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Home My WebLink About200-164C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-17_22232_KRU_1D-42_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22232 KRU 1D-42 50-029-22979-00 Archer VIVID Acoustic LDL 17-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 200-164 T40795 8/22/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.22 08:18:27 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8660'feet None feet true vertical 6399' feet None feet Effective Depth measured 8514'feet 5582', 7828', 7912', 8008' feet true vertical 6301'feet 4397', 5855', 5910', 5972' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 7887' 8000' 5893' 5967' Packers and SSSV (type, measured and true vertical depth)5582' 7828' 7912' 8008' 4398' 5855' 5910' 5972' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 324-350/324-479 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB Blue Packer: SLB Blue Packer: SLB Blue Packer: Baker ZXP SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049Staff RWO/CTD Engineer 8430-8460' 6246-6265' 659' 3-1/2" measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 91' Well Shut-In measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-164 50-029-22979-00-00 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: ADL0025650, ADL0025661 Kuparuk River Field/ Kuparuk Oil Pool KRU 1D-42 Plugs Junk measured Length Production 5081' 3073' Casing 4099' 6088' 5116' 8187' 8660' 6399' 5277' 91'Conductor Surface Production 20" 9-5/8" 57' 5312' 4225' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Liner By Grace Christianson at 4:24 pm, Sep 18, 2024 Page 1/12 1D-42 Report Printed: 9/17/2024 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) 8/8/2024 10:00 8/8/2024 12:00 2.00 MIRU, MOVE RURD P MIRU complete Pre acceptance checklist. 8/8/2024 12:00 8/8/2024 12:45 0.75 MIRU, MOVE RURD P Start loading pits at 12:00. Finish rigging up to kill well in cellar and on rig floor. 8/8/2024 12:45 8/8/2024 13:30 0.75 MIRU, MOVE WAIT T Vac truck pony motor stopped running. Waiting on 3rd truck to continue. 8/8/2024 13:30 8/8/2024 14:15 0.75 MIRU, MOVE RURD P Continue loading pits after truck was repaired. 8/8/2024 14:15 8/8/2024 15:30 1.25 MIRU, WELCTL KLWL P Load well with 8.5# seawater down tubing taking returns up the IA. PR=11 BPM 1100 PSI 8/8/2024 15:30 8/8/2024 16:30 1.00 MIRU, WELCTL OWFF P OWFF for 30 minutes. 0 PSI No flow 8/8/2024 16:30 8/8/2024 17:00 0.50 MIRU, WELCTL MPSP P Set BPV. Perform rolling test to 500 PSI. 8/8/2024 17:00 8/8/2024 19:30 2.50 MIRU, WHDBOP NUND P ND tree and adapter. Function test lift threads with X-O 8 turns. Install test dart in hanger neck. FT LDS. 8/8/2024 19:30 8/8/2024 21:30 2.00 MIRU, WHDBOP NUND P NU DSA and BOPE. 8/8/2024 21:30 8/9/2024 00:00 2.50 MIRU, WHDBOP BOPE P Rig up BOP test equipment. Flood lines. 8/9/2024 00:00 8/9/2024 09:00 9.00 MIRU, WHDBOP BOPE P Initial BOPE test All tests at 250/3500 PSI for 5 Min each. Tested annular, UVBR's, W/3-1/2" Test joint. Tested annular and LPR w/7" test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3-1/2" HT38 floor valve and IBOP. Tested 2" rig floor Demco kill valves. Tested manual and HCR kill valves and manual and HCR choke valves. Tested hydraulic and manual choke to 1500 PSI and demonstrate bleed off. Performed accumulator draw test. Initial pressure=3140 PSI, after closure=1600 PSI, 200 PSI attained =25 sec, full recovery attained =117 sec. 5 back up nitrogen bottles average =2050 PSI. Function tested. UPR=6 Sec, LPR=6 Sec Annular=29 Sec. Simulated Blinds=6, HCR Kill=1 Sec. HCR Choke=1 Sec. Test gas detectors, P.V.T. and flow show. Accumulator 3 position 4 way valve Fail/Pass. Replaced valve and functioned properly. Test witnessed waived by AOGCC rep Austin McLeod. 0.0 0.0 8/9/2024 09:00 8/9/2024 09:30 0.50 COMPZN, RPCOMP RURD P R/D BOP test equipment, blow down lines. Set up to pull tubing. 0.0 0.0 8/9/2024 09:30 8/9/2024 09:45 0.25 COMPZN, RPCOMP MPSP P FMC pull test dart, and BPV. 0.0 0.0 8/9/2024 09:45 8/9/2024 10:00 0.25 COMPZN, RPCOMP PULL P M/U landing joint to tubing hanger, and pull to rig floor. PUW=110K weight broke back to 90K 0.0 7,995.0 8/9/2024 10:00 8/9/2024 10:45 0.75 COMPZN, RPCOMP CIRC P Circulate SxS 7,995.0 7,995.0 8/9/2024 10:45 8/9/2024 11:00 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes. 7,995.0 7,995.0 8/9/2024 11:00 8/9/2024 18:00 7.00 COMPZN, RPCOMP PULL P LD tubing F/7995/ T/ Surface. Cut joint 15.69' long. 7,995.0 0.0 8/9/2024 18:00 8/9/2024 19:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor. R/D power tongs, and other 3.5" handling equipment from the rig floor. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 2/12 1D-42 Report Printed: 9/17/2024 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) 8/9/2024 19:00 8/9/2024 19:30 0.50 COMPZN, RPCOMP OTHR P Install wear ring. 0.0 0.0 8/9/2024 19:30 8/9/2024 21:00 1.50 COMPZN, RPCOMP ELNE P Spot in and rig up Yellow Jacket E-line. Pick up Caliper BHA. 0.0 0.0 8/9/2024 21:00 8/10/2024 00:00 3.00 COMPZN, RPCOMP ELOG P Yellow Jacket E- line RIH F/ surface to 5500'. POOH logging up. Observed suspected buckling on caliper log @ 5301' 0.0 0.0 8/10/2024 00:00 8/10/2024 01:00 1.00 COMPZN, RPCOMP ELOG P Yellow jacket E-line continue logging out of the hole with Caliper BHA. 0.0 0.0 8/10/2024 01:00 8/10/2024 02:00 1.00 COMPZN, RPCOMP ELNE P Yellow Jacket E-line B/D L/D Caliper BHA. P/U M/U CBL BHA 0.0 0.0 8/10/2024 02:00 8/10/2024 06:00 4.00 COMPZN, RPCOMP ELOG P YJOS RIH to 5500' Logging out of the hole for CBL. 0.0 0.0 8/10/2024 06:00 8/10/2024 07:00 1.00 COMPZN, RPCOMP ELOG P RD E-line. 0.0 0.0 8/10/2024 07:00 8/10/2024 09:30 2.50 COMPZN, RPCOMP RURD P Complete processing 3.5" tubing. load BHA in pipe shed. e-xray stand pipe repairs. 0.0 0.0 8/10/2024 09:30 8/10/2024 10:00 0.50 COMPZN, RPCOMP SFTY P PJSM to PU BHA and PU DP. 0.0 0.0 8/10/2024 10:00 8/10/2024 12:00 2.00 COMPZN, RPCOMP BHAH P PU BHA #1 7" casing drift. 0.0 281.3 8/10/2024 12:00 8/10/2024 17:00 5.00 COMPZN, RPCOMP PULD P Start RIH P/U singles of 3.5" DP with BHA F/281.3' T/5390' 281.3 5,390.0 8/10/2024 17:00 8/10/2024 17:30 0.50 COMPZN, RPCOMP BKRM P Rack back one stand, and back ream through CSG F/ 5296' to 5011'. PUWT: 120 K SOWT: 75 K ROTWT: 100K 5K TQ @ 50 RPM Pumping 210 GPM @ 800 PSI> 5,390.0 5,011.0 8/10/2024 17:30 8/10/2024 18:00 0.50 COMPZN, RPCOMP CIRC P Circulate Bottoms up @ 210 GPM @ 800 PSI. 5,011.0 5,011.0 8/10/2024 18:00 8/10/2024 18:30 0.50 COMPZN, RPCOMP OWFF P Flow check 15 min: Static 5,011.0 5,011.0 8/10/2024 18:30 8/10/2024 20:30 2.00 COMPZN, RPCOMP TRIP P POOH F/ 5011' to 281'. 5,011.0 281.0 8/10/2024 20:30 8/10/2024 21:45 1.25 COMPZN, RPCOMP BHAH P L/D BHA # 1 (Drift BHA). 281.0 0.0 8/10/2024 21:45 8/10/2024 23:00 1.25 COMPZN, RPCOMP BHAH P P/U BHA #2 (RBP, and test plug). 0.0 36.0 8/10/2024 23:00 8/11/2024 00:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 180'' to 687'. 36.0 687.0 8/11/2024 00:00 8/11/2024 02:15 2.25 COMPZN, RPCOMP TRIP P Cont. to RIH W/ BHA # 2 F/ 687' to 5250'. 687.0 5,250.0 8/11/2024 02:15 8/11/2024 03:15 1.00 COMPZN, RPCOMP MPSP P Set RBP @ 5250' POOH to 5100' Set test packer 5,250.0 5,100.0 8/11/2024 03:15 8/11/2024 03:45 0.50 COMPZN, RPCOMP MPSP P Rig up and pressure test RBP to 1000 PSI for 30 min. 5,100.0 5,100.0 8/11/2024 03:45 8/11/2024 04:30 0.75 COMPZN, RPCOMP MPSP P Release test packer and OWFF 10 min 5,100.0 5,100.0 8/11/2024 04:30 8/11/2024 06:45 2.25 COMPZN, RPCOMP TRIP P POOH F/ 5100' to surface. 5,100.0 35.8 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 3/12 1D-42 Report Printed: 9/17/2024 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) 8/11/2024 06:45 8/11/2024 07:15 0.50 COMPZN, RPCOMP BHAH P LD BHA/ PU 3-1/2" mule shoe 35.8 6.0 8/11/2024 07:15 8/11/2024 08:30 1.25 COMPZN, RPCOMP TRIP P TIH W/mule shoe and X-O F/6' T/5145' 6.0 5,145.0 8/11/2024 08:30 8/11/2024 12:15 3.75 COMPZN, RPCOMP OTHR P Dump 50' of sand on top of plug. Shut down for 30 minutes allow to sand to fall. 5,145.0 5,145.0 8/11/2024 12:15 8/11/2024 14:00 1.75 COMPZN, RPCOMP TRIP P TOOH F/5145 to surface. 5,145.0 0.0 8/11/2024 14:00 8/11/2024 14:45 0.75 COMPZN, RPCOMP NUND P ND BOP's and pull wear ring. 0.0 0.0 8/11/2024 14:45 8/11/2024 15:15 0.50 COMPZN, RPCOMP RURD P RU FMC and Cameron equipment to grow casing. 0.0 0.0 8/11/2024 15:15 8/11/2024 17:00 1.75 COMPZN, RPCOMP OTHR P Grow casing total growth recorded 13.75" 0.0 0.0 8/11/2024 17:00 8/11/2024 17:30 0.50 COMPZN, RPCOMP OTHR P R/D Cameron equipment in the cellar 0.0 0.0 8/11/2024 17:30 8/11/2024 18:00 0.50 COMPZN, RPCOMP BHAH P P/U and M/U Baker fishing spear. 0.0 0.0 8/11/2024 18:00 8/11/2024 18:30 0.50 COMPZN, RPCOMP OTHR P Engage 7", and pull into 50 K tension. 0.0 0.0 8/11/2024 18:30 8/11/2024 19:30 1.00 COMPZN, RPCOMP OTHR P R/U come a longs to center 7" in well head. FMC install, and drop slips in tubing head. Slack off setting tension in slips. FMC cut 7". 0.0 0.0 8/11/2024 19:30 8/11/2024 20:00 0.50 COMPZN, RPCOMP OTHR P Disengage spear, and pull to rig floor. L/D Cut 7". 0.0 0.0 8/11/2024 20:00 8/11/2024 22:00 2.00 COMPZN, RPCOMP NUND P N/U BOP. 0.0 0.0 8/11/2024 22:00 8/11/2024 22:30 0.50 COMPZN, RPCOMP BHAH P P/U Multi string cutter BHA and M/U. 0.0 0.0 8/11/2024 22:30 8/12/2024 00:00 1.50 COMPZN, RPCOMP TRIP P RIH F/ surface to 3315'. 0.0 3,315.0 8/12/2024 00:00 8/12/2024 00:15 0.25 COMPZN, RPCOMP OTHR P Unannounced kick while tripping drill. Well secure 83 seconds. Personel on station in 1 min 20 seconds. AAR held with crew. 3,315.0 3,135.0 8/12/2024 00:15 8/12/2024 02:00 1.75 COMPZN, RPCOMP TRIP P Cont. to trip in the hole F/ 3135' to 5082'. PUWT: 105 K SOWT: 85 K 3,135.0 5,082.0 8/12/2024 02:00 8/12/2024 02:30 0.50 COMPZN, RPCOMP CPBO P Turn on pumps and locate collar @ 5199.47'. Set down 10 K to confirm. P/U 20' from collar and make cut @ 5099.44'. Pump @ 168 GPM @ 800 PSI. Observe pressure drop to 425 PSI as cutter blades moved to fully extended. Indicating good cut. Pumping 166 GPM @ 800 PSI. 5,082.0 5,099.4 8/12/2024 02:30 8/12/2024 03:30 1.00 COMPZN, RPCOMP CIRC P Start to CBU. Observe well U-tubing between IA, and OA. Diesel back to surface. Shut down pump. Line up to tiger tank and circulate until 8.5 Back to surface. 5,099.4 5,099.4 8/12/2024 03:30 8/12/2024 04:00 0.50 COMPZN, RPCOMP OTHR P Blow down lines. Flush through stack 5,099.4 5,099.4 8/12/2024 04:00 8/12/2024 06:30 2.50 COMPZN, RPCOMP TRIP P POOH F/ 5099.44' to surface. 5,099.4 12.0 8/12/2024 06:30 8/12/2024 07:30 1.00 COMPZN, RPCOMP RURD P RD DP handling tools RU 7" Casing tools. 12.0 12.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 4/12 1D-42 Report Printed: 9/17/2024 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) 8/12/2024 07:30 8/12/2024 08:15 0.75 COMPZN, RPCOMP BHAH P LD 7" casing spear break down BHA. 12.0 0.0 8/12/2024 08:15 8/12/2024 08:45 0.50 COMPZN, RPCOMP SVRG P Service top drive. 0.0 0.0 8/12/2024 08:45 8/12/2024 13:45 5.00 COMPZN, RPCOMP PULL P LD Casing F/5099 T/surface PUW=150K 5,099.0 0.0 8/12/2024 13:45 8/12/2024 14:45 1.00 COMPZN, RPCOMP RURD P RD from testing casing. Set upper test plug. 0.0 0.0 8/12/2024 14:45 8/12/2024 15:30 0.75 COMPZN, RPCOMP BOPE P Test tubing head to 13-5/8" x 11" DSA break to 250/3500 PSI. 0.0 0.0 8/12/2024 15:30 8/12/2024 16:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor, R/D test equipment. Blow down lines. 0.0 0.0 8/12/2024 16:00 8/12/2024 16:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 8/12/2024 16:30 8/12/2024 18:15 1.75 COMPZN, RPCOMP OTHR P Prepare Back off BHA in pipe shed. 0.0 0.0 8/12/2024 18:15 8/12/2024 18:30 0.25 COMPZN, RPCOMP BHAH P PJSM w/ Crew to pick up Back off tool. 0.0 0.0 8/12/2024 18:30 8/12/2024 21:00 2.50 COMPZN, RPCOMP BHAH P P/U Back off BHA. 0.0 93.0 8/12/2024 21:00 8/13/2024 00:00 3.00 COMPZN, RPCOMP TRIP P RIH w/ Back off tooll F/ 93' to 5100'. PUWT: 106 SOWT: 86 93.0 5,100.0 8/13/2024 00:00 8/13/2024 01:00 1.00 COMPZN, RPCOMP TRIP P Cont. to RIH F/ 5100' to 5203'. Tag top of sand on top of RBP @ 5302'. Set down 5K to confirm. Space out Back off tool around casing collar @ 5119'. 5,100.0 5,197.0 8/13/2024 01:00 8/13/2024 01:30 0.50 COMPZN, RPCOMP RURD P L/D singe. R/U test pump, and lines to function back off tool. 5,197.0 5,197.0 8/13/2024 01:30 8/13/2024 08:45 7.25 COMPZN, RPCOMP CPBO P Pressure up Back off tool to 1000 PSI, and wait 5 min. Slack off 5K to confirm lower slips are set. Pressure up on Back off tool again to 3500 PSI. Bleed off and wait 5 min. Slack off an aditional 5K and confirm upper slips set on tool. Set string in slips. Pressure up to 3500 PSI, and bleed off. Allowing tool to relax for 10 min. Repeat 3500 PSI/ 10 min reset cycle decreasing pressure to 1000 PSI untill 4 rotations.were attained Released BO tool PUW=130K tool released weight broke back to 110K SO to sand top at 5203' SOW=85K Drop circ sub dart allow to fall. Screw in with top drive 5,197.0 5,197.0 8/13/2024 08:45 8/13/2024 09:15 0.50 COMPZN, RPCOMP CIRC P Circulate through circ sub at 11 BPM= 575 PSI. 5,197.0 5,197.0 8/13/2024 09:15 8/13/2024 11:00 1.75 COMPZN, RPCOMP TRIP P TOOH F/5197' T/ 130.7 5,197.0 130.7 8/13/2024 11:00 8/13/2024 12:30 1.50 COMPZN, RPCOMP BHAH P LD BHA 130.7 0.0 8/13/2024 12:30 8/13/2024 13:30 1.00 COMPZN, RPCOMP CLEN P Clean and clear floor RU run Clean out 0.0 0.0 8/13/2024 13:30 8/13/2024 16:30 3.00 COMPZN, RPCOMP BHAH T PU 9-5/8" clean out BHA #7 PU 2 stands of collars set down 10K at 185' PU reconfigure less rigid BHA. RIH to 185 set down 10K work pipe unable to get past 185'. 0.0 185.0 8/13/2024 16:30 8/13/2024 19:30 3.00 COMPZN, RPCOMP TRIP P MU, string mill and bullnose TIH F/185' T/1,676' 185.0 1,676.0 8/13/2024 19:30 8/13/2024 20:30 1.00 COMPZN, RPCOMP SLPC P Slip and cut drill line (68') 1,676.0 1,676.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 5/12 1D-42 Report Printed: 9/17/2024 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) 8/13/2024 20:30 8/13/2024 21:00 0.50 COMPZN, RPCOMP TRIP P TOOH, w/BHA #8 F/1,676' T/BHA 1,676.0 229.2 8/13/2024 21:00 8/13/2024 22:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #8 229.2 0.0 8/13/2024 22:00 8/13/2024 22:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #9 w/ported bull nose, tandem 8.5" string mills, flex joint, boot baskets x 2, bumper jar, DC x 6. (243.04') Made past 185' w/7-10k Down weight Set down and work pipe 15k. unable to pass 270.83' 0.0 270.8 8/13/2024 22:30 8/13/2024 23:30 1.00 COMPZN, RPCOMP TRIP P POOH, lay out string reamer 6.23' in length. (227.99') MU BHA #9 270.8 0.0 8/13/2024 23:30 8/14/2024 00:00 0.50 COMPZN, RPCOMP TRIP P TIH 227.1 400.0 8/14/2024 00:00 8/14/2024 00:30 0.50 COMPZN, RPCOMP TRIP P Continue IH w/9-5/8" drift/cleanout assembly F/400' PUW=45k, SOW=45k 400.0 586.0 8/14/2024 00:30 8/14/2024 01:30 1.00 COMPZN, RPCOMP SVRG P O-ring failure on hydralic line under rig floor into secondary containment. Repair/replace or-ring, bring Hyd. pumps back on test flange. Good Test. Service rig equipment 586.0 586.0 8/14/2024 01:30 8/14/2024 04:00 2.50 COMPZN, RPCOMP TRIP P Continue IH w/BHA #9 9-5/8" Drift/cleanout assembly F/586' T/5,090' 586.0 5,090.0 8/14/2024 04:00 8/14/2024 04:45 0.75 COMPZN, RPCOMP CIRC P Circulate 44 bbl high vis sweep @ 11 bpm/2,260 psi Recip pipe 5,050'-5,090', PUW=108k, SOW=84k 5,090.0 5,090.0 8/14/2024 04:45 8/14/2024 06:45 2.00 COMPZN, RPCOMP TRIP P TOOH, with BHA #9 5,090.0 228.0 8/14/2024 06:45 8/14/2024 07:45 1.00 COMPZN, RPCOMP BHAH P LD BHA #9 PU. MU BHA# 10 B type spear. 228.0 218.2 8/14/2024 07:45 8/14/2024 10:00 2.25 COMPZN, RPCOMP TRIP P TIH W/Spear to top of fish at 5090' Establish Parameters. PUW=108K SOW=80K down 5RPM =2K free Tq. Tagged up at 5099' Set down 5K. Pulled up to 125 spear set. S.O to 112K 218.2 5,099.7 8/14/2024 10:00 8/14/2024 11:00 1.00 COMPZN, RPCOMP FISH P Fished stump 10 Rotations Tq-5-6K Tq broke back to 900 Ft/Lbs Weight fell off to 80K. PU clean 5,099.7 218.2 8/14/2024 11:00 8/14/2024 13:30 2.50 COMPZN, RPCOMP TRIP P TOOH F/5099' PUW-110K T/218.2 218.2 218.2 8/14/2024 13:30 8/14/2024 14:15 0.75 COMPZN, RPCOMP BHAH P LD BHA #10 218.2 0.0 8/14/2024 14:15 8/14/2024 16:15 2.00 COMPZN, RPCOMP RURD P RU floor to run casing. RU casing elevators and tongs. MU X-O to safety valve 0.0 0.0 8/14/2024 16:15 8/14/2024 21:15 5.00 COMPZN, RPCOMP PUTB P Run 7" 26# L-80 Hyd 563 casing as per tally LRS on location, spot in and RU 0.0 5,118.7 8/14/2024 21:15 8/14/2024 22:00 0.75 COMPZN, RPCOMP PUTB P Tag top of 7" stump 5118.71' x 2, PUW=145k, SOW=105 Space out, swap out pups to lower casing at floor, R/U to circulate hole over to diesel. 5,119.0 5,119.0 8/14/2024 22:00 8/14/2024 23:30 1.50 COMPZN, RPCOMP RURD P R/U to circulate hole over to diesel. LRS P/T lines to 4k. 5,119.0 5,119.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 6/12 1D-42 Report Printed: 9/17/2024 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) 8/14/2024 23:30 8/15/2024 00:00 0.50 COMPZN, RPCOMP CIRC P Bring pump online @ 2 bpm, confirm returns at tiger tank. Increase rate to 7 bpm 1,800 psi. 0-180 bbls away 5,119.0 5,119.0 8/15/2024 00:00 8/15/2024 01:00 1.00 COMPZN, RPCOMP CIRC P Continue circulating Freeze protect w/LRS 7 bpm at 1,800 psi. 350 bbls away good clean diesel to surface. Shut down pump. R/D LRS, and rig surface equipment 5,119.0 5,119.0 8/15/2024 01:00 8/15/2024 01:30 0.50 COMPZN, RPCOMP OWFF P Monitor well for flow. 5,119.0 5,119.0 8/15/2024 01:30 8/15/2024 04:30 3.00 COMPZN, RPCOMP PUTB P Rot Tq=5,500 ft/lbs, Work pipe 10k torque down, unable to apply enough torque with current RU. Swap out tongs from 15k to 25k. Continue to work torque down to stump 17k. Set slips at neutral weight, confirm torque with tongs to 17k. 5,119.0 5,119.0 8/15/2024 04:30 8/15/2024 05:30 1.00 COMPZN, RPCOMP RURD P RU to test casing 5,119.0 5,120.8 8/15/2024 05:30 8/15/2024 07:30 2.00 COMPZN, RPCOMP PRTS P Pressure test casing to 2500 PSI for 30 minutes. 5,120.8 5,120.8 8/15/2024 07:30 8/15/2024 09:00 1.50 COMPZN, RPCOMP RURD P RD testing equipment from testing casing. 5,120.8 5,120.0 8/15/2024 09:00 8/15/2024 10:00 1.00 COMPZN, WHDBOP NUND P ND tubing head and split stack. 5,120.0 5,120.0 8/15/2024 10:00 8/15/2024 12:00 2.00 COMPZN, WHDBOP NUND P Set slips in casing spool. Hang off 220K on slips 75K over string weight. RU WACHS saw cut casing off remove cut joint. Rack back the BOP's 0.0 0.0 8/15/2024 12:00 8/15/2024 14:15 2.25 COMPZN, WHDBOP NUND P Install pack off and new tubing head. Install new tubing head and BOP's Test Pack off to 4300 PSI for 10 minutes. 0.0 0.0 8/15/2024 14:15 8/15/2024 14:45 0.50 COMPZN, WHDBOP NUND P NU BOP stack to new tubing head. 0.0 0.0 8/15/2024 14:45 8/15/2024 15:30 0.75 COMPZN, WHDBOP BOPE P Test BOP flange break at tubing head. 0.0 0.0 8/15/2024 15:30 8/15/2024 16:00 0.50 COMPZN, RPCOMP RURD P Pull test plug set wear ring in tubing head. 0.0 0.0 8/15/2024 16:00 8/15/2024 17:15 1.25 COMPZN, RPCOMP BHAH P MU BHA #11 0.0 269.9 8/15/2024 17:15 8/15/2024 19:15 2.00 COMPZN, RPCOMP TRIP P TIH, F/Surface T/5,200' tag top of sand. 269.9 5,200.0 8/15/2024 19:15 8/15/2024 20:00 0.75 COMPZN, RPCOMP CIRC P PUH 5,190', circulate/displace diesel OOH. Circulate High vis sweep 44 bbls 5,200.0 5,190.0 8/15/2024 20:00 8/15/2024 21:00 1.00 COMPZN, RPCOMP TRIP P RIH, F/5,190' T/5,200'; PUW=118k, SOW=85 Bring pump online 10 bpm/2,100 psi Rotate down, 20k WOB Rot Tq=4,500-6,400 ft/lbs Rot RPM=45 F/5,200' T/5,211' Sweeps out of hole 5,190.0 5,211.0 8/15/2024 21:00 8/15/2024 23:30 2.50 COMPZN, RPCOMP TRIP P TOOH, with cleanout BHA #11 F/5,211' T/BHA 5,211.0 269.9 8/15/2024 23:30 8/16/2024 00:00 0.50 COMPZN, RPCOMP BHAH P L/D 7" Cleanout-Sand BHA #11 269.9 150.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 7/12 1D-42 Report Printed: 9/17/2024 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) 8/16/2024 00:00 8/16/2024 02:00 2.00 COMPZN, RPCOMP BHAH P Continue L/D 7" Cleanout-Sand BHA #11 Note: Brake down Junk Baskets, clean w/sand no debris 150.0 0.0 8/16/2024 02:00 8/16/2024 02:30 0.50 COMPZN, RPCOMP BHAH P M/U Baker RBP Retrieving tool BHA #12 0.0 77.6 8/16/2024 02:30 8/16/2024 03:00 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 8/16/2024 03:00 8/16/2024 05:00 2.00 COMPZN, RPCOMP TRIP P TIH on stands w/BHA #12 F/surface T/5,211' 77.6 5,211.0 8/16/2024 05:00 8/16/2024 05:30 0.50 COMPZN, RPCOMP TRIP P Rotate down Rot RPM=50, Rot Tq=3,500 ft/lbs, bring pump online 8 bpm/1,100 psi PUW=110k, SOW=80k 5,211.0 5,245.0 8/16/2024 05:30 8/16/2024 06:30 1.00 COMPZN, RPCOMP WASH P Wash down 8BPM = 400 PSI F/5211 T/5244' Pump 50 bbl 100 vis sweep. Circ SxS. 5,245.0 5,245.0 8/16/2024 06:30 8/16/2024 06:45 0.25 COMPZN, RPCOMP MPSP P PUW=110 SOW=80K Screw into plug at 5250' Free tq=3.2K rotate over plug engage neck equalilze plug. Pulled 10K over Observe for 10 minutes. Releasse plug allow element to relax. PUW=120K 5,245.0 5,250.0 8/16/2024 06:45 8/16/2024 07:00 0.25 COMPZN, RPCOMP TRIP P PUH rack back 3 stands. 5,250.0 4,950.0 8/16/2024 07:00 8/16/2024 07:15 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 4,950.0 4,950.0 8/16/2024 07:15 8/16/2024 08:45 1.50 COMPZN, RPCOMP TRIP P TOOH F/4950' T/77.62' 4,950.0 7,762.0 8/16/2024 08:45 8/16/2024 11:00 2.25 COMPZN, RPCOMP BHAH P LD Plug and retrieving head BHA. PU PU BHA#13 7" clean out BHA. 7,762.0 151.2 8/16/2024 11:00 8/16/2024 13:30 2.50 COMPZN, RPCOMP TRIP P TIH W/ BHA F/151.22 T/5355' 151.2 5,300.0 8/16/2024 13:30 8/16/2024 16:00 2.50 COMPZN, RPCOMP PULD P Single in F/5355' T/7983' 7ES RKB 7990' ORKB 7,990.0 8/16/2024 16:00 8/16/2024 17:30 1.50 COMPZN, RPCOMP WASH P Wash and ream Recip BHA across packer set depth from 7950'-7900' Lightly tag top of tubing at 7982' PUW=175K SOW=93K Rot-35 RPM 6.5K 7BPM 1800 PSI Returns dirty at BTMS. Pump 50 BBL 80 Vis sweep circulate SxS. 7,990.0 7,990.0 8/16/2024 17:30 8/17/2024 00:00 6.50 COMPZN, RPCOMP PULD P POOH LD DP PUW=174K SOW=K F/7990' T/BHA 7,990.0 765.0 8/17/2024 00:00 8/17/2024 00:30 0.50 COMPZN, RPCOMP PULD P Continue LD DP F/765' T/BHA 765.0 151.2 8/17/2024 00:30 8/17/2024 02:30 2.00 COMPZN, RPCOMP BHAH P LD Cleanout assembly BHA #12 Brake DP and spear Pull Wear Ring 151.2 0.0 8/17/2024 02:30 8/17/2024 03:00 0.50 COMPZN, RPCOMP PUTB P Prep RF for change of operations Load completion equipment into pipe shed Verify joint count and jewlery running order 0.0 0.0 8/17/2024 03:00 8/17/2024 03:30 0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0 8/17/2024 03:30 8/17/2024 03:45 0.25 COMPZN, RPCOMP SFTY P PJSM w/crews for running completion 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 8/12 1D-42 Report Printed: 9/17/2024 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) 8/17/2024 03:45 8/17/2024 13:45 10.00 COMPZN, RPCOMP PUTB P Run 3.5" L-80 EUE 8rd completion as per tally F/surface T/7982.53' 7ES RKB 7990.3' ORKB PUW=93K SOW=72K 0.0 0.0 8/17/2024 13:45 8/17/2024 14:30 0.75 COMPZN, RPCOMP HOSO P Set down 20K at 7985.43' unable to shear pins Washed down over stump set down 12K sheared pins Tagged at 7989' PU to 90K spaced out 2' off tag. MU hanger to string 0.0 0.0 8/17/2024 14:30 8/17/2024 15:15 0.75 COMPZN, RPCOMP RURD P RU to circulate CI down the tubing taking returns up the IA 0.0 0.0 8/17/2024 15:15 8/17/2024 17:45 2.50 COMPZN, RPCOMP CIRC P Circualte290 BBL's Corrosion inhibited seawater at 3BPM = 225 PSI. down tubing up IA. Drop Ball and Rod 0.0 0.0 8/17/2024 17:45 8/17/2024 18:15 0.50 COMPZN, RPCOMP PRTS T Open up Sensator on IA, bring pump up to 500 psi on the tubing, notice direct communication to IA, open up IA to Kill Tank, bring pump online again, notice returns immediatly to Kill Tank, attempt to cycle pressure up faster, no change. Note: Call out SL @ 18:17 pm (est time of arrival 19:30 pm). 0.0 0.0 8/17/2024 18:15 8/17/2024 19:45 1.50 COMPZN, RPCOMP PRTS T Prep location for SL unit, continue to work pre-move check list Stand by for Slickline, Unit on location @ 19:45. 0.0 0.0 8/17/2024 19:45 8/17/2024 21:00 1.25 COMPZN, RPCOMP SLKL T Spot in SL unit, PJSM with Rig Crew Bring equipment to RF Hang Sheave in blocks Discuss plan forward with SL operator MU SL Tools 0.0 0.0 8/17/2024 21:00 8/17/2024 22:15 1.25 COMPZN, RPCOMP SLKL T SL/RIH w/SL bell guide with impression block inside. 7,840' tag, work wire, unable to pass obstruction, TOOH Brake off LIB, looks like the ball and rod is stuck in lower GLM. SL MU catcher to pull ball and rod. 0.0 0.0 8/17/2024 22:15 8/17/2024 22:45 0.50 COMPZN, RPCOMP SLKL T SL/RU to set packer, still communicating to the IA. RD circulating equipment. 0.0 0.0 8/17/2024 22:45 8/18/2024 00:00 1.25 COMPZN, RPCOMP SLKL T SL/MU SL 2" pulling tool, RIH Spang ball and rod free, contiinue IH to 7,952' POOH with ball and rod 0.0 0.0 8/18/2024 00:00 8/18/2024 01:15 1.25 COMPZN, RPCOMP SLKL T SL/continue POOH, LD and inspect Ball and Rod. good MU ball and rod to running tool. RIH, to 7,840' SLMD spang through, set ball and rod at 7,953'. POOH, Stand back SL 0.0 0.0 8/18/2024 01:15 8/18/2024 01:45 0.50 COMPZN, RPCOMP RURD T RU to set packer and test Bring pump up to 1,000 psi holding, bleed pressure down 0.0 0.0 8/18/2024 01:45 8/18/2024 02:30 0.75 COMPZN, RPCOMP PRTS P Pressure test tubing/set packer Chart 3,500 psi for 30 mins. (good test) Bleed pressure to 1,500 psi 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 9/12 1D-42 Report Printed: 9/17/2024 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) 8/18/2024 02:30 8/18/2024 05:30 3.00 COMPZN, RPCOMP PRTS T Line up down the IA through secondary kill line, bring pressure up to 2,641 psi, shut down, and double block, pressure bleed down to 1,000 psi, trouble shoot, isolate squeeze manifold, pressure back up with same results, line up to the tubing pressure up to 4,069 psi, hold pressure for 30 mins, add block valve on secondary kill, bleed pressure off tubing to 1,500 psi, pressure up IA to 2,500 psi, monitor pressure. 0.0 0.0 8/18/2024 05:30 8/18/2024 07:30 2.00 COMPZN, RPCOMP OTHR T Load pits. Re-torque LDS pressure up tubing and IA attempt to test. test fialed. Sheared SOV while loading pits. 0.0 0.0 8/18/2024 07:30 8/18/2024 08:30 1.00 COMPZN, RPCOMP RURD T RU to to reverse circulate down the IA taking returns up the IA. RU to pull tubing. 0.0 0.0 8/18/2024 08:30 8/18/2024 10:30 2.00 COMPZN, RPCOMP CIRC T Circulate SxS 290 BBL's seawater at 3BPM=500 PSI 0.0 0.0 8/18/2024 10:30 8/18/2024 14:00 3.50 COMPZN, RPCOMP PULL T BOLDS and attempt to pull packer free. Work up to 205K total 177K PUW. 85% of yield. Continue to work pipe. up to 205K Start processing DP in pipe shed. Call E-line to cut tubing. Unable to release packer. 0.0 0.0 8/18/2024 14:00 8/18/2024 19:00 5.00 COMPZN, RPCOMP RURD T RD landing joint and MU short landing joint for E-Line. RU Ak. E-line. Rehead and tie weak point. RIH, cut 3.5" tubing @ 7,887' ORKB. POOH, stand back e-line RU, pull on tubing PUW=93k to confirm cut RD E-line and release e-line 0.0 0.0 8/18/2024 19:00 8/18/2024 19:30 0.50 COMPZN, RPCOMP PULL T Prep RF for standing back 3-1/2" tubing 0.0 0.0 8/18/2024 19:30 8/19/2024 00:00 4.50 COMPZN, RPCOMP PULL T Stand back 3-1/2" tubing in derrick 0.0 1,200.0 8/19/2024 00:00 8/19/2024 02:00 2.00 COMPZN, RPCOMP PUTB T Continue standing back 3.5" completion and LD mandrels. F/1,200' T/Surface *** Note" Cut Joint 15.11', Stump is 16.46' in length. 1,200.0 0.0 8/19/2024 02:00 8/19/2024 02:30 0.50 COMPZN, RPCOMP CLEN T Prep RF for PU/DP Install Wear Ring MU BHA #1 0.0 15.1 8/19/2024 02:30 8/19/2024 11:45 9.25 COMPZN, RPCOMP PULD T RIH on singles from pipeshed w/BHA #1 Yellow Jacket AS-1 test packer F/15' T/7864' PUW= 125K SOW=98K 15.1 7,864.0 8/19/2024 11:45 8/19/2024 12:00 0.25 COMPZN, RPCOMP MPSP T Screw into DP Set AS-1 at 7857' 7,864.0 7,857.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 10/12 1D-42 Report Printed: 9/17/2024 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) 8/19/2024 12:00 8/19/2024 18:00 6.00 COMPZN, RPCOMP PRTS T Set packer at 7857' Close pipe rams open kill pump Attempt to PT casing. 1.5 BPM 2200 psi unable to maintain pressure Release test plug PUH 5 stands Set packer at 7380' Close pipe rams open. Attempt to PT casing. 1.5 BPM 2200 psi unable to maintain pressure. Release test plug PUH 5 stands Set packer at 6994' Close pipe rams open. Attempt to PT casing twice. 1.5 BPM 2200 psi unable to maintain pressure. Release test plug PUH 5 stands Set packer at 6433' Close pipe rams open. Attempt to PT casing above test plug 1.5 BPM pressure up to 2500 psi unable to maintain pressure. Pressure up below test plug to 2500 PSI. Appears casing is good slight flow past test plug down flow line. Bled pressure off. Released test plug PUH 5 stands Set packer at 5962' Close pipe rams open. Attempt to PT casing above test plug 1.5 BPM pressure up to 2500 psi unable to maintain pressure. Bled pressure off. Released test plug PUH 5 stands Set packer at 5487' Close pipe rams. Attempt to PT casing above test plug 1.5 BBBL pressure up to 2500 psi pressure test for 10 min. Bled pressure off. Released test plug RIH 1 stand Set packer at 5577' Close pipe rams. Attempt to PT casing above test plug. 1.5 BBL pressure up to 2500 psi. Pressure 2500 PSI held. RIH 1 stand Set packer at 5672' Close pipe rams. Attempt to PT casing below test plug. 1.5 BBL pressure up to 2500 psi. Unable to maintain pressure. Open pipe rams. Pressure up to 2500 PSI down DP.Pr 7,857.0 5,642.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 11/12 1D-42 Report Printed: 9/17/2024 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) 8/19/2024 18:00 8/19/2024 20:45 2.75 COMPZN, RPCOMP TRIP T TOOH DP on stands, F/5,642' T/BHA 5,642.0 14.9 8/19/2024 20:45 8/19/2024 21:15 0.50 COMPZN, RPCOMP BHAH T LD BHA 14.9 0.0 8/19/2024 21:15 8/19/2024 22:45 1.50 COMPZN, RPCOMP BHAH T MU Dress off assembly BHA #2 0.0 135.5 8/19/2024 22:45 8/20/2024 00:00 1.25 COMPZN, RPCOMP TRIP T TIH, F/135.5' T/3,000' 135.5 3,000.0 8/20/2024 00:00 8/20/2024 01:30 1.50 COMPZN, RPCOMP TRIP T Continue TIH F/3,000' T?7,800' Lightly tag stump 7,871', 10k down PUW=150k, SOW=98k 3,000.0 7,871.0 8/20/2024 01:30 8/20/2024 02:00 0.50 COMPZN, RPCOMP REAM T Ream/wash down F/7,871' T/7,879' RPM=40, ROT WT=120, WOB=2k, TQ off=6k, TQ on=7k, 3 bpm @ 450 psi 7,871.0 7,879.0 8/20/2024 02:00 8/20/2024 03:00 1.00 COMPZN, RPCOMP CIRC T Circulate 50 bbl high-vis sweep @ 8 bpm/1,750 psi, FCP=1,950 psi 7,879.0 7,879.0 8/20/2024 03:00 8/20/2024 03:30 0.50 COMPZN, RPCOMP SVRG T Service rig 7,879.0 7,879.0 8/20/2024 03:30 8/20/2024 12:00 8.50 COMPZN, RPCOMP TRIP T TOOH sideways F/7,879' T/135' UWT=150K 7,879.0 135.0 8/20/2024 12:00 8/20/2024 13:00 1.00 COMPZN, RPCOMP BHAH T LD BHA and clear rig floor REMOVE WEAR RING 135.0 0.0 8/20/2024 13:00 8/20/2024 16:45 3.75 COMPZN, RPCOMP BHAH T Prep rig floor and pipe shed to run completion. Place rig tongs on rig floor. While waiting on completion completion componets to arrive on location: Replace cylinders for bales on TD. Work on hydraulic valve manifold for link tilt. 0.0 0.0 8/20/2024 16:45 8/20/2024 17:45 1.00 COMPZN, RPCOMP OTHR T Unload completion from truck and place in pipe shed. 0.0 0.0 8/20/2024 17:45 8/20/2024 20:00 2.25 COMPZN, RPCOMP OTHR T Lay down two stands from derrick // Tally joints // Verrify new tool lengths // Re-work tally and get engineer approval // Stage tools in order in shed 0.0 0.0 8/20/2024 20:00 8/21/2024 00:00 4.00 COMPZN, RPCOMP PUTB T PJSM w/ all parties // Pick up overshot, x-nipple, packer, run 72 jts tubing from derrick, P/u packer, p/u jt from shed, p/u GLM w/ SOV, run 83 jts from derrick, P/u GLM, run 93 jts from derrick 0.0 2,000.0 8/21/2024 00:00 8/21/2024 08:00 8.00 COMPZN, RPCOMP PUTB T PJSM w/ all parties // Pick up overshot, x-nipple, packer, run 72 jts tubing from derrick, P/u packer, p/u jt from shed, p/u GLM w/ SOV, run 83 jts from derrick, P/u GLM, run 93 jts from derrick. UWT88K, SOW 71K Tag at 7883' set down 15K and sheer. Set down at 7889' with no-go. 2,000.0 7,889.0 8/21/2024 08:00 8/21/2024 09:00 1.00 COMPZN, RPCOMP THGR T LD 3 JTS tubing, PU space out pups, MU tubing hanger to landing JT. MU cement to head pin. Land hanger and calculate space out. 7,889.0 7,886.0 8/21/2024 09:00 8/21/2024 10:30 1.50 COMPZN, RPCOMP DISP T Displace well to CI at 4 BPM, 290 BBLS. 7,879.0 7,879.0 8/21/2024 10:30 8/21/2024 11:00 0.50 COMPZN, RPCOMP THGR T Land tubing hanger and RILDS. 7,879.0 7,885.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Page 12/12 1D-42 Report Printed: 9/17/2024 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) 8/21/2024 11:00 8/21/2024 13:30 2.50 COMPZN, RPCOMP PACK T Pressure up to set packers. Pressured up imediatly to 570 psi. Reverse circ and hear ball and rod tagging chickson at surface. Repeat 3 times. Think ball and rod is stuck in tubing hanger. Break landing joint off of tubing hanger and verify B&R is not there. Install landing joint and reland tubing hanger. 7,885.0 7,885.0 8/21/2024 13:30 8/21/2024 18:30 5.00 COMPZN, WHDBOP SLKL T RU Slickline and RIH to find B&R. Pull to floor and inspect, run ball and rod on seat with slick line 7,885.0 7,885.0 8/21/2024 18:30 8/21/2024 19:15 0.75 COMPZN, WHDBOP PACK P Stage pressure up to 3800 psi set packer // Hold 30 min good tubing test 7,885.0 7,855.0 8/21/2024 19:15 8/21/2024 20:00 0.75 COMPZN, WHDBOP PRTS P Pressure test IA T/ 2500 psi 30 min good test // Shear SOV 7,855.0 7,855.0 8/21/2024 20:00 8/21/2024 20:30 0.50 DEMOB, MOVE RURD P Rig down slick line and pressure testing equipment 7,855.0 0.0 8/21/2024 20:30 8/21/2024 21:00 0.50 DEMOB, MOVE MPSP P Set BPV and test from below 1000psi 10 min good test 0.0 0.0 8/21/2024 21:00 8/21/2024 22:30 1.50 DEMOB, MOVE NUND P Nipple down BOPs 0.0 0.0 8/21/2024 22:30 8/22/2024 00:00 1.50 DEMOB, MOVE NUND P Nipple up tree, pad op confirm tree orientation 0.0 0.0 8/22/2024 00:00 8/22/2024 00:30 0.50 DEMOB, MOVE NUND P Nipple up production tree 0.0 0.0 8/22/2024 00:30 8/22/2024 01:00 0.50 DEMOB, MOVE PRTS P Rig up LRS, PT Production Tree 5000psi 0 0.0 0.0 8/22/2024 01:00 8/22/2024 02:30 1.50 DEMOB, MOVE FRZP P Freeze protect well with 75 bbls LEPD // 2 bbls/min @ 500 psi 0.0 0.0 8/22/2024 02:30 8/22/2024 03:30 1.00 DEMOB, MOVE OTHR P Let well U-tube, blow down liines Rig released 03:30 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/22/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 8,514.0 1D-42 2/1/2004 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install Posr RWO GLD, pull Ball & Rod, RHC, catcher & plug 1D-42 9/3/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1D-42 (C-SAND), 1D-42L1 (??-SANDS) 7/18/2005 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 20 19.14 34.0 91.0 91.0 91.50 H-40 WELDED SURFACE 9 5/8 8.70 34.5 5,312.0 4,225.0 40.00 L-80 BTC MOD Production 7 6.28 0.0 5,116.2 4,099.3 26.00 L-80 563 Production 7 6.28 5,114.0 8,187.3 6,088.3 26.00 L-80 BTC MOD WINDOW L1 4 3.00 8,401.0 8,411.0 6,233.2 9.30 L-80 LINER 3 1/2 2.99 8,000.7 8,660.0 6,398.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 7,886.6 String Max No 3 1/2 Set Depth 5,893.3 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.00 Hanger 10.880 FMC GEN 5 Tubing hanger FMC Gen V 2.900 2,931.2 2,688.0 48.40 Mandrel GAS LIFT 5.968 3.5" MMG S# 24384-19 Camco MMG 2.992 5,521.6 4,358.6 49.91 Mandrel GAS LIFT 5.968 3.5" MMG S# 21131-01 Camco MMG 2.992 5,581.9 4,397.5 49.67 Packer 5.968 SLB Blue pack SLB packer ASS #1 S# C23P-0230 SLB BluePac k 2.992 7,827.8 5,855.0 49.40 Packer 5.968 SLB Blue pack SLB packer ASS #2 S# C23P-0229 Camco BluePac k 2.992 7,854.0 5,872.1 49.33 Nipple - X 4.495 2.813" X Nipple S#050011991-20 HES "X" 2.813 7,875.2 5,885.8 49.40 Overshot 6.000 Poor boy overshot (11.0' swallow W/ 4 pins set 6.3' above bottom of shoe) Baker PB Oversho t 11' 3.610 Top (ftKB) 7,877.1 Set Depth 8,000.0 String Max No 3 1/2 Set Depth 5,966.6 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,911.9 5,909.7 49.61 Packer 5.968 SLB Blue pack SLB packer S# C22P -1092 SLB BluePac k 2.992 7,969.9 5,947.2 49.79 2.813" X 4.495 2.813" X Nipple S#0005069318-13 HES "X" 2.813 7,991.7 5,961.3 49.72 Overshot 6.000 Poor boy overshot (7.1' swallow W/ 4 pins set 3' above bottom of shoe) Spaced out 2' off tag. Baker PB Oversho t 11' 3.610 Top (ftKB) 7,995.0 Set Depth 8,054.0 String Max No 4 Set Depth 6,001.6 Tubing Description Tubing Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 3.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,016.1 5,977.0 49.65 LOCATOR 5.125 BAKER NO GO LOCATOR 3.000 8,017.3 5,977.8 49.64 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY 3.000 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) 34.1 34.1 0.00 EMERGENCY SLIPS Tie back slips FMC 8/15/2024 7.000 7,995.0 5,963.4 49.71 CUT WELLTEC MECHANICAL TUBING CUT, TATTLE-TAIL INDICATED 3.68" BLADE EXTENSION. WELLTE C MECHA NICAL 7/5/2024 2.992 8,414.0 6,235.1 49.16 Whipstock WEATHERFORD LSX-N FLOW-THRU WHIPSTOCK FOR MAIN LEG (1D-36) PRODUCTION PERFS 7/15/2005 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) 2,931.2 2,688.0 48.40 1 GAS LIFT GLV RK 5.8 1,224.0 8/31/2024 SLB MMG 0.188 5,521.6 4,358.6 49.91 2 GAS LIFT OV RK 5.8 0.0 8/31/2024 SLB MMG 0.250 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) 8,000.7 5,967.1 49.70 TIE BACK 7.000 LINER TIE BACK SLEEVE 6.151 8,008.0 5,971.8 49.67 PACKER 5.980 BAKER ZXP LINER TOP PACKER 4.408 8,086.7 6,022.9 49.48 NIPPLE 5.500 HES 'XN' NIPPLE w/2.75"NO GO 2.750 1D-42, 9/17/2024 10:50:26 AM Vertical schematic (actual) LINER L1; 8,400.0-10,822.5 LINER; 8,000.7-8,660.0 IPERF; 8,430.0-8,460.0 FRAC; 8,430.0 SLOTS; 8,411.0-8,475.0 Whipstock; 8,414.0 WINDOW L1; 8,401.0-8,411.0 Production; 5,114.0-8,187.3 CUT; 7,995.0 2.813" X; 7,969.9 Packer; 7,911.9 Nipple - X; 7,854.0 Packer; 7,827.8 Packer; 5,581.9 Mandrel GAS LIFT; 5,521.6 SURFACE; 34.5-5,312.0 Production; 0.0-5,116.2 Mandrel GAS LIFT; 2,931.2 CONDUCTOR ; 34.0-91.0 EMERGENCY SLIPS; 34.1 Hanger; 29.2 KUP PROD KB-Grd (ft) 40.40 RR Date 11/8/2000 Other Elev 1D-42 ... TD Act Btm (ftKB) 8,660.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292297900 Wellbore Status PROD Max Angle & MD Incl (°) 51.24 MD (ftKB) 4,845.87 WELLNAME WELLBORE1D-42 Annotation Last WO: End Date 8/22/2024 H2S (ppm) 70 Date 8/12/2016 Comment Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,430.0 8,460.0 6,245.6 6,265.3 C-4, C-1, 1D-42 2/23/2001 6.0 IPERF 2.5" HSD, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,430.0 8,460.0 1 FRAC 3/22/2001 0.0 0.00 0.00 1D-42, 9/17/2024 10:50:27 AM Vertical schematic (actual) LINER L1; 8,400.0-10,822.5 LINER; 8,000.7-8,660.0 IPERF; 8,430.0-8,460.0 FRAC; 8,430.0 SLOTS; 8,411.0-8,475.0 Whipstock; 8,414.0 WINDOW L1; 8,401.0-8,411.0 Production; 5,114.0-8,187.3 CUT; 7,995.0 2.813" X; 7,969.9 Packer; 7,911.9 Nipple - X; 7,854.0 Packer; 7,827.8 Packer; 5,581.9 Mandrel GAS LIFT; 5,521.6 SURFACE; 34.5-5,312.0 Production; 0.0-5,116.2 Mandrel GAS LIFT; 2,931.2 CONDUCTOR ; 34.0-91.0 EMERGENCY SLIPS; 34.1 Hanger; 29.2 KUP PROD 1D-42 ... WELLNAME WELLBORE1D-42 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): 8660'2965 8078' 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: 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 Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8008'MD/5972'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 200-164 P.O. Box 100360, Anchorage, AK 99510 50-029-22979-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 8054' MD 91' 4225' 91' 5312' 6088'7" 20" 9-5/8" 57' 5277' 8187' Perforation Depth MD (ft): 7/20/2024 8660'659' 3-1/2" 6399' Baker ZXP Liner 6399' 8514' 6301'8087' KRU 1D-42 8430-8460' 8154' 3.5" 6246-6265' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Date: 8/19/2024 324-479 By Grace Christianson at 8:21 am, Aug 21, 2024 X 7/20/2024 SFD 8/21/2024 , ADL0025661 SFD X DSR-8/21/24 10-404 BOP test to 3500 psig Annular preventer test to 3500 psig Aug 21, 2024 Victoria Loepp August 29, 2024 VTL 8/28/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.29 09:25:57 -08'00'08/29/24 RBDMS JSB 082924 1D-42 RWO Procedure Kuparuk Producer Subsidence Repair PTD #200-164 Page 1 of 3 Completed Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPOT, IC-POT tests all passed 5/10/23, but re tests planned pre rig 2. Dummy off top GLMs, leaving GLM at 7920’ open 3. Obtain new SBHP 4. Set plug and catcher in nipple profile at 8087’ MD 5. PT tubing to 2500psi-failed a. Identified tubing leaks from 4863’-5120’ MD 6. RIH with packer on CTU. Set packer at 8068’ and PT to 2500psi-passed Remaining Pre-Rig Work 7. Attempt CDDT TbgxIAxOA to confirm plug and packer as a barrier 8. Cut tubing at ~7995’ MD (first full joint above packer) Rig Work MIRU 1. MIRU Nabors 7ES on 1D-42. Circulate well over to SW. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig cut at ~7,995’ MD Log Cement, Secure casing. Cut and pull casing 6. Rig up eline and run CBL from ~5300’ up to find TOC 7. RIH with 7” G-Plug and set at ~150’ below TOC’ PT to 1000psi for 30minutes. 8. ND BOPE. 9. ND tubing head. 10. NU BOPe to casing head a.Unable to test BOPE flange break at this point due to removal of packoffs, will test after 7” casing has been pulled. 11. RIH with multi string cutter and cut 7” casing above TOC 12. Spear 7” casing 13. Shut in annular if necessary and circ surface to surface heated SW down through cut and up OA to circulate out arctic pack. 14. POOH LD 7” casing Run new casing and cement 15. Dress off 7” stump 16. RIH with new 7”, triple connect 17. Land 7” and confirm triple connect seals with 2500psi PT 18. ND BOP. NU tubing spool. NU BOP. Test break Pull plug 19. Run in to wash sand off top of plug. 20. Pull plug Run new Tubing 21. RIH with new 3 ½” completion to overshot tubing stub 22. Fully locate, PU and circulate in CI brine 23. Land tubing hanger. Install packoffs Subsidence Repair 1D-42 RWO Procedure Kuparuk Producer Subsidence Repair PTD #200-164 Page 2 of 3 24. Drop ball and rod. Pressure up to set packer. 25. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes a. PT IA to 2500psi (Failed) 26. Circ CI out of the hole 27. Pull release Packer, POOH with 3 ½” Tubing a. Unable to pull release, RU eline, RIH and cut above packer 28. MU test Packer on DP, RIH and locate leak 29. RIH with tubing dress off mill, dress off tubing stub at 7887’ RKB Run 3 ½” Completion with Straddle Packers 30. RIH with new 3 ½” completion to overshot tubing stub 31. Fully locate, PU and circulate in CI brine 32. Land tubing hanger. Install packoffs 33. Drop ball and rod. Pressure up to set packers. 34. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 35. Shear SOV 36. Install BPV. PT through SOV 37. ND BOP, NU WH 38. Circ in freeze protect tbg and IA Post Rig Work 1. Pull SOV, install GLD 2. Pull B&R and RHC plug 3. Pull XXN plug General Well info: Wellhead type/pressure rating: FMC Gen V Production Engineer: Barny Dogah Surveillance Reservoir Engineer: Cody Keith Estimated Start Date: 7/20/24 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion, subsidence repair 7” casing and run new 3-1/2” tubing BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CDDT TbgxIAxOA – passed 5/10/23, plan to re-attempt pre rig 1D-42 RWO Procedure Kuparuk Producer Subsidence Repair PTD #200-164 Page 3 of 3 IC POT & PPPOT passed 5/10/23, plan to re-attempt pre rig TBG POT & PPPOT passed 5/10/23, plan to re-attempt pre rig MPSP: 2,965 psi using 0.1 psi/ft gradient Static BHP: 3588 psi/ 6225’ TVD (measured 6/6/24) Description Set Depth MD Set Depth OD ID Weight Length Grade Top Conn Run Date Conductor 91 91 20 19.14 91.5 H-40 WELDED 6/12/2000 Surface 5312 4225 9.625 8.697 40 L-80 BTC MOD 10/28/2000 Production 8187.3 6088.3 7 6.276 26 L-80 BTC MOD 11/2/2000 Production 5116.2 4099.3 7 6.276 26 L-80 563 8/14/2024 Tubing 7995 3 1/2 2.992 9.3 L-80 EUE-M Window 8411 6233.2 4 3 9.3 L-80 7/15/2005 Liner 8660 6398.7 3.5 2.992 9.3 L-80 SLHT 11/7/2000 Liner L1 10822.5 6325 2.375 1.992 4.6 L-80 STL 7/15/2005 1D-42 Current Schematic Surface Casing, cmt to surface, full returns Production Casing, no cbl, 170sx no bump, floats held Conductor L1 Production Liner C-Sand Perfs 8430' RKB - 8060' RKB XN Open OA PC Casing Estimated TOC, 6645' RKB Assuming gauge hole Leak between 5642' RKB and 5655' RKB Production Casing Tie Back •7" 26lb/ft L-80 Hydril 563 Casing •Triple Connect Bushing, Hyd563 Box x BTC Box w/ Skirt @ 5113.22' RKB 3 1/2" Completion Run 8/17/24 •Tubing cut @ 7887' ELMD •3-1/2" x 7" SLB BluePack MRH (Pull to Release) @ 7914' RKB •3-1/2" x 2.813" 'X' Nipple @ 7970' RKB •RHC Installed, Ball and Rod on Seat •Poor Boy Overshot (sized for 3-1/2" tubing stub) Top @ 7991.7' RKB REMAINING COMPLETION LEFT IN HOLE •3 1/2" Tubing Cut @ 7995' ELMD •3-1/2" Locator @ 8016' RKB •Baker 5"x7" Tie Back Sleeve @ 8001' RKB •ZXP Liner Top Packer @ 8008' RKB •Flex Lock Liner Hanger @ 8015.6' RKB •20' Lng 80-40 SBE @ 8027.8' RKB Description Set Depth MD Set Depth OD ID Weight Length Grade Top Conn Run Date Conductor 91 91 20 19.14 91.5 H-40 WELDED 6/12/2000 Surface 5312 4225 9.625 8.697 40 L-80 BTC MOD 10/28/2000 Production 8187.3 6088.3 7 6.276 26 L-80 BTC MOD 11/2/2000 Production 5116.2 4099.3 7 6.276 26 L-80 563 8/14/2024 Tubing 7995 3 1/2 2.992 9.3 L-80 EUE-M Window 8411 6233.2 4 3 9.3 L-80 7/15/2005 Liner 8660 6398.7 3.5 2.992 9.3 L-80 SLHT 11/7/2000 Liner L1 10822.5 6325 2.375 1.992 4.6 L-80 STL 7/15/2005 1D-42 Proposed Schematic - Straddle 8/19/2024 Surface Casing, cmt to surface, full returns Production Casing, no cbl, 170sx no bump, floats held Conductor L1 Production Liner C-Sand Perfs 8430' RKB - 8060' RKB XN Open OA PC Casing Estimated TOC, 6645' RKB Assuming gauge hole Leak between 5642' RKB and 5655' RKB Production Casing Tie Back •7" 26lb/ft L-80 Hydril 563 Casing •Triple Connect Bushing, Hyd563 Box x BTC Box w/ Skirt @ 5113.22' RKB 3 1/2" Completion •FMC Gen 5 Tubing Hanger •3-1/2" 9.3# L-80 EUE-Mod 8RD •3-1/2" x 1.5" MMG GLMs @ Depths: •2945' RKB •~5544' RKB •3-1/2" x 7" SLB BluePack Max (Cut to Release) @ ~5605' RKB •3-1/2" x 7" SLB BluePack Max (Cut to Release) @ ~7824' RKB •3-1/2" x 2.813" 'X' Nipple @ ~7848' RKB •RHC Installed •Poor Boy Overshot (sized for 3-1/2" tubing stub) Top @ ~7884' RKB 3 1/2" Completion Run 8/17/24 •Tubing cut @ 7887' ELMD •3-1/2" x 7" SLB BluePack MRH (Pull to Release) @ 7914' RKB •3-1/2" x 2.813" 'X' Nipple @ 7970' RKB •RHC Installed, Ball and Rod on Seat •Poor Boy Overshot (sized for 3-1/2" tubing stub) Top @ 7991.7' RKB REMAINING COMPLETION LEFT IN HOLE •3 1/2" Tubing Cut @ 7995' ELMD •3-1/2" Locator @ 8016' RKB •Baker 5"x7" Tie Back Sleeve @ 8001' RKB •ZXP Liner Top Packer @ 8008' RKB •Flex Lock Liner Hanger @ 8015.6' RKB •20' Lng 80-40 SBE @ 8027.8' RKB 1 Eller, Cy From:Tuttle, Elliott Sent:Monday, August 19, 2024 6:32 PM To:NSK RWO CM; Eller, Cy; Coberly, Jonathan; Nezaticky, Peter Subject:Fwd: [EXTERNAL]Re: 1D-42 (PTD 200-164) Sundry 324-350 APPROVAL Approved to proceed with straddle packer plan. Elliott Tuttle Conoco Phillips 907-252-3347 &ƌŽŵ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϵ͕ϮϬϮϰϲ͗ϯϭ͗ϮϮWD dŽ͗dƵƚƚůĞ͕ůůŝŽƚƚфůůŝŽƚƚ͘dƵƚƚůĞΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ZĞ͗΀ydZE>΁ZĞ͗ϭͲϰϮ;WdϮϬϬͲϭϲϰͿ^ƵŶĚƌǇϯϮϰͲϯϱϬWWZKs> Elliott, Approval is granted to proceed as written below. Victoria Sent from my iPhone On Aug 19, 2024, at 5:00ௗPM, Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> wrote: Including Cy Eller, other on call engineer. &ƌŽŵ͗dƵƚƚůĞ͕ůůŝŽƚƚ ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϵ͕ϮϬϮϰϰ͗ϱϲWD dŽ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх Đ͗E^<ZtKDфE^<ZtK͘DΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖ŽďĞƌůǇ͕:ŽŶĂƚŚĂŶ ф:ŽŶĂƚŚĂŶ͘ŽďĞƌůǇΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖EĞǌĂƚŝĐŬǇ͕WĞƚĞƌфW͘EĞǌĂƚŝĐŬǇΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕ 'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖ŽŶŬůŝŶ͕ŵǇфŵǇ͘͘ŽŶŬůŝŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁ZĞ͗ϭͲϰϮ;WdϮϬϬͲϭϲϰͿ^ƵŶĚƌǇϯϮϰͲϯϱϬ Victoria, We are still in the hole with the test packer but have identified that the leak is between 5577’ RKB and 5672’ RKB. I have updated the schematic to reflect that. Please provide verbal approval for the following path forward: 1. TOOH with Test packer Assy 2. RIH with tubing dress off assy, dress off stub at 7887’ RKB 2 Run 3 ½” Completion with Straddle Packers 1. RIH with new 3 ½” completion to overshot tubing stub 1. Upper packer being 5577’ RKB or lower. 2. Fully locate, PU and circulate in CI brine 3. Land tubing hanger. Install packoffs 4. Drop ball and rod. Pressure up to set packers. 5. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minute 6. Shear SOV 7. Install BPV. PT through SOV 8. ND BOP, NU WH 9. Circ in freeze protect tbg and IA Thank you, Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 1480 &ƌŽŵ͗dƵƚƚůĞ͕ůůŝŽƚƚ ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϵ͕ϮϬϮϰϴ͗ϮϱD dŽ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх Đ͗E^<ZtKDфE^<ZtK͘DΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗Z͗΀ydZE>΁ZĞ͗ϭͲϰϮ;WdϮϬϬͲϭϲϰͿ^ƵŶĚƌǇϯϮϰͲϯϱϬ Victoria, Thank you, we are currently running in hole with the test packer now. Calculations for estimated TOC, assuming gauge hole is as follows: 7.8859 ft/cuft for 8.5" OH by 7"csg 1.15 cuft/sx 170 sx 195.5 cuft cmt 1541.693 height of cement 6645 TOC Let me know if there is a good time to call or call when you are available. Thanks again. Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 1480 &ƌŽŵ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗^ƵŶĚĂǇ͕ƵŐƵƐƚϭϴ͕ϮϬϮϰϱ͗ϰϴWD dŽ͗dƵƚƚůĞ͕ůůŝŽƚƚфůůŝŽƚƚ͘dƵƚƚůĞΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ х ^ƵďũĞĐƚ͗΀ydZE>΁ZĞ͗ϭͲϰϮ;WdϮϬϬͲϭϲϰͿ^ƵŶĚƌǇϯϮϰͲϯϱϬ 3 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. Elliott, Approval is granted to proceed through leak detection and provide an update. Where is the calculated TOC outside the production casing? We can discuss tomorrow morning. Victoria Sent from my iPhone On Aug 18, 2024, at 3:22ௗPM, Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> wrote: Victoria, 7ES is currently on 1D-42. Once the 3 ½” tubing was installed and packer was set, a IA PT was conducted and failed today (8/18/24) with no response on the OA or T. The casing had/ has integrity down to 5250’ RKB which was tested after the PC repair was completed. We are currently waiting on Eline to cut the tubing above packer so we can trip the tubing out of the hole. The repair would change depending on the depth of leak. We are currently evaluating that depth/ or cutoff, but it would either be a new 3 ½” Completion with straddle packers or a 5.5” Tieback to create a new IA. Please see steps as described below. I have created 3 different schematics for our discussion. Working Schematic, wells current condition Prop Schematic – Straddle – 8.18.24 (Listed as Plan A below) Prop Schematic – 5.5” Tiback – 8.18.24 (Listed as Plan B below) Please provide verbal approval to continue with plan as outlined below. I understand a 10-403CAP will need to be submitted. Run new Tubing 1. RIH with new 3 ½” completion to overshot tubing stub 2. Fully locate, PU and circulate in CI brine 3. Land tubing hanger. Install packoffs 4. Drop ball and rod. Pressure up to set packer. 5. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 1. PT IA to 2500psi (Failed) 6. Circ CI out of the hole 7. Pull release Packer, POOH with 3 ½” Tubing 1. If unable to pull release, RU eline, RIH and cut above packer 2. Retrieve packer down to non-sealing overshot 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 8. MU test Packer on DP, RIH and locate leak 1. Plan A: If leak is below optimum gas lift depth (TVD being worked), 2 production packers will be run straddling the casing leak in the 7”. 2. Plan B: If leak is above optimum gas lift depth (TVD being worked), 5.5” Long string will be required to create new annulus. Plan A: Run 3 ½” Completion with Straddle Packers 9. RIH with new 3 ½” completion to overshot tubing stub 10. Fully locate, PU and circulate in CI brine 11. Land tubing hanger. Install packoffs 12. Drop ball and rod. Pressure up to set packers. 13. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minute 14. Shear SOV 15. Install BPV. PT through SOV 16. ND BOP, NU WH 17. Circ in freeze protect tbg and IA Plan B: Plan to run 5.5” Long string 18. RIH and Fish 3 ½” stub down to the seals @ 8027’ RKB 19. Set plug near surface (obtain needed barriers) 20. ND BOPE’s, NU new Casing Spool 21. Pull plug 22. Run 5.5” Tieback, spot CI and land. RI LDS, Test void to 5000psi. 1. Test 5.5” Casing down to plug @ 8087’ RKB 2. Pressure up down new OA (able to shear SOV on previous completion), shear SOV and circulate down freeze protect, taking returns up 5.5” casing. 23. RIH with new 3 ½” completion to overshot tubing stub 24. Fully locate, PU and circulate in CI brine 25. Land tubing hanger. Install packoffs 26. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes 27. Shear SOV 28. Install BPV. PT through SOV 29. ND BOP, NU WH 30. Circ in freeze protect tbg and IA Thank you very much and I will follow up with a phone call. Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 1480 <1D-42_2023_RWO_Prop_Schematic - 5.5in Tieback - 8.18.24.pdf> <1D-42_2023_RWO_Prop_Schematic - Straddle - 8.18.24.pdf> <1D-42_2023_RWO_Working Schematic 8.18.24.pdf> <Sundry_324-350_070524.pdf> <1D-42_2023_RWO_Prop_Schematic - Straddle - 8.19.24.pdf> ORIGINATED TRANSMITTAL DATE: 8/20/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5007 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 5007 1D-42 50029229790000 Tubing Cut Record 18-Aug-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 200-164 T39463 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.20 15:06:20 -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 tom.osterkamp@conocophillips.com ORIGINATED TRANSMITTAL DATE: 7/16/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4912 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 4912 1D-42 50-029-22979-00 Hoist (with logs) 5-Jul-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 200-164 T39214 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 13:23:32 -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 0 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): 8660'2965 8078' 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: 907-263-4529 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 6399' 8514' 6301'8087' KRU 1D-42 8430-8460' 8154' 3.5" 6246-6265' 7/20/2024 8660'659' 3-1/2" 6399' Baker ZXP Liner 5277' 8187' Perforation Depth MD (ft): 91' 5312' 6088'7" 20" 9-5/8" 57' Burst 8054' MD 91' 4225' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 200-164 P.O. Box 100360, Anchorage, AK 99510 50-029-22979-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8008'MD/5972'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 Adam Klem adam.klem@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD 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 10:17 am, Jun 18, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: Location: Date: 2024.06.18 09:26:52-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-350 DSR-6/18/24SFD 6/18/2024 10-404 VTL 7/5/2024 X X BOP test to 3500 psig Annular preventer test to 2500 psig &':IRU-/& Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.07.05 13:51:37 -08'00'07/05/24 RBDMS JSB 070924 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 17, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 1D-42 (PTD# 200-164). Well 1D-42 was drilled and completed in 2001 as a Kuparuk C sand producer. In 2005 CTD drilled additional footage in the C sands. This well was SI in 2022 for IAxOA leak, with leak identified at 4969' MD. Additionally, there is an estimated 88" of subsidence. Therefore, a subsidence workover is planned. If you have any questions or require any further information, please contact me at +1-907-263-4529 The RWO is to pull tubing from a planned pre-rig tubing cut, then set a plug in the 7" casing. We will log log the 7" for shallow cement, cut and pull the shallow 7", overshot with casing patch. We will then run a new tubing into the seals. Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: Location: Date: 2024.06.18 09:27:12-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem estimated 88" of subsidence 1D-42 RWO Procedure Kuparuk Producer Subsidence Repair PTD #200-164 Page 1 of 2 Completed Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPOT, IC-POT tests all passed 5/10/23, but re tests planned pre rig 2. Dummy off top GLMs, leaving GLM at 7920’ open 3. Obtain new SBHP 4. Set plug and catcher in nipple profile at 8087’ MD 5. PT tubing to 2500psi-failed a. Identified tubing leaks from 4863’-5120’ MD 6. RIH with packer on CTU. Set packer at 8068’ and PT to 2500psi-passed Remaining Pre-Rig Work 7. Attempt CDDT TbgxIAxOA to confirm plug and packer as a barrier 8. Cut tubing at ~7995’ MD (first full joint above packer) Rig Work MIRU 1. MIRU Nabors 7ES on 1D-42. Circulate well over to SW. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig cut at ~7,995’ MD Log Cement, Secure casing. Cut and pull casing 6. Rig up eline and run CBL from ~5300’ up to find TOC 7. RIH with 7” G-Plug and set at ~150’ below TOC’ PT to 1000psi for 30minutes. 8. ND BOPE. 9. ND tubing head. 10. NU BOPe to casing head 11. RIH with multi string cutter and cut 7” casing above TOC 12. Spear 7” casing 13. Shut in annular if necessary and circ surface to surface heated SW down through cut and up OA to circulate out arctic pack. 14. POOH LD 7” casing Run new casing and cement 15. Dress off 7” stump 16. RIH with new 7”, triple connect 17. Land 7” and confirm triple connect seals with 2500psi PT 18. ND BOP. NU tubing spool. NU BOP. Test break Pull plug 19. Run in to wash sand off top of plug. 20. Pull plug Run new Tubing 21. RIH with new 3 ½” completion to overshot tubing stub 22. Fully locate, PU and circulate in CI brine 23. Land tubing hanger. Install packoffs 24. Drop ball and rod. Pressure up to set packer. 25. PT tubing to 3000psi for 30min. Holding 2000psi on tubing, PT IA to 2500psi for 30minutes CBL from ~5300’ up to find TOC 1D-42 RWO Procedure Kuparuk Producer Subsidence Repair PTD #200-164 Page 2 of 2 26. Shear SOV 27. Install BPV. PT through SOV 28. ND BOP, NU WH 29. Circ in freeze protect tbg and IA Post Rig Work 1. Pull SOV, install GLD 2. Pull B&R and RHC plug 3. Pull XXN plug General Well info: Wellhead type/pressure rating: FMC Gen V Production Engineer: Barny Dogah Surveillance Reservoir Engineer: Cody Keith Estimated Start Date: 7/20/24 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion, subsidence repair 7” casing and run new 3-1/2” tubing BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CDDT TbgxIAxOA – passed 5/10/23, plan to re-attempt pre rig IC POT & PPPOT passed 5/10/23, plan to re-attempt pre rig TBG POT & PPPOT passed 5/10/23, plan to re-attempt pre rig MPSP: 2,965 psi using 0.1 psi/ft gradient Static BHP: 3588 psi/ 6225’ TVD (measured 6/6/24) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:8,514.0 1D-42 2/1/2004 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Plug 1D-42 6/7/2024 jhanse11 Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1D-42 (C-SAND), 1D-42L1 (??-SANDS) 7/18/2005 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 20 19.14 34.0 91.0 91.0 91.50 H-40 WELDED SURFACE 9 5/8 8.70 34.5 5,312.0 4,225.0 40.00 L-80 BTC MOD PRODUCTION 7 6.28 33.4 8,187.3 6,088.2 26.00 L-80 BTC MOD WINDOW L1 4 3.00 8,401.0 8,411.0 6,233.2 9.30 L-80 LINER 3 1/2 2.99 8,000.7 8,660.0 6,398.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.7 Set Depth … 8,054.0 Set Depth … 6,001.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 2.992 511.8 511.7 0.70 NIPPLE 4.520 CAMCO 'DS' NIPPLE w/2.875 NO GO PROFILE 2.875 2,653.2 2,498.3 44.03 GAS LIFT 5.390 CAMCO KBUG 2.920 4,839.9 3,922.2 51.21 GAS LIFT 5.390 CAMCO KBUG 2.920 6,235.3 4,821.8 49.59 GAS LIFT 5.390 CAMCO KBUG 2.920 7,150.8 5,414.5 49.55 GAS LIFT 5.390 CAMCO KBUG 2.920 7,920.0 5,915.0 49.65 GAS LIFT 5.390 CAMCO KBUG 2.920 7,971.7 5,948.4 49.79 NIPPLE 5.390 CAMCO 'DS' NIPPLE w/2.813 NO GO PROFILE 2.812 8,016.1 5,977.0 49.65 LOCATOR 5.125 BAKER NO GO LOCATOR 3.000 8,017.3 5,977.8 49.64 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSEMBLY 3.000 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) 4,969.0 4,004.0 50.10 LEAK - CASING PC LEAK IDENTIFIED ON VIVID LDL RUN 2/23/23 2/23/2023 6.280 8,079.0 6,017.9 49.49 CATCHER 2.71 Rig Junk Catcher OAL = 8' 6/6/2024 0.000 8,087.0 6,023.1 49.48 TUBING PLUG 2.813" XXN Plug w/ Fill Extension (52" OAL / 8- 3/16" EQ PORTS) 6/6/2024 0.000 8,414.0 6,235.1 49.16 Whipstock WEATHERFORD LSX-N FLOW-THRU WHIPSTOCK FOR MAIN LEG (1D-36) PRODUCTION PERFS 7/15/2005 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) 2,653.2 2,498.3 44.03 1 GAS LIFT DMY BK 1 0.0 6/4/2024 0.000 4,839.9 3,922.2 51.21 2 GAS LIFT DMY BK 1 0.0 6/4/2024 0.000 6,235.3 4,821.8 49.59 3 GAS LIFT DMY BK 1 0.0 2/19/2017 0.000 7,150.8 5,414.5 49.55 4 GAS LIFT DMY BK 1 0.0 2/19/2017 0.000 7,920.0 5,915.0 49.65 5 GAS LIFT open 1 1/2 0.0 6/6/2024 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) 8,000.7 5,967.1 49.70 TIE BACK 7.000 LINER TIE BACK SLEEVE 6.151 8,008.0 5,971.8 49.67 PACKER 5.980 BAKER ZXP LINER TOP PACKER 4.408 8,086.7 6,022.9 49.48 NIPPLE 5.500 HES 'XN' NIPPLE w/2.75"NO GO 2.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,430.0 8,460.0 6,245.6 6,265.3 C-4, C-1, 1D-42 2/23/2001 6.0 IPERF 2.5" HSD, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,430.0 8,460.0 1 FRAC 3/22/2001 0.0 0.00 0.00 1D-42, 6/7/2024 3:33:29 PM Vertical schematic (actual) LINER L1; 8,400.0-10,822.5 LINER; 8,000.7-8,660.0 FRAC; 8,430.0 IPERF; 8,430.0-8,460.0 SLOTS; 8,411.0-8,475.0 Whipstock; 8,414.0 WINDOW L1; 8,401.0-8,411.0 PRODUCTION; 33.4-8,187.3 TUBING PLUG; 8,087.0 CATCHER; 8,079.0 GAS LIFT; 7,920.0 GAS LIFT; 7,150.8 GAS LIFT; 6,235.3 SURFACE; 34.5-5,312.0 LEAK - CASING; 4,969.0 GAS LIFT; 4,839.9 GAS LIFT; 2,653.2 NIPPLE; 511.8 CONDUCTOR ; 34.0-91.0 KUP PROD KB-Grd (ft) 40.40 RR Date 11/8/2000 Other Elev… 1D-42 ... TD Act Btm (ftKB) 8,660.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292297900 Wellbore Status PROD Max Angle & MD Incl (°) 51.24 MD (ftKB) 4,845.87 WELLNAME WELLBORE1D-42 Annotation Last WO: End DateH2S (ppm) 70 Date 8/12/2016 Comment SSSV: NIPPLE 1D-42 Proposed RWO Completion Surface Casing, cmt to surface, full returns Production Casing, no cbl, 170sx no bump, floats held Conductor L1 Production Liner C-Sand Perfs 8430' RKB - 8060' RKB XN Open OA C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-23_21121_KRU_1D-42_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 21121 KRU 1D-42 50-029-22979-00 Archer Vivid Acoustic LDL 23-Feb-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Imag~roject Well History File Coverege XHVZE This page identifies those items that were not scanned during the initial production scanning ~ phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing Well History File Identifier RESCAN ~ Color items: Grayscale items: [] Poor Quality Originals: E] Other: NOTES: BY: DIGITAL DATA Diskettes, No. [] Other, No/Type BEVERLY ROBIN VINCENT SHERYL~INDY OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYI.. ~WINDY Scai~ning Preparation x 30 BY: BEVERLY ROBIN VINCENT SHERYL QINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY~ (SCANNING IS COMPLETE AT DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~ YES BEVER .... NCENT SHERYL MARIA WINDY DATE:.,2'/--/Z/¢ / NO IF NO IN STAGE 1, PAGE(S) DISCREPAN~~,~ERE FOUND: ............ O THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN I'~ PAGE P~ESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: /si Quality Checked 12/10/02 Rev3NOTScanned.wpd . . Conoc~hillips Alaska RECEIVED AUG 1 3 2007 Alaska OB & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 aÐo-/~1f SCANNED AUG 1 42007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 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. Sincerely, ~- 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 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qal 1 0-32 200-173 10" n/a n/a n/a 6.8 8/8/2007 1 0-36 200-130 20" n/a n/a n/a 4.2 818/2007 1 0-37 200-204 20" n/a n/a n/a 4.2 8/8/2007 1 0-38 200-077 24" n/a n/a n/a 4.2 8/812007 1 0-39 200-216 27" n/a n/a n/a 7.6 8/8/2007 1 0-40 200-190 13" n/a n/a n/a 3.4 8/8/2007 1 0-41 205-188 12" n/a n/a n/a 1.7 8/812007 10-42 200-164 16" n/a n/a n/a 3.4 8/8/2007 10-131 198-110 6" n/a n/a n/a 2 8/8/2007 03/20/07 Schlumbergel' "\ fJi ,.1 . I. L~. / /1'----"/ NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ') ~'1AF~ ~?- 1;. zour sCANNED APR 03 2007 Company: Alaska Oil & Gas Cons C'omm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk dOD -/0 <f Well Job# Log Description Date BL Color CD 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05107 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1 E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1 E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 35-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17107 1 1C-10 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 1042 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 16~ . . . Transmittal Form . r&iWl BAKEl HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman ,"¡(" i'!..tl~.!!;;;~\ ~~,r~~~~~j Reference: 1D-42L1PB1 Anchorage GEOScience Center 'i~, f' {~';;' ....: II Contains the following: i¡ II II i 1 LDWG Compact Disc I (Includes Graphic Image files) I 1 LDWG lister summary i ! i ¡¡ II 'I Ii II II II II II ! ! ¡ I 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log f , LAC Job#: 932692 ¡I Sent By: Deepa Joglekar I Received By: é] -ç. t{/\ ------- :1 II il II 1! " II II !I II II L 'I II II " !I n II il ,I p II ¡ II Date: Oct.16,2006 Date: J D / to¡ / ò (¿; I ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 [)6Ó - 10'-1 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 * 1;>1-03 IL=~I:::~~~ :=~",-~:,;c'~;''':~'~~~;1 l::-;"~''''-£'':'':;:'i r:,~ ~-' ",.,~~, ~, ~,:.: ¡ i""'''' f":~". I ,,"'" , ~...,,~......, i n:~:~ F~-'~·:~-:~-';:::,'! 1=-;", ~~~~: :~' ;...;;,! r<,>'-~- I," l:~.L: I I i I';"n. In r' I~ r /,'.. If ~t·_n Ij~"m .[, ¡I'· ùu;,.. fin i I I~" I I'u r I ¡ L. I ~~'~~> . ~1' MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001640 MD 8660 .--- TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. KUPARUK RIV UNIT 1D-42 Operator CONOCOPHILLIPS ALASKA INC 6399 ~-- Completion Dat 2123/2001 ~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22979-00-00 UIC N REQUIRED INFORMATION Mud Log N__~o Sample Nc) Directional Survey ~-,l~e-~_~. j.j~. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital ~Djgital Type ~Fmt R R (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH I Start Stop CH 5250 8606 Open Received 8/2712001 Survey Report MWD Survey Report BH Pressure/Tamp 10268 ~ICATION 10295 FINAL 7901 8566 FINAL 5250 8606 FINAL FINAL 5250 8606 5250 8606 1/9/2001 119/2001 ch 3/16/2001 OH 9/712001 OH 9/7/2001 ~ C3 ('~ 9/18/2001 4~s~J I~ 9/18/2001 Dataset NUmber/,/comments ...... 1026~'~ 5250-8606 Surface to TD Paper Report Surface to TD Paper Report 7901-8566 BL, Sepia 10268"'"~0-8606 DIGITAL DATA / 0 ;;),c~"- LIS VERIFICATION / 1029~t~5250-8606 Digital Data Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~) Chips Received ?--,,--W/'fIT-" Analysis ~ Received? Daily History Received? Formation Tops (~/N Comments: Permit to Drill 2001640 MD 8660 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. KUPARUK RIV UNIT 1D..42 Operator CONOCOPHILLIPS ALASKA INC 6399 mpletion Dat 2/23/2001 Completion Statu 1-OIL Current Status Date: APl No. 50-029-22979-00-00 UIC N PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99S10-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which' disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Gxeater Kuparuk Team Leader. RT/skad cc.' Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Dis ~osal durin ~ the fourth ~uarter ~ 2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 ., 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 , 2001 CD2.24 2981 100' 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept20ol October 1C-131 1C-i25, 1C-102 ~ 2001 ' CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 , 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 20Ol Nov 2OOl 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 20Ol Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 ' 371 NA* NA* *Freeze protect CD2-15 only ', CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 Total Volum, into Annuli ~or which Dis ~osal Fr~, Pro.ct To~l Volume S~ End Sour~ We~ To~ h(l) Total h(2) Total h(3) Fiui~ Injec~ Da~ Da~ Wall Name Volume Volume Volume Volume S~O~ 0f Annulna 2L-313 262~ 1~ 0 0 26390 ~en, F~'~o~ Mmeh 1999 D~ 2~ ~I,-317, ?I-307 ~ ID-36 301~ 1~ 0 0 302~ O~n, Fr~ ~o~ Oct 2~ ~ov 2~ lDO2, 1D-34 ED1-31 6698 1~ 0 392 7190 o~n, Fr~ ~omct~ Feb 2~1 M~h CDI-14 2~1 ~ 2N-~ 0 0 0 380 380 O~n, F~ ~o~ NA** NA** ** ~ protect volumes only 1D.~ 31915 I~ 0 218 32233 O~n, F~ ~o~ Nov 2~ D~ 2~ 1D-32, 1D~0A 2N-349A 0 0 0 0 0 O~n, Free~ ~~ ...... 1D.42 32~0 1~ 0 265 32~5 O~n, F~ ~o~ D~ 2~ J~ 2~1 1D-37, ID-39 Annular Dis ~osal durin , the fourth quarter of 2001: h(1) h(2) h(3~ Total for FreeT. e F~'eYious New S~ ~ Source Wells Well Name Volume Volume Volume Qufl~r ~otect To~! To~! Date Da~ Volum~ CD2-42 2193 1~ 0 2293 385 31314 33992 June Octo~r CD2-15, CD2-24, CD2-33 2~1 2~1 2P~17 5331 1~ 0 5431 0 627 6058 Sept 2~1 ~em~r 2P~20, 2P~8 2~1 CD2-~ 2981 1~ 0 3081 375 30543 33999 ~uly 2~] ~to~r CD2-15, CD2-33, CD2-39, 2~ CD2-14 1C-16 12338 1~ 0 12438 0 19679 32117 Sept2~l ~to~r .1C-131, 1C-125, 1C-102 2~1 CD2-39 274~ 1~ 0 275~ 379 0 27879 October Novem~r CD2-15, CD2~7 2~1 2~1 CD2-14 14359 1~ 0 1~59 376 0 14835 November ~ember CD2~5, CD2~7 2~1 2~1 , 1C-14 22389 1~ 0 2~89 0 0 22489 ~t2~l Nov 2~1 1C-109 - 2P-438 30331 1~ 0 3~31 212 0 30~3 ~t2~ ~2~ 2P~20, 2P~15, 2P~29 CD2-15 0 0 0 0 371 0 371 NA* NA* *F~eze pmt~t CD2-15 o~y CD2~7 10315 1~ 0 1~15 375 0 10790 ~ 2~ ~ 2~ CD2-34 ' t otut v otume,~' into nnnutt,/or wnt(;n ~tst~osat k~utnortzatton r_~xptrea aurtng tne fourtn ~ruarter &~$: Freeze Protect Total Volume Start l~nd Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ,, i 2L-313 26290 100 0 0 26390 Open, Preeze Protected March 1999 Dec 2000 2L-317, 2L-307 'iD-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 Cl)l-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 2N'305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect ....... volumes only 1 D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, ID-40A 2N-349A 0 0 0 0 0 Open, Freeze Proteeted ...... 11)-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 ri'! {,, WELL LOG TRANSMITTAL To: State of Alaska August 30, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-42, AK-MM-00232 The technical data listed below is being submitted her Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-42: Digital Log Images 1 CD Rom WELL LOG TRANSMITTAL To: State of Alaska Alaska OH and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska August 27, 2001 RE: MWD Formation Evaluation Logs 1D-42, AK-MM-00232 1 LDWG formatted Disc with verification listing. API#: 50-029-22979-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TI~ TRANSMITTAL LETTER TO ~ ATTENTION OF: Speny-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED SEP 0 7 2001 Alaska.Oil,& Gas Cons. Commi~ion Anchomoe PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Poet Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR ~ 5 ?.001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, First Quarter,'2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2001. Please call'me at 263-4603.should you have any questions. Sincerely, . paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lem°n Mike Mooney " Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Zoo ,. o ~'5'" '7.oo-loo 2~o" Annular Disposal durin ; the first quarter-of2001: ' h(1) ' h~(2). ' h(3~ 'Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 cm.33, col-NQ1, Cm-]0, Cm-~s . 2N'318 12276 100 . 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 · CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQI~ CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37~ 1D-39 .- 1D-32 23162 100 0 23262 . 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the first quarter 2001: ~- -Total Volume ' ' ' Start End Source Wells Total h(1) Tota!h(2) Total h(3) Injected Date Date Well Name Volume Volume. Volume Status of Annulus . 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD1-44, CDI-41, CD1- 19A CD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CDI-31, CD1-~' 30 ~ . ( PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 April 5, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1D-42 (200-164) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 1D-42. If you have any questiOns regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sincerely, J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad ORIGINAL RECEIVED APR 06 2001 Alaska Oil & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas [~ Suspended O Abandoned D Service O 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-164 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22979-00 4. Location of well at surface 9. Unit or Lease Name '"'t":";?;'~:::-'T"T'~ !~ 567' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671, 5959099) .... .' - .. ,.. ...... ~,'- Kuparuk River Unit At Top Pmdudng IntervalI [;.~'.'i'E i 10. Well Number AtTotal Depth26' FNL, 1989' FEL, Sec. 26, T11N, R10E, UM (ASP: 559144,5964351)i' "~T"-~-"~"~?/' I,,..'.:mr'~i-J.~ ~ E~ 11.Fleldand PooIID'42 202' FNL, 2044' FEL, Sec. 26, T11 N, R10E, UM (ASP: 559090, 5954175)~.-7--.~.~T~.."~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 35 feetI ADL 25650 & 25661 ALK 471 12. Date Spudded 13. Date T.D. Reached 14. Date Co.mp., Susp. Or Aband. _ 115. Water Depth, if offshore 16. No. of Completions October 23, 2000 November 5, 2000 "~~' '~'~"~' ~~ I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 8660' MD / 6399' TVD 8593' MD / 6354' TVD YES r~ No [~I N/A feet MD 1627' 22. Type Electric or Other Logs Run GR/Res/Neu Dens 23. CASING, LINER AND CEMENTING RECORD SE'I-I'ING DEPTH MD ~ CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 115' 30" 350 sx ASI 9.625" 40# L-80 Surface 5312' 12.25" 600 sx AS III Lite, 350 sx LIfeCRETE 7" 26# J-55 Surface 8188' 8.5" 170 sx Class G 3.5" 9.3# L-80 8001' 8660' 6.125' 172 sx Class G . , .... ;., ~,~;~;~'"'~'~' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD , intewal, size and number) SIZE DEPTH SET (MD) '.~." PACKER'S~=T (MD) 3.5" 8054' 8008' 8430'-8460' MD 6246'-6265' TVD 6 spf '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8430'-8460' 9.4 ppa 16/20 proppant on perfs, 109M# proppant behind pipe, left 23M# In wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 30, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OIL RATIO 4/2/2001 7 hrs Test Pedod > 530 8804 1 176Ii 16616 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVFrY - APl (cot0 press. 230 psi 750 psi 24-Hour Rate > 158 2569 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of o11, gas or water. Submit core chips. .,^ RECEIVED APR 06 2001 .Alaska Oil & Gas Oons. Commissio~ Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE !' ,,.~ :i i"k.,,.I ..?'~', 0 l G Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE YERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8413' 6234' Base Kuparuk C 8485' 6282' Top Kuparuk A 8604' 6361' Base Kuparuk A 8660' 6399' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hl,reby certify that the following Is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed [ ~'~, ~, ~. Title Drillln,q E n,qlneerin,q Supervisor Date-'~-' ~ '" J. Trantham Prepared by Sharon AIIsup. 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 (DF, 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. R E C E IV E D Item 28: If no cores taken, indicate "none". Form 10-407 APR 06 2001 Alaska Oil & Oas Cons, Commissior~ ,Anchorage Date: 12/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-42 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:10/23/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22979-00 10/22/00 (D1) MW: 8.8 VISC: 342 PV/YP: 41/43 APIWL: 10.8 TD/TVD: 115/115 (115) DRILLING @ 350' SUPV:FRED HERBERT / DENNIS CUNNINGH Move rig to 1D-42. Rig accepted on 1D-42 @ 1000 hrs. 10/22/00. Nipple up diverter stack and test. Hold prespud meeting. RIH w/BHA tag ~ 110'. 10/23/00 (D2) MW: 9.6 VISC: 306 PV/YP: 38/41 TD/TVD: 1547/1539 (1432) CIRC FOR WIPER TRIP. DEPTH, 2009' SUPV:FRED HERBERT / DENNIS CUNNINGH Drilling 12.25" hole from 115' to 225' APIWL: 8.6 10/24/00 (D3) MW: 9.6 VISC: 210 PV/YP: 43/48 APIWL: 6.6 TD/TVD: 3197/2865 (1650) DRILLING AHEAD ~ 3650' SUPV:FRED HERBERT Drilling 12.25" hole from 1547' to 2009'. Circ and cond for wiper trip. Pump sweep around. Wiper trip to HWDP, RIH no problems. Circ bttms up. Drilling 12.25" hole from 2009' to 3197' 10/25/00 (D4) MW: 9.7 VISC: 214 PV/YP: 53/58 TD/TVD: 4331/3596 (1134) M/U BHA & RIH W/ BIT 92 SUPV:FRED HERBERT APIWL: 4.8 Drilling 12.25" hole from 3197' to 3825'. Circ sweep around. Drilling from 3825' to 3873'. circ bttms up. POOH to 2009'. RIH to bottom @ 3873'. No problems, circ bottoms up after wiper trip. Drilling 12.25" hole from 3873' to 4331'. circ sweep around, circ hole clean for bit trip. Pump slug. 10/26/00 (D5) TD/TVD: 4331/3596 ( SUPV:FRED HERBERT MW: 9.8 VISC: 192 PV/YP: 57/52 0) DRILLING AHEAD ~ 4499' APIWL: 5.4 POOH. Change bits. RIH, bridge ~ 1975'. Attempt to work thru bridge. POOH for hole opener. RIH w/hole opener to 1975'. ream thru bridge @ 1975' to 2025'. Circ bottoms up. RIH to 4331' w/ no problems. Circ sweep. Circ hole clean. Monitor well pump dry job. POOH w/hole opener. No hole problems. RIH w/bit ~2. Date: 12/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT PaGe: 2 10/27/00 (D6) MW: 9.6 VISC: 195 PV/YP: 53/57 TD/TVD: 5320/4230 (989) CIRC & COND MUD FOR CASING RUN SUPV:FRED HERBERT APIWL: 4.4 RIH, no hole problems. Circ bottoms up. Drilling 12.25" hole from 4331' to 4480'. Work on SCR. Drilling 12.25" hole from 4480' to 5320'. Circ densified sweep, circ hole clean. Control power loss to top drive. IBOP partially closed. Circ hole clean. Monitor well. Pump dry job. POOH slow. 10/28/00 (D7) TD/TVD: 5320/4230 ( SUPV:FRED HERBERT MW: 9.6 VISC: 56 PV/YP: 18/18 0) CEMENT 9-5/8" CASING W/ DOWELL APIWL: 7.2 POOH to 1460'. Proper fill, no hole problems. RIH slow. Circ & cond mud for casing job. Monitor well. Pump dry job. POOH to run casinG. RiG up to run 9.625" casinG. Hold PJSM. Run 9.625" casing to 1600'. Not Getting proper returns. Circ bottoms up. Full returns no losses. Run 9.625" casinG. 10/29/00 (D8) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 5320/4230 ( 0) TROUBLE SHOOT SCR'S SUPV:FRED HERBERT Run 9.625" casinG. Circ and cond mud for cement job. PJSM. Pump cement. Nipple down diverter. Install wellhead and test to 1000 psi. Nipple up BOP stack. RiG up test equipment. 10/30/00 (D9) MW: 8.7 VISC: 40 PV/YP: 12/13 TD/TVD: 5583/4398 (263) DRILLING AHEAD DEPTH 5774' SUPV:FRED HERBERT APIWL: 9.2 Test BOPE to 250/5000. RIH tag cement @ 5223'. PSJM. Drill out plugs cement float equipment and 20' new hole to 5340'. Displace w/LSND mud. Circ to balance out mud weight for LOT. Perform LOT, 14.7 EMW. Drilling 8.5" hole from 5340' to 5583'. 10/31/00 (D10) MW: 8.9 VISC: 40 PV/YP: 12/11 APIWL: 6.6 TD/TVD: 6898/5250 (1315) DRILLING ~ 7150 SUPV:FRED HERBERT., G.R. WHITLOCK Circ and condition mud for PWD test. Perform PWD test. Drill from 5583' to 6898'. Pump sweep and monitor well. Short trip to shoe w/no problems. ChanGe out rig tongs and adjust counter weights. 11/01/00 (Dll) MW: 9.8 VISC: 45 PV/YP: 14/15 APIWL: 5.2 TD/TVD: 8200/6097 (1302) POOH FOR 7" CASING SUPV:G.R. WHITLOCK RIH slow w/no problems. ChanGe shaker screens. Drill from 6898' to 8200'. Circ sweep and condition mud. ( Date: 12/05/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/02/00 (D12) MW: 9.9 VISC: 45 PV/YP: 14/17 APIWL: 5.2 TD/TVD: 8200/6097 ( 0) CHECKING FLOATS SUPV:G.R. WHITLOCK RIH w/no problems. Circ and condition mud for casing job. POOH. Hold safety meeting. Run 7" casing to 8188'. 11/03/00 (D13) MW: 11.5 VISC: 53 PV/YP: 23/19 APIWL: 4.8 TD/TVD: 8200/6097 ( 0) CLEANING OUT 7" CASING SUPV:G.R. WHITLOCK CBU. Circ and cond mud. Cement casing. Did not bump plug. Check floats, OK. Set packoff and test to 5000 psi, OK. Test BOPE to 250/5000 psi. 11/04/00 (D14) MW: 11.5 VISC: 57 PV/YP: 25/26 TD/TVD: 8600/6358 ( 400) CIRC AFTER WIPER TRIP SUPV:G.R. WHITLOCK APIWL: 3.6 RIH to 8006'. Tag cement. Clean out cement to FC ~ 8103' circ for casing test. Test casing to 3500 psi, OK. Drill FC, shoe its, FC and 35' of new hole to 8235'. Circ hole clean for LOT. Run LOT to 15.3 ppg EMW. Displace hole w/new mud. Drill from 8235' to 8600' 11/05/00 (D15) MW: 11.5 VISC: 56 PV/YP: 25/25 APIWL: 3.6 TD/TVD: 8660/6399 ( 60) SUPV:G.R. WHITLOCK Drill from 8600' to 8660'. Circ sweep around. Monitor well. POOH to 8100' w/no problems. RIH w/no problems. Circ until hole clean. POOH. Hold safety meeting. RIH w/liner on 4" DP. 11/06/00 (D16) MW: 11.5 VISC: 51 PV/YP: 20/ 0 APIWL: 3.'4 TD/TVD: 8660/6399 ( 0) RUNNING COMPLETION TUBING SUPV:G.R. WHITLOCK RIH w/liner to 8165'. CBU. RIH w/liner to 8660'. Circ and condition mud. Safety meeting. Pump cement. Bump plug and check floats, OK. Set packer. Safety meeting. POOH. 11/07/00 (D17) MW: 11.5 VISC: 53 PV/YP: 21/18 APIWL: 3.4 TD/TVD: 8660/6399 ( 0) INJECTING MUD SUPV:G.R. WHITLOCK Hold safety meeting. RIH with tubing. Displace well w/seawater. Test tubing to 3000 psi for 15 min, OK. Freeze protect tubing and 7" x 3.5" annulus. N/D BOPE. 11/08/00 (D18) MW: 0.0 VISC: 53 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8660/6399 ( 0) INJECTING MUD AND CLEANING PITS SUPV:G.R. WHITLOCK N/D BOPE and secure. N/U Xmas tree. Test packoff to 5000 psi. Prepare for rig move while cleaning pits and injecting fluids. Rig released at 0830 hrs. 11/8/00. ( ... Page 1 of 2 Well Service Report Well IlJob Scope [IJob Number 1D-42 IID LLXNO SUPPORT-CAPITAL '11m11'O12o24.4 Date IIo~ Work I1~ Number 02123/2001 IIDR~LLING SUPPORT-CAPITAL: PERFORATE W/2.5" IHS~, ~ sPy l[2128 Day IIOperation Complete IIs~f~! [IK~y P~o~ IIsup~.or Il SWS-JOHNSON II ODELL Init Tbg Press II~i,-d Tbg Press IlI~t Inner'Ann IIFin~! Inner Ann Ili,~it Outer Ann 1350 II 800 II 1000 [I 1000 II 980 Daily IIPERFORATED: 8430' - 8460', 2-1/2" HSD, 6 SPF, 60 DEG PHASING. Summary IIOBTAINED SBHP AT 8445'= 3490 PSI. [Perf, Pressure Data] Time IILog Entry I[ll~"~' Outer 980 Ann-][ 11:00 [IARRIVE ON LOCATION, SWS UNIT 2128 ENG. JOHNSON/DROPIK 11'15 IITAILGATE SAFETY MEETING & SPOT UP 111:45 IIR.u. ' 12:45 IIPE~. SAFETY MTG., DISCUSSED NORMAL R.U. PROCEDURES AS WELL lAS WEATHER CONDITIONS , NEARBY HAZARDS, WORKERS ON ISCAFOLDING @ THE END OF OUR WELL FLOW LINE, ASSIGN SPILL ICHAMPION, FILL OUT PAPERWORK. I 13:10 II~RM ~UN & STAB ON WELL TREE [ 13:40 II T LUBE TO 500g FOR 5 MIN./THEN TO 300g & HOLD FOR 15 MIN. 114:00 IIR.I.H. I 14:20 ,. IIPOWER UP UNIT BELOW 200' MSL I 14:45 licK UP WT ABOVE JEWELRY @ 7600' 14:55 IICORRELATE THROUGH JEWLRY 15:30 IILOO UP TO TIE IN. 15:45 IILOG UP INTO SHOOT POSITION. 16:40 IlP~ssu~ UP TUBING TO 3000 PSI, PERF. W/2.5" HSD, 6 SPF GUN/GOOD ISHOT INDICATION. TUBING PRESSURE DROPPED TO 2200 PSI. .16:50 IIP. O.O.H. 17:30 Il@ SURFACE/BLEED DOWN, UNSTAB & CHANGE TO THE 10' GUN I. 18:00 IIR.I.H. w/SECOND GUN 1 ~."~ 4: I I'T'T'~ T'NT Till t~.T TNT # 0 19:45 POSITION TO SHOOT, TBG PRESSURE 900 PSI. SHOOT GUN # 2- GOOD SHOT INDICATION 12o:oo IlP.o.o... I Page 2 ot 2 19:45 POSITION TO SHOOT, TBG PRESSURE 900 PSI. SHOOT GUN # 2- GOOD SHOT INDICATION 12o:oo liP.O.O.H. I 20:45 IIUNSTAB @ SURFACE & CHANGE TOOL FOR PRES. TEMP SURVEY I [ 21:00 IIR.m TO OBTAIN SBHP STATION READING @ 8445' I 22:45 [IFINISH STATION READINGS/P.O.O.H. I I 23:30 IIooH, RD. S~.CU~ mEg. I Page 1 of 2 Well Service Report W~al IIJou s~o~ iiJo~ ~mU~ 1D-42 IIDRILLING SUP~'O~T-C^PXTAL 1102~ 1012024.4 ~=~ I1~ Work I1~' Number o3/22/2~x IIDR~L~G SUPPORT-C~~: IN~I~ C S~D ~CI IIOper~o.CompleteIIs~sa~!Ilgey P~l~onIlSup~or 0 II T~ II raise II DS-G~LEGOS II ODELL · Press IlFin~l Tbg Press IlXnit Inner Ann IIFinal Inner Ann IlI~it Outer Ann 1390 II o II 400 II 500 II 1000 Ilnn~! Outer Ann II 7~o Daily PUMPED INITIAL C SAND FRAC. COMPLETED BREAKDOWN, SCOUR Summary STAGE, AND DATAFRAC. ANALYZED DATAFRAC, NO CHANGE TO ORIGINAL DESIGN. PUMPED PROPPANT STAGES, SAW TSO AT ~50 MINUTES INTO JOB (MATCHES DESIGN PREDICTION), HAD NWBSO W/ 9.4 PPA 16/20 PROPPANT ON PERFS, 109M# PROPPANT BEHIND PIPE. LEFT 23M# IN WELLBORE. [Frac-Refrac] Time IILog Entry 07:30 lids P~ RIG-uP S~TY MEETING. MIRU DS FRAC FLEET. 10:00 PRE-JOB SAFETY MEETING. (11 DS, 2 LRS, 2 APC, 1 PAI). JOB REVIEW, MUSTER AREA, CONGESTED PAD, WATCH FOR OTHER CREWS · WORKING ON PAD. 10:15 FINISH RIG-UP. WORK ON GEL QUALITY. BUILD 20# GEL FOR BREAKDOWN. PRIME UP AND WARM UP LINES. CAN'T GET FLUID TO TATTLE TAIL TANK, LOOK FOR ICE PLUG. BLEED OA FROM 1000 PSI TO 700 PSI. 11:15 ICE PLUG IN CHECK VALVE, TENT AND HEAT CHECK VALVE, BREAK THROUGH' ICE PLUG TO TANK, FLUSH LINE WITH WARM DIESEL. SWAP OUT RUBBER IN WRAP-AROUND ON SUPERPUMPER. ~:~o liszT T~SAV~R, eT LINES TOO000 PSI, GOOD TEST. I 12:05 START BREAKDOWN STAGE. 192 BBL LINEAR 20g GEL. 28 BPM MAX, SAW PRESSURE BREAK BACK FROM 6200 PSI TO 4700 PSI. PERFORMED SDT, XS FRIC = 795 PSI @ 28 BPM, ~ 350 PSI @ 15 BPM. ISIP = 1988 PSI, FG = 0.76 PSI/FT. MAKE GEL FOR SCOUR STAGE. 12:25 START SCOUR STAGE, 100 BBL 40g XL GEL PAD, 50 BBL 1 PPA SCOUR STAGE, 126 BBL LINEAR 20g GEL FLUSH. SAW NO RESPONSE WITH SAND THROUGH PERFS, PERFORMED SDT, XS FRIC = 300 PSI. ISIP = 1949 PSI, FG = 0.76 PSI/FT. MAKE GEL FOR DATAFRAC. I 1 ,~ ./Nt~ II~,l" A D"I" TN A ~ A '~'D A/~ '7'2 'I~'I~T ,4/'YH. 'V'I' g'n_'~'l' OI'x. l~'l~T "')/N4/- T T'N.T'~' A 'D ~ T T~T..I' Page 2 of 2 PERFORMED DECLINE ANALYSIS, FWHTP = 3405 PSI, ISIP = 2140 PSI, PC 1921 PSI, TC = 10.45 MIN, EFFC = 56.4%, FG = 0.79 PSI/FT. NO CHANGE TO JOB DESIGN. MAKE GEL FOR FRAC. 14:05 START PROPPANT STAGES. HAVING PROBLEMS WITH ACTIVATOR PUMP. 2 FALSE STARTS. FLUSH ACTIVATOR LINE. 14:15 START PUMPING FRAC AS PER ORIGINAL DESIGN. SAW TSO INITIATE IN 4-10 PPA RAMP STAGE, 48 MINUTES INTO JOB. LOST ONE PUMP, BROUGHT OTHER TWO UP TO COVER RATE. 15:30 HAD NWBSO 46 BBLS INTO 10 PPA FLAT STAGE AT SURFACE W/9.4 PPA ON PERFS, 109M# BEHIND PIPE. LEFT 23M# IN WELLBORE. SHUT DOWN. :FLUSH DS EQUIPMENT. RIG DOWN FRAC FLEET. 17:00 :DS RIGGED OFF OF WELL, WELL SECURED. ALL TREESAVER CUPS 'RECOVERED. 17-Nov-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 1 D-42 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,660.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Kuparuk-River Unit Phillips Alaska Kuparuk 1D, Slot 1D-42 1D-42 sUrveyed: 5 November, 2000 S UR VEY REPORT 17 November, 2000 Your Re'f:. AP1500292297900 Surface Coordinates: 5959099.20 N, 580670,Sf~ E '(70' f ?' 55.7397' N, Kelly Bushing: '/05.00fl above Mean Sea Level 2'/0' 29' 28.8270' E) . A I-I~lllburton Company Survey ReP. svy9337 Sperry. Sun Drilling Services Survey Report for tD-42 Your Reft AP1500292297900 Surveyed: 5 November, 2000 ' KuparUk River Unit Measured Depth (ft) 0.00 110.00 193.44 281.03 ' 379.84 472.41 561.71 656.65 748.62 838.95 891.37 930.45 1022.66 1112.30 1205.76 Incl. 0.000 0.000 0.320 0.280 1.390 1.070 0.240 0.780 1.420 0.830 0.590 0.500 2.880 4.960 6,940 1300.88 9.120 1393.90 11.370 1486.42 13.360 1583.96 15.190 1674.07 '17.340 1767.12 20.390 1859.44. 23.240 1953.00 26.480 2046.19 27.330 2140.28 29.590' 0.000 .0.000 5.970 224.630 232.520 215.590 73:430 231.670 '218.940 294.150 357.220 285.020 229.880 217.420 232.050 225.050 220.280 224.960 216.500 -207.900 .. 205.860 206~90 206.320 201~560 195.010 Sub-Sea Depth (ft) -105.00 -5.00 88.44 ' 176.03 274.83 367.38 456.67 551.61 643.56 733.88 825.37 917.64 1006.97 1099.92 1194111 1285.64 1376.01 1470.55 1557.06 1645.10 1730.80 1815.68 1898.79 1981.53 Vertical Depth 0.00 110.00 193.44 281~03 379~83 .472.38 56'1.67 656.61 748.56 838.88 -891.29 930.37 1022.54 1111.97 1204.92 . 1299.11 1390.64 1481.01 1575.55 1662.06 1750.10 1835.80 1920.68 2O03.79 2086.53 Local Coordinates- Northings Eastings (it) 0.00 N 0.O0 E 0.00 N 0.00 E 0.23 N 0.02 E 0.32 N 0.10 W 0.58 $ ' 1.22 W Global Coordinates Northings Eastinga (ft) (ft) 5959099.20 N 560670.81 E 5959099.20 N 560670.81 E 5959099.43 N 560670.83 E 5959099.52 N 560670.71 E 5959098.61 N 560669.59 E 1.96 $ ' 2.62 W 5959097.21 N 560668.21 E 2.59 S ..2.92 W 5959096.59 N 560867.91 E 2.93 S 3.24 W 5959096.24 N 560667.60 E 4.21 S 4.45 W '5959094.96 N 560666.40 E 4.81 S '5.75 W . 5959094.34 N 560665.10 E 4.39 $ 6.11 W 5959094.76 N 560664.74 E 4.14 $ 6.28 W 5959095.01 N 560664.56 E 5.53 S 8.44 W 5959093.60 N 560662.41 E 10.06 8 12.52 W- 5959089.04 N 560658.37 E 16.74 S 19.43 W 5959082.30 N 560651.52 E 25.60 S 37.81 S 52.33 S 70.58 S' 91.94 S 29.29 W - 5959073.36 N 560641.72 E 40.44 W 5959061.07 N 560630.68 E 53.89 W 5959046.44 N 560617.34 E 69.46 W 5959028.68 N '560601.92 E 82.77 W . 5959006.59 N 560588.79 E 118.79 149.53 164.71 223.23 265.78'S 96.33W 111.56W 129.13W 146.21W 160.16W 5958979.64 N 560575.44 E 5958948.78 N 560560.46 E 5956913.45 N 560543.18 E 5958874.79 N 560526.41 E 5956832.14 N 560512.80 E Dogleg Rate ('/lOOit) 0.00 0.38 0.65 1.13 0.52 1.42 1.06 0.74 1.61 1.47 1.65 2.85 2.49 2.65 2.51 2.58 2.41 2.84 3.58 3.35 3.11 3.47 2.48 4.09 Vertical Section 0.00 0.00 -0.23 -0.27 0.93 2.69 3.38 3.80 5.39 6.37 6.08 5.90 7.90 13.48 22.00 33.51 48.60 66.62 88.84 113.30 143.05 177.01 215.94 257.88 302.65 Phillips Alaska Kuparuk 1D Comment AK-6 BP_IFR-AK Continued... .17 November, 2000 - 17:19 - 2 - DrillQuest 2.00.05 .-, -Kuparuk River Unit Measured Depth fit} 2228.14 2322.02 . 2413.58 2506.55 2598.67 2691.33 2787.59 2875.72 2969.07 3062.00 3156.02' 3250.49 3345.7O 3438.53 3531.98 Incl. 31.110 34.830 36.570 39.260 42.350 45.200 47.330 48.38O 48.420 48.580 48.610 ~48.570 '48.300 49.780 49.650 Azim. 196.880 194.270 195.830 199.!10 198~16o 196.620 196.550- -197.540 '197.380 198.940 . 200.500 .196.850 · 196.510 198.800 i98.920 3626.78 49.470 198.300 3720.43- 49.310 199.990 3812.34 50.790 197.330 3905.18 50.610 195.860 3999.72 50.270' 196.250 4091.44 50.050 4187.69 '50.220 4264.73 50.450 4277.75 50.310 4376.61 49.600 196.170 198.010 - 197.480 197.550 198.120 Sub-Sea Depth fit) 2057.34 2136.10 2210.45 2283.80 2353.52 2420.42 - 2486.96 2546.10 2608.07 2669.65 2731.84 2794.34 2857.51 2918.36 2978.79 304o.28 3101.24 3160.26 3219.07~ 3279.28 . 3338.04 3399.73 3448.91 3457.21 3520.82 Sperry. Sun Drilfl' g Services survey Repo~. fOr '1D.42 Your Ref: AP1500292297'900 Surveyed: 5 November, 2000 Vertical Depth 2162.34 :2241.10 2315.45 2388.80 2458.52 2525.42 2591.96 2651.10 2713.07 2774.65 2836.84 2899.34 .2962.51 3023.36 3083.79 3145.28 3206.24 3265.26 3324.07 3384.28 3443.04 3504~73 3553.91 3562.21 3625.82 Local Coordinates Northings fit) ' 308.45 S 357.66 $ 409.25 S 463.71 $ 520.75 S 581.92 S ' 648.57 S 711.04 S 777.63 S 843.76 S 910.14 S 977.24 S 1045.48 S · 1112.27 S 1179.73 S -. · 1248.10 S 1315.26 S 1382.01 S 1450.86 S -1520.90 8 1588:53 S 1659.14 S 1715.62 8 1725.18 S 1797.23 $ Global Coordinates Easting$ Northinga Eastings fit) fit) fit) 172.37 W 5958789.37 N 560500.93 E 186.03 W 5958740.05 N 560487.67 E 199.92 W 5958688.35 N 560474.20 E 217.11 W 5958633.76 N 560457.45 E 236.33 W ' 5958576.56 N 560438.70 E -255.46 W ' 5958515.24 N 560420.06 E 275.31 W 5958448.43 N 560400.74 E 294.47 W 5956385.80 N 560382.08 E 315.41 W -5958319.05 N 560361.68 E 337.11 W. 5958252.74 N 560340.53 E 360.90 W 5958186.17 N 560317.27 E 383.58W. 5958118.89 N 560295.13 E 404.03 W - 5958056.49 N 560275.24 E 425.30 W 5957983.54 N 560254.50 E 448.34 W 5957915.89 N 560232.00 E 471.37 W 5957847.33 N 560209.53 E 494.68 W 5957779.99 N 560186.76 E 517.21 W 5957713.06 N 560164.78 E 537.72 W 5957644.05 N 560144.82 E 567.88 W 5957573.84 N 560125.23 E 577.54 W 5957506.06'N 560106.11 E 599.25 W .5957435.28 N 560084.97 E 617.33 W 5957378.65 N 560067.35 E 620.34 W 5957369.06 N 560064.41 E 643.52 W 5957296.84 N 560041.82 E Dogleg Rate ('/100ft) 2.04 4.24 2.14 3.61 3.42 3.28 2.21 1.45 0.14 1.27 1.24 2.90 0.39 2.45 0.17 0.53 1.38 2.74 1.24 0.48 0.25 1.48 0.61 1.15 0.84 Vertical Section 347.00 398.01 451.34 508.45 568.64 632.72 702.24 767.56 837.36 906.96 977.45 1048.28 1119.49 1189.57 1260.86 1333.01 1404.09 1474.54 1546.34 1619.17 1689.55 1763.40 1822.71 1832.73 1908.41 Phillips Alaska Kuparuk ID Comment Continued... 17 November,-2000 - 17:19 DrillQuest ZOO.05 sperrY'sun Drilling Services Survey Report for tD-42 Your Ref: AP1 500292297900 Surveyed: 5 November, 2000 KuparUk River Unit Measured Depth (ft) Incl. . 4471.13 49.260 4564.74 50.260 4661.27 .50.480 4752.17 50.780 4645.88 51.240- 4943.01 50.340 5035~40 49.470 5127.61 49.670 5223.66 50.050 5259.44 50.410 · . 5356.51' 50.740 5413.45 50.490 5513.08 .49.950 5607.36 49.560 5701.71 49.210 5795.68 49.890 5888.96 49.690 5983.64 49.140 6077.33 49.740 6171.60 49.280 6262.96 49.720 6356.02 - 50.420 6451.50'- 50.010 6546.48 49.490 6639.88 49.020 200.470 197.800 197.440 196.890 195.090 200.910 197.840 193.500 195.230 196.760 197.450 198.100 198.260 197.510 - 198.500 198.390 .196.880 197.280 197.200 -197.020 _. - 197.670 198.460. 198.470 198.820 198.360 Sub-Sea Depth (ft) 3582.30 3642.77 3704.34 3762.00 3820.97 3882.40 3941.91 4001.73 4063.65 4086.54 4148.19. 4184.32 .4248.06 4308:97 4370.39 4431.36 4491.58 4553.18 4614.10 4675:31 4734.64 4794.38 4855.47 4916.64 4977.80 Vertical Depth (ft) '3687.30 3747.77 3809.34 3867.00 3925.97 3987.40 .4046.91 4106.73 4168.65 4191.54 4253.19 4289.32 4353.06 4413.97 4475.39 4536.36 4596.58 4658.18 4719.10 4780.31 - 4839.64 4899.38 4960.47 5021.84 5082.80 Local. Coordinates- Northings (ft) 1864.99 S 1932.49 S 2003.34 S 2070.48 $ -2140.50S Eastings (ft) 667.24 W' 690.65 W 713.15 W 733.89 W 753.95 W 2212.03 $ 2278.68 S 2346.23 S 2417.36 S 2443.79 S Global Coordinates Northings Eastinge (ft) (ft) 2515.46 2557.37 2530.11 2698.59 '2768.71 2834.54 2902A3 2971.16 3039.14 3107~66 5957228.89N 560018.65 E 5957161.20N 559995.79 E 5957090.16 N- 559973.86 E 5957022.86N 559953.66E 5956952.68. N 559934.17 E 777.16 W 5956680.97 N 559911.53 E 800.62 W 5956814.13 N 559888.62 E 819.56 W 5968746.43 N 559870.22 E 837.78 W · 5956675.16 N 559852.57 E 845.36 W 5956648.66 N 559845.21 E 3173.97 S 3241.81 S 3311.4-1 S 3380.09 S 3447.16 S 867AIW 5956576~82N 559823.73 E .880~85W 5956534.81N 559810.64E' 904.74W 595646i.87N 559787.34E 926.84W- 5956393.21N 559765.79 E 948.97W 5956324.92 N 559744.20 E 971.60 W .5956256.91 N 559722.13 E 993.18 W 5956188.85 N- 559701.09 E 1014.30 W .- 5956119.95 N 559680.53 E 1035.39 W 5956051.80 N ' 559659.99 E 1056~49 W . 5955983.11 N 559639.45 E 1077.20W 5955916.64N 559819.27 E 1099.33W 5955848.62 N 559597.69 E 1122.57W- 5955778.84N 559575.01E 1145.74W 5955709.97 N 559552.39 E 1168.30W -5955642.72 N 559530.38 E Dogleg Rate ('lt00ft) 1.92 2.43 O.37 O.57 1.57 4.73 2.71 3.59 1.43 3.44 0.65 0.99 0.56 0.73 0.88 0.73 1.25 0.66 0.64 0.51 0.72 0.99 0.43 0.62 0.63 Vertical Section 1980.19 2051.63 2125.97 2196.22 2268.99 2344.19 2414.84 2484.92 2558.17 2585.65 2660.61 2704.62 2781.19 2853.15 2924.76 2996.27 3067.50 3139.39 3210.55 3282.23 3351.69 3423.05 3496.42 3568.91 3639.67 Phillips Alaska Kuparuk ID Comment Continued... DrillQuest 2.00.05 17 November, 2000 - 17:19 - 4 - Kuparuk River Unit Measured Depth' (ft) 6730.54 6824.1.9 6923.23 7016.97 7i10.67 7204.80 7299.22 7392.60 7483.54 7575.61 7669.22 7765.33 7860.41 7954.29 8047.76 Incl. 49.290 49.920 49.68O 49.390 49.490 49.63O 48.730 49.220 49.670 49.910 49.220 49.540 49.320 49.840. 49.550 8127.55 49.400 8207.29- 49.570 8303.83 49.900 8400.47 49.240 8496.68 48.67O .8592.37 8660.00 47.780 47.780 198.040 198.310 1'98.300 197.940 198.070 197.430' 197.150 196.330 196.630 196.140 · 194.810 195.680 196.690 197.550. 197.500 197.130 i96.960 196.510 197.900 197.510 197.300 197.300 Sub-Sea Depth (~) 5037.10 5097.79 5161.71 5222.55 5283.48 .. 5344.53 5406.25 5467.55 5526.68 5586.12 5646.83 5709.40 5771.24 5832.11 5892.57 5944.42 5996.22 6058.62 6121.29 6184.47 6248.22 6293.66 Sperry-Sun Drilling Services Survey Report for fDa42 Your Ref: AP1 500292297900 Surveyed: 5 November, 2000 Vertical Depth (ft) 5142.10 5202.79 5266.71 5327.55 5388.48 6449.53 5511.25 5572.55 5631.68 5691.12 5751.83 5814.40 5876.24 5937.11 5997.57 6O49.42 6101.22 6163.62 6226.29 6289.47 6353.22 6398.66 Local COordinatee Global Coordinates Northlngs Northinga Eaetings (ft) (ft) (ft) '3512.31S 5955577.40 N 559509.48 E 3580.08 S' 5955509.45 N 559487.78 E 3651.90 $ 5955437.45 N 559464.60 E 3719.68 S 5955369.49 N 559442.97 E 3787.38 S.' -5955301.61N 559421.52 E 3855.61S 3923.83 S 3991.29 S 4057.55 S 4125.00 S 4'193.67 S 4264.05 S 4333.41 S 4401.71 S. 4469.69 S 4627.59 S 4585.55 $ 4656.09 S 4726.36 S 4795.48 S 4863.58 S 4911.40 $ Eeetlnge 1189.72 W 1211.97 w 1235.73 w 1257.91 w 1279.91 w 13o1.75w '1322.99 W 1343.28 W 1362.88 W 1382.71 W 1401.73 W 1420.91 W 1441.04 W 1462.08 W 1483.55 W 1 501.60 W 1519.37 W 1540.58 W 1562.33 W 1584.40 W 1605.75 W 1620.64 W 5955233.21N 559400.23 E 5955164.82 N 559379.54E 5955097.19 N 559359.80 E '5955030.78 N 559340.73 E 5954963.17 N 559321.44E 5954894.35 N 559302.98 E 5964823.82 N 559284.37 E -5964754.30 N 559264.80 E 5964685.83 N 559244.31 E 5954617.68 N 559223.40 E 5954559.64 N 559205.81 E 5954501.54 N 559188.51 E 5954430.82 N 559167.87 E 5954360.38 N 559146.69 E 5954291.08 N 559125.18 E 5954222.82 N' 559104.38 E -5954174.88 N 559089.87 E Dogleg Rate (°/'tOOft) 0.40 0.71 0.24 0.43 0.15 0.98 0.85 0.55 0.48 1.31 0.76 0.84 0.89 0.31 0.40 0.27 0.49 1.29 0.67 0.94 0.00 Vertical Section 3708.25 3779.58 3855.22 3926.54 3997.72 4O69.36 4140.80 4211.22 4280.28 4350.55 4421.71 4494.56 4566.73 4638.18 4709.46 4770.10 4830.71 4904.34 4977.89 5O5O.44 5121.80 5171.87 Phillips AlaSka Kuparuk ID Comment Projected Survey Continued... DrlllQuest2.00.05 17 November, 2000 - 'i7:t9 - 5 - Sperry. Sun Drilling Services Survey Report for I D-42 Your Ref: APl 500292297900 SurveYed: 5 November, 2000 ' KuparUk River Unit All data is in feet 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 26.398' (20-Oct-00) The Dogleg seVerity is in Degrees per 100 feet. .. Vertical Section is from Well and calculated, along an Azimuth-of 198.320° (True). Based upon Minimum CurvatUre type calculations, at a Measured Depth of 8660.00ft., The Bottom Hole Displacement is 5171.88ft., in the Direction of 198.262° (True). Phillips Alaska Kuparuk 1D Comments Measured Depth .(ft) .. -- 8660.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6398.66 4911.40 S 1620.64W Comment Projected Survey. Continued... .17 November, 2000 - 17:19 -6- DrillQuest 2.00.05 Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 1D-42 .. . Your Ref: AP1500292297900 Surveyed: 5 November, 2000 Phillips Alaska Kuparuk ID Survey tool program for 1D~42 From Measured Vertical Depth Depth (ft) (ft) To Measured. Vertical Depth Depth (ft) . (ft) 0.00 0.0o .8660.00 6398.66 .. . Survey Tool Description AK-6 BP_IFR-AK 17 November, 2000 - t7:19 - 7 - DrlllQuest 2.00.05 Kuparuk River Unit Phillips Alaska Kuparuk f D, 'Slot ~D-42 ~D.42 MWD Surveyed: 5 November, 2000 SURVEY REPORT 17 November, 2000 Your Ref: AP1500292297900 Surface Coordinates: 5959099.20 N, 560670.8~ E (70° 17' 55.7397' N, 2t0° 29' 28.8270' E) Kelly Bushing: fOS.00fl above Mean Sea Level DRILLING Survey Ref: svy9338 A H,,lllburton Company Sperry-Sun Drilling Services Survey Report for '1D-42 MWD Your Ref: AP1500292297900 . Surveyed: 5 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -105.00 0.00 110.00 0.000 0.000 5.00 110.00 193.44 0.320 7.060 68.44 193.44 281.03 0.280 224.970 176.03 281.03 379.84 1.390 232.620 274.83 379.83 Local Coordinates Northings Eastings. (ft) (ft) 472.41 1.070 215.650 561.71 0.240 73.090 656.65 0.780 231.680 748.62 1.420 218.910 838.95 0.830 294.200 Global Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E 5959099.20 N 560670.81 E 0.00 N 0.00 E 5959099.20 N 560670.81 E 0.23 N 0.03 E '5959099.43 N 560670.84 E 0.32 N 0.09 W 5959099.52 N 560670.71 E 0.58 S 1.22 W 5959098.61 N 560669.60 E 367.38 472.38 1.96 S 2.61 W 456.67 561.67 2.58 S 2,92 W 551.61 656.61 2.93 S 3.24 W 643.56 748.56 4.20 S 4.44 W 733.88 838.88 4.80 S 5.74 W 891.37 0.590 357.790 786.29 891.29 930.45 0.500 285.500 825.37 930.37 1022.66 2.880 229.920 917.54 1022.54 1112.30 4,960 217.670 1006.97 1111.97 1205.76 6.940 232.080 1099.92 1204.92 1300.88 9.120 225.160 1194.11 1299.il 1393.90 11.370 220.510 1285.64 1390.64 1486.42 13.360 225.340 1376.01 1481.01 1583.96 15.190 215.930 1470.55 1575.55 1674.07 17.340 208.480 1557.06 1662.06 5959097.22 N 560668.21 E 5959096.59 N 560667.91 E 5959096.25 N 560667.60 E 5959094.96 N 560666.40 E 5959094.35 N 560665.11 E 4.38 S 6.10 W 5959094.77 N 560654.75 E 4.13 S 6.27 W 5959095.02 N 560654.57 E 5.52 S 8.43 W 5959093.62 N 560662.42 E 10.03 S 12.52 W 5959089.07 N 560658.37 E 16.70 S 19.45 W 5959082.34 N 560651.50 E 25.55 S 29.33W 5959073.41N 560541.69 E 37.72 S 40.51W 5959061.15 N 560630.60 E 52.17 S 54.04W 5959046.59N 560617.19 E 70.44S 69.56W 5959028.20 N 560601.82 E 91.81S 82.89W 5959006.72 N 560588.66 E 1767.12 20.390 206.140 1645.10 1750.10 1859.44 23.240 206.460 1730.80 1835.80 1953.00 26.480 205.890 1815.68 1920.68 2046.19 27.330 201.310 1898.79 2003.79 2140.28 29.590 194.920 1981.52 2086.52 118.56 S 96.65 W 5958979.87 N 560575.12 E 149.31 S 111.85 W 5958948.99 N 560560.16 E 184.61 S 129.19 W 5958913.56 N 560543.11 E 223.23 S - 146.04 W 5958874.80 N 560526.58 E 265.82 S 159.88 W '5958832.10 N 560513.09 E Dogleg Rate ('ll00ft) 0.00 0.38 0.65 1.13 0.52 1.42 1.06 0.74 1.61 1.48 1.66 2.85 2.49 2.54 2.50 2.58 2.42 3.02 3.32 3.38 3.09 3.47 2.40 4.03 Vertical Section 0.00 0.0o -0.23 -0.28 0.93 2.68 3.37 3.79 5.38 6.36 6.07 5.89 7.89 13.46 21.97 33.47 48.54 66.51 88.74 113.21 142.93 176.90 215.86 257.82 302.60 Phillips Alaska Kuparuk 1D Comment MWD Magnetic Continued... f7 November, 2000- 17:21 -2- DrillQuest 2.00.05 Sperry-Sun Drilling-Services Survey Report for 1D-42 MWD Your Ref: AP1 500292297900 Surveyed: 5 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2228.14 31.110 196.790 2057.34 2162.34 2322.02 34.830 194.180 2136.09 2241.09 2413.58 36.570 195.680 2210.45 2315.45 2506.55 39.260 198.870 2283.79 2388.79 2598.67 42.350 197.890 2353.51 2458.51 2691.33 45.200 196.280 2420.42 2525.42 2787.59 47.330 196.150 2486.96 2591.96 2875.72 48.380 197.130 2546.09 2651.09 2969.07 48.420 196.870 2608.07 2713.07 3062.00 48.580 198.600 2669.65 2774.65 3156.02 48.610 200.210 2731.84 2836.84 3250.49 48.570 197.100 2794.33 2899.33 3345.70 48.300 196.680 2857.50 2962.50 3438.53 49.780 198.930 2918.36 3023.36 3531.98 49.650 198.910 2978.78 3083.78 3626.78 49.470 198.220 3040.27 3145.27 3720.43 49.310 198.480 3101.23 3206.23 3812.34 50.790 197.280 3160.25 3265.25 3905.18 50.610 196.020 3219.05 3324.05 3999.72 50.270 196.300 3279.26 3384.26 4091.44 50.050 196.220 3338.02 3443.02 4187.69 50.220 198.180 3399.72 3504.72 4264.73 50.450 197.500 3448.90 3553.90 4277.75 50.310 198.400 3457.20 3562.20 4376.61 49.600 198.270 3520.80 3625.80 Local Coordinatea Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (fi) 308.51S 172.02W 5958789.31N 560501.29 E 357.74 S 185.60W 5958739.97 N 560488.11E 409.36 S 199.37W 5958688.24N 560474.75 E 463.88 S 216.38W 5958633.59N 560458.18 E 521.00 $ 235.34W 5958576.31N 560439.68 E 582.27 $ 254.15 W 5958514.89 N 560421.37 E 649.06 S 273.57 W 5958447.96 N 560402.49 E 711.66 $ 292.29 W 5958385.20 N 580384.28 E 778.42 S 312.70 W -5958318.28 N 560364.41 E 844.70 S 333,90 W 5958251.83 N 560343.74 E 911.21S 357.32W 5958185.13 N 560320.85 E 978.33 S 379.98W 5958117.84N 580298.74E 1046~9 S 400.68W 5958049.51N 560278.59E 1113.22 S 422.13W 5957982.61N 560257.68E 1180.66 S 445.24W 5957914.99 N 560235.11E 1249.05 S 468.21 W 5957846.41 N 560212.70 E 1316.53 S 490,60 W 5957778.75 N 560190.86 E 1383.59 $ 512.22 W 5957711.52 N 580169.78 E 1452.41 S 532.81 W 5957642.53 N 560149.75 E 1522.42 S 553.09 W 5957572.36 N 560130.03 E 1590.03 S 572.81W 5957504.60N 560110.86 E 1660.60S 594.66W 5957433.86 N 560089.58 E 1717.05 S 612.82W 5957377.26 N 560071.87 E 1726.59 S 615.91W 5957367.69 N 560068.86E 1798.43 S 639.72W 5957295.66 N 560045.63 E Dogleg Rate (°/'tOOft) 2.04 4.24 2.13 3.58 3.43 3.30 2.21 1.45 0.21 1.40 1.28 2.47 0.44 2.43 0.14 0.59 0.27 1.90 1.07 0.43 0.25 1.57 0.74 5.43 0.73 Vertical Section 346.95 397.95 451.28 508.38 568.57 632.65 702.15 767.46 837.25 906.64 977.35 1048.18 1119.39 1189.48 1260.77 1332.92 1404.01 1474.46 1546.27 1619.11 1689.49 1763.35 1822.65 1832.68 1908.36 Phillips Alaska Kuparuk ID Comment Continued... DrillQuest 2.00.05 17 November, 2000 - 17:21 - 3 - Sperry-Sun Drilling. Services Survey Report for rD.42 MWD Your Ref: APl 500292297900 Surveyed: 5 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4471.13 49.260 200.420 3582.28 3687.28 4564.74 50.260 197.780 3642.76 3747.76 4661.27 50.480 197.250 3704.33 3809.33 4752.17 50.780 196.720 3761.99 3866.99 4845.88 51.240 194.770 3820.95 3925.95 4943.01 50.340 200.630 3882.39 3987.39 5035.40 49.470 197.710 3941.90 4046.90 5127.61 49.670 193.280 4001.71 4106.71 5223.66 50.050 194.900 4063.64 4168.64 5259.44 50.410 196.520 4086.53 4191.53 5356.51 50.740 197.390 4148.17 4253.17 5413.45 50.490 198.100 4184.30 4289.30 5513.08 49.950 198.250 4248.05 4353.05 5607.51 49.560 197.330 4309.06 4414.06 5701.71 49.210 198.310 4370.38 4475.38 5795.68 49.890 197.970 4431.35 4536.35 5888.96 49.690 196.820 4491.57 4596.57 5983.64 49.140 197.000 4553.16 4658.16 6077.33 49.740 197.230 4614.09 4719.09 6171.60 49.280 196.750 4675.30 4780.30 6262.96 49.720 197.650 4734.63 4839.63 6356.02 50.420 198.370 4794.36 4899.36 6451.50 50.010 198.330 4855.46 4960.46 6546.48 49.490 198.750 4916.83 5021.83 6639.88 49.020 198.200 4977.79 5082.79 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1866.17 S 663.50W 5957227.74N 560022.40 E 1933.68 S 686.87W 5957160.04N 559999.58 E 2004.58 S 709.24W 5957088.96N 559977.78 E 2071.79 S 729.77W 5957021.59N 559957.79 E 2141.89 S 749.53W 5956951.33 N 559938.60 E 2213.53 S 772.37 W 5956879.50 N 559916.34 E 2280.27 S 795.58 W 5956812.56 N 559893.67 E 2347.88 S 814.32 W 5956744.82 N 559875.47 E 2419.09 S 832.20 W 5956673.47 N 559856.17 E 2445.57 S 839.64 W 5956646.93 N 559850.94 E 2517.29 S ' 861.51 W 5956575.04 N 559829.65 E 2559.20 S 874.92 W 5956533.02 N 559816.58 E 2631.95 $ 898.80 W 5956460.08 N 559793.28 E 2700.58 S 920.83 W 5956391.28 N 559771.82 E 2768.65 S 942.71 W 5956323.03 N 559750.48 E 2836.61S 964.97W 5956254.89N 559728.77 E 2904.58S 986.27W 5956186.75 N 559708.02 E 2973.38 S 1007.18W 5956117.79N 559687.67E 3041.40S 1028.13W 5956049.59N 559667.27E 3109.97 $ 1049.08W 5955980.86N 559646.87 E 3176.33 S 1069.62W 5955914.34N 559626.86E 3244.19 S 1091.69W 5955846.30 N 559605.35 E 3313.83 S 1114.79W 5955776.47 N 559582.81E 3382.56 $ 1137.84W 5955707.56N 559560.32 E 3449.68 S 1160.26W '5955640.27 N 559538.44E Dogleg Rate (°ll00ft) 1.76 2.40 0.48 0.56 1.69 4.76 2.59 3.66 1.35 3.62 0.77 1 .O6 0.55 0.85 0.87 0.77 0.97 0.60 0.67 0.62 0.89 0.96 0.43 0.64 0.67 Vertical Section 1980.14 2051.57 2125.91 2196.16 2268.92 2344.11 2414.77 2484.64 2558.06 2585.53 2660.49 2704.50 2781.07 2853.14 2924.64 2996.15 3067.37 3139.26 3210.42 3282.09 3351.55 3422.91 3496.28 3568.77 3639.53 Phillips Alaska Kuparuk 1D Comment Continued... DrillQuest 2.00.05 17 November, 2000 - 17:2~1 - 4 - Sperry-Sun Drilling. Services Survey Report for 1D-42 MWD Your Ref: AP1500292297900 Surveyed: 5 November, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates GlObal Coordinates Depth Northings Easflngs Northings Eastings (ft) (ft) (ft) (ft) (ft) 6730.54 49.290 197.980 5037.08 5142.08 6824.19 49.920 198.200 5097.77 5202,77 6923.23 49.680 198.040 5161.70 5266.70 7016.97 49.390 197.570 5222.53 5327.53 7110.67 49.490 197.620 5283.46 5388.46 7204.80 49,630 196,890 5344.52 5449.52 7299.22 48.730 196.520 5406.24 5511.24 7392.60 49.220 195.600 5467.54 5572.54 7482.54 49.670 196.010 5526.01 5631.01 7575.61 49.910 195.800 5586.10 5691.10 7669.22 49.220 194.330 5646.81 5751.81 7765.33 49.540 195.190 5709.39 5814.39 7860.41 49.320 196.390 5771.22 5876.22 7954.29 49.840 197.270 5832.10 5937.10 8047.76 49.550 197.280 5892.56 5997.56 8127,55 49.400 196.860 5944.40 6049.40 8207.29 49.570 196.490 5996.21 6101.21 8303.83 49.900 195.980 6058.60 6163.60 8400.47 49.240 197.300 6121.28 6226.28 8496.68 48.670 197.210 6184.45 6289.45 8592.37 47.780 196.830 6248.20 6353.20 8660.00 47.780 196.830 6293.65 6398.65 3514.87S 1181.56W 5955574.91N 559517.67E 3582.67S 1203.70W 5955506.93 N 559496.07E 3654.56 S 1227.23W 5955434.85 N 559473.12 E 3722.46 S 1249.04W 5955366.77 N 559451.86 E 3790.32 S 1270.56W 5955298.75 N 559430.89 E 3858.73 S 1291.81W 5955230.16 N 559410.20 E 3927.17 S 1312.35W 5955161.56N 559390.21E 3994.87 S 1331.83W 5955093.71N 559371.27 E 4060.62S 1350.45W '5955027.81N 559353.19 E 4128.98 S 1369.92W 5954959.30 N 559334.27 E 4197.77 S 1388.45W 5954890.36 N 559316.30 E 4268.31S 1407.03W 5954819.66N 559298.28 E 4337.81S 1426.69W 5954750.01N 559279.19 E 4406.22 S 1447.36W 5954681.44N 559259.05 E 4474.29 S 1468.55W 5954613.20 N 559238.43 E 4532.26 $ 1486.35 W 5954555.08 N 559221.10 E 4590.34 S 1503.75 W 5954496.87 N 559204.17 E 4661.06 S 1524.34 W 5954425.98 N 559t84,15 E 4731.54 S 1545.40 W 5954355.33 N 559163.66 E 4800.84 S 1566.92 W 5954285.87 N 559142.70 E 4869.07 S 1587.81 W 5954217.47 N 559122.36 E 4917.01 S 1602.31 W 5954169.41 N 559108.25 E Dogleg Rate ('/'tOOft) 0.35 0.70 0.27 0.49 0.11 0.61 1.00 0.91 0.61 0.31 1.40 0.76 0.99 0.90 0.31 0.44 0.41 0.53 1.24 0.60 0.98 0.00 Vertical Section 3708.11 3779.44 3855.08 3926.40 3997.58 4069.20 4140.63 4211.02 4279.29 4350.30 4421.43 4494.24 4566.39 4637.84 4709.11 4769.75 4830.34 4903.96 4977.48 5050.03 5121.38 .5171.44 Phillips Alaska Kuparuk ID Comment Projected Survey Confinued.., 17 November, 2000,17:21 -5- DrillQuest 2.00.05 Sperry-Sun Drilling-Services Survey Report for 1D-42 MWD Your Ref: AP1500292297900 Surveyed: 5 November, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1D All data is in feet 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 26.398° (20-Oct-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 198.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8660.00ff., The Bottom Hole Displacement is 5171.50ft., in the Direction of 198.049° (True). Comments Measured Depth (ft) 8660.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 6398.65 4917.01 S 1602.31 W Projected Survey Continued... 17 November, 2000 - 17:21 - 6- DrillQuest ZOO.05. Sperry-Sun Drilling Services Survey Report for tD-42 MWD Your Ref: AP1500292297900 Surveyed: 5 November, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 1D Survey tool program for ID-42 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8660.00 6398.65 Survey Tool Description MWD Magnetic 17 November, 2000 - 17:21 - 7- DrillQuest 2.00.05 3/5/01 Scklumkerger NO. 1047 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1D-42 BH PRESSURE SURVEY 02/23/01 1 I s,o.=o: ~^~:t~ 1 6 2001 AlmUOil&GasG0ns.~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. ~. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report, below with the Volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during th, ~ fourth quarter of 2000: h(1)' 'h(2)' h~3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total ' 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 - CD1-44 22410 100 0 22510 0 22510- 2N-347 16434 100 0 16534 15106 31640 1D.30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: . Please find reported below the volumes injected into surface casing by production'casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. ittl~. 24 q' Annular Disposal.du. ring.th,;.fourth quarter of 2000: · -/..Oo- gcc,- ioq- 7.00 - IO ~ ~oo - 1'5 c> " h(1)' h(2)' hi3) Totalfor Previous New Well Name Volume Volume Volume Quarter 'Total Total 2N-343 13713 100 0 13813 "17995 '31808 2L-313 9017. 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 '.100 0 26547 4807 31354 CD1-44 22410 100 0 22510 '0 22510 2N-347' 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100' 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100. 0 12681 0 12681. Ms. Wendy Mahan AOG-CC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: - ' ~otal ~ ~ -: ............. Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD 1-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass 'B. Morrison and M. winfree Sharon Allsup-Drake ' , Well Files PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. T. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 November 9, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-42 Application for Sundry Approval Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached sundry for annular injection for the KRU 1D-42 Well. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Si?erely, ~ Drilling Engineering Supervisor PAl Drilling JT/skad I~ ~ 'l~l RECE, ED [',~0¥ 13 2000 Alas~;a Oil & Anchorage ORIGINAL (' STATE OF ALASKA (' ' ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request:. Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory _ Stratk~raphic _ Service _ 4. Location of well at surface 567' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671,5959099) 6. Datum elevation (DF or KB feet) RKB 35' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-42 At top of productive interval 1' FSL, 1985' FEL, Sec. 23, T11N, R10E, UM (proposed) At effective depth 181' FNL, 2042' FEL, Sec. 26, T11N, R10E, UM (proposed) 9. Permit number / approval number 200-164 10. APl number 50-029-22979-00 11. Field / Pool Kuparuk River Field I Kuparuk River Pool 12. Present well condition summary Total depth: measured 8660 true vertical 6399 Effective depth: measured 8626 true vertical 6379 Casing Length Size Conductor 80' 20" Surface 9.625" Production 8153' 7" Liner 660' 3.5" Perforation depth: measured No perfs true vertical No perfs Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured Depth True vertical Depth 350 sx ASl 115' 115' 600 sx AS III Lite, 350 sx 5312' 4228' LlteCRETE 170 sx Class G 8188' 6090' 172 sx Class G 8660' 6399' 3.5", 9.3#, L-80 @ 8054' Baker ZXP pkr @ 8008', No SSSV 13. Attachments Description summary of proposal _ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface & intermediate cement details and casing detail sheets __X 14. Estimated date for commencing operation November 22, 2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~X Service __ Gas __ Suspended 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Signed ,fle: DrillJng Engineering Supervisor J. Trantharn FOR COMMISSION USE ONLY Questions? Call Todd Mushovic 265-6974 Prepared by Sharon AIl~up-Dreke Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test _ Location clearance _ Mechanical Integr'~y Test_ Subsequent form required 10- ~ ~ Approved by order of the Commission Commissioner Approval no. Date tl/z l ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRI PLI CATE Phillips Alaska Drilling Cementing Details Well N&i~&; 1D-42 Repor~ Date: 10NA/2000 Report Number:. ~ i Rig Name: N~I~ 13E AFC No.: AK0104 Celtng Sizeg.12~, H°M Diameter:112.25' Angle thru KRU:N/A Shoe Depth:~, ~ ~ ~ I LC~:~e % wMho~: . , '~' ::..;:..~.:. ;.:... :-...:'.: ~ Gplrol~ ~r loire on Jol~ 1-13. ~ b~ ~rlng ~ 3 JM~ g JMnt 16 ~ Joi~ 1~. . ,. ' ' ~en~ : ":. '. ::. "": ..', ' ' ~ ~ 18 71 18 , , :-:,::: , ._ ,: ,,':' ': G~s ~fom: G~S a~e~ Total Volume Circulate: "::"' ::~:: :" :':"':" :::':'.':" :' ~ ~ ~ bb~ .:. . ~h 0 ,,,,,,, ' ,. ..... T~: Volume: Weight: ~men~ ?'.,',:;,'.: ,' ,,,:F: ~::: ,'. :,;, :'-',', AR~ W~h ~ 8.S .... ::,?:.'.~. · ,~¥..,.. ...... 0 :,, ',h :~?:h;:,: [~.'::::::: ~, '~:~':::' T~e: Volume: We~ht: ~ ~:...."..:.:.i'~:: :?. ~..~?'~ ~, ~m~,: . ::?.. :.~.,'..~? ...:::~ uuopus~ ~ '-- '~F'":' ' %:~'?" ~'~':: :; :' T~: I MixW~: No. of ~o~:I W.,~ :~..:::;..' '"': ~' :~':'~ .:. ': h ':'..?.' ' ~': '" ::' ':' ...:i:~;':",. :~ ":E.~ ~ G WI ~ DI~, ~ ~, 0A% ~6, ~ D~ 1.~ 61,1,~ ~9 ~l ~ 0~:" '~:: ""~:",:~ ~?, :::/,':. :~.: ' ~e: ! Mix~.mp: INo. of~: I :. =" .: .': .~'.' .'".'7. "'/.'." 70 I Wei~: Y~ld: ~m~ . . , .... :. ' ':~:~':"/~:[ :~'~;:: ~' ~'~ ~s: .... . ... :.~;..~ .... .,~. i.. ...':..: .' I :: ' .:1,1[.~.., ".:,.~ '=;r'.'. ...... :.: '~ ~ :~ ~ ~ ~ ~I~ DiM, ~ Dt~ 0.B~ ~, 0,1~ ~&, 0~ D~ '":~:'.. : '. ': ~. '+. D~~' ~ ::....: ~...~E L=::;, ~. :~ ;::r:~::.;. ~m tail at shoe): ~t~il amun~ shoe): ~r. ~. Up: . . ~,~?:.~.~::. :,~:~::::~:~:?.;E? ..... ::::=' :~...:.~.,:i:..?:.~....:...:,?...:~::...::.' R~pm~t~n ~n~h: ~ip~ti~ speed: ~r. ~. Do~: .:~::.j;... :.'....~.;.~:~ = ~.,......:?: ~' ~O FPM l~k U: ':F~:,:,:'::~: ..,.~.',; r, ~1Diapla~t: ~ual Di~la~en~ S~. ~. In mud: ~,'~;:'.::, ~.':'.. ,: ,,.:, ~ ;::~ .,,, ,,, ~ ~l~i~ t~ ~ ~ent: Op: Bum~ plug: F~ta hel~: ~me:~:4a ii i R~arks:~ full ~ ~ olmael~ a a~. R~p~ ~enl un~ ~ b~om ~u~. aa M BB~ =~ ~ ~ eu~m. I~ ..... : ~ ..... ~.. ' "~ ~ ......... , . Dowell party: IContractor. IAppmved By: 1 NABORS I Fred Herbert J RECEIVED i 3 2000 ~a~ka Oil & '~,~ ' Anchorage Casing Detail 9-5/8" surface casina WELL: ID-42 Phillips Alaska Inc Date; ! 0/28/00 1 OF I PAGES # ITEMS 'COMPLETE DEscRIPTION OF EQUIPMENT RUN LENGTH DEPTH '" Na~ors 16E RKB = ~4.40' ToPS ~-1, , 11 il _ , ~ , 9-$/8" Landir~g 'Joint (RKB)' ' ' 34.40 9-5/8" FMC ~N V FLeD MAND~L HANGER' 2.0~ ' ' ~.~ I~ ~i~ 9-5/r, ~e. L-80 BTC-MOD (1~) .... 5192.26 36.42 ~~co FIo~ Coll~ 1.~ 5228.68 ~~co FI~ Shoe 1.73 ........... B~ OF SHOE ~ ~ ~ i~-11~~ hol, $~0' ~B ~' ~ , ' ~n 9.5/r x 12- ~fom spir~li~r'central~e~ on' joints i i ....... ,, ....... ~ , .,. . ~n ~-$/r x I ~- ! I~'~ ~~fln~ ~~11~*~ on ,~ ~d ioint . . . , , . ~ .... . , , _ ' ~ . ~ , -.,., ,t, .,, , ........ gn~Om¢e . ~ , ,., , , ~ , ~ ~ , , Re~rks: ~ng Weigh~ w~h Blocks, 'l~k' on, ug245~ 70k Bi6CkS. Ran 130jomts"of ca~Jng. ' Dried cas/rig wlfh &67~" plo~flc r~bDi~. U~ed Jet LuDe ~read compound on ~ll connecfion~. CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-42 Date: 10130/00 Supervisor: Fred Herbert Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5'8" 36#, J-55 Casing Setting Depth: 5,312' TMD 4,225' TVD Mud Weight: 8.4 ppg Hole Depth: 5,340' TMD Length of Open Hole Section: 4,243' TVD 28' EMW = Leak-off Press· + Mud Weight 0.052 x TVD -- 1,400 psi + 8.4 ppg 0.052 x 4,243' EMW for open hole section = 14.7 ppg Pump output = 0.0846 bps Fluid Pumped = 5.5 bbl 3,000 psi 2,g00 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,3O0 p,~ 2,200 psi 2,100 psi 2,0(30 psi 1,700 psi 1,~0 psi 1.4(30 psi 1,300 psi 1,200 psi 1,100 pd 1,000 psi 700 psi Opsl~ ;"'~ ",,:,,,,,,~, .................................. ~ LEAK-OFF TEST ~CASING TEST LOT SHUT IN TIME CASING TEST SHUT IN TIME TIME LINE STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE 4 stks 125 ~si ................ i....s..s..t..k~ ....... .2..2..s..~i .... .................... .S..~..k.=. ....... .a.~.s...p~j .... .................... .!_o.~.t~.=. ...... .4.~.s.~.?j .... .................... .1..~.~.t.k.~ ...... .S.~.S.~.~! .... .................... .T .4. ~.t~.=. ...... ~.S.~.~ .... ................... .1..S.~.tk..=. ....... .7.~.S..~j .... ................... !.S.~.t.k.~ ....... .S.~.S..p..~! .... ................... ~.0.~.t.k.~ ...... ~.S.~! .... ................... .2..2.~.t.k..s. ..... .1.,.o.o..o..p..sl_ .................... .2..4.~.tk..s. ...... .1.,.~..o..o..p..s.i... .................... _2..6_s..tk..s. ...... !,~Z_S..E.s)..j ................ i...~..S.~.t.k.~ ...... .T,..~Z.s..P..~.L. ................ i._~..O..s..t.k.~ ...... !,..3Z.s..;..?l _ ................ i...3..1..s..t.k..s...,...1.,..4.0..O._P...s.i... ................ i...3..4..s..t.k..s...i....S..0..e. £.s. j .... ................. , .. _~..s..s..t.k..s. _ i... &O..O. -...?!._. ," 38.tks j 800 psi j ................ I ............................ ~'"' , 40 stks 800 ps, ~ 50stks 800.Esi ~ 60 stks 800 psi ~ 65 stks 800 psi I ' SHUT IN TIME ~ SHUT IN PRESSURE ........... ~ ..... . ................ T ............. T'"I 0.0m~n I ! 800Es~ .,' ........... · ; .... , ............... , ............ 1.0m~n ~ ~ 750pm ::::::::::::::::::::::::::::::::::::::::::::::: 3.0min ; i 725 psi -4-:9---m-Ln- i ! Z-2--s-£-?! ....5.:.o...m.!.n...., ................ L . .7.. .2. .5. ~... .i .... .... .s.;.o...m..Ln... ,' ............... .,...Z.2..5.~.s.., .... 7.0min i i 725~si · ! ! · .___8_:_o___m_,_n.._; ............... i____7__2__s__~_=__, .... ,...~:.o...m.!.n._i ............... L.7..2..s_j~L., ,..!o...9...m. Ln..i ............... L ..7...2_5. p...s.! .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... .O..?.t..k~...j ..... .o..p.?l ..... 4stks ! 100 psi ............. ...~. ............... J .......... ~,. ...... .a 8stks i 250~si ................. r ............... ! .......... ~ ...... ! , 12stks , 50Or'si , ................. F ............... ~ .......... r ...... -I I I · I ................. L..1..6...s.t..k.s....j... Z.2..5..P...s.L ..i 20stks ~ 900ps, ...... - .......................... .I .......... .................... .2..4...s!..k.s...j..& !.O.O..p..s.~,,a,,, I 28 stks ~ 1,275 ps ................ ~. ............... J ........... · .... 32 stks 1,475 ;si 36 stks 1,675 .~si~., ................... .4..O..?.t.k~ ..... )..,.~..2.s..p..s.[.i . 44 stks 2,075 ps, ................ - ............... - ........... 48 stks ...2..,.3..02.p..s.Lj · 52 stks 2,500 pm , ................ & ............... J ........... .t ..... -, 53 stks 2,525 ~si ! 1 , , , ................. . ............... .~ ................. ,.~ ! ! , ! , ................................. I ................. 1 ! - I ~ SHUT IN TIME , SHUT IN PRESSURE ............... l .... i'.iF;~'i'fi'"; ............... ;"~;~'~'~'~;~'; ........... ".' .... r ............... 1 .............. ;.,a,,,~ ,....2:.o...m.;.n....: ............... ,,,...2.;.s..2.s..p..s. ....3.:.o...m.'.,.n....[ ............... L.&,.s..~.s..p.~L. L....4:9...mj.n....L ............... j...2.., .s..2.s..p..s.[ .j 5.0 min ~ i 2,525 ~si 6,.,0 min ,,., 2,525 ,~si 7.0 mln ~ i 2,525 ps, ................ r ............... '1 .................. . ! , · 8.0 m~n ~ i 2,525 ps~ ................ i.--- ...... - ......! .................. · i · 9.0 m~n ; i 2,525 ................. . .............. .4 ........... 4 ...... ,...1..o:.o...m..i.n...[ ............... j...2.:.s..o.o., p..s.Lj 15.0min i | 2,500p. si "'5'b~';~i;.7't ............... 1"~;~'6'~'~;i' ~ ...... : ...... .'"-t ............... I .............. ,..2..5....o...m.!,...,, ............... ~...2.,s..o..o..p...,.:. ,,, _.3..o:.o...m. in...[ ............... l.. ~ ,.~..o.o.. P..~j. j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY --k'-' Phillips Alaska Drilling '7" Cementing Details Well Name: 1D-42 Report Date.' 11/03/2000 Relx)rt Number:. 2 Ri~ Name: I~l~m 16E AFC No,: AK0104 Reid: E~.~. K mruk River Unit I~ntrlllBml Sate type used, inten~la covered and sl~cing . $Pimglldem on Jt~ 2,4-20, Bow. g~'ing~ on it~ 1 and ~. Centering 9uld# on Jt~ 196,191,116,181', 178,173,170,1~7,1M, 1S1, Ik{I .. ." . Weight: PV(prlor cond): PV(after oond): YP(Prlor cond): YP(effer cond): Gels before: Gels after: Total Volume Circulated: PPg. W~lh 0 i.,~!:'l Type: Volume: Weight: ~ 0 :':".:' Typ~:' '- Volume: Weight: Commen~,: '.':i:,i:!,. MUDPUSHXL 30 .... .~, ...!p,, , . '";!~:: ....... Reclpmoation length: Re~iprooatlon spe~d: mr. Wt, , , :'.': '. :~:i Theoretical Displacement: Actuel Displacement: Cail~ul~od top of cement: 'CP: ' Bumped plug: FI°ats held:. ..... ~ Date:11/3/O0 No Yoo Tlme:06:69 : R emerita:Had good tatum; throughout Job. RedprooMa~l pipe thmughoot Job. Cement Company: I Rig Contractor: IAppmved By: Dowell I NABORS H3.R. Whitlock Casing Detail 7" Intermediate casing WELL: 1D-42 Phillips Alaska Inc. DATE: 1 I/1/00 I OF ! PAGES # ITEMs COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH , , Nabors 16E RT t° LDS = 34.10' TOPS , , , , , 7" Landing Joint ,(RKB) 34.10 7" FMC GEN V FLUTED MANDR~L HANGER 1.85 '34,10 jts 3-202 7", 26#, J-55 BTC-MOD (200 jts) 8067.26 35.95 Gemeco Float Collar ' 1.36 8103.2i' jt$' 1-27", 26~, J-55 BTC-MOD"(2 jts)' ' 81.93 8104.57 " :Gem~coFIoatShoe "' 1,46 8186'50 ~ , BTI'M OF SHOE @ 8187.96 " Shoe @ 8187.96 ' ' ' 'TD of 8-1/2" hole'= 8200' MD 6100' TvD ' . 'Run i spiragJider per'iOint on Ioihts'i-20 W'/stop coilar~.' ' , _ ' (Note; joints I & 3 will have' b°w sp...r!ngs due t.o fioc~ equiPr~lent) ...... " ! Run I centering guide On joints ~96, 191,186, 181,176,"i73, 170, 167, 164, 161,158, 155, 152, 149, ( 14 Centering gUides) PU Jt :~02 and put hanger ~n top .......... I I I Ill I 11 II I I I I .... Do not ~Un its. 203-~07. Shoui~l be 5 jts left in Shed.' ........ -- il 11 , ~,, , , __ i i Alaska Oil & Gas Cons. Commission ..... ~.~h~'e ' ' ~ , , __ Remarks: String Weights With Blocks: 240k Up, 'i60k On, 70k Blocks, Ran 202 joints of casing, ' - Driffred casing w#h 6. 151 "plastic rabbit.. CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-42 Date: 11/'//00 Supervisor: G.R. Whitlock Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5'8" 36#, J-55 Casing Setting Depth: 5,312' TMD 4,225' TVD Hole Depth: 8,188' TMD 6,088' TVD Mud Weight: 7.0 ppg Length of Open Hole Section: 2,876' EMW = Leak-off Press. + Mud Weight_ 0.052 x TVD -- 650 psi + 7.0 ppg 0.052 x 6,088' EMW for open hole section = 9.1 ppg Pump output = 0.0197 bps Fluid Pumped = 5.1 bbl I2,g00psl. 2,800 psi z~ m~. ~ LEAK-OFF TEST 2~p~. ~CASlN~ TEST z~l ~LOT SH~T IN TIME z~ ~ CASlN~ TEST SHUT IN TIME 1,~mi I TIME LINE 1,7m~ 1,~ mi 1,~ O~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................... .S..2..s..t.k.~ ...... !0..0. ~.sj .... ................... .S..S..s..t.k.~ ..... !s..o.~i .... ................... .S..O..s..t.k.~ ...... !s..o.~i .... ................... .S..4..s..t.k._s. ...... .2.p..o..e~] .... .................... _S..S..s..t_k.~ ..... .2_.S..O.j~i .... ................... .7..2Ls.!.k.~ ...... Ao.R.R?i .... ................... ?..S.~.t.k.~ ..... ~.S..O.~] .... ................... p_O..s..t.k. ~ ...... &S_.O...e~! .... ................... P_~. ~.tk. ~ ..,... ~.O..O..Rs. i .... ................... .~..~..s..t.k..s. ...... ~.s..o...e~i .... .................... .~..2.~.t~ ...... .s..o..o.~.?i .... .................... .9..S..s.!.k. ~ ...... .s..s..o..Rs.i .... ................... &~..O.~.tk. ?. ..... .s_.o_.o..e.s.i .... .................. .! .O..4.~!.k.?. ..... .s.p..o.~i .... .................. .T.o..~..s..t.k.?. ..... .s..2..s_~?.i .... .................. .T.T.2..s.!.k.?. ..... .s..s_o_e.$j .... ................... .! .4. .0. ~ !.k. ?. ...... .s..s.p_Rs.i .... ._ ................. &s.?..~.k.?. ..... ?.~.s..e~] .... i 160 stks 625 jE. si ................ i _2..O..O_s!k.?. ..... .s..2..s..e?.i .... i 230 stks 625 psi ] 260 stks 625 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... .o..?.~.~.?._j ..... P..P.?! ..... ..................... ~.?!..k?... j...!o..o..e..?.i_.. 8stks i 250DSi , 12stks I 500nsi ................. ,,. _ .! .s...s.t..kLL...T.2..s' p...?.i.... .................... .2..o..?.t..k.s.. j _ ...9.o..o..p..?.i.... .................... .2..4..?.t..k?. ..... .T.,.T.O.O..p.?..~"~. .................... .2.~..s.t..k?. ..... ~.,.2..7.s..p.?:... .................... &2..?.t..k~ ..... .~_,.4..7.s..p.~[.. .................... &s...~.t..k~ ..... .!.,.s_7.s..p..s.L .................... .4..o...s. Lk.s. ..... .~.., .s.?.s.. p..s.[.. .................... ~.?!..k~.j...2.,p..7.s..P..s.L. .................... .4.P...s!..k?...j...2., .~.?.?.P_.s.L. .................... .s..2..?.t..k.s...j...2.:.S..O.?. p..s.i, j · j .................... .S..3..?.t.k_s. ..... .2.,.S.?.S..p.~,..., I I I l SHUT IN TIME SHUT IN PRESSURE .................. "T~6'~i'~"'~ ............... "'~;~'~'g;i' ~ ...... '- ....-.. .... L ............... . ........... .....2:.o...m..,.n. ...................... .2.;.5..2.5..R?.. 1.0rain i i 450~si J ................ '1- ............... f ............... ...~ :.o...mj.n... ,.L ............... i...~-°-9...R.~i...i __3.:.o...mj.n_. ,,'_ ............... ]...~.o_.o..e.s.i...] ....4.:.o...m_i .n_.j. ............... L&S.p_£~i...] ._.5.:.O...mj.n_ ,'.L ............... L.&S..°..e.?i..j . i . i 6.0mln i i 350 psi i ................ ..I. ............... ,& ................. .,i ................... .2.,..s..2..s.R.s.i.. · , · 4,0 m~n i 2,525 i. ................ i. ............... J ........... · ..... J 5.0 min ~ 2,525 osi ........... '" .... r ............... ! ............... :" 60m~n , , 2,525~s~ ..... L'.' .......... L ............... J ........... ~r. ..... _Z..O...m..i.n. ................... j...2.,.s.?.s..R~L. .....8:.o..mj.n. ................... j...2.,.s..2.s..R.s.i.. ..._9.:.o...m.j.n. .................... L.2.., .s.?.s..p..s.L. j..o:.o...mj.n. .................. j..~:.s.?.o..p.~Lj i 7.0 mini i 350 psi ! i 15 0 mini i 2,500 Esi ' ................ ~- ............... ~ .......... ~ ...... ~ ,~ .....;: .......... I' ............... '1 ................. I · I I · , , 80mln , , 350D$1 , ' 20.0mln' , ,~;nnn ' , . .~. : : ~, -,---r_Sl ,- ............... ~- ............... ~ ............... '1 r ................ r ................................. ' ' ' ' ' ' j 25.0m~n; j 2,500psi i-9-:-°---m-!-n- ,', ,,' -3--s--°--RsJ-i ' ' ' ~ ' L./.o.-.o...mj.~..i ............... i....a.~.°.£~i...i L ...a.o....o. _m..Ln...[ ............... !..~:.~..°.°..R~... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ALASILA OIL AND GAS CONSERVATION CO~llSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit ID-42 Phillips Alaska, Inc. Permit No: 200-164 SurLoc: 567'FNL, 421'FEL, Sec. 23, TllN, RIOE, UM Btmhole Loc. 181'FNL, 2042'FEL, Sec. 26, TllN, RIOE, UM Dear Mr. Trantham: 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 has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. ID-42. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production easing annulus of a well approved for annular disposal on Drill Site 1D 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Commissioner .BY ORDER OF THE C~91~IMISSION DATED this _~ ~ 7~ day of October, 2000 dlf/Enclosures cc: Department of Fish & Gmne, Habitat Section w/o end. Department of Environmental Conservation w/o encl. '" STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill r~ Redritl D I lb. Type of well. Exploratory D Stratigraphic Test [~ Development Oil r~] ..-..try I'-! O.epe. I--II Service I--I Deve,opmentGas I--I S~.g,eZo.e !~1 Mu,tip,eZone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 & 25661 ALK 471 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 567' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1' FSL, 1985' FEL, Sec. 23, T11 N, R10E, UM 1 D-42 #U-630610 At total depth 9. Approximate spud date Amount 181' FNL, 2042' FEL, Sec. 26, T11N, R10E, UM October 20, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1' @ Target feetI 1D-40 30' @ 120' feet 2560 8643' MD / 6382' 'I'VD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 49.7° Maximum surface 3356 psig At total depth (TVD) 4040 psig 18. casing program Settin~l Depth size Specifications Top Bottom Quant~ of Cement Hole Caslnc, I Wel~lht Grade coupIIn~l Len~h MD TVD MD TVD (include sta~le data) 30" ... 20" 91.5# H-40 Weld 115' 35' 35' 150' 150' 230 sx ASI 12.25' 9.625" 36# J-55 BTCM 5256' 35' 35' 5291' 4216' 600 sx ASLita & 350 sx LiteCRETE 8.5' 7' 26~ J-55 BTCM 8114' 35' 35' 8149' 6063' 170 sx GasBLOK 6.125" 3.5" 9.3# L-80 SHLT 644' 7999' 5966' 8643' 6382' 150 sx GasBLOK 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production Liner Perforationdeplh: measured 0 R I G INA k DC, 07 Alaska 011 & Gas Cons. true vertica~ Anchorage . 20. Attachments .,ngfee[] PropeW P~at i--I BOP Sketch I~! D~verterSketch I'0l Dri,ing program Dri,~ng,uid progr, m li[IT~mevsdepth p~ot r"l.efract~on ana~,s~s r"! sea~ed report I-I 20~AC 25.0S0 requirements r-I 21. I hereby certily that the foregoing is true and correct to the best of my knowledge Questions? Call Todd Mushovic 265-697,; Signed J. 7'ramha,n ¥'~ ill'- ~'¢,,,~.'~'~1~1~ Title: D~i,,i.o E. gi. ee,i.g Supen,i.o, Date G PreDer~d bv sharon AIIsu~.Drel(~ Commission Use Onl} Permit APl number ISee cover letter Numbe",~~"-"/~ I 50-~:~-,~--.~?'7~:~"~---.)O I Appr°valT~'~l~0'"i~(-) Ifor other requirements Conditions of approval Samples required E] Yes ~L~N° Mud log required D Yes ~' No Hydrogen sulfide measures [] Yes [~ ,No_~.~IF~/ -- Directional survey required 1~ Yes D No RequiredworklngpmssureforBOPE D2M;~ I~ O 1OM;El D Other:. ORIGINAL SIG~,, D Taylor S~.~..~.. ~,o~.ro, Approved by Commissioner the commission Date ,, Form 10-401 Rev. 12/1/85 ° Submit in triplicate . DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-42 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Surface Casing 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[I 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Three possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1 D-42 well path. 1) MASP can be calculated using an expected leak-off of 13.8 ppg EMW (0.72 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2572 psi. The leak off EMW was chosen based on an open hole LOT on well, 1D-40, taken to 13.8 ppg at 4256' TVD (0.72 psi/ft). MASP: (4216 ft)(0.72 - 0.11) = 2572 psi 2) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6220' TVD (0.57 psi/fi) and a gas gradient of 0.11 psi/ff. In this case, MASP would occur at 2861 psi. MASP = (6220 ft)(0.57 - 0.11) = 2861 psi 3) Some prior EBA and GSA wells in this area have experienced gas charged sands in the D-shale as a result of historic Gas Storage Area injection. These sands are located above the Kuparuk reservoir and are expected to occur at +/- 6215' TVD along the proposed well path in the 1D-42 target area. There is a strong possibility that gas charging will be encountered in this well and if this occurs, MASP would be based on a 12.5 ppg equivalent pressure (0.65 psi/ft). Based on this pressure gradient and a gas gradient of 0.11 psi/fi, MASP would occur at 3356 psi. MASP = (6215 ft)(0.65 - 0.11) = 3356 psi Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well must be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to be the pressure exerted by the gas charged D-shale sands at the surface and would remain at 3356 psi as calculated previously. Therefore, based on the possibility of a MASP greater than 3000 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based on the potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 13.0 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6215'. MW = [(6215 ft)(0.65)+150]/6215/.052 = 13.0 ppg In order to allow for a long string design, the minimum LOT in the Mid-HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 13.0 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1 D-42 is 1D-40. As designed, the minimum distance between the two wells would be 30.0' at 120' M D. Drillin(3 Area Risks: Risks in the 1D-42 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-42 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1D-42 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade ,Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 .3 BTC 2,020 psi NA 3,520 psi 2,992 psi 7" 26 J-55 =3 BTC 4,320 psi 3,672 psi 4,980 psi 4,233 psi 3Y2"* 9.3 L-80 12 8rd EUE Mod 10,530 psi 8,961 psi 10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 2O AAC 25.080 (h). KRU 1D-42 Produ4' r PHILLIPS Alaska, Inc. Proposed Completion Schematic A Subsidiary of PHILLIPS PETROLEUM COMPANY Topset Base Case 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 5291' MD / 4216' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2' L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and RK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM. Spaced out w/ 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing to be Determined Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8149' MD / 6063' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 8643' MD / 6382' TVD) 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below I jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 7999' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe 1D-42 Kuparuk Well Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 250 % above. Drilled with 12 1/4" bit. 9 5/8", 47 #casing TMD 5291', Single Stage Design. Tail Slurry TOC is @ 3504' MD ( 800' above the West Sak top). No Port Collar Contingency Base of the Permafrost at 1627' MD Volume Calcs: Pump 20 bbls Arco Preflush, 50 bbls MudPUSH XL @ 10.5ppg . Cement from MD to 3504' with LiteCRETE @ 12.0 ppg and from 3504' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%$1, 1.5%D79 -4.44 ft3/sk (3504'-1627') x 0.3132 ft3/ft x 1.45 (45% excess) = (1627') x 0.3132 ft3/ft x 3.50 (250% excess) = 852.4 ft3+ 1783.5 ft3 = 2635.9 ft3/4.44 ft3/sk = 852.4 ft3 1783.5 ft3 2635.9 ft3 593.7 sks - Round up to 600 sks Have 260 sks of additional Lead on location for Top Out]2nd stage, if necessary Tail Slurry Requirements: LiteCRETE @ 12.0 ppg - 2.46 ft3/sk (5291'-3504') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4110 ft3/ft = 811.5 ft3 + 32.9 ft3 = 844.4 ft3/2.46 ft3/sk = 811.5 ft3 32.9 ft3 844.4 ft3 343.3 sks - Round up to 350 sks BHST = 80 deg F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.5ppg MudPUSH XL, 600 sks (474 bbl) ASLite Lead, 350 sks (153 bbl) LiteCRETE Tail. Displacement is approximately 381 bbls. Circulation: Circulation and cementing at or less than 6 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 700 psi. At 6 bpm, expect 28 minutes of u-tubing after dropping the top plug. .Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 20 or under, Ty = 20 or under. 1D-42 Well Intermediate Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 1/2" bit. 7", 29 #casing TMD 8149'. TOC@ 7349' (800' Shoe Tack). Volume Calcs: Pump 20 bbls Arco Preflush, 30 bbls MudPUSH XL @ 12.0ppg w/0.1#/bbl C359. Cement from 8149' MD to 10517' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%D800- 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7", 29# x 8 1/2" OH: (11317'-10517') x 0.1268 ft3/ft x 1.75 (75% excess) = 177.5 ft3 Shoe Joints: (80') x 0.2086 ft3/ft = 16.7 ft3 Total Volume = 194.2 ft3. 194.2 ft3 / 1.17 ft3/sk = 166 sks - Round up to 170 sks BHST = 150F (estimated) CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 30 bbls 12.0 ppg MudPUSH XL, 170 sks (35 bbls) Class G + adds. Displacement is approximately 417 bbls. Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1400 psi. At 7 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 20 or under, Ty = 20 or under. Kevin Tanner can be reached at the following numbers regarding this job or any other assistance: 265- 6205(w), 336-0067(h), 230-6628(ce11). 1D-42 Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 3 1/2", 9.3 #casing TMD 8643'. TOC@ 7799' (200' over top of liner top). Liner Top @ 7999' Previous casing 7", 299, 8149' TMD. 4", 14# DP, 300' liner lap. Volume Calcs: Pump 20 bbls Arco Preflush, 20 bbls MudPUSH XL @ 13.0ppg. Cement from 8643' MD to 7799' with Class G + adds @ 15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 ft3/sx 3 1/2", 9.3# x 6 1/8" OH: (8643'-8149') x 0.1378 ft3/ft x 1.60 (60% excess) = 108.9 ft3 3 1/2", 9.3# x 7", 29#: (300') x 0.1418 ft3/ft = 21.3 ft3 7", 29#: (200') x 0.2086 ft3/ft = 41.7 ft3 Shoe Joints: (80') x 0.0488 ft3/ft = 3.9 ft3 Total Volume = 175.8 ft3. 175.8 ft3 / 1.2 ft3/sk = 147 sks - Round up to 150 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 20 bbls 13.0 ppg MudPUSH XL, 150 sks (32 bbls) Class G + adds. Displacement is approximately 92 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1700 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 13.0 ppg (preferably lower), Pv = 20 or under, Ty = 20 or under. Cr.ot,,d b~ ,~. FOR: VllgOY]MC~H J Dote plotted: 25-Sep-2000 Plot Reference i~ 42 Vets;on ti1. I Coordinates are ;n lest r.formce .lot ~r42. I frue Vertk:al Degttm ara refermm~ RKB(Nabore 16E). ............. ~ell-: 4 Field : Kuparuk River Unif Location : North Slope, Alaska] Point Begin Angle Nudge Begin Drop EOC Begin Build/Turn Begin Build Begin Build/Turn Base of Permafrost EOC Top West Sok Base West Sok 9-5/8 Casing Pt C80(K-10) C50 C40(K-5) Top HRZ C50(K-2) C20 (HRZ Midpoint) 7 Casing Pt/Bose HR K-1 Top Kuporuk D Target-Top C4 Top C5 Top C2 Top C 1 Top B Shale TD-Cesing Pt MD 250.00 450.00 650.00 950.00 11 00.00 1500.00 1627.08 2857.81 4,304.16 4981.8,3 5291.27 5557.28 6959.04 7,350.59 7808.56 78,36.41 8055.02 8148.95 8269.65 8584.12 8591.86 8452.O8 8458.59 8517.18 8526.46 8642.50 PROFILE COMMENT DATA Inc Dir TVD North East V. Sect Deg/ ~0 0.00 255.00 250.00 0.00 0.00 0.00 0.00 5.00 255.00 44g.g 1 -,5.00 -4.2g 4.20 1.50 0.00 255.00 649.82 -6.01 -8.58 8.40 1.50 0.00 255.00 94g.82 -6.01 -8.58 8.40 0.00 2.25 225.00 1099.78 -8.09 - 10.66 11.05 1.50 8.25 225.00 1298.85 -21.02 -25.59 27.57 5.00 18.01 220.45 1617.00 -76.25 -75.10 95.57 ,,5.00 49.75 197.50 2645.18 -685.82 -289.99 740.51 5.00 49.75 197.50 ,3578.00 - 1756.57 -621.95 184,3.86 0.00 49.75 197.50 4016.00 -2229.54 -777.45 2560.91 0.00 49.75 197.50 4216.00 -2454.72 -848.47 2597.00 0.00 49.75 197.50 4575.00 -2655.75 -904.92 2784.70 0.00 49.'75 197.50 5281.00 -5653.85 -1226.65 5854.21 ('~O, 0 49.75 197.50 5547.00 -5955.35 -1521.08 4168.22 ~ .~0 49.75 197.50 5845.00 -4286.65 - 1426.18 4517.65 0.00 49.75 197.50 5861.00 -4506.89 -1452.57 4558.89 0.00 49.7,3 197.50 6001.00 -4464.55 - 1 482.28 4704.16 0.00 49.75 197.50 6065.00 -4554.55 -1504.50 4777.55 0.00 49.75 197.50 6141.00 -4622.16 -1551.99 4869.45 0.00 49.75 197.50 6215.00 -4705.48 -1558.27 4956.78 0.00 49.75 197.50 6220.00 -4711.11 -1560.04 4962.69 0.00 49.75 197.50 6246.00 -4740.58 -1569.28 4995.58 0.00 49.75 197.50 6265.00 -4759.52 -1575.,31 5015.45 0.00 49.75 197.50 6501.00 -4802.51 -1588.80 5058.51 0.00 49.75 197.50 6507.00 -4809.06 -1590.93 5065.59 0.00 49.75 197.50 6582.00 -4895.51 -1617.57 5155.92 0.00 Phillips Alaska, Inc. Struature: Pad 10 field: Kuparuk River Unit Well: 42 Location: North Slope, Alaska 4OO 800 1200 1600 2000 2400 2800 3200 ~8oo 4000 44O0 4800 5200 5600 6000 6400 RKB ELEVATION: 106' 0.0o Begin Angle Nudge 1.50 Begin Drop 1.50 £0C 198.32 AZIMUTH (TO ***Plane of Proposal*** 0.75 Begin Build/Turn Begin Build 6.00 Begin Build/Turn 11.25 DLS: 5.00 dog per 100 ft 14.21 17.20 Base of Permafrost 21.51 End of Bufld/l'um - 20.20 Inc, 1700.00 Md, 1685.90 Tvd, 117.51 Vs 2.3.15 DLS: 5.00 dog per 100 ft 24.99 Kick off Paint - 27.05 Inc, 2100.00 bid, 2055.06 Tvd, 275.05 Vs 50.04 33.03 59.02 DLS: 3.00 dog per 100 ft 45.01 EOC Top West Sak Base West Sak 9-5/8 Casing Pt CBO(K-IO) TANGENT ANGLE 49.73 DEG ! i i i i i i i i i i i i i i i i 400 800 1200 1600 2000 2400 2800 3200 3600 C50 C40(K-5) C20 (HRZ Midpoint) TOD HRZ C30(K-2) K-1 7 Coslng Pt/Bose HRZ Top KuDoruk 0 Target-Top C4 Top C5 Top C2 Top C1 Top B Shale TD-Cosing Pt i i i i i i i i i 4O00 4400 4800 5200 Azimuth 198.32 with reference 0.00 N, 0.00 E from slot #42 Vertical Section (feet) -> 198.32 AZIMUTH 4963' (TO TARGET) ***Plane o~ Proposal*** Phillips Alaska, Inc. Structure: Pad 1D Well: 42 field: Kuparuk River Unit Loaaflon: North Slope, Alaska <- West (feet) 1 BO0 1500 1200 900 600 ~00 0 I I I I I I I I I I I I I I Begin Angle Nudge Begin Drop EOC Begin Build/Turn Begin Build Begin Build/Turn Base of Permafrost EOC West Sak Base West Sak 9-5/8 Casing Pt :BO(K-lO) C4~(K-5) Top HRZ C.~0(~-2) C20 (HRZ Midpoint) 7 Casing Pt/Base HRZ T~(p__ 1Kuparuk D TToa rget -Top C4 p C3 Top B Shale TD-Casing Pt ,.~00 500 0 500 600 90O 1200 1500 1800 2100 24O0 2700 5000 5300 5600 5900 4200 4,5OO 48OO 5100 ISURFACE LOCATION: I 567' FNI., 421' FEL SEC. 25, T11N, RIOE 0 I LOCATION: I T,ARGET FSL, 1985' FEL SEC. 25, T11N, RIOE TD LOCATION: '181' FNL, 2042' FEL SEC. '26, T11N, RIOE c~t~d ~ ~ FOR: Mll/iIOVEAC~H] Dote p~tt~: 25-~-~ P~t R~ ~ 42 V~n ~1. I ~dl~t~ a~ In f~ refermn~ d~ ~42. I r~ v~t~l ~t~ are Structure: Pad 1D Well: 4 Field : Kuparuk River Unit Location : North Slope, AlaskaI ...... Point Begin Angle Nudge Begin Drop EOC Begin Build/Turn Begin Build Begin Build/Turn Bose of Perm(]frost EOC Top West Sek Bose West Sek 9-5/8 Casing Pt CSO(K-~ O) C50 C40(K-5) Top HRZ C50(K-2) C20 (HRZ Midpoint) 7 Cosing Pt/Bose HR K-1 Top Kuporuk D Torget-Top C4 Top C5 Top C2 Top C1 Top B T.D-Casing Pt MD 250.00 450.00 650.00 950.00 1100.00 1300.00 1627.08 2857.81 4504.16 4981.83 5291.27 5557.28 6939.04 7350.59 7808.56 7856.41 8053.02 8148.95 8269.65 8584.12 8591.86 8452.08 8458.59 8517.18 8526.46 8642.50 PROFILE COMMENT DATA Inc Dir TVD North E(]st V. Sect Deg/lO0 0.00 235.00 · 250.00 0.00 0.00 0.00 0.00 3.00 235.00 449.91 -3.00 -4.29 4.20 1.50 0.00 235.00 649.82 -6.01 -8.58 8.40 1.50 0.00 235.00 949.82 -6.01 -8.58 8.40 0.00 2.25 225.00 1099.78 -8.09 - 10.66 11.03 1.50 8.25 225.00 1298.85 -21.02 -23.59 27.57 3.00 18.01 220.45 1617.00 -76.25 -75.10 95.57 5.00 49.7.3 197.50 2645.18 -685.82 -289.99 740.51 3.00 49.75 197.50 .3578.00 ' - 1736.37 -621.93 1843.86 0.00 49.75 197.50 4016.00 -2229.54 -777.45 2560.91 0.00 49.73 197.50 4216.00 -2454.72 -848.47 2597.00 0.00 49.73 197.50 4575.00 -2653.75 -904.92 2784.70 0.00 49.75 197.50 5281.00 -3653.85 -1226.65 3854.21 0.00 49.73 197.50 5547.00 -5955.35 -1321.08 4168.22 0.00 49.73 197.50 5843.00 -4286.63 - 1426.18 4517.65 0.00 49.75 197.50 5861.00 -4506.89 -1452.57 4558.89 0.00 49.73 197.50 6001.00 -4464.53 - 1482.28 4704.16 0.00 49.75 197.50 6065.00 -4554.55 - 1504.50 4777.55 0.00 49.73 197.50 6141.00 -4622.16 -1531.99 4869.45 0.00 49.73 197.50 6215.00 -4705.48 -1558.27 4956.78 0.00: 49.73 197.50 6220.00 -4711.11 -1560.04 4962.69 0.00 49.75 197.50 6246.00 -4740.38 - 1569.28 4995.58 0.00 · 49.73 197.50 6263.00 -4759.52 -1575.31 5015.45 0.00 49.73 197.50 6301.00 -4802.51 -1588.80 5058.51 0.00 49.75 197.50 6307.00 -4809.06 -1590.93 5065..39 0.00 49.73 197.50 6582.00 -4895.51 -1617.57 5155.92 0.00 I V 220 200 180 160 140 100 8O 6O 40 2O 20 60 BO lOO 12o 14.0 160 180 2OO 220 240 O0 500" 700 800 500 5OO Phillips Alaska, Inc. Structure: Pad 1D Field: Kuparuk River Unit Well: 42 Location: North Slope, Alaska <- West (feet) 120 100 80 60 40 20 0 20 40 700 6O 1000 lO0 600 700 BOO 2500 ~700 800 1200 , / / 1500 ?/1900 / / / / 1 tOO ~2000 800 go0 / / / / ~/~o~°° 220 200 180 '160 140 120 100 1800 1500 1900 900 / /1500 / ! /o/1600 / / / 000 1000 1100 1200 1400 500 e /./1200. /15oo e ~'4oo e 1100 1500 1400 5OO 1000 1100 1200 1600 1400 1500 1500 1100 2100 1700 1200 1800 1200 1300 80 60 40 <- West (feet) 1300 % 80 800 1900 lOO lOO 80 60 40 20 o 20 40 60 8o lOO 12o 14o 160 18o 200 22o 240 20 0 20 4.0 60 BO 100 340 320 300 280 160 200 22O 240 260 280 ~ 300 V e- 520 0 (/) 54O I V 560 58O 400 ~20 460 480 .. Phillips Alaska, Inc. Structure: Pod 1D Field: Kuporuk River Unit Well: 42 Locoflon : North Slope, Alosko <- West (feet) 260 240 220 200 180 160 140 120 .~5oo f 1900 2000 / 1600 / 2100 / 12OO / 1~o 1700 1900 5OO 540 520 300 280 260 240 1500 I I 1400 / I I / I I / 2400 I / I I I / / I I I 1 2500 I ,/2100 / I I I / / I 1 2200 1500 2400 220 200 180 160 140 120 4- West (feet) 1 oo 80 60 40 20 120 ~00 220 24O 2500 1800 1900 58O 4O0 440 46O 480 5O0 100 80 60 40 20 U1 0 C =,4- I V 44O 48O 52O 560 600 64O 680 720 76O 8OO 84O 88O 920 960 1 ooo lO4O 1080 1120 Phillips Alaska, Inc. Structure: Pad 1D Field: Kuparuk River Unit 600 560 520 480 440 400 500 1 600 560 520 480 Well: 42 Location : North Slope, Alaska <- West (feet) 3~0 320 280 240 200 160 120 80 40 0 1500 2400 I 1400 2000 1500 I I I / / / 2700 I ! I / 1600 / / I 2800 2200 I / I I I ~ 2go0 / i' I / I I / / 5000 1700 2500 440 400 360 320 280 240 200 160 <- West (feet) 120 1900 2000 8O 2100 2500 48O 520 560 600 64O 680 720 760 800 840 880 92O 960 lOOO 1080 1120 (" 900 Phillips Alaska, Inc. Structure: Pod 1D Well: 42 Field: Kuporuk River Unit Lo¢oflon : North Slope, Alesko <- West (feet) 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 100 0 100 900 lOOO 11oo 1200 1300 1400 1500 1600 1700 1800 19oo 2000 2100 2200 2300 2400 250O 2600 5100 1 1500 700 1900 270O ZSO0 100 2500 1700 / / 2500 1700 / 2500 / / / ~ 5100 I I / I / 250l 2500 / 5500 1900 I I / ~3500 I / / / / / 5700 2700 29OO / 2100 / 5100 / / I 5900 3300 / / /, I I 4100 / / / / / 4300 5500 5700 5900 2500 4100 25OO lOOO 11oo 12oo 1300 1400 1500 1600 1700 1800 19oo 2200 2300 2400 2500 2600 1 400 1 $00 1200 11 O0 1000 900 800 700 600 500 400 500 200 100 0 100 <- West (feet) ( Phillips Alaska, Inc. 3600 ,.I.- 3800 ,,,I-- '3 4000 0 I 4200 V Structure: Pod 1D Well: 42 Field: Kuparuk River Unit Looaflon : North Slope, Alaska <- West (feet) 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 2200 [ I [ t t I I ~t I I I I~l I I I I I I/~?* ' /?' ' ' ' ' ' L_~l~.l' ' ' ' ' i 2200 2400 -~ / 2500 2400 0 I /.o0 / /~oo /.oo I - 2600 2600-J /4900 / , / / ' /~ / / 2800 1 O0 2500 51 O0 / 2500 5500 ' 2800 /~oo / t~oo ,ooo~ /~oo/~,~oo/.oO~oo , ~oo~ooo ~9oo I /2900 3~oo /3~ oo ~ ,~oo 3~oo / ~o ~ ~oo 700 / ~o .37o~000 3100 -3~o ~4100 /5100 3300 3500 / 3700 / 3900 ~ 5300 41 O0 / 4.400 4600 48OO 5000 5200 5400 5600 / 5500 I I ~ 5700 / / 5900 / I ~ 61 O0 I / 6300 45OO 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 <- West (feet) - 3600 - -3800 - -4000 - -42oo -- - 44O0 -4600 - 48O0 - 5000 52OO 5400 5600 FOR: MIgOVEACH oo330 [oo~ ~oo §00 ~00 Phillips Alaska, Inc. Sfrucfure: Pad 1D Field: Kuparuk River Unif Well: 42 Looaflon : Norfh Slope, Alaska 340 TRUE NORTH 350 0 10 2O 900 3_0 ~oo 1500 ~ 1 O0 29O '7O 280 8O 270 9O 26O 100 25O 10 240 300 130 220 2 150 200 160 190 180 170 Normal Plane Travelling Cylinder- Feet All depths shown are Measured depths on Reference Well' 2O Phillips Alaska, Inc. Pad 1D 42 slot #42 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref: 42 Version#1 Our ref: prop2179 License : Date printed : 25-Sep-2000 Date created : 16-Apr-1997 Last revised : 22-Sep-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.740,w149 30 31.181 Slot Grid coordinates are N 5959099.181, E 560670.547 Slot local coordinates are 567.00 S 421.00 W Projection type: alaska - Zone 4, Spheroi'd: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10445'>,,32,Pad 1E PMSS <0-11712'>,,34,Pad 1E PMSS <121-9505'>,,33PB1,Pad 1E PMSS <9010 - lO951'>,,33,Pad 1E GMS <O-S905'>,,3,Pad 1E GMS <0-7413'> <Depth Shifted>,,24,Pad 1E PMSS <5538-8167'>,,24A,Pad 1E GMS <O-8017'>,,26A,Pad 1E MSS <2370-3605'>,,26,Pad 1E GMS <0-7310'> GMS <0-7811'> GMS <0-7512'> GMS <0-7750'> GMS <0-7190'> GMS <0-8435'> GMS <0-7885'> GMS <0-8150'> GMS <0-7898'> GMS <0-8650'> GMS <0-7420'> GMS <0-9480'> GMS <0-8350'> GMS <0-7467'> GMS <0-6800'> ,30,Pad 1E ,10,Pad 1E ,12,Pad 1E ,13,Pad 1E ,14,Pad 1E ,15,Pad 1E ,17,Pad 1E ,18,Pad 1E ,19,Pad 1E ,20,Pad 1E ,21,Pad 1E ,22,Pad 1E ,23,Pad 1E ,25,Pad 1E ,27,Pad 1E TOTCO Survey,,WS-2,Pad 1E GMS <O-7310'>,,1A,Pad 1E MSS <2819-7345'>,,1,Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance 26~Feb-2000 8041.9 20-0ct-1997 4619.2 17-Aug-1998 3970.0 17-Aug-1998 2661.'7 4-Aug-1992 5421.2 8-Nov-1997 8243.1 12-Nov-1997 6840.1 25-Jun-1997 10157.6 4-Aug-1992 10166.3 g-Jul-1997 10653.6 4-Aug-lgg2 11013.9 4-Aug-1992 10837.3 4-Aug-1992 10970.2 4-Aug-lgg2 10792.9 4-Aug-1992 10773.4 4-Aug-1992 10899.6 4-Aug-1992 10119.5 4-Aug-1992 9148.7 4-Aug-lgg2 7519.5 4-Aug-1992 7893.8 4-Aug-1992 4708.6 4-Aug-1992 6422.8 4-Aug-1992 10013.5 4-Aug-1992 10294.4 4-Aug-1992 7953.1 4-Aug-1992 9406.1 4-Aug-1992 9601.6 M,D, 8642.5 8642.5 6500.0 6460.0 6420.0 7800.0 6980.0 8642.5 4980.0 3600.0 2022.2 3860.0 2022.2 3940.0 3760 0 3380 0 3220 0 3600 0 4080 0 6020 0 8642 5 8360 0 48O0 0 5660 0 6200 0 8148 9 8642 5 Diverging from M.D. 8642.5 8642.5 6500.0 6460.0 6420.0 7800.0 6980.0 8642.5 6660.0 4560.0 4720.0 6280.0 8580.0 7980.O 7680.0 8269.6 4340.0 3600.0 4080.0 6020.0 8642.5 8360.0 8620.0 8380.0 6200.0 8320.0 8642.5 GMS <0-8440'>,,2,Pa(' GMS <0-7195'>,,5,Paa 1~ GMS <O-9837'>,,6,Pad 1E GMS <0-9310'>,,7,Pad 1E GMS <O-7590'>,,8,Pad 1E GMS <0-7000'>,,9,Pad 1E GMS <O-8754'>,,11,Pad 1E GMS <O-6835'>,,29,Pad 1E GMS <0-7665'>,,28,Pad 1E GMS <0-9150'>,,4,Pad 1E PMSS <0 - 11725'>,,35,Pad 1E PMSS <0 - 12005'>,,36,Pad 1E GMS <0-7715'>,,16,Pad 1E PMSS <121 - 9130'>,,31PB1,Pad 1E PMSS <8798-10023'>,,31,Pad 1E PMSS <O-12225'>,,40,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS <O-3252'>,,133PB1,Pad 1D PMSS <1957-5265'>,,133,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <O-11660'>,,36,Pad 1D 141L1PMSS<5475'-9480'>,,141L1,Pad 1D 141 PMSS <O-9550'>,,141,Pad 1D PMSS <0-6543'>,,138,Pad 1D PMSS <O-1288'>,,138PB1,Pad 1D PMSS <O-4414'>,,121,Pad 1D PMSS <377 - 6224'>,,134,Pad 1D PMSS <O-14324'>,,38,Pad 1D PMSS <6527-7378'>,,102,Pad 1D L1PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D PMSS <6143-6767'>,,102PB3,Pad 1D PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <O-5354'>,,102PB1,Pad 1D PMSS <O-12044'>,,30,Pad 1D PMSS <O-11234'>,,11,Pad 1D PGMS <O-8610'>,,6,Pad 1D 139 <PMSS 515 - 4838'>,,139,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D PMSS <5155'- 5905'>,,110A,Pad 1D PMSS <O-4590'>,,118,Pad 1D PGMS <0-8930'>,,5,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PGMS <O-9783'>,,2,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <O-4778'>,,130,Pad 1D PMSS <O-5462'>,,129,Pad 1D PMSS <O-4515'>,,119,Pad 1D PGMS <O-8070'>,,3,Pad 1D PMSS <O-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6580'>,,128,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D GSS <O-173'>,,123,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <O-175'>,,116,Pad 1D PMSS <290-6245'>,,116,Pad 1D PMSS <0-5047'>,,124,Pad 1D PMSS <291 - 5795'>,,125,Pad 1D PGMS <0-8365'>,,1,Pad 1D PMSS <0 - 7150'>,,108,Pad 1D PMSS <O-4850'>,,109,Pad 1D PMSS<O-7045'>,,lll,Pad 1D PMSS <O-9250'>,,12,Pad 1D PMSS <0-8702'>,,14,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS <O-5142'>,,115,Pad 1D 4-Aug-1992 4-Aug-1992 4-Aug-1992 4-Aug-1992 4-Aug-1992 4-Aug-1992 4-Aug-1992 25-Jun-1997 4-Aug-1992 4-Aug-1992 29-0ct-1998 17-Nov-1998 9-Ju1-1997 16-Aug-1998 16-Aug-1998 5-Sep-2000 24-Apr-2000 2-Jun-2000 21-Sep-2000 2-Jun-1998 6-Nov-1997 18-Sep-2000 20-Sep-2000 6-Sep-2000 18-May-2000 18-May-2000 2-Jun-1998 3-Aug-1998 24-~ul-2000 28-Jul-2000 27-Jul-2000 27-Jul-2000 27-Jul-2000 28-Jul-2000 25-Aug-2000 30-Dec-1999 13-Nov-1997 18-May-2000 5-Jun-2000 17-May-2000 2-Jun-1998 13-Nov-1997 2-Jun-1998 2-Jun-1998 4-Aug-1992. 6-Aug-1998 23-Ju1-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 1-Ju1-1998 6-Ju1-1998 17-Aug-1998 29-Aug-1998 4-Sep-1998 13-Sep-1998 8-Sep-1998 17-Sep-1998 2-Jun-1998 19-Au~-1998 10-Dec-1997 28-0c%-1998 2-Jun-1998 3-Sep-1998 21-Jan-2000 6-0c%-1999 2g-Apr-1998 21-Sep-1998 22-Sep-1998 2-Sep-1998 2-Jun-1998 PGMS <0-8850'> 28-May-81,,MP i 17-Ii-II,Pad 1D 23-Apr-1999 PMSS <4674'-5639'>,,125A,Pad 1D 24-Apr-2000 PMSS <O-5205'>,,117,Pad 1D 2-Jun-1998 PMSS <0 - 7340'>,,lO,Pad 1D 28-Apr-1998 PGMS <0 - 6400'>,,WS-8,Pad 1D 27-Apr-2000 PGMS <0-7502'>,,4,Pad 1D 4-Aug-1992 PMSS <0-5015'>,,135,Pad 1D 2-Jun-1998 7044.1 9124.2 10790.8 8755.9 10835.4 10914.5 11041.7 10579.7 10637.9 10800.6 6436.0 9955.6 10876.8 8895.3 7966.8 30.0 635.6 183.9 211.7 211.7 194.8 90.0 3700.0 503.2 169.0 175.0 424.6 188.4 59.7 652 6 652 6 652 6 652 6 652 6 179 6 115 6 171.4 52.8 105.0 635.6 493.1 365.2 693.2 721.7 707.2 221.8 231.0, 237.4 251.0 452.1 592.0 438.3 320.1 307.7 295.6 411.1 397.4 396.4 521.6 521.6 345.4 332.6 823.7 664.5 650.0 621.2 803.6 795.3 465.9 578.1 564.2 549.7 535.7 8656.2 332.6 507.5 41.1 83.3 478.9 46.0 8642 .(~ 4000.0 2066.7 2711.1 2000.0 3460.0 1911.1 4700.0 3760.0 2020.0 8642.5 8642.5 3320.0 8642.5 8642.5 120.0 100.0 780.0 1680.0 1680.0 550.0 0.0 2688.9 1300.0 920.0 950.0 100.0 292.9 278.6 2177.8 2177.8 2177.8 2177.8 2177.8 278.6 1020.0 1811.1 2000.0 1344.4 100.0 264.3 1355.6 100.0 280.0 260.0 140.0 100.0 580.0 100.0 100.0 0.0 100.0 100.0 100.0 100.0 100.0 160.0 292.9 100.0 100.0 100.0 100.0 264.3 100.0 100.0 100.0 1108.3 100.0 100.0 100.0 100.0 280.0 160.0 2611.1 100.0 100.0 1057.1 1740.0 278.6 1388.9 8642.5 4000.0 7350.6 2711.1 8260.0 7180.0 7600.0 4820.0 5240.0 8500.0 8642.5 8642.5 7220.0 8642.5 8642.5 1057.1 100.0 1280.0 1680.0 4640.0 550.0 0.0 2688.9 6140.0 920 0 950 0 1169 4 6060 0 278 6 2177 8 2177 8 2177 8 2177.8 2177.8 278.6 1020.0 1811.1 2000.0 1344.4 100.0 860.0 1355.6 920.0 280.0 260.0 5980.0 6360.0 580.0 5200.0 100.0 880.0 1235.7 100.0 100.0 760.0 100.0 160.0 292.9 100.0 100.0 100.0 100.0 960.0 100.0 100.0 100.0 1108.3 100.0 880.0 100.0 100.0 280.0 160.0 2611.1 100.0 100.0 1057.1 1740.0 760.0 1388.9 PMSS <1465-????>,,34,(' 1D 25-Sep-2000 119.9 ,, 250.( 250.0 Phillips Alaska, Inc. Pad 1D 42 slot ~2 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref: 42 Version #1 Our ref: prop2179 License : Date printed: 22-Sep-2000 Date created: 16-Apr-1997 Last revised: 21-Sep-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.740,w149 30 31.181 Slot Grid coordinates are N 5959099.181, E 560670.547 Slot local coordinates are 567.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1D,42 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O0 R D I NAT E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 235.00 100.00 0.00 N 0.00 E 200.00 0.00 235.00 200.00 0.00 N 0.00 E 250.00 0.00 235.00 250.00 0.00 N 0.00 E 350.00 1.50 235.00 349.99 0.75 S 1.07 W 450.00 3.00 235.00 449.91 3.00 S 4.29 W 550.00 1.50 235.00 549.83 5.25 S 7.50 W 650.00 0.00 235.00 649.82 6.01 S 8.58 W 950.00 0.00 235.00 949.82 6.01 S 8.58 W 1000.00 0.75 225.00 999.82 6.24 S 8.81 W 1100.00 2.25 225.00 1099.78 8.09 S 10.66 W 1125.00 3.00 225.00 1124.75 8.90 S 11.47 W 1225.00 6.00 225.00 1224.43 14.44S 17.02 W 1300.00 8.25 225.00 1298.85 21.02 S 23.59 W 1400.00 11.23 222.77 1397.40 33.24 S 35.28 W 1500.00 14.21 221.47 1494.93 49.59 S 50.02 W 1600.00 17.20 220.61 1591.19 70.02 S 67.78W 1627.08 18.01 220.43 1617.00 76.25 S 73.10 W 1700.00 20.20 220.00 1685.90 94.48 S 88.51 W 1800.00 21.51 212.42 1779.36 123.19 S 109.44 W PROPOSAL LISTING Page 1 Your ref : 42 Version#1 Last revised : 22-Sep-2000 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 Begin Angle Nudge 1.50 1.05 1.50 4.20 Begin Drop 1.50 7.35 1.50 8.4O EOC 0.00 8.40 Begin Build/Turn 1.50 8.69 1.50 11.03 Begin Build 3.00 12.05 3.00 19.06 3.00 27.37 Begin Build/Turn 3.00 42.65 3.00 62.80 3.00 87.78 3.00 95.37 Base of Permafrost 3.00 117.51 3.00 151.35 1900.00 23.13 205.76 1871.88 156.37 S 127.81 W 3.00 188.62 2000.00 24.99 199.99 1963.19 193.92 S 143.58 W 3.00 229.22 2100.00 27.05 195.00 2053.06 235.75 S 156.69 W 3.00 273.05 2200.00 30.04 195.52 2140.90 281.84 S 169.27 W 3.00 320.76 2300.00 33.03 195.95 2226.12 332.17 S 183.46 W 3.00 373.01 2400.00 36.02 196.31 2308.50 386.61 S 199.21W 3.00 429.64 2500.00 39.02 196.63 2387.80 445.01 S 216.48 W 3.00 490.50 2600.00 42.01 196.91 2463.82 507.20 S 235.23 W 3.00 555.44 2700.00 45.01 197.16 2536.33 573.02 S 255.40 W '3.00 624.26 2800.00 48.00 197.38 2605.16 642.28 S 276.94 W 3.00 696.78 2857.81 49.73 197.50 2643.18 683.82 S 289.99 W 3.00 740.31EOC 3000.00 49.73 197.50 2735.08 787.30 S 322.63 W 0.00 848.81 3500.00 49.73 197.50 3058.25 1151.16 S 437.38 W 0.00 1230.30 4000.00 49.73 197.50 3381.41 1515.03 S 552.12 W 0.00 1611.79 4304.16 49.73 197.50 3578.00 1736.37 S 621.93 W 0.00 1843.86 Top West Sak 4500.00 49.73 197.50 3704.58 1878.89 S 666.87 W 0.00 1993.28 4981.83 49.73 197.50 4016.00 2229.54 S 777.45 W 0.00 2360.91 Base West Sak 5000.00 49.73 197.50 4027.74 2242.76 S 781.62 W 0.00 2374.77 5291.27 49.73 197.50 4216.00 2454.72 S 848.47 W 0.00 2597.00 9-5/8" Casing Pt 5500.00 49.73 197.50 4350.91 2606.62 S 896.37 W 0.00 2756.26 5537.28 49.73 197.50 4375.00 2633.75 S 904.92 W 0.00 2784.70 C80(K-10) 6000.00 49.73 197.50 4674.07 2970.48 S 1011.12 W 0.00 3137.75 6500.00 49.73 197.50 4997.24 3334.35 S 1125.87 W 0.00 3519.24 6939.04 49.73 197.50 5281.00 3653.85 S 1226.63 W 0.00 3854.21 C50 7000.00 49.73 197.50 5320.40 3698.21 S 1240.62 W 0.00 3900.73 7350.59 49.73 197.50 5547.00 3953.35 S 1321.08 W 0.00 4168.22 C40(K-5) 7500.00 49.73 197.50 5643.57 4062.08 S 1355.36 W 0.00 4282.22 7808.56 49.73 197.50 5843.00 4286.63 S 1426.18 W 0.00 4517.65 Top HRZ 7836.41 49.73 197.50 5861.00 .4306.89 S 1432.57 W 0.00 4538.89 C30(K-2) 8000.00 49.73 197.50 5966.73 4425.94 S 1470.11 W 0.00 4663.71 All data is in feet unless otherwise stated. Coordinates from slot//42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 5153.93 on azimuth 198.29 degrees from wellhead. Total Dogleg for wellpath is 60.98 degrees. Vertical section is from wellhead on azimuth 198.32 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,42 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E CTAN GU LAR Depth Degrees Degrees Depth C 0 0 R D I NATES PROPOSAL LISTING Page 2 Your ref : 42 Version#1 Last revised : 22-Sep-2000 Dogleg Vert Deg/lOOft Sect 8053.02 49.73 197.50 6001.00 4464.53 S 1482.28 W 0.00 8148.95 49.73 197.50 6063.00 4534,33 S 1504.30 W 0.00 8269.63 49.73 197.50 6141.00 4622,16 S 1531.99 W 0.00 8384.12 49.73 197.50 6215.00 4705,48 S 1558.27 W 0.00 8391.86 49.73 197.50 6220.00 4711,11 S 1560.04 W 0.00 4704.16 C20 (HRZ Midpoint) 4777.35 7" Casing Pt/Base HRZ 4869.43 K-1 4956.78 Top Kuparuk D 4962.69 2DT 9-May-O0 8432.08 49.73 197.50 6246.00 4740.38 S 1569.28 W 0.00 4993.38 Top C3 8458.39 49.73 197.50 6263.00 4759.52 S 1575.31W 0.00 5013.45 Top C2 8500.00 49.73 197.50 6289.90 4789.81 S 1584.86 W 0.00 5045.20 8517.18 49.73 197.50 6301.00 4802.31 S 1588.80 W 0.00 5058.31 Top C1 8526.46 49.73 197.50 6307.00 4809.06 S 1590.93 W 0.00 5065.39 Top B Shale 8642.50 49.73 197.50 6382.00 4893.51 S 1617.57 W 0.00 5153.92 TD-Casing Pt All data is in feet unless otherwise stated. Coordinates from slot ~/42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 5153.93 on azimuth 198.29 degrees from wellhead. Total Dogleg for wellpath is 60.98 degrees. Vertical section is from wellhead on azimuth 198.32 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,42 Kuparuk River Unit,North S1 ope, A1 aska PROPOSAL LISTING Page 3 Your ref : 42 Version#1 Last revised : 22-Sep-2000 Comments in wel 1 path MD TVD Rectangul ar Coords. Comment 250.00 250.00 0.00 N 0.00 E Begin Angle Nudge 450.00 449.91 3.00 S 4.29 W Begin Drop 650.00 649.82 6.01 S B.58 W EOC 950.00 949.82 6.01S 8.58 W Begin Build/Turn 1100.00 1099.78 8.09 S 10.66 W Begin Build 1300.00 1298.85 21.02 S 23.59 W Begin Build/Turn 1627.08 1617.00 76.25 S 73.10 W Base of Permafrost 2857.81 2643.18 683.82 S 289.99 W EOC 4304.16 3578.00 1736.37 S 621.93 W Top West Sak 4981.83 4016.00 2229.54 S 777.45 W Base West Sak 5291.27 4216.00 2454.72 S 848.47 W 9-5/8" Casing Pt 5537.28 4375.00 2633.75 S 904.92 W C80(K-10) 6939.04 5281.00 3653.85 S 1226.63 W C50 7350.59 5547.00 3953.35 S 1321.08 W C40(K-5) 7808.56 5843.00 4286.63 S 1426.18 W Top HRZ 7836.41 5861.00 4306.89 S 1432.57 W C30(K-2) 8053.02 6001.00 4464.53 S 1482.28 W C20 (HRZ Midpoint) 8148.95 6063.00 4534.33 S 1504.30 W 7" Casing Pt/Base HRZ 8269.63 6141.00 4622.16 S 1531.99 W K-1 8384.12 6215.00 4705.48 S 1558.27 W Top Kuparuk D 8391.86 6220.00 4711.11S 1560.04 W 2DT 9-May-O0 8432.08 6246.00 4740.38 S 1569.28 W Top C3 8458.39 6263.00 4759.52 S 1575.31 W Top C2 8517.18 6301.00 4802.31S 1588.80 W Top C1 8526.46 6307.00 4809.06 S 1590.93 W Top B Shale 8642.50 6382.00 4893.51S 1617.57 W TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 5291.27 4216.00 2454.72S 848.47W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8148.95 6063.00 4534.33S 1504.30W 7" Casing 0.00 0.00 O.OON O.OOE 8642.50 6382.00 4893.51S 1617.57W 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2DT g-May-O0 559149.000,5954376.000,0.0000 6220.00 4711.11S 1560.04W 3-Mar-2000 Phillips Alaska, Inc. Pad 10,42 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 42 Version#1 Last revised : 21-Sep-2000 Measured Inclin Azimuth True Vert R E C TAN G U LA R G R I D C 0 0 R D S G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 R D I N AT E S Easting Northing C 0 0 R D I N AT E S 0.00 0.00 0.00 0.00 O.OON O.OOE 560670.55 5959099.18 n70 17 55.74 w149 30 31.18 100.00 0.00 235.00 100.00 O.OON O.OOE 560670.55 5959099.18 n70 17 55.74 w149 30 31.18 200.00 0.00 235.00 200.00 O.OON O.OOE 560670.55 5959099.18 n70 17 55.74 w149 30 31.18 250.00 0.00 235.00 250.00 O.OON O.OOE 560670.55 5959099.18 n70 17 55.74 w149 30 31.18 350.00 1.50 235.00 349.99 0.75S 1.07W 560669.48 5959098.42 n70 17 55.73 w149 30 31.21 450,00 3,00 235,00 449.91 3,00S 4,29W 560666,28 5959096,14 n70 17 55,71 w149 30 31,31 550,00 1,50 235,00 549,83 5,25S 7.50W 560663.09 5959093,87 n70 17 55,69 w149 30 31,40 650,00 0,00 235,00 649,82 6,01S 8,58W 560662,02 5959093,11 n70 17 55,68 w149 30 31,43 950,00 0,00 235,00 949,82 6,01S 8,58W 560662,02 5959093,11 nTO 17 55,68 w149 30 31,43 1000,00 0.75 225,00 999,82 6.24S 8,81W 560661,79 5959092,87 n70 17 55,68 w149 30 31,44 1100.00 2.25 225.00 1099.78 8.09S 10.66W 560659.96 5959091.01 n70 17 55.66 w149 30 31.49 1125.00 3.00 225.00 1124.75 8.90S 11.47W 560659.15 5959090.19 n70 17 55.65 w149 30 31.51 1225.00 6.00 225.00 1224.43 14.44S 17.02W 560653.65 5959084.60 nTO 17 55.60 w149 30 31.68 1300.00 8.25 225.00 1298.85 21.02S 23.59W 560647.13 5959077.97 nTO 17 55.53 w149 30 31.87 1400.00 11.23 222.77 1397.40 33.24S 35.28W 560635.54 5959065.65 n70 17 55.41 w149 30 32.21 1500,00 14,21 221,47 1494,93 49,59S 50,02W 560620,93 5959049,19 n70 17 55,25 w149 30 32,64 1600,00 17,20 220,61 1591,19 70,02S 67,78W 560603,34 5959028,62 n70 17 55,05 w149 30 33,16 1627,08 18,01 220,43 1617,00 76,25S 73,10W 560598,07 5959022,34 n70 17 54,99 w149 30 33,31 1700,00 20,20 220,00 1685,90 94,48S 88,51W 560582,82 5959003,99 n70 17 54,81 w149 30 33,76 1800,00 21,51 212,42 1779,36 123.19S 109,44W 560562,12 5958975,12 n70 17 54,53 w149 30 34,37 1900.00 23.13 205.76 1871.88 156.37S 127.81W 560544.02 5958941.79 n70 17 54.20 w149 30 34.91 2000.00 24.99 199.99 1963.19 193.92S 143.58W 560528.57 5958904.12 n70 17 53.83 w149 30 35.37 2100.00 27.05 195.00 2053.06 235.75S 156.69W 560515.80 5958862.19 n70 17 53.42 w149 30 35.75 2200.00 30.04 195.52 2140.90 281.84S 169.27W 560503.59 5958816.00 n70 17 52.97 w149 30 36.11 2300.00 33.03 195.95 2226.12 332.17S 183.46W 560489.81 5958765.56 n70 17 52.47 w149 30 36.53 2400,00 36,02 196,31 2308,50 386,61S 199,21W 560474.51 5958711,00 n70 17 51,94 w149 30 36,99 2500,00 39,02 196,63 2387,80 445,01S 216,48W 560457,71 5958652,47 nTO 17 51,36 w149 30 37,49 2600,00 42,01 196,91 2463,82 507,20S 235,23W 560439,47 5958590,13 nTO 17 50,75 w149 30 38,04 2700,00 45,01 197,16 2536,33 573,02S 255,40W 560419,83 5958524,16 n70 17 50,10 w149 30 38,62 2800,00 48,00 197.38 2605,16 642,28S 276,94W 560398,86 5958454,73 n70 17 49,42 w149 30 39,25 2857,81 49,73 197,50 2643,18 683,82S 289,99W 560386,15 5958413,09 n70 17 49,01 w149 30 39,63 3000,00 49,73 197,50 2735,08 787,30S 322,63W 560354,36 5958309,36 n70 17 48,00 w149 30 40,58 3500,00 49,73 197,50 3058,25 1151,16S 437,38W 560242.59 5957944,61 n70 17 44,42 w149 30 43,93 4000,00 49,73 197,50 3381,41 1515,03S 552,12W 560130,81 5957579,86 nTO 17 40,84 w149 30 47,27 4304,16 49,73 197,50 3578,00 1736,37S 621,93W 560062,81 5957357,98 n70 17 38,66 w149 30 49,30 4500,00 49,73 197,50 3704,58 1878,89S 666.87W 560019.03 5957215,11 n70 17 37,26 w149 30 50,61 4981,83 49,73 197,50 4016,00 2229,54S 777,45W 559911,32 5956863,61 n70 17 33,81 w149 30 53,83 5000,00 49,73 197,50 4027,74 2242,76S 781,62W 559907,26 5956850,36 n70 17 33,68 w149 30 53,96 5291,27 49,73 197,50 4216,00 2454,72S 848,47W 559842,14 5956637,88 nTO 17 31,60 w149 30 55,90 5500,00 49,73 197,50 4350,91 2606,62S 896,37W 559795,48 5956485,61 n70 17 30,10 w149 30 57,30 5537,28 49,73 197,50 4375,00 2633,75S 904,92W 559787,15 5956458,42 n70 17 29,84 w149 30 57,55 6000,00 49,73 197,50 4674,07 2970,48S 1011,12W 559683,70 5956120,86 n70 17 26,52 w149 31 00,64 6500,00 49,73 197,50 4997,24 3334,35S 1125.87W 559571,93 5955756,11 n70 17 22,94 w149 31 03,98 6939,04 49,73 197,50 5281,00 3653,85S 1226,63W 559473,78 5955435,83 n70 17 19.80 w149 31 06,92 7000,00 49,73 197,50 5320,40 3698,21S 1240,62W 559460,15 5955391,36 nTO 17 19,37 w149 31 07,32 7350,59 49,73 197,50 5547,00 3953,35S 1321,08W 559381,78 5955135,60 n70 17 16,86 w149 31 09,67 7500,00 49,73 197,50 5643,57 4062,08S 1355,36W 559348,38 5955026,61 n70 17 15.79 w149 31 10,66 7808,56 49,73 197,50 5843,00 4286,63S 1426,18W 559279,40 5954801,51 n70 17 13,58 w149 31 12,72 7836,41 49,73 197,50 5861,00 4306,89S 1432,57W 559273,17 5954781,20 n70 17 13,38 w149 31 12,91 8000,00 49,73 197,50 5966,73 4425,94S 1470,11W 559236,60 5954661,86 n70 17 12,21 w149 31 14,00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot ~42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea l~w~.i Bottom hole distance is 5153.93 on azimuth 198.29 degrees from wellhead. Total Dogleg for wel lpath i s 60.98 degrees. Vertical section is from wellhead on azimuth 198.32 degrees Grid is alaska - Zone 4, ~.¢ ~.,~ Grid coordinates in FEET and computed usino the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~ Phillips Alaska, Inc. Pad 1D,42 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 42 Version #1 Last revised : 21-Sep-2000 Measured Inclin Azimuth TrueVert R E C TAN GU LAR GR I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Easting Northing GEOGRAPHIC COORDINATES 8053.02 49.73 197.50 6001.00 4464.53S 1482.2BW 559224.75 5954623.18 n70 17 8148.95 49.73 197.50 6063.00 4534.33S 1504.30W 559203.30 5954553.20 n70 17 8269.63 49.73 197.50 6141.00 4622.16S 1531.99W 559176.32 5954465.17 nTO 17 8384.12 49.73 197.50 6215.00 4705,48S 1558.27W 559150.73 5954381.64 nTO 17 8391.86 49.73 197.50 6220.00 4711.11S 1560.04W 559149.00 5954376.00 nTO 17 8432.08 49.73 197.50 6246.00 4740.38S 1569.28W 559140.01 5954346.65 n70 17 8458.39 49.73 197.50 6263.00 4759.52S 1575.31W 559134.13 5954327.47 n70 17 8500.00 49.73 197.50 6289.90 4789.81S 1584.86W 559124.82 5954297.11 n70 17 8517.18 49.73 197.50 6301.00 4802.31S 1588.80W 559120.98 5954284.58 n70 17 8526.46 49.73 197.50 6307.00 4809.06S 1590.93W 559118.91 5954277.80 n70 17 11.83 w149 31 14.36 11.14 w149 31 15.00 10.28 w149 31 15.81 09,46 w149 31 16.57 09.40 w149 31 16,62 09.12 wl4g 31 16.89 08.93 w149 31 17.07 08.63 w149 31 17.34 08.51 w149 31 17.46 08.44 w149 31 17.52 8642.50 49.73 197.50 6382.00 4893.51S 1617.57W 559092.97 5954193.15 n70 17 07.61 w149 31 18.30 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot ~42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 5153.93 on azimuth 198.29 degrees from wellhead. Total Dogleg for well path is 60.98 degrees. Vertical section is from wellhead on azimuth 198.32 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~ Phillips Alaska. Inc. Pad 1D,42 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 42 Version#1 Last revised : 21-Sep-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 1627.08 1617.00 76.25S 73.10W Base of Permafrost 4304.16 3578.00 1736.37S 621.93W Top West Sak 4981.83 4016.00 2229.54S 777.45W Base West Sak 5291,27 4216.00 2454.72S 848.47W 9-5/8" Casing Pt 5537.28 4375.00 2633.75S 904.92W C80(K-10) 6939.04 5281.00 3653.85S 1226.63W C50 7350.59 5547.00 3953.35S 1321.08W C40(K-5) 7808.56 5843.00 4286.63S 1426.18W Top HRZ 7836.41 5861,00 4306.89S 1432.57W C30(K-2) 8053.02 6001.00 4464.53S 1482.28W C20 (HRZ Midpoint) 8148.95 6063.00 4534,33S 1504.30W Base HRZ 8269.63 6141.00 4622,16S 1531.99W K-1 8384.12 6215.00 4705.48S 1558.27W Top Kuparuk D 8391.86 6220.00 4711.11S 1560.04W 2DT 9-May-O0 8432.08 6246.00 4740.38S 1569,28W Top C3 8458.39 6263.00 4759.52S 1575.31W Top C2 8517.18 6301.00 4802.31S 1588.80W Top C1 8526,46 6307.00 4809.06S 1590.93W Top B Shale 8642,50 6382.00 4893.51S 1617.57W TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 5291.27 4216.00 2454.72S 848.47W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8148.95 6063.00 4534.33S 1504.30W 7" Casing 0.00 0.00 O.OON O.OOE 8642.50 6382.00 4893.51S 1617.57W 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2DT 9-May-O0 559149.000.5954376.000,0.0000 6220.00 4711.11S 1560.04W 3-Mar-2000 Phillips Alaska, Inc. Pad 1D.42 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : 42 Version#1 Last revised : 21-Sep-2000 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 235.00 100.00 0.00 N 0.00 E 0.00 0.48 0.48 0.26 N/A 200.00 0.00 235.00 200.00 0.00 N 0.00 E 0.00 0.96 0.96 0.52 N/A 250.00 0.00 235.00 250.00 0.00 N 0.00 E 0.00 1.19 1.19 0.65 N/A 350.00 1.50 235.00 349.99 0.75 S 1.07 W 1.05 1.90 1.67 0.90 325.00 450.00 3.00 235.00 449.91 3.00 S 4.29 W 4.20 2.80 2.15 1.16 325.00 550.00 1.50 235.00 549.83 5.25 S 7.50 W 7.35 3.77 2.63 1.42 325.00 650.00 0.00 235.00 649.82 6.01 S 8.58 W 8.40 4.11 3.11 1.68 325.00 950.00 0.00 235.00 949.82 6.01 S 8.58 W 8.40 5.28 4.54 2.45 325.00 1000.00 0.75 225.00 999.82 6.24 S 8.81 W 8.69 5.72 4.78 2.58 323.57 1100.00 2.25 225.00 1099.78 8.09 S 10.66 W 11.03 6.63 5.26 2.84 321.67 1125.00 3.00 225.00 1124.75 8.90 S 11.47 W 12.05 6.86 5.38 2.91 321.32 1225.00 6.00 225.00 1224.43 14.44 S 17.02 W 19.06 7.79 5.86 3.17 320.23 1300.00 8.25 225.00 1298.85 21.02 S 23.59 W 27.37 8.51 6.22 3.38 319.63 1400.00 11.23 222.77 1397.40 33.24 S 35.28 W 42.65 9.46 6.72 3.66 318.75 1500.00 14.21 221.47 1494.93 49.59 S 50.02 W 62.80 10.41 7.23 3.97 317.94 1600.00 17.20 220.61 1591.19 70.02 S 67.78W 87.78 11.36 7.76 4.30 317.24 1627.08 18.01 220.43 1617.00 76.25 S 73.10 W 95.37 11.62 7.91 4.39 317.09 1700.00 20.20 220.00 1685.90 94.48 S 88.51 W 117.51 12.30 8.31 4.65 316.66 1800.00 21.51 212.42 1779.36 123.19 S 109.44 W 151.35 13.23 8.89 5.04 315.61 1900.00 23.13 205.76 1871.88 156.37 S 127.81 W 188.62 14.13 9.47 5.44 314.30 2000.00 24.99 199.99 1963.19 193.92 S 143.58 W 229.22 15.01 10.08 5.87 312.88. 2100.00 27.05 195.00 2053.06 235.75 S 156.69 W 273.05 15.86 10.69 6.33 311.43 2200.00 30.04 195.52 2140.90 281.84 S 169.27 W 320.76 16.71 11.34 6.83 310.30 2300.00 33.03 195.95 2226.12 332.17 S 183.46 W 373.01 17.55 12.03 7.37 309.44 2400.00 36.02 196.31 2308.50 386.61 S 199.21W 429.64 18.37 12.76 7.95 308.83 2500.00 39.02 196.63 2387.80 445.01 S 216.48 W 490.50 19.18 13.54 8.57 308.47 2600.00 42.01 196.91 2463.82 507.20 S 235.23 W 555.44 19.97 14.37 9.23 308.36 2700.00 45.01 197.16 2536.33 573.02 S 255.40 W 624.26 20.74 15.26 9.93 308.52 2800.00 48.00 197.38 2605.16 642.28 S 276.94 W 696.78 21.49 16.20 10.68 309.00 2857.81 49.73 197.50 2643.18 683.82 S 289.99 W 740.31 21.91 16.77 11.12 309.42 3000.00 49.73 197.50 2735.08 787.30 S 322.63 W 848.81 22.97 18.18 12.23 310.76 3500.00 49.73 197.50 3058.25 1151.16 S 437.38 W 1230.30 26.81 23.26 16.15 319.83 4000.00 49.73 197.50 3381.41 1515.03 S 552.12 W 1611.79 31.13 28.08 20.10 337.61 4304.16 49.73 197.50 3578.00 1736.37 S 621.93 W 1843.86 34.22 30.61 22.50 347.88 4500.00 49.73 197.50 3704.58 1878.89 S 666.87 W 1993.28 36.21 32.24 24.05 354.50 4981.83 49.73 197.50 4016.00 2229.54 S 777.45 W 2360.91 41.56 35.87 27.87 2.98 5000.00 49.73 197.50 4027.74 2242.76 S 781.62 W 2374.77 41.76 36.00 28.01 3.30 5291.27 49.73 197.50 4216.00 2454.72 S 848.47 W 2597.00 45.10 38.10 30.32 5.87 5500.00 49.73 197.50 4350.91 2606.62 S 896.37 W 2756.26 47.50 39.61 31.98 7.71 5537.28 49.73 197.50 4375.00 2633.75 S 904.92 W 2784.70 47.93 39.87 32.28 7.89 6000.00 49.73 197.50 4674.07 2970.48 S 1011.12 W 3137.75 53.33 43.15 35.95 10.19 6500.00 49.73 197.50 4997.24 3334.35 S 1125.87 W 3519.24 59.20 46.67 39.92 11.73 6939.04 49.73 197.50 5281.00 3653.85 S 1226.63 W 3854.21 64.39 49.73 43.41 12.65 7000.00 49.73 197.50 5320.40 3698.21 S 1240.62 W 3900.73 65.11 50.16 43.89 12.78 7350.59 49.73 197.50 5547.00 3953.35 S 1321.08 W 4168.22 69.27 52.60 46.68 13.30 7500.00 49.73 197.50 5643.57 4062.08 S 1355.36 W 4282.22 71.04 53.64 47.86 13.52 7808.56 49.73 197.50 5843.00 4286.63 S 1426.18 W 4517.65 74.70 55.79 50.31 13.86 7836.41 49.73 197.50 5861.00 4306.89 S 1432.57 W 4538.89 75.03 55.98 50.54 13.89 8000.00 49.73 197.50 5966.73 4425.94 S 1470.11 W 4663.71 76.98 57.12 51.84 14.07 All data is in feet unless otherwise stated. Coordinates from slot ~42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 5153.93 on azimuth lgs.2g degrees from wellhead. Vertical section is from wellhead on azimuth 198.32 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1D.42 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTA COORD 8053.02 49.73 197.50 6001.00 4464.53 S 8148.95 49.73 197.50 6063.00 4534.33 S 8269.63 49.73 197.50 6141.00 4622.16 S 8384.12 49.73 197.50 6215.00 4705.48 S 8391.86 49.73 197.50 6220.00 4711.11 S 8432.08 49.73 197.50 6246.00 4740.38 S 8458.39 49.73 197.50 6263.00 4759.52 S 8500.00 49.73 197.50 6289.90 4789.81 S 8517.18 49.73 197.50 6301.00 4802.31S 8526.46 49.73 197.50 6307.00 4809.06 S 8642.50 49.73 197.50 6382.00 4893.51 S PROPOSAL LISTING Page 2 Your ref : 42 Version#1 Last revised : 21-Sep-2000 NGULAR INATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 1482.28 W 4704.16 77.61 57.49 52.26 14.12 1504.30 W 4777.35 78.75 58.15 53.02 14.20 1531.99 W 4869.43 80.19 58.99 53.98 14.31 1558.27 W 4956.78 81.55 59.78 54.89 14.41 1560.04 W 4962.69 81.64 59.84 54.95 14.42 1569.28 W 4993.38 82.12 60.12 55.27 14.45 1575.31W 5013.45 82.43 60.30 55.48 14.47 1584.86 W 5045.20 82.93 60.59 55.81 14.50 1588.80 W 5058.31 83.13 60.71 55.95 14.51 1590.93 W 5065.39 83.24 60.77 56.02 14.52 1617.57 W 5153.92 84.63 61.57 56.94 14.60 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert, 0 8643 MWD + IFR (Alaska) - Corrected Dat User specified 84.63 61.57 56.94 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated, Coordinates from slot ~42 and TVD from RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 5153.93 on azimuth 198.29 degrees from wellhead. Vertical section is from wellhead on azimuth 198.32 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,42 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 42 Version#1 Last revised : 21-Sep-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 1627.08 1617.00 76.25 S 73.10 W Base of Permafrost 4304.16 3578.00 1736.37 S 621.93 W Top West Sak 4981.83 4016.00 2229.54 S 777.45 W Base West Sak 5291.27 4216.00 2454.72 S 848.47 W 9-5/8" Casing Pt 5537.28 4375.00 2633.75 S 904.92 W C80(K-10) 6939.04 5281.00 3653.85 S 1226.63 W C50 7350.59 5547.00 3953.35 S 1321.08 W C40(K-5) 7808.56 5843.00 4286.63 S 1426.18 W Top HRZ 7836.41 5861.00 4306.89 S 1432.57 W C30(K-2) 8053.02 6001.00 4464.53 S 1482.28 W C20 (HRZ Midpoint) 8148.95 6063.00 4534.33 S 1504.30 W Base HRZ 8269.63 6141.00 4622.16 S 1531.99 W K-1 8384.12 6215.00 4705.48 S 1558.27 W Top Kuparuk D 8391.86 6220.00 4711.11S 1560.04 W 2DT g-May-O0 8432.08 6246.00 4740.38 S 1569.28 W Top C3 8458.39 6263.00 4759.52 S 1575.31W Top C2 8517.18 6301.00 4802.31S 1588.80 W Top C1 8526.46 6307.00 4809.06 S 1590.93 W Top B Shale 8642.50 6382.00 4893.51S 1617.57 W TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 5291.27 4216.00 2454.72S 848.47W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8148.95 6063.00 4534.33S 1504.30W 7" Casing 0.00 0.00 O.OON O.OOE 8642.50 6382.00 4893.51S 1617.57W 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2DT 9-May-O0 559149.000,5954376.000,0.0000 6220.00 4711.11S 1560.04W 3-Mar-2000 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY October 5, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 1D-42 Surface Location: 567' FNL 421' FEL Sec 23 T11N R10E, UM Target Location: 1' FSL, 1985' FEL Sec. 23, T11N, R10E, UM Bottom Hole Location: 181' FNL, 2042' FEL Sec. 26, T11N, R10E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. hereby files this Application for Permit to Drill the development well KRU 1 D-42 Nabors Rig 16e will drill and complete this well. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1D, or hauled to an approved Prudhoe or GKA Class II disposal well. This well will be a producer in the Kuparuk River formation. Though all operations will be monitored for H2S, there has not been any H2S encountered on this pad. Phillips Alaska, Inc. requests an exemption from the H2S requirements. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071) 263-4952 If you have questions or require additional information, please contact Todd Mushovic at 265- 6974 or me at 265-6434 in our Anchorage office. Siq~erely, _ ja.,Jm~~ra~ham~ Drilling Engineering Supervisor Attachments cc: KRU 1D-42 Well File GENERAL DRILL AND COMPLETE PROCEDURE EBA PRODUCER KRU 1D-42 General Procedure: 1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/- 5291 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 36.0# J-55 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut-in BOP's and pressure test casing to 2500 psi (50% of the required working pressure of the BOPE as per 20 AAC 25.030). Test for 30 minutes and record results as per AOGCC regulations. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to the base HRZ (+/- 8149' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run 7" 26.0# J-55 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient ceme~'~ will be pumped for isolation in accordance with Rule 20 AAC 25.030~ 10. Nipple up BOPE and test to 5000 psi. Record results. 11 Shut-in BOP's and pressure test casing to 3500 psi. Test for 30 minutes and record results")a~S'''~ perAOGCC regulations. .,~ , '" ~,~::;:,;":~ i"': ' 12. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 13. Drill 6-1/8" hole to well total depth (+/- 8643' MD) according to directional plan, running LWD .logging equipment as needed. Cimulate and condition hole. POOH 14. Run open hole e-line or drill pipe conveyed logs as needed. 15. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly· Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 16. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 17. Run and land 3-1/2" tubing with gas lift completion. 18. Pull landing joint· Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug· Pressure test production tree. Pull test plug. Secure well. 19. Freeze protect well. Set BPV. Release rig and turn well over to production. 20. Clean location and RDMO in preparation for coiled tubing cleanout and perforating TJM, 10/9/00, v3 ~ .i~,~?iii~,i..... ~~..~!~.;" ;...;,..":i~.. ;.'."??~'. :"~.' "~'~ :i~? ~? ~'"'.~'?~.!:!~~.'~'~.'~' .~.i'.... "~ '.". ';.'~.'' ....'......' '...~' ~.~?~...~...:' '.. :'"':' .'."~..'.~.'. '"' ... ;~ '.'.~/ ~.,:~!:.~ ~.~ ~'~:'~.? ~i .... .~.. '". .... :..";.~ .'" i.'~,..,',',. ',':."~ ."":'!'. '.;..."..~'.;" . ' .... ' .... .' "'. ~.. '". ' ." '. ' '." :~ii:'~'.':;i~;i~ ~!~E ~' ~" ..... '.' :,'; ':':...!,' '". "'"¥'", ~:':"', .... ".' .... "'~'' .... ' ' .".'" "' , ...... .' ' "'" ';'iii"i'~"~'"'!"":~'i~!'!'!-:~"!'~i'~'"'"~";:;'"$;I/:~ ~'~"~-')~'/ ;,.~;~ ~ ~.~'~ .... .........~...:.:.,.::. ~ .,'. · . ."~:! .:i.'..:i:'~ ;i~,;,.'.'?,~..~ .....:..'..';:~,~O;':" ;"'~ 'i:;~i. 'oT'¥A F' . '" ". "" ! .',',:.'. '..... :. .... / ": '""":'~ "~ iblii"at:'/~"Bank°f~'Ju~cti°n: DOwn... '"' .: : ' '" Old.' A B~c;~ " ' '" .... '" '"': '"" '" u, .... ' .... ' ....."" . ' OTpv'N ~~~~'~~..., .' ~' "i" '":" "' ' J ~'"' : '" "' ' ' ' ' ' ' .,'iiI' ! ' I I II ' I I ' ! II ' I I I ' I I I I WELL PERMIT CHECKLIST COMPANY ~"~ .~3.~ WELL NAME/.Z:> '-~-~Z.. PROGRAM: exp dev ~ FIELD & POOL 4//~/O t~)~ INIT CLASS {/ ~[/ /~'O/~--. GEOL AREA ~'. ~,~ , ADMINISTRATION 1. Permit fee attached ....................... ~. Y_~.~ N 2. Lease number appropriate ................... (~iN 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 wellbore plat included ............... (,~PN 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ II APPR DATE 12. Permit can be issued without administrative approval ...... I1..~._ /~,/~-&~Y.~ 13. Can permit be approved before 15-day wait ........... "E-'N"~'~EERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf 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, B & permafrost ....... v/ redrll ~ serv~ wellbore seg ann. disposal para req ~ UNIT# ON/OFF SHORE 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~ ~) N ~.\~. ~,~,e,t-t,,,~¥,.e..~ '[c~.~,.~-~-'~e..~ ' 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... (~ ~) N ~ ' I1' · . 25. BOPEs, do they meet regulation ......... .~ ...... (~ ~ N _ . '~ .... JJ.~J;~l~ .. DAT_E ' 26. BOPE press rating appropriate; test to SI3~O ...psig. ~-~'~_~/tC~tct 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ ~ N ~' ' ~'-'~ . 28. Work will occur without operation shutdown ........... II _~ 29. is presence of H2S gas probable ................. Y N~ Il GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... ~ ' ~ , ',' ' ' ' ~ '.~ , ' ~,~" ' ' ' I1~--- 31. Data presented on potential overpressure zones ....... II 32. Seismic analysis of shallow gas zones .......... '. '. · II APJ[R DATE 33. Seabed condition survey (if off-shore) ....... .... ~. II ,~ ~ /0,/O, DO 34. Contact name/phone for weekly progress reports [~tory only] Y N. ' ' ' ' II ANNULAR DISPOSAL35. With proper cementing records,'this plan II (A) will contain waste in a suitable receiving zone; ....... Y N. GEOLOG~ APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UICIAnnular COMMISSION: Commentsllnstrucfions: c:\msoffice\wordian~diana\checklist (rev. 02/17100) 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 {he readability of the Well History file and to Simpl. ify finding information, informatii)n of this nature is accumulated at the end' of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ld-42.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Aug 23 15:11:30 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-00232 T. MCGUIRE G. WHITLOCK 1D-42 500292297900 PHILLIPS Alaska, Inc. Sperry Sun 23-AUG-01 MWD RUN 4 AK-MM-00232 T. MCGUIRE G. WHITLOCK 23 lin 10E 567 421 .O0 105.00 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 5311.0 2ND STRING . 6.125 7.000 8188.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY. Page 1 ld-42.tapx 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4, MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR-4, AND STABILIZED LITHO- DENSITY (SLD) AND COMPENSATED NEUTRON POROSITY (SNP). 5. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE OF 11/29/2000 FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. MWD DATA CONSIDERED PDC. 6. MWD RUNS 3-4 REPRESENT THE MWD DATA FOR WELL 1D-42 WITH API# 50-029-22979-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8660' MD, 6399' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE PARAMETERS USED IN NEUTRON / POROSITY LOG CALCULATIONS: HOLE SIZE: 6.125" MUD WEIGHT: 11.4-11.6 PPG MUD FILTRATE SALINITY: 500-550 PPM CHLORIDE FORMATION WATER SALINITY: 13000 PPM CHLORIDE FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record' FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 ld-42.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5250.5 8606.0 RPX 5260.0 8613.0 RPS 5260.0 8613.0 RPM 5260.0 8613.0 RPD 5260.0 8613.0 FET 5260.0 8613.0 ROP 5306.0 8660.5 NPHI 8100.0 8558.0 NCNT 8100.0 8558.0 FCNT 8100.0 8558.5 PEF 8115.0 8574.0 DRHO 8187.0 8574.0 RHOB 8187.0 8574.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 3 5250.5 MWD 4 8100.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 ' 1 68 PEF MWD B/E 4 1 68 NPHI MWD PU 4 1 68 NCNT MWD CP30 4 1 68 FCNT MWD CP30 4 1 68 MERGE BASE 8200.0 8660.5 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 5250.5 8660.5 ROP MWD FT/H 0 712,79 GR MWD API 41.56 426.34 RPX MWD OHMM 0.5 1637.88 RPS MWD OHMM 0,34 2000 RPM MWD OHMM 0.61 2000 RPD MWD OHMM 0.88 2000 FET MWD HOUR 0,1364 66.4767 RHOB MWD G/CC 1.908 3.099 First Last Mean Nsam Reading Reading 6955.5 6821 5250.5 8660.5 166,072 6647 5306 8660.5 136.529 6712 5250.5 8606 3.69539 6707 5260 8613 6.04381 6707 5260 8613 17.5287 6707 5260 8613 36.0309 6707 5260 8613 1.79228 6707 5260 8613 2,41327 775 8187 8574 Page 3 DRHO MWD G/CC -0.19 0.267 PEF MWD B/E 4.25 18.84 NPHI MWD PU 10.64 91.1 NCNT MWD CP30 13401.3 47826.4 FCNT MWD CP30 81.6 1601.8 First Reading For Entire File .......... 5250.5 Last Reading For Entire File ........... 8660.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 ld-42.tapx 0.054191 775 8.52721 919 40.9927 917 22522.7 917 304.855 918 8187 8115 8100 8100 8100 8574 8574 8558 8558 8558.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5250.5 RPX 5260.0 RPS 5260,0 FET 5260.0 RPD 5260.0 RPM 5260.0 ROP 5306.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 8144.0 8153.5 8153.5 8153.5 8153.5 8153.5 8200.0 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): O1-NOV-O0 insite 65.44 Memory 8200.0 48.7 50.7 TOOL NUMBER 1700HWGR6 1700HWGR6 8.500 Page 4 DRILLER'S CASING DEPTH (FT): 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,..0 Name Service Order DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 ld-42.tapx LSND-LT 9.90 41.0 9.0 400 7.2 2.000 1.178 1.900 1.500 Units Size Nsam Rep Code Offset Channel 0 4 2 8 3 12 4 16 5 20 6 24 7 28 8 65.0 115.1 65.0 60.0 Name Service Unit Min Max DEPT FT 5250.5 8200 ROP MWD030 FT/H 0 712.79 GR MWD030 API 41.56 426.34 RPX MWD030 OHMM 0.91 24.16 RPS MWD030 OHMM 0,93 2000 RPM MWD030 OHMM 0.84 2000 RPD MWD030 OHMM 0,88 2000 FET MWD030 HOUR 0,1364 8.8623 Mean 6725.25 182.161 140.596 3.03214 3.7587 4.90218 29.5615 0.814532 Nsam 5900 5726 5788 5788 5788 5788 5788 5788' First Reading For Entire File .......... 5250.5 Last Reading For Entire File ........... 8200 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximtun Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Page 5 First Reading 5250.5 5306 5250.5 5260 5260 5260 5260 5260 Last Reading 8200 8200 8144 8153.5 8153.5 8153.5 8153.5 8153.5 ld-42.tapx Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1,0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT PEF GR RPD RPX RPM FET RPS RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 8100.0 8558.5 8100.0 8558.0 8100,0 8558.0 8115.0 8574.0 8146.0 8606.0 8154.0 8613,0 8154.0 8613.0 8154.0 8613.0 8154.0 8613.0 8154.0 8613,0 8187.0 8574.0 8187.0 8574.0 8200.5 8660.5 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 05-NOV-00 Insite 0.41 Memory 8660.0 47.8 49.9 TOOL NUMBER 1670/1684 1670/1684 1670/1684 1670/1684 6.125 Water Based 11.50 56~0 8.5 500 4.8 2. 100 65.0 Page 6 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 RHOB MWD040 G/CC 4 1 68 DRHOMWD040 G/CC 4 1 68 PEF MWD040 B/E 4 1 68 NPHI MWD040 PU 4 1 68 NCNT MWD040 CP30 4 1 68 FCNT MWD040 CP30 4 1 68 ld-42.tapx 1.084 1.700 3.000 Sandstone 2.65 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 44 12 48 13 52 14 132.3 65.0 60.0 Name Service Unit Min Max Mean DEPT FT 8100 8660.5 8380.25 ROP MWD040 FT/H 7.62 215.53 66,047 GR MWD040 API 41.77 277.53 110.89 RPX MWD040 OHMM 0.5 1637.88 7,87269 RPS MWD040 OHMM 0.34 2000 20.4358 RPM MWD040 OHMM 0.61 2000 97.0525 RPD MWD040 OHMM 0,93 2000 76.7758 FET MWD040 HOUR 0.6201 66.4767 7.95029 RHOB MWD040 G/CC 1.908 3.099 2.41327 DRHO MWD040 G/CC -0.19 0.267 0,054191 PEF MWD040 B/E 4.25 18.84 8.52721 NPHI MWD040 PU 10.64 91,1 40,9927 NCNT MWD040 CP30 13401.3 47826.4 22522.7 FCNT MWD040 CP30 81,6 1601.8 304.855 First Reading For Entire File .......... 8100 Last Reading FQr Entire File ........... 8660.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Nsam 1122 921 921 919 919 919 919 919 775 775 919 917 917 918 Page 7 First Reading 8100 8200.5 8146 8154 8154 8154 8154 8154 8187 8187 8115 8100 8100 8100 Last Reading 8660.5 8660.5 8606 8613 8613 8613 8613 8613 8574 8574 8574 8558 8558 8558.5 Next File Name ........... STSLIB.004 ld-42.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 8