack. Pull test plug. Set wear bushing. 8,621.0 8,621.0 5/31/2025 12:30 5/31/2025 13:15 0.75 COMPZN, RPCOMP MPSP P Run stand. Engage, equalize & release storm packer. Rack back stand. L/D retrievial head & storm packer. PUW- 177K. 8,621.0 8,525.0 5/31/2025 13:15 5/31/2025 14:30 1.25 COMPZN, RPCOMP DISP P Displace well to neat 10.4# brine @ 5 BPM, 1500 PSI. 8,525.0 8,525.0 5/31/2025 14:30 5/31/2025 14:45 0.25 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 8,525.0 8,525.0 5/31/2025 14:45 5/31/2025 15:45 1.00 COMPZN, RPCOMP TRIP P TOOH F/ 8525' T/ 6200'. PUW=177K. 8,525.0 6,200.0 5/31/2025 15:45 5/31/2025 20:45 5.00 COMPZN, RPCOMP PULD P LDDP F/ 2600' T/ 271'. PUW=170K. 6,200.0 271.0 5/31/2025 20:45 5/31/2025 22:15 1.50 COMPZN, RPCOMP BHAH P Lay down BHA and collars 271.0 0.0 5/31/2025 22:15 5/31/2025 22:45 0.50 COMPZN, RPCOMP OTHR P Pull wear ring 0.0 0.0 5/31/2025 22:45 6/1/2025 00:00 1.25 COMPZN, RPCOMP CLEN P Clean and clear floor and shed from tools, prep for running casing 0.0 0.0 6/1/2025 00:00 6/1/2025 11:45 11.75 COMPZN, RPCOMP PUTB P PJSM, Pick up and run 3.5" completion per approved tally T/ 8525'. PUW=104K, SOW=72K. 0.0 8,525.0 6/1/2025 11:45 6/1/2025 12:45 1.00 COMPZN, RPCOMP HOSO P M/U hanger & landing joint. Land hanger w/ BTM of WLEG @ 8555.29'. RILDS. 8,525.0 8,555.3 6/1/2025 12:45 6/1/2025 13:00 0.25 COMPZN, RPCOMP RURD P R/U circ equipment. 8,555.3 8,555.3 6/1/2025 13:00 6/1/2025 14:30 1.50 COMPZN, RPCOMP CRIH P Reverse circ 250 Bbls 10.4 CI brine down IA, chased w/ 5 Bbls neat 10.4# @ 3 BPM, 250 PSI. 8,555.3 8,555.3 6/1/2025 14:30 6/1/2025 15:30 1.00 COMPZN, RPCOMP RURD P B/D, R/D circ equipment. Drop ball & rod. R/U testing equipment. 8,555.3 8,555.3 6/1/2025 15:30 6/1/2025 16:15 0.75 COMPZN, RPCOMP PACK P Pressure up set tandem SLB packers T/ 4200 PSI. Held for 30 Min. Passing TBG test. 8,555.3 8,555.3 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Page 9/9 1Q-04 Report Printed: 6/26/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/1/2025 16:15 6/1/2025 17:15 1.00 COMPZN, RPCOMP PRTS P Bleed TBG t/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump TBG pressure, shear out SOV. Pump down IA @ 2 BPM, 300 PSI. 8,555.3 8,555.3 6/1/2025 17:15 6/1/2025 18:15 1.00 COMPZN, RPCOMP RURD P B/D, R/D TBG testing equipment. 8,555.3 0.0 6/1/2025 18:15 6/1/2025 19:00 0.75 COMPZN, WHDBOP MPSP P Install BPV and test 1000 psi good test 0.0 0.0 6/1/2025 19:00 6/1/2025 20:00 1.00 COMPZN, WHDBOP CLEN P Clean floor and cellar for nipple down 0.0 0.0 6/1/2025 20:00 6/1/2025 21:30 1.50 COMPZN, WHDBOP NUND P Nipple down BOPs 0.0 0.0 6/1/2025 21:30 6/1/2025 23:00 1.50 COMPZN, WHDBOP NUND P Nipple up tree adapter and production tree, PT void 5000 psi 0.0 0.0 6/1/2025 23:00 6/2/2025 00:00 1.00 COMPZN, WHDBOP RURD P Rig up circulating equipment for freeze protect 0.0 0.0 6/2/2025 00:00 6/2/2025 01:30 1.50 COMPZN, WHDBOP FRZP P Rig up LRS PT lines and tree 5000 psi, pump 85 bbls down IA FCP 2 BPM @ 1050 psi 0.0 0.0 6/2/2025 01:30 6/2/2025 03:00 1.50 DEMOB, MOVE RURD P Let well U-tube // MISC rig down prep to pull off well // Rig Release 03:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/2/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: TAG - EST 63' of RAT HOLE 9,366.0 1Q-04 10/14/2002 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLD, pulled B&R & RHC 1Q-04 6/18/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: OVERSHOT, STABBED INTO REMAINING PORTION OF 1985 COMPLETION 2/10/2006 osborl NOTE: SIDETRACKED MULT-LATERAL WELL w/4 LATERALS; ONLY L1-03 ACCESSIBLE 2/10/2006 osborl NOTE: MULTIPLE TUBING LEAKS FOUND FOLLOWING CTD WORK 2/6/2006 osborl 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 15.06 36.0 103.0 103.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 4,621.7 3,570.7 36.00 J-55 BTC PRODUCTION 7 6.28 32.9 9,510.9 6,919.9 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.9 Set Depth … 8,555.3 String Max No… 3 1/2 Set Depth … 6,231.4 Tubing Description Tubing – Production 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) 25.9 25.9 0.03 Hanger 7.100 Cameron CXS 7 1/16" x 3 1/2" TBG hanger. EUE top thread. Camero n CXS 2.950 3,438.4 2,796.9 48.02 Mandrel – GAS LIFT 5.973 3.5" x 1.5" MMG, GLM SLB MMG 2.920 6,688.6 4,881.2 47.84 Mandrel – GAS LIFT 5.970 3.5" x 1.5" MMG, GLM, SLB MMG 2.920 7,248.6 5,273.8 43.96 Mandrel – GAS LIFT 5.970 3.5" x 1.5" MMG, GLM, SLB MMG 2.920 7,308.5 5,317.0 43.73 Packer 6.276 SLB 3.5" x 7" BluePack MAX RH Packer, SLB BluePac k Max RH 2.885 7,366.0 5,358.6 43.72 Nipple - X 4.525 3.5" x 2.813", X-Nipple Halliburt on X Nipple 2.813 8,477.6 6,172.8 41.12 Packer 6.276 SLB 3.5" x 7" BluePack MAX RH Packer, SLB BluePac k Max RH 2.885 8,535.5 6,216.5 41.14 Nipple - X 4.525 3.5" x 2.813", X-Nipple Halliburt on X Nipple 2.813 8,554.8 6,231.0 41.17 Wireline Guide 4.500 3 1/2" WLEG WLEG 2.992 Top (ftKB) 8,806.5 Set Depth … 9,023.3 String Max No… 3 1/2 Set Depth … 6,578.5 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,806.5 6,419.8 41.98 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 8,854.6 6,455.4 42.45 BLAST JT 4.500 STEEL BLAST JOINT (OAL = 24.58') 3.000 8,910.6 6,496.6 42.97 PRODUCTION 5.750 CAMCO MMG-2 2.920 8,950.2 6,525.5 43.24 LOCATOR 3.750 BAKER LOCATOR SUB w/ 5' SEALS 3.000 8,951.0 6,526.1 43.25 PACKER 5.875 BAKER FB-1 PACKER 4.000 8,954.3 6,528.5 43.27 SBE 5.625 BAKER SEAL BORE EXTENSION 3.000 8,989.4 6,554.0 43.51 NIPPLE 4.500 CAMCO D NIPPLE w/ NO GO PROFILE 2.750 9,022.5 6,578.0 43.78 SOS 4.500 CAMCO SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,440.0 5,412.0 43.68 LEAK - CASING CASING LEAK AT ~7440' RKB IDENTIFIED VIA ACOUSTIC LDL (0.58 BPM, 2850 PSI) 8/23/2024 6.280 8,803.0 6,417.2 41.95 OBSTRUCTI ON ~ 540 blast rings free floating on top of last blast ring jt. blast ring joints parted leaving them in the hole while pulling completion 5/30/2025 0.000 9,021.0 6,576.9 43.76 CEMENT CEMENT PLUG FOR SIDETRACK 10/7/2005 9,066.0 6,609.3 44.15 Window L1-03 WINDOW TO L1-03, L1-02, L1 -01, L1 10/24/2005 6.151 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) 3,438.4 2,796.9 48.02 1 GAS LIFT GLV RK 1,186.0 6/17/2025 SLB MMG 0.188 6,688.6 4,881.2 47.84 2 GAS LIFT GLV RK 1,263.0 6/17/2025 SLB MMG 0.313 7,248.6 5,273.8 43.96 3 GAS LIFT OV RK 6/17/2025 SLB MMG 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,709.0 8,719.0 6,347.0 6,354.5 C-4, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,722.0 8,726.0 6,356.7 6,359.7 C-4, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 1Q-04, 6/26/2025 3:45:12 PM Vertical schematic (actual) PRODUCTION; 32.9-9,510.9 Window L1-03; 9,066.0 LINER L1-03; 9,064.3-10,570.0 CMT PLUG; 9,021.0 ftKB PACKER; 8,951.0 IPERF; 8,914.0-8,928.0 PRODUCTION; 8,910.6 IPERF; 8,834.0-8,881.0 OBSTRUCTION; 8,803.0 IPERF; 8,771.0-8,777.0 IPERF; 8,756.0-8,764.0 IPERF; 8,742.0-8,753.0 IPERF; 8,735.0-8,740.0 IPERF; 8,722.0-8,726.0 IPERF; 8,709.0-8,719.0 Nipple - X; 8,535.5 Packer; 8,477.6 LEAK - CASING; 7,440.0 Nipple - X; 7,366.0 Packer; 7,308.5 Mandrel – GAS LIFT; 7,248.6 Mandrel – GAS LIFT; 6,688.6 SURFACE; 35.2-4,621.7 Mandrel – GAS LIFT; 3,438.4 CONDUCTOR; 36.0-103.0 Hanger; 25.9 KUP PROD KB-Grd (ft) 42.49 RR Date 3/19/1985 Other Elev… 1Q-04 ... TD Act Btm (ftKB) 9,535.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292125000 Wellbore Status PROD Max Angle & MD Incl (°) 52.95 MD (ftKB) 5,400.00 WELLNAME WELLBORE1Q-04 Annotation Last WO: End Date 2/10/2006 H2S (ppm) 55 Date 7/15/2019 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,735.0 8,740.0 6,366.5 6,370.2 C-4, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,742.0 8,753.0 6,371.7 6,379.9 C-4, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,756.0 8,764.0 6,382.2 6,388.2 C-4, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,771.0 8,777.0 6,393.4 6,397.9 C-3, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,834.0 8,881.0 6,440.2 6,474.9 C-1, UNIT B, 1Q -04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC 8,914.0 8,928.0 6,499.1 6,509.3 UNIT B, 1Q-04 4/24/1985 12.0 IPERF 120° ph;5"Scalloped HDC Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,021.0 9,511.0 6,576.9 6,920.0 CMT PLUG 1Q-04, 6/26/2025 3:45:13 PM Vertical schematic (actual) PRODUCTION; 32.9-9,510.9 Window L1-03; 9,066.0 LINER L1-03; 9,064.3-10,570.0 CMT PLUG; 9,021.0 ftKB PACKER; 8,951.0 IPERF; 8,914.0-8,928.0 PRODUCTION; 8,910.6 IPERF; 8,834.0-8,881.0 OBSTRUCTION; 8,803.0 IPERF; 8,771.0-8,777.0 IPERF; 8,756.0-8,764.0 IPERF; 8,742.0-8,753.0 IPERF; 8,735.0-8,740.0 IPERF; 8,722.0-8,726.0 IPERF; 8,709.0-8,719.0 Nipple - X; 8,535.5 Packer; 8,477.6 LEAK - CASING; 7,440.0 Nipple - X; 7,366.0 Packer; 7,308.5 Mandrel – GAS LIFT; 7,248.6 Mandrel – GAS LIFT; 6,688.6 SURFACE; 35.2-4,621.7 Mandrel – GAS LIFT; 3,438.4 CONDUCTOR; 36.0-103.0 Hanger; 25.9 KUP PROD 1Q-04 ... WELLNAME WELLBORE1Q-04 Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'1Q-0450-029-21250-00 910027200Kuparuk RiverTubing Cut RecordField- Final14-May-25018 1Q-0450-029-21250-00 910027200Kuparuk RiverTubing Cut RecordField- Final15-May-2501184-234 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Glasheen, Brian Subject:RE: [EXTERNAL]Sundry_325-223_051225.pdf 1Q-04 PDT(184-234) Date:Monday, May 19, 2025 9:53:42 AM Thanks for the update Brian. Jack From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Monday, May 19, 2025 9:10 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]Sundry_325-223_051225.pdf 1Q-04 PDT(184-234) Jack, This is an inform that we will be swapping out the tubing head during the RWO on 1Q-04 if the seals are not able to be reused and or we must use our contingency. This will occur on the trip out with the last fishing run. See steps below. 1. Prior to pulling out of hole with fishing BHA set Storm packer at ~50’ and pressure test. 2. ND BOPE. RU Cameron casing growth system on tubing head if needed. ND tubing head. 3. Replace tubing head with Cameron C-bowl Retro/ 5.5’’ Well head if needed. 4. Test 7’’ packoffs to 3000 psi. 5. NU BOP. 6. Install test plug and shell test BOPE and flange break to 250/ 2,500 psi. 7. Release storm packer and continue pulling fishing BHA. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, May 12, 2025 4:30 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: [EXTERNAL]Sundry_325-223_051225.pdf CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brian, After reviewing the CoA and seeing the PC leak is deep and below the TOC then I approve removing the following CoA “Ensure proposed packers above perfs are pressure tested” Jack From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 1Q-04 (184-234) Date:Friday, April 25, 2025 11:40:56 AM Attachments:image001.png From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Monday, April 21, 2025 2:36 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KRU 1Q-04 (184-234) Yes please. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 21, 2025 2:29 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1Q-04 (184-234) So use the same table as below? If so I will include it in the sundry package. From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Monday, April 21, 2025 2:28 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KRU 1Q-04 (184-234) Hey Jack, Yes we would do the same and apply any of the changes that come out in the CO that you are currently working on. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 21, 2025 2:15 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: [EXTERNAL]KRU 1Q-04 (184-234) Brian – Regarding the tie-back contingency for KRU 1Q-04 (leak above 6095’), for similar uncemented tiebacks CPAI has been performing a risk assessment and including a monitoring table. See below. Are you planning to do the same? Thanks, Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Thursday, April 3, 2025 9:07 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Jack – Thank you for your prompt review of this request! A risk assessment was performed and 2N-315 will require an internal waiver to operate as a gas lifted producer. Below is a table noting the additional monitoring required under the internal waiver. Please reach out with any additional questions. Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, April 2, 2025 11:42 AM To: Manning, Leslie <Leslie.Manning@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Hi Leslie, This well appears very similar to the 1R-35 single barrier repair (uncemented tie-back with PC leaks and open shoe), for which CPAI performed a risk assessment and submitted the attached monitoring plan (single barrier mitigations table). Was a similar risk assessment performed? If so, what are the mitigations? Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Tuesday, April 1, 2025 10:26 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 Jack / Victoria – I will be OOO 4/10 -4/22; the 2N-315 RWO is scheduled to start ~4/23. If you complete your review of this Sundry request later than 4/9, please cc Brian Glasheen so that he can answer any questions you may have. Thank you! Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Tuesday, April 1, 2025 10:23 AM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2N-315 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, March 28, 2025 3:19 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: KRU 2N-315 10-403 Hello – See attached 10-403 or KRU 2N-315. Please let me know if you need additional information. Thank you Jenna 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9535'2007 8526' 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: 907-545-1144 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9021' 9-5/8" 67'103' Baker FHL Retrievable Baker FHL Retrievable Baker FB-1 SSSV: None 6937'9021'8577' 7" 16" KRU 1Q-04 8709-8719' 8722-8726' 8735-8740' 8742-8753' 8756-8764' 8771-8777' 8834-8881' 8914-8928' 9478' 6347-6355' 6357-6360' 6367-6370' 6372-6380' 6382-6388' 6393-6398' 6440-6475' 6499-6509' 4587' 9511' Perforation Depth MD (ft): 3-1/2" 4-1/2" 103' 4622' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025634 184-234 P.O. Box 100360, Anchorage, AK 99510 50-029-21250-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8420'MD/6129'TVD 8532'MD/6214'TVD 8979'MD/6546'TVD 8484' 9051' Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3571' Burst 5/15/2025 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6920' Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 J-55 m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-223 By Gavin Gluyas at 9:16 am, Apr 14, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.04.11 08:08:17-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen SFD 5/5/2025 X DSR-4/17/25 10-404 JJL 04/21/25 , ADL0025641 SFD AOGCC witnessed BOP and annular test to 2500 psi.Biennial MIT-T with plug set below packer at ~8200', Biennial IA DDT with fluid levels or MITIAEnsure proposed packers above perfs are pressure tested Note: CoA may change with the outcome of the 3M-19 request for consideration and docket OTH-25-016.For tieback contingency Operator shall operate well per " risk assessed single barrier mitigation table"attachment *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.12 08:04:28 -08'00'05/12/25 RBDMS JSB 051225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 10, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1Q-04 (PTD# 184-234). Well 1Q-04 was drilled and completed in 1985 as a gas lift Kuparuk producer . The well has holes in the tubing and a casing leak at 7440' that will require a rig to repair the casing. There is a WRP stuck at 8513' that was not able to be removed during the pre rig work. The WRP will be address on the rig when the second packer is removed. If you have any questions or require any further information, please contact me at +907-545-1144 The 3-1/2” upper completion will be pulled from a pre-rig cut. Two packer will be removed to retore the selective completion. New 3-1/2” completion with an additional packer to straddle the casing leak will be ran. A contingent tieback option will also be considered if the casing leak is identified above TOC during RWO operations. 1Q-04 Kuparuk Producer Tubing Swap PTD: 184-234 x-11Page 1 of 2 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. DMY all GLM and leave lowest GLM open for circulating 3. SBHP 4. Tubing cut at ~8378’ RKB above the packer. 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1Q-04. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/2500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing and Packers 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. 6. RIH with test packer and set at 7400’ and test above to 2,500 psi to prove casing integrity. 7. Remove packers at 8419’ and 8532’. 8. After packer is removed from 8532’, RU Eline and cut tubing at 8945’ 9. RU fishing BHA and RIH to recover fish Install 3-1/2” Selective Completion 10. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 11. MU new 3-1/2” completion with non-sealing overshot, 3 packers, sliding sleeves, nipple profile, and GLMs. RIH to tubing stub. a. Contingency plan if casing leak is found to be higher than TOC ~6095’ a 5.5’’ tie back string will be installed. Proposed WBS attached. b. Tieback packer will be set at ~ 8200’ and pressure tested to 2500 psi from above to confirm packer is holding. c. 5.5’’ casing will then be ran and stung into seals. 12. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 13. Land tubing hanger, RILDS, PT packoffs and set packer. 14. Pressure test tubing to 3,000 PSI. 15. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 16. Shear out SOV with pressure differential. 17. Install BPV and test. ND BOPE. NU tree. 18. Pull BPV and freeze protect well. 19. RDMO. 1Q-04 Kuparuk Producer Tubing Swap PTD: 184-234 x-11Page 2 of 2 PPost-Rig Work 1. Run GLD. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 5/15/2025 Current Operations: Shut-In Well Type: Producer Wellhead Type: McEvoy, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Rams / Blind Rams / Rams Static BHP: 2627 psi / 6200 TVD measured on 5/30/24 MPSP: 2,007 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut and remove 2 packers. Prove casing integrity. Install a new 3-1/2” completion. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) 1Q-04 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Weight (lb/ft)Grade Conductor #N/A #N/A #N/A #N/A #N/A Surface 3074.7 2431.1 9.625 36 J-55 Production/ Intermediate 11075.9 6998.2 7 26 L-80 Liner #N/A #N/A #N/A #N/A #N/A Tubing 8200 6000 3.5'' 9.3 L-80 PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD 3.5" x 7.0" Packer @ No higher than 6095' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3.5'' Sliding sleeve at xxxx' RKB 3.5'' Sliding sleeve at xxxx' RKB 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker FB-1 Packer @8978' Surface Casing Production Casing Conductor A-sand perfs C-Sand Perfs PC leak 7440 TOC ~ 6095 CBL 85 1Q-04 Proposed RWO Completion Contingent Option COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Weight (lb/ft)Grade Conductor #N/A #N/A #N/A #N/A #N/A Surface 3074.7 2431.1 9.625 36 J-55 Production/ Intermediate 11075.9 6998.2 7 26 L-80 5-1/2'' Tie back 8200 6000 5.5'' 17.5 L-80 Tubing 8200 6000 3.5'' 9.3 L-80 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-1/2'' Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface PBR for 3-1/2" Seals (with port to IA covered with sleeve on install) 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" x 7" Packer @ ~8200 RKB (4" ID) 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3.5'' Sliding sleeve at xxxx' RKB 3.5'' Sliding sleeve at xxxx' RKB 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker FB-1 Packer @8978' Surface Casing Production Casing Conductor A-sand perfs C-Sand Perfs PC leak 7440 Risk Assessed Mitigations Frequency Threshold/Trigger Action Abnormal pressure trends.Further diagnostics to verify well integrity still exists. OA & OOA have an operating pressure limit of 1000 psi (OA > 1000 psi indicates a potential gas lift leak via IAxOA). Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. ϙċÍĖīĖĲČϙI>[ϙŘôŗŪĖŘôŜϙťēôϙſôīīϙťĺϙæôϙŘôŕÍĖŘôîϙſĖťēĖĲϙ͓͐ϙîÍƅŜϙĺŘϙťēôϙſôīīϙıŪŜťϙæôϙŜôèŪŘôîϟϚϙ A failing MIT, which cannot be repaired, requires the well to be secured. Further diagnostics to verify well integrity still exists. Confirmation of IAxOA communication voids the risk assessment and allowance for gas lift. Single Barrier Risk Assessed Mitigations 3. Obtain O anî OO ċīŪiî īôŽôīŜ.Ϛ Annually If the OA fluid level has dropped out more than 200'. ͐. Ϛēô IA, OA & OOA ēave a pressure transmitter to alert operations of abnormal trends. Realtime ͑. AlternatinČ everƅ ͑ϱƅearsϡ ubinČ inteČritƅ fluid level ϼI>[ϽϠ and meèēanièal inteČritƅ test of tēe tubinČ ϼaIϽ ſēièē inèludes tēe sēort seètion of tubinČ beloſ tēe neſ tiebaèħ and neſ paèħer AnnuallƅϠ alternating aI and I>[ ass ϯ >ail. From:Glasheen, Brian To:Lau, Jack J (OGC) Subject:RE: [EXTERNAL]KRU 1Q-04 (184-234) Date:Monday, April 21, 2025 2:36:14 PM Attachments:image001.png Yes please. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 21, 2025 2:29 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1Q-04 (184-234) So use the same table as below? If so I will include it in the sundry package. From: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent: Monday, April 21, 2025 2:28 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KRU 1Q-04 (184-234) Hey Jack, Yes we would do the same and apply any of the changes that come out in the CO that you are currently working on. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, April 21, 2025 2:15 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: [EXTERNAL]KRU 1Q-04 (184-234) Brian – Regarding the tie-back contingency for KRU 1Q-04 (leak above 6095’), for similar uncemented tiebacks CPAI has been performing a risk assessment and including a monitoring table. See below. Are you planning to do the same? Thanks, Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Thursday, April 3, 2025 9:07 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Jack – Thank you for your prompt review of this request! A risk assessment was performed and 2N-315 will require an internal waiver to operate as a gas lifted producer. Below is a table noting the additional monitoring required under the internal waiver. Please reach out with any additional questions. Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, April 2, 2025 11:42 AM To: Manning, Leslie <Leslie.Manning@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 (198-190) Hi Leslie, This well appears very similar to the 1R-35 single barrier repair (uncemented tie-back with PC leaks and open shoe), for which CPAI performed a risk assessment and submitted the attached monitoring plan (single barrier mitigations table). Was a similar risk assessment performed? If so, what are the mitigations? Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Tuesday, April 1, 2025 10:26 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2N-315 10-403 Jack / Victoria – I will be OOO 4/10 -4/22; the 2N-315 RWO is scheduled to start ~4/23. If you complete your review of this Sundry request later than 4/9, please cc Brian Glasheen so that he can answer any questions you may have. Thank you! Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Tuesday, April 1, 2025 10:23 AM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2N-315 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, This application has been received for processing. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Friday, March 28, 2025 3:19 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: KRU 2N-315 10-403 Hello – See attached 10-403 or KRU 2N-315. Please let me know if you need additional information. Thank you Jenna Originated: Delivered to:7-Mar-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1 2 1A-24 50-029-22984-00 909816969 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 1 3 1A-24 50-029-22984-00 909816969 Kuparuk River Plug Setting Record Field- Final 15-Feb-25 0 1 4 1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1 5 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1 6 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1 7 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1 8 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1 9 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1 10 2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T40190 T40191 T40191 T40192 T40193 T40193 T40193 T40194 T40195 T40196 190-162 200-181 223-023 182-051 182-214 184-234 184-035 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 10:25:17 -09'00' 184-234 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-08-23_16005_KRU_1Q-04_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16005 KRU 1Q-04 50-029-21250-00 LeakPoint Survey 23-Aug-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 184-234 T39490 8/26/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.26 14:40:01 -08'00' Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1G-07A 50-029-20872-01 909383029 Kuparuk River Packer Setting Record Field- Final 22-Jul-24 0 1 2 1G-11B 50-029-21008-02 909469734 Kuparuk River Correlation Record ans SBHP Records Field- Final 29-Jul-24 0 1 3 1G-11B 50-029-21008-02 909469734 Kuparuk River SBHP Record Field- Final 29-Jul-24 0 1 4 1G-17 50-029-22945-00 909422685 Kuparuk River Leak Detect Log Field- Final 13-Jul-24 0 1 5 1G-17 50-029-22945-00 909422685 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-24 0 1 6 1G-17 50-029-22945-00 909422685 Kuparuk River Packer Setting Record Field- Final 13-Jul-24 0 1 7 1L-24 50-029-22170-00: 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1Q-04 50-029-21250-00 909422479 Kuparuk River Leak Detect Log Field- Final 10-Jul-24 0 1 9 1Q-04 50-029-21250-00 909422479 Kuparuk River Multi Finger Caliper Field & Processed 10-Jul-24 0 1 10 1Q-09 50-029-21209-00 909422975 Kuparuk River Multi Finger Caliper Field & Processed 19-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 218-051 216-009 199-062 191-066 184-234 184-192 T39436 T39437 T39437 T39438 T39438 T39438 T39439 T39440 T39440 T39441 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:36:38 -08'00' 8 1Q-04 50-029-21250-00 909422479 Kuparuk River Leak Detect Log Field- Final 10-Jul-24 0 1 9 1Q-04 50-029-21250-00 909422479 Kuparuk River Multi Finger Caliper Field & Processed 10-Jul-24 0 1 184-234 Ima ect Well History File ~le 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other:. NOTES: BY: [] Other, No/Type ~REN VINCENT SHERYL MARIA LowELL Project Proofing BY: BEVERLY BRE~SHERYL MARIA LOWELL Scanning Preparation x 30 = ~' BY: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISI Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Stage 2 IF~TAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO YES ~ RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: DATE: IS~ Quality Checked • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~3 ~ 4~~ ~- 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 November 20, 2008 and the corrosion inhibitor/sealant was pumped December 2-3, 2008. 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 90'7-659-7043, if you have any questions. Sincerely, ~,~~ ~ ~ ~ {; ~ ?Q~~ Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 Q-01 184-231 10' 1.25 22" 11 /20/2008 6.80 12/2/2008 1 Q-04 184-234 10' 1.25 22" 11 /20/2008 3.40 12/3/2008 1 Q-07A 198-234 9' 1.10 24" 11 /20/2008 2.95 12/3/2008 1 Q-08A 197-093 8' 1.00 22" 11 /20/2008 3.40 12/3/2008 1 Q-09 184-192 2" NA 2" NA 4.25 12/2/2008 1Q-11 184-199 4'S" 0.50 22" 11/20/2008 4.25 12/2/2008 1Q-12 184-193 21" NA 21" NA 6.80 12/2/2008 1 Q-13 185-044 18" NA 18" NA 5.10 12/2/2008 1 Q-14 185-045 24" NA 24" NA 4.25 12/2/2008 1 Q-23 195-141 24" NA 24" NA 3.40 12/3/2008 Kt:lJt:IVt:LJ STATE OF ALASKA ALASK.L AND GAS CONSERVATION C.ISSION MAR 1 3 2006 REPORT OF SUNDRY WELL OPERATIONSOil&Gas Cons. Commission Anchorage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: 6..-.+~·. BP ,ç¡,(ploraüon-{Al8s'Ka) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 025634' 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 181 Repair Well 181 Pull Tubing 90' 9535' 6937 9021 6577 103' 4622' 9511' ~--- o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension .::2'}t.:.-. 4. Current Well Class: , , '3./s--o¿ 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit 0 Drill Number: 184-234 6. API Number: 50-029-21250-00-00 99519-6612 9. Well Name and Number: Kuparuk 1Q-04 10. Field / Pool(s): Kuparuk River Unit / Kuparuk River Pool'" feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 16" 103' 103' 1640 630 9-5/8" 4622' 3571' 3520 2020 7" 9511' 6920' 4980 4330 8709' - 8928' 6347' - 6509' 3-1/2",9.3# L-80 / J-55 9085' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Baker 'FHL' retrievable packer; Baker 'FHL' packer; Baker 8520'; 8504'; 9013' 'FB-1' packer Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Tubin Pressure Re resentative Dail Gas-Mcf Water-Bbl 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL correct to t e best 0 my knowledge. Sundry Number or N/A if C.O. Exempt: 0('> .NM- 6(3 o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 17. Printed Name Terrie Hubble Title Technical Assistant Signature Form 10-404 Revised 04/2004 564-4628 FL MAk 1 6 ZOOo Date D"3fÌl9/fX? A.. 'ß1(tJG ,,', 'l,¡ró<£ ,~,r:\D Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only / - - Page 1 of 11 BP Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1 Q-04 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 _ D~te I Fro~ - ~~__: HOU~J. Task _~~.ode NP~ ~ Phase ; _ ._. 1/22/2006 06:00 - 07:00 1.00 MOB P PRE 07:00 - 09:20 2.33 MOB PRE P 09:20 - 00:00 14.67 MOB P PRE 1/23/2006 00:00 - 10:30 10.50 MOB P PRE 10:30 - 00:00 13.50 MOB P PRE 1/24/2006 00:00 - 06:00 6.00 MOB P PRE 06:00 - 12:00 6.00 MOB PRE P 12:00 - 18:45 6.75 MOB PRE P 18:45 - 20:45 2.00 MOB P 20:45 - 21 :00 0.25 MOB P 21 :00 - 22:00 1.00 MOB P 22:00 - 00:00 2.00 RIGU P 1/25/2006 00:00-01:15 1.25 RIGU P 01 :15 - 01 :45 0.50 RIGU P 01 :45 - 05:00 3.25 RIGU P 05:00 - 05:20 0.33 WHSUR P 05:20 - 07:45 2.42 WHSUR P 07:45 - 12:30 4.75 WHSUR P 12:30 - 13:00 0.50 WHSUR P 13:00 - 15:00 2.00 WHSUR P 15:00 - 18:00 3.00 BOPSUF P 18:00 - 18:30 0.50 BOPSUF P 18:30 - 22:30 4.00 BOPSUF P 22:30 - 00:00 1.50 BOPSUF P 1/26/2006 00:00 - 06:00 6.00 BOPSUF P PRE PRE PRE PRE PRE PRE PRE WHDTRE WHDTRE WHDTRE WHDTRE WHDTRE PRE PRE PRE PRE PRE Start: 1/22/2006 Rig Release: 2/10/2006 Rig Number: Spud Date: 10/7/2005 End: 2/10/2006 Description of Operations .....--. ....----- --,-- ------ --..-- .-... Warm up moving system, prep to move off well-weather' worsening Place rig on Standby at 0700 hrs due to inclement weather and forecast for worse Send non essential personnel to KOC Presently -38F, 15-25 mph winds w/ -90 WC, Phz 1 Kuparuk start Phz 2 (-34F, 18-32 mph winds) Use rig loader for crew changes Continue WOW Phz 2 (-9F, 18-32 mph SW, -40CF Phz 2 @ 0600 hrs) Kuparuk CPF1, CPF2, GPB go to Phz 3. CPF3 and GPB in Phz 2 (-11 F, 32-46 mph WSW, -62CF w/ blowing snow, low visibility) WOW. Diminishing winds past midnight. Phase 1 on Spine Rd and still Phase III on access roads and pads. 10 pad snowed in. Well Support group plans to clear off this morning. Clearing snow from around rig and camps also clearing 10 pad. Called AOGCC with 12-24hr BOP notice. Pull off 3H-14B. Do Post-Pad Inspection with DSO. Move camps to new location and spot. Rig on the road. Made it to CPF 3 at 1700hrs. Waiting for CP changeout. PJSM Rig arrived on location at 2040 hrs. Spotted near well Held PJSM on backing over well. Move rig over well. Nordic crew change due to flights relays Rig Accepted at 22:00 hrs 1-23-2006. Leveling rig to pad Finished leveling rig. PJSM RU cellar berm, cutting box, RU tiger tank, hardline to same and PT, off load 290 bb19.6 ppg NaCI brine water, RU to reverse circulate and pull BPV. PJSM review hazards assosiated with lubricator and pulling BPV. Review plans for pumping diesel FP from well bore. PU CIW lubricator and pull BPV. Hook-up circulation hoses to cellar manifold. Pump down IA 25bbls 9.6ppg brine displacing diesel. Switch and pump down tbg displacing diesel to Tiger Tank. Set TWC (dry rod) ND 3-1/8" 5M McEvoy tree. Checked LDS. Test hanger threads, made up 7 full rds. NORM tested tree and hauled to Valve Shop. NU 2' spacer spool and 7-1/16" BOP stack, choke/kill lines, and riser. This could take awhile. Very cold temps inside cellar even with heaters going. AOGCC previously notified of test and wavied witnessing. Pre Workover Meeting conducted by S. Mukavitz Finished NU BOP's and riser. Having problems with adaptor below riser, (rust) BOP Test AOGCC Jeff Jones wavered witnessing BOP test Boots on riser failed while hydrostatic testing. Replacing 4 boots on riser while testing some of choke manifold BOP testing and repaired riser boots Printed: 2/13/2006 12:02:20 PM Page 2 of 11 BP Operations Summary Report Start: Rig Release: Rig Number: Phase Legal Well Name: 10-04 Common Well Name: 10-04 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ¡ From - To I Hours I T~~~ ,~~ode NPT 1/26/2006 6.00 BOPSU P 00:00 - 06:00 PRE 06:00 - 08:00 08:00 - 08:30 2.00 WHSUR P 0.50 WHSUR P DECOMP DECOMP 08:30 - 08:40 08:40 - 09:20 0.17 WHSUR P 0.67 PULL P DECOMP DECOMP 09:20 - 10:00 0.67 PULL P DECOMP 10:00 - 10:30 0.50 PULL P DECOMP 10:30 - 13:30 DECOMP 3.00 PULL P 13:30 - 20:30 7.00 PULL P DECOMP 20:30 - 00:00 3.50 PULL C DECOMP 1/27/2006 00:00 - 10:45 10.75 PULL C DECOMP 10:45 - 11 :00 0.25 PULL C DECOMP 11 :00 - 13:00 2.00 PULL C DECOMP 13:00 - 19:15 6.25 PULL C I DECOMP 19:15 - 19:45 0.50 PULL C DECOMP 19:45 - 21 :30 1.75 PULL C DECOMP 1/22/2006 2/10/2006 Spud Date: 10/7/2005 End: 2/10/2006 Description of Operations Leaks on Baker choke, bottom variables, top combi's and lock down screws. Lower Combi's tested Retested variables and upper combi and tested ok at accumulator set on L-Side pressure. IA open during testing. RU shooting nipple and SLB lubricator sections Call town for dispensation for not pulling TWC with lubricator. Granted. All during BOP testing well was monitored for pressures or flow. None seen. WBP set at 8580'. Well was circulated earlier in the day and no gas was seen at surface. Pull TWC with dry rod. Clear rig floor of tools. MU 75t DP elevators. PU 1 jt 3-1/2" DP and TIW XO to 3-1/2" 8rd tbg. MU to tbg hanger. Clear floor and pull hanger to floor. Hanger unseated easily. After streach in tbg seen seal assembly pulling through PBR at max pulls of 114k-120k. (blocks weigh 7K included) Control line came 1:1 to this point. LD hanger and pup jt. Change out elevators to 75t flat top tbg elevators. Pull on next jt #2. Should have cleared PBR but still pulling tight at max pull of 125k. Lost about 8'-10' of control line length based on trying to pull 1 :1. Working pipe to try and regain length. RU and circulate. Continue working pipe. Work pipe to next coupling, normal pulls around 90k last 10'. Control line coming freely but almost too freely. May have parted somewhere. LD jt tbg. Start pulling again and tight imediately. Work pipe up in stages another 15' with max pull of 125k (19k net). Pipe parted while pulling at 90k. After fixing catsass on draw works looks like we have 19K of pipe. That puts it close to the SSSV RU air slips. Pull and LD 3-1/2" tbg. Arrange for fishing tools, DP, DC's LD 98 jts (3067 ft) 3-1/2" 9.3#/ft J-55 Tbg, 1 SSSV and DGLM # 1 All tubulars look good. Recovered all control line and 29 bands. Pulled out of 3-1/2" collar. Top of fish is a 4-1/2" tubing collar at approximately 3100 ft. Fill hole. Tubing displacement was correct on POOH. Unload 3-1/2" tubing in pipe shed and clean and RU rig floor. Loaded pipe shed with 3-1/2" 15.5#/ft X-95 DP and prep Steamed joints, drift and tally. RU floor tongs etc.. PJSM review pipe handling hazards and procedures. Assign job positons PU fishing BHA #1 Finished working on change out of coil reel motor. PU 85 jts 3-1/2" DP and BHA Circulated well bore volume to clean up DP of scale. RIH and tagged the top of the fish at 3,124 ft. Seal Assemby has stabbed into the PBR. Set OS with 20k down and PU. PU wt = 31k up and 25 k down. PU and fish started moving at 125,000 lb. Pulled up from 3124 ft, 70 ft and something parted down hole. After enverything settled down, inspected the derrick, crown and rig footing. OK Printed: 2/13/2006 12:02:20 PM BP Operations Summary Report Page 3 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-04 10-04 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 1 122/2006 2/10/2006 Spud Date: 10/7/2005 End: 2/10/2006 Date From - To : Hours Task Code NPT: Phase Description of Operations ...-.....----.--... 1/27/2006 21 :30 - 00:00 2.50 PULL C DECOMP PU, string wt at the orginal wt of 30k up. OS grapple probably let loose POOH standing pack DP in the derrick. Ordered ot 2.25" ID BS & Jars, alerted SLB to chem cut. 1/28/2006 00:00 - 00:45 0.75 PULL C DECOMP Finish POOH. Recovered some 3-1/2" production tubing 00:45 - 02:00 1.25 PULL C DECOMP LD fish BHA with 2" ID. Removed OS and changed out grapple. Change over to pulling and LD 3-1/2" production tubing. Recoverd 8 its 3-1/2" tubing, GLM # 2 and 1 its 3-1/2" below GLM All 9 jts layed down were not torqued up. It only took a 36" pipe wrench and 1 person to back out the threads witout any effort. Pulled out of 3-1/2" tubing collar Top of fish is a collar at approximately 3,386 ft Total out is 108 jts , 2 GLM and SSV with PJ out of hole. 02:00 - 03:00 1.00 PULL C DECOMP Redress OS, RIH with OS and 6 DC ( ID = 2.6" 03:00 - 06:30 3.50 PULL C DECOMP RIH with OS Tagged Fish at 3,381 ft. PU to 50 k and set OS PU T J to neutral and break off single. PU to 50k set slips, tie-up handles, install safety clamps 06:30 - 07:45 1.25 PULL C DECOMP SWS arrive on location. RU head and string shot. 07:45 - 08:00 0.25 PULL C DECOMP PSJM: Review procedures and hazards with stringshot and sheave.. 08:00 - 08:30 0.50 PULL C DECOMP RU sheave. Bring SS to floor, RIH with SS and MU line wiper with side entry sub. 08:30 - 10:20 1.83 PULL C DECOMP RIH w/ SS/CCUgr. Log gr/ccl f/ 6100'-6400'. Position SS 1-1/2 its below 7th GLM. Fire SS 6264'-6275'. 10:20 - 10:40 0.33 PULL C DECOMP POH w/SS. Shot fired. 10:40 -11:15 0.58 PULL C DECOMP RU Chemical Cutter on ground. 11: 15 - 11 :25 0.17 PULL C DECOMP Brief PJSM review hazards again with all crews concerning chemical cutter. 11 :25 - 16:30 5.08 PULL C DECOMP RIH with CC. Unable to enter DC's at 3200'. TOH. Inspect tool. Check OD's 2.120" but tool has upper/lower centrilizers that are most likely hanging up. Make a 2.125" gauge run. No problems through DC's. Remove upper centrilizer from CC and back-off tension on lower set allowing it to collapse easier. RIH w/CC make it though DC's ok, Stopped at 5300' due to angle of well. Pump at 1.8bpm and run CC to 6400'. Get correlated with SS log. Place cutter head at 6275'. That's 1-1/2jts below 7th GLM. Clear floor and fired CC. Good indication that it fired on the line only. TOH and cutter wouldn't come back through the DC's. Played with that for 1/2hr and made it through. Clear floor and remove chemical cutter from well. Stand back SWS equipment. 16:30 - 17:00 0.50 PULL C DECOMP Pick-up on string. (string wt prior to latching onto fish: 35k1up 30kldn) Went past PU weight where CC was +/- extra 20K over string wt. Something came apart at 95K. Could have parted at cut. Have additional 1 Ok over DP/DC string wt. and moving freely at 45K. LD 1 it. Standback 1 stand. Note that string wts have never been what they should be. Most likey do to hole geometery. 17:00 - 17:30 0.50 PULL C DECOMP RD SWS. Good indication that the cutter worked. Tool intact. 17:30 - 20:45 3.25 PULL C DECOMP TOH with fish.. 20:45 - 23:30 2.75 PULL C DECOMP Released OS and RU to pull & LD completion Most of the 3-1/2" tubing is bent to some degree. Some is Printed: 2/13/2006 12:02:20 PM BP Operations Summary Report Page 4 of 11 Legal Well Name: 10-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: ! From - To I I ?Ode I ~~T I Date Hours I Task Phase Description of Operations I -- -~ --------- --- ...--------... 1/28/2006 20:45 - 23:30 2.75 PULL C DECOMP worst than others but its all bent and corkscrewed and basically not torqtJed to proper values LD 50 jts with 2 GLM 23:30 - 00:00 0.50 PULL C DECOMP Unloaded 50 jts 3-1/2" from pipe shed 1/29/2006 00:00 - 00:30 0.50 PULL C DECOMP Unloading pipe shed of bent 3-1/2" completion tubing 00:30 - 02:00 1.50 PULL C DECOMP LD 3-1/2" Completion Recovered 90 jts of bent and corkscrewed tubing plus 12.5 ft cut off piece 02:00 - 03:00 1.00 PULL C DECOMP RU to run OS with DP 03:00 - 05:00 2.00 PULL C DECOMP RIH with Basket grapple with packoff on 3-1/2" DP 05:00 - 06:00 1.00 PULL C DECOMP Unload Pipe shed of cork screwed3-1/2" tubing 06:00 - 08:45 2.75 PULL C DECOMP RIH with 40 jts DP off pipe racks (4435.50') 08:45 - 10:30 1.75 PULL C DECOMP Bring in another 60jts DP. Clean, drift and strap. 10:30 - 14:30 4.00 PULL C DECOMP Continue RIH with jts from pipe rack to jt #198 (6250.37'). Vis up 9.6ppg brine. Install TIW valve and hook-up to circulate. Change to 80 mesh shaker screens. 14:30 - 15:15 0.75 PULL C DECOMP Circulate above fish at 6.5bpm 270psi 15:15 - 16:50 1.58 PULL C DECOMP Make connection. String wt 49k up 35k dwn. Tag fish 5' in at 6255' . Workover fish while pumping 3bpm see inc in PP to 1600psi. Pull to 95k fish not moving while pumping. Remove circulation hose. Pull in stages to 130k which is 80k over string wt. Not in the mood to part this again. Call for SWS and chemical cutter. 16:50 - 22:30 5.67 PULL C DECOMP Wait for SWS 22:30 - 23:45 1.25 PULL C DECOMP RU SLB 23:45 - 00:00 0.25 PULL C DECOMP RIH with string shot and CCL 1/30/2006 00:00 - 00:45 0.75 PULL DECOMP RIH and located GLM 8-9-10 and 1-1/2 jts below GLM # 10 Logged up to 7,603 ft and set string shot at 7,616 ft 00:45 - 01:10 0.42 PULL DECOMP POOH 01: 10 - 01 :50 0.67 PULL DECOMP RU Chemical Cutter on Eline 01 :50 - 02:30 0.67 PULL DECOMP RIH to 7,690 ft and logged up to 7,550 ft. RIH and chem cut at 7,616 ft ,1-1/2 jts below GLM#10. With 12k pulled on string fired and had good surface indication 02:30 - 04:30 2.00 PULL DECOMP POOH with Chemical Cutter. From 3,500 ft up, had to pump on DP side to collaspe the anchor arms on the chemical cutter. The arms were catching in T J's. After 1,500 ft, pulled normal 04:30 - 05:00 0.50 PULL DECOMP RD Eline, PU on DP 50K, +5k over string wt 05:00 - 05:45 0.75 PULL DECOMP PU 30 ft and cir bottoms up at 6 bpm at 650 psi 05:45 - 11 :00 5.25 PULL DECOMP POOH to fish. 11 :00 - 15:00 4.00 PULL DECOMP Service break OS. LD OS and 1/2jt. Unable to back-off OS from tbg. UD 42jts tbg and 3 GLM's. No bent jts. Seeing that 2·4 threads are showing on most connections above box. Did try on 1 jt to make-up to 1200ft/1bs and took 5 rds. Rec make-up torque values are 1710 min 2280 optimum. Chemical cut looked normal. 15:00 - 16:00 1.00 PULL DECOMP Re-dress OS 16:00 - 21:15 5.25 PULL DECOMP RIH with BHA #4 21 :15 - 23:15 2.00 PULL DECOMP PU and RIH with DP off pipe rack Total DP @ 242 jts in hole up wt 76k dwn wt 48k 23:15 - 00:00 0.75 PULL DECOMP Tagged the top of fish at 7633.5 ft with 23.5 ft in on jt# 242. RU circulating head and cir bottom ups at 6.0 bpm P = 626 psi Small amount of scale coming across shaker 1/31/2006 00:00 - 00:40 0.67 PULL C DECOMP Circulating and cleaning wellbore Printed: 2/13/2006 12:02:20 PM BP Operations Summary Report Page 5 of 11 Legal Well Name: 10-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/1 0/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date I From - To I H~~:~ Task Code I NPT Phase Description of Operations 0..-___._---..- ..._______..________n____._.___._______n. 1/31/2006 00:40 - 01 :00 0.33 PULL C DECOMP Red Op to 3 bpm at 280 psi, worked over fish at 7,633 ft, pump pressure increased 100 psi. Set down with 10k Latched OS and pulled 10 k to confirm (OK) 01 :00 - 01 :15 0.25 PULL C DECOMP Circulated and held PJSM on RU Eline to run CCL conformation log. 01 :15 - 03:00 1.75 PULL C DECOMP RU Eline to 8570 ft. Ran collar log 03:00 - 04:15 1.25 PULL C DECOMP RIH with CCL to 8570 ft. PU ran collar log. Found all jewelry in tack. Same log as orginallog. 04:15 - 08:40 4.42 PULL C DECOMP POOH to re-position the eline sheave in the derrick. Get 15 ft bails from Rig 3 because our 8 ft bails are to short for eline hookup. 08:40 - 09:00 0.33 PULL C DECOMP PJSM with all crews. Review plan forward and hazards. Plan to PU on fish to max 90k wo CCL in string. Remove line wiper assembly from DP and secure e-line/sheave off to A leg drillers side. 09:00 - 10:00 1.00 PULL C DECOMP Pull on fish to 125k several times - no movement. Pull to 150k have l' of movement. Work pipe 6 times at this weight. No further movement. Pull to 158k and fish moving. Work several times and see seal assembly clear PBR. Continues to move 145-150k another 50' then tight. Pull very slowly and fish pops free of tight area, gained 3k over normal string wt. Continue pulling laying down total 5 jts. Fish pulling 78k to 130k range. Fluid not dropping from DP nor is the well swabbing, not loosing fluid either on backside. Strange. Bottom of fish (wI 11' seal assembly) at 8400'. 10:00 - 11 :30 1.50 PULL C DECOMP CBU at 3.1 bpm 510 psi. Call town. Will RU SWS and run CCL after good circulation. Will look to see if packer is coming with fish. Could also have pulled lower seal assembly from packer at 9011'. Nothing over shaker after CBU. 11 :30 - 12:30 1.00 PULL C DECOMP RU SWS line wiper and pump-in sub. RIH wI CCL no gr tagged up on WRP. Results show we have the packer assembly and at least the 1st jt below it that the WPR is set in. Call town. POH with CCL. 12:30 - 14:30 2.00 PULL C DECOMP Conference call with town on way forward 14:30 - 15:00 0.50 PULL C DECOMP RD SLB Eline and change out 188" bails 15:00 - 15:30 0.50 PULL C DECOMP PU on string, started to move at 85k. Pull OOH between 85 to 100 k and sometime pull up to 120k ( DP string wt's 75 k up) PUH with OS from 7482 ft to 7,415 ft. Stood stand in derrick Well not being swabbed only rise a few inches when pulling tighter 15:30 - 15:45 0.25 PULL C DECOMP PJSM with Halco WL on RU to conduct Drift and shift BP sleeve 15:45 - 17:00 1.25 PULL C DECOMP RU Halliburton WL. Install and test slickline lubricator. 17:00 - 19:30 2.50 PULL C DECOMP Run in hole with drift. Tag WRP at 8376'. POOH. 19:30 - 22:30 3.00 PULL C DECOMP Run WRP opening sleeve on slickline. Tag WRP at 8375'. Attempt to hold 100-200 psi pressure on tbg, then open WRP. Repeat several times. Nothing definitve as to whether valve opened or not. POOH. Tell tales on shifting tool indicate opening prong not engaged. Suspect fill. 22:30 - 00:00 1.50 PULL C DECOMP Make up drive down bailer. Run in hole on slick line. Recover 1 + gallon of frac sand. 2/1/2006 00:00 - 01 :00 1.00 PULL C DECOMP Make second run with slickline 2.25" bailer. Work down to Printed: 2/13/2006 12:02:20 PM BP Operations Summary Report Page 6 of 11 Legal Well Name: 10-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: I From - To ! Hours ¡ Task Date Code NPT Phase Description of Operations ~ ' -. ..---.--....--...-..---- .. . ....-.-.--..-- 2/1/2006 00:00 - 01 :00 1.00 PULL C DECOMP 8379'. Recover another 1/2 gallon of sand and scale. No marks on bailer nose. 01 :00 - 03:00 2.00 PULL C DECOMP Run a 2.25" od pump bailer, run #3. Recovered only scale from a depth of 8378'. 03:00 - 05:00 2.00 PULL C DECOMP Run #4 with bailer. Recovered scale, sand and small keeper pin? 05:00 - 07:30 2.50 PULL C DECOMP Run # 5 using 2" drive down bailer Tagged at 8,382 WLMD and worked down to 8,383 ft. POOH, recovered 1/2 gal scale. Had indication of WRP plug from tattle tale and marks on bailer 07:30 - 10:15 2.75 PULL C DECOMP Run #6 2-1/4 Pump bailer Tagged at 8383 ft. Worked several times POOH 1 0: 15 - 11 :45 1.50 PULL C DECOMP RIH # 7with tool to shift WRP sleeve. Tagged high at 8,378 ft. Pounded down several times. No indication at surface. POOH No indication from tattletales in shifting tool 11 :45 - 13:30 1.75 PULL C DECOMP RIH run #8 with 2.25" pump bailer to clean up on top of WRP Tagged again at 8,379 ft WLMD. Working several times. Got to 8,380 ft WLMD. POOH Recovered < 1 pint of scale, frac sand and couple pieces of metal. 13:30-15:41 2.18 PULL C DECOMP RIH Run # 9 wI 2" drive down bailer tagged at @ 8378 ft (3 to 4 ft high) Something fell in when running the shifting tool. SLB is reheading to the small line in their Kuparuk Shop Recovered> 1 pint of solid materal (scale, frac sand and small pieces of metal) Redressed (indicators) on 2" drive down bailer. 15:41 -16:40 0.98 PULL C DECOMP RIH Run #10 wI 2" drive down bailer, SLB been mobilized from Kuparuk. Tagged at 8,379 ft. Worked bailer several times. POOH 16:40 - 16:52 0.20 PULL C DECOMP Check bailer, flapper spring failed because the WRP stem was wedge up inside the drive down bailer. PU 2.27" shifting tool. SLB on location ready to RU if the WRP can't be equalized. 16:52 - 18:00 1.13 PULL C DECOMP RIH with shifting tool. Work down over WRP prong (we hope). POOH. Telltales indicate WRP should be equalized. 18:00 - 19:00 1.00 PULL C DECOMP Rig down Halibur slickline. Discuss cold weather operations and concerns. 19:00 - 19:45 0.75 PULL C DECOMP Rig up to circulate. DP taking 1 bpm at 30-40 psi. Assume WRP is open. 19:45 - 20:45 1.00 PULL C DECOMP Begin to pull on fish. Able to move up hole at at 125k# up wt. Drops back to 30k#, then pull again to 120-125k#. Pull two stands, fish became stuck, unable to move up or down. Pull to 150k#. Fish moved up hole a few feet. Unable to to move again. 20:45 - 21 :15 0.50 PULL C DECOMP Adjust draworks brakes. Discuss situation with town. Request SLB round up a chemical cutter. Hole began taking fluid, up to 20 bph. Order more brine from MI. 21:15 - 22:00 0.75 PULL C DECOMP Pull up to 160k# several times. Pulling at 155k# when something came loose. Weight indicator came loose off dead line. 22:00 - 22:30 0.50 PULL C DECOMP Repair weight indicator. 22:30 - 00:00 1.50 PULL C DECOMP Pull out of hole with fish. 115k# up weight, with drag fluctuations of +1- 5k#. 2/2/2006 00:00 - 04:30 4.50 PULL C DECOMP Continue to pull out of hole. Hole fill normal. Pipe pulling smoothly. Pull 118 stands and one single. 04:30 - 06:45 2.25 PULL C DECOMP Rig up floor to handle recovered tubing. Release from overshot. LD 3-1/2" tbg fish. Printed: 2/13/2006 12:02:20 PM e Page 7 of 11 BP Operations Summary Report DECOMP POOH and LD 1 3-1/2" cut off section 14 jts 3-1/2" tubing GLM # 11 9 jts 3-1/2" tubing Total length lay down = 742.31 ft Top of fish is a 3-1/2" collar. 4 jts 3-1/2" tubing on top of GLM # 12. Approximately top of fish at 8,381 ft, if stung back into packer at 9,012 ft DECOMP Slip and cut 49.75 ft drlg line DECOMP RU hose to IA with transducer to keep hole full and monitor pressure while conducting BOP test. SFAL DECOMP BOP Test Mcevoy Gen III test plug leaked. Call for replace from Drilling Stores. PT to 250/3500 psi wittnessed by John Crisp AOGCC. Test other surface equipment while waiting for test plug. Test BOP stack. No failures. Test witnessed by Hildreth & Goodrich. Rig up Halliburton slickline unit. Hold PJSM mtg with SLB, Nordic, and Halliburton hands. Discuss jog, assignments, contingencies, well control, and hazards. Also discuss cold weather operations. MU impression block tool assemby (2.70" od lib). Run in hole. Set down at 8186', then continue and tag solid at 8265'. POOH. Found evidence of fill on LIB. Did not tag WRP stem. Fish has not fallen back down hole. It is +1- two stands of DP or 124' further up hole than during previous slickline tags on WRP. WRP was at +1-8380' on previous tags, is now at +1-8265'1 Make up bailing assembly. Run in hole. Run in hole with2" drive bailer assembly. Tag again at 8265'. Pull out of hole. Found several cups of flat metal pieces. Run 5" LIB. Tag tubing fish top at 8057'. Pull out of hole. Clear evidence of 3-/1/2" tbg collar impact. Run 2-112" pump bailer. Tag at 8263'. work bailer. Pull out of hole. Recovered several cups of metal and debris. Run 2-1/2" pump bailer. Set down at 8265'. Work bailer. Worked bailer down to 8266 ft. POOH and recovered scale, small pieces of brass. RIH and bailed sveral times without gaining any footage. POOH Recovered small amount scale and damaged the flapper (over the WRP stem) RIH wI 2-1/4" pump bailer RIH with Equalizing Prong and set down at 8,265 ft. Worked down several time POOH RIH with WRP retrieving tool and latched up at 8,265 ft. Jarred on for 20 min up to 1500 lb. Sheared off GD bait sub (22") and left in the hole Didn't see much movement on WRP plug POOH and redressed GD pulling tool and PU 5 ft wt bar, RIH and latched up at 8265 ft. Jarred on for 10 min and JD tool sheared. POOH Dress GS retrieving tool and redress oil jars Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Q-04 10-04 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours I Task Code I NPT Phase -- 2/2/2006 06:45 - 08:00 1.25 PULL C 08:00 - 09:30 09:30 - 12:00 1.50 PULL C 2.50 WHSUR C 12:00 - 15:00 3.00 WHSUR X 15:00 - 19:30 4.50 WHSUR C DECOMP 19:30 - 20:30 1.00 PULL C DECOMP 20:30 - 21 :00 0.50 PULL C DECOMP 21 :00 - 23:30 2.50 PULL C DECOMP 23:30 - 00:00 0.50 PULL C DECOMP 2/3/2006 00:00 - 01:15 1.25 PULL C DECOMP 01:15 - 02:30 1.25 PULL C DECOMP 02:30 - 04:00 1.50 PULL C DECOMP 04:00 - 08:00 4.00 PULL C DECOMP 08:00 - 09:00 1.00 PULL C DECOMP 09:00 - 10:45 1.75 PULL C DECOMP 10:45 - 11 :00 0.25 I PULL C DECOMP i 11 :00 - 12:45 1.75 PULL C DECOMP 12:45 - 13:30 0.75 PULL C DECOMP 13:30 - 15:30 2.00 PULL C DECOMP 15:30 - 16:00 0.50 PULL C DECOMP Start: 1/22/2006 Rig Release: 2/10/2006 Rig Number: Spud Date: 10/7/2005 End: 2/10/2006 Description of Operations _n._._.___...__.._.______... _ .. nno__._____ Printed: 2/13/2006 12:02:20 PM BP Operations Summary Report Page 8 of 11 Legal Well Name: 10-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: From - To ¡Hours I I Date Task Code ~PTI. Phase Description of Operations ____.._____.._n 2/3/2006 16:00 - 16:30 0.50 PULL C DECOMP RIH with "GS" Latched GS on WRP plug 16:30 - 17:30 1.00 PULL C DECOMP Jarred on plug from 600lb to 1900 Ib without any movement for 1 hr 17:30 - 18:00 0.50 PULL C DECOMP Sheared down to release GS from GD baited sub. POOH with wireline tools 18:00 - 18:30 0.50 PULL C DECOMP PJSM. Rig down Halliburton slickline. 18:30 - 19:30 1.00 PULL C DECOMP MU 4.5" overshot assembly. 19:30 - 00:00 4.50 PULL C DECOMP Run in hole with 3.5" dp. Pick up 30 singles. 2/4/2006 00:00 - 02:00 2.00 PULL C DECOMP Continue to RIH with overshot on 3-1/2" dp. Pick up 30 singles. 02:00 - 02: 15 0.25 FISH C DECOMP Jt #254. Up wt 122k#, dn wt: 63k#. PU 6' pup. Engage fish 4' in on pup. Clear foor and prep to RU SLB e-line. 02:15 - 03:00 0.75 EVAL C DECOMP Wait on SLB to repair broken cable spooler head. 03:00 - 03:30 0.50 EVAL C DECOMP Hold PJSM with SLB and Nordic crews. Discuss job, well control, assignments, communications, safe briefing area, hazards & mitigation of same. 03:30 - 04: 15 0.75 EVAL C DECOMP RU SLB e-line. 04:15 - 05:00 0.75 EVAL C DECOMP Run CCL tool to locate WRP and packer. Tag WRP. 05:00 - 05:30 0.50 EVAL C DECOMP Log CCL up above overshot assy. 05:30 - 06:30 1.00 EVAL C DECOMP SLB stopped CCL at 200 ft from surface. Held PJSM after crew change. POOH with CCL. There is 12 ft below the packer to top of the WRP 06:30 - 09:30 3.00 FISH C DECOMP RU to run tubing punch. Tie in and tagged WRP at 8260 ft. Perf 8255.5 ft to 8253.5 ft 10 (holes) Well went on vacuum. Fill hole, took 21 bbl to fill hole (797 ft) Circulated down annulus lossing 1.25 bpm and improved to 0.78 bpm in 30 minutes. Loaded DP and cir well before RD SLB 09:30 - 11 :45 2.25 FISH C DECOMP RIH with string shot. Fired across collar at 8221 ft POOH, SLB having trouble with their counterlencoder Losing 0.4 to 0.25 bpm following the tubing punch. 11 :45 - 13:00 1.25 FISH C DECOMP SLB RU Chem cutter 13:00 - 17:00 4.00 FISH C DECOMP RIH and tied in . PU and set Chem cutter at 8,119 It and shot. PUH cutter stuck in collar at 8,150 ft. Worked several times and pump down DP at various flowrates. After talking to SLB, decided to pull out of weak point. PU to 2100 Ib and tool pulled free. Pulled up to next collar and had to work through. PUH to below OS and took several attempts to work through. POOH smoothly through drill pipe. LD tool, 3 out of 6 anchors still extended. LD Tool 17:00 - 18:30 1.50 FISH C DECOMP POOH with DP and fish. PUH at 118k to 123k somewhat ratty. Getting better after 5 stands. Hole not losing any fluid prior to POOH 18:30 - 19:45 1.25 RIGD C DECOMP Rig down pressure control equipment stood back on rig floor. (lubricator and slickline unit). Store in pipe shed. This frees up a lot of room in pipe rack area. 19:45 - 00:00 4.25 FISH C DECOMP Continue to POH with tbg fish. 2/5/2006 00:00 - 01 :00 1.00 FISH C DECOMP Continue to POH with cut tubing fish. 01 :00 - 01 :30 0.50 FISH C DECOMP Break out overshot from fish. LD BHA and single. 01:30 - 02:15 0.75 FISH C DECOMP POOH and LD: 4 full jts 3-1/2 tbg Printed: 2/13/2006 12:02:20 PM -. Page 9 of 11 BP Operations Summary Report Legal Well Name: 10-04 Common Well Name: 10-04 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 , Date I:rom - To ¡ HO.~,~~ ¡Task ___ 2/5/2006 01:30-02:15 0.75 FISH I Code NPT I__Phase .:.. DECOMP C 02:15 - 03:00 0.75 FISH C DECOMP 03:00 - 09:50 6.83 FISH C DECOMP 09:50 - 10:25 0.58 FISH C DECOMP 10:25 - 10:50 0.42 FISH C DECOMP 10:50 - 11 :10 0.33 FISH C DECOMP 11 :10 - 12:00 0.83 FISH C DECOMP 12:00 - 18:00 6.00 FISH C DECOMP 18:00 - 21 :00 3.00 FISH DECOMP C 21 :00 - 22:30 1.50 FISH C DECOMP 22:30 - 23:00 0.50 FISH C DECOMP 23:00 - 00:00 1.00 FISH C DECOMP 2/6/2006 00:00 - 10:45 10.75 FISH C DECOMP 10:45 - 12:00 1.25 FISH C DECOMP 12:00 - 13:00 1.00 FISH C DECOMP 13:00 - 13:30 0.50 EVAL C DECOMP 13:30 - 14:00 0.50 EVAL C DECOMP 14:00 - 14:45 0.75 EVAL C DECOMP 14:45 - 17:30 2.75 EVAL DECOMP C Start: 1/22/2006 Rig Release: 2/10/2006 Rig Number: Spud Date: 10/7/2005 End: 2/10/2006 Description of Operations ....._n.... ...____ _0". ---.------ ...._u...._ GLM #12 with pups 1 cut it 3-1/2" tbg Total length: 162.11 Top of fish estimated to be at 8219'. Chemical cut was fairly clean, with a smooth od. According to the tbg talley, the tbg stub above the collar looking up is 4.13'. Upper joint recovered was slighly corkscrewed. MU overshot assembly with bumper sub, jars, and drill collars. Add extra extension to overshot to cover cut stub length. Run in hole with fishing BHA. Tagged top of fish at 8215 ft with 253 jts + 16.5 ft in on it # 254 RU Cir sub and Cir at 4 bpm and work over fish at 8215 ft. SD pumps and lached fish and set grapple. With up wt at 132k and down wt at 66k. Jarred down on fish from 140k to 45k 27 times and no movement seen at surface SD cool brake and circulate well at 4 bpm Jarred on fish Total are 60 times down and 11 up. Maybe a foot of movement Cir and mix 1-1/2 ppb Bio pill. Op = 4.0 bpm at 2043 psi Jarred another 11 times down and the packer moved down the hole 18 ft. PU and unable to come up the distanced traveled down. PU singles starting at it 254. RIH and tried to PU offen and was unable to PU Max PU at 240 k . Jarring from 140k to 240 k and jarring down from 140 k to 40k. Worked down to 8961 ft with 263 jts DP in the hole. BHA includes the top packer and tail pipe. BHA len = 686.39. Tagged someting hard at 8961 ft. RU to cir at 8961 ft. Circulate at 1.8 bpm at 1150 psi. Occaisional spikes in pump pressure. Not sure why. 1: 1 rtns. CBU. No solids noted over shaker. Discuss plan with town. Decide to end fishing ops. Rig down circulating head. Work pipe and rotate string to the right to release overshot. Remove extra pipe and kelly from pipe shed. Pull out of laying down drill pipe in singles. Continue to pull out of hole, laying down drill pipe. LD 6 DC and fishing tools. Inspected grapple and stop. The stop is 4" ID ( confirmed) 3.37 ft from bottom. 2-5-3/4" extension above that at 6.65 ft Load out fishing tools and make ready to bring in tubulars. RU wireline for evaluation on tubing stub and drift tubing and parker for integrity to WRP RU Hallibuton WL while loading tubulars RIH with 5-1/2" LIB and tagged at 8490 ft WLMD. POOH and had a picture of a 3-1/2" stub perfectly round RIH with a 2.19" LIB and centralizers to check the drift RIH and set down at 8,494 ft, 4 ft inside of stub (collar). POOH to look at 2.19" LIB Starting to load row 2 in pipe shed of 3-1/2" tubing at 1600 hrs. Marks on the high side and small marks( frac sand) on bottom of 2.19" LIB RU and RIH with 1-3/4" drive down bailer to get sample of fill. .. Printed: 2/13/2006 12:02:20 PM Page 10 of 11 BP Operations Summary Report Start: Rig Release: Rig Number: Phase I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-04 10-04 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours: Task Code! NPT I .. n-----'----_._.. .. 2/6/2006 14:45 - 17:30 2.75 EVAL C 17:30 - 18:30 1.00 EVAL C 18:30 - 20:30 2.00 EVAL C 1/22/2006 2/10/2006 Spud Date: 10/7/2005 End: 2/10/2006 .. ...._ ___ u_____.__.______... Description of Operations DECOMP Tag at 8494' Still loading pipe shed (2 rows in) DECOMP No recovery in bailer. Locate additional slickline tools: a larger bailer with a mule shoe. DECOMP Run 2.25" pump bailer with 2.79 od centralizer. Work deeper than smaller bailer, at 8506'. This is 6' below top of PBR above FHL packer. POOH. Found several cups of scale and frac sand in bailer. Continue to load pipe shed with 3-1/2" tbg. Run 6.0" od gauge ring and junk basket. Tag tbg stub at 8490'. Pull out of hole. Small amount of scale in junk basket. RD Halliburton. Continue to load strap, and drift 3-1/2" tbg in pipe shed. Continue to load pipe shed with 3-1/2" tubing. Drift, strap, and install seal rings in same. RU floor to run completion. Run 3-1/2" EUE 8rd-m tubing completion wI overshot, nipple, FHL pkr, pbr, sliding sleeve, 5 GLMs and nipple. Tag up on stub at 8490' wI OS and see shear pins shear while fully swallow to wt loss. PU 2' off bottom at 62k. Drop ball-on-rod and wait to fall to RHC plug. Pressure up on tubing an'd see packer start to set at 1600 psi. Incr press to 3000 psi and hold for 20 min. Pull out of PBR at 66k and dump pressure. LD one jt, add 3 pups to allow slickline ops to work from floor level starting point and be stung into PBR up to l' Safety mtg re: RU/WL ops Bring HES tools to floor. RU on top of tubing pup wI XO, PIS and packoff RIH and recover ball-on-rod at 8937' WLM RIH to recover RHC plug Fin pull RHC plug from 8937' WLM RIH and set X plug at 8937' WLM. POOH. PT plug to 1000 psi RDMO HES WL PUH 62k and LD 2 ea 10' and 1 ea 4' pups, plus 2 jts tubing. MU RTTS wI storm valve on one pup and one full jt 3-1/2 DP. RIH 39k and set RTTS at 35' RKB (7' below spool). PT above RTTS to 1000 psi against blindlshear rams RUNCMP ND riser. ND BOPS. Lift using bridge crane in cellar. RUNCMP Verify OA pressure is bled off. ND tubing spool. Back out LDS for OA packofflslip assembly. One LDS sheared off. Prep casg spool for replacement plug in LDS port. Pull pack off assembly. Install replacement OA packoff assembly. NU new tubing spool. Inject plastic sealant into packoff void and seals would not energize ND tubing spool and remove packoff assy. Packoff was for larger diameter casing Wait on CIW to get correct packoff from Kup whse Install OA packoff assy. NU new tubing spool Fin clean pits Fin NU new tubing spool. Inject sealant into void and test packoff at 3000 psi NU BOPE and riser. Fill stack and riser. Connection at top of Hydrilleaked 20:30 - 22:30 2.00 EVAL C DECOMP 22:30 - 00:00 1.50 RUNCMP 2/7/2006 00:00 - 03:00 3.00 RUNCMP 03:00 - 18:00 15.00 RUNCMP 18:00 - 21:00 3.00 RUNCMP 21 :00 - 22:00 1.00 WHSUR P RUNCMP 22:00 - 00:00 2.00 WHSUR P RUNCMP 2/8/2006 00:00 - 03:15 3.25 WHSUR P RUNCMP 03:15 - 03:45 0.50 WHSUR P RUNCMP 03:45 - 06:00 2.25 WHSUR P RUNCMP 06:00 - 09:00 09:00 - 13:30 3.00 WHSUR P 4.50 WHSUR P 13:30 - 18:30 5.00 WHSUR P RUNCMP 18:30 - 20:40 2.17 WHSUR N RUNCMP 20:40 - 21 :30 0.83 WHSUR N RUNCMP 21 :30 - 00:00 2.50 WHSUR N RUNCMP 2/9/2006 00:00 - 01 :45 1.75 WHSUR N RUNCMP 01 :45 - 04:45 3.00 WHSUR P RUNCMP Printed: 2/13/2006 12:02:20 PM / - ." - BP Operations Summary Report Page 11 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-04 10-04 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 1/22/2006 2/10/2006 Spud Date: 10/7/2005 End: 2/10/2006 Date i i From - To ¡ Hours i Task Code NPT' Phase I ._.......___._ . ____._n i ....._.____.. ¡_______J.._ Description of Operations ------- - ___._n.___ - .. . _____ _..._ - . .........__ _00_..- __ 06:00 - 07:00 07:00 - 08:30 1.00 WHSUR P 1.50 RIGD P RUNCMP ND riser and fix leak. Fill riser RUNCMP PU RTTS pulling tool and latch up to RTTS. Close annular PT above RTTS to 3000 psi for 10 min to check flange connection RUNCMP Release RTTS and check for pressure. POOH w/ RTTS, LD and load out RUNCMP PU singles and btm out in PBR assembly. Determine space out. LD 3 singles. PU space out pups and top full joint, with hanger & pup assembly. RUNCMP Spot 20 bbls inhibitied brine above PBR and inside tubing. RUNCMP RIH wwhile circulating at 0.5 bpm. Note pressure increase as seal assembly entered PBR. SHut dn pumps. Bleed off. Slack off and land tbg. 62k# up wt, 38k# dn wt. RILDS. RUNCMP Pressure test tubing to 3000 psi for 30 minutes. Chart test. Bleed tbg to 2000 psi. Pressure IA to 3000 psi. Hold and chart for 30 minutes. Bleed IA and tbg to zero. Pressure IA. RP valve sheared at 1800 psi. Back out and LD landing joint. Set two way check in tbg hanger. ND riser and BOPE. Remove from cellar. Remove excess pipe and materials from pipe shed. NU adaptor flange and tree and PT @ 3000 psi. Bring HP lubricator to floor to pull TWC-has 7" Otis and needs 4" WO Kup valve shop to bring XO to HP lubricator Continue loading trailers and prep for move RU XO to lubricator and pull TWC Safety mtg wI LRS. RU cellar manifold and LRS. LRS pump 71 bbls 80 deg diesel down the IA at avg 2.0/950 and take 9.6# brine returns to tiger tank. RDMO LRS. Let diesel U-tube to tubing to FP to 2000' RUNCMP Set BPV. Secure tree in cellar. Remove circ lines. POST Finalize prep for move. Secure tubulars in pipe shed. Load out additonal equipment to BP Stores. Hold PJSM in pump room 1 to review move off well. Rig released at 0830 on 2/10-06. 2/9/2006 04:45 - 05:15 0.50 WHSUR N 05:15 - 05:40 0.42 WHSUR P 05:40 - 06:30 0.83 WHSUR P 06:30 - 09:00 2.50 RUNCOrp 09:00 - 10:00 1.00 RUNCm p 10:00 - 11 :00 1.00 RUNCm p 11 :00 - 13:30 2.50 RUNCm p 13:30 - 20:00 6.50 WHSUR P RUNCMP 20:00 - 00:00 4.00 WHSUR P RUNCMP 2/10/2006 00:00 - 01 :30 1.50 WHSUR N RUNCMP 01 :30 - 03:15 1.75 WHSUR P RUNCMP 03:15 - 06:00 2.75 WHSUR P RUNCMP Printed: 2/13/2006 12:02:20 PM KRU 1Q..o4 Pert (8709-8719) Perf (8742--8753) Cameo Pert (8914--8928) SIDETRACKED MULTI-LATERAL WELL wlFOUR LATERAL LEGS' ONLY L 1-()3ACCESSIBLE MULTIPLE TUBING LEAKS FOUND FOLLOWING C10 WORK - WORKOVER w!TUBING CUT & NEW TUBING, w/POORBOY OVERSHOT STABBED INTO REMAINING PORTION OF ORIGINAL COMPLETION OF 111612005 CEMENT (902HI511. 00:7.0(0) a STATE OF ALASKA _ ALASKAWL AND GAS CONSERVATION CdWIt1lSSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS .Il1N 2 0 2006 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program . sian o Suspend o Repair Well o Pull Tubing o Operation Shutdown a Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension Ancholllge 2. Operator Name: BP Exploration (Alaska) Inc. ddress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 3. 4. Current Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 184-234 6. API Number: 50-029-21250-00-00 99519-6612 90' 9. Well Name and Number: Kuparuk 10-04 10. Field / Pool(s): Kuparuk River Unit / Kuparuk River Pool 8. Property Designation: ADL 025634 11. Present well condition summary Total depth: measured 9535' feet true vertical 6937 feet Plugs (measured) None Effective depth: measured 9021 feet Junk (measured) None true vertical 6577 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 16" 103' 103' 1640 630 Surface 4622' 9-5/8" 4622' 3571' 3520 2020 Intermediate Production 9511' 7" 9511' 6920' 4980 4330 Liner "J, Perforation Depth MD (ft): Perforation Depth TVD (ft): 8709' - 8928' 6347' - 6509' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 3-1/2",9.3# J-S5 9085' Baker 'FHL' packer; Baker 'FB-1' packer; Baker 'FVL' SSSV 8566'; 9013' 1815' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9021' - 9511' RBDMS 8Fl JAN 2 3 2006 Treatment description including volumes used and final pressure: Abandon A Sand Perfs: Pumped 28.5 Bbls of 17 PPG cement, squeezed 9 bbls away behind pipe. Cleaned with Biozan down to 9016' RKB (Target TOC). Oil-Bbl Re resentative Dail Gas-Met Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram a Development 0 Service 17. t at t e oregoing IS true an Sean McLaughlin, 564-4387 Printed Name Terrie Hubble o WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Technical Assistant Phone 564-4628 Date Olll~/O(p Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only Page 1 of 2 e e Hubble, Terrie L From: McLaughlin, Sean M Sent: Wednesday, January 18, 20064:38 PM To: Hubble, Terrie L Subject: FW: FW: 1 Q CTD sidetracks - naming convention FYI- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, September 27,20052:17 PM To: McLaughlin, Sean M Subject: Re: FW: 1Q CTD sidetracks - naming convention Hi Sean, I don't believe that a sundry is required for the work you will do. You are correct that when drilling laterals that a sundry is not required. This one has a little "twist" with the plugging of the A sand in I Q-04. I looked at the "matrix" covering sundry operations for production wells and it also indicates that no sundry is required. A 404 should be submitted for I Q-04 reflecting that the original A sand perfs are plugged. That will keep that file complete. Thanks for checking. Tom Maunder, PE AOGCC McLaughlin, Sean M wrote, On 9/27/2005 1:55 PM: Tom, I'm working a few final details on 1 Q-04L 1 and L 1-01 and had a quick question. Do I need to submit a Sundry for 1Q-04? I thought that because it was a L 1 a Sundry wouldn't be required. We are just plugging the lower A sand perfs. I figured I'd better check to make sure. I've attached a schematic for your convenience. Let me know if you have any questions, Sean 564-4387 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, September 09, 2005 10:58 AM To: Venhaus, Dan (ConocoPhillips) Cc: Gantt, Lamar L; McLaughlin, Sean M; Steve Davies Subject: Re: 1Q CTD sidetracks - naming convention Dan, Naming is fun. Based on the drawings and your discussion, I would agree with your plan on IQ-04 to name the new penetrations -04LI and -04LI-01. On IQ-02, I believe the new penetration name should be 1 Q-02B. There are 2 issues here. In 1 Q-04, you are keeping the original C sand perfs at that BHL and establishing new A sand BHLs. After the work, production will be "coming" from 3 distinct BHLs. The new penetrations are properly called laterals. On 1 Q-02A, the entire present completed interval will be plugged and a new take point established. Since (at this time), none of the old 1/19/2006 Page 2 of 2 interval will be retained thea penetration is properly given the "AeSignation. Adding C sand perfs later will not change the BHL. I hope this helps. Thanks for checking. Tom Maunder, PE AOGCC Venhaus, Dan E wrote, On 9/9/2005 10:38 AM: Tom, We are preparing to drill two CTD sidetracks on wells 1 Q-02A and 1 Q-04 sometime in October. I want to run the proposal by you to make sure our naming convention is consistent. I have enclosed proposed completion schematics for more detail. 1 Q-04 producer Completion is currently a 3-1/2" selective single with C-sand perfs behind the straddle. We plan to cement off the A-sand perfs only and will sidetrack from the motherbore below the bottom packer just above the A-sand. We will drill an A-sand lateral south and complete with a liner with aluminum KO billet. We will then sidetrack off the billet from the first lateral and drill another A-sand lateral north. Since we are technically not abandoning the entire wellbore (C- sand is currently isolated via dummy valves in the production mandrels), I would name these 2 laterals as 1 Q-04L 1 and 1 Q-04L 1-01. And I assume we will need to file a sundry for the A- sand perf abandonment. «1 Q-04 CTD proposed completion.word.doc» 1 Q-02A injector Current completion is a 4-1/2" monobore injector with perfs in the C and A sands. The well has a suspected channel between the A & C. We plan to cement squeeze both the A & C and exit the casing via whipstock just above the A-sand. The existing A-sand perfs will remain covered/squeezed with cement. We will drill just one lateral and complete with slotted liner. The liner top will terminate inside the motherbore casing but will be below the C-sand for future access to perforate. Note that since this is a monobore we are not mechanically required to use cement to exit the casing. The squeeze is for isolation purposes for injection control after the sidetrack. Therefore, I would assume we would file a sundry for the squeeze and the drilling permit would label the sidetrack 1 Q-02AL 1. «1Q-02A CTD proposed completion.word.doc» The real question? Does partial abandonment of the production zone constitute these as laterals or sidetracks? If sidetracks then the naming convention would become 1 Q-04A & 1 Q- 04AL 1 and 1 Q-02B? Please give me a call if you need more clarification. Thanks, Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907 -263-4372 office 907 -230-0 188 cell 1/1912006 e e Field: 1 Q-04 / L 1 / L 1-02 / L 1-01 / L 1-03 (In Order Drilled) Kuparuk River Field Accept: Spud: Release: 10/14/05 10/17/05 11/05/05 Well: .Y·' ,...=.~=~. ,... ·=N~·' PRE-RIG WORK 09/16/05 GAUGED TUBING WITH 2.70" CENT, 3' STEM, BRAIDED LINE BRUSH, & 2.72" GAUGE RING TO 9100' RKB. 09/17/05 LOGGED CALIPER SURVEY FROM TTL AT 9085' RKB TO SURFACE. 09/22/05 BRUSH AND FLUSHED TUBING. PULLED OV AT 8506'. SET SLIP STOP CATCHER SUB AT 7728' RKB. PULLED GLV AT 7588' RKB. 09/23/05 SET DVS AT 7588',5751',3383' RKB. PULLED CATCHER AND SET 2.75" CS-A2 PLUG IN D NIPPLE AT 9051' RKB. 09/24/05 LOADED TUBING AND CASING WITH SW AND DSL. SET DV AT 8506' RKB. ATTEMPTED MITT, STILL GAS IN TUBING. 09/25/05 ATTEMPTED MITT AND lA, TBG AND CASING COMMUNICATING. SET D&D HOLE FINDER BELOW BOTTOM GLM. TESTED TUBING 1500 PSI, GOOD. 09/26/05 IDENTIFIED POSSIBLE TBG LEAK AT GLM. PULLED DV AT 3383' RKB, PKG CUT. 09/27/05 SET 1" DV W/ BK LATCH IN STA# 2 AT 3383' RKB, MITT FAILED, MITIA FAILED. PULLED STA# 7 AND INSPECTED. SET NEW 1"DV, BK LATCH IN STA# 7. BLED BOTH TUBING AND IA TO 0 PSI. LDFN. 09/29/05 BAILED ON TOP OF PLUG, PULLED 2.75" CS-A2 PLUG, RAN 2 1/2" SHORTY SETTING TOOL WITH 31/2" WEATHERFORD ECLIPSE PACKER. (48" OF 1 1/2" STEM TO KNOCK KOBE OFF) (46" OAL). 09/30/05 PERFORMED COMBO MIT, PASSED. PULLED ECLIPSE TEST PACKER. 10/01/05 RAN 21/2" SHORTY SETTING TOOL, ETD. SET 31/2" ECLIPSE TEST PACKER AT 8527' RKB, PERFORMED COMBO MIT, PASSED. 1 0/02/05 PULLED ECLIPSE TEST PACKER AT 8522' RKB. MITIA FAILED. COULD NOT ESTABLISH A LLR FROM IA TO TBG (LEAK TO SMALL). WELL WENT ON VACUUM AND COULDN'T PERFORM CLOSURE TEST ON SSSV. JOB COMPLETE. Pre-Rig Work Summary for MUI_raIS: 1 Q-04 / L 1 / L 1-02 / L 1-01 / L 1-03 e Page 2 10/03/05 A TUBING PUNCH WAS SHOT AT 9016': TUBING PUNCHER LOADED WITH SMALL CHARGES, 4 SPF. A TOTAL OF 9 SHOTS WERE FIRED, OVER A 2' INTERVAL. ALL SHOTS FIRED. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. 10/06/05 USED SLB MEMORY TOOLS TO LOG JEWELRY FROM 9100' - 8450' CTD. FLAGGED PIPE AT 9085' CTD. 10/07/05 PUMPED 28.5 BBLS 17 PPG CEMENT, SQUEEZED 9 BBLS AWAY BEHIND PIPE. CLEANED WITH BIOZAN DOWN TO 9016' RKB (TARGET TOe). DIESEL FREEZE PROTECT TO 2000'. 10/08/05 STROKED HYDRAULICS ON SSSV. 10/09/05 TAGGED CEMENT PLUG AT 9021' WLM. BRUSHED SSSV AT 1815' RKB AND STROKED HYDRAULICS. PERFORMED CLOSURE TEST. GOOD. BLEED TUBING PRESSURE. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 1 _ BP Operations Summary Report 1 Q-04 1 Q-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 10/7/2005 End: 10/14/2005 11/5/2005 From - To Hours Task Code NPT Phase 10/14/2005 13:00 - 14:00 1.00 MOB P 14:00 - 14:15 0.25 MOB P 14:15 - 14:35 0.33 MOB P 14:35 - 15:00 0.42 MOB P 15:00 - 15:15 0.25 MOB P 15:15 - 20:15 20: 15 - 23:00 23:00 - 00:00 10/15/2005 00:00 - 03:15 03:15 - 05:15 05:15 - 06:15 06:15 - 08:15 5.00 MOB P 2.75 MOB P 1.00 RIGU P 3.25 RIGU P 2.00 BOPSU 1.00 BOPSU DescriptionofiOperations PRE Continue to prep rig to move off weIl1B-15. PRE PJSM prior to moving off well. PRE Move rig off well, and down to the entrance of 1B pad. PRE Spot rig at entrance to pad. Repair pressure gauge that is not reading properly. PRE Pre move safety meeting with rig crew, Toolpusher, SLB Team Leader, BP WSL, and a representative from the Kuparuk drilliing toolhouse. PRE Move rig from 1B pad to 10 pad in Kuparuk. Stop move near KRU warehouse to allow field crew change out. PRE Rig on 10 Pad. Found subsidence around mouse hole. Fill in with extra gravel. 10 Pad operator and Toolpusher performed pad inspection. Continue to spot rig mats and plywood as a precaution due to poor location conditions around well head. Hold PJSM with crew. Spot rig over well. Accept rig at 2300 hrs on 10-14-05 PRE Spot cuttings tank. NU BOPs. PRE Continue to rig up on location. Spot and berm flow back tank. Berm cellar area. Take on fresh water for BOP test. Load pits with 8.6 ppg flo pro for mill out. Rig up com and power lines to camps. Measure BOPs and tree. Pressure test BOP body. Check injector chains. Found many loose bolts on tree flanges. Checked entire tree and tightened as required. PRE Pressure test BOPs. Witnessed by BP WSL Gary Goodrich. WAIT PRE Shut down BOP test for 1 hour to allow BP WSL's to change out and to conduct Technical Limits Pretour meeting with oncoming crew. PRE Resume BOP test. Witnessed by BP WSL Greg Sarber. Pressure test 2-3/8" combi's, bag, and perform drawdown test. All passed ok. AES support crew hooked up control panel to SSSV. PU WF motors for milling window. Open MV and SV. Well is dead. Prespud meeting with all rig hands on location, TL, TP, WSL, 2 WF hands. NU hardline from rig choke line to tiger tank. PT to 3500 psi. Make up BHA #1. D331 DSM, WF 1.75 deg motor. BHI Coiltrack MWD BHA with orienter, GR and CCL. RIH with BHA #1. Pump SSSV open with panel. Continue RIH, displacing gas cut diesel and seawater OOH. RIH and tag top of cement at 9048', uncorrected. PUH laying in mud to start our tie in logging pass. Pumping 1.5 bpm thru an open EDC. Log tie in pass down over GR charecter from 8885'. Make -8.5' correction. Relog same interval to check our correction due to critical nature of the window. Log was right on depth. Make CCL pass accross mandrel at 8660', log down and dry tag at 9039'. Check CCL vs jewelry log from SWS Memory Lee CCUGR of 10-6-2005. CCL log exactly on depth to ref log. WEXIT SI pumps. Shut EDC. Kick on pumps to 1.5 bpm. Free spin is 3250 psi at 1.5 bpm. Tag top of cement at 9038.3'. Paint flag. 08:15 - 08:40 0.42 STWHIP P WEXIT 08:40 - 09:10 0.50 STWHIP P WEXIT 09:10 - 10:30 1.33 STWHIP P WEXIT 10:30 - 11 :00 0.50 STWHIP P WEXIT 11 :00 - 13:20 2.33 STWHIP P WEXIT 13:20 - 14:50 1.50 STWHIP P WEXIT 14:50 - 18:15 3.42 STWHIP P Printed: 11f7/2005 9:58:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 2_ BP Operations Summary Report 1 Q-04 1 Q-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/14/2005 Rig Release: 11/5/2005 Rig Number: Spud Date: 10/7/2005 End: From - To Hours Task Code NPT Phase Description of Operations 10/15/2005 14:50 - 18:15 18:15 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 00:00 10/16/2005 00:00 - 00:30 00:30 - 01 :00 01:00 - 02:00 02:00 - 06:00 06:00 - 12:00 12:00 - 12:30 12:30 - 12:50 12:50 - 13:05 3.42 STWHIP P 0.25 STWHIP P 1.50 STWHIP P 1.50 STWHIP P 2.50 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 4.00 STWHIP P 6.00 STWHIP P 0.50 STWHIP P 0.33 STWHIP P 0.25 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Begin milling cement. 1.55/1.55/3500 psi. Initial ROP=16 fph. String wt = 4400 Ibs. DHWOB=2000 Ibs. Mill ahead. Exit tbg tail at 9072' holding HS toolface. See increased mtr work and reactive torque at 9076.8. PU 10'. Mill back down to 9076.5'. See reactive and mtr work again. PU 10'. Mill down to 9077'. Mtr work and reactive. Appear to have contacted the wall of the 7' csg, but this is approximately 2' early. Will go with reactive and mtr work instead of calculated contact depth. Treating flo pro with small amounts of PH6 and sodium bicarb to neutralize effects of cement. Held pre spud mtg with night crew. Open EDC. Log CCL tie in from 8920'. No correction. Circulate out of hole. At surface. Monitor well for flow. Well stable. Get off well. Unstab coil. LD motor and pilot mill. MU Weatherford fixed 2.5 deg mtr w/ HCC one-step window mill w/ brass ring. Stab coil. Test moo. Get on well. Run in hole. Hanging up on a tbg collar every so often. Work and or circulate past each and continue in hole. Slow going. Continue to run in hole. Log CCL tie in from 8920'. Subtract 10' correction. Dry tag at 9077.1 '. Close EDC and tag while circ at 1.6 bpm at 3500 psi fs @ 9076.1' PU l' from btm tag. Begin time milling sequence. Lock brake for 45 min. Begin a very slow time milling schedule. 3450 psi fs @ 1.6 in/out. WHP/BHP/ECD: 18/3820/11.34 ppg. IA/OA/PVT: 660/422/389 bbls. Small amount on metal accumulating on ditch magnets. Continue with window milling operations. Now at 9076', back at flag. Following the David Heam Extended milling schedule. Currently at 25 mintues/0.1'. Free spin is 3500 psi at 1.6 bpm. Milling at 1.61/1.63/3660 psi. String wt = 7300 Ibs. DHWOB=1500 Ibs. ECD=11.42Ibs. BHP=3850 psi. WHP=O psi. All is going according to plan with reasonable motor work and WOB for this point in the time milling sequence. Continue to mill. All indications are that milling is proceeding according to plan. 1.6/1.61/3750 psi. DHWOB=4000 Ibs. String wt=4900 Ibs. PVT =387 bbls. BHP=3920 psi. ECD=11.62 ppg. Caught a sample and examined in GEO shack. Cutting show 98% metal shavings, 2% formation with a few glass beads. We did not pumps glass beads on this well, they must be left in the mud system/possum belly from last well. Formation cuttings could also be left over from the last well. Cutting sample is inconclusive. Park at this depth to see if we get drill off and WOB to come back down. PU off bottom. Sticky pickup at 23 klbs. Pulled 2 klbs over on pickup. Pull up to 9660'. Free spin 3650 psi at 1.61 bpm. WOB = 110 Ibs. RIH slow. Tag up at 9078.4'. Stop coil at 9079.8'. DHWOB=43oo Ibs. String wt=57oo Ibs. Printed: 11/7/2005 9:58:20 AM Page 3 _ Operations Summary Report WEXIT 1.6/1.6/3980 psi. Getting good drill off. Continue milling at 14 fph. We appear to be drilling open hole. Window depths = 9076.1'-9078.9'. Started stacking wt, and losing motor work. WEXIT PU at 4 klbs over. RIH, Tag up at 9081.3'. DHWOB=4780 Ibs. 1.6/1.63/3750 psi. Try drilling OH at 10 fph. Making hole. Catch a bottoms up sample. Sample contained 30% metal cuttings and 70% formation. Confirms we have a window. Continue drilling ahead to get 10' of rathole. PU clean at 22 klbs. RIH, tag at 9091'. POOH to pick up Crayola mill BHA. Follow pressure schedule, pumping at full rate while POH thru an open EDC. Tag up at surface. Flow check well while holding PJSM Re: BHA swap. No flow observed. Lay down BHA #2. 1 Step window mill recovered and gauged at 2.74' Go, 2.73" No-Go. The mill had a good swirll pattern on the face. All indications are we have a good window. Pick up BHA #3, a crayola mill and 1.75 deg motor. The crayola mill gauges 2.74' Go, 2.73' No-Go. WEXIT RIH with BHA #3 to dress window. Open sssv. Follow WHP schedule to maintain pressure on open B shale. WEXIT Log ccl tie in. -10' correction. WEXIT Ream window down at HS tool face. Make several up passes at HS, 90L and 90R. 3470 psi fs @ 1.57 in/out. Dry drift down at HS tf. Window smooth. IAlOAlPVT: 509/577/384 bbls. WHP/BHP/ECD: 22/3873/11.45 ppg. Open EDC. Circulate out of hole. Maintain whp as per schedule. Close sssv with 850 psi trapped below. Continue to surface. At surface. Check for flow. Get off well. Unstab coil. LD tools. Prep for slack management. Pump slack. Cut pipe. Insatll coil connector. Pull and pressure test same. Install e-line head. Test same. MU build assembly (2.6 deg mtr w/ Hyc bicent) Sab coil. Test mwd. Get on well. Pressure up well to 850 psi. Open sssv. Whp remained at 840 psi. PROD1 Run in hole. PROD1 Log tie in pass down over GR charecter at 8880'. Make -15' correction usin the Geologist PDC log. PROD1 Tag bottom at 9087'. PU, bring pumps to full rate. Free SRi 3250 psi at 1.5 bpm. PVT =380 bbls. IAP=380 ps' =530 psi. BHP=3904 psi. ECD=11.57 ppg. at 1.49/1.50/3600. 30 fph. PROD1 9135. Lost partial r momentarily. Drilling at 1.5/1.3/3670 psi. Ret oWly healed up. . ound the Ankorite we were looking for. ROP=6 fph. PVT=374 bbls. IAP=680 psi, OAP=823 psi. Need to bleed OA. Send hand to do so. Drilling at 1.51/1.52/3620 psi. BHP=3935 psi, ECD=11.54 ppg. PROD1 9228', Back out of the Ankorite. Continue drilling build and tum to landing point. PROD1 Wiper trip to the window. Clean PU off bottom at 23 klbs. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Q-04 1 Q-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task 10/16/2005 12:50 . 13:05 0.25 STWHIP P 13:05 - 14:10 1.08 STWHIP P 14:10 - 16:05 1.92 STWHIP P WEXIT 16:05 - 16:15 0.17 STWHIP P WEXIT 16:15 - 17:15 1.00 STWHIP P WEXIT 17:15 - 19:00 1.75 STWHIP P 19:00 - 19:15 19:15 - 21:45 0.25 STWHIP P 2.50 STWHIP P 21 :45 - 23:00 1.25 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 10/17/2005 00:00 - 01 :30 1.50 DRILL P PROD1 01 :30 - 03:30 2.00 DRILL P PROD1 03:30 - 04:15 0.75 DRILL P PROD1 04:15 - 05:50 05:50 - 06:30 1.58 DRILL P 0.67 DRILL P 06:30 - 09:20 2.83 DRILL P 09:20 - 13:45 4.42 DRILL P 13:45 - 14:45 1.00 DRILL P DRILL P Start: 10/14/2005 Rig Release: 11/5/2005 Rig Number: Spud Date: 10/7/2005 End: Description of Operations Printed: 11/7/2005 9:58:20 AM 1 Produc 11!115'AKS, 2.812" EUE WELL w/FOUR LATERAL LEGS; ONLY L 1-03 ACCESSIBLE 1 e e FRANK H. MURKOWSKI, GOVERNOR Al,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Mukavitz Kuparuk Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK _~Lt \ C6\Jç Re: Kuparuk River, 1 Q-04 Sundry Number: 306-013 1 vv _ t Dear Mr. Mukavitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisfj¿ day of January, 2006 Encl. JRN-12-2006 14:12 PHILLIPS OK INC Pfl! CIf;~'¥- 907 265~~Ër'\1ËD · STATE OF AlASKA kt ALASKA OIL AND GAS CONSERVATION COMMISSION . I,;; clAN 1 2 2006 APPLICATION FOR SUNDRY APPROV A~18Sk8 Oil & Gas Cons. Commission 20 AAC 25 280 . 1. Type of Request Abandon 0 Suspend 0 Oþel"lltion Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casIng 0 Repair wèlJ 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approvèd program 0 ~ull Tubing 0 ~erforalé New POOl 0 Re-enter Suspènded Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to D7mber: ConocoPhiJlips Alaska, Inc. Development 0 Exploratory 0 184-234 3. Address: Sltatigraphic 0 Service 0 6. API Number; p, O. Box 100360, Anchorage, Alaska 99510 50-0.29-21250-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 33' 1Q·04 8, Property Designation: 10. Field/Pool(s}: ADL 25634, AL.K 2567 Kuparuk River Field I Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft); Total Depth TVD (ft): EtrectiVè Depth 1'.10 (It): Effective Depth TVD (ft): Plugs (measured); Junk (measUred): 9535' 6937' Casing Length $i;¡¡:e MD TVD Burst Collapse CONDUCTOR 80' 16" 103' 103' SUR. CASING 4589' 9-5/6" 4622' 3571' PROD, CASING 9478' 7" 9511' 6706' L 1-03 LINER TOP 106' 2-3/8" 9167' 6681' Perforation Depth MD (ft); Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8709'-8928' 6347'-6509' 3-1/2" J-55 9085' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER 'FHL'; BAKER 'FB-1' pkl"" 8566'; 9013' Baker 'FVL.' @ 1815' 12. AtlSCl'1ments: Description Summary of Proposal 0 13. Well Class after propOsed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: CommenCing Operations; January 20, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval; Date; WAG 0 GINJ 0 WINJ 0 WOSPL 0 CommiS$ion Representative: 17. I hereby certify that the foregoing is true and Correct ro the besr of my knowledge, Cont..ct Steve Mukavitz @ 263-4021 . ,P,;n!"<,.N,.,._ ASteveMU~ ,t ,_ Title; Kuparuk Drilling en9f¿eer Signature ~~. . .,..J...., J ¡ Phone Date \ I \ L. Db C .., C Co~missio~ Use On!y .. 'ISUndry Nm.o . "'- Condilions of approval; Notify Commission so thaI.. representative may witness - (lLð Plug Integrity 0 BOP Test ~ Mech..nicallntegrity Test 0 L.ocation Clearanœ 0 othe, ~500 P">\ iSO"t' ~S\- Co.<,. ~\o.~ RBDMS 8Ft ,¡AN 1 7 2006 Subsequent ~. - u· ed; 0 l-1 APX~-y¡,0A / APPROVED BY Date: /-/3,0,6 COMMISSIONER THE COMMISSION \./" '-""" Form 10-403 Revised 712005 V 0 I~L Submit in DUPlicate e e Rig Workover - Description Summary of Proposal Well 1 Q-04 Kuparuk Producer Replace Tubing and Repair 7" Wellhead Packing · Verify well is dead. A retrievable bridge plug will have been set in the 3-1/2" tubing below the upper packer and tested from above. The well will be loaded with kill vyeight fluid and a BPV set. Nipple down tree and nipple up and test BOP (pressure test BOP to 3500 psi, based on maximum anticipated surface pressure of 2700 psi). · Pull seals from PBR. If the seal assembly will not release from the PBR, chemical cut tubing in first full joint above the seals. · POOH with tubing to SSSV. Set a 7" storm packer and change out the tubing spool and packing to repair the chronic 7" x 9-5/8" packing leak. Nipple up and function test the BOP. Close blind rams and pressure test tubing spool and packing. POOH with storm packer and remaining 3-1/2" tubing and gas lift completion. · Run a new string of 3-1/2" 9.3# L-80 tubing and a new gas lift completion (will not re-run SSSV). If the tubing was chemical cut, run a "poorboy" overshot and new FHL packer above the 3-1/2" tubing stub. · Space out and test. Nipple up the tree and test. 8JM! 1-11-06 St MD ND Man Mfr Man Type V Mfr V Type V OD rERAL wE-Li-Wi¡:oTJR LA ONLY !.99: 6.151 6382 . up our or poc Ref: WSRs Type OD 12/19-20/99 -- Grade Thread (2) RE: Kuparuk temporary flow approval- IQ-04-(I84-234) e e Suhject: RE: Kuparuk tcmporary flow approval - I Q-04-( I R4-234) From: NSK Problem Well Sup" <n 1617~_i;conocophil1ips.com> Date: Fri, 23 Dec 2005 09:5 I: 17 -0900 To: Thomas Maunder <tom_maundcr@admin.state.ak.us> CC: NSK Problem Well Supv '<11 1617~l)conocophillips.com> Tom, We brought 10-04 online yesterday 12/22/05. We will notify you of the SI date - Which will be no later than 1/22106. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 <C-/(' fJ ~\\à.I::r \~~fl~,t')·'~¡Q~",~!:~,,,,j Xi fL -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 22, 2005 8:23 AM To: NSK Problem Well Supv Subject: Re: Kuparuk temporary flow approval - lQ-04-(184-234) HiMJ, Interesting terms "exit rate". Trying to meet the end of year production forecasts, eh? It is acceptable to bring the well back in to production. With regard to the SCP, I am not sure that they apply since you are applying the gas lift pressure and that pressure is (I believe) well below the SCP thresholds. Based on the pressure thresholds, SCP might apply when the well is SI. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/22/2005 5:46 AM: Tom, ConocoPhillips requests an additional flow period of approximately 3 weeks but not to exceed 30 days for 10-04 (184-234). As stated below, this well has known TxlA communication through a tubing leak and is on the rig workover schedule. The workover is scheduled for mid January on Nordic 2 following the next well which is a 3 week project (3H-14B). The purpose of the flow period is to continue to clean up the drilling fluids from the lateral sections, obtain valuable testing information for future development in the area and to increase exit rate for year end production. The well will be operated with gaslift, therefore the risk from the TxlA communication would be minimized. If the additional short term flow period is acceptable it can be tracked on the Weekly SCP report. lof3 1/5/20067:43 AM RE: Kuparuk temporary flow approval- lQ-04-(I84-234) e e Subject: RE::Kuþaruk temporary flow approval -::t Q-04~,(184-234) From: NSK Problem WellSupv <ri1617@conocophillips.cdm> Date: Thu, 22 Dee 2005 08:59:45 -0900 .. 'JJo:i~i[I'h~~as Maunder <toInlmiimdl@~~in.state.ak.us;;~ / ~.~ Tom, You are right that it is below SCP pressure minimums even when SI. However, I was thinking that might be a good place to keep track of it. But if there is a better place - or if I just email starting and ending dates to you that would be fine too. "exit rate" - you are right again... I didn't want to sugar coat one of the primary driving factors behind the request... Thank you Merry Christmas MJ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 22, 2005 8:23 AM To: NSK Problem Well Supv Subject: Re: Kuparuk temporary flow approval - lQ-04-(184-234) Hi MJ, Interesting terms "exit rate". Trying to meet the end of year production forecasts, eh? It is acceptable to bring the well back in to production. With regard to the SCP, I am not sure that they apply since you are applying the gas lift pressure and that pressure is (I believe) well below the SCP thresholds. Based on the pressure thresholds, SCP might apply when the well is SI. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/2212005 5:46 AM: Tom, ConocoPhillips requests an additional flow period of approximately 3 weeks but not to exceed 30 days for 10-04 (184-234). As stated below, this well has known TxlA communication through a tubing leak and is on the rig workover schedule. The workover is scheduled for mid January on Nordic 2 following the next well which is a 3 week project (3H-14B). The purpose of the flow period is to continue to clean up the drilling fluids from the lateral sections, obtain valuable testing information for future development in the area and to increase exit rate for year end production. The well will be operated with gaslift, therefore the risk from the TxlA communication would be minimized. 10f3 1/5/20067:43 AM RE: Kuparuk temporary flow approval- lQ-04-(l84-234) e e If the additional short term flow period is acceptable it can be tracked on the Weekly SCP report. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NsK Problem Well supv Sent: Sunday, December 18, 2005 2:03 PM To: tom maunder@admin.state.ak.us Cc: NsK Problem Well supv; CPFl Prod Engr Subject: FW: Kuparuk temporary flow approval - 1Q-04-(184-234) Tom: Just a follow-up on the temporary flow approval for 10-04. The well was shut-in this morning, 12/18/05. The next item on the agenda is a workover for a tubing swap. The well was producing the following: Oil: 890, Wtr: 66 (7%), Gas: 1600, FTP: 196, Lift Gas: 706, Lift Press: 968. Let me know if you need anything else; the well will remain shut-in until repaired. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: NsK Problem Well supv Sent: Thursday, December 01, 2005 8:05 AM To: 'Thomas Maunder' Subject: RE: Kuparuk temporary flow approval - lQ-04-(184-234) Thanks Tom. After further discussion the Engineers think we can get adequate cleanup with about 7 good days of flowing, or about 3000 bbls liquid. It will take a couple days to have the GLD installed, so a week after that we should be wrapped up. We can keep you posted, but the expectation is that we will have the rig on site by the end of December. Thanks again. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin,state.ak.u~] Sent: Thursday, December 01, 2005 7:50 AM To: NsK Problem Well supv Cc: Jim Regg Subject: Re: Kuparuk temporary flow approval - 1Q-04-(184-234) 20f3 1/5/2006 7:43 AM RECEIVED DEC 0 G 2005 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIO~ska Oil & Gas Cons. Commission e STATE OF ALASKA e . . 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other ~ "jJ.~"'-r~ Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D ø~J1l;; Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D ~11jJ..1 ~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D '., '~~~~Æ'''~ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21250-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 1 Q-04 8. Property Designation: 10. Field/Pool{s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9535' feet true vertical 6937' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 103' 16" 103' 103' SUR. CASING 4532' 9-5/8" 4622' 4622' PROD. CASING 9421' 7" 9511' 6920' L 1-03 LINER TOF 106' 2-3/8" 9167' 6681' Perforation depth: Measured depth: Intervals between 8709 - 8928 true vertical depth: Intervals between 6347 - 6509 SCANNED DE C 1 6 2005 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9085' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 8566'; 9013' SSSV= SSSV SSSV= 1815' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS BFL DEC 0 6 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casil1gPressure Tubino Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact McConnell / Loveland Printed Name Marie McConnell ~ Title Problem Well Supervisor Signature ~/.--./~ "/Ø~". / Phone 659-7224 Date 12/3/2005 ~~ ~~J~ Form 10-404 Revised 04/2004 'GI~JAL Submit Original Only II e 1 Q-04 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/18/200sITIFL failed during pre-CTD ST diagnostic prep work. 9/27/200SReplaced GLVs w/DVs. MITIA failed 11/6/200slcTD ST completed and rig moved off well. 11/11/200S Tecwel LDL found 3 tbg leaks at 7588' (GLM#10), 7462' (collar), and 6736' (collar). The u er two leaks were smaller than the bottom leak 11/16/200SReplaced DV in GLM#10 at 7588' with new DV. MITIA failed 11/29/200SSet 25.7' long, 3.5" retrievable tbg patch across GLM#10 from 7580 - 7602' 11/30/200sIMITIA failed 12/1/200SMITT with plug at patch top failed with very slow leak. 12/2/200SPulled eclipse patch @ 7580. Due to multiple tbg leaks, can not be repaired by tbg patch. RE: 1 Q-04 (184-234) ) ) ....:. .... .' .:.... :',..,' .....'"....,. :. ...:....,........:....:.. ........,..:.. Subj~ct::B%;::l~:f~:4<~¡8~i234»::::. .:....,... .......:: ." .:.... '..:. :...:....:...'....... .... . .,. "<'):...: ........ ,':.' ':":' Fr~I11':.' .".tll.sµp-I?rake:,...:~.har()1?:. K": ..<;Sh,~ron.K;Alls;p_ Dral~e@.c.~n()9ophi·11iÞ.s.CPÌ1}> D~te: Tb.u,06Qct2Q05LO:l(5:12-Q800> .:....:. ". ..' ....:...'.... ....... .. ... '., ". . ,........... .... . ji~þij14~..iMª~~ ,·:i~B~~~:~~n~.~m@i*~~~;i~~~~~t.:~¡~.~~.i'i::I.I,!II.iII: I.::!:'!:::"···:·:·,:"·:"""":': Tom - I will reconstruct a summary from the daily morning reports to account for the original drilling on this well. We can't find the actual summary either in our records. Thanks, Sharon office phone: 263-4612 fax: 265 - 6224 -----Original Message----- From: Thomas Maunder [mailto:torn maunder@admin.state.ak.us] S en t: We dne s da y, Oc t obe..r.......O..5..·;.........2··6'õ..š··..·..i..·;..·:~i'ã........pi1.......···.............................................................................................. To: Allsup-Drake, Sharon K Subject: Re: 1Q-04 (184-234) Hi Sharon, Any luck finding the 1Q-04 or 1Q-02A information?? Thanks, Tom Allsup-Drake, Sharon K wrote, On 10/3/2005 2:37 PM: the worst part of it is that I'm supposed to have the driIlíng file on this well and now I can't find it. Thanks, Sharon office phone: 263-4612 fax: 265 - 6224 SCANNEl); NOV 0 3 2005 -----Original Message----- From: Thoma s Ma unde r [!!.~~~.LL~..~~..:...~~:~r.r.~!~~~l!.!l_~~:~::~:.q~.~~:~i._~~.~l~~...:.~~:~~~~~.~__:.i?:.~_..:_~~.:.!~~.] Sent: Monday, October 03, 2005 2:36 PM To: Allsup-Drake, Sharon K Subject: Re: 1Q-04 (184-234) Thanks Sharon. Don't you just love it when I get digging into the files?? Tom Allsup-Drake, Sharon K wrote, On 10/3/2005 2:35 PM: I'll check into this. Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [!!l.9:.~._~.:t::.u?u:u~:'<?1!:\~T\aìJ.nder@admin. state. ak . us] Sent: Monday, October 03, 2005 2:34 PM To: Allsup-Drake, Sharon K Subject: 1Q-04 (184-234) 10/10/2005 10:07 AM 10/10/2005 10:07 AM 1 of 1 Sharon, I have been reviewing this file as well and discovered that there was no drilling history filed with the completion report. The report of the Nordic completion work is there, but no drilling activity report. Could you check your file and send us the appropriate paperwork?? Thanks in advance, Tom Maunder, PE AOGCC ~~þject:Jq-04(1~4~2f~)',' . fr()Itl:'::,.Tb.()mas...·Ñfa~nderft0!11+ mªun<ier@admiIl·;$t~ty:.;lk.µ$> l>ate:<Mon,··()30ct2005·14:34:01..0800·· . OO!~li~li¡~~~~~~i~~î~~~~Þ~~I~i¡~$~~r~ijl~~~~iî~~~¡t@~~~~~ ) ) 1 Q-04 (184-234) ) ARCa Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well ) S f U"þ ""0 IJ..A.... Drilling Report - J)~ily J Q -'-{ Contractor IV A~ ö tt5. <. G,.l:. SiZ~ ßt,.Depth UlstCSG <f If·'<!.. <ì 5' t J Depth Today .(l!1~3 PßO Days Actual Da;ys Predicted C:L.\~ ' Depth Yesterday Progress 9~1S ,0 Date' " I ,> '1:'zo·,<6 i;' Formation ~ Operation at 0600 {(..( f..r Tté:U:ASbD @.., 1'0 J 'i-l Cf...8 ~ ~~t~ Wt~: c v~A~::"l NA;;~ Gels. ¡ , Ph. Pump No. &: Type Liner Size SPM GPM D~ (:A\c;OC ~)(rz... P.S.I. ra.ke· , I Chi. Sand Noz. Vel. A.V. - D.P. \~L\-J.~~ 'SoC' . ..-- W:~. i Oil Temp Pit IF.L. Slow Pump Rate A.V. - D.C. Bi t No. Size: Make Type SN Jets Depth In Depth Out F.eet Hrs. , \ t " Torqu;,e Rot. Wt. P.U. Wt. S.O. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time RPM WT.-M Condition Accum. Rot. Hr!i. BOTTOM HOLE ASSEMBLY: (INCLUDIN~ DRILL PIPE SIZE & GRADE) LM'J '"' C;Oß¡;L~ 0 '~S(L.. 'IV '9r/,'~'1 ~ .QtJÑ J éJ. -1.( Ä'S t:~'lk-. <,yLo""~(.""\<H~) ~tt-,<)~\.,. dl~1l¿i,<.. P ÅLv.....~<)6 , M.D. ANGLE DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST/WEST PORE PRESSURE OVERBALANCE TVD SHOCK SUB HRS ·1,....... DRilLING JARS HRS ACCEPT SPUD I '1 00 ',,",·I'-.S "\ -~...'B S 0''10 t\.1\.S. ""\.. \ 0.. ~ s OG,OO--tf/oc ç, N \<) \4 12.\JNNI N(;. "r¡ t, '2...' ~ ~.. <;~ ~i"c... C. ~G-) '2.. 5 ~ --s-rs ',,1"ÂL.. ~O~ C-\t2.L * c:.oN 0 to'lU O. ILl c... PI) rll(> t') 0 ßII,L.S "Her ~"5. Sw~f. ß."J. II 0 0 ,-t \J Crl--\ '-.S -(2..~ v, <: W\ -r V N I í \,.J \-\ \ Lk (L~c:.. ,~ rt. oCA .,. é: <: ~ G-. IJ 007 <;'-"1\ 1'((4 "' 0 ~ ~j".. (MVO Pt.\ ott fo c~ '"( ~ , n ~p(",. '40 V ,ç 1 1'-1 f'V) . C'1'pV.6 ~l..S) PVv-A(i ,,~ 1!>~LS 1-\.,.0 10 r:.u-L.l~~.-r~~"'L(N~·S 1'0 ~oooJØ _ Cl'-.. ,L\c..\L O\.J"( ~"'M t'L.ù(, wi '2... 6P.,LS \..\"'to. ~ tX '" ~vVt\f L.t~ð sx( <1~ ¡;ßLS) C-LÀ<;S è,' C&M.1 @;tc;,,~ Pf(". 'VI1'\'?o 1i..c..L..) /')ð)"O-lqJ ,~",o 0 ..";1) . , ð). O-c..) ~ , J'ø (t.C; ~ '" A~I-J ON lUMPS rI,; '-'N~~, DISP '.l / ~c. ~ ~P,L<; (,"\G,~ <'ALe..) tc .0 (J ~(, Jþ.f'1 I NAßJtt I (;Vrr\"tN(".. fLU(,... w( ? 00 0 ~. "~S--1 c.. <;<,..- - 0 \l. . <:. H ~ c. \L ç- LoA'Í~ - ,~ (.LD 01<, C I ~ @ , ~oc; ~·t cr~.. \.. ,t.~L\.() f> ,,"~ -1 {) ~\1"H(N Go ~l>Lc; Ð~ ß\)Y't\~1N(;.. -PlUG-, c.~(YO ~~ívtNS 14( S \\-\ t...\J .. DU1' -:\o~. R.O. ~~ítt.S . {$LV1l1L~ G"L°, r.\\~ '~1 0 '1 ,0, '1l~ t~1' 0°, A\rL ..,~ø) Ser. Pers. on Loco -? 6 N o/j ~ ( , t" ..,' Accidents Date last Kick Drill Date Last BOP Test '-1) 'A -ßO Ie..> ) "Z... A y"l( 0 ,. \1tl Nn'/LOr l.. ~ , ~I LC~^'\ ø 2.. C.O{)(~(Ü) 2.. NOSt) IJ.¡ tJOJtí)IC. ) 1 "1U60~,qf~'¡'TAL. ')-1(, .5'~ )-r~",,; Diesel on Loco Diesel Used Diesel Rae'd. I Gas Used (MCF) Water Rae'd. RIG q '2..,",,0 From' r A LA'L..~ CAMP 4G, 0 From C (>ç,. I TIME OPERATIONS FROM 0600 TO 0600 Temp C.F. -~S· ..-:'0 Visibility 13 Wind Vel. re Slg ned Ji..L, 'ré^,cr~~~ NORTH ALASKA TIME OPERATIONS LAST 24 HRS. CONT'D: \ 4\S- t r; O~ N, D.. Go OPe., p ~\J. C) "AC-\L.. ~~~ ~ 'f~ ~,f S ",II 00 ~. ¡¿,O, r\\ O\JS~/..,o£é , S' 0 O· .. t CòOO -a..\), "1\ 'I L..I ~ ~. ß. Lö\J 0 Ñ I ~O I c:. ~¿, 0 1t'1 V( A/~ IG.CO" t~~ ~Þl~ ttÓ\,)G--(~ C-U\ oN "if c.c;.c, .'L'..Dtf LAÑÞ(~(,,""1'1' .¡. c:..SG- ~1'Uß. (JO,~8/) Ib;O ·--l \400 }--J., It &oPé. ~~ $:1"ACIL O~ ~10M~ I c¡ 002 ' . 1M ~ik ç: INt::.L ,,'/ C. \) "T' . S ~ l' ~ A(.tl... o~ ~ . ~. \). "j"u 61, N.,G. ~ i ooL . é=N6J1.G., té t(.. "1 l:l;~ ~ AC-'L - G)~ ç .. c; l' /)()L -r 0 3 0 <:) ð ~ - ò Il. '. f.3 IV. ,~(,. AOAiPT'rt. "2..0 00 ç:L,..þN(,..~ -f M. A~""'~~ 'J I:)LV~ ø ~O;: P \) Vt\ ~ '00 IS ßLrS c.rf:~, ~ \oJ M ~ () N ,f'f.t' '<: '1'/. 6,tb\IC. ¡)N <e rL' 0+. f 1J1I\~ @> ~ J; '6 () \tV'. S' t... (J ,,~O '*, ~ <J ~o'^' ~-o å ~ r; 0 t,a\l$ 0 \~ ,~'- <!. -¡ PJ t' h' 2.\00 ~(fc;.\c.w' <! 1000·, ç:~a.E: "~~~C~\orJ till")'\.. (0 A1tc..l'lc... PAU..., L.lOO - "'~O tl..ð.. L(N~~ ~ c.(d.LA~. ~~Lu\U;: Wl:ll "t..fL..<éAS~ Ittc. @ "Z..l10 f~L' 1"'f1·t~ , \ ) ',.: \. t"" ~ f\) ~, 1" () 'tt~, At(Jé{J1 .,. 0 t2..tt. ", c¡, . '\. IÐt'lC'f "A~' -oA~ ~ . ì Casual Labor & Equipment: ) L")O 1) \,J II ~ 0 r; ~ L ~ I L () A 1) "ytJ / ""2...;z... c; ~ 6L. IL. 07 ~ VAL 'Í1t UC}( (~14~ ~~(H) M.D. ANGLE DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST/WEST ANGLE/DIRECTION > :~ . I I i FROM LAST '. (, SURVEY' POINT TO TARGET 'Anglo ,.'i',(. ~ Direction TRAINING SESSION RIG GENERAL INSPECTION DESCRIPTION OF KICK DRILL: r ! ~.~PH , D RIH - q MO~NING TOUR -- WELL 81 D EVENING TOUR -- WELL SI D DRLG '. SAFETY MEETING RIG ELECTRICAL INSPECTION SEC, OS SEC SEC, OS SEC FIRE DRILL OIL SPILL DRILL :,) , DESCRIPTION OF ACCIDENT: NAME O~ INJURED DATE REPORT FILED . EMPLOYER .1 '0, ~: t,,:/, .r ;'. ~ ~ WELL NUMBER .{' cQ .. L( SIGNED /'-.. L. l' ~N c..f'J;"f~( ( ',' .1. DATE '!> - ~ 0 .. ~ ; ( ) ARCO Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well ) Drilling Report - Daily IQ-L( N A~ctlS 2..c, IE Operation at 0600 ,d UN N I N G- ,," C$ c;.. ~~t~ w~:q VIY1 P.vi ~ Y'ß G~,{ Pq:O w$. i rak~ I c~loolsan: Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. Da~ r:A'b~O G:.)(t2. ~~ ~SS 2000 Lfo'7 I~'Z- Bit No. Size Make Type, SN Jets Depth In Depth Out Feet Hrs. ~ t1tt ~ c¡r1... S"-- S t z.ç '( 0& ")1" 3 ...If <=1 4'( 0 <) t; 3 ~ , 5 ~;'-t SiZ;&~gt~t @t ~G ë:~ D~f V~ual Depth Today Depth Yesterday <1S-s~ Days Predicted Date ~"1·9·~C; CJ4t¡o ( Progress ~~ Formation Contractor ~ lYe;., 'tAl<. Sol. Oil Temp , , Pit '.' F.L. A.V. - D.C. ' Slow Pump Rate , '2. ...... "'-1 Co "f '" S t' '" ';II ..;I CD G. 0 0 1:tt RPM WT.-M Condition ~~O ..~ 0 -"3 i-;:S-(...·t .. Torque Rot. Wt. P.U. Wt. 5.0. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time Accum. Rot. Hrs. N f) GOO I 10 ~o 0 1 z..5<;Y <; L. 3Y~ liY~4~°'l4t;~4 ' ., BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) ðl..\À 'C5rq: Ol-{tt, fl:L.1... ~ t-Jt> c)1Að) ~ OG SS1"A~ . '3 J S P'- J ~ S 1A-ð) '"2.... c; 0'-) .s S 1A6) X () 1 '-SA.1tS J ~O 'j~ 14 VJ'O fJ 'td '4- 'c-: Jct <~ ¡:/'O.P, M.D. ANGLE DIRECTION T.V.D, VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST/WEST PORE PRESSURE OVERBALANCE TVD SHOCK,SUB HRS DRILLING JARS HRS 1'100 ANE1L~ , ...~..g f) - S~, ~O ,~d.S ~ -, 0 ''is' OCtOO·C)iIS Ç-'N'Sf~ It-l I~ Y/ ß/JA'ð.Cf .,. ~o ,;t-tOG-"S 0'&' C5 .. O~ () 0 \rJ A ~ ~ '" ttkA "^ ~ I ~ I c; 0 "10 <.J '14 O. N 0 F" I u.... 0'00-'2'30 OrULLIN(, Ç('7'140 -ro .,~~~ (~YLi AIl"t") / 2... ~o --I ~I S I 0 S"'-O '5 H ~ll1' 1 ytt f - NO' t.ö P,UM, I ~ S -I S 00 c. IIU- " c.. 0 N.o M \J y) I ~OO"J~OO Po 0 ~, I.t).e>.e 1<-100" 2.000 c.Þ.C-. I o'-( , 2.000 ·2..1 CO 1'00 H ) L, O. l-t w ø ~ ~ 8f-1 A «CJ ZIOO" 2'10 fUlL 'H. ~... 2.1:3 0.. Z:Z-30 c.. (4 c;. '\'0 ýJ t2...Ärr\.c.. l' 0 ,,". ..,- ~ s \' 0OO1.S ..,. 0 -; 000 \\ 'Z..·2.:30"'2.1\~ fl.u, f'Jovt.'14 ~""A1t 'To "VN c:..~~ ê..'\I;-~ ttUNN'NCr ,," c:...<;v,) "2.G,~ --S..r~11iT<:'" ,,,q '"'11'S our ðfo 'Z'\~ \'o1AJ.... Ser. Pers. on Lo<:. "2.. ~ N ~b ott~ J (... A1t!..-o (\ f Q fl NoftO 1 <... ~ 1)1 J M' l.!HfM ACCiden~ Date Last Kick Drill Date Last BOP Test 3 C-OPJ 'Z. NOS"!:, )Lt NOJtOI~ ITOTAL~O 'fJ '-I(."~~ '\"J1"S'~ Diesel on Lo<:. 3 J Lf l <; Diesel Used to; ~~, Diesel Rae'do<:;COO I Gas Used (MCF) ~~te3R2":'140 From' A ¡JAð tf ~ """~ Temp C.F. Visibility Wind Vel. Signed - ~ t .. '- C; (ð '1 1'-., L. l' ~NG.ð~JlG.. CAMP <.¡ <;ë...o From ,~ç:-I TIME OPERATIONS FROM ,0600 TO 0600 NORTH ALASKA ..----............ ) ARCa Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well } (\ _ L.J Size & Depth Last CSG Days Actual Days Predicted Date ~ --, q ~/8" @Þ LfG ~?.. ~ Y'1 1,.. (~. ¡ç Contractor Depth Today ,~ Depth Yesterday, Progress Formation kJ A'; olt~ Z-.e:. E. crt.{ l..( 0 CJ4'1'O ,. - 0 .. Operation at 0600 ,', ,',,' " . -r I (..\ -(oO'(L1LL AOOI"f.oNI\L r2Àí"}Ol~ ~t~ we~h: tt ~ v4, P,,' i' Y.,. 0 ';/ ~ P;, 0 w~: 'I T1<z. ¡ ~'ç 0 ¡sant S"i. 1°";. I Pit v;ei:'L'" Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. A.V. -D.C. Slow Pump Rate, Da;i Ç'A lCoOO G X t '- «'10 ZCJß /goo 4'fZ- 1:::Iz.. '4 0 ~I i is'''';~·M: Bit No. Size Make Type SN Jets Depth In. Depth Out ~eet "Hrs. 4Pf:/, WT.-M con~ltl,on. '. " 'i~ ~i~c.... Sit,ç: Ll ~i"\' 1"'t{ <&<;10 ~'Lf40 i~o Itt'i.. ;/2.0'%6 }"". 'S."" 'CUlt t>; \e. c.... S Bl.t: 4 og "1~ 1il' <f 44 0 , 4-lto w \ c'l.:yt 'rllt p Çof... L.OC,.~ / -,-j; ,tilt.. ßJf., ~E.c. 512..(: 4"i"~~ I'll QQ40 lNG, 1.Nc.. Torque Rot Wt P.U. Wt. 5.0. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time Accum YiP) Hrs (:Z:O i "'0 -; 00 I '2. S' c;4 '54 ".0 - LtI ~õl ~S ~£.t ,J.O · BOTTOM HoLE ASSEMBLY: (INCLUDING DRILL PIPE $IZE & GRADE) 6t-\A "It("q.'. ð \""\ ~ 'Yl.4'l) tJ'~ $.íA^ 'S DC. S S"1~ß.J' . t , I ,)~ ) C; 0 c., S C;~ Ä"; Jz.... s ., ~) S S '1A~) X 0 J ~ ArtS J '10 "'5'1"5 ~W"".J " 'I- G- , cr. S' C;'I o. p. ) Drilling Report - Daily :., ILv f AJt\.)~ PN(.,YAIL. . ~ M.D. ANGLE DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST ¡WEST PORE PRESSURE '1l.f t..( I OVERBALANCE , 0 '1 TVD ç, ~Cl.3 l' O(J ILUfAtLUI( 'i( ~ 0 c. "fo (> .. c. ~ SAN(> ~,., 0 Cf ðA~(;' ~r Ç/JNO ~cg ß S *1-o-p 'A' S'AtJ D Cf 14'3 fJJA~ 'Ä $ AN!> <7'30ß VJL$-\\ "".ILW\ WLM W'-M. \Iv &.W'. 611"\ lffLf i., ,a01 ~ L. OG~tS 10 Cf4~8 WLI,A SHOCK SUB HRS TIME OPERATIONS FROM 0600 TO 0600 /1 o~CE'~A.S ~",q...f~ O'öO- Øl(~ I 0 S~O ,SfJofl:f "T'(lf (J - tJ 0 'f y'lo1l,LtYA' 0"7 ,.;. Oß30 ..~\rt.CJ::,*~Ó""'t'V' U 0 oC¡'30-tl30 ø öoJ4 (tofL L.O G.~ - N 10 ~¡L,ðU'" J L t().. , -;r"'~ 0, P. 1110 -( 2.00 P U'-Lttt ~~~Vf(~ w,,;. , '2..00 ...1 t~o R. v ~ ~(.H L..U~~~~~ J 'Z~2 l2..."4 w/-rdJ r'~ Co~6o, To oL$ 51'o'fJç,.(J SoL.tD@. '1'~o \NLM.('~ ~ç,~ * c.G:~~U U~ orJ 1CÞO~). \NðYL\t.W l.J (J o¡. IN ,,, '1, M~$ Wl'114'Ovf AN"( Ilf30 f/L(J(,fL/nS. rð 0 014 wI LO~ tLVN~ I . ILf30- t~,~ it, o. L..OG.~G:tlS I t;1!'2 L. O. Nt; Aw P ¡1, U. N is S1A6 ç'c>~ 6JJA 'Þt ~. 12.1 H J W ~14~ 1'flttl1 6i.1D~ Igoo ~ Gt4t;C;) ",cr 0 * , oCal.( O~M. I goo -"10 'N P.S~ ttþ Q..tAVtf\. Ÿ/ Cf 1,<1 #0 144 0 Ser. Pers. on Loco z.. ß ~ A~ o1'tS 1 't- A)'t( ~ (I t ø rt.. N1) ttÓJ~) J M lLU-tEM.J ACCldents¢ ð I TOTAl¿ø ?t <:"Or ) ~ tJ o~1.) \ 4 Nott.t),,- :7 0 Diesel on Loco Diesel Used S Ð M Diesel Rec'd. I Gas Used (MCF) Water Rec'd. "..A 00 l I "Z...) 0'1'1 L; 0 I ¿; 000 - RIG z.-; '00 From J,.. "'''/ (; 1M" Temp C.F. Visibility Wind Vel. Signed I - 'Z.t' - ~ '2- , ? 4 J'... L. "'-(¿N(;'ð~~ CAMP %ë..O -From <:,o~..., DRilLING JARS HRS 2..1..1...Y L E/ w <: ,.. t.O' '1 SPUD 0' '3 Q N1lS ' 1...t 0 .. g s Date Last Kick Drill Date Last BO P Test ')-u:..c¡<; ~-11...i"S NORTH ALASKA TIME , ~ o· 'Z.0Lt.~ 2..0LfS· ê..1>~o '2.:110·Z,lf 00 ~40o~. .' . 04 00 64:o0·'b<;(~ O~I ~ -ð'4<; o~LfS- ~,oo Casual ,Labor & Equipment: M.D. OPERATIONS LAST 24 HRS. CONT'D: c.\~ "'" C.aN't) M\)~ pð OJ.t. ço1l. L OG.S - No ,... ("H'1'-' $ P oi"$otl PItðßLfIMS tl.\J, Loc;.¿.~ III t..\ 'fI(L-OG- tl~N' 2... .f LOG.. r; / C 'Ig2 1'", 4 '0/7,. '" ~M -.J/ 01 L I ç~t./ c;t/r~ * (~L.( ~ftl .. L.oc;. .r; (q'iO" ~o ~ ;'oow t.W\ wI ~o(,1 CNL... "00,"", . L .0, LoGo ~ t N G- .,. 'í) ~....~ ~ ~..ø; S (.f'" LV M ~{ G-E-t. P \i u....:, ~ ~Yl \I (e,,& w .dttoJ t'l..ftN'1AU- 1'1I.{ '10 ,DILIU.AO",ftatJAl." tA~/"¡~Lé '" "-', , . , ~~," , : ~ ;~', ANGLE . . DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST/WEST . .' ~. " ;.. TRAINING SESSION RIG GENERAL INSPECTION DESCRIPTION OF KICK DRILL: \'.', D POH D RIH D"DRLG I, .; .,~ SAFETY MEETING RIG ELECTRICAL: INSPECTION D MORNING TOUR -- WELL SI SEC, OS SEC D EVENING TOUR -- WELL SI SEC, OS SEC FIRE DRILL OIL SPILL DRILL . i /' '.. t DESCRIPTION OF ACCIDENT: NAME OF INJURED DATE REPORT FILED WELL NUMBER J~"''-( EMPLOYER 'I, , , ANGLE/DIRECTION FROM LAST SURVEY POINT " TO TARGET Angle Direction SIGNED }L., L. ~~NCrß~ DATE ~ - 11... ß S ( ( ) ) ARca Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well Drilling Report - Daily Size & Depth Last CSG Days Actual Days Predicted 9 -5/, t, ~ 't ,'-"2.. '1 YLt Depth Today Depth Yesterday Progress tJAßoll$ z...<:a é crYI.fO ~ ;e¡O~' ~5 0 Operation at 0600 .'" S HQI\"· ~Ili P~:P~E'P':,'f'Oft L..CG-S :,~ 7ö'.o v~. 0 P'I't; v,pi· Gy/ ø P;,O w~:O ¡caki. 1'i;(O Sand · s;~ oií-~I:- ,;T:'L"1 Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. A.V. - D.C. SIi" pum4 Rat) D~a ÇA \ G.~ (; X , "2.. ~ 0 3ß~ ,-'"t0l':) 4"1 z... 1'14 184 I ~oo ~,c;"r Bit No. Size Make Type SN Jets Depth In Depth Out Feet Hrs. RP~ WTfM Condition c:g ý-¡,. Se.c. S'i2J~ Lfog1)1,) 3-( 'c;~O C,4l/o 'it;o '1Y2..; rf%O 1 x'o IN C- I Q - 4: Date 1 - ('1 ,. ~ c; Formation Contractor 'r<:oÞÁl.U( K.,ftJG-YA'( ?%o Rot0,w:; 0 P.Ui9'5' S'O'its BHê;W¡¡-Air BH:S~MUd DiL, y~eIlO'- ~CICn;Y~~¡KJ.Þ, BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) 6 '4 A. .. % , ß rr -$ SJ /tW() '~IJC-) '5 S1A6 $.0<" , , , J ).1 <; S 1"10-1':> I 2.... SO c:..., $ S1~", X OJ "SAIJ.S..J *'3 0 ""S'15 I-IW{)f; 't:,'" ¥,'c, ItIt, ç~ '$ ~ a p~ ' M.D. ANGLE DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST /WEST PORE PRESSURE '34 ,<e, , OVERBALANCE , '-f ,3 TVD ~ 'fs C;'" SHOCK SUB HRS TIME OPERATIONS FROM 0600 TO 0600 ACCEPT . 1'100 H..tc; "..q...c¡c, DRilLING JARS HRS "ay't.., t;.7w t:'t.. '2..ai') SPUD 01'3 0 '~d.S ; '1"1 0 ~ 8 C; OGOQ - Oil $ t\ N\ ~ 14 R-U4: ogre;· 0'00 ()IlLG. (:{ g ç,o '1 0 ~"4 0 (, ,,\"t. I·ht~ A(¿.or) ß~tN 51~o1l1 f(LtP@.. o~oo Ser. Pers. on Loco 2.. ~ NA I; OItS '1. A rt.(cO J I "'" I L.CI...\?M)..a C.O'.J I TOTAL z.. N 0 ç '!) 4 N ø t.O , L e: CO Diesel on loc1, CoG, "'{ Diesel Used 4 ~ 0 I Diesel Rae'd. I Gas Used (MCF) _ Temp I C.F. Visibility Wind Vel. Signed -1.."2- -~8' 10 ¡LfL. 'éfVC.r3ft<Cr NORTH ALASKA Accidents Date last Kick Drill Date last BOP Test ¢ ~-, ,~S ,\-)';...ßS Water Rae'd. RIG -' 0,0'0 From J ~ -/JAO '#ø '" ~ W\t\,4 tA~~ CAMP I..{<:"O From 'P~.I IOI___"",..·~"",, JQ-L{ Contractor NASO(lS z.<;,E. Operation at 0600 -rtl.t \J I (J,WA · ~ ~~t~ Wët~+ VI~~ P.,.') Y.P~ G;ìt p'.O W~~~ raKi. IC;~o Sand ~o~ Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. A.V. - D.C. Dt. fA IGoo G X'12. 10Lf L.¡t.' ~oo "',- '~'1 ", Bit No. Size Make Type SN Jets Depth In Depth Out Feet Hrs. RPM Q.Q.1 ~>1.. C-OP 6t<i" OUI,'Jt ,-¡ 4'1'33 ¡C;~O '3~~'1 ~,~'Z... ~o ~ ,"1- ~K sc¡u 4- 0&13'1 ¡ --II ,çcro 1NC- ) ARCa Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well ) Drilling Report ~ Dªily Size ~ D~l~h,(L~ c4G Z z. D¿;S 'Î~ual Depth Today Depth Yesterday ~ S , 0 ,)2;'lCö ( Days Predicted Date '3-/G-ßS F=ormatlon '~' \ ~r~·_.? Progress r31l.( Oil Temp íR. . Pit~ IF.L'<Jt. Slow Pump Rate *, 't 4~ ç,», "00 PSS WT.-M Condition '2.0'0 ~ 0 z.. ..1 ...hW ~;;~ RO'¡¡"O Þ.ui~o s"°"t~5 BH'GY.A" BH~W~td DR\~Tr~A~01iý:i~~t:~i~~¡;~~ BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) g J-t.A'«'1 ~ a '''' 'ð'-RIt t") ~ "'1" JJÂVIDIlJLL X 0 t¿wP ) J } t-3V'1\OL, tJ ~Ç1~-6J YV\W~ NMÞt..} NMS1'A6/ "2...- N)\'\ð~.I NM.. S1M) X<o, "SA'\15J ,\o..,rsHwøp. &~ ~ ~~: B (1'" 't5-g I R w<') S oc- J ~ S1MJ c; 0'- J $ S1AA I ,-- S OC") C; $'1A6) X oJ "1A~ ;0 "S1S N \NO~ (:,CI( Cr ,~. S ~ CS + 11P" DRilLING JARS HRS 2,0' E./w ~b '2.... -z.oß" TIME OPERATIONS FROM 0600 TO 0600 1'1 0 0 AC1~ìu -¡..<¡..as SPUD 0 I ¡ 0 ·1111.) ~ .., '0' (is 0(;00-1..1.(0() O(LtU-'N~ ~/"",'1''-0 ~'~(io (/~V'1 M1tSA~OT) ?-l./ðO · ooL(~ M w 0 C+'N (&-;' S u)(..v é 1 J C.f--'éa. 01(. < wlL E, <iCf' t; 4/'~ oJ ~ ,.,..~ £) o oLf ~. 044.s P ðO 1..1 J L.. D ß f..JA Jþ "1) 4) L.M - N 0 ¡ <:. 0 ttJt~c..'1', ~ ~ · Ol.¡.lf) - o",!, PULL} S ~1l\J ((k w, f Ø) I....fc-IIJJ1AL.L.. O~I.c;... tXoo ~1M') I. U1 ßJ.iA" ß. 'f 'H M.D. ANGLE DIRECTION 12..ß«S ~'ì<;L{ '&-z..~~ ~~oS L.t If. 0 4~,i '-f2., I c..¡ I, e. 1J ~'f I ) é Nt; t :~ e N ~Lf. ; é N ~z... '3 E. T.V.D. VERT. SEC. TOTAL COORDINATES (;.NORJlSbUTH etAS II'WEST PORE PRESSURE ,<1,Lf OVERBALANCE z.. q..., SZ518.'3 Lf S'1~.gS C;G;G, S'1 4 ¡Slf, 1, r;, ~O.''{ 'S'I (;, ..2.0 <;, '0, '5 S-3$3.8a 18')6.10 z...O'1 l. I L{ Zz.C;z.../O z.. "3 '1"1. ocr 411J ,,., Y)'Z.GO L' 'It . '1tt It'1 cr C¡" aLl . . TVD <Õ'Z.4fi SHOCK SUB HRS YY\ l LC Me.YI'\ J "'Z- C ø " ) I TOTAL L B I Gas Used (MCF) . Accidents Date last Kick Drill Date Last BOP Test Ser. Pers. on loc, z.. <¡ N A6o,tS J I AILCo..} I 'Z- tJ ~~ J I '-( NOM} ( - Diesel on Loc. I >, '1G $ Diesel Used l..f 0 I 4 Temp C.F. Visibility Wind Vel. -to -,> 7 ~ NORTH ALASKA A ___ _.. ......... ,)"'1 ''''1S "\. "~.-..f Water Rae'd. I A IAr1 IAt</: ~ RIG ~'J %0 From '(ë w,,~ CAMP 4' 1.. 0 From .' (. fit: - I Diesel Rae'd. - Slg ned /¿ , L. -ré tJ G- &E R("" .1 Q-Lf NABottS z,ra E Operation at 0600 . N AV l- Or<..J LLI Nc;... @. '1 ~ '1" ~~t~ W~:S v; ~ P.,.'! Y.P-1 Ÿ''f P~, <; w~~~ ra~ I C¡'t; olsan~ . 50% Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. D2.. fA I '-00 tØ}( I ~ I 0'i Lf4f) 2.~O 0 3G~ 1<;'1 Bit No. Size Make Type SN Jets Depth In Depth Out Feet Hrs. r<:i:l~ C¡Y'Z.. C-OP It"tlq O\Hz..~'Z.. c¡.~ Y-'3.3 IN~ ZSlf3 JG ~ ) ARCO Alaska, Inc. <> Su bsidiary of AtlanticRichfieldCompany Well Contractor ) Drilling Report - Daily Size & Dep)h Last CSG Days Actual ~ is'/g' @LI G,Z'Z. C; V&. Depth Today Depth Yesterday ., Z. '1 (; 4933~' Days Predicted Date s-15-ßS t=ormation , ~~t:"P\ "i ') HAL. Eo I. J Progress a C$ìL( ~ -.........--..,-..-- Oil Temp Pit ", IF.L.'1(; Slow Pump Rate ~, @41 SPhI\. z.., 3 ~ t"'\ Q f's'J: RPM WT.-M Condition . O~O °lÍo /NG A.V. - D.C. tt,ëOrqlle Rot,. Wt. P.U. Wt. 5.0. Wt. BHAW,t,', - A' ir BHA Wt. Mud DR, LG Time Accum. Rot·nrs".'t/': '1"1..., GOO 41 2.. , $ I Q oG:'f·· '5 S c,Y..., ~gT e.;>'~ tl"T/'O-:G"4~"J1, oð 1/ " BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) ßf....\A ~ 7 ~ ß ''T (tt'l") C; 7'-( , M"!! . ~ íD.' N A V, OAJ LL J X 01 R... 'v-J p) NMO C. ) N W\ SiAß./ m W.o} N M 0(. J N tv\. S '1 AG J 7 .. N M. D C, ~ N ~ 51 A a) )( 0) J Aft ~) \ 0 .., 1'5 ,i W'ð f ....G.""..¡ (,:' ~'I J'. c> ~ D, (J . M.D. ANGLE DIRECTION L\ Cf z.. '1 c:)ttCn ,r;~ 'Jß r;; r")1Y '=>o~ '1 ~'1't,1é ~ "1 0, ~ E N Ge.) E. 'tV t;9:~ t:. N C;1,; E. So.Cf ';o."i C;3, ~ ~o.·5 ~' ( , t) TIME OPERATIONS FRO~ 0600 TO 0600 TOTAL COORDINATES T.V.D. VERT. SEC. [NOIl11S0UTH CFAS0WEST PORE PRESSURE 2. ~, .; "3 "'-"3.'0 7" (j ~ . l.f L ''1C'f ~ 0'1 z. $ ~ , ,GS OVERBALANCE¿.1"Z... 19¡1.'1~ z.CJo~,''7 I02.3.~o Z.'13'.ß~ TVD S",1t I.fo C;'7.' æ ;., 'Cr./ . c¡ ß , , I 2. '5 ~ 2.. Cf) «:t. '1'2. SHOCK SUB HRS 'I Z8 <It /10 '3'4 to. '+ ~ I '- ~,. '88 1» I ct 7. % ;/:/,AS HAS 18 '''" 4L{i~.fl3 1<Ô<ÕO. 'Lf 3'1 Z. ,Z:Z- 3'i 0& .G3 + c;z - 2. 09'7· I") 00 Î;lit~ "\ "'~'f$ SPUD 0110 HIlS "1- I 0.. is \}~OO·OGLjS . ··'.;1:..'OL...", , ", ' " o G ~!). 0' f. '5 . ..F , ~1$,fI;: :" "T.:' ;H: ~ .'. ',~ . '. O,,)LfS-ObOODtiLG- '¢ /4'1~3 --(of) z. Y"J' (4 ~ c.o~Il.'+./~ (Lo-f ANO, ~ 16~1a1ti.) ,~c 0 urlC;{ c:.ol.Jt.~(..·r, aNS MAfJ~ AS F" OLL-oW S :r: /4 8 ~S 10 4 ~¡, $ 51_~t( f.I~ ÿl '50' z.. "10 ;- o'7S ~ C. ..~>' @ '!'f·',··tr't) ç I -S t 0 ''''C)'5'~''~ ~ <;,,4' ~ Y-t. t-t It) ç / ~"3 '2..' ..,-0 ~-;8ß :: ç,-z! <!! V't., l..1rt) ç/ t;4i'; 'fo t;~1 S ~ ~'2' ~ 'II.( Aft) ç I 5 <"0 '1 0 -r 0 ~ 1 01 ~ 3)' (!Þ Y4 /~ '-.J ç I G r G., 'Í 0 (t,t.Có3 ~ ~Lf' @ 1/4.{ /-I1t¡ f./ Cot.¡ ~I 1'0 Gt;¡3 ., '3'2.' @ '/..., HIl) ç! CôC;,g ""(0 GC,( 0 -:. 12' ~ '1(4, t~tt.J ç I G 1) CJ Cf í 0 G rs G -; ø <:. it ' t! Yt- Nit. ) Ser. Pers. on LOCz. ~ NA6o#..S / I At2..(.0j J L N o"(l.:O 1!.- ) I L.A~ M f- ~ Diesel on Loc. J Cf 9'1' Diesel Used Lf '1 go Temp ~ C.F. Visibility Wind Vel. - I -10 13 .3 NORTH ALASKA .._--_..~...- MIL-CH€M) ~ CDP./ ~ NoS"! J I TOTAL 'I <:f Diesel Rec¡d } C; Cj::) I Gas Used (MCF) .. . Signed J<,L. "~~G.~~ Accidents Date Last Kick Drill Date Last BOP Test ¢ 1-11....'&<; 3-11-8~ Water Rec'd. RIG r t\ ;00 From ! A fAD L..A\lk. ~ '1 J ~ '- ""'" I ....e:.. CAMP Co.f G,-z..O From C 'P ç.. I ) ARCa Alaska, Inc. <> , Subsidiary of AtlanticRichfieldCompany Well ) Drilling Report - Daily 1 Q.. '-I Size & Depth Last CSG, Days Actual 9 ;!g'l € Y G Z~ '1 y..., Depth Today Depth Yesterday Days Predicted t-JA~ottS 2." E. 4133 Operation at 0600 T . H \,J I NAVt....OtlJ LL C/'Ì B~A 1/1< '7 ~~t~ Wig~q V~ o· P.Vi Y·i' '; ~ì!» ~h~ _0 Ii": g ra; "'·11100 Isan: Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. Dai... F A "0 0 (c )( I 2.. J 00 4 z.g J'1 '5 0 ~." C; I " ~ ~~N¿. S~y~ ~1<.. T;;A s~\o\~4' J;:,o D4~~ L D4t; 33 F9 I H1/4 l(l , ~Y"1- c.O(J R..4tCf 0 II I 2.72 ~., 4133 IN c... 4 {ëHr:2." ~. Progress ~T\ Date ~-14" ~5 f"ormatlon '~~·c¡~\'(~~ Contractor --., ------ Sol. Oil ' Temp'. ~ ' - PitÇz. IF.L.,? .. A.V. - D.C. 7bOW Pump Rate 'O~ le4G.St'W\ , ::J , nð ,.,~-r RPM WT.-M Condition II 0 ~"O ~... z... t fI-J c.. T1~~ Roti~z. P·t~~ s.O.;t~ BHGW~Air BH~~.MUd D;/~Ti;01 ~;Y1R~~/131/ýN,O BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) ß/4A "'" ~. &\1 <>t.tt.' N A (Lw'l'Ñ ~oc.. N vy\ Ç1'A,ð , J ) J J f'I\ 'l-J f)) N ~() c.. J N \Ÿ\ S1'Að,l Ot2.Il:~ 1 S u-&, "2." N MO(. J N M \ -rM;o J "1 j'.::s(J.S J '" ,..., w ø P.. (f ðt""A !t2 ~ 12,\'1 :~'fl) (;'14 MKI%: a' -rf\~ NAVI Ot1Ju.... J XO, rtwfJ I NrAD(.,J NM S-rA6) MW'o) NMO(.., N w\ S1AA) Z- NM.O('..J N yV\ ~1A~) ~ 0) '1"A~j jO.,,-s U w O~ TOTAL COORDINATES NORTH/SOUTH EAST/WEST M.D. ANGLE DIRECTION T.V.D. VERT. SEC. PORE PRESSURE J '5? S OVERBALANCE c¡ r; TVD "3 c., 0" SHOCK SUB HRS . DRilLING, JARS HRS "V1.. E'N *Gz"" l,.og'1 TIME OPERATIONS FROM 0600 TO 0600 ' ACCEPT SPUD , "loo HitS '3.., ·9 c; 01 '30 \-\RS ,- \ O·t , O~OO..O,'O N. 0. DIVE.tt~~(2.. ~"~é\lV\. R..U. tof2.. TaP ~oß( N~ c w\1" )0 S"uwtf') Oß~O-/OOO PéftÇ'OrlMfO 'ToP -:) o~ 'fJ1 c,.,OS}( COI.-O SEí -r. ~.D, fI.J;j. Hvc.HE£ I 1000.. 1100 JNS1'ALJ..... 1"'AN~C.o $~AL. ~'N(,..J <PlE{} Ny:J} (Af'J tf ~ I( c..~(j. SPoOL... 1100 ·'4L(~ tJ.U. P.,oPê) CI..J~.. ToP rtAM.t; ~ J 1" 1'"0 '5': "-I-V. ':LO\NLIN~*mouW40li I'LfLfS) t.U, """0 "'-~~1" 6ot~. ·e.ofJ~ ~'t S"T~IN\~ 1~~1tO OK. wl1'N~<St:O fI,\.( ( /1) 0 G D S, fJ 11.tE A oCr CI.-, l. .D. \=12-01N\'" E:<6:r. 1130 "Ii 00 IJJ ~1'ALL W EAIl l!,uS/~/N(j. I,OO..?n::)O S"1'~AÞ \ p,u, ßf.lA III t; 4 ~1t\JIŒ ~wo - C~G- OOWNHoLé V~A(ffN(,.. VAL-V? pooo·'2LtS (2...1 H- wI t!>~A·' Z.æ.l~·zz..l\~ lU:'Alft; ~ LL. up 1-1N? VALV~ "Z.2.Lf?- t.11!$ ~~s"\ ~ o/i II <: SGr 1"~ ISo 0 *. - OJ~ )t IS M,N. "~I.~- 004$ Or2J...G.. f L.OA"Í ~'Ou...A~) f,,1.-~ cm"', ç..5.~' 01 Né.W J.loLé (AfJ1 ~ ~'N) Ser. Pers. on LOC~ <i N A'I, oJtS) , AYlC 0 I , 111/ ! (H E-M I ~ C D PJ Accidents Date last Kick Drill Date last BOP Test Z. µ Oç"!) II No tlOl C. (¡t.O LL.' Ñ) ITOTAL Y 5 ¢ -;. /1.-gS 1·/3 ·S~ DleseIOn,l2\. Z. 1'!!t!J Diesel Used ~ e. ?3 Diesel R_ae'~ _ I Gas Used (MCF~ 0 .. . Water Rae'd. ., I ., -, ':) , '- ......., - RIG l.\ t:) 1...00 From , A (JAO Temp C.F. Visibility Wind Vel. Signed L.A"'~ - lrë - 30 1:; ,..~ J(. L. TEÞJe,.eé~~ ' CAMP '-IbLOFrom CP~"':' NORTH ALASKA ------........- TIME OPERATIONS LAST 24 HRS. CONT'D: O~~,. . P.V.' N~'06. e,Cr. ~(.1tc... at CON ð MUO. P~LE='\)LW\ ~A"-; oçç í~~1' l' 0 £"0'2..00 11 . C; ',er (¿'MoW - 01<'" 02.00 .'oz...~ Ou.c,. ~ /,4 G 1;? "-0 Lf'l ~'1 '. (Ao1 'f 0 wt,~) oz.&f~· 0Lt1$ pooH 041~· oC;30 P.ut NA,\Jl" OttlLL. .0 Lté-N1' ",,/ MWO. 's ~rt...\\c.é ~wy') oC;~ 0 - otoo ,-, K v.{ &H1\ 0. "7 Casual Labor & Equipment: ,. T M.D. ANGLE (, ~ ", .' ..... ï ".'.' DESCRIPTION OF KICK DRILL: o POH 0 RIH o MORNING TOUR -- WELL SI \. \ :,t ":,.' .:', : ':', '\ . o EVENING TOUR -- WELL SI DESCRIPTION OF ACCIDENT: NAME OF INJURED DATE REPORT FILED WELL NUMBER ..1 Q .. 4 ; .~ ...\ ~ . 'I DIRECTION T.V.D. o DRLG SEC. OS SEC. OS ",/. rr ~'. t:·,\ r . , , ;, j" '·VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST ¡WEST TRAINING SESSION RIG GENERAL INSPECTION ; , SAFETY MEETING RIG ELECTRICAL INSPECTION SEC ',.. SEC FIRE DRILL OIL SPILL DRILL ~ ~. EMPLOYER , , ; -J: . ; :, I SIGNED I~ IL ,1'~NG..t!,étLG- ( .~ I ." ANGLE/DIRECTION FROM LAST \, - I" .' ~,,:, 'SURVEY POINT r::~, ': 1';. .. TO TARGET . Angle ;' Direction c ¡ J;' ( DATE J... 14 -- 8 ; (;} ARCO Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well co~a~r 1. ct - 4 \\\"ßORC; R\(~ d...~ ç:: Operation at 0600 N '} <;TAC-K / PRE? ç./TOP :rOB ~~t~ we~:~ v~ q P·~·S Y.~ Gy;q P;,5 w~~.~ r~i3~ I ~~o tS~ . Pump No. & Type Liner Size SPM GPM P.S.I. ' Noz. Vel. A.V. - D.P. Data ~ fPt tføOt) to X\d-.. \03 440 d.-loOO .,RI 83 Bit No. Size Make Type SN Jets Depth In Depth Out Feet Hrs. RR S \'J...t/q ß ,Co SOS(' Ef. bq~,~:~() '4 \'1 it "4d-. l\ ì5" ~~ ) ) Drilling Report - Daily Size & Depth Last CSG I Days Actual q S/ß @ L.\ ~d..d.w '3 '/lt Depth Today Depth Yesterday , " Y 104d- 4 \:9;'51 .~ Days Predicted Date Progress 4~/. "3 ~\3 -ßS Formation , ~~L::~ '( Sol. 1011 \\ - A.V. - D.C. ."... ,_.~" Temp , PIt "¢L F.L&d.. Slow Pump Rate, \~C RPM WT.-M Condition ,~o ~~ S-4-I: Torque Rot. Wt. P.U. Wt. .5.0. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time Accum. Rot. Hrs. ^~Ø~ I. (J / 3~o ,as'"\~ \<00 <-'to l08J?>5"O Q1,51S' ,,3,\.1 ~a3/~ \33/4\\t,O. BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) ~ \"T - ~(B $"TF\8 -. M (\{'~ - ~/"" 5TA.f\ -~Wl\ K t\r - ~/M ~\f:\.ß - do.. t-\ Dl', - N./tv\ ~Tf:\l\ - do.... c::...t')l'.- xn - .:r~C2 ',: :J..~t.I, It.R ~g (.\\aJr\P a \ \ Ç() . ", I '\ ~ ~\t:\ -= ,~nc:. a..'" TOTAL COORDINATES PORE PRESSURE t 51 ~ M.D. ANGLE DIRECTION T.V.D. VERT. SEC. rNORTH~OUTH rtAS1)WEST l.\ \in '1 4(LQ' \\l '1~,"3 e: 1>;:1"''''' a.. \ LI tn -BO'1 \qq1 ' OVERBALANCE ~OCø I L\ to LI'a. 5'0. \ \~ '141~ ~ 3~4q ~~ 0'4 qo~ ;1.3'-'1 TVD 3 S 4 c¡ SHOCK SUB HRS TIME OPERATIONS FROM 0600 TO 0600 . DRILLING. JARS HRS l1 ~ 3/.., E/w i",,:J - d...O~" SPUD 0' '30 \\2.S -; -lO - ß5 ACCEPT \ 100 H:~$ :\-q....~~ OtoOo- \d.-30 nRL(Y T /4 b4 d! p... D \"" ::: ~ 3/4 H ~S \d.3~ w 1 PO~ "T~If> TII-hùDP ,SLM NO~OR.~ t-1Ò¡::\LL, ~ I ,,<!.... C.Ot-lO t'\\A-t\ 4- I b~O·\-to L~) w/'- s u..evev TO . ~H Ec...~ MWn (óK) ) \ It> 3D .... I 't'~O POOH F/ q 5"/ß" c.~ú- .,.. LD ß H~ . -/ It '* ,G30./ R U- WO R.T\-\ ~T'A(?- t..Pt.~Ett..S J R.\...Lt-.-t \ Ö ~ .::rT~ "s¡.~ 5Cø =tS5' c...OIl~ \.lrF(e~W ~Tò,.C. wI f:.~ cP 453" ~t=S (&) 4Co~~: \ F\\Jt:) SAt-\F-I o 1 \ ~ -- O~15 ~ - ~ \A... ? l ~\Å. ~ J tv\. v....o L.OO K..~ r~oo (\ I ~ u.... \~-+ c.. E H ç: tJ\E..~ ~ Oð..1 "'''\ P UM P 4 () Q,p, I" I-\,;..t\ ,"TEe:. T L\ to!. ~<;. T/ '!. <:00 P<;' \ CO"'-)) KI G\<. \>. TM 'PI U(... M \ ')( q.. pu... M. c> \ \ nn ~ ~ e.. S rTf, -::. 3 ì t~ ~ t\ L5 ç:. L U. ~ e..'(, 1"\ \.x. T"~ M P f) ~ \-\~ 0 S~ 0 I ~LV.ttL" TFMP .,nD ~ t~.~ t>~e:,.} ,... ~ R~t1 fþ). "5"0 P5', l<\r.,.. " MO ~w.6- M \~ ~ P \..lMÞ 5'00 ç.~ 0\= ~~ "':I:. ld \"''T'-\.OU.T _~ ~M (~\LS4)¡..) t'T~) =- ~~ ßRl <; ~I LlR.eV ~ TEMP Oç. ,",v," @ \"~ P~(- @ S-Cø ßt'M @ ~50 ~S\ J \(.\c..K, TOP þ\ \.lG,. Ser. Pers. on LO~ q N. ~ßOR.~ -.:l N.05 \ _ ~ N.~ \ -.3 (to Lètù -If ¡. .:r _ \ ,",Wv Accidents Date Last Kick Drill Date Last BOP Test l - M \ Le..~eJo'\ - , Pt2..C..O TOTAL 43 -e- 3- \;)...-ßS' Diesel on Loc. t Diesel Used Diesel Rec'd~ I G.as Used (MCF) -c;>- . Water Rec'd. \ -'1.. 4- " t-\.\ LE l.... B;J If ~ 4() RIG.1s l CøOO From p\:""e~ Tem_p \,., b. Visibility Wind Vel. Slgne~ \/1' h? /J' / _ .. , - ot~ t'\l ~LM /C.. II r~ CAMPLl"~O From C!.PF-( NORTH ALASKA ( c) e TIME OPERATIONS LAST 24 HRS. CONT'D: \ wI , (') ~ßl~ \~~O, (J1~-S \-\ \ \ ~[::.~, D \ ~ Ç\' c.~ T wI p [(~ Pt.tM p~ '"'" ~ lA.M 1> PI lA,.("", wI ~ ~ ,~ ~Te.."S / 1'. A I_it U-l p.:,s= 1') ~ Te..fCS =- ~ Õ ~/~I ¿ øt \~OO P~\ l'_\.P. <IÐ- ,os,~ ,-\P<;' (~t'\\,\...\ {)R-E~S Te~, n\(.. ç:.t n~T~ j - . I \--\ l:: l .t'\, H A. n t= tAl l. R F.,.. tA.. ft. t..) ~ T 1-\ e. \A.. - 0 u... T tI_ H.T :r 0 "', \J 0 l'~......,.. (3 ~( ·r OS30TO ~tA.~F) ::rlLS,,\ f.n~\TF\11 M.u.b (Ii) ~tJ~(ij. lO.4-PPC-., Of;~O -0(000 ~\ \..L ~TF\c.k::..... "rt.EP F I ToP .:-roB. LA.J l Ll . \"> F:R.FO~M Pt~C.\lc.. PI\- t<:. r\~ ~ G..-lft WI Ll R.\ ~ ,~ N ~ ç:e') R. \',0 ~ :\()~ O~ ~,- q, -l\. \ Casual Labor & Equipment: t\l ()~ F M.D. ANGLE . DIRECTION T.V.D. VERT, SEC. TOTAL COORDINATES NORTH/SOUTH EAST /WEST ANGLE/DIRECTION FROM LAST SURVEY POINT TO TARGET Angle. Direction TRAINING SESSION RIG GENERAL INSPECTION DESCRIPTION OF KICK DRILL: o POH 0 RIH " ,4 o DRLG o MORNING TOUR -- WELL SI o EVENING TOUR' u WELL SI SEC, OS SEC SAFETY MEETING, 3 -I d.. ~, 'Ô s: RIG ELECTRICAL INSPECTION SEC, OS SEC FIRE DRilL OIL SPILL DRILL DESCRIPTION OF ACCIDENT: NAME OF INJURED EMPLOYER DATE REPORT FILED WELL NUMBER _4 .-1\ - 4 SIGNED 'If Y), p~ DATE 3-J'3-~S-- §! ( ( " . .,~ ,'.'¡' ARCa Alaska, Inc. <> Subsidiary of AtlanticRichfieldCompany Well ct~r~? -L ~ - '4 ~ f-\ ~O~, R \ {.,.. ';i"ln ç: Operation at 0600 b R. LC:r ~ \-\ E:. 'Pt '"' ~t~ weq': '1 V~'1 p. ~ to V ·~·3 GZho Pì. ~ ~.~, l r% d.1 ~' £> () 15a~ 5,' i 011 Pit (" ~:I:'L.¿ 3 . Pump No. & Type Liner Size SPM GPM P.S.I. Noz. Vel. A.V. - D.P. A.V., - D.C."r, Slow Pump Rat~ D! F~ \~O() ~X \;;1.. t()~ "'40 a.40f) 4~5 ~~ \~8 ~ M~~~(\t) Bit No. SIze Make Type SN Jets Depth In Depth Out Feet Hrs. RPM WT.-M Condition Rr(S \d.'/~ ~Ttt c.l\'k~A.'~:01~-f- ~-..(~ \~~() ::tDS'1 "3" ~I/tf 0/40 '<Y;5'" 4-4-l/8 tlR.'4 \6.'/4 (~""l' -n~t\ toPQ4ß ';..~o e10S'1 '-\ tCn'1 d.\\o:\O"A/q qOÆso .1~S' 4-3 - Va ~R, \~'/u ~:Tt' St)~t' ~R(f"\l\~\ ~:~') 4\~' 4\ß~ ~Q... 1/¡J... '\)~~S"~%o \~(" ~~pe'S Rot. ,Wt. P.U. Wt. 5.0. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time Accum. Rot. I-,rs. ~\ t), 3(øo \ ~ 5 t~o q 0 \ Q~J~SO q '1,51!Ç \ ~ lJil H2<. \ tc,":R.~, \33/-... BOTTOM HOLE ASSEMBLY: (INCLUDING DRILLPIPESIZE& GRADE) ß\T- w./~ STA~ -MD~- N./tJ\ 'S'Aß-MWO.. M'" <!. - N 1M ~""Aß - ~'M (\l' - ~/t"\ STA R - ~ SbC- ')( 0 - .:rF\ 1t'::. d.54. ~q' ~ R \-\Wt) P = t \ SO. ~" I T ~ \~ ~:. \ 4. 0 S, ~l.,' "J Size & Depth Last CSG \tø" @ '03.' Depth Today. Days Actual ~'/4 Depth Yesterday '" "" ~. ø...O S., .." 4\~5 M.D. ANGLE DIRECTION T.V.D. VERT. SEC. ;t d. (JI) 9 41. Cø ' M lø4. ~ E ~ooo "~4 ~ s;- <l ;t. 5(\.4 ~ ~ta. 3 e: ~dO~ "bO ~11oR Sl.d.-. N ~"1, 3 F. J..'3~?1 \\03 ~q~O 50.0 N ~fL 3 E ~445" \~5' 3J..(~ q'.<2 N 10.?> E d.. Co 51 I 4 tt>" TIME, .oPERATl.oNS FR.oM .06.0.0 TD .06.0.0 ACCEPT \'00 \-.\~, ~-q-~~ ) Drill i ng Report- Dai Iy Days Predicted Date Progress "3 - fél -ß~ I~.ormatlon l~'N'i. t:,.t.\JL. ~~'t ~\ d..8 T.oTAL C.o.oRDINATES (NDiUH}S.oUTH (EAS-oWEST õlO 40'1 ~,,~ S'6.~ t.. O~ tøot ~ '-' Rbq 1001 )\ ~8 \~Sq PORE PRESSURE Ill: t 'ò .oVERBALANCE ó\. \ '8 TVD ~ a 41 ! SHDCK SUB HRS DRILLING JARS HRS , bto e/w ~ d.. -d;.O e'1 SPUD or~o '"'~~ ",-IO-~~ Ser. Pers. on Loc.' \ a.q ~~t=\O~~ - ~ t...\Q~ \ - ~ 5PERR.'( - a t\..l('J - '?J ROLLN t f\ R<!.O ' T.oTAL3't Diesel on LOC:.o'\\ Diesel Used U ~ l ~ Diesel Rae'd. I Gas Used (MCF) -@- ~ 5"~~ I;:) u \I~OO Temp C.F. Visibility Wind Vel. SlgnedD ý\ (;) ð f A -\0 -.\~O'1t1\ 3~NOT, lI'..~I\,'t'~ NORTH ALASKA ,; ùloDO - bfø"!>t- wit -S U.R\JEY. OfD30-0ßO~ ?OO'c-\ F/ ß l.\Pt. Q- ~lT ~\r-\\\\('~ O~(\O-ðq~fì r_~\..)(- ~\-\~) ~t=R. MW('\ l'_\-\~(_ ß\T~ n't30-In4ç Tl\-\ w/RR.t4::?\ WA~\4 ~R.ÇAM 5'1' T/~TM , I I \04<2' D~LG.--w/RR-1i~ T ~\~'1 I \-\IT' \--\A.\Z..ð S'TeE.AK.,ß\T IO('.~Et)<A~ 0\ 30 P R. ~ 'P ,I POt:) ~ A t)T lO '!(4 '-\R.S I Ot3()-D'\~O l'·\e..~í Pu..M~ P\L\ t>OOH) (!.~~(- ß(T5. R.o<:..\<.. WE.t:'tc.r=b UJ c..o..,e; I , ( o~~o -0&'00 T \ \-\ w/RR ~s ~ ,\ ~ \E.-"-T SPOT ~ ~ ~ C;O ,0 Rlb- T/ ~ (~~ ACr \/~"R Accidents Date Last Kick Drill Date Last BOP Test ~ 0 e.Asu.AL l r:\ ~Oe. Of¿ 1= q u..l P --------.- -e- 3-(d..-as - Water Rae'd. RIG", ~OO From \~A. Q..-fo M\lE L$\~ES CAMP 4løa.O From (!, p (Z _,.. o ~ ARCa Alask'a, Inc. Su bsldiary of AtlanticRichfieldCompany Well ) ) ~-.. ~, Drilling Report --:. Daily Ku..P t. q-~ Contractor ' Size & Depth Last CSG \to"~ \03' Depth Today Days Actual , '/4 Depth Yesterday " .' 5" 0('1' -.1 . ( Days Predicted Date Nf\ßOR~ R lG- a~ E: t~~ 3-((- ~S I Hbrmation j'1 ~:o f(6-\..O t1 e RÞ. ,e Progress 'L~+ Pump No. & Type Data a. \= r:\ \ bOO Bit No. Size Make ~ , <1.'/4 RR ~ I j.. 'I", «1051 N Pt\l \ C\R \ b- ~R.F P TO ~OO~ ~/r\H P-.~~r- ~t~ Wei,ht v~O P·~4 v;O ~%o P~..!í w~~.O I";i~ ~ I ~i~O ¡S-:.. S~iO I:' I Pltt,¿., :T:'L.,,~~ .Li~r;~~ s~~~ GP~4't P¡70%ooö N;~e~. A.V~-;.P. A.~.;~. Slow Pump Rate Type SN Jets Depth In Depth Out Feet Hrs. RPM WT.-M Condition l..q " ~. 0/ toL HTl'. tH'<3A z..Z O;lfD r':~~ .c;on \l..~O \\RO' \.... /~o 130 R- 4- - 'I@, HT~ tl1"'3~ ZO 1ßlø 3-1;}. \ b ~O d-.O 5'1 "51' '; 1.~/c.¡ %0., lOt'. ~ \ We. Operation at 0600 Torque Rot. Wt. P.U. Wt. S.O. Wt. BtlA Wt. - Air BHA Wt. Mud DRLG Time Accum. Rot. Hrs. ad..l\ \ \ n 1 ;¡O \ \ () q I, I 0 0 <;J" ~q 0 \ ~ ~. N. D, c11/~ 113 3/~ N n BOTTOM HOLE ASSEMBLY: (INCLUDINGDRILLPIPESIZE&GRADE) R\T- M~~ ~b-;t~ ßEw:TS\AR-',f/s.- Mt)l\- MW\1-M,t\l'.- {)R.\.r:=~f\ S\.l~~ d..ko('~ ól~C~-)lO -.:r~R..~ ~{~4,'d...o'...... , , I I ~ R.::rTc::. .~ Wt\ P = 1\;:0.!; '1 TO,f\ \ - R \-'\ ~ =- \ 4-, 4-. " TOTAL COORDINATES M.D. ANGLE DIRECTION T.V.D. VERT. SEC. ("NORTH'))OUTH C EA~WEST PORE PRESSURE ï., 7 Co40 3.4 "-\-loq. ~-F 5 '0 Ç,04 ~.~ß 4-. S' 0 OVERBAL.:ANCE ,q '3 <lS¡a.. 1(}.... N- '10, ~.. E.. <l,\ 0 ~1·~' l~ ' 4 ~ 34.'10 . TVD J 1 ~O ' \O,,~ \S'.~ N - L,3 , 3- E 'tßCø 8ô. 3Ç 30, Q,\ ., 4. (,3 SHOCK SUB HRS 1 a.. 410' l '1,~ ~'''101.3-E: \ \ (,,0 1 ~S-- . 5"3. 35 1~4. 33 DRilLING JARS HRS \ S5 Vc.¡ E/w t l\ aß J.3.2 Ñ-rt...l.~...E \:\d.,,\ aO\ '1'\ I QS' ~:¡.. d-.Oe, TIME OPERATIONS FROM 0600 TO 0600 ACCEPT SPUD 1100 \-\ R.~ ~-9 -'òC; or 30 HR$ 3-l0-~S" o,^Ol'\..) FI\\\ TO\-\ I \ 0 ~T~~, t>\..L MA.t..H)t\ t\\ 't\.J 5ç::'~ MWt\, nte.l-=-~'" C oqoo T \ \--\ 1 ~u.. MU.D S A.V£R... ~v...R. OqOO- 004!:: N.~" l- Dfl.\ (-.. T / I ~~O' A.DT =- \ \t-\L~ 004< - oalts TO \-it v;.f ~ \\, ~ ~e.. M. \AJt) , \" \ \\ wi RR. ~,\ ~~ ()~4 ~... 0 bOo \\\ f:\\I \ - 012\ l..... T / "J..() ~., I A b T = :t ~/~ \4 R.S, Ç> 2.-\;J> TO P 00 \-\ . Ser. Pers. on Loc. , a.l\ N~ßOR~- ð..~Q5\- \ M\L~~eM - J. NC.,. - ~ ~OLLt\\ - d- I TOTAlU l.- S~e.RRY- 4 ('..,.() -~ p,o~- \ I\Rt'O , rJ Diesel on Loco Diesel Used 4 0 ~ , I Diesel Rec'~ I Gas Used (MCF) ..e- 14 '3~::l ~..,. T'm~5" CF:"dSCV~'3\~\ 'qd~\IIO~ S"k? n. p~ NORTH ALASKA Accidents Date last Kick Drill Date Last BOP Test -ê- Water Rec'd. I-~ 4-Co MaLE RIG 5~ 44:0 From L...P.\C.ES CAMP 4 fo~O From c.. PF -1 .. - -- -.. ~ ....... o ARCa Alaska, Inc., <> Subsidiary of AtlanticRichfleldCompany Well ) ') Drilling Report - Daily \< ILP 4l{-4 Coñtractor Size & Depth Last CSG l<ø" @ '0 ~ I Depth Today SOO' Days Actual '/4 Depth Yesterday I-fT~i /oJ ' Days Predicted Date \\.\ ~ ß ()«.S R \ C:r ;tl^ E Operation at 0600 Tn ~ F/ K lC,Jc..OFF --OOLS Mud Weight Vis. P.V.' Y.P. Gels. Data ~, g \ 00 I S ~() 8/, ~ 'L .t:" "-I Pump No. & Type Liner Size SPM GPM P.S.I. ~ FA l(ð()O ,G, Xld- 9R 4'" Bit No. Size Make Type SN Jets Depth In R~' ,';tVq ~e.c. S:!¡3Se 313 ~80 ~:,~ Progress ~J 3-fO-~5 F9rmation , ~Þ.\2~R M Ph. W:L. r~3~ I ~h~O I~; Noz. Vel. .. A,.V. - D.P. Sol. '011 '" Temp l.\: - Pit 3"0 IF.L. A.V. - D.C. Slow Pump Rate ,., 5"0 34lø ß~ 114 Depth Out Feet Hrs. RPM 500 .3q'l J.. Va. ) 4 0 WT.-M 0/35 Condition \ 0 '3 , \\f (" Torque Rot. Wt. P.U. Wt. 5.0. Wt. BHA Wt. - Air BHA Wt. Mud DRLG Time Accum. Rot. Hrs. ~O~ ì ç ~ S '1 S 4l, (00 4:a~?J(lO ~ I/~ ¡,IJa. BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) 'ß/~ _ M nr -N/M ~TAß- M W [).... MOl' - NtH STA ß - ~ M Oe, - \\1 1M !'TA ~ - 4 '~tJ C'_ - )(..{) - ..:r~tl ~ 3' 4."1"1 M.D. ANGLE DIRECTION T.V.D. VERT. SEC. TOTAL COORDINATES NORTH/SOUTH EAST/WEST PORE PRESSURE OVERBALANCE TVD SHOCK SUB HRS DRilLING JARS HRS ~ , (,.. ~ ACCEPT SPUD \'ÖO' "R.~ :'.-t¡-~5' f)ï~O HE.~ 1.-10 -Ft~::; O~'O..> ÞRe'.P"R.\c"'J"rfMO\E A(¿.OUNt) C.O~tJ.~R TO .~ C\-lJ.¡ MOVt=· ~AM[:. C \.., 00 ft lÅ R \( ~ I 5 PO\' P \ P"Ë S \-\ ~ 1) e: '\ l'., P u. T'P ~ L( "- F='" q Lt·t PIN ~ Ii ß , \1020 Nu"TA\\.l\c!(t·O ~t=f:\t) ~f)\V 'S'(c...TEM, ~\A Ho'fDRi\ DR,L6-.t-..\\?,....FLOW N \ Ç)) ~ T'~~ P '" {\ \At' D ß \..\ A J t'\. \ ~ S ~ ,^D M\A t), t=CA. f\.lc.. \\ ON -r'f:; ~\ 0\ V o I ~o s ~ 5 T~ M . cn~O-^~~() SP\Á.D LdF:Ll'_q.. ORI. F/'O?/ - ~OO/ A DT d.}/~ l-\R.S O~~O-O~OO TO H. Tn P Lf_\( tÅfJ Tno lc::.. F/ ~lC.L<.oFF. TIME OPERATIONS FROM 0600 TO 0600 »0 ~A~LlAL L.AßoR.. OR t=:.q U-lP Ser. Pers. on Loco ~q \\.\.t\ROR.~- d.. NOS \ - d.. N. <!.. - \ M\L~~E"M- '3 . I TOTAL R.OLLtJ - l f.\ ~('JO Diesel on{~ 351ð Diesel U~ S- t.:,;¡ Dleseri~t; () 0 I Gas Used (MCF) 0 T'm~ ,a: c~ 3 ~ ~i';" 1"\\ ~'Öv~MOTÇ. S;'"!c? r7. j-J~ NORTH ALASKA Accidents Date last Kick Drill Date Last BOP Test -G- 3-3-85 3-d.--ß5 Water Rae'd. RIG SS".ll ,",0 From (:\-1 4- iÞ M' LE LA ~ES CAMP 4 b~ From (!..þ F-t .. --- -... ....- ) ConocriP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 2004 81/ Subject: Report of Sundry Well Operations for 1 Q-04 (APD # 184-234) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 Q-04. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )Ill 111~ M. Moohey Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV O. 3 20D4 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2004 RepairWell D Pull Tubing D Operat. ShutdownD Stimulate 0 Waiver D mb8(~n~S Cm~ Time EJåmiBR'í'89!j Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 90' 8. Property Designation: AD L 25634, ALK 2567 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - .0 Stratigraphic D Exploratory D Service D Re-enter Suspended Well D 5. Permit to Drill Number: 184-234 1 6. API Number: 50-029-21250-00 9. Well Name and Number: 1 Q-04 10. Field/Pool(s): Kuparuk River Oil Field 1 Kuparuk Oil Pool measured 9535' feet true vertical 6937' feet measured 9366' feet true vertical feet Length Size MD 103' 16" 103' 4580' 9-5/8" 4622' 9465' 7" 9511' Plugs (measured) Junk (measured) 9051',9119',9530' TVD Burst Collapse 103' 3570' 6920' Measured depth: 8709'-8719',8722'-8726',8735'-8740', 8742'-8753', 8756'-8764', 8771'-8777', 8834'-8881', 8914'-8928', 9157'- 9224',9285'-9303' true vertical depth: 6347'-6354',6357'-6360',6366'-6370', 6372'-6380', 6382'-6388', 6393'-6398', 6440'-6475', 6499'-6509', 6674'- 6721',6764'-6776' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9085' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 8566'; 9013' SSSV= Baker 'FVL' @ 1815' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9157' -9224', 9285'-9303' RBDMS 8fL MO~Ul 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl SI 104 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinç¡ Pressure Casinç¡ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 172 308 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil 0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Mike Mooney @ 263-4574 Mike Mooney 1t«)1~ Form 1 0-404 Revised 04/2004 Contact Printed Name Signature 210 WDSPLD Title Phone Wells Group Team Leader Date I()Ä"1-04 Prepared bv Sharon A{S~D-Drake 263-4612 OR\G\NAL Submit Original Only ) ) KRU 1 Q-04 . CoôocoPhilliþs Alåskä,ln~. 1 Q-04 J j J Jllf.f J .-: J8f J_:; J..! .~" ..II ~ -¡.'. .. .I.:. - _.JI API: 500292125000 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 9366 LastTag Date: 5/29/2004 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Well Type: PROD Orig Completion: 3/19/1985 Last W/O: Ref Log Date: TD: 9535 ftKB Max Hole Angle: 53 deg (ij) 5400 Angle (ij) TS: 41 deg (ij) 8708 Angle @ TD: 46 deg @ 9535 Rev Reason: GLV design Last Update: 9/3/2004 Grade H-40 J-55 J-55 Size 16.000 9.625 7.000 Top 0 0 0 Bottom 103 4622 9511 TVD 103 3571 6920 Wt 62.50 36.00 26.00 Thread Interval Date 8709 - 8719 6347 - 6354 C-4 12 4/24/1985 120deg ph;5"Scalloped HDC 8722 - 8726 6357 - 6360 C-4 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8735 - 8740 6366 - 6370 C-4 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8742 - 8753 6372 - 6380 C-4 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8756 - 8764 6382 - 6388 C-4 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8771 - 8777 6393 - 6398 C-3 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8834 - 8881 6440 - 6475 C-1 ,UNIT B 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 8914 - 8928 6499 - 6509 UNITB 12 4/24/1985 IPERF 120deg ph;5"Scalloped HDC 9157 - 9164 6674 - 6679 A-4 4 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 deg. CCW F/ 9164 - 9224 6679 - 6721 A-4,A-3 60 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 deg. CCW F/ 9285 - 9303 6764 - 6776 A-2 18 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 deg. CCW F/ Gas Lift MandrelsNalves 5t MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run 0 3/13/1994 1320 5/25/2002 0 4/25/1985 0 3/13/1994 0 4/25/1985 1352 5/25/2002 0 5/12/1994 0 9/26/1993 0 5/25/2002 1382 5/25/2002 0 5/25/2002 0 9/2/2004 Vlv Cmnt 1 1957 1819 Cameo KBUG DMY 1.0 BK2 0.000 2 3383 2760 Cameo KBUG GLV 1.0 BK2 0.125 3 4099 3234 Camco KBUG DMY 1.0 BK2 0.000 4 4637 3580 Cameo KBUG DMY 1.0 BK2 0.000 5 5177 3923 Camco KBUG DMY 1.0 BK2 0.000 6 5751 4280 Cameo KBUG GLV 1.0 BK2 0.156 7 6224 4579 Camco KBUG DMY 1.0 BK2 0.000 8 6698 4887 Cameo KBUG DMY 1.0 BK2 0.000 9 7113 5177 Camco KBUG DMY 1.0 BK2 0.000 10 7588 5519 Cameo KBUG GLV 1.0 BK2 0.188 11 8095 5887 Camco KBUG DMY 1.0 BK 0.000 12 8506 6194 Cameo MMG-2 OV 1.5 RK 0.188 1. BK latch @ 6698' RKB bent slightly up out of pocket; Ref: WSRs 12/19-20/99 Production MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO (1 ) 13 8604 6268 Cameo MMG-2 14 8674 6321 Camco MMG-2 15 8972 6541 Camco MMG-2 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1815 1714 SSSV 8552 6229 SBR 8566 6239 PKR 9013 6571 PKR 9051 6598 NIP 9084 6622 SOS 9085 6623 TTL Fish- History ofFISH Depth Description 9051 Keys & Plug from CR 9119 27'of17/8"TooIString 9530 DMY VALVE Date Run 0 5/30/2004 0 5/30/2004 0 1/28/2003 Vlv Cmnt DPHFCV DPHFCV DMY 1.5 1.5 1.5 RKP 0.000 RKP 0.000 RKP 0.000 Description ID 2.812 2.992 3.000 4.000 2.750 2.992 2.992 Baker 'FVL' Baker PBR Baker 'FHL' Baker 'FB-1' Camco 'D' Nipple NO GO Camco Comment Plan to Push down to Tubing Tail. Tool String lost in rathole 5/8/94; wire recovered 5/10/94; Fish history in WSR. 1.5" DMY valve set 9/15/02, but during check for DMY on 1/27/03, impression of empty socket; 9/15/02 DMY dropped; depth not known. ) 10-04 Well Events Summary Date Summary 08/19/04 RAN GR/CCL FOR DEPTH DETERMINATION: TAGGED BOTTOM AT 93551 - - RAN PST TOOL AND STIMULATED A-4,A-3 PERFS: 9157'-9224' AND A-2 PERFS: 9285'-93031 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: May 17, 2001 THRU: Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May ! 7 ,, 2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. SUMMARY: ! witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. Att.ac. hmen. ts: SVS KRU lQ 5-17-01jc CC; N.O,N-CONFIDENTIAL SVS KRU lQ 5-17-01jc Alas~.,, Oil and Gas Conservation Commis~_.a Safety Valve System Test Report ~tor: ,Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Kupan~ River Umt.', lQ pM,., "' ' Separator psi: LPS .... 85. HPS 5/17/01 Weft Permit Separ Set L/P Test Test Test Date oa, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed G~ or ~E ~Q-0:n~9~m4o ' , ~Q-O~ ~8n:~0 ' ' ~ 7o .... 6~'e ' e .......... , [ . .., , , . ~. [ . [ ~Q-~ ~sn:~o ~ 60 ~ e e !Q-o~ ,~8n:~70~ 70 "'~4 e ..... .. n ........ ox~ ~Q-,06 ,~84:0~0~ ~0 '"~ e ,'e ' , .... 0~ ,~Q-O9 ~84~9:o ~75o :ooo ~9oo p p WAG ~Q,~o.. , ~84~8o8~ ~o. '" ~:.e~. '..?. ..' ....... ~Q-~ [ , .. [ . , . ,, , , . ..~ [ ilQ-12 1841930 .................. t~Q~5 ~ ~85On6o, Q:!~6 ' i8~0~0~' 70'' ~e' 'e .... oX~ Q,:oA i9~60 " ~ ~ 70 ~0 e " g ......... [ [ .c , · ,., [, [ ,. .,] 'IQ-:: . ~9~noo "' a~70 .... ~ 'e e .... ~.Q-:6, ~9~:0 ~ ', .70 .~:., ,e' ~ ..' ........ .. 1Q-08 1970930 3750 2~ 1850 P P WAG ~Q-~ ]~o~6~ ~7~o :oo6 ~8~oe e ' 'wAa ~Q-~4 ~5o4~o ~7~o :ooo ~8~o'" p p ' "WAG ~Q-:n ~9~o~ ~7~o :ooo :ioo' e e w~ [ , [, [[ ~ ~ [ [ . [ .[ ,. Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% J~J90 Day Remarks: 1.,Q7.05 was se.rvi,.ce~l,. &,,. reTt.e,.st ,ed. ,re-.test faile~. & well~w .aC, ~h,u.t, in. for rep.airs._ ..... i _ , i , _ ii i i lli , , i[ , i i i , , it 1.. lift . RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb;::;ION 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 1227' FNL, 1057' FEL, Sec 26, T12N, At top of productive interval 1313' FSL, 1480' FEL, Sec 24, T12N, At effective depth 1593' FSL, 1069' FEL, Sec 24, '1-12N, At total depth 1636' FSL, 1000' FEL, Sec 24, T12N, 5. Type of'Well: Development X__ Exploratory _ Stratigraphic _ Service R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 9 5 3 5 true vertical 6935 Effective depth: measured 9 4 2 3 true vertical 6858 Casing Length Size Structural Conductor 8 0' 1 6" Surface 4580' 9.625" Intermediate Production 9465' 7" Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 90 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-04 9. Permit number/approval number 84-234 10. APl number 50-029-21250 '11. Field/Pool Kuparuk River Field/Oil Pool feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 240 Sx CS II 1100SxCS III& 500 Sx CS I 60 Sx CS I & 480 Sx Class G Measured depth .'~'-:True vertical depth 103' 103' 4622' 3570' 9511' 6920' 8709'-8719', 8722'-8726', 8735'-8740', 8747'-8753', 8756'-8764', 8771'-8777', 8834'-8881', 8914'-8928', 9157'-9224', 9284'-9303' true vertical 6345'-6353', 6355'-6358', 6365'-6369', 6374'-6378', 6381'-6387', 6392'-6396', 6512'-6547', 6498'-6508', 6673'-6720', 6762'-6775 Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9085' Packers and SSSV (type and measured depth) Packer: Baker FHL @ 8566 & Baker FB-1 @ 9013; SSSV: Baker FVL @ 1815' 13. Stimulation or cement squeeze summary Fracture stimulated 'A' sands on 11/23/96. IGINAL Intervals treated (measured) OR 9157'-9224', 9284'-9303' Treatment description including volumes used and final pressure Pumped 167.5 Mlbs of 20/40, 12/18 & 10/14 ceramic proppant into form., fp = 70~0 psi. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 304 270 34 880 273 Subsequent to operation 390 88 150 892 306 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X__ Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. ~____--~¢~~~ Title WellsSu pe ri nten de nt 17. Signed Form 10~04 Rev~0~/15~ / Service SUBMIT IN DUPLICATE ARCO Alaska, Inc. Post Office BOx ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 6, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. . .WELL ACTION ¥)"~' ~ 1H-10 Stimulate i .~- ~ 1 H- 14 Perforate q ~_- ~i_~ 1H-20 Perforate ~L[--Z~ 1Q-04 Stimulate ~5-~ 1Y-24 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR050696 (w/o atch) RECEIVED ~i~,ska 0ii & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X__ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1227' FNL, 1057' FEL, Sec 26, T12N, RgE, UM~//',~ --__.- ..,%.~ At top of productive interval -' 1313' FSL, 1480' FEL, Sec 24, T12N, RgE, UM / At effective depth 1593' FSL, 1069' FEL, Sec 24, T12N, R9E, UM ,. At total depth 1636' FSL, 1000' FEL, Sec 24, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9535 feet 6935 feet 6. Datum elevation (DF or KB) Effective depth: measured 9 4 2 3 true vertical 6858 feet feet RKB 9O Casing Length Size Structural Conductor 1 0 3' 1 6" Surface 4 5 8 0' 9.62 5" Intermediate Production 9465' 7" Liner Perforation depth: measured 8709'-8719', 8722'-8726', 8735'-8740', 8747'-8753', 9284'-9303' true vertical 6345'-6353', 6355'-6358', 6365'-6369', 6374'-6378', 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-04 9. Permit number/approval number 84-234 10. APl number 50-029-21250 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None feet Cemented Measured depth RECEIVED 11 1994 /~laska 011 & Gas Cons. Commi~ Anch0rag.~ True vertical depm 240SXCSII 103' 103' 1100 Sx CS III & 4622' 3570' 500 Sx CS I 60 Sx CS I & 9511' 6920' 480 Sx Class G 8756'-8764', 8771'-8777', 8834'-8881', 6381'-6387', 6392'-6396', 6512'-6547', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9085' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 8566 & Baker FB-1 @ 9013; SSSV: 8914'-8928', 9157'-9224', 6498'-6508', 6673'-6720', 6762'-6775 Baker FVL @ 1815' 13. Stimulation or cement squeeze summary Fractured 'C' sands on 3/27/94. Intervals treated (measured) 8709'-8719', 8722'-8726', 8735'-8740', 8747'-8753', 8756'-8764', 8771'-8777', 8834'-8881', 8914'-8928' Treatment description including volumes used and final pressure Pumped 87.5 Mlbs of 16/20 & 12/18 ceramic proppant into formation, ftrp was 6024 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 105 70 0 930 226 Subsequent to operation 167 20 251 700 248 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 he,~~iat the foregoing is true and correct to the best of my knowledge. Signed V vv." ' /~ " ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ;ion K__I~RUK STIMULATION SUMI~-..Y. WELL: la-O~ ¢ $~ DA~: SERVICE CO: ~~ s~m~~ ARCO REPS: HOLE ANGLE ~ PERFS: ~1' AFE ~: PERFORATED INTERVAL: ~"7oq- ~'/I 9 ~r'r~,- s-r'r7 ") a~ 3 s' - 67,fo I~I ~q - 6'/5~ - FRICTION CORRELATIONS: (PSI/Fr' vs. BPM) ORIENTATION RATE XLGW COMMENTS/OTHER GW SLK WTR SLK DSL D.I~' D. IL~ O. I I~, TVDTOP PERF; ~,,3q~ . MDTOP PERF; ~7c,~ MD TBG TAi: 0'709 MDTBG~: 33' .. ~,63 PRE-TREATMENT CALCULATIONS · EXPECTED TREATING PRESSURE = (FORM FRAC GRAD X ~TOP PER~ + ~G FRIC X MD ~G TAIL) - (~UID~X~T~ P~= . FLUSH VOLUME = (MD ~G TAIL - MD TBG HGR) X ( L~ + (MD TOP PERF- MD ~G TAIL) PRESSURE ANALYSIS ACTUAL FRAC GRADIENT = ISIP / WD TOP PERF + FRAC ~UID GRADIE ~CESS FRICTION = ~TP - ISiP - ~BG FRIC X STEP ~ RATE FWHTP ISIP FG XSFRIC CLOSURE PRESS/-r' EFF. · ~ ~'~ ~ ~9~ .~vs o. ot eeo ~.~/~.?1 a~.(~,.~ EFFECTIVE PAD: PROP PUMPED: TREATMENT SUMMARY TOTAL JOB: t~/1.5 PAD/TOTAL JOB RATIO: / ~:) EFFECTIVE SLURRY.' &~l. -~ PAD/SLURRY RATIO: 16/20 '7~5 ~:~; 12/18 ~ ~'0~ 1()'14. PPA @ PERFS:. /~' ~ PROP IN WELLBORE: SEA WATER USED: //~ / DIESEL USED: / 7 ADDmVES USED; RECEIVED · ---- TOTA_ I1'~. ~' MAY 11 1994 ~,i,~ka UlI & Oas Cons. Commissio~ Anchorage ARCO Alaska, Inc. ~------ Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ~5-c~ 1H-01 flS-:~ct 1H-09 ~...~) 11-'J-10 '1'~..-'5~, 1 H- 11 ~ z-.-t'~o 1H-17 8~- Z~l10-04 Q-04 8,5- t~t 1Y-03 ~5-~t~1Y-04 ACTION Perforate Stimulate Stimulate Perforate Stimulate Stimulate Stimulate Stimulate Perforate Other (conversion) Other (conversion) If you have any questions, please call me at 263-4241. · Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering · RECEIVED NOV 1 2 199; Alask~ ~l & 8as Cons. C~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO AIsska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 1227' FNL, 1057' FEL, Sec 26, T12N, R9E, UM At top of productive interval 1313' FSL, 1480' FEL, Sec 24, T12N, R9E, UM At effective depth 1593' FSL, 1069' FEL, Sec 24, T12N, R9E, UM At total depth 1636' FSL, 1000' FEL~ Sec 24, T12Nr R9E, UM 12. Present well condition summary Total Depth: measured 9 5 3 5 feet true vertical 6935 feet 6. Datum elevation (DF or KB) F{KB 90 f~et ~ 7. Unit or Property name Kuparuk River Unit ~ 8. Well number 1 Q-04 9. Permit number/approval number 84-234 10. APl number 5 o-029-21250 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 9423 feet true vertical 6858 feet Junk (measured) None Casing Length Size Cemented Measured depth Structural Conductor 1 0 3' 1 6" 240 SX CS II 1 0 3' surface 4580' 9-5/8" 1100 SX CS III & 4622' Intermediate 500 SX CS I Production 94 65' 7" 60 SX CS I & 9 51 1 ' Liner 480 SX Class G Perforation depth: measured 8709'-8719', 8722'-8726', 8735'-8740', 8747'-8753', 8756'-8764', 8771'-8777', 9284'-9303' true vertical 6345'-6353', 6355'-6358', 6365'-6369', 6374'-6378', 6381'-6387', 6762'-6775' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9085' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 9013' & Baker FHL @ 8566'; SSSV: Baker FVL @ 1815' 13. Stimulation or cement squeeze summary Fractured "A" Sand on 10/14/93. True vertical depth 103' 3570' 692O' 8834'-8881' 8914'-8928°, 14. 6392'-6396', 6512'-6547', 6498'-6508', 9157'-9224', 6673'-6720', RECEIVED NOV 1 2 199 Intervals treated (measured) A~3Sk,8 Uti & ~15 Cori~i, ~ 9157'-9224', g284'-9303' Treatment description including volumes used and final pressure Pumped 85.1 Mlbs of 16/20 and 12/18 ceramic proppant into formation~ final pressure was 6400 psi. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1470 180 Subsequent to operation 514 483 0 1320 229 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X C~__~ Suspended Service 17. I hereby certify that the~foregoing is true and correct to the best of my knowledge. Signed ~J~~'~ ,' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date /~' '-~'~ 5 SUBMIT IN DUPLICA ~ b ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL lQ-4 DATE 10/14/9 3 DAY 1 TIME 0630 0900 1000 1005 1005 DESCRIPTION OF woRK Hydraulic refracture CONTRACTOR / KEY' PERSON DOWELL / Gallegos PBTD (RKB) [LAST TAG (RKB). DATE 942Y [ 9294'- 10/4/93 1035 1055 1125 1135 LOG ENTRY . . ~, ,., KUPARUK RIVER UNIT KUPARUK PETROLEUM ENG,IIEEr,.ING WELL SERVICE REPORT ',.~ .%: ;:.~ ~;~'.,~ .~ ~ :':'.:'~.'.' ..~ :.;: ... ,, .... , :'-'.!~-' ~-' ./.,,,:..~ 5,~ ~:~ '- .t~;0~'-':'¢: AFC/~C# - SCA# IFIELD COST EST. ACCUMULATED COST [ $142,026 $!42,02,6 [SSSV TYPE / STATUS .- iBAKER FVL - In service ., MIRU Dowell frac equipment and VECO DoWnhole pump. VECO Vac Trk Std by Held Safety Meeting! QC fluids & sand. PT lines to 8300g. Set trips @ 7500g-SI WHP 960g, 7" csg. 2623#, 10" csg. Start pumping operations. RATEI PRESSURE PUMP -IN #1 SLK WTR 25 bpm ] 6100 VOL. 150 TEMP. 82 7" CSG. 3365 PUMP-IN g2 SLK WTR ISIP 2765 2820 5540 45 82 3434 PUMP-IN #3 SLK WTR 25bpmI 5534 45 [ 82 I 3370 ] 2838 DATAFRAC DELAY-XL GW 25 bpm [ 6519 310 ] 84 } 3475 ] BREAKDOWN FLUSH 25bpm} 5544 [ 79 84 ] 3443 ] 2966 SHUTDOWN FOR 1 HOUR-MONITOR PRESS-RESET TRIPS ! 1300 PUMP FRAC TIMFJSTG pad 20/19 19/18 275 I 5aoo/ 7" CSG. 3466 3479 3484 3452 . 3452 3425 -. 3365 82 82 82 PROP. 16~20 16X20 72 12\18 72 72 72 12\18 12\18 12\18 FLUID Delay-XL GV~ Delay-XL GV~ Delay-XL GW Delay-XL GW Delay-XL GV~ Delay-XL GW 1313/1 ppa 1,315/.2 ppa 1321/4 pp~ 1325/,6 ppa ! 330/8 ppa 1337/10 ppa Delay-XL GW 10" CSG. 1200 ,, 120g [XICHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK IXI COMPLETE} [ INCOMPLETE Weather ]Temp. IChili Factor ]Visibility ' iWind Vel. ISigned '_ ' ' ,[ [ [ miles[ mph]-~/9~ ~, , REMARKS CONTINUED: 1344 SCREENED OUT-Ill BBLS INTO 10g STAGE-PRESS JUMPED FROM 5800g->6400~ SUMMARY SCREENED OUT IN 10g STAGE W/111 BBLS PUMPED. TOTAL OF 108,017 # PROPPANT PUMPED -85,054g(14,7(X)g 16/20; 70,354g 12/18) BEHIND PIPE-22,963# 12/18 LEFT IN WELL NOTE: LOST 1/2 OF UPPER/LOWER SEAL CUPS OF TREE SAVER WHEN REMOVEDI DOWELL SERVICE COMPANY DAILY $137,986 ACCUM. TOTAL $137,986 VECO PUMP & VAC TRUCK $2,200 $2,200 PEAK TRUCKING $1,000 $1,000 Diesel (200 BBLS) n ~ r~ "~ NOV 1 2. ~o /~aska Oit & Gas Cons. Cemmis~o~ A,iol-.;mgo Si $840 $142,026 TOTAL FIELD ESTIMATE $142,026 " STATE OF ALASKA AL,...,,~, OIL AND G/~ CONSERVATION COMM~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate ~ Plugging ~ Perforate X Repair well Other_ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service __ 4. Location of well at surface 1227' FNL, 1057' FEL, Sec 26, T12N, R9E, UM At top of productive interval 1313' FSL, 1480' FEL, Sec 24, T12N, R9E, UM At effective depth 1593' FSL, 1069' FEL, Sec 24, T12N, R9E, UM At total depth 1636' FSL~ 1000' FEL~ Sec 24, T12N, R9E~ UM 12. Present well condition summary Total Depth: measured 9535 feet true vertical 6 9 3 5 feet feet RKB 90 7. Unit or Property name Kuparuk River Unit 8. Well number 1 Q-04 9. Permit number/approval number 84-234 10. APl number 5o-029-21250 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) Norle Effective depth: measured 9 4 2 3 feet true vertical 6858 feet Junk (measured) None Casing Length Size Cemented Measured depth Structural Conductor 1 03' 1 6" 240 SX CS II 1 0 3' Surface 4580' 9-5/8" 1100 SX CS III & 4622' Intermediate 500 SX CS I Production 9 4 6 5' 7" 60 SX CS I & 9 51 1 ' Liner 480 SX Class G Perforation depth: measured 8709'-8719', 8722'-8726', 8735'-8740', 8747'-8753', 8756'-8764', 9284'-9303' true vertical 6345'-6353', 6355'-6358', 6365'-6369', 6374'-6378', 6381'-6387', 6762'-6775' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9085' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 9013' & Baker FHL @ 8566'; SSSV: Baker FVL @ 1815' 13. Stimulation or cement squeeze summary Reperforated "A" Sands on 10/3/93. 14. True vertical depth 103' 3570' 6920' 8771'-8777', 8834'-8881' 8914'-8928', 9157'-9224', 6392'-6396', 6512'-6547', 6498'-6508', 6673'-6720', RECEIVED NOV 12 199 Intervals treated (measured) 9157'-9182', 9284'-9292' Treatment description including volumes used and final pressure Anchorage Perf density was 4 spf, 180° phasing, oriented 27° from the Iow side of the hole. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1470 180 Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 514 483 0 1320 229 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby ertify that the foregoing is true and correct to the best of my knowledge. Signed ~~~,~~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date //"'?'"' q'"'~ SUBMIT IN DUPLICATE ARCO Alaska, Inc.' Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS. T?: 1:Zoo PBDT Sc~'. ~0Z23 FIELD-DISTRICT-STATE IDAYS IDATE OPERATION AT REPORT TIME cc' [3OD51OO~ C~. KUPARUK Pl:l HULL. UtVl [J~L,~IPiLI-' o6~o o'/15 013o oqz$ 0~5o /o45' [--} CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather.,~nnd ITM ...... I Chill Fee,or I ¥1$,bilit¥ '1 Wind ¥~1. A~aSka Ijtl & Gas dons. JSigned ARCO Alaska. Inc. Post Office Box 100360 A~cnorag¢. AiasKa 99510-0360 Telephone 907 276 1215 August 18, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - lQ Pad (Wells 1-8) . · ',9, . . . o. Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, ;] Gruber Associate Engineer JG/dmr GRU1/31 Enclosure An~c,"ape PHASE :!: AS-BUILT WELLS I Thru 8 PHASE TT AS-BUILT WELLS 9 Thru 16 (NSK g.05.117dZ ) NO SCALE LOCATED IN PROTRACTED SECTION 2_6 TOWNSHIP IZN, RANGE 9E, UMIAT MER. J NOTE: BASIS OF POSITION IS MONUMENTATiON 19'l~fC~{~' AND IS-2 PER LHD ~ ASSOCIATES WELL t X 528,389~.2 Pod Elov. 52.9 I ,254' FEL WELL 2 Y: 5,984,66'7.24 X= 528,448.$5 Pad Elev. 5?-.6 I, 175' FEL WELL ::5 Y' 5,984,656.79 X-' 528,507.45 F~d Elev. 57..$ !,i 16 FEL WELL 4 Y = 5,984,646.54 3( = 5?-8,566.46 I~d EIov. 52.8 1,057' FEL WELL 5 Y= 5,984,?.91.85 X= 528,503~95 P~d Elev. 53.9 ! 1,17.1 FEL WELL co y= 5,984,30z.?.2 X= 57-8,444.1~, Pod Elev. 53.9 I, 180' FF.L WELL 7 Y= 5,984,3~?..65 X = 52:8,385.78 Pad Elev. 53.8 i ,239' FEL WELL 8 Y=5,984,37.3. X= 528,326,70 Pod Elev. 53.9 I ,298' FEL L~t. 7007.Z'O~.Z057" LOaG. 149046'0¢~484' O.G. Riel. 48. Z ! ,I 95' FNL Lot. 70°22'D9.1014" Long. 149046'07.756" O.G. Elev. 47.9 1,206' FNL Lat. 700?-2'08.9963" Long. 149°46'06,028'' O.G. Elev. 47.7 1,216' FNL Lot. 70°?.2:'08.8913' Long. J 49046'04.:505'' O.G. Elev. 47.5 I,?_27' FNL Let. 70o2?.'05.4070" Long. 149°46'06.171" O.G. Elev. 48.8 1,581' FNL Lot. 70°22'05.5' ;2" Long. 149046'07.899" O.G. Elev. 49.?. 1,571' FNL Lot. 70°22'05.6160" Long. 149046'09.625'` O.G. Elev. 1,560' FNL Lot. 70°27-'05.7211'' Long. 149°,~6'11.35Z" O.G. Eiev, 49.8 I ,549' FNL ARCO Alosko, North DmlLL SITE CONDUCTOR AS- LOCATIONS OCt. l I, I~B,c.. Scoie: By' AS S~OWN Dwi. No. ,RISK .~.3.~ II?d I ; Slope Drii!in~ i , · , IQ BUILT I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AN[:) THAT THI~ PLAT RE~RESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCTOBER 15, 1984. ARCO Alaska, Inc. -...' Post Office B. '"'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/f G3-18-85 Run #1 4570.0-9471.0 ref# ' 70997 -£~[L .~ 44f ~fe~ ~2H-9// 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 ~2H-12 /, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7x/ 03-19-85 Run #1 3594.5-8179.5 ref# 70953"~¢d/~p~, "~2v-16// 06-03-85 Run #1 2973.0-7168.0 ref# 70952'F~d~p 3A-10~! 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11~, 11-16-85 Run #1 3208.0-7330.0 ref# 70989 3A-12~y 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13-''/ 12-01-85 Run #1 1800.0-7597.0 ref# 71047 ~3A-14~/ 12-09-85 Run #1 0144.5-7818.0 ref# 71073 3C-9/, 07-10-85 Ru~ #1 3920.0-8332.5 ref# 70996-r~_~ow4~p 3F-8 ~! 11-09-85 Run #1&2 0115.0-7040.0 ref# ~Q994 _,~3F-9./~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 3F-10~' 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11 ~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 ~03J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 3J-10~z 12-08-85 Run #1 0096.5-7348.5 ref# 71074 Receipt Acknowledged: 'STATE OF A~S~* ARCh Al~tkm Inc ,~ ~ ~ubsidiarv ol AtlmnlicRichheldComDanv Date: ARCO Alaska, inc. Post Office ,~.,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DA'x'E: 09-19-85 TR/~SMITTAL NO: 5360 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND HEREWITH A~iE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF '£~IS TRANSMITTAL. SCHL/ CBL'S 04-26-85 RUN #2 7600-8842 04-26-85 FJ3N ~1 5500-801~ 04-16-85 kUN #1 6095-9046 03-02-85 RUN ~1 3650-6690 04-21-~5 kUN ~1 5595-7888 04-21-85 i~UN ~1 5~95-7383 04-25-85 RUN #1 5900-7818 04-25-85 Ri3N #1 7500-9123 FINAL PRINTS/ 1Q_I~/ 1Q-2~ -~ x/'iQ-4 / '"2U-3 v/. ~2V-9 ~ -~2V-10J 2V-12 / RECEIPT ACKNOWLEDGED: SPAE B. CURRIER CHEVRON D & M DIbTtiTBUT1ON: DRILLING*bL W. PASHER L. JOHNSTON EXXON MOBIL P~ILLIPS 0I~, NSK CLEttK*BL J. KATHMELL DATE: "'.-, ~OhIO /bE UNION K.TULIN/VAULT*FILM ARCO Alaska. Inc. is a Su:~ary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post OffiCe Be,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Q-4 Dear Mr. Chatterton- Enclosed is the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUlO/L84 Enclosures RECEIVED 0 ? 1 1i§ Alaska 0[I & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~.. _ AND GAS CONSERVATION CC -~IISSION W,=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · ;21 Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-234 , , '" 8. APl Number 3. Address P. 0. Box 100360, Anchorage, AK 99510 50- 029-21250. , ,, · 4. Location of welI at surface 9. Unit or Lease Name 1227' FNL, 1057' FEL, $ec.26, T12N, RgE, UN '--[C~(~3:I~N$'' Kuparuk River Unit. · VERIFIED t 10.' Well Number ' At Top Producing Interval 1313' FSL, 1480' FEL, Sec.24, T12N, R9E, UM Surf. ~ __'~ 1Q-4 B.H. ~', 2_-i~ ~1. Field and Pool At Total Depth 1636' FSL, 1000' FEL, Sec. 24, T12N, R9E, UN -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) i 6. Lease Designation and Serial No. Kuparuk Ri vet 0i l Pool 90' RKB} ADL 25634 ALK 2567 12. Date Spudd~'~ '-1-3. Date T.D. Reached 14. Date Conap.. Susp. or Aband. 115. Water De~th, if of'fshore 116. No. of Comple'tions' 03/10/85 03/18/85 03/19/85*I N/A feet MSL J 1 17. Total Depth'lMD+TVD) is. Piu~ Back Depth (MD+TVD) 19. Directional Survey I 20. DepthwhereSSSVset I 21'Thickness°fPermafr°st 9535'MD,6935'TVD 9423'MD,6858'TVD YES I~X NO [] 1815 feet MD 1400' (apprOx) .., , 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/Cal, FDC/CNL, CBL, Gyro ((;CT), CBL . 23. ' .... CASING, LINER AND CEMENTING 'i~ECOR~ sETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD . AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 240 sx CS II. 9-5/8" 36.0# J-55 Surf 4622' 12-1/4,, 1100 sx CS .I. I I & 500 , , , Top job performed w/60 sx .CS " 7" 26.0# '' J-55 ' Surf 9511' 8-1/2" 480 sx Class G , , 24. Perforations open to Production (MD+TVD'(~f Top and Bottom and 25. .~ TUBING. REcoRD. interval, size and number) ~IZE.. DEPTH SET (MD! PACKEF{. SET. (MD) 3-1/2" 9085' ., 8566' & 9013' 9303' - 9285' 9224' - 9157' w/4 spf, 120° phasing 26. ' 'ACID, FRACTURE, CEMENT SQUEEZE, E'TC. 8914'-8928' 8753'-8742' DEPTH INTERVAL (MD) AMouNT & KIND OF MATERIAL U. SED . .. . 8881'-8834' 8740'-8735' w/12 spf, 120~ phasing N/A . . 8777 ' -8771 ' 8726'-8722' .. -- 8764'-8756' 8719'-8709' - ,. , . 27. N/A PRODUCTION TEST · . Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Test'ed pRoDUCTION'FoR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE { GAS-OIL RATIO TEST PERIOD I ~iow Tubir;g Casing Pressur; CALCULATED OIL-BBL GAS-MCF WATER-BBL OI'L GRAVItY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA .... Brief description of lithology, porositV, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG 0 ? Alaska Oil & Gas C0~s, C0mmissi0~ Anchorage - . , . , , · Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and well perforated 4/25/85. CONTINUED ON REVERSE SIDE TEMP/WC55 Submit in duplicate . . . . . 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 8708'~.: 6345' N/A ' Base UPper Sand 8878' 6471' Top Lower Sand ..... 9136' : 6658' : ' . .' ' · ' Base Lower Sand 9304' 6675' . . .~ , : J .~ · .. ~ . . . . . . . · 31. LIST OFATTACHMENTS ~.. . . Gyroscopic Survey (2 copies) ,: - 32. I hereby certify that the fore§oing is :true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal,, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well-is completed for separate production from more than one interval (multiple completion), so state in item i6, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". [:nrrn I h.z~¢17 ALASKA OIL AND 6A$ GONSERI/ATION.GOMMI$SION : :3ool PORCUPINE DRIVE ' "AHCHOflAGE,ALAgKA 99501.1-3lg2 TELEP. HONE(g07) 210,--i433 - DATE: ~ TO: ' ' RE: Well ~ - o brin to your attention that the ~omission has We wish ~ - .-g ~ .~--- ..... uired items on the subject, well Y ........ ~ ~ndicated was completed ~~/?-~~ W~IC~ our ~~ ~ - / .. Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days · after completion of a drilled.well. Please submit the above missing material. · C. V. Chatter! Chairman lc:C.024 ARCO / ka, !nc. Post Office P, ox 10C. 350 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE' 06-2 4-85 TRANSMITTAL NO' 5227 RETURN TO- ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BO:< 100360 ANC!IOIIACE, AK 99510 ~ ?,Sd~SMITT'~D HE~r~dIT RECEIPT AND RETURN ONE SIGNED KUPARUK WELL PRESSU lB-3 x. 04-21-85 iC-4.,, 04-25-35 !!!-3 ~, 03-06=85 iQ-i-. 05-26-U5 !Q-2-- 05 -26 -85 1Q-3'~ 05-18-85 lQ-4-, 05-14-85 1Q-5x 06-06-85 1Q-6.~ 04-23-85 lO-7 ~ 0 ~,-~ 7-85 iQ-S--, 04-03-85 2A-2x, 05-27-85 2A-4 ,, 05 -11-85 2C-5~ 04-23-85 2C-9 '- 04-06-$5 2C-!0x, 04-40-$5 2C-1i,~ 03-29-85 2C-i2x 03-2~o-,.5° 2C-14,,. 04 -23-'-,35 2G-l'- 04-29-85 2!,:-1 x 05-22-85 _ - ~7-85 2H- ~ '- 0 ~-_ 2![-2'- 05-23-85 21I-3-, 05-23-85 2!!-4 x 05-23-85 2V-9-- 05-18-85 2V-!0,~ 05 -17-85 2V-11 '- 05-12-85 2X-2 -- 06-16-85 2X-2 -. 06-14-85 '~X-5- 06-! 2-$ 5 2Z-6' 04-08-85 '"-7_,~ - 0 -i-°. 3 -8 5 ] Z-0--.. 04-01-85 {ECEIP'£ ACKNOWLNDCE COPY OF THIS RE REPORT ENVELOPE DATA PBU BOTH SD. CAMCO S~!IP BOT[t SD. CAMCO PBU BOT[I SD. CAMCO SBHP 'A' SD. CAMCO SBHP 'A' SD. CAMCO SBHP 'A' SD. CAMCO SD!iP BOTH SD. CAMCO lI ARE TIiE FOLLOWING IT"EMS. PLEASE ACKNOWLEDGE TRANSMITTAL. ul S~UT iON- -- C,R'r" ~- -~, ot~ cr-:~,"R 1,. Jrj[~NS'FON · 'Y'.O3 1 [, P~i_.~L r r~S OiL* '' r t?r~.- TD. %mtT',' " * Al~ka CJI & u '-' . .... ., ........ DATE - STATE O? ALASKA* .-' U N!ON * K. T"~I; /VA'''-u~' SB[IP 'C' SD. CAMCO SEi!P CAMCO c~-.'~D 'A' SD CAMCO SBHP 'A' SD. CAMCO {-19 r-D ~/-, .~ ~,~. ~. SD, OTIS SBI!P 'A' SD. CAb!CO °~U 'A: SD BAKER NORm~ SLOPE SDi!P 'A' SD. OTIS cn,tp DOTI! SD OTIS cn,~ ' ' . OT ..... A SD iS onP C SD. OTIS PDU 'A' SD. OTIS & BAKER FOIiP 'A' SD. CAMCO ovvv ovvooooo CAMCO o~,:. A SD. O~S ?wv vvv:,~:oov CAMCO SD"",,. '.A' SD. OTIS SD~[P 'A' SD. OTIS S2iiP 'A' SD. OTIS SBi!P 'A' SD. OTIS SB~ '~ ' CD OTIS SBIiP OTIS SBi]P bOTf! SD. OTIS %Blip DOTal SD. OTIS S~''' BO'"~ °D OTIS S3iiP ???? PBU DOTi! SD. BAKER NOTH SLOPE S:3[IP O0TiI SO. OTIS D- tLET URN TO: ARCO Alaska, Inc. Oost Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF PRESSURE, FLUID, AND ACiD lB-1 SBHP lB-2 SBHP - lB-4 SBHP lB-4 PRE-WORKOVER ID-8 SBHP IE-1A TUBING LEAK 1E-5 COMP PBU ETC. !E-11 LEUTERT Bit SMPL 1E-23 SBHP 1E-23 SBHP 1E-27 TEMP/SPIN-LEAK 1E-27 TUBING LEAK 1G-6 PRESSURE FALL- OFF !H-6 SBHP 1L-5 PBU W/E-LiNE 1L-5 PBU lQ-1 ISIP · !Q-! SBHP 'A'SDS lQ-3 TAG FILL BHP lQ-4 SBHP 'C' SD ETC iQ-4 SBHP ETC lQ-4 ACiD JOB lQ-5 ISIP TEST lQ-7 ACID JOB !Q-9 'C' SD PBU lQ-9 PBU 'C'SD ETC 1Y-I2 FALL-OFF TEST 2A-2 BHP 2A-4 'A 'SD BHP 2A-4 'A 'SD BHP 2A-4 'A'SD BHP 2A-5 SBHP 05-0 5- ***CONTINUED ON THE FOLLOWING RECEIPT ACKNOWLEDGED: HERE%4ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. EVENTS FROM WELL SERVICE REPORTS (ONE COPY OF EACH) DATA 05-3 0-85 CAMCO 05-30-85 CAMCO 05-16- 8 5 CAMCO 05 -24-85 CAMCO 04-2 9-85 CAMCO 05 -03 -85 CAMCO 04-28-8 5 CAMCO 06 -02-85 OTIS 05-22-85 CAMCO 05-23-85 CAMCO 05-0 3-8 5 CAMCO 05-04-85 CAMCO 05-0 7-8 5 CAMCO BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON * :,lOB IL * D & M-F NS~ CLERK 04-29-85 CAMCO 04 -27-85 CAMCO 04-2 9-85 CAMCO 05-30-85 B.J.HUGHES 05-2 6-8 5 CAMCO 05-18-85 CAMCO 05-10-8 5 CAMCO 05-14-85 CAMCO 05-17-85 NOWSCO/B . J. HUGHES 04-29-85 B.J. HUGHES 05-26-8 5 NOWSCO/DOWELL 05-12-85 CAMCO 05-13-8 5 CAMCO 05-05-85 CAMCO 05-27-85 OTIS 05-10-85 CAMCO 05-0 9-8 5 CAMCO 05-11-85 CAMCO 8 5 CAMCO PAGE ** * O ISTi{iB 0T'IOIq: W. PASHER EXXON PUILLIPS OIL* J. EATHMELL4~ DATE: ~'STATE OF ALASI<A.~'' SOHIO* K. TULIN/VAULT ARCO :ska, Inc. ,-dst Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. ?;UPARUK OPERATIONS RE~-OkuS CLERK ATO-! ! 15B P.O. BOX 100360 ANC:iORAGE, AK 99510 DATE- 06-27-85 TRANSMITTAL NO: 5235 ENGINEERING -~A,,SMI~T~D HER-D..~IT[[ ARE THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HoLE LIS TAPES PLUS LISTING (ONE COpY OF SCiILUMBERGER PLEASE ACKNOFTL p. D~-- EACH ) ;3C-12,~ 06-16-85 RUN #! 3756. 0-7598.0 REF !~70547 , 3B-8~ 06-02-85 RUN ~1 3925.5-8516.0 REF !.~70495 · 3B-7% 05-24-85 RUN #i 3268.0-7310 5 REF #70468 '-~-]-9% 06-10--85 RUN ~! 3988.0-8415.0 REF #70526 '3B-5-..~ -05-12-85 nUN #1 3447.5-8148 0 " .2Z-16~ 06-08 85 o - !t · REP 70417 ~,UN 1 4062.5-8163.5 REF #70525 '2V-16~ 06-03-~5 RUN ~,! 2973.0-7168. 0 REF ~70496 '2V-15---.. 05-24-,85 RUN #2 2873.0-6544.5 REF #70470 · 2V-14 ~ 05-16-85 RUN #1 3047.0-7086.5 REF ~70426 '2V-13 --~ 05-07-85 RUN #1 3536.5-8710.5 REF ~70409 'lR-8~ ;06-14-85 RUN #1 4040.5-8576.5 REF i~70546 'iR-6---_. 05-14-85 RUN ~ 5- ~.~ 4623. 9332 5 REF '~ ' 1¢>-15~ 05_1 ~_85 , .... . ~ -' .~oN ~ - '~70422 .-~ 4390.5-8730.0 REP #70415 · iQ-14-...~ 05-2!-~5 RUN #1 4371.0-9027.5 REF #70447 o..,~_~ OF ALASKA SOil_TO U'.'~ION !'(. TULrN/'.z~ ':~ ~ · ~iQ-13 · l(j-4 ~ 05-30-$5 RUN #1 3679.0-7772.5 REF ,~70482 ~ 03-18-85 RUN #1 4570.0-9471.0 REF #70506 *REVISED* _ ' -ECEiPT ACXNow!,EDCS D- STATE OF ALASKA '~-'" ALASKA L~L AND GAS CONSERVATION CO~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84- 234 3. Address 8. APl Number 029--21250 P. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION: 1227' FNL, 1057' FEL, SEC. 26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 89.7 ' 6. Lease Designation and Serial No. ADL 25634, ALK 2567 10. Well Number lQ-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 17, 1985, the"C' sands of Kuparuk well lQ-4 were acidized to improve production. The treatment consisted of 45 BBLS of 12% HCL. Diesel was used for flushing and nitrogen to aid well cleanup. Prior to starting job, equipment was pressure tested to 4000 ppsi. RECEIVED JUN 2 6 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Title KUPARUK 6 / 18 / 8 5 Date .(~ OPERATIONS COORDINATOR ,2~-//b f Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Inc./--``, Post Office ,_. x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 ~qr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Corr~ission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in following wells duplicate are subsequent notices at the Kuparuk River Field. Well Action Date Performed 1A-3 Fracture 1A-q Fracture 1C-5 Perforate 1E-3 Perforate 1E-3 Fracture 1E-4 Perforate 1E-4 Fracture 1E-16 Fracture 1E-17 Fracture 1E-29 Fracture 1F-1 6 Perforate 1F-16 Fracture 1G-1 Fracture 1L-15 Fracture 1 L-1 6 Fracture 1Q-1 Fracture 1Q-4 Acidize 1Q-4 Fracture 1Q-5 Fracture 1Q-6 Fracture 1Q-7 Fracture 1Q-7 Acidize 2C-1 0 Perforate 2D-3 Acidize 2W-13 Acidize 2X-1 2 Ac i d i ze 5/30/85 6/1/85 4/27/85 3/28/85 4/3/85 4/20/85 5/7/85 4/14/85 3/26/85 4/12/85 4/11/85 4/15/85 4/1/85 3/31/85 3/31/85 5/31/85 5/17/85 5/31/85 5/1/85 4/19/85 4/27/85 5/26/85 4/21/85 5/11185 5/20/85 5/12/85 on the if you have any questionS, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-421 2. RECEIVED Alaska Oil & Ua$ Cons. Conlrllissiorl Ar~chorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~--': ALASKA UIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCATION: 1227 ' T12N, R9E, UM FNL, 1057' FEL, SEC. 26, 5. Elevation in feet (indicate KB, DF, etc.) 89.7' (RKB) I6. Lease Designation and Serial No. ADL 25634, ALK 2567 7. Permit No. 84-234 8. APl Number 50- 029-21250 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number lQ-4 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. 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 [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 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 May 31, 1985, the "A" sands of Kuparuk well lQ-4 were hydraulically fractured and propped to improve production. The treatment consisted of 372 BBLS of gelled diesel as pad and carrying fluid and 16,600 LBS of 100 mesh and 20/40 sand as proppant. 84 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. RECEIVED JUN 2 5 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ~./F~ ~ Title OPERATIONS COORDINATOR The space below for Commission use 6/18/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,~RCO Alaska, Inc. Post Office Bt .30360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 3, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' If you 2H-2 2H-13 2H-14 ,, 2H-16 1Q-4 have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L32 Enclosures ECEI vED , JUAIo 4 ]985 Cons. '~nChorage Commission ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany · ~--, STATE OF ALASKA ~ · ALASKA ~L AND GAS CONSERVATION C~ ,MISSION W =LL COMPL__ETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~X GAS [] SUSPENDED [-1 ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-234 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21250 4. Location of well at surface 9. Unit or Lease Name 1227' FNL, 1057' FEL, Sec.26, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 1Q-4 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 89.7' RKB ADL 25634 ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 03/10/85 03/18/85 03/19/85*I N/A feet MSLI 1 17. Total Depth (M D+TVD) 9535 ' MD 18. Plug Back Depth (MD+TVD)19. Directional Survey 9423' MD YES [] NO I-~X I20' Depth where sssv set1815 feet MD } 21. Thickness of Permafrost1400, (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal, FDC/CNL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 240 sx CS I I 9-5/8" 36.0# J-55 Surf 4622' 12-1/4" 1100 sx CS Ill & 500 s: CS I & Top job performed w/60 sx CS I 7" 26.0# J-55 Surf 9511' 8-1/2" 480 sx Class G 24. Perforations open to Production (MD+TVD of Top and BOttOm and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9303' - 9285' 3-1/2" 9085' 8566' & 9013' 9224' - 9157' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8914'-8928' 8753'-8742' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8881'-8834' 8740'-8735' w/12 spf, 120° phasing N/A 8777'-8771 ' 8726'-8722' 8764'-8756' 8719' -8709' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED I1~ 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. None ,o~,, 0il & GaS Cons. Form 10~,07 Rev. 7-1-80 * NOTE: Tubing was run and well perforated 4/25/85. CONTINUED ON REVERSE SIDE TEMP/WC21 Submit in duplicate 29: .':;..? '-'-._. :~' :-'.-."i. ~_ ;:. GEOLOGfC MARKERS. 5~::~ :;' ? ..?:::~...~.,;::::~-~t:+i.'}~;,?~::.4':. '*~'~ -,." 'L,:. ,.- ~;..~,-;'.'"::,.""~."[:;:'FoRi~/iATi~)N::_F,E~t: ~ ~ :::~ ~ ~ ;~, --'% .~ :;.i~:'"' :: .!~ ;~?,; :;'', ,. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH. ,.GOR., an.d-time of each phase. .. · · ; · ..)~-~,.: _::. . ,.. · ~.._ !. ...:. . . ~ ~.: :T .- , '. : '.' · . .-. : . . ' : '] : 'i ' ' '.- - : - · ; ' " " . . , . · - ... · . : . ;,:: .. . . 31. LIST OF ATTACHMENTS ! .. ' ' · Well History {¢omp]egion details) 32. I hereby certify that.:the fo[,e§oin§ is.true-and correct to the best of my knowledge · Signed {~ ~ ~ Title Associate Engineer Date S'~(~)'~' // INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "initial Rel~3rt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ~ County, parish or borough Alaska' Field Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE 504661 North Slope Borough ADL 25634 IState Alaska IWell no. lQ-4 Complete Nordic 1 AP1 50-029-21250 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O, begun JDate IHour ]Prior status if a W.O. Complete 4/21/85 2030 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 4/18/85 4/21/85 thru 4/22/85 4/23/85 4/24/85 · - . Rn CBL f/9414'-6095' WLM. Rn gyro. 7" @ 9511' 9423' PBTD, PU 3½" tbg 10.0 ppg NaC1/NaBr Accept rig @ 2030 hrs, 4/21/85. w/3½" tbg, tag PBTD @ 9423'. ND tree, NU & tst BOPE. RIH 7" @ 9511.' 9423' PBTD, Perf rn #5 10.0 ppg NaC1/NaBr' POOH. RIH w/4" csg guns, 4 SPF, 120° phasing. 9303'-9285' & 9224'-9164'. Perf 7" @ 9511' 9423' PBTD, Rn'g 3½" CA 10.0 ppg NaC1/NaBr RIH w/4" csg gun, 4 SPF, 120°. Perf f/9157'-9164'. RIH w/5", 12 SPF, 120° phasing. Perf f/8914'-8928', 8881'-8834', 8777'-8771', 8764'-8756', 8753'-8742', 8740'-8735', 8726'-8722', 8719'-8709'. PU pkr & tail pipe assy, RIH, set @ 9004'. The above is correct Signature For form preparation and distributiq~, see Procedures Manual, Section 10; Drilling, Pages 86 and 87. IDate 5/20/85 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an oUicial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit I Well no. Kuparuk River ADL 25634 I lQ-4 Auth. or W.O. no. Title AFE 504661 Complete Nordic 1 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 4/21/85 Date and depth Complete record for each day reported as of 8:00 a.m. 4/24/85 API 50-029-21250 I otal 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. I 2030 hfs Old TD Released rig 7" @ 9511' 9423' PBTD, TT @ 9084', RR Crude/Diesel RIH w/278 jts, 3½", 9.3#, J-55 EUE, 8RD IPC tbg. shear PBR & lnd tbg. Set BPV. ND BOPE, NU &tst tree. well to crude. Tst SSSV. RR @ 0600 hrs, 4/25/85. SSSV @ 181~- Top Pkr @ 856~ - Lower Pkr @ 9013' "D" Nipple @ 905~ - Tailpipe @ 9085' Set top pkr, Displ I New TD PB Depth fl ff ~' 9535' - 9425~ PBTD l Date ~.~~~" Kind of rig hrs. Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential.test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected J JN(~ ~, ],~[i Alaska f)i~ ~ n.o ~ ......... I iTitle s, na,u, _ s/20/ss For form preparation and distribution, eeo Proceduree Manual, Section Drilling, Pages 86 and 87. Drilling Superintendent ri:.:: """" :I · ~.. Lfl "! ARCO 4Li~,K.,!,. INC $ UB-S URFA CE DIRECTIONAL SURVEY ~ UIDANCE r-~ ONTINUOUS i-f'lOOL Company ATLANTIC RICHFIELD COMPANY Well Name lq-4 (1227'FN~L,, 1057'FEL, S26,T12N,R9E, UM3 Field/Location K~~, ~o~ ~,oF~,, ~AS~ Job Reference No. 70343 hoooed By: MCBRIDE Date 24-APRIL- 1985 Computed By: CUDNEY GC? DIRECTiONAl, SURVEY CUSTOMER LISTING FOR ARCO AL, A,SKA, INC, ~0-4 KUPA~UK NORTH RbOPE,AbASKA SURVEY DATEI 17 APR 85 ENGINEER1 ~CRRIDE METHODS OF COMPUTATION TO~[, LOCATION: TANGENT[Ab- averaoed deviation and azimuth ~NTE~POLAT~ON~ LINEAR VERTICAL SE~TTON: HORTZ, DIST, PROJECTED ONTO A TARGET AZ~MI.ITH OF NORTH 63 PEG 5 MZN EAST ~RCO AbASKA, INC. .0-4 :UPARUK IORTrt 5[,OPE,ALASKA TRUE SUB-SEA COURSF :AS[IRED VFRT[CAL VEPTTCAL DEVIA?ION AZIMUTH DEPT. D~PTH DEPTH DEG MIN D~G MTN 0.00 ]00,O0 200.00 300 O0 400' .00 500,00 600.00 7on O0 ~00~00 900,00 0 O0 100 O0 200 O0 300 O0 400 O0 499 99 599 86 699 45 7qB 17 8q5 74 COMPU?ATION DRTEI 25-APR-.5 PAGE DATE OF SURVEYI 17 APR 85 KELLY ~USHTNG EbEVAT~ON{ ENGINEERI MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTTCRb DOGLEG RECTANGUb~R C~ORDINATES HOAX[. DEPARTURE SECTION SEVERITY NORTH/SOUTH ERST/WEST DIST,. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEC ~IN -90.00 0 0 10,00 0 6 110,00 0 13 210,00 0 .16 ~10 O0 0 25 400 99 1 24 500 ~6 3 48 609 45 7 0 N 0 0 E S 57 9 ~ 0,03 $ 76 32 E 0,21 $ 86 9 ~ 0.55 , 75 53 £ t,t2 N 72 59 £ N 76 ~ E 7,07 N 77 19 E 15.64 ~ 70 5~ E 3~,47 N 66 10 g 53,0i 70~ 12 11 22 g05.74 13 26 N 63 0 E 78,06 N 65 31 E 107,32 N 66 46 E 140,06 N 64 26 E 175,61 N 64 5 E 215,38 N 63 20 E 260,45 , 62 43 F ]11,78 N 62 1E 369.56 N 62 24 E 432.05 N 61 31 E 497 iO00 O0 992,54 q02,54 15 39 LIO0~O0 1088,15 998 15 18 22 L600 O0 '54 82 145~ g2 33 ~ L700:00 16~ 40 [~34.40 37 22 L800.O0 17~2.45 1612.45 39 56 L900.O0 1797.70 ~687.?0 42 34 .~000,00 1849 74 1759.74 44 56 1919 14 1{a29 t4 46 55 ln96:90 38 90 47 40 202.q;40 49 15 25 2094 25 49 59 90 2157:00 ~0 4" 96 2~20.06 50 5" N 62 21 E 567,?1 N 62 43 g 639.19 ~ 62 57 g .712,74 n 63 27 F 787 N 63 52. E ta62.,~2 ~ 6464 a- 938 ~ I }100,00 ~200,00 1986 ~]00.00 2053 }400 nO 2119 ~500~00 2184 ~600,00 ~700,00 2310 ~800.00 2373 ~900.00 2437 2503 03 2~3 03 ss9 09 2., :o9 ~635 2703 9770 2837 ~903 2970 48 56 48 25 79 2545 79 47 47 17 2613;i7 47 32 57 2680.57 47 55 51 2747 51 48 11 97 2813:97 48 17 ]9 2~80,39 48 24 Oq 2947,09 48 ~ 50 3n[~.50 48 46 N 66 58 E 1323,41 N 67 43 E 1398.~6 N 60 16 ~ 1472.50 N 69 , E 1546,03 N ?0 59 E 1693 ,10 ~ 71 50 ~ i767,05 N 72 33 ~ 1840,85 N 72 58 E 1q14.26 ~ 73 4 E 1987,91 ]000,00 { oi:°o )20 O0 )]0 ,00 4o :oo 3~0 O0 )600,00 )700.00 3R00.O0 3037 3900,00 3103 0 O0 0 27 0 11 0 1,63 4,74 3,62 2,54 ,5~ O8 1.90 0 92 5~ 0 17 0,88 0.9~ 0,89 0,20 },13 ,96 0,83 1,09 0,82 O,6q 4 90,00 FT 0 O0 N O 07 S 0 S 0 13 S 0 20 N ~ 50 ~ 3,37 N 7,84 N 1,5.78 N 26 85 N 39 67 84 104 127 183 214 0,00 E 0 73 g 32 !~ 7 ~7 E 15 3 E 31 31 g 51 44 E 0,00 N 0 0 E 0,09 S 44 31 E O, S 72 21 g 49 N 8 18 E 33 N 11 [ 16 19 N 59 g 3228 N 75 56 E 53 81 N 72 56 E 73 91E 78 64 N 70 2 g 66 , lO0 22 ~ 107 78 , 6, 24 g 71 N 130 3~ E 140 58 N 67 58 E 34 N 162 76 E 176 14 N 67 31E 77 N 198 57 g 21.5 86 N 66 52 E 61N 238 99 g 260 88 N 66 21 E 312 14 N 6548 E 95 . 284.'71 E 97 N 335.78 ; 369 81 N 65 13 E 78 N 449 g 498, 2 N 64 E 247 59 s 510 42 F 567,30 N 64 7 E 2"0 7' N 574 ~4 E 639,27 N 6S 57 E 381 30 N 73 g 862,59 N 63 45 E 414 63 N 842 18 g 938.71 N 63 47 E 447 63 w 91188 ~ 1015,83 N 63 511 ) 480 l? N 982 35 ~ 1093.42 N 63 57 L 602 58 N 1262 22 E 1398,68 N 64 28 E' 630 59 M 1331 26 g 1473,05 N 64 39 E 6~7 46 M 1400 08 E 1546,77 N 64 50 E 683 16 N 1469 34 E 16~0.39 N 65 3 E 708 04 N 1539 34 E 1694.37 N 65 17 E 731 94 N 1610 14 E 1768,70 N 65 33 g 754 75 N 168! 33 E 1842,96 N 65 49 g ~76 68 N 1752.~; ~ 1916.?? N 66 5 E 98 53 N 1824, E 1991, 7 N 66 21E ,RCO A6A,SKA, INC.. 0-4 ~UPARUK IORTH ,5[,,OPE, AI',,AS. KA COMPU?ATION DATE: 25-APR-85 PAGE DATE*OF SURVEY,I 17 APR 85 KEL6Y RUSHTNG EbEVATZONI ENGTNEERI MCBRIDE INTERPOLATED VALUES FOR EVEH 100 F£ET OF MEA,SURED DEPTH 90.00 FT TRUE SUB-SE~ COURSE ;A,SURED VERTICAL VERT?CRD DEVIATION AZIMUTH DEPTN DEPTH DEPTH DEG M~N DEG [000.O0 ]~.~38 93 3078,03 49 17 i100 00 . 75 314].75 49 55 ~200:00 ]208 21 3208 21 3272i71 3337 13 ~300 O0 33R2 ~40o:00 ]4?7 ~500,00 ]401 ~600 O0 3555 ~700:00 3619 ~800,00 3682 [900.O0 3746 49 43 71 49 54 13 49 47 63 3401. 63 49 54 84 3465:~4 50 4 67 3529i67 ~0 56 7~ 359~ 73 50 44 05 3~56.05 50 42 iO00 O0 3809 44 3719,44 i100:00 3872 96 378~.96 ~200,n0 3936 ~300 O0 4000 ~400~00 4061 ~500.00 4121 ~600 O0 4 oo:oo ~800.00 4309 ~q00,00 43?3 50 40 5O 2O 86 3~46,~6 50 30 05 3elO 05 51 q 67 3971:67 '2 57 73 4031,73 52 27 5~ 409],58 51 3~ 05 4156,05 RO 42 90 4~19,90 50 19 6~ 4~83.61 50 30 ~000,00 4437 00 4]47.00 W0 40 5100,00 4500 04 4410.04 51 3 ~200,00 4562 91 44 . 9,72: 50 48 ~300 00 4626 5~ 4'36 52 ,0 20 5400~00 4690 14 4600.14 50 35 5~00.00 4754 44 4664.44 49 4 5600.O0 4820 25 4730.25 48 q 5700.00 48~7 53 4797.53 47 48 5800,00 4954 5~ 4864.55 ~7 3~ 5900.00 50?4 19 4934.19 44 52 7000.00 5094.94 5004.94 44 5% 7100.00 5165,9R 5075.08 44 29 7~00.00 5237.53 5147.53 44 10 7300.00 5309,5~ 5~19.51 a3 44 7400,00 5381,79 5291.79 43 43 7~00.00 5454,1! 5364.11 43 38 7600.O0 5526.50 5436.~0 43 31 7700.00 ~599.05 5~00.05 43 31 7800.00 5671.50 5581.50 43 42 7900.00 5743.80 5653.~0 43 36 N 73 13 E 2067.36 ~ 73 19 E 2137.31 N 73 32 E 2212.52 N 73 54 ~ 2287,61 ~ 74 10 F 2362,71 N 74 23 E 2437,69 , 74 28 ~ 2~1~.84 N 74 37 £ 258~.~8 N 74 46 ~ 2664,29 N 73 q E 274n.24 ~ 72 ~ g 2816,52 N 68 51E 2893,10 N 67 50 E 2969.68 N 64 12 E 3047.08 N 60 41E 3125,80 N 59 4~ E 3205,65 N 59 27 E 3284.07 W ~8 34 ; 3361.97 M 57 57 £ 3438,64 ~ 57 31 E 3592,38 M 57 36 E 3669,65 N 56 32 E 3747,03 ~ 53 7 E 382~.30 ~ 53 12 E 3R90.79 N 53 R E 3974.73 N 52 44 E 4048.88 M ,2 16 E 41.21.57 W 52 16 ~ 4194.47 ~ 53 27 F 4265.09 N 53 18 E 4334,75 N 53 22 E 4404,10 ~ 53 30 E 4472,98 N 53 32 E 4541.44 ~ 53 23 E 4609.56 ~ 53 19 ~' 4677.65 N 53 16 E 4745.64 ~ ~2 59 ~ 4813,42 ~ 52 52 E 4881.29 N 52 50 E 4940,26 0,10 0.21 0,37 0.22 0,59 0,53 0,40 0,99 0.22 i.42 I 54 I 49 2 41 2 04 2 68 2.07 0.17 2,36 0,35 0.31 0,32 0,2] 3,15 0,70 0.25 0,54 2,55 0,60 2,13 1,27 0,78 0,88 0.77 0.5~ 0 44 0 0] 0 53 0 42 0 35 0 13 820 842 864 15 N 2042 885 58 ~ 2115 906 63 N 21~9 927 36 N 2263 947 92 ~ 2336 968 43 ~ 2411 988 88 ~ 2485 10~0 01, N 2560 ,, 1033 1059 1087 1 18 1t55 1195 1235 1274 131.5 1356 1398 1439 1481 15 1618 1664 1 1~09 54 1797 1840,03 ~ 3927 1882,05 N 3983 1923,67 N 4039 1964,9] ~ a095 2006 06 N 4151 2047 27 ~ 4206 2088 51N 4261 21~9 2171 2213 44 N 1806 41 E 2066 37 N 1969 33 E ~ ! 96 E 2 06 E 2445 09 E 25 96 E 2675 41E 2752 J;N 66 36 E N 66 50 E 89 N 67 4 E 7 E 69 N 67 43 E 3 N 67 55 [ N 69 7 E ) ~ N 68 18 E 42 N 68 28 E 12 ~ 2634.22 E 2829 01N 2706,97 E 2906 1 88 47 E 3 9 7O N 3 44 82 N 3253 66 ~ 3525 57 N 68 35 E 74 N 68 38 E 67 N 68 37 E O? N 68 33 E 37 N 68 24 E 49 N 68 12 E 19 N 67 59 Z 38 N 67 47 Z N 67 34 E 3 N 67 21 E 27 8. g 14 N67 gE 60 N 351~ 78 E 88 w 357:52 E 3754 3830 3905 78 N 3635,81 E 3979 O1 N 3696.00 E 4053 16 N 3754,61 E 4125 61N 3813,29 F 4197 80 N 3870,57 E 4267 76 N 16 N 66 30 E N 66 14 E 90 N 65 59 F 3'2 N 65 45 l 32 ~ 65 31 L 60 N 65 17 E 71 N 65 5 E 24 E 4316,92 N 64 53 E 6R F 4405.89 N 64 ~2 E 80 E 4474,42 N 643.2 E 63 ? 4542,59 N 64 22 E 15 F 4610,46 N 64 12 E 58 E 46~B,31 N 64 2 E 90 E 4746.12 N 63 53 E 82 N 4316 94 ~ 4813,74 N 63 44 E 31 ~ 4371 99 ~ 48~1,4~ N 63 35 E 04 N 4427,03 E 4949,36 N 63 26 E VERTICAb DOGbEG RECTANGUEAR COORDINATES HOR~Z., DEPARTURE SECTION SEVERITY NORTH/,50UTH EIST/WEST DIST, FEET DEC/lO0 FEET WEET FEET DEG ~RCO AbASKA, TNC, (UPARIIK ~OR?H SI,OPE,ALASKA TRUE SU~-$E~ COURSE ~RSURED VERTICAL VERTTCaL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG: MTN DEG MTN COMPUTATION DATEI 25-APR-85 PAGE DATE,'O~ SURVEYt~? APE 85 KELbY BUSHING INT£EPOLA?ED VAbUE$ FOR EVEN ~00 ~EE? OF MEASURED DEPTH FEET DEG/~O0 FEET FEET FETE DgG 90,00 FT., tO00.O0 5816 38 5726,38 43 1~ t100.00 5889 4~ 5799,48 42 42 ~00 O0 596] t300 O0 6037 ~400 O0 61i2 ~500 O0 61~8 ~600 O0 6263 ~80~ O0 64! 3 ~qO0.O0 6487 20 587] ~0 42 84 5949:84 41 24 9~ 6022~ 95 41 20 6098,?0 41 5 59 6173,59 41 15 77 6248,72 41 15 59 6~23,59 41 55 39 6399,39 42 54 )000 O0 6560 25 6470.25 43 35 )~00:00 ~612:~ 6K49.~2 44 27 ~300~o0 67-..60 6687.69 45 58 )400 O0 6841,99 675~,q2 46 24 )500:00 ~9~0,87 6R20,~7 46 24 )535.00 6935,00 6~4~,00 46 24 N 52 45 E 5016.94 N 52 46 E 5084 07 , 52 30 E 5i50 55 ~ 52 27 E 5215 95 ~ ~2 26 E 5980 84 N 52 26 E 534~ 57 N 53 2 ~ 5410 16 ~ 54 34 ~ 5475 30 . 54 4~ E 5540 90 ~ 54 5~ E 5675,46 N 55 27 E 5744,~2 N ~6 2 E 5~14,~6 ~ 56 46 F 5885 51 N ~8 12 E 602q.50 N 58 1~ E 6054,77 0 13 0 45 1 2~ 0 0.70 0 8~ 0~ ,00 ~,47 0,00 0,00 0,00 66 N 4481 94 N 4536 92 W 4589 46 N 4642 69 ~ 4694 82 N 4747 69 N 4799 65 N 485 90 N 490~ 2254 2295 2336 2377 2417 4 7 2536 25.74 261,3 ,. 869 , N 50. 3 ~ 519] al '02 ~ 5253 E 50t6 £ 5084 88 E 5150 99 E 52 22 E 5345 41 E 54{0 67 ~ 5475 83 E 5541 87 V 4961,9! E 5608 9 E N 6~ 4 N 6 SE 74 N 62 37 E 44 N6:~ ~o [ ') 68 N 62 24 E · 40 N 62 18 E 29 g 62 13 g 94 E 5676,23 09 E 5745,25 ~ 5815,35 E 5958,70 ~5 ~ 6030,99 10 E 6056,29 N 62 7 E N 62 2 E N 61 58 E N 61 54 E N 61 5 N 61 48 E N 61 47 E ,RC0 A[~ASKA, INC, 0-4 IOR?H SbOP£, ALASKA TRUE 8UB-Sgm COURSE :ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN D~G MTN 0.00 0,00 -90,00 0 .000,00 9g2,54 907,54 15 39 !000,00 1849,74 1759,74 44 56 00,00 ]16 , 0 R, 49 17 i000 00 ]809.44 3710.44 ~0 40 ,000 O0 4437.00 4347.80 $0 49 '000 O0 ~094.94 5004.94 44 55 IO00 O0 58~6.38 5726.]8 43 19 ~000 00 6560.25 6470.75 43 ]5 ~535.00 6935,00 6845.00 46 24 N 0 0 £ N 63 o E 78.06 N 62 2{ E 567.21 N 66 58 F. 1323,4! N 73 1.] E 2062,~6 ~ 72 2 ~ 2816,52 N ~3 1R E 4334,75 ~ 52 45 ~ 5016,94 N 54 58 ~ 5675,46 N 58 12 E 6054.77 90'00 FT VERTTCAL DOGbEG RECTANGULAR COORDINATES HORIZ'~ DEPARTURE S~C?ION SEVE"I?Y NORTH/SOUTH EAS?/NEST DZST, 'ZI"UT" FEET DEG/'O0 FEET FEET FEET 0.00 0 O0 0 O0 N 0.00 E 0 00 "0 0 E 0 10 8, 4 ~ I 54 10331~ ~ 2654,22 E 28~9 57 N 6835 98 27 ~ 6 E 9601 48 N 67 9 0 37 1,3 ]318,9 0 7~ 1840 O] W 3927.24 F 4336 92 N 64 53 E 0 26 2254 66 N 4481,81 ~ 5016 98 N 6~ 17 E ' 0 8~ 2653 29 N 5017,94 ~ 5676 29 N 62 7 E ., 0,00 ~862,5] N 5337,10 £ 6056,29 N ARCO AbASKA, TNC. 10-4 ~UPARUK .VORTH SLOPE,ALASKA TRUE SUB-SEA COURS~ EASURED VBR?ICA~ VE~TICAb DEVTATION AZIMUTH DEPT, DEPTH DEPTH DEG MIN DFG M~N 0.00 90,00 190 O0 290 O0 39O O0 49O O! ~9~ 12 690 48 791 73 894.10 0.00 00 O0 190 O0 290 O0 300 O0 490 O0 590 O0 690 O0 7~0 O0 800 O0 CONPUTATfON DATEI 25-APR-B5 PAGE DATE OF SURVEY.! 17 APR 85 KELbY BUSHTNG EhEVATION{ ENGINEERI MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET Or SUB-SEA DEPTH VERTTCAb DOGbEG RECTANGUb~R COORDINATES HORIZ,i DEPARTURE SECTfON SEVERITY NORTH/SOUTH ERST/WEST DZST.' A~MUTH FEET DE~/100 FEET FEET FEE~ PEG 997 35 1101 05 lOgO 1207 R6 1.1o0 1~15 06 1290 142~ 59 1390 1~3 91 1400 1651.19 1500 178 .~1 1690 191~,75 t7OO 205 ,52 1890 -90.00 0 0 N 0 0 E 0.00 0.00 0 ' 8 51 37 E 0.02 100.00 0 1) $ 74 11 E O. lO0. 0 4 ~ 75 22 E 1, 400,00 1 10 N 73 0 ~ 2,10 500,00 3 39 ~ 75 47 E 6,45 600,00 6 33 ~ 77 51 E 14,51 700,00 11 4 N 71 21 E 29.87 800,00 13 1R ~ 66 30 E 51,66 ~ 62 58 ~ 77,34 N 66 40 E 142,74 ~ 64 6 E 181.29 N 64 5 E ~2~,03 . 62 5R E 279,16 ~ 6t 5~ E 344,08 ~ 62 29 E 42~,70 ~ 61 25 ~ 509.25 ~ 62 38 ~ 60a.29 990 O0 q00.00 15 35 O0 1000 O0 18 25 O0 1100~00 19 57 O0 1~00i00 22 31 O0 1300 O0 25 4~ 00 1400 00 30 21 O0 1500:00 35 40 O0 1600,00 39 30 0 1700,00 43 5 0 1~00,00 46 14 2~04.60 1990 O0 1900.00 47 30 2355.07 ~090 O0 2000.00 48 5~ 2508.95 2100.00 00 50 4 00 2200,00 50 5~ 00 2300,00 50 31 00 2400,00 49 0 O0 2500.00 48 17 O0 2600,00 47 34 O0 2700.00 47 5R O0 2800.00 48 N 62 58 E 716,14 N 63 4t g 828.56 ~ 64 21 E 945.50 M 65 18 E 1067.49 ~ 65 46 E 1190.41 ~ 66 44 ~ i300.49 N 67 48 E 1421.74 N 68 55 ~ 1531.71 N 70 q E 2640,85 ~ 71 3~ E 1751,~5 21q0 2666.74 2290 2825.79 ?390 2980.17 ~490 3131,50 2590 3980.49 2690 3429,n4 2700 3579.01 ~890 N 72 48 E 1862,61 ~ 73 2 E 1972.79 N 73 14 E 2086,44 ~ 73 31 E 2203,nl ~ 73 59 E 2319,44 ~ 74 22 E 2435,80 ~ 74 33 E 2552,77 N 74 42 E 2673.02 ~ 72 27 E 2793.I0 N 68 32 E 2013.50 3729.53 ~900.00 2000,00 48 17 3870.56 3000,00 3000.00 48 36 4n32,~9 3io0.00 310o,00 49 25 4187.31 3290.00 3200.00 49 42 4342.37 3390,00 3300.00 49 54 4497.48 3490.00 3400.00 49 54 4653.16 3500,00 3500.00 50 16 4811.50 3690,00 3600.00 50 43 4960,32 3790,00 3700.00 50 39 5126,65 38q0.00 3800,00 ~0 14 0 O0 0 t2 OilS 0 12 0 i9 219 i 60 4 8! 3 9~ 2 46 2 51 2 45 57 ~,60 3,18 2,07 0,79 0,74 O, 0,69 0.85 0.94 1,16 0,86 0,96 08 0,29 0,16 0,54 ,64 ,43 0,65 0,59 0,00 N 0,05 S 0,15 S 0,23 S O, 19 S O, 14 N 1,34 N 3,11 N 14 7.33 r4 29 S.5,24 N 50 26 52 N ?{ 39 91 N 10 77 ~ 1 69 81N 167 37 ~ 2o~ 08 N 25 94 N 313 09 N 382 22 N 459 54 ~ 546 0,00 E 0 05 E 0 28 E 0 69 E I2~ E 6 50 E 69 E 2O E 90,00 FT 0 0 0 ii ,S 43 46 E ,561 28 E 26 88 1E 29 N 86 24 E 69 N]8 25 ~ 02 N 8 2 E 67 N 76 10 E 46 N 73 6 E E 79 E 143 87 E 181 01E 26 66 E 2;9 32 E 344 88 E 608 77 92 N 70 5 E 39 N 68 23 E N 67 57 E 1 N 67 25 g 40 N 66 44 E 56 N 66 8 E 39 N 6E, 28 E 91 . 64 52 E 38 N 6423 E 37 N 64 0 E 15 90 . 642 7~, lc 716 20 N 6~3 49 E S66 29 S 743 26 F., 828 62 n 6., 45 £ 417 59 iv 84836 £ 94557 N 63 47 E 469 520 567 611 6~2 690 41 N 958 27 n 1070 92 N 1179 51N 1284 31N 1386 55 N 1489 02 N 1595 87 E 1067 60 N 63 54 E 91 E llqO 60 N 64 5 g 14 E 1308 77 N 64 16 E 03 E 1422 20 N 64 32 [ 64 E 1532 41 N 64 48 E ) 63 ~ 1641 90 N 65 7 E 26 E 1753,12 N 65 29 E 926 958 991 1075 1066 32 N 1702.40 E 1864 06 M 1809.34 g 1975 49 N 1919,83 E 2090 41N 2033,34 E 2208 54 N 2147.11 E 2326 84 q 2261.20 g 2443 E 2562 E 7684 88 N 65 54 E 92 N 66 18 E 57 N 66 40 E 28 N 67 2 E O0 n 67 22 E 78 N 67 42 E 31 N 68 I g 27 N 68 19 E 0 N 2376,~6 2 N 2494, 6 92 q 7611,61 g 2805 80 N 68 33 E 48 N 2726.05 E 7927,24 N 68 38 E 0 00 N 0 0 E COMPUTATION DATE: 25-APR-65 PAGE ,~CO ALASKA, INC. 0-4 ;UPARUK lOATH SBOpE,ALASKA DATE OF SURVEY! 17 APR 85 KELLY BUSHING ELEVATION{ 90.00 FT INTERPO[..A?E~ VA~U£S FOR EVEN 100 FEET OF SUB'~EA DEPTH TRUE SUB-SEA COURSE 'ASURED VERTICAl,, VERTZCAL D£VTA?ION AZIHUTH DEPTH D~PTH DEPTH DEG HIN DEG HIN i~64 01 3990 O0 3900.00 51 0 i447 33 4090:00 4dO0,O0 53 13 ~610 31 4190 . .00 4~00,00 50 4300,00 ~925 ~084 ;399 i554 ;703 O0 4100.00 ~1 31 86 4290 ~8 78 4390 OD 50 5 02 4490 O0 4400,00 51 0 ~3 4590 O0 4~00,00 50 32 78 ~6~000 4600 O0 50 35 19 47~0 O0 4700:00 48 56 67 48~0 O0 4800.00 47 49 VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ,: DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, ~ZIMUTH FEET DEC/lO0 FEET FEET FEET DEG N 64 38 E 3034.65 W 57 38 ~ 3535.21 N 57 36 E 3657,~8 N 54 33 ~ 3779.79 N 53 12 E 3899,12 ~ ~3 7 E 4015.00 ~ 52 16 F 4124,25 2 08 1~01 0,14 0 2i 0 37 0 49 3 73 0 0 55 1113 1174 1239 1 1433 1500 1572 1643 171.0 ~ 2952 13 ~ 3063 23 N 337 39 w 347~ 7 N 3574 ~ ~ 3668 83 N 3756 04 E 3048 67 N 68 34 E N 68 18 E 18 E 3425 48 E 3544 O0 E 3665 lO £ 3'787 8 E 3905 53 E 4019 76 E 4177 65 N 38 g 86 N 18 E 79 N 66 59 g IN 66 39 ~ ~ ,ss ,4~ ) 77 H 65 52 E 97 N 65 30 E ~851.~3 4990 00 4900,00 45 36 ~993.02 5090 O0 5000.00 44 58 1133,59 5190 O0 5100,00 44 19 ~72,97 5290 O0 5200,00 43 51 411,34 5390 O0 5300,00 43 43 ~..~ ~oo oo ~oo.oo ~ ~ '236 07 5990.00 5900 O0 al 47 ~s~ ~ ~o~o oo ~ooo:oo ~ ~, ~so~~ s~o oo ~,oo.oo ~ ~ ~s ,~ ~l~o oo ~oo.oo ~ ~ ~o,.~ ~o oo ~oo.oo ~ ~ ~o~.~ ,~oo oo ~oo.oo ~ ~ ~,,~.,~ ~o oo ~oo oo ~, ~ }324.88 6790,00 6700~00 45 55 ~469.73 68o0.00 6~00,00 46 24 9535.00 6935,00 6645.00 46 24 %1 53 5 E 4231.36 N 53 16 E 4329,89 ~ 53 26 F 4427,76 ~ 53 30 E 4522.99 N 53 23 E 4617.29 ~! 53 18 F 4711.35 ~ 52 59 E 4804,94 N 52 49 F 4898,69 N 62 45 ? 4992.48 N 52 46 E 5084.~5 w 52 26 g 5174,26 N 52 26 ~ 5261.05 v 52 26 E 5347,12 w 53 37 E 5433.08 N ~4 43 E 5~20.05 N 54 44 E 5610,06 N 55 8 E 5703,64 ~ 56 2 E 5601,~0 ~ 57 6 E 5903,26 N 58 12 E 6007,66 N 58 12 E 6054.77 3,39 0,69 0,42 0,41 0,45 0,41 0.69 0.31. 1 01 0 31 0 48 1 19 0 89 0.74 1.25 1,35 2.00 0.00 0.00 1777 1837 1896 1953 2010 2067 21~4 218 223~ 2296 43 ~ 384 08 N 04 N 4002 81, N 4080 73 N 4 63 N 4310 99 N 4386 61 ~ 4462 23 N 4536 08 E 4234 20 N 65 10 E 28 E 4332 09 N 64 54 E 55 E 4428 58 E 4524 44 E 4618 00 E 4711 06 E 4805 07 E 4898 01 F 4992 52 E 5084 99 N 64 39 E 22 N 64 24 E 15 N 64 1 ! E 92 N 63 58 E 28 N 63 45 E 85 N 63 33 E 54 N 63 2O E 55 N 63 9 E 2351 61ff 4609 01 E 5174 27 N 62 56 E 5,I 7615 2669 ?725 2782 ?837 58 ~ 4818 N 4869 7~ N 4963 ~9 N 5041 18 ~ 5 63 N 5296 N 62 37 E 06 E 5433 39 N 62 28 g 63 E 5520 51 N 62 20 E 90 E 5610 69 N 62 13 E 27 g 5704 49 N 62 ~ [ 44 E 5802 26 N 61 5:, = ) 98 E 5904 54 N 61 53 E 91 E 6009 11 N 61 49 E 2862,53 N 5337,10 E 6056,29 N 61 47 E IRCO Ab~SKA~ .TNC, .0-4 IOR?H sLOpB~ At, ASKA HARK~R TOP UPPER SAND BASE IJPPER ~AND TOP bOWER 5AND BA$~ t~O~ER ~AND PBTD TD COHPUTATION DATEI 25-APR-85 INTERPOLATED VAtUE$ FOR CHOSEN HORIZONS MEASURED DEPTH BEbOW KB n7o8 oo 8878ioo 9136 O0 9304,00 ~423,00 9535.00 PAGE DATE OF. SURVEy1 !7 APR 85 KEbbY BUSHING EbEVATZONI ENGTNEERI MCBRIDE 90,00 FT 6344,74 6254,74 2539,70 N 4856.98 g 6471.26 63~.~6 2605.13 N 4949.?0 E 6657,79 65 , 9 2707. 4 N 5095'84 E 677So47 66"5,47 2774.01 N SigS'44 E SURFACE bOCATION ORIGINz 12~7~' FNB,I057' FEb SEC 2 .~t2NoRgE UM TV9 RECTAN~UbRR COORDINRTE~ FROM KB SUB-SEA NORTH/SOUTH EAST/WEST ~RC0 AbASKA, ).NC. [0,-4 [UPARUK iOR'r'H SLOPE,ALASKA COMPUTATION DATEI 25-APR.,ES PAGE 8 DATE 'Or. 8URV(~¥~ ~7 APR 85 KEbL,¥ BUSHIN b VRTZONI gO.O0 rT. MARKER TOP UPPER SAND BRSE tIPPER SAND TOP bOWFR SAN~ BASE LOWER ~AND PRTD TD MEASURED DEPTH BEI, OW KB R7A8.,OO B878,00 9136,00 0304,00 94~3.00 q535,00 SURFACE L, OCATiON ORIGIN= 1.227' tNb,lO57' rEt,SEC 26-T12N.RgE,uM TVD RECTANGULAR COORDIIriA?ES FROM KB 8UR-SEA NORTH/SOUTH EAST/WEST 6344.74 6471.~6 6~57. 9 6775.47 6R57,78 6q3~.00 625474 638! 6 6567 ~9 6695 47 6767 78 6845 O0 2539 70 N 26 23 N 2 28 79 N 4856 4949 509,5 519$ 5268 533? 98 E 70 E I) 4 E 44 E 14 E FINAL WELb LOCATION AT TDI T~UE SUB-SEA MEASUPED VERTICAL VE~TTCAb DEPTH DFPTH DEPTH q535,00 6g3~,00 6845,0n HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MTN 6056.29 N 61. 47 E SCHLUMBEROER O I RECT ~[ ONAL SURVEY COMPANY'" ARCO ALASKA INC WELL 1[~-4 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 17 APR 85 REFERENCE O000?OB4B ~ELL NAME: lQ-4 SURFACE LOCATION: 1227' ~L, 1057' FEL,-S26, T12N, R9E, VERTICAL PROJECTION -4000 -2000 0 0 2000 4000 6000 BO00 ! 0000 .... ~...L.L..~ ..... ~.,..~:-.~...~ ...... ~...L.L.~ ...... L.~...~-.~... .... ~--F?~.-~:~..-~-~--.~ ....... :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: ~ i::~::t:::[:~::i: :i:::~: :~ ~ ~ :~: ! :~ ~ i '~ ' --W...~-,,~...~--]-.4.-~-.~-.~ ~ ; : : ~ : : -.4-..~.--~...~::: ...... ~ ~-W-4---~--,~:: ~ 1"4" .... '--~--.~ ...... ~.-~-4---~----.-~--~--~--~---T-W--~--4---~= ..... : : : '-.~--.~---~--~: ~ .... ~-~--4-~---4---~-~4---T ~ * ~: ~ ~: ~ ..... ~ ~-~'-~-~"~"~'- '~-~'-?-7"'~'"~'-~-~"?-~:.: I . , ~ : ..L..i ........... -~-~-++~-.-~.---~-~.,+++-~.- ++-H~~ +i-e.-H-H-H- bFFH--H++-F +'~-~+-~---~-+-+-F~-~~-.-~-+~-~-++. ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ~!.;-..~:::~::~:::~:::~:: ::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ::::::::::::::::::::: --'~--'~--.~'--~'-+.e-'~..F'~ ..... F'~--.+'-~...T---~--.~---~--+-- ~.+.+..~.~.~..;~.~.~.k.~..~.~....~+..~.~...~..~...~`~.~.~.F.~.+..~.~ ...... ~--~-4..+-~-.-~--F-~---~ ..... ~--~-.~--~..-T--~---~-.~---!--..-~q-.-~--~----P~--~-~---i--- '"~i :. i ~ ~ : i ~ ~'" '"'~"'~'"~'"~ ...... ~'"~'"~'"~"'t'"~'""'"'~"~ · "r"~-'7-'7'T"r"~'"~'"~ ....... r"r-'?~ ...... T"r'T"~ ...... r"7"~' '~'T"~"-~'"r"~"-~"-7"-r"T"r--?"~ .... ~-"~--: ............ T"~-t"-r"T"r-'T- "T"7"~"'r"~'"r-'7"7"~-" "T-'~'"~"-r"l'"r"~'-'?'-~ .... ~-f..?-+--~-~--e---~---?- -.-~.-.~,+.-~,,+--~--.~-.-~-,-~ ....... i--+-+.-i-.+--~.-+-~-~ ....... i--.~.--~--.~--.~---~-.-~---~-,-~.-- .~-+--~,--,-..~-~-.~-~---~---~+--~-~-~-.-~ ..... &+.+,-~-t---~--~--!.--i ...... ~-i---&-~-~---~-~--~.-~-~--~-~-i--.~--~-+-+~-~--- · "~'"??'f'-~-'~'"f"~ ....... ~'+'?~'"~-"~'"~'?':"?~-~"f-'f'~'"~-'~'"~--""+'~--'?~'-'k'~?'~"i: ~"-~-+'~-'-~-~'-~"~'--f- -~-'~'*~-~-~-~'-~"f----~"~-'~'~-?+~-~--?-?F-'---f'-~--~b ...... ~'--~--'7 ...... ~."?-.r-'~ ....... ?-~'--~ .......... ~'"?T'~ ....... ~'"?T'?'"]'"?'?-'-r"~ ...... ~--???--T"-?7-"?-?- "-~---. 'r--~---i--.77-+-~ ........... ?+-~--~---r?-~---~ ....... ~'--~---r-~ ...... ~-~"~-'~--- -'~+--~-~-i---~--+'+-.~--- ?'?"T'"' "'~'"~'"T'"~ ....... T"'T'"~'"~ -.-T...~--.:.--~ ....... ~--~-~---+ ....... ~...~-~..-~...J...:~...~...: .~...&..~..4-..~.-.~-.4...~..~ ..... ~...~-.z...~-4..~.--~...~...~- ...~---~.-~-L.~..~-&- ..~..~..~.~..4...~..~...~..g.a ..~...~_~.~..~_.~...~..[~.~...~..~..~.~... :::i::~:::i::~::: ...~...~...~...~ ....... ~..z..~...~ ...... ~..~.~...~.J..z~.~..~ ...... ~...~...~...!..~..~...~..~...~...u...~_z_i..~_i..~2_~ ...... L.~...~...~-i...~:~-~..~_Li.i~ .... ~.LZ!.~..~3.~ ~ ..... ~ ..........~ , ......................................... · ":"~-'r"r"+-~-'r"r"~'", '"~"~'~"r"~'"r: 'r'T-" '~"'r". ~---~'~-r-'~-~--' ~"~'"~-~'T'~"-~-'T"~-'-~'"' "'?'~"?'~'-~-?~'?~-~ '"~"~"~3'-~?~ ???~ ?'~"?~ '-~-?"-?*---?~'--~'? ~ ; : ; ~ ~ ~ ~ ~ '"~ '?'"?'"?'"~'"?"'T"T"? ...... ?'-?'"?'"?'"~'"Y~'; '?"'? ....... V'"?'"?'"V'"?'"7'"?'"V'"T" ""??'"?"? '~ ........ ?'~ ..........~ j?'?z ....... 7'"v-'?'?"* ............ :"-?'T'~'"?'r'-w"?" ~ ....... ?"~"?-?"v ................. z .............. +";'-~'"~'~'~ · -.~...$...~..~ ...... :::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: ::::::::::::::::::::::::: ::::::::::::::::::::::::: :::::::::::::::::::::::: ::::::::::::::::::::::: -.~..+..~..~...~...L.L.~...~ ...... ~-,L-~q...~-.~.~.-~ ...... ~...L.~...L.~..-t..L-L~...,--~...~.-L..~.-j.~.L.-L.L...,.~...L,L.~-{-J--~,.LJ- -.L-LJ.~-L.L-J...;-~--L~-~..L.~..~.L~.~ ~.~.~_.Lj~_j.~... ,.-~...~...;...;...'...L.-L.;...;...~,..L,L.;...~...]...;~.;...~ ..... ;...;...;.~L-.{-~...L.;..L- .-,L.L.L.L.{.,.L.~--L.L... .... ...~...~... :...~"'~'"~" ~ ~ ~: , :: · ~"'?"4'";'"~'"'"':'"~ ..... ....... ~.. ~...~...~ ...~ ....... ,...4...~... u..~...?...; ...... t...4....k..5... L..~...: .............. ~...:...~...4...~...4....~...~...~ ....... ~ .-:-- -~---4---~---~---~---~..-~---~---&---5--4---~---$---4--.~--- ;-- ~-.- --.4-.-4.--4---~---i--.4---,-.-4.--4 ...... ~--.~.-~--4---~---4---&--~.--&---. --~-~---~-.-~.--~---~---4---~--.~--. · ..~..-~.--~--.~.+.~.+.~.--~ ...... ~.-+.-~..-~..-~-.-~.---i-+-~ ..... ~-+-~-...~.--~-++-.~..+.~-~u~g?-~-e~Fs~-~.~-~..~-+.+--.~.-T.++.~...4 ...... ~-+~--+?~-.~.+..-.++..~-.-~...4.+-~-.+.--~.-~ · "~-"~'--i'-'~'-'T-"?-T"i"-i ....... ?'"+"?'t'"t'"?'~"-~ ....... ~'"~ "+'-~ '--T'"~--'~-"f'"f "'T" +"~ '"~" +-i"'+"f'" +" +4--~---~--+-.~ '"!-~-'~'"~ "+" i ......... ~"+4--'~-"~-'-+"~'-F-'~"+"~-+--i-"7'--~'-+-~ ....... ~---~-'-~--~.-+-+-.~---~---~-.-] "f"'?' f'"f'"~"'?"? ...... f'"f""~'"t'"L~'"f"'f"'f ...... f'"f'"f"'~'"'i'"~'"f'"f'"f"'L?~'"f"?f"'f'"f'"f'"t ....... f"~"'~-'-f'"f"-f'--~'"~'--f--'t ....... f...~...?.~..+..~...~.~...t...~...~...~...?.~...~...~...~.Y.~...~...~.~.f...~..+..~...~...~..1 .,,~ ,..~...~...~.,.1 ...~...~ ...~,-.~ ....... ~-..~...~-..4 ...... ~...~.-.~-..~ ....... ~-.-$...~...~...~ ...~..-$-.4...~... 1~ --~ -~ - :---: t--- · ~: :' ~'"~"-~'~'~ .... ??-?.~ ..... ~---~--?-~.--~ · ..L,L~...;...i...~,..~...~..~ ...... ~...~..~...L.~...~,..~...~..,~ ....... ~...~...~.44..~...L.~...L.iJ...~...k~.F~...Li...~.......~...~...L.~...~...~...~...~...L.p..~..:~..~...L.~...~...L.~...FL.L.L..d...~...L:..`q...~...~...~.`.L.~...L.~..~`..q -.-~..-~,--~-,-~.-+-~..-~...~...~ ...... +.--~.-.~--.~---i--.~,4---~..,~ ....... ~..+--~',-~---F+4---i--~--T-+--~-~--+--F+-+-~--+--,.-+-+--~--+--~----F-~---~-+--~ .`+..;...~...~.`+..~...~.`.~...~...~...~...~..+..~...~..+..~..~..`~..F.~.;...~q...i.4~..~..+..~...i ---?-~...~--.i,-,~.--~-..~..-~-.-~ ....... t"-~ ........ !..-i-,.~,--~---:.-,~ ....... i---~.,-~---~--i--~-~-f.~--~-t..~-~-~-t~---~--.~---'.--~---~---~---~"-i---~'--~--~---~--,t---~- ~...~".~``~i...~..~...~-~-~`..~...~...~..~-~...~`..~...~..`~...i.`.~...~..~.`.~..~.`.f...~...~`..~...~ .4..~.. -"~'?'~'-'~"T-~"-~"~ ........... ~".~'-'~---~"-~--'~'--~'--~---~ ....... .... '"~"'~'"7"~'"T'"'F'r'T"~ ....... ~"'r"1'"~"'~'"~"~--'T"?'~ "~'"~'"~'~'"' '-~-~-~'" i-~ ~"~'?"?' "'?'?"T"~'"T'"?"~"~"'~ ....... F"T'q~ T"!" ~"i-'~'"~'--~'"T-~---i"~'?'I'-'~'-'!'-~' --~--?'~'"? "~---~-'-~"~' -..~-.-~ .......... ~ ................................................... ~ .......................... ~ ........... ~.--,-~.4 ............................. ~ ................ ~ ..................................................... ~ ............. ~.--~q.-~--~-..~.- "T"7~ "-'"~'"7~'"?"~ ~'"?"~'"7'~'"7'~'"~'"~'",'"~T~ ~7"F~'"~ ~"T'T' C~"T"~"T" "'~'"~'"~"TYT'~'"?'T'Y'Y"~'":.'"?"~"'~"T"7'F'7'?'T"~'-T"7'?'-7'~ 7'~"'~"'~.-"T'"7'7'7'~"~ · --~,--~.+-~--.b~...~---~---~ ....... ~-+-F~---~.+-~.+-~-..~--?+-~.+-?++-~+-~.+.~+..FF~..F~..+..~...~.~...~+.~..~..~...~...F~.+.~.+.i...~...~...~..~-i..+`~..+.~...i...~.~..+~."~.+.~...~+.k~..~..~...F~ .- ?.-~..-?,?.~..-~...?..?..~ ...... ~-,-~.-.~..-~ ..... ~...~.--~.-4.--:-..~..-~---~...~ ...... ~..4..-~...~.-...~,-.~-..,.,-~.--~-.-~--.~...~..-~ ...... ~-..~-,-.k-4...~---~ ..~,--~...~--- .-.~.-.~---~---~.-.~.--~-..=--~ - ~ ..'.-.~.,-~.--~-..~.-.~..-~-.-~...~...~---~-,-~.--~-.,~..-,-.-~---~..~-..~...~... "-~"+-'~" ~"-~-'?"~"-~' ~-T-'~"'~'---~'+'~--~---~---~'+'~ '"~"'~'"~'"~'"~"'~'~ : ~ ~ ~ · - ~ ~'~'"~'"~ ...... ~'"~"'~'"~'"~'"~'"~'"~ ~ ...... ....... ""'9"~"'~"'~. ~ ~ ~ ..... ~'-~'"~'"~'" ........ F'~'''~'''~'''~ ...... T ~'"~'"~"'~"' ........ '"~'"~'"'?"~"'~"'~'"'~'~ ~ ~ ~ - ~ - - ~ ~ ~'''~ ...... ~'--~ --5-'-~'-~-'-~---~'-'~- .... '~ .... ~ ~"--:'"'-~'--~ .... ....... ~ ~ ~ ~ :!"-~"-~"'~'" ---~-'-~---~---~-'-i---~---~.~: ~ ~ ~ .... -~-- ~--- ...; ....... L..~,..~...L..~ ....... i..'...i,.2.L L..:..,L,.L..L..~ ...... L..~...~..~...~..,L..~..L.i..~.,L..~,..L.LJ...L.L-.L~ ...... L..~...~...L..~...~...~...~...~..~ ...... L...;....L~.i..L..L..L..LJ...L..L.L..L..L.L..~....:~...L.~.-L..~...L.~...L.L..L..L..i -..~.-.~-..F~.+.~.-.~.-.~---~-..~...~...~..-~-.-~.-.~..-~--.~..-F~ ...... ~---~.--~-+-F~---~-.-F~---~-..~---~---~---H---~---~--.~---~---~---~---~---~-- "'T"r"7"?"F'~' "'.-7'7';T"7'?":'"~'"{'"7'~'":'"'.'"~'"7'7'7-~'-' '-'~lRnnn:---?'"?--{'"'~'":-'?"~"-~-~'-'~'":"-~'"~--7 12000 6~. PROJECTION ON VERTICAL PLANE 63. - 243. SCALEO IN VERTICAL DEPTHS HORIZ SCRLE = 1/2000 IN/FT W~L~L NAME: lQ-4 SURFACE LOCATION: 1227' ~L, 1057' FEL,-S26, T12N, R9E, U~ HORIZONTAL PROJECTION 5000 2000 1000 ................ : ' - : ' ~ : : - : i : : : i : - : : :'"i'"'~"':'":'":'"T":"':'":'": i t'".:'"---"':'"T":'":": : i'-:"':-"? ':'"?:'"T":"': F":'":'":'"Y":'":'": ": ~000 6000 7000 EAST ..:4-.;...~..~..:..:.-.:...~., O ":'"':"':'":'":"'~'":'":'":'" J .................. '":"'?-:"?{'"~'":"':'":-"J?"!"'i'":'"J'"~":'":'":j ": ............ :'"+ ....... ~""~'"~'"?:i:~:~::' ' ........ :'":"':'":'"r':'"':'":'": ..... ' : : : i ..... ~----} ...... : : ~ : : : : : : : : ~ : : : : -..r--:.--:---r--r-~--:--:---: P-:-.-4---~.--4---~.---~---:--4...' ._:...:..~..:..i...~...~__.~...~...j...~...~...~...~...:...~...~...~...~..t .................................. ......... : : : : ' : : ...~ ....... :_.~...l...~-.~...~_i... : ? : : T? ? :: : : ~ . : : : : : · 'r":"'r"?'t"-~--': ..... ....... ?' . ..... :.::!:::. :*r..:..~...:...:-.:...:....:..:...?.:...T.7...:...:...:....:...:-:.:..j...:...:...:-.: ¢-':"-~'"¢"J--'~'"~"'&'-:' ..~.-i-..!..-i...i.---i-.!---~...~--~;:;!:: i~ ....... ~-..s..-,---,.-.,...?-?, -..:.-.,...~--.,-..~...~.--~ .- · : ....... .... ....... ==================================== ..:...:...T..:..T...;..-:..-:.-.:.......~...~..~...;..i..~...~...~...~... -1000 : : : : : : : · I : : : i : = i :'''~'''~'''T''T''I'''~''':'''~-:''' .. ::: ::: :: ::: ......... : ..... '"'"i ............. "~-'-;'"~-~'-'~--i"4---!'"i"' : ........ "":'"~"-:'"~'":'":'":"':'": :: :~.. · :"~"!'"':'":":";': ..... : i}ii::i:"':'":'--:"'i'"j'-'i-'-i'''-'H'":'"{"H"H"+- ::~:::: ''' .... :.:.. :::sIT:T: ...... . .... ...~..;~~...;...~.~..~...:..;......;..;..:..;.'.i.~:..:..:.-;...i.~.":..+.~...~...~. !::~'I:::: i<i:{iiii .......... = : : : ~ : : ...? ....... ? ....... ~ ....... :...~-.:..- : : : : j : : : : : : ~ : : ....... i:."'-:'":'":"T"T:"':"':' i' ::::!:::: :-::::.:: : I ....... · , . . : ........ ;:::~' - ooo .... = :...~...i...~...~...~...~...~..~... .'.i.i..~...~-..i.-!...:---:..-?.l-.i~.-~-..i!.-i i~ .... ~:':: i:::~ '"~'"':'~'"~"J":',":"i"T"?"?:'":'*":::: :.: ...... :.~ i:~:-: .:i.: :i'.::l · '~:'"~'"?'--t":": ...... ?"'T'":":'":'"~'"W"~ ....... ?'"?'"T'":"'~'":"'~'"~'":'"?"':'":'"! ..4 ....... ~...~...~ .............. :..J...:.~ ..... T"?'?'"?~ ...... ]'"?'"~"'~'"~'"~'"~'·'~'"~'"?"j ....... i"7 ..... :'T ........ 7": ...... 1 S~TH-~O00 -lO00 0 1000 2000 ~000 4000 WEST Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. RATOR, WEL~ 'N~E-AND NUMBER Reports and Materials to be received by: ' Date Required Date Received Remarks Completion Report Well History Samples Core Description Registered Survey ~ Inclination Survey Directi°nal SurveyS<<%' ~ Drill Stem Test Reports Production Test Reports ,. ~- Log Run'- ~ . . .. D~gltlzed Data ARCO Alaska, Inc. Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Te!ephone 907 276 1215 DATE: 05-2 9-8 5 TRANSMITTAL NO: 5201 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-11i5B P.O. BOX 100360 ANCIIORAGE, AK 99510 ENGINEERING TRANSMITTED HERE~4ITH ARE Tile FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUF~?,] ONE SIGNED COPY OF THIS TFJtNSMiTTAL. SEQUENCE OF EVENTS ACID AND FLUID DATA (ONE COPY OF EACH) 1Q-4/ACID STIMULATION-'C 2B-12 LEAK DETECTION SAND 05-17-85 04-16-85 SEQUENCE OF EVENTS/WSR'S CORRECTED PSI (ONE COPY OF EACH) ID-8 SBHP 04-29-85 1H-6 ~ SBHP 04-29-85 CAMCO CAMCO RECEIPT ACKNOWLEDGED: BPAE* B, CURRIER* C HE VRO N * D & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOB ir.~* PHILLIPS OiL* NS~ CLERK J. EATHMELL* DATE; AlasKa 0il & Gas Cons. (;0remission Anchorage STATE OF ALASKA* £OH IO* UNION* K. ~ UL i,>?/VAULT ARCO AlaSka,/nc. Post Office B" ,00360 Anchorage, Alask Telephon n,,. _ a 99510.0..~m~ e =u/276 1215 May 28, 1985 /Hr C ' Al~sk~ ~V.'. Chat ter ton, Chairrnan uti and 3001 Porcu i Gas Conservation Anchorage, PA~e Dr ire Corrrni /on 99501 ss Dear Mr. Chatterton: Attached are our no*, field we/I IQ-7 an~Ces of intention lQ-2, lQ-3, and 1Q..q~, to fracture Wells I 1: You have any quest ions, · Please Call me at ~JParuk Operations Coord na or I krnc i t At t achmen t (In Tripl /cate) to acidize KUparuk 1A-3, 1A-~ , 263-4543. RECEIVED MAY 2 91985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlantiCRichfieldCornpany STATE OF ALASKA ALASKA t~lL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-234 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 5o- 029-21250 OTHER [] 4. Location of Well SURFACE LOCATION- 1227' T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 89.7' (RKB) 12. FNL, 1057' FEL, SEC. 26, I 6 . Lease Designation and Serial No. ADL 25634, ALK 2567 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Q-4 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~. Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per phone conversation with B. Wondzell (AOGCC) 5/24/85, it is proposed that the "A" sand in Kuparuk well 1Q-4 be hydraulically fractured and propped to improve production. The treatment uses gelled diesel as the pad and carrying fluid and 20/40 sand as the proppant. Diesel will be used as a flush. Lines and equipment will be pressure tested to 2000 psi prior .to starting job, Fluid. Gelled Diesel 430 BBLS Proppant- 20/40 Sand 15,600 LBS ANTICIPATED START DATE. May 26, 1985 RECEIVED MAY 2 9 198§ Alaska 0J! & Gas Cons. Commission Anchorage The space below for Commission use 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KU PARUK _------~'~Ti~_~~ OPERATIONS COORDI NATOR Conditions of Approval, if any: Approved Cop'/ Returned .... Date 5/28/85 Approved by BY LO~Xt£ C. SMITII By Order of COMMISSIONER the Commission Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached is our notice of intention to acidize Kuparuk well 1Q-4. If you have any questions, please call me at 263-4253. field ~Jparuk Operations Coordinator / kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~" ALASKA (aiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-234 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21250 4. Location of Well SURFACE LOCATION- 1227' FNL, 1057' FEL, SEC. 26, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 89.7' (RKB) 6. Lease Designation and Serial No. ADL 25634, ALK 2567 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Q-4 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per phone conversation 5/17/85 with Mike Minde~ of AOGCC, it is proposed that the "C" sand in Kuparuk well 1Q-4 be acidized to improve production. The treatment will consist of 12% HCL solution with MSR100 and an iron sequestering agent and a diesel flush. 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 4,000 psi. Fluid Requirements. 12% HCL Diesel 45 BBLS 100 BBLS ANT ICI PATED START DATE. May 17, 1985 RECEIVED ........ MAY 1 7 AHchorage 14.1 hereby certify that the foregoing is true and correct to the best of myl~v,~jK Sign~ ~~--~,~/-~-~ ~PERAT i ONS COORD I NATOR The space below for Commission use Date 5/17/85 Conditions of Approval, if any: Approved by. COMMISSIONER Approved Copy By Order of the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Ataska, Inc. post Otlice Bo,- .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 A~ril 12, 1985 Mr. C. ~/. chatterton commi s s i ones state of Alaska Alaska Oil & Gas conservation commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 sUBJECT' state ReportS ls' Dear Mr. Chatterton' Enclosed are the March monthly reportS for the following wel 17-11 38-13 L1-9 2U-6 38-14 L2-28 L2-30 lq-3 ~u-7 3B-15 lq-4 2U-8 1Q-5 2v-9 9-27 2C-9 2W-4 2U-5 · If you have any questions, please call me at 263-4944. sincerely, j. Gruber Associate Engineer jG/tw GRuS/LI06 Enclosures RECEIVED APR 1 6 lgB§ Alaska 0il & Gas Cons. C0mmisslorm Anchorage ARCO Aleska, inc. is a Subsidiary o4 A%l[anticRichlleldC°mpan¥ C.~-~_ STATE OF ALASKA ~--- ALASKA 'AND GAS CONSERVATION COl, .¢ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well E~ X Workover operation [] 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100:360, Anchorage, AK 99510 4. Location of Well atsurface 1227' FNL, 1057' FEL, Sec,26, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 89.7' RKB ADL 25634 ALK 2567 7. Permit No. 84-234 8. APl Number 50-- 029-21250 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 10-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. March ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0130 hfs, 03/10/85. Drld 12-1/4" hole to 4642'. Ran, cmtd & tstd 9-5/8" asg. Drld 8-1/2" hole to 9535'TD as of 03/18/85. Ran, cmtd, & tstd 7" esg. PBTD = 9423'. ND BOP. NU tree. Secured well & RR ~ 2130 hrs, 03/19/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft H-40, weld conductor set ~ 103' Cmtd w/240 sx C~ II , · , · 9-5/8" 36 O#/ft, J-SS, BTC csg w/FS @ 4622' Cmtd w/llO0 sx CS Ill sx CS I (top job). 7" 26 O# J-55 BTC csg w/FS ~ 9511' Cmtd w/480 sx Class "G" cmt , · , , . · & 500 sx CS I + 60 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/SP/Cal f/9438' FDC/CNL f/9438' - 8500'WLM - 4622 ' WLM 6. DST data, perforating data, shows of H2S, miscellaneous data EC£1VEb NONE Alaska O# & G;~s COns Anchorage' C°mrnissloe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED &(~~ ~~ TITLE Associate Engineer DATE NOTE--Report ~ 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 10-404 JMM/MR74 Submit in duplicate ARCO Alaska, Inc. ~ Post OfficeIB~J~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 MEMOrRA UM 'to:'=' C" V* Alaska, FROM: Ed,;ar ~. SEpple, Pe tro 1 eum :DA~E: ltarch 19, 1985 NO: TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's Kupal-ak !q-4, Sec. 26, T12N,RgE,UM, Permit No. 8&-234, Nabors Rig 26E. Tuesday, Hatch 12, 1985= I traveled chis date from ARCO's DS L2-28 (SUbject Of another' re~rt) to A~CO's Kuparuk lQ'-4, Nabors Rig 26E, to witness a BOPE test. The drtllinE contractor Was in the process of n£ppling up . Wednesday, Hatch. 13. 19855 The BOPE test commenced at 3=30 pm and Was COnCluded' ~t There were no failures. I filled out, the AOGCC BOPE inspection report which is attached to this~ report. In summary, I witnessed the BOPE ~est on ARCO's Kuparuk lq-4, Nabors Rig 26E. Attachment 02:001 A( Rev. 10/79) LocatiOn, General General-Housekeeping '~ Ri'g ~D~. Reserve Pit. ~ MUd Systems Visual. Audio '-Trip Tank ~ ~:-'. Pit Gauge. Flow Monitor . Gas Detectors BOPE Stafik Pressure ~'~r' Preventer Pipe Rams~ B~ams~ 'C~oke g~~es o ~'~ -. - ' H.C~alve Test Results: Failures '~ - Repair or Replacement of failed equipment to be made within Co~ission office notified. Remarks: ~~ - ACCUMULATOR SYSTEM ull Charge' pressure Pressure After Closure ./ 7.,,9..,~' . psig ?-¢~[..'' Pump incr. clos. pres. 200 psig ~.?m. in~Sec. Pull Charffe Pressure-Attained:. ~_.:.j'~. min:'~-~ Sec. ~ . ,.. Lowe~ KeZZy Ball Type Inside BOP Choke Manifold ¢~Test Pressure No. Valves No. flanges ~ " ""' Hydrau~ca,lly operated choke ~'~'-~ _ Test Time ~/~ daYs and InspectOr/ . . Dis~ributi0n orig. - AO&GCC cc. -:Operator cc - Supervisor - · December 18, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 Kuparuk River Unit lQ-4 ARCO Alaska, Inc. Permit No. 84-234 Sur. Loc. 1227' FNL, 1057' FEL, Sec. 26, T12N, RgE, Btmhole Loc. 1513' FSL, 939' FEL, Sec. 24, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced-well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well 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 spawning 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 com~nencing 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 A~dministrative Code, Chapt~r~70) and by the Federal Water Pollution Control Act, as amenaem. Prior to commencing operations you may.pe_contact~ by a representative of the Department of Environmental ~onservanlon. To aid us in ~cheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. Kewin Kuparuk River Unit lQ-4 -2- December 18, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~y~truly ~rs, C. V. Chatterton Chai~an of Alaska Oil and Gas Conse~ation Co~ission BY OP~DER OF THE COI-~!ISStON lc Enc Io sure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1Q-4 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 1Q-4, along with a $100 application fee Diagrams showing the proposed horizontal project~i.~n.S~ of the wellbore . A proximity plat and vertical A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on January 26, 1985. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kew in Area Drilling Engineer JBK/LST/tw PD/L08 Attachments RECEIVED Alaska 0ii & Gas ¢'- ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... , ALASKA oIL AND GAS CONSERVATION C~,,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I-~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [-] SINGLE ZONE ~ MULTIPLE ZONE [] R£C£I ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1227' FNL, 1057' FEL, Sec.26, T12N, RgE, UPI At top of proposed producing interval 1225' FSL, 1507' FEL, Sec.24, T12N, RgE, UH At total depth 1513' FSL, 939' FEL, Sec.24, T12N, RgE, UN 9. Unit or lease r~l~r2 0il Kuparuk River Unit&AG8$ C0rL9 10. Well number nOhorag8 - 1Q-4 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 89.7', PAD 52.7' I ADL 25634 ALK 2567 12. Bond information (see 20 AAC 25.025) Federal Insurance Company TyPe Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 1Q-5 well360' ¢ surface feet 16. Proposed depth (MD & TVD) 9411' MD, 6824' TVD 18. Approximate spud date 01/26/85 14. Distance to nearest property or lease line miles 939 ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 48 o I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 19. If deviated (see 20 AAC 25.050) 3000 KICK OFF POINT 500 feet. 3444 psig@ 80°F Surface psig@. 6690 ft. TD (TVD) SIZE Hole Casing i24" 16" 12-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 Weld I I J-55 BTC 14524' HF-ERW J-55 BTC 19376' / HF-ERW MD TOP 80' 36' I I 36' 35' SETTING DEPTH TVD MD BOTTOM TVD 36' 116' 116' 36' 4560'I 3570' 35' 9411 '1 6824' I I QUANTITY OF CEMENT (include stage data) + 200 cf 1100 sx Cold Set III & 700 sx Cold Set II 350 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9411'MD (6824' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 3000 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 1Q-4 will be 360' away from lQ-5 at 749'TVD. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The we]] will be completed (see attached sheet) -23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for CDmmission use ( -~1 - ~/ . Area Drilling Engineer DATE . CONDITIONS OF APPROVAL Samples required II Mud log required []YES 60 I I~YES J~_NO I Permit number I Approval date Form 10401 PD/PD08 Directional Survey required I APl number [~(_ES ~]NO I 50- 0 7. ~- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE December 18, 1984 by order of the Commission Submit in triplicate nis$ion PERMIT TO DRILL lQ-4 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECcl ED Alaska Oil & Gas Cons, Commission Ancho~'age )o0 R.I ZON,T oo0 FEET ~ooo ;000 · PT) ARCO PAD ~.1: ..... KUP. _-L_:'_: _:_:. _L_:_:_-_::.~ :::':.': ......... 't ' I ' ' ' ...... ~ ......... ---~'-j .......... BUILD ...... ~ ......... i .... ~-A7 .... BASE. PER~AFROST----T~D=14~ ~ ]~ --~ ......... , ~ , - ~ - , ~ i ~ ....... ::5_:5::: ~/::L: :_::_J '-'::~~:'.::::_J_OP.:LUO~U:-SNDS~.2/~D=~3qOL~.HD=266~DEP=i1053:7~57:~:::: ~ ': :5: .... ; ~ .... ( . , ~ ,,, ~ , ~ . . ~ , , J .... ~ ...... 4 .... ~ :: ~~~~ -~U~ J , , .~ .. / ,. ~ ~ .J . ~ ~t, ~~1~ ~--~~~_~ ~--~ ~ ~- --~ ........... : ........ ~ ............ j ....... ~ . ~ .......... m. __~ ...... J ........ ~ ......... , ..... ' __:_:_~_:__:L:': .-.:...:.'_.~.:.. '-KFS': ..... ':'i ' : ....... ~ ....... I ' ' . :..: :.~..::. :: :. :: ': :~ToP.:Upp~BND8 .' ~vD=~4:8 :T~=85~2~ DEP=54 ...... ~ ............. ~ ....... TARGET ONTR' '-TVD=6418 - ~ ~ ........ ~-:"-~ BASE'KUP ISNDS ~-T-VD=~690 :.::.:?':'. :.:::~::":.:'~':TD (LOOGI~NG P.D::_TVD=682~:_:THD~941]~DEP=~053:~ . _.' ........ J .. i t , . I ~ J ~ i I l ....... ~ ....... J .... ....... . i ...... 6000 · .~ ......... ~ . _ . ~ ...... ~ ........~ ......... ; ....... ~ ...... ~ ............ ~ .... ~ - .. : ..... ~ , . ....... , .... . .... ~ ~ - .. ~ - - ~ - ; .... i .... ~--: ........ ~--: ......! ..... ~ ...... , ~ - : : ii Surface Diverter S,vst~ I. 1G"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 1(;" X 20" 2000 psi double stu(~oeO mO~pter. 20" 2000 psi Urill(n~ spool ~/10" s~Ue outlets. 5. lO" ball valves~ hyOr~ulically actuated, ~/lO" lines to reserve' pit. Valves to open auto~ticmlly upon closure of annular preventer. ~. 20" 2000 psi annular preventer. ?. 20" bell nip~le. ~ain:enance & Operation 1. Upon initial installation close annular preventer verify ~hat ba~l valves have oDeneO properly. 2. Close annular preventer an¢ blow air through ¢iverter lines every 12 hours. Close annular preventer in t~e event :mat gas or fluid fl~ to ~urfame is OetecteC. If necessar7~ ~nually overrioe and close ball valve to upwind diverter line. Do not shut in ~ll under any circ~stmnces. m Conductor ~laska Oil & Gas Cons, Co,,'~ ~"m]s~)~jr,-' ' A~chorage < <, 7 6 DI~ #1 13-5/8" 5000 P~I ~ ~ STACK I. 16" - 21330 P~I T~N<CO ~rA~q'II~ ~ 4. 1~/8" - ~~; P~ ~ K~ L~ A~TC~ CAPACITY TEST I, Q-~ N~D FILL ~TOR RESi~WOIR TO ~ LEVEL WITH ~IC FLUID, 2. ~ THAT AO3.,M.LATCR ~ IS ~X30 P~I W~TH 1500 PSI ~TEEAM CF T~ ~~T~. 3. ~ TI~ T~ ~ ~ ~TS SIXThlY ~ ~TS ~ ~D ~TH ~~ ~ ~. 4. ~~~ ~ ~T, T~ ~~ L~ LI~T 5 4 3 2 > , , . __ 2. 3. 4. 13-5/8" BOP STACK TEST FILL Bi:P STAG( AN:) Q4CKE ~FOLD WlTN ARCTIC DIESS.. Q-ECK 'THAT ALL LO~( DO~ FLI. LY ~ETEACTED. SEAT TEST PLUG IN t~LL~F_AD WITH RUNNING JT ~ ~ IN LO(:Xl:X3V~I SCREt~E~ CLOSE ~ PI~'VENTER LIllE VALVES ADJ~ TO BCP STAOC ALL OTI-ER PRESSI.I~ UP TO 250 PSI AM3 143.D FOR IO M[N, IN- CRE. AS[ PRE,SI.RE TO 3(3(30 PS! AM) t.13LD ~ IO MZN, BLEED ~ TO 0 PSI. LIllE VALVES, CLO~E TCP PIPE EAIv~ ~ H(~ VALVES ~ Kill ~ CHCI<~ LZI~, 6, TES'T TO 250 PSI A~D ~__~O:~__ PSI AS IN STEP 4, ?. CCNTIN.E TESTING ALL V~J. VE~ W'ZTH A ~30 PS'~ LOW ~ 3000 PSI H~. ~T ~ ~N ~ A ~L ~Z~ ~]TZ~ ~ ~, ~Y ~T ~~P]~ ~0 ~] ~~~Z, ~ ~]~ ~ ~ ~T TO ~~D ~ LZ~ ~ F~ ~U]~ ~T ~ V~ 12. ~ ~~]~ V~ F~ ~]~ ~ ~ TO ~]LL~ ~RV~ 14. ~~ ~~ ~ TE~ ~Y ~~ ~T~Y ~E ~ ~]LY. thrdS?8 .. .. -' 10 and' <4.> Cas ' ' (13 thru 2'1)' (,22 thru 26) (6) Add: ........ he'approve8 before .ten day Wait "~:'"' :' m ®. ®~..e®ee ee eeeeeeeee .®ce . ,. ~'.',i.~:::,Dd~";'¥~'erat°r':'~av~ a-bOnd in force.. . . - .'. :.i~":::,~a.~s~a~i'On. order needed ',... ' ' .'leaSe '~umber appropr~atO ~.,. . . in pool:: '" tedii - . · . prope'~., distanca".frOm pr6pert~ acreage aVa i~f::this pool ............ t~i dee .to be.deviated and is wellbore plat u ............... :~"~'""":',r"'"'i thd'-.only :~ffected Party · ' .... ' ', 13. 14.' i5. 16. 1'7. 18. 19. 20. 21~ '.:....:. :.":,...: ..:...?.,:;:!(;. 7.': '.. :;:. .... .--. Is conductor String provided ....................................... Is enough cement used to circulate, on conductor and surface ......... /~T~ Will cement tie in surface and intermediate or production strings ... ) ~ Will cement· cover all known productive horizons ..................... J~ · Will surface Casing protect fresh water zones ....................... Will all casing ~ive adequate safety in collapse, tension and burst.·. · Is this. well to be kiCked off from an existing. Wellbore.. ............ IS...old wellbore abandonment procedure included on 10-403 ............. IS. adequate wellbore separation proposed., ........................... ~ di te qui '' 22. Is a ver r.-system re' red ....................................... . 23 Are necessary diagrams of diverter and BOP equipment attached ..... 241. Does .BOPE have sufficient pressure rating- Test to y,~-~ psi; ..~.2' 25. Does the Choke manifold.comply ,w/AP1 RP-5S (Fab. Y8) .................. , , 26. 'Is. the presence of H2S gas probable ................................. 27 Additional requirements e .eeeeeeleee.eeeeeee.®eeeeee.e................. , Additional Remarks: HO Geology:~ Engineering: HE ~ LCS ,7~-~ BEW ~ rev: 10/29/84 6. CKLT IN ITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologicallY organize this category of information. /gt{-»v( Memory Multi-Finger Caliper Log Results Summary :1' Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska Inc September 17,2005 7021 1 3.5" 9.3 lb. J-55 EUE 8RD Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 Q-44 Kuparuk Alaska 50-029-21250g.:o .... óð 834 Ft. (MD) 9,090 Ft. (MD) Inspection Type : COMMENTS: Co"osive & Mechanical Damage Inspection This caliper data is tied into the Tubing Tail @ 9,085' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good condition. No significant Wall Penetrations, areas of Cross Sectional Wall loss or I.D. restrictions recorded throughout the interval of tubing logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The tool closed early, resulting in a loss of coverage of the top 834 ft. in this well. Therefore the joint numbering is approximate based on average joint length. A temporary tool malfunction resulted in the loss of interpretable data between 9,020' and 9,034'. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>20%) are recorded in the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional wall loss (>11 %) are recorded in the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded in the interval logged. I"~ ........,."',, ("En c., (; ?ODì.: :<;'"'4.·""~\'~h'4.~t., ')," r (..,,,. ,~,ì t....'~. <.1 'i:~,~";":'~,,, ' ~'I"e"",l., .,. I Field Engineer: Wm. McCrossan Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services¡ Inc. I P.O. Box 1369¡ Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(g.ìrnernorylog.com Prudlloe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds. Well: Field: Company: Country: 1 Q-04 Kuparuk ConocoPhillips Alaska Inc USA I Tubing: Weight 9.3 ppf Grade & Thread J-55 EUE 8RD Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 300 250 200 150 100 50 o IIIØ!œ metal loss body o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 266) pene. 0 77 189 0 0 loss 4 260 2 0 0 o o Damage Configuration ( body) 100 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 150) 61 84 5 0 0 PDS Report Overview Body Region Analysis _ penetration body o 26 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins GLM 1 GLM2 GLM3 GLM4 GLM5 GLM6 GLM7 GLM8 GLM9 G LM 10 GLM 11 September 17, 2005 MFC 24 No. 00387 1.69 24 J. Thompson Nom. Upset Upper len. 3.5 ins 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) m.& metal loss body 50 100 GLM 14 GLM 15 Bottom of Survey = 285 Analysis Overview page 2 i i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: lQ-04 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc NominaII.D.: 2.992 in Country: USA Survey Date: September 17, 2005 Joint Jt. Depth I->E'n. Pen. Pen. MC'tClI Min. Damage Profile No. (Ft.) Upset Body 0/0 loss I.D. Comments (% wall) (Ins.) (Ins.) (Yo (Ins.) 0 50 100 26 835 0 0.04 15 5 2.85 Shallow pitting. Lt. Deposits. 27 866 \) 0.04 15 4 2.86 Shallow pitting. Lt. Deposits. 28 898 () 0.03 12 3 2.86 Lt. Deposits. 29 930 0 0.04 17 5 2.85 Line corrosion. Lt. Deposits. 30 959 0 0.03 12 5 2.88 Shallow corrosion. Lt. Deposits. 31 991 0 0.04 16 6 2.89 Line shallow corrosion. Lt. Deposits. 32 1022 0 0.04 16 6 2.86 Line shallow corrosion. Lt. Deposits. 33 1051 0 0.02 9 ., 2.88 .) 34 1083 0 0.04 14 5 2.86 Shallow corrosion. Lt. Deposits. 35 1115 0 0.02 9 2 2.88 Lt. Deposits. 36 1147 0 0.03 13 2 2.89 Shallow corrosion. Lt. Deposits. 37 1178 0 0.02 9 2 2.89 38 1210 0 0.03 10 2 2.89 Lt. Deposits. 39 1241 0 0.04 17 2 2.86 Line shallow corrosion. Lt. Deposits. 40 1273 0 0.04 14 2 2.90 Corrosion. 41 1305 0 0.03 10 2 2.92 42 1337 0 0.03 12 2 2.91 43 1368 0 0.03 11 1 2.93 44 1400 0 0.02 9 2 2.92 45 1432 0 0.03 11 2 2.93 46 1463 0 0.01 3 :3 2.94 47 1495 0 0.05 18 2 2.88 Shallow corrosion. 48 1526 () 0.03 10 2 2.94 49 1556 0 0.04 17 5 2.90 Corrosion. 50 1587 0 0.03 12 6 2.89 51 1617 0 0.04 14 3 2.91 Shallow corrosion. 52 1649 0 0.04 17 :3 2.89 Shallow corrosion. 53 1678 0 0.04 17 3 2.89 Shallow pitting. 54 1709 0 0.04 15 4 2.89 Shallow corrosion. 55 1740 0 0.04 17 :3 2.89 Corrosion. 56 1770 0 0.04 18 11 2.86 Corrosion. 56.1 1801 0 0.01 3 2 2.96 PUP 56.2 1812 0 0 0 0 2.81 SSSV 56.3 1825 0 0.01 4 4 2.95 PUP 57 1833 0 0.04 18 <) 2.88 Shallow corrosion. 58 1864 0 0.04 17 10 2.87 Shallow Corrosion. 59 1896 0 0.04 15 2 2.89 Shallow pitting. 60 1927 0 0.04 18 2 2.88 Co rrosion. 60.1 1953 0 0 0 () N/A GLM 1 (Latch @ 8:00) 61 1963 0 0.04 15 2 2.88 Shallow corrosion. Lt. Deposits. 62 1991 0 0.03 11 3 2.90 63 2022 0 0.04 14 4 2.88 Shallow corrosion. 64 2053 0 0.05 19 :3 2.88 Shallow corrosion. 65 2084 0 0.04 17 4 2.86 Shallow corrosion. 66 2115 0 0.04 14 4 2.86 Shallow corrosion. 67 2146 0 0.04 17 6 2.87 Shallow corrosion. 68 2177 0 0.04 15 7 2.87 Shallow Corrosion. 69 2209 0 0.04 14 2 2.89 Shallow pitting. 70 2241 0 0.04 16 11 2.87 Shallow corrosion. 71 2271 0 0.04 14 3 2.88 Shallow pitting. I Penetration Body Metal Loss Body Page 1 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: lQ-04 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc NominaII.D.: 2.992 in Country: USA Survey Date: September 17, 2005 Joint Jt. Depth I->('n. Pen. Pen. ,r\;\(' La I Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) (1<) (I ns.) 0 50 100 72 2303 0 0.04 14 2 2.88 Shallow corrosion. 73 2334 0 0.04 16 4 2.87 Shallow corrosion. 74 2366 0 0.04 15 3 2.88 Shallow pitting. 75 2397 0 0.04 14 4 2.85 Shallow corrosion. 76 2428 0 0.04 15 4 2.88 Shallow pitting. 77 2459 0 0.05 18 3 2.87 Corrosion. 78 2490 0 0.05 18 4 2.89 Corrosion. 79 2521 0 0.05 18 5 2.86 Shallow corrosion. 80 2552 0 0.02 9 2 2.86 81 2582 () 0.02 7 3 2.87 Lt. Deposits. 82 2613 0 0.03 13 2 2.87 Shallow pitting. 83 2644 0 0.05 20 3 2.86 Shallow corrosion. 84 2675 0 0.03 13 2 2.89 Shallow pitting. 85 2704 0 0.04 14 2 2.89 Shallow corrosion. 86 2735 0 0.05 20 6 2.87 Corrosion. 87 2767 0 0.04 15 7 2.85 Shallow corrosion. 88 2797 0 0.03 11 3 2.86 Lt. Deposits. 89 2827 0 0.03 13 3 2.86 Shallow pitting. 90 2858 0 0.05 20 5 2.88 Shallow corrosion. 91 2885 0 0.03 11 2 2.88 92 2916 0 0.03 11 :3 2.85 93 2946 0 0.04 17 3 2.86 Shallow corrosion. 94 2977 0 0.04 17 2 2.86 Shallow corrosion. 95 3009 0 0.05 18 4 2.86 Shallow corrosion. 96 3038 0 0.05 19 2 2.86 Shallow corrosion. 97 3069 () 0.05 19 9 2.86 Shallow corrosion. Lt. Deposits. 98 3100 0 0.05 19 3 2.87 Shallow corrosion. 99 3130 0 0.05 20 7 2.87 Corrosion. 100 3161 () 0.04 16 .') 2.86 Shallow corrosion. 101 3191 0 0.05 19 4 2.87 Shallow corrosion. 102 3223 0 0.04 18 2 2.86 Shallow corrosion. 103 3255 0 0.04 16 5 2.87 Shallow corrosion. 104 3286 0 0.02 9 2 2.91 105 3318 0 0.03 10 2 2.87 Lt. Deposits. 106 3350 0 0.02 9 3 2.92 106.1 3378 () 0 0 0 N/A GLM 2 (Latch @ 1 :00) 107 3388 0 0.02 7 3 2.92 108 3420 0 0.04 lS 5 2.85 Shallow corrosion. 109 3451 0 0.03 10 3 2.89 110 3482 0 0.03 12 4 2.87 Shallow pitting. 111 3513 0 0.04 15 2 2.88 Shallow corrosion. 112 3544 0 0.02 9 2 2.91 113 3576 0 0.03 10 2 2.92 114 3604 0 0.03 11 4 2.88 115 3635 0 0.02 8 2 2.91 116 3667 0 0.04 14 3 2.86 Shallow corrosion. 117 3699 0 0.02 7 :> 2.90 118 3731 0 0.02 9 2 2.86 Lt. Deposits. 119 3762 0 0.03 13 3 2.88 Shallow pitting. 120 3794 () 0.01 5 2 2.87 . Penetration Body !2~, Metal Loss Body Page 2 :~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 1Q-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc NominaII.D.: 2.992 in Country: USA Survey Date: September 17, 2005 Joint Jt. Depth IJen. Pen. Pen. ¡\t\el¡¡1 Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) <Yc) (Ins.) 0 50 100 121 3823 0 0.05 20 '\ 2.84 Corrosion. ,) 122 3854 () 0.04 15 3 2.87 Shallow corrosion. 123 3885 () 0.04 14 2 2.85 Shallow pittin~. 124 3915 0 0.05 18 4 2.85 Shallow pittin~. 125 3946 0 0.04 17 2 2.88 Shallow corrosion. 126 3976 0 0.03 11 4 2.85 127 4007 0 0.03 13 3 2.87 Shallow corrosion. 128 4039 0 0.03 13 4 2.88 Shallow pitting. 129 4070 0 0.03 13 2 2.86 Shallow pittin~. 129.1 4097 0 0 0 0 N/A GLM 3 (Latch @ 2:00) 130 4107 0 0.03 12 4 2.88 131 4138 0 0.04 17 5 2.83 Shallow corrosion. Lt. Deposits. 132 4169 0 0.03 11 2 2.86 133 4200 0 0.03 13 2 2.85 Shallow corrosion. Lt. Deposits. 134 4232 0 0.03 10 ') 2.87 .) 135 4262 0 0.05 18 2 2.85 Shallow corrosion. 136 4290 0 0.04 16 5 2.86 Shallow corrosion. 137 4321 () 0.03 13 3 2.88 Shallow pittin~. 138 4352 0 0.01 5 ') 2.88 .J 139 4383 0 0.03 10 3 2.85 140 4413 0 0.03 13 4 2.88 Shallow corrosion. 141 4444 0 0.03 12 3 2.89 142 4474 0 0.04 15 4 2.88 Shallow pittin~. 143 4505 0 0.03 11 3 2.88 144 4537 0 0.01 5 3 2.89 145 4568 0 0.04 16 <) 2.85 Shallow corrosion. 146 4598 0 0.03 10 3 2.87 146.1 4627 () 0 0 0 N/A GLM 4 (Latch @ 7:00) 147 4639 0 0.03 13 2 2.87 Shallow corrosion. 148 4668 0 0.04 15 6 2.86 Shallow pittin~. 149 4700 0 0.05 18 3 2.87 Shallow corrosion. Lt. Deposits. 150 4731 0 0.03 11 5 2.85 Lt. Deposits. 151 4762 () 0.03 13 3 2.86 Shallow corrosion. 152 4794 0 0.04 14 3 2.87 Shallow pittin~. 153 4825 0 0.03 12 2 2.85 Shallow pittin~. 154 4855 0 0.03 12 4 2.88 155 4886 0 0.03 10 3 2.89 156 4919 0 0.03 11 2 2.90 157 4950 0 0.03 12 2 2.88 158 4982 0 0.03 10 2 2.86 159 5011 0 0.02 8 2 2.90 160 5043 () 0.02 9 2 2.90 161 5075 0 0.04 14 2 2.88 Shallow corrosion. 162 5106 0 0.03 13 2 2.90 Shallow pittin~. 163 5138 0 0.03 11 2 2.88 163.1 5167 0 0 0 0 N/A GLM 5 (Latch @ 8:00) 164 5180 0 0.02 9 2 2.89 165 5209 0 0.01 6 3 2.92 166 5241 0 0.03 12 2 2.91 167 5270 0 0.03 13 2 2.87 Shallow pitting. Lt. Deposits. I Penetration Body I Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: lQ-04 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc Nominal 1.0.: 2.992 in Country: USA Survey Date: September 17, 2005 Joint Jt. Depth Perl. Pen. Pen. MeIdl Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 168 5302 () 0.03 11 2 2.89 169 5334 0 0.02 9 2 2.90 170 5366 0 0.03 13 2 2.91 Shallow pitting. 171 5395 0 0.02 9 2 2.89 172 5427 0 0.03 13 2 2.89 Shallow pitting. 173 5457 () 0.03 11 ') 2.90 - ) 174 5489 0 0.02 9 2 2.90 175 5520 0 0.05 20 () 2.86 Corrosion. 176 5552 0 0.03 10 2 2.88 Lt. Deposits. 177 5584 () 0.04 15 2 2.88 Shallow pittin~. 178 5614 0 0.03 13 :3 2.87 Shallow pitting. 179 5646 0 0.04 14 2 2.88 Shallow corrosion. 180 5678 0 0.03 13 :3 2.91 Shallow corrosion. 181 5710 0 0.03 13 2 2.88 Shallow pitting. 181.1 5738 0 0 0 0 N/A GLM 6 (Latch @ 8:00) 182 5748 0.03 0.05 18 :3 2.82 Shallow pitting. Lt. Deposits. 183 5779 0 0.03 11 2 2.89 184 5811 0 0.04 15 2 2.90 Shallow pitting. Lt. Deposits. 185 5843 0 0.03 10 2 2.90 186 5874 0 0.05 19 4 2.83 Shallow pitting. 187 5906 0 0.04 14 2 2.87 Shallow pitting. 188 5938 0 0.02 9 3 2.91 189 5970 0 0.02 9 :3 2.90 190 6001 0 0.02 9 2 2.90 191 6031 0 0.03 13 4 2.87 Shallow pitting. Lt. Deposits. 192 6062 0 0.03 11 2 2.88 193 6094 0 0.03 12 2 2.88 194 6126 0 0.03 10 3 2.90 195 6158 0 0.03 10 5 2.90 196 6189 0 0.05 20 2 2.89 Shallow pittin~. 196.1 6217 0 0 0 0 N/A GLM 7 (Latch @ 8:00) 197 6230 0 0.04 16 4 2.86 Shallow pitting. 198 6258 0 0.02 9 2 2.91 199 6290 0 0.03 13 2 2.90 Shallow pitting. 200 6322 0 0.04 15 2 2.89 Shallow pitting. Lt. Deposits. 201 6351 0 0.04 15 2 2.88 Shallow pitting. 202 6383 0 0.02 9 ') 2.90 203 6415 0 0.03 10 2 2.88 Lt. Deposits. 204 6446 0 0.03 11 :3 2.90 205 6478 0 0.03 13 2 2.90 Shallow pitting. 206 6510 0 0.03 12 2 2.91 207 6542 0 0.03 12 2 2.87 208 6573 0 0.03 12 2 2.88 209 6605 0 0.05 19 4 2.88 Shallow corrosion. 210 6636 0 0.03 13 2 2.88 Shallow corrosion. 211 6668 0 0.05 18 3 2.79 Shallow corrosion. 211.1 6698 0 0 0 0 N/A GLM 8 (Latch @ 4:30) 212 6706 0 0.03 13 2 2.79 Shallow corrosion. Lt. Deposits. 213 6738 0 0.02 9 2 2.91 Lt. Deposits. 214 6768 0 0.03 13 2 2.89 Shallow corrosion. I Penetration Body ti:!;: Metal Loss Body Page 4 I~ \\ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: lQ-04 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc NominaII.D.: 2.992 in Country: USA Survey Date: September 17, 2005 Joint Jt. Depth Pen. Pen. Pen. Melal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 215 6800 0 0.03 13 4 2.90 Shallow corrosion. 216 6831 () 0.04 16 3 2.90 Shallow pittin~. 217 6862 () 0.03 10 2 2.90 218 6893 0 0.03 12 2 2.90 Shallow pittin~. 219 6923 () 0.03 13 2 2.90 Shallow pitting. 220 6955 0 0.04 14 2 2.86 Shallow pitting. 221 6986 () 0.04 14 5 2.87 Shallow pitting. 222 7018 0 0.04 16 2 2.88 Shallow pitting. 223 7049 0 0.03 13 2 2.93 Shallow pittin~. 224 7078 0 0.03 10 2 2.95 224.1 7107 0 0 0 0 N/A GlM 9 (latch @ 7:00) 225 7119 0.02 0.04 15 2 2.88 Shallow pitting. 226 7148 0 0.02 9 :) 2.92 227 7180 0 0.03 13 2 2.92 Shallow pitting. 228 7209 0 0.05 19 :3 2.88 Shallow corrosion. 229 7239 0 0.03 10 2 2.91 230 7271 0 0.03 11 :) 2.93 231 7303 0 0.03 13 2 2.92 Shallow pittin~. 232 7335 0 0.03 11 2 2.91 233 7367 0 0.01 5 2 2.94 234 7398 0 0.03 11 2 2.93 235 7430 0 0.03 10 2 2.88 236 7461 0 0.02 9 2 2.92 237 7493 0 0.04 15 2 2.90 Shallow pitting. 238 7525 0 0.04 14 2 2.87 Shallow corrosion. 239 7554 0 0.03 11 2 2.90 239.1 7583 0 0 0 0 N/A GlM 10 (latch @ 9:00) 240 7595 0 0.03 11 2 2.91 241 7624 0 0.02 9 2 2,92 242 7656 0 0.04 17 2 2.87 Shallow corrosion. 243 7686 0 0.04 17 6 2.90 Shallow corrosion. 244 7717 0 0.04 14 3 2.90 Shallow pitting. 245 7748 0 0.02 9 :3 2.91 246 7780 0 0.05 20 2 2.83 Corrosion. 247 7812 0 0.03 12 2 2.86 Shallow pitting. 248 7841 0 0.03 10 :3 2.92 249 7872 0 0.03 11 2 2.90 250 7905 0 0.04 14 2 2.90 Shallow pitting. 251 7937 0 0.02 9 2 2.93 252 7968 0 0.02 6 2 2.90 253 8000 0 0.02 9 2 2.91 254 8031 0 0.04 16 2 2.90 Shallow corrosion. 255 8063 0 0.04 16 1 2.86 Shallow corrosion. 255.1 8093 0 0 0 0 N/A GlM 11 (latch @ 7:00) 256 8099 0 0.05 18 2 2.88 Line corrosion. Lt. Deposits. 257 8131 0 0.04 17 4 2.88 Isolated pittin~. 258 8162 0 0.04 14 :3 2.91 Shallow pittin~. 259 8192 0 0.04 14 4 2.90 Shallow corrosion. 260 8224 0 0.05 20 7 2.88 Corrosion. 261 8255 0 0.04 15 5 2.90 Shallow pitting. I Penetration Body Metal loss Body Page 5 ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: lQ-04 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc Nominal 1.0.: 2.992 in Country: USA Survey Date: September 1 7, 2005 Joint J t. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) 0' (Ins.) 0 SO 100 10 262 8286 0 0.03 13 4 2.90 Shallow pitting. 263 8316 0 0.05 19 2 2.90 Shallow corrosion. 264 8348 0 0.02 9 2 2.88 265 8379 n 0.03 11 2 2.90 266 8411 0 0.03 11 2 2.91 Lt. Deposits. 267 8442 0 0.04 16 4 2.90 Shallow corrosion. 268 8474 0 0.04 15 2 2.84 Shallow corrosion. 268.1 8504 0 0 0 0 N/A GLM 12 (Latch @ 3:30) 269 8512 0 0.03 12 1 2.82 Lt. Deposits. 269.1 8543 () 0.01 5 2 2.94 PUP 269.2 8549 0 0 0 0 N/A 269.3 8561 0 0 0 0 N/A PACKER 270 8570 0 0.04 15 5 2.89 Shallow corrosion. 270.1 8601 0 0 0 0 N/A GLM 13 (Latch @ 10:00) 271 8610 0 0.02 9 2 2.91 272 8641 0 0.03 13 2 2.93 Shallow pitting. 272.1 8672 0 0 0 () N/A GLM 14 (Latch @ 10:00) 273 8682 0 0.04 14 5 2.84 Shallow pitting. Lt. Deposits. 274 8713 0 0.01 5 4 2.97 Blast It. 275 8732 0 0.03 10 5 2.97 Blast It. 276 8752 0 0.01 3 :3 2.98 Blast It. 277 8772 0 0.01 3 3 2.92 Blast It. .. 277.1 8792 0 0.02 8 4 2.97 PUP 278 8807 0 0.01 4 2 2.93 279 8839 0 0.01 3 2 2.94 280 8869 0 0.04 14 2 2.94 Shallow pitting. ~ 280.1 8898 0 0.01 3 1 2.94 PUP 280.2 8902 0 0.01 5 3 2.94 PUP 281 8917 () 0.01 4 4 2.98 Blast Jt. ~ 281.1 8937 0 0.02 7 2 2.97 Blast Jt. PUP 282 8942 0 0.03 10 2 2.92 282.1 8973 0 0 0 0 N/A GLM 15 (Latch @ 2:00) 283 8981 0 0.03 10 3 2.92 283.1 9013 0 0 0 0 N/A Locator 283.2 9020 0 0 0 0 N/A Not Analyzed 283.3 9024 0 0 0 0 N/A Not Analyzed 284 9026 0 0 0 0 N/A Not Analyzed 284.1 9051 0 0 0 0 2.75 o NI PPLE 285 9054 0 0.04 15 4 2.90 Shallow corrosion. r 285.1 9084 0 0 0 0 N/A 50S 285.2 9086 0 0 0 0 2.90 I Penetration Body 1':::¡i} Metal Loss Body Page 6 I) ConocoPhillips Alaska, Inc. 1 Q-Q4 nL.'.! I' _.:g; ..-..... -=-= ::--=-: u H ~ ® API: 500292125000 SSSVType: TRDP Annular Fluid: Reference Log: Last Tag: 9365 Last Tag Date: 4/612005 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String - TUBING Size I Top 3.500 0 Perforations Sum mary Interval TVD 8709 - 8719 6347 - 6354 8722 - 8726 6357 - 6360 8735 - 8740 6366 - 6370 8742 - 8753 6372 - 6380 8756 - 8764 6382 . 6388 8771 - 8TT7 6393 - 6398 8834 - 8881 6440 - 6475 æ14-~8 ~9-~ 9157 - 9164 6674 - 6679 Zone C-4 C-4 C-4 C-4 C-4 C-3 C-1 ,UNIT B UNITB A-4 9164 - 9224 6679 - 6721 6764 - 6776 A-4,A-3 A-2 9285 - 9303 Bottom 9085 KRU 1Q-04 Well Type: PROD Orig Completion: 311911985 Last w/o: Ref Log Date: TO: 9535 ftKB Max Hole An!:Ie: 53 de!:! @> 5400 Angle @> TS: 41 c:Ie!1 @> 8708 Angle @ 1D: 46 deg ((i) 9535 Rev Reason: GLV desi!1n Last Update: 7/10/2005 Top Bottom ND Wt Grade Thread 0 103 103 62.50 H-40 0 4622 3571 36.00 J-55 0 9511 6920 26.00 J-55 ND Wt Grade Thread 6623 9.30 J-55 EUE SRD Status Ft SPF Date Type Comment 10 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 4 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 5 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 11 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 8 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 6 12 4/24/1985 IPERF 12OdEl!1 ph;5"Sealloped HDC 47 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 14 12 4/24/1985 IPERF 120deg ph;5"Sealloped HDC 7 4 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 deg. CCW F/ 60 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 deg. CCW F/ 18 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 dEl!1. CCW F/ Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type VMfr V Type VOD latch Port TRO Date Vlv Run Cmnt 1 1957 1819 Cameo KBUG DMY 1.0 BK2 0.000 0 3/1:3/1994 2 3383 2760 Cameo KBUG GLV 1.0 BK2 0.125 1320 5/25/2002 3 4099 3234 Cameo KBUG DMY 1.0 BK2 0.000 0 4/25/1985 4 4637 3580 Cameo KBUG DMY 1.0 BK2 0.000 0 3/13/1994 5 5177 3923 Cameo KBUG DMY 1.0 BK2 0.000 0 4/25/1985 6 5751 4280 Cameo KBUG GLV 1.0 BK2 0.156 1352 5/25/2002 7 6224 4579 Cameo KBUG DMY 1.0 BK2 0.000 0 5/12/1994 8 6698 4887 Cameo KBUG DMY 1.0 BK2 0.000 0 9/26/1993 (1) 9 7113 5177 Cameo KBUG DMY 1.0 BK2 0.000 0 5/25/2002 10 7588 5519 Cameo KBUG GLV 1.0 BK2 0.188 1382 5/25/2002 11 8095 5887 Cameo KBUG DMY 1.0 BK 0.000 0 5/25/2002 12 8506 6194 Cameo MMG-2 OV 1.5 RK 0.188 0 9/2/2004 1. BK latch @ 6698' RKB bent slightly up out of pocket; Ret WSRs 12/19-20/99 Production MandrelsNalves St MD TVD Man Mfr Man Type VMfr V Type VOD latch Port TRO Date Vlv Run Cmnt 13 8604 6268 Cameo MMG-2 DMY 1.5 RKP 0.000 0 5/612005 Closed 14 8674 6321 Cameo MMG·2 DMY 1.5 RKP 0.000 0 5f7/2005 Closed 15 æ72 6541 Cameo MMG-2 DMY 1:5 RKP 0.000 0 1/28/2003 Closed Other 'plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 1815 1714 SSSV Baker 'FVL' 2.812 8552 6229 SBR Baker PBR 2.992 8566 6239 PKR Baker 'FHL' 3.000 9013 6571 PKR Baker 'FB-1' 4.000 9051 6598 NIP Cameo 'D' Nipple NO GO 2.750 9084 6622 SOS Cameo 2.992 9085 6623 TTL 2.992 Fish - History of FISH Depth DescriPtion Comment 9051 Keys & Plug from CR Plan to Push down to Tubing Tail. 9119 27' of 1 7/S" Tool String Tool String lost in rathole 5/8/94; wire recovered 5/10/94; Fish history in WSR. 9530 DMYVALVE 1.5" DMY valve set 9/15/02, but during eheek for DMY on 1/27/03, impression of empty socket; 9/15/02 DMY dropped; depth not known. =-=::=:: =--= R' )IP,'.'.',e··..' . ".... .. "'V *********.************ . . * * . '.' . ... .... . .' ..* ********************** * . ......,....!ÎJ.Í!!'..""'...,,....~.' *..-.SCHLUMaE~G~R....* *......-......~.~.~.~* .*****..*.-.********** LIS TAPE VERIFICATION LISTING I ''':\ ~.~ ("" I"~ 'I . I ~," 1,'- l t,'" /i , f ,.1.·- D' ''''L, "~!L fi ï/ C LiCC; 3'~) 1985 ~ h<::' a 0'1 & ¡.\.;:......,{ I G23 Cons C '. ","_ . omm:3s~~n Ii ¡ ~ ;_' ~' t C~ ~,. ~~ D-3 '¡II I "~ -- LVP OIO,MO~ VERIFICATION LISTING PAGE O NTINUATiON #. I01 REVIOU$ REEL : ?APE NAME, ~ CONTINUAT'ION # PREVIOUS TAPE EOF ** FI'bE HEADER V,ER$I N # OATE ~ ~AX~[,IM LEN?TH rILE TYP~ PREVIOUS ,00~ 1024 INFORMATION RECORDS ** MN~M CONTENTS UNIT TYPE. CATE SIZE CODE PRESl Z 000 000 001 065 ** COMMENTS * SCHLUmBERgER * ALASKA COMPUTING CENTER COMPANY = ATLANTIC RICHFIELD C'O~PAN¥ LVP 010,~0~ VERIFICATION DTS'TING PAGE 2 COUNTY NORTH &t~OPE BOROUGH ALASKA ,)OB NUMB~IR A? ACC~ 70506 GDPI C~W =. ' : 5" TO 9440' CASING 9,6~5" B 36.00 - BIT SIZE B, ~YPE FLUID =. LSND -WEIGHTED DEN$1,Y =. 9 g LB/G RM = 2..~.90X ~ ~2.0 DF ,0 S RMF = · 0,0 :r ~bUlD [,uss = S,° ' 6 C3 RH AT :B'HT = 247 MATRIX SANOSTONE ~* TH~$ DATA HAS NOr BE~N DEPTH SHIFTED-, OVERLAY8 FIELD PRINTS * SCHLUMbErGER LOGS .T. NCLUDED WITH THIS MAGNETIC TAPE~ * bVP 010 RO~ VERIFICATION LI$?IF, G PAGE 3 * DU.Ab INDUCTION ' E ' * FORMATION DEN$ITY D PENSA.E:D LOG * COMPENSATED NEUTRON [,0~ (FDN) * DA~ AVAILAB5~: 8500' TO 9409' ** DATA FORMAT RECORD ** ENTRY {~,0C,$ TYPE SI~E ,EPR COD, ENT,Y 9 4 1 N 1 b 1 6:6 0 1 66 0 o~ rr oo ooo oo o o ~ ~ 68 oooooooooooooo SrLU DIL OHM~ 00 220 01 0 0 4 I 68 00000000000000 ,~, ~z , o ~ ~ ,8 oooooooooooooo ~P DIL OHMM O0 ~20 44 0 I 66 00000000000000 PI,~ ~V O0 0 O1 0 0 4 1 68 00000000000000 R nxu OAPX O0o 01 0 o 4 1Se00000000000000 ~ rD. OAP! O0~ 001 0 0 4 I6800000000000:000 a~ ru~ ~N oo. ooi o o 4 168oooooooooooooo ,.o~ ,~. .,~oo,,o~ o o , {~ ooooooooooooOOoooooooooooooo ,.,~ ~. oo ooo ooo o ~ ~~0 oooooooooooooo .~.~ .~. .~oo ~,o ooo o ~ ~~oooooooooooooo DATA bVP OlO.H02 VERIFICA?ION L?$?ING PAGE 4 NP~I ?1.6309 NCNb DEPT 9400.0000 SFLU SP -23.7§00 GR RHOB 5~,$867 NPHI .6348 NCNb 2,35q~ DRHO NPHI 33,!.055 NCNL DEPT 9~00.0000 SFI, U OB 2~.754 NPHI 31, 4~7 NCNb OEP? 9100.0000 srLu SP -34.1250 RHOB ~:4414 NpH! 3 2012' NCNb DEP~ 9000,0000 SFt, U SP -34,1875 RHOB ~,4219 DRHO DgPT 8~00,0000 SP, -35,31~5 GR RHOB 2.)906 OReO NpHI 33.6426 NCNb DEPT 8800,0000 SFLU SP -35 ~500 Ga NPHI 24'2676 NCHb D~? 8?00 oooo RHOB 2 439b DRHO NPH! 35:4492 NCN~ OEPT 8600 0000 sFLu 8P '3~:2~00 RHOB 2.3633 NPHI 44.3359 ~CNL RHOB 2 379 DRHO ~PH! 47,6074 NCNb DEPT 8~00.0000 SFLU SP 3~.2500 -'1361.0000 FCN:L ~00, 0 GR 0,.~344 NRtT 1819. 000 FCNL 7 0039 ILO 2576,0308 ~RAT . O0 O0 IFCNL 38,5313 ILO 5~,0000 ~R 3392,0205 NR~T .0000 rCNb 620 ~T 2:64 6: 0 o o'o [,' C N b 31.5391 IGD m. '1875 GR · 0649 NR,AT 28 ,0000 FCNL 6.0664 89'0625 ~R 0,,0264 NEAT 2658 ,.0000 rCNb 4,5 7~ ILO 97 . 0 0635 NEAT 2582:0000 FC~b 2.4824 123 250 GR 1,4048 122 7500 ~.'0~88 NEAT 205 '0 O0 FCNL , 121,7500 ~R 0,0459 NRAT 1871.0000 rCNb 2 6699 iUD 108:6250 GR -255.8750 10~'I1780 , 50 42~ ':I0~6 .2500 B.2500 87.437'5 2,9785 951.0000 30,~438 50. 000 000 4 ,43:75 8~'6t~3 ;0906 s}. 8$3 ~:t875 ,0293 876:.0000 6.5938 8 0625 837,0000 3,55'08 97,6875 2,4746 1050.0000 2,6777 ~2~.6250 . 2441 67 .5000 1.8428 121,7500 500 ,7090 .50OO 1.6934 12~,7500 .8281 '472,0000 2,3633 -999.~500 ALI RNRA IbM ~A:bI. NRA ALI RNRA CALl RNRA CALI NNRA CALl CALl RNRA CALl CALl RNRA CALl RNRA CALl 7,5234 8,8628 3. 0254 6,9961 9,3516 3,2324 3,7070 4590 2,6953 1~,539! ,5156 1.~223 10, 047 4,1094 1,7715 9629 2,4160 -999.2500 LVP' OlO,NO~ VErIFICAtiON I,,,ISTING PAGE 5 RHOB D£PT NPH! DEPT RHOB NP'H~ $~.. N'FH! RHOB SP RHOB NpH! RHOB NPHX RHOB NPH! DEPT SP RHOB NPHX SP RHOB ~PH! DEPT -999 2500 ORHO · ,~99:~oo NCN~ 8.30O - 36 -gg9 -99:9 ,,999 0000 SFLU 1875 ~R 2500 DRHO D500 NCNL * 0 C~R ,~00 DRHO , O0 ffCl~.lb 81 O0,0000 Rrl.,t{ "43,,~375 ~R -9'99, 500 ORHO -999.2500 NCNL 8.000 -ggg ..qO0 999 .g:gg ilio ...,,.o 2500 NCNb 0000 SFLU .~.500 .0000 ~FRRLU ,56~5 · i{ oOoo . =ggg :2500 -999:.2500 3 5996 I61 5000 -999 -ggg NRAT PCNL 2637 29 *0000 OR 'gg9* -ggg'2500 NR T ,25o0 FC b 4160 2~00 "999, -ggg, ~R 2,5'449 ~bD .103,0000 G:R ,999.,2500 NRAT 999,25:00 FCNb 115. (IR '9~9,'25 0 NRAT -999,2500 rCNb 7700.?000 SFLU 1,6748 ThO '30,,...50 OR 88,0000 GR -999,2500 DRHO -999..2500 NRAT -999.2500 MCNi~ -999,2500 FCNL 2 5313 lbo 81~750 GR -qgg, FCNL 2.6289 lbo 8~,8125 GR .2500 MRAT -999,2500 FCNL 83: 5 OR -999,2500 NRAT -999o~.500 IrCNL, 2.2910 ThO 7.600,0000 SFLU 32.1250 GR -999.2500 DRHO -~99.2500 N'CNL. 7500.0000 -32,2500 GR -999 2500 DRHO -q99~2500 NCNb '7400 0000 SrLU -32:~250 GR -999 °2500 DRHO -999,~500 NCNb 7300.0000 SFI. U -999.2500 -99q,2500 3 -' i00 -ggg -999 ,,,9' 2,8203 .~$O0 '999,:2'500 2 -9gg { 8027 '999i25'00 -999 2500 -gg9 2500 2,4785 '999.2500 '999,2500 '999.2500 2.3340 ~999~$00 -gg9. 500 -999.2500 2 4524 RNRA ,At l RN~A ! bM NRA RNRA ALI 'RNRA ~NRA Ib~ ClhI RNRA CALl RNRA ~ALX RN~A CALX RNRA -999,2500 ,gOO '2500 ,2500 .,-99 , )0 999, 2,957~ ,6563 -99},2500 -'999,2500 I'i623 O0 -999, ~00 -999, -999,2500 -999,2500 -999,2500 2.2207 LVP 010.W02 VERIFICA?ION LISTING PAOE 6 SP RHOB NPH! OEP? SP R H OB NpH! S:P O' RH ~ ~PH ! HOB pHI RHO:B ~PHI RHOB NpH! SP RHOB NpH! SP RHOB NPHI SP RHOB NpHI -32.6250 :999,2500 999.5500 72~0,0000 -'99~,~500 ~'999,~50'0 i~00 0000 '3tSO00 999 2500 oo.ooo . 3~"437 999,.2500 6900,0000 -999,~500 -999.2500 680:0.0000 ~38,~500 '999,2'500 -999.2500 6700,0000 999 500 6~00.0000 .937,7500 .699.25O0 ~99.~500 6~,00 0000 -37!4375 -999 2500 -99~.2500 6400 0000 -999.2500 37 3125 999 2500 -~9~.2500 ~R DRHO ~C~L SFLU DRHO ~C~6 :FLU R DRHO DRHO SFLU ~R DRHO NCNb GR DRHO SFLU GR ORHO NCNb OR DRHO NCNb SFLU G~ DRHO 500 ~RAT -999, :500 rCNb -999, FCN6 2,4375 ~00'5000 OR -999,2500 NRAT -999,~500 -999,2500 FCNL ,4375 OR · ,2500 NRAT -99 .2500 FCNL 3,4219 ~6D 104,8125- OR -999,2500 NRAT -999,,~500 FCNL 3 1797 9e,':25oo -999,2500 NRAT -999,.2500 FCNL 3 1, 074 '999' 75 OR · . ,, O0 NRa/' -999,2500 F'CNL 2,7559 I,bD 10B.0000 GR -999,2500 NRAT -999,2500 ?CN6 2 7148 IbD , 105,8750 GR '999°2500 NRAT '999,~500 ~CNL -999.,~500 CAb! -999. 560 RNRA -999.2500 2.2422 -999,2500 CALl '999.2500 RNRA -999.2500 -999 -999 -999 -999 RNRA ,2500 CALI :999'25.00 RNRA 099,2500 =999.2500 CALl ~999,~500 RNRA -999.,~500 -999~250~ CALl -999 O0 "NRA CALl ~,9434 -99 .2500 CALl -999.2500 RNRA '999.2500 2,9805 '999,2500 CALl -999.2500 RNRA -999.2500 -9~ )0 -99~ 0 -999 0 0762 3,5449 , O0 . 3 .999, O0 oo ,4805 -99~,2500 -999.2500 3,3574 -999,2500 -999,2500 2,~88 -999, 50~ -999.2500 2.9570 -99~,2500 -999.2500 LVP 010,HO~ VERIFICATION LISTING PAGE 7 RHOB DEPT RHOB EH, OB RPHI, EPT DEPT ~P RHO, B RHOB DEPT SP RHOB ~PHI ~P RHOB NPHI DEPT i0 ,0000 AFLU 3~,0625 GR 99~,2500 DRffO 99..2500 NCNb 6100 0000 S[LU -37 5625 (i -990 2500 DRHO -999 2500 NCNb '999 . ~CN5 5900 OOi, O SFLU o° ..99, -999,2500 5800,0000 S'F't,U '41,.8125 GR -99~,~500 DRHO -999.2500 MC~1L 5700 ,~000 !' 625 GR -99 56.00. 0000 SFI,,O 43,1250 (IR -999,1~00 DR.O '999, O0 NCNb 5500.0000 SFLU -44.5625 GR -999.2500 DRHO -999-,2500 ~CN~ 5~00,0000 SFbU 45.2500 OR -999,2500 DRHO -999.2500 NCNb 5]00 0000 SFLU - 9,. O0 DEMO -999,2500 NCNb 5200 0000 SFLU -42'. 125 '999,2500 DEMO .-99q.~500 NCNb ~..1387 96, .~500 '999, ~CN 2,2461 ILD ~ 6,5000 GR ...i}~9,2500 ~EAt -99q,,2500 FCNL ,[ 74 r) 1 , 75 -999, ~'500 Iq'RAT .-.999.2500 FC~b 2.~223, 900. ~Ou NRAT .25:00 FCNb 4.09'/7 IbD 92 ,.~500 '999,2500 IqRAT -999.2500 FCNL 2.5098 [~D 96.5625 ~ -9999~.2500 NR~,T - .,2500 FCNL 2.:7832 .~93,.3750 GR I' ..999,2500 NRg .999.2500 FCNL 3 2227 lbo 92'.2500 (IR -999,2500 NEAT -999..2500 FCNb 6.3750 let') ,3125 R 98~ ~' 9_.2500 NR,~,T ~99q,2500 FCNb 2i~738 IbD 100 500 (IR -99~ 500 NEAT -999 500 FCNb ~.4434 -999..2/00 - ~.~: 0 - .2500 2 6758 -999, -999, O0 3 324~ -999.2500 °999° : -999, ,999,25 9 9 O0 · O0 2,8066 -999,2500 "999, $00 3,3984 -999,2500 -999,2500 -99~.2500 5,6680 -999,~500 -999,2500 2o8164 -999.2500 -999,2500 -999.~500 CALl RN~A RCNRA CALl RNRA RNRA {'bM' CALl RNRA C A L I RNRA CALl RNRA CALl R NRA IbM CALl RNRA CAt, I RNRA IbM CALl RNRA 999,2500 2500 -999,2500 -997, r -g99. -999'.2500 4,!094 .-.999. 50o 999,2500 -999,2500 2,7324 -999,2500 -999,2500 3,4707 -999,2500 -999,2500 5,B203 -999,2500 -999.2500 2,662t '999,2500 -999,2500 3 DEPT 5100.0000 SF[,U RHOB -999,.~500 DRHO NPHI -999,~500 NCNb 41,6250 OR RHOB -999,2500 DRHQ NPHI -99g,~500 NCNb DEPT 4900..0000 SFhU -999,2500 DRHO NpH! "999'2500 NCNL ~EPT 4~00.0000 SFLU SP . 44,0000 GR RHOB ~999'2500 DRHO NpH! 999,2500 ~CNL ~EPT 4100.0000 S,FLO SP, ..45.9375 ~ RHOB ~999,2500 HO NPHI 999,~500 NCNL DEPT 4600.0000 SFLU SP .,28,2500 OR RHOB -999,2500 DRHO ~PHI -999.2500 MCNL HOB -999.2500 DRUO MPHI -999.~500 NCNb 6,..1836 93,3750 OR 999,1~'500 FCN~ . 95..~25 -999.250 rC~h 2,.6777 .989g,0000 .99q,2500 ~!RAT 8 ,0000 -99'9,'250.0 -999.~2,50'0 5.B828 88, GR 2000 00~ -999, 500 ~C~5 2000 0000 55,.~ OR "999.2500 ~C'Nh ** F~LE TRAILER FILE NA~E :~DTT ,001 SERVICE NAME DATE I MAXIMUM LENGTH ; 1024 FILE TYPF : NEXT FTLE NAME EOF ** TAPE TRAII...E~ SERVICE NAME {EDIT DATE 1~5/11/20 ORIGIN :FSiA TAPE NA~ 4.3281 ,,.g9 -999; 2:50:0 3 ,,:999 i00 ,,99.g .2891 ,:2500 -999,2500 -999,2500 2500 "999 "'5 0 12 8594 "999~,2500 - 9 . 5oo "999. 2500 Tbl~ CALl RNRA CALl RNRA CA:b! RNRA RNRA CAb ! RNRA IbM ALI RNRA CALl RNRA 999, , ,'99;, 0 ,,~99:, O0 3,1797 '999,2500 'g99.2500 {:6 4,8867 ' 2000,0000 -999,2500 -999.2500 ~O00,iO00 999, 500 -999. 500 'A~,.::,<:..~, Oil a '""" C<ms. ' .... .' ;,"<F,')n [~¥P Ol, O,H02 VERiFICA?ION I~,T$?I~,~G PAGE 9 ~I~. RE.EI,:~ TRAILER ~:$ SERVICE NAME :EDIT ORiG~N : NEX~: RE:Et, .. ~A~ ~ 1 CO~'~EN~S..