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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 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' 5HJJ-DPHV% 2*& )URP :DUG'XVW\. 'XVW\:DUG#FRQRFRSKLOOLSVFRP! 6HQW :HGQHVGD\)HEUXDU\ $0 7R '2$$2*&&3UXGKRH%D\ /RHSS9LFWRULD7 2*& &F 6HQGHQ57\OHU 16.5:2&0 :DUG'XVW\. &RQQHOO\-HII 6XEMHFW 1RWLILFDWLRQRI%23XVHRQ1DERUV(6RQ $WWDFKPHQWV *%23(/HWWHUBBGRF sŝĐƚŽƌŝĂĂŶĚƚŽǁŚŽŵŝƚŵĂLJĐŽŶĐĞƌŶ͕ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚĚŽĐƵŵĞŶƚŝŶƌĞƐƉŽŶƐĞƚŽƵůůĞƚŝŶϭϬͲϬϬϯŝŶŽƌĚĞƌƚŽĚŽĐƵŵĞŶƚƚŚĞƵƐĞŽĨKWĞƋƵŝƉŵĞŶƚŽŶϯ'ͲϬϮ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͘'ŽŽĚĚĂLJ͘ ƵƐƚLJtĂƌĚ ^ĞŶŝŽƌtĞůůƐ ŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH -%5 .58* 37' .58* 37' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Feb 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:2/8/2022 at 10:15 hours Well Location: 3G-02 API Number: 50-103-20146-00-00 PTD Number: 190-137 Rig Name: Nabors 7ES Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503-476-2519. Dusty.Ward@conocophillips.com Operations Summary: Approximately 02:00 on 2/8/2022, the completion was being ran in hole. About at the old perf depths of ~6308’ fill was encounter. The sand/fill was circulated out of well using a high viscous pill. Upon performing a surface to surface circulation to keep working pipe down to final depth and remove fill, a flow check was perform. The well continued to flow a little after 30 minutes and our mud had appeared to lighten to a 12.2+, which was down a bit from the 12.3+ heavy that was in the well. At approximately 10:15 on 2/8/2022, the upper pipe ram was shut-in to confirm it wasn’t ballooning. No pressure was really observed or continued to build, but the well continued to flow through the ballooning checks. BOPE Used: Upper Pipe Ram Reason for BOPE Use: A flow check was being performed after pumping a high viscous pill around near the perfs to clean sand/debris away in order for completion to get fully on depth.Our KWF had lightened up a bit in the high viscous circulations. Actions To Be Taken: KWF will be re-conditioned to a 12.3+ and circulated in the well. A 30 minute no-flow test will be performed. The completion will then be correlated to depth with Eline and the tubing hanger will be landed. Since the completion is being landed out, the BPV will be installed and tested, then the BOPE will be ND and tree will be NU and tested. Then circulating of CI brine and setting the packer will commence. BOPE will be moved with rig to the next well and tested once rigged up for the next wells scope. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells 9 9 9 9 9 -%5 ,pp p p well continued to flow through the ballooning checks. ! " # " $ % $ &' ( )*! + ($ ,- !. /"! ! 0- ,- 12 132+. 2 4 , . " ( $ ))305 !4 )265 !4 & $ )71)5 31015830715 3/2/5 6/0358363+5 9 : , ;88 .7#41< -#/2 )7+/59$ 3/365:$ = :, (8 . 310159$ 307159$ !4 6/035:$ 363+5:$ !4 1 >; ( * , . !4 7 > 3" = $ ( " &' ( $ - ( )" = ? "$- & $ ? ?*!@ % -%? (! !4 &' ! & ; ))7+5+< !4 +05 721)5 * )< 0#34/< - ))215 35 10+75 )2/35 &-A -A*-!$? !& :*! 99**! ! " #$ % 3 $ ! 1 ! ! 6" B " = "!!# &'( )'* +),-%&'( )'* +),.., =8* B '227)2 8A0032 7 & / " @ = 0') .,, ( 3+01#3/283/0#3/365 = $ ( * C $ ,, ,,' 6 ,> 12 132+28132+8D131/7. ? #9 1 35 72)5 2 = -BB=9' E= = !A9 #=- = : ! " ! & ? & ;! $ $ "*!@"? " #B #B +*( ( (= $ (" ( F ,02+.1)3#)37 " = & )72/#)71/58)770#)7+/5 2#626 24121 " 72( By Meredith Guhl at 2:13 pm, Mar 09, 2022 DSR-3/10/22 RBDMS SJC 031122 Page 1/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2022 01:30 1/28/2022 11:00 9.50 MIRU, MOVE MOB P Rig down. Pull pits away from sub. Pull sub off of well. Load office, shop and pit. L/D derrick. Transport T/3G .. 0.0 0.0 1/28/2022 11:00 1/29/2022 00:00 13.00 MIRU, MOVE MOB P Mob from 1L-29 to 3G-02 0.0 0.0 1/29/2022 00:00 1/29/2022 04:00 4.00 MIRU, MOVE MOB P Pull Pits Shop and office off of 1L-29 to 3G-02 Clean up around 1L-29 0.0 0.0 1/29/2022 04:00 1/29/2022 07:00 3.00 MIRU, MOVE MOB P Stage pits on location. Set office and shop. Clean up around well and pad 0.0 0.0 1/29/2022 07:00 1/29/2022 18:00 11.00 MIRU, MOVE MOB P Mob from 1L-29 to 3G-02 0.0 0.0 1/29/2022 18:00 1/29/2022 21:00 3.00 MIRU, MOVE MOB P Spot Sub 0.0 0.0 1/29/2022 21:00 1/30/2022 00:00 3.00 MIRU, MOVE MOB P M/U junk pipe storage area. R/U up Tiger Tank and hard line. Move mud shack and smoke shack into position. Spot cuttings tank. 0.0 0.0 1/30/2022 00:00 1/30/2022 04:00 4.00 MIRU, MOVE RURD P PJSM. Review Derrick Checklist. Raise Derrick and Pin same 0.0 0.0 1/30/2022 04:00 1/30/2022 09:00 5.00 MIRU, MOVE RURD P PJSM. RU Cattle Chute and Bridle down blocks.RIg up rig floor 0.0 0.0 1/30/2022 09:00 1/30/2022 11:00 2.00 MIRU, MOVE RURD P Rig up to the tree and secondary kill for well kill operation, take 9.6ppg. kill weight fluid on in pits 0.0 0.0 1/30/2022 11:00 1/30/2022 12:00 1.00 MIRU, MOVE SFTY P Pre Spud meeting. 0.0 0.0 1/30/2022 12:00 1/30/2022 13:00 1.00 MIRU, MOVE PRTS P Test Tiger Tank lines to 2000 psi. 0.0 0.0 1/30/2022 13:00 1/30/2022 17:00 4.00 MIRU, WELCTL KLWL P Kill well with 444 bbl. 9.6 ppg. Shut in well after 9.6ppg. all the way around. SITP & SICP = 700 psi. attempted to bleed pressure off ( No Go) pressure came back to 700 psi. 0.0 0.0 1/30/2022 17:00 1/31/2022 00:00 7.00 MIRU, WELCTL KLWL P Weight up from 9.6ppg. to 11.9 ppg NaCl NaBr. Load pipe shed with drill pipe. While waiting for trucks from the mud plant. 0.0 0.0 1/31/2022 00:00 1/31/2022 03:30 3.50 MIRU, WELCTL KLWL P Continue Weight up from 9.6ppg. to 11.9 ppg NaCl NaBr. Load pipe shed with drill pipe. While waiting for trucks from the mud plant. 0.0 0.0 1/31/2022 03:30 1/31/2022 08:45 5.25 MIRU, WELCTL KLWL P Kill well with 250 bbl. 11.9 ppg. @2bpm 11.9# NaBr circ'd SxS. Shut in well. Tbg=65 PSI, IA=90 PSI 0.0 0.0 1/31/2022 08:45 1/31/2022 09:00 0.25 MIRU, WELCTL OWFF P Monitor well for 15 minutes pressure increased 7:45 TBG=83 PSI IA=100 PSI 7:47 TBG=95 PSI IA=110 PSI 7:49 TBG=103 PSI IA=120 PSI 7:51 TBG=106 PSI IA=123 PSI 7:53 TBG=109 PSI IA=126 PSI 8:09 TBG=100 PSI IA=125 PSI 9:00 TBG=100 PSI IA=125 PSI 0.0 0.0 1/31/2022 09:00 1/31/2022 10:30 1.50 MIRU, WELCTL RURD P Blow down surface lines. RU to bleed of TBG taking returns to the pits. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 2/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/31/2022 10:30 1/31/2022 11:45 1.25 MIRU, WELCTL OWFF P Start timed bleeds. Bled TBG for 5 Min. Initial Tbg=60 PSI IA=50 PSI 1: Bled for 5 Minutes, Shut in Tbg=50 PSI IA=30 PSI Monitored for build up. 5 minutes Tbg=70 IA=60 10 minutes tbg=70 IA=60 2:Bled for 5 min. shut in Tbg=60 IA=20 5 minutes Tbg=70 IA=50 10 minutes Tbg=80 IA 60 Bled for 5 minutes shut in, Tbg=40 IA=10 5 minutes Tbg=100 IA=50 10 minutes Tbg=100 IA=60 0.0 0.0 1/31/2022 11:45 1/31/2022 18:45 7.00 MIRU, WELCTL RURD P Load and strap DP in pipe shed, Load pits with 11.9# brine built 12.3# NaBr for well kill. 0.0 0.0 1/31/2022 18:45 1/31/2022 22:30 3.75 MIRU, WELCTL KLWL P Kill well with 352 bbl. 12.3 ppg. @2bpm 12.3# NaBr circ'd SxS. Shut in well. Tbg=0 psi., IA=0 psi. 0.0 0.0 1/31/2022 22:30 1/31/2022 23:00 0.50 MIRU, WELCTL OWFF P Monitor well (Static) 0.0 0.0 1/31/2022 23:00 2/1/2022 00:00 1.00 MIRU, WELCTL RURD P Rig down/ Blow Down well kill equipment 0.0 0.0 2/1/2022 00:00 2/1/2022 01:00 1.00 MIRU, WELCTL MPSP P Install BPV and Test to 1000 psi. 0.0 0.0 2/1/2022 01:00 2/1/2022 03:00 2.00 MIRU, WHDBOP NUND P N/D Tree and adaptor 0.0 0.0 2/1/2022 03:00 2/1/2022 12:00 9.00 MIRU, WHDBOP NUND P N/U DSA and BOP, Center stack. Take RKB measurements. Install flow nipple. Grease choke manifold and mud cross. Re check torque on ram doors. 0.0 0.0 2/1/2022 12:00 2/1/2022 20:45 8.75 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's w/ 2 7/8 test joint. TestUVBR''s and LVBR's w/ 3 1/2"test joints. Test blinds rams. Choke valves #1 to #13 & #15 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 3 1/2" EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test one ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1450 PSI, 200 PSI attained =18 sec, full recovery attained =110 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= 33 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1960 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Matthew Herrera. 0.0 0.0 2/1/2022 20:45 2/1/2022 21:00 0.25 MIRU, WHDBOP BOPE T CMV #14, and one ea 2 1/6" auxiliary gate valves below LPR. failed initial test. Valves were greased and functioned and passed retest. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 3/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/1/2022 21:00 2/1/2022 23:15 2.25 COMPZN, WELLPR RURD P Evacuate fresh water from stack, choke and gas buster. R/D testing equipment and test joints. 0.0 0.0 2/1/2022 23:15 2/1/2022 23:30 0.25 COMPZN, WELLPR MPSP P Pull tree test plug and BPV with dry rod. 0.0 0.0 2/1/2022 23:30 2/1/2022 23:45 0.25 COMPZN, WELLPR RURD P M/U landing joint and XO's. M/U to TD. Set down 10K. Mark pipe at RF. BOLDS. 0.0 0.0 2/1/2022 23:45 2/2/2022 00:00 0.25 COMPZN, WELLPR PULL P P/U on completion string. Hanger came off seat @ 60K. PUW=55K 4,625.0 4,625.0 2/2/2022 00:00 2/2/2022 00:45 0.75 COMPZN, WELLPR CIRC P Circ BU @ 5 BPM, 1000 PSI. B/D TD. 4,625.0 4,625.0 2/2/2022 00:45 2/2/2022 02:00 1.25 COMPZN, WELLPR PULL P Pull hanger T/ RF. L/D landing joint and hanger. Hook up SS control line T/ spooling unit. L/D 1 joint of 3 1/2" completion and XO joint T/ 2 7/8" completion. 4,615.0 4,545.0 2/2/2022 02:00 2/2/2022 02:30 0.50 COMPZN, WELLPR RURD P L/D 3 1/2" handling equipment. M/U 2 7/8" handling equipment. 4,545.0 4,545.0 2/2/2022 02:30 2/2/2022 06:00 3.50 COMPZN, WELLPR PULL P L/D 2 7/8" completion string F/ 4545' T/ 2804'. PUW=55K. Recovered a total of 30 of 31 SS bands from control wire. 4,545.0 2,804.0 2/2/2022 06:00 2/2/2022 06:30 0.50 COMPZN, WELLPR RURD P R/D spooling unit and remove from rig floor. 2,804.0 2,804.0 2/2/2022 06:30 2/2/2022 10:00 3.50 COMPZN, WELLPR PULL P Continue POOH F/2804' T/surface. Joint 146 recovered from well sting separated at top of joint 147. 2,804.0 0.0 2/2/2022 10:00 2/2/2022 10:30 0.50 COMPZN, WELLPR PULL P Called town to discuss options for retrieving the rest of the string. 0.0 0.0 2/2/2022 10:30 2/2/2022 11:30 1.00 COMPZN, WELLPR CLEN P Clean and clear rig floor. 0.0 0.0 2/2/2022 11:30 2/2/2022 15:00 3.50 COMPZN, WELLPR PULD P Pick up DP and build stands. Built 30 stands Baker equipment on location to go fishing. 0.0 0.0 2/2/2022 15:00 2/2/2022 16:00 1.00 COMPZN, WELLPR RURD P Load Baker Fishing BHA into pipe shed. T-dog overshot 2.75 'x 5.875" OD, Wash pipe extension 5.88' x 5.75", Drive-sub 1.78' x 5.75", Bumper-sub, 7.9' x 4.75", Up-Jars13.22' x 4.75", 3ea 4.75" DC, 31.25, 30.32, 30.01, Accelerator, 11.03' x 4.75" X-O 1.55' x 4.75" DP 0.0 0.0 2/2/2022 16:00 2/2/2022 17:15 1.25 COMPZN, WELLPR BHAH P Make up BHA #1 T-Dog Overshot OAL=135.69' 0.0 135.0 2/2/2022 17:15 2/2/2022 23:00 5.75 COMPZN, WELLPR PULD P RIH w/ BHA #1 P/U DP. Mechanical trouble with iron roughneck @ 2515'. Used rig tongs T/ M/U DP for remaining trip in hole T/ 3820' Repair made on iron roughneck. 135.0 3,820.0 2/2/2022 23:00 2/2/2022 23:45 0.75 COMPZN, WELLPR TRIP P RIH w/ BHA #1 on stands out of derrick F/ 3820' T/ 4581'. PUW=98K, SOW=88K 3,820.0 4,581.0 2/2/2022 23:45 2/3/2022 00:00 0.25 COMPZN, WELLPR FISH P M/U TD. SO tag fish top @ 4625' swallowed T/ 4633' set down 25K string weight. P/U gained 2K PUW. Repeat 2 more times. PUW=100K. 4,581.0 4,633.0 2/3/2022 00:00 2/3/2022 03:00 3.00 COMPZN, WELLPR TRIP P TOOH F/4633' T/135' 4,633.0 135.0 2/3/2022 03:00 2/3/2022 03:15 0.25 COMPZN, WELLPR OWFF P OWFF for 15 min. 135.0 135.0 2/3/2022 03:15 2/3/2022 04:30 1.25 COMPZN, WELLPR BHAH P L/D BHA#1 recovered collar from joint 147. 135.7 0.0 2/3/2022 04:30 2/3/2022 05:00 0.50 COMPZN, WELLPR SVRG P Service top drive 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 4/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/3/2022 05:00 2/3/2022 06:30 1.50 COMPZN, WELLPR BHAH P MU BHA #2 OAL=128.69' 0.0 128.7 2/3/2022 06:30 2/3/2022 08:30 2.00 COMPZN, WELLPR TRIP P TIH F/128.69' T/4625' PUW=98K SOW=66K 4,625.0 4,625.0 2/3/2022 08:30 2/3/2022 10:00 1.50 COMPZN, WELLPR FISH P Set down 30K engage fish cock and bleed jars, pulled 125K 3 Times fired jars straight pull to 125K. pulled 125K straight pulled to 172K pipe pulled free. PUW=112K. 4,625.0 4,625.0 2/3/2022 10:00 2/3/2022 12:30 2.50 COMPZN, WELLPR TRIP P TOOH F/4625' T/128.69' with fish. 4,625.0 128.7 2/3/2022 12:30 2/3/2022 13:00 0.50 COMPZN, WELLPR BHAH P LD BHA #2. 128.0 0.0 2/3/2022 13:00 2/3/2022 17:00 4.00 COMPZN, WELLPR PULL P L/D 2 7/8" completion, 48 joints, 3 GLM's & OEJ seal barrel. Heavy corrosion on collars of 2 7/8". 1,524.0 0.0 2/3/2022 17:00 2/3/2022 17:30 0.50 COMPZN, WELLPR RURD P R/D 2 7/8" tubing equipment. 0.0 0.0 2/3/2022 17:30 2/3/2022 19:30 2.00 COMPZN, WELLPR BHAH P M/U BHA #3 Clean out assembly. 6.125" junk mill, 7" casing scrapper, boot baskets X2, 6.125" string mill, bumper sub and jars T/ 45' 0.0 45.0 2/3/2022 19:30 2/3/2022 23:45 4.25 COMPZN, WELLPR TRIP P RIH on DP w/ BHA #3 F/ 45' T/ 6135', Set down 5K. No drag seen on trip in hole. PUW=126K, SOW=100K 45.0 6,135.0 2/3/2022 23:45 2/4/2022 00:00 0.25 COMPZN, WELLPR CIRC P P/U 10'. Pump 25 Bbls 80 vis pill @ 3 BPM, 600 PSI 6,135.0 6,125.0 2/4/2022 00:00 2/4/2022 00:45 0.75 COMPZN, WELLPR CIRC P Circ STS. No increase in cuttings seen at shakers when sweep returned. B/D TD. 6,125.0 6,125.0 2/4/2022 00:45 2/4/2022 01:00 0.25 COMPZN, WELLPR OWFF P OWFF - No flow 6,125.0 6,125.0 2/4/2022 01:00 2/4/2022 01:30 0.50 COMPZN, WELLPR TRIP P POOH F/ 6125' T/ 5058'. PUW=126K 6,125.0 5,058.0 2/4/2022 01:30 2/4/2022 03:30 2.00 COMPZN, WELLPR SLPC P Cut and slip 82' of drill line. Service TD, blocks and crown. 5,058.0 5,058.0 2/4/2022 03:30 2/4/2022 05:30 2.00 COMPZN, WELLPR TRIP P POOH F/ 5058' T/ 45', PUW=110K 5,058.0 45.0 2/4/2022 05:30 2/4/2022 06:30 1.00 COMPZN, WELLPR BHAH P L/D BHA#3 MU BHA#4 Gplug/Test Pkr. 45.0 35.8 2/4/2022 06:30 2/4/2022 10:45 4.25 COMPZN, WELLPR TRIP P TIH to 5450 W/G-plug to COE 35.8 5,450.0 2/4/2022 10:45 2/4/2022 11:15 0.50 COMPZN, WELLPR MPSP P Set G-Plug 6 Rotations to the right 20K down released 1 rotation to the left Top of plug at 5444.4' 7ES RKB. PUH 5341' Set test packer, close pipe rams, 5,450.0 5,341.0 2/4/2022 11:15 2/4/2022 13:00 1.75 COMPZN, WELLPR PRTS P Test through kill above test packer to1800 failed. Bleed off residual pressure. Open pipe rams. PUH to 5310' Set test packer, close pipe rams, test through kill above test packer to 1750 PSI charted for 30 minutes, good test. Bleed off open pipe rams Move down-hole to 5325' set test packer. Close pipe rams. Attempt to pressure test to 1800 PSI. failed Casing above 5310' tested to 1800 psi for 30 minutes. 5,341.0 5,325.0 2/4/2022 13:00 2/4/2022 13:15 0.25 COMPZN, WELLPR OWFF P Flow check for 15 minutes after charging behind 7" Slight flow decreasing in rate to pits. 5,325.0 5,325.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 5/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/4/2022 13:15 2/4/2022 13:45 0.50 COMPZN, WELLPR MPSP P Release test packer. RIH to top of G- plug. Equalize plug, and release. 5,444.0 5,444.0 2/4/2022 13:45 2/4/2022 14:00 0.25 COMPZN, WELLPR OWFF P Flow check well for 15 minutes. 5,444.0 5,444.0 2/4/2022 14:00 2/4/2022 14:15 0.25 COMPZN, WELLPR TRIP P PUH to 5296' 5,444.0 5,296.0 2/4/2022 14:15 2/4/2022 15:00 0.75 COMPZN, WELLPR MPSP P Set G-plug at 5296'. Charted plug and 7" casing test to 1800 PSI for 30 minutes. 5,296.0 5,296.0 2/4/2022 15:00 2/4/2022 16:00 1.00 COMPZN, WELLPR PRTS P Charted pressure test on G-plug at 5296' to 1800PSI. Blow down surface lines 5,296.0 5,296.0 2/4/2022 16:00 2/4/2022 19:30 3.50 COMPZN, WELLPR TRIP P TOOH with Test packer F/ 5296' T/ 28'. PUW=107K Open OA T/ atmosphere bleed off 65 PSI of gas. 5,296.0 28.0 2/4/2022 19:30 2/4/2022 19:45 0.25 COMPZN, WELLPR BHAH P L/D test packer. 28.0 0.0 2/4/2022 19:45 2/4/2022 20:00 0.25 COMPZN, WELLPR BHAH P M/U G-Plug retrieval tool. 0.0 11.0 2/4/2022 20:00 2/4/2022 21:00 1.00 COMPZN, WELLPR TRIP P RIH F/ 11' T/ 1433' 11.0 1,433.0 2/4/2022 21:00 2/4/2022 23:00 2.00 COMPZN, WELLPR PACK P M/U 7" storm packer and RIH T/ 109.6' COE. Top of valve @ 88.74'. Set packer. Shear screws sheared opening equalization valve. POOH w/ storm packer. Re-pin valve. Rerun packer and reset at same depth. Release from packer. 1,433.0 1,545.0 2/4/2022 23:00 2/4/2022 23:15 0.25 COMPZN, WELLPR TRIP P POOH 1 stand of DP. 1,545.0 1,545.0 2/4/2022 23:15 2/4/2022 23:45 0.50 COMPZN, WELLPR PRTS P PT storm packer F/ above T/ 1000 PSI for 10 min, against blinds down kill line - Good test. 1,545.0 1,545.0 2/4/2022 23:45 2/5/2022 00:00 0.25 COMPZN, WELLPR RURD P B/D kill line. R/D testing equipment. 1,545.0 1,545.0 2/5/2022 00:00 2/5/2022 06:00 6.00 COMPZN, WELLPR NUND P Remove flow nipple. N/D BOP, DSA and hardware off of tubing spool. Break bolts on tubing spool and verify 7" is in compression. Rig up hydratight, Growing 7" casing. 15.25'" OA growth. 1,545.0 1,545.0 2/5/2022 06:00 2/5/2022 06:30 0.50 COMPZN, WELLPR BHAH P MU 7" Baker casing spear and RIH to top of 7" casing 1,545.0 1,545.0 2/5/2022 06:30 2/5/2022 09:00 2.50 COMPZN, WELLPR WWSP P Remove 7" casing pack off and slips. Installed new Cameron 7" x 11" casing slips. Pulled 284K 100K over string weight set in slips. 30.75" OA stretch for a total of 46". Use Wachs cutter to cut 7" casing. Final cutoff height 4-5/8" above casing flange. 1,545.0 1,545.0 2/5/2022 09:00 2/5/2022 11:30 2.50 COMPZN, WELLPR RURD P Install and torque new 11" 3K x 7" 5K Cameron tubing head. 1,545.0 1,545.0 2/5/2022 11:30 2/5/2022 13:00 1.50 COMPZN, WELLPR PRTS P Plastic pack-off void and test to 3K psi for 10 minutes witnessed by Driller. Tested good. 1,545.0 1,545.0 2/5/2022 13:00 2/5/2022 15:30 2.50 COMPZN, WELLPR BOPE P Set Test plug in wellhead. N/U DSA, BOP, install flow nipple. 1,545.0 1,545.0 2/5/2022 15:30 2/5/2022 16:00 0.50 COMPZN, WELLPR PRTS P Test breaks on stack including top of tubing spool T/ 250/3500 PSI f/ 5 min each - good test 1,545.0 1,545.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 6/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2022 16:00 2/5/2022 17:30 1.50 COMPZN, WELLPR RURD P Pull test plug. Install wear bushing - 6.375" ID, .7' Long. 1,545.0 1,545.0 2/5/2022 17:30 2/5/2022 18:30 1.00 COMPZN, WELLPR BHAH P M/U 7" storm packer retrieval tool T/ stand of DP. 1,545.0 1,545.0 2/5/2022 18:30 2/5/2022 18:45 0.25 COMPZN, WELLPR TRIP P RIH T/ top of 7" storm packer @ 88.74' 1,545.0 1,545.0 2/5/2022 18:45 2/5/2022 19:15 0.50 COMPZN, WELLPR PACK P Engage 7" storm packer. Equalize pressure. Release packer. POOH T/ 1433'. 1,545.0 1,433.0 2/5/2022 19:15 2/5/2022 21:30 2.25 COMPZN, WELLPR TRIP P RIH F/ 1433' T/ G-plug @ 5296', PUW=105K, SOW=95K 1,433.0 5,296.0 2/5/2022 21:30 2/5/2022 21:45 0.25 COMPZN, WELLPR PACK P M/U TD engage G-Plug. Equalize pressure. Release G-plug. RIH 10' past set depth to verify released. 5,296.0 5,306.0 2/5/2022 21:45 2/5/2022 22:30 0.75 COMPZN, WELLPR CIRC P Circ BU 145 Bbls @ 4 BPM, 580 PSI. B/D TD 5,306.0 5,306.0 2/5/2022 22:30 2/5/2022 23:00 0.50 COMPZN, WELLPR OWFF P OWFF - No flow. Gas peculating in the stack. 5,306.0 5,306.0 2/5/2022 23:00 2/5/2022 23:15 0.25 COMPZN, WELLPR TRIP P POOH F/ 5306' T/ 4929', PUW=105K Correct hole fill. Gas continues to perculate in the stack. 5,306.0 4,929.0 2/5/2022 23:15 2/6/2022 00:00 0.75 COMPZN, WELLPR CIRC P Circ BU 130 Bbls @ 5.7 BPM, 950 PSI. B/D TD 4,929.0 4,929.0 2/6/2022 00:00 2/6/2022 00:15 0.25 COMPZN, WELLPR OWFF P OWFF - No flow. Gas peculating in stack, fluid level falling slowly. 4,929.0 4,929.0 2/6/2022 00:15 2/6/2022 03:00 2.75 COMPZN, WELLPR TRIP P POOH F/ 4929' T/ 2950', PUW=95K Correct hole fill. OWFF no more gas migration well is static. POOH F/2950' T/ 22', PUW=75K 4,929.0 22.0 2/6/2022 03:00 2/6/2022 03:30 0.50 COMPZN, WELLPR BHAH P L/D G-plug and retrieval tool T/ surface. 22.0 0.0 2/6/2022 03:30 2/6/2022 04:00 0.50 COMPZN, WELLPR CLEN P Clean and clear RF. Mobilize BHA #6 equipment. 0.0 0.0 2/6/2022 04:00 2/6/2022 05:30 1.50 COMPZN, WELLPR BHAH P M/U BHA #6 overshot w/ 3.25" grapple T/ 129', 0.0 129.0 2/6/2022 05:30 2/6/2022 08:00 2.50 COMPZN, WELLPR TRIP P TIH F/129' to 6137' PUW=120K SOW=106K 129.0 6,137.0 2/6/2022 08:00 2/6/2022 10:00 2.00 COMPZN, WELLPR FISH P TIH to 6137' Engage slick stick. Bleed jars straight pull 175K Slack off set down 30K Jar 75K over 5 times Pulled 200K Set down RIH to 6147' Set down 30K PUH Jar 80K over packer started moving Closed annular attempted to circulate 15 STKs/Min Pump pressure=2750 PSI bled off DP blew down opened annular Worked packer up and down hole Weight broke back125K 5K over Racked one stand. PUW 120K erratic weight swing at 6095' appears we still have fish. 6,137.0 6,223.0 2/6/2022 10:00 2/6/2022 13:00 3.00 COMPZN, WELLPR CIRC P Close ann. Circ 12.3# NaBr SxS down DP up casing, through gas buster @ 1.6 BPM DP=2475 PSI. Worked rate up to 2 BPM DP=2000 PSI. 35 STKS/Min 3500 STKS DP=1775 PSI. 63 BBL Lost 35 STKS/Min 5000 STKS DP=1775 PSI. 51 BBL Lost. 6,223.0 6,223.0 2/6/2022 13:00 2/6/2022 13:30 0.50 COMPZN, WELLPR OWFF P Monitor well for 30 minutes 6,223.0 6,223.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 7/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/6/2022 13:30 2/6/2022 20:30 7.00 COMPZN, WELLPR PULD P LDDP F/ 6223' T/ 214', PUW=125K. 6,223.0 214.0 2/6/2022 20:30 2/6/2022 21:30 1.00 COMPZN, WELLPR BHAH P L/D BHA #6 F/ 214' T/ 88' 214.0 88.0 2/6/2022 21:30 2/6/2022 22:00 0.50 COMPZN, WELLPR RURD P R/U 2 7/8" tubing handling equipment. 88.0 88.0 2/6/2022 22:00 2/6/2022 23:00 1.00 COMPZN, WELLPR PULL P L/D 88' of 2 7/8" completion string from OEJ slick stick T/ SOS, everything recovered out of hole. 88.0 0.0 2/6/2022 23:00 2/6/2022 23:30 0.50 COMPZN, WELLPR TRIP P RIH w/ DP out of derrick T/ 438' 0.0 438.0 2/6/2022 23:30 2/7/2022 00:00 0.50 COMPZN, WELLPR PULD P LDDP F/ 438' T/ 249' 438.0 249.0 2/7/2022 00:00 2/7/2022 01:00 1.00 COMPZN, WELLPR PULD P LDDP F/ 294' T/ surface 249.0 0.0 2/7/2022 01:00 2/7/2022 02:00 1.00 COMPZN, WELLPR CLEN P Clean and clear RF and pipe shed. Remove all Baker fishing tools. 0.0 0.0 2/7/2022 02:00 2/7/2022 03:00 1.00 COMPZN, RPCOMP RURD P R/U 3 1/2" & 4 1/2" tubing handling equipment. Verify jewelry in correct order. Verify joint count on completion tubing. 0.0 0.0 2/7/2022 03:00 2/7/2022 03:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ SLB completion hands, and rig crew on running 3 1/2" completion w/ 4 1/2" tail pipe. 0.0 0.0 2/7/2022 03:30 2/7/2022 04:00 0.50 COMPZN, RPCOMP SVRG P Service rig. Repair faulty sensor on skate. 0.0 0.0 2/7/2022 04:00 2/8/2022 00:00 20.00 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M completion w/ 4 1/2", 11.6#, L-80, Hyd 563 tail pipe. M/U Tq for 4 1/2" Hyd 563 = 3500 ft/lbs. M/U Tq for 3 1/2" EUE-M = 2025 ft/lbs. Baker loc all connections below packer, with out seal rings T/ 3050 ft/lbs. Run-n-seal pipe dope used on non baker lock connections. RIH T/ 6315', took weight. M/U TD wash down @ 3 BPM, 250 PSI T/ 6402. PUW=78K, SOW=68K. Pack off issues- pressure increase and inability to freely move up or down. Working pipe @ 6378' PU T/ 150K, SO T/60K, Pump @ 1 BPM, 1200 PSI. Loss rate 30 BPH w/ pumps on after working pipe through perfs. 0.0 6,378.0 2/8/2022 00:00 2/8/2022 01:00 1.00 COMPZN, RPCOMP RCST P Working pipe @ 6378' PU T/ 150K, SO T/60K, Pump @ 1 BPM, 1200 PSI. Pipe came free. Regained circulation @ 3 BPM, 210 PSI. PUW=78K, SOW=68K. 6,378.0 6,306.0 2/8/2022 01:00 2/8/2022 09:30 8.50 COMPZN, RPCOMP CIRC P Circ @ 3 BPM, 210 PSI. Vis up fluid system and clean hole. Circ hi vis sweep around 50 vis. Large amount of sand seen at shakers. Reciprocating pipe F/ 6390' T/ 6306', PUW=78K, SOW=68K. 6,306.0 6,399.0 2/8/2022 09:30 2/8/2022 10:15 0.75 COMPZN, RPCOMP OWFF P Shut down mud pump and Observed well for flow for 30 minutes. Well flowing, close upper VBR / TIW. 6,399.0 6,398.0 2/8/2022 10:15 2/9/2022 00:00 13.75 COMPZN, RPCOMP COND T Weight up fluid in Pit 3 & 4 from 12.2+ to 12.3+. Unsucessful, large pellets of NaBr did not desolve in system. Remove fluid from pits. Take on new load of 12.3 PPG NaBr. Order 12.7 PPG spike fluid T/ increase KWF T/ 12.3+ PPG NaBr. Wait on spike fluid, 6,398.0 6,398.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 8/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/9/2022 00:00 2/9/2022 04:30 4.50 COMPZN, RPCOMP COND T Wait on spike fluid - temperature related trucking problems. Acquire sack product from CDR3 - frozen material. Bring KWF up T/ 12 .3+ PPG w/ 12.7 PPG spike fluid. 6,398.0 6,398.0 2/9/2022 04:30 2/9/2022 07:00 2.50 COMPZN, RPCOMP KLWL P Bleed minimal PSI of well. Open up and circ 12.3+ PPG NaBr around well @ 3 BPM, 175 PSI, verified string as free, Up Wt 78k / Dn Wt 68k. Circulated 289 bbls. Park string at 6,389' in the slips. 6,398.0 6,398.0 2/9/2022 07:00 2/9/2022 07:30 0.50 COMPZN, RPCOMP OWFF P Monitor well for flow, 30 minutes. No Flow. 6,398.0 6,398.0 2/9/2022 07:30 2/9/2022 07:45 0.25 COMPZN, RPCOMP SFTY P SLB E-Line on location. Hold PJSM with all crew members. 6,398.0 6,398.0 2/9/2022 07:45 2/9/2022 08:30 0.75 COMPZN, RPCOMP RURD P RU/MU E-Line tools. 6,398.0 6,398.0 2/9/2022 08:30 2/9/2022 13:00 4.50 COMPZN, RPCOMP ELOG P RIH & Make correlation log to get packer on depth. Download Data, had good log. RDMO E-Line tools and equipment. 6,378.0 6,378.0 2/9/2022 13:00 2/9/2022 14:00 1.00 COMPZN, RPCOMP PULD T Having issue with pipe skate, unable to L/D pipe without using tugger. 6,378.0 6,378.0 2/9/2022 14:00 2/9/2022 14:45 0.75 COMPZN, RPCOMP HOSO P P/U TBG Hanger, space out. 6,378.0 6,378.0 2/9/2022 14:45 2/9/2022 15:30 0.75 COMPZN, RPCOMP THGR P Land Completion, top of 4 1/2" tail pipe @ 6230.45'. RILDS, and Set BPV. Blow down Stack 6,378.0 6,378.0 2/9/2022 15:30 2/9/2022 16:30 1.00 COMPZN, WHDBOP PRTS P Pressure test BPV to 1000 psi. Good test. Blow surface lines. 6,378.0 6,378.0 2/9/2022 16:30 2/9/2022 19:30 3.00 COMPZN, WHDBOP NUND P PJSM. ND BOP Stack. 6,378.0 6,378.0 2/9/2022 19:30 2/9/2022 21:00 1.50 COMPZN, WHDBOP NUND P Install tree test plug. N/U adaptor spool and tree. R/U circ manifold. 6,378.0 6,378.0 2/9/2022 21:00 2/9/2022 23:00 2.00 COMPZN, WHDBOP PRTS P Test hanger void T/ 5000 "PSI for 15 Min - good test. R/U LRS, test tree T/ 5000 PSI for 15 min - Good test 6,378.0 6,378.0 2/9/2022 23:00 2/10/2022 00:00 1.00 COMPZN, WHDBOP PRTS P Test circ manifold and tiger tank line. Addresses leaking fitting on circ manifold. Test T/ 2500 PSI - good test. Test LRS T/ production valve T/ 5000 PSI - good test. 6,378.0 6,378.0 2/10/2022 00:00 2/10/2022 02:00 2.00 COMPZN, WHDBOP CIRC P Displace w/ 9.8 PPG CI NaCl down tubing taking returns out IA T/ tiger tank @ 3 BPM, ICP=410 PSI, FCP=1380 PSI. Hold back pressure at choke house starting at 55 Bbls into circulation, working up T/ 580 PSI. Pumped total of 165 Bbls. 6,378.0 6,378.0 2/10/2022 02:00 2/10/2022 03:30 1.50 COMPZN, WHDBOP FRZP P LRS pump 70 Bbls diesel freeze protect down tubing taking returns out IA T/ tiger tank @ 2 BPM, ICP=1380 PSI, FCP=2200 PSI. Hold 550 PSI back pressure at choke house. Total volume pumped CI & diesel = 235 Bbls. Total returns T/ tiget tank = 98 Bbls 6,378.0 6,378.0 2/10/2022 03:30 2/10/2022 04:30 1.00 COMPZN, WHDBOP FRZP P Place IT & tubing in communication and U tube well. Intial PSI on T=800, IA=650. After 30 min PSI on T=710, IA=690. After 1 Hr PSI on T=700, IA=700. 6,378.0 6,378.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 9/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2022 04:30 2/10/2022 06:00 1.50 COMPZN, WHDBOP PACK P Drop Baker Intallic 2.795" OD ball. Let ball fall in well for 1 Hr, sw/ T/IA in communication. LRS pump down tubing w/ diesel @ 1 BPM, 900 PSI for 5 Bbls. 1.5 BPM, 1250 PSI for10 Bbls. Total of 15 Bbls pumped. 6,378.0 6,378.0 2/10/2022 06:00 2/10/2022 06:30 0.50 COMPZN, WHDBOP PACK P LRS pump down tubing w/ diesel, initial TBG PSI 1000 / IAP 690 5 bbls pumped: TP 1200 / IAP 790 8 bbls pumped: TP 1300 / IAP 800 10 bbls pumped: TP 1350 / IAP 800 Packer failed to set. 6,378.0 6,378.0 2/10/2022 06:30 2/10/2022 07:30 1.00 COMPZN, WHDBOP WAIT T Waiting on Slickline Unit. 6,378.0 6,378.0 2/10/2022 07:30 2/10/2022 14:00 6.50 COMPZN, WHDBOP SLKL T PJSM. MIRU Slickline unit. Load lubricator to pipe shed. Load tools to Rig floor. 6,378.0 6,378.0 2/10/2022 14:00 2/10/2022 15:00 1.00 COMPZN, WHDBOP SLKL T RIH with 2.33" OD lower drift and 2.75" OD upper drift. Sit down and tagged at 6,335' SLMD. PUH 10' feet and had LRS pressure up on TBG. Able to obtain 2000 psi on TBG. POOH with Slickline. 6,378.0 6,378.0 2/10/2022 15:00 2/10/2022 16:00 1.00 COMPZN, WHDBOP PACK T OOH with SLickline Drift. CLose swap and line up LRS to pressure up on ball seat. Reached 3400 psi at 1 bpm, 5 bbls away, pressure wouldn't build any further. Shut down pump and pressure dropped to 1300 psi. On line again with LRS and pressure up to 3400 psi again after 6 bbls away, still not building pressure. Isolate LRS pump and RU XX -Plug to set in X-Nipple 6,378.0 6,378.0 2/10/2022 16:00 2/10/2022 16:30 0.50 COMPZN, WHDBOP SLKL T RD lubricator and L/D Slickline drift. and brush. M/U XX plug tool string. R/U lubricator and PT T/ 2500 PSI. 6,378.0 6,378.0 2/10/2022 16:30 2/10/2022 17:30 1.00 COMPZN, WHDBOP SLKL T RIH with XX-Plug on Slickline to set in X -Nipple below Packer @ 5344'. Pull slick line tool strin up into lubricator. Shut swab valve. 6,378.0 6,378.0 2/10/2022 17:30 2/10/2022 19:30 2.00 COMPZN, WHDBOP PACK T LRS line up T/ pump down tubing against XX plug @ 5444'. Initial PSI T=1200 / IA=800. LRS pump down tubing bring up PSI T=3250 / IA=925 @ 1 BPM, Bleed well PSI down T=1400 / IA=900. LRS pump down tubing bring up PSI T=2800 / IA=975 @ 1 BPM, Bleed well PSI down T=1200 / IA=800. Break off lubricator. Change out tool string, L/D XX setting tool. M/U 3 1/2" F collar stop hole finder. M/U lubricator. PT lubricator T/ 2500 PSI. LRS pump down tubing bring up PSI T=4550 / IA=3250 @ 2 BPM, Bleed well PSI down T=2800 / IA=3200. LRS pump down tubing bring up PSI T=4750 / IA=3250 @ 2 BPM, Bleed pressure off of IA T=1400 / IA=1000. Packer failed to set. 6,378.0 6,378.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Page 10/10 3G-02 Report Printed: 2/14/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2022 19:30 2/10/2022 21:30 2.00 COMPZN, WHDBOP SLKL T RIH w/ 3 1/2" F collar stop hole finder @ 5340', above XX plug. T=1500 / IA=1100. LRS pump down tubing bring up PSI T=2000 / IA=1500. Communication detected. Bleed well PSI down T=1550 / IA=1125. POOH T/ 5180', above OV. LRS pump down tubing bring up PSI T=2000 / IA=1550. Communication detected. Bleed well PSI down T=1500 / IA=1150. POOH T/ 4290', below GLM #2. LRS pump down tubing bring up PSI T=2100 / IA=1600. Communication detected. Bleed well PSI down T=1500 / IA=1150. POOH T/ 4290', above GLM #2. LRS pump down tubing bring up PSI T=2400 / IA=1180. Test for 5 Min - Good test. Bleed well PSI down T=1500 / IA=1150. POOH T/ surface. Shut in swab valve. Break off lubricator. Change out tools string. L/D 3 1/2" F collar stop hole finder. 6,378.0 6,378.0 2/10/2022 21:30 2/10/2022 22:45 1.25 COMPZN, WHDBOP SLKL T M/U 3 1/2" OM w/ 1 5/8" JP pulling tool. M/U lubricator. PT lubricator T/ 2500 PSI. Open well RIH T/ 4150'. Latch into GLV #2 and pull valve. POOH T/ surface. Break off lubricator. Change out tool string. L/D 3 1/2" OM w/ 1 5/8" JP pulling tool & GLV. 6,378.0 6,378.0 2/10/2022 22:45 2/10/2022 23:45 1.00 COMPZN, WHDBOP SLKL T M/U 1.5" dummy valve, w/ RK latch. M/U lubricator. PT lubricator T/ 2500 PSI. Open well RIH T/ 4150'. Set dummy valve in station #2. POOH T/ surface. T=1600 / IA=1200. LRS pump down tubing bring up PSI T=2325 / IA=1250. Sheared off dummy valve. POOH T/ surface. 6,378.0 6,378.0 2/10/2022 23:45 2/11/2022 00:00 0.25 COMPZN, WHDBOP PACK P LRS line up T/ pump down tubing. Initial PSI T=2000 / IA=1250. LRS pump down tubing bring up PSI T=4800 / IA=1325. 6,378.0 6,378.0 2/11/2022 00:00 2/11/2022 01:30 1.50 COMPZN, WHDBOP PRTS P Bleed tubing off T/ 2100 PSI. LRS pump up tubing T/ 3500 PSI. Test tubing for 30 min - Good test. Bleed tubing T/ 3000 PSI. LRS pump up IA T/ 2500 PSI. Test IA for 30 min - Good test. Bleed PSI on both tubing and IA T/ 500 PSI. 6,378.0 6,378.0 2/11/2022 01:30 2/11/2022 04:30 3.00 DEMOB, MOVE RURD P LRS suck back diesel from lubricator and circ manifole. R/D slick line. R/D circ equipment in cellar. B/D tiger tank. Secure tree. 6,378.0 6,378.0 2/11/2022 04:30 2/11/2022 06:00 1.50 DEMOB, MOVE DMOB P Complete pit cleaning. Blow down pits water and steam. Prep RF for L/D derrick. 6,378.0 6,378.0 2/11/2022 06:00 2/11/2022 12:00 6.00 DEMOB, MOVE MOB P Secure cellar. Prep derrick for L/D. Secure T/D in rotary table, bridle up blocks. RIG RELEASED AT NOON. 6,378.0 6,378.0 Rig: NABORS 7ES RIG RELEASE DATE 2/11/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,326.0 11/6/2021 3G-02 worthms Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set GLV & Liner Top 3/4/2022 3G-02 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,061.0 Set Depth (TVD) … 2,973.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,637.0 Set Depth (TVD) … 6,084.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.2 Set Depth (ft… 6,378.0 Set Depth (TVD) (… 5,854.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 30.2 30.2 0.06 Hanger 2.950 6.930 Cameron Gen IV 510.9 510.9 0.86 Nipple - X 2.813 3.770 Halliburton X Nipple 2,513.4 2,494.7 24.02 GAS LIFT 2.900 5.752 Camco MMG 4,150.4 3,901.0 30.07 GAS LIFT 2.900 5.673 Camco MMG 5,226.3 4,837.4 29.14 GAS LIFT 2.900 5.729 Camco MMG 5,343.9 4,940.0 29.35 Nipple - X 2.813 3.770 Halliburton X Nipple 6,366.3 5,843.8 27.03 Sleeve - Frac 2.660 4.490 Baker 2.66" Ball Seat 6,377.5 5,853.8 27.01 Wireline Guide 3.000 4.500 Baker 3.5" WLEG Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,328.0 4,926.1 29.32 LEAK - CASING Leak in the 7" production casing detected with acoustic log 12/1/2021 6.280 5,932.0 5,456.7 26.91 PACKER Set Northern Solutions AK Mono-Pak Liner Top Packer w/ 1.781" X-nipple @ 5,932' RKB. (See Attachments) 3/4/2022 1.781 A22427201- R00 6,314.0 5,797.2 27.10 WHIPSTOCK 2/20/2022 0.000 6,330.0 5,811.5 27.08 WHIPSTOCK 3-1/2" X 4-1/2" WS 2/16/2022 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,513.4 2,494.7 24.02 Schlum berger MMG 1 1/2 GAS LIFT GLV RK 1,281.0 2/7/2022 2 4,150.4 3,901.0 30.07 Schlum berger MMG 1 1/2 GAS LIFT GLV RK 0.188 1,279.0 3/4/2022 3 5,226.3 4,837.4 29.14 Schlum berger MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 2/7/2022 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,308.0 6,328.0 5,791.9 5,809.7 C-4, A-3, 3G-02 9/9/2005 6.0 APERF 2-1/8" PSE, 45 deg phase 6,339.0 6,378.0 5,819.5 5,854.2 A-2, 3G-02 1/12/1991 4.0 IPERF 4 1/2" Expendable Notes: General & Safety End Date Annotation 8/27/2010 NOTE: 3G-02, 3/7/2022 2:49:54 PM Vertical schematic (actual) PRODUCTION; 35.0-6,637.0 IPERF; 6,339.0-6,378.0 WHIPSTOCK; 6,330.0 Liner; 6,235.2-6,639.0 WHIPSTOCK; 6,314.0 APERF; 6,308.0-6,328.0 PACKER; 5,932.0 Nipple - X; 5,343.9 LEAK - CASING; 5,328.0 Packer (Tubing); 5,292.5 GAS LIFT; 5,226.3 GAS LIFT; 4,150.4 SURFACE; 35.0-3,061.0 GAS LIFT; 2,513.4 Nipple - X; 510.9 CONDUCTOR; 36.0-115.0 Hanger; 30.2 KUP PROD KB-Grd (ft) 36.39 Rig Release Date 10/24/1990 3G-02 ... TD Act Btm (ftKB) 6,659.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014600 Wellbore Status PROD Max Angle & MD Incl (°) 33.39 MD (ftKB) 3,500.00 WELLNAME WELLBORE3G-02 Annotation Last WO: End DateH2S (ppm) 140 Date 12/18/2015 Comment SSSV: TRDP 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. From:Ward, Dusty K To:Regg, James B (OGC); NSK RWO CM Cc:Loepp, Victoria T (OGC); AOGCC Records (CED sponsored) Subject:RE: [EXTERNAL]RE: 3G-02 MPSP update Date:Tuesday, February 1, 2022 8:35:08 AM Jim, Will do. Apologies and thanks. Victoria, We had to bump up a little bit more to finally get it killed. Final KWF was 12.3 ppg. Update BHP = 12.3 ppg 0.052 x 5792 (top perf) = 3705 psig Updated MPSP = 3705 - 579 = 3126 PSIG. Performing BOPE tests to 3500 psig like previously mentioned. KRU 3G-02; PTD 1901370 Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, January 31, 2022 8:51 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL]RE: 3G-02 MPSP update CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3G-02; PTD 1901370 When referencing a specific well, please also include the PTD #. Thank you. Jim Regg Supervisor, Inspections 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. AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Sunday, January 30, 2022 9:42 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: NSK RWO CM <NSKRWO.CM@conocophillips.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: 3G-02 MPSP update Victoria, I hope this finds you well. We circulated our expected KWF on 3G-02 at KUP for the well kill and found higher pressure than planned. We had 9.6 ppg in the well, and still had pressure of 700 psig on the tubing and IA. My BHP calculation is now: 9.6 ppg x 0.052 x 5792 (top perf) = 2891 psig Plus 700 gives me a BHP of 3591 psig. New MPSP = 3591 - 579 = 3012 PSIG. We're going to increase our KWF ppg and kill the well. Then move into setting BPV, ND tree, and move towards getting BOPE on after we get it killed. The New planned BOPE tests will be to 3500 psig on rams and annular. I'm cc'ing the rig and Jim Regg. If I should include any other email in these types of updates, please let me know. Please let me know if you have any questions. Thanks. Good day. Dusty Ward 503-476-2519 Sent via the Samsung Galaxy S10e, an AT&T 5G Evolution capable smartphone Get Outlook for Android 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. From:Regg, James B (OGC) To:Ward, Dusty K; NSK RWO CM Cc:Loepp, Victoria T (OGC); AOGCC Records (CED sponsored) Subject:RE: 3G-02 MPSP update Date:Monday, January 31, 2022 8:51:25 AM KRU 3G-02; PTD 1901370 When referencing a specific well, please also include the PTD #. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Sunday, January 30, 2022 9:42 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: NSK RWO CM <NSKRWO.CM@conocophillips.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: 3G-02 MPSP update Victoria, I hope this finds you well. We circulated our expected KWF on 3G-02 at KUP for the well kill and found higher pressure than planned. We had 9.6 ppg in the well, and still had pressure of 700 psig on the tubing and IA. My BHP calculation is now: 9.6 ppg x 0.052 x 5792 (top perf) = 2891 psig Plus 700 gives me a BHP of 3591 psig. New MPSP = 3591 - 579 = 3012 PSIG. We're going to increase our KWF ppg and kill the well. Then move into setting BPV, ND tree, and move towards getting BOPE on after we get it killed. The New planned BOPE tests will be to 3500 psig on rams and annular. I'm cc'ing the rig and Jim Regg. If I should include any other email in these types of updates, please let me know. Please let me know if you have any questions. Thanks. Good day. Dusty Ward 503-476-2519 Sent via the Samsung Galaxy S10e, an AT&T 5G Evolution capable smartphone Get Outlook for Android From:Ward, Dusty K To:Loepp, Victoria T (OGC) Subject:3G-02 Scope Update Date:Tuesday, December 7, 2021 2:11:48 PM Attachments:9_3G-02_Sundry_321-395_091021_Approved.pdf Victoria, I hope this finds you well. I wanted to update you on 2 small tweaks to the 3G-02 RWO scope on this approved RWO well. 1. When doing the pre-rig diagnostics on 3G-02, a casing leak at 5329’ RKB was found. In consulting our artificial lift SME, we decided to make the base plan to stack a packer higher than originally planned, right above this point at around ~5300’ RKB on this Producer. a. We’ll also add a trip to the plan to set a test packer and confirm casing integrity from ~5300’ RKB to surface, before running the final completion. 2. Per our recent discussions with you and our internal risk assessment done on N7ES for MIRU/RDMO operations, we’d plan to NOT install a BPV for the MIRU/RDMO operations. Thanks for your time. Please let me know if you have any questions. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 C:\Users\aebell\Desktop\December 2021 Data Drop\CPAI Data Drop 12072021\2021-12-01_14493_KRU_3G-02_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 14493 KRU 3G-02 50-103-20146-00 LeakPoint Survey 01-Dec-21 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 FTP ______________________________ ______________________________________ Print Name 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 37' (6HW _______________________________________ Signaturururururururururuuururrururururuurururururruurururuuue Abby Bell By Abby Bell at 10:27 am, Dec 07, 2021 From:Loepp, Victoria T (OGC) To:Ward, Dusty K Cc:Rixse, Melvin G (OGC); Regg, James B (OGC); DOA AOGCC Prudhoe Bay Subject:APPROVAL: BOPE test pressure 2500 psig KRU 3G-02 Date:Tuesday, November 9, 2021 8:40:36 PM Attachments:9_3G-02_Sundry_321-395_091021_Approved.pdf Dusty, Approval is granted to test the BOPE to 2500 psig. Please attach this approval to your approved sundry and have this approval on site for the State inspector to view. Thanx, Victoria Sent from my iPhone On Nov 9, 2021, at 1:31 PM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, Hope this finds you well. For attached and approved RWO Sundry for 3G-02, we got an update SBHP with the following information: 2772 psig @ 5802’ TVD on 11/6/2021 580 psig Gas Column yields new MPSP of ~2191 psig For that reason, the attached BOPE tests for rams and annular are now planned to be done at 2500 psig. Please confirm and let me know if you have any questions. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From:Ward, Dusty K To:Loepp, Victoria T (OGC) Subject:3G-02 recent SBHP and MPSP Updated for RWO Date:Tuesday, November 9, 2021 12:31:14 PM Attachments:9_3G-02_Sundry_321-395_091021_Approved.pdf Victoria, Hope this finds you well. For attached and approved RWO Sundry for 3G-02, we got an update SBHP with the following information: 2772 psig @ 5802’ TVD on 11/6/2021 580 psig Gas Column yields new MPSP of ~2191 psig For that reason, the attached BOPE tests for rams and annular are now planned to be done at 2500 psig. Please confirm and let me know if you have any questions. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From:Ward, Dusty K To:Loepp, Victoria T (OGC) Subject:3G-02 RWO Scope Update Date:Friday, October 29, 2021 10:02:07 AM Attachments:9_3G-02_Sundry_321-395_091021_Approved.pdf Victoria, Hope this finds you well. For the attached approved sundry, our base plan has changed to not install a BPV in the pre- rig step 9 (pg 3 of 6 of attached) before the MIRU operation. That part of the step should be struck from the plan. Consequently, “Pull BPV if need to circulate” in step 1 under MIRU should also be struck. This allows us to move right into checking pressures on Tubing and circulation activities if we need to perform them. Please let me know if you have any question. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell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y Samantha Carlisle at 3:21 pm, Aug 11, 2021 321-395 10-404 VTL 9/9/21 BOP test to 3500 psig Annular preventer pressure test to 2500 psig X DSR-8/16/21 X X DLB 08/11/2021 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date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rocedure Kuparuk Producer CTD Setup PTD #190-137 Page 1 of 1 Remaining Pre-Rig Work 1. POT-T & PPPOT-T. 2. Install hold-open sleeve in SSSV as needed. 3. Updated SBHP. 4. Pull patches. Drift/Tag rat hole. 5. Bullhead non-freezing brine right before setting plug. Set plug and catcher in D nipple at 6232’ RKB. 6. CMIT – TxIA to 2,500 psi. 7. Dummy off GLMs, except pull dummy valve off GLM #6 at 6103’ RKB. (Fluid will short circuit in tubing holes.) 8. Cut tubing at ~6128’ RKB. 9. Install H-type BPV within 48 hrs of rig arrival and prep well for rig. Test BPV. Confirm no pressure build in IA. Rig Work MIRU 1. MIRU Nabors 7ES on 3G-02. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV if needed and confirm as barrier, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing and Packer Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to pre-rig cut (~6128’ RKB). 6. Pull 2-7/8” tubing stub and seals. 7. Pull packer with 2-7/8” tubing tail from ~6167’ RKB. Circulate out packer gas. Confirm NFT as this will be first time exposed to formation. Adjust KWF as required to keep well killed. Cleanout Run 8. Perform a Cleanout run if necessary based on tubing condition. Install in 3-½” Tubing with Big Tail Pipe for CTD Set Up 9. MU 3 ½” completion with WLEG, Big Tail Pipe, nipples, packer, and GLMs. RIH to depth but don’t set packer. 10. RU Eline and correlate completion so Kick Off Joints are at correct depth as needed. 11. Once on depth, space out and land tubing. PT Packoffs. ND BOP, NU Tree 12. Install BPV and test. 13. ND BOPE. NU tree. Test tree. 14. Pull BPV, freeze protect well if needed. 15. RDMO. Post-Rig Work 16. Swap well over to CI seawater by pumping down tubing and up the IA (around the packer). 17. Drop ball. Pressure up on tubing to set packer. 18. Pressure test tubing to 3000 psi for 10 minutes. 19. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 20. Freeze protect as necessary by pumping through top GLV. 21. RDMO. 30 min VTL 9/9/21 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,333.0 8/11/2019 3G-02 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced OV 7/5/2020 3G-02 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) (… 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,061.0 Set Depth (TVD) (… 2,973.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,637.0 Set Depth (TVD) (… 6,084.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5"x2.875" @ 64' String Max … 2 7/8 ID (in) 2.44 Top (ftKB) 30.8 Set Depth (ft… 6,240.4 Set Depth (TVD) (ft… 5,731.7 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 30.8 30.8 0.06 HANGER MCEVOY TUBING HANGER 3.500 64.2 64.2 0.12 XO Reducing CROSSOVER 3.5 x 2.875 2.875 1,821.1 1,819.6 3.56 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 6,149.0 5,650.2 26.90 PBR CAMCO OEJ PBR 2.312 6,166.5 5,665.8 26.91 PACKER CAMCO HRP-1-SP PACKER 5.927 6,232.0 5,724.2 27.00 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,239.7 5,731.1 27.01 SOS CAMCO PE-500 SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,545.0 4,243.1 29.63 UPR PACKER (ME) w/ SPACER PIPE 2-7/8" UPPER P2P w/ SPACER PIPE & ANCHOR LATCH, SN: CPP287044/CPAL287021, OAL 30.86' 9/12/2019 1.375 4,546.0 4,243.9 29.63 SPACER PIPE w/ ANCHOR LATCH 2-1/16" P-110 SPACER PIPE w/ ANCHOR LATCH 9/12/2019 1.600 4,558.0 4,254.4 29.61 TUBING LEAK TUBING LEAK IDENTIFIED w/ RELAY LDL 9/9/2019 2.441 4,575.0 4,269.1 29.58 LWR PACKER (ME) 2-7/8" LOWER P2P, OAL 3.55' 9/11/2019 1.375 CPP287040 4,620.0 4,308.3 29.53 UPR PACKER (ME) w/ SPACER PIPE 2-7/8" UPPER P2P w/ SPACER PIPE & ANCHOR LATCH, SN: CPP287039/CPAL287025, OAL 18.82' 9/11/2019 1.375 4,621.0 4,309.2 29.53 SPACER PIPE w/ ANCHOR LATCH 2-1/16" P-110 SPACER PIPE w/ ANCHOR LATCH 9/11/2019 1.600 4,629.0 4,316.1 29.53 TUBING LEAK TUBING LEAK IDENTIED w/ RELAY D&D HOLE FINDER 9/11/2019 2.441 4,638.0 4,324.0 29.52 LWR PACKER (ME) 2-7/8" LOWER P2P, OAL 3.56' 9/11/2019 1.375 CPP287036 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,308.0 6,328.0 5,791.9 5,809.7 C-4, A-3, 3G-02 9/9/2005 6.0 APERF 2-1/8" PSE, 45 deg phase 6,339.0 6,378.0 5,819.5 5,854.2 A-2, 3G-02 1/12/1991 4.0 IPERF 4 1/2" Expendable Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,330.8 2,323.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,245.0 2/14/2009 2 3,814.2 3,610.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,247.0 2/14/2009 3 4,498.2 4,202.4 MERLA TMPD 1 GAS LIFT OV BK 0.188 0.0 7/5/2020 EXT PKG 4 5,185.6 4,801.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 5 5,749.4 5,294.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 6 6,103.5 5,609.6 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/5/1998 7 6,190.5 5,687.2 MERLA TGPD 1 1/2 PROD DMY RK 0.000 0.0 1/12/1991 Notes: General & Safety End Date Annotation 8/23/2019 NOTE: Heavy & Erratic Weight Swings (Poss. Corkscrewed) Use Slinky Toolstring 8/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2/18/2009 NOTE: DMY VLV @ GLM #4 HAS POSSIBLE STRIPPED FISHING NECK, **DO NOT PULL** 3G-02, 3/23/2021 9:39:37 AM Vertical schematic (actual) PRODUCTION; 35.0-6,637.0 IPERF; 6,339.0-6,378.0 APERF; 6,308.0-6,328.0 SOS; 6,239.7 NIPPLE; 6,232.0 PRODUCTION; 6,190.5 PACKER; 6,166.5 PBR; 6,149.0 GAS LIFT; 6,103.5 GAS LIFT; 5,749.4 GAS LIFT; 5,185.6 LWR PACKER (ME); 4,638.0 SPACER PIPE w/ ANCHOR LATCH; 4,621.0 TUBING LEAK; 4,629.0 UPR PACKER (ME) w/ SPACER PIPE; 4,620.0 LWR PACKER (ME); 4,575.0 SPACER PIPE w/ ANCHOR LATCH; 4,546.0 TUBING LEAK; 4,558.0 UPR PACKER (ME) w/ SPACER PIPE; 4,545.0 GAS LIFT; 4,498.2 GAS LIFT; 3,814.2 SURFACE; 35.0-3,061.0 GAS LIFT; 2,330.8 SAFETY VLV; 1,821.1 CONDUCTOR; 36.0-115.0 HANGER; 30.8 KUP PROD KB-Grd (ft) 36.39 Rig Release Date 10/24/1990 3G-02 ... TD Act Btm (ftKB) 6,659.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014600 Wellbore Status PROD Max Angle & MD Incl (°) 33.39 MD (ftKB) 3,500.00 WELLNAME WELLBORE3G-02 H2S (ppm) 140 Date 12/18/2015 Comment SSSV: TRDP Annotation Last WO: End Date ! !"#$% & "'() (*+,$-.! /00! #$+,$1 2$34 !5 # !%0 1#%36 7 8 9(( * -4 : "*+,$; ( * < 0 ()+ (); +(( * -4 : "*+,$* ( =**: ") (+,$;( =**: "()(;+,$ 0 () + () + 0 () + () +< 0 ()+ (); +;( =**: "()(;+,$* ( =**: ") (+,$ ISSUED AS:PRELIMINARY DATE:ISSUED BY: AS BUILT FOR:APPROVAL MARK-UP QUOTE REVIEW 07-JUN-21PKM X X17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORS BY OPERATOR PIPE RAM CL WELL CHOKE LINE 7 BILL OF MATERIALS 4 13 1 2 1 NO QTY DESCRIPTION BOP, RAM 13 5 8" 5M CAMERON "U" (DOUBLE)1 DRILL SPOOL 13 5 8" 5M w/ (2) 318" 5M OUTLETS. BOP, RAM 13 5 8" 5M CAMERON "U" (SINGLE) 3 6 GATE VALVE, MANUAL 3 18" 5M GATE VALVE, HYDRAULIC 3 18" 5M2 2 BOP, ANNULAR 13 5 8" 5M CAMERON T-90 1 2 4 3 4 4 5 5 5 5 6 7 24" HEIGHT. 67 8 KILL LINE 5 API TARGET BLIND FLANGE 3 18" 5M4 8 DSA 318"5M x 2116" 5M1 F F-TICKET #: THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPER THIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BE REVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES. REV. XREF DESCRIPTION APP.DATE BY TITLE COPYRIGHTED© DATE: DRN BY: ER:B DWG: APP: RIG: SCALE:NABORS SHT NO. OF NABORS RIG 7ES 13 5/8" 5M BOP STACK LAYOUT 14002 7ES PKM NTS 27-MAY-21 SMB 7ES-0008-01 B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM 3470945 01 01DRILLER SIDEOFF DRILLER SIDE 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: E xploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8948'2,304 None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12.A ttachments: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned James Hayes Contact Name:James Hayes Senior Workover Engineer Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng James.C.Hayes @cop.com 263-6927, 918-914-9609 N/A6356' 6167' 5667' 1,821' MD / 1,820' TVD 6,167' MD / 5,667' TVD Perforation Depth TVD (ft): Tubing Size: Length COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): C-Sand 5,792' - 5,810' A-Sand 5,820' - 5,854' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25547, ALK 2661 190-137 PO Box 100360, Anchorage AK 99510 50-103-20146 ConocoPhillips Alaska Inc Size KRU 3G-02 Kuparuk River Field / Kuparuk River Oil Pool L-80 TVD Burst 6240' MD 121' 3060' 5913' 121' 3061' 16" 9-5/8" 80' 7"6602' 3026' Perforation Depth MD (ft): 6637' C-Sand 6,308 - 6,328' A-Sand 6,339' - 6,378' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 5/19/2020 2-7/8" Camco TRCP-1A-SSA Camco HRP-1-SP approval: Notify Commission so that a representative may witness Sundry Number: BOP TestMechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY James Hayes Contact Name:James Hayes Senior Workover Engineer Contact Email: Contact Phone: Date: James.C.Hayes @cop.com 263-6927, 918-914-9609 me: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: Date for 15. Well Status after proposed work: Operations:OILWINJ W DSPL Suspended proval:Date:GASWAGGSTOR SPLUG Representative: GINJ Op Shutdown Abandoned 5/19/2020 nts: Proposal Summary Wellbore schematic13. Well Class after proposed work: ations Program BOP SketchExploratory Stratigraphic Developm ent Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft):1,821' MD / 1,820' TVD 6,167' MD / 5,667' TVDCamco HRP-1-SP Tubing Grade:Tubing MD (ft): L-80 6240' Tubing Size: 2-7/8" Perforation Depth TVD (ft): C-Sand 5,792' - 5,810' A-Sand 5,820' - 5,854' pth MD (ft): 6,308 - 6,328' 6,339' - 6,378' on 5913'7"6637'ate 6602' 3060'3061'9-5/8"e 3026' 121'121'16"or 80' al CollapseSizeTVDBurstMDgLength Junk (MD): None Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD): 2,304 /6167'5667' D (ft): Total Depth TVD (ft): 6356' PRESENT WELL CONDITION SUMMARY esignation (Lease Number):10. Field/Pool(s): ADL 25547, ALK 2661 Kuparuk River Field / Kuparuk River Oil Pool g:8. Well Name and Number: ation or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No KRU 3G-02 ame:4. Current Well Class:5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: 190-137 PO Box 100360, Anchorage AK 99510 50-103-20146 ConocoPhillips Alaska Inc quest: Abandon Plug Perforations Fracture Stimulate Repair We Operations shutdownpair Well Suspend Perforate Other Stimulate Pull Tubing Change Approved Programll Tubing Plug for Redrill Perforate New Pool Re-enter Susp W ell Alter Cas Other: er Casing ___________________ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Mar-20-2020 COMMISSION By Jody Colombie at 9:31 am, Mar 20, 2020 50-103-20146-00-00 6085663761046659 SD 3/20/2020 SD 3/20/2020 X BOP test pressure to 2500 psig CTD Set Up 10-404 VTL 3/26/20 Annular test pressure to 2500 psig ADSR-3/20/2020 320-127 dts 3/26/2020 3/26/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 19 March 2020 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3G-02 (PTD #190-137). 3G-02 was originally drilled in 1990 as an A & C-sand producer. The C-sand has overpowered the under produced A sand in this area. This well was selected by the CTD team as donor well for a CTD sidetrack only the well has 2- 7/8” tubing to allow the C-sand to be isolated and drill a lateral in the A-sand. The workover goal is to pull the 2-7/8” tubing & packer in order to upsize the tubing to 3 ½” tubing with a portion of 4 ½” tubing below the packer to allow for CTD to sidetrack the well. This workover is planned to be execute by Doyon 142. If you have any questions or require any further information, please contact me at 265-6927. Sincerely, James C Hayes Senior Wells Engineer CPAI Drilling and Wells By Jody Colombie at 9:30 am, Mar 20, 2020 3G-02 Rig Workover CTD Setup (PTD #: 190-137) 1 Current Operations: This well is currently producing and awaiting a RWO. Scope of Work: Pull existing 2-7/8” tubing string & run new 3 ½” tubing string General Well info: Well Type: Producer MPSP: 2,304 psi using 0.1 psi/ft gradient Static BHP: 2,947 psi / 6,432’ TVD (9.2 ppg EMW) Wellhead type/pressure rating: McEvoy Gen IV , 11” - 5M psi top ring gasket BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed – Waived MIT-OA PASSED – 03/11/2020 IC POT &PPPOT PASSED – 03/11/2020 TBG POT &PPPOT PASSED – 03/11/2020 Production Engineer: Devin Kozak / Ethan Plunkett Workover Engineer: James Hayes Pre-Rig Work 1.Lock out SSSV 2.Pull 2 - P2P tubing patches 3.String shot and chem cut first joint above the packer 6,130’ MD. 4.Grease tree valves and set BPV. Workover Procedure 1.MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2.Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2,500 psi and annular to 2,500 psi. 3.Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4.Lay down tubing for scrap 5.MU fishing assembly RIH & latch onto tubing 6.Jar tubing free from seal assembly 7.Circulate bottoms up and prepare to close annular in the event the packer has released & there could be trapped gas below the packer 8.POOH, lay down fishing BHA & fish 9.Run back in hole with new fishing assembly to packer 10.Latch onto packer & jar packer free 11.Circulate bottoms up and close annular due to possible trapped gas below packer 12.POOH & LD fish and remaining tubing 13.POOH, lay down milling BHA, and PU packer fishing assembly w/ spear 14.RIH, tag packer top, set spear and jar fish free 15.POOH and LD fish 16.Make up clean out/scraper assembly & RIH to 8,500’ 17.Wash down to 8,750’ MD to clean up perfs 18.POOH & LD clean out assembly 19.MU lower completion string on DP 20.RIH to packer set depth 21.Circulate in corrosion inhibited brine 22.RU E-line run in hole, correlate K1 & verify spaceout 23.POOH & RD E-line 24.Move to set depth drop ball & rod and pressure up to set packer 25.Shear out of PBR & POOH LD DP 26.MU upper completion RIH & tag packer top 27.Determine space out, make up tubing pups & land tubing 28.Pressure test packoffs 3G-02 Rig Workover CTD Setup (PTD #: 190-137) 2 29.Pressure test tubing and then the IA 30.Shear out the SOV and freeze protect the well 31.Install the BPV, ND the BOPE, and NU the production tree Post-Rig Work 1.Reset well house(s) and flowlines of adjacent wells. 2.Pull BPV. 3.RU Slickline. Pull SOV 4.Install OV 5.Pull ball & rod 6.Pull RHC plug in X-nipple 7.Handoff to operations to put back on production. BOP Configuration 2-7/8” x 5” VBR BLIND 2-7/8” x 5” VBR ANNULAR Proposed CTD Sidetrack3G-02Current Setup3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ TBDBaker Permier packer @ ~6,065' MD 3-1/2" HES landing X-nipple TBD' MD (2.812" min ID)3-1/2" Tandem Wedge Assembly16" 62.5# H-40 shoe @ 115' MD2-7/8" 6.5# TubingA-sand perfs6,339' -6,378'16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55shoe @ 3,061' MD7" 26# J-55 shoe @ 6,637' MD3-1/2" 9.3# TubingC-sand perfs6,308' -6,328'C-sand perfs6,308' -6,328'A-sand perfs6,339' -6,378'7" 26# J-55 shoe @ 6,637' MD9-5/8" 36# J-55shoe @ 3,061' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,333.0 8/11/2019 3G-02 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Identified Tubing Leaks, Pulled CSV, Set Two Patches 9/12/2019 3G-02 bworthi Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,061.0 Set Depth (TVD) … 2,973.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,637.0 Set Depth (TVD) … 6,084.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5"x2.875" @ 64' String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 30.8 Set Depth (ft… 6,240.4 Set Depth (TVD) (… 5,731.7 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 30.8 30.8 0.06 HANGER MCEVOY TUBING HANGER 3.500 64.2 64.2 0.12 XO Reducing CROSSOVER 3.5 x 2.875 2.875 1,821.1 1,819.6 3.56 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 6,149.0 5,650.2 26.90 PBR CAMCO OEJ PBR 2.312 6,166.5 5,665.8 26.91 PACKER CAMCO HRP-1-SP PACKER 5.927 6,232.0 5,724.2 27.00 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,239.7 5,731.1 27.01 SOS CAMCO PE-500 SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 4,545.0 4,243.1 29.63 UPR PACKER (ME) w/ SPACER PIPE 2-7/8" UPPER P2P w/ SPACER PIPE & ANCHOR LATCH, SN: CPP287044/CPAL287021, OAL 30.86' 9/12/2019 1.375 4,546.0 4,243.9 29.63 SPACER PIPE w/ ANCHOR LATCH 2-1/16" P-110 SPACER PIPE w/ ANCHOR LATCH 9/12/2019 1.600 4,558.0 4,254.4 29.61 TUBING LEAK TUBING LEAK IDENTIFIED w/ RELAY LDL 9/9/2019 2.441 4,575.0 4,269.1 29.58 LWR PACKER (ME) 2-7/8" LOWER P2P, SN: CPP287040, OAL 3.55' 9/11/2019 1.375 4,620.0 4,308.3 29.53 UPR PACKER (ME) w/ SPACER PIPE 2-7/8" UPPER P2P w/ SPACER PIPE & ANCHOR LATCH, SN: CPP287039/CPAL287025, OAL 18.82' 9/11/2019 1.375 4,621.0 4,309.2 29.53 SPACER PIPE w/ ANCHOR LATCH 2-1/16" P-110 SPACER PIPE w/ ANCHOR LATCH 9/11/2019 1.600 4,629.0 4,316.1 29.53 TUBING LEAK TUBING LEAK IDENTIED w/ RELAY D&D HOLE FINDER 9/11/2019 2.441 4,638.0 4,324.0 29.52 LWR PACKER (ME) 2-7/8" LOWER P2P, SN: CPP287036, OAL 3.56' 9/11/2019 1.375 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,308.0 6,328.0 5,791.9 5,809.7 C-4, A-3, 3G-02 9/9/2005 6.0 APERF 2-1/8" PSE, 45 deg phase 6,339.0 6,378.0 5,819.5 5,854.2 A-2, 3G-02 1/12/1991 4.0 IPERF 4 1/2" Expendable Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,330.8 2,323.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,245.0 2/14/2009 2 3,814.2 3,610.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,247.0 2/14/2009 3 4,498.2 4,202.4 MERLA TMPD 1 GAS LIFT OV BK 0.188 0.0 9/2/2019 EXT PKG 4 5,185.6 4,801.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 5 5,749.4 5,294.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 6 6,103.5 5,609.6 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/5/1998 7 6,190.5 5,687.2 MERLA TGPD 1 1/2 PROD DMY RK 0.000 0.0 1/12/1991 Notes: General & Safety End Date Annotation 2/18/2009 NOTE: DMY VLV @ GLM #4 HAS POSSIBLE STRIPPED FISHING NECK, **DO NOT PULL** 8/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8/23/2019 NOTE: Heavy & Erratic Weight Swings (Poss. Corkscrewed) Use Slinky Toolstring Comment SSSV: TRDP 3G-02, 9/12/2019 7:35:38 PM Vertical schematic (actual) PRODUCTION; 35.0-6,637.0 IPERF; 6,339.0-6,378.0 APERF; 6,308.0-6,328.0 SOS; 6,239.7 NIPPLE; 6,232.0 PRODUCTION; 6,190.5 PACKER; 6,166.5 PBR; 6,149.0 GAS LIFT; 6,103.5 GAS LIFT; 5,749.4 GAS LIFT; 5,185.6 LWR PACKER (ME); 4,638.0 TUBING LEAK; 4,629.0 SPACER PIPE w/ ANCHOR LATCH; 4,621.0 UPR PACKER (ME) w/ SPACER PIPE; 4,620.0 LWR PACKER (ME); 4,575.0 SPACER PIPE w/ ANCHOR LATCH; 4,546.0 TUBING LEAK; 4,558.0 UPR PACKER (ME) w/ SPACER PIPE; 4,545.0 GAS LIFT; 4,498.2 GAS LIFT; 3,814.2 SURFACE; 35.0-3,061.0 GAS LIFT; 2,330.8 SAFETY VLV; 1,821.1 CONDUCTOR; 36.0-115.0 HANGER; 30.8 KUP PROD KB-Grd (ft) 36.39 Rig Release Date 10/24/1990 Annotation Last WO: End Date 3G-02 H2S (ppm) 140 Date 12/18/2015... TD Act Btm (ftKB) 6,659.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032014600 Wellbore Status PROD Max Angle & MD Incl (°) 33.39 MD (ftKB) 3,500.00 WELLNAME WELLBORE3G-02 Doyon 142 BOP & Choke Configuration 2-7/8” x 5” VBR BLIND 2-7/8” x 5” VBR ANNULAR 3G-02 Rig Workover CTD Setup (PTD #: 190-137) 3 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 1 Current Operations: This well is currently producing and awaiting a RWO. Scope of Work: Pull existing 2-7/8” tubing string & run new 3 ½” tubing string General Well info: Well Type: Producer MPSP: 2,304 psi using 0.1 psi/ft gradient Static BHP: 2,947 psi / 6,432’ TVD (9.2 ppg EMW) Wellhead type/pressure rating: McEvoy Gen IV , 11” - 5M psi top ring gasket BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed – Waived MIT-OA PASSED – 03/11/2020 IC POT &PPPOT PASSED – 03/11/2020 TBG POT &PPPOT PASSED – 03/11/2020 Production Engineer: Devin Kozak / Ethan Plunkett Workover Engineer: James Hayes Pre-Rig Work 1. Lock out SSSV 2. Pull 2 - P2P tubing patches 3. String shot and chem cut first joint above the packer 6,130’ MD. 4. Grease tree valves and set BPV. Workover Procedure 1. MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2,500 psi and annular to 2,500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. Lay down tubing for scrap 5. MU fishing assembly RIH & latch onto tubing 6. Jar tubing free from seal assembly 7. Circulate bottoms up and prepare to close annular in the event the packer has released & there could be trapped gas below the packer 8. POOH, lay down fish & fishing equipment 9. Run back in hole with new fishing assembly to packer 10. Latch onto packer & jar packer free 11. Circulate bottoms up and close annular due to possible trapped gas below packer 12. POOH & LD fish and remaining tubing 13. POOH, lay down milling BHA, and PU packer fishing assembly w/ spear 14. RIH, tag packer top, set spear and jar fish free 15. POOH and LD fish 16. MU lower completion string on DP 17. RIH to packer set depth 18. Circulate in corrosion inhibited brine 19. Drop ball & rod and pressure up to set packer 20. Shear out of PBR & POOH LD DP 21. MU upper completion RIH & tag packer top 22. Determine space out, make up tubing pups & land tubing 23. Pressure test packoffs 24. Pressure test tubing and then the IA 25. Shear out the SOV and freeze protect the well 26. Install the BPV, ND the BOPE, and NU the production tree 3M-05 Rig Workover CTD Setup (PTD #: 087-025) 2 Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV 4. Install OV 5. Pull ball & rod 6. Pull RHC plug in X-nipple 7. Handoff to operations to put back on production. BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. FIXED/V BLIND VBR ANNULA pg pp Handoff to operations to put back on production. Proposed CTD Sidetrack3G-02Current Setup3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ TBDBaker Permier packer @ ~6,065' MD 3-1/2" HES landing X-nipple TBD' MD (2.812" min ID)4-1/2" Big Tail Pipe configuration16" 62.5# H-40 shoe @ 115' MD2-7/8" 6.5# TubingA-sand perfs 6,339' - 6,378'16" 62.5# H-40 shoe @ 115' MD9-5/8" 36# J-55 shoe @ 3,061' MD7" 26# J-55 shoe @ 6,637' MD3-1/2" 9.3# TubingC-sand perfs 6,308' - 6,328'C-sand perfs 6,308' - 6,328'A-sand perfs 6,339' - 6,378'7" 26# J-55 shoe @ 6,637' MD9-5/8" 36# J-55 shoe @ 3,061' MD From:Hayes, James C To:Loepp, Victoria T (CED) Subject:3G-02 10-403 Change Date:Tuesday, March 24, 2020 2:47:40 PM Attachments:3G-02 RWO Prop Schematic.pdf 3G-02 General Procedure.pdf Victoria, As we spoke about earlier, this workover has been changed from a “Big Tail Pipe” CTD setup to a Tandem Wedge assembly. Attached is the updated procedure & schematic. Please let me know if you have any questions. Thanks, James Hayes COP - Alaska RWO Engineer / CTD Liaison C: +1 918.914.9609 O: +1 907.265.6927 WELL LOG TRANSMITTAL #905922009 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Record: 3G-02 Run Date: 9/9/2019 and 9/10/2019 190137 3 136 2 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-02 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-103-20146-00 OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: ///9 Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP 18 20-19 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations s2put�,own E]Performed: Suspend ❑ Perforate ElOther Stimulate ❑ Alter Casing E] Alter 'ram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑✓ Re-enter Sus p Well ❑ Other: Install Patch ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhilllps Alaska, Inc. Development ❑� Exploratory ❑ 190-137 3. Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic ❑ Service ❑ TAP[ Number: 99510 50-103-20146-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25574, ALK 2661 KRU 3G-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,659 feet Plugs measured None feet true vertical 6,104 feet Junk measured None feet Effective Depth measured 6,637 feet Packer measured 6,167 feet true vertical 6,085 feet true vertical 5,666 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 115' MD 115' MD SURFACE 3,026 feet 39696 3,061' MD 2,937' MD PRODUCTION 6,602 feet 7 6,637' MD 6,085' MD Perforation depth: Measured depth: 6308'- 6328', 6339' - 6378' True vertical depth: 5792'- 5810', 5820'- 5854' Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" L-80 6,240' MD 5,731' TVD Packers and SSSV (type, measured and true vertical depth) CAMCO TRDP-1A-SSA SAFETY VALVE 1,821' MD 1,820' TVD UPR PATCH PACKER 4,545' MD 4,243' TVD LWR PATCH PACKER 4,575' MD 4,269' TVD UPR PATCH PACKER 4,620'M5 4,308' TVD LWR PATCH PACKER 4,638' MD 4,324' TVD PACKER - CAMCO HRP -1 -SP 6,167' MD 5,666' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-BblCasing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: I 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory p ry ❑ Development Service ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑' Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Sara Carlisle / Rachel Kautz Authorized Name: Sara Carlisle Authorized Title: Well Integrity and Compliance Specialist Contact Email: N2549@conocophilllps.com - J k -' Contact Phone: 907-659-7126 Authorized Signature: �� � Date: 1 1 lC Form 10-404 Revised 4/2017 VT --L ,SgDMS EP 19 2019 Submit Original Only `/ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 16, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patches set across two known tubing leaks in producer 3G-02 (PTD 190-137). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, tV1'W00'V;Vu') Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. `7 KUP PROD WELLNAME 3G-02 WELLBORE 313-02 t-onoeoPhilhps Well Attributes Max Angle &MD TO Alaska. htc_ Fiero Name wenoore AP11.1 INUL eslams III °I mD -(Ind.) Am Him (INS KUPARUK RIVER UNI 501032014DDC PROD 33.39 3,500.00 6,659.0 menl H35(ppm) e An Datnolenon Entl Dale Na-0rE ltt) Rig Releue Dale SSSV:TROP 140 12/182015 Li WO: 36.39 10/24/1980 3CRX2bS9m1973530 PM ii Last Tag vwgjLwonann lc lamal) Annotation pep(M1 ((lKB) EnO Dam W¢IIEan tsa(Motl By Last Tag: RKB 6,3330 611112019 3G-02 jhmmaah6 ' - ' fl HANGER E _"""' Last Rev Reason Ammoneumn End a Wellbore oral Matl sy Rev Ronson: Identified Tubing Leaks, Pulled CSV, SSI Two Patches 9/12/2013/2019 3G-02 baohhl Casing Strings Casino Description SO(im ID (in) TIP (High Bet Depth IXNB) sH depth (rV0)...GraOe Top Tnrea4 CONDUCTOR 16 15.06 36.0 115.0 1150 6250 H-40 WELDED Casing Deeniphon OD(In) ID lin) Top IXNB) sNDep1111XKB) Bet Depth lTVO)... IN *n g... Grea, Top Head SURFACE 95+6 8.92 35.0 3,061.0 2,9]3.3 36.011 JSS BTC coNW mDR:3ann6n Casing Description Dp lin) ID inTop (XKB) Bet Depth IXNB) set Depth lTVp).., wuLen D- ..do Top Hanan PRODUCTION ] 6.28 35.0 6,631.0 6,0867 2600 J-55 BTC Tubing Strings SAFETIVIV, 1.e m6ing Ixa=rpgen TUBING 3.5x2875'@64 string Ma... 2118 ID Pn) 244 Top lnxel 308 sm Depth (X.. 6,2404 set Darm RvDI ( 5,1312 wymn0 650 Crean 1 I Top conneemo EUCTUARM00 Completion Details GASDFT:zsfiae To AI Top loaf Nominal ,up (-he) 1XNB1 (°) Imm Des Co. 1. (in) 30.8 30.8 0.06 HANGER MCEVOYT vinnin picuR 3.500 54.2 64.2 0.12 XO Reducing CROSSOVER 3.5 K 2.875 2.875 1,821.1 1,a19.6 3.56 SAFETY VLV CAMCO TRDP-1q-SSP, SAFETY VALVE 2.312 6,149.11 5,650.2 26.90 PER CAMCO OEJ PSR 2,312 6,1565 5,665.6 26.91 PACKER CAMCO HEP -I -SP PgCKER 5.927 BDEFACE he 6232,0 6,2320 5,124.2 21 NIPPLE -a- NO GO 2.250 5,239.7 5,731.1 2701 SOS CAMCO PE -500 SHEAR OUT SUB 2,441 Gns un, am4.x Other In Hole (Wireline retrievable plugs, Valves, pumps, fish, etc.) "Pi"Do TOPmcI add.FT4.01 T,LODI 4,545.0 (XNG) 4,243.1 1°) 29.63 Des UPRPACKER (ME)eel Co. 771V UPPER P2P SPACER PIPE B ANCHOR LATCH, SIN CPP287044/CPAL287021, OAL 30.86' Run Da+e BOWELS to (in) 1.375 SPACER PIPE UPRPACKERIMEWOSPACER4,545.0 PP1;4,ufio 4,243.9 29.63 SPACERPIPE OR 2-1116P-110 SPACER PIPE w'ANCHOR LATCH 9/1212019 1.600 LATCHAJANC LATCH TER11IFEWADSB.a SPA"al"GECAN4" 4-5-5804,254A 29.61 TUBING LEAK TUBING LEAK IDENTIFIED wI RELAY LOL 95/2019 2441 LATDx;4,51E6 .A PACKER (.It 4s 0 4,95.0 4269.1 29.58 LWRPACKER (ME) 2-7/1 P2P, SN: CPP287000, OAL 355' 911112p19 1.375 4.620.0 4,308.3 29.53 UPRPACKER (ME)w/ 2-]l8'UPPER P2P w/SPACER PIPE&ANCHOR LATCH, SN: CPP287039ICPAL267025, OAL 16.82' 911112019 1.3]5 UPR PRUNER IME) W sPALER SPACER PIPE PwE4,aR0.a BPAc."FeaeANCHOR 4,621.0 43092 29.53 SPACER PIPE WIANCHOR 2-1116'P-110 SPACER PIPE OANCHOR LATCH 911112019 1.600 +ATCH:4.6a+.o LATCH Tu61rvD LEAN; a.6md 4,629.0 4,316.1 29.53 TUBING -LEAK TUBING LEAK IDENTIED wI RELAV OBD HOLE 91112019 2.441 FINDER Gets PACKER IMEµ 4.6lea 4,6380 4,324.0 29.52 (ME) LWRPACKER LOWERSN, Cp,28703E. OAL 6 9/192019 1.315 . U,T:5f050 Perforations &Slots SIO Oen G45 LIFT: B]<9< Tep(M) merrep) Top (XNB) Blm (flN0) (XKB) (XKB) Linked Zane (sho+vYl Data I Typa Lom 6,301 5,3280 5,791.9 5,609.7 G4,g3, GRev 919/2005 6.0 RUPEE 2-lAE PSE, 45 deg phase GASLIR:6+a]S 6,339.0 8,318.0 5,11193 5,6542 q -2,3G-02 111211991 4.0 /PERF 14 Lip Expendable Mandrel Inserts Sit On PBR: 6, 1480 EAUNER:9,ma6 on TopIND) vena Lam Pnrt sire TRp Rnn 'y Top (XNB) (Rest Make Moda Op lint ., Typa Type lin) (pad) Run Date Com 1 2,3308 2,323.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,245.0 2/1-712009 2 3,814.2 3,610.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1 247 2/142009 3 4,498.2 4,202.4 MERLA TMPD 1 GAS LIFT OV BK 11.186 0.0 9/2/2019 EXT PeoDL'CTlox; e.fws PKG 4 5,1856 4,801.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1112/1991 5 5.]49.4 5,294.1 Ml TMPD 1 GAS LIEr DMV BK 0.000 0.01/1211991 NIppLE:83]30 6 6,103.5 5,6096 MERLA TGPD 11/2 GAS LIFT DM' RK 0.000 0.0 41511996 7 6,190.5 5661.2 MERLA TGPD 112 PROD DMV RK 0.000 00 111211991 01 & Sa#ety. - spB.aza] and Data. Annolalon 2/1812009 NOTE: DMYVLV � GLM N4 HAS POSSIBLE STRIPPED FISHING NECK, "00 NOT PULL' 81212m0 NOTE: View SMematicw/Alaska SMamatic90 &/232019 NOTE: Haary&ERaiic WegM1l Swings(POss. Cprkscrewetl)Use Slinky Toolslring APERF; 6,3C&pg,33B0- IPEPF; 6.]38.p8.37B0- ERW ACTION; Ilde.63].0 Date 3G-02 DESCRIPTION OF WORK COMPLETED After a failing TIFL, two tubing leaks were identified in 3G-02 and repaired by installing 2 through tubing patches. The integrity of the patches was confirmed with a passing TIFL 9/15119. 08/14/19 (AC-EVAL) SI TIFL (FAILED DUE TO IN -FLOW AND PRESSURE INCREASE) 09/09/19 09/11/19 09/12/19 09/15/19 RAN LDL f/ CAT SV @ 6232' RKB TO SURFACE, IDENTIFIED LEAK POINT @ 4558' RKB, NO OTHER LEAKS IDENTIFIED. LRS PERFORMED CIRC OUT THROUGH LEAK POINT. PERFORMED CMIT- T x IA TO 2500 PSI **PASS**. PULLED 2.25 CAT STANDING VLV @ 6232' RKB, BRUSH n' FLUSH PATCH AREA FROM 4600' TO 4500' RKB, DRIFT TBG W/ DUMMY 30'x 2.27". RAN 2 7/8 SLIP STOP HOLE FINDER W/ CCL, FROM 4748' RKB (ME) TEST EVERY 4' GOOD NARROW DOWN LEAK TO —4629' RKB GOOD COMBO TEST @ 4633' RKB MOVE UP TO 4627' RKB (ME) TEST FAILED, SET LOWER 2.29" P2P @ 4638' RKB (OAL 3.56'). CMIT- T x IA TO 2500 PSI w/ TTS TEST TOOL SET IN P2P @ SAME **PASS**. SET UPPER 2.29" P2P PATCH ASSEMBLY @ 4620' RKB (18.82' OAL). CMIT- T x IA TO 2500 PSI w/ TTS TEST TOOL SET IN P2P @ SAME **PASS**. SET LOWER 2.29" P2P @ 4575' RKB (OAL 3.55'). CMIT- T x IA TO 2500 PSI w/ TTS TEST TOOL SET IN P2P @ SAME, CMIT T x IA PASS, PULLED TTS TEST TOOL @ 4575' RKB. SET 2.29" P2P SPACER ANCHOR LATCH @ 4545' RKB (ME), SET 2 7/8 TTS TEST TOOL @ SAME, MIT TBG 2500 PASS, CMIT TBG x IA 2500 PASS. PULLED 2 7/8 TTS TEST TOOL @ 4545' RKB. COMPLETE. Initial T/I/O = 150/900/230. IA FL @ 4498' St # 3 OV SI the WV and double blocked the AL line. Stacked the T x IA to T/I/O = SI 800/800/200 in 30 min. IA FL @ Same location Bled the AL line. Bled the IA to 360 psi in 45 min. IA FL @ Same location Start T/I/O = SI 900/360/130 15 min T/I/O = SI 910/360/120 30 min T/I/O = SI 930/360/100. IA FL @ Same location 45 min T/I/O = SI 940/360/100 60 min T/I/O = SI 940/360/100. IA FL @ Same location Final T/I/O = SI 940/360/100 • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ,~~,. ~ ~IA~ ~ ~ ~~~,~~ ~~ Dear Mr. Maunder: -~ 3~ ~ ~-- ~- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15~" 2009. The corrosion inhibitor/sealant was pumped March 10~' and 11~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~' - / ,,..- r.~ /~° ,-1 ~ .--~''~ / i~ / M.J. Ioveland ConocoPhillips Well Integrity Projects Supervisor ~J • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 KRU 3G-02 (PTD# 190-137) R~ Of TxIA Communication . Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, January 30, 2009 10:18 AM ~ ~ ~~3~d~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ` '~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Poletzky, Isabel C Subject: KRU 3G-02 (PTD# 190-137) Report Of TxIA Communication Attachments: 3G-02 Wellbore Schematic.pdf; 3G-02 TIO Plot.ppt Tom/Jim, Kuparuk gaslifted producer 3G-02 (PTD# 190-137) is suspected of having TxIA communication based upon a failed TIFL on 1/28/09. A leakina aaslift valve is the likely, cause so initially, slickline will troubleshoot and repair if possible. The well will be added to the SCP report and will be fixed or shut in by 02/25/09. Attached is a Wellbore schematic and 90 day TIO plot. «3G-02 Wellbore Schematic.pdf» «3G-02 TIO Plot.ppt» ./ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4~fi..A~y Y L~r ~i~{W~ ij ~.+`\ ~(~ {~ L. 4~44~ 6/23/2009 dwa~a~oy~ 0 0 0 o ~n o N .-- ~ ~ _.-1 V ~ ~ v O f/1 = L V .~ ~ i O ,O ~ _ L ` 7 0 N O M O a O a Q 0 Q °o °o - ~,r~ o ISd 0 0 O I O 0 m D 0 0 0 0 Z 0 ~°o~ o D ConocoPhillips~~' °° Well Conr -3G-02 tY a Sc emarw~ - -.__ ~.. ` `s I f i CONDUCTOR, ~ - 11s t SAFETY VLV, `pJ 1sz1 t v i _ OAS LIFT, ~ L ~~ 2,331 ~ ~' I ' SURFACE, i f 3,061 Fi ~ GAS LIFT, f A ~ ?A 3,814 Fk rlf `J 1 •~ GAS LIFT, C ~q 4,496 -Y ''. -~ GAS LIFT, ~ ~.p 5,186 ~ ~1 .~ t ~' w GAS LIFT, 5.749 ,r ~ 3G-02 KUP e _T _ Well Attributes IMax Angle R MD STD III r, .~~i'U1YI Field Name Well Status f rodllnJ Type Incl (°) MD (Itktl) Act Btm (ftKB) 7 ~ i 4600 KUPARUK RIVER UNIT PROD 33.39 3,500.00 6,659.0 1eM H2S (ppm) Date Annotation End Data KB13rd (ft) Rig Release Date _ _ _ L TRDP 120 7/112008 Last WO: 36.39 10/24/1990 --- - ~r-„ Depth (ftKB) End Date Annotation End Date ___ ~:,.I -LM 6.350.0 1/23/2009 Rev Reason: TAG FILL 1/24/2009 - - - - Casing Strings String OD ' String ID Set Depth Set Depth (ND~ String WtWt sui„a =.uing Deacrlptlon lint hn) Top (ftKB) (ftKB) (ftKB) hbs/rt) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 SURFACE 95/8 8.765 0.0 3,061.0 2,973.3 36.00 J-55 PRODUCTION 7 6.151 0.0 6,637.0 6,084.7 26.00 J-55 ~ - Tubing Strings __ - T __ _ String OD Stnng lU Set Depth Set rxpth (ND) String Wt String Tubing Description (Inl Pn) Top (ftKB) (ftKB) (ttK8) (IbeRt) Gratle Strln To Thrd TUBING 3 1/2 2.992 0.0 64.0 64.0 9.30 J-55 EUE8rdABMOC TUBING 27/8 2.441 64.0 6,240.0 5,731.4 6.50 L-80 EUESrdABMOC ` - -- - Other in Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) __ - r N oepw (ND) lop Incl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in 1,821.0 1,819.4 3.58 SAFETY VLV Camco TRDP-IA-SSA' 1/12/1991 2.31 2,331.0 2,323.6 16.49 GAS LIFT MERLA/TMPD/1/GLVBW.188/1300/Comment: STA 1 4/15/1998 2.87 3,814.0 3.610.5 30.51 GAS LIFT MERLA/TMPD/1/GLV/BW25/1409/Comment: STA2 4/15/1998 2.87 4,498.0 4,202.2 29.71 GAS LIFT MERLA/iMPD/1/OVBW.25//Comment: STA3 4/1511998 2.Si 5,186.0 4,802.2 29.08 GAS LIFT MERLA/TMPD/1/DMVBW//Comment: STA4 1/12/1991 2.87 5,749.0 5,293.8 27.55 GAS LIFT MERLA/TMPD/1/DMYBW//Comment: STAS 1112/1991 2.87 6,103.0 5,609.2 26.86 GAS LIFT MERLA/rGPD/1.5/DMY/F?W//Comment: STAG 4/5/1998 2.87 6,149.0 5,650.2 26.90 PBR Camco'OEJ' PBR 1/12/1991 2.31 6,167.0 5,666.3 26.91 PACKER Camco'HRP-I-SP'PACKER 1/12/1991 2.34 6,190.0 5,686.8 26.93 PRODUCTION MERLA/iGPD/1.5/DMY/RK7/!/Comment: CLOSED STA7 1/12/1991 2.87 6,232.0 5,724.3 27.22 NIPPLE Camco'D' Nipple NO GO 1/12/1991 2.25 6,239.0 5,730.5 27.21 SOS Camco PE-500 1/12/1991 2.44 6,240.0 5,731.4 -- - 27.20 TTL - _____. _ 1/12/1991 2.44 Perfora tions _, _ _____ -- --- -- shoe Top (ND) Btm (ND) Dens Top (ftKB) Btm ftKB (ftKB) (ftKB) Zone Date (sh°• Type CommaM 6,308.0 6,328.0 5,791.9 5,809.7 C -0, A-3, 3G-02 9/9/2005 6.0 APERF 2-1/8" PSE, 45 deg phase 6,339.0 6,378.0 5,819.5 5,8542 A -2, 3G-02 1/12/1991 4.0 IPERF 4 1/2" Expendable _I _ i _ PBR, 6,149 t 1 1 -~ r~T PACKER, 6,167 u6 ~' ~"~ C l k' _~ PRODUCTION. I ~`~ 6,190 --- L~„ w i h NIPPLE, 6,232 F\ SOS, 6,239 1 ~ _1 L ~ 4 TTL, 6,240 ~ 7 L JI APERF, , 6,308-6,328 IPERF, , 6,339-6,378 PRODUCTION, 6,637 TD, 6.659 10/31/05 Schlumberger NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 SCANNED NO\! 2 ~ 2D05 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk - Well Job# Log Description Date BL Color CD 1 R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1 A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 ____3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 ~ 2C-04 11022934 INJECTION PROFILE 10/14/05 1 '~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10/26/05 1 1 R-1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1 J-154 11022931 USIT 10/12/05 1 2F-03 ¿I::Q INJECTION PROFILE 10/31/05 1 I SIGNED: fj~ DATE: \ g IV ~\J ~\- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 q;t\- -t1 7 e e Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 20,2005 I?I2Cr:::- Sf? c:IVI2D A/'lck, 0/7 2 6 2005 & Gas C. An ,L 0/18. Co . Cl/oraUe 'I11n118$i0I1 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3G-02 (APD # 190-137) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 3G-02. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, A.j¡(~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells SCANNED NOV 0 9 2005 MM/skad e e RECEIVED SEP 2 6 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 AlaskëPffiTr& Gas Cdn.. CommilJion Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Exten*tth&1ge Change Approved Program 0 Operat. ShutdownD Perforate Q Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill,N~r:, ConocoPhillips Alaska, Inc. Development Q Exploratory 0 ....'#1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20146-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 3G-02 8. Property Designation: 10. Field/Pool(s): ADL 25547, ALK 2661 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6659' feet true vertical 6104' feet Plugs (measured) Effective Depth measured 6324' feet Junk (measured) true vertical 5806' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SUR. CASING 3021' 9-5/8" 3061' 2973' PROD. CASING 6597' 7" 6637' 6085' Perforation depth: Measured depth: 6308' - 6328',6339'-6378' true vertical depth: 5792'-5810',5820'-5854' Tubing (size, grade, and measured depth) 3.5" 12-7/8", J-55 ' L-80, 64' 16240' MD. Packers & SSSV (type & measured depth) pkr- CAMCO 'HRP-1-SP' pkr- 6167' . ._. ~""-' SSSV= Cameo 'TRDP-1A-SSA' SSSV= 1821' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS BFL SEP 2 8 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubina Pressure Prior to well operation 197 557 812 -- 222 Subsequent to operation 353 1118 1156 - 213 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development Q Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name d Mooney Title Wells Group Team Leader ¡ Signature , JI! ~. ^ Phone Date Cj /Z 3.. 05 PreooreJLbv Sharon AI/sun-Drake 263-4612 ~ 1\ t ". Form 1 0-404 Revised 04/2004 ¡AL Submit Original Only e 3G-02 Well Events Summary e Date Summary 09/09/05 PERFORATED 6308' - 6328' WITH 21/8" POWER SPIRAL ENERJET THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M E E L E W A T E R IA L U N D ER T I-I IS M ARK ER · '~-~- STATE OF ALASKA .... ALA,' . OIL AND GAS CONSERVATION COMF,. _:;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development ~ 90' RKB, 53' Pa¢ 3. Address: Exploratory__, 7. Unit or Property: P.O. Box 100360 Stratagrapic ___, Anchorage, AK 99510q3360 Service ___, Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 345' FWL, Sec 24, T12N, R8E, UM 3G-02 At top of productive interval: 9. Permit number/approval number: 1640' FNL, 1490' FEL, Sec 23, T12N, R8E, UM 90-137 At effective depth: 10. APl number: 1552' FNL, 1537' FEL, Sec 23, T12N, R8E, UM 50-103-20146-00 At total depth: 11. Field/Pool: 1550' FNL, 1540' FEL, Sec 23, T12N, RSE, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 6659 feet Plugs (measured) None true vertical 6104 feet Effective Deptl measured 6651 feet Junk (measured) None true vertical 6097 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 243 Sx AS I 121' 121' Surface 3026' 9-5/8" 700 Sx AS III & 3061' 3060' 400 Sx Class G Production 6602' 7" 160 Sx AS III 6637' 5913' Uner Perforation Depth measured 6339'-6378' true vertical 5820'-5854' Tubing (size, grade, and measured depth) .' 3.5", 9.3 Ib/ft, J-55 @ 64' & 2.875", 6.5 lb/fi, L-80 @ 64'-6240' Packers and SSSV (type and measured depth) ' Packer: Camco HRP-1-SP @ 6167'; SSSV: Camco TRDP-1A-SSA @ 1821' ,:~ . 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 4/7/98. Intervals treated (measured) 6339'-6378' Treatment description including volumes used and final pressure Pumped 263,075 lbs of 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 6504 p~t.' 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 341 22 222 1145 167 Subsequent to operation 937 815 1322 1166 165 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~//~1 -- Title: Pr°ducti°n Engineering Supervis°r Date ~//~'d/~ cL Form 1 0-404 Rev CI6/q 5,, .~ IRMIT lid r'311pl I¢"ATI::~-. ARCO Alaska, I~c. , ~_.. KUPARUK RIVEI~ UNII- A K1(3G-02(w4-6)) WELL JOB SCOPE JOB NUMBER 3G-O2 FRAC, FRAC SUPPORT 0403981055.5 DATE DALLY WORK UNIT NUMBER 04/07/98 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~) Yes O No DS-GALLEGOS JOHNS FIELD AFC# CC# DALLY COST ACCUM COST Signe~/~ ~ ~ ESTIMATE KD1984 230DS36G L $151,100 $160,273 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ail'fl I Final O t[i,~ Ann 1111 PSI 1700PSI 500 psi 500 PSII 0PSII - 0PSI DALLY SUMMARY I PUMPED "A" SANDS REFRAC THRU FLUSH ' PLACED 263'075# PROPPANT. TO 10/14 AT 13 PPA AT PERFS. TIME LOG ENTRY 08:30 MIRU DOWELL FRAC; HOTOIL PUMP AND APC SUPPORT. 11:00 HELD ON SITE SAFETY MEETING, JOB PROCEDURE AND EMERGENCY ACTIONS. 11:10 PRESSURE TEST SURFACE EQUIP. TO 10,200 PSI. STARTING WHP 1111 PSI. 11:20 PUMPED BREAKDOWN WITH 100 BBLS 50# GEL, 25 BPM AND 7976 TO 5100 PSI. PUMPED I PPA W/2000 # 20/40 AND FLUSH . PUMPED 2PPA W/3860# 20/40 AND FLUSHED. PUMPED OVER DISPLACE W/STRIAGHT SEAWATER. 72 BBLS AT 5879 PSI. 11:44 SHUT DOWN ISIP 1977 PSI. 12:24 PUMPED DATA FRAC, 5 TO 15 BPM AND FLUSH. 5983 PSI. SHUTDOWN FOR ISIP 2045 PSI AND CLOSURE CALCULATIONS. 13:29 PUMPED 450 BBLS PAD OF 50 # GEL AT 5 TO 15 BPM AND 4302 PSI. 14:05 START PUMPING PROP. (7719# 20/40) 15 BPM 2PPA AND 4362 PSI. 14:11 PUMPED 239,416# 12/18 PROP. 6 PPA TO 11.5 PPA, 15 BPM AND 4252 PSI. 15:32 PUMPED 11,117# 10/14 PROP TO 13.5 PPA, 15 BPM AND 6504 PSI. FLUSHED WITH 37 BBLS, LAST 17 BBLS DIESEL. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $740.00 -APC $7,700.00 $7,700.00 ARCO $500.00 $500.00 -~)OWELL $141,000.00 $141,000.001 HALLIBURTON $0.00 $4,833.00 LITTLE RED $1,900.00 $5,500.00 TOTAL FIELD ESTIMATE $151,100.00 $160,273.00 ALA~r,,A OIL AND GAS CONSERVATION COM,~,~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classifica~on of Service Well OIL ~ GAS l--"1 SUSPENDED [~ ABANDONED [--1 SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-137 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20146 4 Location of well at surface :. ,.,'... ,.,? ,:,'~;,: ~' 'i'1i' LOCATIONS r 9 Unitor Lease Name 2538' FNL, 345' FWL, SEC 24, T12N, R8E, UM / AtTop Producing Interval ~ /,///'~./_~ t / YERiFh~'D / KUPARUK RIVER ~. ........... ~_2. ~ 11 Field and Pool 1550' FNL, 1540' FEL, SEC 23, T12N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'J ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore J16 No. of Completions 10/18/90. 10/21/90. 1/12/91. NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6659' MD, 6104' TVD 6651' MD, 6097' TVD YES I'~ NO E~ 1821' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER F'I'. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 243 SX AS I 9-5/8' 36~ J-55 SURF 3061' 12-1/4" 700 SX AS III, 400 SX CLASS G 7" 26# J-55 SURF 6637' 8-1/2' 160 SX CLASS G .,~ 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) ipACKER SET (MD) 2-7/8" 6240' 6167' 6339'-6378' W/4-1/2" CSG GUN @ 4SPF MD 5820'-5854' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 6306' 5790' NA KUPARUK C BOTTOM 6320' 5802' KUPARUK A TOP 6320' 5803' KUPARUK A Bo'FrOM 6428' 5899' 31. LIST OF A-I-rACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion repod 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 pedinent 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 Well History - Initial Report - Dail~ Instructions: 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 County, parish or borough IState Field ARCO ALASKA INC. NORTH SLOPE I AK JWe~l Lease or Unit no. KUPARUK RIVER FIELD ADL:25547 ALK:2661 3G~2 ITitle J COMPLETION Auth. or W.O. no. AK5121 Operator ARCO W I. ARCO 55. 252072 Spudded or W.O. begun IDate IHour Pr or status it a W.O. SPUD J 10/18/90 I 14: 00 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 01/12/91 ( TD: 0 PB: 0 SUPV: JMM RD HLS E-LINE MW:10.6 NaC1/Br MOVE RIG FROM 3G-15 TO 3G-02, STEAM HEAT WLL SEAL FLANGE AND VLAVE, ND MASTER, NU BOPE, LEVEL RIG, MU CHOKE LINE, MU TEST PLUG AND SET, RU HLS, MU GUN #1, RIH AND PERF: 6359'-6378', MU GUN #2, RIH AND PEP. F: 6339'-6359', RIG DOWN HLS E-LINE DAILY:S20,200 CUM:$613,653 ETD:S613,653 EFC:$1,190,400 The above is correct Signature /~ ~ For form preparation a.l~d'~stribution, ~ see Procedures Manu{~l,/Section 10, Drilling, Pages 86 and~"/. Date ITM $opt, AR3B-459-1-D Number all daily well history Iorms consecutively as they are prepared for each well. ARCO L,., 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 et time. On workovers when an o~/~ciaJ test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the entire operation if space is available. I Accounting cost center code District /State ARCO ALASKA INC. J AK County or Parish NORTH SLOPE ILease or Unit ADL: 25547 ALK: 2661 ITitle COMPLETION Well no. 3G~2 Iotal number of wells (active or inactive) on this~ est center prior to plugging and / bandonment of this well 55.1252072 our Prior status if a W.O. 14:00 KUPARUK RIVER FIELD Auth. or W.O. no. AK5121 Operator I! AR.Co. W.I. I ARCO Spudded or W.O. begun Date SPUD 10/18/90 Date and depth Complete record for each day reported as of 8:00 a.m. NORD'I C 1 01/13/91 ( TD: 0 PB: 6651 SUPV:GB/SK 7) RIG RELEASED MW:10.6 NaC1/Br RD HLS E-LINE, NU FLOW LINE, LOAD PIPE SHED W/ 2-7/8" TBG, STRAP AND TALLY, MU AND RUN 2-7/8" COMPLETION ASSEMBLY, TEST SSSV CONTROL LINE TO 5000PSI, DROP SHEAR OUT BALL, LAND TBG, RILDS, SET PACKER AT 2500 PSI, TEST 15 MIN (OK) PRESS ANN TO 1000 PSI (OK), BLEED OFF PRESS, BOLDS, PRESS TBG TO 1000 PSI PU SHEAR OEJ, BLEED PRESS, RELAND TBG, RILDS, PRESS TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI, TST SSSV (OK), EQUALIZE PRESS, OPEN SSSV, BLEED OFF PRESS, PULL LANDING JT, SET BPV, ND BOPE, NU TREE TEST (OK), PRESS ANN TO 2500 PSI (OK), PRESS TBG AND SHEAR SOS, DISPLACE WELL WITH 450' DIESEL DAILY:S144,941 CUM:$758,594 ETD:S758,594 EFC:$1,190,400 Old TD Released rig INew TD ] PB Depth Date Kind of rig I Type completion (single, dual, etc.) Official reservoir name(s) Classifications (oil, gas, etc.) Producing method Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effec:ive ~a'.e corrected The above is correct . For form preparation and {~tri~ution, ~-~ ~'///~' ~ j Drilling Supt. see Procedures Manual. S~;..tion 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Division of AtlantlcR,chheldCompany O[{IGIN L A GYRODATA DIRECTIONAL SURVEY FOR ARCO ALASKA INCORPORATED kiUPARUkl RIVER UNIT, WELL NUHBER 3G-2 NORTH SLOPE BOROUGH, ALASKA. DATE : 06 DECENBER 1990 GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: S', MEAS C~ DEPTH :, 1,00 '" 2'00 ~"' 3:00 40'0 500 ,, 7 600 7 700 7 800 7 900 7 1000 DIRECTIONAL DRILLING, 7 1100 7 1200 7 1300 7 1400 7 1500 ARCO ALASKA, INC. KUPARUK RIVER UNIT KRU 3G-2 N,63.92,W ROB SHOUP INCLN VERTICAL-DEPTHS ANGLE BKB SUB-SEA 0.19 100.0 10.0 0.26 200.0 110.0 0.29 300.0 210.0 0.56 400.0 310.0 0.84 500.0 410.0 1.04 600.0 510.0 1.71 699.9 609.9 2.36 799.9 709.9 3.16 899.8 809.8 3.68 999.6 909.6 INC. SECTION DISTNCE for Gyrodata Services, 0.1 0.2 0.1 -0.3 -1.1 -2.3 -4.1 -6.9 -10.8 -15.6 3.70 1099.4 1009.4 -20.9 2.18 1199.2 1109.2 -24.7 2.40 1299.2 1209.2 -27.3 2.94 1399.1 1309.1 -30.3 3.48 1498.9 1408.9 -33.8 1598.7 1508.7 -37.6 1698.6 1608.6 -37.5 1798.5 1708.5 -33.7 1898.2 1808.2 -28.2 1998.0 1908.0 -21.9 2097.5 2007.5 -13.2 7/GYRO 7 1600 3.41 7 1700 2.39 7 1800 3.44 7 1900 4.03 7 2000 4.60 7 2100 6.47 RECORD OF SURVEY Inc. Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : 12/05/90 RADIUS OF CURVATURE 11/13/90 90.00 ft AKl190G250 50-103-20146 'Survey Codes: (KRU3G2G Bl.17) DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD N 7.68 W ~,i~-%/::'~-0.2 N 0.0 W N 29.85 E ,7~-~!':~"~' 0.5 N 0.1 E N 51.21 E ~i,~-! 0.9 N 0.4 E N 64.23 E ~::'~":~ 1.3 N 1.0 E N 71.20 E '~':'~'~ 1.8 N 2.1 E N 73.89 E ~y,,,V 2.3 N 3.7 E N 76.94 E "!,~,~:',.~: 2.9 N 6.0 E N 79.49 E "~'.'-.':! 3.6 N 9.5 E N 79.08 E .i. 4.5 N 14.2 E N 80.99 E ':'" 5.5 N 20.1 E N 81.23 E N 68.48 E N 65.17 E N 64.66 E N 66.37 E ').i.::~'. 6.5 N 26.4 E ""-""'"~. 7.8 N 31.4 E , , · 9.4 N 35.1 E 11.4 N 39.3 E 13.7 N 44.4 E - , N 62.90 E 16.3 N N 12.14 W ·.~'.~, 20.5 N N 31.93 Wi.,:~'.':~ 25.2 N N 31.65 W>..~:''~?'.''- 30.8 N N 31.34 W:,:'I~'~''~, 37.2 N N 45.23 W ": ~-~ 44.7 N 49.8 E 51.8 E 49.9 E 46.5 E 42.6 E 36.6 E CLOSURE DL DISTNCE BEARING /100 0.2 N 7.68 W 0.19 0.5 N 5.47 E 0.07 1.0 N 21.80 E 0.03 1.6 N 37.21 E 0.27 2.8 N 50.21 E 0.28 4.3 N 58.51 E 0.20 6.7 N 64.53 E 0.67 10.1 N 69.28 E 0.65 14.9 N 72.50 E 0.80 20.8 N 74.65 E 0.52 27.2 N 76.18 E 0.02 32.4 N 75.97 E 1.52 36 . 3 N 74 . 97 E 0 . 22 40.9 N 73.83 E 0.54 46.4 N 72.83 E 0.54 52.4 N 71.89 E 0.07 55.7 N 68.38 E 1.03 55.9 N 63.19 E 1.05 55.7 N 56.50 E 0.59 56.5 N 48.86 E 0.57 57.8 N 39.29 E 1.88 KRU 3G-2 S MEAS INCLN C DEPTH ANGLE 7 2200 10.52 7 2300 15.32 7 2400 19.08 7 2500 23.81 7 2600 25.38 7 2700 28.23 7 2800 29.16 7 2900 31.46 7 3000 32.03 7 3100 32.44 7 3200 32.81 7 3300 33.08 7 3400 33.09 7 3500 33.39 7 3600 31.46 7 3700 30.37 7 3800 30.39 7 3900 30.36 7 4000 30.19 7 4100 30.11 7 4200 30.04 7 4300 29.98 7 4400 29.92 7 4500 29.71 7 4600 29.54 7 4700 29.49 VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 2196.4 2106.4 1.3 2293.8 2203.8 23.6 2389.3 2299.3 53.1 2482.4 2392.4 89.4 2573.3 2483.3 130.8 2662.5 2572.5 175.6 2750.3 2660.3 223.5 2836.6 2746.6 273.8 2921.6 2831.6 326.4 3006.2 2916.2 379.7 3090.4 3000.4 433.7 3174.4 3084.4 488.0 3258.1 3168.1 542.6 3341.8 3251.8 597.4 3426.2 3336.2 651.1 3512.0 3422.0 702.4 3598.2 3508.2 752.9 3684.5 3594.5 803.5 3770.9 3680.9 853.9 3857.3 3767.3 904.1 3943.9 3853.9 954.1 4030.5 3940.5 1004.1 4117.1 4027.1 1054.0 4203.9 4113.9 1103.7 4290.8 4200.8 1153.2 4377.8 4287.8 1202.4 RECORD OF SURVEY DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD N 62.46 W~i'?'~'~'53.4 N 24.7 E N 65.77 W~1'~!'/'> 63.2 N 4.6 E N 69.77 W~· .... ,' 74.4 N 22.8 W N 70.92 Wc>~/,~V 86.6 N 57.2 W N 70.62 W-~?~i'?"i00.4 N 96.5 W N 68.87 W,I© f~'~'116.0 N 138.8 W N 68.59 W ,' 133.4 N 183.5 W N 66.22 W?~?'~I~?152.8 N 230.1 W N 65.49 W,?!:.I'I~I 174.3 N 278.1 W N 64.44 W~~I<,~,~196.9 N 326.4 W N 64.36 W?:':I':~,7/ 220.2 N 375.1 W N 63.82 W?~!!~,~''? 243.9 N 424.0 W N 64.18 W,?-':','~,?'~267.9 N 473.0 W N 64.45 W,:'""' "'~: 291.6 N 522.4 W N 63.89 W,:t!'~'i'~,'-'' 315.0 N 570.7 W N 61.07 W~:I?~338.7 N 616.3 W N 62.07 W,~"i,.362.8 N 660.7 W N 61.73 W~I!,~":'386.6 N 705.3 W N 62.19 W-;~',"~ 410.3 N 749.8 W N 61.64 W ~"'~433.9 N 794.1 W N 61.89 W::~.~,', 457.7 N 838.3 W N 62.26 W~:''~'. '"481.1 N 882.5 W N 62.38 W .: :'. ?, ~i,,'' 504.3 N 926.7 W N 62.57 W-'' 527.2 N 970.8 W N 62.68 W-~:':~'.'.:'/ 550.0 N 1014.7 W N 63.86 W~.'" 572.1 N 1058.7 W Page 2 12/05/90 CLOSURE D I STNCE BEARING 58.9 N 24.83 E 63.3 N 4.17 E 77.8 N 17.01 W 103.8 N 33.42 W 139.2 N 43.87 W 180.8 N 50.12 W 226.9 N 53.99 W 276.2 N 56.42 W 328.2 N 57.92 W 381.2 N 58.91 W 434.9 N 59.59 W 489.1 N 60.09 W 543.6 N 60.48 W 598.3 N 60.83 W 651.8 N 61.11 W 703.2 N 61.21 W 753.8 N 61.23 W 804.3 N 61.27 W 854.7 N 61.31 W 905.0 N 61.35 W 955.1 N 61.37 W 1005.1 N 61.40 W 1055.0 N 61.45 W 1104.7 N 61.49 W 1154.1 N 61.54 W 1203.4 N 61.61 W DL /1oo 4.09 4.81 3.78 4.73 1.57 2.88 0.93 2.39 0.61 0.51 0.37 0.31 0.11 0.31 1.94 1.31 0.26 0.09 0.21 0.16 0.09 0.11 0.07 0.22 0.17 0.29 ~Survey Codes: 7/GYRO KRU 3G-2 S MEAS INCLN C DEPTH ANGLE 7 4800 29.31 7 4900 29.14 7 5000 29.06 7 5100 29.14 7 5200 29.10 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD 4465.0 4375.0 1251.5 N ,63.84 4552.2 4462.2 1300.3 N 64.12 4639.6 4549.6 1349.0 N 63.63 4727.0 4637.0 1397.6 N 63.73 4814.3 4724.3 1446.3 N 63.85 7 5300 29.27 4901.7 4811.7 7 5400 29.45 4988.8. 4898.8 7 5500 29.71 5075.8 4985.8 7 5600 29.58 5162.7 5072.7 7 5700 28.02 5250.3 5160.3 7 5800 27.06 5339.0 5249.0 7 5900 26.89 5428.1 5338.1 7 6000 26.96 5517.3 5427.3 7 6100 26.86 5606.4 5516.4 7 6200 26.94 5695.6 5605.6 1495.0 1544;1 1593.4 1642.9 1691.0 1737.3 1782.6 1827.8 1873.1 1918.3 1963.8 2009.2 2054.7 2075.2 2127.5 7 6300 27.12 5784.7 5694.7 7 6400 26.98 5873.8 5783.8 7 6500 27.09 5962.8 5872.8 7 6545 27.30 6002.8 5912.8 X 6659 27.30 6104.2 6014.2 W · ~I~.:~593.8 N W~ l~, ,~!~¥ 615 · 2 N W''~- "'~':~ ~' '636 · 6 N W~ :"'~i'~'_-658 · 2 N 1102.8 W 1146.6 W 1190.3 W 1233.9 W 1277.5 W N 63.89 N 64.03 N 64.57 N 65.31 N 63.50 W~?'i!!~ i 701.1 N W,~.~:'!?,: "~,'~722.7 N W~:? '7,',." 744.1 N W?.*'"':' ' 765.0 N 1321.3 W 1365.4 W 1409.9 W 1454.7 W 1498.1 W N 61.41 N 61.82 N 62.34 N 62.58 N 62.99 W ~"'~807.2 N W ?':. i'I,' '" 828.8 N W'-"','"850.0 N W~I?,""~870.9 N W~:'i";',~" 891 . 6 N 1539.1 W 1579.0 W 1619.0'W 1659.1 W 1699.4 W N 62.98 N 62.77 N 63.00 N 61.96 N 61.96 W(-'?:',~".:'-:'912.2 N W;~ClT,~~ 933.0 N W/'; "':" 953.7 N W?':!'I''~963. 2 N W,; ';'~'~ 987o8 N 1739.9 W 1780.3 W 1820.8 W 1839.0 W 1885.2 W Page 3 12/05/90 CLOSURE DL DISTNCE BEARING /100 1252.4 N 61.70 W 0.18 1301.2 N 61.79 W 0.18 1349.8 N 61.86 W 0.14 1398.4 N 61.92 W 0.08 1447.1 N 61.99 W 0.05 1495.8 N 62.05 W 0.17 1544.8 N 62.11 W 0.18 1594.2 N 62.18 W 0.29 1643.6 N 62.26 W 0.22 1691.7 N 62.32 W 1.61 1737.9 N 62.32 W 1.05 1783.3 N 62.31 W 0.19 1828.6 N 62.30 W 0.13 1873.8 N 62.30 W 0.11 1919.1 N 62.32 W 0.12 1964.5 N 62.33 W 0.18 2010.0 N 62.34 W 0.15 2055.4 N 62.36 W 0.12 2076.0 N 62.36 W 0.67 2128.3 N 62.35 W 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-2 Page 4 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/05/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 0 90 0.17 100 190 0.25 200 290 0.29 300 390 0.53 400 490 0.81 500 590 1.02 600 690 1.64 700 790 2.30 800 890 3.08 900 990 3.63 1000 1091 3.70 1100 1191 2.32 1200 1291 2.38 1300 1391 2.89 1400 1491 3.43 1500 1591 3.42 1600 1691 2.48 1700 1792 3.35 1800 1892 3.98 1900 1992 4.55 2000 2092 6.33 2100 2194 10.26 2200 2296 15.13 2300 2401 19.11 2400 2508 23.94 TVD BKB DIFF CRRT BEARING MD-TVD VERT DIRECTION RELATIVE COORDINATES FROM WELL HEAD 90 0 0 N 7.68 W 0.13 N 0.02 W 190 0 0 N 26.10 E 0.50 N 0.03 E 290 0 0 N 49.07 E 0.87 N 0.32 E 390 0 0 N 62.93 E 1.26 N 0.90 E 490 0 0 N 70.50 E 1.72 N 1.98 E 590 0 0 N 73.62 E 2.21 N 3.51 E 690 0 0 N 76.64 E 2.79 N 5.72 E 790 0 0 N 79.24 E 3.51 N 9.09 E 890 0 0 N 79.12 E 4.38 N 13.69 E 990 0 0 N 80.81 E 5.42 N 19.48 E 1090 1 0 N 81.21 E 6.41 N 25.85 E 1190 1 0 N 69.66 E 7.70 N 31.05 E 1290 1 0 N 65.47 E 9.26 N 34.71 E 1390 1 0 N 64.71 E 11.19 N 38.86 E 1490 1 0 N 66.22 E 13.50 N 43.88 E 1590 1 0 N 63.20 E 16.05 N 49.34 E 1690 1 0 N 5.69 W 20.17 N 51.92 E 1790 2 0 N 30.25 W 24.79 N 50.17 E 1890 2 0 N 31.67 W 30.27 N 46.79 E 1990 2 0 N 31.36 W 36.64 N '42.89 E 2090 2 0 N 44.18 W 44.13 N 37.18 E 2190 4 1 N 61.34 W 52.84 N 25.73 E 2290 6 3 N 65.64 W 62.74 N 5.55 E 2390 11 5 N 69.78 W 74.43 N 22.97 W 2490 18 8 N 70.89 W 87.75 N 60.36 W 2500 2619 25.91 2590 29 10 N 70.30 W 103.04 N 104.03 W KRU 3G-2 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/05/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 2600 2731 28.52 2690 2700 2846 30.21 2790 2800 2963 31.82 2890 2900 3081 32.36 2990 3000 3199 32.81 3090 3100 3319 33.08 3190 3200 3438 33.20 3290 3300 3557 32.28 3390 3400 3674 30.65 3490 3500 3790 30.39 3590 3600 3906 30.35 3690 3700 4022 30.17 3790 3800 4138 30.08 3890 3900 4253 30.01 3990 4000 4369 29.94 4090 4100 4484 29.74 4190 4200 4599 29.54 4290 4300 4714 29.46 4390 4400 4829 29.26 4490 4500 4943 29.11 4590 4600 5058 29.11 4690 4700 5172 29.11 4790 4800 5287 29.25 4890 4900 5401 29.45 4990 5000 5516 29.69 5090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 41 13 N 68.78 W 121.32 N 152.60 W 56 15 N 67.51 W 141.85 N 204.53 W 73 17 N 65.76 W 166.16 N 260.16 W 91 18 N 64.64 W 192.44 N 317.15 W 109 19 N 64.36 W 220.04 N 374.81 W 129 19 N 63.89 W 248.41 N 433.13 W 148 19 N 64.28 W 276.90 N 491.78 W 167 19 N 64.13 W 305.11 N 550.48 W 184 17 N 61.79 W 332.51 N 604.89 W 200 16 N 61.97 W 360.52 N 656.46 W 216 16 N 61.76 W 388.12 N 708.16 W 232 16 N 62.07 W 415.50 N 759.66 W 248 16 N 61.73 W 442.92 N 810.81 W 263 16 N 62.09 W 470.17 N 861.82 W 279 15 N 62.34 W 497.02 N 912.86 W 294 15 N 62.54 W 523.59 N 963.75 W 309 15 N 62.68 W 549.76 N 1014.28 W 324 15 N 63.86 W 575.16 N 1064.86 W 339 15 N 63.92 W 599.95 N 1115.36 W 353 15 N 63.91 W 624.41 N 1165.54 W 368 14 N 63.69 W 649.04 N 1215.41 W 382 14 N 63.82 W 673.68 N 1265.38 W 397 15 N 63.88 W 698.26 N 1315.46 W 411 15 N 64.04 W 722.95 N 1365.98 W 426 15 N 64.69 W 747.54 N 1417.19 W 5100 5631 29.09 5190 441 15 N 64.74 W 771.50 N 1468.58 W KRU 3G-2 Page 6 12/05/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5200 5745 27.59 5290 5300 5857 26.96 5390 5400 5969 26.94 5490 5500 6082 26.88 5590 5600 6194 26.93 5690 455 14 N 62.56 W 795.32 N 1516.76 W 467 12 N 61.64 W 819.61 N 1561.96 W 479 12 N 62.18 W 843.52 N 1606.75 W 492 12 N 62.54 W 867.06 N 1651.76 W 504 12 N 62.96 W 890.29 N 1696.84 W 5700 6306 27.11 5790 5800 6418 27.00 5890 5900 6531 27.23 5990 6000 6643 27.30 6090 516 12 N 62.97 W 913.47 N 1742.29 W 528 12 N 62.81 W 936.75 N 1787.71 W 541 12 N 62.29 W 960.09 N 1833.19 W 553 13 N 61.96 W 984.33 N 1878.74 W KRU 3G-2 Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 12/05/90 MEAS INCLN ,VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING 1000 3.68 1000 910 -16 N 80.99 E 6 N 2000 4.60 1998 1908 -22 N 31.34 W 37 N 3000 32.03 2922 2832 326 N 65.49 W 174 N 4000 30.19 3771 3681 854 N 62.19 W 410 N 5000 29.06 4640 4550 1349 N 63.63 W 637 N CLOSURE DL/ FROM-WELLHEAD DIST BEARING 100 20 E 21 N 74.65 E 0.5 43 E 57 N 48.86 E 0.6 278 W 328 N 57.92 W 0.6 750 W 855 N 61.31 W 0.2 1190 W 1350 N 61.86 W 0.1 6000 26.96 5517 5427 1828 N 62.34 W 850 N 1619 W 1829 N 62.30 W 0.1 12/05/90 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-2 Section at: N,63.92,W Surveyor..: ROB SHOUP Computation...' RADIUS OF CURVATURE Survey Date...' 11/13/90 RKB Elevation.' 90.00 ft 3ob Number · AKl190G250 API Number · 50-103-20146 INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 345 EWL S24 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST 0 0.00 0 -90 3061 32.28 2973 2883 6306 27.11 5790 5700 6320 27.09 5802 5712 6320 27.09 5803 5713 DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 N 0.00 E 0 N 359 N 64.85 W 188 N 1966 N 62.97 W 913 N 1973 N 62.94 W 916 N 1973 N 62.94 W 916 N 0E 308 W 1742 W 1748 W 1748 W BASE KUPARUK A 7" CASING PROJECTED TD 6428 27.01 5899 5809 6637 27.30 6085 5995 6659 27.30 6104 6014 2022 N 62.83 W 2117 N 61.96 W 2127 N 61.96 W 939 N 983 N 988 N 1792 W 1876 W 1885 W <KB>O 350 700 i050 i400 i750 ~iO0 2450 280O 3150 3500 3850 420O 4550 4900 5250 5500 5950 6300 350 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 38-2 i Section at: N 63.92 W , , Der Scale.' I inch = 700 feet Drawn ' 12/05/90 Marker Identification MD TVD SECTN A) KB 0 0 -- B) PROJECTED TD 6659 6i04 . - , ,,~ l ... _ INCLN 0.00 .30 0 350 700 i050 i400 i750 2i00 a450 2BO0 3i50 3500 Section Departure ~arker Identification MO KB 0 PROJECTED TO 6659 PLAN VIEH ARCO ALASKA, INC. KRU 3G-2 CLOSURE .....: 212B ft N 62.35 DECLINATION.: 0.00 E SCALE · i inch = 400 feet DRAWN ' i2/05/90 t400 t200 t000 800 600 4OO 200 0 20O 4OO 6OO 800 t000 t400 22OO I i I i , 2000 tBO0 t600 I400 t200 t000 BOO 600 400 200 0 200 <- WEST ' EASI -> /!.UL'~L,L. L-~r'ULUt~I[..AL MA! r'H.I/IL.~ iNVENTORY LiST - /-~7' WELL NAME ,~"~ ,.~;:: -- ,,~ / ! /3 I,~ / CO. CONTACT /~z(::' ~ ' check off or list data as it is receiYed.fli cored inte~als core analysis i ~t received date for 407. if not reo. uircd list as NR d~ ditch intc~als digital data i INI Ikl NO. __/.-'-,2 I' i I ItlTC n],d' A lO Ii111 I Ll'-t V~&Lkl [to thc ~ ~-* footI i (:1' ir",A I I~' I s..) Idi~l, LL ARCO Alaska, Inc. Date: March 8, 1991 Transmittal #: 8030 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-24 1A-17 3G-23 3G-02 3G-15 Receipt Drilling Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation LOg Acoustic Cement Bond LOg 1 1-14-90 6603-9725 12-31-90 5400-8438 1 1-15-90 4200-7282 I 1-1 2-90 41 00-6545 State of Alaska Alaska 0ii & GasN;~t~. CommissiOn Anchotag~ ARCO Alaska, Inc. Date: February 8, 1991 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 8008 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 1 3 Pulse Echo Cement Evaluation Log 1 1 - 1 3 - 9 0 6 0 0 0 - 91 8 7 3 G- 02 Acoustic Cement Bond Log I 1 - 1 2 - 9 0 4 5 0 0 - 6 5 4 7 3G-13 Acoustic Cement Bond Log I 1 -1 3-90 5700-9200 3G-09 Acoustic Cement Bond Log I 0-4-90 5441 -1 0,1 95 Receipt Drilling Acknowledge: -- Date: State of Alaska NSK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,..%'SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 345 FWL,SEC 24,T12N,R8E,UM At top of productive interval 1640 Fnl, 1490' FEL, Sec. 23, T12N, R8E, UM At effective depth NA At total depth 1564'FNL, 1645' FEL, Sec. 23, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 6659 (approx) true vertical 6116 Effective depth: measured NA (approx) true vertical NA Operation Shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ (approx) (approx) Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) feet Plugs (measured) feet feet Junk (measured) feet Casing Length Size Structural Conductor 80' 1 6" Surface 3026 9 5/8" Intermediate Production 6602' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-2 9. Permit number 90-137 10. APl number 50-103-20146 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Cemented Measured depth True vertical depth (approx) 243 SX AS III 1 15' 1 15' 700 Sx AS III & 3061' 2971(approx) 400Sx Class G 160Sx AS III 6637' 1090'(approx) RECEIVED DEC - 4 199e Alaska 011 & Gas Cons. C0mmissio Anchorage 13. Attachments Description summary of proposal Detailed operation program BOP sketch 14. Estimated date for commencing operation January, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil X Gas __ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SiCned /7~(,//,J~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Date IConditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ S bse e Mechanical Integrity Test_ ~,pp~,%~r~ ~8~' require Returned ~the order of the Commission 10-//'-;q Commissioner JApproval No....., _ ,,_---- r / Form 10-403 Rev 06/15/88 ORIGINAL $1BNEO B~ LONNIE C. SMITH SUBMIT IN TRIPLICATE ARC. dil ,..,d Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial RelN3rt" 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 County. parish or borough IState ARCO ALASKA INC. I NORTH SLOPE J AK Field J Lease or Unit KUPARDK RIVER FIELD I ADL 25548 ALK 2661 Auth. or W.O. no. ITitle AK5121 J DRILLING Well no. Operator JARCO w I ARCO I 55.2521 Spudded or W.O. begun IDate IHour Prior stalus if a W.O. SPUD I 10/18/90I 14:00 Date and depth as of 8:00 a.m. 10/19/90 (1) TD: 2434'(2434) SUPV:JMM 10/20/90 (2) TD: 3084' ( 650) SUPV:JMM 10/21/90 (3) TD: 5031'(1947) SUPV:JMM 10/22/90 (4) TD: 6659' (1628) SUPV:JMM Complete record for each day reported DOYON 14 DRLG MW: 9.1 VIS: 83 MOVE RIG F/3G15-3G2, NIPPLE UP & TEST, SPUD @ 14:00 10/18/90 DRLG F/115-2434. DAILY:S76,351 CUM:$76,351 ETD:S76,351 EFC:$1,190,400 M/U BIT & BHA #2 MW: 9.5 VIS: 52 NAVIDRLG 12.25 HOLE 2434'-3084'. CIR, MAKE WIPER TRIP, CIR COND MUD. DROP SS SURVEY. POOH & RET SURVEY. L/D BHA,CLR FLR. R/U TO RUN 9-5/8 CSG. RUN 71 JTS CIRC & COND MUD, REDUCE YP. PMP 80 BBLS H20, 242 BBLS ASIII @12.1PPG, 83BBLS 400 SX @ 15.8. DISPLACE W/ 235BBLS H20 & BMP PLG W/ 2500PSI. FLUSH DIVERTER & VALVES OF CMT. NIPPLE & DIV LINES. M/U MCEVOY SPD HD N NIPPLE UP BOPE. TEST BOPE, ATTMPT TO RUN WEAR BSHNG, TOOL NOT FIT, INSTALL OVER HWDP. INSTALL BHA#2 DAILY:S177,400 CUM:$253,751 ETD:S253,751 EFC:$1,190,400 TURBODRLG @ 5031' MW: 9.6 VIS: 39 CNT BHA#2. RIH. DRILL FLT/CLR, CMT .5 SHOE JT, TEST CSG. DRILL 2ND 1/2 SHOE JT + 10' NEW FMTN, DSPL W/ H20. FMTN TEST TO 12.5 EMW. TEST GOOD. TURBODRILL TO 3106', TURBINE NOT TURNING, MIX N PMP SLUG. POOH TO CHK. STD BK BHA, RET RLL SOURCE, TEST N L/D TURBINE. P/U NEW TURBINE, M/U MOTOR N~P~-SECTS N TEST RIH W/ NEW TURBINE. SLIP N CUT 59.5 OF ~ LN. TURBODRLG 8.5 HOLE - 5031' ~:$85,164 CUM:$338,915 ETD:S338 915 EFC:$1,190 400 CIRc N COND MUD MW:10.5 VIS: 41 TUBBDRLG 8.5 HOLE F/5031'-6004'. CIRC. INTEGRITY TEST. CONTINUE TURBODRL~ TO 6659' (TD). CIRC BTTM UP, DROP SS SURVEY. POOH TO RET LOGS. L/D BHA, M/U BHA SERVICE RIG WHILE PROCESING LOGS. RIH F/ CLEANOUT TRIP. WASH N REAM TO 6659'. CIRC N COND HOLE N MUD. DAILY:S111,268 CUM:$450,183 ETD:S450,183 EFC:$1,190,400 RECEIVED DEC '- 4 1990 Alaska 0ii & Gas Cons. commiss~Or~ Anchorage The above isFg~'rect Signatur~~l~ ~ For form preparetio0/a~d ~is.tribution, ~ see Procedures Ma[lu,~, Section 10, Drilling, Pages 86 a'hd' 87. Date AR3B-459-1-D Number all daily well history torres consecutively as they are prepared for each well. iPage no. AR(. G. and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Fhlai Rel~3rt" 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 fn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC~ Field KUPARUK RIVER FIELD Auth. or W.O. no. AK5121 County or Parish NORTH SLOPE Lease or Unit Title ~[~)'r. 25547ALK 2661 DRILLING IAccounting cost center code Stale Well no. 3G-2 Operator A.R.Co. W.I. ARCO 55. 2523. Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 10/23/90 ( TD: 6659 PB: 0 SUPV:JMM 5) Date 10/18/90 Complete record for each day reported DOYON 14 I otal number of wells (active er inactive) on this os! center prior to plugging and bandonment of this well our I Prior status if a W.O. I 14:00 RELEASE RIG MW: 0.0 POOH LD DP, PULL WEAR RING, S&C DRILL LINE, RU & RUN 185 JTS 7", SHOE @ 6637', CIRC & COND MUD WHILE BATCH MIX CMT, CMT 7" W/160 SX CLASS G, CIP @ 20:30, ND BOPE, SET SLIPS, CUT 7" SB BOPE, INSTALL PO, NU TREE & TEST TO 3000PSI, RELEASE RIG @ 22:30 ON 10/22/90, MOVE TO 3G-22 DAILY:S143,270 CUM:$593,453 ETD:S593,453 EFC:$1,190,400 DEC -4 199~ Alaska Oil & Gas Cons, Commission Anchorage Old TO New TD PB Oeplh Released rig Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P. C.P. Water % CDR Gravity Allowable Elfective date corrected The above is correct sF~ 'l~rro~e~ruerPe~r~ia°nn a~sedic~:~nb%t~)°,n' ~///~.,'.,'.,'.,'.,'.,'~/F~ ~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. Page no. Divl,aon of AtlanllcRIchfleldCompany ARCO Alaska, Inc. Date: November, 1990 Transmittal #: 7942 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-22 3G-02 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return Receipt Acknowledged: Date: .......... DISTRIBUTION: Lynn Goettinger .~.~,~State'of ~,laska RECEIVED NOV 7 6 1~90 Alaska 011 & 13as Cons. CommisSion Anchorage October 10, 1990 Telecopy: (907)276-7542 A. Wayne McBride Area Drill~n ~ ~.g Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-02 A~-.CO Alaska, !nc. Pe~it Mo. 90-137 Sur. Loc. 2538'F~L, 345'~=, Sec. 24, T12N, RSE, Btmhole Loc !564'F~U~, !645'FEL, Sec °3, TlOM PgE Dear Mr. McBride: Enclosed is the approved applicmtion for permit to drill the above referenced well. ~e pemit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until a].l other required perm_itting determinations ar~ made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, ,::. /~,--. .. Co~issioner Alaska Oil and Gas Conse~ation Co~ission BY O~DER OF THE COI-R~ISSIOM d!f Enc to sure cc: Department of Fish & Game, ~tabitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,'~iON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90'. Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 345' FWL, Sec. 24, T12N, R8E, UM K¥0aruk River Unit At top of productive interval (TARGET) 8. Well number Number 1640' FNL, 1490' FEL, Sec. 23, T12N, R8E, UM 3G-02 #U630610 At total depth 9. Approximate spud date Amount 1564' FNL, 1645' FEL, Sec 23, T12N, R8E, UM 14-OCT-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-02 6694' MD 3635'@ TD feet 20' at 1140 feet 2560 6075' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 2060' feet Maximum hole angle 32° Maximum surface 1830 pslg At totaldepth (TVD) 3380 psicj @ 6075 18. Casing program Setting Depth size specification Top Bottom Quantity/ of cement Hole Casin~l Weight Grade Coupling! Length IVO TVD IVD TVD linclude stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625" 36.0# J-55 BTC 3113 35' 35' 3148 3090' 1360 Cu. Ft. AS III & HF-ERW 500 Cu. Ft. Class G 8.5 7" 26.0#1J-55 AB-MO[ 3333' 35' 35' 3368' 3275' 185Cu. Ft. ClassG 8.5 7" 26.0#IJ'55 BTC 3326' 3368' 3275 6694' 6075' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ ,., ,~ ~~ Conductor C~,.~. '(!i ~"~ ~ %~ F D Surface C~-~. !;~ i ~ ,=~- Intermediate " ~¥'¥~'"' '~ 'i ~;;r:~F.~,.-. Production - C',¢ F~ {..~ ~ ! ~.~{ Liner i ~ ~-~i~ Perforation depth: measured ....... ,'o-_. r*'r ~' O0[~[J~,iSSi ....... true vertical .... ;;':_-'-~i {~ii ;-~ ~<~;-~ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report ~20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~ Title Area Drilling En,ineer Date Commission Use Only Permit Number~o.../'/~,~.~ IAPl number 5 0-.,~'~ -- ~ (::~K,~ ~'/.~' I Approval cl~_t(~ / 10 /C~ 0~s~.~See c°ver letter f°r'N othero requirements Conditions of approval Samples required ~Y e s ~" N o Mud log required ~ Y Hydrogen sulfide measures~ Yes ..~ N o Directional survey required '~:~"Yes ~ N o by order of Approved by (_.~-.~.3....,,,~,.~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-02) Spud to 9-5/8" Drill out to surface casino weioht uD Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4- 8 APl Filtrate 10-1 2 8-10 pH 9-1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up 10.7 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: . Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1830 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-02 will be 3G-04. As designed, the minimum distance between the two wells would be 49' at 450' (MD). The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Inc, Pad 3G, Well No: Kupm~-uk Field, Nor'~.h P~'oposecl Slope, Al asea 0 - RKB ELEVATIONt gO' 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ . ? 000 B/ PERMAFROST TVD=1605 T/ UGNU SNDS TVD=l?80 KOP TVD=2060 TMD=2060 DEP=O 3 9 T/ 14 SAK SNDS TVD=2420 TMD=2422 DER=34 15 BUILD 3 DE9 PER 100 FT 21 8/ 14 SAK SNDS TVD=2890 TMD=2919 DEP--190 27 EOC / 9 5/8' CS9 PT TVD--3090 TMD=3148 DEP=302 K'~.tO T'V,D=3320 TMD=3421 DEP=449 AVERAGE ANGLE 32 DEG 39 MI N K-5 TVD=4720 TMD=5084 DEP=1346 ~TARgET - T/ ZONES C-A TVD=5807 TMD=6375 DEP=2043 B/ KUP SNDS TVD=5907 TMD=6494 DEP=2107 TD / LOG PT TVD=6075 TMD=6694 DEP=2215 i I 1000 2000 VERTICAL SECTION I 3000 300 250 20O 150 100 5O 5O 100 450 400 350 300 250 200 150 100 50 0 50 , I I I I I I I I ! I I 1 7O0 ,/ 1,500 "' 1 ;~00 I 300 25O J 200 11 oo j 1 50 "' :3,.1. 00 2100 - I ~ /17'00 j 1 O0 ' "" ~,9, ~ ! ' / oo , "~oo / / 900 1700 I~ . ~ 1 O0 I I I I I I I I I · 450 400 :350 300 250 200 1 50 1 O0 50 0 50 HOR I ZONT AL PROJECT I ON SCALE 1 IN. = 1000 FEET ARCO ALASKA. !ne. Pad 30, Well No' 2 Proposed Kuparuk FI · I d, No.th SI ope , TARGET TVD"5807 THD-6375 DEP-2043 NORTH 898 WEST 1835 TARGET LOCATTON' 1640' FNL, 1490' FEL SEC. 23, T12N, R8E TD LOCATION' 1564' FNL, 1645' FEL SEC. 23, T12N. R8E 2000 1000 1 000 2O00 3000 2000 ,I I N 6;~ 204:3' WEST-EAST 1000 I DEG 55 MI N W (TO TARGET) 0 1000 I I ~SURFACE / SURFACE LOCATION, 2538' FNL, 345' FWL SEC. 24, T12N. R8E GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 3GPAD · J 1 g w Si ., 8, · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed ii' there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. KjPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION , . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO lC' OUTLETS. 5. 117' HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE 2/6~J0 7 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X:X) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO3-1'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2(X)O PSI STARTING HEAD 2. 11" - 3(X:)0 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5(:X:)0 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 C~ECK LEST FOR NEW WELL PE~!ITS (1) Fee (2) Loc , ,, APPROVE DATE (14 thru 22) (23 thru 28) Company Lease & Well No. 1. Is the permit fee attached .......................................... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is we!! located proper distance from other wells ........ ; ........... 5. Is sufficient umdedica:ed acreage available in this pool ............ 6. Is well to be deviated and is we!lbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 10. 1!. 12.' 13. 14. 15. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... ts the lease number appropriate ..................................... Does =he well have a unique name amd number ......................... YES NO 16. 17. lB. t9. 20. 21. 22. 23. IS c6nduc=or string provided ........................................ WiLl surface casing protect all zones reasonably exoected to serve as am underground source of drinking wa=er ..................... //~ , , Is enough cement used to circulate on conductor amd surface ......... ~ Will cement tie in surface and intermediate or production strings . ..' /~f Will cement cover ~ kno~ra productive horizons ..................... /f~ Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an er. isting we!!bore ............. ., ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ..................... ...... /~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate //4' Are necessary diagrams and descriptions of diveruer and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOo psig .. Does :he choke manifold comply w/API EP-53 (May 84) .................. Is the presence of E2S gas probable ............................. ~... , 24. 25. 26. 27. 28. (6) (29 thru 31) rev: 01/30/89 6.011. · ~or 29. 30. 31. 32. expiorator7 and Stratigraphic wel!sr Are data presented on potential overpressure zones? ................. Are seismic analysis dana presented on shallow gas zones ............ If am offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL CLASS STATUS AREA NO. SHORE , ~ Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/11/02 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: FEWD DATE: 90/11/02 ORIGIN OF DATA: 3G-2 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED NOV 16 1990 Alaska Oil & Gas Cons. Commission Anchorage ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G2.MDW SERVICE NAME: FEWD VERSION #: V3.26 DATE: 90/11/02 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-2// API#: 50-103-20146// DATE: 21-0CT-90 LOCATION: 2538' FNL & 345' FWL, SEC. 23, TWP 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA// RIG: DOYON 14// SSDS ENG. KRELL & WESLEY// COMMENTS: >>>>>> NEUTRON AND DENSITY LOGS ARE CALIPER CORRECTED. NO TOOL WEAR COMPENSATION REQUIRED. LOGGING SENSORS DID NOT LEAVE CASING ON RUN 1. NUCLEAR LOG SAMPLE DENSITY WILL BE LESS THAN ONE SAMPLE PER FOOT WHERE ROP EXCEEDS 180 FT/HR. LOGS ARE NOT QUANTITATIVE IN SLIDE INTERVALS WHERE THE BHA IS NOT ROTATING. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 ! 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD GRC MWD NPSC MWD RHOB MWD CAL MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD FXE MWD DDE MWD ROP MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT EWR GRC NPSC RHOB CAL NFO NFl NN0 NN1 FXE DDE ROP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD FT OHMM API P.U. G/C3 INCH CTS CTS CTS CTS HOUR FT/H 68 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR GRC NPSC RHOB CAL NFl NN0 NN1 FXE DDE ROP 2950.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3100.000 5.413 90.297 40.204 531.000 2480.000 2576.000 7.208 3200.000 535.000 5.293 106.842 38.153 2520.000 2552.000 .494 3300.000 2.368 73.511 46.454 496.333 2450.667 2360.000 .499 3400.000 5.634 84.673 38.819 545.000 2504.000 2560.000 .516 3500.000 3.717 95.410 39.649 551.000 2488.000 2392.000 .609 3600.000 548.333 3.641 108.018 37.898 2530.667 2594.667 .563 3700.000 3.009 67.939 33.919 559.000 2808.000 2680.000 .442 3800.000 3.183 92.292 37.631 571.000 2568.000 2512.000 .491 3900.000 557.000 3.080 91.304 35.594 2680.000 2616.000 .567 4000.000 513.500 2.619 100.554 38.533 2528.000 2592.000 .509 4100.000 559.000 2.755 123.028 37.306 2584.000 2504.000 .722 4200.000 567.000 2.664 101.908 35.326 2664.000 2648.000 .597 4300.000 591.000 2.574 111.380 34.671 2632.000 2648.000 .616 4400.000 2.742 91.227 35.992 532.333 2722.667 2626.667 .704 4500.000 2.130 94.696 36.900 583.000 2568.000 2616.000 .556 4600.000 527.000 1.873 110.993 38.347 2509.333 2594.667 .490 4700.000 567.000 2.716 151.948 37.704 2408.000 2520.000 .669 4800.000 591.000 2.822 167.809 36.165 2514.667 2568.000 .506 -999.250 -999.250 -999.250 -999.250 2.223 .599 2.152 1.000 2.140 1.266 2.223 .666 2.279 1.053 2.262 1.206 2.283 .848 2.295 -999.250 2.330 .722 2.312 .787 2.489 1.961 2.253 1.923 2.368 1.058 2.243 1.613 2.272 t.137 2.333 4.167 2.358 3.333 2.284 1.010 -999.250 -999.250 -999.250 -999.250 8.961 96.532 9.126 110.820 9.096 246.789 8.943 260.156 8.911 444.266 8.915 252.363 9.043 100.001 8.909 531.864 8.910 314.575 8.919 313.623 8.907 349.165 8.890 205.664 8.902 134.505 8.937 256.758 8.988 142.788 8.911 303.223 8.924 256.055 9.039 222.001 NFO -999.250 -999.250 511.000 575.000 474.333 541.000 583.000 537.667 567.000 543.000 589.000 529.000 583.000 575.000 583.000 575.000 535.000 543.000 639.000 652.333 4900. 593. 5000. 599. O0O 667 000 000 2.612 129.734 2594.667 2520.000 2.649 105.276 2712.000 2648.000 36.385 2.356 8.977 .505 .980 256.289 34.065 2.402 8.914 .595 1.190 226.137 612.333 575.000 5100. 615. 5200. 599. 000 000 000 000 3.238 113.815 2544.000 2616.000 2.724 106.381 2648.000 2600.000 37.529 2.434 8.915 .499 1.000 349.645 34.027 2.441 9.193 .532 1.220 237.586 567.000 631.000 5300.000 615.000 2.376 110.105 2744.000 2696.000 32.318 2.409 8.911 .625 1.075 209.668 615.000 5400.000 579.000 3.040 110.407 2616.000 2704.000 34.511 2.421 8.985 .466 1.099 279.627 607.000 5500.000 591.000 3.727 95.568 2680.000 2637.333 34.534 2.468 8.917 .551 1.037 256.289 577.667 5600.000 567.000 2.822 122.442 2680.000 2656.000 31.910 2.618 9.133 .846 1.212 302.930 615.000 5700.000 615.000 2.835 95.783 2552.000 2632.000 34.775 2.299 8.908 .708 1.124 205.859 607.000 5800.0O0 599.000 5.503 88.180 2808.000 2776.000 31.269 2.431 8.977 .711 1.000 302.930 623.000 5900.000 589.000 3.531 100.423 2732.000 2728.000 33.050 2.511 9.049 .592 .959 236.865 615.000 6000.000 623.000 2.679 212.968 2360.000 2504.000 38.396 2.284 8.991 1.582 1.639 264.676 615.000 6100.000 711.000 2.771 225.248 2504.000 2520.000 32.907 2.379 8.983 .470 .1.333 320.361 751.000 6200.000 481.000 1.964 109.312 2360.000 2312.000 46.119 2.305 8.942 .985 4.762 191.694 503.000 6300.000 511.000 1.813 112.320 2280.000 2296.000 45.584 2.282 8.863 1.678 2.500 62.874 543.000 6400.000 571.000 5.647 83.673 2672.000 2752.000 35.324 2.395 8.858 1.032 2.083 137.194 559.000 6500.000 551.000 3.035 94.882 2712.000 2568.000 35.928 2.455 8.966 1.433 3.226 33.111 575.000 6600.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 101.172 -999.250 6700.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 398 DATA RECORDS ** FROM 2950.00 TO 6725.00 FT ** FILE TRAILER** FILE NAME: 3G2.MDW SERVICE NAME: FEWD VERSION #: V3.26 DATE: 90/11/02 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: FEWD DATE: 90/11/02 ORIGIN OF DATA: 3G-2 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/11/02 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********
