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Home My WebLink About185-023 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 8040'feet 7675'feet true vertical 6301'feet 7742', 7874'feet Effective Depth measured 7874'feet 7261', 7491'feet true vertical 6171'feet 5691', 5868'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7655' MD 5998' TVD Packers and SSSV (type, measured and true vertical depth) 7261' MD 7491' MD N/A 5691' TVD 5868' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River 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: 3658' 3211' Burst Collapse Production Liner 7999' Casing 6289'8023' 3628' 117'Conductor Surface Intermediate 16" 9-5/8" 84' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-023 50-029-21286-00-00 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: ADL0025633, ADL0025642 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3B-13 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) 231 bopd Gas-Mcf MD 1311 psi Size 117' 4473 bwpd 1294 psi603 mcfd 161 bopd 151 psi3822 bwpd 171 psi N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 548 mcfd Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer Packer: NS Liner Top Packer SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Senior RWO /CTD Engineer 7548-7601', 7714-7762', 7780-7808' feet 5914-5956', 6044-6082', 6096-618' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 9:00 am, Dec 15, 2022 DTTMSTART JOBTYP SUMMARYOPS 10/19/2022 SUPPORT OTHER OPERATIONS SHAKE OFF BAITED PULLING TOOL ABOVE BALL & ROD @ 7600' RKB; PULLED SOV & SET DV @ 7223' RKB; PULLED DV & SET OV @ 4921' RKB; PULLED DV & SET GLV @ 3132' RKB (OBTAIN GOOD TBG TEST); PULLED BAITED PULLING TOOL & BALL n' ROD @ 7644' RKB. IN PROGRESS. 10/20/2022 SUPPORT OTHER OPERATIONS PULLED 2.813" RHC PLUG BODY @ 7638' RKB; DRIFT W/ DMY CEMENT RETAINER DOWN TO 7643' RKB; PERFORMED STEP RATE INJECTIVITY TEST FROM .5 UP TO 2 BPM @ 775 PSI. READY FOR CTU. 10/28/2022 SUPPORT OTHER OPERATIONS 8.5 HOURS OF NPT DUE TO HYDRAULIC HOSE FAILURE, PERFORM TIE IN LOG FROM 7666'' CTMD TO 7000' CTMD AT 50 FPM, STACKED DOWN LUBRICATOR TO REPLACE LEAKING HYDRAULIC HOSE 10/29/2022 SUPPORT OTHER OPERATIONS REPLACED LEAKING HYDRAULIC HOSE ON THE MAST, SET CEMENT RETAINER AT 7640' RKB, PUMP 5 BBLS OF 15.8# CLASS G CEMENT BELOW RETAINER, UN-STING FROM RETAINER AND CIRCULATE 25 BBLS OF POWER-VIS FOLLOWED BY DIESEL TO SURFACE, READY FOR SLICKLINE, IN PROGRESS. 10/31/2022 SUPPORT OTHER OPERATIONS RUN 2.62" X 10' DMY WHIP STOCK DRIFT TO TOP OF CEMENT RETAINER @ 7640' RKB, NO TIGHT SPOTS OR WEIGHT SWINGS, CALIPER TBG FROM 7640' RKB TO 6640' RKB, REQUESTED QUICK TURN AROUND FOR CALIPER DATA. STILL NEED TO MIT-T TBG. 11/1/2022 SUPPORT OTHER OPERATIONS MIT-T TO 1500 PSI *PASSED*. PUMPED 0.4 BBLS DSL DOWN TBG TO REACH TEST PRESSURE. BLED TBG, BLED BACK 0.4 BBLS. RDMO. (JOB COMPLETE) 11/4/2022 DRILLING SIDETRACK MOB 3G to 3B-13, Complete initial BOPe test, test witnessed by Brian Bixby, AOGCC. PT deployment lubricators and tiger tank line. 11/5/2022 DRILLING SIDETRACK Set TOWS @ 7580 HS milled window from TOW 7584' to BOW 7592 'drilled 13' of rat hole 7605' ' reamed window / reamed through 30° ROHS & 30° LOHS dry drift. Drill build section 7605 to 7755'. AVG DLS 37.75° 11/6/2022 DRILLING SIDETRACK P/U build section BHA. Drill build to 7755'. Trip for lateral BHA. High bend motor hung in tree. Get free. PD BHA #4 lateral assembly drilling from 7755' toward TD 11/7/2022 DRILLING SIDETRACK Tripped OOH to pick up a 1.2° AKO motor not able to get the .5° to drop. Still having troubles getting the 1.2° to drop time drill trying to get it to drop 11/8/2022 DRILLING SIDETRACK Drilled to 9,796'. POOH to pick up 0.5° AKO motor. While POOH found two broken chain links during injector inspection. Continue to POOH. PUD BHA #5. Swap and function test new Injector. 11/9/2022 DRILLING SIDETRACK Finish function testing Injector. Pull test and stab pipe. PD BHA #6. Perform shallow BHA test @ 500'. Good test. Open EDC. Injector began sending error codes. Troubleshoot. Replaced bad encoder. RIH to 1,505'. Cont. to experience injector issues. Troubleshoot derrick side motor/chains. Found right angle drive seized. Replacement sent from Deadhorse. 11/10/2022 DRILLING SIDETRACK Install new right angle drive and injector motor. Function test. RIH and tie into K-1 marker for -11' correction. Perform MADD pass from 8050' - 8550' sensor depth. RIH and drill from 9,775' - 9,915'. Had difficulty dropping. Make troughing pass and time drill to 9,935'. Drilled ahead from 9,935' to 10,434' where ROP and motor work fell off. 11/11/2022 DRILLING SIDETRACK Made multiple attempts to drill past 10,434' without success. POOH and PUD BHA #6. Inspect. Found Baker motor had failed. Function test BOP's. MU and PD BHA #7 with new motor. RIH and tied into K-1 for a -15' correction. Drilled from 10,434' to 11,250'. 11/12/2022 DRILLING SIDETRACK Performed short wiper #2. RBIH and drilled from 11,250' to 11,650' using beaded sweeps. Perform long wiper to window. Jet 4 1/2" tubing. Tie into K1 for +2.5' correction. RBIH. 4' from bottom well started taking fluid. Holding 11.4# at the window. Returns dropped to 0.3 - 0.5 BPM. Discuss with Town. Closed choke and drill ahead on 100% losses toward TD. Drilled to midnight depth of 12,066'. 11/13/2022 DRILLING SIDETRACK Drilled to 12,260' when BHA packed off. POOH. PUD BHA #7. Found Strider ERT tool locked up. PD and RIH with BHA #8 - motor, NOV agitator, re-run bit. Tie into K-1 for -14' correction. Cont. RIH to set down at 12,233'. Washed down to 12,240'. See sticky PU's and signs of pack-off, potential D-shale. Perform swab wiper from 12,240'. At surface @ midnight. KRU 3B-13 CTD Summary of Operations 11/14/2022 DRILLING SIDETRACK RBIH. Tie into K-1 for a -13' correction. Gather BHP at 7,560'. Confirm KWF of 11.4#. Cont. RIH to TD. Set down @ 12,263'. Circulate 11.4# LRP to bit. POOH laying in LRP. Lay down BHA #8. PU L1 lower liner section (40 joints slotted). RIH and set lower liner section @ 12,263'. TOL section @ 10,993'. Lay in LRP. POOH. Lay bown BHA #9. At midnight, PU L1 interm. liner section (47 joints). 11/15/2022 DRILLING SIDETRACK RIH with L1 interm. liner section. (47 joints slotted). Tie into window flag for -2.5' correction. Cont. RIH and set down at 10,993'. Confirm latched and release from liner. Lay in LRP. POOH. LD BHA #10. MU BHA #11 - upper liner section. RIH set on depth, pooh freeze protect F/2500', undeploy bha, flush stack and blow down lines, start rdmo 11/18/2022 MAINTAIN WELL PT FL WITH 10 BBLS DSL ( JOB COMPLETE) 11/20/2022 SUPPORT OTHER OPERATIONS TAG LINER TOP W/ MAG STEM & 2.68" MAGNET @ 7497' RKB; MEASURED BHP (2603 PSI) @ 7497' RKB; DISPLACE TBG W/ 65 BBLS OF DIESEL WHILE BRUSH n' FLUSHING TBG ALONG WITH INSIDE OF LINER TOP; SET 3.5" NORTHERN SOLUTIONS LINER TOP PACKER (SN: NS9027) W/ 1.78" R PLUG & SEAL GUIDE @ 7491' RKB; OBTAIN GOOD TBG TEST & PULLED 1.78" R PLUG & SEAL GUIDE @ 7599' RKB. JOB COMPLETE. Page 1/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/4/2022 00:00 11/4/2022 02:30 2.50 MIRU, MOVE MOB P PJSM with Cruz, Jack up and pull pit module off well. Install jeep on pits. Jack up sub. Pull off well 0.0 0.0 11/4/2022 02:30 11/4/2022 04:30 2.00 MIRU, MOVE MOB P On the road to 3B 0.0 0.0 11/4/2022 04:30 11/4/2022 05:30 1.00 MIRU, MOVE MOB P On location, Pull jeeps off, Set mats, R/U cellar spill containment 0.0 0.0 11/4/2022 05:30 11/4/2022 06:30 1.00 MIRU, MOVE MOB P Spot sub over well. Place mats. Set down sub 0.0 0.0 11/4/2022 06:30 11/4/2022 07:30 1.00 MIRU, MOVE MOB P Spot pit module 0.0 0.0 11/4/2022 07:30 11/4/2022 08:30 1.00 MIRU, MOVE MOB P Safe out rig, stairs and landing. Emergency exits. 0.0 0.0 11/4/2022 08:30 11/4/2022 12:00 3.50 MIRU, MOVE RURD P MIRU, Rig up interconnect, Rig up cellar contanment, Spot is shop and half way house, Prep for BOPE test 0.0 0.0 11/4/2022 12:00 11/4/2022 12:12 0.20 MIRU, MOVE SFTY P Crew change out, PJSM, Nipple up BOPE, Accept Rig 12:00 0.0 0.0 11/4/2022 12:12 11/4/2022 14:24 2.20 MIRU, MOVE NUND P Nipple up BOPE, Grease crew out to service tree 0.0 0.0 11/4/2022 14:24 11/4/2022 15:42 1.30 MIRU, MOVE NUND P Flood stack, get final valve alignment 0.0 0.0 11/4/2022 15:42 11/4/2022 15:54 0.20 MIRU, MOVE BOPE P Shell test BOPE to 3500 PSI 0.0 0.0 11/4/2022 15:54 11/4/2022 16:54 1.00 MIRU, WHDBOP BOPE P Start full BOPE test. Test witnessed by Brian Bixbie AOGCC, 250 low, 3500 PSI high Test one swab valve # 2- Good Test two, Blind shear, TV2, C-4,5,8, &12 - Good Test three, TV1, C 3,6,7,11 0.0 0.0 11/4/2022 16:54 11/4/2022 22:30 5.61 MIRU, WHDBOP BOPE P Test four, Super choke C, Manual Choke D Good Test five Charlie1 & 3 & Tango 1 - Good test Test six lower2" pipe slips TIW , R1 & BL1 Good test Test seven Annular - Good test Test eight upper 2" pipe slps Bravo 6 , 8 Lower TIW -Good test 'Test nine Bravo 7 , 5 Fail ' Pass - Good test Test ten 2 3/8" pipe rams - Good Test Draw down test Accumulator - Pass Test striper & inner reell valve - Good 0.0 0.0 11/4/2022 22:30 11/4/2022 23:30 1.00 MIRU, WHDBOP BOPE P Test taiger tank line Test PDL'S Check Accumulator bottles pre charge 0.0 0.0 11/4/2022 23:30 11/5/2022 00:00 0.50 PROD1, WHPST BOPE P Prep to pick up Whipstock & baker BHA 0.0 0.0 11/5/2022 00:00 11/5/2022 00:00 0.00 PROD1, WHPST PULD P PJSM PD whipstock & baker tools 0.0 0.0 11/5/2022 00:00 11/5/2022 02:00 2.00 PROD1, WHPST WPST P Have to RE- WIRE UQC 0.0 0.0 11/5/2022 02:00 11/5/2022 03:00 1.00 PROD1, WHPST WPST P M/U QC stab injector tag up set depths RIH 74.7 7,410.0 11/5/2022 03:00 11/5/2022 05:30 2.50 PROD1, WHPST WPST P At 7410 tie into K-1 -2' Correction close EDC set top of whipstock 7580' bottom 75892.7 set 3 k down 7.0 7,598.0 11/5/2022 05:30 11/5/2022 07:06 1.60 PROD1, WHPST WPST P Open EDC POOH 7,598.0 73.0 11/5/2022 07:06 11/5/2022 08:12 1.10 PROD1, WHPST WPST P At surface, Tag up, Space out, PUD BHA #1 73.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 2/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/5/2022 08:12 11/5/2022 09:12 1.00 PROD1, WHPST WPST P PD BHA #2 window milling BHA with 1° fixed bend motor, 2.80 window mill, and 2.80 string reamer. Make up to coil and surface test. Stab on injector. Tag up and set counters 0.0 78.3 11/5/2022 09:12 11/5/2022 10:48 1.60 PROD1, WHPST WPST P RIH, BHA #2, shallow test BHA @ 500'. Diff 900 PSI. Continue in 78.3 7,440.0 11/5/2022 10:48 11/5/2022 11:00 0.20 PROD1, WHPST WPST P Log K1 for no correction, PUW=28K 7,440.0 7,467.0 11/5/2022 11:00 11/5/2022 11:18 0.30 PROD1, WHPST WPST P Continue in well, displace to milling fluid, shut EDC. ease in to dry tag whipstock. 7,467.0 7,584.0 11/5/2022 11:18 11/5/2022 11:24 0.10 PROD1, WHPST WPST P PUH, PUW=28K, Bring pumps online 1.8 BPM @ 4577 PSI FS, 635 PSI Diff, BHP=3430 7,584.0 7,584.1 11/5/2022 11:24 11/5/2022 14:18 2.90 PROD1, WHPST WPST P 7584.1, Milling window 1.8 BPM @ 4577 PSI FS, Diff=711 7,584.1 7,587.5 11/5/2022 14:18 11/5/2022 16:18 2.00 PROD1, WHPST WPST P Started loosing fluid, ~ .8 BPM, WHP=240 PSI. Oened up choke zero WHP. ECD=11.06. Pump 150+ LSRV hi vis pill. Little to no effect on returns 7,587.5 7,589.7 11/5/2022 16:18 11/5/2022 18:50 2.54 PROD1, WHPST WPST P Try working WHP up to increase ECD's at window before full exit, 40 PSI WHP 11.1PPG ECD @ .3 BPM losses 7,589.7 7,605.0 11/5/2022 18:50 11/5/2022 22:30 3.66 PROD1, WHPST WPST P Exit window BOW 7592' bottom of rat hole 7605' ream window ream through window 30° right and 30° left dry drift clean drift tagged at 7605' pumped a 5x5 gel sweep 7,605.0 7,605.0 11/5/2022 22:30 11/6/2022 00:00 1.50 PROD1, WHPST WPST P POOH PU WT 31 k chase 5x5 to surface At 500' continue OOH 7,605.0 7,605.0 11/6/2022 00:00 11/6/2022 00:18 0.30 PROD1, DRILL PULD P PUD window milling assembly L/D BHA mill 2.79" no go tsing reamer 2.80" no go stab back on well jet BOP stack 0.0 0.0 11/6/2022 00:18 11/6/2022 01:18 1.00 PROD1, DRILL PULD P PJSM PD Build section drilling BHA #3 0.0 0.0 11/6/2022 01:18 11/6/2022 02:18 1.00 PROD1, DRILL TRIP P M?U QC stab injector on well tag up set depth RIH 72.2 7,605.0 11/6/2022 02:18 11/6/2022 08:36 6.30 PROD1, DRILL DRLG P At 7420 tie into K1 -2' RIH close EDC start drilling @ 7605' Bore 4085 Ann 3510 @ 1.7 BPM pump 4220 WHP 285 7,605.0 7,755.0 11/6/2022 08:36 11/6/2022 10:36 2.00 PROD1, DRILL TRIP P Call EOB, Pump 5 X 5 sweeps, Trip out for lateral BHA 7,755.0 73.0 11/6/2022 10:36 11/6/2022 11:00 0.40 PROD1, DRILL PULD P PJSM, PUD BHA #3 73.0 73.0 11/6/2022 11:00 11/6/2022 15:00 4.00 PROD1, DRILL PULD T High bend motor stuck in tree ~ 22 inches up. Check all tree valves, SSV fully pressured up. Cycle tree valves in attemt to move tools, Cycle bag, Unstab PDL. Hook up to BHA. Change orientation. Stab back on. tool still hung up. Reconfigure injector lubricator to be able to strip on higher tool string. Make up injector. PUH for space out number. RIH to 150' pumping. POOH. Tag up and space out 73.0 74.6 11/6/2022 15:00 11/6/2022 16:00 1.00 PROD1, DRILL PULD T PJSM, PUD BHA # 3 74.6 0.0 11/6/2022 16:00 11/6/2022 17:30 1.50 PROD1, DRILL PULD P Lay down BHA #3 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 3/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/6/2022 17:30 11/6/2022 18:30 1.00 PROD1, DRILL TRIP P M?U BHA #4 lateral assembly .5° AKO motor m/u QC stab injector on well tag up set counters RIH shallow hole test tools 78.2 7,420.0 11/6/2022 18:30 11/6/2022 20:00 1.50 PROD1, DRILL TRIP P At 7420' tie into K1 for a -6' correction 7457.8' AT 7650' WT CK 28 K RIH / WT 15K RA came in at 7587' 7,457.8 7,755.0 11/6/2022 20:00 11/6/2022 20:30 0.50 PROD1, DRILL DRLG P On bottom at 7755' having trouble getting going pump a bottoms up getting lots of sand back packing off 7,755.0 7,450.0 11/6/2022 20:30 11/7/2022 00:00 3.50 PROD1, DRILL DRLG P Got a bottoms up RBIH tagged up at bottom of window made it through window on bottom drilling/ Continue drilling 7,755.0 7,926.0 11/7/2022 00:00 11/7/2022 00:00 0.00 PROD1, DRILL DRLG P Continue drilling current depth 7929' Bore 4695,Ann 3561,Diff 1110, WHP 119, Pump 5200 7,926.0 8,200.0 11/7/2022 00:00 11/7/2022 02:18 2.30 PROD1, DRILL WPRT P At 8200' Wper trip up wt 31K 8,200.0 7,755.0 11/7/2022 02:18 11/7/2022 02:36 0.30 PROD1, DRILL DRLG P pump a 5X5 gel sweep 8,200.0 8,484.0 11/7/2022 02:36 11/7/2022 04:48 2.20 PROD1, DRILL WPRT P At 8484' wiper do to fast drilling came up to 7770' RBIH 8,484.0 8,484.0 11/7/2022 04:48 11/7/2022 06:18 1.50 PROD1, DRILL DRLG P Back on bottom drilling 8,484.0 8,766.0 11/7/2022 06:18 11/7/2022 06:30 0.20 PROD1, DRILL WPRT P Pull BHA Wiper, PUW=30K 8,766.0 8,766.0 11/7/2022 06:30 11/7/2022 07:06 0.60 PROD1, DRILL DRLG P Drill, 1.85 BPM @ 4736 PSI FS, BHP=3636, New mud going around 8,766.0 8,885.0 11/7/2022 07:06 11/7/2022 07:12 0.10 PROD1, DRILL WPRT P BHA wiper, PUW=28K 8,885.0 8,885.0 11/7/2022 07:12 11/7/2022 08:06 0.90 PROD1, DRILL DRLG P Drill, 1.85 BPM @ 4832 PSI FS, BHP=3621 8,885.0 9,050.0 11/7/2022 08:06 11/7/2022 09:06 1.00 PROD1, DRILL WPRT P Long wiper #3 to 7600', Jog 4 1/2 9,050.0 7,600.0 11/7/2022 09:06 11/7/2022 09:12 0.10 PROD1, DRILL DLOG P Log tie in @ RA marker for +2' correction 7,600.0 7,627.0 11/7/2022 09:12 11/7/2022 09:48 0.60 PROD1, DRILL WPRT P Comtinue wiper trip to bottom 7,627.0 9,050.0 11/7/2022 09:48 11/7/2022 12:24 2.60 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4713 PSI FS, BHP=3627 9,050.0 9,452.0 11/7/2022 12:24 11/7/2022 13:54 1.50 PROD1, DRILL TRIP P Unable to drop out of zone, Unable to build out of zone. Trip to dial up motor 9,452.0 72.0 11/7/2022 13:54 11/7/2022 15:00 1.10 PROD1, DRILL PULD P At surface, Tag up space out. PJSM PUD BHA #4 72.0 0.0 11/7/2022 15:00 11/7/2022 16:12 1.20 PROD1, DRILL PULD P PD BHA #5 with RR HYC A3 and 1.2° AKO motor. Surface test tool. Tag up set counters 0.0 78.3 11/7/2022 16:12 11/7/2022 18:00 1.80 PROD1, DRILL TRIP P RIH BHA #5, Shallow test 500', continue in EDC open 78.3 7,420.0 11/7/2022 18:00 11/7/2022 18:42 0.70 PROD1, DRILL DLOG P At 7420' tie into K1 for a -6' correction. continue in hole 7,420.0 9,452.5 11/7/2022 18:42 11/7/2022 19:06 0.40 PROD1, DRILL DRLG P Back on bottom @ 9452.5' Resume drilling Bore 4594 Ann 3675 Diff 1082 WHP 231 PUH up wt 34 K 9,452.5 9,547.5 11/7/2022 19:06 11/7/2022 19:54 0.80 PROD1, DRILL DRLG P Still unable to get motor to turn down try time drilling and back reaming 9,574.5 9,560.0 11/7/2022 19:54 11/8/2022 00:00 4.10 PROD1, DRILL DRLG P Pick up drilling speed 9,578.0 9,578.0 11/8/2022 00:00 11/8/2022 02:36 2.60 PROD1, DRILL DRLG P At 9578' continue drilling ahead 100' wiper 9,578.0 9,795.9 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 4/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/8/2022 02:36 11/8/2022 03:24 0.80 PROD1, DRILL TRIP P Pump a 5X5 gel sweep POOH to pick up a .5° AKO motor 9,795.9 9,716.0 11/8/2022 03:24 11/8/2022 04:00 0.60 PROD1, DRILL TRIP P While doing injector inspection found two broken chain link limp OOH to window 9,716.0 9,716.0 11/8/2022 04:00 11/8/2022 08:18 4.30 PROD1, DRILL TRIP P Continue out of well 9,716.0 77.0 11/8/2022 08:18 11/8/2022 10:00 1.70 PROD1, DRILL PULD P At surface, Tag up. Space out, PUD BHA #5 and lay down, Pull UQC 77.0 0.0 11/8/2022 10:00 11/8/2022 12:00 2.00 PROD1, DRILL CTOP T Prep to unstab CT from injector, Remove CT from injector. Secure CT to storage spool with chain and clamp. 0.0 0.0 11/8/2022 12:00 11/8/2022 17:00 5.00 PROD1, DRILL CTOP T Prep for injector swap. Remove stripper, Move ODS PDLto clear area for injector pick. Remove hydraulic amd electrical lines from injector. Remove diamond plate grating from cart. Install rigging to top of injector. 0.0 0.0 11/8/2022 17:00 11/8/2022 20:00 3.00 PROD1, DRILL CTOP T Crane on location. PJSM. Pick injector from cart and set on rig mats. Prep new injector for crane pick and install. Clean injector cart. Pick new injector. Set in cart. 0.0 0.0 11/8/2022 20:00 11/9/2022 00:00 4.00 PROD1, DRILL CTOP T Reconnect hydraulics and electrical. Troubleshoot load cell. Function test new injector. 0.0 0.0 11/9/2022 00:00 11/9/2022 02:00 2.00 PROD1, DRILL CTOP T Continue to function test new injector. Install gripper blocks. Troubleshoot hydraulic lines. 0.0 0.0 11/9/2022 02:00 11/9/2022 03:30 1.50 PROD1, DRILL CTOP T Install injector guards. Raise injector and trolley injector cart back. Prep for stripper install. 0.0 0.0 11/9/2022 03:30 11/9/2022 08:00 4.50 PROD1, DRILL CTOP T Install stripper and lube line. Load section of 2" coil into injector for max pull test. Pull test new injector to 100K. . Rig up and stab coil to injector. 0.0 0.0 11/9/2022 08:00 11/9/2022 08:30 0.50 PROD1, DRILL CTOP P Rewire UQB, test - Good 0.0 0.0 11/9/2022 08:30 11/9/2022 10:12 1.70 PROD1, DRILL PULD P PJSM, M/U & PD BHA # 6. Make up to cpol and surface test. Tag up set counters 0.0 80.2 11/9/2022 10:12 11/9/2022 11:12 1.00 PROD1, DRILL TRIP P RIH BHA #6, Checking counters and injector operation 80.2 500.0 11/9/2022 11:12 11/9/2022 11:42 0.50 PROD1, DRILL TRIP P 500', Stop and shallow test BHA. 1.84 BPM @5040 PSI FS, 950 PSI Diff, shut down pump. Open EDC. 500.0 500.0 11/9/2022 11:42 11/9/2022 16:00 4.30 PROD1, DRILL TRIP T Injector throwing error codes, VFD related. Trouble shoot to failed encode. replace, RIH. Still getting error messages, Continue trouble shoot / repair 500.0 1,505.0 11/9/2022 16:00 11/9/2022 17:30 1.50 PROD1, DRILL TRIP T PJSM, Shut upper and lower 2" pipe slips. Manually lock in rams. Retract skates to roll injector. Troubleshoot derrick side injector chains. Injector chains do not move freely as they should. 1,505.0 1,505.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 5/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/9/2022 17:30 11/9/2022 18:30 1.00 PROD1, DRILL TRIP T Crew changeout. While troubleshooting injector motor Electricians finger was pinched. IP was sent to medic for evaluation. Reported incident to D&W HSE. Safety stand down performed before continuing any further injector troubleshooting. 1,505.0 1,505.0 11/9/2022 18:30 11/10/2022 00:00 5.50 PROD1, DRILL TRIP T Continued troubleshooting. Found derrick side right angle drive seized up. New right angle drive being sent from Deadhorse. 1,505.0 1,505.0 11/10/2022 00:00 11/10/2022 04:00 4.00 PROD1, DRILL TRIP T Attempt to install new right angle drive. Found shaft splines on new right angle drive do not match injector brake. Requested additional right angle drives from Deadhorse. Test fit good. Install right angle drive and injector motor. 1,505.0 1,505.0 11/10/2022 04:00 11/10/2022 05:00 1.00 PROD1, DRILL TRIP T Function test injector. Roll Chains. Good Test. Manuals out on Pipe/Slip rams. Grab traction. Pull to neutral Coil Wt. of 15.5K lbs. Open Upper and Lower Pipe/Slips. PUH top check coil. 1,505.0 1,505.0 11/10/2022 05:00 11/10/2022 08:00 3.00 PROD1, DRILL TRIP P Continue in well, Pick up every 1000' to check coil for scrape marks. Clean down to tie in 1,505.0 7,420.0 11/10/2022 08:00 11/10/2022 08:24 0.40 PROD1, DRILL DLOG P Log K1 for -11' correction, PUW=35K, Close EDC 7,420.0 7,458.2 11/10/2022 08:24 11/10/2022 08:54 0.50 PROD1, DRILL TRIP P Continue in, Clean through window, Set down 7670 to 7675, Pick up run through 7,458.2 8,090.0 11/10/2022 08:54 11/10/2022 09:54 1.00 PROD1, DRILL DLOG P Perform MADD pass, Sensor 8050 to 8550 sensor depth, 8 FPH 8,090.0 8,600.0 11/10/2022 09:54 11/10/2022 10:36 0.70 PROD1, DRILL TRIP P RIH to drill 8,600.0 9,775.0 11/10/2022 10:36 11/10/2022 11:36 1.00 PROD1, DRILL DRLG P 9820 Drill, 1.86 BPM @ 5179 PSI FS, BHP=3791 PSI 9,775.0 9,915.0 11/10/2022 11:36 11/10/2022 13:30 1.90 PROD1, DRILL DRLG P Unable to drop inclination. PUH for a couple of troughing passes, PUW=39K. Perform troughing pass @ 5 FPM. 1.84 BPM @ 5,007 psi. BHP = 3746 psi. 9,915.0 9,915.0 11/10/2022 13:30 11/10/2022 14:30 1.00 PROD1, DRILL DRLG P Time Drill 1 FPH. WOB = 0.2Klbs. CT Wt = 17.4Klbs. 1.84 BPM. BHP = 3722 psi. 9,915.0 9,916.0 11/10/2022 14:30 11/10/2022 15:30 1.00 PROD1, DRILL DRLG P Time Drill 2 FPH. WOB = 0.2Klbs. CT Wt = 18.7Klbs. 1.84 BPM. BHP = 3727 psi. 9,916.0 9,918.0 11/10/2022 15:30 11/10/2022 16:12 0.70 PROD1, DRILL DRLG P Time Drill 20 FPH. WOB = 0.8Klbs. CT Wt = 13.8Klbs. 1.84 BPM. BHP = 3727 psi. 9,918.0 9,935.0 11/10/2022 16:12 11/10/2022 17:30 1.30 PROD1, DRILL DRLG P Increase ROP. Avg 50 FPH. 1.84 BPM @ 3,749 psi. Avg WOB = 1.6K lbs. Avg CT WT 10K lbs. Holding 50 ROP to maintain drop. Geo targeting 87 - 88 deg. 9,935.0 10,044.0 11/10/2022 17:30 11/10/2022 17:36 0.10 PROD1, DRILL WPRT P PUH to 9,958' for BHA wiper. PUW = 35 K lbs. 1.84 BPM. BHP = 3693 psi. 10,044.0 9,958.0 11/10/2022 17:36 11/10/2022 18:00 0.40 PROD1, DRILL WPRT P BOB Drilling. 1.84 BPM. BHP = 3,736 psi. WOB = 1.1K lbs. CT WT = 9.5K lbs. Geo targeting 89-90 deg. 9,958.0 10,044.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 6/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/10/2022 18:00 11/10/2022 18:45 0.75 PROD1, DRILL DRLG P Drill ahead to 10,200'. Avg ROP = 160 FPH. WOB = 1.7K lbs. CT Wt = 6.3 Klbs. 1.84 BPM. BHP = 3773 psi. Geo targetting 90-91 deg. 10,044.0 10,200.0 11/10/2022 18:45 11/10/2022 19:00 0.25 PROD1, DRILL WPRT P PUH for short wiper trip #1 to 9350' chasing sweep uphole. PUW = 37K. 10,200.0 9,350.0 11/10/2022 19:00 11/10/2022 19:15 0.25 PROD1, DRILL WPRT P BOB. Avg CT Wt = 13 Klbs. 1.84 BPM @ 5,029 psi. BHP = 3765 psi. IA = 630 psi. OA = 380 psi. 9,350.0 10,200.0 11/10/2022 19:15 11/10/2022 21:15 2.00 PROD1, DRILL DRLG P OBD. 1.84 BPM in / 1.78 out @ 5154 psi. WHP = 161, IA = 668, OA = 381 psi. BHP = 3769 psi. Holding 11.4 ppg at the window. Avg. WOB = 1K lbs. Avg ROP = 130 FPH. 10,200.0 10,400.0 11/10/2022 21:15 11/10/2022 21:18 0.05 PROD1, DRILL WPRT P Perform 100' BHA from 10,400' to 10,300'. Noticed ROP reduction drilling up through transition zone. PUW = 34 K lbs. 10,400.0 10,300.0 11/10/2022 21:18 11/10/2022 21:21 0.05 PROD1, DRILL WPRT P BOB drilling after BHA wiper. 10,300.0 10,400.0 11/10/2022 21:21 11/10/2022 22:39 1.30 PROD1, DRILL DRLG P Continue to drill ahead at reduced ROP through transition zone per DD. 1.83 BPM @ 5,160 psi. WHP = 147, IA = 625, OA = 389 psi. Avg. WOB = -2 Klbs. Avg ROP = 10 FPH. Diff = 1074 psi. 10,400.0 10,434.0 11/10/2022 22:39 11/10/2022 22:45 0.10 PROD1, DRILL WPRT P Perform 100' BHA wiper due to CT Wt of -3Klbs and minimal motor work. PUW = 39K lbs. Send 5x5 gel sweep to clean hole. 10,434.0 10,300.0 11/10/2022 22:45 11/10/2022 23:15 0.50 PROD1, DRILL WPRT P BOB drilling after BHA wiper. 1,100 psi free spin. Drilled footage on current mud system = 1,802'. 0.8% drill solids. Swap to new mud. 10,300.0 10,434.0 11/10/2022 23:15 11/11/2022 00:00 0.75 PROD1, DRILL DRLG P Attempt to drill ahead @ 10,434'. Seeing no motor work. 0 ROP. Diff. = 1,072 psi. WOB = 3.1 K lbs. CT Wt = - 4 K lbs. 1.83 BPM @ 4,739 psi. WHP = 189, IA = 557, OA = 392 psi. Suspect worn bit or motor. Attempt to work through. 10,434.0 10,434.0 11/11/2022 00:00 11/11/2022 00:30 0.50 PROD1, DRILL DRLG P Made multiple attempts to drill ahead. Stacked -4 K lbs CT Wt. with WOB of 3.2 K lbs. Seeing no motor work or differential. After 2 hours of no progress decision was made to POOH and inspect the BHA. 10,434.0 10,434.0 11/11/2022 00:30 11/11/2022 03:00 2.50 PROD1, DRILL TRIP T POOH with BHA #6. Clean drift through window. Open EDC at 7,550'. At surface. Bump up. 10,434.0 80.2 11/11/2022 03:00 11/11/2022 04:15 1.25 PROD1, DRILL PULD T PJSM. PUD BHA #6. Blowdown and inspect all components. Hycalog Bit is in good shape. Strider ERT checked out ok. Baker motor failed. Can spin the bit box by hand. Will replace Baker motor for BHA #7. 80.2 0.0 11/11/2022 04:15 11/11/2022 04:45 0.50 PROD1, DRILL BOPE P Function test BOP's. Pipe/Slips, Blind, Bag. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 7/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/11/2022 04:45 11/11/2022 05:45 1.00 PROD1, DRILL PULD T MU and PD BHA #7 - new 0.5 deg AKO motor with Strider and rerun same Hycalog 3" bi-center bit. Make up injector and surface test. Tag up and set counters 0.0 80.2 11/11/2022 05:45 11/11/2022 07:18 1.55 PROD1, DRILL TRIP T RIH BHA #7, Shallow test @ 599;1.83 BPM @ 4623 PSI FS 930 PSI Diff, Continue in 80.2 7,420.0 11/11/2022 07:18 11/11/2022 07:48 0.50 PROD1, DRILL DLOG T Log K1 for -15' correction, Clean & adjust counter wheel in injector, PUW=33K 7,420.0 7,457.0 11/11/2022 07:48 11/11/2022 09:06 1.30 PROD1, DRILL TRIP T Continue in well, Clean trip through window and build, Tag up @ 10,434' 8 Hrs NPT for BHI Motor failure 7,457.0 10,434.0 11/11/2022 09:06 11/11/2022 14:18 5.20 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4664 PSI FS, BHP=3738, Go to 95° inc. ROP mostly 20-30 FPH with breaks to 89-90 short lived as we are climbing through intervals. Multiple clean BHA wipers, Good weight transfer 10,434.0 10,713.0 11/11/2022 14:18 11/11/2022 14:30 0.20 PROD1, DRILL WPRT P Short wiper trip, PUW=37K 10,713.0 10,713.0 11/11/2022 14:30 11/11/2022 16:18 1.80 PROD1, DRILL DRLG P OBD, 1.85 BPM @ 4998 PSI FS, BHP=3858, ROP still variable 10,713.0 10,850.0 11/11/2022 16:18 11/11/2022 16:48 0.50 PROD1, DRILL WPRT P Short 400' wiper trip #1 to 10,000', PUW=37K 10,850.0 10,000.0 11/11/2022 16:48 11/11/2022 17:03 0.25 PROD1, DRILL WPRT P Wiper back down to 10,850'. 10,000.0 10,850.0 11/11/2022 17:03 11/11/2022 18:33 1.50 PROD1, DRILL DRLG P OBD, 1.86 BPM @ 4880 PSI FS, BHP=3759. Bore Press = 4691. Diff = 896 psi. WHP = 273, IA = 366, OA = 371. Avtg WOB = 1.3 K lbs. Avg. ROP = 50 FPH. Send 5x5 gel piill. 10,850.0 10,988.0 11/11/2022 18:33 11/11/2022 18:39 0.10 PROD1, DRILL WPRT P Short BHA wiper chasing gel sweep. PUW = 42K. 10,988.0 10,905.0 11/11/2022 18:39 11/11/2022 18:45 0.10 PROD1, DRILL WPRT P Wiper back in hole. 10,905.0 10,988.0 11/11/2022 18:45 11/11/2022 20:00 1.25 PROD1, DRILL DRLG P BOBD. 1.86 BPM in / 4876 psi. 1.75 BPM out. BHP = 3772. WHP = 255 IA = 349 OA = 372. Avg CT Wt = 5 Klbs. Avg. WOB = 0.7 K lbs. Avg ROP = 50 FPH 10,988.0 11,046.0 11/11/2022 20:00 11/11/2022 20:03 0.05 PROD1, DRILL WPRT P BHA wiper. CT WT = -6 Klbs. Poor weight transfer to bit. PUW = 40K lbs. 11,046.0 10,935.0 11/11/2022 20:03 11/11/2022 20:06 0.05 PROD1, DRILL WPRT P Wiper back in hole. 10,935.0 11,046.0 11/11/2022 20:06 11/11/2022 22:06 2.00 PROD1, DRILL DRLG P BOBD. 1.85 BPM in @ 4908 psi. 1.75 BPM out. BHP = 3809. WHP = 257 IA = 381 OA = 373 psi. Avg. WOB = 1 Klbs. Avg ROP = 70 FPH. Avg CT Wt. = 3 Klbs. 11,046.0 11,163.0 11/11/2022 22:06 11/11/2022 22:09 0.05 PROD1, DRILL WPRT P BHA wiper. Poor weight transfer to bit. PUW = 36K lbs. 11,163.0 11,115.0 11/11/2022 22:09 11/11/2022 22:12 0.05 PROD1, DRILL WPRT P Wiper back in hole. 11,115.0 11,163.0 11/11/2022 22:12 11/11/2022 22:24 0.20 PROD1, DRILL DRLG P BOBD. 1.86 BPM @ 4930 psi. 1.76 BPM out. BHP = 3784. WHP = 211, IA = 415, OA = 378. Poor weight transfer to bit. 11,163.0 11,181.0 11/11/2022 22:24 11/11/2022 22:30 0.10 PROD1, DRILL WPRT P BHA wiper. Slow pump rate and by- pass HP screens. Begin pumping 1#/bbl beaded sweeps to improve weight transfer. 11,181.0 11,104.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 8/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/11/2022 22:30 11/11/2022 22:36 0.10 PROD1, DRILL WPRT P Wiper back in hole. Pump 5 bbl beaded sweep. 11,104.0 11,181.0 11/11/2022 22:36 11/11/2022 23:36 1.00 PROD1, DRILL DRLG P BOBD. 1.88 BPM @ 5,013. 1.81 BPM out. BHP = 3790 psi. Drill beads at the nozzle @ 23:00. Send another 5 bbl beaded sweep. Avg ROP = 80 FPH. Avg WOB = 0.5 Klbs. Avg CT Wt = 1.5 Klbs. 11,181.0 11,250.0 11/11/2022 23:36 11/12/2022 00:00 0.40 PROD1, DRILL WPRT P Short wiper trip #2 up to 10,400'. 11,250.0 10,400.0 11/12/2022 00:00 11/12/2022 00:15 0.25 PROD1, DRILL WPRT P Wiper back in hole. Free spin 910 psi. 10,400.0 11,250.0 11/12/2022 00:15 11/12/2022 01:15 1.00 PROD1, DRILL DRLG P BOBD. 1.87 BPM @ 5,235 psi. 1.85 BPM out. BHP = 3829 psi. Continue pumping 1#/bbl beaded sweeps to improve weight transfer. WHP = 223, IA = 433, OA = 379 psi. Differential = 1047 psi. Avg ROP = 100 FPH. 11,250.0 11,331.0 11/12/2022 01:15 11/12/2022 01:18 0.05 PROD1, DRILL WPRT P BHA wiper. Stacking -6.5 Klbs CT Wt, poor weight transfer. PUW 37 Klbs. 11,331.0 11,310.0 11/12/2022 01:18 11/12/2022 01:21 0.05 PROD1, DRILL WPRT P Wiper back in hole. Free spin 906 psi. 11,310.0 11,331.0 11/12/2022 01:21 11/12/2022 01:54 0.55 PROD1, DRILL DRLG P BOBD. 1.83 BPM @ 4,988 psi. 1.79 BPM out. BHP = 3759 psi. Continue pumping 1#/bbl beaded sweeps. WHP = 201, IA = 443, OA = 379 psi. Differential = 980 psi. Avg ROP = 60 FPH. 11,331.0 11,359.0 11/12/2022 01:54 11/12/2022 02:00 0.10 PROD1, DRILL WPRT P BHA wiper chasing gel sweep. PUW = 34K lbs. 11,359.0 11,297.0 11/12/2022 02:00 11/12/2022 02:06 0.10 PROD1, DRILL WPRT P Wiper back in hole. Free spin = 909 psi. 11,297.0 11,359.0 11/12/2022 02:06 11/12/2022 03:21 1.25 PROD1, DRILL DRLG P BOBD. 1.88 BPM @ 5,210 psi. BHP = 3807 psi. WHP = 185, IA = 458, OA = 381 psi. Differential = 1024 psi. Avg ROP = 11,350.0 11,413.0 11/12/2022 03:21 11/12/2022 03:24 0.05 PROD1, DRILL WPRT P Stacking -6 K lbs CT Wt. with WOB = 0.3 K lbs. BHA wiper. PUW = 34 Klbs. 11,413.0 11,300.0 11/12/2022 03:24 11/12/2022 03:27 0.05 PROD1, DRILL WPRT P Wiper back in hole. Free spin = 905 psi. Continue 1 #/bbl beaded sweeps to improve weight transfer. 11,300.0 11,413.0 11/12/2022 03:27 11/12/2022 05:27 2.00 PROD1, DRILL DRLG P BOBD. 1.87 BPM in @ 5258 psi. 1.79 BPM out. BHP = 3816. WHP = 173, IA = 473, OA = 381 psi. Avg diff = 990 psi. Bump 1#/bbl beaded pill volumes up to 10 bbl sweeps. Current lube concentration is 1% Lube 776. 11,413.0 11,503.0 11/12/2022 05:27 11/12/2022 05:39 0.20 PROD1, DRILL WPRT P BHA wiper, PUW=35K 11,503.0 11,503.0 11/12/2022 05:39 11/12/2022 06:51 1.20 PROD1, DRILL DRLG P Drill, 1.87 BPM @ 5230 PSI FS, BHP=3820 11,503.0 11,592.0 11/12/2022 06:51 11/12/2022 07:03 0.20 PROD1, DRILL WPRT P BHA Wiper, PIW=35K 11,592.0 11,592.0 11/12/2022 07:03 11/12/2022 08:21 1.30 PROD1, DRILL DRLG P Drill, 1.85 NPM @ 5000 PSI FS, BHP=3806 11,592.0 11,650.0 11/12/2022 08:21 11/12/2022 10:18 1.95 PROD1, DRILL WPRT P Long wiper to window with tie in, PUW=39K, Rig blacked out @ 10,925' for ~ 15 minutes, Continue out of hole. . Pull up through window Jet 4 1/2 tubing up to 7520 11,650.0 7,580.0 11/12/2022 10:18 11/12/2022 10:24 0.10 PROD1, DRILL DLOG P Tie into RA for + 2.5' 7,580.0 7,625.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 9/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2022 10:24 11/12/2022 11:54 1.50 PROD1, DRILL WPRT P Wiper trip back to bottom. 4' from bottom well started taking fluid ~ 1.2 BPM. WHP=245 holding 11.4 PPG at window. 7,625.0 11,650.0 11/12/2022 11:54 11/12/2022 14:06 2.20 PROD1, DRILL DRLG P Drill, 1.86 BPM @ 5191 PSI FS, BHP=3844. Returns .8 BPM. Work WHP down to get more return rate. Returns erratic. Get down to 200 PSI still under 1 BPM returns. Consult town. 11,650.0 11,776.0 11/12/2022 14:06 11/12/2022 14:24 0.30 PROD1, DRILL WPRT P Decide to shut choke, Pull 400' wiper before shutting well in. returns .5 to .3 BPM, PUW=38K 11,776.0 11,776.0 11/12/2022 14:24 11/12/2022 16:57 2.55 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4660PSI FS, BHP =3643. Shut in choke for low returns .2 - .4 BPM. Avg WOB = 1.5 Klbs. 11,776.0 11,896.0 11/12/2022 16:57 11/12/2022 17:09 0.20 PROD1, DRILL WPRT P Short BHA wiper back to 11,831'. PUW = 38K lbs. 11,896.0 11,896.0 11/12/2022 17:09 11/12/2022 18:21 1.20 PROD1, DRILL DRLG P BOBD, 1.83 BPM @ 5008 PSI, BHP =3743. Choke still shut-in. Drilling on 100% losses. WHP = 11,896.0 11,933.0 11/12/2022 18:21 11/12/2022 18:33 0.20 PROD1, DRILL WPRT P Short BHA wiper back to 11,863'. PUW = 44 K lbs Free spin = 901 psi 11,933.0 11,933.0 11/12/2022 18:33 11/12/2022 19:33 1.00 PROD1, DRILL DRLG P BOBD, 1.86 BPM @ 5008 PSI, BHP =3743. Choke shut-in. Drilling on 100% losses. WHP = 657, IA = 0, OA = 346 psi. Avg ROP = 35 FPH. Avg WOB = 3.3 K lbs. Diff = 1020 psi. 11,933.0 11,973.0 11/12/2022 19:33 11/12/2022 19:39 0.10 PROD1, DRILL WPRT P Short BHA wiper back to 11,935'. PUW = 53K lbs. Increase short wiper trip frequency to monitor increasing PU weights. 11,973.0 11,973.0 11/12/2022 19:39 11/12/2022 20:15 0.60 PROD1, DRILL DRLG P BOBD, 1.87 BPM @ 5225 PSI, BHP =3761. Choke shut-in. Drilling on 100% losses. WHP = 729, IA = 0, OA = 345 psi. Avg ROP = 30 FPH. Avg WOB = 1.36 K lbs. Diff = 1011 psi. Level 4 vibrations @ 11,994' at 20:15. Drilling hard formation. ROP down to 9 FPH. 11,973.0 11,994.0 11/12/2022 20:15 11/12/2022 20:21 0.10 PROD1, DRILL WPRT P BHA wiper back up to 11,977'. PUW = 52K lbs. 11,994.0 11,994.0 11/12/2022 20:21 11/12/2022 22:45 2.40 PROD1, DRILL DRLG P BOBD w/ choke closed holding 11.8# at the window. 1.87 BPM @ 5185 psi. BHP = 3796 psi. WHP = 664 psi. IA = 0, OA = 343 psi. Avg ROP = 20 FPH. Avg WOB = 1 Klbs. Diff = 987 psi. Level 2 and 3 vibrations while drilling hard formation. 11,994.0 12,050.0 11/12/2022 22:45 11/12/2022 23:30 0.75 PROD1, DRILL WPRT P Short Wiper #1 back to 11,200'. PUW = 35 K lbs. Attempt to establish returns. No Joy. Max returns 0.5 BPM dropped off to 0.2 BPM. Closed choke back in. RBIH clean past fault @ 11,760'. CT Wt. bobble at 11,850'. Lowered pump rate to 1 BPM to get through. 12,050.0 12,050.0 11/12/2022 23:30 11/13/2022 00:00 0.50 PROD1, DRILL DRLG P BOBD with choke closed in, holding 11.8# at the window. 1.85 BPM @ 5,107 psi. BHP = 3795 psi. WHP = 677, IA = 0, OA = 353. Diff = 1057 psi. Avg ROP = 25 FPH. Avg WOB = 1 K lbs. 12,050.0 12,066.0 11/13/2022 00:00 11/13/2022 00:33 0.55 PROD1, DRILL DRLG P Drilled to 12,088' with choke closed. Continue pumping beaded sweeps to maintain weight transfer. 12,066.0 12,088.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 10/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2022 00:33 11/13/2022 00:39 0.10 PROD1, DRILL WPRT P BHA wiper to 12,071' . PUW = 53K lbs. 12,088.0 12,088.0 11/13/2022 00:39 11/13/2022 03:09 2.50 PROD1, DRILL DRLG P BOBD. 1.80 BPM @ 4810 psi. WHP = 768 , IA = 0 , OA = 351 psi. Diff = 950 psi. Avg ROP = 40 FPH Avg WOB = 1.2 Avg CT Wt.= 5. Near bit Inc = 99. 12,088.0 12,196.0 11/13/2022 03:09 11/13/2022 03:15 0.10 PROD1, DRILL WPRT P BHA wiper up to 12,179'. PUW = 43K 12,196.0 12,196.0 11/13/2022 03:15 11/13/2022 04:45 1.50 PROD1, DRILL DRLG P BOBD with choke closed. 1.88 BPM @ 4971 psi. WHP = 807 , IA = 0 , OA = 357 psi. Diff = 1008 psi. Avg ROP = 30 FPH Avg WOB = 1 Avg CT Wt.= 2. 12,196.0 12,230.0 11/13/2022 04:45 11/13/2022 04:51 0.10 PROD1, DRILL WPRT P BHA wiper to 12,204'. PUW = 45K. 12,230.0 12,230.0 11/13/2022 04:51 11/13/2022 06:36 1.75 PROD1, DRILL DRLG P BOBD. 12,230.0 12,260.0 11/13/2022 06:36 11/13/2022 08:30 1.90 PROD1, DRILL TRIP T BHA has blugged off, BHA will hold 6500 PSI. Can not pump down CT. POOH. Line up across top to maintain BHP 12,260.0 7,564.0 11/13/2022 08:30 11/13/2022 10:12 1.70 PROD1, DRILL TRIP T Stop and open EDC, Able to pump down coil, Continue out 7,564.0 66.0 11/13/2022 10:12 11/13/2022 11:30 1.30 PROD1, DRILL PULD T PJSM, PUD BHA #7, Talk about potential trapped pressure in BHA. EDC has motor fault erro, high amperage. FVS failed during undeployment. Call change of scope SM. Go to correct checklist. Continue PUD 66.0 0.0 11/13/2022 11:30 11/13/2022 13:42 2.20 PROD1, DRILL PULD T Make up BHA #8 with RR motor, NOV agitator, and RR bit. PD BHA #8, Make up to coil and surface test. Tag up and set counters 0.0 68.7 11/13/2022 13:42 11/13/2022 15:42 2.00 PROD1, DRILL TRIP T RIH BHA #8, Shallow test @ 500'1.81 BPM @4349 PSI FS, 670 PSI Diff, continue in well 68.7 7,420.0 11/13/2022 15:42 11/13/2022 15:48 0.10 PROD1, DRILL DLOG T Log K1 for -14' Correctiom 7,420.0 7,456.0 11/13/2022 15:48 11/13/2022 16:06 0.30 PROD1, DRILL TRIP T RIH to 7559, Sensor 7520 MD, Sensor TVDSS=5807, Annular 3250, EMW=10.7 PPG 7,456.0 7,459.0 11/13/2022 16:06 11/13/2022 18:15 2.15 PROD1, DRILL TRIP T Continue RIH to TD. Set down @ 12, 233'. Off Baker trouble time. 9.5 hours 7,459.0 12,233.0 11/13/2022 18:15 11/13/2022 18:30 0.25 PROD1, DRILL DRLG P Pump beaded pill. Set down CT Wt. @ 12,233'. Attempt to wash back down to previous TD of 12,260'. Slowly washed down to 12,240'. 12,233.0 12,240.0 11/13/2022 18:30 11/13/2022 19:00 0.50 PROD1, DRILL WPRT P BHA Wiper. PUW = 40K. Formation acting sticky. May have entered D- shale. WOB = -2K. Annular pressure showed early signs of pack-off. Decision made to perform swab wiper from 12,240'. 12,240.0 12,240.0 11/13/2022 19:00 11/14/2022 00:00 5.00 PROD1, DRILL WPRT P Pump 10 x 10 sweep. Gel sweep at nozzle. Perform swab wiper to surface @ 40 FPM. Initial PUW of btm = 45K lbs. At 9,200' (21:15) opened choke and established full returns. Slow to 0.3 BPM BPM and 30 FPM, oriented HS through window. Jog 4 1/2" tubing to clean up. Continue pulling swab wiper @ 80 FPM. Tag up. Reset counters. 12,240.0 68.7 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 11/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/14/2022 00:00 11/14/2022 01:24 1.40 PROD1, DRILL TRIP P RIH to 7,400'. Log K-1 for a -13' correction. Park coil at for pressure survey. 68.7 7,560.0 11/14/2022 01:24 11/14/2022 01:30 0.10 PROD1, DRILL CTOP P Harvest static pressure at window to confirm KWF. CTMD = 7560' Sensor TVD = 5893' Annular Pressure = 3335 psi. EMW = 10.9 ppg 7,560.0 7,560.0 11/14/2022 01:30 11/14/2022 01:39 0.15 PROD1, DRILL TRIP P PUW = 36K. Orient high side with pumps at min rate. 7,560.0 7,544.0 11/14/2022 01:39 11/14/2022 03:09 1.50 PROD1, DRILL TRIP P RIH and set down at bottom of window @ 7,594'. PUH and re-drift clean at min rate. Continue RIH. SI choke @ 10,495' to maintain ECD at window above 11.4#. 7,544.0 10,495.0 11/14/2022 03:09 11/14/2022 04:03 0.90 PROD1, DRILL TRIP P Continue RIH with choke closed. Begin pumping beaded sweeps to reach lateral TD. Increased pump rate to 1 BPM to circulate beaded pill down CT. Set down at 12,263'. 10,495.0 12,263.0 11/14/2022 04:03 11/14/2022 04:57 0.90 PROD1, DRILL CIRC P PUW @ TD of 12,263' = 50K lbs. Mix and circulate 11.4# LRP to the bit. 12,263.0 12,263.0 11/14/2022 04:57 11/14/2022 08:18 3.35 PROD1, DRILL TRIP P POOH. Lay in 48 bbls of 11.4# LRP. Pump rate @ 0.5 BPM to reduce losses, maintaining 11.4# ECD at window. Paint EOP flags @ 10944' and 6200'. 12,263.0 111.0 11/14/2022 08:18 11/14/2022 08:48 0.50 PROD1, DRILL OWFF P At 111 feet, Perform 30 min flow check, Good. 111.0 111.0 11/14/2022 08:48 11/14/2022 09:42 0.90 PROD1, DRILL PULD P PJSM. Lay down BHA #8 111.0 0.0 11/14/2022 09:42 11/14/2022 12:12 2.50 COMPZ1, CASING PUTB P PJSM, P/U BHA # 9 - L1 lower liner segment (40 joints) 0.0 1,269.0 11/14/2022 12:12 11/14/2022 12:42 0.50 COMPZ1, CASING PULD P Make up coiltrak to liner. Make up coil and surface test. Tag up set counters 1,269.0 1,313.9 11/14/2022 12:42 11/14/2022 14:21 1.65 COMPZ1, CASING RUNL P RIH with 40 joints of 2 3/8" slotted liner (1,269'). 1,313.9 7,514.0 11/14/2022 14:21 11/14/2022 14:27 0.10 COMPZ1, CASING DLOG P Tie into window flag. -24' correction. PUW = 36K 7,514.0 7,514.0 11/14/2022 14:27 11/14/2022 14:51 0.40 COMPZ1, CASING RUNL P Continue RIH with 1st section of 2 3/8" liner 7,514.0 8,680.0 11/14/2022 14:51 11/14/2022 14:57 0.10 COMPZ1, CASING DLOG P Tie into K-1. +12' correction. Not applied to bit depth. 8,680.0 8,680.0 11/14/2022 14:57 11/14/2022 16:39 1.70 COMPZ1, CASING RUNL P Continue RIH with 1st section of liner. Set down. Release from liner. TOL @ 10,993'. PUW = 36K. 8,680.0 12,263.0 11/14/2022 16:39 11/14/2022 16:42 0.05 COMPZ1, CASING DLOG P Correct bit depth to 10,961' for released liner. 12,263.0 10,961.0 11/14/2022 16:42 11/14/2022 19:36 2.90 COMPZ1, CASING TRIP P POOH pumping LRP. Paint yellow TD flag @ 9,499'. Continue to POOH. Perform RA tie-in. no correction. Cont. POOH. 10,961.0 5,944.0 11/14/2022 19:36 11/14/2022 20:42 1.10 COMPZ1, CASING TRIP P Paint white window flag @ 5,944'. Continue POOH to surface. Perform No Flow Test. Good. 5,944.0 44.0 11/14/2022 20:42 11/14/2022 21:18 0.60 COMPZ1, CASING PULD P Lay down BHA #9 over a dead well. 44.0 0.0 11/14/2022 21:18 11/15/2022 00:00 2.70 COMPZ1, CASING PUTB P PJSM, P/U L1 intermediate liner segment (47 joints). P/U last of intermediate liner section at midnight. 0.0 1,488.0 11/15/2022 00:00 11/15/2022 00:45 0.75 COMPZ1, CASING PULD P Make up coiltrak to liner. Make up coil and surface test. Tag up set counters. 1,488.0 1,532.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 Page 12/12 3B-13 Report Printed: 11/18/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/15/2022 00:45 11/15/2022 01:45 1.00 COMPZ1, CASING RUNL P RIH with 47 joints of 2 3/8" slotted liner (1,488') pumping min rate of 0.3 BPM. 1,532.0 7,433.0 11/15/2022 01:45 11/15/2022 02:00 0.25 COMPZ1, CASING DLOG P Tie-in at window flag for a -2.5' correction. Injector counter off. Clean debris from wheel. Come off on pumps. PUW = 35K just above the window. Cont. RIH. 7,433.0 7,542.0 11/15/2022 02:00 11/15/2022 02:45 0.75 COMPZ1, CASING RUNL P Cont. RIH. Tie-in at RA tag of +18'. Not applied to bit depth. 7,542.0 9,060.0 11/15/2022 02:45 11/15/2022 03:45 1.00 COMPZ1, CASING RUNL P Cont. RIH with intermediate liner. PUW @ 10,902' = 45 K lbs. Apply +18' depth correction based off RA tag. RIH and latch into lower liner segment @ 10,933. PU 49 K lbs to confirm latched. WOB = -10K. Set down. Pump 1.50 BPM to release. Diff = 1,010 psi. PUW = 33 K. 9,060.0 10,933.0 11/15/2022 03:45 11/15/2022 03:51 0.10 COMPZ1, CASING DLOG P Correct bit depth for released liner. Liner Length = 1488.94' 10,933.0 9,444.0 11/15/2022 03:51 11/15/2022 06:51 3.00 COMPZ1, CASING TRIP P POOH laying in LRP #3 to window. Paint White TD flag at 7,492'. Paint Yellow window flag @ 5,444'. Continue POOH. 9,444.0 44.0 11/15/2022 06:51 11/15/2022 07:36 0.75 COMPZ1, CASING PULD P No Flow Test. Good. Lay down BHA #10 over a dead well. 44.0 0.0 11/15/2022 07:36 11/15/2022 10:36 3.00 COMPZ1, CASING PUTB P PU BHA #11 - Upper Liner Segment. Dissolving bullnose, 48 joints slotted, swell packer, 16 joint solid, deployment sleeve. 0.0 2,006.8 11/15/2022 10:36 11/15/2022 11:18 0.70 COMPZ1, CASING PULD P MU Coiltrak to upper liner segment. M/U injector. Surface test. 2,006.8 2,050.7 11/15/2022 11:18 11/15/2022 13:30 2.20 COMPZ1, CASING RUNL P RIH with upper liner segment and Coiltrak tools. Set weight to 12 k lbs, white flag in the horses head. PU Wt 48 k lbs, WOB to neg 14 k lbs - latched up. RBIH, stack 9 k lbs down weight. Pump 1.40 bpm, diff pressure to 880 psi, PU Wt 32 k lbs, WOB 0. Liner set on depth - bottom of upper section, 9500.96' TOL 7497.27'; 2,050.7 9,500.0 11/15/2022 13:30 11/15/2022 15:00 1.50 COMPZ1, CASING DISP P PUH, correct bit depth to reflect dropped off liner. Displace coil and well bore to seawater. 9,500.0 7,445.9 11/15/2022 15:00 11/15/2022 15:24 0.40 COMPZ1, CASING DLOG P Park coil, bit depth 7445.90' TVD. 5,821.85' TVD. Trap pressure of 3,440 psi, choke closed. Observe pressure fall to 3,303 psi. bleed wellhead twice, ***observe pressure stabilize at 3,292 psi - 10.88 ppg EMW. LRS on location, PJSM, PT to 4,700 psi. 7,445.9 7,446.0 11/15/2022 15:24 11/15/2022 17:54 2.50 COMPZ1, CASING TRIP P PUH while turning coil over to diesel. Lay diesel on the fly from 2,500' to surface. 7,446.0 60.0 11/15/2022 17:54 11/15/2022 19:24 1.50 DEMOB, WHDBOP PULD P PUD BHA 480psi under master 60.0 0.0 11/15/2022 19:24 11/15/2022 20:54 1.50 DEMOB, WHDBOP CIRC P Flush stack // pull checks for bop test on 2W 0.0 0.0 11/15/2022 20:54 11/15/2022 21:24 0.50 DEMOB, WHDBOP CTOP P Freeze protect tree // Blow down tiger tank line and rig down tt line 0.0 0.0 11/15/2022 21:24 11/16/2022 00:00 2.60 DEMOB, WHDBOP RURD P Rig down checklists // Rig Released from 3B-13 @ 0000 on 11/16/2022 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/16/2022 3B-13 CTD Schematic Completion 3-1/2" 9.3# L-80 EUE 8rd MOD Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3132, 4922, 7224' SLB BluePack Packer @ 7261' MD (4" ID) 3-1/2" X nipple @ 7379' MD (2.813" min ID) 4-1/2" Maxwell Joints 3-1/2" X nipple @ 7643' MD (2.813" min ID) Cement Retainer @ 7,640' 7" CIBP @ ~7675' MD 7" 26# J-55 shoe @ 8023' MD A-sand perfs 7714' - 7808' MD 9-5/8" 36# J-55 shoe @ 3658' MD 16" 62# H-40 shoe @ 117' MD C1-sand perfs 7548'-7601' MD KOP @ 7580' MD 3B-13L1 TD 12,263' MD Modified by AK 12/08/22 2 3/8" Liner set at 12,263' Slotted liner from 8,009'-12,263' Swell Packer at 7,996' Blank pipe from 7501,-7,996' SBR at 1,497' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag RKB (Est. 66' of Rathole) 7,874.0 3B-13 8/26/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Northern Solutions Liner Top Packer 3B-13 11/19/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: Cut off TBG @ 7366'@ middle of full joint above SBR 10/30/1996 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By Note: 10/12/22 recompleted tubing tail set at 7650' 10/12/2022 NSKRWOCM Ball and rod on seat in RHC plug inside X nipple @ 7644' 10/12/2022 nskrwocm Tubing FP with diesel to 2000'. 8.5# CI seawater from 2000' to 7655' 10/12/2022 NSKRWOCM 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 33.0 117.0 117.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.2 3,657.6 3,210.4 36.00 J-55 BTC PRODUCTION 7 6.28 23.6 8,022.7 6,289.0 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.7 Set Depth 7,655.0 Set Depth 5,998.0 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M 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) 23.7 23.7 0.08 Hanger 7.063 FMC GEN III Tubing Hanger FMC 2.960 3,132.2 2,829.3 44.27 Mandrel GAS LIFT 5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920 4,921.6 4,076.2 47.73 Mandrel GAS LIFT 5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920 7,223.8 5,664.0 42.68 Mandrel GAS LIFT 5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920 7,260.9 5,691.4 41.91 Packer 6.280 SLB 3.5" x 7" BluePack Packer, SN# C21P-1855 SLB BluePac k RH 2.894 7,378.7 5,780.8 39.59 2.81" X nipple 4.500 3.5" x 2.813" L-80, 8rd EUE, X- Nipple SN# 4180362-18 Halliburt on X Nipple 2.813 7,512.7 5,885.7 37.49 XO - Enlarging 3.500 3.5" 9.3# L-80 8rd EUE x 4.5" HYD 563, XO 2.992 7,516.7 5,888.9 37.51 Centralizer 4.500 4.5" TBG w/Maxwell Centralizers Maxwell 3.958 7,600.7 5,955.3 38.08 XO - Reducing 4.500 4.5" 563" x 3.5" 9.3# L-80 8rd EUE, XO 2.992 7,643.9 5,989.3 38.14 2.81" X-nipple 4.500 3.5" x 2.813" , X-Nipple/RHC Plug SN# 4180362-17 Halliburt on X Nipple 2.813 7,653.0 5,996.5 38.15 Wireline Guide 3.500 3-1/2" EUE 8rd Mule shoe 2' Pup cut at 30* 2.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,491.0 5,868.5 37.56 PACKER 2.72" Norther Solutions Liner Top Packer w/ 1.78" R-Nipple (10.9' OAL) Northern Solutions Mono- Pak LTP NSP0 27 11/19/2022 1.780 7,584.0 5,942.2 37.97 WHIPSTOCK 11/6/2022 0.000 7,640.0 5,986.2 38.14 CEMENT RETAINER QUADCO 2.75" SVCR CEMENT RETAINER QUADC O SVCR 10/29/2022 0.000 7,675.0 6,013.8 38.19 CIBP PRESSURE TEST FAILED. PLUG NOT ISOLATING A- SANDS Baker ACT 10/10/2022 0.000 7,742.0 6,066.4 38.18 FISH 3" JDC Dog Retainer Lost in hole 7/14/1991 7,874.0 6,170.5 37.42 FISH 3 PIECES OF HEX PLUG SLIP ENDS (.25X.25X.50") 8/26/2020 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) 3,132.2 2,829.3 44.27 1 GLV RK 1 1/2 1,257.0 10/19/2022 Schlumb erger MMG 0.188 4,921.6 4,076.2 47.73 2 OV RK 1 1/2 0.0 10/19/2022 Schlumb erger MMG 0.250 7,223.8 5,664.0 42.68 3 DMY RK 1 1/2 0.0 10/19/2022 Schlumb erger MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,548.0 7,601.0 5,913.7 5,955.6 C-4, C-3, C-1, UNIT B, 3B-13 5/13/1985 12.0 IPERF 120 deg. phasing, 5" Scalloped Csg Gun 7,714.0 7,762.0 6,044.4 6,082.1 A-4, A-3, 3B-13 5/13/1985 4.0 IPERF 120 deg. phasing, 4" Carrier JJ II Csg 7,780.0 7,808.0 6,096.3 6,118.3 A-2, 3B-13 5/13/1985 4.0 IPERF 120 deg. phasing, 4" Carrier JJ II Csg SLANT, 3B-13, 12/6/2022 4:04:16 PM Vertical schematic (actual) PRODUCTION; 23.6-8,022.7 FISH; 7,874.0 IPERF; 7,780.0-7,808.0 FISH; 7,742.0 IPERF; 7,714.0-7,762.0 CIBP; 7,675.0 2.81" X-nipple; 7,643.9 CEMENT RETAINER; 7,640.0 WHIPSTOCK; 7,584.0 IPERF; 7,548.0-7,601.0 PACKER; 7,491.0 2.81" X nipple; 7,378.7 Packer; 7,260.9 Mandrel GAS LIFT; 7,223.8 Mandrel GAS LIFT; 4,921.5 SURFACE; 30.2-3,657.6 Mandrel GAS LIFT; 3,132.2 CONDUCTOR; 33.0-117.0 Hanger; 23.7 KUP PROD KB-Grd (ft) 36.51 RR Date 3/11/1985 Other Elev 3B-13 ... TD Act Btm (ftKB) 8,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128600 Wellbore Status PROD Max Angle & MD Incl (°) 47.90 MD (ftKB) 5,400.00 WELLNAME WELLBORE3B-13 Annotation Last WO: End Date 11/1/2006 H2S (ppm) 150 Date 11/25/2016 Comment SSSV: NIPPLE General Notes: Last 3 entries Com Date Last Mod By Note: 10/12/22 recompleted tubing tail set at 7650' 10/12/2022 NSKRWOCM Ball and rod on seat in RHC plug inside X nipple @ 7644' 10/12/2022 nskrwocm Tubing FP with diesel to 2000'. 8.5# CI seawater from 2000' to 7655' 10/12/2022 NSKRWOCM Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Slotted Liner 2 3/8 1.99 7,497.3 12,263.0 4.60 L-80 STL Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,584.0 5,942.1 38.74 WHIPSTOCK 11/6/2022 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) 7,995.7 5,962.4 100.0 9 Swell Packer 2.700 NSAK 350-238 OH Permanent QCLL Halliburto n Swell Pkr. 1.686 9,504.1 5,920.2 90.38 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions 1.920 10,993.0 5,892.2 92.11 Deployment Sleeve 2.375 Northern Solutions 1.920 SLANT, 3B-13L1, 12/6/2022 4:04:17 PM Vertical schematic (actual) Slotted Liner; 7,497.3-12,263.0 WHIPSTOCK; 7,584.0 PRODUCTION; 23.6-8,022.7 PACKER; 7,491.0 2.81" X nipple; 7,378.7 Packer; 7,260.9 Mandrel GAS LIFT; 7,223.8 Mandrel GAS LIFT; 4,921.5 SURFACE; 30.2-3,657.6 Mandrel GAS LIFT; 3,132.2 CONDUCTOR; 33.0-117.0 KUP PROD KB-Grd (ft) 36.51 RR Date 3/11/1985 Other Elev 3B-13L1 ... TD Act Btm (ftKB) 12,263.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128660 Wellbore Status PROD Max Angle & MD Incl (°) 100.85 MD (ftKB) 7,891.08 WELLNAME WELLBORE3B-13 Annotation End DateH2S (ppm) 150 Date 11/25/2016 Comment C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-31_21109_KRU_3B-13_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21109 KRU 3B-13 50-029-21286-00 Caliper Survey w/ Log Data 31-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:185-023 T37218 Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.02 09:42:46 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8040'feet 7675'feet true vertical 6301'feet 7742', 7874'feet Effective Depth measured 7874'feet 7261'feet true vertical 6170'feet 5691'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7665' MD 5998' TVD Packers and SSSV (type, measured and true vertical depth) 7261' MD N/A 5691' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River 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: 3658' 3211' Burst Collapse Production Liner 7999' Casing Structural 6289'8023' 3627' 117'Conductor Surface Intermediate 16" 9-5/8" 84' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-023 50-029-21286-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025633 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3B-13 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 117' ~ ~~ Well Remains Shut-In ~~ ~ 322-476/ 322-622 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Senior RWO/CTD Engineer 7548-7601', 7714-7762', 780-7808' feet 5914-5956', 6044-6082', 6096-6118' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 2:14 pm, Nov 10, 2022 DTTMSTART JOBTYP SUMMARYOPS 9/21/2022 ACQUIRE DATA RUN 1: CUT TUBING W/ 1.75" RCT AT 7625.4' RKB RCT HAD 7" X 1" HOLE IN TUBE AFTER CUTTING, SEVERING HEAD OF CUTTER LOOKED LIKE GOOD CUT BUT CONCERNING TO SEE THE SIZE OF HOLE IN THE TUBE AT SURFACE. RUN 2: CUT TUBING W/ 2.0" RCT AT 7529.2' RKB RCT LOOKED NORMAL BACK AT SURFACE. NO HOLES OR EXCESSIVE SLAG. JOB COMPLETE, READY FOR RIG 9/24/2022 MAINTAIN WELL FREEZE PROTECT PUMPED 9 BBLS METH DWN FL PUMPED 1 BBL METH DWN FL TO PRESSURE UP TO 400 PSI 9/25/2022 RECOMPLETION Bridal Up. Review Derrick down checklist. Start hauling out Misc equipment to next location. L/D Derrick. Load shop and Pits. Transport pits, shop and office to 3B-Pad and stage same. 9/26/2022 RECOMPLETION Mob Sub over to 3B-Pad. Change out bridal lines. Spot sub over well. 9/27/2022 RECOMPLETION Spot pits. Raise derrick. Spot auxiliary equipment. Berm in rig. Hook up steam and air to pits. Bridal down. Complete acceptance checklist. Get measurements for riser height and TBG spool. Get Initial pressure on well. RU circulating manifold in cellar. Circulate 8.5 ppg KWF. Bullhead additional 205 bbl.of 8.7 ppg down the I/A and 68 bbl down the tubing. install BPV and Test. 9/28/2022 RECOMPLETION N/U BOPE, and test to 250/3500 psi. Upper pipe rams failed, change out and retest same,Blanking plug fail, replace and retest same. Rig down/Blow down testing equipment 9/29/2022 RECOMPLETION MU landing joint, BOLDS. Pull hanger to the floor, fill the hole, L/D landing joint and hanger,R/U and pull 3 1/2 tubing from 7287'. Recovered 227 joints of TBG, 1 seal Assy w/Locator, 5 GLM and 1 X Nipple. From Joint 151, collars were damaged and pipe showed some pitting. MU BHA #1 and TIH on Drill Pipe., Jar Packer assembly free, Circ B/U through the gas buster. 9/30/2022 RECOMPLETION POOH with Packer assembly L/D same. Pick up BHA #2 (3.5 overshot assembly) Pull packer #2 down to the pre cut, Circ. B/U, POOH, L/D same. 10/1/2022 RECOMPLETION Packer assembly broke off the grapple while jarirng TIH BHA #3 (3.5 overshot assembly) . attempt to pull packer and gas lifts with no success, pulled out of the hole redressed cut lip overshot w/ 3.375 grapple, TIH to 7,327’. Engauge fish and attempt to jar free. 10/2/2022 RECOMPLETION Continue jarring fish loose, contingency if can’t jar loose, run an E-line 2” RCT, but couldn't get pass the tubing stump. TIH with 1.75 RCt & cut @ 7420' and Jar fish free. 10/2/2022 ACQUIRE DATA RIH w/ 2" RCT THROUGH DRILL PIPE, FISHING BHA & OVER-SHOT, THOUGH UNABLE TO PASS TOP OF TUBING STUB, PUH & RIH W/ 1.75" DRIFT, ABLE TO PASS THROUGH OVER-SHOT INTO TUBING STUB, PU & RIH W/ 1-11/16" RCT (ANCHORS MAX OD OF 1.7"), PERFORM CUT OF 3-1/2" TUBING AT ~7420' BELOW PACKER AND ABOVE GLM WITH RADIAL CUTTER TORCH 3B-13 RWO Summary of Operations 10/3/2022 RECOMPLETION Circ. bottoms up, though a closed annular - POOH -L/D Fish, Pick up wash pipe assembly, wash down to the top of the packer, circ. B/U, POOH, L/D wash pipe assembly. 10/4/2022 RECOMPLETION Pick up spear assembly,TIH and wash down to the top of the packer shell. Engauge & Jar packer shell free, circ. B/U, POOH, lost grapple in the hole, M/U Paker mill assembly, TIH 10/5/2022 RECOMPLETION Continue TIH with packer mill assembly, Mill packer down to lower slips, Circ. Hole clean, POOH, L/D packer mill assembly. P/U BHA #10, TIH to 7,394 and drift 3.5 tubing, Slip& Cut. 10/6/2022 RECOMPLETION Continue Slip & Cut off drilling line, TOOH, L/D BHA same. P/U spear assembly, TIH and retrieve tubing and packer parts, Circ B/U, POOH, Hollow Mill container W/Overshot 3.5 grapple,TIH Engauge fish and pull out 10/7/2022 RECOMPLETION L/D BHA and Fish, P/U washover pipe, TIH and wash over the blast rings. TOOH, L/D Burn over shoe, and P/U 6" Burn over shoe, TIH and wash and ream over blast rings,Circ hole clean 10/8/2022 RECOMPLETION Continue Circ. Slip and Cut off Drilline,TOOH, L/D BHA, P/U overshot assembly, TIH and retrieve the blast rings,L/D blast rings and seal assy. 10/9/2022 RECOMPLETION P/U packer mill, TIH T/7,630' mill down to packer slips and chase to bottom. TOOH,BHA 10/10/2022 RECOMPLETION P/U bridge plug, RIH, correlate with E-line and set above the A-sands, TOOH, P/U Test Packer, TIH test bridge plug, and casing. 10/10/2022 ACQUIRE DATA RUN A GR/CCL CORRELATION LOG THROUGH DRILLPIPE IN ORDER TO CORRELATE CIBP ON DEPTH. TIE-INTO K1 MARKER FOR +14' CORRECTION, TAG CIBP AT CCL DEPTH OF 7673.5' (BTM OF TOOL DEPTH 7678'). LOG GR & CCL TO SURFACE. **JOB IS COMPLETE** 10/11/2022 RECOMPLETION Test bridge plug, and casing. POOH, L/D Drill pipe , rig up to run 3.5 completion 10/12/2022 RECOMPLETION Circulate well CI KW brine to surface, Make up the tubing hanger, space out, land, and RILDS. Test packoffs. Drop ball and rod. Pressure up and set packer per packer rep.PT tubing to 3000 psig for 30 minutes. PT the Casing, Shear the SOV, Install BPV, N/U BOPE, N/U Tree & adaptior, 10/13/2022 RECOMPLETION Continue nipple up tree & adaptor. Test tree. Pull test plug and BPV. Freeze protect. allow to u-tube. Rig down prepare to move 10/14/2022 ACQUIRE DATA (PRE-CTD) PT SV, MV,SSV (PASSED) DDT SV, MV, SSV (PASSED) 10/19/2022 SUPPORT OTHER OPERATIONS SHAKE OFF BAITED PULLING TOOL ABOVE BALL & ROD @ 7600' RKB; PULLED SOV & SET DV @ 7223' RKB; PULLED DV & SET OV @ 4921' RKB; PULLED DV & SET GLV @ 3132' RKB (OBTAIN GOOD TBG TEST); PULLED BAITED PULLING TOOL & BALL n' ROD @ 7644' RKB. IN PROGRESS. 10/20/2022 SUPPORT OTHER OPERATIONS PULLED 2.813" RHC PLUG BODY @ 7638' RKB; DRIFT W/ DMY CEMENT RETAINER DOWN TO 7643' RKB; PERFORMED STEP RATE INJECTIVITY TEST FROM .5 UP TO 2 BPM @ 775 PSI. READY FOR CTU. 10/28/2022 SUPPORT OTHER OPERATIONS 8.5 HOURS OF NPT DUE TO HYDRAULIC HOSE FAILURE, PERFORM TIE IN LOG FROM 7666'' CTMD TO 7000' CTMD AT 50 FPM, STACKED DOWN LUBRICATOR TO REPLACE LEAKING HYDRAULIC HOSE 10/29/2022 SUPPORT OTHER OPERATIONS REPLACED LEAKING HYDRAULIC HOSE ON THE MAST, SET CEMENT RETAINER AT 7640' RKB, PUMP 5 BBLS OF 15.8# CLASS G CEMENT BELOW RETAINER, UN-STING FROM RETAINER AND CIRCULATE 25 BBLS OF POWER-VIS FOLLOWED BY DIESEL TO SURFACE, READY FOR SLICKLINE, IN PROGRESS. 10/31/2022 SUPPORT OTHER OPERATIONS RUN 2.62" X 10' DMY WHIP STOCK DRIFT TO TOP OF CEMENT RETAINER @ 7640' RKB, NO TIGHT SPOTS OR WEIGHT SWINGS, CALIPER TBG FROM 7640' RKB TO 6640' RKB, REQUESTED QUICK TURN AROUND FOR CALIPER DATA. STILL NEED TO MIT-T TBG. 11/1/2022 SUPPORT OTHER OPERATIONS MIT-T TO 1500 PSI *PASSED*. PUMPED 0.4 BBLS DSL DOWN TBG TO REACH TEST PRESSURE. BLED TBG, BLED BACK 0.4 BBLS. RDMO. (JOB COMPLETE) C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-28_22057_KRU_3B-13_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22057 KRU 3B-13 50-029-21286-00 Coil Flag 28-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET , S UITE 308, ANCHORAGE, AK 99503 P HONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com W EBSITE : WWW.READCASEDHOLE.COM PTD:185-023 T37211 Kayla Junke Digitally signed by Kayla Junke Date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y Anne Prysunka at 3:30 pm, Oct 24, 2022 Adam Klem Digitally signed by Adam Klem Date: 2022.10.20 06:52:58 -08'00' '65 %23 WHVW WR SVLJ $QQXODU SUHYHQWHU WHVW WR SVLJ ; ; 6)'97/ *&: Jessie L. 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Tyler; NSK RWO CM; Adam Klem Subject:Notification of BOP use on Nabors 7ES on 10/9/2022 Attachments:3B-13 BOPE Letter 10_9_2022.doc Victoria and to whom it may concern, Please see attached document in response to Bulletin 10‐003 in order to document the use of BOP equipment on 3B‐13. Please let me know if you have any questions. Thanks. Good day. Adam Klem Senior RWO/CTD Engineer ConocoPhillips Alaska 700 G St ATO 670 Anchorage, AK 99510 907‐263‐4529 Office 970‐317‐0300 Cell Adam.Klem@conocophillips.com Some people who received this message don't often get email from adam.klem@conocophillips.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3K-13 PTD 1850230 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 9, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 10/9/22 at 13:20 hours Well Location: 3B-13 API Number: 50-029-21286-00-00 PTD Number: 185-023 Rig Name: Nabors 7ES Operator Contact: Adam Klem. (o) 907-263-4529. (c) 970-317-0300. Adam.klem@conocophillips.com Operations Summary: The lower packer at 7,603’ MD was milled up and the annular was closed to circulate any gas that had been trapped below the packer. BOPE Used: Annular Reason for BOPE Use: The annular was closed to halt any uncontrolled flow of packer gas. Actions To Be Taken: The BOPE will be retested to 2500 psig on 3-1/2” OD after current operations of pulling out of hole with drillpipe is accomplished. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Adam Klem Rig Workover Engineer CPAI Drilling and Wells  Kuparurk River Unit  Annular tested 10/10/2022 --jbr J. Regg; 11/16/2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3B-13 JBR 11/04/2022 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:1 Upper VBR's were repaired/replaced after I left the rig. I did not witness the re-test. Test Results TEST DATA Rig Rep:Cozby/YearoutOperator:ConocoPhillips Alaska, Inc.Operator Rep:Rowell/Toussant Rig Owner/Rig No.:Nabors 7ES PTD#:1850230 DATE:9/28/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE221003141728 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 10 MASP: 1928 Sundry No: 322-476 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 3 1/2X5 1/2 F #2 Rams 1 Blind P #3 Rams 1 2 7/8 X 5 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 2 2 1/16 P System Pressure P3000 Pressure After Closure P1475 200 PSI Attained P16 Full Pressure Attained P131 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2020 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 P25 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9 9 9 9 9 9 Upper VBR's did not witness the re-test. F ! " # $! % " & '$ ("" )*$ +, *# - # ./$ 0/ 1$$ " ## ! 2 ,2 3 $ 4* 56 $7 8&5 7 * 9*5 7 * :*5 7 + #* 9* + #* :* 95 7 59*7 ;<59*7 18(8=00('=>010(= " / 6 < : < :9*5 7:*5 7 ' -" !< * ?< +, *# # (+ * ) !< " /6 /$; *6 .:# * @ @ @ 6A@ @"" #@/$; ! 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Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 10/20/2020 Abby Bell PTD: 1850230 E-Set: 34114 5 -02-3 411 WELL LOG TRANSMITTAL DATA LOGGED Pt/3/2015 irl.K.BENDER To: Alaska Oil and Gas Conservation Comm. August 12, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 accEIVEC Anchorage, Alaska 99501 SEP 0 . 7-Ji RE: Production Profile: 3B-13 Run Date: 7/14/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC @halliburton.com 3B-13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21286-00 Production Profile Log 1 Color Log 50-029-21286-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. SNNr . Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC @halliburton.com Date: Signed: _e, p,�. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3B -13 Run Date: 7/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3B -13 Digital Data in LAS format, Digital Log Image file, Interpretation Report � 1 CD Rom 50- 029 - 21286 -00 } U` t7 1 Production Profile Log 1 Color Log 50- 029 - 21286 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton.wood s halliburton.com Date: a M 11 Signed: ikdiki �5 . Conoc~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED lWG 1 3 200í Alaska Oil & Gas Con~ CIUn . . .:I. ...",mISSlon AnChorage August 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED AUG 1 42001 \ßG"'D~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of20". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on July 27,2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner August 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ;¡;µ~ M~d 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 8/7/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 38-02 185-057 32" .4 bbls 20" 7/27/2007 4.2 8/5/2007 38-03 185-060 29' 5.2 bbls 20" 7/27/2007 4.2 8/5/2007 38-04 185-061 14' 2.5 bbls 20" 7/27/2007 4.2 8/5/2007 38-05 185-075 SF N/A SF 7/27/2007 1.7 8/5/2007 38-07 185-077 45' 6.1 bbls 20" 7/27/2007 6.8 8/5/2007 38-08 185-087 14' .5 bbls 20" 7/27/2007 2.5 8/5/2007 38-09 185-113 SF N/A SF 7/27/2007 1.7 8/5/2007 38-11 185-115 20' 2.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-12 185-116 43' 7 bbls 20" 7/27/2007 3.4 8/5/2007 38-13 185-023 43' 5.9 bbls 20" 7/27/2007 11.9 8/5/2007 38-14 185-024 11' 8.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-15 185-025 57' 9 bbls 20" 7/27/2007 7.6 8/5/2007 38-16 185-026 43' 6.8 bbls 20" 7/27/2007 7.6 8/5/2007 Scblumbøpg8P NO. 4054 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~n. 9 ZOOIl Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ¡.) Anchorage, AK 99501 ';;f '.. t\ ¡,rf\ifSil' I~ 6-- ð d5"c(~~"P' Field: Kuparuk Well Log Description Date BL CD Color Job# 11/28/06 . 3B-13 11415652 PROD PROFILE WIDEFT 11/16/06 1 3S-07 11502019 SBHP SURVEY 11/19/06 1 3S-10 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1Y ·23 11502022 PROD PROFILE W/DEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-Ð9 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê -ft--- ~ . Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 85' 1. Operations Performed: '-' --' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSt!Jpd~:j [\JO\I 1 7 Abandon D Alter Casing D Repair Well 0 Pull Tubing 0 Operat. ShutdownD Re-enter Suspended Well Other '<ŒT D D Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Time Extension Exploratory Service D D 5. Permit to Drill Number: 185-023 1 306-237 6. API Number: 50-029-21286-00 9. Well Name and Number: 38-13 8. Property Designation: ADL 25633, ALK 2566 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 8040' feet true vertical 6303' feet measured 7881' feet true vertical 6176' feet Length Size MD 117' 16" 117' 3628' 9-5/8" 3658' 7993' 7" 8023' Plugs (measured) Junk (measured) 7742' TVD Burst Collapse 117' 3211' 6289' Measured depth: 7548'-7601',7714'-7762',7780'-7808' - ~íi::IK- ¡,\F{U 5~A..~r~fi.ioLJ l~V V G, ~. 'ìf'¡Íìf.:, k .1 LU", true vertical depth: 5914'-5956',6044'-6082',6096'-6118' Tubing (size, grade, and measured depth) 3.5", L-80 1 J-55, 7371' 17655' MD. Packers & SSSV (type & measured depth) Baker 'FHL' retriev. Pkr, Otis 'RRH', Otis 'WD' pkr=7301', 7397'; 7631' Cameo 'OS' nipple @ 517' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 210 1233 426 2397 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby ~ify that the foregoing is true and correct to the best of my knowledge. Sundry Numb~~t ~~7: AI1J II i4,IoÞ Contact \~ Gary Eller @ 63-4172 \> ' Printed Name ....;:, ary Eller Oil-Bbl 93 54 CasinQ Pressure TubinQ Pressure 144 153 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Signature Title Phone Wells Group Engineer . I ' ~:~:red b~ ;ha~~/Æ9~e 263-4612 ~~ Form 10-404 Revised 04/2004 "\ ---_-.-..J RBDfv1S BFL" NOV 2 1 2006 n P 1 r::; 1 ,r\ I ^ '. , :,,' ¡ \~ f~: Submit Original Only ConocJ'Phillips Wel/view Web Reporting '..~ ~' Time Log Summary Time Lo~s Date From To Our S. Depth E. Depth Phase Code Subcode T COM 10/23/2006 00:00 01:00 1.00 MIRU MOVE DMOB P Rig down hoses for freeze protect, Set BPV, secure well, finish cleaning cellar and pits. 01:00 05:00 4.00 MIRU MOVE MOB P ROMO. Lower derrick, move pipe shed to 3B-pad. 05:00 08:30 3.50 MIRU MOVE MOB P Move pits and carrier to 3B-pad. 08:30 16:00 7.50 MIRU MOVE RURO P Spot rig mats, layout herculite, spot carrier, pipe shed, and pits, build containment. Raise and scope derrick. Rig accept (á} 13:00 on 10/23/06. 16:00 23:00 7.00 COMPZ~ WELC1 NUNO P Rig up lines on tree for well kill. Pick-up kelly and stand back. Load pits with 10.3 ppg KWF. Spot return tanks and make up hardline. Pull BPV. 23:00 00:00 1.00 COMPZ~ WELC1 CIRC P Hold PJSM. Rig up LRS on tree cap. PT lines 2500 psi. Starting pressure tbg 1100 psi IA 1580 psi. LRS pumped 50 bbls of 150 degree diesel, followed by 290 bbls of 100 degree seawater down tubing, taking returns to flowback tanks. 10/24/2006 00:00 02:00 2.00 COMPZ~ WELC1 CIRC P Complete pumping 50 bbls of 150 degree, followed by 290 bbls of 100 degree seawater down tubing, taking return to flowback tanks. Final pressure tbg 580 psi IA 640 psi. Vac out 120 bbls of return from flowback tanks. 02:00 06:00 4.00 COMPZ~ WELC1 CIRC P Circulate 360 bbls of 10.3 ppg KWF down tubing taking return to flowback tanks before seeing 10.3 ppg returns to tanks. Closed choke, bullhead 20 bbls to perfs. Shut-in and monitor well for 30 mins. Starting tubing/IA pressure 50 psi. After 30 minutes pressure down to 20 psi. Pumped total of 360 bbls and got 265 bbls of returns. 06:00 09:00 3.00 COMPZ~ WELC1 CIRC P Monitoring well pressure dropped to 10 psi. Bleed down and check for flow gas returns on both the tubing and IA rig up to circulate down tubing returns up IA. Checking for fluid level and circulating out any gas @ 3 bpm. we are presently losing 12 BPH, pumped a total of 207 bbls. Shut down monitor well tubing dead and 10 psi on IA, Instal BPV, and NO tree . Rig up to fill IA during NO and NU. 09:00 09:30 0.50 COMPZ~ WELC1 NUNO P Install BPV. page.1ofsl Time LOQs '-' Date From To Dur S. Depth E. Depth Phase Gode Subcode T"-tOM 1 0/24/2006 09:30 14:30 5.00 COMPZ~ WELC1 NUND P NO tree. Install blanking plug (8.5 rounds pulling tool 12.5 rounds).NU BOP stack, flow nipple, hydraulic lines, hoses. 14:30 00:00 9.50 COMPZ~ WELC1 BOPE P Test BOPE; 250/3000 psi and 250/2500 psi annular. Test with both 2-7/8" and 3-1/2" pipe. Test waived by Jeff Jones of AOGCC. 10/25/2006 00:00 03:30 3.50 RPCOr.. OTHR P Cut Drill Line. 03:30 04:00 0.50 RPCOr.. OTHR P Bleed IA from 30 psi to 0 psi 04:00 05:00 1.00 RPCOr.. OTHR P Pull Blanking Plug and BPV 05:00 05:30 0.50 RPCOr.. OTHR P Pull 2-7/8" completion free, up wt 65K. Down wt 37K 05:30 07:30 2.00 RPCOr.. CIRC P Monitor returns; small amount of gas breaking out at surface. Circulate bottoms up (á} 3.5 bpm. 07:30 11 :00 3.50 RPCOr.. RURD P Rig up cable sheave, spooler, etc. Continue to circulate, losses averaging 17 bpm while circulating at 3.5 bpm. Shut down circulation. Pull hanger to the floor and break out/lay down. Release SLB E-line. Monitor fluid level, 3 bph. Rig up headpin and prep to weigh up 2/1 ()# to 10.5#. 11 :00 13:30 2.50 RPCOr.. CIRC P Circulate in 10.5# brine. Shut down and monitor. 13:30 21:00 7.50 7,278 4,400 RPCOr.. PULD P Pull old ESP completion. Initial losses appear to be 17 bph. 21:00 00:00 3.00 4,400 2,500 RPCOr.. PULD P Continue to Pull ESP Completion. Fluid losses are 12 bbls/hr. 160 jts to surface. 10/26/2006 00:00 05:00 5.00 2,500 0 RPCOr.. PULD P Continue pulling old 2-7/8" ESP completion. Losing an average of 10 bbls/hr of 10.5# brine. 05:00 08:00 3.00 0 RPCOr.. PULD P ESP equipment at surface; begin breaking/laying down. Note: have recovered 114 of 116 LaSalle clamps, 9 of 9 flatguards, 46 of 57 flatgaurds. 08:00 10:00 2.00 RPCOr.. RURD P Take down ESP sheave, move unecessary equipment off rig floor, clean up. 10:00 11 :30 1.50 RPCOr.. RURD P Begin spotting/rigging up slickline. Begin circulating across top of hole. 11 :30 15:00 3.50 RPCOr.. SLKL P Perform 5.98 gauge/junk basket run to 7000'; seem to be pushing debris ahead. POOH and empty basket - have recovered approx 2 gals of banding. rubber appearing to be cable insulation, etc. RBIH w/ junk basket and tag at 7360' SLM (zero'd at rig floor). POOH and have recovered more bandinglrubber pieces. RBIH w/5-1/2" LIB. Fluid losses averaging 8-10 bph. PageZof6 Time LORS S'.1re;pth Date From To Dur E. Depth Phase Code Subcode T "-éOM 10/26/2006 15:00 20:00 5.00 RPCOr.. SLKL P Run PDS memory caliper log from top of 2-7/8" stub at 7325' to surface. 20:00 21:00 1.00 RPCOfl. SLKL P Run a 4.75" LIB. Zero LIB at floor, tag top of 3-1/2" stub at 7363' rkb. With LIB on surface, have good picture of tubing stub on LIB. 21:00 00:00 300 RPCOr.. OTHR P Take PH-6 out of pipe shed and finish loading 3-1/2" tubing. 10/27/2006 00:00 03:00 3.00 RPCOr.. OTHR P Finish loading pipe shed with 3.5" tubing. Strap tubing and jewelry. 03:00 06:00 3.00 RPCOr.. RCST P TIH with 3-1/2" Completion. 50 jts in at shift change. 06:00 16:30 10.50 RPCOr.. RCST P Continue running new completion. Tag up top of stub 8" from collar on jt 229 (7366') . 16:30 18:00 1.50 RPCOr.. RCST P Attempt to work over stub, stack 5k-10k#. Repeat. Don't appear to be slipping over. Pick up off and rotate pipe. Reattempt, see "drop" while stacking 15k over but don't appear to be moving down, just stacking wgt. Set down 25k, no movement down other than pipe compression. Discuss options. Note: Well fluid losses averaging 5 bph. Completion string wgt 65k# up, 48k# dn (10k blocks). 18:00 18:30 0.50 RPCOr.. RURD P Rig up slickline. 18:30 19:30 1.00 RPCOr.. SLKL T Run 2.8" LIB on slickline. Zero SL at floor and tag at 7359'. LI B shows 3 tattle tail screws, indicating we are not getting over stub. 19:30 21:30 2.00 RPCOr.. SLKL T Try to work over stub with overshot. Cannot get any deeper. Set down max of 25K, 5K over pull. Try to pick up and rotate pipe, still cannot get deeper. 21:30 00:00 2.50 RPCOr.. PULD X TOH with 3-1/2" completion. 10/28/2006 00:00 06:00 6.00 RPCOr.. PULD P TOH standing back 3-1/2" completion. 80 stands out at shift change. 06:00 09:00 3.00 RPCOr.. TRIP P Continue out of hole standing back completion; lay down 2.813 DS nipple w/pups for RHC plug install. 09:00 11:30 2.50 RPCOr.. PULD P At surface with completion. Visual on overshot shows some scratches entering muleshoe, nothing farther up in the body. Shear screws have been sheared, removal and inspections indicates they were sheared down (most likely from LIB run). Packer appears still in good shape. Finish strapping cleanout equiplworkstring. 11 :30 12:30 1.00 RPCOr.. PULD P Change out pipe handling equipment. Clear rig floor and prep to run workstring. Time Logs Dáte From To 10/28/2006 12:30 18:00 5.50 FISH TRIP P Begin running workstring: 6" rotary shoe w/3-1/2 dress-off mill, wash pipe ext wI wash pipe boot basket, bootbaskets, bumper sub, jar, (4) 4-3/4 drill collars on PH-6 workstring. 18:00 00:00 6.00 FISH 100 jts in hole at shift change. Continue to TIH with PH-6 workstring. 10/29/2006 00:00 02:00 2.00 FISH TRIP P Torque and test Kelly 02:00 03:00 1.00 FISH TRIP P TIH with PH-6 workstring 03:00 05:00 2.00 FISH MILL P Bring pump on at 4 bpm and tag at 7361' rkb. Mill down to 7373.7' rkb with rotary shoe, leaving top of stub at 7370' rkb. 05:00 06:00 1.00 FISH CIRC P Pump 10 bbl viscous gel sweep and chase to surface with 10.5# brine. 06:00 13:00 7.00 FISH TRIP P Pull out of hole standing back PH-6 workstring. Pumping across top of hole on way out. 13:00 15:00 2.00 FISH PULD P At surface; break down BHA. Boot baskets full of metal shavings/banding material. Mill showed wear indicating stub was entered and dressed down. Clear floor and begin prepping for slickline unit. 15:00 19:00 4.00 RPCOr.. SLKL P Slickline on location. Rig up and tag top of stub with LIB at 7372' corrected rkb. Stub appears to be fairly centered and clean on top. 19:00 20:00 1.00 RPCOr.. SLKL P Drift through 3-1/2" stub with 2.5" swage on SL and tag top of Merla patch at 7570'. 20:00 00:00 4.00 RPCOr.. TRIP P MU packer/seal assembly BHA and TIH with PH-6 workstring 10/30/2006 00:00 04:00 4.00 RPCOr.. TRIP P TIH with PH-6 workstring with overshot and Packer/Seal Assembly. 04:00 06:00 2.00 RPCOr.. HOSO P See shear pins on overshot shear at 7371" rkb, tag at 7373' rkb. Space out 1', leaving bottom of mule shoe of overshot at 7372' rkb, top of stub at 7370' rkb. Pressure up tbg to set packer, work up to 1550 psi. No indication of set. 06:00 07:30 1.50 RPCOr.. HOSO P Crew change. Stack wgt, pipe taking wgt at original tag. Attempt to pressure annulus, fluid circulating up tbg, packer not set. Pick back up to set depth at 7367'; pressure up to 1850 psi. Stack pipe wgt, see wgt approx. 2' above tag, packer appears set. Rig up to test IA. Note: Set depth 25.5' up on jt #233. page.4 d16·' Time Loqs '-' T >--COM Date From To Our S. Depth E. Depth Phase Code Subcode 10/30/2006 07:30 08:30 1.00 RPCOfl. DHEQ P PIT IA to 2500 psi; 20 psi drop in 15 mins. Bleed off press from lA, press up tbg to 1000 psi and shear out off PBR (lose at 120k, 38k over). 08:30 18:00 9.50 RPCOfl. RCST P Begin POOH laying down workstring. 170 out at shift change. 18:00 20:00 2.00 RPCOfl. RCST P Finish laying down workstring 20:00 00:00 4.00 RPCOfl. RCST P Start running 3-1/2" completion 10/31/2006 00:00 03:30 3.50 RPCOfl. RCST P TIH with 3-1/2" completion. 03:30 04:00 0.50 RPCOfl. HOSO P Sting seals into seal assembly. No go out for space out calculations. Pull back out of seals to spot corrosion inhibitor. Space out 04:00 06:00 2.00 RPCOfl. CIRC P Pump 10 bbls of corrosion inhibited brine down tubing followed by 60 bbls of 10.5# brine. Prep to land hanger; crossthread while making up. Call out for new hanger. 06:00 07:30 1.50 RPCOfl. HOSO P Crew change. Verify depths, spaceout pups still in string. Stab into seals with charge pump circulating down tbg. See pressure bump; shut down and stroke seals into PBR. See full 12' of drift to no-go. 07:30 09:00 1.50 RPCOfl. PULD P New hanger on loc. Same length as other. Make up hanger to string; re-drift to 2.91. Re-strap Nabors RKB, 21.46' rather than 23.28 as previous believed, putting seal assembly spaceout 3.36 off no-go. Land hanger. RILDS. Final string wgts= 65k# up/47k# down/ blocks 10k# 09:00 11:00 2.00 RPCOfl. DHEQ P Test tubing to 2500 psi; hold for 15 mins- held solid. Bleed off to 1500 psi. Pressure up IA to 3000 psi, hold for 30 mins- held solid. Bleed off pressure on tubing, shear SOV. Bleed well to 0 psi. 11 :00 12:00 1.00 RPCOfl. NUND P LDLJ. Install BPV and begin nippling down stack. 12:00 00:00 12.00 RPCOfl. NUND P ND BOPE. Breaking down stack and removing rams to send BOP's in for inspection. Also clearing slips & elevators off rig floor for inspection. Removed valves from mud cross. 11/01/2006 00:00 02:30 2.50 COMPZ~ RPCOfl. NUNO P NO BOP, breaking down stack & removing rams to send in for inspection. Remove valves. ND OSA. 02:30 06:30 4.00 COMPZ~ RPCOfl. NUND P NU FMC tubing head adapter & tree. Pull BPV. Set TWC. Test hanger & packoffs to 5000 psi. Test tree to 5000 psi. Pull TWC. page50f6·1 Time logs Date From To 11/01/200606:30 10:30 10:30 12:00 12:00 14:00 Dur 4.00 S~Pth E. Depth Phase Code Subcode COMPZ~ RPCOfl. FRZP 1.50 COMPZ~ RPCOfl. RURD 2.00 COMPZ~ RPCOfl. PULD DEMOB MOVE DMOB T"-tOM P RU lines & LRS. Test lines. Little Red pump down lA, reverse circulate well to diesel @ 3.0 bpm thru open SOV in bottom GLM @ 7228' MD, taking 10.5 ppg brine returns from tubing thru outside choke valve to tanks. 254 bbl away, diesel at tanks (280 bbls returned). Shut down, RDMO LRS. P Pick up lubricator and install BPV. Lay down equipment. Secure well. P Break down /Iay down Kelly. Begin general demob of rig equipment. Release Rig @ 1400 hrs, 11/1/06. P Release Rig 14:00, 11/01/06. Rig will move to Nabors' Yard in Deadhorse for some maintenance, then back to work for BP at Milne Point. Rigging down and cleaning rig. Peak trucks expected in the morning. page60f6 SEAL (7285-7288, OD:4.550) PBR (7288-7301, OD:5.020) Perf (7548-7601) Perf (7714-7762) Perf 17780-7808\ -- ,--,,/ KRU 38-13 ConocoPhillips Alaska,lnc. 3B-13 I !f:'."~~~,r'f~' ~-:¡l. .:f. ~:.. ~ -. . ,_. ...> ' , API: 500292128600 SSSV Type: NONE Well Type: PROD Orig 3/11/1985 Completion: Last W/O: 11/1/2006 Angle cæ TS: 38 deg cæ 7547 Angle @ TD: 37 deg @ 8040 Annular Fluid: Rev Reason: WORKOVER, GLV C/O, D&T, Pull RHC Plug Last Update: 11/12/2006 Reference Log: Last Tag: 7881 Last Tag Date: 11/4/2006 Ref Log Date: TD: 8040 ftKB Max Hole 48 deg @ 5400 Angle: Casing String - ALL STRINGS Description Size Top CONDUCTOR 16.000 0 SUR. CASING 9.625 0 PROD. CASING 7.000 0 Bottom TVD Wt Grade Thread 117 117 62.50 H-40 3658 3211 36.00 J-55 8023 6289 26.00 J-55 Wt Grade Thread 9.30 L-80 EUE8rdMod 9.30 J-55 EUE8rd Top 3.500 0 3.500 7366 Perforations"'Surnmary Interval TVD Zone 7548 - 7601 5914 - 5956 ,C-3,C-1,U B 7714 -7762 6044 - 6082 A-4,A-3 7780 - 7808 6096 - 6118 A-2 Type Comment 12 5/13/1985 IPERF 120 deg. phasing, 5" Scalloped Csg Gun 48 4 5/13/1985IPERF 120 deg. phasing, 4" Carrier JJ II Csg 28 4 5/13/1985 IPERF 120 deg. phasing, 4" Carrier JJ II Gas Lift MandrelsNal"éS St MD TVD Man Man Type Mfr 1 2971 2714 CAMCO MMG 2 4778 3979 CAMCO MMG 3 5927 4762 CAMCO MMG 4 6700 5298 CAMCO MMG 5 7228 5667 CAMCO MMG Production Mandrel$NalvèS St MD TVD Man Man Type Mfr Merla TPDX Merla TPDX Merla TPDX VMfr V Type VOD Latch Port TRO Date Vlv Run Cmnt GLV 1.5 RK 0.188 1274 11/3/2006 GLV 1.5 RK 0.188 1267 11/3/2006 GLV 1.5 RK 0.188 1256 11/3/2006 OV 1.5 RK 0.250 0 11/3/2006 DMY 1.5 RKP 0.000 0 11/3/2006 VMfr VOD Port TRO Date Vlv Run Cmnt o 10/4/1995 (1) o 2/16/1994 (2) o 1/19/1981 (3) V Type Latch 6 7437 5826 7 7514 5887 8 7612 5964 1. Closed 2. Closed 3. Closed Other (plugs, equip., etc.) - COMPLETION Depth TVD Type Description ID 24 24 HANGER FMC TUBING HANGER 3.500 517 517 NIP CAMCO 'DS' NIPPLE 2.875 7285 5710 SEAL BAKER SEAL ASSEMBLYw/LOCATOR 2.920 7288 5712 PBR BAKER PBR 3.000 7301 5722 PACKER BAKER 'FHL' RETRIEVABLE PACKER 2.920 7354 5762 NIP CAMCO 'DS' NIPPLE 2.812 7371 5775 Overshot POOR-BOY OVERSHOT 3.750 Other (plugs, eqÜip., etc.):'OI..Ð ·~OMPL.ETlaN{()ldSêll!çfiYeSihglêÇQri1plêtiQijl.;êftiI'tW~11) Depth TVD Type Description ID 7366 5771 OLD TBG *Cut off tubing cæ 7366' 2.992 7388 5788 SBR Otis 2.500 7397 5795 PKR Otis 'RRH' 2.970 7574 5934 PATCH 22' Merla Tbg Patch; Set on 2/9/89 to Cover Leak in Blast Joints @ 2.370 7588' PKR Otis 'WD' NIP Cameo 'D' Nipple NO GO SOS Otis TTL DMY DMY DMY 1.5 1.5 1.5 RM 0.000 RO-5 0.000 RO-5 0.000 7631 5979 7646 5991 7654 5997 7655 5998 Fish - FISH Depth I Description 7742 3" JDC Dog Retainer 3.000 2.750 2.992 2.992 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT} The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 2) 3) 4) 5) 6} 7) 1 8L / EDE Disk 38 - 13 Caliper Report 26 - Oct- 06 Signed: Q.1Jt (10(ì,~hIA~ m~k~V1 1~5" -ùd3 #- J48ó<'¡ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE. AK 99518 PHONE: (9071245-8951 FAX: (907)245-88952 E-MAIL: ..S3..c\..:Y.:.:..c.:\G2(X-...E::).1C.7tf...JS..:;.:..... WEBSITE :;\J'ji"í'!, 'Y=:V;Oi:¡Y'_ ,:8.::0:',J D:\OO _PDSANC-2006ìZ_ Word\Distribution\Trnnsmittal_ Sheets\Trnnsmit_ OriginaIdoc I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Well: Field: State: API No,: Top Log Intvl1.: Bot. Log I ntvl1.: 38-13 Kuparuk Alaska 50-029-21286-00 Surface 7,325 Ft. (MD) ConocoPhìllìps Alaska, Inc. October 26, 2006 7112 1 7" 26 lb. J-55 Casing Inspection Type : Co«osive & Mechanical Damage Inspection COMMENTS: This log is tied into the top of the 7" casing @ O' (Driller's Depth). This log was run to assess the condition of the casing with respect to corrosive and mechanical damages prior to setting a packer. The 7" casing appears to be in good to poor condition. Wall penetrations from 20% to 44% are recorded in thirty joints. The damage appears in the form of isolated pitting, trending towards the low side, and line corrosion. The majority of the casing logged appears to be in good condition. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the casing logged. A 3-D log plot of the caliper recordings across the packer setting interval is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Line Corrosion Isolated Pitting 6,583 Ft. (MD) 6,356 Ft. (MD) 6,395 Ft. (MD) 6,446 Ft. (MD) 6,400 Ft. (MD) Jt. Jt. Jt. Jt. Jt. 166 @ 160 @ 161 @ 163 @ 162 @ ( 44%) ( 43%) ( 38%) ( 36%) ( 36%) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: Wm. McCrossan Witness: Kennedy / B. Gathman I Analyst M. Lawrence "'~(Jì'····'···"·,·\· ,¡.," ...'rECE\' 'E['" ",.;" '.:.;;¡ ,,;iJ'U, ¡,uR' I V" NO\l () 3 2006 . . commissIon 1\laska oa & ~~ /i>-S- -gD3 I I Inc. 3 I I Detail of Across Packer ~4Q snno MIN II) (111ClOO in ) ¡GO[\¡ ~.LJ::1.,~~D.!lQ -- 7250 1 1 Joint 183 I 7260 l- ........ I········ ......... 1 , 7270 - ... , " '- ~~- .- ...... I , 7280 - .......... .......... -- ....... 7290 - I······ ........ Joint 184 I''' 7300 l- I I I I". 7310 l- .......... I " I 7320 Joint 185 I I I I I I I I I I I I I I I I I 2006 I Correlation of Recorded Damage Borehole Profile I Pipe 1 7. in -7317.4') Well: Field: Company: Country: Survey Date: 38-13 Kuparuk ConocoPhillips Alaska, Inc. USA October 26, 2006 I I I Approx. Tool Deviation Approx. Borehole Profile o I I 25 934 I 50 1930 I I 75 2926 0 ... ~ () ...0 ... E u.. ;:j c Z ..c E 100 3936 Q. () 0 0 I I 125 4924 I 150 5920 I I 175 6919 I 185 o 50 7317 100 Damage Profile (% wall) I Tool Deviation (degrees) I Bottom of Su rvey = 1 85 I I I I PDS Report Overview Body Region Analysis I Well: Field: Company: Country: 38-13 Kuparuk ConocoPhìllips Alaska, Inc. USA I Tubing: Nom.OD 7ins Weight 26 f Grade & Thread J-55 Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: Nom.ID 6.276 ins October 26,2006 MFC 40 No. 030807 2.75 40 M. Lawrence Nom. Upset 7ins Upper len. 7.2 ins Lower len. 7.2 ins I I Penetration ami Metal loss (% wail) Damage Profile (% wall) penetration body ::-.,1 metal loss body penetration body o 1 metal loss body 50 100 200 o o to 1% 40 to over 85% 85% 51 0 0 I 150 100 I 50 I pene. loss I I Configuration ( body) 101 40 I 10 151 I 30 20 o I isolated pitting general line ring hole! poss corrosion corrosion corrosion ible hole I o Bottom of Survey = 185 I I Analysis Overview page 2 I I I PDS REPORT JOINT TABU LA TION SH I Pipe: Body Wall: Upset Wall: Nominal ID.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3B-13 Kuparuk ConocoPhillips Alaska, Inc. USA October 26, 2006 I I Joint Jt. Depth ppn. Pen. ppn. ,\llplal Min. Damage Profile No. (Ft.) Body oss 1.0. Comments (%w all) (Ins) (Ins.) (Ins.) 0 50 100 1 0 ( 0.01 2 I 6.25 2 36 () 0.01 I 6.27 3 72 () 0.01 Î 6.26 4 109 0 0.01 ì 6.26 I 5 150 () 0.01 1 6.26 6 186 0 0.01 ì 6.26 7 228 () 0.01 2 I 6.26 8 268 () 0.01 i 6.26 9 310 () 0.01 ì 6.26 10 346 () 0.01 I 6.25 11 384 I 0.01 i 6.26 12 422 C 0.01 'I 6.26 13 461 () 0.01 I 6.26 14 501 () 0.01 i 6.26 15 542 () 0.01 3 I 6.26 16 578 () 0.01 2 I 6.25 17 617 () 0.01 2 i 6.26 18 654 () 0.01 4 i 6.26 19 695 () 0.00 ì I 6.25 20 732 () 0.01 2 i 6.25 21 774 () 0.01 2 I 6.25 22 814 0.01 2 i 6.25 23 855 0.01 I 6.24 24 896 0.01 Î 6.26 25 934 0.01 ¡ 6.25 26 972 0 0.01 1 6.25 27 1013 () 0.01 6.25 28 1054 () 0.01 ¡ 6.26 29 1095 () 0.01 ì 6.25 30 1134 () 0.01 3 I 6.26 31 1175 () 0.01 I 6.25 32 1216 () 0.01 6.26 33 1254 () 0.01 i 6.25 34 1294 () 0.01 i 6.25 35 1335 () 0.01 i 6.26 36 1373 () 0.01 3 I 6.26 37 1414 () 0.01 2 I 6.26 38 1451 () 0.ü1 2 ! 6.26 39 1488 () 0.01 i 6.25 40 1529 CI 0.01 ^ 6.26 41 1571 () 0.01 I 6.26 42 1610 () 0.01 1 6.26 43 1651 () 0.ü3 I 6.26 44 1692 () 0.02 6 1 6.26 45 1732 () 0.01 2 i 6.26 46 1768 C 0.01 j 6.26 47 1810 ( 0.01 ! 6.26 , 48 1847 () 0.01 i 6.26 49 1889 11 0.01 ì 6.26 50 1930 () 0.01 2 i 6.26 I I I I I I I I I I I I I Penetration Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: field: Company: Country: Survey Date: 3B-13 Kuparuk ConocoPhillips Alaska, Inc. USA October 26, 2006 Joint Jr. Depth PHi Pen. Pen. Meidl Min. Damag e Profile No. (Ft.) Body 1.0. Comments (% wall) (I:) (Ins.) (Ins.) 0 50 100 51 1970 0 0.01 1 i 6.26 52 2010 I) 0.01 2 1 6.26 53 2050 D 0.01 2 1 6.26 54 2091 (I 0.01 2 I 6.26 55 2130 (I 0.01 2 I 6.26 56 2171 I) 0.01 3 '! 6.26 57 2210 0 0.01 2 ¡ 6.26 58 2249 I) 0.00 I 6.26 59 2291 I) 0.02 I 6.26 !!J 60 2327 (I 0.01 1 6.25 61 2367 (I 0.01 I 6.25 62 2409 I) 0.01 , 6.26 63 2446 I) 0.00 1 I 6.25 64 2486 I) 0.01 3 I 6.25 65 2527 C 0.01 2 I 6.24 66 2568 I) 0.01 I 6.25 67 2607 I) 0.01 I 6.25 68 2648 I) 0.01 1 6.25 69 2689 () 0.Q1 1 0 6.24 70 2730 II 0.Q1 ì 6.25 71 2770 I) 0.Q1 2 1 6.25 72 2809 0 O.Q1 I 6.25 73 2845 0 0.Q1 ì 6.25 74 2885 ( 0.01 1 6.25 75 2926 i om I 6.26 76 2967 I 0.Q1 I 6.23 77 3008 I 0.Q1 ~¡ 6.25 78 3045 ( 0.Q1 2 ì 6.24 79 3086 ( 0.Q1 ì 6.25 80 3123 0 0.01 i 6.25 81 3164 0 0.Q1 I 6.25 82 3205 0 0.Q1 ì 6.25 83 3246 II 0.01 , 6.24 : 84 3287 II 0.01 1 I 6.25 85 3328 II 0.01 ¡ 6.26 86 3369 0 0.Q1 3 ~! 6.26 87 3410 I) 0.01 '¡ 6.25 88 3450 U 0.01 ì 6.18 89 3492 I) 0.Q1 i 6.26 90 3531 I) 0.01 0 6.26 91 3572 ( 0.01 , 6.26 , 92 3613 ( 0.01 I 6.25 93 3654 ( 0.01 I 6.23 94 3695 ì 0.01 2 1 6.24 95 3736 I 0.Q1 1 6.25 96 3776 0 0.Q1 I 6.25 97 3816 0 0.Q1 I 6.23 98 3857 ( 0.Q1 'I 6.26 99 3897 (I 0.Q1 1 6.24 100 3936 0 0.Q1 3 2 6.24 P Body Metal Loss Body Page 2 I I PDS REPORT JOINT TABU ON SH EET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3B-13 Kuparuk ConocoPhiUips Alaska, Inc. USA October 26, 2006 I I Joint Jt. Depth PC! Pen. PCIL 'Vleldl Min. Damag e Profile No. (Ft.) 'I 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 101 3973 ( 0.01 6.23 102 4014 ( 0.01 6.23 103 4053 I) 0.01 6.23 104 4090 I) 0.01 6.22 105 4131 I) 0.01 1 6.24 106 4172 I) 0.01 2 1 6.24 107 4212 I) 0.01 2 1 6.25 108 4253 I) 0.01 1 6.25 109 4292 0 0.01 I 6.26 110 4333 0 0.01 I 6.25 111 4369 0 0.01 I 6.25 112 4407 0 0.01 1 6.25 113 4445 0 0.00 I 6.25 114 4484 0 0.01 I 6.26 115 4524 I) 0.01 3 ¡ 6.25 116 4562 I) 0.01 3 I 6.25 117 4603 0 0.01 2 '! 6.23 118 4644 0 0.01 2 I 6.24 119 4680 0 0.01 2 I 6.25 120 4721 0 0.01 3 I 6.22 121 4761 I) 0.07 19 I 6.25 Shallow pitting. f" 122 4801 I 0.03 I 6.25 m 123 4843 ( 0.01 6.25 124 4883 I 0.ü3 I 6.25 IIIL 125 4924 ( 0.03 2 6.24 fII 126 4961 I) 0.02 1 6.24 0! 127 5000 0.02 0.04 0 ! 6.25 Shallow pittin\l. m 128 5037 I 0.ü3 ß I 6.25 m 129 5074 0 0.03 I) I 6.25 '" 130 5116 I) 0.04 10 I 6.21 Shallow pitting. '" 131 5156 0 0.ü3 I 6.25 132 5196 0 0.ü2 6.25 ill 133 5236 0 0.01 II 6.25 134 5277 0 0.01 '1 6.25 135 5317 0 0.01 I =; 136 5358 0 0.01 2 ¡ 137 5399 ( 0.01 /1 I 138 5439 ( 0.01 3 I 6.26 139 5479 ( 0.02 (; I 6.25 140 5520 ( 0.04 ¡ 1 6.23 Shallow pitting. 141 5559 ( 0.06 1 1 6.24 Shallow pitling. ~ 142 5601 0 0.04 IJ I 6.23 Shallow pitlirmí. 143 5642 0 0.06 ¡ I 6.24 Shallow pitling. 144 5678 0 0.04 10 I 6.25 Shallow pitting. í"' 145 5719 0 0.01 ., 1 6.25 146 5758 0 0.04 1 , 6.24 Shallow Ditting. : 147 5798 0 0.01 . 6.24 ¡ 148 5839 0 0.ü3 6.24 '" 149 5879 0 0.03 I 6.24 ~ 150 5920 I) 0.04 10 1 6.23 Shallow pitling. I I I I I I I I I I I I I Penetration Body Metal Loss Body Page 3 I PDS REPORT JOINT ULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal I.D.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 38-13 Kuparuk ConocoPhillips Alaska, Inc. USA October 26, 2006 I I Joint Jt. Depth Pc Pen. f'¡, . 'v\eI,11 Min. Damage P r ofile No. (Ft.) Body ID. Comments (%wall) ( (Ins.) (Ins.) 0 50 100 151 5960 0 0.07 jq I 6.24 Shallow nitting. 152 6001 0 0.02 (; I 6.23 153 6042 íJ 0.05 11 I 6.21 Shallow nitting. 154 6079 0 0.04 it) I 6.20 Shallow nitting. 155 6118 oln 0.06 10 ) 6.19 Shallow nittina. 156 6159 oos g~ 10 ) 6.21 Shallow nittina. 157 6199 0 ) I 6.22 Isolated "inina. 158 6239 0111 0.07 6.21 Shallow nittina. 159 6280 01 ) 0.12 6.20 Corrosion. 160 6318 Ooe¡ 0.16 6.21 Isolated "iUina 161 6360 0 0.14 6.18 Isolated nitlincr U. Denosits. 162 6399 001-, 0.13 6.09 Isolated nittincr Lt. Denosits. 163 6438 0011 0.13 Ù, 4 6.18 Line corrosion. Lt. Denosits. 164 ffiR () (il1 0.08 j 6.19 =t=nittinQ 165 6 0 0.08 6.17 ninincr U. DenosÎts. 166 6552 II 0.16 6.20 Isolated ni tti no. 167 6594 11 0.09 6.17 Isolated niltino U. Denosits. 168 6634 11 0.12 6.18 Isolated ni[tin" Lt. Denosíts. 169 6677 11m 0.10 n 1 6.21 Isolated nitting 170 6718 0 0.10 ) ( 6.17 Line corrosion. 171 6757 0 0.10 I )1 2 6.22 Isolated ninina 172 6799 0 0.07 ,) 6.18 Shallow nittino. 173 6840 0 0.10 6.19 Isolated "íttino 174 6878 I) 0.09 6.19 Isolated nittino U. De"osits. 175 6919 I) om 6.21 Isolated ninino 176 6959 0 0.03 6.22 177 6998 0 0.05 'fl 6.20 Shallow nitting. 178 7038 0 0.02 ) 6.19 II 179 7078 0 0.04 I ) 6.20 Shallow nitfina. !II! 180 7119 0 0.04 I 2 6.19 ShaHow"ittino. !II! 181 7155 0 0.06 I I 6.09 Shallow níttina. Lt. Denosíts. i 182 7197 0 0.07 ) ¡ 6.17 Isolated ninine. Lt. Denosits. 183 7236 0 0.07 1 I 6.17 Shallow nítbne. 184 7277 0 0.05 IS ) 6.20 Shallow nítting. 185 7317 0 0.06 fh 1 6.19 Shallow níttinQ. I I I I I I I I I Body Metal Loss Body I I I I Page 4 I I ----- .. - - -- - - .. -.. -- - - .. S Rep rt Cross Secti ns Well: Field: Company: Country: Tubin : 38-13 Kuparuk ConocoPhilHps Alaska, Inc. USA 7 ins 26 f -55 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: October 26,2006 MFC 40 ,'\10. 030807 :05 40 M. Lawrence Cross Section for Joint 166 at depth 6582.653 ft Tool speed = 72 Nominal 10 6.276 Nominal 00 = 7.000 Remaining wall area = 98 % Tool deviation = 51 0 Finger 1 Penetration = 0.161 ins Isolated Pitting 0.16 ins = 44% Wall Penetration HIGH SIDE = UP Cross Sections page 1 -- -.. - - -- Well: Field: Company: Country: Tubin : ------- - ------ S Report Cross Sections 38-13 Kuparuk ConocoPhillips Alaska, Inc. USA 7 ins 26 f J-55 October 26,2006 MFC 40 No. 030807 ;05 40 M. Lawrence Cross Section Tool speed = 70 Nominal 10 = 6.276 Nominal 00 = 7.000 Remaining wall area = 97 % Tool deviation 480 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Joint 160 at depth 6355.563 ft Finger 15 Penetration = 0.156 ins Isolated Pitting 0.16 ins = 43% Wall Penetration HIGH SIDE UP Cross Sections page 2 I KRU 38-13 I ~ 13843 TUBING r- API: 500292128600 Well I1'P,e: PROD A!:!9!e ..@TS: 38 d~7547 (0-7206, SSSV Type: NONE orJg~3/11/1985 A!:!9!e..@TD: 37 d~"@J3040 002875, Annular Fluid: Last 1 0/30/1996 Rev Reason: TAG FILL 102.441) Reference L~: Ref L<Jg Date: Last U¡>date: 10/3/2006 Last Tag: 7206 TD:j8040 ftKB Last ~ate: 9/29/20: Max Hole Ar1gIe:j48 d~.@.5400 'H""'" Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 117 117 62.50 H-40 SUR. CASING 9.625 0 3658 3211 36.00 J-55 11 I. PROD. CASING 7.000 0 8023 6289 ~§.ÇO _.)-55 .. ..... Size Top Bottom TVD .1 Wt .1 Grade Thread 2.875 0 I 7206 5651 J 6.50 1 L-80 ABM EUE 3.500 7366 I 7655 I 5998 9.30 I J-55 I EUE8rd Interval TVD Zone Status Ft SPF Date TYpe Comment 7548 - 7601 5914 - 5956 ,C-3,C-1,U 53 12 5/13/1985 IPERF 120 deg. phasing, 5" B ScallQPed C~ Gun 7714 - 7762 6044 - 6082 A-4,A-3 48 4 5113/1985 IPERF 120 deg. phasing, 4" Carrier JJIIC~ 7780 - 7808 6096 - 6118 A-2 28 4 5/13/1985 IPERF 120 deg. phasing, 4" Carrier JJ II Csg _~:___""nl St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 92 92 MMH FMHO DMY 1.0 BK 0.000 0 1/912000 2 2878 2648 MMH FMHO GLV 1.0 BK 0.125 1250 1/9/2000 3 4380 3709 MMH FMHO GLV 1.0 BK 0.188 1287 1/912000 4 5592 4527 MMH FMHO OV 1,0 BK 0.250 0 2/12/2000 5 7119 .MMH FMHO CV 1.0 BEK 0.000 0 1/9/2000 PUMP (7206-7242, 5t MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv 00:6,100) Mfr Cmnt 6 7437 5826 Merla TPDX DMY 1.5 RM 0,000 0 10/4/1995 Closed SEAL 7 7514 5887 Merla TPDX DMY 1.5 RO-5 0.000 0 2/16/1994 Closed (7242-7255, 8 7612 5964 Merla TPDX DMY 1.5 RO-5 0.000 0 11/19/198 Closed 005.620) lc"'U'''' .eolJÏn. ,èt '.) U:;:;\J\I;; AVI't'U r~¡;I~Ee' I1V'E~1 M~I¡; ~OI\¡U:U ,'II \J\I;;1[ Depth TVD Type Description ID 7162 5619 GAUGE SENTRY Pressure & Temp Gauge 2.875 7194 5642 NIP Cameo 'D' Nipple NO GO 2.250 7206 5651 PUMP Centrilift Model 'GPMT' Series 513 Tandem Pump wI integral intake & bolt on 0.000 head 7242 5678 SEAL Centrilift Model 'GSTB' Tandem Seal Section 0.000 7255 5687 MOTOR Centrilift Model 'KMEG1' Series 562 wi Motor Lead Extension Cable; Bottom 0.000 of ESP 7278' 7366 5771 OLD TBG 'Cut off tubing (âl 7366' 2.992 7388 5788 SBR otis 2.500 7397 5795 PKR Otis'RRH' 2.970 7574 5934 PATCH 22' Merla Tbg Patch; Set on 2/9/89 to Cover Leak in Blast Joints (âl7588' 2.370 7631 5979 PKR otis WD' 3.000 7646 5991 NIP Cameo 'D' Nipple NO GO 2.750 '-- -- 7654 5997 SOS otis 2.992 - 7655 5998 TTL 2.992 --- ~~-FISH - Perf ----- ~""ptlO" 1 Comment (7548-7601) ::::: -, Retainer 1 Lost in hole Date lIIote n Of30/199€ Notes on Tubing Detail 10/30/96 Work Over: Cut off TBG @ 7366' in middle of full joint above the SBR. Left old Selectíve Single Completion there in the well. The 'C' Sand is isolated with DV's & a TubiF}9PATCH between Pkr's. The 'A' Sand is OPEN. 8/3/2001 PACKERLESS COMPLETION, FrS WELL 2/30/2003 WAIVER ED WELL: T x IA COMMUNICATION, PACKER LESS COMPLETION, FAILED ESP -- = - - . .--- Perf - -- (7714-7762) -- -, -. --- -. --- - - - 1= ,-- 1--- I I I I I I I I I I I I I I I I I ) ) ,t7"~ ¡? ¡i:¡tIL : I ! ¡ ¡ : f i ; i ~ '.~~ ¡.J /i1' t' nJJ il~/7;Ji m/·~ ~ '!jn. ..\ ~\.' Ii' , .' JJ1d . '\~ "',, I'· ; ,'I, \\ .,,'- .' 'I' ~, '~, I \\ ¡if' \ ., ", I I '..' I Lrú @) U 01i.n.l / / I I FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gathman Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 11f5-6d;<? Re: Kuparuk 3B-13 Sundry Number: 305-296 ~H'!~W NO\! (1 f¡ 2(\[}5 Dear Mr. Gathman: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's, petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unles rehearing has been requested. DATED thisæay of October, 2005 Encl. 1. Type of Request: Abandon ) ) iJa ;\ ./ ir=:: ,'1 i;b..., STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION SEP 3D APPLICA TION FOR SUNDRY APPROV A'~$k~ Oñi ,& IQ ø:~ ,~ ' 20 MC 25.280 '" 1!1J JJia,;Þ :~~my,~, G:~mmi3~~iq;¡n O 0 ?IJ~r·lfmf~lmll.'I1 o Suspend Operational Shutdown 0 Perforate Waiver .. U' bj\!íi Other 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 o Pull Tubing '0 Perforate New Pool 0 Re-enter Suspended Well 0 Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 85' 8. Property Designation: Kuparuk River Unit 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 185-023 6. API Number: 50-029-21286-00 9. Well Name and Number: 3B-13 Exploratory 0 Service 0 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8040' 6303' Casing Length Size CONDUCTOR 117' 16" SUR. CASING 3573' 9-5/8" PROD. CASING 7938' 7" 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman 3p1/ Perforation Depth MD (ft): 7548'-7601',7714'-7762',7780'-7808' Packers and SSSV Type: pkr= OTIS 'RRH'; OTIS 'WD' no SSSV Signature MD 117' 3658' 8023' TVD Perforation Depth TVD (ft): 5914'-5956',6044'-6082',6096'-6118' Packers and SSSV MD (ft) pkr= 7397'; 7631' no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Tubing Size: 2-7/8" Immediately Date: Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ~~" <).j~~:i ~p\\ê. ";:. \Ú{I-O~ ~\-~ Q-\-'-\-~~ ŒC.~C.~\-· <:.:, LH ~ RBDMS BFL OCT 1 3 2005 Plug Integrity 0 Other: Form 10-403 Revised 7/2005 '-. r~! ! c~[~iS~lcGEA 'I E u u r-'Ll G /"\ APPROVED BY THE COMMISSION Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 7655' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Brad Gathman, 659-7224 Problem Wells Supervisor Date , - ¿ ÿ,. o.j-- Sundry Number: 303-276 ~~ c.?"- -;:). q j..--, Date /f0(' Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3B-13 (PTD 1850230) September 28, 2005 This application is for an extension of Sundry 303-276 for well3B-13 (PTD 1850230) and to document that the AOGCC and ConocoPhillips concur the well maybe produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3B-13 was originally completed in March 1985 as a gas lifted producer. The well was re- completed with an ESP in October 1996. The well produced via ESP until January 2000, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of aworkover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at 7119'measured depth. From thatpoint produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 2878', 4380', and 5592' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per regulations. As per this request, ConocoPhillips intends to produce 3B-13 for an unspecified duration with an exemption to 20 AAC 25 .200 (d) Production Equipment. ) ~ ConocoPhilllps PUMP (7206-7242, 00:6.100) SEAL (7242-7255, 00:5.620) Peri (7548-7601) . .:~' , ]..............'......'..' · ~'r' : J:::::~:·'.I··::~ ') : :::::;:::". :::::::;',:: ." : r:::::::[" ,J··:.·:···,'··.·.I··:·!·:' ::::::;:: .::::::::::;..... , : ·:·1 : ).......:..' , ..................~ .:::::::::,~ :·:·.·!f '·:·:·:·...·..·..íM.·:·~; , .lr::::···~ T....l . ~ I'....: .... I : '-: :1 . ,II wi' ~~~; ~::::::::I~ ~ .::::::::::: ...{..-. ::)::~ - ~ ...{..-. : ~;'J )"... i fU§": !~:)¡'_:~, !I , 8i ' I ~ ~ - -<.- +- Peri ~ (7714-7762) , ~ ~ -<.- - - - - ) 38-13 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 92 92 MMH 2 2878 2648 MMH 3 4380 3709 MMH 4 5592 4527 MMH 5 7119 5588 MMH Production MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 6 7437 5826 Merla TPOX OMY 1.5 RM 0.000 0 10/4/1995 Closed 7 7514 5887 Merla TPOX OMY 1.5 RO-5 0.000 0 2/16/1994 Closed 8 7612 5964 Merla TPOX OMY 1.5 RO-5 0.000 0 11/19/1988 Closed Other (plugs, equip.. etc.) - JEWELRY (OLD SELECTIVE SINGLE COMPLETION LEFT IN WELL) Depth TVD Type Description 7162 5619 GAUGE SENTRY Pressure & Temp Gauge 7194 5642 NIP Camco '0' Nipple NO GO 7206 5651 PUMP Centrilift Model 'GPMT Series 513 Tandem Pump w/ integral intake & bolt on head 7242 5678 SEAL Centrilift Model 'GSTB' Tandem Seal Section 0.000 7255 5687 MOTOR Centrilift Model 'KMEG1' Series 562 w/ Motor Lead Extension Cable; Bottom 0.000 of ESP 7278' *Cut off tubing @ 7366' Otis Otis'RRH' 22' Merla Tbg Patch; Set on 2/9/89 to Cover Leak in Blast Joints @! 7588' Otis 'WO' Cameo '0' Nipple NO GO Otis 7366 5771 7388 5788 7397 5795 7574 5934 7631 5979 7646 5991 7654 5997 7655 5998 Fish~FISH Depth I Description 7742 3" JOC Dog Retainer Generell Notes Date Note 10/30/1996 Notes on Tubing Oetai/1 0/30/96 Work Over: Cut off TBG @ 7366' in middle of full joint above the SBR. Left old Selective Single Completion there in the well. The 'C' Sand is isolated with OVs & a Tubing PATCH between Pkr's. The 'A' Sand is OPEN. 8/3/2001 PACKERLESS COMPLETION, FTS WELL 12/30/2003 WAIVEREO WELL: T x IA COMMUNICATION, PACKERLESS COMPLETION, FAILED ESP API: 500292128600 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: 7207 Last Tag Date: 1/9/2000 Celsing String. ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String· TUBING Size Top 2.875 0 2.875 7366 .Perforation$Summary··.· . Interval TVD 7548 ~ 7601 5914 - 5956 7714 - 7762 6044 - 6082 7780 - 7808 6096 - 6118 OLD TOO SBR PKR PATCH PKR NIP SOS TIL KRU Well Type: PROD Orig Completion: 3/11/1985 Last W/O: 10/30/1996 Ref Log Date: TO: 8040 ftKB Max Hole Angle: 48 deg @! 5400 Size Top Bottom TVD 16.000 0 117 117 9.625 0 3658 3211 7.000 0 8023 6289 Angle ~ TS: 38 deg @! 7547 Angle ~ TD: 37 deg @! 8040 Rev Reason: Waive red \Nell Last Update: 12/30/2003 Wt 62.50 36.00 26.00 Grade H-40 J-55 J-55 Thread Bottom TVD Wt Grade 7206 5651 6.50 L-80 7655 5998 6.50 L-80 Zone Status Ft SPF Date Type 4,C-3,C-1,Ur-. 53 12 5/13/1985 IPERF B A-4,A-3 48 4 5/13/1985 IPERF A-2 28 4 5/13/1985 IPERF Thread ABM EUE ABM EUE Comment 120 deg. phasing, 5" Scalloped Csg Gun 120 deg. phasing, 4" Carrier JJ II Csg 120 deg. phasing, 4" Carrier JJ II Csg FMHO FMHO FMHO FMHO FMHO Date Run 1/9/2000 1/9/2000 1/9/2000 2/12/2000 1/9/2000 Vlv Cmnt DMY GLV GLV OV CV BK BK BK BK BEK 1.0 1.0 1.0 1.0 1.0 0.000 0.125 0.188 0.250 0.000 o 1250 1287 o o ID 2.875 2.250 0.000 2.441 2.500 2.970 2.370 3.000 2.750 2.441 2.441 I Lost in hole Comment A/,ASKA OIL A~D GAS CONSERVATION CO~SSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 shouldbe allowed to continue production with no restrictions. , The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C- 16 should be changed to be similar to the other failed ESP wells with the fluid entry J ~.rCy Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, RandS; Ruedrich Commissioner iSTATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAl_ 20 AAC 25.280 1. Type of Request: Abandon ~] Alter casing [-'"] Change approved program E~ Suspend [] Operation Shutdown [] Repair well [] Plug Perforations r-'] Pull Tubing ~] Perforate New Pool [~ Perforate [~ Variance E~] Stimulate ~] Time Extension [~] Re-enter Suspended Well E~ Annular Disp. r-1 Other [~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ ~-~ Exploratory r--] Stratigraphic ~ Service [~ 5. Permit to Drill Number: 185-023 6. APl Number: 50-029-21286-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 85' 3B-13 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8040' 6303' 7939' 6220' Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 16" 117' 117' SUR. CASING 3573' 9-5/8" 3658' 3211 PROD. CASING 7938' 7" 8023' 6289' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7548'-7601 ', 7714'-7762', 7780'-7808' 5914'-5956', 6044'-6082', 6096'-6118' 2-7/8" L-80 7655' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= OTIS 'RRH'; OTIS 'WD' pkr-- 7397'; 7631' no SSSV no SSSV 12. Attachments: Description Summary of Proposal r~ 13. Well Class after proposed work: Detailed Operations Program [~ BOP Sketch [--1 Exploratory r'-] Development r-~ Service [--1 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil ~ Gas ~] Plugged ['-] Abandoned WAG [~ GINJ r-] WINJ [~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlefs Signature :.->Z'~//..~,~____~ ~ ~)~ Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date Conditions of approval: Notify Commission so that a representative may witness JSundry Number: Plug Integrity Other: Mechanical lntegrityTest ~] L°cati°nClearanc~cEi'VEf=*:~: L,' Subsequent Form Required: Alaska 0ii & Gas Cons. g0mmissim~ Anchorage Approved by: Form 10-403 Revised 2/2003 · COMMISSIONER THE COMMISSION 0 R I G I Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3B-13 (PTD 1850230) September 11, 2003 This application for Sundry approval for well 3B-13 (PTD 1850230) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3B-13 was originally completed in ~ as a gas lifted producer. The well was re- completed with an ESP in October 1996. The well produced via ESP until Janus--.00, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at _7119'mea_s_ur.e~depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 2878', 4380', and 5592' to ke~ep .annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per regulati~ Recent well test data shows the following results: WELL TEST SUMMARY REPORT ( ~'~TOTAL DS WL LENGTH CHK FTP FTT OIL WATER~%WC~,FLUID GAS GOR GLR 3B 13 18:00 176 126 125 148 1507 I 91 /1655 141 951 277 3B 13 17:47 176 123 125 143 1499 \ 91 [ 1642 132 922 256 3B 13 18:00 176 126 124 125 1419 ] 92 ~1544 115 917 204 3B 13 18:00 176 129 122 98 1347 t 93 )1445 100 1027 173 3B 13 17:00 0 133 125 98 1956 ~2054 107 1088 190 FORM TOTAL LIFT GAS RATE 318 289 201 149 285 GAS PRES 1282 1277 1261 1248 As per this request, ConocoPhillips intends to produce 3B-13 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ~ ConocoPhillips Alaska, Inc. 3B-13 AP1:1500292128600 I Well Type:I PROD SSSV Type:l NONE I C°mpleti°n :1 Orig 13,11/1985 Annular Fluid:I I Last W/O:110/30/1996 Reference Log:I I Ref Log Date:I Last Tag:17207 I TD:18040 ftKB Last Tag Date:11/9/2000 I Max Hole Angle:148 deg (~ 5400 Casing String - ALL STRINGS PUMP -/ (7206-7242, OD:5.620) SEAL--/ (7242-7255, 0D:5.620) Peff (7714-7762) Description CONDUCTOR SUR. CASING PROD. CASING Tubing Strin9 - TUBING Size [ Top 2.875 0 2.875 7366 Perforations Summar~ Interval TVD 7548 - 7601 5914 - 5956 7714-7762 6044-6082 7780-7808 6096-6118 Gas Lift Mandrels/Valves Size 16.000 9.625 7.000 Top Bottom 0 117 0 3658 0 8023 3B-13 Bottom TVD Wt IGrade I Thread 7206 5651 6.50 L-80 ABM EUE 7655 5998 6.50 L-80 ABM EUE TVD Wt Grade 117 62.50 I H-40 3211 36.00 J-55 6289 26.00 J-55 Thread IZone /Status I Ft ISPFI Date I Type I Comment ,c-3,C-l,Uq153112 15/13/19851 ,PERF 1120deg. phasing, 5" B / I I I I IScallopedCsgGun A-~,A-3 / 14814 15/13/198511PERF112°deg'phasing'4'' / I I I I Icarrier JJ ii Csg A-2 / I28 I 4 15/13/198511PERFI120deg. phasing, 4" / I I I I ICarrier JJ II Cscj stI MD I TVDI Man I Man I V Mfr I V Type I v OD I LatchI Port I TROI Date I V,v Mfr Type Run 2 128781 26481 MMH I FMHO I I GLV 11.0 I BK 10.125 1125011/9/20001 3 143801 37091 MMH I FMHO I I GLV I 1.0 I BK 10.188 1128711/9/20001 4 55921 45271 MMHI FMHOI I OV 11.0 I BK 10.2501 0 12/12/2000 5 I 7119 55881 MMH I FMHO I I CV 1.0 BEK 0.000I 0 1/9/2000 P~d~tiTh:::M~d:~61:~V~lVe~~: ::i ::: ::: ;'" ;: :: ::: ::: ::: : ii:: :'' Istl MD I TVDI Ma. I ~a. IV~fr IvType I VOD I.atchl Port I TROI Date I V~,, I I IMfr I Type I I I I I I I Run I Cmnt 6 17437t 58261 Merla ITPDX I I DMY 11.5 I RM 10.000I 0 110/4/19951Ciosed 7 175141 58871 Merla ITPDX I I DMY I 1.5 IRO-5 10.0001 0 12/16/19941Closed 8 7612 5964 Merla TPDX I I DMY 1.5 RD-5 I 0.000 I 0 l11/19/198ElCIosed Ot:hei~ i(~lag:S; eqdip;i ~t~:~;~ :~ J:EWEERY; (OLD SEE:ECTIVE SINGLE CO;MPEETiONi LEFT: IN: WELE); ::::: Depth/TVD I Type Description ID 7162 15619 I GAUGE SENTRY Pressure & Temp Gauge 2.441 7194 15642 I NIP Camco 'D' Nipple NO GO 2.250 7206 15651 PUMP Centrilift Model 'GPMT' Series 513 Tandem Pump w/integral intake & bolt 0.000 / on head 7242 15678 I SEAL Centrilift Model 'GSTB' Tandem Seal Section 0.000 7255 15687 I MOTOR Centrilift Model 'KMEGI' Series 562 w/Motor Lead Extension Cable; 0.000 / I Bottom of ESP 7278' 7366 15771 I OLD TBG *Cut off tubing (~ 7366' 2.441 7388 157881 SBR Otis 2.500 7397 15795 I PKR Otis'RRH' 2.970 7574 ]5934 I PATCH 22' Merla Tbg Patch; Set on 2/9/89 to Cover Leak in Blast Joints (~ 7588' 2.370 7631 159791 PKR Otis 'WD' 3.000 7646 15991 I NIP Camco 'D' Nipple NO GO 2.750 7654 159971 SOS Otis 2.441 7655 159981 'l-rE 2.441 Description I Comment Retainer Lost in hole Date ! Note 10/30/199(I Notes on Tubing Detail 10/30/96 Work Over: / Cut off TBG @ 7366' in middle of full joint above the SBR. Left old Selective Single Completion there in /the well. The 'C' Sand is isolated with DV's & a Tubing PATCH between Pkr's. The 'A' Sand is OPEN. 8/3/2001/PACKERLESS COMPLETION. FTS WELL KRU Angle ~ TS: 138 deg @ 7547 Angle @ TD:I37 deg @ 8040 I Rev Reason:I FTS WELL Last Update:15/24/2003 I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3B-13 (Permit No. 85-23 & 396-212) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of sundry well operations for the recent workover on KRU 3B-13. The workover was to pull the existing completion and to install an ESP. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development ORIGINAL WSI/skad STATE OF ALASKA ALASKA .,_ AND GA,~ CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska Inc. [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Install ESP 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 49' FSL, 786' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1277' FSL, 1275' FEL, Sec. 21, T12N, R9E, UM At effective depth i5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service At total depth 994' FSL, 1382' FEL, Sec. 21, T12N, R9E, UM Datum Elevation (DF or KB) RKB 85', Pad 55' 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3B-13 9. P-~'~-it--Nb~5~? / Approval No. 85-23 396-212 10. APl Number 50-029-21286 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured 8040 feet true vertical 6301 feet Effective depth: measured 7939 feet true vertical 6220 feet Casing Length Structural Conductor 30' Surface 3628' Intermediate Production 7993' Liner Plugs (measured) Junk (measured) Fill to 7910' MD Size Cemented MD 16" 229 Sx PF 'C' 93' 9-5/8" 900 sx ASIII & 500 sx Class G 3658' 7" 350 sx Class G & 250 sx AS I 8023' TVD 93' 3210' 6288' Perforation depth' measured true vertical 7780'-7808', 7714'-7762', 7548'-7601' 6095'-6117', 6043'-6081' 5912'-5954' ORIGINAL Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 7278' 3-1/2", 9.3#, J-55, 7655' Packers and SSSV (type and measured depth) Otis RRH packer @ 7397' and Otis WD perm packer @ 7631' 1'3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RELF. iVcu FEB 5 1997 Anch0ra00 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation' 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 454 144 933 1000 675 542 249 2237 900 1300 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L~'L ~. ~,,,.,.._- Title ):)~dZ.~C. ~{.,/.,f,~{{, Date ~'E{~ ' I.~. C~'31_ Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplicate Date: 1/27/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3B-13 RIG:NORDIC WELL ID: 998581 TYPE: AFC:--998581 AFC EST/UL:$ 560M/ 620M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:10/26/96 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21286-00 10/26/96 (Cl) TD: 8040' PB: 7937' SUPV:DEB DAILY:$ 10/27/96 (C2) TD: 8040' PB: 7937' SUPV:DEB DAILY:$ 10/28/96 (C3) TD: 8040' PB: 7937' SUPV: DEB DAILY: $ 10/29/96 (C4) TD: 8040' PB: 7937' SUPV: DEB DAILY: $ 10/30/96 (C5) TD: 8040' PB: 7937' SUPV: DEB DAILY: $ 10/31/96 (C6) TD: 8040' PB: 7937' SUPV:DEB DAILY:$ 11/01/96 (C7) TD: 8040' PB: 7937' SUPV:DEB DAILY:$ PULL VR PLUG & BPV MW: 0.0 Move rig from 3F-11 to 3B-13. Accept rig @ 0330 10/26/96. 3,249 CUM:$ 3,249 ETD:$ 0 EFC:$ 563,249 CBU & WATER BACK BRINE TO MW:ll.1 BRINE Inject brine to kill well. Monitor well, well dead. Test 9-5/8" x 7" packoff to 3000 psi, OK. Test BOPE to 250/3500 psi. Pull tubing. 31,200 CUM:$ 34,449 ETD:$ 0 EFC:$ 594,449 MU BIT & CASING SCRAPER MW:10.9 NABR Circulate 11.0 ppg brine around. Monitor well, stable, slow loss. POH LD 3.5" tubing & jewelry. 56,761 CUM:$ 91,210 ETD:$ 0 EFC:$ 651,210 POH - LDDP MW:ll.0 NABR POH LD DP. Monitor well, slow flow. String in 12.0 ppg brine to weight up to 11.0 ppg. POOH LD DP. 31,200 CUM:$ 122,410 ETD:$ 0 EFC:$ 682,410 RUNNING ESP COMPLETION MW:ll.0 NABR Change top rams to 2-7/8" & test to 250/3500 psi. Held pre-job safety meeting. 45,258 CUM:$ 167,668 ETD:$ 0 EFC:$ 727,668 CIRC THRU CHOKE @ 5898' MW:ll.0 NABR Continue to pick up Centrilift motor & pump hook up ESP cable. Run 2-7/8" tubing and "ESP" cable. Continue to run completion. Well continues to flow. Gained a total of 15 bbls. Shut in well. No casing pressure but crude oil breaking out. 191,965 CUM:$ 359,633 ETD:$ 0 EFC:$ 919,633 DISPLACING BRINE FROM WEL MW:ll.0 NABR Continue running "ESP" and 2-7/8" tubing. NU tree and test to 250/5000 psi. 76,963 CUM:$ 436,596 ETD:$ 0 EFC:$ 996,596 Date: 1/27/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/02/96 (C8) TD: 8040' PB: 7937' SUPV: DLW DAILY: $ INSTALL WINDWALL MODIFICA MW:ll.5 BRINE Continue to displace brine with sea water. Release rig @ 1600 hrs. 11/1/96. Move rig off well. Start installing windwall modification on derrick. 34,650 CUM:$ 471,246 ETD:$ 0 EFC:$ 1,031,246 End of WellSummary for We11'998581 RECEIVED FEB 5 1997 Alaska 0il & Gao rm.n~. _ALASKA OIL ~VO GAS C ONSERYATI ON C O~VlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18, 1996 Mr. Mike Zanghi Kuparuk Drill Site Dev. Supr. ARCO Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Waiver to the Packer Requirements of 25 AAC 25.200(d) to Allow Effective Electric Submersible Pump Completions in 3 KRU Wells Dear Mr. Zanghi: Your November 12, 1996 le~er to the Commission requested a Waiver to the packer requirement of 20 AAC 25.200(d) so that electric submersible pumps (ESPs) could be used safely and efficiently in the Kuparuk River Unit. This request is to alloxv ESP installations in KRU wells 3B-13, 3J-7, & 3J-10. Regulation 20 AAC 25.200(d) requires that "All wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless otherwise specifically approved by the commission." ESP wells are completed with the pump set just above the zone. During pumping operations, the fluid being pumped serves to cool the pump; if gas enters the pump, the pump becomes gas locked and it over heats which results in pump failure. When Kuparuk River crude enters the wellbore, pressure decreases and gas breaks out of solution; this gas tends to rise and accumulate. When sufficient gas has accumulated so that it is sucked into the pump, the pump becomes gas-locked and it overheats because it no longer pumps fluid which would cool it. Therefore, the goal is to find a way to produce the well safely so that gas does not accumulate where it can be sucked into the pump. One option is to set a packer high- 500' for example - this practice does not satisfy the intent of 25.200(d); this is a not a safe completion. ESP wells have to be pulled at intervals from a few months to a few years to change the pumps. It is very difficult to kill a well that has a packer installed at 500' because it is difficult to displace the gas that has accumulated in the annulus; the gas trapped under the packer makes the operation risky. Mr. Mike Zanghi Kuparuk Drill Site Dev. Supt. November 18, 1996 Page 2 A second option is to set a packer below the ESP. Again, this practice does not satisfy the intent of 25.200(d) and is an unnecessary, operation. Subject wells are high water cut (60 to 70%) and possibly could not flow unassisted, at least not at economical rates; therefore its in the State's best interest to have these wells completed with some form of assisted lift. The operators have determined that ESP completions are effective in these high water volume Kuparuk wells. Your request ~br a general waiver for Kuparuk wells can only be accomplished by a conservation order; however, the Commission can issue specific appro,:als. The Commission hereby waives the req.uirement for a packer in Kuparuk River Unit ,,,,'ells 3B- 13, 3J-7, and 3J-10. David W. Chairman ;ton cc: Blair Wondzell bew/espwells 0ct. 29. 1996 10'23AM ARCO ALASKA INC No. STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMIS,51ON APPLICATION FOR SUNDRY APPROVALS ~, 1/3 1. Type of Request: Abandon Alter casing _ Suspend __ Operation Shutdown __ Re-enter suspended well _ Repair well _ Plugging w Time extension _ Stimulate _ Pull tubing ;~ Variance _ P_e~.or. ate_ Other X Install ESP ~. Datum elevation (DF or KB) Change approve,,d p,m. gm~__m_.__ ~2. Name o! Operator i ! ARCO Ala_s_ka;_ Inc, 3. Address J P. O..B.o_x 100360, Anchorage, AK 99510 4. Location o!~ll-at sudace 49' FSL, 786' FEL, Sec. 16, T12N, RgE, UM At top of productive interval 1277' FSL, 1275' FEL, Sec 21, T12N, RgE, UM At e[feetive depth At total depth 99_4'_.F_SLr .1382' FELl Sec. 21~ T12Nr RgE~ UM Type of Well: Development X Exploratory _ Stratigraphic _ Service _ RKB 85' Pad 55' l:eet 7. Unit or Property name Kuparuk River Unit e. Well number 3B-13 __ 9. Permit number 85-2;~ lO. APl number 5__0-1~2g_'21.286 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8040' (approx) tree vertical 6301' Effective depth: measured 7 9 3 7' (approx) tree vertical 621 9' Casing Length Size Structural 3 O' 1 6 ' Conductor Surface 3628' 9-5/8 ' Intermediate Production 7 9 9 3' 7' Uner Pedoration depth: measured test Plugs (measured) feet feet Junk (measured) feet None Cemented 229 Sx PF 'C' 900 sx ASIII 500 sx Class G 350 sx Class G & 250 sx AS I ORIGINAL Measured depth True vertical depth 93' 93' 3658' 3210' 8023' 6288' 7808.7780', 7714'.7762', 7601'.7548' true vertical 6117-6095~, 6043'-6081 ', 5954'-5912' Tubing (size, grade, and measured depth) 3.5', 9.3#, J-55, 7655' Packers and SSSV (b/pa and measured depth) Otis RRH packer ~ 7397' and Otis WD Perm Packer @ 7631', Camco TRDP-1A-$SA S$$V {~ 1881' 13. Attachments Description summary o1' proposal X Contact William Isaacson at 263-4622 with any questions. ___ 14. Estimatecl date I'or commencing operation ____.OAt0ber 26; 1996 16. if proposal was verbally approved Blair WonzelJ 10/28/96 Name of approver. Date Approved Service 17. I hereby certify teat the fo{egoing ts true and correct Io the best o! my knowledge. Signed '~l~¢"'~j._/ Title Drill Site Development Supervisor FOR COMMISSION USE ONLY l Conditions o1: approval: N~mmission so represent=tJve may witness Plug integrity __ BOP Test Mechanical Integrity Test _ Approved by the order of the comm!s_~j~on Form 10-403 Rev 06/15/88 Detailed operation program 15. Status of well classification as: Oil X Gas_ Location clearance Subsequent form require lO- Lh'iginal Signed By f~mdd W. Johnsto~ BOP sketch Suspended IApprov_aJ,, No.._. "1 SUBMIT I~ TRI~PLICATE RECEIVED OCT '-" 0 1996 Alaska Oil & t~as Cons. Commission Anchorage 0¢ t. 29. 996 10:23AM ARCO ALASKA INC No. ~tJ4b I-'. 7./3 KRU 3B-13 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline and dummy off ali GLM's, 2. RIH with E-line and cut tubing in middle of first full joint above top packer, 3. Set BPV in tubing. Install VR plug in annulus valve, GENERAL WO_RKOVER PROCEDURE: MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water, SI well and determine kill wt tluid required. Load pits wi kill wt brine (expected kill wt = 11.0 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down 3-1/2" tubing and all jewelry. 5. PU DP and RIH with bit and scraper to +/-30' above tubing stub. Circulate hole clean. POOH laying down DP. , RIH wi Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 7. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 4.0 days Expected Case: 5.0 days Upper Limit: 7.0 days No: problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion WSI 10/28/96 RECEIVED 0C7' 7, O 1996 Alaska 0il & ~as Cc,<~ (bmmiss~o~ Oct. 29. 1996 · Casing, 7", 26#, J-55 10'23AM ARCO ALASKA INC ]No. 2645 P, 3/3 3B-13 Proposed Comp..tion I. 2-7/8' x 7-1/16' SM FMC Eeeenbie tubing hanger with EFT panatrat~r ~or ESP cable end port for downhole gauge conductor wire, 2-7R" USO tubing pup on bottom. H. 2-718' [..80 EUE 8rd Mod tbg to surface with mO bottom +/-1500' Internally Plastic Coated, Space out 2-718' x 1 · McMurry 'FMHO' mandrels wi DV's as follows: GLM# MD-RKB 2 5600' 3 4400' 4 2900' $ 1OO' NOTE: Install LaSalle cable protectors over the cplg of each o! the first 6 Joints above the bottom GLM, followed by every olher joint to surface. (Wllh the exception of each GINI as noted below.) Each GLIVl (except lhe one et 100') should be made up with a 6' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable spaced out as per procedure C~ble splice from fiat to round cable adjacent to pup above pump LaSalle Pmlectolizers at each o! ESP G, 2-7/8" X 1 · MoMurry 'FMHO' mandrel with OCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differenlial). F, Pup Jr, 2-7/8' x 6' L-~0 EUE 8~'d Mod tubing with LaSalle cable protector on cplg below pup. E, 2 its of 2-7/0' L-~O EUE 5rd Mad Internally Plastic Coated tubing with Baker 'Senby' downhole pressure / temperature gauge clamped onto 1 st J~ of tubing, Conductor Wire for gauge wilt be run to surface with-in lhe 2nd Armor wrap of ESP cable, Install one LaSalle cable protec~r on cplg bob~eon the two joints, D, 2-7t8' Camco 'D' landing nipple with 2,25' No-Go profile, Standing Valve to be set in landing nipple as completion is being made up. C. Cantrlllfl Model 'GPMT' Series 513 Tandem Pump with integral Intake and bolt on head, 2-7/8' x 10' L-80 handling pup on top, 8, Centrilifl Model 'GSTB' Tandem Seal Section. A, Centrlllft Model 'KMEGI' Series 562 Motor with Motor Lead Extension Cable. Bottom of motor set at ,~-7295'MD R KB. stub at 7366' MD RKS, C Sand C Sand Pads 7548' - 7601' RECEIVED OC T ..:'3 0 1996 A Sand Perfs 7714' -7762' 7780' - 7808' PBTD @ 7937' WS110/25/96 ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '"'~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '~'""30-18 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing '~~BO-09 Kuparuk Fluid Level Report 3-1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ska 0ii & G~ u~:;. C;.~a~m~ss,u~ A~cn0rage ARCO Alaska, Inc. Date: March 24, 1989 Transmittal Ct: 7447 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ""',. 3 O- 1 6 Kuparuk Well Pressure Report I - 3 - 1 8 9 Sand 'A' --- 3 O- 1 0 Kuparuk Well Pressure Report 2 - 0 4 - 8 9 Sand 'A° ---- 3 ©- 1 3 Kuparuk Well Pressure Report 2 - 0 8 - 8 9 Sand 'A' ~ 3 O- 03 Kuparuk Well Pressure Report 1 - 0 9 - 8 9 Sand 'A' .-- 3 O- 1 5 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 ~ 2G- 1 4 Kuparuk Fluid Level Report 3-11-89 Tubing '~ 2G- 1 3 Kuparuk Fluid Level Report 3 - 1 1 - 8 9 Tubing '~ 2G-09 Kuparuk Fluid Level Report 3- 1 I -89 Tubing ~ 1 E- 0 3 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Tubing ~ 1 E- 0 5 Kuparuk Fluid Level Report · 3 - 0 9 - 8 9 Tubing 3 O- 1 8 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing ~ 3 H - 1 0 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing ~ 3 A- 0 3 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing ~ 3 H - 0 4 Kuparuk Fluid Level Report 3 - 0 4 - 8 9 Casing ~2 B - 1 4 Kuparuk Fluid Level Report 3 - 1 3 - 8 9 Casing ~ 3 O- 1 3 Sub-Surface Pressure Survey ' 2 - 0 8 - 8 9 Ct 7 2 6 6 5 e,,,, 3 ©- 1 0 Sub-Surface Pressure Survey 2 - 0 4 - 8 9 Ct 7 2 6 5 5 ~30-16 Sub-Surface Pressure Survey 1-31-89 Ct72655 ~' 1 B- 0 7 Kuparuk Fluid Level Report 3 - 3 1 - 8 8 Casing ~1 B - 0 3 Kuparuk Fluid Level Report I - 2 7- 8 8 Tubing ~ 1 B - 0 5 Kuparuk Fluid Level Report 1 - 2 7- 8 8 Tubing '"'"~1 B - 0 7 Kuparuk Fluid Level Report 4 - 2 7 - 8 8 Tubing ~,,~1B-07 Kuparuk Fluid Level Report I-27-88 Tubing ~ 1 L- 0 8 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 Tubing ~m.,~l L- 0 4 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 Tubing ~"'3 H 1 0 Kuparuk Fluid Level Report 3 - 1 7- 8 9 Cas'ng ~ 3 M-0 1 Kuparuk Fluid Level Report ~chorage , 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31- 1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M ;.State of Alaska SAPC Unocal Mobil Chevron _~.~ Co,~c ., A°Cflor4go' uOcq,7~iSsiorz l' ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report 1 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report I 2 - 1 8 - 8 7 3 F-01 Kupaurk Fluid Level Report 8-29-87 3 F-02 Kupaurk Fluid Level Report 8-29-87 3 F- 0 9 Kupaurk Fluid Level Report 8-29-87 3 F-06 Kupaurk Fluid Level Report 8-29-87 3 F- 1 0 Kupaurk Fluid Level Report 8-29-87 3 F- 1 1 Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18-87 3 N- 0 6 Kupaurk Fluid Level Report 5-22-87 3 N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report · 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report 1 2 - 0 4 - 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F-- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 1 E-25 Kuparuk Fluid Level Report 2-19-89 3 B-1 1 Kupaurk Fluid Level Report 2-20-89 3A-03 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31 - 1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M- 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing TubIng Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casin g Casing Tubing Tubin~ CasUal Casin~ ARCO Alaska, Inc. Date: February 9, 1989 Transmittal #: 7422 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 B - 1 3 Kuparuk Fluid Level Report 2 - 0 6 - 8 9 Casing 2 W - 0 1 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 2 X - 1 4 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 3 F- 1 5 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 3 A-01 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 2G-06 Kuparuk Fluid Level Report 1 -31 -89 Tubing 3©- 1 4 Kuparuk Well Pressure Report 1 0- 2 5 - 8 9 Amerada Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: · D&M state of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7296 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. I L- 0 4 Kuparuk Fluid Level Report 9 - 0 6 - 8 8 3 B - 1 3 Kuparuk Fluid Level Report 9 - 0 5 - 8 8 Kuparuk Fluid Level Report 9 - 0 5 - 8 8 Kuparuk Fluid Level Report 9 - 0 5 - 8 8 Kuparuk Fluid Level Report 9- 01 - 8 8 / I D-08 Kuparuk Fluid Level Report 9- 0 1 - 8 8 - 0 3 Kuparuk Fluid Level Report 8 - 3 1 - 8 8 Kuparuk Fluid Level Report 8- 3 1 - 8 8 Kuparuk Fluid Level Report 8 - 3 1 - 8 8 ~/ I E-06 , Kuparuk Fluid Level Report 9-1 7-88 1E-02 . Kuparuk Fluid Level Report 9-1 7-88 Receipt Acknowledged' Casing Casing Casing Casing Casing Tubing Casing Casing Casing Casing Casing DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Date: December 30, 1988 Transmittal #: 7392 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 Z- 1 4 Kuparuk Fluid Level Report 1 2- 2 7 - 8 8 Tubing 1 Y- 0 6 Kuparuk Fluid Level Report 1 2- 2 6 - 8 8 Casing 2 A- 0 5 Kuparuk Fluid Level Report 1 2 - 2 6 - 8 8 Tubing 2 X- 1 4 Kuparuk Fluid Level Report I 2- 2 5 - 8 8 Tubing 2Z- 1 3 Kupaurk Fluid Level Report 1 2- 2 6 - 8 8 Tubing 2 C- 0 9 Kuparuk Fluid Level Report I 2- 2 2 - 8 8 Casing 2 W- 01 Kuparuk Fluid Level Report 1 2- 2 2 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report I 2 - 21 - 8 8 Casing 3 @ - 1 3 Kuparuk Fluid Level Report I 2- 2 1 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 17, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 3B-13 2U-10 2W-12 2X-10 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L64 Enclosures RECEIVED E? 1 1985 Alaska Oil & Gas (.;or~s. "-.'-on Ancl~orafit~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ..... ALASKA ~ .~ AND GAS CONSERVATION CC,...~VlISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-23 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21286 4. Location of well at surface 9. Unit or Lease Name 49' FSL, 786' FEL, Sec.16, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1277' FSL, 1275' FEL, Sec.21, T12N, RgE, UM 3B-13 ,, At Total Depth 11. Field and Pool 994' FSL, 1382' FEL, Sec.21, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 2563:3 ALK 2566 , , 12".' Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 0:3/04/85 0:3/10/85 03/11/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8040'MD,6:301 'TVD 79:37'MD,6219'TVD YES [~X NO [] 1881 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cal, Gyro, CBL, CCL, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 6:3' 24" 229 sx PF "C" 9-5/8" 36.0# J-55 Surf 3658' 12-1/4" 900 sx AS III & 500 sx Class "G" & 92 sx AS I top job 7" 26.0# J-55 Surf 8023' 8-1/2" 350 sx Class G & 250 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7808' - 7780' w/4 spf, 120° phasing 3-1/2" 7655' 7397' & 7631' 7714' - 7762' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7601' - 7548' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adde ~dum, dated 7/26/85, for frac data. ,,, 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours lested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. i24-HOUR RATE I~ 28. CORE DATA , None ~i i.~,~:~ ~ ? ]985 Alaska 0il & Gas Cons. Commission Anch0rags Form 10-407 -b NOTE: Tubing was run and the well perforated on 5/16/85. CRUll/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS i FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7546' 5911' N/A Base Upper Sand 7590' 5945' Top Lower Sand 7700' 60:~2' Base Lower Sand 7868' 6164' 31. LIST OF ATTACHMENTS Addendum i 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t~ ~ .~~ Title Associate Engineer Date ~"'/~'<:~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item :27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-exPlain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6~05~85 3B-13 Frac well w/total 338 bbls diesel, 1050# 100 mesh & 11,462# 20/40 sand. Drilling ~uperintendent R :CElVED Alaska Oit & Gas i.7~;~:s. {;oi~il-~ig~loi-i D~te RETURN TL): ARCO Alaska, Inc.'~-' Post Office uux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO- 1115B P.O. BOX 100360 ANCttORAGE, AK 99510 DATE: 0~-3 0-~5 TRANSMITTAL t~O:5315 ENGINEERING TtQ%NSHITI'ED tiEKEWITH ARE THE FOLLOWING RECEIPT AND RETU}~ ONE SIGNED COPY OF THIS CDL FINAL PRINTS/SCHL/ONE * OF EACH '~ 3B-14 04-10-85 RUN 91 4695-6672 ~3$-16 04-12-85 RUN 91 .5860-7758 ~3B-4 05-U7-~5 RUN ~1 57~2-7758 ~3D-15 U4-12-U5 RUN ~1 6693-8357 ~3b-2 05-U7-85 RUN ~1 4885-8158 ~3B-3"' 05-07-85 HUN %1 4770-6495 ~2U-12 05-04-~5 RUN ~1 6100-7409 N3B-13 U4-1U-U 5 RUN ~1 5689-7921 ITENS. PLEASE ACKNOWLEDGE TRAI~SMITTAL. RECEIPT ACKNO%,LEDGLD: $. CURRIER L. JOMNb'i'oN LXXON ChLV~UN MOBIL PIIILLIPS OIL D & M NSK CLERK*BL ~H~TIiMELL~ DATE: .... STATE Ob' AL'~S~N~*BL SOhiO U N I ON K.TULIN/VAULT*FILM ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 3 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 3 K - 1 8 Kuparuk Fluid Level Report 8 - 2 7- 8 8 3 B - 1 3 Kuparuk Fluid Level Report 8 - 26 - 8 8 ' 3 Q- 15 Kuparuk Fluid Level Report 8 - 2 7- 8 8 ' ' 3N-08A Kuparuk Fluid Level Report 8 - 26 - 8 8 ~ 3 H- 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 I E- 1 2 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 '~ 3 K- 1 4 Kuparuk Fluid Level Report 8 - 2 6- 8 8 ' 31 - 0 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 1 Y- 06 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 1 Y- 07 Kuparuk Well Pressure Report 8 - 2 6- 8 8 Casing Tubing Casing Casing Casing Casing CasIng Casing Casing Both Sands Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, inc. Date: August 26, 1988 Transmittal #: 7'280 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted hereWith are the following items. Please acknowledge. receipt and return one signed copy of this transmittal. 3 H - 2 2 Kuparuk Well Pressure Report 6 - 2 9 - 8 8 Amerada 3 H- 2 2 Kuparuk Well Pressure Report 8 - 1 0 - 8 8 Sand 'A' 3 H - 1 8 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 PBU 3 K - 1 7 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 4- Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B ~ 1 3. Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing Receipt Acknowledged: DISTR!BUTIO..N; D&M State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, inc~'-'~ Post Office . .,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5292 KETURN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS 'CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED kECEIPT AND KUPARUK ~ lB-1. lB-2. ~lB-4' ' 1C-4 · lC-6~' - 1D_8_~ ~. --1H-3 -- lQ-13/ "iQ- 14-/ -.1Q_15-,'~ --lQ-16-~ .1R_5./- ' 1R-6 ~" '~lR_7/ -1R-8 ~'2A-2 ~2W_7-~, ~2¥-3 ~2W-15 3B-t 3B-2/.. 3B-3.~ ~3B-4--' - 3B-6-'- ~3B- 7-- 3B-7/ -3B-~' ~3B- 10~' -3B-11 ~ · - 3B- 12 ' 3B-13. ~3B-14. RECEIPT BPAE* B. CURRIER CHEVRON* D & M* HERE%4ITH ARE THE FOLLOWING ITEMS. RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PLEASE ACKNOWLEDGE 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO £ ' STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT WELL PRESSURE REPORT--ENVELOPE FACE DATA 05-30-~5 CAMCO ~3B- 15 . 05-30-85 CAMCO 3B-16- .... 05-16-85 CAMCO -~ 3C- 11,"" 07- 2 4- 8 5 CAMCO 07-25-85 CAMCO O 7- 30 - 8 5 CAMCO 07-30-85 . CA/4CO 06- 24- 8 5 CAMCO 06- 23 - 85 CAMCO 06- 21- 8 5 CAMCO 06- 21- 85 CAMCO 07- 05- 85 CAMCO 07-06-85 CAMCO 07- 06- 8 5 CAMCO 07- 08 - 85 CAMCO 07-04-85 OTIS 07-26-85 DRESSE~< 07-11-85 OTIS 08-04-85 OTIS 06-14-85 ???? 06-14 - 85 CAMCO 06-28-~5 OTIS 06-15-85 CAMCO 06-15- 85 CA~CO 06-26-85 CAMCO O 6- 26- 85 CA[~CO 06- 28- 85 CAMCO 06- 27- 85 CAI4CO 06-28-85 OTIS 07-18 - 85 CA~]CO 07- 20 - 85 C A/rICO 07- 20 - 85 CAMCO 07- 21- 85 CAMCO 05-29-85 OTIS 05-29-85 OTIS ACKNO~{LEDGED: DISTRIBUTION: DRILLING ¥'4. PAShER L. JOHNSTON EXXON ~'YOB I L* PHILLIPS OIL* NSK CLERK J. RATHMELL* ARCO Alaska. Inc. ~s a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-16-85 TRANSMITTAL NO: 5252 RETURN TO: TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KU PARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HEREWITH ARE THE RETURN ONE SIGNED ENGINEERING FOLLOWING ITEMS. PLEASE ACKNOWLEDGE COPY OF THIS TRANSMITTAL. OPEN HOLE (ONE * OF 3B-13 ~ 5" 2" 5" 2" 5" 2" 3B-14 FINAL PRINTS/SCHL EACH.) DIL/SFL-GR DIL/SFL-GR DEN/NEU PORO DEN/NEU PORO DEN/NEU RAW DEN / NEU RAW CYBERLOOK ~5'~' DIL/SFL-GR 2" DIL/SFL-GR 5" LITHO DEN/NEU PORO 2" LITHO DEN/NEU PORO 5" LITHO DEN/NEU RAW 2" LITHO DEN/NEU RAW 5" LONG SPACING SONIC 2" LONG SPACING SONIC 5" (AND 25" ) MICROLOG 2" MICROLOG CYBERLOOK DUAL DIPMETER-GR 03-09-85 RUN #1 3657-8014 03-09-85 RUN #1 3657-8014 03-09-85 RUN #1 5900-7989 03-09-85 RUN #1 5900-7989 03-09-85 RUN 91 5900-7989 03-09-85 RUN ~1 5900-7989 03-09-85 RUN #1 3657-8014 03-20-85 RUN #2 3311-6770 03-20-85 RUN #2 3311-6770 03-21-85 RUN ~2 6100-6774 03-21-85 RUN #2 6100-6774 03-21-85 RUN #2 6100-6774 03-21-85 RUN #2 6100-6774 03-20-85 RUN #2 3311-6731 03-20-85 RUN #2 3311-6731 03-21-85 RUN #2 6100-6735 03-21-85 RUN 92 6100-6735 03-22-85 RUN #2 6111-6727 03-21-85 RUN #2 3311-6774 3B-16 5" DIL/SFL-GR 2" DIL/S FL- GR 5" DEN/NEU 2" DEN/NEU 5" DEN/NEU 2" DEN/NEU CYBERLOOK PORO PORO RAW RAW 04-06-85 RUN ~1 3412-7828 04-06-85 RUN #1 3412-7828 04-06-85 RUN #1 4300-7805 04-06-85 RUN #1 4300-7805 04-06-85 RUN #1 4300-7805 04-06-85 RUN 91 4300-7805 04-06-85 RUN 91 7150-7890 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING*BL W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL PHILLIPS OIL D & M*BL NSK CLERK*BL J. RATHMELL*BL SOHIO Anch,,er~ UNION K. TULIN/VAULT*FILMS ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR C'-'~Haska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-0 2-85 TRANSMITTAL NO: 5237 RETURN TO: T RANS~.~ I TT E D RECEIPT AND PRESSURE ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-ili5B P.O. BOX 100360 ANC[:ORAGE, AK 99510 HERI?..,iITH ARE THE FOLLOWING ITEMS CKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. TEST FINALS CA~:CO · lQ-9 PBU 03-30-$5./' !Y-!2 FALL-OFF 05-05-85,F/ OTIS 2E-9 STATIC GRADIENT 2E-!3 STATIC GRADIENT 2E-!4 STATIC GRADIENT 2E-!5 STATIC GRADIENT 2U-14' PRESSURE BUiLD-UP 2U-i6 ?RESSU.RE EUILD-UP 2U-16 STATIC GRADIENT 2U-=.o PRESS URE BUiLD-UP 2~-12 STATIC GRADIENT -3~Di~3: STATIC G~DIENT 06-11-85/ O6 -10-85/ 06-10-85" o -og_s - 06-17-85/ 06-06-85/ 06-!3-85/ 06-16-85 / ,,. 0 6-0 8-8 5' 05 -29 -85/ ~ ~.,~.~'~ TURN 2C-3 STATIC TEST 2D-2 24 HR PBU 03-30/3!-85 GAUGE #63132 ' 04-21/22-85 GAUGE #63137 / LYNES iH-3 PRESSURE BUILD-UP 03-03/04-85 GAUGE ~,2059 / A,RCO Alaska, Inc. ~ Post Office Bo.. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 3B-13 2W-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L25 Enclosures ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA(.. _AND GAS CONSERVATION CO /IISSION WEI'L COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-23 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21286 4. Location of well at surface 9. Unit or Lease Name 49' FSL, 786' FEL, $ec.16, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1277' FSL, 1275' FEL, Se¢.21, T12N, RgE, UM 3B-13 At Total Depth 11. Field and Pool 994' FSL, 1382' FEL, Sec.21, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25633 ALK 2566 12, Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/04/85 03/10/85 03/11/85*I N/A feet MS LI 1 171 Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8040'MD,6301 'TVD 7937'MD,6219'TVD YES [~X NO [] 1881 feet MDJ 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Ca1, Gyro, CBL, CCL, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 63' 24" 229 sx PF "C" 9-5/8" 36.0# J-55 Surf 3658' 12-1/4" 900 sx AS Ill & 500 sx Class "G" & 92 sx AS I top job 7" 26.0# J-55 Surf 8023' 8-1/2" 350 sx Class G & 250 s) AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7808' - 7780' w/4 spf, 120° phasing 3-1/2" 7655' 7397' & 7631' 7714' - 7762' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7601' ~ 7548' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ll~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '::~ Form 10-407 * NOTE: Tubing was run and the well perforated on 5/16/85. TEMP/WC46 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7546' 5911' N/A Base Upper Sand 7590' 5945' Top Lower Sand 7700' 6032' Base Lower Sand 7868' 6164' 31. LIST OF ATTACHMENTS Well Hi.~nrv (e. omnletion details1 ., :32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ OJT~ ~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing toot. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report - Daily Instructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Alaska ICounty, parish or borough North Slope Borough Laaae ADL 25633 or Unit Title Comp let ion Field IState Alaska Kuparuk River Auth. or W.O. no. AFE 604437 Roll'N 4 API 50-029-21286 IWell no. 3B-13 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete IDate IHour 5/13/85 Date and depth aa of 8:00 a.m. 5/14/85 5/15/85 Complete record for each day reported ARCO w.I. Prior status 56.24% if a W.O. 1000 hrs. 7" @ 8023' 7937' PBTD, 8040' TD, Rn'g 3½" compl 10.2 ppg NaC1/NaBr Accept rig @ 1000 hrs, 5/13/85. ND tree, NU & tst BOPE. RU DA. TIH & perf w/4" gun, 4 SPF, 120° phasing f/7808'-7780', 7714'-7762'. TIH, perf w/5" gun, 12 SPF, 120° phasing f/7601'-7548'. Rn GR/JB. TIH w/WD pkr & tail, set pkr @ 7631'. RD DA. RU flowln, RIH w/3½" compl string. 7" @ 8023' 7937" PBTD, 8040' TD, Rn'g temp tl 10.2 ppg NaC1/NaBr FIH w/3½" compl string. Instl SSSV & tst contrl in to 5000 psi. Stab into pkr @ 7631', unstabbed, rev'd circ hole. Att to verify that seals are stung into pkr. RU WL unit, TIH w/temp log/CCL. Verified seals are stung in pkr. Found leak in orifice. -,7 The above is correct Signature For form preparation and distribujl'on, see Procedures Manual, Section Drilling, Pages 86 and 87. Date 6/12/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. ',Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District I County or Parish Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25633 Auth. or W.O. no. Title AFE 604437 Completion State Alaska IWell no. 3B-13 Roll'N 4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 5/16/85 Date and depth as of 8:00 a.m. API 50-029-21286 a.R.Co. W.I. 56.24% Date 5/13/85 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1000 hrs. 7" @ 8023' 7937' PBTD, 8040' TD, RR Crude w/diesel cap Fin WL rn. No secondary leak. RIH w/SL & latch circ vlv, TOH. Vlv stuck in open position. TIH w/new ¢irc vlv, POOH. Press tbg to 300#. Tst contrl ins to 5000#. Lnd tbg. Drop ball. Set pkr w/2500#. Shear pins in PBR. Re-lnd tbg. Tst ann to 2500#. · Set BPV. ND BOPE. NU & tst tree. Displ well'w/30 bbls diesel, followed by 230 bbls crude. Tst SSSV. Shear out ball. Set BPV. RR @ 0400 hfs, 5/16/85. Old TD New TD PB Depth 8040' 7937' PBTD Released rig Date K nd of r g 0400 hrs. 5/16/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil . . ' . Single . '. ' Prod~J.c ng method ' ' '' " ' '1 Official reservoir name(s) '. ' Fle~i~g I Kuparuk Sands Potential/test data Well no. Date Reservoir Producing Interval Oil or gas Test time ,~- rio Oil on test ....... Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date The above is correct ~ _~,.,,.~ 6/12/85 For form preparation a%d dis]rib~on, --'- see Procedures Manual, Section I0, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 31, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-13 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3B-13. I have not yet received the well history. When I do, I will forward a copy to you. Also, the tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L23 Enclosures JUN :':' Alaska Oil & Gas Cons, Co[['lm[ssion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALASKAC AND GAS CONSERVATION col' ',ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-XIX ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ' 85-23 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21286 , 4. Location of well at surface ;~",..:'; ;i':: ..... 9. Unit or Lease Name 49' FSL, 786' FEL, Sec.16, T12N, RgE, UMji'~'~"'~ ' Kuparuk River Unit At Top Producing Interval ; ~ 10. Well Number 1277' FSL, 1275' FEL, Sec.21, T12N, R9E, UM ur',.,,- i 3B-13 At Total Depth ~.~. H~ 11. Field and Pool 994' FSL, 1382' FEL, Sec.21, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 85' RKBJ ADL 25633 ALK 2566 12. Date Spudded 03/04/85 13. Date T.D. Reached 03/10/85 14. Date Comp., Susp. or Aband.03/11/85 J 15. Water Depth, if offshore N/A feet MS L 116' N°' °f C°mpleti°ns None 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey [ 20. Depth where SSSV set I 2l. Thickness of Permafrost 8040'MD,6301 'TVD 7937'MD,6219'TVD YES r~x NO [-I N/A feet MD 1600' (Approx) 22. TvPe Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cal, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 63' 24" 229 sx PF "C" 9-5/8" 36.0# J-55 Surf 3658' 12-1/4" 900 sx AS Ill & 500 sx Class "G" & 92 sx AS I top .~ob 7" 26.0# J-55 Surf 8023' 8-1/2" 350 sx Class G & 250 s: AS I ,, 24. Perforations open to Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Fiow Tubing casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr') Press. 24-HOUR RATE ~ 28. CON E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R[CEiV[D Naska 0i! & ~n-_ r ...... .~ Form 10-407 GRU9/WC04 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. · GEOLOGIC MARKERS FORMATION TESTS · NAME _ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7546' 5911' N/A Base Upper Sand 7590' 5945' Top Lower Sand 7700' 6032' Base Lower Sand 7868' 6164' 31. LIST OF ATTACHMENTS w~ ~,,,~y, n ........ ~ ~,,rvey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ .~U~_.2 Title Associate Engineer Date ~-.~)-a~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and'Gas Company g~ Well History - Initial Report - Daily InstructiOns: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or w~rkover operations are started. Daily work prior to sl:~Jdding should be summarized on the form giving inclusive dates only. District I County, parish or borough [State Alaska . I North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ITitle ADL 25633 I 3B-13 Auth. or W.O. no. AFE 604437 J Drill Parker 141 API 50-029-21286 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begUnspudded IDate3/4/85 ]Hour 0830 hrs. IPri°rstatusifaw'O' Date and depth as of 8:00 a.m. 3/05/85 3/06/85 3/07/85 3/08/85 The above is correct Complete record for each day reported 16" @ 63' 1888', (1825'), Rm'g 30' to btm Wt. 9.2+, PV 12, YP 18, PH 9, WL 16, Sol 5 Accept rig @ 2300 hrs, 3/3/85. NU diverter sys. Spud well @ 0830 hrs, 3/4/85. Drl,DD & surv 12¼" hole to 1888'. 1224', 3.1°, S19.5E, 1223.98 TVD, 1.37 VS, 1.45S, 0.51E 1491', 12.1°, S06.5E, 1488.30 TVD, 35.80 VS, 37.05S, 7.12E 1802', 22.7°, S05.5E, 1786.64 TVD, 121.93 VS, 123.52S, 4.04E 9-5/8" @ 3658' 3569', (1681'), Displ cmt Wt. 9.8, PV 10, YP 13, PH 9, WL 14, Sol 11 Drl f/1888'-3692', circ, 10 std short trip, circ, POH. RU & rn 84 ]ts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3658', FC @ 3569'. (TD @ 3692'). Cmt w/900 AS III @ 12.2 ppg, followed by 500 sx C1 "G" w/2% S-1 & .2% D-46 @ 15.8 ppg. Displ cmt w/mud. 1969', 25.5°, S5W, 1939.08 TVD, 190.08 VS, 191.45S, 1.90W 2562', 43.3°, S9.5W, 2427.21TVD, 522.04 VS,. 521.10S, 41.64W 3437', 43.2°, S9.5W, 3058.98 TVD, 1127.17 VSs-llI8.62S, 138.95W 3651', 42.9:°, SgW, 3215.36 TVD, 1273.19VS-~;~i}262.~80S,,162.43W 9-5/8" @ 3658' 5196', (1627'), Drlg Wt. 8.8+, PV 5, YP 12, PH 10.5, WL 16, Sol 5 Fin displ'g cmt, bump plug w/1500 psi. CIP @ 0614 hrs, 3/6/85. ND diverter. Perform top job w/17 bbls AS I @ 16.0 ppg. NU & tst BOPE. PU BHA, GIH, tst csg to 1500 psi. DO cmt & flt equip + formation to 3712'. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 3815', trip f/turbo drl, drl to 5196'. 3651', 42.9°, S9.0W, 3215.36 TVD, 1273.19 VS, 1262.80S, 162.43W 4116', 46.7°, S7.4W, 3545.31TVD, 1600.83 VS, 1587.11S, 209.16W 4652', 47.3°, S5.2W, 3910.86 TVD, 1992.74 VS, 1976.75S, 252.18W 4873', 47.5°, S6.0W, 4060.45 TVD, 2155.32 VS, 2138.65S, 268.05W 9-5/8" @ 3658' 6720', (1524'), Drlg Wt. 9.2, PV 6, YP 9, PH 9.5, WL 8.8, Sol 6.5 Drl & surv 8½" hole to 6720'. 5369', 48.1°, S0.3W, 4393.62 TVD, 2521.66 VS, 2505.53S, 288.24W 5867', 44.7°, Sll.7W, 4737.05 TVD, 2882.16 VS, 2864.19S, 325.94W 6055', 44.4°, S9.9W, 4871.03 TVD, 3013.84 VS, 2993.74S, 350.65W 6569', 47.5°, S10.8W, 5228.41TVD, 3382.84 VS, 3357.16S, 417.02W For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 4/25/85 ]Title Anch0rag~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has Peen assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I or Parish I State Alaska County North Slope Borough I Alaska Field ILease or Unit Well no. Kuparuk River ADL 25633 3B-13 Auth. or W.O. no. JTitle AFE 604437 I Drill Operator ARCO Alaska, Inc. Parker 141 A.R.Co. W.I. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 3/08/85 3/09/85 thru 3/11/85 API 50-029-21286 [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56,2470 Jabandonment of this well I IHour J Prtor status if a W.O. 3/4/85 ! 0830 hrs. I 9-5/8" @ 3658' 6720', (1524'), Drlg Wt. 9.2, PV 6, YP 9, PH 9.5, WL 8.8, Sol 6.5 Drl & surv 8½" hole to 6720'. 5369', 48.1°, S0.3W, 4393.62, 2521.66, 2505.53S, 288.24W 5867', 44.7°, Sll.7W, 4737.05, 2882.16, 2864.19S, 325.94W 6055', 44.4°, SD.DW, 4871.03, 3013.84, 2993.74S, 350.65W 6569', 47.5°, S10.8W, 5228.41, 3382.84, 3357.16S, 417.02W 7" @ 8023' 7937' PBTD, (1290'), RR Brine Drl & surv to 8025', make 45 std short trip. RU & rn DIL/SFL/SP/GR f/8022'-3658', FDC/CNL f/8022'-7350' & 6500'-5900', Cal f/8022'-3500', Shot 30 SWC f/5675'-645~, rec'd 25 cores. TIH, C&C, TOH, LD DP. RU & rn 200 .j~_/~, 7", 26#, J-55 BTC csg w/FS @ 8023', FC @ 7937'. Cmt w/~j~ sx C1 "G" @ 15.8 ppg. Displ w/brine, bump plug. Blow brine f/csg. slips & cut 7" csg. NU wellhead & tst pack-off to 3000 psi. hrs, 3/11/85. Moving to 3B-14. 6874', 46.1°, S14.5W, 5437.20, 3604.31, 3574.10S, 465.71W 7375', 39.6°, S19.2W, 5804.50, 3940.58, 3900.19S, 564.47W 7780', 38.3°, Sl9.3W, 6119.47, 4189.92, 4140.56S, 648.41W 8000', 34.7°, S26.0W, 6296.32, 4316.28, 4261.33S, 698.80W PU BOP, set RR @ 0500 Old TD Released rig INew TD Date 8025' (3/8/85) PB Depth Kind of rig 7937' PBTD 0500 hrs. 3/11/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas peri pUmp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective corrected , or~s, C0~lmission c~t'i ~, The above is correct ~"~'~' Signature (~~._. ?..,~. ,~alL./,.4.2, ~.._ I D at e ITi,lo 4/25/85 Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. S UB-$ URFA CE DIRECTIONAL SURVEY [-~ UIDANCE [C~ONTINUOUS rT-looL Company ATLANTIC RICHFIELD COMPANY Well Name 3B-13 (49'FSL, 786'FEL~ S16~ T12N~ R9E~ UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 70316 Logged By: WEST RECEIVED Date 24-APRIL- 1985 ~ ~o~ Computed By: CUDNEY Alaska Oil & Gas Cons, Commissior~ * SCHbUMB£RGER * GCT DIRECTTONA[, SURVEY CUSTOMER LISTING FOR ARCO AbASKA, INC, 3B-13 I~UPARUK ~ORTH S60PE,AbASKA SURVEY DATE: li APR 95 ENGINEERI T.: WEST HETHOD$ OF COMPUTATION ToOL L, OC~TTON: TANGENTIAb- averaoed deviation and azimuth TNTERPObAT~ONt LINEAR VERTICAL 5ECTION~ HOR~Z, DIST, PROdECTED ONTO A TARGET AZIMUTH OF SOUTH 7 DEC 35 MIN WEST ARCO ALASKA, INC. 3~'13 KUPARUK NOR?H 15LOpE,ALA15KA TRUE hUB-SEA COUR15E EASURFD VERTZCAL VErTiCAL DEVTATZON AZIMUTH DEPTH DEPTH DEPTH DEG MTN DEG M~N 0,00 lO0,O0 200,00 300,00 400,00 500 O0 60O O0 700 O0 ~00 O0 qO0 O0 :. 199 299 399 499 599 699 799 899 O0 98 91:t COMPUTATION DATEI 24-APR-85 DATE OF SURVEY= 11 APR 85 KELLY BUSHING EbEVAT~ONI ENGINEER{ T,: WEST XNTERPOLATED VALUE15 FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGbEG RECTA.NGUbRR cOORDINATES HORXZ, DEPARTURE S~CTXON SEVERXTY NORTH/SOUTH ERST/WEST DXST.. AZ~NUTH FEET DEG/100 FEET FEET FEET DEG MIN 1000 IlO0 120o 1~00 140~ 1500 0 0 N 0 0 £ 0.00 0 20 8 53 ? E 0.85 0 17 ~ 78 ~ ~ 0 Il S 59 50 E 1.13 0 8 S 34 37 ~ 1.32 0 4 S ~0 14 E !.50 0 I $ 76 43 ~ 1.58 0 ! S 57 32 W 1,60 0 2 S 68 53 E 1.61 0 5 S 69 45 E 1,64 -85 O0 14 98 31~ 98 414 98 ~14 98 614 08 714 08 814 98 0 ? ~ 73 41 E 1.?0 0 10 ~ 61 i3 E 1.76 I 5~ S 17 28 E 2.70 S ~.1 47 F 9,66 S 9 46 E 23.35 S 4 14 E 42.51 S 4 2 ~ 65.]5 ~ 6 33 W 95,67 S 3 36 W ~33,28 S 2 $ W 173,39 O0 999 98 914.98 O0 1099 98 1014.98 O0 1199 97 1114.97 O0 i299 65 1~14,65 6 29 O0 1308 58 i313.58 tO 7 O0 1496 6t 1411.61 12 10 O0 1593 80 1508.89 15 4 O0 1689 14 1604.14 20 10 O0 178176 1696.76 23 0 O0 1873 29 1788.29 24 57 2000 O0 19~3 17 1~78,17 ~7 4 2100 O0 205~ ~4 1966.24 ~9 34 2200 O0 213 0 2n51.99 ]2 18 2300 O0 22~0 16 2135.16 35 11 2400 O0 ~30027 23_15 27 38 18 2700 O0 25~10i 2436.01 44 46 2800 O0 ~59! 97 2W06.q? 44 44 2900 O0 2663'16 2~78.i6 44 33 S 2 8 W 8 3 0 W $ 3 35 W S 3 55 W ~ 4 51 W ~ 5 50 W S 6 43 W 8 6 46 W S 7 13 W $ 7 4 W 217 01 264 18 315 46 370 84 430 57 494.~0 562.99 633.33 ?03.80 774.02 $ 6 46 W 844.i7 S 7 21 W 914.31 S 7 28 W 984, 09 $ 6 53 W 1053,59 S 6 32 W 1122.?0 $ 6 2 w 1191.26 S 5 50 W 1259,21 $ 5 3? W 1327,43 S 5 39 W 1397,89 S 5 33 W 1470.13 3000 O0 2734 4~ 2649,42 44 36 3100 O0 ~805 70 2720.70 44 29 3200 O0 2877 32 2792.32 44 4 3300 O0 ~949 2! 2m64,~1 43 55 3400 O0 3021 48 2936.48 43 31 3 oo oo 2? 3oo , 7 43 3600 O0 3167 60 308~.60 42 43 3700 O0 12406Q. 315S.69 43 35 3800 oo 13 1 eo 32 6.6o 45 54 3900 O0 ~390 ?1 3~95.?! 46 31 0 O0 0 38 0 Om 0 4 o 0 09 0 O9 0 05 4 42 2 08 ! 21 66 2 '78 3 48 2 86 25 0 $2 0 1~ 1 O2 0,16 0,77 0.16 0.20 0.68 0,83 0.62 2.03 O, 0 O0 N 0 85 S 1 14 S 1 25 S 48 s ~ 67 S 182 S 0 O0 E 0 09 w 0 43 F. 0 84 E 1 07 E 1 10 E I 13 E 124E PAGE I 85,00 F'T. 86 S 6 14 W 22 S 20 31 E ! S 33 56 E 2 S 35 $3 E 09 s 33 j 10 S3 20 S 34 21 E I 91. S 200S 44 8 S 67 16 S 97 6 S i34 78 S 75 O0 S I 43 E 1:67 E 2,12 E 3.96 E 6 70 E 5 63 E 2 0 44 67 97 39 E 134 60 E 175 39 S 36 52 E 60 S 3954 E 68 1535 10 E 01 S 21 6 E 35 15 15 19 E 97 S 11 28 E 81 S 7 54 E 82 15' 3 18 E 0 S 1 0 E O0 S 0 11 i 3i7 372 432 496 564 04 773 80 S 10 S 43 S 83 S 47 S 27 S 25 S 0 97 w 3 6 9 14 20 27 ~6 44 53'62 W 775 O~ 04 ~ 317 63 ~ 37 24 w 43) W 564 O3 W 635 72 W 705 g5 S 1 28 W 71 S 1 53 W 68 S 2 t9 W 94 15 2 49' 1~,4 S 3 15 $ 3 38 ~ 56 5 3 57 W 843 9{2 982 1051 1255 1323 1393 1465 37 S 99 S 19 S 79 15 S 88 79 $ 96 96 S 103 S 110 64 S 124 56 S 131 61 92 W 845.64 S 4 tl W 70 43 W 915 71 S 4 24 W 51W 985 17 W 1054 6 W 1123 ~4 w 1192 76 W 1260 62 W 1328 49 W 1399 69 W 1471 40 S 4 37 W 84 15 4 47 W 92 S 4 54 W 48 S 4 59 w 45 S $ 2 W 69 15 5 4 w 19 S 5 6 W 47 15 5 8 W 0 O0 N 0 0 E ARCO ALASKA, THC, 3R"13 KUPAR!IK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTTCAE DEV{ATION AZIMUTH DEPTH DEPTH DEPTH D£G, M~N DEG. COMPUTATION DATEI 24-APR-85 DATE OF SURVEY{ ~1 APR 85 KELLY BUSHTNG EhEVATZON{ ENGZN~ER{ T,'WEST INTERPOLATED VALU£$ FOR EVEN 100 FEET OF MEASURED DEPTH VERTTCAL DOGLEG RECTANGULAR COORDXNATES HORXZ,, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG PAGE 2 85°00 PT 4000,00 3449 29 3364 29 46 49 4100.00 3517 65 343~ 65 46 52 4200.00 3585 91 3500 91 47 5 4300,00 3654 4400.00 3722 45OO O0 37o0 4600:00 3858 4700.00 39~6 4800,00 39~3 4900,00 4060 05 3569 05 47 0 22 47 14 4838 90 ,48 47 35 89 397~.89 47 43 5000 O0 41~8 19 4043,]9 47 45 5i00 O0 4195 36 4110,36 47 46 5200 O0 4262 43 47 53 5]0O 5400 5~00 56O0 5700 5800 5900 O0 4329 O0 4396 O0 4463 O0 4531 O0 4600 O0 4671 O0 4741 4177.43 5~ 4244.52 47 53 5 4311.55 47 54 0 4378,70 47 3~ i7 4446,87 46 45 72 4~15,72 45 37 16 4586,16 45 3 89 4656,89 44 5~ 6000 O0 4812 94 4727.94 44 40 6100 O0 4884 10 4799,10 44 32 4870,00 45 ~ 494~,02 500 .89 6200 O0 4955 630O O0 50~5 640O O0 5093 6500 O0 5161 6600 O0 52~9 6700.00 5296 6gO0.O0 5364 6900.00 ~432 O0 02 45 56 89 46 57 63 5076,63 47 41 O~ 5144.02 47 30 38 5211,38 47 33 20 5279.90 46 59 9~ 5347.92 46 5 000,00 ~502,47 5417,47 45 37 ~100,00 5573,13 5489.13 44 3~ 7200,00 5645,04 5560,09 43 10 7300,00 5719,16 5634,16 41 6 7400 O0 5795,63 5710.63 ~9 11 7500 O0 5874,20 5780,~0 37 24 7600 O0 5953,36 586~,]6 38 7700 O0 6031,90 5946,90 ]8 13 800 O0 6110,43 6025.43 38 7 900 O0 6189,70 6104,70 37 S 5 8 W 1542,85 S 4 58 W 1615,76 $ 4 4] W 1688,76 S 4 27 W 1761,84 S 3 56 W 1834'89 S 3 41W 1907,98 S 3 19 W 1981,18 S 3 3 W 2054,48 ~ 2 59 W 2128,04 S 4 25 W 2201,75 ~ 3 49 W 2275.59 S 3 8 W 2349'48 S 2 35 W 2423.40 ~ 2 it W 2497.25 S' I 52 W 2571 ~ 1 48 W 2644 82 S 5 41W 2717 83 ~ 7 25 W 2790 32 S 10 9 W 2861 26 S 10 8 w 293.1 87 S 10 0 W 3002 17 S 9 35 w 3072 ~8 S 8 46 w 3~49 86 S 7 46 W 3214 ~6 ~ 7 58 W 3286 75 S 8 6 W 3360 31 S 9 15 w 3434:18 S 10 37 W 350. 03 S 12 23 W 3581 34 S 14 17 W 3653.62 S 16 11W 3724.79 $ 15 20 W 3794 8, 4 ~ 15 45 W 3863,62 S 16 29 W 3930.09 $ 18 21 W 3993,57 ~ 20 15 w 4054,32 S 20 34 W 411].63 S 20 31W 4173.98 S 90 6 W 4234,]5 S 91 29 W 4293.72 0 64 0 9 o 0 4~ 0 42 0 20 0 2 ~ 0 47 0 86 0 $~ 0 77 0 49 0 0 0 I 0 4 0 0 0,3~ 5 ilo 0,3 0,96 1,72 1,56 1,66 I O0 0 84 2 26 2 3O 2 23 ! i4 0 61 0 O0 1538 .02 S 138 49 W 1544 25 S 5 8 W 1610 72 S 2'3 S '5 8 W ,31 S · 5 7 W 1683 1 1902 1975 204 212~ 21P6 144 54 S 1~1 50 S 156 48 S 162 56 S 167 Il S 171 ! S 175 92 S 179 60 8 184 7 S 189 2 S 194 0 S' 198 49 S 201 5S~ 03 2 S ~06 68 S '211 83 $ ~4 38 S 2 89 W t617 09 W 1690 84 W 1763 22 W 1836 08 W 1909 59 W 1983 69 W 2056 49 w 2130 54 W 2204 49 S '$ 6 ~ 66 S 5 4 W 89 $ ~ $ 4 54 ) S 4 49 W 34 $ 4 48 W 95 W 2278 30 S 4 46 W 44 W 2352 37 S 4 44 W :56' ~41 33 43' ~566 62 2640 72 2713 39 2785 48 2855 40 2925 ~994 66 $ 3063 3133 3204 3275 3348 3421 3494 3566 3637 25 89 S 26~ 50 S .278 S 298 83 S 308 86 S 320 68 S 332 67 S 347 39 S 364 3706 63 $ 383 3774 76 S 402 420 3841 3906 3967 40~6 4083 4141 4199 4256 68 S' 28 S 439 76 $ 458 1 S 479 ~7 S 500 29 $ 522 33 8 543 35 $ 565 50 S 4 41W W 2574 05 W 2648 19 W 2721 9O W 2794 w 2865 ,60 S 4 '36 W 73 S 4 32 W 74 S 4 27 W 89 S 4 27 W 37 $ 4 29 W 10 S '4 36 W 45 S 4 44 W 30 W 3005 52 S 4 52 W W 3075 53 S 4 59 ~ ~ W 3145 81W 3217 63 W 3289 92 W 3363 05 W 3436 69 W 3510 43 W 3583 03 W 3655 86 $ ~ 4 W $ $ 12 W 05 S 5 16 ~ 80 S 5 20 48 S S 26 ' 56 S 5 33 ~ 56 S 5 42 ~ 0 W 3726 0 W 3796 84 W 3864 23 w 3930 54 w 3994 04 W 4054 6~ W 4113 17 w 4174 7! W 423 29 W 429~ 39 S 5 54 W 14 S 6 5 W 66 S 6 15 W 90 $ 6 24 W 16 $ 6 35 W 51 S 6 47 W 85 $ 6 59 W 08 S 7 11 W 38 S 7 22 W 72 $ 7 33 W COMPU?ATIfiN DATE= 24-APR~B5 PAGE 3 ARCO AbA~KA, INC, DATE OF SURVEY! ll APR 85 3F-13 K£LbY BUSHTNG ELEVATIONI 85,00 KUPARIIK N~RTH SLOPE,ALASKA ENGINEERI T, WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRU~ SUB-SE~ COURSE VERT)CAb DOCbEG R£CTANGUbAR COORDINATES HORtZJ.~DEPART'URE EASU~ED V~R?ICAL V£RT)Cab DEVIATION AZIMUTH S~CTXON SEVERITY NORTH/SOUTH ERST/WEST DIST'- AZIMUTH DEPTH DEPTH DEPTH PEG MTN DEG MIN FEET DEG/100 FEET PEET FEET DEG 8000 00 62&9 35 6184,15 37 ~! s 2! 22 w 4352,44 o,oo 43t2,65 s $a?'33 w 43~g.,46 $ ? 45 8040:00 63o~:2! 6~i6,2i 37 i! s 21 22 w 4375,g2 o,o0 4335,17 s SE6,14 w 4375,g& 8' I 49 ARCO ALASKA, ~NC, KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH D£P?H OEPTH DEG 0,00 1000.00 999 2000.00 19~3 3000 O0 27~4 4000:00 ]449 5000,00 4128 6000,00 4812 5502 7000,00 8000,00 6269 8040,00 COMPUTATION DATE:*24-APR-85 PAGE 4 DATE OF SURVEY{ [1 APR 85 - KELLY RUSHING ELEVATION{ 85,00 FT ENGIN£ERI T,. WEST iNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT ! VERT?CRb DOGLFG RECTANGULAR coORDINATES HOR~Z,.'DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST,: AZIMUTH FEET DE~/IO0 FEET FEET FEET DEG MXN N 0 o E 0,00 S ?3 41F 1,?0 S 2 8 W 217 O1 S 6 46 W 844 17 S 5 R W 1542 85 S 3 49 w 2~75 59 ~ lO 0 w 300~ 17 ~ 16 11 w 3?24 ?9 ~ ~!2~ W 435~,44 8 21 22 ~ 4375,g2 0 O0 -8~,00 O' 0 1878 4721 q4 44 4? 5417 47 45 37 3~ 618.4 35 37 21 6216 0,00 0,11 2 21 0 0 ?? 0 ~7 1 O0 0 O0 0 O0 000 N 0 1 0 02 S 138 218 843 1538 2270 2994 3706 4 4~~2 ~5 91 S 80 $ 3? S 3? S 189 66 S 255 63 8 383 65 S 58'7 '1 ? S 596 O0 E 0'~00 N 0 0 E 43 E 2.'39 $ 36 52 E 9? W 2i8,80 S 0 15 W 92' W 845,64 $ 4 1 49 W 1544,2~ S 5 8 30 W 3005,52 $ 452 ' ~ W 4352,46 S ? 45 b 14 ~ 4375,96 $ ? 49 ~ ARCO ALASKA, TNC, 3R-13 KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE IERSURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG M~N 0..O0 0 00 -8~.00 0 0 85 02 85 O0 0,00 0 17 185 02 Z85 O0 100,00 0 18 285 02 285 O0 200.00 0 12 385 02 385 O0 300.00 0 10 485 02 485 O0 400,00 0 5 ~85 02 585,00 500.00 0 68~ 02 685 O0 600.00 0 2 785 02 785 O0 ?00.00 0 885 02 885 O0 808.00 0 085°02 985 O0 900.00 0 ? oo ,ooo.oo o 1386.20 1385 O0 ~300o00 9 47 148~,12 1485 O0 140n.00 12 1590,8{ t585.00 l~O0,O0 14 37 1695.59 1685 O0 1600,00 !9 56 1803.,2 i7~ ~ 1700,00 23 1912.92 ,8 1800.00 25 15 oo o,.oo oo ooo.oo 2257~ ~185 O02100.0033 55 oo = oo.oo 2510 ,64 2385 O0 2300,00 ~1 50 2~49.28 2485 O0 2400,00 44 43 2790 .~0 2585 O0 2~00.00 44 45 oo oo:go O1 ~7~5 O0 2700 0 44 29 3~10~69 2885 O0 2800.00 44 3349.63 ~985 O0 200n,00 43 41 3487.32 3085 O0 3000,00 43 3623.?0 3185 O0 3100 O0 42 51 3761 98 3285 O0 3~00,00 45 10 3906 25 3385O0 3300,00 46 33 4052 22 3485 O0 3400,00 46 51 oo oo.oo 47 4 4345.41 3685O0 3600.00 47 1 4492,21 3785 O0 3700.00 47 4639.45 3885 O0 3800.00 47 17 COMPUTATION DATE{ 24-APR-85 DATE OF SURVEYI 11 APR 85 KELLY BUSHING ELEVATION{ ENG{NEERI T,' WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTTCAL DO,bEG SECTION SEVERITY FEET DEG/$O0 N 0 0 E 0.00 ~ 60 22 E 0.82 ~ 76 24 E 1.07 S 65 22 E g 36 48 E 1,29 ~ 24 23 E 1,48 S 56 36 W 1.57 S,! 32 w .6 ~ 8 7 E ~,6 1.70 1.75 ~..32 8.15 21 08 40 05 63 02 94 15 134 66 178 84 S 64 46 E S 65 52 E S 18 34E S 12 30 E $ 2 53 W S 6 46 W S 3 W S ~ 30 W ~ 2 16 W 228.25 S 3 15 W 283,66 S 3 42 W 346,72 S 4 4i W 418,63 $ 5 57 W 501,64 S 6 4i W ~9~,62 S 7 13 W 696.90 S 6 45 W 795,54 S 7 6 W 894.01 S 7 25 W 991, S 6 42 W 1087,97 ~ 6 5 W 1182.61 S 5 50 W 1275.30 $ 5 34 W 1370.74 ~ 5 32 w 1474,66 $ 5 0 W 1580,92 S 4 43 W 1687,79 S 4 13 W 1795,01 S 3 42 W 1902,28 S 3 13 W 2010,07 0 00 043 0 I0 0 18 0 23 0 16 0 10 0 29 0 10 0 05 0.17 0.06 4,11 4,32 2,~8 1,8 5,84 5,54 1,~1 1. 7 3 6~ 0 22 0 31 ! o 0 0 .3~ 0,83 1,0! 0,66 2.44 0,68 0 7 0 o: o 0,31 PAGE '5 · 85,00 FT RECTANGU[,.a,R COORDINATES HORXZ': DEPARTURE NORTH/SOUTH EAST/WEST DiST, AZIMUTH FEET FEET FEET DEG 0,00 N 0,00 0,80 S 0,16 ,1 2 S 0,35 ,23 S 0,80 , 44 S 1,04 ,65 S 1,16 1,74 S 1,16 1,76 S 1,11 1,77 S 1,1~ 1,8i S 1,22 1908 1 98 S 2618 8708 22 150 S 41 7 S 64 83 S 95 75 S 136 15 S 180 47 S 230 08 S 85 61S 48 70 S 420 55 S 503 28 S 598 64 S 97 21S 95 07 S 892 85 S 989 56 S ]O8: 1271' 1366 1470 1575 1682 1789 1896 2004 8 ~6 67 8O 0'00 N 0 0 E 0,8' 11 26 1,,47 S 37 18 E 2 59 E 40 E 63 E 2 99 E 3 63 E 9 0 E 22 5 E 42 46 E 65 80 E 95 30 E 2 36' $ 36 26 E 56 $ 39 43 8 3, E 48 $ E 52 S a ~8 E 93 $ 3 27 E 17 S 0 58 E 47 S 0 7 E i 40 W 230 08 S 0 20 W W 285 64 S 0 49 ki 9 S 92 ]5 S 102 59 S 112 61S 121 08 S 132 98 S 141 62 S 1 86 S 166 73 S 173 348 W 50~ 8 W 599 W 797 88 W 895 48 W 992 $ 1. 19 W S 1 48 W 71 S 2 22 ~ 49 $ ~~ ~ 58 S .~ 3 06 S 4 ~ 4~ S 4 20 W 8~ S 4 ~8 W 25 W 1089 83 W 1183 40 W t 76 84 w 1372 13 w 147~ 85 W 158 Ol W 16891 40 W 1796 71 W 1904 25 ~ 2012 S 4 ~ ii S 5 8 W 5 $ 5 8 W 33 $ $ 7 ~ 71 S 5 5 N 17 $ 5 1 W 21 S 4 56 W ARCO ALASKA, INC. 3B-13 KUPARIIK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTTCAL DEVIATION AZIMUTH PEPTH DEPTH DEPTH DEG: MIN DEG COMPUTATION DATE: 24-APR-85 PAGE 6 DATE Or SURVEY! tl APR 85 ~ KELLY aUSHING EbEVATIONt 85,00 ENGINEER{ T,: WEST 1HTERPOLATED VALUES FOR EVEN 100 FEET OF SU~-SEA DEPTH VERTTCA~ DOGLEG RECTANGULAR COORDINATES HOR~', DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/~00 FEET FEET FEET PEG 4935 4085 5084 ~ 4185 523~ 64 4285 5~8 76 4385 553~ 46 4485 6101. 48 4787 43 3985 O0 3000.00 47 37 O0 4000.00 47 42 ~ 4,00· 47 46 4200.~ 47 51 0 440O.O0 47 4600. 45 ~ 4,00. 44 4800,~ 40 44 3~ S 2 54 W 2t18.80 S 3 14 W 2338~t0 ~ 1 56 w 2558;37 S 6 24 W 2774~{3 S 10 16 W 2875.12 S 10 6 W 2074,59 S 9 34 W 3073.26 6242 67 4985 6386~98 5085 6934.72 ~185 6683 10 5285 6830 47 5385 6974 86 5485 7116 63 ~585 7254 99 ~685 ~86 26 5785 13 59 5685 O0 4900 O0 45 30 S B 18 W 3173 20 O0 5000 O0 465~ S 7 55 W 327~ 24 O0 5100 O0 47 40 S 8 24 ~ 3385 99 O0 5200 O0 47 36 S 10 21W 3495 55 O0 5300 O0 46 58 S 12 48 w 3603 52 O0 5400 O0 45 49 S 15 57 W 3707 06 Oh 5~00 O0 44 29 S 15 2~ W 3806.39 O0 5600.00 42 10 S 15 45 W 3900,05 O0 5,00.00 39 27 S 18 9 w 3085.02 O0 5800.00 37 20 ~ 20 26 w 4062.17 7640.28 5985 O0 5900.00 38 17 7767,62 6085 O0 6000.00 38 16 7894.10 61m5 O0 6100.00 37 8019.64 6285 O0 6200.00 37 8040,00 6301 21 6216.21 37 S 20 13 W 4137.94 S ~0 13 W 4214.80 S ~1 2~ W 4290,26 S 21 22 W 4363.97 S 21 22 W 4375,92 0 52 0 60 0 53 0 29 0 19 09 8! 26 ~44~ 2553 2663 2769 2869 2967 3064 01 $ 186 57 w2230-,$2 $ 4 47 W 92 S 193 80 W ~340,95 S 4 44 W 31S 199 23 W 2451,42 S 4 39 W 85 S 203 42 W 2561.'.94 S 4 33 W 85 S 207 O0'W 2671;88 S 4 26 W 48 S 250 48 W 297';0' S 4 49 W 18 80 02 02 3492;40 S ,34 3588.40 S I 3689.40 S 12 3785,99 $ 70 3959,49 S 61 4033,85 S 0,38 oo oO:O° O0 · 3266.56 S 2 3374'24 S 31!2 59 Wi33 8 69 S 5 I W 330 43 W 3498 04 S 5 25 3! W 3605 66 S 5 36 W ~ 23 W 3708 74 '$ 5 51W 4106 65 S 4 52 S 4323 71 S 4335 17 S 509,28 w 4118.10 S 7 4 ~ 536, 4214,84 S 7 19 W 563.~J ~ 4290..26 S ? 33 ~ 591.66 W 4364,00 S 7 47 W 596,i4 W 4375,96 S 7 49 W ARCO ALASKA, YNC. 38-13 KUPARUK NOR?H SLOPE,ALASKA MARKER TOP UPPER SAND BASE UPPER AAND T~P LOWER SAND BASE LONER ~AND PRTD TD COMPUTATION DATE~ 24-APR-85 INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 7 ,00 700,00 868.00 7917.00 ~040,00 PAGE DATE OF' SURVE¥~ 11 APR 85 . ' KELLY BUSHYN~ EI~EVATZONI 85,00 ENGINEER ~ T,:: NEST ORYGYN~: 49" FSL,786' FEL.SRC 16-T~,2N,,RgE.U~4 TVD RECTANGULAR COORDZNAT~$ FRO~ KB SU~-SEA NORTH/SOUTH EAST/WEST 59[0.'74 5825,74 5945 49 5860.49 6031:90 ~946,90 6t64.~ 6079'2! 0].~1 t 4059 2'7 S 4077 51 S 4238 S 4277 :],8 S 4335:17 S 48g,e4 498,44 ~7],44 ~96.]4 ARCO AbAE, KAw TNC, KUPARUK NOR?H si, OpE,ALASKA MARKER TOP UPPER SAND BASE UPPER SAND TOP bOWER SAND BASE LOWER SAND PRTD COMPUTATION DATE~ 24-APR-g5 MEASURED DEPTH BEI, OW KB 7546'00 7590,00 ??00,00 7868,00 79~?,00 8040,00 PAGE DATE OF SURVE¥I ]! ASR 85 KEhbY BUSHING EbEVATIONI ENGINEERI T,~ WEST SURFACE:~OCA?ZON OR~G~N~ 49' F$~w?86' FE~.$EC 16.?12N.RgE.U~ TVD RECTANGUbAR COORDZNATES FRO~ KB ~U~-8£A NORTH/SOU?H 5945.49 5860 49 4077 6301.21 6~16 21 4335 17 $ , 85,00 PT FINAh WEI, b 60CAT:ION Al" TOI TRUE SUB-SEA MEASURED VERTICAL VERTICAb DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZTMUTH FEET DEG M~N 8040.00 6301.21 6216,2! 4375,96 $ 7 49 W SCHLUMBERGER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA I NC WELL 3B- 13 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 11 APR 85 REFERENCE 0000703]6 SURFACE LOCATION: 49' FSL, 786' FEL, S16, T12N, R9E, UM VERTICAL PROJECTION 7, .... !-..i.4...4..-f4...4...;...4 ...... i.4.-.;-.-4... ;...4...4..4...4.....;~..~..~...~.......Li...i.-.i...-.~...~...,...4.4...~.-.g.-.L?!.....~...i...~.!..,..-i...i...~...4 ...... :::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,..%.+,.t..-~iil ~ ....... +-..~-..t...+ii~i ..... +"'+"+"~i':il ...... !!!!¢'"¢"4'"¢'" .4...'. :~.: ...... ~...~..4...~ ....... ~...~...~...~.-.f..~...~.4...~~{, .... 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'OPERATOR, W~I~L/NAME' AND N~3MBER Reports and Materials to be received by: ~'/O'--~- Date Required Date Received Remarks Completion Report y Core Chips Core Description Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports LoE Run Digitized Data ARCO Alaska, Inc Post Office ~.-~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 ~.~ay 3, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: ConductOr As-Built Location Plats - 3B Pad Wells 1-4, 13-16,-6-~-2--- - Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU6/LI01 Enclosures If I; ECFIV :D Alaska Oil & ~',-- C ' u ,_l,~ COr~S. OrllrlllSSiOFl ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany WELL t Y=5,991,896.45 Lat. 70°23'20.5210'' II X= 518,178.72 Long 149°51'07.675'' OG. Elev. 49.6 Pad Elev. 54.6 776' FSL 852_' FEL ~t[ WELL2 Y= 5,99,,956.26 Lat. 70° 23'2,.,094'' ~ X= 518,172.79 Long. 149051'07.845" O.G. Elev. 49.5 Pad Elev. 54.2: ,- ~, , 856'FSL 858'FEL 4®!11! 05 ' WELL 5 Y=5,992,015.79 Let 70°23'21.6951'' 30 06 i X= 518,167.27 Long. 149°51'08.000" 20 07 i O.G. Elev 49.2 Pod Elev 54.6 . o8 i,: 896' FSL 863' FEL X= 518,161.64 Long. 1490 51'08.161" I O.G. Eiev. 49.0 Pad Elev. 53.9 955' FSL $68' FEL WELL t3 Y=5,991, 169.7'1 Lat. 70° 2~'1543712" "= !"'1 X = 518,Z47.90 Long. 149° 51' 05.699" O.G. E[ev. 48.5 i:bd Elev. 55.4 49' FSL 786' FEL 96® 09 oiO WELL 14 Y=5,991,229.62 LatTO°23'l$.9607'' 15 · 0tl X= 518,242.16 Long. 149°51' 05.865" t4 · 0t2 QG. Elev. 49.0 Pad Elev. 55.4 13 · 16~,,t5 ... t09' FSL 792' FEL L .- 21~/2_2 WELL 15 Y 5,991,289.1's Let. 70°23'14.5461" ,........~_.~--~'--i X= 518,25~.44 Long. 149°51'06.026' O.G I~Lev. 49.0 Pad. Elev. 55.7 16 9'FSL 797' F E L WELL t6 Y=5,991,$48.87 Let. 70025' 15.133,9" X: 518,230.7'9 Long. 149° 51'06.188'' OG. Elev. 49.0 Pad Elev 55.4 SCALE. N T S 228' FSL 802' FEL LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12N., RANGE 9 E., UMIAT MERIDIAN. ~.~ COORDINATES ARE A.S.P, ZONE 4. SECTION LINE ~1~¢ HORIZONTAL PosITIoN PER LHD'S ON PAD PILING CONTROL PK'S .... ,,:_c:. :-.,s O.GcED_gBOO_$oo:ELEVATIONS :z,~ERPOLATED FROM S/C DWG ~ ~"~' ~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF , _ CP ~ ..- _ _..~ ALASKA AND THAT THIS PLAT REPRESENTS I SURVEY MADE ~ ._'-- · UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF MARCH 3,1cj~5 FOR WELLS 1-4&13-16. '~ ARCO Alaska, Inc. ~ ~~_~ Kuporuk Project .North S,op.e Drilling I ~ DRILL SITE 5B ! CONDUCTOR AS-BUILT ~o ~ LOCATIONS ~ " I Oate. Marc# t~1985 Scale: AS SHOWN ~ ,~ ~ ~ ,,, , / ..._ ./ Drawn By: D-d.W. Dwg. No. NSK 9.05~302d2J i! i i i ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the March monthly reports for the following wells- 1Q-3 2u-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 6 985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanlicRichfleldCompany STATE OF ALASKA *"" ALASKA O,-- AND GAS CONSERVATION CON, MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellT~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-23 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21286 4. Location of Well atsurface 49~ FSL, 786~ FEL, Sec.16, T12N, ReE, UN (Approx) 9. Unit or Lease Name Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKBI ADL 25633 ALK 2566 10. Well No. 3B-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of March ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0830 hfs, 03/04/85. Drld 12-1/4" hole to 3692'. Ran, cmtd, and 9-5/8" csg. Performed top job. Cmtd held, Drld 8-1/2" hole to 8040'TD(3/10/85). cmtd, & tstd 7" csg. PBTD = 7937'. Secured well & RR ~ 0500 hfs, 03/11/85. tstd Ran, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 63'. Cement record n~t available at this time· 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 3658'. Cmtd w/900 sx AS Ill & 500 sx Class "G". (Top job performed w/17 bbls AS I.) 7" 26 O#/ft, J-55, BTC csg w/FS @ 8023' Cmtd w/350 sx Class "G" 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/8022~ - 3658~ FDC/CNL f/8022~ - 7350', 6500' - 5900~ Cal f/8022~ - 5500~ Ran sidewall cores ~ 30 points from 5675' - 6450' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A ,', r. t t l V l: i.) /~taska 0it & t~as Cons. Commission ,~,nchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Repo~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate ARCO Alaska, Inc/'~ Post Office ax 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 T ¢~F'E b-'. , Oi'-.,,:F.-TAPE F'LU2. L]:STING) · : February 19, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupa~ak River Unit 3B-!3 ARCO Alaska, Inc. Permit No. 85-23 Sur. ~c. 49'FSL, 786'FErn, Sec. 16, TI2N, R9E, U~{. Btmhole Loc. 1030'FSL, !358'FEL, Sec. 21, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is requ~.red as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Igater Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewzn Kuparuk River Unit 3B-13 -2- Februarv 19, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enc lo s ute cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ Post Office E~o.. ,00360 Anchorage, A~aska 995J0 Telephone 907 276 1215 February 11, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3B-13 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 3B-13, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on March 6, 1985. If you have any questions, please call me at 263-4970. S/~erely, Area D4~illing Engineer JBK/TEM/tw PD/L32 Attachments qECEIVED Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~.,L AND GAS CONSERVATION CC..,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~X lb. Type of well EXPLORATORY [] REDRILL [] DEVELOPMENT OIL I~[X DEEPEN [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. SERVICE [] STRA~-~RAPH lC SINGLE ZONE [] MU LTl P ~..ZON E ~,x].~ 9. Unit or lease name Kuparuk River 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 49' FSL, 786' FEL, Sec.16, T12N, R9E, UM (Approx.) At top of proposed producing interval 1447' FSL, 1303' FEL, Sec.21, T12N, R9E, UN At total depth 1030' FSL, 1358' FEL, Sec.21, T12N, RgE, UN 10. Well number 3B-13 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0i l Pool RKB 85', PAD 55' ADL 25633 ALK 2566 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line I 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 49' ~ surface Sinclair Ugnu #1 well 3976' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 18. Approximate spud date 8011' MD, 6284' TVD feet 2560 I 03/06/85 19. If deviated (see 20 AAC 25.050) I2o. Anticipated pressures 2765 psig@ RO°F Surface KICK OFF POINT 1200 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 3165 psig@ Rlb.~, ft. TD (TVD) 21 SIZE Hole Casing 24" I 16" 12-1/4"/ 9-5/8" ~-1/2" / 7" 22. Describe proposed Weight 62.5# 36. O# CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW 26. O# program: Proposed Casing, Liner and Cementing Program SETTING DEPTH 3632' Length MD TOP 80' 29' I 29' I 29' 7983' 29' 28' I 28' TVD MD BOTTOM TVD 1091 109' 3661'I 3226' I 8011'1 6284' I QUANTITY OF CEMENT (include stage data) ± 200 cf 900 sx AS III & 500 sx Class G 260 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8011' MD (6284' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3661' MD(3226' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2765 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby cert/j.~at the foregoing is true and correct to the best of my knowledge ?? SIGNED / / ~'~.~'.Z~'.,.,:~"~-~-.~] TITLE Area Drilling Engineer The space f~-~~n use CONDITIONS OF APPROVAL DATE Samples required I~YES [~NO Permit number APPROVED BY Mud log required I-]YES J~]NO Directional Survey required APl number .,[~LY E S I-]NO 50- Approval date .0,2 / / Form 10~,01 (~M) PD/PD34~ [ - ~ z Submit in triplicate. SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 19, 1985 by order of the Commission PERMIT TO DRILL 3B-13 installed and tested upon completion of the job. 3B-13 will be 3976' away from Sinclair Ugnu #1 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6420'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. _. i-'- · ' , : ' ' ' ~ ; : ' ' ' ' -~ -; ' ~ ' i ! ~ ; ' ; ~ ~~ ~ ' i : ' ~ ' ' ~ .... ....... ~ .... : ! ............. ; ........ 'ARCO ALASKAFTtNC;;~ t ~:. ~ : -,-.~ .-~ ....... ,..I--~ .... ~---~ ............ ~ .......... ~ ..... ,_: .... ;..; ._ .... ', ........ ; ..... : ' PAD ~Bi'.'~ELL-:N -1 ~ PROPOSED KUPARUK FIELD.~ORTH~SLOPE,-ALAS~A ........ L;--.: :_~_~..~r:~._:..~._~,-~ ..... ; .... ~.~-~}- ' '~ -~- '" ' ~ ..... -.~ .... ~ .... :'~'~"-:':'i ........... ~-= ......... 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I ............. ~ ......... t ........... · .......... ~ ...... : ................ = .............. 4 .......... ~ ....... ................... ; ................... ~ ....... i .......... F..~TttAN I, fl,IIPSTOC¢.,, lllC. - AI~O ALASKA. INC. PAD 3B. WELL NO, 13 ,ROPOSED KUPARUK F'ZN'-]_D_,L. NORTH. SLOPE: .ALASKA · TVD=1200 THD=1200 DEP-O E~UILD 3 DEe PER 100 FT -BASE''PERHAFROST TVD=1616 THD-1619 DEP=46 ' --~--TI~F-~ ~.-SNDS--- TYD-2026 TI'ID-2054,- DEP"I 8~ '-~-4si"EOC- TVD-2559 TPID-2711 DEP-$68 - - ~,' TOP ~/ SAK SNDS TVD-2721 THD-2943 DEP-7:~2 ~ PT TVD-3226 '1'1'1D"'3661 DEP"1243 · ' ':: ,' '"x. AVERAGE ANOLE £O 2O ~IN ' : .~..~T, OP UPPR SNDS TVD 5868 Tt'ID-.?420 DEP 39t7 _ ........ ",,'~'TARC, ET.,,, CI~ITR TVD-5994 TI'ID~.-TSG9 - '- .,,'-TOP LOI. IR SNDS TVD-6017 THD-?632 DEP,4068 ' . ' . · \ BASE KUP SNDS TVD-6143 TI"tD-7811 DEtP'-'4195 .. . TD (LOG PT) TVD-6284 TI"ID-8011 DEP-4337' ............ : i ~ , O 1000 2000 3000 ............................. VERTICAL SECTIOfl ,, I I 4000 5000 Alaska Oii& Gas Cons. Co[~i~rfisstori Anchorage Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3, 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" si de outlets, 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. im 3 Maintenance & Operation Upon initial installation close annular preventer and verify l~hat ball valves have opened properly. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line.. Do not shut in well under an)/ circumstances. 16" Conductor < < 7 5 4 3 2 ~'-' DIAGRAM #1 !~-5/8' ;. JO PSI RSERA BOP STACK I. 16' - 2000 PSI T.a{~l<~ ST.a~rrI~ 2. I!' - 3000 PSI CASIN~ 3,. Il' - 3000 PSI X 1~-5/8'-- 5000 PSI 5PACIS~ SPCCL 4. 15--5/8" - ~ PSI PlPl~ 5, l~-5/8" - 5C00 PSI DRILLIN$ SPO~L W/~ KILL LIliES 6, 13-5/8" - ~ PSI DOLBLE R~t'W/PIPE RAMS ON TOP, 7. 13--5/8". - 5000 PSI AN',,IJL~ , ,> A(XZMJLATC~ CAPACITY TEST I. Q-ECK ~D FILL ACC1.M.I_ATOR RESERVOIR TO PR(PER LEVEL WITH ~IC ~UI~ ., ,' 2. ~ T~T AC~AT~ ~ 1S ~ ~I ~TH I~ ~I ~T~ ~ T~ ~~T~., 3. ~~ TI~ T~ ~ ~ ~TS SIXThlY ~ ~%S ~ ~D ~TH ~I~ ~ ~. 4. ~~ ~ ~ ~T. T~ ~~ L~ LI~T IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 15--5/8' BOP STACK TEST FILL BO:> STACK AND ~ M~NIFOLD WITH ARCTIC DIESEL. (:3-ECl<: THAT ALL LOCK ~ SCRE~ IN NE:LLFEAD ARE FLLLY RETRACTED. SEAT TEST PLUG IN V~:LL~_AD WITH RUNNING JT AND ~ IN L~ 5. CLOSE ~ PREVE~ ~ MANJAL KILL Ai~ LII~ VALVES ADJACENT TO B(~ STACK. ALL OTt-~ VALVES AI~ CHOKES SHOLLD BE OPEN. 4, PRESSLI~ UP ]'0 250 PSI AI~ HOLD FOR I0 MZN. IN- CREA~ PRESSLRE TO 3000 PSI AI~ HOLD FOE I0 MIN. ElEED PRE~ TO 0 PSI. 5, OPEN ~AR PREVE~ AI~ ~ KZLL ~ CHO~ LI~E VALVES. CLOSE TOP PIPE P. AI~B AAD HCR VALVES ON KILL ~ ~ LIN~, 6. TEST TO 250 PSI Arid 3000 PS! AS IN STEP 4. ?. CO~IN.,E TEST!NS ALL VALVES. LII~:~ ~ WITH A 250 PSI LOW ~ 3000 PSI HI(~i. TEST AS IN STEP 4, DD I~I3T P~~ TEST ANY C'H(3~ THAT, I~ NOT A FULL CLOSING POS]T]VE SEAL ~T CN_Y FI~TION IESI Q-ii, ES THAI DID NOl FULLY CLOSE. 8. ~ TOP PIPE RAM!i AND CLCI~ BO'rfOM PIPE RAMS. TEST BOTTC~ PIPE RAIvIS TO 250 PSI ~ 3000 PSI. 9. CPEN BOTTOM PIPE RAk~ BACK (l,ff I:~UI~NG Jl AMi) PLLL OUT CF HOLE. I0. CL__OSF'_ BLINO ~ ~ TEST TO 250 PSI AI~ 3000 PSI. Ii. CPEN BLINO RAMS ~ RETRIEVE TEST ~ ~ M~FOLD AI~ LIltS ARE FI.I_L OF' ~EZING FLUID. SET ALL VALVES IN DRILLING POSITII3~L 12. TEST STAI~PlpE VALVE..~ KI~I yo KELLY COCX~ DRILL PIPE SAF'ETY VALVE° ~ INSIDE BOP TO 250 PSI 3000 PSI. 13, RECOR9 TEST II~TICIN ~ BLCIfOJT PRE~ER TEST FORM, SIGN, AND SI[NO TO DRILLINS SLPERVISOR. 14. PEI:~'O~ ~TE BCPE TEST AFTER NIPPLINS UP Y/[EKL.¥ THiS~AFTER FLI~TI~LY OPEI:~TE ~ EIAILY. REV I CHECK LIST FOR NEW WELL PgRMITS ITEM (1) Fee (2) Loc APPROVE DATE / r [~thr~ 8) 3. 4. 5. 6. Admin '~ ~IY~ 9. (3) lo. (10 and 19) / 12' (5) BOPE// (22 thr~ (6) Add: Company YES Is the permit fee attached ........................................ Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells ........... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator, the only affected party ................................ .__~ Can permit be approved before ten-day wait ......... Lease & Well No. NO Does operator have a bond in force is a conservation order, needed .............. ~.~'''~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cement cover all known productive horizons ..................... ~]~ 17. Will surface casing protect fresh water zones ....................... .~_., 18. Will all casing give adequate safety in collapse, tension and.burst. 19. Is .this well to be kicked off from an existing wellbore . 20. Is old wellbore abandonment procedure included on 10-403 ............ 21. Is adequate wellbore separation proposed ............................ 22. Is a diverter system required ......................... an~ ~OP ' ~''? ..... ~ 23. Are necessary diagrams of diverter equipment attac . . . 2~. Does BOPE have sufficient pressure rating - Test to ~-~Z~ psig .. ~ 25. Does the choke manifold comply w/API ILP-53 (Feb.78) .................. 26. Is the presence of H2S gas probable ................................. 27. Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engineerin~: LCS rev: 10129184 6. C~T pOOL INITIAL CLASS STATUS GEO. UNIT AREA NO. ON/OFF SHORE 0g 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. , '~E}~IFICATIGN [.~ISTI MG VP oiO.H'O~ VERIR,iCA~'IO,~ L~S?~t4G PA~E I UNIT TYPE CATE SiZE COOE OOO 000 016 065 000 000 006 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 01.2 065 000 000 006 065 000 000 003 065 UNIT TYOE CATE SIZE CODE 000 000 001 065 :VP Ola,!qO'~? v!~?.lI:'iCA~i~}i.i L'TSTING PAGE 2 ****************************************************************************************** O~P~.~Y = ATh~:TIC RICHFIELD T~T~ = ALA~F~ I $ C 0 5 T 'i.' ? 9,09.5" ia 3657' - ii~,IY SIZ~ = 8.5" ×C-PAC. 9,5 R~C 6,2 C~ R~ ~T BHT = ~.,890 ~ 66,0 DF = 2,490 ~ 66,0 DF = 3,170 ~ 666,0 DF = ~.,387 ~ 1,45,0 DF' VP OiO.H02 VEPlFICATIni',~ LiISTiNG SIZE PEPR COD~ ENTRY 1 66 0 4 65 , I ~N I 66 0 'EPT F T 00 000 O 0 0 0 ~ ,FLU nlr~ Oh~M O0 220 O1 0 0 4 b ~ r> i L 0 ~ t~ ~,'~00 12 o 46 O 0 4 b~ OIL c~ k~ ?~ ~ O0 ~20 64 0 0 4 ;P ~ I L ~ V 00 010 01 0 0 4 ]R r'Ir, ~API O0 310 O1 0 0 4 ',R ~;'b~f GAPi O0 ~I0 Ol C 0 ~ ~ g L I m D ¥ ~ ~,~ 00 280 01 0 0 4 ~HOB FOr? q/C3 0() 350 02 0 0 4 ~R~O ? o r,~' GiC3 O0 356 Ol 0 0 4 ~RAT ? f>~"~ O0 4:20 Ol 0 0 4 ~N P .A ? p*.; 00 000 00 0 0 4 ! p H t P 0 r,~ P 'U 00 ~ 90. O 0 0 0 4 !Cf,~L ~ ~.,~*: ~PS O0 330 31 0 0 4 'C~,~b = ~.,:: ~,~ ~PS O0 330 30 0 0 4 PROCESS CODE ¢OCTA~) i 68 00000000000000 i 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 i 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 2,42@0 '83,7227 CALl 3.5042 '377'6094 )grot 8¢](')o POrtO SFf,U 5 7898 'fLn.. 4,7978 ILl~ ;p -27:a951 q~ -;'{~:7277 GR -83.7227 CALl ~i~b 9 n2~'/ n~,](.:~ o,ng?~ r,R..T 3,5042 RNRA .~PH1 4fi.99r~4 ~tC ~".' [, -1439.31~5 ~CNi, -377.6094 ?.5842 99.9023 CaLl , 3,6194 RNRA 493,1406 3.7834 8,5020 3.80.8 4.3835 6 3679 3~8088 ?,7463 9.4238 3.7874 I ~40 ii:!, ?.' -~ 3 ~:~ iL g R -23,a95,~ GF: .t ! 2598 T6P 78'33Q8 0 , 00'63 26 ,t '~ , 5000 'F C ~.~1..., I2!,902,.~ GR Oo ! 108 ~-~R~ T I 7t')3,6t475 FC.~t b 2,7991 0.0640 1903.6875 ~'C~I~ 15~.0625 i~05.6a75 PCMI.~ 3.5764 !bP 171.6875 2004~637~ 15~.6875 dR 0,0127 ~'R~T 20~3.5000 PC~gh 2 42q9 ~3~'1895 GR o. 05 ~ b ~.~R~u.' 2.~ 87.500o 6.21l"I TLP 9.3379 7g,3308 2.9104 847.8125 2,5999 ~09,5273 3.3245 572.81.25 9,5254 81.7773 ~.867~ 876,3125 2.041:3 95,21.48 3,6526 445,3906 2,17~0 12].9023 3,8284 ~16,3906 2.6643 !43.3125 3.4475 528.8i25 2,4202 1.5n,0625 4,02el 451,3906 3.3909 171.6875 3.3342 559.8125 3.83~i 155.6875 ~,5667 502.1~06 ?,96J1 135.18 5 3.3010 &0~.3125 103.33o8 CALl CASi CALl CALI CALl RNPA C A L I RNRA Ib~4 C A I.., I r~NRA PNRA CALl CALl ,5020 072~ 2,7405 9,2441 3,6b06 8,884:8 9,0176. 3,18!9 2,3245 9,5801 4,0710 2.213 :i 4'2351 2.7151 9,79~8 3.5999 2,5803 9,3457 4,0007 3.3831 i0,2520 3.5803 3.8440 10.4551 4,1062 2.9905 10.7363 3.61~4 4.9500 10,79R8 3,5120 ) E P T 6 J 00. n 0 a (,) S ¢ !', U ;p -6~.972"i 2353,5000 5.34a4 !I,D ~ 29,56?5 (;R 24.77.5009 ¢CNL ~,21~2 110.0308 2337. 5000 P.S627 TLD 246!.S000 FCNt, 5,778~ 76,5273 GR 0,00~3 ~RhT 3.8577 !bP ~02:~ GR ~,0195 ~RAT 261.!.5000 WENt.: 2,734~ ILD 83.5273 dR !07,4023 0,0864 2205.5000 2,7971 1t0.5273 4.76~5 129,5625 2,8850 770,R125 2,0686 109,6523 ~.9573 671,3125 2.3596 ~' 31. 2.5 2.7874 !0~.0273 73!.,8125 37!8 7 5273 79.':9417 85 31~5 3,6682 71.9023 798,3125 5,1.687 71,,1523 2'5784 896,3125 2.791.3 ~3,5273 3.1174 607,8125 2,4631 102.4023 3,~358 590.31~5 2,64a7 11~.6523 3,30~8 641.3125 ],0647 110.5273 ~,¢ A C ,A I..., I RNRA IR~ RN~A CALl CALl RNRA RNRA I bM CALl RNRA CALl RNRA CALl RNRA 4,7273 10,5488 2.1i35 :10.0098 3,3225 2.3401 9~7207 3.2795 2,7502 8,7207 ~,3616 4. 086'7 _~,8379 ,213i 3,7131 1.0,4629 3,2698 5,0710 10,2910 2,8206 2.7131 0 8613 2,4338 8.6895 3.7346 2.6116 9.6270 3.4729 3.0667 11,5410 )gP'i 4:gi)fi. r)oo9 SFt, LJ k~pPl! 3~'0i6.0 ~,, C .~.~ 'b 0.03R6 96.7 i 4 g 206 !, 5 00 <.' ~' C :-! L, 2. 8889 t06.5273 0.0278 ~.'.. R A 1" 236.!1 '5000 2! 93,5000 PCNb 96,0023 OR 2381,5000 FC~L 3. 289:3 1:].! .7i. 48 2367,5000 3,3928 ! 09.0'273 23'73,5000 9!.5273 0.0073 3.~299 104.0273 0,0024 3.3772 Ibm 103.9398 OR -0 00~9 xRAT 3.20t4 625.3125 2,5256 96'7i48 ~.791.3 5!9.8i25 3.1.467 I06,5273 3.3'!3.3 677.3125 3,5452 J03.0~98 3,4026 57!.3i25 3.6487 96,9023 2,7092 762.8125 1.03,5898 3.2834 648'3125 3,3596 !11.7148 3,5374 587,3125 3.7659 10Q.0273 3.3342 672.8125 4.0437 91.5273 3,!819 642.3125 3.7!51 !04,0273 3.4~g5 672.8125 !03.~398 3.3948 672.8125 RNRA Ib~ RN~A RNRA CALX CALl Ibm CALl CALl ~NRA CALf CA[,I RN~A CALl PNRA CAbI 3.3694 2.5022 10,8770 3.0901 10.6973 3,4846 3,5002 11,4238 3,838! 3.7092 1~.5488 ...12t3 2,8733 1!,0176 3,5'106 3,2~9 4. 281 3.6721 1~,93~6 ...5256 3,93J9 10,3691 3,e2~4 3.7834 10,7988 3,3069 3.5725 10.8848 3.35q6 .. ;, .. (',, ..... 3 ~.5~3 O~r:,-? ,..~F, On.no 9 SFT, d 3,~344 Tbm 4 ~593 IL,~ .... P -2f~.~539 EPT 4400, E P T 4:300. O 0 4200 oOnG 4t. 3574 40.2832 ;p 3~,86~3 ~ H 0 B 2 ' 27 t 7 ;p 37' 48~3 ; P - '4 O, 4P~'~ i 4! .&645 ;p -! 1. n.P22 / 5273 CR 3. 8694 94,5273 Ga -o. 0049 ~R~T 2!.61,5000 3. 5667 J 0 l. 0898 O, 002 9 ~ k .~ T 2157 5¢"00 ~,02,!523 0,0 142 ~,~ R ~, T 2! .45,5000 2.7346 TLP 2277,5000 FC~lb ~ 0901 3 875 2 ~ lO 5273 2042 6875 4.6609 88 '09337 202~.6875 3,4260 94.7773 GR -0 0010 1995~6875 4.73g0 75.~39~3 CR 0,0161 NR~T 1~'1!.6875 13~7.6a75 Fi:FL !06.5273 3.3557 4.2'781 94,5273 3,0803 625.9125 4,7429 ~01,0898 3.2756 549.3125 4.442~ !02,~52 3,6545 522.3125 3.3030 93.9648 3,58~1 593,3t25 3 258!, 2.1t. 71.48 3 5256 560 81.25 4 2742 !10 5273 3 3694 599 8125 5,1765 88,9648 3.6448 5753125 3,4:417 94.7773 3.9182 45&'1406 5.4578 75.83q8 3 5569 444~3906 i7,3643 4,0671 343,7406 CALl RNRA IbM CALl PNRA CALl RNRA CAI., CALl PNRA CAbi Ib~ (:AL1 PNRA CALl RNRA CALl RNRA IL~ CAI, I PNPA CALl 10,8q57 3,8049 4.1140 10,g551 4,0164 10,9004 3,9338 4.153i 11,0332 4.1062 3.1174 I0,9863 3,8381 3,0276 10,8770 3.8987 4,1062 I1. 785 3,4045 4.88~5 1,02 4 13,51.78 3.3401 li.3379 4,3757 5,0242 lO.61QI 4,4343 2OO0 6875 8: v7o 4,0437 ;E~ V!CF: ~'~/~ ~'.~ K ;El)TI' )ATE ]EEL NAr~,'P :!.42664 15.002o IbM 76.1523 CALl 4.0750 ~NRA 311.8906 2000.6875 8 · 8'170 4. 4460