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Home My WebLink About185-016MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2W-02 KUPARUK RIV UNIT 2W-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 2W-02 50-029-21279-00-00 185-016-0 W SPT 5712 1850160 1500 2160 2160 2160 2160 550 800 800 800 4YRTST P Sully Sullivan 5/2/2023 pt to 3k for 500 psi dp. Pt with 90 deg diesel 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 2W-02 Inspection Date: Tubing OA Packer Depth 805 3000 2945 2930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230503081456 BBL Pumped:1.8 BBL Returned:1.4 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 16:00:31 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2W-02 KUPARUK RIV UNIT 2W-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 2W-02 50-029-21279-00-00 185-016-0 W SPT 5712 1850160 1500 2150 2150 2150 2150 175 440 440 440 INITAL P Brian Bixby 12/21/2022 30 MinPretest Initial 15 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 2W-02 Inspection Date: Tubing OA Packer Depth 460 2800 2750 2750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB221225045427 BBL Pumped:1.5 BBL Returned:1.5 Thursday, January 26, 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: 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 6949'feet 6504', 6529'feet true vertical 6290'feet None feet Effective Depth measured 6643'feet 6225', 6490', 6516'feet true vertical 6048'feet 5712', 5926', 5946'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/ J-55 6537' MD 5963' TVD Packers and SSSV (type, measured and true vertical depth) 6225' MD 6490' MD 6516' MD N/A 5712' TVD 5926' TVD 5946' 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: 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: N/A 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: HLB MFT Feed Through Packer Packer: HLB MFT Feed Through Packer Packer: Baker FB-1 Packer SSSV: Locked Out Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Senior RWO/CTD Engineer 6413-6478', 6595-6660', 6705-6718' feet 5864-5916', 6010-6061', 6097-6107' feet 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 110' ~ ~~ Injector ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-016 50-029-21279-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 25642 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2W-02 Plugs Junk measured Length Production Liner 6862' Casing 6244'6890' 3088' 110'Conductor Surface Intermediate 16" 9-5/8" 79' 3119' 3118' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 10:50 am, Dec 27, 2022 DTTMSTART JOBTYP SUMMARYOPS 9/15/2022 ACQUIRE DATA DRIFT W/ 15' X 2 1/8" OD DMY DRIFT DOWN TO NIPPLE REDUCER @ 6529' RKB; MEASURED BHP (3533 PSI) @ 6450' RKB; PULLED DV @ 6194' RKB; SET 1.812" CA-2 PLUG IN NIPPLE REDUCER @ 6529' RKB (OBTAIN PT & DDT ON PLUG). READY FOR E- LINE TUBING CUT. 9/22/2022 ACQUIRE DATA PERFORM TUBING CUTS W/ 2.0" RCT CUTTER FOR UPCOMING RIG WORK OVER RUN 1: CUT TUBING AT 6513.7' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6500.5' RKB RUN 2: CUT TUBING AT 6384.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6371.0' RKB RUN 3: CUT TUBING AT 6213.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6200.0' RKB JOB COMPLETE, READY FOR RIG 10/5/2022 MAINTAIN WELL PUMPED 8 BBLS METHANOL DOWN FL TO FREEZE PROTECT JOB COMPLETE 10/13/2022 RECOMPLETION Blow down steam and water in pits. Unhook interconnect. Bridle up. L/D derrick. Haul equipment T/ 2W. Pull pits away from sub. Load shop and office. Transport pits, shop and office T/ 2W. Set shop and office. Stage pits on pad. Pull sub off of well. Clean up around 3B-13. Moving sub to 2W-02 10/14/2022 RECOMPLETION Continue moving sub to 2W. Spot sub over well. Spot pits. Spot auxiliary equipment. Hook up steam and air to pits. Raise derrick. Berm in rig. Bridal down. Get measurements for riser height from tubing spool height. Rig up circ manifold in cellar. Take initial pressures T/IA/OA. Pressure test circ manifold & tiger tank T/ 3500 PSI. Bleed free gas off tubing & IA. Bullhead 260 Bbls seawater down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85 Bbls seawater down tubing @ 3 BPM. Record shut in pressure of 275 PSI. Developed plan to blend new KWF of 9.6 PPG. 10/15/2022 RECOMPLETION Condition 10.6 PPG NaCl/NaBr down T/ 9.6 PPG NaCl/NaBr. Bullhead 260 Bbls 9.6 PPG NaCl/NaBr down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85 Bbls 9.6 PPG NaCl/NaBr down tubing @ 3 BPM. Allow formation to relax. 30 minute no flow check. Install ISA BPV. Test from below. Nipple down tree and adaptor spool. Install blanking plug. Nipple up DSA and BOP. Install flow nipple. Fill stack with fresh water. Test BOPE to sundry requirements. 10/16/2022 RECOMPLETION Pull blanking plug and rig down testing equipment. Make up landing joint. BOLDS. Pull hanger to rig floor. Lay down hanger and landing joint. Circulate bottoms up. Lay down 500' of completion. Make up 6" drift and run through well head. Lay down drift. Continue pulling completion. Make up BHA #1 Overshot. Run in hole picking up drill pipe T/ 5584'. 10/17/2022 RECOMPLETION Continue picking up drill pipe. Engage fish @ 6205'. Jar fish free. Circulate out gas and light weight fluid. Pull out of hole. Pull out of hole. Lay down BHA #1 and fish. Seals and packer down to second cut recovered. Make up BHA #2 overshot and run in hole engage fish. Jar blast joints free. Circulate well. Pull out of hole. Lay down BHA #2 overshot. Rig up tubing handling equipment. 10/18/2022 RECOMPLETION Lay down blast ring fish. Clean and clear rig floor. Make up BHA #3 clean out assembly. Run in hole. Wash and ream from 6100' to tubing stub 6504'. Pump hi-vis pill around. Pull out of hole laying down drill pipe and BHA #3. Pull wear bushing. Rig up GBR tubing equipment. Verify joint count and running order. Run 3 1/2" completion string T/ 246'. 10/19/2022 RECOMPLETION Continue running 3 1/2" completion string. Wash overshot onto tubing stub. Fully located. Pick up space out. Make up hanger and landing joint. Circulated 9.6 PPG CI NaCl around. Land hanger. RILDS. Drop ball and rod. Pressure up and set tandem HES MFT packers. Test tubing to 3500 PSI for 30 min. Test IA to 3000 PSI for 30 MIn. Shear out SOV. Set HP BPV. Test BPV from below. Perform rig repair on annular preventer, change out drum clutch on draw works. 2W-02 CTD Summary of Operations 10/20/2022 RECOMPLETION Continue perform rig repair on annular preventer. Nipple down BOP. Set tree test plug. Nipple up adaptor spool and tree. Pressure test hanger void T/ 5000 PSI for 15 min. Rig up LRS, circ manifold and tiger tank. Pressure test tree T/ 5000 PSI for 15 min. Pull tree test dart and HP BPV. LRS pump 71 Bbls diesel freeze protect down IA. Rig down LRS. U-tube well. Rig down circ manifold. Secure tree and cellar. Pull pits away from sub and stage on pad. RDMO 10/23/2022 ACQUIRE DATA (PRE CTD) TREE VALVE TESTS POSTIVE/NEGATIVE (ALL PASS) 10/26/2022 ACQUIRE DATA SHAKE OFF BAITED BALL & ROD PULLING TOOL @ 6300' RKB. PULLED SOV @ 6165' RKB & SET DMY. IN PROGRESS. 10/27/2022 ACQUIRE DATA PULLED BAITED PULLING TOOL & BALL n' ROD @ 6497' RKB. PULLED 2.81'' RHC @ 6503' RKB. DRIFTED W/ 2.625'' x 17' DMY WHIPSTOCK TO TAG TBG CUT @ 6513' RKB (NO ANOMALIES). SET 2.81'' XX PLUG @ 6503' RKB (OBTAIN TBG TEST TO 2500). READY FOR E-LINE. 11/3/2022 ACQUIRE DATA LOG GR/CCL FROM 6497' RKB (JUST ABOVE XX PLUG @ 6404' RKB). TIE INTO K1 MARKER @ 6286' FOR MINUS 8 FT CORRECTION (CBL DATED 3/8/85). JOB IS READY FOR ELINE TO SET WS (WHEN SLB BACK IN FIELD) 11/14/2022 ACQUIRE DATA SET TOP OF BAKER HUGHES GEN II DELTA WHIPSTOCK 2 DEG LOHS AT 6455.0' PDC, CCL TO TOP OF WHIPSTOCK = 14.1', CCL STOP DEPTH = 6440.9' JOB COMPLETE, READY FOR CDR 11/16/2022 DRILLING SIDETRACK Completed rig down checklists, prepped for move to 2W-02 // Mob rig to 2W-02 spot and rig up over well // NU bops rig accepted @ 23:00 // change out riser and prep for bop test 11/17/2022 DRILLING SIDETRACK Grease and fluid pack bop and surface lines, perform shell test, test bops 250/3500 witness waived AOGCC Sean Sullivan // Completed BOP test, test surface lines, Pick up BHA# 1 deploy, RIH, flush well with seawater, swap to milling fluid and mill window F/6459.2 11/18/2022 DRILLING SIDETRACK Completed 2.80" exit , pooh deployed BHA# 2 2.5° lite AKO, Drilled build T/ 6590 MD 5861 TVD, POOH for lateral BHA , RIH with ER Lateral BHA .5° AKO w/ Dynamus bit, log RA tag for WS depth, tag bottom drill ahead 11/19/2022 DRILLING SIDETRACK Drilled ahead pulling wipers every 400' , 8068 started time drilling to attempt to drop angle 11/20/2022 DRILLING SIDETRACK Continued to drill ahead, 8065 encountered siderite cap unable to drop angle for planned TVD drop in lateral, multiple attempts to time mill or break through cap unsuccessful, pooh for higher bend motor to "break through", Deployed BHA# 4 1.2° AKO motor with re-run dynamus , RIH tie in +14' correction, clean counter, start drilling unable to drop angle, start time drilling 11/21/2022 DRILLING SIDETRACK Continued with time drilling, broke through hard layer @ 9080' , motor stalled @ 9149' plugged off with beads, pooh for ER lateral assembly, RIH w/ lateral assembly tie in -8.5' correction drilled to midnight depth 9573 11/22/2022 DRILLING Continued to drill ahead in C1 trying to build angle loosing coil wt 11/23/2022 DRILLING Continued drilling ahead slowly toward TD @ 11861 11/24/2022 DRILLING SIDETRACK Continued to drill ahead toward new TD @ 11,995', TD well, perform swab wiper, RIH tie in K1 -11' correction, stacked in BOW 3 times, Passed through continued to bottom confirming @ 12,000', 11/25/2022 DRILLING SIDETRACK After confirming TD @ 12,000 pump 70bbls 11.4 liner running pill laying in to window, continued to pooh displacing well to 11.4 kwf, Pick up L1 lower liner completion 44 jts slotted liner, RIH with lower completion dropping on bottom leaving top of liner 10,681', pump liner running pill for second liner run, pooh and pick up second run 57 jts slotted liner, ran in hole and latched into lower completion pu wt 50K confirm latch, pump off liner TOL 8892', pump 20 bbls liner running pill start pooh for upper completion 11/26/2022 DRILLING SIDETRACK Pick up and run L1 upper section of completion, latch into mid completion confirm latch, pump off completion check tree bolts, pump sea water and check reservoir pressure @ 11ppg, pooh swapping well to seawater, freeze protect 2500' to surface, continue out of hole perform end of well ops, rig down checklists and nipple down stack rig released 00:00 11/27/22 12/1/2022 ACQUIRE DATA DRIFT TO TOP OF LINER @ 6450' RKB.MEASURE SBHP AT 6450' RKB (2786 psi) JOB COMPLETE. 12/7/2022 PUMPING TRACKING ONLY FREEZE PROTECT FL WITH 8 BBLS METHANOL Page 1/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/16/2022 00:00 11/16/2022 06:00 6.00 MIRU, MOVE RURD P Continue with rig down checklists // prep for rig transport to 2W-02 // Trucks on location 0.0 0.0 11/16/2022 06:00 11/16/2022 06:30 0.50 MIRU, MOVE MOB P Cruz pick up shop and halfway house for tranport 0.0 0.0 11/16/2022 06:30 11/16/2022 07:00 0.50 MIRU, MOVE SFTY P Pre-job meeting with Cruz for pulling off well and moving to 2W pad 0.0 0.0 11/16/2022 07:00 11/16/2022 07:15 0.25 MIRU, MOVE MOB P Jack service module , sow up , pull mats 0.0 0.0 11/16/2022 07:15 11/16/2022 07:30 0.25 MIRU, MOVE MOB P Pull service module from well row and spot on pad 0.0 0.0 11/16/2022 07:30 11/16/2022 07:45 0.25 MIRU, MOVE MOB P Jack sub module , sow up scarf area around sow and turn arc for additional tracktion pull mats 0.0 0.0 11/16/2022 07:45 11/16/2022 08:00 0.25 MIRU, MOVE MOB P Pull sub off well and spot on pad for jeep up 0.0 0.0 11/16/2022 08:00 11/16/2022 08:30 0.50 MIRU, MOVE MOB P Drop pull sows , jeep up both modules sow up , perform final walk arounds verify final safe out 0.0 0.0 11/16/2022 08:30 11/16/2022 13:42 5.20 MIRU, MOVE MOB P Mob rig 09:30 CPF3 // 11:30 Oliktok Y // 13:20 CPF2 // Park CPF2 pad till 13:42 for fuel of sows 0.0 0.0 11/16/2022 13:42 11/16/2022 15:45 2.05 MIRU, MOVE MOB P Mob from CPF2 to 2W pad 0.0 0.0 11/16/2022 15:45 11/16/2022 16:00 0.25 MIRU, MOVE MOB P Stage on pad, remove jeeps prep for spotting on well 0.0 0.0 11/16/2022 16:00 11/16/2022 17:45 1.75 MIRU, MOVE RURD P Drop jeep from sub, prep well , mat and herulite , spot sub over well // spot mats under rig 0.0 0.0 11/16/2022 17:45 11/16/2022 19:00 1.25 MIRU, MOVE RURD P Spot mats for pits // spot pits in place // finish installing mats // 0.0 0.0 11/16/2022 19:00 11/16/2022 22:00 3.00 MIRU, MOVE RURD P Safe out rig // work rig up checklists // 0.0 0.0 11/16/2022 22:00 11/16/2022 23:00 1.00 MIRU, WHDBOP NUND P Nipple up BOPs *** Rig Accepted 23:00 11/16/2022 *** 0.0 0.0 11/16/2022 23:00 11/17/2022 00:00 1.00 MIRU, WHDBOP CTOP P Change out riser // RKBs // load fresh water into pits for circulating // start greasing valves and prepping for bop test 0.0 0.0 11/17/2022 00:00 11/17/2022 03:00 3.00 MIRU, WHDBOP CTOP P Complete grease of stack // Valve crew grease tree // flood up surface lines with fresh water // pressure test PUTZ no leaks // fluid pack surface lines and stack // Shell test good 0.0 0.0 11/17/2022 03:00 11/17/2022 04:12 1.20 MIRU, WHDBOP BOPE P BOP test wintess waived by Sean Sullivan 250/3500 psi Test 1. Swab 2 - Pass Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 - Pass Test 3. BOP TV 1, Charlie 3, 7, & 11- Pass Test 4. Manual choke D & Super choke C - Pass 0.0 0.0 11/17/2022 04:12 11/17/2022 05:00 0.80 MIRU, WHDBOP BOPE T Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 -Fail / Pass grease valve and retest - good test 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 2/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2022 05:00 11/17/2022 10:30 5.50 MIRU, WHDBOP BOPE P Test 6. Charlie 1, 9, Bravo 5, and Tango 1 install TIW test joint Test 7. Lower 2 pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP 250/2500 Test 9. Upper 2 pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 Test 11. 2-3/8 pipe slip rams, TIW#2 check N2 levels Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT 0.0 0.0 11/17/2022 10:30 11/17/2022 12:00 1.50 PROD1, WHPST CTOP P Unstab injector, make up drillers side PDL, PT - good. Unstab and stoe, stab ODS PDL, flood up to tiger tank, PT both - good. **Swap to high line power 12:00 0.0 0.0 11/17/2022 12:00 11/17/2022 14:00 2.00 PROD1, WHPST PULD P PJSM, PU BHA #1, window milling assembly, coil trak, 1° Fixed bend motor, string mill and diamond speed mill * guage in 2.80" no go on both speed mill and reamer 0.0 78.1 11/17/2022 14:00 11/17/2022 15:30 1.50 PROD1, WHPST TRIP P RIH W BHA #1, window milling assembly, close EDC and spin the bit while RIH and flushing well with seawater taking returns to the tiger tank. 78.1 6,286.0 11/17/2022 15:30 11/17/2022 15:42 0.20 PROD1, WHPST DLOG P tie into the K1 for a -5.5' correction 6,286.0 6,351.9 11/17/2022 15:42 11/17/2022 16:18 0.60 PROD1, WHPST DISP P Displace well to power pro 6,286.0 6,351.9 11/17/2022 16:18 11/17/2022 16:30 0.20 PROD1, WHPST TRIP P Bring power pro back inside, RIH and dry tag TOW @ 6,459.47' with a 2.1' pinch point, corrected TOWS - 6,457.4' 6,351.9 6,459.0 11/17/2022 16:30 11/17/2022 16:42 0.20 PROD1, WHPST CIRC P PU Wt 37 k lbs, PUH and set rate, RBIH WH 26 psi, IA 0 psi, OA 2 psi, CT 4133 psi @ 1.86 in and out,BHP 3164 psi, Free spin 750 CT RIH W Wt 22.76 k lbs 6,459.0 6,459.2 11/17/2022 16:42 11/18/2022 00:00 7.30 PROD1, WHPST WPST P Milling 2.80" exit window, F/ 6459.2 T/6465.8 6,459.2 6,465.8 11/18/2022 00:00 11/18/2022 06:12 6.20 PROD1, WHPST WPST P Mill ahead on window F/ 6465.8 T/ 6470 Exit 4.5" @ 6467.3 6,465.8 6,471.0 11/18/2022 06:12 11/18/2022 07:30 1.30 PROD1, WHPST WPST P Drilling ahead in formation. WH 0, IA 506 psi, OA 15 psi, CT 4481 psi @ 1.88 bpm in and 1.72 bpm out. BHP 3126 psi, 10.2 ppg EMW at the window. Experiancing heavy losses when attempting to hold 11.8 ppg at the window. 6,471.0 6,480.0 11/18/2022 07:30 11/18/2022 09:06 1.60 PROD1, WHPST MILL P TD rat hole at 6,480'. PU Wt 33 k lbs, Perform reaming passews at HS, 30L, 30R, and 180 ROHS. Dry drift - clean, Tag bottom 6,480.0 6,480.0 11/18/2022 09:06 11/18/2022 10:30 1.40 PROD1, WHPST TRIP P PU Wt 32 k lbs, PUH into casing, jog tubing, open EDC stage pump to 2.34 bpm in POOH ~100 ft/min, getting ~1.9 bpm back 6,480.0 78.1 11/18/2022 10:30 11/18/2022 11:54 1.40 PROD1, WHPST PULD P Bump up, space out, PJSM, PUD BHA #1. **Mills no go out 2.80" 78.1 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 3/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2022 11:54 11/18/2022 12:24 0.50 PROD1, DRILL CIRC P Stab injector and jet stack, unstab. 0.0 0.0 11/18/2022 12:24 11/18/2022 12:54 0.50 PROD1, DRILL CTOP P Swap out hour'd out upper quick connect, wire tested at 85.2 Ohms and greater than 550 M Ohms 0.0 0.0 11/18/2022 12:54 11/18/2022 14:24 1.50 PROD1, DRILL PULD P PD BA #2, build drilling assembly, 2.5 -° AKO motor with rebuild HCC bicenter bit. 0.0 72.2 11/18/2022 14:24 11/18/2022 15:42 1.30 PROD1, DRILL CTOP P RIH with BHA #2 72.2 6,288.0 11/18/2022 15:42 11/18/2022 15:54 0.20 PROD1, DRILL CTOP P Tie into the K1 for a -10' correction, close EDC, PU Wt 34 k lbs. 6,288.0 6,320.0 11/18/2022 15:54 11/18/2022 16:03 0.15 PROD1, DRILL TRIP P RIH, PU Wt 34 k lbs, pass thorough window - clean Set rate and gather parameters. WH 0 psi, IA 15 psi, OA 19 psi, CT 4006 psi at 1.87 bpm in and 1.78 bpm out, coke wide open and 10.32 EMW at the window. BHP 3152 psi. Free spin 525 psi. 6,320.0 6,480.0 11/18/2022 16:03 11/18/2022 18:03 2.00 PROD1, DRILL DRLG P OBD - CT Wt 20 k lbs, CT 4032 psi, WOB 1.5 k lbs, ROP ~ 80 TD 6590' MD 5861TVD 46.5 average DLS 6,480.0 6,590.0 11/18/2022 18:03 11/18/2022 19:33 1.50 PROD1, DRILL TRIP P POOH for lateral assembly // Tag up and space out 1.2' for pressure un-deploy 6,590.0 75.0 11/18/2022 19:33 11/18/2022 20:33 1.00 PROD1, DRILL PULD P PJSM , Pressure un-deploy BHA# 2 build assembly 75.0 0.0 11/18/2022 20:33 11/18/2022 22:00 1.45 PROD1, DRILL PULD P Pick up and deploy BHA# 3 lateral bha .5° AKO w/ nov agitator and Dynamus Bit 0.0 78.0 11/18/2022 22:00 11/18/2022 23:06 1.10 PROD1, DRILL TRIP P RIH w/ BHA # 3 0.0 6,300.0 11/18/2022 23:06 11/18/2022 23:21 0.25 PROD1, DRILL DLOG P Log K1 for depth control // -11' correction // 6,300.0 6,336.0 11/18/2022 23:21 11/18/2022 23:36 0.25 PROD1, DRILL TRIP P RIH to bottom // Log RA tag for depth Tag @ 6464// RIH to bottom 6,336.0 6,590.0 11/18/2022 23:36 11/19/2022 00:00 0.40 PROD1, DRILL DRLG P Drill ahead F/ 6590' T/ 6608' 6,590.0 6,608.0 11/19/2022 00:00 11/19/2022 02:15 2.25 PROD1, DRILL DRLG P Drill Ahead F/ 6608 T/ 6786 790 diff free spin 4710 pp 1.88 in 1.38 out Ann 3517 Drilling break 200'/hr stall 5.5k DHWOB 6,608.0 6,786.0 11/19/2022 02:15 11/19/2022 02:24 0.15 PROD1, DRILL WPRT P Wiper up to 6600' poor returns check hole conditions // Pu Wt 32K 6,786.0 6,786.0 11/19/2022 02:24 11/19/2022 05:12 2.80 PROD1, DRILL DRLG P Drill Ahead F/ 6786 T/ 6987 890 diff free spin 6,786.0 6,987.0 11/19/2022 05:12 11/19/2022 05:27 0.25 PROD1, DRILL WPRT P PU Wt 32 k lbs, PUH on scheduled wiper #1 6,987.0 6,602.0 11/19/2022 05:27 11/19/2022 05:42 0.25 PROD1, DRILL WPRT P RBIH, RIH Wt 19-18 k lbs 6,602.0 6,987.0 11/19/2022 05:42 11/19/2022 12:36 6.90 PROD1, DRILL DRLG P BOBD, WH 299 psi, IA 339 psi, OA 24 psi, CT 4776 psi at 1.87 bpm in and 1.52 bpm out. Free spin 858 psi. CT Wt 17 k lbs, WOB 0.5 to 3 k, ROP variable. Longer hard spot 7,246 - 7,255' - 30 min BHA wipe, PU Wt 35 klbs Pushed wiper ~ 100 feet 6,987.0 7,503.0 11/19/2022 12:36 11/19/2022 12:51 0.25 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on wiper #2 7,503.0 6,700.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 4/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2022 12:51 11/19/2022 13:06 0.25 PROD1, DRILL WPRT P RBIH 6,700.0 7,503.0 11/19/2022 13:06 11/19/2022 16:48 3.70 PROD1, DRILL DRLG P BOBD, WH 300 psi, IA 535 psi, OA 26 psi. CT 4,544 psi @ 1.88 bpm in and 1.73 BPM out, BHP 11.4 ppg, Free spin diff 725 psi. 7,503.0 8,008.0 11/19/2022 16:48 11/19/2022 18:48 2.00 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on long wiperr for tie in chasing 5x5 sweep, lanch second sweep to timne out for build. Tie in +1' correction, Jetted 4.5", run back in hole to drill 8,008.0 8,008.0 11/19/2022 18:48 11/19/2022 19:18 0.50 PROD1, DRILL DRLG P BOBD F/ 8008' T/ 8056 1.8 bpm 725 diff 8,008.0 8,056.0 11/19/2022 19:18 11/20/2022 00:00 4.70 PROD1, DRILL DDRL P Time drill to drop angel F/ 8056' T/ 8092' Set 30 min then push 10'/hr for 3 feet unable to drop angle Trough attempt to make shelf 8,056.0 8,092.0 11/20/2022 00:00 11/20/2022 01:18 1.30 PROD1, DRILL DDRL P Time drill to drop angel F/ 8092' T/ 8115' Set 30 min then push 10'/hr for 3 feet unable to drop angle Trough attempt to make shelf 8,092.0 8,115.0 11/20/2022 01:18 11/20/2022 03:48 2.50 PROD1, DRILL DRLG P Drill ahead F/ 8115 T/ 8326 8,115.0 8,326.0 11/20/2022 03:48 11/20/2022 04:18 0.50 PROD1, DRILL WPRT P Geo wiper unable to drop angle for planned TVD drop 8,326.0 8,326.0 11/20/2022 04:18 11/20/2022 06:09 1.85 PROD1, DRILL DRLG P BOBD F/ 8326 T/ 8800 1.8 bpm 5100pp 725 diff free spin 8,326.0 8,800.0 11/20/2022 06:09 11/20/2022 06:27 0.30 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on scheduled wiper #2, slight WOG tugs to -1.5 k lbs from 8,492 - 8,362'. 8,800.0 7,990.0 11/20/2022 06:27 11/20/2022 06:45 0.30 PROD1, DRILL WPRT P RBIH, Ct Wt 16 - 12 k lbs on trip, similar WOB bobbls to 0.3 k lbs an trip in from 8,326-8496'. 7,990.0 8,800.0 11/20/2022 06:45 11/20/2022 07:03 0.30 PROD1, DRILL DRLG P BOBD, WH 308 psi, IA 754 psi, OA 31 psi. CT 4635 psi at 1.84 bpm in and 1.6 bpm out. Free spin 704 psi, BHP 3647', targeting 11.4 ppg EMW 8,800.0 8,849.0 11/20/2022 07:03 11/20/2022 09:30 2.45 PROD1, DRILL DRLG P Roll TF to LS and drill ahead to hard bottom stop stick. Near bit inc 88.31° Make 5 gouging passes, PUH at 15 ft/min one BHA length ~ 70', RBIH at 3' ft/min until seeing WOB ~8,850' Make repeated gouging passes for a total of 5 times 8,849.0 8,849.0 11/20/2022 09:30 11/20/2022 12:18 2.80 PROD1, DRILL DRLG P RIH to 8850, WOB increase, park stick for 20 minutes at full rate, TF LS Time drill at 1 ft/hr from 8849.03', near bit inc 88.15°, stage up ROP in incremets to 5 ft/hr. Stacking pipe, bit not moving, diff sticking. Break out and drill past troughing. 8,849.0 8,874.0 11/20/2022 12:18 11/20/2022 14:54 2.60 PROD1, DRILL DRLG P PU, bypass HP screens, add 2 ppb beads to the Hi-vis sweep, pump 5x5 sweep, Weight transfer at slow coil speeds improved but still unable to drop angle. 8,874.0 8,965.0 11/20/2022 14:54 11/20/2022 16:54 2.00 PROD1, DRILL TRIP T PU Wt 35 k lbs, POOH for higher bend motor. Slight WOB tug to 1.2 k lbs @ 7529'. Window clean. Open edc, Pump out of hole targeting 11.4 ppg EMW 8,965.0 78.3 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 5/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2022 16:54 11/20/2022 18:24 1.50 PROD1, DRILL PULD T PUD BHA # 3 ERD drilling assembly. 78.3 0.0 11/20/2022 18:24 11/20/2022 20:00 1.60 PROD1, DRILL PULD T PD BHA# 4 High bend assembly for breaking through Siderite cap / 1.2° AKO w/ Re-run dynamus 0.0 72.0 11/20/2022 20:00 11/20/2022 22:30 2.50 PROD1, DRILL TRIP T RIH with high bend assembly // Tie in K1 +14' correction // Close EDC // PU Wt. at window 32K // 72.0 8,965.0 11/20/2022 22:30 11/20/2022 23:00 0.50 PROD1, DRILL DRLG T OBD F/ 8965' T/ 9002 1.8 bpm 450 diff 34K pick up 8,965.0 9,002.0 11/20/2022 23:00 11/21/2022 00:00 1.00 PROD1, DRILL DDRL T Unable to drop angle start time drilling 9,002.0 9,002.0 11/21/2022 00:00 11/21/2022 03:54 3.90 PROD1, DRILL DDRL T Time drill trough for time drilling //9011 9,002.0 9,011.0 11/21/2022 03:54 11/21/2022 04:06 0.20 PROD1, DRILL WPRT T BHA wiper to aidin weight transfer 9,011.0 9,011.0 11/21/2022 04:06 11/21/2022 06:12 2.10 PROD1, DRILL DDRL T Drilling ahead with reduced pump rate targeting higher WOB, 1.2 bpm in, WOB to 3 k lbs attempting to side track - unsuccessful 9,011.0 9,060.0 11/21/2022 06:12 11/21/2022 09:12 3.00 PROD1, DRILL DDRL T Make 3 low side troughing passes ~ 70 feet, make an additonal pass back 35'. RIH and target higher WOB with reduced pump rate to 1.5 bpm. 9,060.0 9,106.0 11/21/2022 09:12 11/21/2022 09:45 0.55 PROD1, DRILL DDRL T Broke through, Inc fell to 83 °. Drop in structure and drill ahead to stall at 9146'. 9,106.0 9,146.0 11/21/2022 09:45 11/21/2022 10:00 0.25 PROD1, DRILL DDRL T Unable to pump through coil / BHA after stall. Trouble shoot and attempt to cear. Issue is the BHA, most probably the motor. Bleed pumps, open EDC, regain target ECD of 11.4 PPG @ the window. 9,146.0 9,078.0 11/21/2022 10:00 11/21/2022 11:00 1.00 PROD1, DRILL TRIP T POOH in open hole with BHA # 4, hole relatively clean and window clean. 9,078.0 6,434.0 11/21/2022 11:00 11/21/2022 12:24 1.40 PROD1, DRILL TRIP T Slow troll the 4.5" big tail pipe jetting cuttings. 6,434.0 77.8 11/21/2022 12:24 11/21/2022 14:06 1.70 PROD1, DRILL PULD T PUD BHA # 4 medium bend motor. Cycle EDC to test at surface post pumping beads and opening in open hole. EDC sealed but produced an error code. Due to risk of opening EDC then having checks fail and not being able to close the EDC PUD following failed check checklist with EDC closed. 77.8 0.0 11/21/2022 14:06 11/21/2022 14:30 0.40 PROD1, DRILL CTOP T Reconfigure coiltrack tool 0.0 78.0 11/21/2022 14:30 11/21/2022 16:18 1.80 PROD1, DRILL PULD T PD BHA #5, 0.5 ° AKO with RB HCC dynamus 0.0 78.0 11/21/2022 16:18 11/21/2022 19:03 2.75 PROD1, DRILL TRIP T RIH with ERD drilling assembly.// Tie in K1 -8.5' correction // Window clean // PU WT 34K // 78.0 9,149.0 11/21/2022 19:03 11/21/2022 22:27 3.40 PROD1, DRILL DRLG P BOBD F/ 9149 T/ 9506' 1.8 bpm 4923pp 699diff 9,149.0 9,506.0 11/21/2022 22:27 11/21/2022 23:15 0.80 PROD1, DRILL WPRT P 1000' wiper // Pu.Wt. 41K 9,506.0 9,506.0 11/21/2022 23:15 11/22/2022 00:00 0.75 PROD1, DRILL DRLG P BOBD F/ 9506' T/ 9573 1.8bpm 5200psi 750diff 3824ann 1.82bpm in 9,506.0 9,573.0 11/22/2022 00:00 11/22/2022 04:15 4.25 PROD1, DRILL DRLG P BOBD F/ 9573' T/ 9830 1.8bpm 5200psi 750diff 3824ann 1.82bpm in 1.85 out 9,573.0 9,830.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 6/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2022 04:15 11/22/2022 05:33 1.30 PROD1, DRILL WPRT P Wiper to window to clean hole, clean window 9,830.0 6,480.0 11/22/2022 05:33 11/22/2022 05:45 0.20 PROD1, DRILL DLOG P Tie into the RA tag for a +1.5' correction. 6,480.0 6,498.8 11/22/2022 05:45 11/22/2022 06:03 0.30 PROD1, DRILL CIRC P Jet the 4.5" tailpipe 6,498.8 6,407.0 11/22/2022 06:03 11/22/2022 07:15 1.20 PROD1, DRILL TRIP P RBIH, catch 9150-9165' with a MAD pass. Return truck on location, roll to 2 pit system, start exporting mud to the tiger tank for mud swap. 6,407.0 9,830.0 11/22/2022 07:15 11/22/2022 13:03 5.80 PROD1, DRILL DRLG P BOBD, as new mud exited the bit. Dril lahead ~100-180 ft/hr w ~1.4 WOB. PU Wt 32 k lbs, Pick up for new mud parameters @ 9,910' WH 346, IA 903 psi, OA 31 psi CT 4737 psi @ 1.82 bpm in and 1.6 bpm out. Free spin 720 psi, RIH wt 12 k lbs, BOBD, ** New mud at the bit 9,830' 9,830.0 10,236.0 11/22/2022 13:03 11/22/2022 13:21 0.30 PROD1, DRILL WPRT P PU Wt 44 k lbs. PUH on scheduled wiper #1 - clean trip 10,236.0 9,400.0 11/22/2022 13:21 11/22/2022 13:39 0.30 PROD1, DRILL WPRT P RBIH, CT Wt 15-12 k lbs - clean trip 9,400.0 10,236.0 11/22/2022 13:39 11/22/2022 20:00 6.35 PROD1, DRILL DRLG P WH 307 psi, IA 920 psi, OA 31 psi, CT 5,031 psi @ 1.85 in 1.72 bpm out, free spin 720 psi, BHP 3818 psi targeting 11.4 ppg EMW at the window, 12.49 ppg at the bit. OBD, CT Wt 8 k lbs, WOB 1 k lbs. 10,236.0 10,628.0 11/22/2022 20:00 11/22/2022 20:45 0.75 PROD1, DRILL WPRT P Geo Wiper for extension of polygon 10,628.0 10,628.0 11/22/2022 20:45 11/23/2022 00:00 3.25 PROD1, DRILL DRLG P WH 279 psi, IA 503 psi, OA 31 psi, CT 5,031 psi @ 1.85 in 1.72 bpm out, free spin 720 psi, BHP 3818 psi targeting 11.4 ppg EMW at the window, 12.49 ppg at the bit. OBD, CT Wt -8 k lbs, WOB 1 k lbs. 10,628.0 10,878.0 11/23/2022 00:00 11/23/2022 02:45 2.75 PROD1, DRILL DRLG P WH 279 psi, IA 503 psi, OA 31 psi, CT 5,031 psi @ 1.85 in 1.72 bpm out, free spin 720 psi, BHP 3818 psi targeting 11.4 ppg EMW at the window, 12.49 ppg at the bit. OBD, CT Wt -8 k lbs, WOB 1 k lbs. 10,878.0 10,974.0 11/23/2022 02:45 11/23/2022 04:24 1.65 PROD1, DRILL WPRT P PU Wt 33 k lbs, Wiper to window for tie in and clean hole 10,974.0 6,490.0 11/23/2022 04:24 11/23/2022 04:33 0.15 PROD1, DRILL DLOG P Tie into the RA tag for a +3' correction 6,490.0 6,500.0 11/23/2022 04:33 11/23/2022 04:39 0.10 PROD1, DRILL DLOG P Pull to 6448' MD - 5,757.56' TVD park and trap 3,502 psi. Bleed pressure to 3,415' and monitor, stable at 11.4 ppg EMW 6,500.0 6,448.0 11/23/2022 04:39 11/23/2022 04:51 0.20 PROD1, DRILL DLOG P Pull to 6448' MD - 5,757.56' TVD park and trap 3,502 psi. Bleed pressure to 3,415' and monitor, stable at 11.4 ppg EMW 6,500.0 6,448.0 11/23/2022 04:51 11/23/2022 06:39 1.80 PROD1, DRILL TRIP P RBIH - RIH wt 3 k lbs 6,448.0 10,974.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 7/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2022 06:39 11/23/2022 19:09 12.50 PROD1, DRILL DRLG P WH 186 psi, IA 516 psi, OA 30 psi, CT 5,430 psi @ 1,86 bpm in and 1.73 bpm out. Free spin 791 psi. BHP 3911 psi targeting 11.4 EMW getting 12.8 ppg at the bit. OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k lbs, ROP slow, in narpy rock Geo says Ankerite in the samples 10,974.0 11,350.0 11/23/2022 19:09 11/23/2022 20:09 1.00 PROD1, DRILL WPRT P 800' wiper 11,350.0 11,350.0 11/23/2022 20:09 11/24/2022 00:00 3.85 PROD1, DRILL DRLG P WH 177 psi, IA 656 psi, OA 35 psi, CT 5,430 psi @ 1,86 bpm in and 1.73 bpm out. Free spin 791 psi. BHP 3911 psi targeting 11.4 EMW getting 12.8 ppg at the bit. OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k lbs, ROP slow, in narpy rock 11,350.0 11,500.0 11/24/2022 00:00 11/24/2022 05:30 5.50 PROD1, DRILL DRLG P WH 336 psi, IA 506 psi, OA 28 psi, CT 5,067 psi @ 1,86 bpm in and 1.78 bpm out. Free spin 791 psi. BHP 3875 psi targeting 11.4 EMW getting 12.8 ppg at the bit. OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k lbs, ROP slow, in narpy rock 11,500.0 11,662.0 11/24/2022 05:30 11/24/2022 05:48 0.30 PROD1, DRILL WPRT P PU Wt 32 k lbs PUH on wiper trip #1, 11,662.0 10,950.0 11/24/2022 05:48 11/24/2022 06:12 0.40 PROD1, DRILL WPRT P RBIH, Ct Wt 9.5-2.5 k lbs 10,950.0 11,662.0 11/24/2022 06:12 11/24/2022 15:42 9.50 PROD1, DRILL WPRT P WH 311 psi, IA 598 psi, OA 33 psi, CT 5030 psi @ 1.82 bpm in and out. Free spin 770 psi. BHP 3920 psi targeting 11.4 ppg at the window, running 12.85 ppg at the bit. Drill ahead pumping 10 bbl (1ppb beaded sweeps) continuously as one exits the coil, one enters. CT Wt 0 to -5 k lbs, WOB ~ 0.8 to 0.5 k lbs. 11,662.0 11,995.0 11/24/2022 15:42 11/24/2022 19:54 4.20 PROD1, DRILL WPRT P PU Wt 32 k lbs PUH on wiper trip.//Tag up 11,995.0 78.0 11/24/2022 19:54 11/24/2022 21:18 1.40 PROD1, DRILL TRIP P RIH to window confirm KWF // Tie in K1 -11' correction 78.0 6,450.0 11/24/2022 21:18 11/24/2022 21:33 0.25 PROD1, DRILL CTOP P Static at window for KWF 6449.99 MD 5854.43 TVD Ann 3389 Eqiv Md Wt. = 11.13 KWF 11.4 6,450.0 6,450.0 11/24/2022 21:33 11/25/2022 00:00 2.45 PROD1, DRILL TRIP P RIH to confirm TD, stack out in window work through, pick up and run through window again slight WOB bobble, continue in to confirm TD @ 12000' 6,450.0 12,000.0 11/25/2022 00:00 11/25/2022 00:30 0.50 PROD1, DRILL CIRC P Circulate LRP to bit 12,000.0 12,000.0 11/25/2022 00:30 11/25/2022 03:45 3.25 PROD1, DRILL DISP P POOH laying in 11.4 LRP // Paint TD EOP flag 10621.4' end of coil // 12,000.0 81.0 11/25/2022 03:45 11/25/2022 04:00 0.25 PROD1, DRILL OWFF P Flow check well // PJSM laying down tools dead well 81.0 81.0 11/25/2022 04:00 11/25/2022 04:45 0.75 PROD1, DRILL PULD P Lay down BHA# 4 on dead well 81.0 0.0 11/25/2022 04:45 11/25/2022 05:00 0.25 COMPZ1, CASING BOPE P Function test BOPs 0.0 0.0 11/25/2022 05:00 11/25/2022 05:45 0.75 COMPZ1, CASING CTOP P Rig up to pick up liner // inspect blocks and liner running equipment 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 8/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2022 05:45 11/25/2022 07:30 1.75 COMPZ1, CASING PUTB P PU Lower L1 completion 44 joints of 4.6 lb/ft slotted 3-3/8" STL liner over a non ported bull nose and topped with a Northern solutions QCLL ( LOA 1315.96') 0.0 1,315.0 11/25/2022 07:30 11/25/2022 08:00 0.50 COMPZ1, CASING PULD P PU BHA # 6, lower liner running assembly, bump up, set counters, ** lost 13.8 bbls of KW fluid 1,315.0 1,360.0 11/25/2022 08:00 11/25/2022 11:30 3.50 COMPZ1, CASING RUNL P RIH with lower L1 completion, tie into yellow window flag, found at 6368.75' Correction -8.44' Pushed KW away the whole trip in, suspect its going to the mother bore. Attempt to tie into the K1, abandoned as WOB increased, and CT weight decreased. PU Wt 41 k lbs. Continue in hole at speed, caught K1 on the drive by estimate ~ - 2' correction, Saw RA tag on drive by, +1.5' correction - essentially on depth. Set liner on bottom, 11,995.55' PU Wt 44 k lbs, WOB to -2.7 lk lbs. RBIH, stack -9 k CT Wt, WOB 3.26 k lbs, pump to 1.5 bpm, wait for dif to climb to 977 psi, PU wt 36 k, lbs, WOB -1 k lbs. *** TOL 10,684' 1,360.0 11,982.0 11/25/2022 11:30 11/25/2022 15:00 3.50 COMPZ1, CASING TRIP P PUH, park and remove liner length. Displace liner running pill to bit, paint yellow flag @ 4543.06', continue out of hole. 11,982.0 62.3 11/25/2022 15:00 11/25/2022 15:36 0.60 COMPZ1, CASING PULD P Flow check while PJSM, LD BHA # 6, lower liner running assembly. 62.3 0.0 11/25/2022 15:36 11/25/2022 16:12 0.60 COMPZ1, CASING CTOP P Prep floor for running liner, inspect liner running equip. and blocks 0.0 0.0 11/25/2022 16:12 11/25/2022 19:00 2.80 COMPZ1, CASING PUTB P PU Middle L1 completion 57 joints of 4.6 lb/ft slotted 3-3/8" STL liner over a QCLL dissolving bull nose and topped with a Northern solutions QCLL ( LOA 1791.88' ) 0.0 1,791.9 11/25/2022 19:00 11/25/2022 19:30 0.50 COMPZ1, CASING PULD P Rig down liner running equipment // Pick up baker BHA 1,791.9 1,791.9 11/25/2022 19:30 11/25/2022 22:15 2.75 COMPZ1, CASING RUNL P RIH with L1 mid completion , tie into yellow window flag @ 6345.86' , correction -11' correction , Pushed away returns while running in hole, pass through window clean continue in hole, ran to bottom clean latched into lower section @ 10861' PU 50K confirm latch pump off liner 1,791.9 10,684.0 11/25/2022 22:15 11/25/2022 22:45 0.50 COMPZ1, CASING CIRC P Circulate LRP to GS 10,684.0 10,650.0 11/25/2022 22:45 11/26/2022 00:00 1.25 COMPZ1, CASING TRIP P POOH laying in LRP to window continue to surface 10,650.0 5,360.0 11/26/2022 00:00 11/26/2022 01:00 1.00 COMPZ1, CASING TRIP P Continue out of hole for second liner run 5,360.0 88.0 11/26/2022 01:00 11/26/2022 01:48 0.80 COMPZ1, CASING PULD P PJSM and flow check, lay down BHA# 7 dead well 88.0 0.0 11/26/2022 01:48 11/26/2022 04:48 3.00 COMPZ1, CASING PUTB P Pick up 77 jts 2-3/8" liner and 3 solid pups Total liner footage picked up 2440.15 0.0 2,440.2 11/26/2022 04:48 11/26/2022 05:18 0.50 COMPZ1, CASING PULD P PU BHA #8, check pack offs - good, bump up, set counters 2,440.2 2,485.2 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 Page 9/9 2W-02 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/26/2022 05:18 11/26/2022 07:00 1.70 COMPZ1, CASING RUNL P RIH w/ BHA # 8, upper L1 liner running assembly. Tie into the flag for a -7' correction. PU Wt 31 k lbs. WOB -8.6 k lbs. Continue in hole. Find liner top At 8881' CTMD, WOB tot 11 k lbs. PU Wt , 50 k lbs, WOB -20 k lbs. RBIH, stack 11 k WOB, CT wt, 9 k lbs. Pump 1.5 bpm, dif to 936 psi, PU Wt 28 k lbs, WOB 0.1 k lbs. Liner released on depth ** TOL 6450' 2,485.2 8,891.8 11/26/2022 07:00 11/26/2022 08:51 1.85 COMPZ1, CASING DISP P PUH, park and reset depth to reflect dropped off liner. Chase seawater to the bit and then surface, walking rate up to minimize losses and maximize time efficiency 8,891.8 6,425.8 11/26/2022 08:51 11/26/2022 09:12 0.35 COMPZ1, CASING DLOG P Park @ 6475.76 CTMD 6962.69' TVD to sensor. Off pump, choke closed, trap 3490 psi, observe pressure fall slowly, bleed into stable 3,356 psi or 11.0 ppg EMW 6,425.8 6,475.0 11/26/2022 09:12 11/26/2022 11:06 1.90 COMPZ1, CASING TRIP P Line up to LRS, pump 25 bbls diesel while PUH to 2,500 feet. 6,475.0 40.0 11/26/2022 11:06 11/26/2022 12:36 1.50 COMPZ1, CASING PULD P PUD BHA #8, liner running assembly. ***Final pressure T/I/O= 812/0/18 psi 40.0 0.0 11/26/2022 12:36 11/26/2022 13:30 0.90 DEMOB, WHDBOP CIRC P Install nozzle, stab injector, jet stack. 0.0 0.0 11/26/2022 13:30 11/26/2022 16:00 2.50 DEMOB, WHDBOP CTOP P Pop off, cut CTC. Trim pipe - Cut 20' feet, new length old 18,967'. Install new CTC. Pull test to 35 k lbs. Re head and test wire, 81.3 Ohms, Meg'd > 550 M ohms. Pressure test connector to 3,500 psi. - good ** Off shore power and back on generators 0.0 0.0 11/26/2022 16:00 11/26/2022 22:00 6.00 DEMOB, WHDBOP CTOP P Vac stack, Bore-O-Scope stack. Install night cap, flush and blow down to tiger tank. 0.0 0.0 11/26/2022 22:00 11/27/2022 00:00 2.00 DEMOB, WHDBOP NUND P Nipple down BOPs, cap stack Rig Released 00:00 on 11/27/22 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/27/2022 2W-02 Proposed CTD Schematic 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 6165' RKB 3-½" X landing nipple at 6256' RKB (2.813" min ID) 4.5" Centralized Big Tail Pipe (see details) 3.5" x 7.0" Packer @ 6490' RKB (4" ID) 7" 26# J-55 shoe @ 9291' MD A4-sand perfs 8928' - 8946' MD 9-5/8" 36# J-55 shoe @ 4814' MD 16" 62# H-40 shoe @ 115' MD C1-sand perfs 8680'-8710' MD KOP @ 6457' MD 2W-02L1 TD: 12,000' MD Top of Slotted Liner ~6450' MD Centralized Big Tail Pipe * 4-1/2" 11.6# L-80 Base Pipe* 6.0" OD Maxwell Centralizers (36' long)* ~42' Total Length* Set up for 4.5" whipstock thru 3.5" tubing. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 75' of Fill) 6,643.0 2W-02 3/11/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added 2W-02L1 liner top to "other in hole" 2W-02 11/30/2022 fergusp General Notes: Last 3 entries Com Date Last Mod By Top of liner left at 6450' CTMD. Fluids lost to the well bore during drilling, Power Pro Losses: 1816 bbls, NaBr Losses: 224 bbls, Seawater losses: 43 bbls 11/26/2022 ncdr3cm 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 1/2 31.0 110.0 110.0 65.50 H-40 WELDED SURFACE 9 5/8 8.92 30.2 3,118.6 3,117.9 36.00 J-55 BTC PRODUCTION 7 6.28 28.7 6,890.4 6,243.6 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.7 Set Depth 6,512.0 Set Depth 5,943.4 String Ma 3 1/2 Tubing Description Tubing Gas Injection Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD563 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) 26.7 26.7 0.05 Hanger 7.063 FMC GEN IV Tubing Hanger FMC Gen IV 2.960 478.1 478.1 0.13 Nipple - Landing 3.939 3.5" 2.81" X-nipple, SN# 0004717612-3 Halliburt on X Nipple 2.831 6,164.8 5,663.0 36.16 Mandrel GAS LIFT 5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920 6,225.5 5,712.1 35.95 Packer 6.280 3.5" x 7" Halliburton MFT Feedthrough Packer, SN# 0004534635-2 Halliburt on MFT Packer 2.897 6,254.7 5,735.7 35.95 Nipple - Landing 3.937 3.5" 2.81" X-nipple, SN# 0004717612-4 Halliburt on X Nipple 2.831 6,393.5 5,848.1 36.00 XO - Enlarging 4.500 3.5" 9.3# L-80 8rd EUE x 4.5" HYD 563, XO 2.831 6,397.3 5,851.1 36.00 Centralizer 4.500 4.5" 12.6# Hyd 563 TBG w/Maxwell Centralizers Maxwell Offset Centraliz er 3.958 6,480.8 5,918.4 36.69 XO - Enlarging 4.500 4.5" 563" x 3.5" 9.3# L-80 8rd EUE, XO 2.992 6,490.4 5,926.1 36.77 Packer 6.280 3.5" x 7" Halliburton MFT Feedthrough Packer, SN# 0004537135-2 Halliburt on MFT Packer 2.897 6,503.6 5,936.7 36.86 Nipple - Landing 3.940 3.5" x 2.813", X-Nipple SN# 0004717612-5 Halliburt on X Nipple 2.831 6,510.6 5,942.3 36.88 Overshot 5.900 3-1/2" Overshot 8rd EUE Box Baker Oversho t 3.625 Top (ftKB) 6,513.7 Set Depth 6,536.6 Set Depth 5,963.1 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDABM 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) 6,514.8 5,945.7 36.89 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 6,515.7 5,946.4 36.90 PACKER 5.875 BAKER FB-1 PACKER 4.000 6,519.0 5,949.0 36.91 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,529.1 5,957.1 36.94 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.75" ID w/1.81" NIPPLE REDUCER 2.750 6,535.8 5,962.5 36.96 SOS 3.500 BAKER SHEAR OUT SUB. ELMD @ 6527' per SWS IPROF on 9/14/2006 2.992 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) 6,450.0 5,893.7 36.43 LINER TOP 2W-02L1 liner top/deployment sleeve. 11/26/2022 1.992 6,455.0 5,897.7 36.47 WHIPSTOCK 2.625" GEN II BAKER HUGHES DELTA WHIPSTOCK, TOWS AT 6455' PDC, OAL 12.97' BAKER HUGHE S GEN II DELTA H1505 04512 11/14/2022 0.000 6,504.0 5,937.0 36.86 TUBING PLUG Set XX Plug (OAL 25'' / 8 x .125'' EQ PORTS), 10/27/2022 0.000 6,513.7 5,944.8 36.89 CUT 2" RCT TBG CUT AT 6513.7' RKB (pre-RWO Oct 2022) 9/22/2022 2.992 6,529.0 5,957.0 36.94 TUBING PLUG 1.812" CA-2 PLUG (25" OAL) 9/15/2022 9/15/2022 0.000 6,529.2 5,957.2 36.94 NIPPLE REDUCER 2.75" NIPPLE REDUCER 10/3/2013 1.810 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) 6,164.8 5,663.0 36.16 1 GAS LIFT DMY RK 1 1/2 0.0 10/26/2022 Schlumb erger MMG 0.000 2W-02, 12/19/2022 3:48:29 PM Vertical schematic (actual) PRODUCTION; 28.7-6,890.4 IPERF; 6,705.0-6,718.0 IPERF; 6,595.0-6,660.0 TUBING PLUG; 6,529.0 NIPPLE REDUCER; 6,529.2 NIPPLE; 6,529.1 PACKER; 6,515.7 CUT; 6,513.7 TUBING PLUG; 6,504.0 Nipple - Landing; 6,503.6 Packer; 6,490.4 WHIPSTOCK; 6,455.0 Slotted Liner; 6,450.4-12,000.0 WHIPSTOCK; 6,455.0 LINER TOP; 6,450.0 IPERF; 6,413.0-6,478.0 Nipple - Landing; 6,254.7 Packer; 6,225.5 Mandrel GAS LIFT; 6,164.8 SURFACE; 30.2-3,118.6 Nipple - Landing; 478.1 CONDUCTOR; 31.0-110.0 Hanger; 26.7 KUP INJ KB-Grd (ft) 34.50 RR Date 2/14/1985 Other Elev 2W-02 ... TD Act Btm (ftKB) 6,949.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292127900 Wellbore Status INJ Max Angle & MD Incl (°) 40.35 MD (ftKB) 4,600.00 WELLNAME WELLBORE2W-02 Annotation Last WO: End Date 10/20/2022 H2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,413.0 6,478.0 5,863.9 5,916.2 C-4, C-3, C-1, UNIT B, 2W-02 3/16/1985 12.0 IPERF 120 deg. phasing, 5" Dressler Atlas HD 6,595.0 6,660.0 6,009.7 6,061.4 A-4, A-3, 2W-02 3/16/1985 4.0 IPERF 120 deg. phasing, 4" Dressler Atlas JJ 6,705.0 6,718.0 6,097.0 6,107.3 A-2, 2W-02 3/16/1985 4.0 IPERF 120 deg. phasing, 4" Dressler Atlas JJ 2W-02, 12/19/2022 3:48:30 PM Vertical schematic (actual) PRODUCTION; 28.7-6,890.4 IPERF; 6,705.0-6,718.0 IPERF; 6,595.0-6,660.0 TUBING PLUG; 6,529.0 NIPPLE REDUCER; 6,529.2 NIPPLE; 6,529.1 PACKER; 6,515.7 CUT; 6,513.7 TUBING PLUG; 6,504.0 Nipple - Landing; 6,503.6 Packer; 6,490.4 WHIPSTOCK; 6,455.0 Slotted Liner; 6,450.4-12,000.0 WHIPSTOCK; 6,455.0 LINER TOP; 6,450.0 IPERF; 6,413.0-6,478.0 Nipple - Landing; 6,254.7 Packer; 6,225.5 Mandrel GAS LIFT; 6,164.8 SURFACE; 30.2-3,118.6 Nipple - Landing; 478.1 CONDUCTOR; 31.0-110.0 Hanger; 26.7 KUP INJ 2W-02 ... WELLNAME WELLBORE2W-02 General Notes: Last 3 entries Com Date Last Mod By Top of liner left at 6450' CTMD. Fluids lost to the well bore during drilling, Power Pro Losses: 1816 bbls, NaBr Losses: 224 bbls, Seawater losses: 43 bbls 11/26/2022 ncdr3cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Slotted Liner 2 3/8 1.99 6,450.4 12,000.0 5,874.4 4.60 L-80 STL Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,455.0 5,897.7 36.46 WHIPSTOCK 2.625" GEN II BAKER HUGHES DELTA WHIPSTOCK, TOWS AT 6455' PDC, OAL 12.97' BAKER HUGHE S GEN II DELTA H1505 04512 11/14/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,450.4 5,894.0 36.42 Deployment Sleeve 2.375 Shorty deployment Sleeve Northern Solutions na 1.920 8,892.1 5,871.7 89.94 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions na 1.920 10,684.0 5,887.9 90.57 Deployment Sleeve 2.375 NSAK 350-238 OH Permanent QCLL Northern Solutions na 1.920 2W-02L1, 12/19/2022 3:48:30 PM Vertical schematic (actual) Slotted Liner; 6,450.4-12,000.0 WHIPSTOCK; 6,455.0 PRODUCTION; 28.7-6,890.4 WHIPSTOCK; 6,455.0 LINER TOP; 6,450.0 IPERF; 6,413.0-6,478.0 Nipple - Landing; 6,254.7 Packer; 6,225.5 Mandrel GAS LIFT; 6,164.8 SURFACE; 30.2-3,118.6 Nipple - Landing; 478.1 CONDUCTOR; 31.0-110.0 Hanger; 26.7 KUP SVC KB-Grd (ft) 34.50 RR Date 2/14/1985 Other Elev 2W-02L1 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292127960 Wellbore Status SVC Max Angle & MD Incl (°) 101.31 MD (ftKB) 6,740.26 WELLNAME WELLBORE2W-02 Annotation End DateH2S (ppm) DateComment 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: CTD Set-Up 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 6949'feet 6504', 6529'feet true vertical 6290'feet None feet Effective Depth measured 6504'feet 6225', 6490', 6516'feet true vertical 5937'feet 5712', 5926', 5946'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/J-55 6537' MD 5963' TVD Packers and SSSV (type, measured and true vertical depth) 6225' MD 6490' MD 6516' MD N/A 5712' TVD 5926' TVD 5946' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressuN/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: (907) 265-6531Senior Workover Engineer 3119' 3118' Burst Collapse measured TVD Production Liner 6862' Casing Structural 6244'6890' Plugs Junk measured N/A Length 79' 3088' 110'Conductor Surface Intermediate 16" 9-5/8" N/A 5. Permit to Drill Number:2. Operator Name: 4. Well Class Before Work: ADL0025642 Kuparuk River Field/ Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-016 50-029-21279-00-00 Size 110' ~ ~~ Well Remains Shut-In ~~ ~ 7" P.O. Box 100360 Anchorage, AK 99510 3. Address: KRU 2W-02 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 322-466 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. 64113-6478', 6595-6660', 6705-6718' feet 5864-5916', 6010-6061', 6718-6097' feet Packer: HLB MFT Packer Packer: HLB MFT Packer Packer: Baker FB-1 Packer SSSV: None Dusty Ward dusty.ward@conocophillips.com Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 2:14 pm, Nov 18, 2022 DTTMSTART JOBTYP SUMMARYOPS 9/15/2022 ACQUIRE DATA DRIFT W/ 15' X 2 1/8" OD DMY DRIFT DOWN TO NIPPLE REDUCER @ 6529' RKB; MEASURED BHP (3533 PSI) @ 6450' RKB; PULLED DV @ 6194' RKB; SET 1.812" CA-2 PLUG IN NIPPLE REDUCER @ 6529' RKB (OBTAIN PT & DDT ON PLUG). READY FOR E-LINE TUBING CUT. 9/22/2022 ACQUIRE DATA PERFORM TUBING CUTS W/ 2.0" RCT CUTTER FOR UPCOMING RIG WORK OVER RUN 1: CUT TUBING AT 6513.7' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6500.5' RKB RUN 2: CUT TUBING AT 6384.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6371.0' RKB RUN 3: CUT TUBING AT 6213.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH = 6200.0' RKB JOB COMPLETE, READY FOR RIG 10/5/2022 MAINTAIN WELL PUMPED 8 BBLS METHANOL DOWN FL TO FREEZE PROTECT JOB COMPLETE 10/13/2022 RECOMPLETION Blow down steam and water in pits. Unhook interconnect. Bridle up. L/D derrick. Haul equipment T/ 2W. Pull pits away from sub. Load shop and office. Transport pits, shop and office T/ 2W. Set shop and office. Stage pits on pad. Pull sub off of well. Clean up around 3B-13. Moving sub to 2W-02 10/14/2022 RECOMPLETION Continue moving sub to 2W. Spot sub over well. Spot pits. Spot auxiliary equipment. Hook up steam and air to pits. Raise derrick. Berm in rig. Bridal down. Get measurements for riser height from tubing spool height. Rig up circ manifold in cellar. Take initial pressures T/IA/OA. Pressure test circ manifold & tiger tank T/ 3500 PSI. Bleed free gas off tubing & IA. Bullhead 260 Bbls seawater down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85 Bbls seawater down tubing @ 3 BPM. Record shut in pressure of 275 PSI. Developed plan to blend new KWF of 9.6 PPG. 10/15/2022 RECOMPLETION Condition 10.6 PPG NaCl/NaBr down T/ 9.6 PPG NaCl/NaBr. Bullhead 260 Bbls 9.6 PPG NaCl/NaBr down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85 Bbls 9.6 PPG NaCl/NaBr down tubing @ 3 BPM. Allow formation to relax. 30 minute no flow check. Install ISA BPV. Test from below. Nipple down tree and adaptor spool. Install blanking plug. Nipple up DSA and BOP. Install flow nipple. Fill stack with fresh water. Test BOPE to sundry requirements. 10/16/2022 RECOMPLETION Pull blanking plug and rig down testing equipment. Make up landing joint. BOLDS. Pull hanger to rig floor. Lay down hanger and landing joint. Circulate bottoms up. Lay down 500' of completion. Make up 6" drift and run through well head. Lay down drift. Continue pulling completion. Make up BHA #1 Overshot. Run in hole picking up drill pipe T/ 5584'. 10/17/2022 RECOMPLETION Continue picking up drill pipe. Engage fish @ 6205'. Jar fish free. Circulate out gas and light weight fluid. Pull out of hole. Pull out of hole. Lay down BHA #1 and fish. Seals and packer down to second cut recovered. Make up BHA #2 overshot and run in hole engage fish. Jar blast joints free. Circulate well. Pull out of hole. Lay down BHA #2 overshot. Rig up tubing handling equipment. 2W-02 RWO Summary of Operations 10/18/2022 RECOMPLETION Lay down blast ring fish. Clean and clear rig floor. Make up BHA #3 clean out assembly. Run in hole. Wash and ream from 6100' to tubing stub 6504'. Pump hi-vis pill around. Pull out of hole laying down drill pipe and BHA #3. Pull wear bushing. Rig up GBR tubing equipment. Verify joint count and running order. Run 3 1/2" completion string T/ 246'. 10/19/2022 RECOMPLETION Continue running 3 1/2" completion string. Wash overshot onto tubing stub. Fully located. Pick up space out. Make up hanger and landing joint. Circulated 9.6 PPG CI NaCl around. Land hanger. RILDS. Drop ball and rod. Pressure up and set tandem HES MFT packers. Test tubing to 3500 PSI for 30 min. Test IA to 3000 PSI for 30 MIn. Shear out SOV. Set HP BPV. Test BPV from below. Perform rig repair on annular preventer, change out drum clutch on draw works. 10/20/2022 RECOMPLETION Continue perform rig repair on annular preventer. Nipple down BOP. Set tree test plug. Nipple up adaptor spool and tree. Pressure test hanger void T/ 5000 PSI for 15 min. Rig up LRS, circ manifold and tiger tank. Pressure test tree T/ 5000 PSI for 15 min. Pull tree test dart and HP BPV. LRS pump 71 Bbls diesel freeze protect down IA. Rig down LRS. U-tube well. Rig down circ manifold. Secure tree and cellar. Pull pits away from sub and stage on pad. RDMO 10/23/2022 ACQUIRE DATA (PRE CTD) TREE VALVE TESTS POSTIVE/NEGATIVE (ALL PASS) 10/26/2022 ACQUIRE DATA SHAKE OFF BAITED BALL & ROD PULLING TOOL @ 6300' RKB. PULLED SOV @ 6165' RKB & SET DMY. IN PROGRESS. 10/27/2022 ACQUIRE DATA PULLED BAITED PULLING TOOL & BALL n' ROD @ 6497' RKB. PULLED 2.81'' RHC @ 6503' RKB. DRIFTED W/ 2.625'' x 17' DMY WHIPSTOCK TO TAG TBG CUT @ 6513' RKB (NO ANOMALIES). SET 2.81'' XX PLUG @ 6503' RKB (OBTAIN TBG TEST TO 2500). READY FOR E-LINE. 11/3/2022 ACQUIRE DATA LOG GR/CCL FROM 6497' RKB (JUST ABOVE XX PLUG @ 6404' RKB). TIE INTO K1 MARKER @ 6286' FOR MINUS 8 FT CORRECTION (CBL DATED 3/8/85). JOB IS READY FOR ELINE TO SET WS (WHEN SLB BACK IN FIELD) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:10/15/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1850160 Sundry #322466 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2657 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8' x 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate FP System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1510 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)113 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@2045 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:6.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/14/22 12:16AM Waived By Test Start Date/Time:10/15/2022 17:00 (date)(time)Witness Test Finish Date/Time:10/15/2022 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nabors Test with 3 1/2" jnt. HCR Kill had a small leak on high psi greased and re-test - Good Tony Morales / Jim Marmon ConocoPhillips Mark Adams/ Kevin Barr 2W-02 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1015_BOP_Nabors7ES_KRU_2W-02 (KRU 2W-02)        J. Regg; 11/22/2022 ! " # $! % "&%'" *&$)"" ($ &#+, - # ./$ 1$$0/ " ## ! 2 $ ,2 3 895 74& 56 $7 <=5:&7 5:&7:5 7+ #& ;&+ #& :&& ;&5 7& :&5 7 $.4)4> " / 6 = ;:&5 7;&5 7= ; -" !=( #&#+, & ?= * !=)+ & &6/$</6" @@&.;#6'@@ @"" #@/$< ! 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" ! ! # ! $% &'!()%) ! %) &! *+ ,*)+ *+' ) *&$ !"# $!%&'()*+,%-./0 !1#2 /('()('33 /*4444567#8'(9 !"#/80+:)/, '.*8/(- ,; #4#/0< -;4444567#9 !1#2 /('()('33 /*4444567#8'(9 /( 8 ) , #4#/0< -;4444567#9 !1#2 /('()('33 /*4444567#8'(9 !"# +(!, / '()= -,>+* ? : @ -8/( (*/0< -;567#9 #!('33 ; 567#9 ;56 %-./0 /,'() -+%0*'+(/,'() +(%0*+- ?!,/(3 -., 5! 56 !/( -., 5! 56 ,668('$635(/,0,1$5< '$7(,668('%< $6%8,/7 )25$33529$/0$5.83 4827(5(9,(: -813.0 ; ; >@ >@ >@ >@ >@ >@ >@%<1$%256 %<23(5$725 3,3(5$0 &/:(// &+2.(/,1( %,//2)0$7(5,$/6 12 47< '(6&5,37,21 %235$00&$0(5218'28%/( '5,//6322/0Z0287/(76 %235$00&$0(52186,1*/( *$7(9$/9(0$18$/0 *$7(9$/9(+<'5$8/,&0 %23$118/$50&$0(5217 +(,*+7 .,///,1( $3,7$5*(7%/,1')/$1*(0 '6$0[0 ) )7,&.(7 7+,6'5$:,1*,66+2:1758(6&$/(21/<:+(135,17('217+,66,=(3$3(5 7+,6'2&80(17$1'7+(,1)250$7,21&217$,1('+(5(,1,6$&21),'(17,$/',6&/2685(,7,66+2:172<285&203$1<:,7+7+(81'(567$1',1*,7,612772%( 5(9($/('7227+(562586(')25$1<385326(:,7+2877+(:5,77(1&216(172)1$%256,1'8675,(6 5(9 ;5() '(6&5,37,21 $33'$7(%< 7,7/(&23<5,*+7(' '$7( '51%< (5% ':* $33 5,* 6&$/(NABORS 6+712 2) 1$%2565,*(6 0%2367$&./$<287 (6 3.0 176 0$< 60% (6 % 5(9,6('$1',668(')25,1)250$7,21 -81 3.0 '5,//(56,'(2))'5,//(56,'( MEMORANDUM State of Alaska Pretest Alaska Oil and Gas Conservation Commission 15 Min DATE: Friday, May 31, 2019 TO.Jim Regg TVD P.I. Supervisor/ 44, SUBJECT: Mechanical Integrity Tests 2450 - CONOCOPHILLIPS ALASKA, INC. 2450 - 2W-02 FROM: Jeff Jones KUPARUK RIV UNIT 2W-02 Petroleum Inspector 1900 ', Src: Inspector Reviewed By: P.1. Suprv� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2W-02 API Well Number 50-029-21279-00-00 Inspector Name: Jeff Jones Permit Number: 185-016-0 Inspection Date: 5/12/2019 ' Insp Num: mitJJ190531101834 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2W-02 Type Inj W-. TVD 5732 Tubing 2460 2450 - 2450 2450 - PTD is:0ir.a Type Test sPT Test psi 1500 s0O 1900 ', 1820 ' IR2o BBL Pumped: 1,7 - BBL Returned. 1.6 _IA - OA 160 300 290 NO Interval 4vRTST IP/F P Notes: I well inspected, no exceptions noted. - Friday, May 31, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,May 14,2015 P.I.Supervisor � „` /,,( ( c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-02 FROM: Matt Herrera KUPARUK RIV UNIT 2W-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J! -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2W-02 API Well Number 50-029-21279-00-00 Inspector Name: Matt Herrera Permit Number: 185-016-0 Inspection Date: 5/9/2015 Insp Num: mitMFH150511130922 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2W-02 Type Inj I W TVD 5732 Tubing 2340 - 2350 - 2350 - 2350 2350 2350 PTD; 1850160 -,Type Test SPT Test psi 1500 - IA 750 3020 - 2880 - 2885 - 2900 2920 Interval 4YRTST _ J =P/F I OA 322 455 460 465 - 470 ' 475 Notes: Temperature/rate flucuations caused unstable testing conditions Could not get a conclusive test result showing annulus pressure stabilization 2,7tI1;k, IC SCANNED .JUL 1 0 2015 Thursday,May 14,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,May 14,2015 P.I.Supervisor 1 e� 6I SI IS SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-02 FROM: Matt Hen-era KUPARUK RIV UNIT 2W-02 Petroleum Inspector Src: Inspector Reviewed By_- P.I.Supry agc, NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2W-02 API Well Number 50-029-21279-00-00 Inspector Name: Matt Herrera Permit Number: 185-016-0 Inspection Date: 5/9/2015 Insp Num: mitMFHl50511132311 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2W-02 Type Inj W TVD 5732 Tubing 2340 2350 2350 I 2350 - PTD 1850160 Type Test SPT Test psi 1500 IA 2940 2940 ' 2920 2910 - Interval 4YRTST per, P ✓ OA 372 485 485 485 Notes: Attempt to perform casing test on this well hours prior were unsuccessful due to temperature/rate flucuations.Well was left with original test pressure on IA/OA and monitored while testing on drillsite continued on other wells.This MIT was on a 4 year interval Z 16'r Thursday,May 14,2015 Page 1 of I I ect Well History File' ge 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. Z ~"" _'~- ~_/~ Well History File Identifier Organizing(done) I~Tv~o-Sided IIIIIIIIIIIIIIIIIII RESCAN DIGITAL DATA [] Color items: a Diskettes, No. [] Grayscale items: Poor Quality Originals: [] Other: [] Other, No/Type NOTES: BY: BEVERLY BRE~SHERYL MARIA LOWELI. OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] ' Logs of various kinds [] Other Project Proofing .. Iii jjjjjjjjjjj Il Ill Scanning Preparation ~ x 30= + ,/,/ = T OTALPAGES "7 BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ,. Is~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~'/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~~YES NO IF NO IN STAGE '1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: Stage 2 (SCANNING IS COMPLETE~["P,~/'IfS~POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALI'rY. GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention] scanning completed) RESCANN ED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned,wpd STATE OF ALASKA ALL. k OIL AND GAS CONSERVATION COML ..SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other ri Install Tubing Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Patch r r Time Extension Change Approved Program rOperat. 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 185-016 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21279-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25642 . 2W-02 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6949 feet Plugs(measured) 6529 true vertical 6290 feet Junk(measured) none Effective Depth measured 6812 feet Packer(measured) 6250,6516 true vertical 6181 feet (true vertical) 5732, 5946 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16" 110 110 SURFACE 3088 9.625" 3119 3118 PRODUCTION 6862 7 6890 6244' A Perforation depth: Measured depth: 6413'-6478',6595'-6660',6705'-6718SCANNEU .4IN 2 f L J True Vertical Depth: 5864'-5916',6010'-6061',6097'-6107' AO Tubing(size,grade,MD,and TVD) 3.5,J-55,6537 MD, 5963 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6250 MD and 5732 ND PACKER-BAKER FB-1 PACKER @ 6516 MD and 5946 TVD SSSV-BAKER FVL SSSV @ 1909 MD and 1909 TVD 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 1. Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations_XXX GSTOR r WIND r WAG Pr. 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: 313-505 Contact John Peirce Caa,265-6471 Email John.W.Peirce( conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date /� �� V // q/ 4- RB MS- NOV 2 ] Form 10-404 Revised 10/2012 'rz Submit Original Only _ f KUP INJ 2W-02 Conoco Phillips °- Well Attributes Max Angle&MD TD Alaska,Inc WellboreAPI/UWI Field Name Wellbore Stales ncl(°) MD(ftKB) Act Btm(ftKB) Q...,,,i,�,ilkp, 500292127900 KUPARUK RIVER UNIT INJ 40.35 4,600.00 6,949.0 ... Comment- H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date° 2W-02.11116/2013 4:07:05 PM SSSV:LOCKED OUT I Last WO. 34.50 2/14/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'.SLM 6,747.0 11/24/2012 Rev Reason:SET PATCH lehallf 11/6/2013 Sij( �((; � Casing Strings HANGER:267 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread L'.+, CONDUCTOR 161/2 31.0 110.0 110.0 65.50 H-40 WELDED i flit_.■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).., WVLen p...Grade Top Thread t' SURFACE 95/8 8.921 30.2 3,118.6 3,117.9 36.00 J-55 BTC III 111 Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread IIltore,PRODUCTION 7 6.276 28.7 6,890.4 6,243.6 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...I ID(in) Top(ftKB) •Set Depth(ft.,'Set Depth(ND)(...I Wt)Iblft) Grade Top Connection TUBING 31/2 2.992 26.7 6,536.6 5,963.1 9.30 J-55 EUE8rdIPC CONDUCTOR;310-110.0 -� Completion Details Nominal ID Top(ORB) Top(ND)(ftKB) Top Inc](°) Item Des Corn (in) 26.7 26.7 0.05 HANGER FMC GEN III 5M TUBING HANGER 3.500 SAFETY VLV,1,909.2 1,909.2 1,909.1 1.85 SAFETY VLV BAKER FVL SAFETY VALVE-LOCKED OUT 2/19/2002 2.810 6,236.6 5,721.1 35.95 PBR BAKER PBR 2.810 6,250.0 5,732.0 35.95 PACKER BAKER FHL PACKER 2.937 6,400.6 5,853.9 36.01 BLAST RING BLAST RING 9.2#(1) 2.867 6,431,7 5,878.9 36.27 BLAST RING BLAST RING 9.3#(1) 2.867 6,461.6 5,903.0 36.52 BLAST RING BLAST RING 9,2#(1) 2.867 SURFACE,302J.f fe.6 6,514.9 5,945.7 36.89 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 6,515.7 5,946.4 36.90 PACKER BAKER FB-1 PACKER 4.000 GAS LIFT;6,193.9 6,519.0 5,949.0 36.91 SBE BAKER SEAL BORE EXTENSION 4.000 6,529.2 5,957.1 36.94 NIPPLE CAMCO D NIPPLE NO GO 2.75"ID w/1.81"NIPPLE 2.750 REDUCER 6,535.8 5,962.5 36.96 SOS BAKER SHEAR OUT SUB.ELMD @ 6527'per SWS 2.992 IPRRF on 9/14/2006 PBR;6,236.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER;6250.0 Top(ND) Top Intl Top(ftKB) (ftKB) (°) Des Gom Run Date ID(in) 6,355.0 5,817.0 35.98 PATCH OWEN X SPAN PATCH 10/30/2013 2.250 6,529.2 5,957.2 36.94 NIPPLE '2.75"NIPPLE REDUCER 10/3/2013 1.8)0 INJECTION;6,288.4 REDUCER 6,529.2 5,957.2 36.94 PLUG '1.81"CA-2 PLUG 10/3/2013 0.000 Perforations&Slots INJECTION;6.359.8, Shot PATCH;6,355.0• • Dens i\ Tot(TVD) Bbn(TVD) (shots# Top(ftKB) Min(ftKB) (ftKB) (MB) Zone Date t) Type Cots L 6,413.0 6,478.0 5,863.9 5,916.2 C-4,C-3,C-1, 3/16/1985 12.0 IPERF 20 deg.phasing,5" UNIT B,2W- Dressler Atlas HD 02 6,595.0 6,660.0 6,009.7 6,061.4 A-4,A-3,2W- 3/16/1985 ' 4.0 IPERF 120 deg.phasing,4" 02 Dressler Atlas JJ I 6,705.0 6,718.0 6,097.0 6,107.3A-2,2W-02 3/16/1985 ' 4.0'IPERF 120 deg.phasing,4" IPERF;6,41306,478.0- a. Dressler Atlas JJ a Mandrel Inserts Est �i C No Top(ND) Valve Latch Port Size TRO Run m Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date i 6,193.9 5,686.6 MERLA 'TPDX 1 1/2 GAS LIFT DMY R0-5 0.000 0.0 9/7/1990 INJECTION;6,497,5 '. 2 6,288.4 5,763.1 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 9/12/2010 3 6,359.9 5,820.9 MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 6/8/2012 4 6,497.5 5,931.8 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 6/7/2012 Notes:General&Safety SEAL ASSY;65149 End Date Annotation PACKER;6,5157 ' 12/13/2010 NOTE:View Schematic w/Alaska Schematiic9.0 SBE;6,519.0 NIPPLE;6.5292 I PLUG;6,529.2 NIPPLE REDUCER;6,529.2 !ill 1 SOS;6,53511 IPERF;6.595.0-6,660.0- I I IPERF;6,705.0-6,718.0- PRODUCTION.267-6890.4 . 2W-02 Well Work Summary DATE SUMMARY 10/3/2013 B&F TBG. DRIFTED TBG WITH 2.75"x 25' DUMMY PATCH TO 6500'. SET/PULLED CAT SV TO CONFIRM NIPPLE DEPTH @ 6527' SLM. SET 2.75" D x 1.81" D NIPPLE REDUCER IN D NIPPLE. SET 1.81"CA-2 @ 6529' RKB. READY FOR TBG PATCH. 10/18/2013 RIH WITH 20' PATCH. UNABLE TO FALL PAST 4900'. POOH WITHOUT SETTING PATCH. 10/28/2013 Brushed & Flushed Tbg; Drifted 2.74"x 35'to 6400'SLM (Tight Spot 4880'-4975'SLM-Able to drift @ 100' Per Min). Ready for E-Line. 10/30/2013 SET 2.71"x 20' OWENS X-SPAN PERM PATCH FROM 6355'-6375'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 16 MAR 1985. TOOLSTRING SITTING DOWN AT 6349'CCL DEPTH AND UNABLE TO WORK PAST. MIT-T FAILED. TUBING REPEATABLY LOST 200-350 PSI IN 15 MINUTES. NO CHANGE IN IA PRESSURE. 1//7'• THE STATE Alaska Oil and Gas o :3. _ == ALAS Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 0/ (61a Fax: 907.276.7542 SCOMED U John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ` o Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2W-02 Sundry Number: 313-505 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, ommissioner DATED thisll day of September, 2013. Encl. • ' STATE OF ALASKA ,�3 AKA OIL AND GAS CONSERVATION COMiION g�.w, • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Install Tubing Patch J 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 185-016- 3.Address: 6.API Number: Stratigraphic r Service 170 P.O.Box 100360,Anchorage,Alaska 99510 50-029-21279-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J 2W-02 e 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25642 ' Kuparuk River Field/Kuparuk River Oil Pool• 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6949 , 6290 • 6812'- 6181'• none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16" 110' 110' SURFACE 3088 9.625" 3119' 3118' E PRODUCTION 6862 7" 6890' 6244' R EC SEP 2 0 Z013 01:3 9)PNL3 AO GI; Perforation Depth MD(ft): . Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6413'-6478',6595-6660',6705-6718' 5864'-5916',6010'-6061',6097-6107' 3.5 J-55 6537 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER FHL PACKER MD=6250 ND=5732 • PACKER-BAKER FB-1 PACKER MD=6516 ND=5946 SSSV-BAKER FVL SSSV MD=1909 TVD=1909 " 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/6/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r,- Abandoned r Commission Representative: I GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce @conocophillios.com Printed Name John Peirce Title: Wells Engineer Signature - 'a.( ��.e Phone:265-6471 Date 9//CI`13 '�A Commission Use Only Sundry Number:.s,2J.50 5 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Y� RBr c OCT 1 0 2illii- Other: Spacing Exception Required? Yes ❑ No Er/ Subsequent Form Required: 1d 40+ I / P APPROVED BY Approved by: - • � 7 v - COMMISSIONER THE COMMISSION Date: qj-27-13 vLr'g!/ , I pproved application is valid for 12 months from the date of approval. -36a),1_1 Form 10-403(Revised 10/2012) ORIGNAL Submit Form and Attachmen in Duplicate `,�f�, ....-....- • r P I." KUP 2W-02 ConocoPhilliprs :) Well Attributes Max Angle&MD TD x«„01 Wellbore API/UWI Field Name Well Status Incl p) MD(ftKB) Act Btm(ftKB) A8Sk0'(� ' Calrx 500292127900 KUPARUK RIVER UNIT INJ 40.35 4,600.00 6,949.0 oPMOips ' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well COnfig:-7W-02,12/620129.40:14 AM SSSV:LOCKED OUT Last WO: 34.50 2/14/1985 Schematb-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,747.0 11/24/2012 Rev Reason:TAG ninam 12/6/2012 Casin• Strin•s Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,27 ( CONDUCTOR 161/2 31.0 110.0 110.0 65.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Tired �'. SURFACE 95/8 8.921 30.2 3,118.6 3,117.9 36.00 J-55 BTC 1 ' (] Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 28.7 6,890.4 6,243.6 26.00 J-55 BTC III` Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 31/2 2.992 26.7 6,536.6 5,962.9 I 9.30 J-55 EUE8rdIPC Completion Details coNoug% II Top Depth (TVD) Top Inc! Nomi... Top(ftKB) (ftKB) (1 hem Description Comment ID(In) IL26.7 26.7 0.17 HANGER FMC GEN III 5M TUBING HANGER 3.500 1,909.2 1,909.1 1.85 SAFETY VLV BAKER FVL SAFETY VALVE-LOCKED OUT 2/19/2002 2.810 SAFETY VLV, 6,236.6 5,721.1 35.95 PBR BAKER PBR 2.810 6,250.0 5,732.0 35.95 PACKER BAKER FHL PACKER 2.937 6,400.6 5,853.9 36.01 BLAST RING BLAST RING 2.867 6,431.7 5,878.9 36.27 BLAST RING BLAST RING 2.867 6,461.6 5,902.9 36.52 BLAST RING BLAST RING 2.867 6,514.9 5,945.3 36.60 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 6,515.7 5,946.0 36.60 PACKER BAKER FB-1 PACKER 4.000 6,519.0 5,948.7 36.62 SBE BAKER SEAL BORE EXTENSION 4.000 6,529.2 5,956.9 36.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,535.8 5,962.3 36.73 SOS BAKER SHEAR OUT SUB.ELMD @ 6527'per SWS(PROF on 2.992 9/14/2006 Perforations&Slots Shot Top(ND) Btm(TVD) Dons Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Data (sh-. Type Comment "' 6,413 6,478 5,863.9 5,916.2 C-4,C-3,C-1, 3/16/1985 12.0 IPERF 120 deg.phasing,5"Dressler Atlas �„a---�.�„ UNIT B,2W-02 HD PACKER.6.250 6,595 6,660 6,009.7 6,061.3 A-4,A-3,2W-02 3/16/1985 4.0 IPERF 120 deg.phasing,4"Dressler Atlas JJ 6,705 6,718 6,097.0 6,107.3 A-2,2W-02 3/16/1985 4.0 IPERF 120 deg.phasing,4"Dressler Atlas JJ I# II Notes:General&Safety e iii .1 End Date Annotation 12/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 111 /II-/1/1 0 3 a/c,r o S S IPERF, 6,4136,478 t 11 INJECTION, 6,497 SEAL ASSY, 6,515 PACKER,6,516- SBE,6,519 • I NIPPLE.6.529 mg 505,6.536 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run IPERF,min: Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (pai) Run Date Com... 6.595-6,660 1 6,193.9 5,686.6 35.95 MERLA TPDX 1 12 GAS LIFT DMY RO-5 0.000 0.0 9/7/1990 DMY 0 IPERF, ®®®®® a ®®a 1 111 1 1 11 1 ■ 6,705-6,718 W/ 4 6,497.5 5,931.8 36.83 MERLA TPDX 1 12 INJ DMY RM 0.000 0.0 6/72012 Ni i t PRODUCTION, 29-6,890 TD,6,949 • Proposed 2W-02 Permanent Tubing Patch Installation 2W-02 injector was drilled and completed in 1985 with perfs shot in the Kuparuk A and C sands. On 6-08-12, a HFCV in GLM #3 at 6360' RKB was replaced with a DV, but a subsequent hole finder run indicated GLM #3 was leaking. On 12-03-12 an LDL & Caliper verified GLM #3 was leaking. The Caliper showed a min ID of 2.78" at 4769' RKB with good overall tubing condition. Per this procedure, SL will brush & flush tubing around GLM #3 in preparation for a tubing patch, and then will run a Dummy Perm Patch Drift to simulate running a Perm Patch. If the Dummy Patch Drift is successful, SL will set a 1.81" Nipple Reducer in the 2.75" Camco D Nipple at 6529' RKB, then E-line will set a 20' OAL Perm Patch across leaky GLM #3. A 1.81" Plug will be set in the Nipple Reducer then an MIT-T to 2500 psi will verify integrity of the patch and tubing. The plug will then be pulled to put 2W-02 on PWI as an 'A sand only' injector. GLM #2 above the patch is available to regulate a C sand split if needed in the future. Procedure: Slickline 1. RIH and Brush & Flush the 3-1/2" tubing at $340 - $380' RKB around leaky GLM #3 in preparation for a tubing patch. 2. RIH with a 2.75" OD x 25' OAL Dummy Perm Patch Drift assembly to simulate running a —20' OAL perm patch with —5' of running tools. Drift the bottom of the assembly to 6375' RKB. If the 2.75" OD x 25' OAL drift fails to reach 6375' RKB, attempt to drift a 2.75" OD x 4' OAL (top section) made up to a 2.375" OD x 15' OAL (bottom section) to simulate running a retrievable packer and spacer pipe of a retrievable patch to 6375' RKB. If only the retrievable dummy patch drift was successful, terminate this procedure to prepare an alternative retrievable tubing patch procedure and to re-submit a 10-403 Sundry for approval to set a retrievable patch. If neither dummy patch drift was successful, terminate this procedure. 3. Only if the Dummy Permanent Patch Drift (step #2) was successful, proceed with installing a 1.81" Nipple Reducer. RIH & set the 1.81" Nipple Reducer in the 2.75" Camco D Nipple at 6529' RKB. Set a 1.81" Plug in the Nipple Reducer. E-line: 4. RIH & set a 2.715" run OD x —20' OAL Perm Patch at 6355' RKB (top seal). This sets the Perm Patch at 6355 - 6375' RKB to isolate leaky GLM #3. RD E-line. Slickline: 5. RIH & set a 1.81" Plug in the 1.81" Nipple Reducer at 6529' RKB. Perform an MIT-T to 2500 psi to verify the integrity of the patch and tubing string. Pull the 1.81" Plug set at 6529' RKB. RD SL. Return 2W-02 to 'A sand only' PWI service and obtain a valid injection rate. JWP 9/19/2013 • Page 1 of 1 Regg, James B (DOA) 1 G T� (.64_2 19 From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, May 17, 2011 9:43 AM ]�(' k J i l t To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: AOGCC witnessed MIT's 5 -O J Attachments: 2W -09 90 day TIO plot.jpg; 2W -02 90 ay TIO plot.jpg • Jim, Attached are the two TIO plots as requested. Let me know if you need any thing else. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 bye .1 d JUN .4 2.01" From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, May 17, 2011 9:27 AM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: AOGCC witnessed MIT's KRU 2W -02; pre -test pressures are high (IA= 1900psi; OA= 1000psi); please provide TIO plot for our review KRU 2W -09 - declining tubing pressure during test? pre -test IA pressure is high (IA= 2700psi); please provide TIO plot for our review Jim Regg AOGCC 333 With Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Monday, May 09, 2011 8:32 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: AOGCC witnessed MIT's All, Attached are the MIT forms for the following wells that were performed on 05/08/11: 2W pad (8 wells) — 4 year witnessed MITIA's 2K -25 — CMIT TxIA per Sundry # 311 -103 2E -12 — MITIA as per AIO 2B.043 Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 5/27/2011 • KRU 2W -02 PTD 1850160 5/17/2011 TIO Pressures Plot TRN ANNi ANNULUS PRESSURE TRENDS TlUptitil.,-IN IT _ SdO. Sc WELL NAME WI. 2W -O2 ��" 3000 ' – IOW. - iti if. 2700 3000 2400 0 . 2100 _..._.._...---.----- -_-.. r ._, - .. - . - - - ' ._.., • 1800 _.__.. - - - .. - - _ . 1 R • 1500 - ,...A• SWF 1200 c ' * . - - - - — ---- All .Aihk ' _ 900 � - -----._ _ ___ -..__ .. 600 . 300 ., . w 6 ' PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIKE E 16- FEB -11 09.41 MAJOR TIME WEER �� ; "; ; .. BRS '411141:46 PICK TINE: , +',. 4 u CM 9W 8W :/2105 111111112.1 F g • SC TAG NINE DESCRIPTION P-VALUE LATEST PIP WL2W -02 -CHOKE FLOW TUBING CHOKE 7777777 DRILLSITE WELL Pr SCRATCH 82 FLOW TUBING PRESSURE 7777777 PREY WELL iw i:1 pow SCRATCH_82 FLOW TUBING TEMP 2777777 • NEXT WELL Pr 7777777 P. ? ? ? ? ? ?? ENTRY TYPE OPERATOR P' 7727777 - OPERATOR VERIFIED Pr SCRATCH_82 INNER ANNULUS PRES ? ?7 ? ? ?? Pm SYSTEM AUTO ENTRY Pir SCRATCH_82 OUTER ANNULUS PRES ? ? ? ? ? ?? PEr BOTH I KRU 2W-09 PTD 1842190 5/17/2011 TIO Pressures Plot IRN_ANNL TRItAttiLINIT ANNULUS PRESSURE TRENDS too. .,. 901101. sc WELL NAME WLIRU2W-09 3000 Mo. " idod. 2700 41-'4°4111 A 9s0b. itioo. 2400 _ 3060. *A 2100 i \J I t 41111 1800 !IV ,,...,,---'------,-...,,,,r'-■ 1500 \ 1200 40 k 900 , 0 . 6: 600 0 il . 0 . 300 \ 0 , . _ ..,.., 1 4 PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME 16-FEB-11 09:46 MAJOR TIME WEEK 4214M400146 ims i ''' ziriiiii PICK TINE: ' ' 114 fr . ''(` ' ' . ' '1 ITI gar= EOM 111111111M MI • Sc TAG RARE DESCRIPTION P-VALUE LATEST !Mg WL2W-09-CHOKE FLOW TUBING CHOKE 7777777 IIIPREY WELL DRILLSITE WELL Pi SCRATCH 62 FLOW TUBING PRESSURE 7777777 2W 09 poi SCRATCH_82 FLOW TUBING TEMP 7727777 1111 NEXT WELL ili ?TM?? ENTRY TYPE OPERATOR Pill ??????? Pir OPERATOR VERIFIED MR SCRATCH_62 INNER ANNULUS PRES 777777, P SYSTEM AUTO ENTRY • SCRATCH_82 OUTER ANNULUS PRES ??????? PM' BOTH 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 13, 2011 TO: Jim Regg Reff 5' SI u P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-02 FROM: Bob Noble KUPARUK RIV UNIT 2W -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 16- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2W -02 API Well Number: 50- 029 - 21279 -00 -00 Inspector Name: Bob Noble , Insp Num: mitRCN110511094700 Permit Number: 185 -016 -0 Inspection Date: 5/8/2011 Rd Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 2W-02 Type Inj. 1 W . TVD 5732 ' IA t 1900 I 3300 . 3200 I- 3180 - T P.T.DI, 1850160 J yp � TeTest SPT T es t psi 3300 - 1 OA 1000 H 1090 1090 1090 Interval 4YRTST P/F P Tubing 2625 2625 2625 ! 2625 Notes: tit 1 , Feiei a -ie54' IS 5;0NJM.A.' Friday, May 13, 2011 Page I of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 18, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2W -02 Run Date: 9/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2W-02 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21279 -00 Injection Profile Log 1 Color Log 50 -029- 21279 -00 NOV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating fl / Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: • • • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 _ --~ «~ ~ s"~1 ~ ~~r.~~ A~ ~~~ ~ "r4~~ March 5, 2009 Mr. Tom Maunder Alaska Oil t& Gas Commission '~(~~~ ~~~~ M ~~ ~~~ 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23rd , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, iiG!~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/512009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1 /18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 ~'/ %~ ~ ~~ ~' F __.__ _____ ..- o ~ ~,. SC~hml{~~1'~I' NO. 4775 ~-~ ~''~ ~, ../ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # r. Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/1 o/os 2W-04 12061711 INJECTION PROFILE j 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE (5C} A 06/26/08 1 1 1 G-05 12080389 LDL (p 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE °I' _ t / - 06/27/08 1 1 2L-327 12061715 SBHP SURVEY Lj 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY f '~.- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY ~ - 06/29/08 1 1 2N-303 12061717 SBHP SURVEY ~- 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - / 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY S 06!29/08 1 1 iG-09 12080401 INJECTION PROFILE V ~ ( /(per 07/05!08 1 1 2H-05 12080396 SBHP SURVEY ~'`~.n- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY - ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY - f 06/30/08 1 1 i D-07 12080398 SBHP SURVEY - i 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ..- p 06/30/08 1 1 3C-15 11982441 USIT - / 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `~j -~ (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE ~ p -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,g 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. '? r:o)Sjc17 P.I. Supervisor '\?1 DATE: Monday, May 2 ¡, 2007 S{]BJECT: Mechanical Integrity Tests CONOCOPH1LUPS ALASKA INC 2\V ~02 S/ù\~ \~ FROM: John Crisp Petroleum Inspector KUPARUK RlV UNIT 2W-02 Src: Inspector Reviewed By: "¡¡:>O P.I. Suprv .....JD"- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2W-02 Insp Num: mitJCr07052108I852 Rei Insp N urn: Permit Number: 185-016-0 Inspector Name: John Crisp Inspection Date: 5119í2007 API Well Number: 50-029-2]279-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. weill 2W-021Type Inj.¡Z-¡ TVD I 5732 'IA -, 800 I 2050~2030~~0:~_:___l~_ ---=--= P.T.D¡ 1850160 iTypeTest : SPT I Test psi~1500 'j OA;--:;;;--i-~ I 50 I 50 -- . _~~_------L--' ~ ~-~ -~ _r- - -- -----t--- -~- -~ ~- -T --- - - .l!!!erval 4YRTST P/F ~_~___ i../' Tubing I 3050 ----'- 305~_3050 : 3050: I Notes: 5 bb]'s pumped for pressure test. The Operator & I discussed test pressure for VI. on this wen. ] did not request Operator to test above 1500 psi /' required by the State. I agreed that moving 1'\ test pressure 500 psi above tubing pressure was their decision. No problems \vitnessed. ./ sCANNED JUN 0 6 Z007 Monday, May 21, 2007 Page] of 1 PR·:1,~,.'''', \~~, E'-~, .'.:~ (~:':~ if,'-''',': ~ ,¡~ .,. 'it".",-- \~- ,<.\ 01-: \, ,1 ~L_, Sc~lumbepgel' ~(;ANNED OC1 & 1 2.005 nC'f J g ZUOS /~Qj~~~ (em g\ ìi,.~~~¡,! Cü\'~~~. ~, ;rfija~i.~~é,t Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 10/13/06 U,I,e, 1<¿6--0/~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1 J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1 E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T -39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE WIDEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1 F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 Kuparuk ( Color CD ( 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM e State of Alaska - Alaska Oil and Gas Conservation Commission TO: Jim Regg,í?d'" t51,~J,Ir)G P.I. Supervisor '~,:e::{1 DATE: Monday, May 22, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-02 KUPARUK RIV UNIT 2W-02 Src: Inspector \'65'~D1b Reviewed By: P.I. Suprv _~ Comm FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2W-02 API Well Number 50-029-2 I 279-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060515055027 Permit Number: 185-016-0 Inspection Date: 5/14/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2W-02 ¡Type Inj. i N ITVD 5732 I IA : 1310 I 2150 2100 ! 2iOO ! ! i I +-- i iTypeTest : SPT I Test psi ! I P.T. I 1850160 1500 OA i 20 i 20 20 i 20 I I i -----I.--~'~-~Î-- Interval 4YRTST P/F P Tubing i 1000 lOOO i lOOO I 1000 : i ' I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL -, ~..~..,~",-~- ," '~, I;' 1~¡H\.!I1::·F ,:>t;h~I;"'~Il;',..·..· -;: - Monday, May 22,2006 Page I of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 27, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL 2W-02 2W-04 2W-05 3M-12 ACTION Other (Inj Valve) Other (Inj Valve) Other (Inj Valve) Change Program (Temp Conv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR062796 (w/o atch) RECEIVED JUL -'5 1994. Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate g Plugging Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service _X__ 4. Location of well at surface 1279' FNL, 202' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 737' FNL, 1439' FWL, Sec.34, T12N, R9E, UM At effective depth 638' FNL, 1661' FWL, Sec.34, T12N, R9E, UM At total depth 605' FNL, 1737' FWL, Sec. 34, T12N, R9E~ UM 12. Present well condition summary Total Depth: measured 6949' true vertical 6290' f e et Effective depth: measured 681 2' true vertical 61 81 ' feet feet (measured) feet (measured) 6. Datum elevation (DF or KB) RKB 95' 7. unit or Property name Kuparuk River Unit 8. Well number 2W-02 9. Permit number 85-16 10. APl number 5O -029-21 279 11. Field/Pool Kuparuk River Oil Pool 0R GINAL feet Casing Length Size Cemented Structural Conductor 8 9' I 6" 248 Sx Cold Set II Surface 31 19' 9 5/8" 780 Sx AS III & Intermediate 410 Sx Class G Production 68 90' 7" 280 Sx Class G & Liner Measured depth True vertical depth 89' 89' 3119' 3119' 6890' 6243' Perforation depth: measured 6413'-6478' 12 SPF @ 120 degree phasing 6596'-6661', 6705'-6718'4 SPF @ 90 degree phasing true vertical 5863'-5915', 6010'-6062', 6097'-6107' TVD Tubing (size, grade, and measured depth) 3.5" J-55 set at 6537' Packers and SSSV (type and measured depth) Baker FHL @ 6245'~ Baker FB-1 @ 6511'; Baker SSSV @ 1904' 13. Stimulation or cement squeeze summary Intervals treated (measured) = , ~,,~, Oil & ~s Cons. C~mmissio~ Ar~ch0r~g~ Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Re.oresentative Daily Average Production or In!ection Data OiI-Bbl Ges-lVlcf Water-Bbl Casing Pressure 2229 1450 3956 1480 Tubing Pressure 2033 1849 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector t Oil _ Gas Suspended Service X 17. I her~/ertify that the foregoing is true and correct to the best of my knowledge. Signed V ~(~. ~//~~ Title Senior Petroleum Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KUPARUK WELL 2W-02 WELL TYPE: WAG INJECTOR APl # 500292127900 SURFACE LOCATION: 1280' FNL,202' FEL, SEC 33, T12N, R9E TOP KUPARUK: 737' FNL, 1439' FWL, SEC 34, T12N, R9E DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB (RKB--26.7') TREE: FMC GEN III 5000 PSI SPUD: 02/08~85 COMPLETION: 03/17/85 GAS LIFT and FLOW INFORMATION 16': 62.5# H-40 O 89' J 9.625': 36# J-55 O 3118' · TUBING JEWELRY ITEM TYPE ID DEPTH WRDP OTIS MCX 1904' SSSV BAKER FVL 1904' SBR BAKER PBR 2.992' 6231' PKR BAKER FHL 6245' PKR BAKER FB-1 6511' NCGD CAMCO 'D' 2.75' 6524' SHROU'r BAKER 6530' BLAST RINGS 6408' - 6483' 3.5' 9.3# Capacity: MISC. DATA DESCRIPTION Kick off ooint Max Hole Angle: 40 deg Hole Angle thru Kup: 37 dell Last Tag Date: 05/28/92 Rathole: 14' Fish/Obstruction: J-55 ~t 6531' 0.0087 bbl/ft 3100' 6732' 7': 26# J-55 ~ 6890' Capacity: 0.0383 bbl/ft PBTD: 6812' L Valve Port STN Depth Mandrel Size Size I 6189' Merla-TPDX 1.5 DV 2 6283' Merla-TPDX 1.5 DV 3 6355' Merla-TPDX 1.5 DV 4 6492' Merla-TPDX 1.5 .25" CV PERFORATION DATA INTERVAL ZONE FT SPF PHASE COMMENTS 6413-6478 C134 65" 12 120 DA 5" HD 6595-6660 A4 65 4 120 DA 4' JJ II 6705-6718 A3 13 4 120 DA 4' JJ II ~\~,s'v,~ (][I & Gas Cons. commissior~ · ~ Anchorage Last RIH: Revision: 6-18-94 LJE Reason: SI C Sand ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1 O, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission '3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action Anticipated Start Date 2W-02 Variance 11/93 2W-04 Variance 11/93 2W-05 Variance 11/93 If you have any questions, please call me at 263-4241. Si nce ely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED NOV 1 7 1-305 Alaska 0il & Gas Cons. 60mmissior' Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA " ALAbKA OIL AND GAS CONSERVATION COMMI,.,,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program_ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _~X Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1279' FNL, 202' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 737' FNL, 1439' FWL, Sec.34, T12N, R9E, UM At effective depth 638' FNL, 1661' FWL, Sec.34, T12N, R9E, UM At total depth 605' FNL, 1737' FWL, Sec. 34, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 6949' feet (measured) true vertical 6 29 0' feet Effective depth: measured 6 81 2' feet (measured) true vertical 61 81 ' feet Casing Length Size Cemented Structural Conductor 8 9' 1 6" 248 Sx Cold Set II Surface 31 1 9' 9 5/8" 780 Sx AS III & Intermediate 410 Sx Class G Production 689 0' 7" 280 Sx Class G & Liner Perforation depth: measured 6413'-6478' 12 SPF @ 120 degree phasing 6596'-6661', 6705'-6718' 4 SPF @ 90 degree phasing true vertical 5863'-5915', 6010'-6062', 6097'-61 07' TVD Tubing (size, grade, and measured depth) 3.5" J-55 set at 6537' Packers and SSSV (type and measured depth) Baker FHL @ 6245', Baker FB-1 @ 6511'; Baker SSSV @ 1904' 6. Datum elevation (DF or KB) RKB 95' feet 7. Unit or Property na~;~),~ Kuparuk River 8. Well number 2W-02 9. Permit number 85-16 10. APl number 50 -029-21 279 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 89' 89' 3119' 3119' 6890' 6243' t40V 7 995 0il & Gas Cons. O0mrnis¢oD Anc~raoe 13. Attachments Description summary of proposal .~X Detailed operation program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: Oil __ Gas _ Suspended 16. If proposal was verbally approved Name off'rover,.,, Date approved Service WAG INJECTOR FOR COMMISSION USE ONLy/ ' Si~lned Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test _ Approved by order of the Commission Form 10-403 Rev 09/12/90 IApproval No. k 77- Subsequent form require 10-/40~ .-~op '~ved Copy Returned ,Jnginal Signed By ? David W. Johnston Commissioner Date SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 2W-02 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the existing surface controlled, subsurface safety valve in Injection Well 2W-02 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. RECEIVED NOV 1 7 199~t A!~ska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatter Alaska Oil and Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton- Attached in du following wells a Well Action pi icate are subsequent t the Kuparuk River Field- notices on the Date Performed 1L-1 Conver 1L-7 Conver IQ-2 Conver IQ-7 Conver 1Q-11 Conver 1Q-13 Conver 2B-5 Conver 2B-9 Conver 2C-1 Conver 2C-3 Conver 2C-6 Conver 2C-8 Conver 2D-2 Convers 2D-7 Convers 2D-11 Convers -2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-13 Convers 2F-14 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers s on s on s on s on s on s on s on s on S on s on s on s on on on on on on on on on on on on on on on on on on on · on on · on 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11/20/85 11/20/85 11121185 11/21/85 11 /2i /85 11/21/85 11/lq/85 11/14/85 11/14/85 11/lq/85 11/14/85 11/14/85 11/14/85 RECEIVED 11 /1 6/85 11/1 6/85 11/16/85 1 1 / 1 5 / 8~k~ 0il & Gas Oons. 11 / 22 / 85 ARCO Alaska, Inc. is a Subsidiary of AltanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 85-16 3. Address 8. APl Number P. O. BOX 100360,.ANCHORAGE, ALASKA 99510 50- 029-21279 4. Location of Well SURFACE LOCATION' 1279' FNL, 202' FEL, Sec. :33, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 95' (RKB) 6. Lease Designation and Serial No. ADL 25642, ALK 2573 9. Unit or Lease Name KUPARUK RIVER tJNIT 10. Well Number 2W-2 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 15, 1985 Kuparuk well 2W-2 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both "A" and "C" sands. the ?,j o 0 1986' Alaska 0il & Gas Cons. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' "~'/~~' ~~ Title K! IPARI IK The space below for Commission use OPERAT IONS COORD I NATOR Date 1 2 / 1 8 / 8 5 Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc'~"-''. Post Office._..,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. 'Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per dri!lsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013. RECEIVED SEP2 0 O. & Gas Coils. Commissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ALASK;' "iLAND GAS CONSERVATION £ vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Tnc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 so- see attached ,. 4. Location of Well N/^ 5. Elevation in feet (indicate KB, DF, etc.) N/A 6. Lease Designation and Serial No. see attached 9, Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull TQbing [] Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state alt pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of)^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion:~ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. RECE V£D SEP 2 0 9B5 AlaSKa Oil & Gas Cons. commission Anchorage 14. I hereby certify th'at the foregoing is true and correct to the best of my knowledge. Signed ::~, /¢~_.~ ~,~-~w..~-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 ^pproved Copy eturrmd By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 -- 5 - 8 - 9 MA_R/<: 0092 100 96 95 84-152 151 126 143 101 99 159' 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 " 2580 12/15/85 20970 " " 10/15/85 20974 " " 12/15/85 029-21177 25653 2579 12/15/85 21176 " " 10/15/85 21157 " " 10/15/85 21169 " " 12/15/85 21135 25658 2584 10/15/85 21134 " " 12/15/85 21183 " " 12/15/85 21185 " " 10/15/85 029-21246 25658 2584 12/15/85 21227 " " 12/15/85 21213 " " 12/15/85 21214 " " 12/15/85 029-21058 25657 2583 12/15/85 21063 " " 12/15/85 21062 " " 10/15/85 21065 " " 10/15/85 21032 " " 12/15/85 21035 " " 12/15/85 21048 " " 10/15/85 21052 " " 10/15/85 029-21150 25656 2582 12/15/85 21165 " " 10/15/85 21119 " " 10/15/85 21124 " " 12/15/85 21140 " " 10/15/85 21159 " " 12/15/85 21163 " " 10/15/85 029-21269 25644 2575 10/15/85 21270 " " 12/15/85 21283 " " 10/15/85 21303 25643 2574 10/15/85 21262 " " 10/15/85 21264 " " 12/15/85 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25655 25644 25655 25642 I! 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " ~2/15/85 r ECEIV · -, ice' ~lasks (1, il & Gas C;ons. Oo~4m.~-mr, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of Al'aska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16- Dear Elaine- Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw ~. GRU2/L93 Enclosures If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan¥ 'PHASE AS-BUILT WELLS 9 Thru l (NSK 9. OS.ZZ3dZ) 27 34 PHASE T' AS-BUILT WELLS ! Thru 8 LOCATED IN PROTRACTED SECTIONS 33 &34 TOWNSHIP 12 N.~ RANGE 9 E., U.MIAT MER. NO SCALE NOTE' BASIS OF POSITION IS MONUMENTATION AJask 2W NORTH AND p.W SOUTH PER LHD ASSOCIATES. '" Ann [; ~ ~[LL I ¥ - 5,g79,339.00 LAT. 70a2['lS.gg05. X . $18,909.82 LOIt6. tk9°$0'~7.1931" P~O [LEV. 65.1 O.G. [LEV. 50.3 t79 FEL 1,22~ F~L SEC. 33 ~£LL 2 Y = 5,979,253.39 LAT. 70021'16.~&~1 X . $18,gBT.4k LONG. ~0 ELEV. 65.3 0.~. [LEV. ~0.$ 202 TEL 1,27g ¢NL SEC. 33 dELL 3 Y = 5,~7g.227.$0 L~T. 70°2I'lS.~gTg" X - 518.86~.ag LONG. ,1~g°50~8.51~7" P~D £L£¥. ~$.3 0.;. [LEV. 50.7 225 FEL 1,335 FHL SEC. 33 ~ELL ~ ¥ = 5,97g,172.0~ L~¥. X = 518,~2.3~ LONG. I~9°50~.1758" P~D £L£¥. 55.2 3.~. EL~¥. ~I.; 2~8 ~L 1,331FNL SEC, 33 ~£LL 5 ¥ = 5,979,307.17 L~T. 7~°21~I~.6873" X = 518,508.~8 LONG. 581 ~EL 1,255 FNL SEC, 33 dELL 6 ¥ - 5,~?§,3~2.?~ L~?, X = $tE,531.1~ LONG. I~9°50~58.2~1~'' PlO £L£V. 5~.~ 0.~, £LEV. 59.3 558 F~L 1,i~9 F% SEC. 33 i£L~ 7 ¥ = 5,~79,~18.39 L~T. X = 518,553.~7 L0~G. 1~1~$0~57.59~3" ~ £L£¥. 6~.5 0.~. £L~¥. 59.! 535 F£L ~,l~ FNL SEC. 33 ~ELL 8 ¥ = 5,979,~73.~g ~T. 70°31'IE,325~" X . 5lS.575.15 LCNG. i~geS0'ES.9375'' ~D ELEV. 5~.~ 0.G. [LE¥. 59.0 512 FEL 1,088 FNL SEC. 33 I HEREBY CERT,FY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCTOBER ~4, 1984. ARCO Alosk~, Inc. KuPoruk Project North Slooe Drilling DRILL SITE 2W CONDUCTOR AS-BUILT LOCATIONS Oct. 23, 1984 Scole' AS SHOWN Drown By' HZ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2W-2 Dear Mr. Chatterton' Enclosed is a copy of the RFT results for 2W-2. Please include with the Well Completion Report, dated 04/15/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU10/L81 Enclosure cc' 2W-2 Well File RECEIVED JUL. 0 ]91 Alaska 0il & Gas Cons. commiSsblt Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 2Vt-2 RFT Results DEPTH 6421' 6458' 6432' 6477' 6489' 6599' 6611.5' 6620' 6625' 6707' 6715' 3172 psi. 3186 ps~. 3176 3195 3200 psi. 3253 ps 3253 ps 3256 ps 3258 psi 3301 psi. 3295 ps 2802 psi 2888 psi. 2795 psi 2856 psi 2839 psi 2858 psi 2966 psi. 2464 ps~ 2965 psi. 3028 psi 3041 psi RECEIVED JUL :~ 0 ~1~ Alaska Oil & Gas Cons. Commissior~ Anchorage GRUlO/11' tw ARCO Alaska, Inc. Post Office - 100360 Anchorage, Alaska 99510-0360 TelePhone 907 276 1215 tlETURN TO: DATE' 06-27-85 TI~ANor~ITTAL NO: 5236 T RAN St-! ITT E 1) RECEIPT AND OPEN IIOLE (ONE * OF 2U-7 2U-9 2W-2 ARCO ALASKA, INC. I<UPARUK OPERATIONS ENGII',IEERING -" zoo3 o . IIEI(I~'IlT!] ARE TIIE FOLLOWING ITEfdS. . i;[qO;~LEDCE RSTUf{N ONE SZCNr;D COPY OF TI[iS TP¢~NS[4ITTAL. FINALS/SCJIL. P~5" DIL/SFL-GR 03-19-85 P, UN ~1 3625-8137 =7(2" DIL/S?L-CR 03-19-85 RUN {}1 3625-8137 ~5" DEt';/HEU-CR RAW 03-19-85 RUN' ~'1~, 7450-8~_~0. ~2" DEN/NEU-GR RA%~ 03-19-85 RUN #1 ~-7~%~-8140 "~-5" DEN/NEU-CR PORO 03-19-85 RUN ~1 7450-8].40 y2" DEN/NEU-GR PORO 03-19-85 RUN ~1 7450-8140 ~ CYI3ERLOOK 03-19-85 RUN ¢rl 7450-8100 -~5" DIL/SFL-CR 04-04-85 RUN t~l 2" DIL/SFL-CR 04-04-85 RUN ~1 5" DEI'I/N'ZU-PORO 04-04-85 RUN ~1 if P · I; 1 7~2 DEN/.U EU-. OI, O 04-0-4-85 RUN ~' ~5" DEP~/NEU-RAW 04-04-85 RUN ~1 / 2" DE!.I/NEU-i~AW 04-04-85 RUN ~1 ~CYBEiILOOK 04-04-85 RUN ~1 ~RFT .LOG-- 02-12-85 RUN ~CYi;ERLOOK 02-13-85 RUN "/--5" DEIq/NI]U- RAW 02-12-85 RUN ~2" DEN/NE U-RAW 02-!2-U5 RUN 7'~5'' DE N/N~EU- PORO 02-12-85 P, UN ~2" DEN/!4E U- PORO 02-12-85 RUN ¢'--5" DIL/Si.'L-GR 02-12-85 I(UN ¢-,2" DIL / SI:L- CR 02 -12-85 llUN 3705-8337 3705-8337 · _ --o o ,._e ? ¢-ff ?- ~~ Oeo - 7560-8000 -- 6200-6900 6200-6912 6200-6913 6200-6913 #1 6200-6913 3122-6937 3122-6937 BPAE !3. CUR!IIER C JUL;1 i1985 ~ Alaska 0il & Gas Cons. Commission DA T E ' Anchorage so~ z o ~.:'" / s p..,'-,,' UHIOb: I'( m -,--,-_ . ~ U,,_' ~', / v::o ...... ARCO Alaska, lnc Post Office ,.,ox 100360 Anchorage, Alaska 99510-03G0 Telephone 907 276 1215 DATE: 06-27-85 TRANSMITTAL NO: 5236 RETURN TO' TRANSMITTED RECEIPT AND RETURN ONE OPEN IIOLE FINALS/SCIIL. (ONE * OF EACH) ~u ALASKA, INC KUPARUK OPERATIONS ENGINEERING RECORDS CLERK--~/~E--~ ~- ~~ ATO-!llSB P.O. BOX 100360 ' ' ~ AK 99510 A~HOR..~ , I-IERI~'~TTI] A~E Tile FOLLOWING I'fEMS ~E S SIGNED COPY OF THiS TF=%NSMITTAL. 2U-7 2U-9 2W-2 )~5" DIL/SFL-GR 03-19-85 RUN %1 3625-8137 ?~2" DIL/SFL-CR 03-19-85 RUN ~1 3625-8137 ~5" DEN/NEU-CR RAW 03-19-85 RUN' ~1 7450-8140 ~2" DEN/NEU-GR RAW 03-19-85 RUN ~1 .~~--8!40 ~/-5" DEN/NEU-CR PORO 03-19-85 RUN ~1 7450-8140 ~/2" DEN/NEU-GR PORO 03-19-85 RUN ~1 7450-8140 ~ CYBERLOOK 0'3-19-85 RUN ~,1 7450-8100 --/5" DIL/SFL-CR 04-04-85 RUN 2" DIL/SFL-CR 04-04-85 RUN 5" DEI,I / i',",'] U- PORO 04-04-85 RUN 'p-2" DEN/NEU- PORO 04-04-85 RUN -~k5" DEN/NE U-RAW 04-04-85 RUN ~2" DEN/NEU-RAW 04-04-85 RUN ~ CYBERLOON 04-04-85 RUN ~RFT bOG ~ ..... 02-12-85 RUN ~RLOOK 02-13-85 RUN ~" DEN/NEU-RAW 02-12-85 RUN /2" DEN/N~ U-RAW 0~-! -US RUN ~5" DEN/NEU-PORO 02-12-85 RUN ~2" DEN/NEU-PORO 02-12-85 RUN ~5" DiL/SI.'L-GR 02-12-85 RUN ~" D!L/SFL-CR 02-12-85 RUN - 6200-6900 6200-6913 6200-6913 6200-6913 6200-6913 3122-6937 %1 3122-6937 Alaska Oil & Gas Cons. Commission DA T E ' ' ......... -- · ~ STATE SO~IO /SE 'J:' ,,I ' ARCO Alaska, Inc. Post Office Bo.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 21, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-2 Dear Mr. Chatterton' Enclosed is an addendum of the 2W-2 Well the Well Completion Report, dated 03/28/85. questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU9/LIO0 Enclosure History to include with If you have any RECEIVED J U N 2 '3 1985 ,""~"~'"- Ci! a Gas Cons. Commission An~hoi'age ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ADDENDUM_ WELL: ~/~5/s5 2W-2 Arctic Pak. Rn CBL/VDL/GR ~/6758' -5000' Rn gyro f/6750'-surf. RECEIVED Alaska Oil & 6as Col,s. Gominission An~.horage ~nt endent ARCO Alaska, Inc. Post Offi, lox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ,::'_..E Z F'T DATE' AF'RIL o-~ i°8~ ~' '.:.- I' -- 'FRAN,?HITTAL. i'-.J.O' ...r=:t 4g I 'I E: r;' F-- !,-J ]: 'f' I--I ARE T ¢- . ...... ''-, ~' . ..... ..... , I--I,.: F'OI...I.. rll.,.JI~.J(, Il EH~,. F'I_E:A,YE .AI'iI<NF~UI_E.D(;E RET~In'N Oi'-!IT. ST~'~'r':¥'' f'OF'Y OF THIS TRANSMI'FTAL .., ' -. ,I ,..¥ /~ l_ A! -. · ... F F'. ,: a ,-, U F:,' E (]E/'r N1 ,::,-:~ II TTENT I_ I F'T ,:'7OE'_/F'I-::[;1D I._r._l(:; & 'A' SAND F'BLJ S/f!' .....' T-~ * l ' ..... ::,'FBUC, IN~.,Im~_ F'RES'£'LJRE.) ,~ O E/F' B U *OE ,' r.., r.-:~ ~ ,?OE/F'BU SOE,"'C' 'SAND F'BU SOE.,/5'BHF' - 'A' STATIC BHF' DAI'A STATIC BHF' DATA 5'TATZC ]:-:HPDATA £TATiC BHF' DATA r, ,. [: ., ^ ~ T~--~T Z C HF' DraT~ STATIC BHF' DATA .-,T~-.ITIC r'14F'DATA S'FATIC BHF' DATA ,., AT,~ STATIC BHP n ^ .',':TATI~ r:~' r ....... ..... -i i"" ~.--' ~-i ~ 2'TATIC BI-IF:' DATA STATIC, .~.-qHF' DATA ,:~ , r~T.T.C BHF' ~Tf.,TZ~ c,~_,,:, DATA ~. ~ . ,.~~,, i i c! , i r~ ~.TATIC ~:'I~- ~.AT .... Fa, ,:TAT!C E:!--iP DATA :~Tr.qTIC: B!--IF' DATA ~ .'_' i I I STATIC BHF' r',*. S!'ATIC PI-IF' DATA £TATIC ~:"'F' nATA 'C' SANDS 5'UR;"EY !::. C!.!RF.: Z £R ...... V R O N .~, I £ T R I BUT i ON · DRILLING W, F'ASI-IER L, ,.)O]-IN2. TON EXXON MOBIL F'I-I I/_LI F'£' OIL NSK CLEF:i< d, F:ATI--IMELL ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany a//---7/F.'!5, ._, 3,-" i i/85 '. · -) /'> z/o_~ ...., ~.~~ ,_, -~/'-) 185 ,,_., ~-_. . 3/~/.9~ ¥ /,! / 8 'S 5/i 8/,9~ i / .')zt /!qr.{ i/°4/83~-- 31°185.. ~/~/85.. 7.., / -z / ~ ,.'l / ~.", "-- ...: -y / ,--~ ,~ . i,...'~ · · t / f i ,' L7 '..T'. t ,/'~ 4,/F?~-;.' _. _ '1 /""r-i:, ' '-" = · i / 2 o~ ~ L; ':':., · ....: .. RECEIVED APR 2 5 1985 Alaska Oil ,:~s Cons. Commission D A T E ' Anchorr. o,, ,, U i'--.~ I 0 N K TI,II_ T ~-~ s~'.-~ ', T ARCO Alaska, Inc. Post Office Bbx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-2 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L07 Enclosures RECEIVED APR 2 2 ] ]85 Alaska 0il & Gas Cons. Commlssror~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,.AND GAS CONSERVATION C£ VllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21279 4. Location of well at surface 9. Unit or Lease Name 1279' FNL, 202' FEL, Sec.33, T12N, R9E, UM ~ ~. O .~ ~,~ ~ . . ~ i .1~ ~ ~ Kuparuk River Unit At Top Producing Interval } 'V::~':.,~.- i 10. Well Number 737' FNL, 1439' FWL, Sec.34, T12N, RgE, UM ;Su ~ ~ 2W-2 At Total Depth f 5. i'ff. ~ '~ 1 1. Field and Pool 605' FNL, 1737' FWL, 5ec.34, T12N, R9E, UM , i Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri var Oi 1 Pool 95' RKBJ ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions -02/08/85 02/1 2/85 02/14/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6949'MD,6290'TVD 6812'MD,6181 'TVD YES [~X NO []I 1909 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/Cal/SP/GR, FDC/CNL~ RFT~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 89' 24" 248 sx CS II 9-5/8" 36.0# J-55 Surf 3119' 12-1/4" 780 sx AS Ill & 410 sx Class 7" 26.0# J-55 Surf 6890' 8-1/2" 280 sx Cla$$ G 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) 6705' - 6718' w/4 spf, 120° phasing 3-1/2" 65~7 6596' - 6661' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6413' - 6478' w/12 spf, 120° phasing 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 GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD 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 chi~)NONE EC~/ yED APR£ 2. 1985 ,~1~ ,_ · ,,-s~a 0ii & ~as Cons Anchora£e' C°mrnission Form 10-407 * NOTE: Tubing was run and the wel 1 perforated 03/17/85. GRUS/WC48 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH .GOR, and time of each phase. . . . . : Top Upper Sand 6~12~: .. 586], N/A .,. '-.. ~se 'upper sand 6~70~ 5909' ... Top L~er Sand 6576' = 599~' :' ~ ..... . .' : . ~se Lower sand 6725' 6112, . _ -.._ .-~ ,,. ..:'. , ; , · : : . ;. :.- . . . .. . . _ . , . - . ; . 31. LIST OF ATTACHMENTs '.. 32. I h~r~y~;t~th~ t~~fng is true and correct to the best of my knowledge /j INSTRUCTIONS General' This fOrm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of OPeration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection', Gas'Injection, Shut-in, Other,explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report - Dally In~'uction~: Prepare and submit the "Initial Ret~ort', on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPudding should be summarized on the form giving inclusive dates only. District Alaska State I ~un~. ~ri~ or ~rough I North Slope Borough Field I Lease or Unit Kuparuk River I ADL 25642 Auth. or W.O. no. lTItle AFE 203556 I Drily Complete & Perforate -, Parker 141 API 50-029-21279 Alaska JWell no. 2W-2 Operator ARCO Alaska, Inc. IARCO W.I. Prior status if a W.O. IDate IHour Spudded 2/8/85 0800 hrs. S;)udded or W.O. begun 56.24% Date and depth as of 8:00 a.m. 2108185 2/09/85 thru 2/11/85 2/12/85 2/13/85 Complete record for each day reported 16"~ Accept rig @ 0430 hrs, 2/8/85. RU. 16" ~ 5425~_e (5336'), Turbine drlg Wt~,/PV 12, YP 8, PH 10, WL 12.5, Sol 5 Spud well @ 0800 hrs, 2/8/85. Drl & surv 12¼" hole to 3140', C&C, TOH. RU & rn 85 ]ts, 9-5/8", J-55, 36# BTC csg to 3118', FC @ 3036'. M&P 780 sx AS III & 410 sx C1 "G" w/.2% S-I & .2% D-46. Displ using rig pmps, bump plug. ND Hydrl, NU & tst BOPE. TIH, tst csg to 1500 psi; OK. DO cmt & flt equip. Conduct leak-off tst to 12.5 ppg EMW. DD & surv 8½" hole to 5425'. 3340', 6.1°, N71E,- 3339.8 TVD, 7.43 VS, 2.27N, 7.10E 3651', 19.4°, N83E, 3642.49 TVD, 76.42 VS, 16.33N, 74.69E 3963', 29.2°, N79E, 3926.30 TVD, 204.60 VS, 33.96N, 202.39E 4438', 36.4°, N75E, 4319.38 TVD, 470.75 VS, 89.50N, 462.83E 4854', 40.5°, N71.5E, 4645.17 TVD, 729.22 VS, 161.89N, 711.18E 9-5/8" @ 3118' 6949', (1524'), Circ Wt. 10, PV 11, YP 8, PH 9.0, WL 6.6, Sol 10 Drl & surv 8½" hole to 6949'~circ prior to short trip. 5322', 40°, N67.5E, 5002.36 TVD, 1029.61VS, 267.79N, 994.42E 5822', 38.5°, N63.5E, 5389.56 TVD, 1340.58 VS, 398.98N, 1282.29E 6072', 37.5°, N60.5E, 5586.56 TVD, 1489.87 VS, 471.24N, 1418.19E 9-5/8" @ 3118' 6949', (0'), Pmp slug to trip Wt. 10, PV 14, YP 8, PH 9.5, WL 6.0, Sol 10 C&C hole, TOH f/logs. RU Schl, log DIL/SFL/SP/CAL/GR f/6944'-3118', FDC/CNL f/6944'-6200', 3750'-3600', RD Schl. TIH, wsh to btm, C&C, TOH on short trip. 6949', 40°, N65E, 6271', 2024 VS, 722, 1906 The above is correct For form preparation and dlstributi.~. see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Date 3/14/85 ITM Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is nol required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the entire operation if space is available. District ICounty or Parish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. JTitle I AFE 203556 Parker 141 A.R.Co. w.I. Operator ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 2/14/85 North Slope Borough I Accounting State ADL 25642 Drill, Complete & Perforate cost center code Alaska IWell no. 2W-2 API 50-029-21279 rTotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour I Prior status if a w.o. I 7" @ 6890' 6949', (0'), RR POOH, LD DP. Chg rams to 7" & tst. RU & rn 171 jts, 7", 26#, J-55 Butt w/FS @ 6890', FC @ 6861'. Cmt w/280 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Bump plug w/3000 psi f/15 min; OK. Flts held; OK. ND BOP & set slips. Cut off csg & NU wellhead. Tst pack-off to 3000 psi. RR @ 0500 hrs, 2/14/85. Old TO Released rig 0500 hrs. Classifications (oil, gas, etc.) O±i INew TD Date 6949' (2/11/85) I 2/14/85 PB Depth Kind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary Well no. Date Reservoir Producing Interval IOil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and dis~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I County or Parish I State Alaska North Slope Borough Alaska Field IL ...... Unit Iwe,, .~W_2 Kuparuk River ADL 25~42 Auth. or W.O. no. ~Title AFE 203556 I Completion Nabors 1-ES API 50-029-21279 Operator ~A.R.Co. W.I. rrotal number of wells (active or inactive) on this ARCO Alaska, Inc. I 56.24% }cost center prior to plugging and Jabandonment of this well JDate IHour Prior status if a W.O. 0930 hrs. Spudded or W.O. begun Completion 3 / 15/85 Date and depth as of 8:00 a.m. Complete record for each day reported Old TO Released rig 1200 hrs. 7" @ 6890' 6812' PBTD 10.0 NaC1/NaBr Moving rig. 7" @ 6890' 6812' PBTD, RR Kuparuk Crude w/20 bbl diesel cap in tbg Accept ri~ @ 0930 hrs, 3/15/85. ND tree, NU & tst BOPE. RU WL. RIH w/4" csg gun, 4 SPF, 120° phasing. Perf f/6705'-6718', 6596'-6661'. RIH w/5" csg gun, 12 SPF, 120° phasing. Perf f/6458'-6478'. TIH w/5" csg gun, 12 SPF, 120° phasi~ Perf f/6458'-6413'. RIH w/pkr & tailpipe assy, set @ 6510'. RIH w/203 jts, 3½", 9.3#, J-55 8RD, EUE, IPC tbg &lnd. Set pkr & tst. Shear out of PBR. Set BPV, ND BOPE, NU & tst tree. Displ well to crude. Set BPV. RR @ 1200 hrs, 3/17/85. SSSV @ 1909', PBR @ 6237', FHL Pkr @ 6250', FB-1Pkr @ 6516', "D" Nipple @ 6529', Shear out Sub @ 6537', TT @ 6536.62' 3/15/85 3/16/85 thru 3/18/85 New TD Date RECEIVED rcc'd 41 s Ala.~ka 0!! '~E~hCOnS. C0rn~s[s~qn i Anchorage PBTD I Kind of rig 3/17/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on lest Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~ For form pre'~aratio~ and (;,st~ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle 4/11/85 Drilling Superintendent I::: Ii': T LJ I'::t-,! T 0 · .- "T' D ....... · ' · · R [': C [.'. :[ F"I' A I-.!-):,', ARCO Alask.a, lnc Post Olfice Box 100360 Anchorage, Alaska 99510-0360 Teleph'one 907 276 1215 . . r- S Z (: H[.i:L) C.:Ol:"t' (')1= 'rl-.I l :; '['I:,:Ai-I"¢H ]: T'FF.,L. ~ 1 fi~ ..... / i (~ 1 --21 '" ~;',':5 I:;; t..l ? I ..... I ~ o ........ ---' ,' ,*.., 17 ,.~ -2 [:--- i 3.'; '"" 1 .... 1 ;'5- ~:' ':; ""- -- ",-" 9 ' .....- [', brJ. :Ii: i _;.':: i c:.'" ":",, ~, 6 ~ ' ' ~ C) ct' - n b,~-- f ,3 0 t -- 0 -I S '~ " ........ · .-. '"'. ... IR U N-,, .... 1 ,-' c> 0 (-; --- ? ,,., ' '..: ~3 .-:,4---t.:, 0t.-"2o.--C',':'-- 7:3 ,"-; o0'=',5 / - .Ul' -"' bJ -- 1 4 0 t '--S ~ --.~ L~; I? Ui,! ":g: i /'r' O,'h .... :... ~' , ,, "" C) 42 7 C) - ,-, F: U i',l 1 "5' ;', 0 ':~,"~ S' · .... ,., -, ',_'- v t.., ~..- · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-2 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2W-2. I have not yet received a copy of the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L71 Enclosure Oil & Gas Cons, Commission Ancho[a~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA . AND GAS CONSERVATION C£ .vllSSION WELL COMPLETIO# OR RECOMPLETIO# REPORT A#D LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 85-16 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21279 4. Location of well at surface 9. Unit or Lease Name 1280' FNL, 202' FEL, Sec.33, T12N, RDE, UN (Approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2W-2 _ At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 95' RKB ADL 256/+2 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/08/85 02/1 2/85 02/14/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6949'MD 6812'MD YES [] NO E~X N/A feet MDI 1450' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/Cal/SP/GR, FDC/CNL, RFT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 89' 24" 248 sx CS II 9-5/8" 36.0# ' J-55 Surf 3119' 12-1/4" 780 sx AS III & 410 sx Class G 7" 26.0# J-55 Surf 6890' 8-1/2" 280 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A _ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A -- 27. N/A PRODUCTION TEST Date First P~oduction I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hou;sTested PRODUCTION FOR OIL-BBL GAs-McF wATER-BBL CHOKE SIZE I GAs-oILRATIO TEST PER,OD I Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , NONE r-~ ,.,,f Form 10-407 GRUS/WC36 . ,, ~.,..o, 8tj.; Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. - ..... : ~" -', x-~ ~'~~']-" ~. ,' ~:'-", ,~.~-'.,,--~- F.,~-,i,;- -.- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and timeof each phase: _ . ' N/A ' "-" N/A , ~ ';~ -.: , -' . .~,~ -, :; . : ~ . ., . : , · ,. . . .:. . ,,. .. t ; '.. .-; : -- : . . -: , -. '.~ , 31. EIST OF ATTACHMENTS .~. .' _ ' . B2. I herebg certifg that the fore~oin~ is true a~d correct to tho best of INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection'for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Directional Services Pressure Services Chemical Transmission Systems April~,~ 1985 Mr. Randy Ruedrlch ARCO Alaska, Inc. P. 0. Box 560 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-50025 Well: 2W-2(SEC 55 T12N RO9E) Field: Kuparuk Alaska Survey Date: March 08, 1985 Operator: 3. Samec Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Survey on the above well. ~hank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED APR 2 2 1985 Alaska Oil & Gas Cons. commissio~ Anchorage ARCO ALASKA, '2W-2 KUPARUK ALASKA I NC:. SF'ERRY-SUN WELL SURVEYING COMF'ANY ANC:HORAGE ALA'.--;KA COMF'UTATION DATE MARCH 11, 19:s:5 VERTIC:AL SECTION C:ALCLILATED ALONG C:LO'.--;URE DATE OF SURVEY MARCH 8, BOSS GYROSCOPIC SURVEY dOB NLIMBER AK-BO-50023 KELLY BU:--;HING ELEV. = OPERATOR-:=;AMEC ................ TRUE SUB'SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COLIRSE DIRECTION DEGREES DOG-LEG '._:;EVER I TY D E G / 1 <') 0 TOTAL RECTANGLILAR C:OARD I NATES NORTH/.'_--;OUTH EAST/WEST 0 0.00 -95.0C) 0 0 100 100.00 5.00 0 10 ..................... 200 200 00 1O' ._,='. O0 O' "10 300 :300.00 '205.00 0 9 400 400 00 '-' '~ = . . oC ._, 00 0 ............... '500 ._~ O0. O0 405 . O0 <-~_ ,_.°' 600 600.00 505.00 0 3 700 700.00 605.00 0 4 800 800.00 705.00 0 9. A. 0 900 .00 ~,.o r~ ._P:. 00 0 1000 1000.00 '- ' = ;~ U._,. 00 0 .......................... 1100 1100.00 1005.00 0 1200 119'2.99 1104.99 0 1300 12'79.99 1204.99 0 1'400 ..... 1399.9~ 1304.99 0 1500 1499.99 1404.99 0 1600 159'2. '-"" =~ ' . - - ............................ 17001'6~. '~8 1604.98 0 1800 1799.97 1704.9.7 0 1900 1899.94 1804.94 1 ~ ........ oo 1 ?U4. 2 .~000 1'99~ ~'~' '~' '-"~' ~ 100 2099. :q_ A. 2004. :30 ~'-' 2200 2199.69 2104.69 2 ......................... ~ 2400 2:399.50 2:304.50 2 21 2500 2499.42 2404.42 2 :3 z :,00 2599. o6 2504. o6 I 47 2700 2699.31 2604. ¢, 1 i 41 2800 2799.2:3 2704.28 I :30 ..................... 2900 2899.24 2804.24 I 19 N O. 0 E N 44.80 W ...... N'21,6'2 W N 18.60 W N43. OW N'34:10 W N 7.50 W N 42.39 W 11 ........... N' 4'7. O'E 8 N 25.10 E 5 N73. OW 18 "S"'76.50-W 25 S 55.19 W 30 S 53.50 W 18 ...... S 35, 89' W 23 S 15.30 W Om 0. 0. 0. 0. 0. ('). 0. 0. 0. 0. 0. 0. 0. 19 S 19.19 W 0. · -"-' F.~ ...... '--.'"' 30 "'E A '. ... ,~, ._ .,_. 57 N 74.80 E 1. 4'.-.9 N 57.69 E 0. 8 ........... N' 5~.;"~ 87' "E O. :30 N 45.69 E O. 00 18 07 03 07 03 10 (..) ._m 22 19 2:-': 07 2:3 15 ¢)8 '21" 15 33 5'7 :_-9 N 40.6 ? E 0. :2:9 /: N'-' 'Zl:4,3 O' "-'E ................ rF~ '40 N 47.19 E 0.16 N 48.80 E 0.2'2 N" .=._ ¢]'.. 39E .................... 0', ,:..:.'-' ='' N 41.10 E 0.30 N :37.89 E 0.2('-) ., N '"-'.'=" iA.,.,_,. _ E 0.3('). PAGE 1 1985 95.0C) FT. VERT I F:AL F;E C T I O N ('). 0(-) 0.00 (:). 0.11 N 0.11 W -0.0'7 0.37 N 0.28 W -0.14 (-) / ,-- .=.~, N 0..'2:8 W -0· 15 0.88 N 0. ~..~]":' W - 0 .20 I 09 N 0.69 W -0.29 .-~ I~' .~._, N 0.77 W -0.:32 1.:2:6 N 0.82 W -0.33 1' ~'-' . .. · _._-. N 0 74 W -A 20 1.76 N 0.56 W 0.05 i 91 N (:)..=, "-' . ..... =, W 0 08 1 87 N "' 0.91 W -A.'25 1 · 59 N 1.47 W -0. :.=.:'7 i 12 N :2.13 W i :,._, 0 /..4 N '" , .,:.. 64 W -2.28 0.09 N 2.8'.-} W -2.7 0· '=(' ' .... --' A7 W -3 06 ..m .) 43 ._,.. . 1'17 S 3.15 W -:3.:36 1 3'7 S 2 ":'":' W -2 /-,Fl 0. :30 t:..; 0. 19 W - 0. :28 1, ._,7 N 2.7:--: E o.'" F~9.. 4. i'-'N..- ~_.._._.'--'/- E 6, .8'FY 7.50 N '?.02 E 10.9::3 '10,89 N 12.11 E 15. (2)1 1:3.81 N 15. I 1 E: 18. ::::(2) :{6.44 N t:3.01 E 22.41 1L-:-. 66 N 20 .6,2 E ..'._,.'-'= /_-,1 20.77 N :...'"'":' :-':0 E ~.":'._.c' . ._.'--'._~] 22.92 N 24.57 E 3(2).74 24.98 N "-..'5.93 E 32.69 ARCO ALASKA, 2W-2 KUPARUK ALASKA I NC:. SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION BATE MARCH 11, 1985 VERTICAL SECTION CALCULATED ALONG CLOSURE DATE OF SURVEY MARCH 8, BOSS GYROSCOPIC SURVEY- dOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = OPERATOR-SAMEC PAGE 2 1985 95.00 FT. TRUE -SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN 'COURSE DIRECTION DEGREES DOG-LEG SEVERITY BEG/lO0 3000 2999.22 2904.22 i 6 3100 3099.20 3004.20 0 58 ........................ 3200 ....... 31'99, I9 .... 3104-19' 1 1 3300 329~.06 3204.06 4 36 3400 3398.35 3303.35 8 47 ......................... ~00 ...... 34~6'.5I ..... 340'1.51 .... 1'3 '7 3600 3592.99 3497.99 17 17 3700 3687.50 3592.50 20 48 3800 ......... 3900 3869.9~ 4000 3~57.68 ....................... 4'I-00 .......... 4042:'65 4200 4125.19 4300 4206.65 ...................... 4400 4287.41 4500 4366.57 4600 4443.74 ............................. 47'00 ....... 4520.07 4800 4596.73 490(:) 4673.58 .................................... 5000 .... 4750.63 · ~100 ~._.13 5200 4905.91 ....................... ~300 4~83.54 5400 5061.01 5500 5138.34 ........................... 5600 '5215.75 5700 5293.92 5800 5372.31 5900 5451.30 ........ 3684'/88' 3774.99 3862.68 3~47,65 4030.19 4111.65 '4192.41 4271.57 4348.74 4425.07 4501.73 4578.58 4'655.63 4733.13 4810.~1 4888.54 4966.01 5043.34 5120.'~5 51~8.92 5277.31 · _ ~ .J ~, ~ . 24 27 30 33 35 35 36 38 40 40 39 38 38 '3:7 39 39 38 38 37 37 N 29.69 E N 31.19 E ....... N-'33.6~") E' N 64.89 E N75. OE ......... N'"77,6? '-E N :--:2.19 E N 83.60 E ' 1'0 ............... N'""8'2,' 89" E 11 N 79.30 E 13 N 78.10 E 23 ..................... N"'-78 ;"~0" IS ..... 19 N 78.50 E :.-.-:4 N 78. 0 E O. 22 0.14 0.07 3.76 4.34 4.36 4. :3:_--: 3.55 ''3.38 3.40 .=,. 08 ..,. '17 1.93 0.39 "41 ............ N" 77;' 1'..~'" E ...... I',' 22 36 N 76.50 E 1.96 21 N 75./=.0 E 1.84 7 ................. N'"75',' 'I? "'E O, 35 47 N 74.:E:9 E 0.:38 46 N 74. 10 E 0.51 26 ..... N"73,'69 E' 0.42 56 N 72. :-':9 E 0.71 56 N 72.30 E 0.38 'I1 N 7I'. 3~ E .... 0'.'62 15 N 70. 10 E 0.82 26 N 69.19 E 0.60 ' 44 N 68.50 E 0;"84 47 N 67.30 E 0.75 58 N 66.10 E .1..11 ,. 40 N'~;5.19 E' 0,62 TOTAL ......... RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECTION 26.85 N 26.96 28.41 N 27. :--:8 29.'88 N 28, 8'1 32.32 N 32.94 36.00 N 43.96 40.3~/ N 62.43 44.8:3 N 88.26 48.8:-': N 120.64 53-': 34 N 158'. 63 60.12 N 201.42 69.55 N 248.53 80.23'N' 300.14 91.48 N :355.4:3 103.30 N 412.21 "115.96 N 469.81 129.87 N 529.28 145.20 N 590.98 161',49 N 653.50 178.05 N 715.54 195.15 N 777.20 212.83 N 8:38.44 2:_--:0.98 N 89:-':. '.:.~7 249.78 N 958.95 269.41 N 1018.84 290.26 N 10'78.5:3 312.31 N 11:37.99 335.06 N 1196.80 358.62 N 1254.81 38:3.1'7 N 1311.8:3 408.45 N 1367.70 E E E E E E E E E E ._ .. _. E E E E E: E E E E E 34.2'7 35.66 37.02 41.72 53.34 72.23 '~8.08 12S). 167.35 210.00 257.5'.-? 309.84 :365.77 423.2:--: 481.84 542.59 605.90 670.30 73:4.34 798.20 861.85 '~24.98 'P87.81 1050 '"'" . ,_.', .-' 1114.06 1177.45 1240.47 1303.00 1364.92 1425.99 ARCO ALASKA, 2W-2 KLIPARLIK ALASKA INC. SPERRY-SUN- WELL SURVEYING COMPANY ANCHORAGE ALASKA VERTICAL SECTION CALCULATED ALONG CLOSLIRE COMPUTATION DATE MARCH 11, 1785 DATE OF SURVEY MARCH 8, BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = OPERATOR-SAMEC ......... TRUE SUB=SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6000 5530.68 5435.68 6072 5588.11 5493.11 .................... 6'100 5610.54 5515.54 6200 5691.17 5596.17 6300 5772.11 5677.11 ........................ 6400 5853.03 5758'.03 6500 5933.4? 5838.4? 6600 6013.34 5718.34 ......................... 6700 .... 60?2,70 59?7.70 6750 6132.21 6037.21 6800 6171.75 6076.75 ................................... 6900 6250.82 6155.82 6?49 628?.56 6174.56 COURSE COURSE DOG-LEG INCLINATION DIRECTION SEVERITY BEG MIN DEGREES BEG/lO0 TOTAL REC:TANGULAR COORDINATES NORTH/SOUTH EAST/WEST 37 13 N 64.10 E 0.81 434.47 N 1422.65 E 4._,.", 8C) :--:6 5:--: N 63.10 E 0. '.:) 1 ='-'. N 1461.55 E 36 33 .......... N '63.1'0" 'E 1.47 461.38 N 14'76.50 E 35 57 N 62.50 E 0.70 488.41 N 1527.10 E 35 57 N 64.50 E 1.17 514.61 N 1581.65 E 36 0 .......N"65,89 E 0.82 539.25 N 1634,'?;8 E 36 51 N 65.8'~? E 0. ::.-':6 56:3.50 N 168'?. 18 E 37 9 N 66.10 E 0.32 587.98 N 1744.17 E 37 48 ...... N'66.' 0 E 0.64 612.68 N 1799.78 E 3:7 45 N 66.37~ E 0.50 625.04 N 1827.81 E 37 45 N 66.39 E 0.00 637.30 N 1855.86 E 37 45 N 66 '39 E 0.00' 661.81 N 1911.96 E 37 45 N 66.39 E 0.00 673.82 N 1'~3'~).45 E ............................ HORI'ZONTAL DISPLACEMENT = 2053.16 FEET"' AT' NORTH 70 DEG. 50 MIN. EAST AT MD = 6949 THE CALCULATION F'ROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF' C:LIRVATURE · PAGE 3 1 '~}85 '.-?5. O0 FT. ._ VERT I CAL S E C: T I 0 N 1486.4.ti 1=-....,,-. .~.:, 1546. 14 1604.70 1662.93 1721. 17:_--:0.56 1 :_--:40.54 1901. 17 1 'F:~31.70 1962.22 2023.26 2053. 16 METHOD. ARCO ALASKA, INC. 2W-2 KUPARUK ALASKA F;F'ERRY-SI_IN WELL SLIRVEYING COMF'ANY ANF:HORAGE ALASKA COMPUTATION DATE MARCH 11, 1985 PAGE 4 DATE OF SURVEY MARCH 8, 1985 dOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = 95.00 FT. OPERATOR-SAMEC ..... MEASURED 'D~PTH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH ]'RUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 0.00 .................... 1000 1000.00 2000 1799.88 3000 2???.22 4000 '''3?57.68 5000 4750.63 6000 5530.68 - .~ .... 00 0.00 0.00 0.00 'PO5, O0 I', ..~ 1 N .... O. 58 W 0.00 0.00 1704.88 1.57 N 2.7:3 E 0.12 0. 12 2904. . .'~2 ~.'-'/- 85 N 26.9E, E 0.78 0.66 :~8/-,~ 68 ' /-,9.~ N -248 53 E 42 4~ ~ 24? : ..... ,. 63 ~'-' 12 . ,_,..,o-~, N:~,'" c: ..... ::: . 44 E . :37 207 . ~'~. ~_ ~'~ 68 434.4? N 1422. ~ ~- 219 "~' ._~ .... ,. ~,..., E 467.32 . 67~.8z2-' ~ ............... N 1939' ~. . 4.., E 659.44 ........................... 6949 (:, ..'89. ~/_~ 6194.56 THE CALCLILATION F'ROCEDLIRES ARE BASED ON THE USE OF THREE DIMENSIONAL RADILIS OF CURVATLIRE METHOD. ARCO ALASKA. 2W-2 KUPARUK ALASKA MEASURED DEPTH 0 195 295 495 595 ..................... 695' 795 ~5 1095 1195 1295 1395 1495 1695 1795 1 1 INC. SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 11. 1985 DATE OF' SURVEY MARCH JOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SLID-SEA DEPTH ]'RUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0.00 ~5.00 195.00 295.00 3?5,00 495.00 595.00 695.00 795.00 895.00 ~95.00 095.00 195.00 295.00 395.00 495.00 595.00 695.00 795.00 -95.00 0.00 0.00 0.00 O, iO'N 0.10 W 100.00 0.35 N 0.27 W 200.00 0.63: N 0.38 W 300.00 0,87 N 0.51W 400.00 1.08 N 0.68 W 500.00 1.25 N 0.77 W ' 600~00 1~35 N 0.82 W 700.00 1.51N 0.76 W 800.00 1.75 N 0.57 W 900.00 1.90'N ........ 0.57 W 1000.00 1.87 N 0.88 W 1100.00 1.61N 1.44 W 1200.00 1.14-N 2;'10 W 1300.00 0.66 N 2.63 W 1400.00 0.13 N 2.88 W 1500.00 0~47'"'S 3,'06'W 1600.00 1.13 S 3.15 W 1700.00 1.3~ S 2.41W 0.00 O. O0 O. 00 O. 00 0.00 O. O0 0.00 O. O0 O. 00 0.00 O. O0 0.00 0.01 0.01 O. 0I O. 01 O. 02 0.02 0.03 O. 00 O. 00 0.00 0. O0 0.00 O. 00 O. 00 0.00 O. 00 0.00 O. 00 0.00 0, 00 0.00 0.00 0. O0 O. 00 O. 01 PAGE 5 1985 95.00 FT. ARCO ALASKA? 2W-2· KUPARUK ALASKA MEASURED DEPTH 1895 1995 2095 2195 2295 2395 2495 2695 2795 2895' 2995 3095 3195 3295 3396 ...................... 34'?8 3602 3708 I N C. SPERRY-SUN WELL SURVEYING COMPANY ANCHORAaE ALASKA COMPUTATION DATE MARCH 11, 1985 DATE OF SURVEY MARCH JOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEF'TH ]'RUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 1895.00 1800.00 1995.00 1900.00 2095.00 2000.00 2195.00 2100.00 22~5.'00 2200.00 2395.00 2300.00 2495.00 2400.00 ~5~5.00 2500.00 2695.00 2600.00 2795.00 2700.00 28?5.00' '2800,00 2995.00 2900.00 3095.00 3000.00 31~5.00 3100.00 · ~.':.o~ 00 :::200.00 3395.00 3300.00 34~5.00 '3400,00 3595.00 3500.00 3695.00 3600.00 0.38 S 1.47 N 3.9'7 N 7.33 N 10.75 N 13.69 N 16.33 N 18,'57-N .............. 2(3. d. 7 N 22.83 N 24. ~0 "'N .......... 26.78 N O. :32 2.57 5.71 8.87 '11...:.)7 14.97 17.89 20.52 22.71 24.51 '25.'8:3 26.92 28.35 N 27.84 27.8I"N ........ 28~'77 32.19 N 32.67 35.86 N 43.48 40,32'"N ...............62;"1'0 44.92 N 88.89 49.16 N 123.53 0.06 0. 12 0.20 O. 30 0.41 O. 50 O. 58 0.64 0.68 0.72 O. 75 0.78 0.79 0.81 0.93 1.61 3.45 7.11 13.04 0.03 0.06 0.08 0.11 0. I1 0.09 0.08 0. Od, O. ()5 0.04 O, 03 0.02 0.02 O. 02 0.12 0.68 I. 84 3.66 5.93 F'AGE 6 19:E:5 95.0C) FT. ARCO ALASKA, 2W-2 KUPARUK ALASKA INC. SPERRY'SUN"WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 11, 1985 PAGE 7 DATE OF SURVEY MARCH 8, 1985 dOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = 95.00 FT. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL .... DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 3816 3795.00 ......................... ~28 3895,00' 4043 3995.00 4162 4095.00 ....................... 4285 .... 4175.00 4409 4295.00 4536 4395.00 .................. 4667 44'~5.00' 4797 4595.00 4927 4695.00 ..................... 505'? ...... 47~5.00 5185 4895.00 5314 4995.00 ....................... 5443' 5095.00 5573 5195.00 5701 5295.00 ...................................... ~828 ....... 537~'.00 5955 5495.00 '6080 5595.00 3700.00 54.24 N 165.46 E 21.62 3800.00 62;60'N .... 214131E 33.25' 3900.00 74.13 N 270.42 E 48.51 4000.00 87.22 N 334.46 E 68.00 '4100~00 '101.'56"'N 404~06 E ~0.67 4200.00 117.22 N 475.33 E 114.47 4300.00 135.17 N 551.36 E 141.39 '4400~'00' ' I56,0~"N ........... 633',07 E 172.21 4500.00 177.68 N 714.15 E 202.75 4600.00 200.03 N 794.34 E 232.87 4700;00 " 223.12"N ................... 873;'36 E' 262,39 4800.00 247.10 N 950.55 E 290.97 4900.00 272.39 N 102'7.69 E 319.79 5000.00 29~,74"N ........... 1104.65 E ' '348.90 5100.00 328.91N 1181.16 E 378.15 5200.00 358.96 N 1255.61E 406.39 5300. O0 390,35'""'N ............. 1328;'02 'E ' 433.79 5400.00 422.66 N 135)8.23 E 460.17 5500.00 456.14 N 1466.18 E 485.63 8.57 11.63 15.27 19.48 '-"'-" ..... 23. :E:() 26. 91 30. ::3 30. 54 30. 12 29. 5::: 2::. 5:--: 28. :--:1 '29. I 1 29. 25 28. 24 2'7. 40 2/:.. 39 25. 4/_'. ARCO ALASKA, INC. 2W-2 KUPARUK ALASKA SPERRY-SUN WELL-SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 11, 1785 PAGE 8 DATE OF SURVEY MARCH 8, 1'.-.-~85 ,JOB NUMBER AK-BO-50023 KELLY BUSHING ELEV. = "?¢5.00 FT. OPERATOR-SAMEC ............ MEASURED .... DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SLIB-SEA DEPTH ]'RUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 6204 ........... 6328 6451 6576 ............................ 6702 6829 6949 ~, o :: ._,. 0 0 ~ .... F, (') (3 . (3_ 0 4 8 9.6 9 N 1 ._~._,'=' 1 . 5 '7 E P;_ ¢3. 9.. 7 3: 5795.00 5700.00 521.76 N' 1596.64 E 533.28 5895.00 5800.00 551.74 N 166,2.91E 556.94 5995.00 5900.00 582.35 N 1731.46, E 581.98 6095.00 6000.00 613.41N' 1801.42 E 607.92 6195.00 6100.00 6,44.50 N 1872.35 E 634.41 6289.56 6194.56 6,73.82 N 1939.45 E 659.44 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 24.11 23.55 23.6,6 '-'~- 04 25. '~3 26,. 49 25.03 ARCO ALASKA, KUPARUK ALASKA I NC. SPERRY-SUN-WELL SURVEYING COMF'ANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 11, 1985 PAGE 9 DATE OF SLIRVEY MARCH 8, 1985 · . dOB NUMBER AK-B0-50023 KELLY BLISHING ELEV. = 95.00 FT. OF'ERATOR-SAMEC .............. MEASURED ........ E~PTH INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS ]'RUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOL~H EAST/WEST MARKER 6412 ....................... 647'0 6576 6725 ....................... 6750 6812 6949 5862.74 5909.48 5994.21 6112.45 '61'32.21 6181.24 6289.56 5767.74 5814,'48 5899.21 6017.45 6037.21 6086.24 6194.56 542.13 N 1641.42 E TOP UPPER SAND 556.15""N ..... 16'72.76 E BASE UPPER SAND 582.11N 1730.92 E TOP LOWER SAND 618.91N 1813.78 E BASE LOWER SAND 625.04'N I827.81~E SURVEY DEPTH 640.24 N 1862.59 E PLUG BACK TD 673.82 N 1939.45 E TOTAL DEPTH DRILLER ARCO ALASKA, INC. 2W-2 ..... STRATIGRAPHIC SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA MARKER ....... MEASURED DEPTH TVD- THICKNESS BKB BKB SUB-SEA VERT I CAL TOP UPPER SAND 6412 BASE UPPER SAND 6470 TOP LOWER SAND 6576 BASE LOWER SAND 6725 ................. PLUG BACK TD ' ~ 6812 TOTAL DEPTH DRILLER 694~ 5862.74 5767.74 5~0~.48 5814.48 5994.21 58~9.21 6112.45 6017.45 6181;24~' 6086.24 6289.56 61~4.56 COORDINATES WITH REF. TO WELLHEAD (ORIGIN-1279FNL 202FEL) SEC 33 '~TI~N ..... RO~E 542.13N 1641.42E 556.15N 1/_-.72.76E 582.11N 1730.92E 618.91 N i ::: 13.7:--:E 640.24N 1862.59E 6 7:3.8 2N 19:'4'.;~. 4._,E 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. .............. BAT~CAECUEATiONAND ~INTERPOLATION~By RADIUS'OF~CURVATURE ................... DATE 'OF SURVEY MARCH 8, 1985 COMPUTATION DATE MARCH 11, 1985 .JOB NUMBER AK-BO-50023 KELL¥'"BUSHING ELEV. = 95.00 FT. i RdE $CqLE : - ; !NCh 70 E?O. OO ¢ E32.0 2¢!-2 MGqCE 5, i985 -506. CO 69&9 ? ?~ SCqLE 2 ~,',; 38oa. fie \, VERT[CRL SECTIdH !S 2Q53. ~.8 ~L~NG ~X,~.. a.~. ~2e9.5~ ~ 6949 LSqC. Z~ Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. bPERATOR, WELL ~ME J~ND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Well History Samples Core Chips Core Description , Inclination Survey Drill Stem Test Reports Production ~es~ ~eForts · ~ , , ...... Log Run Digitized Data · , ARCO Alaskal Inc. · Post Office F..,... 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~"~ T 'T' i',~ ' F;: I::.- C 0 Ik~) 3' C I... I!: I_..~:; I(,,,- h T (ii--- t t t .5.E.; . . . . r"~i'!CtlOl';:(~(.~E, ~'-.~1,, '"'""~,.-. :; ..,, i ,"-'~,, F,, :.:. r: I:: I'" T ~' '" .. I., C Ii:: I., L:, ';I. ,!: 'i" I::: ]: f.; I.l'l ]: 0 N: . I., ~-., I!E I'~ I:;' .[ I... I... ]' i.I ('; H ~ F' A,:? 1--I Iii; I:;.: !-? ... C!..II':,'I';: :1: l::i':'l ..... I..P..I li.~ :."T,:IH : C IIE V I::: 0 H .... i'l fi I;-,' 'I' I._ 1::'1-1 ]'~: ........ I T ,-- ..,."" "" f'l... ]; I... T) & H H.S;F, C/._r"l:::l( ' ' , p:,.~'r,~ .... .......... · ~ . , -,nl--I..I. AI3~'"~'I Alncbn Inr ;,I n .,,h. IHtnrv nl ARCO Alaska, Inc.'~--.- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 13, 1985 Mr. C. V. Chatterton Commi s s i oner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2W-2 2W-3 2W-4 If you have any Sincerely, . Gruber Associate Engineer JG/tw GRU5/L18 Enclosures questions, please call me at 263-4944. RECEIVED 1 4 1985 Alask~ Oil & Gas Cm'~s. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany - STATE OF ALASKA ALASKA ~>~ AND GAS CONSERVATION CO"~,VllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well [~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-16 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21279 1280' 4. Location of Well atsurface FNL, 202' FEL, Sec.33, T12N, R9E, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 95' RKB 6. Lease Designation and Serial No. ADL 25642 ALK 2573 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2W-2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0800 hrs, 02/08/85. Drld 12-1/4" to 3140'. Ran, cmtd & tstd 9-5/'8" csg. Drld 8-1/2" hole to 6949'TD as of 2/12/85. Ran OHL. Ran, cmtd, & tstd 7" csg. PBTD = 6812'. Secured well and RR as of 0500 hfs, 2/14/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 89'. Cmtd w/248 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS @ 3119'. Cmtd w/780 sx AS Ill & 410 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/FS @ 6890'. Cmtd w/280 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/Cal/SP/GR f/6944' - 3118' FDC/CNL f/6944' - 6200' & f/3750' - 3600' RFT (depth to be submitted with Completion Report) 16. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska Oil & Gas Cons. 17. ~ hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /~ /'~' ~ ~ _,~,c~,~ ~ TITLE Associate Engineer DATE ~-/~-~s' /I NOTE--Repor~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~,04 JMM/MR69 Submit in duplicate M EMORANTOUM TO: THRU: FROM: Stateof Alaska. ALASKA OIL AND GAS CONSERVATION COP-R~ISSION Lonnie C. Smith ~o'~ Commissioner Bobby Foster ,.~. ~ Petroleum Inspector DATE: FILE NO: TELEPHONE NO: February 11, 1985 D.BDF. 11 SU BJ ECT: Witness BOPE Test on ARCO' s 2W- 2, Sec. 33, T12N,R9E,UM, Permit No. 85-16. Saturday, February 9, 1985: The BOPE test began at 6:30 pm and was ConclUded at 8:00 pm. As the attached BOPE test report shows there were two failures, both of which will be repaired and tested. In summary, I witnessed the BOPE test on ARCO's 2W-2. Attachment Attachment 02-001AfRev. '10179) · _ -,',_~-.,~-.:~-'~,~:,:~ ~-~.?~.~-z~ . ,~ ~=~_~ ~' ->C> :' '~'-'<-~ ~.~ t._~~ ' --'-':-~:~ ~:~ _' ~ . ~} . ~ - . .- ~ - - '--'~.~- - :_ '?: -:-9~' - .'L?":.:~:-~::.:.~::~:.(.::: '-~:~:~:.:: ::'.:' : ".:-i-.'-~'--~S~: 0IL'~& GAS:CONSERVATION- C0~ISSION'~-:. ' o _ ..' -. --. -'4 ;perator.' '~~ ' ' "-'~' '" 1'_- '' Representative Location: Sec :: T~R¢~ M f./ :~ Casing Set~ ~2{~ Drilling Contractor -Ri Representative&~~,7 LoeatSon, General~~ell ' ' .... ~" ~CC~ATOR 8YST~ . *eneral Housekee~~RSg Full Charge ~r,ssure ~ }~ O Reserve Pit ~~ . Pressure ~ter' Closure' /f~ psig Mud Systems Visual Audio Pump incr. clos. pres. 200 psig .::-,min % . . Trip Tank w Full Charge Pressure Attained: ~n --sac. ~ft Gauge ~ ~2 ps~g Flow Monitor ~ Controls: Master ~ ~ ~ o~s ~t~tor~ ~mot~~ ~a~ s~h cow~~~. Kell7 and ~loor Sa~et7 Valves BOPE Stack Test ~ressure ~pper Kelly~ /. Test ~ressure Choke LSne Valves / ~~ Choke HanSfold ~~Test ~ressur~~ ~.c.~. v~ / ~~ ~o. v~ Check Valve ~~ Adjustable Chokes / HvdrauScall7 operated choke ~est Results: Failures ~ Test ~e f ~ hrs. Repair or Replacement of faSled equSpment to be made ~th~n ~ days and Inspector~ Co~ssSon offSce notSfSed. Distribution orig. - A0&GCC cc - Operator cc - Supervisor January 28, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2W-2 ARCO Alaska, Inc. Permit No. 85-16 Sur. Loc. 1280'F~U~, 202'FEL, Sec. 33, T12~, R9E, UM. Btmho!e Loc. 751'FSL, 1934'FWL, Sec. 34, T12N, R9E, UM. Dear ~r. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core aped a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their ~drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~in I~,uparuk River Unit -2- ~-- January 28, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may -witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ] · i ~; i~ C. V. ChaE~terton~'' Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o eric!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bb'z-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 21, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2W-2 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2W-2, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore .. A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 8, 1985. If you have any questions, please call me at 263-4970. S ~.cle r e 1 y, JBK/TEM/tw PD/L24 Attachments RECEIVED JAN 2 1985 'Naska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO'rwlVIISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I--1 SINGLE ZONE [] RECEIVE 2. Name of operator ARCO Alaska, Inc. JAN 2 ~ !985 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 AlasKa u~ 9. unit or lease name , ~ulch0rag~. Kuparuk River Unit . 4. Location of well at surface 1280' FNL, 202' FEL, Sec.33, T12N, RgE, UM (Approx.) At top of proposed producing interval 850' FNL, 1535' FWL, Sec.34, T12N, RgE, UM At total depth 751' FNL, 1934' FWL, Sec.34, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 95', PAD 65' I ADL 25642 ALK 2573 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 7059' MD, 6202' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3300 feet. 21 14. Distance to nearest property or lease line miles 202' @ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o [ (see 20 AAC 25.035 (c) (2) Proposed CaSing, Liner and Cementing Program 10. Well number 2W-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 I15. Distance to nearest drilling or completed 2W-1 well 60' @ surface feet 18. Approximate spud date 02108185 27'~c, psig@ 80OF Surface 3130 psig@ 6065 ft. TD (TVD) QUANTITY OF CEMENT SIZE CASING AND LINER SETTING DEPTH Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 2-1/4" 9-5/8" 36.0# J-55 I BTC 3111' 29' I I 29' 3140'I 3140' 780 sx AS Ill & HF-ERW I ~ I 410 sx Class G 8-1/2" 7" 26.0# J-55 / BTC 6274' 28' I I 28' 7059'l 6202' 260 sx Class G blend I 22 Describe HF-ERW ~ I . proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7059' MD (6202' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3140' MD(3140' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2735 psi, Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 2-7/8", 6.7#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby cer,~that the foregoing is true and correct to the best of my knowledge ? / SIGNED TITLE Area Drilling Engineer The space ,~w fo~7_~sio~use"-- CONDITIONS OF APPROVAL DATE Samples required []YES J~NO Permit number APPROVED BY Form 10-401 (T£M) PD/PD25 Mud Icg required []YES [~NO Approval date Directional Survey required APl number [~YES I--INO 50-- 0't,-~ ._"L,/'t.,'7 ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Januazry 28, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2W-2 installed and tested upon completion of the job. 2W-2 will be 60' away from 2W-1 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5492'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JAN 2 Alaska Oil & Gas Cons. Cornmissiort , Anchorage :"-:'1280; .FNLJ :202'. FELL t . { Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & 0Deration 1. Upon initial installation close annular preventer and verify ~hat 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 override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JAN 2 Alaska Oit & Gas Cons, Commissioa . ~chorage RECEIVED JAN 2 5 1985 Alaska Oil & Gas Cons. Commission -.. Anchorage 7 6 5 4 2 ~ DIAGRAM #1 13-5/8' 5CX:X) PSI RSRRA BOP STACK ACO, M,JLATOR CAPACITY TEST I. Q-/~ /V~ FILL ACCUM.LAT(:R RESEAWOIR TO PROPER LE/EL WITH HYDEAU_IC FLUID. 2. ASSURE THAT ACCLI~I. ATCR PI~:SStJI~ IS E~X30 PSI WITH 1500 PSI EO/t~TREAM CF TFE REGI.LATOR. 3. C:8SE~ TIKE_, TI-EN CLOSE ALL UNITS SIM,1TN~EOJEIY /tJ~D RECORD TFE TIldE ~ PRESStI:~ REI~I~INING AFTER Nd. LI~TS ARE CLOSED WITH Q-tNi~ING PUM:> CFF. 4. REC(~RD ON NADC REPORT, TIE ACCEI:~ABLE LOI~E~ LIMIT IS 45 SE~ CLOSIN~ TIldE ~ 1200 PSI REI~IINING 13-5/8" .BOP STACK TEST I. FILL BCP STACK AN:) Q..O(E MN~FQ..D WI'TH ARCTIC DIESEL. 2. Q..EC:K THAT ALL LOCK ~ SCRE~ IN N~.LkF_AD ARE FU. LY RETRACTE. D. SEAT TEST PLUG IN ~ELL~E/~D WITH RIJ~II~ JT AM) RUN IN L(X]([:[:)I~ SCRE~ 5. Q.O_RE__ ~ ~NTER AI~ ~ KILL N~ C:HI:](E L:II~ VALVES ADJACENT TO ~ STACK. ALL OTI-E'R VALVES AI~ ~ SHOJ.D BE OPEN. 4. PRE~ UP TO 250 PSI ~ HClD FOR I0 MIN. IN- ~ PRESSIRE TO 3003 PSI AM) HQ.D F(:R I0 MIN. ~:~ m:'O PRE~_~ TO 0 PSI. 5. ~ ~ ~NTER AAD ~ KILL AN:) CHCKE LIllE VALVES. CL. OSE: TOP PIPE RAM~ AN)I..ICR VALVES ON KILL ~ CHOKE LIltS. 6. TEST TO 250 PSI A/~D ~ PSI AS IN STEP 4. 7. CO~I~ TESTII~ ALL VALVES, LIKES,, /~ (]..13(ES ~TH A 250 PSI LOW AI~ 3000 PSI HIQ-I. TEST AS IN STEP 4. 130 NDT PRE~ TE~-"r ANY O-ICI<E TI~T I~ M3'T A FULL CLOSING POSITIVE SEAL Q-ICKE. OI~LY FLIMgTII3~I TES'T C]4~ES THAT DO M3-1' FULLY CLOI~. 8. (]::EN TOP PIPE RAM~ AN:) CL~ BOTTOM PIPE RA.~. TEST BOTTCM PIPE RA~ TO 250 PSI ~ 5000 PSI. I0. CLOSE BLIN:) ~ AhD TEST TO 250 PSI ~ 50C0 PSI. II. CPEN BI..II~ ~ AM:) RETRIEVE TEST PLUC~ ~ SURE I~N~IIFCLD AN:) LII~,S ARE FLU. CF NON-FREEZING FLUID. SET ALL VALVES IN I~ILL:ING POSITIC~ :2. TEST ST~I~IPE VALVES, ~'~Y, KELLY CCX](S, [::RILL PIPE SAFETY VALVE, AN:) II~II::E B~ TO 250 PSI A/~ ~ PSI. 15, RECCl;D TEST II~F~TION ON BL~ PREVENT~ TEST FORM, SIGN, N~ ~ TO I:::RILLING SIJ:~RVIS(]R. 14. PERF~ ~ BOPE TEST AFTER NIPPLING UP ~ VEEKLY T1-EREAFTER FI,JNCTI~Y OPERATE BCPE DAILY. 510(04001 I~V I LO'~ and ('13' 'thru (:22 thru{ 26~ (6) Add: :i1,~.. to :a ined o1-,;., .:~,~-...-..-, .. ....... . ....... loca~'~d :P~..o'~'~' ~iStaace from pr0pae~Y tine.'-' ' " ...... ': ...... ge available'in .thiSPool ' ".":" -':: ..- ~ i .t~(::~iy: aff'aeted party .... ..' .... '.' ' ' ,' ~L,- -~ . . · · . . · . . . . , ': D'6e~,. oVeraror'h'AVe?:.a' ~o~a' ~- for~e . . ~ ..... ~ .. 11. I;'"' a'd~ni~trative 'approval nee3ea . [. ' . I~ the:lease n~b~r appr6priate ' · . · . . . . 12. .. . ............... ................. 13. L5. 16. 17. 18. 19. 20. 21. Is 9omductor string provided ...................................... Is'~n0~gh cement used to'circulate on conductor and surface ........ WilI ~c~ement. tie. %n Surface and intermediate or production Strings ~ii'! cement, cover all known productive horizons ........ ~t'l~isurfa~e Casing Pr°tect fresh water z°nes"'~'~''~''' iiii~;;i;~'i ~, W$11 all.casing.give adequate safety in .cOllapse, tension' I~ this, Wel~ t°.be kicked off from an existing ~ellbore ...... ~ .... . .. Is 01d wellbore aSa~donment procedure included on 10-40~,...:? .......... i~ adequate wellbore Separation proposed'' - . ..el.el.e.l.em.e.ee. : 22. 23' 24. 25. 26. 27. i di~erter' ' SyStem' required ' ' ' S a . ..e.e.~.......®.....®-®....-..--.---.--- Are.necesS~ry.}.~iagrams of diverter and BOP equipment' attached ....... Does BOPE have-sufficient pressure rating -.Test tO ,~tr2)~ psig .. ~//.~ ,, Does'the choke manifold comply w/API RP-53 (Feb.78) .................. he pr ~"H2S Is t es.rice o gas probable ................................. · Additional ':' ' requirements · A/o'l- :r'oSRl I77fb Additionai .RemarkS: '0 ·. Geology:~E~ngineering: H~~. Lcs' ~~Ew rev: 10/29/84 6. C~T ,. PoO~: . INITIAL "'CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. o. ,") q 0 0 0 0 0 a 4. On3 u6b 065 0.~2 7492 IPH'i ~ ,,4 r"~ ! p t..~ .[ ~P ~ p FI I 6. 49 ','.. :) <i 9 ) ,~ F' ":,., d ? ,,. 4 u '¢ ~ ,r>:{ l.I 9 0. f", ()4, ? ~'~ i,,¢ A i' 3, ? 324 t 63.. ~'759 3 , c~ '!. 73 ! t'! ,, R t 25 57 ~.. 0 o 0 ! 02. 625{) 3-15.500 3.0 a 40 18, :1 7 ] 9 2 · '.,q 437 1, l P, 000 ,,.i 2, ~d&7 3.75(~r) 1 j 0.6'2~'; () 3. ~ 4 2 '2 -q9e' . ? ':.) 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C A I,. ,,[ CA L i P!iPA C A f, I l': b ~,r T · " 0 19~,3 -999. 2500 6 9 3 4: 2500 2.621 1, -q99,2500 2,6523 9,1.4R4 -q9g.2500 2.6094 9.390~ ~94b e , . - <) v 9 · 250 () 2.6250 9. -~9~. 250() 2.670'! 0.4,76b -999.7500 2.~lOb 9.~.6Ro 2.67 r~ 6, q. 2 1 09 `.'2. 'l 73 b -~99. 250u ;P ~P ~P ~! p ~-~ [ 3E~17' ~p nE:r~T S P RnPt~ ,,.,T p H i. '"' 0 9 9, ?, b t} t:,, P, R T..! t 1'-~, 2bO0 C 1 ~ ,t 3. n 0 n 0 F" C >,i 4,4 :,,~, 1,. 4 "[ i,: :'''~' I.. 't. 1.. 0 6 2 5 C R :1, 7 'c, 4,, 0 () 0 (',) r~"C :! ,u 3, S '1 ..1, 2 T ,.. q 9 a., ? '3 r~, 0l,v C' ',": b 2. '76 o 5 I b ~': -, q 9 q. 2500 !~, i{ ~\ - a 9 9, '2 5 a ,,) ~ (.'. ;':i 'i. ~ 5g. a 5 ¢,, 3 - ~ 9 q. ? 5 (: u ',' ?, .'~ 'i' -o9~. ?bp(.; ~" C ~'~ l,, 't o '2 4 -~90r , 2500 .].5859 4.6875 3945 7500 3, I 995 -n99, ?500 -~99. ?$00 2.92 07 ~P,. -ogq. 4.6, 5 2,3 - 0 9 q, 2 50 -'~gq. ! 27. 1250 57. -c, 99. ?500 -ogq.2bO0 CAT,.',[ P i~'i P A 'r I, C: .A T, I ,C A T, i. o N R t~ T L,*i :! 397 9824 4.60°4 9.6172 9. ~.359 -q99,2bO0 3. 2051 1, 0,0547 .-,999. 2500 :2,R164 10,4760 -990. 250(..~ 4, ~.~a7 9. 0844 -999'250U 4 ,'~ 0 9 '~ 8 R, 929'7 -q99,9,500 2OOO. 000(: g.92°7