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Home My WebLink About201-2481. 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 9350'feet 7674', 8139'feet true vertical 6548' feet 7699'feet Effective Depth measured 7201'feet 6495', 6658'feet true vertical 6378'feet 6028', 6146'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)4-1/2" 4-1/2" L-80 L-80 6622' 6655' 6121' 6143' Packers and SSSV (type, measured and true vertical depth)6495' 6658' 6028' 6146' 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: Contact Name: Contact Email: Contact Phone: 325-305 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: Blue Pack Max Packer: ZXP Liner Top SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 Authorized Name and Digital Signature with Date: Authorized Title: RWO/CTD Engineer 2432' 7" 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) Well Not Online Gas-Mcf MDSize 161' N/A 119' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-248 50-029-23063-00-00 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: ADL0025649 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1C-24 Plugs Junk Burst Collapse Tie Back Production 4406' Casing 4138'4406' 6835' 6253' 4670' 161'Conductor Surface 4711'4413' 16" 9-5/8" 2701' 4-1/2" 9345' 6547'Liner 6424-6427', 6430-6440', 6442-6455', 6461-6468', 6472-6474', 6498-6492', 6488-6483', 6481-6479', 6480-6506', 6513-6520' 7485-7520', 7550-7670', 7700-7885', 7945-8015', 8065-8090', 8500-8600', 8650-8750', 8800-8900', 8950-9150', 9180-9215' 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 2:38 pm, Jul 10, 2025 RBDMS JSB 071025 DSR-7/21/25JJL 7/21/25 Page 1/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/4/2025 21:00 6/5/2025 00:00 3.00 MIRU, MOVE RURD P Rig Release off 1R-05 at 21:00. Prep to move to 1C-24. 0.0 0.0 6/5/2025 00:00 6/5/2025 02:00 2.00 MIRU, MOVE RURD P Prep to move to 1C-24. NES trucks showed up at 01:00. 0.0 0.0 6/5/2025 02:00 6/5/2025 04:30 2.50 MIRU, MOVE MOB P Move camp, pits, and shops F/1R-05 T/1C-24. Spot Office and point Comms dish. Rig crew prep sub to move from 1R. 0.0 0.0 6/5/2025 04:30 6/5/2025 10:30 6.00 MIRU, MOVE MOB P Move sub F/ 1R to 1C. Pull on location. 0.0 0.0 6/5/2025 10:30 6/5/2025 11:30 1.00 MIRU, MOVE MOB P Rig crew lay herculite, hang tree in cellar, and spot wellhead equipment behind 1C-24. 0.0 0.0 6/5/2025 11:30 6/5/2025 12:00 0.50 MIRU, MOVE MOB P Spot sub over 1C-24. Shim sub, and slide in matts under front of sub. Place berming. 0.0 0.0 6/5/2025 12:00 6/5/2025 12:30 0.50 MIRU, MOVE MOB P Lay herculite for pits, and back in pits to sub. 0.0 0.0 6/5/2025 12:30 6/5/2025 13:00 0.50 MIRU, MOVE RURD P Raise derrick. 0.0 0.0 6/5/2025 13:00 6/5/2025 19:00 6.00 MIRU, MOVE RURD P Rig crew go through rig acceptance check list. Install berming, and set up landings and walk ways. T/IA/OA= 0/0/60 psi. Bleed OA to zero. Rig accept at 19:00. 0.0 0.0 6/5/2025 19:00 6/5/2025 22:30 3.50 MIRU, WELCTL SEQP P PT lines to 2500 psi. Pump 30 bbls deep clean and chased with 350 bbls of 8.6 ppg seawater at 6BPM/1140 psi. 0.0 0.0 6/5/2025 22:30 6/5/2025 23:00 0.50 MIRU, WELCTL OWFF P Open well and flow check for 30 min. Good no flow test. 0.0 0.0 6/5/2025 23:00 6/6/2025 00:00 1.00 MIRU, WHDBOP MPSP P Set BPV and PT below to 1000 psi for 10 min. 0.0 0.0 6/6/2025 00:00 6/6/2025 03:00 3.00 MIRU, WHDBOP NUND P N/D Tree, and adaptor flange. Tail to corner of cellar and hang off. FMC rep function LDS. Attempt to screw cross over into hanger neck, unable to get X/O threaded into hanger. 0.0 0.0 6/6/2025 03:00 6/6/2025 08:00 5.00 MIRU, WHDBOP NUND P N/U 13 5/8" x 11" DSA, N/U test spool, and BOP. Install riser, and turnbuckles. Change lower pipe rams to 7" fixed CSG rams. 0.0 0.0 6/6/2025 08:00 6/6/2025 09:30 1.50 MIRU, WHDBOP BOPE P Build test joints, and R/U test equipment. Fill lines, and purge stack. Shell test stack. 0.0 0.0 6/6/2025 09:30 6/6/2025 11:00 1.50 MIRU, WHDBOP WAIT T Wait on AOGCC rep to arrive for BOP test. 0.0 0.0 6/6/2025 11:00 6/6/2025 15:00 4.00 MIRU, WHDBOP BOPE P Start BOP test. Test upper pipe rams w/ 3.5", and 4.5" Test joints. Test lower pipe rams w/ 4.5", and 7" test joints. Test annular w/ 3.5", and 7" test joints. Test all choke valves, manual, and HCR choke and kill. Test FOSV, and Dart vavle. Test upper and lower IBOP. Test blind rams. All tests 250 PSI low 2500 PSI high 5 min each. Perform accumulator draw down test. Test witnessed by AOGCC rep Kam St.John. 0.0 0.0 6/6/2025 15:00 6/6/2025 15:45 0.75 MIRU, WHDBOP RURD P R/D BOP test equipment. Drain stack B/D lines. 0.0 0.0 6/6/2025 15:45 6/6/2025 16:15 0.50 MIRU, WHDBOP MPSP P P/U T-bar and pull Test dart and BPV. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 2/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/6/2025 16:15 6/6/2025 16:45 0.50 COMPZN, RPCOMP FISH P P/U spear, RIH and engage tubing hanger. BOLDS. Pull hanger offseat @ 55 K. Pull up to 145K HKLD observe weight break over to 110K OWFF for 5 min: Static. 0.0 6,620.0 6/6/2025 16:45 6/6/2025 17:15 0.50 COMPZN, RPCOMP PULL P Pull hanger to rig floor. L/D spear and hanger. PUWT: 110 K 6,620.0 6,620.0 6/6/2025 17:15 6/6/2025 18:00 0.75 COMPZN, RPCOMP CIRC P R/U Circulating equipment. Circulate bottoms up @ 6 BBL/ min @ 500 PSI. 6,620.0 6,620.0 6/6/2025 18:00 6/7/2025 00:00 6.00 COMPZN, RPCOMP PULL P POOH L/D 4.5" 12.6# Tubing F/ 6600' to 1800'. Observed corrosion from 5179' down. No holes 6,620.0 1,800.0 6/7/2025 00:00 6/7/2025 03:00 3.00 COMPZN, RPCOMP PULL P POOH L/D 4.5" 12.6# Tubing F/ 1800' to surface Observed corrosion from 5179' down. No holes. Cut joint length 15.66' Nice clean WellTec cut. 1,800.0 0.0 6/7/2025 03:00 6/7/2025 03:30 0.50 COMPZN, RPCOMP RURD P RD tubing pulling equipment. Clean floor. 0.0 0.0 6/7/2025 03:30 6/7/2025 04:30 1.00 COMPZN, WELLPR BHAH P M/U BHA # 2, clean out BHA F/ Surface to 242' 0.0 242.0 6/7/2025 04:30 6/7/2025 09:30 5.00 COMPZN, WELLPR PULD P RIH picking up 3.5" HT-38 DP F/ 242' to 6400'. PUWT: 135 K SOWT: 115 K 242.0 6,500.0 6/7/2025 09:30 6/7/2025 10:00 0.50 COMPZN, WELLPR REAM P Clean packer setting depth w/ string mills in BHA F/ 6400-6500'. 6,500.0 6,500.0 6/7/2025 10:00 6/7/2025 10:30 0.50 COMPZN, CSGRCY MILL P Wash down F/ 6500' to top of tubing stump @ 3 BBL/min @ 325 PSI @ 6594.5'. Set down 10K, observe 100-50 PSI pressure increase. P/U and start rotary @ 50 RPM @ 2.2K free TQ increase flow rate to 4 BBL/Min @ 550 PSI. Wash over and dress top of tubing stump F/ 6594.5' to 6595.72'. PUWT: 135 K SOWT: 115 K ROTWT: 125 K WOB: 5- 10 TQ: 3.3K on bottom 6,500.0 6,595.7 6/7/2025 10:30 6/7/2025 11:15 0.75 COMPZN, CSGRCY CIRC P Circulate around high vis sweep @ 9 BBL/Min @ 2000 PSI. Sweep brought back large amount of fill to surface. 6,595.7 6,595.7 6/7/2025 11:15 6/7/2025 11:45 0.50 COMPZN, CSGRCY OWFF P Flow check well F/ 10 Min: Static. Blow down top drive. 6,595.7 6,595.7 6/7/2025 11:45 6/7/2025 13:30 1.75 COMPZN, CSGRCY TRIP P POOH racking back drill pipe F/ 6595.7 to 242'. 6,595.7 242.0 6/7/2025 13:30 6/7/2025 14:30 1.00 COMPZN, CSGRCY BHAH P L/D BHA F/ 242' to surface. 242.0 0.0 6/7/2025 14:30 6/7/2025 15:00 0.50 COMPZN, CSGRCY OTHR P Clean and clear rig floor. 0.0 0.0 6/7/2025 15:00 6/7/2025 15:30 0.50 COMPZN, CSGRCY ELOG P R/U AK E-line on the rig floor, AK E-line P/U CBL tools. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 3/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2025 15:30 6/7/2025 19:00 3.50 COMPZN, CSGRCY ELOG P AK E-line RIH F/ Surface to 4800'. POOH logging up w/ CBL to surface. RD E-line. 0.0 0.0 6/7/2025 19:00 6/7/2025 22:30 3.50 COMPZN, CSGRCY MPSP P MU BHA #3 RBP. RIH and set RBP at 4703' COE. UWT 90K DWT 90K 0.0 4,703.0 6/7/2025 22:30 6/7/2025 23:30 1.00 COMPZN, CSGRCY CIRC P Circulate 45 BBLS at 5 BPM / 535 psi 4,703.0 4,641.0 6/7/2025 23:30 6/8/2025 00:00 0.50 COMPZN, CSGRCY MPSP P PT RBP to 1000 psi for 10 minutes charted. Good test. 4,641.0 4,641.0 6/8/2025 00:00 6/8/2025 06:30 6.50 COMPZN, CSGRCY MPSP P Dump 20 sacks (60lb bags of river sand) down DP at 15 minutes per sack. Then allow it to settle for 30 minutes. Tag top of sand @ 4,667'. 4,703.0 4,641.0 6/8/2025 06:30 6/8/2025 07:00 0.50 COMPZN, CSGRCY CIRC P POOH 2 stands, and circulate string volume @ 212 GPM @ 370PSI. 4,641.0 4,447.0 6/8/2025 07:00 6/8/2025 08:30 1.50 COMPZN, CSGRCY TRIP P POOH racking back drill pipe. 4,447.0 0.0 6/8/2025 08:30 6/8/2025 08:45 0.25 COMPZN, CSGRCY OTHR P Clean and clear rig floor. Pull wear bushing. 0.0 0.0 6/8/2025 08:45 6/8/2025 09:30 0.75 COMPZN, CSGRCY NUND P Pull riser, release turn buckles. N/D BOP and rack back. 0.0 0.0 6/8/2025 09:30 6/8/2025 11:00 1.50 COMPZN, CSGRCY CUTP P R/U Cameron jacks. Grow and stretch 7" CSG. 70 K Starting force. 0" total growth. *Offline pick up and M/U YJOS 7" Spear. 0.0 0.0 6/8/2025 11:00 6/8/2025 13:00 2.00 COMPZN, CSGRCY NUND P Break bolts w/ Cameron grow and stretch equipment still rigged up. Monitor well head for 20 min for growth. R/D Cameron grow and stretch equipment. N/D tubing spool, and set aside. 0.0 0.0 6/8/2025 13:00 6/8/2025 14:00 1.00 COMPZN, CSGRCY CUTP P Stab spear into 7" and pull 100 K tension to clear collar for slips and CSG cut. FMC set slips. Slack off CSG into slips w/ 100 K tension. Release spear, and pull to floor. FMC Cut off Mandrel hanger. 0.0 0.0 6/8/2025 14:00 6/8/2025 15:30 1.50 COMPZN, CSGRCY NUND P N/U BOP to CSG spool. R/U turnbuckles, and install riser. Secure cellar. Fill stack and check for leaks. *Offline: P/U MSC cutter BHA on the rig floor while N/U BOP. 0.0 0.0 6/8/2025 15:30 6/8/2025 16:45 1.25 COMPZN, CSGRCY TRIP P RIH w/ MSC F/ Surface to 3876' UWT87K /SOW 80K 0.0 3,876.0 6/8/2025 16:45 6/8/2025 17:30 0.75 COMPZN, CSGRCY SLPC P Slip and cut 112' drilling line. Inspect breaks and rollers. 3,876.0 3,876.0 6/8/2025 17:30 6/8/2025 18:00 0.50 COMPZN, CSGRCY SVRG P Service rig, grease crown, draw works, and Blakjak. 3,876.0 3,876.0 6/8/2025 18:00 6/8/2025 19:00 1.00 COMPZN, CSGRCY TRIP P RIH F/3876' T/4395' UWT 100K /SOW 90K 3,876.0 4,395.0 6/8/2025 19:00 6/8/2025 20:00 1.00 COMPZN, CSGRCY CPBO P Cut casing at 4395', 80 RPM @ 4900 TQ, Pumping 1BPM @ 140 psi. 4,395.0 4,395.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 4/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/8/2025 20:00 6/9/2025 00:00 4.00 COMPZN, CSGRCY CIRC P Taking returns to tiger tank, pump 50 bbl deep clean pill followed by 120 degree seawater and let soak on backside for 30 minutes. Pump another 50 bbl deep clean pill followed by 120 degree seawater and let soak for another 30 minutes. Circulate seawater at 3BPM/ 391 psi until returns are clean at surface. OA pressure 120 psi. 4,395.0 4,395.0 6/9/2025 00:00 6/9/2025 02:00 2.00 COMPZN, CSGRCY TRIP P Flow check well static. POOH with BHA #5 MSC F/4395 T/surface and LD MSC. UWT 100K / SOW 90K 4,395.0 0.0 6/9/2025 02:00 6/9/2025 02:30 0.50 COMPZN, CSGRCY PULL P MU spear and pull 7"casing from cut. Breakover at 165K, UWT 140K. Remove CSG slips. 0.0 0.0 6/9/2025 02:30 6/9/2025 03:00 0.50 COMPZN, CSGRCY RURD P RU 7" casing equipment. 0.0 0.0 6/9/2025 03:00 6/9/2025 07:30 4.50 COMPZN, CSGRCY PULL P Pull casing F/4350' T/Surface UWT 140K 4,350.0 0.0 6/9/2025 07:30 6/9/2025 08:00 0.50 COMPZN, CSGRCY OTHR P R/D GBR CSG equipment. Clean and clear rig floor. 0.0 0.0 6/9/2025 08:00 6/9/2025 11:30 3.50 COMPZN, CSGRCY OTHR T Attempt to set test plug. When filling the stack fluid observed coming out of the annulus. Pull test plug to rig floor. FMC verify LDS. Marks on test plug, file marks, and attempt to set test plug again. Test plug would not land out on correct RKB measurement. Grease test plug and land out on correct RKB measurement. Would not hold fluid. Pull test plug to rig floor and inspect. No signs of damage. B/O L/D test plug, R/U and flush well head. FMC Rep get another test plug. Attempt to set, unable to get a test. Pull test plug and C/O seal 0.0 0.0 6/9/2025 11:30 6/9/2025 12:30 1.00 COMPZN, CSGRCY BOPE P Set Test plug. R/U test equipment. Fill stack and test lines. Test BOP break to 250 low 2500 PSI high 5 min each: GOOD. R/D test equipment, and pull test plug. 0.0 0.0 6/9/2025 12:30 6/9/2025 13:00 0.50 COMPZN, CSGRCY OTHR P Set wear ring and RILDS. 0.0 0.0 6/9/2025 13:00 6/9/2025 15:00 2.00 COMPZN, CSGRCY BHAH P P/U BHA # 7, Casing Dress off BHA. 0.0 247.0 6/9/2025 15:00 6/9/2025 16:00 1.00 COMPZN, CSGRCY TRIP P RIH w/ Dress of BHA F/ 245' to 4360'. PUWT: 112K SOWT: 97K 247.0 4,360.0 6/9/2025 16:00 6/9/2025 16:30 0.50 COMPZN, CSGRCY MILL P Wash down and tag top of stump @ 4390'. P/U start rotary @ 60 RPM. Slack off and dress top of stump F/ 4390'' to 4391.11'. PUWT: 112 K SOWT: 105 K ROTWT: 97 K (2.2K free torque). PSI: 300 @ 210 GPM. 2.8-3.1K Torque 4-5K WOB. 4,360.0 4,391.1 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 5/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/9/2025 16:30 6/9/2025 17:00 0.50 COMPZN, CSGRCY CIRC P Circulate around 45 BBL/300 High vis sweep @ 460 GPM @ 1860 PSI. Sweep brought back alot of fine cement form surface casing leak at 150'. 4,391.0 4,388.0 6/9/2025 17:00 6/9/2025 19:00 2.00 COMPZN, CSGRCY TRIP P TOH with DP F/4388' T/247' UWT 85K 4,388.0 247.0 6/9/2025 19:00 6/9/2025 20:30 1.50 COMPZN, CSGRCY BHAH P Lad BHA #7 247.0 0.0 6/9/2025 20:30 6/9/2025 21:30 1.00 COMPZN, CSGRCY CLEN P Clean rig floor. Pull wear ring. 0.0 0.0 6/9/2025 21:30 6/9/2025 22:00 0.50 COMPZN, CASING BHAH P RU to run 7" casing handling equipment and load jewelry in pipe shed. 0.0 0.0 6/9/2025 22:00 6/9/2025 23:30 1.50 COMPZN, CASING PUTB P PU casing per tally F/surface T/473' UWT 40K/ SOW 40K 0.0 473.0 6/9/2025 23:30 6/10/2025 00:00 0.50 COMPZN, CASING SVRG P Service rig. Grease rig floor equipment. 473.0 473.0 6/10/2025 00:00 6/10/2025 05:00 5.00 COMPZN, CASING PUTB P PU casing per tally F/473' T/4380' PUWT: 130 K SOWT: 120 K 473.0 4,380.0 6/10/2025 05:00 6/10/2025 05:30 0.50 COMPZN, CASING PUTB P P/U 15', and 9' pup joints. Tag top of stump 4394', No-GO 4398 25K Down. P/U to 50K over and hold for 2 min. Slack off and repeat one more time. 4,394.0 4,398.0 6/10/2025 05:30 6/10/2025 06:00 0.50 COMPZN, CASING RURD P R/U head pin, and test equipment. Fill lines, and purge air. 4,398.0 4,398.0 6/10/2025 06:00 6/10/2025 06:30 0.50 COMPZN, CASING PRTS P Pressure test 7" and CSG patch to 500 PSI for 10 min: GOOD TEST. 4,398.0 4,398.0 6/10/2025 06:30 6/10/2025 07:00 0.50 COMPZN, CEMENT PACK P Line up and inflate ECP per SLB rep. Pressure up to 1500 PSI, and hold for 5 min. Increase pressure in 100 PSI steps holding for 1 min to 1900 PSI. Cont to pressure up to 2900 PSI in 200 PSI steps holding for 2 min. Bleed pressure off of 7" @ 300 PSI/ min to 0 PSI. Indication of ECP inflating. 4,398.0 4,398.0 6/10/2025 07:00 6/10/2025 07:30 0.50 COMPZN, CEMENT PRTS P Line up and pressure test 7" CSG to 2500 PSI for 10 min: GOOD TEST. 4,398.0 4,398.0 6/10/2025 07:30 6/10/2025 11:00 3.50 COMPZN, CEMENT NUND P N/D BOP's Raise, and drain 7". FMC set slips, Slack 7" into slips w/ 10K over string weight set into slips. FMC set up Wach's cutter, and cut 7". Pull 7" cut joint, and pup joints to surface B/O and L/D. Rack back stack on pedastal 4,398.0 0.0 6/10/2025 11:00 6/10/2025 13:00 2.00 COMPZN, CEMENT NUND P Install pack off, N/U tubing spool. FMC rep test pack off to 4000 PSI for 10 min. 0.0 0.0 6/10/2025 13:00 6/10/2025 14:00 1.00 COMPZN, CEMENT NUND P N/U BOP. 0.0 0.0 6/10/2025 14:00 6/10/2025 14:30 0.50 COMPZN, CEMENT BOPE P Set test plug in tubing spool. R/U test equipment. Fill stack w/ water, flush and purge lines. Test BOP break to 250 PSI/ Low 2500 PSI high 5 min each: GOOD. 0.0 0.0 6/10/2025 14:30 6/10/2025 15:00 0.50 COMPZN, CEMENT OTHR P Pull test plug, and set Wear bushing. 0.0 0.0 6/10/2025 15:00 6/10/2025 16:00 1.00 COMPZN, CEMENT BHAH P PJSM. P/U and M/U NCS sleeve shifting BHA. 0.0 57.0 6/10/2025 16:00 6/10/2025 19:30 3.50 COMPZN, CEMENT TRIP P RIH w/ drill pipe F/ 57' to 4398' PUWT: 98K SOWT: 85K 57.0 4,398.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 6/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2025 19:30 6/10/2025 20:00 0.50 COMPZN, CEMENT OTHR P P/U slowly @ locate w/ 15K over pull @ 4349'. Cont. to P/U 15' to 4334'. Set down and set down and confirm ~4' of travel from slip joint in BHA. 4,398.0 4,334.0 6/10/2025 20:00 6/10/2025 20:30 0.50 COMPZN, CEMENT OTHR P Space out, close annular, lubricate pipe, and obtain parameters stripping up through annular to simulate closing NCS sleeve after cement job. PUWT: 110 K 4,334.0 4,334.0 6/10/2025 20:30 6/10/2025 20:45 0.25 COMPZN, CEMENT OTHR P Rack back 2 stands in the derrick, P/U 2 10' pups, and one full joint. RIH one stand. 4,334.0 4,398.0 6/10/2025 20:45 6/10/2025 20:45 COMPZN, CEMENT OTHR P P/U F/ 4398' to 4348', @ 4348' observe 15 K overpull (indicating locate in NCS sleeve). P/U 15' set down 10K to shift tool. Slack off to 4398' 4,398.0 4,398.0 6/10/2025 20:45 6/10/2025 22:30 1.75 COMPZN, CEMENT CIRC P R/U and spot high vis pill inside of 7" @ 4000'. 4,398.0 4,398.0 6/10/2025 22:30 6/10/2025 23:00 0.50 COMPZN, CEMENT CMNT P Locate in NCS sleeve @ 4348'. Set down 15K to engage pack off. Close annular, and pressure up to 1300 PSI. Observe pressure drop, and returns out the annulus indicating sleeve open. Line up and pump taking returns out the OA to confirm NCS sleeve shifted open. 4,398.0 4,348.0 6/10/2025 23:00 6/11/2025 00:00 1.00 COMPZN, CEMENT CIRC P Circulate bottoms up in the 7" x 9 5/8" Annulus. 120 GPM @ 210 PSI. 4,348.0 4,348.0 6/11/2025 00:00 6/11/2025 00:30 0.50 COMPZN, CEMENT SFTY P Pre job safety meeting w/ HAL CMNT crew. 4,348.0 4,348.0 6/11/2025 00:30 6/11/2025 02:00 1.50 COMPZN, CEMENT CMNT P HAL CMNT pump 5 BBLS of fresh water. Shut in lines, and test to 2500 PSI. HAL CMNT pump 10 BBLS died spacer. Batch up CMNT and pump 174 BBLs CMNT @ 3.5 BBL/ Min @ 1680 PSI. CMNT to surface @ 138 BBLS. Once good cement to surface shut down pumping CMNT. HAL CMNT pump 10 BBLS/ Fresh water. Line up w/ mud pumps and displace w/ rig pumps. FCP: 2150 PSI. Cement in place @ 0200 hrs. 4,348.0 4,348.0 6/11/2025 02:00 6/11/2025 02:30 0.50 COMPZN, CEMENT CMNT P Reduce annular closing pressure to 800 PSI, P/U to 160 K, observe indications of sleeve shifting. Flow check annulas: GOOD. 4,348.0 4,348.0 6/11/2025 02:30 6/11/2025 03:00 0.50 COMPZN, CEMENT CIRC P Line up and reverse circulate hole clean. 7 BBL/Min @ 960 PSI. Open annular, put foam ball in drill pipe. 4,348.0 4,348.0 6/11/2025 03:00 6/11/2025 04:30 1.50 COMPZN, CEMENT CIRC P Blow down and R/D circulating lines. Put wiper ball in the drill pipe, kelly up to the string and circulate 1.5 x string volume. 4,348.0 4,348.0 6/11/2025 04:30 6/11/2025 05:00 0.50 COMPZN, CEMENT CLEN P Blow Down Top Drive Flush out BOP stack and Line up trip tank. 4,348.0 4,348.0 6/11/2025 05:00 6/11/2025 08:00 3.00 COMPZN, WELLPR TRIP P POOH and Stand Back 3 1/2" D.P. 4,320.0 57.0 6/11/2025 08:00 6/11/2025 08:30 0.50 COMPZN, WELLPR BHAH P L/D NCS Innovus sleeve shifting BHA per NCS rep. 57.0 0.0 6/11/2025 08:30 6/11/2025 09:30 1.00 COMPZN, WELLPR BHAH P P/U RCJB BHA F/ Surface to 242'. 0.0 242.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 7/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/11/2025 09:30 6/11/2025 10:30 1.00 COMPZN, WELLPR TRIP P RIH w/ RCJB BHA F/ ' 242' to 4212'. 2.5K extra drag observed going through Innovus sleeve @ 4348'. PUWT: 105 K SOWT: 85 K 242.0 4,212.0 6/11/2025 10:30 6/11/2025 14:30 4.00 COMPZN, WELLPR REAM P Wash in the hole F/ 4212' to 4400' @ 120 GPM 220 PSI. @ 4400' drop RCJB ball. Pump pressure w/ ball on seat in RCJB 320 PSI @ 120 GPM. Cont. to RIH to 4620'. Set down 10 K. P/U start pumps @ 120 GPM @ 320 PSI. Start rotary @ 60 RPM @ 2.9 K TQ. Cont. to clean out debris/ sand to 4690'. Leaving ~ 13' of sand on top of RBP. PUWT: 108 K SOWT: 85K ROTWT: 100K 60 RPM @ 2.9 K TQ. 5-8 K WOB. 4,212.0 4,690.0 6/11/2025 14:30 6/11/2025 15:30 1.00 COMPZN, WELLPR CIRC P Pump around high vis sweep @ 11 BPM @ 1600 PSI. Observe sand @ shakers. 4,690.0 4,690.0 6/11/2025 15:30 6/11/2025 16:00 0.50 COMPZN, WELLPR TRIP P Trip out of the hole F/ 4690' to 2134'. PUWT: 105 K SOWT: 85 K 4,690.0 2,134.0 6/11/2025 16:00 6/11/2025 17:30 1.50 COMPZN, WELLPR PULD P POOH L/D Drill pipe. 2,134.0 242.0 6/11/2025 17:30 6/11/2025 18:30 1.00 COMPZN, WELLPR BHAH P POOH L/D BHA F/ 242' to surface. Clean out RCJB w/ Chunks of CMT & Dump sand M/U BHA #9 rerun in hole 242.0 0.0 6/11/2025 18:30 6/11/2025 20:30 2.00 COMPZN, WELLPR TRIP P RIH BHA # 9 W/ clean out Assy 0.0 0.0 6/11/2025 20:30 6/11/2025 22:00 1.50 COMPZN, WELLPR WASH P Start Washing F/ 4680' T/ 4690' UW 115k DN 100k Rot 85k pumping 25 bbls Hi vis Sweep Around @ 6 bbls min w/ 825 PSI W/ No issue 4,690.0 0.0 6/11/2025 22:00 6/12/2025 00:00 2.00 COMPZN, WELLPR TRIP P POOH 6/12/2025 00:00 6/12/2025 01:30 1.50 COMPZN, WELLPR BHAH P L/D BHA # 9 M/U BHA #10 w/ RBP Retrieving tool. Chunks of CMNT, and sand in Junk baskets. 242.0 0.0 6/12/2025 01:30 6/12/2025 02:00 0.50 COMPZN, WELLPR BHAH P P/U BHA # 9 (RBP retrieving BHA). 0.0 30.0 6/12/2025 02:00 6/12/2025 03:30 1.50 COMPZN, WELLPR TRIP P RIH F/ 30' to 4636'. PUWT: 110 K SOWT: 85 K 30.0 4,636.0 6/12/2025 03:30 6/12/2025 04:00 0.50 COMPZN, WELLPR WASH P Start pumps, and wash F/ 4636' to 4696'. @ 4696' tag remaining ~10' of sand. Pumping @ 120 GPM @ 200 PSI. 4,636.0 4,636.0 6/12/2025 04:00 6/12/2025 04:45 0.75 COMPZN, WELLPR CIRC P Pump High vis sweep. Increase flow rate to 252 GPM @ 650 PSI. Circulate hole clean. 4,636.0 4,636.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 8/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2025 04:45 6/12/2025 05:15 0.50 COMPZN, WELLPR MPSP P Release RBP per YJOS fishing rep. Allow to relax for 20 min. 4,636.0 4,636.0 6/12/2025 05:15 6/12/2025 06:00 0.75 COMPZN, WELLPR CIRC P Circulate bottoms up @ 252 GPM @ 650 PSI. 4,636.0 4,636.0 6/12/2025 06:00 6/12/2025 09:00 3.00 COMPZN, WELLPR PULD P POOH L/D DP F/ 4636' to 30'. 4,636.0 30.0 6/12/2025 09:00 6/12/2025 09:30 0.50 COMPZN, WELLPR BHAH P Inspect and L/D RBP BHA. 30.0 0.0 6/12/2025 09:30 6/12/2025 10:00 0.50 COMPZN, WELLPR PRTS P R/U and Pressure test CSG to 2500 PSI for 30 min: GOOD TEST 0.0 0.0 6/12/2025 10:00 6/12/2025 11:00 1.00 COMPZN, WELLPR OTHR P Pull wear bushingFlush BOP, and well head. 0.0 0.0 6/12/2025 11:00 6/12/2025 12:00 1.00 COMPZN, RPCOMP RURD P R/U GBR, and HAL completions equipment. Load remaining completions jewelry verify talley 0.0 0.0 6/12/2025 12:00 6/12/2025 13:00 1.00 COMPZN, RPCOMP PUTB P PJSM w/ Rig crew, GBR, HAL, and SLB completions. P/U and M/U tubing to gauge mandrel. 0.0 189.0 6/12/2025 13:00 6/12/2025 14:00 1.00 COMPZN, RPCOMP OTHR P HAL tie in gauge wire to gauge. Verify lines, and pressure test Tech wire connection to 10,000 PSI for 10 min. 189.0 189.0 6/12/2025 14:00 6/13/2025 00:00 10.00 COMPZN, RPCOMP PUTB P Cont. RIH w/ 4.5" 12.6# L-80 tubing F/ 189' to 5600'. Torque all connections to 3800 ft/lbs using GBR torque turn equipmnet. PUWT: 110K SOWT: 100K 189.0 5,600.0 6/13/2025 00:00 6/13/2025 02:00 2.00 COMPZN, RPCOMP PULD P Cont. RIH w/ 4.5" 12.6# L-80 tubing F/ 5600' to 6608' '.Torque all connections to 3800 ft/lbs using GBR torque turn equipmnet. PUWT: 115k SOWT: 85k 5,600.0 6,608.0 6/13/2025 02:00 6/13/2025 04:30 2.50 COMPZN, RPCOMP PACK P Space out and Locate on stub Tag 6604' and set down and shear pins w/ 15k slick off to 6610' P/U 2' T/ 6608' and Space out w/ 2 - 8.13' pups tot jts run 155 jts 4 1/2" 563 - 2 pups below jt155 M/U FMC hanger and Hook upTEC- Through FMC Hanger and test same All good RIH Land Hanger RILDS (Tot Run157 Clamps,9 Mid Jt Clamps) 5,600.0 6,608.0 6/13/2025 04:30 6/13/2025 07:00 2.50 COMPZN, RPCOMP CIRC P Circ CI DownTubing and chase w/ clean S/W Take Returns out IA @ 3 BBls to Open topTank W/ 350 PSI pump 125 + bbls and spot in IA 6,608.0 6,608.0 6/13/2025 07:00 6/13/2025 08:00 1.00 COMPZN, RPCOMP PACK P Drop Rod 1 7/8" Ball and rod. Allow ball and rod to fall for 20 min. Line up on tubing and pressure up 3500 PSI to set packer. Hold for 30 min: GOOD. Bleed tubing to 1500 PSI and hold. Line up on IA and pressure up @ ~ 1900 PSI, pressure in the tubing started to rise with pressure in annulus. 6,608.0 6,608.0 6/13/2025 08:00 6/13/2025 09:00 1.00 COMPZN, RPCOMP PACK T Bleed IA, and observe tubing pressure bleed off. Bleed well to 0 PSI. Line up on tubing and pressure up to 500 PSI. Observe pressure build up in the annulus as well. Trouble shoot. 6,608.0 6,608.0 6/13/2025 09:00 6/13/2025 09:30 0.50 COMPZN, RPCOMP PACK T Call out HAL slick line. R/D landing/ test joint. 6,608.0 6,608.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Page 9/9 1C-24 Report Printed: 7/7/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/13/2025 09:30 6/13/2025 10:00 0.50 COMPZN, RPCOMP SVRG T Rig service chane top drive gear oil. 6,608.0 6,608.0 6/13/2025 10:00 6/13/2025 10:30 0.50 COMPZN, RPCOMP SLKL T R/U HAL Slick line. 6,608.0 6,608.0 6/13/2025 10:30 6/13/2025 12:30 2.00 COMPZN, RPCOMP SLKL T HAL slick line P/U tools, RIH and set junk catcher @ 6548'. POOH & L/D tools. 6,608.0 6,608.0 6/13/2025 12:30 6/13/2025 14:00 1.50 COMPZN, RPCOMP SLKL T HAL slick P/U GLM valve pulling BHA. RIH @ pull SOV form station 3 @ 6351'. POOH L/D tools. SOV had sheared. 6,608.0 6,608.0 6/13/2025 14:00 6/13/2025 16:00 2.00 COMPZN, RPCOMP SLKL T HAL slick line P/U BHA for setting SOV in GLM. Unable to get SOV to set in GLM. POOH reconfigure BHA. 6,608.0 6,608.0 6/13/2025 16:00 6/13/2025 16:45 0.75 COMPZN, RPCOMP SLKL T HAL slick line RIH w/ second SOV setting BHA. Set SOV in GLM station #3. POOH L/D tools. 6,608.0 6/13/2025 16:45 6/13/2025 17:00 0.25 COMPZN, RPCOMP SLKL T R/D HAL slick line set equipment to the side on the floor. 6,608.0 6,608.0 6/13/2025 17:00 6/13/2025 19:00 2.00 COMPZN, RPCOMP PRTS P R/U test equipment. Fill and purge lines. Test tubing to 3000 PSI for 30 min. Bleed tubing to 1500 PSI and lock in. Pressure up on IA to 2500 PSI. All Good Bleed Down Tubing and Shear SOV All good 6,608.0 6,608.0 6/13/2025 19:00 6/13/2025 20:00 1.00 COMPZN, WHDBOP DSL P R/D Slick line and Install BPV Test T/ 1000 PSI all good 6,608.0 0.0 6/13/2025 20:00 6/14/2025 00:00 4.00 COMPZN, WHDBOP NUND P Blow Down All Equip and Perform Between Well Maintenance of the BOP Change out annular on the BOP Stack first 0.0 0.0 6/14/2025 00:00 6/14/2025 05:00 5.00 COMPZN, WHDBOP BOPE P Continue Perform Between Well Maintenance of the BOP Change out annular on the BOP Stack first and Serivce All BOP Rams and Doors 0.0 0.0 6/14/2025 05:00 6/14/2025 06:00 1.00 DEMOB, MOVE NUND P N/D Stack, and rack back. 0.0 0.0 6/14/2025 06:00 6/14/2025 08:00 2.00 DEMOB, MOVE NUND P FMC, and HAL completions terminate lines at well head. HAL perform checks on lines. 0.0 0.0 6/14/2025 08:00 6/14/2025 10:30 2.50 DEMOB, MOVE NUND P N/U tree and adaptor flange. 0.0 0.0 6/14/2025 10:30 6/14/2025 11:00 0.50 DEMOB, MOVE SEQP P FMC, and HAL completions test connections on well head. FMC test Hanger neck void to 5000 PSI. R/U fill tree with diesel and test to 5000 PSI. 0.0 0.0 6/14/2025 11:00 6/14/2025 12:00 1.00 DEMOB, MOVE FRZP P LRS pump 75 BBLS diesel freeze protect into the anuulus. Line up tubing and IA, and allow to U-tube for 1 hour. Rig release @ 1200. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/14/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,201.0 1C-24 6/26/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLD, Pull catcher, B&R, RHC, Catcher, & RBP. Update tag depth 1C-24 6/26/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: DEFORMED LINER @ 7696'-7715', MIN ID 3.4"; CALIPER SURVEY AVAILABLE 8/19/2005 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 161.0 161.0 62.58 API5LGrB PEB SURFACE 9 5/8 8.83 41.1 4,710.9 4,413.3 40.00 L-80 BTC 7" Tie back 7 6.28 0.0 4,405.7 4,138.3 26.00 L-80 HYD 563 PRODUCTION 7 6.28 4,402.7 6,835.4 6,252.5 26.00 L-80 BTC-MOD LINER 4 1/2 3.96 6,644.0 9,345.0 6,547.4 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 6,621.6 String Max No… 4 1/2 Set Depth … 6,120.5 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD 563 ID (in) 3.96 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) 36.4 36.4 0.11 Hanger 10.880 FMC Gen 5 Tubing hanger FMC GEN 5 3.958 2,303.2 2,218.8 26.02 Mandrel – GAS LIFT 6.040 KBG 4-5 GLM SN 24655-06 SLB KBG 3.865 3,861.9 3,644.2 23.53 Mandrel – GAS LIFT 6.054 KBG 4-5 GLM SN 24655-07 SLB KBG 3.865 6,363.5 5,923.1 34.21 Mandrel – GAS LIFT 6.053 KBG 4-5 GLM SN 24001-17 SLB KBG 3.865 6,431.8 5,978.6 37.17 Sensor - Discharge Gauge 5.670 HAL OPSIS Gauge mandrel HAL OPSIS 3.891 6,495.1 6,028.0 40.12 Packer 5.867 4.5"x 7" Blue Pack max packer SLB bluepack max PH 3.875 6,559.5 6,076.2 43.05 Nipple - X 5.003 X Nipple 3.183" Profile HAL X-nipple 3.813 6,614.5 6,115.6 45.49 Overshot 5.541 PBOS 6.25' total swallow, shear screws 3.45' ~15K SLB PBOS 5.000 Top (ftKB) 6,617.3 Set Depth … 6,654.9 String Max No… 4 1/2 Set Depth … 6,143.4 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT MOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,641.8 6,134.5 46.82 LOCATOR 5.200 NO GO LOCATOR Baker 3.840 6,642.8 6,135.2 46.88 SEAL ASSY 4.750 GBH-22 SEAL ASSEMBLY Baker 3.840 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,615.0 6,436.0 85.66 WHIPSTOCK BOT 4.5" Monobore XL 7/3/2018 0.000 7,674.0 6,440.0 86.58 PLUG CIBP 12/30/2017 0.000 7,699.0 6,441.4 86.81 PINCH POINT COIL TUBING(CTU-11) TAGGED PINCH POINT IN LINER 12/30/2017 3.500 7,699.0 6,441.4 86.81 FISH CIBP 12/30/2017 3.500 8,139.2 6,478.1 85.26 PLUG BAKER INFLATABLE BRIDGE PLUG (OAL=11.58') 3/7/2007 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,303.2 2,218.8 26.02 1 GAS LIFT GLV BK 1 1,215.0 6/24/2025 SLB KBG-4-5 0.250 3,861.9 3,644.2 23.53 2 GAS LIFT OV BK 1 6/24/2025 SLB KBG-4-5 0.313 6,363.5 5,923.1 34.21 3 GAS LIFT DMY BK 1 6/24/2025 SLB KBG-4-5 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,354.4 4,092.2 25.89 Collar - Stage 8.250 7" NCS Cementer NCS Stage collar 6.207 4,378.5 4,113.8 26.05 Packer 8.143 7"x 9 5/8" AZIP Packer SLB AZIP 6.276 6,644.0 6,136.0 46.93 TIEBACK 4.750 LINER TIE BACK EXTENSION 3.958 6,658.1 6,145.6 47.63 PACKER 5.960 4.5" X 7" ZXP LINER TOP PACKER W/HOLDDOWNS, HR PROFILE BAKER 4.300 9,250.9 6,527.7 77.74 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,485.0 7,520.0 6,423.6 6,427.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,550.0 7,670.0 6,430.4 6,439.7 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,700.0 7,885.0 6,441.5 6,455.1 C-3, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 1C-24, 7/10/2025 12:04:31 PM Vertical schematic (actual) LINER; 6,644.0-9,345.0 FLOAT SHOE; 9,343.0-9,345.0 FLOAT COLLAR; 9,282.3- 9,283.4 LANDING COLLAR; 9,250.9- 9,252.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 PINCH POINT; 7,699.0 FISH; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 DEPLOYMENT SLEEVE; 7,601.0-7,601.8 IPERF; 7,485.0-7,520.0 FLOAT COLLAR; 6,931.6- 6,932.9 PRODUCTION; 4,402.7-6,835.4 FLOAT SHOE; 6,833.9-6,835.4 HANGER; 6,666.1-6,672.8 PACKER; 6,658.1-6,666.1 TIEBACK; 6,644.0-6,658.1 SEAL ASSY; 6,642.8 LOCATOR; 6,641.8 Overshot; 6,614.5 Packer; 6,495.1 Sensor - Discharge Gauge; 6,431.8 Mandrel – GAS LIFT; 6,363.5 SURFACE; 41.1-4,710.9 FLOAT SHOE; 4,709.2-4,710.9 FLOAT COLLAR; 4,629.3- 4,630.8 7" Tie back; 0.0-4,405.7 Casing Patch; 4,401.8-4,405.7 Annular Fluid - Seawater; 2,100.0-6,617.3; 6/14/2025 Collar - Stage; 4,354.4-4,359.4 Mandrel – GAS LIFT; 3,861.9 Mandrel – GAS LIFT; 2,303.2 Remedial; 40.0 ftKB Annular Fluid - Diesel; 36.4- 2,100.0; 6/14/2025 PORT COLLAR; 1,023.9- 1,026.9 CONDUCTOR; 42.0-161.0 HANGER; 41.1-42.6 Hanger; 36.4 KUP PROD KB-Grd (ft) 46.42 RR Date 1/26/2002 Other Elev… 1C-24 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292306300 Wellbore Status PROD Max Angle & MD Incl (°) 95.23 MD (ftKB) 8,604.82 WELLNAME WELLBORE1C-24 Annotation Last WO: End DateH2S (ppm) 100 Date 8/11/2023 Comment Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,945.0 8,015.0 6,461.0 6,467.6 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,065.0 8,090.0 6,471.9 6,474.0 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,500.0 8,600.0 6,497.8 6,492.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,650.0 8,750.0 6,488.3 6,483.1 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,800.0 8,900.0 6,480.7 6,478.5 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,950.0 9,150.0 6,480.0 6,506.3 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 9,180.0 9,215.0 6,512.6 6,520.1 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.0 4,378.0 40.0 4,113.4 Remedial 6/11/2025 1C-24, 7/10/2025 12:04:32 PM Vertical schematic (actual) LINER; 6,644.0-9,345.0 FLOAT SHOE; 9,343.0-9,345.0 FLOAT COLLAR; 9,282.3- 9,283.4 LANDING COLLAR; 9,250.9- 9,252.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 PINCH POINT; 7,699.0 FISH; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 DEPLOYMENT SLEEVE; 7,601.0-7,601.8 IPERF; 7,485.0-7,520.0 FLOAT COLLAR; 6,931.6- 6,932.9 PRODUCTION; 4,402.7-6,835.4 FLOAT SHOE; 6,833.9-6,835.4 HANGER; 6,666.1-6,672.8 PACKER; 6,658.1-6,666.1 TIEBACK; 6,644.0-6,658.1 SEAL ASSY; 6,642.8 LOCATOR; 6,641.8 Overshot; 6,614.5 Packer; 6,495.1 Sensor - Discharge Gauge; 6,431.8 Mandrel – GAS LIFT; 6,363.5 SURFACE; 41.1-4,710.9 FLOAT SHOE; 4,709.2-4,710.9 FLOAT COLLAR; 4,629.3- 4,630.8 7" Tie back; 0.0-4,405.7 Casing Patch; 4,401.8-4,405.7 Annular Fluid - Seawater; 2,100.0-6,617.3; 6/14/2025 Collar - Stage; 4,354.4-4,359.4 Mandrel – GAS LIFT; 3,861.9 Mandrel – GAS LIFT; 2,303.2 Remedial; 40.0 ftKB Annular Fluid - Diesel; 36.4- 2,100.0; 6/14/2025 PORT COLLAR; 1,023.9- 1,026.9 CONDUCTOR; 42.0-161.0 HANGER; 41.1-42.6 Hanger; 36.4 KUP PROD 1C-24 ... WELLNAME WELLBORE1C-24 1 Eller, Cy From:Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent:Friday, June 6, 2025 11:21 PM To:Eller, Cy Cc:Hobbs, Greg S; Coberly, Jonathan Subject:Re: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Cy, Your plan to pull the cbl from the SC shoe is approved. The COA to verify of cement can be voided. Jack &ƌŽŵ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗&ƌŝĚĂǇ͕:ƵŶĞϲ͕ϮϬϮϱϭϬ͗ϰϯD dŽ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖ŽďĞƌůǇ͕:ŽŶĂƚŚĂŶ ф:ŽŶĂƚŚĂŶ͘ŽďĞƌůǇΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Hi Jack, I wanted to follow up to confirm that you received my previous email. If all goes well, I expect we will be pulling our CBL over the weekend. Since we are requesting to deviate from the COA on the approved Sundry, I wanted to make sure we are on the same page. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 &ƌŽŵ͗ůůĞƌ͕Ǉ ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵŶĞϰ͕ϮϬϮϱϭϭ͗ϯϱD dŽ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖ŽďĞƌůǇ͕:ŽŶĂƚŚĂŶф:ŽŶĂƚŚĂŶ͘ŽďĞƌůǇΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Hi Jack, Thank you for your response. I received the approved sundry this morning. After looking at your COA and comment on step #6, it appears that I made a typo in my procedure. 2 Our plan is to pull a CBL from the SC shoe, not the PC shoe as listed on the procedure. Please note that we are unable to reach the PC shoe because it is below a liner top packer with 4-1/2” liner. The objective of this CBL is to quickly identify any fill in the OA before cutting and attempting to pull casing. Due to the value of the information, and the nature of the intended use of the log in step #6, we plan to maintain the precedent that the calculated TOC is sufficient for packer placement. I apologize for the confusion, please let me know if you have any questions or concerns with this plan. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 &ƌŽŵ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵŶĞϰ͕ϮϬϮϱϵ͗ϭϴD dŽ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Morning Cy, 1C-24 is with the commissioners, the energy conference has slowed things down. I am hopeful you will have it by EOD, if not I will give you a verbal to start the work. Jack &ƌŽŵ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵŶĞϰ͕ϮϬϮϱϴ͗ϮϬD dŽ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Good morning Jack, Just following up on the 1C-24 Sundry. We are planning to move from 1R-05 to 1C-24 tonight. Do you have any updates you can share on this Sundry? Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 &ƌŽŵ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂǇϮϵ͕ϮϬϮϱϯ͗ϬϱWD dŽ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх 3 Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Thanks Cy. You should have an approved sundry by EOW. Jack &ƌŽŵ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ĞŶƚ͗dƵĞƐĚĂǇ͕DĂǇϮϳ͕ϮϬϮϱϯ͗ϭϯWD dŽ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх Đ͗,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Hi Jack, I wanted to give you an update on 1C-24. Everything went well over the weekend, and with 3K-35 being postponed, the Nabors 7ES line has shifted to the left a bit as well. The current estimated start date shown on the schedule for 1C-24 is 6/4/2025. Please let me know if there is anything you need from me. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 &ƌŽŵ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂǇϭϱ͕ϮϬϮϱϴ͗ϱϳD dŽ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ Interesting. This one has it. Thanks Jack &ƌŽŵ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂǇϭϱ͕ϮϬϮϱϴ͗ϱϮD dŽ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 4 Hi Jack, I believe the original submission had the current and proposed schematics included. Please let me know if you have any opening it and I can resend. Thanks, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 &ƌŽŵ͗>ĂƵ͕:ĂĐŬ:;K'ͿфũĂĐŬ͘ůĂƵΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂǇϭϱ͕ϮϬϮϱϴ͗ϰϰD dŽ͗ůůĞƌ͕ǇфǇ͘ůůĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁W/ͺ<ZhͺϭͲϮϰͺƌĞĐĞŝǀĞĚͺϬϱϭϱϮϱͺƌĞǀŝĞǁ͘ƉĚĨ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cy, Please include current and proposed schematics. Thanks, Jack ORIGINATED TRANSMITTAL DATE: 6/25/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5494 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 5494 1C-24 50029230630000 Cement Bond Log 7-Jun-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 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 201-248 T40609 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.25 08:10:54 -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 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:(201-248) CPAI_KRU_1C-24_received_051525_review.pdf Date:Monday, June 9, 2025 12:05:54 PM From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, June 6, 2025 11:21 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: Re: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Cy, Your plan to pull the cbl from the SC shoe is approved. The COA to verify of cement can be voided. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Friday, June 6, 2025 10:43 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Hi Jack, I wanted to follow up to confirm that you received my previous email. If all goes well, I expect we will be pulling our CBL over the weekend. Since we are requesting to deviate from the COA on the approved Sundry, I wanted to make sure we are on the same page. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Eller, Cy Sent: Wednesday, June 4, 2025 11:35 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Hi Jack, Thank you for your response. I received the approved sundry this morning. After looking at your COA and comment on step #6, it appears that I made a typo in my procedure. Our plan is to pull a CBL from the SC shoe, not the PC shoe as listed on the procedure. Please note that we are unable to reach the PC shoe because it is below a liner top packer with 4-1/2” liner. The objective of this CBL is to quickly identify any fill in the OA before cutting and attempting to pull casing. Due to the value of the information, and the nature of the intended use of the log in step #6, we plan to maintain the precedent that the calculated TOC is sufficient for packer placement. I apologize for the confusion, please let me know if you have any questions or concerns with this plan. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, June 4, 2025 9:18 AM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Morning Cy, 1C-24 is with the commissioners, the energy conference has slowed things down. I am hopeful you will have it by EOD, if not I will give you a verbal to start the work. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Wednesday, June 4, 2025 8:20 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Good morning Jack, Just following up on the 1C-24 Sundry. We are planning to move from 1R-05 to 1C-24 tonight. Do you have any updates you can share on this Sundry? Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, May 29, 2025 3:05 PM To: Eller, Cy <Cy.Eller@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Thanks Cy. You should have an approved sundry by EOW. Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Tuesday, May 27, 2025 3:13 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Hi Jack, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. I wanted to give you an update on 1C-24. Everything went well over the weekend, and with 3K- 35 being postponed, the Nabors 7ES line has shifted to the left a bit as well. The current estimated start date shown on the schedule for 1C-24 is 6/4/2025. Please let me know if there is anything you need from me. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, May 15, 2025 8:57 AM To: Eller, Cy <Cy.Eller@conocophillips.com> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Interesting. This one has it. Thanks Jack From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Thursday, May 15, 2025 8:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf Hi Jack, I believe the original submission had the current and proposed schematics included. Please let me know if you have any opening it and I can resend. Thanks, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, May 15, 2025 8:44 AM To: Eller, Cy <Cy.Eller@conocophillips.com> Subject: [EXTERNAL]CPAI_KRU_1C-24_received_051525_review.pdf CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cy, Please include current and proposed schematics. Thanks, Jack STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 1C-24 JBR 07/25/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test no Failures. 11 Accumulator bottles with 1118 psi Pre Charge avg. Test Results TEST DATA Rig Rep:Tony Morales/Jeffrey HOperator:ConocoPhillips Alaska, Inc.Operator Rep:Seth Burson / Ron Phillips Rig Owner/Rig No.:Nabors 7ES PTD#:2012480 DATE:6/6/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS250606163917 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 2392 Sundry No: 325-305 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 3-1/2" x 5-1/2 P #2 Rams 1 Blinds P #3 Rams 1 4-1/2" x 7" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8 P Kill Line Valves 2 3-1/8" & 2"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3100 Pressure After Closure P1500 200 PSI Attained P13 Full Pressure Attained P161 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5 @ 2100 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1     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): 9350'6548'2392 7699' Casing Collapse Conductor Surface Production Liner 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: 907-265-6049 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 6681', 7674', 8139'6161'6681' KRU 1C-24 7485-7520' 7550-7670' 7700-7885' 7945-8015' 8065-8090' 8500-8600' 8650-8750' 8800-8900' 8950-9150' 9180-9215' 6795' 4-1/2" 6424-6427' 6430-6440' 6442-6455' 6461-6468' 6472-6474' 6498-6492' 6488-6483' 6481-6479' 6480-6506' 6513-6520' 6/15/2024 9345'2701' 4-1/2" 6547' ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): 161' 4711' 6253'7" 16" 9-5/8" 119' Burst 4670' 6655' MD 161' 4413' 6835' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 201-248 P.O. Box 100360, Anchorage, AK 99510 50-029-23063-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6658'MD/6146'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? 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. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD m n s 2 6 5 6 t g c 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 9:02 am, May 15, 2025 325-305 X 10-404 SFD 5/27/2025 Send CBL results to AOGCC. Verify the proposed packer is set in good cement. AOGCC Witnessed BOP and Annular Test to 2500 psi. JJL 5/29/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.04 08:51:22 -08'00'06/04/25 RBDMS JSB 060525 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1C-24 (PTD# 201-248). Well 1C-24 was drilled and completed in January of 2002 by Nabors 245 as a Kuparuk C Sand injector. The well was brought online in February of 2002 with the intention of pre-producing this well for a short time before beginning injection. The well tests yielded better than expected results, and the well was later converted to a permanent producer – the well has never been used for water or gas injection. In July of 2018, Nabors CDR-3 drilled a single lateral to target additional C Sand reserves. In April of 2024, the well failed a TIFL and was shut-in and subsequent diagnostics identified a tubing leak at ~5,926’ RKB. While the well was shut-in, a SCLD revealed a SC leak at ~150’ MD. A tubing patch was installed in an attempt to bring the well back online without gas lift, but a passing MIT-T could not be achieved, so the well was moved forward as a workover candidate. To return the well to production, we are requesting approval to proceed with a rig workover. We plan to pull the 4-1/2” completion from a pre-rig cut above the liner top packer, then cut and pull the 7” production casing, run new 7” production casing, and cement the OA, then perform a casing cleanout run, and a tubing dress off run as needed based on tubing condition. A new 4-1/2” gas lifted completion with a non-sealing overshot and stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1C-24 Kuparuk Producer Subsidence Repair Procedure PTD: 201-248 Page 1 of 3 PPre-Rig Work Remaining 1. Pull DMY valve from GLM at 6,557’ RKB for circulation point. (Completed 5/4/2025) 2. Cut tubing at ~6,620’ RKB 3. CMIT-TxIA to 2,500 psi. 4. T-POT, T-PPPOT, IC-POT, IC-PPPOT. FT LDS. 5. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1C-24. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4-1/2” Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing and jewelry from pre-rig cut at ~6,620’ RKB. 7” Casing Subsidence Repair 6. RU E-Line and pull CBL from PC shoe to surface to verify free pipe. a. No Arctic Pack cement was pumped in the OA of this well. 7. Set plug in 7” casing above any fill identified by CBL. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE, ND tubing head and grow casing as needed using de-tensioning system, pull casing in tension and set slips, NU BOPE to casing head. a. BOPE flange break unable to be tested at this point. Flange break to be tested as soon as practical once test plug can be installed. 9. RIH and cut 7” casing. Shut in and circulate freeze protect out of OA as needed. 10. Spear 7” casing, split BOPE stack and remove casing slips. NU BOPE to casing head. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections as necessary. b. Test BOPE flange break once 7” casing is pulled. 12. RIH with mills to ensure drift for overshot casing patch, ECP, and cementer. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, 7” x 9-5/8” ECP, cementer, and new 7” casing. 14. Engage overshot, set packer and PT casing against RBP to 2,500 psi. 15. Cement 7” x 9-5/8” annulus to surface. 16. ND BOPE, set casing slips, cut excess 7” casing and install packoffs, NU tubing head and BOPE. Test breaks to 250/2,500 psi. 17. RIH and mill up cement and cementer plugs. Perform additional cleanout runs as necessary. 18. RIH and wash sand and debris from top of RBP. Retrieve RBP. *Send CBL results to AOGCC. Verify theproposed packer is set in good cement.-JJL 1C-24 Kuparuk Producer Subsidence Repair Procedure PTD: 201-248 Page 2 of 3 Casing Cleanout Run 19. MU BHA, TIH and perform casing cleanout and tubing dress off runs if necessary, based on tubing condition. Install new 4-1/2” Gas Lift Completion with Stacked Packer 20. MU new 4-1/2” completion with non-sealing overshot, nipple profile, 4-1/2” x 7” packer, DHG, and GLMs. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, drop ball and rod and set packer. 23. Pressure test tubing to 3,000 psi for 30 minutes. 24. Pressure test IA to 2,500 psi for 30 minutes. ND BOP, NU Tree 25. Confirm pressure tests, then shear out SOV. 26. Install BPV and test. ND BOPE. NU tree and PT packoffs. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work 1. Pull SOV and DVs. Install new GLD. 2. Pull ball and rod used for setting packer. 3. Pull pre-rig RBP and catcher from liner. General Well Information: Estimated Start Date: 6/15/2025 Current Operations: Shut in Well Type: Producer Wellhead Type: FMC Gen V. 11” 5M casing head top flange. 11” 5M tubing head top flange. Scope of Work: Pull the existing 4-1/2” completion from pre-rig cut, perform 7” subsidence repair to remediate SC leak, tubing cleanout/dress off run, install a new 4-1/2” gas lift completion with stacked packer. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams 1C-24 Kuparuk Producer Subsidence Repair Procedure PTD: 201-248 Page 3 of 3 FFollowing subject to change with Pre-Rig Work: MIT Results: CMIT-TxIA: Passed (2,500 psi, 1/28/2025) SCLD: SC leak identified at ~150’ MD (6/12/2024) Tubing POT & PPPOT: Passed (4/28/2024) IC POT & PPPOT: Passed (4/28/2024) Static BHP: 3,002 psi / 6,105’ TVD measured on 12/23/2024 MPSP: 2,392 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Production Engineer: Jennifer McLeod Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1C-24 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP 1C-24 1/28/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: DEFORMED LINER @ 7696'-7715', MIN ID 3.4"; CALIPER SURVEY AVAILABLE 8/19/2005 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 161.0 161.0 62.58 API5LGrB PEB SURFACE 9 5/8 8.83 41.1 4,710.9 4,413.3 40.00 L-80 BTC PRODUCTION 7 6.28 39.5 6,835.4 6,252.5 26.00 L-80 BTC-MOD LINER 4 1/2 3.96 6,644.0 9,345.0 6,547.4 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.4 Set Depth … 6,654.9 String Max No… 4 1/2 Set Depth … 6,143.5 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT MOD ID (in) 3.96 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) 36.4 36.4 0.11 HANGER 10.800 FMC GEN V HANGER 4.500 517.6 517.6 1.85 NIPPLE 5.030 DB NIPPLE w/ 3.812 NO GO PROFILE Camco 3.812 2,712.9 2,590.8 23.05 GAS LIFT 5.984 Camco KBG-2 3.938 4,146.5 3,904.3 24.81 GAS LIFT 5.984 Camco KBG-2 3.938 5,188.7 4,846.5 23.97 GAS LIFT 5.984 Camco KBG-2 3.938 5,950.1 5,551.5 18.91 GAS LIFT 5.984 Camco KBG-2 3.938 6,557.7 6,074.9 42.97 GAS LIFT 5.984 Camco KBG-2 3.938 6,602.6 6,107.2 44.97 NIPPLE 5.030 DB NIPPLE w/ 3.75 NO GO PROFILE Millled to 3.80" ID on 1/15/2017 Camco 3.800 6,641.8 6,134.5 46.82 LOCATOR 5.200 NO GO LOCATOR Baker 3.840 6,642.9 6,135.3 46.88 SEAL ASSY 4.750 GBH-22 SEAL ASSEMBLY Baker 3.840 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) 5,926.0 5,528.7 18.89 LEAK TBG LEAK AT 5926' RKB IDENTIFIED VIA LDL (0.5 BPM, 850 PSI) 8/25/2024 3.960 6,681.0 6,160.8 48.77 PLUG 4-1/2" P2P RBP MID- ELEMENT AT 6684' RKB, OAL 8.61' TTS P2P CPP4 5038 1/28/2025 0.000 7,615.0 6,436.0 85.66 WHIPSTOCK BOT 4.5" Monobore XL 7/3/2018 0.000 7,674.0 6,440.0 86.58 PLUG CIBP 12/30/2017 0.000 7,699.0 6,441.4 86.81 PINCH POINT COIL TUBING(CTU-11) TAGGED PINCH POINT IN LINER 12/30/2017 3.500 7,699.0 6,441.4 86.81 FISH CIBP 12/30/2017 3.500 8,139.2 6,478.1 85.26 PLUG BAKER INFLATABLE BRIDGE PLUG (OAL=11.58') 3/7/2007 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,712.9 2,590.8 23.05 1 GAS LIFT DV BK-5 1 8/2/2024 4,146.5 3,904.3 24.81 2 GAS LIFT GLV BK-5 1 1,275.0 6/10/2002 W/ STRI PPED FISH NECK (1/12/ 2018) 0.188 5,188.7 4,846.5 23.97 3 GAS LIFT DV BK-5 1 8/2/2024 5,950.1 5,551.5 18.91 4 GAS LIFT DMY BK-5 1 0.0 1/21/2002 0.000 6,557.7 6,074.9 42.97 5 GAS LIFT DMY BK-5 1 0.0 2/11/2002 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,644.0 6,136.0 46.93 TIEBACK 4.750 LINER TIE BACK EXTENSION 3.958 6,658.1 6,145.6 47.63 PACKER 5.960 4.5" X 7" ZXP LINER TOP PACKER W/HOLDDOWNS, HR PROFILE BAKER 4.300 9,250.9 6,527.7 77.74 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,485.0 7,520.0 6,423.6 6,427.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,550.0 7,670.0 6,430.4 6,439.7 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,700.0 7,885.0 6,441.5 6,455.1 C-3, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,945.0 8,015.0 6,461.0 6,467.6 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 1C-24, 4/28/2025 11:00:25 AM Vertical schematic (actual) LINER; 6,644.0-9,345.0 FLOAT SHOE; 9,343.0-9,345.0 FLOAT COLLAR; 9,282.3- 9,283.4 LANDING COLLAR; 9,250.9- 9,252.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 FISH; 7,699.0 PINCH POINT; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 DEPLOYMENT SLEEVE; 7,601.0-7,601.8 IPERF; 7,485.0-7,520.0 PRODUCTION; 39.5-6,835.4 FLOAT SHOE; 6,833.9-6,835.4 FLOAT COLLAR; 6,754.2- 6,755.5 PLUG; 6,681.0 HANGER; 6,666.1-6,672.8 PACKER; 6,658.1-6,666.1 TIEBACK; 6,644.0-6,658.1 SEAL ASSY; 6,642.9 LOCATOR; 6,641.8 NIPPLE; 6,602.6 GAS LIFT; 6,557.6 Annular Fluid - Inhibited Seawater; 5,188.0-6,835.0 GAS LIFT; 5,950.1 LEAK; 5,926.0 GAS LIFT; 5,188.7 SURFACE; 41.1-4,710.9 FLOAT SHOE; 4,709.2-4,710.9 FLOAT COLLAR; 4,629.3- 4,630.8 GAS LIFT; 4,146.5 GAS LIFT; 2,712.9 Annular Fluid - Gas; 0.0-5,188.0 PORT COLLAR; 1,023.9- 1,026.9 NIPPLE; 517.6 CONDUCTOR; 42.0-161.0 HANGER; 41.1-42.6 HANGER; 39.5-41.5 HANGER; 36.4 KUP PROD KB-Grd (ft) 46.42 RR Date 1/26/2002 Other Elev… 1C-24 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292306300 Wellbore Status PROD Max Angle & MD Incl (°) 95.23 MD (ftKB) 8,604.82 WELLNAME WELLBORE1C-24 Annotation Last WO: End DateH2S (ppm) 100 Date 8/11/2023 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,065.0 8,090.0 6,471.9 6,474.0 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,500.0 8,600.0 6,497.8 6,492.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,650.0 8,750.0 6,488.3 6,483.1 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,800.0 8,900.0 6,480.7 6,478.5 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,950.0 9,150.0 6,480.0 6,506.3 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 9,180.0 9,215.0 6,512.6 6,520.1 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 1C-24, 4/28/2025 11:00:26 AM Vertical schematic (actual) LINER; 6,644.0-9,345.0 FLOAT SHOE; 9,343.0-9,345.0 FLOAT COLLAR; 9,282.3- 9,283.4 LANDING COLLAR; 9,250.9- 9,252.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 FISH; 7,699.0 PINCH POINT; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 DEPLOYMENT SLEEVE; 7,601.0-7,601.8 IPERF; 7,485.0-7,520.0 PRODUCTION; 39.5-6,835.4 FLOAT SHOE; 6,833.9-6,835.4 FLOAT COLLAR; 6,754.2- 6,755.5 PLUG; 6,681.0 HANGER; 6,666.1-6,672.8 PACKER; 6,658.1-6,666.1 TIEBACK; 6,644.0-6,658.1 SEAL ASSY; 6,642.9 LOCATOR; 6,641.8 NIPPLE; 6,602.6 GAS LIFT; 6,557.6 Annular Fluid - Inhibited Seawater; 5,188.0-6,835.0 GAS LIFT; 5,950.1 LEAK; 5,926.0 GAS LIFT; 5,188.7 SURFACE; 41.1-4,710.9 FLOAT SHOE; 4,709.2-4,710.9 FLOAT COLLAR; 4,629.3- 4,630.8 GAS LIFT; 4,146.5 GAS LIFT; 2,712.9 Annular Fluid - Gas; 0.0-5,188.0 PORT COLLAR; 1,023.9- 1,026.9 NIPPLE; 517.6 CONDUCTOR; 42.0-161.0 HANGER; 41.1-42.6 HANGER; 39.5-41.5 HANGER; 36.4 KUP PROD 1C-24 ... WELLNAME WELLBORE1C-24 COMPLETION INFO OD (in) Nom. ID (in) MD (ft RKB) TVD (ft RKB) Weight (lb/ft)Grade Thread Conductor 16 15.062 161 161 62.58 API5LGrB PEB Surface Casing 9.625 8.835 4711 4413 40.0 L-80 BTC Intermediate Casing Tie-Back 7 6.28 ~4850 ~4539 26.0 L-80 HYD563 Intermediate Casing 7 6.28 6835 6252 26 L-80 BTCM Production Liner 4.5 3.958 9345 6547.4 12.6 L-80 NSCT CTD Lateral 2.875 2.375 11401 6975 6.5 L-80 STL Production Tubing 4.5 3.958 ~6618 ~6118 12.6 L-80 HYD563 1C-24 Proposed RWO Schematic Proposed Completion: 4-1/2" 12.6# L-80 HYD563 Tubing to surface 4-1/2" x 1" GLM's @ 2282', 3868', 4618', and as deep as possible 4-1/2" Downhole Gauge & TEC wire to surface 4-1/2" x 7" Packer @ ~6,475' RKB 4-1/2" x 3.813" X-nipple profile 4-1/2" Non-Sealing Overshot @ ~6,618' RKB Proposed Production Casing Tie-Back: 7" 26# L-80 HYD563 Casing from cut to surfcae 7" Cementer 7" x 9-5/8" ECP 7" Sealing Overshot Casing Patch Existing Completion Left in Hole: GBH-22 Seal Assembly and Locator @ 6,643' RKB Liner tie-back extension @ 6,644' RKB 4-1/2" x 7" Baker ZXP LTP @ 6,658' RKB 4-1/2" Baker CTD Whipstock @ 7,615' RKB 9-5/8" Surface Casing @ 4,711' 4-1/2" Production Liner @ 9,345' 16" Conductor @ 161' 1C-24L1 CTD Lateral @ 11,401' 7" Production Casing @ 6,836' SC Leak @ 150' LTP @ 6,658' Intermediate Casing Calculated TOC: 5,900' RKB SC Cement TOC: Surface Liner Estimated TOC: 6,674' RKB from 1/20/2002 CBL ORIGINATED TRANSMITTAL DATE: 5/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5462 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 5462 1C-24 50029230630000 Tubing Cut Record 24-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street 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 201-248 T40511 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:16:42 -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 ORIGINATED TRANSMITTAL DATE: 2/19/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5273 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 5273 1C-24 50029230630000 Plug Setting Record 28-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street 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 201-248 T40103 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.19 15:22:19 -09'00' 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 Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'1CͲ2450Ͳ029Ͳ23063Ͳ00 n/aKuparukRiverLeakDetectLogFieldͲFinal25ͲAugͲ240141CͲ2450Ͳ029Ͳ23063Ͳ00 n/aKuparukRiverMultiFingerCaliperField&Processed25ͲAugͲ240151CͲ2450Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002KuparukRiverPackerSettingRecordFieldͲFinal15ͲSepͲ2401T39680T39680T39680203 115201-248200 173 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch 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 9350'feet 7674', 8139'feet true vertical 6548' feet 7699' feet Effective Depth measured 7674'feet 5914', 5942', 6658'feet true vertical 6440' feet 5517', 5544', 6146'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 6655' MD 6143' TVD Packers and SSSV (type, measured and true vertical depth) 5914' MD 5942' MD 6658' MD N/A 5517' TVD 5544' TVD 6146' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 4711' 4413' Burst Collapse Production Liner 6796' 2701' Casing 6252' 4-1/2" 6835' 9345' 6547' 4670' 161'Conductor Surface Intermediate 16" 9-5/8" 119' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-248 50-029-23063-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025649 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1C-24 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 161' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Pcker: P2P Patch Packer Packer: P2P Patch Packer Packer: ZXP Liner Top Packer SSSV: None Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 7485-7520', 7550-7670', 7700-7885', 7945-8015', 8065-8090', 8500-8600', 8650-8750', 8800- 8900', 8950-9150', 9180-9215' 6424-6427', 6430-6440', 6441-6455', 6461-6468', 6472-6474', 6498-6492', 6488-6483', 6481-6478', 6480-6506', 6513-6520' By Grace Christianson at 12:59 pm, Oct 08, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.10.08 11:55:41-08'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 9/14/2024 REPAIR WELL PULLED 4 1/2 CATCHER @ 6681' RKB, EQUALIZED & PULLED 3.76" RBP @ 6685' RKB, BRUSH & FLUSHED PATCH AREA FROM 6000' TO 5800' RKB, CLEAN DRIFT W/ 3.76" x 28' DUMMY PATCH TO 6100' RKB, ATTEMPT TO SET 3.76" LOWER P2P @ 5945' RKB. IN PROGRESS. 9/15/2024 REPAIR WELL SET LOWER 3.76" PACKER @ 5945' RKB (OAL 4.89' / CPP45044), SET 4 1/2 TTS TEST TOOL @ 5945' RKB, CMIT TBG x IA (2500 PSI PASS), PULLED 4 1/2 TTS TEST TOOL @ 5945' RKB, SET UPPER 3.76" P2P SPACER & ANCHOR LATCH (OAL 29.14' / SN: CPP45011 / CPAL45020) @ 5917' RKB (ME) TOP @ 5913.97' RKB, SET 4 1/2 TTS TEST TOOL @ 5913.97' RKB, MIT TBG 2500 PSI (PASS), CMIT TBG x IA 2500 (FAILED), BLEED IA TO 225 PSI. IN PROGRESS 9/16/2024 REPAIR WELL RAN 4 1/2 SMART HOLE FINDER BRACKET LEAK FROM 4141' RKB TO 4113' RKB (PASSING MITT TO 2500 @ 4113' RKB), PULLED 4 1/2 TTS TEST TOOL @ 5914' RKB, RAN 4 1/2 TTS TEST TOOL TO UPPER 3.76" P2P @ 5914' RKB CMIT TBG x IA TO 2500 PSI (PASS), BLED IA TO 225 PSI FOR BUILD UP. IN PROGRESS. *NOTE* JOB WAS SUSPENDED THE MORNING OF 9/17/24 DUE TO HIGHER PRIORITY WORK 9/19/2024 REPAIR WELL (AC EVAL) BLEED IA FOR BUR. 1C-24 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1C-24 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Tbg Patch 1C-24 9/15/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: DEFORMED LINER @ 7696'-7715', MIN ID 3.4"; CALIPER SURVEY AVAILABLE 8/19/2005 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 161.0 161.0 62.58 API5LGrB PEB SURFACE 9 5/8 8.83 41.1 4,710.9 4,413.3 40.00 L-80 BTC PRODUCTION 7 6.28 39.5 6,835.4 6,252.5 26.00 L-80 BTC-MOD LINER 4 1/2 3.96 6,644.0 9,345.0 6,547.4 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.4 Set Depth 6,654.9 Set Depth 6,143.5 String Max No 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT MOD ID (in) 3.96 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) 36.4 36.4 0.11 HANGER 10.800 FMC GEN V HANGER 4.500 517.6 517.6 1.85 NIPPLE 5.030 DB NIPPLE w/ 3.812 NO GO PROFILE Camco 3.812 2,712.9 2,590.8 23.05 GAS LIFT 5.984 Camco KBG-2 3.938 4,146.5 3,904.3 24.81 GAS LIFT 5.984 Camco KBG-2 3.938 5,188.7 4,846.5 23.97 GAS LIFT 5.984 Camco KBG-2 3.938 5,950.1 5,551.5 18.91 GAS LIFT 5.984 Camco KBG-2 3.938 6,557.7 6,074.9 42.97 GAS LIFT 5.984 Camco KBG-2 3.938 6,602.6 6,107.2 44.97 NIPPLE 5.030 DB NIPPLE w/ 3.75 NO GO PROFILE Millled to 3.80" ID on 1/15/2017 Camco 3.800 6,641.8 6,134.5 46.82 LOCATOR 5.200 NO GO LOCATOR Baker 3.840 6,642.9 6,135.3 46.88 SEAL ASSY 4.750 GBH-22 SEAL ASSEMBLY Baker 3.840 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) 5,914.0 5,517.4 18.89 PACKER - PATCH - UPR 4-1/2" UPR P2P PKR MID- ELEMENT AT 5917' RKB W/ SPACER PIPE AND ANCHOR LATCH, OAL 28' TTS P2P CPP4 5011/ CPAL 45020 9/15/2024 2.000 5,918.7 5,521.8 18.89 SPACER PIPE 2-3/8" SPACER PIPE W/ ANCHOR LATCH 9/15/2024 1.995 5,926.0 5,528.7 18.89 LEAK TBG LEAK AT 5926' RKB IDENTIFIED VIA LDL (0.5 BPM, 850 PSI) 8/25/2024 3.960 5,942.0 5,543.9 18.91 PACKER - PATCH - LWR 4-1/2" LWR P2P PKR MID- ELEMENT AT 5945' RKB, OAL 4.89' TTS P2P CPP4 5044 9/15/2024 2.000 7,615.0 6,436.0 85.66 WHIPSTOCK BOT 4.5" Monobore XL 7/3/2018 0.000 7,674.0 6,440.0 86.58 PLUG CIBP 12/30/2017 0.000 7,699.0 6,441.4 86.81 PINCH POINT COIL TUBING(CTU-11) TAGGED PINCH POINT IN LINER 12/30/2017 3.500 7,699.0 6,441.4 86.81 FISH CIBP 12/30/2017 3.500 8,139.2 6,478.1 85.26 PLUG BAKER INFLATABLE BRIDGE PLUG (OAL=11.58') 3/7/2007 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,712.9 2,590.8 23.05 1 GAS LIFT DV BK-5 1 8/2/2024 4,146.5 3,904.3 24.81 2 GAS LIFT GLV BK-5 1 1,275.0 6/10/2002 W/ STRI PPED FISH NECK (1/12/ 2018) 0.188 5,188.7 4,846.5 23.97 3 GAS LIFT DV BK-5 1 8/2/2024 5,950.1 5,551.5 18.91 4 GAS LIFT DMY BK-5 1 0.0 1/21/2002 0.000 6,557.7 6,074.9 42.97 5 GAS LIFT DMY BK-5 1 0.0 2/11/2002 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,644.0 6,136.0 46.93 TIEBACK 4.750 LINER TIE BACK EXTENSION 3.958 6,658.1 6,145.6 47.63 PACKER 5.960 4.5" X 7" ZXP LINER TOP PACKER W/HOLDDOWNS, HR PROFILE BAKER 4.300 9,250.9 6,527.7 77.74 LANDING COLLAR 4.500 3.958 1C-24, 10/7/2024 5:56:31 PM Vertical schematic (actual) LINER; 6,644.0-9,345.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 FISH; 7,699.0 PINCH POINT; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 IPERF; 7,485.0-7,520.0 PRODUCTION; 39.5-6,835.4 GAS LIFT; 6,557.6 GAS LIFT; 5,950.1 PACKER - PATCH - LWR; 5,942.0 SPACER PIPE; 5,918.7 LEAK; 5,926.0 PACKER - PATCH - UPR; 5,914.0 GAS LIFT; 5,188.7 SURFACE; 41.1-4,710.9 GAS LIFT; 4,146.5 GAS LIFT; 2,712.9 NIPPLE; 517.6 CONDUCTOR; 42.0-161.0 KUP PROD KB-Grd (ft) 46.42 RR Date 1/26/2002 Other Elev 1C-24 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292306300 Wellbore Status PROD Max Angle & MD Incl (°) 95.23 MD (ftKB) 8,604.82 WELLNAME WELLBORE1C-24 Annotation Last WO: End DateH2S (ppm) 100 Date 8/11/2023 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,485.0 7,520.0 6,423.6 6,427.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,550.0 7,670.0 6,430.4 6,439.7 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,700.0 7,885.0 6,441.5 6,455.1 C-3, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,945.0 8,015.0 6,461.0 6,467.6 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,065.0 8,090.0 6,471.9 6,474.0 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,500.0 8,600.0 6,497.8 6,492.4 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,650.0 8,750.0 6,488.3 6,483.1 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,800.0 8,900.0 6,480.7 6,478.5 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8,950.0 9,150.0 6,480.0 6,506.3 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 9,180.0 9,215.0 6,512.6 6,520.1 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 1C-24, 10/7/2024 5:56:32 PM Vertical schematic (actual) LINER; 6,644.0-9,345.0 IPERF; 9,180.0-9,215.0 IPERF; 8,950.0-9,150.0 IPERF; 8,800.0-8,900.0 IPERF; 8,650.0-8,750.0 IPERF; 8,500.0-8,600.0 PLUG; 8,139.2 IPERF; 8,065.0-8,090.0 IPERF; 7,945.0-8,015.0 IPERF; 7,700.0-7,885.0 FISH; 7,699.0 PINCH POINT; 7,699.0 PLUG; 7,674.0 WHIPSTOCK; 7,615.0 L1 LATERAL; 7,601.0-11,401.0 IPERF; 7,550.0-7,670.0 IPERF; 7,485.0-7,520.0 PRODUCTION; 39.5-6,835.4 GAS LIFT; 6,557.6 GAS LIFT; 5,950.1 PACKER - PATCH - LWR; 5,942.0 SPACER PIPE; 5,918.7 LEAK; 5,926.0 PACKER - PATCH - UPR; 5,914.0 GAS LIFT; 5,188.7 SURFACE; 41.1-4,710.9 GAS LIFT; 4,146.5 GAS LIFT; 2,712.9 NIPPLE; 517.6 CONDUCTOR; 42.0-161.0 KUP PROD 1C-24 ... WELLNAME WELLBORE1C-24 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1C-24L1 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install new GLD 1C-24L1 5/18/2019 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 LATERAL 2 7/8 2.38 7,601.0 11,401.0 6.50 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,601.0 6,434.9 85.41 DEPLOYMENT SLEEVE 2.875 Shorty Deployment Sleeve Baker 2.370 9,919.3 6,463.1 90.21 DEPLOYMENT SLEEVE 2.875 Shorty Deployment Sleeve Baker 2.000 1C-24L1, 10/7/2024 5:56:32 PM Vertical schematic (actual) L1 LATERAL; 7,601.0-11,401.0 LINER; 6,644.0-9,345.0 IPERF; 7,550.0-7,670.0 IPERF; 7,485.0-7,520.0 PRODUCTION; 39.5-6,835.4 GAS LIFT; 6,557.6 GAS LIFT; 5,950.1 PACKER - PATCH - LWR; 5,942.0 SPACER PIPE; 5,918.7 LEAK; 5,926.0 PACKER - PATCH - UPR; 5,914.0 GAS LIFT; 5,188.7 SURFACE; 41.1-4,710.9 GAS LIFT; 4,146.5 GAS LIFT; 2,712.9 NIPPLE; 517.6 CONDUCTOR; 42.0-161.0 KUP PROD KB-Grd (ft) 46.42 RR Date 1/26/2002 Other Elev 1C-24L1 ... TD Act Btm (ftKB) 11,401.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292306360 Wellbore Status PROD Max Angle & MD Incl (°) 100.32 MD (ftKB) 10,300.07 WELLNAME WELLBORE1C-24 Annotation LAST WO: End DateH2S (ppm) 100 Date 8/11/2023 Comment Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 T39148 201-248 WELL LOG TRANSMITTAL DATA_L,QGGED t ',M/201� p• m.K.BENDER PROACTIVE DIAgNosiic SERVICES, INC. RECEIVED JAN 1 2 2018 To: AOGCC Makana Bender AOGCC 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) 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: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 29-Dec-17 1C-24 1 Report/CD 50-029-23063-00 -2.41=46t ICO 2) Coil Flag 29-Dec-17 1C-24 Color Log/CD 50-029-23063-00 7":4°t3� Signed : Q �' I..��k� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\P.chives\MasterTemplateFiles\Templates\Distribution\Transmittal Sheets\ConocoPhillips_Transmit,docx 411 -2s3P2-Akc FOCEIVED 2- , JAN 12 2018 Memory Multi-Finger Caliper ' .RI 110 AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-24 Log Date: December 29,2017 Field: Kuparuk Log No.: 14293 State: Alaska Run No.: 2 API No. 50-029-23063-00 Pipe Description: 4.5 inch 12.6 lb. L-80 IBT MOD/NSCT Top Log Interval: 6,038 Ft. (MD) Pipe Use: Tubing and Liner Bottom Log Interval: 7,693 Ft. (MD) Inspection Type : Whipstock Placement Inspection COMMENTS : This caliper data is correlated to the Schlumberger CBL log dated January 20, 2002. This log was run to assess the condition of the 4.5 inch liner between 7,670 feet and 7,690 feet where a whipstock is planned to be set. The caliper recordings indicate the 4.5 inch liner appears to be in good condition in this interval, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. Although no significant I.D. restrictions are recorded throughout the liner logged, an area of slight ovality is recorded in the perforation interval at—7,650 feet, restricting the I.D. to 3.88 inches. The remainder of the 4.5 inch tubing and liner logged appears to be in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded outside of the perforation interval. This is the second time a PDS caliper has been run in this well and the 4.5 inch tubing and liner have been logged. Due to the short interval of liner recorded in the previous caliper log(August 19, 2005), no comparison graph is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : Outside of the perforation interval, no significant wall penetrations(> 18%)are recorded throughout the tubing and liner logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss(> 14%)are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing and liner logged. C. Goerdt C. Waldrop J. McAnelly t iel y t riaineer(s) ?,rtalyst(si r' t ,2 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 0 • 417 .. PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-24 Date : December 29, 2017 Description : Detail of Caliper Recordings From 7,600 Feet to 7,693 Feet. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map I1 1ft:80ft O % 1003.5 inches 4.5 0° 0° 90° 180° 270° 0° Maximum I.D. I I 3.5 inches 4.5 Minimum I.D. I 1 3.5 inches 4.5 Iii IIIF1IIHJoint 241 rillrill Perforations 1111■■ ■■■■ ■■■■`ti■■■■■ 7605 11 ■■■/la■■■■■ I 11111 7610 _. ■ ■■ ■ E ■■ i ■■ + ■■■■tU,i■■■■ • ■■■■rP■1111■■ 111111111111111111111111•1111 , ■1111■i1,■■■■■ • T615 '� 1111111111111111111111111111111111111 ■■■■/13111lM■■■ , 21 111111111?■■11■11 ■■■■r1■■■■■ .f ;ai ■■■■Eui■1111■ -erforations ' 7620 : ■■■■f i■■■■ ■■■■■EI�a■■■■ Joint 242 :� 111111111111M111111111•11111 Perforations Al 1111111111 7625 ■■■■1 'i■■■■ 1 1111111111 li 7630 : HHI ' 1 . 1111 . ■■11■V�■■■11■ . •■■� [ ;■■■11■ 1111■■■ 7635 4III Perforations -4 ■1111 a■■■■■ 7640 1 ■■■■LI■■■■■ 111111111111111111.1111111111111111111 is ■■■■CI■■■■■ ■■■■II111■■■■ ilm 1■■■L1'J■■■11 . ,, • 0 7645 7650 _.._ IS . . Joint 243 Perforations Slight Ovality 7655 (7,650) iA 7660 • I ir 7665 • . k. 7670 •-,-,. U U :I •7 7675 U 1 ..., . Joint 244 7680 Perforations 7685 ! .-.., •-, 0 44 , i fo 7690 Minimum I.D. 3.5 inches 4.5 Maximum I.D. 3.5 inches 4.5 Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map I . 1ft:80ft 0 % 100 3.5 inches 4.5 0° 0° 90° 180° 270° 0° • • eft PDS Report Overview Body Region Analysis Well: 1 C-24 Survey Date: December 29,2017 Field: Kuparuk Tool Type: UW MFC 40 No.213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT MOD/NSCT 3.958 in. 6,038 ft. 6,665 ft. 4.5 in. 12.6 ppf L-80 IBT MOD/NSCT 3.958 in. 6,665 ft. 7,693 ft. Penetration(%wall) Damage Profile(%wall) 50 MIN Penetration body meg Metal loss body 0 50 100 193 row 40 • • irma 30 rm. MIMI 20 um 10 -am • 0 0 to 20 to 40 to over GLM 5 (12:00) 20% 40% 85% 85% • Number of joints analyzed(total=55) 48 0 0 0 ■ r Damage Configuration(body) No 10 - 8 tin W▪ NW6 • 4 235 ■ ■ • 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=7) 2 0 5 0 0 Bottom of Survey=244 = Perforations • • rit PDS Report joint Tabulation Sheet Well: 1C-24 Survey Date: December29,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80IBT MOD/NSCT Tubing 3.958 in. 0.271 in. 6,038 ft. 6,665 ft. 4.5 in. 12.6 ppf L-8 0 IBT MOD/NSCT Liner 3.958 in. 0.271 in. 6,665 ft. 7,693 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 193 603 8 0 0.03 11 2 3.95 194 6061 0 0.04 14 3 3.94 195 6091 0 0.03 12 2 3.94 196 6123 0 0.03 11 2 3.88 Lt. Deposits. 197 6154 0 0.03 11 2 3.93 198 6186 0 0.04 13 3 3.94 199 6216 0 0,03 10 2 3.92 200 6247 0 0.03 10 2 3.94 _ �• 201 6277 0 0.03 12 2 3.93 -� 202 6308 0 0.02 8 1 3.94 • 203 6339 0 0,03 11 2 3.93 • 204 6369 0 0.03 12 2 3.93 205 6401 0 0.03 12 2 3.93 206 6432 0 0.03 12 3 3.94 207 6462 0 0.04 15 3 3.93 Shallow Line of Pits. 208 6492 0 0.04 15 2 3.93 Shallow Line of Pits. 209 6523 0 0.04 13 2 3.94 209.1 6553 0 0.04 15 1 3.93 Pup Shallow Pitting. 209.2 6559 0 0 0 0 3.89 GLM 5(LATCH @ 12:00) 209.3 6567 0 0.04 13 2 3,94 Pup 1111 210 6573 0 0.05 18 3 3.92 Shallow Pitting. 210.1 6604 0 0 0 0 3.74 CAMCO DB NIPPLE NO GO 211 6606 0 0.03 12 2 3.93 L• 211.1 6638 0 0.04 13 1 3.93 Pup 211.2 6644 0 0 0 0 3.83 BAKER GBH-22 SEAL ASSEMBLY 211.3 6656 0 0 0 0 3.84_ BAKER 4.5"X 7"ZXP LI NFR TOP PACKER 211.4 6665 0 0 0 0 3.90 4.5"BAKER HMC LINER HANGER 212 6673 0 0.04 15 1 3.90 Shallow Line of Pits. 213 6704 0 0.01 4 1 3.91 214 673 5 0 0.01 4 1 3.92 215 6766 0 0.02 7 2 3.89 Lt. Deposits. • 216 6797 0 0,01 5 1 3.89 Lt. Deposits. 217 682 9 0 0.02 6 2 3.93 1 218 6862 0 0.02 6 1 3.92 1 219 6893 0 0,02 6 2 3.91 220 6924 0 0.01 5 1 3.91 221 6955 0 0.03 11 1 3,92 •I 222 6986 0 0.02 6 1 3.92 223 7015 0 0.03 12 1 3.91 Tong Mash. 5 224 7046 0 0.02 8 1 3.90 Tong Mash. • 225 7077 0 0.03 . 11 1 3.92 • 226 7109 0 0.02 7 1 3.87 Lt. Deposits. • 227 7139 0 0.04 13 2 3.90 Tong Mash. 228 7167 0 0.04 15 2 3.86 Shallow Line of Pits.Lt. Deposits, 229 7199 0 0.03 9 3 3.87 Lt. Deposits. • 230 7231 0 0.03 10 2 3.89 Lt. Deposits. ■ 231 7263 0 0.02 7 1 3.91 • 232 7294 0 0.03 10 1 3.90 • 233 7326 0 0.03 12 2 3.89 Lt. Deposits. • 234 7358 0 0.04 13 2 3.91I 5 Penetration Body Metal Loss Body Page 1 • • PIII fill 0 PDS Report joint Tabulation Sheet Well: 1C-24 Survey Date: December 29,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT MOD/NSCT Tubing 3.958 in. 0.271 in. 6,038 ft. 6,665 ft. 4.5 in. 12.6 ppf L-80 IBT MOD/NSCT Liner 3.958 in. 0.271 in. 6,665 ft. 7,693 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 235 7388 0 0.02 7 2 3.91 ik... i.•0. 236 7421 0 0.04 15 1 3.84 Tong Mash. 237 7451 0 0.03 13 1 3.90 Lt. Deposits. 238 7483 0 0.16 58 3 3.89 Perforations Lt.Deposits. 239 7514 0 0.14 . 52 4 3.91 Perforations 240 7546 0.06 0.39 100 14 3.88 Perforations Lt.Deposits. 241 7575 0.09 0.20 73 6 3.86 Perforations Lt.Deposits. 242 7607 0 0.15 55 4 3.91 Perforations 243 7638 0 0.18 68 5 3.88 Perforations Lt.Deposits. 244 7670 0 0.04 13 1 3.90 PERFORATIONS Lt. Deposits. I Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 2 KUP PROD 1G24 ConocoPhillips ° Well Attributes Max Angle&MD TD A41.,-,1 c_ I Wellbore APVUWI Field Name Wellbore Status not 7) MD(ftKB) Act Btm(MKS) cvro,raPhrllt(c 500292306300 KUPARUK RIVER UNIT PROD 1.15 349.02 9,350.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1x24,8/30/2016132.14 PM SSSV:NIPPLE 30 7/30/2015 Last WO: 46.42 1/26/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'. Rev Reason:H2S,SET CSV,GLV C/O,PULL pproven 8/30/2016 CSV HANGER;36.4 -" ""- Casing Strings 111 ■rq Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...GradeGTop Thread I CONDUCTOR 16 15.062 42.0 161.0 161,0 62.58 APISLGr PEB I Casing Description OD(in) ID(in) Top MEI) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 41.1 4,710.9 40.00 L-80 BTC AIIIMU.1111=0.^111111 111111ULIMULUMU 41 :.,u r.,, uuu.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(968) Set Depth(TVD)... Wt/Len(I...Grade Top Thread -- ; . ' PRODUCTION 7 6.276 39.5 6,835.4 26.00 L-80 BTC-MOD CONDUCTOR;42.0-161.0 • L. Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread y7 LINER 41/2 3.958 6,644.0 9,345.0 12.60 L-80 NSCT NIPPLE;5176 ° Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 6,644.0 TIEBACK LINER TIE BACK EXTENSION 3.958 6,658.1 PACKER BAKER 4.5"X 7"ZXP LINER TOP PACKER 4.300 C W/HOLDDOWNS,HR PROFILE GAS LIFT,27126 6,666.1 HANGER 4.5"BAKER HMC LINER HANGER 4.420 Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(B...Set Depth(ND)I...Wt(IbIS) Grade Top Connection TUBING 4 1/2 3.958 36 4 6,654.9 12.60 L-80 IBI MOD GAS LIFT;4,146.5 8 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Gom (in) 36.4 36.4 0.11 HANGER FMC GEN V HANGER 4.500 517.6 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 E11 6,602.6 NIPPLE CAMCO DB NIPPLE w/3,75 NO GO PROFILE 3.750 SURFACE:41.1-4.710.9-f ` 6,641.8 LOCATOR BAKER NO GO LOCATOR 3.840 6,642.9 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.840 GAS UFT,s.,ea.7 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl ----- Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) 8,139.2 PLUG BAKER INFLATABLE BRIDGE PLUG(OAL=11.58') 3/712007 0.000 GAS LIFT;5,950.1-1 FerforationS&Slots Shot Dens --- Top(ND) Btm(TVD) (shots/f __ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,485.0 7,520.0 C-4,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg GAS LIFT',6,557.6 f ph 7,550.0 7,670.0 C-4,1C-24 1/24/2002 4.0 (PERF 2.5".0.32"Shot,120 deg ph NIPPLE;6,602.6 7,700.0 7,885.0 C-3,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg ph 7,945.0 8,015.0 C-2,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg ph LOCATOR;6,641 s 8,065.0 8,090.0 C-2,1C-24 1/24/2002 4.0 (PERF 2.5".0.32"Shot,120 deg ph SEAL ASSY;6,6429 - 8,500.0 8,600.0 C4,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg \�wi• ph LLLL,,,�____,,,, ® 8,650.0 8,750.0 C-4,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg ph 8,800.0 8,900.0 C-4,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg ph 8,950.0 9,150.0 C-4,1C-24 1/24/2002 4.0 IPERF 2.5".0.32"Shot,120 deg ph 9,180.0 9,215,0 C-2,1C-24 1/24/2002 4.0 IPERF 2,5".0.32"Shot,120 deg PRODUCTION,39.5.6,635.4--- ph IPERF;7,4e5.0-7,5205 Mandrel Inserts St all IPERF;7,5500.7,670.0 N Top(ND) Valve Latch Port Size TRO Run lop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (Int (psi) Run Date Com 1 2,712.9 Camco KBG-2 1 GAS LIFT GLV BK-5 0.156 1,240,0 6/11/2002 IPERF;7,700.0-7.8890 2 4,146.5 Camco KBG-2 1 GAS LIFT GLV BK-5 0.188' 1,275.0 6/10/2002 3 5,188.7 Camco KBG-2 1 GAS LIFT 'OV BK 0.250 0.0 8/28/2016 PERE;7.945.0-8,016.0 4 5,950.1 Camco -KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 1/21/2002 5 6,557.7 Camco KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 2/11/2002 IPERF;8,065.0-8,090.0 Notes:General&Safety End Date Annotation PLUG;8,139,2 8/19/2005 NOTE:DEFORMED LINER Op 7696-7715',MIN ID 3.4",CALIPER SURVEY AVAILABLE 8/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;8,500.0.8,600.0 IPERF;8,650.0-9750.0 I IPERF;8,8000-8,900.0 IPERF;8,950.0-9,150.0 IPERF;9,180.0-9,215.0 LINER;6,644.0-9,3450 . . Conoc;r;.,illips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED SEP 0 6 2007 Anchorage, AK. 99501 ~ù¡06 ~o\.. Dear Mr. Maunder: ' Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of thes'ë wells was tôund to have a void in the conductor. These voids were filled with a corròsion inhibitor, engineered to prevent water trom 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 fonn 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. :¡~~~. M.J.¿el~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement cumced cement date inhibitor sealant date - ft bbls ft !:Ial 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 '1C-11 199-172 'SF NA NA NA :0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ MaIker.doc ;), l r;~ ^- ~\' i DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 lJrm- ~~ Sf1-Ct¿ Permit to Drill 2012480 Well Name/No. KUPARUK RIV UNIT 1C-24 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23063-00-00 MD 9350'---. ND 6548 r Completion Date 1/26/2002 ,..-' Completion Status WAGIN Current Status WAGIN UIC Y i DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name .----.-----. ...-....-.. 9 Pressure ---- 10852 LIS Verification (data taken from Logs Portion of Master Well Data Maint) {i Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments .-----.--.----------- . ...---...-----.-- -_........__..--~. 25 Blu 1 7250 9230 Case 6/21/2002 D 1 1 1 C ~89 Blu Blu 25 25 25 1 ~~. .... . .. .. , .. $Þ!PQ~L. ,... ....'. ......"" ....'. . . . térTIperatur~ ' Blu 1 . ",,-..---.... -...."..--.-"...,-..,,---- -_--____0"'_"""""_____0_.____--------..--...--------,,---._0"'_0__'0 _.._.o_o_--_.._.~-,,--_.._..o..,,--- """'-----"'__"'0_--_"'_.- --.--.....""..----..-.--....,,- "---"--"-------"""'-""'-- . 0 "..-., '-.""..._.._0___.. -.... Well CoreslSamples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ----Y I Ñ --- Daily History Received? Formation Tops Analysis Received? YtN 134 9297 Open 5/24/2002 134 9297 Open 5/24/2002 134 9350 Case 1/21/2003 Digital Well Logging data 7250 9230 Case 6/21/2002 7250 9230 Case 6/21/2002 7250 9230 Case 6/21/2002 Sample Set Number Comments ( &N ß;/N -"-_._---'--_"_"'0__0"""_'0_,,_0..- '-"'---'-"- -------"_""'_-0--__- "" _.----_...-_.- -'-""-""-----'-------.---'-.-"'-------'-------'-----'--"--.--- -...-.-.-,..,...---------.--.".,..---------.---".--.------.-,---- ""---'-----"-"--"'.__"0____--.._,--- --.."."..--".... -_.... Comments: /IJ~ ~ Ið D I/V\.. S \ .--'-___.__0__'_0______..---.----------------------------...---------------.,,---------.----...---.-- C ~ ~ ~ J ~ r') é\. ~ J W>--ÀCJ~ î.- ~ $"' ( q - c¿ l\ g 'i ~ 0 ko \II ~ C~t~ \.. \II J ) ì) ,,~ JM.- ~ c.~ ':,It - "I M~ ~ ß ~ .~~ m ~~ :~::.- ~: :;:W: d B ~~~~=--=-=~~~~-=~-== ..----------- ==-------"'___.0_____'-------" "_'__0 --- '--'-- -.------..."'.-.---,-..,-----...-.-..------...---- --'.--'----"."-'- ------ - '-7-"--" -rv--- -- ...--. -...- -. __0'_.___-- -'- ,- Date: ~ I--~ ~-'1 ~I I, i .~ éXò/-a l./~ Iftf~CJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 January 16, 2003 RE: MWD Formation Evaluation Logs 1 C-24, AK-J\1l\1-11218 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., J\nchorage, AK 99518 lC-24: Digital Log Images 50-029-23063-00 1 CD Rom ... REceIVED JAN 2. 1 2003 Aia8ka œ & Gas Cons. Cornnùalion Andtcøge ScblUDI~epger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth c=-- Well Job # Log Description Date PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE WIDEFT INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE LEAK DETECTION LOG 05/15/02 OS/23/02 05/15/02 05/16/02 OS/25/02 OS/22/02 OS/24/02 OS/22/02 -' SIGN~ J}O~ NO. 2156 Company: Field: BL Sepia 06112/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color 1 1 1 1 1 1 1 1 RECEIVED DATE: J1JN7T2002 Alaska Oil & Gas Cons. Commiaion AndIorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. :1 \ 'I ao j'd'l8 JoD'Sc) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7111 Avenue, Suite 100 Anchorage, Alaska May 9, 2002 RE: MWD Formation Evaluation Logs 1 C-24, AK-MM-11218 1 LDWG formatted Disc with verification listing. API#: 50-029-23063-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signe~ ~ Date: RECEIVED r{~!:::.y f) ; "OO? .. \. L'¡ L - Alaska Oil & Gas Cons. Commission Anchorage 1 ~. Operations p&rformad: . . . . :.{ it STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '.' .. Op~~ shutdOwn...:.. . . Pull "tòbing - . :: .. 2- Name of Operator Phillips Alaska, Inc. 3- Address p - O. Box 100360 AJ'1chorage, AK 99510-0360 4. Location of well at surface 1666' FNL, 3987 FEL, Sec. 12, T11N, R10E, UM At top of productive Interval At effective depth At total depth 4022' FNL, 2506' FEL, Sec. 11, T11 N, R1 DE, UM 12 - Present well condition summary ï otal depth: measured true vertical Effective depth: Calsfng CONDUCTOR SURFACE PRODUCTION LINER UNER Perforation depth: measured 7485-7520; 7560-7670; 7100-7885: 7945-8015; 8065-8090; 8500-8600; 8650-8750 'r~E 8800-8900.8950-9150; 9180-9215 ~'.n~t... true vertical 6424-6427; 6430-6440; 6441-6455; 6461-6468; 6472-6474;6498-6492: 6488-6483 6481.6479: 6480-6£06: 6513--6520 measured true vertical Length 161' 4609' 6733' 2706' Size 16" 9-5/8" 7" 4.1/2" Tubing (size. grade, and measured depth) 14. - ..... - .". - ~ . ~ . .... S«muIaIe- ARer casing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (asp's 562298, 5968571) (asp's 558523,5966185) 9350 feet 6548 feet Plugs (measured) feet feet Junk (measured) Cemented 9 Cu Yds High Early 120 sx AS LIte & 850 sx UteCrete 185 sx Class G 380 sx GasBlok 4.1~. 12.6Jt. l'.SO Tbg @ 6654' MD. Oll-Bbl ..., . . . . . ..". .. '" .. ........ . . . ... . ..... ... ... .:: ::o".1~2.1..:.:-:.::::>:.:. :'::';:.:.:::::..:~i~j"~:....: . . ~~I._'~~' Gas- Plugging - perforate - Reopait weft - 0Ihet _X GINJ rø WAG 6, Datum elevation (OF or KB feet) AKB 1 02 feet 7. Unit or Property name Kuparuk Unit 8, Well number 1 C-24 9. Permit number I approval number 201-248/ 10, API number 50-029-23063 11. Field I Pool Kuparuk Oil Pool Measured Depth 161' 4711 ' 6835' 9350' True vertical Depth 161' 4413' 6252' 6548' N~QlI!1, G~ CoM. ODmiaoior"l P3ckers & SSSV (type & measured depth) BAKER 4.S. X r lXPUNER TOP PACKER w.'HOLDDOWNS. HRPROFILE @ 6658' MD. A"'~" CAMeO DB r-npPLE WITH 3.812 NO GO PROFILE @ 5tT MD. 13. Stimulation or cement squeeze summary ..." . ... . . .. ."'. . ... .... . . . .... ... .... ....... Intelvals treated (measured) .. . : .::....: .:.: N/A .'.... .......0" . . . . Treatment description including volumes used and final pressure ... : :.: :.~ :..: .":.. :. :.':. . ..: : :."... " . . .. .. .. ... :.: .: ..: : .. .. . '" . ..... ... ...., .. Representative DailY AveraQ9 Production or Injection Data Gas-Mcf Water-Bbi . . ... ... Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Druly Report of Well Operahons _X Or! - 'X - "7. J hereby certify that the foregoing is true and correct to the best of my knowledge, '---'--/1 ~- Signed V. rr~ ~ ~?M:-b~ - Jeff A. Spencer "'ED APR 1 ZOO:Z Casing Pressure Tubing Pressuœ 3054 . 280 SuspE?f1ded - Service - Questions? Call Jeff Spencer 659-7226 Title Production Engineering Supervisor Date 11 (irC,A ?--g ( '"2¿t) 2- Prepared by Robert Christensen 659-7535 11 Io! Ii ~..... ~ ~ ~.......,........ ...."..... ,-.-...... ,~ 1 C-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary . . 2I23I2o02tComm'enced temporary Pre-PrOductional anlnjeCtiÇ>" Service W~.. . " ..., .,' ,_. . I ,.:. .. . I( j { PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 . March 21, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1C-24 (201-248 / 302-084) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 1 C-24. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, -"'~'.."""""~_. . Q""-"'-~:' , -..:.~~\ \ ~.. R. Thomas Greater Kuparuk Team Leader P AI Drilling .<~ RT/skad RECEIVED t.t~\R 2 Z 2002 Alaska Oil & Gas Cons. Commissiofl Anchorage ".)R ' '. J~""'t,. I :, ,,' I , . ~ ' ~."I!' \. : t :\,LINAL ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D Suspended D Abandoned D Service 0 Pre-Produced WAG Injector Converted to Producer 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ' l.:OCA t1ONS 201-248 I 302-084 3. Address .L' 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 svtf~ . I ' 50-029-23063-00 4. Location of well at surface "c:",,~':'~. '::'.;:"'=;"'.'. . ~ ~ ".',. 9. Unit or Lease Name 1668' FNL 1290' FWL Sec. 12 T11N R10E UM'~"'-:::""_!'~i':; (ASP: 562298, 59 ro;~ r) ~.r;-rr Kuparuk River Unit , , , , , i \ \ 'I "" - At Top Producing Interval : I. -£c, c: ó zJ 10. Well Number 1460' FSL, 656' FEL, Sec. 11, T11 N, R10E, UM .~ ~::-::-~~~~--: (ASP:560372, 5966403) 1 C-24 I ',' '", "" , AtTotal Depth ~ ;;Q¡j-" i 11. Field and Pool \ ""'0 ~. ..,----......... ¡' 1256' FSL, 2506' FEL, Sec. 11, T11 N, R10E, UM "'.".,.~.-,.._...-..\",-.,_.~,." (ASP: 558523, 5966185) Kuparuk Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field RKB 41', AMSL 102 ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions January 1, 2002 January 16, 2002 January 26, 2002 NIA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9350' MD 16548' TVD 9250' MD / 6528' TVD YES 0 No D NIA feetMD 1863' 22. Type Electric or Other Logs Run GR/Res, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 161' 24" 9 cu yds High Early 9.625" 40# L-80 Surface 4711' 12.25" 1200 sx AS Lite, 850 sx LiteCrete 7" 26# L-80 Surface 6835' 8.5" 185 sx Class G 4.5" 12.6# L-80 6644' 9345' 6.125" 380 sx GasBlok 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ALL PERFS ARE 4 SPF ----- SIZE DEPTH SET (MD) PACKER SET (MD) 7485' - 7520' MD 6423' - 6427' TVD 8950'-9150' MD 6480'-6507' TVD 4.5" 6655' 6658' 7550' - 7670' MD 6430' - 6440' TVD 9180'-9215' MD 6513'-6520' TVD 7700' - 7885' MD 6441' - 6455' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7945' - 8015' MD 6461' - 6467' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8065' - 8090' MD 6472' - 6474' TVD NIA 8500' - 8600' MD 6497' - 6492' TVD 8650' - 8750' MD 6489' - 6483' TVD 8800' - 8900' MD 6481' - 6479' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 23, 2002 Pre-Produced Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 3/6/2002 12.0 Test Period> 593 648 1371 176 1093 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 280 psi not available 24-Hour Rate> 1186 1296 2741 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECE'VED NIA t~~n2(' 2002 "~ ~ : ¡ \. , <... AlaSka Oil & Gas Cons. CammisSior l And1orage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 0 RIG I NA LRBDMS BFL r ~1AR 2 2 2002 \..9(----- 29. ~.. GEOLOGIC MARKERS 30. ~ FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Kuparuk C Kuparuk D 7475' 7350' 6422' 6402' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 ~ ----Ì-.. Signed. \ ~~\ \ \:J......~-,,-~ \ Randy Thomas KuDaruk Team Leader Date "~(2 \ /'c'~ Prepared by Sharon Allsup-Drake 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 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 (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ~ ~ ....... , --, ~ PHILLIPS ~ IW ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/29/2001 12/30/2001 12/31/2001 111/2002 1/2/2002 ~. ( PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n 1268@ ppco.com Nabors 245 Page 1 of 9 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations Sub From - To Hours Code Code Phase 12:00 - 00:00 00:00 - 12:00 12:00 - 22:00 22:00 - 00:00 00:00 - 12:00 12:00 - 16:00 16:00 -19:30 19:30 - 20:00 20:00 - 00:00 00:00 - 01 :00 01 :00 - 04:00 04:00 - 05:30 05:30 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 08:30 08:30 - 11 :30 11 :30 - 00:00 12.00 MOVE 12.00 MOVE 10.00 MOVE MOVE MOVE MOVE MOVE MOVE MOVE 12.00 MOVE 2.00 RIGMNT RSRV MOVE MOVE MOVE 4.00 MOVE 3.50 MOVE 0.50 MOVE 4.00 MOVE 1.00 MOVE 3.00 MOVE 1.50 MOVE 3.50 MOVE 1.00 MOVE 1.00 MOVE 1.00 MOVE 1.00 MOVE 2.00 MOVE 4.00 DRILL 4.00 DRILL 1.00 DRILL 8.50 DRILL 3.00 DRILL 12.50 DRILL MOVE MOVE MOVE MOVE MOVE MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE DRLG SURFAC PULD SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC DRLG SURFAC Blowdown water & steam on drill module. BI ow down water on utility module. Skid floor 38' to center. Jack up cellar. Put both mo dules on crib blocks. Raise stomper. Move ball mill to 1C pad. Turn both modules and prep to leave 1 R pad. Move Utility module & Drilling module from 1R Pad at KOC "Y" leading to 1C Pad. Back left track on Utility module slid off roa d, Attempt to free same. Tighten tracks on Utility module & Prepair t 0 continue move. Replace teflon under crib block on utility m odule. Move Utility module from KOC "V" to 1C. Move drilling module from KOC to 1C. Spot drilling module over hole. Skid floor. Lower cellar and stomper. Set drilling module down. Turn utility module and mate up to drilling module. Set ball mill in place. Hook up service lines. Turn on steam. Chi nk cellar and sub. Plug and insulate all cracks on rig. Thaw 0 ut speed head on divertor stack. NU 21-1/4" divertor stack and divertor lines Change out saver sub to 4" and rig up to pic k up 4" rental drill pipe. Pick up and stand back 120 jts 4" drill pipe in derrick. Continue picking nd cellar. Rig up Pick up 26 jts 5" k in derrick. Make up 2-8" drill collars. Tag ice at 45'. Change out strip-o-matic Realign divertor. Function test divertor and test Koomey. Make up bit and hwdp. Clean ice from 45'-16 l' inside the conductor to the bottom. Pick up and make bha., orient and test same up and cleaning rig floor a to pickup 5" hwdp. HWDP and jars. Stand bac Pre spud meeting. Spud and drill 161'-230'. Gyro as needed. ART-.75 hrs. Drill 230'-593'. Released gyro @ 485'. Goo d surveys with MWD. ADT-4.8 Hrs, AST-2.5 Hrs, ART-2.3 Hrs. Shakers blinding off from excessive amounts of sand. Loosing mud. Build mud volume and reduce pump strokes while building volu me. Directional drill 593'-1645'. ADT- 8.5 Hrs, Printed: 2/27/2002 11:06:46AM ..... -"""" -00. 1~l'pHiLLìPS) I[Ð ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/2/2002 1/3/2002 1/4/2002 1/5/2002 1/6/2002 ,t' ~i ~ PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n 1268@ ppco.com Nabors 245 Sub From - To Hours Code Code Phase 11 :30 - 00:00 00:00 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 14:00 14:00 - 00:00 00:00 - 20:00 20:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 04:00 04:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 15:00 15:00 - 16:00 16:00 - 20:00 20:00 - 21 :00 21 :00 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 04:00 12.50 DRILL 10.50 DRILL 1.00 DRILL 0.50 DRILL 2.00 DRILL 10.00 DRILL 20.00 DRILL 1.00 DRILL 2.00 DRILL DRLG SURFAC DRLG SURFAC CIRC SURFAC OBSV SURFAC WIPR SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC 1.00 RIGMNT RSRV SURFAC 1.50 DRILL WIPR SURFAC 2.50 DRILL 3.50 DRILL 2.00 DRILL 1.00 CASE 0.50 CASE 4.00 CASE 1.00 CASE 4.00 CASE CIRC SURFAC TRIP SURFAC PULD SURFAC RURD SURFAC SFTY SURFAC RUNC SURFAC CIRC SURFAC RUNC SURFAC 1.00 CEMEN" RURD SURFAC 2.50 CEMEN" CIRC SURFAC 0.50 CEMEN" SFTY SURFAC 3.00 CEMENl PUMP SURFAC 1.00 CEMENl DISP SURFAC Page 2 of 9 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations AST-4.0 Hrs, ART-4.5 Hrs. Drill 1645'-2687'. ADT-4.8 Hrs, ART-4.3 hrs , AST-.5 Hrs Pump sweep and circulate hole clean. Monitor well and blow down top drive. Short trip to hwdp. Rotate and work through tight spot with pumps from 2550'-2535'. N 0 other problems Trip back to bottom. No problems. Drill 2687'-3635'. ADT-9.25 Hrs. ART-7.5 H rs, AST-1.75Hrs. Drill from 3635'-4720'. ADT-15.75 Hrs, ART- 14.0Hrs, AST-1.75 HRS. Pump sweep and circulate hole clean. Monitor well. Pump dry job and short trip to hwdp. No problems. Service rig and top drive. TIH. Wash and ream last stand to bottom. N 0 fill No problems. Pump sweep. Circulate and condition mud to run casing. Monitor well. Pump dry job. Pooh to bha. No problems. LD BHA. Download MWD. PJSM. RU GBR casing tools and Frank's fill up tool. PJSM with all Nabors hands, toolpusher, co mpany man, GBR, Bariod, Sperry and PESI on running casing. Run 50 jts 9-5/8" 40# L-80 BTC casing. Circulate and condition mud At 6 bpm with 3 00 psi. No losses 9.4 ppg in and out. Finish running 9-5/8" 40# L-80 BTC casing. Total of 110 jts were run .Shoe at 4711'. No problems. Rig up Schlumberger cement head and lines. Break circulation slow. Start pumping at 3 b pm and slowly bring rate up to 8 pm at 500 psi. No losses. Pumped a total of 1100 bbls PJSM with all Nabors personnel, toolpusher, company man, mud engineer, APC and Schl umberger cementers. Test lines 3500 psi. Pump 50 bbls CW 100@ 8.3 ppg. Mix and pump 50 bbls mud push @ 10.5 ppg. Mix and pump 600 sxs(475 bbls) A S Lite@ 10.7 ppg. Tail with 100 sxs(40 bbls) Litecrete @ 11.8 ppg. Tail cement was cut 8 7 bbls short because the cement line from t he silo to the mixing tub got plugged with dr y cement and could not unplug it. Drop top p lug and pumped 5 bbls water. Displace cement with 9.4 ppg mud. Displace Printed: 2/27/2002 11 :06:46 AM .... ~ ..... ~~pHiLLiPS) I~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/6/2002 1nl2002 1/8/2002 1/9/2002 ( ( PHILLIPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From - To Hours Code Code Phase 03:00 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 10:00 10:00 - 16:30 16:30 -18:00 18:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 03:30 03:30 - 05:00 05:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 00:00 00:00 - 00:00 00:00 - 05:30 05:30 - 07:30 07:30 - 10:00 1.00 CEMEN' DISP SURFAC 2.00 CASE RURD SURFAC 2.00 WELCTL NUND SURFAC 2.00 WELLSR NUND SURFAC 6.50 WELCTL NUND SURFAC 1.50 WELCTL NUND SURFAC 5.00 WELCTL BOPE SURFAC 0.50 WELCTL NUND SURFAC 0.50 WELLSR PLGM SURFAC 3.50 DRILL PULD SURFAC 1.50 DRILL OTHR SURFAC 5.00 DRILL TRIP SURFAC 2.00 WELCTL SFTY SURFAC 1.00 DRILL SURFAC TRIP 1.00 WELLSF DEOT SURFAC 0.50 RIGMNT RSRV SURFAC 2.00 DRILL DRLG SURFAC 1.00 DRILL CIRC SURFAC 1.00 FRMTST OTHR SURFAC 5.50 DRILL DRLG INTRM1 24.00 DRILL DRLG INTRM1 5.50 DRILL DRLG INTRM1 2.00 DRILL CIRC INTRM1 2.50 DRILL WIPR INTRM1 Page 3 of 9 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations d at 6 bpm. Beginning psi was 500 psi and i ncreased to 1000 psi as cement came up the backside. Slowed pump to 3 bpm with 800 psi and bumped the plug to 1500 psi as calc ulated. Floats held. CIP @ 0400 hrs. Blow down lines, Id cement head, landing jt, and casing elevators. Flush out stack and f low lines. ND divertor and divertor lines Install casing head and tubing head and orie nt same. Nipple up 13-5/8 10K bop stack. Pick up and rig up test equipment. Install te st plug and fill stack. Test bops. Test all valves, rams, choke man ifold 2501 5000 psi for five minutes each. T est hydril 250/3500 psi. No failures. John Crisp with AOGCC waived witnessing test. RD test equipment and blow down choke man if 0 I d Pull test plug and install wear ring. Pu and mu bha. Load MWD, orient and test s am e. Rotate slow and pump slow while going thro ugh the port collar. No problems. Pressured casing to 900 psi for 10 minutes-ok. Tih picking up 4" drill pipe. PJSM. Perform stripping drill with crew. Stri pped three stands and explained the reason s for the drill. Finish tripping in hole. Tag float collar at 4 629' . Rig up and test casing to 2500 psi for 30 mi nute on chart recorder. Good test. Service top drive Drill float equipment and 30' new formation to 4750'/4448'TVD. Circulate and condition mud. 9.3 ppg in and out. Perform LOT with 9.3 ppg mud. Broke down f ormation with 1300 psi. EMW=14.9 PPG Directional drill 4750'-5280'/5072'. ADT- 5 .3 Hrs. Displace well with LSND while drillin g ahead. Drill 5280'-6511' MD 1 6182' TVD. ADT-18.9 Hrs. ART-9.3 Hrs, AST-9.6 Hrs. Drill 6511'-6850' 16250'TVD. Adr-4.5 Hrs, Ar t-2.0 Hrs, ASt-2.5 Hrs. TD per geologist. T op of HRl 6480' MDI 6017' TVD. Btm HAl 68 30'MDI 6250' TVD. Pump sweep and circulate hole clean. Circul ated 3 bottoms up. Monitor well. Pump dry job. Pooh to casing Printed: 2/27/2002 11:06:46AM ~ .... ~ ~'PHILLIPS') I[Ø ",.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/9/2002 1 /1 0/2002 ,II \. ,ii I, '. PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n 1268 @ ppco .com Nabors 245 Sub From - To Hours Code Code Phase 07:30 - 10:00 10:00 - 12:30 12:30 - 13:30 13:30 - 18:30 18:30 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 11 :00 11 :00 - 12:00 12:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 22:00 22:00 - 23:00 2.50 DRILL WIPR INTRM1 2.50 RIGMNT RSRV INTRM1 1.00 DRILL WIPR INTRM1 5.00 DRILL CIRC INTRM1 2.00 DRILL TRIP INTRM1 2.00 DRILL 1.50 DRILL 2.50 DRILL TRIP INTRM1 PULD INTRM1 PULD INTRM1 0.50 WELLSF PLGM INTRM1 1.50 WELCTL NUND INTRM1 0.50 WELLSR PLGM INTRM1 1.50 CASE RURD INTRM1 0.50 CASE SFTY INTRM1 4.00 CASE RUNC INTRM1 1.00 CASE CIRC INTRM1 2.50 CASE RUNC INTRM1 2.00 CASE CIRC INTRM1 1.00 CEMENl PUMP INTRM1 1.00 CEMENl DISP INTRM1 1.50 CEMENl RURD INTRM1 2.00 WELLSF DEOT INTRM1 1.00 WELCTL NUND INTRM1 Page 4 of 9 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations shoe. No problems. Cut and slip 82" drill line. Service top driv e and crown. Tih. No problems. Wash and reaqm last stan d to botom. Pump sweep and circulate hole. Slivers of shale about 1" long were coming over shake r and would not completely clean up. Increa se mud wt 10.3 ppg and circulate around Monitor well-static. Pump dry job and pooh t 0 casing shoe. An occassional 10-20 k drag Monitor well-static. Finish pooh to bha. Lay down 5" hwdp Finish laying down hwdp and bha. Download MWD. Pull wear ring and install test plug. Change top rams 4-1/2" x 7" and test doors 1500 psi. Pull test plug and rig down test it. Ru GBR casing tools and Frank's fill up tool Pre job safety meeting with all Nabors crew s, tool pusher, co man, GBR, mud engineer. Run 110 its 7" 26# L-80 BTC Mod to casing shoe. Break circulation slow and circulate capacit y of casing and annulus(300 bbls). Final pu mp rate @ 7 bpm with 700 psi and no losses Up Wt 195K, Down Wt 150K Finish running 161 its 7" 26# L-80 BTC Mod casing. Casing shoe at 6835'. No problems. Good returns Mlu cement head and break circulation slow. Reciprocate casing and bring pump rate up to 7 bpm with 700 psi and no losses. Up W t-250k, Down Wt- 175 K. Batch mix cement w hi Ie circulating. PJSM.. Test lines 3500 psi. Pump 40 CW 10 0 @ 8.3 ppg. Mix and pump 50 bbls mud pus h @ 12.0 ppg. Pump 185sxs( 38.5 bls) "G" @ 15.8 ppg. Drop top plug and follow with 10 bbls water Displace cement with rig at 6 bpm with 800 psi. Slowed rate to 3 bpm and bumped plug t 0 1500 psi. Floats held. CIP @ 1830. Reci procated casing entire job. 250K up; 175K D own. Full returns. RD cement head, Id casing tools and landing it. Rd bails and install 7" packoff and test sam e to 5000 psi. Change top rams 3-1/2" x 6" Printed: 2/27/2002 11:06:46AM ... ...... ...... ~'PHILLIPS) IWJ "V" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/10/2002 1/11/2002 1/12/2002 1/13/2002 1/14/2002 1/15/2002 From - To 23:00 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 09:30 09:30 - 15:00 15:00 -16:30 16:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 23:00 23:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 12:30 12:30 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 19:30 19:30 - 20:30 20:30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 04:30 { :1' , PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours Code Code 1.00 WELCTL NUND 5.00 WELCTL BOPE Phase INTRM1 INTRM1 3.50 DRILL 1.00 WELLSR NUND INTRM1 5.50 DRILL TRIP PULD INTRM1 INTRM1 1.50 DRILL DEOT INTRM1 1.00 DRILL CIRC DRLG INTRM1 INTRM1 3.00 DRILL 0.50 DRILL LOT 2.00 DRILL CIRC 1.00 DRILL 24.00 DRILL INTRM1 INTRM1 CIRC INTRM1 DRLG PROD 24.00 DRILL DRLH PROD 12.50 DRILL DRLH PROD 2.50 DRILL DRLG PROD 0.50 WELCTL OBSV PROD 1.00 DRILL TRIP PROD 3.00 DRILL TRIP PROD 1.00 WELCTL OBSV PROD 3.50 DRILL TRIP PROD 1.00 DRILL TRIP PROD 2.00 DRILL PULD PROD 1.50 DRILL PULD PROD Page 5 of 9 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations Rlu test equipment Test bops. Test all valves, rams, choke man ifold 2501 5000 psi for five minutes each. T est hydril 250/3500 psi. No failures. John Spaulding with AOGCC waived witnessing te st. RD test equipment, pull test plug and instal I wear ring. LD test jt and blow down. Make up directional bha#3, orient, load MW D and test same. Tih with bha picking up 54 jts 4" drill pipe. Continue rih to top of float collar. Rlu and test casing 3500 psi for 30 minutes Recorded on chart recorded. Rid test equi pment. Drill float equipment and 20' new formation- 6870' MDI 6270' TVD Circulate bottoms up. 10.2 ppg mud in and 0 ut Perform LOT with 10.2 ppg mud at 6870' MD 1 6270' TVD. Broke down formation at 1850 psi. EMW=15.9.ppg Swap mud system over to new 10.7 ppg Isnd mud. Take new slow pump rates. Perform PWD base line test. Directional drill 6870'-7665' per geologist. ADT-18.3 Hrs, ART- 10. Hrs, AST-8.3 Hrs Drill horizontal section per geologist from 7 665'-8577'. Sliding when necessary. Drilled across fault at 8440'/6500' TVD and lost par tial returns. Reduced mud wt to 10.3 ppg a nd regained full returns. Lost a total of 213 bbls mud. ADT-15.8 Hrs. ART-9.7 Hrs. AST -6.1 Hrs. Directional drill 8577'-8862'/6478' TVD. Tr ied to drop angle the last 200'. Slid the enti re section without success. Appears that we are skimming across the top of the sand Circulate and condition mud while decision was made to pooh and change bha. Monitor well. Static Pull five stands out of the hole. Hole not ta king proper fill. Trip back to bottom. Pump out to casing shoe. Hole tight from 7 330' -6800'. Had to pump and rotate throug h tight spots. Pulled 25-30 K over. While p umping lost 75 bbls mud. Monitor well. Static. Pump dry job Pooh. POOH to BHA Down Load MWD, Change Pulser, Lay down Motor, Change Bits Make up Bit & Motor, Set motor to 1.83 AKO Printed: 2/27/2002 11:06:46AM ""'" ..... ~'pHiLLiPS'~ , I~I ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/15/2002 1/16/2002 1/17/2002 1/18/2002 1/19/2002 Date ~. ( '~ Page 6 of 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n 1268 @ ppco.com Nabors 245 Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations Sub From - To Hours Code Code Phase 03:00 - 04:30 04:30 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 12:30 12:30 - 00:00 00:00 - 15:30 15:30 - 21 :30 21 :30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 08:30 08:30 - 12:30 12:30 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 00:00 - 04:00 04:00 - 06:00 1.50 DRILL 4.50 DRILL PULD PROD TRIP PROD 0.50 DRILL CIRC 1.00 RIGMNT RSRV 1.50 DRILL TRIP 0.50 DRILL CIRC 11.50 DRILL DRLG 15.50 DRILL 6.00 DRILL 2.00 DRILL PROD PROD PROD PROD PROD DRLG PROD CIRC PROD WIPR PROD 0.50 RIGMNT RGRP PROD 1.00 DRILL CIRC PROD 3.50 DRILL WIPR PROD 1.00 RIGMNT RSRV PROD 2.00 DRILL WIPR PROD 5.50 DRILL CIRC PROD 3.00 DRILL 1.00 DRILL 6.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 CASE 6.00 CASE 4.00 CASE 2.00 CASE 1.50 CASE 2.00 CASE 1.00 CASE 2.00 CASE 1.00 CASE 2.00 CASE TRIP PROD CIRC PROD TRIP PROD PULD PROD PULD PROD RURD PROD PULR PROD RUNL PROD CIRC PROD RUNL PROD CIRC PROD RUNL PROD CIRC PROD RUNL PROD CIRC PROD 4.00 CEMENl CIRC PROD 2.00 CEMENl PUMP PROD , Orient & Program MWD Surface test MWD, Pick up 12 jts DP, RIH to Shoe Circ. Btm's up @ Shoe Service top drive & Blow down RIH to 8862' - No Problems Circ. Btm's up Drill fI 8862' to 9052' ART= 2.9 hrs AST= 5.1 hrs Drill f/ 9052' to 9350' ART= 12.3 hrs AST = 1 hr. Pump Sweep & Circ. hole clean, Monitor we I 1- Flowing, Circ. & Raise mud wt. 10.5 ppg, Monitor well - Static Attempt to wipe hole without pumping out- n 0 good- well swabbing, Pump out to 8482' (N 0 excess drag)- Found top drive saver sub b ad (Gaulded threads), RIH to 9350' (Hole fre e- good fill) Change out top drive saver sub Circ. Btm's up, Monitor well- OK Pump out to shoe @ 6835' due to hole swab bing- No tight hole, taking correct fill Service top drive & circ btm's up RIH- No problems, Hole in good shape Pump sweep & Circ. & condo mud fI 4-1/2" Ii ner csg., Monitor well- OK Pump out to shoe @ 6835' due to hole swab bing- No tight hole, taking correct fill, SLM Circ. btm's up, Monitor well- OK, Pump dry j ob, Drop rabbit POOH to BHA (SLM- No correction) Down load & Lay down BHA Down load BHA & Lay down same PJSM- Rig to run 4-1/2" liner Run 4-1/2" liner & Hanger assembly RIH to Shoe @ 6835' slow, Break circ every 10 stands Circ Btm's up & Condo Mud @ 2 bpm (Mud 10 ss 4 bph) RIH slow to 7635' Circ Btm's up & Condo Mud @ 2 bpm (Mud 10 ss 4 bph) RIH slow to 8435' Circ Btm's up & Condo Mud @ 2 bpm (Mud 10 ss 4 bph) RIH slow to btm @ 9350' Circ Btm's up & Condo Mud @ 2 bpm (Mud 10 st 14 bbls) Circ. & Condo Mud at 3 bpm @ 450 psi w/ mi nor 4 bph losses Continue to circ. while have PJSM & Batch Printed: 2/27/2002 11 :06:46 AM "'"'" ...... ~~pHíLljps) IW) ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/19/2002 1/20/2002 1/21/2002 '( ~.. Page 7 of 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From - To Hours Code Code Phase 04:00 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 15:00 15:00 - 00:00 00:00 - 01 :00 01 :00 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 12:00 12:00 - 14:00 14:00 - 17:30 17:30 - 20:30 20:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 2.00 CEMEN" PUMP PROD 1.50 CEMENl PUMP PROD 1.00 CEMEN" DISP PROD 1.00 CEMENl OTHR PROD 1.00 CEMEN" CIRC PROD 1.50 CEMEN" PULD PROD 3.00 CEMEN" TRIP PROD 9.00 WELCTL BOPE CMPL TN 1.00 WELCTL BOPE CMPL TN 4.50 CMPL TN TRI P CMPL TN 1.50 CMPL TN TRIP CMPL TN 1.00 RIGMNT OTHR CMPL TN 4.00 CMPL TN TRIP CMPL TN 2.00 CMPL TN CIRC CMPL TN 3.50 CMPL TN TRIP CMPL TN 3.00 CMPL TN CIRC CMPL TN 3.50 CMPL TN TRI P CMPL TN 1.00 CMPLTN TRIP CMPLTN 0.50 RIGMNT RSRV CMPL TN Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations mix 380 sxs (81.2 bbls) Class G GasBLOK C mt. Mixed @ 15.8 ppg wi 3.0%D53, 0.30%D6 5, 0.02%D800, 0.02%C359, 2.00gal/skD600G , 0.02gal/skD47 Mix & Pump 10 bbls CW100 @ 8.4 ppg, Test lines to 4500 psi, Mix & Pump 20 bbls CW10 0 @ 8.4 ppg, Mix & Pump 50 bbls MudPUSH @ 12.0 ppg, Followed by 81.2 bbls of the ba tch mixed cmt. (Pumped spacers & cmt at 3 bpm @ 870 - 300 psi), Shut down, Wash line s, Drop Plug, (Note; Gained in pits 161 bbls while pumping 161.2 bbls of spacers & cmt) Displaced cmt wI total of 107.9 bbls 10.4 pp g mud (109.5 bbls calc.) at rate of 3 bpm @ 300 - 900 psi, Reciprocated csg. 15' until la st 27 bbls of displacement and csg. became sticky, Bumped plug wI 3200 psi & set liner hanger, Pressure up to 4200 psi & set liner packer, Bleed off & check floats- OK, CIP @ 0750 hrs 1/19/02, (Note; Possible loss of 34 bbls while displaceing cmt.), Release fro m Ii n e r Pump 20 bbls to flush out liner top, Rig & re verse out est. 18 bbls good cmt. & all space rs Circ. 3 btm's up at 10 bpm to clean DP Monitor well, Lay down Baker cmt head, Pum p dry job, Blow down top drive POOH & Lay down Baker liner setting tool Pull wear bushing, Change top pipe rams to 2-318", Rig & test all BOPE to 250 low & 500 0 high, Hydril to 250 low & 3500 high, BOP t est waived by AOGCC Chuck Scheve Rig down test equip., Blow down, Set wear b ushing Rig & Pick up 3.75" mill, mud motor & 2-3/8 " DP RIH wi 4" DP from derrick Slip & cut drlg line 105' Continue RIH & tag landing collar @ 9250' Drop ball to open circ sub wI 3500 psi - Circ at 3 bpm @ 1200 psi, did not see any indic ation of sub opening POOH to above top of liner and out of horiz onal section, Pump cap. of DP at rate of 6 b pm @ 3900 psi to insure circ sub open, RIH to 9250' Pump 160 bbls water, 30 bbls hi- vis pill, 37 0 bbls 10.4 ppg brine POOH Rig to lay down 2-3/8" DP Lubricate rig Printed: 2/27/2002 11 :06:46 AM ~ ..... ~ ~'PHILLïps) IW; ~~ ."". Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/21/2002 1/22/2002 1/23/2002 1/24/2002 From - To 01 :30 - 03:30 03:30 - 06:30 06:30 - 09:30 09:30 - 14:30 14:30 - 17:30 17:30 - 21 :00 21 :00 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 1 0:30 1 0:30 - 11 :30 11 :30 - 18:00 18:00 - 19:30 19:30 - 00:00 00:00 - 06:30 06:30 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 13:00 13:00 - 19:00 19:00 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 18:00 18:00 - 20:00 20:00 - 00:00 ( "I \\ Page 8 of 9 PHILLIPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n 1268 @ ppco .com Nabors 245 Sub Hours Code Code 2.00 CMPL TN TRI P 3.00 CMPL TN PL T 3.00 CMPL TN TRIP 5.00 CMPL TN TRIP 3.00 CMPL TN PL T 3.50 CMPL TN PL T 3.00 CMPL TN PL T 1.00 CMPL TN PL T 2.00 CMPL TN TRI P 2.00 CMPL TN TRI P 0.50 CMPL TN TRIP 0.50 RIGMNT RSRV 4.50 CMPL TN PL T 1.00 CMPL TN PL T Phase CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 6.50 CMPL TN TRI P CMPL TN 1.50 CMPL TN PL T CMPL TN 4.50 CMPL TN PL T CMPL TN 6.50 LOG DLOG CMPL TN 1.00 LOG RURD CMPL TN 3.50 LOG 0.50 LOG 1.50 CASE DLOG CMPL TN PULD CMPL TN DEOT CMPL TN 6.00 CMPL TN OTHR CMPL TN 5.00 CMPL TN TRI P CMPL TN 5.00 CMPL TN PERF CMPL TN 1.00 CMPL TN PERF CMPL TN 12.00 CMPL TN PERF CMPL TN 2.00 CMPL TN OTHR CMPL TN 4.00 CMPL TN RUNT CMPL TN Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations Lay down 84 jts 2-3/8" DP & Motor BHA Pick up & test Schlumberger US IT tool Pick up 84 jts 2-3/8. DP RIH slow wi US IT tool to 6450' Rig & Pick up sheaves & side entry sub, & P ump down wire line RIH to 7944'- Tool logged from top of liner t 0 6835' then failed, Unable to get tool start ed again POOH to side entry sub, & POOH wi wire lin e POOH wI wire line & Lay down side entry su b POOH wi 4. DP Rig & Lay down 2-3/8. DP Lay down US IT tools Service rig Inspect & trouble shoot tools- Found piece 0 f wire stuck in btm of US IT tool, Wait on SW S tools to run US IT & Sonic CBL in Combo Pick up Schlumberger US IT & Sonic CBL in Combo Pick up 2-3/8. DP, RIH wi 4. DP to 6486' RIH wi wire line & Pick up side entry sub RIH & log fl 6644' to 8514' Log wI US IT & SSLT in Combo f/ 8514' to 92 50' & f/ 9250' to 64350' POOH wi wire line, Lay down side entry sub, Lay down sheaves POOH wI 4. DP, Lay down 2-3/8. DP Lay down SWS logging tools Close Blind rams & test 7" x 4-1/2" csg to 3 500 psi fl 30 min.- OK Wait on orders due to change in perf. interv ai, Wait on guns, Off load & Configure guns Pick up & RIH wi perf. guns RIH wI perf. guns to 9250' & tag landing co I lar Pick up & space out guns f/ 7485'-7520',75 50'-7670',7700'-7885',7945'-8015',8065'-8 090', 8500'-8600', 8650'-8750', 8800'-8900', 8950'-9150',9180'-9215', Pressure well to 2700 psi, bleed off & fire guns Monitor well- well took 4.5 bbls when guns f ired, Well taking 1.6 bbllhr, POOH wI guns, Lay down 2-3/8" DP, Lay down guns in 20' s ections- All shots fired, Load out Schlumber ger perf. tools Rig & perform injection test on 9-5/8" x 7" a nnulas wI 2180 psi = 17.1 EMW, Flush wI 26 5 bbls water & Freeze protect wI 65 bbls die s e I Pull wear bushing, Hold PJSM, Pick up & ru - Printed: 2/27/2002 11:06:46 AM ....... ~ ..... ~~pHi LlJPS~~ t~1 ~ .",. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/24/2002 1/25/2002 1/26/2002 1/27/2002 ,t , ~,. Page 9 of 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-24 1 C-24 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From - To Hours Code Code Phase 20:00 - 00:00 00:00 - 04:00 04:00 - 05:30 05:30 - 07:30 07:30 - 10:00 10:00 - 17:00 17:00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 05:00 - 10:30 10:30 - 13:00 13:00 - 14:00 14:00 - 00:00 00:00 - 00:00 4.00 CMPL TN RUNT CMPL TN 4.00 CMPL TN RUNT CMPL TN 1.50 CMPL TN RURD CMPL TN 2.00 CMPL TN SOHO CMPL TN 2.50 CMPL TN RURD CMPL TN 7.00 WELCTL NUND CMPL TN 6.50 WELCTL NUND CMPL TN 0.50 CMPL TN FRZP CMPL TN 1.00 CMPL TN RURD CMPL TN 0.50 CMPL TN RURD CMPL TN 3.50 CMPL TN FRZP CMPL TN 5.50 CMPL TN RURD CMPL TN 2.50 CMPL TN RURD CMPL TN 1.00 CMPL TN NUND CMPL TN 10.00 MOVE DMOB MOVE 24.00 MOVE DMOB MOVE Spud Date: 1/1/2002 End: 1/26/2002 Group: Start: 12/27/2001 Rig Release: 1/26/2002 Rig Number: 245 Description of Operations n completion string Run 4-1/2" completion string Change over to long block bails, Rig to & Br eak circ at 2 bpm @ 200 psi, Locate top of SBE @ 6644'- OK Space out & land tbg.,Run in lock downs, Ri g & attempt to test 4-1/2" x 7" annulas to 25 00 psi- 3000 psi RP valve sheared early un able to hold test for 15 min. Lay down landing jL, Install BPV, Rig down GBR & Clean rig floor, Nipple down bell nipp Ie & flow line Remove rams from BOP, Nipple down BOP St ack Install, Nipple up & Test Tree to 250 psi low & 5000 psi high Rig to freeze protect well Change block bails & elevators for laying do wn 4" DP Lay down 4" DP from derrick Install 4-1/16" x 2" 1502 union flange to Tre e, Freeze protect 4-1/2" x 7" ann. w/ 35bbls Diesel, Install BPV & Bullhead 30 bbls Dies el down tbg. @ rate of .75 bpm @ 1400 psi, Blow down all lines Lay down 4" DP from derrick Lay down mouse hole, Clear floor of all Pipe handling, tools, X-O subs, etc. Change out 4-1/16" x 2" w/ 4-1/16" x 1/2" & install all guages on Tree, Release rig at 14 00 hrs 1/26/02 Disassemble mud pumps, clean mud equip., pits, rig floor Prep. rig for stack out, Working on pumps, p its, Rig floor, Cellar, Flush top drive, all m ud lines on rig floor back to ball mill& blow down same. Printed: 2/27/2002 11:06:46 AM Date 02/08/02 02/09/02 02/1 0/02 02/11/02 1 C-24 Event H ¡story ~I; \ Comment STATIC @ 7173' & 6973' WLM, PULLED SHEARED SOV @ 6557' RKB, IN PROGRESS [PRESSURE DATA, GLV] SET PLUG & PRONG @ 6602' RKB, RECOVERD BRINE, SET DV @ 6557' RKB, FAILED PT, IN PROGRESS [OPEN-CLOSE A SAND, GLV, PT TBG-CSG] INSPECTED DV @ 6557' RKB, FOUND LEAK @ 6557' RKB, IN PROGRESS [GLV, LEAK DETECT] REPLACED DV @ 6557' RKB. TESTED TBG & CSG 3000 PSI, OK. SET OV @ 2712' RKB. PULLED PRONG & DB PLUG @ 6602' RKB. [GLV, PT TBG-CSG, OPEN-CLOSE A SAND] Page 1 of 1 2/27/2002 \ C' I II af;lS7?~:JV ~' 02-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-24 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) REceIVED FES 0 7 2002 AIaIIœ Oil & Gas Cons, t;omm" . Anchorage ISSiOn -\- ~ ".':""; " ,. , ... ( Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-24 1 C-24 Gyro Job No. AKFO11218, Surveyed: 16 January, 2002 SURVEY REPORT 5 February, 2002 ( Your Ref: 500292306300 Surface Coordinates: 5968571.44 N, 562297.94 E (70019' 28.7732" N, 149029' 41.4448" W) Surface Coordinates relative to Project H Reference: 968571.44 N, 62297.94 E (Grid) Surface Coordinates relative to Stucture Referance: 49.59 N, 73.70 W (True) Kelly Bushing: 101.6Oft above Mean Sea Level 5pe"""-'V-5UI'l DRILLING seRVIc::es A Halliburton Company DEFINITIVE Survey Ref: svy9831 Sperry-Sun Drilling Services Survey Report for 1C-24 Gyro Your Ref: 500292306300 Job No. AKFO11218, Surveyed: 16 January, 2002 . Measured Depth (ft) Incl. Azim. North Slope, Alaska Kuparuk 1 C Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) -101.60 0.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.00 Tolerable Gyro -18.60 83.00 0.18 S 0.02 E 5968571.26 N 562297.96 E 0.301 0.09 67.40 169.00 0.06 S 0.25E 5968571.38 N 562298.19 E 0.826 -0.17 157.40 259.00 0.02 S 0.75 E 5968571.43 N 562298.69 E 0.851 -0.62 247.39 348.99 1.13 S 1.37 E 5968570.32 N 562299.32 E 0.797 -0.52 Kuparuk River Unit 0.00 83.00 169.00 259.00 349.00 0.000 0.250 0.500 0.500 1.150 0.000 175.000 35.000 135.000 158.000 ( All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.032° (01-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 236.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 349.001t, The Bottom Hole Displacement is 1.77f1., in the Direction of 129.617° (True). Survey tool program for 1 C-24 Gyro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description ( 0.00 0.00 349.00 348.99 Tolerable Gyro ......................-..----.. .'-'-'-"""', '..... 5 February, 2002 - 13:35 Page 2 of 2 DrillQuest 2.00.09.008 !{ ~l """!"".,:'~",.,,~,'{;,~~,,;,,,'I,"0)""""" ,g!""" ,', ~,tW"~, ,C U "-V'," 05-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-24 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 349.00' MD 'MD 9,350.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 0 T 2002 Alaska Oil & Gas Cons. Commi8lion Anchorage \ ;') .¡',\ h.>o .~ f{). \ ~. ~. I ( Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-24 1 C-24 Job No. AKZZ11218, Surveyed: 16 January, 2002 SURVEY REPORT ( 5 February, 2002 Your Ref: 500292306300 Surface Coordinates: 5968571.44 N, 562297.94 E (70019' 28.7732" N, 149029'41.4448" W) Surface Coordinates relative to Project H Reference: 968571.44 N, 62297.94 E (Grid) Surface Coordinates relative to Stucture Referance: 49.59 N, 73.70 W (True) Kelly Bushing: 101.60ft above Mean Sea Level sper'"y-5UI'1 DRILLING seRVices A Halliburton Company DEFINITIVE Survey Ref: svy9833 Sperry-Sun Drilling Services . Survey Report for 1 C-24 Your Ref: 500292306300 Job No. AKZZ11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 349.00 1.150 158.000 247.39 348.99 1.13 S 1.37 E 5968570.32 N 562299.32 E -0.52 Tie-on Point AK-6 BP IFR-AK 480.38 1.490 185.530 378.73 480.33 4.05 S 1.70 E 5968567.40 N 562299.67 E 0.540 0.81 572.68 2.390 188.810 470.98 572.58 7.15 S 1.29 E 5968564.30 N 562299.28 E 0.982 2.85 (' 664.47 5.190 195.610 562.56 664.16 13.04 S 0.13W 5968558.40 N 562297.92 E 3.084 7.26 754.06 7.440 198.450 651.60 753.20 22.45 S 3.05W 5968548.97 N 562295.07 E 2.535 14.87 845.41 8.080 189.660 742.12 843.72 34.39 S 6.00W 5968537.00 N 562292.22 E 1.474 23.89 933.97 8.280 192.120 829.78 931.38 46.76 S 8.38W 5968524.61 N 562289.94 E 0.455 32.67 1031.18 10.350 190.840 925.70 1027.30 62.18 S 11.50 W 5968509.17 N 562286.96 E 2.140 43.73 1125.40 14.320 187.920 1017.73 1119.33 82.04 S 14.70 W 5968489.28 N 562283.93 E 4.264 57.30 1220.69 13.840 188.520 1110.15 1211.75 104.98 S 18.01 W . 5968466.31 N 562280.80 E 0.526 72.66 1313.00 14.590 189.470 1199.64 1301.24 127.37 S 21.56 W 5968443.89 N 562277.44 E 0.851 87.91 1407.55 17.000 192.190 1290.61 1392.21 152.63 S 26.43 W 5968418.59 N 562272.77 E 2.666 105.85 1502.63 19.580 194.560 1380.88 1482.48 181.64 S 33.38 W 5968389.53 N 562266.07 E 2.823 127.58 1597.89 21.510 197.000 1470.08 1571.68 213.80 S 42.50 W 5968357.30 N 562257.22 E 2.216 152.84 1694.18 21.850 199.100 1559.56 1661.16 247.61 S 53.52 W 5968323.39 N 562246.48 E 0.880 180.62 1789.58 21.600 200.240 1648.18 1749.78 280.86 S 65.40 W 5968290.04 N 562234.87 E 0.514 208.80 1886.17 22.250 201.770 1737.79 1839.39 314.53 S 78.34 W 5968256.27 N 562222.22 E 0.896 238.08 1980.99 23.990 201.540 1824.99 1926.59 349.13 S 92.07 W 5968221.56 N 562208.77 E 1.838 268.55 2075.82 24.410 202.370 1911.49 2013.09 385.18 S 106.61 W 5968185.39 N 562194.53 E 0.570 300.49 2170.34 24.940 202.700 1997.38 2098.98 421.63 S 121.73 W 5968148.82 N 562179.71 E 0.579 333.13 ( 2265.16 25.880 204.050 2083.02 2184.62 458.97 S 137.88 W 5968111.34 N 562163.87 E 1.164 367.12 2359.60 26.230 207.930 2167.87 2269.47 496.23 S 156.06 W 5968073.93 N 562146.01 E 1.842 402.76 2453.47 24.860 209.340 2252.56 2354.16 531.76 S 175.44 W 5968038.24 N 562126.92 E 1.597 438.4 7 2549.17 24.090 208.350 2339.66 2441 .26 566.49 S 194.58 W 5968003.36 N 562108.07 E 0.912 473.52 2637.57 24.370 210.370 2420.28 2521.88 598.10 S 212.36 W 5967971.59 N 562090.55 E 0.990 505.73 2738.63 22.600 210.070 2512.96 2614.56 632.90 S 232.64 W 5967936.63 N 562070.57 E 1.755 541 .78 2833.39 22.850 209.750 2600.37 2701.97 664.63 S 250.89 W 5967904.75 N 562052.58 E 0.294 574.45 2928.37 23.160 210.050 2687.79 2789.39 696.81 S 269.39 W 5967872.42 N 562034.34 E 0.349 607.57 3023.35 23.170 211.050 2775.11 2876.71 728.98 S 288.38 W 5967840.09 N 562015.62 E 0.414 641.11 3118.35 23.590 211.280 2862.31 2963.91 761.24 S 307.89 W 5967807.67 N 561996.38 E 0.452 675.12 .'..., '0""" "...,...___h_"_""'----------- ...--.---...... ""_."""'.' .. 5 February, 2002 - 13:34 Page 2 of 6 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for 1 C-24 Your Ref: 500292306300 Job No. AKZZ11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 3212.97 24.560 210.800 2948.70 3050.30 794.31 8 327.79 W 5967774.43 N 561976.75 E 1.046 709.90 3307.39 25.500 211.270 3034.25 3135.85 828.54 8 348.39 W 5967740.03 N 561956.44 E 1.018 745.90 3402.50 24.380 213.160 3120.50 3222.10 862.48 S 369.76 W 5967705.92 N 561935.36 E 1 .445 782.38 ( 3497.13 22.360 213.000 3207.36 3308.96 893.93 8 390.25 W 5967674.31 N 561915.13 E 2.136 816.77 3591.62 23.090 213.280 3294.51 3396.11 924.49 S 410.20 W 5967643.58 N 561895.43 E 0.781 850.22 3685.08 23.430 213.880 3380.38 3481.98 955.24 S 430.62 W 5967612.66 N 561875.27 E 0.443 884.16 3781.00 23.390 214.950 3468.40 3570.00 986.67 S 452.15 W 5967581.05 N 561853.99 E 0.445 919.42 3878.75 23.560 216.270 3558.06 3659.66 1018.33 S 474.83 W 5967549.20 N 561831.58 E 0.565 955.74 3971.31 23.650 217.780 3642.88 3744.48 1047.92S 497.14 W 5967519.43 N 561809.51 E 0.660 990.64 4066.32 24.080 218.180 3729.76 3831.36 1078.21 S 520.80 W 5967488.94 N 561786.11 E 0.484 1027.04 4161.26 24.940 218.800 3816.15 3917.75 1109.04 S 545.31 W 5967457.91 N 561761.85 E 0.945 1064.45 4256.35 25.430 220.780 3902.20 4003.80 1140.12 8 571.21 W 5967426.61 N 561736.21 E 1.025 1103.15 4350.03 25.860 216.310 3986.66 4088.26 1171.828 596.45 W 5967394.71 N 561711.24 E 2.115 1141.65 4444.74 26.500 215.810 4071.65 4173.25 1205.608 621.04 W 5967360.72 N 561686.93 E 0.715 1180.74 4541.64 25.230 213.780 4158.85 4260.45 1240.30 8 645.18 W 5967325.83 N 561663.08 E 1.598 1219.96 4635.07 25.450 215.170 4243.29 4344.89 1273.26 8 667.81 W 5967292.68 N 561640.72 E 0.679 1256.97 4677.48 25.560 215.410 4281.56 4383.16 1288.178 678.36 W 5967277.69 N 561630.30 E 0.356 1273.97 4822.32 25.350 216.290 4412.34 4513.94 1338.63 S 714.82 W 5967226.93 N 561594.26 E 0.299 1 332. 13 4916.81 25.180 215.550 4497.80 4599.40 1371.28 S 738.48 W 5967194.07 N 561570.87 E 0.380 1369.83 5011.55 24.790 213.830 4583.67 4685.27 1404.18 8 761.25 W 5967160.99 N 561548.37 E 0.870 1406.93 ( 5106.27 24.550 213.330 4669.75 4771.35 1437.128 783.12 W 5967127.87 N 561526.78 E 0.336 1443.28 5200.96 23.880 214.060 4756.10 4857.70 1469.43 8 804.66 W 5967095.38 N 561505.50 E 0.775 1479.02 5295.23 23.670 213.050 4842.37 4943.97 1501 .10 8 825.67 W 5967063.53 N 561484.76 E 0.486 1513.96 5390.59 23.770 211.820 4929.68 5031.28 1533.48 S 846.24 W 5967030.99 N 561464.46 E 0.529 1548.93 5485.08 23.350 213.860 5016.29 5117.89 1565.21 8 866.72 W 5966999.09 N 561444.25 E 0.971 1583.45 5581 .39 23.120 214.810 5104.79 5206.39 1596.58 8 888.15 W 5966967.54 N 561423.08 E 0.457 1618.58 5676.12 21.860 213.330 5192.32 5293.92 1626.59 8 908.45 W 5966937.37 N 561403.02 E 1 .458 1652.03 5770.75 20.280 210.540 5280.62 5382.22 1655.44 8 926.47 W 5966908.37 N 561385.25 E 1.977 1682.92 5865.50 18.850 211.920 5369.90 5471.50 1682.57 S 942.91 W 5966881.10 N 561369.03 E 1.586 1711.55 5959.92 18.920 211.230 5459.23 5560.83 1708.61 S 958.91 W 5966854.93 N 561353.25 E 0.248 1739.21 . .- .---. ,,".-""""-""-'."""'.-----"'----- .____0""'_-.-_"-0" ".- 5 February, 2002 - 13:34 Page 3 of 6 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for 1C-24 Your Ref: 500292306300 Job No. AKZZ11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs EIstlngs Northlngs EIstings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6054.49 21.020 212.750 5548.11 5649.71 1735.99 S 976.04 W 5966827.41 N 561336.35 E 2.287 1768.55 6149.15 24.690 218.310 5635.34 5736.94 1765.79 S 997.49 W 5966797.43 N 561315.15E 4.495 1802.84 6242.88 29.210 222.440 5718.87 5820.47 1798.05 8 1025.07 W 5966764.94 N 561287.83 E 5.217 1843.60 6337.22 33.080 228.990 5799.62 5901.22 1831.95 S 1060.06 W . 5966730.75 N 561253.13 E 5.447 1891.46 ( 6432.06 37.180 227.180 5877.17 5978.77 1868.43 S 1100.63 W 5966693.93 N 561212.86 E 4.460 1945.39 6525.59 41 .540 235.110 5949.52 6051.12 1905.42 S 1146.84 W 5966656.56 N 561166.95 E 7.109 2004.32 6620.02 45.740 240.970 6017.87 6119.47 1939.77 S 1202.14 W 5966621.76 N 561111.94 E 6.171 2069.40 6716.89 50.560 243.330 6082.49 6184.09 1973.42 S 1265.94 W 5966587.58 N 561048.43 E 5.296 2141.20 6766.78 54. 190 240.120 6112.94 6214.54 1992.15 S 1300.71 W 5966568.56 N 561013.81 E 8.882 2180.55 6898.65 63.000 248.070 6181.67 6283.27 2040.88 S 1401.89 W 5966518.99 N 560913.04 E 8.425 2291.87 6992.71 67.650 251 .230 6220.94 6322.54 2070.55 S 1482.01 W 5966488.66 N 560833.17 E 5.810 2375.13 7088.25 73.340 256.100 6252.84 6354.44 2095.80 8 1568.38 W 5966462.70 N 560747.01 E 7.650 2461.1 9 7183.03 81.410 261.320 6273.55 6375.15 2113.82 S 1658.98 W 5966443.92 N 560656.56 E 10.066 2546.82 7277.64 81.290 260.890 6287.78 6389.38 2128.28 S 1751.39 W 5966428.70 N 560564.28 E 0.467 2632.01 7371.54 78.1 70 262.820 6304.52 6406.12 2141.37S 1842.84 W 5966414.84 N 560472.94 E 3.890 2715.65 7467.20 83.220 264.650 6319.98 6421.58 2151.66S 1936.64 W 5966403.78 N 560379.23 E 5.606 2799.71 7562.49 84.700 266.880 6330.01 6431.61 2158.66 S 2031.13W 5966396.00 N 560284.80 E 2.798 2882.55 7657.17 86.430 269.570 6337.34 6438.94 2161.58 8 2125.47 W 5966392.29 N 560190.48 E 3.371 2963.02 7751.90 87.290 269.910 6342.52 6444.12 2162.01 S 2220.06 W 5966391.08 N 560095.91 E 0.976 3042.33 7843.93 84.200 269.200 6349.35 6450.95 2162.72 S 2311.82W 5966389.61 N 560004.15 E 3.445 3119.43 ( 7941 .29 84.330 268.610 6359.08 6460.68 2164.57 8 2408.68 W 5966386.95 N 559907.32 E 0.618 3201.42 8035.77 85.080 264.580 6367.80 6469.40 2170.168 2502.57 W 5966380.58 N 559813.48 E 4.321 3282.98 8130.41 85.260 262.650 6375.77 6477.37 2180.64 8 2596.28 W 5966369.32 N 559719.85 E 2.041 3367.08 8224.85 85.250 262.340 6383.58 6485.18 2192.948 2689.59 W 5966356.25 N 559626.65 E 0.327 3451.83 8320.01 84.580 262.030 6392.02 6493.62 2205.82 S 2783.50 W 5966342.58 N 559532.85 E 0.775 3537.40 8415.12 89.570 262.550 6396.87 6498.47 2218.56 8 2877.59 W 5966329.06 N 559438.86 E 5.275 3623.06 8509.92 91.540 262.730 6395.95 6497.55 2230.71 S 2971.60 W 5966316.14 N 559344.96 E 2.087 3708.31 8604.83 95.230 265.630 6390.35 6491.95 2240.32 S 3065.83 W 5966305.75 N 559250.81 E 4.941 3792.36 8699.93 92.590 265.940 6383.86 6485.46 2247.29 S 3160.45 W 5966297.99 N 559156.26 E 2.795 3875.29 8792.92 92.890 262.100 6379.42 6481.02 2256.96 S 3252.81 W 5966287.55 N 559063.98 E 4.137 3957.81 ." -.".. .--..-....."....,,--......--..-.-..----. . .--.-----.---...-..---."..--...-...-. """'-" 5 February, 2002 - 13:34 Page 4 of 6 DriflQuest 2.00.09.008 Spèrry-Sun Drilling Services Survey Report for 1C-24 Your Ref: 500292306300 Job No. AKZZ11218, Surveyed: 16 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8892.08 90.000 262.840 6376.92 6478.52 2269.95 S 3351.07W 5966273.75 N 558965.83 E 3.008 8986.46 85.080 261.250 6380.97 6482.57 2282.99 S 3444.42 W 5966259.93 N 558872.59 E 5.478 9079.48 81.100 258.740 6392.16 6493.76 2299.02 S 3535.34 W 5966243.15 N 558781.81 E 5.048 ( 9174.08 77.530 257.290 6409.70 6511.30 2318.32 S 3626.26 W 5966223.10 N 558691.05 E 4.063 9269.83 77.790 257.970 6430.16 6531.76 2338.36 S 3717.62 W 5966202.30 N 558599.86 E 0.745 9282.79 77.970 258.070 6432.88 6534.48 2340.99 S 3730.02 W 5966199.57 N 558587.49 E 1.581 9350.00 77.970 258.070 6446.89 6548.49 2354.57 S 3794.33 W 5966185.45 N 558523.29 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.031 ° (01-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 236.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9350.00f1., The Bottom Hole Displacement is 4465.53f1., in the Direction of 238.178° (True). Comments ( Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (1t) (ft) (ft) Comment 349.00 9350.00 348.99 6548.49 1.13 S 2354.57 S 1.37 E 3794.33 W Tie-on Point Projected Survey ..", ""-"-",,,,.-------""'.,-.-'-"-- --""-' ",...,.--......,""" 5 February, 2002 - 13:34 Page 5 of 6 Vertical Section 4047.08 4132.28 4217,09 4303.68 4391.06 4402.86 4464.08 . North Slope, Alaska Kuparuk 1 C Comment Projected Survey Oril/Quest 2.00.09.008 Kuparuk River Unit Survey tool program for 1 C-24 Fro m Measured Vertical Depth Depth (ft) (ft) (' 0.00 349.00 0.00 348.99 ( 5 February, 2002 - 13:34 To Measured Vertical Depth Depth (ft) (ft) 349.00 9350.00 348.99 6548.49 Sp.erry-Sun Drilling Services Survey Report for 1 C-24 Your Ref: 500292306300 Job No. AKZZ11218, Surveyed: 16 January, 2002 . North Slope, Alaska Kuparuk 1 C Survey Tool Description Tolerable Gyro (1 C-24 Gyro) AK-6 BP _IFR-AK (1 C-24) ... --'_0- -'-"'_-0___0-_-_- . ."""----"'----""'-_0-- Page 6 of 6 DrillQuest 2.00.09.008 "."..!,{)}-:~A Jr ",..,.,..,¡".""""".,!,,~-""1. ,," "';1",',',' ìl""""H.""';I",',..i, "\>":,~,'.n"c""",>i'"",, ", ", ",.. "'"", ",. ,-"", , "'" ' i¡ :1i 05-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-24 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 349.00' MD 'MD 9,350.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED FEB 0 7 2002 Alaska 0iJ & Gas Cons. Commilion Anchoraøe Attachment(s) ;, ~~) ( Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-24 1 C-24 MWD Job No. AKMM11218, Surveyed: 16 January, 2002 SURVEY REPORT ( 5 February, 2002 Your Ref: 500292306300 Surface Coordinates: 5968571.44 N, 562297.94 E (70019' 28.7732" N, 149029' 41.4448" W) Surface Coordinates relative to Project H Reference: 968571.44 N, 62297.94 E (Grid) Surface Coordinates relative to Stucture Referance: 49.59 N, 73.70 W (True) Kelly Bushing: 101. 60ft above Mean Sea Level sper'""'f""Y-sur, CRIL-L..ING SERVIC:::ES A Halliburton Company Survey Ref: svy9832 Sperry-Sun Drilling Services . Survey Report for 1 C-24 MWD Your Ref: 500292306300 Job No. AKMM11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 349.00 1.150 158.000 247.39 348.99 1.13 S 1.37 E 5968570.32 N 562299.32 E -0.52 Tie-on Point MWD Magnetic 480.38 1.490 184.990 378.73 480.33 4.06S 1.71 E 5968567.40 N 562299.69 E 0.532 0.79 572.68 2.390 188.710 470.98 572.58 7.15 S 1.32 E 5968564.30 N 562299.32 E 0.984 2.83 664.47 5.190 195.560 562.56 664.16 13.05 S 0.09W 5968558.39 N 562297.96 E 3.085 7.23 754.06 7.440 198.420 651.60 753.20 22.45 S 3.01 W 5968548.96 N 562295.12 E 2.535 14.84 845.41 8.080 189.450 742.12 843.72 34.40 S 5.93W 5968536.99 N 562292.29 E 1 .497 23.83 933.97 8.280 192.650 829.78 931.38 46.76 S 8.35W 5968524.61 N 562289.98 E 0.561 32.64 1031.18 10.350 191.080 925.70 1027.30 62.16 S 11 .56 W 5968509.19 N 562286.90 E 2.145 43.77 1125.40 14.320 187.860 1017.73 1119.33 82.02 S 14.78 W 5968489.30 N 562283.84 E 4.275 57.36 1220.69 13.840 188.510 1110.15 1211.75 104.96 S 18.08 W 5968466.33 N 562280.73 E 0.530 72.71 1313.00 14.590 189.510 1199.64 1301.24 127.35 S 21.64 W 5968443.92 N 562277.36 E 0.855 87.97 1407.55 17.000 192.270 1290.61 1392.21 152.60 S 26.54 W 5968418.62 N 562272.67 E 2.669 105.93 1502.63 19.580 194.630 1380.88 1482.48 181.61 S 33.52 W 5968389.56 N 562265.93 E 2.823 127.68 1597.89 21.510 197.120 1470.08 1571.68 213.75 S 42.69 W 5968357.35 N 562257.02 E 2.224 152.98 1694.18 21.850 199.700 1559.56 1661.16 247.49 S 53.93 W 5968323.51 N 562246.07 E 1.051 180.89 1789.58 21.600 200.590 1648.19 1749.79 280.64 S 66.09 W 5968290.26 N 562234.18 E 0.433 209.25 1886.17 22.250 201.870 1737.79 1839.39 314.25 S 79.16 W 5968256.54 N 562221.40 E 0.835 238.61 1980.99 23.990 201.700 1824.99 1926.59 348.82 S 92.97 W 5968221.86 N 562207.87 E 1.836 269.13 2075.82 24.410 203.170 1911.49 2013.09 384.75 S 107.81 W 5968185.81 N 562193.33 E 0.775 301.25 2170.34 24.940 203.570 1997.38 2098.98 420.97 S 123.46 W 5968149.46 N 562177.98 E 0.588 334.21 ( 458.1 0 S 2265.16 25.880 204.700 2083.02 2184.62 140.10 W 5968112.19 N 562161.64 E 1.115 368.50 2359.60 26.230 207.630 2167.87 2269.47 495.31 S 158.40 W 5968074.83 N 562143.66 E 1.412 404.21 2453.47 24.860 210.100 2252.56 2354.16 530.77 S 177.91 W 5968039.21 N 562124.44 E 1.848 439.98 2549.17 24.090 208.650 2339.66 2441 .26 565.31 S 197.37W 5968004.51 N 562105.27 E 1.020 475.20 2637.57 24.370 210.070 2420.28 2521.88 596.93 S 215.15 W 5967972.75 N 562087.75 E 0.731 507.42 2738.63 22.600 209.760 2512.96 2614.56 631.83 S 235.24 W 5967937.68 N 562067.95 E 1.756 543.37 2833.39 22.850 210.370 2600.37 2701.97 663.51 S 253.58 W 5967905.85 N 562049.88 E 0.363 576.08 2928.37 23.160 210.530 2687.79 2789.39 695.51 S 272.39 W 5967873.69 N 562031.33 E 0.333 609.37 3023.35 23.170 210.820 2775.11 2876.71 727.65 S 291.46 W 5967841 .40 N 562012.54 E 0.121 642.94 3118.35 23.590 211.900 2862.31 2963.91 759.83 S 311.08 W 5967809.05 N 561993.18 E 0.632 677.00 5 February, 2002 - 13:34 Page 2 of 6 DrillQuest 2.00.09.008 "- . Sperry-Sun Drilling Services Survey Report for 1 C-24 MWD Your Ref: 500292306300 Job No. AKMM11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 3212.97 24.560 211.370 2948.70 3050.30 792.70 S 331.32 W 5967776.02 N 561973.21 E 1.050 711.96 3307.39 25.500 211.990 3034.25 3135.85 826.69 S 352.30 W 5967741 .85 N 561952.51 E 1.034 748.15 3402.50 24.380 212.820 3120.49 3222.09 860.55 S 373.79 W 5967707.81 N 561931.31 E 1.234 784.70 ( 3497.13 22.360 212.990 3207.36 3308.96 892.07 S 394.18 W 5967676.13 N 561911.18E 2.136 819.04 3591.62 23.090 213.020 3294.51 3396.11 922.68 S 414.06 W 5967645.36 N 561891.56 E 0.773 852.46 3685.08 23.430 214.850 3380.38 3481.98 953.29 S 434.66 W 5967614.57 N 561871.21 E 0.855 886.48 3781.00 23.390 214.760 3468.40 3570.00 984.59 S 456.42 W 5967583.10 N 561849.71 E 0.056 921.84 3878.75 23.560 216.120 3558.06 3659.66 1016.31 S 478.99 W 5967551.19 N 561827.40 E 0.581 958.12 3971.31 23.650 217.580 3642.88 3744.48 1045.96 S 501.22 W 5967521.35 N 561805.42 E 0.639 992.97 4066.32 24.080 218.360 3729.76 3831.36 1076.26 S 524.87 W 5967490.85 N 561782.02 E 0.561 1029.37 4161.26 24.940 219.310 3816.15 3917.75 1106.94 S 549.57 W 5967459.98 N 561757.57 E 0.996 1066.86 4256.35 25.430 221.490 3902.20 4003.80 1137.75 S 575.80 W 5967428.95 N 561731.60 E 1.103 1105.69 4350.03 25.860 216.620 3986.66 4088.26 1169.21 S 601.32 W 5967397.27 N 561706.35 E 2.296 1144.28 4444.74 26.500 216.480 4071.65 4173.25 1202.78 S 626.20 W 5967363.50 N 561681.75 E 0.679 1183.51 4541.64 25.230 214.480 4158.85 4260.45 1237.19S 650.75 W 5967328.89 N 561657.49 E 1.590 1222.91 4635.07 25.450 215.150 4243.29 4344.89 1270.02 S 673.58 W 5967295.87 N 561634.93 E 0.387 1260.01 4677.48 25.560 216.030 4281.57 4383.17 1284.87 S 684.20 W 5967280.94 N 561624.43 E 0.930 1277.04 4822.32 25.350 216.550 4412.34 4513.94 1335.05 S 721.05 W 5967230.45 N 561588.00 E 0.212 1335.38 4916.81 25.180 216.020 4497.80 4599.40 1367.55 S 744.91 W 5967197.75 N 561564.40 E 0.299 1373.17 5011.55 24.790 215.340 4583.67 4685.27 1400.06 S 768.26 W 5967165.05 N 561541.33 E 0.511 1410.52 ( 5106.27 24.550 215.220 4669.74 4771.34 1432.33 S 791.09 W 5967132.59 N 561518.77 E 0.259 1447.31 5200.96 23.880 214.920 4756.10 4857.70 1464.12 S 813.41 W 5967100.62 N 561496.72 E 0.719 1483.41 5295.23 23.670 214.750 4842.37 4943.97 1495.31 S 835.12W 5967069.25 N 561475.27 E 0.234 1518.68 5390.59 23.770 214.320 4929.68 5031 .28 1526.91 S 856.86 W 5967037.47 N 561453.78 E 0.210 1554.20 5485.08 23.350 214.080 5016.29 5117.89 1558.15 S 878.09 W 5967006.06 N 561432.81 E 0.456 1589.09 5581.39 23.120 214.700 5104.79 5206.39 1589.50 S 899.55 W 5966974.52 N 561411.62 E 0.349 1624.23 5676.12 21.860 214.130 5192.31 5293.91 1619.39 S 920.03 W 5966944.47 N 561391.38 E 1.350 1657.76 5770.75 20.280 213.320 5280.61 5382.21 1647.68 S 938.93 W 5966916.02 N 561372.72 E 1.698 1689.08 5865.50 18.850 212.780 5369.89 5471.49 1674.27 S 956.24 W 5966889.29 N 561355.64 E 1.521 1718.14 5959.92 18.920 214.460 5459.23 5560.83 1699.72 S 973.16 W 5966863.70 N 561338.93 E 0.581 1746.25 5 February, 2002 - 13:34 Page 3 of 6 DrmQuest20aO~008 Sperry-Sun Drilling Services . Survey Report for 1 C-24 MWD Your Ref: 500292306300 Job No. AKMM11218, Surveyed: 16 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 Oaft) 6054.49 21.020 215.900 5548.11 5649.71 1726.10 S 991.78 W 5966837.16 N 561320.52 E 2.280 1776.29 6149.15 24.690 221.660 5635.33 5736.93 1754.64 S 1014.89 W 5966808.44 N 561297.66 E 4.536 1811.27 6242.88 29.210 224.160 5718.86 5820.46 1785.69 S 1043.85 W 5966777.15 N 561268.95 E 4.971 1852.52 I' 6337.22 33.080 229.040 5799.60 5901.20 1819.10 S 1079.35 W 5966743.45 N 561233.73 E 4.895 1900.53 \ 6432.06 37.180 232.010 5877.16 5978.76 1853.72 S 1121.50 W 5966708.47 N 561191.87E 4.683 1954.76 6525.59 41 .540 236.280 5949.4 7 6051.07 1888.35 S 1169.60 W 5966673.44 N 561144.06 E 5.485 2013.98 6620.02 45.740 240.140 6017.80 6119.40 1922.59 S 1225.00 W 5966638.74 N 561088.94 E 5.265 2079.09 6716.89 50.560 242.380 6082.42 6184.02 1957.23 S 1288.27 W 5966603.58 N 561025.96 E 5.265 2150.98 6766.78 54.190 243.940 6112.87 6214.47 1975.05 S 1323.52 W 5966585.47 N 560990.86 E 7.686 2190.24 6898.65 63.000 248.700 6181.55 6283.15 2019.99 S 1426.54 W 5966539.68 N 560888.22 E 7.354 2301.02 6992.71 67.650 250.580 6220.81 6322.41 2049.69 S 1506.65 W 5966509.31 N 560808.35 E 5.266 2384.29 7088.25 73.340 253.870 6252.70 6354.30 2077.13 S 1592.38 W 5966481.16 N 560722.86 E 6.782 2471.01 7183.03 81.410 259.810 6273.42 6375.02 2098.08 S 1682.33 W 5966459.46 N 560633.08 E 10.480 2557.71 7277.64 81.290 260.830 6287.65 6389.25 2113.81 S 1774.53 W 5966442.97 N 560541.01 E 1.073 2643.42 7371.54 78.170 263.170 6304.39 6405.99 2126.68 S 1866.01 W 5966429.35 N 560449.65 E 4.129 2726.96 7467.20 83.220 264.450 6319.85 6421 .45 2136.84 S 1959.83 W 5966418.40 N 560355.92 E 5.442 2810.97 7562.49 84.700 268.980 6329.89 6431.49 2142.27 S 2054.41 W 5966412.19 N 560261.39 E 4.976 2893.01 7657.17 86.430 269.280 6337.21 6438.81 2143.70 S 2148.79 W 5966409.98 N 560167.02 E 1.854 2972.70 7751.90 87.290 268.060 6342.40 6444.00 2145.90 S 2243.35 W 5966406.99 N 560072.48 E 1.574 3052.96 7843.93 84.200 267.330 6349.22 6450.82 2149.58 S 2335.04 W 5966402.54 N 559980.82 E 3.450 3131.64 ( 7941.29 84.330 267.550 6358.95 6460.55 2153.91 S 2431.82 W 5966397.41 N 559884.09 E 0.261 3214.91 8035.77 85.080 264.070 6367.67 6469.27 2160.79 S 2525.63 W 5966389.76 N 559790.34 E 3.752 3297.11 8130.41 85.260 262.440 6375.64 6477.24 2171.86 S 2619.27 W 5966377.91 N 559696.79 E 1.727 3381.48 8224.85 85.250 261.750 6383.46 6485.06 2184.81 S 2712.50 W 5966364.19 N 559603.68 E 0.728 3466.51 8320.01 84.580 262.070 6391.89 6493.49 2198.14 S 2806.34 W 5966350.07 N 559509.95 E 0.780 3552.29 8415.12 89.570 263.060 6396.74 6498.34 2210.43 S 2900.49 W 5966337.01 N 559415.90 E 5.348 3637.74 8509.92 91 .540 262.740 6395.82 6497.42 2222.15 S 2994.56 W 5966324.51 N 559321.93 E 2.105 3722.81 8604.83 95.230 266.530 6390.22 6491.82 2231.01 S 3088.85 W 5966314.87 N 559227.71 E 5.568 3806.50 8699.93 92.590 264.130 6383.73 6485.33 2238.73 S 3183.40 W 5966306.35 N 559133.23 E 3.748 3889.78 8792.92 92.890 261.580 6379.29 6480.89 2250.29 S 3275.56 W 5966294.04 N 559041 .18 E 2.758 3973.16 5 February, 2002 - 13:34 Page 4 of 6 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services Survey Report for 1C-24 MWD Your Ref: 500292306300 Job No. AKMM11218, Surveyed: 16 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8892.08 90.000 262.820 6376.79 6478.39 2263.74 S 3373.76 W 5966279.77 N 558943.09 E 3.171 8986.46 85.080 262.020 6380.84 6482.44 2276.17 S 3467.20 W 5966266.56 N 558849.76 E 5.281 9079.48 81.100 258.240 6392.03 6493.63 2291.98 S 3558.14 W 5966250.00 N 558758.95 E 5.880 (' 9174.08 77.530 257.080 6409.57 6511.17 2311.84S 3648.94 W 5966229.39 N 558668.32 E 3.961 9269.83 77.790 257.960 6430.03 6531.63 2332.05 S 3740.26 W 5966208.42 N 558577.17 E 0.938 9282.79 77.970 258.020 6432.75 6534.35 2334.69 S 3752.66 W 5966205.68 N 558564.79 E 1 .461 9350.00 77.970 258.020 6446.76 6548.36 2348.33 S 3816.96 W 5966191.50 N 558500.61 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.031 ° (01-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 236.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9350.00f1., The Bottom Hole Displacement is 4481.50f1., in the Direction of 238.399° (True). Comments ( Measured Depth (ft) Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 349.00 9350.00 348.99 6548.36 1.13 S 2348.33 S 1.37 E 3816.96 W Tie-on Point Projected Survey Vertical Section 4062.64 4147.58 4232.28 4319.08 4406.52 4418.33 4479.58 . North Slope, Alaska Kuparuk 1 C Comment Projected Survey 5 February, 2002 - 13:34 Page 5 of 6 DrillQuest 2.00.09.008 . , . Kuparuk River Unit Survey tool program for 1 C-24 MWD From Measured Vertical Depth Depth (ft) (ft) ( 0.00 349.00 0.00 348.99 ( To Measured Vertical Depth Depth (ft) (ft) 349.00 9350.00 348.99 6548.36 Sperry-Sun Drilling Services Survey Report for 1 C-24 MWD Your Ref: 500292306300 Job No. AKMM11218, Surveyed: 16 January, 2002 . North Slope, Alaska Kuparuk 1 C Survey Tool Description Tolerable Gyro (1 C-24 Gyro) MWD Magnetic (1 C-24 MWD) 5 February, 2002 - 13:34 DrillQuest 2.00.09.008 Page 6 of 6 \ J!1'~ It n 4- ." STATE OF ALASKA "J. 1 s }vY D «.0 ,) 2) 0 3 ¿; ,..f; ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS (il ,\ 1. Type of request: AOan~on- Suspend- Alter casing - Repair well - Change approved program _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1666' FNL, 3987' FEL, Sec. 12, T11 N, R10E, UM At top of productive interval At effective depth At total depth 4022' FNL, 2506' FEL, Sec. 11, T11 N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 161' 16" SURFACE 4609' 9-5/8" PRODUCTION 6733' 7" LINER 2706' 4-1/211 LINER Perforation depth: Operalional shutdown - Plugging - Pulilubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service (asp's 562298,5968571) (asp's 558523, 5966185) 9350 feet 6548 feet Plugs (measured) '¡:~~Q:S~û, '( '~\C~Oê..\ Re-enter suspend&dweU - " '" ,,', TIme extension - Stimulate - ,':':.:: :':': , , , , , , " , "",' " ,'. Variance - Perforate - :':: :::::.:'O::Qttier.:.:. ' 6. Datum elevation (DF or KB feet) RKB 102 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-24 9. Permit number I approval number 201-248 V 10. API number/ 50-029-23063 11. Field I Pool Kuparuk Oil Pool Measured Depth 161 ' 4711' 6835' 9350' True vertical Depth 161' 4413' 6252' 6548' feet feet Junk (measured) 7485~7520;7550'7670; 77OQ~7885:~945'8015;8065.8090;8500-8600;865~7~ 8800-8900; 8950-9150; 9180-9215 ~~t: 6424-6427; 6430.6440; 6441-6455; 6461-6468; 6472-6474,6498-6492, 6488-6483 measured true vertical Cemented Tubing (size, grade, and measured depth ~81-6479;6480.6506:6513-6520 4-1/2", 12.6#, L-80 Tbg @ 6654' MD. EI Mt\R 0 ? 2002 Packers & SSSV (type & measured depth) Alaska Oil & Gas Cons. Commission BAKER 4.5" X 7" ZXP LINER TOP PACKER W/HOLDDOWNS, HR PROFILE @ 6658' MD. Anchorage CAMCO DB NIPPLE WITH 3.812 NO GO PROFILE @ 517' MD. 13. Attachments Description summary of proposal -2C Detailed operations progra'm 14. Estimated date for commencing operation 15. Status of well classification as: 02/22/02 2/20/02 Name of approver Tom Maunder Datta approved Service- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . 1:./ - /) t:- V ~~ . J~ ~P?~¡/~~ Signed ~ ~ Title: Production Éngineering Supervisor J A. S sneer 16. If proposal was verbally approved Oil_X BOP sketch - Gas- Suspended - Questions? Call Jeff Spencer 659-7226 Date ..3 /Ø ~ Robert Christensen 659-7535 ---, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10-~CJ"\ , Original Signed By Cammy OãCfišTi ('.\ ["'\ t""""" í !i.../ : , ~, " " , I " \, 'I', [""'1 ¡ ~.~..".I .!~, "",j' f A roved bY5>rder of .!...~.gommission Form 10-403 Rev 06/15/88 . t- ---j Approval no. ~)..,- ð~Li : Commissioner Date 3/ 'X 10 6. SUBMIT IN TRIPLICATE 1 C~24 { DESCRIPTION SUMMARY PROPOSAL Phillips Alaska Inc. request approval to pre-produce well 1 C-24. This well was completed on January 28, 2002 for injection service. The well was produced for a short period with signification oil production. The pre-production period is estimated to continue until July 15,2002 or until the watercut reaches 1000/0. ( ( ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY " TUBING (0-6654, OD:4.500, ID:3.958) SEAL (6642-6643. OD:4.750) Perf (7485-7520) Perf (7550-7670) Perf (7700-7885) Perf (7945-8015) Perf (8065-8090) Perf (8500-8600) Perf (8650-8750) Perf (8800-8900) Perf (8950-9150) Perf (9180-9215) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ....... ¡: i ,j " , ",< ',' ^ ,. ',:i1! " ,. , ..., I. ,.' ,>; .' , , ,., "0 - Pi": ,:"';t?k :,: - - - - - - - - - - - - - - - - - - f---- ~ r-- ~ ~ r-- r-- - - - - - ,] ¡ , , .... 1C-24 Well Type: SVC Oria Completion: LastW/O: Ref Log Date: TD: 9350 ftKB Max Hole AnQle: 0 deg @ API: 500292306300 SSSV Type: Nipple Annular Fluid: Reference Loq: Last Taa: Last Taa Date: Casino SbinQ - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 LINER 4.500 Tubing String- TUBING Size I Top 4.500 I 0 Peï'fóratlons Summålrv ',' Interval TVD 7485 - 7520 7485 - 7520 7550 . 7670 7550 . 7670 7700 - 7885 7700 ' 7885 7945-8015 7g.¡5-1j015 6065 - 8090 &065 - 8090 8500 - 8600 8500 . 8600 6650 - 8750 8650 - 8750 8800 - 8900 8800 - 8900 8950-9150 8950.9150 9180-9215 9180-9215 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2712 2712 CAMCO KBG-2 2 4146 4146 CAMCO KBG-2 3 5188 5188 CAMCO KBG-2 4 5950 5950 CAMCO KBG-2 5 6557 6557 CAMCO KBG-2 Other'fplugs equip., etc.) - JEWELRY Depth TVD Type 517 517 NIP 6602 6602 NIP 6641 6641 LOCATOR 6642 6642 SEAL 6654 6654 TTL Other I plugs equip., etc.) - LINER Depth TVD Type 6658 6658 PKR 6666 6666 HANGER 9250 9250 COLLAR 9282 9282 COLLAR 9343 9343 SHOE Top 0 0 0 6644 I Bottom I TVD I Wt I 6654 I 6654 I 12.60 '., ' ,',', ':" Zone Status Ft SPF 35 4 120 4 185 4 70 J 2S 4 100 4 100 J 100 .\ 200 .1 35 .1 KRU Bottom 161 4711 6835 9350 " Date 1/24/2002 1;24/2002 1/2J,2002 1/2J'2002 1/24/2002 1/2-1/2002 1/24/2002 1124/2002 1/24/2002 I/2J/201)2 1 C-24 AnQle @ TS: deq @>. Anale @. TD: deg @ Rev Reason: New Well by ImO Last Update: 1/30/2002 TVD 161 4711 6835 9350 Wt Grade Thread 62.58 ~PI5LGrB PEB 40.00 L-aO BTC 26.00 L-aO BTC-MOD 12.60 L-aO NSCT " I Grade I I L-80 I ",':::, , ':' , Type IPERF IPERF 'PERF IPERF ¡PERF IPERF 'PERF 'PERF IPERF 'PERF Thread IBT MOD " ", : ~ '., ' , ' Comment 2.5".0.32" Shot, 120 dea ph 25" 0 32" Shel, 120 deq ph 25'.03.2" Shot 120 de-a pn 25 .032" Shot. 120 dea ph 2 5- 03,2" Shol. 120 aea eh 25'.032" Shot. 120 dea ph 2 fi 032' Snol. 120 dea pn 25" 032" Snel, 120 de<llJh 2 5 0 J,2" Shol. 120 de<! en 25" 0 32'" St'lol, 120 deQ pn V Mfr V Type V OD Latch Port TRO Vlv Cmnt DMY DMY DMY DMY SOY 1.0 1.0 1.0 1.0 1.0 BK-5 BK-5 BK-5 BK-5 BK-5 0.000 0.000 0.000 0.000 0.000 Description CAMCO DB NIPPLE WITH 3.812 NO GO PROFILE CAMCO DB NIPPLE W/3.75 NO GO PROFILE BAKER NO GO LOCATOR BAKER GBH-22 SEAL ASSEMBLY 0 0 0 0 0 Date Run 1/21/2002 1/21/2002 1/21/2002 1/21/2002 1/21/2002 ID 3.812 3.750 3.840 3.840 3.958 Description BAKER 4.5" X 7" ZXP LINER TOP PACKER W/HOLDDOWNS HR PROFILE 4.5" BAKER HMC LINER HANGER 4.5" BAKER LANDING COLLAR NSCT 4.5" BAKER FLOAT COLLAR 4.5" BAKER FLOAT SHOE NSCT ID 3.880 3.990 1.810 0.000 0.000 ;¡ ~1f~1fŒ (ID~ ~~~~~~ ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 333 w. -¡nt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 1 C-24 Phillips Alaska, Inc. Permit No: 201-248 Sur. Loc. 1668' FNL, 1289' FWL, SEC. 12, TIIN, RI0E, UM Btmhole Loc. 1269' FSL, 2280' FEL, SEC. 11, TIIN. RI0E, UM Dear Mr. Mallary, Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 1 C pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION , DATED this 26th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PHILLI~S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY /' ',ì ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Thomas Brockway Phone (907) 265-4135 Fax: (907) 265-1535 Email: tbrockw@ppco.com December 19, 2001 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 1 C-24 Dear Commissioner Taylor: "'......- -] Phillips Alaska, Inc. hereby applies for .a/'ermit to Drill an onshore .njectQ.1' well, KRU 1 C-24, a development well. The well will initiallybe produced, while faciliti s h .€)¡{-ups are being installed. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or re~uire any further information, please contact Scott Lowry at 265-6869. Sinc/, ~./ c/ ///~¿;¡ ¿" , f ¿. fl1-,.1!¿¡7 Tom Brockway /" Interim Drilling Engineering Supervisor (Chuck Mallary on vacation) C €. \\J€. Ü ~~ "'~IÇ C 1 ~ 1\)~~ \ ¡ \.,. >- ~\SS\'ÍJi .~ &. G3S~ \, \(~S~f)O\ ~t\ð\0\~- ORIGINAL 9. Approximate spud date December 31, 2001 14.. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Maximum surface 2752 psig At total depth (TVD) 3456 psig Setting Depth ( I , STATE OF ALASKA \ ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Drill J Redrill DDeepen D 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas D Single Zone œ .hl) 5. Datum elevation (DF or KB) RKB = 41 feet 6. Property Designation ADL 25649 ALK 467 7. Unit or property Name Kuparuk River Unit 8. Well number 1 C-24 1a. Type of work: Re-entry 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1668' FNL, 1289' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1456' FSL, 528' FEL, Sec. 11, T11N, R10E, UM At total depth 1269' FSL, 2280' FEL, Sec. 11, T11 N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 1269' @ TD feet 1C-23 @ 14.8' @ 8' 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size feet Maximum hole angle 87.5 Top Bottom TVD 121' 4379' 6185' 6512' Hole 24" Casino 16" Specifications Grade CouplinQ H-40 Weld L-80 BTC L.80 BTCM L-80 NSCT 41' 6586' Weicht 62.5# 40# 26# 12.6# LenQth 80' 4633' 6695' 2535' MD 41' 41' TVD 41' 41' 41' 6085' MD 121' 4674' 6736' 9121' 12.25" 9.625" 8.5" 7" "'.itS" 4.5" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: Plugs (measured) measured true vertical feet feet Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface 0 Length Size Cemented Measured depth \I-l GA rz-Iz..¡¡ 0 { ~ ,t' ~~ 1}\ '.$ Development Oil U Multiple Zone D 10. Field and Pool Kuparuk River Field Kuparuk Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 9121' MD /6512 I TVD Quantity of Cement (include staae data) 420 sx 15.8 ppg AS 1 650 sx AS Lite & 300 sx LiteCrete 170 sx Class G 360 sx GasBloc True Vertical depth RECEIVE"".' ~.'.'.") ~ . .71 ~.~. Perforation depth: measured DEC 1 920P1 true vertical f\laska Oil & Gas ConS. CommiSSirN' Anchorage 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid prograr:97 0Time vs depttywlot Defraction analysis DSeabed report D 20 AAC 25.050 requirements 0 21. I hereby c~. ertify t f'A'. e forego~ ~ ,~n c rrect £"~¿e ,esÄ :y, (::;~dge -ŒuestlOns? Call SCO~~OW'ì 265;869 Signed /,n--" -~.? Ú ~ 7 ¿. Titl6: Drilling Engineering Supervisor Date! r/- /!I /01 Chuck Mallarv 1111 -. JI II_. --.n,.""£-",, Commission Use Only Permit Number r? /'ì (-- 7-/ /;') API number, /:]. 3 ".I Q /V" ApprovaLPa~ I., I See cover le~er ~ Yb 50- 02-~/-:2-. OCO,."d--c..-c....) 10./;) (ð/'" I for other reqUIrements. Conditions of approval Samples required D Yes ~ No Mud log n!quired ra/' DYes N No Hydrogen sulfide measures ~es D No Directional survey required Jð\ Yes D No Required working pressure for BOPE U2M; D 3M; D 5M; 0 10M; 0 D O~Te~ t BoP E io 50,00 f) <;..~ j C eVK t?-vLt- G! U&;vL,¿ ~ L,{J C] .:' ¡Vz L Y' ..- by order of Approved by UKII 'AI ~1-"IJ=n B'f Commissioner the commission FoRn 10-401 Rev, 12/1/85' D Taylor seamoÕ RIG I N A L Date I~/~lolo I , , Submit in triplicate 'j 1,1 "", Ap"":r;ation for Permit to Drill, Well 1 C-24 t Revision No.O Saved: 19-Dec-01 Permit It - Kuparuk Well 1 C-24 Application for Permit to Drill Document MoximizE Well \!ol~1; Table of Contents 1. Well Name.............. ........................................................ .............................. ............. 2 Requirements of 20 AAC 25.005 (f)........................................................................................................ 2 2. Location Sum mary .... ............ .................................. ..................................... ....... ..... 2 Requirements of 20 AAC 25. 005( c)(2) ............................................................................................. ......2 Requirements of 20 AAC 25.050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) ..........................................................................................,........ 3 4. Dri II i ng Hazards Information... .................. .............................................................. 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementi ng Program............................. ................... ... ..........................4 Requirements of 20 AAC 25. 005( c)(6) ................................................................................................... 4 7. Diverter System Information ............................. ...................................................... 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Prog ram ............................... ............... ... ...... ................................... ... 4 Requirements of 20 AAC 25. 005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 C). Seismic Analysis...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng .. ....................................................... ...................................... 5 Requirements of 20 AAC 25.005 (c)(12) """""""""""""""""""""""""""""".................................... 5 13. Proposed Dri II i ng Program............................................. ......................... ............... 6 ORIGINAL 1C-24 PERMIT IT.DOe Page 1 of 7 Printed: 19-Dec-O1 :r," \ Ap....o:r:ation for Permit to Drill, Well 1 C-24 '~ Revision No.O Saved: 19-Dec-01 Requirements of 20 AAC 25.005 (c)(13) """"""""""""""""""""""""""""""""""""'"..................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments......................... .................. ......................... ......................................... 7 Attachment 1 Directional Plan """""""""""""""""""""""""""""""""""".......................................7 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic..............................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name de5~qnated by the operator and a unique API number assigned by the comml!:,-s-ion under 20 AAC 25. 040(b). For c1 well with multiple well branche!;,~ each branch must similatly be Identified by a unique name and API number by adding a sulfìx to the name des7fJ/7ated for the well by the operator and to the number aSSlfJl7ed to me well by the commi5..<;;ion. The well for which this application is submitted will be designated as lC-24. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application (vr a Permit to Drill must be accompanied by eaäl of'the following item~ except for an item already on file wIth the commission tmcf Identified li7 the applic.otion: (2) a plat Identifyli7g the property and the propmfy's owners and showing (A)the L"'oordinatt;s o{ tIlt! proposed location ot' the well at thi:; surféce/ at the top of each oL?Jective formation and at total depth referenced to governmental section lines. (8) tl7e coordli7ates of tile proposed location of the well at the sur-rac(:;"j referenced to the state plane coordinate system for thl:"- state as maintained by the National Geodetic S'urvey in the National Oceanic and Atmospheric Adminls-tration/ (C) tile proposed depth of the well at the top of each objective {ormation and at total depth/ Location at Surface 11668' FNL, 1289' FWL, See 12, TllN, Rl0E, UM NGS Coordinates RKB Elevation 101.6' AMSL Northings: 5,968,571 Eastings: 562,298 Pad Elevation 60.3' AMSL Location at Top of Productive Interval Ku aruk "C4" Sand NGS Coordinates Northings: 5,966,400 1456' FSL, 528' FEL, Sec 11, T11N, Rl0E, UM Eastings: 560,500 7355' 6392' 6290' Location at Total De th 1269' FSL 2280' FEL NGS Coordinates Northings: 5,966,200 Eastings: 558,750 9121' 6512' 6410' and (0) other information reqUli'ed by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) It' a well is to be intentionally deviate~ the application for a PermIt to Onll (Form 10.-401) must (1) ¡¡7e1ude a pla~ drawn to a sUItable scak~ showing the path of the propo:.1;?d wellbofí::/ ¡¡7e1uding all adjacent wellbores within 200 feet of any portion oft/7e pmpO!!ied wel¿' Please see Attachment 1: Directional Plan ORIGINAL 1C-24 PERMIT ITDOC Page 2 of 7 Printed: 19-Dec-O1 ,( ,~ A?",lõr:ation for Permit to Drill, Well 1 C-24 ,~ Revision No.O , Saved: 19-Dec-01 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wei!,:>~ to the extent that those names are known or discoverable li7 public record:,-- and show tflat each named operator has been furnished a copy of the application by certified mai¿' or (B) state that the applicant is tfle only afTected mo/ner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pennit to Drill must be accompanied by ead7 of the followti7g Item5~ except for an Item already on file with the commission and identified If¡ the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 2.'i,03~ 20 AAC 2.'i.03tÝ¡ or 20 AAC 25. 037, as applicable; Please reference BOP schematics on file for Nabors 245E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following Item5~ except for an item already on file with the commi..'i..c,ion and identitìed in the application: (4) information 017 ellilling hazards/ ineil/ding (A) the maxtinum downhole prð"Sure that may be ef1couf7tere(~ cntelia used to detel7nine if., and maxlinum potentt<.ll sl/rt"ace pressure based on a methane gradient; Based on offset well data, the expected reservoir pressure in the C-4 Kuparuk sand for 1C-24 is -3500 psi at 6500' tvd, 0.54 psi/ft or lOA ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 1C-24 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the C-4 Kuparuk sand target at 6400' tvd: MPSP =(6400 ft)*(0.54 - 0.11 psi/ft) = 2752 psi (8) data on potential gas z()ne$~' The well bore is not expected to penetrate any gas zones. and (C) data c'Onæminq potentläl caw,"!.';." of hole pmiJlems such as abnormally geopresslJred stratal lost circulation zones/ and zones that Imvé? a pf'Opensity for differential stk:;king; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to 01711 must be accompanied by each or the following item~ except for an item already on fìle with the commission and Identified in the application: (5) a description ot'the procedure for conducting formation integrity test~ as required under 20 MC 25. 030(f); j'/ Drill out surface and intermediate casing shoes and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. ORIGINAL 1C-24 PERMIT IT DOC Page 3 of 7 Printed: 19-Dec-O1 I' ~. Agt::'i~ation for Permit to Drill, Well 1 C-24 l Revision No.O , Saved: 19-Dec-01 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by ead¡ of the following item5~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25, 030/ and a description of any slotted line~ pre- perforated line~ or screen to be lÌ¡stallect' Casing and Cementinq Program I Hole Top 8tm Csg/Tbg Size Weigh Length MO/TVO MO/TVO 00 (in) (in) t (lb/ft) Grade Connection (ft) (ft) (ft) Cement Proqram 16 24 62.5 H-40 Welded 80' 41'/41' 121'/121' 420 sx 15.8 ppg ASl 9-5/8 12-1/4 40 L-80 BTC 4633' 41'/41' 4674'/ 4379' Lead: 650 sx 10.7 ppg AS Lite Tail: 300 sx 12.0 ppg 'LiteCRETE' . (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 6695' 41'/41' 6736'/ 6185' 170 sx 15.8 ppg 'G' w/ add. Planned TOC=5936' 4-1/2* fø - ~/?; 12.6 L-80 NSCT 2535' 6?~g' / 6085' 9121'/ 6512' 360 sx 15.8 ppg --¡; 1? 10- 'GasBLOK' slurry 4-1/2 12.6 L-80 BTC-M 6545' 41'/41' 6586'/ 6085' *2 x 4-1/2" external casing packers may used if mud losses are encountered across the fault zone between the UT C3 and DT C4 target sands. If used, the ECP's will be inflated with cement. 7" casing will be top-set above the Kuparuk sands at the base HRZ, and a 4 '12" production liner will be . used and an exception to 20 MC 25.412 (b) is requested. The distance between seals at the top of the /' 4 '12" liner and the top perforaÿon will exceed 200' MD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. A "long-string" design will not be attempted for two reasons: 1) Recent history on 1C/1D pads indicates a low probability of ability to long-string. 2) Running the 4 '12" liner should allow rotation and reciprocation of pipe while cementing, which should improve quality of the cement job. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application tor a Permit to Drill must be accompanied by each of the following items~ except for an item already on l'ì/e with the commission and Identifïed in the application: (7) a diagram and descdption o(the dlverter system as required by 20 AAC 25.03~ unless tllis requirement is waived by the commission under 20 MC 25.03.'i(h)(2)/ Please reference diverter schematic on file for Nabors 245E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by eaä7 of the tollowing item5~ except tor an Item already on file with the commission and identitìed in tile application: (8) a dnlling fluid prograrn Indllding a diagram and desaiptlon of'the drilling fluid system/ as reqwi-ed by 20 AAC 25, 033; Drilling will be done using mud systems having the following properties: ORIGINAL 1C-24 PERMIT ITDOC Page 4 of 7 Printed: 19-0ec-O1 " ( AV'. "~ation for Permit to Drill, Well 1 C-24 '\ Revision No.O Saved: 19-Dec-01 Spud to surface Intermediate Production casinq point Hole Hole Extended bentonite Freshwater LSND Freshwater LSND slurry Initial 1 Final Density (DDO) 8.5-9.4* 9.31 10 PPQ 10.7 Funnel Viscosify(sec) 75-200** 40-55 1 40-55 40-55 Yield Point (cP) 18-60 5-81 20-27 20-27 Plastic Viscosity 8-30 6-131 14-25 14- 25 (lb/lOO sf) 1 0 see. Gel (lb/lOO 10- 30 3-7/4-7 4-7 sf) API Filtrate (cc) 5-15 <6 1 <6 <6 PH 8-9 9-10/9-10 9-10 Solids (%) 5-11 4-10/6-12 6-12 *9.8 ppg if hydrates are encountered **Spud mud should be adjusted to a FV between 200-300 sec/qt to drill gravel beds Diagram of Nabors 245E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application far a Peffmt to Drill must be accompanied by each of the following Items, exa?pt fof' an item already 017 fik? with the commi.,',:çion ami Identified in tl7e applk:atiol7: (9) for an e,<ploratvry or stratigraphic test wel¿ a tabulation setting out the depths ofprediäed abnormally geo-pres..';ured strata as required by 2() AAC ;?'J:{)33(f); NI A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application far a Pel7mt to Drill must be accompanied by eaä7 of the following Item"i¡ except for an Item already on file with the commission ami identified in the application: (10) lor an exploratory or stratigraphic test well a seismic refraction or reflection analySt:<; as required by 20 AAC 25. 061 (a).: Nj A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit tv Drill must be accompanied by each of the fòllowin,q l!em5~ except For an Item already on file with the cvmml..<,:sion and identitied in the application: (11) for a well dlilled finm an offs1lore platforrn mobile bottom-f'ounded 5tTUctUrt~ jack-up dg/ or floating drilling vesse¿ an analysis o(!;t-eabed conditions as required by 20 AAC 25,061(b)¡, Nj A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applic<.-7tkm for a Permit to Drill must be accompanied by each of the following items~ except For an item already 017 file with the commi!>"..<;;ìon and Identified in the application: (12) evidence s'flowing ttlat the requirement,,- of 20 AAC 25.025 {Bonding}l7ave been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. ORIGINAL 1 C-24 PERMIT IT. DOC Page 5 of 7 Printed: 19-Dec-O1 { Af'" "~ation for Permit to Drill, Well 1 C-24 " Revision No.O Saved: 19-Dec-01 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dr/II must be accompanied by each of the fallowing items¡ except far an item already on file wIth the cofmm~c;sion and Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 245E. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run MWD/LWD logging equipment for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surfaE'",'?1f;ement does not circulat~.Jo surface, perform stage or top job. Install and test BOPE to OO!)' psi. Test casing to 2500 psi. 5. Drill out cent and 20'-50' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill ~-1/~" hole to .ba~e HRZ accordi~g to directiona~ plan. Run M~.9'L"YD log~i~g equipment,) for directional monitoring and formation data gathering. <1Æ:?¡~/Ye::..c...hbr14. ¿ fl.~ 7. Ru.n and cement 7" 26#, L-80 BTC-Mod intermediate casing string. Pressure test casing to 3~O pSI. Note: If significant hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Drill o~tement and 20'-50' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW.. 9. Drill 6-1/8" hole to TD according to directional plan. Run MWD/LWD 10, ggi9~ eqUip,m, eJ1,t for fJ directional monitoring and formation data gathering. r;}/</ k::&5/ .l;J¡re.-c -f?'¡p-J'¥-? " 10. Run 4-1/2" 12.6#, L-80 NSCT liner on drill pipe with Baker liner top packer and hanger and ..-4 cement liner. /' 11. Clean out liner and run drill pipe conveyed cement bond log. Pressure test liner to 3500 psi. 12. Perforate using drill pipe conveyed guns. 13. Run 4-1/2" 12.6#, L-80 BTC-MOD completion string. Sting into polished seal bore with seal assembly and pressure test annulus to 2500 psi. 14. Set TWC and ND BOPE. Install and pressure test production tree. 15. Secure well. Rig down and move out. 16. Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applic.'ation fÒr a Permit to On!/ mastc be accvmpanied by eacf¡ oltl7e fiJI/owing Item!J~ except for an Item already on file wIth the commission and Identified in the application: (14) a general descl1i.Jtion ()fhow the operator plans to dl'ipose ofdnlling mud and cuttings and a statement or whether the operator intends to request autl7orizatkJI7 under 20 AA C 25, 080 for an annular disposal OperFltton In the well. / Waste fluids generated during the drilling process will be disposed of down a permitted annulus on lC pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on lC pad, hauled to a KRU Class II disposal well, or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit lC-24 for annular pumping of fluids occurring as a result of future drilling operations on lC pad. ORIGINAL 1C-24 PERMIT IT DOC Page 6 of 7 Printed: 19-Dec-O 1 i 'I 'c AV""'~ation for Permit to Drill, Well 1 C.24 ~: Revision No.O Saved: 19-Dec-01 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. ORIGINAL 1 C-24 PERMIT IT DOC Page 7 of 7 Printed: 19-Dec-O 1 900 1800 2700 4500 5400 6300 .t:: 0 0 0") II 7200 .s::. u .£ 'Iii";"" I ",'"ii"" ,'t<,¡..liiS.'\it'¡'"il",S¡',\¡ L"",'!'\\ï, 0 "i ( Kuparuk River Unit North Slope, Alaska Kuparuk 1C 1 C-24 WPO3A Begin Dir @ 1.000011001t : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 1.5000/100ft: 600.00ft MD, 599.86ft TVD Increase in Dir Rate @ 2.000"/100ft : 800.00ft MD, 799.22ft TVD Increase in Dir Rate @ 3.5000/100ft: 1250.00ft MD, 1241.23ft TVD Increase in Dir Rate @ 4.00001100ft : 1490.94ft MD, 1470.48ft TVD End Dir, Start Sail @ 24.007° : 1578.95ftMD,1551.79ftTVD ~~<) $ Cy {}." ~~ Drill out 8W' Hole.f' ~ "J-~ E' ~'t/:> ~~~ ~Q ~<::> e'? <ö ~ I;í< ^' -~ ^' -,¡;:.- íO" ~". e'?V? O:>~ c{f~",r¡; c:j rf' rß5 ri:" J." íOcp.~C). .;.CJ} .;.. "cs ¡> , ~' ~ ~ ,;.0:) <ö ~~\ ,;.~ .:;<...f-Ø .~#~~.$?' cs .;.' ~- 'è! ~~;¡;. ~-~- -0 m..íO' ",1;> t;::,':5 (~?' rf.p' íO(\.~ cpCY ~ w 50 1'\ CV' <ö " ,.,.. ^~ ~ '. ;(,'6 ° ' , 'io" . CO "íO' cpO:> -:Z. v !::) '.f:> COo"þO:>o" "Ú'f:' (\. <9 ~~ ",<1; ~. ro" " ~ ~ 0ðJ 'þ "cs cgy ç§5 ~':5 ~~ "C) .~ @¡ ~\ @ o\' CO o\? ct'. ~ (;)cs .~ ~C) @ ~ @ Cj e'?' VJ'P' CS ~ (;)cs.~ 7 " Casing ¿,r;- @¡ ~ e'?' Cj e'?' VJ'P' 6736.04ft MD ~ Q~ q'P' . ~ @ ~¿,r;- @ ~r;- (;. 6184.60 TVD ^~' .~ .~, Q" g çJ ~ J ~ 'òv ~ <) ,~.~' .~, Drill Out 6-1/~r Hole ~ <v" <Q0<v~'ò <Q0~~'òQ 0ci;~'ò'>" ~/ ,¿.:-._~ ~ «) /' ~ <v" l(,,-d'/'('I'(.'-4lr/' '" "~/ - '¡~1 ~ ;11£~:'6~n~~ 63!J1'6,OTW'),)<,'56""t.-!S'"18,',/,5,,",9,/,,¡.F,' ',' ',' " "" " " " ' ~ 6511.6ftTVD S/;(' fl.T1JN.!i'lliF. /.156 FSL, 5n ¡:¡~,1.. '\ T(lpC..IUr {,)/",ftl1"',,C3 ".¡U.f:>(! n'/}. 2222.]'1 s. 2316..17 \V f¡51I.f¡i! '{'I'll.. 2JI.!.!1i1 S, .IS67.SU II' S"" U.'f'HN.{(fiiI,:, us') FSi", ¡I¡N, rf.'f. S¡"" lloTlIN.R.l!Jf~. ¡,1¡¡<iI:S!" ,2280 Fei, Till' (.',.3 rrr lC.24 FIwl1 iJ494,:m TliD, 232257 S. .:iJ6fI..U W M3.1.5f! tJ.'I!. ::25ri.,:J.! .'í. 2ôn.76 11' Sf',: .!joT! 1;V.1U1iE. 128.'1 FSI.,. 21.178 pm. .'II'" J!"l'IlN,l<íiil::, 135:\' r.w, /38,'; 1"1'.'1, lúp (.'.4 DT !J468.67 :nD. ,,294,1).1 S, ,jiliW.i)!i W S'it: jj.1'U.."'VoiUIIE. i,J!? FSL 1781 1'1',1, 9-5/8" Casing 4673.9ft MD 4379.0ft TVD sper'r'Y-5ull -..~-.._..-..._-_.."....,..., ',"" .... å5 -æ u (f) DRILLING SERVICES , ,.. - A Halliburton Company 0 DriliQuest 2.~&~inch = 900ft 900 (. 1800 2700 Vertical Section (Well) 3600 4500 Section Azimuth: 236.717" (True North) ORIGINAL c:: ::X:, -......, ~.:". -....",~;" ==== :J::=... r-- Ntd ' TIIP c.", (,iT 6.:!Ii,i,liI! nn If%A4 S, iS1.:;,!'/! W Sr",' /I, 1'IIN,HIIJI';, 1451'> rsl. :i:~8 tim, 7 " Casing le"24 N1II11 6736 04ft MD 6434,SO T\/D, JJ.i6..i3S, 2t>?2. ï'(¡ \~ , '\ 61 Ú 60ft TVD 1'0" C, ¡ (iT Sfl,: .!.i"Tll:\'"lWiE. uS's ¡',SI" 13:iS Fl:!, . {';',JÍ,3.,tiÌ), ,r,l'I"',u,,1J., J.,.29 ,,"',', è.3"I,Ô,"¡:,' W, ' \ ~ _.,-,_____n-'..- Drill Out 6-1/8" Hole ¡:'Iif I F/ï 1,v.[( II)!/, US9 f'i';I" ION; rHi., ~-'----- ' 1'I,'P},".3!,>',;,' " '1","",", ", "", '4 ' ' ~ 4WP3a ~---.::-.~~~':_._--End Dir, Start Sail@87.505°:7354.64ftMD,6391.60ftTVD !i,19~,,¡¡, l\V,J...~.,,'1.),.',>M¡,3 H 1C.2 --- --' S . II n! \' IWi{' l"'~9 P'l ),(r~ rn ,----'- -. ~1~ ':'~;t~~ ~. -~." ~:~~~~--:::::::-'--<J::"~---<>-""_-íi'---~----,,-..... ---------Begin Dir @ 3.000o/100ft: 7860.00ft MD, 6413.60ft TVD 6511.611 TVD ('p'- '" ~'------ -----. ---...... g \ ~ ,------- '--"'--' --End Dir, Start Sail @ 85.723°: 7953.84ftMD,6419.14ftTVD l{) '---.... 1'r>f! (.4 ú1' ._~,..,. --"- B ' 0' @ 3 0000/1O0ft . 8612 24ft MD 6468 24ft TVD II -2500 " ~.... Mlili,~;: :i:VD, :::~Y4.Ii,¡ s, .i(llí\l~-- e~ln, Ir " ° . . , . {3,."" , ,',' ' ',',', , ',', ~'<'r l/.Tu,v"fum,:, 1:11:: /<'$1, /181 1"1:1, End Dlr, Start Sall@85.061.:8643.87ftMD,6470.72ftTVD c 1°,," !'as,' (",> :;:: {,5fí.MiT',1\V41,9IiS,3S,j7,,'iliW å5 ~>(' II,TfIN.NIM" !)!i9FS1,,))80FFi. -.............. Begin Dir @ 3.000"/100ft: 8916.67ft MD, 6494.20ft TVD ~ -.-.-.'---.-r.---.--.-..-------¡----....,--f: n d _0 i rl._~1~.1F ai I -@-~.§.:..tQ?~-~~.@.1~.:1.!?J.tMR!§1~.1:.~1.ttTlQ,-._..._,..__.'-..-.-.-----.-..---r..--.-----..."'...---"-T-".-.------..'--.--.---".T---.-.'.-.- -3500 -3000 -2500 -2000 -1 500 -1000 -500 0 Scale: 1 inch = r; Oft Ref r nee is Tr North DrillQuesl 2.00,09,006 -1000 -2000 Kuparuk River Unit North Slope, Alaska Kuparuk 1 C 1 C-24 WPO3A Begin Dir @ 1.0000/100ft: 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 1.5000/1O0ft : GOO.OOft MD, 599.86ft TVD Increase in Dir Rate @ 2.0000/100ft : 800.00ft MD, 799.22ft TVD """"Increase'in DirRate' @ 3:500"/100fr:'1250:00ft MD;l241 :23frTVD Increase in Dir Rate @ 4.0000/1O0ft: 1490.94ft MD, 1470.48ft TVD End Dir, Start Sail @ 24.007° : 1578.95ftMD,1551.79ftTVD 0 ( '.wf""", f.{;t"liOI/ SiC ¡~,n !Y.IUN, J668 F\ï.. 1,>;,,1) i,j¡: -500 ..... II 9-5/8" Casing " 4673.9ft MD 4379,Oft TVD ( spar'I"J-'5UIl, .,..",."".""".,.."-,...."."""."-...,,,,,..,.._,-,,,...,,-,...-"",...; 1J.~_,I~h.I...N.~_.J?Jê fD!Jc:: §? A Halliburton Company Begin Dir @ 6.0000/1O0ft: 6131.64ft MD, 5710.65ft TVD Phillips Alaska, Inc. ~ r- ""4 \NPO3A ¡ v~¿ MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) ("¡100ft) (ft) 0.00 0.00 0.00 -101.60 0.00 C).OO f\j 0,00 E S96ß571.-H [\j 562297,94 L O.DO 0.00 S¡'IL 300.00 0.00 0.00 198.40 300.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.00 0.00 Begin Dir @ 1.000"/100ft: 300.00ft MD 600.00 3.00 185.48 498.26 599.86 7.82 S 0.75 W 5968563.62 N 562297.26 E 1.00 4.92 Increase in Dir Rate @ 1.500"/1 oott : 600.00ft MD 800.00 6.00 185.48 697.62 799.22 23.44 S 2.25 W 5968547.99 N 562295.89 E 1,50 14.74 Increase in Dir Rate @ 2.000"/100ft : 800.00ft MD 1250.00 15.00 185.48 1139.63 1241.23 104.98 S 10.06 W 5968466.38 N 562288.75 E 2.00 66.03 Increase in Dir Rate @ 3.500o/10Oft: 1250.00ft MD 1490.94 21.00 205.00 1368.88 1470.48 175.27 S 31.32 W 5968395.91 N 562268.07 E 3.50 122.37 Increase in Dir Rate @ 4.000o/1O0ft : 1490.94ft MD .157<3,95 24.01 209.80 1450,19 155.1.79 205.11 S 46.ß9 W 5~)68365.94 N 562252.76 E 4.00 '151.76 End Oil' 18(-)3.37 24.01 209.80 1710.00 1Ü11.60 ~305S3 S 1 04.~39 W 5960265.05 N 562196,09 E 0.00 254.93 Base Permafrosi ( :$343.40 24,01 209.80 3062,00 ~1163.60 82£3.0<3 (' 403.60 \IV 5967740,04 N 561901.23 E 0.00 791.82 Top U~Jnu v C 3r,90.36 24.01 209.80 3653.00 ~~754,60 "1056.50 (' 534.39 W 5967510.54 N 561772.34 E 0.00 1026.52 Top Wesi t;ak ,) 445b.61 24.01 209.80 4078,00 4179.(;0 1 ~~20.l6 C' G~~8.4~:) \IV 500"1345.60 N be1 GlD, í3~:; E 0.00 1195.;.?D Base West Sak :x:. v 4673,80 24.01 200.80 42TI .40 4~37D.00 1 :?9"1.B~1 S 6/:::,:)8 W b961?Gß,O'7 t\J 561636.1G E 0.00 1274.4'7 !~H)iß" Casinq ,. Drìll 8\~:" Hoie - ~ 4849.70 24,0'1 209,80 44~38.00 4539,60 '135U.90 S l08.12 W 5967205.71 N 56.1601.'14 E 0.00 1338.2~:; C-80 ~ 6131.64 24.01 209.80 5609.05 5710.65 1812.51 S 967.28 W 5966750.96 N 561345.74 E 0.00 1803.28 Begin Dir @ 6.000o/1O0ft: 6131.64ft MD - ~ 6502.22 40.57 2~38.65 592~'~.00 6024.()O '1942,26 S '1109.45 \IV 59G6G20. O~3 N 56'1204.66 E 6.00 1993.33 Top ¡"-IHZ § 6736.04 52,98 247.71 608~3.00 6H~4.60 2017.60 S 1261.51 \IV 5966543.44 N 5610r<3.22 E 6,00 2161.79 7" Casinq - Drill f).'lm" 1'.'lole - Base H HZ 6908.40 62.45 252.62 6175.00 6276.60 2066.65 <, 1398.48 W 59664æ.ê!6 N 560916.67 E G.OO 230~:L21 K.1 Lower f<alubìk ,) 7160.02 76.53 258.48 6263,00 6364.60 2124.74 S 1626.13 \IV 5966<1-33.27 N 560689.i} 1 E 6.00 2525.40 Top Kuparuk D ......... '7354.64 8"7.51 2.62.61 6~~OO.00 (;30'j .CO 2'156.44 S 181h,D1 W 6966400.00 N ii6C500.00 F CLOO 2701.44 TarGet Heøl .. Top CA UT l8GO..00 8/.:51 ~~G~~.:51 631/.:'.00 G41 3.GO 2;222.~(9 t~ 2:3'1 GAl W b9G6330,OO [\j hGOOOO.OO E 0,00 3166.03 TarDet ,. Top C..3 UT ,,:) 7953.84 85.72 264.69 6317.54 6419.14 2232.73 S 2409.55 W 5966318.78 N 559907.01 E 3.00 3239.58 End Dir ß'j59.7B 85.72 264,69 6332.90 fA:J4.50 225'1.74. S 26'14.04 W 5966298.00 [\ 559702,69 E 0.00 3420.96 F:.ault (Lower Kalubìk) 8563.42 85.72 264.69 6::~63.00 ß464.60 22Hg,99 S 3014.ß2 IN 5966~:57.50 N 559302.22 E 0.00 3776.44 Dr Top Kuparuk D 8612.24 85.72 264.69 6366.64 6468.24 2293.50 S 3063,30 W 5966252.59 N 559253.78 E 0.00 3819.44 BE~gin Dìr (q.) 3,OOO"/100ft : 8612.24ft MD [16 HH)"( a~S,83 ~::64.sS 636/,0"7 6468.6/ ?2D<:J.. 04 C;, 3069.C>D \V 5DG6?:::;?..OO ~'¡ :::,S9248 E :3..00 ::;ß~~45d Tarq(::;! .. Top C.4 DT 8643.87 85.06 264.52 6369.12 6470.72 2296.49 S 3094.69 W t:¡966249.34 N 559222.42 E ~lOO :3847.32 End Dir 8916.67 85.06 264.52 6392.61 6494.21 2322.47 S 3365.24 W 5966221.12 N 558952.10 E 0.00 4087.75 Begin Dír @ 3.000o/1O0ft : 8916.67ft MD 891 "7,78 85.09 264,52 6392,70 6494.30 2::122.5'1 '" ::K566.3tj IN 5966221.00 f"~ 5S?39;;;'I..OO E ::;,00 40d~j.'1:3 Tan.)(ì'l .j'r)p C-:3 DT ( ,;;! 8918.25 85.11 264.51 6392.74 6494.34 2322.62 S 3366,80 W 5966220.95 N 558950,54 E 3.00 4089.14 End Dir 9120.6~~ ß5.'11 264.(-31 64'10.00 6(-31'1.60 234.1.90 S 3667.~)1 IN (-3966;;:00,00 t~ 65,3750.00 E 0.00 426"7,51 'rota! Depth : 91~20,6~2¡tlV¡D. 4h" Uner ( C) ::x:J - c;-) - =æ: ::t::a.. r-- Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-24 1 C-24 WP3a Revised: 17 December, 2001 PROPOSAL REPORT 19 December, 2001 (' Surface Coordinates: 5968571.44 N, 562297.94 E (70019' 28.7732" N, 149029' 41.4448" W) Surface Coordinates relative to Project H Reference: 968571.44 N, 62297.94 E (Grid) Surface Coordinates relative to Stucture Referance: 49.59 N, 73.70 W (True) Kelly Bushing: 101.60ft above Mean Sea Level 5P E! .-....., V - 5 U 1"1 §:i!L~ L~lr~f~::"~i[§~:y'ïë:-ë 5, A Halliburton Company Proposal Ref: pr09733 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -101.60 0.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.00 100.00 0.000 0.000 -1.60 100.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.000 0.00 200.00 0.000 0.000 98.40 200.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.000 0.00 300.00 0.000 0.000 198.40 300.00 0.00 N 0.00 E 5968571.44 N 562297.94 E 0.000 0.00 Begin Dir @ 1.000°/1 OOft : 300("" MD, 300.00ft TVD 400.00 1.000 185.476 298.39 399.99 0.878 0.08W 5968570.57 N 562297.86 E 1.000 0.55 500.00 2.000 185.476 398.36 499.96 3.47 8 0.33W 5968567.96 N 562297.64 E 1.000 2.19 C) 600.00 3.000 185.476 498.26 599.86 7.828 0.75W 5968563.62 N 562297.26 E 1.000 4.92 Increase in Dir Rate @ 1.500°/1 OOft : 600.00ft MD, 599.86ft TVD ::t:J 700.00 4.500 185.476 598.05 699.65 14.33 8 1.37W 5968557.10 N 562296.69 E 1.500 9.01 - 800.00 6.000 185.476 697.62 799.22 23.43 8 2.25W 5968547.99 N 562295.89 E 1.500 14.7 4 Increase in Dir Rate @ 2.000o/1O0ft : - 800.00ft MD, 799.22ft TVD ~ 900.00 8.000 185.476 796.87 898.47 35.57 8 3.41 W 5968535.85 N 562294.83 E 2.000 22.37 - - <: 1000.00 10.000 185.476 895.64 997.24 51.148 4.90W 5968520.26 N 562293.46 E 2.000 32.16 )::::,.. 1100.00 12.000 185.476 993.79 1095.39 70.138 6.72W 5968501.26 N 562291 .80 E 2.000 44.11 1200.00 14.000 185.476 1091.23 1192.83 92.52 8 8.87W 5968478.85 N 562289.84 E 2.000 58.19 r-- 1250.00 15.000 185.476 1139.63 1241 .23 104.98 8 10.06 W 5968466.38 N 562288.75 E 2.000 66.02 Increase in Dir Rate @ 3.500°/1 OOft : 1250.00ft MD, 1241.23ftTVD 1300.00 16.072 190.644 1187.81 1289.41 118.23 8 11.96 W 5968453.12 N 562286.96 E 3.500 74.88 1400.00 18.521 199.082 1283.29 1384.89 146.85 8 19.71 W 5968424.43 N 562279.45 E 3.500 97.07 1490.94 21 .000 205.000 1368.88 1470.48 175.27 8 31.32 W 5968395.91 N 562268.07 E 3.500 122.37 Increase in Dir Rate @ 4.000°/1 OOft : 1500.00 21 .303 205.553 1377 .33 1478.93 178.23 8 32.72 W 5968392.94 N 562266.70 E 4.000 125.16 1490.94ft MD, 1470.48ftTVD ( 1578.95 24.007 209.795 1450.19 1551.79 205.118 46.89 W 5968365.94 N 562252.76 E 4.000 151.76 End Dir, 8tart 8ail @ 24.007° : 1578.95ftMD,1551.79ftTVD 1600.00 24.007 209.795 1469.42 1571 .02 212.55 8 51.14W 5968358.48 N 562248.56 E 0.000 159.40 1700.00 24.007 209.795 1560.77 1662.37 247.85 8 71.36 W 5968323.00 N 562228.64 E 0.000 195.67 1800.00 24.007 209.795 1652.12 1753.72 283.168 91 .58 W 5968287.53 N 562208.72 E 0.000 231.95 1863.37 24.007 209.795 1710.00 1811.60 305.538 104.39 W 5968265.05 N 562196.09 E 0.000 254.93 Base Permafrost 1900.00 24.007 209.795 1743.46 1845.06 318.47 8 111.79W 5968252.06 N 562188.79 E 0.000 268.22 2000.00 24.007 209.795 1834.81 1936.41 353.77 8 132.01 W 5968216.58 N 562168.87 E 0.000 304.50 ".."..,.,,-.'....'.-..-.'-"'.""--..............---.-........"".-"""""","".................."""""""'..""""."""'-".""""-""'".....................-.............................-.....-....................................-.....................-.........--..........................-"",."",.""",."-.",.",.-",.."",."""".,.-""""."",,-,,,,-........._...............................".................................".."....,...,..-",.".....,.,."..."-,.,."".".,,,.,..,..,.....,,'..".".""'."'."-.""""""'.'-..........""""'.'-"""........ 19 December, 2001 - 9:12 Page 2 of 10 Drí//Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1 C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C 11 OOft) 2100.00 24.007 209.795 1926.16 2027.76 389.08 S 152.23 W 5968181.11 N 562148.95 E 0.000 340.77 2200.00 24.007 209.795 2017.51 2119.11 424.39 S 172.44 W 5968145.64 N 562129.03 E 0.000 377 .05 2300.00 24.007 209.795 2108.86 2210.46 459.69 S 192.66W 5968110.16 N 562109.10 E 0.000 413.33 2400.00 24.007 209.795 2200.21 2301.81 495.00 S 212.88 W 5968074.69 N 562089.18 E 0.000 449.60 2500.00 24.007 209.795 2291 .56 2393.16 530.30 S 233.09 W 5968039.22 N 562069.26 E 0.000 485.88 ( 2600.00 24.007 209.795 2382.91 2484.51 565.61 S 253.31 W 5968003.75 N 562049.34 E 0.000 522.15 2700.00 24.007 209.795 2474.26 2575.86 600.92 S 273.53 W 5967968.27 N 562029.41 E 0.000 558.43 C 2800.00 24.007 209.795 2565.61 2667.21 636.22 S 293.74 W 5967932.80 N 562009.49 E 0.000 594.70 :::x:J 2900.00 24.007 209.795 2656.96 2758.56 671.53 S 313.96 W 5967897.33 N 561989.57 E 0.000 630.98 3000.00 24.007 209.795 2748.31 2849.91 706.84 S 334.17 W 5967861.85 N 561969.65 E 0.000 667.26 ~ - ~ 3100.00 24.007 209.795 2839.66 2941 .26 742.14 S 354.39 W 5967826.38 N 561949.72 E 0.000 703.53 - - 3200.00 24.007 209.795 2931.01 3032.61 777.45 S 374.61 W 5967790.91 N 561929.80 E 0.000 739.81 ~ 3300.00 24.007 209.795 3022.36 3123.96 812.76 S 394.82 W 5967755.43 N 561909.88 E 0.000 776.08 3343.40 24.007 209.795 3062.00 3163.60 828.08 S 403.60 W 5967740.04 N 561901.23 E 0.000 791.82 Top Ugnu 3400.00 24.007 209.795 3113.71 3215.31 848.06 S 415.04W 5967719.96 N 561889.95 E 0.000 812.36 r--- 3500.00 24.007 209.795 3205.06 3306.66 883.37 S 435.26 W 5967684.49 N 561870.03 E 0.000 848.63 3600.00 24.007 209.795 3296.41 3398.01 918.68 S 455.47 W 5967649.01 N 561850.11 E 0.000 884.91 3700.00 24.007 209.795 3387.76 3489.36 953.98 S 475.69 W 5967613.54 N 561830.19 E 0.000 921.19 3800.00 24.007 209.795 3479.11 3580.71 989.29 S 495.91 W 5967578.07 N 561810.26 E 0.000 957.46 3900.00 24.007 209.795 3570.46 3672.06 1024.60 S 516.12 W 5967542.59 N 561790.34 E 0.000 993.74 3990.36 24.007 209.795 3653.00 3754.60 1056.508 534.39 W 5967510.54 N 561772.34 E 0.000 1026.52 Top West 8ak ( 4000.00 24.007 209.795 3661.81 3763.41 1059.90 8 536.34 W 5967507.12 N 561770.42 E 0.000 1030.01 4100.00 24.007 209.795 3753.16 3854.76 1095.21 8 556.55 W 5967471.65 N 561750.50 E 0.000 1066.29 4200.00 24.007 209.795 3844.50 3946.10 1130.528 576.77 W 5967436.17 N 561730.57 E 0.000 1102.56 4300.00 24.007 209.795 3935.85 4037.45 1165.828 596.99 W 5967400.70 N 561710.65 E 0.000 1138.84 4400.00 24.007 209.795 4027.20 4128.80 1201.13S 617.20 W 5967365.23 N 561690.73 E 0.000 1175.12 4455.61 24.007 209.795 4078.00 4179.60 1220.76 S 628.45 W 5967345.50 N 561679.65 E 0.000 1195.29 Base West Sak 4500.00 24.007 209.795 4118.55 4220.15 1236.44 S 637.42 W 5967329.75 N 561670.81 E 0.000 1211.39 4600.00 24.007 209.795 4209.90 4311.50 1271.748 657.64 W 5967294.28 N 561650.88 E 0.000 1247.67 4673.89 24.007 209.795 4277.40 4379.00 1297.83 8 672.57 W 5967268.07 N 561636.16 E 0.000 1274.47 Drill out 8Y2" Hole 9 5/8" Casing .--..-.---..........-.-..-....---..-----.------....-.....-....-..--....-......---..---.................-...-.........".-'.."..-""".-."."'."'...'..."....'........-..--....."""...".."..,.......................,.............""".".",.."."."",..-,".'.'."""".."...'..".."...'..".."'...."'...."""..'.."............-.......-.................-...........-....-..............-..-....-......-....-.....................--.....-...............................-..-........................................................................................................-..-........-..... 19 December, 2001 - 9:12 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 4700.00 24.007 209.795 4301.25 4402.85 1307.058 677.85 W 5967258.81 N 561630.96 E 0.000 1283.94 4800.00 24.007 209.795 4392.60 4494.20 1342.36 S 698.07 W 5967223.33 N 561611.04 E 0.000 1320.22 4849.70 24.007 209.795 4438.00 4539.60 1359.908 708.12 W 5967205.71 N 561601.14 E 0.000 1338.25 C-80 4900.00 24.007 209.795 4483.95 4585.55 1377.668 718.29 W 5967187.86 N 561591.12 E 0.000 1356.49 5000.00 24.007 209.795 4575.30 4676.90 1412.978 738.50 W 5967152.39 N 561571.19E 0.000 1392.77 ( 5100.00 24.007 209.795 4666.65 4768.25 1448.28 8 758.72 W 5967116.91 N 561551.27 E 0.000 1429.05 C' 5200.00 24.007 209.795 4758.00 4859.60 1483.58 8 778.94 W 5967081.44 N 561531.35 E 0.000 1465.32 -=""', 5300.00 24.007 209.795 4849.35 4950.95 1518.89 S 799.15 W 5967045.97 N 561511.43 E 0.000 1501.60 -;:.. 5400.00 24.007 209.795 4940.70 5042.30 1554.20 8 819.37 W 5967010.50 N 561491.50 E 0.000 1537.87 ......., 5500.00 24.007 209.795 5032.05 5133.65 1589.508 839.58 W 5966975.02 N 561471.58 E 0.000 1574.15 t:~"., ~ . 5600.00 24.007 209.795 5123.40 5225.00 1624.81 8 859.80 W 5966939.55 N 561451.66 E 0.000 1610.42 -""""-""'.. ',' --... 5700.00 24.007 209.795 5214.75 5316.35 1660.128 880.02 W 5966904.08 N 561431.73 E 0.000 1646.70 <""~' 5800.00 24.007 209.795 5306.10 5407.70 1695.42 8 900.23 W 5966868.60 N 561411.81E 0.000 1682.98 -'..... ~ 5900.00 24.007 209.795 5397.45 5499.05 1730.73 8 920.45 W 5966833.13 N 561391.89 E 0.000 1719.25 .--- 6000.00 24.007 209.795 5488.80 5590.40 1766.04 8 940.67 W 5966797.66 N 561371.97 E 0.000 1755.53 6100.00 24.007 209.795 5580.15 5681.75 1801.348 960.88 W 5966762.18 N 561352.04 E 0.000 1791.80 6131.64 24.007 209.795 5609.05 5710.65 1812.51 S 967.28 W 5966750.96 N 561345.74 E 0.000 1803.28 Begin Dir @ 6.0000/100ft : 6131.64ft MD, 571 0.65ft TVD 6200.00 26.504 217.435 5670.89 5772.49 1836.70 8 983.47 W 5966726.64 N 561329.75 E 6.000 1830.09 6300.00 30.742 226.331 5758.69 5860.29 1872.108 1015.55 W 5966690.97 N 561297.97 E 6.000 1876.33 6400.00 35.448 233.165 5842.47 5944.07 1907.17 S 1057.28 W 5966655.56 N 561256.53 E 6.000 1930.46 6500.00 40.459 238.543 5921.32 6022.92 1941.51 S 1108.22 W 5966620.79 N 561205.88 E 6.000 1991.89 ( 6502.22 40.572 238.650 5923.00 6024.60 1942.268 1109.44 W 5966620.03 N 561204.66 E 6.000 1993.33 Top HRZ 6600.00 45.672 242.902 5994.36 6095.96 1974.77 S 1167.79 W 5966587.04 N 561146.59 E 6.000 2059.94 6700.00 51.023 246.539 6060.81 6162.41 2006.57 8 1235.35 W 5966554.69 N 561079.29 E 6.000 2133.87 6736.04 52.977 247.714 6083.00 6184.60 2017.60 S 1261.51 W 5966543.44 N 561053.22 E 6.000 2161.80 Drill 6-1\8" Hole 7" Casing 6800.00 56.471 249.659 6119.94 6221.54 2036.56 8 1310.15 W 5966524.08 N 561004.74 E 6.000 2212.86 6900.00 61 .988 252.406 6171.09 6272.69 2064.41 8 1391.39 W 5966495.55 N 560923.74 E 6.000 2296.06 6908.40 62.454 252.624 6175.00 6276.60 2066.65 S 1398.47 W 5966493.26 N 560916.67 E 6.000 2303.21 K1 Lower Kalubik 7000.00 67.554 254.884 6213.70 6315.30 2089.83 S 1478.16 W 5966469.41 N 560837.18 E 6.000 2382.54 7100.00 73.155 257.170 6247.31 6348.91 2112.53 S 1569.51 W 5966445.95 N 560746.02 E 6.000 2471.37 .-............,.....-........-................-.-.........-........--.-....-...................-.......-.-.......-..-..-....---.-.--......--...-.........-.............-....--.-.-..-............-...-..............,...........-.......-.........--..............-..-.....-........................-..............--...-...,....-......-..-...........-.-,............-.....",...,.,-.-...",....-..-......-.......................,..............--......-........-..........--.....-...-.-.-......-.-............-.....-...................................m.............-..-..-....-.....-....-........-..-'.'...-.............-..... 19 December, 2001 - 9:12 Page 4 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 7160.02 76.529 258.475 6263.00 6364.60 2124.74 S 1626.13 W 5966433.27 N 560689.51 E 6.000 2525.40 Top Kuparuk D 7200.00 78.780 259.323 6271 .55 6373.15 2132.26 S 1664.45 W 5966425.44 N 560651.24 E 6.000 2561.57 7300.00 84.420 261 .394 6286.15 6387.75 2148.81 S 1761.94 W 5966408.08 N 560553.90 E 6.000 2652.14 7354.64 87.505 262.506 6290.00 6391 .60 2156.44 S 1815.90 W 5966400.00 N 560500.00 E 6.000 2701.44 End Dir, Start Sail @ 87.505° : ( 7354.64ftMD,6391.60ftTVD Q UT Top C4 Target - Heel- Top C-4 UT, Current ::::c Target 7400.00 87.505 262.506 6291 .97 6393.57 2162.35 S 1860.83 W 5966393.72 N 560455.12 E 0.000 2742.24 - - ~ 7500.00 87.505 262.506 6296.33 6397.93 2175.38 S 1959.88 W 5966379.87 N 560356.18 E 0.000 2832.20 - - 7600.00 87.505 262.506 6300.68 6402.28 2188.41 S 2058.94 W 5966366.01 N 560257.24 E 0.000 2922.15 :æ: 7700.00 87.505 262.506 6305.03 6406.63 2201.44 S 2157.99 W 5966352.16 N 560158.30 E 0.000 3012.11 7800.00 87.505 262.506 6309.39 6410.99 2214.47 S 2257.04 W 5966338.31 N 560059.36 E 0.000 3102.06 ):::. 7860.00 87.505 262.506 6312.00 6413.60 2222.29 S 2316.47 W 5966330.00 N 560000.00 E 0.000 3156.03 Begin Dir @ 3.0000/100ft : 7860.00ft r-- MD, 6413.60ft TVD UT Top C3 Target - Top C-3 UT, Current Target 7900.00 86.745 263.436 6314.01 6415.61 2227.17 S 2356.12 W 5966324.78 N 559960.39 E 3.000 3191.86 7953.84 85.723 264.690 6317.54 6419.14 2232.73 S 2409.55 W 5966318.78 N 559907.00 E 3.000 3239.58 End Dir, Start Sail @ 85.723" : 7953.84ftMD,6419.14ftTVD 8000.00 85.723 264.690 6320.98 6422.58 2236.99 S 2455.39 W 5966314.14 N 559861.21 E 0.000 3280.24 8100.00 85.723 264.690 6328.44 6430.04 2246.22 S 2554.68 W 5966304.09 N 559762.00 E 0.000 3368.31 8159.78 85.723 264.690 6332.90 6434.50 2251.74 S 2614.04 W 5966298.08 N 559702.69 E 0.000 3420.95 Fault (Lower Kalubik) ( 8200.00 85.723 264.690 6335.90 6437.50 2255.45 S 2653.97 W 5966294.04 N 559662.78 E 0.000 3456.38 8300.00 85.723 264.690 6343.36 6444.96 2264.68 S 2753.27 W 5966283.98 N 559563.57 E 0.000 3544.45 8400.00 85.723 264.690 6350.81 6452.41 2273.91 S 2852.56 W 5966273.93 N 559464.35 E 0.000 3632.52 8500.00 85.723 264.690 6358.27 6459.87 2283.14 S 2951.85 W 5966263.88 N 559365.14 E 0.000 3720.59 8563.42 85.723 264.690 6363.00 6464.60 2288.99 S 3014.82 W 5966257.50 N 559302.22 E 0.000 3776.44 DT Top Kuparuk D 8600.00 85.723 264.690 6365.73 6467.33 2292.37 S 3051.15 W 5966253.82 N 559265.93 E 0.000 3808.66 8612.24 85.723 264.690 6366.64 6468.24 2293.50 S 3063.30 W 5966252.59 N 559253.78 E 0.000 3819.44 Begin Dir @ 3.0000/100ft : 8612.24ft MD, 6468.24ft TVD 8618.07 85.834 264.554 6367.07 6468.67 2294.04 S 3069.09 W 5966252.00 N 559248.00 E 3.000 3824.58 DT Top C4 Target - Top C-4 DT, Current Target 8643.87 85.061 264.515 6369.12 6470.72 2296.49 S 3094.69 W 5966249.34 N 559222.42 E 3.000 3847.32 End Dir, Start Sail @ 85.061 ° : 8643.87ftM D ,6470.72ftTVD 8700.00 85.061 264.515 6373.95 6475.55 2301 .83 S 3150.36 W 5966243.53 N 559166.80 E 0.000 3896.79 .....-.....--.-....-........--....--......-.---.............-....-...--.........-....--.-.........-....---....-..........................--...........-................-.........................-.........-...................-...............-............................-..................-..........................--............................-.....-......-.........................................................................-.............-........................--..-....-.-.--.-..-..-.---'.'.-'.-..'.---..".'.'.-'.-"""'-""""--..'-......... 19 December, 2001 - 9:12 Page 5 of 10 DrillQuest 2.00.09.006 <::) ::x:J - - ~ - - :æ: )::::.. r--- Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8800.00 85.061 264.515 6382.56 6484.16 8900.00 85.061 264.515 6391.17 6492.77 8916.67 85.061 264.515 6392.60 6494.20 8917.78 85.094 264.517 6392.70 6494.30 8918.25 85.107 264.511 6392.74 6494.34 9000.00 85.107 264.511 6399.71 6501.31 9100.00 85.107 264.511 6408.24 6509.84 9120.62 85.107 264.511 6410.00 6511.60 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 Local Coordinates Northings Eastings (ft) (ft) 2311.36 S 2320.88 S 2322.47 S 2322.57 S 2322.62 S 2330.41 S 2339.94 S 2341.90 S 3249.53 W 3348.70 W 3365.23 W 3366.34 W 3366.80 W 3447.88 W 3547.06 W 3567.50 W All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 236.717° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9120.62ft., The Bottom Hole Displacement is 4267.51ft., in the Direction of 236.717° (True). Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) C/100ft) 5966233.19 N 559067.71 E 0.000 5966222.84 N 558968.62 E 0.000 5966221.12 N 558952.10 E 0.000 5966221.00 N 558951.00 E 3.000 5966220.95 N 558950.53 E 3.000 5966212.49 N 5966202.13 N 5966200.00 N 558869.53 E 558770.43 E 558750.00 E 0.000 0.000 0.000 Vertical Section 3984.93 4073.06 4087.75 4088.73 4089.14 4161.20 4249.34 4267.51 North Slope, Alaska Kuparuk 1 C Comment Begin Dir @ 3.000°/1 OOft : 8916.67ft MD, 6494.20ft TVD r DT Top C3 ( Target - Top C-3 DT, Current Ta!\:c( End Dir, Start Sail @ 85.107° : 8918.25ftMD,6494.34ftTVD Total Depth: 9120.62ftMD,6511.60ftTVD 4 1/2" Liner TD Target - Toe - Base C3, Current Targe ( 19 December, 2001 - 9:12 -.....--..-.------.,-.--..-..-........-.-,..-----..-.--.....-..-..-....-..-...-......-.....-...-......-...................-.....--.......-.....-.....-.......................-...............--...................--...-.............-..--......................-......-...............-.""..'.."-.."..-."'-"'--.--.--...-'.-...'..'......"'.....-.......-.........'...'.-"..-"--.'-"""""""."."."'-'""-"".".".".-"'..'.""",..'-."..'-.""'.'...'-.-..'.-.'.-.-."..-.-"'....'-'."..'-.-.'..-.---"."'."-.'....-.-..............,........... DrillQuest 2.00.09.006 Page 6 of 10 C) :::t:J - ø - :æ: :J:::==.. r-- Kuparuk River Unit Comments Measured Depth (ft) 300.00 600.00 800.00 1250.00 1490.94 1578.95 4673.89 6131.64 6736.04 7354.64 7860.00 7953.84 8612.24 8643.87 8916.67 8918.25 9120.62 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 300.00 0.00 N 0.00 E 599.86 7.82 S 0.75W 799.22 23.43 S 2.25W 1241.23 104.98 S 10.06 W 1470.48 175.28 S 31.32 W 1551.79 205.11 S 46.89 W 4379.00 1297.83 S 672.57 W 5710.65 1812.51 S 967.28 W 6184.60 2017.60 S 1261.51 W 6391.60 2156.44 S 1815.90W 6413.60 2222.29 S 2316.47 W 6419.14 2232.73 S 2409.55 W 6468.24 2293.50 S 3063.30 W 6470.72 2296.49 S 3094.69 W 6494.20 2322.47 S 3365.23 W 6494.34 2322.62 S 3366.80 W 6511.60 2341.90 S 3567.50 W Sperry-Sun Drilling Services Proposal Report for 1 C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk 1 C Comment Begin Dir @ 1.000°/1 OOft : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 1.5000/100ft : 600.00ft MD, 599.86ft TVD Increase in Dir Rate @ 2.0000/100ft : 800.00ft MD, 799.22ft TVD Increase in Dir Rate @ 3.5000/100ft : 1250.00ft MD, 1241.23ft TVD Increase in Dir Rate @ 4.0000/100ft: 1490.94ft MD, 1470.48ft TVD ( End Dir, Start Sail @ 24.007° : 1578.95ftMD,1551.79ftTVD Drill out 8112" Hole Begin Dir @ 6.0000/1O0ft: 6131.64ft MD, 5710.65ft TVD Drill 6-1\8" Hole End Dir, Start Sail @ 87.505° : 7354.64ftMD,6391.60ftTVD Begin Dir @ 3.0000/1O0ft: 7860.00ft MD, 6413.60ft TVD End Dir, Start Sail @ 85.723°: 7953.84ftMD,6419.14ftTVD Begin Dir @ 3.0000/100ft : 8612.24ft MD, 6468.24ft TVD End Dir, Start Sail @ 85.061 ° : 8643.87ftMD,6470.72ftTVD Begin Dir @ 3.0000/1O0ft : 8916.67ft MD, 6494.20ft TVD End Dir, Start Sail @ 85.107° : 8918.25ftMD,6494.34ftTVD Total Depth: 9120.62ftMD,6511.60ftTVD ( ...... .... .......... -........... ... .... ............................. ..-..-.. .......- ......'."-"'..'.'.'..".".'.'.-.'."'."'.""'...'."""."".". m...... ..... .... .....................-..... .....-............. ........... ....... ..... ......... ... ......... ................. ................. ...... .... ..... ........ ..... ........... ... ........ ............ .... ..-...... .......m.. ..... .................................... .... ....-....-.............. ............ ..... ........ -.-................. .... .-....................... .......... .................. ..... ............................. ...................... ......... ... ....... ......... .............. ...... ...................... 19 December, 2001 - 9:12 Page 7 of 10 DriJ/Quest 2.00. 09.006 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Formation Tops Formati on Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) 1710.00 0.000 0.476 1863.37 1811.60 1710.00 305.53 S 104.39 W Base Permafrost ( 3062.00 0.000 0.476 3343.40 3163.60 3062.00 828.08 S 403.60 W Top Ugnu a 3653.00 0.000 0.476 3990.36 3754.60 3653.00 1056.50 S 534.39 W Top West Sak 4078.00 0.000 0.476 4455.61 4179.60 4078.00 1220.76 S 628.45 W Base West Sak =0 4438.00 0.000 0.476 4849.70 4539.60 4438.00 1359.90 S 708.12 W C-80 - - c-) 5923.00 0.000 0.476 6502.22 6024.60 5923.00 1942.26 S 1109.44 W Top HAZ 6083.00 0.000 0.476 6736.04 6184.60 6083.00 2017.60 S 1261.51W Base HAZ - - 6175.00 0.000 0.476 6908.40 6276.60 6175.00 2066.65 S 1398.47 W K1 Lower Kalubik ~ 6263.00 0.000 0.476 7160.02 6364.60 6263.00 2124.74 S 1626.13 W Top Kuparuk D 6290.00 0.000 0.476 7354.64 6391.60 6290.00 2156.44 S 1815.90 W UT Top C4 ....... 6312.00 0.000 0.476 7860.00 6413.60 6312.00 2222.29 S 2316.47 W UT Top C3 6332.90 0.000 0.476 8159.78 6434.50 6332.90 2251.74 S 2614.04 W Fault (Lower Kalubik) 6363.00 0.000 0.476 8563.42 6464.60 6363.00 2288.99 S 3014.82 W DT Top Kuparuk D 6367.07 0.000 0.476 8618.07 6468.67 6367.07 2294.04 S 3069.09 W DT Top C4 6392.70 0.000 0.476 8917.78 6494.30 6392.70 2322.57 S 3366.34 W DT Top C3 6410.00 0.000 0.476 9120.62 6511 .60' 6410.00 2341.90 S 3567.50 W TD { .........................-.............-. ....... "-".."'."...'...-'.."".............. ."""",.".""""""""."""."""""""",.""""""""" .........-....................... ........ ........................ ............. - ............. .......................... ........................................................ -.................................... ..... -.......................- ................. .....................................-................................ ......... - ............................ ... .............. .... ..................... ................................ ............................... _. -........ ."'.""""'. ..-................. 19 December, 2001 - 9:12 Page 8 of 10 DrillQuest 2.00.09.006 C ::x:J - C") - - :c:: )::::.. r-- Kuparuk River Unit Casing details Fro m Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this wellpath Target Name 1 C-24 Fault Heel - Top C-4 UT Toe - Base C3 Top C-3 DT Top C-3 UT To Measured Vertical Depth Depth (ft) (ft) 4673.89 6736.04 9120.62 4379.00 6184.60 6511.60 Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 North Slope, Alaska Kuparuk 1 C Casing Detail 9 5/8" Casing 7" Casing 4 1/2" Liner ( Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 6434.50 2256.33 S 2672.76 W Point Current Target Mean Sea Level/Global Coordinates: 6332.90 5966293.00 N 559644.00 E Geographical Coordinates: 700 19' 06.5756" N 149030' 59.4415" W 6391.60 2156.44 S 1815.90 W Point Current Target Mean Sea Level/Global Coordinates: 6290.00 5966400.00 N 560500.00 E Geographical Coordinates: 700 19' 07.5606" N 1490 30' 34.4373" W 6511.60 2341.90 S 3567.50 W Point Current Target Mean Sea Level/Global Coordinates: 6410.00 5966200.00 N 558750.00 E Geographical Coordinates: 70° 19' 05.7302" N 149031' 25.5507" W ( 6494.30 2322.57 S 3366.34 W Point Current Target Mean Sea Level/Global Coordinates: 6392.70 5966221 .00 N 558951.00 E Geographical Coordinates: 70° 19' 05.9213" N 1490 31 19.6806" W 6413.60 2222.29 S 2316.47 W Point Current Target Mean Sea Level/Global Coordinates: 6312.00 5966330.00 N 560000.00 E Geographical Coordinates: 70° 19' 06.9116" N 149" 30' 49.0444" W 19 December, 2001 - 9:12 ........................................................................-...................................................................................-........--..................-...-................-.....-........................................................-.....-....................................-......................-........................................-............................................................................................................................-.............................................-...............................................................-........................................,........................ Page 9 of 10 DrillQuest 2.00. 09.006 C) ::::c - C) - - <:: ::t:=.. r-- Sperry-Sun Drilling Services Proposal Report for 1C-24 WP3a Revised: 17 December, 2001 Kuparuk River Unit Target Name Targets associated with this wellpath (Continued) Top C-4 DT Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6468.67 6367.07 2294.04 S 3069.09 W 5966252.00 N 559248.00 E 700 19' 06.2032" N 1490 31' 11.0067" W North Slope, Alaska Kuparuk 1 C Target Shape Target Type Point Current Target ( ( '.-'."."...".."...'--'-"'..-..'-'.'.""-'..'.--.'-"-.-..-.........-...-.---..---.-.--..--.-....................-..--.....--...........-.............-.-......-......-.......-.-....-.,..--........--......-................-......-.....-...-........--........,-,."""",.-."""".-.",..".-"",-.-.,.",...",-.."."...-....-.....-.....-................-..................-..-.-.......---........---.-.........-.-......-....-.......................-............",.,..,."""-."""."""",.-".,."".,,...,..........,....-........................ 19 December, 2001 - 9:12 Page 10 of 10 DrillQuest 2.00.09.006 8 perry -8 un Anticollision Report ~' Company: Field: Reference Site: Reference Well: Reference Well path: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 C Pad 1 C-24 1 C-24 W P2B Date: 12/17/2001 Time: 14:30:23 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 1C-24, True North 1C-24 @ 101.6' ASL 101.6 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths \\-ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.0 ft Depth Range: 61.3 to 9120.6 ft Maximum Radius: 1144.4 ft Reference: Error Model: Scan Method: Error Surface: Plan: 1C-24 WP03A & NOT PLANNED P ISCWSA Ellipse Trav Cylinder North Ellipse + Casing GR,l Casing Point.. -.. I -=-~ MD ft 4503.3 9506.3 TVD ft 4223.1 0.0 Diameter in Hole Size in Name 7.625 5.500 9.875 6.750 7.625" 51/2" Plan: 1 C-24 W P03A Date Composed: Version: Tied-to: 12/17/2001 1 From Well Ref. Point Principal: Yes -..-..-- Summary <---------------------- Offset Well path ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warning ft ft ft ft ft _.. .--- ..-....--.-....-..-. -. ..."."."-". ...---..------ --.-- "'-'--'---"-.'---."-'---..-.--.- ....-...- --..... .....-- Kuparuk 1 C Pad 1 C-01 1 C-01 V1 1001.1 1000.0 78.6 18.1 60.5 Pass: Major Risk Kuparuk 1 C Pad 1 C-02 1C-02 V1 399.7 400.0 33.2 8.9 24.3 Pass: Major Risk Kuparuk 1C Pad 1 C-03 1C-03 V1 398.7 400.0 152.1 8.9 143.3 Pass: Major Risk Kuparuk 1 C Pad 1C-10 1C-10 V1 2518.4 2550.0 362.4 107.5 272.2 Pass: Major Risk Kuparuk 1 C Pad 1C-131 1C-131 V2 250.0 250.0 318.1 5.6 312.5 Pass: Major Risk Kuparuk 1C Pad 1 C-133 1C-133 V6 2560.9 2550.0 127.4 68.3 74.1 Pass: Major Risk Kuparuk 1 C Pad 1 C-14 1C-14 VO 635.1 650.0 166.1 12.3 153.8 Pass: Major Risk Kuparuk 1 C Pad 1 C-15 1 C-15 VO 497.8 500.0 60.6 9.2 51.4 Pass: Major Risk Kuparuk 1 C Pad 1 C-23 1 C-23 VO 399.7 400.0 14.8 8.3 6.5 Pass: Major Risk Kuparuk 1 C Pad 1C-23PB1 1 C-23PB1 VO 399.7 400.0 14.8 8.3 6.5 Pass: Major Risk Kuparuk 1 C Pad 1 C-25 1 C-25 VO 500.6 500.0 42.4 8.5 33.9 Pass: Major Risk Kuparuk 1 C Pad 1 C-26 1 C-26 VO 1156.1 1150.0 65.1 20.4 44.8 Pass: Major Risk Kuparuk 1C Pad 1C-27 1 C-27 V1 300.0 300.0 78.4 7.4 71.0 Pass: Major Risk Kuparuk 1 C Pad Plan 1C-137 ( Y14) 1 C-137 ( Y -14 ) VO Pia 1566.7 1600.0 132.8 28.1 104.8 Pass: Major Risk Kuparuk 1 C Pad Plan: 1 C-129 1C-129 VO Plan: 1C-129 1489.3 1550.0 107.7 29.5 78.6 Pass: Major Risk Kuparuk 1 C Pad Plan: 1C-135 1C-135 V14 Plan: 1C-13 350.6 350.0 271.0 9.1 261.9 Pass: Major Risk ORIGINAL ""'1.1"'1.,", """',,""':!.,"., .wn. CO/J ISlO.' ,,(¡'n~"s """"""""" "",. l' "" " . s,.;. ".",'.....""..".,.. "."",.",;"""",. c."",.,..", 1,<"'" '" ", "",..., 1.., "."",., ,."", 'IT"""""""""""""'" II """.,."""'" ,..>",,~., ".,.'0,1"" I:' :.';:." ¡I .", .1,'" Eo".", """""1 ",0",..,., """",..,,, "., ""!hI".",.."",, ,."",."", ",,"N' "'WI""" ",'.,,'SII' """ c.i.' ".'" II.','.! '.h'W,,' "'" r" """.,, 'kk""," !'I""r.,.,wr"',, -.""" " ".:;."" ",'.":,, ,.""", "w,. .",.". W.,,"'","., \1 """"W."""""," Colour -~~ø -'-200 ."'..-150 nnnn.! 00 .....00-50 """"50 ./ / / I I I I ,/ "100 J .. . I I I . -1--.......... ,./ , ".. . ..... ;...---.~¡ ""-'-"--""""""'" ,. ! ",--:0- . ::::'-'-~/ 120 ::::.......:. ~ --...::;! . ............. ~ -...¡, .~~_.. ,- I I ..--ISO "'.-200 .' ; _._~ ~ ~ -'-"-- ""'l".mll"""'" ,""" ".,.,w"", "~""'.'" "II." ,," ",,~,;. "."'. """.\~ \'><;.:':'~ On.-," .><, ",,". .F;.\\, i::~:';~" I.EGI~'1) - 1('.01 (leor). ~t>j." Ri,k le02 ,IC.UlJ.),t".r Ri,k .".- IC.!I) IIC.0.1). M"", R"k - rC.IOIIC.IO).M"",n~k - Ic.m (lC.I)!,. ~b,'rR"k - ICI.1:III('.I»). ~t1j.lrRi,k Ic.r4i1CI.I).M",'rRi,k - IC.151IC.I\).M.'-~IrRi,k - IC-l311(,.:~3..M"",Ri,k IC.2)J>ßIIIC.2.1J>ßI'.~!a,.rR"k - IC.;I,IC.~51.Majorhk' - IC.2~(lC-~I». M,;,'rR"k ICo27 IIC.~7). M"~,, R¡,k - I'b"IC.I.'7¡YI>I')IIC.I.'7iY.11 - 1'\10: IC.12<iIIC.129I.M",'rRi.,k "",,: IC.I.1~ 11('.1)1). M"", R"k - 1(",24 WJ>2B - \('.24 WJ>O)A O.."".""""",,M.,,""""'" no""""" ",,'" "".11.'"" "»,,, . """., 11""".." . "1""""""..........-.... """'... SECTION DET/III.S Soc MD Inc Azi TVD I.N/-S .,.IV-W DLog TFace VScc Targel I 61.:1 I!.IX) lUX) 6\.:1 0.0 O.f) f).m) om 0.0 2 :1(X).O o.w (UX) :\IXW 0.0 0.0 0.00 om 0.0 :; Im.o .\.IX) 185..18 599.9 -7.8 .0.7 I.1X) IHI.48 4.6 4 8(X).0 6.00 185.48 799.2 ,,23.4 .2.2 \.50 O.IX) 14.0 5 1250.0 15.m 185.48 1241.2 .105.0 .IO.! 2.00 O.lX) 62.8 6 14!JO.9 2\.IXJ 20S.(X) 1470.4 -175.3 -:\1.3 .lSO 14.7.\ 117.3 7 157H.9 24.01 2(~).7Q 1.15\.7 .20.\.1 .46.9 4.IJO ,-J.IH 146.0 8 613\.6 2.!.In 209.79 171()5 -1812.8 -967.2 IJ.I~) om 1763.9 9 n\4.6 87.10 26251 631} \.1 -21%.7 .18IS.1} 6.18) 56.1}(' 26Œ.:1 10 7860.0 87.50 262.\1 114115 -2222.5 .2:116.5 ().(~) 0.18) 3131.1 II 795:1.8 85.72 21>4.I<IJ 6419.1 ..2232.9 .241J1).5 118) m.:;'¡ 3216.1 12 8~12.2 85.72 2M.~Q 646B.2 .22'1:1.'/ --:I()(,:IJ O.O() O.lX) 3807.5 1:1 8618.1 85.8:1 21>4.55 6-168.7 ..2294.:1 .3069.1 .to! 308.23 3812.8 14 86'0.1} 8S.(1I\ 2114.51 6470.7 -22%.7 .3ŒJ4.7 2.1}9 182.96 )8:¡6.0 15 H916.7 85,(16 264.51 6-I!)4.2 .2322.7 .3365.3 O.I~) (),IX) <U)8\.2 /6 H917.8 85,W 211452 649-1,3 -2322.8 ..\,16Ii,3 2.87 18,37 4082.1 17 8918.2 85.11 2114.51 64943 .2322.9 -:(166.7 5.59 :(n52 4082.5 18 9120.6 85.11 21>4.51 1>511.1; .2:\42.1 -:\\(i7.1 0.18) 0.00 .1264..1 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] ( ,'I' ~I lC-24 Drilling Hazards Summary (SEE WEll PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Hazard Drilling into pressured stringers above the Ku aruk sands Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk level Low Low Moderate Low Low Moderate Interval Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s. Diverter drills, increased mud weight. 7" Casin Interval Risk level Low Low Low Moderate 6-1/8" Hole / 4-1/2" Liner Interval Hazard High EGD and swabbing if higher MW is re uired Hole cleaning in long, hi h an Ie tan ent Mud losses across fault zone Risk level Low Moderate Moderate Miti ation Strate Stripping drills, Shut-in drills, Increased mud weight, monitor LWD logs to ensure drillin is sto ed at the base HRZ Good hole cleaning, PWD Tools, Hole 0 ener Mud rheology, PWD tools, minimize ECD sikes caused b movin i e LCM Trip speeds, Proper hole filling (use of trip sheets Pum in out Miti ation Strate Pumping and rotating out on trips as needed to reduce swab and barite sag otential. Good drilling practices. Mud rheology, PWD tools, minimize ECD sikes caused b movin i e LCM 1 C-24 Drilling Hazards Summary prepared by Scott Lowry 12/13/01 ORIGINAL ,'Í .~ (' Differential sticking on Moderate Run mud weight only as high as needed. DT side of fault Do not leave pipe static for long periods of time. ORIGINAL 1 C-24 Drilling Hazards Summary prepared by Scott Lowry 12/13/01 KRU 1C-24 InjectL~ Proposed Completion Schematic T opset Base Case 16" 62.6# @ +1-120' MD TAM 9-5/8" Port Collar Stnd. Grade BTC Threads (+/- 1000' 1VD) Depths are based on Nabors 245E RKB Surface csg. 9-5/8" 40# L-80 BTC (+1- 4674' MD 14379' 1VD) Top-set csg. 7" 26# L-80 BTCM (+1- 6736' MD 16185' 1VD) &, '1.1(," to Contingency if mud losses are observed in fault zone. 2 - Baker 4- %" ECP's. Placement above and below fault zone. Production Liner 4-1/2" 12.6# L-80 NSCT (+1- 9121' MD 16512'1VD) I (" PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required 4-1/2" 12.6# L-80 IBT Tubing to Surface 4-1/2" Camco 'DB' nipple wi 3.813" No-Go Profile. Set at +1- 500' MD 4-1/2" 12.6# L-80 IBT tubing to landing nipple GLM Placement TBD 4-1/2" X 1-1/2" Camco 'KBG-2' mandrel wI shear valve and latch (Max. aD 5.984", ID 3.833"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 4-1/2" 12.6# L-80 IBT tubing 4-1/2" Camco 'DB' nipple wI 3.75" No-Go profile. 1 jt4-1/2" 12.6# L-80 IBTtubing Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly wI 15' stroke, 4-1/2" L-80 IBT box up Liner Assembly (run on driliDipe), set Câ>. +1- 6586' MD Baker 7" x 4-1/2" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7,/ 4-1/2" 'Flexlock' Liner Hanger Baker 12' Seal Bore Extension XO Sub, 5" Stub Acme box x 4-1/2" NSCT pin 4-1/2" 12.6# L-80 NSCT liner as needed 4-1/2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 NSCT casing 4-1/2" Baker Float Shoe ORIGINAL SLL, 12119/01 v1 , .. , , , " " , ' '; """:A:RCO'Åla~'Inc.""': ":"':,""',~",.,;-">,,',,,>" ~,' ":,, tlie:F~'Natì~ftal"a~~¡oiqíi'~~~7~O¡ ," "',', " ,,' ','" ,c~cilgQ~'liÙJ)Õi~, AccÖ\sn1."O~9OOOI}:" , ,""PayilbleThfough, ," " " ,Republic Bank, ShelbYVllle..K(t~OO376 " , " , , ,,', , , :.' , " .. " , , " " " ::;r::r~r:, Phillips Alaska, Inc. ~~f~~~¡~:;:~l~i!¡~t \! ~~~~~:~1~J~~~~~ j¡ ¡)'l)j:¡ ,:' ':' " ,',', " , ,,' """ , , .. ,': , , , "",,"" :":' " , '" ',', " '" ',', ", ,.,J,) ,'"""..,",' .. :-::::::=::,:" ,"', :', ,',:..,':' ," :" " :'::.':- ,::/' " "" "", ":',,:" "::,, " ,,' :'::': ",:" , , , " "'" ":, ,:,',..: ,.... " , , ::'t6..Ú¡eqrder ôf: "?T1:\~1:!i :.9¥:ALÄs~ ,~~:~r: A~i 1:2;-19;'01 AmÞÚnt :. y Óig ~fiet:9p'd~Ys " " ,:~t!I~~::, ~~' 995 Qî3Š~:9' '.. " ':, ¡: , , " ':' \,,",':,,:i:,:/ ',:,':' ',' ',: ,: ,"",..::" "',' "" " "",' ,',' , :"'"" ':,' "'" ,,"':"'" ',,", , "" ,," """ S1&~¡,~~U¡il~l~:;i~l,~jil::~QLtill~:l.~K~L;~;~" .- " ""..:" "" ",'" ..,," :,: ,.:- :,:, ., .'\::: ::,:, ,..~'::~~:L~~.:,:~~,.,.::~:~,~L.~:::::::",:..;,:'::::'.,...".., , " ',,' ,':~;;'~::;;::.~,.,~.,,:..~:::~:::L~:,I,;:,l.':;;,jLLL_::j;::.:Ù~.:~:::":,¿::._:¡,:;,;:.L::"".:;,~:::,:,.,_.", ::.:;::~,.:, , , ., , 1<1:: \i~:rl~t~i-E'~ '¡:.q;¡jiitd" , '...r arr,i:.urw ':'\0>.," ~~~,,(r(lll I,l'.' :' ': " " III 0 0 0 0 . 0 . a 7, b III I:OB ~gtJ~2b 21: Og gOOOOll1 'It ( , TRANSMIT AL LETTER CHECK LIS\ CIR CLE APPRO PRIA TE LETTERIP ARA GRAPHS TO BE INCLUDED IN TRANSMITTAL LETTE, WELL NAME ke!~ /(!~Zt CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA T]ON INJECTI °7 ]NJECT]ON WELL REDRILL CHECK WHAT APPLIES ADD-ONS OPTIONS MULTI LATERAL (If api number last tWG (2) digits are between 6.0-69) P~OT HOLE (PH) . ANNULAR DISPOSAL L-)NO ANNULAR D]SPOSAL L-) YES ANNULAR DISPOSAL THIS WELL D]SPOSAL ]NT ANNULUS SP AC]NG EXCEPT]ON Templates are I.ocated m drive\j.ody\templates "CLUE" The permit is fGr a new wellbGre segment .of existing well . Permit NG, . API NG. . . ProductiGn shGuld cGntinue tG be rep.orted as a functiGn.of the .original API number stated ab.ove. ]n accGrdance with 20 AAC 25..0.05(1), all rec.ords, data and logs acquired fGr the pil.ot hGle must be clearly . differentiated in b.oth name (name .on permit plus PH) and API number (5.0 -7.0/8.0) fr.om recGrds, data and IGgs acquired f.or well(name .on permit). Annular dispGsal has n.ot been requested. . . Annular DispGsal .of drilling wastes will n.ot be appr.oved . . . Annular DispGsal .of drilling wastes will n.ot be apprGved .. . Please nGte that an disP.osal .of fluids generated... . EnclGsed is the apprGved applicati.on fGr permit t.o drill the abGve referenced well. The permit is apprGved ,sùbject t.o full cGmpliance with 2.0 AAC 25..055. Appr.oval tG perf Grate and produce is cGntingent up.on issuance .of a c.onservation .order appr.oving a spacing exceptiGn. (Companv Name) will assume the liability .of any prGtest t.o the spacing exceptiGn that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION A~ DATE AlL /Z.20..[')1 ENGINEERING GEOLOGY AP APPR DATE W GA- . /i-Iu,,/ () { COMP ANY INIT CLASS c:\msoffice\wordian'.diana\checklist (rev. 11/01/100) PROGRAM: exp - dev - redrll GEOLAREA N N 'I N ¡ t (,if @ /1-1 lAD N £~~sc;. ~~ y\Rc;'-C,L- N N ~ Eo ðì!) "Q{' Cf S Ç. N N N 7.-41; G N ¡V/A N N N N Y N ~¡ serv well bore seg _ann. disposal para req - UNIT# o///&() ON/OFF SHORE Þ1 ( i-¡.I C... G.( @N Y~ ~ Çc..L b..t: ( .:J <.-i.J .¡,.. , 0 ' j kUê/Ä- /e -- 02 2..- I c!. -0'3 /~¿J_f.-4:;J(J ~33 ~- 55,- ~ -../~. 2-C>o/ 2t ~,~ ;zt:D~;-¿.-:;r é: ><¿j1..¿.: C: ~ é?- r- v c> /' r ~ u r4Z-- LA V7'l 4-¿$ I))SlgC;õv/ ~to ~~'ff~J CtrLU?LIUS . , Com ments/lnstructions: c 0 Z 0 -I ~ ::0 - -I m - z -I :I: - en yFt!) )- ::0 m » ~' ' ( 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. .. . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available. in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . .'. . . . . 19. Casing designs adequate for C. T. 8 & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . APPR D¡A T~l 26. BOPE press rating appropriate; test to E; 000 psig. ~ / L 'l- 0(' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. . 28. Work. will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Pennit can be issued wlo hydrogen sulfide measures. . . . ,. Y N' 31. Data presented on potential overpressure zones. . . . . . . Y , 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . A A Y N DATE '33. Seabed condition survey (if off-shore). . . . . . . . '.' ~ Y N It... '20.Ö 34. Contact name/phone for weekly progress reports [ex~tory only} Y N ANNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; " (C) will not impair mechanical integrity ~f the well used for disposal; (0) will not damage producing formation or impair recovery from a pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLO,GV: r-E~: UIC'Annular COMMISSION: ~ WM '8~s ~~~ JMH - tz.!2(c tD) ( 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 APPENDIX. No special' effort has been made to chronologically" . organize this category of intonnation. { 'U \ L- Memory Multi-Finger Caliper Log Results Summary ÅOJ - 2\;{ 8 Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 19, 2005 7014 1 4.5" 12.6 lb. L-80 NSCT liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 C-24 Kuparuk Alaska 50-029-23063-00 7,600 Ft. (MD) 7,800 Ft. (MD) Inspection Type : Mill Out Obstruction Inspection COMMENTS: This log is tied into the end of the tubing tail @ 6,654' (Driller's Depth). This log was run to assess the condition of the 4.5" liner and identify possible obstructions or other causes of interference in mill out operations. The caliper recordings indicate severe deformation and ovality in the liner (7,698' - 7,728'). A minimum I.D. of 3.42" is recorded in the most severe oval restriction. A 3-D log plot of the caliper recordings across an interval of oval tubing is included in this report. The joint numbering used in this report is an estimation based on average joint length and depth logged. Due to the deformation of the pipe, accurate wall penetration information is unobtainable throughout the interval of ovality (7, 700' - 7,740). ~:ri\ 1 "'-~i"" S E P .r} ~I '2 0 ('~ '~; ;S,Çi\r~~~'f;,fJ ,\..; ;(,~) - ,.' ..h, I Field Engineer: W McCrossan Analyst: M. Lawrence Witness: T. Hove ProActIve Diagnostic Services, Inc. / 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 Q, Description : Commpnts Joint 243 Perforations Joint 244 I I I II I Joint 245 I Severe I Ovality I Min. I.D. = 3.42" (7,701') Joint 246 Ovality Perforations ( PDS Multi\lIlger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 1 C-24 Date: August 19, 2005 Detail of Caliper Recordings Across OvaJity of Tubing % ~ooo MIN In (1/1000 inJ 500 ~OOO MAX 10 (1/1000 inJ ~oo" 1503000 Nomin:aII.O. ____~oo.o 7660 7670 7680 7690 7700 7710 7720 7730 7740 ..,..,ron < t ~I ---- -----'-..----- ;,. > . ') , -----,----~'-~- ..I~ .-., ---. --,~ - -- - -- ..'~---- ~ -. -- - - ,-". - --~ -,--- ---., -- --- , ~ \. ,. --------- ,;, ---. ..-. - --'-- - .._ __0-_-- _ _ _ _.' . _.,_._. -~ .-- -.- -- ._- .-- -- - ________w_.__ --_.- -" - -- -- --- l. ~. ~._. - --- -... - -~--- -_. -- _. .'-"-- -- \" ,----------,- ~ ,-> ~-~ ----;/ ~ C-- ---\ -i "t.- -.iI =-----~--~-,---"-----= ---------- ~ (---- "' / ¿~ -- - - -- _._~ -.-. --- -- -.- ,..- ~ .,,¡; ---~--------'---- 0/ : "', , ..: . ,. \, ~ ~ (. ~ . ----, --.. -" ----, -- -- --7;--- -.- ---~--- I \~~t~~;~~~ :jll :~lþ!,':I\''' . -'~~i",-'I ~ ~ ~-'l ~ < PDS Multi\.lIger Caliper 3D Log Plol Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 1C-24 Date: August 19, 2005 Detail of Caliper Recordings Across Ovality of Tubing % ~ooo MIN In (1/1000 inJ 500 ~OOO MAX In (1/1000 in..) ~OO" 3003000 N.Qmin;¡ltn. _50_no ~- Jas Description: Commpnts Joint 241 ~erforations 7610 Joint 242 7620 Perforations 7630 7640 Joint 243 7650 Perforations 7660 7670 7680 Joint 244 ------.- ~-,----, --~=---,~---= -~= .~- ,... ___~~____"'_l____"~~~._~_._.__.h ~~__ , -------- --- - - -- - ---- -- --- -- --- ---------1:------------.------ 'II,¡ _._____ .., . ~ __ __ ~. - ._u _ ____.. _~_ ._". -------------- t- ---- ---------~-------- .., --- ----~ -- - ----,--,- ,-- -.-, ---- l ---"-------- -- - -- .--. .,,- - "-- -- -- - ..... .-.----,--. -,--_.~._--- ..- --- .--- -.- .-' ----- ~ ~ ~. I - --- ----- ---, ---- -".--..---. - _.~---- ---- -- ..--..- "-. ..--.-- -- -. ~ - -"--,- ---. -- -. ---.- 7690 _____ --------l..~\--- -_ ____ ,_ ___ ___ .-------.-----...---.-. ---~~.__._..._----- 7700 Joint 245 Severe 7710 Ovallty Min. 1.0. = 3.42" 7720 (7,701') 7730 7740 Joint 246 Ovality 7750 Perforations 7760 7770 Joint 247 Perforations 7780 7790 Joint 248 " "^'"'ft....+iftn... '7'onn \ . --.--------- -----'---~--~~ j) -- ---- . ~ -.,... -- -,---- - --- --- ======~~:r~--=== =====:::-=--~~- - -----,------ --~ r - <......, !:' -- -----~ .__ .___ ,_ ,_ I , --,--- '- " -) ;- l~ -------1: --- f~ ___________ I, ~ .?-i ,( ..- '-'- ... ' -----,--- -.-----..- -_._-_.._---~ ., , .--- -- -- -- --- ----- --"1{;' :- " --~--'-_..- t, .' -,--,---- ~-- -'- --- - ----.- !~ j I -,~~.I-.:~_~"'~,:,~ ~:'-J~- ~~~::, ~. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 09 08:15:58 2002 Reel Header Service name............ .LISTPE Date.....................02/05/09 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date.....................02/05/09 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11218 D. LABRECQUE J. PYRONE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MM-11218 P. SMITH M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) Writing Library. Writing Library. '¡ a C:J/-aL/ 8 /O'65~ Scientific Technical Services Scientific Technical Services 1C-24 500292306300 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 09-MAY-02 MWDRUN 2 AK-MM-11218 D. LABRECQUE J. PYRONE 12 11N 10E 1668 1289 101.60 60.60 MWDRUN 3 AK-MM-11218 T. GALVIN J. PYRONE { 1 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 120.0 4711.0 6835.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS 4. MWD RUNS 2 - 4 WERE DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , AND PRESSURE WHILE DRILLING (PWD). THERE IS A 2 FOOT DATA GAP IN EWR DATA BETWEEN MWD RUNS 3 & 4 DUE TO DIFFERENT TOOL STRING LENGTHS. 5. MWD DATA ARE THE PRIMARY DEPTH CONTROL PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, INC., DATED 2/18/02, QUOTING AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. THERE IS AN APPARENT 22' DEPTH DISCREPANCY FOR THE 711 CASING SHOE. BASED ON A REVIEW OF MWD DATA AND SESSION LOGS, AND A COMPARISON OF A WIRELINE GAMMA RAY (CBL) WITH THE SGRC BY BOTH PHILLIPS AND SSDS STAFF, THE ISSUE REMAINS UNRESOLVED. 6. MWD RUNS 1 - 4 REPRESENT WELL 1C-24 WITH API#: 50-029-23063-00. THIS WELL REACHED A'TOTAL DEPTH (TD) OF 9350'MD/6548.49'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 I' '~. Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 134.0 166.5 4687.0 4687.0 4687.0 4687.0 4687.0 STOP DEPTH 9297.0 9349.5 9304.0 9304.0 9304.0 9304.0 9304.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 134.0 4720.0 6850.0 8862.0 MERGE BASE 4720.0 6850.0 8862.0 9349.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max First Reading Last Reading Mean Nsam ,I , DEPT FT 134 9349.5 4741.75 18432 134 9349.5 ROP MWD FT/H 0.04 621.47 117.634 18367 166.5 9349.5 GR MWD API 16.94 427.63 94.9454 18327 134 9297 RPX MWD OHMM 0.72 1349.93 6.45611 9200 4687 9304 RPS MWD OHMM 0.72 1138.31 6.80406 9200 4687 9304 RPM MWD OHMM 0.66 2000 21.822 9200 4687 9304 RPD MWD OHMM 0.41 2000 18.3441 9200 4687 9304 FET MWD HOUR 0.2 70.84 2.75298 9200 4687 9304 First Reading For Entire File......... .134 Last Reading For Entire File.......... .9349.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 134.0 166.5 STOP DEPTH 4687.0 4720.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 04-JAN-02 Insite 66.37 Memory 4720.0 134.0 4720.0 .3 26.2 # TOOL STRING (TOP TO BOTTOM) :1 ~ I', " VENDOR TOOL CODE DGR $ TOOL TYPE DUAL GAMMA RAY TOOL NUMBER PB02376HG8 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER1S CASING DEPTH (FT): 12.250 116.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 9.50 52.0 9.3 300 5.0 108.1 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 134 4720 2427 9173 134 4720 ROP MWD010 FT/H 1 621.47 144.558 9108 166.5 4720 GR MWD010 API 16.94 136.03 74.4716 9107 134 4687 First Reading For Entire File......... .134 Last Reading For Entire File.......... .4720 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 4687.0 4687.0 4687.0 4687.0 4687.0 4687.5 4720.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 6792.0 6792.0 6792.0 6792.0 6792.0 6799.0 6850.0 09-JAN-02 Insite 66.16 Memory 6850.0 4720.0 6850.0 18.9 54.2 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02391WF4 PB02391WF4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 8.500 4711.0 LSND 10.00 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 49.0 9.3 800 5.4 5.700 4.280 1.920 2.200 90.0 122.2 90.0 1.9 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4687 6850 5768.5 4327 4687 6850 ROP MWD020 FT/H 0.58 382.62 123.057 4260 4720.5 6850 GR MWD020 API 32.66 427.63 148.503 4224 4687.5 6799 RPX MWD020 OHMM 0.72 1349.93 3.19337 4211 4687 6792 RPS MWD020 OHMM 0.72 1138.31 2.97975 4211 4687 6792 RPM MWD020 OHMM 0.66 1527.36 3.45387 4211 4687 6792 RPD MWD020 OHMM 0.72 2000 19.9056 4211 4687 6792 FET MWD020 HOUR 0.2 70.84 2.15981 4211 4687 6792 First Reading For Entire File......... .4687 Last Reading For Entire File.......... .6850 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 ¡ " Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6799.5 6808.0 6808.0 6808.0 6808.0 6808.0 6850.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 8807.0 8814.0 8814.0 8814.0 8814.0 8814.0 8862.0 14-JAN-02 Insite 66.16 Memory 8862.0 6850.0 8862.0 63.0 95.2 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02387HAGR4 PB02387HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 6.125 6835.0 LSND 10.30 44.0 ¡ MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.5 400 4.0 1.970 1.070 1.930 1.990 70.0 135.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6799.5 8862 7830.75 4126 6799.5 8862 ROP MWD030 FT/H 0.04 236 71.4131 4024 6850.5 8862 GR MWD030 API 33.51 238.43 93.934 4016 6799.5 8807 RPX MWD030 OHMM 1.68 605.78 9.10402 4013 6808 8814 RPS MWD030 OHMM 1.14 1086.75 10.0213 4013 6808 8814 RPM MWD030 OHMM 1.22 2000 43.8337 4013 6808 8814 RPD MWD030 OHMM 0.41 2000 18.4135 4013 6808 8814 FET MWD030 HOUR 0.4 67.24 2.87796 4013 6808 8814 First Reading For Entire File......... .6799.5 Last Reading For Entire File.......... .8862 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 ,{ header data for each bit run in separate files. 4 .5000 START DEPTH 8807.5 8816.5 8816.5 8816.5 8816.5 8816.5 8862.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 9297.0 9304.0 9304.0 9304.0 9304.0 9304.0 9349.5 16-JAN-02 Insite 66.16 Memory 9350.0 8862.0 9350.0 77.5 92.9 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02387HAGR4 PB02387HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 6.125 6835.0 LSND 10.30 49.0 9.9 \( ) II1I MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 200 3.2 1.850 .930 1.800 2.200 73.0 152.0 73.0 73.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8807.5 9349.5 9078.5 1085 8807.5 9349.5 ROP MWD040 FT/H 1.33 90.96 33.1971 975 8862.5 9349.5 GR MWD040 API 34.74 95.66 58.5058 980 8807.5 9297 RPX MWD040 OHMM 4.14 26.69 9.64599 976 8816.5 9304 RPS MWD040 OHMM 4.12 30 10.0758 976 8816.5 9304 RPM MWD040 OHMM 4.11 31.17 10.5674 976 8816.5 9304 RPD MWD040 OHMM 4.22 31.22 11.3209 976 8816.5 9304 FET MWD040 HOUR 1.1 28.34 4.7984 976 8816.5 9304 First Reading For Entire File......... .8807.5 Last Reading For Entire File.......... .9349.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/09 Maximum Physical Record. .65535 { File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/05/09 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name............ .LISTPE Date.....................02/05/09 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ¡ '\ Scientific Technical Services Scientific Technical Services