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184-043
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7820'feet None feet true vertical 6463'feet 7259', 7478'feet Effective Depth measured 7109'feet 6691', 7091'feet true vertical 5875'feet 5522', 5860'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" L-80 J-55 6744' 7124' 5566' 5887' Packers and SSSV (type, measured and true vertical depth)6691' 7091 5522' 5860' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3324'2844' Burst Collapse 7722' Casing 6408'7751' 3295' 110'Conductor Surface Tie-Back String 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-043 50-029-21097-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025657 Kuparuk River Field/ Kuparuk Oil Pool KRU 2F-12 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 110' Well Shut-In 325-461 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: SLB BluePack Max Packer: Baker FHL Retrievable SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102 RWO/CTD Engineer 6805-6807', 7218-7232', 7248-7288' 5618-5619', 5967-5978', 5992-6025' Fra O s 6. A PG , g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:37 pm, Oct 06, 2025 Digitally signed by James J. Ohlinger DN: CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2025.10.06 13:06:07-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger RBDMS JSB 100925 J.Lau 11/7/25 Page 1/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/30/2025 06:00 8/30/2025 08:30 2.50 MIRU, MOVE MOB P MIRU Sub and pits. Complete preacceptance checklist. Raise derrick and pin. Preform bridal down checklist. 0.0 0.0 8/30/2025 08:30 8/30/2025 10:00 1.50 MIRU, MOVE RURD P Burn around rim. Hook up interconnect.Rig up to cirrculate. 0.0 0.0 8/30/2025 10:00 8/30/2025 15:00 5.00 MIRU, MOVE RURD P Rig accepted at 10:00. Hook up tiger tank and hardlines. Initial pressures T/IA/OA = 50/50/140psi Take 8.5 Brine into pits. Spot cutting box. Start processing 225 joints of 3.5" HT 38 DP. Make up a 20 BBL deep clean pill. 0.0 0.0 8/30/2025 15:00 8/30/2025 16:15 1.25 MIRU, WELCTL KLWL P Circulate 20 bbls deep clean pill at 5 BPM @ 900 psi followed by 335 bbls 8.5ppg Brine. (150% wellbore volume). One for one returns to tiger tank. Upped the rate to 6 bpm @ 1270 psi. On High line power at 16:15 0.0 0.0 8/30/2025 16:15 8/30/2025 17:00 0.75 MIRU, WELCTL OWFF P Flow check well. OA open and monitored. monitored T and IA for 30 minutes no flow. 0.0 0.0 8/30/2025 17:00 8/30/2025 20:00 3.00 MIRU, WHDBOP NUND P ND tree and adapter, function test all LDS. Clean and inspect tubing hanger lift threads, install blanking plug 10 rotations. NU X-O spool and DSA to BOP's set riser. 0.0 0.0 8/30/2025 20:00 8/30/2025 22:00 2.00 MIRU, WHDBOP RURD P RU to test BOP's take fresh water on rig. Purge air out of system start to fill stack to perform shell test. Fluid observed coming out of IA. 0.0 0.0 8/30/2025 22:00 8/31/2025 00:00 2.00 MIRU, WHDBOP RURD T Checked torque on LDS, torque good increased to 500 Ft/Lbs. attempted to seal possible leak by tubing hanger. IA still leaking by. PU blanking plug R&R tool. Pulled blanking plug, inspected plug and reset plug. Refilled stack no leak at IA. Attempt shell test to 250/3000. IA observed leaking by blanking plug. Pull blanking plug and replace with like kind. RIH torque up blanking plug Fill stack pressure up to 250/3000 PSI IA started leaking by blanking plug. Split stack at spool to tubing head. 0.0 0.0 8/31/2025 00:00 8/31/2025 00:45 0.75 MIRU, WHDBOP NUND T ND BOP's remove Blanking plug apply high sealability thread tape and thread sealant to blanking plug. install blanking plug in hanger neck. NU BOP' 0.0 0.0 8/31/2025 00:45 8/31/2025 01:00 0.25 MIRU, WHDBOP RURD P Shell test to 250/3000PSI. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Page 2/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/31/2025 01:00 8/31/2025 07:00 6.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1600 PSI, 200 PSI attained =16 sec, full recovery attained = 120 sec. UVBR's= 6 sec, Annular= 22 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Kam StJohn 0.0 0.0 8/31/2025 07:00 8/31/2025 07:45 0.75 MIRU, WHDBOP RURD P LD test tool and BD test equipment. Pull blanking plug and suck out stack. 0.0 0.0 8/31/2025 07:45 8/31/2025 08:15 0.50 COMPZN, RPCOMP RURD P Pull BPV and RU Spooling unit on rig floor. 0.0 0.0 8/31/2025 08:15 8/31/2025 09:30 1.25 COMPZN, RPCOMP THGR P MU landing joint, set down 10K and BOLDS, Unseat hanger at 50K. Pull up to 144K and tubing not free. Stage up to 158K and still not free. Re land hanger and MU FOSV. 0.0 0.0 8/31/2025 09:30 8/31/2025 14:30 5.00 COMPZN, RPCOMP WAIT T Processing 3.5" EUE tubing, while waiting on Welltec cutter to cut tubing. 0.0 0.0 8/31/2025 14:30 8/31/2025 16:30 2.00 COMPZN, RPCOMP ELNE T RU Yellow Jacket E-line and WellTec Cutter. 0.0 0.0 8/31/2025 16:30 8/31/2025 19:30 3.00 COMPZN, RPCOMP ELNE T Correlate and cut tubing with Welltec cutter at 6515'. POOH W/Eline. 0.0 8/31/2025 19:30 8/31/2025 20:30 1.00 COMPZN, RPCOMP PULL T Attempt to pull tubing from cut at 6515' PUW=144K 7' of stretch in tubing. unable to move tubing. Called town engineer to discuss plan forward. 8/31/2025 20:30 8/31/2025 23:00 2.50 COMPZN, RPCOMP WAIT T Wait for CBL from Deadhorse. 8/31/2025 23:00 9/1/2025 00:00 1.00 COMPZN, RPCOMP ELNE T MU E-line CBL RIH W/eline start loggging intial pass F/6500' 9/1/2025 00:00 9/1/2025 07:00 7.00 COMPZN, RPCOMP ELNE T Log CBL F/6500' to 4000' sent log in for processing. POOH W/ E-line to surface set up tools to make second cut with Weltec. 0.0 0.0 9/1/2025 07:00 9/1/2025 10:00 3.00 COMPZN, RPCOMP ELNE T Decision made to cut tubing in the middle of the joint just below the GLM. Welltec cut at 5885'. RIH, correlate to GLM at 5861' and cut at 5885'. We now have three Welltrec cuts at 6740', 6515' and 5885'. Stand back E-line while verifing tubing will pull free. 0.0 0.0 9/1/2025 10:00 9/1/2025 10:15 0.25 COMPZN, RPCOMP THGR T Pull hanger to floor. 5,885.0 5,814.0 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Page 3/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/1/2025 10:15 9/1/2025 10:45 0.50 COMPZN, RPCOMP ELNE T RD E-line. 5,814.0 5,814.0 9/1/2025 10:45 9/1/2025 13:45 3.00 COMPZN, RPCOMP PULL P POOH with completion PUW=90K weight broke back to 62K PUW = 62K/ SOW 57K F/surface T/2168'. Recovered 33 SS bands. LD spooling unit. 5,814.0 3,717.0 9/1/2025 13:45 9/1/2025 14:15 0.50 COMPZN, RPCOMP MPSP P MU BHA #1 Storm packer with 30K tubing wt below it. Storm packer set at 103.6' COE PT to 1000 psi for 10 minutes, Good test. 3,717.0 3,800.0 9/1/2025 14:15 9/1/2025 16:00 1.75 COMPZN, RPCOMP NUND P ND BOP stack, pull riser, rack back stack on pedestal and secure. 3,800.0 3,800.0 9/1/2025 16:00 9/1/2025 20:00 4.00 COMPZN, RPCOMP NUND P ND and remove tubing head and pack off. Casing grew 13.5" 3,800.0 9/1/2025 20:00 9/1/2025 22:30 2.50 COMPZN, RPCOMP CUTP P RU wachs saw and cut casing. 9/1/2025 22:30 9/2/2025 00:00 1.50 COMPZN, RPCOMP NUND P NU tubing head to casing head. Tested packoff to 3000 PSI for 15 minutes. 9/2/2025 00:00 9/2/2025 00:45 0.75 COMPZN, RPCOMP NUND P Set test plug in tubing head and NU BOPs 0.0 0.0 9/2/2025 00:45 9/2/2025 04:45 4.00 COMPZN, RPCOMP RURD P RU testing equipment. Fill surface lines and BOP stack Purge system of all air. Perform shell test to 250/4000 PSI. BOP test witness notification not made in time for operation to continue per Sundry requirements. Waiting on response from AOGCC. Notification made at 0144AM to state of Alaska. 0.0 0.0 9/2/2025 04:45 9/2/2025 05:15 0.50 COMPZN, RPCOMP SVRG P Perform rig service 0.0 0.0 9/2/2025 05:15 9/2/2025 14:00 8.75 COMPZN, RPCOMP RURD P Tally and load tubing in pipe shed. 0.0 0.0 9/2/2025 14:00 9/2/2025 17:30 3.50 COMPZN, RPCOMP RURD P Build out DP stands. 0.0 0.0 9/2/2025 17:30 9/2/2025 18:00 0.50 COMPZN, RPCOMP SVRG P Service crown IRN, tongs and draw works. 0.0 9/2/2025 18:00 9/2/2025 20:30 2.50 COMPZN, RPCOMP RURD P Build out DP stands. 9/2/2025 20:30 9/2/2025 22:00 1.50 COMPZN, RPCOMP RURD P Pull wear ring RU testing equipment. Fill surface lines and BOP stack Purge system of all air. Perform shell test to 250/4000 PSI. 0.0 0.0 9/2/2025 22:00 9/3/2025 00:00 2.00 COMPZN, RPCOMP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Page 4/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/3/2025 00:00 9/3/2025 09:30 9.50 COMPZN, RPCOMP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3100 PSI, after closure=1550 PSI, 200 PSI attained =17 sec, full recovery attained = 127 sec. UVBR's= 5 sec, Annular= 27 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2100 PSI. Test gas detectors, PVT and flow show. Test Witnessed Guy Cook 0.0 0.0 9/3/2025 09:30 9/3/2025 10:30 1.00 COMPZN, RPCOMP RURD P RD from testing suck out stack, pull test plug set wear ring. RD from testing RU to Pull storm packer 0.0 0.0 9/3/2025 10:30 9/3/2025 11:00 0.50 COMPZN, RPCOMP MPSP P Equalize and release storm packer 0.0 100.0 9/3/2025 11:00 9/3/2025 11:30 0.50 COMPZN, RPCOMP OWFF P OWFF No flow 100.0 3,800.0 9/3/2025 11:30 9/3/2025 14:15 2.75 COMPZN, RPCOMP PULL P LD storm packer and storm valve LD tubing F/3800' TO surface PUW=62K 3,800.0 0.0 9/3/2025 14:15 9/3/2025 14:45 0.50 COMPZN, RPCOMP RURD P Change out elevators RU to PU BHA 0.0 0.0 9/3/2025 14:45 9/3/2025 15:45 1.00 COMPZN, RPCOMP BHAH P MU BHA #2 Overshot plain control no packoff 0.0 224.3 9/3/2025 15:45 9/3/2025 19:00 3.25 COMPZN, RPCOMP TRIP P P/U 1600' singles out of pipe shed, TIH on stands to top of fish at 5882' 224.3 5,882.0 9/3/2025 19:00 9/3/2025 19:45 0.75 COMPZN, RPCOMP FISH P Pu wt. 125k Dn wt. 90k // Engage fish @ 5885', Pull 50 k over bleed jars, Jar twice @ 100K over, straight pull 125K over fish moving 5,882.0 6,740.0 9/3/2025 19:45 9/3/2025 22:15 2.50 COMPZN, RPCOMP TRIP P OWFF, TOOH w/ fish 6,740.0 1,220.0 9/3/2025 22:15 9/3/2025 23:30 1.25 COMPZN, RPCOMP BHAH P Rack collars lay down BHA insect top of fish 1,220.0 1,000.0 9/3/2025 23:30 9/4/2025 00:00 0.50 COMPZN, RPCOMP PULL P Lay down tubing from cut @ 6515' 1,000.0 300.0 9/4/2025 00:00 9/4/2025 01:00 1.00 COMPZN, RPCOMP PULL P Lay down tubing from cut @ 6515' // Cut jts 10.88' & 14.51' 300.0 0.0 9/4/2025 01:00 9/4/2025 02:00 1.00 COMPZN, RPCOMP BHAH P Make up BHA# 3 clean out BHA // 6-1/8" Tri-cone w/ scraper 0.0 219.0 9/4/2025 02:00 9/4/2025 04:15 2.25 COMPZN, RPCOMP TRIP P TIH tag at 6430' set down 10K WOB work down to 6503' 219.0 6,503.0 9/4/2025 04:15 9/4/2025 06:30 2.25 COMPZN, RPCOMP CIRC P Circ sweep SxS 3 BPM 1300 PSI blow down top drive and surface lines. 6,503.0 6,503.0 9/4/2025 06:30 9/4/2025 08:45 2.25 COMPZN, RPCOMP TRIP P TOOH F/6503 T/219.78 PUW=132K 6,503.0 219.8 9/4/2025 08:45 9/4/2025 10:00 1.25 COMPZN, RPCOMP BHAH P LD BHA F/219' MU BHA #4 24' of 224 PU. 219.8 224.3 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Page 5/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/4/2025 10:00 9/4/2025 14:00 4.00 COMPZN, RPCOMP WAIT T Replace coolant in break system 224.3 224.3 9/4/2025 14:00 9/4/2025 14:30 0.50 COMPZN, RPCOMP BHAH P Finish PU BHA #4 224.3 224.3 9/4/2025 14:30 9/4/2025 17:15 2.75 COMPZN, RPCOMP TRIP P TIH w BHA# 4 fishing assembly to top of fish 6504 224.3 6,504.0 9/4/2025 17:15 9/4/2025 17:45 0.50 COMPZN, RPCOMP FISH P Jar on fish 10 times 100K , straight pull 150 over fish moving up hole 6,504.0 6,450.0 9/4/2025 17:45 9/4/2025 18:45 1.00 COMPZN, RPCOMP CIRC P Circulate SxS , OWFF no flow 6,450.0 6,450.0 9/4/2025 18:45 9/4/2025 21:30 2.75 COMPZN, RPCOMP TRIP P TOOH w/ BHA# 4 and fish 6,450.0 400.0 9/4/2025 21:30 9/4/2025 22:30 1.00 COMPZN, RPCOMP BHAH P Lay down fishing BHA 400.0 200.0 9/4/2025 22:30 9/4/2025 23:00 0.50 COMPZN, RPCOMP PULL P Lay down tubing 6 jts , Cut jts 20.67' and 19.02' 200.0 0.0 9/4/2025 23:00 9/5/2025 00:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 5 clean out bha dress off shoe with string mill 0.0 223.0 9/5/2025 00:00 9/5/2025 03:00 3.00 COMPZN, RPCOMP TRIP P TIH w cleanout/dress off Bha # 5 223.0 6,500.0 9/5/2025 03:00 9/5/2025 05:00 2.00 COMPZN, RPCOMP WASH P Wash in hole cleaning casing to top of stump @ 6728' (7es RKB) PUW=135K SOW=100K Establish milling parmeters PR=3 bpm @ 320 psi Rot 55 rpm Tq off= 3200 ft/lbs Pump pressure increased to 380 at 6728 Tq on 4200 Wash down to 6735' (7ES RKB) PR=3 BPM 600 PSI on. Rotated off PU clean RIH tag at TOF 6728' Bottom of shoe at 6735' 6,500.0 6,735.0 9/5/2025 05:00 9/5/2025 06:30 1.50 COMPZN, RPCOMP CIRC P Circulate sweep 5 BPM 600 PSI while reciprocating DP 100' rot at 50 RPM Chase OOH Sand in returns 6,735.0 6,735.0 9/5/2025 06:30 9/5/2025 07:45 1.25 COMPZN, RPCOMP PRTS P LD 1 stand of DP. RU to test casing. Pressure test 7" intermediate casing to 2500 PSI for 30 minutes. rig down from testing and blow down top drive and surface lines. 6,735.0 6,650.0 9/5/2025 07:45 9/5/2025 12:00 4.25 COMPZN, RPCOMP PULD P POOH sideways F/6650' 7ES RKB to 223' 6,650.0 223.0 9/5/2025 12:00 9/5/2025 13:00 1.00 COMPZN, RPCOMP BHAH P LD BHA and handling equipmetn for DP. 223.0 0.0 9/5/2025 13:00 9/5/2025 14:15 1.25 COMPZN, RPCOMP RURD P RU floor to run tubing completion. Load completion components in the pipe shed. Verify runnig order and tally, 0.0 0.0 9/5/2025 14:15 9/5/2025 14:30 0.25 COMPZN, RPCOMP SFTY P Pre job safety meeting 0.0 0.0 9/5/2025 14:30 9/5/2025 23:15 8.75 COMPZN, RPCOMP PUTB P Start RIH with completion per tally. 0.0 6,730.0 9/5/2025 23:15 9/6/2025 00:00 0.75 COMPZN, RPCOMP HOSO P Work in hole on Jt 214, shear screws @ 6735.03 ( 7K ), continue in hole NG @ 6737.33' ( Nabors 7 RKB ) // Calculate space out, lay down jts 214,213, & 212, make up pup jts 4.22' & 4.23' under jt 212, 6,730.0 6,737.0 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Page 6/6 2F-12 Report Printed: 10/3/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/6/2025 00:00 9/6/2025 00:30 0.50 COMPZN, WHDBOP HOSO P Calculate space out, lay down jts 214,213, & 212, make up pup jts 4.22' & 4.23' under jt 212, make up hanger to top of 212 space out for CI 0.0 0.0 9/6/2025 00:30 9/6/2025 02:00 1.50 COMPZN, WHDBOP CIRC P Circulate in 260 bbls 8.5# CI Brine // 3 bpm @ 258 psi 6,737.0 6,730.0 9/6/2025 02:00 9/6/2025 03:00 1.00 COMPZN, WHDBOP THGR P Suck out stack // Land hanger // RILDS 6,730.0 6,735.0 9/6/2025 03:00 9/6/2025 04:30 1.50 COMPZN, WHDBOP PRTS P Drop ball and rod, rig up test equipment, set packer 3800 psi Test Tubing 3800 psi 30 min good test Bleed tubing pressure T/ 1500 psi PT IA 2500 psi 30 min good test Dump tubing shear SOV, pump 2 bbls ensure circulation Rig down test equipment, pull landing joint 6,735.0 0.0 9/6/2025 04:30 9/6/2025 05:30 1.00 COMPZN, WHDBOP MPSP P RD from testing, LD landing joint, Set BPV, test 1000 psi 5 min good test 0.0 0.0 9/6/2025 05:30 9/6/2025 06:00 0.50 COMPZN, WHDBOP SVRG P Service rig tongs 0.0 0.0 9/6/2025 06:00 9/6/2025 10:15 4.25 COMPZN, WHDBOP RURD P Perform BWM Off High Line at 10:00 0.0 9/6/2025 10:15 9/6/2025 12:00 1.75 COMPZN, WHDBOP NUND P Removed BOP's set test dart in H-Plug. Installed tree and adapter, pressure test hanger void 5000 psi 10 min. Rig up LRS, PT production tree 5000 psi, Pull BPV. 0.0 0.0 9/6/2025 12:00 9/6/2025 13:45 1.75 COMPZN, WHDBOP FRZP P LRS freeze protect well. pumped 75 bbls 2 BPM ICP=600 FCP=800 PSI. U-Tube for 1 hour. 0.0 0.0 9/6/2025 13:45 9/6/2025 15:30 1.75 COMPZN, WHDBOP RURD P RD U-tube and hard line to kill tanks. 0.0 0.0 9/6/2025 15:30 9/6/2025 18:30 3.00 DEMOB, MOVE MOB P RU bridle lines lay over derrick. RD interconnect PU berming from around rig. Prepare to move to 1H-107. 0.0 0.0 9/6/2025 18:30 9/7/2025 00:00 5.50 DEMOB, MOVE WAIT P Perform misc maintenance and prep for move while waiting for rig mats to be set 0.0 0.0 9/7/2025 00:00 9/7/2025 06:00 6.00 DEMOB, MOVE WAIT P Perform misc maintenance and prep for move while waiting for rig mats to be set, trucks on location 05:00, pull pits away move off well Rig Released 06:00 on 9/7/25 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/7/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,259.0 2F-12 4/3/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO - Pull CA2 Plug 2F-12 9/17/2025 rmoore22 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 29.0 3,323.9 2,843.7 36.00 J-55 BTC PRODUCTION 7 6.28 28.7 7,751.2 6,407.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 6,744.0 String Max No… 3 1/2 Set Depth … 5,566.2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.7 23.7 0.04 Hanger 6.980 FMC hanger GEN 4 FMC FMC Gen 4 2.920 2,948.5 2,556.4 40.42 Mandrel – GAS LIFT 5.760 3-1/2" x 1-1/2" MMG SLB MMG 2.920 4,991.1 4,137.3 36.70 Mandrel – GAS LIFT 5.904 3-1/2" x 1-1/2" MMG SLB MMG 2.920 6,631.7 5,472.2 33.53 Mandrel – GAS LIFT 5.930 3-1/2" x 1-1/2" MMG SLB MMG 2.920 6,691.3 5,522.0 33.13 Packer 5.994 3-1/2" x 7" BluePack Max SLB BluePac k 2.885 6,717.4 5,543.9 33.01 Nipple - X 4.479 2.813" X-Nipple HES X-Nipple 2.813 6,739.3 5,562.2 32.93 Overshot 6.000 NS Poor boy overshot Shear pins 3.58' from bottom (spaced out 1' off tag ) Northern Solution s Poor Boy overshot 3.630 Top (ftKB) 6,740.0 Set Depth … 7,123.5 String Max No… 3 1/2 Set Depth … 5,887.4 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd 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) 7,035.7 5,813.0 31.73 GAS LIFT 5.312 MMH FMHO MMH FMHO 2.875 7,077.7 5,848.7 31.99 PBR 5.000 BAKER PBR BAKER 3.000 7,091.4 5,860.3 32.07 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER BAKER FHL 3.000 7,108.5 5,874.8 32.23 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,122.4 5,886.5 32.40 TTL 3.500 VANN GUN TUBING RELEASE 1.810 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) 7,074.5 5,846.0 31.97 HOLES IN TBG SHOT 2" X 2" TBG PUNCH (4spf 0° phase) from 7074.5- 7076.5' 12/13/2018 0.000 7,082.0 5,852.3 32.01 HOLES IN TBG SHOT 2" X 2" TBG PUNCH (4spf 0° phase) from 7082'- 7084' 12/13/2018 0.000 7,259.0 6,001.0 33.11 FISH 1" W x 4" L piece of broken JD skirt. Drifted tubing, appears to be at bottom of well. 4/3/2025 0.000 7,478.0 6,184.3 33.78 FISH VANN GUN 181.55' Vann Gun 4/26/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,948.5 2,556.4 40.42 1 DMY RK 1 1/2 9/6/2025 SLB 4,991.1 4,137.3 36.70 2 GLV RK 1 1/2 1,230.0 9/12/2025 SLB 0.250 6,631.7 5,472.2 33.53 3 OV RPK 1 1/2 9/11/2025 SLB 0.313 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,805.0 6,807.0 5,617.5 5,619.1 5/12/2019 4.0 CMT SQZ Tubing Punch 4spf, 0 Deg Phasing. 7,218.0 7,232.0 5,966.7 5,978.4 A-5, 2F-12 4/26/1984 12.0 IPERF Zero deg. Phasing; 5" Geo Vann Guns 7,248.0 7,288.0 5,991.8 6,025.3 A-4, 2F-12 4/26/1984 12.0 IPERF Zero deg. Phasing; 5" Geo Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 33.0 3,224.0 33.0 2,766.8 Primary – Full Bore Lead 318 bbl 12.2 ppg Arctic Set III + Tail 145 bbl 15.8 ppg Class G **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 33.0 75.0 33.0 75.0 Grouting / Top -Up Top Job 10 bbl Arctic Set I **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 6,350.0 7,751.0 5,239.3 6,407.4 Primary – Full Bore Single Stage 66 bbl 15.8 ppg Class G ^^Csg OD=7 6,811.0 7,050.0 5,622.5 5,825.2 Cement Squeeze Milled out 3/21/25 1/30/2019 2F-12, 10/3/2025 10:44:36 AM Vertical schematic (actual) PRODUCTION; 28.7-7,751.2 FISH; 7,478.0 IPERF; 7,248.0-7,288.0 FISH; 7,259.0 IPERF; 7,218.0-7,232.0 PACKER; 7,091.4 HOLES IN TBG; 7,082.0 HOLES IN TBG; 7,074.5 Primary – Full Bore; 6,350.0 ftKB GAS LIFT; 7,035.7 Cement Squeeze; 6,811.0 ftKB CMT SQZ; 6,805.0-6,807.0 Nipple - X; 6,717.4 Packer; 6,691.3 Mandrel – GAS LIFT; 6,631.7 Mandrel – GAS LIFT; 4,991.1 SURFACE; 29.0-3,323.9 Mandrel – GAS LIFT; 2,948.5 Primary – Full Bore; 33.0 ftKB CONDUCTOR; 30.0-110.0 Grouting / Top-Up; 33.0 ftKB Hanger; 23.7 KUP PROD KB-Grd (ft) 33.01 RR Date 4/19/1984 Other Elev… 2F-12 ... TD Act Btm (ftKB) 7,820.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292109700 Wellbore Status PROD Max Angle & MD Incl (°) 41.23 MD (ftKB) 2,200.00 WELLNAME WELLBORE2F-12 Annotation Last WO: End Date 9/7/2025 H2S (ppm) 110 Date 12/19/2017 Comment SSSV: LOCKED OUT Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,811.0 7,050.0 5,622.5 5,825.2 Cement Squeeze 1/30/2019 2F-12, 10/3/2025 10:44:36 AM Vertical schematic (actual) PRODUCTION; 28.7-7,751.2 FISH; 7,478.0 IPERF; 7,248.0-7,288.0 FISH; 7,259.0 IPERF; 7,218.0-7,232.0 PACKER; 7,091.4 HOLES IN TBG; 7,082.0 HOLES IN TBG; 7,074.5 Primary – Full Bore; 6,350.0 ftKB GAS LIFT; 7,035.7 Cement Squeeze; 6,811.0 ftKB CMT SQZ; 6,805.0-6,807.0 Nipple - X; 6,717.4 Packer; 6,691.3 Mandrel – GAS LIFT; 6,631.7 Mandrel – GAS LIFT; 4,991.1 SURFACE; 29.0-3,323.9 Mandrel – GAS LIFT; 2,948.5 Primary – Full Bore; 33.0 ftKB CONDUCTOR; 30.0-110.0 Grouting / Top-Up; 33.0 ftKB Hanger; 23.7 KUP PROD 2F-12 ... WELLNAME WELLBORE2F-12 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2F-12 JBR 10/22/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 BOP test per sundry after retro-fitting the wellhead from a 3K wellhead to a 5K wellhead. The HCR Choke failed and was serviced for a pass. The chart recorder was out of calibration and had been since 7/17/25 so we had to get another one from Deadhorse and then wait for charts for it from the toolhouse. The test joint came free of the test plug due to rolled threads on the test joint and came to the rig floor during testing. Luckily it didn't get passed the annular. Had to get another test plug from the toolhouse. Lots of waiting for issues to be resolved made for a long test. 3 1/2" test joint used for testing. Test Results TEST DATA Rig Rep:J. Hackworth/R. DornOperator:ConocoPhillips Alaska, Inc.Operator Rep:M. Adams/C. Erdman Rig Owner/Rig No.:Nabors 7ES PTD#:1840430 DATE:9/3/2025 Type Operation:WRKOV Annular: 250/4000Type Test:OTH Valves: 250/4000 Rams: 250/4000 Test Pressures:Inspection No:bopGDC250902061425 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12 MASP: 3714 Sundry No: 325-461 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5' VB P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5' VB P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 FP Kill Line Valves 2 3 1/8" and 2" P Check Valve 0 NA BOP Misc 2 2 1/16" 5000 P System Pressure P3100 Pressure After Closure P1500 200 PSI Attained P17 Full Pressure Attained P127 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2100 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P5 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7820'6463' 7109' 5875'3714 7109' 7259', 7478' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-1102 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 2F-12 6805-6807' 7218-7232' 7248-7288' 7722' 5618-5619' 5967-5978' 5992-6025' 9/18/2025 3-1/2" Baker FHL SSSV: BAKER FVL 3295' 7751' Perforation Depth MD (ft): 110' 3324' 6408'7" 16" 9.625" 80' Burst 7124' MD 110' 2844' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025657 184-043 P.O. Box 100360, Anchorage, AK 99510 50-029-21097-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7091'MD/5860'TVD 1962'MD/1811'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field James Ohlinger james.j.ohlinger@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:37 am, Aug 06, 2025 Digitally signed by James J. Ohlinger DN: CN=James J. Ohlinger, E=James.J.Ohlinger @cop.com Reason: I am the author of this document Location: Date: 2025.08.05 14:14:17-08'00' Foxit PDF Editor Version: 13.1.6 James J. Ohlinger 325-461 10-404 A.Dewhurst 26AUG25 DSR-8/14/25JJL 8/26/25 X AOGCC witnessed initial BOP and annular test to 3000 psi. AOGCC witnessed BOP test to 4000 psi after installing 5K wellhead. Follow attached "procedure for removing the THA" as mitigation against subsidence movement. JLC 8/27/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.27 09:12:54 -08'00' 08/27/25 RBDMS JSB 082725 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 4, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Staff CTD/RWO Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2F-12 (PTD# 184-043). Well 2F-12 was originally spud in 4/10/84 and rig released 4/19/84. The well has primarily been a Kuparuk A-sand Producer. The well has developed AnnComm issues; packer leak and TxIA packer leak that moved it to being a RWO candidate. There was an attempt to fix the packer leak with a cement plug. Post cement job CBL and pressure tests evaluated that the repair wasn't successful. If you have any questions or require any further information, please contact me at +1-907-229-3338. The tubing will be pulled down to the pre-rig tubing cut ~6740' MD. A plug will be placed in the 7" casing to establish a second mechanical barrier to modify the wellhead to a 5000 psi rating. The production casing does have a slow IAxOA leak to gas. A pressure test of the casing will be conducted combined with a drift run to evaluate if a subsidence like repair is required. A new 3.5" completion will be installed with stacked packer to recomplete the well. General Well info Wellhead type/pressure rating: FMC Gen II, 3K psi rated wellhead Production Engineer: Mandy Pogany Reservoir Development Engineer: Grace Knock Estimated Start Date: 09/18/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; 2/16/18 Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig tubing cut, ~6740’. Install new 3-1/2” tubing with a poor boy overshot and stack packer. The production casing does have a slow IAxOA leak to gas. A pressure test of the casing will be conducted combined with a drift run to evaluate if a subsidence like repair is required. The wellhead is rate 3000 psi, so the casing head tubing spool, tubing head adapter, master valve and IA valve will be replaced. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 4/24/25 3000 psi MIT-IA Failed 4/24/25 MIT-OA Passed 5/2/25 CMIT-IA Passed 4/16/25 IC-POT Passed 5/01/25 IC-PPPOT Failed – 5/01/25 TBG POT & PPPOT PASSED – 5/01/25 MPSP: 3714 psi using 0.1 psi/ft gradient Static BHP: 4301 psi / 5875’ TVD measured on 4/03/25 !"#$%&'( ) #*+ RWO engineer verified this MITIA did not occur - JJL ! ! " # $" % & ' ( ')* + '( , + " ( &!( -.! ) / 0 123+( 4.56 # 3& 78 ' & 9 - / &! ,#), $: 1."-,...( ) 1."-,... ( + ' ! '8 ' -...( ;-<( % 8 '= >(( ' ;&& & ><(1 <=((% & +<...($ & & ( ' ( &! " # $ % < , ? $@#; 1 -"2 (& A><.6 7% & ' (() ' > ; ( 2& ) &! #$:,&' ' &!( B / '/ ! 1...( = $:,<...($ &!( 5 ( %*"'(( % +,- .&( " % . -C2&!( '(/9' ,(& , D@ E '&!( $& ( ',&& 3 ,(& , ', @#;, (* , (& -...(-.! &' - 1..(-.! &' / 0 < 3!( , '' ;$ '( 1 > #$: ) ,F( & (( !, &/ = # $ *" 5 D@# . 3+( A.5 ) 9 ( *Follow attached "procedure for removing the THA" as mitigation against subsidence movement - JJL Detailed procedure for removing the THA. (subsidence mitigation) "When ND tubing head adapter flange, back off nuts from the adapter flange to ensure they can move. Tighten the nuts back up to make contact with the flange face but allow them to remain loose. Backoff and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Call RWO ENGR and swap well over to KWF before continue to ND. After ND is completed and BOP’s are installed the well can be swapped back to SW if mechanical barriers are in place and the well passes a 30 min no flow to SW. If no additional tightness is observed, continue ND as planned." 2F-12 Existing RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 H-40 WELDED Surface 3324 2844 9.625 8.92 36 J-55 BTC Production 7751 6408 7 6.28 26 J-55 BTC Tubing 7124 5888 3.5 2.992 9.3 J-55 EUE-rd Arctic Cement Diesel Pack BBLS BBLS 9/1/84 42 53 bbl/ft 0.0297 footage 1414 1785 Pressure test was a failure T-POT Pass 5/1/2025 T-PPPOT Pass 5/1/2025 IC-POT Pass 5/1/2025 IC-PPPOT Fail 5/1/2025 FT LDS/GNS Complete 5/1/2025 MIT-OA PASS 5/2/2025 MIT-IA Fail 4/24/2025 MIT-T Pass 4/24/2025 CMIT-IA Pass 2500 4/16/2025 - 1234 5 -/67 7 COMPLETION FMC Gen II 3000 psi wellhead 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface Baker FVL SSSV @ 1962' RKB (5.87" OD) 3-1/2" Camco MMG gas lift mandrels @ 2105', 4216', 5861', 7036' Baker PBR @ 7078' Baker FHL Packer @ 7091' RKB 3-½" Camco D-nipple at 7109' RKB (2.75" min ID) TTL 7122' RKB Surface Casing Production Casing Conductor A-sand perfs last tag 7263' (4/E 4"$>G (4(&"$"*G @ HI H0 # $J 4 483 4 42835 @ HI H0# $J 4 4 5 "$>G 5 80 "$)!G ;*!G 9( :;( ' " '* -'* % < '$ % 9& (0$ % < ''&" 0 !'*" '(# '%#'(# ' &* 977 -. E (/& !*$;G0!*$"G + -/6 -14 57273 !* >G;55> $ % -"124 5 3 =*$* % 2F-12 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 H-40 WELDED Surface 3324 2844 9.625 8.92 36 J-55 BTC Production 7751 6408 7 6.28 26 J-55 BTC Tubing 6740 3.5 2.992 9.3 L-80 EUEM Tubing 7124 5888 3.5 2.992 9.3 J-55 EUE-rd Arctic Cement Diesel Pack BBLS BBLS 9/1/84 42 53 bbl/ft 0.0297 footage 1414 1785 Pressure test was a failure 6665' RKB Proposed COMPLETION 3-1/2" 9.3# L-80 EUEM Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD 3.5"x7" Packer NIpple Profile PBOS ~6740' RKB COMPLETION 3-1/2" Camco MMG gas lift mandrels @ 7036' Baker PBR @ 7078' Baker FHL Packer @ 7091' RKB 3-½" Camco D-nipple at 7109' RKB (2.75" min ID) TTL 7122' RKB (1.81" ID) Surface Casing Production Casing Conductor A-sand perfs (4/E 4"$>G (4(&"$"*G @ HI H0 # $J 4 483 4 42835 @ HI H0 # $J 4 4 5 "$>G "$)!G $ % -"124 5 !#; G - 1234 5 -/67 7 ))*!G Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,259.0 2F-12 4/3/2025 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled OV, left open pocket, DMY off sta's #1 & 2 2F-12 4/23/2025 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 29.0 3,323.9 2,843.7 36.00 J-55 BTC PRODUCTION 7 6.28 28.7 7,751.2 6,407.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.7 Set Depth … 7,123.5 Set Depth … 5,887.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd 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) 23.7 23.7 0.04 HANGER 8.000 FMC GEN II TUBING HANGER 3.500 1,961.7 1,810.7 41.05 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 10/9/04) BAKER FVL 2.810 2,105.1 1,918.8 41.06 GAS LIFT 5.312 MMH FMHO MMH FMHO 2.875 4,215.6 3,526.7 39.03 GAS LIFT 5.312 MMH FMHO MMH FMHO 2.875 5,861.4 4,837.9 35.57 GAS LIFT 5.312 MMH FMHO MMH FMHO 2.875 7,035.7 5,813.0 31.73 GAS LIFT 5.312 MMH FMHO MMH FMHO 2.875 7,077.7 5,848.7 31.99 PBR 5.000 BAKER PBR BAKER 3.000 7,091.4 5,860.3 32.07 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER BAKER FHL 3.000 7,108.5 5,874.8 32.23 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,122.4 5,886.5 32.40 TTL 3.500 VANN GUN TUBING RELEASE 1.810 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) 7,074.5 5,846.0 31.97 HOLES IN TBG SHOT 2" X 2" TBG PUNCH (4spf 0° phase) from 7074.5- 7076.5' 12/13/2018 0.000 7,082.0 5,852.3 32.01 HOLES IN TBG SHOT 2" X 2" TBG PUNCH (4spf 0° phase) from 7082'- 7084' 12/13/2018 0.000 7,108.5 5,874.8 32.23 TUBING PLUG 2.75" CA-2 PLUG 4/16/2025 0.000 7,259.0 6,001.0 33.11 FISH 1" W x 4" L piece of broken JD skirt. Drifted tubing, appears to be at bottom of well. 4/3/2025 0.000 7,478.0 6,184.3 33.78 FISH VANN GUN 181.55' Vann Gun 4/26/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,105.1 1,918.8 41.06 1 GAS LIFT DMY BK 1 4/23/2025 4,215.6 3,526.7 39.03 2 GAS LIFT DMY BK 1 4/23/2025 5,861.4 4,837.9 35.57 3 GAS LIFT OPEN 1 4/22/2025 Open Pocke t 7,035.7 5,813.0 31.73 4 GAS LIFT DV Integr al Head 1 0.0 12/15/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,805.0 6,807.0 5,617.5 5,619.1 5/12/2019 4.0 CMT SQZ Tubing Punch 4spf, 0 Deg Phasing. 7,218.0 7,232.0 5,966.7 5,978.4 A-5, 2F-12 4/26/1984 12.0 IPERF Zero deg. Phasing; 5" Geo Vann Guns 7,248.0 7,288.0 5,991.8 6,025.3 A-4, 2F-12 4/26/1984 12.0 IPERF Zero deg. Phasing; 5" Geo Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,811.0 7,050.0 5,622.5 5,825.2 Cement Squeeze Milled out 3/21/25 1/30/2019 6,811.0 7,050.0 5,622.5 5,825.2 Cement Squeeze 1/30/2019 2F-12, 4/25/2025 5:01:30 PM Vertical schematic (actual) PRODUCTION; 28.7-7,751.2 FISH; 7,478.0 IPERF; 7,248.0-7,288.0 FISH; 7,259.0 IPERF; 7,218.0-7,232.0 TUBING PLUG; 7,108.5 PACKER; 7,091.4 HOLES IN TBG; 7,082.0 HOLES IN TBG; 7,074.5 GAS LIFT; 7,035.7 Cement Squeeze; 6,811.0 ftKB CMT SQZ; 6,805.0-6,807.0 GAS LIFT; 5,861.4 GAS LIFT; 4,215.6 SURFACE; 29.0-3,323.9 GAS LIFT; 2,105.1 SAFETY VLV; 1,961.7 CONDUCTOR; 30.0-110.0 KUP PROD KB-Grd (ft) 33.01 RR Date 4/19/1984 Other Elev… 2F-12 ... TD Act Btm (ftKB) 7,820.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292109700 Wellbore Status PROD Max Angle & MD Incl (°) 41.23 MD (ftKB) 2,200.00 WELLNAME WELLBORE2F-12 Annotation Last WO: End DateH2S (ppm) 110 Date 12/19/2017 Comment SSSV: LOCKED OUT Originated: Delivered to:7-May-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-04 50-103-21852-00 910026680 Kuparuk River Leak Detect Log Field- Final 4-May-25 0 12 1E-11 50-029-20787-00 910026795 Kuparuk River Leak Detect Log Field- Final 3-May-25 0 13 1E-11 50-029-20787-00 910026795 Kuparuk River Plug Setting Record Field- Final 3-May-25 0 14 1E-36 50-029-22927-00 910026794 Kuparuk River Multi Finger Caliper Field & Processed 29-Apr-25 0 15 2F-12 50-029-21097-00 909990397 Kuparuk River Radial Bond Record Field- Final 16-Apr-25 0 16 3M-19 50-029-21737-00 909953646 Kuparuk River Leak Detect Log Field- Final 27-Apr-25 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40363T40364T40364T40365T40366T40367180-057182-051198-213184-043187-0645/8/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 10:12:05 -08'00'52F-1250-029-21097-00 909990397Kuparuk RiverRadial Bond RecordField- Final16-Apr-2501184-043 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 0 7 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ OperatioW/W�tdown E -]Performed: Suspend E] Perforate ❑ Other Stimulate E] Alter Casing E]CliatgetApproved' I�rygram ❑ Plug for Redrill ❑ •erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Cement/Resin Packer Repair 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 184-043 3. Address: P. O. Box 100360, Anchorage, Alaska Slratigraphic❑ Service ❑ 6. API Number: 99510 50-029-21097-00-00 7. Property Designation (Lease Number): 9. Well Name and Number: ADL 25657 KRU 2F-12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,820 feet Plugs measured None feet true vertical 6,463 feet Junk measured None feet Effective Depth measured 7,660 feet Packer measured 7,091 feet true vertical 6,333 feet true vertical 5,860 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 110' MD 11 O' TVD SURFACE 3,295 feet 9 5/8 " 3,324' MD 2844' TVD PRODUCTION 7,723 feet 7 7,751' MD 6408' TVD Perforation depth: Measured depth: 7218-7232. 7248-7288 feet True Vertical depth: 5967-5978._5992-6025 feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 7,124' MD 5,887' TVD Packers and SSSV (type, measured and true vertical depth) PACKER • BAKER FHL RETRIEVABLE PKR 7,091' MD 5,860' TVD SSSV• BAKER FVL SAFETY VALVE 1,962P MD 1,811'TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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 1770 347 1103 1335 144 Subsequent to operation: 1170 347 1103 1335 144 14. Attachments (required per 20 PA.0 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ED Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-485 Authorized Name: Steve Drake contact Name: Steve Drake Contact Email: Steve.G.Drake@cop.com Authorized Title: Sr. Wells Engineer C. Contact Phone: (907) 263-4062 Authorized Signature: Date: Form 30-404 Revised 4/2017 Y71— /2//6/19 RBDMSHA-J NOV 0 8 2019 Submit Original Only KUP PROD WELLNAME 2F-12 Conoco`Phillips Q'tPAR[JRCIVP.I...T�,Well Attributes Flekl Neme lletee, YUWI W¢I AI85%kl, (IC.omoinn�nnnn. OUT WELLBORE 2F-12 aF.1z, uMumlas4easgm Last Tag VartivelxMrtreec(xWeq .......................................................... ..... AnnWallon Depth lltl(BI Entl Date W¢IIn EoLast Motl ay Last Tag ELM 6,8290 511112019 2F-12 hmaj EN 7- � Last Rev Reason AnnoWdon Entl Dale Wellbore Leat Moe By Rev Reason: Tubing Punch W122p19 2F-12 hhn, Casing Strings epth PVD).-UWIUn I1... Ones Top Th e. Casing Oneonta -him himID11n1 Top (flKR) sal pipe lflKBl Se[p110.0 HAp WELDED CONDUCTOR 16 15.06 30.0 110.0 62.50 ,ons. Description oD pnl In, Pat rep (nnR) sH peplll U-11 sH nape lNp)...eclen(I 6raee OR areae SURFACE 9518 892 290 3,323.9 2,843.] 3600 J-55 BTC coxouc75R; amnno° Casing Descrmeas nn gn) ID pre) Top MR.) Sal Uepe Me) sal Depih lTVD)...2-,.-n ll...Onee Tap TLreae PRODUCTION ) 628 28] ],]512 6,40].6 26.00 755 BTC Tubing Strings Tobin Demnption Sbine Ma... 10 (in) Toppi Eat OspiM1 (h., ee[Depe 1ND)(... Sit (Iter) Dead Top Committee TUBING 3112 2.99 23.7 7,123.5 5,88].5 9.30 J-55 EUE-8rd EPFENVLV; 1.17 Completion Detai is Top(Np) Topintl Nominal Top (flKe) IRQ) P) @m Des Com 10 (in) 237 23J 0.04 HANGER FMC GENII TUBING HANGER 3.500 BAS LIn; 21051 1,961.] 1,81 p.7 41.05 SAFETY VLV BAKER FVL SAFETY VALVE (LOCK ED OUT 1019104) 2.810 7,077.7 5,8487 S1.99 PBR BAKERPBR 3.000 ],091.4 5,860.3 3207 PACKER BAKER FHL RETRIEVABLEPACKER 3.000 ],108.5 5,8]4.8 32.23 NIPPLE CAMCOO NIPPLE NO GO 2750 ],122.4 5,88fiS 3240 TTL VANN GUN TUBING RELEASE 1110 suRFxE; 2a.oa,azAs- Other In Hole (WLreline retrievable plugs, valves, pumps, FSn' etc.) Top RVC) Topinm WE UFT; 4,2159 Top MKB) ],0]4.5 MKIR 5,846.0 c) Des con, 31.9] HOLES IN TBG HOT 2' "TBG PUN sp(0 phase)(rom ]0]45 O78.5' Run Dole 1 201 8 mpn) 0.000 BAS UFT: 58 7,082.0 5,852.3 3201.HOLES IN TBG SHOT "X "TBG PUNCH (4spphase) (rom] - 7084' 1321 g 0.000 cMT soz: s.ere.oa.eozo ],08)0 5,856.6 32.04 SILICASAND LAYED IN SILICA SAND FROM 7107'-7087 1211720 0.1100 8 cam.nl stwm, e,en.o nKe ],103.0 5,8]0.1 32.16 ATH 2. 79"CATCHER I GUTTED "JD ON POF PULLING TOOL PLUG (63"DAL) 12/1 g O.Opp cememil'al;&mlomra ],108.0 5,8]4.3 32.22 CA -2 PLUG 1235" CA -2 PLUG 3162016 0.000 Gus UPT. 7.M7 ],471.0 6,184.3 33.78 FISH VANN GUN 181.55Vann Gun 412611984 I TUUG Perforations & Slots Snot HOLES IN TEG 7,0745- Top Me) BI pMKI Te1flKIB1 B.lTVDmi(B) I LMNee ion¢ Date pens she. 1 Pipe coal 6,805.0 6,8020 5,617.5 5,619.1 511WO19 4.0 CMTSOZ Tubing Punch 4spf, O Deg Phasing. ],2180 ],232.0 5,966.] 5,976.4 A5, 2F-12 42611A 12.0 IPERF Zero deg. hasing5" eo Vann Guns HOLFS IN TBG:Y.092.0 PBR:7.on.7 J,248D ],288D 5,9918 ,.3 6 025 A -0,2F-12 426/1984 12.0 IPERF 'erode PhmIh eo 9: Vann Guns y,;;; Cement Squeezes PACKER 1?ba1< SLICAEANp.7.hanD ToPT7V-n Ren flVD) Top(flne) Ktm(nKB) MRR) (nKK) Des Emtl Dale tom 6,8110 ],050.11 5,822.5 5,625.2 ement 113W2019 14.1# Well Lock Cement WTCHERIIPULUNBTCOC voso Squeeze Squeeze 6,811.0 ],0500 5,622.5 5,825.2 11302019 14.1# Well Lock Cement Squeeze Mandrel Inserts CA PLUc:7.108.0 BI NIPPI£: 7.,.a aX N Top ptl(B Top KE) 1 MIKE)Meke TI; LakM1 Portslxe TRO Run MMeI OD (in) Sery type Type (in) (paq Run pab Com 2,105.1 1,818.8 MMH FMHO 1 GAS LIFTtGLVBK 015642158 3526] MMH FMHO 1 GAS LIFTBK 01883 58614 4BW9 MMH FMHO i GAB LIFTBK 01BB DO 1&1612018 4 ],035.] 5813D MMH FMHO 1 GAS LIFTIntegra 0,000 0.0 12/152018 Head Notes: General & Safety End Data I Annotation ne1212010 NOTE: View Scbematid Wl Alaska SLhematiC9.0 IPERF:?215.67,M0� IPERF: 7.24a.p7,29AO� FISHI7,O0C PRODUCTION: 39.7-],751.2 WELL EVENT SUMMARY 2F-12 FAILED PACKER REPAIR In short, we pumped the cement job and obtained a passing MIT -IA but were unable to obtain a passing DDT on the IA. Coil milled up some of the cement and we ran a CBL afterwards in an attempt to see the top of the cement in the IA but none was found. Decision was made to pump a second cement job so we ran in hole with puncher but already had TxIA communication. Ran a LDL and did not find a leak. Made the decision to go ahead and run the hole punch from 6805-6807' RKB. Unable to achieve circulation. Talked to the DPE and rather than punch multiple holes until we did see communication as well as bringing the cement considerably higher in the IA, decided to send the well to rig work over. 2F-12 CEMENT/RESIN PACKER REPAIR DTTM JOBTYP SUMMARYOPS START 12/13/18 ANN MITT TO 2500 (PASS). SHOT 2" x 2' TBG PUNCH, 4spf, 00 PHASE FROM 7082' TO COMM 7084' RKB. CORRELATE TO TBG TALLY 4-25-84. UNABLE TO ESTABLISH CIRCULATION. SHOT 2" x 2' TBG PUNCH, 4spf, 0° PHASE FROM 7074.5' TO 7076.5' RKB. LRS ON LOCATION TO LOAD TBG x IA WITH 88 BBLS DSL (U -TUBE FOR FREEZE PROTECT). IN PROGRESS. 12/15/18 ANN SET 2.75" AVA CATCHER ON CA -2 PLUG @ 7108' RKB; PULLED HS OV & COMM REPLACED W/ HS DV W/ INTEGRAL LATCH TOP SUB; PULLED GLV & ATTEMPT TO SET OV @ 5861' RKB. IN PROGRESS. 12/16/18 ANN SET OV @ 5861' RKB; REPLACED GLV'S @ 4216' RKB & 2105' RKB; PULLED AVA COMM CATCHER @ SET 2.79" CATCHER W/ GUTTED JD ON CA -2 PLUG @ 7108' RKB; DUMP BAILED 11' OF SILICA SAND FROM 7108'-7097'. IN PROGRESS. 12/17/18 ANN DUMP BAILED SILICA SAND FROM 7097' RKB TO 7087' RKB (TOS). COMPLETE & COMM READY FOR CTU. 1/29/19 ANN BOP TEST. RIH W/ CEMENT NOZZLE, TAKING CT DISPLACEMENT RETURNS COMM FROM TBG, TO TOP OF SAND PLUG AT 7,050' CTMD. PUH 5'. PUMP 66 BBL SD, 100 BBL TREATED SW DOWN CT TAKING RETURNS FROM IA. PUMP 7.5 BBL OF 14.1#/GAL. WELL LOCK CEMENT. DISPLACE CEMENT TO IA. CLOSE IA. SWAP TO TUBING. FOUND SURFACE LINES FROZEN. CIRCULATE OUT CEMENT THROUGH IA TO SURFACE WITH DIESEL. FP TUBING. THAW SURFACE LINES. PUMP FOAM WIPER BALL THRU CT. 1/30/19 ANN RIH W/ CEMENT NOZZLE, TO TOP OF SAND PLUG AT 7,050' CTMD. PUH 5'. PUMP COMM 66 BBL SD, 111 BBL TREATED SW DOWN CT TAKING RETURNS FROM IA. PUMP 10 BBL OF 14.1#/GAL. WELL LOCK CEMENT. PUMP 7 BBLS TO IA. CLOSE IA AND OPEN TUBING LAY IN 3 BBLS OF CEMENT AND POOH PUMPING CT DISPLACEMENT. SHUT IN WELL. PUMP WIPER BALL THRU CT 25 BBLS. RDMO. 2/6/19 ANN CMIT T X IA TO 2500 PSI PASSED DDT -T X IA IN PROGRESS COMM 2/7/19 ANN DDT -T X IA (IN -PROGRESS) COMM 2/8/19 ANN DDT-TxIA (IN PROGRESS), BLEED T & IA TO 0+ PSI (COMPLETE). COMM 4/6/19 ANN DRIFT W/ 2.25" BAILER & TAG TOC @ 6460' RKB. JOB COMPLETE & READY FOR COMM E -LINE. 5/5/19 ANN RIH AND TAG @ 6630' CTMD (6645' RKB). MILL DOWN T06811' CTMD (6826' COMM RKB) SEEING LIGHT MOTOR WORK. BACK REAM UP TO 6435' CTMD. CHASE FINAL GEL PILL OUT OF HOLE AND FREEZE PROTECT WELL. READY FOR NEXT REPAIR PROCEDURE. 5/11/19 ANN RIG UP ELINE. LOG CBL. TAG TOC AT 6829'. DID NOT SEE IA TOC. RIH W/ COMM PUNCHER. COMMUNICATION B/W TBG AND IA PRIOR TO SHOOTING, LLR = 0.8 BPM. DO NOT SHOOT, DECIDE TO LOG LDL. JOB CONTINUED. 5/12/19 ANN LOG LDL, NO LEAK POINT FOUND. PUNCH TBG FROM 6805'- 6807'. UNABLE TO COMM ACHIEVE CIRCULATION. JOB COMPLETE. 6/15/19 ANN (AC-EVAL) DDT- T X IA (PASSED) COMM Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: �4/ AOGCC . ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision w 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 18 40 43 OEM wi TRANSMITTAL DATE rr TRANSMITTALss 1C-28 1J-154 2F-07 2F-12 3M-17 3A-04 3A-01 3M-17 .. # 50-029-23270-00 50-029-23254-00 50-029.21076-00 50-029-21097.00 50-029-21729-00 50-029-22219-00 50-029-21412-00 50-029-21729-00 ORDERSERVICE EBNL-00021 EBSI.00005 EBSI-00006 ECNM-00001 EOSH-00044 EOSH-00045 EOSH-00046 EOSH-00047 FIELDNAME r KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER •DELIVERABLE WL WL WL WL WL - WL WL WL DESCRIPTION PPROF WFL Caliper LDL Caliper WFL-LDL PPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD Color r, TELOGGED Prints 7 -May -19 8 -May -19 10 -May -19 12 -May -19 12 -May -19 13 -May -19 14 -May -19 15 -May -19 CD's 1 1 1 1 1 1 1 1 1L-12 50-029-22033.00 EOSH-00051 KUPARUK RIVER WL PPROF FINAL FIELD 21 -May -19 1 1B-14 50.029-22452.00 DWUJ-00098 KUPARUK RIVER WL LDL FINAL FIELD 24 -May -19 1 fEQ 10 Please return via courier or sign/scan and email a copy to Date and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Pry lgg-l)zt 3 Loepp, Victoria T (DOA) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Tuesday, March 26, 2019 8:51 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair 2nd Attempt Approval Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you! I'm sorry for my misunderstanding of the sundry process. Thank you for being understanding and for your approval. I'll be sure to follow the steps you have lined out accordingly. Thanks again! Steve From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 26, 2019 8:47 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair 2nd Attempt Approval Steve, A 10-404, Report of Sundry Well Operations is required to be filed with the commission within 30 days after the completion of the work(20 AAC 25.280(d)). The expiration of the sundry is not a factor if the work approved by the sundry has been complete. The 10-404 should have been filed by 3/8/2019. That being said, you have approval for a 2n1 attempt under this sundry as outlined in the procedure submitted below under the following conditions: 1. The second attempt must be initiated by 4/15/19. 2. Within 30 days after the work completion, a 10-404 must be submitted. 3. A copy of this approval must be included with your copy of the original approved sundry. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.LoeopC&alaska aov CONFIDENTIALRY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoria.LoeLplp@alaska.gov From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Tuesday, March 26, 2019 8:30 AM To: Loepp, Victoria T (DOA) <victoria.loepp(@alaska.eov> Subject: RE: (EXTERNAL]KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair No. The 10-403 doesn't expire for this well until 11/9/19. From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.zov> Sent: Tuesday, March 26, 2019 8:29 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: RE: (EXTERNAL)KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair Has the 10-404 been submitted for this sundry? From: Drake, Steve G <Steve.G.Drake@conocophillips com> Sent: Tuesday, March 26, 2019 8:28 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair Hi Victoria, The first attempt was completed on 2/8/19. Depending on intervention resources, mainly service coil, would like to make my second attempt within the next couple of weeks. Thanks, Steve From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Tuesday, March 26, 2019 8:22 AM To: Drake, Steve G <Steve.G.Drake@conocophillips com> Subject: [EXTERNAL]KRU 2F-12(PTD 184-043, 318-485) Cement Packer Repair Steve, When was this procedure performed? When would you make the next attempt? Thanx, Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Monday, March 25, 2019 2:44 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: 2F-12 Cement Packer Repair Hi Victoria, I had previously submitted a 10-403 to perform a cement packer repair on 217-12. The procedure was executed and the well passes a positive pressure test but unfortunately does not pass a negative pressure test, draw down to zero, on the IA. Attached is a procedure to make another attempt at a successful packer repair. The bottom half of the procedure is the same as the other one that I've sent you (milling out the cement and installing the gas lift design). The SL, EL and coil steps are new, but again, very similar to the previous procedure. Please let me know if you are ok with this. If so, I can do what we've done in the past, filing a response to this email with the appropriate paperwork. Thanks, Steve Drake CPF2/A1pine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake(c)conocophillips corn Office: (907) 263-4062 Mobile: (907) 223-1166 WELL LOG TRANSMITTAL #905329436 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Tubing Punch Record: 2F-12 FEB 0 5 2019�®V C �; Run Date: 12/13/2018 104043 30 32 8 January 14, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.corn 2F-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21097-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: 0 �! Signed: • • 1 8 4043 WELL LOG TRANSMITTAL #904720036 2 9 3 9 To: Alaska Oil and Gas Conservation Comm. June 11, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RECEIVED JUN 202018 RE: Leak Detect Log: 2F-12 Run Date: 3/17/2018 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-12 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-21097-00 JUN 2 LG 1 Leak Detect Log SGANt 1 Color Log 50-029-21097-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com P1 /0 WI Date: Signed: C7 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 3 ~ a~ ~~ ~ z';v ~~>> Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRII). 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 October 27 and October 30, 2008. The corrosion inhibitor/sealant was pumped November 2, 2008. 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, Perry m 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 r]atp 11 /3/2008 Well Name P7D # 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 2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008 2F-04 183-190 48" NA 48" NA 25.5 11/2/2008 2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008 2F-08 184-021 SF NA 20" NA 2.55 11/2/2008 2F-09 184-036 18" NA 18" NA 1.7 11/2/2008 2F-10 184-040 22" NA 22" NA 1.28 11/2/2008 2F-12 184-043 20" NA 20" NA 2.12 11/2/2008 2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008 2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008 :'~'"'" STATE OF ALASKA ALA~, .m OIL AND GAS CONSERVATION COMMIS~,,.cN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service __ 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 214' FNL, 1440' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1343' FSL, 1284' FEL, Sec. 33, T11N, R9E, UM At effective depth 1066' FSL, 1265' FEL, Sec. 33, T11N, R9E, UM At total depth 973' FSL, 1260' FEL, Sec. 33, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 782O 6463 6. Datum elevation (DF or KB) RKB 125 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-12 9. Permit number/approval number 84-43 10. APl number 5o-029-21097-00 1 1. Field/Pool Kuparuk River Field/Oil Pool feet feet Plugs (measured) None Effective depth: measured 7 6 6 0 true vertical 6333 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3295' 7 - 5 / 8" Intermediate Production 7722' 5.5" Liner Perforation depth: measured Cemented Measured depth True vertical depth 225 Sx CS II 121 ' 121' 930 Sx AS III & 3224' 2766' 710 Sx Class G 325 Sx Class G & 7 7 51 ' 6 4 0 7' 250 Sx AS I 721 8'-7232',7248'-7288' true vertical 5966'-5978',5991 '-6025' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7122' Packers and SSSV (type and measured depth) Packer: Baker FHL @ 7091'; SSSV: Baker FVL @ 1962' 13. Stimulation or cement squeeze summary ORIGINAL Fracture stimulate 'A' Sands on 8/29/97. Intervals treated (measured) 7218'-7232',7248'-7288' Treatment description including volumes used and final pressure Pumped 246.6 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fl:) was 5200 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 215 130 526 975 139 Subsequent to operation 434 266 783 1007 151 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby_.certify that the foregoing is true and correct to the best of my knowledge. Signed ~_Z¢~/_~,. ~_ _~~,.~ Title Wells Superintendent Form 1¢0'4 I~e~/,4¢6¢'¢5"~/8~ - / Date ./~/'~,~~ JAN 06 1998 ,Alaska 0ii & Gas Cons. Commis_~ior~ AP~CO' Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2F-12(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-12 FRAC, FRAC SUPPORT 0815971709.2 DATE DAILY WORK UNIT NUMBER 08/29/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes, O NoI (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC~ CC~ DAILY COST ACCUM COST Signe. d ~- ,,. ESTIMATE KD1357 230DS36FL $1 41,444 $172,515 ./.,,' ~'7 ¥' .L.______-~- '~ Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ~- Final Outer Ann 585 PSI 1200 PSI 480 PSI 500 PSII 50 PSII 150 PSi DALLY SUMMARY I"A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 246579 LBS IN THE FORMATION W/144f PPA OF #12/18 @ THE PERF'S. I FREEZE PROTECTED TBG DOWN TO 3400' W/30 BBLS OF DIESEL.' MAXIMUM PRESSURE 6000 PSI & F.G. @ (.79I. I TIME 09:00 13:00 13:15 14:10 15:10 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRUCK, AND HOT OIL TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D THE HIGH PRESSURE LINES TO 8700 PSI. PUMP BREAKDOWN W/50# DELAYED XI GW @ 27 TO 15 BPM. VOLUME PUMPED 356 BBLS. USED 5893 LBS OF' #20/40 PROP. MAXIMUM PRESSURE 5600 PSi AND ENDING PRESSURE 2900 PSI. S/D AND OBTA;"i".:-;;* 2014 PSI W/F.G. @ (.78). STOOD-BY AND MONITORED WHTP. PULSED TO DETERMINE CLOSURE. D~:-FERMINED CLOSURE TIME OF +-20 MINS @ 1680 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 177 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISIP OF 2068 PSI W/F.G. @ (.79). STOOD-BY AND MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME OF +-12 MINS @ 1723 PSI. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND MONITORED WHTP FOR 5 MINS. PUMPED 247246 LBS OF PROP (13682 LBS OF #20/40 & 233564 LBS OF #12/18). INJECTED 246579 LBS IN THE FORMATION W/14# PPA OF #12/18 @ THE PERF'S. LEFT 667 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED TBG DOWN TO 3400' W/30 BBLS OF DIESEL. MAXIMUM PRESSURE 5200 PSI AND ENDING PRESSURE 3800 PSI. 17:40 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL UNIT. 18:40 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. 19:30 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $680.00 APC '$5,200.00 $11,200.00 DIESEL $400.00 $2,668.00 DOWELL $132,985.00 $144,883.00 HALLIBURTON $0.00 $4,196.00 LITI'LE RED $2,860.00 $6,380.00 NITROGEN $0.00 $2,509.00 TOTAL FIELD ESTIMATE $141,445.00 $172,516.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing O t 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service Location of well at surface 214' FNL, 1440' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1343' FSL, 1284' FEL, Sec. 33, T11N, R9E, UM At effective depth 1067' FSL, 1265' FEL, Sec. 33, T11N, R9E, UM At total depth 973' FSL, 1260' FEL, Sec. 33, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7 8 2 0' feet 6463' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 125' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-12 PrQducer 9. Permit number/approval number 84-4~ / ~ - 10. APl number 50-029-21097 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7660' feet true vertical 6333' feet Junk (measured) Casing Length Size Cemented Structural Conductor I 1 O' 1 6" 225 Sx C.S. II Measured depth 110' True vertical depth 110' Surface 3224' 9-5/8" 930 Sx A.S. III & Intermediate 710 Sx Class "G" Production 775 1' 7" 250 Sx A.S. I & 325 Sx Class "G" Liner Perforation depth: measured 7218', 7232', 7248 '-7288' MD true vertical 5967'-5978', 5992'-6025' TVD Tubing (size, grade, and measured depth) 3224' 2767' 7751 ' 6407' 3 1/2", J-55, 9.3#/ft EUE 7122' MD Packers and SSSV (type and measured depth) -' -.,,,.:, , . ", Packer: Baker FHL @ 7091' MD, SSSV: Baker FVL @ 1962"MCricn0rage 13. Stimulation or cement squeeze summary Intervals treated (measured) 7218'-7232', 7248'-7288' MD Treatment description including volumes used and final pressure 1298 bbls Gelled Diesel, 110,000# 16/20 Carbo-Lite Proppant, WHTP = 3550 PSI M 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water- Bbl Casing Pressure Tubing Pressure Prior to well operation 6/1 8 Subsequent to operation 8/1 5 1267 992 0 350 130 1967 3817 0 400 451 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 I~e~-06/15/88 Date //~,.~ V,/ ~~ SUBMIT IN DUPLICATE ' ARCO Alaska, Inc~~ Subsidiary of Atlantic Richfield Company WELL ] PBDT CONTRACTOR AEMARKS WELL SERVICE REPOR'I IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME A,' SA~D . Gel CC',' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK . ,. DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON' / ~ ~ ARC:TIC COIL TUBING FRACMASTER B, J. HUGHES Roustabouts ,, Diesel 'Methanol " Supervision Pre-Job SafetY/Meeting .. AFE .... TOTAL FIELD ESTIMATE STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMN,._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , ~ Re-enter suspended well ;-; Alter casing T~me extension Change approved program Plugging "7 Stimulate ~ Pull tubing Amend order ,r Perforate ~' Other .] 2 Name of Operator ARCO Alaska? In¢, 3 Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 214' FNL, 1440' FEL, Sec. 33, TllN, RgE, UN At top of productive ~nterval 1343' FSL, 1284' FEL, Sec. 33, TllN, RgE, UM 5. Datum elevation (DF or KB) 125' RKB~' 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-12 Producer feet At effective depth 1067' FSL, 1265' FEL, Sec. 33, T11N At total depth 973' FSL, 1260' FEL, Sec. 33, TllN 11. Present well condition summary 7820 Total depth: measured 6463 true vertical Effective depth: measured 7660 true vertical 6333 , R9E, UM , R9E, UM I feet feet I feet I feet Plugs (measured) Junk (measured) 8. Per m i t8r~u._r~e r 9. APl number 50-- 029-21097 lO..POO~Kuparuk River Oil Pool Casing Length Structural Conductor 110 ' Surface 3224' Intermediate Production 7751 ' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth 16" 225 Sx C.S. II 9-5/8" 930 Sx A.S. III & 710 Sx Class "G" 7" 250 Sx A.S. I & 325 Sx Class "G" 7218' -7232', 7248' -7288' MD True Vertical depth 5967'-5978' 5992'-6025' TVD Packers and SSSV (type and measured depth) Packer': Baker FHL ~ 7091' MD: SSSV: 12.Attachments Description summary of proposal ~ Detailed operations program .[-7; Refracture A Sand with gelled diesel and 16/20 M Carbo-Lite. 13. Estimated date for commencing operation 06/20/88 110' 110' 3224' 2767' 7751' 6407' RECEIVED JUN 2 - ~c.,E,O 3 1/2" J- 55 9.3#/ft "' -Alaska 011 & Gas Cons. CommissiOn , , ~u ~ 7122' M~nch0rage Baker FVL @ 1962' MD BOP sketch ~ 14. If proposal was verbally approved Name of approver Suhsequ~m[ ~vVo~]c Bepo~ecl on Form No., Dat-ed~/~/ Date approved 15. I hereby certify that the{f_oregoing.is true and correct to th~best of my knowledge Signed /~O~ ,~ .;~ .j'~.~.~~ Title Y Commission Use Only Conditions of approval Notify commission so representative may witness I Approval I-;, Plug integrity ~ BOP Test ~ Location clearanceI Approved Copy . Returned ORIGINAL SIGNED BY No. Approved by LONNIE C. SMITH ~' Commissioner by order of ~' the commission Date ~ '--~' L:~/~O~ Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2F-12 Well 2F-12 is currently an 'A' Sand-only producer. The 'A' Sand will be re-fractured to improve flow efficiency. A copy of the proposed procedure is attached. The fracture stimulation will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A 10,000 psi 'tree saver' will be used during the fracture stimulation. Wellhead pressure/fluid level analysis indicates an average reservoir pressure of 2100 psig in the 'A' Sand. There is no gross C Sand interval present in this well. Messrs Lyden and wade June 3, 1988 Page 2, Kuparuk Well 2F-12 'A' Sand Re-Fracture Procedure Charge Code: 230DS28GL 1. Obtain an 'A' Sand 24 hour well test. , MIRU Slickline unit. Tag bottom. Pull GLV's and Run DV's. Set blanking plug in Camco 'D' nipple at 7109' MD-RKB. Pressure test the tubing. Pull blanking plug. 3. Pump Diesel/10% Musol per the attached schedule. Shut down overnight to soak. . . Note: Ensure capability to drop ball sealers if necessary. Maximum perforation diameter 0.40". Recommend :>0.50" diameter balls. Total perfs -- 216 (54' x 4 SPF). RU fracture equipment. Install "Tree Saver". Pressure up 7" annuals to 3500 psi. Check diesel for contamination prior to gelling for frac. Obtain a sample of the proppant'and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3480 psig Fracture Gradient = 0.73 psi/ft (5996' TVD) Tubing Friction -- 170 psi/1000 ft (7090' MD) * If treating pressure during the job exceeds 6000 psi, shut down job and confer with engineering. 7. Rig down frac equipment. Follow attached flowback schedule. KUPARUK WELL 2F-12 °A° SAND FRACTURE PUMP SCHEDULE 6~3~88 ST/~E FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM ~ DESCRIPTION LBS STG/CUM BBLS I DIESEL/10% MUSOL 50.0 5 0 ~ - 0 5 0/ 5 0 65 2 DIESEL FLUSH 63.0 5 0 - - 0 63/ 11 3 11 5 ............................................. SHUT DOWN OVERNIGHT ................................................. 3 GD PRE-PAD 100.0 2 5 0 - - 0 1 00 / 1 00 6 5 .............................................. SHUT DOWN FOR ISIP .................................................. 4 GDPAD 750.0 25 0 16120 M CARBO-LITE 0 750/ 850 165 5 GDw/2PPG 87.3 25 2 16/20 M CARBO-LITE 7334 95/ 945 915 6 GD w/4 PPG 80.8 2 5 4 16/20 M CARBO-LITE 13568 95/ 1040 1010 7 GDw/6PPG 79,1 25 6 16/20 M CARBO-LITE 19930 1 00/ 1140 1105 8 GD w/8 PPG 77.6 2 5 8 16/20 M CARBO-LITE 26084 1 05/ 1 245 1205 9 GDw/10 PPG 79.8 25 10 16/20 M CARBO-LITE 33525 115/ 1360 1310 1 0 GD w/12 PPG 9.8 25 I 2 16/20 M CARBO-LITE 4945 I 5/ 1375 1425 1 I GDFLUSH 63.4 +SV 25 0 - - 0 63.4/ 1438.4 1440 , , , TOTAL UNGELLED DIESEL = 108.0 BBLS +SV TOTAL GELLED DIESEL = 1327.8 BBLS TOTAL MUSOL = 5.0 BBLS 1~20 M CARBO-LITE = 105385 LBS ~ Stage I is Diesel with 10% Musol ~ Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. Stages 5 through 10 are Gelled Diesel with 6 hour breaker and without silica flour. t'T'1 Stage 11 should include a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker (6 hour break). This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 70° to 90° F on the surface. ARCO Alaska, Inc. ~ Post Office b,.,^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 7, 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' 2F-12 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, If . Gruber Associate Engineer JG/tw GRU4/L219 Enclosure RECEIVED 1 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' ' .... STATE OF ALASKA ~- ALASKA _ AND GAS CONSERVATION CC ~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-43 3. Address 8. APl Number P. O. Box 100:360, Anchorage, AK 99510 50- 029-21097 4. Location of well at surface 9. Unit or Lease Name 214' FNL, 1440' FEL, Sec.33, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1343' FSL, 1284' FEL, See.33, TllN, R9E, UM 2F-12 At Total Depth 11. Field and Pool 973' FSL, 1260' FEL, Sec.33, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 125' RKBI ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/10/84 04/16/84 04/26/84I N/A feet MSL .I 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21 Thickness o'f Permafrost 7820'MD,6463'TVD 7660'MD,G333'TVD YES [] NO [] 1962 feet MDJ 1400' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/FDC/CNL, CBL/GR/CCL, Gyro, Temp. Log, CCL/Temp. Log 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# U-40 Surf 110' 24" 225 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3224' 12-1/4" 930 sx AS Ill & 710 sx (',lass G 7" 26.0# J-55 Surf 7751' 8-1/2" 325 sx Class "G" & 250 ,~.x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7230' - 7300' w/4 spf 3-1/2" 7121' 7091' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See Addendum for :racture Stimulation Summary. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD I~ Flow Tubing C~sing Pressure CALCULATED,.k. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED 1 1985 Alaska Oil & Gas Cons. Oommissi~ ,t Anchorage ,, Form 10-407 GRU4/WC58 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ...... ~' FO'RMAT~N q'EST~." . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,.and'time of each phase. .. .. Top Kuparuk "B" 7161~ 5918~ N/A Top Lower Sand 72'0z~~ · 595/~~ Base Lower Sand ' - 73z~3~ 6071~ . . . ., . , · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing Js true ~nd correct to the best of my knowledge Signed (~ ~ _V~~,,.,/ Title .... Date 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- lng 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". ADDENDUM WELL: 2F-12 9/02/84 9/10/84 9/25/84 10/14/84 RECEI\/ MAR 1 3 !985 Alaska Oil & 6as Ci::~.:, ~_ Anchora_~e Arctic Pak w/250 sx CS I, followed by 53 bbls Arctic Pak. 7660' PBTD Rn temp log f/7400'-7020'; did not tag btm due to Vann gun fsh in hole. FRACTURE STIMULATION SUMMARY AFE: 403946 Begin Frac Work At: 1728 hrs, 9/24/84. Dowell frac'd Kuparuk "A" sand perforations 7218'-7232' and 7248'-7288' per 9/20/84 procedure using hot diesel w/5% D-20 and YE4PSD gelled water. Pressured annulus to 1500 psi with diesel. Test lines to 5600 psi; OK. Pumped 40 bbls 90° diesel @ 15 BPM, 4800 psi; 90 bbls gelled wtr @ 15 BPM, 4600 psi - 3700psi. ISIP = 2050 psi. (NOTE: Calculate perf friction of 879 psi - too high.) Flushed tubing w/85 bbls gelled diesel. (Pumped 0 in formation, leaving 0 in casing.) Load to recover 125 bbls diesel and 90 bbls of wtr. Job complete @ 1805 hrs, 9/24/84. FRACTURE STIMULATION SUMMARY AFE 403946 Begin Frac Work At: 1430 Hrs, 10/14/84. Dowell frac'd Kuparuk "A" sand performations 7218'-7232' & 7248'-7288' in seven stages per revised procedure using hot diesel, H20/gel, slick diesel, 100 mesh & 12-20 sand. Pressured annulus to 1200 psi with diesel. Test lines to 6000 psi; OK. Pumped 40 bbls 120° diesel @ 19 BPM w/4900 psi pad containing 5% P-20. Stage #1, 100 bbls of uncrossed linked wtr/gel @ 20 BPM w/3200 psi. ISIP - 1620 psi. Decided not to use ball procedure - friction = 335 psi). Stage #2, pmp 120 bbls cross-linked wtr/gel @ 15 BPM w/3060 psi. Stage #3, 25 bbls wtr/gel w/1 ppg 100 mesh @ 15 BPM w/3100 psi. Stage #4, 30 bbls gel @ 15 BPM w/3280 psi. Stage #5, 26 bbls gel w/2 ppg of 12-20 sand @ 15 BPM w/3450 psi. Stage #6, 50 bbls of gel w/2 ppg of 12-20 sand (11,170#) @ 15 BPM w/2640 psi. STage #7, flush w/18 bbls gel/wtr & 48.5 bbls slick diesel @ 15 BPM w/3400 psi. ISIP = 2030 psi - 15 min SI = 1550 psi. (cont'd) ADDENDUM WELL: 2F-12 to/14/84 10/16/84 Pumped 1000# of 100 mesh & 13,170# of 12-20 in formation leaving unknown amount across perfs in casing. Load to recover 88 bbls of diesel & 355 bbls of wtr. Job complete @ 1525 hrs, 10/14/84. 7660' PBTD (Fill @ 7468' - Btm perf @ 7288') RU Camco, GIH w/CCL/Temp log; unable to get past 6500' (unbroken gel). PU to 4500' & wait on gel. GIH, tag fill @ 7468', log out. SI well f/2nd log. 7660' PBTD Rn 2nd CCL/temp log, tag fill @ 7468', POOH. Release well to Production. Drilling ~uperintendent RECEIVED /~laska Oil & G~s Cons. Commission Anchore~e ........ , ,~ - ~ ......... _ .................. ,,, ~,--- ~:~=-/- - 2F-12 (SEC :3:3 T11N R!;'E) :"':.~:'"'~ ~ ~ COMPUTATION DATE BOSS GYROSC:CiPIC SURVEY APRIl_ 2:3., 1984. KUF'ARUK FIELD ',- ~ ,JOB NIJMBER AK-BO-4008'I ~',~ ................... ~'?~'~ ............. ,.-.... ....... :"?~",. ,., ~?~, · ' ,:'~""~"'~?'~',~"'?'~"'~F?~''~ ~ ..................... ~'"'"'~'": ~ ::~? :' ............. ..., .:,:: · :. ::. :. .: ,. , ,., :~ ~?,. . .. , . · . .,:.. , ....,,.,. ::::::;,:,, ,,.,::.::::::..,., :,,:: ::.;v, ....:,.,,,..: ::::::: ~:,. :::::::::::::::::::::::::::::::::::::::::::::: ~, . , ,-~· ~ ..... ~. ...... .,, .,. ,, ....................................... ~ ......... ,.c~ ..¢~ .......... ..... 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'7:2 E 1 t 0 :E:. 2 4 21.3 2 / .,~ .~.-,...~ I(I .~..(J() ()~) -,.-, ', .-, ,-, .. .--/ ,-/ ..~ -,/-, : :.: .... . j~, '":' .:' .::~. , ..,~. ~ ,-. .-, · .. ....... ~.14 ..... 5~5.00. ,5.~C~0. O0 o~:~.~. 7~ ~ 1~- 71 ~ .. . ........ ~. ~ :.. ............ i.. [1~:: .: .. : ........ ::::::::~:::::~~: . :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ;,, .' : ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . 2F-!2 (SEC 33 T11N RgE) I<LIF'~RLIK F I' ELI3 COMF'UTATION DATE APRIL :2:'::, i984 ,_lOB NLIMBER AK-BO-400! '1 R JE Tl"'l TAL 70?,0 ';';'-"-'; ............. .... :, ~.-,. 00 ~: 7 ("~ (]. 00 :'"': 663 89 S 150.69 E 1 ";' ";': 47 17.47 7168 =':~'-'= " · _,~ z._,. O0 5800. O0 3726.83 S 1.56.'~7._, E 124~. 79 .18. :32 ~ .... 7288 .6025.00 _ ~1900.00 < ~ 3792.20 .... :::::, '::::::::: ...... .:,.~:. ::::::::::::::::::::::::. ~: ::::::.' .>., :::::::::::::::::::::::::::: .:. :::::,' ::.:,¥ ::::::::::::::::::::::: :::::::::::::::::::::::::: . : .,:...:,, :: ...<..:::::::::::: :: ... + . =========================== :::::,.:::,,.,..: :::::::::::::::::::::::::: ::. .:: :... ::. : , · : .:: .::.. :....:.: .:::;:::, :: :.. ::: .::,.:::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .~:::: ::: 7773.._,/- i.:,~., ~.... 00 6300.00 4065.97 S 178.39 E 1348. ~8 23. 16 ' 7820 6462.77 6337.77 4 <'). ':>.. ::_. 09 S 179.6. 7 E 1 o""~q._ 7. ~":":'~, 8.7.5 .~ .<...~...~.~.'...*,~..~(. ~`~.~'~`~`~c~`~:~:~`~`'~`~`~:~;~`~:~"~¢~``~'~`~.~`~`~`~`~.=u~:~.~.~?~: :-..-::.:.-.~.......:......-....--.~...-..-.....-.~.~:::??:,.-:~:..:,..:~ ~.-..~ .......... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::~::::::>~:: '":::'"::::::'?~:":?":' '::':?' ~' '~.:': .: :' '<'"'::'"':::~"'":'::'":"':::*:'::::'~:':':'"':<':':::':':':':':' '?':':'":::':"':::::':':::':::"i::~'" :: :::::::::::::::::::::: ': ::': :::';'> ':: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~:::::::::::::::::::::::::::::::::::::::::::::::::::: R:~:D ::::::::::::::::::::::::::::::::::::::: ) .:: ::::::::::::::::::::::::::::::::::::: :::::.: ::: ':: ... ::: :::::::::::::::::::::::::::::::: ::: :'::: :: .. . :: : :.::::::':' :..: :.:::: ::':::: : :. :.: ::: .: .::::::::::::::::::::::::::::: :::::::::::::':::.:: ::: :: ::::::::::::::::::::::::::::::: ?::::':::::.::' :::::::::::::::::::::::::::::: :.:. '.::.: ::::::::::::::::::::::::::::::::: ::::::::i. :...' · .. :..:..:: :: :::.:':::::.:.: :....:: :::. ~ . . :: ::7 :..:. ..:..:..........:_..::...:.:_:;:j_:::::::.,~:.:. :_. ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: .:: :::::: ': .:: :.. :::::::i'..-::. :::::::::::::::::::::::::::::::::::::::::::::::::::::::: 2F-12 (SEC: :E::'-] T11N R'~)E) ''';''i:''::'~''' L.L~MI-I_IT~-~I IUN DAlE I<I_IPARI_iK FIELD . APRIL 2:E~,, ].'.:.;'84 ,JOB NLIMBER ~-,,<-~=,L,-4,.~O.~,.:. AL AC;k'~, ~ '' ' ..... ~::'[----I I V ,~-,,,:.~..~.-..~ ~.~:-.---.~..~.~t~i,~ .~u~-.,,.~-.,.~.~,:....:~ ...... :..,~ ...... ~s...~-..~.....-.:.,.~0~:.. - ....~?:.:<.~:.:.:.-..:.: ............. ~ ......... :,::..:~.:m:.,.:..~::.:...:,.~..~.:.~.,.,,.:..:-:....:~~ .,.-: .......................... ......................... .~:~:~:~,:~:~.::::.:.. :~ ~::::~;.?~.~,,:: ,. ........ "I'RUE S,UB-SE~ I'OTnL :',;'"~' ?, NE~:~LIRED VERT I C~L v~TI [.~L REF'TANI]I ILaR F"F','"~RD I NATE::::; '",, ¥.~:~¥~$~~~~.~-~.-~:~ ....... ~ ~ ..... ~., .~.,~.~.~.,~ ............... g;..~ ................... ~..,:.g;:.::;.-:.m .:.:.~'.':'.'.:': ...................... '::.':~'.;':: ":':-?' ' .'..': ::::::::::::::::::::::::::::::: .......... ' :::::::::::::::::::::::::::::::::::: ::::~:~:~:::".:~'.' ".~ ..... !':.':~:. :'"'.~ ....... ~; ::::::::::::::::::::::::::::::::: L. '::.~'. ...... ',~ '~:~.~ .::::::...:.:.: ......... : .., :,.~t .. , ...... , :,.:~:$ ............ ........ .?~::::;:~ ......... ~ ........ ~:~:~i~t~ ~:~ ~:~m:::~::::~ .... ~$~:~, .s~/;;~:....:::::. . .... :,:E:~ST.~NE~T ...... '' .::,.: ::.:,:.:: ....... :: .'"::' :: :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :' ::::::::::::::::::::::::::::::::::::::::::::::::::: :,::, : : :,::: ::: :"::::" :": : ::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: :: : ~:~:~:}~:~::~<::gcf~:~c::~:: ~:~ : :~::~:, 72Fi4 .... P;'?~4.40 .~o~..~'-":"~. 40 3746, 15 S 158.17 E TOP F)F [ONER.. _ S~ND 7:]:4:3 6070.84 , '51945.84 :]:821.83 S 16:]E:.!?'P EE BASE OF LOWER SAN[I, ' 7600 , 6284.1~ 615'~, 13 B~64.82 S; 1ZF: /-F:'~ SLI~ DEPTH ~ . ,, ............................... . ......... .:¥~:::= .~ ........ . ................... ~.:~ ......................... ~;...~ ..........~.~ .................... . ........... . .................. ~:::: ..... .:.::..:, ..................... ....:...:.... ............................... ~:~.~. ..¥ ............................................ ~,.,.,~,:~ ........... ¥::..:~ .... ~ ........... :.::::~ ......... ~ ............ ~ ........ :.:'.' .............. -..¥:¥~,,: .:'~: :~?~.~::~:::':':~?:':' ..... · .................................. =~.' ..... ~ ...... ....... '.. ..... ' .... ., : ~ -: ' ........ t .......... .... ~'~m'":'~'~'"~ "~;?~'~'m .... ~ .... ~' '~:~.~ ~t~.~- ~ ........ ~'~ '~ STRAI"I GIRAF'H I C SLIMMARV ~:ili.'~',~'.~;~'. '";~"' D.ERIVED US INA D IL DEF:'T'HS AND SF'ERIRY SLIN SLIRVEY DATA PBTD 766A /:,:3:3:2 ""~ 620'7 '""":" '::':~':;~':.) :3AS 175 27E u ~..! ...I # .. TOTAl. DEPTH DR I LLER 7,:....u 6462 7'7 6:'4:2:7 7'7 4A~:"::. ¢)'-T~F; 179.67E ~::::::::: :.'.4:.,.'.::~:,~..:.~..'..::::;?.:~:::::~::.:::::::::~:~~:~:~~A: =============================================== =============================== ':-:v:. .......... ============================================= .............. :.:..: .............. :.'... '.:...: ............... ~.'.:..'. ........ .'...'. ................ ~'..~..'..'....'..~?,.'....~, ~..',. ..... ..~ .~,.,¢~.4 ~.~ ,i~ .'....'.s ~ ..... ~ ::::. ........... . .............. .,: ................. ~::..,.:::~::.~ ................. . ........ ........ ~ ............. ~:~,.,,..,..~ ............... ~.,.'~:~..,.. ............... ~:::::~ ....................... . ................ ~.,, ............ .,.. ........... .,:.::.: ......... ...: ............. ::: ....................... ,::...: ........ : ................ .:, :::.: .................... .............................................. .;..:,:,.,.~.,..,:~%: :: :::, :.:.: ::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..:::x.:: :. ;.,.:: :,:,:, :::::::::::::::::::::::::::::::::::: :.:.,.:. : :..:. :.:::;x. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~::::~::::~ ,~8.::~::~:,~,.'.:~.~?.~:.,. ::::::::::::::::::::: .:' ;' ' . .... :i!:!i.. i:.i/iiiii!:::f:!::::i:!i::, i;ii?ii!~.!ii:ii.!'iii!i i!::ii?:!:: :;. ':;i;i.ii!i:;Yi.!:.::iiiiii:.f=iii!;i:.:.ili==i:.:!:=.:i:!::ii!!::: '?:,' :? ': ' ; i':: ; ':';'::;: i' :' : DATE O~!i!::~i APR I L ~i~!~!~!~!~:.~ :!. . ' :': . Ni~~iRL. i.40.¢.]:A~~~ , , ;~;: .':::,~ ~.::;::: ::: c:?::: ::i%~,,~ .:.' %:: Il-lB KELLY BUSHING ELEEV = ~""~' (')(-) F'T. ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40031 Well: g2F-12(SEC 33 TllN RgE) Kuparuk Field North Slope, Alaska Survey Date: April 21, 1984 Operator: Samec Scale: 1" = 1000' TRUE NORTH -lo6o. oo Surface Location 214 FNL 1440 FEL -i000.00 000.00 03 @ S 2° 30'E 7820 -5000.00 HORIZONTAL PROJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Ak-BO-40031 Well: ~2F-12(SEC 33 TllN RgE) Kuparuk Field North Slope, Alaska Survey Date: April 21, 1984 Operator: Samec Scale: 1" = 1500' 0.00 500. O0 3000. O0 4500. O0 5000. O0 '7500. O0 ~ 4097.03 @ S 2° 30'E ~7820 15~00. O0 30bO. O0 45~0. O0 VERTICRL PROJEC-f ION Suggest~ form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. · ' -Operator, Well'Name and Number Reports and Materials to be received by: ~-- ~ ~-~ Date Required Date Received RemJrks Cc~pletion Report Yes ~_Well History Yes ~'~3/-8 ~ "Z ~ ~' :-s~s ~,z,~- ?~ _ '~ d/~' . . Mud. Log ~,j __/~i ~ , · Core IX~scription Registered Survey Pla~t Inclina~on S~ey ~ Drill Stm Test Returns ~d~'~ ~s R= · Yes f- ARCO Alaska, Inc/~--- Post Offic ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/17/85 Transmittal No: 4981 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P. O..J~r~' 100360 /or,ge, AK 99510 · . /T/~nsmitted herewith are the following items. ~'and return one signed copy of this transmittal. OTIS PBU SURVEYS- Please acknowledge receipt 2W-8/: 1/08/85 lB-7 '~- 12/14/84 2F-12 1/06/85 . 2F-5 ~ 1/02/85 2W-5/-~ 1/07/85 w-6 ~ 1/07/85 w-7 1/07/85 ilA-1- 12/31/84 1A-i'll>? 12/15/84 lA-l- 12/23/84 lG-5.-- 12/25/84 2F-3~- °12/31/84 2V-SA~ 12/16/84 2B-10 ~ 12/17/84 1Y-9-~ 12/20/84 -~iC-~~ 12/10/84 2F-2~- 12/29./84 2F-15''~ 1/05/85 2F-14 - 1/04/85 2F-9 ~ 1/02/85 2F-8-' 1101/85 API 02 9-21228 '029-2D616 029-21097 029-21073 -- 029-21220' 029-05900 -- ~ 029-20908 07 9-21178 029-21084 029-20935 f~ ~' ~ 02 9-2 05 64'--/~5~ ~'/~~. M~.~..~'~ 029-23 063 029-21048 029-23 090 029-21077 CAMCO PBU SURVEYS 1E-12 ~ 12/14, 16/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Drilling W. Pasher Date:,gdaska 0it ~, ~s Crm~ q?.misgJcr, Anchora~o State of AK BPAE Chevron Geology Mobil G. Phillips Phillips Oil Sohio Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. i~ a sublidiar¥ ol AllanllcRichfieldComl~any ARCO Alaska. Inc..---.. : '-.: -' "' ..- ..: .~ ...... ..-:....',.:.. ".. -; ",ct',,. 9:'- 277 ~ '~', Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O, Box 100360 Anchorage, AK 99510 z/~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP lC-5 " " 1C-6 Gas Disp. 1C-7 PBU 1C-9C~alloff Test 1C-10~,'~_ " " 1D-1 Static BHP 1D-5 Falloff Test 1E-12 Flow BHP/GLV 1E-17 Static BHP 1E-18 " " 1E-24 Injectivity 4/12/84 Camco 4/13/84 " 5/16/84 Otis 4/20a21 Camco 4/29/84 " 5/06/84 " 4119184 " 4/29/84 Otis 7/01/8484 Camco 1/8-11/84 Otis 1103184 " 6/21-22/84" 2F-8 T Log PBU 2F-11 Initial PBU 2F-12 Initial Well 2F-13 " " 2F-14 PBU 2F-15 PBU State /cat Receipt Acknowledged: B. Adams 5/06/84 Otis 5/22/84 Camco 5/15/84 '~ 5/14/84 Otis 5~03~84 " 4/26/84 Camco D&M DISTRIBUTION W.V. Pasher Da t e :';" ~'~;7 ,.,.:~.? C. R. Smith .... F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska · Sohio Union Chevron NSK Operations R&D Well Yiles REV. I RENUMBER ALL WELE. 'ER NSK DRILLING. (180° ROTATION NUMBERING ) REV.?. CHANGE ALL ELEV.; II CHANGE BASIS OF ELEV. NO $0 2¢~~°8 i0 9;.0 ~ 0 ~0 28 BASIS OF PAD ELEV. I$ T'.B.M. O.g. ELEV.-tNTERPOLATED FROM SR" 8 ~- 12-30~ PHASE II ~BUILT CONDUCTORS 27 34 .LOCATED IN PROTRACTED SECTION TOWNSHIP II .N., RAN;GE 9 E-, UMIAT ,BASIS OF LOCATION IS MONUMENTS C.EF.-2 ?_:C MIDDLE PER LHD ASSOCIATES. ,- ,, DR ILLi----..IT E AS dUILT WELL 9 2_.F CONDUCTORS LOCATIONS.' Y: 5,948,84'6.91 X'- 517,761.38 :37' FN L WELL I0 Y=5,948,787.73 X= 517,771.51 96' FNL L(~t. 70° 16'17.10 15" Long. 149° 51'?.2.870" 1470' FEL WELL I'1 Y=5,948,728.56 X-- 517, 781. 64. ' FNL ~~-~- Y---~, 9 48,669. 3 5 ~;27~-- 517,791.81 -~~ 214'FNL Lat. 70° 16'1 (~. 5192" Long. 149°5I'?-2.580" 1460' FEL WELL Int. 70° 16'l 5.9 370" Long. 149°51' 22.289" 1450' FEL Int. 70° 16' 15.35 4~" Long. 1.49°51 '2i.997" 1440' FEr. WELL Y = 5,948, 627..31 X: 517,516.04 ?_61'FNL Int.70° 16'14.89 80" Long. 149° 51 '30.0?.9" 1716 ' FEL Y= 5,948, 68 I. 31 X: 517,505.83 Lot 70° 16'i5.4786" Lo rig. 149°51 '3 0.322." {7?.6' FEL W~ t 16 Y=5,948,740. 50 X' 5l 7,495.75 143'FNL Y · 5,948,799. 60 X' 5i7,485.54 8:~' FNL Lot. 70°16' 16. 0610" Long. 149°5l' 30.6 i i" 1736' FEL Lot.70° 16'I 6. 64.26" Long. 149°'Ji'30.905" 174'6' FEL ECEIV 33 MER.- J ~j'' 0 _~ I984 Alaska Oil (;as Cons. C0mm Anchora,qe DAVID FILUCCI 5276 30 I HEREBY CERTIFY THAT I AM PROPERLY - REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TH{S PLAT REPRESENTS A SURVEY MA D~ UNDER MY DIRECT SUPERVISION Alk~ THAT ALL DETAILS ARE CORRECT AS OF NOV. 5,{985. ARCO Alaska, Inc. Kuparuk ' SioDe Drilling 'COND~ILT LOCATIONS date' 11'9' 8 5 scale' {": 400' ALASKA OIL AIVD GAS CO#SERVATIOtV ~',O~ttllSSlO~/ RE: Well Lo'c. Permit No. Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.;-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well ~-~hich our records indicated was completed O.~-~--~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please 'submit the above missing material. Sincerely, Chairman ARCO Alaska, ! Post Offic= 60~, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 25, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2F-12 Dear Mr. Chatterton' Enclosed are the 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 GRU7/L72 Enclosure RECEIVED Alaska Oil & Gas Cons, Commisslor~ Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ,~ , ~. ~-~- STATE OF ALASK :- . _:, ALAS~.., " _ AND GAS CONSERVATION ;" - /IISSION ~4:~ ---WEL___L COMPLETION OR RECOMPLETION REPORT AND LOG. Status of Well OIL []XX GAS E~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ARCO Alaska, Inc. Address P. 0. Box 100360, Anchorage, AK 99510 Location of well at surface 214' FNL, 1440' FEL, 5ec,33, T11N, RgE, UN At Top Producing Interval 1343' FSL, 1284' FEL, 5ec.33, T11N, RgE, UN At Total Depth VERIFIED / -7. Permit Number 84-43 ~.API Number 50- 029-21097 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-12 11. Field and Poor Kuparuk River Field Kuparuk River 0il Pool 973' FSL, 1260' FEL, seC.33, T11N, R9E, UM Elevation in feet (indicate KB, DF, etc.) T 6. Lease Designation and Serial No. 5. 125' RKB __--------- A L 25657, ALK 2583 .. _ _ ' . . ched D 14. Date Comp., susp. or kban~l.~-'l-5. Water Depth, if offshore I16-No. of Completions Date Spudded 13. Da.re_T:?. Rea ~ J N/A feet MSL J 1 n4/~0/84 04/16/8q' ~L uw/~u~ ~,-, , ~ _' ...... e~ ,o+ I 21 Thickness of Permafrost u ,. : ........ 'M~D~~°nal Survey I 20. Dept, wneru ....... Total Depth {MD+TVD) 18 _F~_u?~.a.c,~ p [~ 1962 feet MD 22. Type Electric or Other Logs Run DIL/SP/GR/FDC/CNL, CBL/GR/CCL, Gyro CASING, LINER AND CEMENTING RECORD -- 23. CASING SIZE 9-5/8" 7" NT. PER FT. 36.0# 26. O# GRADE H-40 J-55 J-55 SETTING DEPTH MD TOP BOTTOM ~ 110' S;J~t:- I 3224~ HOLE SIZE CEMENTING RECORD~ ~,MOUNT PULLED 225 sx Cold__Set I ! 930 sx AS Iii & 710 sx 8-1/2" 325 sx Class "G" & 250 ~ AS I . _ 25. TUB(NC RECORD ~DEPTH ~ PACKER SET {MD) -- 3-1/2~~ 7121' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. -~EPTH INTER~AMOUNT & KIND OF MATERIAL USED N/A 24" 12-1/4" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number} 7230' - 7300' w/4 spf PRODUCTION TEST 27 N/A Da:'~te First P-~0duction 1 Method of Operation (Flowing, gas lift, etc.) RATIO ~ate of-Tes-~--~ Ho~rs Te~UG~iO-n FO~L-~~ GAS-OIL Press. 124.HOUR RATE ~ I COR~ DATA -- 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAY 3 11984 Alaska 0il & Gas Cons. Commission Anchorage Submit in duplicate Form 10407 Rev. 7-1-80 GRU7/WC22 CONTINUED ON REVERSE SIDE ~:, .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .... · . Top Kuparuk "B" 7161~.: 5918' N/A " ' Top Lower Sand .720~' 595/+' Base Lower Sand- - 7?3, 6071' : . ...... ' ' -. · .. . , . · 31. LIST OF ATTACHMENTS · Drilling History_. Como]etlon Summary.. Gyroscopic Survey ¢2 copies) '. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge : ,/.-/-~,//--- , ......... . __..__ / / ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item !6, and in item 24 show the producing intervals for only the interva! reported in item 27. Submit a separate fOrm for each additional interval to be separately produced, showing the data pertinent to such interval. Item 2-1' 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- lng 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". ARCO Oil and Gas Company Well History - Initial Report - Daily InltllJCtialta: Prepare and submit the "Initial RIl~ort" on the first Wednesday alta! a wall is spudded or workover operations are atadad. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River ICoutlty. parish or borough North Slope Borough Laasa or Unit Title ADL #25657 Drill, Complete & Perforate Istate Alaska · )~el~ no. Auth. or W.O. nO. AFE 901903 Operator ARCO Alaska, Inc. Spudded 4/10/84 2215 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. IARCO W.I. Prior status if a W.O. 56.24% 4/11/84 4/12/84 4/13/84 4/14/84 thru 4/16/84 Signature Oritllng, Pages 86 and 87. 16" @ 110' 750', (750'), Drlg Wt. 9.4, PV 20, YP 24, WL 9, PH 10.5, Sol 9 Accept rig @ 1900 hfs, 4/10/84. NU diverter sys. 2215 hfs, 4/10/84. Drl 12¼" hole to 750' Spud well @ 16" @ 110' 3230', (2480'), Drlg Wt. 9.4, PV 9, YP 12, WL 14.5, PH 9.5, Sol 8 DD & surv 12¼" hole to 3230' 2157', 40.9°, S5E, 1961TVD, 673.23 VS, 671.80S, 55.47E 2654', 40.7°, S3E, 2337 TVD, 998.16 VS, 996.26S, 75.31E 3153', 39.9°, SI-1/2E, 2718 TVD, 1320 VS, 1318.49S, 85.86E 9-5/8" @ 3324' 3343', (113'), Tst BOPE M_x'g X-C Polymer Drl to 3343', 18 std short trip, pmp hi-vis pill, POOH to rn 9-5/8" csg. RU & rn 84 its,. 9-5/8", 36#, J-55 BT&C csg + 1 pup & lnd w/FC @ 3241', FS @ 3322'. Cmt w/930 sx AS III with 1/4#/sx Cellophane flake @ 12.2 ppg. Tail in w/710 sx Cl "G" w/2% S-1 & .2% D-46. Displ w/rig pmps. Bump plug. CIP @ 2215 hfs, 4/12/84. ND diverter sys & Hydrl. NU &tst BOPE. 3293', 39.5°, S1E, 2826.32 TVD, 1409.93 VS, 1407.90S, 87.81E 9-5/8" @ 3324' 7689', (4346'), Drlg Wt. 10.2+, PV 18, YP 12, WL 6.5, PH 9.5, Sol 11 Tst BOPE. RIH w/BHA, tag FC @ 3241', tst csg to 1500 psi. DO FC, cmt, FS + 10' new hole to 3353'. Displ w/8.5 XC Polymer. Conduct formation tst to 12.5 EMW. Drl & surv 8½" hole to 7689'. 3550', 40°, Si-1/2W, 3023.91TVD, 1574.21VS, 1572.23S, 87.10E 4333', 38.5°, S3-1/2W, 3628.20 TVD, 2071.94 VS, 2069.61S, 106.12E 5114', 35.9°, S4E, 4248.40 TVD, 2545.40 VS, 2541.80S, 153.51E 6617', 33.3°, S5E, 5478.00 TVD, 3409.01VS, 3404.42S, 198.41E 7526', 34.2°, S3-1/3E, 6243.99 TVD, 3897.33 VS, 3891.54S, 243.79E .RECEIVED MAY 1 1984 Alaska Oil & Gas Cons. Commission Anchnmge IDate Title 4/25/84 I Drilling Superintendent ,, -, ,,, AR3B-459-1-D Number all dally well history forms cofl~acut{valy as they ~re prepared for each well, no. ARCO' uti and Gas Company '" Daily;Well History-Final Report Inslructlona: Prepare and submit the "Rnll Rfl~rf' on the first Wednesday alter allowable has been illighed or well is Plugged. Ablndonld. or Sold. "Final Rapo~' should be submitted also when operations are suspended for an indefinitie or IcPrecleble length of time. On workoveri when an official tilt il not required uPon completion. ,el:tort completion and representative test data in blocks provided. The "Final Report" Iorm may be used 'for reporting the entire operation if space is available. Accounting coat ~ente, code sts,e Alaska Wall no. 2F-12 Oistrict County or Parish Alaska Lease North Slope Borough Field or Unit Kuparuk River ADL #25657 Auth. or W.O. no. T AFE 901903 Drill, Complete & Perforate Operator I A.R.Co. W.I. · ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Oate Spudded I .4/10/84 Iolal number of wells {active or inactive) on this~ DSt center prior to plugging and / bandonment of this well our Prior status if a W.O. 2215 Hrs. Date and depth as of 8:00 a.m. 4/17/84 4118184 4/19/84 Complete record for each day reported 9-5/8" @ 3324' 7820' TD, (131'), POOH Wt. 10.3, PV 18, YP 12, WL 6.5, PH 9.5, Sol 12 Drl 8½" hole to 7800', 20 std short trip, C&C f/logs. Rn DIL/FDC/CNL/GR/SP,.unable to get past 7142' WLM. Rm · 7100'-7820', C&C, 20 std short trip, C&C f/logs. 7780', 39.7°, SOE, 6446.65 TVD 4049.63 VS, 4043.76S, 248.40E 9-5/8" @ 3324' 7820' TD, (0'), Rn'g 7" csg Wt. 10.2+, PV 11, YP 10, WL 7.4, PH 8.5, Sol 11 Rn DLE/SP/GR/FDC/CNL to 7775' WLM. RIH, rm 7740'-7820', CBU, 20 std short'trip, C&C f/csg. RU & begin rn'g 198 its, 7", 26~, J-55 HF-ERW BT&C csg. 7" @ 7751' ' 7820' TD, 7660' PBTD, RR Wt. 10.2 NaC1/Na~r Fin rn'g 198 its +-2 pups, 7", 26t~, J-55' HF-ERW BT&C csg w/FS @ 7751',. FC @ 7660' M&P 325 Cl "G" w/3% KC1, .8% D-60, .2% .' .-" D-46. Displ w/10~2 NaCl/Na~r using rig pmp, bump plug. CIP @ '' -1400 hfs, 4/18/84% ND BOPE, instl 7" pack-off, NU tbg spool & --g'i;. · ,~..~ ~ ,- . tst pack-off to 3000_ psi. ER @ 1800 hrs, 4/18/8'4. ;: .-L.'=~ :! ~-. . -. 7820' 7660' Released rig Date Kind of rig 1800 Hrs. 4/18/84 Rotary Classifications (oil. gas. etc.) O±l Producing method Flowing Type completion (single. dual. sic.) Stn$1e Official rese~ir name(s) Kuparuk Sands Potential test data Well po_ Date . Reservoir Producing Interval Oil or gasTeat lime Production _ ~ ' Oil on test Gal per day Pump size, SPM X length : Choke size T.P. C.P. Water % - GOR Grevily Allowable Elfsctlve date corrected .. The above is correct ~ ~~ 4/25/84 Drilling Superintendent -see Procedures Manual, Section 10. Orilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history ID,ma consecutively as they are prepared tor each well. no. 2F-12 COMPLETION SUMMARY RU Dresser-Atl as/Sperry-Sun. ND 1 ower tree assembly. Ran gauge ring/JB/CBL/GR/CCL f/7648' - 7100' (WLM); good bond. Ran Gyro f/7600' - surface. NU lower tree assembly. RD Dresser-Atlas/Sperry-Sun. Secured well. Accepted rig @ 0500 hrs, 04/25/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran GR/CCL. Tie-in Vann Guns. Ran 3-1/2" completion assy w/tail @ 7121', pkr @ 7091', & SSSV @ 1962' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel fol'lowed by Kuparuk crude. Pressured tbg to 2000 psi & set pkr. Tstd tbg & pkr to 3000 psi for 15 min. - ok. Dropped bar & perforated the following interval w/4 spf: 7230' - 7300' Flowed well to tanks. Dropped guns. (Geo-Vann fish = 182') Closed SSSV. Bled off pressure above SSSV. Pressured tbg to 700 psi. Opened SSSV. Set BPV. Secured well & released rig @ 2000 hrs, 04/26/84. RECEIVED MAY 119B4 Alaska 0il & Gas Cons. Commission Anchorage GRU7/CS22-tw ARCO Alaska, In Post Office sox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2A-1 2F-11 WSP #6I 2A-2 2F-12 WSP #5 2A-3 WSP #15I WSP #7 Oliktok Pt. #2 WSP #9 Thank you. Sincerely, A~ Engineer JBK/SH1: ih ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany RECEIVED MAY ! 8 Aleska Oil & I~s Cons. Commlssio~ Anchorage ' ~' '~'" STATE Oi= ALASKA ALASK.~-'.,._ AND GAS CONSERVATION (,'-" '""/IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 3. Adc~ess, 0, :BOX 100360, Anchora§e, AK 99510 8. APl Nu1~_21097 50-- 214' FNL,1440' FEL, Sec.33, TllN, R9E, UM 9. Unitor LeaseNameKuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate K~<~F, etc.) I 6. Lease Oesielnation and Serial No. PAD 96', 125' ADL 25657 ALK 2583 I ' 0. WeC, IFN_°i 2 11. Fie. I,d~.a,n d.,Pgol ~,~m Klver Unit KPK River Oil Pool April 84 For the Month of ,19__ 12. Depth at end of month, footage drilled, fishing job.s_dir.ectional drilling problems spud date, remarks Spudded well @ 2215 hrs on 04/10/84. Drl~ 12¼"'hole to 3343'. Ran, cmtd & tstd 9-5'/8" csg. Performed top job. Drld 8½" hole to 7820 TD as of 4/16/84. Ran logs. Ran, cmtd & tstd 7" csg. Displ brine from top of 7" csg. Secured well and released rig @ 1800 hrs on 4/18/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36~J J-55 HFERW BTC csg w/shoe @ 3224'. Cmtd w/930 sxs Arctic Set III and 710 sxs class "G". 7" 26¢J J-55 HFERW BTC csg w/shoe @ 7751 cmtd w/325 sxs class "G". 14N~ing resume and brief description 15. Logs run and depth where run DIL/SP/GR/FDC/CNL f/7775 to 3324 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED MAY ! 81984 Alaska Oil & Gas Cons, Commission AnchoraBe NOTE--RepoM' on~l~ni~/Co/r~n is required for each calendar month, regardless of the status of operations, and must be filed/in duplicate with the Alaska Oil and Gas Conservati~>rf Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H'[LT,/M~141 Submit in duplicate KUPARUK ENGINEERING These prints replace the previous ones sent in January, 1984, please destroy the 91d prints as the elevation numbers were in- ' correct. Date: _ ~'~ 9~ ~V Transmittal~~' ********************************** Date Run _/ / / ! / / DISTRIBUTION NSK Operation Blueline Dr ill ing Bluel ine Geology/L. J. Bi/Se R&D Blue!ine D&M RI e~e ~ Baker Blue. line D.B. Schaf er Blueline G eology/Ken Film Sign & return the attached copy as re. tempt of i-da~'~ j \/ Return to: r',!aska Oil ?, ,..Bas C,",r",s. Commission ARCO ALASK~,,r~,.0rINC. ATTN: D. F~9' A~LISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal KUPARUK ENGINEERING TranSmittal Type of Tape_ Date Tape Number _ DISTRIBUTION Smith OH LIS ~/~gn & return the at~'aUc~d copy as receipt of dat'a~ ".. Return to' ARCO ALASKA ATTN- D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 Please note- Blueline, Sepia, Film, Tape, Photocopy ARCO Alaska, In Post Offic~ ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 11, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2F-12 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG' tw GRU7/L40 Enclosure If RECEIVED MAY 1 5 ],gB4 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~'---'- STATE OF ALASKA ~---. ALASK ~.,~_ AND GAS CONSERVATION MISSION 'SUNDRY NOTICES AND REPORTS ON WELLS 1. DR ILLING WELL [] COMPLETED WELL ;1~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-43 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21097 OTHER [] 4. Location of Well Surface: 214' FNL, 1440' FEL, Sec.33, TllN, R9E, UM 51EIevati0ninfeet(indicate KB, DF, etc.) - 125' RKB 12. I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-12 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check 'Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Welt [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU Dresser-Atlas/Sperry-Sun, ND lower tree assembly, Ran gauge ring/JB/CBL/GR/CCL f/7648' - 7100' (WLM); good bond, Ran Gyro f/7600' - surface, NU lower tree assembly, RD Dresser-Atlas/Sperry-Sun, Secured well, Accepted rig ~ 0500 hfs, 04/25/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran GR/CCL. Tie-in Vann Guns Ran 3-1/2" completion assy w/tail'~ 7121', pkr @ 7091', & SSSV ~ 1962'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk crude. Pressured tbg to 2000 psi & set pkr. Tstd tbg pkr to 3000 psi for 15 min. - ok. Dropped bar & perforated the following interval w/4 spf: 7230' - 7300'. Flowed well to tanks. Dropped guns. (GeoVann fish = 182') Closed SSSV. Bled off pressure above SSSV. Pressured tbg to 700 psi. Opened SSSV. Set BPV. Secured well & released rig @ 2000 hrs, 04/26/84. 14. I hereb hat the foregoing is true and correct to the'best of my knowledge. Signed ( Title Area. Drilling Engineer Conditions of Approvl~, if any: RECEIVED MAY t 1984 Alaska 0il & Gas Cons. Oommis,' Date Approved by COMMISSIONER Form 10403 By Order of the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 GRU7/SN18 and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING -' Well Name: Transmittal DISTRIBUTION NSK Operat ions Blueline Dr ill ing Bluel ine F Oeolb~ B~ tate of AK- retur~.,.~he attached · -. ~'~ copy as recei'~,.~'.~a'~.; , ~,. .... Return to: ARCO A~S~, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING · . Date: Well Name: Transmittal DISTRIBUTION NSK Operation Blueline Dr flling - Blueline Geology/L. J. B1/Se ~.. R&D . Blueline D&M Blueline State Bi/SE F.G. Baker Blueline D.B. Schafer Blueline G eology/Ken Film Sign & return the attached copy as receipt of data. Return to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 MEMOR^NDUM TO: THRU: FROM: Sta e of Alaska ALASKA/%,/iOIL AND GAS CONSERVATION CO~'~-IISSION ' C. V~ ~t~rton ~Al~:April 16, 1984 Chai~ ,~ /- FILE NO:D. 21.12 Lonnie C. smith Co~issioner / TELEPHONE NO: ilarold R. Hawkins Petroleum Inspector SUBJECT:witI~eSS BOPE Test ARCO Alaska, Inc. Kuparuk River Unit 2F-12, Sec. 33, TllN,R9E,Ob'I, Permit No. 84-43. ~, April 13, 1984: I left Oliktok Point, subject of another report, to AF. CO's Kuparuk River Unit 2F-i2, to witness a BOPE test. I witnessed the BOPE test on ~P, CO's Kuparuk River Unit 2F-12 well. ! also witnessed the flow line indicators and alarm function tests. There was one failure. i filled out an AOGCC report which is attached. In s~ary, I witnessed the BOPE tests and the mud flow line indicators function test, on Parker Rig No. 141. ARCO is to notify our office ~nen the one failure, the inside kill valve is repaired or replaced and tested. Attachment: April 16, 1984 Chuck Downey, operator for ARCO informed Bobby Foster by phone, that the inside kill valve was replaced and tested okay. flg_~lhl t'-t~,~au lh17(~% O&G N 4 .4/8o STATE OF AI.ASKA ALAS?~\ OIL & GAS CO;~SE}{VA'FIO[I COHHISSION 13.0.P.E. Inspection Report Inspector Operator .Z/~ D~ill±n9 Contracto Representative ~Casing Set Rig ~/~/ Representative. ..................... Location,-General Well Sign General Housekeeping ReseJve pit Rig ACCUt%ULATOR S'YSTEH BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Full Charge Pressure..,~OG° ps.ig Pressure After Closure. / ~-~ psig 200 psig Above Precharge Attained: ~-- miAmi"sec Full Charge Pressure Attained: ~ mia- sec ,' N 2 ,2~_ ~ ~ ~' 2 3~Oj, .2, ~,,,.2 g' ~ ~ ps ~9 Cqntrols: Master Remote Blinds switci] cover Test PressureI _ Kelly and Floor Safety_Valves Upper Kelly. Test Pressure Lower Kelly. Test Pressure Failures Ball Type Test Pressure Inside BOP Choke Manifold Test Pressure ~ Test Pressure. No. Valves ~ I4o. flanges...,~ ~ .' Adjustable Chokes ~/~- ~-1~ llydrauically operated choke ~</~c Test Time ~-'-~:. .... hrs.. 20 Repair or Replacement of failed equipment to be made within ~. days andz'' Inspector/Comm/ssion office notified. ~C,4~,~' .././{~,~.. ,r'/9~,~-/: po~,,-,'~V Mf?:~, o?~MbzO,,~) IY'f'~,Z t)A~z~ ~.',~_: /~:~ ~a TZ~T~P o/f,. F4°~ xz~. /~o/nb~ .~/~ ~a X"~:~-/f~D Distribution orig.' - AOgGCC cc - Operator cc - Supervisor. ARCO Alaska, In~''~ Post Office...,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-12 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on May 15, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Ar~ Drilling Engineer JBK/GRU6L52'tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -" ALASK,-. O~L AND GAS CONSERVATION CO,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-43 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21097 4. Location of Well Surface: 214' FNL, 1440' FEL, Sec.33, TllN, R9E, UM 5. Elevationinfeet(indicate KB, DF, etc.) 125' RKB 12. I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) X] Alter Casing [] Perforations [] Altering Casing [] Perforate Stimulate [] Abandon [] Stimulation [] Abandonment [] RepairWell [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports? 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The! subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: May 15, 1984 Subsequent Work Reportecl pate~ ---/---/"- oa ¥o~n No. ~ 14. I hereby certi, pc~at the foregoing is true and correct to the best of my knowledge. // Signed /'~.~4.~¢3 V_ ~,/- .~2,,r¢4,4,~,~'~ Title The space bel~ ;¢G~//~on use Conditions/of Approv~lcff any: Date Approved by daqOproved Copy --Returned By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 6RU6/SN25 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March 28, 1984 Mr Jeffrey B Kewin Arem Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re:' Kuparuk River b~it 2F-t2 ARCO Alaska, Inc. Permit No. 84-43 Surf. Loc, 214'~,-1440'FW~, Sec,33, TllN, R9E, t~. Btmhole Loc. 961'FSL, 1309'FEL, Sec.33, TI.I_M, R9E, b~,~. Dear Mr. Kewin: EnclOsed is the .approved revised application for permit to drill the above referenced Well. The provi~ion~ of the cover letter, dated March P.O, 1984 accompanying the original approved permit are in effect for this revision. V~ry truly yours, Enclosure .cc: Department of Fish & Game.., Habitat Section w/o encl. Department of En%~ronmental Con~ervation w/o enc!. ARCO Alaska,~ Inc. Post Office Bo.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 lqarch 22, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-12 Dear Mr. Chatterton: Due to a change in the bottomhole location, we are resubmitting the application for Permit to Drill Kuparuk 2F-12. Enclosed are: o A diagram showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system o Diagrams and description of the BOP equipment Since we estimate spudding this well on April 10, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. JBK/JG6L47: tw Enclosures RECEIVED 2 1984 Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ? a. Type of work. ~rator ARCO Alaska, Inc. ~. Address "' STATE OFALASKA ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] REDRILL [] DEVELOPMENT OIL DEEPEN J~] DEVELOPMENT GAS P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 214' FNL, 1440' FEL, 5ec.33, TllN, R9E, UM At top of proposed producing interval 1382' FSL, 1322' FEL, Sec. 33, TllN, R9E, UM At total depth 961' FSL, 1309' FEL, Sec. 33, T11N, R9E, UM 5. Elevation in feet {indicate KB, DF etc.) ] 6. Lease designation and serial no. RKB 125', PAD 96' ADL 25657 ALK 2583 12. Bond information (see 20 AAC 25.025) ~ompany Type Statewi de Surety and/or number #8088-26-27 ~i-3~e and direction from nearest town I 14. Distance to nearest property or lease line 30 mi, NI// of Oeadhorse miles ~ 961' (~ TD feet ?6. Proposed depth (MD & TVD) j~ 17. Number-oT~c-~es ~n ~ 7827' MD, 6480' TVD feet 2560 19. If deviated (see 20 AAC 25.050) I20. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 38 o (see 20AAC25.035 (c) (2) 21 ~ Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH SINGLE ZONE j~STRATIGRAPHiC MULTIPLE ZONE ~ 9. Unit or lease name Kuparuk River Unit ~ number 2F-72 Kuparuk River Field Kupa~uk River 0i] Poo] Amount ,$500,000 ~ance to nearest drilling or completed ~' ~ surface feet 18. Approximate spu----~ dat~ 04/10184 - psig@--8-Q~_F~ Surface .. 30__~84 __psig@_6095__ft. TD (TVD) Weight 26. O# QUANTITY OF CEMENT Length MD TOP TVD MD BOTTOM TVD (include stage data) ~ 930 sx AS III & HF-~ ~ 7827'16480, 425 sx Class G neat I 22. Describe proposed program' -- !ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7827' MD (G480' ~TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. I The 9-5/8" casing will be set through the West Sak Sands at approximately 3242' MD(2845, TVD). A 13-5/8", 5000 ~psi, RSRRA BOPE stack wil? De installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2748 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 we~l will be completed with 3-1/2',, 9.2#, 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 ce~~t the foregoing is true and correct to the best of my knowledge I S~GNED . The space byfo%~-'~--~-- TITLE Area Drilling Engineer DATE Samples required []YES · APPROVED Form 10401 CONDITIONS OF APPROVAL Mud Icg required Directional Survey required ~er ~YES ~O ~L~Es E3NO Approval date /5~~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order, of the Commission Submit in triplicate PERMIT TO DRILL 2F-12 installed and tested upon completion of the job. 2F-12 will be 60' away from 2F-11 at the surface. Also, 2F-12 will be 92' away from 2F-14 at 1630'MD (1440'TVD). At the actual crossing, there will be ±169' of vertical distance between the two wells with 2F-12 crossing over 2F-14. With our normal drilling practice of leading the well to the left, these distances should increase and pose no problem at this shallow depth. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6343'MD, approximately 800'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. : I ~ .... : ~ . ~ ' - ~, ~ ., ~ - ~,. , m~. ~ : ~ I · _ . . : ~ ,, Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter, 20" 2000 psi drilling spool w/lO" side outlets. $. 10" ball valves~ hydraulically actuated, ~/10" lines to reserve pit. Valves to open aut.omatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. 4 i I Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify 6hat ball vaJves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid 'flo~ to surface is detected. )f necessary~ manually override and close ball valve to upwind diverter line. Do not shut in ~ll under any circumstances. 1 6" Conductor ANNUL~ 9 PI~ ~.AMS BLIND DIAGRAM fl 13-5/8" 5000 PSi RSRRA BOP STACK 1. 16" - 2000 psi Tanked s%arting heaO 2. 11" - 3000 psi casing head 3. I1" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drillin9 spool 5, 13-$/8' - 5000 psi pipe rams 13-5/$" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 13-5/8" - 5000 psi blind rams 13-S/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITW HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITI4 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI RISMAINING PRESSURE. · 13-5/,8" BOP S*i'ACX TEST 1. FILL BOP STAC): AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECX THAT ALL HOLD DOWN SC2EWS ARE FULLY RETRACT- kD. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEA/). RUN IN LOCX DOWN SCREWS IN HEAD'.- 3. CLOSE ANNULAR PREVENTER AND 'V'.AJ~'V]~$ TLJl~~ 01: C}-IO~S. F.S 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD'FOR 10 MINUTES. 5. INCRFrJkSE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEEI) TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 8. ~'Pt~BSSL)A~ Z)O~~ 01~ CI-D~ ISOISk?TON VAL.V~S. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEF. D TO ZERO PSI. 11. OPEN BOll'OM Sc'T OF PIPE P. AMS. BACK OFF RUNNING JOtNI AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST-~O 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE ~tANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SiGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- Hatch '~ O, oe~re7 B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2F-12 ARCO Alaska, Inc. Pe~-nnit No. 84-43 Sur. Loc. 2!4'~, ]440'FEL, Sec. 33, TI]~I, R9E, Btmho!e Loc. !!36'FSL, !3!4'FEL, Sec. 33, TI!~.~, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill, the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of ~e]l. cuttings_ ,~. and a mud log are not required. A continuous directional, survey is recuirad. ~ as pe~.. ~0~. 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 spa~wning 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 I~, Alaska Administrative Code, Chapter 70) and by the Federal lTater Pollution Control Act, as amended. Prior to commencing operations you may be contacted bva representative of the Department of Environmental Conservation. To a~d us in ~chodul~ng~.~-_~,.~.~,_. work please nmri hours prior to conmerming i~stal!at'ion of the b!r:~out r~re~.ront~on !~. jeffrey B. K~in Kuparuk River Unit 2F- 12 March 20, 1984 !~9uz~ment so that a representative of the Commission may be pre~ent to witness testing of the equlpm~nt before the ~urface casing shoe is drilled. ?acre a dfverter s~stem is requ~.red, please a!~o notify thim office ~4 ho~r~ prior to com~anclng equipment !nstallat~on so that the Commission may w~tnes$ testing before drilling below the shoe of the conductor ~ipe. In th~ event of suspension or abandonment, please give this office adequate advance not!ficstton so that we may have a w~tness presemt. Va~ t~aly your~, Chai~an of Alaska Oil and Gas Conmervation be Eno lo,ute cc: Department of Fish & Game, Habitat Section w/o encl. De~partt~ent of EnVironmental Conservation. w/o encl. ARCO Alaska, Inc. ~ Post Office B(~_~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 13, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-12 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2F-12, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on April 16, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, · 1 A ing Engineer ~,~,R ! '~ ~;'~..v84' JBK/JG6L32' tw Alaska Oil & Gas '-~-- ~,,_J~ s. L;oml~JssJort Anchorage Enclosures ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA ALASKA OTC AND GAS CONSERVATION COr,,,-WllSSION ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 214' FNL, 1440' FEL, Sec.33, T11N, RgE, UM At top of proposed producing interval 1382' FSL, 1322' FEL, Sec. 33, T11N, RgE, UM At total depth 1136' FSL, 1314' FEL, Sec. 33, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 125', PAD 96' I ADL 25657 ALK 2583 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 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1136' ¢TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7545' MD, 6253' TVD fe~.t 2560 19. If deviated (see 20 AAC 25.050) 12o.Anticipated pressures KICK OFF POINT 500 fe~t. MAXIMUM HOLE ANGLE 38 oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program 9. Unit or lease name ~ Kuparuk River Unit 10. Well number 2F-12 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 2F-11 Well 60' @ surface feet 18. Approximate spud date 04/16/84 2748 psig@ RO°F Surface 3084 .psig@ Rf~c)5 ft. TD (TVD) SIZE Hole Casing ~4" 16" !12-1/4" 9-5/8" B-1/2" 7" Weight 65.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 / Weld J-55 HF-IRW BTC J-55 / BTC I 7517 HF-ERW / I SETTING DEPTH MD TOP TVD 80' 29' I 29' 1 3213 29' 29' I I 28' I 28' MD BOTTOM TVD 109'11 109' 3242'I 2845' I 7545'16253' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 930 sx AS III & 710 sx Class G 425 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7545' MD (6253' 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 3242' MD(2845' 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 (1800 psi for annular). Expected maximum surface pressure is 2748 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 with 3-1/2", 9.2#, 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 certi~ that the foregoing is true and correct to the best of my knowledge Thespaceb. b.b~ ~~sio~-use ' ' CONDITIONS OF APPROVAL Samples required ~]YES /~0 Permit number APPROVED BY~ ',,_ zy-L Form 10-401 GRU6/PD14 Mud log required ~]YES J~INI O Approval date Directional Survey required I APl number ~YES E]NO I 50-- ~ 'L~ - SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 20, 198h by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-12 installed and tested upon completion of the job. 2F-12 will be 60' away from 2F-11 at the surface. Also, 2F-12 will be 92' away from 2F-14 at 1630'MD (1440'TVD). At the actual crossing, there will be ±169' of vertical distance between the two wells with 2F-12 crossing over 2F-14. With our normal drilling practice of leading the well to the left, these distances should increase and pose no problem at this shallow depth. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6343'MD, approximately 800'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. t I ] · ~ , ~ . ~ ', . ~, _ ~ I . , i i i ~[] '11 I . . . ',i~ . . i ~ . , . . . ...... i . , -'i'?/7---7 ...... -_T7, ........ :,--'3~¥-T~--__.-:-: ~ -~'~. i: ~ii ii, ' T .............. ' ........ ~ ......... F ........ ' ..................... ~ .... :-~ ~ ' ~ i -~-~- --: i : , ' i : : ~ ~ · I · -. , ', , · -.i,:,, -. I . _.: _ ._ : : , : i ! I ..~=~.~_~_~__ ~ i ! : ~ i : ! ', , ~. , ~ ; i ~ . : ! : : I ~ ; ! ; ....... .... I- ...... ..... : .......................................... ...... ..................... ---~---- ---~ ¢,~ ~ZlO~~,, i ', i ! ! ~ ! i ~ , ' :' i ~ !' :I ~ ! , ............................. ? ............. ~ ~- : ~ ~ , ~ '- '. . I : ! ~ ' ~ ~ : : ~._' ........... ;L;X ..... ~__-~_~ .......... L_~_ __._~".__..- .i ' ~ .-~, ~ ~" ~ : ~ '- i ~ ! i , i i ! i : i : i i iii ~7T~--' .......... ~-'Y' ......... ~ .... ~- ..... -'I,~~ ! i : -! :, i I : ! i ~ : i ~ ! ~ ! ! i i i~~i ' ! i i i i ¢ i i ! ,: ~ i- ..........J[ _._:_ .....X_~; .... -!'--':'~-L ..... ........ --] :. :' 4-~-~ ~.,'i$1'.,,-z") '. : :i i.TM : i iii :i -~, ;----! i ~! ' : ~ ¥,ii,,j._ : i ! L ~","'! i '~ ....... L'--:-][ ..... ::x~:_-,.-:-!-?-- L '. ! I iii ~ .- _,,,;.~i i i~: ~i-,' i~ :. ~i ~ i ii! .............................. -:- ~'i~-: ....... , , ,.,.~- :. , , , ~ , ..... : ~ ; : i ? --~ ' - -'l~f-F ..... ~- ........... 7 ..... ~-"-- ~ -~- '~i [ i i 71 : · ; 'i i i i ; i ~ i ' ' ..... ' ' ?'~,,I. I ' , ,I , : ' i I ' ' ' ' ' ' ~-' .......... ' ' ' --~-' : ' : ' "- i i : , , , , , ~ . --~-- .... ~ .-..-~ -- - . , . -} ~ . ~ : . : , , ' : 7--'-' --~-,,'--T ' !-~----- ' ~ ~ i ' ~ 1 . , , , , : : , , ~ ; ~ . _ _~__._'_.. ~ ~_,'__~_~_~_ __: ; .. ~ _ .. :.1.~., ~ , , ~ ; ........... ~i~i~FT ............ ? --~ .... t-?~-; ...... ~-.,-4-' --~,~-r ~ ' ' - -i _~Jl ....... -'-li~lj~ ' .1 I '- . . , ~ ' ' i ' , . i '. : '. ] ~, ~ .... ~ : i ;,' ' ' ----' '--7--'---- --~' ' ~-' ! ' ~ ! ~ ' ? ' ~ : ~ i I ..'% i ' i i ; ! : '' ,, i: ~1i i.~. il~ ill iii ~-:------::~ ii+ -7'i,!i ~i i-~ ~ ~ i x ~i ' , " ....... ' ~ i ~ ,' . ' : : ! ~,? .... i i : ; ' ~ , i . ! i ~, : ~ .~ __ _.~ ~ .... ~___ ~_ ___~_.. ~L_ ' ~ ~ ~ ! ~ ~ ~ ~ ...... ; c. .... i!i " ' : ..... ' ' ~ ' '~' ~ i i ~ : I '. ............................. ...... : 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 & Ooeration 1. Upon initial installation close annular preventer and verify 6hat 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 IANaULAR 9 PIPE BLIND r; DIAGRAM ~1 12-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x ].3-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x ].3-5/8" - 5000 psi drilling spool 5. [3-5/8' - SO00 psi pipe rmms 6. 13-5/8" - 5000 psi drilling spool w/choke and kill 1 i nes 7. ].3-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '~. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER L[VEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH ].SO0 PSI DOWNS'FREAM OF THE REGULAT43R. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORO THE TIME AND PRESSURE REMAINING AFTER ~ UNITS ARE CLOSEO WITH CHARGING PUMP OFF. 4. RECORO ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REI~AINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD Will4 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE'FRACT~ ~. PREDE'I'ERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELL~EJ)O. · RUN IN LOCX DOWN SCREWS IN HEAD. · 3. CLOSE ANNULAR PREVENTER AND VALI/~S UPS~ 01: C HOI{~S. DON'~F TEST AGAINST CLO~AaoC~o-~L~.FOR lO 4. TEST ALL COMPONENTS TO 250 PSI MINUTES. 5. INCREASE PRESSURE TO ].800 PSI AND HOLE FOR 10 MINUTES. BLEiD:) TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR i0 8. ~'i:'RB$DdI~ DOWN~_ OF C:[-'D~ ISOLA?TON VJ~,I.,.'V']~$. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTES,T~D MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. ].0. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. ].1. OPEN BOI-FOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPF_N BLINO RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCX.S AND INSIDE BOP TO 3000 PSi WI.TH KOOMEY PUMP. 1S. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. I6. PERFORM COMPLETE BOPE TEST/01~CEiA WEE'XiiAND FUNC- TIONALLY OPERATE BOPE DAIL~f:. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ("2 thru 8) (~. thru 1 ~-)- '-- (10 an~d 11) Casg (12 thru 20) (5) BOPE ~ ..?-o2~-~9t (21 thru 24) (6) Add: Company 1. Is the permit fee attached .......................................... me 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Lease & Well No. YES Is well to be located in a defined pool ................ ~... . Is well located prOper distance from property line ...... Is well located proper distance from other wells ....... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included .. Is operator the only affected party ................................ Can permit be approved before ten-day wait ........................... Does operator have a bond in force ...................................... Is a conservation order needed .. .................................... ts administrative approval needed ................................... Is conductor str±ng provided .................................... Is enough cement used to circulate on condugtor a~d su~fac~ .. Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ......... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to 3~rD psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. NO Additional requirements .............................................. ~ REMARKS Additional Remarks: ff £pRm9~ ~ c) ~Z ~ 0 Geology_: Engi!k~ ering: HW~ K LCS ,,'--( ~EW WVA ~ JK .~~HJH ~ JAL ('/,,.,/_:__ MTMV / rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~ //~'~'{ ITEM APPROVE DATE YES NO REMARKS (2 thrm'8) (8) (3) Admin f~)~-~ % "/f'f i/ (,9 thru 11) (10 and 11) (4) Casg t~2 thru 20) (5) BOPE (21 thru 24) l. IS me 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. the permit fee attached ......................................... Is well to be located in a defined pool ............................ Is well located proper distance from property line .. . Is well located ~roper distance from other wells .... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included .. . Is operator the only affected party ................................ Can permit be approved before ten-day wait .... Does operator have a bond in force ................................... Is a conservation order needed .. .................................... ,':.~,- Is administrative approval needed .................... ............... ,:':"~' Is conductor string provided ..................................... Is enough cement used to circulate on co;dugtor a~d surface .. .~/$ Will cement tie in surface and intermediate or production strings ,.. Will cement cover all known productive horizons ..................... ,~ , ,, Will surface casing protect fresh water zones ....................... ~' Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~;I~' Are necessary diagrams of diverter and BOP equipment attached ....... ~'/~ Does BOPE have sufficient pressure rating - Test to ?z~-~'D psig .. ~F~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: .+,~.~L~, ":"',/~",S cf 25. Additional requirements ............................................. Additional Remarks: Geology: Engiqeering: HWK ~ LCS ~ BEW ~, WVA , JAL ~ JKT~JH ~'r~ ., rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ]'.,TS ATE I~410,4120 ERV?C~ ~A~E : ATE : RFVIO{'$ FTL~ 'N : ~UPARUW EC~: 33 '0UN: UNTT TYmE CAT~] $I~R CODE 000 000 016 06'5 000 000 005 065 000 000 005 065 000 000 002 065 000 0o0 004 065 000 000 002 065 000 000 008 0~5 OhO 000: 006 065 000 000 004 065 ************************************************************************************ SC I~I, U~.~ t~; L,~ C [-", ~ * ~,.L/~SI(A cr~,~!PU'rING CEr,!TEP E~,L = 2~-12 I RL, F, = K !IF'~'I~F, T~TF = AT,~SK~ Og ~T~"BWR ~T aCC: 6o~143 L!~: ~l, hATE LnGC~ED: 17-~P~-~4 Dp: U~H EWSTTY ISC.STTY H 9.695" i~ 3~24' - t:~Tv' SIZE = R.5" Tn 7870' X-C PO, l,V !~R 1. O.~ T.,~IG R~ = ].310 m~ 75,0 DF 37,n $ ~' : 3.710 ~ 75.0 DF c).5 ~C : ~B.130 ~ 75"0 DF 6,5 C~ R~~ ~T BF~T : 1.797 ~ t44.0 DF A?RTX ****************************************************************************** A?Uu .~.pRCTF?C~TTO~'.! qbDC~<$ NF.M SWRVICF. ..q. FRVIC. E'. lJi.{?T EPT PT R t~IL ~APl ~Dw WON C~;l,, ~DN AL1 ~g~' N~ ~.~ ][ APl APl LnG TYP~ rb~ss o n 0 '7 O, 0 7 1~ 46 7 0 0 7 ! 0 42 68 2 ~ 2 ~ ~ 0 42 ]5 1 42 34 q2 42 3~ 93 42 42 1 42 0 0 42 31 32 CODE 66 73 65 66 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SI 1 Z~ PROCESS ~A~PLE 4 0 4: 0 4, 0 t 4, 0 1. 4 0 4 0 1. 4 (1 4 0 .1 4 0 4 0 CODE 68 6~ 6~ 6m 6~ 6m 6m 68 68 6~ 68 6~ 6~ 'EPT ;P )EPT IRA T 6.12~9 3,141~ 'ILO I 3,52 ~PNI . :oooo 6914 3.1445 13,~0234 NPI-II~ O0 FCN[. 563:' &.69~ 4 ~R 90,7 5 0 2,3159 95,3613 84,1.250 13,5234 9,4668 44.~777 413.7500 I06,1250 ORHO CALI DRMO CAL! 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