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198-011
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8677'feet None feet true vertical 6768' feet None feet Effective Depth measured 8088'feet 7893', 8009'feet true vertical 6220'feet 6043', 6148'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 4-1/2" L-80 L-80 7811' 8024' 5970' 6162' Packers and SSSV (type, measured and true vertical depth)7893' 8009' 6043' 6148' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5705' 4446' Burst Collapse Tie-Back String Liner 8197' 7976' Casing 6356' 6119' 8235' 7976' 8677' 6768' 5664' 121'Conductor Surface Production 16" 9-5/8" 79' measured TVD 7" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-011 50-029-22856-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025649 Kuparuk River Field/ Kuparuk Oil Pool KRU 1C-13 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 121' Well Shut-In 324-312 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 SLB: Bluepack RH Packer: Baker FAB-1 SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Staff RWO/CTD Engineer 8334-8415', 8504-8523' 6449-6524', 6607-6625' 645' 4-1/2" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:41 pm, Aug 28, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2024.08.28 10:50:56-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem Page 1/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/26/2024 21:00 7/26/2024 23:30 2.50 MIRU, MOVE MOB P Pull up Rig mats, and herculite. Send rig mats to 1C to prep for rig up. Clean cellar box. Check, and clean any remaining equipment from around 1A-11 or the pad. 0.0 0.0 7/26/2024 23:30 7/27/2024 00:00 0.50 MIRU, MOVE MOB P Move rig from 1A to 1C. 0.0 0.0 7/27/2024 00:00 7/27/2024 04:00 4.00 MIRU, MOVE MOB P Move rig to 1C 0.0 0.0 7/27/2024 04:00 7/27/2024 09:00 5.00 MIRU, MOVE MOB P Spot well head equipment behind well. Lay herculite, and double rig mats. Build dance floor to climb onto double mats. 0.0 0.0 7/27/2024 09:00 7/27/2024 13:30 4.50 MIRU, MOVE MOB P Pull sub over well. 1C-13. Berm in cellar. Set cuttings tank. Wait on 3' x 12" to be trucked to location. Set sub down. 0.0 0.0 7/27/2024 13:30 7/27/2024 15:30 2.00 MIRU, MOVE MOB P Move in auxillary equipment. Mud shack. Smoke shack. Take on 9.0 PPG NaCl into pits. Build 30 Bbls headted deep clean pill w/ vis. Pull RKB's. Take initial pressures. T/I/O = 380/160/200. R/U circulating equipment. Rig accepted @ 15:30 Hrs. 0.0 0.0 7/27/2024 15:30 7/27/2024 20:00 4.50 MIRU, WELCTL RURD P Begin processing DP while waiting on set up of tiger tank & open top tank. R/U tiger tank hard line. Test new rig pump cap seals. 0.0 0.0 7/27/2024 20:00 7/27/2024 20:30 0.50 MIRU, WELCTL SEQP P Flood lines and test to 2500 PSI. Establish circulating rate through blooie line to tiger tank. @ 266 PSI @ 4 BBL/ Min. 0.0 0.0 7/27/2024 20:30 7/27/2024 23:00 2.50 MIRU, WELCTL KLWL P Bleed free gas off of tubing and IA. Line up to pumpd down tubing, and take returns out the IA. Kill well. Pump 30 BBL Deep clean pill, followed by 406 BBLS of 9.0 PPG Brine @ 4 BBL/Min. ICP: 690 PSI FCP: 530 PSI 0.0 0.0 7/27/2024 23:00 7/28/2024 00:00 1.00 MIRU, WELCTL OWFF P OWFF 30 MIN: Static. FMC reps function LDS and gland nuts. 0.0 0.0 7/28/2024 00:00 7/28/2024 00:30 0.50 MIRU, WELCTL MPSP P Set BPV in hanger and test from bellow for 10 min. Pressure transfer to OA. 0.0 0.0 7/28/2024 00:30 7/28/2024 01:30 1.00 MIRU, WHDBOP OTHR P Blow down, and rig down circulating and test lines on the rig floor, and in the cellar. 0.0 0.0 7/28/2024 01:30 7/28/2024 04:00 2.50 MIRU, WHDBOP NUND P N/D tree and adaptor flange. Inspect hanger neck threads. Test run X/O for hanger neck. Screw in 3.25 turns and stopped. Install test plug in hanger neck. 0.0 0.0 7/28/2024 04:00 7/28/2024 08:00 4.00 MIRU, WHDBOP NUND P N/U BOP, Install flow nipple & hook up trip tank line. 0.0 0.0 7/28/2024 08:00 7/28/2024 10:00 2.00 MIRU, WHDBOP RURD P Grease choke manifold and choke & kill lines. R/U testing equipment. Fill stack w/ fresh water. Shell test BOPE. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Page 2/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/28/2024 10:00 7/28/2024 17:00 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2" & 5 ½ test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ & 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3150 PSI, after closure=1750 PSI, 200 PSI attained =17 sec, full recovery attained =107 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 17 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2200 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. 0.0 0.0 7/28/2024 17:00 7/28/2024 17:30 0.50 MIRU, WHDBOP RURD P B/D., R/D testing equipment. Suck out stack. 0.0 0.0 7/28/2024 17:30 7/28/2024 18:00 0.50 MIRU, WHDBOP MPSP P Pull dart & BPV. 0.0 0.0 7/28/2024 18:00 7/28/2024 19:00 1.00 COMPZN, RPCOMP FISH P P/U Baker spear, and M/U to joint of drill pipe. RIH and engauge tubing hanger @ 26'. BOLDS. 0.0 7,973.0 7/28/2024 19:00 7/28/2024 19:30 0.50 COMPZN, RPCOMP THGR P Pull hanger to rig floor. Pull up to 160K, break over to 120K. 7,973.0 7,945.0 7/28/2024 19:30 7/28/2024 20:00 0.50 COMPZN, RPCOMP CIRC P CBU @ 4 BBL/Min @ 525 PSI. R/U spooler, power tongs, and prepare rig floor, and pipe shed to L/D 4.5" tubing. 7,945.0 7,945.0 7/28/2024 20:00 7/28/2024 20:30 0.50 COMPZN, RPCOMP BHAH P Disengauge spear from hanger, break off spear from joint of DP, and L/D both. B/O & L/D tubing hanger. 7,945.0 7,945.0 7/28/2024 20:30 7/29/2024 00:00 3.50 COMPZN, RPCOMP PULL P POOH L/D tubing F/ 7945' to 6445'. PUWT: 125K 7,945.0 6,445.0 7/29/2024 00:00 7/29/2024 05:00 5.00 COMPZN, RPCOMP PULL P POOH L/D 4.5" 12.6 # L-80 NSCT tubing F/ 6445' T/ 2139 6,445.0 2,139.0 7/29/2024 05:00 7/29/2024 05:30 0.50 COMPZN, RPCOMP SVRG P Service pipe skate. Hose leak. 2,139.0 2,139.0 7/29/2024 05:30 7/29/2024 06:00 0.50 COMPZN, RPCOMP PULL P Cont L/D 4 1/2" completion F/ 2139' T/ 1784'. PUW=54K. 2,139.0 1,784.0 7/29/2024 06:00 7/29/2024 06:30 0.50 COMPZN, RPCOMP SVRG P Service pipe skate. Replace hyd hose. 1,784.0 1,784.0 7/29/2024 06:30 7/29/2024 08:30 2.00 COMPZN, RPCOMP PULL P Cont L/D 4 1/2" completion F/ 1784' T/ surface. PUW=51K. 14.3' cut joint. Clean cut. 1,784.0 0.0 7/29/2024 08:30 7/29/2024 09:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. 0.0 0.0 7/29/2024 09:00 7/29/2024 10:30 1.50 COMPZN, RPCOMP RURD P R/D TBG handling equipment. Remove HES spooling unit from RF. Clear pipe shed. 0.0 0.0 7/29/2024 10:30 7/29/2024 12:30 2.00 COMPZN, RPCOMP RURD P Mobilize BHA #2 to RF & pipe shed. 0.0 0.0 7/29/2024 12:30 7/29/2024 13:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #2 skirted dress off mill W/ 6 1/2" string mill. Bumper sub, jars. 1 stand DC's. 2 String magnets T/ 155'. SOW=40K.. 0.0 155.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Page 3/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/29/2024 13:30 7/29/2024 22:00 8.50 COMPZN, RPCOMP PULD P PUDP F/ 155' T/ 7948', PUW=139K, SOW=104K. 155.0 7,948.0 7/29/2024 22:00 7/29/2024 22:30 0.50 COMPZN, RPCOMP REAM P Wash and ream F/ 7948' to 7961 60 RPM @ 4K TQ 4BBL/ Min @ 877 PSI. 7,948.0 7,961.0 7/29/2024 22:30 7/29/2024 23:00 0.50 COMPZN, RPCOMP WASH P Wash down and tag top of stump @ 7973'. Swallow stump 5.24' to 7979' (Tagging top of stump w/ Dress off mill @ 7973). Dress off stump @ 20 RPM @ K TQ. 7,961.0 7,979.0 7/29/2024 23:00 7/30/2024 00:00 1.00 COMPZN, RPCOMP CIRC P Pump 25 BBL Hi Vis sweep @ 4.5 BBL/ Min @ 1098 PSI. 7,979.0 7,978.0 7/30/2024 00:00 7/30/2024 00:30 0.50 COMPZN, RPCOMP PULD P POOH L/D DP to 7,880'. 7,978.0 7,880.0 7/30/2024 00:30 7/30/2024 03:00 2.50 COMPZN, RPCOMP SLPC P Cut and slip drilling line. 7,880.0 7,880.0 7/30/2024 03:00 7/30/2024 10:30 7.50 COMPZN, RPCOMP PULD P POOH L/D DP F/ 7880' to 155' 7,880.0 155.0 7/30/2024 10:30 7/30/2024 12:00 1.50 COMPZN, RPCOMP BHAH P L/D and kick out cleanout BHA. 155.0 0.0 7/30/2024 12:00 7/30/2024 22:00 10.00 COMPZN, RPCOMP RURD P Load and process 195 joints of 5 1/2" tieback liner. Load tieback jewelry and two joints of 3 1/2" tubing. Measure pup joints. Load and RU GBR power tongs and pipe handling equipment. Adjust hi- line power cord to allow stinger access to cellar. 0.0 0.0 7/30/2024 22:00 7/31/2024 00:00 2.00 COMPZN, RPCOMP PUTB P Confirm tally, jewelry, and run order. Run 5 1/2" tieback as per Tally. 0.0 600.0 7/31/2024 00:00 7/31/2024 01:30 1.50 COMPZN, RPCOMP PUTB P Cont. to run 5 1/2" tieback as per Tally. 600.0 2,300.0 7/31/2024 01:30 7/31/2024 02:00 0.50 COMPZN, RPCOMP CIRC P Circulate @ 3 bpm 263 psi // Pipe stopped filling normally // Circulated SxS ensure pipe clean, no abnormalities on BU 2,300.0 2,300.0 7/31/2024 02:00 7/31/2024 05:00 3.00 COMPZN, RPCOMP PUTB P Cont. run 5 1/2" tieback as per Tally. PU Joint #188. Screw in TD. 2,300.0 7,937.0 7/31/2024 05:00 7/31/2024 09:15 4.25 COMPZN, RPCOMP HOSO P Obtain parameters. PUW = 130K, SOW = 90K. Pump Rate = 2.5 BPM @ 568 psi. TIH swallow 4 1/2" tubing stub w/ PB overshot. See shear pins shear out @ 7,975.4' (14K set down). Saw pressure spike to 960 psi after shear out. SD pumps. Cont TIH and space out 2' above no-go. Mark Pipe. Set Joint #188 collar in slips at rig floor. 7,937.0 7,977.0 7/31/2024 09:15 7/31/2024 10:00 0.75 COMPZN, RPCOMP RURD P BD top drive. RU head pin and circ hose for reverse circ. setup. Check pump pressures when over stump. Unable to circ at 1 BPM under 1,000 psi. Cellar gas bubbles increase at 1,000 psi circ pressure. Decided to pump CI above stump at lower circ. pressure. 7,977.0 7,977.0 7/31/2024 10:00 7/31/2024 11:00 1.00 COMPZN, RPCOMP CIRC P PU off stump. Bring pumps on at 3 BPM / 756 psi. Reverse circulated 71 bbls of CI down 5 1/2" x 7" annulus. SD Pumps. Clear lines. RD rev. circ. equipment. 7,977.0 7,971.0 7/31/2024 11:00 7/31/2024 11:15 0.25 COMPZN, RPCOMP HOSO P Screw in TD. Re-land 5 1/2" Tieback (Joint #188) in slips at space out mark (2' space out from no-go). 7,971.0 7,977.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Page 4/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/31/2024 11:15 7/31/2024 14:15 3.00 COMPZN, RPCOMP OWFF P Unscrew Top Drive. OWFF for 30-min. Slight flow/dribble after 30-min. Check OA pressure. 350 psi. Bleed off OA to bleed trailer. Bleed to 300 psi. SI and monitor for 30-min. OA pressure slowly built back up to 340 psi. See slight flow from 5 1/2" casing at rig floor. RU 2" hose to OA and bleed OA to tiger tank. Process 3 1/2" Tubing while working to achieve NFT. Bleed OA free gas and 5 bbls diesel to tiger tanks. OA pressure = 340 psi. 7,977.0 7,977.0 7/31/2024 14:15 7/31/2024 16:30 2.25 COMPZN, RPCOMP OWFF P Monitor OA pressure for 30-min, OA pressure after 30-min = 325 psi. Drain Stack. NFT 5 1/2" x 7" backside (new OA) in cellar. Still showing slight flow. Suspect 7" casing leak is talking with 9 5/8" OA. Discuss option to circ. out OA to 9.0# to achieve a NFT across 5 1/2" + IA + OA. 7,977.0 7,977.0 7/31/2024 16:30 7/31/2024 18:00 1.50 COMPZN, RPCOMP OWFF P OA pressure at 325 psi. Open OA and bleed to tiger tank, keeping hole full using trip tank/charge pump. 7,977.0 7,977.0 7/31/2024 18:00 8/1/2024 00:00 6.00 COMPZN, RPCOMP NUND P Drop Ball and Rod. ND BOP. Install emergency slips. Cut 5 1/2" casing for pack-off. L/D cut joint. Cut Joint (#188) pulled = 27.88'. Set pack-off. Install reducer bushing and new tubing head. Test packoff to 3,500 psi. NU BOP. Process 3 1/2" Tubing on ODS during NUND operations. 7,977.0 0.0 8/1/2024 00:00 8/1/2024 02:30 2.50 COMPZN, RPCOMP NUND P Install new tubing head, orientation verified by pad operator, torque up all bolts on well head and stack, install riser to flow box 0.0 0.0 8/1/2024 02:30 8/1/2024 04:00 1.50 COMPZN, RPCOMP BOPE P Set test plug, test breaks 250/2500 // Pull test plug rig down test equipment 0.0 0.0 8/1/2024 04:00 8/1/2024 06:00 2.00 COMPZN, RPCOMP FRZP P Rig up LRS // PT Lines // Pump 20 bbls LEPD freeze protect into OA @ .75 bpm @ 825 psi taking returns up 5.5" casing // 15 bbls pumped @ .75 bbls/min @ 725 psi 0.0 0.0 8/1/2024 06:00 8/1/2024 07:15 1.25 COMPZN, RPCOMP PACK P RU to chart packer set. Flood lines for PT. OA = 90 psi. OOA = 90 psi. Bring pumps online slowly to set Packer per SLB rep. Ball and rod on seat. Pressure up slowly to approx. 1,300 psi and see initial packer shear. Hold pressure at 1,800 psi for 1-min. Pressure up to 3,500 psi to complete Packer set. Hold for 30-min. Charted. Passed. OA = 300 psi. OOA = 390 psi. 0.0 0.0 8/1/2024 07:15 8/1/2024 08:15 1.00 COMPZN, RPCOMP PRTS P PT 5 1/2" Tieback to 3,000 psi. Chart. Hold for 30-min. OOA = 390. OA = 300 psi 0.0 0.0 8/1/2024 08:15 8/1/2024 08:45 0.50 COMPZN, RPCOMP RURD P Bleed off pressure. OOA/OA bled to 90 psi. Open Blinds. RU IA 1502 integral and plug valve to IA in cellar. Prep rig floor to run 3 1/2" EUE completions. 0.0 0.0 8/1/2024 08:45 8/1/2024 19:45 11.00 COMPZN, RPCOMP PUTB P Verify 3 1/2" completions jewelry run order and tally. PJSM. Run 3 1/2" completions as per Tally. 0.0 7,814.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Page 5/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/1/2024 19:45 8/1/2024 21:00 1.25 COMPZN, RPCOMP HOSO P Tag NG @ 7813.8' Calculate space out // Pick up Pups 10.25', 10.20', 2.03' // Run in hole with jt 244 on top // Run in hole confirm space out with pump pressure spike // Space out to circ in CI 7,814.0 7,777.0 8/1/2024 21:00 8/1/2024 22:00 1.00 COMPZN, RPCOMP DISP P Displace IA with 95 bbls 9.0# Corrosion Inhibited Brine 7,777.0 7,777.0 8/1/2024 22:00 8/1/2024 22:30 0.50 COMPZN, RPCOMP THGR P Attempt to land completion // XO on bottom of hanger assembly too big to fit through packoff // OD of XO = 5.20" ID of packoffs 4.90" // 7,777.0 7,777.0 8/1/2024 22:30 8/2/2024 00:00 1.50 COMPZN, RPCOMP WAIT T Discuss with town engineer // Contact Northern Solutions to machine XO for bottom of hanger // Send hanger and 4' pup to Northern to be bucked up after XO built 7,777.0 7,777.0 8/2/2024 00:00 8/2/2024 06:00 6.00 COMPZN, RPCOMP WAIT T Discuss with town engineer // Contact Northern Solutions to machine XO for bottom of hanger // Send hanger and 4' pup to Northern to be bucked up after XO built. Machining finished and truck headed back from Deadhorse. New hanger arrived on location @ 06:00 7,777.0 7,777.0 8/2/2024 06:00 8/2/2024 07:00 1.00 COMPZN, RPCOMP RURD P Load and MU Tubing hanger w/ new XO pup. MU landing joint to hanger. PUW = 95K. SOW = 72K. 7,777.0 7,777.0 8/2/2024 07:00 8/2/2024 07:30 0.50 COMPZN, RPCOMP THGR P Bring pumps online at min rate. See pressure indicator of seals stinging into SBR. SD Pumps. Open Bleeder. Land Tubing Hanger (seals spaced out 4' off no-go in SBR). RILDS. PT hanger seals to 5,000 psi. 7,777.0 7,810.0 8/2/2024 07:30 8/2/2024 08:45 1.25 COMPZN, RPCOMP RURD P RU testing equipment (hoses, manifold, 2x2 block valves, sensators) for Tubing and IA testing. 7,810.0 7,810.0 8/2/2024 08:45 8/2/2024 11:45 3.00 COMPZN, RPCOMP PRTS P Flood lines. PT Tubing to 3,000 psi for 30-minutes. Charted. Bleed Tbg to 1,500 psi. PT IA to 2,500 psi for 30-min. Charted. Dump Tubing pressure. Shear SOV. Confirm flow path through SOV. Pumped 10 bbls. 1 BPM @ 600 psi. L/D landing joint and XO. 7,810.0 0.0 8/2/2024 11:45 8/2/2024 12:00 0.25 COMPZN, RPCOMP RURD P R/D testing equipment. Drain Stack. 0.0 0.0 8/2/2024 12:00 8/2/2024 12:30 0.50 COMPZN, WHDBOP MPSP P Set BPV. Test BPV to 1,000 psi from below for 10-min. 0.0 0.0 8/2/2024 12:30 8/2/2024 13:00 0.50 COMPZN, WHDBOP OWFF P OWFF for 30-min. 0.0 0.0 8/2/2024 13:00 8/2/2024 16:30 3.50 COMPZN, WHDBOP NUND P ND BOP. Install test dart. NU Tubing Head Adapter and Tree. Orient tree based on pre-rig pictures. 0.0 0.0 8/2/2024 16:30 8/2/2024 17:30 1.00 COMPZN, WHDBOP PRTS P Test Hanger void to 5,000 psi. RU LRS and circ equipment. Test Tree to 5,000 psi. 0.0 0.0 8/2/2024 17:30 8/2/2024 18:00 0.50 COMPZN, WHDBOP MPSP P Pull test dart/BPV. 0.0 0.0 8/2/2024 18:00 8/2/2024 20:00 2.00 DEMOB, MOVE FRZP P RU LRS to pump down IA, taking returns from tubing to tanks. Pump 52 bbls diesel FP. U-Tube for 1 hour // Pump rate 1.5 bpm @ 1800 psi 0.0 0.0 8/2/2024 20:00 8/2/2024 21:00 1.00 DEMOB, MOVE RURD P RD LRS. Clean and clear cellar and tree. Obtain Final Pressures (T/IA/OA/OOA) = 0/180/210/90. Prep for rig move to 1B-04. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Page 6/6 1C-13 Report Printed: 8/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/2/2024 21:00 8/3/2024 00:00 3.00 DEMOB, MOVE RURD P Rig down per checklists // Rig released 00:00 8/3/24 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 8/3/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est.57' of Rathole) 8,560.0 1C-13 11/20/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig GLD, pull B&R/RHC, pulled catcher & hex plug 1C-13 8/10/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/12/2010 ninam 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.1 5,704.9 4,446.4 40.00 L-80 ABM-BTC PRODUCTION 7 6.28 37.9 8,234.9 6,356.1 26.00 L-80 ABM-BTC Tie-Back String 5 1/2 4.95 0.0 7,977.5 6,119.3 15.50 L-80 HYD 563 LINER 4 1/2 3.96 8,031.5 8,677.0 6,768.0 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.5 Set Depth 7,810.6 String Max No 3 1/2 Set Depth 5,969.9 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 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) 33.5 33.5 0.00 Hanger 10.880 FMC Gen 5 Tubing Hanger, 3.5" x 7 1/16" w/ 3" H BPV Profile FMC Gen 5 2.910 2,246.8 2,146.8 46.72 Mandrel GAS LIFT 3.500 3.5" x 1" KBG-2-9 (DMY w/ BK Latch), SN: 24183-17 SLB KBG-2-9 2.818 3,775.5 3,163.7 47.38 Mandrel GAS LIFT 3.500 3.5" x 1" KBG-2-9 (DMY w/ BK Latch), SN:24183-16 SLB KBG-2-9 2.818 7,711.2 5,883.5 30.93 Mandrel GAS LIFT 3.500 3.5" x 1" KBG-2-9 (2,000 psi SOV w/ BEK Latch), SN: 24183-15 SLB KBG-2-9 2.818 7,768.2 5,932.7 29.41 Nipple - X 4.501 2.813" X-Nipple, SN#: 0005011991- 15 HES X-Nipple 2.813 7,789.5 5,951.3 28.85 Locator 4.500 Baker Locator (4.50" OD No-Go) Baker Locator 2.940 7,790.0 5,951.8 28.84 Seal Assembly 3.980 Baker GBH22 80-40 Seal Assembly (4' from fully located) Baker GBH-22 - 80-40 2.940 Top (ftKB) 7,973.0 Set Depth 8,024.4 String Max No 4 1/2 Set Depth 6,162.0 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,994.5 6,134.7 24.55 PBR 5.000 BAKER 80-40 PBR w/ KBH-22 ANCHOR SEAL ASSEMBLY 3.875 8,009.4 6,148.3 24.30 PACKER 5.970 BAKER FAB-1 PACKER 3.938 8,023.4 6,161.1 24.07 SEAL ASSY 5.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.938 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) 35.7 35.7 0.00 EMERGENCY SLIPS 5 1/2" Tieback Emergency Slips set in Casing Head. FMC 7/31/2024 5.500 5,023.0 3,995.6 47.08 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED ON WFL LDL RUN 12/2/23 12/2/2023 6.280 7,831.5 5,988.3 27.79 OTHER 3.5" x 1.5" MMG, GLM, DMY w/ RK Latch SN# 24384-18 7/31/2024 2.992 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,246.8 2,146.8 46.72 1 GAS LIFT GLV BTM 1 1,180.0 8/9/2024 SLB KBG-2-9 0.250 3,775.5 3,163.7 47.38 2 GAS LIFT OV BTM 1 0.0 8/9/2024 SLB KBG-2-9 0.313 7,711.2 5,883.5 30.93 3 GAS LIFT DMY BTM 1 8/9/2024 SLB KBG-2-9 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 Parker 245 ORKB = 35.66'. Nordic 3 RKB = 26.98' 0.000 Parker 245 ORKB = 35.66'. Nordic 3 RKB = 26.98' 0.000 7,793.1 5,954.5 28.76 SBR 5.030 80-40 SBR, 5" HYD 521 Box x 4 1/2" HYD 521 Pin Baker 80-40 SBR 4.000 7,831.5 5,988.3 27.79 Mandrel GAS LIFT 5.891 3.5" x 1.5" MMG, GLM, DMY w/ RK Latch SN# 24384-18 SLB MMG 2.920 7,892.7 6,042.8 26.37 Packer 6.280 7" x 3 1/2" Bluepack RH Packer, SN# 22P-1095 SLB Bluepack RH 2.881 7,947.7 6,092.3 25.33 Nipple - X 4.502 3 1/2" x 2.813 X Nipple, SN# 0005011991-6 HES X Nipple 2.813 7,970.3 6,112.8 24.95 Overshot 5.980 Baker 4 1/2" PB Overshot (2' space out, 6.48' swallow to No- Go) Baker Poor Boy Overshot 4.620 8,031.5 6,168.5 23.94 PBR 5.813 BAKER 80-47 PBR & C-2 SETTING SLEEVE 4.750 8,044.0 6,180.0 23.73 XO BUSHING 4.500 BAKER XO BUSHING 4.000 8,088.4 6,220.7 23.00 NIPPLE 4.500 CAMCO DB NIPPLE w/ 3.75" NO GO PROFILE 3.750 1C-13, 8/22/2024 8:37:36 AM Vertical schematic (actual) LINER; 8,031.5-8,677.0 IPERF; 8,504.0-8,523.0 IPERF; 8,395.0-8,415.0 IPERF; 8,365.0-8,395.0 IPERF; 8,350.0-8,365.0 IPERF; 8,334.0-8,350.0 PRODUCTION; 37.9-8,234.9 PACKER; 8,009.4 Tie-Back String; 0.0-7,977.5 OTHER; 7,831.5 Nipple - X; 7,768.2 Mandrel GAS LIFT; 7,711.2 SURFACE; 41.1-5,704.9 LEAK - CASING; 5,023.0 Mandrel GAS LIFT; 3,775.5 Mandrel GAS LIFT; 2,246.8 CONDUCTOR; 42.0-121.0 EMERGENCY SLIPS; 35.7 Hanger; 33.5 KUP PROD KB-Grd (ft) 46.91 RR Date 2/14/1998 Other Elev 1C-13 ... TD Act Btm (ftKB) 8,677.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292285600 Wellbore Status PROD Max Angle & MD Incl (°) 49.47 MD (ftKB) 2,489.86 WELLNAME WELLBORE1C-13 Annotation Last WO: End DateH2S (ppm) 30 Date 8/12/2016 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,611.3 6,706.8 21.39 LANDING COLLAR 4.500 BAKER LANDING COLLAR 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,334.0 8,350.0 6,448.4 6,463.3 C-4, 1C-13 6/17/1999 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; +/- 90 deg. low side 8,350.0 8,365.0 6,463.3 6,477.3 C-4, 1C-13 4/22/1998 4.0 IPERF SWS 2 7/8" DP, 60/120 phased 8,365.0 8,395.0 6,477.3 6,505.3 C-4, 1C-13 4/9/1998 4.0 IPERF SWS 2 7/8" DB, 180 phased 8,395.0 8,415.0 6,505.3 6,523.9 C-3, C-4, 1C-13 3/5/1998 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; 90 deg. Oriented 8,504.0 8,523.0 6,606.9 6,624.6 C-1, 1C-13 8/24/2011 6.0 IPERF DP, 60 DEG PHASE 1C-13, 8/22/2024 8:37:37 AM Vertical schematic (actual) LINER; 8,031.5-8,677.0 IPERF; 8,504.0-8,523.0 IPERF; 8,395.0-8,415.0 IPERF; 8,365.0-8,395.0 IPERF; 8,350.0-8,365.0 IPERF; 8,334.0-8,350.0 PRODUCTION; 37.9-8,234.9 PACKER; 8,009.4 Tie-Back String; 0.0-7,977.5 OTHER; 7,831.5 Nipple - X; 7,768.2 Mandrel GAS LIFT; 7,711.2 SURFACE; 41.1-5,704.9 LEAK - CASING; 5,023.0 Mandrel GAS LIFT; 3,775.5 Mandrel GAS LIFT; 2,246.8 CONDUCTOR; 42.0-121.0 EMERGENCY SLIPS; 35.7 Hanger; 33.5 KUP PROD 1C-13 ... WELLNAME WELLBORE1C-13 ORIGINATED TRANSMITTAL DATE: 6/28/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4899 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4899 1C-13 50029228560000 Plug Setting Record 27-Jun-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-011 T39090 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.28 13:42:38 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com 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: Pull/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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8677'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/1/2024 8677'646' 4-1/2" 6768' Packer: Baker FAB-1 Packer SSSV: None Perforation Depth MD (ft): L-80 5664' 8334-8415', 8504-8523' 8197' 4-1/2" 6449-6524', 6607-6625' 7" Perforation Depth TVD (ft): 121' 5705' 6356'8235' 16" 9-5/8" 79' 6162' MD 121' 4446' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 198-011 P.O. Box 100360, Anchorage, AK 99510 50-029-22856-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8009' MD and 6148' TVD N/A Adam Klem Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: adam.klem@conocophillips.com (907) 263-4529 Staff RWO/CTD Engineer KRU 1C-13 6768' 8088' 6220' 1953 8088' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:30 am, May 28, 2024 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: Location: Date: 2024.05.23 14:40:30-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 324-312 X BOP test to 2500 psig Annular preventer test to 2500 psig X SFD 5/29/2024VTL 6/24/2024 10-404 DSR-5/29/24*&:JLC 6/24/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.24 15:21:34 -08'00'06/24/24 RBDMS JSB 062624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 22, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 1C-13 (PTD# 198-011). 1C-13 is a producer drilled in 1998 completed with 4.5" tubing and liner and 7" casing. A production casing leak was identified at 5023'MD, along with a fair amount of wall loss noted across entire casing. Therefore, a RWO is needed to pull the tubing and repair the leak. The RWO plan is to pull the tubing then isolate the 7" casing with a 5.5" tieback liner, then run 3.5" tubing. If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem @conocophillips.com, C=US Reason: Location: Date: 2024.05.23 14:40:46-08'00' Foxit PDF Editor Version: 13.0.0 Adam Klem 1C-13 RWO Procedure Kuparuk Producer PTD #198-011 Page 1 of 2 Remaining Pre-Rig Work 1. Pull current DBP plug 2. Get updated SBHP 3. Re-secure with ME plug that can set in 4.5” tubing and drift thru 3.5” tubing 4. Dummy off GLM, leaving GLM at 7915’ RKB open for circulation 5. Cut the tubing in the first full joint above the packer, ~7950’ RKB 6. Install BPV within 48 hrs of rig arrival and prep well for rig. Rig Work MIRU 1. MIRU Nordic 3 on 1C-13. Pull BPV if need to circulate. 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. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4.5” Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to pre-rig cut (~7950’ RKB). 6. When pulling 4.5” tubing, set 7” storm packer and PT to confirm as barrier. 7. ND BOPs. ND old tubing head. NU new casing head for 5.5” tieback. NU BOPs. Test flange breaks. 8. Pull 7” storm packer and remainder of tubing. Run new 5.5” Tie-back 9. MU 5.5” x 3.5” tie-back liner with non-sealing overshot for the 4.5” tubing and 3.5” x 7.0” packer. 10. Once on depth, space out, and circ CI brine to above packer 11. Drop ball and rod. Pressure up to set packer as needed. 12. Pressure test casing and tubing to 3000 psi for 30 minutes and chart. 13. Set 5.5” RBP and PT to confirm as barrier. 14. ND BOPs. NU new tubing head for 3.5” tubing. NU BOPs. Test flange breaks. 15. Pull 5.5” RBP. Install new 3-½” Tubing 16. MU 3 ½” completion with seals, nipples, and GLMs. 17. Once on depth, stab into seals and space out as needed. 18. PU and circulate in corrosion inhibited fluid. Stab back in to seals. 19. Pressure test tubing to 3000 psi for 30 minutes on chart. PT packoffs. 20. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 21. Shear SOV ND BOP, NU Tree 22. Install BPV. 23. ND BOPE. NU tree. 24. Pull BPV, freeze protect well if needed, and set BPV if necessary. 25. RDMO. Post-Rig Work 26. Pull BPV 27. Install GLD 1C-13 RWO Procedure Kuparuk Producer PTD #198-011 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 5k Production Engineer: Banabas (Barny) Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 7/1/2024 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 4.5”completion, install a new 5 ½” casing and new 3 ½” tubing. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross/ Pipe Ram / Mud Cross MIT results: Tbg: MITT to 2500psi 11/4/23, and will have a new MITT pre rig IA: known leak IC POT & PPPOT: passed 11/1/23 TBG POT &PPPOT: passed 10/4/23 MPSP: 1,953 psi using 0.1 psi/ft gradient Static BHP: 2,567 psi / 6139’ TVD measured on 10/20/22 1C-13 Proposed Schematic PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface PBR for 3-1/2" Seals 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" x 7" Packer 2.813" X-landing nipple at xxxx' RKB (2.813" min ID) 4-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE FAB-1 Perm Packer @ 8009' RKB (3.938" ID) DB nipple @ 8088 RKB (3.75" ID) Surface Casing Intermediate Casing Conductor C-sand perfs 7" PC Leak @ 5023' Prod Liner Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est.57' of Rathole) 8,560.0 1C-13 11/20/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added PC leak at 5023' RKB 1C-13 12/2/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/12/2010 ninam 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.1 5,704.9 4,446.4 40.00 L-80 ABM-BTC PRODUCTION 7 6.28 37.9 8,234.9 6,356.1 26.00 L-80 ABM-BTC LINER 4 1/2 3.96 8,031.5 8,677.0 6,768.0 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.6 Set Depth … 8,024.2 Set Depth … 6,161.8 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT ID (in) 3.96 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) 35.6 35.6 0.00 HANGER 10.800 FMC GEN V HANGER 4.500 1,509.6 1,507.7 11.43 NIPPLE 5.210 CAMCO BP-61 LANDING NIPPLE 3.813 2,959.1 2,613.9 48.85 GAS LIFT 5.781 BST AXT 3.828 4,951.0 3,946.6 47.30 GAS LIFT 5.781 BST AXT 3.828 6,421.2 4,921.9 47.23 GAS LIFT 5.781 BST AXT 3.828 7,409.8 5,632.5 36.16 GAS LIFT 5.781 BST AXT 3.828 7,914.9 6,062.7 25.87 GAS LIFT 5.781 BST AXT 3.828 7,957.1 6,100.8 25.17 NIPPLE 5.210 OTIS X NIPPLE 3.813 7,994.3 6,134.6 24.55 PBR 5.000 BAKER 80-40 PBR w/ KBH-22 ANCHOR SEAL ASSEMBLY 3.875 8,009.2 6,148.1 24.30 PACKER 5.970 BAKER FAB-1 PACKER 3.938 8,023.2 6,160.9 24.07 SEAL ASSY 5.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.938 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) 5,023.0 3,995.6 47.08 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED ON WFL LDL RUN 12/2/23 12/2/2023 6.280 8,080.0 6,213.0 23.13 OTHER Set baited (4.5" bait sub) PX prong in plug body ( OAL 100") 10/28/2023 0.000 8,088.0 6,220.3 23.00 TUBING PLUG Set 3.75" DBP plug body 10/28/2023 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) 2,959.1 2,613.9 48.85 1 GAS LIFT DMY T-1 1 0.0 11/4/2023 0.000 4,951.0 3,946.6 47.30 2 GAS LIFT DMY T-1 1 0.0 11/4/2023 0.000 6,421.2 4,921.9 47.23 3 GAS LIFT DMY T-1 1 0.0 1/4/2004 0.000 7,409.8 5,632.5 36.16 4 GAS LIFT DMY T-1 1 0.0 7/12/2016 exten ded packin g 0.000 7,914.9 6,062.7 25.87 5 GAS LIFT DMY T-1 1 0.0 7/25/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,031.5 6,168.5 23.94 PBR 5.813 BAKER 80-47 PBR & C-2 SETTING SLEEVE 4.750 8,044.0 6,180.0 23.73 XO BUSHING 4.500 BAKER XO BUSHING 4.000 8,088.4 6,220.7 23.00 NIPPLE 4.500 CAMCO DB NIPPLE w/ 3.75" NO GO PROFILE 3.750 8,611.3 6,706.8 21.39 LANDING COLLAR 4.500 BAKER LANDING COLLAR 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,334.0 8,350.0 6,448.4 6,463.3 C-4, 1C-13 6/17/1999 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; +/- 90 deg. low side 8,350.0 8,365.0 6,463.3 6,477.3 C-4, 1C-13 4/22/1998 4.0 IPERF SWS 2 7/8" DP, 60/120 phased 8,365.0 8,395.0 6,477.3 6,505.3 C-4, 1C-13 4/9/1998 4.0 IPERF SWS 2 7/8" DB, 180 phased 8,395.0 8,415.0 6,505.3 6,523.9 C-3, C-4, 1C-13 3/5/1998 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; 90 deg. Oriented 8,504.0 8,523.0 6,606.9 6,624.6 C-1, 1C-13 8/24/2011 6.0 IPERF DP, 60 DEG PHASE 1C-13, 12/2/2023 4:47:09 PM Vertical schematic (actual) LINER; 8,031.5-8,677.0 FLOAT SHOE; 8,675.1-8,677.0 FLOAT COLLAR; 8,643.1- 8,644.2 LANDING COLLAR; 8,611.3- 8,612.4 IPERF; 8,504.0-8,523.0 IPERF; 8,395.0-8,415.0 IPERF; 8,365.0-8,395.0 IPERF; 8,350.0-8,365.0 IPERF; 8,334.0-8,350.0 PRODUCTION; 37.9-8,234.9 FLOAT SHOE; 8,233.4-8,234.9 FLOAT COLLAR; 8,154.9- 8,156.3 NIPPLE; 8,088.4-8,089.9 TUBING PLUG; 8,088.0 OTHER; 8,080.0 HANGER; 8,045.5-8,052.3 XO BUSHING; 8,044.0-8,045.5 PBR; 8,031.5-8,044.0 SEAL ASSY; 8,023.2 PACKER; 8,009.2 PBR; 7,994.3 NIPPLE; 7,957.1 GAS LIFT; 7,914.9 GAS LIFT; 7,409.8 GAS LIFT; 6,421.2 SURFACE; 41.1-5,704.9 FLOAT SHOE; 5,703.2-5,704.9 FLOAT COLLAR; 5,617.2- 5,618.7 LEAK - CASING; 5,023.0 GAS LIFT; 4,951.0 GAS LIFT; 2,959.1 STAGE COLLAR; 2,041.6- 2,044.4 NIPPLE; 1,509.6 CONDUCTOR; 42.0-121.0 HANGER; 41.1-43.2 HANGER; 37.9-38.9 HANGER; 35.7 KUP PROD KB-Grd (ft) 46.91 RR Date 2/14/1998 Other Elev… 1C-13 ... TD Act Btm (ftKB) 8,677.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292285600 Wellbore Status PROD Max Angle & MD Incl (°) 49.47 MD (ftKB) 2,489.86 WELLNAME WELLBORE1C-13 Annotation Last WO: End DateH2S (ppm) 30 Date 8/12/2016 Comment SSSV: NIPPLE TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 198-011/ • • '2:1 Cc, zA WELL LOG TRANSMITTAL#903424991 To: Alaska Oil and Gas Conservation Comm. RECEIVED August 17, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Ut,T 04 2010 DATA LOGGED Anchorage, Alaska 99501 , d`'=''3 MK.BENDER RE: Leak Detect Log with ACX: 1C-13 Run Date: 7/14/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-13 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22856-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-029-22856-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED N 0 V 0 32016 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ✓ct/24a yut.i - / .,E:k_"'"( • '2:73g c:=,) WELL LOG EGLIVED TRANSMITTAL JUL 2 0 2016 ,t. AOGCC PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED 1 /2A/201G M.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Diane F.Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 i- 'NED NOV 1 2016 1) Coil Flag 12-Jul-16 1C-13 1 Report /CD 50-029-22856-00 2) Signed : /'22/4L2.4ZL, i' 45,.e„ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:WchivesWasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx RIOCEIVED27139 '''l IP/ JUL 2 0 2015 Memory Multi-Finger Caliper ..... 0 " AOGCC Log Results Summary Company: ConocoPhillips Alaska, LLC. Well: 1C-13 Log Date: July 12, 2016 Field: Kuparuk Log No.: 12400 State: Alaska Run No.: 1 API No. 50-029-22856-00 Pipe Description: 4.5 inch 12.6 lb. L-80 NSCT Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 7,944 Ft.(MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 5 at 7,915 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage to assist in future patching operations. A 3-D log plot of the caliper recordings across GLM 4 where a previous LDL indicated a leak is included in this report. The caliper recordings indicate the 4.5 inch tubing logged appears to be in good to fair condition, with a maximum recorded wall penetration of 22% at a line of pits in joint 196(6,044 ft). Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : Line of Pits 22 196 6,044 Ft. (MD) Line of Pits 22 239 7,370 Ft. (MD) Line Corrosion 21 120 3,712 Ft. (MD) Line Corrosion 21 143 4,424 Ft. (MD) Line of Pits 21 193 5,956 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>7%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. D. Sparks C. Waldrop J. Fama ,:E z 1,,3 a: ,t, , ;i; ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis(amemorvlog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-13 Date : July 12, 2016 Description : Detail of Caliper Recordings Across GLM 4. Comments Depth Maximum Penetration Maximum I.D. 3-D Log Image Map 1ft.240ft 0 % 100 3.5 inches 4.5 0° 0° 90° 180° 270° 0° Minimum I.D. I I 3.5 inches 4.5 Nominal I.D. • 3.5 inches 4.5 ... t 1 7360 Joint 239 7370 7380 Joint 240 7390 I .., 11•'‘ ' -...... ..-11--- .... ..._. 7400 _ Pup Joint 7410 IL....._ GLM 4 . r — - Pup Joint 7420 .f I i - -77 7430 i 1 1 ----._- ... , Joint 241 7440 4 J 7450 i - ... .._ -. 11 -7 7 Joint 242 7460 g , I _. -i, 7A7A _---,- Nominal I.D. . • 3.5 inches 4.5 Minimum I.D. I I 3.5 inches 4.5 Comments Depth Maximum Penetration Maximum I.D. 3-D Log Image Map lft 240ft0 % 100 3.5 inches 4.5 0° 0° 90° 180° 270° 0° 0 0 Correlation of Recorded Damage to Borehole Profile 1111 Pipe 1 4.5 in (37.7-794,44) Well: 1C-13 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: July 12, 2016 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 41 25 773 a in 50 -� 1,551 1111111 75 2,315 GLM 1 100 3,097 E 125 3,855 'i 7_ c Z - L +-C+ J Q 150 4,615 GLM 2 -1 I 175 - 5,394 1 200 _ 6,147 GLM 3 225 _ 6,922 GLM 4 250 --i 7,695 GLM 5 = 257 7,927 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=257 • 110 PDS Report Overview 4-8 0, Body Region Analysis Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Pipe 4.5 in. 12.6 ppf L-80 NSCT Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT 3.958 in. 38 ft. 7,944 ft. Penetration (%wall) Damage Profile(%wall) 300 IN= Penetration body =IN Metal loss body 0 50 100 0.1 250 200 150 100 48.1 50 0 0 to 20 to 40 to over 20% 40% 85% 85% GLM 1 (9:00) 91.3 Number of joints analyzed(total=271) 261 10 0 0 Damage Configuration(body) 145 60 GLM 2 (12:00) 40 193 -. 20 GLM 3 (1:00) 111 IN 0 Isolated General Line Other Hole/ 240.1 Pitting Corrosion Corrosion Damage Pos.Hole GLM 4(6:00) Number of joints damaged(total=64) 10 0 54 0 0 Bottom of Survey=257 0 0 III IL i 110 PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 38 0 0.04 13 1 3.96 Pup • 1 41 0 0.04 14 2 3.95 1.1 73 0 0.02 8 1 3.96 Pup 2 78 0 0.02 8 2 3.96 3 108 0 0.03 9 3 3.94 4 139 0 0.03 10 4 3.93 5 169 0 0.03 10 3 3.96 6 200 0 0.03 10 4 3.93 7 230 0 0.03 10 3 3.96 8 261 0 0.02 8 2 3.96 9 291 0 0.03 11 2 3.94 10 322 0 0.03 10 3 3.94 11 352 0 0.03 10 2 3.95 ■ 12 382 0 0.03 11 4 3.92 ■ 13 413 0 0.03 10 2 3.96 ■ 14 443 0 0.03 10 3 3.95 ■ 15 473 0 0.03 13 2 3.96 a 16 504 0 0.03 13 2 3.95 ■ 17 535 0 0.03 11 4 3.94 a 18 563 0 0.03 13 3 3.92 19 594 0 0.03 9 3 3.87 Lt. Deposits. 20 625 0 0.04 13 2 3.90 Lt. Deposits. ■ 21 654 0 0.03 11 3 3.92 ■ 22 684 0 0.03 12 3 3.96 ■ 23 713 0 0.03 12 3 3.95 ■ 24 743 0 0.03 11 2 3.93 a 25 773 0 0.03 11 2 3.95 ■ 26 803 0 0.03 11 2 3.96 • 27 833 0 0.03 11 2 3.95 ■ 28 864 0 0.03 13 2 3.96 ■ 29 895 0 0.04 13 4 3.93 ■ 30 925 0 0.03 11 4 3.94 31 956 0 0.02 8 3 3.96 32 987 0 0.03 10 2 3.95 ■ 33 1017 0 0.03 11 3 3.91 • 34 1049 0 0.04 14 3 3.96 35 1079 0 0.02 8 2 3.95 36 1110 0 0.03 9 2 3.95 37 1140 0 0.03 11 3 3.95 ■ 38 1171 0 0.03 10 2 3.96 • 39 1201 0 0.03 11 3 3.90 ■ 40 1232 0 0.03 . 11 2 3.96 ■ 41 1263 0 0.03 13 3 3.89 Lt. Deposits. ■ 42 1293 0 0.04 13 3 3.93 ■ 43 1324 0 0.03 10 2 3.96 ■ 44 1354 0 0.04 14 3 3.94 ■ 45 1385 0 0.04 14 2 3.96 46 1415 0 0.03 10 2 3.95 47 1446 0 0.02 8 2 3.95 48 1476 0 0.04 13 4 3.94 'Penetration Body Metal Loss Body Page 1 i • PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 48.1 1507 0 0.02 6 1 3.92 Pup 48.2 1512 0 0 0 0 3.79 Camco BP-61 Landing Nipple 48.3 1515 0 0.01 5 1 3.93 Pup 49 1521 0 0.03 10 3 3.94 50 1551 0 0.02 7 2 3.89 Lt. Deposits. 51 1581 0 0.04 13 5 3.86 Lt. Deposits. 52 1610 0 0.03 12 3 3.96 53 1640 0 0.02 9 2 3.92 54 1671 0 0.04 13 3 3.95 55 1702 0 0.03 13 3 3.95 56 1732 0 0.03 11 2 3.91 57 1763 0 0.03 11 3 3.91 58 1794 0 0.03 10 3 3.95 59 182 5 0 0.02 9 2 3.93 60 1855 0 0.02 9 2 3.93 61 1886 0 0.02 9 3 3.91 62 1917 0 0.04 16 3 3.94 Shallow Line of Pits. 63 1948 0 0.03 12 3 3.88 Lt. Deposits. 64 1978 0 0.03 10 3 3.95 65 2009 0 0.03 13 2 3.95 66 2040 0 0.03 13 3 3.95 67 2071 0 0.03 9 1 3.94 68 2101 0 0.03 13 4 3.94 69 2131 0 0.03 10 3 3.95 70 2162 0 0.03 12 1 3.92 71 2193 0 0.03 12 3 3.94 72 2223 0 0.04 13 3 3.91 73 2254 0 0.04 13 2 3.94 74 2284 0 0.04 15 3 3.94 Shallow Line of Pits. 75 2315 0 0.04 14 2 3.95 76 2345 0 0.04 13 2 3.92 77 2376 0 0.04 14 2 3.96 78 2406 0 0.04 14 3 3.95 79 2436 0 0.03 13 2 3.95 80 2468 0.05 0.05 17 4 3.89 Shallow Line Corrosion.Lt. Deposits. 81 2498 0 0.04 13 2 3.94 82 2528 0 0.03 12 3 3.93 83 2559 0 0.04 13 3 3.93 84 2589 0 0.04 14 3 3.92 85 2620 0 0.04 16 2 3.95 Shallow Line Corrosion. 86 2651 0 0.03 11 3 3.95 87 2681 0 0.06 21 2 3.93 Line of Pits. 88 2712 0 0.04 14 3 3.95 89 2742 0 0.03 10 2 3.94 90 2773 0 0.04 14 2 3.94 91 2803 0 0.03 10 3 3.89 Lt. Deposits. 92 283 5 0 0.04 15 2 3.87 Shallow Line of Pits.Lt. Deposits. 93 2866 0 0.03 13 3 3.94 94 2896 0 0.05 17 7 3.92 Shallow Line of Pits. 95 292 7 0 0.04 15 5 3.92 Shallow Line of Pits. IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 95.1 2957 0 0.05 17 2 3.94 Pup Shallow Line of Pits. 95.2 2962 0 0 0 0 3.88 GLM 1 (Latch @ 9:00) 95.3 2969 0 0.04 14 1 3.93 Pup 96 2975 0 0.03 10 1 3.96 97 3006 0 0.03 13 2 3.90 98 3036 0 0.03 11 3 3.94 99 3066 0 0.03 11 2 3.95 100 309 7 0 0.03 12 2 3.94 ■ 101 312 7 0 0.04 14 2 3.94 102 3158 0 0.04 15 2 3.94 Shallow Line of Pits. 103 3188 0 0.03 10 1 3.94 104 3218 0 0.04 14 3 3.95 105 3248 0 0.03 11 2 3.92 106 3279 0 0.02 8 1 3.93 • 107 3308 0 0.04 13 2 3.93 108 3338 0 0.05 19 3 3.89 Shallow Line of Pits.Lt. Deposits. 109 3369 0 0.05 17 2 3.93 Shallow Line of Pits. imi 110 3399 0 0.04 15 4 3.92 Shallow Pitting. 111 3430 0 0.04 16 2 3.94 Shallow Pitting. 112 3460 0 0.06 21 2 3.89 Line of Pits. Lt.Deposits. mm 113 3492 0 0.05 18 3 3.94 Shallow Line of Pits. 114 3522 0 0.05 18 2 3.93 Shallow Line of Pits. 115 3551 0 0.04 14 3 3.86 Lt. Deposits. 116 3580 0 0.05 20 2 3.92 Line of Pits. 117 3610 0 0.05 19 4 3.94 Shallow Line of Pits. 118 3640 0 0.04 15 4 3.88 Shallow Line of Pits.Lt. Deposits. 119 3672 0 0.05 17 3 3.88 Shallow Line of Pits.Lt. Deposits. 120 3704 0.05 0.06 21 2 3.90 Line Corrosion. 121 3734 0 0.03 9 3 3.94 • 122 3764 0 0.04 15 1 3.93 Shallow Pitting. Am 123 3795 0 0.03 10 2 3.95 • 124 3825 0 0.02 7 1 3.94 • 125 3855 0 0.05 17 2 3.91 Shallow Line of Pits. 126 3886 0 0.03 10 2 3.94 • 127 3916 0 0.05 18 2 3.94 Shallow Line of Pits. 128 3946 0 0.02 8 2 3.94 • 129 3977 0 0.03 10 3 3.91 • 130 4007 0 0.04 14 2 3.93 131 403 8 0 0.03 10 1 3.94 • 132 4068 0 0.04 16 2 3.94 Shallow Pitting. 133 4098 0 0.03 10 1 3.94 • 134 4129 0 0.03 12 2 3.94 135 4160 0 0.05 18 2 3.94 Shallow Line of Pits. mii 136 4190 0 0.02 8 2 3.94 • 137 4221 0 0.04 13 2 3.94 MI 138 4251 0 0.04 15 3 3.93 Shallow Line of Pits. 139 4282 0 0.03 10 2 3.93 • 140 4312 0 0.02 8 2 3.93 • 141 4343 0.04 0.04 16 2 3.94 Shallow Line Corrosion. all 142 4373 0 0.05 17 2 3.95 Shallow Line Corrosion. IPenetration Body Metal Loss Body Page 3 • PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 143 4404 0.04 0.06 21 4 3.92 Line Corrosion. 144 443 3 0 0.04 13 2 3.93 145 4463 0 0.04 15 2 3.91 Shallow Pitting. 146 4494 0 0.04 15 2 3.93 Shallow Line of Pits. 147 4524 0 0.05 18 2 3.92 Shallow Line of Pits. 148 4554 0 0.04 16 2 3.94 Shallow Line Corrosion. 149 4584 0 0.05 17 2 3.92 Shallow Line of Pits. 150 4615 0.04 0.05 20 3 3.94 Line of Pits. 151 4645 0 0.05 17 3 3.88 Shallow Line of Pits.Lt. Deposits. 152 4675 0 0.03 13 3 3.91 • 153 4706 0 0.03 13 3 3.93 • 154 4737 0 0.04 15 2 3.95 Shallow Pitting. 155 4766 0 0.03 9 1 3.95 156 4796 0 0.03 10 2 3.89 Lt. Deposits. 157 482 7 0 0.02 8 2 3.93 158 485 7 0 0.03 10 2 3.90 • 159 4888 0 0.03 10 2 3.93 • 160 4918 0 0.02 8 3 3.92 160.1 4949 0 0.02 8 1 3.92 Pup 160.2 4954 0 0 0 0 3.92 GLM 2(Latch @ 12:00) 160.3 4961 0 0.02 8 1 3.92 Pup 161 4967 0.04 0.04 15 2 3.93 Shallow Pitting. 162 4997 0 0,03 9 3 3.86 Lt. Deposits. • 163 5028 0 0.04 16 2 3.91 Shallow Line of Pits. 164 5059 0.04 0.05 20 3 3.90 Line of Pits. 165 5089 0 0.02 7 2 3.93 166 5120 0 0.03 13 2 3.94 167 5150 0 0.02 8 2 3.92 168 5180 0 0.02 8 2 3.95 169 5211 0 0.03 . 10 3 3.87 Lt. Deposits. • 170 5242 0 0.02 8 1 3.92 171 5273 0 0.02 8 3 3.91 172 5303 0 0.03 10 2 3.90 • 173 5334 0 0.05 17 3 3.92 Shallow Line of Pits. 174 5364 0 0.03 11 2 3.93 • 175 5394 0 0.05 18 2 3.93 Shallow Line of Pits. 176 542 5 0 0.02 9 1 3.94 �• 177 5456 0 0.03 10 1 3.94 178 5486 0 0.03 13 3 3.95 179 5516 0 0.02 7 1 3.91 180 5547 0 0.03 12 3 3.93 181 5574 0 0.03 10 1 3.94 • 182 5604 0 0.03 10 2 3.91 • 183 563 5 0 0.03 10 2 3.93 �• 184 566 5 0 0.02 8 1 3.92 185 5694 0 0.03 10 3 3.89 Lt. Deposits. 186 5724 0 0.03 11 2 3.92 • 187 5754 0 0.03 10 2 3.91 • 188 5785 0 0.05 18 1 3.92 Shallow Line of Pits. 189 5815 0 0.03 12 2 3.92 IPenetration Body Metal Loss Body Page 4 • • Ili PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 190 5847 0 0.03 11 1 3.92 191 5877 0 0.04 14 2 3.90 192 5906 0 0.02 8 1 3.92 • 193 5936 0 0.06 21 1 3.91 Line of Pits. NM 194 5967 0 0.04 16 3 3.91 Shallow Line of Pits. 195 5997 0 0.03 10 2 3.92 Fi 196 6028 0 0.06 22 4 3.87 Line of Pits. Lt.Deposits. 197 6058 0 0.03 10 3 3.91 198 6090 0 0.03 10 1 3.91 199 6118 0 0.04 15 3 3.93 Shallow Pitting. r 200 614 7 0 0.03 12 3 3.90 • 201 6179 0 0.03 11 3 3.91 • 202 6209 0 0.03 13 2 3.93 203 6239 0.04 0.05 19 3 3.86 Shallow Line Corrosion.Lt. Deposits. - 204 6267 0 0.04 14 2 3.93 • 205 6298 0 0.02 7 2 3.86 Lt. Deposits. 206 632 7 0 0.03 12 2 3.93 207 6357 0 0.03 10 3 3.93ill 208 6388 0 0.04 16 3 3.92 Shallow Line of Pits. 208.1 6418 0 0.02 7 1 3.92 Pup 208.2 6424 0 0 0 0 3.89 GLM 3(Latch @ 1:00) 208.3 6430 0 0.04 15 1 3.91 Pup Shallow Line of Pits. ON 209 643 7 0 0.03 13 3 3.95 • 210 646 7 0 0.03 12 3 3.92 • 211 6498 0 0.04 15 1 3.89 Shallow Line of Pits.Lt. Deposits. 212 6529 0 0.05 19 2 3.94 Shallow Line of Pits. mil 213 6559 0 0.04 14 3 3.93 liN 214 6589 0 0.04 15 3 3.91 Shallow Line of Pits. 215 6620 0 0.04 14 3 3.90 . • 216 6651 0 0.03 11 2 3.93 • 217 6681 0 0.03 12 2 3.94 1 218 6711 0 0.04 15 3 3.92 Shallow Line of Pits. 219 6742 0 0.04 15 3 3.92 Shallow Pitting. 220 6772 0 0.03 10 1 3.93 221 6803 0 0.02 7 2 3.89 Lt. Deposits. 222 683 3 0 0.03 11 2 3.92 • 223 6863 0 0.03 11 2 3.93 PI 224 6894 0 0.02 8 1 3.94 C 225 6922 0 0.03 9 3 3.89 Lt. Deposits. 226 6952 0 0.05 17 1 3.94 Shallow Line of Pits. am 227 6983 0 0.03 12 1 3.93 • 228 7013 0 0.02 8 4 3.86 Lt. Deposits. C 229 7045 0 0.03 11 1 3.93 230 7075 0 0.03 11 2 3.92 to 231 7105 0 0.03 10 2 3.93 232 7136 0 0.03 9 2 3.94 233 7167 0 0.02 7 2 3.89 Lt. Deposits. 234 719 7 0 0.02 7 2 3.92 235 722 7 0 0.04 16 2 3.93 Shallow Line of Pits. 236 7256 0 0.03 10 3 3.92 a IPenetration Body Metal Loss Body Page 5 • • PDS Report Joint Tabulation Sheet Well: 1C-13 Survey Date: July 12, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 38 ft 7,944 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 237 7286 0 0.05 18 2 3.90 Shallow Line of Pits. 238 731 7 0 0.04 16 3 3.94 Shallow Line Corrosion. 239 7346 0 0.06 22 3 3.91 Line of Pits. 240 7376 0 0.04 14 3 3.92 240.1 7406 0 0.04 13 2 3.91 Pup 240.2 741 1 0 0 0 0 3.90 GLM 4(Latch @ 6:00) 240.3 7417 0 0.03 13 2 3.91 Pup 241 7423 0 0.02 8 1 3.92 242 7453 0 0.02 8 1 3.91 ` 243 7484 0 0.03 10 1 3.92 244 7514 0 0.02 8 3 3.90 245 7545 0 0.03 10 3 3.90 246 7576 0 0.02 9 2 3.89 Lt. Deposits. l 247 7605 0 0.02 8 1 3.91 I 248 7635 0 0.02 7 2 3.92 • 249 7664 0 0.02 9 1 3.91 • 250 7695 0.04 0.05 18 3 3.88 Shallow Line of Pits.Lt. Deposits. 251 7725 0 0.03 10 1 3.92 252 7756 0 0.02 8 1 3.91 • 253 7788 0 0.03 10 2 3.94 A 254 7818 0 0.03 11 3 3.91 • 255 7849 0 0.02 7 2 3.93 • 256 7879 0 0.04 13 2 3.91 • 256.1 7909 0 0.02 7 1 3.90 Pup Lt. Deposits. 256.2 7915 0 0 0 0 3.82 GLM 5(Latch @ 3:00) 256.3 7920 0 0.05 17 2 3.90 Pup Shallow Pitting. 257 792 7 0 0.02 8 2 3.91 • IPenetration Body Metal Loss Body Page 6 • • 111111 PDS Report Cross Sections 4110 Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: C.Waldrop Cross Section for Joint 196 at depth 6,043.517 ft. Tool speed= 50 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=99% I i / Tool deviation=44° Finger=32 Penetration=0.060 in. Line of Pits 0.06 in.=22%Wall Penetration HIGH SIDE=UP • • ja.S. PDS Report Cross Sections Well: 1C-13 Survey Date: July 12,2016 Field: Kuparuk Tool Type: UW MFC 40 No.217958 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: C.Waldrop Cross Section for Joint 239 at depth 7,370.230 ft. Tool speed=49 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=98% -44\ Tool deviation=30° / ,41__., .„, ..---• ,1 .._ _ , Finger=32 Penetration=0.060 in. Line of Pits 0.06 in.=22%Wall Penetration HIGH SIDE=UP . KU P • 1C-13 COnOCOPh iHIpsi .', Well Attributes Max Angle&MD TO &Ir:k t,Ill(' Overbore APIIUWI Field Name Wen States Incl I'1 MD 159Brie 91 Act 1tKB) 4r..r.ocrtTvup,- 500292285600 KUPARUK RIVER UNIT PROD 49.47 2.489.86 8,677.0 Coa.erM NTS(ppm) Date An..oUlton End Date KH'Grd(8) Rig Release Dab SSW:NIPPLE 65 8:14/2013 Last WOE 46.91 211411998 ScAen-a- „.Actual Annotation Depth(111101 End Date Annotation EBEB ''3nd Date Last.Tag:SLM 8.555.0 8'2212011 Rev Reason'DRILL DATES.'H2S 12'2013 I4A43ER m .,, 11!' Casi • Strin•.S "' Casing Description String 0.... String ID... Top NIKB) Set Depth 11_. Set Depth(TVD)... Stang Wt__ String.-. Stang Top Tied CONDUCTOR 16 15.062 42.0 121.0 121.0 6250 H-40 WELDED Casing Desoriptian String 0... String O... Top IRKS) Set Depth It.. Set Depth(TVD).... String Wt String. String Top Tvd SURFACE 95/8 8.835 41.1 5.704.9 4,446.4 40.00 L-80 ASM-BTC 141 p Casing Desoripliitin String O__ String O._Top(*KB) Set Depth(t._. Set Depth(TVD)._ String Wt_ String... String Top Tixd PRODUCTION 7 6.276 3'S 9 8,234.9 6,345.7 26.00 L-80 ABM-BTC Caebe Oteerlpabn $0019 0... *Mop O... Top(48(0) SN Depth It... Set Dept.mem._ 81nna Wt_. String... String Top Tiled LINER 412 3.958 8..031.5 8.677.0 6.768.0 12.60 L-80 NSCT CONDUCTOR. Liner Details 42-1^.r Top DepM (TYD) Top Old Nomi... Top pate) (RK8) r) Ibw.M•a+lla+o•• COm.rrn O(in) NIPPLE.l,el0 - - _- 1 8.031.5 6.168.4 23.21 PER BAKER 80.47 PBR 8 C-2 SETTING SLEEVE 4.750 8,044.0 6,179.9 23.14 50 BUSHING BAKER 50 BUSHING 4.000 I8.04.x.5 6.181.3 23.13 HANGER BAKER!AMC HYDRAULIC LINER HANGER 3.937 8,088.4 6,220.7 22.88 NIPPLE CAMCO DB NIPPLE w/3.75"NO GO PROFILE 3.750 Tubing Strings 7.6 .41 Drwr.p bo,. Strong 0... Slang ID Top eke) Sot Depth i1_.. Set Depot 179D1._ String WI... Soon ... Stn g Top Thrd TUBING 4 t 3.958 35.6 8.1/242 U 161 7 12 60 L-80 NSCT Completion Details Top 0511.5 GA82888III- -'1 4590) Top kW Norm._ Top(axe) 111110) (') Ib.DesolpHon Comment ID lin) 35.6 35.6 -1.90 HANGER FMC GEN V HANGER 4.500 1,509.6 1,507.5 11.47 NIPPLE CAMCO BP-Si LANDING NIPPLE 3.813 !LOT 7.957.1 6.100.9 25.17 NIPPLE OTIS X NIPPLE 3.813 GAS4.101 7,994.3 8,.134.6 24.55 PBR BAKER 80.40 PER vet 58)1-22 ANCHOR SEAL ASSEMBLY 3.875 - ---1 8,6@9.2 6,148.0 23.34 PACKER BAKER FAB-1 PACKER 3.938 8.023.2 6.160.8 23.26 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.938 Perforations&Slots Shot Top(IVO) Bim(TVD) Dens Top MUM SWI(nx8)-__(V U M (Rlmi Zoom ors 481.._ Type Conn.* SURFACE. `r 8.334.0 8.350.0 6.448.4 6.463,3 C-4.1C-13 6/17/1999 4.0(PERF SWS 2118"DP 180 deg.phasing:+I- 41-5.705 90 deg.low side 8,350.0 8,365.0 6,463.3 6,477.3 C-4,1C-13 4/22/1998 4.0 IPERF SINS 2 718"OP.60.'120 phased GAS UFT. 8,365.0 8,395.0 6,477.3 6,505.3 C-4,1C-13 4/9/1998 4.0 IPERF SWS 2 7/8^DB.180 phased 6.421 8.395.0 8,415.0 6,505.3 6.523.9 C-3.C-4,1C-13 3/5/1998 4.0 IPERF SWS 2 7/8"OP,180 dog-phasing;90 rang Oriented 8.504.0 8.523 0 6.606 9 6.624.6 C.1,i(;.13 82412011 6.0(PERF OP 60 DEG PHASE rAs LIFT 7,410 --- Notes:General&Safety End Date Annotation 8+12.2010 NOTE View Schematic wi Alaska Schematic-9,0 AS LIFT ?.815 NIPPLE.7.957-- i NW.7.004 .... �1 PACKER,8000 SEAL ASSY- Ti 8:023- ;} [ 7 moo " 7 388 Mandrel Details (PERFTop Depth Top Poet E 334-8,356`22 22 ..-2222 S._ I390) WG DD Valve Latch Size TRO Run (peer. IL.. Top price. 8) 4') Pass aad eel IMI SON Type Type (i•*) Ip'er) Run Dra-.. Clam Ca 350-8,3455 --MEAT 111011116all11161116116M6111MAXT /GAS LIFT GLV T-1 0.)56 1,240.9 6/13/2005 ' &'3 ___- ® 4.951.0 :3,946.1ram ES'I AXT In GAS LIFT OV allE® 0.0 1/4/2004 5.305-8'415 - 6,421.2 4,922.1 47.23 BST AXT Ili GAS LIFT 13MY0.000 @.0 1/4/2004 IIII pE(u_ - _ 7.409.8 5.632.5 35.55 BST AXT GAS LIFT OMY ®0.000 0-0 7/25/2003 8.504.8.523 ___ " 5 7,914..9 6.062.7 25.87 BST AXT GAS LIFT DMY ®0.000 0.0 7/25/2003 _ 1 LINER- 4-032.8:077-"4, TO,8.577 • ... Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. / (~. "' ~.,/J File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other COMMENTS: Scanned by~ildred Damtha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ STATE OF ALASKA ALASKA• AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Rug Perforations r Stimulate ' ' Other '°"' Alter Casing r Pull Tubing r Perforate New Fool r Waiver f Time Extension r Change Approved R f - Operat. Shutdown r Perforate fi Re -enter Suspended Well "° 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development Exploratory r ` 198 - 011 3. Address: 6. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 " 50 - 029 - 22856 - '430 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 • 1 C - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8677 feet Plugs (measured) None true vertical 6768 feet Junk (measured) None Effective Depth measured 8611' feet Packer (measured) 8009 true vertical 6706' feet (true vertucal) 6148 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5664 9.625" 5705 4446 PRODUCTION 8197 7" 8235 6356 LINER 646 4.5" 8677 6768 Perforation depth: Measured depth: 8334' 8415', 8504' - 8523' True Vertical Depth: 6448' 6524', 6607' 6625' SEP 2�1 rt W O% & Gas Cons. r�p111SSI0n Tubing (size, grade, MD, and TVD) 4.5, L -80, 8023 MD, 6161 TVD Al 8 • ndlerAt er Packers & SSSV (type, MD, and TVD) PACKER - BAKER FAB -1 PACKER @ 8009 MD and 6148 TVD CAMCO LANDING NIPPLE @ 1510 MD and 1508 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 540 1278 2540 -- 213 Subsequent to operation 689 1258 2919 -- 243 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p° ° Service r Stratigraphic r 15. Well Status after work: Oil 67 A Gas r WDSPL E Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ f SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 91 ig I11 14BDMS SEP 14 2011 f E3 •ft Form 10 -404 Revised 10/2010 ubmit Original Only 1C-13 Well Work Summary DATE SUMMARY 7/1/11 PERFORM FCO W /SLICK DIESEL TO HRD TAG @ 8590 CTMD, INITIAL AO@ 8372 CTMD, ENCOUNTERED LIGHT TO HEAVY CRUDE IN RETURNS, WAS UNABLE TO USE D GEL SWEEPS DUE TO SLUGS OF POSSIBLE BIOZAN IN D GEL, OPEN APPROX 175' OF TUBING BELOW BOTTOM PERS, NO SIGN OF ANY SOLIDS IN RETURNS, WH SI FP, READY FOR SL, IN PROGRESS, 7/5/11 ATTEMPT TO GUAGE TBG 3.77 ", NO SUCCESS. BRUSH & FLUSH TBG TO 8505' SLM. DRIFT TBG 20' 3" DMY PERF DRIFT TO TAG @ 8493' SLM (est 8521' RKB). COMPLETE. 8/18/11 RAN 10' PERFORATING GUN (2.75" OD) AND ATTEMPT TO REACH A DEPTH OF 8524'. TAGGED SHALLOW, BOTTOM OF TOOL (PERFORATING GUN) WAS 8505' . MAKE MULTIPLE TAGS AT TD WITH SAME PICK -UP. ABORTED JOB, WELL NEEDS FCO. 8/21/11 PERFORMED CLEAN OUT TO 8575' CTMD, PUMPING GEL SWEEPS. CLEANED APROX 160 FEET BELOW BOTTOM PERF. SOME HEAVY SLUDGE IN RETURNS, NO SOLIDS SEEN. FREEZE PROTECTED TO 2500'. JOB COMPLETE. 8/22/11 TAGGED a 8555' SLM.pRIFTED TO TAG DEPTH W/ 2.875" X 10' & 3" X 10', OAL =21', NO PROBLEMS ENCOUNTER. JOB COMPLETE 8/24/11 PERFORATE 8504 -8523' WITH HSC 2.75" DP 60 DEG PHASED 6 SPF 15 GRAM MILLENIUM CHARGES. CCL TO TOP SHOT: 7.5'. CCL STOP AT 8496.5. CORRELATED TO SCHLUMBERGER CBL DATED 01- MAR -1988. �,� P : KU • 1C 13 litups WetAtiributes Max Angle & MD _ A(%1Si(a 1ri Wellbore A►WWI Feld Name ( Status Inc! V) IMO (flKB) Act Btrn (ftKB) tSA ,,„,„,,!„ - _ 500292285600 1KUPARUK RIVER UNIT PROD 49.4/ 2,489.86 8,677.0 _ Comment H25 Last Ta SLM 8 0 8122!201 ( Rev Reason: A 'Annotation End Date KB Gre (ft) b Rig Release Da -" SSSV NIPPLE Last WO � ._ 469.9 1 2/14/1998 1. _____ „Adi.....:.„,". __ g nec7c Wit,_.dw_ __ ,..,�_ A Ann taboo Depth (flKB) End Data [Annotation Last Mod . End Date g: DD TAG _& PERFS I nlnam I 9/7/2011 HANGER, 5 3z i Casing Strings Casing Description String 0... String ID .. Top (ftK8) Set Depth (f... Set Depth (ND) .. IString Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121 0 62.50 H-40 WELDED -- -� - -' Casing Description String 0... String ID ... Top (ftK8) Sat Depth (i_. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 41.1 5,704.9 4,446.4 40.00 L ABM - BTC ry Gating Description String 0... String ID ... Top (itlfB) Set Depth (( -- Set Depth (ND) String Wt... String ... String Top ThN PRODUCTION 7 6.276 37.9 8,234.9 6,355.7 26.00 L ABM - BTC Casing Description String 0... String ID . Top (kKe) Set Depth (f... Set Depth (TVD) - String Wt... String ... �.. String Top Thrd t. LINER 4 1/2 3.958 8,031 5 8,677 0 6,768.0 12.60 L -80 NSCT M s, Liner Details _ CONDUCTOR, Top Depth 42 -121 °[ '. (ND) Top Intl N omi... / Top OWE) (h (°) Item Description Comment ID go) NIPPLE, 1,510 8,031.5 6,168.4 23.21 PBR BAKER 8047 PBR & C - 2 SETTING SLEEVE 4.750 __ - _- 8,044.0 6,179.9 23.14 XO BUSHING BAKER XO BUSHING 4.000 8,045.5 6,181.3 23.13 HANGER BAKER HMC HYDRAULIC LINER HANGER 3.937 8,088.4 6,220.7 22 88 NIPPLE CAMCO DB NIPPLE mil 3.75" NO GO PROFILE 3.750 .:', Tubing Strings 'Tubing Description String 0 String ID ... Top (5168) Set Depth (1... Set Depth (D) ... String Wt... Str ng ,.. String Top Thrd ' TUBING 4 1/2 3.958 I 35.6 I N 8,024.2 I 6,161.7 12.60 I L -80 I NSCT Completion Details Top Depth __._.. GAS LIFT, (IVD) Top Inel Neal._ 2,959 Top (ftKB) ( B) (') Hnn Desalplbn Comment ID (in) _. 35.6 35.6 -1.90 HANGER FMC GEN V HANGER 4.500 g " 1,509.6 1,507.5 11.47 NIPPLE CAMCO BP-61 LANDING NIPPLE 3.813 GAS LIFT, 7,957.1 6,100.9 25.17 NIPPLE OTISX NIPPLE 3.813 lir 4,951 7,994.3 6,134.6 24.55 PBR BAKER 80-40 PBR w/ KBH -22 ANCHOR SEAL ASSEMBLY 3.875 1 8,009.2 6,148.0 23.34 PACKER - BAKER FAB -1 PACKER 3.938 8,023.2 6,160.8 23.26 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.938 G Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (NEB) Bbn (flKB) (MOM NIKE) zone Date (sh... Type Continent SURFACE, 8,334 8,350 6,448.4 6,463.3 C-4, 1C -13 6/17/1999 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; +/- 41 - 5,705 90 deg. low side 8,350 8,365 6,463.3 6,477.3 C4, 1C-13 422/1998 4.0 IPERF SWS 2 7/8" DP, 60/120 phased GAS U,4HT21 , 8,365 8,395 6,477.3 6,505.3 4/9/1998 4 0 IPERF SWS 2 7/8" DB, 180 phased 6 2' 8,395 8,415 6,505.3 6,523.9 3/5/1998 4.0 IPERF SWS 2 7/8" DP, 180 deg. phasing; 90 deg. Oriented AYIII - 8,504 8,523 6,606.9 6624.6, 8/24/2011 60, IPERF DP, 60 DEG PHASE GAS LI m -- - ' _. Notes: General & Safety___ , _ End Date Annotation 8/12/2010 NO I 6 View Schematic w/ Alaska Schemanc9 0 lit GAS ;..1: ,_ _. 5 NIPPLE, 7,957 - _ , I + PBR, 7,994 - - -- J PACKER. 8,009 SEAL ASSY. 1 8,023 -_ _ 1 11 PRODUCTION, 835 - - Mandrel Details IPERF, Top Depth Top Port '- 8334. 8350 --- - -- - -- ' - (1 Inc' OD Valve Latch Size TRO Run IPERF, -"! Stn Top (fiK81 OWE) ( °) Make Model lint Serv__ Type Type (in) (Pee Run Dab Con,. 8,35ERF, _ - 1 2,959.1 2.613.9 48.85 BST AXT 1 GAS LIFT GLV T -1 0.156 1,240.0 6/132005 8.3656495 r 2 4,951.0 3,946.1 46.47 BST AXT 1 GAS LIFT OV T -1 0.250 0.0 1/42004 IPERF, 7. 8,3958,415 . --- 3 6,421.2 4,922.147.23 BST AXT 1 GAS LIFT DMY T -1 0.000 0.01/42004 IPERF, 4 7,409.8 5,632.5 35.55 BST AXT 11 GAS LIFT DMY T -1 0.000 0.0 7/25/2003 8,5048,523 m - - ___. _____ 5 7,914.9 6,062.7 25.87 BST AX 1 1 GAS LIFT DMY T -1 0.000 0.0 7/25/2003 LINER. 8,031 -8,6]7 \ • TD, 8,6]7 - - - -- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • RECEIVED JAN 0 7 2009 Alaska Oil & Gas Cons. Commission Anchorage `~ ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a 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. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Kl ' _ ~~;~~ JAiv ~ ~~ 200 ConocoPhillips Well Integrity Supervisor • . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) __ Kuparuk Field _ _. 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 1F-09 183-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 196-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1 C-111 201-128 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 98-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 206-001 14' 6" 2.00 18" 8/27/2007 9.00 8/29/2007 1 C-21 205-034 38' 10" 4.00 18" 8/27/2007 8.60 8/29!2007 1 C-23 199-034 10' 10" 1.50 18" 8/27/2007 23.00 8/29/2007 ~"t0--- 03/05/07 Schlumberger NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 ~11\\) (;þ ~. 7001 I /-,,, {-, "." " StANNaJ MAR 3 0 2007 II d,~", /91f -0/1 Field: Kuparuk Well Job# Log Description Date Color CD BL 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1 R-08 11628971 INJECTION PROFILE 02/15/07 1 1 F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17/07 1 1F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19/07 1 1C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 35-26 11638813 INJECTION PROFILE 01/21/07 1 1C-121 11665391 INJECTION PROFILE 02/05/07 1 1J-180 11665390 US IT 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1J-118 11665392 USIT 02/22/07 1 1 D-11 11665393 INJECTION PROFILE 02/24107 1 2M-OS 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1 F-13 11665401 INJECTION PROFILE 03/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'15 . . 198-011-0 KUPARUK RIV UNIT 1C-13 50- 029-22856-00 ARCO MD 08677 ×' TVD'06768 o~~mpletionDate: -2/13/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8269 ~ SPERRY MPT/SLD/GR/EWR4/CNP OH 3/4/98 3/4/98 L CBL 7900-8591 ' : CH 5 3/6/98 3/13/98 L CNTG r41qAL 8150-8591 ~'' ~' CH 5 8/4/98 8/6/98 L DSSI ~2 7670-8632 OH 3/19/98 3/25/98 L 'DSSI-DELTAT ~<~AL 7670-8632 OH 3/19/98 3/25/98 L DSSI-SSTVD ~ 7670-8632 OH 3/19/98 3/25/98 R MWD SRVY -64~Y 0-8677 OH 3/8/98 3/11/98 T 8347 ~' SCHLUM DSI OH 3/19/98 3/25/98 T 8590 ~'~ SCHLUM CNTG CH 8/4/98 8/6/98 Daily Well ups ~.?- ~ ~ Are Dry Ditch Samples Required? yes ~___~, ,And Received.a--yes-.qtt~ Was the well cored? yes ~~ Analysis Description Received.~.~,&~aa.~ Sample~S~T~g'~ Thursday, February 03, 2000 Page 1 of 1 8/4/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrle NO. 11400 Company: , Alaska Oil & Gas Cons Corem Attn: ~ Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job it Log Description Date BL RF Sepia US Tape , , :!C-!3 ~-~'-O% [ :~';~'~qO 98356 CNTG 980301 I I 1 ,' , SIGNED: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 27, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 C- 13 (Permit No. 98-11) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1 C-13. If there are any questions, please call 265-6890. Sincerely, G. C. Alvord Drilling Engineer Kuparuk Drill Site Development GCA/skad ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~1 GAS E~ SUSPENDED E~] ABANDONED ~---1SERVICE ~] . ., 2 Name of Operator 7 Pe~it Number ]~.}~?~ U~ ~ (~'~'~ ~'~ ARCO ~aska, Inc 98-11 3 Addr~ 8 APl Number P.O. Box 100360, ~chorage, AK 99510-0360 .,. 50-029-22856 4 Location of well at su~ace ~~~ 9 Unit or Lease Name 2258' FNL, 2555' ~L, Sec. 1, T11 N, R10E, UM [ ............. KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease D~ignation and Sedal No. Kuparuk River Oil Pool Rig RKB 41', Pad 61'] ADL 25649 ALK 467 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or ~and. ~ 15 Water Depth, if offshore 16 No. of Completions 27-Jan-98 08-Feb-98 13-Feb-98] NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ~20 Depth where SSSV set ~ 21 Thickness of pe~afrost 8677' MD & 6768' ~D 8611' MD & 6706' ~D YES ~ NO ~ N/~ feet MD 1465' APPROX 22 Type Electdc or ~her Logs Run G~/Res, Dipole Sonic, NMR, CBT/GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD I CASING SIZE; WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5~ H-40 SURF. 121' 24' 9 cu. Yards High Early 9.625' 40.0~ L-80 SURF. 5705' 12.25' 612 sx AS III LW, 600 sx Class G, 60 sx AS I 7" 26.0~ L-80 SURF· 8235' 8.5' 135 sx Class G 4.5' 12.6~ L-80 8031' 8677' 6.125' 116 sx Class G 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size ~d number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 8009' 8009' 8395'-8415' MD 6505'-6524' ~D 8365'-8395' MD 6477'-6505' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8350'-8365' MD 6463'-6477' ~D DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf 27 PRODUCTION TEST ~DI~IklAI Date First Production~9/ga Method of Operation (Flo~ng,Fiowing~ "~' e~c.) U i ~ I ~ t i ~ R L Date of Test Hours T~ted PRODUCTION FOI OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE ~ GAS-OIL RATIO ~24/98 12.00 TEST PERIOI: 1214 lO3O 0 176~ 969 Flow Tubing Casing Pr~sure CALCU~TED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) Pr~. 160 -]5 24-HOUR RATE: 22~ 2~87 0 23.5° 28 CORE DATA B~ef d~cription of lithology, porosity, fractures, apparent dips and pr~ence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8332' 6446' Base Kuparuk C 8522' 6624' Top Kuparuk A 8677' 6768' ..... ' "" {'; 'tq c,, -,'~ Base Kuparuk A 8677' 6768' Total pump volumes for this event: Category 1. 7090 Category 2. 100 Category 3. 0 Total: 7190 Total to Date: 7190 Annulus left open - freeze protected with diesel. 31. LIST OF ATI-ACHMENTS Summary of Daily Ddlling Reports, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / - ' Prepared~by Narr~Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/1/98 ARCO ALASKA INC. ~ ~ .... Page: 1 WELL SUMMARY REPORT WELL:lC-13 WELL_ID: AK9109 TYPE: AFC: AK9109 7M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/27/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22856-00 01/26/98 (D1) TD: 121'(121) SUPV:GRW 01/27/98 (D2) TD: 273'(152) SUPV:GRW 01/28/98 (D3) TD: 2572' (2299) SUPV:GRW 01/29/98 (D4) TD: 5140' (2568) SUPV:GRW 01/30/98 (D5) TD: 5720' (580) SUPV:GRW 01/31/98 (D6) TD: 5720'( SUPV:GRW 0) 02/01/98 (D7) TD: 5720'( SUPV:GRW 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MIXING MUD, LOADING SHED W/DP Hold safety meeting. Move rig from iD pad to lC pad. Accept rig @ 2030 hrs. 1/26/98. MW: 8.8 VISC: 145 PV/YP: 14/42 APIWL: 7.6 DRILLING @ 950' N/U diverter and function test. Drill from 121' to 273' MW: 10.4 VISC: 143 PV/YP: 29/42 APIWL: 8.2 DRILLING @ 3380' Drill from 273' to 1175'. Circ and condition gas cut mud. Drill from 1175' to 2572'. Circ and condition gas cut mud. Raise mud weight to 10.4 ppg. MW: 10.4 VISC: 160 PV/YP: 37/51 APIWL: 6.0 POOH FOR BIT ~2 CBU, no gas on bottoms up. Drill from 2572' to 3042'. Had gas show at 2860' Drill from 3042' to 4069'. Had gas shows at 3330' Drill from 4069' to 5140' MW: 10.4 VISC: 195 PV/YP: 42/51 APIWL: 5.0 R/U CASERS Drill from 5140' to 5214' POOH. Had several tight spots. Drill from 5214' to 5720' MW: 10.4 VISC: 126 PV/YP: 36/40 APIWL: 6.4 RUNNING 1" POOH. Tight from 1741' to 1550'. Worked thru tight spots and freed up. Hold safety meeting. Run 9-5/8" casing to 5705'. Pump first stage cement. MW: 10.1 VISC: 86 PV/YP: 30/ 0 APIWL: 8.2 N/U BOPE Clean out diverter stack. Try to run 1" tubing w/o success. Run 1" tubing to 248' and plugged tubing. Pull 1". Run back to 248' and circ clean. Wash to 290'. Attempt to circ down casing through stage tool to get injection rate, had circulation up 16" x 9-5/8" annulus. N/U diverter stack. Pump second stage cement. Date: 4/1/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/02/98 (D8) TD: 5720' ( SUPV: GRW 0) 02/03/98 (D9) TD: 6210' (490) SUPV:DEB 02/04/98 (D10) TD: 8248' (2038) SUPV: DEB 02/O5/98 (Dll) TD: 8248' ( 0) SUPV:DEB 02/06/98 (D12) TD: 8248' ( 0) SUPV:DEB 02/07/98 (D13) Tm: 8336'( 88) SUPV:DEB 02/08/98 (D14) TD: 8667' (331) SUPV:DEB 02/09/98 (D15) TD: 8667'( 0) SUPV:FH MW: 9.0 VISC: 97 PV/YP: 9/ 3 APIWL: 36.0 DRILLING CEMENT N/D diverter. N/U BOPE and test to 300/5000 psi. Drill stage collar @ 2114' MW: 8.6 VISC: 34 PV/YP: 4/ 4 APIWL: 12.8 DRILLING AT 7050' Tag cement @ 5358' Drill out cement & float equipment & drill 20' of new hole to 5740' Perform formation leak-off test. Leaked off at 13.4 ppg EMW. Drill from 5740' to 6210' MD. MW: 9.2 VISC: 39 PV/YP: 10/ 8 APIWL: 9.2 POH FOR 7" CASING Drill from 6210' to 8248' MD. Perform open hole leak-off test. Leaked off at 11.8 ppg EMW. MW: 9.1 VISC: 40 PV/YP: 10/ 6 APIWL: 7.4 NU FLOW NIPPLE Run 7" casing to 8235' Pump 7" casing. MW: 11.4 VISC: 44 PV/YP: 20/13 APIWL: 6.6 CIRCULATE & CONDITION 11.4 PPG ND BOP stack & riser. NU tubing head. Test packoff to 5000 psi, OK. NU BOP stack. Test BOPE. MW: 12.5 VISC: 49 PV/YP: 29/22 APIWL: 3.8 DRILLING AT 8382' MD Tag cement at 8147' Drill cement, drill float collar at 8162', drill cement to 8225' Drill cement & drill out shoe at 8242' Clean out rathole & drill 20' new hole to 8268' MD. Test formation to 16.0 ppg EMW; no leak-off. Drill 20' more hole to 8288' MD. Re-test formation to 16.0 ppg, no leak-off. Drill to 8336' MD. Gas and oil cut to 10 ppg. Very slow flow. Shut-in well. MW: 13.0 VISC: 50 PV/YP: 31/24 APIWL: 3.6 CBU & MONITOR WELL Weight up to 12.7 ppg. Monitor well with 12.5 ppg around, well dead. Drill from 8336' to 8382' MD. Thaw out & drain water from air lines on top drive. (Froze up because top drive was above wind walls while weighting up). Drill to 8477' MD. Gas cut to 11.9 ppg. Well flowing a small trickle. Drill to 8677' MD. Connection gas at bottoms up from connection at 8477' cut mud to 9.8 ppg, still 12.7 ppg in pressure balance. MW: 13.3 VISC: 51 PV/YP: 34/20 APIWL: 3.6 POOH W/NUMAR LOG WITH SWS Circ & rotate back to bottom for MAD pass from 8413' to 8677' Circ bottoms up, mud weight cut to 12.5 ppg. Monitor well, slight flow. Raise mud weight to 13.3 ppg. Run GR, Date: 4/1/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 Dipole sonic. 02/10/98 (D16) TD: 8667' ( 0) SUPV:FH MW: 13.5 VISC: 53 PV/YP: 33/20 APIWL: 3.4 POOH TO RUN LINER Run Numar log. Freeze protect annulus. CBU, gas cut mud to 12.5. Monitor well, flowing slightly. Circ and condition mud, gas cut to 12.6 ppg. Monitor well, flowing small amount. Circ and condition mud, oil and gas to surface. Raise mud weight to 13.7 ppg. 02/11/98 (D17) TD: 8677'( 10) SUPV:FH MW: 13.7 VISC: 54 PV/YP: 30/23 L/D 6.125" BHA FROM DERRICK Run 4.5" liner. Pump cement in liner. APIWL: 3.4 02/12/98 (D18) TD: 8677' ( 0) SUPV:FH MW: 13.7 VISC: 58 PV/YP: 32/28 APIWL: 3.5 DISPLACE WELL WITH WATER RIH w/7" casing scraper and stinger to liner top @ 8032' Circ gas & oil on bottoms up. Monitor well. No gas or oil. RIH with packer and set ~ 8021' 02/13/98 (D19) TD: 8677' ( 0) SUPV:FH MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 INSTALL DIVERTER Set packer. Test 4.5" liner to 3500 psi. Test 7" casing to 3500 psi. Displace well w/seawater. Hold safety meeting. Run 4.5" tubing. Freeze protect well w/diesel. 02/14/98 (D20) TD: 8677' ( 0) SUPV:FH MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED @ 1400 HRS. 2/14 ND BOPE. Rig released @ 1400 hrs. 2/14/98. APIWL: 0.0 End of WellSummary for Well:AK9109 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1C-13(W4-6)) WELL JOB SCOPE JOB NUMBER 1 C-13 PERFORATE, PERF SUPPORT 0409982105.7 DATE DAILY WORK UNIT NUMBER 04/09/98 PERFORATE C-4 SANDS DAY OPERATION COMPLETE SUCCESSFUL I YES YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 1500 PSI 1175 PSI 175 PSI DAILY SUMMARY KEY PERSON BARTZ SUPERVISOR JONES Final Inner Ann I Initial Outer Ann Final Outer Ann 175 PSII 500 PSI 500 PSI SWS PERFORATED C-4 SANDS FROM 8365' TO 8395' WLM USING 2 7/8" DP 4 SPF. DONE WITH 500# UNDERBALANCE. I TIME LOG ENTRY 12:00 SWS (BARTZ & CREW) MIRU, SECURE RADIO SILENCE, HELD TGSM. 13:45 MU GUN, PT LUBRICATOR TO 3000#. STATIC TBG PRESS = 1500#, BLED OFF GAS TO 1000#. 14:15 RIH W/20' 2 7/8" DP 4 SPF, 180 DEG PHASED, 90 DEG ORIENT. CORR TO CBL LOG 3-1-98 & PERFED FROM 8375' TO 8395'. TP INCREASED 50# TO 1050#. POH & LD GUN, ALL SHOTS FIRED. 17:18 MU GUN, PT LUBRICATOR TO 3000#. BLED TP TO 1000#. RIH W/10' 2 7/8" DP 4 SPF AS ABOVE. CORR & PERFED FROM 8365' TO 8375'. POH & LD GUN, ALL SHOTS FIRED. 19:45 RIG DOWN & RELEASE SWS RIG & CREW. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1C-13(W4-6)) WELL JOB SCOPE JOB NUMBER lC-13 FRAC, FRAC SUPPORT 0323980811.5 DATE DAILY WORK UNIT NUMBER 04/02/98 "C" SAND ROPE DAY OPERATION COMPLETE I SUCCESSFUL I YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 500 PSII 3250 PSII 0 PSI DAILY SUMMARY KEY PERSON DS-GALLEGOS SUPERVISOR CHANEY Final Inner Ann Initial Outer Ann I Final Outer Ann 500 PSI 0 PSII 0 PSI "C" SAND ROPE COMPLETED. PLUG SHEARED @ 8500 PSI AND DROPPED TO 3500 PSI. USED 300 MSCF OF N2 IN WELLBORE. TIME LOG ENTRY 13:00 S/LINE IN PROGRESS. DISPLACED 120 BBLS OF DIESEL DOWN THE 7" AND TOOK RETURNS UP THE TBG. 14:30 15:30 RU DOWELL N2 UNIT. HELD SAFETY MEETING W/ENTIRE GROUP (15 PEOPLE ON LOCATION). BEGIN DISPLACING TBG W/N2 @ 4000 SCFM. TAKING RETURNS UP THE 7" CSG. USED 100 MSCF OF N2 FOR DISPLACEMENT. 16:00 S/D DISPLACEMENT AND STOOD-BY FOR HES S/LINE TO FIX TOOL PROBLEM. 16:15 RESUMED OPERATION DISPLACING TBG W/N2 AND TAKING RETURNS UP THE BACKSIDE. 17:00 S/LINE OOH AND DV SET PER PROCEDURE. 17:15 PT'D 7" CSG TO 1000 PSI TO CONFIRM DV IS SET AND HOLDING. PT GOOD AND DEPRESSURED THE 7" BACK TO 500 PSI. 17:30 STOOD-BY FOR S/LINE TO SET FRAC SLEEVE. 18:00 RU TREESAVER AND ASSOCIATED N2 EQUIP. 19:00 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSi. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9400 PSI. 19:30 STARTED PUMPING N2 RAISED WHTP 8500 PSI AND SHEARED DISK. WHTP DROPPED FROM 8500 PSI DOWN TO 3500 PSI IN 20 MINS. USED 200 MSCF OF N2. 20:45 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 21:15 21:45 REMOVED TREESAVER (ALL CUPS RETURNED). PJD COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1C-13(W4-6)) KEY PERSON SWS-ELMORE SUPERVISOR SCHUROSKY Final Inner Ann I I 2OO PSI Initial Outer Ann I I 0 PSI Final Outer Ann 0 PSI WELL JOB SCOPE JOB NUMBER 1 C-13 PERFORATE, PERF SUPPORT 0223981859.2 DATE DAILY WORK UNIT NUMBER 03/05/98 PERFORATE 8395' TO 8415' DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES InitiaITbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 750 PSII 0 PSI DAILY SUMMARY PERFORATE WITH 20' HC 4SPF DEEP PEN. GUN FROM 8395' TO 8415' TIME LOG ENTRY 14:00 MIRU SWS, APC PUMP, HOLD TGSM,PERF. SAFETY 15:00 MAKE UP GUN AND TOOLS 15:30 PT LUB & STACK TO 3000#. OPEN WELL AND PT TBG. TO 2000# AFTER 15 MIN. TBG. BLEED TO 1800#. PUMPED UP ONCE MORE TO 2000# AND AGAIN TBG. BLEED TO 1800#. 16:00 RIH WITH 20' 2 7/8 HC GUN 4SPF 180 DEG PHASE. 90 DEG +- ORENT., CCL, AND HEAD, TOTAL LENGTH 31' 17:45 PT 7" ANN TO 1000# FOR 15 MIN HELD GOOD. TIE IN TO GR/CCL CBT LOG DATED 3/1/98 FOR DEPTH CONTROL. 18:00 SHOOT GUNWITH 700 PSI ON TBG.WITH GUN AT 8395' TO 8415' - GOOD INDICATION AT SURFACE GUN FIRED 18:30 POOH 19:00 AT SURFACE, CHECK GUN, ALL SHOTS FIRED RDMO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1C-13(W4-6)) WELL JOB SCOPE 1C-13 PERFORATE, PERF SUPPORT DATE O3/O 1/98 DAY 1 DALLY WORK PERFORATE, PERF SUPPORT OPERATION COMPLETE ISUCCESSFUL IKEYPERSON YES YES SWS-DECKERT Initial Tbg Press 0 PSI DAILY SUMMARY JOB NUMBER 0223981859.2 UNIT NUMBER SUPERVISOR BLACK 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI IRAN CBT FROM 8598' - 7900' ELM (APPEARS TO BE GOOD CEMENT FROM TOP TO BOTTOM). RAN 3 PASSES CNL FROM 8598'- 8150' ELM. TIME LOG ENTRY 10:00 MIRU SWS (DECKERT & CREW). TGSM & JOB OVERVIEW. MU 3.4" TOOL ASSEMBLY (CNL/GR) TL-28'. PT BOPE TO 3000 PSI. 11:00 RIH & TAGGED BOTTOM @ 8598' ELM. TIE IN WITH 2/9/98 SWS DIPOLE SHEAR SONIC IMAGER. LOG 3 CNL PASSES FROM 8598'- 8150' ELM. POOH FOR CBT RUN. 15:00 15:30 AT SURFACE. MU 3.4" TOOL ASSEMBLY (CBT/GR/CCL) TL-44'. PT BOPE TO 3000 PSI. RIH, TIE IN & LOG FROM 8598 - 7900' ELM. APPEARS TO HAVE GOOD CEMENT TO ABOVE LINER TOP PACKER. POOH. 18:30 AT SURFACE. BEGIN RD. 19:30 RD COMPLETE. SECURE WELL & LEAVE LOCATION. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, iNC. KRU \ 1C-i3 500292285600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 8/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM80108 KELLY BUSHING ELEV. = 101.90 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. · 00 .00 -101.90 0 0 N .00 E .00 .00N 121.00 121.00 19.10 0 0 N .00 E .00 .00N 191,18 191.17 89.27 1 33 S 82.19 E 2.22 .13S 294.08 294.05 192.15 0 30 N 60.75 E 1.16 .10S 462.22 462.18 360.28 0 22 N 42.17 W .42 .68N .00E .00 .00E .00 .95E .20 2.73E .84 3.01E 1.67 643.68 643.64 541.74 0 25 N 31.70 W .05 734.23 734.18 632.28 0 40 N 34.89 W .27 824.17 824.12 722.22 0 34 N 36.01 W .10 1004.85 1004.77 902.87 1 6 N 29.05 W .30 1188.28 1188.17 1086.27 1 1 N 26.71 W .05 1.71N 2.25E 2.37 2.43N 1.77E 2.89 3.23N 1.20E 3.45 5.50N .19W 5.11 8.51N 1.78W 7.40 1280.73 1280.58 1178.68 2 6 N 26.67 W 1.18 1373.33 1372.94 1271.04 5 52 N 18.77 W 4.09 1468.36 1467.09 1365.19 9 37 N 7.90 W 4.22 1562.41 1559.18 1457.28 13 45 N 6.95 W 4.40 1655.32 1648.58 1546.68 17 46 N .88 W 4.67 10.77N 2.92W 9.13 16.78N 5.21W 14.01 29.25N 7.86W 24.83 48.14N 10.30W 41.77 73.28N 11.85W 64.89 1748.82 1736.87 1634.97 20 40 N 6.11 E 3.95 1841.77 1822.75 1720.85 24 15 N 7.44 E 3.90 1934.80 1905.54 1803.64 29 55 N 9.68 E 6.19 2027.01 1982.96 1881.06 35 48 N 13.08 E 6.68 2121.41 2056.83 1954.93 41 10 N 16.19 E 6.04 103.97N 139.23N 181.09N 230.09N 286.88N 10.31W 94.27 6.09W 128.86 .29E 170.40 10.27E 219.87 25.20E 278.35 2213.56 2123.74 2021.84 45 40 N 17.77 E 5.03 2303.82 2185.20 2083.30 48 29 N 18.81 E 3.23 2489.87 2307.30 2205.40 49 28 N 20.31 E .80 2677.77 2429.62 2327.72 49 17 N 22.04 E .70 2961.54 2615.51 2513.61 48 50 N 21.23 E .27 347.43N 43.73E 341.59 410.18N 64.48E 407.66 542.43N 111.48E 548.02 675.42N 163.00E 690.60 874.72N 242.05E 904.90 3242.65 2802.14 2700.24 47 57 N 20.64 E .36 1071.04N 317.16E 1115.07 3522.09 2991.24 2889.34 46 52 N 20.60 E .39 1263.58N 389.61E 1320.77 3803.28 3182.45 3080.55 47 26 N 21.44 E .30 1456.02N 463.57E 1526.89 4170.21 3426.32 3324.42 49 14 N 21.79 E .50 1710.84N 564.55E 1800.86 4451.65 3612.58 3510.68 47 52 N 21.60 E .49 1906.86N 642.54E 2011.72 4733.28 3800.47 3698.57 48 25 N 22.79 E .37 2101.08N 721.79E 2221.32 5012.05 3988.06 3886.16 46 59 N 22.71 E .51 2291.23N 801.53E 2427.25 5132.73 4069.58 3967.68 48 0 N 22.60 E .85 2373.34N 835.80E 2516.11 5291.49 4175.44 4073.54 48 20 N 22.82 E .24 2482.48N 881.47E 2634.28 5478.21 4298.16 4196.26 49 28 N 21.67 E .76 2612.72N 934.73E 2774.88 ORIGINAL o · . SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA., iNC. KRU k 1C-13 500292285600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 8/98 DATE OF SURVEY: 020898 MWD SURVEY JOB NUMBER: AKMM80108 KELLY BUSHING ELEV. = 101.90 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5635.19 4400.57 4298.67 49 4 N 22.35 E .41 2723.02N 979.31E 2893.76 5952.30 4608.93 4507.03 48 46 N 22.88 E .16 2943.69N 1071.23E 3132.54 6229.87 4793.00 4691.10 48 9 N 22.70 E .23 3135.22N 1151.71E 3340.03 6512.90 4984.30 4882.40 46 47 N 22.04 E .51 3328.08N 1231.10E 3548.38 6791.17 5177.05 5075.15 45 31 N 21.83 E .46 3514.23N 1306.06E 3748.93 7070.35 5375.46 5273.56 43 53 N 20.91 E .63 3697.08N 1377.64E 3945.23 7163.35 5443.24 5341.34 42 31 N 20.58 E 1.49 3756.62N 1400.19E 4008.89 7257.10 5513.11 5411.21 41 5 N 21.28 E 1.59 3814.99N 1422.51E 4071.37 7349.77 5584.53 5482.63 38 3 N 21.99 E 3.32 3869.87N 1444.27E 4130.38 7444.35 5660.48 5558.58 35 4 N 21.52 E 3.18 3922.20N 1465.16E 4186.69 7535.42 5735.59 5633.69 33 48 N 21.33 E 1.39 3970.14N 1483.97E 4238.17 7630.69 5815.06 5713.16 33 7 N 20.82 E .77 4019.16N 1502.86E 4290.70 7723.18 5893.59 5791.69 30 36 N 20.63 E 2.74 4064.82N 1520.14E 4339.51 7818.09 5976.30 5874.40 28 6 N 20.54 E 2.63 4108.36N 1536.49E 4386.01 7912.12 6060.06 5958.16 25 55 N 19.69 E 2.35 4148.44N 1551.19E 4428.71 8006.42 6145.42 6043.52 24 21 N 19.28 E 1.68 4186.20N 1564.55E 4468.76 8099.63 6230.84 6128.94 22 48 N 19.66 E 1.66 4221.35N 1576.97E 4506.04 8191.31 6315.51 6213.61 22 16 N 19.89 E .60 4254.42N 1588.86E 4541.18 8329.86 6444.30 6342.40 20 59 N 25.46 E 1.75 4301.51N 1608.46E 4592.13 8424.63 6532.71 6430.81 21 13 N 24.66 E .40 4332.43N 1622.92E 4626.12 8518.80 6620.45 6518.55 21 22 N 23.84 E .35 4363.62N 1636.97E 4660.23 8623.33 6717.78 6615.88 21 23 N 23.63 E .07 4398.50N 1652.31E 4698.25 8677.00 6767.76 6665.86 21 23 N 23.63 E .00 4416.44N 1660.15E 4717.78 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4718.16 FEET AT NORTH 20 DEG. 36 MIN. EAST AT MD = 8677 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 19.88 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,677.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. KRU \ lC-13 500292285600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 8/98 DATE OF SURVEY: 020898 JOB NUMBER: AKMM80108 KELLY BUSHING ELEV. = 101.90 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -101.90 1000.00 999.93 898.03 2000.00 1960.82 1858.92 3000.00 2640.81 2538.91 4000.00 3315.19 3213.29 .00 N .00 E .00 5.42 N .14 W .07 .07 215.00 N 6.89 E 39.18 39.10 901.71 N 252.54 E 359.19 320.01 1591.12 N 516.69 E 684.81 325.62 5000.00 3979.84 3877.94 6000.00 4640.37 4538.47 7000.00 5324.76 5222.86 8000.00 6139.57 6037.67 8677.00 6767.76 6665.86 2283.10 N 798.12 E 2976.74 N 1085.18 E 3651.52 N 1360.23 E 4183.70 N 1563.68 E 4416.44 N 1660.15 E 1020.16 335.36 1359.63 339.47 1675.24 315.61 1860.43 185.19 1909.24 48.81 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, iNC. KRU \ 1C-13 500292285600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 8/98 DATE OF SURVEY: 020898 JOB NUMBER: AKMM80108 KELLY BUSHING ELEV. = 101.90 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -101.90 101.90 101.90 .00 201.92 201.90 100.00 301.93 301.90 200.00 401.94 401.90 300.00 .00 N .00 E .00 N .00 E .17 S 1.24 E .06 S 2.79 E .39 N 3.28 E .00 .00 .00 .02 .02 .03 .02 .04 .00 501.94 501.90 400.00 601.94 601.90 500.00 701.95 701.90 600.00 801.95 801.90 700.00 901.96 901.90 800.00 .88 N 2.84 E 1.44 N 2.42 E 2.12 N 1.98 E 3.05 N 1.33 E 3.87 N .74 E .04 .00 .04 .00 .05 .00 .05 .01 .06 .01 1001.97 1001.90 900.00 1101.99 1101.90 1000.00 1202.01 1201.90 1100.00 1302.07 1301.90 1200.00 1402.47 1401.90 1300.00 5.45 N .16 W 7.14 N 1.09 W 8.73 N 1.89 W 11.64 N 3.31 W 19.92 N 6.12 W .07 .02 .09 .02 .11 .02 .17 .06 .57 .40 1503.75 1501.90 1400.00 1606.59 1601.90 1500.00 1711.59 1701.90 1600.00 1818.98 1801.90 1700.00 1930.63 1901.90 1800.00 35.60 N 8.72 W 1.85 59.32 N 11.30 W 4.69 91.26 N 11.38 W 9.69 130.10 N 7.26 W 17.08 179.09 N .04 W 28.73 1.28 2.84 5.01 7.38 11 66 2050.60 2001.90 1900.00 2182.73 2101.90 2000.00 2329.02 2201.90 2100.00 2481.56 2301.90 2200.00 2635.26 2401.90 2300.00 243.76 N 13.58 E 48 326.68 N 37.18 E 80 428.05 N 70.57 E 127 536.51 N 109.29 E 179 645.55 N 150.90 E 233 .70 .83 .12 .66 .36 19 96 32.13 46 29 52.54 53 70 2788.61 2501.90 2400.00 2940.86 2601.90 2500.00 3092.83 2701.90 2600.00 3242.30 2801.90 2700.00 3391.39 2901.90 2800.00 753.31 N 194.53 E 286 860.20 N 236.41 E 338 966.87 N 277.85 E 390 1070.80 N 317.07 E 440 1174.28 N 356.05 E 489 .71 .96 .93 .40 .49 53 35 52.25 51 97 49.47 49.10 3537.68 3001.90 2900.00 3684.19 3101.90 3000.00 3832.04 3201.90 3100.00 3979.89 3301.90 3200.00 1274.23 N 393.62 E 535.78 46.29 1374.37 N 431.50 E 582.29 46.50 1475.73 N 471.31 E 630.14 47.85 1577.10 N 511.12 E 677.99 47.85 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KRU \ iC-13 500292285600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 8/98 DATE OF SURVEY: 020898 JOB NUMBER: AKMM80108 KELLY BUSHING ELEV. = 101.90 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4132.80 3401.90 3300.00 1684.53 N 554.03 E 730.90 52.92 4285.97 3501.90 3400.00 1792.26 N 597.10 E 784.07 53.17 4435.73 3601.90 3500.00 1895.88 N 638.19 E 833.83 49.76 4584.85 3701.90 3600.00 1998.72 N 678.94 E 882.95 49.12 4735.43 3801.90 3700.00 2102.57 N 722.41 E 933.53 50.58 4885.75 3901.90 3800.00 2206.03 N 765.87 E 983.85 50.31 5032.35 4001.90 3900.00 2304.92 N 807.26 E 1030.45 46.60 5181.04 4101.90 4000.00 2406.48 N 849.59 E 1079.14 48.69 5331.30 4201.90 4100.00 2509.90 N 893.01 E 1129.40 50.26 5483.97 4301.90 4200.00 2616.79 N 936.35 E 1182.07 52.67 5637.21 4401.90 4300.00 2724.43 N 979.89 E 1235.31 53.24 5789.87 4501.90 4400.00 2831.10 N 1023.77 E 1287.97 52.65 5941.63 4601.90 4500.00 2936.30 N 1068.12 E 1339.73 51.77 6093.29 4701.90 4600.00 3041.34 N 1112.43 E 1391.39 51.65 6243.22 4801.90 4700.00 3144.40 N 1155.55 E 1441.32 49.93 6392.55 4901.90 4800.00 3246.77 N 1198.18 E 1490.65 49.33 6538.60 5001.90 4900.00 3345.44 N 1238.13 E 1536.70 46.05 6683.91 5101.90 5000.00 3443.19 N 1277.61 E 1582.01 45.31 6826.63 5201.90 5100.00 3537.72 N 1315.47 E 1624.73 42.72 6968.28 5301.90 5200.00 3630.98 N 1352.38 E 1666.38 41.65 7107.02 5401.90 5300.00 3720.81 N 1386.70 E 1705.12 38.73 7242.22 5501.90 5400.00 3805.88 N 1418.96 E 1740.32 35.20 7371.71 5601.90 5500.00 3882.30 N 1449.27 E 1769.81 29.49 7494.84 5701.90 5600.00 3949.06 N 1475.73 E 1792.94 23.13 7614.98 5801.90 5700.00 4011.14 N 1499.81 E 1813.08 20.14 7732.84 5901.90 5800.00 4069.42 N 1521.87 E 1830.94 17.86 7847.11 6001.90 5900.00 4121.16 N 1541.29 E 1845.21 14.28 7958.64 6101.90 6000.00 4167.57 N 1558.03 E 1856.74 11.52 8068.24 6201.90 6100.00 4209.89 N 1572.88 E 1866.34 9.60 8176.60 6301.90 6200.00 4249.18 N 1586.97 E 1874.70 8.36 8284.45 6401.90 6300.00 4286.83 N 1601.47 E 1882.55 7.85 8391.58 6501.90 6400.00 4321.56 N 1617.93 E 1889.68 7.13 8498.89 6601.90 6500.00 4356.98 N 1634.03 E 1896.99 7.31 8606.27 6701.90 6600.00 4392.80 N 1649.81 E 1904.37 7.39 8677.00 6767.75 6665.85 4416.44 N 1660.15 E 1909.25 4.87 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 3/19/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11938 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape SIGNED: . DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 3/6/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11896 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk (Reservoir Analysis Logs) RF Sepia Floppy Disk lc-:t3 (:~' O[ ~ ~ ]~o[~) LOC G~/CCL-CS? 9S0301 I 1 2S-31 q~'l'5~ (Za~ ~-~AT. UA?ZO, ~8o~-o? I 1 .... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 F! I I--I--I IM CS SEFI~JICE S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas COnservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage,....Alaska. 99501 ~'~/~.. ~ --~(.,., ._ ~?/~ ' / i RE: MWD Formation Evaluation Logs 1C-13, AK-MM-80108 March 11, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1C-13: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22856-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22856-00 2" x 5" MD Neutron & Density Logs: 50-029-22856-00 2" x 5" TVD Neutron & Density Logs' 50-029-22856-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 3/6/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11896 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk ~.c-~.3 q~' (~t [ ~ Bom ~x~ (:m/CC~-CB? 98030~. I 1 ~-3:[ qh ' I'._.%'~ ~ SW~T~?'ro~ 980207 I 1 3G-08 (~ O' 0 (~ ~- PZ~)DOCT'rObl' g~OF'rT.~ W/(;~-~ 980228 I 1 _. i SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ,. MWD Forrdatibn Evaluation Logs 1C-13, March 4, 1998 AK-MM-80108 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22856-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO: David Joh~n, Chairman.,,,~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 2, 1998 THRU: Blair Wondzell,~ FILE NO: P. I. Supervisor ~3 ,,1_ FROM: John Spauldin~'~~ SUBJECT: Petroleum Ins aaxIbbef, doc Confidential: Yes , No X BOPE Test, Parker 245 ARCO / KRU / 1 C-13 Kuparuk River Field PTD 98-11 Monday February 2, 1998: I traveled to ARCO's Kuparuk River Field to witness the BOPE Test on Parker rig 245. The AOGCC BOPE Test Report is attached for reference. Valve number 11 failed on the choke manifold, it was repaired and testing was continued. All other portions of the rig were found to be excellent shape. Summary: I witnessed the successful BOPE test on Parker 245, 4 hour test time, 0 failures. Attachments: aaxlbbef, xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Rig No. Operator: ARCO Well Name: 1C-13 Casing Size: 9 5/8" Set @ 5,705'md Test: Initia X Weekly Other DATE: 2/2/98 245 PTD # 98-11 Rig Ph.# 659-7670 Rep.: Guy Whitlock Rig Rep.: Fred Herbert Location: Sec. 12 T. 11N R. IOE Meridian Urniat Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok Well Sign ok Drl. Rig ok Hazard Sec. ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 'i 250/5,000 P 1 250/5,000 P '1 250/5,000 P 1 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 25O/25OO P 1 250/5,000 P 1 250/5,000 P 1 250/5,00O P 1 250/5,000 P 2 250/5,000 P 1 250/5,000 P NA MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 2 Hydraulic Chokes Test Pressure 250/5,000 38 250/5,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2200 avg. 3,000 P 700 P minutes 28 sec. minutes 26 sec. X Remote: X Psig. Number of Failures: '/ ,Test Time: 4.0 Hours. Number of valves tested 28 Repair or Replacement of Failed Equipment will be made within 1 days. otify the Inspector and follow with Written or Faxed verification to the AQGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: choke valve failed will be repaired and retested within 24 hours. Distribution: orig-Well File c - Oper./Rig c- Database c- Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021 L (Rev.12/94) Aaxlbbef. xls _~ .. STATE OF ALASKA ..~ "~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 16. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKB, 61' Pad 3. Address: Exploratory__. 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service _. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1394' FNL, 885' FWL, Sec 12, T11N, R10E, UM 1C-13 At top of productive interval: 9. Permit number/approval number: 2372' FNL, 2503' FWL, Sec 1, T11N, R10E, UM 98-11 Af effective depth: 10. APl number: 2267' FNL, 2533' FWL, Sec 1, T11N, R10E, UM 50-029-22856-00 Af fatal depth: 11. Field/Pool: 2258' FNL, 2555' FWL, Sec 1, T11N, R10E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8677 feet Plugs (measured) None true vedical 6768 feet Effective Depfl measured 8611 feet Junk(measured) None true vertical 6706 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu Yards High Early 121' 121' Surface 5664' 9,625" 612 Sx AS III LW & 5705' 4446' 600 Sx Class G w/60 Sx AS I tail Production 8197' 7" 135 Sx Class G 8235' 6356' Liner 646' 4.5" 116 Sx Class G 8677' 6768' Perforation Depth measured 8334'-8415' true vedical 6447'-6524' Tubing (size, grade, and measured depth) 4.5", 12.6 Ib/ft, L-80 @ 8009' "-~'~ ..... Al~-u~~-u'~''~ ' Packers and SSSV (type and measured depth) Pkr: Baker 80-47 PBR @ 7994' & Baker FAB-1 Packer @ 8009'; SSSV: None, nipple @ 1510' 13. Stimulation or cement squeeze summary Perforate 'C4' sand on 6/17/99. Intervals treated (measured)ORIGINAL 8334'-8350' Treatment description including volumes used and final pressure Perforated using 2-7/8'" HSD gun w/DP charges @ 4 spt, final pressure was 900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2904 2431 1212 1150 175 Subsequent to operation 3255 2760 1415 11 50 220 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date /~_~r_~'. Form 10-404 R(~/0~)/115/88 SUBMIT IN DUPLICATE ARC~3 Alaska, Inc. KUPARUK RIVER UNIT ~--~ ~ZLL SERVICE REPORT 1C-13(4-1)) WELL 1C-1 3 DATIE 06/17/99 DAY 1 FIELD ESTIMATE JOB SCOPE PERFORATIONS-E-LINE DALLY WORK 2 7/8" HSD 4 SPF PERFORATE 8334-8350' OPERATION COMPLETE I SUCCESSFUL I I KEY PERSON (~ Yes O No ~_~ Yes O No SWS-JOHNSON AFC# ICC# ! DAILY COST ACCUM COST AK0034 230DSl 0CG $7,204 $8,593 InitiaITbg IFinalTbg I Initial IA I Final IA I Initial OA IFinalOA ITTL Size 800PSII 900PSII 1100PSII 1100PSII 600PSII 600PSII 0,000 " JOB NUMBER 0615991520.1 UNIT NUMBER 2128 SUPERVISOR SCHUDEL Signed Min ID I Depth 3.750" I 8088 FT DALLY SUMMARY PERFORATED: 8334'-8350'. [Perf] TIME LOG ENTRY 08:00 ARRIVE WELL SWS UNIT 2128, ENG JOHNSON 10:15 PRESSURE TEST BOP/RISER TO 3000# 10:20 SHUT WELL IN AT WING, AND SD GAS LIFTTO RIH 10:25 RIH WITH CCL/16' 2 7/8" HSD PERF GUN 10:55 TIE IN TO CBT DATED 3/1/98 11:35 BLEED WELL DOWN THROUGH WING FROM 950 TO 700 PSIG. ASSUMED 500' COLUMN OF GAS, 27% WATER CUT. 700 PSi WHP WAS BEST GUESS FOR 500 PSI UNDERBALANCE, AS REQUESTED ON PROCEDURE. 11:40 SHOT 8334-8350 11:47 POOH 12:30 AT SURFACE, ALL SHOTS FIRED, RIG DOWN 13:30 LEAVE LOCATION. NOTIFIED DSO TO BOL. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $120.00 APC $100.00 $100.00 HALLIBURTON $0.00 $669.00 LITTLE RED $0.00 $600.00 SCHLUMBERGER $7,104.00 $7,104.00 TOTAL FIELD ESTIMATE $7,204.00 $8,593.00 ARCO Alaska, Inc. Post Office Bo~-',~0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #1 below 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1 C-15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously reported volume of 220 barrels was ~umped into this annulus during the drilling of the well. This was the volume required to flush and freeze protect the annulus during initial drilling operations, not a volume of disposal fluids injected prior to the receipt of authorization for annular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 35095 Open, Freeze Protected 1C-13 I 26800 100 0 26900 , Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO' s, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two ! Total i Volume Current Status of Total h(1) Total h(2) Total h(3) i Well Name Volume Volume Volume i Injected Annulus 2A-22 16749 100 0 ~ 16849 Open, Freeze Protected · 2F-19 20725 100 0 ! 20825 Open, Freeze Protected 3K-27 37173 100 0 i 37273 Open, Freeze Protected 3K-26 33970 100 0 i 34070 Open, Freeze Protected 1E-31 33645 100 0 . 33745 Open, Freeze Protected 1E-32 45205 100 0 i 45305 Open, Freeze Protected 3Q-22 6245 100 0 . 6345 Open, Freeze Protected 1Q-24 23158 100 0 i 23258 Open, Freeze Protected 1Q-26 25931 100 0 ! 26031 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files TONY KNOWLES, GOVERNOR AI, ASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 23. 1998 Michael Zanghi Drilling Superintcndcnt ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 C- 13 ARCO Alaska, Inc. Permit No.: 98-11 Sur. Loc.: 1398'FNL. 892'FWL. Sec. 12. T1 IN. R10E. UM Btmhole Loc: 2216'FNL. 2499'FWL. Sec. 1. T11N. R10E, UM Dear Mr. Zanghi: Encloscd is the approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dctcrminations arc made. This approval includes annular disposal of drilling wastcs and is contingent on obtaining.a well cemented surface casing confirmed bra valid Formation Integrity Test (FIT) - cementing records. FIT data. and any CQLs arc to be submitted to the Commission prior to thc start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximatcly 24 hours) of thc BOPE test performed before drilling below the surface casing shoc must be given so that a rcprcscntativc of thc Commission mav witness the test. Notice max; be given by contacting the Commission pctrolcum field inspector on thc North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game. l labitat Set:lion w,o encl. Department of Environmental Conservation ~-,o encl. STATE OF ALASKA ...... -,~LASK~JOIL AND GAS CONSERVATION COMMIS~SYON PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill [~ /lb TypeofWell Exploratory E StratigraphicTest [--~ Development Oil X Re-Entry E~ Deepen [~! Service 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25649, ALK 467 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1398' FNL, 892' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2311' FNL, 2463' FWL, Sec. 1, T11 N, R10E, UM 1 C-13 #U-630610 At total depth 9. Approximate spud date Amount 2216' FNL, 2499' FWL, Sec. 1, T11 N, R10E, UM 1/26/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 C-06 8677' MD 2216'@ TD feet 30' @ 500' feet 2560 6732' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1300' feet Maximum hole angle 48.5° Maximum surface 3805 psig At total depth (TVD) 4439 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' 41' 41' 121' 121' __.200 CF 12.25" 9.625" 40.0# L-80 BTC-ERV~ 5637' 41' 41' 5678' 4429' 750 Sx Arcticset III & 570 Sx Class G 8.5" 7" 26# L-80 BTC MOD 8221' 41' 41' 8262' 6342' 80 sx Class G - Top 500' above shoe 6.125" 4.5" 12.6# L-80 NSCT 615' 8062' 6154' 8677' 6732' 70 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet1 5 199 Effective depth: measured feet Junk (measured) true vertical feet AJaska casing Length Size Cemented Measured depth True ~e~rt~c[]a~ ~ Structural Conductor Surface Intermediate Production Perforatio~i;;;th: measured 0RItSINAL true vertical 20. Attachments Filing fee X Property plat r~ BOP Sketch X DiverterSketch X Ddlling program X Drilling fluid program X Time vs depth plot E~ Refraction analysis E~ Seabed report F~ 20 AAC 25.050 requirements X 21. IherebycertilthattheTegoing. / / is true and correct to the best of my knowledge Signed ~k.(/ { Title Drilling Superintendent Date ('""" cC?. For questions, please call Tom Brockway '"'i 5A0P- C°mmisii°n Use Only Permi~;~c.~_be~/j ~ I number Approval date See cover letter for ~ ~.. ~ -- ~- ~-- ~' ,~'~' other requirements Condiiions of approval Samples required r-: Yes ~;~ No Mud log required E: Yes ,~ No Hydrogen sulfidemeasures ~;~ Yes [~ No Directional surveyrequired ]~ Yes [~ No Required workingpressureforBOPE ~_1 2M E 3M ~ 5M E~ 1OM [~ 15M Other: by order of Approvedby Da~! i/¢.u. 6:hnSt0, Commissioner the commission Date /'~¢:~,~ D. aissi0 Form 10-401 Rev. 7-24-89 Submit in trip ate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 1C-13 TAB,01/14/98, v. 1 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (+/- 5,678') according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 5000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (+/- 8262') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. Test breaks in BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6.125" hole to well total depth (8677') according to directional plan, running LWD logging equipment as needed. 12. Rig up and run E-line logs. 13. Run and cement 4-1/2" NSCT liner with Baker liner-top hanger and integral PBR. Set_+200' inside intermediate casing shoe to provide appropriate liner lap. 14. Run Baker 'FAB-I' packer with seal assembly. Sting into liner PBR and set packer. Pressure test liner to 3500 psi. 15. Run completion assembly. Latch PBR and seal assembly into FAB-1 packer. Pressure test tubing and annulus. 16. ND BOPE and install production tree. 17. Shut in and secure well. 18. Clean location and RDM© in preparation for coiled tubing cleanout and perforating. Note: Perforating strategy is still being decided. This well may be tubing-conveyed perforated with Parker 245 or Nordic 2. Note: As a dedicated producer, cased hole cement bond logs (SLT-J or CBT) w[[~ ~.p~. ~ri~r~ the cement job requires evaluation. ~ 15 199 Alaska 0il & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1C-13 Drillin.q Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 ___10% Drill out to 7" interm, casing 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drill out to TD 12.2 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System' Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 2,613 psi. MASP = (4429 ft)(0.70 - 0.11) - 2613 psi Maximum anticipated surface pressure is calculated using a intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 3,805 psi. Therefore, ARCO Alaska, Inc. will do a one- time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. MASP = (6342 ft)(0.70 - 0.11 ) -- 3805 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1C pad are expected to be 3900 psi (0.61 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6412'. Well Proximity Risks: The nearest existing well to 1C-13 is 1C-06. As designed, the minimum distance between the two wells would be 30' at 500' MD. Drillin.q Area Risks: Risks in the 1C-13 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations' Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1C-13 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that lC-13 be permitted for annu!ar pumping occurring as a result of drilling operations, per proposed regulations~20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.2 ppg for drilling wastes. Using 12.2 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.2 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure - 4310 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (lb/fi) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). 1C-13 TAB, 1/14/1998, v. 1 '~r',Je Ve,t:cc! Oep:ns ere reference RK8 (Por,~er ~f245) A-' CO asKa, ncU Well · 13 Location : North Slope, Alaska Structure : Pad lC Field : Kuparuk River Unit I TD LOCATION: 2216' FNL, 24gg' FWL 400 0 SEC. 1, T11N, RiOE i ~ ~ East (feet) -> 4GO 800 12CC I J I ) I 60O 400 ~ TD - 4- i/2. LinerS% _ TARGET./ ~Top. C4{ .///'> Base HFCZ/~¢~ o ,~ aE¥^,,ON: ~o2' 19.78 AZIMUTH 4641' (TO TARGET) ¢oo ***Plane of Proposal*** cay -~ ~Begin Angle Dr 800 i TAROET LOCATION: J i 2.31 ;' FNL 2465' FWL / i SEC 1 TI!N RIOF i ~./r-~ 1200 i 0 I ' ' ' - ~ , au ,~.~..m .... ~KOP TVD=t300 TMD=t300 ~= TARO¢T ~ J/' ' q ;~.oc ~;~4~3 ~7 9 5/8 c~ i t!8.o2 DLS: 5.00 deg per 100 ft ~ORIm 4367 J ~23.1g ~/ PERMAFROST geD=lB02 TMD=1818 DEP=IO0 ~ST 1571 / ~0=2208 TMB=2325 0EP=396 ' JMAXIMUM ANGLE~ uuun ~ ~ / Bos~mcfros, [ ~ ¢ ~8~in Turn to Target 4 ~~53~ OEP=2682 ~ ~ 44oo4 ~MD:5678 DEP=2908%~ 4 ~~972 D~=3~9 ~ ~80 ' ~STMATED ~' I ~ I !398' FNL, 892' FWL 5200~ ~~MD=6910 DEP=3832~ 4.7x ~ ., . o. o C~0 ~ TA 2.73 o ~ 38.73 5fiC0~ ~ ~ ' C~0 ~ ~ ~ ~ ~ ~34.73 ' DLS: 2.~0 de~ oar l Ou ft i 30.73 C35 6r. ce j C30 ~i 26.73 q T/ D(EOD) ~D=5~12 TM0=8337 DEP=~626 X'~ 22.7~ ~'coJ TARGET KUP/C4 TVD:6453 TMD:B380 DEP:4641 ~ j T/ C3 ~D=6500 TM0=8430 0EP=4658 ~ ' J T/ C2 ~D=6552 TMD=8454 DEP=4670~_ T/ C1 ~D=6595 TMD=8531 DEP=¢6g3 T/ B SHALE WD=66~3 TMD=6653 TMD=8572 DEP=470~ 6800 ~D - CS6 P~ ~=6732 ?MD=86?? 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Vertical Section (feet) -> Azimuth ~9.78 with reference 0.00 N, 0.00 E from slot ~13 2CC0 ~8co ~CO 4000 550C 320C ? 280C k2400 L - 20C0 ~ :80C ~ 12co L L EGO ~ zOO L 0 ~ z0C Z O A c,~=.,~= ~y ~ For: D PETRASH Do:~ r.,otte¢ : 8-Jcn-g8 ;T~e VerdC¢l ~e~s ere re~ere~ce RKB ~P~rker A, CO Alaska, lnc'7'J Structure : Pad 1C Well : 13 J I Field : Kuparuk River Unit Location : North Slope, Alaskc[ / West (feet) · East (feet) -> 320 280 240 200 160 120 80 40 0 40 80 120 !60 2C0 240 280 32C 600 560 520 ~ 4-80 4-4-0 J170( 4. oo -i -~ 1200 I 360 fl .+-- (P 280i 1°°°I ._.C q gOO 0 800 . z ! 7oo [ 2O0' 600 I I / / / 3100 / / 2400 / 1500 ,' / 3000 ,,/ / i i:4oo 29oo'! / ;/2300 , / , / 1300 2800 ,, / 600 / / , 1900 8OO 700 1 500 1400 - 640 - 600 550 52C 48C - 4CC 500 i -~5n I I ' ~ ~- 320 2100// / ,//1400 J Z // : o ? / :,.- 28'3 '-~ 2000,? / [ / J 2300 ~ool /~o 200 I~oo~/" "! ~ i 900 7 1700,/ l 700A 1600 ~ %1900 500 ~ ~ 1500 V oo ::,- o _,~.. 500 F ilgO0 1 160 ~ 1 70( I 500' d i20 q 40 ~ 5000 0 --~ 3600 80 n 1200 00 000 O0 I I I i J I I I I I [ i ~ I J I i [ I tI t I I I I i I ~ 320 280 240 200 160 120 80 40 0 40 80 120 160 200 24-0 280 320 <- West (feet)' East (feet)-> · ! io~:~=~ For: D PETRASH r'c~e r.;ottec: a-Jcn-~8 ~ot ~e~erence is ~3 Versian ~4. C~ordmo~es are ;n fee~ reference Ve,hce~ ~ep~ns ore reference RKB (P~rker ff2~O). A C0' A}k I .... [ r c. Structure · Pod 10 Well : 13 Field : Kuporuk River Unit Locofion : North Slope, Alosko Easf (feet) -> 400 .300 200 i CO 0 100 200 ,300 400 500 600 700 800 900 1000 I i 00 ~ 200 2400 , , , , , , ' , , , , , , , ,/~, , , , I , , ! ,/~, , , i 240C 650 / ; 23O0 4-OO0 ¢' - 2300 / 630 / 2200 3900/ ~ 2200 / 6100 / 5200 2100 3800/ ,'- 2~00 ; 2000 -~ h 2000 5700 I 3700/ 3100 / / i 500 ~ .'5500 ,' ~- ~ 900 3600/ 5000 L / 1800 5300 / ' 1800 / 3500/ / 51 O0 ,, ~-, 700 1700 ,' 340%/ r- 4-900 /' ,, 2800 ,, r: 60o A ~O0? / 4700 J " , Z / L 700 [ 0 32o0// 4500 / / ~- ~,'c;o / ,," 2600 -'~ 3100¢' ~ (I) 4300 -: 3.30 2900/" - 1:00 2000 3900 / .,/ / 2800/ 2300 ! : ooo 1900 3700 ~ / ~ 2700 / ,,' 2200 ~ goo / I ,,' [- 1800 3500 2600-'¢' L / ~oo i / " t 1700 3300 .,'~500 2000 700 [ 700 / / , ,~00 60O ~ 3100 ,1'- 600 ! ~5oo 500 , , i ~ ~ ~ ~ , ~ , ~ ,. * ' ' ~ ~ ~ ~ 500 400 300 200 100 0 1 O0 200 300 400 500 600 700 800 900 1000 1 i O0 ! 200 Eosf (feet) -> A 1600 I 1500 Q) (D 1400 ,. 0 Z 13C0 1200 1i0o lOGO goo c,~o~,c w ~=. For: D PETRASH ~c,, Reterence is 1~ version ~4. True C~=r~:.o~es ore :n feet reference slat Ver:,c¢l ~eg~s ~re ref~e~ce ~ CParaer Ai CO Alaska, nc;i Structure : Pod lC Well : 15 [ Field : Kuparuk River' Unit Location : North Slope, Alaska] ~COC 3900 3fiCC 3700 East (feet) -> 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 , , , , , , , , , , , , , ' ' , , , , ,,,~, , , , I ' 'A ] 4'00 5700 ~ 4CO0 5600 500 ~ 3900 5500 400 ~ 3800 5400 b ' /~ 3700 5500 O0 F 5200 O0 ~ 3500 5100 ~" /// /100 3400 5000~ // /o ¢900 ~ O0 4800 ~ ,,,, /5900 / ,' // 4700/ ,/ /3~oo ~ 4600¢/_ / ~ 2900 L ~ / /5700 4500 ~ 2800 ~ 0 ,,, 3600 ~ ~ 2700 i ,,/ / 5500 q / 6800 ~ / 4200 / ~ i ~ h 2500 6700 J F ] ¢6600 4100 / /5400 ~ F 4000 /' I , , , ~ , , , , , , , , , ~ , ~ , , , ,-2200 500 400 500 600 700 800 900 1000 1t00 1200 1~00 1400 1500 1600 1700 1800 1900 East (feet) -> 5660 3500 ] A 33C0 = I "~ 32C0 - 3;CC - © Z 30CO- 2goc - 2800 - 27OO 2600 2500 24CC , ~6500 23C0 d 22C0 I , , , ~ ~ , ~ 3200 3'CO 3CCC ARCO Alaska, Inc. Pad 1C 13 slot #13 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref : 13 Version #4 Our ref : prop2672 License : Date printed : 8-Jan-98 Date created : 12-Dec-97 Last revised : 8-Jan-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is nT0 19 31.423,w149 29 53.087 Slot Grid coordinates are N 5968837.558, E 561896.888 Slot local coordinates are 1398.00 S 892.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath MSS <0-7000'>,,9GI,Pad 1C PMSS <O-11300'>,,11,Pad 1C GMS <0-10243'>,,6,Pad lC GMS <0-9600'>,,8,Pad 1C GMS <0-7780'>,,1,Pad 1C GMS <0-7615'>,,2,Pad 1C PGMS <0-9002'>,,10GI,Pad 1C GMS <0-9700'>,,3,Pad 1C GMS <0-7575'>,,4,Pad 1C GMS <0-7753'>,,5,Pad 1C GMS <0-9784'>,,7,Pad 1C PMSS <0-17089'>,,12,Pad 1C ~MS <6948-7570'>,,WS#24,Pad 1C Closest approach with 3-D Minimum Distance method Last revised 2-Jan-98 19-Mar-97 5-Aug-92 5-Aug-92 5-Aug-92 5-Aug-92 5-Aug-92 5-Aug-92 5-Aug-92 5-Aug-92 5 -Aug- 92 7-Jan-98 17-Dec-97 Distance 337 5 307 0 30 2 248 6 570 2 449 3 230 0 322 3 171.0 89.9 149.8 210.6 7724.6 1625.0 300.0 500.0 1675.0 1300.0 1300.0 0.0 1200.0 1450.0 200.0 400.0 1808.7 8677.1 Diverging from M.D. 1625.0 300.0 2680.0 1675 1300 1300 0 1200 1450 8171 400 1808 8677 7 6 5 4 1. 13 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 5/8" 5000 PS. BOP STACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PS! AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 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 FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH '~-~UPARUK RIVER uN~ 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9,94 · WELL PERMIT CHECKLIST COMPANY./~yP~2_,~ FIELD & POOL ~'~E:~/2~>¢__.2 INIT CLASS ._/"~/~_..Z../' I ~.~ ,} GEOL AREA ~::~? O UNIT# _/',///~:~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ~lrilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS ENGINEERING ~A~__~ DC'TE 14. Conductor string provided ................... LY~ N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ (.~N~Y N(._~ 18. CMT will cover all known productive horizons: ......... 19. Casing designs adequate for C, T, B 8, permafrost ....... (.~N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... u,- N ~-' 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. DOPEs, do they meet regulation ................ ~ N 26. DOPE press rating appropriate; test to ~"'¢,,~¢~::, psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. N GEOLOGY 30. Permit can be issued w,o hydrogen sulfide measures ..... y ~'~..//~ /~ 31. Data presented on potential overpressure zones ....... . , 32. Seismic analysis of shallow gas zones ............. Y//N - 33. Seabed N condition survey (if off-shore) ............. ,,,/'t' 34. Contact N name/phone for we.ekly progress reports ..... ,/I'. Y lexploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: JDH ~ RNC'''~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 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. FiELE ~_,L~.~i~ : ?UJPAHblE BOROUGH . NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22856-00 REFERENCE ~,~0 : 981 i 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 98/03/17 ORIGIN : FLIC JOB NUMBER: LOGGING ENGINEER: OPERA TOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING '. DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 98113 S. Morrison F. H~bert 12 lin iOE 1398 892 102. O0 60. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8235.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED DATA ACQUIRED ON ARCO ALASKA'S lC-13 WELL. THIS DATA IS THE ETZt.~A?:7 ~_:~ 3~3,7~C£ ZC'GS F?;¥ ?:~iS ~.',~EL£. : PAGE: : : : $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (~iEASURED DEPTH) BASELINE DEPTH MERG~ DATA SO.CE ~WG TOOL CODE R~ NO. ~S: ~23~. 0 .......... EQOlrVALENT UNSHIFTED DEPTH .......... DAS PASS NO. ........ MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED MAIN LOG DATA ACQUIRED IN OPENHOLE. NO DEPTH CORRECTIONS WERE MADE AS THIS DATA IS THE PRIMARY DEPTH CONTROL LOG. THE DT COMPRESSIONAL COMES FROM THE DSI P & S MODE, THE DT SHEAR COM~S FROM THE DSI UPPER DIPOLE MODE. BOTH DT'S HAVE RELABELED AT THE ALASKA COMPUTING CENTER. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** DEPT FT 1092653 O0 000 O0 0 i 1 i 4 68 0000000000 TENS DAS LB 1092653 O0 000 O0 0 1 1 1 4 68 0000000000 CALl DAS IN 1092653 O0 000 O0 0 1 1 ! 4 68 0000000000 GR DAS GAPI 1092~53 O0 000 O0 0 i ! i 4 68 0000000000 DT DAS US/F 1092653 O0 000 O0 0 i i 1 4 68 0000000000 DTSH DAS US/F 1092653 O0 000 O0 0 1 1 1 4 68 0000000000 SC~ DAS 1092653 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8669.000 TENS.DAS 5853.000 CAL1.DAS -999.250 GR.DAS -999.250 DT. DAS -999.250 DTSH.DAS -999.250 SCRA.DAS -999.250 DEPT. 8234.000 TENS.DAS 5430.000 CAL1.DAS DT.DAS 120.762 DTSH.DAS 257.480 SCRA.DAS 6.293 GR.DAS 2.132 66.709 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DAS 8234.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP F~EPiE 7650.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DAS REMARKS: THIS FILE CONTAINS THE CLIPPED MAIN LOG DATA ACQUIRED UP INTO CASING. NO DEPTH CORRECTIONS WERE MADEAS THIS DATA IS THE PRIMARY DEPTH CONTROL LOG. THIS DATA HAS BEEN RELABELED AT THE ALASKA COMPUTING CENTER. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** -z ¥¥ .'.'.- '- :- HE:E:- i '.-£7 .FEEl-ZEE C?Z .&Fi _&?Z %?Z FiLE ;.tT/Z ;/L¥/5 SiZE ZcCZ~. ~ LZZ Zi?~ ZZ~ES :'-Si/ :'.iT.SS E~U? Z_E--/ JZZZ GRCH DAS GAPI 1092653 O0 000 O0 0 2 1 1 4 68 0000000000 DT DAS US/F 1092653 O0 000 O0 0 2 1 1 4 68 0000000000 DTSH DAS US/F 1092653 O0 000 O0 0 2 1 ! 4 68 0000000000 SCRA DAS 1092653 O0 000 O0 0 2 i i 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 8234.000 TENS.DAS 5430.000 GRCH.DAS DTSH.DAS 257.480 SCRA.DAS 2.132 DEPT. 7650.000 TENS.DAS 4927.000 GRCH.DAS DTSH.DAS 244.725 SCRA.DAS 2.174 66. 709 DT.DAS 120. 762 87.222 DT.DAS 112.572 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: **** FILE TRAILER **** FILE NAFiE : EDIT .002 SERVICE : FLIC VERSION · O01CO1 · .:-.-:k JZ-:TM. HZLu ;i&. '. DEPTH INCR~4ENT: O. 5000 FILE S~Y VENDOR TOOL CODE ST_~RT DEPTH STOP DEPTH ..................................... 8626.0 8234.0 DSI $ LOG HEADER DATA DATE LOGGED: 9-FEB-98 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1000 9-FEB-98 TIME LOGGER ON BOTTOM: 1715 9-FEB-98 TD DRILLER (FT) : 8677.0 TD LOGGER (FT) : 8672.0 TOP LOG INTERVAL (FT) : 8234.0 BOTTOM LOG INTERVAL (FT) : 8669.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL ArUMBER GR GAi~4A RAY SGT-L DSI DIPOLE SONIC DSST-B LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 Dipole, P & S, Low Freq. P & S Modes run. Mud resistivities provided by Sperry Sun. Rig Parker 245. THE REPEAT SECTION SHE'A~ COif]ES F.EC2.~ THE LOWER DIPOLE RECEIVER MODE. THE MAIN LOG SHEAR COME FROM THE UPPER DIPOLE RECEIVER MODE. THIS FILE CONTAINS THE RAW MAIN OPENHOLE LOGS SAMPLED AT 0.5' $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 8 TYPE REPR CODE VALUE 3 73 32 RSHC DSI 1092653 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8688.500 TENS.DSI -999.250 CALI.DSI -999.250 GR.DSI -999.250 DTCO.DSI -999.250 DT2.DSI 172.648 PR.DSI -999.250 RSHC.DSI -999.250 DEPT. 8234.000 TENS.DSI 5430.000 CALI.DSI DTCO.DSI 120.762 DT2.DSI 257.480 PR.DSI 6.293 GR.DSI 66.709 0.359 RSHC.DSI 2.132 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 FILE S~Y VE~OR TOOL CODE ST~T DEPTH STOP DEPTH ..................................... DSI $ LOG HEADER DATA DATE LOGGED: 9-FEB-98 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 1000 9-FEB-98 TIME LOGGER ON BOTTOM: 1715 9-FEB-98 TD DRILLER (FT) : 8677.0 TD LOGGER (FT) : 8672.0 TOP LOG INTERVAL (FT) : 8234.0 BOTTOM LOG INTERVAL (FT) : 8669.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY DSI DIPOLE SONIC $ TOOL NUMBER SGT-L DSST-B LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.125 8235.0 8234.0 1.3ud resiszivicies provided bl,- Rig Par~er 245. THE REPEAT SECTION SHEAR COMES FROM THE LO~,'IER DIPOLE RECEIVER MODE. THE ~LqIN LOG SHEAR COi~E FRO?.! Ch-E UPPER DIPOLE RECEIVER MODE. THIS FILE CONTAINS THE RAW REPEAT OPENHOLE LOGS SAMPLED AT O. 5 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 . . LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR~1998 12:45 PAGE: 11 TYPE REPR CODE VALUE 5 66 ._ : : j 7; ''t : -- _ - /5 -__ . - --- '.-J . - 3 i :~--z-_: -- ~ -: ' - = c~ __ ' _7-_ - ..................................................................... ** DATA ** DEPT. 869i.000 TENS.DSI 1383.000 PR.DSi DT1.DSI 171.173 DTCO.DSI 92.213 CALI.DSI 0.261 RSHC.DSi 1. 757 2. 732 GR.DSI 114. 990 * * END OF DATA * * **** FILE TRAILER **** FILE NAlVlE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 12 **** FILE HEADER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION : O01CO1 TD LOGGER (FT) : ~672. 0 TOP LOG INTERV~ (FT): 8234.0 BOTTOM LOG INTERVAL (FT) : 8669.0 LCGGIi?G SPEED (FPHR) : TOOL STRING (TOP TO ~OTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~L~ RAY DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : TOOL NUMBER SGT-L DSST-B 6.125 8235.0 8234.0 LSND 13.00 50.0 9.2 .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 13 RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) MUD AT ~4EASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) ~.FJD FILTRATE AT (MT): · : 1. 990 !. 420 71.0 71.0 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VADUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 14 ** SET TYPE - CHAN ** -..-.-r ---U? ..... i-- c~cl- l_~ ~21 %21 _%Ri 3.77 5¥21. l.il2 2.122 2.1i2 122. *~** FiLE iP~AiLER *~* FILE N~%IE : EDIT .005 SERVICE · FLIC VERSION · O0!CO1 DATE : 9~/03/i7 I4AXREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIFIBER 6 RAW CASED HOLE REPEAT PASSES LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 15 Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 ? : - ' -:'- - 7 --'- ~i i' D3~ZLL~.~- CASi3~G DEPTh- ~F?) : LOGGERS CASING DEPTH (FT) : BOREHOLE SOA~ITIONS £4UD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEAStrRED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): SGT-L /.z2z 8234.0 LS2'iD i3. O0 50.0 9.2 1. 990 71.0 1. 420 71.0 2. 760 71.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 16 REM3L~KS: Standoffs on DSI. Dipole, P & S, Low Freq. P & S Modes run. Mud resis~ivities provide~ b~,r Sperr? Sun. 1 66 0 .? ~ ~ 8 68 0.5 9 65 FT ~i 66 36 22 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 TENS DSI LB 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 PR DSI 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 RSHC DSI 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 DT1 DSI US/F 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 DTCO DSI US/F 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 GR DSI GAPI 1092653 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1998 12:45 PAGE: 17 DATA ** 5. ~J'3 -. : z-5 J5 £ 7 ' : 5L5 ' CO~TINUATION ~ : 1 PREVIOUS TAPE : CO;.9.1EtiT · D~CO ALAS~ INC, !C-i3, KUP_~UK, API ~50-029-22856-00 * * * * REEL TP~AILER * * * * SERVICE NAME : EDIT DATE : 98/03/17 ORIGIN : FLIC REEL NAME : 98113 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, lC-13, KUPARUK, API #50-029-22856-00 Sperry-Sun Drilling Services LIS Scan Utility Thu Feb 26 12:44:22 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/02/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 3 AK-MM-80108 B. HENNINGSE G. WHITLOCK ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1C-13 500292285600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 26-FEB-98 MWD RUN 4 MWD RUN 4 AK-MM-80108 AK-MM-80108 B. HENNINGSE B. HENNINGSE D. BREEDEN D. BREEDEN 12 llN 10E 892 .00 101.90 60.40 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 5705.0 8.500 7.000 8235.0 6.125 8677.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 & 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTP), AND STABILIZED LITHO- DENSITY (SAD). 5. MWD DATA FROM 8235'MD, 6356'TVD (7" CASING SHOE) TO 8659'MD, 6752'TVD WERE ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE (ROTATING) FOR MWD RUN 4. 6. THIS WELL REACHED A TOTAL DEPTH OF 8677'MD, 6767'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SPSF = SMOOTHED COMPENSATED THERMAL NEUTRON PoROsITY (SANDSTONE MATRIX- FIXED HOLE SIZE). SBDC = SMOOTHED BULK DENSITY COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. CURVES WITH A SUFFIX OF "M" DENOTE MAD PASS DATA. ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6.125" MUD FILTRATE SALINITY: 200 - 500 PPM CHLORIDES MUD WEIGHT: 12.5 - 12.8 PPG FORMATION WATER SALINITY: 9500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5650.0 8630.5 ROP 5717.0 8670.0 FET 8219.5 8637.5 RPD 8219.5 8637.5 RPM 8219.5 8637.5 RPS 8219.5 8637.5 RPX 8219.5 8637.5 FCNT 8222.0 8576.0 NCNT 8222.0 8576.0 NPHI 8222.0 8576.0 PEF 8241.0 8595.0 DRHO 8241.0 8595.0 RHOB 8241.0 8595.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 5650.0 7656 7658 7659 7663 7665 7699 7701. 7701. 7711. 7713 7726 7729 733 735 746 765 768 772 774 776 0 793 5 842 0 848 0 855 0 869 0 874 0 GR 5655.0 5 7661.5 0 7663.0 5 7665.0 0 7667.0 0 7668.0 5 7707.0 0 7708.5 5 7710.5 5 7718.5 5 7720.0 5 7735.0 0 7736.5 0 7740.5 0 7744.0 5 7754.5 5 7770.5 0 7775.5 0 7780.0 0 7781.5 7784.0 7802.0 7850.5 7856.0 7863.5 7876.0 7881.5 EQUIVALENT UNSHIFTED DEPTH 7878.5 7882.0 7885.5 7887.0 7889.5 7891.0 7893.0 7894.0 7900.0 7902.5 7907.5 7912.5 7915.5 7917 5 7918 5 7922 0 7925 5 7936 5 7938 5 7941 5 7947 0 7949 5 7951 0 7953 0 7954.5 7959.5 7962.0 7964.0 · 7966.5 7969.5 7973.5 7976.0 7977.5 7978.5 7981.5 7985.0 7986.5 7989.5 7990.5 7991.5 7994.0 7996.5 7997.0 '7999.5 8005.0 8008.0 8015.0 8015.5 8016.0 8018 0 8022 0 8024 5 8026 5 8028 0 8029 5 8033 0 8036 0 8036 5 8038 0 8040 5 7886.0 7889.5 7894.0 7895.0 7897.0 7899.0 7901.0 7901.5 7906.5 7910.5 7917.5 7919.5 7922.5 7924.0 7925.0 7928.5 7934.5 7943.5 7946.0 7948.5 7952.5 7956.5 7958.5 7960 5 7961 5 7966 0 7968 5 7970 5 7972 0 7976.5 7979.5 7982.0 7985.0 7985.5 7988.0 7991.0 7993.0 7995.0 7995.5 7997.0 7999.5 8001.5 80O2.0 8005.0 8010.5 8013 0 8021 5 8022 5 8023 0 8024 5 8028 5 8031 0 8033 0 8034 5 8035 5 8039 5 8042 0 8043.0 8044.5 8046.0 8041.0 8043.0 8045.0 8047.0 8049.5 8051.0 8053.5 8O60.5 8072.0 8074.0 8075.5 8076.5 8079.0 8080.5 8082.5 8083.0 8084.5 8085.0 8O9O.5 8092.0 8143.5 8145 0 8151 5 8184 0 8186 0 8188 5 8216 0 8237.0 8239.0 8246.0 8247.5 8250.0 8252.0 8260.0 8263.5 8264.5 8266.0 8273.5 8275.0 8276.5 8284.0 8289.5 8291.5 8301.5 8305.5 8309.5 8311.5 8323 0 8325 0 8327 0 8329 0 8331 5 8336 0 8343 5 8346 0 8354 0 8359.5 8363.0 8364.5 8371.5 8047.5 8049.5 8051.5 8054.0 8058.5 8059.5 8062.0 8069.0 8077.5 8080.5 8081.0 8081.5 8086.0 8088.0 8088.5 8089.0 8090.5 8091.0 8098.0 8098.5 8155.0 8156.5 8160.5 8190.5 8192.5 8194.5 8221.5 8242.0 8243.5 8252.0 8256.0 8257.5 8259.5 8268.0 8272.0 8273.5 8275.0 8281.5 8283.5 8285 0 8292 5 8296 5 8299 5 8309 5 8314 0 8317.5 8320.5 8331.5 8333.0 8334.5 8336.5 8339.0 8345.0 8351.0 8354.0 8361.5 8367.5 8372.0 8373.0 8381.0 8374.5 8379.5 8385.5 8390.0 8400.0 8406.0 8417.5 8420.0 8424.5 8426.0 8432.0 8438.0 8441.5 8445.0 8446.0 8448.0 8451.0 8454.0 8456.5 8468.0 8470 0 8472 0 8473 5 8504 0 8506 0 8507 0 85O8 0 8509 5 8510.5 8512.0 8514.0 8522.0 8528.0 8536.5 8539.5 8543.5 8546.0 8548.5 8582.0 8585.0 8588.0 8670.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8383 5 8388 0 8394 5 8399 0 8409 0 8415 5 8426 5 8430.5 8434 5 8435 5 8440 0 8448 0 8450 5 8453 5 8455 5 8456 0 8460 0 8462 0 8463 5 8476 5 8479 0 8480.5 8482 0 8512 0 8514 0 8515 0 8516 0 8517 5 8518 5 8520 0 8522.0 8530.0 8536.0 8545.0 8548.0 8552.0 8554.0 8557.0 8591.0 8594.0 8595.5 8677.5 BIT RUN NO MERGE TOP MERGE BASE 3 5720.0 8248.0 4 8248.0 8677.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 5650 8670 7160 ROP 4.3218 599.62 175.698 GR 13.2027 429.605 117.357 RPX 0.0805 41.782 5.21568 RPS 0.061 36.5713 5.16445 RPM 0.064 2000 69.1815 RPD 0.05 2000 44.3731 FET 0.6663 14.2126 2.72913 NPHI 17.56 104.06 38.0193 NCNT 517.809 1489.81 979,151 FCNT 1.904 25.5908 11.4349 RHOB 1.7116 2.9656 2.38484 DRHO -0.061 0.2578 0.0485904 PEF 6.5298 18.7288 10.3061 Nsam 6041 5911 5962 837 837 837 837 837 709 709 709 709 709 709 First Reading 5650 5715 5650 8219.5 8219.5 8219.5 8219.5 8219.5 8222 8222 8222 8241 8241 8241 Last Reading 8670 8670 8630.5 8637.5 8637.5 8637.5 8637.5 8637.5 8576 8576 8576 8595 8595 8595 First Reading For Entire File .......... 5650 Last Reading For Entire File ........... 8670 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 8220.0 8615.0 8225.5 8560.0 8225.5 8560.0 8225.5 8560.0 8226.5 8621.0 8226.5 8621.0 8226.5 8621.0 8226.5 8621.0 8226.5 8621.0 8232.5 8578.5 8232.5 8578.5 8232.5 8578.5 8262.5 8652.5 MAD RUN NO. MAD PASS NO. MERGE TOP 4 8248.0 MERGED MAD PASS. $ MERGE BASE 8677.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max f~ames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR I~AD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 NPHI MAD P.U. 4 1 68 NCNT MAD CNTS 4 1 68 FCNT MAD CNTS 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 28 32 36 40 44 48 52 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 8220 8652.5 8436.25 866 RAT 47.646 140.16 85.4888 781 GR 29.301 126.962 78.6829 791 RPX 0.146 32.341 4.95798 790 RPS 0.068 29.243 4.82863 790 RPM 0.103 2000 34.0072 790 RPD 0.053 2000 30.6403 790 FET 10.256 39.596 20.5909 790 NPHI 20.65 94.17 37.9805 670 NCNT 523.553 1512.68 958.565 670 FCNT 2.1484 24.5508 11.1971 670 RHOB 1.874 2.923 2.3628 693 DRHO -0.091 0.125 0.034018 693 PEF 6.977 19.685 1t.3944 693 First Reading 8220 8262.5 8220 8226.5 8226.5 8226.5 8226.5 8226.5 8225.5 8225.5 8225.5 8232.5 8232.5 8232.5 Last Reading 8652.5 8652.5 8615 8621 8621 8621 8621 8621 8560 8560 8560 8578.5 8578.5 8578.5 First Reading For Entire File..- ........ 8220 Last Reading For Entire File ........... 8652.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5655.0 ROP 5720.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8205.5 8248.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 04-FEB-98 ISC 5.06 CIM 5.46 MEMORY 8248.0 5720.0 8248.0 22.3 48.8 TOOL NUMBER P0932CG6 8.500 8.5 LSND 9.20 390.0 9.5 700 9.2 .000 .000 .000 .000 46.1 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5655 8248 6951.5 5187 5655 GR 13.2027 429.605 123.807 5102 5655 ROP 24.9421 599.62 198.66 5057 5720 Last Reading 8248 8205.5 8248 First Reading For Entire File .......... 5655 Last Reading For Entire File ........... 8248 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8206.0 8638.0 FET 8225.0 8645.0 RPD 8225.0 8645.0 RPM RPS RPX FCNT NCNT NPHI PEF DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8225.0 8225.0 8225.0 8227.5 8227.5 8227.5 8246.0 8246.0 8246.0 8248.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8645.0 8645.0 8645.0 8585.0 8585.0 8585.0 8602.5 8602.5 8602.5 8677.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 08-FEB-98 ISC 5.06 CIM 5.46 MEMORY 8677.0 8248.0 8677.0 21.0 21.4 TOOL NUMBER P0921SP4 P0921SP4 P0921SP4 P0921SP4 6.130 6.1 LSND 12.50 49.0 9.5 5OO 3.8 1.990 1.184 1.420 2.760 51.1 .6 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 4 FT/H 4 1 GR MWD 4 API 4 1 RPX MWD 4 OHMM 4 1 RPS MWD 4 OPIMM 4 1 RPM MWD 4 OHMM 4 1 RPD MWD 4 OHMM 4 1 FET MWD 4 HOUR 4 1 NPHI MWD 4 P.U. 4 1 NCNT MWD 4 CNTS 4 1 FCNT MWD 4 CNTS 4 1 RHOB MWD 4 G/CC 4 1 DRHO MWD 4 G/CC 4 1 PEF MWD 4 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max Mean DEPT 8206 8677.5 8441.75 ROP 4.3218 215.237 41.0577 GR 27.8016 141.773 80.4004 RPX 0.0805 2000 7.61024 RPS 0.061 36.5713 5.18721 RPM 0.064 2000 68.8906 RPD 0.05 2000 44.1957 FET 0.6663 14.2126 2.72976 NPHI 17.56 104.06 38.0617 NCNT 517.809 1489.81 975.14 FCNT 1.904 25.5908 11.3951 RHOB 1.7116 2.9656 2.38188 DRHO -0.061 0.2578 0.0484455 PEF 6.5298 18.7288 10.3554 First Last Nsam Reading Reading 944 8206 8677.5 859 8248.5 8677.5 865 8206 8638 841 8225 8645 841 8225 8645 841 8225 8645 841 8225 8645 841 8225 8645 716 8227.5 8585 716 8227.5 8585 716 8227.5 8585 714 8246 8602.5 714 8246 8602.5 714 8246 8602.5 First Reading For Entire File .......... 8206 Last Reading For Entire File ........... 8677.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 4 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8225.5 8622.5 FCNT 8231.0 8569.0 NCNT 8231.0 8569.0 NPHI 8231.0 8569.0 FET 8232.0 8628.5 .RPD 8232.0 8628~5 RPM 8232 . 0 8628.5 RPS 8232 . 0 8628 . 5 RPX 8232.0 8628.5 PEF 8238.0 8587.5 DRHO 8238.0 8587.5 RHOB 8238.0 8587.5 RAT 8271.0 8660.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 08-FEB-98 ISC 5.06 CIM 5.46 MEMORY 8677.0 8248.0 8677.0 21.0 21.4 TOOL NUMBER P0921SP4 EWR4 CNP SLD $ ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P0921SP4 P0921SP4 P0921SP4 6.130 6.1 LSND 12.50 49.0 9.5 5OO 3.8 1.990 1.184 1.420 2.760 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 4 FT/H 4 1 68 4 2 GR MAD 4 API 4 1 68 8 3 RPX MAD 4 OHMM 4 1 68 12 4 RPS MAD 4 OHMM 4 1 68 16 5 RPM MAD 4 OHMM 4 1 68 20 6 RPD MAD 4 OHMM 4 1 68 24 7 FET MAD 4 HOUR 4 1 68 28 8 NPHI MAD 4 P.U. 4 1 68 32 9 NCNT MAD 4 CNTS 4 1 68 36 10 FCNT MAD 4 CNTS 4 1 68 40 11 RHOB MAD 4 G/CC 4 1 68 44 12 DRHO MAD 4 G/CC 4 1 68 48 13 PEF MAD 4 BARN 4 1 68 52 14 51.1 Name Min Max Mean Nsam DEPT 8225.5 8660 8442.75 870 RAT 47.646 140.16 85.6381 779 GR 28.955 126.962 78.983 795 RPX 0.146 32.341 4.96299 794 RPS 0.068 29.243 4.83038 794 RPM 0.103 2000 33.8597 794 RPD 0.053 2000 30.5057 794 FET 10.256 39.596 20.7417 794 NPHI 20.65 94.17 38.1024 677 NCNT 523.553 1512.68 955.403 677 FCNT 2.0186 24.5508 11.1342 677 RHOB 1.874 2.923 2.3613 700 DRHO -0.091 0.125 0.0340643 700 PEF 6.977 19.685 11.4151 700 First Reading 8225.5 8271 8225.5 8232 8232 8232 8232 8232 8231 8231 8231 8238 8238 8238 Last Reading 8660 8660 8622.5 8628.5 8628.5 8628.5 8628.5 8628.5 8569 8569 8569 8587.5 8587.5 8587.5 First Reading For Entire File .......... 8225.5 Last Reading For Entire File ........... 8660 File Trailer Service name ............. STSL!B.O05 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * COMPANY NAME : ARCO ALASKA INC. WELL NAblE : 1C-13 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292285600 REFERENCE NO : 98356 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/15 ORIGIN : FLIC REEL NAME : 98356 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK, lC-13, API #50-029-22856-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/15 ORIGIN : FLIC TAPE NAME : 98356 CONTINUATION # : 1 PREVIOUS TAPE : COM~fENT · ARCO ALASKA INC., KUPARUK, lC-13, API #50-029-22856-00 TAPE HEADER KUPARUK CASED HOLE WIRELINE LOGS WELL NAME: lC-13 API NUMBER: 500292285600 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 15-JUL-98 JOB NUMBER: 98356 LOGGING ENGINEER: S DECKERT OPERATOR WITNESS: R BLACK SURFACE LOCATION SECTION: 12 TOWNSHIP: liN RANGE: IOE FNL: 1398 FSL: FEL: FWL: 892 ELEVATION(FT FROM MSL O) KELLY BUSHING: 102.00 DERRICK FLOOR: GROUND LEVEL: 60. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/F~ 1ST STRING 9.675 5705.0 40.00 2ND STRING 7.000 8235.0 26.00 3RD STRING 4.500 8677.0 12.60 PRODUCTION STRING 4.500 8009.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASUREDDEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DAS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 09-FEB-98 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 8581.0 8573.5 8572.0 8559.0 8555.0 8551.5 8549 5 8545 5 8545 0 8540 5 8540 0 8537 0 8528 5 8528 0 8518 0 8514 5 8514 0 8506.5 8506.0 8501 0 8499 5 8492 0 8484 0 8474 5 8472 5 8470 0 8467 5 8465 0 8461 5 8451 5 8449 5 8445 5 8440.5 8440.0 8435.0 8431.5 8430.0 8427.5 8426.0 8423.0 8421.5 8417.5 8416.0 8413.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88888.5 88886.5 8579.5 8573.0 8572.5 8558.5 8558.5 8556.0 8551.0 8546.0 8540.0 8536.5 8528.0 8514.0 8506.0 8500.5 8498.0 8491.5 8482.5 8473.5 8470.0 8460.5 8451.0 8445.0 8439.0 8434.0 8431.5 8426.5 8424.0 8423.0 8421.0 8417.5 8411.0 8548.5 8543.0 8540.0 8528.0 8517.5 8513.5 8506.5 8491.5 8473.5 8468.0 8465.5 8451.0 8441.5 8431.0 8417.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8409.0 8401.0 8399.5 8398.0 8394.0 8392.5 8390.5 8389.0 8386.5 8380.0 8379.5 8372.5 8368.5 8366.0 8361.5 8361.0 8359.5 8353.5 8352.5 8348.0 8347.5 8345.5 8342.5 8338.5 8335.0 8334.5 8331.5 8330 0 8325 0 8324 0 8319 5 8314 5 8312 5 8309 0 8303 5 8298 5 8294 5 8291 5 8290 5 8289 5 8287 5 8284 5 8275 0 8274 5 8271 5 8264 0 8262 5 8250 5 8249 5 8246 0 8243 5 8240 0 8236 0 8231 0 8228 5 8224 0 8408.0 8399.0 8396.0 8394.0 8390.0 8387.5 8385.5 8379.5 8371.5 8366.0 8363.5 8359.5 8353.5 8348.5 8345.0 8343.5 8340.5 8335.0 8331.5 8325.0 8320.5 8316.5 8309.5 8303.0 8298.5 8294.0 8291.5 8289.5 8284.0 8275.0 8273.0 8264.5 8263.0 8250.0 8246.5 8242.5 8240.0 8237.0 8231.0 8230.5 8223.0 8400.0 8390.0 8380.0 8371.5 8363.0 8353.5 8348.5 8345.0 8336.0 8331.5 8325.0 8320.5 8311.5 8291.5 8289.5 8284.0 8275.0 8250.0 30-JUL-1998 08:29 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-i998 08:29 8223.5 8223.0 8220.0 8219.0 8205.0 8205.0 8198.0 8197.5 8188.5 8188.5 8187.5 8186.5 8187.0 8186.5 8184.0 8184.0 8181 . 5 8181 . 0 8168.5 8168.5 8155.5 8155.0 8155.0 8151.0 8151.5 8149.5 8149.5 8145.5 8145.0 8145.0 8143 . 0 8143 . 5 8141.0 8141.0 100.0 100.0 99.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S lC-13 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE DAS GAI~LA RAY, ALSO PASS #1 NPHI AND THE DAS GAMMA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~W~augY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 8575.5 8140.0 CNTG 8583.5 8139.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ND?4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 6 NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CNTC CNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 GR DAS GAPI 1159708 O0 000 O0 0 1 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 8596.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 GR.DAS 68.962 DEPT. 8050.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 GR.DAS 109.459 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: FILE HEADER FILE NIIMBER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUN, VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8575.0 8140.0 CNTG 8584.0 8139.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 8577.0 8572.5 8567.0 8559.0 8554.5 8552.0 8549.5 8545.5 853 6.0 8529.0 8528.0 8522.0 8514.5 85O9.5 8506.0 8503.0 8501.0 8497.5 8492.5 8492.0 8484.0 8479.0 8473.5 8472.0 8468.5 8465.5 8465.0 8463.5 8459.5 8456.0 8455.0 8451.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88888.0 88887.0 8576.0 8572.5 8566.5 8558.5 8554.5 8551.0 8548.5 8546.0 8535.5 8528.0 8527.5 8521.5 8514.0 8513.5 8509.5 8506.0 8503.5 8502.5 8500.5 8496.5 8491.5 8491.0 8482.5 8477.5 8472.5 8471.5 8467.5 8465.5 8464.0 8462.5 8459.0 8455.0 8456.0 8451.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 8447.0 8446.0 8442.5 8442.0 8436.5 8436.5 8432.5 8431.5 8431.0 8431.0 8428.0 8427.0 8424.5 8424.0 8423.0 8423.0 8424.0 8417.5 8417.5 8410.0 8408.0 8405.0 8403.5 8400.0 8399.0 8397.0 8396.0 8391.5 8391.0 8388.5 8387.5 8386.5 8385.0 8380.0 8380.0 8379.5 8379.5 8376.0 8376.0 8372.0 8373.5 8370.5 8372.0 8368.5 8368.0 8367.5 8370.0 8365.5 8366.0 8363.0 8363.5 8361 . 0 8363.0 8360.0 8359.5 8354.0 8353.5 8348.5 8348.5 8346.0 8345.0 8344.0 8343.5 8343.5 8343.5 8341.0 8340.0 8340.0 8340.5 8335.5 8336.0 8331.5 8331.0 8329.5 8330.0 8329.0 8328.5 8325.0 8325.0 8324.0 8325.0 8323.5 8323.5 8312.5 8312.0 8309.0 8309.5 8308.0 8307.5 8306.5 8305.5 8306.0 8306.0 8299.0 8298.5 8291.5 8291.5 8291.0 8291.5 8287.5 8287.5 8286.0 8288.0 8284.0 8283.5 8278.0 8278.0 8275.0 8275.0 8274.5 8275.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 8269.5 8267.0 8264.0 8259.5 8256.0 8250.5 8250.0 8246.0 8243.0 8242.5 8238.5 8237.5 8234.0 8230.5 8229.0 8223.0 8222.5 8221.0 8218 0 8210 0 8208 0 8204 0 8201 5 8199 0 8194 0 8188 0 8187.0 8185.5 8183.5 8182.5 8182.0 8180.0 8177.5 8173.0 8169.5 8164.5 8160.5 8155.5 8150.5 8150.0 8147.5 8143.0 100.0 $ 8264.5 8259.5 8255.5 8250.0 8246.5 8242.5 8240.0 8234.0 8230.5 8223.5 8221.0 8219.0 8205.0 8198.0 8186.0 8184.5 8182.0 8169.0 8163.0 8160.5 8155.5 8149.5 8143.0 100.0 8269.5 8266.5 8250.0 8245.5 8242.0 8237.5 8229.5 8223.0 8212.0 8209.5 8202.5 8193.5 8186.5 8184.0 8181.0 8178.0 8177.0 8171.5 8155.0 8150.5 8146.5 99.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CTIRVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center · _/ 30-JUL-1998 08:29 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1159708 O0 000 O0 0 2 1 i 4 68 0000000000 CRAT CNTG 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1159708 O0 000 O0 0 2 1 i 4 68 0000000000 CFEC CNTG CPS 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1159708 00' 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1159708 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 11 DEPT. 8575.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. ClFTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 70.000 TENS. CNTG DEPT. 8139.500 NPHI.CNTG 56.277 ENPH. CNTG NRAT. CNTG 4.588 CRAT. CNTG 4.490 ENRA. CNTG FCNT. CNTG 221.625 CNTC. CNTG 1045.844 CFTC. CNTG CFEC. CNTG 402.645 GRCH. CNTG -999.250 TENS. CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 57.047 CPHI.CNTG 6.969 NCNT. CNTG 233.963 CNEC. CNTG 2550.938 CCL.CNTG -999.250 -999.250 -999.250 -999.250 54.388 1037.188 2806.188 0.547 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION : O01CO1 DATE . 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREFiENT: 0.5000 FILE SUM~zARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 8575.0 8139.0 CNTG 8584.0 8141.0 $ CURVE SHIFT DATA - PASS TO PASS (~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 12 BASELINE DEPTH 88888.0 8578.0 8577.0 8573.5 8573.0 8570.0 8566.5 8561.5 8559.0 8558.5 8555.5 8549.0 8545.0 8543.5 8543.0 8540.5 8539.5 8536.0 8533.5 8528.5 8520.5 8518.0 8517.0 8514.5 8514.0 8510.0 8508.5 8506.5 8502.5 8500.5 8492.5 8491.0 8486.5 8484.0 8482.0 8478.5 8475.0 8474.0 8469.0 8468.5 8465.5 8464.5 8462.5 8459.5 8457.0 8455.0 8454.5 8453.0 8451.5 8446.5 8440.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88888.0 88887.0 8573.0 8569.5 8558.5 8556.0 8545.5 8542.5 8539.5 8533.5 8528.0 8520.5 8517.5 8514.0 8503.5 8501.0 8491.0 8482.5 8473.5 8466.5 8464.5 8459.0 8457.5 8454.5 8451.0 8446.0 8577.0 8576.0 8572.5 8566.5 8561.5 8558.5 8548.5 8541.5 8540.0 8535.5 8533.5 8527.5 8517.5 8513.5 8510.5 8508.5 8506.5 8503.0 8491.5 8486.0 8483.5 8480.0 8477.0 8473.5 8469.0 8465.5 8462.0 8456.0 8454.0 8441.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 13 8436.0 8431.0 8428.0 8424.0 8423.0 8422.5 8417.0 8411.0 8408.0 8405.5 8405.0 840O. 5 8400.0 8395.0 8391.0 8388.0 8386.5 8380.5 8379.0 8375.5 8373.0 8367.0 8363.0 8361.0 8360.0 8359.5 8352 5 8348 0 8347 5 8345 5 8344 0 8342 5 8335 5 8335 0 8328 5 8328 0 8325 0 8324.0 8319.5 8312.5 8307.0 8299.0 8291.5 8290.5 8284.5 8284.0 8280.0 8277.5 8275.0 8274.5 8271.5 8267.0 8266.5 8263.5 8259.5 8436.5 8430.5 8426.5 8423.0 8417.5 8409.0 8404.5 8399.0 8394.5 8387.5 8385.5 8379.5 8376.0 8366.0 8363.5 8360.0 8353.5 8348.5 8345.0 8343.5 8335.5 8329.5 8325.0 8320.5 8298.5 8291.5 8284.0 8277.0 8275.0 8267.0 8263.0 8425.0 8424.0 8408.5 8403.5 8399.5 8388.0 8380.5 8375.5 8363.0 8361.0 8348.0 8343.5 8336.0 8328.5 8325.0 8312.0 8305 5 8291 5 8283 5 8280 0 8275 0 8271 0 8266.5 8259.5 . _ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 14 8258.5 8256.0 8250 5 8249 5 8243 5 8239 5 8235 5 8234 5 8223 5 8222 0 8220 0 8218 0 8214 5 8207 5 8207.0 82OO. 5 8199.0 8194.0 8189.0 8187.5 8186.5 8183.0 8181.5 8177.5 8176.0 8174.5 8170.5 8168.0 8163.5 8161.5 8159.5 8158.0 8156.0 8154.0 8147.0 8146.0 8144.0 100.0 8259.5 8250.0 8243.0 8240.0 8234.5 8223.0 8219.0 8207.5 8197.5 8188.5 8186.0 8182.0 8176.0 8168.5 8163.0 8157.0 8145.0 99.0 8256.0 8250.0 8239.0 8236.0 8223.0 8221.5 8219.0 8213.5 8209.5 8202.5 8193.5 8186.5 8181.0 8178.5 8176.0 8169.0 8160.5 8159.5 8155.0 8154.0 8146.5 8145.0 101.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1159708 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8575.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 76.313 TENS. ClFTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 16 DEPT. 8139.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 54.219 TENS. CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL. CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3M~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS--ERS .......................... 1, 2, 3, CNTG REM~ARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3.THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1159708 O0 000 O0 0 4 1 1 4 NPHI CNAV PU-S 1159708 O0 000 O0 0 4 1 1 4 NRAT CNAV 1159708 O0 000 O0 0 4 1 1 4 CPHI CNAV PU-S 1159708 O0 000 O0 0 4 1 1 4 CRAT CNAV 1159708 O0 000 O0 0 4 1 1 4 ENPH CNAV PU-S 1159708 O0 000 O0 0 4 1 1 4 ENRA CNAV 1159708 O0 000 O0 0 4 1 1 4 NCNTCNAV CPS 1159708 O0 000 O0 0 4 1 1 4 FCNT CNAV CPS 1159708 O0 000 O0 0 4 1 1 4 CNTC CNAV CPS 1159708 O0 000 O0 0 4 1 1 4 CFTC CNAV CPS 1159708 O0 000 O0 0 4 1 1 4 CNEC CNAV CPS 1159708 O0 000 O0 0 4 1 1 4 CFEC CNAV CPS 1159708 O0 000 O0 0 4 1 1 4 GRCH CNTG GAPI 1159708 O0 000 O0 0 4 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 8575.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI. CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENR~.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 66.938 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 18 DEPT. 8140.000 NPHI.CNAV -999.250 ArRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 51.469 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREFiENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH ........................... CNTG 8605.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIM~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 8138.0 O1-MAR-98 CP 44.2 1112 O1-MAR-98 8580.0 8598.0 8140.0 8585.0 1800.O LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-i998 08:29 PAGE: 19 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NEUTRON $ TOOL NUM~ER ........... SGTL 664324 CNTG 125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8677.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER -7.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): RE~ARKS: CORRELATED TO SWS DIPOLE DATED 9-FEB-98. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUAI~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1159708 O0 000 O0 0 5 1 i 4 68 0000000000 RTNR PS1 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1159708 O0 000 O0 0 5 1 i 4 68 0000000000 CNTC PS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1159708 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 21 DEPT. 8605.500 NPHI.PS1 TNRA.PS1 2.734 RTNR.PS1 CNEC. PS1 4298.559 RCEF. PS1 RCFT. PS1 890.025 CNTC. PS1 GR.PS1 68.813 TENS. PSi DEPT. 8138.000 NPHI. PS1 TNRA.PS1 4.908 RTNR.PS1 CNEC. PS1 2898.010 RCEF. PS1 RCFT. PS1 240.091 CNTC. PS1 GR.PS1 54.313 TENS. PSi 24.269 ENPH. PS1 2.795 ENRA.PS1 1002.706 RCEN. PS1 2440.329 CFTC. PSi 1805.000 CCL.PS1 63.907 ElVPH. PS1 5.435 ENRA.PS1 471.798 RCEN. PS1 1119.369 CFTC.PSi 2620.000 CCL.PS1 26.740 TNPH. PS1 4.317 CFEC. PS1 4033.229 RCNT. PS1 909.385 NPOR.PS1 0.586 47.159 TNPH. PS1 6.224 CFEC. PS1 2725.978 RCNT. PS1 235.869 NPOR.PS1 0.586 22.427 995.812 2533.543 22.427 66.185 465.653 1147.671 67.033 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : OOiCO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMF2TT : 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... CNTG 8605.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH .......... 8139.5 O1 -MAR-98 CP 44.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-i998 08:29 PAGE: 22 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1112 O1-MAR-98 8580.0 8598.0 8140.0 8585.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NEUTRON $ TOOL NUMBER ........... SGTL 664324 CNTG 125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8677.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER -7.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): RE~ULRKS: CORRELATED TO SWS DIPOLE DATED 9-FEB-98. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-~L-1998 08:29 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NIIFZB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1159708 O0 000 O0 0 6 1 i 4 68 0000000000 RTNR PS2 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1159708 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 24 DEPT. 8605.500 NPHI.PS2 TNRA.PS2 2.496 RTN-R.PS2 CNEC. PS2 4282.216 RCEF. PS2 RCFT. PS2 965.832 CNTC. PS2 GR.PS2 62.156 TENS.PS2 DEPT. 8139.500 NPHI.PS2 TNRA.PS2 4.469 RTNR.PS2 CNEC. PS2 2839.471 RCEF. PS2 RCFT. PS2 237.894 CNTC. PS2 GR.PS2 54.656 TENS.PS2 20.194 ENPH. PS2 2.552 ENRA.PS2 1129.130 RCEN. PS2 2414.574 CFTC. PS2 1850.000 CCL.PS2 55.898 ENPH. PS2 4.308 ENRA.PS2 440.324 RCEN. PS2 1070.487 CFTC. PS2 2615.000 CCL.PS2 22.294 TNPH. PS2 3.819 CFEC. PS2 4017.895 RCNT. PS2 986.841 NPOR.PS2 0.586 55.938 TNPH.PS2 6.890 CFEC. PS2 2657.045 RCNT.PS2 246.308 NPOR.PS2 0.391 19. 069 1121. 367 2506. 804 19. 069 50.468 412.093 1174.551 47.519 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUM~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 8606.0 8138.5 $ LOG HEADER DATA DATE LOGGED: O1-MAR-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 25 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): CP 44.2 1112 O1 -MAR-98 8580.0 8598.0 8140.0 8585.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NEUTRON $ TOOL NUMBER ........... SGTL 664324 CNTG 125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8677.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER -7.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS DIPOLE DATED 9-FEB-98. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 26 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~ SAMP ELAW CODE (HEX) DEPT FT 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 RTArR PS3 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS$ CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1159708 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:29 PAGE: 27 DEPT. 8606.000 NPHI.PS3 TNRA.PS3 2.529 RTNR.PS3 CNEC. PS3 4204.596 RCEF. PS3 RCFT. PS3 923.225 CNTC. PS3 GR.PS3 68.375 TENS. PS3 DEPT. 8138.500 NPHI.PS3 TNRA.PS3 4.217 RTNR.PS3 CNEC. PS3 2866.032 RCEF. PS3 RCFT. PS3 257.728 CNTC. PS3 GR.PS3 57.250 TENS.PS3 20.705 ENPH. PS3 2.586 ENRA.PS3 1055.546 RCEN. PS3 2337.723 CFTC. PS3 1785.000 CCL.PS3 51.312 ENPH. PS3 4.500 ENRA.PS3 459.834 RCEN. PS3 1096.069 CFTC. PS3 2570.000 CCL.PS3 23.975 TNPH. PS3 4.011 CFEC. PS3 3945.066 RCNT. PS3 943.307 NPOR.PS3 0.586 49.790 TNPH. PS3 6.431 CFEC. PS3 2740.250 RCNT.PS3 269.752 NPOR.PS3 0.586 19.509 1048.289 2427.019 19.509 44.385 445.626 1154.436 43.676 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION . O01CO1 DATE : 98/07/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/15 ORIGIN : FLIC TAPE NA~E : 98356 CONTINUATION # : 1 PREVIOUS TAPE COF~ENT : ARCO ALASKA INC., KUPARUK, lC-13, API #50-029-22856-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/15 ORIGIN : FLIC REEL NAME : 98356 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC., KUPARUK, lC-13, API #50-029-22856-00
