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Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-07A 50-029-20495-01 909619502 Kuparuk River Packer Setting Record Field- Final 20-Oct-24 0 12 1E-28A 50-029-20832-01 n/a Kuparuk River Packer Setting Record Field- Final 16-Jan-25 0 13 1F-08 50-029-20836-00 909737879 Kuparuk River Plug Setting Record Field- Final 3-Dec-24 0 14 1H-101 50-029-23585-00 909606936 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-24 0 15 1R-20 50-029-22207-00 909678505 Kuparuk River Packer Setting Record Field- Final 11-Nov-24 0 16 2A-16 50-103-20042-00 909780661 Kuparuk River Multi Finger Caliper Field & Processed 1-Jan-25 0 17 2C-03 50-029-20968-00 909740014 Kuparuk River Plug Setting Record Field- Final 14-Jan-25 0 18 2M-07 50-103-20178-00 909618938 Kuparuk River Plug Setting Record Field- Final 25-Oct-24 0 19 2W-01 50-029-21273-00 909740411 Kuparuk River Radial Bond Record Field- Final 7-Jan-25 0 110 3B-04 50-029-21323-00 909740412 Kuparuk River Multi Finger Caliper Field & Processed 3-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39999T40000T40001T40002T40003T40004T40005T40006T40007211-062213-095182-162217-138191-108185-147183-089192-080185-010185-061T400081/23/2025182 162217-138191 10841H-10150-029-23585-00909606936Kuparuk RiverMulti Finger CaliperField & Processed28-Oct-2401Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:13:51 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-25_15991_KRU_1H-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15991 KRU 1H-101 50-029-23585-00 Caliper Survey w/ Log Data 25-Jun-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-138 T39095 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.01 09:25:07 -08'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2024-04-20_23022_KRU_1H-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23022 KRU 1H-101 50-029-23585-00 Caliper Survey w/ Log Data 20-Apr-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-138 T38744 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:10:35 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-02-17_22586_KRU_1H-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22586 KRU 1H-101 50-029-23585-00 Caliper Survey w/ Log Data 17-Feb-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-138 T38521 2/21/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.21 10:05:43 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11994'feet None feet true vertical 3954' feet None feet Effective Depth measured 11994'feet 6292'feet true vertical 3954' feet 3852'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 5472' 3632' Packers and SSSV (type, measured and true vertical depth)6292' 3852' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-403 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Baker HRD-E ZXP SSSV: None Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Workover Engineer 6888-8279', 8657-11902' 3950-3955', 3972-3956' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 2170 Gas-Mcf MD ~ Size 119' 2420 1240730 ~ ~~ 375 measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-138 50-029-23585-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025636, ADL0025639 Kuparuk River Field/ West Sak Oil Pool KRU 1H-101 Plugs Junk measured Length 1839' 119'Conductor Surface Intermediate 20" 10-3/4" 80' Liner 6794' Casing 3945'6832' 5653' 4-1/2" 11945' 3955' 1879' 1765' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:44 am, Nov 27, 2023 Page 1/7 1H-101 Report Printed: 11/21/2023 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) 10/21/2023 12:00 10/21/2023 16:30 4.50 MIRU, MOVE MOB P Move sub F/1R T/ G&R access road. 0.0 0.0 10/21/2023 16:30 10/21/2023 18:15 1.75 MIRU, MOVE MOB P Hold for field change out. 0.0 0.0 10/21/2023 18:15 10/21/2023 22:30 4.25 MIRU, MOVE MOB P Continue to move from 1G/R access road to 1H pad 0.0 0.0 10/21/2023 22:30 10/22/2023 00:00 1.50 MIRU, MOVE MOB P Sub base on 1H pad Spot artic enrty way and set stairs on rig office Prep well head equipment for setting behind rig 0.0 0.0 10/22/2023 00:00 10/22/2023 05:00 5.00 MIRU, MOVE MOB P Pull DSA from cellar, hang tree in cellar, spot equipment behind well, lay herculite around well and set rig mats around well, build double mat dance floor 0.0 0.0 10/22/2023 05:00 10/22/2023 08:00 3.00 MIRU, MOVE MOB P Spot rig over well. Shim and level. 0.0 0.0 10/22/2023 08:00 10/22/2023 11:00 3.00 MIRU, MOVE MOB P Spot auxiliary equipment. R/U circ manifold. Take on seawater. Rig accepted @ 11:00 Hrs. 0.0 0.0 10/22/2023 11:00 10/22/2023 14:00 3.00 MIRU, WELCTL COND P Fill pits w/ seawater. Build 40 Bbls deep clean pill. 0.0 0.0 10/22/2023 14:00 10/22/2023 14:30 0.50 MIRU, WELCTL PRTS P Flood circ manifold PT tiger tank lines T/ 2500 PSI. 0.0 0.0 10/22/2023 14:30 10/22/2023 15:00 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on well kill. 0.0 0.0 10/22/2023 15:00 10/22/2023 16:45 1.75 MIRU, WELCTL KLWL P Initial pressures TBG=850, IA=200. Bleed free gas off of IA. Bleed free gas off of TBG. Pump down IA 40 Bbls down IA w/ no returns to surface. Bullhead 230 Bbls down IA @ 5 BPM, ICP=550, FCP=360. Pumps off PSI fell to 0 PSI. Bullhead 132 Bbls down TBG @ 5 BPM, ICP=900, 0.0 0.0 10/22/2023 16:45 10/22/2023 18:00 1.25 MIRU, WELCTL OWFF P Flow check, TBG and IA on a vac, monitor for 30 min Slight flow out TBG in 45 min, IA no longer on a vac Shut in monitor PSI, TBG build to 80 PSI in 1 HR 0.0 0.0 10/22/2023 18:00 10/22/2023 22:00 4.00 MIRU, WELCTL SIPB P Continue to monitor pressure on TBG and IA - TBG @ 80 PSI, IA @ 90 PSI Blow air thru all lines to insure clear, install 2" block valve in hard line for isolation from blooie line to cellar line While blending 9.0 PPG KWF in pits, with 9.6 PPG from 1B Break hard line to kill tanks, pull bleed trailer out and spot derrick line Put hard line back together and test 0.0 0.0 10/22/2023 22:00 10/22/2023 22:30 0.50 MIRU, WELCTL KLWL P Open up TBG to bleed off gas cap, line up to go thru choke noticed choke gauge said 600 PSI Bleed down to 270 PSI get fluid out Shut well in to change out gauges and reconfigure 1502 Tee's 0.0 0.0 10/22/2023 22:30 10/22/2023 23:00 0.50 MIRU, WELCTL KLWL P While closing in super choke notice air pressure seem low, trouble shoot air supply problem, air line freezing up in motor room 0.0 0.0 10/22/2023 23:00 10/22/2023 23:30 0.50 MIRU, WELCTL KLWL P Continue to adjust 2" Tee's in cellar for gauges and change out bad gauges on TBG and IA for monitor pressures Test lines in cellar 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 2/7 1H-101 Report Printed: 11/21/2023 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) 10/22/2023 23:30 10/23/2023 00:00 0.50 MIRU, WELCTL KLWL P PJSM circulate 9.0 PPG NaCl 0.0 0.0 10/23/2023 00:00 10/23/2023 00:45 0.75 MIRU, WELCTL KLWL P Open up TBG 430 PSI, bleed off free gas, bleed DN to 250 PSI, open IA 130 PSI, bleed off free gas to 120 PSI Line up pump down TBG returns out IA to tank have 265 PSI on TBG and 107 PSI on IA, pump @ 2 BPM pump 12 BBLS no PSI increase on IA, shut down check line up, line up good, continue pumping down TBG, pump a total of 44 BBLS, no increase in IA pressure, shut down pump 0.0 0.0 10/23/2023 00:45 10/23/2023 02:00 1.25 MIRU, WELCTL KLWL P Line up bullhead 9.0 PPG NaCl down IA, pump at 5 BPM 330 ICP at 115 BBLS into bullhead catch PSI on TBG side to 90, pump 1.5 times volume pump a total of 207 BBLS down IA 306 PSI FCP Line up to bull head down TBG, pump @ 5 BPM 93 PSI, pump 1.5 times volume pump a total of 127 BBLS DN TBG 64 PSI FCP, with 20 PSI on IA 0.0 0.0 10/23/2023 02:00 10/23/2023 02:45 0.75 MIRU, WELCTL OWFF P Flow check, TBG static, IA have 10 PSI on it, bleed off IA, IA static Blow down lines in cellar while flow check 0.0 0.0 10/23/2023 02:45 10/23/2023 03:30 0.75 MIRU, WELCTL MPSP P Set BPV, test from below with rolling test at 4 BPM 165 PSI for 10 min Take 3 1/2 BBLS to catch pressure after pumps off for 82 Minutes 0.0 0.0 10/23/2023 03:30 10/23/2023 04:00 0.50 MIRU, WHDBOP RURD P B/D and rig down circ lines, rig up kill line to IA to keep under hanger full 0.0 0.0 10/23/2023 04:00 10/23/2023 07:00 3.00 MIRU, WHDBOP NUND P N/D tree, inspect hanger threads and install test dart. Filling hole w/ 10 Bbls every 1/2 hour. 0.0 0.0 10/23/2023 07:00 10/23/2023 13:00 6.00 MIRU, WHDBOP NUND P N/U BOP. Swap circ hose over T/ IA continue filling hole w/ 10 Bbls every 1/2 hour. Align stack. Install flow box and flow nipple. M/U trip tank hose. M/U choke & kill lines. 0.0 0.0 10/23/2023 13:00 10/23/2023 14:00 1.00 MIRU, WHDBOP RURD P R/U testing equipment. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 3/7 1H-101 Report Printed: 11/21/2023 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) 10/23/2023 14:00 10/23/2023 21:00 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2" & 4 1/2" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ & 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3000 PSI, after closure= 1650 PSI, 200 PSI attained = 24 sec, full recovery attained = 123 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. 0.0 10/23/2023 21:00 10/23/2023 21:30 0.50 MIRU, WHDBOP RURD P Blow down lines, rig down testing equipment 0.0 0.0 10/23/2023 21:30 10/23/2023 22:00 0.50 COMPZN, RPCOMP RURD P Bring up HES spooling unit to pipe shed and bring to rig floor Bring up 4 1/2" HYD 563 thread protectors Rig up to pull 4 1/2" TBG 0.0 0.0 10/23/2023 22:00 10/23/2023 22:30 0.50 COMPZN, RPCOMP MPSP P Pull test dart Attempt to pull BPV, have pressure under plug, pull running tool out of hole and pop it in the BPV would not close Close blind rams Line up to see pressure, on TBG and IA Have 290 PSI on TBG under blinds Bring on mud pump equalize pressure on HCR kill valve 0.0 0.0 10/23/2023 22:30 10/23/2023 23:15 0.75 COMPZN, RPCOMP CIRC P Bull head 9.0 PPG NaCl down TBG at 5 BPM pump 127 BBLS - 1 1/2" times TBg volume 0.0 0.0 10/23/2023 23:15 10/23/2023 23:45 0.50 COMPZN, RPCOMP MPSP P Flow check, check for pressure on TBG and IA, both TBG and IA on a vac, open blind rams Pull BPV 0.0 0.0 10/23/2023 23:45 10/24/2023 00:00 0.25 COMPZN, RPCOMP RURD P Finish rigging up to pull 4 1/2" TBG 0.0 0.0 10/24/2023 00:00 10/24/2023 00:30 0.50 COMPZN, RPCOMP PULL P Make up landing joint to hanger, make up top drive to landing joint, set DN 10K BOLDS 0.0 0.0 10/24/2023 00:30 10/24/2023 00:45 0.25 COMPZN, RPCOMP PULL P Pull hanger to floor Hanger off seat @ 105K, 90K UP clean 0.0 5,448.0 10/24/2023 00:45 10/24/2023 01:45 1.00 COMPZN, RPCOMP OWFF P Attempt to establish a loss rate filling backside Fill hole take 120 BBLS to fill hole Could not keep hole full fast enough to calculate a loss rate PJSM laying down tubing while attempting to get loss rate 5,448.0 5,448.0 10/24/2023 01:45 10/24/2023 02:45 1.00 COMPZN, RPCOMP CIRC P Notice had 120 PSI on TBG side after attempting to get a loss rate 5,448.0 5,448.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 4/7 1H-101 Report Printed: 11/21/2023 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) 10/24/2023 02:45 10/24/2023 03:30 0.75 COMPZN, RPCOMP PULL P Lay down landing joint and hanger Hook up control line to spooling unit 5,448.0 5,448.0 10/24/2023 03:30 10/24/2023 10:00 6.50 COMPZN, RPCOMP PULL P POOH laying down tubing spooling up control line. Filling hole with 15 BBLS every 30 min plus pipe displacement. Pipe below lowest GLM, looked good externaly. Some blistering in internaly on joints #1 & #2. Seals recovered in good condition. Total of131 cross collar, 10 half clamps recovered. 5,448.0 0.0 10/24/2023 10:00 10/24/2023 11:00 1.00 COMPZN, RPCOMP RURD P R/D HES spooling unit. R/D tubing handling equipment. 0.0 0.0 10/24/2023 11:00 10/24/2023 12:00 1.00 COMPZN, RPCOMP CLEN P Clean & clear RF and pipe shed. Load Baker tools into pipe shed. 0.0 0.0 10/24/2023 12:00 10/24/2023 13:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Change out saver sub. 0.0 0.0 10/24/2023 13:00 10/24/2023 13:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Baker and rig crew on running G plug. 0.0 0.0 10/24/2023 13:15 10/24/2023 13:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 G plug T/ 18'. 0.0 18.0 10/24/2023 13:45 10/24/2023 20:00 6.25 COMPZN, RPCOMP PULD P RIH F/ 18' T/ 5225' COE, PUW=94K, SOW=79K. 18.0 5,225.0 10/24/2023 20:00 10/24/2023 20:30 0.50 COMPZN, RPCOMP MPSP P Set G-Plug @ 5,225' (ME). Top of plug = 5,220'. Bottom of plug = 5,231'. Good set. Release after set and TOOH to next tool joint. 5,225.0 5,206.0 10/24/2023 20:30 10/24/2023 22:30 2.00 COMPZN, RPCOMP CIRC P Close UPR. Circ BU taking returns through MGS to cuttings tank to clean up and fluid pack the well in prep for G- plug PT. 2 BPM @ 124 psi. Begin processing 4 1/2" 13CR VAMTOP Tubing. 5,206.0 5,206.0 10/24/2023 22:30 10/24/2023 23:00 0.50 COMPZN, RPCOMP TRIP P Rack back 3 stands of 3 1/2" DP to 4,958'. RU to PT. 5,206.0 4,958.0 10/24/2023 23:00 10/24/2023 23:30 0.50 COMPZN, RPCOMP PRTS P PT to 1,000 psi for 15-min. Chart. 16 strokes to pressure up. Initial = 1,100. 15-min = 1,080 psi Pass. 4,958.0 4,958.0 10/24/2023 23:30 10/25/2023 00:00 0.50 COMPZN, RPCOMP BHAH P M/U Storm Packer. 4,958.0 4,978.0 10/25/2023 00:00 10/25/2023 00:30 0.50 COMPZN, RPCOMP TRIP P MU and TIH w/ Storm Packer to 101'. 4,978.0 5,070.0 10/25/2023 00:30 10/25/2023 00:45 0.25 COMPZN, RPCOMP MPSP P Set Storm Packer @ 101' (ME). Release from Storm packer. TOOH. 5,070.0 0.0 10/25/2023 00:45 10/25/2023 01:00 0.25 COMPZN, RPCOMP RURD P Prep rig floor to PT Storm Packer. Blow Down TD. Close Blind Ram. Line up to pump down kill line. 0.0 0.0 10/25/2023 01:00 10/25/2023 10:30 9.50 COMPZN, RPCOMP PRTS T Set storm packer @ 101' COE. Release POOH. PT storm packer - Fail. Made multiple attempts to test eliminating surface leaks from the scenario all failed. Release storm packer. Called out new packer and storm valve. POOH & inspect. Remove storm valve. Ran TST pacer set @ 91' COE. PT TST packer T/ 1000 PSI for 15 Min - Pass. Storm valve appears to be problem. M/U new storm vale to packer. RIH set storm packer @ 107' COE. Release, POOH. 0.0 0.0 10/25/2023 10:30 10/25/2023 11:00 0.50 COMPZN, RPCOMP PRTS P PT Storm Packer to 1,000 psi. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 5/7 1H-101 Report Printed: 11/21/2023 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) 10/25/2023 11:00 10/25/2023 11:30 0.50 COMPZN, RPCOMP OWFF P Suck out stack B/D surface lines. 0.0 0.0 10/25/2023 11:30 10/25/2023 13:00 1.50 COMPZN, RPCOMP NUND P N/D BOP 0.0 0.0 10/25/2023 13:00 10/25/2023 13:45 0.75 COMPZN, RPCOMP NUND P N/D old Vault Tubing Spool. 0.0 0.0 10/25/2023 13:45 10/25/2023 14:45 1.00 COMPZN, RPCOMP NUND P N/U new SteamFlo Tubing Spool. Install secondary IA valve. 0.0 0.0 10/25/2023 14:45 10/25/2023 15:15 0.50 COMPZN, RPCOMP PRTS P Pump plastic pack in pack off void. PT pack off T/ 5000 PSI for 15 MIn. 0.0 0.0 10/25/2023 15:15 10/25/2023 19:15 4.00 COMPZN, RPCOMP NUND P N/U BOP. N/U choke & kill. Install flow nipple. 0.0 0.0 10/25/2023 19:15 10/25/2023 21:00 1.75 COMPZN, RPCOMP RURD P Install test plug. Open IA valve. Reconfigure hoses and greylocks due to stack position. Load completion jewelry, landing joint, tubing hanger to rig floor. Drift Tubing hanger. 0.0 0.0 10/25/2023 21:00 10/26/2023 00:00 3.00 COMPZN, RPCOMP PRTS P PT breaks on BOPE, choke, and kill lines to 250/2500 psi. Swap out bad sensator. On initial test greylocks leaked. Tighten up and retest. Passed. Drain Stack. 0.0 0.0 10/26/2023 00:00 10/26/2023 01:00 1.00 COMPZN, RPCOMP RURD P Blow Down lines. Drain Stack. Pull Test Plug. Install wear bushing. Prep rig floor pipe handling equipment. 0.0 0.0 10/26/2023 01:00 10/26/2023 02:00 1.00 COMPZN, RPCOMP TRIP P TIH to Storm Packer @ 107'. 0.0 107.0 10/26/2023 02:00 10/26/2023 02:45 0.75 COMPZN, RPCOMP TRIP P Equalize and release Storm Packer. PUW = 94K, SOW = 79K. Break floor valve off stand. TOOH w/ Storm Packer. L/D same. 107.0 0.0 10/26/2023 02:45 10/26/2023 03:15 0.50 COMPZN, RPCOMP TRIP P TIH w/ 3 stands and equalize/release G- Plug @ 5,225'. 0.0 5,225.0 10/26/2023 03:15 10/26/2023 03:45 0.50 COMPZN, RPCOMP OWFF P OWFF. Monitor DP and IA. 5,225.0 5,225.0 10/26/2023 03:45 10/26/2023 09:00 5.25 COMPZN, RPCOMP PULD P TOOH laying down 3 1/2" Drill Pipe. Pump 15 bbls every 30-min plus hole fill. 5,225.0 18.0 10/26/2023 09:00 10/26/2023 09:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 (G-Plug) 18.0 0.0 10/26/2023 09:30 10/26/2023 10:00 0.50 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 10/26/2023 10:00 10/26/2023 11:00 1.00 COMPZN, RPCOMP RURD P Clean and Clear rig floor and pipe shed. 0.0 0.0 10/26/2023 11:00 10/26/2023 11:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Change out link tilt cylinder. 0.0 0.0 10/26/2023 11:30 10/26/2023 14:45 3.25 COMPZN, RPCOMP RURD P RU GBR pipe handing equipment for 4 1/2" 13CR Tubing. RU HES spoolers for chem injection line and TEC Wire. Verify jewelry lengths, run order, and tally. 0.0 0.0 10/26/2023 14:45 10/26/2023 15:15 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES, GBR & rig crew on running completion w/ control lines. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 6/7 1H-101 Report Printed: 11/21/2023 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) 10/26/2023 15:15 10/27/2023 00:00 8.75 COMPZN, RPCOMP PUTB P Run 4 1/2", 12.6#, 13 Cr, Vamtop completion as per Tally. Vamtop torque turned T/ 4440 Ft/lbs. Jet lube seal guard dope used. Hook up chemical injection line. Install gauge. PT gauge T/ 10000 PSI for 10 Min. Found bad collar when M/U GLM w/ SOV. Replaced Collar. Cont. RIH per tally checking TEC wire com's. every 1,000' per HES rep. Cont. to pump 15 bbls brine every 30 minutes. Midnight depth of 2,910'. Cont. running 4 1/2" completions. 0.0 2,910.0 10/27/2023 00:00 10/27/2023 05:30 5.50 COMPZN, RPCOMP PUTB P Cont. running 4 1/2" Completions as per tally, pumping 15 bbls brine every 30 minutes. PUW = 85K, SOW = 70K. Fully locate Seals in SBR @ 5463.5'' Nordic 3 RKB. Fill IA T/ surface. Verify no losses indicating seals are engaged. PU 4' for space out. Mark Pipe. 2,910.0 5,463.5 10/27/2023 05:30 10/27/2023 06:15 0.75 COMPZN, RPCOMP HOSO P Pickup slowly verify when fluid level started to drop, locating top of SBR. Space out. L/D joint 127. M/U Tubing Hanger and Landing Joint. Installed 133 cross collar clamps and 10 half clamps on 4 1/2" completion. 5,463.5 5,427.0 10/27/2023 06:15 10/27/2023 07:15 1.00 COMPZN, RPCOMP THGR P Terminate chem. injection control line and TEC wire through Tubing Hanger. Pump 15 bbls CI brine down backside every 30-minutes to maintain CI on backside prior to landing hanger. 5,427.0 5,427.0 10/27/2023 07:15 10/27/2023 07:30 0.25 COMPZN, RPCOMP PRTS P PT hanger terminations T/ 5000 PSI. 5,427.0 5,427.0 10/27/2023 07:30 10/27/2023 08:00 0.50 COMPZN, RPCOMP THGR P Land Tubing Hanger. Set Hanger Lock- Ring. Bottom of Seals @ 5474.2' ORKB. Drop Ball and Rod. Top fill TBG w/ 9.0 PPG NaCl. 5,427.0 5,474.0 10/27/2023 08:00 10/27/2023 08:15 0.25 COMPZN, RPCOMP PRTS P PT hanger seals to 5,000 psi for 15-min. 5,474.0 5,474.0 10/27/2023 08:15 10/27/2023 09:00 0.75 COMPZN, RPCOMP RURD P R/U head pin on landing joint. Service green 1502 testing valves. RU pressure testing hoses and valves to Tubing and IA using green valves. 5,474.0 5,474.0 10/27/2023 09:00 10/27/2023 11:00 2.00 COMPZN, RPCOMP PRTS P PT Tubing to 3,000 psi for 30-min. PT IA to 2,500 psi for 30-min (holding 1,500 on Tubing). Dump Tubing pressure to shear SOV. Pump down IA taking returns from Tubing to verify flow path through SOV @ 2 BPM, 800 PSI. 5,474.0 5,474.0 10/27/2023 11:00 10/27/2023 11:15 0.25 COMPZN, RPCOMP RURD P Attempt R/D tubing testing equipment. Crude flowing from tubing side. 5,474.0 5,474.0 10/27/2023 11:15 10/27/2023 12:00 0.75 COMPZN, RPCOMP CIRC P Circ 81 Bbls 9.0 NaCl down T/ SOV. 5,474.0 5,474.0 10/27/2023 12:00 10/27/2023 12:15 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow from tubing. 5,474.0 5,474.0 10/27/2023 12:15 10/27/2023 12:30 0.25 COMPZN, RPCOMP MPSP P Pull landing joint. Set HP BPV. 5,474.0 0.0 10/27/2023 12:30 10/27/2023 12:45 0.25 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min from below. 0.0 0.0 10/27/2023 12:45 10/27/2023 14:30 1.75 COMPZN, WHDBOP RURD P B/D surface lines. Suck BOP out. R/D landing joint. Send out HES spooling units. R/D GBR. 0.0 0.0 10/27/2023 14:30 10/27/2023 16:30 2.00 COMPZN, WHDBOP NUND P Change out LPR T/ 7" fixed for next well. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Page 7/7 1H-101 Report Printed: 11/21/2023 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) 10/27/2023 16:30 10/27/2023 21:00 4.50 COMPZN, WHDBOP NUND P N/D BOP. Rack back on stump. N/D test spool. Grease up and stinger outside. Prep Tubing Spool for CSBS seal bushing. Stinger bushing press plate into cellar. 0.0 0.0 10/27/2023 21:00 10/28/2023 00:00 3.00 COMPZN, WHDBOP NUND P Press CSBS Seal Bushing into Tubing Spool. Install test dart. N/U Tubing Head Adapter. 0.0 0.0 10/28/2023 00:00 10/28/2023 02:30 2.50 COMPZN, WHDBOP NUND P Continue N/U Tubing Head Adapter. PT hanger void to 5,000 psi. Terminate chemical injection line and TEC wire through tubing head adapter. TEC wire final check after terminated: Pressure = 1,690 psi. Temp = 70 F. R/D BOP Riser. 0.0 0.0 10/28/2023 02:30 10/28/2023 08:30 6.00 COMPZN, WHDBOP NUND P N/U Production Tree. Reconfigure old tree - remove horizontal well head adapter, add SSV, align wing valve to production, and valves to Driller Side to clear TEC Wire and Control lines. Orientation confirmed by CPF1 drill site lead. 0.0 0.0 10/28/2023 08:30 10/28/2023 09:00 0.50 COMPZN, WHDBOP RURD P R/U testing equipment. Fill tree w/ diesel. 0.0 0.0 10/28/2023 09:00 10/28/2023 10:00 1.00 COMPZN, WHDBOP PRTS P PT Tree to 250/5000 psi for 5-min. 0.0 0.0 10/28/2023 10:00 10/28/2023 10:15 0.25 COMPZN, WHDBOP RURD P R/D testing equipment. Drain diesel from tree. 0.0 0.0 10/28/2023 10:15 10/28/2023 10:45 0.50 COMPZN, WHDBOP MPSP P Pull 'HP' BPV and test dart. 0.0 0.0 10/28/2023 10:45 10/28/2023 11:30 0.75 COMPZN, WHDBOP RURD P RU LRS & circ manifold. Confirm hardline is rigged back up. 0.0 0.0 10/28/2023 11:30 10/28/2023 12:00 0.50 COMPZN, WHDBOP PRTS P PT circ manifold and tiger tank lines. 0.0 0.0 10/28/2023 12:00 10/28/2023 14:00 2.00 COMPZN, WHDBOP FRZP P Pump 83 bbls of diesel down IA taking returns from Tubing to tanks @ 2 BPM, ICP=1550, FCP=1850. U-Tube for 1 hour. 0.0 0.0 10/28/2023 14:00 10/28/2023 15:00 1.00 COMPZN, WHDBOP RURD P B/D, R/D circ lines. Secure tree. Final pressure T/IA/OA = 80/100/25. 0.0 0.0 10/28/2023 15:00 10/28/2023 17:00 2.00 DEMOB, MOVE DMOB P Secure rig for move. Remove auxiliary equipment. Rig Release @ 17:00 Hrs. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/28/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1H-101 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set post rig GLD. Pull RHC. 1H-101 11/3/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Chrome tubing from surface to 5472' RKB 10/28/2023 spilch Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 39.1 119.1 119.1 78.67 B SURFACE 10 3/4 9.95 40.7 1,879.3 1,764.6 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.8 6,832.3 3,945.1 29.70 L-80 Hyd 563 LINER 4 1/2 4.00 6,291.9 11,944.9 3,955.1 11.60 L-80 IBT-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.7 Set Depth 5,472.2 String Max No 4 1/2 Set Depth 3,631.5 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L80 Top Connection 13 Cr ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.7 35.7 0.00 Hanger 13.475 13 5/8" StreamFlo DMLX Hanger w/ 6.25 RH ACME Top thread Streamfl o DMLX 3.900 506.9 506.2 6.14 Nipple - X 4.952 Halliburton 3.813" X Nipple Profile Halliburt on X-nipple 3.813 2,854.3 2,352.4 57.19 Mandrel GAS LIFT 6.373 4-1/2" x 1" KBMG, GLM, 13 Cr SLB KBMG 4.000 4,664.4 3,294.8 62.66 Mandrel GAS LIFT 6.381 4-1/2" x 1" KBMG, GLM, 13 Cr SLB KBMG 4.000 5,271.4 3,561.8 66.84 Mandrel GAS LIFT 6.374 4-1/2" x 1" KBMG, GLM SLB KBMG 4.000 5,340.5 3,588.0 68.80 Sensor - Discharge Gauge 5.430 4-1/2" Halliburton Gauge Mandrel, (SN: MXM19080-01) Halliburt on Gauge - MXM 3.842 5,406.6 3,610.7 70.88 Mandrel INJ 5.588 4-1/2" Halliburton Chemical Inection Mandrel Halliburt on Chem Injection Mdrl 3.893 5,430.7 3,618.5 71.35 Nipple - X 5.007 Halliburton 3.813" X Nipple Halliburt on X-nipple 3.813 5,446.0 3,623.4 71.64 Locator 5.390 Tri-Point 192-47 Locator Sub (5.39" OD) Tri-Point 192-47 Locator 3.880 5,446.6 3,623.6 71.65 Seal Assembly 4.740 Tri-Point 192-47 Seal Assembly (4.02' from fully located) Tri-Point 192-47 Seal Assembl y 3.830 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,854.3 2,352.4 57.19 1 GAS LIFT GLV BK 1 1,558.0 11/3/2023 SLB KBMG 0.250 4,664.4 3,294.8 62.66 2 GAS LIFT GLV BK 1 1,727.0 11/3/2023 SLB KBMG 0.313 5,271.4 3,561.8 66.84 3 GAS LIFT OV BK 1 0.0 11/3/2023 SLB KBMG 0.438 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,291.9 3,851.7 74.39 PACKER 5.500 Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 563 pin Baker PN: H296- 45-0131, Control # 106140604- 01 5.750 6,311.8 3,857.0 74.35 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control # 105769670 4.880 6,344.2 3,865.8 74.27 XO 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# IBT- pin Crossover 3.930 8,290.5 3,954.7 90.63 PACKER 6.340 Baker 6" OD Swell Packer #1 "A" SN: 049169-001-8 Baker 920 Compound 1834, PN H301-87- 0397, SN: 049169-001 3.970 8,646.8 3,971.2 87.08 PACKER 5.950 Baker 6" OD Swell Packer #2 "B" SN: 05826-001-14 Baker 920 Compound 1834, PN H301-87- 0397, SN 052826-001 - 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,888.2 8,278.7 3,950.1 3,954.8 WS A2, 1H-101 12/4/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 8,656.8 11,901.5 3,971.7 3,955.5 WS A2, 1H-101 12/4/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-101, 11/21/2023 11:48:31 AM Vertical schematic (actual) LINER; 6,291.9-11,944.9 SLOTS; 8,656.8-11,901.5 SLOTS; 6,888.2-8,278.6 INTERMEDIATE; 37.8-6,832.3 L1 SLOTTED LINER; 6,186.5- 11,812.7 PACKER; 6,126.7 L2 SLOTTED LINER; 6,028.3- 11,809.0 PACKER; 5,929.5 L3 SLOTTED LINER; 5,834.6- 11,802.3 PACKER; 5,656.0 L4 SLOTTED LINER; 5,559.7- 11,708.5 NIPPLE; 5,494.0 Seal Assembly; 5,446.6 PACKER; 5,439.4 Nipple - X; 5,430.7 Mandrel GAS LIFT; 5,271.4 Mandrel GAS LIFT; 4,664.4 Mandrel GAS LIFT; 2,854.3 SURFACE; 40.7-1,879.3 Nipple - X; 506.9 CONDUCTOR; 39.1-119.1 Hanger; 35.7 KUP PROD KB-Grd (ft) 39.09 RR Date 1/7/2018 Other Elev 1H-101 ... TD Act Btm (ftKB) 11,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358500 Wellbore Status PROD Max Angle & MD Incl (°) 92.61 MD (ftKB) 9,045.69 WELLNAME WELLBORE1H-101 Annotation Last WO: End Date 10/28/2023 H2S (ppm) DateComment SSSV: NONE 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11994'None Casing Collapse Conductor Surface Intermediate Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Tubing Grade:Tubing MD (ft): 6292' MD and 3852' TVD N/A Perforation Depth TVD (ft):Tubing Size: L-80 5474' Packer: Baker HRD-E ZXP Flex-Lock LTP SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636, ADL0025639 217-138 P.O. Box 100360, Anchorage, AK 99510 50-029-23585-00-00 ConocoPhillips Alaska, Inc. KRU 1H-101 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3954'11994'3954'1257 psi None MD 119' 1765' 3945' 119' 1879' 6832' 20" 10-3/4" a 1839' Perforation Depth MD (ft): 7-5/8"6794' Slotted Liner: 6888-8279', 8657- 11901' 4-1/2" Slotted Liner: 3950-3955', 3972-3955' 119455653' 4-1/2" 3955' P s 66 t Form 10 403 Revised 10/2022 Approved application valid for 12 months from date of approval Submit PDF to aogcc permitting@alaska gov 10/1/2023 Date: By Grace Christianson at 3:34 pm, Jul 18, 202 323-403 X DSR-7/19/23MDG 7/24/2023 X 10-404 VTL 8/03/2023 X BOP test to 2500 psig Annular preventer test to 2500 psig GCW 08/08/2023JLC 8/10/2023 08/10/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.10 13:59:53 -08'00' RBDMS JSB 081123 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West Sak Producer 1H- 101 (PTD# 217-138-0). Well 1H-101 was drilled in 2018 as a gas lift producer of the West Sak. Holes were discovered in the tubing in 2023 after failing a TIFL and the well was worked over. After the workover however, additional corrosion was found on a flange of the wellhead for the horizontal tree. A vertical tree configuration was managed to flow the well, but a full wellhead replacement is now desired with a workover. If you have any questions or require any further information, please contact me at +1503-476-2519. The tubing will be pulled from seals, a new wellhead will be put on the well, then new 4.5" completion will be ran. 1H-101 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-138 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Dummy off GLMs. 3. MIT-IA. 4. Open deepest GLM for circulations. 5. Prepare well for rig arrival within 48-72 hours of rig arrival. Rig Work MIRU 1. MIRU Nabors Nordic 3 on 1H-101. (No BPV will be installed pre-rig due to internal risk assessment for Nordic 3.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to seals (6778’). Install New Wellhead 6. RIH with DP and set G-plug and/or storm packer. Test same to confirm as barrier. 7. ND BOPs. ND horizontal wellhead tubing spool. NU new vertical tubing spool. NU BOPs. Test same. 8. Pull plugs/storm packers from wellbore. Circulate out packer gas as needed. Install new 4-½” Tubing 9. MU 4 ½” completion with seals, gauge, nipples, Chem Injection, and GLMs. a. Note: A 4.5” x 7-5/8” packer is available as a contingency option if any need to stack a packer arises. 10. RIH with completion. Once on depth, sting into SBE. 11. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. 12. Drop ball/rod. Pressure test tubing to 3000 psi for 30 minutes and chart. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. Test BPV as needed. 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well if necessary. 18. RDMO. Post-Rig Work 19. Pull all plugs from tubing string and install GLD. 20. Turn over to operations. 1H-101 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-138 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vetco Gray MB222A, 5M psi top flange. Change to StreamFlo Vertical Big Bore, 5M. Production Engineer: Will Parker Reservoir Development Engineer: Marina Krysinski Estimated Start Date: 10/1/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently online. Well Type: Producer Scope of Work: Pull the existing 4-1/2” completion from seals. Run casing plugs/storm packer. Swap out tubing spool. Run new 4-1/2” completion and stab back into PBR with seals. BOP configuration: Annular / Pipe Rams / Blind Rams /Cross/ Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T PASSED on RWO 3/19/2023. MIT-IA PASSED on RWO 3/19/2023. MIT-OA N/A IC POT &PPPOT PASSED – 3/19/2023 TBG POT &PPPOT PASSED – 3/19/2023 MPSP: 1257 psi using 0.1 psi/ft gradient. Static BHP: 1643 psi / 3601’ TVD measured on 1/19/2018. (Higher end of pressure range seen since drilled.) Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed GLD. Pulled Plug 1H-101 4/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: A 90 day waiver is in place. Do not pressure the tree/well over 2000 psi. 4/13/2023 fergusp General Notes: Last 3 entries Com Date Last Mod By Freeze protected 10-3/4" x 7-5/8" outer annulus with total of 90 bbls IsoTherm 11/29/2017 d142cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 39.1 119.1 119.1 78.67 B SURFACE 10 3/4 9.95 40.7 1,879.3 1,764.6 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.8 6,832.3 3,945.1 29.70 L-80 Hyd 563 LINER 4 1/2 4.00 6,291.9 11,944.9 3,955.1 11.60 L-80 IBT-m Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.1 Set Depth … 5,474.2 Set Depth … 3,632.1 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L80 Top Connection HYD563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.1 33.1 0.00 Hanger 10.813 4-1/2" Vetco Grey MB-228 11" x 4 1/2" Hanger w/ 4.909 MCA Box Up Vetco Grey MB-228 Offset 5.750 523.7 522.8 6.30 Nipple - X 4.999 Halliburton 3.813" Nipple Profile Halliburt on X-nipple 3.813 2,882.3 2,367.6 57.11 Mandrel – GAS LIFT 6.370 4-1/2" x 1" KBMG, GLM SLB KBMG 3.870 4,658.7 3,292.2 62.67 Mandrel – GAS LIFT 6.350 4-1/2" x 1" KBMG, GLM SLB KBMG 3.870 5,257.3 3,556.2 66.50 Mandrel – GAS LIFT 6.360 4-1/2" x 1" KBMG, GLM SLB KBMG 3.870 5,325.1 3,582.3 68.30 Sensor - Discharge Gauge 5.675 4-1/2" Halliburton Gauge Mandrel Halliburt on Gauge - MXM 3.926 5,390.4 3,605.4 70.42 Nipple - X 5.001 Halliburton 3.813" Nipple Profile Halliburt on X-nipple 3.813 5,445.9 3,623.3 71.64 Locator 4.500 Baker 192-47 Locator Sub (5.38" OD) Baker 192-47 Locator 3.880 5,447.6 3,623.9 71.67 Seal Assembly 4.500 Baker 192-47 Seal Assembly w/ seal on bottom 16' of assembly (4' off no- go) Baker 192-47 Seal Assembl y 3.870 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,882.3 2,367.6 57.11 1 GAS LIFT GLV BK 1 1,558.0 4/15/2023 KBMG 0.250 4,658.7 3,292.2 62.67 2 GAS LIFT GLV BK 1 1,727.0 4/14/2023 KBMG 0.313 5,257.3 3,556.2 66.50 3 GAS LIFT OV BK 1 0.0 4/14/2023 KBMG 0.438 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,291.9 3,851.7 74.39 PACKER 5.500 Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 563 pin Baker PN: H296- 45-0131, Control # 106140604- 01 5.750 6,311.8 3,857.0 74.35 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control # 105769670 4.880 6,344.2 3,865.8 74.27 XO 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# IBT- pin Crossover 3.930 8,290.5 3,954.7 90.63 PACKER 6.340 Baker 6" OD Swell Packer #1 "A" SN: 049169-001-8 Baker 920 Compound 1834, PN H301-87- 0397, SN: 049169-001 3.970 8,646.8 3,971.2 87.08 PACKER 5.950 Baker 6" OD Swell Packer #2 "B" SN: 05826-001-14 Baker 920 Compound 1834, PN H301-87- 0397, SN 052826-001 - 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,888.2 8,278.7 3,950.1 3,954.8 WS A2, 1H-101 12/4/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long 1/8" id SLOTS; 6,888.2-8,278.6 INTERMEDIATE; 37.8-6,832.3 FLOAT SHOE; 6,829.4-6,832.3 SBE; 6,324.4-6,344.2 HANGER; 6,314.6-6,324.4 NIPPLE; 6,311.8-6,314.6 L1 SLOTTED LINER; 6,186.5- 11,812.7 HANGER; 6,186.5-6,205.9 Triple connect bushing; 6,186.5 Triple connect bushing; 6,183.3 XO; 6,166.4 SBE ; 6,146.7 PACKER; 6,126.7 L2 SLOTTED LINER; 6,028.3- 11,809.0 HANGER; 6,028.3-6,047.8 Triple connect bushing; 6,028.3 Triple connect bushing; 6,025.1 XO; 5,969.1 SBE ; 5,949.4 PACKER; 5,929.5 L3 SLOTTED LINER; 5,834.6- 11,802.3 HANGER; 5,834.6-5,854.0 Triple connect bushing; 5,834.6 Triple connect bushing; 5,831.4 XO; 5,695.5 SBE ; 5,675.9 PACKER; 5,656.0 L4 SLOTTED LINER; 5,559.7- 11,708.5 Hanger; 5,559.7-5,579.1 Triple connect bushing; 5,559.3 Triple connect bushing; 5,556.1 NIPPLE; 5,494.0 XO; 5,479.1 SBE; 5,459.4 Seal Assembly; 5,447.6 PACKER; 5,439.4 Locator; 5,445.9 Nipple - X; 5,390.4 Sensor - Discharge Gauge; 5,325.1 Mandrel – GAS LIFT; 5,257.3 Mandrel – GAS LIFT; 4,658.7 Annular Fluid - CI Seawater; 2,000.0-5,474.2; 3/19/2023 Mandrel – GAS LIFT; 2,882.3 SURFACE; 40.7-1,879.3 FLOAT SHOE; 1,875.9-1,879.3 Annular Fluid - Diesel; 33.1- 2,000.0; 3/19/2023 Nipple - X; 523.7 CONDUCTOR; 39.1-119.1 HANGER; 40.7-41.0 HANGER; 37.8-38.4 Hanger; 33.1 1H-101 Proposed RWO Completion_Alt1 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1879 1765 10.75 9.95 45.5 L80 HYD563 HYD563 Production 6832 3945 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 11945 3955 4.5 4 11.6 L80 IBTM IBTM Tubing 5475 3632 4.5 3.96 12.6 L80 VAMTOP VAMTOP PROPOSED COMPLETION 4-1/2" 12.6# L-80 VamTop 13Cr Tubing to surface 3.813" X-Nipple 9Cr or 13Cr 4-1/2" Camco KBMG gas lift mandrels @ TBD 9Cr or 13Cr Gauge Mandrel (TEC wire with Clamps to Surface) 9Cr or 13Cr Chem Injection Mandrel (1/4" Line to Surface) 3.813" X-Nipple 9Cr or 13Cr 4-1/2" Seals 9Cr or 13Cr REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (6291' RKB) Seal Bore Extension. 4.750" ID (6325' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-06-27_21146_KRU_1H-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21146 KRU 1H-101 50-029-23858-00 Caliper Survey w/ Log Data 27-Jun-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-138 T37798 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.30 10:21:13 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-27_22096_KRU_1H-101_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22096 KRU 1H-101 50-029-23585-00 Caliper Survey w/ \ Log Data 27-May-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-138 T37682 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.01 10:24:41 -08'00' 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Thursday, March 23, 2023 9:18 AM To:Yearout, Paul Cc:Regg, James B (OGC) Subject:RE: 7ES BOP Test 3-17-23 Attachments:Nabors 7ES 03-17-23 Revised.xlsx Paul, Attached is a revised report changing the MASP to 1257 based on sundry # 323‐125. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Yearout, Paul <Paul.Yearout@nabors.com> Sent: Saturday, March 18, 2023 7:57 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <NSKRWO.CM@conocophillips.com> Cc: Henson, James <Jim.Henson@nabors.com>; greg.s.hobbs@conocophillips.com; Kneale, Michael L <michael.l.kneale@conocophillips.com> Subject: 7ES BOP Test 3‐17‐23 Hello all, The lower pipe rams were not test, the report has been corrected to reflect this. Please keep this report for your records. Thank you Paul Yearout 7ES Toolpusher Nabors Alaska Drilling Inc. Office 907‐670‐ 6132 Cell 907‐244‐6322 paul.yearout@nabors.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1H-101PTD 2171380 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:3/17/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2171380 Sundry #323-125 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1257 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)133 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@ 1950 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 23 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/13/23 9:20 Waived By Test Start Date/Time:3/16/2023 21:30 (date)(time)Witness Test Finish Date/Time:3/17/2023 1:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nabors All Tests with 4 1/2"Test joint. All alarms tested. Bottle precharge - 1050. Kelly Cozby/ Paul Yearout ConocoPhillips Kevin Barr/ Dale Rowell KRU 1H-101 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0317_BOP_Nabors7ES_KRU_1H-101        J. 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Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11994'None Casing Collapse Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Slotted Liner: 6888-8279', 8657- 11901' 4-1/2" Slotted Liner: 3950-3955', 3972-3955' 119455653' 4-1/2" 3955' 20" 10-3/4" 80' 1839' Perforation Depth MD (ft): 7-5/8"6794' MD 119' 1765' 3945' 119' 1879' 6832' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3954' 11994' 3954' 1257 psi None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636, ADL0025639 217-138 P.O. Box 100360, Anchorage, AK 99510 50-029-23585-00-00 ConocoPhillips Alaska, Inc. KRU 1H-101 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): 6292' MD and 3852' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 6337' 3/14/2023 Packer: Baker HRD-E ZXP Flex-Lock LTP SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 2:18 pm, Feb 28, 2023 323-125 SFD 3/1/2023 DSR-2/28/23 BOP test to 2500 psig Annular preventer test to 2500 psig X VTL 03/08/2023 X 10-404 GCW 03/08/23JLC 3/8/2023 3/9/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.09 10:17:00 -09'00' RBDMS JSB 030923 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 27, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West Sak Producer 1H- 101 (PTD# 217-138-0). Well 1H-101 was drilled in 2018 as a gas lift producer of the West Sak. Holes were discovered in the tubing in 2023 after failing a TIFL and it has become a RWO candidate. If you have any questions or require any further information, please contact me at +1503-476-2519. The tubing will be pulled from seals in the liner top packer and a new 4.5" completion will be ran. 1H-101 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-138 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Set plug below tubing seals if possible. 3. CMIT-TxIA 4. Prepare well for rig arrival within 48-72 hours of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-101. (No BPV will be installed pre-rig due to internal risk assessment for N7ES.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to seals (6778’). a. If holes appear to be from External corrosion, then consult with town engineer and discuss possible Eline caliper of 7-5/8”. If not, then move to re-complete. Install new 4-½” Tubing 6. MU 4 ½” completion with muleshoe, 4.5” x 7-5/8” packer, gauge, CMU, nipples, Chem Injection, and GLMs. a. Note: “Alt1” completion schematic would use seals instead of muleshoe and sting back into SBE rather than stacking a 4.5” x 7-5/8” packer. If seals arrive in time, this is preferred option. Also, the Chemical Injection mandrel and line may or may not be ran in either of these scenarios. 7. RIH with completion. Once on depth, sting into SBE. 8. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. Set packer. 9. Pressure test tubing to 3000 psi for 30 minutes and chart. 10. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. Test BPV as needed. 13. ND BOPE. NU tree. 14. Pull BPV, freeze protect well if necessary. 15. RDMO. Post-Rig Work 16. Pull all plugs from tubing string and install GLD. 17. Turn over to operations. 1H-101 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-138 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vetco Gray MB222A, 5M psi top flange Production Engineer: Will Parker Reservoir Development Engineer: Sayeed Abbas Estimated Start Date: 3/14/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently online, but will be SI after 28 day clock expires from failed TIFL. Well Type: Producer Scope of Work: Pull the existing 4-1/2” completion from seals. Run new 4-1/2” completion and stab back into PBR with seals with muleshoe and stacked packer. (*Note: If seals arrive in time, will run new seals and eliminate stacked packer. Want AOGCC to be aware of both options for lower seal so we don’t need to revise. Thanks.) BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed TIFL 2/23/2023 CMIT-TxIA 7-5/8” casing passed initial drill tests. Expected to pass in upcoming diagnostics once plug can get set. MIT-OA N/A IC POT &PPPOT PASSED – 2/24/2023 TBG POT &PPPOT PASSED – 2/24/2023 MPSP: 1257 psi using 0.1 psi/ft gradient Static BHP: 1643 psi / 3601’ TVD measured on 1/19/2018 1H-101 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1879 1765 10.75 9.95 45.5 L80 HYD563 HYD563 Production 6832 3945 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 11945 3955 4.5 4 11.6 L80 IBTM IBTM Tubing 5475 3632 4.5 3.96 12.6 L80 TXPM TXPM PROPOSED COMPLETION 4-1/2" 12.6# L-80 HYD563 Tubing to surface 3.813" X-Nipple 4-1/2" Camco KBMG gas lift mandrels @ TBD CMU Gauge Mandrel (TEC wire with Clamps to Surface) Chem Injection Mandrel (1/4" Line to Surface) 4-1/2" x 7-5/8" Packer 3.813" X-Nipple 4-1/2" Muleshoe (Non-Sealing) REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (6291' RKB) Seal Bore Extension. 4.750" ID (6325' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing 1H-101 Proposed RWO Completion_Alt1 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1879 1765 10.75 9.95 45.5 L80 HYD563 HYD563 Production 6832 3945 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 11945 3955 4.5 4 11.6 L80 IBTM IBTM Tubing 5475 3632 4.5 3.96 12.6 L80 TXPM TXPM PROPOSED COMPLETION 4-1/2" 12.6# L-80 HYD563 Tubing to surface 3.813" X-Nipple 4-1/2" Camco KBMG gas lift mandrels @ TBD CMU Gauge Mandrel (TEC wire with Clamps to Surface) Chem Injection Mandrel (1/4" Line to Surface) 3.813" X-Nipple 4-1/2" Seals REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (6291' RKB) Seal Bore Extension. 4.750" ID (6325' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1H-101 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed new GLD 1H-101 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt General Notes: Last 3 entries Com Date Last Mod By Freeze protected 10-3/4" x 7-5/8" outer annulus with total of 90 bbls IsoTherm 11/29/2017 d142cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 39.1 119.1 119.1 78.67 B SURFACE 10 3/4 9.95 40.7 1,879.3 1,764.6 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.8 6,832.3 3,945.1 29.70 L-80 Hyd 563 LINER 4 1/2 4.00 6,291.9 11,944.9 3,955.1 11.60 L-80 IBT-m Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.1 Set Depth … 5,475.2 Set Depth … 3,632.4 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.1 33.1 0.00 HANGER 10.813 4-1/2" Vetco Grey MB222A offset hanger w/ parent bowl (13.375"-- 10.813 OD) Vetco Grey MB222A offset 5.750 2,763.5 2,303.1 57.06 GAS LIFT 6.437 Camco 4-1/2" x1" KBMG Mandrel, TXP-m ( 2303' TVD) Camco KBMG 3.860 4,438.0 3,190.8 62.69 GAS LIFT 6.437 Camco 4-1/2" x1" KBMG Mandrel, TXP-m ( 3191' TVD) Camco KBMG 3.860 5,247.9 3,552.4 66.28 GAS LIFT 6.437 Camco 4-1/2" x1" KBMG Mandrel, TXP-m ( 3552' TVD) Camco KBMG 3.860 5,316.1 3,579.0 68.01 SLIDING SLEEVE 5.490 4-1/2" Baker CMU w/ 3.812 DB profile Baker CMU w/ 3.812 DB profile 3.812 5,379.6 3,601.7 70.07 GAUGE 5.635 Camco 4-1/2" Solid gauge Mandrel, NDPG, single gauge, TXP-m Camco SGM-FS 3.864 5,446.2 3,623.4 71.65 LOCATOR 5.380 Baker 192-47 locator (OD 5.38") Baker 192-47 3.880 5,447.7 3,623.9 71.68 SEAL ASSY 4.500 Baker 192-47 locator seal assembly w/mule shoe---below located Baker 192-47 3.870 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,763.5 2,303.1 57.06 1 GAS LIFT GLV BK 1 1,481.0 5/29/2020 Schlumb erger Camco BK 0.156 4,438.0 3,190.8 62.69 2 GAS LIFT GLV BK 1 1,545.0 5/29/2020 Schlumb erger Camco BK 0.188 5,247.9 3,552.4 66.28 3 GAS LIFT OV BK 1 0.0 5/29/2020 Schlumb erger Camco BK 0.406 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,291.9 3,851.7 74.39 PACKER 5.500 Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 563 pin Baker PN: H296- 45-0131, Control # 106140604- 01 5.750 6,311.8 3,857.0 74.35 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control # 105769670 4.880 6,344.2 3,865.8 74.27 XO 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# IBT- pin Crossover 3.930 8,290.5 3,954.7 90.63 PACKER 6.340 Baker 6" OD Swell Packer #1 "A" SN: 049169-001-8 Baker 920 Compound 1834, PN H301-87- 0397, SN: 049169-001 3.970 8,646.8 3,971.2 87.08 PACKER 5.950 Baker 6" OD Swell Packer #2 "B" SN: 05826-001-14 Baker 920 Compound 1834, PN H301-87- 0397, SN 052826-001 - 3.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,888.2 8,278.7 3,950.1 3,954.8 WS A2, 1H-101 12/4/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-101, 2/27/2023 1:21:03 PM Vertical schematic (actual) LINER; 6,291.9-11,944.9 SLOTS; 8,656.8-11,901.5 SLOTS; 6,888.2-8,278.6 INTERMEDIATE; 37.8-6,832.3 L1 SLOTTED LINER; 6,186.5- 11,812.7 PACKER; 6,126.7 L2 SLOTTED LINER; 6,028.3- 11,809.0 PACKER; 5,929.5 L3 SLOTTED LINER; 5,834.6- 11,802.3 PACKER; 5,656.0 L4 SLOTTED LINER; 5,559.7- 11,708.5 NIPPLE; 5,494.0 PACKER; 5,439.4 GAUGE; 5,379.6 SLIDING SLEEVE; 5,316.1 GAS LIFT; 5,247.9 GAS LIFT; 4,438.0 GAS LIFT; 2,763.5 SURFACE; 40.7-1,879.3 CONDUCTOR; 39.1-119.1 HANGER; 33.1 KUP PROD KB-Grd (ft) 39.09 RR Date 1/7/2018 Other Elev… 1H-101 ... TD Act Btm (ftKB) 11,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358500 Wellbore Status PROD Max Angle & MD Incl (°) 92.61 MD (ftKB) 9,045.69 WELLNAME WELLBORE1H-101 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,656.8 11,901.5 3,971.7 3,955.5 WS A2, 1H-101 12/4/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-101, 2/27/2023 1:21:04 PM Vertical schematic (actual) LINER; 6,291.9-11,944.9 SLOTS; 8,656.8-11,901.5 SLOTS; 6,888.2-8,278.6 INTERMEDIATE; 37.8-6,832.3 L1 SLOTTED LINER; 6,186.5- 11,812.7 PACKER; 6,126.7 L2 SLOTTED LINER; 6,028.3- 11,809.0 PACKER; 5,929.5 L3 SLOTTED LINER; 5,834.6- 11,802.3 PACKER; 5,656.0 L4 SLOTTED LINER; 5,559.7- 11,708.5 NIPPLE; 5,494.0 PACKER; 5,439.4 GAUGE; 5,379.6 SLIDING SLEEVE; 5,316.1 GAS LIFT; 5,247.9 GAS LIFT; 4,438.0 GAS LIFT; 2,763.5 SURFACE; 40.7-1,879.3 CONDUCTOR; 39.1-119.1 HANGER; 33.1 KUP PROD 1H-101 ... WELLNAME WELLBORE1H-101 ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7'' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: a 1-7-138 MAY 0 8 20119 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Singerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10.404) K Date 5/6/2019 uparuk Field 1J & 1H Corrosion Well Name Initial top of Vol. of cement Final top of Cement tap off Corrosion inhibitor/ API # PTD # cement purr ed cement date inhibitor sealant date It bbls ft al 1J-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 1H-101 50029235850000 2171380 2'10" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 5/5/2019 1H-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 2.2 5/5/2019 1H-1086 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 5/5/2019 1H-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.5 5/5/2019 1H-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2.2 5/5/2019 1 H-111 50029235810000 2171330 2' 0.35 9" 2 5/5/2019 111-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 2.2 5/5/2019 1H-114 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.7 5/5/2019 1 H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 5/4/2019 1.8 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 2 5/5/2019 1H-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 1 H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 1.7 5/5/2019 1H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 2 5/5/2019 5/4/20191.8 5/5/2019