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Home My WebLink About182-177MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-06 KUPARUK RIV UNIT WSW-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 WSW-06 50-029-20851-00-00 182-177-0 S SPT 2660 1821770 1500 692 690 686 683 128 139 139 139 OTHER P Adam Earl 6/3/2025 MIT-IA class 2 slurry inj. Well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-06 Inspection Date: Tubing OA Packer Depth 5 1810 1680 1640IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250604090511 BBL Pumped:1.7 BBL Returned:1.1 Wednesday, July 23, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-06 KUPARUK RIV UNIT WSW-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 WSW-06 50-029-20851-00-00 182-177-0 S SPT 2660 1821770 1500 730 730 729 729 0 20 20 20 INITAL P Bob Noble 8/17/2024 Initial MIT-IA for class 2 well as per sundry 324-451 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-06 Inspection Date: Tubing OA Packer Depth 0 1820 1760 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240818155456 BBL Pumped:0.8 BBL Returned:0.7 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 9 6OXUU\LQMHFWRU sundry 324-451 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:31:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-06 KUPARUK RIV UNIT WSW-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 WSW-06 50-029-20851-00-00 182-177-0 N SPT 2660 1821770 1500 100 100 100 100 0 0 0 0 OTHER P Adam Earl 8/10/2024 MIT-IA tested as per Sundry 324-451 "post RWO/repair; pre injection" 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-06 Inspection Date: Tubing OA Packer Depth 400 1860 1760 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812132341 BBL Pumped:0.5 BBL Returned:0.4 Tuesday, October 15, 2024 Page 1 of 1 9 9 99 9 9 999 9 9 99 9 9 9 Sundry 324-451 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 14:51:47 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3835'feet None feet true vertical 3430' feet None feet Effective Depth measured 3835'feet 2895', 2966', 3557'feet true vertical 3430'feet 2599', 2600', 3185'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 2952' 3560' 2647' 3188' Packers and SSSV (type, measured and true vertical depth)2895' 2966' 3557' 2599' 2600' 3185' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Cretaceous Undef WDSP 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Authorized Title: 2449' 2228' Burst Collapse 3788' Casing 3426'3820' 2413' 80'Conductor Surface Production 16" 10-3/4" 41' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-177 50-029-20851-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025648 Kuparuk River Field/ Cretaceous Undef WDSP KRU WSW-06 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 80' N/A 324-451 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: BluePack Packer: SC1-L1 Gravel Pack Packer: Sump Packer SSSV: None Staff RWO/CTD Engineer 3160-3720' 2829-3334' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Contact Name:Elliott Tuttle Contact Email:elliott.tuttle@conocophillips.com Contact Phone: (907) 263-4742 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2024.09.06 14:51:04-08'00' Foxit PDF Editor Version: 13.0.0 Elliott Tuttle By Grace Christianson at 3:22 pm, Sep 06, 2024 Page 1/4 WSW-06 Report Printed: 9/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/3/2024 00:00 8/3/2024 01:00 1.00 MIRU, MOVE RURD P Rig down from 1C-13 and clean around well, pad operator inspect and sign off on environmental, rig prep to move to 1B pad 0.0 0.0 8/3/2024 01:00 8/3/2024 05:00 4.00 MIRU, MOVE MOB P Mob rig from 1C pad to 1B pad and stage on end of pad for well work. On pad @ 05:00. 0.0 0.0 8/3/2024 05:00 8/3/2024 18:00 13.00 MIRU, MOVE WAIT P Wait on Pre-Rig Scope and Pad prep to be completed before spotting over well. Also waiting on Tree and Wellhead equipment to be hung and staged behind well. E-line cut complete and E- line RD and off pad @ 12:00 noon. Begin pad prep scope (deenergize electrical, pull instrumentation, pull wellhead, remove riser, move semi trailer, install 1502 integrals on Tubing Spool). 0.0 0.0 8/3/2024 18:00 8/4/2024 00:00 6.00 MIRU, MOVE WAIT P Well prep finish prepping well for well work // Roads and pads level pad for rig // TH misc prep for rig 0.0 0.0 8/4/2024 00:00 8/4/2024 01:30 1.50 MIRU, MOVE WAIT P Wait for pre-rig well prep to be completed 0.0 0.0 8/4/2024 01:30 8/4/2024 04:00 2.50 MIRU, MOVE RURD P Set mats and herculite around well // Spot well head equipment in cellar and hang tree // Prep to pull over well 0.0 0.0 8/4/2024 04:00 8/4/2024 10:00 6.00 MIRU, MOVE RURD P Spot rig over well @ 05:00. Install dunnage in cellar. Safe out rig. Perform rig acceptance checklist. Spot returns tanks and RU hardline. Measure RKB's. Accept rig @ 10:00. Take on 9.4# KWF into pits. RU circulating equipment to Tubing and IA in cellar and out to manifold. Gather initial pressures. T / IA / OA = 15 psi / 20 psi / 20 psi. 0.0 0.0 8/4/2024 10:00 8/4/2024 15:30 5.50 MIRU, WELCTL KLWL P PT hardline and circ manifold out to tanks to 2,500 psi. Bleed free gas from Tubing and IA. PJSM for well kill. Line up to pump down Tubing taking returns from IA out to tanks. Pump 30 bbls Deep Clean pill. Chase with 140 bbls 9.4# KWF @ 4 BPM / 219 psi. ICP = 219 psi. FCP = 314 psi (140 on the choke side) SD Pumps. 0.0 0.0 8/4/2024 15:30 8/4/2024 16:00 0.50 MIRU, WELCTL OWFF P OWFF for 30-min. Function LDS's. Begin to load 115 Joint Tubing in pipe shed. 0.0 0.0 8/4/2024 16:00 8/4/2024 17:00 1.00 MIRU, WHDBOP MPSP P Set BPV. 0.0 0.0 8/4/2024 17:00 8/4/2024 18:00 1.00 MIRU, WHDBOP PRTS P Test BPV to 1,000 psi from below for 10- min. 0.0 0.0 8/4/2024 18:00 8/4/2024 18:30 0.50 MIRU, WHDBOP RURD P R/D circ hoses on rig floor and in cellar. 0.0 0.0 8/4/2024 18:30 8/4/2024 20:30 2.00 MIRU, WHDBOP NUND P Nipple down tree // Install blanking plug 0.0 0.0 8/4/2024 20:30 8/4/2024 22:30 2.00 MIRU, WHDBOP NUND P Nipple up XO spool // Nipple up BOPs // Torque all bolts on stack and adapter spool // Install riser 0.0 0.0 8/4/2024 22:30 8/5/2024 00:00 1.50 MIRU, WHDBOP OTHR P Grease stack and choke manifold // Flood lines // purge air 0.0 0.0 8/5/2024 00:00 8/5/2024 01:00 1.00 MIRU, WHDBOP RURD P Rig up BOP test equipment. Flood lines. Purge air. Shell Test. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/8/2024 Page 2/4 WSW-06 Report Printed: 9/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/5/2024 01:00 8/5/2024 08:00 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/25000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2" Test Joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3150 PSI, after closure=1750 PSI, 200 PSI attained =20 sec, full recovery attained =120 sec. UVBR's= 5 sec, LVBRs=4 sec. Annular= 19 sec. Simulated blinds= 4 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average =2200 PSI. Test gas detectors, PVT and flow show. F/P on CMV #5. Witness waived by AOGCC repGuy Cook. 0.0 0.0 8/5/2024 08:00 8/5/2024 08:30 0.50 MIRU, WHDBOP RURD P RD testing equipment. L/D 3 1/2" test joint. Drain Stack. Ensure lines to tanks are all blown down. 0.0 0.0 8/5/2024 08:30 8/5/2024 09:00 0.50 MIRU, WHDBOP MPSP P Pull blanking plug and IS-A BPV. 0.0 0.0 8/5/2024 09:00 8/5/2024 09:15 0.25 COMPZN, RPCOMP BHAH P MU 3 1/2" Spear. 0.0 6.0 8/5/2024 09:15 8/5/2024 09:30 0.25 COMPZN, RPCOMP FISH P TIH w/ Spear to Wellhead. Engage 3 1/2" Tubing. 6.0 6.0 8/5/2024 09:30 8/5/2024 09:45 0.25 COMPZN, RPCOMP PULL P Set 10K down. BOLDS. Pull Tubing Hanger to rig floor. Unseat @ 65K. Drag to floor @ 58K. 6.0 6.0 8/5/2024 09:45 8/5/2024 10:00 0.25 COMPZN, RPCOMP BHAH P L/D 3 1/2" Spear and Tubing Hanger. 6.0 2,923.0 8/5/2024 10:00 8/5/2024 10:30 0.50 COMPZN, RPCOMP RURD P MU XO #505 (3 1/2" IF Box x 3 1/2" IBT Pin) to Floor Valve. MU XO #704 (3 1/2" EUE Box x 3 1/2" IBT Pin). RU head pin and circ. hose. 2,923.0 2,923.0 8/5/2024 10:30 8/5/2024 11:15 0.75 COMPZN, RPCOMP CIRC P Circ STS (105 bbls 9.4#) @ 4 BPM / 79 psi. 2,923.0 2,923.0 8/5/2024 11:15 8/5/2024 12:45 1.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. Monitor KWF to see if static or on losses. Fluid column static. Prep rig floor to pull 3 1/2" tubing. Finish processing 3 1/2" DP. 2,923.0 2,923.0 8/5/2024 12:45 8/5/2024 14:00 1.25 COMPZN, RPCOMP PULD P Pull 3 1/2" Tubing from pre-rig cut @ 2,950' to 2,613'. PUW = 50K. SOW = 50K. 18K Tubing WT hanging. FIll Tubing and Backside. Monitor KWF fluid for 15 minutes. Static. 2,923.0 2,613.0 8/5/2024 14:00 8/5/2024 14:15 0.25 COMPZN, RPCOMP BHAH P MU Storm Packer to 3 1/2" IBT Tubing using XO #505 0.0 19.0 8/5/2024 14:15 8/5/2024 14:30 0.25 COMPZN, RPCOMP TRIP P PUW = 53K. SOW = 50K. TIH and set Storm Packer @ 63' COE (56' Top). Hanging 18K off Storm Packer. Release from Storm Packer (23 turns to the left). 19.0 63.0 8/5/2024 14:30 8/5/2024 15:00 0.50 COMPZN, RPCOMP TRIP P TOOH w/ setting tool. L/D same. 63.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/8/2024 Page 3/4 WSW-06 Report Printed: 9/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/5/2024 15:00 8/5/2024 19:00 4.00 COMPZN, RPCOMP PRTS P Close Blinds. RU sensator to test spool. Line up to PT through kill. PT Storm Packer to 1,500 psi. Charted. Failed. Closed manual kill. Chart improved. Bleed off and reattempt. Pressure back up to 1,500 psi for 30-min. Charted. Initial = 1680 psi. 15-min = 1440 psi. 30-min = 1380 psi. Failed. Bleed off. Purge air. Service choke and kill valves. Re-attempt PT of Storm Packer to 1,500 psi. Triple blocked. HCR Choke and Kill + Mud Manifold Kill Line + CMV #13. Passed. 0.0 0.0 8/5/2024 19:00 8/5/2024 19:30 0.50 COMPZN, RPCOMP RURD P RD sensator from test spool. Bleed off pressure. Open Blinds. Drain Stack. 0.0 0.0 8/5/2024 19:30 8/5/2024 20:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. Bleed 10psi OA pressure to bleed trailer. Gas. 0.0 0.0 8/5/2024 20:00 8/5/2024 22:30 2.50 COMPZN, RPCOMP NUND P ND BOP, 11" 5K x 7 1/16" 5K DSA, 7 1/16" 5K x 7 1/16" 3K spool. ND old Tubing Head. FMC install plastic pack on 7" mandrel hanger. NU new tubing head and reducer bushing. PT pack-off to 3,250 psi. 0.0 0.0 8/5/2024 22:30 8/6/2024 00:00 1.50 COMPZN, RPCOMP NUND P Nipple up BOPs 0.0 0.0 8/6/2024 00:00 8/6/2024 01:30 1.50 COMPZN, RPCOMP NUND P Complete N/U of BOPs, install riser and hook up trip tank lines 0.0 0.0 8/6/2024 01:30 8/6/2024 05:30 4.00 COMPZN, RPCOMP PRTS P Install test plug // Fill stack // Pressure test stack break 250/2500 0.0 0.0 8/6/2024 05:30 8/6/2024 06:00 0.50 COMPZN, RPCOMP RURD P Rig down test equipment 0.0 0.0 8/6/2024 06:00 8/6/2024 07:00 1.00 COMPZN, RPCOMP MPSP P Pick up storm packer pulling tool, pull storm packer and lay down 0.0 2,900.0 8/6/2024 07:00 8/6/2024 07:30 0.50 COMPZN, RPCOMP SVRG P Service hydraulic system 2,900.0 2,900.0 8/6/2024 07:30 8/6/2024 11:00 3.50 COMPZN, RPCOMP PULL P Pull 3.5" completion from welltec cut 2,900.0 0.0 8/6/2024 11:00 8/6/2024 11:30 0.50 COMPZN, RPCOMP CLEN P Clean rig floor 0.0 0.0 8/6/2024 11:30 8/6/2024 12:00 0.50 COMPZN, RPCOMP OTHR P Install wear ring in tubing head 0.0 0.0 8/6/2024 12:00 8/6/2024 13:30 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 3 Dress off / Drift BHA 6-1/8" dress off shoe and 6-1/8" string mill 0.0 0.0 8/6/2024 13:30 8/6/2024 18:30 5.00 COMPZN, RPCOMP PULD P TIH picking up singles drill pipe 0.0 2,936.0 8/6/2024 18:30 8/6/2024 19:30 1.00 COMPZN, RPCOMP WASH P Make up TD to drill pipe // Pump 5 bbls/ min @ 496 psi // Wash over stump @ 2943' 200 psi increase as wash over stump // NG @ 2954' 2,936.0 2,954.0 8/6/2024 19:30 8/6/2024 20:15 0.75 COMPZN, RPCOMP CIRC P Pump sweep and circulatd SxS ensure hole clean for running completion 2,930.0 2,930.0 8/6/2024 20:15 8/6/2024 21:45 1.50 COMPZN, RPCOMP TRIP P TOOH for completion run 2,930.0 48.0 8/6/2024 21:45 8/6/2024 22:15 0.50 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 48.0 0.0 8/6/2024 22:15 8/6/2024 22:45 0.50 COMPZN, RPCOMP OTHR P Pull wear ring 0.0 0.0 8/6/2024 22:45 8/6/2024 23:30 0.75 COMPZN, RPCOMP RURD P Rig up to run 3.5" completion // Put tools in order and inspect 0.0 0.0 8/6/2024 23:30 8/7/2024 00:00 0.50 COMPZN, RPCOMP PUTB P Pick up and run 3.5" completion jewelery 0.0 150.0 Rig: NORDIC 3 RIG RELEASE DATE 8/8/2024 Page 4/4 WSW-06 Report Printed: 9/5/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/7/2024 00:00 8/7/2024 04:30 4.50 COMPZN, RPCOMP PUTB P Pick up and run 3.5" EUE completion F/97' T/2912. SOW52K, PUW 57K. 150.0 2,912.0 8/7/2024 04:30 8/7/2024 05:30 1.00 COMPZN, RPCOMP THGR P MU top drive, wash down to 2953', set down 15K and saw a pressure increase 128 psi. Calculate space out. 2,912.0 2,912.0 8/7/2024 05:30 8/7/2024 07:00 1.50 COMPZN, RPCOMP DISP P Reverse circulate 9.7 ppg CI brine. Pump 78 bbls at CI 2.5 BPM at 128 psi. 2,912.0 2,912.0 8/7/2024 07:00 8/7/2024 07:30 0.50 COMPZN, RPCOMP THGR P RIH to Land tubing hanger. PUW 59K, SOW 53K and set down 10K. RILDS. 2,953.0 2,953.0 8/7/2024 07:30 8/7/2024 11:00 3.50 COMPZN, RPCOMP PACK P RU testing equipment, stage packer up in stages 500 psi to 3600 psi. Hold 3500 psi for 30 minutes charted to test packer and tubing. Drop tubing pressure to 1200 psi and PT IA to 1800 psi for 30 minutes charted. Dump pressure on tubing to zero to shear SOV. Pump through SOV to confirm sheared. 0.0 0.0 8/7/2024 11:00 8/7/2024 11:30 0.50 COMPZN, RPCOMP RURD P RD circ hose and landing joint. Pull landing joint. 0.0 0.0 8/7/2024 11:30 8/7/2024 12:30 1.00 COMPZN, RPCOMP MPSP P Set BPV and Test 1000 psi/minutes. Good test. 0.0 0.0 8/7/2024 12:30 8/7/2024 17:30 5.00 COMPZN, RPCOMP NUND P ND BOPE/ NU Tree. Pressure test void 5K good test 0.0 0.0 8/7/2024 17:30 8/7/2024 19:30 2.00 COMPZN, RPCOMP PRTS P Rig up little red // PT Tree 5K with LEPD and little red services 0.0 0.0 8/7/2024 19:30 8/7/2024 20:00 0.50 COMPZN, RPCOMP MPSP P Pull BPV for freeze protect 0.0 0.0 8/7/2024 20:00 8/7/2024 22:00 2.00 DEMOB, MOVE FRZP P Freeze protect Tubing and IA to 2000' with 75 bbls diesel. // Pump 2 bpm @ 1200 psi // U-tube well 0.0 0.0 8/7/2024 22:00 8/8/2024 00:00 2.00 DEMOB, MOVE RURD P Rig down checklists and pull off well 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/8/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,523.0 WSW-06 11/18/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swapped SOV fo DMY, Pulled B&R, RHC, catcher & RBP WSW-06 8/9/2024 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 80.0 80.0 65.00 H-40 WELDED SUR. CASING 10 3/4 9.95 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread PROD. CASING 7 6.28 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.1 Set Depth 2,951.5 String Max No 3 1/2 Set Depth 2,647.1 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.0 30.9 0.03 Hanger 10.844 FMC Gen 5 Tubing Hanger, TC-1A- EMS (3 1/2" EUE w/ "H" BPV Profile) FMC Gen 5 2.950 2,835.5 2,547.6 31.75 Mandrel GAS LIFT 5.855 3.5" x 1.5" MMG, GLM, 1,000 psi SOV w/ RKP Latch, SN#: 21913-08 SLB MMG 2.920 2,895.3 2,598.7 30.85 Packer 5.993 7" x 3 1/2" Bluepack Packer, VAMTOP, SN#: C24P-1207 SLB Bluepac k 2.894 2,921.7 2,621.4 30.58 Nipple - X 4.502 3 1/2" x 2.813 X Nipple, w/ RHC-M Installed, SN#: 0005011991-1 HES X Nipple 2.813 2,942.9 2,639.6 30.38 Overshot 5.980 INNO 4 1/2" PB Overshot (2' space out, 6.48' swallow to No-Go) Baker Poor Boy Oversho t 4.620 Top (ftKB) 2,950.0 Set Depth 3,559.6 String Max No 4.14 Set Depth 3,187.7 Tubing Description Tubing Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,965.6 2,659.2 30.16 LOCATOR 5.000 LOCATOR Baker 4.000 2,966.1 2,659.7 30.16 PACKER 5.968 70B2-40 SC1-L1 GRAVEL PACK PACKER Baker Model SC-1L 4.000 2,970.3 2,663.3 30.12 EXTENSION 5.560 80-40 PERFORATED GRAVEL PACK PACKER EXTENSION Baker Model 'S' 4.400 2,976.0 2,668.3 30.06 SBR 5.560 SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION 5.560 LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETY JT 4.150 SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN 4.140 BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 O-RING 3.500 O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) Baker 2.400 3,546.3 3,175.6 25.10 SCREEN 4.140 BAKERWELD .006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH 5.000 80-40 SNAP LATCH Baker MODEL E-22 2.985 3,557.0 3,185.3 25.02 SUMP PACKER 5.875 SUMP PACKER Baker Model F- 1 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,950.0 2,645.8 30.31 CUT CUT TUBING WITH WELLTEC MECHANICAL CUTTER 8/3/2024 2.990 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,835.5 2,547.6 31.75 1 SOV- Open RKP SLB NOVA 10 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,356.7 2,153.2 35.06 Stage Collar 7.000 Baker Model J 6.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing WSW-06, 9/5/2024 10:49:17 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SCREEN; 3,546.3 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 XO THREAD; 2,982.1 PACKER; 2,966.1 CUT; 2,950.0 Nipple - X; 2,921.7 Packer; 2,895.3 Mandrel GAS LIFT; 2,835.5 SUR. CASING; 35.1-2,448.5 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Hanger; 30.9 KUP DISP KB-Grd (ft) 41.01 RR Date 11/11/198 2 Other Elev WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBOREWSW-06 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 120.0 41.0 120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 9/5/2024 10:49:21 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SCREEN; 3,546.3 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 XO THREAD; 2,982.1 PACKER; 2,966.1 CUT; 2,950.0 Nipple - X; 2,921.7 Packer; 2,895.3 Mandrel GAS LIFT; 2,835.5 SUR. CASING; 35.1-2,448.5 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Hanger; 30.9 KUP DISP WSW-06 ... WELLNAME WELLBOREWSW-06 ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4975 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4975 WSW-06 500292085100 Tubing Cut Record 3-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 182-177 T39391 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:36:16 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Ugnu Oil Pool UgnuOil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3835'3430' 3835' 3430'1085 3028' None Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-6049 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: K-55 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 2966'MD/2600'TVD 3557' MD/ 3185' TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25648 182-177 P.O. Box 100360, Anchorage, AK 99510 50-029-20851-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 3560' MD 80' 228' 3426' 80' 2449' 16" 10-3/4" 41' Baker 70B2 SC1-LR Gravel Packer Baker F1 Sump Packer SSSV: None 7"3788' 2413' Perforation Depth MD (ft): 3820' KRU WSW-06 3160'-3720'2829'-3334' 8/3/2024 3-1/2" m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:03 am, Aug 05, 2024 324-451 Victoria Loepp 8/2/2024 10-404~ 340' MD above the top Ugnu perforation. VTL 8/5/2024 BOP test to 2500 psig Annular preventer test to 2500 psig Same A.Dewhurst 05AUG24 X DSR-8/5/24 Cretaceous Undef WDSP A variance to 20 AAC 25.412(b) is granted to allow the packer to be placed X DSR-8/5/24 X email 8/2/2024 JLC 8/6/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.08.07 07:58:07 -08'00' 08/07/24 RBDMS JSB 080824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 2, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Class II Disposal Injector WSW-06 (PTD# 182-177). Well WSW-06 was drilled and completed in November of 1982 by Parker 191 as an Ugnu water source well. The well was converted to a Class II disposal well in 1988 by removing the jet pump and isolating the jet pump profile. The Iso-Sleeve and Slip-Stop assembly isolating the jet pump profile have leaked and been replaced and modified multiple times in the past with varying success. Most recently, the jet pump profile was milled to remove the ID restriction, and a tubing patch was set over the profile, then the well failed a CMIT-TxIA and the tubing patch was removed. The well currently exhibits Tubing x IA communication. A failing CMIT-TxIA and subsequent leak detect log indicated a packer leak. The well has been shut in since February of 2024. To return the well to injection/disposal, we request approval to proceed with a rig workover to pull the tubing from a pre-rig cut above the upper packer, replace the tubing head, and run a new 3-1/2” completion string with a non-sealing overshot and stacked packer. Additionally, we are requesting a variance from 20 AAC 25.412(b) to stack the packer greater than 200’ MD above the top perforation. The 11/05/1982 CBL of the 7” production casing shows TOC at ~2,467’ RKB, near the surface casing shoe. The planned packer set depth is approximately ~2,915’ RKB. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells WSW-06 Kuparuk Disposal Well Tubing Swap with Stacked Packer PTD: 182-177 Page 1 of 2 PPre-Rig Work 1. CMIT-TxIA to 1800 psi failed (2/17/2024) 2. T-POT/PPPOT passed (8/2/2024) 3. IC-POT/PPPOT failed (8/2/2024) 4. LDS Function Test – OK (8/2/2024) 5. MIT-OA to 1800 psi passed (8/2/2024) 6. Tubing cut at ~2,950’ RKB. 7. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on WSW-06. No BPV will be set for MIRU due to Nordic 3 internal risk assessment. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. Replace Tubing Head 6. RIH with plug or storm packer. Set and test to confirm set. 7. ND BOPs. ND tubing head. NU new tubing head. PT Packoffs. NU BOPS. Test breaks to 250/2500 psi. 8. RIH and retrieve plug and storm packer. Cleanout 7” Casing as Needed 9. RIH with casing scraper and tubing dress off mill as needed. Install 3-1/2” Completion with Stacked Packer 10. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLM. RIH to tubing stub. 11. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 12. Land tubing hanger, RILDS, PT packoffs, drop ball/rod, and set packer. 13. Pressure test tubing to 1,800 PSI. 14. Pressure test IA to 1,800 PSI. ND BOP, NU Tree 15. Shear out SOV with pressure differential. 16. Install BPV and test. ND BOPE. NU tree. 17. Pull BPV and freeze protect well. 18. RDMO. WSW-06 Kuparuk Disposal Well Tubing Swap with Stacked Packer PTD: 182-177 Page 2 of 2 PPost-Rig Work 1. Pull SOV and replace with DV. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 8/3/2024 Current Operations: Shut-In Well Type: Class II Disposal Injector Wellhead Type: FMC. 11” 3M casing head top flange. 7-1/16” 3M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 1,398 psi / 3,134’ TVD measured on 11/28/2023 MPSP: 1,085 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above upper packer, swap tubing head, and install a new 3-1/2” completion with a stacked packer. Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Cody Keith Production Engineer: Banabas Dogah Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: CTU (Post FCO) 3,709.0 WSW-06 10/20/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added HEX Plug w/ MOE at 3065' RKB WSW-06 7/15/2023 jconne Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 39.080.080.065.00 H-40 WELDED SUR. CASING 10 3/4 9.95 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread PROD. CASING 7 6.28 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.2 Set Depth … 3,559.6 Set Depth… 3,187.7 String Ma… 3 1/2 Tubing Description TUBING - GRAVEL PACK Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.02HANGER 8.000 FMC TUBING HANGER BakerModel SC-1L 2.992 2,925.4 2,624.630.54 NIPPLE 4.500 NATIONAL JET PUMP PROFILE NIPPLE BHA Baker Model SC-1L 2.660 2,965.6 2,659.2 30.16 LOCATOR 5.000 BAKER LOCATOR Baker Model SC-1L 4.000 2,966.12,659.7 30.16 PACKER 5.968 BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER Baker Model SC-1L 4.000 2,970.3 2,663.3 30.12 EXTENSION 5.560 BAKER 80-40 MODEL 'S' PERFORATED GRAVEL PACK PACKER EXTENSION Baker Model SC-1L 4.400 2,976.0 2,668.3 30.06 SBR 5.560 SEAL BORE RECEPTACLE Baker Model SC-1L 4.000 2,977.5 2,669.6 30.05 EXTENSION 5.560 LOWER CASING EXTENSION Baker Model SC-1L 4.400 2,982.9 2,674.3 30.00 SAFETY JT 4.150 SHEAR OUT SAFETY JOINT Baker Model SC-1L 2.992 3,116.1 2,790.5 28.41 SCREEN 4.140 BAKERWELD GRAVEL PACK SCREEN Baker Model SC-1L 2.992 3,545.7 3,175.1 25.11 O-RING 3.500 BAKER O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) Baker Model SC-1L 2.400 3,546.3 3,175.6 25.10 SCREEN 4.140 BAKERWELD .006 TELL TALE SCREEN Baker Model SC-1L 2.992 3,556.1 3,184.5 25.03 SNAP LATCH 5.000 BAKER 80-40 MODEL E-22 SNAP LATCH Baker Model SC-1L 2.985 3,557.0 3,185.3 25.02 SUMP PACKER 5.875 BAKER MODEL F-1 SUMP PACKER Baker Model SC-1L 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,060.32,741.629.11 TUBING PLUG INTERWELL 180-350 HEX PLUG W/ MOE @ 3065' RKB, OAL = 5.85' INTERW ELL HEX PLUG 180-35028102 5 7/15/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,356.7 2,153.2 35.06 Stage Collar 7.000 Baker Model J6.276 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,160.03,208.02,829.22,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.03,222.02,878.92,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.03,281.02,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.03,308.02,944.92,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.03,340.02,986.02,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.03,370.03,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.03,506.03,030.03,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.03,540.03,150.93,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.03,600.03,206.23,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.03,224.33,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase WSW-06, 7/15/2023 12:00:19 PM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 TUBING PLUG; 3,060.3 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 RR Date 11/11/198 2 Other Elev… WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 41.0120.0 41.0120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 7/15/2023 12:00:21 PM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 TUBING PLUG; 3,060.3 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP WSW-06 ... WELLNAME WELLBORE WSW-06 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 80 80 16 15.062 65 H-40 Weld Surface 2448.5 2228.1 10.75 9.95 45.5 K-55 BTC Production/ Intermediate 3820 3426 7 6.28 26 K-55 BTC Tubing 3559.6 3187.7 3.5 2.99 9.2 K-55 BTC PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" x 1-1/2" MMG GLM 3-1/2" x 7" Packer 3-1/2" x 2.813" "X" Nipple Profile 3-1/2" Non-sealing Overshot EXISTING COMPLETION LEFT IN HOLE Baker Locator Seal Assembly Baker SC-1 Gravel Pack Packer @ 2966' RKB Baker Perforated Gravel Pack Extension @ 2970' RKB 3-1/2" Shear Out Safety Joint @ 2982' RKB 3-1/2" x 0.006" BakerWeld Screens @ 3116' - 3545' RKB O-Ring Seal Sub @ 3545' RKB Baker Tell-Tale Screen @ 3546' RKB Baker E-22 Snap Latch Anchor @ 3556' RKB Surface Casing Shoe - 2448' RKB Production Casing Shoe - 3820' RKB Conductor - 80' RKB Ugnu B Perfs 3580' - 3720' RKB Ugnu C Perfs 3256' - 3540' RKB PC TOC ~2467' RKB from 11/05/1982 CBL From:Loepp, Victoria T (OGC) To:Hobbs, Greg S; Eller, Cy Cc:Roby, David S (OGC); Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Regg, James B (OGC); DOA AOGCC Prudhoe Bay Bcc:Chmielowski, Jessie L C (OGC) Subject:KRU WSW-06(PTD 182-177, Sundry 324-450) Replace tubing with stacked packer APPROVAL Date:Friday, August 2, 2024 6:43:00 PM Greg, Cy, We have received the sundry request for the workover of KRU WSW-06. Approval is granted to proceed with the scope outlined in the submitted sundry. BOPE test to 2500 psig and annular preventer test to 2500 psig. The sundry will be processed on Monday, August 5, 2024. Victoria Loepp Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Eller, Cy To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S; Coberly, Jonathan; Company Man, Nordic 3 Subject:WSW-06 RWO 10-403 Date:Friday, August 2, 2024 5:03:40 PM Hi Victoria, Slickline was unsuccessful in their attempts to repair the Tubing x IA communication by replacing the iso sleeve in WSW-05, so we are planning to move forward with the WSW-06 rig workover. Nordic 3 will be finishing up the workover on 1C-13 some time tonight/early tomorrow morning and moving to 1B pad. I have submitted a 10-403 for the proposed scope of work for the WSW-06 workover which will consist of: Pulling the 3-1/2” tubing from a pre-rig cut above the upper packer. Replacing the tubing head. Installing new 3-1/2” tubing with a stacked packer. We are requesting your consideration of a verbal approval to move forward with the pre-rig tubing cut, and the proposed workover on WSW-06. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 182-177 T39358 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.06 10:04:13 -08'00' 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 3S-26 50-103-20361-01 201040_3S-26_CBL_21Sep2023 201040_3S-26_IBC-CBL_25May23 201040_3S-26_Perf_05Jun23 201040_3S-26_Perf_27Jun23 201040_3S-26_RBP_17Jun23 NUNA-1 50-103-20645-00 211155_NUNA-1_JetCut_02Mar2023 WSW-06 50-029-20851-00 182177_WSW-06_HexPlug_15Jul2023 12 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38415 T38417 T38418WSW-06 50-029-20851-00 182177_WSW-06_HexPlug_15Jul2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 12:46:14 -08'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2024-02-26_22151_KRU_WSW-06_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22151 KRU WSW-06 50-029-20851-00 Archer Vivid Acoustic LDL 26-Feb-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 182-177 T38699 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:38:48 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU WSW-06 (PTD 182-177) Update and plan forward 1/10/24 Date:Wednesday, January 10, 2024 9:35:27 AM Attachments:MIT KRU WSW-06 diagnostic MITT 1-8-24.xlsx MIT KRU WSW-06 diagnostic MITIA 12-16-23.xlsx WSW-06.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, January 10, 2024 8:27 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU WSW-06 (PTD 182-177) Update and plan forward 1/10/24 Chris, KRU WSW-06 (PTD 182-177) was recently reported for IA pressure increase on 12/4/23. The well was shut in and freeze protected. After the well was shut in the tubing pressure decreased to the point there was minimal differential pressure between the tubing and the IA and the IA pressure increase was no longer observed. DHD performed a passing MITIA on 12/16/23. Slickline set a test tool in the tubing patch at 2918’ and performed a passing MITT on 1/8/24. With the passing pressure tests and being unable to activate the IA pressure increase the plan is to bring the well on injection for a 30-day monitor period to determine if the IA pressure increase will reactivate and if so to allow for diagnostics while the well is online. Any proper paperwork for continued injection or corrective action will be submitted once the monitor and diagnostic period has been completed. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 From: Byrne, Jan Sent: Monday, December 4, 2023 8:34 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure increase Chris, KRU WSW-06 (PTD 182-177) DHD was requested to assist applying a gas cap to the IA and while doing so observed suspect IA communication. DHD pivoted into an IA-DDT and reported slow linear pressure build up. The well is shut in and freeze protected, and the plan is to begin diagnostics with wireline to determine the source of the IA pressure increase. Any proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. I’ve included a 2-week TIO trend in addition to the 90-day TIO trend since the well was only recently BOI post patch installation. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,523.0 WSW-06 11/18/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update Tag depth WSW-06 11/18/2023 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 80.0 80.0 65.00 H-40 WELDED SUR. CASING 10 3/4 9.95 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread PROD. CASING 7 6.28 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 29.2 Set Depth … 3,559.6 Set Depth … 3,187.7 String Max No… 3 1/2 Tubing Description TUBING - GRAVEL PACK Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.02 HANGER 8.000 TUBING HANGER FMC 2.992 2,925.4 2,624.6 30.54 NIPPLE 4.500 JET PUMP PROFILE NIPPLE BHA. **MILLED OUT TO 2.80" 10/10/23** National 2.660 2,965.6 2,659.2 30.16 LOCATOR 5.000 LOCATOR Baker 4.000 2,966.1 2,659.7 30.16 PACKER 5.968 70B2-40 SC1-L1 GRAVEL PACK PACKER Baker Model SC-1L 4.000 2,970.3 2,663.3 30.12 EXTENSION 5.560 80-40 PERFORATED GRAVEL PACK PACKER EXTENSION Baker Model 'S' 4.400 2,976.0 2,668.3 30.06 SBR 5.560 SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION 5.560 LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETY JT 4.150 SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN 4.140 BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 O-RING 3.500 O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) Baker 2.400 3,546.3 3,175.6 25.10 SCREEN 4.140 BAKERWELD .006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH 5.000 80-40 SNAP LATCH Baker MODEL E-22 2.985 3,557.0 3,185.3 25.02 SUMP PACKER 5.875 SUMP PACKER Baker Model F- 1 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,917.5 2,617.8 30.62 PACKER - PATCH - UPR 2.725" PIIP Upper Patch Packer (Upper Patch Assembly includes Upper Packer, spacer pipe, and Anchor Latch) OAL = 20.9'. Mid-element set @ 2919.97' RKB. TTS PIIP CPP3 5155 10/13/2023 1.625 2,921.2 2,621.0 30.58 ANCHOR LATCH ON SPACER PIPE Spacer Pipe w/ Anchor Latch (Part of the Upper Patch Assembly) TTS CPAL 35203 10/13/2023 1.600 2,937.6 2,635.1 30.43 PACKER - PATCH - LWR 2.725" PIIP Lower Patch Packer (Set mid-element @ 2940' RKB) TTS PIIP CPP3 5120 10/13/2023 1.625 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,356.7 2,153.2 35.06 Stage Collar 7.000 Baker Model J 6.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase WSW-06, 11/19/2023 10:19:40 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 PACKER - PATCH - LWR; 2,937.5 NIPPLE; 2,925.4 ANCHOR LATCH ON SPACER PIPE; 2,921.2 PACKER - PATCH - UPR; 2,917.5 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 RR Date 11/11/198 2 Other Elev… WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBOREWSW-06 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 120.0 41.0 120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 11/19/2023 10:19:42 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 PACKER - PATCH - LWR; 2,937.5 NIPPLE; 2,925.4 ANCHOR LATCH ON SPACER PIPE; 2,921.2 PACKER - PATCH - UPR; 2,917.5 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP WSW-06 ... WELLNAME WELLBOREWSW-06 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1821770 Type Inj N Tubing 600 2100 1750 Type Test P Packer TVD 2660 BBL Pump 0.1 IA 80 120 120 Interval O Test psi 1500 BBL Return OA 0 0 0 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1821770 Type Inj N Tubing 1750 2000 2000 2000 Type Test P Packer TVD 2660 BBL Pump 0.1 IA 120 120 120 120 Interval O Test psi 1500 BBL Return OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1B Pad Hills 12/16/23 Notes:Diagnostic MITT, failed in first 15 mins, bumped pressure back up and passed. Notes: WSW-06 WSW-06 Notes:Diagnostic MITT, bumped pressure up after 1st attempt and passed with no pressure loss. Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU WSW-06 diagnostic MITT 1-8-24 (002) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure increase Date:Monday, December 4, 2023 4:54:33 PM Attachments:WSW-06.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, December 4, 2023 8:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure increase Chris, KRU WSW-06 (PTD 182-177) DHD was requested to assist applying a gas cap to the IA and while doing so observed suspect IA communication. DHD pivoted into an IA-DDT and reported slow linear pressure build up. The well is shut in and freeze protected, and the plan is to begin diagnostics with wireline to determine the source of the IA pressure increase. Any proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. I’ve included a 2-week TIO trend in addition to the 90-day TIO trend since the well was only recently BOI post patch installation. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 3,523.0 WSW-06 11/18/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update Tag depth WSW-06 11/18/2023 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 80.0 80.0 65.00 H-40 WELDED SUR. CASING 10 3/4 9.95 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread PROD. CASING 7 6.28 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 29.2 Set Depth … 3,559.6 Set Depth … 3,187.7 String Max No… 3 1/2 Tubing Description TUBING - GRAVEL PACK Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.02 HANGER 8.000 TUBING HANGER FMC 2.992 2,925.4 2,624.6 30.54 NIPPLE 4.500 JET PUMP PROFILE NIPPLE BHA. **MILLED OUT TO 2.80" 10/10/23** National 2.660 2,965.6 2,659.2 30.16 LOCATOR 5.000 LOCATOR Baker 4.000 2,966.1 2,659.7 30.16 PACKER 5.968 70B2-40 SC1-L1 GRAVEL PACK PACKER Baker Model SC-1L 4.000 2,970.3 2,663.3 30.12 EXTENSION 5.560 80-40 PERFORATED GRAVEL PACK PACKER EXTENSION Baker Model 'S' 4.400 2,976.0 2,668.3 30.06 SBR 5.560 SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION 5.560 LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETY JT 4.150 SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN 4.140 BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 O-RING 3.500 O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) Baker 2.400 3,546.3 3,175.6 25.10 SCREEN 4.140 BAKERWELD .006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH 5.000 80-40 SNAP LATCH Baker MODEL E-22 2.985 3,557.0 3,185.3 25.02 SUMP PACKER 5.875 SUMP PACKER Baker Model F- 1 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,917.5 2,617.8 30.62 PACKER - PATCH - UPR 2.725" PIIP Upper Patch Packer (Upper Patch Assembly includes Upper Packer, spacer pipe, and Anchor Latch) OAL = 20.9'. Mid-element set @ 2919.97' RKB. TTS PIIP CPP3 5155 10/13/2023 1.625 2,921.2 2,621.0 30.58 ANCHOR LATCH ON SPACER PIPE Spacer Pipe w/ Anchor Latch (Part of the Upper Patch Assembly) TTS CPAL 35203 10/13/2023 1.600 2,937.6 2,635.1 30.43 PACKER - PATCH - LWR 2.725" PIIP Lower Patch Packer (Set mid-element @ 2940' RKB) TTS PIIP CPP3 5120 10/13/2023 1.625 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,356.7 2,153.2 35.06 Stage Collar 7.000 Baker Model J 6.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase WSW-06, 11/19/2023 10:19:40 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 PACKER - PATCH - LWR; 2,937.5 NIPPLE; 2,925.4 ANCHOR LATCH ON SPACER PIPE; 2,921.2 PACKER - PATCH - UPR; 2,917.5 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 RR Date 11/11/198 2 Other Elev… WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBOREWSW-06 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 120.0 41.0 120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 11/19/2023 10:19:42 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 PACKER - PATCH - LWR; 2,937.5 NIPPLE; 2,925.4 ANCHOR LATCH ON SPACER PIPE; 2,921.2 PACKER - PATCH - UPR; 2,917.5 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP WSW-06 ... WELLNAME WELLBOREWSW-06 MULTIPLE TAG TREND (1 x 8) SCALE 1500 13 1] 10 8 7 5 9 2 1 TREND GROUP NAME: i CLIPBOARD_9$� 45 ---------- ------------ ------------ ------------- ------------- ------------- ------------- ------------ ------------ --------- -- -- --------- ------------- --- -------- 90 __________ _____________ ____________ _____________ __________ ------------- _.__________ _____________ ____________ __________.. __ _._.__ _ _ _______ 35 __________ _____________ ____________ _____________ _____________ _____________ _____________ _____________ ____________ _____________ ___ _________ _____ _______ __ _ ________ 80 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ ___ _________ _____________ __ __ _______ 25 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ ___ _________ _____________ _____ _______ 70 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ ___ _________ _______ _____ _ ___ ____ 1 5 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ ___ _________ ______ __ ___ __ ______ 60 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ ___ _________ _____ ____ _ _ _ _ ______ 05 __________ _____________ ____________ _____________ _____________ _____________ _____________ ____________ ____________ ____________ _________ ___ __ _____ -----______ s0------------------------------------------------------------------------------------------------------------- PLOT START TIME SWITCH TO HISTORIC TIME SAVE CURRENT ?????7777777777 HIDE TREND SELECT DATA SCALE TYPE TAG MANE DV TI-1B7005 DV PI-1B5243 DV PI-1B5227 . DV PI-1B5176 I� t � SAVEZLOAD GROUPS GROUP SELECT LIST --------------------------- MINOR TIME MAJOR TIME WEEK ZOOM ®p ------------------------ PAGE 1/ 1 .qFAUTO GI® ------------------ PICK MOVE No M N No -------------------------- j--------------------------------------- PLOT DURATION PLOT END TIME HRS - HRS 04-DEC23 08:25 MEMMM F rI-27 25 _. __. ...__.._.... __._.. __ .._._.. PICK TIME DESCRIPTION PICK VAL LATEST 1B WS6 GRIND & INJECT WELL FLOWLINE TEMP ??????? 41.9 1B WS6 GRIND & INJECT WELL OA PRES ?777777 -13.6 1B WS6 GRIND & INJECT WELL IA PRES ?????7? 84.2 1B WS6 GRIND & INJECT WELL FLOWLINE PRES ?777777 704. 777777 777777 777777 777777 ■ TREND STAIRSTEP ■ TREND PLOT 3a4 ■ TREND PLOT 2s6 a TREND XZY 1-4 TREND BUILDER = MAXIMIZE TREND = GROUP EMAIL = TREND GROUP LIST E Clipboard Excel Email 6CSV attachment Email To tuser ID or email address) INSTANT HOURI: MINUTE ■ SIMPLE TR SETUP ADD TO FAVORITES MULTIPLE TAG TREND (1 x 8) SCALE 1500 13 11 10 8 7 5 4 2 1 TREND GROUP NAME. i CLIPBOARD_95 45 r 90 ------- 4 ------------ ------------ - -- ------- ---- 4 ___ ___ ____________ ____ 35 _ __ _ __ __ ___ _ __ ____________ BO_ __ _ _ __ __ ___ ____ _ _____ _________________________________ ____ 25 - _ _ __ ___ _____ ______ ___ _______ ___________ ____________ ____ 70 - -- - - --- ----- ------ --- - -- -- ----------- ------------ _ 15 _ __ _ _ _ ____ ______ _ __ _______ _________ 60 ______ __ _______ ________ SO ----------------------------------------------------------------------- ----------------------------------------------------------------- J ---------------------------- ----------- PLOT START TIME I SWITCH TO HISTORIC TIME SAVE CURRENT ?????7777777777 MINOR TIME DAY MAJOR TIME WEEK ZOOM ®0 PAGE 1/1 PICA MOVE m MAX ee AUTO PAC IldB MIN No HIDE SELECT DATA TREND SCALE TYPE TAG NANE DESCRIPTION HV TI-1B7005 1B WS6 GRIND & INJECT WELL FLOWLINE TEMP HV PI-1B5243 1B WS6 GRIND & INJECT WELL OA PRES HV PI-1B5227 1B WS6 GRIND & INJECT WELL IA PRES HV PI-1115176 1B WS6 GRIND & INJECT WELL FLOWLINE PRES I- SAVE/LOAD GROUPS TREND STAIRSTEP TREND PLOT 3a4 GROUP SELECT LIST TREND BUILDER MAXIMIZE TREND Off ■ TREND PLOT 2z6 GROUP EMAIL PLOT DURATION HRS - BRS PICK VAL 62.3 -13.1 781.6 735. 777777 777?7? ?7777? ?????? LATEST 41.9 -13.6 84.2 704. PLOT END TIME 04-DEC-23 08:25 KT-77 F- SEND Tc ■ Clipboard ■ Excel ■ Email M CSV attachment Email To (user ID or email address) rtA INSTANT M HOURLY PE MINUTE MDAILY TREND X/Y 1-4 TREND GROUP LIST ■ SIMPLE TR SETUP ■ ADD TO FAVORITES Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 13KͲ26 50Ͳ029Ͳ22764Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 16ͲJulͲ23 0 1 23KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 15ͲOctͲ23 0 1 33OͲ18 50Ͳ029Ͳ21793Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 19ͲNovͲ23 0 1 4WSWͲ06 50Ͳ029Ͳ20851Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 13ͲOctͲ23 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 3K-36 PTD: 197-077 T38175 2. 3K-27 PTD: 197-046 T38176 3. 3O-18 PTD: 188-026 T38177 4. WSW-06 PTD:182-177 T38178 12/1/2023 4WSWͲ06 50Ͳ029Ͳ20851Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 13ͲOctͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:13:24 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-06 KUPARUK RIV UNIT WSW-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 WSW-06 50-029-20851-00-00 182-177-0 N SPT 2660 1821770 1500 260 260 260 260 230 360 360 360 OTHER P Austin McLeod 10/18/2023 Post patch. Sundry 323-487 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-06 Inspection Date: Tubing OA Packer Depth 115 1740 1610 1590IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM231018191306 BBL Pumped:0.7 BBL Returned:0.7 Tuesday, December 5, 2023 Page 1 of 1            1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3835'feet None feet true vertical 3430' feet None feet Effective Depth measured 3835'feet 2917', 2938', 2966'feet true vertical 3430' feet 2618', 2635', 2660'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" K-55 3560' MD 3188' TVD Packers and SSSV (type, measured and true vertical depth)2917' MD 2938' MD 2966' MD N/A 2618' TVD 2635' TVD 2660' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Ugnu Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2448' 2228' Burst Collapse Production Liner 3788' Casing 3426'3820' 2413' 80'Conductor Surface Intermediate 16" 10-3/4" 41' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-177 50-029-20851-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL25648 Kuparuk River Field/ Ugnu Oil Pool KRU WSW-06 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 80' ~ ~~ Disposal Well ~~ ~ 323-487 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: 70B2-40 SC1-L1 Gravel Pack Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 265-6471Senior Well Integrity Specialist 3160-3720' 2829-3334' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:03 am, Nov 07, 2023 Digitally signed by Jan Byrne DN: OU=Well Integrity, O=AK Wells, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I am the author of this document Location: Anchorage tower Date: 2023.11.07 09:25:44-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 10/10/2023 ACQUIRE DATA MIRU, CHANGE PACK OFF'S & PERFORM CHAIN INSPECTION. PICK UP 2.80" MILL. MILL THROUGH NJP NIPPLE AT 2925' RKB. POOH, RDMO. READY FOR PATCH. 10/12/2023 ACQUIRE DATA BRUSH n' FLUSH PATCH AREA FROM 2950' TO 2900' RKB, TBG OPEN 2.75", CLEAN 2.72" PATCH DRIFT TO 2975' RKB (OAL 20'). IN PROGRESS. 10/13/2023 ACQUIRE DATA SET LOWER 2.72" P2P @ 2940' RKB (CE) (SN: CPP35120), CMIT TBG x IA 1700 PSI W/ 3 1/2 TTS TEST TOOL IN LOWER PACKER (PASS), SET 2.72" P2P SPACER ANCHOR LATCH @ 2919.97' RKB (CE), MIT IA 1700 PSI (PASS). READY FOR DHD. 10/16/2023 ACQUIRE DATA (AC-EVAL) IA-DDT (PASSED) 10/18/2023 ACQUIRE DATA (SW) WSW-06 STATE WITNESSED (AUSTIN McLEOD ) MIT-IA PASSED TO 1740 PSI. WSW-06 Tubing Patch Summary of Operations 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Patch 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk River Field Ugnu Ugnu 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3885 3885 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Jan Byrne Contact Email: Contact Phone: 907-265-6471 Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/21/2023 3.5 Baker 70B2 SC1-LR Gravel Packer Baker F1 Sump Packer No SSSV 3820 Perforation Depth MD (ft): 3160 - 3720 3788 2829 - 3334 34267 16 10.75 41 2413 80 2228 80 2449 K-55 TVD Burst 3560 MD ConocoPhillips Alaska, Inc Length Size Proposed Pools: Plugs (MD): KRU WSW-06 3486 2966 MD / 2660 TVD 3557 MD / 3185 TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25648 182-177 P.O. Box 100360, Anchorage, Alaska 99510 50-029-20851-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 3486 Tubing Grade:Tubing MD (ft): 3060 Janbyrne@conocophillips.com Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=AK Wells, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.08.28 11:45:29-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne By Grace Christianson at 2:45 pm, Aug 28, 2023 323-487 X 3430' SFD X -00 SFD VTL 10/4/2023 3835' SFD DSR-8/28/23SFD 9/7/2023 *&:JLC 10/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 13:27:11 -08'00'10/04/23 RBDMS JSB 100523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU WSW-06 (PTD 182-177) to install a retrievable tubing patch over a jet pump profile. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Jan Byrne DN: OU=AK Wells, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.08.28 11:44:38-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 1B-WSW-06 passed its SW MITIA on 6/6/23, but failed a follow up IA-DDT on 6/8/23 and was reported to the AOGCC for suspect TxIA communicaƟon. MulƟple modiĮed packing stacks were aƩempted to get the iso sleeve to hold, but the IA-DDT conƟnued to fail. A HEX plug was set 3060' and a passing CMIT and C-DDT passed. This WWR is for a tubing patch to be set over the NJP proĮle subsequent Coil milling the ID to regain tubing integrity. Risks/Job Concerns (Include DriŌ informaƟon on high deviaƟon wells, or wells with tag issues): x Class II Disposal well x MAX IA test pressure 1700 psi. (tubing spool limited to 3000 psi. IA valves limited to 2000 psi). x Jet Pump Nipple at 2,925' RKB has a nominal ID of 2.660", but caliper logged on 7.29.23 reported an ID of 2.566". x Need approved 10-403 sundry prior to seƫng tubing patch. Steps(Author: please include SSSV notes and note any future work required to capture rate beneĮt listed above (include esƟmated days/units in cost)): Relay or Eline/Slickline 1. RIH with lower 2.72" P2P and set mid element at 2940'. 2. SƟng into lower P2P with test tool and perform CMIT TxIA to 1700 psi. Record TIOs. Pull test tool. 3. RIH with upper patch assembly and sƟng into anchor latch. The patch should be 20' element to element seƫng the upper P2P mid element at 2920'. 4. Perform MITIA to 1700 psi. Record TIOs. 5. SL RDMO. 6. DHD to perform IA-DDT to 0 psi. 7. DHD to perform SW MITIA. 8. Turn over to MI/OperaƟons once SW MITIA has been completed. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: CTU (Post FCO) 3,709.0 WSW-06 10/20/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added HEX Plug w/ MOE at 3065' RKB WSW-06 7/15/2023 jconne Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 39.080.080.065.00 H-40 WELDED SUR. CASING 10 3/4 9.95 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread PROD. CASING 7 6.28 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.2 Set Depth … 3,559.6 Set Depth… 3,187.7 String Ma… 3 1/2 Tubing Description TUBING - GRAVEL PACK Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.2 29.2 0.02HANGER 8.000 FMC TUBING HANGER BakerModel SC-1L 2.992 2,925.4 2,624.630.54 NIPPLE 4.500 NATIONAL JET PUMP PROFILE NIPPLE BHA Baker Model SC-1L 2.660 2,965.6 2,659.2 30.16 LOCATOR 5.000 BAKER LOCATOR Baker Model SC-1L 4.000 2,966.12,659.7 30.16 PACKER 5.968 BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER Baker Model SC-1L 4.000 2,970.3 2,663.3 30.12 EXTENSION 5.560 BAKER 80-40 MODEL 'S' PERFORATED GRAVEL PACK PACKER EXTENSION Baker Model SC-1L 4.400 2,976.0 2,668.3 30.06 SBR 5.560 SEAL BORE RECEPTACLE Baker Model SC-1L 4.000 2,977.5 2,669.6 30.05 EXTENSION 5.560 LOWER CASING EXTENSION Baker Model SC-1L 4.400 2,982.9 2,674.3 30.00 SAFETY JT 4.150 SHEAR OUT SAFETY JOINT Baker Model SC-1L 2.992 3,116.1 2,790.5 28.41 SCREEN 4.140 BAKERWELD GRAVEL PACK SCREEN Baker Model SC-1L 2.992 3,545.7 3,175.1 25.11 O-RING 3.500 BAKER O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) Baker Model SC-1L 2.400 3,546.3 3,175.6 25.10 SCREEN 4.140 BAKERWELD .006 TELL TALE SCREEN Baker Model SC-1L 2.992 3,556.1 3,184.5 25.03 SNAP LATCH 5.000 BAKER 80-40 MODEL E-22 SNAP LATCH Baker Model SC-1L 2.985 3,557.0 3,185.3 25.02 SUMP PACKER 5.875 BAKER MODEL F-1 SUMP PACKER Baker Model SC-1L 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,060.32,741.629.11 TUBING PLUG INTERWELL 180-350 HEX PLUG W/ MOE @ 3065' RKB, OAL = 5.85' INTERW ELL HEX PLUG 180-35028102 5 7/15/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,356.7 2,153.2 35.06 Stage Collar 7.000 Baker Model J6.276 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,160.03,208.02,829.22,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.03,222.02,878.92,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.03,281.02,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.03,308.02,944.92,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.03,340.02,986.02,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.03,370.03,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.03,506.03,030.03,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.03,540.03,150.93,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.03,600.03,206.23,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.03,620.03,224.33,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase WSW-06, 8/28/2023 11:21:04 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 TUBING PLUG; 3,060.3 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 RR Date 11/11/198 2 Other Elev… WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 41.0120.0 41.0120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 8/28/2023 11:21:06 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 Float Shoe; 3,818.2-3,820.0 Float Collar; 3,732.6-3,734.2 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 Marker Joint; 3,141.5-3,184.2 TUBING PLUG; 3,060.3 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 SUR. CASING; 35.1-2,448.5 Float Shoe; 2,446.6-2,448.5 Float Collar; 2,366.0-2,367.6 Stage Collar; 2,356.7-2,358.9 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 Casing Hanger; 35.1-39.3 Casing Hanger; 32.3-36.6 HANGER; 29.2 KUP DISP WSW-06 ... WELLNAME WELLBORE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure increase Date:Tuesday, June 13, 2023 9:05:33 AM Attachments:WSW-06.pdf WSW-06 90 day TIO trend 6.8.23.png From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, June 8, 2023 3:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure increase Chris, KRU WSW-06 (PTD 182-177) is exhibiting suspect IA pressure increase. DHD bled the IA pressure down, but it recharged back to near tubing pressure. The well is shut in and freeze protected, and the plan is to begin diagnostics with wireline to determine the source of the IA pressure increase. Any proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTU (Post FCO) 3,709.0 10/20/2021 WSW-06 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Iso Sleeve & Slip Stop 10/22/2021 WSW-06 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 39.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SUR. CASING OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 35.1 Set Depth (ftKB) 2,448.5 Set Depth (TVD) … 2,228.1 Wt/Len (l… 45.50 Grade K-55 Top Thread Buttress Thread Casing Description PROD. CASING OD (in) 7 ID (in) 6.28 Top (ftKB) 32.3 Set Depth (ftKB) 3,820.0 Set Depth (TVD) … 3,426.0 Wt/Len (l… 26.00 Grade K-55 Top Thread Buttress Thread Tubing Strings Tubing Description TUBING - GRAVEL PACK String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 29.2 Set Depth (ft… 3,559.6 Set Depth (TVD) (… 3,187.7 Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 29.2 29.2 0.02 HANGER FMC TUBING HANGER 2.992 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.660 2,965.6 2,659.2 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL 'S' PERFORATED GRAVEL PACK PACKER EXTENSION 4.400 2,976.0 2,668.3 30.06 SBR SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETY JT SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 O-RING BAKER O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) 2.400 3,546.3 3,175.6 25.10 SCREEN BAKERWELD .006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 3,557.0 3,185.3 25.02 SUMP PACKER BAKER MODEL F-1 SUMP PACKER 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,923.0 2,622.5 30.56 SLIP STOP 3'' SLIP STOP (OAL 19'' / 1.5'' ID) 10/22/2021 1.500 2,925.0 2,624.2 30.55 ISO-SLEEVE 2.79'' ISO SLEEVE (4 AVA SEALS) W/ G FN (OAL 18.5'' / 1.99'' ID) 10/20/2021 1.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 120.0 41.0 120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 10/23/2021 2:45:56 PM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 ISO-SLEEVE; 2,925.0 SLIP STOP; 2,923.0 SUR. CASING; 35.1-2,448.5 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 Rig Release Date 11/11/1982 WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBOREWSW-06 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE MULTIPLE TAG TREND [1 x8) 200 D SCALE TREND GROUP NAME: X CLIPBOARD_143 250.0 1sun isoo.o 1000. 1345 ?????? 1190 7????? max 1035 AUTOSCALE 880 Iffow now725 agag .rno 570 GET P SAVEIM 415 'x 50.0 260 0.0 -so.o Ins o. ????? —so - - - - - - '---------------------------------------------------------------------------------------------------I-------------------------------------------------------------------------- PLOT START TIME MINOR TIME PAGE I/1 PICK MOVE PLOT DURATION PLOT END TIME ?????? 09 -MAR -23 13:20 MAJOR TIME WEEK ,&, 7,&. M MAX EQ 2184.0 08 -JUN -23 14:20 on 7TOSWITCH HISTORIC TIME ZOOM ©E MIN MU QT-�� 7 SAVE CURRENT ??????????????? HIDE SELECT MRTR PICK TIME 2.g_APR-23 16:12:59 TREND SCALE TYPE TAG NAME DESCRIPTION PICK VAL LATEST Clipboard �A1PE . DV TI -1$7005 1B WS6 GRIND & INJECT WELL FLOWLINE TEMP 64.4 62.3 Trending DV PI-IB5243 111 WS6 GRIND & INJECT WELL OA PRES 26.8 44.3 Excel DV PI-IB5227 1B WS6 GRIND & INJECT WELL IA PRES 34.9 -12.6 DV PI-IB5176 1B WS6 GRIND & INJECT WELL FLOWLINE PRES 801. 769. Email+' cso avva�nmexv . 777777 Email Tu email address) . 777777 iAdam Becia ?????? DATA I M INSTANT HOURLY 77???? FTE]= MINUTE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. WSW-06 KUPARUK RIV UNIT WSW-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 WSW-06 50-029-20851-00-00 182-177-0 N SPT 2660 1821770 1500 550 550 550 550 30 30 30 30 OTHER P Brian Bixby 6/6/2023 MIT-IA for Class 2 Slurry Well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT WSW-06 Inspection Date: Tubing OA Packer Depth 610 1820 1720 1690IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607095253 BBL Pumped:0.5 BBL Returned:0.5 Wednesday, July 26, 2023 Page 1 of 1           1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Wednesday, September 22, 2021 7:18 AM To:AOGCC Records (CED sponsored) Cc:Brooks, Phoebe L (CED) Subject:FW: KRU WSW-06 (PTD 182-177) Update 9.16.21 Attachments:MIT KRU WSW-06 diagnostic MITIA 9.15.21.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, September 16, 2021 2:18 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW‐06 (PTD 182‐177) Update 9.16.21 Chris, KRU WSW‐06 (PTD 182‐177) After performing fluid sampling work for the upcoming conversion to class one disposal injection, Slickline reset the isolation sleeve at 2925’ with new packing and passed an MITIA after which an IA‐DDT was performed and passed. Once fluids are available, expected to be withing the next few days, the plan is to bring the well on disposal injection with DHD technicians present to monitor the well for any annular communication. If the well proves to maintain integrity it will be returned to its ‘normal’ status. If anncomm is observed the well will be shut in and diagnostics will begin anew. A 10‐426 with aforementioned tests is attached. Please let me know if you disagree with or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Friday, September 10, 2021 9:00 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW‐06 (PTD 182‐177) Report of suspect IA pressure Chris, KRU WSW‐06 (PTD 182‐177) was reported by Operations for having had multiple bleeds on the IA while the well was online. The well was shut in and freeze protected after which DHD performed initial diagnostics including passing tubing pack off tests and a passing MITIA (see attached 10‐426). The IA pressure was bled for a draw down test which in the initial hour looked promising, but overnight the tubing pressure decreased and the IA pressure increased indicating TxIA communication. The plan is for the well to remain shut in and begin diagnostics with wireline asap. The proper 2 paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821770 Type Inj N Tubing 250 250 250 250 Type Test P Packer TVD 2660 BBL Pump 0.6 IA 260 1705 1675 1665 Interval O Test psi 1500 BBL Return 0.5 OA 320 320 320 320 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821770 Type Inj N Tubing 233 233 233 233 233 233 Type Test P Packer TVD 2600 BBL Pump IA 235 0'1111Interval O Test psi 1500 BBL Return OA 250 250 250 250 250 250 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1B PAD Galle 09/09/21 Notes:Diagnostic MITIA Notes: Notes: Notes: WSW-06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Diagnostic IA-DDT Notes: Notes: Form 10-426 (Revised 01/2017)MIT KRU WSW-06 diagnostic MITIA 9.15.21 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, September 14, 2021 2:54 PM To:AOGCC Records (CED sponsored) Subject:FW: KRU WSW-06 (PTD 182-177) Report of suspect IA pressure Attachments:WSW-06.pdf; WSW-06 90 day TIO trend 9.10.21.jpg; MIT KRU WSW-06 diagnostic MITIA 9.9.21.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, September 10, 2021 9:00 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU WSW‐06 (PTD 182‐177) Report of suspect IA pressure Chris, KRU WSW‐06 (PTD 182‐177) was reported by Operations for having had multiple bleeds on the IA while the well was online. The well was shut in and freeze protected after which DHD performed initial diagnostics including passing tubing pack off tests and a passing MITIA (see attached 10‐426). The IA pressure was bled for a draw down test which in the initial hour looked promising, but overnight the tubing pressure decreased and the IA pressure increased indicating TxIA communication. The plan is for the well to remain shut in and begin diagnostics with wireline asap. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 340' Above Btm Perf) 3,380.0 2/13/2021 WSW-06 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set ISO Sleeve & Slip Stop 2/28/2021 WSW-06 raineg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 39.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SUR. CASING OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 35.1 Set Depth (ftKB) 2,448.5 Set Depth (TVD) … 2,228.1 Wt/Len (l… 45.50 Grade K-55 Top Thread Buttress Thread Casing Description PROD. CASING OD (in) 7 ID (in) 6.28 Top (ftKB) 32.3 Set Depth (ftKB) 3,820.0 Set Depth (TVD) … 3,426.0 Wt/Len (l… 26.00 Grade K-55 Top Thread Buttress Thread Tubing Strings Tubing Description TUBING - GRAVEL PACK String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 29.2 Set Depth (ft… 3,559.6 Set Depth (TVD) (… 3,187.7 Wt (lb/ft) 9.20 Grade K-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 29.2 29.2 0.02 HANGER FMC TUBING HANGER 2.992 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.660 2,965.6 2,659.2 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL 'S' PERFORATED GRAVEL PACK PACKER EXTENSION 4.400 2,976.0 2,668.3 30.06 SBR SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETY JT SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 O-RING BAKER O-RING SEAL SUB ((MILLED TO 2.40" 5/12/2015) 2.400 3,546.3 3,175.6 25.10 SCREEN BAKERWELD .006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 3,557.0 3,185.3 25.02 SUMP PACKER BAKER MODEL F-1 SUMP PACKER 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,923.0 2,622.5 30.56 SLIP STOP 3'' SLIP STOP (OAL 19'' / 1.5'' ID) 2/28/2021 1.500 2,925.0 2,624.2 30.55 ISO SLEEVE 2.79'' ISO SLEEVE W/ G FN (OAL 18.5'' / 1.99'' ID) 2/28/2021 1.990 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, WSW-06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, WSW- 06 11/7/1982 12.0 IPERF Vann Guns, 60 deg. phasing 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, WSW- 06 3/6/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, WSW- 06 3/5/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, WSW- 06 3/3/2015 6.0 APERF Deep Star Strip Gun w 15.5. gram penetrating chg, triphase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.0 120.0 41.0 120.0 Remedial Cement Squeeze pumped 36 bbls Arctic set II cement through 3/4" pipe set at 120' 11/2/1982 WSW-06, 3/1/2021 8:23:56 AM Vertical schematic (actual) PROD. CASING; 32.3-3,820.0 APERF; 3,710.0-3,720.0 APERF; 3,690.0-3,710.0 APERF; 3,670.0-3,690.0 APERF; 3,600.0-3,620.0 APERF; 3,580.0-3,600.0 SUMP PACKER; 3,557.0 SNAP LATCH; 3,556.1 SCREEN; 3,546.3 O-RING; 3,545.7 IPERF; 3,519.0-3,540.0 IPERF; 3,385.0-3,506.0 IPERF; 3,352.0-3,370.0 IPERF; 3,336.0-3,340.0 SCREEN; 3,116.1 IPERF; 3,290.0-3,308.0 IPERF; 3,256.0-3,281.0 IPERF; 3,216.0-3,222.0 IPERF; 3,160.0-3,208.0 XO THREAD; 2,982.1 EXTENSION; 2,977.5 SBR; 2,976.0 EXTENSION; 2,970.3 PACKER; 2,966.1 LOCATOR; 2,965.6 NIPPLE; 2,925.4 ISO SLEEVE; 2,925.0 SUR. CASING; 35.1-2,448.5 Remedial Cement Squeeze; 41.0 ftKB CONDUCTOR; 39.0-80.0 HANGER; 29.2 KUP DISP KB-Grd (ft) 41.01 Rig Release Date 11/11/1982 WSW-06 ... TD Act Btm (ftKB) 3,835.0 Well Attributes Field Name SHALLOW SANDS Wellbore API/UWI 500292085100 Wellbore Status DISP Max Angle & MD Incl (°) 35.52 MD (ftKB) 2,500.00 WELLNAME WELLBOREWSW-06 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821770 Type Inj N Tubing 250 250 250 250 Type Test P Packer TVD 2660 BBL Pump 1.6 IA 60 1800 1765 1750 Interval O Test psi 1500 BBL Return OA 280 310 310 310 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1B PAD Hembra 09/09/21 Notes:Diagnostic MITIA Notes: Notes: Notes: WSW-06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)MIT KRU WSW-06 diagnostic MITIA 9.9.21 (002) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 28, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. WSW -06 KUPARUK RIV UNIT WSW -06 Src: Inspector Reviewed By: n P.I. Supry Comm Well Name KUPARUK RIV UNIT WSW -06 API Well Number 50-029-20851-00-00 Inspector Name: Lou Laubenstein Permit Number: 182-177-0 Inspection Date: 7/28/2021 Insp Num: mitt -01-210728100121 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WSW -06 Type Inj 1 s, TVD 2660 Tubing 750 750 750 - 750 —1 - — - - PTD 1821770 Type Testi SPT jest psi 1500 IA 430 1820 1690 - 1670 BBL Pumped: 0.6 BBL Returned: 0.6 OA 125 - 195 190 - 190 - Interval _ OTHER P/F _P ;/ Notes: MIT -IA for Class 2 Injection well. -� - Wednesday, July 28, 2021 Page 1 of I Originated:Delivered to:6-Apr-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-21 50-103-20094-00 907019707 Kuparuk River Leak Detect Log Field- Final 12-Mar-21 0 1 2 3H-21 50-103-20094-00 907019707 Kuparuk River Plug Setting Record Field- Final 12-Mar-21 0 1 3 WSW-06 50-029-20851-00 906976270 Shallow Sands Multi Finger Caliper Field & Processed 13-Feb-21 0 1 4 5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 04/07/2021 PTD: 1821770 E-Set: 34918 04/07/2021 Transmittal No:2018-02WS Baker Hughes- Transmittal Form 17021 Aldine Westfield Rd., Houston, TX 77073 Tel: 1-713-879-0061 From:Baker Hughes Reg. Agency Alaska Oil and Gas Conservation Commission Attn. Abby Bell Name:Guillermo Bur Natural Resource Technician II Location:333 West 7th Avenue Department:Wireline Services 907-793-1225 Date:1-Mar-21 JOB NUMBER: WELL Several Page 1/1 Item No:Digital Copies WSW-06 well - MVRT log reports (PDF) Name Format 1 50029208510000_WSW-06_MVRT_EVAL_2-25-2021.pdf PDF 1 TRANSMITTED BY DATE:RECEIVED BY: DATE: Guillermo Bur 1-Mar-21 SIGN IN RECEIVED BY SECTION AND RETURN SIGNED COPY TO BH DESCRIPTION - SFTP logs Received by the AOGCC 03/08/2021 PTD: 1821770 E-Set: 34764 03/10/2021 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 26, 2019 TO: Jim Regg q P.I. Supervisor I e�� TJr'l9 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. WSW -06 FROM: Lou Laubenstein KUPARUK RIV UNIT WSW -06 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry J Sp— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW -06 API Well Number 50-029-20851-00-00 Inspector Name: Lou Laubenstein Permit Number: 182-177-0 Inspection Date: 6/10/2019 InspNUm: mitLOL190611085742 Rel Insp Num: Packer Depth Well WSW -06 ' Type Inj 5' TVD 2660 Tubing PTD 1821770 Type Test SPT Test psi 1500 IA BBL Pumped: 0.7 - BBL Returned: 0.7 OA IntervalOTHER P/F P ✓ Notes: Retest ; MIT -IA for a calss 2 slurry well Pretest Initial 15 Min 30 Min 45 Min 60 Min 620 - 620 - 620 - 620 - 90 7810 1710 1690 9 _-14 - 14 14 Wednesday, June 26, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg2p DATE: Monday, July 8, 2019 P.I. Supervisor I 1 j 10jq SUBJECT: Mechanical Integrity Tests 1 CmocoPhillips Alaska, Inc. WSW -06 FROM: Lou Laubensteln KUPARUK RIV UNIT WSW -06 Petroleum Inspector Sre: Inspector Reviewed By: c-1.- y�> P.I. Supry `>I`p — NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW -06 API Well Number 50-029-20851-00-00 Inspector Name: Lou Laubenstein Permit Number: 182-177-0 Inspection Date: 6/10/1019 i Insp Num: mitLOL190611084251 Rel Insp Num: Monday, July 8, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WSW -06 - Type Inj S , TVD 2660 - Tubing 620 620 620 6m - --- PTD 1821770 Type Test SPT Test psi 1500 IA 90 1800 ' 1640 1610 - BBL Pumped: 2 BBL Returned: 0.8 - OA 10 14 14 - la - Interval OTHER P/F P - -- - - -- - - Notes: MIT -IA for a Class 2 slurry well ✓ Monday, July 8, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 29,2017 TO: Jim Regg (Rt. �/ P.I.Supervisor 1((7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. WSW-06 FROM: Lou Laubenstein KUPARUK RIV UNIT WSW-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW-06 API Well Number 50-029-20851-00-00 Inspector Name: Lou Laubenstein Permit Number: 182-177-0 Inspection Date: 6/25/2017 Insp Num: mitLOL170625163115 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WSW-06 ' Type Inj S 'TVD 2660 - Tubing 975 975 " 975 - 975 - PTD 1821770 Type Test SPT Test psi 1500 - IA 670 1700 ' 1625 - 1620 - BBL Pumped: 0.3 ' BBL Returned: 0.7 - OA 40 45 45 • 45 - Interval OTHER P/F P ✓ Notes: 2 Year MITIA Class 2 disposal well eTe atiAL 1(V SCANNED AUG 2 220u, Thursday,June 29,2017 Page 1 of 1 • • Loepp, Victoria T (DOA) From: Wallace,Chris D(DOA) Sent: Wednesday, February 08, 2017 8:52 AM To: Loepp,Victoria T(DOA) Subject: FW: KRU 1B-WSW-06(PTD#182-177) Report of IA pressure anomaly Attachments: MIT KRU 1B WSW-06 diagnostic MIT1A 02-06-17.xlsx;WSW-06 schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged ft 2.017, SCkti DK MA, Does CPAI need to submit more documentation?Or should they have submitted documentation for the work? Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent:Tuesday, February 07,2017 4:25 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>;Senden, R.Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 1B-WSW-06(PTD#182-177) Report of IA pressure anomaly Chris, Diagnostics were done and identified the Isosleeve @ 2925'was leaking. The Isosleeve was pulled,the seals redressed including adding some more AVA seals to the sleeve. A passing MITIA was done with Slickline to verify that integrity had been restored. The sleeve was already in the well so no new additional equipment was required to regain integrity. Attached is a copy of the MITIA that was performed by the Slickline crew and a wellbore schematic for reference. ConocoPhillips would like to be able to re-instate Class II disposal injection back into the well. Please advise on any paperwork or requirements that may be required to return the well to injection. Please let me know if you have any questions. Brent Rogers/Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Cell Phone(907) 394-0402 WELLS TEAM canoaphimips 1 • • PTD l g2 - J 7- From: NSK Problem Well Supv Sent:Thursday,September 22,2016 8:02 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: KRU 1B-WSW-06(PTD#182-177) Report of IA pressure anomaly Chris, KRU 1B-WSW-06(PTD#182-177)Class II Disposal well was reported for exhibiting suspect IA pressure swings around midnight on 9-22-16. DHD was mobilized to perform diagnostics and the well failed an MIT-IA and inner casing pack off testing. The well has been shut in and freeze protected and CPAI plans to set a tubing plug to secure the well. Diagnostics will continue to determine the leak mechanism and facilitate evaluation of potential repair options. Upon conclusion of the diagnostics a follow up email with the plan forward and any required paperwork for corrective action or continued injection will be submitted. A wellbore schematic is attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM Conoca'P1tilYps 2 • S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaatalaska.aov AOGCC.InspectorsMalaska.aov phoebe.brooks(ialaska.aov chris.wallacenalaska.aov OPERATOR: ConocoPhillips Alaska Inc. FIELD/UNIT/PAD: Kuparuk/KRU/1B DATE: 02/06/17 OPERATOR REP: Burley-HES AOGCC REP: • Well WSW-06 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821770 Type Inj N Tubing 275 300 300 300 300 300 Type Test P Packer TVD 2660 BBL Pump IA 300 1720 1640 1630 1630 1630 Interval 0 Test psi 1500 BBL Return OA 0 0 0 0 0 0 Result P Notes: Diagnostic MBIA Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing _ Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA - Result No s: Well Prr+crelres: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA MIS: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result mem: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass O=Gas O=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT URU in WSW-06 diagnostic MITIA 02-0e-17.6su w 0 KUP DISP11110 WSW-06 ConocoPhillips ; Well Attributes Max Angle&MD TD :ll.l�-. 'I.I.. Wellbore API/UWI Field Name Wellbore Status ncl(1) MD(1tKB) Act atm(ftKB) Lou t.rlkt5 500292085100 SHALLOW SANDS DISP 35.52 2500.00 3,835.0 .,. Comment H2S(ppm) Date Annotation End Date KB-Grd(6) Rig Rebase Date WSW-06,9/2/201512:34:35 PM SSSV:NONE Last WO: 41.01 11/11/1982 Verbal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,714.0 2/11/2015 Rev Reason:PULL IBP,SET SLV 8 SLIPSTOP hipshki 9/2/2015 HANGER;292 Ni Casing Strings Casing Description OD(in) ID(in) Top MMB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(2..Grade Top Thread CONDUCTOR 16 15.062 39.0 80.0 80.0 65.00 H-40 WELDED _ Casing Description OD(in) ID(in) Top)ftKB) 'Set Depth(MB) Set Depth(TVD)...Mien(I...Grade Top Thread L,..., r SUR.CASING 103/4 9.950 35.1 2,448.5 2,228.1 45.50 K-55 Buttress 1 Thread Casing Description OD(In) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Warm(I...Grade Top Thread 1 PROD.CASING 7 6.276 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings Tubing Description String Ma...ID(in) Top(BOB) Set Depth(ft..J Set Depth(TVD))...IWI(Ib/ft) (Grade Top Connection v TUBING-GRAVEL 3 1/2 2-992 29.2 3,559.6 3,187.7 9.20 K-55 BTC --'�CONDUCTOR;39.080.0' `Y J'. l PACK Completion Details Nominal ID Top(M8) Top(TVD)(BOB) Top Incl r) Item Des Can (in) 29.2 29.2 0.02 HANGER FMC TUBING HANGER 2.992 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.660 2,965.6 2,659.2 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 1 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL'S'PERFORATED GRAVEL 4.400 SUR.CASING;35.1-2,4455-• t PACK PACKER EXTENSION 2,976.0 2,668.3 30.06 SBR SEAL BORE RECEPTACLE 4.000 SLIPSTOP;2,923.4 2,977.5 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 I_l ISO SLEEVE;2,925.4 f�i 2,982.9 2,674.3 30.00 SAFETY JT SHEAR OUT SAFETY JOINT 2.992 NIPPLE;2,925.4 7` 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 0-RING BAKER 0-RING SEAL SUB 1.500 3,546.3 3,175.6 25.10 SCREEN BAKERWELD.006 TELL TALE SCREEN 2.992 LOCATOR;2,985.6 3,556.1 3,184.5 25.03 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 PACKER,28561 ft 3,557.0 3,185.3' 25.02 SUMP BAKER MODEL F-1 SUMP PACKER 4.000 EXTENSION;2,9703 • PACKER 988;2,976.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl EXTENSION;2,977.5 *IdiTop(ftKB) (ftKB) (°) Des Com Run Date ID(in) XO THREAD;2,982.1 2,923.4 2,622.9 30.56 SLIPSTOP SLIPSTOP 9/1/2015 2,925.4 2,624.6 30.54 ISO SLEEVE 2.81"z 1.0"ISO SLEEVE 9/1/2015 1.000 Perforations&Slots Shot I Dens Top(PID) Ben(T1/0) (sirotsH ' Top(BOB) Btm(59KB) (f0(13) (ftKB) Zone Date t) Type Corn I3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing (PERF;3,160.03,208.0 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, 11/7/1982 12.0 (PERF Vann Guns,60 deg. WSW-06 phasing I• 3,256.0 3,281.0 2,914,5 2,936.8 UGNU C, 110/1982 12.0 IPERF Vann Guns,60 deg. (PERF;3,216.03,222.0 I I WSW-06 phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, 11/7/1982 12.0 (PERF Vann Guns,60 deg. __ WSW-06 phasing (PERF;3,256.03,281.0-' 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, 1177/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing - - 3,352.0 3,370.0 3,000.4' 3,016.5 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. IPERF;3,290.03,308.0- - WSW-06 phasing SCREEN;3,116.1 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. IPERF;3,336.03,340.0_ _.. WSW-06 phasing - -- 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing /PERF;3,352.03,370.0 . 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating chg,triphase IPERF;3,385.03,5060-- 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating chg,triphase IPERF;3,519.03,5400 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w - I - WSW-06 15.5.gram penetrating chg,triphase 0-RING;3,545.7 t 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating SCREEN;3,548.3 chg,triphase SNAP LATCH;3,558.1 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, 3/3/2015 6.0 APERF Deep Star Strip Gun w SUMO PACKER;3,537.0 a WSW-06 15.5.gram penetrating chg,triphase UGNU B, 6.0 Deep Star Strip Gun w - ._ WSW-06 1.5.gram penetrating APERF;3,580.03,B00.0- -..-. chg,triphase APERF;3800.0-6620.0--. Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Ben(ftKB) (RKB) (ROB) Des Start Date Com APERF;3,570.04.680.0 41.0 120.0 41.0 120.0 Remedial 11/2/1982 Cement Squeeze APERF;3,890.03,710.0 APERF;3,7t0.03,720.0--/- PROD.CASING;32.33620.0-/ • • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, February 08, 2017 11:16 AM To: NSK Well Integrity Supv CPF1 and 2 Cc: Senden, R.Tyler Subject: RE: KRU 1B-WSW-06 (PTD# 182-177) Report of IA pressure anomaly Brent, Looking at our data,the Sundry report 10-404 for sundry 314-605 dated 4/29/15, shows the wellbore schematic dated 3/10/2015-that doesn't have the Isosleeve. Our records show the witnessed MITIA of 1/17/2016 and a solids free disposal of 4 year cycle or slurry disposal of 2 year cycle. My understanding is the next scheduled 1B pad testing month is June 2017, so this well will probably be tested in June 2019. The email dated 9/22/2016 reporting the Tubing to IA pressure anomaly, has the Wellbore schematic dated 9/2/2015 showing the Isosleeve. The requirements for sundry reporting and MITIA witness when tubing is replaced is more obvious than a changing of the Isosleeve. Due to the Isosleeve probably being the cause of the Tubing x IA pressure anomaly,this probably triggers a 10-404 so that we can capture any changes and get a correct wellbore. However, I will print out the most recent wellbore schematic and you are approved for return to injection. No additional requirements. Please note the 02/06/2017 non-witnessed MITIA will not reset the 4 year MITIA requirement as there is no indication that we were notified to witness or waived witness etc. SCANNED FEB 0 8 2017 Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent:Tuesday, February 07, 2017 4:25 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>; Senden, R.Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 1B-WSW-06(PTD#182-177) Report of IA pressure anomaly Chris, • • • Diagnostics were done and identified the Isosleeve @ 2925'was leaking. The Isosleeve was pulled,the seals redressed including adding some more AVA seals to the sleeve. A passing MITIA was done with Slickline to verify that integrity had been restored. The sleeve was already in the well so no new additional equipment was required to regain integrity. Attached is a copy of the MITIA that was performed by the Slickline crew and a wellbore schematic for reference. ConocoPhillips would like to be able to re-instate Class II disposal injection back into the well. Please advise on any paperwork or requirements that may be required to return the well to injection. Please let me know if you have any questions. Brent Rogers/Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Cell Phone(907)394-0402 ipliWELLS TEAM From: NSK Problem Well Supv Sent:Thursday,September 22,2016 8:02 PM To:Wallace,Chris D(DOA)<chris.wallace(a@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: KRU 1B-WSW-06(PTD#182-177) Report of IA pressure anomaly Chris, KRU 1B-WSW-06(PTD#182-177)Class II Disposal well was reported for exhibiting suspect IA pressure swings around midnight on 9-22-16. DHD was mobilized to perform diagnostics and the well failed an MIT-IA and inner casing pack off testing. The well has been shut in and freeze protected and CPAI plans to set a tubing plug to secure the well. Diagnostics will continue to determine the leak mechanism and facilitate evaluation of potential repair options. Upon conclusion of the diagnostics a follow up email with the plan forward and any required paperwork for corrective action or continued injection will be submitted. A wellbore schematic is attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM Conocaisisps 2 • • F KUP DISP • WSW-06 Conoco fillips = Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm((MB) r..,o,,alh,p, 500292085100 SHALLOW SANDS DISP 35.52 2,500.00 3,835.0 ^• ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date WSW-00,9/2/201512'.3435 PM SSSV'.NONE Last WO: 41.01 11/11/1982 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3.714.0 2/11/2015 Rev Reason:PULL IBP,SET SLV 8 SLIPSTOP hipshkf 9/2/2015 HANGER,29.2--.1M Casing Stnngs Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 39.0 80.0 80.0 65.00 H-40 WELDED 1111 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(ND)... WtlLen(I...Grade Top Thread SUR.CASING 103/4 9.950 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread PROD.CASING 7 6276 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt(lb/ft) Grade Top Connection -1',1\-1‘CONDUCTOR,39.0-80 0• �TUBINGPACK -GRAVEL 31/2 2.992 29.2 3,559.6 3,187.7 9.20 K-55 BTC Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com (in) / 1 29.2 29.2 0.02 HANGER FMC TUBING HANGER 2.992 J 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.660 2,965.6 2,6592 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 II 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL'S'PERFORATED GRAVEL 4.400 SUR.CASING;36.1-2,415.5 I. PACK PACKER EXTENSION 2,976.0 2,668.3 30.06 SBR SEAL BORE RECEPTACLE 4.000 SLIPSTOP;2,923.4 2,877.5 0 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 150 SLEEVE;2,820.4 2,982.9 2,674.3 30.00 SAFETY JT SHEAR OUT SAFETY JOINT 2.992 NIPPLE;2,925.4 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 3,545.7 3,175.1 25.11 0-RING BAKER O-RING SEAL SUB 1.500 LOCATOR;2,805.0 3,546.3 3,175.6 25.10 SCREEN BAKERWELD.006 TELL TALE SCREEN 2.992 3,556.1 3,184.5 25.03 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 PACKER;2,800.1 3,557.0 3,185.3 25.02 SUMP BAKER MODEL F-1 SUMP PACKER 4.000 EXTENSION;2,970.3 PACKER SBR;2,076.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl EXTENSION;2,977.5 Top(ftKB) )ftKB) (°) Des Com Run Date ID(in) XO THREAD;2,9821 2.923.4 2,622.9 30.56 SLIPSTOP SLIPSTOP 9/1/2015 2,925.4 2,624.6 30.54 ISO SLEEVE 2.81"x 1.0"ISO SLEEVE 9/1/2015 1.000 Perforations&Slots Shot Dana Top(TVD) Btm(TVD) (shotalf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3,180.0.3,208.0 3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, 11/7/1982 12.0 (PERF Vann Guns,60 deg. - WSW-06 phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. IPERF;3,210.0-3,222.0 WSW-06 phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3,250.09,281.0 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3,290.0-3,305.0- 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing SCREEN;3,116.1 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3,338.0-3,340.0 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3952.0-3,370.0- 3,580.0 3,600.0 3,206.2 3,224.3 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w I WSW-06 15.5.gram penetrating chg,triphase IPERF;3,35503,500.0-• 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating chg,triphase IPERF;3,519.0-3,540.0- 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating chg,triphase 0-RING;9545.7 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating SCREEN;3,540.3 chg,triphase SNAP LATCH;3,550.1 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, 3/3/2015 ' 6.0 APERF Deep Star Strip Gun w SUMP PACKER;3957.0 - WSW-06 15.5.gram penetrating __ chg,triphase UGNU B, 6.0 Deep Star Strip Gun w i WSW-06 1.5.gram penetrating APERF;3,500.05,000.0 chg,triphase APERF;3,000.03,020.0-- Cement Squeezes Top(ND) Blot(TVD) Top(ftKB) BM,(ftKB) )ftKB) (ftKB) Des Start Date Com APERF;3,070.03,890.0- 41.0 120.0 41.0 120.0•Remedial 11/2/1982 .- Cement Squeeze APERF;9,890.03,710.0- APERF;3,710.03,720.0- 7- PROC CASING,32 3-3 820.0--. • . Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, September 22, 2016 8:02 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: KRU 1B-WSW-06 (PTD# 182-177) Report of IA pressure anomaly Attachments: WSW-06.pdf Chris, KRU 1B-WSW-06(PTD#182-177)Class II Disposal well was reported for exhibiting suspect IA pressure swings around midnight on 9-22-16. DHD was mobilized to perform diagnostics and the well failed an MIT-IA and inner casing pack off testing. The well has been shut in and freeze protected and CPAI plans to set a tubing plug to secure the well. Diagnostics will continue to determine the leak mechanism and facilitate evaluation of potential repair options. Upon conclusion of the diagnostics a follow up email with the plan forward and any required paperwork for corrective action or continued injection will be submitted. A wellbore schematic is attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM Conoalhillips SCMOR JAM 1 7 DI • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,January 25,2016 Supervisor C TO: Jim Rp121-Z zI�� SUBJECT: Mechanical Integrity Tests P.I.P CONOCOPHILLIPS ALASKA INC WSW-06 FROM: Johnnie Hill KUPARUK RIV UNIT WSW-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJIa(2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW-06 API Well Number 50-029-20851-00-00 Inspector Name: Johnnie Hill Permit Number: 182-177-0 Inspection Date: 1/17/2016 Insp Num: mitJWH160121151053 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WSW-06 , Type Inj D" TVD 2660 - Tubing 600 600- 600 r 600 PTD 1821770 - ,Type Test SPT Test psi 1500 - IA 880 1700 . 1660 1660 al INITAL AL P/F P ✓ OA 345 430 , 450 470. Notes: 0.4 bbls diesel used Monday,January 25,2016 Page 1 of 1 t1 WELL LOG TRANSMITTAL DATA LOGGED et/2112015 K BENDER To: Alaska Oil and Gas Conservation Comm. September 14, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 t 22 RE: Plug Setting Record: WSW-06 Run Date: 8/17/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com WSW-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20851-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton ..._. Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518CANN } r, W. Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: M�4�� u P 2) /82 -/777 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, May 12, 2015 10:54 AM To: 'Huck, Drew' Subject: RE:WSW-06(PTD 182-177, Sundry 314-605) Drew, Injection may begin on this well. A State witnessed MIT-IA is required after stabilized injection or within two weeks of starting injection. Thanx, Victoria Victoria Loepp SCANNED ,I UN ji 8 2015 Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp©alaska.gov From: Huck, Drew [mailto:Andrew.Huck@conocophillips.com] Sent: Monday, May 11, 2015 5:12 PM To: Loepp, Victoria T(DOA) Cc: Hunter, Lindsey L Subject: WSW-06 and new SPOC Victoria, First, I wanted to let you know that I will be the new single point of contact for the 1B Class II Disposal wells at the Kuparuk River Unit taking over from Lindsey Hunter. Second, I wanted to ask about the 10-403 and the following 10-404 that was submitted for 1B-WSW-06(PTD 182-177, Sundry 314-605). Looking at the 10-403,we had requested to return the well to injection and I wanted to make sure that after receiving the 10-404,you had all of the information you needed; I believe I submitted everything consistent with what was done for 1B-WSW-05. At this point, is there anything else you need,or can we begin injection in the well? Regards, 1 Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) 2 STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Return to Injection Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r-Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182-177 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20851-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25648 KRU WSW-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CCL Kuparuk River Field/Lower Tertiary(Upper Ugnu) 11.Present Well Condition Summary: Total Depth measured 3885 feet Plugs(measured) None true vertical 3486 feet Junk(measured) None Effective Depth measured 3885 feet Packer(measured) 2966, 3557 true vertical 3486 feet (true vertical) 2660, 3185 Casing Length Size MD TVD Burst Collapse CONDUCTOR 41 16 80 80 SUR.CASING 2413 10.75 2449 2228 PROD.CASING 3788 7 3820 3426 RECEIVED MAY 042015 Perforation depth: Measured depth: 3160-3540, 3580-3620, 3670-3720 OAR /"� 1g 2015 OG V V True Vertical Depth: 2829-3170, 3206-3224, 3288-3334 S Tubing(size,grade,MD,and TVD) 3.5, K-55, 3560 MD,3188 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER @ 2966 MD and 2660 TVD SUMP PACKER-BAKER MODEL F-1 SUMP PACKER @ 3557 MD and 3185 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 not applicable Subsequent to operation not applicable 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service jd Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt 314-605 Contact Drew Huck @ 265-6828 Email Andrew.Huck@cop.com Printed Name Drew Huck Title Drilling Engineer Signature QQ�� ?it,/ Phone:265-6828 Date !-,1/2 egis- ¢ I �i �w� RBDMS MAY - 6 2015 vri_ VIForm 10-404 Revised 10/2012 Submit Original Only Mt KUP DISP WSW-06 ConocoPh1 ips 9 Well Attributes IMaz Angle&MD TD Alaska,Inc. Wellbore AP7/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) r,ev s.d'h,Wp, 500292085100 SHALLOW SANDS DISP 35.52 2,500.00 3,835.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date WSW-06,3/1020152:10:47 PM SSSV:NONE Last WO: 41.01 11/11/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,714.0 2/11/2015 Rev Reason:PERFORATE hipshkf 3/10/2015 HANGER;29.2 Ip i Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 39.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -c SUR.CASING 103/4 9.950 35.1 2,448.5 2,228.1 45.50 K-55 Buttress Thread 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PROD.CASING 7 6.276 32.3 3,820.0 3,426.0 26.00 K-55 Buttress f Thread ' 'M"Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(IbMt) Grade Top Connection .M�CONDUCTOR;39.0410.0 ,Ir. II.. PACK G-GRAVEL 3 12 2.992 29.2 3,559.6 3,187.7 9.20 K-55 BTC Completion Details iNominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 29.2 29.2 0.02 HANGER FMC TUBING HANGER 2.992 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.990 2,965.6 2,6592 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL'S'PERFORATED GRAVEL 4.400 PACK PACKER EXTENSION SUR.CASING;35.1.2,4485- : A 2,976.0 2,6683 30.06 SBR SEAL BORE RECEPTACLE 4.000 2,977.5 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 NIPPLE;2.925,4 1 2,982.9 2,674.3 30.00 SAFETY JT SHEAR OUT SAFETY JOINT 2.992 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 LOCATOR;2,965.6 _ 3,545.7 3,175.1 25.11 0-RING BAKER 0-RING SEAL SUB 1.500 PACKER;2,9661 s-r 3,546.3 3,175.6 25.10 SCREEN BAKERWELD.006 TELL TALE SCREEN 2.992 v u EXTENSION;2,970.3 Z �. 3,556.1 3,184.5 25.03 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 SBR:2,9760 3,557.0 3,185.3 25.02 SUMP BAKER MODEL F-1 SUMP PACKER 4.000 PACKER EXTENSION.2.977.5 '*i Perforations&Slots SO THREAD;2,982.7 �s Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 3,160.0 3,208.0 2,829.2 2,871.8 K-15 Marker, 11/7/1982 12.0 (PERF Vann Guns,60 deg. WSW-06 phasing I3,216.0 3,222.0 2,878.9 2,884.2 K-15 Marker, 11/7/1982 12.0 IPERF Vann Guns,60 deg. I WSW-06 phasing 3,256.0 3,281.0 2,914.5 2,936.8 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. •IPERF;3.160.0-3.208.0 WSW-06 phasing 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. • • WSW-06 phasing • • • - - 3,336.0 3,340.0 2,986.0 2,989.6 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. IPERF;3,216.0-3.222A-. WSW-06 phasing 3,352.0 3,370.0 3,000.4 3,016.5 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing IPERF;3,256.0.3,281 0- 3,385.0 3,506.0 3,030.0 3,139.2 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing (PERF;3,290.0-3,308.0 3,519.0 3,540.0 3,150.9 3,169.9 UGNU B, 11/7/1982 12.0 IPERF Vann Guns,60 deg. WSW-06 phasing SCREEN;3,11E1 3,580.0 3,600.0 3,206.2' 3,224.3 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w (PERF;3,336.0.3,340.0 WSW-06 15.5.gram penetrating chg,triphase 3,600.0 3,620.0 3,224.3 3,242.5 UGNU B, 3/6/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating IPERF;3.3520.3,370.0 chg,triphase 3,670.0 3,690.0 3,288.2 3,306.5 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating IPERF;3,385.0.3,506.0 chg,triphase • 3,690.0 3,710.0 3,306.5 3,324.9 UGNU B, 3/5/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating (PERF;3,519.0.3,540.0 chg,triphase 3,710.0 3,720.0 3,324.9 3,334.1 UGNU B, 3/3/2015 6.0 APERF Deep Star Strip Gun w WSW-06 15.5.gram penetrating 0-RING;3.5457 ( chg,triphase SCREEN;3.546.3UGNU B, 6.0 Deep Star Strip Gun w 1 WSW-06 1.5.gram penetrating SNAP LATCH;3.556.11- air chg,triphase IMM SUMP PACKER:3.557.0 f Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 41.0 120.0 41.0' 120.0 Remedial 11/2/1982 APERF;3,580.0-3,6000- Cement Squeeze APERF;3,600.0-3,6200 APERF;3,6700-3,6900- APERF;3,690.0.3,710.0- APERF;3,710.0.3,720.0 PROD.CASING;32b3,820.0- WSW-06 WELL WORK SUMMARY DATE' SUMMARY 12/25/2014 DRIFTED TBG TO 3545' RKB WITH DUMMY MOTOR& MILL. MEASURED BHP @ 3545' RKB 1408 PSI. READY FOR CTU. 2/4/2015 VERY LATE START DUE TO CT TRACTOR FUEL PUMP ISSUES, MIRU CTU, JOB IN PROGRESS. 2/5/2015 RIH TO MILL 0-RING SUB FROM 3530' CTMD TO 3540' CTMD WITH A 2.0"TAPERED MILL, RUN#2 MILLING SAME AREA WITH A 2.40"TAPERED MILL, F/P TBG TO 3500'CTMD, RETURN IN AM FOR FCO, JOB IN PROGRESS. 2/6/2015 COMPLETED WEEKLY BOP TEST, PERFORM FILL CLEANOUT TO 7" FLOAT COLLAR ASSEMBLY AT 3726' CTMD USING SLICK DIESEL WITH DIESEL GEL SWEEPS AT 1.7 BPM WHILE MAINTAINING 1:1 RETURNS, LIGHT SAND CONCENTRAIONS OBSERVED IN RETURNS, WELL LEFT F/P TO 3726'CTMD, READY FOR S/L DRIFT, JOB IN PROGRESS. 2/8/2015 DRIFT TBG W/2.29"CENT, TAG FILL @ 3714' SLM (3721' RKB); BAIL FINE SAND/METAL SHAVINGS DOWN TO 3725' RKB. JOB SUSPENDED 2/10/2015 BAIL FINE SAND FROM 3712-3718' SLM. IN PROGRESS 2/11/2015 BAIL FILL FROM 3712-3719'SLM (3726'RKB); DRIFT W/DMY PERF GUN TO 3726' RKB. TURN OVER TO E-LINE. 2/28/2015 LOG CORRELATION AND JEWELRY PASS. STOP JOB DUE TO WEATHER. JOB IN PROGRESS. 3/3/2015 PERFORATE FROM 3720'TO 3710' USING 2.125"TRI PHASE DEEP STAR STRIP GUN LOADED WITH 15.5 GRAM DEEP PENETRATING CHARGES. CCL TO TOP SHOT: 9.5', CCL STOP DEPTH: 3700.5'. LOG CORRELATED TO SLB CBL DATED AUG 11, 1998. IN PROGRESS. 3/5/2015 PERFORATED INTERVAL 3690 THRU 3710 WITH A DEEP STAR PERFORATING GUN. MADE PERFORATION AT CCL STOP DEPTH OF 3680.5'WITH A CCL TO TOP SHOT OFFSET OF 9.5'. PERFORATED INTERVAL 3670 THRU 3690 WITH A DEEP STAR PERFORATING GUN. MADE PERFORATION AT CCL STOP DEPTH OF 3657.5'WITH A CCL TO TOP SHOT OFFSET OF 12.5'. 3/6/2015 PERFORATED INTERVAL 3600'THRU 3620'WITH DEEP STAR PERFORATING CHARGES. PERFORATE AT CCL STOP DEPTH OF 3590.5'WITH A CCL OFFSET OF 9.5'. PERFORATED INTERVAL 3580'THRU 3600'WITH DEEP STAR PERFORATING CHARGES. PERFORATE AT CCL STOP DEPTH OF 3570.5'WITH A CCL OFFSET OF 9.5'. READY FOR LRS/SL. 4/5/2015 SET 2.81" ISO SLEEVE (1" ID) @ 2925' RKB; SET SLIP STOP ON ISO SLEEVE; MIT IA TO 1700# (PASS), READY FOR INJECTIVITY TEST. 4/20/2015 PERFORM INJECTIVITY TEST TO 5BBLS/MIN (JOB COMPLETE) i I Ln N 14 o - Ti• 1 Ill 1 O 1 N Li-) - co N 1 Cr 1 t I0 00 d I- o 1 0 `' o R3CU _ fQ � Cr; •R i a N . ca42 N o 1 0 N +' CU Al _ o a CC N c + ` Ln •> 1 - ,� .470 U C! O _ o O ♦ .-I • VI • ♦ ISII/11411 _ IM111111 _ o i I ' o o o LD d' o o CO L Tr N N N N .-I .--I e--I (Pisd) [aw,tLS`E]Cl/J.,ZZZ`E @ dH8 pa;einDieD 2-551 G WELL LOG TRANSMITTAL DATA LOGGED 325/2015 vi.K.BENDER To: Alaska Oil and Gas Conservation Comm. March 9, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 'RECEIVED MAR 24 ?Oh RE: Perforation Record &Jewelry Log: WSW-06 Run Date: 2/28/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com WSW-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20851-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6—e4f-eeet Imag'~[~Project Well History File Cover Page 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. j ~ ~:;'~- J _/~/Z Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [] Diskettes, No, [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: ~F1 Logs. of various kinds [] Otb er Project Proofing BY: ~ BREN VINCENT SHERYL MARIA LOWELl. Scanning Preparation ~ / x 30 = .~ + ~/ = TOTAL PAGES Production Scanning Stage '1 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES '~......,..,~ Stage 2 IF NO IN STAGE 1, PAGE(S)DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCENT~ MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDiVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCN.E OR COLOR IMAGES) NO NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd . • t-l� • � 'icl� �� ,� i5 Ferguson, Victoria L (DOA) u'�t) From: Hunter, Lindsey L <Lindsey.Hunter @conocophillips.com> Sent: Friday, October 25,2013 1:26 PM To: Ferguson,Victoria L(DOA) Subject: RE:WSW-03(PTD182-142, Sundry 313-27 WSW-06(PTD182-177, Sundry 313-268),WSW-07(PTD182-188, Sundry 313-26 �, Victoria, I'm sorry I haven't sent the information on these yet. We are still trying to decide what direction we want to go with these wells. For now I guess we can withdraw the sundries while we finalize our plans and we will re-submit when the decisions are made. Thanks, Lindsey SCANNED } ) r1 Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunte crconocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent: Friday, October 11, 2013 12:07 PM To: Hunter, Lindsey L Subject: [EXTERNAL]WSW-03(PTD182-142, Sundry 313-270), WSW-06(PTD182-177, Sundry 313-268),WSW- 07(PTD182-188, Sundry 313-267), Lindsey, Please send me an email to withdraw these sundries or information to finish processing. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson a(�,alaska.gov 1 RBDMS OCT 2 9 2 STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMMI•N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 1 Rug for Redrill r Perforate New Pool — Repair w ell r Change Approved Pr'.gram r Suspend Rug r Perforate r Pull Tubing r Time tension r p Plu Perforations Operational Shutdown (` Re-enter Sus- P•Well 1--- Stimulate r Alter casing r Other:Return to, 'jection P • 2.Operator Name: 4.Current Well Class: 5.Permit to Dri umber: ConocoPhillips Alaska,Inc. Development r Exploratory r 182-177'.. 3.Address: Stratigraphic r Service W., 6.API Nu ber: P.O. Box 100360,Anchorage,Alaska 99510 • 0-029-20851-00 • 7.If perforating, 8.Well Name and Number::' What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No : WSW-06 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25648 , Kuparuk River Field/Lower Tertiary(Upper Ugn '• 11. PRESENT WELL CONDITION SUMMAR -' Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(meas ed): Junk(measured): 3885 • 3486. Casing Length Size MD D Burst Collapse CONDUCTOR 41 16 80' /80 SUR.CASING 2413 10.75 2449' 2228' RECEIVF PROD.CASING 3788 7 3821' 3426' 11AY 3 0 Z013 Perforation Depth MD(ft): Perforation Depth TVD 1 • Tubing Size: Tubing Grade: Tubing MD(ft): • from 3160'-3540' 2829'-3170' 3.5 K-55 3560 Packers and SSSV Type: ••cker-an.SSSV MD(ft)and TVD(ft) PACKER-BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER ' o_ -•6r TVD=2660 SUMP PACKER-BAKER MODEL F-1 SUMP PACKER D 3 7 TVD=3185 NO SSSV 12.Attachments: Description Summary of Propos- p 1.. Well Class after proposed work: Detailed Operations Program )" BOP Sk:tc Exploratory r Stratigraphic F Development r Service f . 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil F Gas r WDSPL ✓ . Suspended F 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR F SPLUG F 17. I hereby certify that the foregoing is true and corn ct to the best of my knowledge. Contact: Lindsey Hunter @ 265-6427 Email: Lindsey.Hunteracop.com Printed Name L• t a unter Title: Drilling Engineer Signature r ,; Phone:265-6427 Date S 2..// 3 Commission Use Only Sundry Number:3 5 �(f_Z/n� Conditions of approval: Notify Commission so that a representative may witness Plug Integrity I— BO- est r Mechanical Integrity Test r Location Clearance r Other: Spacing Excep•.n Required? Yes ❑ No [6 Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Approved application is valid for 12 months trom the date of approval. Form 10-403(Revised 10/2012) oRIGIN ,k , Submit Form and Attachments in Duplicate n\111 \\ KUP WSW-06 COnocoPhiliips -' Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/DWI Field Name Well Status Inc'(°) MD(ftKB) Act Btu(ftKB) car GPs eups 500292085100 SHALLOW SANDS DISP 35.52 2500.00 3,835.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NONE Last WO: 41.01 11/11/1982 Well Cents:-WSW-06,5/7!2013 8:23:34 AM Schemallc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 3,557.0 11/11/1982 Rev Reason:WELL REVIEW osborl 5/7/2013 HANGER,29 - Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f.,.Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 39.0 80.0 80.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SUR.CASING 10 3/4 9.950 35.1 2,448.5 2,228.2 45.50 K-55 Buttress Thread Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt.,.String...String Top Thrd PROD.CASING 7 6.276 32.3 3,820.0 3,426.0 26.00 K-55 Buttress Thread Tubing Strings Tubing Description String 0...{String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING-GRAVEL 31/2 I 2.992 29.2 3,559.6 3,187.8 9.20 K-55 ETC PACK Corn rletionDetails yf Top Depth (TVD) Top Inc! Nomi... Top(ftKB) (ftKB) F) Item Description Comment ID(in) CONDUCTOR, 29.2 29.2 -0.01 HANGER FMC TUBING HANGER 2.992 39-80 Remedial 2,925.4 2,624.6 30.54 NIPPLE NATIONAL JET PUMP PROFILE NIPPLE BHA 2.990 Cement , Squeeze.4t `-; 2,965.6 2,659.3 30.16 LOCATOR BAKER LOCATOR 4.000 2,966.1 2,659.7 30.16 PACKER BAKER 70B2-40 SC1-L1 GRAVEL PACK PACKER 4.000 2,970.3 2,663.3 30.12 EXTENSION BAKER 80-40 MODEL'S'PERFORATED GRAVEL PACK PACKER 4.400 EXTENSION 2,976.0 2,668.3 30.06 SBR SEAL BORE RECEPTACLE 4.000' 2,977.5 2,669.6 30.05 EXTENSION LOWER CASING EXTENSION 4.400 2,982.9 2,674.3 30.00 SAFETYJT SHEAR OUT SAFETY JOINT 2.992 I ; 3,116.1 2,790.5 28.41 SCREEN BAKERWELD GRAVEL PACK SCREEN 2.992 I 3,545.7 3,175.3 25.45 0-RING BAKER 0-RING SEAL SUB 1.500 3,546.3 3,175.8 25.44 SCREEN BAKERWELD.006 TELL TALE SCREEN 2.992 ,$ 3,556.1 3,184.7 25.30 SNAP LATCH BAKER 80-40 MODEL E-22 SNAP LATCH 2.985 3,557.0 3,185.5 25.29 SUMP BAKER MODEL F-1 SUMP PACKER 4.000 SUR.CASING, PACKER 35-2,449 Perforations&Slots NIPPLE,2,925 " Shot 1.. Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date loft- Type Comment LOCATOR, 3,160.0 3,208.0 2,829.3 2,872.4 K-15 Marker, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing 2,966 WSW-06 PACKER,2.986 ` 3,216,0 3,222.0 2,879.4 2,884.7 K-15 Marker, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing EXTENSION, WSW-06 2,970 r ,. ,' 3,256.0 3,281.0 2,914.7 2,936.9 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing 565,2,976 WSW-06 EXTENSION. __- 3,290.0 3,308.0 2,944.9 2,960.9 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing 2,e78 WSW-06 XO THREAD. 2'962 3,336.0 3,340.0 2,986.1 2,989.7 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing WSW-06 3,3520 3,370.0 3,000.5 3,016.6 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing WSW-06 TT1 3,385.0 3,506.0 3,030.0 3,139.9 UGNU C, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing WSW-06 -_ 3,519.0 3,540.0 3,151.4 3,170.2 UGNU B, 11/7/1982 12.0 IPERF Vann Guns,60 deg.phasing IPERF, WSW-06 iki 3,160-3,208 -= IPERF, 3,2153,222 IPERF, A 3,2563,281 IPERF, 3,290-3,306 SCREEN,3,116 IPERF, _=- - 3.3363,340 PERF, 3,352-3,370 IPERF, 3,3853,506 ''l IPERF, F=j-_ ii I E. 3,519-3,540 IPERF, - 0-RING.3.546 000 SCREEN,3,548 0 0 0 000 SNAP LATCH, J T 3,556 SUMP PACKER,3,557 PROD. CASING, 32-3,820 TD,3,835 Ferguson, Victoria L (DOA) �lJ - 0 • /? From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Wednesday, June 19, 2013 3:57 PM To: Ferguson, Victoria L(DOA) Cc: Wallace, Chris D(DOA); NSK Fld Drlg Supv; Jolley, Liz C Subject: RE: ConocoPhillips Water Source Step rate test SCANNED ) Victoria, Please see the information you requested below. I wanted to verify diesel was our preferred fluid for step rate tests with our field drilling supervisor before I responded, which is why you received the email today. From now on you can consider me the single point of contact for this project, I apologize for the confusion. "r•• - -------- WSW-02—PTD 182-137 1. MITIA's in 1989, 1993 and 1997 passed. Well was used to dispose of pigging fluid in 1991 and was not in use after 1991. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1710 psi on 5/9/13. 2. Plan forward for this well is to complete further investigation to see if it will be an adequate slurry injection well, this is the only well we are considering for slurry injection at this time, the rest of the WSWs will remain class 2 fluid disposal wells. Once the sundry is approved we plan to use this well to inject class two fluids while monitoring other well pressures on 1B pad to confirm that they are not in communication with this well. We would like to perform a step rate test before we begin injection,our preferred fluid is diesel. 3. We are currently verifying cement bond logs of surrounding 1B wells and confirming upper shale zone confining pressures from previous modeling results. We are currently working on a plan to monitor surrounding wells while using WSW-02 as a class 2 fluid disposal well to confirm that it will be an adequate slurry injector. We plan to submit all of our results when our studies are complete and the sundry requesting slurry service is submitted. WSW-03—PTD 182-142 1. MITIAs in 1988, 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-05—PTD 182-164 1. MITIAs in 1988, 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was used for pit dewatering from 1996- 2001,has not been used since 2001 but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 1 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-06—PTD 182-177 1. MITIAs in 1988, 1993 and 1997 passed. Well was never used for injection. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1690 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-07—PTD 182-188 1. MITIAs in 1993 and 1997 passed. Well was used for pit dewatering from 1997-2001 and was not in use after 2001. Well passed MITIA to 1700 psi on 4/27/13 and passed a state witnessed MITIA to 1735 psi on 5/9/13. 2. Plan forward is to use this well as a class 2 fluids disposal well. We would like to perform a step rate test before we begin injection, our preferred fluid is diesel. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. WSW-09—PTD 182-196 1. MITIAs in 1992, 1996, 2000, 2004, 2006, 2009 passed. Well was not used for injection but was kept current on its MITIA schedule. Well passed MITIA to 1715 psi on 3/29/12 and passed a state witnessed MITIA to 1700 psi on 5/9/13. A step rate test was performed on this well on 6/8/13 using diesel. 2. Plan forward is to use this well as a class 2 fluids disposal well. 3. We do not anticipate a need to use this well as a slurry injection well so no further testing will be performed. Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Wednesday, June 19, 2013 2:16 PM To: Hunter, Lindsey L Cc: Wallace, Chris D (DOA); NSK Fld Drlg Supv Subject: [EXTERNAL]FW: ConocoPhillips Water Source Step rate test Lindsey, 2 We sent you an email on 6/6/2013 outlining the following information request for the Sundries on the WSWs: We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MITs and step rate tests 3. Plans for hydraulic modeling prior to slurry injection We have not received this information but instead the request to Jim Regg from the NSK Drilling Supervisors was received as outlined below. Please provide the information requested to process these sundries and we would appreciate a single point of contact for review and approval of this work. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferciuson(a_)alaska.gov From: Wallace, Chris D (DOA) Sent: Wednesday, June 19, 2013 1:19 PM To: Ferguson, Victoria L (DOA) Subject: FW: ConocoPhillips Water Source Step rate test Victoria, Did you get a response from the CPAI town engineer on the Sundries? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542 (fax) chris.wallace @alaska.gov From: Regg, James B(DOA) Sent: Wednesday,June 19, 2013 10:37 AM To: Wallace, Chris D (DOA) Subject: FW: ConocoPhillips Water Source Step rate test Jim Regg 3 AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Fld DrIg Supv [mailto:n13350conocophillips.com] Sent: Wednesday, June 19, 2013 10:34 AM To: Regg, James B (DOA) Subject: ConocoPhillips Water Source Step rate test Good morning Jim, I am emailing you in regards for permission to perform a step rate injection test utilizing diesel in our class two injection wells on 1B pad in Kuparuk, Alaska-specifically WSW-02,05,09.. We choose diesel in the event a well locks up during injection for permafrost concerns. WSW-02 =API 500292081200 WSW-05=API 500292083800 WSW-09 =API 500292086800 We have intentions of installing a G&I unit on 1B pad in Kuparuk and would like to perform this preliminary feasibility test. We would assume a max bottom hole pressure of 2500 PSI based of our TVD of 2,850'-3,181' along with a current proved MIT on each wellbore. We would like to inject less than or equal to 1 1/2 time our tubing volumes to perform this test. Currently these wells are freeze protected with diesel and we do not see an issue with pushing this into the formation but do wish your guidance. Best regards, Rock Bobby Morrison/Rock Rauchenstein NSK Field Drilling Supervisors 907-659-7726 Pager 907-659-7000, 243 n 1335(a�conocophillips.com 4 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Thursday, June 06, 2013 10:20 AM To: 'lindsey.hunter @cop.com' Cc: Wallace, Chris D (DOA) Subject: WSW-02, WSW 03, WSW-05, WSW-06, WSW-07, WSW-09 Attachments: 1821640 WSWell 05 Class II Permit Lindsey, We received Sundrys for the subject wells and are requesting the following information: 1. Brief history of each well including results of previous MITs 2. Plan forward including planned MITs and step rate tests 3. Plans for hydraulic modeling prior to slurry injection Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson r .alaska.00v From: Wallace, Chris D (DOA) Sent: Thursday, June 06, 2013 9:59 AM To: Ferguson, Victoria L(DOA) Subject: FW: WSW Path Forward From: Wallace, Chris D (DOA) Sent: Monday, May 06, 2013 12:27 PM To: 'NSK Problem Well Supv'; Regg, James B(DOA) Cc: DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: RE: WSW Path Forward Brent, As in the attached email, if the well status and intent of use is being changed then a 10-403 should be prepared with all relevant information. If these wells are to be used for slurry injection,then the appropriate hydraulic modeling should be performed to establish the injection pressure and rate limitations to avoid fracturing the well into the confining layers. This would then be included into the MIT test pressure consideration. The MIT you speak of should be performed to the maximum anticipated surface pressure, 1500 psi, or 0.25 psi/ft x packer depth TVD ft whichever is greater. As per Guidance Bulletin 10-002 MIT,Shut in Wells "The Commission's preference is to witness an MIT while a well is actively injecting and wellbore conditions (rate and temperature)are stable. If the well is in a short-term shut-in status when the MIT is due,the Commission should be notified and provided an alternate date for testing based on when injection will be recommenced. Injection wells that are shut in long-term (undetermined when injection will restart) need not be tested until they are ready to recommence injection. In lieu of an MIT for the long term shut-in well, the operator must provide to the Commission a quarterly graph of tubing, inner annulus and outer annulus pressures." Please schedule MITs with the inspectors at your earliest convenience,to the maximum that you feel is adequate for your path forward. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Friday, May 03, 2013 11:12 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay; Hunter, Lindsey L; NSK DHD Field Supervisor Subject: FW: WSW Path Forward Chris, As described below and with Lindsey previously,there are 6 wells that CPAI would like to perform witnessed MIT's on while the well is shut in. Currently there is no injection piping connected to these wells in order to test while injecting. The tests are to bring them current in their compliance testing and then to apply for the appropriate approvals as needed. Would this be an acceptable plan? Please advise. Please let me know if you have any questions. Thank you. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 From: Hunter, Lindsey L Sent: Friday, May 03, 2013 10:37 AM To: NSK Problem Well Supv Subject: WSW Path Forward Brent, The plan I discussed with Chris Wallace is to use the Ugnu water source wells on 1B pad(converted to class 2 injectors in 1988) to replace the ailing 1R-18 class 2 injection well. We plan to start by injecting class 2 drilling fluids while monitoring the reservoir 2 performance,in the near future we'll be requesting permission from the state to use 2-3 of the wells for slurry injection of drilling cuttings. Please let me know if you need any other information from me. Thanks, Lindsey Lindsey Hunter Senior Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 Lindsey.hunteraconocophillips.corn 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg _ DATE: Wednesday,May 15,2013 13 SUBJECT: Mechanical Integrity Tests P.I.Supervisor ' g y CONOCOPHILLIPS ALASKA INC WSW-06 FROM: Lou Grimaldi KUPARUK RIV UNIT WSW-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry \161,4a- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT WSW-06 API Well Number 50-029-20851-00-00 Inspector Name: Lou Grimaldi Permit Number: 182-177-0 Inspection Date: 5/9/2013 Insp Num: mitLG130509123726 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I WSW-06 1'Type Inj N TVD i 2660 - IA 360 1720 1700 1690 PTD 1821770 T yp e Test sPT;Test psi 1500 -1 OA 0 0 0 OTHER P 1100 • 1100 1100 1100 P/F Tubing Interval I__--- Notes: Test for possible restart. .4 bbl's pumped.IA pressure dropped below CPAI allowance.Repressured with 4 gallons and resterted test.Good test. %OW FEB 2 0 2014 Wednesday,May 15,2013 Page 1 of 1 • • ® ® v ConocoPhillips Alaska 11as� - rm I P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 MAR 14 20 2 t'''fi t= mA 1 l,- March 9, 2012 Alaska OH & Gas Cons. Commission Anchorage 9 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 g Z _ 177 Anchorage, AK 99501 WSW) —° Commissioner Dan Seamount: 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. Sin, MJ veland ConocoPhillips Well Integrity Projects Supervisor • i • Cre nocoPhAmmmps 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 1B, 1 C,1 D, 1E 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 113-02 50029205310000 1801330 SF NA 16" NA 2.98 1/21/2012 113-06 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW -04 50029208330000 1821590 8'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW-06 50029208510000 1821770 20" NA 20" NA 2.13 1/21/2012 c .), 1C -11 r 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 10-18 50029229390000 1990050 SF NA 18" NA 2.55 2/10/2012 1C-26 50029229440000 1990510 SF _ NA 18" NA 3.75 2/10/2012 10- 128 50029229000000 1981330 2" NA 26" NA 3.83 2/10/2012 • S~T BY: ~CO A~S~ 7~, 3~/ ;11-27-97 ; 8'18A1~1 ; KPS/WF-IJLS/CNST/PROJ~ 907 276 7542;# 1/ 4 ,q' '"CEIVED - r- NOV 2B 199/' ; . Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Meehani~ Integrity Test I OR' .i.N'A[. ' DPE~R: ARCO Alaska, tr;c, FIELD / UNiT I PAD: Kuparuk'/KRU DATE; 10/5/97 170 ~0 ~50 250 ~ 1:45 , N ..... P Oi, ese/ 3,052 7# / 26# / JS~ ;:3.5 1500 .160 2~000 1,850 1,650 ..... WS W-03 'X21MMENTS: I i 35 tsoo o 1,~ao i 1,a*o I ~88o ! .... I Observed. initial pressure for 30 min. no leakage. N .... P D,,~f I ~, ~,o~,, I 7" / ~6~ / ,~ss 7" / 26~ / J55 ~5oo 200 I ~96o ~86o 100 10:00 1850 WSW,06 WSW.07 2,833 7"/26#/J55 I3.5t1500 100 1001100110019;071'F' 150 2000 I960 1960 WSW-11 l 2859 I D~eset I' 3,292.. I 7' / 2ro# / J55 I I "I 2100 I 2050 t 2050 I 2050 &5 ~5oo I too ~G .... .~"LUID CODES : FRESH WATER INJ. i = GAS INJ. ;: SALT WATER INJ. I= NOT INJECTWG TESTTYPE.- M: ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALYTEST D = DIFFERENTIAL TEMPEP, A'rURE TES"T. ANI~ULAR FLUID: P.P.G. Grad. WELL TEb"T: DESE~ I O. 35 Initral GLYCOL ! 0.00 4 - Year X SALT WATER 0o 00 Workover DRILLING MUD 0.00 Other OTHER ~ 0.00 istril3~.tiort: ~g - Well File - Operalor - Dalabase -Trip P431 File OPERATOR REP SIGNATURE: MIT WSW 10/05/97 SCANNED DEC ! ~ 2002 (Rev 9117/g~) ARCO Alaska, Inc. ~ Posl Office~ ~'360 Anchorage~ ~ska 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine. Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for November on these drill sites' 1-22 13-6 1-23 '13-11 1-24 13-13 6-24 13-14 7-15 lC-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 A1 so enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F-7 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. - Sincerely, P. A. VanDusen District Drilling Engineer PAV'JG'sm Attachments GRU1/L3 ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany -~:- ~' '- ,~.. - STATE OF ALASKA . -~. ALASKA- ._AND GAS CONSERVATION CL .'MISSION MONTHLY REI:I'ORT OF DR;ILI. II,IO WOItKOVEIt il. Drilling wellX[~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, AK 99510 4. Location of Well 319' FNL, 528' FEL, Sec. 9, T11N, R10E, UM at surface 5. Elevation in feet (indicate KB, DF, etc.) 98' RKB 6. Lease Designation and Serial No. ADL 256/+8 ALK /+66 7. Permit No. 82-177 8. APl Number 029-20851 50- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. WSW-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. November ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1700 hfs, 10/30/82. Drld 13-1/2" hole 'co 2/+70'; ran, cmtd, & tstd 10-3/4" csg. Drld 8-3/4" hole to 3835'; ran logs; ran, cmtd & tstd 7" csg. Ran CBL. · Perf'd. Performed cased-hole gravel pack over perforated interval. Ran 3-1/2" compl. assy. Secured well & released rig ~ 0200 hrs, 11/11/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2448'. Cmtd w/1400 sx AS 7" 26 O#/ft, K-55, BTC csg w/shoe ~ 3820' Cmtd w/375 sx Class G II I & 250 sx AS I SEE DRILLING HISTORY 14. Coringresumeandbriefdescription None 15. Logs run and depth where run DLL/GR f/3825'-2449' FDL/CNL/Cal/GR f/3158'-3560' CBL/VDL/CCL/GR NFD f/3545'-2950' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Senior Drilling Engineer A E SIGNED .f //,._~//~'~ / x,,,~/J, ~ TITLE D T NOTE--R~ort o~n ~'hi~orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and/3as Conserva/ion Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU 1/MR11 Submit in duplicate WSW-6 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1700 hrs, 10/30/82. Drld 13-1/2" hole to 2470'. Ran 60 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2448'. Cmtd 10-3/4" csg w/1400 sx AS III & 250 sx AS I. ND Hydril & diverter. Pumped 216 sx AS II top job. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 3835' TD (11/03/82). Ran DLL/GR f/3825'-2449'. Ran FDL/CNL/Cal/GR f/3158'-3560'. Ran 87 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 3820'. Cmtd 7" csg w/375 sx Class G. Arctic packed 7" x 10-3/4" ann w/50 bbls H20, 220 bbls Arctic Pack, & 110 sx AS I. Tstd csg to 2~500 psi - ok. Ran CBL/VDL/CCL/GR. Disp hole w/NaC1. Ran Gyro f/3700'-surf. Set sump pkr @ 3557'. Perf'd: 3160'-3208' 3216'-3222' 3256'-3281' 3290'-3308' 3336'-3340' 3352'-3370' 3385'-3506' 3519'-3540' Performed cased-hole gravel pack over perforated interval. Pumped pre-pak Baker Sand. Ran NFD f/3545'-2950'. Ran 3-1/2" completion assy (see attached tubing detail sheet),PBTD = 3733'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp tbg & ann (to 2926') w/diesel. Secured well & released rig @ 0200 hrs, 11/11/82 JG:llm 12/10/82 GRU1/DHIO Anchora9'~ Comrnis~ic,~ TO: William VanAlen FRC~: D. W. Bose/Lorie L. Johnson Transmitted herewith are the fOllowing: PI.~ASE NOTE:~~~B~~~ F- FIlM, T- TAPE, PC , PHOTCCOPY ARCO ALASKA, INC. ATI~: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 v / ~"" ~ -,, ,~-,,, ~' '1 .:i {,l~) ~ D~: A~CO Al~ska, Inc. STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION Meeheni~l Integrity Test FIELD / UNIT I PAD: KuperukTKFIU DATE: WSW-02 ... Oiesel 7" / 26# / J55 COMMENTS: O_bsep/ed initiai..pressure for 30 min. no leakage. WSW.03'~ 3~ I 7" / 26# / J55 7' / £6# / J55 1/VSW- ~ 1 2859 3~29£ 7" 1 26# ! J55 170 250 250 250 11:45 150~ 160 .,, ~500 200 1960 1860 1850 I ~.,~"] l 2~oo I ~.o,~o I ~o~o .. ~oo I ?oo I ~o I ~o zoso i ~:~e 1550 "I'BG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS IN,,I. S = SALT WATER INJ. N = NOT INJECTING Distribution: oriel- Well File : - Operator " c- Database ~ c- Trip R~! File ~. c - Inspeelor TESTTYPE: M = ANNULUS MON rTORING P = STD ANNULUS PRESSURE 'rEST R = IN1T=RNAL RAD, TRACER SURVEY A = TEM PERATLJRE ANONtALY TEST D = DIFFERENTIAL TEMPERATURE TEST OPERATOR REP SIGNATUi=iE: MIT WSW 10105/97 ANNULAR FLUID: P.P.G. Grad, WELL TEST: DffiS~ [ O. 35 Initial GLY1;(:X. ~ O. 00 4 - Year X SALT WATER 0.00 Wo rkove r DRILLING MUD 0. O0 Otb e r OIl-ER 0,00 (Rev 9/17/96) 1. Type of Request: 2. Name of Operator - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~ REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate Pull tubing __ Alter casing __ Repair well ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Plugging Perforate Pull tubing Other X Change Approved Program 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 321' FNL, 530' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1001' FSL, 510' FEL, Sec. 9, T11N, R10E, UM At effective depth 1052' FSL, 506' FEL, Sec. 4, T11N, R10E, UM At total depth 1052' FSL, 506' FEL, Sec. 4, T11N, R10E, UM Present well condition summary Total Depth: measured true vertical 12. Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2 4 4 8' Intermediate Production 3 8 2 0' Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 10O 7. Unit or Property name Kuparuk River Unit 8. Well number WSW 6 9. Permit number/approval number 82-1 77/8-520 10, APl number 50-029-20851 11. Field/Pool Upper Ugnu 3820' MD feet Plugs (measured) 3425' TVD feet None 3820' MD feet Junk (measured) 3425' TVD feet None Size Cemented Measured depth True vertical depth 1 6" 400 Sx AS II 80' MD 80' TVD 1 0-3/4" 1200 Sx AS III & 2448' MD 2230' TVD 250 Sx AS I 7" 375 Sx Class G 3820' MD 3425' TVD true vertical Tubing (size, grade, and measured depth) 3 1/2", 9.2#, 3557' MD Packers and SSSV (type and measured depth) Baker SC-1 @ 2966', Baker F-1 @ 3557' MD, No SSSV 2820'-3180' TVD (total interval) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Conversion to water iniection 14. feet Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ ,qlaska Oil & Gas Cons. Ccmmissio, Anchorage Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 5000 Bbl/day 16. Status of well classification as: Oil _ Gas Suspended 17. I hereby certify that the fo~regoing is true and correct to therb~est of my knowledge. Si~lned . /¢4/t itle //?-,~ .~ ~ ~' ~"~.. Form i0-404 FY~v~/15/88 : Tubing Pressure 1000 Service Water Inj Date ///~..~ [~ ¢? SUBMIT IN D~PLI'CATE ARCO Alaska, Inc~t~ Subsidiaq/of Atlantic Richfield Compan,~--"~ WELL ~.,bNTRACTOR REMARKS iPBDT FIELD- DISTRICT- STATE OPER/~TION AY R~PORT TIME DAYS D~D.~,TE KUPARUK ODEI~A,'rlC)NS ~.~ING CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon TIme extension Change approved program)(, Plugging '~ Stimulate .? Pull tubing 2 Name of Operator ARCO Alaska, Inc. 11. Present well condition summary Total depth: measured 3820 ' true vertical 3425' Suspend . ' Operation Shutdown ~ i Re-enter suspended well '- Alter casing [': Address PO Box 100360, Anchorage, AK 99510 Location of well at surface 321' FNL, 530' FEL Sec. 9 TllN R10E UM At top of productive ~nterval' ' ' ' 1001' FSL, 510' FEL, Sec. 9, TllN, R10E, UN At effe, ctive depth 1_052 FSL, 506' FEL, Sec. 4, TllN, R10E, UM At total depth 1052' FSL, 506' FEL, Sec. 4, T11N, RiOE, UM MD feet TVD feet Effective depth: measured 3820' MD feet true vertical 3425' TVD feet Casing Length Size xxx~X~cdx~xa4xxxxx Conductor 80' 16" Amend order ! Perforate Fi Other. R~,.BD~t(~(~ elevation (DF or KB) 6. Unit or Property name Kuparuk River Unit 7. Well number WSW 6 8. Permit number Permit #82-177 9. APl number 50- 029-20851 10. Pool Upper Ugnu Surface 2448' 10-3/4" xxx~X~e Production 3820' 7" Liner Plugs (measured) None feet Perforation depth: Junk (measured) None Cemented 400 SX AS II measured 1200 SX AS III & 250 SX AS I 375 SX Class G Measured depth 80' MD 2448' MD 3820' MD ~ue Vertical depth 80' TVD 2230' TVD 3425' TVD 3160'-3208' 3216'-3222' 3256'-3281' 3290'-3308' 3336'-3340' ' , , , 3352'-3370' 3385'-3506' 3519'-3540' MD true vertical 2820'-3180' TVD (total interval ) Tubing (size, grade and measured depth) 3~" 9 2# 3557' MD ~' , ,, , Packers and SSSV (typ_e and measured depth] Baker SC-1 @ 2966', Baker E-1 @ 3557' MD, No SSSV ,.._ Alaska Oil & Gas [,o];s, C~maas/on Detailed operations progra~'~~P sketch 12.Attachments Description summary of proposal 13. Estimated, ~Jate for commencing operation dUly, l~J~ 14. If proposal was verbally approved ~t~bseqtte~t Work tteDo~te~ o~ Form No ..... Dated__/._/-- Name of approver Date approved 15. I hereby certify that the foregoing is true and Rorrect to t,.he be,,,st of my.knowl~_dge. /¢'~~ /f~~~~~ ~r. upera~lons bnglneer Signed ,- Title Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. EJ Plug integrity I~. BOP Test ~ Location clearance] Approved Copy /~( Mec..",~.a...-~ic~.! ha~.rib, -.,,;:~,, Returned ~)RIGINAL SIGNED aY LONNIE C. SMITH 6/30/88 Date by order of Commissioner the commission Date ~ Submit in triplicate Sundry Notices wsw 3 wsw 4 wsw 5 wsw 6 These wells were drilled for use as creataceous source water in Increment 1 Waterflood at Kuparuk River Field. They are completed in the Upper Ugnu. Water production from these wells to date has been in excess of 70 million barrels. The intent is to convert these wells from producers to injectors to dispose of non-hazardous, Class II reserve pit water. Recent correspondance with the EPA has confirmed the Class II classification of reserve pit water. No BOP will be used for the proposed work. The estimated BHP in the Upper Ugnu is 1000 psi. No workover fluids are required. Procedure for WSW Conversion . 2. 3. 4. 5. Pull hydraulic jet pump. Pull standing valve. Run 'pump through' jet pump. Install injection piping and associated pumping equipment. Begin injection. '--" STATE OF ALASKA ALA~,,,A OIL AND GAS CONSERVATION CON,,,dlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon T~me extension Change approved program~,,, Plugging '~. Stimulate .! Pull tubing 2 Name of Operator ARCO Alaska, Inc. Suspend ' Operation Shutdown .; Re-enter suspended well -- Alter casing Ii 99510 3 Address PO Box 100360, Anchorage, AK 4. Location of well at surface FEL, Sec. 4, T11N, RiOE, UM feet feet Amend order f Perforate [' Other . R~.mD~lt(~6n elevation (DF or KB) 6. Unit or Property name Kuparuk River Unit 7. Well number WSW 6 8. Permit number Permit #82-177 9. APl number 50-- 029-20851 10. Pool Upper Ugnu 321' FNL, 530' FEL, Sec. 9, T11N, RIOE, UM At top of productive ~nterval 1001' FSL, 510' FEL, Sec. 9, T11N, RiOE, UM At effective depth 1052' FSL, 506' FEL, Sec. 4, T11N, RIOE, UM At total depth 1052' FSL, 506' 11. Present well condition summary Total depth: measured 3820' MD true vertical 3425' TVD Plugs (measured) None feet Effective depth: measured 3820' MD true vertical 3425' TVD Casing Length Size xxx~(k~x~xxxxx Conductor 80' 16" Surface 2448' 10-3/4" XXX~e Production 3820' 7" Liner Perforation depth: measured feet Junk (measured) None feet Cemented 400 SX AS II 1200 SX AS III & 250 SX AS I 375 SX Class G true vertical 2820'-3180' TVD (total interval ) Measured depth ~ue Vertical depth 80' HD 80' TVD 2448' MD 2230' TVD 3820' MD 3425' TVD 3160'-3208' 3216' -3222' 3256'-3281' 3290'-3308' 3336'-3340' 3352'-3370' 3385' -3506' 3519' -3540' MD Tubing (size, grade and measured depth) 3½", 9.2#, 3557' MD Packers and SSSV ~y~e and measured depth) Baker SC-1 @ 2966', Baker F-1 @ 3557' MD, No SSSV 12.Attachments Description summary of proposal'~ Detailed operations program _[]; BOP sketch 13. Estimated, for commencing operation u,y, 14. If proposal was verbally approved Name of approver Form No.- Dated ~/~/~ Date approved 15. I hereby certify that the foregoing is true and R,orrect to t..he be§t of my.knowl~.dge. __ __ r~ '~ br. uperal;lons e. nglneer Signed ~Z/C4m ~j~~~/_pw Title /~/ Commission Use Only Conditions of approval Approved by 6/30/88 Date N~otify commission so representative may witness I Approval No. Plug integrity Fl. BOP Test ~ Location clearance ~~Jc~a! lntegr/ty Test Approved Copy ,~.,IIGINAL SlGNED Returned L0#NJE C. ~iRITH ~ ~-~'¢~'----~'~'~ by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Sundry Notices wsw 3 wsw 4 wsw 5 wsw 6 These wells were drilled for use as creataceous source water in Increment 1 Waterflood at Kuparuk River Field. They are completed in the Upper Ugnu. Water production from these wells to date has been in excess of 70 million barrels. The intent is to convert these wells from producers to injectors to dispose of non-hazardous, Class II reserve pit water. Recent correspondance with the EPA has confirmed the Class II classification of reserve pit water. No BOP will be used for the proposed work. The estimated BHP in the Upper Ugnu is 1000 psi. No workover fluids are required. Procedure for WSW Conversion 1. 2. 3. 4. 5. Pull hydraulic jet pump. Pull standing valve. Run 'pump through' jet pump. Install injection piping and associated pumping equipment. Begin injection. TO: William VanAlen FRCM: Transmitted herewith are the following: PLEASE ~~~ F- FTI~4, T- TAPEr PC- PHOTOCOPY ARCO ALASKA, INC. Alaska Oil A'i'i"N :p. O. ~'"-~-':-~BOX 3607'-~.,,,~-~/'-£-2--- ~_-"~ ' - ~~~311 ~nChorage ~~, ~. 99510 ' D. W. Bose Transmitted herewith are the foll~ing: PT.FASE NOTE: ~-~~, F - Frr~I, T - TAPE, PC- PH(YlK)CDPY ANCHORAGE, AK. 99516 v '~l]Ora,qe U/nr~issiori ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 27, 1982 Mr. C. V. Chatterton Commi s s i one r State of Alaska ' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are completion reports and gyroscopic surveys for the following wells: WSW-6 WSW-7 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:sm Enclosures GRU1/L17 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKA,,-~ AND GAS CONSERVATION cC ..MISSION WELL COMPLETION OR RECOMI LETION REI ORT AND LOC 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Water Source Well 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-177 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20851 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 319' FNL, 528' FEL, Sec. 9, T11N, R10E, UM VERIFIED Kuparuk River Unit At Top Producing Interval Sur~. .~ 10. Well Number 878' FSL, 457' FEL, Sec. 4, T11N, R10E, UM B.H.. .r~f wsw-6 At Total Depth 11. Field and Pool 1150' FSL, 366' FEL, Sec. 4, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lower Tertiary (Upper Ugnu) 98' RKB ADL 25648, ALK 466 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 0/30/82 11/03/82 11/11/82 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ I-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 3835'MD,3439'TVD ~733'MD,3345'TVD YES [] NO [] None feet MDI 1625' (approx) 22. Type Electric or Other Logs Run , DLL/GR, FDL/CNL/Cal/GR, CBL/VDL/CCL/GR, NFD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 220 sx AS II 10-3/4" 45.5# K-55 Surf 2448' 13-1/2" 1400 sx AS III & 250 sx A~ I 7" 26.0# K-55 Surf 3820' 8-3/4" 375 sx Class G & 110 sx IS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3160'-3208' 3336'-3340' See Attached 'ubin9 Detail Sheet 3216' -3222' 3352' -3370' 3256'-3281 ' 3385'-3506' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 3290'-3308' 3519'-3540' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I MethOd of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASiMCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECeiVED DEC2 8 1982 Alaska 0il & Gas Cons. Commission ~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC5 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Ugnu 3160' 2829' N/A Top Lower Ugnu 3560' 3188' 31. LIST OF ATTACHMENTS Drilling History, Tubing Detail Sheet, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separatelv produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores take. n, indicate "none". ' ' ' ' - ~ING/TbBINGILINER DEI~-.. DRILL SIq E._/Z/_,3'/4,) .,'¢z'~ --- -o~ "' ,'<~ ~ ,~_~. DATE ~/_//t~_Z~ ARCO Alaska,~nc. ~, Page / of / pages Subsidiary of AtlanticRichfieldCompany #ITEMS COMPLETE DISCR1PTION OF EQUIPMENT RUN LEN -~'~H DEPTH · _ . , . ~ . . . . ! . "'. , z",,,'~/'' ~'.'i ~'~::'-~ .'- ..... . ,_~_._~,'_ .... . - .,., - : .. ,,., ,. , _ ~1 ~ - ,, .:, ........ . .... ~~~ ' .. , _ .- ~ '. ~ - ~, ._ _' ~ ~. z ~ ~~ rc ~ , ~ 7 ' . , , .... , . , , , , ~ , I , ' ~ .o~ou o. ~u~,~ ~t~:~ I~ E [ ~R~-),. Remarks DEC 2 8 ]982 AlasKa 0ii & Gas Cons. Comrnissiur~ WSW-6 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1700 hrs, 10/30/82. Drld 13-1/2" hole to 2470'. Ran 60 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2448'. Cmtd 10-3/4" csg w/1400 sx AS III & 250 sx AS I. ND Hydril & diverter. Pumped 216 sx AS II top job. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 3835' TD (11/03/82). Ran DLL/GR f/3825'-2449'. Ran FDL/CNL/Cal/GR f/3158'-3560'. Ran 87 jts 7", 26#/It, K-55, BTC csg w/shoe @ 3820'. Cmtd 7" csg w/375 sx Class G. Arctic packed 7" x 10-3/4" ann w/50 bbls H20, 220 bbls Arctic Pack, & 110 sx AS I. Tstd csg to 2500 psi - ok. Ran CBL/VDL/CCL/GR. Disp hole w/NaC1. Ran Gyro f/3700'-surf. Set sump pkr @ 3557'. Peri'd: 3160'-3208' 3216'-3222' 3256'-3281' 3290'-3308' 3336'-3340' 3352'-3370' 3385'-3506' 3519'-3540' Wash perforations. Pre-pack peris utilizing retrievable packer. Cleanout well to sump packer. Performed cased-hole gravel pack over perforated interval. Ran NFD f/3545'-2950'. Ran 3-1/2" completion assy (see attached tubing detail sheet). PBTD = 3733'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp tbg & ann (to 2926') w/diesel. Secured well & released rig @ 0200 hrs, 11/11/82 JG:llm 12/10/82 GRU1/DHIO RECEIVED DE C 2 8i._982 Alaska Oil & Gas Cons. GomraJssion Anchorage SPERRY-SUN WELL SURVEYING COMPANY PAGE ~ ANCHORAGE ALASKA ARI~.O ALASKA, INC. '~ ~-~ ~ .... DATE OF ~LIRVEY NOVEMBI=R 05, 1~82 "' ' '" ....... ~ ~ (b ~ ~::~:~::::A~ ~:~::::~:~: '~:~:::::~::~:~::~ ::::::::::::::::::::::::::::::: ~.~~.~`~.~:~.~.~:~.:.~:~`~:~:~::~:~:~::.~..~.:~::~f~.~;~:;~.~:~:~:.~.~:~.~:~.~:`~:~`:~::~:~.~..~..~:~:~:~::~:~.~::~.~:~:~::~::~::~:~.:~:~:~:::~:.~.~::~:~:.:~:~::~:~:~:~::~.::~::~:~:::.~:~:~:~:~.~:...~.~..~::~::~::~::::::~:~:.~:~:~::~.~::.:`~.+~::~:~.~E~M~::~.~:~.~H~:.~::::~.~:~.~.~::~:~:::::.:~.~:.~::~:~::~::~:~::~:~:~.~::`~:.~:~:~.:.~:~::~:~:;~.~::::~.::~::~ ~.~? c~ ~ OPERATOR- d. SAHEC VERTICAL SECTION CALCULATED ~LO~ C~SLIRE :::::"::::~: :~'"~:: ~~.': '"' :~::" ::': :'::: '"'~': '~: ::::::::::::::::::::::::::::::: ?::::::'":':'~" ::':'::':':~'~"~i~'~::~:~:~]i~:'~'~:~~ '.~:~~:' ::~::::: :::::::::::::::::::::::::::::;~ '. ..~ ~::~:~:::::~:~:~:.~:``~:.:~:~:~:~`.~:~:.:..:.~:::~.~::~.:~:~:::]~:::~.~:~:~:~:~:::~.~:~.:~.~:~:~:.:.:~:~:~:.:.:.:~:~:~:~:~:~:~:.:~:~.~.~:.}~:~:~:~:.~`:.:.:~.~..~:~:~:~:~:~:~:~.:~:~:~:~:.:~:~:~1~:~~ ~ ~. ~:~ ' ,~:E~] ,:·,:~:: :~ ": '~ ,~~ ~ :] .' · ) 0 0.00 -98.00 0 0 N O. 0 E 0.00 0.00 0.00 0.00 100 100.00 2.00 0 5 ~ 82. o~N...~ 0.0~ 0.01 s ' 0,08 H ~0.02 500 4~.~ 401.~ 0 40 N 12.50 E 0.47 1.80 N 0.27 E 1.82 ~00 5~9.~1 501.~1 3 41 N ~.1~ E 3.03 5.58 N 0.74 E 5.~3 700 6~.51 ~01.~1 ~ 2~ N ~. 0 E 2,74 14.37 N ~8 E 14.47 l:O0o: ~ ~2::' :~7~:::?: :~'~:~: 894.::: ~, ~7::~:~::~:;:~:o: ~00 1087.43 ~89.43 20 ~3 N 0.80 E 3.27 107.68 N 6.44 E 107.74 1200 1180.11 1082.11 23 50 N 1.80 E 3.64 145.18 N 7.31 E 145.10 1300 1270.51 1172.51 2~ 45 N 2. 0 E 2,~1 187,87 N 8.73 E ;~7.70 ~::~:: ~'?",~:: i :: :: ~ :: :: ~ ~ ~ :: ~::~':~:.~::', ::::::::::::::::::::: 1700 1&09.08 15 ."~ . . ,11 o~ 33 7 N I 0 E 2.04 400.14 N ~ 05 E 398.72 1800 1692.75 1594.75 33 17 1900 1776.03 1678.03 33 56 ~ooo ......... i ~'~:' ~-', ..... i~ i'~,~ :' ;~----' 'i§~'" =~ 2100 1941.59 1843, 59 : 34 /:'123: 2200 2024.12 1926.12 "34 22 2300 2106.49 2008.49 34 41 2400 2188.38 2090.38 35 21 2500 2269.84 2171.84 35 31 2700 2433,55 2335.55 33 56 2800 2517.30 2419.30 32 17 2~00 2602.52 2504.52 30 47 N 1. 0 E 0.16 454.90 N 10.01E 453.25 N 0.80 E 0.6~ 510.23 N 10.88 E . ., 5~8.37 .... N '2, O' N 2.39 E 0.40 735.53 N 16.98 E 732.95 N 2.60 E 0.67 792.87 N 19.49 E 790.23 N 3.69 E 0.66 850.77 N 22.67 E ~8.13 N 8.89 E 1.74 1071.21 N' 46.57 E 1069.85 ARCO ALASKA, INC. SPERRY-SUN WELL SURVEYING COMPANY PAGE 2 ANCHORAGE ALASKA ....... DATE OF SURVEY NOVEMBER 05, 1982 OPERATOR- d. SAMEC VERTICAL SECTION CALCULATED ALONG CLOSURE ) 3000 2688.84 2590.84 29 50 3100 2776.09 2678.09 28 38 N 10.10 E N 12.~'60 E __ 35£10 3133.49 3035.4.9 25 28 N 1~.19 E 0.75 1341.77 N 112.20 E 1345.98 3600 3224.06 3126.06 24 41 N 20.50 E O. 95 1381 . 64 N 126.59 E 1387.19 3700 3315.~1 ~217.41 23 16 N 22.60 E 1.66 1419.46 N 141.50 ~ 1426,41 HORIZONTnL D~SF'LnCE~ENT = t~77.62 FEET nT NORTH 6 .Ea, t7 ~N. nsr'nr = ~e~ THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. c, 0 0 SPERRY-SUN WELL SURVEYING COMPANY PAGE 3 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY NOVEMBER 05, 1982 OPERATOR- d. SAMEC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. --~.~'- '~'-?'::-~ ~,', ,,,.,, ',' ,,.,., ,::. ,.,,, ,.,..,....,..~., ,.,.: :...,.,.,,,.,.,'~.. ,..., ....., .:,..... ;,..:. ,.............. :..........:... :. ;. :.;.: ,....,.,.,,,., ... ,.,... ,. ,,... ,.. ;.. :,.: ,.,,,,.,...,......:...,., ,,; .: ,., :,: :, :, ,....,..: .. :.., :..,,.. x,-. :, ..x. ;.: ,-,,, ,,-,-.-... ,.: ,., :, :, x-x + :.:,-.-..~-.-,.,-.-,-, :.: ,~ ~, ;+ :,; o > ~.~.~ +::,: ,: +:+-,:, :,:,:, :.~, ~.: ,:,~, ~, :+-+., :,x.:.~ ,: ,:~: ~. ~.: .: .;. ;.:.: ,: ,x,: +:, :.:.:. ;, ;+~,:, :, ;.~ ,;c.:,/;.:.:.:, :o :, :, x ,~o ~. ;. :+: o: +:. > ;,:.;.~ ¢, :.~,:, :. ~, ;.~, :, :, :. :,:, :.:,: ,~, :,:,:. :.~ ,: ,~, ;. :, :. ;, :,:. :, :. xo ;, :,: ,:, ;,: ;. :, :. :, :, ;.: <, ;+ ~.~ .: ~, :, ~.;, :.,.,, :, :. :, :, ;, ~, ~. ;. :c x .;, :, :,~, :, ~.~.~, ;,~. :, ;. :. :,:, :, ;,:. ;, :, ~, ;, :,,, ;. ;, :: :t ,: .x+: :. x. :,: + :,k. d: k,>:4M,:.;,:, PAGE ARCO ALASKA, INC. 0 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA OPERATOR- SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~]EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 O. O0 -~8. O0 O. O0 O. O0 O. O0 498 498.00 400 O0 1 77 N 0.26 E 0.01 0.00 598 598. O0 500. O0 5.47 N O. 73 E O. 09 O. 08 005 ~8. O0 ~00. O0 77.45 N 5.56 E 7.58 3.83 111 10~8. O0 1000. O0 111 . ~5 N 6.50 E 13.2~ 5.71 121~ , 11~8.00 1100.00 153.1~ N 7.57 E 21.~0 8.31 686 1598. O0 1500. O0 806 1698. O0 1600. O0 458.34 N 10.07 E 108.28 19.52 92~ 1798. O0 1700. O0 525.04 N ,~ 1 . 08 E 128 ~ 49 20.21 .0. 0 G SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE ALASKA ARCO ALASKA, INC, 13ATi~ ~3~' ~IlRV;:V NAVP'I,li~P"R A.~. 1.~.A. OPERATOR-d. SAMEC '-~EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 2047 1898. O0 · ,,? ?... .~,,., ........... : ..~ ..,-~,.,~,,~,-~ _,,.,,~.~... ............. 2534 2298, O0 2657 2398, O0 1800, O0 592, 64 N 12, 33 E 149, 20 2200, O0 870, 84 N 23, 97 E 236, 60 2300, O0 941 , 35 N 30, 06 E 259, 11 20.71 22, 80 22, 52 2777 2498, O0 2400, O0 1007, 32 N 37, 74 E 279, 17 20, 06 3237 28~8, O0 2800, O0 1231 , 32 N 7~, 23 E 33~, 77 12, 81 3835 3439,42 3341,42 1279,99 N 92,16 E 351,74 11,97 1325,80 N 106,64 E. 362,69 10,95 1468.72 N 162.00 E 395.58 [ 3.67 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN '.THE NEAREST 20.:FOOT .:MD:~(.EROM:.~:RADIUS OF~CUR~,TUf~E) PO'I:N~$~!i~ : : :: i; ARCO ALASKA~ !NC. SPERRY-SUN WELL SURVEYING COMPANY ' PAGE ANCHORAGE ALASKA DATE pF SURVEY NOVEMBER OPERATOR- d. SAMEC INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 70.80 E TOP UPPER UGNU ]EPTH DRILLER © 0 ARCO ALASKA, INC. ~sw-6 ~ SEC ~ T11N R ~ OE), , COORDINATES, · -MARKER ....... MEASURED DEPTH ........ TVD THICKNESS WITH REF. TO WELLHEAD ......................................... _B_~_B..~____~ .... B!~ SUB-SEA VERT I CAL ¢ OR I O I N- 31 ~FNL 528FEL ) _ ) TOP LOWER UGNU 3560 3187.72 308~· 72 1365· ~gN 120.73E , SURVET DEPTH 3700 3315.41 3217.41 141 ~7.46N 141 . 50E . PBTD '~ '-~ '--'~ o7~3 ~45.73 3247.73 1431 · 50N 146 · 51E 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMF'UTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. ........ [I~TA"OAI~CUI'AT'IO~-'-AND'--~IT'ERPOL~'Ti-ON BY RADIL$ OF:.CL!RVATURE': · ' '''' ~'"·::' ~: '" ::::".. :' ::":':: '!:':i COMPUTATION DATE NOVEMBER 08, 1~82 DATE OF SURVEY NOVEMBER 05, 1~782 dOB NUMBER BOSS-16125 ~ ........ ~ . . :::.:~. · : . . .x, :...:..i..:.::..:.:.:.x.:. ~.-:.:,x .:.:.-...:.:.:,.'.: '.. ' -: :. -,,.:. ::-. :-:., : ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16125 Well: WSW-6 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: November 5, 1982 Operator: John Samec Scale: 1" = 300' TSUE NOBTH 3835 ! OO.;O0 ~00. O0 I00 O0 -30~.00 Surface Location (319FNL 528FEL) 300.00 HORIZONTF L PBOJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16125 Well: WSW-6 (SEC9 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: November 5, 1982 Operator: John Samec Scale: 1" = 1400' O. O0 700. O0 ! 400. O0 2100. O0 2800. O0 3500. O0 ~ 1477.62! @ N6o 17'E · ,ob. oo ,~bo. oo 2,bo. oo VERTICCqL PROJECTION Suggested f' '~ to ke insertc~t in each "Acti% well folder to d~eck zor tin'~ly ccx~liance with our' rc<julations. We~ Na~ and Number Reports and Materials to'be received by: /~-//-' ~ . Date Required Date Received Remarks · comPletion Report . Yes / · We11 History Yes -.. _Samples, --PL ,, ' = Mud, Log . . /K6 -- ~/ ' ----- Core Chips _ . ,. ...... . Core Doscription Registered Survey Plat ,-,. t~ ¥ ~',- ~¢~ : Inclination, Survey , //~/'~ "------"-"--" 6 ~ _ Directional, . . . Survey .~e3--Pf. , /r~,, Drill Stun Test Reports /~/d_.~te_ , , , ~ ,. . ,. · Prod~cti6n Test Reports ., , ~.., , .e.3 t'~-m~-~~ ~:.,: ";~ :~:_-~. h · , .... · Digitized. Data - ]C~-/ I-- / ~ --' Y'~ ;'~ :"" ARCO Alaska, Inc~.-... Post~O i'fic( x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November !2, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: State Reports Dear Mr. Chatterton: Enclosed 'are monthly reports for October on these drill sites: 1-21 18-7 1-22 18-10 6-23 1E-26 6-24 1E-27 7-15 1F-7 13-14 1F-8 13-15 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well completion reports for: 1-20 1G-2 6-22 1G-3 13-16 wsw-3 1E-30 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen District Drilling Engineer PAV:JGOI:ltc Attachments ARCO Alaska. Inc. is ,1 subsidiary ol AllanlicRichhcldCompany .~--. STATE OF ALASKA ALASKA ~. _ AND GAS CONSERVATION CO,.,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well IX[IX Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-177 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 so- 029-20851 4. Location of Well atsurface 319' FNL, 528' FEL, Sec. 9, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 98' RKB 6. Lease Designation and Serial No. ADL 25648 ALK 466 9. Unit or Lease Name Kuparuk River Unit 10. Well No. WSW-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of October ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1700 hrs, 10/30/82. Drld 13-1/2" hole to 2470' as of 10/31/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests N/A 14. Coring resume and brief description None 15. Logs run and depth where run None to date 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV 1 8 1982 Oil & Gas Cons. t;ommissi0n &n~,hnr2nR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE Sr. Dril 1 ing Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate WSW-6 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1700 hrs, 10/30/82. Drld 13-1/2" hole to 2470' as of 10/31/82. JG-11m 11/08/82 KUPARUK ENGINEERinG D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: · RECEIPT A~.~: pT,FASE 'RETURN i:LSEEIt~ TO: ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 THRU: Lonnie C. Smith../~ Commissioner MEMORANDUM State of Alaska ALASKA~OIL AND GAS CONSERVATION COMMISSION TO: Co ~~~rtc, n DATE: November 8, 1982 Cha~~/ FILE NO: 108A/L FROM: Ed~.ar W. Sipple, Petroleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's Kuparuk WSW-6 Sec. 9, TllN, R10E, UM Permit ~]o. 82-177 Parker Rig 191 Nove~mber. ~i, 1982 - I traveled to ARCO's Kuparuk ~?~-6, Park~r--.iigw 191. Parker was in the process of running casing. T_uesday~_~ Novemb~._ r_ .2 ,_ !98_2 - The BOPE test commenced at 3:45 a.m. and ~as concluded at 7:45 a.m. There ¥~re four (4) failures. Three valves on the choke manifold and the remote control panel didn't actuate the control upon command. A Parker electrician changed out an electrical board inside the control panel, it tested satisfactorily. Mr. Ken Jones will repair or replace the valves on the choke manifold and will notify the A.O.G.C.C. office when the valves test to 3000 psi. I filled out the A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test on Kuparuk's WS~'~'-6. There were four (4) failures. The control panel was repaired before I left the location. The three valves that leaked on the choke ~anifold ~re redundant valves, therefore rig operations -were allowed to proceed conditioned On their repairing and testing the valves %-~thin three days. The A.O.C~.C.C. office ~.ill be notified when the valves are repaired' and tested' Attachment: Mr. Ken Jones of ARCO called A.O.G.C.C. office on November 3, 1982. The three leaking valves on the choke manifold ~re repaired and tested to 3000 psi. 4/81 , SqATL OF ALASKA OIL CAS OONSERVATJ~ I C~-DiISSION B .O. P .E. Inspection l,lu~ort Inspector Location: Sec ~ Fril ling Contractor [~Dcation, General' Well Sign ceneral Housekeeping__ Peserve pit Representative --,Rig # I 9; ,Representative Rig ]Full C3]arge Pressure _ . Pressure After Closure ~Punp incr. clos. pres. 200 psig . J~ll Cha~e Pres~re Atta~: R~te L~v Blinds ~itd~ cover . Test ~es~e Nelly and Flmr Safe~ Valves · / Jo ~ ~r Nelly./O KTest ~essure BOPE Stack Annular Prev_enter-- Pipe ~ams OK B lind Rams ._~Jl / fYs/~ ~'/ Choke Line Valves__--:, H .C .R. Valve cD .:. Kil 1 Line Valves ~/< Check~ Valve ~ ~ ~ Lo~r Kal 1}: ~-/';~ Test / ~ ~l Test Bal 1 Typ~__ Ins ide BOP ¢~/( Test Test Results: Failures. ~epair or Replacement of failed equipment to be made within Inspector/Ccr~ni~sion office notified. psig psig ~D min2~ sec. 22_ rain JS sec. p%ig Pres s lire Fressure Pres sure Choke ~nifold No. Valx~s_ No. flange s_~ ? pdjUStable Chokes 2 6q,(?~ ~_~__ t~drauically operated choke ....... lf-~ -i- ~:2T - Y--i L-l- 5--~_'---- L--i. ---- 77 C l'2:.--'72 ' ' _ ..... Test Time' Test Pressure ~00 o days and (~~ ...~['~ (~_ . ~tt ok dF( Distribution orig. - AO&CCC cc - Operator cc - Supe rxrisor /d, O, d. C c_ o .~-.r~./al November 2, 1982 !~r. Jeffrey. B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kupar~m River Unit WSW-6 Dear ~.~. Ke%~n: it has come to my attention that the October 28, 1982 cover letter to your Well Permit Application for 'has an error-in the second paragraph. ~e paragraph now reads "if coring ...... Samples of well cuttings and a mud.log are required ..... " It should read "...Samples of well cuttings and a mud lo~ are not reqUired...'' Sorry for my goof! Sincerely, / ? ~ '? '-'~'::~. V. Chatterton Chairman CVC:be Cctober 28, 1982 Mr. Jeffrey B. ~ewin Senior Drilling Engineer ARCO Alaska, In¢. P. O. Box 360 ~nchoragev Alaska 99510 Kuparuk ~2[ver Unit WS~-6 ARCO Alaska, Inc. Perm. it ~o. 82-177 Sure Loc. 321'FNL, 530'FEL, Sec. 9, TllN, ~10~, UM. Be~hole Loc. 1305'FSL, 502'FEL, Sec. 4, TllN, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. 'Samples of well cuttings and. a mud log are required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If a~ilable, a tape containing the digitized log info~ation shall be submitted on all logs for copying except experi~ntal logs, velocity surveys and di procter surveys. ~ny rivers in Alaska and their drainage systems have been classified as im~rtant for the spatting or migration of anadromous fish. Operations in these areas are sub3ect to AS !6.05.870 and the regulations promulgated thereunder t~ 5, (Ti ~ Alaska A~---~nistrative Code). Prior to comr~ncinc o~rat~o~.s you may be contacted by the Habitat Coordinator's ~-~=, Pepartment of Fish and ~ame. Pollution of any w~ters of the State is prohibited by AS 46, Chapter 3, Article 7 an~ the regulations promulgated thereunder (Title !8, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amende¢~. Prior to cc~ncing o~rations you may he contacted by a representative of the ~_~.partment of Environmental Conservation. To aid us in scheduling field ~.~Drk, please notify this office 2~ hours prior to commencing installation of the blowout Mr. Jeffrey B. Kewin Kuapruk River Unit WSW-6 -2- Ocotber 28, 1982 prevention equip~nt so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe_- is drilled. Where a diverter system is required,' please also notify this office 24 hours prior to commencing equip~ent installation so that the Commission may witness testing before drilling below the shoe of the conductor pi~. In the event of sus~nsion or abandonment, please give this office adequate advance notification so that we may have a w~ tness present.' Very truly yours, C.-V. Chat~terton ~ Alaska 0i! and ~s Conservation Commission sure Department. of Fish & Came, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. cvc ~be ARCO Alaska, Inc Post Offic~ x ,. Anchorage, Alaska 99510 Telephone 907 277 5637 October 22, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk Water Source Well #6 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk WSW #6, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1B-3, 1B-4, 1B-5, 1B-6, 1B-10, 1B-11, WSW-2, WSW-3, WSW-4, WSW-5, and WSW-6. . o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o An analysis of well proximity - water source, Well No. 6. As we anticipate spudding this well on or before October 1982, any questions regarding these wells should be directed to Mr. Rich Gremley in our office at 263-4972. Sincerely, ~~~neer · JBK/JG:sm GRU2/L20 Alaska Oil Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~'-- ~'-"-' STATE OF ALASKA ~ ALAS, . OIL, ,,4D GAS CONSERVATION ,-OMIt. CSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] Water Source XXDEVELOPMENTOIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE ~]X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 321' FNL, 530' FEL, Sec. 9, T11N, R10E, UM At top of proposed producing interval 954' FSL, 508' FEL, Sec. 4, T11N, RIOE, UM At total depth 1305' FSL, 502' FEL, Sec. 4, TllN, RIOE, UM 10. Well number WSW-6 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 57' GL, 62' PAD, 98' RKB ADL 25648 ALK /+66 12. Bond information (see 20 AAC 25.025) I-ederal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 Mi. NW Deadhorse miles 3975 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 3899' MD, 3424' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 35 Ol(see20AAC25.035 (c) (2) Lower Tertiary (Upper Ugnu) Amount $500,000 15. Distance to nearest drilling or completed WSW#5 well at surface,60 feet 18. Approximate spud date 10/¢l./82 1537 psig@ 80° Surface 1500 ~ psig@ 3424 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight ;24" 16" 65# ..;13-1/2" 10-3/4" 45.5# 18-3/4" 7" 26# 22. Describe proposed program: ;ASING AND LINER Grade Coupling H-40 I Welded K-55 IBTC K-55 JBTC SETTING DEPTH Length' MD TOP TVD 80' 36.5'1 36.5' 2353' 36' I 36' I 34'5'11 34.5' 3926' MD BOTTOM TVD 116' 116' 2389'12200' I 3899'13424' I QUANTITY OF CEMENT (include stage data) 250 cf ± PF II 1200 sx Arctic Set Ill 250 sx Arctic Set I 250 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River Unit, water source well to approximately 3899' MD, 3424' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 1537 psig based on warming of a gas bubble rising at constant volume. A 3-1/2" gravel pack screen will be run to ± 2900' TVD and gravel packed. The interval will be produced by a downhole pump set above the gravel pack packer on 3-1/2" 9.2# J-55 BUTT. TBG. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Ugnu formation and reported on subsequent reports. '23.' hereby certify t_hat the foregoing is true and correct to the best of my knowledge OCTZ~~)" J'"*'f~Z SIGNED ~/~/,,~,Z',--- TITLESr. Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required I Mud log required I Directional Survey required APl number []YES eNO I []YES I~NO [ '~[YES []NO 50- (P ~.- ~-'?-- O ,~..~ '/ I ~ date Permit number APPROVED BY SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE October 28, 1982 Form 10-401 GRU2/PD10 Submit in triplicate ANALYSIS OF WELL PROXIMITY WATER SOURCE WELL NO. 6 ARCO Alaska, Inc., proposes to drill Water Source Well (WSW) No. 6 on 60' spacing adjacent to existing WSW No. 5, as shown on the attached wellbore proximity plot. The wellbores for the subject wells are vertical to 500' TVD, which is the point where both wellbores are kicked off. At this point, the areas of uncertainty of the individual well surveys would be 18' in diameter based upon typical field-observed accuracies for the surveying tools utilized. Assuming a worst-case situation, the areas of uncertainty would not intersect or overlap one another. Further, after reaching kick-off point, the subject wellbores are directionally drilled at diverging angles further widening the margin of safety. In addition, as shown on the attached proximity plot, WSW No. 6 crosses the wellbores of 1B-3 and 1B-11GI; however, in both instances, the crossing distances exceed 200'. In light of the above, we feel we can safely drill Water Source Well No. 6 and avoid proximity problems with the adjacent wellbores. JBK:sm 10/19/82 KEW1/AWP2 13-5/8" 5000 PSI 'RSRRA BOP STACK I . 2. 3. 4. . C- ) 16" Bradenhead 16" 2000 PSI x lO" 3000 FSI casing head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kill lines -- 13-5/8" 5000 PSI pipe' rams- - .. 13-5/8" 5000 PSI. blind ra~s 13-5/8" 5000 PSI annular . " -. _. . . . ACCLC. IULATOR CAPACITY TEST .- .- CHECK ~J~ FILL ACCLE-,qJLATOR P~,.ESEF..'~OIR ~ PROPER L~'E[ WITri HYDRAULIC FLUID: ASSURE IP~T ACCL~-;ULATOR PP~ESSURE IS 3~rJO PSI WITH.1500 PSI D(YJI~TRF_~ OF THE OBSERVE TIHE THEN CLOSE ALL UNITS OUSLY AJ;D RECORD THE TIP£ AND PF~S~ ING AFI~R ALL UItITS ~,RE CLOSED WIi~I. ~.~RGING Pb~P OFF. RECORD ON IADC REPORT. THE.~ ACCE?¥~'_~LE LG'JER LIHIT IS 45 SECONDS CLOSIh"G 7IHE ~ 1200 PSI P~INII~ PRESSURE. - 13-5/8' BOP STACK TEST FILL BOP STACK AND NA,'tlFOLD UII'H ~--"~C DIESEL. ~H, ECK THAT ALL HOLD DG',~( SCR~S 'AR£ FL~_I_Y RE- TI:LAC'FED. PREDETE~qI{;E DEPTH THAT '.--F~-T PLUG I,'iLL SEAT AIJD SEAT IN 14ELI_HFEAD. R'.~ Ill LOCK DCT,4N SCR~JS Iii HEAD. =__- 3. CLOSE ~';:tULAR PREVENTER AND CdO.~S ~ BYPASS P R~S Y~VES 0:( ,.~qIFOLD. . : : lO HIHU]ES. - ._ ~ 5. iNC~c PRESSURE TO ]8~ RS] A~ ~ FOR ]0 NiNUTES. BLEED TO ZERO PSI. - _ ' 6. 0~ '~U~ PREY~ER ~'~D CLOSE T~ S~ OF PIPE 7. IN,EASE .PR~SURE TO 30~ ~I' ~ ~'FOR lO -4 ': ' - . ii'~ ]-.-'~-' ~- HII~TES. - 8. CLmE V~VES DIRELY U~:4 OF m BLEED ~PHSTR~4 P~ESSUP~""~ ~0 ZEPJ ~ ~ V~VES. TEST R~.1~IH!hG"" U[~TED )~qIFCLD TBG "''~ - ' ' ' ' V~VES, IF AhY, ~I~ ~,~ ~I UPST~q OF VALVE ~(D ZERO PSI D~NST~H. BLE~ ~ST~ _. 9. OPEH TOP S~ OF PIPE ~ ~iD CLg~E B~ ' B~ OF PIPE ~v~. . -' ]0. II;CR~SE PRESSURE TO 3~ PSI ~D H~ FOR 10 ]l. OPEN BOUOH S~ OF PIPE ~., BACK OFF l(I~;g J0l~ AND PULL O~ OF HOLE. ~E BLIt~ ?, . DA ~ ~ FOR 10~I~. I ']2. OPE., BLIfID PAHS AND REC~ER TEST PL~. P~E _ _ DIESEL ~;D ~L VALV~ A~ S~ ]N . _ ' P~ITI~I. ' - 13. T~T ST~';DPIPE V~VES TO 3~ ~'- - -~.'~',:~-!?:~.'~ ~' b',im'~' -..-~-,-, .... : ~.~.._ -_.~.14. TEST KE~Y CO~S ..... :-' : {~t~;'>~j-~';~`~3 ]S. RECORD TEST INFO?J~TION - '' __ :: - - T~T FOP:4 SIGht A;ID SEND TO DRILLI;G S~- ~ ;-. : "- _- VISOR. - ' --=-' -' ~ 16 PE~O~-I COlPLETE BOPE TE~ . = - -- . -- _ ---~ FU~ICTIOf~LLY OPEP~TE BOPE ~ILY. -. - t ' -® Surface D~ ~rter Ssstem \ Maintenance & Operation ~ 1. Upon initial installation close annular I preventer and verify that ball valves ! - have opened properly. ! 2. Close annular preventer and blow air ~__ · through diverter lines every 12 hours. 3~ Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell .nipple. 16" Conductor 1111 i % 11 111 ii 1~ · · · /J' // ,4Y 0 0 0 0 ~ 0 0 ,;' 0 O, 0 0 4 T/4'I% I/'/c//,//,7'?' - mm il I j I I - -;q ARCO Alilkl, Inc. ~ , , ~nw "' date: -]8SSOB, ~-~ I , drawn by:~ dwg, no. Nf~ "og,qJt . i i CHECK LIST FOR NEW WELL PERMITS Company ~. cO Lease & Well No. ITEM APPROVE DATE ..~/~>~ - ~.~.,.y~ (1) Fee / (2) Loc (2 thru 8) (4) Casg (12 thru 20) (5) 'BOPE ~ /~ -~-g~- (2.1 thru 24) YES NO Is the permit fee attached . . .. 2. Is well to be located in a ~'. 3. Is well located proper distance from property .?~/~--~ 4, Is well located proper distance from other wells ....... .............~.... 5. Is sufficient undedicated acreage available in this pool . . 6. Is well to be deviated and is well bore plat included ........ ' 7. Is~operator the only affected party ........... ' ..... '.'. · 8. Can permit be approved before ten-day wait .......................... . 10. 11. 12. 13. 14. 15. 16.. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force Is a conservation order needed ''' Is administrative approval needed Is conductor string provided ........................................ ~ Is enough cement .used to circulate on conductor and surface , ...... .. ~ Will cement tie in surface and' intermediate or production strings . Will cement cover all known productive horizons ....... ............ ~. . Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst ~,T~ Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... H~ Are necessary diagrams of diverter ~'~;~';~g[;~;~;'~;;~g~;~ .__ -- Does BOPE have sufficient pressure rating - Test to ~J) ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~ RtI~ARKS Additional Remarks: o Geology: Engineering: M .cs - ~VA~~~ RAD -- JAL HJH ~ rev: 08/19/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Company LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. Well D.S. B-WSW-6 Field KUPARUK County, State N. SLOPE, ALASKA Date 11-3-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale , . RS Resistivity Short DLL .2 - 2000 RD " Deep " " · , SP Spontaneous Potential " i0-100, 100-200 , GR1 Gamma Ray 1 " " CN Compensated Neutron CD/CN 60 - 0 DENP Density Porosity " " DEN Density CDL 2 - 3 CORR Correction " -.5 - .5 iFIL~=LA151~ PROGRAM=LISTER 0:... ':"~ ' ......... ~'~ ,~1~ ~ ~ .............................. .~,~:.,..:..,......:...:~. ...... :..::~:.;..:::-;~.....:.- .- :. ~x::.; ;.::~ U~i' ~ ~ ~UlI~; ~ D ~ 0~ ~ ~ ~1 ~ ............................. · ~-.~.~p~:~.~, , ::~ ~:~: : · ~ ¢~ ~ ~. ~,1~ ~ ~'~ ~~ ................................ PAGE DEN CORR 2.1 2.1 .0 .i .0 .i -i .0 .i .i .1 ,i .A -i 0.0 0.i 0.3 0°5 0.i 0.0 0.0 .32..7 ~L e /' 2.i ' '-0.0 2.1 0.0 -- 2.1 -0.0 2,1 ..... -0.0 ' 2.1 -0.0 2.1 -0.0 2.1 l~.0 '2.i 0.0 A A 2'i 'u.u 2,?,. 2.1 -0.0 2.1 -0.i PAGE ARCO ALASKA INC. ~L¥~*::!..-~>~f~.,;!~::~:?v "?'i" ~.'i" ..' .".'i'~ : '.." >'"'~.'' '. . . ../'? :': ..':. 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