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Home My WebLink About186-0401. 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 9315'feet None feet true vertical 6478' feet 8775'feet Effective Depth measured 9010'feet 8009', 8682', 8766', 8863' feet true vertical 6255'feet 5543', 6016', 6078', 6148' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)2-7/8" 2-7/8" 2-7/8" L-80 L-80 J-55 8728' 8838' 8935' 6050' 6130' 6201' Packers and SSSV (type, measured and true vertical depth)8009' 8682' 8766' 8863' 5543' 6016' 6078' 6148' 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: 4639'3289' Burst Collapse Production 9270' Casing 6463'9294' 4608' 110'Conductor Surface 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-040 50-029-21550-00-00 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: ADL00256631, ADL0025521 Kuparuk River Field/ Kuparuk Oil Pool KRU 3I-08 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 110' Not Online 325-187 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 Packer: SLB Blue Pack Packer: Baker FH Packer: CAMCO RHP-1-SP SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742RWO Engineer 9008-9028', 9018-9019', 9026-9027', 9040-9089' 6254-6269', 6261-6262', 6267-6268', 6277-6311' 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 11:04 am, Jun 02, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.06.02 10:02:03-08'00' Elliott Tuttle DSR-6/3/25 RBDMS JSB 061225 JJL 6/13/25 Page 1/8 3I-08 Report Printed: 5/30/2025 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) 5/5/2025 20:00 5/5/2025 22:00 2.00 MIRU, MOVE RURD P LD derrick and complete rig move checklist. 0.0 0.0 5/5/2025 22:00 5/6/2025 00:00 2.00 MIRU, MOVE WAIT T Wait on roads and pads to clear road and shoulder. Wind in blowing 40 mph with gusts to 55 MPH. 0.0 0.0 5/6/2025 00:00 5/6/2025 14:00 14.00 MIRU, MOVE WAIT T Wait on roads and pads to clear road and shoulder. Wind in blowing 40 mph with gusts to 55 MPH. Load pipe tubs, matting boards, and other equipment on to trailers. 0.0 0.0 5/6/2025 14:00 5/6/2025 15:00 1.00 MIRU, MOVE MOB P Move office F/ 3A to 3I. Move ancilary equipment to next location. Install jeep onto pits, and hook up to sow. 0.0 0.0 5/6/2025 15:00 5/6/2025 16:30 1.50 MIRU, MOVE MOB P Move sub, and pits F/ 3A to 3I. 0.0 0.0 5/6/2025 16:30 5/6/2025 17:30 1.00 MIRU, MOVE MOB P Turn sub into the wind, and raise derrick. Lay hercultie, and plywood around 3I-08. 0.0 0.0 5/6/2025 17:30 5/6/2025 18:30 1.00 MIRU, MOVE MOB P Spot sub over 3I-08. 0.0 0.0 5/6/2025 18:30 5/6/2025 19:30 1.00 MIRU, MOVE MOB P Set mats under sub, and shim. Spot in mud pits. 0.0 0.0 5/6/2025 19:30 5/6/2025 22:00 2.50 MIRU, MOVE MOB P Bridal down blocks. R/U Internconnect between mud pits, and sub. Set berming around the sub, and pits. Lower stairs, and complete rig acceptance check list. 0.0 0.0 5/6/2025 22:00 5/7/2025 00:00 2.00 MIRU, WELCTL KLWL P Take on seawater to pits. Rig Accept at 22:00. 0.0 0.0 5/7/2025 00:00 5/7/2025 02:00 2.00 MIRU, WELCTL KLWL P Take on seawater to pits. Build deep clean pill. 0.0 0.0 5/7/2025 02:00 5/7/2025 05:30 3.50 MIRU, WELCTL CIRC P Pump deep clean pill followed by seawater at 3 BPM/570 psi. 0.0 0.0 5/7/2025 05:30 5/7/2025 06:00 0.50 MIRU, WELCTL OWFF P Flow check well for 30 min in the cellar. . 0.0 0.0 5/7/2025 06:00 5/7/2025 06:30 0.50 MIRU, WELCTL OTHR P Blow down tiger tank lines. P/U T-bar, and pull tree cap. Drain tree. 0.0 0.0 5/7/2025 06:30 5/7/2025 07:30 1.00 MIRU, WHDBOP MPSP P Set BPV, and test from below to 1000 psi for 10 min: Good test. 0.0 0.0 5/7/2025 07:30 5/7/2025 09:00 1.50 MIRU, WHDBOP NUND P N/D tree and adptor flange, inspect adaptor flange for re-use. Function all lock down screws on the tubing spool. Install test dart. 0.0 0.0 5/7/2025 09:00 5/7/2025 10:30 1.50 MIRU, WHDBOP NUND P N/U BOP. C/O IBOP on top drive. 0.0 0.0 5/7/2025 10:30 5/7/2025 15:00 4.50 MIRU, WHDBOP OTHR P Rig crew perform between wells maintenance of BOPs. Start to build test joints offline. 0.0 0.0 5/7/2025 15:00 5/7/2025 16:00 1.00 MIRU, WHDBOP RURD P R/U test equipment, and fill and flush lines. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 2/8 3I-08 Report Printed: 5/30/2025 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) 5/7/2025 16:00 5/7/2025 22:00 6.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular to 3500PSI on 2-7/8" and 3-1/2" test joint, UVBR's, LVBR's w/2-7/8" and 3-1/2" test joint. Test #1) Blind Rams, CMV 1-2-3-16, RIg Floor Kill, Outer Test Spool Valve, IBOP. Test #2) Blind Rams, CMV 4-5-6, HCR Kill, Inner Test Spool Valve, Manual IBOP. PU 3.5" Donut Test Joint w/HT-38 TIW Test #3) LPR, HT-38 TIW & Dart. Test #4) Annular (3,500 psi), CMV 7-8- 9, Manual Kill, Test #5) Hydraulic Super Choke and Manual Adjustable Choke (1,500 PSI Test). Test #6) UPR, CMV 10-11 PU 2-7/8" Donut Test Joint w/3.5" EUE FOSV, Test #7) Lower Rams Test #8 Annular (3.500 psi), CMV 12-13- 15, 3.5" FOSV. Test #9) UPR, CMV 14. Test #10) HCR Choke. Test #11) Manual Choke. Hydraulic accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =17 sec, Full recovery attained = 235 sec. UVBR's= 5 sec, Annular= 25 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2150 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan. 0.0 0.0 5/7/2025 22:00 5/8/2025 00:00 2.00 COMPZN, RPCOMP THGR P Pull BPV, MU spear and pull 2-7/8" hanger free at 72K over block weight. RU tbg tongs and handling equipment. Flow check well, no flow. 0.0 0.0 5/8/2025 00:00 5/8/2025 08:30 8.50 COMPZN, RPCOMP PUTB P POOH LD 2-7/8" completion F/ Pre rig cut @ 8724 (ORKB) to surface. Recovered 271 full joints, 1 cut joint (12.77'), 6 GLMs w/ pup joints, and one x-nipple with pup joints. 8,724.0 0.0 5/8/2025 08:30 5/8/2025 09:00 0.50 COMPZN, WELLPR OTHR P Clean and clear rig floor. R/U test equipment. Flush kill line. 0.0 0.0 5/8/2025 09:00 5/8/2025 09:30 0.50 COMPZN, WELLPR PRTS P Close blind rams and attempt to test 7" CSG to 2500 PSI: Observe pressure "break over" @ 2200 PSI. Continue to pump to 2400 PSI. OA pressure started @ 250 PSI and increased to 480 PSI while brining up the pressure in the IA. Shut in and allow pressure to stabilize, pressure in IA dropped and started to stabilize @ 1100 PSI, OA pressure dropped F/ 480 PSI to 450 PSI while allowing IA pressure to stabilize. Bled off pressure in IA to 0 PSI. OA pressure bled to 280 PSI. 0.0 0.0 5/8/2025 09:30 5/8/2025 10:00 0.50 COMPZN, WELLPR OTHR P Blow down choke and kill lines, install wear bushing. 0.0 0.0 5/8/2025 10:00 5/8/2025 11:00 1.00 COMPZN, WELLPR BHAH P P/U BHA # 2, Dress off BHA F/ Surface to 233' 0.0 233.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 3/8 3I-08 Report Printed: 5/30/2025 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) 5/8/2025 11:00 5/8/2025 17:00 6.00 COMPZN, WELLPR PULD P RIH Picking up drill pipe F/ 233' T/7800' UWT 137K. SOW 100K 233.0 7,800.0 5/8/2025 17:00 5/8/2025 18:00 1.00 COMPZN, WELLPR SLPC P Slip and cut 68' drill line. 7,800.0 7,800.0 5/8/2025 18:00 5/8/2025 18:30 0.50 COMPZN, WELLPR SVRG P Grease top drive, blackjack, draw works, iron rough neck and crown. 7,800.0 7,800.0 5/8/2025 18:30 5/8/2025 20:00 1.50 COMPZN, WELLPR PULD P PU DP from and ream F/7992' T/8087'. Ream F/ 8623' T8718' 7,800.0 8,718.0 5/8/2025 20:00 5/8/2025 20:30 0.50 COMPZN, WELLPR MILL P Verify top of tubing stub at 8722', mill F/8722' T/8723' UWT 150K, SOW 105K, ROTW 127K. Torq 5.6K to 8K at 100 rpm. 8,718.0 8,723.0 5/8/2025 20:30 5/8/2025 21:30 1.00 COMPZN, WELLPR CIRC P Pump 40 bbl hi vis sweep and circ SxS. Flow check well: no flow 8,723.0 8,723.0 5/8/2025 21:30 5/9/2025 00:00 2.50 COMPZN, WELLPR TRIP P Trip DP out of hole standing back DP in derrick. F/8723 T/5000' 8,723.0 5,000.0 5/9/2025 00:00 5/9/2025 02:00 2.00 COMPZN, WELLPR TRIP P Trip DP out of hole standing back DP in derrick. F/5000' T/234' 5,000.0 234.0 5/9/2025 02:00 5/9/2025 03:00 1.00 COMPZN, WELLPR BHAH P LD BHA #2 (6 drill collars and 6-1/8" milling assy.)F/234' T/surface 234.0 0.0 5/9/2025 03:00 5/9/2025 09:00 6.00 COMPZN, WELLPR ELOG P RU SLB E-line with Reed 40 arm caliper log. RIH and log from tubing stub up @ 8723' to 4600'. SLB E-line POOH F/ 4600' to surface. Rig crew load and strap 2 7/8" EUE tubing. 0.0 0.0 5/9/2025 09:00 5/9/2025 09:30 0.50 COMPZN, WELLPR ELOG P SLB E-line and Read L/D logging tools. R/D SLB E-line. 0.0 0.0 5/9/2025 09:30 5/9/2025 10:00 0.50 COMPZN, WELLPR BHAH P P/U Test packer BHA. 0.0 15.0 5/9/2025 10:00 5/9/2025 10:15 0.25 COMPZN, WELLPR TRIP P RIH w/ Test packer F/ 15' to 587'' 15.0 587.0 5/9/2025 10:15 5/9/2025 11:00 0.75 COMPZN, WELLPR MPSP P Space out and set test packer @ 587'. Purge lines, close upper pipe rams and test above test packer to 2500 PSI and hold for 5 min: GOOD TEST. Release test packer. 587.0 587.0 5/9/2025 11:00 5/9/2025 13:30 2.50 COMPZN, WELLPR TRIP P Cont. to RIH w/ Test packer F/ 587' to 8665'. PUWT: 142 K SOWT: 105 K 587.0 8,665.0 5/9/2025 13:30 5/9/2025 13:45 0.25 COMPZN, WELLPR CIRC P Circulate string volume @ 4 BBL/Min @ 550 PSI. 8,665.0 8,665.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 4/8 3I-08 Report Printed: 5/30/2025 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) 5/9/2025 13:45 5/9/2025 15:45 2.00 COMPZN, WELLPR MPSP T Set test packer @ 8662' COE. Set down 20K R/U to test and fill lines. Pressure up to 1100 PSI Pressure no longer building. Observe flow down the flow line. Bleed pressure set down 40K Pressure built to 2500 PSI, and fell off, flow observed down the flow line. Set down 50K on test packer and attempt to test, similar result. Bleed pressure and P/U to attempt to overpull on packer, packer moved freely. Go through steps to fully release, and then set test packer. Set down 40K and rig up test lines. Attempt to test to 2500 PSI. Unable to get pressure to hold. Release test packer and set lower @ 8672'. Attemtp to test bellow, stage up pressure in 500 PSI incraments, at 1000 PSI observed flow up the annulus. Shut BOPs and pressure test from above to 1000 PSI (same test as BPV test). With drill pipe shut observed pressure stabilize. 8,665.0 8,672.0 5/9/2025 15:45 5/9/2025 16:30 0.75 COMPZN, WELLPR MPSP T Attempt to release test packer, test packer would not release trouble shoot until test packer released. 8,672.0 8,700.0 5/9/2025 16:30 5/9/2025 21:30 5.00 COMPZN, WELLPR MPSP T Set test packer at 8700' COE and PT from below. Failed PT and observed flow up annulus. At 8030' COE PT annulus above test packer. Failed test and observed fluid returning up drill pipe. Conclude test packer failed. 8,700.0 8,030.0 5/9/2025 21:30 5/10/2025 00:00 2.50 COMPZN, WELLPR TRIP T TOOH F/8030 T/3300' 8,030.0 3,300.0 5/10/2025 00:00 5/10/2025 00:45 0.75 COMPZN, WELLPR TRIP T TOOH F/3300' T/950' 3,300.0 950.0 5/10/2025 00:45 5/10/2025 01:00 0.25 COMPZN, WELLPR MPSP T Tried to set Test packer at 950' and it would not set. 950.0 956.0 5/10/2025 01:00 5/10/2025 02:00 1.00 COMPZN, WELLPR TRIP T TOOH F/956 to surface. 956.0 0.0 5/10/2025 02:00 5/10/2025 02:30 0.50 COMPZN, WELLPR BHAH T MU new test packer. 0.0 20.0 5/10/2025 02:30 5/10/2025 03:00 0.50 COMPZN, WELLPR TRIP T TIH F/20' T/953' 20.0 953.0 5/10/2025 03:00 5/10/2025 04:15 1.25 COMPZN, WELLPR MPSP T Shallow test packer at 953'. Having trouble getting it to set. Unable to get a test on the test packer. 953.0 953.0 5/10/2025 04:15 5/10/2025 05:00 0.75 COMPZN, WELLPR TRIP T Trip out of the hole and remove unloader from test packer. 953.0 0.0 5/10/2025 05:00 5/10/2025 05:30 0.50 COMPZN, WELLPR TRIP T RIH F/ Surface to 955' w/ YJOS test packer. 0.0 955.0 5/10/2025 05:30 5/10/2025 06:00 0.50 COMPZN, WELLPR MPSP T Set test packer at 955' and test to 2500 PSI from above: GOOD. Bleed pressure and release test packer. 955.0 955.0 5/10/2025 06:00 5/10/2025 09:30 3.50 COMPZN, WELLPR TRIP T RIH F/ 955' to 8664' @ 90 ft/min PUWT: 142 k SOWT: 105 k 955.0 8,664.0 5/10/2025 09:30 5/10/2025 10:00 0.50 COMPZN, WELLPR SVRG T Rig service grease crown, blocks, draw works, and rig floor equipment. 8,664.0 8,664.0 5/10/2025 10:00 5/10/2025 10:30 0.50 COMPZN, WELLPR CIRC T Circulate string volume @ 4 BBL/MIN @ 540 PSI. 8,664.0 8,664.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 5/8 3I-08 Report Printed: 5/30/2025 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) 5/10/2025 10:30 5/10/2025 11:00 0.50 COMPZN, WELLPR T Set test packer @ 8665' COE. Line up and attempt to test below test packer to 2500 PSI. Observe flow up the annulus. Trouble shoot, and attempt 2 more times. Bleed pressre rig down test equipment, and release test packer. 8,664.0 8,665.0 5/10/2025 11:00 5/10/2025 12:00 1.00 COMPZN, WELLPR TRIP T POOH F/ 8665' to 8030' 8,665.0 8,030.0 5/10/2025 12:00 5/10/2025 13:00 1.00 COMPZN, WELLPR PRTS T Set test packer @ 8026'. Rig up and test from above to 2500 PSI. Observe flow coming up drill pipe as pressure dropped off. Consult town on plan forward. Bleed remaining pressure, and release test packer. 8,030.0 8,026.0 5/10/2025 13:00 5/10/2025 13:30 0.50 COMPZN, WELLPR TRIP T POOH F/ 8026' to 7086'. 8,026.0 7,086.0 5/10/2025 13:30 5/10/2025 15:00 1.50 COMPZN, WELLPR PRTS T Set test packer @ 7086' and attempt to test above test packer. Observe flow up drill pipe. Bleed pressure, and release test packer. Release test packer. Repeat above steps @ 6150', 5204', & 4626'. Flow up drill pipe reduced, but did not stop, and pressure continued to drop. 7,086.0 4,626.0 5/10/2025 15:00 5/10/2025 16:30 1.50 COMPZN, WELLPR TRIP T POOH F/ 4626' to 942' 4,626.0 942.0 5/10/2025 16:30 5/10/2025 17:00 0.50 COMPZN, WELLPR MPSP T Set test packer @ 942'. and test from above to 2500 PSI. GOOD TEST. 942.0 942.0 5/10/2025 17:00 5/10/2025 17:30 0.50 COMPZN, WELLPR TRIP T POOH F/ 942' to surface w/ test packer. UWT 45K 942.0 0.0 5/10/2025 17:30 5/10/2025 18:00 0.50 COMPZN, WELLPR BHAH T Inspect & L/D Yellow Jacket test packer. 0.0 0.0 5/10/2025 18:00 5/10/2025 18:30 0.50 COMPZN, WELLPR BHAH T PU and MU Baker test packer. 0.0 0.0 5/10/2025 18:30 5/10/2025 19:00 0.50 COMPZN, WELLPR TRIP T RIH to 955' 0.0 955.0 5/10/2025 19:00 5/10/2025 19:30 0.50 COMPZN, WELLPR MPSP T PT above the test packer to 2500 psi for charted 5 min. Good test. 955.0 955.0 5/10/2025 19:30 5/10/2025 23:30 4.00 COMPZN, WELLPR TRIP T TIH F/955 T/8665' restricted to 90 fpm per Baker rep. 955.0 8,666.0 5/10/2025 23:30 5/11/2025 00:00 0.50 COMPZN, WELLPR MPSP T Set Baker test packer at 8,666' and pressure test 2,500 psi down drill pipe up under test packer. Bled off instantly and saw returns up annulus. Call town and make descision to POOH to 8,030' and test down back side above test packer. 8,666.0 8,666.0 5/11/2025 00:00 5/11/2025 01:00 1.00 COMPZN, WELLPR TRIP T POOH to 8,030' to test above test packer. 8,666.0 8,030.0 5/11/2025 01:00 5/11/2025 02:00 1.00 COMPZN, WELLPR MPSP T Set Baker packer at 8,030' and PT to 2500 psi down annulus above test packer. Failed test. Flow observed up drill string. 8,030.0 8,030.0 5/11/2025 02:00 5/11/2025 03:00 1.00 COMPZN, WELLPR MPSP T Pull packer up to 7449', set test packer and attempt to test from above: FAIL. Continue to pull up and retest above test packer @ 6913'. Pressure test for 5 min. Appeared to be good test. 8,030.0 6,913.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 6/8 3I-08 Report Printed: 5/30/2025 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) 5/11/2025 03:00 5/11/2025 06:00 3.00 COMPZN, WELLPR MPSP T RIH w/ Test packer to 7132', attepmt to pressure test above test packer to 2500 PSI: Failed pressure test. Pull up hole laying out joints of drill pipe testing after each joint to 6193'. Unable to get passing test, discovered 3 washed joints while laying down singe.s 6,913.0 6,913.0 5/11/2025 06:00 5/11/2025 12:00 6.00 COMPZN, WELLPR MPSP T POOH w/ test packer setting and testing every 5 stands. Test from above to 2500 PSI and failed @ 6823', 6350', 5878', 5405', 4932', 4458', 3985', 3512', 3039'. Pull test packer up to 2557' and test to 2500 PSI from above GOOD TEST. Hold pressure for 30 min to confirm. Discuss results w/ town. Mobilize 2 7/8" HT PAC work string to the rig. 6,913.0 2,557.0 5/11/2025 12:00 5/11/2025 13:00 1.00 COMPZN, WELLPR TRIP T POOH w/ test packer F/ 2557' to surface. 2,557.0 0.0 5/11/2025 13:00 5/11/2025 13:30 0.50 COMPZN, WELLPR BHAH T Inspect test packer. Wear on elements of test packer. L/D test packer, and send back to Baker for redress. 0.0 0.0 5/11/2025 13:30 5/12/2025 00:00 10.50 COMPZN, WELLPR TRIP T RIH w/ Drill pipe 10 stands at a time and pressure test DP to 2500 psi for 5 minutes looking for leaks while waiting on Baker test packer and PESI 2-7/8" HT Pac drill pipe to show up. A total of 86 stands tested good. There are 72 stands stood back on drillers side and 14 stands on off drillers side to make an "L" for standing back 2-7/8" DP. At the same time 290 joints of 2-7/8" HT pac DP was loaded and tallied in the pipe shed. 0.0 0.0 5/12/2025 00:00 5/12/2025 01:00 1.00 COMPZN, WELLPR TRIP T RIH w/ Drill pipe 10 stands at a time and pressure test DP to 2500 psi for 5 minutes looking for leaks while waiting on Baker test packer and PESI 2-7/8" HT Pac drill pipe to show up. A total of 86 stands tested good. There are 72 stands stood back on drillers side and 14 stands on off drillers side to make an "L" for standing back 2-7/8" DP. At the same time 290 joints of 2-7/8" HT pac DP was loaded and tallied in the pipe shed. 0.0 0.0 5/12/2025 01:00 5/12/2025 02:00 1.00 COMPZN, WELLPR RURD T C/O handling equipment to run 2-7/8". RU tubing tongs. 0.0 0.0 5/12/2025 02:00 5/12/2025 03:00 1.00 COMPZN, WELLPR BHAH T MU Baker test packer BHA #6 with XO to 2-7/8" HT Pac pipe. 0.0 0.0 5/12/2025 03:00 5/12/2025 10:30 7.50 COMPZN, WELLPR PULD T RIH P/U singles of 2 7/8" HT PAC drill pipe from surface to 6889'. PUWT: 85K SOWT: 65K 0.0 6,889.0 5/12/2025 10:30 5/12/2025 11:00 0.50 COMPZN, WELLPR PRTS T Set test packer @ 6889 COE. Rig up, and purge lines. Close upper pipe rams and pressure test F/ 6889' to surface to 2500 PSI: GOOD TEST hold for 30 min. Release test packer. 6,889.0 68,889.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 7/8 3I-08 Report Printed: 5/30/2025 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) 5/12/2025 11:00 5/12/2025 12:30 1.50 COMPZN, WELLPR PULD T Cont. to P/U 2 7/8" HT PAC drill pipe F/ 6889 to 8678'. PUWT: 100K SOWT: 75K 6,889.0 8,678.0 5/12/2025 12:30 5/12/2025 13:00 0.50 COMPZN, WELLPR PRTS T Circulate 60 BBLS down the drill string @ 2 BBL/Min @ 600 PSI. 8,678.0 8,678.0 5/12/2025 13:00 5/12/2025 16:30 3.50 COMPZN, WELLPR PRTS T Set test packer @ 8665' and attempt to test bellow to 2500 PSI. NO TEST. Consult town on plan forward. Release test packer and move down to 8673' set test packer. R/U and test bellow test packer to 2500 PSI. Make several attempts. Send final charts to town for approval. Town approved charts. 8,678.0 8,673.0 5/12/2025 16:30 5/12/2025 17:00 0.50 COMPZN, WELLPR OTHR P R/U rope for 2 7/8" HT PAC pipe in the derrick. R/D test equipment. 8,673.0 8,673.0 5/12/2025 17:00 5/12/2025 17:30 0.50 COMPZN, WELLPR TRIP P POOH F/ 8673' to 8030' 8,673.0 8,030.0 5/12/2025 17:30 5/12/2025 19:00 1.50 COMPZN, WELLPR PRTS P Set test packer @ 8030' COE and test 2500 psi from above. Good 30 minute charted test. Sent charts to town and placed in Maxwell folder. Release packer and blow down test lines. 8,030.0 8,030.0 5/12/2025 19:00 5/12/2025 23:30 4.50 COMPZN, WELLPR PULD P POOH LD 2-7/8" DP to pipe shed F/8030' T/2900'. UWT 50K DWT 45K. 8,030.0 2,900.0 5/12/2025 23:30 5/13/2025 00:00 0.50 COMPZN, WELLPR SVRG P Service rig. Grease all rig floor equipment. 2,900.0 2,900.0 5/13/2025 00:00 5/13/2025 03:00 3.00 COMPZN, WELLPR PULD P LD 2-7/8" DP from 2900' to 11' UWT 50K/ DWT 45K 2,900.0 11.0 5/13/2025 03:00 5/13/2025 03:30 0.50 COMPZN, WELLPR BHAH P LD Baker test Packer BHA. 11.0 0.0 5/13/2025 03:30 5/13/2025 04:15 0.75 COMPZN, WELLPR TRIP P Trip in the hole with 7 stands of 2-7/8" DP out of derrick. 0.0 651.0 5/13/2025 04:15 5/13/2025 05:15 1.00 COMPZN, WELLPR PULD P LD 21 jts of 2-7/8" sideways. 651.0 0.0 5/13/2025 05:15 5/13/2025 08:30 3.25 COMPZN, WELLPR TRIP T Trip in the hole with 3-1/2" DP out of derrick. 0.0 8,100.0 5/13/2025 08:30 5/13/2025 13:30 5.00 COMPZN, WELLPR PULD P POOH L/D 3 1/2" Drill pipe. 8,100.0 0.0 5/13/2025 13:30 5/13/2025 14:30 1.00 COMPZN, WELLPR OTHR P M/U running tool BOLDS and pull wear bushing. Clean and clear rig floor. 0.0 0.0 5/13/2025 14:30 5/13/2025 15:00 0.50 COMPZN, WELLPR SVRG P Service pipe skate, and rig floor equipment. 0.0 0.0 5/13/2025 15:00 5/13/2025 16:00 1.00 COMPZN, WELLPR RURD P R/U to run upper completion on the rig floor. 0.0 0.0 5/13/2025 16:00 5/14/2025 00:00 8.00 COMPZN, WELLPR PUTB P PJSM w/ Crew pick up and RIH w/ 2 7/8" EUE 6.5# upper completion from surface to 4300' PUW=48K SOW=45K 0.0 4,300.0 5/14/2025 00:00 5/14/2025 06:30 6.50 COMPZN, WELLPR PUTB P RIH W/2-7/8" EUE completion F/4300' T/8736' PUWT: 75 K SOWT: 58 K 4,300.0 8,736.0 5/14/2025 06:30 5/14/2025 08:00 1.50 COMPZN, WELLPR PUTB P Cont. slack off to 8736', observe shear screws shear @ 15K down @ 8736'. Cont. to slack off to 8740' w/ 10K down. P/U and space out. 8,736.0 8,736.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Page 8/8 3I-08 Report Printed: 5/30/2025 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) 5/14/2025 08:00 5/14/2025 11:00 3.00 COMPZN, WELLPR CIRC P Reverse circulate in corrosion inhibited sea water @ 2.5 BBL/ Min @ 475 PSI. 8,711.0 8,711.0 5/14/2025 11:00 5/14/2025 12:00 1.00 COMPZN, WELLPR THGR P Drain stack, and land hanger RILDS. Drop ball and rod, and allow to fall for 15 min. 8,711.0 8,736.5 5/14/2025 12:00 5/14/2025 12:45 0.75 COMPZN, WELLPR PACK P Line up on tubing, and pressure up to 3500 PSI to set packer. Observe "soft shear" of packers @ 1800 PSI. Cont. to increase pressure to 3500 PSI, and hold for 30 min: GOOD TEST. 8,736.5 8,736.5 5/14/2025 12:45 5/14/2025 13:30 0.75 COMPZN, WELLPR PRTS P Bleed tubing pressure to 1500 PSI, line up on annulus, pressure up to 2500 PSI for 30 min: GOOD TEST. line up on tubing, and bleed pressure, observe SOV shear, and IA pressure bleed. Bleed both pressures to 0 PSI. 8,736.5 0.0 5/14/2025 13:30 5/14/2025 14:00 0.50 COMPZN, WELLPR MPSP P Set BPV, and test from bellow to 1000 PSI for 10 min: GOOD TEST. 0.0 0.0 5/14/2025 14:00 5/14/2025 16:30 2.50 COMPZN, WHDBOP NUND P N/D BOP, N/U Tree and adaptor flange. 0.0 0.0 5/14/2025 16:30 5/14/2025 17:00 0.50 COMPZN, WHDBOP PRTS P Cameron rep pressure test hangerneck void to 5000 PSI: GOOD. Fill tree w/ Diesel, and pressure test to 5000 PSI: GOOD. 0.0 0.0 5/14/2025 17:00 5/14/2025 20:00 3.00 COMPZN, WHDBOP FRZP P Pump 70 BBL's diesel down IA taking returns up the tubing 2BPM at 600 PSI. 0.0 0.0 5/14/2025 20:00 5/15/2025 00:00 4.00 DEMOB, MOVE DMOB P Demob rig, hang bridle lines in derrick, pick up berming around rig, pull flow line, prep rig to move to 3R-18. NES called at 930 PM arrived on location at 1130 PM requested 1200 PM arrival Laid derrick over at 1145 PM. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 5/15/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,010.0 3I-08 6/4/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install GLD, pull B&R, RHC, Catcher, RBP 3I-08 5/28/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: IA x OA COMMUNICATION 11/25/2011 hipshkf NOTE: View Schematic w/ Alaska Schematic9.0 7/21/2010 ninam 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 30.6 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 4,638.5 3,289.1 36.00 J-55 BTC PRODUCTION 7 6.28 23.7 9,294.4 6,462.7 26.00 J-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) -1.4 Set Depth … 8,728.2 String Max No… 2 7/8 Set Depth … 6,050.0 Tubing Description Tubing – Completion Upper Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 20.5 20.5 0.04 Hanger 6.930 Cameron Gen IV Tubing Hanger, 2 7/8" EUE Camero n Gen 4 2.485 3,599.9 2,777.4 62.83 Mandrel – GAS LIFT 5.506 2-7/8" x 1-1/2" MMG SN25343-03 SLB MMG 2.366 6,826.1 4,749.7 46.36 Mandrel – GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 076AG06 SLB MMG 2.366 7,949.5 5,502.3 46.69 Mandrel – GAS LIFT 5.424 2-7/8" x 1-1/2" MMG SN 089AG06 SLB MMG 2.366 8,008.7 5,543.0 46.62 Packer 5.906 2-7/8" x 7" SLB BluePack cut-to- release Packer SN C23P-1327 (above 8030") SLB BluePac k 2.373 8,681.5 6,016.3 43.91 Packer 5.904 2-7/8" x 7" SLB BluePack cut-to- release Packer SN C23P-1326 (below 8673') SLB BluePac k 2.373 8,700.7 6,030.2 43.83 Nipple - X 3.650 2-7/8" X Nipple 2.313" SN APF23G0264-89 Halliburt on 2.313" X 2.313 8,720.1 6,044.2 43.71 Overshot 5.900 2 7/8" TBG PBOS (swallow 4.14' to shear, swallow 4.56' @ 2.6' off tag) NS PBOS 2.995 Top (ftKB) 8,725.0 Set Depth … 8,837.9 String Max No… 2 7/8 Set Depth … 6,129.8 Tubing Description *COPY* TUBING WO Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-M ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,748.5 6,064.8 43.54 SEAL ASSY 3.240 BAKER SEAL ASSEMBLY LOCATOR 2.430 8,752.5 6,067.6 43.52 PBR 5.460 BAKER 80-32 POLISHED BORE RECEPTICLE 3.250 8,766.4 6,077.7 43.43 PACKER 5.970 BAKER FH PACKER 2.430 8,815.7 6,113.6 43.21 NIPPLE 3.250 HALLIBURTON X NIPPLE 2.312 8,831.4 6,125.0 43.18 OVERSHOT 6.010 BAKER POORBOY OVERSHOT 3.000 Top (ftKB) 8,838.0 Set Depth … 8,934.8 String Max No… 2 7/8 Set Depth … 6,200.6 Tubing Description TUBING Original Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,845.5 6,135.3 43.16 PBR 3.500 CAMCO OEJ-10 PBR 2.297 8,863.0 6,148.1 43.14 PACKER 7.000 CAMCO RHP-1-SP PACKER 2.875 8,902.1 6,176.7 43.08 NIPPLE 3.500 CAMCO D NIPPLE NO GO 2.250 8,934.1 6,200.1 43.11 SOS 2.875 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,200.0 5,675.1 45.92 LEAK - CASING PC leak at ~8200'. Found by temperature anomaly. 10/14/2019 6.280 8,775.0 6,084.0 43.38 FISH BOW-SPRING CENTALIZER METAL "BANDS" LIH POST CHEMICAL CUT (~5.5 AT 0.5" x 10") 4/12/2025 0.000 8,800.0 6,102.2 43.23 Tubing leak Tubing leak below upper stacker packer @ 8800' RKB. 7/28/2016 8,820.0 6,116.8 43.20 LEAK LEAK DETECTION LOG - LEAK FOUND AT 8820' IN THE FIRST JOINT BELOW GLM #8, 7/28/2007 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) 3,599.9 2,777.4 62.83 1 GAS LIFT GLV RK 1 1/2 1,227.0 5/21/2025 SLB 0.375 6,826.1 4,749.7 46.36 2 GAS LIFT GLV RK 1 1/2 1,245.0 5/21/2025 SLB 0.250 7,949.5 5,502.3 46.69 3 GAS LIFT OV RK 1 1/2 5/21/2025 SLB 0.250 3I-08, 5/30/2025 2:11:34 PM Vertical schematic (actual) PRODUCTION; 23.6-9,294.4 IPERF; 9,060.0-9,086.0 IPERF; 9,040.0-9,060.0 IPERF; 9,026.0-9,027.0 IPERF; 9,018.0-9,019.0 APERF; 9,008.0-9,028.0 PACKER; 8,863.0 Tubing leak; 8,800.0 FISH; 8,775.0 PACKER; 8,766.4 Nipple - X; 8,700.7 Packer; 8,681.5 LEAK - CASING; 8,200.0 Packer; 8,008.7 Mandrel – GAS LIFT; 7,949.5 Mandrel – GAS LIFT; 6,826.1 SURFACE; 30.6-4,638.5 Mandrel – GAS LIFT; 3,599.9 CONDUCTOR; 30.6-110.0 Hanger; 20.5 KUP PROD KB-Grd (ft) 36.49 RR Date 3/4/1986 Other Elev… 3I-08 ... TD Act Btm (ftKB) 9,315.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292155000 Wellbore Status PROD Max Angle & MD Incl (°) 62.83 MD (ftKB) 3,600.00 WELLNAME WELLBORE3I-08 Annotation Last WO: End Date 6/10/2011 H2S (ppm) 180 Date 5/19/2015 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,008.0 9,028.0 6,253.9 6,268.5 A-3, 3I-08 5/30/1997 4.0 APERF 2 1/8" EnerJet BH,180deg phase 9,018.0 9,019.0 6,261.2 6,262.0 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,026.0 9,027.0 6,267.1 6,267.8 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,040.0 9,060.0 6,277.3 6,291.8 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,060.0 9,086.0 6,291.8 6,310.8 A-3, 3I-08 5/24/1986 4.0 IPERF 4"CsgGun HJ II;90deg phase 3I-08, 5/30/2025 2:11:35 PM Vertical schematic (actual) PRODUCTION; 23.6-9,294.4 IPERF; 9,060.0-9,086.0 IPERF; 9,040.0-9,060.0 IPERF; 9,026.0-9,027.0 IPERF; 9,018.0-9,019.0 APERF; 9,008.0-9,028.0 PACKER; 8,863.0 Tubing leak; 8,800.0 FISH; 8,775.0 PACKER; 8,766.4 Nipple - X; 8,700.7 Packer; 8,681.5 LEAK - CASING; 8,200.0 Packer; 8,008.7 Mandrel – GAS LIFT; 7,949.5 Mandrel – GAS LIFT; 6,826.1 SURFACE; 30.6-4,638.5 Mandrel – GAS LIFT; 3,599.9 CONDUCTOR; 30.6-110.0 Hanger; 20.5 KUP PROD 3I-08 ... WELLNAME WELLBORE3I-08 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-09_21194_KRU_3I-08_Caliper Survey_Log Data_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21194 KRU 3I-08 50-029-21550-00 Caliper Survey w/ Log Data 09-May-25 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 186-040 T40409 5/15/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.15 08:04:32 -08'00' ORIGINATED TRANSMITTAL DATE: 4/21/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5392 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5392 3I-08 50029215500000 Tubing Cut Record 11-Apr-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Lorna.C.Collins@conocophillips.com Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 186-040 T40325 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:22:01 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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): 9315'2875 None 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: 907-263-4742 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 Elliott Tuttle elliott.tuttle@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 J-55 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6463' 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: 3289' Burst AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8766'MD/6078'TVD 8863'MD/6148'TVD 8838' 8935' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025631 186-040 P.O. Box 100360, Anchorage, AK 99510 50-029-21550-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 4/15/2025 2-7/8" 2-7/8" 110' 4639' KRU 3I-08 9008-9028' 9040-9086' 9270' 6254-6269' 6277-6311' 4608' 9294' Perforation Depth MD (ft): Baker FH packer Camco RHP-1-SP Packer SSSV: None 6478'9010'6255' 7" 16" 8780' 9-5/8" 79'110' 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 By Grace Christianson at 11:03 am, Apr 01, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.03.31 07:54:05-08'00' Elliott Tuttle 325-187 , ADL0025521 SFD 10-404 SFD 4/4/2025 X DSR-4/2/25 *AOGCC Witnessed BOP and Annular test to 3500 psi. *Biennial MIT-T w/ plug set below upper overshot at ~8722' RKB, Biennial IA DDT w/ fluid levels or MITIA *Pressure test both upper & lower proposed packers (lower packer can be tested post rig include in 10-404) Note: These conditions of approval may change to be in-line with the outcome of the 3M-19 request for reconsideration and docket OTH-25-016. JJL 4/8/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. 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JJL Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,010.0 6/4/2016 3I-08 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Annotated Tbg Leaks Identified w/ EL LDL 10/15/2019 3I-08 bworthi Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.6 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 30.6 Set Depth (ftKB) 4,638.5 Set Depth (TVD) … 3,289.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 23.7 Set Depth (ftKB) 9,294.4 Set Depth (TVD) … 6,462.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BUTT Tubing Strings Tubing Description TUBING WO String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 24.7 Set Depth (ft… 8,837.9 Set Depth (TVD) (… 6,129.8 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 24.7 24.7 0.04 HANGER FMC TUBING HANGER 2.347 507.5 507.4 2.16 NIPPLE CAMCO DS NIPPLE w/ 2.312' PROFILE 2.312 8,748.5 6,064.8 43.54 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 2.430 8,752.5 6,067.6 43.51 PBR BAKER 80-32 POLISHED BORE RECEPTICLE 3.250 8,766.4 6,077.7 43.43 PACKER BAKER FH PACKER 2.430 8,815.8 6,113.7 43.21 NIPPLE HALLIBURTON X NIPPLE 2.312 8,831.4 6,125.1 43.18 OVERSHOT BAKER POORBOY OVERSHOT 3.000 Tubing Description TUBING Original String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 8,838.0 Set Depth (ft… 8,934.8 Set Depth (TVD) (… 6,200.6 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,845.5 6,135.3 43.16 PBR CAMCO OEJ-10 PBR 2.297 8,863.0 6,148.1 43.14 PACKER CAMCO RHP-1-SP PACKER 2.875 8,902.1 6,176.7 43.08 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,934.1 6,200.1 43.11 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 8,050.0 5,571.3 46.49 TUBING LEAK Tubing Leak Identified with EL LDL 10/14/201 9 2.441 8,085.0 5,595.5 46.37 TUBING LEAK Tubing Leak Identified with EL LDL 10/14/201 9 2.441 8,115.0 5,616.2 46.26 Tubing leak TBG Leak 7/28/2016 8,132.0 5,627.9 46.19 TUBING LEAK Tubing Leak Identified with EL LDL 10/14/201 9 2.441 8,166.0 5,651.5 46.06 TUBING LEAK Tubing Leak Identified with EL LDL 10/14/201 9 2.441 8,780.0 6,087.6 43.35 PLUG 2-7/8" P2P RBP(CPP287045), OAL= 8.45' 10/4/2019 0.000 8,800.0 6,102.2 43.23 Tubing leak Tubing leak below upper stacker packer @ 8800' RKB. 7/28/2016 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 9,008.0 9,028.0 6,253.9 6,268.5 A-3, 3I-08 5/30/1997 4.0 APERF 2 1/8" EnerJet BH,180deg phase 9,018.0 9,019.0 6,261.2 6,262.0 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,026.0 9,027.0 6,267.1 6,267.8 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,040.0 9,060.0 6,277.3 6,291.8 A-3, 3I-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg phase 9,060.0 9,086.0 6,291.8 6,310.8 A-3, 3I-08 5/24/1986 4.0 IPERF 4"CsgGun HJ II;90deg phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,035.5 2,499.1 CAMCO KBMG- M 1 GAS LIFT GLV BK-5 0.156 1,293.0 6/22/2011 2 5,132.5 3,589.5 CAMCO KBMG- M 1 GAS LIFT GLV BK-5 0.188 1,329.0 6/22/2011 3 6,382.8 4,444.5 CAMCO KBMG- M 1 GAS LIFT GLV BK-5 0.188 1,322.0 6/22/2011 4 7,349.8 5,098.9 CAMCO KBMG- M 1 GAS LIFT OV BK-5 0.250 10/4/2019 5 8,099.4 5,605.4 CAMCO KBMG- M 1 GAS LIFT DMY BK-5 0.000 0.0 6/10/2011 6 8,694.1 6,025.4 CAMCO KBMG- M 1 GAS LIFT OPEN BEK 10/4/2019 Notes: General & Safety End Date Annotation 7/21/2010 NOTE: View Schematic w/ Alaska Schematic9.0 11/25/2011 NOTE: IA x OA COMMUNICATION 3I-08, 10/15/2019 7:46:07 AM Vertical schematic (actual) PRODUCTION; 23.6-9,294.4 IPERF; 9,060.0-9,086.0 IPERF; 9,040.0-9,060.0 IPERF; 9,026.0-9,027.0 IPERF; 9,018.0-9,019.0 APERF; 9,008.0-9,028.0 SOS; 8,934.1 NIPPLE; 8,902.1 PACKER; 8,863.0 PBR; 8,845.5 OVERSHOT; 8,831.4 NIPPLE; 8,815.8 Tubing leak; 8,800.0 PLUG; 8,780.0 PACKER; 8,766.4 PBR; 8,752.5 SEAL ASSY; 8,748.5 GAS LIFT; 8,694.1 TUBING LEAK; 8,166.0 TUBING LEAK; 8,132.0 Tubing leak; 8,115.0 GAS LIFT; 8,099.4 TUBING LEAK; 8,085.0 TUBING LEAK; 8,050.0 GAS LIFT; 7,349.8 GAS LIFT; 6,382.8 GAS LIFT; 5,132.5 SURFACE; 30.6-4,638.5 GAS LIFT; 3,035.4 NIPPLE; 507.5 CONDUCTOR; 30.6-110.0 HANGER; 24.7 KUP PROD KB-Grd (ft) 36.49 Rig Release Date 3/4/1986 3I-08 ... TD Act Btm (ftKB) 9,315.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292155000 Wellbore Status PROD Max Angle & MD Incl (°) 62.83 MD (ftKB) 3,600.00 WELLNAME WELLBORE3I-08 Annotation Last WO: End Date 6/10/2011 H2S (ppm) 180 Date 5/19/2015 Comment SSSV: NIPPLE 3I-08 Proposed RWO Completion Updated 3/28/24 Description Set Depth Set Depth OD (in)ID (in) Weight (lbs)Grade Top Conn Run Date Conductor 110 110 16 15.062 62.5 H-40 Welded 2/27/1986 Surface 4639 3289 9.625 8.921 36 J-55 BTC 2/27/1986 Production 9294 6463 7 6.276 26 J-55 BUTT 3/4/1986 TUBING WO 8832 6130 2.875 2.441 6.5 L-80 EUE-M 6/8/2011 TUBING ORIGINAL 8934 6200 2.875 2.441 6.5 J-55 EUE8rdAB 5/24/1986 New Tubing 8722 6045 2.875 2.441 6.5 L-80 EUE-M WƌŽĚƵĐƚŝŽŶĂƐŝŶŐĞŵĞŶƚ͗> ƐƚŝŵĂƚĞĚdK͗ϳϴϱϬΖD ƐƚŝŵĂƚĞĚdKY͗ϴϮϱϬΖD ^ƵƌĨĂĐĞĂƐŝŶŐĞŵĞŶƚ͗ZĞƚƵƌŶƐƚŽ ƐƵƌĨĂĐĞŶŽƚĞĚ PROPOSED COMPLETION Cameron Gen 4 (KRU) Wellhead 2 7/8" 6.5# L-80 EUE 8rd Tubing to surface 2 7/8" Camco MMG gas lift mandrels @ TBD SLB BlueMax Packer @ ~8120' RKB (2.43" ID) SLB BlueMax Packer @ ~8670' RKB (2.43" ID) 2 7/8" X landing nipple at xxxx' RKB (2.312" min ID) Poor Boy Overshot above 8722' RKB REMAINING COMPLETION LEFT IN HOLE Tubing cut @ ~8724' RKB Baker 80-32 PBR @ 8752.5' RKB Baker FH Packer@ 8766.4' RKB 2 7/8" P2P RBP @ 8780' MD - 10/4/2019 Non AnnComm tubing leak at ~8800' MD HES X Nipple @ 8815.8' RKB (2.312" ID) Baker Poorboy OS @ 8831.4' RKB Camco OEJ-10 PBR @ 8845.5' RKB Camco RHP-1-SP Pkr @ 8863' RKB Camco D Nipple @ 8902.1' RKB (2.25" ID) Surface Casing Production Casing Conductor A-sand perfs 9008' - 9086' RKB Pkr Depth ~8120' RKB Suspected PC Leak between ~8170' MD to 8232' MD ƌĐƚŝĐWĂĐŬĞĚͲ ϭϵϴϲ͗ ĂůĐƵůĂƚĞĚdK͗ϭϵϱϬΖZ< ĂůĐƵůĂƚĞĚ K͗ϯϬϬϬΖZ< WELL LOG TRANSMITTAL #906015810 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3I-08 Run Date: 10/4/2019 November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3I-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21550-00 RECEIVED DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC @hal liburtton.ccom lyoqlxp( Date: Signed: Originated: 50-029.21022-00 Delivered to: TRANSMITTAL DATE 29 -Oct -19 Schlumberger DELIVERABLE WL #2900119-SP02 DATA TYPE FINAL FIELD DATELOGGED Printsr 12 -Oct -19 AOGCCTRANSMITTAL PTS - PRINT CENTER .�.'`y ATTN:Natural Resources Technician 11 6411 A Street - Alaska Oil & Gas Conservation Commision Anchorage, AK 99518 r; 333 W. 7th Ave, Suite 100 (907) 273-1700 main (907)273-4760 fax .w,' Anchorage, AK 99501 1F -1d 50-029.21022-00 ORDERSERVICE DWUJ-11034 FIELD NAME DESCRIPTION KUPARUK RIVER DELIVERABLE WL DESCRIPTION PPROF DATA TYPE FINAL FIELD DATELOGGED Printsr 12 -Oct -19 1 30-04 50-029-22219-00 KUPARUK RIVER WL SCMT FINAL FIELD 11 -Oct -19 1 1B-03 50-029-20588-00 KUPARUK RIVER WL PPROF FINAL FIELD 13.Oct-19 1 1D -04A 50.029-20416.01 KUPARUK RIVER WL LDL FINAL FIELD 11 -Oct -19 1 31-08 50-029.21550-00 KUPARUK RIVER WL LDL FINAL FIELD 14 -Oct -19 1 1D -04A 50.029-20416-01 fflEDWI-OOO25 KUPARUK RIVER WL CALIPER FINAL FIELD 17 -Oct -192N-329 50-103-20257-00 KUPARUK RIVER WL CALIPER FINAL FIELD 21 -Oct -19 1 L 7 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package X ' have been verified to match the media noted above. The specific P nt Name Signature Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Please return via courier or sign /scan and email a copy to Schlu erger and CPAI. AlaskaPTSPrintCenteranslbcom Tcm.Osterkam ccnoco hill s.com _ _ SLBAuditor- Schlumberger-Private • STATE OF ALASKA OCT1 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS PtOGGC 1.Operations Abandon r Rug Perforations r Fracture Stimulate fl Pull Tubing r Operations shutdown r Performed. Suspend fl Perforate r Other Stimulate r Alter Casing rChange Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Rrn, Re-enter Susp Well r Other: Tubing patch pr 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development For Exploratory r 186-040 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21550-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025631 KRU 31-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9315 feet Plugs(measured) N/A true vertical 6478 feet Junk(measured) N/A Effective Depth measured 9010 feet Packer(measured) 8766, 8863 true vertical 6255 feet (true vertical) 6078, 6148 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110' SURFACE 4608 9.625 4639 3289' PRODUCTION 9271 7 9294 6463' Perforation depth: Measured depth: 9008'-9028'&9040'-9086' CAb®9!E® Fa! c, rt 017, True Vertical Depth: 6254'-6259'&6277'-6311' Tubing(size,grade,MD,and TVD) 2.875,J-55, 8934 MD, 6200 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE w/2.312' PROFILE @ 508 MD and 507 TVD PACKER-BAKER FH PACKER @ 8766 MD and 6078 TVD PACKER-CAMCO RHP-1-SP PACKER @ 8863 MD and 6148 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development j7 Service r Stratigraphic fl Copies of Logs and Surveys Run r16.Well Status after work: Oil F Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data "'" GSTOR r VVINJ r WAG r GINJ fl SUSP rSPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Dusty Freeborn/Jan Byrne Email: n1617t conocophillips.com Printed Name Dust Freeborn Title: Well Integrity Supervisor Signature Phone:659-7126 Date -7-oc 'A, V17._ 10/1 /16, Form 10-404 Revised 5/2015 !� / RSDS L\--0(..12�� Submit Original Only • • RECEIVED ConocoPhillipsC. 12 2016 Alaska A0000 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 7th day of October 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Ms. Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 31-08 PTD 186-040 for a tubing patch set to repair the tubing leak that was identified at 8115'. Please call Jan Byrne or myself if you have any questions. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 • • Date Event Summary 05/19/16 Failed WC TIFL 07/28/16 LDL identified tubing leak at 8115' MD 09/05/16 Set 2 7/8"WFT widepak LE lower packer at 8125'. CMIT-TxIA passed. 09/13/16 Set 2 7/8"WFT widepak LE upper packer, spacer pipe and anchor at 8109' (OAL 16.15'). MIT-IA failed. Diagnostics suggest upper packer failure. 09/24/16 Set patch extention with Slip stop, K2 packer, spacer pipe and WFT widepak anchor at 8094'. 09/29/16 TIFL passed proving integrity of the tubing patch. KUP PROD • 31-08 ConocoPhillips #1 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Fold Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cvwcoewatps 500292155000 KUPARUK RIVER UNIT PROD 62.83 3,600.00 9,315.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Data 31-08,10/6/2016 2.16:00 PM SSSV:NIPPLE 180 5/19/2015 Last WO: 6/10/2011 36.49 3/4/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _...._..,..._...........__ _ Last Tag:SLM 9,010.0 6/4/2016 Rev Reason:SET PATCHS AND SLIP STOP pproven 10/6/2016 HANGER;24.7 .- Casing Strings Casing Description 013(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread - CONDUCTOR 16 15.062 30.6 110.0 110.0 62.50 H-40 WELDED aorta Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread mannumuniasamausmsomminiii`ata'+11l , ANL SURFACE 9 5/8 8.921 30.6 4,638.5 3,289.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 23.7 9,294.4 6,462.7 26.00 J-55 BUTT `~Tubing Strings CONDUCTOR;30.6-110.0-& Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO 27/8 2.441 24.7 8,837.9 6,129.8 6.50 L-80 EUE-M NIPPLE;507.5 ` Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(") Item Des Com (in) 24.7 24.7 0.04 HANGER FMC TUBING HANGER 2.347 507.5 507.4 2.16 NIPPLE CAMCO DS NIPPLE w/2.312'PROFILE 2.312 GAS LIFT;3,035.4 8,748.5 6,064.8 43.54 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 2.430 - 8,752.5 6,067.6 43.51 PBR BAKER 80-32 POLISHED BORE RECEPTICLE 3.250 8,766.4 6,077.7 43.43 PACKER BAKER FH PACKER 2.430 8,815.8 6,113.7 43.21 NIPPLE HALLIBURTON X NIPPLE 2.312 8,831.4 6,125.1 43.18 OVERSHOT BAKER POORBOY OVERSHOT 3.000 SURFACE;30.64,838.5-+ Tubing Description Steng Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING Original 27/8 2.441 8,838.0 8,934.8 6,200.6 6.50 J-55 EUE8rdABMOD GAS LIFT;5,132.5 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 1") Item Des Corn (in) 8,845.5' 6,135.3 43.16 PBR CAMCO OEJ-10 PBR 2.297 L. 8,863.0 8,863.0' 6,148.1 43.14 PACKER CAMCO RHP-1-SP PACKER 2.875 GAS LIFT;6,382.8 8,902.1 6,176.7 43.08 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,934.1 6,200.1 43.11 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;7,349.8 Top(TVD) Top Incl Top(RKB) (RKB) 1') Des Com Run Date ID(in) 8,093.0 5,601.0 46.34'SLIP STOP SLIP TOP ON K2 PATCH 9/24/2016 -- 8,094.0 5,601.7 46.34 PATCH K2 PKR,1.91"SPACER PIPE,WIDEPAC ANCHOR 9/24/2016 1.000 (2 SHEAR SCREWS,(SN:CPS278006),15.25' SLIP STOP,8,093.0 i OAL/13'ME TO NO-GO/1"ID PATCH;8,094.0 _ GAS LIFT;8,099.41 - i'r 8,109.0 5,612.0 46.28 PATCH 2.23"WFT WIDEPAK LE PACKER(CP278021), 9/23/2016 1.310 I SPACER PIPE,&WIDEPAK ANCHOR (CPS278015)PATCH ASSEMBLY(16.15'OAL/ 1.31"ID) PATCH;8,109.0 �, 8,125.0 5,623.1 46.22 PATCH 2 7/8"WFD WIDEPACK LE PACKER LOWER 9/5/2016 1.460 iI+ ANCHOR @ 8125'RKB.(2.23"OD,1.46"ID,4'LIH, PATCH;8,125.0 #CPS2780029)-(3.78'OAL) Perforations&Slots IIIShot GAS LIFT,0 694.1 Dens Top(TVD) atm(TVD) (shotslf Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date t) Type Corn 9,008.0 9,028.0 6,253.9 6,268.5 A-3,31-08 5/30/1997 4.0 APERF 2 1/8"EnerJet BH,180deg phase 9,018.0 9,019.0 6,261.2 6,262.0 A-3,31-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg SEAL ASSY;8748.5 phase 9,026.0 9,027.0 6,267.1 6,267.8 A-3,31-08 5/24/1986 1.0 IPERF 4"CsgGun HJ II;90deg PBR;8,752.5 I 1 phase L _J 9,040.0 9,060.0 6,277.3 6,291.8 A-3,31-08 5/24/1986 1.0 IPERF 4"CsgGun HJ I1;90deg PACKER;8,766A phase 9,060.0 9,086.0 6,291.8 6,310.8 A-3,31-08 5/24/1986 4.0 IPERF 4"CsgGun HJ 11;90deg -- phase Mandrel Inserts NIPPLE;8,815.8 #. St ati on Top(TVD) Valve Latch Port Size TRO Run OVERSHOT;8,831.4 I::fj'I N. Top(ftKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com l- 1 3,035.5 2,499.1 CAMCO KBMG- 1 GAS LIFT GLV BK-5 0.156 1,293.0 6/22/2011 ! M PBR;0.0455 2 5,132.5 3,589.5 CAMCO KBMG- 1 GAS LIFT GLV BK-5 0.188 1,329.0 6/22/2011 ' PACKER;8,863.0-.- :' - - M a 3 6,382.8 4,444.5 CAMCO KBMG- 1 GAS LIFT GLV BK-5 0.188 1,322.0 6/22/2011 NIPPLE;8,902.1 M I 4 7,349.6 5,098.9 CAMCO KBMG- 1 GAS LIFT OV BK-5 0.250 0.0 6/22/2011 ' M sos;8,934.1 Y' 5 8,099.4 5,605.4 CAMCO KBMG- 1 GAS LIFT DMY BK-5 0.000 0.0 6/10/2011 M 6 8,694.1 6,025.4 CAMCO KBMG- 1 GAS LIFT DMY BEK 0.000 0.0 6/21/2011 - M _ Notes:General&Safety APERF;9,008.0-9,028.0 L_ End Date Annotation IPERF;9,018.0-9,019.0- 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 11/25/2011 NOTE:IA x OA COMMUNICATION Ir IPERF;9,026.0-9,027.0 IPERF;9,040.0-9,060.0-- IPERF;9,060.0-9,086.0 PRODUCTION;23.8.9,294.4 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. I _~ ~- ~ ~/"~) Well History File Identifier RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: Other: P~L~ ORGANIZED BY: ~REI~ Project Proofing DIGITAL DATA Diskettes, No, [] Other, No/Type NOTES: VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [3 Maps: [:] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: BEVERLY BREN VtNCE~ MARIA LOWELL RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: /O//~'~ /O / Quality Checked (done) Rev1 NOTScanned.wlxl • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 10, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 3I -08 Run Date: 6/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3I -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21550 -00 I ? g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ::=* SEP I "'e 20 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 'c �1 (( Signed: 1/ ( S 11 )--if I I 186 -6 `40 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 11, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: 3I -08 Run Date: 5/10/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3I -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029- 21550 -00 D 3 l 0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 2.A\ Signed: /41) V 114 • V STATE OF ALASKA ALASKA 411AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell J✓' Rug Perforations r Stimulate r Other r Alter Casing r Rill Tubing J;� Perforate New Pool ]- Waiver J Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 186 - 040 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic E Service A 50- 029 - 21550 -00"' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25631 `" , 31 -08 9. Field /Pool(s): r Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9315 feet Plugs (measured) 8902 true vertical 6478 feet Junk (measured) None Effective Depth measured 9207 feet Packer (measured) 8766, 8863 true vertical 6398 feet (true vertucal) 6078, 6148 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 SURFACE 4608 9.625" 4639 3290 PRODUCTION 9271 7 9294 6463 Perforation depth: Measured depth: 9008' 9028', 9040' - 9086' ° � ,�r True Vertical Depth: 6254'- 6269', 6277-6311' 4' ;� `°' �wpr a o Tubing (size, grade, MD, and TVD) 2.875, L -80, 8838 MD, 6200 TVD ty /, f t. Packers & SSSV (type, MD, and TVD) PACKER - BAKER FH PACKER @ 8766 MD and 6078 TVD r r,7 a ' ,, �`, PACKER - CAMCO RHP -1 -SP PACKER @ 8863 MD and 6148 TVD ,, NIPPLE - CAMCO DS NIPPLE w/ 2.312' PROFILE @ 507 MD and 507 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 191 625 1374 -- 157 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development go. . Service r Stratigraphic r 15. Well Status after work: . Oil gi Gas fl WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ f SUSP E SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson a, 263 -4693 Printed Name Erik Nelso / Title Wells Engineer Signature t Phone: 263-4693 Date .,,,e,,e., RBDMS JUL 1 3 2011 c) Form 10 -404 Revised 10/2010 e- a' Y , If Submit Original Only A'g— /i v..- .. • KUP • 31 -08 t .Ii . ra Well Attributes M ax Angle MD TD " ' °' - W Ilbore APUUWI 1 F eld Name Well Status Ilncl ( °) MD (ft8 8) Act Btm (kKB) _ 500292155000 I KUPARUK RIVER UNIT I PROD ! 6283 360000 9,315.0 co. xoiM Ikp: -- Comment H2S (ppm) Date An notation End Date KB Grd (6) Rig Release Date "' SSSV NIPPLE 140 12/31/2008 ( Last WO 36.49 3/4/1986 "'"""' -" "- A otahon Depth (ftKB) End Date Anrwtatron Last Mod .. End Date �..a� Last Tag: SLM 1 9,050.0 4;29/2011 Rev Reason WORKOVER I mnam � 6/18/2011 Casing Strings Casing Description String 0... String ID ... Top (kKB) 'Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 25 - -- - -- CONDUCTOR 16 15.062 30.6 110.0 110.0 62.50 H - 40 WELDED I F Casing Description String 0... String ID ... Top (ftl(B) Set Depth (E.. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 30.6 4,638.5 3,290.1 36.00 J - 55 BTC Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String .. String Top Thrd *, ,. ,� • < PRODUCTION 7 6.276 23 7 9,294 4 6 462 7 26.00 J-55 BUTT Tu bing_ Strings al Tubing Description String 0... String ID ... Top (kKB) Set Depth (f... S Depth (TVD) . String Wt... String String Top Thrd TUBING WO 27/8 2.441 247 I 8,837.9 I et 6,1297 6.50 L -80 EUE -M C0NDU3 00 Completion Details *'..;:- Top Depth In (TVD) Top Inc' Nomi... Top (kKB) (ft") (°) Item Description Comment _._ ID (In) NIPPLE, 507 - tit 24.7 24.7 0.01 HANGER FMC TUBING HANGER 2.875 ig 507.5 507.3 1 -91 NIPPLE CAMCO DS NIPPLE w/ 2.312 PROFILE 2.312 IF 8,748.5 6,064.9 43.54 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 2.430 8,752.5 6,067.7 43.52 PBR BAKER 80-32 POLISHED BORE RECEPTICLE 3.250 GAS LIFT, 3,o35 _- - - 8,766.4 6,077.8 43.43 PACKER BAKER FH PACKER 2.430 I 8,815.8 6,113.5 43.00 NIPPLE HALLIBURTON X NIPPLE 2.312 8,831.4 6,125.0 43.02 OVERSHOT BAKER POORBOY OVERSHOT 3.000 i � : Tubing Description String 0... String ID ... Top (f1KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thai TUBING Original 2 7/8 2.441 8,838.0 8,934.8 6200 5 6.50 J-55 EUE8rdABMOD ;. AMY °� SURFACE, , Completion Details - > ,r= �' , , , __ _ .-- -a s4 � 'f,'' ; 314,639 .Top Depth (TVD) Top Int Nomi... Top (kKB) (ftK8) (°) item Desoripkon Comment ID (in) GAS LIFT, _ - - 8,845.5 6,135.3 43.03 PBR CAMCO OEJ - 10 PBR _ -- 2.297 5.132 - _ ir $863.0 6,148.1 43 05 PACKER CAMCO RHP -1 -SP PACKER 3.247 it 8,902.1 6,176.6 43.02 NIPPLE CAMCO D NIPPLE NO GO 2.250 It 8,934.1 6,200.0 43.07 SOS CAMCO SHEAR OUT SUB 2.441 GAS LIFT. Other In Hole (reline retrievable plugs, valves, pumps, fish, etc.) ir, 6,383 Top Depth fit (TVO) Top Ind it T p (MB) «CB) (1 Desertion Comment Run Date ID (in) 8,902 6,1765 43.02 PLUG CA -2 PLUG 5/5/2011 0.000 GAS LIFT, Perforations & Slots 7,350 it Shot Top (TVD) Btm gum Dens T Btm (ftKB) (fIKB) (ftKB) Zone Date ( Type Comment 9,008 9,028 6,254.2 6,268 7 A-3, 31 -08 5/30/1997 4.0 APERF 2 1/8" EnerJet BH,180deg phase GAS 114r, 9,018 9,018 6,261.4 6,261.4 A-3, 31-08 5/24/1986 1.0 IPERF 4 "CsgGun HJ 11;90deg phase 6.699 � 9,026 9,026 6,267.2 6,267.2 A-3, 31-08 5/24/1986 1.0 IPERF 4 "CsgGun HJ 11;90deg phase I mo , 9,040 9,060 6,277.4 6,291.9 A-3, 31-08 5/24/1986 1.0 IPERF 4 "CsgGun HJ 11;90deg phase It 9,060 9,086 6,291 9 6,310.8 A -3, 31 -08 5/24/1986 4.0 IPERF 4 "CsgGun HJ 1150deg phase GAS LIFT. - No Safety : General Safet Annofa 7, III - - - ton Date 7 /21/2010 NOTE: View Schemat c vo Alaska SchematiC9.D SEAL ASSY. - ° 8,749 yy rr PBR, 8,753 -- Li PACKER, 8,766 it ait Ilk J NIPPLE, 8,816 _ --- -- _ OVERSHOT, 8,831 -- It PBR, 8,845 -_- l ... I PACKER, 8,863 - PLUG, 8.902 NIPPLE, 8,902 ff`. SOS, 8,934 _ -- _ _' Mandrel Details Top Depth Top ... ! Port (TVD) Intl OD Valve Latch Size : TRO Run Stn Top (ftKB) (ftKB) (°) Make Model ('n) Sery TYPe Type ( (psi) Run Date Con... '^ IPERF, a P. 1 3,035.5 2,498 8 58.01 CAMCO KBMG - M 1 GAS LIFT DMY BK - 5 0.000 0.0 6/10/2011 APERF, _ _ �^ 9,008 - 9,028 2 5,132.5 3,589.6 49.68 CAMCO KBMG - M 1 GAS LIFT DMY BK - 5 0.000 0.0 6/10/2011 IPERF, 9,026 3 6,382.8 4,444.5 46.97 CAMCO KBMG -M 1 GAS LIFT DMY BK -5 0.000 0.0 6/10/2011 4 7,349.8 5,098.9 48.43 CAMCO KBMG -M 1 GAS LIFT DMY BK -5 0.000 0.0 6/10/2011 IPERF, "`^ 5 8,099.4 5,605.4 46.32 CAMCO KBMG -M 1 GAS LIFT DMY BK -5 0.000 0.0 6/10/2011 9,040.9,066 lag 9,Ofi0.9,066 IPERF -v. i 6 8,694.1 6,025.4 43.87 CAMCO KBMG -M 1 GAS LIFT SOV BEK 0.000 0.0 6/10/2011 PRODUCTION, 24-9,204N --a ■ TD, 9,315 . • ConocoPhitlips Time Log & Summary Wenview Web Reporting Report Well Name: 31 - 08 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/6/2011 9:00:00 PM Rig Release: 6/14/2011 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/05/2011 24 hr Summary Prepare rig for move to 31 pad. Moving Boiler room, motors, pits, pumps to 31. Leave pad @ 2300 hrs. 20:00 23:00 3.00 MIRU MOVE RURD P Prepare to move rig f/ 2K -08A to 31 -08. Rigging down utility lines and electric. Jack up modules, load on Peak trucks. 23:00 00:00 1.00 MIRU MOVE MOB P Move Pits, Boilers, Motors, pumps f/ 2K pad. Left location @ 2300 hrs. 06/06/2011 Move rig from 2K pad to 31 pad, and rig up. Rig accepted @ 2100 hrs. Build scaffolding around tree, set and berm in tiger tank. 80 psi IA / 300 psi OA. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Rig move from 2K pad to 31 mad.. Move boiler complex, pump comples, pit complex. SIMOPS prep pipeshed and sub base for next load. 12:00 13:30 1.50 0 0 MIRU MOVE MOB P Move sub base, pipeshed complexes, and rock washer to 31 -08. 13:30 15:30 2.00 0 0 MIRU MOVE MOB P Pepare location for sub, spot sub base, and shim in place over well. 15:30 18:30 3.00 0 0 MIRU MOVE MOB P Lay rig mats down for the rig modules. Spot in place all rig complexes and rock washer. 18:30 21:00 2.50 0 0 MIRU MOVE RURD P Work on rig acceptance checklist. Prepare the rig for operations. Hook up all lines, service connections and inner hookups. Doyon 141 accepted for 31 -08 @ 21:00 hrs. 21:00 00:00 3.00 0 0 SURPRI RPEQPI RURD P Rig up double annulus valve, rig up scaffolding, rig up 500 barrel tiger tank, and choke house. Bring on 400 bbls of 9.6 ppg brine. 06/07/2011 Displace well to 9.6 ppg brine. 340 Barrels pumped. 340 barrels returned. Set BPV. N/D Tree. Install adaptor flange. Nipple up and test BOPE. 00:00 02:00 2.00 0 0 SURPRI WELCTI CIRC P PJSM, R/U hard line to tiger tank. SIMOPS, P/U lubricator, PJSM, Pull BPV. 0 PSI on tubing. Low pressure test with air to tiger tank © 120 psi good. 02:00 03:15 1.25 0 0 SURPRI WELCTICIRC P R/U to pump down tubing taking returns to the tiger tank, test all lines with brine. 250 psi low, 3500 psi high. 5 mins each. Good. 03:15 03:30 0.25 0 0 SURPRI WELCTI CIRC P PJSM, Displace well to brine. Discuss well control issues. Page 1 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 0 0 SURPRI WELCTL DISP P Displace well w/ 9.6 ppg brine, take returns into tiger tank. IA =30 psi initial, IA =0 psi final. Pump schedule: 1 BPM= 100psi. 2 BPM= 300 psi. 3 BPM= 800 psi. KWF @ cut (Choke 3/4 closed). 4 BPM= 550 ( Choke open). 5 BPM followed pump schedule from 550 psi to final CP = 1750. Pumped 340 barrels, 337 barrels measured in tiger tank. 340 bbls manifested to recycle. 05:00 06:30 1.50 0 0 SURPRI WELCTL DISP P Blow down lines, monitor well for 30 mins. Well static. Set BPV 06:30 08:30 2.00 0 0 SURPRI WELCTL BOPE P Rig down lines, take down scaffolding, SIMOPS. Make up floor valves, TEst emergency shut down on SCRS, and top drive with rig electrician. 08:30 09:30 1.00 0 0 SURPRI RPEQP1 NUND P PJSM, bleed pressure off control line to SSSV, bled pressure off test void of tree adaptor. 09:30 10:45 1.25 0 0 SURPRI WELLPF NUND P Nipple down tree. 10:45 12:00 1.25 0 0 SURPRI WELCTL NUND P P/U and install adaptor flange, extension 12:00 16:30 4.50 0 0 SURPRI WELCTL NUND P PJSM, Nipple up BOPE, extend riser. 16:30 22:30 6.00 0 0 SURPRI WELCTL BOPE P Test BOPE,_test all choke valves, upper & lower 2 7/8" x 5" VPR's. annular preventer, upper & lower n �� IBOP, 4" kill line DEMCO valve, 4" L' dart & floor valves, blind ram, kill & �e choke HCR valves, manual choke & lit kill valves, all tested to 250 psi low, L 3500 psi high, straight line for 5 mins each, charted. Accumulator test data: start pressure= 3050 system. After closing = 1850 psi. 200 lb increase in 52 secs. Full pressure attained = 3mins, 21 secs. 5 bottle average = 2175 psi., AOGCC Jeff Jones waived witness of test @ 15:23 hrs. 22:30 00:00 1.50 0 0 SURPRI WELCTL BOPE P R/D test lines, clear rig floor, blow down choke and kill lines, suck out stack, IA= Opsi. OA =300 psi. SIMOPS. Rig up to OA to bleed tank. PJSM prepare to pull BPV. 0 SURPRI RPCOM RURD P PJSM, 06/08/2011 Attempt to pull string free. Stuck. Mobilize E -line for another cut. Rig up E -line. Perform second cut @ 8830' MD. Success. Pull old tubing string. 00:00 01:00 1.00 0 0 SURPRI RPCOM RURD P PJSM, R/U Doyon casing equipment, UHT double stack tongs. Page 2 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 0 0 SURPRI RPCOM PULL P P/U and make up 3 pup joints. Screw into hanger, back out lock downs. Attempt to pull string free. NoGo. Pulled to 115k 12 times. Mobilize Halliburton E -line crew. 02:30 05:00 2.50 0 0 SURPRI RPCOM CIRC P Circulate bottoms up. Wait on E -line. 05:00 05:30 0.50 0 0 SURPRI RPCOM OWFF P Monitor well for 30 mins. Static. 05:30 06:00 0.50 0 0 SURPRI RPCOM RURD P Rig dowon circulating equipment. 06:00 08:30 2.50 0 0 SURPRI RPCOM RURD P PJSM. Rig up to run E -line cutting tool. (MCR radial cutting torch). P/U long bails. Spot Halliburton E -line truck. 08:30 08:45 0.25 0 0 SURPRI RPCOM SFTY P PJSM on rigging up electric line to rig floor. Hanging sheaves, and bring tools to the rig floor. 08:45 09:00 0.25 0 0 SURPRI RPCOM RURD P Pull 85k tension on string set slips. 09:00 12:00 3.00 0 0 SURPRI RPCOM RURD P Continue to rig up Halliburton electric line equipment 12:00 12:30 0.50 0 0 SURPRI RPCOM SFTY P PJSM. Crew change. Discuss Electric line safety and hazzard recognition. 12:30 14:00 1.50 0 0 SURPRI RPCOM CUTP P RIH with E -Line tubing cutter. MCR radial cutting torch. Make cut @ 8830' MD. 14:00 15:15 1.25 0 0 SURPRI RPCOM ELNE P POOH w/ E -line, R/D circ. head & pack off. UD all XO's. 15:15 16:00 0.75 8,830 8,830 SURPRI RPCOM PULL P Pull on tubing string to 115k several times., pulled free P /tI 75k S/O 55k 16:00 16:45 0.75 8,830 8,830 SURPRI RPCOM PULL P R/U casing equipment, break out 3 joints, lay down hanger, R/U to circ. 16:45 17:45 1.00 8,830 8,830 SURPRI WELCTI. CIRC P Circulate bottoms up. 5 BPM. 1450 psi. SIMOPS. Lay down all e-line equipment. Clean and clear rig floor. 17:45 19:00 1.25 8,830 8,830 SURPRI RPCOM RURD P Change out bales, install bell guide on top drive, make up rig floor safety valve. SIMOPS. Monitor well. Static. 19:00 00:00 5.00 8,830 8,830 SURPRI RPCOM PULL P PJSM. Pulling and laying down tubing and gas lift mandrels.. Hazard recognition. UD 57 jts. while spooling up control line. Retrieved 32 steel bands. UD SSSV on joint. Pumped dry job, continue to UD 2 7/8" EUE tubing. UD 121 joints, 1 GLM, Calculated = 9 bbls, Actual 9.5 bbls. 06/09/2011 Lay down and strap 2 7/8" tubing. 281 joints, 1 SSV, 8 GLM's, 13.3' of cut tubing. (8822.32'). TOF. P/U Bowen 150 overshot fishing assembly, single in the hole w/ 4" DP. Engage fish on depth. Fish. 00:00 05:00 5.00 8,822 8,822 SURPRI RPCOM PULL P PJSM, crew change, Continue to lay down 2 7/8" tubing. 281 joints, 1 SSSV, 8 GLM's, 13.3' cut joint. 8822.32'. TOF. Calc disp =21.07 bbls, Actual disp =22.0 bbls. Page 3 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 07:45 2.75 8,822 8,822 SURPRI RPCOM PULL P Count and strap all old tubing. Place outside to be Normed. Clean and clear rig floor. Load pipeshed with 4" drill pipe. Rig down tubing running equipment. 07:45 09:45 2.00 8,822 8,822 SURPRI RPCOM BOPE P Rig up and test with 4" test joint. Annular test 250 psi low, 2500 psi high, Test top VPR's to 250 psi low. 3500 psi high. 5 min test each charted. Rig down, monitor well. Static. 09:45 12:00 2.25 8,822 8,822 SURPRI RPCOM FISH P PJSM, Pick up Baker fishing assembly. SIMOPS strap 4" drill pipe in pipeshed. 12:00 12:30 0.50 8,822 8,822 SURPRI RPCOM FISH P PJSM, Set wear ring, (6 1/16" ID), run in lock down screws. 12:30 13:45 1.25 8,822 8,822 SURPRI RPCOM FISH P Make up BHA. Bowen 150 overshot, 2 7/8" basket grapple, hollow mill container w/ 2 7/8" insert, circ sub, bumper sub. 13:45 20:00 6.25 8,822 8,822 SURPRI RPCOM FISH P Single in the hole with 4" drill pipe to top of fish. TOF= 8822.32'. P/U = 165k, S/O = 88k, Rot = 120k, 7k torque with 20 rpm. 20:00 20:30 0.50 8,822 8,822 SURPRI RPCOM SFTY P Discuss well control. Hard shut in. Wait and weight method. Possibility of unseating our packer. 20:30 00:00 3.50 8,822 8,822 SURPRI RPCOM FISH P Fishing operations: Engage fish 12' in on joint # 275. On depth. Place 10k wt. on fish. P/U to 175k, 10k over, S/O to 100k, P/U to 200k. Work pipe w/ 32k over. No -Go. Put in 4 wraps in DP. Continue to work pipe. Put 3 more turns in. 7K torque trapped. Work up to max up weight of 208. 40K over. Work up and down with the trapped torque. No -Go, total time on fish 2 hours. Contact RWO Eng. Stop operations. Advised to POOH and run TBG. Release from fish. Circ. Bottoms up. 06/10/2011 CBU, Monitor well, static, POOH. Fish was caught! UD Bowen overshot assembly, P/U 6" Dress off shoe/ wash pipe assembly. TIH, dress off stump. 00:00 00:30 0.50 8,822 8,829 SURPRI RPCOM FISH P PJSM, CBU @ 85 SPM, 300 GPM, 1100 PSI, 37% flow, 40 RPM, 7k TQ. No noticeable material seen at the shakers. 00:30 01:00 0.50 8,829 8,829 SURPRI RPCOM FISH P Monitor well. Static. 01:00 04:45 3.75 8,829 8,829 SURPRI RPCOM FISH P UD two singles, blow down top drive, POOH W/ 4" DP from 8810' MD to 199' MD. Calculated = 52.3, Actual = 52.5 04:45 06:30 1.75 8,829 8,829 SURPRI RPCOM FISH P Lay down 4.75" Drill Collars / Baker fishing assembly / UD recovered fish , 7.10' Page 4 of 9 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:30 10:00 3.50 8,829 8,829 SURPRI RPCOM FISH P Clear and clean rig floor, Service top drive, service draw works, grease upper IBOP, Monitor well via trip tank. 10:00 10:45 0.75 8,829 8,829 SURPRI RPCOM PULD P PJSM, Make up Wash pipe, dressing mill assembly, P/U 6 Drill Collars. 10:45 12:00 1.25 8,829 8,829 SURPRI RPCOM TRIP P RIH W/ 4" DP to 3501' MD. P/U 79K, S/O = 66K 12:00 14:15 2.25 8,829 8,829 SURPRI RPCOM TRIP P Continue to RIH W/ 4" DP to 8783' MD. Establish milling parametes, and SPR's. Wash down to 8829' MD and tag top of the stump on depth. P/U 160k, S/O 93k, ROT 119k, 6k TQ, 1/2 BPM 100 psi, 3 BPM 300 psi 14:15 18:45 4.50 8,829 8,835 SURPRI RPCOM MILL P Dress off tubing stump 8829' to 8835' , MD. 40 to 80 rpm, 7 to 9K TQ, 1/2 to 3 BPM. 18:45 19:30 0.75 8,835 8,835 SURPRI RPCOM MILL P Begin circulating BU @ 3 BPM, 1800 psi, indicating some flow restriction. Drop dart to open circ. sub 19:30 20:15 0.75 8,835 8,835 SURPRI RPCOM MILL P CBU with open circ. sub @ 7 BPM, 300 GPM, 40 RPM, 7k TQ, no noticeable material on BU. 20:15 20:45 0.50 8,835 8,835 SURPRI RPCOM TRIP P Monitor well, static. PJSM of tripping out of the hole. Discuss Well Control, proper hole fill. 20:45 00:00 3.25 8,835 8,835 SURPRI RPCOM TRIP P PJSM, Tripping, Well control, Lay down 2 singles, POOH 5 stands, good hole fill, B/D top drive and continue to POOH to run tubing. 06/11/2011 POOH to BHA #2. Found 6' tubing, 5 Ibs metal in assembly. UD. P/U BHA #3, cut lip guide, dress off mill, TIH, No -Go. POOH for BHA#4, concave mill, TIH, mill 6 ". POOH. 00:00 00:30 0.50 8,835 8,835 SURPRI RPCOM TRIP P POOH from 3028' MD to 203' MD. Displace actual 53.5 bbls, calc. 52.25 bbls. 00:30 01:30 1.00 8,835 8,835 SURPRI RPCOM PULD P UD BHA #2, break off and dress off mill, found 6' of 2 7/8" tubing stuck up inside the mill assembly, plus 5 lbs of metal shavings packed around the wash pipe. 01:30 04:00 2.50 8,835 8,835 SURPRI RPCOM PULD P Clear and clean rig floor. Load pipe shed with 4 3/4" collars, restrap, P/U Baker tools. Stand back one stand collars, M/U BHA #3. Hold postion. 04:00 06:00 2.00 8,835 8,835 SURPRI RPCOM OTHR P Wait on wash pipe extension for BHA #3. Came from Baker shop Deadhorse. 06:00 06:45 0.75 8,835 8,835 SURPRI RPCOM PULD P Continue to make up BHA to 201' MD. 06:45 10:00 3.25 8,835 8,835 SURPRI RPCOM TRIP P TIH to 8826' MD. P/U = 162k, S/O 90k, P/U 15' pup and 2 singles. Page 5 of 9 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 8,835 8,835 SURPRI RPCOM MILL P Break circulation. 4 BPM, 450 PSI, 40 RPM. 7K TQ, 6k WOB, Tag @ 8838' MD with 3 foot swallow. No rotation, saw 200 psi increase in pressure. Tagged 3x's. P/U to 8834' MD. Restart milling process, same parameters, but ran up to 11k WOB. No head way made. Appears to be side stabbing. Prepare to POOH for concave mill. 12:00 13:00 1.00 8,835 8,835 SURPRI RPCOM MILL P PJSM, CBU @ 6BPM, 850 PSI, Monitor well for 20 mins. Static. UD 13:00 15:30 2.50 8,835 8,835 SURPRI RPCOM TRIP P POOH to 201' MD. 15:30 16:00 0.50 8,835 8,835 SURPRI RPCOM PULD P Rack back one stand of collars, UD 2 jts. collars, UD Baker assembly #3. Minor marks seen on the leading edge of the inner mill. 16:00 17:00 1.00 8,835 8,835 SURPRI RPCOM PULD P Clear and clean rig floor/ Lay down tools and pick up off beaver slide. 17:00 18:00 1.00 8,835 8,835 SURPRI RPCOM SLPC P Slip and cut drill line. 18:00 19:15 1.25 8,835 8,835 SURPRI RPCOM PULD P M/U BHA #4. Concave mill, two boot baskets, circ. sub, bumper sub, 6 spiral collars. 19:15 22:00 2.75 8,835 8,835 SURPRI RPCOM TRIP P TIH w/ BHA #4. 4" DP. To 8786' MD. Calc. = 52 bbls. Actual = 50.25 bbls. 22:00 23:00 1.00 8,835 8,836 SURPRI RPCOM MILL P Establish milling parameters, P/U = 157k, S/O = 93k, Rot = 120k, 60 RPM, 7K TQ. Mill @ 3 BPM, 400 PSI, 60 -80 RPM, 7 -8.5k TQ, Pick up tag stump w/ no rotation 3x's. Confirm Top Of Stump to be 8835.5' MD. Milled .7' to 8836.27' MD. 23:00 00:00 1.00 8,836 8,836 SURPRI RPCOM CIRC P CBU @ 7 BPM, 1200 PSI, 36% flow, Monitor well 20 mins. Static. X6/12/2011 POOH w/ BHA#4. Concave mill. R/U and run lower completion. Overshot, Packer, Polish Bore Receptacle, locate & set on bottom. 8839.1' MD. POOH to 3866' MD. Set storm packer. N/D BOPE, change out 7" pack off. 00:00 03:00 3.00 8,836 8,836 SURPRI RPCOM TRIP P PJSM, Slow pump rates. Blow down top drive, P/U = 162k, POOH to 217' MD. Actual = 52 bbls, Calc. = 52.25 bbls. 03:00 03:45 0.75 8,836 8,836 SURPRI RPCOM PULD P Lay down BHA #4. Good indication of milling on the face of the concave mill. 03:45 04:15 0.50 8,836 8,836 SURPRI RPCOM RURD P Clear and clean rig floor, lay down fishing equipment. P/U poor boy overshot. 04:15 06:00 1.75 8,836 8,836 SURPRI RPCOM PULD P PJSM, R/U to run 2 7/8" lower completion. Poor Boy Overshot, 'X' Nipple, PBR, Packer. Page 6of9 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 8,836 8,836 SURPRI RPCOM TRIP P TIH w/ 2 7/8" EUE, L -80, 6.5#, Packer assembly, on 4" DP. Down to 8833' MD, P/U = 149k, S/O = 95k. Actual = 51 bbls, Calc. = 50.12 bbls. SAFETY STAND DOWN with both crews. Discuss the broken leg accident. Good participation! 12:00 12:15 0.25 8,836 8,836 SURPRI RPCOM SFTY P Continue Safety Stand Down. Discuss trip hazards. 12:15 12:30 0.25 8,836 8,836 SURPRI RPCOM RUNL P Locate and space out Poor Boy Overshot, pull off tubing stub. Located top of stump @ 8836.2' MD. 12:30 13:45 1.25 8,836 8,836 SURPRI RPCOM CIRC P PJSM, spot 35 BBLS inhibited seawater @ 3 BPM, 300 PSI. 13:45 14:45 1.00 8,836 8,839 SURPRI RPCOM PACK P Drop ball. space out Packer, pressure up to 2500 PSI & set Packer, (Baker "FH" 47B2), hold_ pressure for 10 mins. bleed pressure to zero, pressure up annulus to 500 PSI for 5 mins. bleed pressure to zero, pressure up to 2000 PSI, hold, pick up out of PBR, verify pressure drop. Packer set @ 8839.1' MD. 14:45 15:45 1.00 8,839 8,839 SURPRI RPCOM CIRC P CBU @ 7 BPM, 900 PSI, Monitor well for 20 mins., Static, blow down top drive. 15:45 17:30 1.75 8,839 8,839 SURPRI RPCOM TRIP P TOOH to 3866' MD. Stand #40 in the hole. Calc. = 28 BBLS. Actual = 28.25 BBLS. P/U 75k, S/O 67k. 17:30 19:45 2.25 8,839 8,839 SURPRI RPCOM PACK P M/U Storm Packer. P/U 14' pup joint, RIH and set Packer, R/U and test above Packer to 500 PSI. Good. Pull out one stand, pup joint, running tool. R/U and test Storm Packer. 250 PSI low, 10 mins. 1500 PSI high 10 mins, charted. R/D and empty stack 19:45 20:15 0.50 8,839 8,839 SURPRI RPCOM SFTY P PreJob safety meeting. Nipple down BOPE. Discussed hazards, working overhead, pressure, pinch points with the Sweeny wrench, trip hazards. 20:15 22:00 1.75 8,839 8,839 SURPRI RPCOM NUND P Nipple down BOPE. Remove adapter spool. 22:00 00:00 2.00 8,839 8,839 SURPRI RPCOM NUND P Bleed tubing head void, N/D tubing spool, pull pack off, prep the 7" Hanger for new pack off. 06/13/2011 C/O 7" Pack Off & Spool. N/U BOPE, test, UD Seal Stem, RIH W/ 273 Jts. 2 7/8" TBG. 8- GLM's. Space out, and land. Test TBG to 2500 PSI. 00:00 01:45 1.75 8,839 8,839 SURPRI RPCOM DHEQ P PJSM, Set new 7" pack off. N/U tubing spool, test pack off, 250 PSI low, 5 mins., 3000 psi, high, 30 mins. 01:45 04:00 2.25 8,839 8,839 SURPRI RPCOM NUND P N/U adapter flange and BOPE. 04:00 06:00 2.00 8,839 8,839 SURPRI RPCOM BOPE P R/U and test adapter & choke flanges, 250 psi low, 5 mins., 3500 psi high, 5 mins., Charted. R/D test equipment. Page 7 of9 . i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 8,839 8,839 SURPRI RPCOM PULL P Retrieve the storm packer and lay down. 07:00 08:30 1.50 8,839 8,839 SURPRI RPCOM TRIP P TOOH to UD seal stem assembly. Actual = 22.75 bbls. talc. = 21.6 bbls. 08:30 09:30 1.00 8,839 8,839 SURPRI RPCOM RCST P Pull wear bushing, R/U tubing running equipment. 09:30 12:00 2.50 8,839 8,839 SURPRI RPCOM RCST P PJSM, Picking up and running 2 7/8" tubing. RIH w/ 40 joints, 2 GLM's. 12:00 20:00 8.00 8,839 8,839 SURPRI RPCOM RCST P PJSM, Continue to RIH w/ 2 7/8" tubing as per detail. P/U 233 joints. 6 GLM's. Calc. = 20.25 bbls. Actual = 19.25 bbls. P/U = 75k, S/O = 58k. 20:00 21:15 1.25 8,839 8,839 SURPRI RPCOM RCST P P/U Joint # 274, M/U circulating head, roll pump. stank off, witnac¢ari the seals entering the PBR. RIH to No -Go depth. Tag up 1.18' high to drill pipe depth. Calculate space out. Need 4.13' pup. 21:15 21:45 0.50 8,839 8,839 SURPRI RPCOM THGR P M/U hanger, M/U landing joint, R/U to circ. 35 BBLS inhibited brine. 21:45 22:30 0.75 8,839 8,839 SURPRI RPCOM CIRC P PJSM, Pump 35 BBLS inhibited brine, spot in annulus & 1 BBL in tubing. Pump @ 5 BPM 1300 PSI. 22:30 00:00 1.50 8,839 8,939 SURPRI RPCOM THGR P Drain stack, Land tubing hanger, RILDS, to test tubing. Pressure test tubing to 2500 PSI for 30 mins. Charted. X6/14/2011 Test IA to 2500 PSI. Pressure up to shear SOV. Rig down. ND BOP's. NU Adapter flange and tree. Test same to 250 / 5000 PSI. Pull BPV. Rig up Little Red, abd pump 335 BBLS of freeze protect diesel at 1 BPM - 250 PSI. FCP = 250 PSI. SIMOPS: Lay down 4" DP. Clean Rockwasher & pits. Install BPV. Secure tree & cellar. Rig Released at 20:00 HRS. 00:00 00:45 0.75 0 0 SURPRI RPCOM DHEQ P Held PJSM. Continue test IA to 2500 PSI. Recod on chart. Bleed all pressues. 00:45 01:15 0.50 0 0 SURPRI RPCOM DHEQ P Rig up. Shear out SOV. Observed pessu to 2500 3 times with no shea. Bleed pressue to 0 PSI. Pressue up tbg to 1500 PSI. Pressure IA to 2500 PSI, shut in. Bleed pessue on tbg, observing SOV sheared with communication, confiming shear. 01:15 02:00 0.75 0 0 SURPRI RPCOM DHEQ P Rig down all test equipment. Lay down landing joint. Install 2.5" HT BPV. Blow down choke & kill lines. 02:00 05:00 3.00 0 0 SURPRI RPCOM NUND P Hels PJSM. Nile down BOP's, Change out manual and choke line valves. 05:00 09:00 4.00 0 0 SURPRI RPCOM NUND P Nipple up adapter flange.Test same to 250 / 5000 PSI. Nipple up Tree. Test same to 250/5000 PSI. Pull BPV. Page 8 of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:30 1.50 0 0 SURPRI RPCOM FRZP P Helds PJSM. RU Little Red services. Displace well to diesel pumping 335 BBLS at 1 BPM - 250 PSI. SIMOPS: Clean & clear rig floor. RU to lay down Drill pipe. Cleaning rockwashwer & Pits. 10:30 12:00 1.50 0 0 SURPRI RPCOM PULD P Lay down 4" drill pipe via mouse hole. 45 jnts total. Crew Change 12:00 16:00 4.00 0 0 SURPRI RPCOM PULD P Continue lay down 4" drill pipe via mouse hole. Continue Freeze protect well pumping diesel. FCP = 250 PSI. Max pressure observed = 1100 PSI. Shut in well, rig down Little Red services. Cleaning rockwashwer & Pits. 16:00 17:30 1.50 0 0 SURPRI RPCOM NUND P Remove secondary annulus valve. Install wellhead flanges. Set 2 1/2" H BPV. Clean & clear cellar area. Secue tree and cellar box. 17:30 20:00 2.50 0 0 SURPRI RPCOM PULD P Continue lay down remaining 4" drill pipe. Continue clean pits. Unload piope shed. Rig released at 20:00 HRS. Page 9 of 9 31 -08 Well Work Summary dh DATE JOBTYP SUMMARY 1/9/11 Reservoir BRUSHED TBG IN ATCH INTERVAL @ 8750' - 8850' RKB (0 ,VERY VERY TIGHT). TAGGED Surveillance D NIPPLE @ 8902' RKB WITH 2.25 GAUGE RING. IN PROGRESS. 1/10/11 Reservoir DRIFT TBG TO 8351' RKB WITH DUMMY PATCH DRIFT (34' BARBELL ASS'Y). READY Surveillance FOR GYRO & PATCH. 2/1/11 Reservoir HOIST GYRO FROM SURFACE TO 9000'. LOG REPEAT WHILE POOH. HAD TO RUN (1) Surveillance 7' WEIGHT BAR TO GET INTO WELL. SURVEY HAD SOME ERRONEOUS READINGS POSSIBLY CAUSED BY VIBRATION FROM WEIGHT BAR. SENT DATA TO HOUSTON FOR EVALUATION. 2/4/11 Tubing / SET 2 7/8" WEATHERFORD PACKER AT 8840' RKB (MID- ELEMENT). CORRELATE TO Casing Patch TUBING DETAIL DATED 5/24/86. MAXIMUM RUNNING OD OF PACKER MEASURED AT 2.24 ". READY FOR SLICKLINE. 2/20/11 Tubing / TEST ER PKR @ 8838' RKB; CMIT TO 2500 PSI, PASS. IN PROGRESS. Casing Patch 2/21/11 Tubing / ATTEMPT TO SET 42' PATCH ONLY ABLE TO GET TO 8637' SLM WITH PUMP ASSIST. Casing Patch LAYED DOWN DUE TO HIGH WIND & PHASE CONDITIONS. IN PROGRESS 2/22/11 Tubing / RAN 2.25" AND 2.28" TANDEM BROACHES TO LOWER PKR @ 8838' RKB. BRUSHED Casing Patch AND FLUSHED WITH 41' DRIFT ASS'Y; COUPLE TIGHT SPOTS. ATTEMPTED SET 42' PATCH SPACER. STUNG INTO LOWER PKR @ 8838' RKB, UNABLE TO SHEAR GS. PULLED PATCH BACK OUT. IN PROGRESS. 4/3/11 Tubing / SET 42' -2" SPACER & TIEBACK RECEPACLE IN LOWER ER PKR @ 8840' RKB. COMBO Casing Patch TESTED T x IA 2500 PSI, PASSED. SET 15' UPPER PKR / PATCH ASS'Y @ 8783' RKB WITH SLICKPUMP. TBG & IA COMMUNICATING; SUSPECT UPPER ASS'Y NOT FULLY ENGAGED PRIOR TO PKR SETTING. IN PROGRESS. 4/5/11 Tubing / SET TEST TOOL IN UPPER ER PKR 8783' RKB, TBG & IA COMMUNICATING & UNABLE Casing Patch TO GET COMBO TEST. RAN HOLEFINDER, DETERMINE LEAK IS OV @ 8390' RKB IS LEAKING. PULLED UPPER ER PKR / PATCH ASS'Y @ 8783' RKB, SNAP LATCH ASS'Y WAS NOT SHEARED. ATTEMPT TO RUN TEST TOOL TO "SO" TIEBACK RECEPTACLE, UNABLE TO GET DN DUE TO SHEAR SCREW IN TEST TOOL BACKING OUT. IN PROGRESS 4/7/11 Tubing / TESTED LOWER PATCH ASSY @ 8798' RKB.ATTEMPT TO PULL LEAKING OV @ 8390' Casing Patch RKB.PULLED TESTTOOL @ 8798' RKB,SCALE.UNABLE TO SET UPPER PATCH ASSY @ 8798' RKB,PATCH WAS SET @ 8334' SLM WHILE PULLING OUT OF HOLE.IN PROGRESS 4/8/11 Tubing / PULLED UPPER PATCH WITH SNAP LATCH "SO" STINGER ASSY FROM 8319' SLM Casing Patch (OAL =15' 1 ").PULLED LOWER "SO" TIEBACK SPACERPIPE SNAP LATCH ASSY FROM LOWER ER PKR @ 8840' RKB (OAL =42' 2 ") BRUSH AND FLUSH TBG.SET LOWER "JJ" TIEBACK SPACERPIPES SNAP LATCH ASSY (OAL =42' 2 ") IN ER PKR @ 8840' RKB.TESTED T X IA WITH "JJ" TESTTOOL.GOOD.IN PROGRESS 4/9/11 Tubing / ATTEMPT TO SET UPPER WEATHERFORD PATCH ASSY APPEARS HES 1.69" Casing Patch SLICKSHOT /MSST HAD PROBLEMS. PULLED LOWER JJ TIEBACK,SPACERPIPES STINGER ASSY (42' OAL) FROM LOWER ER PKR @ 8840' RKB.PULLED LOWER ER PKR FROM 8840' RKB. COMPLETE. 4/20/11 Drilling Support PRE RWO T -POT ( PASSED ), T -PPPOT ( PASSED ), IC -POT ( FAILED ), IC -PPPOT - Exp WO PASSED) FT -LDS ALL NORMAL. 4/29/11 Drilling Support MEASURED BHP @ 9047' SLM: 4216 PSI. IN PROGRESS. - Exp WO 5/1/11 Drilling Support GAUGED TBG TO 2.27" TO 8902' RKB. ATTEMPTED SET 2.25" CA -2 PLUG, UNABLE TO - Exp WO WORK THRU OEJ @ 8820' SLM. BRUSHED & FLUSHED SCALE IN OEJ @ 8845' RKB. JOB SUSPENDED FOR RIG JOB. 5/3/11 Drilling Support DRIFT TBG TO 2.25" TO TAG D -NIP @ 8863' SLM. ATTEMPT CLOSURE TEST FAILED. - Exp WO SET Z -5 LOT IN SSSV @ 1800' RKB, NO FLOWTUBE MOVEMENT NOTICED. IN PROGRESS 5/4/11 Drilling Support LOCKOUT TRDP 1A -SSA @ 1800' RKB. BRUSH & FLUSH OEJ @ 8845' RKB. ATTEMPT - Exp WO TO SET CA -2 PLUG @ 8902' RKB. IN PROGRESS 31 -08 Well Work Summary 5/5/11 Drilling Support TAGGED @ 9085' BROACH TBG TO 2.29" TO 8902' RKB: SET 2.25" CA -2 PLUG @ - Exp WO 8902' RKB. IN PROGRESS 5/6/11 Drilling Support CMIT TO 3000 PSI, GOOD. BLEED TBG/ IA TO 200 PSI, GOOD. SET CATCHER @ 8902' - Exp WO RKB. IN PROGRESS. 5/7/11 Drilling Support PULLED 1.5" DMY VLV @ 8801' RKB. BLEED TBG DOWN TO 40 PSI & IA DOWN TO 0 - Exp WO PSI. READY FOR E- LINE. 5/9/11 Ann -Comm IC -POT (PASSED), BLEED T AND IA 5/10/11 Drilling Support CUT 2 7/8" TUBING USING A 1.69" MCR RADIAL CUTTING TORCH AT A DEPTH OF 0t< - Exp WO 8822' WHICH WAS IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE OEJ. RIGGED DOWN AND TURNED WELL OVER TO DSO. ` 5/11/11 Drilling Support BLEED IA - Exp WO 6/21/11 Drilling Support PULLED BALL & ROD @ 8815' RKB. REPLACED SOV WITH DV @ 8694' RKB. MITT - Exp WO 2500 PSI, PASSED. PULLED DVs @ 7349', 6382' RKB. IN PROGRESS. 6/22/11 Drilling Support PULLED DVs @ 5132' & 3035' RKB. SET OV @ 7349' RKB, GLVs @ 6382', 5132', 3035' - Exp WO RKB. PULLED RHC BODY @ 8815' RKB. ATTEMPTED PULL CATCHER @ 8902' RKB. IN PROGRESS. 6/23/11 Drilling Support BROACHED TBG TO 2.28" TO 8838' SLM. BAILED METAL DEBRIS @ 8840' SLM. IN - Exp WO PROGRESS. 6/24/11 Drilling Support BAILED METAL DEBRIS @ 8840' SLM. RETRIEVED METAL DEBRIS WITH MAGNET @ - Exp WO 8846' SLM. IN PROGRESS. 6/25/11 Drilling Support BAILED METAL DEBRIS @ 8847' SLM. RETRIEVED METAL DEBRIS WITH MAGNET @ - Exp WO 8849' SLM. IN PROGRESS. 6/26/11 Drilling Support BAILED METAL DEBRIS @ 8850' SLM. RETRIEVED METAL DEBRIS WITH MAGNET @ - Exp WO 8851' SLM. IN PROGRESS. 6/27/11 Drilling Support RETRIEVED METAL DEBRIS WITH MAGNET @ 8848' SLM. BAILED FINE GRIT/ SMALL - Exp WO METAL PIECES @ 8851' SLM. IN PROGRESS. 6/28/11 Drilling Support BAIL SCHMOO/ FINE GRIT f/ 8850' -8853' SLM, RECOVERED LARGE CONICAL METAL - Exp WO PIECE @ 8851' SLM, IN PROGRESS. 6/29/11 Drilling Support BAIL FILL/ METAL DEBRIS f/ 8854' TO —8883' SLM. IN PROGRESS. - Exp WO 6/30/11 Drilling Support BAIL FILL/ METAL DEBRIS f/ 8880' TO 8894' SLM, PULL CATCHER @ 8894' SLM, PULL - Exp WO 2.25" CA -2 PRONG @ 8902' RKB. IN PROGRESS. 7/1/11 Drilling Support BAIL FILL f/ 8890'- 8900' SLM, PULL 2.25" CA -2 PLUG BODY @ 8902' RKB. PERFORM 30 - Exp WO MIN SBHP © 9034' RKB = 4231 PSI, 155 DEG F. 15 MIN GRADIENT @ 8897' RKB =4186 PSI. COMPLETE. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 9, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 5 %01! RE: Packer Setting Record: 3I -08 Run Date: 2/4/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3I -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21550 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 t6,-4)616 Fax: 907 - 273 -3535 a 0"451 rafael.barr on.com euElvED Date: , :>>.e Signed: 6 _, ON 3 Gst) Cent , .z • ! WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 26, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 �» Anchorage, Alaska 99501 06, NOV 15 2010 RE: Bottom Hole Pressure Survey: 3I -08 Run Date: 10/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3I -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21550 -00 Bottom Hole Pressure Survey Log 1 Color Log 50 -029 - 21550 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Ll Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wk aliil to com ;- Date: Signed: • ~~~~ ~~ ~~~~~~~~~ ~i- PrtoAcme Diayaosiic Sem~ices, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Ancho~age, Alaska 99501 [9~7) 659-5102 C~ RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Caliper Report 2) 14 Aug-09 31-08 1 Report / EDE 50-029-2155Q00 ~ "` ~.~.t i ( ~ ~.j~~~A ~~~, s~a ~~~'~ . . ?~S (~ - ~ ~ '~c `35' ~- n ~ ~. `~ ; 1 .' ' ~ ~~,. Signed : ~: Date : Print Name: ~ ~~ ~ j ~£_= -.. _. a _Y , ,~v-. J, ,~, . ~. ~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAI AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8957 FAx: (907)245~8952 E-MAIL. 'Q,,.i~w~3~:?i~~' ..,?!~~'.~::?~ iBv.~.~~'s~. WEBSITE !t1'.if.PJ,"r.'.3 ..~ l~.,z9..,~~'i,. ~ 3t:" C:\Doeuments and Settings\Owner\DesktoplTransmit_Conoco.docx ~ ~ ~ ~ • Memory Mu~~Fir~ger Galiper Log Resul~s aurnmary Company: ConacoPhillips Alaska, lnc. Well: 31-08 Log Date: August 14, 2009 Field: Kuparuk Log No. : 10582 State: Alaska Run No.: 2 API No.: SQ-029-21550-00 Pipe1 Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD ABMOD Top Log Intvl: Surface Pipe1 Use: Tubing Bot. Log Intvl: 8,935 Ft. (MD) ~ Inspection Type : Corrosive 8 Mechanrcaf Damage Mspection COMMENTS : ~ This caliper data is fied into fhe bottom of the tubing tail ~ 8,935' (Driller's Depth). This 1og was run to assess the condition of the tubing with respect to coROSive and mechanical damage. ' The caliper recordings indicate the 2.875" tubing is in good to poor condifion. Wall penetrafions from 20% to 59% are recorded throughout the tubing. Recorded damage appears in the forms of isolated pitting, areas of general corrosion and intermittent line corrosion. No significant areas of cross-sectional wall loss are recorded. Atthough the caliper recordings indicate shallow deposits throughout the tubing that may mask ' additional corrosive damage to the tubing, no significant I.D. restrictions are recorded. The caliper recordings indicate slight corkscrewed tubing (5,000' ~ 8,900'). ' This is the second time a PDS caliper has been run in this well and the 2.875" tubing has been logged. A comparison between the current and previous log (August 5, 2007) indicates an increase in the presence of shallow deposits, likely masking additional corrosive damage to the tubing. A comparison plot iNustrating the differences in ma~cimum recorded penetrations befinreen logs on a joint-by-joint basis is induded in this t report. Deposits obstructed four caliper fingers throughout the log interval. MAXIMUM RECORDED WALL PENETRATIONS : Isolated Pitting ( 59%) Jt. 173 ~ 5,371 Ft. (MD) Isolated Pitting ( 45%) Jt. 123 ~ 3,846 Ft. (MD) CoROSion ( 33%) Jt. 136 ~ 4,234 Ft. (MD) Isolated Pitting ( 32°l0) Jt. 126 (c~ 3,935 Ft. (MD) Line Corrosion ( 31%) Jt. 121 @ 3,775 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL L~SS : No significant areas of cross-sectional wall loss (> 11 °r6) are recorded. MAXiMUM RECORDED ID RESTRICTIQNS : No significant I.D. restrictions are recorded. Field Engineer. G. Etherton Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Senlices, Inc. / P.O. Box 136°, Stafford, TY '%49 i Phone: (2g1} or (SS8) 565-Q085 Fa~:: (281) 565-1369 E-mail: PDS:amemoiylog.com Prudhoe 6ay Field Office Phor~e: (907) 659-230? Fax: (907) 059-2314 I ~ fv -~CY-~D ~ ~s4'3~~ • Correlation of Recorded Dama~ ~ Pipe 1 2.875 in (-7.4' - 8934.9') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 31-08 Kuparuk ConocoPhillips Alaska, Inc. USA August 14, 2009 ^ Approx. Tool De viation ^ A pprox. Borehol e Profil e -3 750 1529 2312 GLM 1 3100 ~ 3880 ~ ~ ~ .~ 4656 y Q a~ ~ GLM 2 5433 6214 GLM 3 GLM 4 6999 GLM 5 7792 GLM 6 GLM 7 8583 GLM 8 284.1 8935 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviafio n (degr ees) Bottom of Survey = 284.1 1 25 50 75 100 125 ` , a ~ ~ ~ ~ Z 150 c ~o 175 200 ~25 250 - 275 t I _ --~ - • • ~.~~ Minimum Diameter Profile Well: 31-08 Survey Date: August 14, 2009 Fieid: Kuparuk Tool: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 incfies Country: USA Tubing I.D.: 2.441 inches Miiimum Measured Diameters (In.) 7.69 1 J9 1.89 1.99 2.09 2.19 229 239 0.1 7 14 21 28 35 4Z 49 56 62 69 76 82.1 89 96 103 770 117 124 i 731 L E isa ~ 745 Z L t52 ~~ 159 166 172 179 186 193 2W 207 273 220 227 233 240 246 253 259 266 272 279 283 ~ • c Maximum Recorded Penetration ti ~' Comparison To Previous Well: 31-08 Survey Date: August 14, 2009 Field: Kuparuk Prev. Date: August 5, 2007 Company: ConocoPhillips Alaska, Inc Tool: UW MFC 24 No. 212330 Country: USA Tubing: 2.875" 6.5 Ib J-55 [U[ 8RD A Overlay Difference Diff. in Max. Pen. (mis) -50 -25 0 25 50 _, d .a E ~ Z « e .a -25 -12 0 12 25 Approx Corrosion Rate (mpy) 70 20 30 40 50 59 69 74 88 98 108 118 128 - 138 148 158 768 7 77 1 &7 197 - Z07 216 226 235 244 254 263 272 281.7 . • PDS Report Overview sµ Body Region Analysis Well: 31-08 Survey Date: August 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhiltips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Wei~t Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 ppf__ J-55 EUE SRD ABMOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (9'0 ~+alt) ~ penetration body ~ metal loss body 250 -- 200 150 100 ; ~ 50 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 285 pene. 0 118 118 47 2 0 loss 81 202 2 0 0 0 Damage Co~rf'iguration ( body ) 100,- - - - -- 8U - b(1 - ~t~ - 2t~ - 0 isulaleJ gencral Iine ring hole/poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 116 88 22 6 0 0 Damage Pr~le (% wall) ~ penetrafion body ~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 Bottom of Survey = 284.1 Analysis Overview page 2 PDS •ORT OINT TABULATION S• ) Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABMG~NeII: 31-08 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 14, 2009 Joint No. )t Depth (Ft.) I'c~n. U~>sc~t (In~.) Pen. Body (Ins.) Pen. % Metal Loss °i~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -7 l1 0.03 14 6 2.37 PUP Lt. De osits. 1 -3 0 0.02 8 6 234 Lt De sits. 2 32 0 0.02 10 3 2.38 Lt De sits. 3 64 t) 0.01 6 0 2.40 4 95 0 0.01 4 0 239 5 126 0 0.02 8 1 2.40 6 157 0 0.02 9 11 2.40 7 188 0 0.02 8 (~ 2.40 8 219 0 0.02 9 tl 2.40 9 250 (1 0.02 8 7 239 10 281 l) 0.02 9 1 2.41 11 313 0 0.01 7 O 2.38 12 344 0 0.02 8 0 2.39 13 375 (1 0.01 6 4 2.39 14 407 O 0.02 8 5 2.41 15 438 l1 0.02 8 ,' 2.40 16 470 0 0.02 10 5 2.40 17 500 0 0.02 8 5 2.40 18 532 0 0.02 11 G 2.39 19 563 0 0.01 7 7 2.40 2Q 594 0 0.01 6 ~ 2.40 21 624 0 0.02 9 0 2.40 Lt De sits. 22 655 0 0.02 9 1 2.41 23 687 0 0.02 10 1 2.40 24 719 1) 0.02 9 6 2.41 25 750 0 0.02 10 0 2.40 26 782 U 0.02 S 2 2.40 27 813 0 0.01 6 6 2.41 28 844 (1 0.01 6 6 2.41 29 875 0 0.02 8 2.41 30 907 0 0.02 9 1 2.40 31 938 U 0.02 10 9 2.39 32 969 0 0.02 8 0 2.40 33 1001 O 0.01 7 0 239 34 1032 0 0.02 9 6 2.40 35 1064 t) 0.01 6 O 2.40 36 1095 t) 0.02 11 t) 2.39 37 1126 t1 0.02 8 2 2.40 38 1158 0 0.01 6 0 2.38 39 1189 O 0.01 4 3 2.39 40 1220 O 0.02 9 1 2.39 41 _ 1251 0 0.02 8 1 2.42 42 1282 U 0.01 6 (1 2.40 43 1314 0 0.01 6 6 2.40 44 1345 O 0.02 8 4 238 45 1375 0 0.01 E~ ~ 2.39 46 1404 0 0.02 9 2.41 47 1435 l1 0.02 9 U 2.40 48 1466 0 0.02 9 1 239 49 1498 (1 0.01 6 1 2.40 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEEf Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABMGWeII: 31-08 Body Wall: 0.217 in field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 14, 2009 Joint No. Jt. Depih (Ft.) f'c°n. UF~set (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °/~ Min. I.D. (Ins.) Comments Damage Profile (%wall} 0 50 100 50 1529 (1 0.02 11 8 2.39 51 1560 ll 0.02 £3 1 2.41 52 1592 0 OA2 11 1 2.41 53 1623 ll OA2 9 6 2.41 54 1653 ll 0.01 4 (i 2.40 55 1685 U 0.01 7 5 2.41 56 1716 0 0.01 6 4 2.40 57 1747 0 0.01 6 ~ 2.40 57.1 1778 0 0 0 0 2.31 SSSV 58 1787 O 0.02 8 1 2.41 59 1818 0 p.01 6 2 2.41 60 1850 O 0.02 11 6 2.40 61 1880 (1 0.01 4 i 2.41 62 1912 O OA2 8 3 2.41 63 1943 O 0.01 6 (i 2.41 64 1974 (1 0.01 6 i 2.40 65 2~05 ll 0.02 8 5 2.41 66 2036 (1 0.02 11 2 2.41 67 2067 ll 0.02 10 5 2.41 68 2097 (1 0.02 8 3 2.39 69 2129 0 0.02 9 2 2.40 70 2160 0 0.02 8 2 2.41 71 2190 (1 0.01 7 4 2.40 72 2222 0 0.01 4 1 239 73 2252 0 0.02 11 5 2.38 74 2281 0 0.02 10 2 2.41 75 2312 t) 0.01 6 E~ 2.40 76 2344 O 0.01 4 3 2.39 77 2374 0 0.01 6 Cl 239 78 2405 0 0.02 8 ~ 2.39 ~9 2436 0 0.02 8 2 2.40 80 2467 0 0.01 7 ; 238 81 2499 0 0.02 8 5 2.40 82 2530 U 0.01 6 0 238 82.1 2561 0 0 0 0 N A GLM 1 Latch ~ 9:00 83 2568 0 0.02 8 4 2.38 84 2599 U 0.02 9 1 2.38 85 2630 U 0.02 9 5 238 86 2662 0 0.02 8 II 2.40 87 2693 0 0.01 7 3 2.38 88 724 (1 0.02 8 2 2.38 89 2756 0 0.02 8 1 2.38 90 2787 O 0.02 8 (, 2.38 91 2818 0 0.01 4 4 2.38 92 2849 ll 0.02 9 2 238 93 2881 U 0.02 9 ~' 2.37 94 2912 O 0.02 9 4 2.38 95 2943 0 0.02 10 6 2.39 96 2974 0.05 0.02 9 3 2.40 Pittin in u set. 97 3006 0 0.02 17 3 2.39 ~; PenetraUon Body Metal Loss Body Page 2 ~ • PDS REPORT JOINT TABULATION SHEEf Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABMC,1Nell: 31-08 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: AuAust 14, 2009 Joint No. )t Depth (Ft.) ~'c~n. ll~„c~t (liis.) Pen. Body (Ins.) Pen. °!o Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3038 0 0.03 13 1 2.38 99 3069 0 0.03 15 b 2.38 Shallow ittin . 100 31 UO l1 0.01 7 4 238 101 3131 O 0.02 10 4 2.37 102 3162 0 0.04 20 Z 2.38 Isolated ittin . 103 3194 0 0.03 12 6 2.38 104 3225 0 0.02 11 4 .38 105 3256 0 0.02 10 3 236 106 3288 0 0.03 13 1 2.38 107 3318 O OA2 11 Z _ 2.38 108 3349 0 OA2 11 l 2.39 109 3381 0 0.03 14 1 2.38 110 3413 t) 0.04 17 3 2.40 Shallow ittin . 111 3443 (1 0.01 6 i 237 112 3475 0 0.03 13 5 2.40 113 3506 0 0.04 16 5 2.40 ShalloW plltin . 114 3541 tl 0.03 16 2 2.40 Shallow ittin . 115 3570 0 0.03 15 6 2.40 Shallow ittin . 116 3603 () 0.04 17 7 239 Shallow ittin . 117 3630 tl 0.04 20 2 2.38 Isolated ittin . 118 3661 (1 0.05 24 '; 238 Isolatedpittin . 119 3694 t) 0.04 18 G _. 2.41 Shallow ittin . 120 3726 0 0.05 23 G 238 Isolated ittin . 121 3758 0 0.07 31 6 238 Line corrosion. Lt. De osits. 122 3788 O 0.04 20 5 2.38 Isolated ittin . 123 3819 0 0.10 45 :t 2.39 Isolated ~ttin . 124 3851 0 0.04 21 6 2.42 Isolated ittin . 125 3880 O 0.05 24 3 238 Isolated pittin . 126 3913 U 0.07 32 4 _ 2.40 _ Isolated ittin . 127 3945 O 0.06 28 3 2.37 Isolated pittin . 128 3977 0 0.04 18 2 2.39 Shallow ittin . 129 4008 0 0.03 15 4 2.39 Shallow ittin . 130 4039 0 0.06 28 4 239 Isolated pittin~. 131 4070 0 0.04 19 5 2.40 Shallow pittinR. 132 4101 0 0.04 20 6 2.40 Isolated pitting. 133 4132 0 0.06 26 3 2.40 Isolated pittin . 134 4161 0 0.05 22 5 237 _ Isolated pittin . 135 4192 0 0.03 16 6 238_ Shallow pitting~Lt. De sits. 136 4223 U 0.07 33 5 . 2.38 Corrosion. 137 4254 O 0.04 18 7 2.37 Shallow ittin . 138_ 4285 0 0.04 18 8 238 Shallow~itting_ 139 4317 0 0.04 19 3 .__ 2.38 __ Shallow ittin . 140 4347 ll 0.04 19 3 2.39 Shallow pittinQ. 141 4378 O 0.05 21 4 2.38 Isolated ittin . 142 --- .. 4408 U 0.04 17 4 2.37 Shallow ~ittin~. 143 4439 ll 0.04 18 2 2.40 $hallow ~ittin . _ 144 ..__ 4470 0 0.05 21 4 __ 2.40 _ _ Isolated UittinR. 145 4501 l) 0.03 16 2 239 Shallow ittin . 146 4533 0 0.03 14 3 2.37 Shallow pittin . 147 4564 0.07 0.04 17 4 _ , 2.37 _ Shallow ittin . Penetration Body ~ Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABM~/Vell: 31-08 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 14, 2009 Joint No. Jt. Depth (Ft.) Pen. UEnc~t (Ins.) Pen. Body (Ins.) Pen. % Meta~ Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 148 4595 0 0.04 18 5 2.37 Shallow ittin . 149 4625 0 0.04 19 7 235 Shallow ittin . 150 4656 0 0.03 12 1 2.37 151 4686 0 0.03 16 2 2.35 Shallow ittin . 152 4717 0 0.04 17 5 2.35 Shallow ittin . 153 4747 0 0.03 16 G 2.37 Shallow ittin . 154 4778 0 0.03 15 7 238 Shallow ittin . 155 4809 0 0.03 14 3 2.37 156 4840 Q OA4 18 6 2.38 Shallow ittin . 157 4871 0 0.03 12 7 2.39 158 4902 (1 0.02 11 11 2.39 159 4933 0 0.03 15 2 2.36 Shallow corrosion. 160 4963 0 0.02 11 4 236 161 4994 0 0.02 11 2 2.35 162 5025 U 0.02 11 6 2.41 163 5055 U 0.02 11 4 2.37 164 5086 0 OA2 9 8 2.41 165 51 17 0 0.04 19 1 2.35 Shallow corrosion. 166 5149 0 0.02 11 3 238 167 5179 0 0.02 9 2 238 168 5211 0 0.01 ,' 2 2.38 169 5242 0 0.01 6 5 2.42 169.1 5271 0 0 0 0 N A GLM 2 Latch ~ 10:00 170 5278 0 0.07 30 ~ 2.42 Isolated itti~ . 171 5309 0 0.05 23 4 2.39 Isolated ittin . 172 5339 0 0.05 25 4 2.40 Isolated ittin . 173 5370 0.13 0.13 59 3 2.40 Isolated ittin . Lt. De sits. 174 5402 0 0.06 26 5 2.39 Isolated pittin . 175 5433 0 0.03 14 5 2.40 176 5465 ll 0.03 12 6 2.41 177 5495 0 0.06 29 3 2.39 Isolated ittin . 178 5527 U 0.01 7 2 238 179 5558 0 0.03 12 2 2.39 180 _ 55~30 0 0.03 14 4 2.38 181 5621 O 0.03 12 1 238 182 5651 0 0.02 10 1 2.39 183 5683 0 0.02 9 1 2.39 184 5715 0 0.02 9 1 238 185 5746 0 0.03 14 1 237 186 5777 0 0.02 9 1 2.38 187 _ 58Q9 0 0.02 9 4 2.40 188 5840 0 0.02 8 1 2.38 189 5871 U 0.02 9 4 2.38 190 5902 0 0.03 12 1 2.39 191 5934 0 0.02 10 2 2.41 192 5965 0 0.02 10 2 238 193 5997 0 0.02 9 3 2.40 194 6028 0 0.02 9 2 2.39 195 6057 0 0.05 23 3 2.38 Isolated ittin . 196 6089 0 0.02 9 1 2.41 Penetration Body Metal Loss Body Page 4 ~ • PDS REPORT JOINT TABULATION SHEEf Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABMC,1Nell: 31-08 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.27 7 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 14, 2009 )oint No. )t. Depth (Ft.) Pc~n. UE>~c~t (ins.) Pen. Body (Ins.) Pen. % Metal Ioss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 197 6120 0 0.02 11 1 2.39 198 6151 0 0.04 18 1 2.39 Shallow ittin . 199 6183 0 0.03 12 4 2.39 200 6214 0 0.03 14 4 2.40 201 6243 0 0.03 12 2 2.41 202 62 74 0 0.02 8 1 2.41 203 6305 0 0.02 9 3 2.40 204 6337 0 0.03 14 2 239 205 6368 0.O(> 0.02 9 3 2.41 Pitcin in u set 206 6400 0 0.03 14 2 2.42 207 6430 0.05 0.02 £i 4 2.39 Pittin in u set. 207.1 6462 U 0 0 0 N A GLM 3 Latch ~ 10:00 208 6469 0 0.02 9 1 2.39 209 6501 0 0.04 17 1 2.38 Shallow ittin . 210 6533 0 0.02 9 1 2.38 211 6563 0 0.03 14 3 238 212 6595 0 0.01 7 2 238 213 6627 0 0.02 11 2 2.39 214 6657 0 0.03 16 1 238 Shallow pittin . 215 6688 0 0.03 15 5 237 Shallow ittin , 216 6720 O 0.03 12 1 2.40 217 6750 0 0.03 14 2 2.37 218 6781 0 0.03 13 3 238 219 6814 0.07 0.03 13 1 237 Pittin in u set. 220 6845 0 0.03 14 2 2.40 221 6876 0 0.04 16 2 2.40 Shallow ittin . 222 6907 0 0.02 8 2 238 223 6938 O 0.05 25 2 2.38 Isolated pittin . 224 6968 (1 0.04 19 2 _ 2.38 Shallow ittin . 225 6999 0 0.04 17 5 2.40 Shallow pittin . 226 7031 0 0.03 12 4 2.41 227 7061 0.06 0.04 18 2 2.39 Shallow ittin . 227.1 7092 0 0 0 0 N A GLM 4 Latch ~ 430 228 7099 0 0.04 20 2 2.40 Isolated ittin . 229 7130 0 0.03 15 3 238 Shallow ittin . 230 7161 0 0.03 13 2 2.40 231 7193 0 0.04 19 5 238 Shallow ittin . 232 7225 0 0.03 14 3 2.38 233 7255 0 0.03 14 1 2.37 234 7287 0 0.03 14 1 2.37 235 7318 0 0.04 20 4 2.40 Isolated ittin . 236 7349 0 0.04 17 5 2.38 Shallow ittin . 237 7380 l) 0.03 15 3 2.37 Shallow ittin . 238 7411 0 0.04 20 1 235 Isolated ittin . 239 7443 (1.12 0.04 17 3 2.37 Shallow ittin . 240 7473 U 0.04 18 2 238 Shallow ittin . 241 7505 t) 0.04 19 3 .38 Shallow ittin . 241.1 7535 (? 0 0 0 N A GLM 5 Latch ~ 4:00 242 7542 ~1 0.05 21 6 2.37 Isolated ittin . 243 _ 7575___ _ c~ 0.04 2Q_ _ _:3_ 2.35 Isolated pittinQ. _____ Penetration Body Metal Loss Body Page 5 . • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD ABMC,1Nell: 31-08 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: August 14, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Upsc•t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 244 7605 (1 0.04 18 1 2.36 Shallow ittin . 245 7636 O 0.04 17 2 2.35 Shallow ittin . 246 7668 0 0.04 17 3 238 Shallow ittin . , 247 7699 (1 0.03 16 2 2.36 ShalloW~ittin . I 248 7730 0 0.05 24 2 2.36 Isolated pittin . Lt De osits. 249 7761 0 0.04 19 2 235 Shallow ittin . 250 7792 O 0.05 23 1 235 Isolated ittin . Lt. De osits. 251 7823 O 0.05 22 4 235 Isolated ittin . 252 7853 ll 0.04 17 1 2.35 Shallow ittin . 253 7883 0 0.04 19 2 233 Shallow ittin . Lt. De osits. 254 7916 0 0.04 19 0 233 Shallow ittin . 255 7946 ll 0.04 18 1 2.31 Shallow ittin . Lt. De osits. 255.1 7978 0 0 0 0 N A GLM 6 Latch @ 11:00 256 7983 l).(17 0.04 1 F3 5 235 Shallow ittin . Lt. De osits. 257 8014 ll 0.04 19 3 2.33 Shallow corrosion. Lt. De osits. 258 8046 0 0.06 26 2 234 Corrosion. Lt. De sits. 259 8077 0 0.05 24 3 235 Line corrosion. Lt. De osits. 260 8109 0 0.04 19 1 234 Shallow ~ttin . Lt. De osits. 261 8140 (1 0.05 22 0 232 Corrosion. Lt De sits. 262 8171 0 0.05 25 1 232 Corrosion. Lt. De sits. 263 8201 0 0.05 24 2 2.32 Corrosion. Lt. De sits. 264 8233 0 0.05 25 2 2.33 Corrosion. Lt. Deposits. 265 8264 O.OEi 0.05 24 2 2.31 Corrosion. Lt. De siis. 266 8294 0.05 0.06 26 3 2.34 Line corrosion. Lt. De osits. 267 8326 0.08 0.05 24 1 2.31 Line corrosion. Lt. De osits. 268 8358 (1 0.05 24 ~ 2.32 Corrosion. Lt. De sits. 268.1 8388 0 0 0 0 N A GLM 7 Latch @ 1:00 269 8397 t) 0.07 30 2 2.32 Corrosion. Lt. De sits. 270 8427 O 0.04 21 0 2.29 Line corrosion. Lt. De osits. 271 8459 O.U(i 0.04 21 1 2.30 Corrosion. Lt. De sits. 272 8489 O 0.04 20 0 230 Isolated pittinR. Lt. Deposits. 273 8521 (1 0.05 21 0 2.30 Corrosion. Lt. Deposits. 274 8551 O 0.05 24 0 2.28 Corrosion. Lt. De sits. 275 8583 O 0.05 23 tl 230 Isolated ittin . Lt. De osits. 276 8615 (1 0.07 30 0 2.29 Corrosion. Lt. De sits. 277 8646 0.O5 0.06 25 1 2.29 Corrosion. Lt. De sits. 278 8676 O 0.05 23 0 2.28 Corrosion. Lt De sits. 279 8706 cl 0.07 31 1 2.29 Corrosion. Lt. De sits. 280 8738 O 0.06 27 1 2.32 Line corrosion. Lt. De osits. 281 8769 ll 0.05 23 1 232 Corrosion. Lt. De sits. 281.1 8801 ll 0 0 0 N A GLM 8 Latch ~ 9:00 282 8810 O 0.04 17 2 2.32 Shallow ittin . Lt. De osits. z82.1 8838 O 0 0 (1 2.30 Camco'OEI-10' PBR 282.2 8862 U 0 0 O 3.25 Camco'RHP-I-SP' Packer 283 8868 l) 0.04 20 2 2.33 Corrosion. Lt. De sits. 283.1 8902 U 0 0 0 2.25 'D' Nip le No Go 284 8904 O 0.06 28 0 ._ 2.26 _ _ Corrosion. Lt. De sits. 284.1 8935 (~ 0 0 c) 2.33 SOS L _ Penetration Body Metal Loss Body Page 6 ~ ~ ~c~.~, PDS Report Cross Sections .. Well: 31-08 Survey Date: August 14, 2009 Field: Kuparuk Tool Type; UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 2.875 ins 6.5 f)-55 EUE 8RD ABMOD AnalYst: __ __ M. Lawrence Cross Section for Joint 173 at depth 53 70.63 ft Tool speed = 43 Nominal ID = 2.441 Upset OD = 3.085 Remaining wall area = 95 % In upset region Tool deviation = 46 ° Finger 5 Penetration = 0.128 ins Isolated Pitdng 0.13 ins = 59% Wall Penetra6on HIGH SIDE = UP ~ • Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections 1 `-~ V •' Well: 31-08 Survey Date: August 14, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 2.875 ins 6.5 f)-55 EUE 8RD ABMOD Anal st: M. Lawrence Cross Section for Joint 123 at depth 3845.67 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 97 % Tool deviation = 69 ° Finger 17 Penetration = 0.098 ins Isolated Pitdng 0.10 ins = 45°/a Wall Penetration HIGH SIDE = UP ~ • Cross Sections page 2 ~ ~~,~ KUP ~ 31-08 ~OI'lOC0~11~~1 5 ~ P ell Att rlbutes x An le 8 ND ~ ~ TD _ ~~~`~~°'"~ ~~~~ . ...- .. eliDae A~_ ` 500292155000 -._.- _ i74 Name _'___ KUPARUKRNERUWT W Stalus PRODUCING U(') 6233 QIICB) 3,600.00 Act Btm (I~CB~ 9,315.0 ' ... -~ ------- CommM-_ -- _ __. __ SSSV~TRDP ~ .. _ ._ _- HY9 ~ppm~ 740 ae 12/31/2008 Anrnfidon LastWO: ~ 6ate _ . - . _ _. . NB-Gd--IRI_- 36.49 ___ ~fig~e ease ats 314/1986 ~con -.-0 a, ~,~ aa _ ~. oc. -- _,a . .., ... .._- -- Annaanon -_ =._= oep np~ e) e, ~xe ~ anaran -_.,.. ~ew ey- aoe~e Lasf Tag: CTTA 9 .294.0 727R009 Rev Reason: CTM FCO TD TAG tripiwj 7/28I2009 CBS~II ~Ih 5 ~ BhYy M9 ~~M~ ~~~~ 1 A 9WI etM p Casi~- D exrlpbn 1~U M TuP (KKel (~01 1~01 10sm1 Graa e attB~g Top llrctl . CONDUC TOR 16 15.062 30.0 110.0 1 10.0 62.SO H-40 SURFACE - 5/ 8 8765 0.0 4.639.0 3,2 90.3 36.00 J-55 conoucroa, ~io PRO~UC TION 7 6.151 0.0 9.294. 6.4 62.4 26.00 J-55 x ~,b~n serm ~ ~ ~ n.a~ u e.~a~ m~ ~•a T~ mKa s~+ m~~ sN mKa 1 ~g~ ~m~a ~ 9 ~ r~ m.a ~~~ ~~ ~~o o ~ TUBING 2 7/ 8 2.441 ~ 0.0 - 8.935.0 ~~~ 6.2 00.6 6.50 J-55 EUE&dABMOD Other I n Hole A ll Jewel . Tub~ Run b R etrievable, Fish, et -- c. q, (~) rop nc~ GASLFT. TUPIItl(8) (KK6~ l~ Desc~tptlon Coimnnt Ru~Oete DIW z,seo ~.gpp ~,5gg.5 -34.77S AFETYVIV TRDPCAAa C~TRDP-IA-S8A 3/4/1986 2.312 2.580 2.249.4 55.15 G PS IIFT CMACO/KB MG/1/GLVBK/.156/1297/ Conrr~ent: S'fA 1 7/112007 2.347 amFr.r~. sas ~ 5. 80 3.686.0 48.66 G AS LIFT C OIK 11 /GLVBK/l/ Commm t STA 2 7I10l2007 2.347 . 6.467 4.501.9 46.99 G AS IFT CPMCO/KB MGl1/DMYBTMI/I Corrm ent: STA 3 6R42008 2.34 7.095 4.9 .8 .42 I OlKB MGl1 MYBK//ICamien t 5TA4 6 42008 . 4 ~,as iFT. 5 160 7.538 5.223.8 18.26 G AS LI T CMACOI B t~Mdl1lGLVBKl.313/12841 Camxint: STA 6/242008 2.34 . 7.979 5,522.6 46.66 G ASUFT CAMCOIKB AAG/1ID BKI//Carmen t STA6 6l192007 2.347 8.391 5.809.0 45.04 UFT CAMCOIKB MG/1/OVBW.788//Cami ent: STA7 6l12/2009 2.347 8.801 6.102.7 42.99 G AS UFT MMH2 7I8 X 1 1I2I1.SIDMYIRKIII CamxnC STA 8 7/82007 2.347 GASLPT. S S 1 6 9 03 P 13 BR CALACO' E,L10'78R 3l4H986 2297 6 ~61 . . . . 8.863 6.118.1 43.U5 P ACI~R CAMCO'R HP-7SP' PACI~R 3/4/1966 3.247 8.902 6.7 6.5 1.02 N IPPLE CPMCO'D' NIPPLE GO 3/4/1986 2250 eas~FT, ~ oss 8,934 8.199.9 43.07 S OS SHEARTO OL 3/4l1986 2.441 8.935 6.20 .6 43.0 1 TL 3l4l1986 2.441 Perfora tions ~ Slots GAS LFT, - - - TaP 1~1 ~ f~l ~ ~ 7.53s Top Otln ~qt8~ (~) (KK0) Za~s D~e (~- Co nM~elY 9,008 9.028 6.254.2 6,268.7 M 3. 31-OS SI3011997 4.0 APERF 2 1!8' EnerJH BH.180deg phase 9.018 9.018 6161.4 6,261.4 A 3. 1-08 52411986 1.0 IPE RF 4"CsgG~x~ HJ 11:9 0deg phese ~ 9.026 9.026 6.267.2 6.267.2 A 3. 34-08 524/1986 1.0 IPE RF 4'CSgGUn HJ 11:9 0deg phase i s~s 9.040 9.060 6.277.4 6.291.9 A 3. 3408 SR4/1986 1.0 I F 4 CsgGun HJ 11:9 0deg pAase 9.060 9.086 6,291.9 6.310.8 M 3. 3F08 5l24l1986 4.0 IPE RP 4'CspGun HJ 11:90deg phase Notes: Gamral 3 Sa/~ly G/S LFT EIO U M! Anlotatloll . e ssi 11 /12200 _' ' 0 ~ NO TE Fxtrertn trag nded: potside ca ksaewed Nbing from 7130 ' - 8300' MD 6/222005 ~ NO TE: WAIVERED WEIL: IA x OA ANN ULAR COMMUNICATION GASLFT, 8,801 P&i. 8.815 PACi~R. 8,863 NWPLE. 8,902 SOS, 8.930 ~ TTL, 8,935 IPERF,9,at8 PPERF , 9,WC9.028 IPERF,9,026 WERF, 9,0449.060 IPERF. B.W69.086 PRODUCiION, 9.294 TD.9,315 • • • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~. c 6 l• ~. -. April 17, 2009 ,~ p~~ ,r~ ~ u Mr. Tom Maunder ~b~,~; ` Alaska Oil & Gas Commission - ~ "i 333 West 7th Avenue, Suite 100 ~ Anchorage, AK 99501 ~y4.~ ~ ~ ~ ~~ ? <'r~a ~ Dear Mr. Maunder: 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 April 7th , 2009. The corrosion inhibitor/sealant was pumped April 15th and 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 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 31-01 185-307 58' 10.10 4' 1" 4!7/2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4R/2009 8.50 4/15/2009 31-04 185-310 26' 4" 4.10 2' 4/7/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 Sc~lumbel'gel' NO. 4468 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I,) 5CANNE.O OC1 312007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Date BL Color CD Job# Log Description 2N-327 11839673 PERF/SBHP ~)ö~ - ()~q 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE ù-:¡:c..IG\-S--/::1~ 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE /0, (-oc:Fi 10/04/07 1 2M-09A 11846446 WFL t):1:.C- ,qt, -(--AI) 10/04/07 1 31-08 11837517 LDL I~{.. - (WI" 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE ¡O¡ t;) -O5l) 10/03/07 1 1J-102 11846451 INJECTION PROFILE UJ:<L ~ - no 10/10/07 1 1Y-02 11837516 INJECTION PROFILE i JT0J '5(~ - ~ 10/01/07 1 1 E-112 11846450 INJECTION PROFILE l )T{\ .:j^<.J -rf:!. / 10/10/07 1 2T-12A 11839669 LDL I~.(p - I ~ 5\ 10/02/07 1 28-07 11837522 INJECTION PROFILE í..Yï c.. I "'if4 -("Ç)(.( 1 0/05/07 1 1E-12 11846447 DDL I~.:l-/'"')("Ö 1 0/08/07 1 2N-327 11839671 SCMT ~()-+-- ()C:,<1 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. '3 10/25/07 . . Scblumbepger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1R-27 31-08 2M-19 3G-26 1R-18 1Y-01 2C-08 3H-32 1Y-10 3G-08 1A-06 2N-337B 2U-08 1 G·12 2N-343 2N-327 2N-327 3K·01 2X-04 2Z-29 2X-19 1 A-20 1 F-13 1H-10 1Q-10 2U-05 2D-12 2H-06 Job# 11850425 11839638 11813070 11813071 11837482 11813072 11813073 11837483 11837485 11813075 11837486 11837489 11813076 11837490 11745232 11837491 11837491 11632749 11846430 11850419 11850420 11850421 11850422 11846432 11846431 11846433 11846434 11846435 AUG 2; '7 Z007 cr¡¡nmission 10G7 SC~NEO I\UG 3 1 d, NO. 4384 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description FPIT It:} / -/0;) LDL )~(ð-rHt\ INJECTION PROFILE 1,....1\ .CI 1-17.-:1 LDL Jt1l1-I'"\-:f...{-" SBHP/DDL lC? 1 -. ^'f'i9- INJECTION PROFILE UU - 1'K3--cf)ó INJECTION PROFILE' / )TI" 11r.7.. -(~c< LDL -,'ùv., _ N") / INJECTION PROFILE U~ J'X7.. -rh' ¡ PRODUCTION PROFILE· 1~r-. - () "fr INJECTION PROFILE í YT"C' I "if I-Ill... PRODUCTION PROFILE . ¡::¡N _ - J { A-:;( LDL W1it ,~-~ I PRODUCTION PROFILE 1~3. - ~d. MEM INJECTION PROFILE . ()~ ¡C;-k - rA:::J SONIC SCANNER .~-:t ~~ SONIC SCANNER-FMI .1"\"...... -,...... PRODUCTION PROFILE . J"Írfo - 1,)1 INJECTION PROFILE / ,;-1' I.ç,~ -II*' SBHP SURVEY /~~":"J::A SBHP SURVEY j '\ ¢ - l~.<..- SBHP SURVEY J o.r-. - JI..~ SBHP SURVEY l):I:.C' J~~ -li./l.J SBHPSURVEY /~~-~~ SBHP SURVEY J'1r4 - 1t:1"'X INJECTION PROFILE I ~ ï:f\. J1ir.~ - (")J~ PRODUCTION PROFILE I ~£/ -l"Aq LDL liir.C: -IIß{ Date 08/18/07 07/28/07 07/29/07 07/30/07 07/31/07 07/31/07 08/01/07 08/01/07 08/03/07 08/04/07 08/04107 08/06/07 08/06/07 08/07107 08/08/07 08/08107 08108/07 08112107 08/13107 08/13/07 08/13107 08/14107 08114/07 08/14/07 08/14/07 08115107 08/16/07 08/17/07 BL Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ";)7l Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/22/07 . . e e WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 Report / EDE 31-08 Caliper Report 05-Aug-07 1) 2) 3) 4) 5] 6) 7) I ~{, _ol.(O .1f IS-g;)C::, S:~NED Þ.\}G 1 '11\)\)7 Signed: (t,Ji---- RECE\VED Date : AUG 1 {) 2QQ7 Print Name: alA r~~+¡IA e- ~~.(7A , ion {\Ja$ka Oil & Gas Coos. commlss l\nchorage PRoACTIVE DIAGNOS11C SERVICES, INC., 130 W. INTERNA110NAL AIRPORT RD SUrrE C, ANCHORAGE, AI< 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHOR..I.GE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D;\Masœr _copy _00 ]DSANC-2OxxIZ_ WordlDistnòutionlTmnsmit1at SbeetslTransmit _ Original,doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1Desc.: Pipe1 Use: ConocoPhillips (Alaska) Inc. August 5, 2007 7183 1 2-7/8" 6.5 lb. J-55 Tubing Well: Field: state: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 31-08 Kuparuk Alaska 50-029-21550-00 Suñace 8,904 Ft. (MD) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into the D Nipple @ 8,902' (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 2-7/8" tubing logged is in good to poor condition, with a hole recorded @ 8,820'. Wall penetrations in excess of 20% wall thickness are recorded in 84 ofthe 283 joints logged. The damage recorded appears mostly in the form of Isolated Pitting, with some general corrosion and Line Corrosion beginning to form. An area of slight to moderate buckling is recorded from -7,100' to the end of the log at 8,900'. There are no areas of significant Cross Sectional Wall loss recorded throughout the interval oftubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting 282 @ 173 @ 241 @ 147 @ 228 @ (100%) ( 47%) ( 42«'Æi) ( 39%) ( 37%) Jt. Jt. Jt. Jt. Jt. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. s-cANNED AUG 1 72007 8,820 Ft. (MD) 5,380 Ft. (MD) 7,523 Ft (MD) 4,570 Ft. (MD) 7,126 Ft. (MD) I Field Engineer: Wm McCrossan Analyst: J. Thompson Witness: C. Kennedy I 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@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I~ (p-ti-tC ~ 153d<ø Correlation of Recorded I Pipe 1 2.875in (23.1'-8901.8') I I I I GlM 1 GlM 2 Q:¡ .D E :::¡ z ..... c: § GlM 3 I GlM 4 I GlM 5 GlM 6 I GlM 7 GlM 8 283.1 I 0 I Bottom of = 283.1 I I to Well: Field: Company: Country: Survey Date: 31-08 ConocoPhillips Alaska Inc USA August 5, 2007 Approx.Too!Dewation Approx. Borehole Profile 50 Damage Profile (°;0 wall) I Tool Deviation (degrees) 23 772 1549 2331 3116 3895 ..... u... .5 4666 5442 6220 7003 7794 8583 8902 100 Well: Field: Company: Country: 31·08 Kup<iruk ConocoPhillips Alaska Inc USA Survey Date: Tool Tool Size: No. of Ana st: August 5,2007 UW MFC 24 No. 212330 1.69 24 J. Thom 6.0 ins Tubing: Nom.OD 2.875 ins Weight 6.5 f Grade & Thread Nom.lD ·55 WE 8RD AS Mod 2.441 ins Nom. Upset 2.875 ins Penetration ami Metallo!>s (% wall) Damage Profile (% wall) penetration body metal loss body penetration body o 1 meta! loss body 50 100 200 150 100 50 0 o to 1°;', 1 to 10% 10 to 20 to 40 to over 20% 40"1" 85% 85% GLM 1 1 o Damage ( body ) 150 50 GLM2 100 GLM3 GlM4 GLM 5 GLM6 GLM 7 GLM8 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ¡ble hole Bottom of Survey = 283.1 II I Iii I~ Analysis Overview page 2 I I I ~~COJ:lllIl!IDbL.~j 1 8120 I 8130 I 8740 I I rmro 8780 I I 8770 I 8780 I I 2001 Detail Patch Interval 8710 I I I I I I I 8790 8800 8810 8820 I I I NT lATION EET Pipe: Body Wall: Wall: 1.0.: 2.875 in 6.5 0.217 in 0.217 in 2.441 in j-55 WE 8RD AB MàNell: 31..08 Field: Kuparuk Alaska ¡ne Country: USA Date: August 5, 2007 I I I I I I I I I I I joint jt. Depth Pen, Pen. Perl. . ¡vie tal Min. ~ ' profile No. ,t !.D. Comments (Ins.) (Ins.) 0 50 100 ~ ~ ~ ;; 001 6 0 2.37 5 149 ¡ 2.3ft 6 HìO 1 2.38 7 211 ( 0 1 8 242 ( 0 I 9 77"" 0 n 10 ""OS 0.02 11 336 0.02 2.37 12 ~ 1 2.38 13 ¡ I 2.38 14 ¡ I 2.18 15 461 2.35 16 492 17 523 18 554 19 586 20 617 n 21 647 0 22 678 0 0.07 7:4:> 23 701.} 11 0.01 7- 2.39 24 740 . 2.39 25 772 2.41 26 803 2.40 27 834 2.39 28 865 2.41 29 897 .0' 2.40 30 928 0.03 31 960 0.02 'I 32 991 0.02 2 33 1022 0.03 1 34 1054 0.02 'I 35 1085 0.02 1 fí 36 1116 0.03 Ii 1 9 37 1147 I 0,07 I 2.39 38 1179 I ±¡O2 2.38 39 1210 ( 02 7.40 40 1241 ( 0.01 ;L40 41 1272 0.01 2"{q 42 1303 002 ~ 2.39 43 1334 0.02 2.40 44 1365 . 239 45 1395 fif 2.39 46 1424- 2.40 47 145S 2,41 48 1486 0.02; 1 ¡ ~:: 49 1518 50 1549 I 0.03 121 6 2.40 Body Meta! loss JOINT TABULATION Pipe: Body Wall: UpsetWali: NominaII.D.: 2.875 in 6.5 0.217 in 0.217 in 2.441 in J-55 WE 8RD AS M<Well: field: Company: Country: Survey Date: 31-08 Kuparuk ConocoPhmips Alaska fnc USA 5,2007 I Joint Jt Depth Pen. Pen. Pen ¡\/tela! Min. .11\ ...~ No. LD. Comments 101 (Ins.) (Ins.) (Ins.) 0 '" ""ill 51 1580 ) 52 1612 2.41 51 1643 2.43 54 1 6 2 55 1 56 1 !f 0.02 57 =1767 0.01 57.1 1798 0 SSSV 58 I 1 0.01 59 1 60 HI69 ittin¡;¡:. r 61 1900 62 1931 2.42 63 1962 Ú I j 2.40 I 1993 I 65 I 66 2055 67 2086 I 68 2116 69 2148 0.01 2AO 70 2178 0.02 11 2.41 71 2209 0.ü1 2.40 72 2240 0.02 ! 1 2.42 ~ 73 2270 =;: m~ 2.38 Shallow oíttimI. 74 2300 2.41 75 2331 2.40 76 +11 ( 0.01 2.40 77 393 ( OJì1 2.39 78 2423 m=F 79 ¡ 2454 ~485 516 0.02 82 2548 0.02 ~ 2577 ( 0 NA GLM 1 (Latch @ 7:001 2586 ( 0.02 ! 2.37 84 2617 0.02 2.38 85 2648 2.37 U. Deno<;it". 86 2679 j - H .37 87 2710 - r----- .36 88 27< .38 89 0.02 r----- 2.40 90 0.04 ! 2.38 III 91 0.02 m~® 92 0.03 2.38 93 0.03 2.38 94 2929 0.02 2.38 95 2960 0.02 2.39 96 2991 0.01 2.39 97 3022 0.02 :J t 1 I 2.40 98 3053 0.01 3 2.38 I I 2 I I PDS REPORT INTTABULATION EET I I 2.875 in 6.5 ppf J·55 WE BRD AB McWe!l: 0.217 in Field: 0.217 in Company: 2.441 in Survey Date: 3!.o8 Kuparuk ConocoPnillips Alaska Ine USA August 5, 2007 I Joint Jt Depth Pel Pen. Pen. Ivlelal Min. ~v Profile No. II Body 1.0. Comments wall) (Ins) (Ins.) (ins.) 0 50 100 99 3085 0 ~ ~ 100 3116 0 -* 101 3147 ( . 'h,lIow ~ffino. 102 3178 0.03 î Shallow nittinQ. 1O~ 3209 0.02 1 2 104 3241 0.03 Shallow flittinQ. 105 3272 0.01 2.38 Shallow oittimI. 106 3303 0.03 2.38 ShaJ!ow oiuio2. 107 3334 0.04 ~ Shallow oitunl:!. 108 3365 0.03 10G '1396 0 Isolated ni!:tinQ. 110 3428 0 O. Shallow oiUinQ. 11 3459 0 O. 112 0 O. '¡ttimI. . . 2.40 Shallow Ditunl!. 0.04 2.41 Isolated niliiot!. 16 0.04 2.37 Isolated niWoQ'. 117 0.0'1 2.37 IsolatPd o¡tunQ. 118 3676 1 2.36 Iso!atpd oittin2. 1 9 3708 2.38 Isolated nitting:. 1 0 3739 . 2.38 Corrosion. Lt. Deoosits. 1~ O. 19 238 Isolated niUimI. 1 2 0.05 2.39 Isolated oittinl!. 1.3 3833 ( 0.08 2.37 Isolated nitti!"IQ. 124 3864 0 0.05 2.38 Isolated pitting. 125 3895 0 0.07 2.35 Isolated oiWnQ. 126 3926 0 ~ 2AO Isolated oiWnQ. 127 3q57 0 2.37 Isolated oiUinQ. 128 3989 0.04 2.37 nittinl!. 129 4020 O.O~ I: 1 m=± Isolated oittim~. 130 4051 ittinl!. 131 4082 Isolated nittinQ. 132 4113 II 2.39 Isolated oittinQ. 133 4144 0.07 2.39 Isolated oittim:¡. 134 4173 0.07 2.38 Isolated oittinl!. 135 4204 0.04 ) 2.40 Shallow 136 4235 o. i5 2.38 Isolated oitunl!. 137 4265 . 'I 2.37 Isolated oitting. 138 4297 0 0.05 ~4 2.38 Isolated oittíll!l. 139 4328 0 0.04 2.31'1 ¡..alated nittínq. 140 4358 0 0.07 2.38 141 411'19 n 2.37 l..o!iHpd oiitÎnQ. 142 4419 237 Isolated oitUf1!:!.. 143 4450 0 0.05 2.41 Isolated oittiolL 144 4481 0.05 0.04 2.38 Shallow oíUim1:. 145 4512 0 0.03 2.39 146 i 4544 0 O. 236 Shallow nittin2. 147 4')75 0 O. 2.38 isolated OÎttiM. 148 4605 0 0.04 2.38 Shallow oíttin¡;¡. I I I I I I I Body Body Page 3 I JOINT LATION Pipe: Body Wall: Wan: I.D.: 2.875 in 6.5 ppf J-55 fUE 8RD AB M<Well: 0.217 in field: 0.217 in Company: 2.441 in 31-08 Date: ConocoPhiilips Alaska Inc USA August 5, 2007 I I I I joint jt. Depth Pe, Pen. Pen~ Metal Min. Damage Profile No. (Ft.) 'I Body !.D. Comments R(IŒ) (Ins.) 0 50 100 149 0.04 19 +=+=12.35 Shallow oiuimz. 150 4666 1 .04 19 237 Shallo 151 4697 (J i.04 17 2.38 Shallow DÌuing. 152 4727 i.03 16 3 2.36 ittim;¡;. 153 47.'17 W4 311 ittÎnQ. 154 471111 .03 .39 ,iHinQ. 155 4819 8 Isola 4849 Shallow oiUim!. 157 i ARRfJ 158 ' 4911 159 4942 160 i 49n 161 162 5064 166 5157 0 2.35 167 5189 (J 0.02 8 2 2.39 168 5219 (J 0.02 I 1 2.38 169 5251 0 0.02 D 2.39 169.1 5278 0 NA c;¡ M 2 (Latch @ 7:00) 170 5287 0.07 3 ? ,9 Isolated oiUin\!. 171 <:719 I ,~ Isolated oittim!.. 172 5348 0.05 ? ~) Isolated oittimz. 173 5379 0.10 1 '~~ Isolated DiUing. 174 '14'0 0.06 Isolated nittin2. 175 .'1442 0.04 Shallow rlÎtli02. 176 5473 0.03 2.41 177 5504 0.07 2.39 Isolated Dittim!.. 178 5535 0.03 2.40 Shallow oittimz. 179 5566 0.03 W Shallow oittim!.. 180 5598 181 5629 2.39 Isolated pitting. 182 5660 1 238 Shallow nittÎnq. 183 5692 2.39 184 5723 Isolated oîttimz. 185 5754 o. i.5 0.03 2.39 186 5785 (L i5 0.02 H 2.39 187 5816 ( 0.02 1 2.39 188 5 8 ( 0.03 2.39 189 , '9 ( 0.03 2.39 Shallow pittim!.. Lt. Deoosik. 190 , 0 ( 2.40 191 , ~ 1 2.40 192 5972 ( (f 2.41 193 6004 ( 2.39 194 6035 ( ~) ( 2.38 195 6064 ( 14 1 2.41 1% 6096 0 9 2 2.41 197 6126 0 0.03 n I 2.38 Body Loss Body Page 4 Pipe: Body Wall: UpsetWal!: Nominal I.D.: Joint Jt. Depth No. (Ft.) 198~ 199~ 200 6220 201 6249 202 6281 203 6311 204 205 206 207 207.1 6467 208 6474 209 6506 210 11'111 211 6568 212 6600 ~ ~ 216 6725 217 6756 21ft 6787 219 681ft 220 6849 221 1)880 222 6911 223 6941 224 6972 225 7001 226 7035 227 06' 227.1 09~ 228 101 229 7132 230 7165 231 7196 232 722 233 7251 234 721)' 235 7322 216 7352 237 7384 238 7415 239 7445 240 7476 241 7507 22431 I 75:~ 244 7608 I I 2.875 in 6.5 0.217 in 0.217 in 2.441 in JOINT TABULATION J-55 EUE BRD AB M<Well: Field: Company: Coun try: Survey Date: 31-08 Kuparuk ConocoPhillips Alaska Jnc USA August 5,2007 Pen. Pen. Pen. Metal Min, Body I.D. Comments (Ins) (los.) (Ins.) _haIlOWOitti02. (d nitlin2. Ii-I . (,.(1 'I oittin2. (i.1 11 ') oittim!. Lt Denosits. o 0.03 1; 238 o run I ' 239 Shallow nittinQ. tiili- 2.41 Shallow nittinQ. i2 ...l = ~ "lAkh @ 4"'01 0.03 ___~ 2.37 2.38 Shallow nitlinQ. 2.40 0.0 o o ( I II Shallow oittirnl. iU:În2:. Isolated oittin2:. ·ttin!!. Ch .11. ;"';'. Lt. Deoosits. ¡.,ola 2.37 2.37 237 2.40 2.39 2.37 21q 2.40 2.38 2.36 2.38 0.04 iWrnl. o ') 4 ~1 Isolated oittimL Isolated Dittin!!. >. . I t O. )t¡ t ( ( ( í o It¡ o 17 237 ~. N/A 239 2.38 239 2.36 Line corrosion. 2.36 Shallow citrinº" ~ Isolated oittirnI. '---- ~ Isolated o~ili.rnI. Bucklinº'. 2.15 i!:tirnI. BuddirnI. 2.36 Line corrosion. 236 ittil12:. Bucklin2:. 2.36 2.35 Corrosion. 0.04 o 0.08 0.05 I : 0.03 I 0.05 ¡ itl.Írnl. GlM 4 (latch @ 7:0Oì ittin!!. Isolated Dittirnl. ( ¡ í ¡ 0.17 ¡ o 0.08 2.36 '5 2.35 I 4 I 2.35 Isolated oittinSl. Buckling. Page 5 1M _ ,;~"". o 1'''5;'''''1 100 II lATION NT J-55 EVE BRD AS M<WeU: Field: Pipe: Body Wall: VpsetWali: Nomina! 1.0.: 2.875 in 6.5 0.217 in 0.217 in 2.441 in 31"()8 Kuparuk ConocoPhillips Alaska ¡Ile USA 5, 2007 Joint Jt. Depth Pen. Pen. Pen. Min. No. t(~ :;:t~ t 1.0. Comments (ins.) 245 7640 0 ittimz. Bucklioo. 246 1(>10 Ii Iso ated oittioo. Bucklin!!. 247 7701 Is 248 7732 ( ittillll. Buckling. 249 7763 ( ittinQ. Buck!in2. 250 7794 ( Bucklirnl. 251 7824 1:2 I 252 7856 2.39 lso!ated nitlirnl. 253 7886 254 7916 t .36 i Isolated oitlinrL Bucklin>!. 255 7QAR i 0.0 i :1 ~'i Isolated oitlioo. Buck!iml. 255.1 7979 N/A GlM 6 {latch @ 2:0m 2% 7986 ~ 4 2.33 Corrosion. RllcklinQ. 257 8016 \ 0.05 2.29 Corrosion. Buckling. 258 R04f1 ±it Shallow corrosion BuddinQ. ~ ¡ ine corrosion. Bucklin2. 0.1'7 2.31 line corrosion. Buddinll. 8140 t 2.32 Corrosion. Bllcklinll. 262 8172 ( 0.06 232 Corrosion. Bucklin\<:. 263 8203 0 0.04 3 2.35 Corrosion. Buck!in>!. 264 8235 0 0.06 'i 236 Corrosion. Bucklinlil. 26S fl266 0 O. ~ Isolated nitling. RuddinlI. 266 8297 0 O. line mrrosion. Buddimz. 267 8328 0 O. ~ Corrosion. Bucklin\!. 268 8359 Isolated oittim;¡. .268.1 8391 I 0 0 GLM 7 (Latch@ 7:001 .269 8396 0 0.05 Corrosion. Buckling. 270 8428 0 0.04 2.34 Shal!ow corrosion. Buckling. 271 0 2.33 Corrosion. Buddioq. 272 8490 0 2.32 Bucklinq. 273 8522 0 0.04 ~ Shallow corrosion. Buddinq. 274 8552 0.06 0,05 Line corrosion. Bucklin>!. 275 8583 0 , 0.05 Corrosion. Budding:. 276 8615 0 . 0.04 I Shallow corrosion. Buckl¡n2. 277 8645 0 0.06 :2 2.30 Une corrosion. SIIcklina. 278 8677 0.03 ±~ 279 R70R o ){¡ nos Corro..ion. Bucklinq. 280 8739 0.04 Shallow oittinR. Buckl¡oo. 281 8770 0.04 2.32 Shallow nittinll. 281.1 8801 0 ~ 1: I GÒM 6 ''-'m @ 20m 282 8808 2821 8838 0 paR 282.2 8863 0 VA! .K!"\( 283 8870 0.17 0.06 26 2.34 Corrosion. Buckling. 283.1 8902 0 0 0 I 2.25 I o NIPPLE 6 Profile o 50 100 - Well: field: Company: - 31-08 Kuparuk ConoeoPh¡lIips Alaska Joe USA 2.875 ins 6.5 f -55 WE 8RO AB Mod Tubin : 43 10 2.441 Nominal 00 '" 2,875 Remaining wan area'" 96 % Tool deviation'" 35 0 - S rt C Sections Survey Date: Tool Type: Tool Size: No. Anal st: August 5, 2007 UW MFC 24 No. 212330 1.69 24 . Thom son 8820.68 ft Finger 2 Penetration'" 0.365 ins HOLE 0.37 ins'" 100% Wall Penetration HIGH SIDE'" UP page 1 .. .. .. Well: Field: 31-OB .. .. Country: Tubin: ConocoPhmips Alaska Inc USA 2.875 ins 6.5 ·55 WE 8RD AS Mod Tool 43 Nominal 10 '" 2.441 Nominal 00'" 2,875 Remaining wall area '" 95 "I" Tool deviation'" 48 0 .. .. .. .. .. s Survey Date: Tool Too! Size: No, of¡:ingers: Anal st 53 ft 2 Penetration'" 0.102 ins Isolated Pitting 0.10 ins'" 47% Wall Penetration HIGH SIDE'" UP Cross Sections page 2 .. .. SSSII (1800-11.101, 00:2,875) I "",s Lift MandrelNalve 1 (2580-2581, I Gas Lift MandrèlNalve 2 {5280-5281, (¡"sLift , I'IdreIlDummy A-3 Valve 3 (6467-6468, 00;4.750) - 6267 A-3 8 4 "",_lift A-3 0 1} MandrelNalve 4 6267 - 6269 A-3 2 4 (7095-7096, 6277 - 6292 A-2 20 "",slift A-2 26 4 , I'IdreIlDummy Valve 5 (7538-7539, 00:4.750) GasUft , I'IdreIlDummy Valve 6 (7979-7980, 00:4.750) GasUft Man<!!'eWalve 7 (8391-8392, I "",sLift MandrelNalve 8 {8801-8802, PBR (8845-8846, OD'2.875) PKR (8863-8864, 00:6.151 ) NIP (8902-8903, OD;2.875) TUBING (0-8935, 00;2,875, ID;2,441) Perf (90013-9028) Perf (9040-9060) I I KRU s ems. f' ^- 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 /' Other AI1@þragfl Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 186-040 I ...- 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21550-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 71' 31-08 ;/ 8. Property Designation: 10. Field/Pool(s): I ADL 25631, ALK 2564 Kuparuk River Field 1 Kuparuk Oil Pool ... 11. Present Well Condition Summary: Total Depth measured 9315' ~ feet true vertical 6478' . feet Plugs (measured) Effective Depth measured 8896' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 4568' 9-5/8" 4639' 3289' PROD. CASING 9223' 7" 9294' 6462' Perforation depth: Measured depth: 9008'-9028',9040'-9086' true vertical depth: 6254'-6269',6277'-6311' SçANNED AU G 0 3 20Q7 Tubing (size, grade, and measured depth) 2-7/8", J-55, 8935' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' @ 8863' Cameo TRDP-1A-SSA SSSV= 1800' 12. Stimulation or cement squeeze summary: RBDMS BFL AUG 0 12007 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 40 bbls 7.5% HCI 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubinn Pressure Prior to well operation 234 803 456 -- 131 Subsequent to operation 140 ;' 811 565 -- 133 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after 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 it C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer 7/2.5/07 Signature ~""tä7_- Phone: 265-6471 Date Prenared bv Sharon Allsun-Drake 263-4612 I { -., ~. )If;> 7·2.1.07 . . RECEIVED STATE OF ALASKA JUL ALASKA OILAND GAS CONSERVATION COMMISSION . 2 5 2007 REPORT OF SUNDRY WELL OPERA TION~laska Oil & Ga C n Form 10-404 Revised 04/2006 0 R \ G \ N A L AA\ ~i?J};ib ;IY DATE 6/6/07 6/19/07 6/27/07 7/3/07 7/6/07 7/7/07 7/8/07 7/9/07 7/10/07 7/11/07 7/12/07 7/13/07 7/14/07 . . 31-08 Well Events Summary Summary MITOA-PASSED, TIFL-FAILED(WC) BRUSH & FLUSH TBG TO -8122' RKB & #6 GLM. DRIFT TBG W/ 1.75" SAMPLE BLR TO -8896' RKB & OBTAIN SAMPLE OF SCALE. PULL & REPLACE 1" DVW/ SAME @ 7979' RKB. JOB COMPLETE TIFL- FAILED RIH with 2.20 mill, TO of 8850 CTMD, Pulled 27k, Very little scale in rtns, POOH, RU Side jet nozzle & brush, Bull Head 40 bbls 7.5% Hydrochloric acid, Let stand for 15 min, Jet all mandrels with S/W. Weight pulls Decreased by approx 5000 Ibs, POOH. BRUSHED & FLUSHED MANDREL'S @ 8801',7095',6467',5280' & 2580' RKB'S. SET 2.30" CATCHER SUB @ 8902' RKB. (***PU WEIGHTS WITHIN NORMAL PARAMETERS. NO INDICATION OF CORKSCREWTBG***). JOB IN PROGRESS. ATTEMPT TO PULL ORIFICE @ 8802' RKB & GLV @ 7095' RKB. SMALL AMOUNT OF SCALE PIECES & POWDER COMING BACK IN TOOLS. JOB IN PROGRESS. PULLED 1.5" ORIFICE @8801' RKB. (LATCH & VLV BODY COVERED WITH HARD SCALE. CHECK BAD). REPLACED WITH DMY. PULLED GLV @ 7094' RKB. REPLACED WITH ORIFICE (.25" PORT). PULLED DMY @ 6467' RKB. JOB IN PROGRESS. RETRIEVED 1.5" DMYVLV FROM 8902'. BRUSH & FLUSH MANDRELS @ 8801',6467',5280' & 2580' RKB'S. PULLED & RE-SET 2.30" CATCHER @ 8902' RKB. ATTEMPT TO SET 1.5" DMY VLV @8801' RKB. INCONCLUSIVE. JOB IN PROGRESS. SET GLV (TRO=1314/ PORT= 5/32") @ 6467' RKB. PULLED GLV @ 5280' RKB. REPLACED W/ 1" GLV (TRO= 1291/ PORT= 5/32"). BRUSHED MANDREL'S @2580' & 5280' RKB'S. JOB IN PROGRESS. PULLED GLV @2580' RKB. REPLACED WITH GLV (TRO= 1297/ PORT=5/32"). PULLED 2.30" CATCHER @ 8902' RKB. UNABLE TO DRAW DOWN IA FROM 900# (***IA FLUID PACKED***). TUBING PRESSURE HOLDING @ 1000#. JOB IN PROGRESS. ~ RAN TEST TOOL & TESTED TBG @ 8883' & 8824' RKB'S. FAILED. ISOLATED TBG LEAK BETWEEN 8824' & 8783' RKB'S. (***AREA OF STA #8 @ 8801' RKB***). JOB IN PROGRESS. PULLED 2.30" CATCHER SUB @ 8902' RKB. PULLED 1.5" DMY VL V @ 8801' RKB. REPLACED WITH EXTENDED PACKING DMYVLV. SET 2.25" CAT STANDING VLV @ 8902' RKB. MITT FAILED. JOB IN PROGRESS. (***STA #8 BELLY UP/ DIFFICULT TO LOCATE & SET). JOB IN PROGRESS. RAN CHECK SET TO 8801' RKB. VERIFIED DMY VLV SET. ATTEMPT TO BLEED DOWN lA, TBG TRACKS, FAILED IA DRAWDOWN. Ready for TxlA LLR & Eline LDL. .¡ 7/16/07 Established a liquid leak rate from tubing to IA at 1 bpm and 1550 psi MICROFILMED 9/11/00 DO NOT PLACE UNDER THIS PAGE ANY NEW MATERIAL STATE OF ALASKA AI_~KA OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Stimulate X Plugging Perforate Repair well Other__ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 230' FSL, 47' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1449' FSL, 1532' FEL, Sec. 5, T12N, At effective depth 1298' FSL, 1332' FEL, Sec. 5, T12N, At total depth 1253' FSL, 1273' FEL, Sec. 5, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 9 31 5 true vertical 6477 feet feet 6. Datum elevation (DF or KB) RKB 71 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 31-08 9. Permit number/a 10. APl number 5o-029-21550-00 roval 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9 2 0 7 true vertical 6398 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' Surface 4 6 0 8' Intermediate Production 8376' Liner Perforation depth: measured Cemented 250 Sx CS II 1550 Sx CS III & 340 Sx Class G 300 Sx Class G & 175 Sx CS I 1 6" 9-5/8" 7" 9008'-9028',9040'-9086' true vertical 6253'-6261',6276'-6305' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8935' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 8863'; SSSV: Camco TRDP-1A-SSA @ Measured depth 110' 4639' 9294' 1800' True vertical depth 110' 3389' 13. Stimulation or cement squeeze summary Fracture stimulated 'A' sands 6/01/97. Intervals treated (measured) 9008'-9028',9040'-9086' Treatment description including volumes used and final pressure Pumped 109 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp = 8400 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mc'f Water-Bbl Casing Pressure Prior to well operation 461 311 327 1282 Subsequent to operation 600 394 475 1289 Tubing Pressure 167 169 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. ForyO-~4'"~ °R~' 0~'-/15'~8 I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE .~CO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(31-08(W4-6)) WELL JOB SCOPE JOB NUMBER 31-08 FRAC, FRAC SUPPORT 0523971714.5 DATE DALLY WORK UNIT NUMBER 06/01/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~) Yes (~) No DS-YOAKUM CH',ANEY_.~, / FIELD AFC# CC# DALLY COST ACCUM COST S',~ ,,r~d / ESTIMATE KD1049 230DS361L $100,175 $107,286 , ~,,'/ I._/~--- -"--'~...~" Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial outer Ann I Final Outer A~ 950 PSI 900 PSI 50 PSI 500 PSII 600 PSII '~'00 PSI DALLY SUMMARY "A" SAND REFRAC COMPLETE, SCREENED OUT EARLY. INJECTED 109000 LBS OF PROP IN THE FORMATION W/8.9# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 9200 PSI & F.G. @/.70) TIME 06:00 07:45 08:10 09:10 10:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG AS REQUIRED. SET TREESAVER. PT'D HIGH PRESSURE LINES AND EQUIP TO 10000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. VOLUME PUMPED 300 BBLS. USED 5950 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 9100 PSI AND ENDING PRESSURE 3800 PSI. S/D AND OBTAINED ISIP OF 1638 PSI W/F.G. @ 1.70). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 177 BBLS. MAXIMUM PRESSURE 8400 PSI AND ENDING PRESSURE 3900 PSI. S/D AND OBTAINED ISIP OF 1812 PSI W/F.G. @ (.73). PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT EARLY. PUMPED 126590 LBS OF PROP. INJECTED 109000 LBS OF PROP IN THE FORMATION ( 13590 LBS OF #20/40 & 113000 OF #12/18 ) W! 8.9# PPA OF #12/18 @ THE PERF'S. LEFT 17590 LBS OF PROP IN THE WELLBORE. FRAC SLEEVE WILL BE COVERED W! FILL. 12:00 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 12:45 13:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $672.00 APC $5,700.00 $8,250.00 DIESEL $400.00 $400.00 DOWELL ~ ~ $90,665.00 $90,665.00 HALLIBURTON $0.00 $3,669.00 LR-~LE RED $3,410.00 $3,630.00 TOTAL FIELD ESTIMATE $1 00,1 75.00 $107,286.00 STATE OF ALASKA REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate ;X Pull tubing Alter casing Repair well Plugging Perforate _ Pull tubing Other 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 230' FSL, 47' FWL, Sec. At top of productive interval 1449' FSL, 1532' FEL, Sec. At effective depth 1297' FSL, 1352' FEL, Sec. At total depth 1253' FSL, 1273' FEL, Sec. 31, T13N, R9E, UM 5, T12N, R9E, UM 5, T12N, R9E, UM 5, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9 31 5' feet Plugs (measured) 6477' feet 6. Datum elevation (DF or KB) 71' RKI~ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 31-08 9. Permit numbor/~pr~al numb...~ 86-40 ,' , 10. APl number $o-0;~)-21550 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9207' feet Junk (measured) true vertical 6398' feet Casing Length Size Cemented Measured depth Structural Conductor 8 0' 1 6" 250 Sx CS II I 1 0' Surface 4608' 9 5/8" 1550 Sx CS III & 4639' Intermediate 340 Sx Class "G" Production 9271' 7" 300 Sx Class "G" 9294' Liner 175 Sx CS I Perforation depth: measured 9018', 9026', 9040'-9060', 9060'-9080' MD true vertical 6260', 6266', 6276'-6291', 6291'-6305' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 EUE Tubing with tail @ 8935' Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr @ 8863'~ Camco TRDP-1A-SSA SSSV @ 1800' 13. Stimulation or cement squeeze summary Refracture stimulated the 'A' Sands interval with 20/40 mesh proppant. Intervals treated (measured) Kuparuk 'A' Sands Treatment description including volumes used and final pressure 14. True vertical depth 110' 3289' 6462' Pumped 115,000# of 20/40 mesh proppant and 1381 bbls of gelled diesel ~ 4135 psig ReDresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 495 201 0 1080 154 910 336 0 800 159 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev~/'06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ,,/ELL TRACT(~R _~c.c,~ ~u~ToN REMARKS IPBDT fFIELD ' DZ~,.CbSTATE OPERATION AT REPORT TIME IDAYS DAT~ 505 ,- ~-o - ).5Z5 -- C.o - 1511 -- 7_.o- 5..550 57_0o [] CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK knots ISi ned STATE OF ALASKA !~ ALASKA OIL AND GAS CONSERVATION COMMISSION ?~ ~'~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X.~ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 230' FSL, 47' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1449' FSL, 1532' FEL, Sec. 5, T12N, R9E, UM At effective depth 1297' FSL, 1352' FEL, Sec. 5, T12N,R9E, UM At total depth 1253' FSL, 1273' FEL, Sec. 5, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 9315' 6477' 9207' 6398' feet feet feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 71 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 31-08 9. Permit number 86-40 10. APl number 5o-029-21550 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Structural Conductor 8 0' Surface 4 6 0 8' Intermediate Production 9 2 7 1 ' Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 1 6" 250 Sx CS II 1 1 0' 1 1 0' 9 5/8" 1550 Sx CS III & 4639' 3289' 340 Sx Class G 7" 300 Sx Class G 9294' 6462' 175 Sx CS I 9018' MD, 9026' MD, 9040'- 9060' MD, 9060'- 9080' MD true vertical 6260' TVD, 6266' TVD, 6276' - 6291' TVD, 6291' Tubing (size, grade, and measured depth 2 7/8" J-55 set at 8935' Packers and SSSV (type and measured depth) HRP-lSP @ 8863', TRDP-1A-SSA SSSV~ 1800' RECEIVED 6305' TVD M~~/ 2 (::) 191 9 Oil & Gas CoaS. 13. Attachments Description summary of proposal _ Detailed operation program X.~ Refracture stimulate the 'A' Sand interval (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: July, 1989 Oi~ ~ Gas __ 16. If proposal was verbally approved Name of approver Date approved Service Producer BOP sketch Suspended 17. I hereby certify that the foregoing is true and correct to the ,~est of my knowledge. Si~ned ~ ~ ."~4,~~ ~~ Title ,-x.¢ ~/,~..z..~ ,4...~/-t..t. Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 10- ~4 Commissioner IIAppr°val NoT~ ,Approve6 C.oP¥ Returne-~ Date SUBMIT IN TRIPLICATE Kuparuk Well 31-08 Application for Sundry Approval May 22, 1989 . . . The static bottomhole reservoir pressure is estimated to be 2600 psig based on adjacent well data taken 2/19/89. No workover fluids will be used during the stimulation. No BOPE is required. The treatment will be pumped through a surface manifold. RECEIVED laA¥ 2 6 'A' Sand Refracture Stimulation Procedure Kuparuk Well 31-8 Fracture Treatment . . . . . . Pressure up 2-7/8" by 7" annulus such that the final pressure during the fracture treatment will be 3500 psig. RU fracturing equipment and tree saver. All fluids should be maintained at 70° to 90° F on the surface. Pump 100 bbl PREPAD containing 40 lb/1000 gallons silica flour at 20 BPM. Shutdown for ISIP and to check perf friction. Leave well shut-in for five minutes to allow pressure to stabilize. * Check tank straps against flow meter. Correct for flush volume after frae. Pump fracture treatment per the attached schedule. * Pump rate should be 20 BPM. * Use silica flour in the PREPAD AND PAD ONLY at 40 lb/1000 gallons. Slurry and flush stages should contain NO silica flour. * The gelled diesel prepad, pad and slurry stages should contain an 8 hour breaker. The flush volume should contain Iow temperature breaker. * The frac schedule may be approximated by smooth ramp-ups using the vendor's computer. * Expected WHTP = 4247 psig (during pad stage) based on: Frac gradient A Sand TVD (mid perf) Tubing Tail (MD) Tubing friction Bleed down annulus pressure after the job. . 0.65 psi/ftTVD 6239' TVD (Tbg Hgr) 8888' MD (Tbg Hgr) 270 psi/1000 ft RECEIVED MAY 2 6 1989 N~k~ Oil & Gas Cons. Commlm~ion · Anchorage WELL 31-08 FRAC PUMP SCHEDULE CLEAN VOLUME PROPPANT DIRTY VOLUME CUMULATIVE STAGE HITS STAGE (BBb) (POUNDS) (BBL) DIRTY VOL (BBb) PERFS @ (BBb) BREAKDOWN 1 00 0 100 1 00 5 5 SD FOR ISIP (30 MINUTES TO ALLOW LEAKOFF OF PREPAD AND PROVE FLOWMETERS) PAD 900 0 900 1000 155 SLURRY STAGES 2 PPG 36.8 3088 40 1040 1055 4 PPG 34.0 5713 40 1080 1095 6 PPG 94.9 23915 120 1200 1135 8 PPG 177.4 59606 240 1440 1255 10 PPG 27.8 11676 40 1480 1495 FLUSH 52 0 52 1532 1535 TOTAL 1423 1 03998 1532 VOLUME TO PERFS (BBL) = 55 BBLS I I PROPPANT = 20/40M CARBOLITE PUMP RATE = 20 BPM ~REAKDOWN F GD + 40 LB/,1000 GAL SIL, ICA FLOUR + 8,HR BREAKER I'~IAD = GD + 40 LB/1000 GAL SILICA FLOUR + 8 HR BREAKER '._~i. URRY = GD + BREAKER , (NO SILICA ,FLOUR) ~;:~) TEMP BREAKER DURING L, AST HALF OF, FLUSH I;:I~BTIMATED TREATING PRESSURE (DURING PAD) = 4247 psi 5/22/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5943 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3I-3 3I-4 3J-10 3J-11 3I-8 3I-7 3I-5 3N-2A CET 2-12-86 6100-7610 CET 2-12-86 6300-8280 CET 2-11-86 5686-7181 CET 2-11-86 6084-7520 CET 3-8-86 7400-9176 CET 3-8-86 4950-7238 CET 3-7-86 6100-9948 CET 2-15-86 7315-8761 · :. Receipt Acknowledged: DISTRIBUTION: Drilling Mobil NSK SAPC Oil & Gas (.;ohs. Commi~iat~ BPAE Anch=,~vron Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~,VlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 7. Permit Number 2. Name of Ooerator ARCO Ala§ka, inc. ~i~,-~,-40 3_Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21550 , 4.2~c~at~Lo~f ~/~lI at surface 9. Unit or Lease Name FWL, Sec.31, T13N, RgE, UM Kuparuk River Unit ~41~o~ Producino Interval 10. Well Number FSI_, 1532' FEL, Sec.5, T12N, R9E, UM 31-8 ~z~_-r_o. taLDepth 11. Field and Pool 5:5 FSL, 1273' FEL, Sec.5, T12N, R9E, UM Kuparuk River Field 5. ~[leyat~(~in feet (indicate KB, DF, etc.) 6~Lease Designation and Serial No. Kuparuk River 0il Pool ~DL 25631 ALK 2564 i 1~.2~ ~/S6P6U d d ed 13. Date T.D. Reached 03/02/86 06/24/86* 14' Date c°mp" Susp' °r Aband'. I15' water Depth' if OffshOre N/A feet MSL ] 16. No. of Completions 1 "1'7. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DireCti'0nal Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9315'MD,6477'TVD 9207 'MD ,6398 'TVD YESx[xl NO [] 1800 feetMDI 1650' (approx.) 22. Type Elect.ric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GCT, CET/GR/Cal 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 ii0~ 24" 7bO sx C5 II ~-5/0~ Sb.0# J-Sb Surf 4639' 12-1/4" 1550 sx CS III & 340 sx Zlass G 7" 2b.U# J-55 Surf 9294' 8-1/2" 300 sx Class G & 175 sx ~'S I '24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9018 'MD 6260 'TVD 2-7/8" 8935 ' 8863 ' 9026 'MD 6266 'TVD 9040'-9060 'MD 6276'-6291 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9060 '-9080 'MD 6291 ' -6305 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addencum, dated 6/26/86, for fracture data N/A 27. 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 .... Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Drilled RR 3/4/86. Perf'd well & ran tubing 5/25/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/093 Submit in duplicate/) 29. f ' .' 30. ~. , GEOLOGIC MARKERS ' "FORMATION TESTS '.. · ., · NAME :' Include interval tested,' pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8841 ' $131' N/A Base Kuparuk C 8899' 5173' Top Kuparuk A 8993' 5242' , , . Base Kuparuk A 9157' 5361' · .. 31. LIST OF ATTACHMENTS Addendum (dated 6/26/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~//~f~g~ ~~ Associate Engineer Signed__ ,,~,~,,, J' Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10~,07 ADDENDUM WELL: 3I-8 3/17/86 3/20/86 6/24/86 Arctic Pak well w/175 sx CS I, followed by 58 bbls Arctic Pak. Rn CET/GR/CAL/gage ring f/9207'-7400'. Rn GCT gyro f/9120'-surf. Frac Kuparuk "A" sand perfs 9018', 9026', 9040'-9060' & 9060'-9086' in 9 stages per 6/23/86 (revised) procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd ann to 2200 psi w/diesel. Tst ins to 8100 psi; OK. Stage #1: 20 bbls 140° diesel w/5% Musol @ 6.5 BPM w/3900 psi Stage #2: 73 bbls gel/diesel @ 11-20 BPM w/7000-5800 psi Stage #3: 20 bbls gel/diesel pre-pad @ 20 BPM w/4700-4520 psi Stage #4: 20 bbls gel/diesel w/1 ppg 100 mesh @ 21BPM w/4520-4500 psi Stage #5: 134 bbls gel/diesel pad @ 21BPM w/4500-4430 psi Stage #6: 20 bbls gel/diesel w/3 ppg 20/40 @ 21BPM w/4430-4550 psi ("on fly") Stage #7: 37 bbls gel/diesel w/6 ppg 20/40 @ 20 BPM w/4550-5240 psi ("batch") Stage #8: 25 bbls gel/diesel w/8 ppg 20/40 @ 20 B?M w/5240-5470 psi ("batch") Stage #9: 49 bbls gel/diesel flush @ 20-15 BPM w/5470-8000 psi. Screened out 5 bbls short of full displacement. Pmp'd 850# 100 mesh & 18,894# 20/40 in formation leaving 1350# 20/40 in csg. Load to recover 398 bbls of diesel. Job complete @ 1750 hrs, 6/24/86 Released to Production to flow f/cln up. ' Drill n~ Supervi6_o~ /Date STATE OF ALASKA ALASKA b,- AND GAS CONSERVATION CO~V~MISSION ¥,~:: WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDEDX~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, I nc. i~-40 3. Address 8. APl Number' P. 0. Box 100360, Anchorage, AK 99510 50- 029-21550 4. Location of well at surface 9. Unit or Lease Name 230' FSL, 47' FWL, Sec.31, T13N, R9E, UM L~'~~ Kuparuk River Unit At Top Producing Interval 10. Well Number 1449' ESL, 1532' FEE, Sec.5, T12N, R9E~ UM ISur~Sur',.~ ~'~ ' ,"-I 31-8 At Total Depth~B.~-t.~-~----~ 11. Field and Pool 1253' FSL, 1273' FEL, Sec.5, T12N, R9E, UM ........................ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 71' RKB ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/23/86 03/02/86 03/04/86 N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9315'MD,6477'TVD 9207 'MD ,6398 'TVD YES ®x NO []I N/A feet MD 1650' (approx) 22. Type Electric or Other Logs Run DIL/CR/SP/SFL, FDC/CNL, Cal, GCT, CET/GR/Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 250 sx 'CS II 9-5/8" 36.0# J-55 Surf 4639' 12-1/4" 1550 sx CS Ill & 340 s: Class C 7" 26.0# J-55 Surf 9294' 8-1/2" 300 sx Class G & 175 s~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~1~ 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 RECEIVED APR 1 6 1986 AJaska 0il & Gas Cons. Commission Form 10-407 DAM2/WC06 Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE GEOLOGIC MA'-R KERS 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH TRUE VERT. DEPTH 6131 ' 6173' 6242' 6361 ' 8841' 8899' 8993' 9157' 30. i ~ FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-- ., ing and th~ Ioc~iti.on or, the cementing tool. Item 27: Method. of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In~ jection, Ga~'lnjection, 'Shut-in, Other-explain. · Item 28' If ~° ,cores.taken, indicate "none". Form 10-407 q/ll/0o ~UB.~URFACE DIRECTIONAL ~URVEY [~UIDANCE [~[ONTINUOUS E~OOL Company ARCO ALASKA INCORPORATED Well Name WELL 3.1-8 (230'F. SL, 4..7'FWL, S31, Ti~N, R9E') Field/Location ~u~ARu~:, ~0[~ SLOPF., ALASKA i i II i i i i Job ,Fleferen ,c, e ,No; 71356 Loaaed By; sARBER Date 18-MARCH- 1986 C ,omputed 8¥: HALSTEAD GCT DIRECTIgNAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 31-8 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 08 MAR 86 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTZON: mORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 46 DEG 40 MIN EAST CDHPUT~TIg~ DAT~: 18-M~R-86 PAGE I ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA INTERPOLflT:D VALUES FOR TRUE SUB-SE& ~EASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0,00 0,00 -71.00 100,00 99,90 28,90 200,00 199,90 128,90 300,00 299.89 228.89 400,00 399.89 328,89 500.00 499.88 428.88 ( '.00 599.65 528.65 .00 698.87 627.87 800.00 797.15 726.15 900.00 894.64 823.64 1000,00 991.00 920,00 1100,00 1086,38 1015,38 1200,00 1179,82 1108.82 1300.00 1270,70 1199.?0 1400,00 1358,93 1287,9.3 1500.00 1444.09 1373.09 1600.00 1526,51 1455,51 1700,00 1608.26 1537.26 1800.00 1690.40 1619.40 1900,00 1771.39 1700,39 2000.00 1849.67 1778,67 2100,00 1925,67 1854,67 2200.00 1999,95 1928.95 2300,00 2071.51 2000.51 2400.00 2139.28 2068.28 2500.00 2202.37 2131.37 6 ~- .00 2260,27 2189.27 7( ,00 2316.07 2245.07 280u.00 2370,98 2299.98 2900,00 2425,65 2354,65 3000.00 2479.73 2408.73 3100.00 2532.34 2461.34 3200.00 2583.90 2512.90 3300.00 2634.03 2563.03 3400.00 2682.93 2611.93 3500,00 2730,49 2659,49 3600,00 2776,66 2705.66 370~,00 2822,46 2751.46 3800,00 2868,94 2797.94 3900.00 2915.88 2844.88 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 0 1 5 9 11 14 EVEN VERTIC SECTi FEE 100 FEET DATE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: ENGINmER: SARBER OF MEASURED DEPTH AL DOGLEG RECTANGULAR ON SEVERITY NORTH/SOUTH T DEG/IO0 FEET 0 0 N 0 0 E 0.00 0.00 0 11 S 13 50 W 0,14 0,22 0 24 S 6 19 E 0.53 0,10 0 29 S 23 34 E 1.19 0.19 33 S 70 24 E 1,92 1,12 54 S 52 19 E 3,73 2,76 21 S 50 41 = 10,18 1.68 4 S 46 2 ~ 22.37 4.22 40 S 46 48 E 40,81 1,84 9 S 47 2 E 63.02 2.82 89,71 1.73 119.74 3,84 155,31 3,84 196,96 3,35 243.99 3,51 296.36 3,23 352.98 0.92 410,53 0,69 467.54 1.66 526,16 2,90 16 33 S 46 8 E 18 51 S 46 49 E 22 45 S 47 11 E 26 20 S 46 57 E 29 47 S 46 40 E 33 19 S 46 56 E 35 2 S 48 23 E 35 10 S 48 48 E 34 54 S 48 6 E 3'7 10 S 48 20 E S 48 41 E 588,34 1,99 S 43 35 E 653,28 0,95 S 48 28 E 720.19 2,13 S 49 0 E 789.97 3,08 S 49 50 E 863.40 3.59 S 50 35 E 940.80 4,04 S 50 36 E 1022,12 0,79 S 50 22 E 1104.92 0.61 S 50 11 E 1188.32 0.37 S 49 46 E 1271.91 0,64 39 34 41 17 43 2 45 42 49 2 52 51 55 44 56 23 56 51 56 50 57 53 58 34 59 26 60 17 61 10 62 2 62 50 62 37 62 3 61 42 S 49 33 E S 49 8 E S 48 57 E S 49 4 E S 48 58 E S 48 51 E S 48 47 E S 48 48 E S 48 24 E 548 4 E 71,00 FT 1355.91 1.11 1440.86 0.70 1526.47 1.13 1612.92 0.87 1700.07 0.96 1787,98 0,83 1876.61 0,49 1965.44 0.35 2053,93 0.43 2142.19 1.09 COORDINATES HORIZ, DEPARTURE EAST/WEST DIST, AZIMUTH FEET FEET DEG MIN 0,00 N 0,22 S 0.78 S 1,53 S 1,94 S 2,90 S 7,03 S 15,18 S 27,92 S 43.04 S 61. 82. 106. 134. 166. 202 · 240 · 278. 316 · 355 · 397. 440. 484. 530. 578. 627. 679. 732. 785. 839. 893. 949. 1005. 1062. 1119. 1177. 1235. 1294. 1352. 1411. 43 16 32 68 90 80 99 96 83 89 08 O1 36 45 29 84 51 31 67 52 99 38 56 29 5O 29 72 25 75 53 0,00 E 0,00 0,01 W 0,22 0,01 W 0.78 0.19 E 1,54 0,82 E 2,10 2,40 E 3,76 7,37 E 10.18' 16.43 E 22.37 29.76 E 40.81 46.04 E 63,02 65.'38 E 89,71 87,10 E 119,74 113,21 E 155,31 143,71 E 196.96 177,99 E 243,99 216,11 E 296,36 257.92 E 352.99 301.22 E 410.55 343.87 E 467.57 387.61 E 526.21 434.23 E 588.41 483.01 E 653.38 533.16 E 720.32 585.61 E 790.14 641.42 E 863.62 701.09 E 941.12 764.14 E 1022.57 828.15 E 1105,49 892.47 E 1189.02 956.59 E 1272.74 1020.68 E 1356.84 1085.22 E 1441.88 1149.90 E 1527.56 1215.24 E 1614.08 1281,09 E 1701,31 1347,41 E 1789.28 1414.14 E 1877.98 1481,05 E 1966.87 1547,51 E 2055.41 1613,40 E 2143,70 N 0 0 E S 3 25 W S 0 59 w S 7 3 E S 22 52 E S 39 31 E S 46 22 E S 47 16 E S 46 49 E S 46 55 E S 46 47 E S 46 40 E S 46 47 E S 46 51 E S 46 50 E S 46 49 E S 46 56 E S 47 11 E S 47 20 E S 47 26 E S 47 33 E S 47 40 E S 47 44 E S 47 49 E S 47 57 E S 48 9 E S 48 21 E S 48 30 E S 48 38 E S 48 43 E S 48 47 E S 48 49 E S 48 49 E S 48 50 E S 48 51 E S 48 51 E S 48 51 E S 48 51 E S 48 50 E S 48 49 E ARCO ALASKA, INC. 3I-B KUPARUK NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 4000.00 2963.84 4100.00 3012.65 4200.00 3062.18 4300.00 3112.26 4400.00 3163.19 4500,00 3215.00 ' 9.00 3267.62 3,00 3321.51 4~dO.O0 3378.91 4900.00 3439.?0 5000.00 3503.51 5100.00 3567.87 5200.00 3632.45 5300.00 3698.40 5400.00 3764.91 5500.00 3832.81 5600.00 3901.46 5700.00 3970.40 5800'00 4039.49 5900.00 4108.89 6000,00 4178,48 6100,00 4248.29 6200,00 4318.08 6300,00 4387,13 6400,00 4455,37 6500.00 4523.62 · 00 4661.19 6 d. O0 4730.88 6900.00 4799.53 TO00.O0 4866.00 7100.00 4932.21 7200.00 4998.42 7300.00 5064.98 7400.00 5131.27 7500,00 5197.57 7600.00 5264.22 7700.00 5331.36 7800.00 5399,05 7900,00 5467,31 COMPUTATION INTERPOLATED VALUES FOR DATE: 18-MAR-86 P/IGE 2 D4TE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: SARBER EVEN 100 FEET OF MEASURED DEPTH SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH SECTION DEPTH DEG MIN DEG MIN FEET 2892.84 61 3 S 47 36 E 2941.65 60 32 S 47 9 E 2991.18 60 12 S 46 52 E 3041.26 59 34 S 46 32 E 3092.19 59. 6 S 46 12 E 3144.00 58 36 S 45 41 E 3196.62 57 57 S 45 25 E 3250,51 56 21 S 45 10 E 3307,91 53 47 S 45 29 E 3368,70 51 19 S 45 45 E 49 58 S 46 20 E 49 55 S 46 55 E 49 10 S 46 17 E 48 32 S 45 44 E 47 53 S 45 31 E 46 47 S 43 21 E 45 30 S 43 4 E 46 21 S 43 44 E 46 11 S 43 2 E 46 0 S 41 14 E 3432.51 3496.87 3551.45 3627.40 3693.91 3761.81 3830.46 3899.40 3968.49 4037.89 4107,48 45 47 S 41 31 E 4177.29 45 40 S 42 14 E 4247.08 46 1 S 41 36 E 4316,13 46 43 S 39 36 E 4384,37 47 1 S 39 15 E 4452.62 46 54 S 39 39 E 4521.12 46 38 S 39 59 E 4590.19 45 55 S 40 32 E 4659,88 45 57 S 40 52 E 4728,53 47 31 S 40 17 E 71.00 4795.00 48 41 S 39 12 E 4861.21 48 25 S 39 2 E 4927.42 48 26 S 39 33 E 4993,98 48 23 S 40 13 E 5060,27 48 29 S 40 56 E 5126.57 48 26 S 42 2 E 5193,22 47 59 S 43 5 E 5260,36 47 34 S 43 40 E 5328,05 47 12 S 44 27 E 5396.31 46 43 S 45 34 E DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH DEG/IO0 FEET CDDR EAST FEE OlNATES HORIZ. DEPARTURE /WEST DIST. AZIMUTH T FEET DEG MIN 2229.93 2317.20 2404.07 2490.62 2576.67 2662.20 2747.22 2831.43 2913.28 2992.66 0,74 1470,45 S 0,48 1529,54 S 0,40 1588.77 S 0,63 1648.14 S 0,80 1707.52 S 0,98 1766.99 S 1.04 1826.56 S 3.33 1885.81 S 2,40 1943,42 S 2.48 1998.92 S 1678. 1742. 1806. 1869. 1931. 1992. 2053. 2113. 2171, 2228. 42 E 2231.44 S 48 46 E m 66 E 2318 70 S 48 43 : 21 E 2405,53 S 48 39 c 18 E 2492,03 S 48 35 E 48 E 2578.03 S 43 31 E 95 E 2663.48 S 48 26 E 64 E 2748.41 S 48 20 E 51 E 2~32.53 S 48 15 E 69 E 2914.29 S 48 10 E 46 E 2993.6i S 48 6 E 3069.64 3146.18 3222.53 3297.68 3372.35 3445.70 3518.26 3590,59 3662,78 3734,54 0.49 2052.37 0.35 2104.90 2.07 2157.12 0.60 2209.56 1.77 2261.57 1,48 2313.92 0,53 2367,14 0.49 2419.76 1.49 2472.04 0.68 2525.51 S 2283.86 E 3070.55 S 48 3 E S 2339.53 E 3147.06 S 48 1 E S 2395.22 E 3223.39 S 47 59 E S 2449.08 E 3298.50 S 47 56 E S 2502.66 E 3373.13 S 47 53 E S 2554,11 E 3446,40 S 47 49 E S 2603,66 E 3518,86 S 47 43 E S 2653,45 E 3591.10 S 47 38 E S 2703,38 E 3663,23 S 47 33 E S 2751,59 E 3734,89 S 47 27 E 3506.02 3877.38 3948.77 4020.71 4093.18 4165.69 4238.02 4309.88 4381.22 4453,52 0.63 2579.52 S 2798. 0.35 2632.80 S 2846. 1.42 2685.89 S 2894. 1,95 2740,76 S 2941, 0.35 2797.45 S 2988. 0.08 2853.85 S 3034. 0.64 2909.82 S 3081. 1.30 2965.04 S 3127. 1,15 3019.36 S 3174, 2,08 3074,51 S 3222, 90 E 3806.28 S 47 20 E 73 E 3877.57 S' 47 14 E 80 E 3948.91 S 47 8 E 93 E 4020.79 S 47 1 E 09 E 4093.21 S 46 53 E 56 E 4165.70 S 46 45 E 20 E 4238.02 S 46 38 E 90 E 4309.89 S 46 31 E 72 E 4381.26 S 46 26 E 09 E 4453.59 S 46 20 E 4527.69 4601.95 4676.27 4750.38 4824.82 4899.37 4973,74 5047.72 5121.26 5194,30 1.22 3131.91 S 3269. 0.54 3190.22 S 3316. 1.25 3248.22 S 3364. 0.52 3305.47 S 3412. 0.78 3362.36 S 3460. 1.02 3418.46 S 3510. 0.24 3473.29 S 3561. 0.83 3527.18 S 36.11. 1,04 3580,09 S 3663, 1.02 3631.75 S 3714. 91 E 4527.82 S 46 14 E 99 E 4602.16 S 46 6 E 45 E 4676.58 S 46 0 E 31 E 4750.79 S 45 54 E 98 E 4825.34 S 45 49 E 55 E 4899.98 S 45 45 E 06 E 4974.42 S 45 42 E 93 E 5048,47 S 65 40 E 11 .E 5122.05 S 45 39 E 79 E 5195.12 S 65 38 E FT ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 18-MAR-86 PAGE DATE OF SURVEY: 05 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPT~ TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 71.00 FT 8000.00 5535.93 5464.93 46 39 8100.00 5604.80 5533.80 46 19 8200.00 5674.06 5603.06 45 55 8300.00 5743.85 5672.85 45 28 8400.00 5814.27 5743.27 45 0 8500.00 5885.19 5814.19 44 34 ( ~' %.00 5956.63 5885,63 44 16 J.O0 6028.52 5957.52 43 50 88U0.00 6100.97 6029.97 43 14 8900.00 6173.94 6102.94 43 5 S 46 26 E 5267.04 S 47 24 E 5339.54 S 48 36 E 5411.65 S 49 43 E 5483.20 S 50 35 E 5554.07 S 51 27 E 5624.36 S 52 10 E 5694.04 S 52 28 E 5763.20 S 52 32 E 5831.78 S 52 40 E 5899.79 0.68 0.85 1.19 1.05 0.63 0.84 0.58 0.46 0.65 0.20 3682.28 S 3767.13 E 526T.87 S 45 39 E 3731.80 S 3820.07 E 5340.35 S 45 40 E 3780.08 S 3873.66 E 5412.42 S 45 42 E 3826.90 S 3927.85 E 5483.90 S 45 44 E 3872.35 S 3982.40 E 5554.70 S 45 48 E 3916.69 S 4037.22 E 5624.91 S 45 52 E 3959.93 S 4092.22 E 5694.50 S 45 56 E 4002.32 S 4147.31 E 5763.57 S 46 1 E 4044.33 S 4201.96 E 5832.07 S 46 5 E 4085.79 S 4256.34 E 5900,01 S 46 10 E 9000.00 6246.90 6175.90 43 10 9100.00 6319.76 6248.76 43 19 9200.00 6392.66 6321.66 43 10 9300.00 6465.58 6394.58 43 10 9315.00 6476.52 6405.52 43 10 S 52 48 E 5967.80 S 52 53 E 6035.88 S 52 56 E 6103.94 S 52 56 E 6171.95 S 52 56 E 6182.16 0.33 0.42 0.00 0.00 0.00 4127.26 S 4310.72 E 5967.96 S 46 14 E 4168.60 S 4365.31 E 6035.99 S 46 19 E 4209,87 S 4419.94 E 6104.00 S 46 23 E 4251.11 S 4474.54 E 6171.99 S 46 28 E 4257.29 S 4482.74 E 6182.19 S 46 28 E VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN COHPUTATiON DATE: 18-MAR-85 PAGE 4 ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 1000 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN VERTICAL DOGLEG SECTION SEVERITY FEET DEG/100 0.00 0.00 -71.00 0 0 N 0 0 E 1000.00 991.00 920.00 16 33 S ~6 8 E 2000.00 1849.67 17T8.67 39 34 S 48 41 E 3000.00 2479.73 2408.73 57 53 S 49 33 E 4000.~0 2963.84 2892.84 61 3 S 47 36 E 5000.00 3503.51 3432.51 49 58 S 46 20 E 6r 3.00 4178.48 4107.48 45 47 S 41 31 E 7( ~.00 4866,00 4795.00 48 41 S 39 12 E 80u0.00 5535.93 5464.93 46 39 S 46 26 E 9000.00 6246.90 6175.90 43 10 S 52 48 E 0.00 0.00 89.71 1.73 588.34 1.99 1355.91 1.11 2229.93 0.74 3069.64 0.49 3806.02 0.63 4527.69 1.22 5267.04 0.68 5967.80 0.33 DATE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: 71.00 =T ENGINEER: SARBER MEASURED DEPT RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 0.00 N 0.00 E 0.00 N 0 0 E 61.43 S 65.38 E 89.71 S 46 47 E 397.08 S 434.23 E 588.41 S 47 33 E 893.99 S 1020.68 E 1356.84 S 48 47 E 1470.45 S 1678.42 E 2231,44 S 48 46 E 2052.37 S 2283.86 E 3070.55 S 48 3 E 2579.52 S 2798.90 E 3806.28 S ~7 20 E 3131.91 S 3269.91 E 4527.82 S 46 14 E 3682.28 S 3767.13 E 5267.87 S 45 39 E 4127.26 S 4310.72 E 5967.96 S 46 14 E 9315.00 6476.52 6405.52 43 10 S 52 56 E 6182.16 0.00 4257.29 S 4482.74 E 6182.19 S 46 25 E COMPUTATION OATE: ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FSR :VEN MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEG MIN GEG MIN VERTIC SECTI FEE 0.00 71.10 171.10 271.10 371.11 471.12 1.25 I.B2 773.32 875.64 0.00 -71.00 0 0 71.00 0.00 0 13 171.00 100.00 0 23 271.00 200.00 0 28 371.00 300.00 0 25 471.00 400,00 1 16 571.00 500.00 4 34 671.00 600.00 7 52 771.00 700.00 11 11 871.00 800.00 13 28 N 0 0 S 12 40 S 1 54 S 19 14 S 77 Z S 56 24 S 50 17 S 46 55 S 46 35 S 47 16 O. O. O, O. 1. 2. 7. 18. 35, 57. 979.14 1083.79 1190.48 1300.33 1413.91 1532.38 1654,38 1776.39 1899.51 2027.76 971.00 900.00 16 10 1071.00 1000.00 18 20 1171.00 1100.00 22 24 1271.00 1200.00 26 21 1371.00 1300.00 30 17 1471.00 1400.00 34 14 1571.00 1500.00 35 9 1671.00 1600.00 34 36 1771.00 1TO0.O0 37 9 1871.00 1800,00 40 8 S 46 12 E S 46 38 E S 47 13~ S 46 57 E S 46 40 E S 47 18 E S 48 46 E S 48 6 E S 48 20 E S 48 41 E 83. 114, 151. 197, 250. 314. 384. 454, 525. ,506. 2160.67 2299.27 2449.21 2619.14 2800.03 2983.54 .74 .36 35~1.56 3804.38 1971.00 1900.00 42 11 2071.00 2000.00 45 41 2171.00 2100.00 50 50 2271.00 2200.00 55 52 2371.00 2300.00 56 51 2471.00 2400,00 57 43 2571.00 2500.00 59 10 2671.00 2600.00 60 57 2771.00 2700.00 62 47 2871.00 2800.00 62 3 S 48 S 49 S 50 S 50 S 50 S 49 S 48 S 48 S 48 S 48 29 0 18 34 11 35 58 59 47 23 693. 789. 900. 1037. 1188. 1341. 1504. 1678. 1865. 2057. 4014.75 4217.78 4415.16 4606.37 4786.53 4949.46 5104.86 5258.56 5409.11 5555.69 2971.00 2900.00 60 58 3071.00 3000.00 60 8 3171.00 3100.00 58 58 3271.00 3200.00 57 54 3371.00 3300,00 54 5 3471.00 3400.00 50 15 3571,00 3500.00 49 56 3671.00 3600.00 48 40 3771.00 3700,00 47 46 3871.00 3800.00 46 38 S 47 S 46 S 46 S 45 S 45 S 46 S 46 S 45 S 45 S 42 33 47 7 24 26 0 57 39 24 53 E 2242. E 2419. E 2589. E 2752. E 2902. E 3030, E 3149, E 3266. E 3379. E 3486. 18-MAR-86 PAGE 5 DATE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: SARBER 71.00 FT 100 FEET OF SUB-SEA DEPTH AL DOGLEG RECTANGULAR COORDINATES ON SEVERITY NORTH/SOUTH EAST/WEST T DEG/iO0 FEET FEET HORIZ. DIST. FEET DEPARTURE AZIMUTH DEG MIN O0 0.00 0.00 N 0.00 E 09 0.26 0.12 S 0.02 E 38 0.12 0.58 S 0.03 W 97 0,18 1.30 S 0.10 E 73 0.09 1.88 S 0.60 E 96 1.56 2.44 S 1.76 E 67 3,46 5.43 S 5.43 E 19 4.57 12.29 S 13.41 E 53 1.54 24.31 S 25.92 E 14 2.78 39.04 S 41.72 E 0.00 N 0 0 E 0.12 S 9 20 E 0.58 S 2 50 W 1.31 S 4 26 E 1.97 S 17 42 E 3.01 S 35 53 E 7.67 S 44 59 E 18.19 S 47 29 E 35.53 S 46 50 E 57,14 .S 46 54 E 81 2.01 57.34 S 61.12 E 63 3.25 78.66 S 83.39 E 70 3.76 103.88 S 110.56 E 10 3,35 134.78 S 143.82 E 91 3.86 171.64 S 183,02 E 39 2.54 215,08 S 229.30 E 24 0.37 261.63 S 281.42 E 10 1.20 307,84 S 333,87 E 85 2.90 355,69 S 387.38 E 10 2.01 408.81 S 447,58 E 83.81 S 46 49 E 114.63 S 46 40 E 151.71 S 46 47 E 197.11 S 46 51 E 250.91 S 46 50 E 314.39 S 46 49 E 384.25 S 47 5 E 454,13 S 47 19 E 525.91 S 47 26 E 606.18 S 47 35 E 58 2.19 466.70 S 513.23 E 45 3.08 530.11 S 585.21 E 95 3.93 602.42 S 670.28 E 93 0.69 689.56 S 776,38 E 34 0.37 785,69 S 892,49 E 97 1.50 884.94 S 1010.05 E 77 1.04 991.30 S 1133.53 E 53 0.91 1105.35 S 1264.82 E 55 0.79 1228.43 S 1405.81 E 80 0.41 1355.32 S 1550.41 E 693.70 S 47 43 E 789.61 S 47 49 E 901.21 S 48 3 E 1038.40 S 48 23 E 1189.05 S 48 38 E 1342.88 S 48 46 E 1505.84 S 48 49 E 1679.75 S 48 50 E 1866.90 S 48 51 E 2059.28 S 48 50 E 82 0,53 1479.15 S 1687,95 E 50 0.70 1599.33 S 1817.46 E 67 1.00 1716.51 S 1940.85 E 62 1.11 1830.35 S 2057.49 E 38 2.27 1935.77 S 2163.92 E 95 1.82 2025.58 S 2255.94 E 90 0.33 2107.44 S 2342.24 E 59 0.56 2187.81 S 2426.85 E 12 2.08 2266.29 S 2507.51 E 15 0.39 2343.58 S 2581.73 E 2244.34 S 48 46 E 2420.95 S 48 39 E 2591.01 S 48 30 E 2753.80 S 48 20 E 2'903.40 S 48 11 E 3031,87 S 48 4 E 3150.78 S 48 1 E 3267.43 S 47 57 E 3379.90 S 47 53 E 3486.79 S 47 46 E COMPUTATION ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA DATE: 18-MAR-86 TRUE MEASURED VERTICAL DEPTH DEPTH INTERPOLATED VALUES ~OR ;VEN 100 FEET OF 5700.87 3971.00 5845.45 4071.00 5989.27 4171.00 6132.49 4271.00 6276.53 4371.00 5422.92 4471.00 '9.18 4571.00 ~.06 4671.00 6op8.10 4771.00 7007.59 4871.00 SUB-SEA COURSE VERTICAL DOGLEG VERTICAL DEVIATION AZIMUTH SECTION SEVERITY DEPTH DEG MIN DEG MIN FEET DEG/IO0 7158.49 4971.00 7309.06 5071.00 7459.89 5171.00 7610.13 5271.00 7758'60 5371.00 7905.37 5471.00 8051.01 5571.00 8195.60 5671.00 8338.66 5771.00 8480.05 5871.00 3900.00 46 21 S 43 45 E 3591.22 0.49 4000.00 46 1 S 42 6 E 3695.46 1.52 4100.00 45 48 S 41 26 E 379~.36 0.54 4200.00 45 39 5 42 17 E 3900.55 0.26 4300.00 46 30 S 40 6 E 4003.78 1.73 4400.00 46 59 S 39 22 E 4109.81 0.39 4500,00 46 41 S 39 52 E 4215.74 0.44 4600.00 45 53 S 40 37 E 4319.89 1.00 4700.00 46 45 S 40 36 E 4423.02 1.73 4800.00 48 41 5 39 6 E 4533.35 1.19 8620.06 5971.00 8758.80 6071.00 8895.98 6171.00 9033.03 6271.00 9170.30 6371.00 9307.44 6471.00 9 ~' ~.00 6476.52 4900.00 48 35 S 39 20 E 4645.35 0.58 5000.00 48 25 S 40 16 E 4757.11 0.45 $100.00 48 27 S 41 34 E 4869.44 0.88 5200.00 47 58 S 43 8 E 4981.25 0.33 5300.00 47 23 S 44 6 E 5090.84 0.61 5400.00 46 42 S 45 37 E 5198.20 0.96 5500.00 46 26 S 46 54 E 5304.08 0.89 5600.00 45 57 S 48 33 E 5408.50 1.26 5700.00 45 19 S 50 7 E 5510.67 0.90 5800.00 44 40 S 51 18 E 5610.38 0.75 5900.00 44 11 S 52 18 E 5707.97 0.64 6000.00 43 30 S 52 25 E 5803.65 0.77 6100.00 43 5 S 52 40 E 5897.05 0.20 6200.00 43 11 S 52 51 E 5990.26 0.34 6300.00 43 10 S 52 56 E ~ 6083.74 0.00 6400.00 43 10 S 52 56 E 6177.01 0.00 6405.52 43 10 S 52 56 E 6182.16 0.00 PAGE 6 DATE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: SARBER 71.00 SUB-SEA DEPTH RECTANGULAR COOROINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FEET FEET FEET DEPARTURE AZIMUTH DEG MIN 2420.22 S 2653.89 E 3591.73 2496.14 S 2725.56 E 3695.86 2573.75 S 2793.81 E 3798.63 2649.99 S 2862.38 E 3900.72 2727.68 S 2931.00 E 4003.87 2810.42 S 2998.72 E 4109.83 2892.61 S 3066.80 E 4215.74 2972,67 S 3134.46 E 4319.91 3051.16 S 3202.18 E 4423.07 3136.33 S 3273.52 E 4533.49 S 47 38 E S 47 30 E S 47 20 E S 47 12 E S 47 3 E S 46 51E S 46 40 E S 46 31 E S 46 23 E S 46 13 E 3224.15 S 3344.64 E 4645.62 3310.65 S 3416.68 E 4757.53 3396.08 S 3490.52 E 4870.02 3478.78 S 3566.20 E 4981.94 3558.29 S 3641.86 E 5091.62 3634.47 S 3717.59 E 5199.02 3707.69 S 3794.08 E 5304.90 3778.00 S 3871.29 E 5409.27 3844.61 S 3948.92 E 5511.35 3907.93 S 4026.26 E 5610.94 S 46 3 E S 45 54 E S 45 47 E S 45 42 E S 45 39 E S 45 38 E S 45 39 E S 45 41 E S 45 46 E S 45 51 E 3968.50 S 4103.28 4027.11 S 4179.53 4084.12 S 4254.15 4140.90 S 4328.73 4197.62 S 4403.72 4254.17 S 4478.60 4257.29 S 4482.74 E 5708.41 S 45 57 E E 5803.97 S 46 3 E E 5897.28 S 46 10 E E 5990.40 S 46 16 E E 6083.82 S 46 22 E E 6177.05 S ~6 28 E E 6182.19 S 46 28 E FT COMPUTATION DATE: 18-MAR-86 ? ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLGPE,ALASKA MARKER TOP KUP~RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A ~TD INTERPOLATED VALUES FOR MEASURED DEPTH ~ELOW KB 8841.00 8899.00 8993.00 9157.00 9207.00 9315.00 CHOSEN HORIZONS FROM KB 6130.87 6173.21 6241.80 6361.30 6397.76 6476.52 ORIGIN: TVD DATE OF SURVEY: 08 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: SARBER 71.00 230 ' SUS-SEA 6059.87 6102.21 6170.80 6290.30 6326.76 6405.52 FSL, SURFACE LOC 47' FWL, SEC 31, RECTANGULAR CO NORTH/SgU'TH 4061.35 S 4085.38 S ~124.36 S 4192.14 S 4212.76 S 4257.29 S ATION T13Nt RgMt ORDINATES EAST/WEST 4224.25 E 4255.79 E 4306.90 E 4396.46 E 4423.76 E 4482.74 E FT UM COMPUTATION DATE: iS-MAR-S6 PAGE 8 ARCO ALASKA, INC. 3I-8 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A ~BTO ~*~**~*~* STRATIGRAPMIC MEASURED DEPTH BELOW KB 8841.00 8899.00 8993.00 9157.00 9207.00 9315.00 DATE OF SURVEY: 08 MAR 86 KELLY ~USHING ELEVATION: 71.00 ENGINEER: SARBER FRGM ORIGIN: 230' TVD SUB-SEA FSL, 47' FW REC NO SURF L S T~NG RTH/ ACE LOCATION AT EC 31 T13N, R9M, ULAR ~OOROINATES SOUTH EAST/WEST 6130.87 6173.21 5241.80 6361.30 6397.76 6476.52 6059.87 6102.21 6170.80 6290.30 6326.76 6405.52 061. 085. 124. 192. 212. 257. 35 S 4224.25 E 38 S 4255.79 E 36 S 4306.90 E 14 S 4396.46 E 76 S 4423.76 E 29 S 4482.74 E FT UM FINAL MEASURED OEPTH 9315.00 WELL LOCATION T~UE' VERTICAL DEPTH 6476.52 AT TD: SUB-SEA VERTICAL DEPTH 6405.52 HORIZONTAL OEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6182.19 S 46 28 SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL S ! -8 FIELD KUPARUK COUNTRY USA RUN DATE LOOOED 08 - MAR - 86 REFERENCE O000?IBSB WE~L 3I-8 (20'FSL, 47'FWd, S3~1, T13N,"R9E) HORIZONTAL PRO~ECTION NORTH 2000 R£F 0000'7 ! o0o - ~ ooo -2000 -BO00 -4000 -SO00 80UTH -6000 -2000 SCALE = l/lO00 IN/FT -1000 0 ]000 2000 ~000 4000 6000 6000 E~T WELL 3I-8 (230'~FSL, 47'k%~, S? T13N, R9E) VERTICAL PROJECTION SOUTH -!0000 -8000 -6000 -4000 -2000 0 0 gO00 4000 6000 I NORTH PROJECTION ON VERTICRL PLANE NORTH - SOUTH SCALED IN VERTICAL DEPTHS HORIZ SCRLE = 1/2000 IN/FT WELL 3I-8 (230'FSL, 47'FWL, Sx~L-T13N, R9E) HE VERTICAL'PROJECTION 313. -4000 -gO00 0 0 2000 40 PROJECTION ON VERTICAL PLANE 135. - 313. SC~t. EO IN VERTICPi. OEPTI-ff~ HORIZ SCALE = 1/2000 IN/FT zooo 133. Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, W]~LL NAME'AND NUMBER Reports and Materials to be received by: Date ' Required Date Received Remarks Completion Report ~e~ ?f~<~---~ ~~, Well History s~~s ~~~/ ~'~ .... d/( ,, Mud Log Core Chips Core Description Registered Survey Plat 7~ Inclination Survey , - Dr~ll Stem Test Reports ~roduct~on Test Reports / Digitized Data ARCO Alaska. inc. ~ Post Office .100360 Aflcnorage. ~asKa 99510-0360 Telephone 907 276 1215 ' P~-~CU RN TO: ARCO ALASKA, i~NC. ATTN~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATZ 06-08-86 Transmit'-ed herewi~,h are t~he following items. Please acknowledge receipt and return one signed copy of ~his ~ransmittal. Open Hole Final Prints: Schl: One * of each /2T-l~"~'' DIL/SFV--GR 03-08-86 ~2" .EIL/SFL-GR 03-08-86 ~5" Den/Neu-GR (poro) 03~08-86 5" ~en/Neu-GR (raw) 03-08-86 ?/~2" Den/Neu-GR (raw) 03-08-86 ~Cyberlook 03-08-86 ~roduc:ive I~terval 03-08-86 ~RFT Log 03-08-86 v/3I-9 5" DIL/S?L-GR 03-13-86 2" DIL/S?L-GR 03-13-86 k 5" Den/Neu (poro) 03-13-86 2" Den/Neu (poro) 03-13-86 5" Den/Neu (raw) 03-13-86 2" Den/Neu (raw) 03-13-86 · - Cyber!o0k 03-13-86 '~ 3N-7~ 5" DiL/SFL-GR 03-06-86 ~ii DiL/SFL-GR 03-06-86 .~ ' Den/Neu-GR (pore) 03-06-86 ~ Den/Neu-GR .(porc~ 03-06-86 '~'5" Den/Neu-GR (raw) 03-06-86 2" Den/Neu-GR (=aw) 03-06-86 ~Cyber!ook 03-06-86 Run #1 Run ~-~I Run #1 Run Run #! Run #1 Run Run # 1 Run #I Run :#1 R,?n #1 Run #1 Run #1 Run Run Run #1 Run ~.~1 Run -~1 Run -~/1 Run Run Run Run #1 367i-8365 3671-836,5 367!-834,0 3671-83z.0 3671-8340 3671-8340 7850-83413 785o-8 o 7957-8212 1500-9122 1500-9122 8440-9096 8440-9096 8440-9096 8440-9096 8440-9065 1800-7777 1800-7777 6790-7752 6790-7752 6790-7752 6790-7752 7190-7752 Receipt Acknowledc Run #1 Run #1 Run #1 Run #1 Run #I 1500-9204 1500-9204 8750-9178 8750-9178 8750-9178 8750-9178 )a=e: ~ :ate of Ra:h~eil*b 1 D & M'bi NSK Files*bl Vaul t*f ilms STATE OF ALASKA "' ALASKA, alL AND GAS CONSERVATION COMM~, ..,iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other ~ 2. Name of Operator 5. ARCO Alaska, Inc. R 3. Address 6. P.O. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 7. 230'FSL, 47'FWL, Sec.31, T13N, R9E, UM 3 At top of productive interval 8. 1449' FSL, 1532'FEL, Sec.5, T12N, R9E, UM 8 At effective depth 1297'FSL, 1352'FEL, Sec.5, T12N, R9E, UM At total depth 1253'FSL, 1273'FEL, Sec.5, T12N, R9E, UM Operation shutdown [] Stimulate [] Plugging [] Perforate ~/ Pull tubing Datum elevation (DF or KB) KB 71' Unit or Property name upar~lk River tlni~ Well number I-8 Approval number 0 9. APl number 50-- 029-21550 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 9315 true vertical 6477 Effective depth: measured 9207 true vertical 6398 Casing Conductor Surface Length Size 80 ' 16" 4608 ' 9-5/8" 9271 ' 7" Production feet Plugs (measured) N o n e feet feet Junk (measured) None feet Cemented Measured depth 250 sx CS I I 110'MD 1550 sx CS I II & 4639'MD 340 sx Class G 300 sx Class G & 9294'MD 1 75 sx CS I True Vertical depth 110 ' TVD 3289'TVD 6462 ' TVD Perforation dePth: measured 901 8 ' M D 9026 'MD true vertical 6260 ' TVD 6266 'TVD 9040'-9060'MD 9060'-9080'MD 6276'-6291'TVD 6291'-6305'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8935' Packers and SSSV (type and measured depth) HRP-1SP pkr @ 8863' and TRDP-1A-SSA SSSV ~ 1800' 12. S~/~lation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 4i~ f~~ ;~~ Form 10-404 Rev. 12-1-85 j Title Associ ate Engineer (DAM) SW0/042 Date Submit in Duplicate 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 Rel~ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is r~ot required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska JWell no. 31-8 District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25631 Auth. or W.O. no, T t e AFE Completion Nordic 1 Operator A.R.Co. ARCO Alaska, Inc. Spudded or w.O.completebegun Date API 50-029-21550 W.I. [Total number of wells (active or inactive) on this Jcost center prior to plugging and 56.24% Jabandonment of this well I Hour I Prior status if a W.O. 5/24/86 I 0630 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 5/25/86 0245 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing 7" @ 9294' , ~i~I , .~ '~ .~U~~ 9207' PBTD, RR Diesel / Accept ri~ @ 0630 hr~, 5/24/86. ND tree, NU & tst BOPE. Perf well @ 9018' & 9026~1SPF & 90~0'-9080' @ 4 SPF. Rn 2-7/8", J-55, 6.5#, EUE 8RD AB Mod tbg w/SSSV @ 1800', HRP-1-SP Pkr @ 8863' TT @ 8935' ND BOPE, NU & tst tree Displ well w/diesel RR @ 0245 hrs, 5/25/86. New9207' PBTD TD PB Depth Date Kind of rig 5/25/86 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abo~e is correct Sign at u(~(~~_._~ Date JTitle 6/04/86 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor STATE OF ALASKA ALASK,. OIL AND GAS CONSERVATION COMM,.~$1ON APPLICATION FOR SUNDRY APPROVALS feet 1. Type of Request: Abandon © Suspend ~ Operation Shutdown ~ Re-enter suspended well !'M Alter casing !~i Time extension ~ Change approved program ~ Plugging ~ Stimulate ~. Pull tubing ~ Amend order !; Perforate '.~I Other ~'" 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 229'FSL, 47'FWL, Sec.31, T13N, R9E, UN At top of productive interval 1371'FSL, 1375'FEL, Sec.5, T12N, R9E, UM (approx.) At effective depth 1422'FSL, 1214'FEL, Sec.5, T12N, R9E, UM (approx.) At total depth 1380'FSL~ 1154'FEL, Sec.5, T12N, R9E, UH (approx.) 5. Datum elevation (DF o'r KB) 71 ' RKB 6. Unit or Property name Ku_Daryk River Unit. 7. Well number 3Z-8 8. Permit number 86 -40 9. APl number 50_029 -21550 11. Present well condition summary Total depth: measured 931 5 true vertical 6475 Effective depth: measured 9207 true vertical 6396 Casing Conductor Surface Length 80' 4608 ' 9271 ' Production feet feet feet feet 10. Pool Ku'paruk River Oil Pool Plugs (measured) N o ne Junk (measured) N o ne True Vertical depth 110'TVD 3298 'TVD 6459 ' TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured depth 16" 250 sx CS II 1lO'MD 9-5/8" 1550 sx CS Ill & 4639'MD 340 sx Class C 7" 300 sx Class G & 9294'MD 1 75 sx CS I None RECEIVED MAY 1 4 1986 A!aska 0JJ & 0~s Cons, C0u}mission 12 Attachments · Well Hi story None Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June, 1 986 14. If proposal was verbally approved Date approved Name of approver SA/037 Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~-u~ ~~ .,~,-~JL'/'~ ~ ~j,t_~ Title As socia te Engineer Signed ~/ Commission Use Only ( DAM ) Conditions of approval Notify commiSsion so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner IAppr°val N°' ~ by order of the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report- Dally Inetructione: Preoare and submit the "Initial Repo~' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summa~zed on the form giving inclusive dates only. District ICounty, parish or borough North Slope Borough ILease or Unit 25631 Title I Drill IState Field Alaska Kuparuk River Alaska IWell no. 3I-8 Auth. or W.O, no. AFE AK0979 Parker 141 API 50-029-21550 Operator ]ARCO W.I. ARCO Alaska, Inc. SpuddedorW.O. begUnspudded ]Date 2/23/86 IH°ur 2315 hrs. IPri°rstetusifaw'O' D~e and depth as of 8:~ a.m. 2/22/86 thru 2/24/86 2/25/86 2/26/86 2/27/86 2/28/86 Complete record for each day reported 56.24% 16" @ 110' 680', (585'), Drlg Wt. 9.3, PV 10, YP 18, PH 9.5, WL 16.4, Sol 6 Accept rig @ 1900 hfs, 2/23/86. NU diverter sys. Spud well @ R Ir E IV ED 16" ~ 110' ~g. 9.6, PV 11, YP 19, PR 10, ~ 17, Sol 7 Drl & su~ 12k" hole to 2695'. 1062'~ 17.8:, S45.4E, 1051.24 T~, 102.21 VS, 1464', 32.1°, S46.1E, 1414.75 T~, 272.01 VS, 189.28S, 1952'41E 1971', 39.0~, S48.SE, 1829.63 T~, 562.93 VS, 384.43S, 411.28E 2535', 54.2°, S50.0E, 2224.30 T~, 963.78 VS, 647.15S, 714.47E 16" @ 110' 4288', (1593'), Drlg Wt. 9.7, PV 12, YP 18, PH 9.5, WL 14.2, Sol 9 Drl & surv 12¼" hole to 4288'. 2902', 57.1°, SSO.8E, 2431.38 TVD, 1266.04 VS, 840.29S, 947.93E 3221', 59.8°, $49.7E, 2598.29 TVD, 1537.38 VS, 1014.12S, 1156.94E 3564', 62.3°, S49.0E, 2764.32 TVD, 1837.12 VS, 1209.64S, 1384.66E 3986', 61.3°, S53.7E, 2963.74 TVD, 2207.64 VS, 1441.92S, 1675.11E 9-5/8" @ 4639' 4660', (372'), ND diverter Wt. 10, PV 10, YP 15, PH 9.5, WL 14.8, Sol 9 Drl & surv 12¼" hole to 4660', short trip, circ, POOH. RU & rn 116 ]ts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4639', FC @ 4556'. Cmt w/1550 sx CS III & 340 sx C1 "G". ND diverter. 4239', 60.3°, S51.3E, 3087.17 TVD, 2427.35 VS, 1576.36S, 1850.32E 4550', 58.3°, S48.7E, 3245.93 TVD, 2694.29 VS, 1748.22S, 2055.17E 9-5/8" @ 4639' 5157', (497'), Turbine drlg Wt. 9, PV 6, YP 3, PH 10, WL 22.4, Sol 5 ND diverter, NU & tst BOPE. RIH w/BHA, DO FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Rotary drl f/4660'-4977', turbine drl to 5157'. 4942', 50.5°, S44.2E, 3474.12 TVD, 3013.02 VS, 1967.82S, 2286.18E The above is correct Signature ~ ~___~~~. For form preparation and dlstributlol~ see Procedures Manual, Section 10,- Drilling, Pages 86 and 87. IDate/ . ] Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentia ly. Attach descri,ption of all cores..Work pe.rfo.rmed by Prod, ucin~ S?ction will be reported on "Interim" sheets until final completion. Report official or representative test on "~-inal" form. 1) Suomit "lnlerlm" sheets when nheo out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I Alaska Field ~Lease or Unit Kuparuk River! ADL 25631 Complete record for each day while drilling or workover in progress IState North Slope Borough Date and deptl~ as of 8:00 a.m. 3/01/86 thru 3/03/86 3/04/86 Alaska Well no. 3I-8 9-5/8" @ 4639' 9315', (4158'), Chg brake pads Wt. 9.9, PV 11, YP 6, PH 8.5, WL 9, Sol 12 Turbine drl & surv 8½" hole to 9315', 50 std short trip, circ, POOH. RU Schl, log DIL/GR/SP/SFL f/9315'-4634', cont w/GR to 1500'. Rn FDC/CNL f/9315'-8750', CAL f/9315'-4634', RD Schl. Chg brake pads. 5456', 47.3°, S46.4E, 3812.01TVD, 3400.24 VS, 2240.27S, 2561.50E 6420', 7449', 7946', 8447', 8886'~, 9240', 47.2°, S40.9E, 4473.46 TVD, 4100.39 VS, 2746.90S, 3046.10E 48.6°, S45.4E, 5160.78 TVD, 4864.34 VS, 3307.76S, 3567.24E 46.6°, S48.3E, 5495.91 TVD, 5231.35 VS, 3558.76S, 3835.00E 44.8°, S54.2E, 5845.82 TVD, 5588.77 VS, 3783.19S, 4114.64E 43°, S54.3E, 6162.14 TVD, 5890.51 VS, 3961.04S, 4361.69E 43.4°, S55.9E, 6420.19 TVD, 6130.22 VS, 4099 69S, 4560.44E 9-5/8" @ 4639' 9315', (0'), Rn'g 7" csg Wt. 10, PV 11, YP 4, PH 8.5, WL 7.6, Sol 12. RIH, 20 std short trip, circ, LD DP. Chg rams & begin rn'g 7" csg. The above is correct Signature For form preparation an~ distribution see Procedures Manual ~ection 10, Drilling, Pages 86 and 87 Date JTitle 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 official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish State Alaska North Slope Borough Field Kuparuk River Auth. or W.O. no. AFE AK0979 Lease or Unit Title ADL 25631 Drill Alaska IWe,, ~-8 Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded API 50-029-21550 A.R.Co. W.I. 56.24% Date I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our I Prtor status if a W.O. 2315 hrs. I 2/23/86 Date and depth as of 8:00 a.m, 3/05/86 Complete record for each day reported 7" @ 9294' 9207' PBTD, 9315' TD, RR 10.0 ppg NaC1/NaBr Rn 222 its, 7", 26#, J-55 BTC csg w/FC @ 9207', FS @ 9294'.Cmt w/lO0 sx C1 "G" w/2% A-2, 1% R-7 & 2 GHS FP-SL, followed by 200 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1 GHS FP-SL. CIP @ 1330 hrs, 3/4/86. ND BOPE. NU & tst tree. RR @ 1930 hfs, 3/4/86. Old TD New TO 9315' TD Released rig Date 1930 hrs. 3/4/86 Classifications (oil, gas, etc.) 011 Flowing Producing method PB Depth K nd of rig Type completion (single, dual, etc.) Single 9207 ' PBTD Rotary Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test !Gas Der day Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature /~ Date ]Title I For form preparation and0diStributi°n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska. In,.,. Post Office Box 100360 Ancl~orage. AlasKa 99510-0360 Telephone 9G:" 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DAI~E 04-01-86 TRANSMITTAL # 5613 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tapes plus Listings: Schl: One of each 3N-9 03-23-86 Run 3N-8 03-14-86 Run 3N-8A 03-19-86 Run 3N-7 03-06-86 Run 31-12 03-22-86 Run 3I-9 03-13-86 Run 3i-8 03-02-86 Run 2T-17 03-08-86 Run Receipt Acknowledged: state 0f AK. ~--' STATE OF ALASKA ..... ~ r~ ALASKA ~..~. AND GAS CONSERVATION CO,.,MISSION ~_- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS i 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-40 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21550 4. Location of Well at surface 229' FSL, 47' FWL, Sec.31, T13N, R9E, UM I 6. Lease Designation and Serial No. ADL 25631 ALK 2564 For the Month of. February , 19 86 5. Elevation in feet (indicate KB, DF, etc.) 71 ' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2315 hrs, 2/23/86. Drld 12-1/4" hole to 4660'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9315'TD (3/2/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 9207'. Secured well & RR ~ 1930 hrs, 3/4/86. 13. Casing or liner rMn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/250 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4639'. Cmtd w/1550 sx CS III & 340 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 9294'. Cmtd w/300 sx Class G. 14. Coringresumeand briefdescription None 15. Logs run and depth where run DIL/GR/SP/SFL f/9216' - 4638'; GR to 1500' FDC/CNL f/9216' - 8750' Cal f/9216' - 4638' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR27 Submit in duplicate MEMO RAN UM State .... of .Alaska ' , KA OIL A,~ GAS CONSERVATION COM>IISSIoM ALA C, V e~-'~~{e~ton DAVE: March 5, 1986 TO: Chai F~tE NO.' D.ADA. 14 TH RU: FROM: Lonnie C. Smith ~ ~'~' 7J TELEPHONE NO.: Commissioner SUBJECT: B.O.P.E. Test ARCO KRU 3I-8 Doug Amos Permit No. 86-40 Petroleum Inspector Kuparuk River Field Tuesday, February 25, 1986: I traveled this date from Anchorage to ~-r~dh°~ Bay tO-witness ~l{e B.O.P.E. Test at ARCO's KRU 3I-8 Well. Wednesday February 26, 1986: The B.O.P.E. Test was delayed due to e~l-~-~ob-ie~, ..... Thursday, February.27, 1986: The testing commenced at 12:15 p.m. and Was c°n~I'h~d at 1;.30 "p,m, The check valve on the kill line failed, but was repaired and retested this date. I filled out an A.O.G.C.C. B.O.P.E. Inspection Report which is attached. In summary, I witnessed the B.O.P.E. Test at ARCO's KRU 3I-8 Well. 02-001A(Rev 10-84), - STATE OF ALASKA %,.i.., ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report' Inspector "~., ~~ ~) Operator ~ f-Z) Location: Sec ~1 T%5~R~ M '[,I,~/[. Dril ling Contractor .~LM<~ ~__ · Well ~U ~ Representative Permit #, ~ ~/~l~asing Set Rig ~ ~ Representativ~ Location, General Well Sign General Housekeeping, Reserve pit Rig BOPE stack Annular Preventer Pipe Rams ~ ~ ~d~' Test Pressure Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pressure ::~. ~ ps ig Pressure After Closure ;.~O~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: N2 '~-~0 ~L2-~, ~..2-~gD 'Z.I O~9 psi9 / ~ Controls: Master ~. _ Remote ~min z~ sec min f>~_ sec Blinds switch cover~ ,.Kelly and Floor Safety Valves Upper Kelly 1 ~' Test Pressure Lower Kelly l ~ Test Pressure Ball Type, /~ Test Pressure Inside BOP I ~ Test Pressure Choke Manifold ~ ~ Test Pressure No. Vel yes ~ ~ No. flanges ~1 ~ Adjustable Chokes Hydrauically operated choke. ,, Test Results: Failures \ Test Time, 1 hrs. Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. II \ Remarks: ANkuk ~)A-~v~ ~.~D £ ~o~:s ~t~;~_~o-O % Dis tribut ion orig. - A0&GCC cc - Operator cc - supervisor Inspector~ ' February 6, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 TELECOPY NO. 276-7542 Re: Kuparuk River Unit 3 I-8 ARCO Alaska, Inc. Permit No. 86-40. Sur. Loc. 229'FSL, 47'FWL, Sec.31, T13N, R9E, Btmhole Loc. I162'FSL, l153'FEL, Sec.5, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved aPplication for permit to drill the above referenced well. The permit to dritl.-~does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where 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. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office ~3~× 100360 AnchoraGe, A~aska 99510-03¢~0 Telephone 907 276 1215 January 27, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3I-8 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3I-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Proximity plots A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on February 25, 1986, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JFB/tw PD/L219 REC :iVED Enclosures FEB 0 1986 Altlskt 0il & G;m Cons, (;0mlllj,sS|011 Anchorage ARCO Alaska, Inc. is a Subsidiary o1 AtlanticRichfieldCornpany la. Type of work. -' STATE OF ALASKA ,, - ~""~"C~"/~,,. ALASKA OiL/-~,, O GAS CONSERVATION CO1~1 M;,~,JI~ O~ PERMIT TO DRILL ~0 AAC DRIL~ ~ lb, Type of well EXPLORATORY ~ SERVICE ~ STR C REDRILL ~ DEVELOPMENT OIL ~X SINGLE ZONE ~ DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE ~ 2. Name of operator ARCO Alaska, inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 229' FSL, 47' FWL, Sec.31, T13N, RgE, UN At top of proposed producing interval 1371' FSL, 1375' FEL, Sec.5, T12N, RgE, UN At total depth 1162' FSL, 1153' FEL, Sec.5, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 40' I ADL 25631 ALK 2564 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse 16. Proposed depth(MD & TVD) 9375' MD, 6435' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 miles 1153' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 52 o (see 20 AAC 25.035 (c) (2) 10. Well number 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 31-7 well 25' ~ surface feet 18. Approximate spud date 02/25/86 2709 psig@__ 80°F Surface 3114 _psig@ 611 1 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing 24" 1 6" 12-1/4" 9-5/8" 8-1/2" 7" 22. Describe proposed Weight 62.5# 36.0# 26.0# program: CASING AND LINER Grade Coupling H-40/ Weld -55/HF-EIW BTC -55/HF-EIW BTC Length 80' SETTING DEPTH MD TOP TVD 32' I 32' I 4266' 32' 32' 1 MD BOTTOM TVD 1124 112' 42981 3286' ] I 31' 93751 6435' 9344' 31 ' I QUANTITY OF CEMENT (include stage data) + 200 cf 1500 sx AS I II'~ 340 sx Class G 400 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9375'MD(6435'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 BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2709 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 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-8 will be 25' away from 31-7 at the surface. 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. (continued on attached sheet) 23. I hereby certify_that the foregoing is true and correct to the best of my knowledge SIGNED /7~f~ TITLE Regional Drilling Engineer DATE The space ~f~r ~myon use CONDITIONS OF APPROVAL Samples required []YES ~0 Permit number APPROVED BY Form 10-401 Mud log required [~YES ¢~:) ~ C/~ ~ Appr°val dat~_; 0 6/8 6 _. (JFB) ~~1~ · PD~ Directional Survey required APl number ~Y. ES I-]NO 50- ~' L- '~' - %-! ,5~,-~'L~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission February 6, 1986 Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL 31-8 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED F E B 0 3 1986 Alaska Oil & Gas Cons. Commissiorl Anchorage .... ~ ..........' ......... $~ -- E 1 IN;"' - 1000.. FEET i'. ....'._' ........ KUPARUK FIELD, NORTH SLOPE,-ALASKA 5000 . .. . 1 000 ' O_ "- 1 000 2000 . 3000 4000 .1 ......... ;_._- ;I000_','1 ...... I I · I ' SURFACE LOOAT ! OH, .......... . 229' FSL. 47" FWL .... SEC, 3! · ~T13#._-RgE -: ................ '__~': .... ....... O_ ' SURFACE 2000 R E.CE._i rED ...... , .......... .. FEB O ~ 1986 ..........._ Alaska Oil &-Gas Cons. Commission Anchor3ge .......... TVD-6253; DEP-6105 : ..... :--"" .... :':':.'-"':':7.:'.:-:_'--: ............................ SOUTH 4189 .............................................. EAST 4441 · · ' ................................ , .......... 1320' ESL. .... , ......... ~ .......................................... SEC. 5. TI2#. RgE 1162' FSL. 11,.53' FEL ...... ~ ......................... ~ ................ SEC. 5, T!2#, R~ : ..... -'-:'"-":--::-"---:-": :--:-'-:-' S- 46. DEG 40' MI N E - . - ....... ~ .......... t5105':.--(TO TARCET) ..... '.' .......................... PAD 3I. WELL NO: 8 PRUPOSED KUPARUK FIELD. NORTH SLOPE. '-:']"." . .......... - ' . .--?']._- ]_'_"] ] ..] .... .'iT EASTMAN WHIPSTOCK~' INC-:] .... !- . ; BASE PERMAFROST . .TVD=1641 TMD=1723 DEP=378 2000 . ..... s EOC ..... TVD=1998...THD=2222. DEP=725 ~ ' TOP . _ -- : TOP W SAK SNDS TVD=2826 T~D=3557 DEP=1772 - - ........ .']_'.~'"]] ..... .%~ .... T ........:12'.- TVD=3086 T~D=3976 DEP=2101 .......... ...... T.VD'3286 TMD=4298 DEP=2354 AVERAGE ANGLE ......... 51 DEG -40 'HIN ' ' . ........ RECkiVED ......... K-5 TVD=4791 TMD=6724 DEP=4256 .... F E B 0 3 1986 Alaska 0il & GaS'Cons. Commission Anchorage ......... ~ zo.~ ~ ~v~=~,~4 ~.~=~ ~-~o~o ...../ ---:'~~T.c.~ ~v~:~s~ ~.~=~o~, ~=~,os .." "-----"--'-'--'",- ;000] .............. ~---B/ KUP'SNDS ..... :-TVD- - -~ TD": (LO~ PT) TVD=64~5 'TMD=9~Z5 DEP=6~5 __ ':_ ;..]_. :__']'_.._ :_..' ;-. -'. ; :_-;- .... -_'~ :_- ....... -:: '.. .............. ~ ..... ~,. ....... ~ , , , , - -. 0 -.'.---"~].--: i000". ': - 2000 ............ ~000 4000 5000 6000 ZOO0 .............. : ........... ;"' ..... ]] .... ]'T,]?'TS]:.]' ..... 7]]--,'- ...... ]']'7:-"VERT leAL- S~OT [ ON ........................................ ........... 300 200 3 O0 0 .i '1 O0 200 :300 400 500 600 1867 i \\ ' 1 67 ,/ ' ,,'~~"~~t. '~' '~, .,:'~' "~'~,,~_~.. /. ~' /F990_~' ~. '"". ~ ~1455~ ." ' - .' ~' ~- :.~'~~,;~ ~iV~~ -~~. ,~ ~. . ~ ~4 .. ., ~ . ~ = , ' ~ :~ : 1500 : ~ : . ~ t ~ . < I ~ ' , 700 ' ~7 a' ' I ....... · . . .' ........... ; .... ~ ................ 0 _ ~ '-.'-'i, .... x '- ' ' ' ...... · , 300 200 I 100 1 I !00 I 200 ],,455 ! 30O I 400 , 500 -, 6oo KUPARUK IRI VER UNIT 20" DIVERTER SCHEMATIC 6 DE S CR I P T I ON I. IG" C~CTOR. 2. TANI<O STARTER HEAD. 5. TAt,l<O SAVER SUB. 4. TAI'~<O LOWER QUICK-C~CT ASSY. 5. TANI<O UPPER QUICK-C~CT ASSY. 6. 20" 2C)C~ PSI DRILLING SPOOL W/I0" OUTLETS. 7. I0' HCR BALL VALVF_~ W/lO' DIVERTER LINEg. VALVE~ OPEN AUTOMATICALLY UPON CLOSURE OF ANI~AR PREVENTER. 8. 20" 2000 PSI AI~NULAR PREVEI~ER. ~INTENANCE & OPERATION i I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 1 2. CLOSE Ah~NULAR PREVENTER AND BLOW AIR THROUGN DIVERTER LINES EVERY 12 HOURS. CLOSE AhINULAR PREVENTER IN THE EVENT 'THAT AN IhFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, -1;.~,;'.;...~__,¥ 0;"-."..-.-_.~ r -- --' '--''' CLOSE APPROPR I ATE VALVE TO ACHIEVE DOWNWIND DIVERSION' DO NOT SHUT IN ~ELL UNC~R ANY CIRCUMSTANCES. i 7 6 DIAGRAM #I 1~,-5/8" ,,,¢~X:P PSI RSRRA BOP STACK I. 16' - 2000 PSI TAN<CO STARTING 2. I1' - ~ ~I ~I~ 3. i1' - ~ ~I X 1~8' - ~ 4. 1~8' - ~ ~I PI~ 5. 1~8' - ~ ~I ~ILLI~ ~ KI~ LI~ 6. 1~8' - ~ ~I ~E ~ W/PI~ ~ ~ T~, 7. 1~8' - ~ ~I AC(],.MJLATOR CAPACITY TEST I. C~ECX AN3 FILL A~TC~ RE:SESRVOIR TO'PRCPER LEVEL WlTN HYDRAULIC FLUID. 2. ~ TNAT A~TC~ PRE~ IS 3000 PSI WlTN 1500 PSI ~TRC_./NM OF' ~ REGLLATOR. -3. ~VE TIke, THEN CLOSE ALL UNITS SIDIJLTAN~OJ~Y AIND RE~ THE TINE[ A/ND PRE~ REMAINING AFTER ALL UNITS ARE CLOEF_D WITH CHARGING PLIN~ CFF. 4. RECCI~) ON NAg~ REPORT, TFE: ACCEPTABLE LC~NER LIMIT IS 45 SE~ CLOSING TINE AN) 1200 PSI REMAINING PRE~. 5 4 I . 4, S. . . 9. 10. 11. 12. 13. RECEJVE,D FEB O ~ 198~ 13-5/8" BOP STACK TEST FILL BOP STACX AN] CHOKE ~IFOLD WITH ARC'TIC DIESEL. Q-I~CX TNAT ALI. LO(:X ~ ~ IN WE1.LJ-EAD ARE F'L,LLY RETRACTED. SEAT TEST PLUG IN WITH RUNNING ,IT AhD RLtN IN L~ CL__rE~E_ AhNJLAR PR~ AN] MANUAL KILL AN] CHO<E LIAE VALVES ADJACE~rT TO BCP STAQ<. ALL OT~_R VALVES AN] C~O<ES SHCU_D BE OPEN. PRE~ UP TO 250 PSI AN) HOLD FOR I0 MIN. IN- CREASE PRE~ TO 3000 PSI AN] HOLD FCR lO MIN. BLEED PRE~ TO 0 PSI. OPEN ~ PREVENTER AN] MAh~AL KILL AN] CHCKE LI~E VALVES. CLOSE TOP PIPE RAMS AN] HCR VALVES ON KILL AN2 CHO<E LI~ES. TEST TO 250 PSI AN] 3000 PSI AS IN STEP 4. (X]NTINJE TESTING ALL VALVES, LIN~S, AN2 CNCKES WITH A ~ PSI LC~ AN] 3000 PSI HIGH. TEST AS IN STEP 4. EX] NOT PRESSURE TEST A~Y O-tO<E THAT IS NOT A FULL CLOSIN~ POSITIVE SEAL ~. CN.Y ~I6t4 TEST Q-O<E$ THAT BO Nor FULLY CLOSE. OPEN TOP PIPE RAMS AN:) CLOSE BOTTCM PIPE TEST BOTTQ~ PIPE RAMS TO 250 PSI AN) 3000 PSI. OPEN BOTTQ~ PIPE RAMS, BAQ< OUT RLt~4ING JT AN) PLI_L OUT OF HOLE. CLOSE BLIND RAMS AI~D TEST TO 250 PSI AN3 3000 PSI. CF:.N BLIN3 RAMS AN3 RETRIEVE TEST PLUG. MAkE SURE MANIFOLD AN3 LIN~S ARE FULL. OF N:]N-FRF_JEZING FLUID. SET ALL VALVES IN DRILLING POSITICt4. TEST STAN3PIPE VALVES, KELLY, KELLY CCx:Xs, DRILL PIPE SAFETY VALVE, AN:) INSIDE BOP TO 250 PSI AN) 3000 PSI. RE~ TEST IN=~TION ON BLClNOLrf PR~/~ TEST FCt~, SIGN, AN3 SF_AD TO BRILLIN3 SUPERVISOR. PERFCI:~ O34:%ETE BOPE TEST AFTER NIPPLING UP AN:) VFr_EKLY THEREAFTER ~IONALLY OPERATE B6PE DAILY. Gas Cons. Commission Anchoraoo 510084001 REV. 2 u~¥ ~ ¢, IC~¢- ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephor~e 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3I Pad (Wells 1- 16) Dear Mr. Chatterton. Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RFCFFYFD AJ~sk~t 0il & ~a~ Uu~S, Uul~nissJ0~ Anchorage If ARCO Alaska. "2. is 8 Subsidiary of AtlanticRichfieldCompany · i[ll ~'= ~ EY SCALE: I"= I MIL NOTES I, COORDINATES ARE A.S.E ~ ZONE 4. 2, SECTION LINE DISTANCES ARE TRUE. 5. HORIZONTAL POSITIONS BASEDON ON-PAD CONTROL PER L.H.D. 6 ASSOC. '4. VERTICAL POSITIONS BASED ON TBM 3[-4 PER ~ LHD6ASSOC. t 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. ~ CED- RlXX - 5050 rev. ~ j LOCATED IN PROTRACTED SEC.51,TI3 N, RgE, U. MER. LOCATED IN PROTR~TED SEC.~,TI3 N, R8E, U. MER. I 1- Y= 5,007,2~5.50 LAT. 70°~5'5~.0592'' 9- Y= 6,007,i21.00 LAT. 70°25'50.4432" X= 50~,056.44 LONG. 149055'03.596" X= 507,867.91 LONG. 149°56'09. i34" 179' FWL, 345' FSL 0G. 33.5', PAD 39.9' 180' FSL, 10' FEL 0G. 35.0', PAD 39.9' ~- Y= 5,007,259.06 LAT. 70°25'51.~97~'' 10- Y= 6,007,104.59 LAT. 70°~5'50.28~1 X= 50~,037.66 LONG. 149°55'04.14S'' X= 507,849.il LONG. 149°56'09.686" 160' F'WL, 328' FSL 0G. 33.7', PAD 39.9' 164' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70°25'5i.7370'' 11- Y= 6,007,0S8.16 LAT. 70°25'50.1206 X= 508,0i8.80 LONG. 149°5~'04.702'' X= 507,830.23 LONG. 149°56'10.~40" 141' FWL, 312' FSL 0G. 33.7', PAD 40.0' 147' FSL, 4~' FEL 0G. 35.0, PAD 40.1 4- Y= 6,007,~36.23 LAT. 70°25'51.575~" i~- Y= 6,007,071.76 LAT. 70°~5'49.9595 X= 507,999.99 LONG. 149°56'05.~55 X= 507,~11.32 LONG. 149°56'10.796" ~ 122' FWL, ~95' FSL 0G. 33.~', PAD 40.0' 13i FSL, ~6 FEL 0G. 35.0, PAD 40.1 ~ , !3- Y= 6,007 055.3~ LAT. 70°25'49.7981 ~ 5- Y= 5,007,Z19.81 LAT. 70°~5 51.4i39" , ~ X= 507,98i.i6 LONG. 149°55'05.808'' X= 507,792.3~ LONG. 149°55'11.353" ~ 104' FWL, 279' FSL 0G. 33.9', PAD 40.0' 1t5' FSL, ~5' FEL 0G. 35.0', PAD 40.1' ~ ~ o 6- Y= 5,007,203.20 LAT. 70°25'5t.2507" ~- Y= 5,007,03S.S~ LAT. 70 25 49.5359" X= 507,9~2.12 LONG. 149~55'06.3~7'' X= 507,773.~3 LONG. 149°5~'11.903'' ~5' FWL, ~52' FSL 0G. 34.0', PAD 39.9' 9~' FSL, 104' FEL 0G. 35.0, PAD 40.1' 7- Y= 5,007,1~6.7~ LAT. 70~25'51.0~95'' i5- Y= 6,007,022.42 LAT. 70°25'49.4749 X= 507,943.27 LONG. i49°55'05.920'' X= 507,754.~3 LONG. 149056 1~.455 66' FWL, ~46' FSL 0G. 34.2', PAD 39.8" S2' FSL, 1~3' FEL 0G. 35.0', PAD 40.Z' . ~- Y= 5,007,i70.37 LAT. 70°25'50.9282'' !6- Y= 6,007,005.0~ LAT. 70°25'49.3137 ~ X= 507,924.40 LONG. 149o55'07.475" X= 507,73~.04 LONG. 149~55'13.007'' , 47' FWL, 230' FSL 0G. 34.5', PAD 39.~' 65' FSL, 142' FEL 0G. 35.0', PAD 40.2' , CERTIFICATE OF SURVEYOR; ~ ME~EBY CERTIFY THAT I ~M PROPERLY ~ ~EGISTERED ~ND ~ICENSE~ TO PRACTICE LAND ~ __11"'~' ~,~m/~ ~. ~ ARCO Alaska, Inc. "~ ' '- '~ ~/~/7~ r ~~ ~,~ .~ ~5~ AS-BUILT LOCATIONSask~ o t i u , ~J~SArct~c Bou/evard, Suite 201, Anchorage, Aiaska 9~503 ~ls~LE AS S~OWN " ~! , JljOB ~ , CHECK LIST FOR NEW WELL PERMITS Company 'Lease & Well No. /~/Z-~ ITEM APPROVE DATE (1) Fee (2) Loc . 8) . mi 3. 4. 5. 6. 7, 8. <3> 'Admin(~_c--/ %'¥~ 9. < -th U /fA lO. (10 and 12) ~ 12. (lj -thru 21) (5) BOPE (22~ thru 26) 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26, 27. YES NO Is the permit fee attached ......................................... / Is well to be located in a defined pool ............................ Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ ~_ Is operator the only affected party ................................. Can permit be approved before ten-day wait ................. ......... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ...................................~'~ Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production s~ri~gs ...~ Will cement cover all known productive horizons ................. Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ........ ,. ................... ~ Is a diverter system required ....................................... Are necessary diagramS of diverter and BOP equipment' attached ....... Does BOPE have sufficient pressure rating - Test to _~_~ pstg Does the choke maffifold comply w/API RP-53 (Feb.78) .................. Is the pra~m~ce of II2S gas probable ............... . ................. Additional requirements ' eeeeeeee~eeeeeeeeeeee.eeeeeeeeeeeeeeeo,eeeeee Additional Remarks: REMARKS o H 0 ~eo logy: Eng %n~e e ring: HWK ~ LcS ~ WVA rev: 03/13/85 6,0il INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. LIS TAPE VERIFIC,~TION LISTING RECEIVED APR 1 5 1906 Aiaskm 0tl & ~ms Oon~. Commission .VD OlO.H02 VERIFICATION LISTING PAGE 1 ,--,- RE:L HEADER ~:~ ~RVICE NAME :EDIT )ATE :86/03/16 ]RIGIN : ~EEL N4ME :149461 ]ONT!NUATION ~ :01 ~REVIOUS REEL : 'OMMENTS :LIBRARY TAPE :-'~;~ TAPE HEADER ;~.-' ~ERVICE NAME :ECIT ]ATE :$6/03/i6 ]RIGIN :0000 FAPE NAME : ]DNTINUATION ~ :01 ~R~VIOUS TAPE : 'OMMENTS :LIBRARY TAPE ,-¥ FIL:- HEADER -,-"~- :ILE NAME :EDIT .001 ~ERVICE NAME : ~ERSION ~ : ]~TE : 'qAXIMUM LENGTH : lOZ4 :ILE TYPE : ~REVZOUS FILE : ~."'".,. INFORM4TION R"'CORDS,- qNEM CONTENTS iN : ~RCO ALASKA !NC ~N : 3I-8 :N : KUPARUK ,rSW~: 13N ~ECT: 31 ~OUN: N.SLDPE ~T/IT: ~LASKA ~TRY: USA 'qNEM CONTENTS ~R~S: E ...... CSMM'-NTS ...... UNIT TYPE CATE SIZE CODE 000 000 019 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 OOO 000 003 065 UNiT TYPE C&TE SIZE CODE 000 000 001 065 .VP OlO.H02 VERIFICATION LISTING P~G5 2 i.' SCHLUMBERGER ',,' &LA S KA C ~MPU~T'I NG :CENT E R '"':' ;OMPANY : ARCO ALASKA IN'C ~ELL = 3I-8 =IELO = KUPARUK 'OUNTY = NORTH SLOPE 50ROUGH ~TATE = ALASKA JD~ NUMBER AT ~CC: T1323 ~U'N .~1, DATE LOGGED: 2-MAR-2$ .DP: Lo 5,, CUDNEY ;ASiNG FYPE FLU'ID )ENSITY /ISCOSITY )H :LUID LOSS : 9.625" @ 4638' - SIT SIZE = 8.5" TO 9315' = NATIVE CLAG : 'I0.0 LB/G RM : 4.0gO @ 6.4,0 DF : 35.0 S RMF : 3.950 ~ 64.0 DF = 9°0 RMC : 2.710 @ 64.0 DF = 9.0 C3 RM ~T BHT : 1,853 @ 147. DF qATR!X SANDSTONE .Vp 010.H02 VERIFICATION LISTING PAGE 3 qOLE CORRECTION : CALIPER .... --,-~',-'~: THIS DATA H~S NOT B~=EN_ D~PTH_ SHIFTED- uVERLAYS FZELO PRINTS "'~'"~'~',,--,--,--,-~,- SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNE~TI:C TAPe: DUAL INDUCTION SPHERICALLY FOCUSED LOG DATA AVAILABLE: 9204' TO 4640' ~ORMATigN OENSIT¥ COMPEN'SATED LOG (FDN) COMPENSATED NEUTRON LOG (FDN) GAM~ RAY IN CASING (GRoCNL) ~TA AVAILaBLe; 4540' TO ~500' .,. ~ ~ ~ .,. ~. ~ ~ ~ ~.. ~ .,.~' ~ ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ,~ ~..,. .,--,- DATA FORMAT RECORD-,-.,. .V'P OIO.H02 VERIFICATION LZSTiNG P,&GE 4 :NTRY BLOCKS )ATUM ~NEM TYPE 15 0 SPECIFICATION BLOCKS SERVICE SERVICE 10 ORDER ~ )E PT ~FLU OIL ILO OIL [LM OIL ~ P OiL ;R DIL JR FDN ;AL I ,~DN ~HOB FON )RHO FON 4R AT FDN ~NRA FDN JPHI mON JCNL PON :CNL FDN ~R CNL UNIT FT OHMM OHMM OHMM MV GAPI GAPI IN G/C3 G/C3 PU CPS CPS GAPI API L 0 G O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 SIZE .I 1 4 4 1 i REPR CODE 66 66 73 65 66 66 API API ~PI FILE YPE CLASS MOD NO. 000 O0 0 0 220 Oi 0 0 120 46 0 0 120 44 0 0 010 O1 0 0 310 O1 0 0 310 O1 0 0 280 O1 0 0 350 0,2 0 0 356 O1 0 0 ~20 O1 0 0 000 O0 0 0 890 O0 0 0 330 131 0 0 330 30 0 0 310 O1 0 0 SI ENTRY 0 1 6O .lin 1 0 ZE SPL REPR PROCESS CODE (OCTAL) i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 000000'00000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 DATA ' PT :E ~HOB ~DHI 9249.5000 SFLU -5.1165 GR -999.2500 DRHO -999.2500 NCNL DEPT ~P ~HOB ,~PHI 9200.0000 SFLU -44.6445 GR 2.4768 DRHO 46.6797 NCNL )EPT ~P ~HOB qPHI 9100.0000 SFLU -49.8008 GR 2.4221 DRMO 34.9633 NCNL DEPT qPHi 9000.0000 SFLU -49.3633 GR 2.4084 ORHO 33.2031 NCNL ]EPT qHOB ~900.0000 SFLU -45.8320 GR 2.4377 DRHO 4.0398 iLO 12.2754 GR -999.2500 NR4'T -999.2500 FCNL 3.2678 ILO 12.2754 GR 0.1289 NRAT 2002.6875 FCNL 4.7820 ILO 89.4023 GR -0.0083 NRAT 2469.5000 FCNL 5.7625 ILD 98.0273 GR 0.0024 NRAT 2591.5000 FCNL 5.7898 ILD 77.2148 GR -0.0053 NRAT 5.9421 ILM 4.6570 -999.2500 CALI -999.2500 -999.2500 RNRA -999.2500 -999.2500 SR -999.2500 3.0002 ILM 3.11'74 12.275~ CALI 8.5645 3.6956 RNRA 4.1335 484.1406 GR -999.2500 4.7976 ILM 4.7625 89.4023 C~Li 8.8379 3.0725 RNRA 3.3792 730.3125 GR -999.2500 5.2781 tLM 5.4070 98.0273 CALI 8.6504 2.9651 RNRA 3.2717 791.8125 GR -999.2500 7.0515 iLM 7.4031 77.2145 C~LI 8.7363 2.9866 RNRA 3.5139 .V'P 010.HO2 VErifiCATION L!$TIN~ PA~E 5 ~PHI )EPT ;P ~HOB ~PHI )E PT ;P ]HOB tPHI )EPT ;P ~HOB tPHI )EPT ;P ~HOB ~PHi )EPT ~P ~HOB IPHI )EPT ;P ~HOB IPHI )r-pT ;P ~HOB ~PHI ~HOB ~PHI Dr-pT ~P RHOB ,~PHI qPHI .,EPT SP 33.4473 NCNL 8800.0000 SFLU -39.5195 GR 2.4026 DRHO 32.4707 NCNL 8700.0000 SFLU -36.9570 GR -999.2500 O2HO -999.2500 NCNL 8500.0000 SFLU -35.4258 GR -999.2500 DRHO -999.2500 NCNL 8500.0000 SFLU -30.8545 GR -999.2500 DRHO -999.2500 NCNL 8400.0000 SFLU -31'8701 GR -999.2500 DRHO -999.2500 NCNL 8300.0000 SFLU -29.80?5 GR -999.2500 DRHO -999,2500 NCN:L 8200.0000 SFLU -31.1826 GR -999.2500 DRHO -999.2500 NCNL BIO0.O000 SFLU -28.7607 GR -999.2500 DRHJ -999.2500 NCNL ~000.0000 SFLU -27.65?0 GR -999.2500 DRHO -999.2500 NCNL ?go0.o000 SFLU -26.a539 GR -999.2500 ORHO -999.2500 NCNL 7300.0000 SFLU -30.5420 2597.5000 mCNL 5.5593 ILD 109.2773 GR 0.0605 NRAT 2239.5000 FCNL 2.0999 ZLO 129.1875 GR -999.2500 NRAT -999.2500 FCNL 2.1936 ILO 111.4648 GR -999.2500 NRAT -999.2500 FCNL 2.7249 ILO 128.6875 GR -999.2500 NRAT -999.2500 FCNL. 3.2924 ILO 192.5875 GR -999.2500 NRAT -999.2500 FCNL 4.1~92 ILD 197.0625 GR -999.2500 NRAT -999.2500 FCNL 3.8401 ILD 149.0625 GR -999.2500 NRAT -999.2500 FCNL 4.3484 ILD 119.0273 GR -999.2500 NR~T -999.2500 FCNL 2.9?88 ILO 126.4023 GR -999.2500 NRAT -999.2500 FCNL 3.6956 iLD 112.6523 GR -9~9.2500 NR~T -999.2500 FCNL 5.7429 ILD 102.9023 GR 738.8125 GR 3.4436 ILM 109.27'73 CALl 3.0198 RNRA 644.8t25 GR 1.8536 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.0901 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.4709 ILM -999.2500 CALI ,-999.2500 RNRA -99'9.2500 GR 3.0803 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.4104 iLM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.5159 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR ~.0710 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.6604 ILM -999.ZSO0 CALl -999.2500 RNRA -999.2500 GR 3.9456 iLM -999.2500 CALl -999.2500 RNRA -999.2500 GR 5.2507 ILM -999.2500 C~LI -999.2500 4.1570 9.9082 3.4709 -999.2500 1.9210 -999.2500 -999.2500 -999.2500 2.1604 ,-999.2500 -999.2500 -999,2500 2.5754 -999.2500 -999.2500 -999.2500 3.1096 -999.2500 -999.2500 -999.2500 3.5491 -999.2500 -99'9.2500 -999.2500 3.5725 -999.2500 -999.2500 -999.2500 4.0710 -999.2500 -999.2500 -999.2500 2.7327 -999.2500 -999.2500 -999.2500 3.994~ -999.2500 -999.2500 -999.2500 5.0515 -999.2500 .V'P OlO,H02 VERIFICATION LISTING PAGE JPHI )EPT ~HOB JPHI ~P ~,HOB ~PHZ )EPT ~P ~HOB )EPT ~P ~HO8 qPHI )EPT 5P ~HOB qPHI 3EPT ~P 2HOB qPHI )EPT ~P ;HOB qPHi 3=PT 3P 2HOB qPHI 3EPT SP qPHi DEPT SP RH05 qPHI -999,2500 ORHO -999,:2500 NCNL 7'?00,0000 SFLU -27,9~82 GR -999,2500 DRHO -999,2500 NCNL 7600,0000 SFLU '-29,fi951 GR -999,2500 DRHO -999,2500 NCNL 7500,0000 SFLU -28,901~ GR -999,2500 DRHO -999,2500 NCNL 7~00,0000 SFLU -28,7920 OR -999,2500 DRHO -999,2500 NCNL 7300.0000 SFLU -35.9258 OR -999.2500 DRHO -999.2500 NCNL TZO0,O000 SFLU -31,85~5 OR -999,2500 DRHO -999.2500 NCNL 7100,0000 SFLU -33,4258 GR -999,2500 DRHO -999,2500 NCNL 7000.0000 SFLU -32.0820 OR -999.2500 DRHO -999,2500 NCNL 6900.0000 SFLU -30.4170 GR -999.2500 DRHO -999.2500 NCNL 6500,0000 SFLU -30,2507 GR -999.2500 -999.2500 NCNL -999,2500 NRAT .-999,2500 FCNL 4,5750 iLD 8:5,2148 GR -999,2500 NR~T -999,2500 FCNL 5,723~ ILD 71,1523 GR -999,2500 NRAT -999,2500 FCNL 3,3928 ILO 121,0273 OR -999,2500 NRAT -999,250'0 FCNL 3,2502 110,9548 OR -999,2500 NR~T -999,2500 FCNL 3,5100 ILD 108,5898 GR -999,2500 NRAT -999,2500 FCNL .2.578~ ILD .123,5273 GR -999,2500 NRAT -999,2500 FCNL 2.5784 ILO 120.6523 GR -999,2500 NRAT -999.2500 FCNL 3,7561 ILD 101,2148 GR -999.2500 NRAT -999,2500 FCNL ~,0437 ILD 1~3,8125 GR -999,2500 NRAT -999,2500 FCNL 3.8752 ILD 136,~375 GR -999,2500 NR~T -999,2500 FCNL ,-999,2500 RNRA -999,2500 GR 3,8186 ILM -999,2500 CALI -999,2500 RNRA -999,2500 OR 3,6702 ILM '-999,2500 CALI -999,2500 RNRA -999.2500 GR 3,5198 ILM -999,2500 CALI -999,2500 RNRA -999,2500 GR 3.1643 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.7092 tLM -999.2500 CAL! -999.2500 RNRA -999.2300 GR 2,4319 ILM -999,2300 CALI -999,2300 RNRA -999.2500 OR 2,6213 ILM -999.2500 CALt -999,2500 RNRA -999,2500 GR 3.2327 ILM -999.2500 CALl -999,2500 RNRA -999,2500 GR 4.2390 ILM -999,2500 CALi -999,2500 RNR~ -999,2500 GR 3.9514 ILM -999,2500 CALl -999,2500 RNRA -999,2500 GR -999,2500 -999,2500 ~.0515 -999,2500 -999,2500 -999,2500 3.9084 -999.2500 -999.2500 -999.2300 3.5569 -999.2500 -999.2500 -'999.2500 3.1897 -999.2500 -999.2500 -999.2500 3.6975 -999,2500 -999,2500 -999,2300 2.3577 -999,2500 -999,2500 -999,2500 2.7053 -999.2500 -999.2500 -999.2500 3.2717 -999.2500 -999.2500 -999.2500 4.1843 -999.2500 -999.2500 -999.2500 3,9280 -999.2500 -999.2500 -999.2500 DEPT 6700.0000 SFLU 2,2288 ILD 3.0471 ILM 2.9221 LYF OlO,H02 VERIFICATION LISTING ~AGE ? ~.HOB qPH I ]EPT SP WPHI DEPT SP ~PHI se ~HOB qPHi D~PT RHOB ~PHI ]EPT ~HOB ~ PHI DEPT SP qPHI SEPT SP qHOB NPHI DEPT S~ RHOB WPHI SP RHOB NPHZ DEPT SP ~PHI -30,9170 GR -999,2500 DRHO -999,2500 NCNL 6500,0000 SFLU -32,9883 GR -999,2500 DRHO' -999,2500 NCNL 6500,0000 SFLU -24,3545 GR -999,2500 DRHO -999,2500 NCNL 6400,0000 SFLU -25,6201 GR -999,2500 ORHO -999,2500 NCNL 6300.0000 SFLU -30.4639 GR -999,2500 DRHO -999,2500 NCNL 6200,0000 SFLU -28,4014 GR -999,2500 DRHO -999.2500 NCNL 6100,0000 SFLU -27,3857 GR -999.2500 ORHO -999,2500 NCNL 6000.0000 SFLU -26,6201 GR -999,2500 DRHO -999,2500 NCNL 5900,0000 SFLU -26.6201 -999,2500 ORHO -999,2500 NCNL 5800,0000 SFLU -27,9482 GR -999.2500 DRHS -999,2500 NCNL 5700.0000 SFLU -27.0254 GR -999.2500 DRHO -999.2500 NCNL 161,3125 GR .-999,2500 NRAT -999,2500 FCNL 2,0002 iLO 116.6523 GR -999,2500 NR~T -999,2500 FCNL 1,8536 ]ILO 112,0273 GR' -999,2500 NRAT -999,2500 FCNL 2,2209 ILO 127.3398 GR -999,2500 NRAT -999,2500 FCNL 2.6135 ILD 81,1523 GR -999,2500 NRAT -999,2500 FCNL 2.4788 ILO 78.7148 GR -999.2500 NRAT -999.2500 FCNL 2,2'756 ILO 104.4648 GR -999.2500 NRAT -999,2500 FCNL 3,3674 ILD 99,7773 GR -999,2500 NRAT -999.2500 FCNL 5.0515 ILO 114.4023 GR -999,2500 NRAT -999,2500 FCNL 3,328~ ILO 94,1523 GR -999,2500 NRAT -999,2500 FCNL 3.7893 ILO 116.4023 GA -999.2500 NRAT -999.2500 FCNL -9~9.2500 CALI -999.2500 RNRA -999,2500 GR 2,1565 ILM -999,2500 CALI --999.2500 RNR4 -999,2500 GR 1.7823 ILM -999.2500 CALI -999,2500 RNRA -999.2500 GR 2,4709 ILM -999,2500 CALI -999,2500 RNRA -999,2500 GR 2,7092 ILM -999,2500 CALI -999,2500 RNRA -999,2500 GR 2,6702 ILM -999,2500 CALI -999.2500 RNR~ -999,2500 GR 2,5413 ILM -999.2500 CALl -999.2500 RNRA -999,2300 GR 3.8245 ILM '999.2500 C~LI -999.2500 RNRA -999.2500 GR 5,0398 ILM -9:99,2500 CALl -999,2500 RNRA -999,2500 GR 3,7151 !LM -999,2500 CALI -999,2500 RNR~ -999,2500 GR 4.1179 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999,2500 -999,2500 -999,2500 2.1311 -999,2500 -999.2500 -999.2500 1.8057 -999.2500 -999.2500 -999.2500 2.3674 -999.2500 -999.2500 -999.2500 2,7288 -999,2500 -9'99,2500 -999,2500 2.6311 -999.2500 -999.2500 -999.2500 2.4670 -999.2500 -999.2500 '999.2500 3.7014 -999.2500 -999.2500 -999.2500 5.0281 '-999.2500 -999.2500 -999.2500 3.6038 -999.2500 -999.2500 -999.2500 3.9827 -999.2500 -999.2500 -999.2500 _~P OIO.MO2 V~RIFICATION LISTING PAGE ]EPT qPHi "'~. m T :~ HO 5 ~PHI ]EPT ~HOB qPHI ]EPT ~P qPHI ]EPT ~P ~HOB ~PHI ]EPT ~P qPHI ]EPT ~P ~HOB ~ PHi ]EPT ~PHI ]EPT 5P HHO~ 3EPT ~JPHI 3EPT SP RHO8 $500.0000 SFLU -27.8701 GR -999.2500 ORHO -999.2500 NCNL 5500.0000 SFLU -27.8232 GR -999.2500 ORHO -999.2500 NCNL 5400.0000 SFLU -28.3389 GR -999.2500 DRHO -999.2500 N!CNL 5300.0000 SFLU -27.1670 GR -999.2500 ORHO -999.2500 NCNL 5200.0000 SFLU -2¢.1670 GR -999.2.500 DRHO -999.2500 NCNL 5100.0000 SFLU -2~.0107 GR -999.2500 DRHO -999.2500 NCNL 5000.0000 SFLU -12.4355 GR -999.2500 DRHO -999.2500 NCNL 4900.0000 SFLU -23.4951 GR -999.2500 ORHO -999.2500 NCNL 4800.0000 SFLU -22.2451 GR -999.2500 DRHO -999.2500 NCNL 4700.0000 SPLU -19.8389 GR -999.2500 DRHO -999.2500 NCNL 4600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3.6487 i~LO 102.9023 GR -999.2500 NR4T -999.2500 FCNL 3.2249 ILO I10.?148 GR -999.2500 NRAT -999.2500 FCNL 3.5569 ILD 110.5273 GR -999.2500 NRAT -999.2500 FCNL 4.24]29 ILD !13.5898 GR -999.2500 NRAT -999.2500 FCNL 2.7209 ILD 88.2148 GR -999.2500 NRAT -999.25.00 FCNL 3.0862 ILO 130.93T5 GR -999.2500 NR~T -999.2500 FCNL 3.~120 ILO 107.5898 GR -999.2500 NR~T -999.2500 FCNL 3.6018 ILO 100.0898 GR -999.2500 NRAT -999.2500 FCNL 3.8264 ILO 106.4023 GR -999.2500 NRAT -999.2500 FCNL 4.8640 !LD 9!.5273 GR -999.2300 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL 4.2039 ILM -999.2500 CALi -999.2500 RNR~ -999.2500 GR 3.8381 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 4.4226 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 4.6609 I~LM -999.2500 C4LI -999.2~00 RNRA -999.2500 GR 3.1526 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.6018 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.2053 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 4.4734 ILM -999.2500 CALl -999.2500 RNR4 -999.2500 GR 4.5281 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 5.8054 iLM -999.2500 CALI -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR 4.0203 -999.2500 -999.2500 -999.2500 3.7190 -999.2500 -999.2500 -999.2500 4.2468 -999.2500 -999.2500 -999.2500 4.4929 -999.2500 -999.2500 -999.2500 2.9260 -999.2500 -999.2500 -999.2500 2.4963 -999.2500 -999.2500 -999.2500 2.8831 -999.2500 -999.2500 -999.2500 4.2507 -999.2500 -999.2500 -999.2500 4.2664 -999.2500 -999.2500 -999.2500 5.5281 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 60.9805 .V~ OlO.H02 VERIFICATION LISTIN$ PAGE 9 )EPT ;P iPHI )EPT ;P ~HOB ~PHi )EPT ~HOB ~PHI )EPT ~P 2HOB }EPT ~P ~HOB gPHI )EPT SP qPHI DE~T SP :~ H .'OB xtPH I DEPT SP RHOB qPHi DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP 4500.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 4400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 4300.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 4200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 4100.0000 SFLU -999.2500 GR -999.2500 9RHO -999.2500 NCNL 4000.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3900.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3800.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 NCNL 3TO0.O000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 3500.0000 SFLU -999.2500 GR -999.250J DRH3 -999.2500 iLD -999.250.0 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999. 2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 N'RAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR · -999.2500 NRAT -999.2~00 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.250'0 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 OR -999.2500 NRAT -999.2500 FCNL -999.2500 ILS -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR&T -999.2500 tLM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 iLM -999.2500 CALi -999.2500 RNRA -999.2500 GR -999.2500 -9'99.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -'9'99.2500 RNRA -999.2500 GR -999.2500 iLM -999.2500 CALl -999.2500 RNR~ '-999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR& -999.2500 GR -9'99.2500 iLM -999.2500 CALl -99'9.2500 RNR~ -999.2500 -999.2500 -999.2500 52.2305 -999.2500 -999.2500 -999.2500 42.9805 -999.2500 -999.2500 -999.2500 62.386'7 -999.2500 ,-999.2500 -999.2500 55.3555 -999.2500 .-999.2500 -999.2500 58.1680 -999.2500 -999.2500 -999.2500 44.1680 -999.2500 -999.2500 -999.2500 53.2617 -999.2500 .-999.2500 -999.2500 49.5117 -999.2500 -999.2500 -999.2500 56.5117 -999.2500 -999.2500 -999.2500 55.7930 -999.2500 -999.2500 -999.2500 .VP O~O.HO2 VERiFICA'TiON LISTING PAGE 10 ~PHI -999.2500 NCNL )EPT 3z~O0.O000 SFLU ;P -999.2500 GR ~HO:B -999.2500 DRHO ~PHI -999.2500 NCNL )EPT 3300.0000 SFLU ~P -999.2500 GR ~HOB -999. 2500 DRHO ~PHi -999.2500 NCNL )EPT 3200.0000 SFLU ½P -999.2500 GR ~HOB -gg9.zSO0 DRHO ,}PHI -999.2500 NCNL )EPT 3100.0000 SFLU 5P '-999.2500 GR ~HOB '-999.2500 DRHO ~PHi -999.2500 NCNL 3EPT 3000.0000 SFLU SP -999.2500 GR ~HDB -999.2500 ORH8 qPHI -999.2500 NCNL )EPT 2900.0000 SFLU 5P -999.2500 GR ~HOE -999.2500 DRHO qPHi -999.2500 NCNL 3EPT 2800.0000 SFLU SP -999.2500 GR RHO5 -999.2500 DRHO ~P~I -999.2500 NCNL DE~T 2700.0000 SFLU SP -999.2500 GR RHOB -999.2500 ORHO i~PHI -999.2500 NCNL 3EPT 2600.0000 S~LU SP -999.2500 GR RHg5 -999.2500 ORHj HPHI -999.2500 NCNL 3EPT 2500.0000 SPLU SP -999.2500 GR RH~5 -999.2500 ~RHO NPMI -999.2500 NCNL 35~T 2400.0000 SFLU SP -99'9.2500 GR -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 ~CNL -999.2500 IL~ -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -9'99.2500 NRAT -999.2500 FCNL -999.2500 iLD -999.2500 GR -999.3500 NRAT -999.2500 mCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -99'9.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 !LM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRd -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -ggg.2$O0 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALi -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI 63.2617 -999.2500 -999.2500 -999.2500 41.2305 -999.2500 -999.2500 -999.2500 26.7561 -999.2500 -999.2500 -999.2500 54.5430 -999.2500 -999.2500 -999.2500 39.4805 -999.2500 ,-999.2500 -999.2500 24.7861 -999.2500 -999.2500 -999.2500 33.1055 -999.2500 -999.2500 -999.2500 44.3242 -999.2500 -999.2500 -999.2500 62.6055 -999.2500 -999.2500 -999.2500 33.0742 -999.2500 -999.2500 -999.2500 4~.1055 -999.2500 -999.2500 ~V~ OiO.HOZ VERiFiCATION LISTING PAGE ~HOB -999.2500 DRHO qPHI -999.2500 NCNL ]EPT 2300.0000 SFLU 3P -999,2500 GR RHOB -999.2500 DRHO ~PHi -999.2500 NCNL ]EPT 2200.0000 SFLU ~P -999.2500 GR ~HDB -999.2500 ORHD ~PHI -999.2500 NCNL ]EPT 2100.0000 SFLU ~P -999.2500 GR RHOB -999,2500 ORHO ~PHI -999.2500 NCNL DEPT 2000.0000 SFLU 3P -999.2500 GR qHOB -999.2500 DRHO ~PHI -999,2500 NCNL DEPT 1900,0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO ~PHI -999.2500 NCNL 3EPT 1800.0000 SFLU SP -999.2500 GR ~HD~ -999,2500 ORHO ~PHi -999.2500 NCNL DEPT 1700.0000 SFLU 5P -999.2500 GR ~HO5 -999.2500 DRHO ~PwZ -999.2500 NCNL ]EPT 1600.0000 SFLU SP -999.2500 GR qHO6 -999.2500 DRHg ~PHi -999.2500 NCNL DEPT 1500.0000 SFLU S~ -999.2500 GR ~HD5 -999.2500 DRHO NPHI -999.2500 NCNL SEPT 1495.0000 SFLU SP -999.2500 GR RHO~ -999.2500 DRaG NPHI -999.2500 NCNL -999.2500 NRA'T -999.2500 FCNL -999.2500 ILO -999.2500 G2 -999.2500 NR~4T -999.2~00 ~CNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR4T -999.2500 FCNL -999.2500 ILD · -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2~00 FCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 iLD -999.2500 GR -999.2~00 NR~T -999.2500 FCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CaLI -999.2500 RNR~a -999.2500 GR -999.2500 ILM -999.2500 C~Li -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C4LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~Li -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNRA -999.2500 G~ -999.2500 41.2930 -999.2500 -999.2500 -999.2500 44.3242 -999.2500 -999.2500 -999.2500 44.1367 -999.2500 -999.2500 -9'99.2500 44.5117 -999.2500 -999.2500 -999.2500 ~$.7617 -999.2500 -999.2500 -999.2500 35.3242 -999.2500 -999.2500 -999.2500 51.4492 -999.2500 -999.2500 -999.2500 37.4492 -999.2500 -999.2500 -999.2500 56.2617 -999.2500 -999.2500 -999.2500 36.5117 -999.2500 -999.2500 -999.2500 45.0~30 Vp' ~1'0.H02 VERIFICATION LISTING PAGE 12 FiLE TRAILER-,-"-,- 'iLE NaM: :EDIT .001 ,=RVICE N~.ME : 'ERSION ~ : ~TE : IAXIMUM LENGTH : 1024 :ILE TYPE : IEXT FILE NAME : :.",: TAPE TRAILER ',ERVICE NAME :EDIT )ATE :86./03/16 IRIGIN :0000 'APE NAME :t323 :ONT!NUATION ~ :01 JEXT TAPE NAME : ~OMMENTS :LIBRARY TAPE :-':,'~ REEL TRAILER ::~-~ ~-RVICE NAME :EDIT ]ATE :86/03/16 ~RIGIN : ~EEL NAME :149461 ~ONTINUATION ~ :01 ,JEXT REEL NAME : ~OMMENTS :LIBRARY TAPE