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Home My WebLink About181-194STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3A-09 JBR 02/21/2023 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:2 Tested with 2-7/8", 3-1/2" and 7" Jt's. HCR Choke F/P greased and retested good. 7" x 3-1/2" XO failed to test twice before torqued correctly to pass test on LPR and Dart valve. 11 Accumulator bottles with 1000psi precharge. The XO is below the Dart valve, this is why I called it a F/P. Test Results TEST DATA Rig Rep:Tony Morales/Jim MarOperator:ConocoPhillips Alaska, Inc.Operator Rep:Mark Adams/Kevin Barr Rig Owner/Rig No.:Nabors 7ES PTD#:1811940 DATE:1/5/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopKPS230106093755 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8.5 MASP: 2709 Sundry No: 322-670 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 1 FP 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8" x 5" V P #2 Rams 1 Blinds P #3 Rams 1 7" Fixed P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"FP Kill Line Valves 2 3-1/8" & 2"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3000 Pressure After Closure P1400 200 PSI Attained P15 Full Pressure Attained P122 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@1980 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 P27 #1 Rams P5 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 FP FP Tested with 2-7/8", 3-1/2" and 7" Jt's. HCR Choke F/P greased and retested good. 7" x 3-1/2" XO failed to test twice before Tested with 2-7/8", 3-1/2" and 7" Jt's. HCR Choke F/P greased and retested good. 7" x 3-1/2" XO failed to test twice before torqued correctly to pass test on LPR and Dart valve. 11 Accumulator bottles with 1000psi precharge. The XO is below the Dart valve, this is why I called it a F/P. 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 feet 5736'feet true vertical feet 5688', 5729', 6072', 6124', 6150', 6200' feet Effective Depth measured 5736'feet 5685', 5815', 6028'feet true vertical 5734'feet 5683', 5813', 6025'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80/J-55 6039' MD 6036' TVD Packers and SSSV (type, measured and true vertical depth) 5685' MD 5815' MD 6028' MD N/A 5683' TVD 5813' TVD 6025' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2165' 2165' Burst Collapse Production Liner 6397' Casing 6421'6424' 2135' 112'Conductor Surface Intermediate 16" 10-3/4" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-194 50-029-20699-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 0025631 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3A-09 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 112' ~ ~~ Well Remains Shut-In ~~ ~ 322-670 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: Baker FH Packer Packer: AVA RHS-XL Retrvbl Packer Packer: Baker DB Retvbl Packer SSSV: None Jonathan Coberly jonathan.coberly@conocophillips.com (907) 265-1013Staff RWO/CTD Engineer 5992-6005', 6082-6100', 6107-6147', 6172-6178' 5989-6002', 6079-6097', 6104-6144', 6169-6175' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 6430' 6427' By Samantha Carlisle at 1:21 pm, Feb 10, 2023 Page 1/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/3/2023 13:30 1/3/2023 19:00 5.50 MIRU, MOVE MOB P 1:30 off 3A-08 moving to 3A-09. Clean up around 3A-08. Hang tree and stage wellhead equipment in cellar. Spot sub over 3A-09. Set mats and spread herculite. 1/3/2023 19:00 1/3/2023 21:00 2.00 MIRU, MOVE MOB P PJSM w/ Curz and rig crew on spotting pits. Spot pits up to sub. Set mats and spread herculite. 1/3/2023 21:00 1/3/2023 23:00 2.00 MIRU, MOVE MOB P Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Complete acceptance checklist. Get measurements for riser height from tubing spool height. Begin taking on 9.8 PPG NaCl into pits. 1/3/2023 23:00 1/4/2023 00:00 1.00 MIRU, WELCTL COND P Take on 9.8 PPG NaCl into pits. Build 50 Bbls deep clean pill & 20 Bbls hi-vis pill. Rig up circ manifold in cellar. . Take initial pressures T/IA/OA. . Bleed free gas off TBG/IA. Kill Well. 1/4/2023 00:00 1/4/2023 02:30 2.50 MIRU, WELCTL COND P Take on 9.8 PPG NaCl into pits. Build 50 Bbls deep clean pill & 20 Bbls hi-vis pill. Rig up circ manifold in cellar. . Take initial pressures T/IA/OA. . Bleed free gas off TBG/IA. Kill Well. 1/4/2023 02:30 1/4/2023 03:00 0.50 MIRU, WELCTL PRTS P PT circ manifold and tiger tank lines T/ 3000 PSI. Check initial pressures: OA=0, IA=45, TBG=75 1/4/2023 03:00 1/4/2023 05:00 2.00 MIRU, WELCTL KLWL P Bleed free gas off of IA. Bleed free gas off of TBG. Fluid gas mix bleed pressure down T/ 20 PSI TBG/IA. Pump 42 Bbls deep clean pill @ 4 BPM, 350 PSI. Pump37 Bbls hi-vis pill @3.5 BPM, 330 PSI. Pump 250 Bbls 9.8 PPG NaCl @ 4 BPM, 525 PSI. While holding 100 PSI back pressure at choke skid. 1/4/2023 05:00 1/4/2023 06:00 1.00 MIRU, WELCTL OWFF P OWFF no flow 1/4/2023 06:00 1/4/2023 07:00 1.00 MIRU, WELCTL RURD P Blow down lines to kill tank and cellar lines 1/4/2023 07:00 1/4/2023 07:45 0.75 MIRU, WELCTL MPSP P Pick up t-bar set HP BPV 1/4/2023 07:45 1/4/2023 08:15 0.50 MIRU, WELCTL PRTS P Test under BPV to 1000 PSI for 10 minutes. 1/4/2023 08:15 1/4/2023 08:45 0.50 MIRU, WHDBOP SVRG P Service rig 1/4/2023 08:45 1/4/2023 09:15 0.50 MIRU, WHDBOP RURD P RD test equipment and blow down lines form testing. LD T-bar. Bleed off adapter void verify 0 PSI on IA. 1/4/2023 09:15 1/4/2023 10:45 1.50 MIRU, WHDBOP NUND P N/D tree and adaptor spool. Inspect hanger neck threads Install tree test dart. 1/4/2023 10:45 1/4/2023 15:00 4.25 MIRU, WHDBOP NUND P NU BOPS set 2 X-O spools to accommodate the 7" testing set bop stack torque and install riser. 1/4/2023 15:00 1/5/2023 00:00 9.00 MIRU, WHDBOP RGRP P Start BWM open ram cavities, inspect and document. install 7" rams in lower position. 1/5/2023 00:00 1/5/2023 00:30 0.50 MIRU, WHDBOP RGRP P Complete BTW. No deficiencies identified. 1/5/2023 00:30 1/5/2023 01:30 1.00 MIRU, WHDBOP RURD P R/U testing equipment. M/U 2 7/8", 3 1/2" & 7" TJ's. Fill stack with fresh water. Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 2/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/5/2023 01:30 1/5/2023 02:00 0.50 MIRU, WHDBOP PRTS P Shell test BOPE. 1/5/2023 02:00 1/5/2023 10:15 8.25 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular & UVBR's w/ 2 7/8" test joints. Tested UVBRs w/ 3 ½ test joint. Tested LPR w/ 7 test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1400 PSI, 200 PSI attained =15 sec, full recovery attained =122 sec. Annular= 27 sec. UVBR's= 5 sec, Simulated blinds= 5 sec. Simulated LPR= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1980 PSI. Test gas detectors, PVT and flow show. Test witnessed by AOGCC rep Kam StJohn. 1/5/2023 10:15 1/5/2023 10:30 0.25 MIRU, WHDBOP BOPE T HCR choke failed initial test. Greased and functioned. Passed retest. 1/5/2023 10:30 1/5/2023 11:30 1.00 MIRU, WHDBOP RURD P Blow down all surface lines and choke pump out the BOP stack. RD from testing BOPE, RU floor to pull tubing, PU T-bar. 1/5/2023 11:30 1/5/2023 12:15 0.75 MIRU, WHDBOP MPSP P Pull 3" CIW HP dart and BPV. 1/5/2023 12:15 1/5/2023 13:00 0.75 COMPZN, RPCOMP PULL P MU landing joint to hanger BOLDS. PUW=60K weight did not break back. Pull hanger to floor, LD hanger and landing joint. 5,632.0 5,604.0 1/5/2023 13:00 1/5/2023 13:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 5,604.0 5,604.0 1/5/2023 13:30 1/5/2023 18:00 4.50 COMPZN, RPCOMP PULL P LD tubing F/5604 T/ 2294', PUW=60K. 5,604.0 2,294.0 1/5/2023 18:00 1/5/2023 19:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Work on 2 7/8" hand slips. 2,294.0 2,294.0 1/5/2023 19:00 1/5/2023 21:45 2.75 COMPZN, RPCOMP PULL P POOH w/ 2 7/8" completion F/ 2294' T/ surface, PUW=38K. 173 joints and 10.81' cut joint. Clean chem cut. 2,294.0 0.0 1/5/2023 21:45 1/5/2023 22:15 0.50 COMPZN, RPCOMP CLEN P Clear pipe shed and rig floor. Break hanger off of landing joint. 0.0 0.0 1/5/2023 22:15 1/5/2023 23:15 1.00 COMPZN, RPCOMP RURD P R/D tubing equipment. Mobilize BHA #1 to rig floor and pipe shed. 0.0 0.0 1/5/2023 23:15 1/5/2023 23:30 0.25 COMPZN, RPCOMP SFTY P PJSM w/ Baker and rig crew on picking up BHA. 0.0 0.0 1/5/2023 23:30 1/6/2023 00:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 Overshot T/ 74', SOW=31K. 0.0 74.0 1/6/2023 00:00 1/6/2023 00:30 0.50 COMPZN, RPCOMP BHAH P Cont M/U BHA #1 Overshot F/ 74' T/ 208', SOW=38K. 74.0 208.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 3/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/6/2023 00:30 1/6/2023 05:00 4.50 COMPZN, RPCOMP PULD P PUDP w/ BHA #1 F/ 208' T/ 2261', PUW=65K, SOW=65K. Took 10K string weight @ casing patch. Kelly up rotate @ 8 RPM, 1K free Tq. ROT=65K. Worked through top of patch w/ rotation. Cont PUDP F/ 2261' T/ 3900', SOW=90K. 208.0 3,900.0 1/6/2023 05:00 1/6/2023 06:30 1.50 COMPZN, RPCOMP PULD P Cont RIH F/ 3900 T/5602' PUW=115K SOW=115K, 3,900.0 5,602.0 1/6/2023 06:30 1/6/2023 07:00 0.50 COMPZN, RPCOMP FISH P PR=3BPM 300 PSI Engage top of tubing stump at 5631' Set down 10K DP=400PSI Set down 20K worked seals down to 5637 W/20K down. PUH to 5613' Pressure fell back to 200 PSI seals released from PBR. PUH to 5598' 5,637.0 5,598.0 1/6/2023 07:00 1/6/2023 07:45 0.75 COMPZN, RPCOMP CIRC P Circulate BUS at 5BPM condition well. 9.8# NaCl In and out. Shut down pump bleed off DP. 5,598.0 5,598.0 1/6/2023 07:45 1/6/2023 08:00 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 5,598.0 5,598.0 1/6/2023 08:00 1/6/2023 08:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Grease IR & draw works 5,598.0 5,598.0 1/6/2023 08:30 1/6/2023 10:30 2.00 COMPZN, RPCOMP TRIP P Start TOOH F/5598 T/ 208', PUW=115K 5,598.0 208.0 1/6/2023 10:30 1/6/2023 12:30 2.00 COMPZN, RPCOMP BHAH P Stand back collars and L/D BHA, cut joint and seal assembly. F/ 208', PUW=38K. 208.0 0.0 1/6/2023 12:30 1/6/2023 13:00 0.50 COMPZN, RPCOMP SVRG P Service rig. TD & Blocks 0.0 0.0 1/6/2023 13:00 1/6/2023 18:00 5.00 COMPZN, RPCOMP ELNE P RU E-line and RIH W/CBL to top of patch set down at patch Work down to DV collar at 2710' Eline depth. Unable to get any deeper. Sent draft log from down pass to town. POOH W/E-line to surface. On surface at 4:15. Stand back E-line and start processing data. Gool log showing TOC Q@1650'. R/D E-line. 0.0 0.0 1/6/2023 18:00 1/6/2023 18:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 7" G plug T/ 20', SOW=30K. 0.0 20.0 1/6/2023 18:30 1/6/2023 19:30 1.00 COMPZN, RPCOMP TRIP P RIH w/ G plug F/ 20' T/ 1692', PUW=55K, SOW=55K. 20.0 1,692.0 1/6/2023 19:30 1/6/2023 20:00 0.50 COMPZN, RPCOMP PACK P M/U TD. Set G plug @ 7123' COE. Release from plug. 1,692.0 1,692.0 1/6/2023 20:00 1/6/2023 21:00 1.00 COMPZN, RPCOMP TRIP P POOH F/ 1692', PUW=55K. L/D setting tool 1,692.0 0.0 1/6/2023 21:00 1/6/2023 21:15 0.25 COMPZN, RPCOMP RURD P R/U testing equipment. 0.0 0.0 1/6/2023 21:15 1/6/2023 21:30 0.25 COMPZN, RPCOMP PRTS P PT 7" G plug @ 1723' T/ 2500 PSI for 10 MIn. 0.0 0.0 1/6/2023 21:30 1/6/2023 22:00 0.50 COMPZN, RPCOMP RURD P R/D. B/D testing equipment. 0.0 0.0 1/6/2023 22:00 1/6/2023 22:30 0.50 COMPZN, RPCOMP TRIP P M/U mule shoe & RIH T/ 953', PUW=40K, SOW=40K. 0.0 953.0 1/6/2023 22:30 1/6/2023 23:15 0.75 COMPZN, RPCOMP COND P R/U sand hopper. Dump 300# 20-40 sand = 13' down DP. 953.0 953.0 1/6/2023 23:15 1/6/2023 23:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 953' T/ 100', PUW=40K. 953.0 100.0 1/6/2023 23:30 1/7/2023 00:00 0.50 COMPZN, RPCOMP COND P R/U sand hopper. Dumping 20-40 sand down DP. 100.0 100.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 4/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2023 00:00 1/7/2023 01:15 1.25 COMPZN, RPCOMP COND P Continue dumping 350# 20-40 sand = 15' down DP. Total of 28' of sand on top of G plug. 100.0 100.0 1/7/2023 01:15 1/7/2023 01:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 100', L/D mule shoe, 100.0 0.0 1/7/2023 01:30 1/7/2023 02:30 1.00 COMPZN, RPCOMP NUND P Pull flow nipple. N/D BOP and 7 1/16" 5K x 11" 5K DSA. 0.0 0.0 1/7/2023 02:30 1/7/2023 04:00 1.50 COMPZN, RPCOMP NUND P N/D IA valves and blank flanges and studs off of tubing head. Remove LDS from tubing head. Backing out LDS on casing head. . 0.0 0.0 1/7/2023 04:00 1/7/2023 09:00 5.00 COMPZN, RPCOMP RURD T 1 LSD seized up. Identified pre rig - not repaired ahead of rig work. Steamed head, attempt to free up seized LDS. unable to free up LDS. Run in 10 LDS. N/D tubing head, grind off tip of LDS, install tubing head. Release LDS's. 0.0 0.0 1/7/2023 09:00 1/7/2023 11:00 2.00 COMPZN, RPCOMP RURD P Grow casing N/D TBG head. 7" casing 3.25" growth. RD hydratight. 0.0 0.0 1/7/2023 11:00 1/7/2023 15:45 4.75 COMPZN, RPCOMP NUND P NU 11" 5K x 11" 3K DSA NU BOPS. Simultaneously test cement line and kelly hose for upcoming cement ops. LRS preheating diesel for upcoming OA flush. Continue loading pipe shed W/ 7" Hyd 563. 0.0 0.0 1/7/2023 15:45 1/7/2023 16:15 0.50 COMPZN, RPCOMP SVRG P Service rig. Replace damaged slings for centering BOP stack. 0.0 0.0 1/7/2023 16:15 1/7/2023 17:00 0.75 COMPZN, RPCOMP NUND P Center stack and install new riser. 0.0 0.0 1/7/2023 17:00 1/7/2023 17:30 0.50 COMPZN, RPCOMP RURD P Mobilize MSC. 0.0 0.0 1/7/2023 17:30 1/7/2023 18:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 MSC T/ 8' 0.0 8.0 1/7/2023 18:00 1/7/2023 18:45 0.75 COMPZN, RPCOMP TRIP P RIH T/ 1522', PUW=50K, SOW=48K. 8.0 1,522.0 1/7/2023 18:45 1/7/2023 19:15 0.50 COMPZN, RPCOMP CPBO P Obtain parameters: Pump @ 3 BPM, 300 PSI, @ 5 BPM, 650 PSI. Rotate 80 RPM, Free Tq= .8K. Locate collar @ 1573'. RIH T/ 1590'. Cut pipe @ 5 BPM, 1.2K Tq. Arctic pack returns seen at surface. 1,522.0 1,590.0 1/7/2023 19:15 1/7/2023 19:45 0.50 COMPZN, RPCOMP CIRC P CIrculate 100 Bbls taking returns out to cuttings tank. Returns coming back initially @ 7.4 PPG. End of circulation 9.8 PPG. 1,590.0 1,590.0 1/7/2023 19:45 1/7/2023 20:15 0.50 COMPZN, RPCOMP OWFF P OWFF - No Flow. P/U T/ 1522'. R/D blower hose. B/D TD. 1,590.0 1,522.0 1/7/2023 20:15 1/7/2023 21:00 0.75 COMPZN, RPCOMP TRIP P P/U T/ 1522'. R/D blower hose. B/D TD. POOH F/ 1522' T/ 8', PUW=50K. 1,522.0 8.0 1/7/2023 21:00 1/7/2023 21:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #4, MSC 8.0 0.0 1/7/2023 21:15 1/7/2023 22:15 1.00 COMPZN, RPCOMP BHAH P M/U cement hose and manifold up to TIW & head pin on top of joint of DP. M/U BHA #5 spear T/ 12'. 0.0 12.0 1/7/2023 22:15 1/7/2023 22:45 0.50 COMPZN, RPCOMP FISH P RIH engage 7" casing T/ 36'. P/U 2' to bring clean 7" T/ 1590 T/ 1588', PUW=65K. 12.0 1,588.0 1/7/2023 22:45 1/7/2023 23:00 0.25 COMPZN, RPCOMP PRTS P PT LRS T/ TIW T/ 3500 PSI. 1,588.0 1,588.0 1/7/2023 23:00 1/7/2023 23:15 0.25 COMPZN, RPCOMP PULL P P/U F/ 1588' T/ 1575'. Close LPR. 1,588.0 1,575.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 5/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2023 23:15 1/8/2023 00:00 0.75 COMPZN, RPCOMP CIRC P LRS pumping 170* diesel @ 1.8 BPM, ICP=300 1,575.0 1,575.0 1/8/2023 00:00 1/8/2023 06:00 6.00 COMPZN, RPCOMP CIRC P LRS pumping total of 135 BBls 180* diesel @ 1.8 BPM, FCP=450. Pump 45 Bbls deep clean pill w/ rig @ 5 BPM, 400 PSI. Let diesel soak for 45 Min. LRS pump 270 Bbls 180* seawater @ 1.75 BPM, FCP=500. . Let hot seawater soak for 45 Min. Circulate well over to 9.8# NaCl 5BPM 600 PSI. 1,575.0 1,575.0 1/8/2023 06:00 1/8/2023 06:30 0.50 COMPZN, RPCOMP OWFF P Open pipe rams OWFF 1,575.0 1,575.0 1/8/2023 06:30 1/8/2023 07:30 1.00 COMPZN, RPCOMP RURD P RD cement line to DP. Blow down top drive and surface lines RU GBR casing to LD 7" 26# casing. 1,575.0 1,575.0 1/8/2023 07:30 1/8/2023 08:00 0.50 COMPZN, RPCOMP SFTY P PJSM W/GBR Nabors BOT discuss LD casing operations hazards and mitigations. discuss plan forward for LD casing. 1,575.0 1,575.0 1/8/2023 08:00 1/8/2023 12:00 4.00 COMPZN, RPCOMP PULL P LD spear and casing hanger. LD casing F/1575' T/ surface. 38 full joints and cut joint, measured 16.65' 1,575.0 0.0 1/8/2023 12:00 1/8/2023 12:30 0.50 COMPZN, RPCOMP RURD P LD Casing running tools power tongs and clear floor 0.0 0.0 1/8/2023 12:30 1/8/2023 13:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 1/8/2023 13:00 1/8/2023 14:00 1.00 COMPZN, RPCOMP BHAH P Build BHA while waiting on Cameron to arrive W/test plug. 0.0 0.0 1/8/2023 14:00 1/8/2023 14:30 0.50 COMPZN, RPCOMP MPSP P Drain stack PU and set test plug, RILDS 0.0 0.0 1/8/2023 14:30 1/8/2023 18:00 3.50 COMPZN, RPCOMP PRTS P Attempt to test BOP break at casing spool. LDS impact junk ring unable to attain passing BOP test. Install smaller profile test plug seal. Reset test plug in lower casing head profile. PT stack breaks 250/3000 PSI for 5 min each. 0.0 0.0 1/8/2023 18:00 1/8/2023 18:15 0.25 COMPZN, RPCOMP SFTY P R/D testing equipment. 0.0 0.0 1/8/2023 18:15 1/8/2023 18:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6, 10 3/8" casing scrapper T/ 214', SOW=35K. 0.0 214.0 1/8/2023 18:45 1/8/2023 19:15 0.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #6 F/ 214' T/ 1538', PUW=60K, SOW=57K. 214.0 1,538.0 1/8/2023 19:15 1/8/2023 19:30 0.25 COMPZN, RPCOMP WASH P M/U TD. Circ @ 4 BPM, 150 PSI. RIH tag 7" stub w/ 5K @ 1590' 1,538.0 1,590.0 1/8/2023 19:30 1/8/2023 20:00 0.50 COMPZN, RPCOMP CIRC P Circ BU @ 8 BPM, 600 PSI 1,590.0 1,590.0 1/8/2023 20:00 1/8/2023 20:30 0.50 COMPZN, RPCOMP OWFF P OWFF, POOH T/ 1538', PUW=60K. B/D TD 1,590.0 1,538.0 1/8/2023 20:30 1/8/2023 21:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 1538' T/ 214', PUW=60K. 1,538.0 214.0 1/8/2023 21:00 1/8/2023 21:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #6 R/ 214', PUW=35K. 214.0 0.0 1/8/2023 21:30 1/8/2023 22:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 1/8/2023 22:00 1/8/2023 22:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 7" dress off shoe 8 1/2" string mills T/ 238', SOW=xxxK 0.0 238.0 1/8/2023 22:30 1/8/2023 23:15 0.75 COMPZN, RPCOMP TRIP P RIH F/ 238' T/ 1568', PUW=60K, SOW=60K. 238.0 1,568.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 6/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/8/2023 23:15 1/9/2023 00:00 0.75 COMPZN, RPCOMP MILL P Obtian parameters: Pump @ 4 BPM, 150 PSI, Rotate @ 65 RPM, .8K Free Tq. ROT=55K. Wash down tag top of 7" @ 1590'. Mill over top on 7" stub. 1,568.0 1,590.0 1/9/2023 00:00 1/9/2023 01:30 1.50 COMPZN, RPCOMP MILL P Mill over top on 7" stub @ 4 BPM, 150 PSI, 65 RPM, 1.5-2.2K Tq, 5 WOB T/ 1590.5'. P/U off stub. Had considerable trouble getting back over to top of stub. Appeared that cut lip on 8.8" OD dress off shoe was finding center of 7". Worked for 45 Min to get over top of stub again. Mill T/ 1591'. 1,590.0 1,591.0 1/9/2023 01:30 1/9/2023 02:00 0.50 COMPZN, RPCOMP CIRC P Circ 30 Bbls hi-vis pill around @ 7 BPM, 460 PSI. Consult with town. Decision made to ship Bowen Casing Patch T/ Baker to have cut lip OD enlarged for 10 3/4" casing. 1,591.0 1,591.0 1/9/2023 02:00 1/9/2023 02:15 0.25 COMPZN, RPCOMP OWFF P OWFF. POOH T/ 1568', PUW=60K. B/D TD. 1,591.0 1,568.0 1/9/2023 02:15 1/9/2023 02:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 1568' T/ 1373', PUW=60K. 1,568.0 1,373.0 1/9/2023 02:30 1/9/2023 03:30 1.00 COMPZN, RPCOMP SLPC P Slip and cut 46'' of drill line. 1,373.0 1,373.0 1/9/2023 03:30 1/9/2023 04:00 0.50 COMPZN, RPCOMP TRIP P POOH R/ 1378' T/ 243', PUW=55K. 1,373.0 243.0 1/9/2023 04:00 1/9/2023 05:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #7 F/ 243'. PUW=35K. 243.0 0.0 1/9/2023 05:00 1/9/2023 06:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor for running casing. 0.0 0.0 1/9/2023 06:00 1/9/2023 08:00 2.00 COMPZN, RPCOMP RURD P Remove short bails install long casing bails adjust clamps and time link tilt. 0.0 0.0 1/9/2023 08:00 1/9/2023 08:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 1/9/2023 08:30 1/9/2023 13:00 4.50 COMPZN, RPCOMP WAIT T Waiting on 9-5/8" shoe on 7" casing patch to get reworked to 10-5/8" for tying back 7" 0.0 0.0 1/9/2023 13:00 1/9/2023 14:00 1.00 COMPZN, RPCOMP RURD P RU GBR torque turn and calibrate computer for running casing. 0.0 0.0 1/9/2023 14:00 1/9/2023 18:15 4.25 COMPZN, RPCOMP PUTB P PU Casing patch Shoe 9.625" OD RIH with 7" 26# L-80 Hyd 563 using Jet Lube Seal Guard torque turn connections to 9400 Ft./Lbs. F/surface T/1591'. PUW=65K, SOW=65K, Engage 7" w/ patch no-go out @ 1594'. P/U T/ 100K verify overshot holding. S/O T/ 45K 0.0 1,594.0 1/9/2023 18:15 1/9/2023 19:30 1.25 COMPZN, RPCOMP RURD P R/U HES cement head and circulating equipment. B/D all lines to open top tanks and to cement unit. Latch up elevators on 7" P/U T/ 115K on weight indicator =50K tension in 7". 1,594.0 1/9/2023 19:30 1/9/2023 20:00 0.50 COMPZN, RPCOMP PRTS P PT 7" casing & patch T/ 2500 PSI for 15 MIn. Pressure up open HES Cementer @ 3350 PSI. Close LPR 1/9/2023 20:00 1/9/2023 21:30 1.50 COMPZN, RPCOMP CIRC P HES pump 145 Bbls 140* water @ 4 BPM, 660 PSI around taking returns T/ 400 Bbls open top tank out OA. 1/9/2023 21:30 1/9/2023 21:45 0.25 COMPZN, RPCOMP PRTS P HES PT cement line T/ 4000 PSI. 1/9/2023 21:45 1/9/2023 22:00 0.25 COMPZN, RPCOMP RURD P HES batch up spacer.. Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 7/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/9/2023 22:00 1/9/2023 23:30 1.50 COMPZN, RPCOMP CMNT P HES pump 20 Bbls 10 PPG spacer 2.5 BPM, 190 PSI. Shut down B/D lines T/ 400 Bbls open top. Line up to take returns to 250 Bbls open top tank. Batch up cement. Cement wet @ 22:13 Hrs. HES pump 93.8 Bbls 15.3 PPG primary cement @ 4 BPM, 550 PSI. Shut down drop closing plug. HES pump 5 Bbls water. Swap over to rig and displace w/ 9.8 PPG NaCl @ 4 BPM, once cement seen at surface apply 300 PSI back pressure at choke house1480 PSI on pumps. Bumped plug @ 55.4 Bbls. Pressure up saw HES cementer close @ 1900 PSI. Pressure up T/ 2950 PSI for 5 Min. Cement reruns out of OA at surface. Bleed pressure off. Open up at cement head verify HES cementer is closed and holding. 1/9/2023 23:30 1/10/2023 00:00 0.50 COMPZN, RPCOMP CLEN P Close annular. Open LPR. Pump contaminate pill down kill line out through choke hose to open top tanks. B/D cement line. B/D hard line and choke hose out to open top tanks. 1/10/2023 00:00 1/10/2023 01:00 1.00 COMPZN, RPCOMP CLEN P Continue pump contaminate pill down kill line out through choke hose to open top tanks. B/D cement line. B/D hard line and choke hose out to open top tanks. Suck out open top tanks. 1/10/2023 01:00 1/10/2023 02:00 1.00 COMPZN, RPCOMP RURD P R/D HES cement unit and cement head. 1/10/2023 02:00 1/10/2023 02:30 0.50 COMPZN, RPCOMP SVRG P Service rig - grease low torque valves. 1/10/2023 02:30 1/10/2023 12:15 9.75 COMPZN, RPCOMP WOC P Waiting on cement to reach 500 PSI compressive strength. 1/10/2023 12:15 1/10/2023 13:15 1.00 COMPZN, RPCOMP NUND P Spilt stack and expose 7" CSG. 1/10/2023 13:15 1/10/2023 15:15 2.00 COMPZN, RPCOMP WWSP P Pull 150K on CSG. Center 7" CSG by using come along's to align Slips. Install 10-3/4" x 7" Non-Automatic slips. RILDS. 1/10/2023 15:15 1/10/2023 17:00 1.75 COMPZN, RPCOMP RURD P RU and cut 7" CSG with WACHS saw. Break Out 7" Pup Joint and RDMO GBR Equipment. 1/10/2023 17:00 1/10/2023 19:00 2.00 COMPZN, RPCOMP NUND P Install 7-1/16" 5K x 11" 3K Tubing Head. 1/10/2023 19:00 1/10/2023 19:15 0.25 COMPZN, RPCOMP PRTS P PT Hanger Void Test. 1/10/2023 19:15 1/10/2023 22:00 2.75 COMPZN, RPCOMP NUND P Install test plug. N/U DSA & BOP. Install flow nipple. 1/10/2023 22:00 1/10/2023 22:30 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill stack with fresh water. 1/10/2023 22:30 1/10/2023 23:00 0.50 COMPZN, RPCOMP PRTS P PT BOP stack break T/ 250/3000 PSI for 5 min each. 1/10/2023 23:00 1/10/2023 23:30 0.50 COMPZN, RPCOMP RURD P B/D, R/D testing equipment. Pull test plug. Set wear bushing. 1/10/2023 23:30 1/11/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 1/11/2023 00:00 1/11/2023 01:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #8 6" roller cone bit drill out assembly T/ 240', SOW=38K. 240.0 1/11/2023 01:00 1/11/2023 01:30 0.50 COMPZN, RPCOMP TRIP P RIH F/ 240' T/ 1467', PUW=58K, SOW- 58K. 240.0 1,467.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 8/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2023 01:30 1/11/2023 06:30 5.00 COMPZN, RPCOMP MILL P Hook up blower hose. RIH dry tag TOC @ 1546'. Obtain parameters: Pump @ 4 BPM, 250 PSI. Rotate @ 80 RPM, 1.2K Free Tq, ROT=55K. Mill F/ 1546 T/ 1574', @ 5 BPM, 390 PSI, 80-140 RPM, 1.2-2 K Tq. WOB=2-10K. Chased Plug down to 1659' PUW 58k / SOW 8k. Pumped 20 bbl HI-Vis Sweep @ 5 bpm, 410 psi, rotating at 80-100 RPM, Torque 1.3K, WOB 2-5K, Shut down pumps and dry tagged sand at 1703', Dry Drilled 2'. 1,467.0 1,705.0 1/11/2023 06:30 1/11/2023 08:00 1.50 COMPZN, RPCOMP TRIP P TOOH with BHA #8 1,705.0 240.0 1/11/2023 08:00 1/11/2023 08:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #8, boot baskets were empty and Bit was still at gauge. 240.0 0.0 1/11/2023 08:30 1/11/2023 09:00 0.50 COMPZN, RPCOMP BHAH P PU BHA #9, RCJB with Boot Baskets and String Magnets 0.0 248.0 1/11/2023 09:00 1/11/2023 09:30 0.50 COMPZN, RPCOMP PRTS P RU Test Manifold and PT 7" Casing to 2500 psi and chart for 30 minutes. 0.0 0.0 1/11/2023 09:30 1/11/2023 10:30 1.00 COMPZN, RPCOMP TRIP P TIH w/BHA #9. 248.0 1,660.0 1/11/2023 10:30 1/11/2023 11:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. 1,660.0 1,660.0 1/11/2023 11:00 1/11/2023 11:15 0.25 COMPZN, RPCOMP TRIP P TIH w/BHA #9 to top of sand. 1,660.0 1,700.0 1/11/2023 11:15 1/11/2023 13:00 1.75 COMPZN, RPCOMP WASH P RU Blower Hose. Wash and Circulate sand from top of G-Plug at 1720' Pump Rate 3 bpm, 320 psi, rotating at 78 rpm, 1.7K torque. Increase rate to 7 bpm, 1380 psi and wash down to 1715'. Pump 10 bbl sweep. Remove Blower Hose. 1,700.0 1,715.0 1/11/2023 13:00 1/11/2023 14:00 1.00 COMPZN, RPCOMP TRIP P TOOH to BHA #9. PUW 55k 1,715.0 248.0 1/11/2023 14:00 1/11/2023 16:00 2.00 COMPZN, RPCOMP BHAH P L/D BHA #9 large pieces of debris in RCJB. MU BHA #10. 5.320" OD Model "L" Retrieving Head. 248.0 0.0 1/11/2023 16:00 1/11/2023 18:00 2.00 COMPZN, RPCOMP CIRC P Circ sand off of RBP retrieval neck @ 10 BPM, 900 PSI. 1,720.0 1,720.0 1/11/2023 18:00 1/11/2023 18:45 0.75 COMPZN, RPCOMP PACK P Engage RBP. Attempt to release RPB. Pun past set depth T/ 1750' 1,720.0 1,750.0 1/11/2023 18:45 1/11/2023 19:00 0.25 COMPZN, RPCOMP CIRC P Circ BU+ @ 10 BPM, 900 PSI. 44.5 1,720.0 1/11/2023 19:00 1/11/2023 19:15 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 1,750.0 1,742.0 1/11/2023 19:15 1/11/2023 20:30 1.25 COMPZN, RPCOMP PULD P LDDP F/ 1742' T/ 40', PUW=50K 1,742.0 40.0 1/11/2023 20:30 1/11/2023 21:00 0.50 COMPZN, RPCOMP BHAH P Pull BHA #10 retrieval tool T/ RF. No RBP on retrieval tool. Inspect retrieval tool. 40.0 0.0 1/11/2023 21:00 1/11/2023 21:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0 1/11/2023 21:30 1/11/2023 22:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #11 Shoe w/ RCJB T/ 215', SOW=35K 0.0 215.0 1/11/2023 22:30 1/11/2023 23:15 0.75 COMPZN, RPCOMP TRIP P RIH F/ 215' T/ 1730', PUW=60K, SOW=60K. 215.0 1,730.0 1/11/2023 23:15 1/11/2023 23:45 0.50 COMPZN, RPCOMP REAM P Tag RBP @ 1759'. P/U Obtain parameters. Pump @ 7 BPM, 1315 PSI. Rotate @ 65 RPM, 1K Free Tq. ROT=57K. Wash and ream w/ 1.2=2K Tq. Took weigh @ 1764'. Pushed through took weight again at presumed collar in 7" @ 1804' set down 10K. 1,730.0 1,804.0 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 9/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2023 23:45 1/12/2023 00:00 0.25 COMPZN, RPCOMP CIRC P Pump 25 Bbls hi-vis pill around. Chased out of hole @ 10 BPM, 2575 PSI. 1,804.0 1,804.0 1/12/2023 00:00 1/12/2023 00:15 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 1,804.0 1,725.0 1/12/2023 00:15 1/12/2023 00:30 0.25 COMPZN, RPCOMP TRIP P POOH racking back 2 stand DP T/ 1635', PUW=60K. 1,725.0 1,635.0 1/12/2023 00:30 1/12/2023 01:30 1.00 COMPZN, RPCOMP PULD P LDDP F/ 1635' T/ 215', PUW=60K. 1,635.0 215.0 1/12/2023 01:30 1/12/2023 02:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #11 F/ 215', PUW=35K. 215.0 0.0 1/12/2023 02:30 1/12/2023 02:45 0.25 COMPZN, RPCOMP BHAH P M/U BHA #12 Short catch retrieval tool T/ 43' 0.0 43.0 1/12/2023 02:45 1/12/2023 03:15 0.50 COMPZN, RPCOMP TRIP P RIH T/ 1776', PUW=55, SOW=55 43.0 1,776.0 1/12/2023 03:15 1/12/2023 03:30 0.25 COMPZN, RPCOMP PACK P Kelly up engage RBP @ 1804'. Release RBP. P/U T/ 1745'. RBP hanging up in 7" collars. 1,776.0 1,745.0 1/12/2023 03:30 1/12/2023 03:45 0.25 COMPZN, RPCOMP OWFF P OWFF 1,745.0 1,745.0 1/12/2023 03:45 1/12/2023 05:15 1.50 COMPZN, RPCOMP TRIP P POOH F/ 1745 T/ 1590'. Had to work RBP through new casing patch and cementer. Pump and rotate. Continue POOH. F/ 1590' T/ 43' 1,745.0 43.0 1/12/2023 05:15 1/12/2023 07:00 1.75 COMPZN, RPCOMP BHAH P L/D BHA #12. RBP recovered. Ensure Wear Bushing is still in place. 43.0 0.0 1/12/2023 07:00 1/12/2023 08:30 1.50 COMPZN, RPCOMP TRIP P TIH in with 24 Stands of Drill Pipe to 2245' 0.0 2,245.0 1/12/2023 08:30 1/12/2023 10:30 2.00 COMPZN, RPCOMP PULD P TOOH Laying down Drill Pipe. 2,245.0 0.0 1/12/2023 10:30 1/12/2023 11:00 0.50 COMPZN, RPCOMP CLEN P Clean & Clear Rig FLoor. 0.0 0.0 1/12/2023 11:00 1/12/2023 11:30 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 0.0 1/12/2023 11:30 1/12/2023 12:30 1.00 COMPZN, RPCOMP MPSP P Had Issues removing wear ring. Wash and Jetted on Wear Ring. Finally able to remove wear ring. 0.0 0.0 1/12/2023 12:30 1/12/2023 13:00 0.50 COMPZN, RPCOMP SVRG P Service Rig. 0.0 0.0 1/12/2023 13:00 1/12/2023 14:00 1.00 COMPZN, RPCOMP PULD P C/O Elevators. RU Power Tongs. Verify running order of Jewelry and TBG Count. 0.0 0.0 1/12/2023 14:00 1/13/2023 00:00 10.00 COMPZN, RPCOMP RCST P RIH w/ 2-7/8", 6.4#,L-80, EUE=M Production String T/ 5653'. PUW=60K, SOW =60K, 0.0 5,653.0 1/13/2023 00:00 1/13/2023 01:00 1.00 COMPZN, RPCOMP RCST P Kelly up and wash seals into PBR F/ 5653'. @ 1.5 BPM, 200 PSI. Pressure spike T/ 500 PSI seen @ 5673'. Fully located @ 5694' 7ES RKB. 5,653.0 5,694.0 1/13/2023 01:00 1/13/2023 02:15 1.25 COMPZN, RPCOMP PULD P L/D 2 joint T/ 5653'. P/U landing joint, baker lock new collar on joint. M/U head pin and cement hose. M/U T/ hanger, M/U hanger T/ string. 5,694.0 5,653.0 1/13/2023 02:15 1/13/2023 03:00 0.75 COMPZN, RPCOMP CRIH P Circ 180 Bbls 9.8 PPG CI brine down tubing around back side, chased w/ 5 Bbls 9.8 PPG NaCl @ 4 BPM, 925 PSI. 5,653.0 5,653.0 1/13/2023 03:00 1/13/2023 03:45 0.75 COMPZN, RPCOMP HOSO P RIH and land hanger w/ bottom of seals @ 5674.56' ORKB, PUW=60K, SOW=60K. RILDS 5,653.0 5,674.6 1/13/2023 03:45 1/13/2023 05:30 1.75 COMPZN, RPCOMP PRTS P Drop ball and rod. PT tubing T/ 3000 PSI for 30 Min. Bleed tubing T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump pressure and shear the SOV. 5,674.6 5,674.6 Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 Page 10/10 3A-09 Report Printed: 2/8/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 1/13/2023 05:30 1/13/2023 05:45 0.25 COMPZN, RPCOMP RURD P RD Testing Equipment. Back out Landing Joint. 5,674.6 5,674.6 1/13/2023 05:45 1/13/2023 06:00 0.25 COMPZN, RPCOMP MPSP P PU and Install BPV. 0.0 0.0 1/13/2023 06:00 1/13/2023 06:15 0.25 COMPZN, RPCOMP PRTS P PT BPV for 10 mins @ 1000 psi. 0.0 0.0 1/13/2023 06:15 1/13/2023 10:00 3.75 COMPZN, WHDBOP RGRP P Open Lower Ram body and remove 7" Rams and Install 2-7/8" Fixed Rams. 0.0 0.0 1/13/2023 10:00 1/13/2023 12:45 2.75 COMPZN, WHDBOP NUND P ND BOPE. Install Test Dart, NU TBG Adapter and Wellhead. 0.0 0.0 1/13/2023 12:45 1/13/2023 13:00 0.25 COMPZN, WHDBOP PRTS P PT Packoffs to 5000 psi for 15 Mins. 0.0 0.0 1/13/2023 13:00 1/13/2023 13:30 0.50 COMPZN, WHDBOP RURD P RU Test Manifold. 0.0 0.0 1/13/2023 13:30 1/13/2023 16:30 3.00 COMPZN, WHDBOP RURD T While Rigging up for testing, RTM failed to identify different thread type for tree cap for testing. The wrong cap was installed and the threads was cross threaded and damage the threads beyond repair. Remove top section from old wellhead and install on the new one. 0.0 0.0 1/13/2023 16:30 1/13/2023 17:00 0.50 COMPZN, WHDBOP SVRG P Rig Service. 0.0 1/13/2023 17:00 1/13/2023 17:15 0.25 COMPZN, WHDBOP PRTS P Fluid Pack and PT Tree to 5000 psi for 15 mins. 1/13/2023 17:15 1/13/2023 17:30 0.25 COMPZN, WHDBOP SFTY P Pull tree test dart and BPV. PJSM w/LRS and Rig Crew. 0.0 1/13/2023 17:30 1/13/2023 18:00 0.50 COMPZN, WHDBOP RURD P Spot and MIRU LRS Pumping Unit. 1/13/2023 18:00 1/13/2023 22:00 4.00 COMPZN, WHDBOP FRZP P Pump 12 bbls diesel down IA taking returns from tubing. IA pressured up to 2,500 psi. No returns at tiger tank. Pumped 15 bbls of hot diesel down Tubing taking IA returns to warm up well. Resumed pumping down IA taking returns up tubing. ICP = 400 psi, 65 Bbls away hit trips set @ 2500 PSI. Shut down let pressure relax. Squeeze in additional diesel. FCP = 2500 psi. Loaded IA with 70 bbls diesel. Total bbls of diesel pumped for job = 97. Place TBG & IA in communication allow well to U-tube. Pressures equalized @ ~2150 PSI. Isolate IA, bleed tubing down to 1500 psi. IA tracked down to 1,500 psi. 1/13/2023 22:00 1/14/2023 00:00 2.00 DEMOB, MOVE DMOB P Secure tree and cellar. Remove all fluids from pits. Unhook interconnect. Rig: NABORS 7ES RIG RELEASE DATE 1/14/2023 DTTMSTART JOBTYP SUMMARYOPS 12/7/2022 ACQUIRE DATA COMBO MIT TXIA TO 2500 PSI (PASS) 12/8/2022 SUPPORT OTHER OPERATIONS PULLED GLV & SET DV @ 5330' RKB; PULLED GLV @ 4736' RKB. IN PROGRESS. 12/9/2022 SUPPORT OTHER OPERATIONS SET DV @ 4736' RKB; PULLED GLV'S & SET DV'S @ 3893' & 2612' RKB; PULLED DV @ 5605' RKB (LEFT OPEN). READY FOR E-LINE TBG CUT. 12/14/2022 SUPPORT OTHER OPERATIONS RUN 1: PERFORM STRING SHOT OVER INTERVAL 5623' - 5633' RUN 2: CUT TUBING AT 5633.0', CCL TO CUTTER = 12.2', CCL STOP DEPTH = 5620.8' 1/3/2023 RECOMPLETION MIRU 7ES Spot sub base and pits. Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Complete acceptance checklist. Rig up circ manifold in cellar. Get measurements for riser height from tubing spool height. Take on 9.8 PPG NaCl. Build deep clean pill and hi-vis spacer. 1/4/2023 RECOMPLETION Take on 9.8 PPG NaCl. Build deep clean pill and hi-vis spacer. Take initial pressures T/IA/OA. . Pressure test circ manifold and tiger tank lines. Bleed free gas off TBG/IA. Pump deep clean pill and hi-vis spacer followed by 9.8 PPG NaCl around well. 30 Min no flow test. Install HP BPV. Test BPV T/ 1000 PSI for 10 min. Nipple down tree and adaptor spool. Inspect hanger neck threads, function LDS. Install tree test dart. Nipple up spools to accommodate 7" rams in lower cavity and BOP. Perform between well maintenance, install 7" rams in lower LPR cavity. 1/5/2023 RECOMPLETION Complete between well maintenance. Rig up test joints and testing equipment. Fill BOP with fresh water and shell test. Test BOPE to sundry requirements, 2 7/8", 3 1/2" & 7" test joints. Make up landing joint to hanger. BOLDS. Pull hanger to rig floor. OWFF. Lay down 2 7/8" completion- 173 joints and 10.81' cut joint. Clean and clear rig floor and pipe shed. Making up BHA #1 Overshot. 1/6/2023 RECOMPLETION Continue make up BHA #1 overshot. Pick up drill pipe T/ 5631'. Engage tubing stub. Pull seal assembly free. Circulate well. Pull out of hole racking back drill pipe. Lay down BHA #1 and fish. Rig up E-Line and run CBL from 2700 to surface. Top of cement @ 1650'. Rig down E-line. Run in hole with RBP set @ 1723' COE. Pull out of the hole and lay down setting adapter. Run n hole with mule shoe on bottom DP T/ 953' . Dump 13' of sand down drill pipe using the KB-1 Sand dump funnel. Pull out of hole T/ 100'. Dumping sand down drill pipe. 1/7/2023 RECOMPLETION Dumped 28' of sand down drill pipe. Pulled out of hole laid down mule shoe. Nipple down BOP & drilling spool. Stripped hardware off of tubing spool. BOLDS on casing head, one seized LDS on casing spool. Nipple down tubing head. Cut pin off of seized LDS on casing head. Nipple up tubing head. BOLDS on casing head. Rig up hydratight equipment Remove tubing head. 3.25" OAL growth. Nipple up DSA and BOP. Make up BHA # 4 Multi string cutter. Run in hole with cutter T/ 1590'. Cut 7 casing. Arctic pack observed at surface. Pumped 120 Bbls to cuttings tank. Pull out of hole and lay down cutter. Make up BHA #5 7 casing spear w/ pack off. Run in hole to top of casing hanger. Engage spear in hanger. Pressure test LRS and cement line. Pick 7" string up 15'. Close lower pipe rams. LRS pumping 180* diesel down tubing. 3A-09 RWO Summary of Operations 1/8/2023 RECOMPLETION Continue pumping total of 135 Bbls 180* diesel. Pump 45 Bbls deep clean pill with rig. Let diesel soak. LRS pump 270 Bbls of 180* seawater. Let seawater soak. Displace well back to 9.8 PPG NaCl. rig up GBR casing equipment. Lay down spear and 7" casing. Rig down GBR. Test breaks on BOP stack. Make up BHA #6 10 3/8" casing scrapper. Run in hole to 7" stub@ 1590'. Circulate well. Pull out of hole and lay down BHA #6. Make up BHA #7, 7" dress off with string mills. Run in hole. Obtain parameters and begin dressing off 7" stub @ 1590'. 1/9/2023 RECOMPLETION Continue dressing off 7" stub T/ 1591'. Had considerable trouble getting cut lip past to of 7". Sent Bowen Casing Patch to Baker to have OD of cut lip enlarged for 10 3/4" casing. Pump 30 Bbls hi-vis pill around. Pull out of hole T/ 1373'. Slip and cut drill line. Pull out of hole and lay down BHA #7. Wait on modified Bowen Casing Patch. Rig up GBR casing. Verify joint count and jewelry running order. Run 7" Hyd 563 tie back sting as per tally. Engage overshot on casing stump. Rig up cement head to casing on floor. Pull 130K on weight indicator. Install plug on floor. Pressure test 7" and patch T/ 2500 PSI. Opened HES cementer @ 3350 PSI. HES pump hot water and cement 7" as per cement plan with LPR closed taking returns to open top tanks. Drop closing plug and displace with rig. Once cement seen at surface apply back pressure to squeeze cement. Plug bumped pressure up T/ 2950 PSI. Bleed to 0 verify ES cementer in closed position and holding. Close annular and open LPR and flush black water pill out OA to open top tanks. 1/10/2023 RECOMPLETION Continue washing up cement equipment. Suck out open top tanks. Rig down HES cement unit and cement head. Wait on cement to reach 500 PSI compressive strength. Split BOP stack and pick up to expose 7". Install 10 3/4" x 7" non automatic slips. Set slips in 25k tension. RILDS. Cut 7" with WACHS saw. Pull cut joint. Rack back BOP. Install new 11" 3K x 7 1/16" 5 tubing head. Test packoff to 3000 PSI for 15 Min. Install test plug. Nipple up BOP. Test BOP breaks 230/3000 PSI. Pull test plug. Set wear bushing. 1/11/2023 RECOMPLETION Make up BHA #8 Drill out assembly. Run in hole. Drill out cement and plug F/ 1546' T/ 1705'. Dry drill on sand top. Circulate hi-vis pill around. Pull out of hole and lay down BHA #8. Pressure test 7" casing T/ 2500 PSI for 30 Min. Make up BHA #9 Shoe with RCJB. Run in hole T/ 1720'. Wash sand of top of plug. Circulate hi-vis pill around. Pull out of hole and L/D BHA #9. Make up BHA #10 RBP retrieval tool. Run in hole. Circulate sand off of RBP neck. Attempt engage RBP and release. Circulate bottoms up. Lay down drill pipe and BHA #10 - no RBP. Make up BHA #11 Shoe w/ RCJB. Run in hole T/ 1759'. Pushed packer T/ 1804' set down 10K. Pump hi-vis pill around. 1/12/2023 RECOMPLETION OWFF. Pull 2 stand out of hole T/ 1635'. Lay down drill pipe and BHA #11. Make up BHA #12 short catch retrieval tool. Run in hole. Engage RBP and release. Pull out of hole, worked RBP through new casing patch and cementer. Pull out of hole T/ 43'. Lay down drill pipe and BHA #12. Pull wear bushing. Rig up tubing handling equipment. Verify jewelry running order and joint count. Run 2 7/8" completion as per tally to 5653'. 1/13/2023 RECOMPLETION Wash seals into PBR @ 5673'. Tag no-go at 5694'. Space out. Make up hanger and landing joint. Pump CI NaCl fluid. Land string. Bottom of seals at 5674.56' ORKB. RILDS. Drop ball and rod. Pressure test tubing T/ 3000 PSI for 30 Min. Pressure test IA T/ 2500 PSI for 30 Min. Shear out SOV. Lay down landing joint. Set HP BPV. Pressure test BPV to 1,000 psi from below for 10 minutes. Change lower pipe rams for upcoming well. Nipple down BOP stack. Install tree test dart. Nipple up new tubing head adapter and tree. Damaged otis connection. Change flange out. Pressure test hanger void and tree to 5,000 psi. Pull tree test dart and BPV. Freeze protect well with 72 bbls diesel. Allow well to U- Tube. Secure tree and cellar. Demob. 1/16/2023 MAINTAIN WELL SHAKE OFF BAITED 2" JD ABOVE BALL n' ROD @ 5629' RKB; PULLED SOV & SET OV @ 5570' RKB; PULLED DV'S & SET GLV'S @ 5570' & 2920' RKB. OBTAIN GOOD TBG TEST. IN PROGRESS. 1/17/2023 MAINTAIN WELL PULL BALL n' ROD @ 5629' RKB, PULL RHC @ 5629' RKB, ATTEMPT TO PULL CATCHER @ 5735' RKB, OBSTRUCTIOIN IN TUBING @ 5683' RKB,SEVERAL ATTEMPTS TO BREAK THOUGH W/ BAILERS, RUN LED IMPRESSION BLOCK, POSSIBLE METAL FRAGMENTS IN WELL, RUN SEVERAL MAGNETS W/O SUCCESS, JOB IN PROGRESS 1/23/2023 MAINTAIN WELL PUMP 5 BBLS METH DWN FL & PT FL TO 3000PSI 1/31/2023 MAINTAIN WELL RAN 1.70 X-MAGNET DOWN TO 5683' RKB (RECOVERED SMALL AMOUNT OF METAL SHAVINGS) MADE MULTIPLE BAILER RUNS W/ 2" & 1/75" BAILER DOWN TO SAME W/ SMALL AMOUNT OF RETURNS; RAN POKER W/ TTL PINS & 1/75" BAILER DOWN TO 5683' RKB (MINIMUM RECOVERY & PINS UNTOUCHED). IN PROGRESS. 2/1/2023 MAINTAIN WELL RAN SEVERAL WIRE GRABS & BROKE THRU DEBRIS BRIDGE @ 5685' RKB DOWN TO 5702' RKB; MAKE MULTIPLE BAILER RUNS REMOVING FILL/DEBRIS FROM 5702'- 5716' RKB. IN PROGRESS. 2/2/2023 MAINTAIN WELL BAILED LARGE AMOUNT OF METAL DEBRIS (NON FERROUS METAL PIECES AS LARGE AS 1.75~2.86"-->SEE ATTACHMENTS) W/ MULTIPLE BAILERS FROM 5716'- 5726' RKB. IN PROGRESS. 2/3/2023 MAINTAIN WELL MAKE SEVERAL RUNS W/ 2.25" BAILER RECOVERING LARGE METAL DEBRIS & FILL FROM 5726'-5731' RKB (BAIL BOTTOM INDICATES @ TOP OF CATCHER). IN PROGRESS. 2/4/2023 MAINTAIN WELL BAIL FILL & PULLED 2.30" CATCHER @ 5731' RKB; UNABLE TO EQUALIZE XX PLUG @ 5736' RKB DUE TO FILL; RAN 1.5" BAILER INSIDE X-LOCK & STILL UNABLE TO EQUALIZE; SET OFF 2" HYDROSTATIC BAILER ON TOP OF PLUG @ 5736' RKB AND UNABLE TO PULL BAILER FREE FROM PLUG; MAKE TWO ATTEMPTS JARRING 2 HOURS TOTAL ATTEMPTING TO PULL BAILER FROM PLUG. IN PROGRESS. 2/5/2023 MAINTAIN WELL (WEATHER DELAYED START DUE TO -38°F) MAKE SEVERAL ATTEMPTS TO PULL 2" HYDROSTATIC BAILER @ 5728' RKB WHILE BLEEDING DOWN TUBING PRESSURE WITH NO MOVEMENT (4 HOURS TOTAL). IN PROGRESS. 2/6/2023 MAINTAIN WELL ATTEMPT TO PULL BAITED 2" HYDROSTATIC BAILER @ 5728' RKB JARRING 1 HOUR ON 1ST ATTEMPT & BECAME DETAINED FOR 2 HOURS ON 2ND ATTEMPT (UNABLE TO SHEAR OFF OR PULL FREE), BEFORE BREAKING WIRE @/NEAR ROPE SOCKET (41' TOOLSTRING IN HOLE) RAN 2.25" IMPRESSION BLOCK & OBTAIN PICTURE OF ROPE SOCKET W/ 2" OF WIRE; JARRED DOWN ON FISH FOR 1 HOUR IN ATTEMPT TO SHEAR GS (BLIND BOX DOES NOT INDICATE GOOD CONTACT); RAN 2.24" IMPRESSION BLOCK & OBTAIN PICTURE OF CLEAN FLATTENED ROPE SOCKET. (DRIVE TO PRUDHOE TO PICK UP LARGER CRANE). IN PROGRESS. 2/7/2023 MAINTAIN WELL ATTEMPT TO SHEAR OR PULL SLICKLINE TOOLSTRING (2 HOURS OF JARRING W/ NO MOVEMENT) @ 5681' RKB; READY FOR PLAN FORWARD (FISH IN HOLE= 41' SLICKLINE TOOLSTRING W/ 1 3/8" EXTERNAL F.N. LATCHED ON TO 7' BAITED HYDROSTATIC BAILER W/ 1.81" INTERNAL F.N.). Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,087.0 3A-09 9/7/2012 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled catcher, Left Fish in hole 7' bailer & 41' Toolstring 3A-09 2/6/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: ORIGINAL TUBING CUT @ 6039', FISH PUSHED DOWNHOLE 12/9/2012 osborl NOTE: RIGS RKBs FOR CSG vs WO TUBING AFFECT TUBING/CSG TOPS 10/15/2012 osborl NOTE: TUBING SCALE @ 5800' - 6054' 10/9/2003 WV5.3 Conversio n NOTE: WAIVERED WELL: 1A x OA COMMUNICATION 1/9/2003 ninam NOTE: WORKOVER 9/21/1992 osborl General Notes: Last 3 entries Com Date Last Mod By TUBING SCALE @ 5800'' - 6054'' 10/9/2003 Admin WAIVERED WELL: 1A x OA COMMUNICATION 1/9/2003 Admin 6124'' Left 1.5"" CV in rathole. 7/17/2000 Admin 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 32.0 112.0 112.0 62.58 H-40 WELDED SURFACE 10 3/4 9.95 30.0 2,164.6 2,164.6 45.50 J-55 BTC Tie-Back String 7 6.28 26.9 1,594.0 1,594.0 26.00 L-80 Hyd 563 PRODUCTION 7 6.28 26.9 6,424.4 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.9 Set Depth 5,674.6 Set Depth 5,672.2 String Ma 2 7/8 Tubing Description Tubing Completion Upper Wt (lb/ft) 6.50 Grade L80 Top Connection EUE Mod ID (in) 2.44 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) 23.9 23.9 0.01 Hanger 7.000 Cameron Gen 4 Tubing hanger FMC TC-1A ENS 2.910 2,921.0 2,920.7 1.25 Mandrel GAS LIFT 4.650 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 5,232.7 5,230.8 3.75 Mandrel GAS LIFT 4.650 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 5,571.2 5,568.8 1.74 Mandrel GAS LIFT 4.650 2-7/8" X 1" KBMG, GLM SLB KBGM 2.371 5,630.2 5,627.8 1.58 Nipple - X 3.240 2.313 X Nipple HES X 2.313 5,651.9 5,649.5 1.52 Locator 3.450 Baker locator Baker Locator 2.400 5,652.9 5,650.5 1.52 Seal Assembly 3.230 Baker 80-32 Locating Seal Assembly (7' From Fully Located) Baker 80-32 Seal Assembl y 2.390 Top (ftKB) 5,660.1 Set Depth 5,800.0 Set Depth 5,797.5 String Ma 2 7/8 Tubing Description Stacker Packer Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8RND ID (in) 2.44 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) 5,660.1 5,657.7 1.50 PBR 5.960 BAKER 80-32 PBR 2.420 5,685.2 5,682.8 1.57 PACKER 5.960 BAKER FH PACKER 2.420 5,736.2 5,733.7 1.70 NIPPLE 3.250 CAMCO X NIPPLE 2.313 5,786.9 5,784.5 1.66 LOCATOR 3.750 NO GO LOCATOR 2.440 5,788.8 5,786.3 1.66 SEAL ASSY 3.375 AVA LOCATING SEAL ASSEMBLY 2.437 Top (ftKB) 5,798.9 Set Depth 6,033.6 Set Depth 6,031.0 String Ma 2 7/8 Tubing Description TUBING WO 1992 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8RDABM ID (in) 2.44 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) 5,798.9 5,796.4 1.63 SEAL ASSY 3.625 AVA LOCATOR SEAL ASSEMBLY 2.437 5,801.4 5,799.0 1.62 PBR 5.700 AVA PBR 3.375 5,815.5 5,813.1 1.58 PACKER 6.150 AVA RHS-XL RETRIEVABLE PACKER 3.000 5,983.0 5,980.5 1.50 BLAST RING 4.500 CARBIDE BLAST RING (1) 2.441 6,032.6 6,030.0 1.50 SEAL ASSY 3.625 BAKER LOCATOR SEAL ASSEMBLY 2.437 Top (ftKB) 6,028.0 Set Depth 6,039.0 Set Depth 6,036.5 String Ma 6.276 Tubing Description Tubing - Production Wt (lb/ft) 6.50 Grade J-55 Top Connection ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,028.0 6,025.4 1.50 PACKER 6.276 BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE 2.441 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) 26.9 26.9 0.01 EMERGENCY SLIPS McEvoy Type SA-SH 1/10/2023 7.000 2,260.0 2,260.0 1.01 PATCH HGR UPPER PRODUCTION CASING PATCH HANGER 10/28/2012 5.660 3A-09, 2/8/2023 7:54:31 AM Vertical schematic (actual) PRODUCTION; 1,490.0-6,424.4 FISH; 6,200.0 APERF; 6,172.0-6,178.0 FISH; 6,150.0 IPERF; 6,107.0-6,147.0 RPERF; 6,107.0-6,147.0 FISH; 6,124.0 IPERF; 6,084.0-6,100.0 APERF; 6,082.0-6,100.0 FISH; 6,072.0 PACKER; 6,028.0 PRODUCTION; 6,017.9 IPERF; 5,992.0-6,005.0 PRODUCTION; 5,939.2 PRODUCTION; 5,857.2 PACKER; 5,815.5 PLUG; 5,736.0 FISH; 5,729.0 FISH; 5,688.0 PACKER; 5,685.2 Nipple - X; 5,630.2 Mandrel GAS LIFT; 5,571.1 Mandrel GAS LIFT; 5,232.7 Mandrel GAS LIFT; 2,921.0 PATCH HGR; 2,391.2 CSG PATCH; 2,269.7 Cement SQZ; 2,320.0 ftKB SQZ; 2,320.0-2,340.0 PATCH HGR; 2,260.0 SURFACE; 30.0-2,164.6 Tie-Back String; 26.9-1,594.0 Production String 2 Cement; 26.9 ftKB CONDUCTOR; 32.0-112.0 EMERGENCY SLIPS; 26.9 Hanger; 23.9 KUP PROD KB-Grd (ft) 35.29 RR Date 2/25/1982 Other Elev 3A-09 ... TD Act Btm (ftKB) 6,424.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292069900 Wellbore Status PROD Max Angle & MD Incl (°) 3.75 MD (ftKB) 5,197.01 WELLNAME WELLBORE3A-09 Annotation Last WO: End Date 1/12/2023 H2S (ppm) 160 Date 12/16/2013 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,269.7 2,269.7 1.14 CSG PATCH BAKER ExPATCH PRODUCTION CASING PATCH SET TO ISOLATE UGNU PERFS 10/28/2012 5.660 2,391.2 2,391.1 1.95 PATCH HGR LOWER PRODUCTION CASING PATCH HANGER 10/28/2012 5.660 5,688.0 5,685.6 1.57 FISH 1.5" SLICKLINE TOOLSTRING (1 3/8" EXTERNAL FISH NECK) W/ 2.20" GS PINNED W/ 1/4" BRASS (41' OAL) ENGAGED IN BAIT SUB OF HYDROSTAIC BAILER. 2/6/2023 0.000 5,729.0 5,726.6 1.68 FISH BAITED (1.81" INTERNAL FISH NECK) 2" HYDROSTATIC BAILER (7' OAL) 2/4/2023 0.000 5,736.0 5,733.6 1.70 PLUG 2.31" XX PLUG (41" OAL) 5/1/2014 6,072.0 6,069.5 1.40 FISH CUT ORIGINAL TBG TAIL NIPPLE/SOS (OAL=8') 12/10/2012 0.000 6,124.0 6,121.4 1.26 FISH CV 1.5" CV IN RATHOLE 7/17/2000 7/17/2000 0.000 6,150.0 6,147.4 1.25 FISH DMY GLVs TWO 1.5" DMY GLVs LOST IN RATHOLE 7/20/2007 7/20/2007 0.000 6,200.0 6,197.4 1.25 FISH CV 1.5" CV WRU LATCH, LOST IN RATHOLE 11/29/2005 11/29/2005 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) 2,921.0 2,920.7 1.25 1 GLV BK 1 1,286.0 1/16/2023 SLB KBMG 0.125 5,232.7 5,230.8 3.75 2 GLV BK 1 1,316.0 1/16/2023 SLB KBMG 0.125 5,571.2 5,568.8 1.74 3 OV BK 1 1/16/2023 SLB KBMG 0.188 5,857.2 5,854.8 1.50 6 PROD DMY RK 1 1/2 0.0 9/7/2007 5:00 0.000 5,939.2 5,936.7 1.50 7 PROD DMY RK 1 1/2 0.0 9/7/2007 5:30 0.000 6,017.9 6,015.4 1.50 8 PROD DMY BK 1 0.0 9/7/2007 1:30 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,576.7 1,576.6 0.35 Collar - Stage 8.125 7", HES Cementer HYD 563 Halliburto n HES Cementer 5.840 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 2,320.0 2,340.0 2,320.0 2,339.9 UGNU, 3A-09 7/1/1986 6.0 SQZ UGNU PERFS 5,992.0 6,005.0 5,989.5 6,002.5 C-4, UNIT B, 3A- 09 11/8/1986 12.0 IPERF 90 deg. phase; 5" HJ II Csg Gun 6,082.0 6,100.0 6,079.4 6,097.4 A-4, A-3, 3A-09 10/17/1992 6.0 APERF 0 deg. phase 2 1/8" Enerjet 6,084.0 6,100.0 6,081.4 6,097.4 A-3, 3A-09 11/8/1986 4.0 IPERF 0 deg. phase 2 1/8" Enerjet 6,107.0 6,147.0 6,104.4 6,144.4 A-2, 3A-09 11/8/1986 4.0 IPERF 0 deg. phase 2 1/8" Enerjet 6,107.0 6,147.0 6,104.4 6,144.4 A-2, 3A-09 10/17/1992 6.0 RPERF 0 deg. phase 2 1/8" Enerjet 6,172.0 6,178.0 6,169.4 6,175.4 A-1, 3A-09 10/17/1992 4.0 APERF 2 1/8" Enerjet Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,320.0 2,340.0 2,320.0 2,339.9 Cement SQZ Squeeze off Ugnu Perfs 3A-09, 2/8/2023 7:54:32 AM Vertical schematic (actual) PRODUCTION; 1,490.0-6,424.4 FISH; 6,200.0 APERF; 6,172.0-6,178.0 FISH; 6,150.0 IPERF; 6,107.0-6,147.0 RPERF; 6,107.0-6,147.0 FISH; 6,124.0 IPERF; 6,084.0-6,100.0 APERF; 6,082.0-6,100.0 FISH; 6,072.0 PACKER; 6,028.0 PRODUCTION; 6,017.9 IPERF; 5,992.0-6,005.0 PRODUCTION; 5,939.2 PRODUCTION; 5,857.2 PACKER; 5,815.5 PLUG; 5,736.0 FISH; 5,729.0 FISH; 5,688.0 PACKER; 5,685.2 Nipple - X; 5,630.2 Mandrel GAS LIFT; 5,571.1 Mandrel GAS LIFT; 5,232.7 Mandrel GAS LIFT; 2,921.0 PATCH HGR; 2,391.2 CSG PATCH; 2,269.7 Cement SQZ; 2,320.0 ftKB SQZ; 2,320.0-2,340.0 PATCH HGR; 2,260.0 SURFACE; 30.0-2,164.6 Tie-Back String; 26.9-1,594.0 Production String 2 Cement; 26.9 ftKB CONDUCTOR; 32.0-112.0 EMERGENCY SLIPS; 26.9 Hanger; 23.9 KUP PROD 3A-09 ... WELLNAME WELLBORE3A-09 RBDMS JSB 120222 STATE OF ALASKA . . ALA OIL AND GAS CONSERVATION CONOSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other gr. Cut Tubing Tail Alter Casing r Rill Tubing r Stimulate - Frac r Waiver f Time Extension E Change Approved R - ogram j Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IV Exploratory r 181 -194 3. Address: 6 . API Number: Stratigraphic r Service r 50- 029 - 20699 -00 P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25631 - 3A - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River 00 Pool 11. Present Well Condition Summary: Total Depth measured 6430 feet • Plugs (measured) none true vertical 6427 feet Junk (measured) 6072, 6124, 6150, 6200 Effective Depth measured 6342 feet Packer (measured) 5685, 5816, 6028 true vertical 6338 feet (true vertical) 5683, 5813, 6025 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 112 112 SURFACE 2135 10.75 2165 2164 PRODUCTION 6398 7 6424 6421 NED MAR G 2013. RECEIVED JAN 22 2013 Perforation depth: Measured depth: 2320 -2340, 5992 -6005, 6082 -6100, 6107 -6147, 6172 -6178 � / / -� C True Vertical Depth: 2320 -2340, 5990 -6003, 6079 -6097, 6105 -6145, 6170 -6176 \14�1.,+ Tubing (size, grade, MD, and TVD) 2.875, L -80, 5800 MD, 5798 TVD 2.875, J -55, 5800' - 6072' MD, 5798' -6070' TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FH PACKER @ 5685 MD and 5683 TVD PACKER - AVA RHS -XL RETRIEVABLE PACKER @ 5816 MD and 5813 TVD PACKER - BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE @ 6028 MD and 6025 TVD SSSV - CAMCO DS NIPPLE @ 514 MD and 514 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 225 348 411 -- 138 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 9 r Service r Stratigraphic E 16. Well Status after work: " Oil I✓ Gas r WDSPL r Daily Report of Well Operations _XXX GSTOR T" WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Howard Gober @ 263 -4220 Email Howard.Gober @conocophillips.com Printed Name Howard Gober Title Wells Engineering Supervisor Signature Phone: 263 -4220 Date V2-1/13 ____ Form 10 -404 Revised 12/2012 4 101/P V L f:" Submit Original Only 2/12/ `� 3A -09 Well Work Summary • DATE SUMMARY 12/9/12' CUT TUBING TA IL OFF WI CUTTER AT DEPTH OF 6039' CCL_ TO CUTTER 5' CCL STOP AT 6034'. POST CUT TAGGED TAIL AT 6039' 12/14/12 DISLODGE CUT TUBING TAIL @ 6040' RKB & MOVED 8' OF 2 7/8 TAIL PIPE DOWNHOLE; TAGGED TOP OF FISH @ 6072' RKB ( EST. 10' ABOVE TOP PERF) . JOB COMPLETE. s KUP • 3A -09 ConocoPhillips 0. Well Attributes Max Angle & MD TD 0 I t „ ;t II', Welibore APVUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Coryllpkps 500292069900 KUPARUK RIVER UNIT PROD 3.75 5,197.01 6,424.0 "" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date °'° SSSV: NIPPLE 160 1/9/2013 Last WO: 10/29/2012 35.29 2/25/1982 Well ConhiS. -39-09 1/11/201370034 AM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... Date Last Tag: SLM 6,087.0 9/7/2012 Rev Reason: GLV C /O, FISH, PULL RHC osborl 1/10/2013 HANGER. 24 - -, - -, Casing Strings o- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd } �'� CONDUCTOR 16 15.062 32.0 112.0 112.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING, 30 SURFACE 103/4 9.950 30.0 2,164.6 2,164.6 45.50 J - 55 BTC TUBING PUP, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TIM... String Wt.. String ... String Top Thrd 81 • I T CONDUCTOR, PRODUCTION 7 6.276 26.9 6,424.4 26.00 J -55 BTC 32 - 112 Tubing Strings Tubing Description String 0... 'String ID ...Top (ftKB) Set Depth (f... Depth (TVD) ... ng Wt... String ... String Top Thrd NIPPLE, 514E TUBING WO 2012 I 2 7/8 Str 2.441 J 23.9 I 5,660.8 'Set D 5,658.4 'String I L -80 I EUE8rdABMOD Completion Details Top Depth (TVD) Top Inc! Nomi..- SURFACE, i... T op (ft/03) MB) ( °) Item Description Comment ID (in) 30 23.9 23.9 -29.05 HANGER MCEVOY GEN III TUBING HANGER 2.875 PATCH HGR, 514.4 514.4 -22.46 NIPPLE CAMCO DS NIPPLE 2.312 • 2,280 2,320 5,659.8 5,657.4 1.50 SEAL ASSY BAKER LOCATING SEAL ASSEMBLY w/21.66' SEALS & 5' SPACEOUT 2.441 050 PATCH, Tubing Description String 0... String ID... To (ftKB) Set Depth (f... Set Depth (TVD) -.. Strin Wt... String String Top Thrd Cement 502 ' - - Stacker Packer f 2 7/8 I 2.441 I 5, 660.1 1 5,800.0 I 5,797.5 I 6.50 I L - 80 l EUE 8RND 2,320 PATCH HGR, I Completion Details 2,391 Top Depth (TVD) Top Ind Nomi... Top (508) (MOB) 0) Item Description Comment ID (in) ME 5,660.1 5,657.7 1.50 PBR BAKER 80 PBR 2.420 GAS LIFT. 2.612 5,685.3 5,682.9 1.93 PACKER BAKER FH PACKER 2.420 5,736.2 5,733.7 1.80 NIPPLE CAMCO X NIPPLE 2.313 I I 5,786.9 5,784.5 1.66 LOCATOR NO GO LOCATOR 2.440 5,788.8 5,786.4 1.66 SEAL ASSY AVA LOCATING SEAL ASSEMBLY 2.437 GAS LIFT, Tubing Description String 0... String ID ...l (RKB) Set Depth (f... Depth (TVD) . -. String Wt.. String ... String Top Thrd 3.as4 TUBING WO 1992 l 2 7/8 I 2.441 I 5,798.9 I 6,033.6 'Set D 6,031.0 I 6.50 I L -80 I EUE8RDABM ON Completion Details GAS LIFT, Top Depth 4,736 ° - (TVD) Top Inc! Nomi... ONO Top (RKB) (ftKB) 0) Item Description Comment ID (in) EN 5,798.9 5,796.4 1.63 SEAL ASSY AVA LOCATOR SEAL ASSEMBLY 2.437 GAS LIFT, 5.330 5,801.4 5,799.0 1.62 PBR AVA PBR 3.375 NM 5,815.5 5,813.1 1.58 PACKER AVA RHS -XL RETRIEVABLE PACKER 3.000 5,983.0 5,980.5 1.63 BLAST RING CARBIDE BLAST RING (1) 2.441 GAS LIFT, 5.605 ` 6,032.6 6,030.0 1.50 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.437 _ Tubing Description String 0. String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String -.. String Top Thrd TUBING Original 1.. 5 11/16 I 3.250 I 6,028.0 I 6,039.0 6,036.5 SEAL ASSY. _ - Completion Details 5,660 I Top Depth PBR, 5,560 _ (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) 0) Item Description Comment ID (in) PACKER. sties - 6,028.0 6,025.4 1.51 PACKER BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE 3.250 Mil Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) IIIIIII Top Depth NIPPLE, 5.736 Or[ (ND) Top Inc! IIIII Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) MN 2,260.0 2,260.0 1.01 PATCH HGR UPPER PRODUCTION CASING PATCH HANGER 10/28/2012 5.660 LOCATOR, 2,269.7 2,269.7 1.14 CSG PATCH BAKER ExPATCH PRODUCTION CASING PATCH SET TO 10/28/2012 5.660 SEAL ASSY, ISOLATE UGNU PERFS 5,789 • SEAL ASSY, 2 ,391.2 2,391.1 2.00 PATCH HGR LOWER PRODUCTION CASING PATCH HANGER 10/28/2012 5.660 • 5,799 PBR, 0801 ` 1, 6,072.0 6,069.5 1.25 FISH CUT ORIGINAL TBG TAIL NIPPLE /SOS (OAL =8') 12/10/2012 0.000 PACKER, 5,816 6,124.0 6,121.4 1.25 FISH CV 1.5" CV IN RATHOLE 7 /17/2000 7/17/2000 0.000 - 6,150.0 6,147.4 1.25 FISH DMY GLVs TWO 1.5" DMY GLVs LOST IN RATHOLE 7/20/2007 0.000 - 7/20/2007 PRODUCTION, 57 . 6,200.01 6,197.41 1.25 FISH CV 1.5" CV WRU LATCH, LOST IN RATHOLE 11/29/2005 11/29/2005 0.000 5,8 - Perforations & Slots PRODUCTION, - Shot 5,939 Top (ND) Btm (TVD) Dens _ Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (sh... Type Comment r -� IPERF, - - ' = 2,320.0 2,340.0 2,320.0 2,339.9 UGNU, SQZ UGNU PERFS 5,992.0 6,005.0 5,989.5 6,002.5 C-4, UNIT B, 11/8/1986 12.0 IPERF 90 deg. phase; 5" HJ II Csg Gun 5,892 - 6,005 "� - 30 6,082.0 6,100.0 6,079.4 6,09 7.4 A-4, A-3, 30 -09 10/17/1992 6,0 APERF 0 deg. phase 2 1/8" Enerjet PRODUCTION, 6.018 ' 6,084.0 6,100.0 6,081.4 6,097.4 A -3, 3A -09 11/8/1986 4.0 IPERF O deg. phase 2 1/8" Enerjet PACKER 6028 - - �� 6,107.0 6,147.0 6,104.4 6,144.4 A -2, 3A-09 11/8/1986 4.0 IPERF Odeg. phase 2 1/8" Enerjet SEAL ASSY, 1� 6,107.0 6,147.0 6,104.4 6,144.4 A -2, 3A-09 10/17/1992 6.0 RPERF 0deg. phase 2 1/8" Enerjet 8,033 , ' ( 1 6,172.0 6,178.0 6,169.4 6,175.4 A -1, 3A -09 10/17/1992 4.0 APERF 2 1/8" Enerjet Mandrel Details FISH, 6,072 V Top Depth Top Port APERF, (ND) Inc' OD Valve Latch Size TRO Run 6,082 -0,100 Stn Top (5108) (ftKB) 0) Make Model (In) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 2,612.3 2,612.1 1.50 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,247.0 11/6/2012 6,084-0,100 - -- FISH, 8,124 2 3,893.7 3,893.3 1.75 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,271.0 11/6/2012 IPERF, - - _ 6,1078147 -- 3 4,735.5 4,734.5 2.27 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,300.0 11/6/2012 RPERF. 6,10743147 - - ' 4 5330.1 5,328.1 3.39 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,289.0 11/7/2012 FISH.8.150 15 5 5,605.0 5,602.7 1.65 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 11/7/2012 APERF, _ 6 5,857.2 5,854.8 1.50 CAMCO MMG-P 1 1/2 PROD DMY RK 0.000 0.0 9/7/2007 5:00 6. 172 4317e Zi - -- 7 5,939.2 5,936.7 1.50 CAMCO MMG-P 1 1/2 PROD DMY 'RK 0.000 0.0 9/7/2007 5:30 FISH, 6,200 0 8 6,017.9 6,015.4 1.54 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/7/2007 1:30 I I TD, 6,424 PRODUCTION, ° 27 -6,424 • KUP 3A -09 ConocoPhillips1 Aaska.Inc. Cor d1Ulllps KB -Grd (ft) Rig Release Date 35.29 2/25/1982 Well Confiq: - 3A-09 1/1112013 7:08.34 AM - Schematic - Actual HANGER. 24 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top BM) Btm (RKB) (FMB) (RKB) Description Start Data Comment TUBING. 30 2,320.0 2,340.0 2,320.0 2,339.9 Cement Squeeze 7/1/1986 Squeeze off Ugnu Perfs TUBING PUP, 81 Notes: General & Safety CONDUCTOR, End Date Annotation 32 - 112 9/21/1992 NOTE: WORKOVER NIPPLE, 514 1/9/2003 NOTE: WAIVERED WELL: 1Ax OA COMMUNICATION 10/9/2003 NOTE: TUBING SCALE @ 5800' - 6054' 11/10/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/15/2012 NOTE: RIGS RKBs FOR CSG vs WO TUBING AFFECT TUBING/CSG TOPS SURFACE, + 12/9/2012 NOTE: ORIGINAL TUBING CUT @ 6039', FISH PUSHED DOWNHOLE PATCH MGR, 2,260 \ SOZ, 2,320 -2,340 CSG PATCH, 2,270 __- Cement SOZ. _ 2,320 PATCH NOR, 2,391 GAS LIFT. 2,612 GAS LIFT. 3,894 GAS LIFT, 4,736 { — GAS LIFT. 5,330 t GAS LIFT, 5,605 SEAL ASSY. 5,660 P96, 5,860 L� PACKER, 5,685 — NIPPLE, 5.738 yr[ LOCATOR, 5,787 SEAL ASSY, 5,789 SEAL ASSY, 5.789 PBR, 5,801 PACKER. 5.816 - PRODUCTION, 5.857 PRODUCTION, 5,939 IPERF, 5,9924405 1 .... PRODUCTION. ( l 8.08 �■ PACKER, 8.028 ASSY, SEAL ASSY, 6.033 F l FISH, 6,072 APERF, 6,0824,100 IPERF, 6,084-6,100 FISH. 6,124 IPERF, 6,107 -6,147 — - RPERF, 0 tt 6,1074.147 -- FISH, 6,1 APERF, 6,1724.178 FISH, 6,200 S2 TO, 6 424 PRODUCTION, a 27 -6,424 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM•ION r REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Ft?rforations r Perforate r Other E Alter Casing p' Pull Tubing 17 Stimulate - Frac r Waiver r ' Time Extension E Change Approved Program r Operat. Shutdow n r Stimulate - Other "" Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p,-,... Exploratory r 181 - 194 3. Address: 6. API Number: Stratigraphic r® Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20699 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25631 — — 3A -09 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6430 feet Plugs (measured) 5736', 6041 true vertical 6427 feet Junk (measured) 6124', 6150', 6200' Effective Depth measured 6342 feet Packer (measured) 5685, 5816, 6028, true vertical 6338 feet (true vertucal) 5683, 5813, 6026 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112 112 SURFACE 2124 10.75 2164 2164 PRODUCTION 6384 7 6424 6421 RECEIVED SCANNED FEB 2 8 2013 NOV 19 2012 Perforation depth: Measured depth: 2320'- 2340', 5992 -6005, 6082 -6100, 6107 -6147, 6172 -6178 AOGCC True Vertical Depth: 2320 -2340, 5990 -6003, 6079 -6097, 6105 -6145, 6170 -6176 Tubing (size, grade, MD, and TVD) 2.875, L -80, 6034 MD, 6031 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FH PACKER @ 5685 MD and 5683 TVD PACKER - AVA RETRIEVABLE PACKER @ 5816MD and 5813 TVD PACKER -BAKER DB RETRIEVABLE PACKER @ 6028 MD and 6026 TVD SSSV - CAMCO DS NIPPLE @ 491 MD and 491 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 . Service r Stratigraphic r 16. Well Status after work: Oil f Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -314 Contact Brett Packer tu'�, 265 - 6845 Email J. Brett.Packer(atconoconhillios.com Printed Name J. Brett Packer Title Wells Engineer Signature t , 23 7 0 Phone: 265 - 6845 Date (( Form 10 - 404 Revised 10/2012R8rM NOV 2 1 1012 Ne � 3 ubmit Original Only 3 2 ti KUP • 3A -09 a ConocoPhillips - Well Attributes Max Angle & MD TD AlaRltA.11'1C Wellbore API/UWI Field Name Well Status !nci (°) MD (ftKB) Act Btm (ftKB) 500292069900 KUPARUK RIVER UNIT PROD 3.75 5,197.01 • 6,424.0 • - Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well Coned - 3A - 09, 11/5120126 :09:31 AM -SSSV: TRDP 210 11/13/2010 Last WO: 10/29/2012 35.29 2/25/1982 Schematic Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date ___. „. Last Tag: SLM 6209.0 12/26/2008 Rev Reason:WORKOVER ninam 11/5/2012 Ng P. Casing Strings HANGER, 29 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String .. String Top Thrd �,_ _ CONDUCTOR 16 15.062 32.0 112.0 112.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd .SURFACE 103/4 9. 950 30. 2,164.6 2,164.6 45.50 J - 55 BTC CONDUCTOR, I Casing Descri ption Stri 0... Stri ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... St ring ... String lop Thrd 32 PRODUCTION 7 6.276 26.9 6,424.4 26.00 J - 55 BTC NIPPLE, 491 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CASING PATCH 6.1 5.660 2,260.0 2,409.8 5.75TSS Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt... String ... String Top Thrd Upper Completion 2 7/8 2.441 29.0 5,660.8 5,658.4 6.50 L - 80 EUE8rdABMOD SURFACE, L 30 -2.165 a Completion Details Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 29.0 29.0 -28.98 HANGER MCEVOY GEN III TUBING HANGER 2.875 SQZ. 490.5 490.5 -22.78 NIPPLE CAMCO DS NIPPLE 2.312 2,320 - 2,340 Cement SQZ, _ Mil 5,638.1 5,635.7 1.56 LOCATOR 2.441 2.320 5,639.2 5,636.8 1.56 SEAL ASSY BAKER 80 SEAL ASSEMBLY 2.441 Tubing Description ing 0... String ID ...Top (ftKB) Depth (f... Depth (TVD) ...ng Wt.,. String ...String Top Thrd Stacker Packer I Str 2 7/8 I 2.441 I 5,660.1 ISM 5,800.0 I Set D 5,797.5 I Stri 6.50 L -80 I EUE 8RND Completion Details Top Depth GAS LIFT, ! (TVD) Top Intl Nomi... 2.566 T op (ftKB) (ftKB) (°) Rem Description Comment ID (in) 5,660.1 5,657.7 1.50 PBR BAKER 80-32 PBR 2.420 5,685.3 5,682.9 1.93 PACKER BAKER FH PACKER 2.420 5,736.2 5,733.7 1.80 NIPPLE CAMCO X NIPPLE w /RHC PLUG INSTALLED 2.313 GAS LIFT, 5,786.9 5,784.5 1.66 LOCATOR NO GO LOCATOR 2.440 3,872 5,788.8 5,786.4 1.66 SEAL ASSY AVA LOCATING SEAL ASSEMBLY 2.437 GAS LIFT, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 4,714 -I TUBING WO 27/8 I 2.441 I 5,798.9 !Set I 6 6 L -80 EUE8RDABM Completion Details Top Depth GAS LIFT, (TVD) Top Inc! Nomi... 5,308 Top (ftKB) (MKB) ( °) Item Description Comment ID (in) 5,798.9 5,796.4 1.63 SEAL ASSY AVA LOCATOR SEAL ASSEMBLY 2.437 GAS LIFT, _ 5,801.4 5,799.0 1.62 PBR AVA PBR 3.375 5,583 5,815.5 5,813.1 1.58 PACKER AVA RHS-XL RETRIEVABLE PACKER 3.000 LOCATOR, 5,983.0 5,980.5 1.63 BLAST RING CARBIDE BLAST RING (1) 2.441 SEAL ASSY, s, SY. 6,032.6 6,030.0 1.50 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.437 5.639 r Tubing Description String 0... String ID ...Top (ftKB) Set Depth (f... Set Depth (ND) ...String Wt... String ... String Top Thrd PBS 5,660 j TUBING Original 1 511/16 I 3.250 I 6,028.0 i 6,047.3 I 6,044.8 I I ._ Comp Details PACKER, 5,885 EMI - Top Depth MO (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) CATCH,730 ER, 6,028.0 6,025.5 1.51 PACKER BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE 3.250 5 NIPPLE, 5,736 ;��,!•; 6,040.7 6,038.2 1.25 NIPPLE CAMCO D NIPPLE NO GO 2.250 PLUG, 5,73 7 i all 6,046.6 6,044.1 1.25 SOS CAMCO SHEAR OUT SUB 2.441 MB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc. LOCATOR. Oth I HlL P 9 P P etc.) 5,787 Top Depth SEAL ASSY, (ND) Top Inc! 5 SEAL ASSY, Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 5,799 5,730 5,727.6 1.81 CATCHER 10/28/2012 0.000 PBR, 5,801 PACKER, 5,816 5,736 5,733.8 1.80 PLUG RHC PLUG 10/28/2012 0.000 6,041 6,038.2 1.25 PLUG 2.25" CA -2 PLUG 9/8/2012 0.000 6,124 6,121.4 1.25 FISH CV 1.5" CV IN RATHOLE 7 /17/2000 7/17/2000 0.000 PRODUCTION, 6,150 6,147.4 1. 25 FISH DMY GLVS TWO 1.5" DMY GLV6 LOST IN RATHOLE 7/20/2007 0.000 5,857 7/20/2007 PRODUCTION, 6.200 6,197.4 1.25 FISH CV 1.5" CV WRU LATCH, LOST IN RATHOLE 11/29/2005 11/29/2005 0.000 5,939 Perforat 8 Slots Shot IPERF, A. Top (ND) Btm (ND) Dens 5,992'6.005 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment 2,320 2,340 2,320.0 2,339.9 UGNU, 3A-09 7/1/1986 6.0 SQZ UGNU PERFS PRODUCTION, 5,992 6,005 5,989.5 6,002.5 C-4, UNIT B, 11/8/1986 12.0 IPERF 90 deg. phase; 5" HJ II Csg Gun 6.018 3A -09 PACKER, 6,028 6,082 6,100 6,079.4 6,097.4 A-4, A -3, 3A -09 10/17/1992 6.0 APERF 0 deg. phase 2 1/8" Enerjet SEAL ASSY, 6.033 6,084 6,100 6,081.4 6,097.4 A - 3, 3A - 09 111/8/1986 4.0 IPERF 0 deg. phase 2 1 /8" Enerjet NIPPLE, 6,041 PLUG, 6,041 Mandrel Details 805,8,047 Top Depth Top Port (ND) Inc' OD Valve Latch Size TRO Run APERF, Stn Top (ftKB) (ftKB) (1 Make Model _ (!n) Sery Type Type (in) (psi) Run Date Com... 6,082 -6,100 _ • 1 1 2,588.5 2,588.3 1.50 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 10/28/2012 IPERF, 6.0846,100 2 3,872.1 3,871.6 1.75 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 10/28/2012 FISH, 6,124 IPERF, 3 4,713.9 4,712.9 2.50 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 10/28/2012 6,1076,147 RPERF, 6,107 ' 4 5,308.4 5,306.4 3.45 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 10/28/2012 ' 5 5,583.4 5,581.0 1.71 CAMCO KBMG 1 GAS LIFT SOV BEK -5 0.000 0.0 10/28/2012 FISH, 6,150 Q 6 5,857.2 5,854.8 1.50 CAMCO . MMG - P 1 1/2 PROD DMY RK 0.000 0.0 9/7/2007 5:00 APERF, 6,172-6,178 APERF, M M 7 5,939.2 5,936.7 1.50 CAMCO MMG-P 1 1/2 PROD DMY RK 0.000 0.0 9/7/2007 5:30 FISH, 6,200 Q 8 6,017.9 6,015.4 1.54 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/7/2007 1:30 TD, 6.424 PRODUCTION, 4. 276,424 KUP • 3A -09 ConocoPhillips if Alaska. Inc KB-Grd (ft) Rig Release Date 35.29 2/25/1982 Well Cones: - 34-09, 11/5/2012 6:09:31 AM SchematIs -Actual PP Perforations & Slots Shot HANGER, 29 Top (TVD) Btm (TVD) Dens I Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.. Type Comment 6,107 6,147 6,104.4 6,144.4 A - 2, 3A 11/8/1986 4.0 IPERF 0 deg. phase 2 1/8" Enerjet 32 e9 CONDUCTOR. 6 6 6 6 A -2, 3A-09 10/17/1992 6.0 RPERF Od phase Enerjet 6,172 6,178 6,169.4 6,175.4 A -1, 3A -09 10/17/1992 4.0 APERF 21/8 "Enerjet NIPPLE, 491 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ft613) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment SURFACE, 2,320.0 2,340.0 2,320.0 2.339.9 Cement Squeeze 7/1/1986 Squeeze off Ugnu Perfs 30 -2,165 Notes: General & Safety End Date Annotation 1/9/2003 NOTE: WAIVERED WELL: 1A x OA COMMUNICATION 10/9/2003 NOTE: TUBING SCALE @ 5800' - 6054' soz, 2,320 - 2,340 11/10/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Cement z 320 10/15/2012 NOTE: RIGS RKBs FOR CSG vs WO TUBING AFFECT TUBING/CSG TOPS GAS LIFT y 2.588 GAS LIFT, pp 3,872 GAS LIFT, 4,714 GAS LIFT, 5,308 GAS 5,583 LOCATOR, 5,838 VIM SEAL ASSY, 5,639 _. PBR, 5,560 L i PACKER, 5,685 - l♦ CATCHER,_ 5,730 NIPPLE, 5,736 PLUG, 5,736 fa LOCATOR, 5,787 SEAL ASSY, 5,789 SEAL ASSY, 5,799 - PBR, 5,801 PACKER, 5,816 PRODUCTION, 5,857 PRODUCTION, 5,939 - 1♦ IPERF, _ 5,992 - 6,005 PRODUCTION, 6,018 PACKER, 6,028 SEAL ASSY, 6,033 "411.1116." NIPPLE, 6,041 -_ PLUG, 6,041 .• SOS, 6,047 APERF, 8,082PE100 PERF, 6,084-6,700 FISH, 6,124 IPERF, - - -- 6,107.6,147 - - -- RPEFF, 8.107 -6,747 FISH, 6,150 APERF, 6,172 -6,178 Ell FISH, 6200 ID. 6,424 PRODUCTION, 27-6,424 3A -09 Pre Rig Well Work Summary DATE SUMMARY 8/28/12 PRE -RIG T POT- FAILED, -POT- PASSED; IC PPPOT- PASSED; 10 IN PROGRESS; OC PPPOT- IN PROGRESS; FUNCTIONED LDS HAD TO APPLY 2 SUPER SOAKERS ON IC LDS, ALL THE REST WERE FUNCTIONAL. WILL NEED TO RETURN TO FINISH JOB. 8/31/12 OC POT'S, LDS'S: OC SLOTTED BLEEDER & 2 IC LDS'S REMAIN SEIZED (CURRENTLY SOAKING IN KROIL). WILL RETURN ATA LATER DATE. 9/5/12 PUMPED 5 BBL TO OPEN SSSV FLAPPER. GUAGED TBG TO CATCHER @ 6022' SLM. IN PROGRESS. 9/6/12 BAILED FILL OFF CATCHER @ 6020' SLM; PULLED SAME. BAILED FILL ON CA -2 PLUG. IN PROGRESS. 9/7/12 BAILED SCALE, PULLED CA -2 PLUG FROM 6040' RKB. TAGGED TD @ 6087' RKB. IN PROGRESS. 9/8/12 MEASURED BHP @ 6081' RKB: 3317 PSI. SET CA -2 PLUG @ 6040' RKB. READY FOR WRP. 9/13/12 (RWO): UNSUCCESSFULLY ATTEMPTED TO FREE STUCK SLOTTED BLEEDER AND IC- LDS. FOUND 5 STUCK OC- LDS.REMAINING OC -LDS'S FUNCTION NORMALLY. BLED OOA FROM 56 PSI TO 0 PSI IN 30 SEC. 10/8/12 SET WRP IN MID JOINT BELOW PACKER AT 5816'. MID ELEMENT SET AT 5837' CCL TO MID ELEMENT 10.3' CCL STOP AT 5826.7' 10/9/12 (PRE RWO) ATTEMPTED TO FREE UP SEIZED LDS'S, 2 ON THE IC (STILL SEIZED), 3 ON THE OC (GOT ONE LOOSE, 2 STILL SEIZED), ATTEMPTED TO LOOSEN OC POT SLOTTED BLEEDER, STILL SEIZED CONTINUED TO SOAK WITH PENETRATING OIL. 10/9/12 SET CATCHER SUB © 5819' SLM. ATTEMPTED PULL OV @ 5441' RKB. IN PROGRESS. 10/10/12 ATTEMPTED PULL OV @ 5441' RKB; APPARENT SEVERE SCALE. IN PROGRESS. 10/11/12 ATTEMPTED PULL OV @ 5441' RKB; WITH 1.26" LIB CONFIRMED OPEN POCKET. PULLED AVA CATCHER ON WRP @ 5837' RKB, NO VALVE. SET 2.28" x 83.5" JUNK CATCHER @ SAME. RAN POCKET PUNCH TO GLM @ 5441' RKB: OPEN. SET DV @ 5441' RKB. PULLED DV @ 5741' RKB; OPEN POCKET FOR CIRCULATION. IN PROGRESS. 10/12/12 ATTEMPTED EXERCISE TRDP -IA -SSA @ 1789' RKB IN PREP FOR LOCK OUT. VALVE APPARENTLY SCALED UP; NO MOVEMENT ON FLAPPER OR FLOW TUBE. READY FOR E /L. 10/12/12 (PRE RWO) ATTEMPTED TO FREE UP SEIZED LDS'S. 2 ON THE IC ( BOTH STILL SEIZED). 2 ON THE OC (ONE FREED, 1 STILL SEIZED), ATTEMPTED TO LOOSEN OC POT SLOTTED BLEEDER, STILL SEIZED. BLED OOA FROM 10 PSI TO 0 PSI. 10/13/12 Attempt CMIT (failed). Initial T /IA/OA = 700/1050/100. Able to pump 150 bbls of diesel at 1.0 BPM to IA, final pumping pressures were T /IA/OA= 1550/1525/100. Shut down and wait 30 minutes, read pressures T /IA/OA= 700/325/100. 10/16/12 PERFORMED LEAK DETECT WITH ASSISTANCE FROM LRS. FOUND FLUID ENTERING TUBING FROM IA AT 5741' AND 5441' AND EXITING OUT OF KNOWN FLUID LEAK IN UGNU STRADDLE PACKER ASSEMBLY. SUSPECT SMALL LEAK IN THE IA AS FLUID PASSES THROUGH THE UGNU STRADDLE PACK ASSEMBLY. PUMPED 290 BBLS OF SEAWATER DOWN IA DURING LEAK DETECT PROCESS. FREEZE PROTECTED WELL WHEN DONE WITH 68 BBLS OF DIESEL DOWN IA AND 15 BBLS OF DIESEL DOWN TUBING. • C ©nocoPhillips Time Log & Summary WeItwew Web Reporting Report Well Name: 3A - 09 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 10/22/2012 10:00:00 AM Rig Release: 10/29/2012 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/21/2012 24 hr Summary Move Camp t/ 3B pad, Prep & move rig components t/ 3A -09, SUb on the road @ tool House. 13:00 00:00 11.00 MIRU MOVE MOB P Move Camp t/ 3B pad, Prep & move rig components t/ 3A -09, SUb on the road © tool House. Prep 3A -09 t/ recieve rig. 10/22/2012 Move & spot rig over 3A -09, spot complexes, Rig accepted @ 1000 hrs, r/u & displace well t/ 9.6 ppg brine, nipple down tree nipple up adaptor and BOP stack. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Mobilize sub & pipe shed t/ 3A -09 02:00 07:00 5.00 0 0 MIRU MOVE MOB P Spot sub, lay mats, and set power pack on 3A -09 07:00 08:30 1.50 0 0 MIRU MOVE MOB P Spot pipe sheds 08:30 10:00 1.50 0 0 MIRU MOVE MOB P Work on rig acceptance check list, Rig accepted @ 1000 hrs 10:00 12:00 2.00 0 0 COMPZ RPCOM RURD P Take on brine to pits, finish putting stairways down. 12:00 14:15 2.25 0 0 COMPZ RPCOM RURD P R/U hard lines to tiger tank, Prime pumps. 14:15 15:30 1.25 0 0 COMPZ RPCOM RURD P P/U & test lubricator t/ 250/2500 psi, pull BPV (125 psi) R/D 15:30 15:45 0.25 0 0 COMPZ RPCOM OTHR P flood lines t/ tiger tank test lines t/ 250/ 1500 psi 15:45 18:00 2.25 0 0 COMPZ RPCOM CIRC P Displace well w/ 9.6 ppg brine @ 84 gpm 200 psi, 254 bbl 18:00 19:00 1.00 0 0 COMPZ RPCOM OWFF P Blow down lines observe well for flow (static) Install BPV 19:00 19:15 0.25 0 0 COMPZ RPCOM SFTY P Pre Job safety meeting on Nippling up BOP's 19:15 00:00 4.75 0 0 COMPZ RPCOM NUND P Nipple down tree install test dart, function lockdowns on tubing head, Install adaptor flange, Nipple up stack, Prep tools f/ changing rams. 10/23/2012 Change rams & test BOP's, choke valve failed test rebuild & retest , R/U & pull hanger, tubing parted down hole above second packer, CBU gas to surface circ. well clean Observe well for flow static, POOH UD 2.875 tubing 00:00 00:15 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on changing rams. 00:15 03:15 3.00 0 0 COMPZ RPCOM OTHR P Change rams t/ 2 7/8 X 5 VBR's in top 3 1/2 X 6 VBR's in bottom. 03:15 03:30 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on testing BOP's Page 1 of 7 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 08:45 5.25 0 0 COMPZ RPCOM BOPE P Test BOP's t/ 250/3500 psi, Test Top, Blind & Ann. w/ 2.875 test jt. Test choke valves 1 -14 ( 9 failed ) HCR & Man. choke & kill, TIW & Dart, Auto & Man. IBOP, 4" demco, Acc. Test. 08:45 10:30 1.75 0 0 COMPZ RPCOM BOPE P Rebuild & retest valve Good test 10:30 11:00 0.50 0 0 COMPZ RPCOM RURD P R/D test equipment 11:00 11:30 0.50 0 0 COMPZ RPCOM OTHR P Pull TWC & Dart. 11:30 12:15 0.75 0 0 COMPZ RPCOM RURD P R/U pull hanger, M/U landing jt. BOLDS 12:15 12:30 0.25 0 0 COMPZ RPCOM PULL P P/U on 2.875 tubing string, pull up t/ 130K no indication of shear of p ckers,_wt 131K dropped t/ 47K up wt on idicator. 12:30 15:15 2.75 0 0 COMPZ RPCOM CIRC P Circ. & fill hole took 17 bbls @ 126 gpm 125 psi, circ. well flow incresed 50% , gas buble t/ surface, circ out gas, shut down pump monitor well slight flow, circ. bottoms up, observe well for flow, static, monitor well f/ 30 min. 15:15 15:45 0.50 0 0 COMPZ RPCOM PULD P UD tubing hanger & pups. 15:45 18:15 2.50 2,301 0 COMPZ RPCOM PULL P POOH UD 2.875 tubing, recovered 32 SS bands, 71 jts. SSSV, upper dual string packer, 7' telescoping swivel, string parted in 2 -7/8" mandrel of lower dual packer, leaving 67' of 1.9" OD tubing and the lower completion below the packer in the hole. Total length recovered 2301.07 18:15 19:00 0.75 0 0 COMPZ RPCOM RURD P R/D camco line spooler & casing equipment. 19:00 20:30 1.50 0 0 COMPZ RPCOM BOPE P R/U & test BOP's w/ 4" test jts. Tes Ann. t/ 250/3500 test pipe rams t/ 250/4000. 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P R/D test equip. set wear ring. 21:00 21:30 0.50 0 0 COMPZ RPCOM OTHR P Load shed w/ drill collars & strap tally 21:30 21:45 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on singling in the hole 21:45 23:45 2.00 0 0 COMPZ RPCOM TRIP P Trip in the hole with collars & 12 stnds of drill pipe 10/24/2012 RIH w/ 2" overshot tag fish © 2293' engauge fish t/ 2298' POOH w/ BHA & 1.9" fish 66.58' recovered, M/U &. RiFTw7speaFBHA engauge fish @ 2362' work string, string free w/ 20K extra weight, POOH w/ lower portion of completion, L/D completion , RIH w/ 7" casing scra 3er t/ 5803' top of PBR 5790' 00:00 01:00 1.00 0 0 COMPZ RPCOM TRIP -P-POOH w/ 12 stands dp & 2 drill collars 01:00 01:15 0.25 0 0 COMPZ RPCOM PULD P P/U BHA components 01:15 01:30 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on P/U BHA 01:30 02:30 1.00 0 223 COMPZ RPCOM PULD P P/U Overshot BHA Page 2of7 Time Los • • 9 Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 02:30 04:00 1.50 223 2,293 COMPZ RPCOM TRIP P Single in the hole f/ 223' t/ 2293' tag top of fish. 04:00 04:45 0.75 2,293 2,298 COMPZ RPCOM FISH P Break circ. @ 84 gpm 50 psi, tag up @ 2293' pump psi increase, shut down pumps slack of t/ 2298' (5' of swallow) P/U no overpull observed, estatblich circ. 84 gpm 70 psi. 04:45 05:00 0.25 2,298 2,298 COMPZ RPCOM OWFF P Blow down Top Drive Observe well for flow static. 05:00 05:30 0.50 2,298 220 COMPZ RPCOM TRIP P POOH f/ 2298' t/ 220' 05:30 06:30 1.00 220 0 COMPZ RPCOM PULD P Stand back & UD BHA & fish length of fish recovered 66.58' of 1.9" pipe 06:30 07:00 0.50 0 0 COMPZ RPCOM OTHR P Clean & clear rig floor, p/u BHA components f/ next run 07:00 07:15 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on P/U BHA 07:15 08:15 1.00 0 223 COMPZ RPCOM PULD P M/U spear BHA 08:15 09:30 1.25 223 2,299 COMPZ RPCOM TRIP P TIH f/ 223' t/ 2299' 09:30 10:30 1.00 2,299 2,362 COMPZ RPCOM FISH P M/U Top drive tag up on top of fish @ 2358' slack off t/ 2362' work over pull t/ 40K, bleed jars off, Work string t/ 155K on indicator broke free w/ 20K weight increase. Rack stand back. 10:30 11:00 0.50 2,362 2,357 COMPZ RPCOM OWFF P Observe well for flow static 11:00 12:30 1.50 2,357 223 COMPZ RPCOM TRIP P POOH f/ 2357' t/ 223' 12:30 12:45 0.25 223 223 COMPZ RPCOM OWFF P Observe well for flow static 12:45 13:30 0.75 223 0 COMPZ RPCOM PULD P Stand Back & UD BHA 13:30 13:45 0.25 0 0 COMPZ RPCOM RURD P R/U t/ UD fish, Lower packer assy. & tubing 13:45 14:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on UD tubing 14:00 17:45 3.75 0 0 COMPZ RPCOM PULL P POOh w/ 2.875 comletion 17:45 19:00 1.25 0 0 COMPZ WELLPF OTHR P R/D tubing equip. clean & clear rig floor, P/U BHA components 19:00 19:15 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on P/U BHA 19:15 20:15 1.00 0 250 COMPZ WELLPF PULD P P/U scraper/tandem mill BHA 20:15 22:00 1.75 250 5,782 COMPZ WELLPF TRIP P RIH f/ 250' t/ 5782' 22:00 00:00 2.00 5,782 5,803 COMPZ WELLPF CIRC P M/U top drive wash down t/ 5803' w/ 210 gpm 500 psi, pressure increse t/ 1000 psi, P/U circ. Hi -Vis sweep around, large tar balls & sand on return of sweep, tag top or PBR @ 5790' 10/25/2012 Pooh w/ casing scraper,R/U E Line equip. RIH w/ 40 arm caliper logging tool, POOH R/D P/U test Packer & RIH t/ 5803', test WRP t/ 3000 psi, test ann t/ 1000 psi no test wouldn't hold psi, test ava packer t/ 3000 psi good test, pooh t/ 4558' 00:00 00:15 0.25 5,803 5,803 COMPZ WELLPF SFTY P Pre Job Safety Meeting on POOH Simops observe well for flow static 00:15 00:30 0.25 5,803 5,308 COMPZ WELLPF OTHR P Blow down top drive Page 3 of 7 • • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 5,308 250 COMPZ WELLPF TRIP P POOH f/ 5308' t/ 250' hole took proper fill 02:00 03:30 1.50 250 0 COMPZ WELLPF PULD P Stand back & UD BHA, clean & clear rig floor 03:30 03:45 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on Nipple up shooting flange. 03:45 06:15 2.50 0 0 COMPZ WELLPF NUND P Nipple down riser & adaptor flange, nipple up shooting flange, clean up all tools. 06:15 06:30 0.25 0 0 COMPZ WELLPF SFTY P pre job safety meeting on r/u eline 06:30 09:00 2.50 0 0 COMPZ WELLPF ELOG P Spot eline truck r/u eline lubricator and equipment. 09:00 14:00 5.00 0 0 COMPZ WELLPF ELOG P M/U eline tool string 40 arm caliper logging tool, RIH t/ 5800' 14:00 14:45 0.75 0 0 COMPZ WELLPF ELOG P R/D eline tool string & equipment. 14:45 16:30 1.75 0 0 COMPZ WELLPF NUND P Nipple down shooting flange niplle up riser and adaptor flange. 16:30 17:30 1.00 0 221 COMPZ WELLPF PULD P P/U test packer BHA 17:30 20:45 3.25 221 5,803 COMPZ WELLPF TRIP P RIH w/ test packer t /5803 verify no go @ 5792' 20:45 22:15 1.50 5,803 5,699 COMPZ WELLPF RURD P R/U & test WRP t/ 3000 psi P/U UD single p/u pup set packer @ 5699' test t/ 3000 psi test good, test ann. t/ 1000 psi no test, bleed off r/d test equip. 22:15 22:30 0.25 5,699 5,699 COMPZ WELLPF OWFF P Observe well for flow static 22:30 00:00 1.50 5,699 4,558 COMPZ WELLPF TRIP P Pooh f/ 5699' t/ 4558' 10/26/2012 Pooh t/ 2365' set test packer test casing t/ 3000 psi test good, POOH t/ 2275' test casing t/ 3000 psi test good, unset packer gas /oil breaking out. CBU, slight flow, RIH t/ 2460' CBU gas /oil on bottoms up, Weight up t/ 9.8 ppg, OWFF slight flow circ. well wait on sodium bromide, weight system t/ 10.5 ppg, well static, POOH t/ 1326' 00:00 00:45 0.75 4,558 2,365 COMPZ WELLPF TRIP P Pooh f/ 4558' t/ 2365' 00:45 01:45 1.00 2,365 2,385 COMPZ WELLPF PRTS P Set test packer @ 2385' test below packer t/ 3000 psi good test. R/D test equipment 01:45 02:00 0.25 2,385 2,275 COMPZ WELLPF TRIP P Pooh f/ 2385' t/ 2275' 02:00 02:45 0.75 2,275 2,275 COMPZ WELLPF PRTS P Set test packer @ 2275' R/U & test casing t/ 3000 psi good test 02:45 03:00 0.25 2,275 2,275 COMPZ WELLPF OWFF P Observe well for flow gas breaaqking out © surface no pit gain. 03:00 03:30 0.50 2,275 2,275 COMPZ WELLPF CIRC P CBU 210 gpm 150 psi gas & oil observed @ bottoms up. 03:30 03:45 0.25 2,275 2,275 COMPZ WELLPF OWFF P Observe well f/ flow slight flow observed but slowing down gas still migrating to surface. 03:45 04:15 0.50 2,275 2,460 COMPZ WELLPF TRIP P RIH f/ 2275' t12460' below ugnu perforations. 04:15 05:00 0.75 2,460 2,460 COMPZ WELLPF CIRC P Observe well for flow slight flow, weight up system t/ 9.6 ppg brine coming back light, circ © 84 gpm 80 psi 05:00 05:15 0.25 2,460 2,460 COMPZ WELLPF OWFF P Observe well for flow slight flow not slowing down 2 bbl gain per hour. Page 4 of 7 • • • ' Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 05:15 06:00 0.75 2,460 2,460 COMPZ WELLPF CIRC P Weight up system t/ 9.8 ppg 84 gpm 80 psi 06:00 07:00 1.00 2,460 2,460 COMPZ WELLPF OWFF P Observe well for flow slight flow 2 bph rate 07:00 09:30 2.50 2,460 2,460 COMPZ WELLPF CIRC P CBU 84 gpm 50 psi gas & oil @ botoms up continue circ. 09:30 11:30 2.00 2,460 2,460 COMPZ WELLPF OWFF P Observe well for flow well flowing 2 bph rate 11:30 18:00 6.50 2,460 2,460 COMPZ WELLPF CIRC P Circ. © 84 gpm gas & oil observed @ btms up wait on NABR to be delivered 18:00 21:45 3.75 2,460 2,460 COMPZ WELLPF CIRC P Weight up t/ 10.5 ppg w/ sodium bromide 84 gpm 50 psi 21:45 22:15 0.50 2,460 2,460 COMPZ WELLPF OWFF P Observe well for flow well static 22:15 22:30 0.25 2,460 2,460 COMPZ WELLPF SFTY P Pre Job Sasfety Meeting on POOH 22:30 00:00 1.50 2,460 1,326 COMPZ WELLPF TRIP P POOH w/ test packer f/ 2460' t/ 1326' 10/27/2012 POOH w/ test packer, R/U & run in hole w/ Stacker Packer, spot inhb. brine, space out 3' above PBR, set @ 5685' top of PBR @ 5660' POOH, RIH w/ EXPATCH swatch f/ 2260 t/.2409', Pooh w/ swedge t/ 2308' tight spots 20K -67K over pull 00:00 00:45 0.75 1,326 195 COMPZ WELLPF TRIP P POOH f/ 1326' t/ 195' 00:45 01:00 0.25 195 195 COMPZ WELLPF OWFF P Observe well for flow static. 01:00 01:30 0.50 195 0 COMPZ WELLPF PULD P UD & test packer 01:30 01:45 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on P/U BHA 01:45 02:30 0.75 0 0 COMPZ WELLPF RURD P R/U tubing equipment & p/u BHA for Stacker Packer run 02:30 03:30 1.00 0 148 COMPZ WELLPF PULD P P/U BHA as per detail 03:30 06:30 3.00 148 5,711 COMPZ WELLPF TRIP P RIH f/ 148' t/ 5711' 06:30 07:45 1.25 5,711 5,711 COMPZ WELLPF CIRC P Spot 10 bbls corrosion inhibited brine on bottom @ 84 gpm 50 psi 07:45 08:15 0.50 5,711 5,630 COMPZ WELLPF PACK P Space out seal assy. 3' off BPR, pressure up & set FH packer & shear PBR top of PBR 5660.8' top of packer @ 5685.45 08:15 10:15 2.00 5,630 5,630 COMPZ WELLPF CIRC P Circ & condition brine f/ 10.1 ppg t/ 10.5 ppg @ 300 gpm 750 psi 10:15 10:30 0.25 5,630 5,630 COMPZ WELLPF OWFF P Observe well for flow, static 10:30 12:30 2.00 5,630 2,400 COMPZ WELLPF TRIP P POOH f/ 5630' t/ 2400' 12:30 13:15 0.75 2,400 2,400 COMPZ WELLPF CIRC P Spot 15 bbls inhibited brine @ 2400' 84 gpm 65 psi 13:15 13:30 0.25 2,400 2,400 COMPZ WELLPF OWFF P Observe well for flow, static 13:30 14:30 1.00 2,400 28 COMPZ WELLPF TRIP P POOh f/ 2400' t/ 28' 14:30 14:45 0.25 28 0 COMPZ WELLPF PULD P UD BHA 14:45 15:00 0.25 0 0 COMPZ WELLPF SFTY P Pre Job Safety Meeting on P/U BHA 15:00 16:30 1.50 0 179 COMPZ WELLPF PULD P P/U EXPATCH BHA 16:30 18:45 2.25 179 2,260 COMPZ WELLPF TRIP P RIH w/ BHA f/ 179' t/ 2260' Page 5 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 22:45 4.00 2,260 2,409 COMPZ WELLPF SWDG P Swedge Expatch f/ 2260' t/ 2235' Normal swedge pressure 1500 -3000 psi @ 2335' had t/ pressure up t/ 5000 psi t/ swedge tight spot, cont. swedge t/ 2409' 22:45 00:00 1.25 2,409 2,308 COMPZ WELLPF SWDG P POOH w/ swedge f/ 2409' t/ 2308' pulling tight 20K -67K over pull 10/28/2012 Continue Pooh w/ swedge t/ 2120' test casing t/ 2500 psi f/ 30 min. Pooh UD BHA, R/U & RIH w/ 2.875 completion, spot inhibited brine, space out tubing & land on hanger 4.21' above locator, test tubing t/ 3000 psi f/ 30 min. test ann. t/ 2500 psi f/ 30 min. set BPV test in direction of flow, Nipple down stack & riser Nipple up tree. 00:00 00:15 0.25 2,308 2,120 COMPZ WELLPF TRIP P Continue t/ POOH working through patch f/ 2308' t/ 2260' stand back stands t/ 2120' w/ 20 - 40 K over pull through patch 00:15 01:15 1.00 2,120 2,120 COMPZ WELLPFOTHR P Blow down top drive, perform post jarring derrick inspection 01:15 02:45 1.50 2,120 2,120 COMPZ WELLPF PRTS P R/U & test casing t/ 2500 psi f/ 30 min good test, R/D test equip. blow down lines. 02:45 04:00 1.25 2,120 44 COMPZ WELLPF TRIP P Pooh f/ 2120' t/ 44' 04:00 05:00 1.00 44 0 COMPZ WELLPF PULD P UD BHA Clean & clear rig floor,P /U equip. f/ next run 05:00 06:00 1.00 0 0 COMPZ RPCOM RURD P Pull wear ring, R/U t/ run completion 06:00 13:30 7.50 0 5,626 COMPZ RPCOM RCST P Run 2.875 completion as per detail 13:30 15:00 1.50 5,626 5,660 COMPZ RPCOM RURD P R/U & establish circ. w/ charge pump, slack off observe pressure increasa when seals enter PBR, shut down pump, no on locator @ 5660' 15:00 16:15 1.25 5,660 5,570 COMPZ RPCOM PULD P UD 3 jts M/U space out pups and hanger redress seals on hanger, M/U landing jt. 16:15 16:30 0.25 5,570 5,570 COMPZ RPCOM SFTY P Pre Job Safety Meeting on displacing well to inhibited brine 16:30 17:15 0.75 5,570 5,570 COMPZ RPCOM CIRC P Spot 125 bbls inhibited brine in the IA @ 126 gpm 425 psi 17:15 19:15 2.00 5,570 5,656 COMPZ RPCOM PRTS P Land hanger w/ loaator 4.21' f/ PBR, RILDS, R/U & Test tubing t/ 3000 psi f/ 30 min good test, bleed off tubing t/ 1500 psi test ann. t/ 2500 psi f/ 30 min. good test, bleed off tubing and shear SOV, bleed well t/ 0 psi. 19:15 20:15 1.00 0 0 COMPZ WHDBO OWFF P R/D test equip, Observe well for flow, static, Set BPV test in direction of flow t/ 1000 psi f/ 10 min 20:15 21:15 1.00 0 0 COMPZ WHDBO OTHR P Flush stack w/ safe surf-o blow down lines, suck out stack 21:15 21:30 0.25 0 0 COMPZ WHDBO SFTY P Pre Job Safety Meeting on Nippling down stack 21:30 00:00 2.50 0 0 COMPZ WHDBO NUND P Nipple down riser & bell nipple, set stack back, nipple down adaptor spool, Nipple up wellhead. 10/29/2012 Continue Nipple up adaptor and wellhead, attempt t/ test seals leaking, c/o seals test tree and seals t/ 5000 psi, secure wellhead, UD 4" DP, Rig Release @ 2000 hrs. Page 6 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode ' T Comment 00:00 01:45 1.75 0 0 COMPZ WHDBO NUND P Continue Nipple up adaptor flange & tree. 01:45 03:00 1.25 0 0 COMPZ WHDBO PRTS P Pressure test hanger void 250/5000 psi, test adaptor flange wouldn't test. 03:00 04:30 1.50 0 0 COMPZ WHDBO NUND P nipple down adaptor flange, CIO adaptor due to damage on tree removal. 04:30 05:00 0.50 0 0 COMPZ WHDBO RURD P R/U t/ L/D dp while waiting on adaptor flange. 05:00 09:30 4.50 0 0 COMPZ WHDBO NUND P Nipple up adaptor flange & tree test t/ 250/5000 si, test hanger seals t/ p 9 3000 psi, fill tree w/ diesel test tree t/ 250/5000 psi. 09:30 10:30 1.00 0 0 COMPZ WHDBO OTHR P attempt t/ pull BPV pressure on tubing call f/ lubricator. 10:30 15:30 5.00 0 0 COMPZ WHDBO PULD P LID 4" Dp from derrick 15:30 17:00 1.50 0 0 COMPZ WHDBO OTHR P R/U & pull BPV w/ lubricator 200 psi observed on tubing, bleed off, R/D 17:00 20:00 3.00 0 0 COMPZ WHDBO FRZP P R/U LRS pump 85 bbls diesel down IA, put tubing and IA in communication U -Tube until static. Secure Wellhead. 20:00 20:00 0.00 0 0 COMPZ MOVE MOB P Release Rig @ 1800 hrs. Page 3A -09 Post Rig Well Work Summary DATE SUMMARY 1114112 GAUGED TBG TO 2.27" TO 6' RKB. ATTEMPTED PULL RHC @ 5738'RKB. RAN 2.15" LIB TO 5736' RKB, PIC OF 2.31" G F /N. IN PROGRESS. 11/5/12 PULLED 2.313 RHC PLUG BODY @ 5736' RKB. PULLED SOV @ 5583' RKB. CIRC 132 BBL DSL DOWN IA UP TBG TO WELL 13. COMBO MIT 2500 PSI, PASSED. IN PROGRESS. 11/6/12 PULLED DVs © 5308, 4713, 3872, 2588' RKB. SET GLVs @ 2588, 3872, 4713' RKB. LOST KOT TRAY w/ CENTRALIZER (58 "OAL). IN PROGRESS. 11/7/12 FISHED KOT TRAY @ 1276' SLM. SET GLV © 5308', OV @ 5583' RKB. GAUGED TBG TO 2.27" TO 5790' SLM. PRESSURE TEST TBG 2500 PSI, PASSED. ATTEMPTED PULL CATCHER @ 5830' RKB. IN PROGRESS. 11/8/12 BAILED FILL f/ 5790' TO 5796' SLM. R/D FOR MAINTENANCE. IN PROGRESS. 11/9/12 BAILED FRAC SAND AND SMALL RUBBER PIECES FROM 5803 TO 5805' SLM. MARKS INSIDE BAILER BOTTOM INDICATIVE OF MISSING OV FROM 10/11/2012. ATTEMPTED RECOVER VALVE, NO SUCCESS. IN PROGRESS. 11/10/12 PULLED CATCHER FROM 5806' SLM; RECOVERED LARGE METAL DEBRIS IN CATCHER. ATTEMPTED EQUALIZE WRP @ 5837' RKB. MOVED WRP UPHOLE W/ EQUALIZING SLEEVE. UNABLE TO WORK WRP PAST 5786' SLM. IN PROGRESS. 11/11/12 PULLED 2 -7/8" WRP FROM 5791' SLM. PULLING TOOL DESTROYED. BOTTOM CONE OF WRP & 2 SLIPS LEFT IN HOLE. RECOVERED MOST OF RUBBER ELEMENTS W/ PUMP BAILER. IN PROGRESS. 11/12/12 MADE MULTIPLE BAILER AND MAGNET RUNS TO FISH © 6024' SLM. RECOVERED SMALL AMOUNTS OF RUBBER AND 1 SMALL METAL PIECE. 2.24" LIB SHOWS WRP SLIP VERTICALLY AGAINST TUBING WALL. CENTRALIZED 1.57" LIB SHOWS 1/2 OF COLLET PROFILE IN BOTTOM CONE. IN PROGRESS 11/13/12 2.24" LIB SHOWS SLIP @ 09:00. ATTEMPTED TO MOVE SLIP W/ MODIFIED JD SKIRT. CALLED TO ASSIST DOYON 141. IN PROGRESS. lit— C14, • • f a �; WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 1, 2012 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 3A-09 Run Date: 10/25/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A-09 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20699-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: `'‘ ,/ Signed: .1/1.:1. �_s - t9<1 2\9 -7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3A -09 Run Date: 10/8/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20699 -00 SCANNED APR 0 2 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 2(0 Signed: � d f • • " r E, /SEANPARNELLGOVERNOR k ALASKA OIL AND GrAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 J. Brett Packer Workover Engineer ConocoPhillips Alaska, Inc. t q I - ( 711 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A -09 Sundry Number: 312 -314 Dear Mr. Packer: St:,ANNEO AUG a 0 Z(J1, Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 aniel T. Seamount, Jr. Commissioner DATED this day of August, 2012. Encl. „/ e T • • ConocoPhillips RECEIVED Alaska AUG 1 5 2012 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AOGCC August 14, 2012 AOGC;C; Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Well 3A -09 (PTD# 181- 194). Producing well 3A -09 originated as exploration well West Sak #23 which was drilled in February 1982. West Sak #23 was drilled to evaluate both the Ugnu and Kuparuk formations. The 7” production casing was run to its current depth at 6,424' MD and a two -stage cement job was pumped to span the Kuparuk and Ugnu formations. A cement bond log indicated good cement • coverage across the Ugnu, but poor cement across the Kuparuk, therefore, several remedial cement squeezes followed to obtain adequate coverage across the Kuparuk. In July 1986, a RWO to recomplete this well as a Kuparuk producer was unsuccessful. The Ugnu squeeze perforations originally passed a pressure test to 2,000 psi, but while performing the remedial cement squeezes on the Kuparuk, the Ugnu perforations broke down and were no longer holding. Another cement squeeze was performed on both the Kuparuk and Ugnu, but they still could not get a pressure test on the Ugnu. An attempt was made to patch the 7" casing across the Ugnu, but the patch did not completely set and parted. Due to a lack of available equipment to patch or isolate the Ugnu perfs, they were running out of options and decided to just set a cement retainer above the Kuparuk and come back at a later time with a better plan. In November 1986, they rigged back up on this well, finished milling up the remainder of the patch left from the previous workover, milled up the cement retainer above the Kuparuk, and cleaned out the well to PBTD. A selective completion was installed across the Kuparuk A &C sands and a 2 '/8" gas lift completion with a dual- string straddle packer assembly was run to straddle the Ugnu squeeze perfs. Once installed. everything pressure tested, they rigged down. and the well was brought online. Six years later, a workover in September 1992 ensued to pull & replace the straddle assembly. When they pulled the completion, surprisingly, everything pulled out including the upper selective packer, all the way down to the bottom permanent packer. The upper selective packer was replaced and the same style dual- string straddle packer assembly was installed to cover the Ugnu perfs. The completion run in 1992 lasted almost 20 years until August 2011 when the well failed a TIFL. Further diagnostics and leak detect logs determined a leak in the tubing at the bottom connection of the 4' pup joint and the top of the lower AL -5 packer which is within the straddle assembly over the Ugnu. The tubing and IA track each other which means there is also a leak in either the 1.9" bypass between the straddle packers or in one of the AL -5 packers themselves. The proposed workover objective is to pull the tubing including the dual- string straddle packer down to the upper selective packer, patch the 7" casing across the Ugnu using a Baker expandable patch, and run a 2'/8" gas lift completion. This Sundry is intended to document the casing repair as well as request approval to workover the well. A more detailed Well History is included with this sundry application for your reference. If you have any additional questions or require any further information, please contact me at 265 -6845. Sincerely, 7 —c 7� Brett Packer Wells Engineer CPAI Drilling and Wells ti ' VI, lrl, STATE OF ALASKA E'V E D •KA OIL AND GAS CONSERVATION COMM APPLICATION FOR SUNDRY APPROVALS AUG 1 5 2012 20 AAC 25.280 Isbw r t � 1. Type of Request: Abandon r R r Perforate ug for Redrill Perforate New Pool Repair w ell p- , Chan e m r Suspend r Rug Fbrf orations r Perforate r Rill Tubing ge Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate After casing g 5,7 Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development jy . Exploratory r 181 - 194 • 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20699 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 171 3A -09 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25631 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6430 • 6427 6342' 6338' 6041' 6124', 6150', 6200' Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112' 112' SURFACE 2124 10.75 2164' 2164' PRODUCTION 6384 7 6424' 6421' Perforation Depth MD (2320' - 2340', 5992 -6005, Perforation Depth TVD (ft): 2320'- 2340', Tubing Size: Tubing Grade: Tubing MD (ft): 6082 -6100, 6107 -6147, 6172 -6178 5990 -6003, 6079 -6097, 6104 -6144, 6169 -6175 2.875 L -80 6031 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER AL -5 DUAL PACKER MD= 2287 TVD= 2287 PACKER - BAKER AL -5 DUALSTRING PACKER (UGNU SANDS) MD= 2366 TVD= 2366 PACKER - AVA RHS -XL RETRIEVABLE PACKER MD= 5816 TVD= 5813 PACKER - BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE MD= 6028 TVD= 6025 SSSV - CAMCO TRDP -1A SSA MD =1789 TVD =1789 12. Attachments: Description Summary of R f 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/27/2012 Oil ji , Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer © 265 -6845 Printed Name // J. Brett Packer ,1/1- Title: Workover Engineer Signature , /'` `Phone: 265 -6845 Date " // ` y // Commission Use Only Sundry Number: t Z`NA/ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test /Mechanical Integrity Test r Location Clearance r Other: /3` / / C".J 1 t O ,35 p 5 i Subsequent Form Required: ilir � A APPROVED BY Approved by: p/ COMMISSIONER THE COMMISSION Date: ��' ` ' p��Ae (� V �"'' i31FtN�fO►�t0 e17 . � // ��"{► tt ,n-� Submit in Duplicate (- F•Ly -r�•• 0/.3 !l ORIGINAL i� €0� �- „ • • 3A -09 Well History Summarized by Brett Packer Producing well 3A -09 originated as exploration well West Sak #23 which was drilled in February 1982. West Sak #23 was drilled to evaluate both the Ugnu and Kuparuk formations. Conventional cores, sidewall cores, and open -hole logs were obtained from both these formations. The 7" production casing was run to its current depth at 6,424' MD and a two -stage cement job was pumped to span the Kuparuk and the Ugnu. They did not bump the plug on the 1 stage across the Kuparuk. A cement evaluation tool (CET) log indicated good cement coverage across the Ugnu from 2,205' - 2,700' but showed inadequate cement across the Kuparuk with a cement top at 6,270' below the Kuparuk. Therefore, the 7" casing was perforated from 5,914' - 5,916' and squeeze cemented w/ 31 bbls cement. The Kuparuk A &C sands were then perforated in four runs between 5,992' - 6,178' RKB. A drill -stem test showed an average of 450 bopd from the Kuparuk A &C sands. Afterward, a bridge plug was placed above the Kuparuk at 5,874' w/ cement on top so that the Ugnu could be perforated for a flow test. The Ugnu was perforated from 2,320' - 2,340' and showed no flow potential at all. Therefore, the Ugnu was squeeze cemented and the well was left with a cement retainer and cement plug in the 7" casing across the Ugnu as well as the bridge plug & cement set above the Kuparuk. Later, this wellbore was to be utilized as a Kuparuk producer and the well name changed to 3A -09. In July 1986, a RWO to recomplete this well was unsuccessful. After milling out the cement retainer and cement in the 7" casing across the Ugnu, the Ugnu squeezed perforations passed a pressure test to 2,000 psi. They continued in the hole and milled up the cement and bridge plug in the 7" casing above the Kuparuk and pushed the plug to a PBTD of 6,316' MD. They ran another CET log and determined the previous remedial cement squeeze across the Kuparuk was not sufficient, therefore, a bridge plug was set at 6,060' RKB, the 7" casing was perforated from 6,040' - 6,042' and a 2 " remedial cement squeeze was done. After milling out this cement retainer, and while attempting to get a pressure test on the Kuparuk squeezed perfs, the Ugnu perforations broke down and were no longer holding. As a result, another cement retainer was run to 6,030' MD, 8 bbls cement was pumped below the retainer into the squeeze perfs from 6,040' - 6,042', then a retrievable test packer was run and set at 5,730' and 31 bbls cement was pumped below the test packer into the perfs at 5,992' - 6,002', then the test packer was moved uphole to 2,009' and 33 bbls cement squeezed into the Ugnu perforations at 2,320' - 2,340'. After WOC, they drilled out the cement in the 7" casing across the Ugnu and across the squeezed perfs at 5,992' - 6,005'. They ran a test packer and the pressure test failed again. They ran another CET, then milled up the bridge plug at 6,060' and pushed it to bottom at 6,317'. They decided to attempt to patch the 7" casing across the Ugnu perfs, a 40' Homco patch was installed from 2,310' - 2,350' MD, but the patch failed to set completely and they pulled out of the hole with only the upper 20' of the patch. They picked up a test packer, RBIH and set at 2,470' below the stuck patch and tested the Ugnu perfs and they failed once again. Running out of options, they decided to set a cement retainer at 5,856' and come back later with another plan. In November 1986, they rigged back up on this well, commenced milling up the remainder of the patch from 2,338' - 2,351', then continued into the hole and milled up the cement retainer at 5,856'. They cleaned out the well to PBTD, re- perfed from 5,992' - 6,005', then set a DB permanent packer and tailpipe at 6,028'. An FH straddle packer assembly was run and set at 5,830', then a 2'/8" gas lift completion with a couple AL -5 dual string packers were run to straddle the Ugnu perforations from 2,289' - 2,366'. Once installed, everything pressure tested, they rigged down, and the well was brought online. Six years later, a workover in September 1992 ensued to pull & replace the straddle assembly. When they pulled on the tubing, the tubing parted below the upper AL -5 dual string packer. The upper packer was removed and they commenced fishing the remaining completion. They latched onto the tubing stub, pulled up with 100K lbs and it came free. When they got out of the hole, they discovered they had retrieved the lower AL -5 packer, the entire tubing string, seal assembly, PBR, FH packer, blast joints and seal assembly down to the bottom DB packer. The upper selective packer was replaced with an AVA RHS -XL retrievable packer and the same style dual- string straddle packer assembly was installed to cover the Ugnu perfs. The completion run in 1992 lasted almost 20 years until August 2011 when the well failed a TIFL. Further diagnostics and leak detect logs determined a leak in the tubing at the bottom connection of the 4' pup joint and the top of the lower AL -5 packer which is within the straddle assembly over the Ugnu. The tubing and IA track each other which means there is also a leak in either the 1.9" bypass between the straddle packers or in one of the AL -5 packers themselves. The proposed workover objective is to pull the tubing including the dual- string straddle packer down to the upper selective packer, patch the 7" casing across the Ugnu using a Baker expandable patch, and run a 2 7 /s " has lift completion. • 3A -09 Ri g Workover • Pull & Replace 2 ' /g" Tubing, Install 7" Casing Patch (PTD #: 181 -194) Current Status: This well has been SI since August 2011 due to ann -comm issues. A tubing leak was found at the bottom connection of the 4' pup joint and the top of the lower AL -5 dual - string packer. The leak is within the straddle section and the tubing and IA track each other indicating there is a leak in either the 1.9" bypass or in one of the AL -5 packers themselves. Scope of Work: Pull the 2 ' /8" tubing and straddle packer assembly which is currently straddling Ugnu perfs down to the upper selective packer. Install a 7" casingpatch across the Un u perfs an install a 2 '/8 "was lift string. General Well info: L � / /6, / /25 , _ Z 7_17 S Well Type: Producer 4 .– 2 t • MPSP: 2,217 psi (Avg. SITP = 500 psi, prior to plug set in t u bing tail) Reservoir Pressure /TVD: 2,821 psi / 6,044' TVD (9.0 ppg) from Panex on 9/17/07. Wellhead type /pressure rating: McEvoy Gen I, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -OA passed on 11/15/10. CMIT -TxIA— Failed on 10/29/11. Earliest Estimated Start Date: September 27, 2012 Production Engineer: Evan Reilly / Jeremy Mardambek Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre -Rig Work 1. RU Slickline: Pull CA -2 plug at 6,041' MD. Obtain SBHP. Re -set CA -2 plug. Install 2-7/8" WRP at 5,837' MD. Set catcher sub on top of plug. Pull GLV's and dummy off GLM's #1-4. Pull DV from GLM #5 at 5,741' MD, leave pocket open. 2. CMIT -TxIA to 3000 psi. a. If CMIT -TxIA fails, run LDL to determine if leak is only at 2365' or if any flow is going down the tubing past the WRP. 3. PT tbg & csg packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if seeing any pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. f yG „ �, fc 3. Set BPV & blanking plug, ND tree, NU BOPE & test to 250/3500 psi. '� 2 r a i 1 L,' b7 C' C h s � 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 2 -7/8" tubing. a. If straddle packers and /or seal assembly will not pull free, RU E -line: Fire a string shot and cut the tubing at 5775' RKB (middle of the first full joint above the PBR). i. If straddle packers still will not release, RU E -line: Fire a string shot and cut the tubing at 2265' RKB (middle of the first full joint above the upper straddle packer). ii. RIH w/ overshot dressed for 2 -7/8" tubing on 3 -1/2" IF drillpipe, latch onto tubing stub and jar straddle packer assembly free. POOH standing back drillpipe. • 3A -09 Ri g Workover Pull & Replace 2 ' /8" Tubing, Install 7" Casing Patch (PTD #: 181 -194) b. RIH w/ overshot dressed for 2 -7/8" tubing on 3 -1/2" IF drillpipe, latch onto tubing stub and jar seal assembly free. POOH laying down drillpipe. 6. Offload old tubing, rack & tally new tubing. 7. RIH w/ casing scraper & 2 -7/8" stinger on drillpipe, cleanout down to the bottom of the PBR. 8. POOH standing back drillpipe. 9. RU E -line: RIH w/ HES 7" caliper, log from 5800' back to surface, RDMO E -line. 10. MU test packer and RIH on drillpipe to 5700' MD, set test packer, PT below to 3000 psi, PT backside to check for leakoff (may leak thru the Ugnu squeeze perfs). If leaking, work test packer uphole to verify leak location. a. With drillpipe in the well, set a storm packer at —100' w/ drillpipe hanging below. b. NDBOP & Tubing head. L ( h /Soo r, c. Replace tubing head and IC packoffs. d. NU BOP & test to 250/3500 psi. e. Release storm packer and POOH laying down storm packer. 11. Continue POOH standing back drillpipe. Lay down test packer. 12. MU Baker 7" Expandable Patch, RIH to 2366' MD, circulate corrosion inhibited fluid in the IA behind the patch, install Ex- Patch. PT casing to 3500 psi. 13. POOH laying down drillpipe. 14. MU new 2 -7/8" GL completion and RIH to just above the PBR. 15. Slowly cycle the charge pump and look for pressure increase as the seals engage the PBR. Shut down charge pump. Space out 1' from fully located. Mark the pipe and POOH two joints. 16. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited brine. Land the hanger, RILDS. 17. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 18. Pull the landing joint, install two -way check. 19. ND BOPE. 20. NU and test tree. Pull two -way check. 21. Swap well over to corrosion inhibited seawater. 22. Freeze protect through the SOV, set BPV. 23. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV from lower mandrel, install GLD. Pull catcher sub, pull WRP, pull CA -2 plug. 4. Turn well over to operations. • • ConocoPhill s Well: 3A -09 2012 RWO Proposed Completion DS C 16" 62.6# H -40 to 112' MD e ti9 10 -3/4" 45.5# J -55 to 2,164' MD y. / Baker 7" 260 Expandable Casing Patch i 3 Joints, 6" OD/5.5" ID (pre - expansion), 6.276 "OD /5.776" ID (post - expansion), 80 ksi from Ugnu Squeezed Perfs 2,320' - 2,340' MD 2272' - 2392 MD o New 2 -7/8" Gas Lift Completion . ....... 2 -7/8" 6.50 L-80 EUE 8rd Tubing to surface. 2.312" Landing Nipple w / 'DS' profile @ - -500' MD (5x) 2 -7/8" x 1" KBMG Gas Lift Mandrels @ TBD arr Existing Completion Existing Completion xri»>rrrrr_ AVA PBR @ 5,801' MD (3.375" ID) r AVA RHS-XL Packer @ 5,816' MD 2 -7/8" x 1 -1/2" MMG Prod. Mandrels @ 5,857', 5,939', and 6,018' MD. Baker Packer w/ 5' SBE @ 6,028' MD 1st Remedial Cmt Squeeze Perfs 5,914' - 5,916' MD ® 2.25" Landing Nipple w / 'D' profile @ 6,041' MD _ ® L C4 sand perfs 5,992' - 6,005' MD _ L L 2nd Remedial Cmt Squeeze Perfs (9040' - 6,042' MD • )DC "o A1—A4 sand perfs 6,082' — 6,178' MD — 1 School of Fish ' it , Cement retainer, bridge plug, 1.5" CV & latch, (2x) 1.5" DV's, and the kitchen sink @ 6,317' MD 7" 26# J -55 BTC shoe at 6,424' MD 1■ , I Updated: 8/13/2012 .. a KU P • 3A -09 ConocoPhillips ' Well Attributes Max Angle & MD TD AIa,Sita3 Uu: Wellbore API /UWI Field Name Well Status Inc! (1 MD (ftKB) Act Btm (ftKB) 500292069900 KUPARUK RIVER UNIT PROD 3.75 5,197.01 6,424.0 Comment H2S (ppm) Date Annotation End Date KB .Grd (ft) Rig Release Date SSSV: TRDP 210 11/13/2010 Last WO: 9/21/1992 35.29 2/25/1982 Well Config: - 3A-09, 6/19/2012 8:58:46 AM Schematic -Actual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,209.0 12/26/2008 Rev Reason: GLV C/O ninam 6/19/2012 HANGER, 29 '--" . Casing Strings It Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 40.0 2,164.0 2,164.0 45.50 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 40.0 6,424.0 26.00 J -55 BTC CONDUCTOR, Tubing Strings 42 -772 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO I 2 7/8 2.441 I 29.4 I 6,033.6 I 6,031.0 I 6.50 L - 80 EUE8RDABM SAFETY VLV, 1,789 V. ° I Completion Details IIIII Top Depth II (TVD) Top loci Nomi.,. SURFACE. Top (ftKB) (RKB) n Rem Description Comment ID (in) 4o - z.7e4 29.4 29.4 -28.98 HANGER MCEVOY GEN III TUBING HANGER 3.500 - 1,788.9 1,788.9 -5.32 SAFETY VLV CAMCO TRDP -1A -SSA SAFETY VALVE 2.312 BULLN2,286 ' _ 2,284.8 2,284.7 1.34 PACKER BAKER AL -5 DUALSTRING PACKER (UGNU Sands) 2.375 CONNECTOR, 2.286 2,365.8 2,365.7 2.00 PACKER BAKER AL - 5 DUALSTRING PACKER (UGNU Sands) 2.375 PACKER, 2,287 - .. air .. PACKER, 2,285 ;�,,. 5,798.9 5,796.4 1.63 SEAL ASSY AVA LOCATOR SEAL ASSEMBLY 2.437 i SWIVEL, 2,294 �: 5,801.4 5,799.0 1.62 PBR AVA PBR 3.375 5,815.5 5,813.1 1.58 PACKER AVA RHS-XL RETRIEVABLE PACKER 3.000 SOZ 5,983.0 5,980.5 1.63 BLAST RINGS CARBIDE BLAST RINGS 2.441 2.320 6,032.6 6,030.0 1.50 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.437 Cement SW, . 020 2 320 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd SHORT STRING I 1.9 I 1.516 I 2,285.6 I 2,377.4 I 2,377.3 I 2.75 I N-80 NU -10R SAFE JT i Completion Details 4 , `.r' CONNECTOR. Top Depth 2,366 = (TVD) Top Intl Nomi... PACKER, 2,366 PACKER, 2,368 �' Top (ft ftKB) KB) ( (') Item Description Comment ID (in) 2285.6 2,285.5 1.35 BULLNOSE PERFORATED BULLNOSE 1.550 BULLNOSE. L „ 2286.4 2,286.4 1.37 CONNECTOR LEFT HAND SAFETY CONNECTOR 1.625 2,286.7 2,286.6 1.37 PACKER BAKER AL -5 DUAL PACKER 1.900 II 2,294.2 2,294.1 1.47 SWIVEL TELESCOPING SWIVEL, SUB SCOPE DOWN 1.550 GAS LIFT, - __ 2,363.5 2,363.4 2.00 SAFETYJT SHEAR OUT SAFETY JOINT 1.550 2,552 - 2,365.8 2,365.7 2.00 CONNECTOR LEFT HAND SAFETY CONNECTOR 1.550 GAS LIFT, 4,072 I. 2,366.1 2,366.0 2.00 PACKER BAKER AL -5 DUAL PACKER 1.900 2,3762 2,376.2 200 BULLNOSE PERFORATED BULLNOSE 1.550 GAS LIFT, 4,930 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd pu TUBING Original 6.15 3.000 6,028.0 6,047.3 6,044.8 GAS LIFT, 5,441 I OM Completion Details Top Depth (TVD) Top Inc' Nomi... GAS LIFT, Top (ftKB) (RKB) (') Item Description Comment ID (in) 5.741 6,028.0 6,025.5 1.51 PACKER BAKER DB RETRIEVABLE PACKER; 60K TO RELEASE 3.000 IF 6,040.7 6,038.2 1.25 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,046.6 6,044.1 1.25 SOS CAMCO SHEAR OUT SUB 2.441 REAL ASSY, . 5,799 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) P8R, 5,801 Top Depth PACKER, 5,816 (TVD) Top Inc] M I F- Top (RKB) (RKB) (') Description Comment Run Date ID (in) . 6,041 6,038.2 1.25 PLUG 2.25 CA -2 PLUG 8/25/2011 0.000 Ill 6,124 6,121.4 1.25 FISH CV 1.5" CV IN RATHOLE 7 /17/2000 7/17/2000 PRODUCTION, 6,150 6,147.4 1.25 FISH DMY GLVs TWO 1.5" DMY GLVs LOST IN RATHOLE 7/20/2007 5,857 7/20/2007 - 6,200 6,197.4 1.25 FISH CV 1.5" CV WRU LATCH, LOST IN RATHOLE 11/29/2005 11/29/2005 PRODUCTION, 1.1 Perforations & Slots 5.939' Shot Top (TVD) Btm (TVD) Dens 1171.11, Top (ftKB) Btm (RKB) (ftKB) (ftKB) Zone Date Oh- Type Comment 2,320 2,340 2,320.0 2,339.9 UGNU, 3A-09 7/1/1986 6.0 SOZ UGNU PERFS IPERF, _ 5,992 6,005 5,989.5 - 6,002.5 C-4, UNIT B, 11/8/1986 12.0 IPERF 90 deg. phase; 5" II Gun 5,992 - 6,005 - - A 09 6,082 6,100 6,079.4 6,097.4 A-4, A -3, 3A-09 10/17/1992 6.0 RPER 0 deg. phase 2 1/8 HJ "Ene rjet PRODUCTION, 6.018 6,084 6,100 6,081.4 6,097.4 A -3, 3A -09 11/8/1986 4.0 IPERF Odeg. phase 21 /8" Enerjet 6,107 6,147 6,104.4 6,144.4 A -2, 3A -09 11/8/1986 4.0 IPERF 0 deg. phase 2 1/8" Enerjet SEAL ASSY, PACKER, 8,028 : . 6,107 6,147 6,104.4 6,144.4 A -2, 3A -09 10/17/1992 6.0 RPERF 0 deg. phase 2 1/8" Enerjet 6,033 ` "'_=' 6,172 6,178 6,169.4 6,175.4 A-1, 3A -09 10/17/1992 4.0 APERF 21/8 "Enerjet NIPPLE,6,041 ! ■ '! PLUG, 6,041 If SOS,6,047 Mandrel Details Top Depth Top Port APERF, (TVD) Incl OD Valve Latch Site TRO Run 6,082 -6,700 . Stn Top (RKB) (RKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Cont,.. IPERF, 6,084$100 1 2,551.6 2,551.4 1.50 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,282.0 8/16/2011 3:00 FISH, 6,124 I 2 4,071.8 4,071.3 1.48 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,283.0 8/18/2011 2:00 IPERF, 3 4,930.2 4,929.0 3.50 MMH FMHO 1 GAS LIFT GLV BTM 0.188 1,314.0 8/18/2011 11:30 6.107 RPERF, 4 5,441.4 5,439.1 3.45 MMH FMHO 1 GAS LIFT OV BK 0.188 0.0 8/17/2011 6:30 6,107 - 6,147 5 5,740.7 5,738.3 1.79 CAMCO MMG-P 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/20/2007 10 :30 FISH, 6,150 6 5,857.2 5,854.8 1.50 CAMCO MMG-P 1 12 PROD DMY RK 0.000 0.0 9/7/2007 5:00 7 5,939.2 5,936.7 1.50 CAMCO MMG-P 1 12 PROD DMY RK 0.000 0.0 9/7/2007 5:30 APERF, 6,172. 6,178 0 El 8 6,017.9 6,015.4 1.54 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/7/2007 1:30 FISH, 6,200 PRODUCTION, 40 -6,424 TD, 8,424 KUP 3A -09 ConocoPPhill � `9 Alaska . Irlc. Conoco Plentp KB-Grd (ft) Rig Release Date ••• Well Gonne: -3A -09, 6/19/20128: 546 AM 35.29 2/25/19$2 8 Schematic - Actual HANGER, 29 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 2,320.0 2,340.0 2,320.0 2,339.9 Cement Squeeze 7/1/1986 Squeeze off Ugnu Perfs Notes: General & Safety MI End Date Annotation CONDUCTOR, 1/9/2003 NOTE: WAIVERED WELL: 1A x OA COMMUNICATION 42 - 1 42 - 112 Is 10/9/2003 NOTE: TUBING SCALE @ 5800' - 6054' lig SAFETY VLV, _ 11/1 0 /2010 NOTE: View Schematic w/ Alaska Schematic9.0 1,7e9 9/14/2011 NOTE: TUBING LEAK LOCATED @ 2369' IN LOWER AL -5 PACKER USING ELINE LDL SURFACE, It 40- 2,184 lit BULLNOSE, 2,OR6 CONNECTOR. , 2,288 --- PACKER, 2,287 - PACKER, 2,285 �,.. SWIVEL, 2.294 l„ i SQZ, 2.320 -2,340 Cement 602, 2,320 SAFETY IT, 2,364 . CONNECTOR, - :. 2,386 PACKER, 2,366 PACKER, 2,386 i BULLNOSE, 2.376 GAS LIFT, 2,552 I. GAS LIFT, 4,072 GAS LIFT, 4,930 GAS LIFT, 5,441 �* a I ' , GAS LIFT, 5,741 a. : .: it SEAL ASSY, 5.799 PBR, 5,801 PACKER, 5,816 _ -_ PRODUCTION, 5.857 IL Q I Q J PRODUCTION, 5,939 or ir IPERF, 1 - -- 5,992-6,005 al PRODUCTION, 8,018 PACKER, 6,028 SEAL ASSY, 6,033 NIPP 6,04 PLUG. 6,041 It 505, 6,047 APERF. 6,082-6,100 PERF, 6,084-6,100 FISH, 6,124 IPERF, 6,1076,147 RPERF, 6,107-6,147 FISH, 6,150 APERF, 6,1726,178 FISH, 6,20. PRODUCTION. 40-8,424 TD, 6,424 ` c r6 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 `> " 4 RE: Leak Detect Log: 3A -09 Run Date: 11/28/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20699 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: V Gkk Signed: )44-■ l WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 19, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 $tNik1E,0 S E RE: Multifinger Imaging Tool (MIT) / Leak Detect Log: 3A -09 Run Date: 9/14/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -09 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 20699 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 401/1"1— Signed: ' 4 .r / • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~f.. ~~ ~, e Oi€ Gas ~o.~s ~~,:~, w~, chop APR ~ ~ `~;:~ ~., , .~ ~~ ~~-~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15t1i, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kv lein~ ConocoPhillips Well Integrity Projects Supervisor C~ ConocoPhiliips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ~~ Report of Sundry Operations (10-404) Kuparuk Field Date 411 712 0 0 9 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 3A-09 (PTD# 181-194) Report O~led TIFL • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, December 11, 2008 2:48 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3A-09 (PTD# 181-194) Report Of Failed TIFL Attachments: 3A-09 Wellbore Schematic.pdf; 3A-09 TIO Plot.ppt Jim/Tom, Page 1 of 1 Kuparuk gas-lifted producer 3A-09 (PTD# 181-194) failed a TIFL on 11/15/08 during the course of regularly scheduled waiver compliance testing. Due to an oversight on our part, the TxIA communication was not reported to your office within the allotted 72 hour period. Wellwork to repair the communication was completed on 11/27/08 and a subsequent TIFL passed on 12/9/08. Attached is a 90 day TIO plot and a schematic. «3A-09 Wellbore Schematic.pdf» «3A-09 TIO Plot.ppt» ~ Please contact me at your convenience if you have questions or comments:`" "" "` Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ' iP ,~~:4 ` t '~~ i ~, hd ~ k ALL` i V ~~~~ t 12/10/2009 T!I!O Plot - 3A-09 1200 1000 800 N a 600 400 200 ,.:, ., -.~ ... Ir .............................................. ~,i .'~............................................ ii ..i................ i .................. . i ...... ~:~~ . ~ ................................................................................................. G i........................... ~d .......... . 0 +++++ 11-Sep-08 24-Sep-08 07-Oct-08 20-Oct-08 02-Nov-08 15-Nov-08 28-Nov-08 Date 200 150 a E as 100 Y 0 V 50 0 U KRU 3A-09 Car~~coFhillips Alaska, inc. SSSV (1789-1790, ~_ ___ OD:2.875) 3A-09 API: 500292069900 Well T e: PROD An le TS: 2 d 5990 SSSV T e: TRDP Ori Com letion: 2/25/1982 An le TD: 1 d 6430 Annular Fluid: Last WlO: 9/21/1992 Rev Reason: GLV C!O Reference Lo Ref Lo Date: Last U date: 10/16/2007 Last Ta : 6135' SLM TD: 6424 ftKB PKR Last Tan Date:. 10/7/2007 _ Max Hole Angle_ 4 deq (a7 5290__ __ __,__ _,__T (zze5-z28s, - Casing Strin -ALL STRINGS OD:6.151) TUBING (2283-2377, OD:1.900, ID:1.516) PKR (2366-2367, ~. ,' >~. ~. -, ~ -}~, I .xC: C- ]i ~., - SEAL (58015802, OD:2.875) PKR (5816-5817, OD:6.151) TUBING (0-6034, OD:2.875, ID:2.441) PKR (6034b035, OD:6.151) NIP (6047-6048, OD:2.875) TUBING (6034-6054, OD:2.875, ID:2.441) Perf (60826100) Perf (6107-6147) Pert (6107-6147) Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 112 112 62.58 H-40 SUR. CASING 10.750 0 2164 2164 45.50 J-55 PROD. CASING 7.000 _ 0 6424_ 6424 26.00 J-55 Tubin String-,TUBING (Baker AL-5 Qualstring Pkr's & TBG (run off-side 2 7/8" Tbg); UGNU S; -- -- Size To Bottom TVD Wt Grade Thread 2.875 0 6034 6031 6.50 L-80 ABM-EUE 2.875 8034 6054 6051 6.50 J-55 EUE8rdAB-M Tubin Sg tying - 1.9" TUBING _ _ _ Size ,_ __ To _Bottom TVD Wt_ __~ GradE Thread 1.900 ."'283 2377 2377 2.75 1 !1 _ NU 1fC Perforations Summary _ Interval TVD Zone Status Ft SPF Date T e Comment 2320 - 2340 2320 - 2340 C 20 0 7/1/1986 S z 5992 - 6005 5989 - 6002 C-4,UNIT B 13 12 11/8/1986 IPERF 90 deg. phase; 5" HJ II Csg 6172 - 6178 I 6169 - 6175_ _1__ A-1 _ _____ I 6 ~ _4_x_10/17/1992 !_APERF i 2 1/8" Eni Stimulations & Treatments - -_ - --- Interval Date Type i Comment 2320 - 2340 7/1/1986 Cement SQZ I U9nu Perfs --- - - - _. G_ a_s_Lift Mandrels/Valves St ~ MD i TVD Man-Mfr i Man Type V Mfr I V Type V OD ~ Latch j PPort I TRO 'roduction Mandrels/Valves St MD I TVD I Man Mfr I Man DMY I 15 I RK _~ 0.00[ Type V OD Latch Port DMY 1.5 RK 0.00( ,: ~~~ 7 5939 5936 Camco MMG-P DMY 1.5 RK 0.000 0 9/7/: 8 6018 8M5 MMH FMHO DMY _ 1.0 BK_ 0.000 0 9/7/: Other plugs,~uip., et c.) --COMPLETION ___ __ ;, IIrI r,F~ De th TVD T e Descri tion 1789 1789 SSSV Camco TRDP-IA-SSA' 1 ~ - --- 2283 2283 BYPASS 1.9" DUAL STRING IN IA BETWEEN UGNU ISOLATION PACKERS TO ALLOW i I COMUNICATION ACROSS ISO-PACKERS FOR GAS LIFT AND CIRCULATING. t PERFORATED BULLNOSE AT EACH END OF THE 1.9" STRING. ~. Fish -FISH De th 6124 CV 6150 DMY ?nn xC n' __ IN 2.441 Perf (6172b178) ~~iY~~l" Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 6'ry ¢ e ~ ~ ` ~ ~ - . iii ~~ f ~~ ~~~E~ APR ~ ~ 200$ Log Description C.~--. NO. 4650 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04/08/08 1A-19 12031469 LEE TOOL PROD PROFILE 03/21/08 1 1 F-07 12031470 PROD PROFILE t ~ ~- 03/22/08 1 3A-09 11980648 PROD PROFILE (--(9 03/22/08 1 2A-22 11970645 MULTI-FINGER CALIPER 03/20/08 1 1 F-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 i G-09 11996613 INJECTION PROFILE (J 2 - 04/05/08 1 iJ-159 11994646 GLS (o _- 04/06/08 1 2W-15 11996615 PRODUCTION PROFILE 04/07/08 1 1 L-08 11996616 PRODUCTION PROFILE L - 04/08/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r~ .,'...............-.- . ¡ tt 2001 08/30/07 Se heDnan". ." ..1';:....,,\111.,;. "\t'l (~t~(n';':\~'J;:' NO. 4398 srANNED SEP 1 g 2007 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C-¿ Field: Kuparuk Well Job# Log Description Date BL Color CD 2H-02 11846438 INJECTION PROFILE l )ï:l' I"ðLf- C)-:r~ 08/21/07 1 2P-427 11846437 INJECTION PROFILE t" (' ,.QÎ"\ ~ - N. "'$( 08/20/07 1 1A-07 11850429 INJECTION PROFILE l) 1('.. , 1r i-I ::<:~ 08/22107 1 10-08 11850427 SBHP SURVEY /~ -a..ç~ 08/20/07 1 3A-09 11850426 GLS Ñ: I-ICJ¿,¡ 08/20/07 1 2W-09 11850428 INJECTION PROFILE U J:~ I W - .g ,"\ 08/21/07 1 1 L-17 11839642 INJECTION PROFILE UTl' ,qJ-Ö~3 08/23/07 1 2M-13 11839643 PRODUCTION PROFILE 08/24/07 1 1G-04 11837494 INJECTION PROFILE Ul('~ /'7r~-J~/ 08/24/07 1 2N-350 11839644 DDL 8öl- 1--:t5 08/25/07 1 2N-350 11839645 PM IT "t)" / _ I ~ ,<; 08/26/07 1 1 A-OS 11839646 INJECTION PROFILE t),:\ (' / "ir i -/ÆY4 08/27/07 1 2H-15 11837498 INJECTION PROFILE (y:rc... I "'If4 -f1~ 08/29/07 1 2A-04 11839649 INJECTION PROFILE u:r:c- J 1rlI- 65~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 3A-09 PTD # 181-194, notice of Tx wommunication Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, August 26,20079:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: 3A-09 PTD # 181-194, notice ofTx IA communication Attachments: 3A-09.pdf; 3A-09 90 day TIO.gif q J~\ù7 ~t.tq Tom, 3A-09 PTD # 181-194, gas lift producer, is suspect of having T X IA communication. A gas lift survey identified a possible influx of gas into the tubing in the area of the lower straddle packer @ 2366'. This is a non-typical well in that there is a dual string straddle assembly, packers placed at 2285' and 2366', above the more traditional production casing packer set at 5816' The purpose is to deliver lift gas to the lower GLMs while isolating squeezed perforations from 2320-2340'. Please see enclosed schematic. The well is currently shut and has a plug in the nipple @ 6047, note the C sands are open and well is not isolated from the formation. T/I/0=1 040/1300/170 psi. The well is internally waivered for IA X OA communication and is included in the quarterly sustained casing pressure report. Immediate action will be to dummy off the C sand mandrels, load the well, and perform a traditional leak detect log to pinpoint the leak point. I've enclosed a 90 day TIO plot. Let me know if you have any questions. sCANNED SEP 1 1 2007 Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «3A-09.pdf» «3A-09 90 day TIO.gif» 9/512007 WEEK 21:1-MAY-IH 09:31 SCRATCH 6 FLOW TUBING PRESSURE SCRATCH_6 OUTER ANNULUS PRES PKR I ~~~v ~ R:~=-_ ~ ...... .00: Las! 11'10: OJOL D i ~, TV!) : If¡;_ i i 0 112 2 10.750 0 i '164 2164 i 45.50 J·55 I ~O i O· ""'''''' ovv" 5989 6002 C·4.UNIT 13 i 13 ! 12 ~ 2 I--ª- 6081 ·6097 St VMfr .VO!) Latch pon TRO Date Run VI\! i Cmnt 2552 2552 MMH ( 1287 " ",!;I¿UV/ 4072 4071 MMH ( ~ -~!! .MMIi ( St V Type VOD Latch Pan Cml'1t HFCV 1.5 RK 0.000 0 I ¡OPEN HFCV 1.5 RI< OODO 0 i'~ 2.312 2283 2283 BYPASS 1.9" ,.",,,, <::TRJl\lr "rION T( AI ,,¡w 1516 - ---. COMUNICATION . FOR GAS LlF~ ,~..,~ - iJ\ln<::¡::; , """ = =-iI= 2285 PI<R ,ker'AI PKR ,kef 'AI .~~~ SEAL ;~JJf PKR ~ \L R ,,,<::¡::: )¡¡meo' ¡po e~ 6044 P 18 i? . 81312007 .QQ§Q. .? 11912003 I NOTE: i WELL '" v j ," "VI~ = = 1 0/912003 i I NOTE: TUBING SCALE @ 5800' . 6054' = = --- - -. ---- -- --- --.- - --- - -- -- - - -- . PKR SEAL PKR TUBING PKR TUBING Perf (6082-$100) Perf Perf (6107-6147) Perf (6172-6178) 11/26/03 Schlumberger NO. 3053 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD (' 3H-13A Q to '- JCfT PRODUCTION PROFILE 11/08/03 1 3A-09 ?= \ .. '9 L\ PRODUCTION PROFILE 11/09/03 1 2K-24 >., <1 ... I?f\ SBHP SURVEY 11/10/03 1 2K-25 qo -(){::::J. SBHP SURVEY 11/10/03 1 1D-12 9'9 ~ CJ8L. PLUG SET & SBHP SURVEY 09/11/03 1 . ( ",,,,,'... ....... ,''''''' .,."'.... -'" '- ~ t..( i;-' ~ - m- ~ V. . t:, , ~ \ .. ~ fl.... 'v L. ~ ' .--;-. . ... . SIGNE~l"1\" t j';~'~ ~-^'~ DATE: DEC 22 200:: ... }~i~3k~ Oil & GéI.:, Î..Iuil~. '-'v'jiliiS~IOi, Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Anchorage ----- " ' ~','.','¡f'h\!~IH~IHt::I('i n5J~\1 ~ @ 2DO~ \~.... ~~(\ \~)\\:R(r'\\n'\jt\~[Ç,ß." dlHll~ 10 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ,~'J~ Commissioner Tom Maunder, ~~~~'~ P. I. Supervisor ~1 o~,- o\ FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: January 7, 2001 Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sunday, January 7, 2001: I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety Valve System Test Reports indicate I Witnessed the testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with I failure observed'. The surface safety valve on well 3A-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing.today he demonstrated good test procedure and was a pleasure to. work with The wellhoUses .on these two pads were very clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 3A & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components, KRU 3B Pad, 6 wells, 12 components, 19 wellhouse inspections I failure 0 failures Attachment: SVS KRU 3A Pad 1-7-01. CS SVS KRU 3B Pad 1-7-0.1 CS X Unclassified COnfidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well ' Permit Separ Set L~ Test Test Test Date Oil, WAG, GmJ, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE 3A-01 1851860! 64 70 50 P P O~ 3A-03 1852060 3A-05 1852210 64 70 50 P P O~ 3A-08 1852240 64 70 60 P 4 O~ 3A-09 1811940 64 70 60 P P O~ 3A-12 1852390 64 70 60t P P O~ 3A-13 1852810 64 '70 40' .P P O~ 3A-16 1852840 64 70 70 P P ·· OIL 3A-17 ·1961320 · 3A-18 1961330 64 70 · 50· P P · OIL · · Wells: 8 Components: 16 Failures: 1 Failure Rate: 6.3% [290 Remarks: Surface. Safety Valve on well 3A,08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: , Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk/KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit. Separ Set L~ T~t Test Test Date Oil, WAG, G~J, Number~ Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3B-03 1850600 64 70 60 P P ~m 3B-04 1850610 64 70 50 P P ~m 3B-06 1850760 64 70 50 P P Om 3B-08 1850870 3B-09 185113'0 64 70 ~' 70 P P Om 3B-11 .1851150 64 70 '50 P." P om 3B-13 1850230 " ' , , 3B-14 1850240 , Wells: 6 Components: 12~ FailUres: 0 Failure Rate: [] 90 Day Remarks: Good Test 1/9/01 Page 1 of 1 svS KRU 3B Pad 1-7-01 CS.xls ,;A OIL AND GAS ~VATION COMMI ~. ~ REPORT OF SUNDRY WELL OPERATIONS O R I 61tV ,41, 1. Operations Performed: Operation Shutdown . Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator 15. Type of Well: I Development .~. ARCO Alaska. Inc. Exploratory _ 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510I Service __ 4. Location of well at surface 720' FSL, 800' FEL, SEC.7, T12N, R9E, UM At top of productive intewal 750' FSL, 819' FEL, SEC.7, T12N, R9E, UM At effective depth 758' FSL, 820' FEL, SEC.7, T12N, R9E, UM At total dep~th 758' FSL~ ~20' FEL~ SEC.7~ T12Nr R9Er UM 12. Present well condition summary Total Depth: measured 643O' true vertical 6342' Effective depth: measured 6 3 42' true vertical 6 3 38' Casing Length Size Structural Conductor 80' 1 6" Plugging Perforate Other 6. Datum elevation (DF or KB) RKB 87' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-09 9. Permit number/Approval Number 81-194 / ADDrV. N/A . . 10. APl number 50-029-2 0699 00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet None feet Junk (measured) feet None Cemented 250 SX AS II Measured depth True vertical depth 112' 112' Surface 21 3 2' 1 0 - 3 / 4" Intermediate Production 6 3 9 2' 7" Liner 1000 SX FONDU & 21 64' 250 SX AS II 255 SX CLASS G & 6 4 2 4' 125 SX AS I Arctic Pack w/300 SX AS I Perforation depth: measured 6084'-6100', 6107'-6147', true vertical 6081'-6097', 6104'-6144', Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 (J-55 TAIL) @ 6047' Packers and SSSV (type and measured depth) AVA RHS-XL RETR PKR @ 5816', BAKER DB PERM PKR @ 6028', 6172',6178' 61 69'-61 75' 2164' 6421 ' Alaska 0il & Gas Cons, BAKER DUAL STRINK PKR @ 2285' AND 2366'r AND CAMCO 2-7/8" TRDP-1A-SSA SSSV ~ 1789' 13. Stimulation or cement squeeze summary A SAND FRACTURE TREATMENT Intervals treated (measured) 6084'-6100', 6107'-6147', 61 72'-61 78' Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsecluent to operation 5O2 393 5 1109 2624 3851 0 1196 Tubing Pressure 142 301 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification Water Injector__ 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 Rev 09/12/90 Title Operations Engineer Date 2' /f~/'/ f,-?') SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 10/31/92 TO 10/31/92 CPF-3 DS-3A 3A-09 10/31/92 GELLED sEAWATER REFRAC W/ BJ SPECTRA FRAC G3500. PUMPED 200 BBL BD STAGE @ 25 BPM. MAX PRES DURING BD = 6975 PSI, FINAL TREATING PRES = 5005 PSI, ISIP = 1560 PSI, FG = 0.70, EXCESS FRIC = 545 PSI. FLUIDEFF NOT CALCULATED BECAUSE OF PRESSURE SPIKE DURING SHUTDOWN, (ONE PUMP ACCIDENTALLY ROLLED OVER). PUMPED 100 BBLS PAD, FOLLOWED BY 582 BBLS OF 16/20 & 12/18 SLURRY IN 2PPA - 10PPA STAGES. TAGGED PAD W/ SCANDIUM-46, TAGGED 6-10 PPA STAGES W/ GOLD-198. BEGAN HAVING PUMP TROUBLE DURING THE 6PPA STAGE, LOST ALL BUT ONE PUMP DURING FLUSH, RATE DROPPED TO 5 BPM. .WELL SCREENED OUT 16 BBLS INTO 34 BBL FLUSH. JOB DESIGN 120M LBS, IN FORMATION 5M LBS OF 16/20 & l16M LBS OF 12/18, IN WELLBORE 6M LBS OF 12/18. TOT FLUIDS;.SW = 753 BBLS, DSL = 16 BBLS, ADD = 15 BBLS. ALL SURFACE.EQUIPMENT CLEAR OF RADIOACTIVE MATERIAL. (HARRISION/GOLDEN) 0 R 1 6 IN A L ~ OIL AND ~ ~RVATION O=~MI~:~iON FI£POFIT OF SUNDFIY W£LL OP£FIATION$ 1. Operations performed: Operation Shutdown __ Pull tubing X Alter casing Stimulate __ Plugging __ Repair well __ Other Perforate 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 720' FSL, 800' FEL, SEC 7, T12N, RgE, UM At top of productive interval 750' FSL, 819' FEL, SEC 7, T12N, RgE, UM At effective depth At total depth 758' FSL~ 820' FEL~ SEC 7~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 6430' true vertical 6427' 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 87'. PAD 60' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-09 9. Permit number/approval number 81-194(Conserv Order No. 10. APl number 50-029-20699 11. Field/Pool Kuparuk River Oil Pool 261). Effective depth: measured 6342' true vertical 6338' feet Junk (measured) feet Casing Length Size Structural 8 0' 1 6 ' Conductor Surface 21 32' 1 0- 3/4' Intermediate Production 6392' 7 ' Liner Perforation depth: measured 6084'-6100', 6107'-6147', 6172'-6178' M D true vertical 6081'-6097', 6104'-6144', 6169'-6175' TVD Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80(J-55 tail) @ 6047' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 250 SX AS II 112' 112 ' 1000 SX FONDU 2164' 21 64' &250SXASII 255 SX CLASS G 6424' 6421' 125 SX ASI ArcticPack w/ oo x s,RECEIVED NOV - 1992 ,Alaska Oil & Gas Cons. 6omrulss'ton Anchorage AVA RHS-XL RETR PKR @ 5816',BAKER DB PERM PKR @ 6028', CAMCO 2-7/8' TRDP-1A-SSA @ 1789' MD BAKER DUAL STRING PKR @ 2285' AND @ 2366'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaoe Production or In!e~tiQn Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector Oil ,~ Gas Suspended Servica 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10("4C~4 Rev 05/17/89 Title Area Drilling Engineer Date/0/:~/'~ ~_~ ...... SUBMIT I~ DOPUCATE ARCO ALASKA INC. DAILY OPERATION~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3A-09 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029- 0699 81-194 ACCEPT: 09/14/92 12:09 SPUD: RELEASE: 09/21/92 08:09 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 09/15/92 ( 1) TD: 6430 PB: 6342 09/16/92 (2) TD: 6430 PB: 6342 POOH/TBG STRING. LD TBG MW: 8.7 NaC1 CONT MVE F/30 PAD TO 3A PAD. ACCEPT RIG @ 12:30 HRS 09/14/92. RU HARDLINE & KILL LINE. LOAD S/W. PULL BPV. RU OTIS SL. TEST LUB TO 1400 PSI. PULL DV F/GLM @ 5446'. RD OTIS SL. TEST HARD LINE TO 1000 PSI. REPAIR LEAK. DISPLACE WELL W/SW. PMP 50 BBLS DIESEL TO HARD LINE/PROD LINE. SHUT IN. MONITOR WELL. WEIGHT UP BRINE TO 8.7+ PPG. CIRC 8.7 PPG BRINE AROUND. MONITOR WELL-STATIC. 'SET BPV. ND TREE. NU BOPE. PULL BPV. SET TEST PLUG. TEST RAMS & ANN PREV TO 3000 PSI. TEST MANIFOLD TO 3000 PSI. PULL TEST PLUG. MU TBG LANDING JT. WORK PIPE. PULL TBG STRING/PKR FREE W/ 78K#. CIRC THROUGH CHOKE. HAVE GAS BUBBLE IN RETURNS. LD TBG HGR. POOH W/TBG STRING. LD TBG UNLOAD COMP STRING(2-7/8")F/SH MW: 8.8 NaC1 FIN POOH W/TBG. LD 2-7/8" TBG. RECOVERED SS C-LINE BAND, BAKER AL-5 PKR, SHEASR OUT SAFETY JT, 2 JTS 1.9" TBG. MU TRI-STATE O.S. W/3.66 GRAPPLE. PU DC'S OIL JARS, B.S., D.P. & TIH TO TOP OF FISH @ 2358'. PU KELLY, LATCH ON FISH. PU 90K HOOK HEAD, SLIP OFF FISH. RE-LATCH FISH, PU 90K & SLIP OFF FISH. REPEAT SAME RESULTS ON THIRD ATTEMPT. SET BACK KELLY & POOH. RE-DRESS O.S. W/3-5/8" GRAPPLE & TIH TO FISH @ 2358'. LATCH FISH, PU 100K, FISH FREE-CBU. POOH. STD DP & DC'S IN DERRICK. LD TRI-STATE O.S.,SECOND BAKER AL-5 PKR, 109 JTS 2-7/8" TBG, 7-2-7/8" X 1 MERLA GLM'S, 1-2-7/8" X 1-1/2" MCMURRY GLM, BAKER 2-7/8" X 7" PBR · SEAL ASSY W/BAKER 2-7/8" X 7" FHL HYD. SET RETR PKR, 30' OF 2-7/8" BLAST JTS, BAKER SEAL ASSY F/ BAKER DB PERM PKR & ALL TBG PUPS ASSOC W/COMP STRING. RECOVERED SCRAP METAL APPROX 4-1/2" X ll"(LOOKS LIKE PIECE OF CSG PATCH) N.O.R.M. TESTED EVERYTHING PULLED FROM HOLE-OK. UNLOAD COMP ASSY F/PIPE SHED. R ElVED NOV - 1992 ,Alaska Oil & Gas Oons. ~ommtssion Anchorage WELL : 3A-09 OPERATION: RIG : NORDIC PAGE: 2 09/17/92 ( 3) TD: 6430 PB: 6342 09/18/92 ( 4) TD: 6430 PB: 6342 09/19/92 ( 5) TD: 6430 PB: 6342 TIH W/S ASSY F/PKR ON DP MW: 8.8 NaCl PU & RUN DC'S IN HOLE. MU BAKER STORM PKR & SET ON DP. TEST STORM VALVE TO 500 PSI. ND BOPE STACK. BLEED GAS & ARCTIC PAK FROM 7" X 10-3/4" ANN. ND TBG SPOOL. REPLACE SEALS/PRIMARY PACKOFF. REPLACE SECONDARY PACKOFF IN SPOOL. CHANGE PIPE RAMS IN BOP TO 3-1/2". NU TBG SPOOL, TEST FLANGE. INSTALL BOWL PROTECTOR. NU BOP. MU BAKER RETRV TOOL F/STORM VALVE. LATCH INTO STORM VALVE. TEST BOP FLANGE & 3-1/2" PIPE RAMS. PULL BAKER STORM VALVE TO FLOOR. BREAK & LD STORM PACKER. TIH W/DP REMAINING IN DERRICK. LOAD PIPE SHED W/DP, DRIFT & STRAP SAME. PU DP & TIH TO PKR @ 6026'. CIRC HOLE CLEAN. POOH & LD DC'S. PU BAKER SEAL ASSY FOR BAKER "DB" PKR ON DP & TIH. POOH LD DP MW: 8.8 NaCl FIN TIH W/SEAL ASSY ON DP-TAG BAKER DB PKR @ 6026' NORDIC RKB. STING INTO PKR-RU OTIS SL-TEST LUB & RIH W/2.2 GUAGE TOOL TO TOP OF FILL @ 6166'. POOH. MU 2.25" 'R' PLUG ON W/L. RIH & ATTEMPT TO SET IN D NIPPLE-WOULD NOT SET. POOH. MU W/L BRUSH TOOL W/2.25 OD & TIH. BRUSH ACROSS D NIPPLE WHILE BULLHEAD BRINE DN TBG. POOH. MU 2.25" R PLUG & RIH. SET PLUG IN D NIPPLE. POOH. RD W/L UNIT. CBU. POOH W/SEAL ASSY. RE-DRESS SEAL ASSY, RACK & TALLY 2-7/8" COMP EQUIP. PU BAKER DB PKR SEAL ASSY, MCMURRY 2-7/8" TBG, CAMCO 2-7/8" X 1-1/2" GLM W/DV RK LATCH, 1 JT 2-7/8" TBG, AVA RHS-XL RETRV HYD SET PKR W/PBR W/9' STROKE. RD TBG TONGS. RU DP RUNNING EQUIP. TIH W/ABOVE COMP EQUIP ON DP. TAG TOP OF DB PKR, STING IN & LOCATE OUT W/l# UP ON LOCATOR SUB-PRESS UP ON DP TO 3000 PSI & SET AVA RHS-XL PKR, HOLD PRESS F/15 MIN. RELEASE PRESS-TOP OF PBR @ 5791' NORDIC RKB DP MEASUREMENT. POOH LAYING DN DP. TIH W/TRI-STATE OS ON DP MW: 8.8 NaC1 FIN LD DP. PULL BOWL PROTECTOR. LOAD PIPE SHED W/2-7/8" TBG, MEAS DRIFT & INSTALL SEAL RINGS IN TBG. BRING IN COMP JEWELRY, DRIFT & STRAP, CHANGE PIPE RAMS IN BOP TO 3-1/2" & TEST .SAME. DRESS AVA SEAL ASSY F/RHS-XL PKR. PU 2-7/8" COMP STRING & RIH W/SAME-RUN 178 JTS 2-7/8" TBG W/AVA SLICK STICK, 5-GLMS, 2 BAKER AL-5 DUEL STRING PKRS, W/64.80' OF 1.90" TBG BETWEEN PKRS, CAMCO SSSV. TEST SSSV C-LINE & STB INTO AVA RETRV PKR (TOOK 10K OVER STRING WT TO GET BTM AL-5 PKR THRU 7" CSG PERFS @ 2320'-2340'). VERIFY STAB IN W/500 PSI ON TBG. PU TBG STRING TO SPACE OUT F/TBG HGR & SHEARED OUT BAKER SAFETY JT @ 2361' BEFORE SHEAR OUT HOOK LOAD WAS 36K, AFTER SHEAR OUT PU HOOK LOAD 19K. POOH W/TBG & STAND IN DERRICK. LD SSSV & TOP BAKER AL-5 DUEL STRING PKR. RECOVER ALL C-LINE BANDS. RD TBG RUNNING TOOLS, RU DP TOOLS RACK & TALLY 12-4-3/4" DC'S & 6 JTS DP. MU TRI-STATE OS W/3-5/8" GRAPPLE, B.S. OIL JARS, ETC. TIH W/TRI-STATE O.S. ON DP. RECEIVED NOV - 3 Alaska Oil & Gas Cons. (;ommissio,~ Anchorage WELL : 3A-09 OPERATION: RIG : NORDIC PAGE: 3 09/20/92 (6) TD: 6430 PB: 6342 09/21/92 (7) TD: 6430 PB: 6342 MU TRI-STATE OS ON DP MW: 8.8 NaC1 FIN TIH W/OS ON DP. LATCH ON FISH. POOH W/FISH. LD FISHING TOOLS & BAKER AL-5 PKR. POOH W/2-7/8" COMP TBG, DRIFT & STAND IN DERRICK-(CHANGE OUT SEAL RINGS). SLIP & CUT DL. TEST 3-1/2" X 1-1/2" CAMCO GLM TO VERIFY THAT CV IS HOLDING IN 1-1/2" C.V. DRESS AVA SEAL ASSY. MU SEAL ASSY ON 2-7/8" TBG & TIH W/SAME. RUN SEAL ASY ON 3405' OF 2-7/8" TBG. MU X/O F/2-7/8" 8RD TBG TO 3-1/2" IF DP & FIN IN HOLE W/2396' OF 3-1/2" DP TO AVA RHS-XL PKR. STING INTO AVA PKR W/SEAL ASSY & PRESS TEST SEALS TO 2500 PSI. TEST GOOD. BLEED OFF PRESS. POOH LAYING DN 2396' OF DP. LD 4-3/4" DC'S. RD DP FLOOR EQUIP & RU TBG RUNNING EQUIP. PU BAKER AL-5 DUEL STRING PACKERS. BAKER SHEAR SUB SHEARED W/BTM AL-5 PKR +- 60' BELOW ROTARY TABLE & TOP AL-5 PKR GOING THRU ROTARY TABLE. PU & LD TOP DUAL PKR & 2 JTS TBG BETWEEN PKRS. RD TBG EQUIP. RU DP EQUIP, RACK & TALLY 65 JTS DP & 12-4-3/4" DC'S. MU TRI-STATE OS ON DC'S & TIH FOR FISH. MU SPACE OUT PUPS & TBG HGR MW: 8.8 NaCl TIH W/0S ON DP. TAG FISH @ 2320' LATCH ON FISH. RIG TO POOH. POOH W/FISH. RELEASE OS. LD AL-5 PKR & LOAD OUT SAME. POOH W/REST OF 2-7/8" TBG & STAND IN DERRICK. PU TRI-STATE 6" SWEDGE ON DP & TIH THRU TIGHT SPOT @ 2331'. TOOK +- 6K TO PUSH SWEDGE THRU-MADE SEVERAL PASSES THRU TIGHT SPOT & LAST FEW PASSES TOoK ONLY +- 1K TO PUSH THRU. POOH LD DP TOOLS. RU TBG RUNNING TOOLS. RE-DRESS AVA SEAL ASSY. RUN 106 JTS 2-7/8" TBG & COMP JEWELRY. START TO PU BAKER AL-5 DUEL STRING BTM PKR W/1.90" SAFETY SHEAR JT-FOUND THAT SHEAR JT MANDREL HAD BEEN DRIVEN IN PKR RECEPTACLE & GALLED THE SEALING AREA. PULLED & REDRESSED SEAL AREA-INSTALLED NEW MANDREL. MU BAKER AL-5 DUEL STRING PKRS W/2 JTS 1.90" TBG BETWEEN PKRS & 2 JTS 2-7/8"-CONT IN HOLE W/2-7/8" COMP STRING & JEWELRY. RUN 178 JTS 6.5# L-80 EUE 8RD AB-MOD IPC TBG W/JEWELRY & PUPS & 69' OF 1.90 TBG BETWEEN DUEL STRING BAKER AL-5 PKRS. RECEIVED NOV - 1992 Alaska Oil & Gas Cons. Commissior~ ;Anchorage WELL : 3A-09 OPERATION: RIG : NORDIC PAGE: 4 09/22/92 ( 8) TD: 6430 PB: 6342 RIG RELEASED MW: 8.8 NaC1 MU TBG HGR, ATTACH C-LINE & TESTS C-LINE. RAN 31 SS BANDS ON C-LINE. UNABLE TO LAND OUT TBG HGR IN TBG SPOOL-LIKES 1-1/2" SETTING DEEP ENOUGH N TBG SPOOL. RU OTIS WL & RIH W/2.25 LIB TO D NIPPLE-NO OBSTRUCTION UNDER SEAL ASSY. RD WL UNIT. CLOSE SSSV. ND BOP. BTM SEAL ON TBG HGR NOT COMPRESSED ENOUGH TO ALLOW TBG HGR TO SEAT. PU TBG STRING +- 1' & SET DN HARD ON TBG HGR SEALS. COMPRESS SEALS & LAND TBG-RILDS. NU TREE. TEST TREE TO 250 PSI & 5000 PSI-OK. OPEN SSSV. PULL TEST PLUG. SET BAKER AL-5 DUAL PKR'S W/3500 PSI F/15 MIN & TEST 2-7/8" TBG-TEST GOOD. PRESS ANN TO 2500 PSI & TEST CSG-TEST GOOD. BLEED PRESS & TEST SSSV-TEST GOOD. OPEN SSSV & BLEED OFF ALL PRESS. DISPLACE WELL W/DIESEL. CK IN CV NOT HOLDING. RU OTIS SL TO PULL PLUG F/D NIPPLE. RIH W/ RET TOOL F/PLUG-MIS-RUN DID NOT PULL PLUG. RUN BACK IN HOLE W/RET TOOL. LATCH ONTO PLUG & PULL SAME. RD WL UNIT. BLOW DN LINES, SHIP OUT FLUIDS F/RIG PITS. DRESS UP WELL SITE. RELEASE RIG @ 2030 HRS 09/21/92. SIGNATURE: (dri~up~t DATE: ARCO Alaska, Inc. ~ Post Office l~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5933 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 2T-12A 2A-11 3A-9 lA-1 3A-9 1H-3 3K-13 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844 ' CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil .SAPC Unocal Vault (film) .. Chevron ARCO Alaska, Inc. is a Subsidiary of AllanllcRichfieldCompany STATE OF ALASKA . -- ALASK AND GAS CONSERVATION C ~dMISSION , W ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-194 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20699 4. Location of well at surface 9. Unit or Lease Name 720' FSL, 800' FEL, Sec.7, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 750' FSL, 819' FEL, Sec. 7, T12N, R9E, UM 3A-9 At Total Depth 11. Field and Pool 758' FSL, 820' FEL, Sec.7, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 87' RKB, 60' PadI ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 01/29/82 02/14/82 02/25/82* N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+'l'VD) l'9. DirectionalSurvey I 20.'DepthwhereSSSVset i 21. Thickness of Permafrost 6430'MD,6427 'TVD 6342'MD,6338'TVD YES ~[ NO [] 1790' feet MD 1550' , , 22. Type Electric or Other Logs Run DIL/GR/MSFL/SP, FDC/CNL/BHCS/GR, MLL/Caliper, HP Temp-Gradio-Fluid Sampler, Gyro, CET .... 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEiWT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 ' Surf ' ' 112' .... 2q"' ' 250 sx AS II 10-3/4" 45.5# K-55 Surf 2165' 13-1/2" 1000 sx Fondu & 250.sx tS II , , , 7" 26.0# K-55 Sur.f 6424' .. 8-3/4" 255 sx ~lass G & .. . . . 1,25 sx AS I Arctic pac. k w/ 300 sx AS .i 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORE~ interval, size and number) ,SIZE DEPTH SET (MD) PACKER SET (MD) w*5992' - 6005'MD 5989'-6002'TVD, 12 spf. 90° phasin] 2-7/8" 6047' 2289'.2366.5830'. 6084' - 6100'MD 6081 '-6097'TVD & 6028' 6107' - 6147'MD 6104 ' -6144 ' TVD 4 spf 0° phasin;126'. ' '' 'ACID, FRAcTuRE, CEMENT'SQUEEZE, ETC. 6172' - 6178'MD 6169'-6175'TVD .-' -..- DEPTH INTERVAL(MD'i AMOUNT& K1ND OF MATERIAL USED · ', 2320'-2340' 127 sx AS I &. 200 sx CS I 5914'-59i6' ' .1.50. sx C1 ass S992'-R005' !50 sx Class G **Reperforated 6040 ' ,RO~?, 275 s~ 27. PRODUCT. ION TEST ..(See atta.ched Addendum. for fracture data). Date First Production Method of Operation (Flowing, gas lift, etc.) O~/~/R9 . · Date ~f T~s;t- Hours Tested PRODUCTION ~]~;' 8~L-BBL ' GAs~McF W~A:TER-BBL' 'CHOKE SI'ZE ..]1GA~S-oIL RATIO 02/22/82 . 16.5 TESTPERIOD I~ 298 91.4 48/64 . .295 CF/B Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. Il0 1320 24-HOUR RATE I~ 450/day 133/day 0 23.4° (~ 60° :~8. ' ' CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description attached to Well Completion Report dated 3/19/82. 0 9 1987 ,.. Alask~ 0it & ~,s Cons. Commission A~,c~,0rage Form 10-407 * NOTE: Well Worked over & completed 11/5/86. WCl/158 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit. in duplicate~ Top Cretaceous 1273' 1273' Cretaceous interval test: Kuparuk River 5975' 5971' Perf'd 2340' - 2320' Formation Formation Pressure - 1005 psi (calculated) Produced 3.3 bbl of formation water in 9 hrs, 20 mi n. Kuparuk interval test: See attachment w/Well Completion Report date~3/19/82. 31. LIST OF ATTACHMENTS Addendum, (dated 12/15/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~f~ ~~L~ Associate Engineer ]_~,~ Signed 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". Form 10-407 ADDENDUM WELL: 12/13/86 3A-9 Frac'd "A" sand perfs 6084'-6100', 6107'-6147', 6172'-6178' in eight stages per 12/5/86 procedure using gelled diesel, 100 mesh & 20/40 sand. Press'd ann to 2200 psi w/diesel. Tst Ins to 7500 psi; OK. Pmp'd 50 bbls 5% Musol followed by 36 bbls cln diesel @ 2 BPM, 2500 psi. Stage #1: Pmp'd 100 bbls gelled diesel Pad A @ 20 BPM, 4200 psi. Stage #2: Pmp'd 35 bbls gelled diesel Pad B @ 20 BPM, 4200 psi. Stage #3: Pmp'd 10 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM, 4100 psi. Stage #4: Pmp'd 75 bbls gelled diesel Pac C @ 20 BPM, 4050 - 4200 psi. Stage #5: Pmp'd 10 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM, 4150 psi. Stage #6: Pmp'd 16 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 4150 psi. Stage #7: Pmp'd 20 bbls gelled diesel w/8 ppg 20/40 mesh @ 12 BPM, 2600 psi. - Stage #8: Pmp'd 34 bbls gelled diesel flush @ 20 BPM, 5200 psi. Total sand in formation: 400# 100 mesh & ±11,340# 20/40 mesh. Underflushed by 2 bbls leaving approx 675# 20/40 mesh in csg. Load to recover 300 bbls of gelled diesel & 50 bbls 5% Musol & .36 bbls cln diesel. Job complete @ 1153 hrs, 12/13/86. Drilling Supervisor i987 Cons. Commission · Da6e ( ' STATE OF ALASKA '~k~' ALASKA . AND GAS CONSERVATION COMMI .)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other Operation shutdown ~ Stimulate .~ Plugging ~ PerforateXZ Pull tubing 99510 2. Name of Operator ARCO Alaskaa Inc. 3. Address P.O. Box 100360 Anchorage, AK Workover/Compl eti on 4. Location of well at surface 720'FSL, 800'FEL, Sec.7, T12N, R9E, UN At top of productive interval (same as above) At effective depth (same as above) At total depth (same as above) feet feet feet feet 11. Present well condition summary Total depth: measured 6430 'MD true vertical 6427 'TVD Effective depth: measured 6342 'MD true vertical 6339 'TVD Plugs (measured) 5. Datum elevation (DF or KB) RKB 7Q' 6. Unit or Property name Kuparuk River Unit Casing Length Size Conductor 80 ' 16" Surface 2132 ' 10-3/4" P roducti on 6392 ' 7" 7. Well number Feet "~A,r 8. Approval number 17'~ 9. APl number 50-- 029 10. Pool Kuparuk River 0il Pool None Junk (measured) None Cemented Measured depth 200 sx AS II 112'MD 1000 sx Fondu 2164 'MD 255 sx Class G & 6424'MD 125 sx AS I True Vertical depth 112 'TVD 2164 'TVD 6421 'TVD Perforation depth: measured true vertical 5992' - 6005 'MD 6084'-6100'MD 5989' - 6002'TVD 6081 '-6097'TVD 6107'-6147'MD 6104 '-6144 'TVD 6172 ' -6178 'MD 6169 ' -6175 ' TVD Tubing (si2e; grade and measured depth) · 2-7/8", J-55, tbg w/tail ~ 6047' Packers and SSSV (type and measured depth) AL-5 pkrs ~ 2289' & 2366', FH pkr ~ 5830'~ DB pkr ~ 6028'~ & FVL SSSV ~ 1790' 12. Stimulation or cement squeeze summary Intervals treated (measured) 6040'-6042 ' 5992 ' -6005 ' 2320' -2340' Treatment description including volumes used and final pressbre RECEIVED DEC - 8 1986 Alaska 0il & Gas Cons. Commissio Anchorage 13. 275 sx Class G~ 150 sx Cla~? G. :;{00 ~;~ ~:~ I Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ~ubsequent to operation 14. Attachments (Workover Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~'~ ( ~r-- ~ Signed ~,~ ~ .~,f,~L~ Title Assoc~at. Enoi,~.~_r' Date /¢..-,~-~.¢ - Form 10-404 Rev. 12-1-85 ¢ (DAH) SW0/128 Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily IIv Inltructlonl: Prepare and submit the "Initial Rei~ort' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to s~udding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk R/var Auth. or W.O. no. AFE AK1720 ICounty. parish or borough North Slope Borough .Lease or Unit ADL 25631 Title Completion State Alaska ell no. 3A-9 ~/0 AP1 50-029-20699 11/1/86 for each day reported IARCO W.L Prior st~tua if a W.O. 56.24~ 0100 hrs. t~/05/86 -'.,7'~ @ 6424' 6316' PBTD, TIH ppg NaC1 @ 0100 hfs ND tree~.; TIH w cas @ 2330,', mill patch @ 2338'-2351', lost wt. Pmp 20 milt, RIH w/6-1/8" bit, TIH, tag @ 584~~ 6296t. Circ hi-vis pill, POR. RIH w/bit brine, POH. RU Schl, rn 5" csg sun w/12 ~ram. gun took @ 2325; misfire, POOH. Rn GR/JB rn. RIH w/bit & cs$ scrpr to 2300!. 7" @ 6424' 6316' PBTD, TIH w/pkr assy 10.1 ppg NeC1 ..... Rm f/2330'-2350' w/bit & scrpr, POOH. TIH, pipe. Jar pipe loose, wrk pipe to 2315', CBU, POOB, GR/JB rn to 6075', POOH. RU & per~ f/5992-~'60~5 phas/n$. MU DB pkr WLM, set @ 6028", RD Schl. MU FHp~r, TIH v/3½" DP. 7" @ 6424' 6316' PBTN,.TSC SSSV set @ 5830'. Shear off f/PBR, POH, LD DP. Rn 2-7/8" ~ & lnd tbs. Set dual pkrs w/2500 psi @ 2289' & 2366'. Tst tbs &$$SV. SSSV @ 1790'. Press tbg. to 300 psi. Press tbs to 2500 psi. RECEIVED DEC- 8 1986 0it & Gas Cons. Commission Anchorage The a_~lls correct Drilling, Pages 86 and 87. ITitle Drilling Supervisor ARCO Oil and Gas Company Daily WeJi History-Final Report Inst~clions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~t" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, rebort completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish I Alaska Field }Lease or Unit Kuparuk River Auth. or W.O. no. [Title AFE AK1444 Nordic 1 North Slope Borough ADL 25631 IAccounting State cost center code Alaska IWell no. 3A-9 W/O Completion AP1 50-029-20699 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate Workover I 11 / 1/86 Date and depth Complete record for each day reported as of 8:00 a.m. Iotal number of wells (active or inactive) on this i DSt center prior to plugging and ~ bandonment of this well I our ] Prior status if a W.O. 0100 hrs. 11/06/86 7" @ 6421' 6316' PBTD, RR 10.1 ppg NaCl Set BPV. ND BOPE, NU & tst tree to 250/5000 psi. w/diesel. RR @ 1230 hfs, 11/5/86. Displ well RECEIVED PB Depth Kind of rg DEC- 8 1986 Alaska 0il & Gas Cons. C0mrn!ssi0n Anchorage Old TD New TD 6316' PBTD Released rig Date 1'230 hrs. 11/5/86 Classifications (oil, gas, etc.) [ Type completion (single, dual, etc.) Oil [ Single Producing method [ Official rese~oir name(s) Flowing I Kuparuk Sands Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Theatre is correct For form preparat~/~1 and distributt ,o~ Drilling Supervisor see Procedures Manual, Section 10, Drilling, Pages 86 and 87. STATE Of ALASKA '~ ALA( OIL AND GAS CONSERVATION CO~ ,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate .,~ Pull tubing Alter Casing ~ Other [] Workover 2. Name of Operator ARCO Alaska_. Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 720'FSL, 800'FEL, Sec.7, T12N, R9E~ UN At top of productive interval (same as above) At effective depth (same as above) At total depth (same as above) 5. Datum elevation (DF or KB) RKB 70' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number ~A-9 8. Approval number 173 9. APl number 50-- 029-20699 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80 ' Surface 2132' P roducti on 6392 ' 6430 'MD 6427 'TVD 6342 'MD 6339 'TVD Size 16" 10-3/4" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 200 sx AS II 1000 sx Fondu 255 sx Class G & 125 sx AS I CR ~ 5856' None Measured depth ll2'MD 2164 'MD 6424 'MD True Vertical depth ll2'TVD 2164 'TVD 6421 'TVD Perforation depth: measured true vertical 6084 ' -61 O0 'MD 6081 '-6097 'TVD 6107 ' -6147 'MD 6104 ' -6144 'TVD 6172 ' -6178 'MD 61 69 ' -6175 ' TVD Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12. Stimulation or cement squeeze summar-y RECEIVED AuG 2 6 1986 13. Intervals treated (measured) 6040 '-6042 ' ~ 5992 '-6005 ', 2320'-2340' Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 275 sx Class C: 150 sx Class G. 200 sx CS I Representative Daily Average Production or Injection Data N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequentto operation 14. Attachments (Workover Well History) Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85~ Title A~_~n~_int-_~ Fnnin~.er (DAM) SW0/088 Date Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily InlUlictionl: Prepare and submit the "leltill RIl~ort" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1720 Nordic 4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 7/24/86 7/25/86 7/26/86 thru 7/28/86 7/29/86 7/30/86 7/31/86 Date and depth as of 8:00 a.m. Count. ~rish or borough North Slope Borough {Laa~ orUnit ADL 25631 Title Recompletion ISta!e Alaska Well no. 3A-9 AP1 50-029-20699 IDat, 7/23/86 IH°ur Complete record for each day reported 0400 hrs. IARCO W.I. Prior status if a W.O. 56.24% 7" @ 6424' 6342' PBTD, Drlg cmt 10.2 ppg NaCl/NaBr Accept rig @ 0400 hfs, 7/23/86. ND tree, chg out tbg spool to 5000 psi & tst. NU & tst BOPE. RIH w/3~' DP to 2148', tst csg to 3000 psi.- Drl cmt & rater f/2148'-2244'. 7" @ 6424' 6342' PBTD, Drlg cmt 10.2 ppg NaC1/NaBr Drl cmt &retnr f/2244'-2368', tst Ugnu perfs; OK, POOH, chg bit. RIH, tag cmt @ 5538', drl cmt. 7" @ 6424' 6316' PBTD, Drlg 10.1 ppg NaC1/NaBr Drl cmt & rater f/5713'-5875'. RIH to 6316', circ out gas bubble, monitor well, POOH. Rn gage ring/JB to 6307'. RU Schl, rn GR/CET log f/6316'-5500' & 2600'-2000'. RU & perf f/sqz @ 6040'-6042' @ 4 SPF. Set BP @ 6060' & rater @ 6015'. RIH, sqz perfs w/200 sx C1 "G" w/.63% FL-28, .3% CD-31, .15% R-2 & .1% FP-8, POOH. RIH, tag TOC @ 5562', WOC. DO cmt. Tst Ugnu perfs to 2000 psi; OK. DO cmt &retnr. 7" @ 6424' 6316' PBTD, Rev out cmt 10.1 ppg NaC1/NaBr Fin DO cmt to 6051', tst sqz perfs 6040'-6042' WLM, circ, POOH. RIH w/R-3 pkr, isolate leaks @ Ugnu perfs @ 2320', "C" sand perfs @ 5992' & sqz perfs @ 6040', POH. PU retnr, RIH, sqz perfs 6040'-6042' w/8 bbls (75 sx) C1 "G" w/.6% FL-28 & .3% CD-31 @ 1/4 BPM, 1000 psi. Rev out cmt. 7" @ 6424' 6316' PBTD, RIH w/bit 10.1 ppg NaC1/NaBr POH. RIH w/R-3 pkr on DP & set @ 5730'. Sqz 150 sx C1 "G" w/.63% FL-28, .3% CD-31 & .15% A-2 into "C" sand perfs @ RECEIVED 5992'-6005'. Pull up, reset R-3 pkr @ 2009' & sqz 200 sx CS I into Ugnu perfs. POH, WOC. 7" @ 6424' AUG 2 ~, iSSS 6316' PBTD, RIH w/pkr 10.1 ppg NaC1/NaBr AlasKa o. a uas uoas. 6ommis RIH to 2130' drl cmt to 2338' RIH to 5828', drl cmt &retnr ' · Anchorage to 6056' (top of BP), circ hole cln, trip f/sqz pkr. The above is correct Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas ,,pany · Daily V eil History-Final Report In$lruciion$: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or weii is Plugged, Abandoned. or Sold. "Fieal Rel~oft" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1720 Nordic 4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover ICounty or Parish Lease or Unit Title North Slope Borough ADL 25631 Accounting cost center code State Alaska Recompletion API 50-029-20699 IWell no. 3A-9 IA.R.Co. 56.24% Date 7/23/86 Iotal number of wells (active or inactive) on this i DSt center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0400 hrs. I Date and depth as of 8:00 a.m. 8/Ol/86 8/02/86 thru 8/04/86 Complete record for each day reported 7" @ 6424' 6316' PBTD, RIH w/bit & scrprs 10.1 ppg NaC1/NaBr POH w/tst pkr. RU Schl, rn CET across Ugnu & Kuparuk, RD Schl. RIH w/bit, DO retnr & push to 6317'. Trip f/csg scrprs. 7" @ 6424' 6316' PBTD, RR 10.1 ppg NaCl/NaBr RIH, displ well to cln brine, POH. RU Schl, rn CCL/GR, RD Schl. Set patch @ 2310'-2350' WLM, patch failed, POH. RIH w/mill, tag patch @ 2334' MD, mill & dress off top, POH. RIH to 2470', set R-3 pkr @ att to tst csg patch. Pmp'd in @ 1 BPM, 750 psi. Set CR @ 5856'. ND BOPE, NU & tst tree. RR @ 0415 hfs, 8/3/86. RECEIVED AUG 2 1986 Alaska 0il & Gas Cons. Commission Anchorage Old TD Released rig 0415 hrs. Classifications (oil, gas, etc.) Oil New TO PB Depth 6316' PBTD Date Kind of rig 8/3/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test Qata Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day I · Pump size, SPM X length Choke size T.P. C~P. Water % GOR Gravity Allowable Effective date corrected The above is correct iii~arag~a ~ IDate ITM ~//~__ Drilling Supervisor nd see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ALASi~"~,JiL STATE OF ALASKA I~olON AND GAS CONSERVATION COM .. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing r- Time extension r~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order ~ Perforate © Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 720'FSL, 800'FEL, Sec.7, T12N, RgE, UN 5. Datum elevation (DF or KB) 70 ' RKB 6. Unit or Property name Kupmrt, k River llnlt;, 7. Well number 3A-9 At top of productive interval (same as above) At effective depth (same as above) At ,total depth [same as above) 8. Permit number Permit #81-94 g, APl number 50-- 029 -20699 10. Pool Kuparuk River Oil Pool feet 11. Present well condition 'summary Total depth: measured 6430 feet Plugs (measured) 21 47 'MD true vertical 6427 feet 5548 'MD feet jUnk (measured) Effective depth: measured 6342 No ne true vertical feet 6339 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 sx AS II 112'MD 112'TVD Surface 2132' 10-3/4" 1000 sx Fondu 2164'MD 2164'TVD Production 6392' 7" 255 sx Class G & 6424 'MD 6421 'TVD 1 25 sx AS I _. Perforation depth: measured 61 72 ' -61 78 'MD true vertical 2320'-2340'TVD, 5989,-6001~,~V~¥,~({SlllL-l~097 K E t,. E/VE IJ 61 69 ' -6175TVD Tubing (size, grade and measured depth) NONE Packers and SSSV (type and measured depth) NONE 12.Attachments 2320'-2340'MD, 5992'-6005'MD, 6084'-6100'MD, 6107'-6147'MD, 'TVD, 6104 '-6144 'TVD Description summary of proposal~., JUN 1 3 986 Alaska Oil & 6as Cons. Gommissio~ Detailed ope~l~t~rogram [] BOP sketch 13. EStimated date for commencing operation June 24, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~.~ Title Associate Engineer Commission Use Only ( JWR ) SA/063 Date (~-/2-~.~ Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance by order of the commission Date Submit in triplicate APPLICATION FOR SUNDRY APPROVALS 3A-9 SUMMARY OF PROPOSAL ARCO Alaska, Inc., proposes to: 1. MIRU workover rig. 2. Drill out cement plugs and clean out to PBTD. 3. Complete the well as a single completion. 4. After the rig is released, a frac job will be done. BHP = 3162 psi ~ 6123 'MD/6120 'TVD Workover Fluid - NaC1/NaBr RECEIVED JUN 1 ~ 1986 Alaska U~l m Gas Cons, Commisslo~ Anchorage SA/O63a:tw ANNULAR PREVENTER § BLIND RANIS 5 PIPE RAHS 4 TUBIN6 HEAD , . , 1! '!. '15" CONDUCTOR SWAGED TO 10-3/4" 2, 11"-3000 PS! START!N6 HEAD !2 ,3, 11 "-3000 PSt X 7-1 / 16"-5000 PSI '"" 1 ~ UB!NG HEAD ,4, 7-]/16" - 5000 PSi PiPE P, AMS !3. 5, 7-1/t6" - 5000 PSt BLIND RAMS 14. 6. 7-l / 16" - 5000 PS! ANNULAR '~. 5. ACCUMULATOR CAPACITY TEST i. CHECK AND FiLL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE tS 3000 PSI WITH 1500 PS! 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. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAIN1NC~. PRESSURE. '"'/"~ % -"2 '~-" BOP STACK TEST " CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO t800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PS1. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS, INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, iF ANY, WITH 3000 PSi UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, OPEN TOP SET OF PiPE RAMS AND~m~e~..~ ~~,, ,~,, ~, OF PIPE ~,-~-~c r~oou~c ~ v ~vv~ r~, AND nu~ FOR 10 M;NUT~S. ~,~u TO ZERO PSi. ~N 60~Oi-i SET 0~. BACKOFF PUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR ~0 Mill. BLEED TO ZERO OPEN BLIND RAMS AND RECOVE~ TEST PLUG, MAKE Sb~ MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET ~ ~ THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND iNSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST '~' '~' ~,,~,,. SiGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. dG dUNE 12, 1986 (NORDIC RIO t0-3/4") ARCO Alaska, Inc. f'~ Post Office B~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-9 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 GRU11/L10 Enclosure If RECEIVED AUG 2 61~ -' ~,-,,,~ ~;,~ 6 ~.:~$ Cons. Commission · , .... h~rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L LXI~ OTHER [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360, Anchorage~ AK 99510 4. Loc. aticm of Well burTace: 720' FSL, 800' FEL~ Sec.7, T12N~ RgE, UN 5. Ele~oD~r~ feet (indicate KB, DF, etc.) 12. I 6. Lease Designation and Serial No. ADL 25631 ALK 256/+ 7. Permit No. 81-194 8. APl Number 50- 029_206~cj 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-9 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) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing, (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc.~ has officially changed the we]] designal:ion of West Sak #23 t:o 3A-9. RECEIVED AUG 2 6 1965 ~, ~. u~:s C0~s. Commission Y.~,nchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢J ~'~/ ,~/jt(..~ _./ Title Associate Engineer The space b~/~TM for Commission use V Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 GRU11/$N01 Rev. 7-1-80 Submit "Intentions" in Tripl cate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. I~ Post Office B~,. ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 6, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' West Sak #23 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to change the designation of West Sak #23 to 3A-9 and incorporate it into the 3A pad development scheme. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUIO/LI09 Enclosure cc: 3A-9 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED AnChorage STATE OF ALASKA jM ALASKA ILAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Na~t~(~ C~l;lera~:or ~lasKa~ Inc. 3. Address P, 0, Box 100360, Anchorage, AK 99510 4. Location of Well Surface= 720' FSL, 800' FEL, Sec.7, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 70' 12. I 6. Lease Designation and Serial No. ADL 25631 ALK 2564 7. Permit No. 81-194 8. APl Number 50- 029-20699 9. Unit or Lease Name Kuparuk River Unit: 10. Well Number West Sak #23 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 Well [] 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 change the we]] designation of West Sak #23 to 3A-9. This redesignation would be effective immediately and 3A-9 would be incorporat:ed int:o t:he 3A pad development scheme. RECEIVED AUG 0 9 ~ Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' . Title The space bel~{N for Commission use Date Conditions of Approval, if any: Approved by GRUi O/SNi 3, Approved Copy Rqturnecl By Order of COMMISSIONER the Commission Submit Inte/ntlons ~nTr~pl~cate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION / / November 9, 1984 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-31 92 TELEPHONE {907) 279-1433 ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Submittal of Form 10-403, "Sundry Notices and Reports on Wells," to Request an Extension of Time for Suspended Wells. Gentlemen: It is requested that the Form 10-403 for the extension of time for suspended wells under 20 AAC 25.270(b) be submitted at an esrly date. The request should include: · A request for a one year extension. A reason for the extension of time. A description of future clean-up plans, if applicable. The following wells are included under this request: Delta State No. 1 Delta State No. 2 East Bay State No. 1 Gull Is. State No. 1 Gull Is. State No. 2 Highland State No. 1 Kavik Unit No. 3 Ugnu SWPT-1 West Sak SWPT-1 Kuparuk River State No. 1 N. Prudhoe Bay State No. 1 West Sak River State No. 1 West Sak River State No. 2 West Sak River State No. 3 West Sak 25631 No. 23 Sag Delta 31-11-16. NW Eileen State No. 1 Prudhoe Bay State No. 1 Prudhoe Bay Unit Term A Prudhoe Bay Unit TR T-3C Put River State No. 1 Ravik State No. 1 West Beach No. 1 West Beach No. 2 West Beach No. 3 W. Mikkelsen State No. 1 Kuparuk 28243 No. 1 West Sak River State No. 5 West Sak River State No. 6 West Sak 25590 No. 15 East Ugnu No. 1 Yours very truly, }larry O. Kugle~ Commissioner be:2.K.T ARCO Alaska, Inc. (o'~, Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- West Sak #23 Dear Mr. Chatterton' The Well Completion report, dated 03/19/82, incorrectly lists the RKB as 87'. It should be 70'. Please make this change to your records and files. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:tw GRU7/L54 xc: B. Byrne, ATO 1069B Well File EC IVED Alaska Oil & ,,,, [i~$ Co~s. CoMrrliss/Orl Anchorage ARCO Alaska, ~nc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, InC. Extension Exploration ' Bill van Alen- AOGC TRANSHITTAL · . . From' E×t. E×pl n~mt.i_o_~_ - T,._ .Tohnsto.~. te- April 2, 1984 . ansm~tted herewith are the following: One Sepia Mylar. Each ARCO: W?;' SaM #:2~:' 2-12-82 I! 2-13-82 2-16-82 2-12-,82 2-20-82 2-23-82 2-6-82 2-14-84 2-6-82 .2-12-82 2-13-82 2-5-82 2-13-82 · BHCS Run 2,3 CNFD " DPMTR Run 3 CBL Run 1 MLL " 3 ~ EPL " " " 2 RFT " 2 CPL-SHDT C.SMPL TKR " 2 FDC Run 2,3 · -CPL/CYK Run 3 " " 2 AR PLT Run 1 CORE GAMMA RAY LOG 2" & 5" 2" & 5" 5" 2" & 5" 5" 5" 5" 5" 5" 2" & 5" 5" 5" 5" leceipt kcknowl edgment: teturn Receipt to' /~RCO Alaska, Inc. Extension ExPloration P. O. Box 100360 Anchorage', AK 99510 Attn' Date' _ Anchorage Processed by' Lucille Johnston ATO-1015 x4599 ARCO Alaska, Inc. Extension Exploration TRANSHITTAL ,ate- ,3--2- ::2. - S'J/ 'ransmitted herewith are the following' Receipt Acknowledgment: ~ Return Receipt to Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn- ~aska Oil & Gas Cons, Commission Anchorage Date' Processed by,.:~_~_.~j'~ ARCO Alaska, Inc. Extension Exploration tRANsMzTTAL 2(- · _ e,-om:Z,-,_, Date- ~ - ~-- ~V Transmitted herewith are the following' Receipt Acknowledgment: ~ Return Receipt t3~~CO Alaska, Inc. ~/' Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn- Da te · Alssk-~ Oil & Gas Cons. Commission ARCO Alaska, Inc. Extension Exploration T RAN SM I TTAL O' ,ate' ~-~ ~- ~ 'ransmitted herewith are the following- Receipt wl edgmen~: lReturn Receipt to: ARCO Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn- Date- ALASKA OIL AND GAS CONSERVATION COMMISSION Permit No. Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501-:-319 2 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 which our records indicated was completed' c~~-'~c2 : 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, C. V. Chatt Chairman ARCO Alaska, Inc.~ {'= Post Office Box,d0360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 12, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' West Sak 23 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG:tw GRU4/LIO0 Encl osures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA* {'. AND GAS CONSERVATION CO~: /IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20699 4. Location of Well Surface: 720' FSL, 800' FEL, Sec.7, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 87 ' RKB 12. I 6. Lease Designation and Serial No. ADL 25631 ALK 2564 9. Unit or Lease Name Kuparuk 25631 10. Well Number West Sak 23 11. Field and Pool Kupar'uk 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 Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~(X 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 Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., requests that the subject well be allowed to remain in suspended status. Subsequeat Work Approved Copy Returned. 14. I hereby certj~I/that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Area Dri I l ing Engi neet Date The space b~/e~v~or~Co ssion use Condition)F'of Approval, if any:OU~ representative inspected this ~II site on August 16, I983 and cleanup was satisfactory for a suspended location. A subsequent inspection will be necessary by August 1984. ~i,~ 0t~t~ N,~L SIGNED By Order of 0/~ l/~.~,~- Approved by BYLONNIE g.IN!TI' COMMISSIONER the Commission Date / ---- Form 10-403 Rev. 7-1-80 GRU4/SN53 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: _-- ..... o~rator-~'-~ ~~0 Date Suspended Address ~_. _'~o~ ~~ ~3~-6~f~9~ /~/ ' Surface noca{i~ Of [q~li ~ ....... ~'-~ermit No. ~;- Sec.~, T /~ ~_, R~~, _~ M. Unit or Lease Name ~~'~-~_ - Field & Pool fW~~~ ~';~~ Condition of Pad _._~/~Dm~f)_ ~-,~/~ Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard Attached to Information correct Cellar - Opened Yes No Fi 1 led ~ No Covered ~ No WaterWell - Plugged off Capped Open O No '~es No No No Rat Hole Open Yes No Fil led Yes No Covered ~) No Exp la na ti on Photographs taken to verify above conditionsG No Exp la naton Work to be done to be acceptable This well and location is (acceptable) (u~ac=nS.~]:.!~) to be classified as suspended for the pe. rio~ of Inspected by: Da ts: Revised 8/24/82 ARCO Alaska, Inc. P. O. -n. ox 100360 Anchorage, Alaska 99510 Res Cleanup Inspection for the ~-ollcwing Susa.ended Welis: D.S. 11-14; Sec. 28, ~'llI-'i, A15B, U.I;~.. Delta State I-lo. 1; Sec. 10, T10[;, R16L, Delta State No. 2; £ec. 35, Til~, P. 16L, East Bay State No. 1; Sec. 15, T/i~, Ri5E, U.~.~. Gull Island ~%'o. 1; Sec. 28, T12~, ELSE, O.~i. Gull Island [-..'-o. 2; Sec. 28, 5'12~,, RI5L, U.~.'~. }~ighland State I~o. 1; S=c. 24, Tll~, Kavik Ko. 1; Sec. 7, T3N, R23E, Kavik ~o. 3; Sec. 8, T31~, ~23E, U.M. ~obil .Kupar,uk 28243-1; Sec. 17, T13/.~, I~llL, ~.~orth Prudhoe Bay State ~-~o. 1; Sec. 23, T12~.;, P.14B, U.[.i. Prudhoe Bay State No. 1; Sec. 10, Tlll~', K14L, [..~;. Eavik State ~o. 1; Sec. 32, T9~, R9E, Term A (41-33-12-14); Sec. 33, T12}~, R14E, U.M. Tract ~ell T3C (17-11-15); Sec. 17, =:13R~, R15E, Ugnu SWPT ~.~o. 1; Sec. 7, T12k~, ~%i0L, U.~. West Beach State ~.~'o. 1; Sec. 25, TI2~, F;14E, D.~'i. '~. West ~each State ~[o. 2; Sec. 25, Ti2~, R14E, U.M. ¥~est Beach State ~o. 3; Sec. 25, T1214, R14E, U.[~. West SaP. ~o. 15; Sec. 5, T10I~, RSE, U.~. West Sak.~.'.l~o.' 23; Sec. 7, T121~, ~gL, U.M. West Sak ~:o. 24; Sec. 5, Yi1N, RILE, D.R. Wesk Sak River State ~o. 3; Sec. 26, TllI~.~, I{9~, U.S. %~est Sak River State }~o. 5; Sec. 11, T10~, R10~, U.~-~. West Sak ~iver State No. 6; Sec. 29, Tllt~, BP Put River 01-10-14; Sec. 11, T10~, kl4E, U.~. BP Put River 02-10-14; Sec. 11, T10~, ~.~14E, BP Put aiver 11-10-14; Sec. 11, T105, R14E, U.~.~. BP Put River 12-10-14; Sec. 11, T10};, R14E, BP Put River 13-10-14; Sec. 13, T10N, ~14E, U.M. BP Put River 14-10-14; Sec. I3, T1ON, ~14E, U.}i. BP ~t River 17-10-15; Sec. 19, ~:10[~, }~15E, U.I.~. ¢~ntlemen ~ Our representatives inspected these 32 well sites on August 14 and August 23, 1983. The following wells will require the sub~-~ittal oi for~'; 10-407, Well Com.~pletion or P. eco~pletion Re,crt and Log, to classif1 as suspended wells. All requests for classifications are initiatea by the o~.~rator on forr,~ 10-407: Prudhoe Zay State Term A {41-33-12-14 Tract ~ell T2C (17-11-15 The followin~ wells need well ~igns: F, avik Ro. 1, %ell sign not properly, attached and in ~oor condition. Prud~'~oe Ra~- State ~:o. 1 following well sites need the rat hole covered= I~ighland State ~s~o. 1 ~avik ~¢o. 1 ~a~ik State ~'o. 1. Tract Well T3C West'Sak ~o. 15 Pru. d/~o~ Bay State ~o. 1 EP Put River 13-10-14 The fcllowing we11 ~it~.e need ~:rcvem~nt in housekeeping and trash removal ~ Pru~oe '~ Sta~e ~o. 1,' the well house also is in condition. West Sak No. 24 West Sak River State ~o. 6 The following ~ell~ do not have all outlets on the tree DTudhoe Bay State X~o. 1 ~.~orth Prudhoe ~a}-- State ~avik }:o. 1 All of the 32 listed ~ll& require the submittal of. io.rn~ 10-403, Sundry ~otices and Reports on Well~, to request and further extension o~ one. ~ear for the suspended ~ites as re~iuired under 20 AAC 25.170(b)(1)(2) and (3). It is requested that deficiencies be correctud as ~oon as possible and photographic evidence su~lied this office. Also ~lea~e submit at ~n earl}~ date the required £or~s 10-403 and 10-407. A subsequent in~p~ctlon wil ~e nece~.ary b~' August, 1984. S in ce. re 1 }-~ ionnie C. $~tth C oa~r:i s s ioner LCS/J~:T: lc: 103: E M EMORAI 'L.)UM TO: Stat ' of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION C. ~~att~erton Thru: Lonnie C. Smith FROM: DATE: Commissioner ' '?("' '''~ ' ELEPHONE NO: Ben LeNorman ~v SUBJECT' Petroleum Inspector August 25, 1983 108B:S4 Inspect Thirty-two ARCO Locations for Surface Cleanup for Suspension, North Slope. Sunday, August 14, 1983: I departed my home at 3:15 pm for a 3:45 pm showup and 4:45 pm departure via Alaska Airlines, Flight No 341 for Deadhorse arriving at 7:10 pm Weather: +36°F light wind, fog. Monday, August 15, 1983: Inspection of forty-one abandoned and su-spended wells began at 9:00 am and continued until 3:30 pm on Wednesday, August 17. Separate reports cover abandoned wells and a BOPE test on ARCO's DS 4-20 Monday evening. I recommend to the Commission the following wells be approved for suspension: Delta State #2 Delta State #1 Gull Island ~1 Gull Island #2 Team "A" 33-12-14 N. Prudhoe Bay State #1 Highland State #1 Mobil Kuparuk 28243 Ugnu SWPT #1 West Sak #23 West Sak # 3 West Sak #5 Ravik State #1 West Sak #24 West Sak #15 West Sak # 6 Kavik # 3 West Beach State #1 West Beach State #2 West Beach State #3 East Bay State #1 T3C 17-11-15 Put River 01-10-14 Put River 02-10-14 Put River 11-10-'14 Put River 12-10-14 Put River 13-10-14 Put River 14-10-15 Unknown DS 11-14 I recommend to the Commission the following wells not be approved until deficiences as noted on the suspended well and location report are corrected: Kavik # 1 Prudhoe Bay State #1 I departed Deadhorse via Alaska Airlines, Flight #56 at 4:30 pm arriving in Anchorage at 6:10 pm and at my home at 6:40 Pm. In summary,. I inspected thirty-two ARCO locations for well sus- pension and location cleanup. Attachments February 4, 1983 Mr. P. A. VanDusen District Drillin~ Engineer ARCO Alaska, Inc. P. O. Eox 360 Anchora§e, Alaska 99510 Dear Mr. VanDusen: The Alaska Oil an~ Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well ts not o'n file with the Commission. The Oil and Gas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to the following wells, ~t. }iikkelsen Unit No. 2 Prudhoe Bay Unit DS 14-9A Kuparuk River Nit WSW-1 Prudhoe Bay Unit DS 14-DAR Oltktok Point [to. 1 %,lest Sak 28242 No. 24 ~est Sak 25631 }lo. 23 PBU No. Prudhoe Bay St. No. 2 Prudhoe Bay Unit DS 1-22 PBU Eil een No. 1. Thank you for your cooperation in this matter. Yours very truly, Harry W. Kugler. Commissioner BY ORDER OF THE COMMISSION b~ ARCO Alaska, Inc .... Post Office ( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 7, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas-Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501~. SUBJECT' Sundry Notices and Completion Report Dear Mr. Chatterton- Enclosed are Sundry Notices for the following wells' Gull Island St. #2 West Sak 23 Put River #1 Also encl'osed is a completion report for West ~likkelson Unit #2. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL24: 1 lm Enclosures ARCO Alaska. Inc. is a subsidiary of AllanticRichfieldCompany RECEIVED JAN 1 i Alaska 0il & Gas Cons~ C0mmissior~ Anchorage ALASKA(~,,L AND GAS CONSERVATION ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER ~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-194 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20699 4. Location of Well Surface: 720' FSL, 800' FEL, Sec. 7, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 87' RKB 6. Lease Designation and Serial No. ADL 25631 ALK 256/+ 9. Unit or Lease Name Kuparuk 25631 10. Well Number West Sak 23 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0il Pool 12. 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 Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~(X 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 ofstarting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc. requests an extension of' one (1) year to complete clean-up requirements on subject suspended well. All pits will be filled per AOGCC regulations. This extension will allow work to be done during summer,when ice and snow present no problems. The AOGCC will be notified when the location inspection can be performed, t, Approved Copy Returned ['.'/-/ RECEIVED JAN 1 1 1983 Alaska 0it & Gas Cons: Commission Anchorage 14. I. hereb~regoing is true And correct to the best of my knowledge. Signed / ! "' - ~ ~d~~//~;~ Title Area Dril ling Engineer The space below for Commission use Date Conditions of Approval, if an¥:Otlr representative inspected this site on July 17, 1982 and it ~s found that the rat hole needed to be cut-off and covered and there was no well guard. subsequent inspection will be necessary by August 1983'. ORIGINAl. SIGNED By Order of Approved by BY I-ON~!-~ ~- SM!T.~. COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 GRU1/SN6 Submit "Intentions" in Tripiicate and "Subsequent Reports" in Duplicate October 26, 1982 A~D A~ska, Inc. P. O. ~ox 360 Anchorage, Alaska 99510 ~ C~n~i~~~ ~~d~ ~ ~. 23, ~ 7, TI~, ~, ~. ~nt~n~ ~~ ~ ~11s, ~ ~~ a o~ ~r ~e~n ~r cl~. ~n~ly, · ~ / a ~: v d ~ - · August 12, 1982 & Mr. Minos Hebert ARCO Alaska, Inc. ANO Room 321 P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Hebert In reference to our conversation this date regarding clean-up and- inspection of ARCO well sites on the Arctic Slope, I am enclosing a copy of our letter of May 21, 1982 to Mark Major regarding clean- .~ In addition to the wells oh this list add: -'West Sak %13 %. ~est Sak $24 West Sak 925 Eileen %1 North Prudhoe Bay St. %2 Gull Is. St. %1 Gull Is. St. %2 W. Bay St. %1 W. Mikkelsen Unit %2 Some of the wells on the 'i~sts are for repeat clean-up inspec- tions while others are being inspected for the first time. Wells in a suspended status require a yearly clean-up inspection. When the clean-up inspection is approved as satisfactory for abandoned wells no further~iinspection is required. sincerely, ~trolem~ Engineer Enclosures I MEMOR IDUM of Alaska ~ASKA OIL AND GAS CONSERVATION COMMISSION Chai ~. ~ Thru: nni& C. Smith Commi ssioner FROM: Edgar Wo Sipple, Petroleum Insl:~cto~ DATE: August 5, 1982 FILE NO: 108/G TELEPHONE NO: SUBJECT: Conduct a Clean-up Inspection on ARCO's Kuparuk ,River Field West Sa~No. 23 Sec. 7, T12N, R9E, Permit No. 81-194 Mgnday,_.JDly 19,._1982 - Steve Hubbard of ARCO, Mike Minder and I traveled this ~at,.e by helicopter by ARCO's Kuparuk River Field, West Sa~.No. 23 (suspension). As the attached pictures indicate; picture %2 shows that there is no w~ll guard and the rat hole needs to be cut off or covered. The area ~s clean, the pits ~re still open as picture #1 indicates, and the flare pit was still open. I red,mend the Commission not approve ~the final inspection until the status suspension on W~st Sa~ No. 23 is changed. In summary, I conducted a su~spension clean-up on ARCO's Kuparuk River Field West Sa~ No. 23. I recommend a final inspection be done on a later date. Attachment: Steve Hubbard of ARCO called this office on J~ly 20, 1982 at 9=0'0 a.m. The well guard was put around th~ well. The rat: hole was cut off and covered. : 02-001 A ( Rev.10/79) , .. \L\SKA OIL :\~;D CAS C_":\:~j. ;~\':\TI ~, CU:-::lISSION I, ' ' \ß'r Þ; t."ðf,', (", ,,', "~URFACE ABANlJÜ:nIENT REPORT r,",',""" I f/- ¡f{-- ' 20 AAC 25, ART rCLE 2 $tJ..s ~ Ii,) þj tttE INFORMATION: <\ " - .Operàtor 141l¿"lJ Date Downhole P & A ..,. Address /'.0 I'¡~'f- J ~o ÃÑd\. ..d.,k..,.... q'iS-/o \ \ IUrf.âce Location of Well. Permit No. Y/- ¡tit.¡ n. Ft. F ~ L, 10t) Ft. Fe L, API No. 50- ,ð 2t1-12:0' 9 <9 See.' 7 ' T.J:Z:.. K, R.!L!.-, .~M. Unit or Lease Name ki.,A ;#,,4,' ~~ol~'-:5iJJ Well No. W J' ~ ., - 'l.. '? Field & Pool J<'£(p.I'~/¡4#K Jl< uJIlt .. AAC 25.120: WELL ABANDONMENT MARKER: Bia. Steel Post (4"Min.) , Length (10' Min.) Height Above Final Grade Level (4' Min.) Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds Set: On Well Head, On Cutoff Casing, In Concre~e Plug Distance BelQw Final Grade Level Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed, With Blinds, With Cement, Other INFORMATION BEADWELDED DIRECTtLY TO MARKER POST: (List Where Diffetent from File Information) Operator -.t)((c; , Unit or Lease Name Kuttt.att.t¡"\ I.A) rA~"'U Well Number ~'I'.$'~- 1-3 . Surface Loca,t,ion O,f W"ell:"" ' 720 Ft. FLL,-ð6 "Ft.! Fe. L, Sec 7 ,T 1"2../JL, R ~, L, ~M 20AAC 25.170: LOCATION CLEAN-UP PITS: ~i,¡ledI:I:),.<~J..:i.persR~~pyed or Buried -' Debris SURFACE OF PAD AND/OR LOCATION: Rough' ~Smooth_, Contoured'~Flat_, Compacted -' Other CLEAN UP OF PAD AND/OR LOCATION: Clean ~'Pipe Scrap, ,Iron Scrap, Wood, Mud, Cement, Paper -' Other ¡lJr IJtJtt,,: (.AlLlJ., 1 tJ..IÅ/' /) - - - / SURROUNDING AREA: " Wooded ,Brush , Tundra~Grass , Dirt, Gravel, Sand_,Other - - - - - GONDITIONSURROUNDING AREA: Clean ,,',"---¡ Trash f¡~~~::-Ši te , Trees and/ or Brush from Clearing Site, Other- - - -""',~'1'!'-~""'.'''' ACCESS' ROA'D: Dirt -' Gravel -'. Ice -' Other ---Jf& ~^}) CONDITION ACCESS ROAD AND SURROUNDING: Glean, Rough, Smooth, Trash from Operations, Trees and/or Brush from Clearing Road, Spoil fïomClearing RiQad , Other - - REMAINING TO BE DONE:~' vf,P- t ,fA./ hð/--f h.~.., ¡¿k'1 1c+1J1~ j ~ ( ~,1 I }/~'/'¿4",1 I ", /' {, " RECOMMr:1'ID- APPROV.AL OF ABANDONMENT: Yes.. NOV Final Inspection "(S"I.I.$i!.tN$~ IN,SPECTED BY ~+-""J. ~"~ 7' . DATE 71/t/~ OS/26/81. "', ) , , ' .'" ""',~ (~ C" "", <- ,...-- ,' ~ ~ \./"> ~" ç: fV"\ ~ ?¥- ~\ ~, ~y - ~~ \ l~ r" / ',/>'" <;: -''''''~~' ....- ~ ........ ~ J1 ""~ ~ ~: JJer.¿ '~ ~(~. ",. "'.. - \ ~J' ~<4..... 171 "'''"1 .,"'.,;~ ARCO Alaska, Inc. $ Post Office Bo}~., .~0 Anchorage, Alaska 99510 Telephone 907 277 5637 SHIPPED TO: STATE OF ALASKA Alaska Oil ~ Gas Conservation Comm. 3001 Poreupi.~e Dr. Anoh. ,Ak. 99501 Attn: William VanAlen DATE' June 5,1982 OPERATOR: ARCO NAME' West SAMPLE TYPE: Core chip' &-Dry .Ditch NUMBER OF BOXES SAMPLES SENT: . Dry Ditch 90- 5992 (30' interval) 6000- 6180 (10' interval) 6210- 6400 (30' interval) Core Chip 2281 - 2286 2300 2321 - 2338 2341 - 2360 5992-.- 5995.3 5997 - 6055:2 6057 - 6113.3 6117 - 6%76 SHIPPED BY: ~~_~L~_K.,.~ ~ Tere~a flnr,,?/Pnlan lnb $!,perviso~ UPON RECEIPT OF THESE SAMPLES, .PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: "· ARCO ALASKA, INC. P.O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN: R. L. BROOKS RECEIVED BY: ~ ~ t" ~' I !! !~ Ii DATE: ARCO Alaska, Inc. is a subsidiary o! AtlanticRichfieldCompany ~ate: '~ ;7' ~' Transmitted herewith are the following' urn recei'pt to: Arco Oil and oas ' ~orth Slope District Attn: C. Mulliken P. O. Box 360 Anchorage, Alaska 99510 :)ate: WEST I K "23" ' PROTRACTS" : 2EEi..C. 7, T 12N, RgE, U- M. 720' FSL, 800 . · LAT. = 70° Z4' 15.95" LONG.= 149° 56' 15.90" Y = 5,997, !01.5 X = 507,647.3 ASP ZONE 4 ICE PAD LIMITS . PAD ELEV.= 38.1' WELLBORE 0 '-4 w ST SA~ Z~ ~ VICINITY MAP i© MILE '7 / / / / IDw GYRO MARKER 2", 2"x 8' POLE ~ 5,996,608.89./ 507,7.79.30 LC GRAVEL PLACED= 38,630 Yds.~. · [ HEREBY CERTIFY THAT I AM ~:, ~ ~ · _ PROPERLY REGISTERED AND · .,c~.~o ~o ...~,c~ ,,.~ ~~' ~"{~. ~Y o ~~ AS-.U~LT SURVEYIN~ IN THE STATE OF -. ·, v ~ 1~0~ -- - II II ALASKA AND THAT TH,S PLAT ~:~~~~S~ OiiE ~as Cons C~,~EST SAK "23" REPRESENTS AN AS-BUILT SURVEY ~E BY ME,OR UNDER MY DIRECT · SUPERVISION. AND THAT ALL ARE CORRECT~ AS OF~ DATE ' 1°"~'''WR. ]~w~' .ONSK3.17_37:. ........ . . ?m~ - m , mi m * m m m Atlantic Richfield Company North Slope District To: TRANSMITTAL From: - / / ~a.~ '/,'&.cz m. : ' itted herewith are the following:' 11 g' II ! Return] receipt to: Arco Oil and Gas North Slope District Attn: C. Multiken P. O. Box 360 Anchorage, Alaska 99510 RECEIVED Atlantic Richfield Company North Slope District To: TRANSMITTAL From: Transmitted herewith are the following: ledgeZ,./' Receipt Ackn ow Retuznn receipt to: Arco Oil and Gas North Slope District Attn: C. Mullike~~~) P. O. Box 360 ;atchorage, Alaska 99510 Atlantic Richfield Company · NORTH SLOPE DISTRICT ransmitted herewith are the following: · From: ..ceipt A ckng-,,'!e dge'.-~ .~turn receipt to co Oil and Gas North Slope DiStrict Attn: ~ ~ ~ P.O. Box 360 ' ~ ~h~v~ A1 nska 99510 Date: .R.ECEIYED APR 1 51S82 Alaska Oil & Gas Cons. Commis~or~ Anchorage Processed by: I Atlantic Richfield Company NORTH SLOPE DISTRICT TRANSMITTAL o: · ate: From: ransmitted herewith are the following: ceipt~/~Ackn°wle _ _-_ turn--pt to: Arco Oil and Gas Date: RECElYEI APR 1 ~ 1982 North Slope District Attn: ~. f~]h'M.~ P.O. Box 360 ^.-...~. ..... ^', ..~.~ .... o.o~'~n Alaska Oil & Oas Cons. Anchorage Processed by:' 0...I ~J~_y:~_[[( ~ ARCo. Ala~,,; Inc. [ ...... Post Office Bo~. .60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports. Dear Si r' EnclOsed are Well Completion Reports for the following drill sites' 13-20 15-1 1A-14 1A-15 .:~,:~WS.~..~23 ......... Also enclosed are monthly reports .for February on these drill sites: 11-7 13-23A '14-29 14-30 15 -2 Ei leen No. Oliktok Pt. No. 1 Copies of the DS 13-20 gyroscopic survey were sent to you under separate cover. Si ncerely,/~ - P. A. Van Dusen District Drilling Engineer REEE!¥E , PAV' JG/hrl Enclosures GRU2/B14 ARCO Alaska. tm;; is a Sub~,uiiary of Athtnliclq~chfie',dComp,~ny .... ' ' STATEOF ALASKA /' ALASKA . ND GAS CONSERVATION c- ..~ ,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL IX] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-194 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50-029-20699 4. Location of well at surface 9. Unit or Lease Name 720' FSL, 800' FEL, Sec. 7, T12N, R9E, UM Kuparuk 25631,..~/~-~ At Top Producing Interval 10. Well Number ~.,~j~_~ At Total Depth 11. Field and Pool 758' FSL, 820' FEL, Sec. 7, T12N, RDE, UM Kuparuk River Field evation in feet (indicate KB, DF, etc.) 16. Lease Designation and SeriaI No. Kuparuk River 0il Pool ~KB, 60' Pad ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 01-29-82 02-14-82 02-25-82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6430', 6427' 6342' 6338' , YES [] NO [] N/A feet MD 1550' 22. Type Electric or Other Logs Run DIL/GR/MSFL/SP, FDC/CNL/BHCS/GR, MLL/Caliper, HP Temp-Gradi0-Fluid Sampler 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD · CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 24" 250sx AS II 10-3/4" 45.5# K-55 Surf 2165' 13-1/2,' lO00sx. Fondu.-& 250sx AS II ' 7" 26# K-55 Surf 6421' · ~ 873/4""405sx Class G cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD i.nte[val, size and number) .SIZEi. ' DEPTH SET (MD) PACKER SET (MD) N/A 5992'-6005' w/4 spf 0° phase . ....~ ,~.~.'. ? 6084'-6100'- 26'.' "' ACID, FRACTURE, CEMENT SQUEEZE, ETC. ._. 6107' ,6147'r'"~' .DEPTH INTERVAL (MD) .AMOUNT & KIND OF MATERIAL USED ... .. ''. ~ .. ,,. ,., .~ ,: ,. ~ , , 6172'-6178' . 2320-2340 w/4s.pf 150 sx Cl'ass G cement · 5914-5916 w/4sPf 150 sx Class G cement 27. PR'ODucTi'oN T'ESI: ""-' ' Date Fi~st.PrQduction .. , I Method of Operation (Flowing, gas lift, etc.) . 02-22-82IFlowing (see attachment 'for addition~'] information) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~02-22-82 .16.5 TESTPE.RIOD ~ 298. .9~:,.4- - 4~/¢;4I?c~ CF/B . Flow 'Tub' rig. Casing.Pressure CALCULATED OI L-BBL GAS-MCF.. wATER~B,B...L OIL GRAVITY-APl (corr) Press. 11'0 1320 24-HOUR' RATE ~ 450/day 133/day. .. -0- 23.4° ~ 60° 28. CbRE DATA - .. -' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , , Form 10-407 Submit in duplicate Rev. 7-1-80 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 Cretaceous 1273' 1273' Cretaceous interval test- Perfd 2340' -2320' Kupa~uk River Formation Pressure- 1005 psi (calculated). Formation 5975' 5971' Produced 3.3 bbl of formation water in 9 hrs, ~ 20 mi n. · Kuparuk interval test- see attachment. Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .~ S igned~~ T it,~ Sr. Drlg. E ngr. D~t~ C/ ,~~ 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:,1f 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 w' he,.ther t~om ground level (GL) or other elevation (DF, KB, etc.). (tern 23' Attacl~'e~J m~pPle~nental records for this well sh0'Uld show the details of any multiple stage cement- ing and the location of the cementing'tool. ., Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, ShUt-in, Other-explain. Item 28" If no cores taken, indicate "none" Form 10-407 CONF[OEN TIA KUPARUK RIVER UNIT Well Test Report Test Title Well Status Date -'PRE. LI Nil I~ARY WELL DATA Bottomhole Location Perforating Data Perforations S'~q~, -_~ , Mud Type Kuparuk Sands Tested Upper Middle ~' Lower Total Flow Time Oil Rate qSO BPD Choke Gas Rate I~ MCFD FTP Water Rate - BPD FFBHP GOR 2q5 CF/B HP @ MD Cum Oil ~ ...BBL HP @ SS TEST DATA Hrs. Total ~ /64 %~0 PSI I $ ?..0 PSI G, OG, OFT Shut-in Time !~. Hrs. API Grav ~J.q Viscosity ~.W CP Bo I.T.I 'RB/B WellBore Radius .~&q~ FT Compressibility -L%¢~-~PS I- 1 Drawdown Time to end of WBS HR Slope (m) lis PSI/CYC P lhr lq I~¢:} PSI Pi '~tzq PSI Kh ~&q$ MDFT Thickness (H) _ BO, FT Permeability (K) ~el.~' MD Sk in PI Actual .~qo BPD/PSI PI Ideal .~ BPD/PSI Flow Efficiency q(. % ANALYS I S Buildup Time to end of Slope (m) P lhr p* Kh Thickness (H) Permeabil i.ty Skin PI Actual PI Ideal Flow Efficiency WBS S.$ HR ~'~,~. PS I / CYC %~ PS I %~qO PSI &~,~ MDFT $~ FT ?.?,.. I MD .'Zqo BPD/PSI .~'~ BPD/PS I q-/ % Comments: MAR "' HCV 11/3/81 B-19 /~/~ i~! C! l%F i~IT! A / L~L~i~I! I IJE. l~! i I/~L ~ " . i1 ~ CONF~ WEST SAK NO. 23 ~~~~ Core Descriptions ,.~~ Core #1: 2,280' - 2,300'; Rec. 6.3'. Sandstone, dark brown, fine grained, good porosity, oil stained; and siltstone, dark gray-green. No apparent dips. Core #2: 2,300' - 2,320'; Rec. 0.51. Silty claystone and sandy siltstone, medium gray-green, low porosity, slight oil stain. No dips. Core #3: 2,320' - 2,3401; Rec. 17.5'. Sandstone, medium gray-green, fine to coarse grained, minor black and white pebbles, poor to good porosity, oil stained. Minor interbedded siltstone, dark gray-green. No dips. Core #4: 2,340' - 2,360'; Rec. 20.0'. Sandstone, greenish- gray, mostly fine grained with some gravel, good porosity, oil stained. Interbedded siltstone, dark gray; clay, greenish brown and lignite, dark brown to black. No dips. Core #5: 5,992' - 5,9971; Rec. 3.3'. Sandstone, gray- brown, mostly fine to medium grained, glauconite and siderite, fair to poor porosity, slight oil stain. No dips. Core #6: 5,997' - 6,0571; Rec. 58.21. Interbedded sandstone, medium brown, fine grained, good porosity, oil stained; and siltstone, medium gray. No dips. Core #7: 6,0571 - 6,117'; Rec. 56.3'. Sandstone, medium brown, fine grained, good porosity, oil stained; and interbedded sandstone, as above; and siltstone, gray-brown. No dips. Core #8: 6,117' - 6,177'; Rec. 59.7'. Interbedded sandstone, medium brown, fine grained, good to poor porosity, oil stained; and siltstone, medium gray. CONFIDENTIAL L\ L~(" 11, ,! ''"' ", J: \ I' \' : :,' ¡" li,J,' ~ " ','C"" ,Ii "M Ki I I, j/"' .) ~-~: West Sak 23 Drilling Hi story NU hydril & diverter system. Spudded well @ 0130 hrs, 01/29/82. Drld 13-1/2" hole to 2170' Ran multishot. Ran DIL/SFL/GR/SP from 2165' to surface. Ran 52 jts 1013/4", 45.5#/ft, K-55 casing w/shoe @ 2165'. Cmtd 10-3/4" csg w/lO00 sx Fondu and 250 sx AS II cmt. ND hydril and diverter. Instld 10-3/4" packoff & tstd to 2000 psi. NU BOPE & tstd to 3000 psi. Tstd csg to 1500 psi - ok. Drld FC, FS, & 10' new formation. Tstd formation t6 12.5 ppg EMW - ok. Drld 9-7/8" hole to 2280'. Change mud system over to bland KC1 coring mud. RIH w/core bbl #1 from 2280'-2300', recovered 6.3'. RIH and core #2 from 2300' to 2320'--recovered 1/2'. RIH core #3 from 2320' to 2340'--recovered 17.4'. RIH and core #4 from 2340' to 2360',-recovered 20'. Drld 8-3/4" hole to 3050'. Ran DIL/GR/MSFL/SP and FDC/CNL/GR/BHCS/GR. RIH and ran RFT thru Creta- ceous sands. Contd drlg 8-3/4" hole to 5992'. RIH and core #5 from 5997' to 6057'--recovered 58.2'. RIH and core #6 from 6057' to 6117'--recovered 56.4'. RIH and core #7 from 6117' to 6177'--recovered 59.5'. Drld 8-3/4" hole to 6400'. Ran multishot. Ran DIL/MSFL/GR & dipmeter from 6400'-2800'. RIH w/sidewall coring gun; 30 shots--28 recovered. Drld 8-3/4" hole to 6430'. Ran 155 its 7", 26#, K-55 casing w/FS @ 6421' Cmtd 7" csg w/255 sx Class G cmt lead slurry followed by 150 sx AS I tail siurry. Instld 7" packoff & tstd to 3000 psi - ok. Tstd csg to 2000 psi. Drld cmt to 6432' PBTD. Tstd csg to 2000 psi - ok. Ran CBL/VDL/GR from 6432' to 10-3/4", csg shoe. RIH w/perf gun and fire 4 spf thru 5914'-5916'. RIH and set EZ Drill @ 5868' Sting into EZ Drill and pump 150 sx Class G cmt. Drld retainer & cmt to 6~42'. Displaced 3-1/2" DP to 5898' w/45 bbl diesel. Set RTTS @ 5898' and tstd 3-1/2" x 7" annulus to 1500 psi - ok. RIH and perfd the following intervals w/4 spf: 6172'-6178', 6107'-6147',t6084'-6100', and 5992'-6005'. Flowed well to separa- tor for production test- oral production 280 bbl. Displaced well to NaC1/NaBr brine. Set 7" EZ Drill @ 5874'--spot 50 bbl ,Class G cmt on top of retainer. Set 7" packer on DP @ 2202'. Dropped ball and set packer. Tstd 3-1/2" x 7" annulus to 1500 psi - ok. PU 25' off pkr and displace 3'-1/2" DPopen~ew/N~ RIH and perf 2320'-2340' w/4 spf. RIH w/HP temp-gradio-fluid sampler, well to flow. Latch & unset pkr @ 2202'. Set EZ Drill @ 2235' and squeeze perfs w/127 sx AS I into formation and 23 sx below retainer. Sting out of retainer and dump 50 sx AS I on retainer. Arctic Pak 10-3/4" x 7" annulus w/300 bbl HoO, 250 sx AS I, and 120 bbl Arctic Pack. ND BOPE. Secured tree and r~leased ~g @ 2100 hrs, 02/25/82. Suspension was discussed with Lonnie Smith on 02/22/82. Suspension was witnessed by state inspector. GLV:hrl 03/19/82 ALV1/A16 I: E£E[VED Cons. Commission CONFIDENTIAL :'-"--::.'J---~J::'":'-'::" Y-'-Y::--: }:'::'!~-":..!'-"::.':.?}'?-~::'-':'-'".' ' . '~::" "'"'-' ' '.A PE-I-ROI_~NE C~RAIVY --:~'.-:-.,'." .- .... -7--- .... -" ...... -.-' :- :-:: :-: -~. .- -_,.,: . : .. .: :,_.... ...... ..:--.-=~'::::.----- ...-::_..:...:>::;:.:¥:::.::~=._::=:.:..:...::.:-..- -- --- - - .- - :.-.:.-_.__ --...:. .:-._-.:- ...... _-.- .... . ....... - .. ,._-.-.-_-.-:.--' .:..~-_::--.. .... ~ ............ ':X.-_'.'." ~ :::i:::'. . _:: ii_/; ........... '...-..L. _:-'-'./.'".:.'ii: :'_'...: ::' - ............. 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' ':_ ::~:'~::.-.:'.--'.".:'-'-.':::... - ....................':::7 ...'.'~'.'.-' ...................... : . - · - :'-' '":"':;.: ':" .,' :' --:y. :::...-_...:=-...- -'/:-:.X.'-' ':'-: _.: WEST SAK WELL N(]! ,:~ '- JOB NO~ A0:1.8,:~0245 KUF'ARUI~ F:'IE;I...I), NORTH ,:~I,..OF'E, AI...A,:~IxA .. hi H,;~, 0 -,,. 1'2 ~ ..... H D CAMERA NO~ 1488, 16.,9 10 DEG A/U NO~ ;~41A, 456A RIG; F'ARKER 141 ........ I) E C L'I N A T I 0 N'I ...... ;~ 0 A Pt:' t'l.:l(')l. ANE' CC)Mf:~NY RECORD OF SURVEY TANGENTIAL IdE'I'HOD ~r.]O ALASKA, I .ZST ~SAE ' WELL'-'NO JF'ARUK FIEL. D, NORTH SLOPE ALASKA JOB NO: A0182S0245 T I ME DATE .... 09; 07: 16 02-..FE:B--8''~ " F.' A S U R E: D D R I F' T D R I I::'"1" C C) U R S E V E R T I C A L. V E R 1" I C A L $ tJ B S E A I"',: E: [: T A N O [.EF]I-I ANGLE: I)IF~:ECTION L.I-':.N(:~IH DEF'TH SE[;'TION TVD C 0 0 R D I N F E E: 1' ............. D ...... Pi ................. D ....... M: ............. F' E E'l .............. F E E T: .............. 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E .................. 91"; ......... 1' 51'0";8 9 ............. 1" 1-;'3 0 .......... I'q 403'89 .................. 1";'50 .... N ........... i'J:W20-E ........... I'iT~ 0 ......... N .:. .,.= E ......... 13-I'2-- 1603, 0 50 N 67 0 E 9o,.. 160~...89 19,07,, 1539.89,_ 1.81 N 11,94 E 12,08 N 81 ,:.')°,= E 0.16 1694, 0 4~ N 84 0 E 91. :1.693.88 13.26 1623.88 1.94 N 13,12 E 13.27 N 81 -178¥5----l--4'~-N-'8~'~~'"92';---T78~ ........ I-8T0"~7~-B'4 ~2W~ .... ~~ ~ ".~ ,' 163' 1877. "~ . . . 2. . 2 ... 0 N 86 0 E 91.. 1876 78 19 23 1806 78 3:6 N 19 09 E 19. 4 N 82 58 E 0.27 :1. 969"~ ................ 1 ........... 0" N ' 76 ........... 0'" E ................ 92 ~ ...... 1'9 '68" ;"77 ...... 20'"~' '83: ......... 1' 898 ;-'77 .............. 2774 ...... N ---- 20 ';'65- E ........ 20"; 83: ........ N'"'82 -'26' ' E:.' ....... 1";- i' 2-' 2060. . .1. :1.5 N 63 0 lie 91. 2059.75. 22.71. 1989.75 3:.65 N ~,~o,~.42.. E 22.71. N 80 46 E 0.39 ,.090. ?. :30 N 71 0 E 30. 208~.74 23.49 2019.74 3.90 N ... 23.16 g ,=3.49 N 80 ,=._ .:. 1.05 ..-1,:.6. 1 0 ,.~ 89 ..... O-IF.] ........ 3'c'i': ........... 21'2,5"V"/3 ..... ---24';'1"1"'~2055T'73: ....... ---3:"; 8'9--N · .. RO,JEGTED TO TD · ,.170. 1 0 S 89 0 E:.' 44. 2169.7:3 24.86 2099.73 3.88 N 24,56 E "') e . ,~4 86 N 81 2 E 0,00 FINAL CLOSURE - DIRECTION; N 81 D l ST ANCE; 24,86 DEGS i MINS 49 SEC, S E ,..,,. F:' E E T ,., - Suggested form to be inserted in each "Active" well folder to d~.cck for tin'ely cc~,,pliance with our regulations. Oi~rator, Well ~ame and Number Reports and Materials to be received by: ~-~7--~- Date F..cquired Date Received · , ,. Ccrr~letion Report Yes ........... . ........ ~ -..~:. x ;; . , Wel 1 Hist°~ Yes ... Mud L~ .. ~re ~ips . ~ ...... ...,.~ .... Core ~scriptio= ...... ~.~ ~ ,,. ~ ~2~ - ~ ~ Registered Su~ey Plat ~e~ ~".0 77 '~Z' . . . Inclination Su~ey ~S ~-"~ ~ , ......... . .... , · , ~ , ............. Drill St~ Test Re~s .~'2 ,:~:"' :~..., "~' - - - -' .... 0~. _ Pr~u~ion Test Re~rts ,..~ .... ~ ~,~,.~;..~ STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDIX Atlantic Richfield Company ~ORTH SLOPE DISTRICT TRANSMITTAL ' Wm. Van Allen .-Alaska State Oil & Gas- ' :e: Mar. 19, 1982 tnsmitted herewith are the following: . One Copy .- ARCO: Kuparuk Field West 'Sak #~3 .. . .' · · ' :2222/24-81 -Camco Pressure Data From: R.' W. Crick - Ext. Exploration ceipt Acknowledge: j turn receil,t t .~~Arco Oi; and Gas North Slope District At tn: Lucille JohnS~ton P.O. Box 360 · · REC. EIVED_ "' ~qla'~a~~s. Cons. C~ ' A,c, orage ...... o.u, %. Processed by:___Lucil]e Johnston ALASKA OIL AND GAS CONSERVATION COM~ISSION Thru: Cha~~rton Cha~TM Lonnie C. Smith Commissioner Doug Amos Petroleum Inspector ~darch 4, 1982 Witness Plugging for Suspension of ARCC.'s West Sak ~23 Well Sec. 7, T12N, R9E, U.b~. on Parker Rig No. 141 Tuesday, February 23, 1982 - I traveled this d. ate from Anchorage t~'~u~hoe Bay""to"'w~tneSs the plugging of aRCO's West Sak No. 23 wel 1. Upon arrival I was informed that a 7" E2 drill retainer had been set at 5,872'. At 7~45 p.m. a 50 sak class "C,,." cement plug at 15.8 ppg had been placed on top of the E2 drill retainer. W~ednesday,._February_2~4,_ !_9.82 - At 12:25 a.m. I accompanied Tom Fithian, ARCO representative to the rig floor and witnessed the tagging of the second plug. The toF: of plug number two was confirmed at 5,548' with 70,000 pounds of weight. At 3:00 p.m. I again accompanied Tom Fithian to the rig floor to witness the setting of a 7" E2 drill retainer. This retainer was set at 2,235' and tested with 40,000 lbs weight and 1000 psi pressure. At 5:00 p.m. a 2.5 bbl/min pump rate was established and 10 bbls of water followed by 33% bbls of Arcticset I cement at 15.7 ppg were pumped below the E2 drill retainer. At 5:24 p.m. the pumps were stopped and a hesitation squeeze procedure was commenced. The perforation was squeezed with a total of 7 bbls of cement. The maximum surface pressure used to squeeze with was 700 psi, after completion of the squeeze procedure and with pump shut off the perforation held 500 psi with no bleed down for 15 minutes. The drill pipe was unstung from the E2 drill retainer and approxi- mately 8 bbls of cement was spotted on top of the retainer. T~h_u~s~d~a¥~_ February_ ~25~___!9_8_2.. - At 7:15 a.m. I witnessed the tagging of the third and final plug. The plug was tagged with open end and drill pipe and 10,000 lbs of weight at 2147'. The remainder of the 7" x 10 3/4" annulus was filled with 7'2 ppg Arctic Pak. In summary, I witnessed the plugging for suspension of ARCO's West Sak %23 well. There were three plugs set in the 7" casing 1 081~ Chat Chatterto~'~' March 4, 1982 and the. remainder of the 7' x 10 3/4' annulus filled with 7.2 pp~ Arctic Pak. For ad~/tional information on plugs set, see attached drawing showing the well bore. ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: .Chat ~~~e/ton Lonnie t2. Smith / commissioner Bobby Foste~ ~ ~. Petroleum Inspector February 5, 1982 Witness BOPE Test on ARCO's West Sa~ #23 Sec. 7, T12N, R9E, Ub~ Permit #81-194 S_unday,~_January .31,_ 1982 - I traveled this date to Prudhoe Bay to witness the upcoming BOPE test on ARCO's West Sag #23. ..M.0~n.day,. Febru_ary. !,___1_9_8_2 - Standing by for BOPE test. _T.uesday,~ Febr~a~__2~_ _1_9_82 - After numerous delays the BOPE test began-at 12:00 a.m. and was halted at 6:00 a.m. due to the bottom set of pipe rams leaking. The rig crew opened the ram doors and discovered a round piece of metal approximately 3/4" ~in diameter and 1%" long in the ram block body. This had caused a "wash-out" in preventer body. John Nydegger, ARCO drilling foreman, informed me that the lower set of preventers would, have to be replaced. Wednesday~ Fe_bru_a~_ _3,_._19_8_2 - The BOPE stack was removed, the bott°m set of preventers replaced, and the stack was set on the well head spool. After tightening the flanges and connections disconnected when the stack was picked, up another pressure test was performed. Everything tested okay. This includes the valve in the choke manifold which fa iled~ the first test. The accumulator unit did not perform correctly during the intial test and I informed John that pressure after closure and the full charge pressure time was not satisfactory. I requested that the precharge pressure be checked on all the bottles, the master valve on the annular preventer control be replaced and the pressure control valves controlling the manifold pressure and the annular preventer be repaired/replaced and myself or the A.O.G.C.C. notified. In summary I witnessed the BOPE test on ARCO's West Sa~ %23. Attachment: I spdke with Larry McDowell on February 16, 1982, and he informed me that the accumulator unit had been repaired. Eight bladders were replaced, the four %~ay valve on the annular preventer replaced, and the precharge pressure checked on all the accumulator bottles. ©~&G ~4 4/8o STATE OF A1,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~~O__~_~4 /"-~/~.,/~., Drilling C6ntr, ctor ~ ~cation, General ~/~ "' Wel 1 Sign General Housekeeping RigReserve pit,. , BOPE Stack Annular Preventer / Pipe Rams -, Blind Rams / Choke Line Valves H.C.R. Valve / Kill Line Valves ' 'Z Check Valve · Representative JOA~J ~/~ ~_~-~OC~,~'' Permit # ~ /- /~' '/ ' ; l~e~asing Set ~ ~ 1~ ~" ft. Rig 9/~/ Representative- ~O~ ~)~&,3~,J ACCUMU~TOR SYSTEM / Full 'Charge Pressure~0~O psig Pressure After Closure//~ psig 200 psig Above Precharge Attained: / min ~ sec Full Charge Pressure Attained: ~ min~ sec Controls: Master~~ Remote~_~ Blinds switch cover~ / Test Pres sure 1.3' o Kelly and Floor Safety Valves Upper Kelly,. / Test Pressure Lower Kelly.. ,/ Test Pressure Ball Type / Test Pressure Inside BOP ~ Test Pressure Choke Manifold c/~ Test Pressure~_~',£D No. Valves ~ ! No. flanges Z ~ I Adj usfable Chokes .Hydrauically operated choke / Test Results: Failures I Test Time Repair or Replacement of failed equipment to be made within ~ days and InspectorXCo, mmission office noti. fied., ~ December 31, 1981 Ur. D. ~. Smiley Senior Drilling Engineer ARCO Alaska, Inc. P, O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk 25631 West Sak 23 ARCO Alaska, Inc. Permit No. 81-194 '~ur. Loc.= ?20'FSL, 800'FEL, Sec ?, T12N, ~9~; U~. Bottomhole Loc. = S A M ~ Dear Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud log are required. An inclination survey is required. If available, a tape containing the digitized log information shall be submitted on all logs .for copying except experimental log's, velocity surveys and dipmeter surveys. },iany rivers in Alaska and their drainage syste~us have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to A~ 16.50.870 and the regulations pr~lgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Itabitat Coordinator's office, Department of Fish and Garde. Pollution of any waters of the State is prohibited/by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. D. S. ~iley Kuparuk 25631 West Sak 23 -2- December 31, 1981 cmfcaencinff operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreefate your notifying this office within 48 hours after the well is spudded. We would al so like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout, preventer equt'.p~ent before surface castn[~ shoe is dril led. In the event of suspension or abandonment, please ~ive this office adequate advance notification so that we may have a wi tness present. Very truly yours, Chairman of Alaska Oil & Gas Conservation Coa~tssion F. al, elosure ce~ Department of Fish & .Game, Babitat Section w/o enol. Department of Environmental Conservation w/o/enel. HHH~be Mr. Blair Wondzel 1 Alaska Oil & Gas Conservation Comm. Office Of The Governor 3001 Porcupine Drive Anchorage, Alaska 99501 Governmenta/ Coordination ~Init September 11, 1981 IVI/S- O I B$ Subject: ARCO BEAUFORT SEA 214 OIL & GAS PERMIT State I D Number AK810910-O5FP Dear Mr. Wondzel 1: The referenced project has been rec~ for a Consistency Determi Management Program ( A C management district do, coastal management Please inform us 1 s consi stent wi area. If you be identi fy thoSe project consi Your comments' its decision To be cons Thank you for your' wfth the State Clearinghouse i th the Alaska Coastal rnment or coastal district input. when: ~he t,~.gf s project in your )lease make the makes ACMP. 10-07-81. Dave Haas State Federal Assistance Coo Enclosure - with distribution list of reviewers PROPOSED FUNDIN~ e.. STATE BER OF BEHF. F1TINQ I ,~. LO,IU. I .00 · . OTi,IER I f. TOT,~L ,] $ .DO 16. PROJECT ~TART ~17. PR'CM£CT DATE ~"~..- .,..o.r,~, &~¥I DURATION 19 F-.,STIMATED DATE TO BE: SUEM.~'~'ED TO FEDERAL AGENCY 'No. 2 letter-_ :.VIEW COHPLETION DATE for applicant- ,/~//~/~ /for reviewers- /~//?. ~/COMMUNITY AND REGIONAL AFFAIRS - SC~IO RurAL CAP -/P7X08 TYPE REVIEW EDUCATION - SE020 ENVIRONMENTAL CONSERVATION - SV200 Southeastern Region - SV201 Southcentral Region- SV202 No rthe rn Reg i on - SV203 v~_FISH AND GAME (Central Office) - SFIO0 Juneau'- SFI01 Ancho rage- SF102 |,~ ~ai thanks - SF103 ///TRANSPORTATION & PUBLIC FACILITIES- STl15 LABOR- SL010 LAW - SW010 MILITARY AFFAIRS - SMOIO Z~__NATURAL RESOURCES - SNIO0 BIA- FIIO0 - AFN - NS202 BLM - FI200 U.S. FOREST SERVICE - FAIO0 U.S. PUBLIC HEALTH SERVICES- FWI03 CORPS OF ENGINEERS- FD202 CITY OF: NATIVE CORPORATION' PUBLIC SAFETY - SP010 ~./COMMERCE & ECONOHIC DEVELOPMENT - SD010 l~mo/E.) BOROUGH' REVENUE - SRO10 MOA - BZOIO CRIMINAL JUSTICE PLANNING AGENCY - SWIO0 NORTHERN HSA.- PDNO0 ,I ,.ALASKA COURT SYSTEM- SJOIO ---- SOUTHCENTRAL HSA - PZSO0 OFFICE OF COASTAL MANAGEMENT - SGIO0 SOUTHEASTERN HSA PHSO0 / HEALTH AND SOCIAL SERVICES - SH500 OTHER LETTERS' ADMINISTRATION - SAOIO REPLY TO ATT[NTION OF: NPACO-RF-P Beaufort Sea 214 DEPARTMENT OF THE A(,MY:'':'--~:-' "-"::' -! -' :-' ALASKA DISTRICT, CORPS OF ENGIN~'ERS .- · P.O. BOX 7002 '" -- -' ~ -' REGULATCRY PqJNCTIONS B1R/~NEH!'"L::-.~: ,.-'" '-;:-'-- - (907) 279-4123 9 September 1981 PUBL;C NOTICE NPACO No. 071-0YD-4-810337 An application has been received in this office from ARCO Alaska, Inc., P.O. Box 360, Anchorage, Alaska 99510, for a Department of the Army permit under Section 404 of the Clean Water Act (Public Law 95-217) to construct an exploratory drill pad (West Sak 23) in the Kuparuk Oil Field, Section 7, T12N, R9E, U.M., near P-r-~-Shoe Bay, Alaska, as shown on the plans attached to this notice. The applicant proposes to place approximately 35,000 cubic yards of gravel for the following work' a. Construct a 300'x450' exploratory drill pad and a 120'xl20' staging pad. b. Construct four lO'x2OO'x5' berms to create a 200'x200' flare pit with a 20'x150' access road. c. Construct four lO'x70' berms and a lO'x350' berm to create a 70'x350' three-section reserve pit. Gravel placed for the project would have a minimum depth of 5', 2-1 side slopes, and would be obtained from the Kuparuk Mine Site "C." Approximately 6 acres of wetlands would be impacted for the project. In addition to the aforementioned 6-acre area to be impacted for this project, the applicant has requested comments on the 900'x900' area indicated on the plan, which encompasses the proposed project. The applicant has stated that this area, approximately 18.6 acres, is the maximum area which would be impacted by future expansion. A Certificate of Reasonable Assurance or waiver of certification is required for this activity under Section 401 of the Clean Water Act (Public Law 95-217). This certification, or waiver thereof, is issued by the Alaska Department of Environmental Conservation, Juneau, Alaska. The Division of Policy Development and Planning, State of Alaska, is reviewing this work for consistency with the approved Alaska Coastal Management Program. Preliminary determinations indicate the issuance of this permit is a major Federal action not significantly affecting the human environment, and an environmental impact statement is not required. NPACO-RF-P Beaufort Sea 214 The evaluation of the impact of the activity on the public interest will include application of the guidelines promulgated by the Administrator, EPA, under authority of Section 404(b) of the Clean Water Act (Public Law 95-217). The National Register of Historic Places and the latest published version of the Federal Register have been consulted in regard to the proposed activity. Consultation of the National Register constitutes the extent of cultural resource ~nvestigations by the District Engineer, and he is otherwise unaware of the presence of such resources. Preliminary determinations indicate that the proposed activity will not affect an endangered species or their critical habitat designated as endangered or threatened pursuant to the Endangered Species Act of 1973 (87 Stat. 884). Formal consultation pursuant to Section 7 of the Act with the Department of Interior or Commerce is not required for th~s prop~sed activity. The decision whether~ to issue a permit will be based on an evaluation of the probabl'e impact of the proposed activity on the public interest. That decision will' reflect the National concern for ~both protection and utilization of important resources. The benefit which reasonably may be expected to accrue from the proposal must be balanced against its reasonable foreseeable detriments. All factors which may be relevant to the proposal will be considered; among those are conservation,· economics, aesthetics, general environmental concerns, historic values, fish and wildl~ife values, flood damage Prevention, land use, navigation, recreation, water supply, water quality, energy needs, safety, food production, and, in general, the needs and welfare of..the people. · Any person may request, .in writing, within the comment period .specified in this notice, that a-public hearing be held to consider this application. Requests for public hearings shall state, with particularitY, the reasons for holding a public hearing. Written~ statements received 'in this office on or before 9 October 1981 will become a part of the record and will be considered in the determination. Any response to this notice shoUld be mailed to the Alaska District, Corps of Engineers, ATTN: Regulatory Functions Branch, P.O. Box 7002, Anchorage, Alaska 99510. If further information is desired concerning this notice, contact Ms..Kathy Curtis at (907)'752-4942 or (907) 279-4123. :. FOR. THE DISTRICT ENGINEER: 3 Incl 1. Plan 2. ACMP Notice 3. 401 Notice M. J~MES WOLFE~ Chief, Permit Processing Section Regulatory Functions Branch i:~UCHO~. ALASKA V I C I N I TY HAP I~ N~RRISON BAY B£RUFORT SEA PROPOSEO EXPLORRTORY DRILL SITE VICINITY HAP !t ILF.~ OLIICTO~ PT LOCATION' ~EST SEC 7. B, 17. 18: Tt2N-RgE U.M. ADL 2-ff~3~AD~ EXPLORATORY DRILL WEST SAK 23 KUPRRUK FIELD NORTH SLOPE BOROUGH STATE OF ALASKA SITE I0' FLAJ~E P IT SECTION B-B VERTICAL SCALE, I ": 20 ' HCRIZCNTAL SCALE' i0' .i O.' 60'/~, RESERVE PIT · DRILLING PAD I TUNDRA SECTIC~N A-A VERTICAL SC, ALE' I" HORIZONTAL SCALE' I '~ ......... A--~-- - - HELICOPTER - - - I I ICE PAD - - ' ......... ! - 450' .... SITE 120' B- - - - - - -B- - - PLAN VIEW ~-. .. - - ~' - -'LR'~-- ' ~ 'SCALE, · · ACREAGE, i B~6 ACRES GRAVEL vOLu~, '~5,000 C.Y. PURPOSE, OIL FIELD DEVELOP~,~ENT ADJACENT PROPERTY OWNER, STALE OF ALASKA DATUM' t/'-=AN SEA LEVEL t-OC~TION':~'700.' FSL, 700' FEL, Sec' 7, 'T12N, RD~d~ . . PROPOSED SITE PLAN EXPLORATORY DRILL SITE ~E~ST SAK 25 KUPARUK FIELD NORTH SLCPE BOROUGH STATE OF ALASKA APPLZC~TIO~ B~'* /~CO AI.~S~ ~NC. .SHEET, 2 OF ~ DATE~ 8/7/81 DIVISION OF POLICY DEVELOP.Mr-NT ?aND PL~NNING / Pouch AD-Juneau 99B11 STATE OF ALASKA ])i¥ISiON OF POLICY DEVELOPMENT AND PLANNING Notice of Application for Certification cf Ccnsistency with the Alaska Coastal Management Program Nc. rice is hereby given that a request is being' filed with the Division' of Policy Development and Planning for concurrence, as provided in Section 307 (c)(3) of the Coastal Zone Management Act of 1972, as amended [P.L. '94-370; 90 Stat.. 1013; 16 U.S.C. 1456 (c)(3)], that the project described in the Corps of Engineers Public Notice No. 071-0YD-4-810337 , will comply w/th the Alaska Coastal Management Program and t~at-the .4 . project will be conducted in a manner .consistent wish that program. Any person desiring to present views on considerations pertaining to the project's compliance or consistency with the Alaska Coastal Management Program may do so by providing h~s views in writing to the State Clear- jngho~se, D,i~ision of Policy Deve].opmer;~ and Planning, Office of the Coverno[, Pou'ch AD, Juneau, Alaska 998'11, within 20 days.of publication of t_his noticc, Incl 2 DEP~F. OF ENVIRONMENT.~.,L (~ONSERVATION POUCH 0 - JUNEAU $~1I NOTI~ OF APPLICATION FOR STATE WATER QUALITY CERTIFICATION Any applicant for a Federal license or permit to conduct any activity which may result in .any discharge into the navigable waters must first applyfor and obtain certification from the Alaska Department of Environmental ConSerVation that any such discharge will comply with the Clean Water Act of'1977 (PL 95-217), the Alaska Water Quality Standards and other~applicab!e State laws. By Agreement between the U.S. Army cOrPs of Engineers and the AlaSka Department of Environmental Conservation applicationfor a Department of the Army Permit.may also serve as applica- tion for state Water Quality Certification when such certification is ,.. necessary. Notice is hereby given that the application for a Department of the Army Permit described in the Corps of Engineers Public Notice No. 07]-0¥D-4'8]0337 also serves as application for State Water Quality Certification from the Alaska Department of Environmental Conservation, as provided~in Section 401 of the Clean Water Act of 1977 (PL 95-217). The Department will review the proposed activity to insure that any dis- charge to waters of the United States resulting from the referenced pro- ject will comply with the Clean Water Act of 1977 (PL 95-217) the Alaska Water Quality Standards and other applicable State laws. Any person desiring to comment on the water quality impacts of the pro- posed project may do so by writing to: Alaska Department of Environmental Conservation NOrthern Regional Office P.O. Box ].601 Fairbanks, Alaska 99701 Telephone: 452-1714 within 30 days of publication of this notice. Incl 3 ARCO Alaska, Inc. / Post Office Bt,, .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 December 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamil ton: ARCO Alaska, Inc. proposes to drill a delineation well, Kuparuk West Sak 23, commencing on approximately January 6, 1982. Attached please find: 1. A "Permit to Drill" application form. 2. A plat showing surface and target locations. e A determination of maximum pressure to which BOPE could be subjected. 4. ' Diagrams and operational procedures for the 20" 2000 .psi diverter'stack ~and 13-5/8" 5000 psi RSRRA stack. Please feel free to contact us at 263-4272 if we can be of any assistance. Sincerely, Sr.' Dril ! ing Engineer DDS: CLC: 1 tc Attachments RECEIVEI) DEC2 9 1981 Aiasl(.a 0it & Gas Cons. Commission ~ch0rags ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany · {. STATE OF ALASKA C~'~-. ALASKA ~ AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] Del i neation DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN I-1 DEVELOPMENT GAS I--1 MULTIPLE ZONE [] 2. Name of operator · ARCO Alaska, ]]nc. PlqlklIZln I ITIAI 3. Address UUlll lULl1 I I/'~1., P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 720'FSL, 800'FEL, Sec. 7, T12N, R9E, UM DEC2 9]c~] Kuparuk 25631 At top of proposed producing interval " 10. Well number Straight Hole Al~ska0il& Gas Cons. Cornrniss[o:.m . West Sak 23 At total depth Anc.h0rage 11 Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0il Po01 EST, 55'GL/60'Pad/87'KB 25633 ALK 2564 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number Fed :Ins Co 8088-26,-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 40 Miles ~IWDeadhorse miles 720' feet well 2½ Mi l es feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6400'MD 6400'TVD feet 2560 1/30/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures2410 psig@ O-32-~ Surface KICK OFF POINT __ feet. MAXIMUM HOLE ANGLE 0 oI (see 20 AAC 25.035 (c) (2) 3080 psig@ 6077 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program · SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 72" Corrua~ted Ce'lar 5' Pad I Pad 32' I 32' Backfilled . 24" 16" 65# - H-40 {elded ~'! 80' Pad ~ Pad 107''1 107' 250sx AS II 13½" 10-3/4 45.5# K-55 BTC 2173' Pad ~, Pad 2200' 12200' llOOsx Fondu 250sx AS 8½" 7" 26# K-55 BTC 6373' Pad ~ Pad 6400' 16400' 400sx EXT G+ I I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field Delineation well to 6400'MD. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOP stack will be installed on the 10-3/4" surface string & tested upon installation and weekly to 3000 psi. The well will be completed with 3½" tubing and packer., Non-freezing fluids will be left in uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk'formation and cretaceous sands'. A downhole safety valve will be installed with the completion string and will be shut.and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commission use / CONDITIONS OF APPROVAL I Samples required Mud Icg required Directional Survey required APl number ]~r,Y ES []NO ~,Y ES ENO t-)YES ~NO 50-- Permit number Approval date' o~/. /~z/- 12/31/81 I SEE COVER LETTER FOR OTHE,R REQUIREMENTS BY_~ ,COMMISSIONER DATE December 31, APPROVED 1981 by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 Ii .. v, I.,o4o,o00 .... ~ v, I,.040.000 ! i:-i- · ii i, ii · ! + '1 5§ 4 SOCAL 1~5 · 5O9 L 85 -)5516 UNION AMOCt 979 · 47!34 . .: :.'.:.:: ~84 t I,i K466 84 AL~469 $ ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3080 psia : 3065 psig from RFT & pressure buildup date. This pressure @ 5990' SS = 6077' TVD will be balanced by 9.7 ppg mud wt. Normal drilling practice calls for 10.3 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 175 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2410 psig during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (165OF, 3080 psia), gas migration to the surface w/o expansion, and cooling to 32OF winter cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf: volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf ie no expansion Ti Tf Then Pf = P.T : (3080 psia)(32 + 460) ~ (165o~ + 460) Pf = 2425 psia = 2410 psig Surface Dive .er System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. '20" bell nipple. Maintenance & Operation ~-~ 1. Upon initial installation close annular I preventer and verify that ball valves ! have opened properly. . I 2. Close annul.ar preventer and blow air ~,_ ~ through diVerter lines every 12 hours. t 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RNNULRR PREVENTOR BLIND RRMS 8 (R-5/8" 5000 PSI RSRRA BOP STACK(" 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. lO" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACC~IULATOR CAPACITY TEST PIPE RRHS 7 DRILLING~~ q sP6OOL FJJ / PIPE RRHS ~ ITBG HD 3 CSG 1 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE~qINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST RE~tAINING UNTESTED MANIFOLD ~.~ VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF ~\~GIkLVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM ./,~ ,~,~'~¥~'~0 ZERO PSI. ~ ' ~%~. OPEN TOP SET OF PIPE ~4S AND CLOSE BOTTOM SET OF PIPE ~MS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO ll. OPEN BOTTOH SET OF PIPE R~S. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND ~,IS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND R~IS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESELPOSITION. AND ALL VALVES ARE SET IN DRILLING 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOHEY PUMP. 15, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FOPJi SIGN AND SEND TO DRILLING SUPER- VISOR. 16. PERFORI4 COIIPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (I) Fee ~ f~/~'/ (2 thru 8) YES NO 1. Is the permit fee attached .......................................... ~ . ,, me 3. 4. 5. 6. 7. 8. (3) Admin ~ ,'~~ (9thru 11) 10. 11. (4) Casg ~ tz/$~{ (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. (5> BOPE _ ~~ l~I~/~! (21 thru 24) REMARKS Is well to be located in a defined pool ..................... [ Is well located proper distance from property line ..... !ii!iiiiiiii~i 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 ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ...~~ Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. 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-~QO ~s~'~ -- Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements Additional Remarks: Geology: Engingering: HWK ~g. LCS ~ 'BEW~ WVAjAL ~ JKT ----__ PAD _iT)_ rev: 03/10/81 INITIAL I GEO. UNIT ON/OFF POOL CLASS STATUSt 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. * DEPTH · ~IP DIP · Pf:~ DEV. UIA~ DI. AM e e kZl. · AZ1. e 2tb6 3,~0 J42 1.2 67 ~ 210B ~{ 4.,7 134 1.2 74 ll.i * 2170 4.9 253 1;.2 72 11.9 * 2172 5,0 278 1.2 8i II.8 11,.8 * 2174 ~,2 291 1.2 95 11.7 11,.6 * 2176 {, I 222 1.2 94 10.9 11,.0 ~ 2178 4, 4 le,7 1.2 * 2182 4,3 223 1.2 88 * 21~4 21,~.4 132 1.2 * 218~ ),5 60 1.2 ~ 2188 1.2 e 2190 1o2 90 e 2192 1.2 85 10.1 10.5 ~ 2194 5.~0 186 1.2 83 10.2 * 2196 8,~1 191 I.{ ~0 I0.4 I0.6 * 2200 4.~B 152 I .4 76 10.5 ~10. 2202 1.4 77 220.4 4.;~ 251 1.4 2206 1.4 79 8.6 2208 1.4 2210 ),:5 238 1.'4 76 2212 2.~8 296 I'.4 74 lO,l 2214 1t,~4 204 1.,~ 74 221~ ~,,2 202 1.4 75 222'0 I 0 *5 26:4 ,t'. 4 2222 '~. 4 2'64 I .4 7b 2224 2, 5 252 I.,4 79 2226 l .9 74 1~. ~ 222~ 3.6 122 1.4 2.230 1.4 , 232 5 9 282 1.4 2234 -14,4 28:5 1.4 79 22{ 1.4 .77 9.t 22~8 '2), 2 273 1,4 2240 25.2 276 1.4 22'42 3),~2 2.93 1.4 73 2244 1.4 71 2246 i.4 224B ~.9 111 1.4 71 2250 2,4 2252 ~,2 2256 4,5 97 1.4 ?I 9.4 2258 ~,1 171 1.$ 69 i0.7 22b0 ].4 245 1.4 bb 11.7 2262 ~.9 330 1,.-4 68 12.0 226b b,8 180 1.4 74 I0.~ 22;72 5.~ lb7 1.5 71 11.0 2276 7¢8 9.2 9.~ 10.2 lO.B I0.8 I0 11.I 9.3 2282 214.8 19! 1.5 60 2284 ~.:4 t60 1.5 67 11.5 ~2 3.!7 116 1.~ 73 9.7 ~294 1.-4 70 IO.6 2t06 1.4 71 9.8 2~1o 1.5 75 2312 5.9 192 1~.~ ~9 8,2 2314 1.6 2~18 26,3 154 1.6 79 2122 I..~ 8B 10.0 2324 1.8 2{{0 1.8 2~{2 1 2{3~ 1.8 233e 23.38 I. 8 2340 234~ 2344 2346 9,4 i48 1-8 2350 ~10,;5 105 1.8 2 ~64 2~bb 1.8 2380 1'.~t 146 2.0 23'B2 2,,8 4.9 2.0 2~8& ~l 0~9 12~ 2.0 2~88 O, b ~45 2.0 2,~vO ~I~,~ 340 2392 1~,;7 344 ~94 ~,~2 331 2.0 2{96 9,.1 28t 2.0 2~g8 2.0 2402 I~.~7 ~23 2404 ~,~ 1~2 2.0 =$ORE,,H,OI, E · OUAL, AZI. INDEX # DE~TH ~ ,[ I,P DIP * DEV 240b 10,0 19~ 2.0 240~ 11,,2 19~ 2.1 2410 'I),4 189 2412 ~, J 151 2.1 2414 5.8 15~ 2.0 241e 5.1 101 2.0 2418 4,~ 52 24~0 4.8 ~0 2.0 2422 ~.0 77 2424 2.4 1~7 2. i 2428 ~3 2.9 1.7) 2.2 2432 I ,~7 81 2434 ~, 2 151 243~ :2440 2.2 24~2 3,~7 191 2~44 5,9 194 2448 2.9 37 2452 2.~7 22-1 2.2 2454 4,2 22'I 2-2 2456 8, b 17.4 2.2 245~ 1~, 2 124 2.2 2~60 '~, 5 195 2.2 2462 2~66 1.,:5 203 2468 3.3 1~:3 2.2 2470 1,. I 20 2.2 2472 ~. 0 2~ 2474 4.1 332 2.2 .247b 4.2 210 2480 4, 4 2.39 2.2 24~ 4 2.5 2.4:7 2.2 . DEV. DIAM DJ~AM AZI. 1-3 2-4 82 8O 81 82 78 7:7 80 82 '/8 75 77 8O ~2 82 85 78 91 8.2 8.1 8,8 8.2 8.4 8.3 8.4 8.6 ~.7 8.3 8.1 8.3 8.2 8.3 8.3 8.5 8.2 8.2 8, S 8.3 8.~ 8.2 B.5 8.2 8.b 8.2 8.7 8.2 8.7 ~.1 9.7 ~, 2 8.5 8.4 ~.2 9,0 8,7 8.3 8,9 9,2 ~.4 8.8 8.4 ~.5 8.1 A C A C C A C C A A A A A 2480 ~.3 lbl :2.2 89 Z492 ), 5 167 2.3 91 249~ T,O 145 2.4 86 9.2 2498 ~. 3 14-5 2.4 82 9.0 2500 2.9 15~ 2,4 81 9.0 2502 2.~7 192 2.4 ~4 2504 ~,~ 64 2.3 85 9.8 2508 ,15, 6 151 2.2 88 9.9 25.10 2.2 92 10.5 2512 2.2 87 10.4 2522 11~,2 136 2.2 90 10,2 252b 9,6 i26 2.2 90 2'~28 7:,~7 140 2.2 95 gS~O 5,~5 211 2.2 99 9.6 2534 ~, b 245 2.0 99 2540 6.8 225 2.0 lOi 2542 ~.0 1~4 2.0 101 2544 ~, I 15 2.1 100 8.9 29'46 ~.! 15 2,2 100 8.9 2550 ),,l 29-I 2.2 100 8.8 2552 ~. 3 52 2.2 100 8.~ :2554 1.0 83 2.2 103 8.9 2558 2.! 178 2.0 101 8.5 2560 4,0 i8:5 2.0 101 8.5 2~2 o,O i67 2.0 103 2564 3-8 224 2.0 103 8..) * 2566 ~,,1 242 2,,0 I02 ~ 2568 5,4 24~ 2.0 103 a ~570 2.8 24e 2.0 103 + 2572 4,4 173 2.0 103 * 2576 3.0 JO5 2.0 108 ~ 2578 ~,,7 248 ~.0 109 ~ 2580 6.0 ~6B 2.0 109 * 2582 '5.~7 267 2.0 1'05 , 2586 2.9 ~7~ 2.0 ,lO& * 2588 3.0 ]3~ 2.0 108 ~ 2590 0.~ 165 2.0 106 ~ 2592 ~, 4 1]¢~ 2.0 103 ~ ~598 1,9 !0'4 ,m 2~00 ~. 3 {33 I~.~ ~I04 * 2bOb 2.0 10 t ~ 2~OB 2.o 104 * 2bio b, 4 ~2 2.0 107 ~ 2612 4,,,i 144 2.0 105 ,~ 2614 1,8 197 2.0 ilO0 * 2620 2.2 ~2 ~* 2624 2.0 106 * 2626 2.0 l 0 ~ * 2628 2.0 96 * 2630 2.0 98 * 2b~4 2.0 99 '* gb)e 2.0 106 * 26 38 ~. 0 I 15. ~ 2~40 2,0 !19 ~ 2~42 ~.0 1 18 * 2644 2.'0 1i3 A A A A C C A A A A A C A 264~ 2.0 107 2648 2.0 104 2650 2.0 97 2652 Io9 I00 2658 68.2 21 2°0 i20 2662 l:o~ 130 2606 1:.9 2670 t,~ 1~74 2.0 2672 2.0 127 2~74 9.4 ~i9 2.0 124 2676 3.I 22~4 2.0 121 2~82 0.~ 2t2 2.0 124 2690 ~,5 ~99 1.9 125 2092 0.9 242 1~.8 :122 2094 ~,~4 241 1.8 12I 26~6 2,~ 232 1.~ 269~ ~, 0 ~72 I.~ 123 2702 4.8 1~9 1.8 124 2710 b~,l 262 1.8 117 2716 ~,3 }19 1.8 2718 {10.:~ {:7:3 1.8 2720 ~,:8 248 1.8 126 2722 9,3 i8.7 1o8 125 2728 1.8 120 8.b 8.5 ..{ 2't~0 1-.8 122 9.O 6.2 · 22B4 1.8 121 9.4 8.2 ~ 27{8 11..~ 1~6 l..B {27 8.7 8.2 u * 2~40 ~, 3 194 1.8 128 ~.5 ~.2 A · 2744 ], 5 236 I.~:' 127 8.5 ~. 2 A { 274~ ).4 2'72 1.8 125 8.5 ~.2 A · 2750 4,0 255 1.8 122 8.6 8.2 C ~ 2752 2.~ 5 1.8 122 8.5 8.2 C * 2760 3.] 318 1.6 12~ 8.5 B.2 A *: 2~2 ~,~0 318 1.6 12~ ~.4 8.2 A · 27~'6 7.~ lO~ l.~ 129 B,7 0,2 A -~ 2790 ~, ) 221 i.~ i32 8.5 ~. 4 A ~ 2792 6..9 2~34 L.? ~{ 2~ 8.7 8, O A ~ 2794 1.6 125 '9,1 8.9 ~ 2798 ~1 ~.8 2~ 1,.~ t30 9.4 ~. 7 C ,~ 2800 ~10.9 263 I~.6 129 g.4 ~, 6 A ~ 2802 5.0 295 1.5 i~9 9.2 B~,~ C ,~ . OUA6. OX, AM e IS~GT 2'4 · =A All, 280b 14.4 219 1.4 126 2808 1.5 127 9.0 2810 1.6 127 9.1 9.4 2812 1.6 130 9.2 ~,7 2014 1.6 ~27 2818 e,O 15,5 1.8 127 9.~ 2820 ,D,l 82 1.? 131 2~4 2,{ 243 1.6 129 2828 1.6 122 2830 1'5 125 2832 ~,5 19 1.4 124 9.1 28{4 I.'4 123 2836 6,~8 ~9 :1.4 123 2840 7.i8 '3'3 i,..4 ~t24 2842 1.4 1~4 ~.~ V.O 284~ :I.:5 120 28,46 1,~ i19 2a52 1.6 i34 2854 9,~ 4:5 1.6 135 2856 ),0 227 1.~ 131 2872 1.4 1~2 9.1 2878 1,5 129 28B0 l,b 132 2884 1.6 1i9 ~ FORMATION ~ 60:~EI~O~E ~ UUAL, ~ '''''''''''''''''''''''''''''''''''''''''''''-''--'-'-' ~ND~X ~ 2~B6 34, 5 247 1.6 12b 9.5 e.4 [) ~ 2~90 1.6 12~ 9.3 ~,7 ~ 2892 4, 3 14:3 I ,b 127 ~,4 8,5 C · 2898 1',~ lB8 1,6 123 9,1 8, 5 C ~ 2900 3~ ~ 22.4 I .6 125 8.6 8.3 A ~ 2908 ~,9 20b 1.4 128 9.2 a.4 C · 2910 ~ 5 185 1,4 123 8,8 ~, 3 A · 2912 ~, 0 2 01 1.4 120 8.5 8.2 i ~ 2914 ~),.l 207 1,4 120 8,5 6.2 A a 29!} 9,}7 {0:1 I ,.4 122 8,9 ~. 3 C ~ 292.4 5:,~ 1,4~ 1,4 12.3 9,0 a. 6 A ~{ 2926 o, ;5 i 91 1,4 I 17 9* ~' 9, o i { 2928 a,4 254 1,4 110 9,4 9.1 A · 2930 1~,,2 1~6,9 1.4 124 9..4 9..n C a 29.32 ~, 3 I82 1..4 122 9.3 ~.6 A · 2934 9,;5 178 1.4 120 9.3 8.4 a ~ 2936 6,8 20l 1,4 ~1'20 9,5 8, 4 A ~ 2940 5,,9 2~5 1~.4 ~1~1 9.4 8.5 A +,~ 2942 '5,:1 325 1,4 122 9..4 8,4 C · 2'94t 1.4 124 9,4 8.5 . 2.94b ~I 4, 3 15,I 1 .,3 121 9'.~ a. 7 C :a 29b0 '~.8 18:7 1.2 122 9.7 8~.8 C · 2956 i0,3 209 1.3' 122 9.8 8.] A , 2958 9,:5 1,91 I .2 126 9. I 8,..~ A ~ 2960 13,0 208 1,2 126 9..b ~,4 i ~ 2962 {12,~ 21~3 1.2 125 9.4 8.5 A: ,~ 2964 7,9 185 { ,2 118 ~.2 8,8 i * D~P'I H 2966 .14{.-4 i83 1.2 109 2908 1.2 115 2970 2974 1.2 115 2976 1.2 2978 2988 O, 2992 2994 2996 3002 3004 ~),4 189 1.0 118 3006 3008 3010 ~014 1.8 2:];1 i'.O 118 301~ 1.0 I17 ~020 },'5 2{0 1.0 120 ]024 1.0 117: 3026 ]02~ 30{0 3040 ~,,2 215 'I .0 i16 3042 A A A A A A A A A D 2 INDEX 3046 0.;7 129 1.0 112 ~04~ 0.~ ~t2 1.0 '104 ~090 5,~ 295 1.0 104 {052 1.0 108 ~094 1.0 147 i.O 109 ~096 {, 4 104 1.0 3058 ),:8 24~ 1.0 1.10 ~ObO l'.,l 2.4 1.0 112 ,,~0.74 }, 4 182 0.~ 1'10 ~07 8 2' .~7 180 O. 9 ~',0~2 3.~ I'81 0.8 ;{0~4 5, 0 191 0.8 ti2 3086 ~, 0 I77 O. 8 11'3 3088 0.8 ~090 8,~'5 358 0.8 104 3092 0.8 104 {094 2,~7 ~2'I 0.8 102 J096 ), I 149 0-8 I01 {O.gB 0.9 l~b9 0.8 ~10'2 ~I0'0 ~, ~ ~125 0.8 ~104 0.9 2:15 0.8 104 3112 ~.,4 20'1 0.8 103 3114 2.~5 1~3 0.8 103 .3lib ),~5 200 0.8 102 3118 1.9 2.9~ 0.~ 97 3120 a.~ 262 0.8 97 3122 5.2 252 0.8 97 3124 ~, 0 250 0.8 ,~12b ~, 0 214 312B 2.5 178 3132 },",0 49 3142 {, 0 38 J144 ~, 5 26 3154 ~, ] 101 3160 9.0 ~2, t 3i6~ 31 ~ 0 31 2 ~.4 217 3192 2.~ 224 319 4 i .~7 214 3196 1.9 221 3198 ], 6 2:10 J'202 ~.~7 195 3204 ),~2 137 .liOb * 3214 * ~2 , 3250 ~ ~ 7~ , 3:28,0 I91 0.8 86 8.9 206 O.B Sb 8.9 8.6 195 0.8 88 9.1 ~,6 237 0.8 89 9.2 235 0.8 89 9.2 ~'7 0.8 8b 9.1 bO 0.8 83 9.1 8.6 152 0.8 83 g.l 8.5 Ii 0,8 8~ q.1 8.5 't5 0.8 86 9.1 ~.6 194 0,8 88 9.0 124 0.8 87 8.8 .179 0.8 BO 8.9 15~ 0.8 85 9,1 ~.6 153 0.8 84 ~.9 52 0.7 83 8.9 819 0,7 83 8.9 ~,6 360 0.7 84 9.0 3:7 0.8 86 g.O i6t 0.8 84 8.~ 15:3 0,8 §3 8.8 86 O.a 8{ 8.g ~.6 0.8 82 9.0 8.6 2~t4 0.8 82 9.1 1.5'1 0.8 82 ~..0 8.6 179 0,8 83 9,0 8.6 180 0.8 83 9.0 243 0.~ 86 ~.9 ~.:6 ~99 0.8 89 8.8 0.6 lO0 0.8 87 8.9 82 0.8 83 g.l 8.6 22:3 0.8 80 9.! I9:3 o.~ 81 ~.1 185 '0.~ 85 a.o 8.6 :70 0.8 89 g.l 8,6 328e 4,2 89 0.8 3290 3.;T 200 O.R ~292 ),;7 208 0.8 329,4 3,,'b ~06 3296 '18,:5 69 0.8 3.300 ,15.6 9~ 0.8 {302 0.7 {~lb ?.g {52 0.7 ~3'I 8 1':1 .~4 3 44 0 3320 ~1),~5 ~45 ~324 10.9 358 0.9 3~26 ~lO, I ~57 0.:7 33~2 0.8 33~ ~40 e, 0 7'3 3342 '0,-0 71 0.8 ~{344 7 .'.8 l~g 0 ~34~ e,~2 13'~ 3348 4~.~ 157 ~356 ~, S 2'31 O. 3358 2:.~7 229 0..8 3.360 0.8 ~]G2 ~.:8 302 0.8 2' 4 * =A 3:374 3376 3384 3392 3~00 3404 3~0~ ~ 4't 0 ,3420 ..~ ~ 0 B5 0.8 79 130 0.8 78 ~41 0.8 7~ 198 0,8 78 260 0.,8 180 0,8 LIb 0,8 84 10.4 200 0.8 79 I0.0 215 0.8 78 9.8 0,8 79 0,8 77 93 0,8 77 9.5 ~4 0,8 49 0,8 ~0 lO.l ~5 0',8 62 0,8 '79 10.2 59 0.8 0.8 79 10,I 0,8 '79 10.'~ 0,8 0.8 8~ 10.2 134 0.8 80 96 0.7 79 10.~ I~14 0.7 79 131 0.7 7g I0.2 1~;5 0,~ 77 10.2 ,70 0.8 76 10.2 'I2'7 0'.,8 i09 0,8 75 ,!.2~ 0.8 77 9.9 1~t9 0,8 79 i08 0..~ 79 II5 0.~ 76 9.7 0,8 74 7-9 9 5,5 !l 0,0 5 ,~7 7-4 344 8 ~450 3452 {4~0 ]~80 , * ~4~6 3504 3514 * 3524 1,49 124 t07 11.4 ilO,.2 80 6., 2 95 t~,0 105 13 ,~ '13;6 11"~2 , i i9 ~,2 tt5 109 0,8 70 0.8 6b 9.9 0.8 68 0.7 71 10.0 0.6 72 10.1 0.6 72 t0.1 O.b 7t 10.1 0.6 70 10.o 0.6 67 9.9 O,b b5 1.0.0 O:.b b7 10..I 0.6 70 0.~ 69 10.2 0.6 69 1.0.2 0,6 69 t0.0 0.6 ~8 I0.0 O.S 67 10.0 0.6 65 0.5 6'4 9.9 0.4 65. 0,4 ~5 0.4 63 9.4 0.4 59 0.4 57 0.4 4b 0.4 32 9.0 0.4 28 0.4 27 9.2 0.4 26 0.'~ 16 9.2 0.2 il 0.~ 3:5~ 0.3 3]~ 0.2 3~1 9.~ 0.3 320 9.{ 0.4 322 0:,~ ]23 0.4 325 0.4 32b 9.~ 352e ~551 ~54.0 3542 3552 20,;4 ~572 9,~0 ~574 3576 10 3586 29.2 35'90 21 3592 ~594 3602 DEV., {)lAM D AZI. i -3 0.4 326 107 0.,4 329 87 O. 87 0,4 332 75 0,4 335 95 0.4 334 I02 0.4 333 1~3 0,4 329 150 0.4 324 lb4 I03 0.4 319 0.~ 314 20) o.4 199 208 0.4 3'12 19~ 0,4 .309 l&'O 161 0.4 19i 20'1 0.4 304 i80 0.4 114 155 151 125 175 169 180 182 I.SB 0.6 291 -i5~ 0 178 176 173 0.6 291 i7 4 0 0.~ 360b 17,.8 1:78 3610 13.3 168 0.6 ~i4 {{9.9 198 0.7 {bi6 ~19.0 199 0.~ {~ ~0 14.2 17 6 0 3624 ~14, ~ ih9 0.8 {630 13 .'~ 155 0 {6{4 ~1~, 4 157 0.8 3640 {I~,2 151 0.8 3'~42 ~{,4 151 0.8 ~644 ilO, 9 15~ 3~4~ ~30.;~ 151 ~648 ~I 0,, 3 439 O. ,{650 8,9 141 ~52 8,2 l~ 0.8 {~54 ;, 0 1,15 O. 8 3662 5, 3 101 o,9 3'~64 ~,3 I02 0.9 3666 ~,4 10.5 1,0 ~572 3,~ 103 ~674 3.9 !5:3 I~.0 3~76 2-~8 90 1.0 3678 ), 3 123 1.0 ~680 ~.~2 141 1.0 SUB2 9.0 i58 36~4 ~I 0,~8 =167 .1.0 # AZI. AZI. t-3 2-4 · =A 297 9.2 8.5 A 297 9.2 8.5 A 298 9.2 ~.5 A 297 9.2 8.5 C 295 9,{ 8,5 A 296 9.3 8,5 A 296 9.4 8.5 A 2'94 9.4 8.5 A 295 9.3 8.5 A 296 9.3 8.5 A 2.97 9.2 8.5 A 294 9.2 8.6 A 296 9.2 8,6 302 9.2 ~.6 C 305 9.1 ~,6 A 305' 9.1 8.6 A {02 9. t e.6 A 302 ~.0 8.e D 302 9,0 8.6 B 299 8-.~ 8.6 B 298 8-8 8.6 A 30'1 8.8 8.6 A 297 8.~ ~.e A 294 8..~ 8.~ A 297 8.9 8,6 A 296 8.8 ~.6 A 296 8.9 8.6 A 293 9..! 8.6 A 2.9~ 9.1 8.6 ~ 292 9.$ 8,5 A 292 9.3 a.5 C 2'9'3 9-,3 ~.5 C 296 9.~ 8.6 C 296 9.3 8,6 A 297. '9,3 ~.5 A 297 ~.3 8,:5 C # # 3~88 4.5 g~ 1,0 297 9.3 ~692 '10,,5 136 I .0 300 9.3 3694 ~,2 155 l.l 300 3700 1.2 301 9.2 ~704 30. I 92 1.2 297 9.~ )706 9. { 82 1.2 297 9.2 370~ 12,0 75 1.2 298 9.2 3710 '~39,i7 90 1.2 298 3712 3~.8 88 1.2 2g~ 9.2 37%~ ~,o 76 %.2 296 9.2 371-~ ~, 5 1~6 1,2 295 9.2 ~71~ },~ 161 1-2 295 9.2 3720 4.5 106 1.2 294 9.2 ~724 {39.g 255 1,2 ~b 9,1 37'26 1 ..2 286 9. I 3.72~ '~,~ 53 1:.2 288 9.1 ~TJO ~,4 76 1.2 290 37,32 0,~1 87 1,2 288 9.3 ~736 ,},:5 9~ 1.2 287 9 37:4 ~ ~ .,2 I-32 {. 2 288 9.3 3744 !,.9 ~9 1.2 284 9.4 3750 I .4 284 9.3 3752 ). 1 96 1.4 285 9.3 3754 3.9 8I 1.4 287 9.3 3760 1'.9 81 I .4 2.~ # OUib. -'''- # INDEX 8.5 A 8,5 C B.5 C 8.5 B 8.b D B.6 8,5 8.6 A 8.6 A 8.5 A 8.5 A ~,5 A 8,5 A B.6 B,6 A '8,6 A 8,5 A 8.5 a 8.5 C 376t, 1.4 289 ~tTb~{ 10.1 121 l.i ~88 3770 9, ] 112 1.4 287 ]772 9, 3 I13 1.4 ~66 37{4 '1,.'5 I i2 1.4 2B6 3778 B.9 1~17 1,.4 289 t780 9. I 118 t .4 287 1'78~ 9.~2 119 1,.~ ~85' {784 ,10.8 1~i~ 1.4 2B~! t790 10.1 ~21 1.6 283 3792 9:.8 1~19 1.6 28i t79,4 9.5 124 1.6 279 ~TVo lO. I 123 I .6 275 3798 )10,9 132 I .'~ 374 ~00 10.9 12,1 1.6 277 380~ 10,8 I18 1.6 279 t804 ~0,0 262 1.6 2.77 1810 3,o 170 1.6 2,71 .~812 ~1), ~ 1~1 1 I .6 2,75 3814 ~10, 4 Itl 1.6 2-75 ~8.1~ 1,.6 2i0 1.6 272 3~20 ~i I ,;7 9'~ 1.6 171 3822 1:2~.J 108 { .~ 272 3824 li..~ 124 1.6 274 3~2~ 1~,~2 i,l.~ 1.6 2,74 3~28 1,~, o 103 1.6 g~71 t830 15:.;~ 102 I .,6 2'71 3a~2 ~16.~7 lO~ 1'.6 2-~0 3834 ~10.~7 1~1.2 1.7 269 18tB ~lO,J 1.'14 1.8 267 3.840 ~.9 lO0 1 .~ 269 3842 {,5 -I0~ 1.8 270 3844 2,.8 4-4 1.8 27t {846 6.0 43 i.? 274 9.1 8.6 A ~50 1.7 270 ~.u ~852 1.8 269 ~.0 ]854 0.~7 226 1.8 269 8.9 8.6 A {85b ), 5 1~0 1.8 2~8 ~.9 ~.6 C ~858 ~.;8 1{5 1..8 2~7 9.0 8.6 A 3860 9.0 12~ l.B 267 9.0 8.b A .~ ~ ~4 9, ~ t~ i 5 1.8 26 { 8.9 8. ~ A ~6U i0.4 1.4{ 1.8 258 9.0 1810 {,5 1il 1.8 260 B.9 8.6 A 3872 ~,~4 IQ0 1.~ 263 8.9 8.6 A ~874 ~,2 92 1.8 26~ B,~ 8.6 A 3876 ),~8 9U I.B 263: 8.B 8.6 A {882 3,~2 ~0 1:.8 267 8.8 8.7 A 38~ 3.~? ~4 1.9 2~2 8.8 8,7 A 388B ~, ~ 77 2.0 264 8.8 8.7 A 3890 1{,,2 1 2.0 267: B?.~ ~. ? A 3~92 ~,1 8.~ 2.0 2~9 8.7 ~.7 A 3B94 4, 1 ~6 .2.0 269 8.7 ~.~ 3896 4.~5 78 ~.o 269 ~.7 e.7 A 3898 3.~7 7~ 2,0 270 8.7 8.7 A 3900 4, 3 ~'l 2,0 270 8.7 8,7 A 3902 4.9 74 2.0 269 8.7 B, 7 A ~904 ~.:8 6~ ].0 2~7 8.7 B.? A ~'~0-6 3.~2 58 2.0 267 8.~ ~.9 A .{90'8 2, 6 I07 2.0 269 ~.7 8.7 A 3910 2.8 lO8 2.0 268 8.7 ~,~7 k 39t4 ~,0 62 2.0 207 8.7 $.6 A 39i~ 5.3 79 .2,0 268 8.7 8.7 A 3920 3.4 78 2.0 270 8.~ 3922 O,~i 8,5 2.0 269 8.9 3924 ~..9 84 2.0 268 8.~' 8,6 A 3920 ~930 3934 ~9~b t938 3940 :J946 ]950 3960 ~,962 3964 {970 ~974 397 ~ 39~2 3990 3994 3~98 4002 4004 e ',tIP DiP . DEV. DEV. 'DIA{~ DI~ · B~ST t # Ag, l, * AZI o 1-,) 2'4 83 2.0 268 75 2.0 271 74 2.0 271 60 2.,0 208 43 2.0 266 31 2.0 269 32 2,0 58 2,0 270 36 2.0 ~2 2.0 2~7 64 2.0 ~3 2.0 264 46 2.0 264 32 2.1 263 22 2,{ 2.9 2.! 2,63 22 2.'1 264 29 2,.2 265 2.2 262 2.2 260 75 2.2 '71 2.2 259 70 2,2 2:58 75 2.2 257 7.5 2,2 254 ,70 2,2 eS 2.2 247 68 2.2 247 76 2.2 2:46 75 2.2 245 32 2.2 243 t24 2,2 243 ATL^NTIC H!lCHFIEbD COMVA ~B.~T 8A{~ ~23 PAGE 24,.F16E 2 4006 ~. I 114 2.2 243 4008 I ,7 10'7 2°2 244 4010 {~. ] 120 2,2 244 40i2 1,,0 114 2.2 243 4016 0,9 71 2.2 245 4022 1.0 iii 2,2 239 4024 i .2 ~ 2.2 ~028 O, 1 129 2,2 240 4030 0.~2 ~0 2.2 239 .4032 O, 3 ~ ~.2 238 40~6 O. ~ t02 2,2 236, 4042 0.8 ~1'1 2.2 234 40~.4 O, 5 252 2.2 23~ 40~ O, 3 284 2.2 405~ ~, 6 27'3 2.2 234 4060 1,6 279 2,2 4064 ~, ] 297 2.1 233 4070 ~,~4 18~ 2,2 235 4072 2.4 217 2,1 241 4074 ~. I 19:6 2,1 2.46 407~ 5.g 12V 2,,0 .2.51 4080 3, ~ 105 2,0 2.50 40~2 ], 4 91 2.1 252 4084 ], I I00 2,2 251 4086 ,) . i 110 40t~U 2, ! ~090 ]. ~ 97 409~ ~. 4 97 4104 ~, 2 92 {Il 8 I0',5 70 41 ~O '9,4 75 ~1 {~ ~. 0 20'4 414~ i.~ 222 4164 i, ,~2 24 i 2-4 2.'2 251 8.6 ~.6 2.2 25~ 8.6 8.6 A ,, 2.2 25,t 8.b 8.6 2.2 250 8.b 8,6 2.2 253 8.5 ~.6 A 2.2 255 8.6 8.~ 2.2 256 8.6 8.6 A 2-2 259 8.7 8.6 2,2 262 8.7 ~, 6 A 2.2 2~2 8.7 ~,6 2,2 258 8..7 '~.7 A 2.2 256 8.7 8.6- A 2.2 258 8.7 8.6 A 2.3 2'61 8.7 8.e A 2.4 259 8.b a,6 A 2.4 257 8.b 8.7 A 2.4 257 8.6 8.5 A 2.4 259 ~.6 ~.5 A 2.4 258 8.7 8,6 A 2.4 25~ 8.7 a.~ A 2,4 25 9 8:. b a, e A 2.4 255 8.7 ~,7 A 2.4 255 ~:.7 ~.7 2.4 257 8,7 8.~ a 2.4 258 8.6 8.7 2.4 257 8.6 8.=7 A 2'..4 260 ~-6 0.8 A 2,4 259 8.~ 9.8 2.-4 259 8.7 9.0 A 2.'4 260 S,7 9.0 A 2.4 26{ 8..7 (~.9 A 2.4 262 ~.u ~.g A 2.4 2bO 8.6 9.1 A 4166 0,9 19J 2°4 260 4170 4,b b2 2°4 260 8°? ~172 {,4 55 2,4 260 4174 2,B 73 2°4 261 8.? 4178 .),4 70 2.4 25B 41~6 {,B ~9 2.4 25! 4190 },3 85 2,4 250 4200 b,O 104 2°4 260 4201 6.8 1~2 2'..4 159 '4204 9,4 102 2,4 258 4208 14,9 97 2.,~4 26~ 8.b 42!2 ']1.'8 109 2'o4 257 4214 2.4 256 ~.~ 421o 21.0 ?~ 2.4 25] 4220 1~. ~ 11~ 2,~ 25~ 8.6 4222 ~1~, 6 94 2.4 259 4224 18.,~ 85 2.4 25b 8.6 4226 i19,5 7:9 2.4 256 4228 10.~1 94 2°:4 255 42~2 ~5,~7 2~2 2:,2 ~55 8.6 4236 2.2 245 4238 2.2 245 8.6 4240 0,1 205 2.] 246 4244 35.:0 65 ~,4 250 8.8 2°4 # =A * 4246 28,5 03 2.4 4248 31e. O 6e 2.4 4250 2e,,O 66 2.4 42~b 10.2 15 2.4 425B ~I0,:{ I0 4260 ~, 5 1 4264 2 426b }.:~ ]50 2.3 4274 ~, 6 3 ,~276 1~. 5 334 4288 2~.~7 30 ~296 ~.~ 242 2.4 4304 ~, ] 297 2..4 430~ ~.8 296 4310 ~. 4 30~ 2.4 43i2 ~, ~ 236 4314 ),5 18'3 4316 4.~ 133 a320 ~, 4 232 4322 ~,-4 2'02 2.5 4~24 ~, 3 i94 2.5 1 '3 2-4 * :cA ~ 252 245 246 242 240 238 237 239 242 242 243 2.43 243 24b 245 244 ~40 237 241 242 240 240 241 243 243 245 246 245 244 2'43 243 # m ~'O~MATIUN # 8O~EHOLE # QUAL. ~ DiP DIP 4~2~ 2, 0 202 2.5 245 41~0 ~,5 1~9 2.5 245 8.7 9.0 ~{3~ 1.6 180 2,~ 2~J 8.~ 9.0 ~jJO 40, 4 10~ 2.6 24i 8.8 9.0 4J$8 39,9 {Ol 2.6 2t7 8.8 9,0 4348 2.~ 239 ~.7 9.7 435~ 5,J 85 2.6 2~1 8.6 9.7 4'352 1.~7 't96 2.6 241 4556 2,~ 20,4 2.6 242 4,360 5,'3 250 2.6 244 8.4 9.8 4364 '~, ] 309 2.7 242 8.5 9.8 4~70 3,9 .2~30 2,.8 ~43 ,4~72 1,9 ~14 2.8 ~4~ 437B 4.5 1.9'9 2.8 244 43~4 1,~ 2'32 2.8 2~;4 &386 t,.8 262 2.8 244 8,.6 9.5 &390 t.0 2t9 2.B 245 8.5 9.4 4]92 3,9 195 2.~ {46 4,394 ,~,4 ,i98 2:.~, 245 g.6 9,.5 4396 2,~t 219 2.8 245 8.6 9.4 419~ },.0 203 2.8 2.4,4 8.7 9.4 4400 }, 2 i57 2.8 2'4t 8.7 9.5 4404 0,~4 129 2,~ 24,4 8.6 9.4 A C A A A A A A A A A A A - · AZI. * AZ1. 1-] 4405 1.6 155 4408 ~,b lbo ~.9 244 4410 {,5 163 2,0 244 4412 1,1 176 4414 ~.{ 17,7 ~416 ~.5 169 2.8 248 4420 ),2 204 4422 0,17 25.7 4424 0,8 215 ~,0 4425 4.2 154 3.0 245 ~434 2,0 22~ 3,0 249 4436 2-,.8 24I 3,0 2.53 · 4~0 ~.2 21:~ 4442 :~,0 180 3,0 255 ~4~b 2,}7 235 3~,0 2158 ~450 ~,.0 249 ~452 1,8 ~1.5 3,0 254 4458 2.! 2.18 44~0 2,{ 173 3.0 254 44~2 i.,~8 190 3,0 252 4464 ~,8 2.33 3.°0 254 44~6 6°2 209 3,0 2.57 44b8 e,O 212 3,0 257 4470 6.0 214 4'472 ~,O 22{ 3.0 259 4474 .~, 3 22t 4,~7~ 1.9,0 28,7 447'8 7, g 246 ~.0 256 4480 '~2 245 4482 ~,2 245 3.0 260 4484 9,0 243 ~.0 259 44e6 8,2 243 448~ u.9 4490 7.8 4494 10,.I 205 3.0 259 ~49~ 408 1~1~ ~..0 4498 4,'0 109 ~.0 263 4502 ~, 6 85 4510 9,.~1 106 4512 lO.g 112 3.1 2~4 451~ 0,4 284 3.2 26b 4520 {,0 152 3.2 26'3 4522 {, 5 45~0 ~,.3 2.50 ~.~ 2~4 ~5 {6 4,4 4~,40 ~,,,i 310 4544 O, 9 109 4548 0.~7 -!.3:7 3..4 2:7~ 4550 ~, ] 4554 .), { 19 q558 2',8 179 3.3 269 4560 4.4 19 ~ 3.2 2'70 4562 5,~2 175 ~564 ~,3 lb8 ~...) 2~2 · 456~ 6.8 16b 3.4 273 8.6 9.0 · 4568 ~.9 2(~5 3.4 272 8.7 9, 0 , 4570 ~.;7 223 3.4 275 . 4572 ~.8 16'3 3.4 277 8.7 9.~ · 4574 7.6 172 3.4 278 8.8 9.1 , 45~0 i. 3 42 3.4 277 ~.~ 9.0 · 45~2 ~,5 97 ~.4 277 ~.8 9.0 · i584 3.4 ~82 · 4586 ~.:I 64 ~,4 282 · 4588 2,.4' ~UO 3.4 281 8 · ,45~0 2.~ 357 3.-4 27~ 8.~ 9, 1 · 4592 2.8 I~7 3,.4 276 8.7 ~ 4594 2.2 ~8 ~.~ 280 '~ 459b {.0 72 3.4 284 ~ 4:598 2.9 [~,7 }.4 {,79 8..6 9~ 3 · 4,bOo 4.~ 1~8 3.4 276 B.5 9.4 · 4602 5,1 81 3.4 2?8 8.5 9.4 ~ 4604 1-,~7 61 .3.4 279 8:.5 9.2 · 4608 ~.:1 54 3.~ 277 8.5 9.4 · qfilO 2.3 63 3.2 276 8..5 9,6 . 4620 3.17 93 3~,2 278 8,.5 ~10.0 · 4622 6.0 55 3.2 277 ~-,5 · ~62~ ~, 3 12~ 3.2 ~88 8.5 !0.2 a 4~32 ),0 102 3.2 289 8.7 10.2 · 4634 3.2 288 8.7 10.'1 · i6{.e 3.2 285 8'.~ 10.1 · 4638 3.2 287 8.5 10.3 ~ 4640 3.2 281 8.4 10,2 -~ 4642 3.2 2'~0 · 4644 3.2 281 B.7 i'0.4 A C .C A A A A A C A A A A A A A A C ¢ A ¢ C C C ~ DKPTti · ',1~ iF DIP ~ DEV. D~V. · 4646 ).2 2~) ~.4 10.5 · 4648 ).2 286 R.4 10.4 ~ ~650 ).2 286 R.5 10.5 · 4~54 ~.2 285 8.4 I0.~ ~ 46~0 3.2 287 8.2 11,.0 ~ 466~ 3,2 294 8,2 11~,0 · 4666 3,2 292 8.4 10,9 · 4bbB 3.~ 289 8.} 10.7 ~ 4670 3.I 2:88 8.1 i0.4 ~ 4672 3.1 2B8 { 467& 3.2 290 7.8 10.5 ~ ~6'Ib ~,2 294 ~ ~680 3,2 293 7.9 10.7 ~ 4~92 9.,0 3)~ {.2 302 ~ 4694 5,6 295 3,2 )04 8,1 10.2 · 4696 3,i 299 8, l 10.1 a aY00 3.o 296 8.0 10.2 · ~'702 i,~,FI i73 3.0 297 8.1 10.2 ~ 4704 ,'~O.q I{]0 ).0 294 8.0 -lO, 1 ~ ~706 3.0 293 8.0 10.0 ~ 4708 3'.0 299 8.1 10.1 · 4110 20,;7 lB.7 3,.0 30,1 8.2 10.1 ,~ 4712 ~5,6 180 3.0 298 8.1 10.1 · 4714 2~, 3 1'~0 3.0 299 · 4'llb 2,~,O 180 3,O 301 7.9 I0,2 · 4718 3.0 300 7.9 10, 1 ~ 4720 9.2 263 3.0 100 7,9 1.0.2 · 4722 7.6 265 ,}~.O 298 , 4724 9.;~ 264 3.I 299 8,0 10.6 D D a D D D D D ~]I, AN'{IC ,R1Ci'~FIELD CC{I~PA W~ST 8AI'~ #23 PAGE ~,{-i;Ib~ 2 ,i 4746 4754 4766 4770 a77 2 4790 ~794 479~ 4800 t ~IP DXP , , DEV. OlA~ DIAH AZI, 1-{ 2-4 213 219 28I. 2~ 271 8~ 16'4 3.2. 300 3,2 301 8.0 IO,7 3,2 303 3.2 30t S,O IO,e ~,2 299 8,1 10.2 1,2 305 8,3 I0.1 3.2 30~ ~.4 IO.0 3.2 306 ~,4 9,'g 3,2 304 ~,4 IO,0 3,2 ~01 3,I ~00 8,~ IO.0 3,0 299 8, 5 10:, 2 3,0 ~03 3,1 ~07 $,O iO,4 3.2 308 8,i I 0 :3. :2 309 8,2 1 o. 4 3,2 3:1~0 3,:1 310 8,7 9.3 3. t 3-t 0 8, .~ 9, I 3,0 313 8.5 9.0 3;,0 t Jl4 ~.b ~, 0 3,0 3! 2 3,2 31~ 3,2 311 3.2 :31t 8.5 9,~t 3.2 ~i:O 8.5 9.4 :3,2 : 314 8,6 9,7 3,.3 316 3,:3 31 3 3~. 3 ~ 16 8,7 9, )~3 ~3t8 8,7 9, 8 .3,3 31 ~ 3,3 {10 8,5 9,7 3.3 i 15 ~:. 5 9,6 D A ~ 4808 ~,0 189 ~ 4812 {,J 180 * 4818 ~.0 179 ~ 4820 50.~7 'i29 3.2 a 4824 0o~ 273 3.2 * 4~]2 0*8 16'5 3,2 ~ ~842 ~l~,~ 145 * ~848 ~,~ 250 # 4850 4,'4 24~ 3..2 # 4892 ~,2 ~2e ~ ~a60 ~,4 217 3.4 ~ 4~74 3,9 ~i6 3°4 ~ 4884 5,2 202 AZlo 1-3 ~-4 * =A 31'7 316 Jib 319 324 326 32.~ 317 313 ~14 ~15 315 ~i6 3'1~ t17 314' 320 321 320 319 320 322 319 317 ~18 ~32] 333 335 3,tl ~30 ~29 4888 4890 4892 4~94 4896 4898 4902 4904 4900 4908 49i 0 4922 49~0 49~0 494~ 49.~8 4950 ~954 4956 4958 4960 · UUAL, -----------* DIAN · BEST 2-4 * b,! 21t) ].b 329 3.6 329 3.6 330 4,5 217 3.6 329 4.9 ~10 3.7 326 J{ O.~e 240 3.~ 327 6.9 233 3.7 324 4.,.8 2~7 .],.e ~319 5,:8 224 ~.6 317 ~I0, I 222 {..b 310 10.6 214 3.7 {11 1{,~2 231 3.8 31.2 12,2 2~'3 3.8 312 0,:0 52 3.8 313 ~,~ 315 3.9 316 4.0 316 4.0 3i9 4.0 324 5, 3 237 4.0 324 1~ .~1 ~ 195 4.0 32 2 4,5 196 4.0 320 7,2 153 4.1 323 5.,1 157 4.1 322 6.9 51 4.0 ~20 4.9 .42 4.0 321 5.6 140 4.0 326 4.0 3'27 4.0 325 ~0, ~ JSi 4.0 324 4..I 325 e,~l t'O:V 4.0 33o 9,4 112 4.0 331 · ~.0 94 4.0 326 b, 'b 85 4.0 327 .4, 2 101 4.0 329 3.'~ 1.05 4.0 329 3~4 7,6 4.0 328 AT6Ai~T{~C i~ICt{Pl~6f~ CUNI-'A {~.I~T ~A{~ e23 PA6E 36oi"ILi~ 2 49~6 },l 70 4.0 327 8.u 9.3 49uB ),5 272 4.0 3~0 8o7 9,4 4970 ~,3 210 4.0 333 8.6 9.5 4972 1~,9 130 4.0 326 ~.9 4974 ~,0 127 4.0 323 8.9 9.5 4976 4.0 324 8.8 9.4 4978 },6 201 4.0 323 8.8 9.4 4980 5.8 249 4,0 325 8.8 9.5 49B2 400 328 8.8 9,4 49~6 3.~7 343 4.0 324 ~.8 9o! 49a8 9..0 4i 4.0 323 8.; 4990 %,4 159 4.0 324 8.b ~992 ~.;2 17,1 4.0 325. 8.6 9.4 4994 4.0 ~24 8.6 5000 0.3 287 4-0 325 S-.6 9.5 5002 5,4 128 4.0 326 8.8 9.5 5004 ~.b ~8:4 4'.0 327 8,9 9.6 5006 9,b 8,9 4.0 327 8.8 500~ b,6 9.7 4'.0 325 8.7 5010 ,iO.iB 'I30 4.0 325 8.7 9.2 50i~ 9,3 114 4,0 327 8-.8 9.2 50!4 9.8 31,9 4'.0 326 8,a 5016 5,9 15:4 4.0 326 8.~ 9.0 5018 4.0 323 8.9 9.1 5020 4.0 3'18 9.0 9.1 5022 b.;7 94 4.0 3i6 8.9 9,0 5024 ,4'.17 ]2B 4.0 319 8.9 5026 3.8 4 4.0 3~1 8.9 ~02~ .5,0 ]50 4.0 320 8.9 8.8 5050 ~10,2 ~2,4 4.0 32'1 8.9 8,9 5032 4.0 325 8.9 9.0 5036 ~8.:8 289 4.0 2~4 8.9 ~.9 5038 gl.~2 300 4.0 325 9.0 5040 4°0 J25 9.! 904:2 4.1 325 9.2 ~.7 5044 4.2 326 9.4 ~- OUAL,. --# INDEX D D D D 504~ 5048 5050 4.2 505~ ]2, b 15~ 4.2 5054 20.6 342 4.2 5056 2~, 0 ]4'I 4.2 ~05u 4.2 50bO 5'5 31 3 4.2 5062 4.g ~04 4.2 50bb 24, 2 {40 4.4 50?0 ~, 6 292 5072 4~.2 38 4.4 5074 4 5080 ~ ,~ 260 5082 4.4 50'84 4.4 5090 e, 3 1~.7 5092 i3.0 195 4'.4 5100 20,0 15 9102 4.3 5108 2.b 41 4.4 5112 4.6 511~ 5.~i 32 4.6 5118 7..~ 28 4.6 5120 5122 4.4 5124 D~V. {.)lAM DIAM ~ BL~T ,m AZIo 1') 2'4 * =A * 522 9.5 323 321 9.0 3t9 'J2O ~23 324 324 328 9..5 330 9.5 328, 331 3,33 333 9.4 333 333 J~3 3]2 9.1. 333 ~.1 332 332 9.] 333 9.3 333 9.4 332 9.~ 9.3 331 9.4 )29 9,4 D D D D 512b 4.4 5128 3.,1 77 4.4 5130 ~, 3 104 4,5 5132 4.3 I00 4.6 5138 4.0 1 1.5 5140 3:.:B 1~1.7 4.6 5144 0..~ ib] 5148 2.8 79 5i54 {,~4 ,121 51S8 t'.{7 1 5160 2 ,{7 1'~5 5162 2, e 10~ 4.6 5164 2.~ 9B 5168 3,5 80 4.6 5170 2.9 ~ 5t,74 4, 3 269 4.6 5178 ~, ~ &7 4.6 5180 }, ~ 79 4.6 5184 ], ,4 59 4.5 5190 D~ ~ 124 4.6 ~1~4 4, ~ 87 4.6 51gO 3.,7 g8 4.:6 5200 ).~7 107 4 ~202 ~,6 112 4.6 5204 3.~6 105 AZI, 329 332 9.5 333 334 337 9.7 338 3~6 335 333 332 9.b 330 329 '33'0 3:30 9 329 329 3~3 330 327 329' 323' 9.0 )24 9.0 329 ~29 322 8.5 322 ~2B 8.4' 329 520b %.1 107 4.b 328 5210 3,4 102 4.5 325 5212 5~14 521b ~,4 101 4.4 321 5218 5220 4.3 92 4.6 3i8 5222 5226 3,0 63 4.4 316 522~ 5236 5244 ~, 2 81 4.~ 330 5.248 {.3 ?,9 4.6 3~'0 5252 ~',.e 98 4.~ 325 b254 5262 5270 5272 7~.9 :76 4,.a ]28 5274 ~,4 106 4.4 329 5276 a,2 10~ 4.4 332 5284 AZl. 1-3 2-4 52~a 4.5 ]26 8.5 9.5 ~92 5,6 97 4.6 3~7 8.~ 9.4 5310 2,2 107 4.4 ~24 8.~ 9.6 5112 },,5 94 4.4 323 8.4 9.6 5~14 4,,0 90 4.4 327 ~.5 5116 ~,0 94 4.4 328 8.5 9.8 5}I~ ~,5 2,5 4~.'4 328 8.6 9.8 55~0 3.;! 115 4.4 3~0 8.5 9.fi 5322 ),e 10~ ~.5 330 8.5 9.5 5324 2.~8 1!31 4.5 i3!$0 8.5 9.3 5~26 2.0 101 ~.5 ~28 8-5 9.2 5~2~ ~,'0 5~ 4.4 ~2b 8.~ 9.2 5~30 }.4 45 4,4 3~7 8,7 9,2 ~]32 ~.9 8! 4.4 '~27 §3~4 2.9 82 4.4 326 8,6 9.4 5336 ~,4 95 4.3 ]2~ ~.5 9.1 5~40 I.:9 9~ 4.4 ]26 8.6 9,0 5342 2.,I 8~ 4.3 324 8.6 9.2 534b 3.2 90 4.2 322 5~56 2°,8 bi 4..4 320 8.5 9, 5 5358 2,17 67 ¢. 3 .320 8.5 9.5 ~3~2 ~, 4 ba 4.2 319 5161 ;.5 7'0 4.,2 319 8,~ 9,~ --# DEPTH b366 53'/0 5.{72 5382 5388 5420 54~0 5444 8~ 4,2 322 ~..6 e2 4,2 3~3 R,b 52 4,2 322 8,6 lO.O 98 4,2 ~23 8.7 8~ 4,2 ~23 ~.6 9,7 65 4,2 322 8.5 9.6 78 4,2 324 8,6 9, 75 4,~ 325 R,5 92 4.2 ~28 8.6 9.6 ~72 4,2 329 ~,6 9.~ 45 4,2 ~29 8,~ 9,6 5'~ 4.2 329 8.6 8'9 4,2 329 8-,b 106 4,2 $28 8,8 9,8 101 4,2 {2B 8,6 9.7 l~lO 4,2 328 8,5 9, 46 4.2 32B. ~.5 9.7 74 &,2 33:3 a,7 9.5 7~ 4.2 3{5 8.7 9~4 9~ 4.2 3~4 ~.~ 9.3 I04 4.2 333 8,~. 99 4,.1' 333 ~.8 9.2 90 4,0 333 8,~ 9.2 87 4,0 ~14 ~.8 9~ 4,0 3'35 8.~ 9, 1 91 4,0 3.33 a.~ 9,2 8~ ~,0 333 8,9 89 4,0 332 ~,9 9.2 78 4,0 332 8,9 9-3 :76 4,0 333 8.9 9.3 '~3 4,0 334 8.8 9, 2 8i 4.0 ~3 8.7 9.2 90 4,0 3,]3 8,8 9, 2 # A A A A A A A C A A 544.6 ~,0 92 4.0 332 8°? 9.~ A b448 1.9 89 4.0 33i 8.8 9.3 A 5450 1o~? 81 4.0 3{0 ~.~ 9,3 A 5452 ~,2 79 4.0 {30 8.8 9.3 A 5456 2.9 77 4'.0 '3)1 B.8 9.2 A 5458 2.~? 87 4.0 ~32 8.8 9.2 A 54b0 2.3 102 4.0 3~3 8.8 9,3 a 5464 ~,6 89 4,,0 ~32 ~.8 9,3 A 5468 2.j, 95 4.0 {~1 g.g 9.3 a 54~§ {, { 73 3.8 331 8.. 8. 9.2 A 5480 2.~4 92 ~.~ ~3~ 8.? 9.2 A 5482 2,.18 9-~ 3.8 '336 ~.8 9.3 A 548,{ 2,,4 B~! ].8 333 ~.7 9.3 A 5490 l~.e 5,7 $.8 339 8.5 ~.7 A 5492 ~,3 ~4 3.8 338 8.b ~,9 A 549~ ~,5 72 ~,8 336 8.6 9.2 A 5502 ],:5 77 3.8 ~39 ~.4 9.3 A 5504 1.9 8'4 3,7 339 8.5 9.4 A 5506 ),:5 95 ].7 340 ~.5 9.3 A 5508 {, 0 84 3.8 3~9 8.7 9.4 A 55'10 1.~ 50 3.7 3'36 8.8 9-4 a 55i2 1:.:8 60 3~.7 337 8.8 9,5 A 5514 ~,2 8'7 3.6 339 8.8 9.6 A 5516 ),0 230 3.6 3'36 8°~ 9.~ A 5518 ~,3 gO 3.6 335 8.~ 9.5 A 5520 2,17 t04 3.7 335 8.9 9,5 C 5524 ~,4 1'0~ 3.6 3)6 9.0 9.7 A * · AZI. # AZI, !-3 5~30 0,~7 ~6 5532 I,.~7 '89 3.8 3~2 553b ~, 0 74 5540 2.9 54 5542 1'.~7 I01 55~4 ~, 3 ~ 5546 }, ~ 90 3.6 336 5550 ~10, 2 296 5552 ~,-1 93 3.b 337 555~ I~.3 97 55:~ 1'.f'7 4.3 3.~ .34~'0 556~ 1'.~7 I~3 4 55~8 1.~ 121 5570 ~, 0 118 5572 2.,2 114 3.b 339 b.57~ ),~! 14t 3.6 340 5578 0.{7 85 5582 ~, 4 86 3.6 340 5584 ~.3 149 3.6 338 55~8 ~, I 55 5592 1.6 70 5594 1.9 84 3.6 3~.8 5596 1 ..8 i6 1 3~,6 337 5598 1~,~7 I01 3.5 337 5600 3,2 i06 ~.4 338 5~02 1 .J 8? 3.4 ~3 38 9.6 9.6 9,8 9.8 9,9 9.8 9,4 9,,4 9.4 9.5 9.7 9.6 A ~ A i A ~ A · A a R · C · R ~ A ~ ~ DEPT~ · DI * 5606 5 b 18 ~20 * 5622 562 4 * 5636 * 5640 5646 * 5670 * 5672 , 5676 ~23 3.4 339 8.8 9.8 a 119 3.4 339 9.0 9.6 ~ 122 3.4 3~7 9.0 9,7 A 187 3,4 337 9°0 9.6 A 94 3.4 337 9.0 9,4 A 90 3.4 335 9.0 9.5 i 90 3.4 332 9.0 9.5 A 67 3.3 330 ~.,9 9..4 A 69 3.3 3S2 8.9 9,3 A 66 3,2 333 9.0 9°2 A $~ 3.2 333 9.0 9.2 A 339 3,3 333 9.O ~.2 A 114 ~.'3 3'35 9.! 9.~ C 3,19 3.2 314 9.1 9.3 C 67 3.2 335 9.-1 9,2 C 29 3.2 335 9.1 9.2 A 8,~ 3.3 334 9,0 9.2 a 83 ~.2 333 9.0 9,3 A 80 3°2 3)3 8.9 9.3 A ~4 3.2 3~6 a,.B 9,2 A 98 3.2 336 8.8 9..3 C 4:3 3.2 334 8.~ 9.4 A 6'3 3.2 334 8.9 9.4 A 77 t.2 3'32 8.8 9,2 i 84 3.2 330 8.9 9.2 A 58 3.2 329 8.v 9.2 A 6; 3.2 327 8.9 9°0 A 83 3~.2 326 8.8 8.9 A 100 3,.2 326 8.9 9.0 A 7:b 3.O 327 8.8 ~.1 A 72 3.0 325 8,8 9.1 A 7.~ 3,0 323 8.8 9.1 A 62 3.0 32t 8'..~ 9,0 A 75 3.0 3.18 8.~ 8.9 A {4 · · AZI. e AZI. 1-3 2-4 · =A · 5688 5690 9092 5698 5700 5702 5704 2,1 41 3,0 329 570b 2..1 31 3,0 327 5708 5712 5714 571b b720 5722 ~728 57{2 2,8 ~27 57~ 5736 57.40 $744 57{b 574~ 1,0 340 5750 5752 5754 5756 5758 57b0 5762 5764 ********************************************************************************* DEPTH 5768 5. I 340 2.4 ~07 8.~ ~.q 5770 5.9 ~50 2.4 309 8.9 9.0 A 5~7~ ~, G 9 2.4 306 9.0 9. t a 5778 3.0 2 2.4 306 9.0 9.1 A 5780 2.~7 338 2:.4 306 9.0 9,2 A 5782 ).2 349 2.4 308 ~.0 9.2 57a4 ~.:5 35~ 2.4 ~05, ~.0 9, 1 576b ~, 4 ~51 2.4 302 9.0 9. I A 576~ ). 3 60 ' 2.4 302 9.0 9, 1 5790 1',~7 6 2.4 30~ 9.0 9.1 a 5792 2.9 28 2.4 30t 9.1 9, 2 A 5796 4.0 ~ 2.4 ~0~ 8.9 9.] A 579~ ~,'4 242 2:.4 ~06 6.7 9.t 5800 ~,,,4 240 2.4 309 8.6 9,0 h 5~04 ~,9 2~ 2,4 311 8.~ 9.,1 A 5810 2,,9 56 2.4 3i5 9.2 9.2 A 5814 {, 3 335 2*4 3i4 ~.2 9.3 A 5~1~ 5.9 3.5'B 2,.-4 318 9.:1 9, 4 A 5824 ~l {:.:B 138 2,.4 ;319 9:.5 9,~ C 5626 ~13,5 i~9 2.:4 ]14 9.b 9,8 C 5'~2~ 4,,2 203 2.4 314~ 9.5 9.,7 A 5832 7'8 7 2,,4 32i 9.~ 9, 2 A 58J6 2.4 329 9.I 9,0 5838 2.4 326 9.0 ~.'8 5840 ~.0 iO.~ 2.4 .:{22 9. I 8.~ A 5842 3.:1 122 2.4 324 9.2 8.9 A 5~44 4.17 200 2.4 32.5 9.2 9,9 A AZI . 5846 6, 6 I14 2.4 5848 5.6 1~9 2.4 5862 {, 4 23~ 2.4 319 5b56 }, I 211 2.4 32{ 5658 0,5 297 2,4 325 5860 0-.~8 230 2,4 324 ~864 }.0 359 ~.4 322 58~6 O, 2 8,1 2.4 58~8 t,5 76 2,4 ~24 58:70 1~,5 70 2,'4 322 5880 l'.,e ~3 2.4 5886 ~.~B 218 2,4 5888 0.9 45 2.3 5890 0.~ ~.32 2.2 329 589a o,6 90 2,2 332 589~ O, 6 79 2'.2 336 5902 2,2 3,32 590~ 2.2 3,36 5906 2,2 590B 3.3 207 2.2 338 5~10 3,~1 211 2,2 340 5922 0,9 3~,,7 2.2 334 592-~ e. 0 2 33 2.2 335 2-4 , 592~ 4. I 307 2.~ 33B 9.~ 11,.0 5930 ,).:5 340 2.2 341 9.8 I 1,.2 5932 2.2 33B 9.b 11,,0 5934 ~,4 243 2.2 33b 9.5 11,.2 593~ 4.0 292 2.2 337 9.i 11.4 5938 O, 5 22 2.2 ~8 9.5 11,. I 5940 9.0 52 2.2 t40 9.5 10.8 59-42 5,3 266 2.2 340 9.b II~.3 5944 7,,5 252 2.2 33b 9.7 ll,.q 5948 2.2 {36 9.8 11.~ 5950 2.2 3)9 9.~ 11~.4 5952 2.9 6'9 2.2 341 5954 2.2 342 10.2 11'.3 b95b 2.1 346 ll ,) I'1~. 1 5958 2.i 341 1 l.'G t0,5 5962 2.2 337 :9.6 12,O 59~b 2.2 ,3.37 ~.0 59~8 7,.0 44 2.2 329 9-I lO.O 5970 3,:0 62 2.2 325 5972 2.1 ]26 59.1~ 2.1 323 9.1 8.9 59,'7~ {,~5 be 2.1 317 5980' L.';7 203 2.2 320 g.O ~.7 5982 ~, I t49 2.2 321 9.2 9.1 59~4 ),~7 73 2.2 )20 ~.1 9. i 5986 .),~ 21 2.1 318 9.2 8.9 5988 {,6 35~ 2.0 317 9.3 8.9 5990 ~. ~ 95 2.0 .320 5992 ],2 I2 2.0 32u 9.0 8.6 599~ ), 6 12 2.0 ~27 5996 8 .{~ 3.43 2. l 324 8.4 8.3 6000 5,4 300 2.2 335 8.5 8,5 6002 2.2 343 6004 5,2 I1 2. I 342 DEPTH · DIP UIP ~ DEV, ~EV, DIA~ D1A~ bO0~ l..b 30 ~.1 33~ ~.4 a.4 A 6008 2,0 Il ~,~ 324 8.4 8,4 A 6010 1,,2 52 2.1 .32~ ~,5 8.,5 i 6012 ~,I 111 2.0 330 8.4 8,4 A 6024 I~.U 14 2.0 321 a.5 8,7 ~02b 2,1 I0 2.0 322 8.~ 8~,? A o02U ~.0 lO 2.0 326 ~.,? 8,7 6032 2.0 ~3~0 2.0 336 8,6 8,6 A b038 ~, 0 323 2.0 3.33 ~.6 8,6 ~040 ). 3 30 2.1 3.30 8., 6 a, e A b042 1.,3 ~55 2:,1 329 a.7 8,6 605~ 1'9 330 2,0 33;7 8.7 8,? A 60~0 0,~5 45 2,2 338 8.7 8,~ A 60~2 0,1 3~0 2.1 ~1 8.8 8.,7 uUbb 0,~1 1.4~ 2,0 344 ~.~ ~.7 60~8 0,.3 231 2.0 34~ 8.'7 ~,.7 A 60~2 O, 2 352 2,'0 3~3 8:,~ ~,.7 6074 ~,2 214 2,0 34I 8.8 ~,7 A 6076 2.~7 236 2.0 339 8.8 ~, 7 A UO~2 5,4 229 2.0 3{3 B.5 8,5 A b084 0,;7 262 2:,0 340 8.3 8.4 A ~'IL, RNTiC [tICt*tI"I~L, LI C£t.MPA Nlt.~T SAK {23 bOSh ~,2 174 2.0 349 60~8 %.6 i 7 2.0 349 6090 3.8 360 2:.0 347 b09~ 1.1 I~7 2.0 347 6098 ~, 5 77 1.9 341 b104 2..~ 2e 1.8 322 610b ~, 5 9 1.8 320 6108 3,4 iS0 1.8 313 ~l 10 1.9 ~2 1..9 303 6114 ~, I 2 2.0 320 6120 5.,I 194 2.0 326 6124 0,;5 i,75 2.0 333 bl 2b 2.~1 I42 2* 0 335 6128 2. I 146 2,0 3)9 61~0 ~,0 82' 2,0 141 bill ),5 30 2.0 340 6140 1.3 {82 1.9 338 6142 {, 3 271 1.8 343 6144 2,'0 288 t..8 3.48 ~ 14 b 0., 3 t 1'9 1.8 35 0 b158 0.9 ~I-1 I~.8 ~35~ blbO 0.~ ~ I .8 355 blb2 {,,2 47 I~.8 350 6164 2..0 I03 I.g 343 A?LAI, ITI;C ~I{£H[IELD ~COM,la;~ EST ~K 12,:1 P~GF 51 FiLL 2 DEPTH P * DEV 616H 1.8 82 1.8 b174 ~1~,1 159 bl?b ~,0 67 i.8 e178 I,4 41 ~180 l.l? 350 1.8 61B2 0.i8 38 ~184 {,4 J6 1..8 blg~ 3,,1 917 big~ 0.8 352 6I'98 0.~ :300 b200 ),1 i4'0 b202 ~,:5 3'01 1-8 b~04 l,b I 1!o8 b212 2.0 35 ~214 ~,4 94 b21,~ 1o8 12.9 b218 0.'§ 147 62'20 O.g 311 i".8 0222 0oi7 t08 1.8 622~ 0:.~ 8.9 ~22~ 0.:8 95 1.8 62~.4 9,5 330 6238 4,8 ]15 b240 },~ ~32 1.7 b242 b,5 131 1.7 624& 2~,0 117 1.7 -------------,---------------- I~DEX · . DEV, DIA~ D~AM · BE:ST * AZlo 1'3 2-4 * =A 340 342 342 338 336 336 334 335 338 336 ]3,4 336 340 346 ~49 35,1 ]52 3.51 351 ~352 353 3-53 353 35~ 358 ~]5!5 355 355 355 354 ]54 353 35.2 358 2 2 2 * # 88 I,.6 357 67 1.6 348 7~ 1.6 3]6 ~.8 ~.8 ~ I.~ 334 ~.9 ~5 1.6 3~3 9.0 8.9 82 t.b )3b 9.0 ~1, I .6 338 1~7 1.6 347 8.9 ~.9 1'48 1.6 350 8.9 ~.9 1~9 i.b 350 !2B 1.6 350 124 1.6 350 9,0 134 I .6 3:5~ 125 i,5 350 :123 1.5 350 119 1.5 353 8.7 ~.7 i05 1.4 347 8.8 8.8 C -! A a A J, A ~ C ~a 6326 ~356 ~358 &3&O 639'~ 1~.9 1i0 1~.4 112 10,2 121 I0.] 1'18 10.5 115 ~,,2 115 10.9 110 9.0 95 10,2 112 123 I'27 106 7 7 108 iOl o AZI. 1.4 341 1.4 347 1.4 350 1.4 344 1,4 1.4 {44 1o4 )40 1,4 334 1.4 331 t.,4 1.4 3:15 1,6 312 311 312 ,1.~ 315 1.7 316 1.8 315 1.~ 3.18 1o9 2.0 329 '2.0 327 2.0 320 2.0 312 ATLANTIC RI£HFI~bD C.G~.'.t. A WEiST SAIK hi :} PAGE i-I;'IL~ i] 5854 ~, 0 199 5856 ~,,4 ~04 2.4 5858 3',0 201 2.4 5860 4, 5 246 2.4 5862 ~.:~ 231 2*4 5864 ~, 2 ~.72 2.5 586~ 2.6 586~ {.;2 181 2,6 5870 ~, I 127 2.5 5872 2.~ ~5 56 74 ~, I ~ :41 2'..4 58:78 ~..2 147 2, ~eSO ~, ~ 227 5890- 1:,:'9 20.3 2.4 5B92 O, 6 49 5894 0,:4 38 5~98 l.l 12i 2.4 5900 1 .~7 '18 5902 590~ ~, 4 ~25 2,4 ~OB 2,4 5908 2.3 5910 O,.O 1~72 2.3 5912 ).:0 1~0 2. 5916 {,:3 182 2.4 591~ ),5 193 2.~ ~'920 l{. ~ '~29 2,4 5922 3.~ 2B:3 5924 '0.9 24:1 2.'4 5926 {,,~ 195 2,4 EOf' EH,~LL , OUAho · . ,,. *.-,,,...,.-,-,-, "'--'-,,."' ' '"' ""' '' "" ' ~ INDEX aZl. 1-3 2'4 , 314 9..0 318 9,0 9.1 318 9.2 9.2 31'/ 9.5 9,2 319 9.4 9.1 323 9.) 9.1 .327 9.2 9,1 3'28 9.2 9.1 3;~1 9.'4 9,3 ~31 9.4 9.3 329 9.5 9.~ 3~9 9.6 9.2 330 9.6 9.:1 330 9,5 9,0 329 9.4 8.9 328 9.2 0.7 3~ 9.5 9.2 3~3 9,6 ~:1 9,7 32'7 9,7 323 9,.3 9,1 325 ~.9 ~,.7 328 8.9 329 9,0 ~.9 3~2 9.1 9,1 336 g.7 9. 3,~6 10, 1 9.b 3'34 I O, 1 9.6 332 10.0 9.5 331 !0.3 10.~ ~'33 10.0 33'3 10-2 9. 3'~2 10-. ] 9. 334 I0. I 9. 330 t 0., 3 9.8 ~29 10.2 9."I 333:, 9.9 ){~ 10.2 A A (.; A A A C C A A A A A A A r~ C,' A A A 5928 b,~ 27b 2.4 3]2 10.7 9.6 5930 {,9 274 2.4 334 I0.9 9.7 5932 9,,1 ~2~ 2.4 ~36 tl.2 9.8 5934 8.i7 ~16 2.4 335 11.1 59~b 2.4 ]34 11.0 9.6 5958 ~.~ 267 2.4 ]]5 11.2 9,6 59{0 {,6 241 2.4 3{5 1{.2 9.5 5942 ~,1 3~ 2.4 334 10.8 9.5 5944 5,4 16b 2.,4 J{6 I0.9 594e ~,~5 i, 64 2.4 337 11.4 10.0 5950 2.3 339 11,3 9.9 59'54 2.2 335 ll.O 5958 5.~ 242 2,3 341 11.2 10,,~ 59~0 2.2 342 10.7 5962 ,},,~2 3:39 2.3 3'38 10.6 1~.1 59~0 2.4 339 ~.9 g.1 5972 3, ,1 65 2.!4 333 10.0 9.3 5974 2.4 338 g.8 5976 2.3 339 9.0 59~8 ~.,4 94 2.2 3~5 8.8 ~.9 5980 ~,:0 ~ 2,3 333 $~.6 5982 0.i8 16~ 2.3 '337 B,7 5984 2.2 162 2.3 ~40 9.2 9.2 59~6 3,~ 1~8 2.2 ~37 9:.3 59~8 ~,~3 4,7 2.~ 3,32 9.1 5'990 ~,'2 3! 2.2 3,30 9.0 5992 3.9 ~15 2,1 ~335 8.8 5994 5,] 65 2.2 340 8.7 8.9 5996 3,6 -77 2.2 344 8-6 ~,7 5998 9,9 182 2.2 345 8.~ 6000 ).2 52 2.2 347 8'.4 6002 0.~8 349 2.2 356 8-5 6004 2.2 7 8.4 ~.4 A A A .A A A A C A A bOO8 0,5 314 2.2 .{49 bOlO 1.8 42 2.2 t41 UO12 2,0 ~4 2.2 34~ 6014 ~.S 83 2.2 34b 8.5 O01& ~, ~ 76 2.2 344 o018 ], 3 .6~ 2.2 ~42 b022 I ,;7 40 2,,2 352 602~ ~, I 17 2.2 352 602b 2.1 5'0 2,1 351 8.8 6028 ~,:4 39 2.0 350 ~030 I .9 30 2'.0 346 bO]2 ~, I 104 2.1 319 603b {.5 ~9 2.1 33~ 8.7 ~0,3a 2,1 81. 2 · 1 337 6040 0,~ ~:52 2~.0 33~ 6050 2.0 -49 2.2 324 ~052 ~, 6 20 2.2 ~22 8.8 6002 }, 4 9 2.2 329 6068 0,.6 6~ 2.2 33t ~0.7~ 0 ,~7 2e :2 2.2 335 8 ~0'7~ 0.~7 3~lb 2..2 3~9 8.9 607& O,e 2'78 2.2 339 6080 0.9 29,4 2.2 338 6084 3,9 2~1 9 2.2 33~ 60~6 },,2 28,7 2-2 340 # D~PTH # :~ IP ~P · DEV. DEV. 6088 0.9 29~ 2.1 344 6090 3.5 21 2.! 343 6092 3oi7 2 2.0 346 6094 i,, 3 347 2.0 347 60~6 ].0 134 2.0 350 ~098 0.9 138 2.0 353 o100 ~,0 13.3 2,0 351 6104 1.~7 72 ~.0 347 610~ 1.9 bi 2,.0 ~346 ,blOB 2..~ 42 2.0 344 61!0 3,,1 31 2.0 343 61 ~2 ~, 4 100 2.0 346 ~ii4 1.~6 104 2.0 346 6116 ),4 3'7 1,9 ]44 6124 I .8 bO 6126 .{,~2 35 1.8 352 6128 t, ~ 153 1..9 ]52 ~ 130 ~, 6 150 i 6134 ), ~ 57 1.9 35.4 ~148 1,.0 300 2.0 330 6150 ~,;i ~!,~ 2.0 341 ~152 '),~1 289 2.0 340 ~154 1..~ ~:1~ 2'.0 341 ~156 1,, 3 328 2.0 342 6i58 ~.I ~2:1 2.0 339 6i~0 0.~ 259 2.0 ~40 6162 1,,:9 i69 2.0 342 616~ ~,~7 120 2.0 345 ~166 O, ~ 46 '2.0 346 b174 2.~ 19 2.0 617~ 3,1 357 2,0 6178 3,,2 i2.9 2.0 bl~O 2,~ 125 2.0 ~182 0'8 1713 2.0 bi84 0.~ 211 2.0 ~1~ {,6 2.7 2.0 blBH ~.2 9~ 2,0 b190 1,6 ~0 2,0 ~194 ~,0 109 1.9 619~ 2,,:! 94 2°0 6202 3,2 b:l 6204 2.~ 42 6206 0.8 341 6208 0.6 322 2.0 6210 ~.~2 84 2.0 b2i, 2 ~,,1 54 2.0 6214 2.~,9 ~,7 2.0 6216 ~,5 24 6218 {,2 108 ~220 0 *6 89 1 6222 0,:4 222 62 ;2,4 O, 6 g ~ 2,0 b226 0.2 98 2.0 ~228 ~,.~ 110 2.0 ~230 0.,3 156 2.0 ~234 2.0 62.36 9,i7 132 2.0 62]8 2.0 ~240 9.;2 2.0 6242 5.4 2.0 ~244 ~,2 2.0 6246 4,3 .{48 35t 351 35O 348 349 3,54 354 35O 356 354 & 352 '337 337 343 354 357 }57 35 9 355 ~' 8.7 8.8 ~.7 8.8 8.7 8.9 8.9 9.0 8.9 8.9 8.9 8.9 9.0 9.0 9.0 9.0 8..9 b248 3.,9 80 1 6250 ,3. I ~ 4 6252 ~2~0 ~, S 104 6272 ~, 4 92 1.6 b274 ~:.8 75 6276 1.6 b278 9 ,~,7 bl 1, 6286 13 ,,8 8.1 1 ~29o 8,J I07 6292 9.g 120 b300 lO, ] 101 1.~ ~ ~ 04 8, :4 94 6ilo 9,9 lob ~312 9, ~ 10.4 1.4 6320 I~,2 10~ 1.4 ----------------------------, AZi. I'3 2'4 ************************************** 357 357 35b 359 359 355 346 340 338 338 339 342 345 3'4'7 350 35 0 352 354 355 354 352 347 354 354 349 331 63{0 10.3 9b 1.4 332 ~334 .1{,6 B5 1.4 331 ~344 1.4 337 b346 1.5 ~34~ 9, 4 87 1.6 6S50 ~, 5 93 1.6 3~5 6354 1.6 6356 1.6 342 63~0 ll.O 99 1.6 341 ~:)~4 1.6 334 6366 1,2.9 9.7 1'..6 U 3 ~ 8 1. b 6370 1~, 3 114 1.6 b{72 ,] 5:.~8 i~0'7 1,.7 328 637~ 1,8 322 ~378 10,0 90 1.7 618U l .8 3:!6 ~90 2.0 3i0 ~t92 2,0 302 63.94 I .9 295 b196 I ,a 293 ~400 1.8 298 ~ ~Z.~ · ~:~ 1-3 2-4 * * TOP * 21Ob,O ~):.0 342. 1,2 6~, 1.1,~ I~1.8 b · O~IENTEg ECCENTRICITY AZIMbTM LISTING &RCO ALASK~ INCo ALASKA THE gTA~3~ OEVTATION OF THESE POI~TS IS 3~.717 TME ~EAN El~ THE DI~ECTIt3N gF I~AJ,3~ AXIS r,~ THE POINTS ,~- A TgTAL OF g29 PQZNT$ WITH ECCENTRICITY G~E~Tr-P~ I~'~TE~V~L LENGTH UgED IN THE C~PUTg. T~O~I ~S 44~.00 THE L~ST D~TA POINT U,$[D AT 2602'00 FEET. !HE FirST DtTA POI~iI USE¢ W~S AT 3045.00 FEET. RECEIVED. APR - ~ i984 Alaska 0il & Gas Cons. Commission Anchorage 114~.00 0,30 311Z.Oa ~.30 31iI.50 0.30 31&t.00 ~.3~ Iii 3!3~.00 ~.30 17~ 313~,0Q 0,20 173 3136.30 0.20 173 313~.5~ ~.20 1~3 31~5.OO 0.20 17~ 3i)3.~~' ~.20 ~1 ~133.00 0.20 17~ 313Z.~0 0.t0 169 313~,00 ~,I0 t6~ 1130.~0 0.I0 166 31~D.00 0.10 )12~,50 0,10 16~ 312~.Q0 0. I0 165 ~lZ~SO 0,10 165 3127.00 0.10 16) 3126.~0 O.iO 16~ ~lZ~,50 O.aO 16'~ 312k.50 0.10 165 3123.00 C.lO 165 ~122.0~ ~.I0 ...- 165 V~LUE VALU~ ~ ~ SC~i~It4ATEB V ~L~JE VALUE ~ALUE v ~LU.E ~!SC. RI~I~AT~ VALUa Y~LUE DISCrimINaTED V!L.UE DISC'~IPI~T~D Y'~LU~ V'~LUE O'ISCRI~NRT~O V~LU~ VALUE DISC~itlATE~' VALU~ VILU~ O~SCRI~t~T~O VALU~ DISCRImINaTED -VRLUE VALUE DI,$C RI~,INATED VALUE DISC~I~ItI~TE~ V~LUE DISC~IFINAT~D V~LU~ OlSCRI~t~RT~O .. VALUE VALU~ DISCRIMINATED ~!~0.00 ~119o00 3115.00 ~11~.00 ~109. ~0 310g. O0 3~0~.00 3~07.00 3106.~0 3106.00 3105.00 310~.5Q 3103.00 31G~.OO 310~.sG ~100.~0 ~0~.00 209~.50- 3096.50 309~.00 3095.00 0.20 165 VALUE 0.20 165 V~LUE OZSCP.!P. INATDO 0.20 165 VALUE O. 20 165 VALUE O. ZO 165 VRLU~ 0.20 165 V).LUE O.ZO 163 V~LUE DISC. RI~ZN~TED O. ZO I63 V~LU~ 0.20 162 V~LU~ OISC.RI~N~TED 0.20 161 VtLU~ O.2D 160 VALUE ~.20 160 VALUE DISCRit~[NATEO g.lO 160 V~LU~ 0.10 160 V~LUE DZSCRI~Z~T~ 0.10 160 V~LUE DZSCRIHI~I.a TE.D . . 0. I0 1&0 VALUE D: SC~I'~IN~TEO 0.1'0 1~0 V~LUE DI SCR~MINATEO 0.10 159 VILUE ~I SC~I~INiTi~ 0.I0 159 VALUE ~ISC~2~z~ATEo 0.10 15~ VALUE DISCrimINaTED 0.10 1~9 VALUE DZSC~ [NATE~ 0.I0 15~ VALUE DISC~I~!INAT~D O.IO 15~ VALUE DZSC~[P'ZNaTED 0.10 1~7 VaLU~ OISCRI~I~T[O 0.20 1~ V~LU~ OTSC~I~Z~tT~O 0.10 isa VALUE DISCRI~tt~ATEO 0.10 1S5 VALOE DISCRI~t:flATEO 3093.50 0.2 ~091.50 3O~O.CO 0.~ 3089.50 0.40 308~.00 0.30 30~,C0. 0.30 3086-50 0.30 .3eSS.~O 0.~0 ~OSS.O0 30~.00 3083.00 30~l. SO 307~.00 0.20 3078.50 0.20 3075.00 0.20 30~7.50 3077.00 0.1 3076,00 3075.50 307~. 50 0.2 307~.50 O. 2 3071.50 3070.~0 0.2 3070.00' 306~.50 0.2 306g.00 35S8.50 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,,. 0 0 0 150 1 '~ ~ VALUE V A YALtJ~ VALUE VALUE VALU? VALUE V~LUE V~LUE VALU~ V~LU8 V~L{J~ VALU~ V~LU~ 'VALU~ VALU~ VALU~ VaLU~ V~LUE v V mL VmLU~ VALUE VALUE VALU~ YALU~ VALUE V!LU~ VALUE VALU~ VALV~ VALUE VALUE V~LUE V AL U~ VALUE VALUE VALU~ VALU~ V ~LU ~ VALUE VALUE VaLU8 VALUE V~LUff VRLU~ VALUE 3068.00 0.30 . .,,.. 142 VALUE DI SC~.!t~INATEO ~ :~066oS0 3065,,O0 0.20 3065.50 ~065.00 0.20 ~06~.~ ~.10 306~.~0 0.10 30~3.~0 O.tO 30~3.~0 0.10 306Z.~O ~061.50 ~061.00 '30fi~.50 0.10 30~0.00 0.10 30~9.~0 ~.10 ~058.50 ~.t0 3057.00 .30~.50 305~.00 0.30 305~.~g 0.30 3055.00 0.30 3OS&.50 3053,50 0.30 3053.00 0.30 305~.00 0.20 30~I.50 0.2~ 30~t. O0 O.lO 305~.50 0.10 30~0.00 0.10 30~9.50 0.10 3049.00 0.10 30&~.50 0.00 30~T.50 0.I0 30~T.O0 304~.50 0.30 ~045.50 0.50 30~5.00 C.6O ~04~.50 0.70 30~3.50 0.90 30~3.00 30~Z.50 O.gO ~O~2.OO I.~0 3041.50 1.00 301~.00 1.00 CALIP~P OIFCERENC~ MAJOR AXIS DIRECTION 1,r, 3 143 I¢3 145 I¢6 1~7 153 157 1'53 1~1 14,1 VALUE VALUE VALUE VALUE VALUE VALLIE VALUE V~LLtE VALUE YALUE VALUE VALUE VALUE VALUE YALUE V~LUE V~LU~ V~LU~ VALUF V~LUE VALUE VALUE V~LU~ V~LU~ V~LU~ V~LUE VALUE VALUE V~LUE VRLU*E VALU~ VALU~ V~,LUE VALU~ VALUE' VALU~ VALUE VALUE 30~7.00 3~36.50 0.80 30~6.~C, 303S00~ 0.70 303~.90 303Z.00 O.TO ~0~I.50 O.TO 3031.00 0.~0 3030.00 '302g.50 302~.00 ~02~.'S0 O.aO ~g~.O~ 0.80 302~.~0 0.90 302~.00 3023.50 30~3.00 0.90 ~022.50 ~022.00 3021.~0 ~02i.00 302~.'~0 ~0.00 0.90 30%~.~0 0.90 30I~.Oe 301~ .00 3017.00 301'S.~0 3015.00 0.90 301~.50 O.gO 301~.00 137 137 !37 13~ 13,~ 137 137 137 136 13~ 136 137 137 137 137 1~1 ,mb . P~'E 6 3010.50 O. gO 3010.00 o.go 3009.~0 0.90 147 30~g. O0 O.BO 147 ~00~.5~ 0.~0 300B.O0 0.80 ~007.50 ~.60 147 300~. OO 0.70 1~ 30~6.00. 0.~.0 144 300~.00 0..~0 147 300~.~0 0.~0 3003.00 0.60 3002.~0 O.~O 3001.50 0.6.0 148 ~OOt.OO 0.60 ~000.50 ~.~0 3~00.00 0.60 2~9~.50 0.60 299T.50 0.60 2~97.00 0.70 2~9 ~. O0 0.7~ 147 299~.50 0.70 {47 ZggS.0C 0.70 Z99~.50 ~.TO 1~7 2993.00 C.6O 2991.50 0.40 ZggO. 50 0.40 148 2990.00 0.40 2g~g.~O 0.40 . ~4~ 29~.50 0.~0 29~e.00 0.60 2~7.50 ~.~0 145 29~7.00 O.~O VALUE OISC{~I}~I~ATED VALUE OISCRI}~ IIaAT£O VALUE ':ISC~I~IN~T~D' VALUE DISCEI~ATEO. 0.60 0.50 0.40 0.60 0.30 0.30 0.30 O.SO O. SO O.SO 0.60 O.SO 0.~0 0.00 O.IO O.OO O.OD 0.00 0.10 C.~O O. tO 1.00 1.1~ ~.20 1.20 0 !960.00 P&GE 7 aXIS ~!REcrlo~d , I~6 1¢9 15! 151 151 YAL'UE V~LUE ,. V~LU~ VALUE V~LUE ~ I SCRIMI~AT,EO' VALUE OISC~I~IH~TED VALUE ~ISC~I~IN~TE~ VALUE 5ISC~I~INATE~ 152 ., l~l 1~I 157 !&Il' ~**~0 1.30 1~ ~95).~0 1.2O I~7 ~9~.~0 1.20 1~ ~95Z.00 1,20 148 Z)~8. ~0 0.~0 1SO ' Zg~i.~C 0.~0 29~7.0~ 0.~0 1~9 .. ~g45.~0 0.99 Z94~.SO. t. O0 1~6 . Z9~3.00 0.90 Z~Z. O0 0.90 294I.S0 0,90 2941.00 0.90 156 2~40.B0 1.00 i~6 2~39. ~0 1,00 l~ l 2938.50 I.lO 2')~ 7. ~O 1.1 0 1~7 2~3T.00 l,lO 2936.50 1.10 147 Zi3&.OO 1.10 147 Z{35.~0 - '1.00 2935.0~ 1.00 293¢.00. ~.90 2933.50 0.80 2.933.C0 0.80 148 292~.~0 0.30 [928.50 0.3~ 147 2~27.50 C.~O 2927.0~ 0.~0 2926.50 0.30 2}2¢.00 0,40 147 2}23,~0 8.40 147 2~Z2.00 0.30 2921.50 C.40 147 Z92X.O0 ~-50 147 Z920.00 0.70 147 2919.50 0.70 14'3 291~.50 O.&O 149 291~.00 0.t0 149 ~917.5~ O.SO 150 2917.00 0.40 291~.~0 0.~0 151 2916,00 0,30 15t Zgl~.SO 0.30 ZVli. SO 0.30 153. 2913.50 0.~0 2~13.00 0.~0 154 2912.~0 0,~0 291Z,00 O+~O ZVlI.SG 0.40 2910.~ ~.5~ 154 Z909.~0 0.60 29~9.G~ 0.70 !53 290B.50 0.~0 152 2908.00- 0.90 ' 1~1 lVOT.~O 0.90 151 Z907.00 l. OO 1'50 2906.50 1.00 149 2906.00 1.00 V~LU6 VALU~ i2I SC ~If;It:~,T~ D V~LUE DI $£R 3{:t~,I~ATED V ALLtE DI$CRININATED VALUE OI$C~ i~-I{'~A'TE O V '~LU'~ C'I SCRIV, INAT~C VALUE {3I$C£!,~YNAT~O VALUE VALUE VALUE VALUE V~LUE VALUE VALUE O i'S C~ I M l[ NiT i.r,',',) VALUE. DISCPINI. NATE~ VtLUE DI~C~I~INiTE'8 VALUE OISC~I~INATEO V~.LUE DISCRIFINATED VALUE ~ SCR[H]NRT~ VALUE OISC~IHINATED 905.00 O.gO 148 905.~0 0.~0 I~B 90~.00 O. BO 147 90t.50 0.40 146 gOl.O0 0.50 I~6 900.50 0.50 1~6 891.50 0.60 1~ 896.50 ~.70 150 89~,00 0.90 1~ :89Z.00 0.80 15'~ '891,00 O.G~ 152 ~89.50 0.70 152 . [88~-50 0.80 153 ~8 ?.50 1.'OD 153 ~887.0~ l. O0 153 ~886.~0 1.10 153 [gB~.O0 1.ZO 15Z ~85,5Q l.ZO 152 ~88~.00 1.20 I~9 ~883.50 1.20 1~9 ~883.00 1,20 14~ ~B81.50 1.30 . 1~6 [881.00 1.30 1~5 ~880.50 1.40 14~ ~879.50 1.40 14~ ~$79.OO 1.30 14) 1878o0§ 1.30 1~,3 ~ Z$76,,,5(} 1.0@ !47 287~.50 ~,60 t~T~.O0 0,50 15~ 287~.00 0.20 I57 .Z~TZ,50 O, 10 1 2871.$0 e.tO 70 2871,~ 0,10 79 2870.50 0.20 71 2870.00 0.20 2~69.50 0.t~ 28&geO0 0.10 160 28&'9.50 0.20 2867.00 0.60 158 Z8&5.~O 0.80 1~6 Z86~,.00 0.~0 155 Z ~ ~. 50 O. 9.0 3. 55 2~62.50' 1.00 152 2961, OQ 'l. O0 t51 2t61.00 C.8.9 1~1 Z~60.50 0.80 I51 2851.56 0.~0 149 Z~57,00 ~.5o 1~ 2~5~.50 0.60 1~5 281~.00- 0.70 - ZSS3.O0 0.~0 ~852.~0 1.00 143 ~85Z.~0 1.I0 .:: Iii VALU5 VALUE VALUE V/~LLIE vmtlJ~ VALU~ VALUf VAL~ V ALU! VALU~ VALUI V,~LdE VALUE VaLUF: DISCII~i~&TEO DISC~I~INiT~9 DISCtlMIN~TE~ ~Z$C~Z~I~{.ATED DISC~T~INATE9 Io20 1o20 1.30 IoZ0 1o10 Io00 0.10 0.20 O. 7..0 0.~0 0.30 0.3~0 0, t0 0.0;3 0°40 0.60 1.0C O.gO 2~36,,50 0.90 2836.00 2835.50 0.70 2~{3U.OO 0,,60 283~..50 283~.,00 0.30 2032°50 ~.'20 Z832,00 0,20 2~31,50 0,30 2831.00 l~.4D 283.9.50 2830,00 (1.50 282 .q.5~ 0o40 t82.8.50 0.20 282~.00 0. I0 2827,50 2827.00 0.10 282'6.50' 0.2.0 292~o00 0.30 2625.50 0.30 2815.00 1¢3 1~I 157 16~ 161 ?I VALU~ VALU~ ¥1LtJ~ V.mLU~ ViLU~ VALUE VALU'~ VaLU~ V~LUE V~LU~ V ~LU E VALUE VALUE VAL~E VALUE VALUE V AL tie VALUE VALUE VALUE VALUE 'VALUE' V~LUE V'aLUE VALUE VALUE VALUE VALUE DISCRiMI~ATED ., D!$CiI~INATEO DISCRIMINATED O, ZSCRI~iNtTEO 2~9.50 281~.50 ZS~T.SO 23~7.00 ZSI6.00 Z~lSo~O 2906,,, 280.3;,, ?.80]-. ~800. ~799o O,ZO 0.30 0,30 0.40 0.~0 0.40 0.40 0.¢0 0.30 0o30 0.20 ~.!~ 0.10 0o00 0,10 0o10 0.10 0.20 0.20 0.30 O.lO 0.20 ~.~0 0.60 0.60 0.70 0-70 0.80 0.60 0.~0 0,30 0.10 O.lO 0.00 0,I0 0.23 0.30 0.60 0.70 0.90 0.~0 O.BO 0.70 0.70 151 150 t51 if2. 15Z 15Z 150 6,5 6}' 6~ 157 VALUE V~LUE V~,LUE V~LUE VALUE V~LYE VALUE V~.LUE V ALU ~. VALUE VALUE VALU~ vi LU'E V~LUE VALUE V~LU5 ~ALU~ V~LU~ V~LU~ V~LUE VALUE V ALU E VALUE VALUE. V~LUE V~,LUE VALUE V~LUE VALUE VALUE VALUE VALUE V6L~JE YALU~ VALUE VALUE DISC~IMIN~TE~ rjI$CRI~:I~ATE~ ~t SC K'I'Pt~ITEO ~l SC~I~I~ATED OISC~INI~ATEo DTSCR~INATEO DISCrimINATED O:ISCR~NAT~O DISCRIMINATE0 O,I$~RIMINATED OISC~IMINITEO OI$CRI~I~ITED OISCRIPIN~TEO OIS{~I~IN~TEO OISCRI~IN,~TEO ~I$C~I~INATEO ~?9ToO0 OoSO ~795.0~ O. ZO ZI~Z.5O 0.00 Z789.50- 0.40 130 V~lg~ ZT67.SO 0.60 27at. O0 ~.60 125' Z786.50 0.70 124 278S.00 0.~0 !23 ~78~. SO 0.~0 123 Z78~.00 0.~0 1781.50 O.BO 27~Z.50 0.~0 123 ZT82.00 0.80 1Z3 2781.50 '0. BO 1 Z781.00 0.90 2780. S0 0.90 122 Z778.00 0060 122 Z777.00 0,5~ 12Z 277i. G0 0.40 Ill VtLUE 2773.50_ 0.40 2773.00 0.40 1ZO VALUE 27T~.50 0.40 2771.5g 0.50 119 Z76S.00 0.6'0 ~767.~0 0.~ 1746.00 0.40 Z?6~.O0 e,ZO 113 Z763.~ 0.20 ~761.50 O.ZO ~7t~.50 0.30 Z76B.~O O.3G ZTS~.EO 0.~0 lT~9.00 0.~0 1i5 Z758.~0 0.~0 Z758. O0 O. 30 1'1.5 1T~7'50 0.30 116 ZTST.~O 0.30 116 ~756.00 ~.10 117 ~755.50 0.20 118 ~755..00 0.10 176~.50 0. I0 ~753.50 0.20 E753.00 C.20 I. ZZ ~75Z.50 0.30 ~75Z.00 0.3C E7~1.50 0.30 12'5 ~751.00 0.40 125 :750.0C, 0.50 '.7~.~0 0.50 ~7~a.50 O.~O 126 ~7aB.OO 0.30 :74~.50 0.30 126 ~'747.0~ C.30 '.746.50' 0.30 126 :746.00 - 0.30 "- 125 .745.50 ~.30 125 .7~S,00 0.40 TAi. EO 0.40 125 744.00 0.40 ,.:-~ Iii ¥ ALUE VALUE VALUE VALUE VALUE VALUE V~LU~ YALU£ VALUE VALUE V~LU-~ VALUE V ~LU E VALUE V~LU~ VALU~ VALUE V~LU~ VaLU~ YALU~ YALU~ V~LU~ VALU~ VALU~ VALUE VALUE VALUE VALUE VALUe VALUE VALUE VALUE VALUE VALUE VALUE VALU~ VALUE VIILUE VALUE OI$C~I~I~{TEO OlSCRI~INATEO DISC£I~]~ATE~ ~ISCR~PINATEO 2743.,00 C.&O 123 Z742.50 0.~0 17.3 27&2.00 9.&O t2Z 2741..$0 O.hO 122 27&1o0~ 8.40 121 2.73~.~ C.40 119 2739.00 0.70 11~ 27~%.00 0.90 120 2736' 50 0.90 121 273~.00 1.0~ 27~5.~0 1.00 123 273~. 50 1.10 125 27~.00 1.10 126 Z713,00 1.I 0 127 '27~2.50 1.20 Z73Z.O0 1.20 127 .27~1.50 1.10 127 2t31.00 1.00 117 2730.0e 0.70 2729,50 0.50 127 2729.00- 0.30 127 2717.~0 O.OO 37 272~.0Q 0.00 I26 1716.50 0. I0 · 27Zi:.00 0.10 125 ~725.~0 o.10 Z725.00 O.lO 272~,~0 ~.10 122 2{2~.00 6.10 120 27Z~.S0 O. IO 120 Z72),00 0.20 2723,00 O.ZO 2721050 0,'30 121 2721.00 0.40 121 2720.50 0,50 121 ZTZO. O0 0.60 _ Z719'50 0.70 121 ~71~.00 O.TO Z717.50 C.80 121 ~TiT. O~. 0.80 VALUE VALUE VALU~ VALU£ VALUE VALUI VALUE VALUE VALUE ~I$CP.I~ZNRTED VALUE OI$C~. I~IMtTED vACu~ V~LU~ VALUE V~LU~ V~LU[ VaLU~ ~ALU~ VALUE V~L~D V~LU~ VALU~ 'VALUE 2 Ti.r-,. ;~0 o.?n... IT1S.O0 0.60 118 Z?I~,.EO 0.60 Z71.r.,. GO 0.50 117 271~.00 ¢.~0 120 r.?ll. O0 O.SO 12,2 t711.00 0.60 I25 /710.00 0.70 2709.00 0.30 129 270?.50 0.3~ 270~.00 0.I0 Z?03.00 0.00 132 270~.00 0.20 /701.50 0.~0 126 t701-00 0.20 126 /700.50 0.I0 122 Z700.O0 0.10 1699.50 0.I0 12.0 /6'9B. 50 0.10 I1 9 169~. ~0 O. 10 1 1597.00 0.I0 119 !696. t0 0.20 119 ~b95.00 O.ZO 119 /69~. 50 0.20 119 ~93.50 0.2C 119 /6~5.00 0.20 119 /692.50 0.30 1i9 /692.00' 0,30 1691.50 0.30 119 ~6~1.00 0.30 ~690. S0 0.30 119 V~LUE VALU~ VALUE VALUf VALUE VALU~ VALU~ DISCRIMINAT~O. VALUE ~.~SCR IMINATEO V~LU~ CISCRIMiNATED VALUE OlIC~I~INITiD VILUF ~tSC~ IHI~T~O VALU~ ~! SC~I~II~tTEO VALUE ~IS[tI~INIT~O V~LUE VALUE DZ SC~IH~ATED. VALU~ VALUE VALUE OISCRIM!NATEO ~6gO.O0 0.30 - -. 119 VAL'U~ DI$CRI~It,~ATEO . 5EPTH 2687.00 268~,~0 ~68Z.00 ~679.50 ~S79.00 Z678.00 ~677.50 ~676.0~ }675.09 ~672.00 ~67t.00 ~67 O. O0 :66~.50 :66T.50 '.665.50 :66~.50 663.00 0.,~0 0.~0 129 0.4,0 118 ~o~0 118 0.30 118 0.30 11.5 0.20 0.20 0. t0 119 ~.!~ 11~ ~.10 116 ~.10 It~ O.O~ 113 0.10 11~ 0.10 113 0.10 113 0.20 11~ 0.20 0.20 11~ 0.~0 ~.20 11 3 0.20 112 0.20 0.20 0.20 0.20 105 0.30 10~ 0.40 0.50 93 O.~O 9~ 0.40 0.30 0.30 .. 0.40 C.40 VALUE VALUE VALUE VALUE VALUE V~LUE VALUE VALUE YALUE VALUE VALUE V~LU~ VALUE VALUE V&LUE DI$C~IPINATE9 OISCRI~iNtTEO DISCR~f~T~AT~O DISCRIMINATED O!SCRI~I~T~O DISCrimINATeD DISCrimINATED V~LU~ VmLUE VALUE VALUE V~LUE VALUE V~LUE VALUE VALUE vaLUE VALUE V ALU E VALUE ¥ ALUE ¥~LUE VALU~ VALUE VALUE' VALUE VA~U~ VALUE VALUE V.~LUE VtLUE VALUE VALUE VALUE V &LUE VALUE VALUE VALUE DISCRIMINATED DISCRI~INATEG ~I$Cll~INtrEO DI~CRIMI~ATEO DISCRIMINATEO 2662.00 0.~0 2661.5~ :.30 ~6~.5~ O.~O 2660.~ O.~O 265~.50 0.50 26S7.50 0.70 26S7.00 O.~O 2656.00 0.90 30 2655.~0 O.gO 2655.G0 1.~0 265~.00 t.00 Z653.50 1.00 2653.00 1.0P 2651.50 1.00 g650.50 0.90 77 2650.00 0.9~ 2~.00. O.SO 26~6.~0 t.ZO 2&~5.00 1.10 75 26~2.50 0.60 2~Z. OO 0.50 ~63~.00 O.IO 53 VALUE ~63B.~0 0,~0 2637.50 0.~0 2636.00 0.,50 ... ,DEPTH CAL~PEq ~iFFEREaCE NAJO~ AXIS DIRECTION · Z63,6,.00 263~.0~ 2531.00 2630.50 262 9. O0 2~2~.50 Z627.00 262~.00 Z62~.50 262~.~0 26Z~.00 2623.00 2622.50 Z~2Z.O0 2621.50 262~ .00 2G20.50 2620.00 2619.5'0 2617.50 2616.00 2615,50 261~.~0 26i~.50 2611.00 2~10.50 ~0~.50 O. 20 I 'VALUE O. 60 l 0 0.60 i~ 0.70 1T O. GO ~3 0.40 37 V~L'U~ 0.2~ 52 VALU~ O-ZO ST V~LUE 0,30 6C VALUE 0.~0 62 VALUE 0 40 63 V~LU~ 0.50 6~ O.IO 6~ 1.00 6~ 1.10 6~ 1.20 "' 6~ 1.40 63 1.40 63 1.~0 63 2607. 2601'.00 2~G~.50 1.00 260§°00 250~.50 0,8.0 260~.00 0.70 '260~.o 50 0°70 .260~,o00 ~602.00 1.20 -VARIABLE : ~JT ~F.-' VA &O.O0 160.,0 180.0 i ' I . 1 ! 3 ~ 3! I FROM 31¢go00 FT TO . OEPT{ VALUE .. . [~¥P OlO,H02 VF, RIFICATION LISTING :I,, REEL HEADIB.,R DATE I CO.~BN~S I~ CO~M~ _ ** TAPF HEADER ~V~C~ ~A~ ~'-~ I~g~.V~:C ~:' ._. DATE TAPE NAN~ 1626~6 ~REVIO[..'S TAPE CONTENTS UNIT TYPE: ~ 000 000 000 000 0"00 000 :..~:; :~ --000 UNIT :~ TYPE 000 CATE SIZE CODE 000~ 01.6 065 000 014 O6 000 008 06~ 000 002 065 000 003 065 000 00! 065 06~ O65 000 004~ _ 065 CATE &IZE CODE 000 007 065 LVP 010,~02 VE~IFICA?IPN LISTING ** R~CORD TYP~ 047 - ~i~ COMMENTS ** SCHLUMBERGER !'l PACIFIC COAST COMPUTING CENTgR COMPANY = ARCO ALASKA CO. WELL = WEST SAK # 23 FIELD = KUPAPUK COUNTY : ~, SLOPE JOB# 10707,62656 DIL RUN #3, LO~G~D 12-FEB-~2 BOTTOM LOG INTERVAL TOP LOC INTERVAL BIT SI~E TYPE HOL~ FLUID DENSITY VI$CO${TY PH 6401 2761 10 8 10,3 45~05 0.0 LVP 010,HO2 VEPlFICATION LISTING Fbl]ID LOSS RMF e ~EA$, ?EMP, RMC e MEAS, TEMP, R~ ~ PHT REMARKSI ~: RU~ ! I DUAL ~NDUCT!ON, - ' ---' ' ' RUN 2 & 31 DUAl. LA?EROLOG. MERGE POINT81 ': ::~-;" '-~::: :~-:'~: ~:~,~..~;~'":~".:::~:~'<~: ~ : ~ : DLL+DTbt 2+31 2900 FDC/CNbl 2900 (NO OVER~AP AVA:IbAB~E):, - ~;~' -..': -:.- DATA FORMAT R~CORD $* ~NTRY BLOCKS TYPE $~ZE 0 66 DATUM SPECiFiCATION ~bOCKS MNEM SERVICE SERVICE UNIT API Ap! ID ORDER # LOG TYPE CLASS DEPT FT 0 NSrb Pbb OHM~ 0 bbs Db~ OH~M 0 PROCESS 8AMPLE REPR LVP 010,H02 LbD' DLL CA6! DbL SP DLL NPH! rDN NRRT FDN NCNb ?CNb FDN PROX PRX CALI PRX MNOR PRX MINV PRX OT FHC GR BHC.--"--' OHMM ~API IN ~V PU C/C3 G/C3 GAPI OHMM OHMM OHMM U$/F PAGE : -i~--:.:.i. :I..: !: ~:-.:. _ 0 31 32 0 0 4 0 1 8 6 0 28 : '37 0 ~' 0-'~:':~' .,"i:::~ .::: ..0:: 0 I 0 0 0 4 0 i 68 42 68 2 0 !-0~ ,---:..&. O- : 42 44 0 0 0 4 0 t 68 0 4 0 1 42 42 21 125 2 052'32 6O 0 0 4 0 ! 61 0 4 0 1 68 -~!0: : .14: O: · : :i-~.; :/~!:!68':~i' '::-'--~: 3t 32 0 0 4 0 DATA DEPT DRHO NRAT CALl DRHO NRAT CALl ~R OEPT GR DRHO NRA CAbl OEPT DRHO NRRT GR ORHO MRAT 5 , -999, -999, -999, -99g, 6,400. °099. 6300 103 0 B -999, 6200, 1t5' O, 6100 5000 0000 2500 2500 2500 2500 0000 0000 1069 3047 0039 2500 0000 8125 0298 25O0 0000 8125 0767 4316 81 0000 3125 0146 84~8 CAb! MNOR RHOB NCNb ~NOR CALI RHOB CNB NOR MNOR MSF6 CALI RHOB NCNb 182~ :999 FC 4 B 2 2!3~. 3 8 2 1696 1 9 2 2194 359 0000 FC 244i 6000- ~':: ~ ':<<~ ~ : X- :'-.' ~ ::- <':; 7:;:'::::~::: : : - CALl 8.2266 DEPT 6000, MSWh NRA? NCNb CAL! 8.4688 MNOR GR -999.~500 DEer 59oo.oooo GR 107, CALl CALl 999,2500 GR . I MNOR NRR? ] CALl 9 GR -999 00 Srb 01 6 RHOB 60~4 NCNB 0547 MNOR 2500 DEPT 5700 OR 227 DRHO ~ NRAT -999 0000 MSrb 9750 CAL! 0239 RHOB 6 11 NCN R~g4 MNO~ 2500 DEPT 5600 ~R 151 DRHO 0 NRAT 3 CALl 9 0000 6250 CALl 0078 6250 NCNb 9062 2500 L~STING 7008 46~ii0.000 rCNb 172! '595 8359 4082 4 8 2 1683 I ~9 MINV o..o o,o, 3438 MNOR ekbI GR -99a,2500 0000 MSFb 2500 CAI,! NCNb 8594 MNOR ~500 O£PT 540~ OR I0 DRHO 0 NRAT 3 -99 DEPT 5300,0000 MSFE GR 113.5625 CAL! 196~ I ,8 7 MINV 4 O814bb8 8:5859 SP PAGE: 5 )0 i7 L4 -999 LVP 010.H02 NRAT -q9 VERIFICATION b)$TING 0,018! RHOH 3,205~ NCNb 9,984 ~NOR 9.2500 DEPT 520~,0000 MSFb QR 9 .5625 CALI DRHO 0,~78 RHOB CAbl 8.6406 MNOR GR °999,2500 DEP? 5]00, ER 02, DRHO NRAT GR '999, DEP~ 5000, GR 108' NRAT -999. OEP'l' 4900 NRA? ) GR -999 OEPT 4800, OR 130. DRHO ~ ~R '999 DEPT 4700 GR ORHO 0 NRA -999 DEPT 4600 DRHO 0 NRA? CAI,! 9 GR -999 0000 0000 CALI 0474 RHOB i836 NCNb 0703 ~NOR 2500 000 4)0 RHOB 355 NCNb 0 0000 5000 NCNb 38t3 MNOR 2900 0000 6250 0 40 ~HOB 2~$4 NCNb 945] NNOR 2500 0000 MSrb 625 CALl 091~ RHOB 876 NCN 304~ b MNOR 2500 0000 2500 0298 5879 NCNb 3594 2500 PAGE 2, 3984 '-CAb! 193~:0000 FC 49~i MI 4~ 2, 2048, 1,6810 2,1543 bbs 9'0547 SP 2~386.7:-~ 1610,0000 FCNL · 3,2650 Lb8 4782 MINV 48 · , :!875 SP 4629 1680;0000 FCNL , I{9026 M{NV -==~ :~'~ 0384 bbs 7246 MINV 2, 4~80. ~bb8 10,1797 aP 1450i0000 rCN~ 0042 b~8 554'7 8 '~.~ 2969 CAL! :ooo'o ~986 ~INV t4 bVP OIO,H02 VERIFICATION DEP? 4~00 GR 55 DRHO 0 OR -g99 0000 MSFB 6250 ~ABI 0532 RHOB MNOR 2500 DEPT 4400 OR 157 DRHO 0 NRR? 3 R -999 0000 MSFB 1250 CALI 0342 RHOB 5859 NCNB 2969 YNOR 2500 OEPT 4300.0000 GR t5l,O000 ORHO ~:,348 .HOB NRAT 4551 OR 999,2500 OEPT 4200 OR 8~ DRHO CAbI 8 GR -999 5625 CALl 0449 4434 CNB 7813 MNOR 2500 OEPT 4t00 GR DRHO OR -999 0000 RHOB NOR 2500 OEPT 4000, OR o..o NR~T CAb! GR 000 MSFb Nb 8 MNOR OE:P'I' 3900 NRAT OR -999 0000 RHOB 57 2500 DEP? 3800 OR 99 DRHO 0 NRAT 3 0000 M$1rb 0625 CAb! ~½27 RHOB 81 NCNB 2266 MNOR 9 2 t ! 170{ 1,8177 1 PROX ,6 1568 5l PROX ' NV ' DT ',' 1785, 24 BVP 010.H02 V£RIFICA~ION -999.2500 OEP? 3?OO GR tO0 DRHO 0 NRA? ] -999 OEP? 3600 OR 93 DRHO 0 NRRT 3 CAt,! 8 ~R -999 DEPT 3500 GR 9~ DRHO NRRT 3 GR -999 OEP? 3400 GR 93 DRHO 0 NRAT )0 OEP? 3300, GR 100, NRR CAbt GR -999. OEP? 9~, 3200, GR DRHO OR '999. 0000 MSFb 6250 CALI O483 RHOB 4004 NCNb 9844 MNOR 2500 0000 MSFL 9375 CALl 0039 RHOB 43?5 NCNb 914 M 250~ NOR 0000 M&rb 0391 RHOB 34i8 NCNb 2500 000250 CAbk 40! RH08 414 NCNb 9062 2500 0000 MSrb 1250 CALl 0054 RHOB ~3~ NCNb 92 MNOR 2500 0000 MSFL 18~5 CALl NCNb 9 81 ~NOR ~t00 D~PT 3{00,0000 MSFb OR 7i 8125 CALl NRAT 3 NCNb ~AbI 8:5547 MNOR OR -999,~500 DEPT 3000,0000 MSFL ~R 102,3125 CAb! DRHO 0,0171 ~HOB 9 2 1686 1 189~ 2 9 1835 i 10 149{ ! 4 9 16'73 2 166 )0 rCNb 8626 9798 LbS ~Abl 0065 MINV 0000 rCNL 7900 '~:INV -.~i ::ili':-.' !!'t NV 0 6479 DT 35 )0 4t PRO: 15~3 CAI., L VP NRA? DEPT DRHO NRA? CAb! DEP? ~R DRHO NRA~ CAb! DEP? ORHO GR OEPT GR ORHO GR OEP? NRAT CAL! GR DEPT GR NRAT GR DEP? OR ORHO NRA? CAL! DEPT 010.H02 VERIFICA?ION 3,!)23 IMCNb 106, ,000 2qO~ 0000 MSFL 7:2500 CAL! 0.035~ RHOB 3,472 NCML 8,2813 MNOR 80,1875 2800,0000 MSFL 81,0625 CALl 0420 RHOB 5938 .NOR 2700,0~ O0 NSrb 6t,2~13 CALl ~:0020 RHOB -999,2500 OR 7t,]750 2600,0000 MSFb 82,9500 CALl 9395 NCWb -q99.25o0 MNO~ 9],0625 2500,0000 MSFL 76,5000 CALl ~:0493 RHOB 5566 NCNb =q99,2500 MN'OR ?3.8750 2400,0000 76~4395 CALl '8 0 SCNL 2500 MNOR 'q~O,?500 2300 46 0 4 -999 48 0000 56{5 CALl NCNb 2500 MNOR 1875 2200,0000 MSFL 2~ -999 . 1423 ,,999 7510 MINV 2500 MINV 5046: ~bS 804'/ 8P 1:0~5 CAbI 0000 FCNL )500' )INV 2t87 2500 MINV -999 25'0.0 ~0 . 1,54]0 LbS bVP 010,H02 DRHO NRA? CAb! GR GR DRHO NRA? CALi GR DEPT DRHO MR'AT AL! R DEPT GR DRHO NRAT CALl DRHO MRA? CAt! ~EPT DRHO NRAT CAb! ~R VERIFICATI.fiN L!STING PAGE 1 76.3t25 -99q,2500 ?~4375 2100,0000 .999,2500 .999,2500 999'25OO -999,2500 2000.0000 -999'2500 -999,,2500 -999,2500 -999'29OO iO00,O000 . 45,9062 .999.~500 '999'2500 1800,0000 -999,2500 .999~2~00 -999~2500 [?00,0000 ' 48,4688 999,2500 l oo'oooo 61,8t25 -999,2500 '999~500 -q99,2500 1500.0000 :999,2500 999.2500 -999.2500 RHOB MNOR I -q99 2500 CAt,.[ RHOB MNOR -9 NCNb MNOR ! 0000 -999 M$1rb CAb! RHOB DT :150 0 CAb: RHOB NCNb MNOR MSlrb gALI MNCNb NOR CALl RHOB NCNb MNOR CAT.,! RHOB MNOR -999 -99! -9 '99~ · ,999 2500 -999 LVP GR NRAT GR GR DRHO MRAT GR DE:PT DRHO NRAT DEP? GR DRHO NRA O~PT GR DRHO CAb! GR GR DRNO NRAT CAb! GR DRHO NRA'F D~P? DRNO NRA? O[O,H02 VERIEICATION 1400,000 MSFb 39~656~ CAL! -999.{~0 RHO. 'q99, 0 NCNb -999,2500 MNOR e999o2500 l]O0,O000 62,?198 .999,2500 RHOB 500 NCNb 999,2500 1200,0000 -999,250o -999,2:$00 NCNb -999~ ltO0,O000 MS~L 2S00 RHOB -999.2500 NCNb -999~2500 MNOR -999~2500 tO00,O000 4375 2$00 NCNb -~99.2Soo MNOR -999,2500 9O0,0OO0 30~406 ,999~ 2500 ?00 0000 . 6~2500 9~9,2500 0999,2500 MSlPb c gb NOR RHOB NCNb MNOR AL! HOB LISTING -999 . 29. 999, -.999. -999 ~, -999 !50 2 -999 ,.999 - -999 999, '999, -999 iO0 S JO · ,~ ,,9 ~999, -999,25( 0 . / / CALl GR ~R DRHO NRAT CALI GR ORHO NRAT 010.H02 VERIFICA?ION -999,2500 MN~R -999,~500 600. 00 MSFE . 66.~25 CALI g99,2500 RHOB -999,2500 NCNb -999.2 O0 ~NOR -999,2~00 500,0000 . 45, 5 CALl -999,95~0, NCN~ -999.25 0 MNOR -999,2500 DEPT 400 ORHO -999 NRAT -999 CAbI -999 GR -999 DEPT )00. OR . 46, DRHO .999. NRAT 9990 OR -999, D£PT 200 OR 59 DRHO -999 NRAT -999 CALl -999 OR -999 DEP? 100 OR . 39. DRHO 999 NRAT -999 CAbI '999 OR -999 OR 26 ORHO -999 NRAT -999 CALI ~R -999 8i25 CALl 2500 RHOB 2500 NCNb 500 MNOR 50O 0000 MSF.L 0 CALl 25 0 MNOR 2500 O0 RHOB 0 MNOR 2500 0000 MSFL 3750 CALl 2500 RHOB 500 NCNb 500 MNOR 2500 0000 MSFL $?i9 CALl ~ 0 NCNb 2500 MNOR 25O0 LTSTING PAGE -999.2500 MINV -<:< DT -~ -J:i "':< - . 3,2539 .,. 999; -999, ,I -999, '999,2500 HINV 2 1496 5 -999 ,.999 -999 -999 . 9 ~ 999 -999 '999 -999 -99' 0 C 2500 MINV · ~58 ,D 9 ~0 -999 -999 -999 -9'99 -999 -999 -999 2O00 -999 ,,.999i -999 -999 -999 -99'9 8P 2500 FCNL ,,999 iO0 2500 PROX MINV ~500 ~500 rCNb !SO0 ~I~V 5156 bLS 5¥P OlO.H02 VERIFICATIO~ LISTING rILE NAME SERVICE NAME VERSION # nA?E : ~AXIMU~ LENGTH I t024 FILE TYP~ NEXT FILE NAME ** TAPF TRAIt, ER ** SERVICF NAME ISERV~C DATE I~2/03/24 OR~GIN 11070 TAPE NAME 162656 CONTINUATION # 10~ NEXT TAPE NAM~ l COMMENTS ITAPE COMMENTS ~* REEl, TRAIbER SERV)CE 'NAME ISERVIC DA?E 1~2/03/~4 ORIGIN l REEL NAME IREEb ID CONTINUATION # 101 NEXT REE~ NAME