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Home My WebLink About201-083 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 201-083/ TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 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 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-17_15912_KRU_2A-19A_CameraJob_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15912 KRU 2A-19A 50-103-20497-01 Camera Job 17-Mar-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:201-083 T37584 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.07 11:34:59 -08'00' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Kayla Junks at 9:48 am, Mar 29, 2023 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q 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 ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ Stretigraphic ❑ Service ❑ 201-083 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20197-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025571, ADL0025570 KRU 2A-19A 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9681, feet Plugs measured None feet true vertical 6130' feet Junk measured None feet Effective Depth measured 9454' feet Packer measured 8062', 8928' feet true vertical 5942' feet true vertical 5027', 5538' feet Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 121' 121' Surface 3916' 9-5/8" 3957' 2796' Intermediate Production 912V 7" 9160, 5706' Liner 751' 3-1/2" 9679' 6128' Perforation depth Measured depth 9360-9380', 9432-9454' True Vertical depth 5865-5881', 5924-5942' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8945' MD 5550' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker S3 Prod Packer 8062' MD 5027' TVD Packer. Baker ZXP Liner Top Packer 8928" MD 5538' TVD SSSV: None N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Well Remains Shut -In - - - - Subsequent to operation: - - - - - 13b. Pools active after work: Kuparuk River Oil Pool 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.2e3) 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 LJ WDSPL 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: 323-096 Authorized Name and DdcuSMned by: Digital Signature with Date: t -`7. Mar-28-2023 Contact Name: Jonathan Cobedy e5440471U]e2ur6_ Contact Email: ionathan.cobedvCilconocoohillios.com Authorized Title: Staff RWO/ CTD Engineer Contact Phone: (907) 265-1013 Sr Pet Eng: ISr Pat Geo: I ISr Res Eng: DSR-3/29/23 RBDMS JSB 033023 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 C..cPhllltps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time I End Tme Dur per) Phase Ac fty Code Time P-T-X Operation Start Depth(llKB) End Depth(RKB) 2/25/2023 2/25/2023 4.50 MIRU, MOVE MOB P Continue to RDMO / MOB to 2A 0.0 0.0 00:00 04:30 2/25/2023 2/25/2023 1.50 MIRU, MOVE MOB P Cruse Construction trucks on location. 0.0 0.0 04:30 06:00 Load up shop / Parts house / Camp 2/25/2023 2/25/2023 2.00 MIRU, MOVE MOB P Pull pits away from rig prep to transport 0.0 0.0 06:00 08:00 shop pits and office to 2A pad 2/25/2023 2/25/2023 2.00 MIRU, MOVE MOB P Pull rig off well clean up prep mob rig to 0.0 0.0 08:00 10:00 2A 2/25/2023 2/26/2023 14.00 MIRU, MOVE MOB P Mob rig to 2A pad stop at 3F for 45min 0.0 0.0 10:00 00:00 wait on truck to pick up tool at Doyon19 for Doyon 26 // continue mob to 2A 2/26/2023 2/26/2023 4.50 MIRU, MOVE MOB P Continue MOB to 2A-119 0.0 0.0 00:00 04:30 2/26/2023 2/26/2023 1.50 MIRU, MOVE MOB P On Location, Position equipment 0.0 0.0 04:30 06:00 2/26/2023 2/26/2023 1.50 MIRU, MOVE RURD P Stage equipment in cellar// Raise 0.0 0.0 06:00 07:30 derrick // PJSM and prep to spot rig over well 19 2/26/2023 2/26/2023 2.50 MIRU, MOVE RURD P 180' rig and spot over well 0.0 0.0 07:30 10:00 2/26/2023 2/26/2023 2.00 MIRU, MOVE RURD P Spot pits to sub 0.0 0.0 10:00 12:00 2/26/2023 2/26/2023 1.50 MIRU, MOVE RURD P Complete rig up checklist ««« Rig 0.0 0.0 12:00 13:30 Accepted 2/26/23 @ 13:30 ««« 2/26/2023 2/26/2023 2.00 MIRU, WELCTL KLW L P Rig up cellar RU to kill well, 0.0 0.0 13:30 15:30 2/26/2023 2/26/2023 1.25 MIRU, WELCTL KLWL P Pumped 350 BBL's 8.9# NaCl8 BPM 0.0 0.0 15:30 16:45 500 PSI IA 300 PSI 2/26/2023 2/26/2023 0.25 MIRU, WELCTL RURD P Blow down surface eq. 0.0 0.0 16:45 17:00 2/26/2023 2/26/2023 0.50 MIRU, WELCTL OWFF P OWFF for 30 minutes. 0.0 0.0 17:00 17:30 2/26/2023 2/26/2023 0.50 MIRU, WHDBOP OTHR P Set BPV, PT 1000PSi for 10 minites 0.0 0.0 17:30 18:00 2/26/2023 2/26/2023 1.00 MIRU, WHDBOP RURD P Rig down circulation equipment in cellar 0.0 0.0 18:00 19:00 2/26/2023 2/26/2023 1.50 MIRU, WHDBOP NUND P Nipple down tree and adapter, Prep well 0.0 0.0 19:00 20:30 head, Install test dart. Function LDS 2/26/2023 2/26/2023 3.00 MIRU, WHDBOP NUND P Nipple up DSA / BOP equipment 0.0 0.0 20:30 23:30 2/26/2023 2/27/2023 0.50 MIRU, WHDBOP SVRG P Service Rig 0.0 0.0 23:30 00:00 2/27/2023 2/27/2023 1.50 MIRU, WHDBOP RURD P Rig up BOP test equipment, test joint 0.0 0.0 00:00 01:30 Page 1/8 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 C..p Ph Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTee I End Tme Dur per) Phase Ac Ity Code Time P-T-X Operation Start Depth(ftKB) End Depth(ftKB) 2/27/2023 2/27/2023 5.50 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 0.0 0.0 01:30 07:00 250/2500 PSI for 5 Min each, Test annular 250/2500 on 3-1/2"" test joint. Tested, UVBR's and LVBR's on 3-1/2 test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT- 38 FOSV and IBOP. Test 3 I/F EUE FOSV. Test 2" rig floor Demco kill valves. 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=1500 PSI, 200 PSI attained =12 sec, full recovery attained =149 sec. UVBR's= 6 sec, LVBR's= 6 sec. Annular=28 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =2020 PSI. Witnessed waived by AOGCC rep Guy Cook 2/27/2023 2/27/2023 0.50 MIRU, WHDBOP MPSP P Pull test dart and BPV 0.0 0.0 07:00 07:30 2/27/2023 2/27/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 07:30 08:00 2/27/2023 2/27/2023 0.75 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 0.0 0.0 08:00 08:45 Process drill pipe for dean out run 2/27/2023 2/27/2023 1.00 COMPZN, RPCOMP THGR P Install landing joint // Set 10K down on 8,910.0 8,875.0 08:45 09:45 hanger back out LDS // P/U on tubing, hanger off seat @ 120K. PUW=105K. 2/27/2023 2/27/2023 1.25 COMPZN, RPCOMP CIRC P Circulate B/U @ 6 BPM, 700 PSI. 8,875.0 8,875.0 09:45 11:00 2/27/2023 2/27/2023 6.50 COMPZN, RPCOMP PULL P Lay down 3-1/2" Completion string F/ 8,875.0 3, 100.0 11:00 17:30 8875' T/ 3100', PUW=85K. 2/27/2023 2/27/2023 1.50 COMPZN, RPCOMP MPSP P M/U 7" storm packer. RIH and set @ 3,100.0 3,166.0 17:30 19:00 66' COE. Release from packer. L/D setting tool. 2/27/2023 2/27/2023 0.50 COMPZN, RPCOMP PRTS P PT storm packer against blinds, T/ 1000 0.0 0.0 19:00 19:30 PSI for 10 Minutes - GOOD 2/27/2023 2/27/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 19:30 20:00 2/27/2023 2/27/2023 1.50 COMPZN, RPCOMP NUND P Blow down choke and kill lines. Nipple 0.0 0.0 20:00 21:30 down stack and riser. Nipple down DSA. Disconnect kill line swivel 2/27/2023 2/27/2023 1.00 COMPZN, RPCOMP NUND P Prep cellar and well head, Remove IA 0.0 0.0 21:30 22:30 valves and flanges. Bleed off void. Confirm no flow from CA 2/27/2023 2/28/2023 1.50 COMPZN, RPCOMP NUND P PJSM w/ Hydratite rep. Break casing 0.0 0.0 22:30 00:00 adapter bolts. Rig up casing growing equipment 2/28/2023 2/28/2023 3.00 COMPZN, RPCOMP CUTP P Rig up Hydratite casing growing 0.0 0.0 00:00 03:00 equipment. Start releasing compression on 7". Initial pressure 17K. 39 Cycles. Final growth 24.75" 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP RURD P Rig down / load out Hydratight 0.0 0.0 03:00 03:30 equipment 2/28/2023 2/28/2023 0.70 COMPZN, RPCOMP CUTP P M/U 7" casing spear, Latch casing, Pull 0.0 0.0 03:30 04:12 100K over hook. Casing stretched 13". Re -land in emergency slips. Total growth of 37.75". 2/28/2023 2/28/2023 0.30 COMPZN, RPCOMP BHAH P Release spear, Lay down spear 0.0 0.0 04:12 104:30 Page 2/8 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 ca,.c�Ph Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time I End Tme Dur(hr) Phase Ac Ity Code Time P-T-X Operation Start Depth(flKB) End Depih(RKB) 2/28/2023 2/28/2023 1.50 COMPZN, RPCOMP CUTP P Make final cut on 7" casing above 0.0 0.0 04:30 06:00 casing spool w/ WACHS saw. Redress and re -install Gen 4 Type AS 11" x 7" primary pack off seal. 2/28/2023 2/28/2023 2.75 COMPZN, RPCOMP NUND P Install new 7 1116" top by 11" 3K C bowl 0.0 0.0 06:00 08:45 tubing spool w/ 7" NX secondary packoff bushing. Install 2nd IA valve on spool. 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP PRTS P PT packoff void T/ 3000 PSI for 15 Min - 0.0 0.0 08:45 09:15 Good test. 2/28/2023 2/28/2023 2.25 COMPZN, RPCOMP NUND P Install test plug. N/U DSA and BOP. 0.0 0.0 09:15 11:30 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 11:30 12:00 2/28/2023 2/28/2023 1.00 COMPZN, RPCOMP RURD P Fill stack w/ fresh water. R/U testing 0.0 0.0 12:00 13:00 equipment. Thaw out test pump manifold 2/28/2023 2/28/2023 1.00 COMPZN, RPCOMP PRTS P PT BOP stack breaks and kill line 0.0 0.0 13:00 14:00 breaks 250/2500 PSI. Leak on kill line. Retest BOP stack breaks and kill line breaks 250/2500 PSI - Good test 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP RURD P Suck out stack. Pull test plug. R/D 0.0 0.0 14:00 14:30 testing equipment. 2/28/2023 2/28/2023 0.75 COMPZN, RPCOMP MPSP P M/U storm packer retrieval tool. P/U 2 3,166.0 3,100.0 14:30 15:15 singles. Engage packer and release. POOH and UD storm packer. PUW=50K. 2/28/2023 2/28/2023 0.25 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 3,100.0 3,100.0 15:15 15:30 2/28/2023 2/28/2023 4.50 COMPZN, RPCOMP PULL P UD 3 1/2" completion F/ 3100' T/ 3,100.0 0.0 15:30 20:00 surface, PUW=50K. Cut joint=4.8". Cut condition looks good. Cut joint major erosion. Couplers on last 20 joints show corrosion . Photos on file. Clean and dear rig floor 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP SVRG P Service Rig, Top Drive, Crown, and Iron 0.0 0.0 20:00 20:30 rough neck 2/28/2023 2/28/2023 0.50 COMPZN, RPCOMP RURD P Install wear ring bushing. 6 7/16" ID, 0.0 0.0 20:30 21:00 Rum in two LDS 2/28/2023 2/28/2023 1.00 COMPZN, RPCOMP BHAH P Pick up BOT BHAJars & Bumper sub. 0.0 0.0 21:00 22:00 Pick up overshot 2/28/2023 3/1/2023 2.00 COMPZN, RPCOMP WAIT T Wrong size grapple in package. Will not 0.0 0.0 22:00 00:00 fir in housing. Hot shot grapple from Deadhorse 3/l/2023 3/1/2023 1.50 COMPZN, RPCOMP WAIT T Wailing on Grapple. House keeping on 0.0 0.0 00:00 01:30 rig floor, pits, and cellar 3/l/2023 3/1/2023 1.00 COMPZN, RPCOMP BHAH P Grapple on location. Install into housing. 0.0 228.3 01:30 02:30 Make up drilling BHA#3 with hollow mill conlainer,Overshot, LBS, Jars, 6 Drill collars, and accelerator T/ 228', SOW=38K. 3/l/2023 3/1/2023 7.50 COMPZN, RPCOMP PULD P Trip in hole with 3 1/2" work string F/ 228.3 8,837.0 02:30 10:00 238' T/ 8837', PUW=155K, SOW=92K. 3/l/2023 3/1/2023 2.00 COMPZN, RPCOMP FISH P Kelly up ROT @ 40 RPM, 8.6K Free Tq. 8,837.0 8,945.0 10:00 12:00 RIH saw fish top @ 8900'. Swallowed T/8906'. Warm up jars. Start hitting jars @ 50K over working up T/ 100K over. Straight pull starting @ 120K over working up T/ 165K over. Total of 65 hits no pipe movement. 3/1/2023 3/1/2023 0.50 COMPZN, RPCOMP SVRG P Service rig - post jarring inspection. No 8,945.0 8,945.0 12:00 12:30 deficiencies identified. Consult with town. Decision made to straight pull to 95% tensile. Page 318 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time I End Tme Dur(hr) Phase Ac Ity Code Time P-T-X Operation Start Depth(fiKB) End Depih(RKB) 3/1/2023 3/1/2023 1.75 COMPZN, RPCOMP FISH P Jar @ 100K over work straight pull up F/ 8,945.0 8,833.0 1230 1415 165K over T/ 195K over. 30 Hits no pipe movement. Consult with town. Decision made to release from fish and change completion plan to poorboy overshot stacker packer. Rotate T/ the right to release form fish. Pipe free, PUW=155K. Rackbackl stand T/ 8832'. B/D TD. Remove blower hose. 3/1/2023 3/1/2023 3.00 COMPZN, RPCOMP TRIP P POOH F/ 8833' T/ 228', PUW=155K. 8,833.0 228.0 14:15 17:15 3/1/2023 3/1/2023 1.25 COMPZN, RPCOMP BHAH P L/D BHA#3. 14' piece of 3 1/2" tubing 228.0 0.0 17:15 18:30 stub twisted off in grapple. Consult with town. Decision made to procede with dummy packer drift with wash pipe and dress off mill 3/1/2023 3/1/2023 0.50 COMPZN, RPCOMP SVRG P Service rig, Skate, top drive 0.0 0.0 18:30 19:00 3/1/2023 3/1/2023 1.20 COMPZN, RPCOMP BHAH P M/U BHA#4 w/ wavey bottom shoe, 0.0 47.9 19:00 20:12 wash pipe ext., dress off mill, Dial pin X- O, 6.125 string mill, flex joint, 6.125 string mill, bumper sub, Jars, XO. OAL=47.92' 3/1/2023 3/2/2023 3.80 COMPZN, RPCOMP TRIP P Trip in well with dummy packer, 47.9 to 47.9 7,995.0 20:12 00:00 7995 midnight. Clean trip. No stacking observed 3/2/2023 3/2/2023 1.00 COMPZN, RPCOMP TRIP P Continue RIH F/ 7995' T/ 8184', 7,995.0 8,184.0 00:00 01:00 PUW=160K, SOW=80K. 3/2/2023 3/2/2023 0.50 COMPZN, RPCOMP SVRG P Service Rig. 8,184.0 8,184.0 01:00 01:30 3/2/2023 3/2/2023 1.90 COMPZN, RPCOMP WASH P Wash down F/ 8184' T/ 8846', @ 5 8,184.0 8,846.0 01:30 03:24 BPM. 920 PSI, PUW=160K, SOW=80K. 3/2/2023 3/2/2023 0.20 COMPZN, RPCOMP REAM P Obtain parameters @ 8846' 8,846.0 8,846.0 03:24 03:36 PUW=160K. SOW=80K pumping @ 5 BPM, 1000 PSI. Rotate @ 30 RPM, 8.5K Free Tq. ROT=105K. 3/2/2023 3/2/2023 1.00 COMPZN, RPCOMP REAM P Make up last stand. Wash and ream F/ 8,946.0 8,911.0 03:36 04:36 8846' T/ 8911'. See initial torque @ 8910'. Call TOF @ 8911'. Back ream up. RIH, Bring RPM to 50 RPM 8420 Lb/Ft torque, Pump 5 BPM @ 1100, PUW=170K, SOW=105K 3/2/2023 3/2/2023 2.40 COMPZN, RPCOMP MILL P Mill F/ 8911' T/ 8913.7', @ 5 BPM, 1050 8,911.0 8,913.7 04:36 07:00 PSI, Torque 9.4-11.5K. 4-6K WOB 3/2/2023 3/2/2023 1.00 COMPZN, RPCOMP CIRC P Pump 35 Bbls 75 hi-vis sweep around. 8,913.7 8,913.7 07:00 08:00 Chased out of hole @ 7.5 BPM, 2300 PSI. Dumped sweep as it returned to surface. 3/2/2023 3/2/2023 0.50 COMPZN, RPCOMP TRIP P OWFF. Rack back 1 stand T/8842. 8,913.7 8,842.0 08:00 08:30 3/2/2023 3/2/2023 3.75 COMPZN, RPCOMP BKRM P BKRM OOH F/ 8842' T/ 8184'. @ 5 8,842.0 8,184.0 08:30 12:15 BPM, 830 PSI. 60 RPM, 9.8K free Tq. ROT=110K. Back ream each stand up, back down, and backup. 9.8-11 K Tq. ROT PUW 110-120K. 3/2/2023 3/2/2023 0.25 COMPZN, RPCOMP OWFF P OWFF-no flow. B/D TD. R/D blower 8,184.0 8,184.0 12:15 12:30 hose. 3/2/2023 3/2/2023 3.00 COMPZN, RPCOMP TRIP P POOH F/ 8184 T/ 47', PUW=155K 8,184.0 47.0 12:30 15:30 3/2/2023 3/2/2023 0.50 COMPZN, RPCOMP SHAH P L/D BHA #4 F/ 47' T/ surface. Inspect 47.0 0.0 15:30 16:00 mill - light wear patern on mill. 3/2/2023 3/2/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. IR and draw works. 0.0 0.0 16:00 16:30 Page 4/8 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTee I End Tme Dur per) Phase AclWity Code Time P-T-X Operation Start Depth(WB) End Depih(RRB) 3/2/2023 3/2/2023 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor and pipe shed. 0.0 0.0 16:30 17:00 3/2/2023 3/2/2023 1.00 COMPZN, RPCOMP RURD P R/U tubing handling equipment. 0.0 0.0 17:00 18:00 Complete processing 3 1/2" EUE-M completion string. Verify joint count. 3/2/2023 3/3/2023 6.00 COMPZN, RPCOMP PUTS P Pickup/RIH on 3,5" EUE-M Tubing 0.0 3,909.0 18:00 00:00 String T/ 3909', SOW=50k, PUW=55k 3/3/2023 3/3/2023 5.50 COMPZN, RPCOMP PUTS P Continue RIH on 3,5" EUE-M Tubing 3,909.0 8,902.0 00:00 05:30 String F/ 3909 T/ 8902', PUW=92, SOW- 62K. 3/3/2023 3/3/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. 8,902.0 8,902.0 05:30 06:00 3/3/2023 3/3/2023 1.25 COMPZN, RPCOMP HOSO P Kelly up on joint # 289. Pump @ 2 8,902.0 8,920.0 06:00 07:15 BPM, 150 PSI. S/O pressure spike T/ 250 PSI @ 8918.5. Indication shear pins popped. Set down 20K @ 8923.8'. P/U T/ 8921'. Mark pipe. UD joints #289 & #288. M/U space out pups 10.2% 4.45% 4.21', 2.07'. M/U joint #288. RIH and swallow sub 1' from fully located, bottom of overshot @ 8922'. M/U 3 1/2" EUE FOSV on top of string. 3/3/2023 3/3/2023 1.25 COMPZN, RPCOMP RURD P R/U HES slick line. 8,920.0 8,920.0 07:15 08:30 3/3/2023 3/3/2023 1.75 COMPZN, RPCOMP SLKL P RIH w/ 2.80" dummy drift run T/ 8918' 8,920.0 8,920.0 08:30 10:15 SL depth, Could not pass. POOH. Consult with town, decision made to make 2.71" drift run. 3/3/2023 3/3/2023 1.75 COMPZN, RPCOMP SLKL P RIH w/ 2.71" dummy drift run T/ 8928' 8,920.0 8,920.0 10:15 12:00 SL depth, 10' past tubing stub, could not pass further. POOH. Consult with town, decision made to make 2.5" bailer run. 3/3/2023 3/3/2023 1.50 COMPZN, RPCOMP SLKL P RIH w/ 5% 2.5" mule shoe ball type bailer 8,920.0 8,920.0 12:00 13:30 T/ 8928' SLM. Hard bottom bottom. Unable to make any hole. POOH' 3/3/2023 3/3/2023 1.00 COMPZN, RPCOMP RURD P At surface w/slickline. Bailer mostly 8,920.0 8,920.0 13:30 14:30 brine, pipe dope, and metal slivers. No big pieces. Consult town, RID slickline 3/3/2023 3/3/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. 8,920.0 8,920.0 14:30 15:00 3/3/2023 3/3/2023 4.75 COMPZN, RPCOMP TRIP P POOH F/ 8920' T/ surface racking back 8,920.0 0.0 15:00 19:45 3 1/2" completion string. UD poorboy overshot. PUW=95K 3/3/2023 3/3/2023 1.00 COMPZN, RPCOMP PULD P Prep RF for running in on DP 0.0 19:45 20:45 PU TST III Storm Packer and place in mouse hole, remove protective cover, visqueen, and inspect elements, Pull out of mouse hole, and leave hanging on elevators PU "G" RBP, place in mouse hole, remove protective cover and inspect packer element. 3/3/2023 3/3/2023 0.50 COMPZN, RPCOMP PULD P Crew change, PJSM with Rig team, and 0.0 0.0 20:45 21:15 third parry BOT. 3/3/2023 3/3/2023 0.50 COMPZN, RPCOMP PULD P Stab "L" Retrieveing tool onto "G" RBP, 0.0 49.8 21:15 21:45 PU out of mouse hole, and place in hole in slip and w/dog collar. 3/3/2023 3/4/2023 2.25 COMPZN, RPCOMP TRIP P RIH onfDP w/BHA#5 w/ 3.5" "G" RBP 49.0 6,956.0 21:45 00:00 and TST III Storm packer F/ 49' T/ 6956', SOW=83K Page 518 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 C..p Ph Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time I End Tme Der per) Phase Ac fty Code Time P-T-X Operation Start Depth(flKB) End Depth(RKB) 3/4/2023 3/4/2023 1.00 COMPZN, RPCOMP TRIP P Continue RIH w/3.5" NC38/ DP w/BHA 6,956.0 8,816.0 00:00 01:00 #5 w/ 3.5" "G" RBP and TST III Storm packer F/6,956' SOW=83k 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP PRTS P Set "G" Plug @ 8,808', release from G- 8,816.0 8,808.0 01:00 01:30 plug, PT x 2 Failed Test bleed pressure off 3/4/2023 3/4/2023 0.75 COMPZN, RPCOMP PRTS P PUH, PUW=188k, SOW=88k, Set test 8,808.0 8,724.0 01:30 02:15 packer and PT @ 8,766' & 8,724' Failed tests, bleed pressure off 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP TRIP P Release test packer 8,724.0 8,247.0 02:15 02:45 Very ratty POOH, PUW=206k, w/15-20k weight swings, SOW=88k, hesitate to relax element Rack back 5 stands 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP PRTS P PUH, PUW=196k, SOW 87k, Set and 8,247.0 8,157.0 02:45 03:15 PT @ 8,247' & 8,157' Failed tests, bleed pressure off 3/4/2023 3/4/2023 0.75 COMPZN, RPCOMP TRIP P Release test packer 8,157.0 7,776.0 03:15 04:00 PUH, PUW=165k, SOW=88k, hesitate to relax element Rack back 5 stands 3/4/2023 3/4/2023 0.30 COMPZN, RPCOMP PRTS P PUH, Set and PT @ 7,776' 7,776.0 7,776.0 04:00 04:18 *** Good Test ***, SOW=82k 3/4/2023 3/4/2023 0.20 COMPZN, RPCOMP PRTS P RIH 1 stand, PUW=155k, SOW=72k 7,776.0 7,872.0 04:18 04:30 Set and PT @ 7,872' ** Good Test 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP SVRG P Service Rig 7,872.0 7,872.0 04:30 05:00 Top Drive and Iron rough necks 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP PRTS P RIH 1 stand 7,872.0 7,966.0 05:00 05:30 Set and PT @ 7,966' `* Good Test 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP PRTS P RIH 1 stand 7,966.0 8,063.0 05:30 06:00 Set and PT @ 8,063' `* Good Test `** 3/4/2023 3/4/2023 0.80 COMPZN, RPCOMP TRIP P RIH F/ 8063' T/ 8816'. 8,063.0 8,816.0 06:00 06:48 3/4/2023 3/4/2023 0.70 COMPZN, RPCOMP MPSP P Engage G plug. Rotate right and release 8,816.0 8,816.0 06:48 07:30 3/4/2023 3/4/2023 0.75 COMPZN, RPCOMP PULD P Trip out of hole laying down DP. F/ 8816 8,816.0 7,894.0 07:30 08:15 T/7894', PUW=175K 3/4/2023 3/4/2023 1.75 COMPZN, RPCOMP SLPC P Slip and cut 90' drill line 7,894.0 7,894.0 08:15 10:00 3/4/2023 3/4/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease blocks and crown. 7,894.0 7,894.0 10:00 10:30 3/4/2023 3/4/2023 6.00 COMPZN, RPCOMP PULD P LOOP F/ 7894' T/ 49', PUW=150K. 7,894.0 49.0 10:30 16:30 3/4/2023 3/4/2023 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #5. All components at 49.0 0.0 16:30 17:30 surface 3/4/2023 3/4/2023 1.00 COMPZN, RPCOMP PUTB P Prep RF for running completion 0.0 0.0 17:30 18:30 Load/Inspect Jewelry in pipeshed PJSM with Rig Team and Baker 3/4/2023 3/5/2023 5.50 COMPZN, RPCOMP PUTB P PU PoorBoy Overshot, redress with new 0.0 6,990.0 18:30 00:00 shear pins x 3, Pickup/Run 3,5" EUE-M Tubing String completion as per approved tally Midnight SOW=6,990' 3/5/2023 3/5/2023 1.50 COMPZN, RPCOMP PUTB P Continue IH w/3,5" EUE-M Tubing 6,990.0 8,733.0 00:00 01:30 String completion as per approved tally Midnight SOW=6,990' Page 6/8 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db2A-19 RIG RELEASE DATE 3/6/2023 C..o Ph Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time I End Tme Dur(hr) Phase Ac Ity Code Time P-T-X Operation Start Depth(fiKB) End Depih(RKB) 3/5/2023 3/5/2023 1.25 COMPZN, RPCOMP PUTB P Single In to joint #283, bring pump 8,733.0 8,890.0 01:30 0245 online @ 2.0 bpm @ 160 psi pump pressure, slowly lower joint #284. see pressure increase 235 psi @ 8,916', shut down pump, continue IH slow, fully locate @ 8,922' w/6 k down, pick back up and repeat same, PU 2'to 8,920', mark pipe, 5' stick out of hole - 18.5' on joint #284 Layout 30.76' and 18.5' = 49.26', 49.26'- (Rig RKB, Hanger and pup) 30.88'= 18.38' MU spacer pups 10.20' and 8.21' (18.41') to bottom of joint #282 3/5/2023 3/5/2023 0.75 COMPZN, RPCOMP PUTB P MU hanger to landing joint w/head pin 8,890.0 8,890.0 02:45 03:30 and cement hose, place above rig floor 3/5/2023 3/5/2023 2.25 COMPZN, RPCOMP CIRC P Circulate 277 bbls 8.9 ppg Cl down the 8,890.0 8,890.0 03:30 05:45 tubing, chased w/ 10 Bbls 8.9 PPG NaCl taking returns up the IA, 3 bpm @ 232 psi 3/5/2023 3/5/2023 0.75 COMPZN, RPCOMP HOSO P RIH and land hangerw/ bottom of 8,890.0 8,920.2 05:45 06:30 overshot @ 8920.2' ORKB. RILDS. Drop 1 5116" ball and rod. 3/5/2023 3/5/2023 0.50 COMPZN, RPCOMP PACK P Pressure up on tubing T/ 3500 PSI and 8,920.2 8,920.2 06:30 07:00 set S-3 packer. Hold pressure for 15 min allow element to expand. 3/5/2023 3/5/2023 1.50 COMPZN, RPCOMP PRTS P PT tubing T/ 3000 PSI for 30 min - Good 8,920.2 8,920.2 07:00 08:30 test. Bleed TBG T/ 1500 PT IAT/ 2500 PSI for 30 Min - Good test. Dump TBG pressure shear out SOV. Pump down IA @ 2 BPM, 870 PSI. 3/5/2023 3/5/2023 0.50 COMPZN, RPCOMP RURD P B/D cement line. L/D landing joint. 8,920.2 8,920.2 08:30 09:00 3/5/2023 3/5/2023 0.50 COMPZN, RPCOMP MPSP P Set HP BPV. 8,920.2 8,920.2 09:00 09:30 3/5/2023 3/5/2023 0.50 COMPZN, RPCOMP PRTS P PT BPV From below T/ 1000 PSI for 15 8,920.2 0.0 09:30 10:00 1 1 Min. 3/5/2023 3/5/2023 0.50 COMPZN, WHDBOP SVRG P Service rig. Service tubing tongs. 0.0 0.0 10:00 10:30 3/5/2023 3/5/2023 1.50 COMPZN, WHDBOP SFTY P Training w/ Doyon casing rep on tubing 0.0 0.0 10:30 12:00 tongs. 3/5/2023 3/5/2023 1.00 COMPZN, WHDBOP CLEN P Jet BOP stack. B/D surface lines. Suck 0.0 0.0 12:00 13:00 BOP out. 3/5/2023 3/5/2023 9.00 COMPZN, WHDBOP SVRG P Between well maintenance. 0.0 0.0 13:00 22:00 LVBR's 3 1/2" x 5 1/2" packers and top seals changed out proactively. Door seals replaced. 3/5/2023 3/5/2023 0.50 COMPZN, WHDBOP SVRG P Service Rig 0.0 0.0 22:00 22:30 3/5/2023 3/5/2023 0.50 COMPZN, WHDBOP RURD P Nipple down BOP stack and DSA, 0.0 0.0 22:30 23:00 secure on peg. 3/5/2023 3/6/2023 1.00 COMPZN, WHDBOP RURD P Install tree test dart, MU new adaptor 0.0 0.0 23:00 00:00 flange and new 3-1/8" 5k wellhead PT hanger void T/5000 psi, PT Wellhead to 5,000 psi. Pull tree test dart and BPV. 3/6/2023 3/6/2023 1.00 COMPZN, W HDBOP RURD P Spot in & RU LRS drillers side of rig, PT 0.0 0.0 00:00 01:00 1 1 1 1 lines to 3,500 psi Page 718 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) db 2A-19 RIG RELEASE DATE 3/6/2023 C..p Ph Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTee I End Tme Dur(hr) Phase Ac Ity Code Time P-T-X Operation Start Depth(ftKB) End Depth(ftKB) 3/6/2023 3/6/2023 1.00 COMPZN, W HDBOP FRZP P Circulate 71 bbls of diesel freeze protect 0.0 0.0 01:00 02:00 down the IA @ 2.0 bpm/1,100 psi pump pressure, taking returns to the tiger tank. Shut down pump, bleed pressure off of lines, blow down tiger tank line. , back and RD LRS hose. 3/6/2023 3/6/2023 1.00 COMPZN, WHDBOP RURD P Allow well to U-Tube until pressure 0.0 0.0 02:00 03:00 stabilize. 180 psi on tubing, 0 on the IA Sim-ops, RU bridle line to blocks `"` Final Pressures Tubing=150, IA=150, OA=65 "" 3/6/2023 3/6/2023 1.00 DEMOB, MOVE RURD P Prep RF for laying over derrick 0.0 0.0 03:00 04:00 Lay down cattle shoot and hand rails, etc. 3/6/2023 3/6/2023 2.00 DEMOB, MOVE RURD P Lay over derrick 0.0 04:00 06:00 Work Rig move check list, load out trucks, call out electrician and disconnect support modules Rig Release @ 06:00am Page 8/8 Report Printed: 3/24/2023 KRU 2A-19A RWO Summary of Operations DTTMSTARTJOBTYP SUMMARYOPS 11/13/2022 ACQUIRE DATA BRUSH n' FLUSH RBP INTERVAL FROM 8950'-9050' RKB; DRIFT W/ 2.72" DMY RBP DOWN TO 9226' RKB. READY FOR E-LINE TO SET RBP. 11/15/2022 ACQUIRE DATA SET QUADCO 3.5" PIIP RPB AT 9005' RKB (MID -ELEMENT), CCL TO ME = 11.8% CCL STOP DEPTH = 8993.2' pro] =ZKi7LIFAl»:0Iq 2/14/2023 ACQUIRE DATA (PRE RWO) FUNCTION TESTED ALL T & IC LDS/GN'S, T-POT (PASS), T-PPPOT (PASS), IC -POT (PASS), TIGHTEND IC STUD BOLTS, IC-PPPOT (PASS), MIT-OA TO 1800 PSI (PASS), 2/19/2023 ACQUIRE DATA SET 2.79" CATCHER SUB W/ 3-1/2" RBP STINGER (63" OAL) ON TOP OF RBP @ 9002' RKB, PULLED 1-1/2" OV FROM STATION # 5 @8891' RKB. JOB IN PROGRESS, READY FOR E-LINE 2/20/2023 SUPPORT OTHER RIG UP E-LINE FOR TUBING CUT. FIRE STRINGSHOT OVER THE INTERVAL OPERATIONS FROM 8902' - 8912'. CCL TO TOP = 4.75'. CCL STOP DEPTH = 8897.25'. CUT TUBING WITH CHEMICAL CUTTER AT 8910'. CCL TO SEVERING HEAD = 11.1', CCL STOP DEPTH = 8898.9'. JOB COMPLETE. 2/21/2023 ACQUIRE DATA (PRE RWO) BLED GAS FROM IA FOR RIG PREP (COMPLETE) 2/25/2023 RECOMPLETION Complete RDMO 3G, MOB to 2A-19 2/26/2023 RECOMPLETION On 2A, Spot sub & pits, Raise Derrick, R/D bridal lines, R/U interconnect. Load 540 BBIs 8.9PPG brine to pits. R/U circulation lines in cellar. Pump 340 BBIs brine around. Flow checlk well. Install BPV. N/D tree and adapter. Nipple up BOPE. 2/27/2023 RECOMPLETION Complete BOPE Test. M/U landing joint, Back off LDS. Pull hanger to floor. Circ BU. Pull 3 1/2 completion 8800 to 3100'. Make up storm packer, Trip in 66'. Set packer and PT 1000 PSI /10 Min. Nipple down stack. Nipple down DSA. Break casing hanger bolts. M/U Hydratite expansion control tool. 2/28/2023 RECOMPLETION Grow 7" casing total of 24.75" of growth. Rig down hydratight equipment. Engage 7" spear pull 100K tension in 7". Re -land in emergency slips. 13" of stretch, total growth of 38.75". Rlg up WACHS saw. Make final cut 7" casing above casing head. Redress and re -install Gen 4 Type AS 11" x 7" secondary seal pack off. Nipple up stack. PT connection. M/U storm packer retrieval tool. Latch and release packer. Trip out lay down packer. Pull rest of completion to cut — 3100'. M/U overshot fishing BHA to retrieve seal Ass. 3/1/2023 RECOMPLETION Pick up drill pipe T/ 8900'. Engage tubing stub. Attempt to jar seals free unsuccessfully. Rotate to right attempt to release grapple. Pipe free. Pull out of hole. Lay down BHA #3. Make up BHA #4 Dress off mill and tandem 6 1/8" string mills. Run in hole T/ 7995'. 3/2/2023 RECOMPLETION Continue run in hole and wash and ream F/ 8200' T/ tubing stub @ 8911'. Dressing off tubing stub T/ 8913.7'. Pump hi-vis pill around. Back ream out of hole F/ 8842' T/ 8184'. Pull out of hole F/ 8184' T/ 47'. Lay down BHA #4. Complete processing 3 1/2" EUE-M tubing string. Rig up tubing handling equipment. MU BHA #5 w/poorboy overshot, RIH on tubing string to 3,909' 3/3/2023 RECOMPLETION Continue run in hole with 3'/2" EUE tubing string. Wash down joint #289 @ 2 BPM T/ locate tubing stub. Full locate @ 8922'. Space out. Rig up slick line. Run 2.8" drift tagged tubing stub. Run 2.71" drift past tubing stub. Run 2.5" bailer, minimal returns. Rig down slick line. Pull out of hole racking back 3 1/2" completion string, lay down poorboy overshot. MU/Run BHA #5 G-plug w/test packer to 6,956' 3/3/2023 SUPPORT OTHER DRIFT W/ 2.80" BAR BELL ASSEMBLY TAG @ 8919, RKB UNABLE TO PASS OPERATIONS THROUGH TBG STUB, DRIFT THROUGH TBG STUB W/ 2.71" SWAGE @ 8919' RKB TAG @ 8928' RKB, RAN 2.5" x 5' BAILER TAG @ SAME. JOB COMPLETE. 3/4/2023 RECOMPLETION Continue IH on 3.5" DP w/BHA #5 F/ 6956' T/ 8816'. Test, Set "G" Plug, test failed, PUH, working up hole to find competent 7" casing. Passing test @ 7776'. Working back in hole 1 stand at a time to find leak point. narrow down competent 7" casing to 8,063'. retrieve G-plug. POOH, LID DP sideways. Prep/Run Completion, Redress/MU Poorboy overshot, begin running 3.5" completion as per approved tally. T/6,990' SOW=55k 3/5/2023 RECOMPLETION Continue RIH w/3.5" EUE, fully locate @ 8,919', Space out, MU hanger and landing joint, circulate 277 bbls of 8.9 ppg Cl chased with 10 BBI 8.9PPG NaCl. Land hanger. RILDS. Drop ball and rod. Pressure up and set packer 3,500 PSI. PT Tubing to 3,000 psi F/ 30 min. Bleed tubing T/ 1,500 PSI, PT IA 2,500 psi F/ 30 min. Dump Pressure on tubing to shear the SOV.. Pull landing joint.Set HP BPV. PT from below T/ 1000 PSI for 10 Min. B/D surface lines. Perform between wells maintenance. Nipple down BOP stack and DSA, Install tree test dart, NU wellhead and adaptor spool, PT hanger void & Tree T/5k, Pull test dart and BPV, 3/6/2023 RECOMPLETION RU LRS, PT lines to 3,500 psi, pump 71 bbls of diesel freeze protect down the IA taking turns to the Tiger tank, U-Tube well, Secure tree and cellar, RDMO. 3/10/2023 SUPPORT OTHER SHAKE OFF BAITED BELLED PULLING TOOL ABOVE BALL n' ROD @ 8110' RKB; OPERATIONS PULLED SOV & SET OV @ 8003' RKB; PULLED DV & SET GLV @ 7884' RKB. IN PROGRESS. 3/11/2023 SUPPORT OTHER PULLED DV & SET GLV @ 3877' RKB; PULLED CATCHER, BALL n' ROD, & 2.813" OPERATIONS RHC PLUG @ 8810' RKB; DRIFT W/ 2.25" BAILER & UNABLE TO PASS 8916' RKB; RAN BARBELL ASSEMBLY W/ 1.5" BAILER & TAGGED AT SAME; RAN MULTIPLE DRIFT'S TAGGING @ SAME 8916' RKB; RAN 2.70" IMPRESSION BLOCK & 2.79" IMPRESSION BOCK ON DE -CENTRALIZER @ TAGGED AT SAME (PICTURES SUGGEST @ TBG STUB OR METAL DEBRIS ACROSS TBG STUB / SEE ATTACHMENTS). READY FOR CTU. 3/16/2023 SUPPORT OTHER TRAVEL FROM 3Q TO 2A. ON WEATHER STANDBY DUE TO COLD OPERATIONS TEMPERATURES, -36*F, FROM 04:00 TO 10:00. MIRU. BOP TEST. JOB IN PROGRESS. 3/17/2023 SUPPORT OTHER MIRU ON 2A-19A. P/U 2.50 DJN F/ DRIFT. RIH T/ 8896, TAG, CIRC DIESEL WHILE OPERATIONS RIH. POH, F/P 2500' AND CLOSE SWAB. LINE UP T/ PUMP DOWN COIL W/ F/W AND BLOW DOWN COIL W/ NITROGEN AND POP OFF. M/U READ CAMERA. POP ON, PT 4200 PSI, OPEN UP SWAB, RIH, TAG @8922.7 CTM. RUN CAMERA FOR 60 MINS. CROSS CAMERA W/ 15 BBLS METH AND 20 BBLS F/W, CHASE W/ N2. ALL GOOD. POOH AND F/P 2600', CLOSE SWAB, R/U NIGHT CAP, GO TO DAYLIGHT ONLY. *JOB IN PROGRESS* 3/18/2023 SUPPORT OTHER R/U BHA # 3 W/ QUADCO TOOLS. PT 4200 PSI, RIH AND TAG @ 8925', MILLING F/ OPERATIONS 8925 TO 8960', SHUT DOWN PUMP AND DRY DRIFT T/ 8981' CTM. TAG 8981', P/U 5', PUMP 3 BBLS D/G SWEEP AROUND, POOH. UD BHA #3, M/U BHA #4, CHANGE OUT PACK OFF, INSTALL NIGHT CAP, P.T. 2500 PSI, ALL GOOD. *JOB IN PROGRESS* 3/19/2023 SUPPORT OTHER PJSM W/ CREW. M/U BHA #4 VENTURI RUN, RIH T/ 8962' CMD, POOH, L/D OPERATIONS QUADCO VENTURI TOOL,M/U # 5 BHA GS SPEAR. VENTURI CONTENTS: PIECES OF METAL,ONE SMALL BRASS PIECE (picture in attachments). RIH W/GS SPEAR, NO GO @ 8910 CTM, ATTEMPT 15 TIMES PUMPS ON/PUMPS OFF AND WORK STRING, NO GO. POOH, L/D BHA# 5, INSTALL NIGHT CAP, PT 2500 PSI, ALL GOOD. COULD NOT FIND ANY DAMAGE ON GS SPEAR *JOB IN PROGRESS* 3/20/2023 SUPPORT OTHER PJSM W/ CREW, POP ON, PT QCS 4200PSI, ALL GOOD. OPEN UP SWAB, RIH, OPERATIONS TAG @ 8907' CTM, WORK PIPE @ TOP OF STUB, NO GO. POOH, UD BHA #6 AND M/U # 7, ADD WT BARS, ATTEMPT BACK BEND COIL. POP ON, PT, RIH. TAG CATCHER AND LATCH UP, SET DOWN 5000K @ 8981', POOH. UD BHA # 7, NO FISH. *JOB IN PROGRESS* 3/21/2023 SUPPORT OTHER PJSM / POP ON, PT, RIH W/ BHA #8. TAG FISH @8979.9, WORK PIPE, SET DOWN OPERATIONS 4 TIME W/ VENTURI, POOH, RECOVER 3 SMALL METAL PIECES & 1 1/2 CUP OF SAND. M/U BHA 9 GS SPEAR, RIH, TAG 8985', WASH DOWN CTM (SET DOWN 2) (1 TIME NO PUMP), SET DOWN 5K, POOH. L/D GS SPEAR, NO FISH. M/U BHA #10 LIMAR SPEAR, RIH, START WASHING F/8979' T8991'. SET DOWN 5K, PICK UP 15000K-30000K OVER STRING WT, SET BACK DOWN, PUMP 3 BBLS D/G SWEEP AROUND, SHUT DOWN, BLEED OFF ALL PRES T/ 0, POOH SLOW, 3K OVER STRING WT. CLOSE SWAB, POP OFF, L/D BHA # 10, NO FISH. *JOB IN PROGRESS* 3/22/2023 SUPPORT OTHER PJSM, M/U BHA #11 LIMAR SPEAR, POP ON, PT. RIH T' 8985', PUMP 8BBL D/G OPERATIONS SWEEP AROUND, TAG FISH @ 8989', SET 2-7K, FIRED JARS DOWN 1 TIME, POOH. NO FISH. L/D BHA # 11. R/D, BLOW COIL DOWN W/ N2, RELEASE, RDMO T/ HILCORP F/ 3 WEEKS *READY FOR SLICKLINE* 3/23/2023 SUPPORT OTHER PULLED CATCHER FROM 8997' RKB. ATTEMPTED TO EQUALIZE 3-1/2" P2P RBP OPERATIONS @ 9003' RKB, UNABLE TO GET PRONG ALL THE WAY IN PLUG. RAN 2.25" PUMP BAILER TO RBP @ 9003' RKB, RECOVERED -2 CUPS OF RIG DEBREE/SAND, IN PROGRESS 3/24/2023 SUPPORT OTHER BAILED -1.5 GALLONS OF SAND FROM ON TOP OF RBP, EQUALIZED AND OPERATIONS PULLED 3-1/2" P2P RBP FROM 9003' RKB. JOB COMPLETE KUP PROD WELLNAME 2A-19A WELLBORE 2A-19A ConocoPhillips Alaska, Inc. ` p CONWCTORi Manuel Mira. Mand,N FSWQ 8,MMO FRID, baazD IINER: 8,928.69,k]B0� Well Attributes Max Angle & MD TD FIAd Name Werbde A%VIVA Wsu re -a-, I d ) KUPARUK RIVER UNIT 501032019J01 PROD 0.90 MB IKKB) 5,26L25 Pei BM(bKB) 9,JfiS0 Commem X2a 1ppml Deft an.Melion Le two: 3nd "Dale 31312023 aSkaso g 41.00 RRDett 1V111993 Omer aev.. Annotation D.Wh )XKB) WNIEore End Data last Moat By Last Tag' RKB 9,454.0 2A-19A 3130/2018 'proven Last Rev Reason Annotation wdno- 1 End Date last Mctl By Rev Reason: Pulled catcher & RBP 2A-19A 1 3/2412023 IMMUSID Notes: General & Safety Annotation Endbus I Last Mad By NOTE: WELL SIDETRACKED fi1112001 iriplaj Casing Strings cap Des DD tin) ID (na) Top dri Set epm Set mKB) niSKB) Depth With -en aM1m) Grade Top Thread CONDUCTOR 16 1506 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 95s; &92 11.4 3,957.1 2,795.6 4J.00 L-80 BTC WINDOW A ] 112 S00 9,138.0 9,150.0 5,698.4 PRODUCTION Post BUT ] S28 39.0 9,160.0 5,705.8 26.00 L-80 BTCHMOD LINER Sill 299 e,928.0 9,679.0 6,128.5 9.3D L-80 'T..MOD Tubing Strings: string max indicates LONGEST segment of string t D.plM1..at Deptn... suns Ma... rnhine DeactlpNon Wt1Ihm1 Grade Topeannestlon rop ltlKel sa'.. 28.3 8,920.2 5,532J 3112 Tubing -Completion Upper 9.30 L-80 EUE l Dlin) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Tap(Min Tap bri (MG) Topincl I°) Nam Das OD Nominal (ln) Corn Make Mobl Ncn,,W ID tin) 28.3 M3 0.08 Hanger 7.010 Tubing Hanger, Cameron CXS wI FMC 3.5 EUE 8N Top &Bottom CXS 2.00 523.4 5225 7.20 Nipple-X 4.514 3.5"x 2.813°X-Lending Nipple HES XNipple 2.813 3.876.9 2J582 5&08 Mandrel -GAS LIFT S250 3.S X P KBMG. GLM SLB KBMG 2920 7.883.9 4,927.7 56.66 Mantlrel - GAS LIFT S250 3.S X P KBMG. GLM SLB KBMG 2920 8.003.8 4,994.1 55.85 Mandrel -GAS LIFT S290 3.S X P KBMG. GLM SLB KBMG 2920 8.062.0 5,026.9 56.03 Pecker 6.280 Baker 3112 X T' S-3 Produnion Baker Packer 5-3 Pmducti on Packer &030 8,117.6 5,057.4 57.23 Nip a-X 4.514 3.Sx 2.81T" 1-anding Nipple HES X Nippla, 2813 8,913.4 5,527.9 46.14 Overshot 6.000 Baker3.SxT'Poorboy Overshot Baker (6.2' of papillae) 2' From tiny located Pocrecy Oversho t 3.610 Top nIKB) SN DepI1,... Set DeptM1... lbi,g Ma... Tu01n8 DesarllNlon 8,916.0 8,945.1 5,550.2 31/2 Tubing -Completion vn 86m) Grade Top conMCtion ID6n) Lovrer 9.30 L-80 EUEBRDMOD 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top prog Top ITVO) IbXB) Topincl (°) Mena Des OD Nominal (in) Core Meke Model Neutral No (in) 8,935.6 5,5414 45.26 NIPPLE 4.540 CAMCO DS LANDING NIPPLE Wl 2813- NO GO PROFILE 2.813 8,943.9 5,549.3 4509 SEALASSY 4.000 BAKER 80-40G6(L22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(fIKB) Tep(TVD) (XKB) Topincl(') Des C. Make MeadN SIN Run Data D(in) B.916.0 5,529.] ...Lb CUT Milletl tubing Tl Ndun ltlresa off during 2023 RWO) ND2023 2992 8,927.0 5.537.4 4544 LEAK LDL-QSBPM eI ILou PSI WELL HEAD PRESSURE 9I12J2012 0.000 Mandrel Inserts : excludes pulled inserts Top mKa) Top ITVD) (XKB) St at! Top No larval58.08 N1 Sery valve Type OD (in) TIRO Run (pal) RunDataCons Make NoG allo t- big 810.(88 3,876.9 2,753.2 5&08 1 GLV LV K BK 1 3I11Y2023 .,orSchlund, erger KBMG 0.188 7,883.9 4,927.7 %66 2 GLV BK 1 1,2820 3110/2023 ScNumb .,at KBMG 0.250 8,003.8 A994.1 55.85 3 Ov BK 1 Q0 311012023 SCNumb erger jKBMG 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top(XKB) Tap MD) (XKB) Top ma (°) Item Dee Do staining (in) Cam Make Model Nammall0 (in) 9,923.0 5,538.2 45.42 PACKER 5.980 BAKER ISOLATION ZXP LINER TOP PACKER 4.410 8,943.0 5,518.7 45.11 NPPLE 5.500 BAKERRSNPPLE 4.250 8,974.3 5,570.9 41.55 XC THREAD 3.500 2.992 8,981.3 5,575.9 4T47 XC THREAD 3.500 2992 9,352.9 5,859.1 35.24 PBR 3.500 POLISHED 64.5' BORE 1.28'length, above XN NO GO 2.750 9,416.9 5,911.4 M.91 NIPPLE 4.520 HOWCO PROFILE, XN NIPPLE w12.75 2.635' NO GO 2.W5 9,575.8 6,0425 33.91 XO THREAD 3.500 2.992 9,5]8.9 fi,045.1 33.88 LAND coL NG AR 3.500 2.992 Perforations & Slots Top MKB) B.rftKB) T (DKB) mKB) Urflad Zone Data Do- Dam (shobm) Tym Com 9,360.0 9,380.0 5,860.9 5,881.2 G4, 2A-19A 9/23120IT I 6.0 APERF 2.S HSD, DJ, HMX, fi0° ph KUP PROD WELLNAME 2A-19A WELLBORE 2A-19A 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:2/27/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2010830 Sundry #323-096 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1951 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 P 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"P 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)1500 P Check Valve 0 NA 200 psi Attained (sec)12 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)149 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1027 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@ 2020 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 28 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 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 2/25/23 5:47 AM Waived By Test Start Date/Time:2/27/2023 1:30 (date)(time)Witness Test Finish Date/Time:2/27/2023 7:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors All Tests with 3 1/2" Test joint. All alarms tested. Tony Morales / Paul Yearout ConocoPhillips Chase Erdman / Jim Newell KRU 2A-19A Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0227_BOP_Nabors7ES_KRU_2A-19A        By Meredith Guhl at 1:34 pm, Feb 15, 2023 323-096 X X BOP test to 2500 psig Annular preventer test to 2500 psig DSR-2/15/23 DLB 02/15/2023 X ADL0025570 DLB VTL 02/22/2023 10-40 GCW 02/22/23 JLC 2/22/2023 2/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.23 09:51:03 -09'00' RBDMS JSB 022423 201083 • 29 25 4 WELL LOGRECEIVED mANsmirrAL MAY 1 1 2018 PROACTIVE DIAGNOSTIC SERVICES, INC. GCC To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANS JUN ! '1,7018 1) Caliper Report 01-May-18 2A-19A 1 Report /CD 50-103-20197-01 2) OP Signed : ` Date : (( �( ff22 �V Print Name: NA_ ' l PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(p7MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM DAAchives\MasterTemplateFiles\Templates\Di stribution\TransmittalS heels\ConocoPhillips_Transmit.docx • • 10 1033 29254 Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-19A Log Date: May 1,2018 Field: Kuparuk Log No.: 14322 State: Alaska Run No.: 1 API No. 50-103-20197-01 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD MOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,896 Ft.(MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 5 at 8,891.1 feet(Driller's Depth). During logging operations,another pass was made after communication with the caliper was lost. This report is the combination of the two caliper passes. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to poor condition, with a maximum recorded wall penetration of 58% in a line of corrosion in joint 121 (3,815 feet). Additional wall penetrations ranging from 20%to 48%wall thickness are recorded in 68 of the 292 joints logged. Recorded damage appears as isolated pitting, a line of pits and sometimes broadening into line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS : Description Pel cent Wali Penetration Juni _feptPi Line Corrosion 58 121 3,815 Ft. (MD) Line Corrosion 48 135 4,257 Ft. (MD) Line Corrosion 47 125 3,954 Ft. (MD) Line Corrosion 47 132 4,173 Ft. (MD) Line Corrosion 46 146 4,603 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss(> 9%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. C.Goerdt HY. Yang J. Condio, J. Fama Held Engineer(s) Analyst(s) VVitn..ss(es) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • Correlation of Recorded Damage to Borehole Profile L., Pipe 1 3.5 in (23.0'-8,896.0') Well: 2A-19A Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 1, 2018 Approx.IIApprox.Borehole Profile Tool Deviation IIPp 1 26 25 782 3 50 1,563 75 2,345 A 100 Zak 3,128 GLM 1 —..� 125 3,929� 150 4,712 a '5 a� GLM 2 175 5,507 200 ., 6,284 GLM 3 —� 225 7,087 250 7,869 GLM 4 —� 275 8,667 GLM 5 - 281.2 8,891 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=281.2 • • PDS Report Overview CIRS. Body Region Analysis Well: 2A-19A Survey Date: May 1,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: HY.Yang Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD 2.992 in. 23 ft. 8,896 ft. Penetration(%wall) Damage Profile(%wall) 250 mil Penetration body Metal loss body 0 50 100 0.1 200 M 150 - J A 100 48 A 50 01 17. 0 0 to 20 to 40 to over 98 a 20% 40% 85% 85% 1 GLM 1 (5:00) Number of joints analyzed(total=292) _ 223 55 14 0 — 145 1 Damage Configuration(body) +i 80 = GLM 2 (12:00) 1 60 192 1. 40 Iii _ GLM 3 (9:00) a 20 239 Oil 0 GLM 4(11:30) Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole al Number of joints damaged(total= 124) GLM 5 (4:30) 47 0 77 0 0 Bottom of Survey=281.2 • • titPDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 23 0 0.01 6 3 2.96 Pup 1 26 0 0.02 9 5 2.94 1.1 56 0.04 0.04 15 8 2.93 Pup Shallow Pitting. 2 59 0 0.02 7 4 2.91 3 90 0 0.03 12 6 2.94 4 122 0 0.02 9 5 2.96 5 153 0 0.03 10 5 2.95 6 185 0 0.03 10 4 2.96 7 216 0 0.02 8 5 2.96 8 247 0 0.03 10 6 2.94 9 279 0 0.03 11 7 2.95 10 310 0 0.02 9 6 2.95 11 341 0 0.03 10 5 2.95 12 373 0.04 0.04 17 5 2.94 Shallow Pitting. 13 404 0 0.02 9 5 2.95 14 436 0 0.02 8 4 2.96 15 467 0 0.04 14 4 2.95 16 498 0 0.02 8 5 2.93 16.1 530 0 0 0 0 2.86 Camco DS Nipple 17 531 0 0.02 8 3 2.92 18 562 0 0.02 8 4 2.95 19 594 0 0.02 9 4 2.92 20 625 0 0.03 10 4 2.94 21 657 0 0.02 7 4 2.96 22 688 0 0.02 . 9 6 2.94 23 719 0 0.02 9 4 2.96 24 750 0 0.02 9 4 2.95 25 782 0 0.03 10 5 2.95 26 813 0 0.02 7 5 2.92 27 845 0 0.03 11 5 2.94 28 876 0 0.03 12 7 2.96 29 907 0 0.02 7 4 2.95 30 939 0 0.02 9 7 2,95 31 970 0 0.03 10 7 2.96 32 1002 0 0.05 18 4 2,93 Shallow Pitting. 33 1033 0 0.03 11 4 2.94 34 1064 0 0.03 11 6 2.92 35 1096 0 0.03 11 6 2.96 36 1125 0 0.02 . 9 7 2.95 37 1156 0 0.03 13 6 2.95 38 1187 0 0.03 11 6 2.94 39 1219 0 0.02 9 4 2.96 40 1250 0 0.03 11 7 2.95 41 1282 0 0.04 16 5 2.94 Shallow Pitting. 42 1313 0 0.02 8 6 2.96 43 1344 0 0.02 9 6 2.96 44 1376 0 0.02 8 4 2.95 45 1407 0 0.03 10 4 2.94 46 1438 0 0.02 7 5 2.94 47 1470 0 0.03 10 7 2.95 'Penetration Body Metal Loss Body Page 1 • • ri-r:3S PDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ("Yo wall) (in.) (in.) % (in.) 0 50 100 48 1500 0 0.03 11 5 2.95 ■ 49 1531 0 0.03 11 3 2.95 ■ 50 1563 0 0.03 13 9 2.96 51 1594 0 0.02 9 5 2.96 52 1625 0 0.03 11 6 2.95 53 1657 0 0.02 7 4 2.94 54 1688 0 0.04 17 8 2.93 Shallow Pitting. Slight Ovalitv. 55 1720 0 0.02 8 4 2.96 56 1751 0 0.04 15 6 2.95 Shallow Pitting. II 57 1783 0 0,03 13 6 2.95 • 58 1814 0 0.04 14 7 2.93 1 59 1846 0 0.03 10 5 2.93 ■ 60 1877 0 0.03 12 2 2.96 ■ 61 1907 0 0.04 14 4 2.94 I 62 1939 0 0.02 9 3 2.94 ■ 63 1970 0 0.03 11 6 2.94 II 64 2001 0 0.04 15 8 2.97 Shallow Pitting. 1 65 2033 0 0.05 19 7 2.95 Shallow Pitting. 1 1 66 2064 0 0.03 12 5 2.96 II I 67 2096 0 0.03 11 4 2.96 ■ 68 2127 0 0.04 15 5 2.96 Shallow Pitting. ■ 69 2158 0 0.03 11 7 2.95 a 70 2190 0 0.03 10 6 2.95 4 71 2220 0 0.03 10 5 2,96 72 2251 0 0.02 9 4 2.93 il 73 2283 0 0.03 11 7 2.96 ii 74 2314 0 0.03 11 7 2.96 iii 75 2345 0.05 0.06 23 7 2.95 Isolated Pitting. 1 76 2377 0 0.03 11 6 2.96 a 77 2408 0 0.04 16 7 2.97 Shallow Pitting. i 78 2440 0 0.03 10 7 2.95 1 79 2471 0.05 0.08 32 9 2.94 Line of Pits. i 80 2502 0 0.05 20 4 2.93 Isolated Pitting. ■ 81 2534 0 0.03 12 6 2.92 Slight Ovalitv, ■ 82 2565 0 0.04 17 5 2.96 Shallow Pitting. ■ 83 2596 0.04 0.04 14 6 2.96 ■ 84 2628 0.05 . 0.05 19 6 2.95 Shallow Pitting. a 85 2659 0.04 0.07 26 6 2.94 Line of Pits. 1 86 2690 0 0.05 18 7 2.95 Shallow Pitting. i 87 2722 0 0.04 15 6 2.93 Shallow Pitting. ■ 88 2753 0 0.04 15 6 2.95 Shallow Pitting. ■ 89 2784 0 0.09 36 , 9 2.95 Isolated Pitting. 90 2816 0 0.07 26 9 2.96 Line of Pits. 91 2847 0.04 0.03 13 7 2.96 ii 92 2878 0 0.05 18 6 2.95 Shallow Line of Pits. 1 93 2910 0 0.06 24 6 2.94 Isolated Pitting. a 94 2941 0 0.03 11 7 2.95 95 2972 0 0.03 10 3 2.94 01 96 3004 0 0.02 9 2 2.96 r 97 3035 0 0.07 27 2 2.97 Isolated Pitting. IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 98 3067 0 0.03 11 5 2.97 99 3098 0 0.10 41 6 2.94 Line of Pits. 100 3128 0 0.10 40 5 194 Line of Pits. 101 3160 0.04 0.06 22 6 2.95 Line of Pits. 102 3191 0 0.04 15 7 2.95 Shallow Pitting. 103 3222 0 0.07 29 6 2.97 Line of Pits. 104 3254 0 0.04 15 4 2.94 Shallow Pitting. ■ 105 3285 0.04 0.06 25 6 2.95 Isolated Pitting. 106 3316 0.04 0.09 34 7 2.95 Line of Pits. 107 3348 0 0.08 31 6 , 2.92 Line of Pits. ■ 108 3379 0.05 0.08 33 5 2.91 Line of Pits. 108.1 3411 0.04 0.04 15 6 2.95 Pup Shallow Line of Pits. 108.2 3417 0 0 0 0 2.93 GLM 1 (Latch @ 5:00) 108.3 3423 0 0.04 14 6 2.91 Pup ■ 109 3429 0 0.11 42 6 2.93 Line Corrosion. ■ 110 3461 0 0.10 40 6 2.94 Line Corrosion. ■ 111 3492 0 0.11 43 6 2.95 Line Corrosion. 112 3523 0 0.07 27 4 2.94 Line Corrosion. 113 3554 0 0.10 38 4 2.95 Line Corrosion. ■ 114 3586 0 0.06 23 4 2.93 Line of Pits. 115 3617 0.05 0.10 41 7 2.94 Line of Pits. 116 3647 0 0.03 13 4 2.95 117 3679 0.04 0.06 23 6 2.94 Line of Pits. 118 3710 0 0.07 28 6 2.95 Line of Pits. 119 3741 0 0.03 13 6 2.93 ■ 120 3773 0 0.05 18 4 2.93 Shallow Pitting. 121 3804 0 0.15 58 8 2.96 Line Corrosion. 122 3835 0 0.07 28 5 2.94 Line of Pits. 123 3866 0 0.09 36 4 2.95 Line Corrosion. ■ 124 3898 0 0.05 19 2 2.95 Shallow Line of Pits. ■ 125 3929 0 0,12 47 7 . 2.95 Line Corrosion. 126 3961 0.04 0.08 33 3 2.95 Line Corrosion. ■ 127 3992 0 0.08 31 5 2.94 Line of Pits. 128 4023 0 0.04 17 6 2.94 Shallow Pitting. 129 4055 0 0.07 29 5 2.94 Line of Pits. 130 4085 0 0.04 14 3 2.92 ■ 131 4116 0.05 0.08 30 8 2.92 Line of Pits. Slight Ovality. 132 4148 0 0.12 47 6 2.95 Line Corrosion. 133 4179 0 0.07 28 4 2.92 Line Corrosion. 134 4210 0.06 0.06 24 4 2.94 Line Corrosion. 135 4242 0 0.12 48 4 , 2,95 Line Corrosion. 136 4273 0 0.10 41 4 2.95 Line Corrosion. 137 4305 0 0.04 15 3 2.93 Shallow Pitting. ■ 138 4336 0 0.03 12 6 2.93 ■ 139 4367 0 0.04 16 7 2.93 Shallow Line of Pits. 140 4399 0 0.11 42 6 2.95 Line Corrosion. ■ 141 4430 0.05 0.05 20 4 2.93 Isolated Pitting. ■ 142 4461 0 0.04 16 5 2.95 Shallow Line of Pits. ■ 143 4493 0 0.05 19 5 2.94 Shallow Line of Pits. ■ 144 4524 0 0.05 21 4 2.95 Line of Pits. IPenetration Body Metal Loss Body Page 3 • • Ps PDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 145 4556 0 0.11 43 5 2.96 Line Corrosion. 146 4587 0 0.12 46 5 2.93 Line Corrosion. 147 4618 0 0.05 21 4 2.93 Line of Pits. ■ 148 4649 0 0.09 35 6 2.94 Line Corrosion. 149 4681 0 0.04 14 4 2.92 150 4712 0.05 0.09 35 5 2.94 Line Corrosion. 151 4744 0 0,07 27 3 2.95 Line of Pits. ■ 152 4775 0.04 0.09 37 2 2.94 Line Corrosion. ■ 153 4806 0.04 0.09 35 2 2.93 Line of Pits. ■ 154 4837 0.05 0.03 12 6 2.95 155 4869 0.04 0.06 22 7 2.94 Isolated Pitting. 156 4900 0 0.04 14 6 2.92 157 4931 0 0,05 20 3 2.92 Line of Pits. ■ 158 4962 0 0.05 21 6 2.94 Isolated Pitting. 159 4993 0 0.04 16 5 2.95 Shallow Pitting. 160 5024 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 161 5056 0 0.05 21 4 2.94 Line of Pits, ■ 162 5087 0 0.04 14 4 2.94 163 5118 0.07 0.05 21 3 2.94 Line of Pits. ■ 164 5149 0.05 . 0.05 19 2 2.94 Shallow Pitting. 165 5181 0 0.05 21 4 2.93 Line of Pits. 166 5212 0 0.03 11 6 2.94 167 5244 0 0.02 9 3 2.94 168 5272 0 0.03 10 4 2.93 ■ 169 5304 0 0.02 9 6 2.94 170 5334 0 0.05 19 3 2.94 Shallow Pitting. ■ 171 5366 0 0.03 10 4 2.94 ■ 172 5397 0 0.03 11 6 2.93 173 5426 0 0.04 17 6 2.93 Shallow Pitting. 173.1 5458 0 0.04 16 4 2.92 Pup Shallow Line of Pits. 173,2 5464 0 0 0 0 2.89 GLM 2(Latch @ 12:00) 173.3 5470 0 0.02 8 2 2.93 Pup 174 5476 0 0.03 13 5 2.94 ■ 175 5507 0 0.07 26 5 2.95 Line of Pits. 176 5538 0.04 0.05 21 6 2.95 Line of Pits. 177 5569 0 0.03 13 5 2.91 178 5600 0 0.06 25 4 2.93 Line of Pits. 179 5632 0 0.06 22 3 2.93 Line of Pits. ■ 180 5663 0 0.05 20 4 2.95 Isolated Pitting. ■ 181 5694 0 0.04 15 6 2.91 Shallow Pitting. 182 5726 0 0.06 25 3 2,95 Line of Pits. 183 5757 0 0.03 11 3 2.95 184 5788 0 0.05 21 6 2.94 Line of Pits. 185 5820 0 0.06 22 5 2.95 Line of Pits. 186 5851 0 0.05 18 5 2.93 Shallow Line of Pits. 187 5882 0 0.04 15 6 2.95 Shallow Pitting. 188 5914 0 0.04 14 4 2,91 ■ 189 5945 0 0.06 24 4 2.94 Line of Pits. ■ 190 5975 0 0.03 11 6 2.93 191 6007 0 0.05 20 4 2.93 Line of Pits. Penetration Body Metal Loss Body Page 4 • • 41-1 PDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 192 6038 0 0.03 11 2 2.95 193 6067 0 0.02 9 6 2.95 • 194 6097 0.05 0.05 20 6 2.94 Line of Pits. 195 6128 0 0.02 9 4 2.94 196 6160 0 0.03 10 5 2.94 197 6191 0 0.03 12 2 2.96 ■ 198 6221 0 0.04 17 8 2.93 Shallow Pitting. 199 6253 0.04 0.05 19 4, 2.96 Shallow Pitting. ■ 200 6284 0 0.04 16 2 2.90 Shallow Pitting. ■ 201 6315 0 0.04 14 5 2.94 ■ 202 6347 0 0.03 11 5 2.94 203 6378 0 0.02 8 2 2.94 204 6410 0 0.02 9 5 2.93 205 6441 0 0.05 18 6 2.91 Shallow Pitting. ■ 206 6473 0 0.05 18 4 2.94 Shallow Line of Pits. ■ 207 6504 0 0.03 13 6 2.95 ■ 208 6535 0.04 0.05 20 6 2.93 Line of Pits. ■ 209 6567 0 0.03 11 2 , 2.91 ■ 210 6598 0.05 0.04 17 3 2.95 Shallow Pitting. ■ 211 6630 0 0.05 19 4 2.92 Shallow Line of Pits. ■ 212 6661 0 0.05 19 6 2.95 Shallow Line of Pits. 213 6693 0 0.02 8 5 2.94 214 6724 0 0.04 15 2 2.92 Shallow Pitting. • 215 6756 0 0.04 17 5 2.94 Shallow Pitting. 216 6787 0 0.04 17 3 2.94 Shallow Pitting. • 217 6819 0 0.02 9 5 2.92 ■j 218 6849 0 0.02 9 2 2,93 ■ 219 6881 0 0.05 19 6 2.92 Shallow Line of Pits. 220 6912 0 0.02 8 2 2.94 221 6944 0 0.04 15 2 2.95 Shallow Pitting. 221,1 6975 0 0.02 6 2 2.87 Pup 221.2 6982 0 0 0 0 2.87 GLM 3(Latch a 9:00) 221.3 6988 0 0.03 10 2 2.89 Pup • 222 6994 0 0.03 11 5 2.94 ■ 223 7025 0 0.04 14 7 2.94 224 7055 0 0.04 14 4 2.93 . ■ 225 7087 0 0.04 14 5 2.93 226 7118 0 0.02 9 3 2.95 227 7149 0 0.02 9 6 2.90 228 7181 0 0.03 11 4 2.88 Mash. ■ 229 7212 0 0.03 10 4 2.93 ■ 230 7242 0 0.03 10 2 2.95 ■ 231 7274 0 0.02 9 6 2.94 232 7305 0 0.02 8 2 2.95 233 7337 0 0.03 11 7 2.92 234 7368 0 0.02 7 4 2.93 235 7399 0 0.04 15 5 2.94 Shallow Pitting. ■ 236 7431 0 0.04 14 2 2.95 • 237 7462 0 0.03 13 5 2.95 ■ 238 7494 0 0.03 13 7 2.93 Penetration Body Metal Loss Body Page 5 110 • 4 Li PDS Report Joint Tabulation Sheet Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Analyst: HY.Yang Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 23 ft. 8,896 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 239 7525 0 0.03 11 4 2.93 ■ 240 7556 0 0.03 13 6 2.91 ■ 241 7587 0 0.04 14 3 2.91 ■ 242 7618 0 0.04 15 5 2.93 Shallow Line of Pits. ■ 243 7650 0 0.04 15 3 2.91 Shallow Line of Pits. ■ 244 7681 0 0.03 10 3 2.88 245 7713 0 0.02 6 2 2.91 246 7744 0 0.02 9 5 2.94 • 247 7776 0 0.03 11 7 2.95 248 7807 0 0.04 14 5 2.94 249 7837 0 0.02 9 4 2.93 250 7869 0 0.02 8 3 2.93 251 7900 0 0,03 11 5 2.91 252 7932 0 0.02 8 2 2,93 253 7962 0 0.03 11 4 2.92 ■ 254 7993 0 0.03 11 4 2.91 ■ 255 8025 0 0.03 11 3 2.92 256 8056 0 0.02 9 6 2.92 257 8088 0 0.03 11 7 2.93 257.1 8119 0 0.02 8 3 2.89 Pup 257.2 8126 0 0 0 0 2.89 GLM 4(Latch® 11:30) 257.3 8131 0 0.02 9 2 2.90 Pup 258 8138 0 0.04 16 2 2.91 Shallow Line of Pits. 259 8168 0 0.02 7 2 2.92 • 260 8199 0.04 0.03 11 2 2.95 261 8229 0 0.03 12 7 2.93 262 8261 0 0.03 11 2 2.94 263 8291 0 0.03 11 3 2.93 ■ 264 8324 0 0.04 15 6 2.95 Shallow Pitting. • 265 8356 0 0.03 11 5 2,94 ■ 266 8386 0 0.03 11 2 2.95 267 8417 0 0.02 9 3 2.94 • 268 8449 0 0.04 14 3 2.94 269 8480 0 0.05 20 4 2.92 Line of Pits. ■ 270 8512 0.06 0.05 19 4 2.86 Shallow Line of Pits.Slight Ovality. ■ 271 8543 0 0.04 14 4 2.94 ■ 272 8575 0 0.04 14 2 2.93 273 8605 0.04 0.04 15 2 2.93 Shallow Line of Pits. 274 8635 0 0.03 11 5 2.95 ■ 275 8667 0 0.03 11 3 2.95 ■ 276 8698 0 0.03 11 5 2.93 277 8730 0 0.02 7 2 2.93 278 8760 0 0.02 8 2 2.92 279 8793 0 0.02 7 3 2.94 280 8823 0 0.02 8 2 2.95 281 8856 0 0.03 11 4 2.90 ■ 281.1 8886 0 0.05 20 4 2.93 Pup Line of Pits. 281.2 8891 0 0 0 0 2.92 GLM 5(LATCH @ 4:30) IPenetration Body Metal Loss Body Page 6 • • PDS Report Cross Sections Well: 2A-19A Survey Date: May 1,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: HY.Yang Cross Section for Joint 121 at depth 3,815.140 ft. Tool speed=51 -,..11144141414411., Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=54° 1 110 Finger= 14 Penetration=0.147 in. Line Corrosion 0.15 in.=58%Wall Penetration HIGH SIDE= UP • • (RS. PDS Report Cross Sections Well: 2A-19A Survey Date: May 1, 2018 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: HY.Yang Cross Section for Joint 135 at depth 4,257.410 ft. Tool speed=50 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=55° 1 -44. ,_ .,, __ ...,_ , \ , \ ._ . .. ........._ Finger= 17 Penetration=0.122 in. Line Corrosion 0.12 in.=48%Wall Penetration HIGH SIDE=UP KUP PROD • 2A-19A ConocoPhillips _ 1 Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Aiaska,Irlc. 501032019701 KUPARUK RIVER UNIT PROD 60.94 5,261.25 9,765.0 con000Plrnrs Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ' ... SSSV:NIPPLE 40 11/20/2015 Last WO: 5/31/2001 41.00 11/1/1993 2A-19A,4/102018 650:18 AM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:RKB 9,454.0 3/30/2018 pproven Last Rev Reason HANGER;28.2 Annotation End Date Last Mod By Rev Reason:TAG,New Gas Lift Design 4/6/2018 pproven ' (y .1., .-" "' Casing Strings LhCasing Description OD(m) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 'IllCONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 41.4 3,957.1 2,795.6 47.00 L-80 BTC •• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOWA 7 1/2 8.000 9,138.0 9,150.0 5,698.4 .n.AJCONDUCTOR;42.0-121.0 'A 4 - Casing Description OD(In) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' 1104 PRODUCTION Post 7 6.276 39.0 9,160.0 5,705.8 26.00 L-80 BTC-MOD NIPPLE;532.9 S/T Casing Description OD(in) lb(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 31/2 2.992 8,928.0 9,679.0 6,128.5 9.30 L-80 EUE8RDMO _ 0 Liner Details GAS LIFT;3.419.84 Nominal ID Top(ftKB) Top(TVD)(RKB) Top Incl(6) Item Des Com (in) t--- 8,928.0 5,538.2 45.42 PACKER BAKER ZXP LINER TOP ISOLATION PACKER 4.410 8,943.0 5,548.7 45.11 NIPPLE BAKER RS NIPPLE 4.250 •' 8,945.8 5,550.6 45.05 HANGER BAKER FLEX LOCK HYDRAULIC LINER HANGER 4.408 € i 8,955.2 5,557.3 44.85 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 SURFACE;41.4-3.957.1--. 9,352.9 5,859.1 35.24 PBR POLISHED BORE 1.28'length,64.5'above XN NO 2.750 GO g 9,416.9 5,911.4 34.91 NIPPLE HOVVCO XN NIPPLE w/2.75 PROFILE,2.635"NO 2.635 GAS LIFT;5,467.4 $ GO Tubing Strings Tubing Description I String Ma...I ID(in)2.882I Top(ftKB) (Set Depth(ft../Set Depth(TVD)I.../Wt(Ib/ft) I Grade (Top Connection TUBING 31/2 28.2 8,945.11 5,550.21 9.3011 L-80 EUEBRDMOD GAS LIFT;6,982.0- Completion Details Top(TVD) Top Incl Nominal __ Top(RKB) (RKB) (°) Item Des Com ID(in) 28.2 28.2 0.08 HANGER WKM GEN IV 5M TUBING HANGER 3.500 I. 532.9 532.0 7.52 NIPPLE CAMCO DS NIPPLE 2.875 GAS LIFT;8,124.9 ! 8,935.5 5,543.4 45.26 NIPPLE CAMCO DS LANDING NIPPLE w/2.813"NO GO PROFILE 2.813 8,943.9 5,549.3 45.09 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 3.000' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(WD) Top Incl Top(ftKB) (MKB) (°) Des Com Run Date ID(in) -- 8,900.0 5,518.7 46.84 PACKER 35'KB'UPPER STRADDLE PACKER,3"GS FISHING 12/28/201 1.870 NECK UP 2 GAS LIFT;8,891.1 J ,TII 8,904.7 5,521.9 46.60 PATCH 2 3/8"TUBING STL L-80 12/28/201 1.995 2 PACKER;8,900.0 v- 8 922,7 5,534.4 45.65'PACKER 35'KB'LOWER STRADDLE PACKER 12/28/201 1.810 I 2 PATCH;8.904.7 I,r Perforations&Slots PACKER;8,922.7 _ Shot Dens ■ Top(WD) Btm(TVD) (shotaiR f Top(ftKBL atm(ftKB) (RKB) (ftKB) Zane Date I Type Com NIPPLE;8,935.5 9,360.0 9,380.0 5,864.9 5,8812 C-4,2A-19A 9/23/2001 6.0 APERF 2.5"HSD,DJ,HMX,60 deg I E ph 9,432.0 9,454.0 5,923.8 5,941.9 A-3,2A-19A 6/17/2001 6.0 (PERF 2.25"HSD,power jet chgs, SEAL ASSY;6943.9 - 60 deg ph Z Stimulations&Treatments ®® Proppant Designed(Ib) Proppant In Formation(lb) Date I II 6118/2001 ij Stimulations&Treatments Vol Clean Pump Stg# Top(RKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 9,432.0 9,454.0 6/18/2001 Proppant Designed(lb) Proppant In Formation(lb) Date 1/11/2002 Stimulations&Treatments Stg8 TopftKB Btm(ORB) Date StimlTreat Fluid Vol Clean Pump 1 (ftKB) (bbl) Vol Slurry(bbl) WINDOW A 9,138.0-9,150.0-/ \ 1 9,360.0 9,380.0 1/11/2002 Mandrel Inserts PRODUCTION Post SIT; St 39.0-9,160.0 a8 on Top(WD) Valve Latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(in) 8ery Type Type (in) (psi) Run Date Corn 1 3,419.8 2,513.5 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,269.0 4/2/2018 10:00 FRAC;9,360.0 2 5,467.4 3,589.3 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,294.0 3/31/2018 11:30 APERF;9,360.0.9.380.0--4: 1 3 6,982.0 4,416.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,290.0 3/31/2018 9:00 4 8,124.9 5,061.4 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,287.0 3/30/2018 12:00 5 8,891.1 5,512.6 CAMCO MMG 11/2 GAS LIFT OV RK 0.188 0.0 3/31/2018 4'.30 (PERF;9,432.0-8,454.0, - Notes:General&Safety FRAC;9,432.0 _ I End Date Annotation 6/1/2001 NOTE:WELL SIDETRACKED 11/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 9/12/2012 NOTE:Mandrel Orientation:#1)10:00.#2)11:30#3)9:00,#4)12:00,#5)4:30 9/12/2012 NOTE:IDENTIFIED TUBING LEAK @ 8927'RKB w/ELINE LDL LINER;8,928.0-9,679.0 • RFGOVED Alaska AUG 29 201b P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 25, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission SCORED SEP 3 0 2016 333 West 7th Avenue, Suite 100 '�� Anchorage,AK 99501 Commissioner Cathy Foerster: 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 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 at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor 1 1 • • 1 4 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 STATE OF ALASKA , ALIJA OIL AND GAS CONSERVATION COMIADION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations E Fracture Stimulate r Pull Tubing E Operations shutdown r Performed: Suspend r Perforate r Other r- Alter Casing F Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: conductor Extension F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen F Exploratory r 201-0830 3.Address: 6.API Number: Stratigraphi 1--- Service r P. O. Box 100360,Anchorage,Alaska 99510 - 50-103-20197-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025571 KRU 2A-19A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9681 feet Plugs(measured) None true vertical 6130 feet Junk(measured) None Effective Depth measured 9579 feet Packer(measured) 8900, 8923, 8944 true vertical 6045 feet (true vertical) 5519, 5534, 5549 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 122' 122' SURFACE 3916' 9 5/8 3957' 2796' PRODUCTION 9121' 7 9160' 5706' LINER 751' 31/2 9679' 6129' RE Perforation depth: Measured depth: 9360-9380, 9432-9454 AUG Q 4 20th True Vertical Depth: 5876-5892, 5935-5953 SCANNED JAN 2 6 2C17, AOGCC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 8944 MD, 5549 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO DS NIPPLE @ 533 MD and 532 TVD PACKER=35'KB' UPPER STRADDLE PACKER,3"GS FISHING NECK UP @ 8900 MD and 5519 TVD PACKER=35'KB' LOWER STRADDLE PACKER @ 8923 MD and 5534 TVD SEAL ASSY=BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY @ 8944 MD and 5549 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: \ Daily Report of Well Operations F Exploratory r Development F Service E Stratigraphic E Copies of Logs and Surveys r 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation fl GSTOR r WINJ I- WAG E GINJ Iv SUSP r SPLUG I- 17. 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: 316-350 Contact Roger Winter Email: n1927(a�concophillips.com Printed Name o er Winter Title: NSK WI Field Supervisor ?/�V/. Signature S Phone:659-7506 Date ..fig Form 1U-404 Revised 5/2U /� L,TL ' /z/IL RBDMS \,U AUG - 4 201fi�ubmlt Original Only • • ConocoPhillips RECEIVED Alaska AUG 0 4 20115 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AO GCC July 27, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. well 2A-19A, PTD 201-083 conductor extension, Sundry# 316-350. Please contact myself at 659-7506 or MJ Loveland at 659-7043 if you have any questions. Sincerely (! Roger Winter ConocoPhillips Well Integrity Field Supervisor • • 2A-19A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/26/16 Prep and weld 11" conductor extension made with 16"62# .375 wall pipe. iC O O - - '''..-;-;511 ,., to; , , 0 ), O �> �' t L r+-- ice+ (n Ci O V — ' �"' ,y., : .D vvi t� a • ,,� 0 1 p '5_, 0 -.. - 0 II ICE ..� „' rt / O 0 CNr .. .., ffr; ,1„, f , , -, ,....„, 4, ,. T .., 4':-it. 44"€r ., � +° .s .i , �. g ,,,.,.=3,..:* . ' 4 , `*� � 33,3e.;d e 3 41 n „,„+.:1 , ,.,. ., : „.2...; ,.,:, .., . :. ,)..9t4t.yr*-4,5?,4?"r,-- �n.40,,,,_ , r 0,, li ..„ r4 oirolf....„:„...,.., ,. ,_ if �� °° 6,..,,, ,16%*,,..,. ,,.....,,, sp OF 7� �w�'�.��,� THE STATE• Alaska Oil and Gas ti ;,Pe t. • 0f AL AS4, , A Conservation Commission tsitt>� 333 West Seventh Avenue �., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALA9�� Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. SCANNED JUL 1 3 2016 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-19A Permit to Drill Number: 201-083 Sundry Number: 316-350 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 04 Cathy P Foerster Chair DATED this .S day of July, 2016. RBDMS " JUL 0 6 2016 III II/ RECEIVED STATE OF ALASKA JUN 7 y D ALASKA OIL AND GAS CONSERVATION COMMISSION `.f// APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 / 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well Id Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r . Other conductor Extension F' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development p- . 201-0830 ' 3.Address: Stratigraphic r Service " 6.API Number. P. 0. Box 100360, Anchorage,Alaska 99510 50-103-20197-01 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No r KRU 2A-19A " 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025571 . Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9681 - 6130 ' 9579' - 6045' ' 3000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121' 121' SURFACE 3916' 9 5/8 3957' 2796' PRODUCTION 9121' 7 9160' 5706' LINER 751' 3 1/2 9679' 6129' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9360-9380,9432-9454 ' 5876-5892,5935-5953 3 1/2 L-80 8944 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE=CAMCO DS NIPPLE . MD=533 TVD=532 PACKER=35'KB'UPPER STRADDLE PACKER, , MD=8900 TVD=5519 PACKER=35'KB'LOWER STRADDLE PACKER . MD=8923 TVD=5534 PACKER-Baker ZXP Liner Top Isolation packer ' MD=8928 TVD=5549 12.Attachments: Proposal Summary raj" WellBore Schematic r" 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r ' Service r 14. Estimated Date for 15. Well Status after proposed work: 07/20/16 r • WIND Suspended Commencing Operations: OIL r ' r WDSPL r P r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17. I hereby certify that the foregoing is true Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: MJ.Loveland( cop,com / Title: NSK WI Project Supervisor Signature Z,f 71i Date: 7 Commission Use Only Conditions of approval. Notify Commission so that a representative may witness Sundry Number: \Le — 35° Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS 1-k- JUL 0 6 2016 Post Initial Injection MIT Req'd? Yes r No r A /� Spacing Exception Required? Yes r No VSubsequent Form Required: /P - 4 n APPROVED BY 2..Approved by: (✓ COMMISSIONER THE COMMISSION Date: � S- // 914d cikti/C Submit Form and Form 10-403 Revised 11/2015 oRrivGlINOAL for 12 months from th9 date of approval. Attachments in Duplicate • • ~v • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 JUN 2 9 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC June 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2A-19A, PTD 201-083 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, ''/ /2// MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska, Inc. Kuparuk Well 2A-19A (PTD 201-083) SUNDRY NOTICE 10-403 APPROVAL REQUEST 06-26-16 This application for Sundry approval for Kuparuk well 2A-19A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. A 33" conductor extension was welded to the conductor in 2011. Since then during normal operations the conductor has continued to subsidence and needs another—9" extension With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor . KUP PROD • 2A-19A ConocoPhillips 2 Well Attributes Max Angle&MD TD Alaska,Inc- Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) acrrPrvups 501032019701 KUPARUK RIVER UNIT PROD 60.94 5,261.25 9,765.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2A-19A,6/10/201612'56'33 PM SSSV:NIPPLE 40 11/20/2015 Last WO: 5/31/2001 41.00 11/1/1993 Vertcal schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,446.0 6/8/2016 Rev Reason:H2S,TAG pproven 6/10/2016 HANGER'.282 ir'> Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .' CONDUCTOR 16 15.062 42.0 121.0 121.0 62,50 H-40 WELDED Casing Description OD(in) ID(In) Top(BOB) Set Depth(BOB) Set Depth(TVD)...WtlLen(I,..Grade Top Thread SURFACE 9 5/8 8.921 41.4 3,957.1 2,795.6 47.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOWA 71/2 6.000 9,138.0 9,150.0 5,698.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION Post 7 6.276 39.0 9,160.0 5,705.8 26.00 L-80 BTC-MOD .AAd'CONDUCTOR;42,0-121,0 J' �.r,n-,Ir�S(T Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;532.9 - LINER 31/2 2.992 8,928.0 9,679.0 6,128.5 9.30 L-80 EUE8RDMO D Liner Details Nominal ID Top(ROB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LFT 381,3 8 i 8,928.0 5,538.2 45.42 PACKER BAKERZXP LINER TOP ISOLATION PACKER 4.410 8,943.0 5,548.7 45.11 NIPPLE BAKER RS NIPPLE 4.250 8,945.8 5,550.6 45.05 HANGER BAKER FLEX LOCK HYDRAULIC LINER HANGER 4.408 8,955.2 5,557.3 44.85 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 9,352.9 5,859.1 35.24 PBR POLISHED BORE 1.28'length,64.5'above XN NO 2.750 SURFACE;41.4-3,957.1-4 GO 9,416.9 5,911.4 34.91 NIPPLE HOWCO XN NIPPLE w/2.75 PROFILE,2.635"NO 2.635 GO GAS LIFT:5,467.4A c Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(WO)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 28.2 8,945.1 5,550.2 9.30 L-80 EUE8RDMOD Completion Details Nominal ID GAS LIFT;6,982.0 Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des TUBING (in) 28.2 28.2 0.08 HANGER WKM GEN IV 5M HANGER 3.500 532.9 532.0 7.52 NIPPLE CAMCO DS NIPPLE 2.875 8,935.5 5,543.4 4526 NIPPLE CAMCO DS LANDING NIPPLE w/2.813"NO GO 2.813 GAS LIFT;8,124.9 L E PROFILE 8,943.9 5,549.3 45.09 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) _ 8,900.0 5,518.7 46.84 PACKER 35'KB'UPPER STRADDLE PACKER,3"GS 12/28/2012 1.870 FISHING NECK UP GAS LIFT;8,691.1 8,904.7 5,521.9 46.60 PATCH 2 3/8"TUBING STL L-80 12/28/2012 1.995 8,922.7 5,534.4 45.65 PACKER 35'KB'LOWER STRADDLE PACKER 12/28/2012 1.810 PACKER;8,900.0 -` Perforations&Slots 1111 Shot PATCH;8,904.7 Dons PACKER;8,922.7 To ftKB Btm(BOB) oD) atm(TVD) (sht( Top(ftKB) (ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 9,360.0 9,380.0 5,864.9 5,881.2 C-4,2A-19A 9/23/2001 6.0 APERF 2.5"HSD,DJ,HMX,60 deg ph X Ij 9,432.0 9,454.0 5,923.8 5,941.9 A-3,2A-19A 6/17/2001 6.0 (PERF 2.25"HSD,power jet NIPPLE;8,935.5 t chgs,60 deg ph .1 Lt Stimulations&Treatments ,--=.I-., Min Top Mac Btm SEAL ASSY;8,943,9 - Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 12' 9,432.0 9,454.0 5,923.8 5,941.9 FRAC 6/18/2001 'A3'FRAC,210M#BEHIND PIPE,10 PPA ON I , PERFS 9,360.0 9,380.0 5,864.9 5,881.2 FRAC 1/11/2002 C-SAND FRAC,96,000#16/20 CARBOLITE,10 ppa s ON PERFS Mandrel Inserts St at, on Top(WD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD((n) Sere Type Type (in) (psi) Run Date Com 1' 3,419.8 2,513.5 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,317.0 7/12/2014 2 5,467.4 3,589.3 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,352.0 7/12/2014 l 3 6,982.0 4,416.2 CAMCO KBMM 1 GAS LIFT OV BK ' 0.188 7/12/2014 WINDOW A;9,138.0-9,150.0) 4 8,124.9 5,061.4 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 7/12/2014 5 8,891.1 5,512.6 CAMCO MMG 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 10/14/2007 PRODUCTION Post S?; 39.0-9,160.0 Notes:General&Safety End Date Annotation 6/1/2001 NOTE:WELL SIDETRACKED FRAC;9,380.0 APERF;9,360.0-9,380.01 11 11)18/2010 NOTE:View Schematic w/Alaska Schematic9.0 9/12/2012 NOTE:Mandrel Orientation:#1)10:00.#2)11:30 f13)9:00,#4)12:00,#5)4:30 M 9/12/2012 NOTE:IDENTIFIED TUBING LEAK @ 8927'RKB Md ELINE LDL (PERF;9,432.0-9,454.0, FRAC:9,432.0 - _I LINER;8,928.0-9,879.0 Image~oject Well History' File Cover I~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~. (~ ~- {~~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) / [] Color items: [~ Diskettes, No. I [] Maps: [3 Grayscale items: [] Other, No/Type [] Other items scannable by [] Poor Quality Originals: large scanner D Other: OVERSIZED (Non-Scannable) NOTES: [3 Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL/~'A'RI'IA~WINDY Scanning Preparation I x 30 = '~0 BY: BEVERLY ROBIN VINCENT SHERYL,~INDY ~_.O = TOTAL PAGES ~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ P BEVERLey'S)VINCENT SHERYL MARIA WINDY DA TE;"~C~'~/S//' - ~ IF NO IN STAGE 1, PAGE(S)DISCREPANCIES WERE FOUND: ~ YES ~ NO BEVERL'~INCENT SHERYL MARIA WINDY DA TE;~'-(~ ~I~S, SY: Stage 2 BY; (SCANNING IS COMI~LETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYECALE OR COLOR IMAGES ) RESCANNEDB¥; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Comments about this file: Quality Checked (do..) 12/10102Rev3NOTScanned.wpd • - STATE OF ALASKA ALA OIL AND GAS CONSERVATION CON.SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon I`°` Repair w ell r Plug Perforations r Perforate 1 — Other Set Patch Pull Tubing Assembly Alter Casing j"" g � Stimulate - Frac j '" Waiv ('"" Time Exte j"" Chan Approved Program j'°"` Operat. Shutdow n l Stimulate - Other E Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l Exploratory r 4 201 -083 3. Address: 6. API Number: Stratigraphic [ Service E P. O. Box 100360, Anchorage, Alaska 99510 — 50 - 103 - 20197 - — Ja 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25571 ^ — 2A - 19A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9681 feet Plugs (measured) none true vertical 6130 feet Junk (measured) none Effective Depth measured 9579' feet Packer (measured) 8900, 8923, 8928 true vertical 6045 feet (true vertical) 5530, 5545, 5549 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121 121 SURFACE 3916 9.625 3957 2807 PRODUCTION 9117 7 9157 5705 LINER 751 3.5 9679' 6140 RECEIVED JAN 29 2013 %AWE© MAR 0 5 2013 Perforation depth: Measured depth: 9360 - 9380, 9432 - 9454 ADC True Vertical Depth: 5876 -5892, 5935' -5953' Tubing (size, grade, MD, and TVD) 3.5, L -80, 8945 MD, 5561 TVD • . Packers & SSSV (type, MD, and TVD) PACKER - 'KB' UPPER STRADDLE PACKER @ 8900 MD and 5530 TVD PACKER - 'KB' LOWER STRADDLE PACKER @ 8923 MD and 5545 TVD PACKER - BAKER ZAP LINER TOP ISOLATION PACKER @ 8928 MD and 5549 TVD SSSV - CAMCO DS LANDING NIPPLE @ 533 MD and 533 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 109 731 967 -- 224 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development ; Service E Stratigraphic r 16. Well Status after work: — Oil ici Gas E WDSPL E Daily Report of Well Operations XXX GSTOR I- WINJ f WAG r GINJ E SUSP f SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Email John .W.PeirceCcr�conocophillips.com Printed Name John Peirce Title Wells Engineer Signature A .. Phone: 265-6471 Date i _ 2,3-13 Form 10-4 4 Revised �1 /2012 BDMS JAN 3 0 2013 , � VI-- 1' Sub" . Original Only Z// 7 /1 3 � �',0} t KUP • 2A -19A ConocoPhillips Well Attributes Max Angle & MD TD (Alaska. if 1 Wellbore AP W WI Field Name Well Status Ind (.) MD (ftKB) Act Btm (ftKB) 501032019701 KUPARUK RIVER UNIT PROD 60.94 5261.25 9,765.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' - SSSV: NIPPLE 20 10/10/2011 Last WO: 5/31 /2001 41.00 11/1/1993 Well Confiq - 2A-19A, 10 2 3 8:33:28 AM Schematic - 11 AClu Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,477.0 12/16/2012 Rev Reason: Pull Plug/Catcher, set Patch, Tag osborl 1/10/2013 Casing Strings HANGER. 28 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r , CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd �.._,r... _......�:,.. F SURFACE 95/8 8.921 41.4 3,957.1 2,806.6 47.00 L -80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOWA 71/2 6.000 9,138.0 9,150.0 5,707.4 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 39.0 9,160.0 5,715.2 26.00 L -80 BTC -MOD ' Post S/T F _, I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd CONDUCTOR, LINER 31/2 2.992 8,928.1 9,679.0 6,139.5 9.30 L -80 EUE8RDMOD 42 -121 Liner Details NIPPLE, 533 1 Top Depth (TVD) Top Intl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 8,928.1 5,549.2 45.11 PACKER BAKER ZXP LINER TOP ISOLATION PACKER 4.410 8,943.0 5,559.7 44.93 NIPPLE BAKER RS NIPPLE 4.250 GAS LIFT _ 3,420 8,945.8 5,561.6 44.90 HANGER BAKER FLEX LOCK HYDRAULIC LINER HANGER 4.408 8,955.2 5,568.3 44.78 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 9,352.9 5,870.1 35.24 PBR POLISHED BORE 128' length, 64.5' above XN NO GO 2.750 p 9,416.9 5,922.4 34.91 NIPPLE HOWCO XN NIPPLE w/ 2.75 PROFILE, 2.635" NO GO 2.635 it Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, , l TUBING 31/2 2.992 28.2 8,945.1 5,561.1 9.30 L -80 EUE8RDMOD 41 FM Details Top Depth (TVD) Top Inc( Nomi... GAS LIFT, Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 5,467 28.2 28.2 0.29 HANGER WKM GEN IV 5M TUBING HANGER 3.500 532.9 532.9 7.52 NIPPLE CAMCO DS NIPPLE 2.875 8,935.6 5,554.4 45.02 NIPPLE CAMCO DS LANDING NIPPLE w/ 2.813" NO GO PROFILE 2.813 GAS LIFT 8,943.9 5,560.3 44.92 SEAL ASSY BAKER 80-40 GBH -22 LOCATOR SEAL ASSEMBLY 3.000 6.982 - - t `. all Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) IN Top Depth V /Top (ftKB) {RK ( ") Description Comment Run Date ID (in) GAS LIFT 8 5 .7 46.84 PACKER 35 'KB' UPPER STRADDLE PACKER, 3" GS FISHING 12/28/2012 1.870 8,126 - -. - -- - NECK UP 8,904.7 5,533.0 46.60 PATCH 23/8 "TUBINGSTLL -80 12/28/2012 1.995 8,922.7 5,545.4 45.65, PACKER 35.(KB' LOWER ST ARDLE PACKER . --, 12/28/2012 1.810 _. __ - --- -"-- j Perforations & Slots Shot GAS LIFT, Top (NO) Btm (TVD) Dens 8,891 Top (ftKB) 8tm (ftKB) (ftKB) (ftKB) Zone Date (ah- Type Comment 9,360.0 9,380.0 5,875.9 5,892.3 C-4, 2A -19A 9/23/2001 6.0 APERF 2.5" HSD, DJ, HMX, 60 deg ph PACKER, 8,900 _ _ 9,432.0 9,454.0 5,934.8 5,953.3 A -3, 2A -19A 6/17/2001 6.0 IPERF 2.25" HSD, power jet chgs, 60 deg ph Stimulations & Treatments PATCH, 8,905 Bottom PACKER, 8,923 - - Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment • 11 s. 9,360.0 9,380.0 5,875.9 5,892.3 FRAC 1/11/2002 C FRAC, 96,000# 16 /20 CARBOLITE, 10 ppa NIPPLE, 8,936 ON PERFS 9,432.0 9,454.0 5,934.8 5,953.3 FRAC 6/18/2001 'A3' FRAC, 210M# BEHIND PIPE, 10 PPA ON 1 PERFS SEAL ASSY, - Notes: General & Safety 8,944 End Date Annotation " 6/1/2001 NOTE: WELL SIDETRACKED Ill 11/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9/12/2012 NOTE: IDENTIFIED TUBING LEAK @ 8927 RKB w/ ELINE LDL WINDOW A, 1 , • 9,138 -9,150 PRODUCTION Post SR, 39-9,160 APERF, tMandrel Details 9,360- 9.380 Top Depth Top Port FRAC, 9,360 ' I 1 I (ND) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,419.8 2,524.5 59.55 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,331.0 3/19/2011 10:00 2 5,467.4 3,600.2 58.55 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,323.0 10/14/2007 11:30 WERE, 9,432 - 9,454 1 i ® t 1 3 6,982.0 4,427.1 55.53 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,347.0 10/14/2007 9:00 FRAC, 9432 4 8,124.9 5,072.3 57.34 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 7/27/2012 12:00 5 8,891.1 5,523.6 47.32 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/14/2007 4:30 ■ LINER. \ 8,928 -9,879 \ .J L TD (2A -19A), 9,765 • • 2F -19A Well Work Summary 12/28/2012 SET 22'x2.38 "OD BAKER PATCH FROM 8900' - 8922'. 2.74" UPPER PACKER MID - ELEMENT AT 8900' PLACING 2.74" LOWER PACKER MID- ELEMENT AT 8922'. LOG CORRELATED TO TUBING COMPLETION RECORD DATED 31 MAY 2001. READY FOR SLICKLINE. 11, • - 2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 14, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: 2A -19A Run Date: 9/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -19A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20197 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED APR 0 2 2013 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: \ 0 a Signed: I • • °Phillips Q Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 March 9, 2012 Commissioner Dan Seamount °`' : X`�'i P�' ^^ Alaska Oil Gas Commission 9 P� :nIda fr 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 O 3 Commissioner Dan Seamount: -- Vi Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907- 659 -7043, if you have any questions. Sincerel , MJ veland ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # • PTD # , cement pumped cement date inhibitor sealant date ft bbls ft gal r > 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/11/2012 2M-02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 2M-29 50103201830000 1920970 SF NA 24" NA 3.4 2/11/2012 2T-18 50103202130000 1950170 42" 0.50 9° 11/22/11 2.55 2/12/2012 2T-28 50103202250000 1950920 9° NA 16" NA 2T-207 50103202780000 1982310 22'3" 3.70 7" 11/21/11 2.98 2/12/2012 . 2T-215 50103202800000 1982420 18'6" • 2.40 10" 11/22/11 4.25 2/12/2012 2X-06 50029209880000 1831100 SF NA . 21" NA 2.13 2/12/2012 STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS I 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other p Conductor Pull Tubing Perforate New Pool Wa iver Extension Alter Casing r 9 r r r Time Extension (! Change Approved Rogram r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: Permit Drill Number: p 5. Pe t to ConocoPhillips Alaska, Inc. Development r Exploratory r r• 201 - 083 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 _ 50 103 - 20197 - 01 — OQ 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025571 r v 2A -19A 9. Field /Pool(s): A Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9681 feet Plugs (measured) None true vertical 6130 feet Junk (measured) None Effective Depth measured 9334 feet Packer (measured) 8928 true vertical 5844 feet (true vertucal) 5538 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 1640 630 SURFACE 3916 9.625 3957 2807 6870 4750 PRODUCTION 9728 7 9765 6164 7240 5410 LINER 751 3.5 9679 6129 10160 10540 RECEIVED Perforation depth: Measured depth: 9360'- 9380', 9432' -9454' DEC 2 8 2011 True Vertical Depth: 5876'- 5892', 5935' -5953' 7 1lftska Uri & Ues bons. Commission (size, grade, MD, and TVD) Tubing ( 9 ) 3.5 ", 9.3 PPP, L -80, 8934 MD, 5554 TVD Packers & SSSV (type, MD, and TVD) PACKER = BAKER ZXP ISOLATION PACKER @ 8928' MD and 5549' TVD SSSV = CAMCO "DS" NIPPLE AT 522' 0 MD and 522' TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): { Treatment descriptions including volumes used and final pressure: � �� a.JA�l � L 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r * Service r Stratigraphic r 15. Well Status after work: — Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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: 311 -357 Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title Well Integrity Project Supervisor Signature - Phone: 659 -7043 Date: 12/24/11 ``x 1 (t ffi; ,. lead /• 7. IL. Submit Ori inal Only Form 10-404 Revised 10/2010 g y • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 24, 2010 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 2A-19A, PTD 201 -083, Sundry 311 -357, gas lift oil, conductor extension. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, , 7 ;T7�d 44 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Name of Recipient Page 2 of 2 12/25/11 '" �,� 'perms., � 3 v T Y . . , .. , : ,.....1 ' ,, j ' ii i „ F 1 4 4 fr 4, X ;WI ©Conoco This photo i and canno publis writt; Con • 2A -19A • DESCRIPTION OF WORK COMPLETED • SUMMARY Date Event Summary 12/23/11 Prep and weld 36" conductor extension with 16" 62# .375 pipe. • • ‘ I-P i v--[E atta SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. � �` D� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -19A Sundry Number: 311 -357 Dear Ms. Loveland: a• `? ` -i'- Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ` day of November, 2011. Encl. ATE OF ALASKA •��, £ ECEV E • ALASKA OIL AN•AS CONSERVATION COMMISSI Till' OV 1 1 � APPLICATION FOR SUNDRY APPROVALSt`' 20 AAC 25.280 ji & Pas rms. Commit. •y' 1. Type of Request: Abandon r Rug for Redrill r Ferforate New Pool r Repair well r Chang ter� a erogram r Suspend r Rug Perforations r Perforate r PUII Tubing r tine tension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Conductor extention r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 1 ConocoPhillips Alaska, Inc. Development r' Exploratory r 201 -083 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20197 - 01 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property Tine 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 2A - 19A • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025571 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9681 4 6130 • 9334' 5844' Casing Length Size MD TVD Burst Collapse CONDUCTOR (QC) 80 16 121' 121' SURFACE (QC) 3916 12 3957' 2796' LINER (QC) 751 6.15 9679' 5704' PRODUCTION 9728 7 9765' 6129' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9432 - 9454, 9360 - 9380' 5924 - 5942, 5865 - 5881' 3.5 L - 8933 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - LINER BAKER ZXP TOP ISOLATION PACKER MD= 8928 TVD= 5538 Nipple - MD= 523' 12. Attachments: Description Sunmary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/25/2011 Oil rI • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and corr to the best of my kn edge. Contact: MJ Loveland /Martin Walters Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature ��f'/ Phone: �, et -7c1 c�/� Date ,// z�� SS j Commission Use Only • Sundry Number :3 V- c � 7 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test do Mechanical Integrity Test r Location Clearance r Other: . — r4_ v 1 do 4_44,w.c„Jt-iJ a It, a '4 tv .•( L Subsequent Form Required: /v — j 0 Ad ir APPROVED BY ) 17/67// Approved by: COMMISSIONER THE COMMISSION Date: ` pp /l• / • • le , , t( Form 10 -403 ReviragDMS NOV 17 i� Su bmit in Du lic to / ( l R 1 G 1 N A L le "("ft • • ConocoPhillips Alaska, Inc. Kuparuk Well 2A -19A (PTD 201 -083) SUNDRY NOTICE 10 -403 APPROVAL REQUEST November 13, 2011 This application for Sundry approval for Kuparuk well 2A -19A is to extend the conductor to / original height so as to prevent any further corrosion to SC. This well is Kuparuk gas lifted oil well and is currently on line. At some point during normal operations the conductor subsided about 40" inches. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor. 2. Examine SC below where landing ring was for any corrosion damage. 3. Install anti - corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to braiden head and fill the void with cement and top off with sealant. 5. File 10 -404 with the AOGCC post repair. P4iz) NSK Problem Well Supervisor 05/07/05 • Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~ N~~~ ;~ ~ 2087 d,," ~` ~ ~ Enclosed please find a spreadsheet with a list of wells-.from. the Kuparuk field (KRIJ). Each of these wells was found to have a void in the conductor. 'fihese voids were filled with a 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 corrosion inhibitor/sealant was pumped on November 10, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerer , ~~ ~ ~ ~ " ~~, ! - ~ ~~ ; Perry Klei ConocoPhillips Well Integrity Projects Supervisor ~,, • • nc® eIIIpS leaks Inca Surface Casing by Conductor annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 11 /10/2007 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 2A-15 185-146 5" NA 5" NA 3.5 11/10/2007 2A-16 185-147 39" NA 39" NA 21 11/10/2007 ZA-"" 201-083 12" NA 12" NA 6 11/10/2007 2A-20 193-151 9" NA 9" NA 7.5 11/10/2007 2A-24 193-144 5" NA 5" NA 2 11/10/2007 2A-25 196-062 10" NA 10" NA 2 11/10/2007 10/13/06 SChlllllbBPgep G!NilP.i~~\t Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 8(;A!:~r~E[)j ~1i ':': 0) JL Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 [Jot-oiG Field: Kuparuk Well Job# Color CD Log Description Date BL 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE WIDEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T-39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26106 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V -08A 11216327 US IT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm _ Marker, doc Permit to Drill 2010830 MD 9681 ~ 'FVD DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. KUPARUK RIV UNIT 2A-19A Operator CONOCOPHILLIPS ALASKA INC 6130 J Completion Dat 6/17/2001 ~' Completion Statu l-OIL Current Status l-OIL APl No. 50-103.20197-01-00 UIC N REQUIRED INFORMATION Mud Log N._9o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop !,E-I~ ..~D Ver LIS Verification [~~C GR GammaRay Directional Survey MWD Survey ¢RE~S/-I-EMP 1 FINAL FINAL FINAL 9100 9343 9138 9643 9443 9681 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Open 1/3/2002 ~11~ 14 CH 6/19/2001 OH 6/19/2001 OH 7/30/2001 Case 7/2/2002 C4d~24 Comments Directional Survey, Paper Copy MWD Survey, Digital Data 9343-9443 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received? ~ Analysis ~-- RP.r~.ived ? Daily History Received? ~ N Formation Tops ~ / N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 0l, 2002 RE: MWD Formation Evaluation Logs 2A-19A, AK-MM-10165 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2A-19A: Digital Log Images 50-103-20197-01 1 CD Rom RECEIVED Alaska Oil & Oas Cons. Comm/~/on An~orage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 February 19, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2A-19A (201-083) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation activity on the KRU well 2A-19A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED F£~ ~ 0 200'd /ilaska Oil & Gas Co~s. Cor~missior~ Anchorage ~ STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ h 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4601' FNL, 50' FEL, Sec. 14, T11N, RSE, UM At top of productive interval 1483' FNL, 1286' FEL, Sec. 22, TllN, RSE, UM At effective depth At total depth 1595' FNL, 1367' FEL, Sec. 22, T11 N, RSE, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ ~sp~ 498340, 5960099) (asp's 491828, 5957944) (asp's 491748, 5957829) 6. Datum elevation (DF or KB feet) RKB 124 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A- 19A 9. Permit number / approval number .,~.,,.;.~_ ~ ,~.. ,~,-~-.~,~ .--~.,,, ~ ,.,, .................... . ~ 10. APl number 50-103-20197-01 11. Field / Pool Kuparuk Qil Pool 12. Present well condition summary Total depth: measured true vertical 9681 feet 6130 feet Plugs (measured) Effective depth: measured 9334 feet true vertical 5844 feet Casing Length Size CONDUCTOR 121' 16" SURFACE 3833' 9-5/8" PRODUCTION 9641' 7" PROD LINER 751' 3-1/2" PROD LINER Junk (measured) Cemented 200 sx Permafrost 660 sx AS 111, 540 sx Class G 225 sx Class G 190 sx Class G Measured Depth 121' 3957' 9157' 9679' True vertical Depth 121' 2796' 5704' 6129' Perforation depth: measured 9432' - 9454', 9360' - 9380' true vertical 5924' - 5942', 5865' - 5881' RECEIVED Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg @ 8928' MD. BAKER ZXP LINER TOP ISOLATION PACKER @ 8928' MD. CAMCO 'DS' @ 523' MD. FEB 2 0 ZOO?_ Alaska ()ii 8, Gas Cows. Commissio~ Ancl~orage 13. Stimulation or cement squeeze summary Intervals treated (measured) 9360'- 9380' Treatment description including volumes used and final pressure C-sand frac, 96000# 16/20 carbolite, 10 ppa on perfs 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation 344 1650 644 Subsequent to operation SI Casing Pressure Tubing Pressure - 263 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil ~ X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended Service _ Questions? Ca//Mike Mooney 263-4574 Signed Michael Mooned/ Form 10-404 Rev 06/15/88 Title Wells Team Leader Prepared b~/ Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 2A-19A Event History 01/11/02 01/16/02 01/17/02 01 / 18/O 2 01/20/02 01/21102 01/22/02 PUMPED INITIAL C SAND FRAC. PLACED 96M# 16/20 PROPPANT BEHIND PIPE, 10 PPA ON PERFS, 83% OF DESIGN. HAD NWBSO IN EXTENDED 10 PPA STAGE, LEFT 26M# IN WELLBORE. [FRAC- REFRAC] CLEANED OUT TO 1900' CTM W/DOWNJET NOZZLE TO ENSURE NO ICE PLUG. RBIH W/1.75" BALLDROP NOZZLE AND REV-OUT SAND TO 7100'. INJECTOR SUMP DRAIN HOSE FROZE, WAS FORCED TO POOH TO THAW HOSE/DRAIN SUMP. (CONT. ON NEXT WSR). [FCO] CONTINUED. RBIH AND REV'D-OUT FILL TO TOP OF 2.75" PXN PLUG SET @ 9417' RKB. WASH PASSES MADE ACROSS MANDRELS. WELL FREEZE PROTECTED W/DIESEL TO 2500'. [FCO] TAGGED FRAC SAND IN TBG @ 9338' WLM. JOB SUSPENDED DUE TO WEATHER [TAG] INSTALLED OV @ 8880' RKB. IN PROGRESS. [GLV] INSTALLED NEW GAS LIFT DESIGN. BAILED @ 9334' WLM. EST 64'+ FILL ABOVE PXN PLUG [GLV] BAILED FRAC SAND F/9336' TO 9340' WLM, EST. 60' FILL ABOVE PXN PLUG. [OPEN-CLOSE A SAND] Page 1 of I 2/11/2002 WEI,I, LOG TRANSNIYUFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 18, 2001 RE: MWD Formation Evaluation Logs 2A-19A, AK-MM-10165 1 LDWG formatted Disc with verification listing. APl#: 50-103-20197-01 PLEASE ACKNOWLEDGE' RECEIPT BY ~IGNING-AND RETURNING A' COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED Pf,. LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2A-19A (201-083) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on the KRU well 2A-19A. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4601' FNL, 50' FEL, Sec. 14, T11 N, RSE, UM At top of productive interval 1483' FNL, 1286' FEL, Sec. 22, T11N, R8E, UM At effective depth At total depth 1595' FNL, 1367' FEL, Sec. 22, T11N, RSE, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service_ (asp's 498340, 5960099) (asp's 491828, 5957944) (asp's 491748, 5957829) 6. Datum elevation (DF or KB feet) RKB 124 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-19A 9. Permit number / approval number 201-083 / 10. APl number 50-103-20197-01 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 9681 feet 6130 feet Plugs (measured) Effective depth: measured 9441 feet true vertical 5931 feet Junk (measured) Casing Length Size CONDUCTOR 121' 16" SURFACE 3833' 9-5/8" PRODUCTION 9641' 7" PROD LINER 751' 3-1/2" PROD LINER Cemented 200 sx Permafrost 660 sx AS III & 540 sx Class G 225 sx Class G 190 sx Class G Perforation depth: measured 9360'-9380',9432'-9454' true vertical 5865'-5881', 5924'-5942' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 8928' MD. Packers & SSSV (type & measured depth) BAKER ZXP LINER TOP ISOLATION PACKER @ 8928' MD. CAMCO 'DS' @ 523' MD. Measured Depth 121' 3957' 9157' 9679' True vertical Depth 121' 2796' 5704' 6129' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 383 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 1466 794 460 1635 900 Casing Pressure Tubing Pressure - 232 243 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Gas ~ Suspended Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /¢/~-~/~ ,/~ ~ Title Staff Engineer Michael Mooney Questions? Call Mike Mooney 263-4574 Prepared by Sharon Al~sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2A-19A Event History 09/23/01 09/28/01 PERFORATED C SANDS 9360'-9380', W/2-1/2" HSD, P J, HMX, 6 SPF, 60 DEG. TAGGED TD @ 9435'. [PERF, TAG] PUMP 10 BBLS SW W/30 GALS WAW-5206 OF PREFLUSH & 29 BBLS SW W/160 GALS SCW-4004 OF TREATMENT. [SCALE INHIBITOR] Page 1 of 1 10[15/01 7/19~2OO 1 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1303 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1J-03 ZOJ~ 0a%~ SBHP 06/27101 '1 D-101 Z~)f)"/~ ~ INJECTION PROFILE 06121101 ID-107 Z.r~-,~'~'~ INJECTION PROFILE 06124101 1D-128 J~ --/~ ~ INJECTION PROFILE 07/06/01 IR-26 /~/- ~Z INJECTION PROFILE 0610~0t 2A-19A ~1 -~ SBHP STOPS 06117/0t ~F-O8 16E-~z) PRODUCTION PROFILE 0612S/01 2G-9 l~~ [O5 GAS LIFT SURVEY 07103101 2G'09 ] ~'J0 ~ PRODUCTION PROFILE 07/~4101 2N-326 ~ IE~ PRESS & TEMP BASELINE 07/0~01 2N-326 ~ e~l~ WFURSTIPSP 07104101 2V-03 t e~' [~ WF~RST-A 06109101 3J-07A ~el' ~ SBHP SURVEY 06/19/01 3M-01 ~J~~IZ INJECTION PROFILE 06/29101 30-05 I~-O~ INJECTION PROFILE 06/24101 30-10 /~- ~ INJECTION PROFILE 07105101 30-19 I~- O~ RST BO~LDL 06104101 C~ SlGNE 4'~ ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. RECEIVED JUL 30 2001 Anchorage PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4136 Fax: (907) 265-6224 July 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2A-19A (201-083 / 301-086) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 2A-19A. If you have any questions regarding this matter, please contact me at 263-4135 or Brian Noel at 265- 6979. Sincer~ .<, T Brockway Interim Drilling Engineering Supervisor PA1 Drilling TAB/skad RECEIVED JUL 1 6 2001 AJaska 0/I & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas [] Suspended D Abandoned D Service D. ~~' 2. Name of Operator ~:.~ ~irJ~ 7. Permit Number Phillips Alaska, Inc. ~j i~ 201-083 / 301-086 3. Address .-I ~.~j ~.~ :. 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360'~ ~ 50-103-20197-01 4. Location of well at surface ~";i~T;~ ',~'-;:~?"I 9. Unit or Lease Name 676' FSL, 53' FEL, Sec. 14, T11N, R8E, UM (ASP: 498341, 5960098) ;: ...... ,.i ~:~i.'" :' ! Kuparuk River Unit At Top Producing Interval i ~"¢-~?~'-~L~ J/ 10. Well Number 1483' FNL, 1286' FEL, Sec. 22, T11N, R8E, UM (ASP: 491828, 5957944) !~ '---- ~¢£:?.?~, ~ 2A-19A At Total Depth ~ ..... .,~ .~ 11. Field and Pool 1599' FNL, 1367' FEL, Sec. 22, T11N, R8E, UM (ASP: 491748, 5957829) ~ ....................... J Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 124'I ADL 25571 ALK 2669 12. Date Spudded 13. Date T.D. Reached 14. Dat.e Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 27, 2001 May 28, 2001 "'/~00!,~"^"- "-' --ii N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9681' MD / 6130' TVD 9579' MD / 6045' TVD YES [~] No DI N/A feet MD 1600' (approx) 22. Type Electric or Other Logs Run GR/Res, PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 200 sx Permafrost 9.625" 47 & 36# L-80 & J-55 Surface 3957' 12.25" 660 sx AS III & 540 sx Class G 7" 26# L-80 Surface 9157' 8.5" 225 sx Class G 3.5" 9.3# L-80 8928' 9679' 6.125" 190 sx Class G bridge packer set @ 9157' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8933' 8928' 9432'-9454' MD 5924'-5942' TVD 6 spt 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9432'-9454' see details in attachment 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 27, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 6/27/2001 5-3/4 hrs Test Period > 152 320 400 209 I 1381 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 246 psi 1227 24-Hour Rate > 575 794 1638 24° 28. CORE DATA Brief descdption of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.RECEIVED N/A JUL 1 6 001 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit In duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9354' 5860' Base Kuparuk C 9384' 5885' Top Kuparuk A 9392' 5891' Base Kuparuk A 9582' 6048' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Su, r~ey 32. I hereby certify~t~t the foll~?ng is tree a~o/~ct to the best of my knowledge. Questions? Brian Noel 265-6979 Signed,., , ,. Title Interim Dri Iinq Enqineefinq Supervisor Date INSTRUCTIONS Prepared by Sharon AIIsup-Dral~e General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5; Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 ORIG NAL JUL 6 001 Alaska 0il & Gas Cons. Commission Anchorage Operations Summary 2A- 19A Rpt Date 05/23/01 12:00 AM 05/24/01 12:00 AM Comments Rig move complete@ 0830 hrs. PJSM & ops on well plan. Rig up circulation lines. Install berms around rig. Off load 350 bbl sea water to mud tnks& pt hard lines to 1500 psi. Pull bpv & vr plug. Annulus pressure 300 / tbg 200 psi. Complete laying flow lines for circulation. Pressure hard lines & cir system to 1000 psi / 5 minutes. Displace well fluids [cir down tbg] taking returns from annulus to flow back tank w/330 bbl sea wtr, 4 bpm / 370 psi. Monitor well dead for 15 minutes. Install bpv, nd tree & set out side cellar area. Mi replacement tree. NU 7 1/16" x 5000 psi bop, install choke / kill lines / hydraulic lines / function rams. Reassembly riser to accomodate shorter cameron well hd system. Complete riser assembly. Recover bpv. Install test plug & reconfigure rams. Test bope as per AOGCC rep to 250 / 3500 psi. Annular to 3000 psi. Recover bpv Make up Idg jt to hanger & pull hanger to floor. Required 95K lbs pull to pull hanger out of bowl, then fell off to 80k lbs string wt [string wt in sw approx 75k lbs]. Pull hanger above observe well static. Circulate w/8.5 ppg sw, @ bottoms up observed 18 ppm gas @ shakers on rig gas system. Continued to circulate w/eratic Iow gas units, sw gas cut. Si, ck csg pressure @ 160 psi, open dhsv wi 5k lbs control pressure, @ that time both tbg & csg showed 200 Continued to oberve well static @ 650 psi. pressures slowly increased to 670 psi.. Order out 480 bbl 11.1 ppg mud [cai kill wt 10.7 ppg]. Hauling excess sw to disposal. NOTIFY: John Spaulding [aog¢c] of intension to kill well w/11.1 ppf using drillers 05/25/01 12:00 AM Pressure test circulating hose to 2000 psi: START KILL; Pumped 20 bbl spacer followed by kill weight mud of 11.1 ppg. Initial circulating pressure 1050 psi calculated problems holding due to aired up pumps. Complete pooh w/ completion lid same], pumped second dry slug, fill up correct. Rec 30 of 31 cont line clamps, left in hole one clamp [1 x 5.5 long x .125"]. Rec cont line to spool, recovered chemical cut area [hanging by one 3/4" strip], one 6' pup 05/26/01 12:00 AM Clean / organize floor / PJSM for scrapper run. ,RIH w/6.125" bit & scrapper on 3.5" dp, tag pbr @ 9243'. Ru to circulate, complete crew change. Cir / condition @ 4 bpm / 1000 psi, unable to work deeper than 9243'. Depth is sufficient / spacing adequate for space out for setting cibp & whipstock. Pjsm & clean / police floor. Make up cibp to setting tool & trip in on dp. Tag up on pbr @ 9243' rkb Nordic 3. Ck up / down wts of 127k / 113 k lbs. Strap out to setting depth of top of cibp of 9157'. Drop ball & cir down [4 bpm / 1390 psi], increase pressure to 1500 psi when ball hit setting cibp @ 9157'. Pressure test / chart cibp to 3000 psi / 30 min, aogcc notified, not present. Pooh w/setting tool, no damage to same. Pjsm Clean up floor & strap bha components. Make up milling assmby to whipstock, pu / mu mwd tools [orient - scribe] & remaining bha. .i~ Operations Summary . 2A- 19A 05/27/01 12:00 AM 05/28/01 12:00 AM 05/29/01 12:00 AM 05/30/01 12:00 AM Tih on dp to 9100', ck up / down wts pump on / off of 125/63 k lbs & 143 \ 70 k lbs. Orient whipstock tool face 45 deg left of high side. Circulate down to tag cibp @ 9157', set down 15k over string, set anchor @ 39 deg left of high side. Pick up to n Break cir. Cut window 9138 - 9150 & formation to 9162'. 3100 psi/250 gpm / 2-3 k lbs bit wt / torq 9k ft-lbs in steel / 6k in formation / rpm 80. Ditch magnates in place - mc approx 5 gallons 1/8 to 1/4 .... flat plate like shards. Mud samples @ shaker (:;ir/cond/sweep hole. Pull mill into csg. Conduct charted F.I.T.; impose 410psi by pumping .4 bbl down dp w/11.1 ppg mud in hole, emw = 12.5 ppg. Bled back 1.6 bbl. FIT rpt e-mailed in. Aogcc notified - no show. Pooh to 8500'. Cut drlg line. Complete pooh. Lay down / gage mills - all in gage upper mill 6.15". Pu bit, motor & mwd tools as per dir assmby. Conduct surface cks on mwd equip. Complete pu bha & tih 9050'. Orient tools & slide through window [did not take any weight] tag up on pipe tally @ milled td of 9162', no fill. NOTE: on metal shards: cai total metal to rec = 156 lbs. Have takened four 12 hr magnate "captures" for esti 60, 30, 20 & 3 lbs = 113 lbs. Drlg - slide 9162 - 9334'. 1st reliable azmuth from survey 9281, bit depth 9331'. Azmuth & inc good started rotating. Rot drlg 9334 - 9353'. ECD increased rapidy to 12.8 emw. Lost 20 bbl mud. Pu off td, work pipe, lower mw to 10.9 ppg & adjust pv / yp to 49 / 22. Cir ecd decreased to 12.1 ppg Sd pumps. Monitor well static. Rot drlg 9353 - 9681' [Well TDed for liner]. Good coarse / target control. No mud losses. Circulate bu, flow ck. Well flowing 6 bph. Circulate & raise mw to 11.0 ppg heavy. OPS after Midnight: Monitor well for 1/2 hr, gaining 2 bph, raised mw to 11.1 & trip to window, well took 1 1/2 bbl. Monitor 1/2 hr, gaining 2 bph, si [@0530 hrs] for 40 min gaining 70 psi. bleed off press Pooh to window, noted well flowing 2 bph, tripped to td [ no fill] & raised mw to 11.7 ppg in two circulations, minor gas w/traces of oil to surface. Monitor well taking 1.5 bph. Drop 2.1" rabbit & pooh to window,ck well taking 1 - 1.25 bph, pump dry slug. Pooh standing back dp. Lay down bha, download mwd data. Pu / Mu 3.5" float equip to liner & trip in hole making up liner to "3' long polish bore w/ 2.75" id ........ " Threads in box of polish bore pull away from body of tool down to ab mod groove. Located a shorter [1.28 vs 2.71 '] 2.75" polish bore nipple. Continue to tih w/liner assmby. Complete tih w/liner assmby filling every 5 stands. Tag up @ td of 9681' on dp tally, no fill Cir cond mud to 11.6 ppg smooth. Ck up wt of 130k & down of 65k lbs. Conduct PJSM on cmt & liner hanging ops. Dowell press test lines to 4000 psi / 10 min & cmt 3.5" liner as follows: Lead w/20 bbl fw, 15 bbl chemical wash, & 40 bbl 13 ppg mud push @ 1500 psi / 4 bpm. Follow w/ 34 bbl [190sx] slurry {15.8 ppg / yield 1.2 / } of class G Gas Block - batched mix Operations Summary 2A-19A W/running tool stinger inside liner top reverse circulate 400 bbl mud @ 2800 psi / 5.8 bpm, diverted approx 7 bbls cmt contaminated mud. SD & rig down down floor equip. 05/31/01 12:00 AM Pooh laying down dp. RIH w/hwdp from derrick, pooh Id same [incomplete @ rpt time]. Complete laying down hwdp. Pu / Mu Baker GBH seal bore assmby & rih on 3.5" tbg installing tubing accessories as noted in completion plan. w/seal assembly @ 8900' peressure test liner & csg to 3500 psi [charted] for 32 minutes. Initial recorder pressure 3400 psi final 3350 psi [1.47% loss], digital gages show a steady 3500 w/no pressure loss. Bleed off pressure. Run a total of 282 jts & space w/one 2.34' pup to locate end of seal assmby 2' above Iocator hub [ ZXP bearing race] @8933'. The liner top is 6.5' above the bearing race. 06/01/01 12:00 AM PU 20' above liner top. Circulate @ 8 bpm / 2200 psi 40 bbl hi vis sweep, 30 bbl caustic wash followed by 800 bbl cleam sea water, returns clean after 750 bbls. Install one 2.34' pup under full jt of tbg & hanger w/2' pup below & lower to tbg head: pu wt = 85k lbs & 50k down [string wt].Run in tie down bolts. Open annulus / monitor for returns. Test tbg to 3500 psi [chart] for 15 min, bleed tbg to 1500 psi & pressure annulus to 3500 psi. Did not shear dump valve. Increase annular pressure in 100 psi incriments to 3900 psi where valve sheared. 80% burst of 7"x 26 ppg L-80 csg -- 5800 psi Recover Idg jt, install back press valve & nd riser & bop. Nu X-Mass tree. Pull bpv, install test plug & test tree 250 / 5000 psi. Test void to 5000 psi. Pull test plug. Pump 90bbl diesel down 7 x 3.5" annulus @ 3.5 bpm / 470 psi. Take returns to pits fromtbg. Manifold tbg / annulus together via rig choke & allow to u-tube into place Cai freeze protection to 2420'. Pressures equalized after 55 minutes. Install BPV, prepare to move to 3J. Rig released at 01:30 AM. Date Comment 2A-19 Event History 05/07/01 SET HALLIBURTON BRIDGEPLUG 3-1/2" AT: 9255 FT~ CCL TO TOP OF PLUG: 10 FT~ STOP CCL AT: 9244 FT~ I MIT TEST SUCCESSFUL ( PUMPED DIESEL THROUGH THE IA) I I APLIED CHC CUTTER AT: 9240 FT~ CCL TO SEVERING HEAD: 24.6 FT~ STOP CCL AT: 9215.4 FT 06/10/01 06/11/01 06/12/01 06/17/01 06/18/01 DRIFT TUBING. SET 1-1/2" DV @ 8874' WLM (8880' RKB) WASH DN THROUGH MUD FROM LINER TOP FOUND PBTD AT 9568' CTM. LEFT SW TO TD. FREEZE PROTECT WELL TO 2600'. TAGGED @ 9580' RKB, PT TBG TO 2500# HELD, DRIFTED TBG W/23' OF 2.65" DUMMY GUN'S TO 9580' RKB (Tag, PT Tb~-Cs~) PERFORATED: 9432' - 9454', 6 SPF - SBHP AT 9443'= 3600.2 PSIA, TEMP= 154.7 DEG F PUMPED POST-SIDETRACK FRAC. WELL LOCKED UP DURING BREAKDOWN STAGE WHEN FLUIDS HIT PERFS. SURGED TO TANK TO OPEN PERFS BACK UP. FINISHED BD STAGE, HIGH PERF FRIC. PUMPED SCOUR STAGE, PERF FRIC DROPPED OFF. PUMPED DATAFRAC, INCREASED PAD TO 600 BBLS. SAW TSO IN FRAC AT ~96 MINUTES (DESIGNED FOR 93 MINUTES). WELL PRESSURED OUT WITH 210M# BEHIND PIPE, 10 PPA ON PERFS, 71% OF DESIGN PLACED. LEFT 22M# SAND AND ONE TREESAVER RUBBER IN WELLBORE. (Frac-Refrac) Page I of I 6/21/01 14-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2A-19A ,, Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,106.73' MD 9,138.00' MD 9,681.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN19 Z001 Aia~ 0il& Gas Cons.~ DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 2A, Slot 2A-19 2A-19A Job N°. AKMM10165, Surveyed: 28 May, 200~ SURVEY REPORT 8 June, 2001 Your Ref: API.50103201970~ SUrface Coordinates: 5960097.73 N, 498340.74 E (70° 18' 07.9683" N, Kelly Bushing: 123.95ft above Mean Sea Level 150° 00'48.3824"W) nRILLIN{; Sr=RVII~E5 A Halliburton Company Survey Ref: svy9558 Sperry-Sun Drilling Services. Survey Report for 2A-19A Your Ref: API-50'i0320'i9701 Job No. AKIVIM10165, Surveyed: 28 May, 200'i KuparUk ·River Unit Measured Depth (ft) Incl. Azim. 9106.73 43.370 248.980 9138.00 43.320 250.700 9281.36 35.950 221.290 9302.16 35.730 217.530 9341.06 35.300 211.350 9439.76 34.790 212.480 9536.79 34.240 214.890 9630.66 33.440 216.630 9681.00 33.440 216.630 Sub-Sea VertiCal Depth Depth (ft) (ft) Local COordinates Global Coordinates Northings - Easfings Northings Eastings (ft) (ft) (ft) (ft) 5542.86 5666.81 2028.72 S 6369.00W 5958070.42 N 491971.29 E 5565.60 5689.55 2036.12 S 6389.15W 5958063.02 N 491951.14 E 5676.91 5800.86 2084.48 S 6464.09W 5958014.68 N 491876.19 E 5693.77 5817.72 2093.89 S 6471~82W 5958005.27 N 491868.46 E 5725.45 5849.40 2112.50 S 6484.59W 5957986.66 N 491855.68 E 5806.25 5930.20 2160.61S 6514.55W 5957938.56 N 491825.71E 5886.21 6010.16 2206.35 S 6545.03W 5957892.83 N 491795.22 E 5964.18 6088.13 2248.77 S 6575.57W 5957850.41N 491764.67 E 6006.18 6130.13 2271.03 S 6592.12W 5957828.15 N 491748.12 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and 'Eastings are relative to Well. . Magnetic Declination at Surface is 25.922° (25-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 251.960° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9681.00ft., The Bottom Hole Displacement is 6972.35ft., in the Direction of 250.991° (True). Dogleg Rate (°/~OOft) 3.779 13.935 10.636 9.292 0.836 1.517 1.339 0.000 Vertical Section 6684.16 6705.61 6791.84 6802.11 6820.01 6863.40 6906.55 6948.72 6971.35 North Slope, Alaska Kuparuk 2A Comment Tie on point Top whipstock Pr~ected su~ey 8 June, 2001 - 5:~2 Page 2 of 3 DrillQuest 2.00.08.005 Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 2A-19A Your Ref: API-50~0320~970~ Job No. AKIVlM10165, Surveyed: 28 May, 2001 North Slope, Alaska Kuparuk 2A COmments Measured Depth (ft) Station Coordinates 'I'VD Northings Easfings (ft) (ft) (ft) Comment 9106.73 5666.81 2028.72 S 6369.00 W Tie on point 9138.00 5689.55 2036.12 S 6389.15 W Top Whipstock 9681.00 6130.13 2271.03 S 6592.12 W Projected survey Survey tool program for 2A-~9A F'rom To Measui'ed Vertical MeasUred Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 9681.00 6130.13 Survey Tool Description MWD Magnetic (2A-19A) 8 June, 2001 - 5:~12 Page 3 of 3 DrillQuest 2.00.08.005 Re: 2A-19 well kill and P&A { Subject: Re: 2A-19 well kill and P&A Date: Fri, 25 May 2001 14:21:14 -0700 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Brian D Noel <bnoel@ppco.com> CC: aogcc_prudhoe_bay@admin.state.ak.us, "Randy L. Thomas" <rlthomas@ppco.com>, James A Trantham <jtranth@ppco.com>, Nordic 3 Company Man <n1433@ppco.com> Brian, Thanks for the information. I will be interested to hear what is determined with regard to the incomplete cut. You had mentioned so other recent chemical cuts that were not completely successful. If you have a listing of these, I would appreciate it. Aside from the information with regard to the cut, i will not require anything further. Good job to all. Tom Maunder, PE Petroleum Engineer AOGCC Brian D Noel wrote: :> :> :> :> :> :> :> :> :> :> :> :> :> :> ;> :> ;> ;> Here's summary of the well kill completed on 5/24/01, before pulling the tubing and sidetracking: Well parameters: 7" casing, 3-1/2" tubing, single packer, gaslifl completion in Kuparuk C/A sand. Pre-rig: pulled rock screen from tubing tail, unable to pump into perfs (sand & rock fill up to tubing tail), eline set bridge plug in tubing at 9255' (packer at 9272'), chemical tubing at 9240', open pocket mandrel at 9209'. Pressure tested tubing/casing to 3000 psi. Rig operations: Rig moved onto well 5/23/01, circulated seawater around, monitored well- no pressure on tubing or casing. Set BPV, pulled tree, NU and tested BOPE. Pulled BPV and then pulled hanger to floor. Circulated 8.5 ppg seawater and at bottoms up had 18 ppm methane gas at shakers. Circulated a little longer with Iow gas readings. Shut well in at approx, lO:30am on 5/24/01 with 160 psi on casing, pump up control line to open SSSV, had 200 psi on both tubing and casing. After 40 rain SI, 650 psi on both tubing and casing. Continued to monitor well while waiting on sufficient mud volume for kill. North slope inspector John Spauiding notified while waiting. Well static with pressure slowly building to 670 psi in 5 hours. Kill weight calculated from shut in pressure = 10. 7 ppg. Well kill: - Used wait & weight method to kill. - At 6pm circulated on choke 20 bbl high vis spacer ahead of 11.1 ppg LSND mud (10.7 ppg for kill plus trip margin when drilling sidetrack). - Surface to surface volume = 74 bbls in tubing + 261 bbls in annulus. - Initial bottoms up had ~ O. 8 ppg (seawater cut mud), diverted to tank. - After 446 bbls pumped, shut in pressure on tubing = 0 psi, casing = 70 psi. - Made second circulation with 11.1 mud, smooth 11.1 ppg returns, checked shut in pressure on tubing and casing, well dead. I of 2 5/25/01 4:21 PI~ Re: 2A-19 well kill and P&A > - Monitored well for 30 rain - static at midnight. > Current operation: > 5/25/01 - Pulled 3-1/2" tubing with no problems. The chemical cut left > approx 3/4" circumference of tubing uncut (just enough attached that when > pulling hanger to floor, the seal assembly and pup with bridge plug pulled > free from packer's PBR). Thus exposing casing to formation pressure. > As discussed yesterday, since fill level is at tubing tail and unable to > pump into formation, plan to set 7" bridge plug at 9170' plus cement back > into welibore after sidetrack liner is run will meet the P&A requirements > for 2A-19. I will fax new P&A drawing reflecting~he missing tubing > stub/bridge plug. ~'~ > Let me know if you have any questions. Thanks - Brian 265-6979 Tom Maunder <tom maundert'~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 5/25/01 4:21 PM FROM:, ~PHILLIPS AK I: FAX NO.: 9072651535 ~ 05-25-01 03:37P P.O1 AnchE Phillis Alaska ~.c. 700 G Street, ge, AK 99501 FAX Number of pages including cover sheet: To: Phone: F~ ?hone: CC: Wells Group Phone: Fax phone: Location: REMARKS: [-] Urgent ['"1 For you~ review 1'-] Reply ASAP [~] Please comment 'RECEIVED FROM: PHILLIPS AK FAX NO.: PHILLIPS Ala '-a, Inc. A 3ubsidiary of PHILLIPS PETROl. cUM COMPANY sssv (1784-178S, OD:$.g,'~) G~= Uft -- lan~mlfDummy Valve 1 (2018-2019, OD:5.390) lendre~Oummy Valve OD:5.390) landrel/Dummy Valve {6197.6198, OD:5.390) Gas Lift landrel/Dummy V~)lve 4 {7534-?~30, 00:5,390) Gas Lift ...................... 9072651535 ,1 '(RU 2A-19 APl: 50103201'9700 · . 35SV Type;. TR DP Annular Fluid: R~fefmn=e Lo.~.;. .. " Last Tag;. 9396 La.~..Tag Datc: 3/25fO1 .... Casing String - SURFACE Descr!pflon Size : SUR. CASING 9.62,5 . SUR. CASING 9.625 Casing S.tring - CONDUCTOR Descr!ption ' ' Size CONDUCTOR 16.000 .Casing .String__,__~.RODU CTIO N Description Size PROD. CASING 7.000 Tubing ,..s.t~.i.n. g_-T.U...B ! N G Si~e top I'-'~'~t'i°r" ...... 3.500 ' 0 ;" / ~'929e Perforations Su'mmary Interval TVD Zone 9378 - 9404 ~870 ~ 51~89 C-4 We~ Ty~e..: PROD Gag C0;~p!etio~?.TfTf79'3-" Last W/O: Ret Log Date: TD: 9785 flKB M~x Hote Angle:' 61. ~..e. gj~_~..2.72 05-25-01 03:37P P.02 2A-19 : Angle @ TS: 4Z deg (~ 9374 ........... A~gle (~ TO;. 40 deg @ 9788 Rev Rea~oe_:._Ta_~g_~.~ set CR-.Loc! · _.i ...... "[.~'~'t" Up.d_a_~e_L 4/2/01 ' Top Bottom TVD Wt Grade Thread o o o ' ";~,-,5'~- L-S0 '" 0 __3957 '. .... _2..8.0! .......... 'i....36.00 L-80 __ Top Bottom TVD [ Wt 'G~'ade Thr~l' .......F-~'~o ~-~o 0 12~ 121 " Top Bottom TVD : Wt Ora'de Thread" 0 9765 6164 ~ 26.00 L-80 leh(ff¢llDummy Valve 5 [8731-8732, OD:S.390) Lift ...................... landml~umm,v V~lw 6 (920~9210, O0:5,968) PKR [9272-9273, OD:5.938) TVO ......... Wt ....... Grade [ ........... Ti~r~ad ....... 5810 ~' J).SO ......... ~1-50 .... i .... 1~2'~'~.'~.D . '""'~ Status I Ft [_~,_P_~.. D.,,.a,.t..e.__,i ."i:);jji~'i'i,'' Comment i 26 [ 6 4/13/98 , APERF 2.5" HC DP; 60 deg. phasing ' [ . , no orient 9460- 9490 5931 - 5954 A-3 "?-30 ! 4 3t3/94 i IPE~i:'-~4 1/2" HSD; 180 d~. pha,~inl Stimulations &.._T._r.~a., t .m,e n_~.i ..... ......... i'itterval Date · Type ........... i ' ................. Comment ..................... o- o 4/24/97 Scale Inhibitor ...! PumPed10 abls SW W/30 Gal SS-8206 G,~s Lin MandrelSNalves ................................... St MD ' TVD [ Man Man VMfr VType [ VOD Latch Port TRO Date Vlv ,: ...... ' Mfr ' Type ,.. I Run Cmnt '"T" 2018' 17831McMurryl FMHO DMY 11,0 BK '"0.'~)~'":~'"'"'b-- ...... --2' .... 4~91 3 ' 6J'~7' 398'~ i MCMurry["" FMHO ................ ~ DM'?"" i 1 0' -'§'k "0',~'00 I~ 0 ........ %/2'-'~/-~'~~'~ .... -4"-- ~-6'§~ 4791 I~'~Murryl "F"~'~"~'~ ............ = DMY .... ,f'~' BK ......... ' 0,000I "'~' .........§7'27t97 5' 8731i 54101McMurrYl FMHO [ DMY 1 1'o BK 0,000J 0 ' 8127197' ..... ~" ',.,9.2.~9i 5744[ camc~'T'~'-, M-"~'I~ ........... '~ ~'k~'~[-"1~5' RK .... 0'.0so ~ ..... 5 ....... 8/28/~-- ..,Other (p~ugs, equip,~_.e.t,,c:) - JEWEi'-I~¥ ...... ... ' ......................... ID 2,813 3.0'00 3.000 ? 7,~0 ,.D....e. pth TVD TyRe I Description ..... 17&4 1620 S$~'V Camco TRDP-2A-SS^ (as per CAMCO 3/2..!./_2.-_0.0_0)~i"""~' .... -'=~'§ .... 5781 PBR ~ Baker ....... ; ....... ' .... c~T2' ,' 5791 P"~'I~'~R_'L> ' ................... "' t ~87 5802 NIP "'~'~li~"~ie NO GO'- Se~ 2,?~," CA-Lock w/rOck screen §'~'~§'~J~ ....... /U~~~';_" sos~ .......................... KEL, I' IVI:U TUBING .......... (O-9296 ...... 00',3.500, / IO:2.9921 909 -- (9297,9291~, "" 00:3,500) ~-. " Pert ::; ~,,; (~460-~4~) ..... 2.984 AbAS~ OIL AND GAS CONSERVATION COPlP~ISSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc P.O. Box 100360 Anchorage AK 99510 TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 2A-19A Phillips Alaska, Inc. Permit No: 201-083 Sur Loc: 676' FSL, 53' FEL, Sec. 14, TllN, R8E, UM Btmhole Loc. 1614' FNL, 1364' FEL, Sec 22, TllN, R8E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be apProved for. this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be'contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. BlOwout prevention equipment (BOPE)must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed Prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607, Commissioner BY ORDER OF THE COMMISSION DATED this f '~ -fi day of May, 2001' jjc/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [~] Reddll BI I lb. Type of well. Exploratory D Stratigraphic Test BI Development Oil r~ Re-entl¥ E~ Deepen F~I Service BI Development Gas E] Single Zone ~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 124 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25571 ALK 2669 Kuparuk River Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 676' FSL, 53' FEL, Sec. 14, T11 N, RSE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1443' FNL, 1268' FEL, Sec. 22, TllN, RSE, UM 2A-19A #59-52-180 At total depth 9. Approximate spud date Amount 1614' FNL, 1364' FEL, Sec. 22, T11N, RSE, UM May 11,2001 $200,000 12. Distance to nearest properly line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1268' @ Targ~ feet 2A-07 18.2' @ 450' feet 2560 9678 ' MD / ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 9162' MD Maximum hole angle 37.6° Maximum surface 2671 psig At total depth (TVD) 3300 psig 18. Casing program Setti%l Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Weight Grade couplinc~ Length MD TVD MD TVD tinclude sta~e datat 6.125" 3.5" 9.3# L-80 EUE 8rd Mot 668' 9010' 5596' 9678' 6112' 31 bbls Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9785 feet Plugs (measured) true vertical 6179 feet Effective Depth: measured 9683 feet Junk (measured) true vertical 6101 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 sx PFC 121' 121' Surface 3916' 9.625" 660 sx ASIII L, 540 sx Class G 3957' 2800' Production 9721' 7" 225 sx Class G 9765' 6164' Liner RECEIVED Perforation depth: measured 9378'-9404', 9460'-9490' M,,~Y 0'7 -- true vertical 5870'-5889', 5931'-5954' AlaSka Oil & Gas Cons. Comm-s~ 20. Attachments Filing fee ~] Property Plat F~ BOP Sketch BI Diverter Sketch BI Drilling progra~l'~ Drilling fluid program r~ Time vs depth plot DRefraction analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby certify that the for, cgoing, is true and correct to the best of my knowledge Questions? Brian Noel 265-697~ _ Signed Title: Drilling Engineering Supervisor Date James Trantham 2/'~,/~' ~,//~~,,~,~ ,'Zczd/'Z ,]-'~---5~, ,/~~~ Pre~)ared bv Sharon AIIsu~-Drak~ Commission Use Onl~ Permit Number2 O,,/ ~ ~",,.~ APl number50./LT~ ,~ ~ / ~ ~' '-" O ~/~ I Approval date ~/?/1~/ ISee cover letter - - Ifor other requirements Conditions of approval Samples required D Yes [~ No Mud Icg required D Yes [] No Hydrogen sulfide measures D Yes ~ No Directional survey required [] Yes D No Required working pressure for BOPE E]2M; D 3M; . D 5M; D 10M;E~ ~ '~(~.,~ ~>~.~ ~.~(~R't~'¢~,~"'~' r'Ck'~"~*~ ~'~. Other: ORIGINAL SIGNED BY by order of Approved by D Tavlnr ~¢2mn~nf Commissioner the commission Date . ORIGINAL Form 10-401 Rev. 12/1/85 · Submit in triplicate I A~{~' ~tion for Permit to Drill, Well 2A-19 Revision No,0 Saved: 7-May-01 Permit It- Kuparuk Well 2A-19A Application for Permit to Dr/Il Document MaxWell MOxinlizE Well Table of Contents 1 1 w m 1 = ! al sm 10. 11. 12. 13. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................ 2 Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 Casing and Cementing Program ............................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 3 Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 4 Abnormally Pressured Formation Information ...................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 Seismic Analysis ..................... ' ................................................. 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 Proposed Drilling Program ...................................................................................... 5 ORIGINAL 2A-19A PERMIT IT. DOC Page I of 6 Printed: 7-May-01 14. 15. 'i~ A~¢' ztion for Permit to Drill, Well 2A-19 % Revision No.0 Saved: 7-May-01 Requirements of 20 AAC 25.005 (c)(15) ................................................................................................ 5 Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25. 005 (c)(14) ................................................................................................ 6 Attachments ............................................................................................................. 6 Attachment I Directional Plan ................................................................................................................ 6 Attachment 2 Well Schematic .............................................................................................. 6 1 1 Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unJque name designated by the operator and a unique APl number a.~g~gned by the comm/ssion under 20 ~C 2&'~ 040(b). For a well with multiple well brand~e.~ each branch must 5imilarly be identifibd by a unique name and AP[ number by adding a .~z~x to the name des/~gnated ~or the well by the operator and to the number &~'igned to the welt by the commisL~Yon, The well for which this Application is submi~ed will be designated as 2A-[gA. Location Summary Requirements of 20 AAC 25.005(c)(2) Afl applic~tion fbr a Permit to Dr/Il must be accon?par#ed by each ot"the fbi/owing item.$ except for an/tern a/ready on file with the commission and identified in the ,~p/ication: (2) a p/at identifying the property and the proDe/f)/'s owner~ and showing (A)the coord#lates of the proposed location of tile well at the sudace, at the top of each ob./ecb've £ormation, and at total depth, referenced to governmental sect/bn lines'. (B) the coordinates of the proposed location o? the well at the surface, re£erenced to the state plane coordinate system for this state as maintained by the National G'eode~ic Survey in the National Oceank:' and Atmospheric AdministraUon; (C) the propo.~'ed depth o? the well at the top of'each objective formation and at total depth; Location at Surface I 676' FSL~ 53' FEL~ Sec 14~ TllN~ R8E~ UN NGS Coordinates J RKB E/evationI 124' AMSL Northings: 5,960,097.2 Eastings: 498,341.4 Pad Elevation 94' AIVlSL Location at Top of 1443' FNL, 1268' FEL, Sec 22, TllN, R8E, UM Productive :l:nterval (Kuparuk "A3" Sand) NG$ Coordinates Neasured Depthz RKB: 9435 Northing~: 5,957,941 Eastings: 491,824 Total Vertica/Depth~ RKB: 5920 Total Vertical Depth~ $$: -5796 Location at Total Depth J 1614' FNL, 1364' FEL Sec 22, TllN, R8E, UM NGS Coordinates Neasured Depth~ RKB: 9678 North/rigs: 5,957,812 Eastings: 491,752 Tota/Vert/ca/Depthz RKB: 6112 Total Vertical Depth~ $$: -5988 and (D) other' information required by 20 AAC 25,050(b); Requirements of 20 AAC 25. 050(b) Ifa we//is to be intentionally deviated, file application fi;r a Permit to Dr/i/(Fbrm 10..40.Z) mu.s~t· (1) include a plat; drawn to a suitable sca/e, showi/Lg tile path of tile proposed wellbore, including all adjacent wellbore.¢ w/thin 200 Feet o? any portion o? the pr'opo~ed well; Please see Attachment 1' Directional Plan ORIGINAL 2A- 19A PERM/T I T. DOC Page 2 of 6 Printed: 7-May-01 m 1 1 Sm ,, etlon for Permit to Drill, Well 2A-19 Revision No.0 Saved: 7-May-01 and (2) for ali wells within 200 £eet of the proposed wel/bore (A) list the names of the operator~' of those wells, to the eztent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dr///must be accompanied by each o? the ?ollowing items, except for an item already 0/7 file with ~h~ commission and identified//7 the application: (.7) a diagram and description of'the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.055, or 20 AAC 2~.057, as applicable; Please reference BOP schematics on file for Nordic 3. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application £or a Permit to Drill must'be accompanied by each o? the fo/lowing items, except for an item a/ready on file w/th the commission and identified in the application: (q) /hfbrrnation on df#ling hazards; b~cluding (A) the maximum downho/e pres:~ure that may be encountere~ criteria u~ed to deterrnine i~ and ma~ifnum potent/a/suffb~ pressure based on a methane gr~?dienC' The expected reservoir pressure in the Kuparuk sands for the 2A-19A wellbore replacement sidetrack is 3300 psi at 5900' tvd, 0.56 psi/fL or 10.8 ppg EMW (equivalent mud weight). This pressure was obtained from 2A-19 and matches offset pressure data for the Kuparuk sands. The maximum potential surface pressure (MPSP) while drilling the sidetrack is calculated using above reservoir pressure, a gas gradient of 0.11 psi/fi, and A3 sand target mid-point 5935' tvd' MPSP =(5935 fL)~(0.56 - 0.11 psi/fi) = 2671 psi (B) data on potential gas zones;' The well bore is not expected to penetrate any gas zones. and that have a propensity for differentia/ s.fl'cking~ No significant drilling hazards anticipated. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Df#1 must be accompanied by each of the fo/lowing item~; except for an item a/ready on file w/Ih the c~mmis~on and identified in the app/i~¥~tion: (5) a d~s'cription of'the pt'ocedure for condu~$ing tormat/on fiTtegrity test~ as required under 20 ~C 2~030(t); Perform F:[T test to 12.5 ppg (max expected ECD at window for 11.1 ppg LSND mud and cuttings) in accordance with the Kuparuk LOT/F]:T procedure, that Phillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AAC 25. 005(c)(6) An application fo/' a Permit to Dr/Il must be accon?panied by each of the fbi/owing it~ff~ except for an item a/ready on file with the commission and identified b~ the app/ic~tion: (6) a complete proposed casing and cementing program as requit~d by 20 AAC 25.03~ and a desr'ription of'any s~tted fineo pre- perforated l/ner; or screen to be insta//e~' ORIGINAL 2A-19A PERMIT IT. DOC Page 3 of 6 Printed: 7-May-01 'i Ar~~ ttion for Permit to Drill, Well 2A-19 Revision No.0 Saved: 7-May-01 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/R) Grade Connection (ft) (ft) (ft) Cement Program 3-1/2 6-1/8 9.3 L-80 EUE 8rd 668' 9010'/5596' 9678'/6112' 31 bbls Mod Class G w/ 3-1/2 9.3 L-80 EUE 8rd 9010' 30 / 30 9010' / 5596' additives Mod 1 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to DHIi must be accompanied by each of the follow#Lq items, except ?or an/tern a/ready on file with the comm/.csion and/dent/fled in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, un/ess this requirement is waived by the commist~Yon under 20 AAC 25. 035(h)(2); N/A - Sidetrack out of 7" with BOP installed. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to DH// must be accompanied by each of' the following/ten?s, except fbr an item ,.~lready 0/7 file w/th the CCh'Tn?Z/sion and identified in the application: (8) a drillirLq fluid program, including a d/'c~zram and description of the d/il/i/Lq #uid system, as rec,'red by 20 A4C 25:033; Drilling will be done with a LSND system having the following properties: M/I1/nE Dr/I1/nE Dens/ty (ppg) 11.1 11,1 Funnel V/scos/ty(sec) 45-60 45-60 Y/eld Po/nt (cP) 25-30 20-25 Plastic Viscosity (lb/lO0 sf) 8-18 8-18 10 sec, ~el (lb/lO0 sf) 4-8 4-8 10 min. Gel ('lb/lO0 sf) 8-16 8-16 API Filtrate (cc) < 5 < 5 pH 9-9.5 9-9.5 So#ds (%) 10-16 10-16 Diagram of Nordic 3 Mud System on file. Drilling fluid system of Nordic 3: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers, Fluid Agitators Pit Volume Totalizer (Visual and Audio Alarm), Fluid Flow Sensor Trip Tank Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. , Abnormally Pressured Formation Information Requirements of 20 AAC 25. 005 (c)(9) An application fo/' a Pern?it to Drill must be acc/re?partied by ead~ of the ;bltow/ng items; except for an item Wready on file with the d~mmistsion and identified b~ the application: (9) fbr an exp/orato/y or stratigraph/c test wel~ a tabu/at/on se¢irLo out the depths d prc~iicted abnormal/y geo-prest¢ured sb'ata as required by 20 N/A - Application is not for an exploratoq or stratigraphic test well. ORIGINAL 2A-19A PERMIT IT. DOC Page 4 of 6 Printed: 7-May-01 AI~' '.t/on for Permit to Drill, Well 2A-19 \ · Revision No.0 Saved: 7-May-O1 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the ?o/lowing items, except for' an item a/ready on file w/th the commission and identified in the app/icatTbn: (10) for an exploratory or stratigraph/c test wet/, a seismic refract/on or reflect/on analysis as required by 20 AAC 25. 061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25. 005 (c)(11) An application for a Permit to Dr/i/must be accompanied by each of thc, following item.$ except for an/tern a/ready on file with the cornrni~sion and identified in the application: (11) fo/' a well drilled fi'om an offshore pl,~tform, mobile bottom-founded structure, jack.-up f~g, or rToating dH/ling vessel, an analysis of'seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12, Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application thc a Permit to Dr/ii must be accompanied by each of the fo#owing H:ems; except for an item a/ready or/fl/e with the conm?ission and identi/ied in the application: (12) evidence showirLq that the requirernents ot'20 AAC 25.025 (Bondir~.)have been met; Evidence of bonding for Phillips Alaska, ]:nc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An application for a Permit to DH// must be accompanied by each of' the follow/nE item.c, except fbr ,~n item ,~ready on file with the commL~sion and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. M]:RU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Verify well is dead. Circulate well to 1:[.! ppg milling fluid through tubing cut at 9245' MD. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. 6. RU E-line Unit. RTH and set Bridge Plug at 9178' MD. Test bridge plug/7" casing to 3000 psi. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, etc and RTH. Orient and set whipstock w/IVlWD. Shear off whipstock bolt and mill window in 7" casing and 20' formation. Perform F]:T test to :[2.5 ppg (max expected ECD at window for 1:[.1 ppg LSND mud and cuttings). POOH and LD milling assembly. Note: ]:f unable to obtain adequate F[-I', squeeze window with cement, redrill and test again. 8. R]:H w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH and lay down drilling assembly. 9. Run 3-:[/2" liner to TD w/:[50' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH laying down 3-1/2" DP. 11. Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). ::[2. R]:H w/3-:[/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to seawater and land tubing. Test tubing and annulus to 3000 psi. :[3. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic 3. ORIGINAL 2A- 19A PERMIT I T. DOC Page 5 of 6 Printed: 7-May-01 14. 15. I /~r ~tion for Permit to Drill, Well 2A-19 Revision No.0 Saved: 7-May-01 Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill rnustc be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (14) a general description of how the operator ptan$ to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AA£ 2~.080 for an annular disposal operation in the we//.; Waste fluids generated while drilling the sidetrack will be hauled to a KRU Class I! disposal well. All cuttings generated will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The surface by production casing annulus was left open and freeze protected at the end of original drilling operations in November 1993. To date the annulus has not been utilized for annular disposal operations, but Phillips Alaska may evaluate and request authorization for its use at a future date. Attachments Attachment I Directional Plan Attachment 2 Well Schematic. ORIGINAL 2A-19A PERMIT IT. DOC Page 6 o! 6 Printed: 7-May-01 Phillips Alaska, Inc. Pad 2A 19A slot #19A Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 19A Version #4 Our ref : prop4640 License : Date printed : 20-Apr-2001 Date created : 18-Apr-2001 Last revised : 20-Apr-2001 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.315,w150 0 46.817 Slot location is n70 18 7.963,w150 0 48.362 Slot Grid coordinates are N 5960097.236, E 498341.431 Slot local coordinates are 676.00 N 53.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ~o- % Phillips Alaska Inc. TieIIn Survey · : Structure : Pad 2A Well : 19 5680 ~ Kuporuk River Unit Location : North Slope, Alaska 5700 Tp Wlndow/lntrPh Pi~,,, 5720- blill Bry/Bgn Drp/Trn % 574O- 42 9~ 5760 - 42'~3K- ~ 5780 - DLS: 14.70 de~ per ~00' ' 58.28 5820- k ~ 5840- ' ~ - ~oc ~ 'x "~ 5860- Target - C4 E . 251,.96 AZIMUTH ' r'~ Kup B -~ ~oo- ~u,~ % x~, 37.61 DEC; E Kup A4 ~ '%.% ¢ ~o- ~u.A~ \ Iv Ba~ N~t sg~o- · Kup A2 \,~ 5980- ~~ 6000 - ~ '\.% ~040 - 6060 - 6o8o 'i~';;;;';;;';':";ig;' ......................... );~:i'"V'i~;;~'i'b; .... i d°;:,:'Z: ITdu~ V~¢ficm D~pth! ~¢e r~f*¢*n¢* RK8 124' {Nordic ~), 6120 d I~'llEEUO~S I INTEQ 6640 6660 6680 6700 6720 6740 6760 6780 6800 6820 6840 6860 6880 6900 8920 6940 6960 6980 Vertical Section (fee'[) -> Azimuth 251.96 with reference 0.00 N, 0.00 E from slot #19A ORIGINAL D=t. p~oH~: 2o-Aer-~x)l True Vart~cal Deplns ore reference RKB 124" (Nof¢3;c 3)d BAKER HUOHE5 .............................. ~.~.~ .............................................. <- West (feet) 6680 6660 6640 6620 6600 6580 6560 6540 6520 6500 6480 6460 6440 6420 Phillips Alaska, Inc. Structure : Pad 2A Well : 19A :,._.....F.!el.d :, .KUF~?r~.I~. River Unit Location : North Slope, Alaska 251.96 AZIMUTH E0C 6831' (TO TARGET) Target- C4 ***Plane of Proposal*** Kup B Kup A6 Kup A5 Kup A4 Kup A3 TRUE Base Net Pay Kup A2 Kup A1 TD - Casing Pt TD LOCATION: J 1614' FNL, 1364' FEL SEC. 22, T11 N, R8E TARGET LOCATION: ] 1443' FNL, 1268' FEL SEC. 22, T11 N, RSE 6400 6380 6360 6340 SURFACE LOCATION:] 676' FSL, 5,3' FEL SEC. 14, T11N, R8E 6320 1980 2000 2020 2040 2060 2080 2100 2120 O 2140 (- 2160 2180 I V 2200 2220 2240 2260 2280 2300 2320 2340 ORI ItV,4L PhilliDs Alaska, Inc. Pad 2A,19A KuDaruk River Unit,North Slope, Alaska ~' Measured Inclin. Azimuth True Vert R E C T A N G U L A Depth Degrees Degrees DeDth C O O R D I N A T E 9116.78 43.37 248.98 5676.86 2028.72 S 9148.93 43.32 250.72 5700.24 2036.32 S -9162.33 44.69 248.79 5709.88 2039.55 S 9162.50 44.69 248.79 5710.00 2039.59 S 9174.53 44.69 248.79 5718.56 2042.65 S PROPOSAL LISTING Page 1 Your ref : 19A Ver~ #4 Last revised 20-Apr-~ 9200.00 42.93 244.02 5736.94 2049.69 S 9232.34 41.00 237.52 5761.00 2060.22 S 9300.00 38.28 222.49 5813.22 2087.66 S 9356.36 37.61 209.04 5857.74 2115.62 S 9356.69 37.61 209.04 5858.00 2115.84 S R Dogleg Vert S Deg/100ft Sect 9388.24 37.61 209.04 5883.00 2132.67 S 9395.82 37.61 209.04 5889.00 2136.72 S 9402.13 37.61 209.04 5894.00 2140.08 S 9414.75 37.61 209.04 5904.00 2146.82 S 9434.95 37.61 209.04 5920.00 2157.60 S 6369.01 W 0.00 6684.17 Tie-In Survey 6389.73 W 3.71 6706.22 Tp Window/Intrp Pt 6398.46 W 14.30 6715.52 KOP/Base Whipstock 6398.57 W 0.00 6715.64 Base HRZ 6406.46 W 0.00 6724.09 9477.87 37.61 209.04 5954.00 2180.50 S 9500.00 37.61 209.04 5971.53 2192.30 S 9503.12 37.61 209.04 5974.00 2193.97 S 9556.14 37.61 209.04 6016.00 2222.26 S 9677.87 37.61 209.04 6112.44 2287.21 S 6422.61 W 14.70 6741.63 6441.47 W 14.70 6762.82 K-1 Marker 6474.43 W 14.70 6802.66 6494.60 W 14.70 6830.50 EOC 6494.63 W 0.00 6830.59 2A-19A C4 Rvsd 5-Mar-01 6503.98 W 0.00 6844.69 Kup B 6506.22 W 0.00 6848.08 Kup A6 6508.09 W 0.00 6850.90 Kup A5 6511.83 W 0.00 6856.54 Kup A4 6517.81 W 0.00 6865.57 Kup A3 6530.53 W 0.00 6884.75 Base Net Pay 6537.08 W 0.00 6894.64 6538.00 W 0.00 6896.03 Kup A2 6553.71 W 0.00 6919.73 Kup A1 6589.77 W 0.00 6974.14 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot #19A and TVD from RKB 124' (Nordic 3) (124.00 Ft above mean sea level). Bottom hole distance is 6975.41 on azimuth 250.86 degrees from wellhead. Total Dogleg for wellpath is 29.84 degrees. Vertical section is from wellhead on azimuth 251.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL PhilliDs Alaska, Inc. Pad 2A,19A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 19A Version #4 Last revised : 20-Apr-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 9116 9148 9162 9162 9232 9356 9356 9388 24 9395 82 9402 13 9414 75 9434 95 9477 87 9503 12 9556 14 9677.87 78 93 33 50 34 36 69 5676 5700 5709 5710 5761 5857 5858 5883 5889 5894 5904 5920 5954 5974 6016 6112 86 2028 24 2036 88 2039 00 2039 00 2060 74 2115 00 2115 00 2132 .00 2136 .00 2140 .00 2146 .00 2157 .00 2180 .00 2193 .00 2222 .44 2287 72 S 6369.01 W Tie-In Survey 32 S 6389.73 W Tp Window/Intrp Pt 55 S 6398.46 W KOP/Base Whipstock 59 S 6398.57 W Base HRZ 22 S 6441.47 W K-1 Marker 62 S 6494.60 W EOC 84 S 6494.63 W 2A-19A C4 Rvsd 5-Mar-01 67 S 6503.98 W Kup B 72 S 6506.22 W Kup A6 08 S 6508.09 W Kup A5 82 S 6511.83 W Kup A4 60 S 6517.81 W Kup A3 50 S 6530.53 W Base Net Pay 97 S 6538.00 W Kup A2 26 S 6553.71 W KuD A1 21 S 6589.77 W TD - Casing Pt Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2A-19A C4 Rvsd 5-Mar 491847.000,5957983.000,0.0000 5858.00 2115.84S 6494.63W 8-Mar-2001 ORI IIV, L Phillips Alaska, Inc. Pad 2A 19A slot #19A Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 19A Version #4 Our ref : prop4640 License : Date printed : 20-Apr-2001 Date created : 18-Apr-2001 Last revised : 20-Apr-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.315,w150 0 46.817 Slot location is n70 18 7.963,w150 0 48.362 Slot Grid coordinates are N 5960097.236, E 498341.431 Slot local coordinates are 676.00 N 53.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-14797'> PMSS <0-6791'>, PGMS <0-8497'> PGMS <0-7863'>, PGMS <0-8130'>, PGMS <0-8150'>, PGMS <0-7125'>, PGMS <0-6675'>, PGMS <0-7260'>, PGMS <0-8535'> PMSS <0-7763'> PGMS <0-8205'> PGMS <0-9185'> PGMS <0-8156'> PGMS <0-7131'> PGMS <0-6673'> PGMS <0-7630'>, ,22,Pad 2A 18,Pad 2A ,8,Pad 2A 14,Pad 2A 15,Pad 2A 13,Pad 2A 12,Pad 2A ll,Pad 2A 10,Pad 2A 9,Pad 2A 7,Pad 2A 6,Pad 2A 5,Pad 2A 4,Pad 2A 3,Pad 2A 2,Pad 2A lA,Pad 2A PMSS <3841-7425'>,,1,Pad 2A PGMS <0-9888'>, 16,Pad 2A PMSS <0-11700'> ,23,Pad 2A PGMS <0-11545'> ,20,Pad 2A PGMS <0-11839'> ,21,Pad 2A PGMS <0-9934'>, 17,Pad 2A PGMS <0-9674'>, 24,Pad 2A PMSS <0-14391'> ,25,Pad 2A PGMS <0-9785'>(135' RKB),,19,Pad 2A PGMS <0-9784'>DpthShft,,19,Pad 2A Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 30-May-1995 4106 1-Jan-1999 6538 3-Aug-1992 5682 3-Aug-1992 8096 3-Aug-1992 8441 3-Aug-1992 8514 3-Aug-1992 7026 3-Aug-1992 5587 3-Aug-1992 5069 3-Aug-1992 5610 3-Aug-1992 3502 3-Aug-1992 2341 3-Aug-1992 3663 3-Aug-1992 7554 3-Aug-1992 7258 3-Aug-1992 7406 3-Aug-1992 7862 3-Aug-1992 7862 3-Aug-1992 8216 10-0ct-1993 4697 26-Dec-1993 1154 26-Dec-1993 3081 26-Dec-1993 5014 26-Dec-1993 2658 14-Apr-1996 2991 9-Apr-2001 6 9-Apr-2001 0 0 9116 3 9116 5 9116 5 9116 7 9116 3 9116 8 9116 8 9116 2 9116 6 9116 5 9116 7 9116 0 9116 8 9116 8 9116 8 9116 5 9116 5 9116 9 9116 6 9116 2 9116 5 9116 5 9116 5 9116 9 9116 3 9183 0 9116 9116 8 9116 8 9116 8 9116 8 9116 8 9116 8 9116 8 9116 8 9116 8 9356.7 9116.8 9356.7 9677.9 9116.8 9116.8 9116.8 9116.8 9116.8 9116.8 9116.8 9116 8 9116 8 9116 8 9116 8 9116 8 9183 0 9116 8 ORIGINAL KRU 2A-19A Pro(odcer Proposed Completion H. 3-1/2" 5M WKM Gen IV PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down. G. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surface. F. 3-1/2" Camco 'D' landing nipple with 2.812" ID No-Go profile set at +/-500' MD. 9-5/8" 47 & 364¢ L-80 @ 3957' E. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/ 3-1/2" x 1" Camco 'KBMM' mandrels w/DV's, spaced out as follows: GLM# M._.~D TVD Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 2 TBD TBD 3 TBD TBD 4 TBD TBD 5 TBD TBD 6 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. D. 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6" L-80 handling pups installed on top and bottom of mandrel. C. 1 joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing B. 3-1/2" Camco 'D' landing nipple with 2.75" ID and No-Go profile 3-1/2" liner top at +/-9010' MD Top of Whipstock & KO P at +/-9160' MD Window in 7" A. Baker 3-1/2" 'GBH-22' Tubing Seal Assembly w/17' of seals and special Iocator to locate in liner tie back sleeve. Locator 5.125" OD, seals 4.0" OD. 6' L-80 Handling Pup Joint installed. Liner Top Baker 5" x 7" 'C-2 ZXP' Liner Top Isolation Packer. Baker 5" x 7" 'HMC' Hydraulic Liner Hanger. Baker '80-40' SBE (12' Length w/4" ID seal bore). 3-1/2" EUE 8rd Mod pin down. Solid Liner 3-1/2" 9.3# L-80 EUE 8rd Mod from Liner Hanger to Landing Collar. Bridge Plug at +/-9178' MD Abandoned Perfs C4-Sand A3-Sand .. Fill Future Perfs 3-1/2" EUE 8rd Landing Collar. 1 joint 3-1/2" L-80 EUE 8rd Mod tubing. 3-1/2" EUE 8rd Float Collar. 2 joints 3-1/2" L-80 EUE 8rd Mod tubing. 3-1/2" EUE 8rd Float Shoe. 7" 26# L-80 @ 9765' TD @ +/- 9690' ORIGINAL BDN 5/7/01 PHILLII:/,., Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 May 7, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Dear Sirs: KRU 2A-19A 676' FSL, 53' FEL, Sec. 14, T11N, R8E 1443' FNL, 1268' FEL, Sec. 22, T11 N, R8E 1614' FNL, 1364' FEL, Sec. 22, T11 N, R8E Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2A-19A. The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids generated from drilling the sidetrack will be pumped down an approved KRU Class II disposal well and all drill solids will be hauled to an approved Prudhoe Bay facility for grind and inject disposal. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Dave Shafer, Geologist (20 AAC 25.071) 263-4284 If you have any questions or require further information, please contact Brian Noel at (907) 265-6979 or James Trantham at (907) 265-6434. RECEIVED 0'7 Alaska 0il & Gas C~s. Commiss/o~ Anchorage Sincerely, James Trantham Drilling Engineering Supervisor ORIGINAL Express® Cash Advance Draft 130 American ~/- ...~ 2o:'~_~o,,o~, DATE ~,o ,,~ ~,,t./. ~../,- <~.l~..l, ,~,_i .i/,.',, ~ s~ ,,'"~ ~.:,~.~ ' ", / /' ~ .~'" ...... , ,.. ..~ .... . _' .....~ DOLLARS Issued by In~e~d P~ymen~ Sys~m, inc. En~lewood, Colo~o NO, T VALID FOK AHOUNT OVER $ I 0~ P.y~l..t No.est Bmnk of G~nd ]un.ion - Downtown, N~ <~ ~L~p- WELL PERMIT CHECKLIST CoMpANy /~,'~///'J ~ c WELL NAME~.,,~-//~ PROGRAM: exp day ~ reddl se~ wellbore sag ann. disposal para req FIELD & POOL ~}~'~ _ INIT C~SS ~~ /~ ~v~/ GEOL AR~ ~ADMINIST~TION 1. Pe~it fee effaced ....................... ~ N 2. Lease numar appropriate ................... Y N 3. Unique well name and number .................. Y N 4. Well I~ted in a defined pool .................. Y N 5. Well I~t~ proper distan~ Eom drilling unit bounda~ .... Y N 6. Well I~ted proper distance ~om other wells .......... Y' N 7. Suffident a~eage available, in drilling unit ............ Y N. 8. If deviate, is well.re plat included ............. ,.. Y N 9. Operator onN afl. ed pa~ ................... Y N .. 10. Operator has appropriate ~nd in force ............. ~[~ N 11. Pe~it ~n be issued without ~nse~ation order ........ ~ N ~~~D~~ 12. Ps.it ~n.be issued without adminis t~tive approval ......~ N ~ 13. Can ~ be approved before l~day wait ........... N ENGINEERING 14. Condu~orstHng provided ................... Y N~ 15. Suda~ ~sing proteus all kno~ USDWs ........... Y 16. CMT vol adequate to dr~late on ~nductor & su~ ~g ..... Y 17. CMT vol adequate to.ti~in long s~ng to sud ~g ........ Y N~ 18. CMT will ~ver all known produ~ive horizons. ' ~ N 19. Casing designs adequate for C, T, B & pe~afrost .......~ N 20. Adequate tankage or resale pit ................. N 21. If a r~ddll, has a 1~03 for abandonment been approved... N ~-~~ 22. Adequate wellbore separation proposed. . N ~sN~ ~%~ ~ % ~%~%~G~~~ .. 23. If dive~r required, does it meet regulations ~ 24. Drilling.fluid program schematic & equip list ~d;~u;t; ~ ~ ~ ~ ~ ~ N 25. BOPEs, d° they meet regulation ......... ~... '... ~ N ~ ~ . ~ . '- ~~(~'~ ~ 26. BOPE press rating appropriate; test to ~ psig. ~N ~~ 6%~ ~~' ~ ~~ ~ ' 27. Choke manifold ~mplieS w/APl RP-53 (May 84) ......... ~ N 28. Wo~ ~11 o~ur without operation shutdown ........... ~ ~ ~. ~ ~ · ' 29. Is presen~ of HmS gas probable ................. Y GEOLOGY .. 30. pe~it ~n be issued wlo hydrogen sulfide measures ...... Y N_~ . ' ' 31. Data presented on potential ove~ressure zones . ...... Y~ 32. seismic analysis of shallow gas zones ........ ..... ~ N ~D T 33. Seabed ~ndition suwey (if off-shore) ............. ~ Y N / ~ ' ~ ~~/~. Conta~ name/phone for weekly progress repo~s [explorato~ly] Y N With proper cementing records, this plan ~ ANNU~R DISPOSAL35. (A) will ~ntain waste in a suitable receiving zone~ ....... Y N APPR DATE (B) will not ~ntaminate freshwater; or ~use d~lling waste... Y N (C) will not impair mechanical integH~ of the well used for diSposal; Y' N (D), will not damage producing fo~ation or impair recove~ from a Y N pool; and (~), will not circumvent 20 ~C 25.252 or 20 ~C 25.412. Y N ......... , , , GEOLOGy: ENGINEERING: ' UlClAnnular COMMISSION: Commen~llnstructions: . , . ..,,,, .... , 0 Z 0 Z c:Vnsoffice\wordian~diana\checklist (rev. 111011100) Well History File APPENDIX Information of detailed nature that is not partiCularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding informatiOn, information, of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Dec 10 13:17:13 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. RECEIVED JA .I 0 5 2002 Alaska Oil & Gas Cons. Corniness o~-, An~orage Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2A-19A 501032019701 PHILLIPS Alaska Inc. Sperry-Sun Drilling Services 10-DEC-01 MWD RUN 2 AK-MM-10165 B. HENNINGSE R. BOWIE lin 8E 676 53 123.95 93.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9138.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION STATUS OF MWD DATA IS PENDING PER E-MAIL FROM R.KALISH (SSDS) TO D.SCHWARTZ (PHILLIPS ALASKA) DATED 09/12/01. 6. MWD RUN 2 REPRESENTS WELL 2A-19A WITH API~: 50-103-20197-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9681'MD/6130'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9100.5 9643.0 RPX 9131.5 9650.0 RPS 9131.5 9650.0 RPM 9131.5 9650.0 RPD 9131.5 9650.0 FET 9131.5 9650.0 ROP 9138.0 9680.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 9100 . 5 9680 . 5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR Min 9100.5 0.09 40 08 1 34 1 34 1 35 0 07 0 51 Max Mean Nsam 9680.5 9390.5 1161 162.78 40.3422 1086 352.01 118.736 1086 1421.58 7.9568 1038 1525.32 8.22766 1038 2000 26.9112 1038 1421.69 11.0091 1038 24.38 2.53464 1038 First Reading 9100.5 9138 9100.5 9131.5 9131.5 9131.5 9131.5 9131.5 Last Reading 9680.5 9680.5 9643 9650 9650 9650 9650 9650 First Reading For Entire File .......... 9100.5 Last Reading For Entire File ........... 9680.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPM RPD FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9100 5 9131 5 9131 5 9131 5 9131 5 9131 5 9138 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 9643 0 9650 0 9650 0 9650 0 9650 0 9650 0 9680 5 28-MAY-01 Insite 4.30 Memory 9681.0 9138.0 9681.0 33.4 43.3 TOOL NUMBER PB01967GR4 PB01967GR4 6.125 9138.0 LSND 11.10 68.0 9.3 2100 3.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2.000 1.128 2.050 2.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 70.0 129.4 70.0 70.0 Name Service Unit DEPT FT R0P MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 9100.5 0.09 40 08 1 34 1 34 1 35 0 07 0 51 Max Mean Nsam 9680.5 9390.5 1161 162.78 40.3422 1086 352.01 118.736 1086 1421.58 7.9568 1038 1525.32 8.22766 1038 2000 26.9112 1038 1421.69 11.0091 1038 24.38 2.53464 1038 First Reading 9100.5 9138 9100.5 9131.5 9131.5 9131.5 9131.5 9131.5 Last Reading 9680.5 9680.5 9643 9650 9650 9650 9650 9650 First Reading For Entire File .......... 9100.5 Last Reading For Entire File ........... 9680.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File