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Home My WebLink About188-0311. 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 9450'feet None feet true vertical 6670' feet 9190' feet Effective Depth measured 9167'feet 8735'feet true vertical 6488' feet 6206' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8777' MD 6233' TVD Packers and SSSV (type, measured and true vertical depth) 8735' MD N/A 6206' 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: 322-711 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: HLB MFT Packer SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597Senior CTD Engineer None None 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) 125 Gas-Mcf MD ~ Size 110' 690 138899 Well was Shut-In ~~ 157 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-031 50-029-21797-00-00 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: ADL0025513 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3O-15 Plugs Junk measured Length Production Liner 9389' Casing 6652'9422' 2739' 110'Conductor Surface Intermediate 16" 9-5/8" 74' 2774' 2242' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 12:49 pm, Mar 06, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.03.06 07:56:59-09'00' Foxit PDF Editor Version: 12.0.1 Page 1/13 3O-15 Report Printed: 2/27/2023 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) 1/14/2023 00:00 1/14/2023 08:30 8.50 MIRU, MOVE DMOB P Bridal up. Lay over derrick. R/D tiger tank line. Move cuttings tank and mud shack. Disconnect electrical in interconnect. Trucks on location @ 03:45. Load shop and office. 1/14/2023 08:30 1/14/2023 10:30 2.00 MIRU, MOVE MOB P Move Pit's, Office, and shop f/3A-Pad to 3O-Pad. Spot Office complex and Shop. 1/14/2023 10:30 1/14/2023 17:30 7.00 MIRU, MOVE MOB P Move Sub f/3A-Pad to 3O-Pad. Sub on pad @17:30 Hrs. 1/14/2023 17:30 1/14/2023 20:30 3.00 MIRU, MOVE MOB P Hang tree in cellar. Spot wellhead equipment behind well. Spot sub over well, lay mats and herculite. 1/14/2023 20:30 1/14/2023 22:30 2.00 MIRU, MOVE MOB P Trucks on location @ 20:00 Hrs. Spot pits to sub, lay mats and herculite. Sent Notification to AOGCC. 1/14/2023 22:30 1/15/2023 00:00 1.50 MIRU, MOVE MOB P Berming in rig. Spot cuttings tank. R/U tiger tank line & Choke House. 1/15/2023 00:00 1/15/2023 04:00 4.00 MIRU, MOVE MOB P Continue berming in rig. Spot mud shack. Connect electrical. Hook up inter connect. Turn steam and air on to pits. Offload 14.5# KWF into pits. 1/15/2023 04:00 1/15/2023 09:30 5.50 MIRU, MOVE MOB P Raise derrick. Bridal down. Complete rig acceptance checklist. Get measurements for riser height from tubing spool height.Accept rig at 0930 hrs. Rig up circ manifold in cellar. 1/15/2023 09:30 1/15/2023 10:00 0.50 MIRU, WELCTL SFTY P PJSM on Well Kill Operations. 1/15/2023 10:00 1/15/2023 13:00 3.00 MIRU, WELCTL KLWL P Begin Well Kill Operation. ITP:2250 psi / IIAP: 1800 psi. Online with pump at 2 bpm, 950 psi, Increase to 3 bpm for the entire well kill. Intitial Pump pressure 1450 psi, Final Circulating Pressure 220 psi. 14.4 PPG Heavy KWF back after 6400 STKS, Shut down at 7000 STKS. OWFF. 1/15/2023 13:00 1/15/2023 13:30 0.50 MIRU, WELCTL OWFF P OWFF for 30 mins. 1/15/2023 13:30 1/15/2023 14:00 0.50 MIRU, WELCTL SVRG P Rig Service. 1/15/2023 14:00 1/15/2023 15:15 1.25 MIRU, WELCTL WAIT P Wait on Cameron. 1/15/2023 15:15 1/15/2023 15:30 0.25 MIRU, WELCTL MPSP P Install Type " HP " BPV 1/15/2023 15:30 1/15/2023 15:45 0.25 MIRU, WELCTL PRTS P PT BPV from below to 1000 psi for 10 min. 1/15/2023 15:45 1/15/2023 18:45 3.00 MIRU, WHDBOP NUND P ND Wellhead, Threads look good, XO made up 8-3/4 Turns. Dart Valve Made up 14-1/2 Turns. NU DSA and BOPE. 1/15/2023 18:45 1/15/2023 19:15 0.50 MIRU, WHDBOP SVRG P Service rig 1/15/2023 19:15 1/15/2023 20:45 1.50 MIRU, WHDBOP RURD P R/U testing equipment. Space out doughnut test joint in BOP. Fill BOPE w/ fresh water. Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 2/13 3O-15 Report Printed: 2/27/2023 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) 1/15/2023 20:45 1/16/2023 00:00 3.25 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Test annular 250/2500 on 2 7/8" test joint. Tested, UVBR's and LPR on 2 7/8" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 3 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=1500 PSI, 200 PSI attained =21 sec, full recovery attained =111 sec. UVBR's= 5 sec, LVBR's= 6 sec. Annular= 27 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1930 PSI. Witness waived by AOGCC rep Guy Cook. 1/16/2023 00:00 1/16/2023 02:45 2.75 MIRU, WHDBOP BOPE P Cont Initial BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Test blinds rams. Choke valves #8 to #15, upper and lower top drive well control valves. Test 2" rig floor Demco kill valves. Testmanual and HCR choke valves. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Guy Cook. 1/16/2023 02:45 1/16/2023 03:30 0.75 MIRU, WHDBOP RURD P B/D, R/D testing equipment. Suck out stack. 1/16/2023 03:30 1/16/2023 04:00 0.50 MIRU, WHDBOP SVRG P Rig Service 1/16/2023 04:00 1/16/2023 04:15 0.25 COMPZN, RPCOMP MPSP P Pull tree test dart and BPV. 1/16/2023 04:15 1/16/2023 05:15 1.00 COMPZN, RPCOMP RURD P R/U landing joint. M/U to hanger. M/U TD set 10K down. BOLDS. 1/16/2023 05:15 1/16/2023 06:45 1.50 COMPZN, RPCOMP CIRC P Circulation and Condition Mud. Heavy Clobbered up mud for the first 80 bbls, had to take outside to get from contaminating pit system. Looked like peanut butter type fluid. 1/16/2023 06:45 1/16/2023 07:15 0.50 COMPZN, RPCOMP RURD P RU Handling equipment and Control Line Spooler. 1/16/2023 07:15 1/16/2023 11:30 4.25 COMPZN, RPCOMP PULL P L/D Tubing Hanger and Pup. Continue OOH laying down Completion. 8,778.0 6,992.0 1/16/2023 11:30 1/16/2023 12:45 1.25 COMPZN, RPCOMP PULD P Break out SSSV. Disconnect Control Line. Remove Spooler and Control Line from Rig Floor. 30 Bands Recovered from Control Line. 6,992.0 6,992.0 1/16/2023 12:45 1/16/2023 15:45 3.00 COMPZN, RPCOMP PULL P Continue to pull and L/D 2-7/8" Completion T/ 5553', PUW=65K 6,992.0 5,553.0 1/16/2023 15:45 1/16/2023 16:30 0.75 COMPZN, RPCOMP CIRC P Circulate BUS @ 3 bpm, 1035 psi.. Pump 15 Bbls dry job. 5,553.0 5,553.0 1/16/2023 16:30 1/16/2023 16:45 0.25 COMPZN, RPCOMP OWFF P OWFF. B/D TD. 5,553.0 5,553.0 1/16/2023 16:45 1/16/2023 23:00 6.25 COMPZN, RPCOMP PULL P Continue L/D completion F/ 5553' T/ 2000', PUW=60K. 5,553.0 2,000.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 3/13 3O-15 Report Printed: 2/27/2023 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) 1/16/2023 23:00 1/16/2023 23:30 0.50 COMPZN, RPCOMP CIRC P Circ STS @ 3 BPM, 425 PSI. Mud in pits =*55. Mud coming back OOH F/ 1000' =*48. OWFF Bleed OA T/ 0 PSI. 2,000.0 2,000.0 1/16/2023 23:30 1/17/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig 2,000.0 2,000.0 1/17/2023 00:00 1/17/2023 04:30 4.50 COMPZN, RPCOMP PULL P Continue L/D completion F/ 2000' to surface. PUW-40K. Heavy scale after GLM #6 @ 7855'. Inspect cut joint - slightly flared. 267 joints & 5.83' cut joint lied down. 2,000.0 0.0 1/17/2023 04:30 1/17/2023 05:30 1.00 COMPZN, RPCOMP CLEN P Clean and clear RF and pipe shed. 0.0 0.0 1/17/2023 05:30 1/17/2023 06:00 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 0.0 1/17/2023 06:00 1/17/2023 07:00 1.00 COMPZN, RPCOMP BHAH P PU/MU BHA #1. 7" AS1X Packer. 0.0 18.6 1/17/2023 07:00 1/17/2023 08:45 1.75 COMPZN, RPCOMP TRIP P TIH w/BHA #1 on 2-7/8" TBG. 18.6 1,362.0 1/17/2023 08:45 1/17/2023 09:30 0.75 COMPZN, RPCOMP CIRC P Circulate S/S at 3 bpm, 700 psi. 1,362.0 1,362.0 1/17/2023 09:30 1/17/2023 13:00 3.50 COMPZN, RPCOMP TRIP P TIH w/BHA #1 on 2-7/8" TBG. 1,362.0 3,820.0 1/17/2023 13:00 1/17/2023 14:30 1.50 COMPZN, RPCOMP CIRC P Circulate and Condition Mud at 3.5 bpm, 920 psi. 3,820.0 3,820.0 1/17/2023 14:30 1/17/2023 15:00 0.50 COMPZN, RPCOMP MPSP P Set Test Plug. BOP: 3,820' / TOP: 3814' 3,820.0 3,820.0 1/17/2023 15:00 1/17/2023 15:45 0.75 COMPZN, RPCOMP PRTS P PT and Chart test Plug to 2000 psi for 15 minutes. 3,820.0 3,820.0 1/17/2023 15:45 1/17/2023 22:00 6.25 COMPZN, RPCOMP TRIP P TOOH Laying Down 2-7/8" TBG // Well control drill while pooh 1:35 reaction time crews responded in correct and timely fashion // Lay down 117 jts 2-7/8" tubing 3,820.0 5.0 1/17/2023 22:00 1/17/2023 22:15 0.25 COMPZN, RPCOMP BHAH P L/D BHA #1 setting tool 5.0 0.0 1/17/2023 22:15 1/17/2023 23:15 1.00 COMPZN, RPCOMP CLEN P Clean and clear floor // Prep for picking up BHA# 2 0.0 0.0 1/17/2023 23:15 1/18/2023 00:00 0.75 COMPZN, RPCOMP BHAH P Strap and tally 12 jts 4-3/4" 47# 3-1/2' IF drill collars 0.0 0.0 1/18/2023 00:00 1/18/2023 02:00 2.00 COMPZN, RPCOMP BHAH P Consult with town engineer and Yellow Jacket rep, decision made to pick up and run 9 - 4-3/4" 47# 3.5" IF drill collars, Storm packer, 3 jts 3.5" HT38 drill pipe P/U wt with full string 40K S/O wt with full string 42K Run to set depth ~105' COE 1 turn right engage slips set down wt of collars ~ 10K Back off setting tool 26 turns pick up off setting tool 31K up wt 0.0 387.0 1/18/2023 02:00 1/18/2023 02:30 0.50 COMPZN, RPCOMP PRTS P Test storm packer 1000psi 15 min 387.0 0.0 1/18/2023 02:30 1/18/2023 03:00 0.50 COMPZN, RPCOMP CLEN P Flush out stack for changing rams 0.0 0.0 1/18/2023 03:00 1/18/2023 06:00 3.00 COMPZN, RPCOMP OTHR P Change lower rams from 2-7/8" fixed rams to 3.5" X 5.5" VBR's 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 4/13 3O-15 Report Printed: 2/27/2023 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) 1/18/2023 06:00 1/18/2023 12:00 6.00 COMPZN, RPCOMP NUND P ND BOPE and DSA. Check Tubing spool, under tension. Dispatch Hydratight Rep. RU Hydratight Equipment and Grow 7" Casing. Total Growth 5-1/2" with 6000 psi, 129,600 lbs. of upward force. RD Hydratight equipment. 0.0 0.0 1/18/2023 12:00 1/18/2023 12:30 0.50 COMPZN, RPCOMP WAIT P All Rods are loose. 30 Min stand down, still no Movement. 0.0 1/18/2023 12:30 1/18/2023 13:15 0.75 COMPZN, RPCOMP PULL P PU Packoff Puller and pull packoffs. 0.0 1/18/2023 13:15 1/18/2023 13:45 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 0.0 1/18/2023 13:45 1/18/2023 16:15 2.50 COMPZN, RPCOMP WWSP P PU/MU 7" Spear on Drill Pipe. Engage 7" Casing and Pull 25k over block weight. Set slips in 25k tension. Cut 7" with WACHS saw, cut a total of 7-1/4" of CSG. Install IC Packoffs. RD WACHS Cutter. 0.0 0.0 1/18/2023 16:15 1/18/2023 18:00 1.75 COMPZN, RPCOMP NUND P PU/NU New Tubing Spool. 0.0 0.0 1/18/2023 18:00 1/18/2023 19:15 1.25 COMPZN, RPCOMP PRTS P PT Packoffs to 3000 psi for 15 mins. 0.0 0.0 1/18/2023 19:15 1/18/2023 22:00 2.75 COMPZN, RPCOMP NUND P Nipple up BOP's and adapter spool install test plug 0.0 0.0 1/18/2023 22:00 1/19/2023 00:00 2.00 COMPZN, RPCOMP BOPE P Test Upper 2.75" X 5.5" VBR's w/ tubing spool and DSA breaks 250 / 4000 - Pass Test Lower 3.5" X 5.5" VBR's 250 / 4000 - Pass Pull test plug install wearbushing 6-3/8" ID 0.0 0.0 1/19/2023 00:00 1/19/2023 00:30 0.50 COMPZN, RPCOMP BHAH P Pick up Storm Packer BHA 0.0 0.0 1/19/2023 00:30 1/19/2023 01:30 1.00 COMPZN, RPCOMP MPSP P Pull storm packer 0.0 391.0 1/19/2023 01:30 1/19/2023 03:00 1.50 COMPZN, RPCOMP BHAH P Lay down Storm Packer BHA 391.0 0.0 1/19/2023 03:00 1/19/2023 05:15 2.25 COMPZN, RPCOMP TRIP P Trip in hole picking up singles // Hit ice plug ~470' // Kelly up to single wash down pass ice plug circulate bu // continue in with singles 0.0 2,000.0 1/19/2023 05:15 1/19/2023 06:00 0.75 COMPZN, RPCOMP CIRC P Circulate and Condition KWF @ 4 bpm, 500 psi. PUW 52K / SOW 48K 2,000.0 2,000.0 1/19/2023 06:00 1/19/2023 08:00 2.00 COMPZN, RPCOMP TRIP P Continue to single in with BHA #4 on DP. 2,000.0 3,744.0 1/19/2023 08:00 1/19/2023 09:00 1.00 COMPZN, RPCOMP CIRC P Circulate S/S @ 4 bpm, 915 psi. 14.4 PPG in / 14.4 PPG Heavy out, fluid temp out 59 degrees. 3,744.0 3,744.0 1/19/2023 09:00 1/19/2023 09:45 0.75 COMPZN, RPCOMP MPSP P Located and Engaged Top of Plug @ 3,783', confirmed latched. Pump Dry Pill. PUW 83Kl, SOW 58K. 3,744.0 3,783.0 1/19/2023 09:45 1/19/2023 11:45 2.00 COMPZN, RPCOMP TRIP P TOOH standing back Drill Pipe. 3,783.0 7.0 1/19/2023 11:45 1/19/2023 12:30 0.75 COMPZN, RPCOMP BHAH P OOH. L/D BHA #4, Retrieval Tool and Test Packer. Recovered 2 more Control Line Bands for a total of 32 bands. 7.0 0.0 1/19/2023 12:30 1/19/2023 13:45 1.25 COMPZN, RPCOMP BHAH P MU BHA #5. 5-3/4" Dress off Guide and 5-3/4" Overshot Bowl Dressed for 2-7/8" Tubing with Oil Jars and Accelerator. 0.0 323.2 1/19/2023 13:45 1/19/2023 16:00 2.25 COMPZN, RPCOMP TRIP P TIH w/BHA #5 on Drill Pipe down to top of TBG stub. 323.2 5,051.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 5/13 3O-15 Report Printed: 2/27/2023 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) 1/19/2023 16:00 1/19/2023 16:45 0.75 COMPZN, RPCOMP CIRC P Circulate and Condition KWF @ 4 bpm, 1030 psi. Slip & Cut Drilling Line. 5,051.0 5,051.0 1/19/2023 16:45 1/19/2023 18:30 1.75 COMPZN, RPCOMP SLPC P Cut and slip drill line 5,051.0 5,051.0 1/19/2023 18:30 1/19/2023 19:00 0.50 COMPZN, RPCOMP SVRG P Change dies in gripper block 5,051.0 5,150.0 1/19/2023 19:00 1/19/2023 23:30 4.50 COMPZN, RPCOMP TRIP P Trip in picking up singles T/ 7900 Mud flowing over pipe stopped to circulate 5,150.0 7,900.0 1/19/2023 23:30 1/20/2023 00:00 0.50 COMPZN, RPCOMP CIRC P Circulate B/U 7,900.0 7,900.0 1/20/2023 00:00 1/20/2023 00:30 0.50 COMPZN, RPCOMP CIRC P Circulate B/U // Flow check no flow // MW in 14.4+ // MW out 14.5 7,900.0 7,900.0 1/20/2023 00:30 1/20/2023 01:30 1.00 COMPZN, RPCOMP TRIP P Single in DP T/ 8700' 7,900.0 8,700.0 1/20/2023 01:30 1/20/2023 02:00 0.50 COMPZN, RPCOMP FISH P Wash down 2 jts // 50 spm // Up wt. 175K Dn wt. 78K // Tag fish 8757' 7K WOB // Pick up 8741' to circulate B/U 8,700.0 8,741.0 1/20/2023 02:00 1/20/2023 03:00 1.00 COMPZN, RPCOMP CIRC P Circulate B/U @ 5 bpm 2500psi MW in 14.4+ MW out 14.4+ 8,741.0 8,741.0 1/20/2023 03:00 1/20/2023 03:30 0.50 COMPZN, RPCOMP FISH P PU wt 175K Dn wt 78K // Tag fish 8757' , pu rotate over fish 30rpm @ 9800 ft/lbs trorque // Overshot fish 8' T/ 8765'/ Pick up 195K fish engaged // PU T/ 235K Jar on lower completion 8,741.0 8,765.0 1/20/2023 03:30 1/20/2023 03:45 0.25 COMPZN, RPCOMP JAR P Jar on fish 4 times // fish move up hole 191K 8,765.0 8,738.0 1/20/2023 03:45 1/20/2023 05:45 2.00 COMPZN, RPCOMP CIRC P Cir B/U 4000stks // Circulate 3 bpm @ 1325 psi // MW in 14.4+ MW out 14.5. Pump Dry Job. 8,738.0 8,738.0 1/20/2023 05:45 1/20/2023 10:15 4.50 COMPZN, RPCOMP TRIP P TOOH f/8738' PU WT 185K 8,738.0 323.0 1/20/2023 10:15 1/20/2023 12:15 2.00 COMPZN, RPCOMP BHAH P Standback Drill Collars and L/D BHA. Recovered Top of cut TBG Section, patch, CT tools and seal Assy. 323.0 0.0 1/20/2023 12:15 1/20/2023 15:00 2.75 COMPZN, RPCOMP PULL P Start Cutting TBG, CT Tools and Patch from Completion Sting. Three Layers of Equipment, very difficult to remove. Total Tool Lenght: 88.65' 0.0 0.0 1/20/2023 15:00 1/20/2023 15:30 0.50 COMPZN, RPCOMP SVRG P Rig Service 0.0 0.0 1/20/2023 15:30 1/20/2023 16:15 0.75 COMPZN, RPCOMP BHAH P RU BHA #6, spear assembly for HB Baker Packer. 0.0 322.0 1/20/2023 16:15 1/20/2023 17:15 1.00 COMPZN, RPCOMP TRIP P TIH w/BHA #6 322.0 3,000.0 1/20/2023 17:15 1/20/2023 18:15 1.00 COMPZN, RPCOMP CIRC P Circulate to ensure circ port on spear clear // well not ballanced flowing up pipe circ 15# mud out of hole 3,000.0 3,000.0 1/20/2023 18:15 1/20/2023 19:30 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA # 6 3,000.0 6,000.0 1/20/2023 19:30 1/20/2023 20:15 0.75 COMPZN, RPCOMP CIRC P Circulate to ensure circ port on sper clear 6,000.0 6,000.0 1/20/2023 20:15 1/20/2023 21:30 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA# 6 6,000.0 8,700.0 1/20/2023 21:30 1/20/2023 23:00 1.50 COMPZN, RPCOMP WASH P Wash down to fish // Up wt. 180K Dn wt. 80K // Pump 65spm 1750psi // 14.4+ in 14.5+ out // Wash down final five jts pipe and bottoms up prior to engaging fish 8,700.0 8,835.0 1/20/2023 23:00 1/21/2023 00:00 1.00 COMPZN, RPCOMP FISH P Tag fish @ 8839' set down 5K @ 8840' // Start Jarring ops // Jar Hits = 10 total 8,835.0 8,835.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 6/13 3O-15 Report Printed: 2/27/2023 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) 1/21/2023 00:00 1/21/2023 05:00 5.00 COMPZN, RPCOMP JAR P Jarring operation on lower completion packer. 100 Jar Hits, PUW:180K / SOW: 75K 8,835.0 8,835.0 1/21/2023 05:00 1/21/2023 05:30 0.50 COMPZN, RPCOMP SVRG P Service Top Drive. Inspection from Fishing Ops. 8,835.0 8,835.0 1/21/2023 05:30 1/21/2023 10:15 4.75 COMPZN, RPCOMP JAR P Continue Jarring to shear Packer at 180K and 75K DN. 8,835.0 8,835.0 1/21/2023 10:15 1/21/2023 11:15 1.00 COMPZN, RPCOMP SVRG P Derrick Inspection. 8,835.0 8,835.0 1/21/2023 11:15 1/21/2023 12:00 0.75 COMPZN, RPCOMP JAR P Continue Jarring to shear Packer at 180K and 75K DN. 8,835.0 8,835.0 1/21/2023 12:00 1/21/2023 13:00 1.00 COMPZN, RPCOMP CIRC P Circulate dry Job. 215 Jar Hits and no movement, release from Packer. 8,835.0 8,835.0 1/21/2023 13:00 1/21/2023 16:45 3.75 COMPZN, RPCOMP TRIP P TOOH w/Fishing Assy. 8,835.0 323.0 1/21/2023 16:45 1/21/2023 17:45 1.00 COMPZN, RPCOMP BHAH P Standback Drill Collars and L/D Fishing BHA. 323.0 0.0 1/21/2023 17:45 1/21/2023 19:45 2.00 COMPZN, RPCOMP WAIT P Wait on burn shoe for BHA# 7 0.0 0.0 1/21/2023 19:45 1/21/2023 21:15 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 7 Burn Shoe 0.0 360.0 1/21/2023 21:15 1/22/2023 00:00 2.75 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 7 360.0 8,000.0 1/22/2023 00:00 1/22/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 7 8,000.0 8,800.0 1/22/2023 00:30 1/22/2023 06:00 5.50 COMPZN, RPCOMP MILL P Kelly up circulate fluid // Tag fish 8833.8' // Up wt. 155K Dn Wt 80K // ROT 50rpm Trq 9500 ft/lbs// Up Wt 150K Dn wt 100K // Attempt to Burn over packer F/ 8832' will no success. 8,838.0 8,832.0 1/22/2023 06:00 1/22/2023 10:00 4.00 COMPZN, RPCOMP TRIP P Circulate Dry Job. TOOH to inspect and change BHA if needed. 8,832.0 362.0 1/22/2023 10:00 1/22/2023 11:30 1.50 COMPZN, RPCOMP BHAH P Standback Drill Collars. L/D Washpipe and 6-1/8" OD Shoe Assy. Recovered 1.5" Wide x 6" Long piece of metal from the shoe. 362.0 0.0 1/22/2023 11:30 1/22/2023 12:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 0.0 1/22/2023 12:00 1/22/2023 12:45 0.75 COMPZN, RPCOMP BHAH P PU/MU 6-1/8" OD Junk Mill Assy. 0.0 326.0 1/22/2023 12:45 1/22/2023 16:45 4.00 COMPZN, RPCOMP TRIP P TIH w/BHA #8 to top of PBR on drill pipe. 326.0 8,834.0 1/22/2023 16:45 1/22/2023 20:00 3.25 COMPZN, RPCOMP MILL P RU Blower hose. Tag top of PBR @ 8834' // Up wt. 188K Dn Wt 84K // ROT 50rpm Trq 9500 ft/lbs. Circulating rate 3 bpm, 1780 psi. RPM 68, 9.8K Torque. 5- 8K WOB // Mill T/ 8835.50' abrupt mill off moved 1' ( max depth 8835.5 ) unable to make progress, 16K wob w/ 9500 - 10000 torq// decision made TOOH check tools 8,834.0 8,835.5 1/22/2023 20:00 1/23/2023 00:00 4.00 COMPZN, RPCOMP TRIP P Circulate Dry Job , TOOH inspect tools 8,835.5 1,700.0 1/23/2023 00:00 1/23/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Trip out of hole with junk mill 1,700.0 362.0 1/23/2023 00:30 1/23/2023 01:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA #8 junk mill and inspect // Mill shows wear from PBR // OD junk mill 6-1/8" full gauge // ~ 4" X 1" thin metal shaving found in junk basket // Continue laying down BHA 362.0 0.0 1/23/2023 01:30 1/23/2023 02:45 1.25 COMPZN, RPCOMP BHAH P Pick up BHA #9 burn shoe 0.0 362.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 7/13 3O-15 Report Printed: 2/27/2023 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) 1/23/2023 02:45 1/23/2023 05:45 3.00 COMPZN, RPCOMP TRIP P TIH w/ Burn shoe BHA on drill pipe 362.0 7,345.0 1/23/2023 05:45 1/23/2023 08:15 2.50 COMPZN, RPCOMP SLPC P Slip & Cut Drilling Line. Cut a total of 88 feet of drilling line. 7,345.0 7,345.0 1/23/2023 08:15 1/23/2023 09:15 1.00 COMPZN, RPCOMP TRIP P Continue to TIH with Burn shoe BHA on Drill Pipe. 7,345.0 8,814.0 1/23/2023 09:15 1/23/2023 14:15 5.00 COMPZN, RPCOMP MILL P Kelly up and RU Blower hose @ 8814'. Tag top of PBR @ 8835.3' // Up wt 185K Dn Wt 82K // ROT 62 rpm, Free Trq 10,200 ft/lbs. Pumping @ 3 bpm, 1550 psi. 3-5k WOB. No footage made. 8,814.0 8,835.0 1/23/2023 14:15 1/23/2023 18:00 3.75 COMPZN, RPCOMP TRIP P Pump 15 bbls of 16.8 ppg Dry Job. Blow down Top Drive. TOOH w/BHA #9. 8,835.0 362.0 1/23/2023 18:00 1/23/2023 18:30 0.50 COMPZN, RPCOMP SFTY P Well Control Drill - Kick While Tripping. 1,800.0 1,800.0 1/23/2023 18:30 1/23/2023 19:30 1.00 COMPZN, RPCOMP TRIP P Cont. TOOH with BHA #9. 1,800.0 362.0 1/23/2023 19:30 1/23/2023 20:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA # 9 - 4 7/8" ID Burn Shoe. 362.0 0.0 1/23/2023 20:00 1/23/2023 20:45 0.75 COMPZN, RPCOMP BHAH P PU BHA #10 - 5 1/8" ID Burn Shoe w/ float in bit sub. 0.0 365.0 1/23/2023 20:45 1/24/2023 00:00 3.25 COMPZN, RPCOMP TRIP P TIH with BHA #10 on Drill Pipe 365.0 8,200.0 1/24/2023 00:00 1/24/2023 00:15 0.25 COMPZN, RPCOMP TRIP P Trip in hole with burn over shoe //6-1/8" OD 5-1/8" ID wavy bottom burn shoe 8,200.0 8,830.0 1/24/2023 00:15 1/24/2023 05:15 5.00 COMPZN, RPCOMP MILL P Install blower hose // Kelly up start pumping // Mill over packer to slips // Pump 62 spm 1575 psi // Up wt 160K SO wt 80K ( Not rotating) // Tag fish 8834' pick up // Rot 11rpm 8000 trq PU wt 155K SO 875K Tag fish 8833' // PU ROT 55rpm 10500' trq SO wt 105K Pump rate 51 spm @ 1475psi// Mill F/ 8833.8' Stack 17K WOB Torque 9500 - 10500 @ 8834.92' Mill till 04:10 break through continue to burn down to slips @ 8847.5' Picking up singles 8,830.0 8,847.5 1/24/2023 05:15 1/24/2023 12:15 7.00 COMPZN, RPCOMP TRIP P Circ bottoms up // blow down TD remove blower hose // TOOH w/ BHA# 10 8,847.5 362.0 1/24/2023 12:15 1/24/2023 13:45 1.50 COMPZN, RPCOMP BHAH P LD BHA F/362' T/Burn shoe. Inspect burn shoe for signs of wear. 362.0 0.0 1/24/2023 13:45 1/24/2023 15:15 1.50 COMPZN, RPCOMP BHAH P MU BHA #11 Spear, BS, O.J., pump out sub, 9 collars, and accelerator 0.0 321.9 1/24/2023 15:15 1/24/2023 18:45 3.50 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 11 321.9 8,830.0 1/24/2023 18:45 1/24/2023 19:00 0.25 COMPZN, RPCOMP FISH P PU wt 185K SO wt 80K // Spear fish ng 8835.5' // PU 200K fish engaged 8,830.0 8,835.5 1/24/2023 19:00 1/24/2023 22:30 3.50 COMPZN, RPCOMP JAR P Jar on fish no movement 8,835.5 8,835.0 1/24/2023 22:30 1/24/2023 23:15 0.75 COMPZN, RPCOMP OTHR P Inspect derrick 8,835.0 8,835.0 1/24/2023 23:15 1/25/2023 00:00 0.75 COMPZN, RPCOMP JAR P Jar on fish 8,835.0 8,835.0 1/25/2023 00:00 1/25/2023 03:00 3.00 COMPZN, RPCOMP JAR P Jar on fish 177 total hits no movement 8,835.0 8,835.0 1/25/2023 03:00 1/25/2023 03:30 0.50 COMPZN, RPCOMP OTHR P Inspect mast and TD during jarring operations 8,835.0 8,835.0 1/25/2023 03:30 1/25/2023 09:00 5.50 COMPZN, RPCOMP TRIP P Release Spear // Circ and pump dry job // TOOH for burn shoe 8,835.0 362.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 8/13 3O-15 Report Printed: 2/27/2023 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) 1/25/2023 09:00 1/25/2023 11:15 2.25 COMPZN, RPCOMP BHAH P LD BHA #11 inspect spear. MU BHA #12 4,75" ID burn shoe 362.0 362.7 1/25/2023 11:15 1/25/2023 12:00 0.75 COMPZN, RPCOMP SVRG P Service top drive 362.7 362.7 1/25/2023 12:00 1/25/2023 16:30 4.50 COMPZN, RPCOMP TRIP P TIH F/362.7' T/8819' 362.7 8,845.0 1/25/2023 16:30 1/26/2023 00:00 7.50 COMPZN, RPCOMP MILL P Establish milling parmeters PUW=171K, SOW=73K PR=3BPM 1500 PSI 60 RPM Free Tq.=10.4K Over top of PBR at 8835' slight bobble RIH to 8847' top of packer Set down 7K-10K Mill ahead stall @ 8848.33' PU re- establish perameters continue milling 8,845.0 8,847.0 1/26/2023 00:00 1/26/2023 06:00 6.00 COMPZN, RPCOMP MILL P Continue milling packer T/8850' 8,847.0 8,847.0 1/26/2023 06:00 1/26/2023 06:15 0.25 COMPZN, RPCOMP SIPB P Well flowed back 5 BBL's. Gas at flow line, Shut in anular. Observe casing pressure built up to 30 PSI. Line up to pump taking returns through the choke to the gas buster back to the pits. 8,835.0 8,835.0 1/26/2023 06:15 1/26/2023 11:00 4.75 COMPZN, RPCOMP CIRC P Circulate 2 BPM 14.4# LSND down DP taking returns to pits through gas buster. ICP=1100 PSI SBS DP at 1040 PSI maintain 1040 on DP Continue to circulate SxS stroke 14.5# in 14.4# out Contiue to circulate second SxS at 2 BPM till 14.4# in and out. 8,835.0 8,835.0 1/26/2023 11:00 1/26/2023 11:15 0.25 COMPZN, RPCOMP OWFF P Shut down pump open annular blow down choke line OWFF for 15 minutes. 0 flow and flowline. 8,835.0 8,835.0 1/26/2023 11:15 1/26/2023 21:15 10.00 COMPZN, RPCOMP MILL P Circulate down DP at 2 BPM establish milling parameters. PUW=185K, SOW=80K, ROT WT=105K, 60-75 RPM 10.4K free tq. 3BPM 1480 PSI. Mill down F/8847.7' 10K Down 8,835.0 8,847.0 1/26/2023 21:15 1/27/2023 00:00 2.75 COMPZN, RPCOMP TRIP P Circ B/U // Pump Dry Job // TOOH for new burn shoe 8,847.0 5,500.0 1/27/2023 00:00 1/27/2023 01:30 1.50 COMPZN, RPCOMP TRIP P Trip out of hole for new burn shoe 5,500.0 632.0 1/27/2023 01:30 1/27/2023 02:15 0.75 COMPZN, RPCOMP BHAH P Rack collars // lay down burn shoe 632.0 0.0 1/27/2023 02:15 1/27/2023 03:00 0.75 COMPZN, RPCOMP BHAH P Pick up burn shoe // RIH w/ collars 0.0 632.0 1/27/2023 03:00 1/27/2023 06:00 3.00 COMPZN, RPCOMP TRIP P TIH F/632 T/ 8847' 632.0 8,847.0 1/27/2023 06:00 1/27/2023 06:30 0.50 COMPZN, RPCOMP SVRG P Rig service drawworks 8,847.0 8,847.0 1/27/2023 06:30 1/27/2023 23:30 17.00 COMPZN, RPCOMP MILL P Establish milling parameters 3 BPM 1100 PSI Rot Wt.= 120K PUW=135K SOW=75K start milling on packer 8,847.0 8,848.0 1/27/2023 23:30 1/28/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 8,848.0 8,848.0 1/28/2023 00:00 1/28/2023 04:30 4.50 COMPZN, RPCOMP MILL P Continue milling packer unable to mill through packer OD with multiple changes to PR, weight on bit, and RPM. PUH to 8778 8,848.0 8,778.0 1/28/2023 04:30 1/28/2023 06:00 1.50 COMPZN, RPCOMP CIRC P Condition well Circ BUS 4.5 BPM 2000 PSI pump dry job 8,778.0 8,778.0 1/28/2023 06:00 1/28/2023 08:30 2.50 COMPZN, RPCOMP SLPC P Slip and cut drill line. 8,778.0 8,778.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 9/13 3O-15 Report Printed: 2/27/2023 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) 1/28/2023 08:30 1/28/2023 09:00 0.50 COMPZN, RPCOMP SFTY P Perform DROPS inspection on derrick 8,778.0 8,778.0 1/28/2023 09:00 1/28/2023 09:30 0.50 COMPZN, RPCOMP SVRG P Service top drive Change out die blocks 8,778.0 8,778.0 1/28/2023 09:30 1/28/2023 12:00 2.50 COMPZN, RPCOMP TRIP P Start TOOH F/8778 T/ 632' 8,778.0 336.0 1/28/2023 12:00 1/28/2023 14:30 2.50 COMPZN, RPCOMP BHAH P LD BHA #13 PU BHA #14 336.0 336.0 1/28/2023 14:30 1/28/2023 17:30 3.00 COMPZN, RPCOMP TRIP P TIH F/8336 T/8800 336.0 8,800.0 1/28/2023 17:30 1/28/2023 20:15 2.75 COMPZN, RPCOMP MILL P Get perameters // 35spm 1100 psi So Wt. 84K Pu Wt. 175K ROT 52rpm @ 10,200 ft/lbs // Tag PBR @ 8835' // Dress top of PBR , while rotating packer moved down hole T/ 8841.5' top of PBR , while rotating continues to move down hole slowly, not rotating stack 10K WOB no movement 8,800.0 8,842.0 1/28/2023 20:15 1/28/2023 21:00 0.75 COMPZN, RPCOMP CIRC P Circ bottoms up for trip out of hole 8,842.0 8,835.0 1/28/2023 21:00 1/28/2023 23:30 2.50 COMPZN, RPCOMP TRIP P TOOH for test packer 8,835.0 3,900.0 1/28/2023 23:30 1/29/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Rig service grease blocks and topdrive 3,900.0 3,900.0 1/29/2023 00:00 1/29/2023 01:30 1.50 COMPZN, RPCOMP TRIP P Trip out of hole for test packer 3,900.0 362.0 1/29/2023 01:30 1/29/2023 03:15 1.75 COMPZN, RPCOMP BHAH P Break down and lay down BHA // Break down tools send to pipe shed // Chunks of metal in boot basket 1" wide 3" long 362.0 0.0 1/29/2023 03:15 1/29/2023 04:15 1.00 COMPZN, RPCOMP BHAH P Pick up test packer BHA 0.0 296.0 1/29/2023 04:15 1/29/2023 09:00 4.75 COMPZN, RPCOMP TRIP P Trip in hole with test packer T/8807' 296.0 8,807.0 1/29/2023 09:00 1/29/2023 11:00 2.00 COMPZN, RPCOMP CIRC P Ciculate and condition hole. Prepare to test casing. Close in pipe rams, flood kill line. 8,807.0 8,807.0 1/29/2023 11:00 1/29/2023 11:30 0.50 COMPZN, RPCOMP MPSP P Set test packer at 8807', COE @ 8803'. Pressure test casing to 500 PSI. for 30 minutes 8,807.0 8,807.0 1/29/2023 11:30 1/29/2023 12:15 0.75 COMPZN, RPCOMP SFTY P Hold prejob safety meeting to lay down 1 joint of drill pipe. 8,807.0 8,807.0 1/29/2023 12:15 1/29/2023 13:15 1.00 COMPZN, RPCOMP PULD P Clear Ice plug from kill line following saftey meeting to lay down one joint of DP. Release test packer RIH 3' past set depth to 8810'. LD one joint of drill pipe. 8,807.0 8,771.0 1/29/2023 13:15 1/29/2023 16:30 3.25 COMPZN, RPCOMP TRIP P TOOH F/8771' T/295' PUW=190K. 8,870.0 295.0 1/29/2023 16:30 1/29/2023 17:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA 295.0 0.0 1/29/2023 17:00 1/29/2023 18:30 1.50 COMPZN, RPCOMP BHAH P Pick up overshot BHA 0.0 300.0 1/29/2023 18:30 1/29/2023 21:00 2.50 COMPZN, RPCOMP TRIP P Trip in hole with overshot // BOP drill while tripping pipe reaction time XXX sec 300.0 3,064.0 1/29/2023 21:00 1/29/2023 22:00 1.00 COMPZN, RPCOMP SVRG P Adjust high and low drum clutch for propper operation 3,064.0 3,064.0 1/29/2023 22:00 1/30/2023 00:00 2.00 COMPZN, RPCOMP TRIP P Trip in hole with overshot 3,064.0 7,200.0 1/30/2023 00:00 1/30/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Trip in hole with overshot 7,200.0 8,820.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 10/13 3O-15 Report Printed: 2/27/2023 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) 1/30/2023 00:30 1/30/2023 02:00 1.50 COMPZN, RPCOMP FISH P Latch onto fish @ 8841' // SO wt. 80K Pu wt. 165K // Tag fish @ 8840' work down to 8843' // Pump rate 36 spm 1090 psi // unable to grab fish 8,820.0 8,841.0 1/30/2023 02:00 1/30/2023 03:30 1.50 COMPZN, RPCOMP CIRC P Circulate BUS. Pump dry job. 8,841.0 8,841.0 1/30/2023 03:30 1/30/2023 08:00 4.50 COMPZN, RPCOMP TRIP P TOOH F/8841' T/320' 8,841.0 362.0 1/30/2023 08:00 1/30/2023 09:00 1.00 COMPZN, RPCOMP BHAH P LD BHA #16. 362.0 0.0 1/30/2023 09:00 1/30/2023 10:30 1.50 COMPZN, WHDBOP RURD P Clear floor, set up to test BOP. Empty stack, pull bowl protector, MU safety valve and IBOP to test joint, set test plug. 0.0 0.0 1/30/2023 10:30 1/30/2023 11:30 1.00 COMPZN, WHDBOP BOPE P Fill stack with water purge air out of surface lines line up to start testing. 0.0 0.0 1/30/2023 11:30 1/30/2023 19:00 7.50 COMPZN, WHDBOP BOPE P BOPE test, Tested BOPE at 250/4000 PSI for 5 Min each, Test annular 250/2500 on 3-1/2" test joint. Tested, UVBR's and LPR on 3-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 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=1450 PSI, 200 PSI attained =14 sec, full recovery attained =110 sec. UVBR's= 5 sec, LVBR's= 6 sec. Annular= 28 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1996 PSI. Witness waived by AOGCC rep Brian Bixby. 0.0 0.0 1/30/2023 19:00 1/30/2023 20:00 1.00 COMPZN, RPCOMP SVRG P Adjust DW throttle and check brushes 0.0 0.0 1/30/2023 20:00 1/30/2023 21:00 1.00 COMPZN, RPCOMP OTHR P Remove plug and install wear ring 0.0 0.0 1/30/2023 21:00 1/30/2023 22:00 1.00 COMPZN, RPCOMP BHAH P Pick up spear bha 0.0 362.0 1/30/2023 22:00 1/31/2023 00:00 2.00 COMPZN, RPCOMP TRIP P Trip in hole with spear 362.0 4,500.0 1/31/2023 00:00 1/31/2023 01:30 1.50 COMPZN, RPCOMP TRIP P TIH w/ spear 4,500.0 8,771.0 1/31/2023 01:30 1/31/2023 02:15 0.75 COMPZN, RPCOMP FISH P Attempt to engage fish @ 8841' top of fish // PU wt. 165K SO wt. 80K Pump 52spm @ 1477psi // pass through top of fish @ 8841' NG out @ 8846.7' ( 5.7' swallow with spear ) , PU 200K set down T/ 75K fish popped free move down to 8848' // PU T 8799' w/ 5-10K wt bobbles ( overpull ) , stop to circulate B/U Fish on 8,771.0 8,799.0 1/31/2023 02:15 1/31/2023 04:00 1.75 COMPZN, RPCOMP CIRC P Circulate B/U planned shut in of annular to control any gas from under packer 8,799.0 8,799.0 1/31/2023 04:00 1/31/2023 08:30 4.50 COMPZN, RPCOMP TRIP P Start TOOH F/8799' PUW=168K T/362 8,799.0 362.0 1/31/2023 08:30 1/31/2023 11:30 3.00 COMPZN, RPCOMP BHAH P LD BHA #17 PBR, packer and tail pipe recovered. PU BHA #18 Clean out BHA 362.0 330.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 11/13 3O-15 Report Printed: 2/27/2023 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) 1/31/2023 11:30 1/31/2023 16:00 4.50 COMPZN, RPCOMP TRIP P TIH F/330 T/8742' 330.0 8,742.0 1/31/2023 16:00 1/31/2023 17:00 1.00 COMPZN, RPCOMP SVRG P Service draworks 8,742.0 8,742.0 1/31/2023 17:00 1/31/2023 19:00 2.00 COMPZN, RPCOMP CIRC P Ciculate BUS condition well @ 3 BPM, 1150 PSI. 8,742.0 8,742.0 1/31/2023 19:00 2/1/2023 00:00 5.00 COMPZN, RPCOMP RGRP T Attempting to remove drum clutch hub from shaft. Circulating to keep fluid moving @ 3 BPM, 1150 PSI. 8,742.0 8,742.0 2/1/2023 00:00 2/1/2023 18:00 18.00 COMPZN, RPCOMP RGRP T Remove drum clutch hub from shaft. Circulating to keep fluid moving @ 3 BPM, 1150 PSI. 8,742.0 8,742.0 2/1/2023 18:00 2/2/2023 00:00 6.00 COMPZN, RPCOMP RGRP T Install new drum clutch hub on shaft. Circulating to keep fluid moving @ 3 BPM, 1350 PSI. 8,742.0 8,742.0 2/2/2023 00:00 2/2/2023 02:30 2.50 COMPZN, RPCOMP RGRP T Install new drum clutch. B/D TD. Run blocks up and down in hi and low gear. Clutch is functional. 8,742.0 8,742.0 2/2/2023 02:30 2/2/2023 08:30 6.00 COMPZN, RPCOMP REAM P R/U blower hose. P/U T/ 8687'. Obtain parameters. PUW=180K, SOW=80K. Pump @ 5 BPM, 2580 PSI. Rotate @ 50 RPM, 9.5K Free Tq. ROT=105K. Wash & ream down T/ 8782' and back upT/ 8678'. Wash in hole T/ 8845''. Wash & ream through perf zone F/ 8845' T/ 9190'. Slight work starting @ 8985'. More extensive work through perfs 10.5-11K Tq. 5K WOB. 8,742.0 9,190.0 2/2/2023 08:30 2/2/2023 09:45 1.25 COMPZN, RPCOMP CIRC P Circ BU @ 5 BPM, 2580 PSI. Pump 20 Bbls dry job. 9,190.0 9,190.0 2/2/2023 09:45 2/2/2023 10:00 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. 9,190.0 9,190.0 2/2/2023 10:00 2/2/2023 16:45 6.75 COMPZN, RPCOMP TRIP P LDDP F/ 9190' T/ 320'. PUW=185K 9,190.0 320.0 2/2/2023 16:45 2/2/2023 19:00 2.25 COMPZN, RPCOMP BHAH P L/D BHA #18 R/ 320' T/ surface. PUW=45K. 320.0 0.0 2/2/2023 19:00 2/2/2023 20:00 1.00 COMPZN, RPCOMP RURD P Clean and clear RF and pipe shed. 0.0 0.0 2/2/2023 20:00 2/2/2023 20:30 0.50 COMPZN, RPCOMP CLEN P Pull wear bushing 0.0 0.0 2/2/2023 20:30 2/2/2023 21:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 2/2/2023 21:00 2/2/2023 21:45 0.75 COMPZN, RPCOMP RURD P R/U tubing handling equipment. Verify joint count and jewelry running order. 0.0 0.0 2/2/2023 21:45 2/2/2023 22:15 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES and rig on running 3 1/2" EUE-M completion string, 0.0 0.0 2/2/2023 22:15 2/3/2023 00:00 1.75 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M completion T/ 1025'. SOW-35K. EUE-M torqued T/ 2250 Ft/lbs. Jet lube seal guard dope used. 0.0 1,025.0 2/3/2023 00:00 2/3/2023 03:00 3.00 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M completion F/ 1025' T/ 3481'. SOW=42K. EUE-M torqued T/ 2250 Ft/lbs. Jet lube seal guard dope used. 1,025.0 3,481.0 2/3/2023 03:00 2/3/2023 03:15 0.25 COMPZN, RPCOMP SFTY P Crew change out. PJSM w/ rig crew on running 3 1/2" EUE-M completion. 3,481.0 3,481.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 12/13 3O-15 Report Printed: 2/27/2023 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) 2/3/2023 03:15 2/3/2023 09:45 6.50 COMPZN, RPCOMP RCST P RIH w/ 3 1/2", 9.3#, L-80, EUE-M completion F/ 3481' T/ 8741'. SOW=53K. EUE-M torqued T/ 2250 Ft/lbs. Jet lube seal guard dope used. Final weights 95K PU. 65 SOW. 3,481.0 8,741.0 2/3/2023 09:45 2/3/2023 11:00 1.25 COMPZN, RPCOMP PULD P M/U tubing hanger to landing joint. M/U to tubing string. Land tubing hanger with BPV installed. Visually verify landing via annulas valve. Line up on annulas. Bottom of WLEG @ 8777.05' ORKB. 8,741.0 8,777.1 2/3/2023 11:00 2/3/2023 11:30 0.50 COMPZN, RPCOMP SVRG P Service rig. 8,777.1 8,777.1 2/3/2023 11:30 2/3/2023 12:00 0.50 COMPZN, RPCOMP PRTS P Test BPV. 500 PSI / 10 minutes - GOOD. Back out landing joint 8,777.1 8,777.1 2/3/2023 12:00 2/3/2023 13:00 1.00 COMPZN, WHDBOP RURD P R/D tubing handling equipment. 2/3/2023 13:00 2/3/2023 19:00 6.00 COMPZN, WHDBOP CLEN P Clean rig floor,flush surface lines pumps and circulating system, Johnny whack the BOP stack. Pull rotary table covers and begin cleaning under rotarty table with super sucker. 2/3/2023 19:00 2/3/2023 19:30 0.50 COMPZN, WHDBOP SVRG P Service rig 2/3/2023 19:30 2/3/2023 21:00 1.50 COMPZN, WHDBOP NUND P N/D BOP. 2/3/2023 21:00 2/3/2023 22:00 1.00 COMPZN, WHDBOP NUND P Install tree test dart. N/U adaptor spool and tree. Add lubricator extensions to top of tree. 2/3/2023 22:00 2/3/2023 22:15 0.25 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min - Good test. 2/3/2023 22:15 2/3/2023 23:15 1.00 COMPZN, WHDBOP RURD P R/U circ manifold in cellar. Blow air through choke hose and into open top tank and tiger tank. Spot LRS and 2 vac trucks w/ CI NaCl. R/U LRS to circ manifold. 2/3/2023 23:15 2/3/2023 23:45 0.50 COMPZN, WHDBOP PRTS P LRS PT tree T/ 5000 PSI. 2/3/2023 23:45 2/4/2023 00:00 0.25 COMPZN, WHDBOP MPSP P Pull tree test dart & BPV. 2/4/2023 00:00 2/4/2023 01:00 1.00 COMPZN, WHDBOP PRTS P PT tiger tank line T/ 4000 PSI. 0.0 0.0 2/4/2023 01:00 2/4/2023 05:30 4.50 COMPZN, WHDBOP CRIH P LRS pump 10 Bbls 90* diesel through choke house to tiger tank to warm up lines. LRS Circulate out 14.4# LSND with 400 Bbls 10.5# CI NaBr down IA taking returns to 400 Bbls open top tank @ 2 BPM reducing T/ 1.5 BPM. Increasing back pressure in choke house to 1300 PSI. 10.5 PPG returns at surface. FCP TBG=1300, IA=1400. Draw down test, bled IA T/ 1000 PSI. Pressure increased T/ 1050 PSI. 0.0 0.0 2/4/2023 05:30 2/4/2023 05:42 0.20 COMPZN, WHDBOP RURD P Drop ball and rod for packer set. Line up LRS down tubing. Line up chart to IA and tubing 0.0 0.0 2/4/2023 05:42 2/4/2023 06:12 0.50 COMPZN, WHDBOP PRTS P Bring LRS online down tubing. 4625 Tubing,, IA=1500 PSI. Hold and PT tubing for 30 Min. Good test FTP=4625, FIA=1500 0.0 0.0 2/4/2023 06:12 2/4/2023 07:00 0.80 COMPZN, WHDBOP RURD P Bleed off tubing to 1500 PSI. Line up down IA. Pressure up to 2500 PSI 0.0 0.0 2/4/2023 07:00 2/4/2023 07:30 0.50 COMPZN, WHDBOP PRTS P 30 Min PT IA @ 2500 PSI- Good chart 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 Page 13/13 3O-15 Report Printed: 2/27/2023 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) 2/4/2023 07:30 2/4/2023 08:30 1.00 COMPZN, WHDBOP FRZP P Bleed down tubing pressure.See SOV shear. T=450 PSI, IA=450 PSI. Line up LRS down IA returns up tubing. Circ in 71 BBls diesel freeze protect@ 2 BPM, ICP=1200, FCP=1500, holding 800 PSI back pressure at choke house. 0.0 0.0 2/4/2023 08:30 2/4/2023 10:30 2.00 COMPZN, WHDBOP FRZP P Place TBG & IA in communication, U tube well. B/D, R/D circ manifold and tiger tank lines. Final pressures TBG=1050, IA=1325, OA=0. Off Hi Line 10:00 0.0 0.0 2/4/2023 10:30 2/4/2023 12:00 1.50 DEMOB, MOVE DMOB P Clean and secure tree. Continue cleaning pits and rotary table. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/4/2023 DTTMSTART JOBTYP SUMMARYOPS 10/26/2022 ANNCOMM MOVE FROM 1J, SPOT CTU AND R/U. P/U FISHING BHA WITH UP/DOWN JARS, TEMPRESS TOOL & WEIGHT BARS, TOTAL LENGTH = 30.52'. RI DOWN TO TOP OF FISH @ 8762' CTMD. BEGIN JARRING X 20 HITS BOTH DIRECTION. START PUMPING 1 BPM TO ENGAGE TEMPRESS TOOL, UP DIRECTION FOR 20 MINS, DOWN DIRECTION FOR 20 MIN. CONTINUE JARRING. JOB ONGOING. 10/27/2022 ANNCOMM PUMPED OFF FISH POOH AND CUT 250' OF COIL LATCH BACK UP TO FISH JARRED 56 TIMES PUMPED OFF POOH TO CUT PIPE 50 FT. RIH ATTEMPT TO JAR AND TEMPRESS UP/DOWN AT THE SAME TIME. ADDITIONAL 60 JAR HITS. NO LUCK. FREEZE PROTECT WELL. DIESEL IN IA & TUBING. 10/28/2022 ANNCOMM CONTINUE TO POOH WITH CT FREEZE PROTECTING WITH SD. CLOSE SWAB VALVES, LAY DOWN FISHING TOOLS, CHANGE PACK OFFS, RDMO TO 3B PAD. CONTACT DSO. 11/18/2022 SUPPORT OTHER OPERATIONS (PRE RWO) FT LDS/GN'S, T POT (PASS) T PPPOT (PASS), IC POT (PASS) 12/18/2022 SUPPORT OTHER OPERATIONS TAG FISH @ 8792' RKB & MEASURE BHP (4502 PSI) @ 8730' RKB; DEPLOYED AVA CATCHER & PULLED VINTAGE 1988 DV @ 8308' RKB (LEFT POCKET OPEN); SET DV @ 7849' RKB & PULLED CATCHER @ 8792' RKB; DRIFT W/ 2.34" GAUGE RING & TAG NO-GO ON TRSSSV @ 1786' RKB. READY FOR E-LINE. 12/19/2022 ACQUIRE DATA (PRE-RWO) BLEED OA FOR DDT (IN-PROGRESS) 12/20/2022 ACQUIRE DATA (PRE-RWO) BLEED OA FOR DDT (COMPLETE) OA-DDT (PASSED) 12/29/2022 SUPPORT OTHER OPERATIONS CUT 2-7/8" TBG W/ 1-11/16'' RCT @ 8778.1' RKB CCL TO CUTTER = 14.1', CCL STOP DEPTH = 8764' RKB, CORRELATED TO TBG TALLY DATED 11-5-1988, JOB IS READY FOR SL. 12/31/2022 SUPPORT OTHER OPERATIONS DRIFT TBG W/ 2.31"G-RING ON FULL BORE WIRE BRUSH TO 1786'RKB. DRIFT 2.35" G-RING TO 1786'RKB. SET ISO SLEEVE IN SSSV @1786' RKB. JOB COMPLETE, READY FOR RIG. 1/14/2023 RECOMPLETION Bridal up. Lay over derrick. Pull pits away from sub. Pull sub off of well and stage on pad. Move and spot office and shop. Stage pits on pad. Clean up around well. Move sub to 3O pad. Load wellhead equipment in cellar and hang tree. Spot sub base and pits. Berming in rig. 1/15/2023 RECOMPLETION Continue berming in rig. Hook up interconnect and electrical to pits. Raise derrick. Bridling down. Offloading 14.5# KWF. Accept rig. Rig up circ manifold in cellar. Get measurements for riser height from tubing spool height. Gather initial T/IA/OA pressures. PT circ. manifold and tiger tank hard line to 4,000 psi. Pump 404 Bbls 14.4+ PPG kill mud around well taking returns to tiger tank and open top tank. 30 Min no flow check. Install HP BPV. Pressure test BPV from below. Nipple down tree. Inspect tubing hanger neck threads. Function LDS. Install tree test dart. Nipple up BOP. Testing BOPE w/ 2 7/8" test joint. 3O-15 RWO Operations 1/16/2023 RECOMPLETION Continue testing BOPE. Pull tree test dart and BPV. Rig up tubing handling equipment. Make up landing joint. BOLDS. Pull hanger to rig floor. Circulate well. Connect control line to spooling unit. Pull out of hole racking back or laying down completion to SSSV and lay down. Rig down spooling unit. Lay down completion to 2000'. Circulate well. 1/17/2023 RECOMPLETION Lay down completion to cut joint, 267 joints and 5.83' cut joint. Slightly flared cut. Clean and Clear rig floor. Make up BHA #1 RBP and run in hole on used 2 7/8" tubing to ~3500'. Set RBP and release. Pressure test RBP T/ 2000 PSI for 15 Min. Pull out of hole lay down 2 7/8" tubing. Run Storm packer and set top of packer 3814', test to 2000psi for 15min good test, Trip out of hole laying down 2-7/8" completion tubint, lay down bha# 1 setting tool for storm packer , strap collars for BHA# 2 1/18/2023 RECOMPLETION Nipple down BOPE, DSA and Old TBG Spool. 7" casing grew 5.5", spear casing pull 25K set slips in tension, cut 7-1/4" off casing for tubing spool, Process remaining drill pipe. Nipple up new Tubing spool and IC Packoffs. PT Packoffs to 3000 PSI for 15 Min. Install Test plug. Nipple up BOPE. Pressure test UPVRs and LVBR w/ 3 ½ IF test joint and stack break to 250/4000 psi. Pull test plug and install wearbushing ID 6-3/8" 1/19/2023 RECOMPLETION Pull upper storm packer, install wear bushing. Pick up RBP setting tool BHA, RIH picking up 3-1/2" DP, Pull RBP, Pick up overshot BHA run in on DP stands and singles, 1/20/2023 RECOMPLETION Overshot and pull remainder of upper completion, Trip out of hole stand back collars, cut and lay down completion Trip in hole with spear, wash down to top of fish @ 8839' , spear into fish start jarring operation 1/21/2023 RECOMPLETION Continued to jar on lower completion 215 jar hits total, perform inspections of topdrive and guards, trip out and lay down spear bha, pick up burn shoe BHA trip in hole 1/22/2023 RECOMPLETION Attempt to burn over packer, tag packer @ 8833.8 unable to make progress, TOOH inspect BHA found metal in Burn shoe ~ 1" wide 7.5" long 1/4" thick, TIH w/ junk mill, Mill PBR F/ 8833.5' T/ 8835.5, unable to make progress again.TOOH to inspect BHA. 1/23/2023 RECOMPLETION TOOH and L/D BHA #8 - Junk Mill. Wear marks on mill from top of PBR. PU BHA #9 - Burn Shoe. TIH. Slip and cut 88' of drilling line. Cont. TIH to 8.814'. Kelly up. Tag top of PBR @ 8,835.3'. ROT @ 62 RPM with pumps at 3 BPM. No footage made. Pump dry Job. TOOH to PU larger 5 1/8" ID burn shoe. 1/24/2023 RECOMPLETION Burn down over PBR w/ 5-1/8" ID burn shoe , TOOH pick up spear BHA, TIH spear into fish and start jarring ops 1/25/2023 RECOMPLETION Continue jarring on fish total hits 177 ( 7.5 hrs ) no movement, trip out of hole pick up burn shoe, trip in hole mill on packer 1/26/2023 RECOMPLETION Continued to burn over packer for 2' , circulate out packer gas after cutting elements, continue to mill on packer with limited progress, 6 hrs no progress decision made to TOOH for new burn shoe 1/27/2023 RECOMPLETION Complete trip out of hole, lay down and inspect burn shoe found cracked sections, pick up new burn shoe trip in hole, continue to mill on packer 1/28/2023 RECOMPLETION Continued to mill on packer with no success, TOOH for dressing assembly for PBR ( plan to run poor boy overshot ), TIH get perameters, start dressing PBR @ 8835', packer moved down hole while rotating T/ 8841' top of PBR, circulate B/U TOOH, perform rig service 1/29/2023 RECOMPLETION Confirm top of PBR @ 8841' , trip out of hole for test packer , lay down PBR dressing bha and inspect, no damage, pick up test packer BHA, trip in hole , set packer @ 8807' and test casing to 500psi 30min good test, trip out of hole with test packer, decision made to pick up over shot for fishing packer that moved down hole, lay down test packer pick up overshot bha trip in hole 1/30/2023 RECOMPLETION Attempt to over shot fish, set down on top of PBR, popped over and unable to grab with overshot w/ spiral grapple, TOOH standing back pipe in derrick, lay down bha and inspect, top of PBR found in overshot along with broke spiral grapple, rig up and test BOP's witness waived AOGCC Brian Bixby, pick up spear fishing assembly trip in hole to 4500' 1/31/2023 RECOMPLETION TOOH with PBR, packer and tail pipe. TIH with clean out assembly T/ 8742'. Problem identified with drum clutch. Circulate well @ 3 BPM while attempting to remove clutch hub from shaft. 2/1/2023 RECOMPLETION Remove drum clutch hub from shaft. Install new drum clutch hub on shaft. Begin installing new drum clutch, Circulating to keep fluid moving @ 3 BPM, 1350 PSI. 2/2/2023 RECOMPLETION Complete installing new drum clutch. Test clutch. Pick up T/ 8687'. Obtain parameters. Wash & ream down past perfs T/ 9190'. Circulate well. Pump dry job. Lay down drill pipe and BHA #18. Pull wear bushing. Verify joint count and jewelry running order. Rig up tubing handling equipment. Run in hole with 3 1/2" EUE-M completion as per tally T/ 1025' 2/3/2023 RECOMPLETION Continue run in hole with 3 1/2" EUE-M completion as per tally T/ 8741'. Make up hanger and landing joint. Land hanger with WLEG @ 8777.05'. RILDS. Test BPV from below. Clean rig floor. Pull rotary table covers and cleaning under rotary table with supper sucker. Nipple down BOP. Install tree test dart. Nipple up adaptor spool and tree with lubricator extensions. Rig up circ manifold in cellar. Blow down to open top and tiger tank. Spot LRS and 2 vac trucks with CI brine. Rig up LRS. Pressure test tree to 5000 PSI. Pull test dart and BPV. 2/4/2023 RECOMPLETION Pressure test tiger tank line to 4000 PSI. Pump 10 Bbls 90* diesel through hard line. LRS Displace 14.4 PPG LSND out of well with 10.5 PPG CI NaBr pumping down IA taking returns to open top tank. 10.5 PPG returns to surface. Final surface pressure 1050 PSI. Load ball and rod in tree. Launch ball and rod. LRS pressure up and set packer with 4650 PSI differential pressure. Test tubing T/ 4650 PSI for 30 Min. Test IA T/ 2500 PSI for 30 Min. Dump tubing pressure and shear out SOV. Establish circulation rate. LRS pump 71 Bbls diesel freeze protect down IA. U-tube well. Secure tree and cellar. Demob. 2/7/2023 SUPPORT OTHER OPERATIONS ATTEMPT TO SET CATCHER & INADVERTENTLY PULLED BALL n' ROD @ 8765' RKB; PULLED SOV & SET OV @ 8705' RKB; PULLED DV @ 7011' RKB. IN PROGRESS. 2/8/2023 SUPPORT OTHER OPERATIONS SET GLV @ 701' RKB; PULLED DV & SET GLV @ 3523' RKB (OBTAIN IA DDT); PULLED RHC PLUG BODY @ 8765' RKB & TAGGED TD W/ 2" BAILER @ 9167' RKB. JOB COMPLETE. 2/18/2023 PUMPING TRACKING ONLY PRESSURE TESTED FL TO 3000 PSI FREEZE PROTECT PUMPED 10 BBLS METH DWN FL Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 2' of fill) 9,167.0 3O-15 2/8/2023 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLD, Pulled RHC, & Tagged 3O-15 2/8/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: 12/1/2010 pproven 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 36.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 2,773.6 2,242.1 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 9,422.1 6,652.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.0 Set Depth 8,777.1 Set Depth 6,233.5 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.0 33.0 0.10 Hanger 7.100 Cameron 3.5" CXS Tubing Hanger Camero n CXS 2.950 497.0 496.0 9.50 Nipple - X 4.498 2.813" X-Nipple Halliburt on X 2.813 3,523.7 2,750.4 46.30 Mandrel GAS LIFT 5.870 3-1/2" x 1-1/2" MMG GLM SLB MMG 2.920 7,011.5 5,056.8 49.14 Mandrel GAS LIFT 5.900 3-1/2" x 1-1/2" MMG GLM SLB MMG 2.920 8,705.4 6,187.4 50.10 Mandrel GAS LIFT 5.920 3-1/2" x 1-1/2" MMG GLM SLB MMG 2.920 8,735.1 6,206.4 49.99 Packer 6.280 3-1/2" x 7" Halliburton MFT Packer Halliburt on MFT 2.897 8,765.5 6,226.0 49.87 Nipple - X 4.507 2.813" X-Nipple Halliburt on X 2.813 8,776.6 6,233.2 49.83 Wireline Guide 4.500 WLEG Halliburt on WLEG 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,190.0 6,502.7 49.42 FISH 2/3's of 5.75" over shot grapple left in hole 1/19/2023 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) 3,523.7 2,750.4 46.30 1 GLV RK 1 1/2 1,229.0 2/8/2023 SLB MMG 0.125 7,011.5 5,056.8 49.14 2 GLV RK 1 1/2 1,220.0 2/8/2023 SLB MMG 0.188 8,705.4 6,187.4 50.10 3 OV RK 1 1/2 0.0 2/7/2023 SLB MMG 0.188 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,083.0 9,098.0 6,433.0 6,442.8 A-3, 3O-15 6/10/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. ph 9,104.0 9,126.0 6,446.7 6,461.0 A-2, 3O-15 6/10/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. ph 9,148.0 9,169.0 6,475.4 6,489.0 A-1, 3O-15 6/23/1988 8.0 IPERF 4.5" Ultrapak Csg, 45 deg ph 3O-15, 2/27/2023 4:42:41 PM Vertical schematic (actual) PRODUCTION; 33.0-9,422.1 FISH; 9,190.0 IPERF; 9,148.0-9,169.0 IPERF; 9,104.0-9,126.0 IPERF; 9,083.0-9,098.0 Nipple - X; 8,765.5 Packer; 8,735.1 Mandrel GAS LIFT; 8,705.4 Mandrel GAS LIFT; 7,011.5 Mandrel GAS LIFT; 3,523.7 SURFACE; 35.0-2,773.6 Nipple - X; 497.0 CONDUCTOR; 36.0-110.0 Hanger; 33.0 KUP PROD KB-Grd (ft) 40.00 RR Date 5/7/1988 Other Elev 3O-15 ... TD Act Btm (ftKB) 9,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292179700 Wellbore Status PROD Max Angle & MD Incl (°) 53.23 MD (ftKB) 4,000.00 WELLNAME WELLBORE3O-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:1/30/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1880310 Sundry #322-711 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:3882 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 P BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)14 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)110 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1995 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/29/23 12:38 PM Waived By Test Start Date/Time:1/30/2023 11:30 (date)(time)Witness Test Finish Date/Time:1/30/2023 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nabors All Tests with 3 1/2" Test joint. Tony Morales / Paul Yearout ConocoPhillips Mark Adams / Chase Erdman KRU 3O-15 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0130_BOP_Nabors7ES_KRU_3O-15          J. Regg; 6/1/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:1/16/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1880310 Sundry #322-711 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:3882 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)111 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1930 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 27 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/14/23 4:24 AM Waived By Test Start Date/Time:1/15/2023 21:00 (date)(time)Witness Test Finish Date/Time:1/16/2023 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors All Tests with 2 7/8" Test joint. Kelly Cozby / Jim Marmon ConocoPhillips Dale Rowell / Kevin Barr KRU 3O-15 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0116_BOP_Nabors7ES_KRU_3O-15         J. Regg; 5/31/2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9450'8792' Casing Collapse Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 Senior RWO/CTD Engineer Tubing Grade: Tubing MD (ft): 8864' MD and 6290' TVD 8795' MD and 6245' TVD 8828' MD and 1786' MD and 1604' TVD Perforation Depth TVD (ft): Tubing Size: J-55 8938' Packer: Baker HB Packer Packer: WFD ER Patch Packer Packer: WFD ER Patch Packer SSSV: Camco TDDP-1A-SSSA Safety Vlv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025513 188-031 P.O. Box 100360, Anchorage, AK 99510 50-029-21797-00-00 ConocoPhillips Alaska, Inc. KRU 3O-15 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6670' 9115' 6454' 3882 psi None MD 110' 2242' 110' 2774' 6652'9422' 16" 9-5/8" 74' 2739' Perforation Depth MD (ft): 9083-9098', 9104-9126', 9148- 9169' 9389' 6433-6443', 6447-6461', 6475- 6489'2-7/8" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 1/10/2023 By Anne Prysunka at 1:28 pm, Dec 20, 2022 322-711 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2022.12.20 07:03:58-09'00' Foxit PDF Editor Version: 12.0.1 Shane Germann 12/22/2022 DSR-1/3/23 X VTL 1/12/2023 X BOP test to 4000 psig Annular preventer to 2500 psig 10-404Brett W. Huber, Sr. GCW 01/13/23JLC 1/13/2023 1/13/23 RBDMS JSB 011923 Shane Germann Senior Wells Engineer CPAI Drilling and Wells P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 19, 2022 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 3O-15 (PTD# 188-031). 3O-15 was drilled and completed in 1988 as an A-sand producer. The well was patched across a GLM @8801' RKB in 2008. There became tubing to IA communication and the patch was attempted to be pulled, but was unsuccessful. Heavier weight brine was pumped to knock down pressure and a spear stuck in patch around ~8795' RKB in 2022. The well then became a RWO candidate. The scope of the RWO is to pull the 2-7/8" single completion down through packer and tubing tail, then test the 7.0" casing and change out IC Packoffs in wellhead. Then a new 3.5" single completion will be installed with 3-1/8" tree. If you have any questions or require any further information, please contact me at 406-670-1939. Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2022.12.20 07:03:13-09'00' Foxit PDF Editor Version: 12.0.1 Shane Germann 3O-15 RWO Procedure Kuparuk Producer PTD #188-031 Page 1 of 2 Remaining Pre-Rig Work 1. Lockout or install hold open sleeve in SSSV as needed for wellwork. 2. Open lowest GLM accessible in upper completion. Close the rest. 3. SBHP. 4. Cut the tubing nominally at ~8780’ RKB in the middle of the first full joint above the stuck spear in the patch. 5. OA DDT. 6. Prepare well for rig arrival within 48-72 hrs before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3O-15. (A BPV will not be installed pre-rig for MIRU due to internal risk assessment on N7ES). 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead with 30 minute No Flow Test with KWF in the well. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4000 psi. Test annular 250/3,500 psi. Retrieve Tubing, Packers, and Tubing Tail Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to first cut (~8780’ RKB). 6. RIH with fishing BHA and fish tubing stub and seals from PBR. TOOH. 7. RIH with test packer and confirm 7.0” casing integrity. 8. Set storm packer near surface and test to confirm as barrier. ND BOPE and swap tubing spool to new tubing spool and change/test packoffs. 9. NU new spool and test lower flange to 3000 psig with packoffs (due to limitation of exposed wellhead flange.) Then NU BOPE and test break of upper new tubing spool flange to BOPs to BOPE test pressure against a test plug. Finish POOH with storm and test packer. 10. RIH with fishing BHA and fish packer and tubing tail. TOOH. Cleanout Run 11. Perform a Cleanout run if necessary based on tubing condition. Install in 3-½” Tubing Single Completion 12. MU 3 ½” completion with WLES, nipples, packer, and GLMs. 13. Once on depth, space out as needed and land tubing hanger. ND BOP, NU Tree, Set Packer and Test Completion 14. Install BPV and test to confirm as barrier. ND BOPE and NU tree. Test Tree. Pull BPV. 15. Circulate in Corrosion Inhibited fluid. 16. Set packer 17. Pressure test tubing to 3000 psi for 30 minutes on chart. 18. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 19. Confirm pressure tests, then shear out SOV with pressure differential. 20. Freeze protect well if necessary. 21. RDMO. Post-Rig Work 22. Pull BPV if installed. 23. Install GLD. 24. Pull any plugs or ball/rod used for setting packer. 3O-15 RWO Procedure Kuparuk Producer PTD #188-031 Page 2 of 2 General Well info: Wellhead type/pressure rating: Cameron Gen IV. Top 7-1/16” Flange 5K. Bottom 11” Flange 3K. Production Engineer: Brian Lewis Reservoir Development Engineer: Kaylie Plunkett Estimated Start Date: 1/10/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 2-7/8” completion down through packer and tubing tail, upgrade wellhead, install a new 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A (Holes, Leaks) MIT-IA Failed 9/28/2020 MIT-OA N/A IC POT PASSED – 11/18/2022 TBG POT &PPPOT PASSED – 11/18/2022 MPSP: 3882 psi using 0.1 psi/ft gradient Static BHP: 4502 psi / 6203’ TVD measured on 12/18/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,115.0 10/12/2007 3O-15 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Spear in Fish 1/17/2022 3O-15 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 2,773.6 Set Depth (TVD) … 2,242.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 9,422.1 Set Depth (TVD) … 6,652.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 33.0 Set Depth (ft… 8,937.9 Set Depth (TVD) (… 6,338.1 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 33.0 33.0 0.10 HANGER 2.875 6.000 CIW CIW 5000 PSI TUBING HANGER 1,786.5 1,604.2 45.39 SAFETY VLV 2.312 5.125 CAMCO TRDP-1A -SSA CAMCO TRDP-1A-SSA SAFETY VALVE 3,252.0 2,563.1 46.70 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 5,364.7 3,956.0 47.77 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 6,410.0 4,664.8 49.18 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 6,902.9 4,985.8 49.12 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 7,390.2 5,304.6 47.31 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 7,849.4 5,619.5 45.78 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 8,308.8 5,931.3 49.00 GAS LIFT 2.347 4.750 McMurry FMHO McMurry HTC 2 7/8 x 1" FMHO GLM w/ dummy BK- 2 8,801.5 6,249.3 49.73 GAS LIFT 2.375 5.460 Merla TGPD MERLA 2 7/8 x 1 1/2" TGPD GLM w/ 48/64 C.V. RK Latch 8,850.1 6,280.7 49.47 PBR 2.376 4.750 Baker BAKER PBR 8,864.0 6,289.8 49.40 PACKER 2.376 6.062 Baker HB BAKER HB PACKER 8,902.9 6,315.2 49.20 NIPPLE 2.250 3.668 CAMCO D CAMCO D NIPPLE 8,937.0 6,337.5 49.14 SOS 2.441 3.750 Baker SOS BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,792.5 6,243.4 49.77 OTHER 2.25" BAIT SUB, X-OVERS, & BOWEN ITCO SPEAR (1.70" GRAPPLE) = 33" OAL 1/22/2022 0.000 8,795.0 6,245.0 49.76 PATCH 2 7/8" WEATHERFORD LOWER ER PACKER 8828' 10/12/08; UPPER ER PACKER & SPACER STINGER 8795' OAL 33' SET 10/15/08 10/15/2008 1.310 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,252.0 2,563.1 46.70 1 GAS LIFT DMY BK 0.000 0.0 9/10/2020 2 5,364.7 3,956.0 47.77 1 GAS LIFT DMY BK 0.000 0.0 9/10/2020 3 6,410.0 4,664.8 49.18 1 GAS LIFT DMY BK 0.000 0.0 1/26/1997 4 6,902.9 4,985.8 49.12 1 GAS LIFT DMY BK 0.000 0.0 9/10/2020 5 7,390.2 5,304.6 47.31 1 GAS LIFT DMY BK 0.000 0.0 11/5/1988 6 7,849.4 5,619.5 45.78 1 GAS LIFT OPEN 1/29/2021 7 8,308.8 5,931.3 49.00 1 GAS LIFT DMY BK 0.000 0.0 11/5/1988 8 8,801.5 6,249.3 49.73 1 1/2 GAS LIFT PATC H RK 0.000 0.0 9/24/2008 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,083.0 9,098.0 6,433.0 6,442.8 A-3, 3O-15 6/10/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. ph 9,104.0 9,126.0 6,446.7 6,461.0 A-2, 3O-15 6/10/1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. ph 9,148.0 9,169.0 6,475.4 6,489.0 A-1, 3O-15 6/23/1988 8.0 IPERF 4.5" Ultrapak Csg, 45 deg ph Notes: General & Safety End Date Annotation 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3O-15, 1/17/2022 8:14:05 PM Vertical schematic (actual) PRODUCTION; 33.0-9,422.1 IPERF; 9,148.0-9,169.0 IPERF; 9,104.0-9,126.0 IPERF; 9,083.0-9,098.0 SOS; 8,937.0 NIPPLE; 8,902.9 PACKER; 8,864.0 PBR; 8,850.1 PATCH; 8,795.0 GAS LIFT; 8,801.5 GAS LIFT; 8,308.8 GAS LIFT; 7,849.4 GAS LIFT; 7,390.2 GAS LIFT; 6,902.9 GAS LIFT; 6,410.0 GAS LIFT; 5,364.7 GAS LIFT; 3,252.0 SURFACE; 35.0-2,773.6 SAFETY VLV; 1,786.5 CONDUCTOR; 36.0-110.0 HANGER; 33.0 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 5/7/1988 3O-15 ... TD Act Btm (ftKB) 9,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292179700 Wellbore Status PROD Max Angle & MD Incl (°) 53.23 MD (ftKB) 4,000.00 WELLNAME WELLBORE3O-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 3O-15 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 110 110 16 15.06 62.5 H40 Welded Welded Surface 2774 2242 9.625 8.92 36 J55 BTC BTC Production/ Intermediate 9422 6652 7 6.28 26 J55 BTC BTC Tubing 8938 6338 3.5 2.992 9.3 L80 EUEM 8rd EUEM 8rd PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" GLMs @ TBD 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" WLEG Surface Casing Production/Intermediat e Casing Conductor A-sand perfs 7083' - 9169' RKB ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1880310 E-Set: 34350 12/08/2020 Abby Bell • • ConocoPhillips ~s~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 ~~l~:_s'.. . Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we1130-15 (PTD 1880310). This report records the completion of the tubing patch repair on this well. Please call Brent Rogers or Martin Walters at 659-7224 if you have any questions. Sincerely, Brent Ro ers g Problem Well Supervisor Attachments n • ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~ON~ 1. Operations Performed: Abandon ^ Repair Well ^ • Plug Perforations ^ Stimulate ^ OEtfgf.` ' Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Nu mber: COnOCOPhlllips Alaska, InC. Development^ . Exploratory ^ 188-031 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21797-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 59' ~ 30-15 8. Property Designation: 10. Field/Pool(s): ADL 25513 ~ ALK 2554 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9450' • feet true vertical 6670' ` feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 2714' 9-5l8" 2773' 2242' 3520 psi 2020 psl PRODUCTION 9363' 7" 9422' 6652' 4980 psi 4320 psi Perforation depth: Measured depth: 9083' - 9098', 9104' - 9126', 9148' - 9169' true vertical depth: 6433' - 6443', 6447' - 6461', 6475' - 6489' Tubing (size, grade, and measured depth) 2-7/8", J-55, 8938' MD: 2-7/8" Weatherford tubing patch, 8795' - 8828' Packers & SSSV (type & measured depth) Baker'HB', 8864' MD Camco TRDP-1A-SSA, 1786' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature c7~~~fi~ i Phone 659-7224 Date 11/3/2008 r Form 10-404 Revised 04/2004 ~ ~ ~ ~~ M L, ~~;~ ~r~ ~ t00 Submit Origin, - I ,. ~i ~>£ ~Jy 30-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/11/08 BRUSHED & FLUSHED TBG f/ 8798' - 8828' RKB. DRIFTED TBG WITH 23' x 2.25" DUMMY PATCH TO 8834' RKB. READY FOR E/L. 10/12/08 SET WEATHERFORD 2 7/8" ER PACKER AT 8828'. 10/15/08 RAN 2-7/8" ER PKR WITH SPACER /SNAP LATCH ASS'Y (MIN ID 1.31", 33' OAL). ENGAGED LOWER PKR @ 8828' RKB & SET (SWS E-FIRE). TESTED UPPER PKR, 'GOOD. TESTED IA, GOOD. READY FOR DHD. 10/16/08 MITIA -passed (post tubing patch) Initial T/I/0= 1200/1240/925. T & IA FL AS. up IA with 2 bbls diesel, T/I/0= 1200/2500/950, 15 min: 1200/2425/950, 30 min: 1200/2410/950. Bled IA. Final T/I/0= 1200/1000/925 10/17/08 PULLED DVs @ 6903', 5365', 3252' RKB. SET OV @ 7849', GLVs @ 6903', 5365' RKB. IN PROGRESS. 10/18/08 SET GLV @ 3252' RKB. PULLED CATCHER @ 8808' RKB. COMPLETE. TIFL -passed, Initial T/I/0=250/1425/950. Shut in well and lift gas, shot initial IA FL @ 7849' (Sta# 6 OV). Stacked out tubing with lift gas, T/I/0=1225/1225/950. Bled IA down, shot second IA FL Cad same location. Final T/I/0=1250/700/925. SummarX~et 33' Weathertord retrievable patch 8795' - 8828_'. MITIA prior to patch. TIFL after BOL passed to test the GLVs. _, i~,• KUP ~ 30-15 ~OIIOCOP~'ll~~l p5 Well Attributes Alaakn U I' Wellbore API/UWI Field Nams Wall Status ProNInJ Well Typa Inc! (°) MD (kKB) TD (max) (k... . 500292179700 KUPARUK RIVER UNIT PROD 53.23 4,000.00 9,450.0 Comment H23 (ppm) D ate Annotation End Date KB-Grd (k) Rlg Release Date °• SSSV: TRDP 175 7/1/2008 Last WO: 40 00 5/7/1988 Wed : -3615 1 0/L7/Y008325 01 PM . etk -Actual Annotation DapN (kKB) End Date Annofatlon End Date Last Tag: SLM 9,115.0 10/12/2007 Rev Reason: PATCH LENGTH CORRECTION 10/22/2008 Casin Strin s String OD String ID Set Depth Set Depth (TVD) SMng Wt String Casing Description (In) (In) Top (kNB) (rtl(B) (kl(B) (Iba/I[) Grade String lop Thrd cokoucroR, n9 CONDUCTOR 16 15.06 2 0.0 110.0 110.0 62.50 H-00 SURFACE 95/8 8.76 5 0.0 2,773.0 2,241.8 36.00 J-55 sAfETV vL 1 PRODUCTION 7 6.15 1 0.0 9,422.0 6,652.1 26.00 J-55 1 ~ O Tubin Strin s Stdng OD String ID Set Depth Set Depth (TVO) SMng Wt String Tubing Descrlpgon (In) (In) Top (kKB) (ttKB) (kKB) (Ibs/tt) Grade String Top Thrd suRfncE, TUBING 27/8 2.44 1 0.0 8,938.0 6,338.1 6.50 J-55 EUESrdABmod 2'73 Other I n Hole A ll Jewel :Tubi n Run & Retrievable Fish etc. Top Dspth (ND) Top GAS LIFT, Top (kKB) (RKB) Inc! (°) Description Cammant Run Date ID (In) 3,zsz 1,786.0 1,603.8 45.38 SAFETY VLV Camco'TRDP-IA-SSA' 6/24!1988 2.312 3,252.0 2,563.1 46.56 GAS LIFT MMH/FMHO/1/GLV/BK/.156/13471 Comment: STA 1 10/18/2008 2.347 GAS LIFT 5,365.0 3,956.2 47.77 GAS LIFT MMH/FMHO/1/GLV/BK/.18a1371/Comment: STA 2 10/18/2008 2.347 , s,395 6,410.0 4,665.2 49.80 GAS LIFT MMH/FMHO/1/DMY/BK///Comment: STA3 1/26/1997 2.347 6,903.0 4,985.7 49.00 GAS LIFT MMH/FMHO/1/GLV/BK/.188/1354/Comment: STA4 10118/2008 2.347 7,390.0 5,304.5 47.31 GAS LIFT MMH/FMHO/1/DMY/BK/// Comment: STA 5 11/5/1988 2.347 GAS LIFT, 7,849.0 5,619.1 45.65 GAS LIFT MMH/FMHO/1/OV/BK/.188// Comment: STA 6 10/18/2008 2.347 9.410 8,309.0 5,931.4 49.00 GAS LIFT MMH/FMHO/1/DMY/BK/// Comment: STA 7 11/5/1988 2.347 8,795.0 6,245.0 49.76 PATCH 2 7/8" WEATHERFORD LOWER ER PACKER 10/12/08; 10115/2008 1.310 UPPER ER PACKER 8 SPACER STINGER OAL 33' SET 1a15/oa GAS LIFT, 8 903 $,$02.0 6,249.4 49.38 GAS LIFT MERLAlrGPD/1.5/PATCH/RK///Comment: STAB 9/24/201)8 2.375 , 8,850.0 6,280.6 49.29 PBR Baker PBR 6/24/1988 2.376 8,864.0 6,289.8 49.27 PACKER Baker'HB' PACKER 6/24/1988 2.376 cAS uFr, 8,903.0 6,315.2 49.20 NIPPLE Camco'D' Nipple NO GO 6/24/1988 2.250 7.390 8,937.0 6,337.5 49.14 SOS Baker 6/24/1988 2.441 13,938.0 6,338.1 49.14 TTL 6/24/1988 2.441 Perforations GAS LIFT, Shot 7,849 Top (TVDI Btm (TVD) Dens Top ((tK8) etm (kKB) (kKB) (kKB) Zorn Dab (sh.^ Type Commenl 9,083.0 9,098.0 6,433.0 6,442.8 A-3, 30-15 6/ta1989 12.0 IPERF 2 1/8" EnerJet, 60 deg. ph 9,104.0 9,126.0 6.446.7 6,461.0 A-2, 30-15 6Ita1989 12.0 IPERF 21/8" EnerJet, 60 deg. ph GAS LIFT, e.3os 9,14$,0 9,169.0 6,475.3 6,489.0 A-1, 30-15 6/2311988 8.0 IPERF 4.5" Ultrapak Csg, 45 deg ph GAS LIFr, 8.802 PATCH 8 795 , , PBR 8 850 , , PACKER, 8,884 NIPPLE, 8.903 SOS, 9,937 ~ rn, e.a39 IPERF, 9,083-9,098 IPERF, 9,101-9.1211 IPERF, 9,11&a,169 PRODUCTION, 9 422 TD, 9,450 ~~ ~~ ~:, ,. c Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth _ 'ti.~~ i.3 uFar~' Well Job # Log Description NO. 4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 i L-23 12097405 SBHP SURVEY j 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /~- D O ~ 09/10/08 1 1 3G-25X 12080437 LDL ~ - '3 Cl (0 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C, C / 09/14/08 1 1 3M-13 12096541 LDL - (yL( j (~l.j 09!10/08 1 1 2Z-13A 12100446 LDL Q(o- ('}O ''~U 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - 5''a 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE "t O 09/20/08 1 1 30-15 12100452 LOL - ~ Q 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE a ~ 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY S- (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY _ ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 1 R-34 12080444 _ GLS ~jC .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .: L ~~~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~'~~ '~ ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS ~ - -"' 10/07/08 1 1 36-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT ... 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE -- 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE G) C ..~ G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ,I'O~C 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • l".4NSf~lL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hoie/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuiflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~. ; ~;, ; 130 West International Airport Road ~'~"~~~~ ~~' ~' ~" ~~~~ Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 13Sep-08 3x15 1 Repo 7~~~=~~900 ~F h~: 2) r ~~; ~ 2008 ~ ~. Signed : '` ~ ~ ~~ ~~. ~K d,c~. ~ ~ ~ l~~~A~~ ~' Print Name: ~ ~;Inr1~-.~>h~ ic_o ~'_.1~,~, G;c PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-AAAIL : pdsanchorage(a~mem©rylog.eorn WEBSITE : wnvw.tvtert~®rylog.com C:lDocmnen6 and Settings\Owner\Desktop\Ttansmit_BP.doc 1 u Memory Multi-Finger Capper & MTl" S Results. Summary Company: ConocoPhitiips Alaska, Inc. Well: 30-15 Log Date: September 13, 2008 Field: Kuparuk Log No.: 8712 State: Alaska Run No.: 1 API No.: 50-029-21797-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD AB MOD Top Log Intvl.: SurtaCe Pipet Use: Tubing Bot. Log Intvl.: 8,900 Ft. (MD) Pipet Desc.: 7" 26 ib. J-55 Top Log intvl.: 2,766 Ft. (MD) Pipet Use: Production Casing Bot. Log Intvl.: 8,893 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The data in this log is tied into the Baker `HB' Packer @ 8,864' (Driller's Depth), This is the first time a PDS Multi-Finger Caliper and 12 Arm Magnetic Thickness Tool (MTT) has been run in this welt. The MTT responds to the total thickness of metal of the 2.875" tubing and 7" production casing. A single pass at 8Hz was made at 20 fpm from surface to 8,893'. The additional metal volume of the 9.625" surface casing interferes with the normal function of the MTT, so no interpretable results are available from the end of the 9.625" surface casing (2,766') to surface. INTERPRETATION OF CALIPER LOG RESULTS This log was run to assess the condition of the 2.875" tubing logged with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 2.875" tubing logged is in good to poor condition, with a hole re~rded below GLM 8 in joint 269 (8,818'). Other recorded damage appears as scattered pitting, areas of general corrosion and line corrosion. Although no significant I.D. restrictions are recorded, the caliper recordings indicate buckling, increasing in severity with depth, from 6,400' to 8,900'. Slight ovality due to buckling is recorded throughout this interval. A 3-D log plot of the caliper recordings across the hole in joint 269 is included in this report. 2.875" TUBING -MAXIMUM RECORDED WALL PENETRATIONS Hole! (100%) Jt. 269 ~ 8,818 Ft. {MD) ' Line Corrosion (31°~) Jt. 252 ~ 8,272 Ft. (MD) No other significant wall penetrations (> 20°~) are recorded throughout the interval logged. ^ 2.875" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 12%) are recorded throughout the interval logged. 2.875" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No sign cant I.D. restrictions are recorded throughout the interval logged. ~~ ~ FroAc6ve Diagnostic Ser+;ices, Inc. / P.Q. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSC~~memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 ~~-~3r /~~3~ • I II INTERPRETATION OF MTT LOG RESULTS 1 The Average Metal Thickness Relative to the Calibration Point graph indicates relative metal loss ranging from 1 °~ to 6% throughout the logged interval. A maximum overall metal loss of 6% is indicated in joint 260 (8,511' - 8,541'), which appears to be associated with a thinner casing joint. A 1"scale log plot of the MTT recordings at 8Hz from 2,766' to 8,893' is included in this report. The Delta Metal Thickness (%) curve in this plot refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. This log plot shows a pattern of general corrosion in broad bands of high frequency metal thickness variance throughout the log. An expanded log plot of the interval from 8,807' to 8,844', showing a detailed plot of isolated metal loss ' where the caliper recorded a hole in joint 269, is included in this report. Plots of similar isolated metal loss events where the caliper did not indicate significant internal corrosive damage from 5,396` to 5,433` and 8,147' to 8,183' are also included. ' Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated downhole (8,129'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 2.875" tubing and 7" production casing. Field Engineer: K. Miller Analyst: M. Lawrence (Ml7) & HY. Yang (MT"T) Witness: C. Fittzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffor~~, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PGS~~?memoryfog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • ~.~~ PDS Multifinger Caliper 3D Log Plot ~ ~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 30-15 Date : September 13, 2008 Description : Detail of Caliper Recordings Across Hole in Joint 269 (8,818) • • Correlation of Recorded Damage to Borehole Profile Pipe 1 2.875 in (16.3' - 8874.7') Well: 30-15 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: September 13, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 20 826 1638 2470 GLM 1 3282 4097 _c t .~ 4903 GLM 2 5724 GLM 3 6545 GLM 4 GLM 5 7359 GLM 6 8182 GLM 7 GLM 8 270 8875 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 270 1 25 50 75 100 ~ 125 ;_ Z _0 150 175 200 2 50 _ • • PDS Report Overview ~~ ~. Body Region Analysis Well: 30.15 Survey Date: September 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE 8RD AB MOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~, metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 276 pene. 12 105 157 1 0 1 loss 47 226 3 0 0 0 Damage Configuration (body ) 40 30 20 1O 0 ~solaKSi general line ring hole /puss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 52 31 18 2 0 1 Damage Profile (°~ wall) tii~ penetration body rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 Bottom of Survey = 2 70 Analysis Overview page 2 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB MCWeII: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft.) I'f•n. Ul~s~•i (Iran.) Pen. Body (Ins.) Pc~n. °i~> ~tctal Ir~s~ ~, Min. LD• (Ins.) Comments Damage Profile (%walQ 0 50 100 .1 16 U 0.01 6 tl 2.38 PUP 1 20 iI 0.02 1U U 2.38 1.1 52 a 0.01 G ! ~ 2.35 PUP 1.2 62 t~ 0.02 ti ii 2.35 PUP 1. 70 a 0.01 i 1 2.38 PUP 1.4 76 i1 0.01 t~ ~ +~ .37 PUP 2 81 a .0 tai I 2.36 3 113 U 0.01 ~~ 2.38 4 146 i ~ 0.01 1 I 2.38 5 178 t ~ 0.01 4 1 2.37 6 211 U .01 (, > 2.37 7 44 iI 0.02 Ii) 2.38 8 277 a 0.02 II ~ 2.38 9 310 ~ ~ 0.01 E~ 2.38 10 342 ~! 0.03 Il 2.37 11 374 ! ~ 0.02 I 1 I 2.38 1 407 t> 0.02 II I 2.40 13 439 t~ .01 7 2.38 14 472 t ~ 0.01 6 2.38 1 504 !~ 0.0 1 n I 2. 8 16 537 a 0.02 II I 2.38 17 570 t~ 0.01 b ~1 2.38 18 602 i I 0.01 6 U 2.38 19 631 ~~ 0.03 14 ~ 2.37 0 664 a 0.01 4 , 2.38 21 696 ~) 0.02 1 I -t 2.38 22 729 U 0.03 1Z ~ 2.38 23 761 U 0.02 1O ~ 2.37 24 793 U 0.03 14 ~' 2.38 25 826 iI 0.02 11 I 2.38 26 859 U 0.01 6 1 2.38 27 891 a 0.01 7 2.38 8 924 ~? 0.03 12 _' 2.37 29 957 iI 0.02 10 1 2.37 30 990 (I 0.01 6 ? 2.38 31 1022 ~~ 0.03 1 "i I 2.37 32 1055 iI 0.02 11 _' .38 33 1087 U 0.03 1 Z s 2.36 34 1120 U 0.02 I U 1 2.39 35 1152 t~ 0.03 ll 4 2.37 36 1185 i ~ 0.03 12 _' 2.38 37 1217 i) 0.02 t3 ~ 2.38 38 1249 a 0.01 6 I 2.38 39 1282 Ii 0.02 ~) -t 2.38 40 1313 iI 0.02 11 1 2.37 41 1345 ~ ~ 0.02 1 1 -1 2.37 42 1378 ~ ~ 0.02 1 I I 2.37 43 1409 ~ ~ 0.03 11 ? 2.37 44 1442 c ~ 0.02 I 1 2.38 45 1475 ~ I 0.02 8 ~ ~ 2.38 _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB MN1/ell: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~s~•t (Ins.) Pen. Body (Ins.) I'en. % ~1etil I ~~ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1508 t) 0.03 13 ~ 2.37 47 1540 I I 0. 2 1 1 4 2.38 48 1573 t ~ 0.01 G 4 2.39 49 1606 ~ ~ 0.01 4 ~ 2.38 50 163 ~ ~ 0.01 (; -1 2.38 51 1671 U 0.01 3 3 2.38 52 1704 U 0. 1 3 2.38 53 1736 It 0.02 10 3 2.38 53.1 1769 U 0 U U 2.31 SSSV 54 1783 U 0.03 12 5 2.37 55 1816 (~ 0.00 1 2.37 56 1849 t ~ 0.01 4 3 2 36 57 1882 tt .03 12 ? 2 36 58 1915 ~ ~ 0.00 1 =1 2.36 59 1947 ~ ~ 0.01 3 ~' 2.36 60 1980 tt 0.01 4 1 2.37 61 2013 ~~ 0.02 I1 2.37 62 2045 U 0.00 1 ~ 2.35 63 2078 tI 0.03 13 5 2.37 64 2111 t ~ 0.01 4 4 2.36 65 143 U 0.01 6 •1 2.37 66 2176 (1 0.02 1 U 5 2.38 67 2208 tI 0.01 t~ -! 2.36 L De osits. 68 2241 tt 0.00 1 ~ 2.38 69 2274 i1 0.01 t~ t, 2.38 70 2306 U 0.02 ti ~ 2.40 71 23 9 ~1 0.01 ~ 2.38 72 2372 ~? 0.03 1 -' ~ 2.36 73 2405 (t 0.03 15 ~ .36 Shallow itti 74 2437 ~1 0.02 11 - 2.39 75 2470 tI 0. 2 lit ~t 2.39 76 2502 a 0.03 1 ~~ a 2.37 77 2535 tI 0.02 II 2.37 78 2567 ~~ 0.04 18 t~ 2.36 Shallow ittin . 79 2600 a 0.03 I ~' -1 .37 80 2633 ~ ~ 0.02 1 U - 2.37 81 2661 tt 0.03 IZ "> 2.37 82 2694 tI 0.03 1Z ~, 2.37 83 2726 ~t 0.03 14 ~ 2.37 Lt. De osits. 84 2759 U 0.03 15 2.39 Shallow ittin . 85 2790 ~! 0.02 1~.~ - 2.37 86 2823 ~ } 0.04 1 E~ 2.36 Shallow corrosion. 87 2856 t ~ 0.03 I ~ 2.36 88 2888 ~~ 0.03 12 (~ 2.38 89 29 0 it 0.03 14 ~ 2.37 90 2953 U 0.04 18 ~~~ 2.36 Shallow ittin . 91 2985 ~ ~ 0.03 14 -l 2.36 Lt. e osits. 92 3016 ~ t 0.03 1~' !, 2.37 93 3049 tt 0.04 17 'S 2.36 Shallow ittin Lt. De osits. 94 3081 a 0.02 Il tt 2.36 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB MCWeII: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. t )I~~et lln.l Pen. Body (Ins.) Pen. °o ~;1c~r~l I <,~ti ~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 3114 t i 0.03 14 (~ 2.36 96 3146 ') 0.04 1' 2.36 Shallow i in . 97 3179 i) 0.04 I ~' S 2.37 Shallow ittin Lt. De sits. 98 3 1 1 i) 0.03 1 ~ ti 2.35 LL De osits. 98.1 3244 t) 0 i ~ n N A GLM 1 Latch @ 10:00 99 3250 t) 0.03 I t; 2.36 Shallow corrosion. 100 3282 i ~ 0.03 14 - 2.37 101 3315 t~ 0.03 12 (~ 2.35 102 3 48 t) 0.01 s ; 2.35 103 3380 l) 0.03 14 ~ 2.36 104 3413 t~ 0.03 14 3 2.35 105 3445 !) 0.02 1 1 2.35 106 3478 t) 0.01 ~ ~~ 2.35 107 3511 a 0.02 1 U ~ 2. 6 108 3543 i ~ 0.03 1-3 -3 2.35 109 3576 t) 0.03 12 a 2.38 110 3609 t) 0.00 I 5 2.35 111 3642 U 0.02 t3 t, 2. 8 112 3674 t) 0.02 Ill 5 2.36 Lt. De osits 113 3707 i) 0.02 11 t, .35 114 3738 t~ 0.03 1_' 2.36 115 3771 U 0.02 Ill (~ 2.36 116 3804 U 0.02 11 i 2.36 117 3836 0 0.03 12 5 2.36 1 8 3869 (1 0.01 3 ~1 .36 119 3901 U 0.00 1 b 2.36 20 3933 a 0.02 11 4 2.36 121 3966 t) 0.01 3 5 2.36 122 39 9 i) 0.03 14 6 2.35 Lt De osits. 123 4032 U 0.00 1 ? 2.37 124 4064 O 0.03 15 ~ 2.36 Shallow ittin . 125 4097 O 0.01 -1 2.36 126 4127 U 0.02 1U 5 2.35 127 4159 t) 0.04 1 F3 (, 2.35 Shallow corrosion. 128 4192 i) 0.00 1 5 2.37 129 4224 U 0.01 3 _' 2.37 130 4255 a 0.02 1 U (, 2.38 131 4288 a 0.03 I4 5 2.36 13 4321 i 1 0.01 (~ 4 2.38 133 4353 t) 0.02 11 (i 2.35 134 4386 t) 0.02 10 ,' 2.38 135 4418 t1 0.03 14 i 2.36 136 4451 t~ 0.04 1 ~) (~ 2.35 Shallow ittin . 137 4483 a 0.02 11 3 2.36 138 4515 a 0.02 1(~ (~ 2.36 139 4548 i~ 0.03 I ~ ~ 2.37 140 4581 ~ ! 0.01 -1 1 2.38 141 4613 ~! 0.03 Li 2.35 Lt. De osits. 142 4646 U 0.0 lit r 2.37 143 4678 a 0.01 - 2.36 Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB MCWeII: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Upset (Ins.) Pen. Body (Ins.) I'c n. % ~1c~t,il I oss °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 144 4711 tl 0.03 12 5 2.38 145 4740 U 0.03 15 -1 2.36 Shallow ittin . 146 4773 tt 0.03 13 ~' 2.37 147 4805 t ~ 0.02 1 1 4 2.38 148 4838 U 0.03 1 ~ 4 2.36 149 4871 tt 0.02 1 U t) 2.38 150 4903 i t 0.02 I 1 ~ 2.36 151 4936 a 0.01 -1 2.37 152 4968 t t 0.03 i ~ 2.36 153 001 t ~ 0.03 i `~ ! 2.36 Shallow ittin . 154 5034 tt 0.03 15 ! 2.37 Shallow ittin . 155 5066 a 0.03 1 Z t, 2.37 _ 156 5099 U 0.04 19 _' 2.36 Shallow ittin . 157 5131 tt 0.00 1 -1 2.36 Lt. De osits. 158 5164 tl 0.03 15 _' 2.35 hallo ittin . 159 5197 U 0.03 1? 2.35 160 5230 U 0.04 18 ~ 2.35 Shallow ittin . 161 5262 (t 0.02 10 2.35 162 5295 t? 0.03 15 t, 2.35 Shallow corrosion. 163 5327 a 0.00 1 2.39 163.1 5355 t1 0 ~) u N A LM 2 atch ~ 8:00 164 53 7 l) 0.04 1 t3 I I 2.36 Shallow corrosion. 165 5399 U 0.02 1 U 2.36 166 5432 U 0.03 14 -1 2.36 67 546 tt .O1 ~ ~ 2.3 168 5496 i ~ 0.01 1 2.38 169 5528 it 0.02 11 b 2.35 Lt De osits. 170 5561 (t 0.02 1 1 ~1 2.38 , 171 5594 t1 0.04 1 ti i 2.36 Shallow ittin . 172 5626 (t 0.0 8 2.39 173 56 8 t 1 0.04 1U I 2.35 Cor osion. 174 5691 t t 0.02 8 7 2.37 175 5724 t 1 0.04 1 ? a 2.35 Shallow corrosion. Lt. De osits. 176 5757 U 0.01 ~ ~ 2.38 177 789 U 0.02 1 l) a 2.35 178 5821 ~ t 0.03 15 2.35 Shallow ittin . 179 5854 t t 0.03 I ; ~ 2.36 180 5887 it 0.02 ~~ 2.37 181 5920 U 0.02 11 I 2.36 182 5953 t~ 0.02 11 3 2.37 183 5985 tt 0.04 1 ~ 1 2.36 Shallow ~ttin Lt. De sits. 184 6018 t~ 0.02 1 ~l ~' 2.37 185 6051 U 0.02 11 I 2.37 186 6084 a 0.03 15 U 2.35 Shallow corrosion. 187 6117 a 0.01 ~ 1 2.34 188 6148 t) 0.03 12 i 2.37 189 6180 t t 0.00 1 1 2.36 190 6213 t ~ 0.04 19 I 2.35 Shallow corrosion. 191 6246 ~ } 0.01 -# 2.37 192 6278 t> 0.04 '~,~ U 2.35 Isolated ittin . _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB Mr1Nel1: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft) I'~~n. t Il~.~~i (Irn.i Pen. Body (Ins.) Pc~n. ,, ~tc~t,~l I rxs ~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 631 1 ~ t 0.03 I ~ 2.35 194 6 3 t t 0.02 I I 2.35 195 6375 tt 0.03 I~' ~ .38 19 .1 6404 t t 0 O O N A GLM 3 Latch ~ 2:00 196 6416 i t 0.00 1 2.38 197 6446 t! 0.03 I t, -~ 2.35 Shallow ittin . 198 6479 tt .03 1 _' i~ .37 Bucklin . 199 6512 tt 0.04 I'1 I 2.35 Shallow corrosion. 2 0 6545 a 0.03 I ; ~ 2.37 Bucklin . 201 6577 U 0.03 I t, I 4 Shallow itt n . 202 661 U 02 I t t U .38 B ckli 203 6642 tt 0.01 t, I 2.37 204 6677 U 0.04 1 ~ Z 2.35 Shallow corrosion. 20 6707 tt 0.02 I t t a 7 Bucklin . 06 6739 tt 0.02 I t t I 2.38 207 6772 a 0.01 t, i~ 2.38 Bucklin . 208 6804 t t 0.04 I ~t t t 2.35 Shallow c rrosion. 20 6837 a 0.01 ~ ' 2.39 Bucklin . 210 6869 i 1 0. 3 I _' I I .38 210.1 6901 n 0 t t i t N A GLM 4 Latch ~ 1:30 211 6911 U 0.03 I ~' 2.36 ucklin . 212 6941 (t 0.01 7 b 2.37 Bu klin . 213 6973 a 0.0 1 U 9 2.37 Sli ht Ovali due to Bucklin . 214 7006 O 0.03 1<' ~ 2.36 Bucklin . 1 7040 U .0 1 3 t3 2.36 Sli ht v li ue to u klin . 216 7073 U 0.02 1 1 _' 2.37 Bucklin . 217 7105 tt 0.0 lt) 1 2.36 ucklin . 218 7138 t) 0.04 ZU 5 2.35 Bucklin .Corrosion. 21 7171 U 0.04 1 ~) I U 2.36 Shallow corrosion 220 7200 U 0.03 1:3 5 2.37 Bucklin . 221 723 U 0. 4 16 2.35 Bucklin Shallo ittin . 222 7262 t t 0.02 1 t) ~ 2.38 Bucklin . 223 7 94 tt 0.0 1 1 ~ 2.37 Bucklin Lt. De sits. 224 7326 t t 0.03 1 ~' I 2.37 Bucklin . 225 7359 a 0.02 ~t .37 Bucklin . 225.1 7389 tt 0 tt u N A GLM 5 Latch ~ 10:30 226 7400 tt 0.01 i 1 2.37 Bucklin . 227 7428 tt 0.01 V i 2.38 Bucklin . 228 7461 U 0.02 11 (~ .35 Bucklin . 229 7493 tt 0.01 4 I 2.36 Bucklin . 230 7526 tt 004 fit) (, 2.35 Bucklin .Isolated ittin . 231 7558 t t 0.02 I t t 2.37 Bucklin . 232 7591 t) 0.03 1 ~' I 2.35 Bucklin . 233 7624 t t 0.01 ; t~ 2.38 Bucklin . 34 7655 tt 0.0 I:.' S Bu lin its. 235 7687 t t 0.03 15 I _' 2.37 Sli ht Ovali due to Bucklin .Shallow ittin . 236 7720 t t 0.04 16 tt 2.38 Bucklin Shallow ittin . 237 7752 tJ 0.03 14 -t 2.35 Bucklin . 2 8 7784 ! t 0 04 1 t3 J 2.35 Bucklin ~. Shallow corrosion. 239 7817 ~ t 0.02 1(1 ~ ~ 2.37 Bucklin ~. _ Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD AB M(Well: 30-15 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: September 13, 2008 Joint No. Jt. Depth (Ft.) I'i•n. t tl„~~I (Ins.j Pen. Body (Ins.) I'c•n. % ~k•r,il Loss `%~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 239.1 7841 u 0 l) +~ N A GLM 6 Latch ~ 4:30 240 7858 t) 0.02 i ~4 2.36 Bucklin . 241 7888 ! t 0.02 1 U ~' 2.37 Bucklin . 242 7921 tl 0.04 lt3 ~ 2.35 Bucklin .Shallow ittin . 243 7954 tl 0.03 14 -1 2.35 Bucklin .Shallow ittin . 44 7987 (~ 0.02 11 f3 2.35 Bucklin . 245 8019 l~ 0.02 I 1 6 2.36 Bucklin Lt De sits. 246 8052 l) 0.04 1 ~) i 2.35 Bucklin .Shallow corrosion. 247 8086 U 0.03 12 ~ 2.36 Bucklin . 248 8117 U 0.02 11 a 2.36 Bucklin . 249 8148 t~ 0.0 14 I .35 B ckli 250 8182 U 0.02 11 i, 2.37 Bucklin . 251 8214 t ~ 0.0 I I ! ~ 2.36 Sli ht Ovali due to Bucklin . 25 8246 U 0.07 ~ I is 2.37 Bucklin .Line corrosion. Lt. De osits. ~ 253 8277 U 0.03 L3 ~ 2.37 Bucklin . Lt. De sits ,; 253.1 8309 tl 0 0 U N A GLM 7 Latch ~ 3:00 254 8317 a 0.02 I U ti 2.38 Bucklin . 255 8348 t 1 0.03 1 _' 2.37 Bucklin . 256 8380 t ~ 0.04 1 ti ~ 2.35 Bucklin .Shallow corrosion. 257 8414 t~ 2 1 1 ~~ .3 I~ ht Ov li d e to Buckli 258 8445 a 0.03 15 2.35 Bucklin .Shallow ittin . 259 8478 U 0.02 1 U - 2.37 Bucklin . 260 8510 0 0.02 10 2.37 Bucklin . 261 8543 U 0.02 l U ~ 2.36 Bucklin . 262 8576 U .04 18 2.35 Bucklin .Shall c rr sion. 263 8609 t ~ 0.03 I _~ ' ~ 2.36 Bucklin . 264 8641 a 0.01 !;~ 2.38 Bucklin . 265 8674 t ~ 0.04 1 tt (~ 2.38 Bucklin Line shallow corrosion. 266 8706 U 0.03 15 -1 2.35 Bucklin Sh Ilow ittin . 267 8738 0 0.03 15 ~> 2.35 Bucklin .Shallow ittin Lt. De osits. 268 771 U 0.04 18 1(1 2.38 B klin .Shallow ittin . 268.1 8800 U 0 l) tl N A GLM 8 Latch ~ 9:30 Han U 2 9 8815 U 0.26 l UU 4 2.38 Hole! 269.1 8846 U 0.01 4 1 2.36 PUP 269.2 8852 t~ 0 0 0 2.38 PBR 269.3 8864 0 2.38 PACKER 270 8875 0.03 2.36 Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections Well: 30.15 Survey Date: September 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 2.875 ins 6.5 f •55 EUE 8RD AB MOD Anal st: M. Lawrence Cross Section for Joint 269 at depth 8818.163 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 96 Tool deviation = 58 ° Finger 9 Penetration = 0.264 ins Hole! 0.26 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 (` PDS Report Cross Sections Well: 30-15 Survey Date: September 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf I-55 EUE SRD AB MOD Analyst: M. Lawrence Cross Section for Joint 252 at depth 8272.134 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 94 Tool deviation = 51 ° Finger 17 Penetration = 0.068 ins Line Corrosion 0.07 ins = 31% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 Average Recorded Metal Thickness Relative to Calibration Point 2.875" Tubing / 7" Casing Wel: 3Cti15 Field: Kuparuk Company: ConocoPhidips Alaska, Inc. Country: USA Survey Date: September 13, 2008 ^ D ecrease ^ In crease GLM 1 1 ~ 3282 125 4097 150 4903 GLM 2 pp L L Q~ ~ 175 5724 ~ ~ .c Z t ~. c n. ~ ~ GLM 3 200 6545 GLM 4 GLM 5 7359 GLM 6 250 8182 GLM 7 GLM 8 270 8875 - 50% 0 5 0% C hange i n Metal Thickn ess (% ) Bottom of Survey = 270 3G~ Recorded Magnetic Thicki~s Log Data - 8Hz Pass 2.875" 6.5 Ib J-55 Tubing & 7" 26 Ib J-55 Production Casing P~~~ k ~. ~~ September 13, 2008 Database File: 3o-15.db Dataset Pathname: 8HzPass.1 Presentation Format: mtt_bw Dataset Creation: Mon Sep 15 23:48:58 2008 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:1200 -100 Delta Metal Thickness {%) 100 2.3 MTTP01 {rad) 12.3 0 Line Speed (ftlmin) -200 -6.5 MTTP12 {rad) 3.5 n of 9.625" Surface tal Thickness :ollar 2900 Collar 3000 3100 3200 GLM 1 3300 3400 3500 3600 3700 3800 3900 4000 4100 4'00 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 GLM 2 5400 5500 5600 5700 5800 5900 6000 6100 600 6300 r_~nn GLM 4 6500 6600 6700 6800 GLM 4 7000 7100 7200 7300 GLM 5 7500 7600 7700 7800 GLM 6 7yoo Detail of MTT Recordin (8,807' - 8,844') Hole Recorded by Caliper @ 8.818' September 13, 2008 PNDACIwE k SERV{C~r I~ Database File: 3o-15.db Dataset Pathname: 8HzPass.1 Presentation Format: 2 scale Dataset Creation: Mon Sep 15 23:48:58 2008 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:60 0 MTTFREQ (Hz) 20 2 MTfP01 {rad) 12 -50 Delta Metal Thickness {%) 50 -6.8 MTTP12 {rad) 3.2 0 Line Speed (ft/min) -200 r ~ Re cord ing Freq uenc y GLM 8 t r i S d ~ ~ ne p ee T bi C ll i u n g o a ~ 4'` - `, D elta Met al T hick ness 8820 Ho le re ~ cord ed by c alipe r j 1 1 ~ f Sens or 8 Ph ase Shift ;~ ~ Sensor 10 Phase Shi ft T ubing Jt. ~fi9 S t 9 Ph S hift ens or a se i s = ~. Cas ing Coll a s 8840 y 1 ~ Tu bing Col lar -r `- 0 MTTFREQ (Hz) 20 2 MTTP01 (rad) 12 -50 Delta Metal Thickness (%) 50 -6.8 MTTP12 (rad) 3.2 P~+~ -~ ~. ~~. De~ of MTT Recordings of Isol d Event in Tubing Jt. 165 2.875" 6.5 Ib J-55 Tubing & 7" 26 Ib J-55 Production Casing {5,397'to 5,432'} September 13, 2008 Database File: 3o-15.db Dataset Pathname: 8HzPass.1 Presentation Format: 2 scale Dataset Creation: Mon Sep 15 23:48:58 2008 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:60 0 MTTFREQ (Hz) 20 2 MTTP01 (rad) 12 -50 Delta Metal Thickness (%) 50 -6.8 MTTP12 (rad) 3.2 0 Line Speed (ft/min) -200 - -~ Tub ing Collar r ti 5`~ en sor 9 Phase Shift I~ ~ ,(.. = Delta Metal Thic kness ~ S enso r 8 Phase Shi SI I S Sensor 10 Phase Shift ~ ~ y.. ,~. i S d ne p ee Re cord ing F req uenc y ~ ~ ~ i C 4 a s ng ol lar ~: Tubing Jt.16 5420 Isol ated Me tal L oss Tubi n Colla r b. 0 MTTFRE~ (Hz) 20 2 MTTP01 (rad) 12 -50 Delta Metal Thickness (°/a) 50 -6.8 MTTP1~ (rad) 3.2 0 Line Speed (ft/min) -200 S PM01AC1IVE otx~os,Hc sew.ACe4 ING De~ of MTT Recordings of Isol~f Event in Tubing Jt. 249 2.875" 6.5 Ib J-55 Tubing & 7" 26 Ib J-55 Production Casing (8,147'to 8,183') September 13, 2008 Database File: 3o-15.db Dataset Pathname: BHzPass.1 Presentation Format: 2 scale Dataset Creation: Mon Sep 15 3:48:58 2008 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:60 0 MTTFREO (Hz) 20 2 MTTP01 {rad) 12 -50 Delta Metal Thickness {%) 50 -6.8 MTTP12 (rad) 3.2 0 Line Speed (ft/min) -200 a u bing Coll ar - - a Del ta M etal Thickness Se nsor 8 P hase Sh ~ ~ ~ ~ Sensor 1 ift ~ 0 P has e Sh ~ Li S d S I I ne pe e { i Se nsor 12 Pha se S hift Re cord ing F req uen cy ~ Isola fi ted Meta T l Lo ss Ca sing Colla 8160 Tubing Jt. 249 y _ 8180 T ubi ng C ollar (, 0 MTTFREQ (Hz) 20 2 MTTP01 {rad) 12 -50 Delta Metal Thickness (%) 50 -6.8 MTTP12 (rad) 3.2 0 I inP SpPp~1 (fflmin) -?Ofl KRU 30-15 ConocoPhillips Alaska, Inc. 30-15 API: 500292179700 Well T e: PROD An le TS: 49 de 9017 sssv SSSV Type: TRDP Orig C i 5/7/1988 Angle @ TD: 50 deg @ 9450 om let on: (1766-1767• oD z a7s Annular Fluid: Last W/O: Rev Reason: TAG . . ) Reference L Ref L Date: Last U ate: 10/13/2007 Last Ta : 9115' ELM TD: 9450 ftK6 Last Ta Date: 10/12/2007 Max Hole An le: 53 de 4000 Gas Lift Casin Strin -ALL STRINGS MararewaNe Descri lion Size To Bottum TVD Wt Grade Thread 1 (3252-3253 CONDUCTOR 16.000 0 110 110 62.50 H-40 , SUR. CASING 9.625 0 2773 2242 36.00 J-55 PROD. CASING 7.000 0 9422 6652 26.00 J-55 Gas Lift Tubin Strin -TUBING MarMrelNahe Size To Bottom ND Wt Grade Thread 2 5365 3 6 2.875 0 8938 6338 6.50 J-55 EUE 8RD AB MOD ( , -5 6 Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment Gas Lin 9083 - 9098 6433 - 6443 A-3 15 12 6/10/1989 IPERF 2 1!8" EnerJet 60 d h ~rareUDunmy 9104 - 9126 6447 - 6461 A-2 22 12 6/10/1989 IPERF 2 1/8" EnerJet 60 d h valve 3 (solo-sa11, oD:a 76o) 9148 - 9169 6475 - 6489 A-1 21 8 6/23/1988 IPERF 4.5" Ultrapak Csg, 45 deg h . Ga s Lift M andr elsNalve s Gas Lift M St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt andrel/Valve ~ 1 3252 2563 MMH FMHO GLV 1.0 BK 0.156 1332 6/21/2001 (69036904, 2 5365 3956 MMH FMHO GLV 1.0 BK 0.188 1359 6/21/2001 3 6410 4665 MMH FMHO DMY 1.0 BK 0.000 0 1/26/1997 4 6903 4986 MMH FMHO GLV 1.0 BK 0.188 1349 6/21/2001 Gas Lift - 5 7390 5305 MMH FMHO DMY 1.0 BK 0.000 0 11/5/1988 '"`~~D1r'n'y VaHeS 6 7849 5619 MMH FMHO OV 1.0 BK 0.188 0 6/21/2001 (7390.7391, 7 8309 5931 MMH FMHO DMY 1.0 BK 0.000 0 11/5/1988 oD:a.75o) 8 8802 6250 Merla TGPD DMY 1.5 RK 0.000 0 5/17/2001 Other lu s ui .et c. -JEWELRY Gas Lift De th TVD T escri lion ID Mandrewaloe 1786 1604 SSSV Camco'TRDP-IA-SSA' 2.312 6 (76as-765o 8850 6281 PBR Baker 2.376 , 8864 6290 PKR Baker'HB' 2.376 8903 6315 NIP Camco'D' Ni le NO GO 2.250 Gas Lin 8937 6337 SOS Baker 2.441 i ndreVDUmmy 8938 6338 TTL 2.441 Valve 7 (8309-8310, 00:4.750) Gas Lift ~ ndreiiDUmmy Vahre 8 (8802-8803, 00:5.460) PBR (8850-8851, 00:2.876) PKR (88648865, 00:6.151) NIP (8903-8904, 00:2.875) TUBING (0$938, 00:2.875, 10:2.441) Pert (90639098) Pert (91049126) Perf (9148-9169) • ~011000P~'1I I ~ 1 S p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: AU G ~ ~ 2DD8 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 July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/30/2008 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 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7!30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder, P. I. Supervisor DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad F. ridav, January 26, 2.001' ! traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components With one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, 12 wells, 24 components, I failure '4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: _phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: "Chuck Schex;e Field/Unit/Pad: ..Kuparuk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS . i ii i i .i · I . j . Ri i ~ ........ ~i'i .... ]i'i" '~" .... .... ~":-'--': ' ...... ' .... i ....... - ..... ~"-":':i'-.~ -"-'" -':"'""' · ..... ,' ~:-,' ':~T:":-::i~;: ';' ;,,"'"" "-:':': '~'~" '~: '":'l il .... ;" Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gm J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 30-01 1880730 "' ~7 "70 80 P P ..... OIL 304J2 ' 1880740' ' ~7 70 ' 60 ' P P ' OiL 30-03 1880750~ 67 · ' 70 60 P P ........... OIL 30-04 1880620' ' 67 70 65 P 'P OIL 30-06 1880600 30-08 1880640 67 70 ' '70 P' P ..... C~IL 30-09 ' ' 1880610' ' 67 ' 70. 40 P P ..... OIL 30-11 1880420' 6)1 ' 70 ' 60' P '""P ..... OIL 30-13' 1880400 67 70 60 "P P ' OIL 30-14 1880390 30-15 1'880310 67: 70! 70 P P OIL 30-18 1880260 ' ' '67: 70! 55 P P ' OIL 30-20 1970450 67 701 60 P P OIL 30:05 8807 ,0 3,75,0 20,0,0 ', "' 3?' ' ' ". ..... Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% [390 Day Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested .~.d. passe.d' this dat,e. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANy NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA AI..~oKA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1084' FNL, 2048' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1878' FSL, 1766' FWL, Sec. 21, T13N, R9E, UM At effective depth 1751' FSL, 1547' FWL, Sec. 21, T13N, R9E, UM At total depth 1710' FSL, 1473' FWL, Sec. 21, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 58 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 30-15 9. Permit number/approval number 88-31 10. APl number 5o-029-21797-00 11. Field/Pool Kuparuk River Field/Oil Pool 9450 feet Plugs (measured) None 6670 feet Effective depth: measured 9339 feet Junk (measured) None true vertical 6599 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 175 Sx AS I Surface 2 73 9' 9 - 5 / 8" 1000 Sx AS III & Intermediate 300 Sx AS II Production 9389' 7" 600 Sx TLW & Liner 390 Sx Class G Perforation depth: measured 9083'-9098', 9104'-9128', 91 49'-91 69' true vertical 6433'-6442', 6446'-6462', 6475'-6488' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 8938' Packers and SSSV (type and measured depth) Packer: Baker HB @ 8864'; SSSV: Camco TRDP-1A-SSA @ 1786' Measured depth True vertical depth 115' 115' 2774' 2242' 9422' 6652' 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 1/30/97 ORiGiNAL, , Intervals treated (measured) ..'.: .- ' ~".: 9083'-9098', 9104'-9128', 9149'-9169' Treatment description including volumes used and final pressure Pumped 194.8 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 7300 psi 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7 5 5 3 6 3 0 974 183 Subsequent to operation 1032 4 4 9 48 1011 185 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~f/~~"~--v-t~ ~z~/,.~ Title Wells Superintendent Form 1¢¢'4~-4f' R~ev,/O(~/~/8~.) - / Date i~Pf .~2 SUBMIT IN DUPLICATE ID: ~xRU.,' ~ l.,'Nk/DR ILL I Hi~ ALI. WEL~S LOCATED IN SEC. 22 T. t:5 N., R. 9E., UMIAT MERIDIAN. ,o mil. mm m viCINITY MAP SCN. E I-z a MILES NOTES I. ALL COORDINATES ARE A.S.E, ZONE 4. 2. ALL DISTANCES ~IOWN ARE TRUE. ~. ELEVATIONS AR[ 4. REFER. FIELD BOOK L.-aa-3~ 5. O.~k ELEVATIONS FROM CED-RIXX-$3~5,:& 6. HORIZONTAL I)O~tTION BASED (3/4 ~C) CoNTrOL MONUMENTS ~ k,OUN~[IU~Y & " ' ....................... OIST .... DiST O.& Well ¥ ASP$ , X LATITUDE LONGITUOE~ FNL. .EWL Flev.F_Jev_ ~1 6,022,095.27 5~.5,478. Z7 700~8' 17,338" 149~ 47'30.89~'' ~4' 154Z' 11.5' 23.9' 6,022,07~.~ 525,490.94 ~o~' 17. 128" 149047'~0.5~" 745' 1855' 17.7: 3 6,0Z2,052, I~ 525,~3.67 ~' 16.gl~" 149~47~30. I~: 76Y 1867' 17.9 $ 6,0ZZ,~e.~ 5ZS,eZa.~a 7~8, t~5,, 149°47,29.4~. 8l I, 189~; la. i 6,021,965.~ 5~5,555.~ 8' l~9 14~47 28.6~. 85~; ' 1917, 18.2, 6~0~ I ~. I~ 5~ t578. Z7 i5.632 149 47 27.974 89T 194t 18.4 I0 G,O21,84~ ~ 525,623.6l ~28' 14.~3" 149047'26.6~'' 975' 1906' 18.7' Il 6,OZI ,822. ~ 525,635,7l~ . ~' 14.651" 149e 4T'ZI.295" ~7' t99~', 1~6' 23.5' t3 6,OZ ,779. 16 525,66t .~ ~e~, 14.223" 349°47 25.5~, 1041', 2~4', 18.~', 23.0, 14 6,02 ~7. ~ 5Z5,6~.~ ~e~, 14.010" -149o47',~5,~, tO~ ~0~, Ig.O, 15 6,02],735. 76 5Z5 ,~6. I Z ~e~ 13.~5" 149o47 24.8~ i064: ZO4e, 19.0, ~.~; 16 6,0~1,?14. 15 5Z5,6~. 17 ~e28' 13.~5" 149047'~4.4~" II~ 20~, 19.1 17 6,0Zl ,69~ 525,710.85 ~' 13. S69" 149047'Z4.0~" t IZf 2073 19.0' t8 6,0~ I ,670.97 525,7~.~ ~29' 13. 157" 149047'~3,733" 1149' 2085' 19.0' 23.3' , i i ~1 .... . i .... ' : - I HEREBY C[~FY THAT I ~ P~OP~;Rt.Y REGISTERED ~ ~ZNSED ~ ~ ~CE ~ND ~UR~ING tN ~E ~A~ ~ A~SKA AND ~AT ~IS PkAT REPRESENT~ A L~ATION ~ ~PERVI~ION, ~D ~AT ~k DIMENSIO~ ~ ~ m mm ....... i i i i LOUNSBURY Associates STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL. r-~ GAS [[[] SUSPENDED .;~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Perm, l,i~, I~,u, mber ARCO Alaska, inc. OO-31 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21797 4. Location of well at surface 9. Unit or Lease Name 1084' FNL, 2048' FWL, 5ec.22, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1878' FSL, 1766' FWL, Sec.21, T13N, R9E, UM 30-15 At Total Depth 11. Field and Pool 1710' FSL, 1473' FWL, Sec.21, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 58' I ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 04/29/88 05/06/88 1 2/09/88* i N/A feet MSL 1 ,, 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey ! 20. Depth where SSSV set J 21. Thickness of Permafrost 9450'MD/6670'TVD 9339'MD/6599'TVD YES t~' NO [] 1786' feet MD 1700' (approx) 22. Type Electric or Other Log's Run DIL/GR/SP/SFL, FDC/CNL, CAL~ GR~ CET~ GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED' 16" 62.5# H-40 Surf 115' 24" 175 sx AS I 9-5/8" 36.0# J-55 Surf 777z~' 17-1/~' 1A~~ ~ Ag III £. '~ ~, ~q II 7" 26.0# J-55 Surf qb.??, 8-!/-?'' 600 sx TLW & 390 sx C~.~.~ C , 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. TUBING RECORD , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/8 spf, 45° phasing 2-7/8" 8938' 8864' .. , 9148 ' -9168 ' MD/6475 ' -6488 ' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adden~ urn, dated 1-24-89 for fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None _ ';-.- -. _ NOTE: Drilled RR 5/7/88. Perforated well and ran tubing 6/24/88. - Fractured well 12/9/88. Form 10-407 WC5/094 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,'."" ? ~ · 30~ ' GEOLOGIC MARKERS FORMATION TESTS . . :, . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,J Top Kuparuk C 9006' 6382' N/A Base Kuparuk C 9025' 6395' Top Kuparuk A 9068' 6423' Base Kuparuk A 9213' 651 7' 31. LIST OF ATTACHMENTS ~ddendum (dated 1-24-89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 'Si.ned ? ~ ~-~~_ _ TitleArea Drilling Engr' 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 (D.F, 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: 6/06/88 8/05/88 9/24/88 lO/O2/88 lO/O8/88 30-15 RU SOS. Rn CET f/9339'-2700'. Rn 6-1/8" GR. Rn GCT f/9303'-50'. RD Schl. RU hot oil unit. Pressure tst to 3000 psi. Pmp 21 bbls hot diesel w/5% Musol @ .25 BPM, 3500 psi. Displ w/59 bbls cln diesel. Final pressure = 3500 psi. Turn well over to Production. Attempt frac of Kuparuk A-1 Zone perfs 9149'-9169' per procedure dated 9/12/88 as follows: Stage 1: Stage 2: Stage 3: Flush: Breakdown: 100 bbls gelled diesel, 0 - 15 BPM, 2000 psi Breakdown: 100/200 bbls gelled diesel @ 15 - 20 BPM, 2000 - 6580 psi Pad A: 50/250 bbls gelled diesel @ ±20 BPM, 6000-6700-6000 psi Pad Scour: 50/300 bbls gelled diesl, .5 ppg @ 20 BPM, 6000 psi Pad B: 500/800 bbls gelled diesel @ 0 - 1.5 ppg, 20 BPM, 6000 - 4200 psi 23/823 bbls gelled diesel @ 4200 - 5300 psi 68/891 bbls gelled diesel @ 1.5 - 4.8 ppg, 20 BPM, 5300 - 6300 psi 9/900 bbls gelled diesel @ 4.8 - 5.5 ppg @ 20 BPM, 6300 to 7800 psi 7/907 bbls gelled diesel (compressing fluid only) @ ±7250 psi Frac screened out with 3 ppg @ perfs. (See comments attached). Fluid to Recover: 841 bbls Sand in Zone: ±3550# Sand in Casing: ±7800# RU fracmaster. Pressure tbg to 4000 psi. GIH, tag bridge ~ 635', break circ .5 BPM, 650 psi. Start N2 @ 100 scf 1350 psi. GIH, increase pmp rate to 1BPM, 300 scf/min @ 3000 psi @ 7000'. GIH to 8000', increase gell/diesel rate to 1.5 BPM @ 3550 psi. RIH, wsh sand f/7500'-8937'. At 8937', increase rate to 2.25 BPM gell diesel, 400 scf/min, 3600 psi. Wsh f/8937'-9330'. Circ two times btms up, switch to cln diesel, POOH. Turn well over to Production. RU hot oil unit. Press tst Ins to 3500 psi. Pmp 21 bbls hot diesel w/5% Musol @ 1.5 BPM, 2400 psi dn tbg. Displ w/55 bbls cln diesel @ 1.5 BPM, 2400 psi. Secure well. A D D E N D U M (cont'd) WELL: 30-15 10/09/88 10/19/88 Att to frac Kuparuk "A" sand perfs 9149'-9169' per procedure dated 10/7/88 w/o success. Tree saver failed. Failure to hold may indicate fluid erosion damage in top of tubing pup and tbg hgr. Job suspended. Well previously rigged up to frac. Tree saver failed early in job. Well flushed @ low rate. Tree saver mandrel showed corrosion. Set tst plug. Tbg press - 0 psi/Annulus pressure = 550 psi. Att to tst tree to 5000 psi; fluid pmp'g away @ 3000 psi. Quit pmp'g. Pressure came down to 650 psi. Bleed off pressure to 0. Annulus pressure stable @ 550 psi. Secure well. Hanger threads appear to be washed. Pull tst plug. lO/25/88 RU & pmp fresh wtr dn hole; rate decreased f/0.6 BPM to 0.4 BPM. Call f/hot oil truck. Observe slow wellhead leak f/btm of 7" csg head. Pmp Arctic Pak to prevent annulus freeze-up (total 44 bbls). Pmp 17 bbls hot diesel. Secure well. 12/09/88 Frac Kuparuk "A" sand perfs 9149'-9169' in seven stages per revised procedured dated 11/17/88 as follows: Stage iA: Pmp 150 bbls gelled diesel pre-pad @ 10/14/20 BPM, 5200/6200/5350 psi Stage lB: Pmp 32 bbls gelled diesel @ 20 BPM, 5300 psi Stage 2: 400 bbls gelled diesel @ 13-20 BPM, 6550-5200 psi Stage 3: 55 bbls gelled diesel, 2 ppg 20/40 Carbolite @ 5200-5430 psi Stage 4: 55 bbls gelled diesel, 4 ppg 20/40 Carbolite @ 20 BPM, 5430-6200 psi Stage 5: 55 bbls gelled diesel, 6 ppg 20/40 Carbolite @ 5850-6300 psi Stage 6: 50 bbls gelled diesel, 8 ppg 20/40 Carbolite @ 6300-6700 psi Stage 7: 58 bbls gelled diesel flush @ 17.5-19 BPM, 6700-5875 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: Drilling Supervisor 855 bbls diesel 42,600# 20/40 296# 20/40 5300 psi SUB-SURFACE DIRECTIONAL SURVEY [~]UIDANCE ~]ONTINUOUS F~'] OOL Company ARCO ALASKA, INC. Well Name 30-15 (1084'FNL, 2048'FWL, SEC 22, T13N, R9E, UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Jol~ Reference No. 72815 Loaaed By: MCBRIDE Date 5-June-88 Computed By: KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INCo 0-15 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 05-JUN-88 ENGINEER: M. MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORZZo DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 67 DEG 55 MIN WEST ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 20-JUN-88 PAGE 1 DATE OF SURVEY: 05-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 100.00 100.00 42.00 0 18 N 45 17 E 200.00 200.00 142.00 0 34 N 21 38 E 300.00 299.99 241.99 I 21 N 89 50 W 400.00 399.80 341.80 5 19 S 70 54 W 500.00 498.90 ¢40.90 9 37 S 74 43 W 600.00 597.01 539.01 12 39 S 76 I W 700.00 693.84 635.84 16 4 S 74 40 W 800.00 789.01 731.01 19 45 S 74 42 W 900.00 882.12 824.12 22 38 S 73 20 W 1000.00 973.55 915.55 25 23 1100.00 1062.78 1004.78 28 4 1200.00 1149.67 1091.67 31 15 1300.00 1233.76 1175.76 34 15 1400.00 1314.76 1256.76 37 22 1500.00 1393.20 1335.20 39 15 1600.00 1469.07 1411.07 41 51 1700.00 1542.44 1484.44 4.3 53 1800.00 1613.36 1555.36 45 37 1900.00 1681.74 1623.74 48 17 2000.00 1746.32 1688.32 51 8 2100.00 1808.75 1750.75 51 12 2200.00 1872.19 1814.19 49 58 2300.00 1937.27 1879.27 49 5 2400.00 2001.46 1943.46 51 11 2500.00 2064.39 2006.39 50 20 2600.00 2129.01 2071.01 49 21 2700.00 2193.86 2135.86 49 46 2800.00 2259.02 2201.02 48 52 2900.00 2325.05 2267.05 48 24 3000.00 2391.78 2333.78 47 54 3100.00 2459.04 2401.04 47 26 3200.00 2527.09 2469.09 46 52 3300.00 2595.69 2537.69 46 32 3400.00 2664.51 2606.51 46 29 3500.00 2733.56 2675.56 46 11 3600.00 2802.49 2744.49 46 39 3700.00 2870.97 2812.97 46 59 3800.00 2937.43 2879.43 49 59 3900.00 3000.46 '2 962.;46 .- : 51 45 VERT[CAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E -0.15 0.51 0.08 N 0.13 E -0.78 0.18 0.83 N 0.50 E -0.69 4.06 1.52 N 0.13 E 5.06 4.69 0.09 S 5.42 W 18.14 3.69 3.99 S 17.96 W 37.23 3.28 8.76 S 36.63 W 61.93 3.04 15.10 S 60.70 W 92.36 4.20 128.56 2.45 S 69 45 W 168.95 S 71 31 W 214.02 S 73 36 W 263.31 S 75 19 W 317.06 S 76 18 W 375.10 S 77 20 W 436.36 S 75 29 W 500.71 S 72 37 W 568.27 S 70 0 W 638.61 S 68 40 W 711.55 S 67 11W 787.88 S 67 0 W 865.99 S 67 50 W 943.28 S 67 51 W 1019.20 S 67 21 W 1095.87 S 68 12 W 1173.59 S 68 55 W 1249.89 S 68 2 W 1326.01 S 68 28 W 1401.85 S 69 6 W 1476.95 S 69 21 W 1551.41 S 69 42 W 1625.38 S 70 5 W 1698.61 S 70 16 W 1771.30 S 70 21 W 1843.80 S 70 36 W 1916.06 S 71 16 W 1988.40 S 71 38 W 2061.13 S 71 51 W 2135.66 S 70 47 W 2213.14 3.08 3.03 3.57 3.08 2.49 2.53 3.21 2.78 2.64 2.75 3.03 1.20 1.61 1.96 1.71 1.87 0.59 1.06 0.78 0.81 0.20 1.14 0.43 0.23 0.35 0.56 0.33 1.43 3.02 2.59 0.00 N 0 0 E 0.15 N 58 37 E O. 97 N 31 8 E 1.52 N 4 43 E 5.42 S 89 0 W 18.40 S 77 28 W 37.66 S 76 33 V, \ 62.56 S 76 I k 23.23 S 90.24 W 93.19 S 75 33 W 33.09 S 125.31 W 129.61 S 75 12 W 46.05 S 163.65 W 170.00 S 74 17 W 61.05 S 206.20 W 215.05 S 73 30 W 75.82 S 253.40 W 264.50 S' 73 ZO W 90.30 S 305.53 W 318.59 S 73 32 W 104.59 S 362.37 W 377.16 S 73 54 W 118.70 S 422.76 W 439.11 S 74 19 W 133.66 S 486.13 W 504.17 S 74 37 W 152.56 S 551.38 W 572.09 S 74 32 W 174.99 S 618.18 W 642.47 S 74 11 W 200.92 S 686.37 W 715.17 S 73 41 W 229.43 S 757.18 W 791.17 S 73 8 W 260.10 S 829.03 W 868.87 S 72 34 W 289.75 S 900.41 W 945.88 S 72 9 W 318.23 S 970.79 W 1021.61 S 71 51 W 347.60 S 1041.61 W 1098.08 S 71 32 W 376.97 S 1113.56 W 1175.64 S 71 17 W 404.76 S 1186.63 W 1251.88 S 71 8 W 432.79 S 1255.41 W 1327.92 S 70 58 k 460.86 S 1325.87 W 1403.68 S 70 49 W 488.08 S 1395.87 W 1478.74 S 70 43 W 514.42 S 1665.53 W 1553.19 S 70 39 W 540.37 S 1534.83 W 1627.17 S 70 36 W 565.49 S 1603.66 W 1700.45 S 70 36 W 590.16 S 1672.11 W 1773.20 S 70 33 W 614.56 S 1740.4¢ W 1845.76 S 70 33 W 638.79 S 1808.60 W 1918.09 S 70 32 W 662.40 S 1877.08 W 1990.53 S 70 33 W 685.61 S 1946.16 W 2063.40 S 70 35 W 708.91 S 2017.14 W 2138.08 S 70 38 W 733.63 S 2090.72 W 2215.70 S 70 39 W ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPE,ALASKA COMPU'TATION D~TE: 20-JUN-88 PAGE ' 2 DATE OF SURVEY:. 05-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3061.18 3003.18 53 13 4100.00 3121.51 3063.51 52 16 4200.00 3183.51 3125.51 51 17 4300.00 3246.66 3188.66 50 4400.00 3311.77 3153.77 48 19 4500.00 3378.27 3320.27 48 23 4600.00 3444.83 3386.83 48 12 4700.00 3511.57 3453.57 48 10 4800.00 3578.18 3520.18 48 14 4900.00 3644.83 3586.83 48 3 5000°00 3711.67 3653.67 48 3 5100.00 3778.46 3720.46 48 7 5200°00 3845.22 3787.22 48 7 5300.00 3912.08 3854.08 47 56 5400.00 3979.25 3921.25 47 40 5500°00 ¢046.69 3988.69 47 32 5600.00 4114.24 4056.24 47 24 5700.00 ¢182.11 4124.11 47 8 5800.00 4250.21 4192.21 47 1 5900.00 4318.45 4260.45 46 53 6000.00 4387.02 4329.02 46 32 6100.00 ¢455.79 4397.79 46 36 6200.00 4524.37 4466.37 46 53 6300.00 4591.85 4533.85 48 16 6400.00 4657.88 4599.88 49 7 6500.00 4722.83 4664.83 49 40 6600.00 4787.61 4729.61 ~9 33 6700.00 4852.66 4794.66 49 18 6800.00 4917.95 4859.95 49 9 6900.00 4983.37 4925.37 49 7 7000.00 5048.84 4990.84 49 7 7100.00 5114.20 5056.20 49 15 7200.00 5179.17 5121.17 49 48 7300.00 524).81 5185.81 49 9 7400.00 5310.83 5252.83 47 6 7500.00 5378.63 5320.63 47 37 7600.00 5445.87 5387.87 47 34 7700.00 5514.60 5456.60 45 41 7800.00 5584.58 5526.58 45 37 7900.00 5654.33 ~5596.33 45 56 DEG MIN FEET DEG/IO0 FEET FEET FEET OEG MIN S 69 30 W 2292.53 S 69 27 W 2.372.25 S 68 38 W 2450.69 S 67 56 W 2528.22 S 69 9 W 2604.10 S 69 7 W 2678.78 S 68 37 W 2753.39 S 68 34 W 2827.86 S 68 28 W 2902.44 S 68 24 W 2976.99 S 68 25 W 3051.37 S 68 30 W 3125.78 S 68 32 W 3200.24 S 68 24 W 3274.59 S 68 33 W 3348.67 S 68 37 W 3422.50 S 68 39 W 3496.23 S 68 31 W 3569.67 S 68 22 W 3642.89 S 68 ZZ W 3715.99 S 68 23 W 3788.77 S 68 3 W 3861.37 S 67 43 W 3934.14 S 67 :4 W 4007.94 S 66 52 W 4083.04 S 66 59 W 4159.05 S 66 35 W 4235.22 S 65 59 W 4311.14 S 65 36 W 4386.83 S 65 32 W 4462.40 S 65 28 W 4537.92 S 65 24 W 4613.54 S 65 8 W 4689.48 S 64 36 W 4765.67 S 63 34 W 4839.70 S 63 24 W 4912.99 S 62 47 W 4986.76 S 60 48 W 5058.96 S 60 28 W 5129.81 S 60 20 W 5200.86 0.48 I .97 1 1.19 1.62 0.61 0.69 0.68 0 0.28 0.31 0.22 0.18 0.25 0.19 0.22 0.54 0.20 0.07 0.15 0.25 0.25 0.95 1.19 1.27 0.18 0.45 0.48 0.11 0.17 0.21 0.18 0.77 3.35 0.23 0.77 1.92 1.44 0.36 0.32 760.76 S 2165.39 W 229.5.14 S 70 38 W 788.69 S 2240.08 W 2374.87 $ 70 36 W 816.68 S 2313.38 W 2453.31 S 70 33 W 845.50 S 2385.36 W 2530.77 S 70 28 W 873.30 S 2455.97 W 2606.62 S 70 25 W 899.79 S 2525.81 W 2681.29 S 70 23 W 926.75 S 2595.39 W 2755.89 S 70 20 W \ 953.93 S 2664.73 W 2830"33 S 70 18 ~, ) 981.23 S 2734.14 W 2904.88 S 70 15 W 1008.62 S 2803.47 W 2979.39 S 70 12 W 1036.00 S 2872.64 W 3053.74 S 70 10 W 1063.30 S 2941.87 W 3128.13 S 70 7 W 1090.56 S 3011.15 W 3202.56 S 70 5 W 1117.85 S 3080.32 W 3276.89 S 70 3 W 1145.02 S 3149.24 W 3350.94 S 70 I W 1171.98 S 3217.98 W 3424.75 S 69 59 W 1198.82 S 3286.66 W 3498.47 S 69 57 W 1225.63 S 3355.03 W 3571.89 S 69 55 W 1252.52 S 3423.14 W 3645.09 S 69 54 W 1279.48 S 3491.09 W 3718.17 S 69 52 W 1306.27 S 3558.77 W 3790.93 S 69 50 W 1333.21 S 3626.18 W 3863.50 S 69 48 W 1360.57 S 3693.62 W 3936.24 S 69 46 W 1388.94 S 3761.75 W 4009.97 S 69 44 W 1418.37 $ 3830.85 W 4084.99 S 69 40 W 1448.13 $ 3900.80 W 4160.93 S 69 37 W 1478.11 S 3970.8.4 W 4237.03 S 69 34 W 1508.64 S 4040.38 W 4312.85 S 69 31 {, ',) 1539.73 S 4109.45 W 4388.43 S 69 27 W 1571.01 S 4178.31 W 4463.90 S 69 23 W 1602.36 S 4247.09 W 4539.31 S 69 19 W 1633.80 S 4315.94 W 4614.83 S 69 15 W 1665.57 S 4385.01 W 4690.67 S 69 12 W 1697.88 S 4454.12 W 6766.76 S 69 8 W 1730.40 S 4520.82 W 4840.67 S 69 3 W 1763.22 S 4586.59 W 4913.84 S 68 58 W 1796.59 S 4652.66 W 4987.48 S 68 53 W 1830.94 S 4716.64 W 5059.55 S 68 47 W 1866.04 S 4778.85 W 5130.26 S 68 40 W 1901.44 S 4841.17 W 5201.19 S 68 33 W ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 20-JUN-88 PAGE 3 DATE DF SURVEY: 05-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000.00 5723.57 5665.57 46 30 8100.00 5791.87 5733.87 47 23 8200.00 5859.02 5801.02 48 12 8300.00 5925.17 5867.17 48 56 8400.00 5990.42 5932.62 49 31 8500.00 6055.06 5997.06 ¢9 55 8600.00 6119.31 6061.31 50 4 8700.00 6183.45 61Z5.45 50 7 8800.00 6247.77 6189.77 49 44 8900.00 6312.79 6254.79 49 12 9000.00 6378.24 6320.24 49 9100.00 6443.67 6385.67 49 17 9200.00 6508.75 6650.75 49 25 9300.00 6573.55 6515.55 50 9400.00 6637.65 6579.65 50 8 9450.00 6669.70 6611.70 50 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 60 7 W 5272.37 S 60 4 W 5364.73 S 59 57 W 5418.12 S 59 5~ W 5492.60 S 59 51 W 5567.44 S 59 37 W 5642.96 S 59 39 W 5718.80 S 59 43 W 5796.72 S 59 45 W 5870.51 S 60 20 W 5945.78 0.81 1.10 0.80 0.73 0.52 0.42 0.07 0.39 0.81 0.28 1937.26 S 6903.81 W 5272.60 S 68 26 W 1973.68 S 4967.12 W 5344.87 S 68 19 W 2010.70 S 5031.30 W 5418.20 S 68 12 W 2068.26 S 5096.22 W 5692.43 S 68 6 W 2086.21 S 5161.80 W 5567.45 S 67 59 W 2124.68 S 5227.69 W 5662.96 S 67 52 W 2163.40 S 5293.82 W 5718.81 S'67 66 W 2202.15 S 5360.03 W 5794.78 S 67 39 W 2260.76 S 5626.16 W 5870.62 S 67 33 W 2~.78.67 S 5492,00 W 5945.95 S 67 27 W S 60 19 W 6020.74 S 59 51 W 6095.66 S 59 50 W 6170.82 S 60 37 W 6246.28 S 60 40 W 6322.42 S 60 40 W 6360.69 0.50 0.35 0.20 6.12 0.00 0.00 2316.02 S 5557.74 W 6021.00 S 67 22 W 2353.79 S 5623.27 W 6096.02 S 67 17 W 2391.93 S 5688.91 W 6171.30 S 67 11 W 2429-91 S 5754.93 W 6246.89 S 67 6 W 2467.50 S 5821.84 W 6323.16 S 67 I W 2486.29 S .5855.30 W 6361.31 S 66 59 W ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 20-JUN-88 PAGE 4 DATE DF SURVEY: 05-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -58.00 0 0 1000.00 973.55 915.55 25 23 2000.00 1746.32 1688.32 51 8 3000.00 2391.78 2333.78 47 54 4000.00 3061.18 3003.18 53 13 5000.00 3711.67 3653.37 48 3 6000.00 4387.02 4329.02 46 3Z 7000.00 5048.84 4990.84 49 7 8000.00 57Z3.57 5665.57 46 30 9000.00 6378.24 6320.24 49 2 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE . SECTION SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 69 45 W 168.95 S 67 11 W 787.88 S 69 21 W 1551.41 S 69 30 W 2292.53 S 68 25 W 3051.37 S 68 23 W 378,9.77 S 65 28 W 4537.92 S 60 7 W 5272.37 S 60 19 W 6020.74 9450.00 6669.70 6611.70 50 8 S 60 40 W 6360.49 0.00 3.08 3.03 0.20 0.48 0.31 0.25 0.21 0.81 0.50 0.00 N 0.00 E 0.00 N 0 0 E 46.05 S 163.65 id 1'70.00 S 74 17 W 2Z9.43 S 757.18 W 791.17 S 73 8 W 514.42 S 1465.53 W 1553.19 S 70 39 W 760.76 S 2165.39 W 2295.14 S 70 38 W 1036.00 S 2872.64 W 3053.74 S 70 10 W 1306.27 S 3558.77 W 3790.93 S 69 50 W '~,, 1602.36 S 42,~7.09 d 4539.31 S 69 19 ~ 1937.26 S 6903.81 W 5272.60 S 68 26 W 2316.02 S 5557.74 W 6021.00 S 67 22 W 0.00 2486.29 S 5855.30 W 6361.31 S 66 59 W ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: 20-JUN-~8 PAGE 5 DATE OF SURVEY: 05-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 58.00 58.00 0.00 0 7 S 55 33 E 158.00 158.00 100.00 0 33 N 22 9 E 258.01 258.00 200.00 0 34 N 14 2 W 358.07 358.00 300.00 3 34 S 73 35 W 458.61 458.00 &O0.O0 8 0 S 72 37 W 560.12 558.00 500.00 11 24 S 75 59 W 662.81 658.00 600.00 14 52 S 75 I W 767.18 758.00 700.00 18 24 S 74 35 W 873.92 858.00 800.00 22 5 S 74 6 W 982.86 958.00 900.00 24 50 1094.59 1058.00 1000.00 27 56 1209.71 1158.00 1100.00 31 34 1329.59 1258.00 1200.00 35 13 1454.82 1358.00 1300.00 38 23 1585.13 1458.00 1400.00 41 37 1721.62 1558.00 1500.00 44 24 1864.75 1658.00 1600.00 47 14 2018.69 1758.00 1700.00 51 21 2177.93 1858.00 1800.00 50 18 VERTICAL DOGLEG RECTANGULAR'COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST- AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 2331.84 1958.00 1900.00 49 33 2489.91 2058.00 2000.00 50 31 2644.59 2158.00 2100.00 49 31 2798.44 2258.00 2200.00 48 53 2949.50 2358.00 2300.00 48 6 3098.46 2458.00 2400.00 47 27 3245.13 2558.00 2500.00 46 40 3390.54 2658.00 2600.00 46 30 3535.37 2758.00 2700.00 46 20 3680.97 2858.00 2800.00 46 45 0.00 0.00 0.00 N 0.00 E -0.01 1.08 0.00 S 0.01 E -0.49 0.30 0.44 N 0.35 E -1.08 2.29 1.34 N 0.62 E 1.83 3.85 0.92 N 2.35 W 11.80 4.24 2.22 S 11.83 W 28.99 3.00 6.74 S 28.55 W 52.08 3.35 12.51 S 51.13 W 81.69 3.99 118.69 2.35 3832.21 2958.00 2900.00 50 44 3994.68 3058.00 3000.00 53 13 4159.10 3158.00 3100.00 51 33 4317.67 3258.00 3200.00 50 2 4469.50 3358.00 3300.00 48 23 4619.75 3458.00 3400.00 48 11 4769.70 3558.00 3500.00 48 15 4919.70 3658.00 3600.00 48 3 5069.35 3758.00 3700.00 48 6 5219.14 3858.00 3800.00 48 5 · S 70 5 W 161.74 S 71 25 W 211.51 S 73 46 W 268.28 S 75 41 W 333.87 S 76 53 W 408.41 S 76 5 W 490.87 S 72 15 W 583.23 S 68 51 W 685.49 S 66 56 W 802.47 S 67 42 W 926.38 S 67 32 W 1043.37 S 68 8 W 1165.78 S 68 23 W 1283.76 S 68 28 W 1400.68 S 69 20 W 1513.88 S 69 41 W 1624.24 S 70 10 W 1731.47 S 70 22 W 1836.94 S 70 53 W 1941.60 S 71 30 W 2047.23 S 71 39 W 2160.39 S 69 30 W 2288.27 S 69 3 W 2418.73 S 68 4 W 2541.77 S 69 15 W 2655.99 S 68 36 W 2768.11 S 68 30 W 2879.83 S 68 24 W 2991.6& S 68 29 W 3102.97 S 68 30 W 3214.49 0.00~ N 0 0 F. 0.01 'S 84 26 E 0.56 N 38 11 E 1.47 N 24 49 E 2.52 N 68 36 W 12.04 S 79 22 W 29.34 S 76 42 F 52.64 S 76 15 k 20.39 S 79.89 W 82.45 S 75 41 W 30.30 S 115.79 W 119.69 S 75 20 W 3.40 2.83 3.6Z 3.43 1.67 3.27 2.78 3.25 1.82 1.70 43.60 S 156.86 W 162.81 S 74 28 W 60.24 S 203.81 W 212.53 S 73 3I W '77.24 S 258.19 W 269.50 S 73 20 W 94.52 S 321.96 W 335.55 S 73 38 W 112.38 S 395.15 W 410.82 S 74 7 W 131.16 S 476.52 W 494.25 S 7'4 36 W 157.07 S 565.69 W 587.09 S 74 28 W 191.50 S 662.08 W 689.2Z S 73 52 W 235.14 S 770.61 W 805.69 S 73 I W 283.37 S 884.76 W 929.03 S 72 14 W 2.77 1.90 1.85 0.80 0.71 1.16 0.46 0.32 0.89 0.47 327.40 S 993.15 W 1045.73 S 71 45 W 374.05 S 1106.32 W 1167.84 S 71 19 W 417.09 S 1216.19 W 1285.72 S 71 4 W 460.43 S 1324.78 W 1402.51 S 70 50 W 501.18 S 1430.41 W 1515.67 S 70 41 W 539.98 S 1533.77 W 1626.04 S 70 36 W 576.67 S 1634.59 W 1733.33 S 70 34 V 612.26 S 1733.98 W 1838.89 S 70 33 k ) 647.20 S 1832.74 W 194.3.66 S 70 33 W 681.23 S 1932.94 W 2049.47 S 70 35 W 1.76 0.46 0.83 1.72 0.55 0.65 0.62 0.29 0.31 0.22 716.67 S 2040.67 W 2162.86 S 70 38 W 759.27 S 2161.40 W 2290.88 S 70 38 W 805.15 S 2283.57 W 2421.35 S 70 34 W 850.55 S 2397.93 W 2544.31 S 70 28 W 891.69 S 2504.50 W 2658.50 S 70 24 W 932.11 S 2609.10 W 2770.60 S 70 20 W 972.94 S 2713.10 W 2882.28 S 70 16 W 1014.02 S 2817.10 W 2994.04 S 70 12 W 1054.94 S 2920.6¢ W 3105.32 S 70 8 W 1095.78 S 3024.41 W 3216.80 S 70 5 W ARCO ALASKA~ INC. 3 0-15 KUPARUK NORTH SLOPE ~ ALASKA COMPUTATION DATE: 20-JUN-88 PAGE 6 DATE OF SURVEY: 05-JUN-88 KELLY BUSHING ELEVATION= 58.00 FT ENGINEER: M. MCBRIOE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET OEG/IO0 FEET FEET FEET OEG MIN 5368.42 3958.00 3900.00 47 44 5516.75 4.0 58.00 4000.00 47 32 5664.53 ~.158. O0 4100.00 47 10 5811.42 4.258.00 4.200.00 47 l 5957.75 4.35'8.00 4300.00 46 40 6103.21 4.458.00 4400.00 46 36 6249.50 4.558. O0 4500.00 47 32 6400.19 4.658.00 4600.00 49 7 6554.32 4.758.00 4700.00 49 37 6708.19 4.858.00 4800.00 4.9 18 6861.23 4.958.00 4900'.00 49 8 7013.99 5058.00 5000.00 49 8 7167.30 5158.00 5100.00 ,4.9 33 7321.41 5258.00 5200.00 ¢8 31 7469.46 5358.00 5300.00 47 24 7617.92 5458.00 5400.00 47 14 7762.01 5558.00 5500.00 45 32 7905.27 5658.00 5600.00 45 56 8050.21 5758.00 5700.00 46 54 8198.48 5858.00 5800.00 48 12 8350.17 5958.00 5900.00 49 16 8504.56 6058.00 6000.00 49 56 8660.30 6158.00 6100.00 50 7 8815.81 6258.00 6200.00 49 38 8969.11 6358.00 6300.00 49 5 9122.00 6458.00 6400.00 49 22 9275.92 6558.00 6500.00 49 42 9450.00 6669.70 6611.70 50 8 S 68 30 W 3325.31 S 68 38 W 3434.86 S 68 33 W 3543.66 S 68 21 W 3651.25 S 68 25 W 3758.07 S 68 3 W 3863.71 S 67 23 W 3970.47 S 66 52 W 4083.18 S 66 50 W 4200.45 S 65 56 W 4317.35 S 65 34. W 4433.10 S 65 29 W 4548.49 S 65 15 W 4664.58 S 64 18 W 4781.67 S 63 27 W 4890.55 S 62 26 W 4999.89 S 60 29 W 5102.90 S 60 19 W 5204.62 S 60 4 W 5308.57 S 59 57 W 5417.00 S 59 58 W 5529.97 S 59 3'7 W 5646.41 S 59 3,8 W 5764.57 S 59 49 W 5882.44 S 60 24 W 5997.60 S 59 51 W 6112.18 S 60 17 W 6228.05 S 60 40 W 6360.49 0.24 0.23 0.13 0.06 0.56 0 1.81 1.27 0.42 0.50 0.03 0.13 0.79 3.15 0.73 2.90 0.17 0.35 0.84 0.80 0.58 0.40 0.27 0.87 0.33 0.27 1.61 0.00 1136.48 S 3127.50 W 3327.59 S 70 I W 117.6.48 S 3229.49 W 3437.11 S 69 59 W 1216.12 S 3330.83 W 3545.89 S 69 56 W 1255.60'S 3430.91 W 3653.45 S 69 53 W 1294.97 S 3530.22 W 3760.24 S 69 51 W 1334.08 S 3628.35 W 3865.84 S 69 48 W 1374.43 S 3727.19 14 3972.53 S 69 45 W 1418.42 S 3830.98 W 4085.13 1464.36 S 3938.90 W 4202.29 S 69 36 W 1511.18 S 4046.05 W ¢319.05 S 69 31 W 1558.88 S 4151.62 W 4.434.64 S 69 25 W I606.75 S 4256.72 W 4549.87 S 69 I9 W 1655.12 S 4362.38 W 4665.81 S 69 13 W 1704.84 S 4668.56 W 4782.73 S 69 7 W 1753.15 S 4566.~6 W 4891.43 S 68 59 W 1802.66 S 4654.37 W 5000.59 S 68 52 W 1852.67 S 4755.24 W 5103.40 S 68 42 W 1903.31 S ~844.46 W 5204.94 S 68 33 W 1955.4T S 4935.49 W 5308.76 S 68 23 W 2010.13 S 5030.32 W 5417.08 2067.24 S 5129.06 W 5529.98 S 68 2 W 2126.44 S 5230.70 W 5646.41 S 67 52 W 2186.78 S 5333.73 W 5764.61 S 67 42 W 224.6.79 S 5436.58 W 5882.56 S 67 32 W 2304.48 S 5537.45 W 5997.8.3 S 67 24 W 2362.17 S 5637.69 W 6112.56 S 67 15 W 2420.83 S 5738.94 W 6228.63 S 67 7 W 2486.29 S 5855.30 W 6361.31 S 66 59 k ARCO ALASKAt INC. 3 O-Z5 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TO COMPUTATION DATE: 20-JUN-88 PAGE 7 DATE OF SURVEY= 05-JUN-88 KELLY OUSHING ELEVATION: 58.00 FT ENGINEER:' M. MCBRIDE INTERPOLATEO VALUES FOR CHOSEN HORIZONS MEASUREO DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1084 FNL~ Z048 FWLt SEC. 2Zs'TZ3N, RgE,UM TVO RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 9006.00 6382.17 6324.17 2318.27 S 9025.00 6394.62 6336.6Z 2325.40 S 9068.00 6422.77 6364.77 2341.64 S 9213.00 6517.21 6459.21 2396.89 S 9339.00 6598.56 6540.56 2444.57 S 9450.00 6669°70 6611.70 2486.29 S 5561o67 W 5574o13 W 5602.30 W 5697.45 W 5781.02 W ) 5855.30 W ARCO ALASKA, INC. 3 0-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 20-JUN-gB · PAGE ' B DATE OF SURVEY:' 05-JUN-88 KELLY BUSHING ELEVATION: 58°00 FT ENGINEER: M. MCBRIDE · ~~:~:~ STRATIGRAPHIC SUMMARY MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MEASURED DEPTH BELOW KB 9006.00 9025.00 9068.00 9213.00 9339.00 9450.00 FROM KB SURFACE LOCATION AT ORIGIN= 1084 FNL, Z048 FWL, SEC. 22, T13N, RDE,UM TVO RECTANGULAR COORDINATES SUS-SEA NORTH/SOUTH EAST/WEST 6382.17 6324.17 2318.27 S 5561.67 W 639¢.6Z 6336.62 2325.40 S 5574.13 W 6422.77 6364.77 2341.64 S 560Z.30 W 6517.21 6459.21 2396.89 S 5697,45 W 6598.56 6540.56 2444.57 S 5781.02 W 6669.70 6611.70 2486.29 S 5855.30 W i) FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9450.00 6669.70 6611.70 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET OEG MIN 6361.31 S 66 59 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY WELL FIELO COUNTRY ARCO ALASKA, INC. 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H-~"-~ ..... ~.--~--.~-~-H-++..f-~-+-H---{ · -'~ ....... ~'"~ ...... *'"*'"~'"~ ...... f"f"N ........ kghBd'-?"f"~ ....... f"f"f"~ ...... f"f"N' H"i'"?"f"~'"f"f"f"t ....... ~...H---~ ....... ~-+.-~-.-.~ ....... H--.H ....... H--+--.~ ...... H.--H -.I-..{...}...~...~"'~"T"~'"~ ....... ~'"~'"~'"~ ..... 4,.--~..+.4 ....... ~...~...~..-~-.-~-..~.-+.-~..-~ ...... {..+.+..~ ...... ~.-+..~-~--. ~-+.4-~-~--.~..-~..+.+-.~ ...... ~-....-+--~ ....... ~-.4--+.-.~ ........ ?~..-~----~ ........ F.4-.-~---+ ....... F--~--+.-~ ...... ~...~--.{---+ .... PROJECTION ON VERTICAL PLANE 248. - 68. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT ARCO Alaska, Inc. Date: March 24, 1989 Transmittal Ct: 7447 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360. Please aCknowledge receipt and return '-,. 30-1 6 --- 30-10 '"--- 30'-13 .,,..,,~ 3 O- 03 .,,~ 30-15 · -.~ 2G-14 ~ 2G-13 · '~,~ 2G-09 ~ 1 E-05 30-18 ""~ 3H-10 ~3A-03 '"~3H-04 ~2B-14 ~30-13 e,~30-10 "~'~ 30-16 ~"1 B-07 '"'"',,1 B-03 ""~"- 1 B- 05 '""'"~1 B-07 ~1B-07 '~1L-08 ~,,,~1L-04 ~"'"~3 H- 1 0 '~',,,. 3 M- 01 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kuparuk Fluid Level Report Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report 1-3-189 2-04-89 2-08-89 I -09-89 3-04-89 3-11-89 3-11-89 3-11-89 3-O9-89 3-O9-89 3-O9-89 3-09-89 3-09-89 3-04-89 3-13-89 :2-O8-89 2-04-89 I -31 -89 3-31 -88 1 -27-88 1 -27-88 4-27-88 1 -27-88 2-12-88 2-12-88 Sand 'A' Sand 'A' Sand 'A' Sand 'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing 3-17-89 C..as,~g tasi~a .... ~.~ Coils. ~chorage ~ O- 09 Kuparuk Fluid Level Report 3 - 18 - 89 Casing '~'"~3 O-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~'=*30-18 Kuparuk Fluid Level Report 3-1 7-89 Casing '~::~BO-09 Kuparuk Fluid Level Report 3- 1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing Receipt Acknowledged' - .......................... Date' - ........... DI,.STRIBUTION' D&M State of Alaska SAPC Chevron Unocal Mobil "-'" STATE OF ALASKA ALA,_, ,A OIL AND GAS CONSERVATION COMMIS,... ON REPORT OF SUNDRY WELL OPERATIONS t. Operations performed: Operation shutdown __ Stimulate __ Plugging B Perforate m Pull tubing ~ Alter casing __ Repair well __ Pull tubing ~ Other'~ ~'¢0RKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 1003,60, Anchorage, AK 4. Location of well at surface 99510-0360 1084' FNL, 2048' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1878' FSL, 1766' FWL, Sec.21, T13N, R9E, UM At effective depth 1751' FSL, 1547' FWL, Sec.21, T13N, R9E, UM At total depth 1710' FSL, 1473' FWL, Sec.21, T13N, R9E, UM 5. Type of Well: Development ~._ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) RKB 58 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-15 9. Permit number/approval number 88-31/8-810 10. APl number 50-- 029-21797 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 9450'MD ~ 6670'TVD feet Plugs (measured) None Effective depth: measured true vertical 9339'MD feet 6599'TVD feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2739' 9389' measured 9148'-9168'MD trueve~ical 6475'-6488'TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail ~ 8938' Packers and SSSV (type and measured depth) Size 16" 9-5/8" 7" Cemented 175 sx AS I 1000 sx AS III & 300 sx AS II 600 sx TLW & 390 sx Class G Baker 'HB' pkr @ 8864' & Camco 'TRDP-1A-SSA' 555V @ 1786' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure None Measured depth True vertical depth 115'MD 2774'MD 115'TVD 2242'TVD 9422 'MD 6652'TVD i:C iVED 0il & Gas Cons, 14. N/A Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 1 t6. Status of well classification as: Copies of Logs and Surveys ruq__ I '% Daily Report of Well Operations ~ * Oil "v__ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service feet Form 10-404 Rev 06/15/88 *NOTE: Title Area Drilling Engineer Workover Well History (Dani) SW03/066 Date / ~/'¢?/Z,,~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O, no1 AK3072 ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25513 Title COMPT,F. TE state 30-15 jWell no. API: 50-029-21797 Operator ARCO IARCO W.I. 56.0000 . Prior status if a W,O. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 11/05/88 TD: 9450 PB: 9339 SUPV:CD/LB IDate IHour 11/4/88 I 1030 HRS Complete record for each day reported NORDIC 1 NU TREE 7"@ 9422' MW:10.0 NACL/NABR MIRU, ACCEPT RIG AT 1030 ON 11/4/88, DISPLACE WELL W/ 10 PPG BRINE, SET BPV, ND TREE, NU BOPE AND TEST, SPEAR TBG, POH, LD TBG HGR AND SSSV, PU NEW SSSV AND RIH, SPACE OUT, PU NEW TBG HGR, LAND TBG, TEST TBG, TEST ANNULUS TO 2500 PSI FOR 30 MINUTES, TEST SSSV, SET BPV, ND BOPE, NU TREE. NOTE: CAMCO 'TRDP-1A-SSA' SSSV @ 1786', BAKER 'HB' PKR @ 8864' & TT @ 8938'. DAILY:S40,880 CUM:$982,917 ETD:S982,917 EFC:$1,425,000 For form prepara~#'~ ~'~d distribution,C~ see Procedures ~la~ual, Section 10, Drillino, Panes 8&..a~nd 87. I Oate / /I , / . j ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is 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. Accounting coat center code District ARCO Alaska, Inc. [C°untycl[l~[i~ SLOPE Stat~K ~ie,d KUPARUK RIVER UNIT L~e ~) r~''-~''~'. 2-'~'~ 30-15 IWell no. Auth. or W.O.~3072 l'riue ~E~'-~' API: 50-029-21797 Operator ARCo Spudded or WA(~~ Co. Ee~0000 11/4/88 dnumber of wells (active or inactive) on this, center prior to plugging and onment of this well Date and depth as of 8:00 a.m. 11/06/88 ( 1. TD: 9450 PB: 9339 SUPV:CD/LB ~ rec,~:[f~l~Chl,, day reported Old TD New TD Released rig Date ClasSifications (oil, gas, etc.) RIG RELEASED 7"@ 9422' MW: 0.0 DIESEL NU TREE, TEST TREE TO 5000 PSI, OPEN SSSV, DISPLACE WELL TO DIESEL, TEST ORIFICE VALVE, SET BPV, RELEASE RIG AT 1130 HRS, 11/5/88 DAILY=S34,871 CUM=$1,017,788 ETD:S1,017,788 EFC=$1,425,000 K~iBnDepth tType completion (single, dual, etc.) ~' ~ name(s) Producing method Potential test data Well no. [Date Pump size, SPM X length Reservoir Producing Interval Choke size The above is correct see Procedurals ~ranual, Section 10, Drilling, Pages"'86 and 87. Test time Production OII on test Gas per day Gravity Allowable Effective date corrected '-'"' ~ STATE OF ALASKA ""' A L,-,,.,KA OIL AN D GAS CONSERVATION COM M I,.,,.,, ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ____ Alter casing __ Repair well ~/' Change approved program __ 2. NameofOperator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360~ Anchorage¢ AK Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other 5. Type of Well: Development Exploratory Stratigraphic .9951 0 I' 0360 Service 6. Datum elevation (DF or KB) RKB 58 ' 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 8. Well number 30-15 1084' FNL, 2048' FWL, Sec.22, T13N, RgE, UM At top of productive interval 9. Permit number 1878' FSL, 1766' FWL, Sec.21, T13N, R9E, UM At effective depth 1547' FWL, Sec.21, T13N, RgE, UM 1473' FWL, Sec.21, T13N, R9E, UM 1 751 ' FSL, At total depth 1 71 0 ' FSL, 12. Present well condition summary Total depth: measured true vertical 9450 ' M D feet Plugs (measured) 6670 ' TVD feet 9339 'MD feet Junk(measured) 6599 ' TVD feet Size Cemented Effective depth: measured true vertical 16" 175 sx AS I 9-5/8" 1000 sx AS III 300 sx AS II 7" 600 sx TLW & 390 sx Class G 91 48' -91 68 'MD Casing Length Structural Conductor 80 ' Surface 2739 ' Intermediate Production 9389 ' Liner Perforation depth: measured true vertical RR-~,I? & R-~l 10. APl number 50-- 029-21797 11. Field/Pool Kuparuk River Oil None None Measured depth 6475 ' -6488 ' TVD 115'MD & 2774 'MD 9422'MD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail ~ 8937' Packers and SSSV (type and measured depth) HB pkr @ 8863' and FVLD SSSV @ 1785' 13. Attachments Description summary of proposal ¢' Detailed operations program __ BOP sketch v/ 14. Estimated date for commencing oPeration Nove. mber 1~ 1..,988 , 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~, Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ( D a n Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved Copy ORIGINAL SIGNED BY Returned LONNIE C. SMITH Approved by order of the Commissioner Date /~,//Z S A 4 / 01 21 Approval No. feet Pool True vertical depth llS'TVD 2242 'TVD 6652 ' TVD Date/0 -~:~,,1'~ --,~ ~ SUBMIT IN TRIPLIOATE Commissioner Form !0-403 Rev 06/15/88 Kuparuk River Unit Well 30-15 Preliminary Workover Procedure Summary: The purpose of this workover is to replace the top joint of tubing and the tubing hanger. This equipment was damaged during a hydraulic fracture treatment when the treesaver failed. This allowed sand laden fluid to erode the tubing hanger. Testing of the wellhead has shown the tubing hanger does not have pressure integrity. Pre-Rig Operations 1. MIRU slickline unit. 2. RIH and tag fill. 3. Obtain BHP. 4. Set BP in D-Nipple, Rig Operations 1. MIRU Nordic #1. 2. Circulate kill weight fluid into well. 3. ND tree. NU BOPE. Test BOPE. 4. Spear tubing below tubing hanger. POH. LD hanger and damaged tubing. 5. Run completion with new hanger. 6. ND BOPE. NU new tree and new adapter flange. 7. Displace well to diesel. 8. Secure well. Release rig. Completion Fluid = NaCI/NaBr Brine Expected BHP -- $/o~ Psi Anticipated Start Date = /t,~ × ~ ANNULAR PREVENTER § PIPE RArl$ 4 BLIND RAHS '5 TUBIN6 HEAD 1. 16' CONDUCTOR SWAGED TO 10-:5/4" 2. 11'-:5000 PSI STARTING HEAD 11"-5000 PSI X 7-1 / 16"-5000 TUBING HEAD 4. 7-1/16" - $000 PS1 PIPE RAMS ,5. 7-1/16" - 5000 PSI BLIND RAHS 6. 7-1 / 16" - 5000 PSI ANNULAR Accur'tULATOR CAPACITY TEST 1. CHECK AND FILL AccurULATOR RESERVOIR TO PRC~ER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PI~SSLIRE IS :5000 PSi WITH 1500 PSI DOWNSTREAH OF THE REGULATOR. :5. OBSERVE TIrlE, THEN CLOSE ALL UNITS sIrULTA~SLY AND RECORD THE TlrlE AND PRESSURE REMAININ~ AFTER ALL UNITS ARE CLOSED WITH CHARGING PUI"IP OFF, 4. RECORD ON THE IADC REPORT., THE ACCEPTABLE LOWER LIr'IlT IS 45 SECONDS CLOSII~ TIrE ANO 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCPEIw~ ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-OOWI~ SCREW~ IN HEAD. CLOSE ANNULAR PREVENTER AND I~HOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COt'IPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI ANO HOLD FOP. 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RArlS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9, OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR[ 10 I'IlNUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO :5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO :~000 PSI WITH KCX:)FIEY PUHP. 1:~. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN ANO SEND TO ORILLING SUPERVISOR. 14. PERFORM COI'lPLETE BOPE TEST ONCE A ~E:EK AND FUNCTIONALLY OPERATE BOPE DAILY. ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. t30-1 5 Kuparuk Fluid Level Report 7- 1 1 - 8 8 30-10 Kuparuk Fluid Level Report 7- 1 1 -88 2 D- 1 5 Kuparuk Fluid Level Report 7 - 1 2 - 8 8 2A-06 Kuparuk Fluid Level Report 7-1 2-88 1G-07 Kuparuk Fluid Level Report 7- 0 8 - 8 8 1G-08 Kuparuk Fluid Level Report 7- 0 8 - 8 8 1 G- 1 5 Kuparuk Fluid Level Report 7 - 0 8 - 8 8 31 - 01 Kuparuk Fluid Level Report 7- 0 8 - 8 8 31 - 1 2 Kuparuk Fluid Level Report 7- 0 8 - 8 8 2 A- 0 3 Kuparuk Fluid Level Report 7- 0 6 0 8 8 3 H - 1 4 Post Frac Job Report 7 - 0 9 - 8 8 2 B - 1 6 Bollom Hole Pressure' Survey 7 - 0 3 - 8 8 3 J - 1 0 Kuparuk Well Pressure Report 3 - 0 8 - 8 8 Receipt Tubing Tubing Casing Tubing Casing Casing Casing Tubing Tubing Casing AIIo Frac A-10 PBU Amerad Acknowledged: --'- ........................ Date: ............ DISTRIBUTION; D&M State of Alaska SAPC Mobil Unocal Chevron r--. STATE OF ALASKA ~ ALAS,,,-, OIL AND GAS CONSERVATION COM; .... $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] PerforateX3 Pull tubing Alter Casing [] Other E~ CHANGE BHI'. & COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1084' FNL, 2048' FWL, 5ec.22, T13N, RgE, UM At top of productive interval 1878' FSL, 1766' FWL, Sec.21, T13N, RgE, UM At effective depth 1751' FSL, 1547' FWL, Sec.21, T13N, RgE, UH At total depth 1710' FSL, 1473' FWL, Sec.21, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 58 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-15 8. ApproVal number 8-312 & 8-431 9. APl number 50-- 029-21797 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 9450 ' MD 6670 ' TVD Casing Conductor Surface measured 9339 'MD true vertical 6599'TVD Length Size 80 ' 16" 2739' 9-5/8" Production 9389' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth ~ue Vertical depth 175 sx AS I 115'MD 115'TVD 1000 sx'AS III & 2774'MD 2242'TVD 300 sx AS II 600 sx TLW & 9422'MD 6652'TVD 390 sx Class G Perforation depth: measured 9148'-9168'MD true vertical 6475'-6488'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8937' Packers and SSSV (type and measured depth) HB pkr @ 8863' & FVLD SSSV ¢ 1785' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well Hi_story w/Addendum, dated 6/15/88) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) 5W03/017 Submit in Duplicate Feet ADDENDUM WELL: 6/06/88 30-15 RU SOS. Rn CET f/9339'-2700'. Rn 6-1/8" GR. Rn GCT f/9303'-50'. RD Schl. rilli~' S~upervis~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is 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. Accounting cost center code District lState ARCO ALASKA INC. / AK / I County or Parish I NORTH SLOPE Field ILease or Unit I Well no. KUPARUK RIVER UNIT I ADL: 25513 30-15 I I Title I COMPLETE AND PERFORATE Auth. or W.O. no. A~3072 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a,m. 06/24/88 ( 1 TD: 9450 PB: 9339 SUPV:DL 06/25/88 ( 1 TD: 9450 PB: 9339 SUPV:KR/DL API: 50-029-21797 IA.R.Co. W.I. ~otal number of wells (active or inactive) on thisI ~ost center prior to plugging and 56,0000 ~bandonment of this well IDate / ~our I Prior status if a W.O. 06/23/88 / 1500 HRS Complete record for each day reported NORDIC 1 RIH WITH COMPLETION 7"@ 9422' MW:10.0 NACL/NABR MIRU. ACCEPT RIG @ 1500 HRS 6/23/88. ND TREE. NU BOPE AND TEST TO 3000 PSI. PERFORATE 'A' SAND FROM 9148'-9168' W/8 SPF, 45 DEGREE PHASING. RIH W/ 2-7/8" COMPLETION ASSEMBLY. DAILY:S48,488 CUM:$819,536 ETD:S819,536 EFC:$1,425,000 RELEASED RIG 7"@ 9422' MW: 6.9 DIESEL SET PACKER. TESTED TUBING, ANNULUS AND SSSV. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. SET BPV. SECURED WELL AND RELEASED RIG @ 1600 HRS, 6/24/88. (TAIL @ 8937', 'FVLD' SSSV @ 1785', '~B' PACKER @ 8863') DAILY:S122,501 CUM:$942,037 ETD:S170,989 EFC:$2,196,048 Type completion (single, dual, etc.) Old TD J New TD I PB Depth I I Released rig I Date IKind of rig Classifications (oil, gas, etc.) Producing method Official reservoir name(s) 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 lengih Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature i~ ~).~,J~ ~/,~ ~,, IDate ITM "'/-ID-~'5 ASSOCIATE ENGINEER For form preparation ~1 distribution, see Procedures Manu~L/Section 10, Drilling, Pages 86 and 87. I E,MORANDUM ' State of Alaska ALASKA OIL AND GAS CONSERVATION COFR~ISSION TO: Lonnie C Smith CommisSioner DATE: July 12, 1988 FILE NO: D. HRH. 55 THRU: Michael T Minder /~'~C~<' Sr Petroleum Engineer TELEPHONE NO: SUBJECT.' BOP Test AAI KRU 30-15 Permit No. 88-31 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspec ~June 23, 1988: I left SAPC PBF 42 (44-21-11-12), subject of ~rts, t° AAI KRF to witness a BOP Test. There were no failures. I filled out an AOGCC Report which is attached. In summary, the BOP Test was performed by the NORDIC RIG, crew satisfactorily. Attachment 02-001A (Rev. 8/85) 0&G ~/4 5184 Insoector STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Well 'Operator .~_ ~ Location: Sec Drillin~ Contractor Location, General General Housekeeping Reserve Pit 0/( Mud Systems Visual Trip Tank ~ ~f. Pit Gauge ~ /4 Flow Monitor ~ ,/,{ Gas Detectors ~/~ Aud~io BOPE Stack Annular Preventer Pipe Rams Btind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures .... fV'~/./~ Upper KellM Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves / ~ No. flanges ~ F Representative p 0///~/d < ~ 7-/~/~/~ Permit # ~Casing Set @ ~ 2/~ ft. ----- Representative /~/~. ~/~/~ ~ ACCUMULATOR SYSTEM Full Charge Pressure _~ ~ psig Pressure After Closure /~~ psi~ ---- Pump incr. clos. pres. 200 psi~ ~ minf~sec. Full Charge Pressure Attained: / min ~f-sec. N2 , T~d ~Y~zF-~&z~ ~ Controls: Master Remote ~/~ Blinds switch cover · Kelly and Floor Safety Valves Test Pressure Test Pressure / Test Pressure ~-~ Test Pressure Test Pressure Adjustable Chokes Tf~,~ ~/~_c Hydrauica!ly operated choke Test Time ~ hrs. ~ Repair or Replacement of failed equipment to be made within~-~-----days and Inspector/ Commission office notified. Remarks: ~??Z/~ I~'ZL~¥ ~+~.z~ A~x--R z,~X~ >/ ~7~ ~b ~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: 7193 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30 - 1 3 Cement bond Log (CBT) 6 - 6 - 8 8 .. 6 4 9 0 - 7.81 8 3 O- 1 5 Cement Evaluation Log (CET) 6 - 5 - 8 8 2 6 9 5 - 9 3 2 4 3 O- 1 4 Cement Evaluation Log (CE'I') 6 - 5 - 8 8 2 2 9 5 - 8 0 0 6 If you have any questions, concerning this or any other transmittals please call me at 265-6835. ~-~ Receipt Acknowledged' - .......................... Date: ............ DISTRIBUTION: NSK Drilling State of Alaska(+sepm) .... .::;!:.:,.,~ STATE OF ALASKA ALASK,~, Oil AND GAS CONSERVATION COMM._dION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend .'-q Operation Shutdown ~ Re-enter suspended well D Alter casing C Time extension ~. Change aPproved program ~ Plugging D Stimulate D Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 5. Datum elevation (DF or KB) R K B 59 ' feet 6. Unit or Property name Kuparuk River Unit 7. Well number 30-15 8. Permit number 88-31 9. APl number 50-- 029-21 797 10. Pool Kuparuk River Oil Pool 4. Location of well at surface 1084' FNL, 2048' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1320' FSL, 1848' FWL, Sec. 21, T13N, RgE, UM (approx) At effective depth 1845' FSL, 1532' FWL, Sec. 21, T13N, R9E, UM (approx) At total depth 1804' FSL, 1456' FWL, Sec. 21, T13N, R9E, UM (approx) 9450 ' MD feet Plugs (measured) 671 6 ' TVD feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 9339 'MD true vertical 6643 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 2739 ' 9-5/8" feet Junk (measured) feet Cemented 175 sx AS i 1000 sx AS III & 300 sx AS II 600 sx TLW & 390 sx Class G None None Measured depth ~ue Verticaldepth 115'MD llS'TVD 2774'MD 2248'TVD 9422'MD 6698'TVD Production 9389' 7" Perforation depth: measured NONE true vertical NONE RECEIVED ~0rage ' Tubing (size, grade and measured depth) NONE Packers and SSSV (type and measured depth) NONE Description summary of proposal [] Detailed operations program [] BOP sketch 12.Attachments Well Hi story 13. Estimated date for commencing operation June 1 988 Subsequent Work l~ported on Form No. '~-2-~Datecl~)-/-~/~ Date approved 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~LLL~.¢..~ Title Associate Engineer Commission Use Only (Dani SA3/101) Conditions of approval Approved by I Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI ORIGINAL SIGNED BY LONNIE C. SMITH NO. Approved Copy Returned Commissioner Date by order of the commission Date Submit in triplicate Form 10-403 Rev 12-1-85 ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday afte; a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no, AK3072 lCounty, parish or borough · NORTH SLOPE Lease or Unit ADL: 25513 Title DRILL Jst~ 30-15 jWell no. API: 50-029-21797 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m, 04/30/88 ( TD: 1790'( 1 SUPV:JCP 05/01/88 ( TD: 2790'( 1 SUPv:jCp 05/02/88 ( TD: 4880'( 2 SUPV:JCP 05/03/88 ( 4 TD: 7130'( 22 SUPV:JCP 05/04/88 ( TD: 8460'( SUPV:JCP 05/05/88 ( TD: 9300'( SUPV:RB 05/06/88 ( TD: 9450'( SUPV:RB 05/07/88 ( TD= 9450'( SUPV:RB The above is correct J ARCO W.I. I°' I II IPrior status if a Complete record for each day reported DOYON 14 ) 90) oo) 90) ,0) ) 30) ~0) DRLG MW: 9.6 VIS:105 FIN MOVING RIG TO 30-15. NU DIVERTER SYSTEM. MU BHA. SPUD AT 1630 HRS ON 4/29/88. DRLD 12-1/4" HOLE W/ NAVI-DRL TO 1790'. DAILY:S69,665 CUM:$69,665' ETD:SO EFC:$1,494,665 50) TEST BOPE'S 9-5/8"@ 2774' MW: 9.4 VIS: 76 DRLD 12-1/4" HOLE TO 2790'. CIRC. SHORT TRIP. CIRC AND COND MUD. POOH. LD BHA. RU AND RUN 70 JTS OF 9-5/8" CSG W/ SHOE AT 2774' AND FC AT 2693'. CIRC. CMT CSG W/ 1000 SX OF AS III AND 300 SX OF AS II. CIP AT 0015 HRS 5/1/88. ND DIVERTER SYSTEM. NU BOPE STACK. RU AND TEST SAME. DAILY:S185,340 CUM:$255,005 ETD:S255,005 EFC:$1,425,000 DRLD 9-5/8"@ 2774' MW: 9.2 VIS: 42 FIN TEST BOPE'S. INSTALL WR. PU BHA AND RIH TO FC. TEST CSG TO 2000 PSI. OK. DRLD FLOAT EQUIP AND 15' NEW HOLE. PERFORM LOT. DRLD 8-1/2" HOLE TO 4880'. DAILY:S42,087 CUM:$297,092 ETD:S297,092 EFC:$1,425,000 DRLG 9-5/8"@ 2774' DRLD 8-1/2" HOLE F/ 4880' TO 7130'. DAILY:S43,309 CUM:$340,401 ETD:S340, MW: 9.3 VIS: 34 401 EFC:$1,425,000 MW: 9.4 VIS: 34 POOH FOR NEW BIT. DRLG 9-5/8"@ 2774' DRLD F/ 7130' TO 7156'. SURV. PUMP PILL TIH. DRLD F/ 7156' TO 8460' W/ NAVI-DRL. DAILY:S59,227 CUM:$399,628 ETD:S399,628 EFC:$1,425,000 POOH FOR LOGS 9-5/8"@ 2774' MW:10.0 VIS: 40 NAVIDRILL 8-1/2" HOLE TO 9300'. CIRC AND COND HOLE. PU KELLY ,,, ,o O,Eoo EiVE CIRCULATE. DROP SURVEY. PUMP DIESEL PILL. POOH FOR LOG~ DAILY:S52,010 CUM:$451,638 ETD:S451,638 EFC:$1,425 DRLG 9-5/8"@ 2774' MW: 9.9 VIS: POOH. RU $O$. RIH AND LOG W/ DIL/GR/SP/SFL F/ 9300' TO 2774', Ga F/ 9300 TO 2774 ~D¢/CNL F/ 9300' TO 8~ gllC~L~a F/ 9300' TO 2774'. RD SOS. MU BHA AND RIH. DRLD 8-1/2" ~OLE TO 9450'. DAILY:S45,755 CUM:$497,393 ETD:S497,393 EFC:$1,425,000 TEST WELLHEAD 7"@ 9422' MW:10.0 VIS: CIRC BTMS UP. SPOT PILL. POOH LDDP. RU AND RUN 236 JTS OF 7", 26# J55 BTC CSG W/ FC AT 93.41 AND FS AT 9422'. CMT CSG W/ 600 SX OF TLW AT 11.9 PPG AND 390 SX OF CLASS G AT !5_8 PPG_ CI? AT g!~3O HRS ~/~/~ ~m q~.~pq ~n ~T~¢K Signature {~ ~_-/ ~''/]~.FJ~ For form prepare~n and distribution, see Procedures/IV~nual, Section 10, Drilling, Pages J.~ and 87. Joete~.~ ITit,e AS,.9OCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "nler m" sheets until f nal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not ess frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District iCounty or Parish IState ARco Alaska, Inc. J NORTH SLOPE AK Field ,ILoase or Unit IWoll no. KUPARUK RIVER UNIT J 30-15 Date and depth IComplete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 NU TREE. DAILY:S222,386 CUM:$719,779 ETD:S719,779 EFC:$1,425,000 RECEIVED J U N ,l 0il & Gas Qms, Com~'~issi~) Anchorage The above is correct Signature For form preparatio/~'~n-d-dis-tributior~ -- see Procedures M~r)'ual Section 10, Drilling, Pages 86~d 87 Date ~"~)-~ ITit,eASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is 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~ ' IAcc°unting cost center code District I Stat~[K ARCO Alaska, Inc. Field County or Parish NORTH SLOPE ILease or Unit ADL: 25513 Title DRILL KUPARUK RIVER UNIT 30-15 JWell no. Auth. or W.O. no. AK3072 Operator ARco Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Date Complete record for each day reported API: 50-029-21797 W.I. ITotal number of wells (active or inactive) on this Icost center prior to plugging and I 56. 0000 labandonment of this well I IHour I Prlor status if a W.O. 04/29/88 | 163o I O5/08/88 ( TD: 9450'( SUPV:RB o) DOYON 14 RIG RELEASED 7"@ 9422' MW: 0.0 VIS: INJECT 60 BBLS OF DIESEL INTO 30-17. INJECT 60 BBL DIESEL INTO 30-15. TEST FLANGES AND PACKOFF TO 3000 PSI. RELEASE RIG @ 0800 HRS 5/07/88. DAILY:S51,269 CUM:$771,048 ETD :$771,048 EFC: $1,425,000 RECEIVED JUN i ii~,, ~ Oil & Gas Corts. Coni~'~:~iss~r~ Anchorage Old TD I New TD PB Depth I Released rig I Date I Kind of r g I I Classifications (oil. gas, etc.) Type completion (single, dual, etc,) Producing method I Off c a reservoir name(s) I 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 The above is correct ------A, A'PF' f-'ltd~ll~ti~f~IfA For form prepar{l(¥on and distribution, see Procedures ~bnual, Section 10, Drilling, Pages 86 and 87, ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7165 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '""~30-16A 5" Dual Induction 4-27-88 4600-8337 ~,30-16A Cyberlook 4-27-88 7500-8200 '"~O-16A 2" Dual Induction 4-27-88 4600-8337 ~'30-16A 2" & 5" Porsity FDC 4-27-88 7450-8311 ~,,~. O~¥30:16A 2"& 5" Raw FDC 4-27-88 7450-8311 15 5" Dual Induction 5 - 05 - 8 8 2773 - 9291 .~30-15 2" Dual Induction 5-05-88 2773-9291 .330-15 2" & 5"FDC 5-05-88 2773-9265' Porosity O-15 2" & 5" Raw FDC 5-05-88 2773-9265 30-15 Cyberlook 5-05-88 8700-9291 ~(~ Oe~ '30:TM Cyberlook 5-13-88 7490-8000 14 2" &5" Raw FDC 5-1 3-88 7490-8021 '"",80~'"~30:14 2"&5" Porosity FDC 5-13-88 7490-8021 14 2" Dual Induction 5-13-88 2364-8046 ""-,30-14 5" Dual Induction 5-13-88 2364-8046 ~'='~30-13 2" Dual Induction 5-21-88 4340-7945 ~,30-13 5" Dual Induction 5-21-88 4340-7945 ~'"'30-13 Cyberlook 5-21 -88 7300-7900 ~-30-13 2" & 5" Porosity FDC 5-21-88 7196-7919 -'~"' 30-13 2" & 5" Raw FDC 5-21-88 7196-7919 265-6835.1f you have any questions, concerning this or any other transmittals~F~~please caJ~me a~~ Alaska 0il & Gas G0ns. 60mn]iBai~}lt MEMORANDUM State uf Alaska ALAS~ OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith~2~ DATE: May 9, 1988 Commissioner ~,~,., t..¢¢5 F,LE NO: D. BDF. 106 THRU: Michael T Minder ~~~ Sr Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test AAI KRU DS 30-15 Permit No. 88-31 Kuparuk Rv Field FROM: Bobby D Foster i[~'>-~', Petroleum Inspector ~und_~_y, May 1.,..1988: The test began at 5:30 a.m. and was completed a~ 7:00 a~mi~ '~S'~U~e attached BOP test report shows, there were no failures. In summary, I witnessed the satisfactory BOP test on ARCO Alaska, Inc drill site 30-15. Attachment 02-00IA(Rev. 8/85) ' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Location: Sec Drillin8 Contractor t Location, General Date General Housekeeping ~ Rig ~ Reserve Pit ~.~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Test Pressure Annular Preventer / Pipe Rams Blind Rams / ~-~ Choke Line Valves / H.C.R. Valve / Kill Line Valves Check Valve -- -- Representative 9~Casing Set @ ~74 '~' ' Representative ACCUMULATOR SYST~ Full Charge Pressure ~o psi~ Pressure After Closure /~ psi~ Pump incr. clos. pres. 200 ps~K ~ min~/ sec. Full Charge Pressure Attained: ~ min~f sec. Controls: Master Remote ~~ Blinds sw~tch cover~5 Test Results: Failures Repair or Replacement of failed equipment to be made within Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ,~ Test Pressure No. Valves /V No. flanges Adjustable Chokes / Hyd~autcglly operated choke Test Time ] }/~ hrs. days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor STATE OF ALASKA ALASh,~ OIL AND GAS CONSERVATION COMN,,,-,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing r'_: Time extension [] Change approved program '~. Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate C Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1084' FNL, 2048' FWL, Sec.22, T13N, R9E, At top of productive interval (@ target) 2010' FSL, 1940' FWL, Sec.21, T13N, R9E, At effective depth N/A At total depth 1932' FSL, 1747' UM UM FWL, Sec.21, T13N~ R9E~ UM 5. Datum elevation(DF or KB) 6. UnitorProperty name Kuparuk River Unit 7. Well number 30-15 8. Permit number RR-31 9. APl number 50-- 029-21 797 10. Pool Kuparuk River Oil Pool feet 11. present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Perforation depth: measUred true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) feet feet Plugs (measured) feet feet Junk (measured) Cemented Measured depth True Vertical depth 12.Attachments Description summary of proposal 13. Estimated date for commencing operation April 28:, 1988 Detailed operations program [] BOP sketch 14. If proposal was verbally approved Name of approver Subsequent Work~e.~ported Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ .~-fcO(~ TitleAsso(piate Engineer Commission Use OnIy~/~¢EM) SA3,89 Conditions of approval Notify commission so representative may w~triess ( I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI .~,pproved Copy turned LO~NIE C. SMITH Approved by Commissioner Form 10-403 Rev 12-1-85 Date by order of the commission Date Submit in triplicate APPLICATION FOR SUNDRY APPROVALS ARCO ALASKA, INC. 30-15 CHANGE BOTTOMHOLE LOCATION Due to suspected faulting at the originally proposed BHL of 30-15, it is at the target proposedlocation, to move the BHL approximately 700'NNE (690'N, )?c~ T, ~'~'~'~---~4~/X'~/,//d, This change reduces the MD of the well from 9453' to 9167'. The 9-5/8" casing depth does not change. Revised directional plans are attached. All other items of the original permit remain unchanged. SA3/89a 4/27/88 ~D-3799 TI'ID.500~ DEP-2932:'t .... ~,.._ , :. . , K-5, TVD-5749~.-THD-zgo9 DEP'-508g 6000 ........ T/ZONE'-D: .....T VDu-6284:~TI'ID-8708-'" DEP- 5681~ T/ ZONE C?; TVD'6'$33;; TMD-SZZg DEP-5?31~' T/ ZONE' A:i-' 'TVD=655t'THD"8808 DEpm$.ZS~ '. . TARGET CNTR~*-,--TVD.!6405iTHD-888Z...DEP $8t. 5 B/ KUP' SND$;*::'TVD~6459::i THD-gg6z DEP"58Z4 TD (LOG: PT),i~ '; ,TV.D+~6595.;:. TMD-g! 6Z' DEP-6023. 6ooo, .I. ?'ooo ! HdRIZONTAL PRoJEcTiON SCALE IlIN. ' lO00 FEET z 1 000 . 3;0. Wel ~ o Kuper'ulr Field. Nor. th t ?ooo Booo TYD-6405 TI'ID-8887 DEP,,~! $ SOUTH 218~ .gEGT 5,388~ TAROET LOCATION ~ 2010' FSL. 1940' Fgl. SEC'. 21 · :TI3N. RgE 1000 _ 2000 _ 3000 _ TD LOOAT!ON ( 1632' IrBL, 17'47' F'VL KC:. ~1. TI314, Rg~ Revl,ed Pr. opo,el SI ope, Aleeke 5000 ¢000 WEST-EAST 3000 2000 1 000 SURF.~CE LOC~TKON ~ 1084' FNL. 204;8' 1=141. SEC. 22, T 13N. RgE S 67. DE(;...55 I'I].N ~ 58!15' (TO TARGET) ~ 000 1 50 I 1 O0 50 0 50 1 O0 1 50 I I I I I I ,. 100 100 ....... 15.0_ · 300 ~ 4800 / 4got~ 300 sooo ! ~ ',,.300 800 ~ 2900 O0 ......... ~ -. / ! 5600 / ! 5700 ....... /S.°° / 7 59o0 / 6000 .......... 1 TOO 7'00 t 31 8OO 1600 ~Ioo goo. ! 3100 1000 3200 1100 600 \ 300 %1 TOO 400 \ 500 \ · \~ soo 600 \ \ TOO 800 '~ ~ go0 .. 200... : 150_ .100 100 15C 20~ 1 50 1 O0 50 0 50 100 150 March 31, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Tetecopy: (90'7) 276-7542 Re.- Kuparuk River Unit 30-15 ARCO Alaska, Inc. Permit No. 88-31 Sur. Loc. 1084'FNL, 2048'FWL, Sec. 22, T13N, RgE, Btmhole Loc. 1219'FSL, 1654'F~, Sec. 21, T13N, R9E, Ul.f. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter ~system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~y~ truly ~yoqrs, C 2~'~V. Cha'ft-e~t-on ' Chai~an of Alaska Oil and Gas Conservation Con~ission BY ORDER OF THE CO~IISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section'w/o encl. Department of Environmental Conservation w/o enc!. STATE OF ALASKA ALASK/-¥_wlL AND GAS CONSERVATION G,~VIMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill E~I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24' feet Kuparuk River Field Kuparuk River Oil Poo 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510-0360 ADL 25513 ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1084'FNL, 2048'FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu,mber Number 1320'FSL, 1848'FWL, Sec.21, T13N, RgE, UM 30-15 #8088-26-27 At total depth 9. Approximate spud date Amount 1219'FSL, 1654'FWL, Sec.21, T13N, RgE, UM 04/21/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15§ Prop. osed depth (MD and TVD) property line 30-16 : 453'MD 1219'@ TD feet 25' @ Surface feet 2560 (6583'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 50 0 Maximum surface 1140 psig At total depth El'VD) 3028 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80'I 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0~ J-55 BTC 2639' 35' 35' 2674'J 2219' 900 sx AS III & HF-E~W 300 sx AS 8-1/2" 7" 26.0~ J-55 BTC 9419' 34' 34' 9453 6588' 450 sx TLW lead & HF-EtW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. TUC 5UU ' above UGNU Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor REi::EIVED Surface Intermediate MAR 2~ ]988 Production Liner Alaska 0il & Gas Cons. C0mmis,, Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [~ Property plat [] BOP Sketch [~, Diverter Sketch'~ Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby//ce/?f~hat the fore/g~ng~rue,7~//" and correct to the best of my knowledge e~ /,/ Signed [ .~...~.,Ox~/ ./...../~./.,,~,.~,/ Title Regional Drilling Engineer Dat Use Only ~"~ / / Permit Number A n her I Approval date '~ ........ I ,~e-~Cv~er letter ¢__,~--~/ 50-- 029 .- 2.1797 I 03/31/88 I for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required Lq Yes 1~ No Hydrogen sulfide measures E~ Yes [] No Directional survey requi.red ~ Yes [] No Required ~~~~~_, workin sure B M; ~ 3 [] 5M; [] 10M; [] 15M Other: .,. by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPHENT WELLS I. Move in rig, 2. Install FHC diverter system. 3. Drill 12~" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing, 5. Install and test blow out preventer. Test. casing to 2000 psig, 6. Drill out cement and I0' new hole. Perform leakoff test. 7. Drill 8~' hole to logging point accordin~ to directional plan. 8. Run open hole lois. 9. Continu~ drillini 8~" hole to p~ovid~ 100' between plu~ back total depth and bottom of Kupa~k sands. 10. Run ~d cedar 7" casing. P~essure test co 3500 psis, I1. D~squeeze ~cCic Pack and ca,nc ia 7" x 9-5/8" a~ul~. 12. Nipple d~ blow ouc p~eveu~er and install ce~ora~ ~s ~ee. 13. Secure well and release ~i~. 14, ina ~sed hole logs, Novi ~ vorkover rig. Nipple up bl~ ou~ pr~eater, 16, Pick up 7' ca8~S scraper and ~ubins, ~rip ~ hole ~o plus hick d~p~h. Circula~e hole vi~h clean brine and ~rip ~ of hole tubins back. 17.' Per,orate and ~n...comple~ion asse~ly, sec and ~es~ p~c~r. 18. Hippie d~ bl~ ouc preventer and install ~o ~roe, ; ~ :'";:;;'... .19. Chanse over to diesel. "~ ' 20. Flow v~ll to ta~s. Shut 21. Secure yell and release 22. Fracture DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR LI~IK4 / ih MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC RECEIVED MAR 2 4 !988 Alaska Oil & Gas Cons. ~mm|~ Anchorage Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 FV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. ~__,~ nW~5/ih MAR 2 4 1988 Alaska Oil & Gas Co~, Commissl~i{~ Anchorage ARCO!ALASKA. f~'~. "-' .................................. Ped' 30, Ni~ll No8 !$ Pr'opoee8 Kupmruk Fleld,~ Nor'~:h Slope, _ .. RKB_ EL£V. AT.~ON,._ _$9, KOP' TVD*'300 TIID-300 DEP"O 3 ~ I~ BUILD :3 1 O0.O _ ~. :>t~- .......... ~PER_. lO0 FT .. ! B/ PERMAFR.OST TVD-I Z19 THD-1 900 DEP-632 / '~ i EOC TVD 17'60 THD-1962 DEP-67'9 ....................... " I .............. .................... ~' ' ' ' ' "'",,. ~-,~ *vo-,;'~, ,"~-,,~ ~":'~o~~ AVERAGE ANGLE '"" ' 491 DEG 52 :I"IIN T/ ZONE A TVD-635! TMD"9085 DEP'6125 '-' ~ '-, ~1000 rO0.O - 0 TARGET CNTR TVD=6405 THD-9169 DEP=6189 B/ KUP SNDS TVD-6459 THD=9253 DEP-6253 TD (LOG PT) TVD-6588 THD-9453 DEP-6406 2000 3000 4000 5000 VERTICAL SECT[ON i i ~B~¥~D~ooo MAR 2 ............................... Al'as~ Oil & Gas ~chorage 1 000 . 1000 _ 2000 . ARco ALASKA. [no. P.d 30. Well Not 15 Propo.ed ~uperuk Field. North Slope. Ale.k. HORIZONTAL PROJECI I. ON ' SCALE 1 IN. = 100~ FEET 7'000 6000 5000 4000 WEST-,EAST ;5000 I 2000 I TARGET CENTER TVD=6405 THD'=G16G DEP,.6189 SOUTH 287'6 bEST 5480 TARGET LOCAT ! OH' 1320' FSL. 1848' FWL SEC. 21. TI3N, RGE" TD LOCATION' 1219' FSL. 1656' FWL SEC. 21. T13N. RSE S 62 OEG!'r?~lCJ IqlN W 61 89': (TO T^ROET) 1000 ! 1000 I SURFACE :LOCAT [ ON, 1084' FNL. 20~' FWL~, SEC. 22. T13H. RGE , . I' 2200 ; . 1 900~ 2000 2050' 2100 1000 1050 I100 1150 1200 .. _ 1250 1 300 _ 1400 / / / / / 1900: 1 950~ 900 / / / / / / / lzoo 2150: ! .,. ~300 ~'"~ 00 ~z i.<~p~1~° ,;'~300 300 ~ _~P* too' / ,' ~UU / ~ ~00 I~o~°~ ~ ~oo 500 I~ ~500 I 900 ~ I I I I ill00 I I I I I I I f 1300 I I I I I I I I I '~700 \ \ \ \ ~, go0 \ \ \ \ \ 1,1100 \ \ \ \ \ \ \ \ 100C 1 0513 1100 11513 1 206 1250 1300 1 350 1 400 :1 900, 1 950 2000 2050 21 O0 2150. 2200 . KUPARUK RIVER UNIT 20" DIVERTER SCHEHATIC =1 I= 4 DESCRIPTION 1. 16' CONDUCTOR 2. FIIC SLIP-ON ~ELD STARTING HEAD :5. FHC DIVERT'ER ASSEHBLY WITH 'P,/O 2-1/16" 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLIN6 SP(X)L W/10" OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES. A SINGLE VALVE 01~1~ AUT~TICAU. Y UPON CLOSURE OF ANNUL~ Pl;E~N~. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS AIN:~OVAL OF THIS DIVERT'ER SYSTEH AS A VARIANCE FROH 20AAC2S.0:35(b) MAINTENANCE & OPERATION 3 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN' INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUHSTANCES 7 ~ DI~ #1 1~-=~/8" ,5000 P~I ~ ~ STAO< 4. 1~-5/8" - ,~ PSI PIPE KILL LII~S 7, 1~8. - ~ ~I ~~ 4 i1{ i i ii ii ii i ' 2 ACOJvU_ATCR CAPACIIY TEST · I. O-ECl( AI~ FILL A~?DR i~ERVOIR TO I.~L ~TH HY~IC ~UI~ ~ THAT ACO.tU. ATOR ~ IS ~300 PSI 15OO PSI D01MNS~ OF TFE REGLLATOR. 3. ~ TIIwF_, TI-EN O.05E ALL. UNXTS SIMJLTN~OLS. Y AI~ I~CI~ TI~ TII~ AI~ ;~ I~INING ~ 4. ~~~~~, ~~~ L~ LI~T 13-5/8" BCP STACK' TEST FILL BCP STAC3( AN3 CHI3~ MliN]F~ IMETH ~IC DIESEL. CFI[CZ THAT ALL LOCI( ~ ~ IN N~I.~ ARE FLLLY RE~ED. SEAT TEST PLUG IN W~ITH ~Ih~ JT ~ ~ IN L~ :3. C~L':~__ ~ P~EVE~ ~ I~ KILL AI~ LIllE VALVES ADJ~ TO BCP STACIC ALL OTI-ER 4. I:'I~SSU~ UP TO 250 PSI AI~ l-a.D FOR I0 k'IIN. IN-. ~ Pl~~ TO 3000 PS! AM) I-a.D FOR I0 nm r~D I:~E~ TO 0 1:~3~. LI~E VALVES. CLOSE TCP PIPE RAIw~ ~ ~ VALVES C~ Kill A~D CHC:(~ ~.TEST TO25OPSI AI~)~I3OP~I AS INSTEP4. ?. CCNTI~ TESTI~ ALL VALVES. LII~.S. ~ CHOKES WITH A ZSO PSI LC~ A~D 3000 PSI HIOH. Tk'~T AS IN .bDT A hULL O_OSIN~ POSITIVE SEAL CI-~ CI~LY 8. CTrr-N TOP PIPE RAb~ ~ CL(~ BOTTOM PIPE ~. TEST BOTTOM PIPE RA%~ TO 2)50 PSI ~ 3000 PSI. 9. ~ BOTTOM PIPE ~ BAO( OUT I~NG JT AhD PU_L OJT CF HOLE. :(1 CL08E BLIhD RAb~ ~ TEST TO ~50 PSI ~ 30CO PSI. II. CI:~N 8LII~D RA~4S ~ RETRIEVE l~ST PLUG. ~ MN~LIF'CLD AN) LIliES A;~ FILL. CF NON-FI~EEZING FLUII~ SET ALL VALVES IN DRILLING PO~ITICN. 12. TEST STRIPE VALVI'~,. KELLY. KELLY C(]O(~ DRILL PIPE SAFETY VALVE. AN) [I~IDE B(~ TO 250 PSI AhD ~300 PSI. I~. ~tEO31~ TEST IhF~TION CN BL~ PREVENTER TEST FORf& SIGN, ~ ~ TO DRILLING 14. PERFCRM ~TE BC~ TEST AFTER N[PPL[NG UP t~EKLY TI~:REAFTER FU~T[CNALLY ~TE BOPE i~ I Q4:)~4oo I CHECK LIST FOR NEW WELL PERMITS Company /,O/~(D Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee ~ ~/~'/~9~ 1. Is the permit fee attached .......................................... ~j~ (2 thru 8) (8) (3) A m,n 9. (9 thru 13) 10. 11. (10 and 13) 12, 13. (4) Casg (14 thru 22) (5) (23 thru 28) 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. _~_ .. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ .~ .. 6. Is well to be deviated and is wellbore plat included ................ ~ ' 7. Is operator the only affected party ................................. .. .. 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... .4~ Is administrative approval needed ................................... _~L Is the lease number appropriate ..................................... 2~_ .... Does the well have a unique name and number ......................... ~ ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 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 wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... /~ Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. /~ Does BOPE have sufficient pressure rating - Test to .~OO~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .. ~Y REMARKS (6) /sM (~9 thru 31) (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. // ~/'+, .... 30. Are seismic analysis data presented on shallow gas zones .... ;~"''''//~4~ed 31. If an offshore loc., are survey results of seabed conditions . o mm Geology: Engi, n~eering: rev: 02/17/88 6.011 "' INITIAL GEO. '"' UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. TAPE ATIO~ LISTIN6 LVP OIO,H02 VERIFICATION blSTiNG PAGE I ** REEL HEADER SERV'iCE NAME :EDIT DATE UR!GIN_:, .2_. R£Eb NAME ,1~t46~ REViOUS REEL , COMMENTS ~LiS TAPEw ARCO KUPARUK 3 0-15w AP! 50-029-21797 ** TAPE HEADER SERVIC~ NAME :EDIT 'ORIGIN :7274 TAPE NAME CONTINUATION # :01 PREVIOUS TAPE COMMENTS :LI6 ~TAPE, ARCO KUPARUK 3 0-1.5~ AP! 50-029-21797 ** FILE HEADER ** FILE NAME :EDIT ,001 SERVICE NAME : V' ~ [ER$ION # t ATE { ~AXIMUM LENGTH { 1024 Fib~ TYPE 't PReViOUS rXbE INFORMATION RECORD~ $* MNEM CONTENTS ARCO AL,~$KA, INC, 3 0-15 KUPARUK 9E 13N 22 NORTH SLOPE ALASKA CN WN FN RANG: TOWN: SECT: COUN: 6TAT{ CTRY{ USA $~ COMMENTS UNIT TYPE CATE SIZE CODE 000 000 017 065 000 000 006 065 000 000 008 065 000 000 002 065 000 000 003 065 000 000 002 065 000 000 013 065 000 000 006 065 000 000 003 065 bVP 010,H02 VERIFICATION LI$?ING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY ~. ARCO ALASKA, INC, WEbb = 3 0-15 AP1 # = 50-029~21797 FIELD = KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA dOB NUMBER AT AKCCI 72746 RUN #i, DATE bOGGED I 05',MR¥',88 bDPt R~ KRU~EbL CASING TYPE: FLUID DENSITY ~'I$CO$ITY 9.625" 92773'(bOGGER) LSND POLYMER 10,0 bB/G 40,,~ S 91C~ 4, BIT SIZE = 8,5" TO 9297'(LOGGER) R~ RMF R~ AT BHT 4,23 ~ 73 Dr 70 65 DF 2;271 9 142 DF i,:)FIbE EDIT,O01 CONTAINS DATA OF DUA6 INDUCTION bOG COIL). FORMATION DENSITY LOG (FDC), COMPENSATED NEUTRON bOG (CNL), bVP OlO,H02 VERIFICATION bISTING PAGE 3 AND GAMMA RAY THRU CASING SAHPbED 2~)FZbE EDI?~O02 CONTAINS DATA OF HI AND CO~PENSA?ED NiEU?RON (CNH)SA~PbED ~ 1~2"~ THIS DATA HAS NOT SEEN DEPTH SHIFTED -~OVERLAY$ r'IEbD PRINTS ~**:** DUAb INDUCTION SPHERI'CAbbY FOCUSED bOG C,DIL) F~RST ~O bAST READINGI _ 9291' TO 2773' FORMATION DENSITY COmPENSATED bOG c.roc) FIRST TO bAST READINGI 9265' TO 8691' COMPENSATED NEUTRON LOG (.CNb) FiR$T TO bAST READING~ 9251' TO 86.91' GAM~A RAY '~N CASING (.CSG) :FIRST T(] bAST READING~ 2773' T:O 989' 1,2" FORMATION: DENSITY COMPENSATED bOG (,FDH) FIRST TO bAST READINGI 9265' TO 8793' 1,2" COMPENSATED NEUTRON: bOG CeCNH) ' FIRST TO bA&T READI:NGI 925!' TO 8793' LVP OlO,H02 VERIFICATION LISTING PAGE 4 ** DATA. FORMAT RECORD ENTRY BLOCKS TYPE SIZE 2 4 8 9 16 0 DATUM SPECIFICATION BLOCKS MNE) SERVICE SERVICE UNIT APl APl ID ORDER # DEPT EN~ FLU DIL IP EN$ FDC PHI FDC RHOB FDC DRHO FDC ~FDC FDC FFDC FDC CAb! FDC GR FDC TENS CNG NPHI CNb TNRA CNL RTNR CNL CFTC CNb CNTC CNL GR CN5 TENS CSG GR CSG REPR CODE ENTRY 66 0 66 65 ,lin 66 ~r 1 66 0 API bOG TYPE CLASS MOD NO, FT O0 000 O0 0 0 GB O0 6)5 OH~M O0 2!0 OHMM 00 1 0 OHMM O0 1 0 MV O0 ~010 GAPI O0 31g LB O0 6 PU O0 890 G/C3 O0 oo CPS CPS IN GAPI PU O0 354 O0 354 O0 8O oo O0 890 O0 42O O0 000 O0 000 O0 000 O0 000 O0 000 O0 310 O0 635 CPS CPS CPS CPS GAPI LB GAPI O0 4 21 0 0 4 Ol 0 0 4 46 0 0 4 44 0 0 4 Ol 0 0 4 O1 0 0 4 2i 0 0 4 O0 0 0 4 oo oo ,, Oi 0 0 4 02 0 0 4 O1 0 0 4 O1 0 0 4 21 0 0 4 O0 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O1 0 0 4 0 0 4 0 ! 0 0 4 1 1 1 1 1 1 1 1 1 PROCESS CODE O0 ~OCTAb) 68 O0 000'000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 DATA DEPT IL~ PHI F~C ~PHI ~CN? TENS 9309 0000 TENS 3 I~!6 SP 7~ 441 RHOB 0000 CAb! 56 9369 TNRA 1768 5054 CFTC "999 2500 GR DEPT 9300 0000 TENS IL) 3!1098 SP DPHI 12 4741 RHOB FFDC 727 0000 CALI 4880.0000 SFLU '7,5000 GR 2.4 3 DRHO 8.5~0 GR 4,3893 RTNR .413.8 CNTC 5524,0000 SFLU ',,,lg,$O00 GR I 031 GR 3 83 0 83 4 1785 1733 ILD 3,1757 43 5 TENS 4880,0o00 1816 NFDC 797 5000 4375 TENS 4880:0000 6992 RCFT 371,2062 0811 GR 83.4375 3.1713 ILD 3,1743 8~.4375 TENS 5524'0000 ,1816 NFDC 797,5000 83,4375 TENS 5524,0000 bVP 010,H02 VERIFICATION LISTING PAGE 5 RCNT TENS DEPT DPH! FFDC TENS DEPT FFDC RCNT TENS DEPT DPH! NPHI RCNT TENS DEPT F~oc NPH! RCNT TENS DEPT FFDC ~¢NT TENS DEPT DPH! FFDC NpH! ~CNT TENS DEPT 5~.9369 TNRA 1'76 ,5054 CFTC '999.2500 GR 9200 0000 TENS 9 7813 SP 17. 5279 RHOB 567 0000 CALl 35:3581 TNRA 2090 64'01 CFTC -999 2500 GR 9100 I! 13 4.83 3O 2329 -999 0000 TENS 5842 SP 7009 RHOB 0000 CALl 7940 TNRA 6353 CFTC 2500 GR 9000 0000 TENS 4 5287 SP 7 7357 RHOB 417 0000 CALX 30 I~52 TNRA 2191 99 CFTC -999 2500 GR 8900 0000 TENS 2 2521 SP 14 8334 RHOB 547 5000 CALl 45 3267 TN~A 1728 87~ CFTC -999 2'5 GR 8800,0000 TENS 2 4239 RHOB 698,0000 CALl 46,6103 TNRA 1580,1482 CFTC 999.2500 GR 8700,0000 TENS 2 2262 RHOB 631.5000 CALX 45,8680 TNRA 1714,7432 CFTC '999,2500 GR 8600,0000 TENS 3.2647 SP 4t3, CNTC '999,2500 6960 -8 2 9 -999 0 SFLU DRHO 2 GR CNTC 2500 178~,6992 RCFT '0845 GE ,0843 ,6875 ~i.oo25 Nr.OC ,6875 TENS .CrT ,7915 GR 742],0000 SFLU ,2402 OR . 4241 DRHO ,9 31 GR 82 85~,8 91 RTNR '7 41 CN'TC 234~ '999,2 O0 ,~625 GR ,~225 DRHO , 469 GR 2,~720 RTNR 041 CNTC 796'~500 -999, 7008 9 493 -999 :~000 SFLU DRHO 875 GR 721 RTNR 042 CNTC 50O 6988,0000 SFLU '1],7813 GR .2801 DRHO ,9609 GR ~,7237 RTNR 448,8695 CNTC -999,2500 7120 -45 2 3 489 -999 0000 SFLU 3125 GR 3164 DRHO 6094 GR 6540 RTNR 8707 CNTC 2500 6~92,0000 SFLU 58,7813 GR 8999 ILD 6250 TENS 0048 NFDC 6250 TENS · 0338 RCFT 0024 GR 4,4305 iLD · 5000 TENS II~*0340 NFDC 115,5000 TENS ."CrT !24,00 TENS 0 0274 NFDC ,79 RCFT I784,0~64 GR , TENS 0,0010 NFDC 104,3125 TENS t66~.7547 RCFT ,1577 GR 7554 I D 9375 T~NS NFDC 0000 RCFT 13~,3928 ILD .7500 TENS 1,2062 3873,4375 9,'1162 6960'0000 587~5000 6960'0000 596'9318 84'6875 74~'6529o000 556 0000 7428 0000 4'3756 oooo 6394 ~I55000 2,~933 7008. 000 61~5000 O0 0000 7440 7980 124 5000 698t '0224 .=0000 632 0000 6988 0000 388 4334 104 3125 2 7705 7120 0000 604 0000 7120 0000 437 2257 I01 9375 3,1069 '999,2500 LVP OlO,H02 YER!FiCATION bIS:TING PAGE DPH! -999,2500 RHOB FFDC "999.2500 CAb! NPH! '999;2500 TNRA RCN~ "999.2500 :CFTC TENS -999,2500 GR DEPT 8500,0000 TENS ib~ 2,7938 SP DPHI -999,2500 RHOB FFDC -~9,2500 CAbI NPH! - 9,2500 TNRA R~NT -999,2500 CFTC TEN~ "999,2500 GR DEPT 8400.0000 TENS DPH'I '9 2500 RHOB FFDC "999,2500 CAb! NPHI -999,2500 TNRA RCNT -999, O0 CFTC TENS -999.~00 GR y EPT 8300,0000 TENS h~ 3,~ 60 SP DPH! -999, O0 RHOB FFDC -999;2500 CAbl NpHI -999.2500 TNEA RCNT -999,2500 CFTC TENS -999,2500 GR DEPT 8200,0000 TENS DPHI -999;2500 RHOB "999.2500 CADI RCNT -999,2500 CFTC TENS -999,2500 GR D'£PT 8100,0000 TENS ibm 2,7415 Se DPHI -999,2500 RHOB FFDC -999,2500 CAbI NPHI -999,2500 TNRA NT -999,2500 CFTC ~NS -999.2500 G" DEPT 8000 IbM DPH! -999 FFDC -999 PH! -999 .CNT -999 TEN5 "999 0000 TENS 4951 BP 2500 RHOB 2500 CAb[ 2500 TNRA 2500 CFTC 2500 GR -999,2500 -999,2500 -999,2500 -999,2500 -999;2500 7004,0000 -9,2734 -999,2500 -999,2500 '999,2500 "999,2500 '999,2500 7148,0000 76;!1875 "999,2500 "999,2500 "999,2500 '999,2500 '999.~500 760,0000 ;,2500 "999,2500 '999'2500 "999,2500 '999'2500 6984,0! -999,2 O0 '999.2500 '999,2500 -999.2500 "999,2500 6952,0000 ."55,0938 :999, 500 .999,~500 999, .999.) 500 500 '999,2500 6812 0000 -37 3125 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 DRHO OR RTNR CNTC SFbU GR DRHO GR RTNR CNTC SFbU GR DRHO GR RTNR CNTC GR DRHO OR RTNR CNTC GR DRHO OR RTNR CNTC SFbU GR DRHO GR RTNR CNTC GR DRHO OR RTNR CNTC "999,2500 '999,2500 "9999,2500 "99 '2500 3,0380 206,8750 "999,2500 '999'2500 '999,2500 '999'2500 3,8466 .110"6250 :999,2500 -999'2500 '999,2500 "999,2500 3,5 4 .999.2 00 999.2 00 :999,2500 999.2500 2,7567 .I57,5000 .999'2500 999;2500 -999"2500 -999,2500 2 4102 83 3125 -999 2500 -999 2500 -999 2500 -999 2500 2,7878 81'7500 '999:~500 "999 500 -999 500 NFDC TENS RCFT IbD TENS NFDC TENS RCFT GR IbD TENS NFDC TENS GR 'IbD TENS NFDC TENS RCFT GR ibD TENS NFDC TENS RCFT GR IbD TENS NFDC TENS RCFT TENS NFDC TENS RCFT GR '999,2500 -999,2500 '999,2500 · '999; 2500 . 2,7082 999,2500 -999,2500 :999,2500 ' 999,250:0 "999,2500 3 1514 -999 500 -999 500 -999 500 0 ~999 3,5896 -999,2500 -999,:2500 -999,2500 '999,2500 -999,2500 2,4118 -999,2500 '999,2500 -999,2500 -999,2500 -999;250O 2,6151 -999,2500 -999,2500 "999,2500 '999, $ 1654 -999 2500 -999 2500 -999 2500 .-999 2500 -999 2500 LVP 010,H02 VERIFICATION LISTING PAGE 7 EPT L~ DP~I FFDC TENS DEPT DPHI FFDC NPH! RCNT DEPT DPHI FFDC RCNT TENS OEPT FFDC RCN? DEPT DP~I FFDC PCNT TENS DEPT DPHI FFDC NPH! TENS DEP? DpH! FFDC RCNT 7900 0000 TENS 2 4087 SP -999:2500 RHOB -999.2500 CALl -999 2500 T~RA -999 2500 CFTC -9992500 GR 7800,0000 TENS 3,8162 SP '999,2500 RHOB -999'2500 CA~I ~999'2500 T~RA -999,2500 CFTC '999,2500 GR 7700,0000 TENS = 2,5740 500 :9~9'2 RHOB 999,:2500 '999,2500 TNRA w999,2500 CFTC '999"2500 GR 7600,0000 TENS .993,:0755 .99~,2500 RHOB .2500 CALl '999.2500 :T~RA ~999;2500 CFTC -999,2500 GR 7500 0000 TENS 3 5252 SP -999 2500 RHOB -999 2500 CAL! -999 2500 TNRA -999 2500 CFTC -999 2500 GR 7400 0000 TENS 3 3617 SP -999 2500 RHOB -999 2500 CALl ~999 2500 TNRA -999 2500 CFTC '999 2500 GR 7300,0000 TENS -99 2500 RHOB '999,~500 CALl -999, 500 TNRA '999,2500 CF?C .oooo '5~ ,:'23 .3750 GR .68~ I~D TENS ,2500 GR -999,~500 TENS '999,:2500 RTNR '999,2500 RCFT "~99;3500 CNTC '999,2500 GR " 99;:2500 6492 0000 SFbU -41:093~ GR -999,2500 DRHO -999,2500 GE -999,~500 RTNE -999,2500 CN'TC '999,2500 6560,0000 SFLU -44;a125 GR :999,2500 DRHO 999'2500 GR -999,2500 RTNR -999'2500 CNTC -999,2500 6500,0000 SFbU: -39,7t~8 OR -999.2500 DRHO -999;2500 GR 2500 CNTC -999,:2500 6444,0000 SFLU '52,9375 GR -999,2 O0 DRHO '999,2 O0 GR '999,2500 RTNR '999,2500 CNTC '999,2500 6268,0000 SFLU '44,4~75 GR '999.2500 DRHO '999,2500 OR '999'2500 RTNR - 99,~500 CNTC "~99,2500 6180 o5 -999 -999 -999 -999 0000 SFLU 9453 GR 500 DRHO 500 GR 500 RTNR 500 CNTC 3,9204 .118,5625 TENS 999,2500 NFDC :999,2500 TENS .999,2500 RCF? 999,2500 GR 2,4674 ILD 97,1250 TENS '999,2500 NFDC '999,2500 TENS '9~9,::2500 ~CFT '9 9';2500 GR 2.9255 ,2500 NFDC ' ,2500 TENS '9 ;2500 RCFT '9 ,2500 GR 3,3716 IbD 99,3125 TENS -999,2500 NFDC -999,2500 TENS '999,2500 RCFT -999,2500 GR 3 3697 ILD 0 NFDC -999 2500 TENS -999 2500 RCFT -999 2500 GR 3 2091 90 6250 TENS '999 2500 NFDC '999 2500 TENS '999 50O RCFT '999 ~500 GR ,2500 -999'~500 '999,:~00 '999,2500 '999,2500 3,6953 '999,2500 '999,2500 -999,2500 '999;2500 '999,2500 '999, .999,~ 500 500 -999~i~ O0 -999~ ~00 2500 -999,2500 -999, 0 -999, ~0 O0 -999, ~00 3,4448 '999,2500 '999,2500 -999,2500 '999. ..999,~ 500 5OO 3 2992 -999 2500 '999 2500 '999 2500 -999 2500 "999 2500 3,3753 '999,2500 "999,2500 '999,2500 -999,2500 -999,2500 LVP 010,H02 VERIFICATION biB?ING PAGE 8 TENS "999,2500 GR DEPT 7200,0000 TENS ~M' OPH! ;999.2500 RNOB rFDC ,999,2500 CAbI NPHI '99:9;250'0 TNRA RCNT '999.2500 CFTC TENS DEPT 7100.0000 .TENS IbM 3,:~988 DPHI -999,;~500 RHOB FFDC -999:500 CALI NPHI -999 ~500 RCNT -999::~ 500 CFTC TENS -999'2500 GR DEPT 7000,0000 TENS !bM DPH! ~ 999:,2500 RHOB FFDC "9:99,2500 CAb! NpH! '999,2500 ~TNRA TENS :"999,2500 DEPT 6900,0000 TENS DPHI :999.2 O0 RHOB FFDC ,999.2500 CALf NPH! 999,2500 TNEA ~CNT '999.2500 CFTC FEN8 -999.2500 GR y EPT 6800.0000 TENS bN 3.1337 SP DPH! '999.2500 RHOB FFDC :999.2500 CAb! NpHI .999,2500 TNRA RCNT 999.2500 CFTC TENS "999.2500 GR DEPT 6700.0000 TENS DpHI '99 2500 RHOB FFDC '999.2500 CAb! NP~i -999.2500 TNRA RCNT -999.2500 CFTC TENS -999.2500 OR DEPT 6600,0000 TENS DPH! ,,9 2500 RHOB FFDC '999.2500 CAL! -999,2500 6~40,0000 SrbU :9~6.4063 GR 99~,2500 DRHO '.2500 GR '999.2500 R'TNR '999~500 CNTC -999.2500 6332,0000 SFbU · -48.8437 GR '999,2500 DRHO - 9 .2soo o. 99.':2500 CNTC -999~2500 89.0 TENS -999,250 -999,2500 NFDC -999;2500 -'999,2500 TENS '999.2500 '999,2500 RC:FT '999'2500 "999.2500 GR -999'2500 .:t229 .999'2500 NFDC -999.2~00 :999,2500 TENS -999,2500 ~999.2500 RCFT -9:99,2500 999.2500 GR -999,2500 250 TENS -999,2500 :~99.2500 DRHO -999,2500 NFOC -999,2500 99.2500 :GR -999'2500 TENS -999"2500 '999.2500 R:TNR -9!' 500 RC~T -999.:2500 c, c ,IgI,.] oo G, , ,25oo '999.2500 25 .~99,2500 DRHO -999,. 500 NFDC -999.2500 99.2500 GR -999,i 5 TENS -999'2500 R?NE ,999,1 O0 -999.2500 500 RCFT -999.2500 -999.;2500 CNTC -999'2500 GR -999,2500 -999,2500 5~I~ 0000 SFbU · : 6250 GR -999 2500 DRHO "999 2500 GR -999 2500 RTNR -999 2500 CNTC -999 2500 2.9546 IbD 91. 625 TENS -999.~500 NFDC -999'2500 TENS ~999.2500 RCF? -999,2500 GR 30964 -999 2500 -999 2500 =999 2500 -999 2500 -999 2500 5500 0000 SFbU '68 3750 GR -9 -9~ 2500 OrHO 2500 GR -999 2500 RTNR -999 ~500 CNTC -999 ~500 69 .999. 500 NFDC ,999. 500 TENS 999. 0 RCFT -999,]~0 GR 2 -999 -999 -999 -999 =999 5178 2500 2500 2500 250O 2500 5368.0000 srbu -77.9375 GR -999.2500 DRHO -999.2500 GR 2.9965 IbD 98 8125 TENS -999i~500 NFDC -999 500 TENS 3.2709 '999.2500 "999,2500 '999,2500 LVP 010,~02 VERiFiCATiON bISTXNG PAGE 9 NPHX -999,:2500 ?NRA RCNT -999,::2500 CFTC TENS '999.2500 GR DEPT DPHI NPHI TEN8 DEPT DPH! FFDC NpHI RCNT TENS 6500 0000 2 9115 '~99 2500 "' 99 2500 "999 2500 · "999 2500 -999 25O0 -999,2500 RTNR -Egg,2500 CNTC -999,2500 T£NS 5400,i0000 SFbU 8P RHOB .;~.2500 GR ,2500 DRHO C~LI '999,2500 GR TNRA '999;2500 RTNR CF?¢ '999,2500 CNTC GR -999'2500 6400,0000 TENS 1,8498 8P -999~2500 RHOB -999,2500 CAb! -999'2500 TNRA -999,2500 CFTC "999.2500 GR PEPT 6300,0000 TENS IbM 2,8650 :SP DPH! -999,2500 RHOB FFDC *999,2500 CALX NPHI '99 RCNT .99~.2500 TNRA ,2~00 CFTC TE~S -999~2500 GR DEPT DP.I FFDC NpHI RCNT TENS DEPT IbM' DPH! FFDC NpHi RCNT TENS ,0000 TENS 620~,1873 SP "999.2500 RHO8 "999;2500 CAbI "999,2500 TNRA "999,2500 CFTC -999~2500 GR 6100.0000 TENS 2500 RHOB "999.2500 CALX '999~2500 TNRA "999,2500 CFTC -999;2500 GR 000,0000 TENS 3,2647 SP RHOB 9.2500 CALf 9,2500 TNRA 9,2500 CFTC 99.2500 GR 5900.0000 TENS 2,9620 SP DEPT ib~ DPHI FFDC NpH! RCNT TENS IbM 5284,000,0 "~4~0625 ' '999,~500 DRHO "999:1500 GR '999i~500 RTNR '999 i~$00 CNTC "999,2500 5320,0000 SFbU 'I3,8203 GR :999,2500 DRHO: :999.2500 GR 999.'2500 RTNR ~999,2500 CNTC '999'2500 5300,0000 ,9~4! GR '94~ SFLU ,2500 DRHO "999.2500 GR "999,2500 RTNR '999,2500 CNTC "99902500 5228.0000 SFLU : ,2500 DRHO .250~ GR "999,2500 RTNR '999'2500 CNTC -999,2500 5068.0000 SFLU "31.0938 GR -999,2500 DRHO "999,2500 GR -999.2500 RTNR -999.2500 CNTC '999.2500 4948,0000 SFLU -26,0625 GR O0 RCFT i0.4.~262 ZbD 500 TENS "999,:~00 NFDC '999, O0 TENS '999, RCFT .999,~500 500 GR , 750 TENS .999;:2500 NFDC 999,2500 TENS '999,2500 RCFT '999'2500 GR ,7262 *2500 NFDC ,2500 TENS -9:99,2500 RCFT "999,2500 OR . 3,2478 lbo 7'1250 TENS -999;2500 NFDC "999'2500 TENS 0 GR 2500 TENS -999,2500 NFDC -999,2500 TENS "999~2500 RCFT "999.2500 GR ! 0 99 2500 2500 0,7338 9 '8125 TENS NFDC TENS RCFT GR ILD TENS "999,2500 '999,2500 .99~'9204 ,2500 '999,2500 -999,2500 '999,2500 "999,2500 1,9936 "999,2500 -999;2500 "99:9,2500 '999'2500 *999,2500 9635 999:2500 -999 2500 -99~ 50 ,2500 :99~,2500 999,2500 '999'2500 -999,2500 .99~'2962 .2500 -999 2500 -999 2500 "999 2500 -999 2500 3 2 69 -999 2~00 -999 2500 "999 2500 '999 2500 '999 2500 3,0083 "999,2500 bVP 010,~02 V~RIFICATiON ~ISTING PAGE 10 DPH! FFD¢ TENS ~p~! TENS DEPT DPHI NPH! RCNT TENS DEPT DPH! Froc a~I ~CNT TEN~ DEPT oP~I FFDC NPH! DEPT DPH!. FFDC NpH! RCNT TENS DEPT DPHX FFDC NpH! RCNT TENS '999,2500 RHOB -999,2500 CAbI -99~.2500 TNRA ;2500 CFTC '~9,2500 GR 5800,0000 TENS . 1,3898 SP 999,2500 RHOB -999,2500 CAbI -999,2500 T'~RA -999.2500 -999,2500 5700,]~000 TENS '999, O0 CFTC -999,2500 5600,0000 TENS 4,I538 SF '999,2500 RNOB '999,2500 CAbI "999,2500 TNRA ~999,2500 CFTC -999,2500 GR 5500,0000 TENS 999.~500 RHOB 500 CAbI '999,2500 TNRA -'999,2500 CFTC -:999'2500 GR 5400 0000 TENS 2 6267 SP -999 2500 RHO8 -999 2500 CALI '999 2500 TNRA -999 2500 CFTC -999 2500 GR 5300 0000 TENS 3 2848 SP -999 2500 RHOB 0999 2500 CAbI -999 2500 TNRA '999 2500 CFTC -999 2500 GR -999,2500 DRHO -999,2500 GR ~999~2 O0 O0 CNTC 999,~500 4852,0000 .'25,828! 999,2500 DRHO '999;2500 GR '999,2500 RTNR '999,2500 CNTC '9~9,2500 '20ii DRHO '999 ~ GR '999 }00 GR '999,~I~500 RTNR '999 ~500 CNTC 4604,0000 SFbU -0;5674 GR -999;2500 DRHO "999,2500 GR '999,2500 RTNR -999,2500 CNTC "999,2500 4452,0000 SrbU '5,7852 GR -999,2500 DRHO -999,2500 GR '999,2500 RTNR '999'2500 CNTC '999,2500 4~9 0000 SrbU ;00 GR 500 CNTC -999,2500 4420, O0 SFLU . .999.!500 DRHO .999' 500 GR 999. 500 RTNR '999. 500 .999.~500 CNTC '999,2500 NFDC '999,2500 :TENS '999,2500 RCFT -999;2500 OR 91,0667 tbD ,6250 TENS -999,~500 NFDC '999,~500: TENS -999 1500 RCFT '999,'~1500 ,7500 TENS ~999~2500 N~DC ,2500 999;2500 RCFT -999,2500 GR 3,7117 IbD 87,0000 TENS '999,2500 NFDC '999,2500 TENS '999,2500 RCFT 0999'2500 OR 8750 T~NS '999, TENS '999, 500 RCFT '999,~500 GR -999 '999 '999 '999 · 37 I P t75 0 2 O0 NFDC 0 RCFT 2500 GR 2.9874 XLD 79,8750 TENS -999,{500 NFDC :999,2500 TENS 999,2500 RCFT -999,2500 GR -999.2500 -999'2500 -99'9,2500 ...999'2500 99~*5392 · :' .2500 -999~2500 -999,2500 -999,250:0 '999'2500 2,8998 -999,2500 -999,2500 -999,2500 -999;2500 -'999'2500 4,1856 0999,2500 -999,2500 -999'2500 -999,2500 -999,2500 2,9647 -999,2500 "999 !500 -999 !500 -999 !500 -999 :500 2,6990 -999,2500 -99902500 -~9.2500 = 9,2500 '999,2500 3,5367 -999,5 ~999,~5 O0 O0 '999,2500 5O0 bVP'OIO,B02 VERIFICATION LISTING PAGE DEPT DPHI FFDC D£PT DPH! FFDc ~P~! ~C~T TENS DE.PT DPHI FrDC N~pH! RC~T TENS DEPT ~P~I FFDC NpHI TENS DEPT DPH! FFDC NPH! TENS DEPT DpH! NPHI Bc T PEPT DPH! FFDC NPHI RCNT 5200,0000 TENS ~08,:0000 SFLU . 2.8101 8P -999,2500 CALl '999,2500 GR -999,2500 TNRA '999,2500 RTNR :999,2500 CFTC '999;2500 CN?C 999,2500 GR '999,2500 51oo,oooo TENS .999*25 0 RHOB 999,2500 CAbI .999 '999,2500 TNRA 999 -999'2500 CFTC -999 :'999,2500 OR '999 5000.0000 TENS 4094 3.1673 SP '1:0 -999.2500 RHOB '999 '999.2500 CAbI '999 -999.2500 TNRA '999 '999,2500 CFTC '999 '999.2500 GR '999 4900,0000 . 3,8313 .999.2500 RHOB ;999,2500 CALI 999,2500 TNRA :999.2500 CFTC 999,2500 GR 4800.0000 TE.S 4.1076 SP '999.2500 RHOB '999.2500 CAb! -999.2500 TNRA '999,2500 CFTC '999,2500 GR 2.6649 IbD 2.9645 78.7500 TENS -999'2500 '999'2500: NFDC -999;::2500 .999,2500 TENS .-999~.2500 '999'2500 RCFT -999,2500 -999,2500 OR '999,2500 .0000 SrbU .7891 GR 8~''8646 ,4375 ,2500 DRHO -999,2500 ,2500 GR :'999.2500 .2500 RTNR '999,2500 .2500 CNTC '999...2500 .2500 .0000 8rbU .578! OR '5000 '2500 DRHO '9 . ~2500 ,2500 GR '9 .2500 RTN" -9!i'2500 .2500 · 2500 CNTC -9 .2500 '2500 4054,~000 srbu ,3058 .9~9. 9~8 GR 0000 '2500 DRHO '999.1!500 -999.2500 GR -999,~!500 -999,2500 R?NR -999,1!500 -999,2500 CNTC -999,,!500 -999,2500 ibD 3,4088 TENS -999'2500 NFDC '999.2:5 0 :TENS -999,25g0 RCFT -999.2500 GR -999,2500 3980 '999 :999 999 -999 -999 lbD 3,3407 TENS -999,2500 NFDC '999,2:5 0 TENS -999.25~0 RCFT -999.2500 GR -999.2500 ... 4700.0000 TENS 3754 5.!258 SP -19 -999.2500 RHOB -999 -999,2500 CALI -999 '999,2500 TNRA '999 '999,2500 CFTC '999 -999.2500 GR -999 IbD 3 TENS -999 NFDC '999 TENS -999 RCFT -999 GR -999 I 8o 250'0 2500 4600.0000 TENS 4,6222 SP "999.2500 RHOB -999.2500 CAbI -999.2500 TNRA '999.2500 CFTC 0000 SFbU ~,6099 5469 GR . 8 .1875 TENS }500 DRHO 999.2500 NFDC }500 GR -999,2500 TENS }500 RTNR -999,2500 RCFT }500 CNTC -999,2500 GR }500 4,2988 '999,2500 "999,2500 "999,2500 '999.2500 '999,2500 0000 SrbU 4.6098 0781 GR 2500 DRHO .9~.8750 TENS .2500 NFDC 2500 GR -999.2500 TENS 2500 RTNR -999,2500 RCFT 2500 CNTC -999,2500 GR 2500 5 -999 -999 -999 -999 -999 2500 500 ~500 2500 3870,0000 SFLU 4,3524 XLD '23,0469 GR 81.8125 TENS -999.2500 DRHO -999'2500 NFDC -999.2500 GR -999.2500 TENS '999.2500 RTNR '999.2500 RCFT '999,2500 CNTC '999,2500 OR 4 -999 -999 -999 -999 -999 9832 25OO 0 2500 2500 LVP :010,H02 VERIFXCATION LISTING PAGE 12 TENS -999, DEPT 4S00, ILM DpH! '999' FFDC "999, NPH! "999, ReNT -999. TENS '999. DEPT 4400, FFDC -999': NPHI. -999, RCNT -999, TENS "999, DEPT 4300, IbM rFOC -999, NpH! '999, RCNT -ggg' TENS -999. DEPT 4200, FFDC '999, NPH! '999. -~S -999, DEPT 4100 IbM 25 DpH! =999 FFDC -999 NPHI -999 RCNT -999 TENS -999 DEPT 4000 IbM I52 DpHI -999 FFDC .999 NpHI -999 ~CNT -999 EN$ -999 DEPT ]900. Ib~~ 107. DPHI -999. FFDC '999, 250O GA O000 TENS 2500 RHOB .25.00 CAbl 25O0 TNRA 2500 CFTC 2500 Ga 0000 TENS 5836 '$P 2500 RHOB 2500 CAb! 2500 :TNRA 2500 CFTC 2500 GR 0000 TENS 5642 BP O0 CAb! 500 TNRA O0 GR 000~ TENS 399 BP 2500 RHOB 2500 CAbI 2500 TNRA 2500 CFTC 2500 GR 0000 TENS 4188 BP 2500 RHOB 2500 CAbI 2500 TNRA 2500 CFTC 2500 GR 0000 TENS 4550 BP · O0 ~00 RHOB 2500 TNRA 2500 CFTC 2500 Ge 0000 TENS 8702 SP 2500 RHOB 2500 CAbI "999,2500 3830,0000 SFbU '40,5625 OR '999,2500 DRHO '999.2500 GR "999,:2500 RTNR '999..2500 CNTC "999.2500 3724,0000 SFbU '28,03t3 GR '999,2500 DRHO "999.2500 GR '999,2500 RTNR '999,2500 CNTC 3874.0000 SFhU · R -32,78~3 ~HO -999.2500 -999.2500 GR "999,2500 RTNR =999,2500 CNTC '999.2500 3800,:0000 SFbU -39,5938 GR -999,2500 DRHO "999":2500 GR -999'2500 RTNR -999;2500 CNTC '999.2500 3770.0000 SrbU '61.'78~3 GR '~99,2500 DRHO ' 99.2500 GR '9 ,2500 CNTC '999,2500 -999 -999 -999 9 0000 SFGU 0625 GR 2500 DRHO 2500 GR 2500 RTNR ;2500 CNTC .2500 3470 ,,,69 "999 '"999 0000 SFbU 25 GR 500 GR ~500 '99'9'2500 '999,2500 6,7923 66.9375 "999;2500 '999,2500 -999,2500 -999.2500 4.7732 64.6250 ,2500 '99 ,2500 '99~,2500 6,4874 74,8125 '999,2 -999. 500 .9..: soo 31,~991 . 6i, i87 999, 500 "999'~500 50O '999'~500 '999, O0 143.4607 36,8437 : 9. soo 999, 500 IbD TENS NFDC TENS RCFT GR IbD TENS N~DC TENS RCFT IbD TENS NFDC TENS RCFT TENS NFDC TENS RCFT GR TENS NFDC TENS RCFT GR IhD TENS NFDC TENS RCFT GR TENS NFDC TENS 13.5216 -999.2500 -999:2500 -9992500 -999 ~500 -999 500 7,7084 '999,2500 -999,~500 '999.2500 -999.2500 -999~2500 5,8544 -999.2500 -999.2500 -999.2500 .999.2500 ,999.2500 6 8535 -999 2500 -999 2500 '999 2500 '999 2500 "999 2500 22,4306 -999.2500 '999.2500 .2500 -999.2500 130,8244 "999.2500 '999,2500 '999,2500 "999.2500 -999..2500 79.3041 '999,1500 '999, 500 '999,2500 bVP OIO,H02 VERIFICATION bISTXNG PAGE !3 NPH! RCNT yEPT DPHI FFDC NPHI DEPT DpH! FFDC NPH! RCNT DEPT FFDC RCNT DEPT IbP' DPHi FFDC ~¢~T TENS DEPT FFDC NpHI RCNT TENS DEPT DPH! FFDC NPHI RCNT TENS DEPT -999,2500 TNRA '999,2500 CFTC -999,:2500 GR 3800,0000 ~N& 14'4759 ~ '999,2500 RHO8 -999;2500 CAL! -999,2500 TNRA '999,2500 CFTC "999,2500 GR 3700,0000 TENS 999,2500 RHOB · 999'2500 'TN~A -999,2500 CFTC "999,2500 G~ 3600,000 12'969~ TENS "999,2500 RHOB -999,2500 CAL'! -999,2500 TNRA -999'2500 CFTC -999,2500 GR 3500,0.000 TEN& 11.,:Z250 SP '999,2500 RHOB '999~2500 CALl '999,2500 TNRA -999,2500 CFTC -999,2500 GR ,0000 TENS 340~,5075 SP -999,2500 RHOB -999;2500 CALl =999,2500 TNRA '999,2500 CFTC '999.2500 GR 3300 O0 -999 2500 -999 2500 "999 2500 '999 2500 '999 2500 '999,2500 RTNR "999,2500 CNTC "'999,2500 3340,0000 SFLU '52.2500 GR -999'2500 DRHO '999,2500 GR '999,2500 RTNR '999,2500 CNTC '999,2500 3264.0000 srLu · ~59,:o938 ' '999,2500 '999'2500 .9~.2500 CNTC 3104.0000 &FLU -58,7500 GR -999,2500 DRHO -999,2500 RTNR '999.'2~0 GR '999,2 0 CNTC "999,2500 3034,~0~ SFLU '61,,6 GR "999,2500 DRHO -999,,~0 GR "999,'25 0 RTNR -999.2500 CNTC -999o~2500 3034,0000 SFLU -999 DRHO -999;2500 GR -999,2500 RTNR -999,2500 CNTC -999.2500 TENS 3024,0000 SFLU SP "65.5625 GR RHOB "999.2500 DRHO CALl -999.2500 GR TNRA -g99,2500 RTNR CFTC "999,2500 CNTC GE '999..2500 3200,0000 TENS t3,5631 SP 3040.0000 SFLU -69.8125 GR -999,2500 RCFT .999,2500 G~ TENS 500 'RCFT 999, 500 GR 86 14,5 -999,2500 aFDC: '999,.:25.00 TENS "999,2500 12,7062 lbD . 63,28!3 .999'.2500 NFDC 2999,2500 TENS .999,2500 RCFT 999,2500 GR '999 O0 -999 0 -999 2500 -999 2500 I3 5799 !o 999 O0 -999 500 14 6186 47:5938 XLD TEN& RCFT GR XLD TENS NFDC TENS RCFT GR XLD TENS NFDC TENS RCFT GR ILD TENS '999.250(9) "999,250 . 15,1607 999.2500 '999;;2500 '999,2500 2500 I5,,4832 -999,2500 -999.,2500 '999,2500 -999,250~ '999'250 . 23,7889 999,2500 "999'2500 '999,2500 '999.2500 -999,2500 .9~'1976 ;2500 -999,2500 -999'2500 '999'2500 "999,2500 '999,2500 "999,2500 "999,2500 -999,2500 10,3395 -999,2500 "99'9,2500 -999,2500 -999,2500 '999,2500 500 bVP OIO,H02 VERIFICATION LIST'ING PAGE 14 DPHi -999' ~0 FFDC '999,~ 0 RHOB O0 CAb! NPHI -999,~ O0 TNRA RCNT -999, ~00 :CFTC TENS -999,25'00 OR DEPT 3100,0000 TENS ILM . I3'2838 SP OP~! :999'2500 e~OS FFDC ;999,2500 CALl NPH'I -999,'2500 TNRA RCNT '999,2500 CFTC~ TENS -999,2500 OR '999,2500 -999;2500 ' 999,2500 '999,2500 -999,2500 2960 0000 '62 2813 '999 25OO :'9992500 =999 250:0 '999 2500 '9992500 DEPT 300~,0000 TENS 2894,0000 IbM' 65,2366 SP -50,0313 DP.H! -999,2500 RHOB '999.2500 FFDC -999'2500 CAb! -999;2500 NpH! -999,2500 TNRA -999,2500 TENS -999,2500 -999,2500 DEPT 290:0,0000 iLM . 18,4363 DPH! .999,2500 FFDC ~.999.2500 NpH! =999,2500 RCNT ~999,2500 TENS 999,2500 0000 i492 ~50o ~500 2500 2500 0000 SP RHOB TNRA CFTC GR DEPT 2800 DPH! =999 FFDC '999 NpHI '999 RCNT '999 TENS 2680 0000 2500 2500 2500 2500 2500 0000 TENS RHOB CAb! TNRA CFTC GR DEPT 2700 !b~ -999 DpHI '999 FFDC '999 NPHI -999 RCNT -999 TENS 2554 0000 2500 2500 2500 2500 2500 0000 TENS SP RHOB CALl TNRA CFTC GR DEPT 2600 ILH '999 DPH! '999 FFDC =999 NpHI -999 RCNT -999 TENS 2540 TENS SP RHOB CALl TNRA CFTC GR o°°o 9~ ,78~3 ,2500 '99,2500 '999,2500 '999,2500 '999,2500 2884'i~00 .999,2500 .999.2500 63 -999.~500 -999, 500 =999,2500 -999,2500 '999, O0 ]4,5625 -999 2500 -999 2500 '999 2500 -999 2500 -999 2500 -999 2500 53 8750 DRHO GR RTNR CNTC SFbU GR ORHO ~R RTNR CNTC GR DRHO GR RTNR CNTC SFbU GR DRHO GR RTNR CNTC SFbU GR DRHO RTNR CNTC SFbU GR DRHO GR RTNR CNTC SFLU GR DRHO GR RTNR CNTC =999,2500 '999'2500 '999' 2500 '999'21500 ,7813 '999,2500 '999'2500 '999'2500 '999,2500 I,2838 ,664! '999,2500 '999,2500 '999,2500 '999,2500 24,2~26 25 47,0 O0 '999'2~00 -999,2 '999'2 O0 '999,2~00 ~10,7277 . 54,t875 ,999,2500 999,2500 ~999,2500 999,2500 '999,2500 '999,2500 '999,2500 '999,2500 '999,2500 -999'2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 NFDC TENS RCFT GR TENS NFDC TENS RCFT GR IbP TENS NFDC TENS ReFT GR IbD TENS NFDC TENS RCFT GR TENS NFDC TENS RCFT GR IbD TENS NFDC TENS RCFT GR TENS NFDC TENS RCFT '999,2500 =999,2500 -999 ;2500 -999'2500 . 15,5783 999,2500 -999,2500 -999,2500 -999'2500 46,4700 '999,2500 '999,'2500 '999;2500 -999~'2500 -999,2500 ,2500 -999,~500 '999,2500 -999,2500 -999~2500 11,8433 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 '999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 '999,2500 -999.2500 LVP 010,H02 VERIFICATION LISTING PAGE 15 DEPT ~500.0000 TENS -9'99 ib~ 999,2500 SP -999 DPHI -999.~500 aHOB -999 FFOC -999.2500 CAb.! -999 ~H! .999,2500' ?~RA -999 RCNT 999,2500 CFTC -999 TE~S 2534,0000 27 ::50 DRHO 0 GR '50 RTNR 50° 0 C~TC 46:88 OEPT 2400,0000 I~NS Ib~ '999,2500 DPHI -999;2500 RHOB FFDC -~99.2500 :CAbI NPHZ -999.2500 TNRA RCNT -999.2500 CFTC TENS 2364,~0000 GE -999,2500 SFbU -999.2500 GR -999;:2500 DRHO -999.2500 GR -999;2500 RTNR -999,:2500 CN?C 35,5000 DEPT .~300,0000 TENS IbM 999*2500 DPH! .-999.,~500 RHOB FFD¢ -999,12500 CAbI ~HI -999~500 T~RA ~C~? -999,12500 CFTC TENS 2300,0000 GR -999.:25:00 IbD -999.2500 tENS '999.2500 aFDC ,2500 ReFT '999,2500 GE '-999.2500 '999,2500 TENS :999'2500 NrDC .999,2soo :999,2500 RCF? 9199.2500 GR 999,2500 -999.2500 GR -999,2~00 TENS -999.2500 DRHO -999'2J00 -999,2500 GR -999,2500 -999,2500 RTNR -999,2500 -999.2500 CNTC -999,2500 GE 3~,¢688 DEPT 2200.0000 TENS '999.2500 SFbU ibm -999.2500 -999;2500 GR DPH! ' -999,2500 RHOB -999,2500 DRHO FFDC '999,2500 CAb! -999,2500 GR NPH! -999,2500 TNRA -999,2500 RTNR RCNT '999.2500 CFTC -999.2500 CNTC TENS 241¢.0000 GR 33~3125 -999. GR '999, -999'2500 CNTC 4~.6250 DEPT DPH! FFDC NPH! RCNT TENS 2~00,0000 TENS -999.2500 SP '999,2500 RHOB '999.2500 CAb! -999.2500 ~NRA '9 ~'2500 CFTC 2~ ,0000 OR -999 2500 SFbU -999 2500 GR -999 2500 DR,O soo '999 2500 NR '999 2500 CNTC 44 6250 DEPT FFDC NpH! TENS 2000,0000 TENS '999,2500 S~ '999,2500 RHOB '999,~500 CAbI '999. 500 TNRA '999.2500 CFTC 2~6~.0000 OR :999.2500 SFbU 999.2500 GR -999,2500 DRHO -999,~500 GR -999. 500 RTNR -999.2500 DEPT DPH! FFDC 1900 0000 TENS '999 2500 SP '999 2500 RHOB -999 2500 CAbI -999 2500 TNRA -999 2500 CFTC ~999,2500 IbD 999.2500 TENS -999,2500 NFDC :999,2500 TENS ,999'2500 RCFT 999.2500 GR ,', -999 -999 -999 .999 999 500I'D 500 T~NS 2500 NFDC 2500 TENS '999,2500 -999,250q -999.250o -999.2500 ?99.2500 999'2500 TENS NFDC TENS RCFT -999 ,,999 ',,999 -999 2500 IbD 2500 TENS 2500 NFDC 2500 TENS 2500 RCFT 2500 GR -999,2500 -999,2500 '999,2500 '999,2500 "999'2500 -999~2500 -999,2500 -999,2500 -999'2500 -999,2500 -999'2500 -999,2500 .~'2:50o 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.:2500 -999,2500 -999,2500 o999,2500 -999,2500 -999.2500 -999,2500 -999.2500 LVP OlO.H02 VERiFICATiON LXSTING PAGE 16 TE'NS 2094,0000 G8 D~PT 1800,000:0 ~TENS Xb~ -999;:2500 SP DpHx -999'2500 RHOB FFDC -999,~500 CAb! NPH! -999,2500 TNRA RCNT -999.2500 CFTC TENS 2124,0000 GR DBPT ~700.0000 TENS Xb~ ,999'2500 DPH! -999'2500 RHOB FFDC '999,2500 CALX NPHI -999,2500 TNRA RCNT -99'9,2500 CFTC TENS 1945'0000 GR DEPT 1600,0000 TENS X~ -999.2500 SP PPHX -999,2500 RHOB FFDC -999,2500 CALX NPHX -999,12500 TNRA RCNT -999~2500 CFTC TENS i975,0000 GR DEPT 1500 !bM -999 DPH! -999 FFDC -999 HPH! -999 RC~T -999 TENS 1930 0000 TENS 2500 SP :2500 TNRA 2500 CFTC 0000 GR DEPT DpHI rrDC NPHI RCNT TENS 1400,0000 1999,~500 999,2500 -999,2500 '999,2500 '999,2500 1865,0000 TENS RHOB CAb! TNRA CFTC GR DEPT ibm DPHI FFDC NpHI TENS 1300,0000 '999,2500 -999,2500 :999,250o 999.2500 1730,0000 TENS SP RHOB CALI TNRA CFTC GR DEPT Ib~ DPHI FFDC 36,7500 -999,2500 SFbU -999,2500 IbD -999.2500 GR -999;2500 TENS -999.2500 DRHO -999,2500 NFDC -99~"2500 GR -999,2500 TENS -99 ,2500 RTNR -999,2500 RCFT -999.2500 CNTC -999,2500 GR 27-3750 -999:500 -999 1500 '999 '9992500 '999;2500 33~,4375 -999,2500 -999.2500 -999,2500 ~999,2500 ~999.2500 '999,2500 32~5938 '999. '999' -999,:~ '999, O0 24,~ 50 '999 2 00 i oo -999 500 -999 500 -999 2500 -999 2500 30 3438 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 44 5625 SFbU GR DRHO OR RTNR CNTC SFbU GR DRHO GR RTNR CNTC SFbU GR DRHO RTNR CNTC SFLU GR DRHO GR RTNR CNTC SFbU GR DRHO GR RTNR CNTC ~200.0000 TENS -999.2500 SFbU 999,2500 SP -999.2500 GR -999.2500 RHOB -999.2500 DRHO '999.2500 CALI -999.2500 GR -999,2500 'IbD -999,:2500 TENS :999,2500 NFDC' ~999,25:00 TENS :999,2500 RCFT 999,.2500 GR '999,~2500 XbD: '999,2500 TENS '999,2500 NFDC '999~2500 T~N$ '999,2500 RCFT '999.2500 ~ '999,2500 XLD '999,2500 TENS -999,.25.00 NFDC '99902500 T~NS -999;.2500 RCFT -999,2500 GR '999,2500 IbD -999,2500 TENS -9 ,2500 TENS "999,2500 RCFT '999,2500 GR -999,2500 XLD ~999,2500 TENS .999,2500 NFDC g99,2500 TENS '999,2500 RCFT -999,2500 GR "999,2500 ILD -999.2500 TENS -999. 0 NFDc -999.~55~0 TENS '999,2500 =999,2500 -999;2500 -999,2500 :999'2500 999,2500 -999,2500 -999,2500 -999,2500 ~999,2500 -999,2500 -999,2500 -999,2500 '999,2500 '999.2500 -999,2500 -999.2500 -999;2500 -999,2500 -999,2500 "999,2500 '999.2500 '999,2500 -999.2500 -999,~500 -999,2500 -999, 500 '999, 500 }oo O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999,2500 -999,2500 -999,2500 bVP OIO,H02 VERIFICATION LISTING PAGE NP.X -999,2S00 TNRA ,,999,2500 R'rNR -99o~9.2500 RCFT RCNT -999.2500 CFTC '.999,2500 CNTC -9.,~,.2500 GR TENS X645,0000 GR 26,53X3 DEPT ~100.0000 TENS IbM 999'2500 SP DPHI -999;2500 RHOB FFDC '999.2500 CAEI NPHX -999'2500 TNRA R~NT -999,25'00 CFTC TENS I630,0000 GR -999,2500 8FLO -999,2500 OR -999;2500 DRHO -999,2500 GR -999,2500 RTNR -999,2500 CNTC 60,1250 DEPT lO00,O000 TENS IbM "999,2500 5P DPHI :999,2500 RHOB FFDC .999.250'0 CALl NpHX -999,~500 TNRA RCNT -999'2500 CFTC TENS 1555,0000 GR '99g,2500 SFLU -999,:250:0 GR :999.2500 DRHO 999,:2500 GR -999,2500 RTNR -999,2500 CNTC 50,2813 .EPT .988,5000 TENS ILM ..~999. 2500 SP ~PHI ' ,999,2500 RHOB FF'DC 999,2500 CALl N'PHX -999.2500 TNRA RCNT -999,2500 CFTC TENS 1540,0000 GR "999.2500 SFLU "999,2500 GR '999,2500 DRHO "999,2500 GR '999,2500 RTNR "999,2500 CNTC 47,3750 FILE NAME ~EDIT ,001 SERVICE NAME ~ VERSION # l DATE ~ AXI~UM LENGTH ~ 1024 ILE TYPE ~ NEXT FILE NAME ~ "9999,2500 '99 ,2500 -999,2500 I:LP -9:99,2500 :999.2500 TENS -999,2500 .999,2500 NFDC -999,2500 999,2500 TENS -999,2500 -999'2500 RCFT '999,2500 "999,2500 GR -999,:2500 -999, O0 TENS -999,2500 -999.~500 NFDC -999,2500 "999.:2500 TENS -999,2500' "999'2500 RCFT -999'2500 '999,2500 GR ~999,2500 -9 .9~,2500 X D ,2500 T~NS '999,2500 NFDC -999,2500 TENS -999.2500 RCFT -999.~00 GR -999,2:500 -999,2500 -999,2500 '999,2500 -999'2500 -999;:2500 ** FILE HEADER ** FILE NAME ~EDXT ,002 SERVICE NAME : VERSION # ~ DATE ~ NAXXMUN LENGTH ~ 1024 FILE_TYPE ~ PREVIOUS-FILE : ** DATA FORHAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 5~P 010,H02 VERIFICATION LISTING PAG~ 18 2 I 66 0 4 i 66 8 4 73 12 9 4 65 ,lin 16 i 66 0 i 66 0 DATUM SPECIFICATION BLOCKS ~.NEM SERVICE SERVICE UNIT AP{< APl! APl API FIiaE ID ORDER # LOG TYPE CLASS MOD NO, DEPT DPH! FDH DRHO FD'H HFDC FDH FFDC CAL! OR FDH NpHI CNH TNRA CNH R?NR CHH RC~T CNN RCNT CNH CFTC CNH CNTC CNH OR CHH FT O0 000 bB O0 635 PU O0 890 G/C3 O0350 G/C3 O0 56 O0 54 O0 oo O0 910 O0 6 5 O0 8 0 O0 42O O0 000 O0 000 '00 000 O0 000 O0 000 CPS CPS bB CPi{ CPi{ CPS CPS GAP! O0 310 O0 0 0 21 0 0 4 00 0 0 4 02 0 0 4 0 0 4 0101 0 0 4 02 0 0 4 O! 0 0 4 Ol 0 0 4 0 0 .4 O0 0 0 4 Ol 0 0 4 0:0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O1 0 0 4 DATA DEPT GR RTNR CNTC 9307 4004 TENS -0 0120 NFDC 883~25 TENS 3 b560 RCrT 16194844 GR DEPT 9300.2988 TENS DRHO -0,0120 NFDC OR 88,3125 TENS RTNR 3,6560 RCFT CNTC 1619,4844 OR DEPT DRHO GR RTNR CNTC DEPT DRHO GR RTNR CHTC 8 3750 TENS 2114; 0522 GR 9100,2988 TENS · '0,0056 NFDC 6_5,6875 TENS 3,3090 RCFT 2342.7793 GR 4968 899 4968 433 88 0000 DPH! 0000 FFDC 0000 NPHI 5424 0000 DPH! 899 0000 FFDC 5424 0000 NPHI 433 8731 RCNT 88 3125 6832 0000 DPH! 602 0000 FFDC 68320000 NPXI 784~ 2994 RCN. T 375O 71~64.0000 DPH! ,0000 FFDC 7344,0000 NPHI 825,8905 RCNT 65,6875 SIZE SPiE, REPR ,PROCESS CODE (OCTAL,) 4 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 t 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 i 68 00000000000000 I 68 00000000000000 68 00000000000000 I 68 00000000000000 i 68 00000000000000 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 S6 ,5908 RHOB 270645,0000 CRLI ,3571 TNRA 1604,4468 CFTC ~,:71063 ,5 O0 3,4149 483,7555 56.5908 RHOB 2706,0000 CAb! 45,3571 TNRA 1604.4468 CFTC I 7163 5 3906 3 4149 483 7555 RHOB 1979,~914 TNRA 964 CFTC 9, 3,0605 706,7656 15,5485 RHOB 519,5000 CAbI 4487 CFTC 2.3936 8,9844 2,8592 846.6539 LVP OlO,H02 VERIFICATION LISTING PAGE 19 DEPT GR R~TNR CNT¢ DEPT DRHO RTNR DEPT OReO RTN~ C~?C DEPT DR~O GR RT~R CNTC 9000,2988 TENS 0,0858 NFDC 3,,5625 TENS 3 ' l It t RCFT 2184,70,9 0 GR 8900'2988 TENS 0,0064 NFDC ! ; :0625 TEN $ 4,1429 RCFT 1781.'4888 GR 880.0,2988 TENS 00,'7 "FDC 10i!6875 :TENS 4167 RCFT 1726.2588 GR 8792 9004 TENS -0 0033 NFDC 1133 0'625 TENS 8545 RCFT 1711 4241 GR 7328,0000 DPHI 6 8,0000 FFDC 73!9,.73278 RCNT ;o000 113;5625 ' 6884'0000 DPHZ 605,5000 FFDC 6884,0000 NPHI :[ lB, 06 6872,~0000 DPHI 615.00 FFDC 68.72,00~§ ~PHI 401,4395 RCNT 109' 6875 ' 6932,0000 DPH! 615.0000 FFDC 6932,0 0 NPH! 401.4~905 RCNT I 13,0625 $, '3496 RHOB 447'7500 CALi 3~.4476 TNRA 2238' 5347 CF TC i 7.6 2¢ 6 R t4 ol~ 58~2 0000 c~b! 44,2113 TNRA 1802,4t43 CFTC _ 33,i 104 67:~.5000 49,2825 TNRA 1762,9551 CFTC ,50~0 CALI ,gl g TNRA !615.5146 CFTC FILE NA~E :EDIT ,002 SERVICE NAM~ l DATE =_ MAXIMUM LENGTH = 1024 ** TAPE TRAILER ** SERVICE NAME . =EDIT DATE =88/05/15 ORIGIN =7274 TAPE NAME CONTINUATION # NEXT TAPE NAME ~ COMMENTS =SIS TAPE, ARCO KUPARUK 3 0-~5, ** ~EEL TRAILER SERVICE NAME IEDIT DATE =88/05/15 ORIGIN { REEL NAME =72746 CONTINUATION # 2,5454 I0.0391 2,'$952 752,2080 2,3593 · 9,2500 ,62463 481,5 i71 2,28: 5. 3 9.0078 3,8736 ~51 ,:3537 2,2934 3,9581 464,7886 ~VP 010,H02 VER!F~CA?ION: ~$~ING PAGB 20 :OM~EN'T$ ;bis TAPE, ARCO KUPARUK ] 0-15~ AP! 50-029-21~797