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198-242
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U TABS 2T-215 JBR 07/01/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 2-7/8", 3-1/2", and 7" test joints. Manual Choke failed, rebuilt and passed retest. Annular failed on 2-7/8" high psi, twice on chart and two more times during trouble shooting. Changed out and passed retest. There were a few 2" valves that were used on top of test joints that also leaked and had to be swapped out. This was a long test mainly due to wellhead lockdown leaks and waiting on wellhead hands two times, Test dart also failed initially. I was made aware that this would be the 5th annular that has been changed between this rig and Nordic 4 in the last month. One of which was changed and wouldn’t pass any tests and was immediately swapped out. When asked why, I was told that the normal Hydril elements weren’t readily available when they needed to order them so they went with a different brand. I was told these were the last two of this type and Hydril elements were either ordered already or will be ASAP. This test was started on 5/11/24 and finished on 5/12/24. FSV Misc 2 each are: 3 ½” EUE FOSV and 4 ½” EUE FOSV, BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold. Test Results TEST DATA Rig Rep:Hansen/ BezoldOperator:ConocoPhillips Alaska, Inc.Operator Rep:T. Wiese/C. Erdman Rig Owner/Rig No.:Nordic 3 PTD#:1982420 DATE:5/12/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopJDH240513113902 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 30 MASP: 936 Sundry No: 324-227 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 2 P 12 PNo. Valves 1 FPManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 13-5/8"FP #1 Rams 1 2-7/8"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 1 7" Fixed P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8" 5K P HCR Valves 2 3-1/8" 5K P Kill Line Valves 1 3-1/8" 5K P Check Valve 0 NA BOP Misc 2 2-1/16" 5K P System Pressure P3050 Pressure After Closure P1800 200 PSI Attained P19 Full Pressure Attained P95 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2100 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P10 #1 Rams P3 #2 Rams P3 #3 Rams P3 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 9 FPFP 2 Manual Choke failed Annular failed 5th annular that has been changed between this rig and Nordic 4 in the last month test was started on 5/11/24 and finished on 5/12/24 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 4967'feet None feet true vertical 3347' feet None feet Effective Depth measured 4967'feet 3851', 4290', 4325'feet true vertical 3347'feet 2734' 2966', 2986'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 4010' 2812' Packers and SSSV (type, measured and true vertical depth)3851' 4290' 4325' 2734' 2966' 2986' 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: Tabasco 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: 4473' 3070' Burst Collapse Gravel Pack Liner 4321' 640' Casing 3004' 3346' 4357' 4965' 4436' 110'Conductor Surface Tie-Back String 16" 9-5/8" 72' measured TVD 7" 4" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-242 50-103-20280-00-00 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: ADL0025569 Kuparuk River Field/ Tabasco Oil Pool KRU 2T-215 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 110' N/A 324-227 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: HES ESP Feed Thru Packer: HES THT Permanent Packer: Baker Model C Gravel Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Staff RWO/CTD Engineer Slotted Liner: 4434-4953' Slotted Liner: 3048-3339' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:24 pm, Jun 25, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.06.25 13:46:24-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle Page 1/13 2T-215 Report Printed: 6/17/2024 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) 5/8/2024 18:00 5/8/2024 21:00 3.00 MIRU, MOVE RURD P Rig down move off well, clean up well and sign off environmental, prep for transport to 2T 0.0 0.0 5/8/2024 21:00 5/9/2024 00:00 3.00 MIRU, MOVE MOB P Mobilize rig to 2T 0.0 0.0 5/9/2024 00:00 5/9/2024 06:00 6.00 MIRU, MOVE MOB P Mobilize rig from 3R to CPF-3. Stage at CPF-2 for field change out. 0.0 0.0 5/9/2024 06:00 5/9/2024 11:30 5.50 MIRU, MOVE MOB P Cont. rig move from CPF-3 to Olikok Y. 0.0 0.0 5/9/2024 11:30 5/9/2024 16:30 5.00 MIRU, MOVE MOB P Cont. rig move from Oliktok Y to CPF-2. 0.0 0.0 5/9/2024 16:30 5/9/2024 18:00 1.50 MIRU, MOVE WAIT P Wait for changeout of field at CPF2 0.0 0.0 5/9/2024 18:00 5/9/2024 23:00 5.00 MIRU, MOVE MOB P Cont. rig move from CPF2 to 2T pad // Rig on pad 23:00 0.0 0.0 5/9/2024 23:00 5/10/2024 00:00 1.00 MIRU, MOVE OTHR P Look at prep around well, soft spot in pad where thawed creating low spot mobilize roads and pads to level out, hang tree in cellar along with DSA's 0.0 0.0 5/10/2024 00:00 5/10/2024 01:00 1.00 MIRU, MOVE OTHR P Hang new contingency 3 1/8" tree in cellar, hang DSA's. Two trees on location. Base Plan is to re-use old 4 1/16" tree currently on the well. 0.0 0.0 5/10/2024 01:00 5/10/2024 05:00 4.00 MIRU, MOVE WAIT T Wait for roads and pads to fix in front of well, pad not level in for front of rig and large soft spot developed due to warm temps // Change out lower rams to 7" fixed. 0.0 0.0 5/10/2024 05:00 5/10/2024 08:00 3.00 MIRU, MOVE MOB P Lay cellar pit liner and T-mats. Lay rig mats for rig spot in. Spot sub over well. Berm in rig. 0.0 0.0 5/10/2024 08:00 5/10/2024 10:00 2.00 MIRU, MOVE MOB P MIRU. Spot support equipment. Mud Shack, Cuttings Tank. Complete rig acceptance checklist. Take on 8.6# SW. Accept rig at 10:00AM. 0.0 0.0 5/10/2024 10:00 5/10/2024 17:30 7.50 MIRU, WELCTL RURD P Obtain initial pressures. T/IA = 100 / 80 psi. Spot in bleed tank. Bled IA to 0 psi. Spot in Kill Tank and Highline trailer. R/U circ manifold. Move tiger and open top tanks around to Off Driller side to make room for Slickline and rig prep work on 2T-203. R/U hardline to tanks. Spot in Vac Trucks. 0.0 0.0 5/10/2024 17:30 5/10/2024 21:00 3.50 MIRU, WELCTL KLWL P PJSM. PT hardline to tanks to 2,500 psi. Bleed free gas from Tubing and IA. Line up to circulate down IA taking returns from Tubing. Come online and pump 242 BBLS 8.6# Seawater down IA taking tubing returns to tanks. SD Pumps. Bullhead 60 bbls 8.6# Seawater down Tubing into formation. Injection rate 2 bpm @ 555 psi 0.0 0.0 5/10/2024 21:00 5/10/2024 22:00 1.00 MIRU, WELCTL OWFF P R/U 600 psi gauge manifold to Tubing and IA. Monitor pressures. OWFF for 30-minutes. Charged up formation, wait for it to relax 0.0 0.0 5/10/2024 22:00 5/10/2024 22:30 0.50 MIRU, WELCTL RURD P Rig down circulating hoses 0.0 0.0 5/10/2024 22:30 5/10/2024 23:00 0.50 MIRU, WELCTL MPSP P Set BPV, test 1000 psi 10 min . unable to get full pressure test on BPV, rolling 500 psi test, confirmed barrier 0.0 0.0 5/10/2024 23:00 5/11/2024 00:00 1.00 MIRU, WHDBOP NUND P Nipple down Production tree 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 2/13 2T-215 Report Printed: 6/17/2024 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) 5/11/2024 00:00 5/11/2024 01:00 1.00 MIRU, WHDBOP NUND P Nipple down tree, inspect hanger threads, install test dart in BPV 0.0 0.0 5/11/2024 01:00 5/11/2024 06:00 5.00 MIRU, WHDBOP NUND P Nipple up BOPs, install flow riser, grease valves for bop test, obtain RKB's for Nordic 3 0.0 0.0 5/11/2024 06:00 5/11/2024 10:00 4.00 MIRU, WHDBOP RURD P Rig up test equipment for testing BOPs, flood stack and surface lines. Crew change out. 0.0 0.0 5/11/2024 10:00 5/11/2024 13:00 3.00 MIRU, WHDBOP BOPE T Attempt shell test. Found gland nut leaking. Attempt to tighten. Still leaking. FMC hand on location. Function LDS/GN. Re-tighten. Found another GN leaking. Tighten. Re-test. Found hydraulic HCR drip. Isolated. Cont. to troubleshoot leaks. Run 7" donut test joint. Test below LPR. Failed. Pull test dart. Flush BPV w/ 5 bbls SW. Re-set and re-test test dart w/ new seal. Passed. 0.0 0.0 5/11/2024 13:00 5/11/2024 13:30 0.50 MIRU, WHDBOP BOPE P Rig up testing equipment. Re-attempt shell test. Obtain passing shell test. RU ESP dance floor hooch and stage genset/heater off critical path. Use charge pump to fill IA w/ SW to surface. Monitor for 30-min. Re-fill to estimate fluid loss rate. Estimate 8 bbls/hour static loss rate. Perform IA hole fill every hour w/ charge pump. 0.0 0.0 5/11/2024 13:30 5/11/2024 16:00 2.50 MIRU, WHDBOP BOPE P Begin initial BOP test. Obtain 2 passing tests against the blinds and LDS gland nut began leaking. Call out FMC to tighten or repair as needed. 0.0 0.0 5/11/2024 16:00 5/11/2024 20:00 4.00 MIRU, WHDBOP BOPE T Wait on FMC to arrived back on location to tighten/repair LDS. Finish processing 150 Joints of 3 1/2" IF DP while waiting. Complete Koomey Drawdown test while waiting for FMC to repair LDS GN. 0.0 0.0 5/11/2024 20:00 5/12/2024 00:00 4.00 MIRU, WHDBOP BOPE P Continue initial BOP test to 250/2500 psi. Start Nordic BOP 10-hr test duration here. 0.0 0.0 5/12/2024 00:00 5/12/2024 03:30 3.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE all componants at 250/2500 PSI for 5 Min each, UVBR's w/ 2-7/8" and 3 1/2" test jts Test blinds rams. Test LPR (Fixed 7" Rams) and Annular w/ 7" & 2-7/8" test jt 250/2500 5min each Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1800 PSI, 200 PSI attained =19 sec, full recovery attained =95 sec. UVBR's= 3 sec, LPRs= 3 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2100 PSI. Test gas detectors, PVT and flow show. Witnessed by AOGCC rep Josh Hunt 0.0 0.0 5/12/2024 03:30 5/12/2024 06:00 2.50 MIRU, WHDBOP RGRP T Change out annular. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 3/13 2T-215 Report Printed: 6/17/2024 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) 5/12/2024 06:00 5/12/2024 19:00 13.00 MIRU, WHDBOP BOPE T Continue to replace bag. Retest annular w/ 2 7/8" and 7" test joints. Complete BOP test. Nordic BOP test start: 5/11 @ 20:00. Contractor is provided 10 hours to complete BOP testing before going on Code 8. 10 hour duration ended @ 5/12 @ 06:00. Code 8 from 06:00 until finish BOP test. 0.0 0.0 5/12/2024 19:00 5/12/2024 19:30 0.50 COMPZN, RPCOMP RURD P Blowdown lines. R/D testing equipment. Drain Stack. 0.0 0.0 5/12/2024 19:30 5/12/2024 20:00 0.50 COMPZN, RPCOMP MPSP P Pull test dart and BPV. OWFF for 10- min 0.0 0.0 5/12/2024 20:00 5/12/2024 21:00 1.00 COMPZN, RPCOMP RURD P Prep floor to pull 3 1/2" ESP completions. Hang Sheave. Ensure cutters are on rig floor. 0.0 0.0 5/12/2024 21:00 5/12/2024 21:45 0.75 COMPZN, RPCOMP THGR P MU 5" RH Acme FMC Landing Joint w/ CPAI XO#527 and a 3 1/2" IF pup to clear the rig floor. Screw in TD. Set 10K down on Hanger. BOLDS.. Pull 135K to release 9 5/8" Packer. Space out landing joint across the bag. Allow element to relax 15min for pumping 0.0 4,255.0 5/12/2024 21:45 5/13/2024 00:00 2.25 COMPZN, RPCOMP CIRC P Pump 30 BBL Deepclean pill. Chase pill w/ 450 bbls of 8.6# SW until returns are clean. Bring pump rate up to 2 BPM @ 650 psi. Monitor returns at tanks. No returns, Mix up second deep clean pill Attempt to reverse circulate, 1 bpm @ 626 psi Returns @ tank , continue to circulate IA volume ensure clean. Estimate dynamic loss rate using tank level sensors. Pump rate 33 spm ( 2 bpm ) @ 982 psi 4,255.0 4,255.0 5/13/2024 00:00 5/13/2024 01:00 1.00 COMPZN, RPCOMP CIRC P Complete circulating // 33 spm @ 982 psi // Pump 300 bbls clean fluid in and out 8.6# // Unable to get good circulation rate believe packer still sealed due to not being able to pick hanger to floor 4,255.0 4,255.0 5/13/2024 01:00 5/13/2024 01:30 0.50 COMPZN, RPCOMP OWFF P Observe well for flow no flow // Blow down tiger tank line 4,255.0 4,255.0 5/13/2024 01:30 5/13/2024 02:30 1.00 COMPZN, RPCOMP THGR P Lay down landing jt and tubing hanger, rig up Summit spooling unit to ESP cable Discharge port orientation directly to Offdriller side of rig ( Lined up with tubing discharge valves on tree 4,255.0 4,230.0 5/13/2024 02:30 5/13/2024 03:00 0.50 COMPZN, RPCOMP PULL P Pull and lay down 3.5" ESP completion 1 jt slight drag on element 6K move down stack wt on elements, pick up clean 70K to collar // Up wt after circulation 70K // Total clamps recovered= 1 Cross collar // Cut esp cable at clamp lower into well to space out jt in pipe rams // Close in UPR to circulate out packer gas. 4,230.0 4,186.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 4/13 2T-215 Report Printed: 6/17/2024 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) 5/13/2024 03:00 5/13/2024 13:00 10.00 COMPZN, RPCOMP CIRC P Circulate IA bottoms up @ 3 bpm @ 450 psi good returns observed at surface. Slow rate to 1 BPM @ 273 psi. Est. 33% loss rate (20 BPH). Circ out residual packer gas to tiger. At 08:00 see dirty returns with minimal packer gas. Swap to Open Top. Increase pump rate to 2 BPM @ 310 and 3 BPM @ 560 psi. Pushing fluid away. Returns dropped off. Reduce rate to 1 BPM @ 160 psi to maintain 80% returns. Cont. circ out until see clean 8.6# SW back. Circ a total of 680 bbls before seeing clean returns. SD Pumps. Blowdown lines to tanks. 4,186.0 4,186.0 5/13/2024 13:00 5/13/2024 13:30 0.50 COMPZN, RPCOMP OWFF P SD Pumps. Monitor pressures for 30- min. T/IA = 0 psi / 0 psi. On active trip tank. Static loss rate of approx. 4 BPH. 4,186.0 4,186.0 5/13/2024 13:30 5/13/2024 18:00 4.50 COMPZN, RPCOMP PULL P Pull to cut ESP cable. PUW = 71K. L/D tubing and clamps until have enough ESP cable to rig up to ESP spooler. Pull 3 1/2" ESP completions from 4,186' to 3,186'. 4,186.0 3,186.0 5/13/2024 18:00 5/13/2024 20:30 2.50 COMPZN, RPCOMP PULL P Saw 5K over pull @ 3,186' (8' into Joint #96, Jewelry depths; GLM @ 1,045' / Packer @ 1,164'). Cut ESP cable. Re- run Joint #97. Space out clean joint across stack. Crew C/O. Mix 40 bbl pill (X2) w/ 1% Lube776. Displace down backside to lube up to approx. 1,000'. 3,186.0 3,186.0 5/13/2024 20:30 5/13/2024 23:00 2.50 COMPZN, RPCOMP PULL P Cont. to pull 3 1/2" Completions F/ 3,186' to 2,639'. PUW = 55K. At Joint #82 (GLM is @ approx. 700' and Packer @ approx 800'). Cont. to watch for overpulls as jewelry crosses 9 5/8" tight spot. Saw 5K overpulls @ 2,798' and 2,533' (suspect packer hanging up at collars). Pulls clean after slacking off. Pulled 7K over @ 2,397' (Joint #71). Unable to work back down w/ string weight. Screw in TD. Work pipe free 3,186.0 2,400.0 5/13/2024 23:00 5/14/2024 00:00 1.00 COMPZN, RPCOMP OTHR P Work pipe free moving down // Secure ESP cable prep for run in hole with GS 2,400.0 2,400.0 5/14/2024 00:00 5/14/2024 01:00 1.00 COMPZN, RPCOMP CLEN P Clean up floor prep for running in hole with singles // Clean up floor from pulling ESP completion 2,400.0 2,400.0 5/14/2024 01:00 5/14/2024 10:00 9.00 COMPZN, RPCOMP PUTB P Install GS and deployment sleeve // Single in hole drop off tubing // Work pipe through tight spots ( packer depth 400' to 800' ) // Tag packer @ 4327' // Pump off string leaving bait sub @ 1932' 2,400.0 4,327.0 5/14/2024 10:00 5/14/2024 12:00 2.00 COMPZN, RPCOMP TRIP P TOOH for IBP 1,932.0 10.0 5/14/2024 12:00 5/14/2024 12:30 0.50 COMPZN, RPCOMP BHAH P Break off GS spear prep for plug bha 10.0 0.0 5/14/2024 12:30 5/14/2024 13:00 0.50 COMPZN, RPCOMP CLEN P Clean rig floor prep for plug run 0.0 0.0 5/14/2024 13:00 5/14/2024 14:45 1.75 COMPZN, RPCOMP TRIP P Pick up IBP // TIH to set depth @ 1920' 0.0 1,920.0 5/14/2024 14:45 5/14/2024 18:00 3.25 COMPZN, RPCOMP MPSP P Set IBP @ 1921' // Stage up 1200 psi 1800 psi 1950 psi // setting tool shear 1950 psi // set down 13k pick up 2k over string wt good set // Rig up test equipment test IBP 1000 psi 10 min 1,920.0 1,921.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 5/13 2T-215 Report Printed: 6/17/2024 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) 5/14/2024 18:00 5/14/2024 19:00 1.00 COMPZN, RPCOMP SLPC P Slip and cut drill line, 66' trim 1,921.0 0.0 5/14/2024 19:00 5/14/2024 19:30 0.50 COMPZN, RPCOMP TRIP P TOOH for mule shoe 1,921.0 0.0 5/14/2024 19:30 5/14/2024 20:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #2 IBP setting tool. M/U mule shoe to DP 0.0 0.0 5/14/2024 20:30 5/14/2024 21:30 1.00 COMPZN, RPCOMP TRIP P P/U 19 stands and working single 0.0 1,793.0 5/14/2024 21:30 5/14/2024 22:30 1.00 COMPZN, RPCOMP RURD P Rig up sand pump plumbing and sand dump platform. Get sand to floor 1,793.0 1,793.0 5/14/2024 22:30 5/15/2024 00:00 1.50 COMPZN, RPCOMP OTHR P Dump 50 sacks all purpose sand 1,793.0 1,793.0 5/15/2024 00:00 5/15/2024 14:00 14.00 COMPZN, RPCOMP OTHR P Continue dumping sand // Tag sand @ 1873' 1,793.0 1,876.0 5/15/2024 14:00 5/15/2024 16:00 2.00 COMPZN, RPCOMP TRIP P Trip out of hole for caliper // Lay down mule shoe, Clear and clean rig floor 1,876.0 0.0 5/15/2024 16:00 5/15/2024 17:00 1.00 COMPZN, RPCOMP ELNE P PJSM // Rig up E-line and caliper // 0.0 0.0 5/15/2024 17:00 5/15/2024 18:30 1.50 COMPZN, RPCOMP ELOG P RIH w/AK eline & Reed cased hole caliper to 1800' Log to surface. R/D Eline equipment 0.0 0.0 5/15/2024 18:30 5/15/2024 20:00 1.50 COMPZN, RPCOMP NUND P ND BOPE stack 0.0 0.0 5/15/2024 20:00 5/15/2024 21:30 1.50 COMPZN, RPCOMP NUND P ND Tubing / Casing head, ND 4 1/16 tubing valves, ND 2 1/8" IA valve 0.0 0.0 5/15/2024 21:30 5/15/2024 22:00 0.50 COMPZN, RPCOMP NUND P Remove old wellhead equipment from cellar 0.0 0.0 5/15/2024 22:00 5/15/2024 23:00 1.00 COMPZN, RPCOMP NUND P Nipple up casing head. Nipple up 2 1/16 valve to IA. Set stack down on casing head to energize seals. Run in LDS's. Test void 1000PSI/10 minutes 0.0 0.0 5/15/2024 23:00 5/16/2024 00:00 1.00 COMPZN, RPCOMP NUND P Nipple up BOPE 0.0 0.0 5/16/2024 00:00 5/16/2024 01:30 1.50 COMPZN, RPCOMP NUND P Continue NU BOPE. NU riser and air boot 0.0 0.0 5/16/2024 01:30 5/16/2024 02:00 0.50 COMPZN, RPCOMP WWSP P Set 10 3/4" test plug 0.0 0.0 5/16/2024 02:00 5/16/2024 03:30 1.50 COMPZN, RPCOMP WWSP P Fill stack, Purge air, test flange break, Blind rams, kill HCR to 2500 PSI/ / 5 min, IA open. Pull test plug 0.0 0.0 5/16/2024 03:30 5/16/2024 05:30 2.00 COMPZN, RPCOMP BHAH P M/U BHA #4, 8.5 Taper mill, flex joint, 8.5" string reamer. Jars, DC's 0.0 0.0 5/16/2024 05:30 5/16/2024 07:00 1.50 COMPZN, RPCOMP TRIP P TIH drifting down to 370' 0.0 370.0 5/16/2024 07:00 5/16/2024 11:00 4.00 COMPZN, RPCOMP MILL P Pump 5 bpm @ 90 psi // Rot 61 rpm @ 3600 tq // Mill F/ 370' Tq 4125 @ 388' Tq 4500 @ 399' Tq 4900 @ 400' Several passes from 390' to 410' , drill pipe show torque but no weight on bit, time mill through area. Work tight spots down to 497' drift clean with 8.5" mills 370.0 497.0 5/16/2024 11:00 5/16/2024 12:30 1.50 COMPZN, RPCOMP TRIP P Dry drift F/ 450' T/370'no overpulls TOOH for 8.625" mills 497.0 225.0 5/16/2024 12:30 5/16/2024 13:30 1.00 COMPZN, RPCOMP BHAH P Break down milling BHA 8.5" 225.0 0.0 5/16/2024 13:30 5/16/2024 15:00 1.50 COMPZN, RPCOMP BHAH P Pick up BHA 4 8.625" mills 0.0 200.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 6/13 2T-215 Report Printed: 6/17/2024 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) 5/16/2024 15:00 5/16/2024 16:00 1.00 COMPZN, RPCOMP TRIP P TIH to 370' 200.0 370.0 5/16/2024 16:00 5/16/2024 20:00 4.00 COMPZN, RPCOMP MILL P Mill tight spot in casing F/ 370' T/ 390', 60 RPM, Free Tq. 5.5K, 8 BPM 210 PSI. 2 3K WOB. Ream three times. Dry drift with 4K drag Blow down top drive 370.0 397.0 5/16/2024 20:00 5/16/2024 20:30 0.50 COMPZN, RPCOMP TRIP P Continue in well, 397.0 1,171.0 5/16/2024 20:30 5/16/2024 21:00 0.50 COMPZN, RPCOMP MILL P Set dowm, PUH, KU mill 1171 to 1200', 60 RPM. 3.8K free Tq. 8 BPM @ 400 PSI. Ream through 3 times. Dry drift 4K drag. Rotate to 1300' clean. Blow down top drive. 1,171.0 1,300.0 5/16/2024 21:00 5/16/2024 22:00 1.00 COMPZN, RPCOMP TRIP P POOH 1300 to BHA 1,300.0 218.0 5/16/2024 22:00 5/16/2024 22:30 0.50 COMPZN, RPCOMP BHAH P Stand back 2 stands 4 3/4" collars, 8.625 reamers 218.0 0.0 5/16/2024 22:30 5/17/2024 00:00 1.50 COMPZN, RPCOMP PRTS P PT 9 5/8" casing to 1000PSI Pump @ 2 BPM for 8 BBls. Un able to build pressure beyond 160 PSI. Shut down pump. Immidiate bleed off. Monitor well for fluid loss rate @ 3 BPH. Consult town on plan forward 0.0 0.0 5/17/2024 00:00 5/17/2024 01:00 1.00 COMPZN, RPCOMP BHAH P Load rest of collars on location, M/U BHA #6 storm packer 0.0 280.0 5/17/2024 01:00 5/17/2024 03:30 2.50 COMPZN, RPCOMP TRIP P Trip in hole, P/U Storm packer @ 1317', Continue in to 1801', PUW=65K, SOW=65K, Set packer 494' COE. Pump down string to 1000PSI. Bleed off slowly with fluid rising in stack. Seeping by packer element. Line up down kill line 1.5 BPM @161 PSI. Leak @ ~ 370 to 390' area 280.0 1,801.0 5/17/2024 03:30 5/17/2024 05:00 1.50 COMPZN, RPCOMP TRIP P Release storm packer, Start out of hole, Packer clean up through 400 to 370 1,801.0 50.0 5/17/2024 05:00 5/17/2024 05:30 0.50 COMPZN, RPCOMP BHAH P Lay down packer BHA 50.0 0.0 5/17/2024 05:30 5/17/2024 06:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 5/17/2024 06:00 5/17/2024 07:30 1.50 COMPZN, RPCOMP BHAH P Pick up and run RCJB clean out assembly 0.0 60.0 5/17/2024 07:30 5/17/2024 09:00 1.50 COMPZN, RPCOMP BHAH P Run drill collars in hole 60.0 221.0 5/17/2024 09:00 5/17/2024 12:00 3.00 COMPZN, RPCOMP TRIP P Trip in hole to top of sand 221.0 1,873.0 5/17/2024 12:00 5/17/2024 13:30 1.50 COMPZN, RPCOMP WASH P Pump 9 bpm @ 3255 psi wash in hole T/ 1909' // Circ B/u // No losses while circulating 1,873.0 1,909.0 5/17/2024 13:30 5/17/2024 17:30 4.00 COMPZN, RPCOMP TRIP P Flow check well // No Flow // TOOH to empty basket 1,909.0 225.0 5/17/2024 17:30 5/17/2024 18:30 1.00 COMPZN, RPCOMP BHAH P Lay down and inspect RCJB 225.0 0.0 5/17/2024 18:30 5/17/2024 19:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 to retrieve IBP 0.0 212.0 5/17/2024 19:00 5/17/2024 20:00 1.00 COMPZN, RPCOMP TRIP P Trip in well, to 1871 212.0 1,871.0 5/17/2024 20:00 5/17/2024 22:00 2.00 COMPZN, RPCOMP FISH P KU, Pump online 2 BPM @ 67 PSI, Set down @ 1909. No latch, PUH bring rate up to 9 BPM @ 825 PSI, Set back down pumping. S/D pump. get 10K overpiull. Rotate 9 times. Let element relax 30 Min. Loss rate 8 BPM 1,871.0 1,909.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 7/13 2T-215 Report Printed: 6/17/2024 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) 5/17/2024 22:00 5/17/2024 23:00 1.00 COMPZN, RPCOMP TRIP P POOH from 1918' to 212, PUW=65K 1,909.0 212.0 5/17/2024 23:00 5/18/2024 00:00 1.00 COMPZN, RPCOMP BHAH P At BHA, Recovered IBP, Lay down retrieaval tool 212.0 0.0 5/18/2024 00:00 5/18/2024 01:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #8, overshot, to retrieve old ESP completion. 0.0 209.0 5/18/2024 01:00 5/18/2024 02:00 1.00 COMPZN, RPCOMP TRIP P Trip in hole, BHA #8 209.0 1,875.0 5/18/2024 02:00 5/18/2024 02:30 0.50 COMPZN, RPCOMP TRIP P 1875, KU, PUW=82K, SOW=55K, 2 BPM @ 61 PSI. Get returns, Ease in hole. 5 RPM. Take weight. S/D pump and rotary Set down. Pull up hole. PUW=100K. Dragging Had to work 1898 to 1871' 2 BPM. On elevators @ 1871 1,875.0 1,932.0 5/18/2024 02:30 5/18/2024 05:30 3.00 COMPZN, RPCOMP TRIP P Continue out of well 1,871.0 100.0 5/18/2024 05:30 5/18/2024 07:00 1.50 COMPZN, RPCOMP BHAH P Rack back drill collars // Disengage overshot // 100.0 2,000.0 5/18/2024 07:00 5/18/2024 08:00 1.00 COMPZN, RPCOMP RURD P Rig up floor to pull tubing 2,000.0 2,000.0 5/18/2024 08:00 5/18/2024 11:00 3.00 COMPZN, RPCOMP PULL P Pull 3.5" ESP completion spooling wire up on summit spooler // Lay down packer, no visible damage // clamp esp cable together for pull 2,000.0 1,500.0 5/18/2024 11:00 5/18/2024 11:30 0.50 COMPZN, RPCOMP SVRG P Service chain on skate, replace master link 1,500.0 1,500.0 5/18/2024 11:30 5/18/2024 18:00 6.50 COMPZN, RPCOMP PULL P Continue to pull esp completion. Lay down guage and ESP Assembly 1,500.0 0.0 5/18/2024 18:00 5/18/2024 22:00 4.00 COMPZN, RPCOMP BHAH P Clear and clean rig floor, Prep floor for 2 7/8" pipe run. C/O elevators, Prep power tongs 0.0 0.0 5/18/2024 22:00 5/19/2024 00:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #9 Fill clean out with VAX tool, 1047.71 0.0 0.0 5/19/2024 00:00 5/19/2024 03:00 3.00 COMPZN, RPCOMP BHAH P BHA 9 in well with VAX tool 0.0 1,047.7 5/19/2024 03:00 5/19/2024 09:30 6.50 COMPZN, RPCOMP TRIP P Rig floor back to 3 1/2 DP, P/U DP singles to 3000', TIH on stands to 4287' 1,047.7 4,287.0 5/19/2024 09:30 5/19/2024 15:00 5.50 COMPZN, RPCOMP WASH P Wash from 4287' // Pump 5 bbls/min @ 1000 psi // Up wt 85K Dn wt 74K // Work pipe in hole T/ 4320' stack out on packer pick up work down again drift into packer // Continue to vac T/ 4800' unable to proceed further 4,287.0 4,800.0 5/19/2024 15:00 5/19/2024 18:00 3.00 COMPZN, RPCOMP TRIP P TOOH racking stands in derrick 4,800.0 800.0 5/19/2024 18:00 5/19/2024 23:00 5.00 COMPZN, RPCOMP BHAH P Lay down BHA 7" Vax tool, 7" joint, Jars // 26 jts 2-7/8" tubing, VAX tool full. Anticipate 2 7/8" to be full to check valves. Little sand in 2 7/8" pipe. Pull wet 800.0 0.0 5/19/2024 23:00 5/20/2024 00:00 1.00 COMPZN, RPCOMP BOPE P Function test BOPs. Make repairs to skate 0.0 0.0 5/20/2024 00:00 5/20/2024 01:00 1.00 COMPZN, RPCOMP BHAH P C/O floor equipment for DP ops / Repair skate buggy chain attachment point 0.0 0.0 5/20/2024 01:00 5/20/2024 02:00 1.00 COMPZN, RPCOMP SVRG P Service Rig - Spinners tongs, EZ torque equipment 225.0 0.0 5/20/2024 02:00 5/20/2024 03:00 1.00 COMPZN, RPCOMP BHAH P PJSM, P/U BHA #10. Tapered 8.5" mill, Flex joint, 8.5" string reamer 0.0 225.0 5/20/2024 03:00 5/20/2024 08:00 5.00 COMPZN, RPCOMP TRIP P Trip in well, BHA #10 // Drift to 4300' // Circulate sweep SxS to clean hole 225.0 4,300.0 5/20/2024 08:00 5/20/2024 10:30 2.50 COMPZN, RPCOMP TRIP P Blow down TD // POOH for casing run 4,300.0 225.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 8/13 2T-215 Report Printed: 6/17/2024 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) 5/20/2024 10:30 5/20/2024 11:45 1.25 COMPZN, RPCOMP BHAH P Lay down BHA # 10 225.0 0.0 5/20/2024 11:45 5/20/2024 14:15 2.50 COMPZN, RPCOMP CLEN P Clean up rig floor // move out BOT tools from shed // Modify Mule Shoe to 29' // Bring completion in shed 0.0 0.0 5/20/2024 14:15 5/20/2024 15:45 1.50 COMPZN, RPCOMP CLEN P Pick up bop flush tool, flush bop's from milling activities 0.0 0.0 5/20/2024 15:45 5/20/2024 18:00 2.25 COMPZN, CASING PUTB P Rig up run liner. P/U Mule shoe and X- Nipplke 0.0 40.4 5/20/2024 18:00 5/20/2024 20:00 2.00 COMPZN, CASING PUTB P Crew change out, PJSM run completion, C/O Elevators to 5 1/2" run 5 1/2" Jewelry. C/O elevators and floor equipment to 7 " 40.4 138.0 5/20/2024 20:00 5/21/2024 00:00 4.00 COMPZN, CASING PUTB P Run 7" liner per procedure. Cementralizer every other joint, Best of life 2000 pipe dope. 138.0 2,945.0 5/21/2024 00:00 5/21/2024 03:00 3.00 COMPZN, CASING PUTB P Continue to make up 7" tie back liner. Tag @ 4357, Jt 105. P/U and retag 4357. PUW=115, SOW=95K. Lay down 105,104,103. M/U 33.32' Pups 15.45, 10.08, 7.79. P/U Jt 103. Go to make up hanger FMC does not have correct equipment 2,945.0 4,357.0 5/21/2024 03:00 5/21/2024 06:00 3.00 COMPZN, CASING PUTB T Miss match tubing hanger landing joint 4,357.0 4,318.0 5/21/2024 06:00 5/21/2024 07:00 1.00 COMPZN, CASING THGR P Make up langing jt and tubing hanger // Land casing on depth 4,357.0 4,357.0 5/21/2024 07:00 5/21/2024 11:00 4.00 COMPZN, CASING PACK P Drop ball and rod // 3.813" x-nipple // Rig up pump in subs // pump 4bbls / min unable to get ball to seat // rig up slick line to push ball and rod to bottom // 4,357.0 4,357.0 5/21/2024 11:00 5/21/2024 12:00 1.00 COMPZN, CASING PACK P Pressure up on packer 3600 psi // Losses stopped indicated packer set // Good pressure test 10 min 4,357.0 4,357.0 5/21/2024 12:00 5/21/2024 13:00 1.00 COMPZN, CASING RURD P Rig down packer setting lines and test chart 4,357.0 4,357.0 5/21/2024 13:00 5/21/2024 14:00 1.00 COMPZN, CASING SLKL P Pull ball and rod // Pull RHC // Rig down slick line 4,357.0 4,357.0 5/21/2024 14:00 5/21/2024 15:00 1.00 COMPZN, CASING THGR P Set packoffs in tubing hanger 4,357.0 4,357.0 5/21/2024 15:00 5/21/2024 16:00 1.00 COMPZN, CEMENT CLEN P Clean and clear rig floor for picking up BHA // Lay down 0.0 0.0 5/21/2024 16:00 5/21/2024 17:30 1.50 COMPZN, CEMENT BHAH P Pick up NCS BHA #11 0.0 25.0 5/21/2024 17:30 5/21/2024 21:45 4.25 COMPZN, CEMENT TRIP P Trip in hole with NCS tools tagged up @ 4223', PUW=80K, SOW=74K. Set 10K down. P/U locate reducer bushing in tie back string @ 4215'. Attempt T/ run through NCS HP2 Multi Cycle Frac Sleeve repeatedly. Could not pas 4223'. SFC tool functioning correctly. P/U T/ 4219'. Spot trucks and spread contamination pill around into tanks. 25.0 4,219.0 5/21/2024 21:45 5/21/2024 22:15 0.50 COMPZN, CEMENT CIRC P Close annular bullhead 50 Bbls staging pumps up T/ 5 BPM, 1110 PSI. Attempt to flush Frac sleeve. 4,219.0 4,219.0 5/21/2024 22:15 5/21/2024 23:15 1.00 COMPZN, CEMENT TRIP P Attemp to RIH past frac sleeve mutiple times. Could not pass 4223'. Identify 2 7/8" PH-6 pin x 3 1/2" XO and tool joints OD to large to pass rhrough reducer bushing. Desicion made to pull and reconfigure w/ 2 joints of 2 7/8" 511 tubing. 4,219.0 4,219.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 9/13 2T-215 Report Printed: 6/17/2024 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) 5/21/2024 23:15 5/22/2024 00:00 0.75 COMPZN, CEMENT TRIP P POOH F/ 4219' T/ 1000'. PUW=80K. 4,219.0 1,000.0 5/22/2024 00:00 5/22/2024 00:30 0.50 COMPZN, CEMENT TRIP P POOH F/ 1000' T/ 22' PUW=40K. 1,000.0 22.0 5/22/2024 00:30 5/22/2024 01:15 0.75 COMPZN, CEMENT BHAH P L/D BHA #11 NCS. Remove XO. 22.0 0.0 5/22/2024 01:15 5/22/2024 02:15 1.00 COMPZN, CEMENT SVRG P Service rig. Work on service loop. Mobilize 2 7/8" slips & elevators T/ RF. Mobilize 2" Stub acme x 2 3/8" Pac XO. 0.0 0.0 5/22/2024 02:15 5/22/2024 02:45 0.50 COMPZN, CEMENT RURD P R/U tubing handling equipment. 0.0 0.0 5/22/2024 02:45 5/22/2024 03:45 1.00 COMPZN, CEMENT BHAH P M/U BHA #12 NCS w/ 2 joints of Hyd 511 T/ 77' 0.0 77.0 5/22/2024 03:45 5/22/2024 04:15 0.50 COMPZN, CEMENT RURD P R/D tubing handling equipment. 77.0 77.0 5/22/2024 04:15 5/22/2024 07:15 3.00 COMPZN, CEMENT TRIP P RIH F/ 77' T/ 4200' // Up wt 80K Dn wt 75K 77.0 4,200.0 5/22/2024 07:15 5/22/2024 08:15 1.00 COMPZN, CEMENT OTHR P Locate cement sleeve with NCS tool @ 4223' // Lay down single jt of drill pipe space out with 15' pup jt of 3.5" IF drill pipe 4,200.0 4,223.0 5/22/2024 08:15 5/22/2024 10:00 1.75 COMPZN, CEMENT CIRC P Pressure test NCS pack off 500 psi // Close Annular pressure up 850psi shift open sleeve confirm flow out OA to tiger tank // Circulate 150 bbls 130° water out OA to warm up well for cementing operations // Pump 3 bbls/min @ 415 psi w/ full returns according to tiger tank 4,223.0 4,223.0 5/22/2024 10:00 5/22/2024 12:00 2.00 COMPZN, CEMENT CMNT P PT lines 4000psi line up down drill pipe taking returns up "OA" to open top tank o Spacer 10 bbls Fresh water with red dye o Lead 110 bbls of 15.3ppg with LCM o Tail 100 bbls of 15.3ppg + 17 bbls contingency top out o Total Cement 210 bbls (75% excess over cased hole annular volume of 120 bbls) + 17 bbls top out Displace pipe with rig pump leaving 2 bbls tail in string 16 bbls Cement to cuttings tank 10 bbls 15.3# cement Total cement gone to formation est. 60 bbls 4,223.0 4,223.0 5/22/2024 12:00 5/22/2024 13:00 1.00 COMPZN, CEMENT CIRC P Pick up shift sleeve closed // Run below sleeve set packer //Reverse circulate down annulus taking returns up drill pipe // Circulate tubing volume X 2 Pump rate 6 bbls/min @ 500 psi // 12.2 to 13# circulated out of pipe PT against packer and sleeve 500psi ensure closed 4,223.0 4,223.0 5/22/2024 13:00 5/22/2024 14:00 1.00 COMPZN, CEMENT CLEN P Rig down hoses and clean floor for TOOH 4,223.0 4,220.0 5/22/2024 14:00 5/22/2024 16:00 2.00 COMPZN, RPCOMP TRIP P TOOH till 10K over block wt hanging 4,220.0 1,200.0 5/22/2024 16:00 5/22/2024 17:00 1.00 COMPZN, RPCOMP MPSP P Set storm packer @ 80' COE // 10K string wt under packer. L/D stand of DP & running tool. 1,200.0 1,280.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 10/13 2T-215 Report Printed: 6/17/2024 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) 5/22/2024 17:00 5/22/2024 17:30 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. 1,280.0 1,280.0 5/22/2024 17:30 5/22/2024 18:00 0.50 COMPZN, RPCOMP PRTS P PT storm packer T/t 1000psi 10min 1,280.0 0.0 5/22/2024 18:00 5/22/2024 18:30 0.50 COMPZN, RPCOMP RURD P R/D testing equipment. 0.0 0.0 5/22/2024 18:30 5/22/2024 20:00 1.50 COMPZN, RPCOMP NUND P N/D BOP, rack back on pedestal. 0.0 0.0 5/22/2024 20:00 5/22/2024 21:00 1.00 COMPZN, RPCOMP NUND P N/U new 11" 5K x 11 5K tubing head. 0.0 0.0 5/22/2024 21:00 5/22/2024 21:30 0.50 COMPZN, RPCOMP PRTS P PT packoff T/ 5000 psi for 15 Min. 0.0 0.0 5/22/2024 21:30 5/22/2024 22:00 0.50 COMPZN, RPCOMP MPSP P Set 11" test plug. 0.0 0.0 5/22/2024 22:00 5/23/2024 00:00 2.00 COMPZN, RPCOMP NUND P N/U 2nd IA vavle & BOP. 0.0 0.0 5/23/2024 00:00 5/23/2024 01:30 1.50 COMPZN, RPCOMP NUND P N/U BOP. Install riser, connect trip tank hose. 0.0 0.0 5/23/2024 01:30 5/23/2024 02:00 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack w/ fresh water. 0.0 0.0 5/23/2024 02:00 5/23/2024 02:45 0.75 COMPZN, RPCOMP PRTS P PT stack breaks T/ 250/2500 PSI. 0.0 0.0 5/23/2024 02:45 5/23/2024 03:15 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Suck out stack. 0.0 0.0 5/23/2024 03:15 5/23/2024 04:15 1.00 COMPZN, RPCOMP MPSP P Pull test plug. Set wear bushing. ID = 6.371" 1,200.0 1,200.0 5/23/2024 04:15 5/23/2024 04:45 0.50 COMPZN, RPCOMP CIRC P M/U BHA #13 Retrieval tool. RIH engage storm packer. Equalize and release packer. 1,200.0 1,200.0 5/23/2024 04:45 5/23/2024 05:45 1.00 COMPZN, RPCOMP TRIP P TOOH L/D storm packer. POOH T/ BHA racking stands in derrick 1,200.0 75.0 5/23/2024 05:45 5/23/2024 06:30 0.75 COMPZN, RPCOMP BHAH P Swap to tubing tongs, lay down 2 Jts 2- 7/8" along with NCS tools 75.0 0.0 5/23/2024 06:30 5/23/2024 07:00 0.50 COMPZN, RPCOMP CLEN P Clean up floor prep for E-Line operations 0.0 0.0 5/23/2024 07:00 5/23/2024 08:30 1.50 COMPZN, RPCOMP RURD P Spot e-line trucks, rig up sheave on blocks and pull up e-line // Make up tools on beaver slide 0.0 0.0 5/23/2024 08:30 5/23/2024 12:00 3.50 COMPZN, RPCOMP ELOG P Gyro interval 4218' - 3700' 0.0 0.0 5/23/2024 12:00 5/23/2024 13:00 1.00 COMPZN, RPCOMP RURD P Rig down E-line 0.0 0.0 5/23/2024 13:00 5/23/2024 15:00 2.00 COMPZN, RPCOMP BHAH P Pick up clean out BHA, 24 Jts 2-7/8" Hyd 511 tubing with 2 boot baskets T/ 943' 0.0 943.0 5/23/2024 15:00 5/23/2024 19:30 4.50 COMPZN, RPCOMP TRIP P TIH to ~4187. PUW=80K, SOW=74K. 900.0 4,187.0 5/23/2024 19:30 5/23/2024 19:45 0.25 COMPZN, RPCOMP WASH P Wash F/ 4187' T/ 4280'. Circ @ 5 BPM, 610 PSI. Wash through reducer bushing no pump pressure change. 4,187.0 4,280.0 5/23/2024 19:45 5/23/2024 20:15 0.50 COMPZN, RPCOMP TRIP P RIH F/ 4280' T/ 4537', PUW=83K, SOW=74K. Took 4 K string weight. 4,280.0 4,537.0 5/23/2024 20:15 5/23/2024 22:00 1.75 COMPZN, RPCOMP WASH P Wash through hard spot F/ 4537' T/ 4539' @ 5 BPM, 1150 PSI. Wash T/ 4650' 4,537.0 4,650.0 5/23/2024 22:00 5/23/2024 22:30 0.50 COMPZN, RPCOMP CIRC P Circ 15 Bbls hi-vis sweep around @ 5 BPM, 950 PSI. No solids at shakers. 4,650.0 4,650.0 5/23/2024 22:30 5/23/2024 22:45 0.25 COMPZN, RPCOMP TRIP P TIH F/ 4650' T/ 4811', PUW=K, SOW=xxK. Took 5K sting weight. 4,650.0 4,811.0 5/23/2024 22:45 5/23/2024 23:00 0.25 COMPZN, RPCOMP WASH P Wash in hole F/ 4811' T/ 4834', @ 5 BPM, 1250 PSI. 4,811.0 4,834.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 11/13 2T-215 Report Printed: 6/17/2024 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) 5/23/2024 23:00 5/23/2024 23:45 0.75 COMPZN, RPCOMP CIRC P Circ 15 Bbls hi-vis sweep around @ 5 BPM, 900 PSI. Trace sand back at shakers. 4,834.0 4,834.0 5/23/2024 23:45 5/24/2024 00:00 0.25 COMPZN, RPCOMP WASH P Wash in hole F/ 4834' T/ 4928', @ 5 BPM, 1600 PSI. 4,834.0 4,928.0 5/24/2024 00:00 5/24/2024 01:00 1.00 COMPZN, RPCOMP CIRC P Circ 30 Bbls hi vis sweep around @ 5 BPM, 960 PSI. Lot of sand back at shakers. 4,928.0 4,928.0 5/24/2024 01:00 5/24/2024 01:30 0.50 COMPZN, RPCOMP WASH P Wash in hole F/ 4928' T/ 4937', @ 5 BPM, 960 PSI. PUW=86K, SOW=70K. Tagged no-go @ 4937' PSI increase T/ 1300 PSI, corresponding no flow to surface. Set down 10K multiple times. P/U 3' off of no-go T/ 4933'. 4,928.0 4,933.0 5/24/2024 01:30 5/24/2024 04:00 2.50 COMPZN, RPCOMP CIRC P Circ 25 Bbls hi-vis sweep around @ 5 BPM, 950 PSI hole unloaded. Circ additional 30 Bbls hi-vis sweep around until shakers cleaned up. 4,933.0 4,933.0 5/24/2024 04:00 5/24/2024 04:30 0.50 COMPZN, RPCOMP OWFF P OWFF, B/D TD. 4,933.0 4,924.0 5/24/2024 04:30 5/24/2024 08:30 4.00 COMPZN, RPCOMP PULD P LDDP F/ 4933' T/ 945', PUW=86K. 4,924.0 945.0 5/24/2024 08:30 5/24/2024 11:30 3.00 COMPZN, RPCOMP BHAH P Lay down boot baskets and 24 jts 2-7/8" Hyd 511 tubing 945.0 0.0 5/24/2024 11:30 5/24/2024 12:30 1.00 COMPZN, RPCOMP CLEN P Clean up floor prep to run 3.5" ESP completion 0.0 0.0 5/24/2024 12:30 5/24/2024 13:00 0.50 COMPZN, RPCOMP OTHR P Pull Wear bushing 0.0 0.0 5/24/2024 13:00 5/24/2024 16:00 3.00 COMPZN, RPCOMP RURD P Rig up to run 3.5" ESP completion // Hang sheaves for Tec wire // Bring ESP tools to pipe shed and lay out // string ESP wire through sheave // Pull Tec wire through sheave for running completion // 0.0 0.0 5/24/2024 16:00 5/24/2024 19:30 3.50 COMPZN, RPCOMP PUTB P Pick up Summit pump assembly. Connect ESP cable. Perform initial ESP cable check. PTG= 6.13 G-Ohms. PTP= .6.Ohms. Fill pump assembly w/ oil. 0.0 17.0 5/24/2024 19:30 5/25/2024 00:00 4.50 COMPZN, RPCOMP PUTB P RIH w/ 3.5" 9.3#, L-80, EUE completion, F/ 17' T/ 158'. Feed through packer. Splice MLE T/ lower packer feed through. Splice upper packer feed through T/ ESP cable. Perform ESP cable check on lower & upper splices. Installing cannon clamps on each connection. EUE torque T/ 2350 Ft/lbs. Run-n-seal dope used. 17.0 158.0 5/25/2024 00:00 5/25/2024 01:00 1.00 COMPZN, RPCOMP PUTB P Finish splice upper packer feed through T/ ESP cable. Perform ESP cable check on lower & upper splices. PTG= 3.816 G-Ohms. PTP=.3.0 Ohms 158.0 158.0 5/25/2024 01:00 5/25/2024 02:00 1.00 COMPZN, RPCOMP PUTB P RIH F/ 158' T/ 213'. Opsis gauge. Connect tech wire. PT T/ 10000 PSI for 10 Min. 158.0 213.0 5/25/2024 02:00 5/25/2024 03:00 1.00 COMPZN, RPCOMP PUTB P Cont RIH F/ 213' T/ 624' SOW=45K Installing cannon clamps on each connection. EUE torque T/ 3050 Ft/lbs. Run-n-seal dope used. 213.0 624.0 5/25/2024 03:00 5/25/2024 03:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 624.0 624.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 12/13 2T-215 Report Printed: 6/17/2024 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) 5/25/2024 03:30 5/25/2024 13:30 10.00 COMPZN, RPCOMP PUTB P Cont RIH F/ 624' T/ 3967'' PUW=70K, SOW=60K Installing cannon clamps on each connection. EUE torque T/ 3050 Ft/lbs. Run-n-seal dope used. Test cable and Tec wire 50 Jts good test 3.0 Phase to phase. 4.29G PTG Test cable and Tec wire 69 Jts good test 3.0 phase to phase 4.26G PTG Test cable and Tec wire 90 Jts good test 2.4 phase to phase 4.25G PTG Test cable and Tec wire 121 Jts good test 2.8 phase to phase 4.18G PTG 624.0 3,967.0 5/25/2024 13:30 5/25/2024 15:00 1.50 COMPZN, RPCOMP THGR P Make up TC2 XO pup to landing Jt // Pick up tubing hanger // Orient to wellhead. Clamp count: 128 cross collar - dual channel. 2 half clamps - duel channel. 1 MLE spice - duel channel. 4 GLM mid joint. 4 half clamps - single channel. 1 splice clamp - duel channel. 1 motor protector. 2 seal protector. 3,967.0 3,967.0 5/25/2024 15:00 5/25/2024 18:00 3.00 COMPZN, RPCOMP PUTB P Terminate ESP & Tec wire through hanger. Connect power leads and Tec wire to tubing hanger. Test cable and Tec wire @ hanger good test 2.8 phase to phase. 3.52G PTG. 3,667.0 4,010.0 5/25/2024 18:00 5/25/2024 19:00 1.00 COMPZN, RPCOMP PUTB P RIH & land hanger w/ BTM of ESP centralizer @ 4010' ORKB. RILDS. Test cable and Tec wire @ hanger good test 2.8 phase to phase 4.49G Opsis gauge reading TGB = 1212 PSI, 64.3*, IA = 1213 PSI, 63.1* 4,010.0 4,010.0 5/25/2024 19:00 5/25/2024 20:00 1.00 COMPZN, RPCOMP RURD P R/U testing manifold for circ and PT. 4,010.0 4,010.0 5/25/2024 20:00 5/25/2024 20:30 0.50 COMPZN, RPCOMP PRTS P PT circ manifold T/ 3500 PSI. 4,010.0 4,010.0 5/25/2024 20:30 5/25/2024 21:30 1.00 COMPZN, RPCOMP CRIH P Reverse circ 131 Bbls CI seawater down IA. followed by 10 Bbls neat seawater @ 2.5 BPM, 180 PSI 4,010.0 4,010.0 5/25/2024 21:30 5/25/2024 22:00 0.50 COMPZN, RPCOMP PACK P Drop ball & rod. Set HES feed through ESP packer @ 3500 PSI. Hold for 5 Min. Bleed TBG PSI T/ 1500 4,010.0 4,010.0 5/25/2024 22:00 5/25/2024 23:00 1.00 COMPZN, RPCOMP PRTS P PT IA T/ 2500 PSI for 30 Min. Dump TBG PSI, shear out SOV. Pump down IA @ 2 BPM, 390 PSI. 4,010.0 4,010.0 5/25/2024 23:00 5/25/2024 23:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D TBG testing equipment. Pull landing joint. Send wire over sheaves to spoolers. Leaving sheave w/ rope for next well. 4,010.0 4,010.0 5/25/2024 23:30 5/25/2024 23:45 0.25 COMPZN, RPCOMP MPSP P Set HP BPV 4,010.0 4,010.0 5/25/2024 23:45 5/26/2024 00:00 0.25 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min. 4,010.0 0.0 5/26/2024 00:00 5/26/2024 01:00 1.00 COMPZN, WHDBOP RURD P Pump remaining seawater off of rig out to tiger tank. B/D, R/D testing equipment. 0.0 0.0 5/26/2024 01:00 5/26/2024 01:30 0.50 COMPZN, WHDBOP SFTY P PJSM on BWM. Cleaning pits w/ hot water w/ citric acid & deep clean. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Page 13/13 2T-215 Report Printed: 6/17/2024 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) 5/26/2024 01:30 5/26/2024 11:00 9.50 COMPZN, WHDBOP NUND P Perform BWM. C/O LPR F/ 7" T/ 2 7/8" x 5 1/2" VBR's. C/O blinds. Clean pits for filtered seawater. 0.0 0.0 5/26/2024 11:00 5/26/2024 12:30 1.50 COMPZN, WHDBOP NUND P Nipple down BOPs 0.0 0.0 5/26/2024 12:30 5/26/2024 16:00 3.50 COMPZN, WHDBOP NUND P Nipple up production tree // Terminate ESP and Tec wires // Orient tree match 209 per pad operators request 0.0 0.0 5/26/2024 16:00 5/26/2024 18:30 2.50 COMPZN, WHDBOP RURD P R/U LRS & circ equipment for freeze protect. 0.0 0.0 5/26/2024 18:30 5/26/2024 19:00 0.50 COMPZN, WHDBOP PRTS P LRS PT tree T/ 5000 PSI for 5 Min. 0.0 0.0 5/26/2024 19:00 5/26/2024 19:30 0.50 COMPZN, WHDBOP MPSP P Pull tree test dart & BPV. 0.0 0.0 5/26/2024 19:30 5/26/2024 22:00 2.50 COMPZN, WHDBOP FRZP P LRS pump 80 Bbls diesel freeze protect down IA. @ 2 BPM. ICP=300, FCP=550. U-tube well for 1 Hr. 0.0 0.0 5/26/2024 22:00 5/26/2024 23:00 1.00 COMPZN, WHDBOP RURD P B/D, R/D circ equipment. Final pressure T/IA/OA = 200/200/0. Secure tree and cellar. 0.0 0.0 5/26/2024 23:00 5/27/2024 00:00 1.00 DEMOB, MOVE DMOB P Demob. Remove auxiliary equipment from rig. R/D hard line around cellar. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/27/2024 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:2T-215 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set SOV, Set TTC-ESPCP 2T-215 6/5/2024 jhanse11 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/16/2010 ninam Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 38.0 110.0 110.0 62.58 H-40 WELDED SURFACE 9 5/8 8.70 37.4 4,472.6 3,069.5 40.00 L-80 BTC MOD Tie-Back String 7 6.28 36.4 4,357.0 3,003.7 26.00 L-80 HYD563 GRAVEL PACK LINER 4 3.48 4,325.1 4,965.0 3,345.5 11.60 L-80 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.6 Set Depth 4,010.0 String Max No 3 1/2 Set Depth 2,811.9 Tubing Description Tubing Production 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) 32.6 32.6 0.00 Hanger 10.836 FMC, 11" x 3 1/2" ESP Tubing hanger, 3 1/2" TC-II Top FMC ESP Hanger 2.950 2,409.9 2,072.0 64.63 Mandrel GAS LIFT 5.530 3 1/2" x 1" KBMG, GLM SLB KBMG 2.920 3,737.8 2,677.9 60.78 Mandrel GAS LIFT 5.404 3 1/2" x 1" KBMG SLB KBMG 2.920 3,796.2 2,706.7 60.33 Gauge Mandrel 4.503 HES Opsis Gauge Mandrel)HES Opsis 2.932 3,851.1 2,733.9 60.36 Packer 6.276 3 1/2" x 7" HES ESP Feed-Thru Packer, HES ESP Feed- Thur 2.918 3,912.5 2,764.0 60.77 Nipple - X 4.499 2.813" HES X-nipple (SN#: 0005011991-4) HES X-Nipple 2.813 3,933.8 2,774.4 60.65 Sensor - Discharge Gauge 5.620 Discharge Adapter / Gauge Unit Summit Pressure Sub 2.992 3,974.9 2,794.5 60.84 Annular Connection Port (ACP) 5.130 TTC Perforated Intake Summit TTC PCP 2.992 3,979.3 2,796.7 60.73 Seal - Protector 5.130 Tandem Seal Section ( 8.94' , 8.94' ) Summit 513 Series 3,997.2 2,805.5 60.28 Motor - Gear Reducing Unit (GRU) 5.380 Gear Reduction Unit Summit GRU 3,999.4 2,806.6 60.22 Motor 5.620 ESP Motor and Adapter Summit 562 series, 60hp 4,006.1 2,809.9 60.05 Sensor - Discharge Gauge 3.500 Motor Pressure Gauge, 2 3/8" EUE 8RD Summit Gauge 4,008.2 2,811.0 59.97 Centralizer 5.620 Motor Centralizer, 2 3/8" EUE 8RD Summit Centraliz er 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) 3,945.0 2,779.9 60.62 SLIP STOP SET SLIP STOP 6/5/2024 0.000 3,952.0 2,783.4 60.68 PACKOFF SET D&D PACK OFF 6/5/2024 0.000 3,954.0 2,784.3 60.69 ESP SUMMIT 22-1500 TTC- ESPCP (SN# 14132966, PN# 900751002 OAL 24.5") 6/5/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,409.9 2,072.0 64.63 1 SOV BK 1 6/3/2024 Set to shear @ 2500 psi SLB KBMG 3,737.8 2,677.9 60.78 2 DMY BK 1 6/3/2024 SLB KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,218.2 2,925.1 55.40 XO Reducing 7.000 7" 26# L-80 HYD563 Box X 5 1/2" 17# L-80 HYD563 Pin XO 4.892 4,220.0 2,926.1 55.40 XO Threads 5.500 5 1/2" 17# L-80 HYD563 Box X 5 1/2" 17# L-80 SBTC Pin 4.892 4,226.1 2,929.5 55.37 Sleeve - Frac 7.000 5 1/2" NCS HP2 Multi-Cycle Frac Sleeve (SN#: 0050996) NCS HPT Multi Cycle Frac Sleeve 4.850 4,232.7 2,933.3 55.39 XO Threads 5.500 5 1/2" 17# L-80 SBTC Pin x 5 1/2" 17# L-80 HYD563 Pin XO 4.892 4,279.6 2,959.9 55.51 XO Threads 5.500 5 1/2" 17# L-80 HYD563 Box X 5 1/2" 17# L-80 VAMTOP Pin XO 4.772 4,289.6 2,965.6 55.53 Packer 8.697 5 1/2" x 9 5/8", 17# L-80, HES THT Perm Packer (SN#: 0005061647-01) HES THT Packer 4.797 2T-215, 6/17/2024 10:08:19 AM Vertical schematic (actual) GRAVEL PACK LINER; 4,325.1- 4,965.0 SLOTS; 4,434.0-4,953.0 SURFACE; 37.4-4,472.6 Tie-Back String; 36.4-4,357.0 Motor; 3,999.4 Motor - Gear Reducing Unit (GRU); 3,997.2 Seal - Protector; 3,979.3 Annular Connection Port (ACP); 3,974.9 ESP; 3,954.0 PACKOFF; 3,952.0 SLIP STOP; 3,945.0 Nipple - X; 3,912.5 Packer; 3,851.1 Gauge Mandrel; 3,796.2 Mandrel GAS LIFT; 3,737.8 Mandrel GAS LIFT; 2,409.9 Intermediate String 1 Cement; 37.0 ftKB CONDUCTOR; 38.0-110.0 Hanger; 32.6 KUP PROD KB-Grd (ft) 36.07 RR Date 12/31/199 8 Other Elev 2T-215 ... TD Act Btm (ftKB) 4,967.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032028000 Wellbore Status PROD Max Angle & MD Incl (°) 64.79 MD (ftKB) 2,893.57 WELLNAME WELLBORE Annotation Last WO: End Date 7/23/2012 H2S (ppm) 5 Date 12/11/2016 Comment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,295.9 2,969.1 55.53 XO Threads 5.500 5 1/2" 17# L-80 VAMTOP Box X 5 1/2" 17# L-80 HYD563 Pin XO 4.809 4,306.1 2,974.9 55.52 XO Reducing 5.500 5 1/2" 17# L-80 HYD563 Box X 4 1/2" 12.6# L-80 IBTM Pin XO 4.809 4,316.6 2,980.8 55.50 Nipple 5.210 3.813" X-Nipple, 4 1/2" IBTM Box x Pin, (SN #: 0004915658-7) HES X Nipple 3.813 4,325.1 2,985.7 55.48 PACKER 8.470 BAKER MODEL C GRAVEL PACK PACKER 4.750 4,330.2 2,988.5 55.47 EXTENSION 6.625 UPPER EXTENSION 3.428 4,334.9 2,991.2 55.47 SLEEVE 7.000 BAKER GRAVEL PACK SLIDING SLEEVE 4.875 4,337.8 2,992.9 55.46 EXTENSION 6.625 LOWER EXTENSION 5.500 4,357.5 3,004.0 55.43 XO Reducing 7.250 XO SUB 7.25" x 4.24" 4.240 4,358.4 3,004.5 55.43 XO Reducing 5.550 XO SUB 5.55" x 3.428" 3.428 4,953.4 3,339.2 57.13 XO Reducing 4.000 XO SUB 4.5" x 3.5"3.500 4,954.0 3,339.5 57.13 O-RING 4.250 O-RING SUB 2.375 4,961.0 3,343.4 57.13 VALVE (2)4.500 FLAPPER VALVES 2.375 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 4,434.0 4,953.0 3,047.5 3,339.0 West Sak B, TABASCO, TE_1, 2T-215 3/23/1999 99.0 SLOTS OPEN HOLE GRAVEL PACK Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 37.0 4,230.0 37.0 2,931.8 Intermediate String 1 Cement 15.3 # Cement to survace confirm 10 bbls returns 5/22/2024 2T-215, 6/17/2024 10:08:22 AM Vertical schematic (actual) GRAVEL PACK LINER; 4,325.1- 4,965.0 SLOTS; 4,434.0-4,953.0 SURFACE; 37.4-4,472.6 Tie-Back String; 36.4-4,357.0 Motor; 3,999.4 Motor - Gear Reducing Unit (GRU); 3,997.2 Seal - Protector; 3,979.3 Annular Connection Port (ACP); 3,974.9 ESP; 3,954.0 PACKOFF; 3,952.0 SLIP STOP; 3,945.0 Nipple - X; 3,912.5 Packer; 3,851.1 Gauge Mandrel; 3,796.2 Mandrel GAS LIFT; 3,737.8 Mandrel GAS LIFT; 2,409.9 Intermediate String 1 Cement; 37.0 ftKB CONDUCTOR; 38.0-110.0 Hanger; 32.6 KUP PROD 2T-215 ... WELLNAME WELLBORE 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: Tabasco Oil Pool Tabasco Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 4967'3347' 4967' 3347'936 None 4243' Casing Collapse Conductor Surface 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: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Elliott Tuttle elliott.tuttle@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): 2268'MD/2007'TVD 4325'MD/2986'TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025569 198-242 P.O. Box 100360, Anchorage, AK 99510 50-103-20280-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 4255' MD 110' 3070' 110' 4473' 16" 9-5/8" 72' Baker Twin Seal ESP Baker Model C Gravel Pack 4436' KRU 2T-215 4" 5/10/2024 4965'640' 3-1/2" 3346' m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc permitting@alaska gov Perforation Depth MD (ft): 4434-4953' (Slots) Perforation Depth TVD (ft): 3048-3339' (Slots) By Grace Christianson at 9:16 am, Apr 19, 2024 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O=Conoco Phillips, CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2024.04.18 20:49:19-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle 324-227 X VTL 4/23/24 SFD 4/20/2024 X BOP test to 2500 psig Annular preventer test to 2500 psig 10-404 DSR-4/23/24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.25 14:31:46 -08'00'04/25/24 RBDMS JSB 042624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 18th, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over 2T-215 (PTD# 198- 242) on Nordic 3. 2T-215 was drilled and completed in 1998 as a Tabasco Producer and was recompleted in 2012 to place a packer above the ESP. The well has a gravel packed liner and is currently setup with a 3 ½” tubing PCP ESP Upper completion. When replacing the wireline retrievable pump in 2023, the pump eye broke off and cannot be retrieved. Because of this, the well moved to RWO. The existing 3-1/2” tubing and ESP completion will be pulled from the well and a test packer will be run to verify casing integrity down to top of liner. Then, a cleanout will be performed down inside the 4” gravel packed liner and a new 3-1/2” tubing ESP completion will be installed. It was noted in the 2012 RWO that the casing required swaging to install the packer and ESP completion and remains a risk for this RWO since the well has a single string of casing. If casing deformation is encountered, we are prepared to swage the casing followed by milling it to drift. If milling is required, a 7” casing longstring is planned and will be cemented to surface. If you have any questions or require any further information, please contact me at 907-252-3347. Elliott Tuttle Rig Workover Engineer CPAI Drilling and Wells 2T-215 Tabasco Producer Pull and Replace ESP Procedure PTD: 198-242 Page 1 of 3 PPre-Rig Work Completed 1. Pulled WL retrievable ESP components from well (2/29/24) 2. Pulled OV from station #3, took SBHP survey @ 4221’ RKB, 2927’ TVD @ 1197psi (3/1/24) 3. Perform Casing evaluation using magnetic based logging tool, did not find deformed casing (3/6/24) 4. Function test LD’s & GN’s, T-POT/ PPPOT, PC-POT/ PPPOT Passed (3/31/24) 5. MIT-IA to 2500psi, Passed (4/1/24) Remaining Pre-Rig Work 6. Pull DV from sta #2, let gas migrate to surface, bleed gas, re-install DV into sta #2 7. Install OV in sta #1 8. Ready well within 48hrs of rig arrival Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2T-215. No BPV set for MIRU due to Nordic 3’s internal risk assessment. 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. Circulate/ bullhead KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 PSI. Test annular 250/2,500 PSI. Retrieve 3-1/2” Tubing, Packer and ESP 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to ESP assy at 4355’ RKB. a. Set annular and circulate potential packer gas. Contingency Subsidence Remediation 1. Cut and band ESP cable to the tubing, MU deployment sub and drop tubing off on top of 4” Gravel Packer liner at 4325’ RKB. a. It is possible the packer, 8.83” OD, does not drift the known casing impingement @ 386’ RKB that was noted in the 2012 RWO. 2. Attempt to swedge casing as completed during the 2012 RWO to obtain needed drift. a. If Successful, RIH and PU tubing and lay down rest, move to “Cleanout Run” b. Unsuccessful: 3. Set RBP above tubing stub, and dump sand (obtain needed barriers) 4. ND Tabasco Gen 1 Horizontal Unihead wellhead, NU Gen 5 Slimhole WH in preparation for secondary casing string. a. Test voids to 5000psi, test lowest most connection to 2500psi against shallow plug. 5. Mill restriction in 9 5/8” Casing (Alter Casing) 6. Cleanout down to plug and retrieve. 7. Pull rest of tubing OOH, lay down same. 8. RU Eline: RIH with RBP/ IBP and set in 4” Liner – if needed as barrier. 2T-215 Tabasco Producer Pull and Replace ESP Procedure PTD: 198-242 Page 2 of 3 9. MU and RIH with 7” long string of casing with Packer and cementing valve. 10. Space out and land 7” string of casing in new Gen 5 head, drop ball and rod, set packer. 11. Cement 7” x 9 5/8” Annulus through DP manipulated cementing valve above set 5 ½” x 9 5/8” packer to surface. 12. RU Eline: Retrieve Ball and Rod, RHC plug, and RBP/ IBP (if set) Cleanout Run 13. Perform a cleanout of the gravel pack liner using a reverse circulating tool with ~500’ of tailpipe (VACS Engine). Test Casing down to New Packer Depth 14. TIH with Test Packer, set at 4200’ RKB, test from above. Confirm casing integrity. Install 3-1/2” Completion with ESP 15. Run 3.5” upper completion with feed through Packer, chemical injection valve, sliding sleeve, PCP ESP, gas lift mandrel(s), and downhole gauge. RIH to depth, spaceout. 16. Drop ball and rod and set packer. 17. Pressure test tubing to 1,500 psi for 30 minutes, chart test. 18. Pressure test IA to 2,000 psi for 30 minutes, Chart test. ND BOP, NU Tree 19. Confirm pressure tests, then shear out SOV with pressure differential. 20. Install BPV and test. ND BOPE. NU tubing head adapter assembly, NU tree and test tree to 5000 psi for 10 minutes. 21. Pull BPV and freeze protect well. 22. RDMO. PPost-Rig Work 23. Dummy off Sheared SOV in GLM(s) 24. Pull any plugs. 25. Install ESP General Well Information: Estimated Start Date: 5/10/2024 Current Operations: Shut in Well Type: Producer Wellhead Type: FMC Tabasco Gen 1 Horizontal BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 1241 psi / 3048’ TVD measured 3/1/24 7.8ppg EMW MPSP: 936 psi using 0.1 psi/ft gradient 2T-215 Tabasco Producer Pull and Replace ESP Procedure PTD: 198-242 Page 3 of 3 Scope of Work: Pull the existing 3-1/2” tubing by pull releasing packer and laying down same. Address subsidence damage if present and install 7” casing long string if loss of 9 5/8” casing integrity and cement. Lastly, a cleanout inside liner will be performed and install new 3 ½” tubing ESP completion and packer. PPersonnel: Workover Engineer: Elliott Tuttle (907-252-3347 / Elliott.tuttle@conocophillips.com) Reservoir Surveillance Engineer: Kevin Wiggs Production Engineer: Natalie Parker Dye Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled and set new slipstop & Packoff 2T-215 6/3/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.010/16/2010 ninam General Notes: Last 3 entries Com Date Last Mod By Schematic updated by J.Peirce.10/16/2000 Admin Set 2000 psi to Tbg to Csg SOV on BK. 10/4/2000 Admin Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 38.0 110.0 110.062.58 H-40 WELDED SURFACE 9 5/8 8.70 37.4 4,472.6 3,069.5 40.00 L-80 BTC MOD GRAVEL PACK LINER 4 3.48 4,325.1 4,965.0 3,345.5 11.60 L-80 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.1 Set Depth… 4,254.9 Set Depth… 2,945.9 String Ma… 3 1/2 Tubing Description TUBING 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) 36.1 36.1 0.00 HANGER 10.850 FMC, 11" x 4-1/2" TUBING HANGER FMC TC-BH- EMS-EC -HT 4.000 2,148.31,943.6 55.38 ESP Mandrel 5.390 GLM, 3 1/2" x 1" KBMG (S/N:15392 -14) Camco KBMG2.920 2,267.8 2,006.7 60.37 PACKER 8.830 BAKER TWIN SEAL ESP PACKER Baker Twin Seal 3.920 2,387.02,062.264.50 ESP Mandrel 5.390 GLM, 3 1/2" x 1" KBMG (S/N:15392 -17) Camco KBMG2.920 4,113.0 2,866.1 56.88 ESP Mandrel 5.390 GLM, 3 1/2" x 1" KBMG (S/N:15392-06) Camco KBMG 2.920 4,165.22,895.1 55.65DISCHARGE5.310 WELLLIFT DISCHARGE GAUGE UNIT WellLiftDGU 2.990 4,222.8 2,927.6 55.38 INTAKE 4.725 CENTRILIFT TTC SLOTTED INTAKE RECEIVING ASSEMBLY (2,930-FT TVD) CENTRI LIFT CSE844 2XA 2.990 4,227.2 2,930.2 55.37 SEAL 5.130 CENTRILIFT TANDEM SEAL SECTION CENTRI LIFT C30916 0/C3091 61 4,241.0 2,938.0 55.41 GEAR BOX 5.380 CENTRILIFT GRU (11.42:1) (S/N: 11985667) CENTRI LIFT C61108 4 4,242.82,939.0 55.41 MOTOR5.620 CENTRILIFT ESP MOTOR- 562MSP1 60/1240/29 (S/N: 12059547) CENTRI LIFT C32064 3 4,251.1 2,943.7 55.44 SENSOR 4.500 WELLLIFT MGU (S/N: 192-00825) WELL LIFT PWELE 9001 4,253.0 2,944.8 55.44 Centralizer 8.000 BAKER MACHINED CENTRALIZER 1.990 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) 36.036.00.00 ESP Cable 7/21/2012 0.000 4,179.0 2,902.9 55.59 SLIP STOP Slip-Stop (OAL = 19") 6/3/2023 1.400 4,181.0 2,904.0 55.58 PACKOFF 3 1/2" D&D PACKOFF ASSEMBLY (OAL 92") 6/3/2023 1.625 4,189.0 2,908.5 55.54 ESP Summit PCP (34' 8" OAL) 5/18/2023 0.000 4,243.0 2,939.1 55.41 FISH Pump eye guide form PCP pump. The piece is pie shaped 2.75" high X 4" long. 5/9/20230.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,148.3 1,943.6 55.38 1ESPDMYBK 10.0 7/22/2012 0.000 2,387.0 2,062.2 64.50 2 ESPDMYBK 10.0 7/22/2012 0.000 4,113.0 2,866.1 56.88 3 ESP SOVBK 1 2,500.0 5/19/2023 2500 PSI Tubin g Shear 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) 4,325.1 2,985.7 55.48 PACKER 8.470 BAKER MODEL C GRAVEL PACK PACKER 4.750 4,330.2 2,988.5 55.47 EXTENSION 6.625 UPPER EXTENSION 3.428 4,334.9 2,991.2 55.47 SLEEVE 7.000 BAKER GRAVEL PACK SLIDING 4.875 SLOTS; 4,434.0-4,953.0 SURFACE; 37.4-4,472.6 SENSOR; 4,251.1 MOTOR; 4,242.8 FISH; 4,243.0 INTAKE; 4,222.8 ESP; 4,189.0 PACKOFF; 4,181.0 SLIP STOP; 4,179.0 DISCHARGE; 4,165.2 ESP Mandrel; 4,113.0 ESP Mandrel; 2,387.0 PACKER; 2,267.8 ESP Mandrel; 2,148.3 ESP Cable; 36.0 CONDUCTOR; 38.0-110.0 4,954.0 3,339.5 57.13 O-RING 4.250 O-RING SUB 2.375 4,961.0 3,343.4 57.13 VALVE (2) 4.500 FLAPPER VALVES 2.375 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 4,434.0 4,953.0 3,047.5 3,339.0 West Sak B, TABASCO, TE_1, 2T-215 3/23/1999 99.0SLOTSOPEN HOLE GRAVEL PACK SLOTS; 4,434.0-4,953.0 SURFACE; 37.4-4,472.6 SENSOR; 4,251.1 MOTOR; 4,242.8 FISH; 4,243.0 INTAKE; 4,222.8 ESP; 4,189.0 PACKOFF; 4,181.0 SLIP STOP; 4,179.0 DISCHARGE; 4,165.2 ESP Mandrel; 4,113.0 ESP Mandrel; 2,387.0 PACKER; 2,267.8 ESP Mandrel; 2,148.3 ESP Cable; 36.0 CONDUCTOR; 38.0-110.0 2T-215 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 110 110 16 15.06 62.58 H-40 Welded Welded Surface 4473 3069 9 5/8 8.835 40 L-80 BTC Mod BTC Mod Liner 4965 3345.5 4 3.48 11.6 L-80 Tubing 4255 2946 3 1/2 2.992 9.3 L-80 EUE Mod EUE Mod FMC ESP Hanger PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd-Mod Tubing to surface 3 1/2" X Nipple @ ~500' RKB (2.813" ID) 3-1/2" Camco MMG gas lift mandrel @ TBD 3 1/2" Dual Sensing Gauge (annulus/ Bore) Above Packer 3-1/2" x 9 5/8" ESP Packer (deep as possible) (3" ID) 3 1/2" X Nipple @ ~500' RKB (2.813" ID) 3-1/2" Camco MMG gas lift mandrel @ TBD ESP Discharge Integrated Gauge Unit @ ~4220' RKB Slotted intake Recieving Assembly Adapter GRU Adapter Summit ESP Motor 3 1/2" x 8" OD Centralizer Gravel Pack Liner Baker Model C Gravel Packer Packer @ 4325.1' RKB)Production Casing Conductor Open Hole Gravel Pack 4434' - 4953' RKB Gravel Pack Liner Std ESP Cable Ecapsulated ESP Cable 1/4" TEC Wire 2T-215 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 110 110 16 15.06 62.58 H-40 Welded Welded Surface 4473 3069 9 5/8 8.835 40 L-80 BTC Mod BTC Mod Liner 4965 3345.5 4 3.48 11.6 L-80 Tubing 4155 2900 3 1/2 2.992 9.3 L-80 EUE Mod EUE Mod Tie Back Liner 4255 2946 7 6.276 26 L-80 Hyd563 Hyd563 FMC ESP Hanger PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd-Mod Tubing to Surface 3 1/2" X Nipple @ ~500' RKB (2.813" ID) 3-1/2" Camco MMG gas lift mandrel @ TBD 3 1/2" Dual Sensing Gauge (annulus/ Bore) Above Packer 3-1/2" x 9 5/8" ESP Packer (deep as possible) (3" ID) 3 1/2" X Nipple @ ~500' RKB (2.813" ID) 3-1/2" Camco MMG gas lift mandrel @ TBD ESP Discharge Integrated Gauge Unit @ ~4220' RKB Slotted intake Recieving Assembly Adapter GRU Adapter Summit ESP Motor 7" OD Centralizer PROPOSED COMPLETION 7" 26# L-80 Hyd563 Casing to Surface 5.5" 15.5# NCS Cement Sleeve 5.5" x 9 5/8" Hyd Set Packer 5.5" 4.562" XN Nipple Jnt 4 1/2" Tubng, Full Mule Shoe Gravel Pack Liner Baker Model C Gravel Packer Packer @ 4325.1' RKB) Baker Gravel Pack Sliding Sleeve @ 4334.9' RKB TD @ 4965' RKB Production Casing Conductor Open Hole Gravel Pack 4434' - 4953' RKB Gravel Pack Liner Std ESP Cable 1/4" TEC Wire Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: ~C~ Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~ildred Daretha Nathan Lowell u TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ AL OIL AND GAS CONSERVATION COMMSION RECEIVED i r REPORT OF SUNDRY WELL OPERATIONS AUG 2 3 2012 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r • Stimulate - Frac r Waiver � skare & : 0 1t . Commission Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter SuspenstiMeNt. e 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r " 198 - 242 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 20280 - 00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 " • 2T - 215 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. none Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 4967 feet Plugs (measured) None true vertical 3347 feet Junk (measured) None Effective Depth measured 4965 feet Packer (measured) 2268, 4325 true vertical 3346 feet (true vertucal) 2207, 2986 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 117 117 SURFACE 4435 9.625 4473 3068 LINER 640 4 4965 3345 Perforation depth: Measured depth: open hole gravel pack liner 4434 -4953 - " True Vertical Depth: 3045' -3339' i Tubing (size, grade, MD, and TVD) 3.5, L -80, 4255 MD, 2946 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER TWIN SEAL ESP PACKER @ 2268 MD and 2007 TVD PACKER - BAKER MODEL C GRAVEL PACK PACKER @ 4325 MD and 2986 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 138 19 3 -- 241 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r r Service r Stratigraphic r 16. Well Status after work: „ Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: • none Contact Erik Nelson a 263 -4693 Printed Name Erik Nels. - , Title Sr. Wells Engineer Signature / Phone: 263 -4693 Date L2 v ZZ /e,_, 'r, � r �I�il cl eeU6 23 2012 V � � 2 Form 10 ^ Ise 1`f ORIGINAL . l , IZ / Submit Original Only ' b. 4, KUP • 2T -215 .' a ConocoPhillips u Well Attributes Max Angle & MD TD Inc Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Ca<a,•k� - 501032028000 TABASCO PROD 64.79 2,893.57 4,967.0 Commnt H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ' - SSSV: e NO NE 1 0 10/28/2011 Last WO: 7/23/2012 36.07 12/31/1998 Well Conic - 2T -215, 7/23/2012 7.14'35 AM - schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WORKOVER osborl 7/23/2012 Casing Strings ,k,- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 38 r CONDUCTOR 16 15.062 38.0 110.0 110.0 62.58 H - 40 WELDED 11 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd __ = SURFACE 95/8 8.697 37.4 4,472.6 3,068.4 40.00 L -80 BTC MOD ... Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 4 3.476 4,325.1 4,965.0 3,345.5 11.60 L -80 LINER Liner Details CONDUC TOR. _ I _ Top Depth 3 (TVD) Top Intl Nomi... Top (too) ( °) Item Description Comment ID (in) 4,325.1 2,985.7 55.46 PACKER BAKER MODEL C GRAVEL PACK PACKER 4.750 4,330.2 2,988.5 55.46 EXTENSION UPPER EXTENSION 3.428 ESP Cable, 36 4,334.9 2,991.2 55.45 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 4.875 ESP Mandrel, 4,337.1 2,992.4 55.45 SBE BAKER SEAL BORE 4.750 2,148 11111 4,337.8 2,992.9 55.45 EXTENSION LOWER EXTENSION 5.500 4,357.5 3,004.0 55.43 X0 Reducing X0 SUB 7.25 "x4.24" 4.240 4,358.4 3,004.5 55.43 X0 Reducing X0 SUB 5.55 "x3.428" 3.428 IIIIIn 4,434.2 3,045.5 54.09 SCREEN BAKERWELD GRAVEL PACK SCREEN 3.476 11111 4 ,9 53 . 4 3,339.2 57.13 X0 Reducing 3.500 PACKER, 2,268 4,954.0 3,339.5 57.13 0 -RING 0 -RING SUB 2.375 I 4,961.0 3,343.4 57.13 VALVE (2) FLAPPER VALVES 2.375 Tubing Strings Tubing Description String 0... String ID ... Top (569) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3 1/2 I 2.992 I 36.1 ISO 2,946.0 I 9.30 I L-80 EUE Completion Details Top Depth (ND) Top Inc! Nomi... ESP Mandrel, Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 2387 36.1 36.1 -0.41 HANGER FMC, 11" x 4 -1/2" TUBING HANGER 4.000 I 1111 2,267.8 2,006.7 60.76 PACKER BAKER TWIN SEAL ESP PACKER 3.920 4,165.2 2,894.8 55.22 DISCHARGE WeIILIFT DISCHARGE GAUGE UNIT 2.990 i lir 4,222.8 2,927.6 55.36 INTAKE CENTRILIFT TTC SLOTTED INTAKE RECEIVING ASSEMBLY 2.990 ESP Mandrel, (2,930 -FT ND) 4.113 4,227.2 2,930.4 55.65 SEAL CENTRILIFT TANDEM SEAL SECTION 1 : 4,241.0 2,938.1 55.63 GEAR BOX CENTRILIFT GRU (11.42:1) (S/N: 11985667) 4,242.8 2,939.1 55.63 MOTOR CENTRILIFT ESP MOTOR- 562MSP1 60/1240/29 (S /N: 12059547) IR 4,251.1 2,943.8 55.61 SENSOR WELL LIFT MGU (S/N: 192- 00825) DISCHARGE, 4,165 4,253.0 2,944.9 55.61 Centralizer BAKER MACHINED CENTRALIZER 1.990 ' Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) 0") (1 Description Comment Run Date ID (in) i 36.0 36.0 - 0.41 ESP Cable 7/21/2012 0.000 INTAKE, 4,223 SEAL 4,227 n .. �`` Perforations & Slots Shot GEAR BOX, �• Top (ND) Btm (TVD) Dens 4,241 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (.h... Type Comment MOTOR, 4,243 4,434.0 4,953.0 3,045.4 3,339.0 West Sak B, 3/23/1999 99.0 SLOTS OPEN HOLE GRAVEL PACK e ' TABASCO, TE_1, 2T -215 SENSOR, 4,251 Notes: General & Safety Centr 25 4,253 End Date Annotation I 10/16/2010 jNOTE: View Schematic w /Alaska Schematic9.0 i 4 I Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,148.3 1,943.6 55.83 Camco KBMG 1 ESP DMY BK 0.000 0.0 7/22/2012 SURFACE, 37 2 2,387.0 2,062.2 64.55 Camco KBMG 1 ESP DMY BK 0.000 0.0 7/22/2012 LOTS, 4 953 = V 3 4,113.0 2,866.1 56.88 Camco KBMG 1 ESP DMY BK 0.000 0.0 7/22/2012 El GRAVEL PACK LINER, 4,325 -4,965 TD, 4,967 2T -215 Well Work Summary , DATE. SUMMARY 5/22/12 PRE- RWO - -T -POT (PASSED)OPPPOT (PASSED), PRIMARY CASING FOGER SEAL -PO (PASSED), PRIMARY CASING HANGER SEAL -PPPOT (PASSED), FUNCTION TESTED ALL LDS'S (GOOD) 5/26/12 PULLED SLIPSTOP, PACKOFF, AND 40' x 3 -1/2" PCESP FROM 4202' RKB. LEFT SOV SHEARED, TBG & IA FREEZE PROTECTED WITH DSL. READY FOR BPV. 7/2/12 DRIFT TBG. TO 3.67" TO XO @ 4102' RKB. MEASURE BHP @ 4215' RKB ( 1063 psi) & 4032' RKB ( 1022 psi ). COMPLETE • • Conoco hillips Time Log & Summary We //view Web Reporting Report Well Name: 2T - 215 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/7/2012 10:00:00 PM Rig Release: 7/23/2012 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/07/2012 24 hr Summary MIRU Nordic Rig 3. 21:00 22:00 1.00 0 0 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -209 to 2T -220 Accept Nordic Rig 3 at 22:00 hrs on 7 -07 -12 22:00 00:00 2.00 0 0 MIRU MOVE RURD P Spot Cuttings Box, Hook up Hardline, Spot Auxiliary Equipment and Load pits w/ Filtered 8.6 ppg 3 % KCL Brine. 07/08/2012 Kill Well, Install BPV, Nipple Down Tree, Nipple up BOPE and Test 250 / 3500 psi. 00:00 01:30 1.50 0 0 COMPZ WELCTL MPSP P Load Lubricator and Pull Back Pressure Valve. 01:30 03:00 1.50 0 0 COMPZ WELCTL CIRC P PJSM, PT lines, Open Well, 70 psi on Tbg. Bullhead 100 bbls 9.0 ppg 3% KCL down Tbg - 03:00 08:00 5.00 0 0 COMPZ WELCTL OTHR T Found VR plug in IA. Callout for valve crew to remove VR pull from csg valve port. Remove 1502 integral flange and lubricate out VR plug. re- install 1502 Integral flange, RU kill lines. PT kill lines at 250 / 3,500 psi. ready to continue on killing well. 08:00 12:00 4.00 0 0 COMPZ WELCTI CIRC P Open up well, 40 psi TBG 230 psi L: IA. Vent off gas. Pump 100 bbls \ V recovered 62 bbls = 62% returns, ,v Continue to pump 80 bbls recovered 63 bbls, Empty Kill tank. Mix and pump 2 ppg hi visc sweep for 31 bbls and chase with 280 bbls at 3 bpm 210 psi Recovered 222 bbls of 311 bbls pumped = 71% returns. Total volume pumped today as of Noon =591 bbls recovered 436 12:00 13:30 1.50 0 0 COMPZ WELCTL OWFF P Monitor well, pull kill tank, reload Vac truck w/ 290 bbls of 8.5 ppg, Filter 290 bbls +/- of 8.5 ppg off truck. Call out wellhead technician \ f while monitoring well for flow. Well f`-. 1 on vac. 13:30 14:00 0.50 0 0 COMPZ WHDBO MPSP P Install BPV and blow down �Q circulation lines. 14:00 15:15 1.25 0 0 COMPZ WHDBO NUND P PJSM, ND Tree, Inspect hanger � n threads - good. Install Blanking DIua. 15:15 18:30 3.25 0 0 COMPZ WHDBO NUND P PJSM, Install and NU 11" 5M Class III BOPE along with choke and kill Tines. Page 1 of 15 Time Logs 411/ • Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 00:00 5.50 0 0 COMPZ WHDBO BOPE P RU test equipment - Shell test - work air from system and observe for leaks. Test BOP with 3 -1/2" and 4 -1/2" Test joint at 250 / 3,500 psi. 3 'Q < RD Test equipment. 6() 24 hr notice was given at 06:45 hrs on 7 -07 -12 and Right to witness was waived by Jeff Jones at 17:26 hrs on 7- 08 -12. 07/09/2012 Finish BOPE Test 250 / 3500 psi. Pull BPV/ Blanking Plug, Circ, UnLand Hanger, Circulate Well, Lay Down Tbg Hanger, TOOH Laying Down Tbg 00:00 02:00 2.00 0 0 COMPZ WHDBO BOPE P Continue to conduct Initial BOP test at 250 / 3,500 psi w/ 3 1/2 and 4 1/2 test joints. RD Test equipment. 24 hr notice was given at 06:45 hrs on 7 -07 -12 and Right to witness was waived by Jeff Jones at 17:26 hrs on 7- 08 -12. J Q 02:00 03:15 1.25 0 0 COMPZ RPCOM PLUG P Rig Down Hoses and pull Blanking, Plug and BPV. ti,. 03:15 11:30 8.25 0 0 COMPZ RPCOM CIRC P PJSM, Rig up Hoses and Bullhead (-• 200 bbls Diesel 200 down IA at 3 bpm- ICP 190, FCP 380. 165 bbls returned to kill. Circulate out 35 bbl 2 ppg Hi Visc sweep followed by 423 bbls of 8.5 ppg 3% KCL. Returning 8.5 ppg clean KWF through Gas buster at 1.5 bpm. 11:30 13:30 2.00 0 0 COMPZ RPCOM OWFF P Monitor well for flow - good no flow - slight vac. RU heat trace equipment 13:30 14:00 0.50 0 0 COMPZ RPCOM OTHR P _ BOLDS and unland hanger and Pull to rig floor at 90k up wt. Up wt 86k# and Down 74k #. 14:00 14:30 0.50 4,264 4,236 COMPZ RPCOM OWFF P Monitor well on Trip tank while megging ESP cable. 14:30 15:30 1.00 4,236 4,146 COMPZ RPCOM PULD P POOH from 4,236 -ft to 4,146 -ft laying ESP cable in pipe shed. String ESP cable over sheave. 15:30 00:00 8.50 4,146 550 COMPZ RPCOM PULD P Continue to POOH laying down ESP completion from 4,146 -ft to 550 -ft. Up 44k# and Down 44k #. 07/10/2012 Lay down ESP Equipment, MU MI Swaco Cleanout Assy, Clean Out to top of SC -1 GP Packer at 4325'. RIH with 9 -5/8" Baker RBP. 00:00 01:30 1.50 550 0 COMPZ RPCOM PULL P Continue to POOH laying down ESP completion from 4,146 -ft to 550 -ft. Up 44k# and Down 44k #. 01:30 03:00 1.50 0 0 COMPZ RPCOM PULD P At Pump Intake, LD Seals, Gear Box, and Motor Page 2 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 07:30 4.50 0 0 COMPZ RPCOM PULD P Load Pump Boxes in Pipe Shed, double check de- completion and offload de- completion. Clean Rig Floor and pipe shed. Load pipe shed with clean out assy. Clamp Count Recovered from Decompletion: 1799 ea. Flat Bands 471 ea. 6 -ft Flat Guards 29 ea. 4 -ft Flat Guards 20 ea. 3 -ft Flat Guards 4 ea. 3 -1/2" NOVA Clampc 20 ea. 4 -1/2" NOVA Clamps 2 ea. sentry Guard Clamps 1 ea. 6 -ft End Shoe 1 ea. Motor Protectolizer 3 ea. Pump Protectolizers 07:30 08:00 0.50 0 28 COMPZ WELLPF OTHR P Set wear ring. 08:00 08:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with MI Swaco wellbore cleaning dept. 08:15 09:00 0.75 0 59 COMPZ WELLPF PULD P PU and MU Clean out BHA #1 to 59 -ft 09:00 10:30 1.50 59 389 COMPZ WELLPF TRIP P RIH w/ BHA #1 and set down at 388.64 -FT. POOH to 59 -ft to BHA #1 10:30 11:30 1.00 389 0 COMPZ WELLPF PULD T POOH breaking down and laying down BHA #1 11:30 13:00 1.50 0 0 COMPZ WELLPF OTHR T Change out Foley 1,200 tongs for Foley 1,500 tongs for 4 1/2 IF connections. 13:00 14:30 1.50 0 0 COMPZ WELLPF TRIP T PU and MU BHA #2 (Razorback CSG scraper and 8.5" Bit) RIH to 386 -ft and set down. POOH and breakdown BHA #2 14:30 17:00 2.50 0 4,327 COMPZ WELLPF TRIP T MU and BHA #3 (8.5" Bit) RIH, seen small bobble at 388 -ft, Continue to RIH to 4,327 + /- FT. PU 2 -ft ft. and prepare to circulate. 17:00 19:00 2.00 4,325 4,325 COMPZ WELLPF CIRC P Circulate 3% KCL 8.5 ppg SW at 6 bpm at 820 psi w/ 100% returns, increase to 8 bpm at 1,300 psi w/ 80% returns. 19:00 19:30 0.50 4,325 4,325 COMPZ WELLPF OWFF P Monitor well for flow - slight losses 19:30 22:30 3.00 4,325 0 COMPZ WELLPFTRIP P POOH f/ 4,325 -ft, seen slight over pull at 388 -ft. Continue to POOH and Break down BHA #3 22:30 00:00 1.50 0 1,280 COMPZ WELLPFTRIP P PU, MU and RIH w/ BHA #4 (Baker "G" Lock -set RBP) seen slight slackoff wt at 388 -ft and was able to Continue to RIH w/ No problems to 1280 -ft, Up wt 55k, Dn wt 55k 07/11/2012 Continue RIH and Set Baker RBP Top at 4,267 -ft. Pressure Test RBP. Dump 20 -ft sand. POOH. RIH with Baker Casing Scraper Assembly. Tag TOS at 4,248 -ft. POOH. RU E -line. Run Logs. Page 3 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 1,280 4,395 COMPZ WELLPF TRIP P Continue to RIH w/ No problems from 1280 -ft, Up wt 55k, Dn wt 55k. to 4,300 -ft, Up wt 80k, Dn wt 73k. several attempts to set RBP at 4,300 -ft, slips will not catch, Set RBP top at 4,384 -ft. PUH 1 stand and RU test equipment. 03:00 04:00 1.00 4,395 4,295 COMPZ WELLPF PRTS P Pressure test 9 -5/8" casing to 1150 psi, leak at choke valve, bleed down casing and replace quarter turn valve. Attempt to pressure test casing again, failed, check for all possible surface leaks, able to pump 2 bpm at 450 psi, shut down well on vac. 04:00 04:45 0.75 4,295 4,240 COMPZ WELLPF MPSP T RIH and release RBP, fluid level fell out, PUH and set RBP top at 4,267 -ft. PUH 1 joint and RU test equipment. 04:45 05:30 0.75 4,240 4,240 COMPZ WELLPF PRTS P Pressure test 9 -5/8" casing to 1500 psi on chart 30 minutes. good. RD test equipment. 05:30 10:30 5.00 4,240 4,240 COMPZ WELLPF OTHR P RU and dump 1000lbs 20/40 sand ( -20 -ft) PJSM- Crane on location at 07:00, swap out ESP cable spools while dumping sand. complete dumping sand, PUH while rotating and pumping 1 DP volume slowly to 4,150 -ft, let sand settle. 10:30 13:00 2.50 4,240 0 COMPZ WELLPF TRIP P PJSM, POOH from 4,145 to surface, lay down BHA #4 13:00 15:30 2.50 0 4,248 COMPZ WELLPF TRIP P PU and MU BHA #5 and RIH to TOS at 4,248 -ft, set 5k down. PU to 4,216 -ft 15:30 16:30 1.00 4,216 4,216 COMPZ WELLPF SVRG P Service rig 16:30 19:00 2.50 4,216 0 COMPZ WELLPF TRIP P Continue to POOH from 4,216 -ft. Lay down BHA #5. 19:00 19:30 0.50 0 0 COMPZ EVALWE NUND P PJSM, install dutch riser 19:30 21:30 2.00 0 0 COMPZ EVALWE RURD P PJSM, RU HES E -Line, PT Lubricator 21:30 00:00 2.50 0 4,248 COMPZ EVALWE ELOG P RIH w/ Cast -M tool to 4,248 -ft and log out of the hole at - 1,000 -ft / hour. 07/12/2012 Complete E -line Logs. RD E -line. C/O UPR's to 2 -3/8" Solid Body. Test UPR's and Annular 250/3500 psi. MU and RIH with RBP Retrieving tool. Wash sand from top of RBP. 00:00 05:00 5.00 3,000 0 COMPZ EVALWE ELOG P Continue to log out of the hole at 1,000 -ft / hour from 3,000 -ft with Cast -M tools. Down load logs to ship logs for interpretation and RD Cast -M tools. 05:00 11:30 6.50 0 4,248 COMPZ EVALWE ELOG P MU and RIH w/ Gyro Data tool to 4,248 -ft and log out of the hole @ 1,000 -ft / hr, down load logs to ship logs for interpretation and RD Gyro data tools. 11:30 12:00 0.50 0 0 COMPZ EVALWE RURD P PJSM, RD HES E -Line Page 4of15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 0 0 COMPZ WELLPF MPSP P Drain stack, pull wear ring and Set Test Plug. 12:30 14:30 2.00 0 0 COMPZ WELLPF BOPE P Change out UPR's to 2 -3/8" solid bodies. 14:30 17:00 2.50 0 0 COMPZ WELLPF BOPE P RU and Test UPR's and Annular with 2 -3/8" Test Joint 250 / 3500 psi. RD Test Equipment 17:00 18:00 1.00 0 0 COMPZ WELLPF OTHR P Pull test plug and install wear ring 18:00 22:30 4.50 0 4,248 COMPZ WELLPF TRIP P PU, MU BHA #6 ( "L" retrieving head). RIH w/ BHA #6 ( located Gemeco 754 Cement staging tool at 1,786 -ft )Pressure test casing at 1,500 psi for 10 minutes - good test Continue to RIH 4,248 -ft. 22:30 00:00 1.50 4,248 4,267 COMPZ WELLPF CIRC P Reverse circulate sand off RBP. Up wt 80k, Dn wt 74k, Strip down from 4,248 -ft thru Annular 6 bpm ICP 650 psi, wash down to 4,270 -ft, FCP 530 psi at 6 bpm, 396 bbls total pumped. 07/13/2012 Release RBP. Circulate Well. POOH. Secure well. Secure ODS failed elevator. Release RBP. Circulate Well._ POOH. MU and RIH with MI Swaco Gravel Pack Clean Out Assembly. Slip / Cut Drill Line. 00:00 01:30 1.50 4,267 4,267 COMPZ WELLPF CIRC P Engage and release RBP. Reverse Circulate 2 -1/2 DP volumes. 01:30 02:00 0.50 4,267 4,267 COMPZ WELLPF OWFF P Monitor well for flow 02:00 03:30 1.50 4,267 1,958 COMPZ WELLPF TRIP P PJSM, POOH from 4,267 -ft to 1,958 -ft with Baker "G" Retrievable bridge plug. 03:30 04:30 1.00 1,958 1,958 COMPZ WELLPF RGRP T (Stopped the job) due to failure in Off Driller Side Elevator which dropped while raising at 28 -ft plus above ground level and fell, coming to rest on rear hydraulic motor of system. Investigate and come to agreement on suspending well operations and calling out crane to secure /remove ODS elevator from rig before continuing on with well operations. Follow up measurements from pipe shed door threshold taken on 7 -14 -12 Top of 3rd layer of 4 1/2" tubing on rack is 19 inches the off driller side door threshold Approximant height that the off driller side elevator can travel above the threshold is 44 inches by field calculations as Nordic Toolpusher First door rest above threshold on the off driller side door is 37 1/2 inches Second door rest (which the door was originally set in) above threshold on the off driller side door is 55 1/2 inches Page 5 of 15 • Time Logs Date From To. Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 1,958 1,952 COMPZ WELLPF RGRP T Call out crane, Set 9 -5/8" Baker Model "G" Lock -set Top at 1,941 -ft to secure well for removal operation of failed equipment not knowning time span of addressing abnormal condition on rig equipment and prevent any further damages to equipment and environment. 05:00 05:30 0.50 1,952 1,952 COMPZ WELLPF RGRP T Pressure test RBP to 500 psi, good, well secure. Crane on site. 05:30 08:00 2.50 1,952 1,952 COMPZ WELLPF RGRP T PJSM on critical lift with Nordic 3 and Crane crews. Lower elevator carrier to ground, disconnect and cap hydraulic lines. elevator secured. 08:00 11:00 3.00 1,952 0 COMPZ WELLPF TRIP P PJSM, Engage and release RBP. Reverse Circulate 1 -1/2 DP volumes. POOH from 1,952 -ft to surface, LD BHA #6 and RBP. 11:00 12:30 1.50 0 0 COMPZ WELLPF OTHR P Change over floor equipment to run Clean Out Assembly. 12:30 13:30 1.00 0 0 COMPZ WELLPF SFTY P PJSM- Discuss how to assemble, operate and equipment needed to for operation (Vac trucks, fluids, returns etc.) 13:30 14:30 1.00 0 685 COMPZ WELLPF PULD P PU, MU BHA #7 Gravel Pack Screen Clean Out Assembly to 685 -ft. 14:30 17:30 3.00 685 685 COMPZ WELLPF OTHR T Wrong Cross over Thread was ordered out - 2 7/8 PAC box x 2 3/8 8rd pin. Cross over needed was 2 7/8 HT PAC Box x 8rd pin, Being shipped from (Arctic Pipe / WFT) 17:30 20:00 2.50 685 843 COMPZ WELLPF PULD P PJSM- Continue to MU MI Swaco Well Scavenger Debris Recovery Tool with correct Cross Over. 20:00 20:30 0.50 843 843 COMPZ WELLPF OTHR P PJSM- Change over floor equipment. 20:30 22:00 1.50 843 4,230 COMPZ WELLPF TRIP P RIH with BHA #7 MI Swaco WSDRT to 4,230 -ft, Up wt 80k, Dn wt 74k, set in slips, Kelly up and hang blocks. 22:00 23:30 1.50 4,230 4,230 COMPZ WELLPF SLPC P Slip / Cut Drill Line. 23:30 00:00 0.50 4,230 4,230 COMPZ WELLPF SFTY P PJSM- Discuss job proccess with new crew, stripping procrdure, how to operate clean out equipment and equipment needed for operation (Vac trucks, fluids, returns etc.) 07/14/2012 Clean Out Gravel Pack Screens to 4,950 -ft. Circulate Well. POOH. Prep to Run Completion. PU MU lo_w_ er, ESP Completion. 00:00 00:30 0.50 4,230 4,230 COMPZ WELLPF FCO P Notify DSO and Security of bleeding gas on pad. Establish parameters - Up 79k, Dn 71 k, 4 bpm at 400 psi, Dn 73k, rotating 75k, 5 bpm 630 psi, 6 bpm 850 psi and 7 bpm at 1100 psi. Page 6 of 15 it Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:30 07:00 6.50 4,230 4,950 COMPZ WELLPF FCO P RIH w/ Clean out string pumping 4 bpm, ICP 400 psi, Dn wt 73k, take weight at 4,327 -ft (Top SC -1 Packer) PU rotate and pass thru, take weight at 4,339 -ft (GP Sliding Sleeve) PU rotate thru, DN wt 75k, continue RIH 3 fpm, pumping 4 bpm, 400 psi taking clean returns thru shakers to pit 1, PUH and finish of first stand, pump 35 bbls, 7 bpm, 1100 psi to clear tail pipe and clean out tool screens. Repeat same process for 7 more stands and 1 single to complete GP clean out to 4,950 -ft. 1,326 total bbls fluid pumped with 1:1 returns thru out job. 07:00 07:30 0.50 4,950 4,235 COMPZ WELLPF TRIP P POOH from 4,950 -ft to 4,235 -ft, drop 1 -3/4" ball to open Single Action Bypass port, let fall 30 minutes. 07:30 09:00 1.50 4,235 4,235 COMPZ WELLPF CIRC P SAB port opened at 730 psi, circulate 35 bbl high -vis sweep and chase w/ 270 bbls of filtered 3% 8.5 ppg SW around 6 bpm, 600 psi until returns clean. 09:00 09:30 0.50 4,235 4,235 COMPZ WELLPF OWFF P Monitor well for flow - 9 bph losses 09:30 12:30 3.00 4,235 850 COMPZ WELLPF TRIP P PJSM, BDTD, POOH from 4,235 -ft to 850 -ft (BHA #7) 12:30 13:00 0.50 850 850 COMPZ WELLPF OTHR P PJSM, Change out floor equipment. 13:00 14:15 1.25 850 655 COMPZ WELLPF PULD P POOH laying down Debris chambers and draining the same from 850 -ft to 655 -ft. 14:15 15:00 0.75 655 0 COMPZ WELLPF PULD P POOH laying down 2 3/8 511 hydril TBG from 655 -ft to mule shoe. 15:00 16:30 1.50 0 0 COMPZ WELLPF OTHR P Change floor equipment over and PU, MU and Lay down MI razor back and Magnet in prep for shipping. 16:30 17:15 0.75 0 0 COMPZ RIGMN1 RGRP X Preventive maintenance of Driller side elevator - Inspect and observe operation of pipe elevator observing for operational smoothness, failures and flaws. Found chain on front side closest to the cellar tight and the one on the motor room side had 1" ± movement. 17:15 21:00 3.75 0 0 COMPZ WELLPF OTHR P PJSM, Off load Clean out assy and non - essential equipment not needed. Bring in ESP Completion equipment into the house. Set test plug and wash bop at 2.3 bpm at 370 psi, Reverse circulate above test plug and clean up above test plug. Pull test plug. 21:00 22:00 1.00 0 0 COMPZ RPCOM OTHR P Change over floors. Line up running order. MU ESP cable over sheve. Prep to run completion. 22:00 23:30 1.50 0 0 COMPZ RPCOM PULD P PJSM- PU, MU Motor, GRU and Seals, fill with lubricant. Page 7 of 15 Time Logs • • Date From To ' Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 27 COMPZ RPCOM RCST P PU and connect I -wire and ESP cable MLE. RIH with ESP installing protectolizers, Seal clamps and Cross Collar clamps as needed. 07/15/2012 Run ESP with Feedthru Packer Completion to 540 -ft, change in scope, POOH and prep to drift 9 5/8 casing past anomaly at 388 -ft to insure packer would pass. RIH w/ 8.5" OD swage to 427 -ft with no problem, POOH, MU and RIH w/ 8 3/8" OD x 9 -ft drift tool, took wt at 380 -ft and and set down at 386 -ft. POOH. Discuss results w/ town engineer. Order out larger CSG swages. 00:00 01:00 1.00 27 90 COMPZ RPCOM RCST P Continue to RIH with ESP installing 3 ea. Motor Protectolizers, 4 ea. Seal Section Clamps and 3 ea. Cross Collar Clamps to Discharge Gauge Unit. 01:00 02:00 1.00 90 90 COMPZ RPCOM OTHR P MU connection for I -wire from Motor Gauge Unit to Discharge Gauge Unit, Make ESP Cable electrical inspections and tests. 02:00 07:00 5.00 90 90 COMPZ RPCOM OWFF T 3 -1/2" Cannon clamps delivered for 4 -1/2" completion. Contact Warehouse and DTH on delivery of 90 ea. 4 -1/2" Cannon Clamps. Monitor well on trip tank. Load Clamps. Discover once again that wrong clamps were delivered, locate and ship proper clamps for job, Rig crew discovered that none of the clamps delivered had ss pins - called engineer to discuss if they were needed for these 2T pad projects. 07:00 08:00 1.00 90 540 COMPZ RPCOM RCST P Continue to RIH with 4 -1/2" tubing and ESP completion installing jewelry per running order and clamps per program to 540 -ft. 08:00 09:00 1.00 540 540 COMPZ RPCOM OTHR P Discuss with Town Engineer about drifting well bore prior to RIH w/ packer as BHA's (8.5" bit and short scraper), Baker "G" test plug went thru but seen small amount of wt slack off. Baker completions showed high concern, so decision was made to POOH and drift w/ 8.5" CSG swage and 8 3/8 x 7 -ft drift to simulate packer 09:00 11:00 2.00 540 0 COMPZ RPCOM TRIP X POOH from 540 -ft w/ ESP completion for drift run prior to RIH w/ ESP thru 9 5/8, 40#, L -80 casing deformation at 388 -ft. 11:00 14:00 3.00 0 0 COMPZ WELLPF OTHR X Change over floor equipment to 3 1/2 DP, Load 6- 6.25" OD DC's, Off load fishing tools from and bring to rig floor, strap and build BHA Tally. Set Wear Bushing 14:00 16:00 2.00 0 201 COMPZ WELLPF PULD X PJSM- PU MU BHA #8- Bull Nose, 8 -1/2" Swage, Bumper Sub, XO, 6 ea. DC's, XO Sub, XO Sub, 16:00 17:00 1.00 201 427 COMPZ WELLPF SWDG X RIH w/ BHA #8 on DP to 427 -ft with no sign of casing trouble at 388 -ft. Page 8 of 15 •i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 427 0 COMPZ WELLPF TRIP X POOH with BHA #8 standing back DC's. LD 8 -1/2" Swage. 19:00 21:00 2.00 0 0 COMPZ WELLPF PULD X PJSM- PU MU BHA #9 to 386 Final depth. Work multiple times 380 to 386 -ft, taking 6k push from 380 -ft to 10k set down at 386 -ft. POOH with 5k overpull from 386 -ft to 380 -ft. Continue to POOH and lay down BHA #9 and lay down 8 3/8" OD Drift tool. 21:00 00:00 3.00 0 0 COMPZ WELLPF OTHR X Wait for swages to arrive from dead horse. 07/16/2012 Load TOOLS in pipe shed upon arrival. Attempt to swage open tight spot in casing , drift. Conduct weekly BOP Test. 00:00 03:00 3.00 0 0 COMPZ WELLPF OTHR X Contiue to monitor well on trip tank while tools are deploying from Dead horse. Tools arrived at 2 AM, Load tools in pipe shed and build BHA #10. 03:00 05:30 2.50 0 388 COMPZ WELLPF TRIP X MU and RIH w/ BHA #10 and RIH to 380 -ft and take wt. Work thru with Top drive weight to 388 -ft, unable to pass, 8 -3/4" swage will not pass 380 -ft, 20k overpull to free up. 05:30 06:30 1.00 380 380 COMPZ WELLPFOTHR X Post swaging derrick inspection. 06:30 08:00 1.50 388 0 COMPZ WELLPF TRIP X PJSM- POOH from 380 -ft and LD 8 -3/4" swage 08:00 11:00 3.00 0 400 COMPZ WELLPF SWDG X PJSM- MU and RIH w/ 8 -5/8" swg, XO, 8 -1/2" swg, XO, Bumper Sub, Oil Jar, XO, DC's, XO, XO (BHA #11) on DP to 381 -ft, Up wt 55k, Dn wt 56k, slide thru 15k 381 to 388 -ft, 15k overpull back up thru same, work tandem swage assembly until 5k down and up thru 381 -ft to 388 -ft consistently. 11:00 12:00 1.00 380 0 COMPZ WELLPF TRIP X PJSM- POOH from 380 -ft and LD BHA #11. 12:00 14:00 2.00 0 400 COMPZ WELLPF TRIP X PJSM- MU and RIH w/ 8.38" X 9 -ft Wash Pipe Drift, Bumper Sub, Oil Jar, XO, DC's, XO, XO (BHA #12) on DP to 381 -ft and slid thru 10k to 388 -ft and fall out, PU thru 5k, rotate 180 °, slide thru 15k and take wt at 388 -ft, 10k to pull out, rotate 180° slid thru 10k and fell out at 388 -ft, 10k overpull back up thru 388 -ft to 381 -ft. Confer with town engineer. Call Baker to have 8.438" OD x 4 -ft drift fabricated for 8.38" TSS drive sub. 14:00 15:00 1.00 400 0 COMPZ WELLPF PULD X PJSM- POOH from 380 -ft and LD BHA #12. 15:00 16:00 1.00 0 0 COMPZ WELLPF OTHR X Clean and clear floors, Bring in baker tools Page 9 of 15 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 16:00 19:30 3.50 0 663 COMPZ WELLPF MPSP X PU MU Baker Model "G" Lock -set, Model; "L" retrieving head, DC's and RIH on DP, Set Top at 663 -ft. Had problems getting plug to set properly. 19:30 20:00 0.50 663 0 COMPZ WELLPF TRIP X PJSM- POOH from 663 -ft and LD BHA #13. 20:00 20:30 0.50 0 0 COMPZ WELLPF PRTS X Test RBP to 1500 psi and chart same for 15 minutes. Good Test. 20:30 21:00 0.50 0 0 COMPZ WELLPF MPSP X PJSM. Pull Wear Bushing and Set Test Plug. 21:00 22:30 1.50 0 0 COMPZ WHDBO OTHR P PJSM. Change Out UPR from 2 3/8" Solid Ram's to 2 7/8" x 5" VBP's Rams. 22:30 00:00 1.50 0 0 COMPZ WHDBO BOPE P Start Testing BOPE 250/3500 psi. Test Annular and Choke Manifold. X7/17/2012 Finish weekly BOP Test. Pull RBP. Condition Well and Drift Tight area at 388 -ft 00:00 06:00 6.00 0 0 COMPZ WHDBO BOPE P Continue with Weekly BOP testing, 250/3500 psi and chart same. 06:00 07:00 1.00 0 0 COMPZ WHDBO MPSP P Finished Weekly BOP Test. Pull Test Plug and Set Wear Bushing. 07:00 08:00 1.00 0 667 COMPZ WHDBO PULD P PJSM- MU & RIH with Retriever Head Assembly to pull RBP. 08:00 09:30 1.50 663 663 COMPZ WHDBO CIRC P Latch and Release RBP at 663 -ft. Circulate well 1.5 volumes, monitor well, 4 bph losses. 09:30 10:30 1.00 663 0 COMPZ WHDBO PULL P POOH and UD Retriever Assembly and RBP, BHA #14. 10:30 11:00 0.50 0 205 COMPZ WELLPF PULD X PJSM- PU MU Baker Twin Seal Packer Dummy Drift Assembly (BHA # 15) 8.380" OD x 48" OAL Drift Body, TSS Drive Sub, OJ, XO, 6 ea. DC's, XO, XO. 11:00 11:30 0.50 205 395 COMPZ WELLPFTHGR X RIH with BHA #15, slid thru at 6 to 8k from 381 -ft to 386 -ft, 10 to 15k overpull coming backe thru 386 -ft to 381 -ft. 11:30 12:30 1.00 395 0 COMPZ WELLPF TRIP X POOH from 380 -ft, Marks on gauge 180° opposite each other, one side starts at bottom and is 3 -ft up gauge, opposite marks start 2 -ft up from bottom of gauge. UD BHA #15. Confer with town engineer. 12:30 14:00 1.50 0 2,335 COMPZ WELLPF PULD X PJSM- PU MU Baker Twin Seal Packer Dummy Drift Assembly (BHA # 16) 8.380" OD x 48" OAL Drift Body, TSS Drive Sub, XO and RIH on 3 -1/2" DP, Slid Thru tight area at 1 to 2k, pull back thru with no overpull, Baker Rep. good with results, continue RIH to 2,335 -ft to ensure casing clear to packer set depth, Up wt. 60k, Dn wt 56k. 14:00 15:30 1.50 2,335 0 COMPZ WELLPF TRIP X POOH from 2,335 -ft, no over pull thru tight area at 388 -ft to 381 -ft, LD BHA #16. 15:30 16:30 1.00 0 0 COMPZ WELLPF OTHR X Off load Baker tools. Page 10 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:00 1.50 0 0 COMPZ WELLPFOTHR X Single Down Drill Collars in derrick. Swap over floors to run completion. Single down 4 -1/2" tubing stands in derrick. 18:00 00:00 6.00 0 0 COMPZ WELLPF OTHR X Off load complete 4 -1/2" tubing and jewelry completion (Twin Seal Packer assembly left in house) Load, drift and tally 3 -1/2" completion. Prep to run completion. 07/18/2012 Run and land 3 1/2" TTC- ESPCP Completion with Feedthru packer 00:00 03:00 3.00 0 0 COMPZ WELLPF PULD X Continue to Load, Rack and Tally 3 1/2" Completion. Call Out Centrilft at 2 am. Drifted Tubing to 2.867" 03:00 03:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Running Completion with Nordic, Cetrilift and CPAI. 03:30 07:30 4.00 0 2,000 COMPZ RPCOM RCST P Review Running order again, pulled wear bushing, filled out hot work permit for performing electrical test on ESP cable. Check electrical test on ESP cable. Start running new 3 1/2" ESP Completion and continue to perform electrical test every 1000 -ft. 07:30 11:30 4.00 2,000 2,000 COMPZ RPCOM ALFT P Make up Packer with Safety Joint and FOSV. Make Splice thru Baker 9 -5/8" Twin Seal Feed -thru Packer. Perform electrical test on ESP cable splice. leave disconnected until crossover arrives. 11:30 13:00 1.50 2,000 2,000 COMPZ RPCOM OTHR T Waiting on crossover ordered out from Alpine delivered to Deadhorse for completion. Clean and clear floors and pipe shed. 13:00 17:00 4.00 2,000 4,237 COMPZ RPCOM RCST P Connect cable splice at top of packer and preform electrical test on cable and downhole equipment. Continue running new 3 1/2" ESP Completion, no problem thru 9 -5/8" casing tight spot. Continue to perform electrical test every 1000 -ft. 17:00 18:00 1.00 4,237 4,237 COMPZ RPCOM THGR P MU Landing joint with side port isolation sleeve and Tubing Hanger to completion. 18:00 20:30 2.50 4,237 4,237 COMPZ RPCOM OTHR P Make Final Splice thru FMC Tubing Hanger. 20:30 00:00 3.50 4,237 4,237 COMPZ RPCOM THGR P Land Tubing Hanger 74K Up Weight / 68K Dn Weight. Test Pack -off 250/5000 psi. Had Problem testing Pack -off. Pulled landing joint, inspected and replace seals. Tested good. 07/19/2012 Circulate CI / filtered brine. Set WRP and Set Baker packer.Set BPV, ND BOP's and tested ESP power Cable. Unable to obtain a good ESP integrity test. NU BOP's Page 11 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P PJSM. RU Hoses for Circulating Brine in cellar and PT same to 250/3500 psi. Call HES Slick -line crew. 01:00 02:30 1.50 0 0 COMPZ RPCOM CIRC P PJSM. Circulated 30 bbls of CI / filtered brine followed with 125 bbls of non- CI filtered brine down IA at 2 BPM. ICP 450 psi and FCP 500 psi. SLick -line crew on Location 02:30 03:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM with HES and Nordic Crew. 03:00 05:00 2.00 0 0 COMPZ RPCOM PULD P Removed side port isolation sleeve and re- installed landing joint. MIRU HES Slick -line and Load Tools to Rig Floor. 05:00 09:00 4.00 0 0 COMPZ RPCOM SLKL P Perform drift and correlation run to GLM #3 and Flag wire. 09:00 11:30 2.50 0 0 COMPZ RPCOM MPSP P MU and RIH with a Weatherford WRP on HES DPU and set in the middle of the first full joint below the lowest GLM at 4,066 -ft. POOH. Lay down Slickline equipment. 11:30 12:00 0.50 0 0 COMPZ RPCOM PRTS P RU testing equipment. 12:00 13:00 1.00 0 0 COMPZ RPCOM PACK P PT and Chart WRP to 500 psi for 5 minutes. Start the process for setting the Baker Twin Seal ESP packer at 2,208 -ft per procedure and Baker rep. 13:00 13:30 0.50 0 0 COMPZ RPCOM PRTS P PT IA and Chart for 30 minutes, Good. 13:30 16:30 3.00 0 0 COMPZ RPCOM OTHR P Start Depressurization Process on the ESP Cable. 16:30 17:00 0.50 0 COMPZ RPCOM OWFF P Monitor well for flow 30 minutes. 17:00 18:30 1.50 COMPZ WHDBO MPSP P Remove Landing joint, drain stack and set TWCV. 18:30 21:00 2.50 COMPZ WHDBO NUND P ND BOPE. 21:00 21:45 0.75 COMPZ WHDBO OTHR P Make ESP Electrical checks. Unable to obtain good reading on the ESP cable. Call town Engineer and discuss finding. 21:45 22:00 0.25 COMPZ WHDBO SFTY P Hold PJSM with FMC,Centrilift,MI and Nordic to discuss plan forward. Call out Baker Completion Rep. 22:00 22:15 0.25 COMPZ WHDBO RURD T Rig down Hoses and equipment from celler. Pull Two -way check and install BPV and Blanking Plug. 22:15 00:00 1.75 COMPZ WHDBO NUND T NU BOPE 07/20/2012 Test BOP Break. Pull WRP and Condition Well. Shear Baker Twin Packer and Pull Completion. 00:00 00:30 0.50 COMPZ WHDBO NUND T Continue to Nipple Up BOP's. 00:30 01:30 1.00 COMPZ WHDBO BOPE T Fluid Pack and Shell Test BOP'S and Chart 250/3500 psi. 01:30 02:30 1.00 COMPZ WHDBO MPSP T PJSM. Pull Blanking Plug and BPV. RU Landing Joint with FOSV and X -Over for SLick -line Lubricator. Page 12 of 15 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:30 06:00 3.50 COMPZ RPCOM SLKL T PJSM. MIRU SLick -line and Load Tools to Rig Floor. Cut Line and Re -head. MU and RIH and Locate, Latch and Pull WRP. 06:00 07:00 1.00 COMPZ RPCOM PULD T At surface with WRP, UD and RDMO Slick -line. 07:00 08:30 1.50 4,207 4,200 COMPZ RPCOM THGR T MU Landing Joint, BOLDS. Un -seat Hanger and Shear Baker Twin Packer at 155k, PU tubing hanger above flowcross. Monitor well. 08:30 13:30 5.00 4,200 4,200 COMPZ RPCOM CIRC T Bullhead 160 bbls down TBG 1.5 bpm ICP 470 psi, FCP 490 psi, shut in TBG /IA 220 psi, monitor well, TBG /IA at 10 psi, Revearse 1.5 TBG volumes 2 bpm at 60 psi, shut in and monitor 30 minutes, well taking 4.2 bph. 13:30 15:00 1.50 4,200 4,170 COMPZ RPCOM PULD T PJSM- Pull Hanger to floor, Preform electrcal checks, Seal Nut on bottom of threaded cable penetrator not tightened to specs allowing penetrator to fill with wellbore fluid. UD same. RU and connect ESP cable to spooler. 15:00 21:00 6.00 4,170 1,975 COMPZ RPCOM PULL T TOOH Standing back 3 1/2" Completion, removing clamps and spooling cable to Packer. While spooling ESP cable, Discovered that the Cable was damage section from surface the top of packer and needed to replace that section of cable. Call out for crane support at 1700 hours to swap out ESP spools after further discussion with town engineer. 21:00 22:30 1.50 1,975 1,975 COMPZ RPCOM PULD T UD packer, secure well, Meg cable. PJSM. UD 1 joint below Packer and Install 2 -10' Pup Joints. MU Baker Twin Seal packer. 22:30 00:00 1.50 1,975 1,975 COMPZ RPCOM OTHR T Start making Lower ESP Cable Splice on packer. 07/21/2012 Swap Out ESP Spools. Run and land Completion. 00:00 03:00 3.00 1,975 1,975 COMPZ RPCOM OTHR T Finish making Lower and Upper ESP Cable Splice on packer. 03:00 10:00 7.00 1,975 1,975 COMPZ RPCOM OTHR T Waiting On Crane Service to swap out ESP Spool. 10:00 10:15 0.25 1,975 1,975 COMPZ RPCOM SFTY T PJSM with Centralift, ASRC Crane and Nordic 3 Crews of hazards of spool swap. 10:15 11:30 1.25 1,975 1,975 COMPZ RPCOM OTHR T Remove damaged cable spool from rig and bring in new 5000 -ft of new #1 flat cable (spare spool) MEG new cable spool, good. RDMO ASRC crane. Page 13 of 15 y s • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 13:15 1.75 1,975 1,975 COMPZ RPCOM OTHR T PJSM- Run new cable over sheave and MU new cable connector. Connect cable splice at top of packer and preform electrical test on cable and downhole equipment. 13:15 13:45 0.50 1,975 1,975 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Running Completion with Nordic, Centrilift and CPAI. Review new running order. 13:45 17:00 3.25 1,975 4,225 COMPZ RPCOM RCST P Run 3 1/2" ESP Completion installing clamps on every collar above packer to surface, no problem thru 9 -5/8" casing tight spot. Perform electrical test every 1000 -ft. 17:00 18:00 1.00 4,225 4,225 COMPZ RPCOM RCST P MU tubing hanger to landing joint with side port isolation sleeve. 18:00 23:00 5.00 4,225 4,225 COMPZ RPCOM OTHR P PJSM. Make final splice thru FMC tubing hanger. Check Electrical Integrity on ESP Cable. Good Reading On Meter. 23:00 00:00 1.00 4,225 4,255 COMPZ RPCOM THGR P Install Final Clamp below Hanger, continue down and land Hanger, 75k Up Wt / 68k Dn Wt. RILDS 07/22/2012 Pump CI Fluid, Set WRP and Packer. ND BOPE and NU Tree. Freeze Protect and RDMO 00:00 00:30 0.50 4,254 4,254 COMPZ RPCOM PRTS P Test Hanger packoff to 250/5000 psi. 00:30 01:30 1.00 4,254 4,254 COMPZ RPCOM PULD P PJSM. RU Hoses in cellar and PT same to 250/3500 psi. 01:30 02:30 1.00 4,254 4,254 COMPZ RPCOM CIRC P PJSM. Bullhead 35 bbls of CRW -132 followed with 120 bbls brine at 3 bpm, 500 psi. 02:30 02:45 0.25 4,254 4,254 COMPZ RPCOM SFTY P PJSM with Nordic and HES. Discuss hazard for RU SLick -line and Tools. 02:45 03:15 0.50 COMPZ RPCOM PULD P RU SLick -line Lubricator and Tools. 03:15 04:30 1.25 COMPZ RPCOM SLKL P RIH with Slick -line to drift and correlate down below GLM #3 at 4,113 -ft and Flag Wire.(2.79" Drift) 04:30 07:00 2.50 COMPZ RPCOM MPSP P MU Weatherford 3 1/2" WRP on Slick -line. RIH and set WRP in the first full joint below GLM #3 at 4,145 -ft. POOH- PJSM- LD slickline equipment. 07:00 09:30 2.50 COMPZ RPCOM PACK P PJSM- RU hoses, pressure test & chart WRP to 500 psi for 5 minutes. Start the process for setting the Baker Twin Seal ESP packer at 2,268 -ft per procedure and Baker rep. Pressure up TBG to 2600 psi (hold 5 min) bleed TBG down to 1050 psi, pressure up IA to 1600 psi, pressure up TBG to 3550 psi (hold 5 min) bleed TBG down to 0 psi, IA at 1550 psi 09:30 10:00 0.50 COMPZ RPCOM PRTS P Chart 30 minute MIT -IA x Packer test at 1550 psi, good. 10:00 13:00 3.00 COMPZ RPCOM OTHR P Begin Baker Centilift's Depressurization Schedule on the ESP Cable. Page 14 of 15 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:00 13:30 0.50 COMPZ RPCOM OWFF P Monitor well for 30 minute No Flow Test. 13:30 14:00 0.50 COMPZ WHDBO MPSP P PJSM- RD test equipment, remove landing joint, drain stack and set TWCV. Barriers are in place, 14:00 15:30 1.50 COMPZ WHDBO NUND P PJSM - ND BOPE. 15:30 16:00 0.50 COMPZ WHDBO OTHR P Check the ESP cable /motor electrical integrity phase to phase and phase to ground for all three legs, Good. 16:00 17:00 1.00 COMPZ WHDBO NUND P PJSM- NU tubing head adapter and tree. • 17:00 18:45 1.75 COMPZ WHDBO PRTS P PJSM- Pressure test Hanger Voids and Tree 250/5000 psi. Check cable /motor electrical integrity. 18:45 19:15 0.50 COMPZ WHDBO MPSP P Pull Two Way Check Valve. 19:15 19:30 0.25 COMPZ RPEQP1SFTY P PJSM - Slickline RU /RD and pumping hazards with HES, LRS, Nordic and CPAI. 19:30 19:45 0.25 COMPZ RPEQP1SLKL P RU SLick -line Lubricator and Tools. 19:45 20:15 0.50 COMPZ RPEQP1 RURD P Drop Catcher Sub & RIH and pull 1" Dummy valve on BK latch from GLM #1 at 2,148 -ft- POOH. 20:15 22:30 2.25 COMPZ RPEQPI CIRC P Pressure test equipment, LRS pump 30 bbls diesel (neat) 125 bbls gelled diesel, 10 bbls diesel (neat to clear surface equipment. ICP 500 psi at 2 bpm, FCP 400 psi 22:30 23:30 1.00 COMPZ RPEQPI SLKL P RIH and set 1" Dummy valve on BK latch in GLM #1 at 2,148 -ft- POOH. 23:30 00:00 0.50 COMPZ RPEQPI PRTS P RU Hoses and Pressure test TBG to 1500 psi for 30 minutes on chart. bleed TBG to 0 psi and monitor TBG / IA for flow. 07/23/2012 Finished Tubing Test. Set 4" BPV. Made Final Check On ESP Cable. Secure Cellar and RDMO Nordic Rig 3 00:00 00:30 0.50 COMPZ RPCOM PRTS P Continue to Pressure test TBG to 1500 psi for 30 minutes on chart. bleed TBG to 0 psi and monitor TBG / IA for flow. 00:30 01:30 1.00 COMPZ RPCOM PULD P RDMO Halliburton Slickline and Little Red Services. 01:30 01:45 0.25 COMPZ RPCOM MPSP P Set 4" Type "H" BPV and make final ESP cable /motor electrical integrity checks. Cable Check Out Good. 01:45 06:00 4.25 COMPZ MOVE RURD P Blending Filter Brine. Empty and Clean pits. 06:00 08:00 2.00 COMPZ MOVE MOB P Secure cellar, RDMO Nordic Rig 3. Nordic Rig 3 Released at 08:00 on 07/23/2012 Page 15 of 15 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 4 t tYt ' L , ' ktt*ij:) MAV March 9, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission AnflgoPz.L 333 West 7 Avenue, Suite 100 -- Anchorage, AK 99501 /qa Commissioner Dan Seamount: ca / 5 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerl MJ veland ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) • Kuparuk Field Date 3 -09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/11/2012 2M -02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 2M -29 50103201830000 1920970 SF NA 24" NA 3.4 2/11/2012 2T-18 50103202130000 1950170 4'2" 0.50 9" 11/22/11 2.55 2/12/2012 2T-28 50103202250000 1950920 9" NA 16" NA 2T-207 50103202780000 1982310 22'3" 3.70 7" 11/21/11 2.98 2/122012 . c ). 2T-215 50103202800000 1982420 18'6" 2.40 10" 11/22/11 4.25 2/12/2012 2X-06 50029209880000 1831100 SF NA . 21" NA 2.13 2/122012 1 198-242-0 KUPARUK RIV U TABS 2T-215 50- 103-20280-00 Roll #1: Start: Stop Roll #2: Start Stop MD 0_49~6_7 _~VD 03347 Completion Date: ~34ff5~9 Completed Status: 1-OIL PHILLIPS ALASKA INC current: T Name Interval D 9201 ~ 1,3,4 SPERRY MPT/GR/EWR4 OH Sent Received T/C/D · 5/21/99 5/21/99 L DGR/EWR4-MD,,,..----~ FINAL 117-4967 OH 5/27/99 5/27/99 L DGR/EWR4-TVD ~FINAL 117-3348 OH 5/27/99 5/27/99 L PEX-CN/LDTt.~--- FINAL 4463-4959 OH 4/20/99 4/27/99 L PEX-LL/GR .~....,o~"~,. FINAL 4463-4959 OH 4/20/99 4/27/99 R SRVY RPT SPERRY 4A.02,6.,q,4967. OH 3/23/99 3/26/99 T 9040 ~ I SCHLUM PEX-HALS OH 4/20/99 4/27/99 Wednesday, March 28, 2001 Page 1 of 1 WELL LOG TRANSMFVFAL To: State of Alaska Alaska Oil and Gas Conservation Corem Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs May 27, 1999 2T-215, AK-MW-90049 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2T-215: 2" x 5" MD Resistivity & Gm Ray Logs: 50-103-20280-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20280-00 I BlueYtne 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEDED ¢,~v ~? ~999 ~ 0il & Oas C~s. Commi~i0n 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 26, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-215 (Permit No. 98-242) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 2T-215. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader PM/skad ECEiVED 27 1999 Alaska Oil & (]as Cons, Comrnissior~ Anchorage .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL OOMPLETION OR RECOMPLETION REPORT AND LOG Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number Y 'O7 ARCO Alaska, Inc. 98-242 3. Address 8. APl Number~,R~4J~LqI(2, P. O. Box 100360, Anchorage, AK 99510-0360 50-103-202'80-'"" 0ii & GaS 00Ji8, 4. Location of well at surface r- ........... : .... 9. Unit or Lease Name AncJloraae ........ 729' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 'i,,~/,~/~.~ ¢~ Kuparuk River Unit At Top Producing Interval ~ ~ ¢ 10. Well Number 2027' FNL, 1502' FWL, SEC 1, T11 N, R8E, UM 'i "/~'~;i'.:ri':~: i. 2T-215 At Total Depth ........ ~ , ;11. Field and Pool 1672' FNL, 1636' FWL, SEC 1, T11N, R8E, UM ..... ' ..... ' ..... ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. 28 feetI ADL 25569 ALK 2667 Tabasco Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 23, 1998 March 17, 1999 March 23, 1999 '¢/tI N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 4967' MD/3347'TVD 4965' MD/3346' TVD YES [] No []I N/A feetMD 1540' (approx) 22. Type Electric or Other Logs Run GR/Res, HALS/Den/CNL/GR/MCFL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-FOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 28' 117' 24" 9 cu yds High Early 9.625" 40# L-80 28' 4472' 12.25" 419 sx AS III L, 910 sx Class G, 60 sx AS I 4" 9.5# L-80 4325' 4965' 8.5" GRAVEL PACK 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" x 3.5" 4102'/4227' 4325' (gravel pack pkr) 4434'-4953' MD 3048'-3339' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. gravel pack DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST i i L.c) Date First Production Method of Operation (Flowing, gas lift, etc.) ~J ~ April 20, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/4/1999 22.0 Test Period > 212 21 30 176 14 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 326 psi 0 24-Hour Rate > 216 31 32 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved (Permit #98-242) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Top Tabasco Base Tabasco GEOLOGICMARKERSr ' MEAS. DEPTH 4512' 4922' TRUE VERT. DEPTH 3092' 3322' 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. ..... FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. Title Ddllin.q Team Leader Date INSTRUCTIONS Prepared by Sharon Aflsup-Drake 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. Item 28: If no cores taken, indicate "none". Form10-407 Date: 4/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-215 WELL_ID: AK9701 TYPE: AFC: AK9701 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/23/98 START COMP:03/18/99 RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY: 0 API NUMBER: 50-103-20280-00 12/22/98 (D1) TD: 117' (117) SUPV:DONALD LUTRICK 12/23/98 (D2) TD: 1726' (1609) SUPV:DONALD LUTRICK 12/24/98 (D3) TD: 3305'(1579) SUPV:DONALD LUTRICK 12/25/98 (D4) TD: 3532' (227) SUPV:DONALD LUTRICK 12/26/98 (D5) TD: 3532' ( 0) SUPV:DONALD LUTRICK 12/27/98 (D6) TD: 4477' (945) SUPV:DONALD LUTRICK DRLG MW: 8.6 VISC: 175 PV/YP: 40/50 APIWL: 8.5 Move rig to 2T-215. NU diverter and function test. MW: 9.5 VISC: 135 PV/YP: 29/42 DRLG AT 1825' APIWL: 5.2 Drilling from 117' to 1725'. CBU. POH. Tight at 1444' Back ream from 1444' to 1348' MW: 9.5 VISC: 116 PV/YP: 40/55 POH TO REPAIR STANDPIPE UNION AP IWL: 5.2 Ream from 1423' to 1725'. Drilling from 1725' to 3305' MW: 9.5 VISC: 111 PV/YP: 40/55 REPAIR DRAWWORKS APIWL: 5.2 Drilling from 3305' to 3500' Control drilling from 3500' to 3532'. Survey on bottom. Observed leak in stand pipe. Located leak in 4" union on stand pipe gooseneck. POH. Tight from 2968' to 2872' Swabbing. Circ and back ream from 1919' to 1444'. POH. No problems. Inspect union for damage. Valve union for damage. Replace gasket. RIH. Hit bridge at 1667' Work pipe from 1667' to 1760' DRLG MW: 9.5 VISC: 95 PV/YP: 35/38 APIWL: 5.2 Work on drawworks disc brake. Wash and ream to 1759' Wash and ream to 2049' LD BHA MW: 9.6 VISC: 88 PV/YP: 27/42 APIWL: 5 . 5 Drilling from 3532' to 4477'. Circulate hole clean. Wiper trip to 3532'. No problems. Date: 4/20/99 ARCO ALASKA INC. WELL SUM~4ARY REPORT Page: 2 12/28/98 (D7) TD: 4477'( 0) SUPV:DONALD LUTRICK MW: 9.7 VISC: 48 PV/YP: 21/15 CEMENT 2ND STAGE APIWL: 5.8 Circ and condition mud for csg. Pump dry job. POH. No swabbing. No tight hole. RIH w/9-5/8" casing. 12/29/98 (D8) TD: 4477'( 0) SUPV:DONALD LUTRICK MW: 9.0 VISC: 31 PV/YP: 8/ 5 CUT AND SLIP DRLG LINE APIWL: 9.8 Pump cement. Did not bump plug. Check floats, drop opening bomb. Circ out cement contaminated mud. Pump cement to surface. Bumped plug. Floats OK. ND diverter. NU BOPE and test to 2000 psi. 12/30/98 (D9) TD: 4477'( 0) SUPV:DONALD LUTRICK MW: 8.4 VISC: 28 PV/YP: 0/ 0 POH W/ MULE SHOE APIWL: 0.0 Tag cement at 1783' Drill out stage tool. Tag cement stringers @ 4106' Drill out cement and wiper plug to landing collar $ 4351' 12/31/98 (D10) TD: 4477'( 0) SUPV:DONALD LUTRICK MW: 8.4 VISC: 28 PV/YP: 0/ 0 RIG RELEASED APIWL: 0.0 Finish displace well with seawater. Freeze protect well with diesel. ND BOPE. NU tree and test to 5000 psi. Secure well. Release rig ~ 1300 hrs. 12/31/98. 03/14/99 (Dll) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD: 4477' ( 0) MOVING 5" DP BACK TO ODS SUPV:DEARL W. GLADDEN MOVE RIG FROM 2T-220 TO 2T-215. NIPPLE DOWN TREE, PULL HANGER AND TWO JOINT DEAD STRING.NU BOPE AND FLOW NIPPLE. UPCOMING OPERATIONS:P/U 54 JTS 3 1/2" DP & SB IN DERRICK - P/U BHA - TIH - DISPLACE DIESEL CAP - TAG BAFFLE 03/15/99 (D12) MW: 9.6 VISC: 43 PV/YP: 11/19 APIWL: 0.0 TD: 4477' ( 0) DRLG FLT SHOE ~ 4472' SUPV:DEARL W. GLADDEN NU BOPE AND FLOW RISER. TEST BOPE. PU 54 JOINTS 3.5" DP AND STAND BACK IN DERRICK. RIG UP TO HANDLE 5" DP. RIH WITH BIT #1 TO 2600'. DISPLACE DIESEL FROM WELL. RIH TO 4346' AND DISPLACE HOLE TO 9.6 PPG DRILLING MUD. TEST CASING. CLEANOUT TO 4347' UPCOMING OPERATIONS:C/O TO OLD TD- MAKE 20' NEW HOLE - LOT- CHANGE OUT TO NONE DAMAGING FLUID - DRILL AHEAD Date: 4/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/16/99 (D13) MW: 9.5 VISC: 49 PV/YP: 11/23 APIWL: 4.0 TD: 4477' ( 0) DRILL TO 4967' TD, CIRC, SHORT TRIP TO SHOE ONE TIGHT SPOT SUPV:DONALD L. WESTER Drill out casing and 20' new formation. Perform leak-off test. Continue drilling 8.5" hole to 4950' UPCOMING OPERATIONS: CIRCULATE AND CONDITION HOLE. POOH FOR E-LOGS 03/17/99 (D14) MW: 9.6 VISC: 48 PV/YP: 12/18 APIWL: 4.0 TD: 4967'( 490) P/U BHA #2 3-1/2" MULE SHOE, 9-5/8" TANDUM SCRAPER ASSY SPAC SUPV:DONALD L. WESTER Continue drlg 8.5" hole from 4950' to 4967' R/U Schlumberger and run e-line logs. Test BOP's. OPERATIONS:SPOT PILL PULL TO 9-5/8" CSG SHOE 4472' CHANGE OVER TO FILTER 15% KCL BRINE COMPLETION FLUID. POOH STAND BACK 3.5" DP. L/D 5" DP Date: 4/20/99 ARCO ALASKA INC. WELL SUMFLARY REPORT Page: 4 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-215 WELL_ID: AK9701 TYPE: AFC: AK9701 STATE:ALASKA 20280-00 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/23/98 START COMP:03/18/99 RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103- 03/18/99 (C15 TD: 4967' PB: 0' 03/19/99 (C16 TD: 4967' PB: 4965' 03/20/99 (C17 TD: 4967' PB: 4965' 03/21/99 (C18) TD: 4967' PB: 4965' 03/22/99 (C19) TD: 4967' PB: 4965' CONTIUE PUMPING CAUSTIC W MW: 9.4 KCL SUPV:DONALD L. WESTER INSTALL WEAR RING. PU 3-1/2" MULE SHOE AND TANDEM 9-5/8' SCRAPERS AND RIH TO TD AT 4967'. CIRCULATE HOLE. SPOT ZANVIS PILL ACROSS OPEN HOLE. DISPLACE 9-5/8" CASING TO 9.4 PPG COMPLETION BRINE. CLEAN PITS, MIX AND PUMP CAUSTIC PILL. FILTER BRINE TO 5 NTU'S. SAFETY MEETING ON CAUSTIC CIRCULATE CAUSTIC WASH. UPCOMING OPERATIONS:TOOH FOR BAKER OPEN HOLE SCREEN ASSY. SUPV: RIH TAG BTM ~ 4965', CIRC MW: 9.4 KCL Continue pumping hog wash around. Pump acid pickle job. Run Baker screen assembly. Install SC-1 packer. RIH w/Baker screens on 3.5" DP. UPCOMING OPERATIONS:GRAVEL PACK OPEN HOLE. POOH L/D 3.5" DP & RIH W/ 5" DP & L/D L/D 3.5" DP. CHANGE TOP R MW: 0.0 SUPV:DONALD L. WESTER Continue running Baker screen assembly. Set SC-1 packer @ 4325' Pump Formic acid job. Gravel pack screens. UPCOMING OPERATIONS:L/D 5" DP CHANGE TOP RAMS TO 4.5" RIH W/ 4.5" TBG M/U CENTRILIFT ESP EQUIPM MW: 0.0 SUPV:DONALD L. WESTER RIH w/4.5" tubing. UPCOMING OPERATIONS:RUN COMPLETION ASSY. N/D BOPE N/U TREE FREEZE MW: 0.0 SUPV:DONALD L. WESTER PJSM. RIH w/tubing and continue to run completion equipment. N/D BOPE. UPCOMING OPERATIONS:MOVE OFF WELL CLEAN UP LOCATION. MOVE TO 3K PAD Date: 4/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 03/23/99 (C20) TD: 4967' PB: 4965' RIG RELEASED ~ 10:00AM MW: 0.0 SUPV:DEARL W. GLADDEN NU tree and test to 250/5000 psi. Do final test on ESP cable, heat trace and "I" line cable. Ail OK. Freeze protect well. Move rig off. Release rig at 1000 hrs. 3/23/99. UPCOMING OPERATIONS:MOVING RIG TO 3K-31 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T, Slot 2T-215 2T-215 Job No. AKMM90049, Surveyed: 17 March, 1999 ORIGINAL SURVEY REPORT 23 March, 1999 Your Reft API-5010320280 Surface Coordinates: 5970709.72 N, 498944.99 E (70° 19' 52.3479" N, 150° 00' 30.8066" W) Kelly Bushing: 110.28ft above Mean Sea Level RECEIVED ,Oil&Ga~Con. s. Commission sper',r',~=sun o RI !..., L.I N ~ S~RVIC::~S SurveyRef:svy8413 A l*lAU,,l~t,~l/*l'O~w~ Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: AP1-$010320280 Job No, AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/'~OOft) Vertical Section (ft) Comment 2T-215 D-19 o.oo lO9.73 193.37 281.27 373.05 0.000 o.00o -110.28 0.00 o.0o0 o.ooo -o.55 109.73 0.460 61.31o 83.09 193.37 0.660 65.940 17o.98 281.26 1.o5o 64.490 262.75 373.03 461.15 1.08o 33.380 350.84 461.12 550.02 1.0oo 23.330 439.70 549.98 640.67 1.64o 13.190 530.32 640.60 701.9o 2.990 39.620 591.50 701.78 730.57 3.770 47.620 620.12 730.40 761.39 4.61o 49.580 650.86 761.14 79o.18 5.720 50.260 679.53 789.81 819.25 6.880 51.770 708.43 818.71 848.81 8.000 52.780 737.74 848.02 878.19 8.870 51.21o 766.80 877.08 907.56 9.660 49.840 795.78 906.06 939.39 9.930 50.220 827.15 937.43 968.47 lO.53o 49.520 855.77 966.05 998.48 11.31o 48.770 885.23 995.51 1028.63 11.880 47.480 914.77 lO25.o5 1059.76 12.660 46.100 945.19 1055.47 1088.20 13.220 44.220 972.91 lO83.19 1121.41 13.730 42.710 1005.20 1115.48 1152.42 15.030 40.860 1035.24 1145.52 1182.51 16.670 38.490 1064.18 1174.46 0.00 N 0.o0 E 5970709.72 N 498944.99 E 0.00 N 0.00 E 5970709.72 N 498944.99 E 0.16 N 0.29 E 5970709.88 N 498945.28 E 0.54 N 1.07 E 5970710.26 N 498946.06 E 1.11N 2.31E 5970710.83 N 498947.30 E 2.16 N 3.49 E 5970711.88 N 498948.48 E 3.57 N 4.26 E 5970713.29 N 498949.25 E 5.56 N 4.87 E 5970715.28 N 498949.86 E 7.64 N 6.09 E 5970717.36 N 498951.08 E 8.85 N 7.26 E 5970718.57 N 498952.25 E 10.34 N 8.95 E 5970720.06 N 498953.94 E 12.00 N 10.94 E 5970721.72 N 498955.93 E 14.01 N 13.42 E 5970723.73 N 498958.41 E 16.35 N 16.45 E 5970726.07 N 498961.44 E 19.00 N 19.84 E 5970728.72 N 498964.83 E 22.01 N 23.49 E 5970731.73 N 498968.48 E 25.49 N 27.64 E 5970735.21 N 498972.63 E 28.82 N 31.59 E 5970738.53 N 498976.58 E 32.54 N 35.89 E 5970742.25 N 498980.88 E 36.59 N 40.40 E 5970746.30 N 498985.39 E 41.12 N 45.22 E 5970750.83 N 498990.21E 45.61 N 49.73 E 5970755.32 N 498994.73 E 51.23 N 55.05 E 5970760.94 N 499000.05 E 56.97 N 60.18 E 5970766.68 N 499005.18 E 63.30 N 65.42 E 5970773.01N 499010.42 E 0.000 0.550 0.233 0.426 0.649 0.224 0.749 2.756 3.173 2.764 3.861 4.031 3.815 3.063 2.793 0.872 2.107 2.642 2.077 2.677 2.463 1.866 4.446 5.858 0.00 0.00 0.25 0.88 1.85 3.24 4.83 6.91 9.29 10.83 12.82 15.08 17.82 21.07 24.75 28.85 33.56 38.06 43.05 48.42 54.35 60.14 67.27 74.44 82.21 Continued... 23 March, 1999 - 15:17 - 2- DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: API-5010320280 Job No. AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1214.72 18.290 37.150 1094.91 1205.19 1246.61 19.550 35.990 1125.07 1235.35 1276.07 20.880 35.060 1152.72 1263.00 1310.25 22.000 33.210 1184.53 1294.81 1342.96 23.230 31.270 1214.73 1325.01 1373.71 24.130 28.700 1242.89 1353.17 1405.75 25.260 26.640 1272.00 1382.28 1437.49 26.530 25.140 1300.55 1410.83 1465.28 27.860 23.800 1325.27 1435.55 1501.19 29.910 22.510 1356.71 1466.99 1533.12 31.210 22.570 1384.20 1494.48 1564.50 .33.150 22.570 1410.76 1521.04 1595.21 34.580 22.840 1436.26 1546.54 1627.23 35.300 23.080 1462.51 1572.79 1659.31 35.410 23.740 1488.67 1598.95 1690.12 35.470 23.040 1513.78 1624.06 1721.61 36.960 22.690 1539.18 1649.46 1752.62 38.790 22.610 1563.66 1673.94 1784.61 39.730 23.140 1588.43 1698.71 1816.47 40.610 23.190 1612.77 1723.05 1845.18 41.910 22.680 1634.35 1744.63 1879.57 44.160 22.160 1659.49 1769.77 1912.12 46.340 22.120 1682.40 1792.68 1942.45 47.760 21.660 1703.07 1813.35 1975.01 49.160 21.190 1724.66 1834.94 Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) 70.94 N 71.35 E 5970780.65 N 499016.35 E 79.25 N 77.50 E 5970788.96 N 499022.51 E 87.54 N 83.42 E 5970797.25 N 499028.42 E 97.88 N 90.42 E 5970807.59 N 499035.43 E 108.52 N 97.13 E 5970818.23 N 499042.13 E 119.22 N 103.29 E 5970828.92 N 499048.30 E 131.07 N 109.50 E 5970840.78 N 499054.51E 143.54 N 115.55 E 5970853.25 N 499060.56 E 155.10 N 120.81 E 5970864.81 N 499065.82 E 171.05 N 127.62 E 5970880.76 N 499072.64 E 186.05 N 133.85 E 5970895.75 N 499078.86 E 201.48 N 140.26 E 5970911.18 N 499085.28 E 217.27 N 146.87 E 5970926.96 N 499091.89 E 234.15 N 154.02 E 5970943.85 N 499099.04 E 251.19 N 161.40 E 5970960.88 N 499106.42 E 267.58 N 168.49 E 5970977.28 N 499113.52 E 284.72 N 175.72 E 5970994.42 N 499120.75 E 302.29 N 183.05 E 5971011.99 N 499128.08 E 320.95 N 190.92 E 5971030.64 N 499135.95 E 339.84 N 199.00 E 5971049.53 N 499144.04 E 357.28 N 206.38 E 5971066.97 N 499151.42 E 378.97 N 215.33 E 5971088.66 N 499160.37 E 400.38 N 224.04 E 5971110.07 N 499169.09 E 420.98 N 232.31 E 5971130.67 N 499177.36 E 443.67 N 241.22 E 5971153.35 N 499186.27 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 5.182 91.44 4.123 lOl.38 4.644 111.21 3.827 123.35 4.397 135.67 4.453 147.85 4.433 161.13 4.502 174.93 5.269 187.6o 5.966 204.92 4.073 221.15 6.182 237.85 4.682 254.95 2.289 273.27 1.239 291.81 1.332 309.65 4.777 328.24 5.903 347.26 3.12o 367.49 2.764 388.02 4.677 406.94 6.623 430.39 6.698 453.50 4.812 475.69 4.433 500.06 Continued... 23 March, 1999 - 15:17 - 3- DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: AP1-$010320280 Job No. AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2006.40 49.290 21.780 1745.16 1855.44 2037.71 49.730 21.530 1765.49 1875.77 2070.12 50.640 20.900 1786.24 1896.52 2102.00 52.420 19.740 1806.08 1916.36 2133.04 54.370 19.310 1824.58 1934.86 2165.87 56.550 19.190 1843.20 1953.48 2197.48 57.850 19.480 1860.32 1970.60 2228.68 58.840 19.100 1876.69 1986.97 2261.03 60.130 18.720 1893.12 2003.40 2292.94 61.270 17.940 1908.74 2019.02 2324.38 61.910 17.690 1923.69 2033.97 2388.56 64.560 17.550 1952.59 2062.87 2452.35 64.780 17.830 1979.89 2090.17 2515.04 64.610 18.480 2006.68 2116.96 2578.63 64.210 18.270 2034.15 2144.43 2642.47 64.200 18.670 2061.93 2172.21 2704.20 64.030 17.670 2088.88 2199.16 2768.45 64.340 17.440 2116.86 2227.14 2832.01 64.470 17.410 2144.31 2254.59 2893.57 64.790 17.750 2170.69 2280.97 2958.49 62.820 19.020 2199.35 2309.63 3021.83 61.920 19.400 2228.72 2339.00 3082.62 61.050 19.770 2257.74 2368.02 3148.38 61.400 18.950 2289.40 2399.68 3211.70 61.050 18.880 2319.88 2430.16 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 465.79 N 249.92 E 5971175.47 N 499194.98 E 487.92 N 258.71 E 5971197.60 N 499203.77 E 511.13 N 267.72 E 5971220.81 N 499212.78 E 534.53 N 276.38 E 5971244.21N 499221.45 E 558.02 N 284.71E 5971267.70 N 499229.78 E 583.55 N 293.62 E 5971293.22 N 499238.69 E 608.62 N 302.42 E 5971318.29 N 499247.49 E 633.68 N 311.19 E 5971343.36 N 499256.27 E 660.05 N 320.22 E 5971369.72 N 499265.31 E 686.46 N 328.97 E 5971396.14 N 499274.06 E 712.79 N 337.43 E 5971422.46 N 499282.52 E 767.40 N 354.78 E 5971477.07 N 499299.88 E 822.33 N 372.30 E 5971532.00 N 499317.40 E 876.19 N 389.96 E 5971585.85 N 499335.07 E 930.61 N 408.04 E 5971640.28 N 499353.16 E 985.13 N 426.25 E 5971694.79 N 499371.37 E 1037.90 N 443.56 E 5971747.56 N 499388.70 E 1093.04 N 461.01 E 5971802.70 N 499406.15 E 1147.73 N 478.17 E 5971857.39 N 499423.33 E 1200.76 N 494.98 E 5971910.41 N 499440.13 E 1256.04 N 513.34 E 5971965.68 N 499458.51 E 1309.03 N 531.80 E 5972018.67 N 499476.98 E 1359.35 N 549.71E 5972069.00 N 499494.89 E 1413.73 N 568.82 E 5972123.37 N 499514.00 E 1466.24 N 586.81E 5972175.87 N 499532.00 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Vertical Rate Section (°llOOft) (ft) Comment 1.482 523.82 1.531 547.63 3.180 572.52 6.268 597.48 6.380 622.39 6.647 649.43 4.184 675.99 3.338 702.54 4.114 730.40 4.160 758.21 2.152 785.83 4.134 843.06 0.526 900.64 0.976 957.27 0.696 1014.58 0.564 1072.03 1.483 1127.52 0.580 1185.28 0.209 1242.52 0.721 1298.07 3.506 1356.28 1.517 1412.38 1.528 1465.78 1.216 1523.41 0.561 1578.89 Continued... 23 March, 1999 - 15:17 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: AP1-$010320280 Job No. AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3274.03 61.950 19.110 2349.62 2459.90 3338.08 61.980 20.640 2379.72 2490.00 3401.87 61.870 19.050 2409.75 2520.03 3464.89 61.680 18.480 2439.55 2549.83 3528.70 62.240 19.380 2469.55 2579.83 3593.68 62.610 19.280 2499.63 2609.91 3653.78 62.190 19.530 2527.47 2637.75 3720.09 60.960 19.060 2559.04 2669.32 3783.82 60.330 18.780 2590.28 2700.56 3843.81 60.310 18.950 2619.98 2730.26 3909.77 60.790 18.770 2652.41 2762.69 3942.15 60.600 18.540 2668.26 2778.54 3974.46 60.850 18.830 2684.06 2794.34 4006.53 60.040 18.410 2699.88 2810.16 4035.32 58.840 18.490 2714.52 2824.80 4070.38 58.080 18.560 2732.86 2843.14 4101.70 57.140 17.950 2749.63 2859.91 4165.14 55.650 17.620 2784.74 2895.02 4225.41 55.370 17.370 2818.87 2929.15 4292.35 55.540 17.330 2856.83 2967.11 4354.85 55.430 18.020 2892.25 3002.53 4407.69 55.370 18.590 2922.25 3032.53 Local Coordinates Global Coordinates Northings ~ Eastings Northings Eastings (ft) (ft) (ft) (ft) 1518.03 N 604.64 E 5972227.66 N 499549.84 E 1571.19 N 623.86 E 5972280.83 N 499569.07 E 1624.13 N 642.96 E 5972333.76 N 499588.18 E 1676.71N 660.82 E 5972386.34 N 499606.05 E 1729.98 N 679.10 E 5972439.61N 499624.33 E 1784.33 N 698.16 E 5972493.95 N 499643.40 E 1834.57 N 715.86 E 5972544.19 N 499661.11 E 1889.61 N 735.13 E 5972599.22 N 499680.38 E 1942.15 N 753.14 E 5972651.77 N 499698.40 E 1991.47 N 769.99 E 5972701.08 N 499715.26 E 2045.82 N 788.56 E 5972755.43 N 499733.84 E 2072.58 N 797.59 E 5972782.18 N 499742.87 E 2099.27 N 806.62 E 5972808.88 N 499751.90 E 2125.71 N 815.53 E 5972835.32 N 499760.82 E 2149.23 N 823.37 E 5972858.83 N 499768.66 E 2177.56 N 832.87 E 5972887.16 N 499778.16 E 2202.68 N 841.15 E 5972912.28 N 499786.45 E 2252.99 N 857.29 E 5972962.59 N 499802.60 E 2300.36 N 872.22 E 5973009.96 N 499817.54 E 2352.99 N 888.67 E 5973062.59 N 499833.99 E 2402.06 N 904.30 E 5973111.65 N 499849.63 E 2443.35 N 917.96 E 5973152.94 N 499863.30 E Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°ll00ft) Vertical Section (ft) Comment 1.480 2.109 2.206 0.852 1.523 0.586 0.790 1.957 1.o6o 0.248 0.766 0.853 1.101 2.771 4.175 2.174 3.422 2.388 0.577 0.259 0.927 0.895 1633.65 1690.18 1746.45 18Ol.96 1858.25 1915.84 1969.09 2027.39 2082.92 2135.o2 2192.43 2220.65 2248.82 2276.70 2301.48 2331.34 2357.76 241o.54 2460.15 2515.20 2566.64 2610.10 Tie-On survey Continued... 23 March, 1999 - 15:17 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: AP1-$010320280 Job No. AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Alaska State Plane Zone 4 Kuparuk 2T Dogleg Rate (°/100fi) Vertical Section (ft) Comment 2T-215 4573.56 54.990 19.910 3016.97 3127.25 2571.91 N 962.85 E 5973281.49 N 499908.20 E 4666.53 55.590 20.670 3069.91 3180.19 2643.59 N 989.35 E 5973353.17 N 499934.72 E 4760.87 56.220 20.080 3122.79 3233.07 2716.82 N 1016.55 E 5973426.40 N 499961.93 E 4855.36 56.370 20.160 3175.22 3285.50 2790.63 N 1043.59 E 5973500.21 N 499988.98 E 4948.60 57.130 20.940 3226.35 3336.63 2863.64 N 1070.97 E 5973573.21 N 500016.36 E 4967.00 57.130 20.940 3236.33 3346.61 2878.08 N 1076.49 E 5973587.65 N 500021.88 E 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 26.961° (17-Mar-99) ' The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 20.507° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4967.00ft., The Bottom Hole Displacement is 3072.81ft., in the Direction of 20.507° (True). 0.692 0.932 0.845 0.174 1.074 0.000 2746.23 2822.65 2900.78 2979.38 3057.36 3072.81 Projected Survey Continued... 23 March, 1999 - 15:17 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2T-215 Your Ref: A PI-5010320280 Job No. AKMM90049, Surveyed: 17 March, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2T Comments Measured Depth (ft) 4407.69 4967.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3032.53 2443.35 N 917.96 E 3346.61 2878.08 N 1076.49 E Comment Tie-On survey Projected Survey 23 March, 1999- 15:17 - 7- DrlllQuest Oil:Ill_liNtS To: State of Alaska May2L, 1999 Alaska Oil and Gas Conservation Corem Atm.: Loft Taylor 3001 Porcul~te Dr. Anchorage, Alaska 99501 MWD Formation-Evak~on Logs 2T-215, AK, MM-90049 1 LDWG fonmtted Disc with-verification listing API#: 50-103-20280-00 PLEASE ACKNOWLEDGE RECEIPY BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITFAL LEI~FER TO THE ATYENTION OF: Sperry-Sim Ddtting Service Atto: Yum Galvin 5631 Sitverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Dat~,,AY ? 1 1999 AJaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 4/)~/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATI'N: Sherrie NO. 12505 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL Sepia LIS Tape 2T-215 ~ ~:~1~)~0 99151 PEX-HALS 9903~.'7 1 2T-215 99151 PEX-LATEROLOG 990317 1 1 2T-215 99151 PEX-CNL/LDT 990317 1 1 SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ri I:i I I_1_ I I~1 G S I:: I::! ~.~ I I-- ~ S 23-Mar-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 2ND PORTION DRILLED W/NEW KBE Re: Distribution of Survey Data for Well 2T-215 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,407.69' MD 'MD 4,967.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) I:,,!AR 2. 6 g99 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Re: 2T-215 Permitted TD ~:~- ~/.~ ~ Subject: Re: 2T-215 Permitted TD Date: Thu, 11 Mar 1999 16:25:49-0900 From: B lair Wondzell <Blair Wondzell~admin. state.ak.us> Organization: SOA-AOGCC To: Thomas A Brockway <TBROCKW~mail.aai.arco.com> Thomas, The proposed depth increase is within the distance where no official approval is needed. This constitutes verbal approval. Blair 3/11/99. Thomas A Brockway wrote: > > Dear Mr. Wondzell, > > Arco Alaska Inc, hereby requests a revision of permit #98-242 referencing > Tabasco well 2T-215 located in the Kuparuk River Unit. The current permit lists > a proposed TD of 3456' TVD / 5137' 3~D. Due to recent changes in the geologic > prognosis which indicate a thicker Tabasco pay zone than originally thought, > Arco Alaska requests permission to TD the well at +/- 3548' TVD / +/- 5313' > If this permit change requires the submission of a Form 403 Sundry for approval, > please advise and I will complete one ASAP. Please feel free to contact me with > any questions that you may have. > Sincerely, > Thomas A. Brockway > Operations Drilling Engineer > 263-4135 1 of 1 3/11/99 4:26 PM 0 F! I L..I_ I I~ I~ S I=: I:::1 ~J I I-- I::: S 11-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-215 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 4,477.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS cONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 2. 1998 Tom McKay Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-215 ARCO Alaska, Inc. Permit No: 98-242 Sur Loc: 729'FSL. 556'FWL, Sec. 1. T1 IN. R8E. UM Btmhole Loc. 1543'FNL, 1669'FWL, Sec. 1, T1 IN, RSE. UM Dear Mr. McKay: 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. 2T-215. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2T 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 usc 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 thc Commission to witn~ of BO~..~PE installed prior to drilling new hole. Notice ma.',' be given )~nspector on thc North Slope pager at 659-3607. D avi d-W. J ohns.t, oh"~-- ~ ~'--~"~x Commissioner ',,~ 1 ~ BY ORDER OF T · ISSION dlffEnclosures Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Consen'ation w/o encl. STATE OF ALASKA ALAS~-KA OIL AND GAS CONSERVATION COMM'~F~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 88' feet Kuparuk River Field 3. Address 6. Property Designation Tabasco Oil Pool (Proposed) P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 729' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2042' FNL, 1517' FWL, Sec. 1, T11 N, R8E, UM 2T-215 #U-630610 At total depth 9. Approximate spud date Amount 1543' FNL, 1669' FWL, Sec. 1, T11N, R8E, UM 12/4/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line 2T-30 5137' MD 1517' @ Target feet 103.1' @ 1190' feet 2560 3456' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAO 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 62.08° Maximum surface 2108 psig At total depth (TVD) 2481 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 82' 28' 28' 110' 110' +_200 CF 12.25" 9.625" 40# L-80. BTC 4425' 28' 28' 4453' 3064' 505 Sx Arcticset III & 894 Sx Class G & 60 sx AS I 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 iti i!tii~°lr ~ E C ~, i V F,,, D Ipnrtoe~u%~id~te 0 R i G I N A L Liner [\~0V I 8 1998 Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sket~u~''''~- Drilling program X Drilling fluid program X Time vs depth plot F~, Refraction analysis E~ Seabed report ~,, 20 AAC25.050 requirements X 21. I hereby certify that the foregoing is true arid correct to the best of my knowledge --..~/' j / ,,~ Signed / ~ ~/~/' ~/~'~ ~ ~ i~'/~./V' Title Shallow Sands Team Leader Date //' /' .^. (j' Cofnmission Use Only PerrAit Number., I APl numb~er ,-, _ ~ ,~..... I Approval date_. -~ ,,~'.~ I See cover letter for /~ii¢-- ~ ~rrov'~, I 150' /SCm'~4 ~'re"~uireC~d %~ ~ ~ I /'_.~. ~'~/-. '""~' "~ I °therrequirements Cond"onso app a ape q ~ Yes ~ No ~udlogrequired E,I Yes ~ No Hydrogen sulfidemeasures [] Yes ~1 No Directional survey required ~ Yes E.~ No Required working pressure for BOPE Ei 2M [] (,~ [] 5M [] 10M [] 15M Other: Original Signed By 0avid W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Drill, Case and Completion Plan for Tabasco 2T-215 (N) Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 19. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/4453') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, POOH. 5. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. Pick up 8-1/2" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. Shut in B©P's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Freeze protect well. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 10. Secure well. Release rig. 11. Move in / rig up Nordic Rig 3. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. Drill 8-1/2" hole to well total depth (+/- 5137') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH Run open hole wireline logs as needed. RIH with clean out BHA. Scrape casing. Displace well to completion brine. Pump caustic wash. Pump pickle job. Circulate brine. Pump acid pill across formation. Reverse out with brine. POOH Run in hole with 4" Gravel Pack screen assembly. Set gravel pack packer. Pressure test lines. Pump gravel pack sand and pack screens. Reverse out excess sand. Circulate well to non-freezing, clean completion brine. POOH Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing. Run in well with ESP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. , . 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 2T-215 (N) Page 1 TAB, 11/16/98, v. 1 25. Make surface electrical connections as required. 26. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 27. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. 2T-215 (N) Page 2 TAB, 11/16/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Drillinq Fluid Properties: Well Tabasco 2T-215 (N) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Doyon Rig 19 Spud to 9-5/8" surface casing 8.5-9.6 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Nordic Rig 3 Drill out to TD 10.2 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drillincl Fluid System: Doyon Rig 19 Triple Derrick Shale Shakers Centrifuge, Mud Cleaner Desander, Degasser Pit Level Indicator (Visual/Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Nordic Rig 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 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: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 14.1 ppg EMW (0.73 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2236 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' TVD (0.73 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3399 ft)(0.73- 0.11) = 2108 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3087'. Well Proximity Risks: The nearest existing well to 2T-215 is 2T-30. As designed, the minimum distance between the two wells would be 103.1' at 1190' MD. Drilling Area Risks: Risks in the 2T-215 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or wil_~l be pumped down the surface/production casing annulus of an existinq well on 2T Pad. (Note that cement rinseate will not be iniected 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 2T-215 4-1/2" x 9-5/8" tubing annulus will be filled with kill weight brine and diesel after setting the 4-1/2" production tubing string and prior to the drilling rig moving off of the well. 16" Conductor @ 80' J Weathedord Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 1781' MD / 1696' TVD) 4-1/2r' Nova Clamps All Depths RKB Nordic 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 it, 3-1/2" 9,3# L~80 EUE8RD tubing A. Centrifilt Series 562 ESP assembly w/power cable, 562" OD Super~Bands to top of Y-block 9-5/8" Surface Casing 40,0# L-80 BTCM (+/- 4453' MD / 3064' TVD) Weil TD - Open Hole Gravel Pack (+/- 5137' MD / 3456' TVD) Producer 2T-215 (N) Producer Completion iN. FMC Tabasco Producer horizontal wellhead/hanger system w/ 125 amp penetrators M. Heat Trace, Raychem, 3000' L. 4-1/2" 12,6# L~80 BTCM tubing to sur[ace K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pln J. 3 its, 3-1/'2" 9.3# L-80 BTCM tubing 3,865" Special Ciearance couplings L Baker Dual 'Sentry' gauges, 3-1/2", w/ i-wire, Clamp-on style (suction) and Sidemount kit (discharge) H. 3-1/2" x 10' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x HydsII 511pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" iD Hydrill 511 D, 3 its, 2~7/8" 6.5# L-80 Hyddll 511 flush it tubing C. 2-7/8" Wireline Entry Guide, Hyddll 511 Grovel Pack Assembly (run on d811pipe) -- Baker SC+I Gravel Pack packer, 9-5/8" -- 4 jts, Baker 4" blank tubing, Hunting Seal Lock threads -- Baker ceramic flapper valve -- Baker 4" Gravel Pack screen, Hunting Seal Lock 20 gauge (0,02") screen 12-20 US mesh gravet pack sand 11" 50'- '] psi BOP Stack-- Nor 'lc Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells J Choke Line 5 2 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 16" Divr ter Schematic -- DoYc.~ Rig 19 Kuparuk River Unit Tabasco Operations .. 21 1/4' 2{:)00 PSI, liSP HYDRIL EIOP/DIVERTEP~. ." STUDDED T{::)P/q'LANC~ BOTTOM 1' C/W PLUG · I : : · SURFACE DIVERTER CONFIGURATION ' .. 16' 150 P~ I-PfDR. OPERATED KNIFE GATE VALV~ 11i' FLG'D ~ UNE " 13-5/8" 5C_..0 psi BOP Stack--Dc.~3n Rig 19 Kuparuk River Unit Tabasco Operations - Producer WelIs 4' 8 $ 0 1/4' ,]' 0 ~/4' 1' 10 1' 10 1/e' CHOKE UNE ~/6' ~ooo PS~ HC~ VALVE 3 1/8' 5ooo P~ CATE v~.vE: · EtOP STACK WELt_HE. AB .. ! J . 13 s/a". sooo PSi HYDRIL ANNULAR BOP, ' STUDDED TOP/T1.ANGED BOTTOM · ----------SINGLE 13' 5/8". 5000 PS1, 10" uI% OPEEATOES. I-fig RIL PIPE · ! BOP ,STACK ELEVATION n.~cE ~'ro~/STUDDF'D TOP' . BUND SH~ ~ 3 1/8" ~ ~ HCR v~ . 2" ~ UNE . 3 i/8' ~ ~ ~ v~ ~OE ~O~/~DD~ ToP SIN~ 13 5/8", 5000 Psi, lo"'M~ OP~TOR~' ~RIL PIPE ~ ~C~GE . ~ ~ HUB ~ ~CE REV DATE BY CK APP I 1 9/16/98 MRT JM I PEE 2 1 11 112 208 207 T · 31 · 30 · 29 ® 28 · 27 · 26 · 202 · 23 · 22 · 2 · 3 · §. · 6 · 8 201e · 9 DRILL SITE 2-T · I0 · il · 12 e 3See 14 · 15 36e e. 17 · 19 · 20 · 21 · 37 VICINITY MAP 1' = 2 MILES SEE SHEET '2 FOR NOTES AND LOCATION INFORMATION (NO SCALE) LEGEND o NEW CONDUCTOR LOCATIONS e EXISTING CONDUCTORS ARCO Alaska, Inc. Subsidiery of A[lantic Richfield Compeny CADD FILE NO. DRAWING NO: LK622012 LOUNSBURY ASSOCIATES, INC. E~NEERS PLANNERS SURVEYOR~ AREA: 21 MODULE: XX DRILL SITE 2-T WELL CONDUCTORS 207-210,215,218 & 220 AS-BUILT LOCATION SHEET: REV: CEA-D2TX-6220D12 om oF. 2 1 UNIT: D2 ON PER B# K98075ACS NOTES 1. BASIS OF LOCATION AND ELEVATION ARE DRILLSITE 2-T MONUMENTS PER LHD & ASSOCIATES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D, 27. ALL DISTANCES ARE TRUE. 3. ELEVATIONS SHOWN ARE B.P.M.S.L 4. WELLS ARE LOCATED WITHIN PROTRACTED SECTION 1, T. 11 N., R. 8 E., UMIAT MERIDIAN, ALASKA. 5. DATE OF SURVEY: 9/13/98, FIELD BK, L98-71 pg. 14-23. 6. DRILL SITE 2-T GRID NORTH IS ROTATED 179' 59' 40" WEST FROM A.S.P. ZONE 4 GRID NORTH. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2-17 LOCATIONS, CEA-D2TX-6220D7 FOR CONDUCTOR 18-23, 26-..32, 56-38 & TABASCO LOCATIONS, AND CEA-D2TX-6220D9 FOR CONDUCTOR 202. [VICINITY MAP ~"= 2 MILES LOCATED IN SECTION 1, T 11 N, R 8 E, U.M. SEC. SEC. ' WELL LINE LINE O.O. PAD NO, ¥ X LATITUDE LONGITUDE O/S O/S - ELEV. ELEV. F,S.L. F.W.L 207 5,970,610.10 498,945.02 70'19'51.368" 150'00'..30.805" 6.30' 556' 75.2' 80.4' 208 5,970,622.69 498.944.87 70'19'51.492" 150'00'.30.810" 642' 556' 75.2' 80.4' 209 5,970,6.35.10 498,944.90 70'19'51.614" 150'00'.30.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.7.38" 150'00'.30.814" ~67' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.`348" 150'00'.30.807" 729' 556' 74.2' 80.4' 218 5,970,747.74 498,944.97 70'19'52.722" 150'00'.30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150'00'.30.810" 792' 556' 74.1' 80.4' ARCO Alaska, Subsidiary of Atlantic Richfield Company CADD FILE NO. [ LK622012 I 9/16/98 I DRAWING NO: . suRVEyoR'S CERTIFICATE I HEREBY CERTIFY THAT I ,AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS ,4 SURVEY DONE 8Y ME OR UNDER MY DIRECT SUPERVISION AND. THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 16, 1998. LOUNSBURY ~/J[~. & ASSOCIATES, INC. AREA: 2T MODULE: XX DRILL SITE 2-T WELL CONDUCTORS 207-210,215,218 &: 220 AS-BUILT LOCATION J SHEET: IREV= CEA-D2TX-6220D12 oo:2 oF' 2 UNIT: D2 1 · c ..... ~ ay ,;0~. For: BROCKWAY] Date plotted : 5-NOv-g8 i re'ct Re!ere~ce ,s 215 Vetmon T%e Va-bec: Ce=i~n cra reference I~TEQ ARCO Alaska, Structure : Pad 2T Well : 215 I Field : Kuparuk River Unit Location : North Slope, Alaskal 20.56 AZIMUTH 2680' (TO TARGET OFFSET) · ,,-Plane of Prcposal=** 0 ~ RKB ELEVATION: 116' 2~o ~ ! 500 i East (feet) -> 0 250 500 750 ~ O00 1250 ,._ TO LOCATION: j --.~Tm _ zcoo 15~3' FNL, 1669' FWL ~cse Tcooscc SEC. ~, TI~N, ROE , / k 275C / Torget Too Tem~-cc Se~d~ ' 9 5/8- Casing End ~g!e Drop ~ 2250 TARGET CENTER LOCATION: 2042' FNL, 1517' FWL SEC. t, T11N, R8E ! /Base Wes( Sek Sends TARGET OFFSET / h ~ 750 ~0=3087 / TMD=4~93 OEP=2680 , NORTH 2509 ?7 ~- ~,500 EAST 941 L- k- ~ 250 -~ ,8.00 i ] '' 70 BEGIN TURN TO TARGET TVD=9¢9 TMO=950 OEP=19 , ,.. West ~ CCC -.' ~ ' · ~ ', ; '5.}2 ~ ] \~:9.09 DLS: 4.00 deg per 100 ft K-i ~ ,z:0 i ~22.94 EOC ~- 750 c' j X'~,,,26,85 '--3 ~ %- ' 8/ P~RMAFRO~T 'i'VD=I !96 TMD=1540 OEP=224 :- 500 0 !750 -~ 'X..46.54 rids j- 25n '~'---- -it %.%7.~..~. 4750'50 /Bcse Permafrost F 584¢ ~ 2000 J '"%~'4~O01-VD::002 TMO=2292 OEP:769 ¢..~ -(~/Begin Turn to Target (~ j _ "--,~.~3 TVD=2057 TMO=2410 DEP=873 Z~ ' ~ -r/ W ~AK SNDS TVD=2~88 TMD=2~q0 DEr' 120 '-2~0]MAXIMLTM ANGLE '--...~ws ' ~ ~'=~ L 2~0 V 25co i SURFACE LOC^TION: J s/~~~=;~ 0E~=-~9~5 "-... i ~29' / ~0=3799 OEP = 2100'"~-.~2.06 ~:~°! '"'-,,~m.~6 ~ aLS: zoo i ENO ANGLE_DROP TVO=2892 TM0=4155 DEP=2402'~06 .... [?ARGE% - ?07 ~ABASCO ?VD=308? ?~D=~493 DE?=8680%'q ~°~ TARGET ANGLE J, 5 5 DEG TI) -CSO PT TVD=3~56 TMD=Si3? DEP--3~07 ~500 J , i i i i i i i i i i i i i i i i J I i i i i i I 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 5250 Vertical Section (feet) -> Azimuth 20.56 with reference 0.00 N, 0.00 E from slot #215 A I Z o . ~°t 240 1 220 i 200 ] 180] i 40 . . 0 Z 60 40 20 0 ARCO Alaska, Inc. Structure : Pad 2T Well : 215 Field : Kuparuk River Unit Location : North Slope, Alaska 300 /1000 ,,,,' 1~07~ [ F'"" /~800 ' L /i' ,,,/ / /// / /'/;/ i' ~ o o ,," ~" 900 ,/ /' ] 000 1600 26C t700 ,'/ /' ,/'~ 200 / /// / /~ 240 , oo ,,,, ,,; ;i/ ,'"/; /// 18oo ! ,";/ / '" / ,i'" , 220 / / / ?' ,;:oo ;' 'Ii 500 2oo : /1100 ;/' /900 ,, / , : " // 2~'~0 ,-' : " /' ,'f ,? ,,.,,'~^ / / 800 / ; // '" '" ,"' ,'I / I ,,,I/,,,/, ,, ,'"'" ,'"'" ,,, 1600 ! / ,' / , ,' 160 / / / ,' " ' 1400.,' ' " '~'~ ' '"" / n ~ Z / " " ! ' 700 ,"' ] 000 "' i ''" " ~1 700 ,' ,' _.C 120 " ,' ,' "' " / '/ I ,' CD 1 O0 !/500 ,," ." 900 ,.'1 300 6oo ' "-~- "" / 8po 4' / 'i .-'"'" L ' / " " ~ 60 ~... / 500 ,' ,' ~ ~-~- .... aa. ....,,, ,, ,, I ,/1400 ," ," 40 -~,/ 700 /1/1 O0 ,,"' ,,"/'600 i800/'/' /~,~ F 4u o.~' ..,,~'o o '// ' .- o " e'~oo ..<:]oo .,- I " 1600 /' ,,-'6'00 i 100~ .- " .-" 200 ........ "¢ 2o~ ~-" 5oo..--' ~-~o'~' ",,,,',,,, .... L 20 20 .~.-. 600 ....... t g00',:',, 11 1200 700 40 '"t, ~,00 50( 600 ........ - ..... 11 O0 i I 60 t I I~ I I I i 60 40 20 0 20 4 60 80 100 120 140 160 180 200 220 24-0 250 East (feet) -> East (feet) -> 20 40 60 80 100 120 14-0 160 180 200 220 240 250 Plot Reference ~s ;]15 Version ! Coordinotes ore ;n ~e~ reference slot ~215. ~True VerHcol ~e~(h8 are re~erence ~K8 (Ooyon 2O 40 6O 8O 62O 6OO .580 560 540 1 520 5O0 480 - A 460 ~ ~20 .q-- © Z 400 - 38O 360 3~0 J 320 ~ 300 ] 280! 260 t 240 1 ARCO Alaska, Inc.[ Sfrucfure : Pad 2T Well : 215 Field : Kuparuk River Unif LocaHon : Norfh Slope, Alaska[ aa 20 ! ! ! 2100 , / / I I , / / / i ~ 200 , / / / / / ; / / ! / / / / / / / ! / 1000 ! / ; / / / ; , / / / / / / / / / / / / / ¢' ~1oo ! , ! / / ; / ! / / / / / ; / ,, ,' / 2000 ' !/; / / / 1000 ,'" /'"'/'"' // / 1300/ / / / / / / / / / 9 O0 ,/ / / ,' / 20 40 60 80 100 120 140 160 East (feet) -> 40 160 180 200 220 240 260 280 3GC 320 I I [ t /,//,//// ' 'I' ' / 1800 I00' / / 900 ,/1100 /' /' / / / / / / , / / / / / / 14-00 ,/ / / / / / ,,,,,,' !500 ,~ 2800 ,,'" ,,'"' //i_ /" 1700 / ~/' 180 200 220 240 260 2~0 ' 3~0 ' 3~0 East (feet) -> : 620 -- - 580 - 56O L 54O 520 50o ~80 460 A ~0 Z ° 380 i3¢0 320 300 250 2rio I 0ate p~otted : 5-Nov-98 Caorc;notes ore ~n feet reference slot ~215, Vertical CeDthS Ore reference~ RKB (0ayah 19). fNT~ 880 ] 8S0 t 8~0 ] 820 l 800 - 780 760 740 ] 720 1 7C0 fl 680 660 6z-O 62o ] 6C0 I 580 560 5"0 520 -~ 160 1300 180 200 I . / ,, ; / ; ! / ,, 2jO0 / ,' l/ //I 160 220 / / ,, / / / / / / ,' / / / / / / / / 240 24-00 ! ARCO Alaska, Inc.] 2500 Struct .... Pad 2T Wei,: 215 I '~ ~' Field : Kuparuk River Unit Location : North Slope, Alaskaj East (feet) -> 260 280 500 320 ,340 360 .380 400 280 300 East (feet) -> 180 200 220 240 260 4-20 4~-0 460 ~-860 /700%;"' - 7EO / ~- 74C / r IX 0 68O CD 660 520 340 360 380 400 420 4/0 460 620 600 580 56O 5,4.0 520 ~ Ccorc~nates ore ~n feet rc~crence slot t215. J ~Tr~e Vert;c¢l Oepths ~re reference aK8 (Doyen lg].~ ~ '~ / ARCO Alaska, Inc. Structure : Pad 2T Well : 215 Field : Kuporuk River Unit Location : North Slope, Alcska Eost (feet) !060 1040 1020 920 '+- 9C0 q~ 88C L_ O Z 860 84.,3 820 8o0 780 760 720 t 700 , 220 240 220 240 260 280 300 320 340 360 380 4-00 4-20 4-40 4-60 4.80 500 520 ,,, 0 / / 2200 // 26OO ,/ 1040 / ~ r- - ! 020 ,;,:,/,/ ' /'1 a o o - / gSO / F 9,50 I / i~ c~-o I / ' F 920 / / . / ,' / ,' /~ / ,, ~ ? 9~0 / 2500 3400 2100/,"/ f~ / / ~ ~4C L 820 // w 80C / 1~? L 78C 1200 //, I 760 ' ' 100 ///'//' ~ 740 / / ,' 720 , ,,' ~ , . , ,' ~ , ~ ~ ~ , 700 260 280 300 320 340 360 380 400 420 440 ~60 480 500 520 [~st (feet) -> 94-0 96O 1000 ] A ARCO Alaska, Inc.[ Cccr~mates ~r~ ;n {eot rete~ence stot ~215. [ ; .... , ........ c ........ ~i RKB (Ooycn 19).] ': ~ [~st (feet) -> 180 240 300 360 420 480 540 600 660 720 780 840 900 960 1020 ~080 ~ :~0 Field : Kuporu;< River Unit Location : North Slope, Alaska[ 21C0 204.0 1980 1920 1860 1800 1740 1680 1620 1560 1~C0 14~0 1380 1520 1260 1200 1140 1080 1020 180 ~oo / /~oo.,',:,. ,,;/ / / , - 204o ,,, ,,, / ,,'. /' 1 600 I- 1980 / .oo/ ,,,,:,,.oo /~ / , ,/ 2oo /'"' ~oo / / // '" ' ' ," / ,,' / '. // /2600 :" i ~co/ ,"/ / / .,'" / / // /' ,,,,, / / / /~oo ,; / ./ / 4~oo / / ," / / .," / t ,, / / / / ~ :7~o ;ooo ? / ,'" / / / / L / / ,/ /~oo ,," 2600 / / / / ~680 , / /1700 t / ,/ ,,' / .," / / / : ~oo / .'" / / L._/,;oo / ' ~ / h5o~ / / ~257 ~ / . / ,/ ,,,, I [ ,' 4100J / / " / ," / ,' h o 5oo / / 4ooo~,,'" ,/ ,"' / /" /,,"' L / / /1 600 /; /Z400 "" 12¢b0 /./ t ' ' - ,. -~oo/., : // Aoo / / 1¢oo.¢: : //' ,¢ .... ," ," ,~ ~ ~ 52o / / // / ,,' //~ 40o "'/ ,' I ¢ / / ,' ,' .' , / 300/ 1900 · ,' ~400 I _" / / ~ ' , // ," ~ 2700 / ,; t / /" ,,<,:;/ /' ,,," /" 0 ~'"' I/ / / /' / / ..../ 240 300 560 420 480 540 600 660 720 780 840 900 960 1020 ! 080 11 Easf (feel) -> Coord;natcs ore in feet reference slot ~215. True Vertical Oe~ths ~re reference RK8 (Ooyon 19')· 3060 5GO0 2940 2880 2820 2760 ~ ARCO Alaska, Inc. Structure : Pad 2T Well : 215 ' Field : Kuporuk River Unit Location : Nor-th Slope, Alaska 2700 ! 21 O0 2640 ; / / ,, 2580 '1 ! ,' 2520 / / 2460 1 ,'/ 2400 .I i' 2000 I / · / 2340 ,, j : ; - 2280 i / 2220 -~ ! / 2 ~ 60 ¢' 1900 ,' ; 2100 2040 1980 Easf (feel) -> 640 600 660 720 780 840 900 960 1020 1080 1140 1200 1260 1320 1380 1440 5500 ,, /' .' ~ ,' / / / : 3400 ¢ / / ,' I / /2200 / / / 5400 : / / / / /' /' / / / / / 2600 / / / / / / 3300 ~ / / 5300 , t / ~ / / / 3000 ,, , /~90o ,," / ,' / / ? - / ,' / ,' / / / 5200 / / / 5200 / / / / / / / / /" / 2500 / / 5~oo / / " / / 5~oo {/ /' ,, 5000 ,/~ 1800 / ,' / / / 3000. ~/ /2400 iI 4900 /~/ // ,, '¢ / 2800 /" / ,/1700 / /' / / / / 4800 2900 / / / ,' / /, / / , 1700 ~ / ,' / / ¢' 2500 " 7OO/,' ¢ ,' / / / ,/~' 2800 ,, / ,,,,""' 4~600 / ,' / / / / / / / / / / / / / / / 540 600 660 720 780 840 900 960 1020 1080 1140 1200 1260 1320 1360 1440 Easf (feel) -> 3060 3000 2940 2880 2820 L - 2760 /1800 ,, 2640 / - 2580 F F 252O -- - 2480 J300 ¢/ 240c ? 234c ~ 2280 ? 2220 L21~0 ,,,,, ~ 2100 ,/1900 ~ I2040 ? L 1980 A Z O ARCO Alaska, Inc. Pad 2T 215 slot #215 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 215 Version #4 Our ref : prop3072 License : Date printed : 5-Nov-98 Date created : 16-Jul-98 Last revised : 5-Nov-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.172,w150 0 47.034 Slot location is nT0 19 52.341,w150 0 30.800 Slot Grid coordinates are N 5970709.063, E 498945.207 Slot local coordinates are 729.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <893 - 12977'>,,23,Pad 2T PGMS <0-7897'>,,3,Pad 2T PMSS <O-9298'>,,27,Pad 2T PMSS <O-4175'>,,201,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <O-12821'>,,21,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PGMS <O-8262'>,,14,Pad 2T PGMS <0-7625'>,,15,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <5917-7957'>,,16A,Pad 2T PGMS <O-7650'>,,8,Pad 2T PGMS <0-8250'>,,10,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PMSS <O-9845'>,,19,Pad 2T PMSS <O-10570'>,,29,Pad 2T PGMS <O-8890'>,,2A,Pad 2T PMSS <1287-1725'>,,2,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T PGMS <O-6725'>,,12B,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PGMS <0-6789'>,,il,Pad 2T PGMS <O-7868'>,,13,Pad 2T Closest approach with 3-D Minimum Distance method Last revised Distance 25 -Aug- 98 26 -Aug- 98 23-Jan-98 26 -Aug- 98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23 -Jan- 98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23- jan- 98 23-Jan-98 23-Jan-98 23- Jan- 98 26 -Aug- 98 26-Aug- 98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 277.2 351.7 210.6 489.5 303.8 714.0 243.7 811.9 465.8 156.5 817.9 672.9 701.4 727.0 727.0 727.0 474 8 570 7 104 9 777 6 201 0 285 8 285 8 620 9 620 9 620 9 601 9 651 3 1000.0 710.0 1060.0 100 0 770 0 100 0 1020 0 200 0 2282 5 1330 0 600 0 720 0 710 0 0 0 0 0 0 0 720 0 750 0 1712 1 730.0 941.7 925.0 925.0 740.0 740.0 740.0 300.0 710.0 Diverging from M.D. 1000 710 1060 100 770 100 1020 200 5137 1330 600 720 710 0 0 0 720 750.0 1712.1 730.0 941.7 925.0 925.0 740.0 740.0 740.0 710.0 710.0 PGMS <0-8445~>,,17,P~ .T PGMS <O-8160~>,,4,Pad 2T PGMS <O-7670~>,,5,Pad 2T PGMS <0-8208~>,,6,Pad 2T PGMS <O-6975~>,,7,Pad 2T PGMS <O-6370~>,,9,Pad 2T PMSS <12144-13360'>,,38A, Pad 2T PMSS <4627 - 10686~>,,30A, Pad 2T PMSS <O-4749~,,30,Pad 2T PMSS <5497-13787~>,,32B,Pad 2T PMSS <O-5924~>,,32,Pad 2T PMSS <4850 - 5918~>,,32A, Pad 2T MSS <4046-4427~>,,202,Pad 2T PMSS <469-10632~>,,18,Pad 2T 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 16-Jul-98 16-Julo98 24-Feb-98 24-Feb-98 24-Feb-98 26-Aug-98 21-Oct-98 751.9 374.7 399.4 359.8 450.7 501.6 664.0 103.1 103.1 143.0 143.0 143.0 222.5 763.6 200.=.~j' 720.0 720.0 1160.0 710.0 710.0 100.0 1190.0 1190.0 925.0 925.0 925.0 950.0 500.0 200.0 720.0 720.0 1160.0 710.0 710.0 100.0 1190.0 1190.0 925.0 925.0 925.0 950.0 500.0 ARCO Alaska, Inc, Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 17, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-215 Tabasco Producer, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a producer using an open hole gravel pack completion technique for sand control purposes. The surface hole will be drilled and cased using Doyon Rig 19. After this rig moves off the well, Nordic Rig 3 will move onto location to drill out the production interval and run the completion. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" I-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (o) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-215, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is December 4, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincer~e .¢)~ /// /',? / Thomas A. Brockway Operations Drilling Engineer Attachments: CC: Tabasco 2T-215 Well File Tom McKay ATO-1060 Jack Walker ATO-1200 Steve Kranker ATO-1252 Lewis Ledlow ATO-1063 'ARcOAia~ka,"inc'i' '{~ ............................................................... Kuparuk Unit Disbursement Acc'ount P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF':REVENUE ALASKA OIL .& GAS:CONSERVATION COMMI 3001 PORCUPINE DRIVE ~..~..~..~. 230091758 NOVEMBER 12, 1998 *,*:~: VOiD AFTER 90 DAYS *** 73-426 839 0997587 EXACTLY **********'100 DOLLARS AND O0 CENTS ¢**********.100.00 The First National Bank of Chicago-0710 Chicago;: Illinois Payable ThroUgh Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230091758 ,' 2:;009 ;, ? 5g,,' '-'OB :icloh 2P, 2'.' 099 ? S~; · WELL PERMIT CHECKLIST _ WELl_ NAME~;,,~'~,'/ .~"~- ~--- ,2.~ PROGRAM: exp [] dev,~ redrll [] serv [] wellbore seg II ann. disposal para req ~ FIELD&POOl._ ....... COMPANY ~.,~,~.-.~. ~ INIT CLASS _~ff~._ /'-~ ~/ GEOL AREA ~ ~'~ UNIT#_ .//¢.,/_~:~__. ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................. 4 Well located in a defined pool .................. 5. Well Iocaled proper dislance 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 ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING AP. PR.. OA-rE 14. Conductor string provided ................... 15. Stuface casing protects all known USDWs ........... 16. CMl vol adequate to circulate on conductor & surf csg ..... 17. CM 1 vol adequate to tie-in long string to surf csg ........ 18. CMl' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~00~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. -' N Y N N N N ~N IIGEOLOGY ANNULAR DISPOSAL 35. APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presenled on potential overpressure zones ....... Y .,,H"' ,,all ,,/'? ................................................... 32. Seismic analysis of shallow gas zones ..... ' ........ /Y/N 33. Seabed condition survey (if off-shore) ............. /Y N ................................................................................................................. 34. Contacl name/phone for weekly progress reports ....... / Y N ....... [exploratory only] ......................... : .................................... ~ :z ................................................................... With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will nol impair mechanical integrity of the well used for disposal; (D) will nol damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N G.E.'_O..~,.QO G Y: ENGINEERING: UIC/Annular BEW~ ~ ~f~.~A/M ............ JDI~ COMMISSION: RNC CO ¢_.~~ Comments/Instructions: M c:h(!l,,hsl u~v 0512919R Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. % o4oap RECEIVED .............................. A~ Oil & GasCons. . * ALASKA COMPUTING C~ER . ............................ ....... SCHL~ERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-215 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASF~ API NUMBER : 501032028000 REFERENCE NO : 99151 LIS Tape Verifit-a~ion Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/04/16 ORIGIN : FLIC REEL NAME : 99151 CONTINUATION # : PREVIOUS REEL : CO~4MENT · ARCO ALASKA, 2T-215, PRUDHOE BAY, API #50-103-20280-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/04/16 ORIGIN · FLIC TAPE NAME : 99151 CONTINUATION # : 1 PREVIOUS TAPE .. CO~4MENT : ARCO ALASKA, 2T-215, PRUDHOE BAY, API #50-103-20280-00 TAPE HEADER KUPAR UK OPEN HOLE WIRELINE 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN1 99151 B BOEH~fE WESTER WELL CASING RECORD 1ST STRING 2ND STRING 2T-215 501032028000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 16-APR-99 RUN 2 RU}7 3 .......... 1 lin 8E 729 558 110.28 29.88 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4472.0 LIS Tape Verifit~6ion Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED OPEN HOLE PEX AND HALS DATA AQUIRED ON ARCO ALASKA'S 2T-215 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE '. 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE '. FILE HEADER FILE NUMBER: 1 EDITED MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged. DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE SDN CNT DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4963.0 4428.0 4928.0 4428.0 4953.0 4461.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTIANS THEMAIN PASS EDITED DATA. THE CURVES ARE CLIPPED AT FIRST READING ANDATLAST READING. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... SDN CNT DLL RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape VerifS=~ion Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43~ ~J PAGE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1217535 O0 000 O0 0 1 1 GR SDN GAPI 1217535 O0 000 O0 0 i 1 SP SDN MV 1217535 O0 000 O0 0 1 1 TENS SDN LB 1217535 O0 000 O0 0 1 1 DEV SDN DEG 1217535 O0 000 O0 0 1 1 CNTC CNT CPS 1217535 O0 000 O0 0 1 1 CFTC CNT CPS 1217535 O0 000 O0 0 1 1 FCNT CNT CPS 1217535 O0 000 O0 0 1 1 NCNT CNT CPS 1217535 O0 000 O0 0 1 1 CRAT CNT 1217535 O0 000 O0 0 1 1 NRAT CNT 1217535 O0 000 O0 0 i 1 NPHI CNT PU-S 1217535 O0 000 O0 0 1 1 TNPH CNT PU-S 1217535 O0 000 O0 0 1 1 CALl SDN IN 1217535 O0 000 O0 0 1 1 DRHO SDN G/C3 1217535 O0 000 O0 0 1 1 PEF SDN BN/E 1217535 O0 000 O0 0 1 1 RHOB SDN G/C3 1217535 O0 000 O0 0 1 1 MSFL SDN 0H~941217535 O0 000 O0 0 1 1 MINVSDN Oh?4~ 1217535 O0 000 O0 0 1 1 ~NOR SDN OH~M 1217535 O0 000 O0 0 1 1 LLD DLL Otff4M1217535 O0 000 O0 0 1 1 LLS DLL OHNk~1217535 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 PAGE: ** DATA ** DEPT. 4963.000 GR.SDN DEV. SDN 57.045 CNTC. CNT NCNT. CNT -999.250 CRAT. CNT TNPH. CNT -999.250 CAL1.SDN RHOB.SDN -999.250 MSFL.SDN LLD.DLL -999.250 LLS.DLL DEPT. 4428.000 GR.SDN DEV. SDN 55.274 CNTC. CNT NCNT. CNT 952.707 CRAT. CNT TNPH. CNT 51.344 CAL1.SDN RHOB.SDN -999.250 MSFL.SDN LLD.DLL -999.250 LLS.DLL -999.250 SP.SDN -999.250 CFTC. CNT -999.250 NRAT. CNT -999.250 DRHO.SDN -999.250 MINV. SDN -999.250 82.731 SP. SDN 1057.609 CFTC. CNT 3.842 NRAT. CNT -999.250 DRHO.SDN -999.250 MINV. SDN -999.250 -999.250 TENS.SDN -999.250 FCNT. CNT -999.250 NPHI.CNT -999.250 PEF. SDN -999.250 I4NOR.SDN 372.563 TENS.SDN 262.732 FCNT. CN~f 3.935 NPHI.CNT -999.250 PEF. SDN -999.250 ~iNOR.SDN 2392.000 -999.250 -999.250 -999.250 -999.250 2482.000 237.245 49.602 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN N-UMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 FILE SU~ff~RY LIS Tape VerifiC-ation Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43~'' PAGE .. VENDOR TOOL CODE START DEPTH PEX 5010.0 HALS 5010.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~4A RAY HCNT COMPENSATED NEUTRON SDN DENSITY HALS LATEROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OHNM) AT TE~4PERATURE (DEGF) MUD AT MEASURED TE~IPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH LOG STOP DEPTH 4411.1 4411.1 17-MAR-99 8C0-205 900 17-MAR-99 1700 17-MAR-99 4967.0 4963.0 4428.0 4963.0 TOOL NUMBER ........... HGR HCNT HRDD HALS-B 8.500 4472.0 4461.0 BARADRIL-N 9.60 46.0 8.0 4.0 150.0 O. 820 65.0 O. 680 65.0 1.230 65.0 THERMAL SANDSTONE 2.65 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 PAGE: LOG ASSUMES A SANDSTONE MATRIX=2.65 G/C3 MDEN BOWSPRING RUN ONNEUTRON TOOL THIS FILE CONTAINS THE MAIN PASS RAW DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 136 4 66 1 5 66 6 73 7 65 8 68 O. 166 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 TENS LOG LB 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 TNRA LOG 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR LOG 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 DEVI LOG DEG 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 SP LOG MV 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 NPOR LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HCAL LOG IN 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 LLD LOG OhlV~1217535 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 PAGE: NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) LLS LOG 0H~241217535 O0 000 O0 0 2 1 1 4 68 0000000000 HRLD LOG 0H~1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HRLS LOG 0b24~1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA LOG G/C3 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ LOG 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ LOG G/C3 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 I~4IN LOG 0P24~1217535 O0 000 O0 0 2 1 1 4 68 0000000000 H~NO LOG OH~R41217535 O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ LOG OH2V~l 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RX08 LOG OHFR~1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HCNT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HCFT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HGR LOG GAPI 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RHFT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 RHNT LOG CPS 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 DPHZ LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HTNP LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 HNPO LOG PU 1217535 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5009.992 TENS.LOG TNRA.LOG 2.632 GR.LOG RCNT. LOG 1562.108 DEVI.LOG TNPH.LOG 27.858 NPOR.LOG LLS.LOG 60000.000 HRLD.LOG PEFZ.LOG -999.250 RHOZ.LOG RXOZ.LOG 2.482 RXO8.LOG HGR.LOG 124.728 RHFT.LOG HTNP.LOG 27.858 HNPO.LOG DEPT. TNRA.LOG RCNT. LOG TNPH.LOG LLS.LOG PEFZ.LOG RXOZ.LOG HGR.LOG HTNP.LOG 4411.158 4.233 891 750 47 462 -999 250 -999 250 -999 250 -999 250 -999 250 TENS.LOG GR.LOG DEVI.LOG NPOR.LOG HRLD.LOG RHOZ.LOG RXO8.LOG RHFT.LOG HNPO.LOG 625.000 124 728 -999 250 27 180 45000 000 -999 250 2 485 575.639 27.180 2486.531 79.776 55.345 46.979 -999.250 -999.250 -999.250 -999.250 -999.250 CNTC.LOG 1739.853 CFTC.LOG RTNR.LOG 2.801 RCFT.LOG SP.LOG 158.813 NPHI.LOG HCAL.LOG 7.827 LLD.LOG HRLS.LOG 2166.915 HDRA.LOG H~4IN. LOG 0.154 B2viNO.LOG HCNT.LOG 1739.854 HCFT.LOG RHNT.LOG 1562.108 DPHZ.LOG CNTC.LOG 1052.568 CFTC.LOG RTNR.LOG 4.566 RCFT.LOG SP.LOG 372.563 NPHI.LOG HCAL.LOG -999.250 LLD.LOG HRLS.LOG -999.250 H72RA.LOG HT4IN. LOG -999.250 B2~INO.LOG HCNT. LOG -999.250 HCFT.LOG RHNT.LOG -999.250 DPHZ.LOG 682.396 575.639 29.243 60000.000 -999.250 0.207 682.396 60721.211 277 751 224 078 56 751 -999 250 -999 250 -999 250 -999 250 -999250 ** END OF DATA ** LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43 PAGE **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW REPEAT PASS Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SO?~fARY VENDOR TOOL CODE START DEPTH PEX 4945.0 HALS 4945.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH .......... 4374.7 4374.7 17-MAR-99 8C0-205 900 17-MAR-99 1700 17-MAR-99 4967.0 4963.0 4428.0 4963.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~4MA RAY HCNT COMPENSATED NEUTRON SDN DENSITY TOOL NUMBER HGR HCNT HRDD LIS Tape Verif~-c~tion Listing Schlumberger Alaska Computing Center . , 16-APR-1999 10:43-~ PAGE: HALS LATEROLOG HALS- B BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 4472.0 4461.0 BOREHOLE CONDITIONS MUD TYPE: BARADRIL-N MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) : 46.0 MUD PH: 8.0 FLUID LOSS (C3): 4.0 MAXIMUM RECORDED TEMPERATURE (DEGF): 150.0 RESISTIVITY (OF~gff) AT TEMPERATURE (DEGF) : MUD AT NiEASURED TEMPERATURE (MT): O. 820 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 680 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 1.230 MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): R~VzARKS : PRIMARY DEPTH LOG LOG ASSUMES A SANDSTONE MATRIX=2. 65 G/C3 ~4DEN BOWSPRING RUN ON NEUTRON TOOL THIS FILE CONTAINS THE RAW REPEAT PASS DATA. $ LIS FORMAT DATA 65.0 65.0 65.0 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 136 4 66 1 5 66 6 73 7 65 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43''~'' PAGE: 10 TYPE REPR CODE VALUE 8 68 0.166 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RPT LB 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 TNRARPT 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 GR RPT GAPI 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR RPT 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RCNTRPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI RPT DEG 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 SP RPT MV 1217535 O0 000 O0 0 3 1 ! 4 68 0000000000 NPHI RPT PU 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH RPT PU 1217535 O0 000 O0 0 3 1 I 4 68 0000000000 NPOR RPT PU 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HCAL RPT IN 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 LLD RPT 0tflv~1217535 O0 000 O0 0 3 1 1 4 68 0000000000 LLS RPT OHMM1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HRLD RPT 0H~4~1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HRLS RPT OHMM1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA RPT G/C3 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ RPT 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ RPT G/C3 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HMIN RPT OHMM 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 h?/INORPT 0tfiv~1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ RPT Otfi~M1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RX08 RPT OH~M 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HCNT RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HCFT RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HGR RPT GAPI 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RHFT RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 RHNT RPT CPS 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ RPT PU 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HTNP RPT PU 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 HNPO RPT PU 1217535 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43~'' PAGE: 11 ** DATA ** DEPT. TNRA . R P T RCNT. RPT TNPH. RPT LLS. RPT PEFZ. RPT RXOZ . RPT HGR. RPT HTNP. RPT 4945 000 3 159 1475 629 35 132 4 131 -999 250 3 353 129.331 35.206 TENS. RPT GR. RPT DEVI. RPT NPOR. RPT HRLD. RPT RHOZ . RPT RX08. RPT RHFT. RPT P~NPO. RPT DEPT. 4374.667 TENS.RPT TNRA . RPT 3. 981 GR. RPT RCNT.RPT 1033. 758 DEVI.RPT TNPH. RPT 48. 671 NPOR. RPT LLS.RPT -999.250 HRLD.RPT PEFZ.RPT -999.250 RHOZ.RPT RXOZ.RPT -999.250 RXO8.RPT HGR.RPT -999.250 RHFT.RPT HTNP.RPT -999.250 HNPO.RPT 2795.000 CNTC.RPT 129.115 RTNR.RPT -999.250 SP.RPT 35.096 HCAL.RPT 4.548 HRLS.RPT -999.250 H~IN. RPT 3.349 HCNT.RPT 460.786 RHNT.RPT 34.909 2585.000 CNTC.RPT 79.645 RTNR.RPT 55.137 SP.RPT 44.711 HCAL.RPT -999.250 HRLS.RPT -999.250 H~IN. RPT -999.250 HCNT.RPT -999.250 ~.RPT -999.250 1673.632 CFTC.RPT 3.288 RCFT.RPT 165.688 NPHI.RPT 7.914 LLD.RPT 3.868 PZDRA.RPT 0.841 H~INO.RPT 1675.683 HCFT.RPT 1486.710 DPHZ.RPT 1050.382 CFTC.RPT 4.506 RCFT. RPT 344.813 NPHI.RPT -999.250 LLD.RPT -999.250 PZDRA.RPT -999.250 HFiNO.RPT -999.250 HCFT.RPT -999.250 DPHZ.RPT 554.231 470.885 37.860 4.831 -999.250 1.081 554.035 60721.211 271.881 257.531 52.207 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 99/04/16 ORIGIN ' FLIC TAPE NAME : 99151 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, 2T-215, PRUDHOE BAY, API #50-103-20280-00 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 16-APR-1999 10:43'~ PAGE: 12 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/04/16 ORIGIN : FLIC REEL NAME : 99151 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, 2T-215, PRUDHOE BAY, API #50-103-20280-00 Sperry-Sun Drilling Services LIS Scan Utility Thu May 20 11:37:03 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 99/05/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific RECEIVED Physical EOF Comment Record TAPE HEADER TABASCO 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: MWD RUN 1 AK-MM- 90049 J. MlkRTIN D. LUTRICK Mz Y 21 1999 Alaska Oit & Gas Cons, Commi~ Anchorage 2T-215 501032028000 ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 20-MAY-99 MWD RUN 3 MWD RUN 4 AK-MM-90049 AK-MM- 90049 J. MARTIN M. HALL D. LUTRICK D. GLADDEN 1 lin 08E 729 556 110.30 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 110.30 80.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 16.000 110.0 12.250 9.625 4465.0 8.500 4967.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY P~IASE-4 (EWR4) . MWD RUN 2 MADE NO FOOTAGE AND IS NOT PRESENTED. THIS HOLE SECTION WAS DRILLED BY RIG DOYON 19 WITH KBE 117.55' AMSL. 3. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS. THIS SECTION OF HOLE WAS DRILLED BY RIG NORDIC 3 WITH KBE 110.28' AMSL. 4. MWD RUNS 1 AND 3 ARE DEPTH CORRECTED UPWA/~D 7.3', AND MERGED DATA IS DEPTH SHIFTED TO THE SWS PEX GR OF 03/99. PDC KBE IS 110.28' 5. MWD RUNS 1-4 REPRESENT WELL 2T-215 WITH API# 50-103-20280-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4967'MD, 3348'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI/MBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH STOP DEPTH 84.5 4948.5 93.5 4424.0 93.5 4424.0 93.5 4424.0 93.5 4424.0 131.5 4424.0 133.0 4957.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 84.5 4433.0 4456.5 4458 5 4466 0 4494 0 4530 0 4544 5 4559 0 4565 5 4576.0 4588.5 4608.5 4620.0 4626.0 4667.5 4672.0 4676.0 4686.0 4692.0 4712.5 4734.0 4750.0 4754.0 4758.0 4770.5 4782.0 4789.5 4799.0 4804.0 4808.5 4823.0 4829.5 4841.0 4843.0 4862.5 4900.0 4905.5 EQUIVALENT UNSHIFTED DEPTH GR 92.0 4440.5 4464.0 4466.5 4474.0 4502.5 4538.5 4551.5 4566.5 4572.5 4583.5 4596.5 4616.5 4629.5 4635.5 4677.0 4680.5 4683.0 4693.5 4700.0 4721.0 4742.5 4758.5 4762.0 4765.5 4778.0 4790.5 4798.0 4807.5 4811.5 4816.0 4830.5 4837.0 4849.0 4850.5 4870.0 4907.5 4914.0 4916.0 4924.5 4916 . 5 4926 . 0 4918 . 0 4928 . 0 4920.5 4930.5 4957.5 4967.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 3 MWD 4 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 110.0 3525.0 4470.0 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 ...................... -999.25 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 MERGE BASE 3525.0 4470.0 4967.0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 84.5 4957.5 2521 9747 ROP 2 2813.38 151.834 9650 GR 10.3056 150.154 82.4859 9729 RPX 1.0729 2000 28.7414 8662 RPS 0.2256 2000 43.638 8662 RPM 0.3438 2000 89.802 8662 RPD 0.3462 2000 176.856 8662 FET 0.1213 49.8425 1.01743 8586 First Reading 84.5 133 84.5 93.5 93.5 93.5 93.5 131.5 Last Reading 4957.5 4957.5 4948.5 4424 4424 4424 4424 4424 First Reading For Entire File .......... 84.5 Last Reading For Entire File ........... 4957.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 ~ DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 92.0 3477.0 RPD 101.0 3487.0 RPM 101.0 3487.0 RPS 101.0 3487.0 RPX 101.0 3487.0 FET 139.0 3487.0 ROP 140.5 3525.0 $ LOG HEADER DATA DATE LOGGED: 25-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: ISC 5.07 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 3532.0 TOP LOG INTERVAL (FT) : 117.0 BOTTOM LOG INTERVAL (FT) : 3532.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .5 MAXIMUM ANGLE: 64.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DUAL GAMMA P_AY ELECTROMAG. RESIS. 4 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 TEMPEPGATURE (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Pl158CRG8 Pl158CRG8 12.250 12.3 SPUD 9.50 116.0 8.6 200 5.2 5.000 3.773 8.000 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD 1 HOUR 4 1 68 4 2 RPD MWD 1 OHMM 4 1 68 8 3 RPM MWD 1 OHMM 4 1 68 12 4 RPS MWD 1 OHMM 4 1 68 16 5 RPX MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 GR MWD 1 API 4 1 68 28 8 32.8 First Last Name Min Max Mean DEPT 92 3525 1808.5 FET 0.1213 7.9161 0.566783 RPD 0.3462 2000 224.185 RPM 0.3438 2000 112.946 RPS 0.2256 2000 53.9167 RPX 1.0729 2000 35.0186 ROP 8.9221 2486.61 174.203 GR 10.3056 140.301 72.2653 Nsam 6867 6697 6773 6773 6773 6773 6770 6771 Reading 92 139 101 101 101 101 140.5 92 Reading 3525 3487 3487 3487 3487 3487 3525 3477 First Reading For Entire File .......... 92 Last Reading For Entire File ........... 3525 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3477.5 FET 3488.5 RPD 3488.5 RPM 3488.5 RPS 3488.5 RPX 3488.5 ROP 3527.5 $ LOG HEADER DATA STOP DEPTH 4420.0 4431.5 4431.5 4431.5 4431.5 4431.5 4469.5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 $ BOREHOLE ~ 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~2qDOFF (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 ...................... -999.25 Depth Units ....................... 27-DEC-98 ISC 5.07 iSC 5.07 MEMORY 4477.0 3532.0 4477.0 55.4 62.6 TOOL NLTMB ER Pl182CRG8 Pl182CRG8 12.250 12.3 SPUD 9.60 88.0 8.6 200 5.5 4.500 3.441 6.500 5.000 32.8 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 FET MWD 3 HOUR 4 1 RPD MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPS MWD 3 OHMM 4 1 RPX MWD 3 OHMM 4 1 ROP MWD 3 FT/H 4 1 GR MWD 3 API 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 3477.5 4469.5 3973.5 FET 0.2375 49.8425 2.59101 RPD 3.2104 19.58 7.16264 RPM 2.8858 20.6874 6.82037 RPS 2.8378 22.0269 6.78542 RPX 2.7098 19.6094 6.23611 ROP 20.626 2813.38 115.95 GR 68.8811 150.154 106.409 First Last Nsam Reading Reading 1985 3477.5 4469.5 1887 3488.5 4431.5 1887 3488.5 4431.5 1887 3488.5 4431.5 1887 3488.5 4431.5 1887 3488.5 4431.5 1885 3527.5 4469.5 1886 3477.5 4420 First Reading For Entire File .......... 3477.5 Last Reading For Entire File ........... 4469.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NLTMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4420.5 ROP 4470.0 $ 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: STOP DEPTH 4958.5 4967.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): 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 17-MAR-99 ISC 5.07 ISC 5.07 MEMORY 4967.0 4465.0 4967.0 55.0 57.1 TOOL NUMBER P1251CG6 8.500 8.5 BA/~DRILL-N 9.60 49.0 8.0 4_.0 .000 .000 .000 .000 26.7 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4420.5 4967.5 4694 1095 4420.5 ROP 1 154 67.7711 996 4470 GR 43.91 145.93 104.973 1077 4420.5 Last Reading 4967.5 4967.5 4958.5 First Reading For Entire File .......... 4420.5 Last Reading For Entire File ........... 4967.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/05/20 Origin ................... STS Reel Name ................ UNKNOWN Scientific Continuation Number..' .... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File
