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Home My WebLink About199-0981. 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 11770'feet 11400'feet true vertical 6379' feet None feet Effective Depth measured 11322'feet 10849'feet true vertical 5971'feet 5585'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 10935' 10978' 5651' 6684' Packers and SSSV (type, measured and true vertical depth)10849' 5585' 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: 6546' 3586' Burst Collapse Liner 11085' 825' Casing 6370' 6379' 11117' 11769' 6512' 115'Conductor Surface Production 16" 9.625" 75' measured TVD 7" 3.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-098 50-029-22951-00-00 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: ADL0025660 Kuparuk River Field/ Kuparuk Oil Pool KRU 1L-28 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) 39 Gas-Mcf MDSize 115' 6677 13211574 Well Shut-In 226 324-495 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Blue Pack RH Max SSSV: None Leslie Manning leslie.manning@conocophillips.com (907) 263-3731Staff RWO/CTD Engineer 11295-11320', 11334-11363', 11518-11538' 5947-5969', 5981-6008', 6147-6166' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:47 am, Oct 24, 2024 Digitally signed by Leslie Manning DN: OU=Wells, O=ConocoPhillips, CN=Leslie Manning, E=leslie.manning@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.24 08:52:02-08'00' Foxit PDF Editor Version: 13.0.0 Leslie Manning Page 1/4 1L-28 Report Printed: 10/22/2024 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) 9/21/2024 18:00 9/21/2024 21:00 3.00 MIRU, MOVE MOB P Pull sub off well. Hang tree in celllar. Clean up around 1L-08. Lay mats and dunnage in front of 1L-28 in prep to pull rig over well. Spot rig over 1L-28. 9/21/2024 21:00 9/21/2024 23:30 2.50 MIRU, MOVE RURD P Safe out rig. Center rig over well. Berm in cellar. Spot in hardline manifold and cuttings tank. Measure RKB's. Work through rig acceptance checklist. Spot in support equipment. Spot returns tanks on ODS. RU hardline. Clean up pad in front of 1L-08 for Environmental inspection. Gather initial pressures: T/IA/OA = 1310 / 1075 / 60 psi. Accept rig @ 23:30PM. Take on seawater into pits. Build 35 bbl DeepClean pill. Confirmed w/ Pad Op SSV is fully pumped open (some stem was still sticking out of cylinder). 9/21/2024 23:30 9/22/2024 00:00 0.50 MIRU, WELCTL RURD P RU circulating lines in cellar for well kill. Cont. to spot in support equipment and load SW in pits. 9/22/2024 00:00 9/22/2024 01:00 1.00 MIRU, WELCTL RURD P Cont. RU circ hoses in cellar and hardline at tanks. 9/22/2024 01:00 9/22/2024 01:45 0.75 MIRU, WELCTL PRTS P PT circ manifold and tiger tank lines to 2500 psi. Check lines.Pump fluid out to tanks to obtain baseline Blooie line pressure at kill rate. 3 BPM / 4 BPM / 5 BPM = 180 / 310 / 460 psi. B/D line to tanks. 9/22/2024 01:45 9/22/2024 02:00 0.25 MIRU, WELCTL SFTY P PJSM for well kill. 9/22/2024 02:00 9/22/2024 08:00 6.00 MIRU, WELCTL KLWL P Bleed free gas from Tubing and IA. Initial IA = 941 psi. Limit Blooie line pressure to 150 psi. Bled IA to 400 psi. Swap to Tubing. Initial = 375 psi. Bleed Tubing to 200 psi. Mostly fluid. Less gas B/D hardline. Suck out Tiger Tank. Pump 32 Bbls heated SW DeepClean pill. Chase with 458 bbls of 8.5# Seawater. Pump rate 3 @ BPM FCP=560 psi. Measured 8.5 PPG returns at surface. SD pump. Start processing Tubing while bleeding gas. 9/22/2024 08:00 9/22/2024 08:45 0.75 MIRU, WELCTL OWFF P OWFF for 30-min. Bleed OA F/ 180 PSI T/ 0 PSI. 9/22/2024 08:45 9/22/2024 09:15 0.50 MIRU, WELCTL MPSP P Pull tree cap. Set IS-A BPV. 9/22/2024 09:15 9/22/2024 09:30 0.25 MIRU, WHDBOP PRTS P Test BPV to 1,000 psi from below 10- min. 9/22/2024 09:30 9/22/2024 10:00 0.50 MIRU, WHDBOP RURD P B/D, R/D circ equipment. 9/22/2024 10:00 9/22/2024 12:00 2.00 MIRU, WHDBOP NUND P ND Tree. Inspect hanger neck threads - good 10 turns. Function LDS. Install slip over blanking plug. 9/22/2024 12:00 9/22/2024 14:30 2.50 MIRU, WHDBOP NUND P N/U BOP. Install flow nipple. Hook up trip tank line. 9/22/2024 14:30 9/22/2024 16:45 2.25 MIRU, WHDBOP RURD P R/U testing equipment. Fill stack w/ fresh water. Grease HCR vavle. Rig: NORDIC 3 RIG RELEASE DATE 9/26/2024 Page 2/4 1L-28 Report Printed: 10/22/2024 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) 9/22/2024 16:45 9/22/2024 21:30 4.75 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2". 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 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=3050 PSI, after closure=1750 PSI, 200 PSI attained = 23 sec, full recovery attained = 109 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 = 1900 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Adam Earl. 9/22/2024 21:30 9/22/2024 23:30 2.00 COMPZN, RPCOMP RURD P Drain stack. Blowdown lines. RD testing equipment. Pull blanking plug. L/D test joint. Bleed IA. Slight flow from IA. 3 PSI on IA. Bleed off IA to bucket. 9/22/2024 23:30 9/23/2024 00:00 0.50 COMPZN, RPCOMP MPSP P Pull IS-A BPV. 9/23/2024 00:00 9/23/2024 00:30 0.50 COMPZN, RPCOMP THGR P Screw Landing Joint into Hanger neck threads. Screw in TD. Set 10K down. BOLDS. Pull hanger to rig floor. Pull 175K to unseat (cycled to 175 twice to unseat hanger). Drag to floor at 120K. Saw 30K over pull to 150K with hanger approx. 2' below floor. Fell off and pulled hanger to rig floor @ 120K. 0.0 10,930.0 9/23/2024 00:30 9/23/2024 02:00 1.50 COMPZN, RPCOMP CIRC P Pump 25 bbl high vis pill. Circ STS @ 8 BPM / 1323 psi. Load jewelry. Replace Joint #17 (bent) w/ spare joint A. 10,897.0 10,897.0 9/23/2024 02:00 9/23/2024 02:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. B/D Top Drive. Finish loading jewelry. 10,897.0 10,897.0 9/23/2024 02:30 9/23/2024 15:00 12.50 COMPZN, RPCOMP PULL P Pull 3 1/2" tubing F/ cut @ 10,930', started to see sporadic corrosion on collars & tubing after pull GLM #1 @ 4272'. Located hole in TBG on joints #248 & #251. Corrosion gets worse, with scale on after GLM #3 @ 9066'. Corrosion decreasing after joint # 306, Hole in joint #346. Pulled total of 346 joints & 16.48' cut joint. Clean cut. Some scale on last couple joints. 10,897.0 0.0 9/23/2024 15:00 9/23/2024 16:00 1.00 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0 9/23/2024 16:00 9/23/2024 16:30 0.50 COMPZN, RPCOMP SVRG P Clean & grease elevators, slip & tubing tongs. 0.0 0.0 9/23/2024 16:30 9/23/2024 17:00 0.50 COMPZN, RPCOMP SFTY P PJSM on running BHA #1 on tubing. 0.0 0.0 9/23/2024 17:00 9/23/2024 17:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1, poorboy overshot w/ 7" CSG scraper T/ 55' 0.0 55.0 9/23/2024 17:30 9/24/2024 00:00 6.50 COMPZN, RPCOMP PULD P RIH w/ 3 1/2", 9.3#, L-80, EUE-M F/ 55' T/ 5,776'. EUE torqued T/ 2250 Ft/lbs. Jet lube seal guard dope used. 55.0 5,776.0 Rig: NORDIC 3 RIG RELEASE DATE 9/26/2024 Page 3/4 1L-28 Report Printed: 10/22/2024 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) 9/24/2024 00:00 9/24/2024 07:00 7.00 COMPZN, RPCOMP PULD P Cont. TIH w/ 3 1/2" Tubing w/ casing scraper to 10,882' (approx. 3 joints above expected tubing stub). Work scraper acrossed new packer set interval. 5,776.0 10,882.0 9/24/2024 07:00 9/24/2024 08:15 1.25 COMPZN, RPCOMP CIRC P Screw in TD on #347. Pump 15 bbl hi- vis sweep. Circ STS. 10,882.0 10,882.0 9/24/2024 08:15 9/24/2024 10:00 1.75 COMPZN, RPCOMP WASH P Obtain parameters. PUW = 110K. SOW = 64K. 3.5 BPM @ 305 psi. Wash down. Screw in TD on #348. Wash down. Screw in TD on #349. Slowly wash down and locate top of tubing stub @ 10,931.7' (see pressure indicator). Cont. TIH. Wash down to 10,934'. Set 20K down. PUH off stub. Repeat wash down. 2.5 BPM @ 196 psi. Set 22K down and shear screws sheared out @ 10,934'. Continue wash down to 10,937'. See final pressure indicator at no-go. Set 15K down to confirm fully located. 10,882.0 10,937.0 9/24/2024 10:00 9/24/2024 11:30 1.50 COMPZN, RPCOMP CIRC P PUH off stub. Pump 15 bbl hi-vis pill. Circ STS. 10,937.0 10,928.0 9/24/2024 11:30 9/24/2024 12:45 1.25 COMPZN, RPCOMP PRTS P L/D Joint #349. RU testing equipment. MU head pine and block valve to tubing. RU sensator to test spool. Close UPR. PT 7" casing to 2,500 psi for 15-min. Chart. Good test. 10,928.0 10,912.0 9/24/2024 12:45 9/24/2024 18:30 5.75 COMPZN, RPCOMP PULD P L/D Joints #348 - #344. TOOH racking back Stands #113-78 in derrick. L/D Joint # 235. Rack back Stands #77-1. L/D Joints #3 - #1. 10,912.0 50.0 9/24/2024 18:30 9/24/2024 19:15 0.75 COMPZN, RPCOMP BHAH P L/D BHA #1 (7" casing scraper). 50.0 0.0 9/24/2024 19:15 9/24/2024 20:15 1.00 COMPZN, RPCOMP RURD P Clean and clear rig floor. Prep floor to run 3 1/2" EUE completions. Re-dress PBOS w/ new shear screws. Verify jewelry and run order. 0.0 0.0 9/24/2024 20:15 9/25/2024 00:00 3.75 COMPZN, RPCOMP TRIP P Run 3 1/2" Completions as per Tally to 4,000'. MU last full joint above tubing stub. 0.0 4,000.0 9/25/2024 00:00 9/25/2024 06:30 6.50 COMPZN, RPCOMP TRIP P Run 3 1/2" Completions as per Tally F/ 4,000' T/ 10,916'. MU last full joint (#354) above tubing stub. 4,000.0 10,916.0 9/25/2024 06:30 9/25/2024 07:15 0.75 COMPZN, RPCOMP WASH P Screw in TD. Obtain parameters. PUW = 110K. SOW = 64K. Pump rate = 1.5 BPM @ 96 psi. Wash down over tubing stub @ 10,930.5' N3 RKB. See press. indicator. Cont. swallowing stub. See shear screws @ 10,933.3' (12K shear). Cont. swallow and fully locate @ 10,936.8'. Set 10K down. PUH. Repeat set down. Set 3K down @ 10,935.6' PU to neutral. Mark Pipe. Calculate space out. 10,916.0 10,936.0 9/25/2024 07:15 9/25/2024 08:00 0.75 COMPZN, RPCOMP HOSO P L/D partial joint #345, full joint #344, and full joint #343. Measure and calculate space out. MU space out pups (10.13' + 4.09'). MU last full joint #343. MU tubing hanger, landing joint, head pin, and circ hose to choke. 10,936.0 10,855.0 9/25/2024 08:00 9/25/2024 10:45 2.75 COMPZN, RPCOMP CIRC P Circulate 290 bbls of 8.6# CI into annulus. 2BPM @ 226 psi. SD Pumps. Blow down lines. 10,855.0 10,855.0 Rig: NORDIC 3 RIG RELEASE DATE 9/26/2024 Page 4/4 1L-28 Report Printed: 10/22/2024 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) 9/25/2024 10:45 9/25/2024 12:30 1.75 COMPZN, RPCOMP THGR P Land Hanger. RILDS. Drop ball and rod. RU testing equipment w/ green testing valves and sensators on Tubing and IA. Monitor OA. 10,855.0 10,932.0 9/25/2024 12:30 9/25/2024 13:30 1.00 COMPZN, RPCOMP PACK P Pressure up Tubing to set SLB Packer per rep. See initial shear @ 1,800 psi. Hold Tubing @ 3,500 psi for 30-min. Chart. Pass. 10,932.0 10,932.0 9/25/2024 13:30 9/25/2024 14:00 0.50 COMPZN, RPCOMP PRTS P Bleed Tubing to 1,500 psi. PT IA to 2,500 psi for 30-min. Pass. Chart. Dump tubing pressure. Shear SOV. Pump 10 bbls to confirm flow path. 2 BPM @ 248 psi. 10,932.0 10,932.0 9/25/2024 14:00 9/25/2024 14:30 0.50 COMPZN, RPCOMP RURD P R/D testing equipment. L/D landing joint. 10,932.0 0.0 9/25/2024 14:30 9/25/2024 15:30 1.00 COMPZN, RPCOMP MPSP P Set BPV. Test to 1,000 psi from below for 10-min. Chart. 0.0 0.0 9/25/2024 15:30 9/25/2024 18:30 3.00 COMPZN, WHDBOP NUND P ND BOP. Call out LRS pump. Install test dart. NU Tbg head adapter. NU new tree. Ensure tree is in proper orientation per pictures. 0.0 0.0 9/25/2024 18:30 9/25/2024 20:30 2.00 COMPZN, WHDBOP PRTS P RU LRS. PT hanger void to 5000 psi for 15-min. PT new tree to 5000 psi. 0.0 0.0 9/25/2024 20:30 9/25/2024 21:00 0.50 COMPZN, WHDBOP MPSP P Pull BPV and test dart. 0.0 0.0 9/25/2024 21:00 9/25/2024 22:00 1.00 COMPZN, WHDBOP FRZP P RU LRS to IA. Line up hardline to take returns to open top. Pump 72 bbls diesel down IA. U-Tube for 1 hour. Final Circulating pressure 710 psi @ 2 bpm 0.0 0.0 9/25/2024 22:00 9/26/2024 00:00 2.00 DEMOB, MOVE MOB P Record Final Pressures. T/IA/OA = 75/ 110 / 20. Clean and clear cellar. Prep for rig move to 2B-02. 0.0 0.0 9/26/2024 00:00 9/26/2024 06:00 6.00 DEMOB, MOVE MOB P Continue prepping for rig move, toolhouse take loads to 2B pad. Clean out pits. Perform maintenance on skate chain. Clean out rig sumps. Perform rig maintenace while waiting on highline crew to disconnect rig. Perform drift inventory. 0.0 0.0 9/26/2024 06:00 9/26/2024 12:00 6.00 DEMOB, MOVE MOB P Disconnect highline. Back off 1L-28. Prep for move to 1F. Rig Release @ 12:00 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 9/26/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 11,322.0 1L-28 4/9/2023 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post RWO GLD install, pull RHC's, pull catcher & RBP 1L-28 10/9/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL - 1L-28, 1L-28L1, 1L-28L2, 1L-28L2-01 2/8/2008 osborl 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 40.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.70 34.8 6,546.4 3,585.9 40.00 L-80 BTCM PRODUCTION 7 6.28 32.0 11,116.8 5,795.8 26.00 L-80 BTCM WINDOW TO L2-01 4 3.50 11,315.0 11,325.0 5,973.4 LINER 3 1/2 2.99 10,944.1 11,769.0 6,378.5 9.30 L-80 EUE8rdMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.0 Set Depth 10,934.6 String Max No 3 1/2 Set Depth 5,650.5 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.0 30.0 0.25 Hanger 6.980 3.5" x 7" FMC Gen 4 Tubing Hanger - 3 1/2" EUE top, H-BPV FMC Gen 4 2.920 3,436.0 2,253.2 65.08 Mandrel GAS LIFT 5.900 3.5" x 1.5" MMG, GLM, SN: 24657- 06 SLB MMG 2.990 5,557.2 3,171.7 64.29 Mandrel GAS LIFT 5.874 3.5" x 1.5" MMG, GLM, SN: 24657- 09 SLB MMG 2.990 10,788.7 5,541.1 43.41 Mandrel GAS LIFT 5.907 3.5" x 1.5" MMG, GLM SN: 24657- 01 SLB MMG 2.920 10,848.8 5,585.4 41.72 Packer 6.025 3.5" x 7" BluePack RH Max VAM TOP B/P SN: C23P-1917 SLB BluePac k 2.894 10,906.4 5,628.9 40.24 Nipple - X 4.505 3.5" x 2.813" X-Nipple SN: 0005011991-14 Halliburt on X 2.813 10,927.6 5,645.1 39.70 Overshot 6.030 3 1/2" x 7" Poorboy Overshot w/ 6.6' of swallow (2' space out off no-go) Inno Poorboy Oversho t 3.625 Top (ftKB) 10,930.0 Set Depth 10,977.5 String Max No 3 1/2 Set Depth 5,683.9 Tubing Description Tubing Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 3.00 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) 10,951.7 5,663.7 39.06 SEAL ASSY 3.500 80-40 GBH-22 SEAL ASSEMBLY w/LOCATOR BAKER 3.000 10,976.5 5,683.1 38.34 SHOE 3.500 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 11,321.0 5,969.8 27.38 PATCH KB LOWER PACKER ASSEMBLY MID-ELEMENT AT 11366'. TOP OF PACKER AT 11359', PACKER TOTAL LENGTH = 17.71'. RUN BAKER UPPER KB WHIPSTOCK PACKER WITH MID ELEMENT AT 11325'. TOP OF ASSEMBLY AT 11321.5' AND BOTTOM OF ASSEMBLY AT 11329' - ORIENTED TO 11.7 DEG RIGHT OF HIGH SIDE WITH WPP TOOL BAKER 12/29/2007 1.812 11,400.0 6,040.3 26.35 PLUG WRP, WRP PULLING TOOL set 9/25/06-STUCK IN PLACE 9/15/2006 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,436.0 2,253.2 65.08 1 GAS LIFT GLV RK 1 1/2 1,225.0 10/6/2024 SLB MMG 0.125 5,557.2 3,171.7 64.29 2 GAS LIFT OV RK 1 1/2 10/5/2024 SLB MMG 0.250 10,788.7 5,541.1 43.41 3 GAS LIFT DMY RK 1 1/2 9/25/2024 SLB MMG 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) 10,944.1 5,657.9 39.28 PACKER 5.937 ZXP LINER TOP PACKER BAKER 4.375 11,668.3 6,285.5 22.74 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,295.0 11,320.0 5,946.8 5,968.9 C-4, 1L-28 6/22/2000 6.0 APERF 2.5" HSD, 60° phasing 11,334.0 11,364.0 5,981.4 6,008.1 C-4, C-3, C-1, 1L -28 3/19/2000 4.0 APERF 2.5" HSD, 60° phasing 11,518.0 11,538.0 6,147.3 6,165.7 A-5, 1L-28 12/19/1999 4.0 IPERF 2.5" HSD, 180° phasing 1L-28, 10/22/2024 11:57:26 AM Vertical schematic (actual) LINER L1; 11,324.3-13,150.0 LINER; 10,944.1-11,769.0 IPERF; 11,518.0-11,538.0 FRAC; 11,518.0 PLUG; 11,400.0 SLOTS; 11,345.0-11,376.0 APERF; 11,334.0-11,364.0 PATCH; 11,321.0 FRAC; 11,295.0 WINDOW TO L2-01; 11,315.0- 11,325.0 REFRAC; 11,295.0 APERF; 11,295.0-11,320.0 PRODUCTION; 32.0-11,116.8 CUT; 10,930.0 Nipple - X; 10,906.4 Packer; 10,848.8 Mandrel GAS LIFT; 10,788.6 SURFACE; 34.8-6,546.4 Mandrel GAS LIFT; 5,557.2 Mandrel GAS LIFT; 3,436.0 CONDUCTOR; 40.0-115.0 Hanger; 30.0 KUP PROD KB-Grd (ft) RR Date 11/23/199 9 Other Elev 1L-28 ... TD Act Btm (ftKB) 11,770.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295100 Wellbore Status PROD Max Angle & MD Incl (°) 66.56 MD (ftKB) 2,336.25 WELLNAME WELLBORE1L-28 Annotation Last WO: End Date 9/25/2024 H2S (ppm) 130 Date 3/24/2022 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,518.0 11,538.0 1 FRAC 2/12/2000 0.0 0.00 0.00 11,295.0 11,364.0 2 FRAC 5/7/2000 0.0 0.00 0.00 11,295.0 11,320.0 1 REFRAC 11/12/2006 0.0 0.00 0.00 1L-28, 10/22/2024 11:57:27 AM Vertical schematic (actual) LINER L1; 11,324.3-13,150.0 LINER; 10,944.1-11,769.0 IPERF; 11,518.0-11,538.0 FRAC; 11,518.0 PLUG; 11,400.0 SLOTS; 11,345.0-11,376.0 APERF; 11,334.0-11,364.0 PATCH; 11,321.0 FRAC; 11,295.0 WINDOW TO L2-01; 11,315.0- 11,325.0 REFRAC; 11,295.0 APERF; 11,295.0-11,320.0 PRODUCTION; 32.0-11,116.8 CUT; 10,930.0 Nipple - X; 10,906.4 Packer; 10,848.8 Mandrel GAS LIFT; 10,788.6 SURFACE; 34.8-6,546.4 Mandrel GAS LIFT; 5,557.2 Mandrel GAS LIFT; 3,436.0 CONDUCTOR; 40.0-115.0 Hanger; 30.0 KUP PROD 1L-28 ... WELLNAME WELLBORE1L-28 Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11LͲ28 50Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003 Kuparuk River Plug Setting Record FieldͲFinal 17ͲSepͲ24 0 121LͲ28 50Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003 Kuparuk River SBHP RecordFieldͲFinal 17ͲSepͲ24 0 131QͲ09 50Ͳ029Ͳ21209Ͳ00 909524807 Kuparuk River Packer Setting Record FieldͲFinal 27ͲAugͲ24 0 141RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Leak Detect Log FieldͲFinal 12ͲSepͲ24 0 151RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Multi Finger CaliperField & Processed 13ͲSepͲ24 0 161RͲ05 50Ͳ029Ͳ21330Ͳ00 ALSL764Ͳ001 Kuparuk River Plug Setting Record FieldͲFinal 12ͲSepͲ24 0 171RͲ20 50Ͳ029Ͳ22207Ͳ00 909524808 Kuparuk River Multi Finger CaliperField & Processed 28ͲAugͲ24 0 181YͲ27 50Ͳ029Ͳ22379Ͳ00 909524542 Kuparuk River Leak Detect Log FieldͲFinal 22ͲAugͲ24 0 191YͲ27 50Ͳ029Ͳ22379Ͳ00 909524542 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 110 2AͲ04 50Ͳ103Ͳ20026Ͳ00 909593148 Kuparuk River Multi Finger CaliperField & Processed 22ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39684T39684T39685T39686T39686T39686T39687T39688T3968810/21/2024199-098184-192185-070191-108193-088184-053T39689Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:39:57 -08'00'199-098184 1921LͲ2850Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003KuparukRiverPlugSettingRecordFieldͲFinal17ͲSepͲ240121LͲ2850Ͳ029Ͳ22951Ͳ00 ALSL764Ͳ003KuparukRiverSBHPRecordFieldͲFinal17ͲSepͲ2401T39684T39684 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11770' 6379' 11322' 5971'2318 11400' None Casing Collapse Conductor Surface 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: 907-263-3731 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 Kuparuk River Field Leslie Manning leslie.manning@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10944'MD/5658'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025660 199-098 P.O. Box 100360, Anchorage, AK 99510 50-029-22951-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 10978' MD 115' 3586' 115' 6546' 6370'7" 16" 9.625" 75' ZXP Liner Top Packer SSSV: None 6512' 11117' Perforation Depth MD (ft): KRU 1L-28 11295-11320' 11334-11363' 11518-11538' 11085' 3.5" 5947-5969' 5981-6008' 6147-6166' 9/25/2024 11769'825' 3-1/2" 6379' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Leslie Manning DN: OU=Wells, O=ConocoPhillips, CN=Leslie Manning, E= leslie.manning@conocophillips.com Reason: I am the author of this document Location:Date: 2024.08.28 16:17:13-08'00' Foxit PDF Editor Version: 13.0.0 Leslie Manning 324-495 By Grace Christianson at 10:16 am, Aug 29, 2024 BOP test to 2500 psig Annular preventer to 2500 psig A.Dewhurst 30AUG24 VTL 9/5/2024 10-404X X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.06 14:42:02 -07'00' 09/06/24 RBDMS JSB 091024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 26, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Leslie Manning Senior RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 1L-28 (PTD# 199-098). If you have any questions or require any further information, please contact me at 512.755.6782. Well 1L-28 was drilled and completed in 1999 by Pool Rig 6 as a Kuparuk A&C-sand producer. In 2006 a WRP became stuck in place in the 3-1/2" liner between the A&C sands. In 2008 CTD laterals L1, L2, & L2-01 were drilled in the Kuparuk C-sands. In 2017 a leak was identified at 10,890' RKB via LDL and a tubing patch was installed to repair the leak and return the well to production. In April 2022 the well was shut-in due to a failed TIFL that ultimately resulted in locating two leaks in the tubing at 7,790' RKB and 7,877' RKB. In order to re-establish Kuparuk C-sand production a rig workover is required to pull and repace the tubing and restore integrity to the tubing. 1L-28 RWO Procedure Kuparuk Producer P&R Tubing PTD #199-098 Page 1 of 2 Remaining Pre-Rig Work 1. Test T & IC packoffs, FTLDS 2. Get updated SBHPS 3. Dummy GLM Stations #1-4, leaving open pocket in Station #5 for circulation 4. Set RBP below packer 5. Set catcher 6. CMIT to 2500 psi 7. Cut the tubing at mid-joint of first full joint above the packer (~10,930’ RKB) 8. Prep well for rig ~48 to 96 hours before rig arrival; confirm no gas in OA, IA, or Tubing MIRU 1. MIRU Nordic 3 on 1L-28 2. Circulate seawater 3. 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 if needed 4. 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 Tubing 5. Pull BPV, MU landing joint, and BOLDS 6. Pull 3-1/2” tubing from tubing cut Install in 3-½” Tubing with packer and seal assembly 7. MU & RIH w/ 3-1/2” completion w/ non-sealing overshot, packer, nipple, and GLMs 8. Once on depth, circulate CI brine, space out as needed, land tubing hanger, RILDS, drop B&R, and set packer 9. Pressure test tubing to 3,000 psig for 30 minutes on chart 10. Pressure test inner annulus to 2,500 psig for 30 minutes on chart ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential 12. Install BPV 13. ND BOPE, NU tree, PT tree 14. Pull BPV, freeze protect well, and set BPV if necessary 15. RDMO Post-Rig Work 16. Pull BPV 17. Pull B&R 18. Pull catcher 19. Pull RBP 20. Install GLD 1L-28 RWO Procedure Kuparuk Producer P&R Tubing PTD #199-098 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV Tubing Head (5K Top, 3K Bottom). Production Engineer: Banabas Dogah Reservoir Development Engineer: Cody Keith Estimated Start Date: 9/25/2024 Workover Engineer: Leslie Manning (office: 907.263.3731; email: Leslie.Manning@conocophillips.com) Current Operations: This well is currently shut in Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion, install a new 3-1/2” completion BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross/ Pipe Ram MIT results: MIT-T: N/A (Leaks identified at 7,790’ RKB & 7,877’ RKB) CMIT-TxIA: Passed to 2,500 psig 6/4/2022 MITOA: Passed to 1,800 psig 5/28/2017 IC-POT: Passed 10/29/2016 IC-PPPOT: Passed 10/29/2016 T-POT: Passed 1/21/2017 T-PPPOT: Passed 1/21/2017 MPSP: 2,318 psi using 0.1 psi/ft gradient Static BHP: 2,913 psi / 5,951’ TVD measured on 2/21/22 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 11,322.0 1L-28 4/9/2023 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated Pulled Patch & H2S reading 1L-28 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL - 1L-28, 1L-28L1, 1L-28L2, 1L-28L2-01 2/8/2008 osborl 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 40.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.70 34.8 6,546.4 3,585.9 40.00 L-80 BTCM PRODUCTION 7 6.28 32.0 11,116.8 5,795.8 26.00 L-80 BTCM WINDOW TO L2-01 4 3.50 11,315.0 11,325.0 5,973.4 LINER 3 1/2 2.99 10,944.1 11,769.0 6,378.5 9.30 L-80 EUE8rdMOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.0 Set Depth … 10,977.5 Set Depth … 5,683.9 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD 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) 30.0 30.0 0.25 HANGER 8.000 FMC GEN IV TUBING ANGER 3.500 553.3 552.4 6.59 NIPPLE 4.520 DS NIPPLE - MILLED OUT TO 2.82 ON 12/9/2007 CAMCO 2.820 4,258.0 2,614.7 63.40 GAS LIFT 6.018 CAMCO MMM 2.920 7,197.4 3,864.4 64.84 GAS LIFT 6.018 CAMCO MMM 2.920 9,051.4 4,656.1 64.46 GAS LIFT 6.018 CAMCO MMM 2.920 10,316.6 5,233.7 55.55 GAS LIFT 6.018 CAMCO MMM 2.920 10,835.8 5,575.7 42.08 GAS LIFT 6.018 CAMCO MMM 2.920 10,912.1 5,633.2 40.10 NIPPLE 4.540 'W' NIPPLE SELECTIVE PROFILE CAMCO 2.813 10,951.7 5,663.7 39.06 SEAL ASSY 3.500 80-40 GBH-22 SEAL ASSEMBLY w/LOCATOR BAKER 3.000 10,976.5 5,683.1 38.34 SHOE 3.500 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,790.0 4,118.0 64.03 LEAK - TUBING TBG LEAK IDENTIFIED AT ~7790' RKB BY EL LDL 5/29/2022 2.992 7,877.0 4,156.0 64.53 LEAK - TUBING TBG LEAK IDENTIFIED BETWEEN 7877' AND 7890' RKB BY EL PEAK HOLE FINDER 6/26/2022 2.992 11,321.0 5,969.8 27.38 PATCH KB LOWER PACKER ASSEMBLY MID-ELEMENT AT 11366'. TOP OF PACKER AT 11359', PACKER TOTAL LENGTH = 17.71'. RUN BAKER UPPER KB WHIPSTOCK PACKER WITH MID ELEMENT AT 11325'. TOP OF ASSEMBLY AT 11321.5' AND BOTTOM OF ASSEMBLY AT 11329' - ORIENTED TO 11.7 DEG RIGHT OF HIGH SIDE WITH WPP TOOL BAKER 12/29/2007 1.812 11,400.0 6,040.3 26.35 PLUG WRP, WRP PULLING TOOL set 9/25/06-STUCK IN PLACE 9/15/2006 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) 4,258.0 2,614.7 63.40 1 GAS LIFT OV RK 1 1/2 0.0 5/4/2022 0.250 7,197.4 3,864.4 64.84 2 GAS LIFT DMY RK 1 1/2 0.0 1/16/2017 0.000 9,051.4 4,656.1 64.46 3 GAS LIFT OPEN OPEN 1 1/2 0.0 6/3/2022 0.000 10,316.6 5,233.7 55.55 4 GAS LIFT DMY RK 1 1/2 0.0 11/15/2010 0.000 10,835.8 5,575.7 42.08 5 GAS LIFT DMY RK 1 1/2 0.0 5/14/2017 EXT PKIN G 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) 10,944.1 5,657.9 39.28 PACKER 5.937 ZXP LINER TOP PACKER BAKER 4.375 11,668.3 6,285.5 22.74 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,295.0 11,320.0 5,946.8 5,968.9 C-4, 1L-28 6/22/2000 6.0 APERF 2.5" HSD, 60° phasing 11,334.0 11,364.0 5,981.4 6,008.1 C-4, C-3, C-1, 1L -28 3/19/2000 4.0 APERF 2.5" HSD, 60° phasing 1L-28, 6/13/2023 3:02:52 PM Vertical schematic (actual) LINER L1; 11,324.3-13,150.0 LINER; 10,944.1-11,769.0 FLOAT SHOE; 11,766.9- 11,769.0 FLOAT COLLAR; 11,701.8- 11,702.9 LANDING COLLAR; 11,668.3- 11,669.2 IPERF; 11,518.0-11,538.0 FRAC; 11,518.0 PLUG; 11,400.0 SLOTS; 11,345.0-11,376.0 APERF; 11,334.0-11,364.0 PATCH; 11,321.0 FRAC; 11,295.0 WINDOW TO L2-01; 11,315.0- 11,325.0 DEPLOY; 11,324.3-11,325.7 APERF; 11,295.0-11,320.0 REFRAC; 11,295.0 PRODUCTION; 32.0-11,116.8 FLOAT SHOE; 11,115.4- 11,116.8 FLOAT COLLAR; 11,029.3- 11,030.6 SHOE; 10,976.5 SBE; 10,964.7-10,977.5 SEAL ASSY; 10,951.7 HANGER; 10,958.0-10,964.7 PACKER; 10,944.1-10,958.0 NIPPLE; 10,912.1 GAS LIFT; 10,835.8 GAS LIFT; 10,316.6 GAS LIFT; 9,051.4 LEAK - TUBING; 7,877.0 LEAK - TUBING; 7,790.0 GAS LIFT; 7,197.4 SURFACE; 34.8-6,546.4 FLOAT SHOE; 6,544.7-6,546.4 FLOAT COLLAR; 6,470.2- 6,471.7 GAS LIFT; 4,258.0 NIPPLE; 553.3 CONDUCTOR; 40.0-115.0 HANGER; 34.8-36.7 HANGER; 30.0 KUP PROD KB-Grd (ft) RR Date 11/23/199 9 Other Elev… 1L-28 ... TD Act Btm (ftKB) 11,770.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295100 Wellbore Status PROD Max Angle & MD Incl (°) 66.56 MD (ftKB) 2,336.25 WELLNAME WELLBORE1L-28 Annotation Last WO: End DateH2S (ppm) 130 Date 3/24/2022 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,518.0 11,538.0 6,147.3 6,165.7 A-5, 1L-28 12/19/1999 4.0 IPERF 2.5" HSD, 180° phasing Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,518.0 11,538.0 1 FRAC 2/12/2000 0.0 0.00 0.00 11,295.0 11,364.0 2 FRAC 5/7/2000 0.0 0.00 0.00 11,295.0 11,320.0 1 REFRAC 11/12/2006 0.0 0.00 0.00 1L-28, 6/13/2023 3:02:54 PM Vertical schematic (actual) LINER L1; 11,324.3-13,150.0 LINER; 10,944.1-11,769.0 FLOAT SHOE; 11,766.9- 11,769.0 FLOAT COLLAR; 11,701.8- 11,702.9 LANDING COLLAR; 11,668.3- 11,669.2 IPERF; 11,518.0-11,538.0 FRAC; 11,518.0 PLUG; 11,400.0 SLOTS; 11,345.0-11,376.0 APERF; 11,334.0-11,364.0 PATCH; 11,321.0 FRAC; 11,295.0 WINDOW TO L2-01; 11,315.0- 11,325.0 DEPLOY; 11,324.3-11,325.7 APERF; 11,295.0-11,320.0 REFRAC; 11,295.0 PRODUCTION; 32.0-11,116.8 FLOAT SHOE; 11,115.4- 11,116.8 FLOAT COLLAR; 11,029.3- 11,030.6 SHOE; 10,976.5 SBE; 10,964.7-10,977.5 SEAL ASSY; 10,951.7 HANGER; 10,958.0-10,964.7 PACKER; 10,944.1-10,958.0 NIPPLE; 10,912.1 GAS LIFT; 10,835.8 GAS LIFT; 10,316.6 GAS LIFT; 9,051.4 LEAK - TUBING; 7,877.0 LEAK - TUBING; 7,790.0 GAS LIFT; 7,197.4 SURFACE; 34.8-6,546.4 FLOAT SHOE; 6,544.7-6,546.4 FLOAT COLLAR; 6,470.2- 6,471.7 GAS LIFT; 4,258.0 NIPPLE; 553.3 CONDUCTOR; 40.0-115.0 HANGER; 34.8-36.7 HANGER; 30.0 KUP PROD 1L-28 ... WELLNAME WELLBORE1L-28 1L-28 Proposed RWO Completion COMPLETION INFO OD (in) Nom. ID (in) MD (ft RKB) TVD (ft RKB) Weight (lb/ft)Grade Thread Conductor 16" 15.06" 115 115 62.58 H-40 WELDED Surface 9-5/8" 8.7" 6546 3586 40 L-80 BTCM Production/Interm ediate 7" 6.28" 11117 5796 26 L-80 BTCM Liner 3-1/2" 2.99" 11769 6379 9.3 L-80 EUE 8rd Mod Tubing 3-1/2" 2.99" 10978 5684 9.3 L-80 EUE 8rd Mod Created by: Leslie Manning 8.27.2024 PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8RD Mod Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3,438' RKB, 5,555' RKB, & TBD (as deep as possible above packer) 3.5" x 7.0" Packer @ xxxx' RKB (4" ID) 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker 5" x 7" ZXP LT Packer 3-1/2" 9.3# EUE 8rd Mod Liner Baker Upper KB Whipstock Packer CTD Laterals (L1, L2, L2-01) Fish: 3-1/2" WRP & WRP Pulling Tool (set stuck in place) 9-5/8" Surface Casing 7" Production/Intermediate Casing 16" Conductor A-sand perfs: 11,518' - 11,538' RKB C-Sand Perfs: 11,334' - 11,364' RKB 11,295' - 11,320' RKB WRP 3-1/2" Liner CTD Laterals 3-1/2" Tubing 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. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-29_22027_KRU_1L-28_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22027 KRU 1L-28 50-029-22951-00 Caliper Survey w/ Log Data 29-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:199-098 T36684 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 09:41:30 -08'00' STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIV0ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations U Fracture Stimulate LJ Pull Tubing LI Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 2 Re-enter Susp Well ❑ Tubing patch El 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc Development ❑., Exploratory ❑ 199-0980 3.Address: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic ❑ Service ❑ 6.API Number: 50-029-022951-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25660 KRU 1L-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11770 feet Plugs measured none feet true vertical 6379 feet Junk measured none feet Effective Depth measured 11770 feet Packer measured 10952 feet true vertical 6379 feet true vertical 5664 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 16 115' 115' Surface 6512' 9 5/8 6547' 3586' Intermediate RECEIVED Production 11085' 7 11117' 5796' Liner 825' 3 1/2 11769' 6378' j U N 1 3 2017 Perforation depth Measured depth 11295'-11538' feet AOGC ° True Vertical depth 5947'-6166' feet � Tubing(size,grade,measured and true vertical depth) 3 1/2", L-80, 10978'MD,5684'TVD 22'Retrievable patch from 10876'-10898'MD Packers and SSSV(type,measured and true vertical depth) SSSV Nipple Camco DS nipple 553'MD 552'TVD Seal Assembly Baker 80-40 GBH-22 10952'MD 5664'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED .+IJt 242011 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations EExploratory ❑ Development❑., Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Brent Rogers Authorized Title: Well Integrity Supervisor Contact Email: n1617@cop.com Authorized Signature: Date:06/09/17 Contact Phone: 659-7224 - (7L 7/y- `1 Form 10-404 Revised 4/2017Submit Original Only r6/7 RBDMS 0 7JUN 1 4 2017 • • `. • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUN 1 3 2017 AOGCC June 9, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Development KRU well IL-28 (PTD 1990980). The report is for a tubing patch that was set to repair a leak above the Seal Assembly. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • Date Event Summary 05/13/17 BRUSH n' FLUSH DOWN TO 10,912' RKB; SET 2.813" MA-2 PLUG W/SINGLE SPARTEK GAUGE @ 10,912' RKB; PLUG FAILED TO PRESSURE TEST; W/ HOLEFINDER DETERMINE LEAK TO BE BETWEEN 10,912' & 9052' RKB; SET CATCHER/PT ASSEMBLY ON PLUG @ 10,912' RKB & PULLED DV @ 10,835' RKB. LRS CIRC'ING OUT W/290 BBLS CISW& 110 BBLS DIESEL (U-TUBE FP). IN PROGRESS. 05/16/17 MIRU. RUN 1: PERFORM BASELINE TEMPERATURE PASS DOWN TO NIP @ 10912' LRS START PUMPING 0.5 BBL/MIN. PERFORM STATION ABOVE PLUG. PLUG IS HOLDING. BEGIN LOG UP @ 120 LOOKING FOR LEAK. LEAK FOUND @ 10890'. PERFROM UP/DOWN PASSES OVER LEAK AT STATION SURVEYS @ 10900'/ 10895'/ 10890'/ 10885'. DROP DOWN AND PERFORM MAIN PASS TO SURFACE LOOKING FOR OTHER LEAKS. NO OTHER LEAKS FOUNDS. ***JOB IN PROGRESS*** 05/17/17 RUN 2: CALIPER, PERFORM REPEAT PASS OVER INTERVAL 10900' - 10750'. PERFORM MAIN PASS OVER INTERVAL 10900' -SURFACE. RDMO. 06/03/17 BRUSHED & FLUSHED PATCH SETTING AREA f/ 10,860' TO 10,910' RKB. SET 2.72" PIIP WITH AGGRESSIVE SLIPS (#CPP35126) MID ELEMENT @ 10,897.5' RKB. WITH TEST TOOL SET IN PKR CMIT T x IA TO 2500 (PASS). IN PROGRESS. CMIT TO 2500. PRE-T/I/O= 1500/1150/10. PSI UP WITH 22.2 BBLS. START= 2500/2250/110 15 MIN= 2400/2100/100 30 MIN= 2390/2000/90. CONFER W/PWS. RU TO IA. PRE T/I/O= 2350/1975/80. PSI UP w/3.1 BBLS. START= 2775/2450/120 15 MIN= 2750/2350/120 30 MIN= 2700/2300/120 45 MIN= 2675/2275/120. CONFER W/CO REP & PWS, GOOD. 06/04/17 SET UPPER 2.72" PIIP (#CPP35124), 17.52' SPACER PIPE, ANCHOR LATCH (#CPAL35051) MID ELEMENT @ 10,875.5' RKB. MIT TBG & CMIT T x IA(TEST SNAP LATCH) TO 2500 PSI. JOB COMPLETE. SET IN UPPER PKR @ 10,831' SLM (10,875.5' RKB). MITT TO 2500. PRE-T/I/O= 1450/300/0. PSI UP W/ 15.5 BBLS. START=2500/310/0. RD LRS TO RELOAD. 15 MIN= 2300/325/0. ***FAIL*** PRE-T/1/0= 1825/350/0. BUMP BACK UP w/4.6 BBLS. START=2500/375/0 15 MIN= 2325/400/0. PSI BACK UP w/0.6 BBLS. START= 2500/400/0 15 MIN= 2375/400/0 30 MIN= 2275/400/0. CONFER W/CO REP & PWS. RU LRS TO IA. CMIT TxIA TO 2500 psi (TO TEST SNAP LATCH). PSI UP w/5.2 BBLS TO PSI UP. START=2550/2500/140 15 MIN= 2575/2450/140 30 MIN= 2560/2450/130. CONFER W/CO REP & PWS. Executive Tubing leak at 10890'was patched with a 22' Quadco retrievable tubing patch. Patch integrity Summary was confirmed with passing MITT/CMITs. - KUP PROD • 1 L-28 4 Conor Phillips Of Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(1 MD(MB) Act Blm(5KB) �ornrmnpc 500292295100 KUPARUK RIVER UNIT PROD 66.56 2,336.25 11,770.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-28,6/6/20175x7:52 PM SSSV:NIPPLE 25 8/2/2015 Last WO: 11/23/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _..... _.___. _......_... Last Tag: 11,371.0 11/1/2007 Rev Reason:PULL PLUG 8 CATCHER,SET pproven 6/6/2017 HANGER;30.0 PATCHES Ili Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(Too)... Wt/Len(I...Grade Top Thread ii CONDUCTOR 16 15.062 40.0 115.0 115.0 52.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.697 34.8 6,546.4 3,585.9 40.00 L-80 BTCM Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) 'Sat Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.0 11,116.8 5,795.8 26.00 L-80 BTCM Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOW TO L2-01 4 3.500 11,315.0 11,325.0 5,973.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "A-AJCONDUCTOR;40.0-115.0 1..!)7 +✓..1�LINER 31/2 2.992 10,944.1 11,769.0 6,378.5 9.30 L-80 EUE8rdMOD Liner Details NIPPLE;553.3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) • 10,944.1 5,657.9 39.28 PACKER BAKER ZXP LINER TOP PACKER 4.375 10,958.0 5,668.6 38.88 HANGER BAKER HMC LINER HANGER 4.375 GAS LIFT;4,258.0 = 10,964.7 5,673.8 38.68 SBE BAKER 80-40 SBE 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 30.0 10,977.5 5,683.9 9.30 L-80 EUE8rdMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (in) SURFACE;34.8-6,548.4- A. 30.0 30.0 0.25 HANGER FMC GEN IV TUBING ANGER 3.500 553.3 552.4 6.59 NIPPLE CAMCO DS NIPPLE-MILLED OUT TO 2.82 ON 2.820 12/9/2007 GAS LIFT;7,197.4 10,912.1 5,633.2 40.10 NIPPLE 'CAMCO'W NIPPLE SELECTIVE PROFILE 2.813 10,951.7 5,663.7 39.06 SEAL ASSY 'BAKER 80-40 GBH-22 SEAL ASSEMBLY w/LOCATOR 3.000 GAS LIFT;9,051.4 10,976.5 5,683.1 38.34 SHOE 3.000 ■ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc/ Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) 10,875.0 5,605.0 41.04 PATCH 2.72"PIIP(#CPP35124),SPACER PIPE,ANCHOR 6/4/2017 1.610 GAS LIFT;10,318.6 LATCH(#CPAL35051/22.88'OAL/1.61"ID) 10,897.0 5,621.7 40.48 PATCH 2.72"PIIP w/AGGRESIVE SLIPS(#CPP35126/ 6/3/2017 1.625 4.01'OAL/1.625"ID) 11,321.0 5,969.8 27.38 PATCH BAKER KB LOWER PACKER ASSEMBLY MID- 12/29/2007 1.812 GAS LIFT;10,835.8 ELEMENT AT 11366'.TOP OF PACKER AT 11359', PACKER TOTAL LENGTH=17.71'.RUN BAKER UPPER KB WHIPSTOCK PACKER WITH MID ELEMENT AT 11325'.TOP OF ASSEMBLY AT PATCH;10,875.0 11321.5'AND BOTTOM OF ASSEMBLY AT 11329' -ORIENTED TO 11.7 DEG RIGHT OF HIGH SIDE WITH WPP TOOL PATCH;10,8970 1 I 11,400.0 6,040.3 26.35 PLUG WRP set 9/15,WRP PULLING TOOL set 9/252006- 9/15/2006 STUCK IN PLACE NIPPLE;10,912.1 1rrr� Perforations&Slots Shot 11E; Dens Top(ND) Bim(TVD) (shots/f ,, Top(ftKB) Btm(ftKB) (ftKB) (MB) Zone Date t( Type Corn O•g• r 11,295.0 11,320.0 5,946.8 5,968.9C-4,1L-28 6/22/2000 6.0 APERF 2.5"HSD,60 deg I"1.�f; phasing SEAL ASSY;10,951.7 I - - 11,334.0 11,364.0 5,981.4 6,008.1 C-4,C-3,C-1, 3/19/2000 4.0 APERF 2.5"HSD,60 deg 1L-28 phasing SHOE;10,976.5 - - 11,518.0 11,538.0 6,147.3 6,165.7 A-5,1L-28 12/19/1999 4.0 IPERF 2.5"HSD,180 deg phasing Stimulations&Treatments Proppant Designed(ib) Proppant In Formation(Ib) Date PRODUCTION;32.0-11,116.8 2/12/2000 Stimulations&Treatments REFRAC;11,295.0 , 1 , APERF;11,295.0-11,320.0 Illy Vol Clean Pump Stg# Top(MB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 11,518.0 11,538.0 202/2000 Proppant Designed(Ib) Proppant In Formation(Ib) Date I 5/7/2000 WINDOW TO L2-01;11,315.0- I Stimulations&Treatments 11,325.0 Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) FRAC;11,295.0 1 11,295.0 11,364.0 5/7/2000 PATCH;11,321.0, • Proppant Designed(Ib) Proppant In Formation(Ib) Date APERF;11,334.0-11,364.0 11/12/2006 SLOTS;11,345.0-11,376.0 Stimulations&Treatments 1 Vol Clean Pump ' Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) I 1 11,295.0 11,320.0 11/12/2006 Mandrel Inserts St ali PLUG;11,400.0 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com FRAC;11,518.0 1 4,258.0 2,614.7 CAMCO MMM 11/2 GAS LIFT OV R-20 0.188 0.0 1/16/2017 IPERF;11,518.0-11,536.0 I 2 7,197.4 3,864.4"CAMCO MMM 11/2 GAS LIFT DMY R-20 0.000 0.0 1/16/2017 3 9,051.4 4,656.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK - 0.000' 0.0 1/15/2017 4 10,316.6 5,233.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/15/2010 5 10,835.8 5,575.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/14/2017 EXT PKIN G LINER;10,944.1-11,769.0 LINER L1;11,324.3-13,150.0, KUP PROD • 1 L-28 ma ConocoPhillips aWala Alaska.Inc. �ts+�,ri✓npi� x IL-28,6/6/2017 5:27:53 PM Vertical schemacc(actual) HANGER;30.0 • m' Or--' Notes:General&Safety End Date Annotation 14J ,{p 2/8/2008 NOTE:MULTI-LATERAL WELL-1L-28,1L-28L1,1L-28L2,1L-28L2-01 J.�� 1/6/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CONDUCTOR;40.0-115.0 ' NIPPLE;553.3 GAS LIFT;4,258.0 SURFACE;34.8-6,546.4-• GAS LIFT;7,197.4 GAS LIFT;9,051.4 1 GAS LIFT;10,316.6 GAS LIFT;10,835.8 PATCH;10,875.0 PATCH;10,897.0 NIPPLE;10,912.1 �I 1E pp ;E SEAL ASSY;10,951.7 II: II. SHOE;10,976.5 I PRODUCTION;32.0-11,116.8 REFRACT 11,295.0 APERF;11,295.0-11,320.0 WINDOW TO L2-01;11,315.0- 11,325.0 FRAC;11,295.0 PATCH;11,321.0, i APERF;11,334.0-11,364.0 j SLOTS;11,345.0-11,376.0 liE PLUG;11,400.0 FRAC;11,518.0 !PERF;11,518.0-11,538.0 LINER;10,944.1-11,769.0 LINER L1;11,324.3-13,150.0+ STATE OF ALASKA + ALA,OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations H Fracture Stimulate H Pull Tubing H Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑., Re-enter Susp Well ❑ Other: Bradenhead repair ❑., 2.Operator ConocoPhillips Alaska, Inc. 4.Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑., Exploratory ❑ 199-098 3.Address: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic ❑ Service ❑ 6.API Number: 50-029-22951-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025660 KUPARUK RIV UNIT 1L-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A KUPARUK RIVER UNIT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 11770' feet Plugs measured 11,400' fe EC E'V E D true vertical 6379' feet Junk measured None feet MAY Effective Depth measured 11,400' feet Packer measured 10,952' feet ,y'Af 3 0 201 7 true vertical 6040 feet true vertical 5,664' feet ACC Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 75 16 115 112 N/A N/A Surface 6512 9.625 6546 3586 N/A N/A Intermediate N/A N/A N/A N/A N/A N/A Production 11085 7 11117 5796 N/A N/A Liner 825 3.5 11769 6379 N/A N/A Perforation depth Measured depth 11295-11518 feet True Vertical depth 5947-6166 feet Tubing(size,grade,measured and true vertical depth) 3.5,L-80,10,978'MD,5,664'TVD Packers and SSSV(type,measured and true vertical depth) Baker ZXP liner top packer, 10,944'MD,5658'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED ',,,,q, 0; 1 i ri 17 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run H 16.Well Status after work: Oil E Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Roger Mouser Contact Name: Roger Mouser Authorized Title: NSK Well Integrity Field Supervisor Contact Email: N1927@conocophillips.com Authorized Signature:i/Ll/ieitiv./A---7 Date: 5 I-/9- Contact Phone: 907-659-7506 ten- . YI/ p 2017 Form 10-404 Revised 4/2017 /( i/( 1 RBDMS �V MAI 3 1 Submit Original Only • • • Annular Communication History 1L-28 1L-28 was noted as having minor SCxAtmosphere communication on 10/29/2016. Communication repaired and Pressure tested by 5/28/17. Date Comment 5/28/17 (MISC)MITOA POST BRAIDEN HEAD REPAIR PASSED TO 1800 PSI. Initial T/I/O=SI vac/vac/0+ Pressured up OA to 1000 psi with 1.17 bbls T/I/O=vac/vac/1000. 15 min T/I/O=vac/vac/980(-20 psi).No signs of leaks. 30 min T/I/O=vac/vac/980(same). Pressured OA to 1800 psi with 1.22 bbls. 15 min T/I/O=vac/vac/1745 (-55 psi). 30 min T/I/O=vac/vac/1740(-5 psi).Bled OA 10 minutes(fluid)to 0 psi. Final T/I/O=SI vac/vac/0+. 5/27/17 Inspection of BH seal weld- by Kakiviik(Passed). 5/26/17 (MISC) STARTER HEAD REPAIR(COMPLETE). Welders completed 3 weld pass around starter head and welded old leaking conductor welds. Electricians re-wrapped beads and welds w/blankets to start slow 12 hour cool down period. Monitored well for 1 hr to ensure no problems post weld. Final T/I/O=SI VAC/VAC/2. 5/21/17 (SEC)Prep well for starter head repair, CDDT TxIA Passed to 0 psi,Load OA complete,OA FL @—32". 12/21/16 STARTER HEAD REPAIR PREP Buffed and cleaned starter head and assisted Kakivik with their UT and MT inspections. Bled OA to 0 psi in 45 min (charged liquid and gas). SI multiple times to allow gas to break out. Let OA breath for 1 hr. SI for 30 min BUR=T/I/O 265/1380/0+.Bled OA to 0 psi in 10 sec(gas). OA FL@28' 3 ft deep cellar(cellar has 2" of ice with 2" of H2O beneath it). 10/29/16 (AC EVAL) MITOA- FAILED DUE TO BRAIDEN HEAD LEAK @ 1500 PSI. 12 O'CLOCK POSITION. T POT- PASSED. T PPPOT- PASSED. IC POT- PASSED. IC PPPOT- PASSED. TIFL- PASSED.BLED OA FOR BUR-GAINED 1 PSI. IN 30 MINUTES. KUP PROD • 1 L-28 ConocoPhillips il° Well Attributes Max Angle&MD TD AIa'6)1 It1c. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,,_. r„rvupc 500292295100 KUPARUK RIVER UNIT PROD 66.56 2,336.25 11,770.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-20,1/20/2017 149:05 PM SSSV:NIPPLE 25 8/2/2015 Last WO: 11/23/1999 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation -Last Mod By End Date ........................................................__ _yg�B�y_ ....Last Tag: 11,371.0 11/1/2007 Rev Reason:GLV C/O pproven 1/20/2017 HANGER;30.0 -Sis -i Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 115.0 115.0 52.58 H-40 WELDED lik ) i, fr Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.697 34.8 6,546.4 3,585.9 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.0 11,116.8 5,795.8 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOW TO L2-01 4 3.500 11,315.0 11,325.0 5,973.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 10,944.1 11,769.0 6,378.5 9.30 L-80 EUE8rdMOD .A.A/CONDUCTOR;40.0-115.0. r..J,..II,. Liner Details NIPPLE;553.3IN Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 10,944.1 5,657.9 39.28 PACKER BAKER ZXP LINER TOP PACKER 4.375 -i 10,958.0 5,668.6 38.88 HANGER BAKER HMC LINER HANGER 4.375 10,964.7 5,673.8 38.68 SBE BAKER 80-40 SBE 4.000 GAS LIFT;4,258.0-1-4 Tubing Strings Tubing Description I String Ma...ID(in) Top(EKB) Set Depth(ft..Set Depth(TVD)(...Wl(lb/ft) Grade Top Connection TUBING 31/21 2.9921 30.01 10,977.51 5,683.91 9.301 L-80 I EUE8rdMOD Completion Details / Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inol(°) Item Des Com (in) 30.0 30.0 0.25 HANGER FMC GEN IV TUBING ANGER 3.500 SURFACE;34.8-8,546.4-+ 4. 553.3 552.4 6.59 NIPPLE CAMCO DS NIPPLE-MILLED OUT TO 2.82 ON 2.820 - 12/9/2007 GAS LIFT;7,197.4 10,912.1 5,633.2 40.10 NIPPLE CAMCO'W NIPPLE SELECTIVE PROFILE 2.813 10,951.7 5,663.7 39.06 SEAL ASSY -BAKER 60-00 GBH-22 SEAL ASSEMBLY w/LOCATOR 3.000 10,976.5 5,683.1 38.34 SHOE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;9,051.4 lop(ND) Top incl Top(kV(Et) (ftKO) (') Des Corn Run Date ID(in) 11,321.0 5,969.8 27.38 PATCH BAKER KB LOWER PACKER ASSEMBLY MID- 12/29/2007 1.812 ___ ELEMENT AT 11366'.TOP OF PACKER AT 11359', PACKER TOTAL LENGTH=17.71'.RUN BAKER UPPER KB WHIPSTOCK PACKER WITH MID GAS LIFT;10,316.6 ELEMENT AT 11325'.TOP OF ASSEMBLY AT 11321.5'AND BOTTOM OF ASSEMBLY AT 11329' -ORIENTED TO 11.7 DEG RIGHT OF HIGH SIDE WITH WPP TOOL 11,400.0 6,040.3 26.35 PLUG WRP set 9/15,WRP PULLING TOOL set 9/252006- 9/15/2006 GAS LIFT;10,835.8 E STUCK IN PLACE -- Perforations&Slots Shot NIPPLE;10,912.1 Dene Top(TVD) Btr11(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,295.0 11,320.0 5,946.8 5,968.9 C-4,1L-28 6/22/2000 ' 6.0 APERF 2.5"HSD,60 deg 3. t phasing 1,.aa,�i 11,334.0 11,364.0 5,981.4 6,008.1 C-4,C-3,C-1, 3/19/2000 4.0 APERF 2.5"HSD,60 deg 1L-28 phasing ri•l!' 11,518.0 11,538.0 6,147.3 6,165.7 A-5,1L-28 12/19/1999' 4.0 IPERF 2.5"HSD,180 deg SEAL ASSY;10,951.7 11 Am I phasing SHOE;10,976.5 a Stimulations&Treatments Proppant Designed(Ib) 1 Proppant In Formation(Ib) 1 Dale 2/12/2000 Stimulations&Treatments Min Top I Max Btm I Top(TVD) I Btm(TVD) I I Vol Clean I Vol Slurry Depth(ftKB) Depth(ftKB) (ftKB) (kKB) Stg 8 Date Stith/Treat Fluid Pump(bbl) (bbl) PR000CTION;32.0-11,118.8 11,518.0 11,538.0 6,147.3 6,165.7 1 2/12/2000 APERF;11,295.0-11,320.0 - Proppant Designed(Ib) 1 Proppant In Formation(lb) Date REFRAC;11,295.01 5/7/2000 r Stimulations&Treatments - _ _ Mm Top Max Btm Top(TVD) Btm(WO) Vol Clean Vol Sleep Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg# Date Stiml'reat Fluid Pump(bbl) (bbl) 11,295.0 11,364.0 5,946.8 6,008.1 1 5/7/2000 WINDOW TO L2-01;11,315.0- Proppant Designed(Ib) Proppant In Formation(Ib) Date t 11/12/2006 11,325.0 Stimulations&Treatments FRAC;11295.0 Min Top Max Btm Top(TVD) Btm(TVD) Vol Clean Vol Slurry PATCH;11,321.0, Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg# Date Slim/Treat Fluid Pump(bbl) l (bb APERF;11,334.0-11,384.0 11,295.0 11,320.0 5,946.8 5,968.9 1•11/12/2006 SLOTS;11,345.0-11,376.0 I Mandrel Inserts St all N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date ' Com 1 4,258.0 2,614.7 CAMCO MMM 1 1/2 GAS LIFT OV R-20 0.188 0.0 1/16/2017 2 7,197.4 3,864.4 CAMCO MMM 1 1/2 GAS LIFT DMY R-20 0.000 0.0'1/16/2017 3 9,051.4 4,656.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/15/2017 PLUG;11,400.04 10,316.6 5,233.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0.11/15/2010 FRAC;11,518.0 (PERF;11,518.0-11,538.0- I� _. 5 10,835.8 5,575.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/15/2010 Notes:General&Safety End Date Annotation 2/8/2008 NOTE:MULTI-LATERAL WELL-1L-28,1L-28L1,1L-28L2,1L-28L2-01 1/6/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 LINER;10,944.1-11,769.0 - LINER L1;11,324.3-13,150.01 • • • 7z 9 -c V C C V • OC C ++--' Y Q 'i v, .„ (v 0 c0 0,0 �c O ut Q T 2 v) v C- a p Q c(6 Q V v, O X ij dc -OO -U °' -,„..'' .., , , to C Q O U C +_ 4.4 , , t ts. 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 OCT 21 2015 AOGGC October 25, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 " 0 Ll;, Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. No cement was pumped. The corrosion inhibitor/sealant was pumped October 24, 2016. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 659-7506, if you have any questions. Sin rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/25/2016 1H-09,1L-28&3H-34 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1H-09 50029223450000 1930290 11.5" NA 11.5" NA 5.10 10/24/2016 ( 1 L-28 50029229510000 1990980 14.5 NA 14.5 NA 5.50 10/24/2016 3H-34 50103206430000 2111280 14" NA 14" NA 6.80 10/24/2016 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate Alter CasingF p Other Stimulate(— Change Approved Program I— Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Extend Conductor F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Developmen I7 Exploratory r 199-098 3.Address: 6.API Number: Stratigraphi ( Service (- P.O. Box 100360,Anchorage,Alaska 99510 50-029-22951-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL0025660 KRU 1L-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11770 feet Plugs(measured) 11400' true vertical 6379 feet Junk(measured) None Effective Depth measured 11400 feet Packer(measured) 10912, 11321, 11400 true vertical 6040 feet (true vertical) 5633,5970,6040 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 115 115' SURFACE 6512 9.625 6546 3586' PRODUCTION 11085 7 11117 5796' LINER 825 3.5 11769 6379' RECEIVED ' Perforation depth: Measured depth: 11295-11320, 11334-11364, 11518-11538 True Vertical Depth: 5947-5969,5981-6008,6147-6166 °� ' Et AO6CC Tubing(size,grade,MD,and TVD) 3.5,L-80, 10978 MD,5664 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE-MILLED OUT TO 2.82 ON 12/9/2007 @ 553 MD and 552 TVD NIPPLE-CAMCO'W'NIPPLE SELECTIVE PROFILE @ 10912 MD and 5633 TVD PATCH-BAKER KB LOWER PACKER ASSEMBLY MID-ELEMENT AT 11366'. TOP OF PACKER AT 11359',PACKER PLUG-WRP SET 9/15,WRP PULLING TOOL SET 9/25/2006-STUCK IN PLACE @ 11400 MD and 6040 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): 3CANWE� i it/, ')n' _ Treatment descriptions including volumes used and final pressure: /� 'L 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory I- Development F Service r Stratigraphic (- Copies of Logs and Surveys r 16.Well Status after work: Oil F Gas r WDSPL E Printed and Electronic Fracture Stimulation r GSTOR E WINJ r WAG r GINJ r SUSP I- SPLUG I- 17. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-397 Contact Roger Winter Email: n1927conocophillips.com Printed Name Roger Winter Title: NSK Well Integrity Field Supervisor /// Signature ei,� (7t,„ Phone: 659-7506 Date ?A:9 / /c /C Form 10-404 Revised 5/2015 `� / / RBDMS W S 2 8 1016 Submit Original Only • • ConocoPhillips RECOVEto Alaska P.O. BOX 100360 )E P 2 7 2016 ANCHORAGE,ALASKA 99510-0360 G September 23, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1L-28, PTD 199-098 conductor extension. Please contact me at 659-7506 or MJ Loveland at 659-7043 if you have any questions. Sincelyerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor pill r* 'ykyolie ... .� V t V O t V � r r S" a t •. T r �t • TT ,,, F TM1:. xx 4 1 L-28 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/16 Weld 8" conductor extension onto conductor with 16" 62# .375 pipe. • • VOF T� h• -=->a ��\�yyy�sA THE STATE Alaska Oil and Gas F -- pf Conservation Commissi®n : ALASKA th _;_ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Maisk907.201-3572 ' Off,A, °gY+ Fax: 907.276.7542 www.aogcc.alaska.gov Roger Winter SCANNED JAN 1 3 2017 NSK Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-28 Permit to Drill Number: 199-098 Sundry Number: 316-397 Dear Mr. Winter: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1:1944-d-i/L- Cathy . Foerster Chair 141"— DATED this Q of August, 2016. RBDMS AUG 1 5 2016 • • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 8 2O1 APPLICATION FOR SUNDRY APPROVALS 'f'l /,6 20 AAC 25.280 AOGC 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well E Operations shutdown r Suspend E Perforate r Other Stimulate E Pull Tubing E Change Approved Program r Plug for Redrill r Perforate New Pool E Re-enter Susp Well E Alter Casing IF F• Other:Extend Conductor F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Developmen F • 199-098 - 3.Address: 6.API Number: Stratigraphi r Service E P.O.Box 100360,Anchorage,Alaska 99510 50-029-22951-00. 7.If perforating, / 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No F / KRU 1 L-28 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025660 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11770 ' 6379 - 11400' • 6040' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 115' 115' SURFACE 6512 9 5/8 6546' 3586' PRODUCTION 11085 7 11117' 5796' LINER 825 31/2 11769' 6379' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11295-11320,11334-11364,11518-11538' 5947-5969,5981-6008,6147-6166 3.5 L-80 10978 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) • NIPPLE-CAMCO DS NIPPLE-MILLED OUT TO 2.82 ON 12/9/2007 MD=553 TVD=552 , NIPPLE-CAMCO'W'NIPPLE SELECTIVE PROFILE MD=10912 TVD=5633 - PLUG-WRP SET 9/15,WRP PULLING TOOL SET 9/25/2006-STUCK IN PLACE MD=11400 TVD=6040 % 12.Attachments: Proposal Summary 17 WeliBore Schematic F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development - F Service r 14.Estimated Date for 15. Well Status after proposed work: 09/28/16 OIL F WINJ r WDSPL E Suspended E Commencing Operations: 16.Verbal Approval: Date: GAS E WAG r GSTOR E SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Roger Winter Printed Name Roger Winter Phone: 659-7506 Email: n1927@conOCOphillips.com C Title: NSK Well Integrity Field Supervisor Signature tek2,0Date: 7 (967/, Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ILO - 3g' Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance E Other: Witf-- 8 r Post Initial Injection MIT Req'd? Yes r No ,� ' Spacing Exception Required? Yes r No ll/ Subsequent Form Required: /0 -40 APPROVED BY Approved by: % COMMISSIONER THE COMMISSION Date:Sit/6 {^J GuiNiAdE Submit Form and Form 10-403 Revised 11/2015 Approved application is al /ice 1I of approval. entsin Du '43te 1` RBi n c �,1(.� 5 70, Iry . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 11-28, PTD 199-098 conductor extension. Please contact me at 659-7506 or MJ Loveland at 659-7043 if you have any questions. Sinc ely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska, Inc. Kuparuk Well 1L-28 (PTD 199-098) SUNDRY NOTICE 10-403 APPROVAL REQUEST 07-26-16 This application for Sundry approval for Kuparuk well 1L-28 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • ✓ KUP PROD • 1L-28 CQCIOCoPIiIlipS Well Attributes Max Angle&MD TO ; • Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) Me(ftKB) Act Btm(ftKB) fix,,,,ps 500292295100 KUPARUK RIVER UNIT PROD 66.56 2,336.25 11,770.0 ••• Comment H2S(pent) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1L-28,7/6/2016124658 AM --SSSV:NIPPLE 190 8/14/2012 Last WO: 11/23/1999 Vertical schematic:(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._..._... _............_.. ..._..Last Tag: 11,371.0 11/1/2007 Rev Reason:GLV C/O pproven 7/6/2016 HANGER;30.0 ' a -Casing Strings �. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 115.0 115.0 52.58 H-40 WELDED i' 3 'Ilde Casing Description OD(in) ID(in) Top(ftK8) Set Depth(ftKB) Sat Depth(TVD)...Wt/Len(I...Grade Top Thread i ' SURFACE 9 5/8 8.697 34.8 6,546.4 3,585.9 40.00 L-80 BTCM Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Vii.Il PRODUCTION 7 6.276 32.0 11,116.8 5,795.8 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOW TO L2-01 4 3.500 11,315.0 11,325.0 5,973.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 3 1/2 2.992 10,944.1 11,769 0 6,378 5 9 30 L-80 EUE8rdMOD .ANCONDUCTOR;40.0-115.0- Liner Details NIPPLE;553.3 N in IID Top(ftKB) Top(ND)(ftKB) Top Incl(7 Item Des Corn (in) 10,944.1 5,657.9 39.28 PACKER BAKER ZXP LINER TOP PACKER 4.375 10,958.0 5,668.6 38.88 HANGER BAKER HMC LINER HANGER 4.375 I10,964.7 5,673.8 38.68 SBE BAKER 80-40 SBE 4.000 CAS LIFT;4258.E ,Est Ti Tubing Strings r... _3y Tubing Description IString Ma...I ID(in) I Top(ft6B) I Set Depth(ft..I Set Depth(TVD)(...I Wt(ib/ft) (Grade I Top Connection TUBING 1 31/2 2.992 30.0 1097751 5,6839 9.30 L-80 EUE8rdMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(°) Item Des Com I (in) 30.0 30.0 0.25 HANGER FMC GEN IV TUBING ANGER 3.500 SURFACE;34.8-6,546.4-4, S; 553.3 552.4 6.59 NIPPLE CAMCO DS NIPPLE-MILLED OUT TO 2.82 ON 2.820 1t 12/9/2007 10,912.1 5,633.2 40.10 NIPPLE CAMCO'W NIPPLE SELECTIVE PROFILE 2.813 GAS LIFT;7,197.4 - 10,951.7 5,663.7 39.06 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY w/LOCATOR 3.000 10,976.5 5,683.1 38.34 SHOE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) �� _ GAS LIFT;9 051.4 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) 11,321.0 5,969.8 27.38 PATCH BAKER KB LOWER PACKER ASSEMBLY MID- 12/29/2007 1.812 ELEMENT AT 11366'.TOP OF PACKER AT 11359', PACKER TOTAL LENGTH=17.71'.RUN BAKER UPPER KB WHIPSTOCK PACKER WITH MID GAS LIFT;10,316.6 I 1ELEMENT AT 11325'.TOP OF ASSEMBLY AT 11321.5'AND BOTTOM OF ASSEMBLY AT 11329' -ORIENTED TO 11.7 DEG RIGHT OF HIGH SIDE WITH WPP TOOL 11,400.0 6,040.3 26.35 PLUG WRP set 9/15,WRP PULLING TOOL set 9/25/2006- 9/15/2006 GAS LIFT;10635.8 I 41 STUCK IN PLACE Perforations&Slots 111111116h1: Shot NIPPLE;10,912.1 Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com All 11,295.0 11,320.0 5,946.8 5,968.9 C-4,1L-28 6/22/2000 6.0 APERF 2.5"HOD,60 deg 3 I phasing r 11,334.0 11,364.0 5,981.4 6,008.1 C-4,C-3,C-1, 3/19/2000 4.0 APERF 2.5"HSD,60 deg I kr 1L-28 phasing SEAL ASSY;10,951.7 ,�.d 11,518.0 11,538.0 6,147.3 6,165.7 A-5,1L-28 12/19/1999 4.0 (PERF 2.5"HSD,180 deg ItII.I phasing SHOE;10,976.5 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 11,518.0 11,538.0 6,147.3 6,165.7 FRAC 2/12/2000 'A'SAND FRAC 11,295.0 11,364.0 5,946.8 6,006.1 FRAC 5/7/2000 'C'SAND FRAC PRODUCTION;32.0-11,116.8 • 11,295.0 11,320.0 5,946.8 5,968.9 REFRAC 11/12/200 PUMPED C SAND FRAC AS DESIGNED.PLACED 6 1850009 16/20 CARBOLITE IN FORMATION,10 APERF;11,295.0-11,320.0 - PPA ON PERFS. REFRAC;11,295.0 r- Mandrel Inserts St ' - ati on Top(TVD) Valve Latch Port Size TRO Run il N. Top(ftKB)i (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com WINDOW 70/2-01;11,315b- L 1 4,258.0 2,614.7 CAMCO MMM 11/2 GAS LIFT GLV R-20 0.188 1,274.0 10/14/2013 11,325.0 FRAC;11,295.0 2 7,197.4 3,864.4 CAMCO MMM 11/2 GAS LIFT GLV R-20 0.188 1,273.0 10/14/2013 PATCH;11,321.0-, I 3 9,051.4 4,656.1 CAMCO MMM 1 1/2 GAS LIFT OV RK 0.250 0.0 7/3/2016 APERF;11,334.0-11,364.0 ( 4 10,316.6 5,233.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/15/2010 SLOTS;11,345.0-11,376.0 1 5 10,835.8 5,575.7 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/15/2010 Notes:General&Safety End Date Annotation _41 2/8/2008 NOTE:MULTI-LATERAL WELL-1L-28,1L-28L1,1L-28L2,1L-28L2-01 PLUG;11,400.0 1/6/2009 -NOTE:VIEW SCHEMATIC w/Alaska Schematic9 0 FRAC;11,518.0 (PERF;11 �_ _I LINER;10,944.1-11,769.0 LINER L1;11,324.3-13,150.01 Pages NOT Scanned in this Well History File XHVZE This pa§e identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~f-~Oc)' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Zr/~ ~'/-~; ~/ ~' Poor Quality Original- Pages: Other- Pages: DIGITAL DATA El Diskettes, No. Other, No/Type -OVERSIZED Logs of various kinds Other COMMENT5: Scanned bO~dred'D;r~,, · TO RE-SCAN Nalhan Lowell Date.'~ Notes: D,-, ~,-,.,~.-,n,-,H hr/' ~:z~,,o.~ Mi~..~l 13~retha Nathan Lowell Date: /s/ 11 /02/07 NO.4356 .;~~i~~, Schlumberger -DCS '' ' 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 c '~ ~~ ~ i ~~, ~~~ ~~~ ~' ~ ~ Field: Kuparuk Well Job # Log Description Date BL Color CD 1D-103 11837528 INJECTION PROFILE 10/27/07 1 1L-28 11839680 PRODUCTION PROFILE 'f0128107 1 2N-310 11839674 DDL '- ~ - 90130!07 1 1C-190 11837524 INJECTION PROFILE (~j ~"- (~.' 10120/07 1 2V-16 11837526 PRODUCTION PROFILE - 'y"' 10/24107 1 1H-04 11837527 INJECTION PROFILE Z 10/25/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~. 4-== UI!L~LL LQG TF~A~1/Sl~/I/T7"~4L FroActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MT'T) The technical data listed below is being submitted herewith. Please acknov~edge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, tnc. Attn: Robert A. Richey 130 West International Airport Road suite c Anchorage, AK 99518 Fax: (907) 245.8951 1 } Caliper Report 0-Nov-07 1 L-28 2) Signed : y. ~,m Print Name: ~ i . ` ~ p ..~~' ~(~,~_ ~~} - U9~ ~ ~~~~(5 1 Report / Eta 50-029-22951-00 - ;~ Date : `' ,j ti PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT lie SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-NWL: ~r~s~~s~~ar~m~Cr.~~e~~r?f'~~9 ~~TT WEBSR'E: ~rflrrr.~~aao~^~i~~..~~e~s D:VHaster_CopY_~_PDSANG20~act2_Wmd\QistrfbufionlTrans~aittal_Sheets\Transndt_Ouginal_Naw.doc ~ ~ Memory Multi-Finger Caliper S Log Results Summary Company: ConocoPhlllips Alaska, Inc. Welt: 1L-28 Log Date: November 1, 20t}7 Field: Kuparuk Log No.: 8646 State: Alaska Run No.: 1 API No.: 50-029-22951-00 Pipet Desc.: 3,5" 9.3 Ib. L-80 EUE 8rd Top Log Intvll.: Surface Pipet Use: Tubing & Liner Bot. Log lntvll.: 11,348 Ft. (MD) inspection Type : Corrosive & Mechanical Damage Inspection CQMMENTS This ca/iper data is lied into the Tubing Tail @ ?0,952' (Drills Depth). This tog was run to assess the condition of the tubing & liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tuning & liner logged is in good condition. There are no significant Watt Penetrations (excluding perforation intervals), areas of Cross Sectional Wall loss or I.D. restrictions recorded throughout the tubing and liner logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Paige of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRAl10NS No significant wall penetrations {>18°~) are recorded {excluding perforation intervals). MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall toss (>13%} are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. d ~ -t~9~f ~` t~ ~~1~ Field Engineer: K Miller Analyst: J. Thompson Witness: C. Kennedy ProActive Diagnostic Services, Inc. ,~ P.O. Box 1369, Stafford, TX 77491 Phone: (281) or (888) 565-9085 Fax: (281) 505-1369 E-mail: PDS'amemoryiog.com Prudhoe Bay Field Office Phone: (907) 059-2307 Fax: (907) 059-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-27.8' -11329.1') Well: 1 L-28 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: U5A Survey Date: November 1, 2007 ^ A pprox. Tool Deviation ^ Approx. Borehol e Profil e 1 50 -2 5 1527 100 3084 GLM 1 150 4655 ..-. ~ v ~ ~ E ~ ~ ._ Z 200 6215 c ~ g- w ~ GLM 2 250 7800 GLM 3 300 9380 GLM 4 GLM 5 350 10989 361 11329 0 5 0 1 00 Dam age Profile (% wall) / Tool Deviation (degr ees) Bottom of Survey = 361 • • PDS Report Overview -~ ~. Body Region Analysis Well: 1 L-28 Survey Date: November 1, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body +~ metal loss body 300 250 2 0 0 15 0 0 1 0 50 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of ~oints anal sed total = 375 pene. 0 257 loss 113 259 114 0 1 3 3 0 0 0 Damage Configuration (body ) 40 30 20 10 0 aulaled general hne ring ilOle/pOSS pining corrosion corrosion corrosion ible trole Number of 'oints dama ed total = 54 36 15 0 0 3 Damage Profile (% wall) ~ penetration body ,~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 361 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 9.3 ppf L-80 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: -LATION SHEET 1 L-2 8 Kuparuk ConocoPhillips Alaska Inc USA November 1, 2007 Joint No. Jt. Depth (Ft) Pe•n. I)I»c•t Ilns.) Pen. Body (Ins.) Pen. %~ 'v1c•t<rl Icss `,'-~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 -28 U 0.01 (~ U 2.9 PUP 1 -2 tt 0.0 4 ~ .97 1.1 3 tt 0.02 t3 4 2 94 UP 1.2 13 U .0 t3 i 2.94 PUP 1.3 ct 0.02 ~ u 2.93 PUP 2 25 U 0.02 t3 2.93 3 56 U 0.03 I1 I .92 4 87 t t 0.02 £~ s .96 5 118 a 0.03 12 a 2.95 6 150 t t 0.02 8 t, .96 7 181 ! t 0.02 s .95 8 212 (t 0. 2 9 4 2.9 243 a 0.02 7 3 .9 1 75 U 0.0 ~t ~~ 2.96 11 05 U 0.02 £~ 4 2.96 1 336 a 0.02 - ~ 2.95 13 368 a 0. 2 t3 -1 .94 14 99 tt 0.03 11 4 .96 1 431 U .0 7 3 .97 16 46 U 0.0 3 ~ .96 16.1 49 I t 0 U t t .81 DS Ni e 17 495 t) 0.02 £i 3 .96 18 5 6 U 0.02 ~~ s 2.93 19 557 a 0.02 tt _' 2.96 58 t? ;t ; 21 620 ~) 0.02 7 t 2.97 2 652 t) 0.02 ti ~ .95 23 682 tl 0.02 ti ~' 2.96 4 714 t) 3 1 U s .95 25 745 t) 0.02 7 4 2.96 26 776 t t 0.0 7 ~ 2.9 27 808 tt 0.03 12 ~ 2.93 8 839 U 0.02 i .95 29 870 U 0.02 i 4 2.96 30 901 It 0.02 ~ 4 .96 31 933 t) 0.02 9 4 2.96 32 65 C1 0.0 7 ~3 .96 33 996 U 0.02 ~) 1 2.94 34 102 7 U 0. 2 8 _' 2.97 35 1059 U 0.02 i 2.95 36 1090 U .03 11 .9 37 1122 (1 0.02 7 ~ 2.93 38 1153 U 0.02 ~) 3 2.96 39 1184 0 0.02 9 I 2.94 40 1216 U 0.02 9 U 2.94 41 1247 U 0.02 8 I 2.94 42 1278 U 0.02 9 I 43 1310 ~) 0.02 7 4 2.96 44 1339 t t 0.0 ~) 2.9 45 1370 a 0.03 1 u _' 2.95 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. )t. Depth (Ft.) I't~n. IlF>sei Ilrn.j Pen. Body (Ins.) I'crn. % Vtc~t.jl loss ",~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1402 I> 0.02 ~) 2.94 47 1433 u 0 02 ~ 1 2.95 48 1464 U 0. 2 t3 3 .95 hallow 'n 49 1496 t) 0.0 7 t~ 2.95 50 152 7 U 0.03 1 _' 2.96 51 1559 U 0. 2 ~) ; 2.94 5 1590 U 0.03 12 4 2.95 53 1621 ~) 0.02 ~) ~ 2.95 54 1653 U 0.02 ti ~ 2.95 55 1684 a 0. 2 t3 2 95 56 1714 t) 0.02 ~) ~1 3 57 1746 a 0.02 ~) 5 2.94 58 1777 t) 0.0 11 ~' .90 59 1808 I) 0.03 1 1 I 2. 1 60 1838 ~ I .0 ti 4 2.93 61 1870 U 2 ti 1 2.93 6 1 1 t).ut> 0 03 l I Z .93 63 193 U 0.03 13 5 2.92 Sh It orr s" n. 64 1964 U 0.02 t3 ~~ 2.95 65 1995 t) 0.02 ~) 2.92 66 2025 U 0.0 11 I .92 7 056 U 0.0 ~) ' .9 2088 tl 0.0 t3 1 2.92 6 2119 ~~ 0.02 ') 2 2.94 70 1 1 t) .03 1 1 1 91 71 2181 ~ ~ 0.02 I 2.93 72 21 U 0.04 14 I .92 h I ow corro ion. 73 2244 I) 0.02 ~) U 2.93 74 2274 U 0.02 9 2 .96 75 2306 l) 0.02 7 t) 2.92 7 2336 a 0.02 t3 U 2.94 77 2367 U 0.02 t3 ~' 2.91 78 2399 U 0.02 ~) ' 3 79 2430 U 0.02 ~) _' 2.94 80 2462 t) 0.02 ~~ _' 2 94 81 2493 II 0.02 ~) ? 2.95 8 5 3 a 0.02 ~) O .93 83 2554 ~) 0.02 7 I 2.94 84 2585 U 0.03 11 1 2. 3 85 2616 U 0.02 t3 I 2.94 86 2647 t~ 0 02 ~) I 2 87 2678 U 0.02 7 I) 2.93 8 2709 t1 0. 2 t3 U .93 89 2738 t) 0.02 f3 1 2.94 90 2770 U 0.0 ~) Z 2.94 91 2801 U 0.02 7 0 2.94 92 2832 a 0.02 ti ? 3 93 2864 I) 0.02 8 Z 2.94 94 895 ~) 0.02 `) .96 95 2927 ~~ 0.02 t3 ~ 2.96 Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Corr any: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. Jt. Depth (Ft.) I'cn. Uhs~~t (Ins.) Pen. Body (Ins.) I'en. % ti1e~t.~l loss ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2958 a 0.03 1 U ! .91 97 2990 t) 0.0 £3 .95 98 30 1 C) 0.0 7 .94 99 3 52 t) 0.03 1 U _' 2.9 1 3 4 t) 0.0 ~) 2.94 101 31 U 0.02 7 2. 4 102 3147 t) 0.02 t3 U .9 103 3177 U 0.02 ~) _' 2.95 Shallow ittin . 104 32 7 u 0.02 ~) ~ 2.95 105 3238 U 0.02 ~) ~ .94 106 3269 t) 002 9 ~' 2.96 107 3300 a 0.0 1 2.9 108 3330 tl 0.02 7 t) 2.9 109 3360 t~ 0 02 9 1 2.93 110 3391 U 0.02 ~~ 1 2.93 1 1 3422 t) .03 I2 2.94 11 3454 U 0. 2 7 i 2.93 113 3485 U 0.02 ti I .95 114 3 16 U 0.02 ~) .' .95 115 547 U 0.0 9 Z .93 116 3579 t ~ 0.0 ~) 3 2.93 117 3610 U 0.02 t3 1 2.93 118 3 0 t~ 0.0 9 ~' 2.94 119 3671 U 0.03 11 1 2.93 370 t) 0.0 i U .95 121 3734 a 0.02 i 3 2.95 1 3765 t ~ 0.02 7 ~ .93 123 3796 t) 0.02 t3 I 2.91 1 4 3827 a 0.02 i I 2. 3 125 3858 ~ ~ 0.02 t3 1 2.93 12 3889 tJ 0.0 t3 I 2.95 127 3921 t) 0.03 11 ,' 2.96 128 3951 U 0.03 11 ~ 9 129 3981 a 0.03 1 t) ~' 2.93 13 4012 ~) 0.03 1 i) ~ .93 131 4043 ~ ~ 0.03 l i 2.95 Shallow ittin . 132 4074 t) 0. 3 1:: -1 3 133 4106 n 0.03 12 1 2.94 13 413 7 U 0.03 1 1 1 2.91 135 4168 U 0.02 ti _' 2.93 135.1 4199 U.U3 .03 10 .94 PUP D osits. 135.2 4205 U 0 t) U N A GLM I n a 135.3 4215 t) 0.03 13 f, 2.96 PUP Shal o 'ttin . 136 4219 tl 0.02 ~? ~ 2.94 137 4 51 U 0.03 11 I 2.94 138 4281 U 0.02 ~) ~ 2.93 1 4313 U .03 1 < 5 2.91 140 4343 O 0.03 1 1 _' 2.93 41 4374 ~,~ 0. 4 1 ~ i .93 Shallow ittin . 142 4407 t~ 0.03 I > 2.95 _ Shallow axrosi~m. Penetration Body Metal Loss Body Page 3 ~ Pipe: Body Wall: Upset Wall: Nominal I.D • • PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 UEU 8rd 0.2 54 i n 0.254 in 2.992 in Well: 1 L-28 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: November 1, 2007 Joint No. Jt. Depth (Ft.) Pr~n. Ilh.et (In~.i Pen. Body (Ins.) Pc~n. % ~Ic~t.~l lo~> °~~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 143 443 7 O 0.03 1 U ~ 2.95 144 4468 t) 0 03 1 1 4 2.94 145 500 U O.D4 15 Z .94 S Ilow ~n . 146 4531 l).U5 0.02 t3 1 2.94 147 4 62 a 0.03 11 ~ 2.93 148 459 U 0.03 13 ~ 2.96 Shallow ittin . 14 4623 ~) 0 04 14 2 2.93 hallow orrosion. 150 4655 i) 0.0 10 3 2.94 151 4686 ~) 0. 3 I U I 93 152 4718 U 0.04 I ~ 1 .95 Sha low ittin . 153 4749 (_) 0.02 8 _' 2.96 15 4780 U 0.03 13 2.92 Shallow ittin . 55 4811 l) 0.02 ~) ~ 2.93 156 4843 (1 0.03 1 Z Z 2.93 1 7 4875 U 0.03 11 ~' 2.94 158 490 t ( 0.0 11 3 2.94 159 49 7 O 0.0 I ~ l .9 Sh II itti 160 496 U 0. ~) ~ 9 161 4998 0 0.03 1 3 5 2.94 Sh Ilo itti 162 029 t) 0.03 1 ~ ~~ 2.94 163 5061 ~) 0.0 13 4 2.92 Shallow ittin . 164 5093 O.U5 0.0 ~) -3 2.95 165 123 U 0.04 15 I I 2.93 hallow ittin . 166 5155 t1 0.03 I 4 2.93 Shallow "ttin . 1 187 O 0.03 11 4 2.93 168 5218 ~ 0.02 r) 3 2.97 169 5248 U 0.03 1l) 2 2.96 170 5279 U 0.04 1 ~ 3 2.92 Shallow corrosion. 171 5310 U 0.03 12 5 2.93 172 5341 U 0.04 16 3 2.94 Shallow itti 173 5372 U 0.0 9 5 2.96 174 5403 U 0.03 11 4 2.92 175 5435 0 0.03 11 5 .95 176 5466 O 0.02 ~) 1 2.93 177 5498 U 0.03 1.3 3 2.94 hallow ittin . 178 5529 U 0.02 ~) 2.94 179 5561 U 0.02 ~) 5 2.96 180 5592 0 0.03 13 ~1 2.94 Shallow ittin . 181 562 a 0.02 ~) 4 2.92 182 5655 U 0.02 ~> 2 2.96 1 3 56 U 0.03 11 ~ 2. 1 184 5718 O 0.03 1l) 2 2.96 185 5749 ~) 0.02 ~~ 2.9 186 5781 U 0.02 9 5 .93 187 5810 O.t)5 0.02 8 ~' 2.97 188 5840 (1 0.02 ~) ? 2.96 189 5871 O 0.03 1 1 1 2.93 190 5902 ~ ~ 0.03 1 1 2.93 191 5935 0.03 ! ~ 2.96 Shallow 'tti 192 5966 0.03 . ' 2.96 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf LSD EUE 8rd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. )t. Depth (FtJ I'~rn. Ulx~~l (Irn.) Pen. Body (Ins.) f'c~n. % Mt~t,~l loss °io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 19 5997 !? 0.0 13 ~ 2.9 Shallow corrosion. 194 602 7 U 0.0 6 I .95 195 6059 !) 0.0 12 1 ,93 ha I w i tin 196 609 U 0.0 £s I 2.95 197 6 2 l) 0.02 8 2 2.94 198 6153 (1 0.02 `) 2 2.95 19 6184 U 0.03 1 1 1 2.9 200 6215 U 0.03 1l) 2.92 201 6246 U 0.02 ~) ~ .94 20 6278 U 0.02 t3 ? 2.95 203 63 0 t~ 0.02 £3 _~ 2. 04 6341 t) 0.02 £i _' 2.95 05 6372 ~~ 0.02 `~ ? 2. 20 6404 U 0.0 £i 2 2.96 07 6436 t) 0.03 11 1 2 3 208 6467 t~ 0.02 £i I 2.96 6498 ~) 0 02 £i ~ ~ 2.9 210 6530 ~) 0.02 £i t) 95 1 6 60 t) 0. 3 1.3 .92 S a w 21 6590 l) 0.02 £~ I 2.94 13 6621 a 0.03 L3 I 2.91 Shall w itti 2 4 6652 t) 0.04 1 5 1 2.93 Shallow corrosi n. 15 6684 0 4 16 1 94 Shallow c rrosi n. 216 6715 t) 0.02 1 2.93 17 747 U .0 1 > I .93 ha 1 orr i 218 6778 U 0.02 £~ t ~ 2.94 219 6809 t) 0. 1 S .92 Shall itti 220 6841 O 0.02 1 2.94 221 6871 ~) 0.03 1 Z ~' .9 222 6903 t) 0.02 8 2 2.93 223 6934 U 0.02 £f 2 2.91 224 6966 U 0.02 `) ; 2.93 225 6997 U 0.03 11 _' 2.91 226 7029 t1 0.02 `~ _' .91 227 7060 t) 0.0 ~ {) 2.94 228 7091 U 0.05 1 £i 3 2.92 Shallow corrosion. 9 71 3 t ~ 0.0 `) ' 94 229.1 7148 t ~ 0.02 7 ~ 2.94 PUP 2 9.2 7159 t t 0 U 0 N A GL n a 229.3 7165 t~ 0.03 13 (~ 2.94 PUP Shallow i tin . 230 7173 U 0. 3 11 2. 2 231 7205 t ~ 0.03 1 1 2 2.94 3 7 6 O.US 0.0 11 _' 2.95 233 7267 t l 0.02 £i I 2.94 2 4 7298 t) 0.04 1 ; ~ ~ 2.94 Sha I w Corr Sion. 235 7331 ~) 0.03 1 U ~ 2.94 236 7363 tt 0.0 9 t9 2.97 237 7394 U 0.03 12 £t 2.97 Shallow itti 38 7 26 n .03 1 z 95 239 7457 t l 0. 3 1 1 I 2.92 Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 UEU 8rd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. Jt. Depth (Ft) I'crn. Ul~s~~t (Ins.) Pen. Body (Ins.) Pc~n. °i4> Met.il Icxs °<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 240 7488 tt .04 14 ~ 2.93 Shallow corrosion. 241 7520 U 0 2 7 5 2.96 242 7551 U 0.02 ~) 1 2.95 243 7582 t t 0.02 ~> 3 2.95 244 7614 U 0.02 £3 (~ 2.93 Lt De osits. 245 7646 U 0.02 7 5 246 7676 t) 0.02 9 ~' 2.93 247 7708 U 0.02 ~) ~' 2.95 24$ 7737 U 0.02 ~) ~ 2.95 249 7770 l).U ~ 0.02 7 l 2.94 250 7800 tt 2 ~~ 2.9 251 7832 !) 0.02 ~t ~ 2.94 252 7862 U 0.02 t3 2.95 253 7893 a 0.03 I3 .91 Shallow ittin . 254 79 5 u 0.04 14 I 2.93 Shallow ittin . 55 7955 a 0.0 ~ ~ .93 25 7986 tt 0.03 I"~ 4 2.91 Shallow it 'n . 257 8018 t t 0.03 1~ 1 2.95 258 8 49 ! t 0.0 12 _' 2.91 259 8081 t) 0.02 ~) 1 .95 60 8112 t) 0.02 t3 I 2.94 261 8143 U 0.03 13 3 2.91 Shallow ~ttin . 262 176 t) 0.02 ') 3 2.93 263 8207 U 0.02 £; I 2.94 64 38 a 0.02 £3 u 265 8266 t) 0.02 ~) 2.91 266 8297 tt .03 tU a .9 267 8327 U 0.02 '~ ~ 2.93 68 8359 U 0.02 ~) I 2.93 269 8391 !~ 0.02 ~~ i 2.94 2 7 8421 ! ! 0.02 t9 ~ 2.91 271 8453 !) 0.03 I ~' I 2.94 2 7 8484 U 0.02 9 I 2.94 273 8516 a 0.04 1 7 ? 2.92 Shallow corrosion. 274 8547 !) 0.04 13 2.91 Shallow it 'n . 275 8578 U 0.02 ~) _' 2.93 276 8608 O 0.03 II I .93 277 8640 !) 0.02 £3 2.95 278 8672 !~ 0.04 I i I 2.9 Shallow ittin 279 8704 a 0.02 ~~ 2.94 280 8734 t) .04 1t3 4 2.91 Sh Ilo corrosi n. 281 8767 a 0.02 £3 I 2.93 82 8797 ! t 0.0 9 ' .94 283 8829 !! 0.04 1~ I 2.92 Shallow itti 284 8859 !) 0.02 ~) 1 2.95 285 8890 a 0.02 ~~ I 2.93 286 8921 tt 0.0 '~ I 2.9 287 8953 u. I ~ 0.03 1 I 1 2.92 28 8983 ~. ~ 0.02 ') 1 .94 28 .1 9010 !! 0.02 f1 !~ 2.96 PUP ~'~'o L)ata Avail Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE Srd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. )t Depth (FtJ P~~n. Ui~tiel IlnS.j Pen. Body (Ins.) Pen. °i~> Mt~tal Lutis `Y~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 288. 9013 U 0 U U N A GLM 3 Latch ~ 7:00 88.3 9028 tl .04 1 i ~' 2.91 PUP Sh I w 'ttin . 89 9036 tt 0.02 9 !) 2.93 290 9066 t~ 0.03 1h 2.91 291 90 6 u 0.03 1 I I 2.92 292 9129 t~ 0.02 8 I 2.94 93 91 0 t~ 0. 3 1t) ti 2.94 294 9191 t I 0.0 9 _' 2.95 9 2 U 0.03 12 ~ .9 96 9254 a 0.02 7 ~ .96 97 9285 t1 .0 8 I 94 298 9316 it 0.02 f3 .94 99 9349 U 0.02 f1 2.9 300 9380 l1 0.03 I1 I 2.91 301 9411 I 0.02 ~~ ~' 2.94 02 9441 t) 0.02 ~~ 1 .9 30 9474 U 0. 3 13 3 .96 hallow i 'n 304 9505 t l .0 ~~ 1 2.93 05 9536 U 0. 13 t 2.91 Shalto i ti 306 9568 t1 0.04 14 1 2.90 Shallow itti 307 9599 rl 0.02 fi I 2.95 308 9631 U 0.02 is 2 2.94 309 661 a 0.0 '~ 1 .93 310 9692 U 0.02 ti 1 2.92 311 7 (I 0.0 £3 1 9 312 9753 it 0.02 ti 1 2.93 313 9784 tl 0 8 2 2.94 314 9816 U 0.04 15 2 2.93 Shallow 'ttin . 315 9847 t) 0.03 1 U ,? .91 316 9879 i~ 0.03 I 4 2.93 Shallow ittin . 317 9910 t I .02 ~) ~' 2.90 318 9942 t? 0.03 11 ~ 2.93 319 973 t1 0.02 ti 2 2.93 320 10005 (1 0.02 ~) 2 2.93 321 100 6 U 0.0 8 2 .91 t De osits. 322 10067 U 0.02 ~) 1 2.90 2 1 09 i) 0.02 ~~ 3 94 3 4 10129 it 0.02 `~ 2 294 5 10160 n 0.02 '? 1 2. 3 326 10191 i~ 0.02 '> 2.95 327 02 1 U 0.02 ~~ 3 3 328 10252 u.u5 0.03 11 1 2.93 3 .1 10283 ti 0 ~) n N A PUP N Data Avail 328.2 10286 U 0 U t~ N A GLM 4 Latch ~ 12:00 328. 1 295 U 0.03 11 _' .96 PUP 329 10304 U 0.03 11 _' 2.95 330 103 5 t~ 0.0 F3 2.94 31 10366 ~ ~ 0.02 7 I 2.95 2 1 39 t~ .0 - 2.9 333 10428 iJ 0.03 1u ~ 2.95 __ Penetration Body Metal Loss Body Page 7 • • PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Well: 1 L-28 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2007 Joint No. Jt. Depth (Ft.) I'c~n. IJl~sc~t (Ins.) Pen. Body (Ins.) Pc~n. °/, :Vlctal Los. °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 334 10460 0 0.02 £t 2 2.94 335 10491 0 0.03 1,? ~ 2. 1 36 10522 U 0.03 10 t .9 337 10553 U 0.02 ~) -£ .95 338 10584 0 0.02 ~t ~ 2.95 339 10616 t t 0.02 t3 2.93 340 10647 U 0.02 7 ' 2.94 341 10678 U 0.03 11 a 2.94 342 1 709 0 0.03 12 2.93 43 107 t t .02 ~) 5 2.9 344 1 771 a 0.0 1 3 7 2.92 S to itti . De sits. 344. 10800 a 0. 1 4 1 .94 P P 44. 10805 tt 0 0 0 N A GLM a ch ®8:3 344.3 10814 tt 0.0 ~~ 4 .95 PUP 45 1 822 U 0.02 8 1 2.93 346 10853 t t 0.03 11 ? 2. 3 3 .1 1 885 t t 0 U u 2.8 W i l 347 10887 U 0.01 4 ~ 2.93 347 10918 0.11 .0 £3 ~' .9 P P 3 10924 0 D.02 9 ? .96 348.1 10952 u 0 U 0 N A X Over 349 10959 0 0.02 £i ? .96 First t. liner 50 10989 ~~ 0.02 ti ~' .94 351 11020 0 0.03 12 5 2.89 5 110 U £3 1 353 11083 a 0.02 £3 0 2.92 354 11114 t t 0.02 8 Z .94 355 11144 t t 0.02 7 U 2.92 56 11174 U .02 8 ' .94 357 11205 a 0.03 1 s 2.93 Shallow corrosion. 358 11236 0. t U 0.14 ~ ~ 2.91 Perforation Interva 359 11267 O.U£i 0.25 ')' - 2.92 Perforation Interval 360 1 30 >1~) 0. 5 100 12 2.94 Perforation Interval 361 11329 U.-15 0.31 100 la 2.96 Perforation Interval Penetration Body Metal Loss Body Page 8 KRU 1 L-28 ConocoPhillips Alaska, Inc. 1 L-28 API: 500292295100 Well T : PROD An le TS: 28 d 11291 TUBING ~o-1os5z, OD:3.50D SSSV Type: NIPPLE Orig COm IetlOn: 1123/1999 Angle @ TD: 23 deg ~ 11770 , i0:z.9sz) Annular Fluid: DSUSW Lest WlO: Rev Reason: GLV C/O Reference L Ref L D ate: Last U te: 10!312005 Last Ta : 11465 WLM TD: 11770 ftK6 SURFACE Last Ta Date: 4192005 Max Hole A le: 67 d 2336 c~48. ~ , Casin Stri - AL 00:9.625, ~~~) D68CrI lion Size To Bottom TVD Wt Grede Thread _ CONDUCTOR 16.000 0 115 115 52.58 H-40 WELDED SURFACE 9.625 0 6546 3586 40.00 L-80 BTCM PRODUCTION 7.000 0 11117 5796 26.00 L-80 BTCM ~ROOUCnoN (0.11117 LINER 3.500 1094 4 11769 6378 9.30 L$0 EUE 8RD 00:7.000, Tubi Stri -TUBING wrz6.ao) Size To Bottom TVD Wt Grade Thread 3.500 0 10952 5664 9.30 L80 EUE8RD Perforations Summa 0as ~m Interval TVD Zone Status Ft SPF Date T Comment MandreWaNe z - © I 11295 - 11320 5947 - 5969 C-4 25 6 6/22/2000 APERF 2.5" HSD, 60 d asin (7197-7198, J 11334 - 11364 5981 - 6008 ~d C-3 C-1 30 4 3/192000 APERF 2.5' HSD 60 d basin 11518 - 11538 6147 - 6166 A-5 20 4 12/19/1999 IPERF 2.5" HSD 180 hasi I ~ Stimulations & Treatments cea ant In erval Dete T Com ent MandreWaNe ©- I 11518 - 11538 2/12/2000 FRAC 'A' SAND FRAC t9o51_so52 11295 - 11364 5!72000 FRAC 'C' SAND FRAC Gas Lift Mandrels/Valves ~ ~ St MD TVD Man Mir Men Type V Mfr V Type V OD Leah Port TRO Date Run Vlv C M 1 4258 2615 CAMCO MMM CAMCO GLV 1.5 RK 0.156 1265 8/30/2005 ©J 2 7197 3864 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1254 8/302005 3 9051 4656 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1230 8292005 I 4 10316 5234 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1206 8/29/2005 ( l 5 10836 5576 CAMCO MMM CAMCO OV 1.5 RK 0.250 0 8282005 f -- Other lu s ui .etc. -JEWELRY ~ © De th TVD Descri n ID 553 552 NIP CAMCO DS NIPPLE 2.813 10912 5633 NIP CAMCO W NIPPLE 2.813 10944 5658 PKR BAKER ZXP LINER PACKER 4.375 Nlp 10952 5664 SEAL BAKER SEAL ASSY 8 0-40 GBH-22 3.000 10912 10913, OD:4.520) PKR 1094410945, OD:7.000) LINFJ2 1094411769, 00:3.500, Wt9.30) I ~ Pert 1129511320) FRAC ', 1129511364) Pert 11334-11364) Pert 1151&11538) FRAC 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 14, 2007 RECEIVED O C T 1 ? 2007 Alaska Ail & Gas Cons. Anchorage Commi~oA a Mr. Tom Maunder ` \~ Alaska Oil & Gas Commission. ~ 333 West 7~' Avenue, Suite 100 ~~~ Anchorage, AK 99501 ~~;:~~:~~~~ h10V 0 ~ 200? Dear Mr. Maunder: -Enclosed please find a~ spreadsheet with a list of wellsfrom the Kuparuk field (KRiJ). ° Each of these wells was found to have a void in the conductor. These voids were 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. The cement top jobs were pumped on August 21 & September 28, 2007 and the corrosion inhibitor/sealant was pumped on. September 28 & 29, 2007. The attached spreadsheet presents the well name, top' of cement depth prior to filling, and volumes used on each conductor: Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~,~ _~ ~ Perry Kl - ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field natn ..,,... ~.,...,~ ell Name TD # 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 1 L-28 199-098 15' 6" 2 4" 8!29/2007 1 .9/28/2007 1 C-102 201-161 29' 8 24" 9/21 /2009 11.5 9/29/2007 1 D-10 198-049 sf n/a sf n/a 4 9/29/2007 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 . Other ""TI' 0I1f" Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 , Exploratory 0 199-098 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22951-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 31', PAD 81' 1 L-28 8. Property Designation: 10. Field/Pool(s): ADL 25660: ALK 470 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: . Total Depth measured 11770' feet true vertical 6379' . feet Plugs (measured) 11400' Effective Depth measured 11530' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 84' 16" 115' 115' SURFACE 6515' 9-5/8" 6546' 3586' PRODUCTION 11086' 7" 11117' 5796' LINER 825' 3-1/2" 11769' 6378' Perforation depth: Measured depth: 11295'-11320',11334'-11364',11518'-11538' "tÞ\~fc'~"~\~:~ ") <" true vertical depth: 5947'-5969',5981'-6008',6147'-6166' r ::þ'-j':r-.~rj '-";'4>"'~""''''' ,;;...:.;. Tubing (size, grade, and measured depth) 3-1/2" , L80, 10952' MD. Packers & SSSV (type & measured depth) pkr= BAKER ZXP LINER PACKER pkr= 1 0944' Cameo DS nipple @ 553' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 11295'-11320' Treatment descriptions including volumes used and final pressure: pumped 185000# of 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation 50 807 46 -- 160 Subsequent to operation 514 2616 rol -- 381 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0' Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 . GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: -Contact Guy Schwartz @ 265-6958 Printed Name GuySch~A . Title Wells Group Engineer Signature a~ (,Y-J:A Phone Date 11-7... 7- 0 fP Prena""" h" Sharon AII.."n-Drake 263-4612 d' .....~ RBDMS 8Fl . , ~b If. 7()·C>f.. RECEIVED (t,¡(S NOV 2 OJ 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TION~aska Oil & Gas Cons. Commission . . STATE OF ALASKA Form 10-404 Revised 04/2004 OR\G\NAL t ::I fnQ~ f\ J SUb~Orig.inal Only ~ 120,/{% DATE 10/28/06 10/30/06 11/4/06 11/5/06 11/6/06 11/7/06 11/8/06 11/9/06 11/10/06 11/11/06 11/12/06 11/15/06 . . 1 L-28 Well Events Summary Summary TAGGED HYDRATES @ 970' SLM DRIFTED TUBING DOWN TO 5000' CTMD (2980 TVD) WHILE PUMPING SLICK DIESEL.LEFT WELL SHUT IN AND FREEZE PROTECTED FOR SLlCKLlNE TO TAG AND DUMP BAIL SAND ACROSS A SANDS IF NEEDED FOR A UPCOMING C-SAND FRAC. DRIFT TUBING W/2.74" LIB. TAG TOP OF WRP/FISH @ 11370' SLM. PULLED GLVs @ 9051' & 10316' RKB. SET DV @ 10316' RKB. IN PROGRESS. GAUGED TUBING W/2.56" GAUGE RING. BRUSH & FLUSH. RAN LIB TO STA#4 @ 10316' RKBAND OBTAINED PICTURE OF LOST KOT ARM SPRINGS AND CONFIRMED EMPTY POCKET. ATTEMPTED TO RETRIEVE LOST 1.5" DV - UNSUCCESSFUL. SET 2.81" MA-2 PLUG @ 10912' RKB. SET CATCHER SUB @ 10889' SLM. PULLED OV @ 10836' RKB. IN PROGRESS. RAN POCKET BROACH TO STA#4 @ 10316' RKB. PULLED GLVs & SET DVs @ 4258' & 7197' RKB. SET DVs @ 9051' & 10316' RKB. IN PROGRESS. LOAD TBG & IA WITH 395 BBL SW & 120 BBL DSL. SET DV @ 10836' RKB. PULLED CATCHER SUB @ 10889' SLM. IN PROGRESS. TESTED TBG & IA INDIVIDUALLY TO 3500 PSI, PASSED. PULLED MA-2 PLUG @ 10912' RKB. RETRIEVED LOST 1.5" DV. IN PROGRESS. DUMP BAILED SAND FROM 11390' -11354' RKB (TARGET 11325'). IN PROGRESS. DUMP BAILED SAND FROM 11358' - 11329' RKB. CAPPED WITH SLUGGITS FROM 11329' -11321' RKB. WELL READY FOR FRAC. ATTEMPTED FRAC JOB, UNABLE TO GET TREESAVER TO FUNCTION. RIG DOWN AND SEND TREESAVER TO SHOP FOR RE-BUILD. PUMPED C SAND FRAC AS DESIGNED. PLACED 185000# 16/20 CARBOLlTE IN PORMATION, 10 PPA ON PERFS. FLUSHED TO COMPLETION. SAW TIP SCREEN OUT - 35 MINUTES INTO JOB. PERFORM POST FRAC CLEAN OUT DOWN TO TOP OF WRP @ 11381' CTMD BEFORE GETTING STRUCK FROM CROSS FLOW OR PIECES OF FRAC SLEEVE RUBBER LEFT IN HOLE FROM FRAC.WAS TO OBTAIN PIPE MOVEMENT AGAIN FROM SURGING PUMP AND PRESSING UP ON CHOKE.POOH WITH 1 FOR 1 RETURNS AND FORMATIONS SAND WHILE WASHING TUBING AND GLM FOR GAS LIFT DESIGN. LEFT WELL SHUT IN AND FREEZE PROTECTED. . ~ ConocoPhUlips Alaska, Inc. 1L·28 TUBING (0-10952, 00:3.500, 10:2.992) C-SANO c- r-. FRAC f- f--' (11295-11320) + ~ ~ ~ FRAC H (11295-11364) ~ <- t3 --"- FRAC ^ (11518-11538) API: 500292295100 SSSV Type: NIPPLE Annular Fluid: DSUSW Reference Log: Last Taa: 11530' RKB Last ~Date: 9/10/2006 DescriDtion CONDUCTOR SURFACE PRODUCTION LINER Tubing String. TUBING Size I Top I 3.500 I 0 I Perforations Summary Interval TVD 11295 -11320 5947 - 5969 11334 -11364 5981 - 6008 11518 -11538 6147 - 6166 Stimulations & Treatments Interval Date 11518 - 11538 2/12/2000 11295 - 11364 51712000 11295 -11320 11/12/2006 . KRU 1 L-28 Anale @ TS: 28 dea @ 11291 Anale @ TO: 23 dea lID 11770 Rev Reason: TAG FILL, GLV C/O, Set PLUG, FRAC Last UPdate: 11/14/2006 Well Type: PROD Oria Completion: 11/23/1999 Last w/o: Ref Log Date: TO: 11770 ftKB Max Hole Anale: 67 deo cæ 2336 Bottom TVD wt Grade Thread 115 115 52.58 H-40 WELDED 6546 3586 40.00 L-80 BTCM 11117 5796 26.00 L-80 BTCM 11769 6378 9.30 L-80 EUE 8RD TVD I wt I Grade 1 Thread 5664 I 9.30 I L80 I EUE8RD Status Ft SPF Date Type Comment 25 6 6/22/2000 APERF 2.5" HSD, 60 dea ohasina 30 4 3/19/2000 APERF 2.5" HSD, 60 dea ohasina 20 4 12/19/1999 IPERF 2.5" HSD, 180 dea ohasina Comment Size 16.000 9.625 7.000 3.500 Top o o o 10944 Bottom I 10952 I Zone C-4 C-4,C-3,C-1 A-5 Tvpe FRAC FRAC C-SAND FRAC Gas Lift MandrelsJValves St MD TVD Man Man Type V Mfr Mfr 1 4258 2615 CAMCO MMM CAMCO 2 7197 3864 CAMCO MMM CAMCO 3 9051 4656 CAMCO MMM CAMCO 4 10316 5234 CAMCO MMM CAMCO 5 10836 5576 CAMCO MMM CAMCO Other [Pluas, eQuip., etc.) . COMPLETION DeDth TVD Tvpe 553 552 NIP 10912 5633 NIP 10944 5658 PKR 10952 5664 SEAL 11400 6040 PLUG 'A' SAND FRAC 'c' SAND FRAC PUMPED C SAND FRAC AS DESIGNED. PLACED 185000# 16/20 CARBO LITE IN PORMATION, 10 PPA ON PERFS. FLUSHED TO COMPLETION. SAW TIP SCREEN OUT - 35 MINUTES INTO JOB. V Type V OD Latch Port TRO Date Run Vlv Cmnt DMY DMY DMY DMY DMY 1.5 RK 0.000 0 1.5 RK 0.000 0 1.5 RK 0.000 0 1.5 RK 0.000 0 1.5 RK 0.000 0 , Description 11/6/2006 11/6/2006 11/6/2006 11/6/2006 11n /2006 ID 2.813 2.813 4.375 3.000 0.000 CAMCO OS NIPPLE CAMCOW NIPPLE BAKER ZXP LINER PACKER BAKER SEAL ASSY 80-40 GBH-22 WRP set 9/15, WRP PULLING TOOL set 9/25/2006 09/15/06 SCblumberger RECEIVEr:: NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth S£P 1 5 2006 ~ Ojl 3& Gæ Cons. Comæ$)3JÇ;] ~ llì C) -ÓC} <x-" ~ .'I!.!' ..,"Nt:V :;tv :t ~¡ V k,·..r'<Ml~~~ ,~~ ~v Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Color CD Job # Log Description Date BL 2A-18 11213804 LDL 09/09/06 1 1 A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1 L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1J-102 11421625 USIT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumbargep -. .. .. .~ .Ct: \\if: 0 Rt '-- =-rr- 9 0 1GaS \>:(.v ~ '-' . 0(1 , ,....,,{\'\\\i\~ ',! . 1 r. ,$ conS. v'J . \Á~~ C-\\ U. Ga . . A..~ ~\Î~O~~ . 1\ ç:.. , . ~ . Û 2l1ÙLj ~\\), \ f\~~ 2,> sCl\~Nþ~j 0/ =. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # Log Description Date 10-02 11166733 INJECTION PROFILE 11/30/05 1 E-07 11154107 PROD PROFILE WIDEFT 01/01/06 1 E-1 05 11141240 INJECTION PROFILE 12/30/05 1 G-12 11144060 PROD PROFILE WIDEFT 12/28/05 1 L-28 Ic,q -CAb 11141239 PROD PROFILE WIDEFT 12/29/05 38-08 11154108 PRODUCTION PROFILE 01/02/06 38-02 11154109 INJECTION PROFILE 01/03/06 NO. 3644 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 1 1 1 1 1 1 1 ~- ê·~ . 'I) . - -:-#- \ ) (t SIGNED: J "!¡Jcqrf£ul) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: iJ ØD /6 01/05/06 .~ ~ DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990980 Well Name/No. KUPARUK RIV UNIT IL-28 Operator PHILLIPS ALASKA INC. API No. 50-029-22951-00-00 MD 11770 TVD 6379 Completion Date 11/22/1999 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples N_._Qo Directional Survey No -- DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Interval Log Log Run Oil / Dataset Type Media Format _N.~.~- Scale Media No Start Stop CH Received Number Comments ........................ ~ScM~' 5 ............. -~i-N/~I'- ..... ~0-8~0 ~7 --CH ...... ~4.i~d~)-O .................. BLi6) D DGR/CTN/SLD-MD.. t~ ~,,. 25 FINAL 11066 11117 OH 4/28/2000 ~ ...D. GR/CTN/SLD-TVD ~ ~ 25 ~ SRVY RPT J,..~I~GR/EWR-MD. ~:~ ~',~' 25 0~/ DGR/EWR-TVD ~-' 25 j PROD-SPIN/TEM/ 5 FINAL 5755 5796 ' OH 4/28/2000 0 11770 OH 1/4/2000 FINAL 6546 11770 OH 4/28/2000 FINAL 3586 6379 OH 4~28~2000 FINAL 100 11600 CH 9~8~2000 O 4~28~2000 09523 SPERRY. PRES REDO 6510-11719 T Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Received? Y / N Daily History Received? (~i N Formation Tops Receuived? ~/N Comments: Permit to Drill No. 1990980 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. KUPARUK RIV UNIT 1L-28 Operator PHILLIPS ALASKA INC. APl No. 50-029-22951-00-00 MD 11770 TVD Compliance Reviewed By: 6379 ._~on~~ate 11/22/1999 Completion Status l-OIL Current Status Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, First Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the first quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 2000. Annular Injection during th,; first quarter of 2000: h(1)~ h(~) 'h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-32 25683 100 0 25783 7548 33331 CD 1-42 4320 100 0 4420 387 4807 CD1-36 33174 100 0 33274 393 33667 CD1-38 9064 100 0 9164 0 9164 1L-28 3884 100 0 3984 0 3984 Total Volumes into Annuli for which Injection Authorization Expired durin$ the first quarter 2000: ¥otal Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1 C-15 48890 100 0 48990 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED FEB 0 5 Alaska Oil h Gas Cms. C0mmmi0n PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR % 5 ~.001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular DiSposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired dUring the first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ,2.oo-loo Annular Dis ~osal durin ~ the first quarter of 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 CD1-33, CD1-NQ1, CDI-10, CD1-28 2N-318 12276 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37, 1D-39 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2001: Y ' Total Voiume Y ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of AnnUlus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD 1-44, CD 1-41, CD 1- 19A CD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1- 30 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 120 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 89' FSL, 216' FWL, Sec. 29, T11 N, R10E, UM (asp's 540278, 5949060) 1 L-28 At top of productive interval 9. Permit number / approval number 1599' FNL, 2116' FEL, Sec. 28, T11N, R10E, UM (asp's548473, 5952701) 199-098 At effective depth 10. APl number 50-029-22951 At total depth 11. Field / Pool 1597' FNL, 1918' FEL, Sec. 28, T11 N, R10E, UM (asp's 548670, 5952705) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11770 feet Plugs (measured) Tagged PBTD (6/9/00) @ 11655' MD. true vertical 6379 feet Effective depth: measured 11655 feet Junk (measured) true vertical 6273 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 9 cu yds High Early 115' 115' SURFACE 6426' 9-5/8" 702 Sx AS III L & 806 G 6546' 3586' PRODUCTION 10997' 7" 115 Sx Class G 11117' 5796' LINER 825' 3-1/2" 255 Sx Class G 11769' 6378' Perforation depth: measured 11295 - 11320'; 11334 - 11364'; 11518 - 11538' true vertical 5947 - 5969'; 5981 - 6008'; 6147 - 6166' R~LCEIV~D Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 10952' MD. FEB 7 3 200I Packers & SSSV (type & measured depth) BAKER ZXP LINER PACKER @ 10944' MD. 4.1ask.~ 0il & ~i~ COr~. ¢orrlfl- CAMCO DS @ 553' MD. 13. Stimulation or cement squeeze summary . ,F'! Intervals treated (measured) (see attached) ' k~.i //i ./,//i . Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mc{ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 158 337 1 - 168 Subsequent to operation 1554 1875 37 - 179 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 W' .~4~,~ Title: Date Pr@parco[by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 L-28 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT'& PERFORATING OPERATIONS 3117100: Made multiple runs w/dump bailer to spot 17' of Sluggit cap on proppant fill, to top off an isolation plug across the 'A' sand open perforation interval located at: 11518 - 11538' MD 4/18/00: RIH & tagged top of isolation plug at 11454' MD. 5/7/00: MIRU & PT equipment to 9000 psi. Pumped an initial 'C' Sand Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval located above the isolation plug at: 11334 - 11364' MD Pumped Breakdown: a) 148 bbls Gel @ 31 bpm, followed by b) Shutdown. ISIP @ 1735. Resumed pumping Scour Stage: c) 125 bbls Pad, followed by d) 40 bbls Scour Stage w/1 ppa proppant concentration, followed by e) 151 bbls 20# Linear Flush, followed by f) Shutdown. ISIP @ 1850. Resumed pumping Data Frac: g) 150 bbls Crosslinked Gel, followed by h) Shutdown. Resumed pumping Frac Treatment: i) Pad stage, followed by j) Crosslinked Slurry stages, w/proppant concentrations ramped up from 1 to 10 ppa, followed by k) Flush stage, followed by I) Shutdown. RD. Placed a total of 132,000 lbs of proppant into the formation. 5/8/00: Performed a CT proppant & isolation plug fill cleanout to 11666' MD. 6/22/00: MIRU & PT equipment. RIH w/perforating guns & shot 25' of perforations in the 'C4' sand as follows: Added perforations: 11295 - 11320' MD Used 2.5" HSD carriers & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. Returned the well to production w/lift gas & obtained a valid well test. 8131/00 Schlumberger NO. 470 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print ,,, 1L-28 (REDO) PRODUCTION PROFILE 000821 I 1 2C-08 ~ c. MEM INJECTION PROFILE 000824 I 1 2F-07 PRODUCTION PROFILE 000823 I 1 2W-02 C,t,! C..,. INJECTION PROFILE 000824 I 1 3C-06 PRODUCTION PROFILE/DEFT 000822 I 1 3Q-13 /,,4,1 (-. INJECTION PROFILE 000825 I 1 1D-30 20339 CMR TOTAL POROSITY 000808 2 .... ,- - rL\/F ) ,. / , / SIGN DATE: AJaska Oil & Gas c,u~. Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 8/28/00 Schlumberger NO. 458 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1B-07 ~,1, ~ INJECTION PROFILE 000820 I 1 1D-30 STATIC PRESSURE & TEMP 000819 I 1 1 L-28 PRODUCTION PROFILE 000821 I 1 2A-02 l~,t <- INJECTION PROFILE 000817 I I Dr'f'El\ Cl~ AUG 2 9 2000 SIGNED _._J DATE: Alaska 0ii & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. PI-I LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 2, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1L-28 (199~98 / 399-205) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the post-drilling operations on 1L-28. This report covers the work done after the completion report was submitted. If there are any questions, please contact me at 265-6830. Sincerely, R. Thomas Kuparuk Drilling Team Leader Phillips Drilling RT/skad 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 _X Frac 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development X 31 ' RKP_ 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: 89' FSL, 216' FWL, Sec. 29, T11N, R10E, UM (ASP:540278,5949059.5 1L-28 At top of productive interval: 9. Permit number/approval number: 1599' FNL, 2116' FEL, Sec. 28, T11 N, R10E, UM (ASP:548472.7, 5952701.2 199-98 / 399-205 At effective depth: 10. APl number: 50-029-22951 At total depth: 11. Field/Pool: 1597' FI,IL 1918' FEL, Sec. 28, T11 N, R10E, UM (ASP: 548670, 5952705 Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total Depth: measured 11770 feet Plugs (measured) true velffica, 6379 feet ORIGINAL Effective Deptt measured 11668 feet Junk (measured) true vertical 6285 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 16" 9 cu. Yds High Early 115' 115' Surface 6515' 9.625" 702 sx AS III L & 6546' 3588' 806 sx Class G Production 11086' 7" 115 sx Class G 11117' 5796' Liner 11738' 3.5" 255 sx Class G 11769' 6383' Perforation Depth measured 11518'-11538' MD, 11334'-11364', 11295'-11320' true vertical 6147'-6166' TVD, 5981 '-6008', 5947'-596~' ~:~ ~:~,,:.? ?~. ~ ~!~ M.: E~r~)' Tubing (size, grade, and measured depth) ,~--'~L.:~.~ 0 ~, ~!.~i~i:..i 3.5", 9.3#, EUE Mod @ 10977~ Packers and SSSV (type and measured depth) ~:-~fi~i~O,~:~ Baker ZXP LT pkr @ 10944', No SSSV' '3. Stimulation or cement squeeze summary Intervals treated (measured: see allached Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Rep.off of Well Operations _Z Oil _z~ Gas Suspended Service .17. I hereby ~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' .~ "t' ~ I~'' ~ Title: Date ~, ~ Randy Thomas Drilling Engineering Supervisor Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMIT IN ~ DUPLICAT~ PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1L-28(W4-6)) WELL JOB SCOPE JOB NUMBER 1 L-28 DRILLING SUPPORT-CAPITAL 0608000912.2 DATE DAILY WORK UNIT NUMBER 06/22/00 PERF 2145 DAY 1 OPERATION COMPLETE SUCCESSFUL YES YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 900 PSI 900 PSI 900 PSI DAILY SUMMARY KEY PERSON SWS-VETROMILE Final InnerAnn I Initial Outer Ann1900 PSI 500 PSI SUPERVISOR KENNEDY Final Outer Ann 500 PSI PERFORATE; INT: 11295'-11320'; 2 1/2" HSD P J, 6 SPF, 60 DEGREE PHASING..[Perf] TIME LOG ENTRY 08:30 MIRU, GETTING CROSS-OVER FOR ROLLERS FROM SLICKLINE 09:00 TEST TOOL ON SURFACE, WAITING FOR XO 10:45 ARM GUN AND PT TO 3000 PSI 11'15 12:25 12:55 SHOT AT 11295'-11320', GOOD WEIGHT INDICATION. POOH 13:50 START RIG DOWN 14:45 RDMO RIH W/CCL, SAFE, 2-1/2" HSD GUN (32' TOTAL, 25' SHOT), ROLLERS TIE INTO SWS SCMT DATED 15-DEC-99 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~k, WELL SERVICE REPORT ~ K1(1L-28(W4-6)) WELL JOB SCOPE JOB NUMI~ER " 1 L-28 FRACTURING. 0302001526.3 DATE DAILY WORK UNIT NUMBER 05/07/00 C SAND INITIAL FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 YES YES DS-GALLEGOS ODELL FIELD AFC# CC# Signed ESTIMATE AK9901 230DS10LG InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 1310 PSI 1860 PSI 580 PSI 500 PSII 1761 PSI 850 PSI DAILY SUMMARY PUMPED INITIAL C SAND FRAC TO COMPLETION, 132M# 16/20 LDC BEHIND PIPE, 10 PPA AT PERFS, 1M# LEFT IN WELLBORE. [Frac-Refrac] TIME LOG ENTRY 07:30 MIRU DS EQUIPMENT. ROLL AND HEAT WATER IN TANKS. 11:00 SAFETY MEETING (1 PAl, 10 DS, 1 APC, 2 LRS) JOB REVIEW, MUSTER AREA, SLICK SPOTS. CONTINUE HEATING TANKS. PRIME UP PUMPS, WARM UP LINES. SET TREESAVER. ATTEMPT PT, FOUND LEAK IN TREATING LINE, REPLACE SEAL RING. 12:00 PT LINES TO 9000 PSI, GOOD TEST. CONTINUE TO HEAT WATER. 13:15 FINISH HEATING WATER, RIG UP LRS TO BACKSIDE. PRESSURE UP TO 3500 PSI. 13:25 START BREAKDOWN STAGE. 148 BBLS AT 31.6 BPM MAX. SAW GOOD BREAKBACK TO 6525 PSI AT 31 BPM. PERFORM SDT, ISIP = 1735, FG = 0.74, XS FRICTION = 1742 PSI @ 31 BPM. MAKE MORE GEL IN PCM. 13:50 START SCOUR STAGE. 125 BBL PAD, 40 BBL 1 PPA SCOUR, 151 BBL 20# LINEAR FLUSH. REDUCED XS FRICTION TO 460 PSI. ISIP = 1850 PSI, FG = .76. MAKE MORE GEL IN PCM. 14:25 START DATAFRAC. PUMPED 150 BBLS DATAFRAC, PERFORMED DECLINE ANALYSIS. SAW CLOSURE AT 20.8 MINUTES, CLOSURE PRESSURE = 1657 PSI, 61% EFFICIENCY. CUT PAD TO MINIMUM. 15:30 START SAND STAGES. PUMP JOB TO COMPLETION, 132M# BEHIND PIPE, 10 PPA AT PERFS, LEFT 1000# IN WELLBORE. TSO SEEN AT -24 MINUTES INTO JOB. LOST ONE PUMP IN 8 PPA STAGE, BROUGHT RATE UP ON OTHERS TO COMPENSATE. MONITOR PRESSURE FOR 15 MINUTES. 16:35 JOB COMPLETE, FLUSH PUMP AND LINES, RIG DOWN DS. 16:00 DS RIGGED OFF OF WELL, ALL TREESAVER RUBBER RECOVERED. WELL SECURED. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total-volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: h(1)' h(2) h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~ 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 ~oo - o 3 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 28, 2000 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, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the first quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 2000. Annular In/ection durin$ the; first quarter of 2000: h(1) h(~) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-32 25683 100 0 25783 7548 33331 I CD1-42 4320 100 0 4420 387 4807 CD1-36 33174 100 0 33274 393 33667 ! CD1-38 9064 100 0 9164 0 9164 · 1L-28 3884 100 0 3984 0 3984 Total Volumes into Annuli (or which bzjection Authorization Expired durin$ the first quarter 2000: ' ~ I ¥otal f ~ Total h(1) Total h(2) Total h(3) i Volume ] Well Name Volume ] Volume Volume i Injected] Status of Annulus 1C-15 48890 I 100 0 I 48990 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Randy Thomas Doug Chester Kuparuk Environmental: Engel / Snod~ass B. Momson and M. Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC FirstQuarter 2000 Annular Injection Report Page Two DRI LLI i'~ B c; E RV' I r- E c; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1L-28, April 25, 2000 AK-MM-90176 1 LDWG formatted Disc with verification listing. API#: 50-029-22951-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Tun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: APR 218 ~000 Sign Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1L-28 (Permit No. 199-98/399-205) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1L-28. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,uION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~ Gas [~ Suspended F~ Abandoned F~ Service 2. Name of Operator ~ ~-~ fl 7. Permit Number ARCO Alaska, Inc. ~. I 199-98 / 399-205 3. Address -;~--~"~'~.-,,.~'~':7_- 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-029-22951 4. Location of well at surface ' ' '-, . " 9. Unit or Lease Name 89' FSI_, 216' FW[_, Sec. 29, T11 N, R10E, UM (ASP:540278,5949059.5) i '.. · Kuparuk [:liver Unit At Top Pro0ucing Interval 10. Well Number 1599' FNI_, 2116' FEI_, Sec. 28, T11 N, R10E, UM (ASP:548472.7, 5952701.2.') : i-~.-~' :~ 11_-28 At Total Depth ! ....~ ~ 11. Field and Pool 1597' FN,II-, 1918' FEI_, Soc. 28, 'I'11N, R10E, UM (ASP: 548670, 5952705) Kuparuk [:liver Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 31', Pad 81 feetI ADL 25660 ALK 470 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore '16. No. of Completions November 3, 1999 November 18, 1999 November 22, 1999 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSVset 21. Thickness of Permafrost 11770'MD/6379'TVD 11668'MD/6285'TVD YES [~] No F~I N/A feetMD 1650' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 9 cu yds High Early 9.625" 40# L-80 Surface 6546' 12.25" 702 sx AS IIIL, 806 sx Class G 7" 26# L-80 Surface 11117' 8.5" 115 sx Class G 3.5" 9.3# 8rd EUE 10944' 11769' 6.125" 255 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10956' 10944' 11518'-11538' MD 6147'-6166' TVD 4 spf 11334'-11364' MD 5981 '-6008' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11518'-11538' 165000# 16/20 behind pipe, 11 ppa at perfs 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 19, 2000 Gas Lift Date of Test Hours Tested Production for OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE leAS-OIL RATIO 2/28/2000 12.0 Test Period > 388 658 1 176I 1430 Flow Tubing Casing Pressure Calculated OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY - APl (corr) press. 186 491 24-Hour Rate > 776 1316 2 23" 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 11291' 11371' 11500' 11621' 5943' 6014' 6131' 6242' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and graviS. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-FFACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Chip Alvord Title Drilling Engineering Supervisor Questions? Call Bill Lloyd 265-6531 INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 Date: 12/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iL-28 WELL_ID: AK0043 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:il/03/99 START COMP: RIG: POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22951-00 11/01/99 (D1) TD/TVD: 0/0 SUPV:FRED HERBERT MW: 0.0 VISC: 0) MIRU 0 PV/YP: 0/ 0 APIWL: 0.0 Start rig move from iD-ii. Release rig from construction 0200 hrs. 11/1/99. Move rig to iL pad. Rig up. 11/02/99 (D2) TD/TVD: 0/0 SUPV:G.R. WHITLOCK MW: 0.0 VISC: 0) RIGGING UP 0 PV/YP: 0/ 0 APIWL: 0.0 Take down booster wheel spreader. Set BOP on stump. Hang diverter Hydril. Spot rig over hole. Set mats. Skid rig. Spot motor module. Set cattle chute. Hook up utilities and service lines. Rig up cellar. Rig up diverter. Spot ball mill. Hook up service lines to ball mill. 11/03/99 (D3) TD/TVD: 134/134 SUPV:G.R. WHITLOCK MW: 8.6 VISC: 164 PV/YP: 27/39 134) DRILLING @500' APIWL: 10.8 N/U diverter. Change out leaking hyd. fitting on iron roughneck. Function test diverter. Fill hole and break circ. Check for leaks. Drill from 100' to 134' 11/04/99 (D4) TD/TVD: 1706/11499 SUPV:G.R. WHITLOCK MW: 10.0 VISC: 112 PV/YP: 41/42 1572) DRILLING ~ 2500' APIWL: 7.2 Drill from 134' to 1208'. Run gyro survey. MWD quit. POOH. Change MWD. RIH. Drill from 1208' to 1706' 11/05/99 (D5) MW: 10.0 VISC: 97 PV/YP: 30/33 APIWL: 5.4 TD/TVD: 4302/2625 (2596) DRILLING @ 4980' SUPV:G.R. WHITLOCK Replace broken spring in ball mill. Drill from 1706' to 4302'. CBY. POOH to HWDP. RIH to 3272' Break circ. Take benchmark survey. RIH. 11/06/99 (D6) MW: 10.5 VISC: 110 PV/YP: 37/47 APIWL: 6.2 TD/TVD: 6208/3446 (1906) CIRC AT CASING PT. SUPV:G.R. WHITLOCK RIH. CBU. Drill from 4302' to 5057' Circ out gas. Drill from 5057' to 5277'. Circ and wt up to 10.5 ppg. Drill from 5277' to 6208'. Date: 12/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/07/99 (D7) MW: 10.5 VISC: 82 PV/YP: 29/38 TD/TVD: 6560/3951 ( 352) RUITNING 9-5/8" CASING SUPV:G.R. WHITLOCK APIWL: 5.2 Drill from 6208' to 6284' Repair stroke counter/remove plastic from suction valve. Drill from 6284' to 6560' Circ sweep around. Flow check. POOH to 4200' w/no problems. RIH. Circ sweep around. POOH to HWDP. R/U casers. Hold safety meeting. Run 9-5/8" surface casing. 11/08/99 (D8) MW: 10.2 VISC: 62 PV/YP: 25/19 APIWL: 6.4 TD/TVD: 6560/3951 ( 0) N/U BOPE SUPV:G.R. WHITLOCK Safety meeting. Run 9-5/8" casing. Circ casing volume. Continue to run casing and circ casing volume. Safety meeting. Pump cement. Did not bump plug. Check floats, OK. Good returns throughout job. N/D diverter. 11/09/99 (D9) MW: 8.5 VISC: 36 PV/YP: 4/ 6 APIWL: 11.4 TD/TVD: 6560/3951 ( 0) CCM TO 8.5 PPG FOR LOT SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Hang back diverter. Install FMC Gen IV casing head. Install double studded adapter, HCR's, choke and kill lines on stack. Connect hydraulic hoses. Test BOPE-Hydril ~ 250/2500 psi. RIH w/HWDP. Tag cement @ 6315'. Service rig and top drive. Clean electrical motor on top drive. 11/10/99 (D10) MW: 9.0 VISC: 46 PV/YP: 14/16 APIWL: 6.8 TD/TVD: 8280/4325 (1720) DRILLING ~ 8871' SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Clean top drive motor. Test casing to 3000 psi, OK. Drill cement, float equipment and 20' of new hole. Displace hole w/ new LSND mud. Perform FIT to 15.3 ppg EMW. Drill from 6581' to 8280' 11/11/99 (Dll) MW: 9.3 VISC: 44 PV/YP: 17/19 APIWL: 6.2 TD/TVD: 9680/4925 (1400) DRILLING ~ 10100' SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Drill from 8280' to 9029'. Circ barafibre sweep around. Monitor well. Pump dry job. POOH from 9029' to 6491' Service rig and topdrive. Fill pipe and drill from 9029' to 9680'. 11/12/99 (D12) MW: 9.1 VISC: 41 PV/YP: 11/17 APIWL: 5.8 TD/TVD:lll17/5795 (1437) SHORT TRIP TO 9-5/8" SHOE SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Drill from 9680' to 11117' Pump Hivis weighted barofiber sweep around. Date: 12/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/13/99 (D13) MW: 9.4 VISC: 43 PV/YP: 17/19 APIWL: 5.6 TD/TVD:lll17/5795 ( 0) CIRC AT THE SHOE SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Circ sweep around. Raise mud weight to 9.4 ppg. Monitor well. Pump dry job and POOH to shoe. Perform LOT to 10.7 ppg EMW. Circ and condition mud. Pump weighted barafibre sweep. POOH. 11/14/99 (D14) MW: 9.4 VISC: 44 PV/YP: 16/19 APIWL: 5.6 TD/TVD:l!l17/5795 ( 0) TESTING BOPE SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Hold safety meeting. Run 7" casing to 11118'. Circ and condition mud. Pump cement. Bump plug. N/D BOPE. Set packoff. 11/15/99 (D15) MW: 11.7 VISC: 51 PV/YP: 29/25 APIWL: 4.4 TD/TVD:lll17/5795 ( 0) RIH PU 4" DP SUPV:G.R. WHITLOCK/SCOTT REYNOLDS Set stack on. Install choke line. Test BOPE, Hydril 250/3000 psi. Swap dies in iron roughneck. Change out elevators. Try to pump through tools to test. Pressure increased rapidly to 3200 psi $ 70 spm. TOOH to find problem. Bit and motor plugged with plastic. Work motor until it could pump freely. Unplug jets in bit. Install bit on motor. Drop plastic ball to test circulating sub. Opened OK. Break circulation and drop steel ball to close circulating sub. PU t/circulating sub, break same and retrieve balls f/ball catcher. 11/16/99 (D16) MW: 11.7 VISC: 52 PV/YP: 30/25 APIWL: 4.0 TD/TVD:lll17/5795 ( 0) WAITING ON WEATHER SUPV:G.R. WHITLOCK/SCOTT REYNOLDS M/U 10 stands to drill with and rack in derrick. RIH to 10886' CBU. Hold safety meeting and perform stripping drill. Test casing to 1500 psi for 30 min., OK. CBU through PBL sub every 2 hrs while waiting on weather. 11/17/99 (D17) MW: 11.7 VISC: 47 PV/YP: 23/26 APIWL: 3.8 TD/TVD:l1287/5940 (170) DRILLING $ 11500' SUPV:R. L. MORRISON JR. Phase 3 weather conditions. Circulate bottoms up every 2 hours. Drop ball circulate down and close PBL sub. Drill out cement from 10928' and float collar at 11030' Signal failure on PWD. Recovered signal. Drill out cement and shoe at 11117' Drill new hole from 11117' to 11138' Displace mud with clean 11.7 ppg mud. Perform FIT at 7" casing shoe, EMW=14.9 ppg. Drill 6-1/8" hole from 11138' to 11287' Date: 12/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 11/18/99 (D18) MW: 12.1 VISC: 49 PV/YP: 28/32 APIWL: 3.6 TD/TVD:l1770/6379 483) PUMPED OUT 10 STDS. DROP BALL TO OPEN PBL SUPV:R. L. MORRISON JR. Drill 6-1/8" hole to 11,770'. Circulate bottoms up. Pump weighted bara fiber sweep. Monitor well - static. Pump out of hole to shoe. Monitor - static. Run back to bottom - no fill. Circulate bottoms up. Mud cut from 11.7 to 11.1 ppg. Circulate and weight up to 11.9 ppg. Monitor well - static. Pump to shoe. Monitor well - static. Run back to bottom - No fill. Circulate bottoms up. Mud cut from 11.9 to 12.1 PPg. Circulate and weight up to 12.1 ppg. Monitor well. Pump out to shoe. 11/19/99 (D19) MW: 12.1 VISC: 49 PV/YP: 28/32 TD/TVD:l1770/6379 0) RUNNING 3.5" LINER ON DP SUPV:R. L. MORRISON JR. POH. LD BHA. RIH 3.5" liner. APIWL: 3.6 11/20/99 (D20) MW: 0.0 VISC: 49 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1770/6379 0) POOH SUPV:R. L. MORRISON JR. Continue RIH with liner to 11,116' C&C mud. RIH. to 11, 770'. C&C. Cement liner-full returns. Set hanger w/shoe ~ 11,769' Set liner top packer. Rotate off liner. Circ clean (rec spacer and 2 bbls cement). 11/21/99 (D21) MW: 11.9 VISC: 72 PV/YP: 35/40 APIWL: 6.4 TD/TVD:l1770/6379 0) SET BPV AND NIPPLE DOWN STACK SUPV:R. L. MORRISON JR. POH. RIH 3.5" completion. Land tubing in seal bore. Reverse out mud with sea water. 11/22/99 (D22) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1770/6379 ( 0) LAYING DOWN 5" DRILL PIPE SUPV:R. L. MORRISON JR. Rev out mud with SW. Land tubing hanger. Test annulus and liner lap to 3000 psi. Press up tbg to 3250 psi to shear RP valve. Freeze protect annulus with diesel. Set BPV. ND BOPE/NU tree. Test tree to 250/5000 psi, OK. LD drill pipe. 11/23/99 (D23) TD/TVD:l1770/6379 ( SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIG RELEASED FROM 1L-28 @ 1400 HRS 11/23/99 Prepare rig for move to 1R-01 ST. ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K 1 (1L-28(W4-6)) WELL JOB SCOPE JOB NUMBER 1 L-28 FRACTURING. 0209001901.2 DATE DAILY WORK UNIT NUMBER 02/12/00 A SAND FRACTURE TREATMENT DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I YES YES DS-DUGAN ODELL FIELD AFC# CC# Signed ESTIMATE AK0044 230DS10LG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 915 PSI 1750 PSI 0 PSI 500 PSI 450 PSII 600 PSI DAILY SUMMARY PUMPED INITIAL FRACTURE TREATMENT. PLACED 165000# 16/20 BEHIND PIPE (94% OF DESIGN), 11 PPA AT THE PERFS. SAW PROBABLE TIP SCREENOUT DURING JOB, HAD SUDDEN PRESSURE INCREASE IN 10-12 PPA STAGE W/CONTINUED RAPID PRESSURE RISE. CUT SAND, FLUSHED TO COMPLETION. [Frac-Refrac] TIME LOG ENTRY 06:30 DS ON LOCATION. RIG UP FRAC EQUIPMENT. HAD TROUBLE WITH ONE SUPER PUMPER, RIGGED IT OUT AND RIGGED IN TURBINE. 09:30 09:50 SAFETY MEETING (14 DS, 1 ARCO, 1 APC, 2 LRS). JOB REVIEW, MUSTER AREA. PRIME UP PUMPS, LOW PRESSURE TEST, GOOD. WARM UP LINES, SET TREE SAVER. PRESSURE TEST LINES TO 9500 PSI. GOOD TEST. 10:15 START BREAKDOWN STAGE. 158 BBLS LINEAR GEL, 30 BPM, 8200 PSI MAX, BROKE BACK TO 5700 PSI. PERFORM SDT, XS FRIC = 950 PSI. ISlP = 1908, FG = .76. MIX UP 50# GEL. 10:35 PUMP SCOUR STAGE. 75 BBL PAD, 40 BBL 1 PPA SCOUR, 152 BBL 20# LINEAR FLUSH. 20 BPM, 4300 - 4700 PSI. PERFORM STEP DOWN TEST, XS FRICTION = 655 PSI @ 20 BPM. ISlP = 1920 PSI, FG = .76. 11:00 12:05 START DATAFRAC. 175 BBLS 50# XL GEL, FLUSH WITH 102 BBLS 20# LINEAR GEL. ANALYZE DF FOR CLOSURE AND FLUID EFFICIENCY. ISIP = 1982 PSI, FG = .77. SAW PRESSURE BUILD UP WHILE MONITORING FOR DECLINE. DOESN'T' MAKE SENSE. REMOVE HEATERS FROM PRESSURE TRANSDUCERS AND REPEAT DATAFRAC. START DATAFRAC # 2. 175 BBLS 50# XL GEL, FLUSH WITH 104 BBLS 20# LINEAR GEL. 20 BPM, 4247 PSI. SHUT DOWN, ANALYZE DATAFRAC, PC = 1899 PSI, TC = 8.1 MINUTES. FLUID EFFICIENCY = 40%. ADJUST PAD VOLUME TO 210 BBLS BASED ON CLOSURE TIME. MIX GEL FOR FRAC. TIME 13:10 LOG ENTRY PUMP PROPPANT STAGES. PUMPED JOB AS PER DESIGNED, WITH 11 PPA ON SURFACE, SAW SUDDEN INCREASE IN PRESSURE OF -200 PSI, THEN INCREASED SLOPE ON PRESSURE INCLINE. ANTICIPATE SCREENOUT, CUT SAND, WENT TO FLUSH, GOT JOB FLUSHED TO COMPLETION. PLACED 165000# SAND BEHIND PIPE, 11 PPA ON PERFS. ESTIMATED 580# SAND IN WELLBORE. 14:30 JOB COMPLETED, RIG DOWN DS EQUIPMENT. 15:45 DS RIGGED OFF OF WELL, WELL SECURED. ALL TREE SAVER RUBBERS RECOVERED. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,[ WELL SERVICE REPORT '~' K1(1L-28(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 1 L-28 DRILLING SUPPORT-CAPITAL 1204991002.4 DATE DAILY WORK UNIT NUMBER 12/19/99 CBL - PERF 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES SCHUDEL FIELD AFC# CC# Signed ESTIMATE AK0043 230DS10LO InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 0 PSI 450 PSI 0 PSI 700 PSII 1250 PSI 300 PSI DAILY SUMMARY CEMENT BOND LOG FROM PBPD TO TOP OF 3.5" LINER LAP. TOP OF CEMENT FOUND AT 10980 F.RIH W/20 FOOT - 2.5 INCH HSD GUN 4SPF 180 DEG PHASING. PERF DEPTH: 11518-11538 F.[Perf] TIME LOG ENTRY 08:00 MIRU 2128, HSE MEETING TOPICS - MUSTER AT PAD ENTRANCE (UP WIND), COLD WEATHER CAUTIONS (- 35), JOB PROCEDURE DISCUSSED, EXTRA SPILL PRECAUTIONS DUE TO WELL BEING FLUID PACKED 09:30 STAB ON - PRESSURE TEST 3000 # - OK 09:45 RIH W/SWIVEL/1 WT BAR/PL CENT/PBMS/PL CENT/SCMT/PL CENT 11:00 ON BOTTOM - RUN TIE IN PASS - START LOGGING 12:00 POOH 13:00 ON SURFACE - BLEED DOWN LUBRICATOR - SET UP FOR PERF RUN 14:15 RIH W/HEAD/1 WT BAR/ECCENT ORIENTED SAFE FIRING HEAD/20 FT GUN 16:30 START PERF TIE IN PASS 17:00 SHOT GUN - GOOD SHOT INDICATION - POOH 17:45 ON SURFACE - RIG DOWN 18:45 PULL OFF LOCATION ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,~' K1 (1 L-28(W4-6)) WELL JOB SCOPE JOB NUMI~ER 1 L-28 PERFORATIONS-E-LINE 0222001848.4 DATE DAILY WORK UNIT NUMBER 03/19/00 PERFORATE 30'C SAND 2150 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 9 YES YES SWS-ROJAS RENNIE FIELD AFC# CC# Signed ESTIMATE AK0044 230DS10LG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 450 PSI 1200 PSI 0 PSI 0 PSII 0 PSI 0 PSI DAILY SUMMARY PERFORATED 11,334'-11,364' WITH 2.5" HSD GUNS W/60 DEG PHASING ALTERNATING BH/PJ CHARGES. WHP INCREASED FROM 450 PSI TO 1300 PSI AFTER FIRST SHOT, DECREASED TO 1200 PSI AFTER SECOND SHOT. TIME LOG ENTRY 18:15 LEAVE PRUDHOE BAY SHOP 19:30 ARRIVE AT IL PAD. RIG UP STARTS. 21:10 WITH RADIO SILENCE ON PAD AND RIG NOTIFIED, AS PER PE, MU GUN, COLLAR LOCATOR AND ROLLLERS. START PRESSURE TEST. 21:30 PT TO 3000 PSI, RIH. 11:00 TIE IN PASS, SHORT JOINT AT 10983' 11:10 PERFORATED INTERVAL FROM 11344-11364. WITH 2.5" HSD GUN LOADED IN ALTERNATING FASHION WITH POWER JET CHARGES AND BIG HOLE. COLLAR LOCATOR STOPPED RESPONDING. POOH. WHP BEFORE PERFORATING 420 PSI 12:15 ON SURFACE, BLEEDING LUBRICATOR. WHP 1150 PSI. FLUID PACKED. 12:30 RIH WITH 10' GUN, ROLLERS, CCL AND WEIGHT BAR 02:10 START TIE IN PASS. GOT IT THE SECOND TRY. 02:35 PERFORATED THE INTERVAL FROM 11334-11344. PRESSURE BEFORE SHOOTING WAS A 1300 PSI. AFTER SHOT IT DROPPED TO 1200 PSI. LOG OFF. 02:45 POOH 03:20 BUMPING UP. GUN SHOT. RIG DOWN STARTS. RELEASE RADIO SILENCE. 04:00 RIG DOWN COMPLETE. DRIVE BACK TO PRUDHOE BAY. North Slope Alaska Alaska State Plane 4 Kuparuk 1L 1L-28 Surveyed: 18 November, 1999 SURVEY REPORT ORIgINaL 28 December, 1999 Your Ref: API-500292295100 Surface Coordinates: 1813273.33 N, 164676.82 E (70° 16' 18.338Y N, 149° 40' 27.2585" W) Kelly Bushing: 119.90ft above Mean Sea Level RECEIVED ,qa~& ~s coas. Co~~ DRILLING SERVICE== Survey Ref: svy8949 Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.000 0,000 -119.90 0.00 100.00 0.830 52.000 -19.90 100.00 265.00 2.200 52.000 145.03 264.93 378.28 3.650 59.650 258.16 378.06 476.90 5.180 61.850 356.49 476.39 568.94 6.880 59.140 448.02 567.92 657.14 8.000 71.270 535.48 655,38 750.53 9.860 68.160 627.73 747.63 843.75 12.800 67.730 719.13 839.03 935.48 16.410 65.800 807.88 927.78 1023.34 20.800 64.510 891.13 1011.03 1122.86 27.360 68.700 981.94 1101.84 1206.36 32.180 70.830 1054.40 1174.30 1296.93 37.110 72.110 1128.89 1248.79 1395.26 43.270 71.050 1203.97 1323.87 1486.17 48.850 69.730 1267.03 1386.93 1585.26 54.490 67.270 1328.47 1448.37 1673.53 59.060 65.870 1376.82 1496.72 1776.08 65.120 65.310 1424.80 1544.70 1871.53 63.370 65.540 1466.28 1586.18 1964.04 63.440 66.430 1507.69 1627.59 2058.86 64.690 66,070 1549.16 1669.06 2150.22 64.470 65.760 1588.38 1708.28 2245.00 65.820 65.980 1628.21 1748.11 2336.26 66.560 65.430 1665.06 1784.96 0.00 N 0.00 E O.45 N 0.57 E 3.13 N 4.01 E 6.29 N 8.83 E 9.98 N 15.47 E 14.77 N 23.86 E 19.45 N 34.21E 24.51 N 47.79 E 31.39 N 64.76 E 40.56 N 85.99 E 52.37 N 111.40 E 68.30 N 148.70 E 82.58 N 187.61 E 98.90 N 236.42 E 118.98 N 296.58 E 140.97 N 358.21E 169.50 N 430.47 E 198.88 N 498.19 E 236.32 N 580.66 E 272.07 N 658.84 E 305.74 N 734.40 E 340.08 N 812.45 E 373.76 N 887.78 E 408.91N 966.26 E 443.26 N 1042.36 E Global Coordinates Dogleg Northings Eastings Rate (m) (m) (°/100ft) 1813273.33 N 164676.82 E 1813273.46 N 164676.99 E 0.830 1813274.29 N 164678.04 E 0.830 1813275.26 N 164679.50 E 1.323 1813276.39 N 164681.52 E 1.561 1813277.87 N 164684.07 E 1.872 1813279.31 N 164687.22 E 2.180 1813280.88 N 164691.35 E 2.057 1813283.00 N 164696.51 E 3.155 1813285.83 N 164702.96 E 3.971 1813289.47 N 164710.69 E 5.018 1813294.39 N 164722.03 E 6.808 1813298.80 N 164733.87 E 5.909 1813303.86 N 164748.72 E 5.502 1813310.07 N 164767.02 E 6.303 1813316.88 N 164785.77 E 6.226 1813325.69 N 164807.75 E 6.015 1813334.76 N 164828.34 E 5.344 1813346.30 N 164853.42 E 5.929 1813357.33 N 164877.19 E 1.846 1813367.71N 164900.16 E 0.864 1813378.31N 164923.90 E 1.362 1813388.69 N 164946.80 E 0.390 1813399.54 N 164970.67 E 1.440 1813410.13 N 164993.80 E 0.981 RECEIVED ,, "04 2000 Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) Comment 0.00 0.70 4.93 10.62 18.18 27.79 39.15 53.61 71.92 95.04 123,06 163.61 204.98 256.23 319.39 384.66 462.29 536.11 626.68 712.64 795.35 880.62 963.14 1049.13 1132.62 Continued... 28 December, 1999 - 14:53 -2- ~Jllll~Oii & Gas Cons. Commimion Anchorage DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Measured Depth (ft) Incl, Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 2429.97 66.170 65.820 1702,63 1822.53 2520,93 65,380 65.350 1739.95 1859,85 2618,59 65.170 65.200 1780,80 1900,70 2715.36 65.020 64.500 1821,55 1941.45 2810.82 64.950 65.050 1861,91 1981,81 2902,10 64.320 64.480 1901.02 2020,92 2997.86 64.140 64.670 1942,65 2062.55 3090.81 64.220 65.330 1983.13 2103,03 3187.89 63.850 64,320 2025.64 2145,54 3280,16 63.700 64.480 2066,41 2186,31 3372.51 64.870 64.330 2106,48 2226,38 3467,22 65.190 64,950 2146,46 2266,36 3560.47 64,310 64.200 2186,24 2306,14 3656.00 63.960 63,960 2227,92 2347,82 3746.11 63.790 63.510 2267,59 2387.49 3841.11 63.560 63.750 2309.72 2429,62 3934.95 63.230 65.330 2351,75 2471,65 4030.00 63.870 64.540 2394,09 2513,99 4125.72 63.850 65.120 2436.26 2556.16 4216.87 63.790 65.510 2476,47 2596,37 4312,33 62,890 65,760 2519.31 2639,21 4407.95 63,300 65,560 2562,57 2682,47 4500,90 64.210 65,600 2603,68 2723,58 4592,57 64.630 65,870 2643,26 2763,16 4687.19 65,820 66.050 2682,91 2802,81 478.69 N 1120,56 E 512.98 N 1196.09 E 550,08 N 1276,67 E 587,38 N 1356,11E 624,25 N 1434.37 E 659.41 N 1508.98 E 696.44 N 1586.86 E 731.80 N 1662,69 E 768,92 N 1741,68 E 804,69 N 1816,33 E 840,63 N 1891,37 E 877,40 N 1968,95 E 913,61N 2045,12 E 951,19 N 2122,44 E 986.99 N 2194,99 E 1024,81 N 2271.27 E 1060.88. N 2347,03 E 1096,93 N 2424,11E 1133,48 N 2501,88 E 1167.64 N 2576,20 E 1202,83 N 2653,92 E 1237,98 N 2731,61E 1272,44 N 2807,52 E 1306,42 N 2882,89 E 1341,42 N 2961,35 E Global Coordinates Northings Eastings (m) (m) 1813421.06 N 165017.58 E 1813431.63 N 165040.55 E 1813443.07 N 165065.04 E 1813454.57 N 165089.20 E 1813465.94 N 165112.99 E 1813476.77 N 165135.67 E 1813488.19 N 165159.35 E 1813499.09 N 165182.41 E 1813510.53 N 165206.42 E 1813521.55 N 165229.12 E 1813532.63 N 165251.93 E 1813543.97 N 165275.52 E 1813555.13 N 165298.67 E 1813566.71N 165322.18 E 1813577.74 N 165344.23 E 1813589.39 N 165367.42 E 1813600.51N 165390.45 E 1813611.62 N 165413.89 E 1813622.89 N 165437.53 E 1813633.42 N 165460.13 E 1813644.27 N 165483.76 E 1813655.11N 165507.38 E 1813665.74 N 165530.46 E 1813676.22 N 165553.38 E 1813687.02 N 165577.24 E Dogleg Rate (°/100ft) 0.564 0.988 0.256 0.674 0.527 0.891 0.259 0.645 1.010 0.225 1.275 0.683 1.192 0.431 0.486 0.331 1.546 1.004 0.544 0.390 0.971 0.468 0.980 0.530 1.269 Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) Comment 1218.46 1301.41 1390.10 1477.84 1564.32 1646.77 1732,96 1816.61 1903.86 1986.59 2O69.75 2155.57 2239.87 2325.76 2406.58 2491.64 2575.50 2660.58 2746,48 2828.26 2913.57 2998.83 3082.19 3164.87 3250.78 28 December, 1999 - 14:53 -3- RECEIVED Continued... DrillQuest 1,05,04e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 SurVeyed: 18 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (m) (m) 4784.33 65.460 65.490 2722.98 2842.88 4879.47 65.210 65.520 2762.68 2882.58 4975.70 64.360 65.760 2803.67 2923.57 5069.81 65.070 64.270 2843.87 2963.77 5163.50 65.630 63.430 2882.95 3002.85 5255.05 65.610 64.500 2920.74 3040.64 5349.93 64.180 64.540 2960.99 3080.89 5445.28 63.850 64.790 3002.77 3122.67 5541.97 64.090 64.870 3045.20 3165.10 5632,57 65.300 64.820 3083.93 3203.83 5726,23 64.870 64.560 3123.38 3243.28 5822,02 64.360 64.160 3164.45 3284.35 5914.40 64.030 63.880 3204.66 3324.56 6008.83 64.310 64.310 3245.81 3365.71 6104,62 66.210 63.550 3285.89 3405.79 6197.66 65.690 63.950 3323.81 3443.71 6292.00 65.740 63.970 3362.61 3482.51 6387.20 66.160 62.460 3401.41 3521.31 6474.44 66.050 62.220 3436.75 3556.65 6608.36 65.720 61.920 3491.46 3611.36 6704.35 64.890 63.420 3531.57 3651.47 6790.34 64.560 65.100 3568.28 3688.18 6891.13 64.010 63.820 3612.02 3731.92 6985.94 63.480 65.150 3653.96 3773.86 7080.81 65.060 66.500 3695.15 3815.05 1377.74 N 3042.05 E 1413.58 N 3120.73 E 1449.49 N 3200.04 E 1485.44 N 3277.16 E 1522.97 N 3353.60 E 1559.56 N 3428.52 E 1596.52 N 3506.08 E 1633.20 N 3583.54 E 1670.15 N 3662.18 E 1704.97 N 3736.31 E 1741.28 N 3813.10 E 1778.73 N 3891.12 E 1815.16 N 3965.89 E 1852.29 N 4042.34 E 1890.53 N 4120.48 E 1928.11N 4196.68 E 1965.86 N 4273.95 E 2005.03 N 4351.55 E 2042.06 N 4422.20 E 2099.31 N 4530.19 E 2139.36 N 4607.66 E 2173.12 N 4677.70 E 2212.27 N 4759.63 E 2248.90 N 4836.37 E 2283,89 N 4914.33 E Dogleg Rate (°/100ft) Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) 1813698.22 N 165601.78 E 0,643 3339.27 1813709.27 N 165625.70 E 0.264 3425.72 1813720.35 N 165649,81E 0.912 3512.77 1813731.43 N 165673.26 E 1,618 3597.84 1813742.99 N 165696,50 E 1.011 3682.92 1813754.27 N 165719,27 E 1.065 3766.23 1813765.66 N 165742.85 E 1,508 3852.10 1813776.96 N 165766.40 E 0,419 3937.78 1813788.36 N 165790.31E 0.259 4024.63 1813799,09 N 165812.85 E 1,336 4106.51 1813810.28 N 165836.20 E 0.524 4191.42 1813821.82 N 165859.92 E 0.653 4277.91 1813833.05 N 165882.64 E 0.450 4361.01 1813844.49 N 165905.89 E 0.506 4445.95 1813856,27 N 165929.64 E 2.110 4532.87 1813867.85 N 165952.81 E 0.683 4617.74 1813879.48 N 165976.29 E 0.056 4703.66 1813891.55 N 165999.88 E 1.514 4790.47 1813902.95 N 166021.35 E 0.281 4870.04 1813920.58 N 166054.18 E 0.320 4991.94 1813932.91 N 166077.73 E 1.662 5078.97 1813943.32 N 166099.02 E 1.808 5156.68 1813955.38 N 166123,93 E 1.268 5247.44 1813966.67 N 166147.25 E 1.377 5332.42 1813977,46 N 166170.96 E 2.102 5417,87 RECEIVED 04 2000 Comment Continued... 28 December, 1999 - 14:53 -4- DrillQuest 1.05. 04e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim, Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (m) (m) 7175,26 64.940 65,430 3735.06 3854.96 7268.18 64,510 65.450 3774.74 3894.64 7363.57 63.830 65.990 3816.30 3936.20 7454.60 65.450 65.110 3855.29 3975.19 7549.92 65,230 64.960 3895.06 4014.96 7645.03 64.650 65.360 3935.34 4055.24 7737.55 64.270 63.850 3975.23 4095.13 7830.42 63.850 64.730 4015.86 4135.76 7925.96 65.250 66.670 4056.91 4176.81 8019.38 65.030 66.390 4096.19 4216.09 8114.05 64.750 67.690 4136.36 4256.26 8208.94 64.480 66.770 4177.04 4296.94 8303.18 64.060 67.060 4217.96 4337.86 8397.52 63.710 66.750 4259.48 4379.38 8491.89 65.880 67.110 4299.67 4419.57 8585.04 65.500 67.420 4338.02 4457.92 8678.89 65.150 67.300 4377.20 4497.10 8771.50 64.820 66.190 4416.36 4536.26 8868.50 64.760 66.570 4457.67 4577.57 8961.73 64.570 65.830 4497.57 4617.47 9057.47 64.450 67.570 4538.77 4658.67 9151.90 64,120 66.920 4579.75 4699.65 9246.63 63,700 68.110 4621.41 4741.31 9341.54 64,360 67.850 4662.97 4782.87 9434.23 63,950 67.970 4703.37 4823.27 2318.75 N 4992.51E 2353.68 N 5068.93 E 2388.98 N 5147.20 E 2423.03 N 5222.07 E 2459.60 N 5300.60 E 2495,79 N 5378.79 E 2531,59 N 5454.20 E 2567,82 N 5529.44 E 2603.31N 5608,07 E 2637.06 N 5685,82 E 2670.50 N 5764,75 E 2703.68 N 5843,79 E 2736.97 N 5921.89 E 2770.20 N 5999.81 E 2803.65 N 6078.36 E 2836.46 N 6156.66 E 2869.29 N 6235.37 E 2902.42 N 6312.47 E 2937.58 N 6392.88 E 2971.59 N 6469.97 E 3005.77 N 6549.34 E 3038.68 N 6627.80 E 3071.21N 6706.41E 3103.21 N 6785.51 E 3134.58 N 6862.80 E 28 December, 1999 - 14:53 -5- Dogleg Rate (°/~ 00ft) 1813988.22 N 166194.73 E 1813998.99 N 166217.97 E 1814009.87 N 166241.77 E 1814020.37 N 166264.53 E 1814031.65 N 166288.41 E 1814042.81N 166312.18 E 1814053.84 N 166335.11 E 1814065.01N 166357.98 E 1814075.95 N 166381.89 E 1814086.37 N 166405.53 E 1814096.69 N 166429.53 E 1814106.93 N 166453.57 E 1814117.20 N 166477.32 E 1814127.46 N 166501.02 E 1814137.78 N 166524.90 E 1814147.91 N 166548.71 E 1814158.04 N 166572.65 E 1814168.27 N 166596.10 E 1814179.12 N 166620.55 E 1814189.61N 166643.99 E 1814200.16 N 166668.13 E 1814210.31 N 166691.99 E 1814220.36 N 166715.89 E 1814230.24 N 166739.95 E 1814239.93 N 166763.46 E RECEIVED 1.035 0,463 0,876 1.982 0.272 0.719 1.529 0.965 2.347 0.360 1.278 0.921 0.525 0.474 2.325 0.508 0.391 1.143 0.360 0.746 1.645 0.712 1.212 0.738 0.457 Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) Comment 5503.47 5587.49 5673.34 5755.59 5842.19 5928.33 6011.77 6095.23 6181.49 6266.25 6351.97 6437.68 6522,57 6607.28 6692.65 6777.53 6862.80 6946.71 7034.47 7118.74 7205.15 7290.22 7375.27 7460.56 7543.95 Continued... DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9528.21 65.130 66.650 4743.78 4863.68 9622.92 64.720 66.100 4783.91 4903.81 9717.81 64.450 65.850 4824.64 4944.54 9813.63 64.280 65.600 4866.09 4985.99 9907.50 63.800 66.270 4907.19 5027.09 10002.50 61.870 65,190 4950.56 5070.46 10097.24 59.320 68,060 4997.08 5116.98 10191.43 58,450 67,260 5045.75 5165.65 10285.77 56.430 68,480 5096.52 5216.42 10382.22 53.670 69.150 5151.77 5271.67 10469.98 51,080 71.050 5205.34 5325.24 10565.50 48,800 73.470 5266.82 5386.72 10662.29 46.650 75,040 5331.93 5451.83 10756.75 44.300 76.560 5398.16 5518.06 10851.23 41.650 76.730 5467.28 5587.18 10944.26 39,280 79,480 5538.06 5657.96 11037,46 36,560 80.850 5611.58 5731.48 11155.84 34,440 82.470 5707.95 5827.85 11209,74 31,950 85.240 5753.05 5872.95 11307.05 27,560 89.540 5837.52 5957.42 11403.24 26,310 90.360 5923.28 6043.18 11500.59 23.720 89.080 6011.49 6131.39 11597.38 23,120 88.160 6100.30 6220.20 11695.42 22.600 88.760 6190.64 6310.54 11701.20 22.630 88.620 6195.98 6315.88 3167.31 N 6941.08 E 3201.69 N 7019.68 E 3236.58 N 7097.96 E 3272.10 N 7176.71E 3306.51 N 7253.77 E 3341.25 N 7330.82 E 3374.01 N 7406.55 E 3404.65 N 7481.14 E 3434.61 N 7554.78 E 3463.19 N 7628.48 E 3486.86 N 7693.82 E 3509.16 N 7763.43 E 3528.61N 7832.35 E 3545.14 N 7897.63 E 3560.02 N 7960.28 E 3572.49 N 8019.34 E 3582.30 N 8075.76 E 3592.29 N 8143.77 E 3595.47 N 8173.09 E 3597.79 N 8221.29 E 3597.84 N 8264.86 E 3598.01N 8306.02 E 3598.94 N 8344.48 E 3599.96 N 8382.55 E 3600.01N 8384.77 E 28 December, 1999 - 14:53 -6- Global Coordinates Dogleg Northings Eastings Rate (m) (m) (°/lOOft) 1814250.03 N 166787.26 E 1,785 1814260.64 N 166811.16 E 0.681 1814271.40 N 166834.97 E 0.371 1814282.35 N 166858.91 E 0,295 1814292.97 N 166882.34 E 0.821 1814303.68 N 166905.77 E 2.269 1814313.79 N 166928.80 E 3.769 1814323.25 N 166951.48 E 1.176 1814332.51 N 166973.88 E 2.403 1814341.33 N 166996.30 E 2.918 1814348.66 N 167016.18 E 3.413 1814355.57 N 167037.36 E 3.075 1814361.61 N 167058.33 E 2.525 1814366.75 N 167078.20 E 2.739 1814371.39 N 167097.27 E 2.808 1814375.29 N 167115.25 E 3.189 1814378.37 N 167132.43 E 3.055 1814381.53 N 167153.14 E 1,959 1814382.54 N 167162.08 E 5.408 1814383.33 N 167176.76 E 5.014 1814383.41 N 167190.04 E 1.356 1814383.53 N 167202.59 E 2.718 1814383.88 N 167214.31 E 0,726 1814384.25 N 167225.91E 0.581 1814384.27 N 167226.59 E 1,066 RECEIVED Alaska State Plane 4 KUparuk 1L Vertical Section (ft) Comment 7628.78 7714,57 7800.27 7886,66 7971.05 8055,56 8138.08 8218.69 8298.17 8377.14 8446.48 8519.18 8590,11 8656.52 8719.88 8778.96 8834.57 8900.85 8928.99 8974.05 9013.97 9051.73 9087.31 9122.59 9124.64 Cont~ued... DrillQuestl.0~O4e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11770.00 22.630 88.620 6259.48 6379.38 3600.65 N 8411.24 E Global Coordinates Dogleg Northings Eastings Rate (m) (m) (°/100ft) 1814384.51N 167234.66 E 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.694° (30-Oct-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 66.300° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11770.00ft., The Bottom Hole Displacement is 9149.52ft., in the Direction of 66.825° (True). Alaska State Plane 4 Kuparuk 1L Vertical Section (ft) Comment 9149.13 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11770.00 6379,38 3600.65 N 8411.24 E Projected Survey 28 December, 1999 - 14:53 -7- RECEIVED Continued... DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 1L-28 Your Ref: API-500292295100 Surveyed: 18 November, 1999 North Slope Alaska Alaska State Plane 4 KUparuk 1L Survey tool program From' Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 1 ~ 770.00 Vertical Depth (ft) 6379.38 Survey Tool Description MWD Magnetic RECEIVED 2.000 An~0r~ 28 December, 1999 - 14:54 - 8 - DrillQuest 1.05.04e ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 2000 Mr. Tom Maunder Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1L-28 Additional Information for Sundry for Annular Injection Dear Mr. Commissioner: Enclosed is additional information to be attached to the sundry recently submitted for KRU 1L-28. If there are any questions, please call 265-6531. Sincerely~3 /,~/~ Drilling Engineer~ AAI Drilling WBL/skad RECEIVED ght., 000 /~10il & Gas Cons. Commisfion DRILL SITE MAINTENANCE PUMP REPORT WIRELINE / D.S.O. / DRILLING / OTHER I JOB TYPE /~/LJ~JU ' DS/WELL MATERIALS !BBLS MATERIALS BBLS MATERIALS BBLS '~~ O ~ /'~o~ '~ ~.S- ~, " " ! .... PUMP OPERATOR CREW NAMES SIGNATURE ~0 ~ ~000 Anc~or~e Re: 1L-28 InjeclJon test-PTD 199-098 r_.. , Subject: Re: 1L-28 Injection test--P'lD 199-098 Date: Thu, 17 Feb 2000 10:17:25 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: William B Lloyd <WLLOYD@mail.aai.arco.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us> Bill, You are correct...the hot oil unit test will develop the second pressure plot to allow a final determination for annular disposal. Please forward the plot when available, I attach it to the sundry and make the determination according to the information. Please call with any questions. Tom. Maunder William B Lloyd wrote: > Tom, > After we talked this afternoon, I recalled that this past spring or summer, > Blair had requested we start doing pre-permit injection tests on these wells we > were requesting Al permit. Basically what we have been doing is to get a hot > oiler on the annulus with a chart and get a LOT that way. If that's still ok > with you guys, that's what I'll do on 1L-28. Let rte know. Thanks > Bill Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of I 2/17/00 10:17 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator 5. Type of Well: ARCO Alaska, Inc. Development__X 3. Address Exploratory_ P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service __ 4. Location of well at surface 89' FSL, 216' FWL, Sec. 29, T11 N, R10E, UM At top of productive interval 1599' FNL, 2116' FEL, Sec. 28, T11N, R10E, UM (ASP:548472.7, 5952701.2) At effective depth At total depth 1597' FNL, 1918' FEL, Sec. 28, T11 N, R10E, UM (ASP: 548670, 5952705) Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other _X Annular Injection 6. Datum elevation (DF or KB feet) RKB 31 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 L-28 9. Permit number/approval number 199-98 10. APl number 50-029-22951 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Conductor 84' Surface 6515' Intermediate 11086' Production 11738' 11770 6379 11668 6285 Size 16" 9.625" 7" 3.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu. Yds High Early 702 sx AS IIIL, 806 sx Class G 115 sx Class G 255 sx Class G Measured Depth TrueverticalDepth 115' 115' 6546' 3588' 11117' 5796' 11769' 6383' Perfo ration depth: " measu red true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 11518'-11538' MD 6147'-6166' MD 3.5", 9.3#, EUE Mod @ 10977' Baker ZXP LT pkr @ 10944', No SSSV RECEIVED FEB 09 2000 0il & Gas Cons. Cor~F.,issio~ Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation February 23, 2000 6. If proposal was,verbally,,~,_z.~ ")' ' ~'appr°ved. ~.~;'"~: ~,~.'r~ ~,~ Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedRandyThomas/,//~*-~,'~;r,~,,'"'~ ~'~'~ Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Questions? Call Bill Lloyd 265-6531 Date Prepped by Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance _ Mechanical Integrity Test__ Subsequent form required 10- .... Approved by order of the Commission SIGNED BY.' (~hristenson Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Casing Detail - E-5/8" $ ur/ace ca$//7_o W E L L: 1 L. 2 8 ARCO Alaska, Inc. DATE: 10110199 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS - 34.80' TOPS 9-5/8" Landing Joint (RKB) 34.80 9-518" FMC GEN IV FLUTED MANDREL HANGER 1.91 34.80 166 its 9.518", 40#, L.80 BTC.MOD (jts 3.13, 15.53,55.58,60.69,71.102,104.173) 6433.53 36.71 Gemeco Float Collar 1.45 6470.24 2 jts 9-518", 40//, L.80 BTC-MOD (jts 1.2) 72.99 6471.69 Gemeco Float Shoe 1.68 6544.68 BTM OF SHOE @ 6546.36 6546.36 TD of 12.1/4" hole - 6560'MD Leaving 13.64' of rat hole 54 Gemeco Bow Spring CENTRALIZERS 1lit on first 54 jts 1 Gemeco Bow Spring CENTRALIZER on jt #173 Run 168 its. Leave 5 jts in the pipe shed (its.14,54,59,70,103) I:t~marlr$: Str[t~g Weights ~ith Bioe. l~$: x~xl~ ti#, x~xlt Bn, xxlt ~locit$. Ra# xxx }o[#t$ o! ,~,[ag. ~a$i## w[th 8.§"plastic r~l~l~it. 115~# ~,t.o.tff~ ~Ot~O thr, arl compoun# ot~ all ,, Pool E Orillin# Supervisor: G.R. Whitloc~ ARCO Alaska, Inc. Cementing Details Well Name: 1L-28 Repert Date: 11109199 Report Number: 1 Rig Name: Pool 6 AFC No.: AKO043 Field: Kuparuk River Unit Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9.625 12.25 66.2 6546.36 6470.24 Centralizers State type u~e~, inten/a/$ covers# an# spec~n§ Comments: ! bowspring centralizerljt on firct 54 its. 1 bowspring centralizer on jt #173. Fir$t 2 centralizers on stop rings Mud Weight: PV(pdor cend): PV(after cond}: YP{pdor cend): YP(after cond): Comments: 10.2 38 25 42 19 Gels before: Ge!s after: Total Volume Circulated: 23168 7/22 :Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.4 Spacer 0 Comments:Typo: Volume: Weight: 1st 3 bbl contained 5# cello-flakes ARCO Spacer 50 10.5 Lead Cement 0 Comments: Type: I Mix wtr ternp: No. of Sacks: I Weight: Yield: AS Iii LiteJ 80 702J 10.7 4.43 Additives: G wi 50%D124, 9%D44, 0.4%D46, 30%D54,1.5%S1,1.5%079 GIll 80 806 15.6 1,17 Additives: G wi 1% S1, .2%D46, 0.3%D65 Displacement 0 Comments: Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: 6.5 6.5 270 Reciprocation length: Reciprocation speed: Sir. Wt. Down: 15 1 fpm 120 Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 490 493 221 Calculated top of cement: CP: Bumped pIug: Floats held: Surface Date:1118199 No Yes Time:l 8:06 Remarks:Good returns throughout job. Circulated 309 bb] slurry to surface. Had trouble mixing cement at start of tail slurry. Reciprocated until tail started around shoe. Cement Company: DS Rig Contractor: Approved By: POOL G.R. Whitlock CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 L-28 Reason(s) for test: Casing Size and Description: 9-5/8" 40#, L-80 BTC Casing Setting Depth: 6,546' TMD 3,584' TVD Mud Weight: 8.5 ppg Date: 11/9/99 Supervi :s~r: Whitlock/Reynolds [] Initial Casing Shoe Test ~- ~,,~. [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher IVl~c~Vei~4i~ Hole Dept~ 6,~' T~ ~ 3,~0' T~ Length of Open Hole Section: ~ 34' EMW - Leak-off Press. + Mud Weight 0.052 x TVD = 1,270 psi + 8.5 ppg 0.052 x 3,600' EMW for open hole section = 15.3 ppg Pump output = 0.0846 bps Fluid Pumped = 2.3 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,(:~)0 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,(;O0 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi --e,-- LEAK-OFF TEST ~ CASING TEST .... ...... LOT SHUT IN TIME / -=,;,~ CASING TEST SHUT IN TIME ~tI' lONE ~ TIME LINE STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ...................... 9__s__'t_k__s_ ......... _q__p__s_i_ ..... . 5stks . 280 psi .................... ZE.s__t.k_.s_ ...... Ls__O__e_s_] .... .................... .2_ .o_.s__tk_.s_ ..... Z,__o_o__o__Es!_. .................... _~..s_.s_ _t.k_.s_ ..... 1,__2_o__o__p__s!_. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... _q__s_L~_s_ ......... _o___p__s! .... ...................... _S___s_t__k_s_ ....... _3__o__q__p__s_L_j ..................... _!_0___s_tk__s_ ...... .................... _!_s___s_t_k__s_ ...... _9_s__O__e__sL_~ .................... _2_ 9_ _ _s_tk_ _s_ ..... _!,_Lo_o___p__s_L .................... _2__s___s_tk__s_ ..... _! _, _~_ _9_ _ _p_ _s_ L .................... _~Z.s__t.k_.s_ ..... ! ,_ _2_7_ _O_ _ _P_ _S! ....................... _a_ 9_ _ _s_tk_ _s_ ..... .......................................................................... _3__5___s_t_k__s_ ..... _1_,_8__5_0___p_~' 40 stk$ 2,100 i ................ .~ ................ j. ................. .~ i .................................. i .................. .................... _4_.5_._s!k_.s_ ..... _2_,_~_ _5_0__ _P_ _s_L. .................... .S._O_._s.t.k_.s_ ..... ~,_6__~__p__s!_' ........................................................................ .S_.S_._s_t.k_.s_ ..... .2_ , _S_ _Tk p_ .s_ i_ _' ~ 58stks . 3,050 psi., i ~. ................................ J ~ .................. i ................................. j ................. i i i i I ................ .=1 ................ ~. ................. i i ................. i- ............... -~ .................. i ................ -t ................................. I I ................ -I ................ I· ................. I ] I I I SHUT IN TIMEI SHUT IN PRESSURE 1.0 Tin 2,995 psi 1 "--~'.'E~-i~ ...................... .... _0_:_0_ __m_!p_ ...................... _1_ _, _2Z_O_ _ p_ _si ....... __4:_o___m__i_n_ ................... ] _ _ _2_, ?_ _~_o_p_ _s_i_ _ ] .... _! : 9_ _ _m_ ! _n_ ...................... 1,__2_o__q__p__s! ..... __5:_o___mj_n_ .................... L _2_,_~Z_S_p_ _s_Lj ...................... _t ,_ _a_o_ _o_ _ p_ _sl ..... __6:_o__m_i.n_ ................... ____3_:9___m_Ln- ...................... 1,__2_o__o___p__s_i_ ..... __7:p__mj_n_ ................... ~___2_,_~_?_5_p__s_L~ 4.0 min 1,175 psi 8.0 min ...................................................................................... L__5_. 9___m_i_n_ ................... i__ldZ.s__e_sl ...... .9_..o__.mj.n_ ................... i 6.0min . i 1,150psi j i 10.Omin i 2,955 psi ................................................. ~ ................ ~. ............... J ................. i___Z.p_..m_!9_ ................... j__l,!_s_ 9___p__s_L.' .... ]_9:.o__.mj.n_ ................... :._~,_9._5.s___p_.s_[_j i 8.0 min i 1,150 psi _2__0:_0_ _m_j_n_ i _2_;_9_5_0_ ! 9.0 Tin ~ 1,150 psi 25.0 Tin I 2,950 psi I ................................. 'l' ................. =1 I ................................. 1 ................. L_3__o_:p_..m_!p_ ................. i__ 1,~_.s_9__.p__s.~_ ..... _s__o:_o___mj_,_ .................. L .2_,_9.§.o__ .p_ .s_L j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Schlumberger NO. 121121 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1L-03A 20011 SCMT 991126 1 1 L-28 20009 SCMT 991219 1 1R-01A 20013 SCMT 000108 1 2N-34~ U l~ 99~50 :.s~ -$~ qq,~{~ 990827 I I 1 PI t' FI~/FI) Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. FEB 04 ~_000 Alaska Oil & G~!'5 L.,.,.;:,. Anchorage 1/25/00 28-Dec-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1L-28 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 11,770.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ¢ ,'~"~" 04 2000 - ,%; ',: i u-- i ..~--~'~., ~; ~-~:~lVl .. ,~,H~.~'...., -: Fax No. 907.265.1155 [] Ument - 0 For Review 0 ~ ~ 0 ~ ~ . 0 ~ Recycle T l,o, q s /AY KRU 1L-28 Proposed Completion TAM 7-5/8" Pod Collar Stnd. Grade BTC Threads (+/- 1000' MD / 1000' TVD) Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 6549' MD / 3588' -I'VD) All Depths Reference Pool 6 RKB ; 5-1/2" 15.5# L-80 LTC Mod [~t (+/- 11160' MD / 5840' TVD) 3-1/2" 9,3ff L-80 Special C~earance BTC Mod Tubing (+/- 11770' MD / 6383' TVD) i. 3-1/2" Gan IV tubing hanger with 3-1/2" L-80 EUE BRD-Mod pin down H, 3-1/2" L-80 9,3# EUE 8RD-Mod tubing to sur[ace G. 3-I/2" Camco 'DS' nipple w/2.812" No-Go profile set at +/- 500' MD. F. 3-1/2" L-BO 9.3# EUE BRD-Mod tubing to 'DS' Landing Nipple w/3-1/2" x 1" Camco 'KBG-2-9' Mandrels w/DV valves (Max OD 4.725", ID 2.gO"), 15' L-80 crossover hand[ling pups (BTC x Special Clearence EUE 8rd) installed. Spaced out as follows. GLM # TVD-RKB MD-RKB 1 TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD E, 3-1/2" x 1' Camco 'KBG-2-9' Mandrel w/DCK-2 valve and latch (Max. OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (BTC x Special Clearence EUE 8rd) ins[ailed on GLM, D. Ijt 3-1/2" L-80 g.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'W' landing nipple with 2.813" ID and Selective prolile B. Ijt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker '45-40' special clearance PBR w/10' of effective stroke. 4.80" O.D. seal bore 4.0" I.D., seals 3.0" I,D, Model 'KBH' Anchor Seal Assembly made up on bottom (2.78" I.D.) and 6' L-80 handling pup installed on top of PBR. 3.1/2" x 5" Baker 'SABL-3' permanent packer run as a liner top packer (Minfmum ID through packer 2.780"). 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing from Polish Bore to Packer. 3-1/2° Halliburton 1~olish Bore' BTC Pin x Pin w/8" of effective slroke (Max OD 3.75", Seal Bom ID 2,75"). 2 - 10' 3-1/2~ 9.3# L-80 BTC Pup Joints. 3-1/2" Ha[l~urton 'XN' Landing NiRore BTC Pin x Special Clearance Box w/2,75" ID and No-Go profile (Max OD 3.94", Min ID 2.635"). 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing from Landing Collar to ~(N' Nipple. 3-1/2" Baker Landing Collar EUE 8rd Box x Pin w/4.25" OD. 1 Joint 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing. 3.1/2" Baker Float Collar BTC Box x BTC Pin w/4.25" OD. 2 Jolnl 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing. 3-I/2" Baker Float Shoe BTC Box up w/4.25" OD. TAB, 9/20/g9, vl KRU 1L-28 Proposed Completion 12-1/4' Hole Surface csg. 9 5/8" 40# L-80 BTCM (+/- 6549' MD / 3588: TVD) All Depths Reference Pool 6 RKB 8-1/2" Hole 7" 26# L-80 BTC Mod (+/- 11160' MD/5840' TVD) 6-1/8" Hole 3-1/2" 9.3# L-80 EUE Mod Tubing (4/- 11770' MD / 6383' TVD) I. 3-I/2" Gen IV tubing hanger w~th 3-1/2" L-80 EUE 8RD-Mod pin dow~ H. 3-1/2" L-80 9.3f EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 'DS' nipple w/2.812" No-Go profile set at +/- 500' MD. f. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to 'DS' Landing Nipple w/3-1/2" x 1" Camco 'KBG-2-9' Mandrels w/DV valves (Max OD 4.725", ID 2.90"). 15' L-80 crossover handlling pups installed. Spaced out as follows. GLM ~ TVD-RKB MD-RKB t TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD E. 3.1/2" x 1" Camco 'KBG-2-9' Mandrel w/DCK-2 valve and latch (Max. OD 4.725", ID 2.90'). 15' L-80 crossover handling pups (BTC x Special Clearance EUE 8rd) installed on GLM. D. Ijt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'W' landing nipple with 2.813" ID and Selective profile B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker '80-40' PBR w/10' of effective stroke, 4,80" O.D, seal bore 4.0" I.D., seals 3.0" I.D, Model ~BH' Anchor Seal Assembly made up on bottom (2.78" I.D.) and 6' L-80 handling pup installed on top of PBR. 3-1/2" x 7" Baker 'ZXP' liner top packerw/Baker HMC hanger (Minh'num ID through packer 2,780"). 3-1/2" 9.3# L-80 EUE Mod Tubing from Polish Bore to Packer. 2 - 10' 3-1/2" 9.3# L-BO BTC Pup Joints, 3-1/2' Halliburton 'XN' Landing Nipple BTC Pin x Special Clearance Box w/2.75" ID and No-Go profile (Max OD 3.94", Mtn ID 2.635"). 3-1/2" 9.3~ L-80 EUE Mod Tubing from Landing Collar to 'XN' Nipple, 3-1/2" Baker Landing Collar EUE 8rd Box × Pin w/4.25" OD. 1 Joint 3-1/2" 9.3# L-80 EUE Mod Tubing. 3-1/2" Baker Float Collar BTC Box x BTC Pin w/4.25" OD. 2 Joint 3-1/2° 9.3# L-80 EUE Mod Tubing. 3-1/2" Baker Float Shoe BTC Box up w/4.25" OD. TAB, 9/20/99, vl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _X Pull tubing _ Variance _ Perforate _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 89' FSL, 216' FEL, Sec. 29, T11N, R10E, UM At top of productive interval 1588' FNL, 2112' FEL, Sec. 28, T11N, R10E, UM At effective depth At total depth 1589' FNL, 1891' FEL, Sec. 28, T11 N, R10E, UM Other _ 5. Type of Well: Development__X Exploratory __ Stralig raph ic __ Service 6. Datum elevation (DF or KB feet) RKB 31 [eet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 L-28 9. Permit number/approval number 99-98 10. APl number 50-029-22951 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11770 true vertical 6383 Effective depth: measured 11770 true vertical 6383 Casing Length Size Conductor 120' 16" Surface 6518' 9.625" Intermediate 11129' 7" Production 11739' 3.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured Depth True vertical Depth 9 cu. Yds High Early 120' 120' 71o sxAS 111,830 sx Class G 6549' 3588' 130 sx Class G 11160' 5840' 240 sx Class G 1 1 770' 6383' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A Packers & SSSV (type & measured depth) N/A 13. Attachments Description summary of proposal X Detailefl operations program ~ BOP sketch 14. Estimated date for commencing operation October 13, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil m Gas m Suspended m Service __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~j~,. ~_~,, ('~%~ Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Questions? Call Dill Lloyd 265-6551 Date Prepared by Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- 40 ~ oo¢ j,~tuINAL SIGNED BY ,,,!e(~ .~ Approved by order of the Commi~ion ~.ki .~.~i~f~n~on ......... ;,;OO'` ~,~ C~~missi°ner Approval no..~ Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE TON Y KNO WL ES, GO VEI~NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 7. 1999 Chip Alvord Drilling Engineering Supe~'isor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1L-28 ARCO Alaska. Inc. Permit No: 99-98 Sur Loc: 89'FSL. 216'FEL. Sec. 29. T1 IN, R10E. UM Btmhole Loc. 1589'FNL. 1891'FEL. Sec. 28. T11N. R10E. UM Dear Mr. Alvord: Encloscd is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integnt}.., Test (FIT). Cementing records. FIT data. and anv CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing atmulus of a well approved for annular disposal on Drill Site iL must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice max- be givcn bx' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 l'~i'~ype ofwork: Drill [] Redrill O I lb. Type ofwell. Exploratory D StratigraphicTest J~J Development Oil J~J Re-entry F~ Deepen FIJ Service D Development Gas D Single Zone BI Multiple Zone BI 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 31', Pad 81 feet ,3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25660 ALK 470 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 89' FSL, 216' FEL, Sec. 29, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1588' FNL, 2112' FEL, Sec. 28, T11N, R10E, UM 1L-28 #U-630610 At total depth 9. Approximate spud date Amount 1589' FNL, 1891' FEL, Sec. 28, T11N, R10E, UM October 11, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1588' @ Targl feet 1L-20X 15.0' @ 100' feet 2560 11770 'MD/6383 'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250' MD Maximum hole angle 64 Maximum surface 2117 psig At total depth (TVD) 2512 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Len~lth MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 89' 31' 31' 120' 120' 9.875" 7.625" 29.7# L-80 BTCM 6518' 31' 31' 6549' 3588' 482 sx AS III & 558sx Class G 6.75" 5.5" 15.5# L-80 LTC Mod 11129' 31' 31' 11160' 5840' 64 sx Class G 4.75" 3.5" 9.3# L-80 BTCM 610' 11160' 5840' 11770' 6383' 10 ex Class G ~%,~A\~, 19. To be completed for Redrill, Re-entry, and Deepen Operations. I,.~"~ ~ Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet 0RII31NAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor ,i-'*~, j~ ~" .~ i~,~'; ~' ¢,%, ~ Surface ~:,~ ~,.~ ~. ¢ % Production Perforation depth: measured A!~,S~(~ 8ii ~' GbtS 0OilS, ~;0[i~ Anchorage true vertical 20. Attachments Filing fee [~] Property Plat BI BoP Sketch [~] Diverter Sketch ~] Drilling program [~] Drilling fluid program [~ Time vs depth plot BRa*action analysis D Seabed report F~ 20 AAC 25.050 requirements BI 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Carl Mark Chambers 265-131~. Signed /~_~, ~/', ~ Title: DdllingEngineeringSupervisor Date 'Chip Alvord prcnared hv Sharon Commission Use Onl} Permit Number J APlnumber IAppr°va' date~ ~'~ OiC~ ieee cover letter .~/~;:;~-- ~;~f~ 50- (~..~-- .~.2. ~;~,~-// - (~)~--____Jforotherrequirements Conditions of approval Samples required D Yes ~ No Mud Icg required [~ Yes [~ No Hydrogen sulfide measures ]~ Yes D No Directional surveyrequired J~ Yes D No for BOPE D2M: D 3M; D ~ ~, 10M;D Required working pressure Other: ~JRIGINAL SIGNED' BY Robert N. Chdstenson by order of -¢~ Approved by Commissioner the commission Date / 0- ~ --~ Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 September 23, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 1 L-28 89' FSL, 216' FEL, Sec 29, T11 N, R10E, UM 1588' FNL, 2112' FEL, Sec. 28, T11 N, R10E, UM 1589' FNL, 1891' FEL, Sec. 28, T11N, R10E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1L pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1 L pad. The well is designated as a producer and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" surface casing string, a 5-1/2" intermediate casing string, and a 3-1/2" production liner. The well will be drilled and completed using Pool Rig 6. Completion plans call for running 3-1/2" production tubing with gas lift mandrels as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 9) 10) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARC©'s designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Meg Kremer, Geologist (20 AAC 25.071) 265-6460 Please note that the anticipated spud date for this well is October 11, 1999 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Sincerel.~ Tohp°e~a~o nA~ ~rr~nk~aEYn g i n re~ Attachments: CC: KRU 1L-28 Well File Chip Alvord Bill Lloyd Jeff Corwith ATO- 1030 ATO- 1008 ATO- 1284 KRU 1L-28 Proposed Completion TAM 7-5/8" Port Collar Stnd. Grade BTC Threads (+/- 1000' MD / 1000' -r'VD) Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 6549' MD / 3588' -I'VD) All Depths Reference Pool 6 RKB 5-1/2" 15.5# L-80 LTC Mod (+/- 11160' MD / 5840' TVD) 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing (+/o 11770' MD / 6383' TVD) I. 3-1/2" Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 'DS' nipple w/2.812" No-Go profile set at +/- 500' MD. F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to 'DS' Landing Nipple w/3-1/2" x 1" Camco 'KBG-2-9' Mandrels w/DV valves (Max OD 4.725", ID 2.90"). 15' L-80 crossover handlling pups (BTC x Special Clearence EUE 8rd) installed. Spaced out as follows. GLM # TVD-RKB MD-RKB 1 TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD E. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DCK-2 valve and latch (Max. OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (BTC x Special Clearence EUE 8rd) installed on GLM. D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'W' landing nipple with 2.813" ID and Selective profile B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker '45-40' special clearance PBR w/10' of effective stroke. 4.80" O.D. seal bore 4.0" I.D., seals 3.0" I.D. Model 'KBH' Anchor Seal Assembly made up on bottom (2.78" I.D.) and 6' L-80 handling pup installed on top of PBR. 3-1/2" x 5" Baker 'SABL-3' permanent packer run as a liner top packer (Minimum ID through packer 2.780"). 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing from Polish Bore to Packer. 3-1/2" Halliburton 'Polish Bore' BTC Pin x Pin w/8" of effective stroke (Max OD 3.75", Seal Bore ID 2.75"). 2 - 10' 3-1/2" 9.3# L-80 BTC Pup Joints. 3-1/2" Halliburton 'XN' Landing Nipple BTC Pin x Special Clearance Box w/2.75" ID and No-Go profile (Max OD 3.94", Min ID 2.635"). 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing from Landing Collar to 'XN' Nipple. 3-1/2" Baker Landing Collar EUE 8rd Box x Pin w/4.25" OD. 1 Joint 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing. 3-1/2" Baker Float Collar BTC Box x BTC Pin w/4.25" OD. 2 Joint 3-1/2" 9.3# L-80 Special Clearance BTC Mod Tubing. 3-1/2" Baker Float Shoe BTC Box up w/4.25" OD. TAB, ~2~99, vl GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER UNIT- PRODUCER KRU 1 L-28 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up Pool Rig 6. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/6549') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering: 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: TAM Port Collar will be placed in the 7-5/8" casing 1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). Drill 6-3/4" hole to 5-1/2" intermediate casing point (+/- 11160') according to directional plan running LWD logging equipment as needed. Run and cement 5-1/2" 15.5# L-80 BTCM casing string to surface. Adequate cement will be pumped to place cement top +\- 500' above the casing shoe. Displace cement with mud. 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. 10. Nipple up BOPE and test to 5000 psi. Record results. Pressure test casing to 3,500 psi for 30 minutes per AOGCC regulations. Record results. 11. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). Drill 4-3/4" hole to well total depth (+/- 11770') according to directional plan, running LWD logging equipment as needed. Run and cement 3-1/2" 9.3# L-80 BTCM Special Clearance liner with SABL-3 permanent packer. Make a cleanout run with bit and scrapers if necessary. Displace to filtered seawater. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3500 psi. Freeze protect well. Pull landing joint. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. Release rig. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. . . . . 12. 13. 14. 15. 16. 17. 18. 1L-28 TAB, 9/20/99, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 L-28 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casin~] 8.5-10.0 16-26 25-50 150-250* 10-20 15-40 8-15 8-10 6-9% Drill out to 5-1/2" Intermediate casing 9.5-10.5 4-8 5-8 35-40 2-4 4-8 8-15 9.5-10 4-7% Drill out to TD 11.9-12.4 5-15 5-12 30-40 2-4 4-8 4-5 through Kuparuk 9.5-10 <11% Drillinq Fluid System: Pool Rig 6 Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaners *Spud mud should be adjusted to a FV between 150-250 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 an expected surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 2117 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3588 ft)(0.70 - 0.11 ) = 2117 psi In the intermediate hole section, maximum anticipated surface pressure is calculated using an expected intermediate casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 3445 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 = (5840 ft)(0.70 - 0.11) = 3445 psi 1L-28 TAB, 9/20/99, vl Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 1L-28 target location are expected to be ~3600 psi (0.61 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.2 ppg would be predicted as the maximum mud weight needed to safely drill in this formation using conventional drilling methods, assuming a TVD of 5925'. Well Proximity Risks: The nearest existing well to 1L-28 is 1L-20X. As designed, the minimum distance between the two wells would be 15.0' at 100' MD. Drilling Area Risks: Risks in the 11.-28 drilling area include high pressures in the Kuparuk formation, lost circulation and potential borehole instability in and below the permafrost formation. High Kuparuk formation pressures will be addressed by setting intermediate casing above the Kuparuk C sands. Lost circulation and borehole instability will be addressed with lost circulation material (LCM), high viscosity spud mud, and reduced circulating rates as needed. Based on previous DS 1L drilling results, 10.5 ppg mud should be adequate to control formation pressures from spud through intermediate hole TD without resulting in lost circulation. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on 1L pad or hauled to the nearest permitted Class II disposal 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 1L-28 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We anticipate that 1L-28 will be requested to be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. All necessary documentation for the permitting of this well for annular injection will be provided after the well is completed. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 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 shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.5 ppg for drilling fluid wastes. Using 12.5 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure Max Pressure = (12.5 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.5 ppg) * (0.052) * (3588') + 1,500 psi = 3832 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: 1 L-28 TAB, 9/20/99, vl Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 3 BTCM 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3-1/2" *9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 1L-28 TAB, 9/20/99, vl Created by rrx-e FOR: BROCKWAY Dole plott~d : 22-S~p- t ggg Plot Reforonc~ {e 25 Version ~6 . Coordrnotes ora {n feel reference slot {2B. True Vertical Depths ore reference RKB (Pool 6).{ 500 1000 1500 '+- 2000 2500 -i-- Q $000 3500 L 4O00 45OO I 5OO0 55O0 6000 65OO 7000 ARCO Alaska, Inc. Structure: Pad 1L Well: 28 Field: Kuporuk River Unit Louafion: North Slope, Alaska ~ RKB ELEVAITON: 121' 0.00 2.00 Begin 2 Deg/lO0' Build 6 oo 66.3 AZIMUTH ia.aa BegS. 5 Deg/~oo' 8,,~,d 8976' (TO TARGET) 20.00 ***Plane of Proposal*** 0.00 DLS: 5.00 deg per 100 ft 0,00 0'6000.00 Base Permafrost West Sa/Bk Casing Pt 80 64.35 DEG Begin Drop & Turn 61 7~ C50 c4o DLS: ,3.00 de9 per 100 f~ 50.61 45.1B CSO 59,88 C20 34 76 EOC K..-1K-1 )~);~- ~9 69 Top C3 Target-Top C4/Begin Angle urop --~-; ' Top C1 Top B Shale Top A4 Top M{luveoch TD-Cosing Pi I { I I I I I I I I { I { I I { I I I I I I I I I I II I I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 ,:3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section (feet) -> Azimuth 66,$0 with reference 0,00 N, 0,00 E from slot #28 cre*~e~ by ,'~x,. FOR: BROCKWAY Dote plotted: 22-Sep- t gg9 Plot Reference {e 2B Veteran 1~6 . Coord~notea ora in feet reference slot ~28. True Vertlcol Depths ore reference RKB (Pool ARCO Alaska, Inc. Structure: Pad 1L Well: 28 Field: Kuparuk River Unit Loaation: North Slope, Alaska East (feel) -> 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4BO0 5200 5600 6000 6400 6BO0 7200 7600 8000 B400 BBO0 ] , [ ~ [ ] ~ ~ [ ] [ ] [ [ [ ~ t ] [ ] ~ ] j ~ [ j [ ~ ~ ~ ~ [ ~ ~ ] ~ ~ j [ j ~ [ 4000 Top Miluveach TD-Cas{ng Pt Top A4 ~ Top~,B Shale lop ~, / Top C3 ~ --~ Torget-Top C4/BegJn Angle Drop / Bose HRZ / c2o ~ c5o ~ C40 ~ C50 ~ Beg~n Drop & Turn~ ~ ,r- ~_ ~ [~'~eo 't~b Base westwest SokSok ~)~' ~se TARSET TOP C4: I J58B' FNL, 2J~2' FELI st Sak [ SEC. 2~, T~N, R~OE J JTARGET TOP A5: J 1588' FNL, 2014' FEL SEC. 28, T11N, RI OE TD LOCATION: 1589' FNL, 1891' FEL SEC. 28, T11N, RIOE / EOC ../ Bose Perm. efrost ~,~,~ Begin 5 Deg/lO0' Build Begin 2 De§/lO0' Build 3600 3200 2800 2400 2000 1600 1200 8OO 40O ESTIMATED SURFACE LOCATION: 89' FSL, 216' FEL SEC. 29, T11N, RIOE Created by rlxee FOR: BROCI~AY Date plotted: 22-5ap-1999 Plot Reference ts 28 Version ~6 . Coordinates are in feet reference slot 1~28. True Vertical Depths are reference RKB (Pool 5), INT~'.Q ARCO Alaska, Inc. Structure: Pad 1L Well : 28 Field: Kuparuk River Unit Looatlon : North Slope, Alaska Point Begin 2 Deg/lO0' Bui Begin 5 Deg/lO0' Bui Base Permafrost EOC ~Top West Sa k Base West Sak 7-5/8 Casing Pt C80 Camp SS Begin Drop & Turn C50 C40 C50 C20 Base H RZ 5-1/2 Casing Pt K-1 EOC Target-Top C4/Begin Top C3 Top C1 Top B Shale EOC/Top A5 Top A4 Top Miluveach TD-qasinq Pt P MD 250.00 650.00 1 649.98 1777.00 4989.95 6087.28 6549.31 7094.51 7154.57 10005.70 1OO46.07 1O421.82 10884.44 11060.88 11114.65 11160.58 11181.84 11259.50 11260.66 11522.98 11338.95 11342.56 11476.37 11506.02 11569.71 11769.71 ROFIL Inc 0.00 8.00 58.00 64.35 64.35 64.35 64.35 64.35 64.35 64.35 63.22 52.76 40.28 35.74 54.59 55.26 32.74 30.87 50.87 29.00 28.52 28.42 24.40 24.40 24.40 24.40 E COMMENT Dir TVD 65.41 250.00 65.41 648.70 65.41 1461.00 65.41 1522.21 65.41 2915.00 65.41 3588.00 65.41 5588.00 65.41 3824.00 65.41 3850.00 65.41 5084.17 65.89 5102.00 70.86 5501.00 79.51 5619.00 83.73 5758.00 85.27 5802.00 86.67 5840.00 87.35 5858.00 90.00 5924.00 90.00 5925.00 90.00 5979.00 90.00 5993.00 90.00 5996.00 90.00 6116.00 90.00 6143.00 90.00 6201.00 90.00 6385.14 DATA North 0.00 11.60 231.07 277.55 1482.41 1893.98 2067.27 2271.76 2294.29 5563.64 3378.57 3496.50 3585.03 3601.25 3604.22 3606.01 3606.62 3607.59 3607.59 3607.59 3607.59 3607.59 3607.59 3607.59 3607.59 3607.58 East 0.00 25.35 505.03 606.17 3239.91 4139.42 4518.1 6 4965.07 5014.31 7351.45 7384.45 7679.78 8002.29 8109.64 8140.38 8165.78 8177.45 8218.35 8218.95 8250.05 8257.73 8259.36 8318.95 8331.20 8357.51 8440.12 V. Sect 0.00 27.88 555.31 666.53 3562.51 4551.59 4968.04 5459.46 5515.60 8083.45 8119.67 8457.50 8768.59 8875.21 8902.55 8926.52 8957.46 8975.50 8975.85 9004.52 9011.36 9012.85 9067.42 9078.65 9102.72 9178.57 Deg/lO0 0.00 2.00 )0 5.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3,00 3.00 ,, b 3.00 3.00 3.00 0.00 3,00 3.00 3.00 3.00 0.00 0,00 0.00 Created by r~x=e FOR: BROCKWAY Date plotted: 22-Sep-1999 Plot Reference is 2B Version ~6 . Coordinates are in feet reference slot 1~28. true Vertical Depths are reference RKB (Pool INTEQ ARCO Alaska, Inc. Structure: Pad 1L Well: 28 Field : Kuparuk Rlver Unit Looatlon : Norlh Slope, Alaska East (feet) -> 120 100 BO 60 40 20 0 20 4(3 60 80 lO0 120 140 160 180 200 220 240 2§0 2.80 160' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 160 140 ~ 140 120 1200 lOO ~ ,~1100 80 '~6O0 .-- "k,,00 .~ '" 1000 "%800 .- '",~00 ~ ~ 000 /-/° 900 1 -'"'-------.~zr1'oo 1200 1400 .~'~oo~-~-~.~- 13oo 500 ...~'"~ 600 700 '~..- *'~600 ~ ~800 ~900 1000 11.~ -" 500 o ~ o 700 800 900 20 ~0 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 20 100 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 22.0 240 260 280 East (feet) -> 80 I 60 ,.i--40 ~- 2o 0 Z 120 100 A 60 I Z 0 .-I= 40 20 tl) 80 60 Craot.g by rlxaa FOR: BROCI~AY note p~otted: 22-5ep-1999 Plot Reference is 28 Version #6 . Coordinates ore in fee!, reference slot 1~28. True Vertlcol Depths ore reference RKB (Pool INT~ ARCO Alaska, Inc. Sfruofure: Pod 1L Well .' 28 Field: Kuparuk River Unit Loooflon : Norlh Slope, Alaska 4OO 560 520 28O A 240 I 200 160 120 80 4O East (feet) -> 80 120 160 200 240 280 520 560 400 440 480 520 560 600 640 680 720 760 800 840 880 ,.- ~roo 1700 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 900 .-- --' ~'" ,,.-1~00 ~.~-~--'~ 1900 1700 1700 --,- .~ 1500 1500 ~o.~~_~1300 1500 9OO ~ 1300 11 ~ ~~.~~'~ 3~60 1100 i i i i ~ i[ i i i i i i i i I i i i i i i i I i i i i i i i i i i 200 240 2 0 320 360 400 440 480 520 560 600 640 680 720 760 800 840 East (feet) -> i i i 80 120 400 36O 320 28O 240 A I Z 200 0 160 --i- 120 80 40 40 880 Created by rlxee FOR: BROCKWAY Date plotted: 22-Sep- 199g Plat Reference ls 28 Versfon ~6 . Coordinates are in feet reference slot ~28. True Vertical Depths are reference RKB (Pool ARCO Alaska, Inc. Sfruoture: Pad 1L Well: 28 Field: Kuparuk River Unit Looaflon : North Slope, Alaska East (feet) -> 500 600 700 800 900 1000 11 O0 1200 1500 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 2500 1200 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1200 1100 1000 9OO 800 700 600 500 700 170O 400 2500 300 1500 200 100 2500 2100 1900 1900 1700 1900 j j 2900 21 O0 2700 900 31 O0 2500 2300 2100 2100 1900 3300 2500 2300 25O0 "" 2100 3500 2700 2500 2500 2300 5900 5700 2900 2700 5100 2700 4100 1100 1000 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 East (feet) -> 900 BO0 700 Z 0 600 500 400 300 1 O0 200 Creoted by rlxsa FOR: BROCKWAY Dote plotted: 22-Ssp-1999 Plot Reference rs 28 Version ~6 . Coordinotes ore in feet reference slot 1~28. True Vertlcol Depths ore reference RKB (Pool INTEQ ARCO Alaska, Inc. Structure: Pod 1L Well: 28 Field: Kuporuk River Unlt Looeflon -' North Slope, A I 1600 400 Easf (feet) -> 1800 2000 2200 2400 2600 2800 5000 3200 3400 5600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 2800 ~ ~ ~ ~ ~ 2800 2600 ....~ ~600 .... -"'0 ~4100 2400 ~' 2400 2200 .2200 2000 2000 1800 1200 5500~ 1000 .- 5700"~'"'*~ 4700 4900 -'¢"2500 5100~ ~ 4500.~..~~'~ 4700 800 4500 ~ 4300 ./ ~ 800 430_.~...~~'''' 4100 4100 4100-~ ~ 5900 5700 5900 ---,- 5700 .~._~'~'4500 600 5700 ~ 5500 5500 600 __ 51 ..-~"-~ 400 ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ , ~ ~ ~ ~ ~ , , , ~ , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 400 1800 2000 2200 2400 2600 2800 5000 5200 3400 5600 5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 I I I I I I I 3300 2900 ~ ~ ~ ~ ~ 2700 ~ ~ 2500 East (feet) -> 1800 Z o 1600 '-~ ~-- 1400 (D =-i- 1000 1200 Created by r{xse FOR: BROCKWAY Dote plolied: 22-Sep-1999 Plo[ Reference ls 28 Version i~6 - Coordinates are in feet reference slot I'rue Verticol Depths are reference RKE{ (Pool ARCO Alaska, Inc. Sfruafure: Pad 1L Well: 28 Field .' Kuparuk River Unit Looatlon : North Slope, Alaska 5600 5200 4800 4400 4000 5600 ~200 Z 2800 2400 Eosf (feel) -> 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 61 O0 ~ 5600 5500 4500 ~ 4400 oo ~ 5500 ~ 6100 ~ ~ ~ ~ 4900 5300 ~ / / ~___ / ~ 4500 4900 / ~ / / / ~ 4100 2400 2000 ~ 3700 2000 1600 ~~~61 oo ~~ 1600 1200 , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 1200 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 Eosf (feet) -> Arco Alaska, [nc. Pad 1L 28 stot #28 Kuparuk River Unit North S[ope, Ataska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 28 Version #6 Our ref : prop44 License : Date printed : 23-Sep-99 Date created : 16-Sep-99 Last revised : 20-Sep-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 40 33.55 Slot location is nTO 16 18.334,w149 40 27.262 Slot Grid coordinates are N 5949059.066, E 540278.174 Slot local coordinates are 89.00 N 216.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel[path PMSS <6116 - 7571'>,,3A,Pad 1L PGMS <O-8475'>,,3,Pad 1L PMSS <O-4285'>,,3PB1,Pad 1L PMSS <O-lO065'>,,26,Pad 1L PMSS <O-11500'>,,20,Pad 1L PGMS <O-10345'>,,23,Pad 1L PGMS <O-9241'>,,24,Pad 1L PGMS <O-8700'>,,17,Pad 1L PGMS <O-7950'>,,13,Pad 1L PGMS <O-10176'>,,22,Pad 1L PGMS <O-12550'>,,21,Pad 1L PGMS <O-9353~>,,25,Pad 1L PGMS <O-7478'>,,1,Pad 1L PGMS <O-6469'>,,14,Pad 1L PGMS <0-7800'>,,18,Pad 1L PGMS <0-6721'>,,2,Pad 1L PGMS <0-7795'>,,5,Pad 1L PGMS <0-8470'>,,6,Pad 1L PGMS <0-9369'>,,11,Pad 1L PGMS <0-8103'>,,12,Pad 1L PGMS <0-6704'>,,15,Pad 1L PGMS <0-7830'>,,16,Pad 1L PGMS <0-8839~>,,19,Pad 1L PGMS <0-7668'>,,4~Pad 1L PGMS <0-6700'>,,7, Pad 1L PGMS <0-9100'>,,lO,Pad 1L PGMS <0-7810'>,,8,Pad 1L PGMS <0-10125'>,,9,Pad 1L Closest approach with 3-D Minimum D~stance method Last revised 20-Se=-99 20-Se~-99 20-Se~-99 20-Se~-99 20-Se=-99 20-SED-99 20-Sea-99 20-Se~-99 20-Se=-99 20-Se=-99 20-Se~-99 20-Se~-99 20-Se=-99 20-$e=-99 20-Se=-99 20-Se=-99 20-Se=-99 20-Se=-99 20-Se=-99 20-Se~-99 20-Se~-99 20-Se~-99 20-Se~-99 20-Se~-99 20-Se~-99 20-S~-99 20-S~ ~-99 20-S~ ~-99 Distance M.D. Diverging from M.D. 440.6 100.0 100.0 440.6 100.0 100.0 440.6 100.0 100.0 654.7 200.0 200.0 15.0 0.0 11769.7 721.6 100.0 100.0 747.8 0.0 11480.0 572.5 0.0 0.0 620.4 0.0 0.0 534.0 0.0 0.0 354.2 283.3 283.3 774.3 0.0 0.0 383.9 250.0 250.0 645.1 0.0 0.0 695.8 0.0 0.0 408.8 200.0 200.0 288.5 1015.0 1015.0 248.0 650.0 650.0 413.7 250.0 250.0 474.3 283.3 283.3 596.0 250.0 250.0 549.5 0.0 0.0 595.0 0.0 250.0 477.2 283.3 283.3 176.9 890.0 890.0 43.0 765.0 765.0 125.0 790.0 790.0 130.9 1515.0 1515.0 ARCO Alaska, Inc. Diverter Schematic Pool #6 Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS L, J 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator BSA 13-5/8" 5,000 psi x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple 3" 5,000 psi WP Shaffer GATE VALVE [~Ti~~ raulic actuator Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD) Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One Stage Cement Job / No Cement / to Surface Cement / below Port / Collar / (1000' TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion WELL PERMIT CHECKLIST ...... & /// INITCLASS __/~<2¢-" ,//-"0,7 ADMINISTRATION C. OMPANy _.,~~ .. WELL N .A. ME/~.~/~- Z'~:~' PROGRAM: exp__ GEOL AREA ENGINEERING ,~P~ DATE 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 drilling 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 ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOREs, do they meet regulation ........ 5cJoL~------ 26. BORE press rating appropriate; test to '!~q~'t.-hO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N N N N N N N N N N N dev ~ redrll __ serv ~ wellbore seg ann. disposal para req __ ~:>?("~ UNIT# % .~'(:~,/r") (") ON/OFF SHORE GEOLOGY 30. 31. 32. APPR D~,TE/ 33. Data presented on potential overpressure zones ....... Y' Seismic analysis of shallow gas zones ............. , Seabed condition survey (if off-shore) ............. Y ~ Contact name/phone for weekly progress reports Iexplorato Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan /g,.~"ct(.~.¢ ~,'~/,t:~$~{ ¢~JL~'~ (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annutar COMMISSION: RP~ BE ,w~(-Lf.t, WM DWJ ~ SFD ' ~ JDH . ~.,~-~ RNC TE M,~uI:~L~ ~ ,-%% CO Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is aCcumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Apr 18 15:33:54 2000 Reel Header Service name ............. LISTPE Date ..................... 00/04/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: OPEPJtTOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-90176 T. MCGUIRE G. WHITLOCK 1L-28 500292295100 ARCO Alaska, Inc. Sperry Sun 18-APR-00 MWD RUN 4 AK-MM-90176 T. MCGUIRE B. MORRISON 29 liN 10E 89 216 .00 119.90 85.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 120.0 8.500 9.625 6546.0 6.130 7.000 11117.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RECEIVED APR 2 8 000 Alaska Oil & Gas Cons. Commission Anchorage REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA R_AY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD) . 5. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF ARCO, ALASKA INC. OF 2/7/00. MWD DATA CONSIDERED PDC. 6. MWD RUN 1-4 REPRESENT WELL 1L-28 WITH API 50-029-22951-00. THIS WELL REACHED A TOTAL DEPTH OF l1770'MD, 6379'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PH3tSE SHIFT DERIVED RESISTIVITY ( EXTPJt SHALLOW SPACING ) SESP = SMOOTHED PRASE 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 SBD2 = SMOOTHED BULK DENSITY COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARA_METERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 11.60 - 11.75 PPG MUD FILTRATE SALINITY: 450 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 PPM CHLORIDES FLUID DENSITY: 1.00 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 ....... 00/04/18 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; DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START GR 6510 ROP 6560 FCNT 11107 NCNT 11107 NPHI 11107 RPD 11107 RPM 11107 RPS 11107 RPX 11107 FET 11107 RHOB 11117 PEF 11117 DRHO 11117 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA .5000 DEPTH .0 5 0 0 0 0 0 0 0 0 5 5 5 (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 11719 0 11770 0 11666 5 11666 5 11666 5 11722 0 11722 0 11722 0 11722 0 11722 0 11683 0 11683 0 11683 0 EQUIVALENT UNSHIFTED DEPTH .... BIT RUN NO MERGE TOP MERGE BASE 3 6510.0 11065.5 4 11066.0 11770.0 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 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 PU-S 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 NCNT MWD CP30 4 1 68 FCNT MWD CP30 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD B/E 4 1 68 36 40 44 48 52 10 11 12 13 14 Name Service Unit Min Max DEPT FT 6510 11770 ROP MWD FT/H 2.44 595.25 GR MWD API 34.82 487.97 RPX MWD OHMM 0.35 1417.7 RPS MWD OHMM 0.33 1058.57 RPM MWD OHMM 0.29 2000 RPD MWD OHMM 0.33 1967.16 FET MWD HOUR 0.7299 117.286 NPHI MWD PU-S 18.47 73.26 NCNT MWD CP30 14826.2 34511.4 FCNT MWD CP30 120.56 755.38 RHOB MWD G/CC 2.24 3.23 DRHO MWD G/CC -0.17 0.26 PEF MWD B/E 3.47 16.11 Mean Nsam 9140 10521 114.565 10420 120.76 10419 9.69794 1231 9.06902 1231 30.0381 1231 27.0447 1231 3.60288 1231 36.1267 1120 22021.2 1120 318.995 1120 2.42599 1132 0.0422703 1132 7.48283 1132 First Reading 6510 6560.5 6510 11107 11107 11107 11107 11107 11107 11107 11107 11117.5 11117.5 11117.5 Last Reading 11770 11770 11719 11722 11722 11722 11722 11722 11666.5 11666.5 11666.5 11683 11683 11683 First Reading For Entire File .......... 6510 Last Reading For Entire File ........... 11770 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/18 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 ....... 00/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLIMBER: 2 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 GR ROP $ LOG HEADER DATA DATE LOGGED: START DEPTH STOP DEPTH 6510.0 11065.5 6560.5 11117.0 12-NOV-99 SOFTWA/~E 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 $ BOREHOLE ~ 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 TERMPER3kTURE: 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 Depth Units ....................... Datum Specification Block sub-type...0 Insite 630.91 Memory 11117.0 36.6 65.9 TOOL NUMBER P1362HGV6 8.500 6546.0 LSND 9.10 41.0 8.5 450 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 127.4 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 6510 11117 8813.5 9215 ROP MWD030 FT/H 2.44 595.25 122.37 9114 First Reading 6510 6560.5 Last Reading 11117 11117 ~R MWD030 API 40.67 487.97 122.471 9112 6510 11065.5 First Reading For Entire File .......... 6510 Last Reading For Entire File ........... 11117 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/18 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 ....... 00/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPS NPHI FET FCNT RPM NCNT RPD RPX PEF RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. 4 .5000 START DEPTH 11066 0 11107 0 11107 0 11107 0 11107 0 11107 0 11107 0 11107 0 11107 0 11117 5. 11117 5 11117 5 11117 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: STOP DEPTH 11719 0 11722 0 11666 5 11722 0 11666 5 11722 0 11666 5 11722 0 11722 0 11683 0 11683 0 11683 0 11770 0 18-NOV-99 Insite 0.41 Memory 11770.0 22.6 34.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1376GR4 P1376GR4 P1379NL4 P1379NL4 6.130 11117.0 LSND 11.70 47.0 8.8 5O0 4.0 2.300 1.150 2.000 3.500 60.0 129.7 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 NCNT MWD040 CP30 4 1 68 36 10 FCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CC 4 1 68 44 12 DRHO MWD040 G/CC 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 Name Service Unit Min Max Mean Nsam First Reading Last Reading ' DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S NCNT MWD040 CP30 FCNT MWD040 CP30 RHOB MWD040 G/CC DRHO MWD040 G/CC PEF MWD040 B/E 11066 4 98 34 82 0 35 0 33 0 29 0 33 0.7299 18.47 14826.2 120.56 2.24 -0.17 3.47 11770 161.7 427.14 1417.7 1058.57 2000 1967.16 117.286 73.26 34511.4 755.38 3.23 0.26 16.11 11418 1409 11066 11770 60.0955 1306 11117.5 11770 108.833 1307 11066 11719 9.69794 1231 11107 11722 9.06902 1231 11107 11722 30.0381 1231 11107 11722 27.0447 1231 11107 11722 3.60288 1231 11107 11722 36.1267 1120 11107 11666.5 22021.2 1120 11107 11666.5 318.995 1120 11107 11666.5 2.42599 1132 11117.5 11683 0.0422703 1132 11117.5 11683 7.48283 1132 11117.5 11683 First Reading For Entire File .......... 11066 Last Reading For Entire File ........... 11770 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/04/18 Origin ................... STS Reel Name ................ UNK~OWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File