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Home My WebLink About189-093 • COVED • STATE OF ALASKA DEC 19 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDOICC la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 0 Suspended❑ lb.Well Class: ?Ab ?%b by 20AAC 25.105 20AAC 25.110 Development Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: 'LC ro Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/31/2016 189-093/316-379/ 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 9/10/1989 50-103-20114-00 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 46'FSL,94'FEL,Sec 2,T1ON, R8E, UM 9/18/1989 KRU 2K-11 Top of Productive Interval: 9.Ref Elevations: KB:154 17. Field/Pool(s): 1246'FNL,979'FEL,Sec 11,T1ON, R8E, UM GL: 118 BF: Kuparuk River Field/Kuparuk River Oil Pool ' Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 1286'FNL,993'FEL,Sec 11,T1ON, R8E, UM 6630/6303 ADL 25588 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498310 y- 5938350 Zone- 4 6870/6541 ALK 2674 TPI: x- 497426 y- 5937058 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 497412 y- 5937018 Zone- 4 1815/1815 1496/1463 5. Directional or Inclination Survey: Yes ❑ (attached) No El 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A swat .4'R 2 6 21J1./ 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 36 115 36 115 24 9 5/8 36 J-55 35 2997 35 2949 12 1/4 900 sx AS III,375 sx Class G 7 26 J-55 31 6854 31 6525 8 1/2 225 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 6442 6469/6044 all perfs squeezed off ��41A11 T+'-�" 00 tJY) 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑ 01311 t to Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1.1.- cement plug @6630 35 bbls 16.5#cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A plugged back Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - . Form 10-40 Revise 11/ 5 VTL 4-jTi7 //7 CONTINUED ON PAGE 2 RBDMS IA,L DEC 2 1 2016 Submit ORIGINIAL on -643 l( 0 1 1 4 L,,%:7 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1496 1463 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Cement Report,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and��correct to the b st of my knowledge. Contact: Mike Callahan A263-4180 /'2 /.//5 6 Email: Mike.Callahanacop.com Printed Name: G.Eller v Title: Lead CTD Engineer Phone: 263-4172 Date: /Z//%//r INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • 2K- 11 DTTMSTI JOBTYP SUMMARYOPS 10/26/16 DRILLING RIH W BHA#2, memory caliper. Log pilot hole, POOH, lay down caliper and pick up SIDETRACK BHA#3, tubing under reamer. RIH and under ream 3.5" tubing from 6320-6435. POOH, lay down under reamer and pick up BHA#4, casing under reamer, RIH and under ream 7" casing from 6445-6455'. 10/27/16 DRILLING Under ream 7" casing from 6455-6519'. Trip for under reamer. Under ream 7" casing SIDETRACK from 6445 to 6540. 10/28/16 DRILLING Perform injectivity test to 2500 psi, no injectivity. POOH w BHA#5 casing under reamer. SIDETRACK PU BHA#6, clean out/cement nozzle. Clean out hole to 6542', batch and lay in 9 bbls of 16.5 ppg class G cement. Clean out to 6407'. POOH and lay down BHA#6. Test E- line, good. Jet stack and clean/ inspect ram bodies, replace upper/lower blind rams. 10/29/16 DRILLING Completed cleaning/ inspection of BOP rams. Test BOPE to 250/4700 psi - passed. PU SIDETRACK BHA#7 -cement milling assembly. RIH &tie into gamma ray for a + 15' correction. 10/30/16 DRILLING Tag TOC @ 6409'. Mill 2.80" pilot hole to 6553', POOH, lay down BHA#7. PU BHA#8, SIDETRACK caliper, RIH and log pilot hole. POOH and lay down BHA#8. PU BHA#9, 3 1/2" monobore XL whipstock, RIH and set whipstock. ( TOW 6510, 10 *LOHS). POOH 10/31/16 DRILLING Lay down BHA#9. PU BHA#10, 2.80"window milling assembly, RIH &tag TOW @ SIDETRACK 6510'. Time mill exit window in 7" casing and rat hole, POOH, lay down BHA#10 PU BHA#11, build section MHA& RIH. 11/1/16 DRILLING Drill build section from 6531 ft, unable to hit required doglegs, altered build section per SIDETRACK engineer and geo's, Land build section at 6790 ft(6175 ft TVD) invert and drill upward to new planned EOB at 7125 ft, 42° avg DLS. Saw large amount of frac propant in samples at shaker from near EOB. POOH, laydown BHA#11. 11/2/16 DRILLING PU BHA#12 to drill A-Lateral with a 0.45°AKO motor& new style HCC 3.0" bi-center bit. SIDETRACK RIH, +8 ft correction at K1. Had to work BHA through several areas in the build section starting from 6705 ft to 6900 ft. Drilled from 7125 ft to 8260 ft with planned wiper trips at 7625 ft and 8125 ft. Average ROP of 70 ft/hr, encountered sharp drilling breaks 7343 - 7351 ft, 250 to 300 ft/hr ROP, follwed by slow drilling in Ankerite 7580-7590 ft. Also have been getting back significant carbolite frac sand across shaker starting at EOB and continued thoughout drilling progress. 11/3/16 DRILLING Continued to directional drill A-Lateral from 8310 ft to 8734 ft. Performed long wiper trip SIDETRACK at 8475 ft, with 10x10 sweep. Pumped 5x5 timed to clean up the sump area. Made 2 passes working pipe through 7800-7700 and 6780-6695 ft to clean-up. Getting frac sand and large shale pieces at shaker. Tie-in at RA marker, +14.5 ft correction. Calibrated pressure at window, holding 12.1 ppg ECD, annular pressure bled off 30 psi. 11/4/16 DRILLING Continued to directional drill A-Lateral from 8734 ft to 8974 ft. Early wiper trip at 8891 ft SIDETRACK to window to clean hole, pumped 10x10 and 5x5 sweeps, circulated a BU, hole relatively clean, good amount of cuttings at the shaker. Calibrate BH pressure above the window at 6450 md, 6124 tvd, 4061 psi, 12.75 equivalent MW. Continued to drill with poor weight transfer, pumping several lube pills before adding 2.25% Lube 776 & 1.75% LTQ to active system. • • 11/5/16 DRILLING Continue to drill A-Lateral from 8974 ft. TD was called early after slowed drilling SIDETRACK progress, ROP's less than 10 ft/hr. Performed long wiper trip to swab, working tight area at 6600 to 6800 ft. Tied-in to RA tag for+19 ft correction. RIH and corrected depth +1.5 ft at the K1, sat down in tight area, made back ream pass from 6760 to 6600 ft. Confirmed TD at 9058 ft. Layed in 33 bbl Hi Vis 13.0 liner pill with alpine beads follwed by K-formate KWF. POOH, paint flags at 6602 and 3972 ft, performed 30 min no flow test at surface. Layed down BHA#12 11/6/16 DRILLING Function test BOPE, no failures. Rig up and run 13 joints of 2-3/8"slotted liner assembly, SIDETRACK observed well showing possible flow. Stopped to monitored for 15 minutes, Decision to close SSSV, pull out and laydown liner. After laying down 7 joints, made up safety joint and ran in. Closed BOPE, upper and lower 2-3/8" pipe rams. Notified town engineer of BOP closure and discussed plan forward. Monitored SITP for an hour, built 50 psi in 30 min, then decreased to 25 psi with 12.9 ppg KWF. Made up blind sub, 2-3/8" safety joint w/TIW valve to the 6 joints of slotted liner in well. Tripped in to window and monitored SITP with same results. Built up potassium formate KWF from 12.9 ppg to 13.1 ppg and circulated 104 bbl with 18 bbl loss. Observed well for 1 hour, no flow observed. POOH with liner pumping displacement and managing losses to 5 bbls. At surface by midnight, prep to perform no flow test again. 11/7/16 DRILLING Perform 30 min flow check. Laid down safety joint and 6 joints of 2-3/8" slotted liner. SIDETRACK Ran safety joint and tested the following BOPE per AOGCC; upper/lower 2-3/8" pipe rams and TIW valve to 250/4700 psi test pressure. Monitor hole for flow. Pick up and run 35 joints of 2-3/8" slotted liner with a shorty deployment sleeve. Perform liner running drill, 3.25 minute response time. Trip in with liner pumping min rate with minimal losses. Tie into previous blue EOP flag for-5' correction. Continue in hole, started stacking weight at 6755 ft. Working liner to bottom from 6700 to 7910 ft as of midnight. 11/8/16 DRILLING Continue working liner to 8054 before + 18' correction at RA marker. Estimate TOL © SIDETRACK 7009'. Release from liner, Circ in Beaded liner pill lay in up to window. RBIH to push on liner, Unable to pass 6760, Trip out for FC BHA 11/9/16 DRILLING Trip in with clean out BHA, Tie in for+7'. Displace well to 8.6 PPG Flo Pro, Trip in initial SIDETRACK tag @ 8650'. Work down to 6759. Observed pinhole in CT string. Shut down pumps Trip out. PUD BHA# 15. Blow CT string dry with N2. Prep for CT string swap 11/10/16 DRILLING Continue CT reel swap, stab pipe in injector, install inner reel iron, Pump 5 BBI meth SIDETRACK spear into coil, Prep for head up 11/11/16 DRILLING Complete CT string change out. Trip in with Clean out BHA, Clean 6760 to 6796. Near bit SIDETRACK inclination not matching old hole. POOH killing well. 11/12/16 DRILLING Run caliper in open hole to assess anchor setting depth. Run OH anchor billet to 6589 SIDETRACK and set @ 30° ROHS. Trip out and start full bi weekly BOPE test. Test witness waived by Bob Noble, AOGCC 11/13/16 DRILLING Complete BOPE Test, Kick off top of anchor billet @ 6577. Drill build turn to 6710'. Trip SIDETRACK and pick up lateral BHA, RIH 11/14/16 DRILLING Drill AL1 lateral section 6710 to 8580 SIDETRACK 11/15/16 DRILLING Drill AL1 lateral section to TD of 8,900' MD. Pump sweeps. Perform swab wiper. RBIH, SIDETRACK perform static BHP survey at window, 13.15ppg equivalent pore pressure. Wait on 13.4ppg micronized barite KWF. • • 11/16/16 DRILLING Wait on KWF. Lay-in beaded liner pill followed by 13.4ppg KWF. Flow check- 1 BPH SIDETRACK losses. PU and RIH BHA#21 (AL1 Slotted Liner) to 7,283' MD. 11/17/16 DRILLING RIH & set top of AL1 slotted liner @ 6,852'. Circ out KWF. POOH, PUD BHA#21 (liner SIDETRACK running BHA). PD BHA#22 (anchor billet), however, failure in toolstring. PD BHA#23 (anchor billet again). RIH. Set TOB @ 6,840'. POOH. PUD BHA#23. PD BHA#24 (A lat KO assembly). Begin RIH. 11/18/16 DRILLING Cont RIH w BHA#24, KO anchor billet©6,840'. Drill build section to TD © 7,200'. Swap SIDETRACK to A lateral drilling assembly(BHA#25). Drill A lateral to 7,773' towards planned TD of 9,550'. 11/19/16 DRILLING Drilled ahead from 7,773' to 8,668'. Weight transfer issues while drilling lower A4 sand SIDETRACK lobes. Trip for agitator. PUD BHA#25. 11/20/16 DRILLING Function test BOP. PD BHA#26 (agitator). RIH, drill ahead from 8,668' to 9,405'. SIDETRACK 11/21/16 DRILLING Drilled A lateral to TD of 9,550'. Perform swab wiper, RBIH, confirm TD. Lay-in beaded SIDETRACK liner pill followed by KWF. Flow check- dead well. LD BHA#26. PU & run non-ported bull nose + 38 of 102 slotted liner joints. 11/22/16 DRILLING PU remaining 64 joints of 102 total and RIH with BHA#27, A lat slotted liner. Begin SIDETRACK stacking weight at 7136', unable to work liner past 8106'. POOH w BHA#27. Flow check, good, lay down 52 joints of 102. RBIH with BHA#28, A lat slotted liner'bottom section'. 11/23/16 DRILLING RIH w BHA#28, A lat slotted liner. Tie in to original EOP flag for-8.5' correction. SIDETRACK Stacked weight© 8087', unable to work liner deeper. PUH to 7992 and set A lat slotted liner, top at 6435' bottom 7992'. Displace well to seawater with diesel FP from 2500' to surface. Set BPV, flush & blow down lines, Clean &empty pits, ND BOP. - Rig released @ 12:00 midnight. 11/28/16 DRILLING MEASURED BHP @ 6435' RKB (4242 PSI) REPLACED DV W/OV @ 4815' RKB. SUPPORT - REPLACED DV W/GLV© 3932' RKB. REPLACED DV W/GLV©2345' RKB. BLEED CAPITAL IA FOR 1000 PSI DP ACROSS VALVES, GOOD TEST. JOB COMPLETE. • a Operations Summary (with Timelog Depths) 0 2K-11 itilps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase EC Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/22/2016 10/22/2016 5.00 MIRU MOVE MOB P Prep rig to move to 2K-11,PEAK 0.0 0.0 03:00 08:00 trucks arrived 0400. 10/22/2016 10/22/2016 8.50 MIRU MOVE MOB P Moved rig from 1H-07 to 2K pad. 0.0 0.0 08:00 16:30 10/22/2016 10/22/2016 4.75 MIRU MOVE MOB P Prep wellhead area for rig.Spotted 0.0 0.0 16:30 21:15 drilling sub followed by pits sub. 10/22/2016 10/23/2016 2.75 MIRU MOVE RURD P Continue rigging up 0.0 0.0 21:15 00:00 10/23/2016 10/23/2016 1.00 MIRU MOVE MOB P Continue MIRU,work post rig move 0.0 0.0 00:00 01:00 checklist 10/23/2016 10/23/2016 3.00 MIRU WHDBOP NUND P Nipple up BOPE,change out risers, 0.0 0.0 01:00 04:00 Measure stack,Grease stack.Check wellhead,3 loose bolts between Swab 1 and Swab 2. 10/23/2016 10/23/2016 2.00 MIRU WELLPR OTHR P Start filling coil,Bring fluid in pits,Test 0.0 0.0 04:00 06:00 Inner reel iron-Shell test BOPE,Rig Accept @ 06:00 10/23/2016 10/23/2016 10.00 MIRU WHDBOP BOPE T Perform BOPE test to 250/4700 psi 0.0 0.0 06:00 16:00 (2500 psi annular).Upper blinds-re- test&pass. *Witness waived by AOGCC State Inspector,Brian Bixby,on 10/22/2016 @ 1530 via e-mail." 10/23/2016 10/23/2016 2.25 MIRU WHDBOP PRTS P PT surface lines,blowdown TT line. 0.0 0.0 16:00 18:15 10/23/2016 10/23/2016 2.25 MIRU WHDBOP MPSP P PJSM,lubricate out BPV. Pressurized 0.0 0.0 18:15 20:30 to 500 psi prior to pulling BPV, immediately depressurized when BPV was pulled.RD lubricator+extension. 10/23/2016 10/23/2016 2.00 SLOT WELLPR OWFF T Install UQC checks.Pre-SPUD w 0.0 0.0 20:30 22:30 focus on well hazards with entire team.Prepare to PU cement milling assembly,BHA#1.Hook up to SSSV control line port,pressure up to 5000 psi to open SSSV.Open MV,50 psi WHP.Bleed to TT.Fill hole. Monitor well,built back up to 50 psi. 10/23/2016 10/24/2016 1.50 SLOT WELLPR MILL T Prepare for PD of BHA#1.Blow down 0.0 15.0 22:30 00:00 TT line.PJSM,PD BHA#1.WHP 170 psi. 10/24/2016 10/24/2016 1.75 SLOT WELLPR MILL T Cont PD BHA#1 -MU motor/bit assy 15.0 62.5 00:00 01:45 in rotary table to upper tool string. 10/24/2016 10/24/2016 1.65 SLOT WELLPR MILL T RIH BHA#1 pumping 0.65 BPM SW. 62.5 6,135.0 01:45 03:24 10/24/2016 10/24/2016 0.45 SLOT WELLPR DLOG T GR tie-in,minus 1'correction. 6,135.0 6,262.0 03:24 03:51 10/24/2016 10/24/2016 0.40 SLOT WELLPR CIRC T Swap to viscosified SW(Power-Vis). 6,262.0 6,294.0 03:51 04:15 Close EDC. 10/24/2016 10/24/2016 1.75 SLOT WELLPR MILL T PUW=41k, RIH,tag cement @ 6,306'. 6,294.0 6,306.0 04:15 06:00 PUH,3 stalls @ 6,306'with HS orientation pumping 1.8 BPM.Try 90° ROHS,90°LOHS, 180°ROHS with lower pump rate of 1.55 BPM. 10/24/2016 10/24/2016 1.50 SLOT WELLPR MILL T Crew change,Run valve checklist, 6,306.0 6,310.0 06:00 07:30 been at 6310 tough spot,Sample to geo mostly cement little metal, 1.4 BPM @ 2120 PSI FS Page 1/29 Report Printed: 11/28/2016 • i Operations Summary (with Timelog Depths) :, k , 71- 2K-11 CoeiocoPhddps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2016 10/24/2016 2.80 SLOT WELLPR MILL T Get past 6310 tight spot at 130° 6,310.0 6,343.0 07:30 10:18 LOHS,ROP up to 13FPH 10/24/2016 10/24/2016 0.40 SLOT WELLPR WPRT T Stall and bit stuck,pull free on second 6,343.0 6,343.0 10:18 10:42 cycle @ 60K,BHA Wiper to 6100' 10/24/2016 10/24/2016 3.30 SLOT WELLPR MILL T 6343',Mill, 1.47 BPM @ 2260PS1 FS, 6,343.0 6,363.0 10:42 14:00 Get past 6343 @ 30R 10/24/2016 10/24/2016 0.10 SLOT WELLPR MILL T Milling break,6363 to 6367 No WOB 6,363.0 6,367.0 14:00 14:06 of differential pressure,Motor in to 6367 @ 30 FPM.Get back to hard cement @ 6367 10/24/2016 10/24/2016 2.60 SLOT WELLPR MILL T 6367,Mill, 1.48 BPM @ 2290 PSI FS, 6,367.0 6,383.0 14:06 16:42 still getting stalls,try different TF's 10/24/2016 10/24/2016 0.20 SLOT WELLPR WPRT T Pull BHA Wiper,PUW=53K 6,383.0 6,383.0 16:42 16:54 10/24/2016 10/24/2016 4.60 SLOT WELLPR MILL T 6383',Mill, 1.5 BPM @ 2305 PSI FS 6,383.0 6,396.0 16:54 21:30 10/24/2016 10/24/2016 0.20 SLOT WELLPR WPRT T Wiper to 6320,PUW=53K 6,396.0 6,396.0 21:30 21:42 10/24/2016 10/25/2016 2.30 SLOT WELLPR MILL T 6396',Mill, 1.45 BPM @ 2295 PSI FS. 6,396.0 6,409.0 21:42 00:00 10/25/2016 10/25/2016 3.50 PROD1 RPEQPT MILL P Mill ahead, 1.44 BPM @ 2336 psi FS. 6,409.0 6,430.0 00:00 03:30 Multiple stalls. Erratic WOB, pressures. 10/25/2016 10/25/2016 0.40 PROD1 RPEQPT MILL P Milling break,6,430 to 6,436.No WOB 6,430.0 6,436.0 03:30 03:54 or differential pressure.Found hard cement again @ 6,436'. 10/25/2016 10/25/2016 2.80 PROD1 RPEQPT MILL P Mill ahead to hard spot @ 6,446(5' 6,436.0 6,448.0 03:54 06:42 passed TT,likely contacting 7" casing). Numerous stalls,worked through. 10/25/2016 10/25/2016 3.10 PROD1 RPEQPT MILL P Mill ahead, 1.78 BPM @ 3095 psi FS. 6,448.0 6,503.0 06:42 09:48 Rate varied from 2-30 FPH. 10/25/2016 10/25/2016 0.15 PROD1 RPEQPT WPRT P BHA wiper,PUW=43k.Swap TF. 6,503.0 6,503.0 09:48 09:57 10/25/2016 10/25/2016 0.95 PROD1 RPEQPT MILL P Mill ahead, 1.8 BPM @ 3125 psi FS. 6,503.0 6,517.0 09:57 10:54 -16 FPH. 10/25/2016 10/25/2016 1.85 PROD1 RPEQPT MILL P Milling break,6,517'to 6,530'.No 6,517.0 6,531.0 10:54 12:45 WOB or differential pressure. Found hard cement again @ 6,530'. Work through 6,530'by varying TF& rate. Discuss with town-decision made to run caliper next(instead of under- reamer)to assess the WS setting area for competent cement. 10/25/2016 10/25/2016 1.00 PROD1 RPEQPT WPRT P PUH,dry drift transition area. 6,531.0 6,435.0 12:45 13:45 Backream through transition area twice @ 1 FPM, 1.8 BPM. 10/25/2016 10/25/2016 0.10 PROD1 RPEQPT DLOG P Tie-in K1 marker for+3'correction. 6,435.0 6,461.0 13:45 13:51 10/25/2016 10/25/2016 0.65 PROD1 RPEQPT MILL P RBIH,cont milling to depth of 6,540'. 6,461.0 6,540.0 13:51 14:30 1.5 BPM @ 2590 psi FS.--26 FPH. CTSW=13.9k. 10/25/2016 10/25/2016 1.25 PROD1 RPEQPT WPRT P PUH,dry drift transition area.Back 6,540.0 6,440.0 14:30 15:45 ream transition zone three more times, WOB bobble when RIH-0.5k. 10/25/2016 10/25/2016 0.25 PROD1 RPEQPT OWFF P PUH to 6,292',flow check well.Live 6,440.0 6,292.0 15:45 16:00 well,plan for PUD BHA#1. Page 2/29 Report Printed: 11/28/2016 e • 111 Operations Summary (with Timelog Depths) 2K-11 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time '.. Dur(hr) Phase Op Code' Activity Code Time P-T-X Operation (MKB) End Depth(ftKB) 10/25/2016 10/25/2016 1.60 PROD1 RPEQPT TRIP P POOH BHA#1. Flow Check,Good, 6,292.0 60.7 16:00 17:36 Crew Change. 10/25/2016 10/25/2016 2.50 PROD1 RPEQPT RURD P Lay down BHA#1. Struggled to 60.7 0.0 17:36 20:06 remove BHA from tree,uncertain where we were stuck but bit was across the master by approx 1'. Worked BHA up,Closed Master. Found cement chunks when vacuuming out the BOP stack. D-331 mill maintained 2.79"NoGo. 10/25/2016 10/25/2016 2.30 PROD1 RPEQPT CIRC P MU Nozzle,pop on and jet stack,pop 0.0 0.0 20:06 22:24 off. 10/25/2016 10/26/2016 1.60 PROD1 RPEQPT RURD P PJSM,Close swabs,open master, 0.0 62.5 22:24 00:00 185 psi on managed pressure line. Bleed pressure,no flow observed. Filled Stack with water,opened swab valves,flow check,good,RU memory caliper,bump up, **Fingers programmed to open 25:10 and close@ 25:34 10/26/2016 10/26/2016 1.50 PROD1 RPEQPT TRIP P RIH w BHA#2-HES memory caliper. 62.5 6,433.0 00:00 01:30 10/26/2016 10/26/2016 2.10 PROD1 RPEQPT DLOG P Tie into K1 Marker,-1.5'correction. 6,433.0 5,900.0 01:30 03:36 Wt Ck,45 k lbs. Park at 6535'wait for fingers to open. Pick up Wt 45k lbs, POOH 50 fpm logging caliper of milled pilot hole. 10/26/2016 10/26/2016 1.00 PROD1 RPEQPT TRIP P POOH with BHA#2 Memory Caliper. 5,900.0 58.6 03:36 04:36 10/26/2016 10/26/2016 1.00 PROD1 RPEQPT OWFF P Flow check,monitor through open 58.6 58.6 04:36 05:36 whitey valve on injector. 10/26/2016 10/26/2016 2.10 PROD1 RPEQPT RURD P Crew change.PJSM, PUD BHA#2. 58.6 58.6 05:36 07:42 Step 50 of PUD checklist-realized spaced out incorrectly,DBV not exposed(14 inches too deep).Strip back on,reverse steps.Trouble-shoot injector counter-slipping. 10/26/2016 10/26/2016 1.60 PROD1 RPEQPT RURD P Tag-up,spaceout again watching 58.6 0.0 07:42 09:18 counter. PUD BHA#2. 10/26/2016 10/26/2016 0.65 SLOT WELLPR RURD T Inspect EDC,re-configure BHA. 0.0 0.0 09:18 09:57 10/26/2016 10/26/2016 1.90 SLOT WELLPR RURD T PJSM, PD BHA#3(2.25"under- 0.0 71.0 09:57 11:51 reamer). 10/26/2016 10/26/2016 1.60 SLOT WELLPR TRIP T RIH BHA#3.Troubleshoot counter 71.0 6,450.0 11:51 13:27 (RIH was negative value).Cont RIH. 10/26/2016 10/26/2016 0.25 SLOT WELLPR DLOG T Tie-in to K1 for+18.5'correction. 6,450.0 6,470.0 13:27 13:42 10/26/2016 10/26/2016 1.30 SLOT WELLPR UREM T PUW=46k.PUH to 6,320.Close EDC. 6,470.0 6,490.0 13:42 15:00 Roll pumps on to 1.8 BPM,UR from 6,320'to 6,400'.SD pumps.RIH to 6,410'.Roll pumps back to 1.8 BPM. UR from 6,410'to 6,435'.SD pumps. Open EDC.Pump 0.3 BPM,RIH 50', bring pumps up to 1.8 BPM. 10/26/2016 10/26/2016 1.70 SLOT WELLPR TRIP T POOH w BHA#3 pumping max rate 6,490.0 84.7 15:00 16:42 through EDC.Perform jog @ 500'. 10/26/2016 10/26/2016 1.70 SLOT WELLPR RURD T Pressure undeploy BHA#3 Tubing 84.7 0.0 16:42 18:24 under reamer. Page 3/29 Report Printed: 11/28/2016 0 • Operations Summary (with Timelog Depths) 4 2K-11 ConocoPtaittlps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2016 10/26/2016 1.00 PROD1 RPEQPT RURD T Pick up BHA#4 casing under reamer. 0.0 0.0 18:24 19:24 10/26/2016 10/26/2016 1.80 PROD1 RPEQPT PULD T PJSM,Pressure deploy BHA#4 0.0 66.4 19:24 21:12 casing under reamer. 10/26/2016 10/26/2016 1.50 PROD1 RPEQPT TRIP T RIH. Tie into K1 marker for+14.5' 6,637.0 6,445.0 21:12 22:42 correction. Wt Ch 44k lbs.Close EDC,zero WOB,bring pumps to min rate, RIH,tag bottom,6540'CTMD, PU Wt 44k lbs.PUH to 6445'. 10/26/2016 10/27/2016 1.30 PROD1 RPEQPT UREM T Park at 6445',increase pump rate to 6,445.0 6,455.0 22:42 00:00 1.52 BPM,CT 2475 psi,differential 1048 psi,ease into it with auto drill,2 f/hr,WOB 160 lbs. Work up to 20 fph averaging-900 lbs WOB with no apparent motor work. 10/27/2016 10/27/2016 4.00 PROD1 RPEQPT UREM T Under ream to 6455' PU Wt 38k lbs, 6,455.0 6,519.0 00:00 04:00 back ream to 6447'. RBIH, No WOB seen until 6455'. Reaming ahead at- 20 fph averaging-800-900 lbs WOB with no apparent motor work. Light cuttings at the shaker. 8 stalls at -6519-6516' getting shallower each stall. note previous drilling break when milling was at 6517-6530. 10/27/2016 10/27/2016 1.50 PROD1 RPEQPT UREM T Continuing to stall, 10 total. 6512'PU 6,519.0 6,450.0 04:00 05:30 Wt 58.3 k Lbs. back ream up hole to 6450'. 10/27/2016 10/27/2016 0.80 PROD1 RPEQPT UREM T RBIH,stall multiple times @ 6,509'. 6,450.0 6,509.0 05:30 06:18 Decision made to POOH&check UR blades/body. 10/27/2016 10/27/2016 1.70 PROD1 RPEQPT TRIP T POOH pumping min rate into tubing, 6,509.0 66.0 06:18 08:00 open EDC,POOH pumping max rate. Perform jog @ 500'. 10/27/2016 10/27/2016 1.50 PROD1 RPEQPT RURD T PJSM,PUD BHA#4(7"csg UR). 66.0 0.0 08:00 09:30 10/27/2016 10/27/2016 1.50 PROD1 RPEQPT RURD T Re-dress UR with new blades,re- 0.0 0.0 09:30 11:00 configure BHA w new Weatherford motor. 10/27/2016 10/27/2016 1.75 PROD1 RPEQPT RURD T PJSM, PD BHA#5(7"csg UR). 0.0 66.0 11:00 12:45 10/27/2016 10/27/2016 1.25 PROD1 RPEQPT TRIP T RIH BHA#5. 66.0 6,432.0 12:45 14:00 10/27/2016 10/27/2016 0.20 PROD1 RPEQPT DLOG T Tie-in K1 for+11.5'correction. 6,432.0 6,467.0 14:00 14:12 PUW=47k. 10/27/2016 10/27/2016 2.00 PROD1 RPEQPT UREM T RIH to 6,525',close EDC,back-ream 6,467.0 6,525.0 14:12 16:12 0.5 FPM, 1.5 BPM @ 3685 psi up to 6,510'. RIH and repeat. Ream down, stalling at 6,512'.Attempt higher pump rate(1.7 BPM),extreme vibration. 10/27/2016 10/27/2016 1.20 PROD1 RPEQPT UREM T RIH,back-ream trouble section twice 6,525.0 6,520.0 16:12 17:24 more.Ream down,stall 3 more times. 10/27/2016 10/27/2016 2.60 PROD1 RPEQPT UREM T RIH to 6,520'start down ream. Ream 6,520.0 6,540.0 17:24 20:00 to bottom,frequent stalls,trouble area, 6512'. PU Wt 50k lbs,PUH Wt 46k lbs. Page 4/29 Report Printed: 11/28/2016 • !� Operations Summary (with Timelog Depths) 2K-11 ConocoPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code _ Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2016 10/27/2016 3.00 PROD1 RPEQPT UREM T Back ream to tubing tail @ 3 fpm. 6,540.0 6,445.0 20:00 23:00 Slight bobble—6512', Turn around and ream to bottom at 1.5 fpm,2 stalls at 6505,bypassed w pump down, restart at 6508,clean sailing. Stall at 6516,worked through to TD. Back ream to TT. Saw motor work spike at 6509 taperting off by 6495'. 10/27/2016 10/27/2016 0.30 PROD1 RPEQPT UREM T Down on the pumps,Pull UR back into 6,445.0 6,540.0 23:00 23:18 the tubing,no weight bobbles, RIH tag TD,dry, 10/27/2016 10/28/2016 0.70 PROD1 RPEQPT UREM T Open EDC,Pull up hole to TT while 6,540.0 6,429.0 23:18 00:00 pumping 1.8 bpm, CT 2915 psi,Wh 95 psi, PU wt 48 k lbs, PUH wt 46 k lbs. 10/28/2016 10/28/2016 0.30 PROD1 RPEQPT UREM T Shut down pumps,Close Choke, 6,429.0 6,466.0 00:00 00:18 perform injectivity test to 2500 psi,no leak off. Bleed down. 10/28/2016 10/28/2016 0.30 PROD1 RPEQPT UREM T RIH tie into K1 +3'correction, PUH, 6,429.0 6,466.0 00:18 00:36 paint white flag @ 6466.(100'from bottom on cement run) 10/28/2016 10/28/2016 1.30 PROD1 RPEQPT UREM T POOH pumping 1.8 bpm, 1/4-1/2" 6,466.0 77.0 00:36 01:54 pieces of cement and metal cuttings at the shaker. Jog @ 500',increase in cuttings amount and size,up to 1". Pictures on S drive 10/28/2016 10/28/2016 3.35 PROD1 RPEQPT UREM T PJSM, PUD BHA#5,7"casing under 77.0 0.0 01:54 05:15 reamer#2,clean rig floor. 10/28/2016 10/28/2016 1.30 PROD1 RPEQPT SQEZ T PJSM,make up BHA#6,clean out/ 0.0 15.0 05:15 06:33 cement nozzle.Change packoffs, MU injector.Tag-up,prep to RIH. 10/28/2016 10/28/2016 1.95 PROD1 RPEQPT SQEZ T RIH,set depth to painted flag,+14' 15.0 6,542.0 06:33 08:30 correction.Cont RIH.Tag-up early @ 6,519'.Work pipe to bottom,tag bottom. 10/28/2016 10/28/2016 1.25 PROD1 RPEQPT SQEZ T Pump 10x10 sweeps,chase up to TT 6,542.0 6,436.0 08:30 09:45 pumping 1.8 BPM(picture of sweep returns on S drive). Cement mixed at 0850.8 hr and 8 min thickening time.24 hr cure time. 10/28/2016 10/28/2016 1.75 PROD1 RPEQPT SQEZ T RIH,PU 2'off bottom.SLB pumping 5 6,436.0 6,540.0 09:45 11:30 bbls water,9 bbls 16.5 ppg cement,5 bbls water at 0.5 BPM, 1200 psi circ pressure.Rig pumping 20 bbl Hi-Vis spacer until 1.6 bbls of cement out the nozzle.Held back pressure with choke to maintain 1:1 returns. Well IA pressure stayed below 60 psi throughout pumping job. 10/28/2016 10/28/2016 0.75 PROD1 RPEQPT SQEZ T Start PUH while laying in cement at 6,540.0 4,696.0 11:30 12:15 0.5 BPM.Ramp up speed from 15 FPM to 104 FPM to match returns rate.All cement out nozzle @ 5,250'. Cont PUH to 4,700'.Close choke and pressure up to 1300 psi WHP(WHP during pumping—600 psi). Page 5/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 0 2,4 2K -11 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 10/28/2016 10/28/2016 2.00 PROD1 RPEQPT SQEZ T RIH pumping 0.5 BPM to contaminate 4,696.0 15.0 12:15 14:15 cement down to 6,407'. Increase pump rate to 1.8 BPM.Hi-Vis pill out of nozzle,begin PUH(PUW=35k) washing cement out of hole.Returns to TT. 12.3 ppg slug seen on MM with bottoms up. 10/28/2016 10/28/2016 1.75 PROD1 RPEQPT SQEZ T Close master,flow check while PJSM 15.0 0.0 14:15 16:00 for LD BHA#6(nozzle),replace UQC, test Eline.Test as good as seen previously. 10/28/2016 10/28/2016 2.00 PROD1 RPEQPT CIRC T Pump cement contamination pill 0.0 0.0 16:00 18:00 through surface lines and jet BOP stack follow with SW to prep for BOPE test. 10/28/2016 10/29/2016 6.00 PROD1 RPEQPT CIRC T PJSM,Lock out,Open BOP rams 0.0 0.0 18:00 00:00 inspect/clean same. Replaced upper and lower blind rams. 10/29/2016 10/29/2016 5.50 PROD1 RPEQPT GLEN T Inspect/clean upper and lower 2 3/8" 0.0 0.0 00:00 05:30 rams. Replace 9 of 12 ram door seals.Re-torque BOP bolts. Valve Crew serviced tree. 10/29/2016 10/29/2016 3.70 PROD1 WHDBOP RURD T Fill stack,shell test to 4,700 psi.Two 0.0 0.0 05:30 09:12 door seals leaking on stack.Replace. Total of 11 of 12 door seals replaced. 10/29/2016 10/29/2016 0.80 PROD1 WHDBOP RURD T Shell test to 4,700 psi again.Fail, 0.0 0.0 09:12 10:00 leaking ODS upper blind ram door seal.CO again(had rolled on previous installation). 10/29/2016 10/29/2016 8.50 PROD1 WHDBOP BOPE P Shell test to 250/4,700 psi.Pass. 0.0 0.0 10:00 18:30 Start BOP test 250/4,700 psi(2,500 psi on annular). No failures. **AOGCC inspector,Jeff Jones, waived witness at 16:04 on 10/28/2016 via e-mail." 10/29/2016 10/29/2016 2.50 PROD1 RPEQPT MILL T Open master to 200 psi. Bleed 0.0 67.0 18:30 21:00 pressure,monitor,no increase. Open swabs,start no flow test. PJSM,no flow test good. Reinstall quick test sub, install CT nozzle,stab on,PT quick test sub union,good,pop off. Make up BHA#7,cement pilot hole mill.(Mill 2.79"NG) **HES crew inspected/tested cable for real time caliper and confirmed camera XO connection. Ready to run real time calipers. 10/29/2016 10/30/2016 3.00 PROD1 RPEQPT MILL T RIH,open EDC, pump 5 bbl pill and 67.0 6,409.0 21:00 00:00 swap from used milling fluid to new milling fluid while tripping in hole. Tie into gamma ray log from 6175-6291' for+15 foot correction. Close EDC, Wt Ck 42k lbs. RIH, 10/30/2016 10/30/2016 0.20 SLOT WELLPR MILL T Dry tag TOC 6409'. POH,PU Wt 42 k 67.0 6,409.0 00:00 00:12 lbs. Bring pumps up to 1.8 bpm,Circ 2766 psi,free spin diff,406 psi, RBIH, Page 6/29 Report Printed: 11/28/2016 • i Operations Summary (with Timelog Depths) , tet', a • >> 2K-11 CcoPhittips ,: r. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2016 10/30/2016 2.00 SLOT WELLPR MILL T Milling pilot hole, 6410'ROP 26 fph, 6,409.0 6,438.0 00:12 02:12 WOB 1.33 klbs,Circ 3095 psi,760 psi diff. 5 stalls at 6425,6429,6437,& again at 6437'. Pu Wts at 47 k lbs. Rotated TF to 160 left,ROP 12 f/hr, 626 psi diff,WOB 1.3 k lbs. 10/30/2016 10/30/2016 2.00 SLOT WELLPR MILL T Orient TF back to 20 right. Mill ahead 6,438.0 6,463.0 02:12 04:12 Circ 2700 psi,WOB 1.2k lbs, ROP 12 f/hr,diff 670 psi. ROP picked up to 22 f/hr after 6443',WOB 1.67 k lbs. 10/30/2016 10/30/2016 0.80 SLOT WELLPR MILL T Mill ahead Circ 3000 psi, 1.67 bpm, 6,463.0 6,481.0 04:12 05:00 WOB 1.4 k lbs,ROP 22 f/hr,diff 670 psi. 10/30/2016 10/30/2016 0.25 SLOT WELLPR WPRT T BHA wiper, PUW=51k. 6,481.0 6,481.0 05:00 05:15 10/30/2016 10/30/2016 2.50 PROD1 RPEQPT MILL T Milling ahead, 1.7 BPM @ 2860 psi 6,481.0 6,550.0 05:15 07:45 FS,WOB 2k, ROP 30.Couple stalls @ 6,540',worked through to TD. 10/30/2016 10/30/2016 0.75 PROD1 RPEQPT DLOG T PUH(PUW=50k),tie-in to K1 for+3' 6,550.0 6,460.0 07:45 08:30 correction.RIH,confirm TD @ 6,553'. Pumping 0.3 BPM. PUH,dry drift to TD,WOB 0.9k @ 6,443'.PUH. 10/30/2016 10/30/2016 0.25 PROD1 RPEQPT MILL T Backream up 1 FPM and ream down 5 6,460.0 6,462.0 08:30 08:45 FPM twice w TF LS,once with TF 160°LOHS.Dry drift transition area, WOB 0.9k @ 6,442'. 10/30/2016 10/30/2016 2.60 PROD1 RPEQPT TRIP T POOH.Jog from 237'to 500'.Cont 6,462.0 70.0 08:45 11:21 POOH.Spaceout. 10/30/2016 10/30/2016 0.40 PROD1 RPEQPT OWFF T OWFF-good no flow test. 70.0 70.0 11:21 11:45 10/30/2016 10/30/2016 0.75 PROD1 RPEQPT RURD T PJSM, LD BHA#7(mill maintained 70.0 0.0 11:45 12:30 2.79"NoGo) 10/30/2016 10/30/2016 0.50 PROD1 RPEQPT CIRC T Jet BOP stack.Small chunks of 0.0 0.0 12:30 13:00 cement in returns. 10/30/2016 10/30/2016 0.70 PROD1 RPEQPT DLOG T PJSM,MU BHA#8(real-time caliper). 0.0 26.0 13:00 13:42 10/30/2016 10/30/2016 1.60 PROD1 RPEQPT TRIP T RIH W Real time HES caliper. Tie in 26.0 6,433.0 13:42 15:18 W Hal. 10/30/2016 10/30/2016 0.50 PROD1 RPEQPT DLOG T Log cement pilot hole,3 passes. 6,433.0 6,540.0 15:18 15:48 10/30/2016 10/30/2016 1.30 PROD1 RPEQPT TRIP T POOH W BHA#8 6,540.0 26.0' 15:48 17:06 10/30/2016 10/30/2016 ' 1.00 PROD1 RPEQPT PULD T Flow Check, PJSM,Lay down BHA 26.0 0.0 17:06 18:06 #8,HES caliper. 10/30/2016 10/30/2016 2.20 PROD1 RPEQPT PULD P High side whipstock, PJSM,PU BHA 0.0 74.0 18:06 20:18 #9,Baker 3 1/2 monobore XL Whipstock,surface test tool,open EDC,tag up. 10/30/2016 10/30/2016 2.00 PROD1 RPEQPT TRIP P RIH W whipstock @ 80 fpm.Wt Ck 74.0 6,520.0 20:18 22:18 46.9 k lbs.Tie into the K1 for a+13' correction. 10/30/2016 10/30/2016 0.20 PROD1 RPEQPT WPST P Off the pump,Close EDC. RIH wt 13 74.0 6,520.0 22:18 22:30 k lbs in pilot hole. PU 5520.55, Oriented 10 LOHS. Roll the pumps, pressure broke back @ 4700 psi. Stacked weight5.7 k lbs,good. Set Whipstock. Page 7/29 Report Printed: 11/28/2016 0 • ° Operations Summary (with Timelog Depths) 2K-11 c ooa trips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2016 10/30/2016 1.20 PROD1 RPEQPT TRIP P POOH 6,520.0 64.0 22:30 23:42 10/30/2016 10/31/2016 0.30 PROD1 RPEQPT PULD P @ Surface 64.0 64.0 23:42 00:00 10/31/2016 10/31/2016 1.70 PROD1 RPEQPT PULD P PJSM,No flow test,-good,lay down 64.0 0.0 00:00 01:42 BHA#9,whipstock running BHA. 10/31/2016 10/31/2016 2.00 PROD1 WHPST PULD P PJSM,PU BHA#10,window milling 0.0 74.0 01:42 03:42 assembly.String mill 2.80"NoGo, Window mill 2.80"NoGo.Surface test tool,tag up,open EDC. 10/31/2016 10/31/2016 1.75 PROD1 WHPST TRIP P RIH,EDC open,Tie in at K1 for+13' 74.0 6,459.0 03:42 05:27 correction. 10/31/2016 10/31/2016 0.80 PROD1 WHPST CIRC P Displace wellbore to used FloPro mud 6,459.0 6,436.0 05:27 06:15 system for milling window.Close EDC. Wt check,PUW=40k,RIH. 10/31/2016 10/31/2016 8.25 PROD1 WHPST WPST P Dry tag TOWS @ 6,510'.Mill window 6,436.0 6,531.0 06:15 14:30 10°LOHS, 1.78 BPM @ 4450 psi FS, 0.7-3.0k WOB,ROP 1 increasing slowly to 6 FPH as worked through casing into formation. 10/31/2016 10/31/2016 1.00 PROD1 WHPST REAM P PUH,PUW=37k.Ream up through 6,531.0 6,501.0 14:30 15:30 window three times at 1 FPM(10° LOHS,30°ROHS,40°LOHS) 10/31/2016 10/31/2016 2.00 PROD1 WHPST TRIP P Dry drift window twice.Slight WOB 6,501.0 74.0 15:30 17:30 bobble first time.PUH,pump 5x5 sweeps.Jog back in hole 40 FPM, stop,open EDC.Resume pumping and POOH.Switch over to hi-line power.Cont POOH.Spaceout.Close EDC. 10/31/2016 10/31/2016 2.00 PROD1 WHPST PULD P Flow check,PJSM,LD BHA#10. 74.0 0.0 17:30 19:30 SIM OPS: Blowdown/clean Choke A 10/31/2016 10/31/2016 1.50 PROD1 WHPST CIRC P Jet BOP stack.Open manual valves 0.0 0.0 19:30 21:00 on stack and pump through to clean. 10/31/2016 10/31/2016 1.50 PROD1 DRILL PULD P PJSM,PU BHA#11 (build section,RB 0.0 72.0 21:00 22:30 HCC+2.4°AKO motor). 10/31/2016 11/1/2016 1.50 PROD1 DRILL TRIP P RIH,swap well over to new FLO=PRO 72.0 6,531.0 22:30 00:00 SF, Tie in to K1 for+9'correction. Close EDC. 11/1/2016 11/1/2016 4.00 PROD1 DRILL DRLG P 1.70 bpm,free spin-420 psi,CT 6,531.0 6,568.0 00:00 04:00 4212 psi OBD,ROP 4,WOB 1.65k lbs.CT wt 11.4 k lbs. 11/1/2016 11/1/2016 2.00 PROD1 DRILL DRLG P DD build section, 1.7 bpm,CT 4300 6,568.0 6,635.0 04:00 06:00 psi,WH 600 psi,RROP 17 f/hr,WOB 1 k lbs, PU to rotate tool,against stops, PU Wt,41 k lbs. BHA out window,Target WOB 2.5 to 3k lbs. 11/1/2016 11/1/2016 0.50 PROD1 DRILL DRLG P PUH Log/Tie into K1 and RA tag. 6,635.0 6,635.0 06:00 06:30 PU Wt 40 k lbs. 6544 RBIH, 11/1/2016 11/1/2016 1.20 PROD1 DRILL DRLG P BOBD, 1.8 bpm,Ct 4800 psi,Wh 245 6,568.0 6,692.0 06:30 07:42 psi,CT Wt 11.6 k lbs,WOB 2.4 k lbs, ROP 141 f/hr.935 psi diff. 11/1/2016 11/1/2016 2.00 PROD1 DRILL TRIP P Unable to make required dog leg 6,692.0 6,692.0 07:42 09:42 POOH, PU Wt 49 k lbs, Consult W town,evaluate options while circulating.RBIH Page 8/29 Report Printed: 11/28/2016 0 0 Operations Summary (with Timelog Depths) 2K-I l conacoPhilliprs • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/1/2016 11/1/2016 8.00 PROD1 DRILL DRLG P BOBD,Adjusted landing point, 1.4 6,692.0 7,048.0 09:42 17:42 bpm,CT 3774 psi,WH 467,CT Wt 12k lbs,WOB 1.88 k lbs,ROP 30 f/h. Land build section at 6790 ft(6175 ft TVD),invert and drill upward. Surging choke,most likely blockage,swapped from A to B. BHA wipers at 7048 11/1/2016 11/1/2016 0.30 PROD1 DRILL WPRT P Stacking wt,make short wiper trip to 7,048.0 7,048.0 17:42 18:00 6850',40K PUW, 11/1/2016 11/1/2016 1.50 PROD1 DRILL DRLG P Drill to 7112',stacking wt,short BHA 7,048.0 7,125.0 18:00 19:30 wiper,continue to drill to 7125 ft, 11/1/2016 11/1/2016 0.50 PROD1 DRILL WPRT P Pull wiper trip while Geologists consult 7,125.0 7,125.0 19:30 20:00 town for EOB decission,41K PUW, wiper to 6600'and back to 6970'when decission was made to POOH 11/1/2016 11/1/2016 1.80 PROD1 DRILL TRIP P EOB called at 7125', Pull back thru 7,125.0 72.6 20:00 21:48 window,open EDC at 6370',Trip for Lateral BHA,jog at surface from 200 to 500',bump up. 11/1/2016 11/2/2016 2.20 PROD1 DRILL PULD P Hold PJSM, PUD Build section BHA 72.6 0.0 21:48 00:00 #11. 11/2/2016 11/2/2016 2.20 PROD1 DRILL PULD P Hold PJSM,PU&pressure deploy 0.0 72.2 00:00 02:12 BHA#12 with 0.45°AKO motor with New style HCC,3.0"bi-center bit. Back flush both chokes A&B. 11/2/2016 11/2/2016 2.50 PROD1 DRILL TRIP P Trip in with EDC open,following MP 72.2 6,420.0 02:12 04:42 schedule. 11/2/2016 11/2/2016 0.20 PROD1 DRILL DLOG P Log K1,+8 ft correction 6,420.0 6,464.0 04:42 04:54 11/2/2016 11/2/2016 1.00 PROD1 DRILL TRIP P Close EDC,trip in thru build section at 6,464.0 7,125.0 04:54 05:54 min rate,50 FPM,SD at 6705',work down to 6737',work pipe,bleed pump pressure off,pull 70K to get free,work tight area,try running in at 1 BPM, 11/2/2016 11/2/2016 3.50 PROD1 DRILL DRLG P BOBD, 1.7 bpm,CT 4833 psi,WH 7,125.0 7,434.0 05:54 09:24 350 psi,CT Wt 7.8k,WOB 2.25k lbs, ROP 116 f/hr. Sharp drilling break from 7343-7351,ROPs 250-300 f/hr. Passed suspected fault@ 7350'. Coil weight falling off starting around 7200', snubbing. Well continues to give up frac sand,Started approx.7125'bit depth. 11/2/2016 11/2/2016 4.40 PROD1 DRILL DRLG P Drilling ahead, 1.77 bpm,CT 5070 psi, 7,434.0 7,625.0 09:24 13:48 WH 528,holding 12.0 ppg managed pressure,CT wt-5.5 k lbs,WOB 2.57 k lbs,ROP 42 f/hr. Raining carbolite across the shakers. ROP dropped, 7580-90,suspect ankerite. Drilling break,7590'then suspect ankerite again at 7613 11/2/2016 11/2/2016 0.40 PROD1 DRILL WPRT P PUH,PU weight,44 k lbs,Trip#1 7,625.0 6,900.0 13:48 14:12 11/2/2016 11/2/2016 0.20 PROD1 DRILL WPRT P RBIH 6,900.0 7,625.0 14:12 14:24 Page 9/29 Report Printed: 11/28/2016 0 • Operations Summary (with Timelog Depths) 2K-11 ocoPhiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time "' End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2016 11/2/2016 6.20 PROD1 DRILL DRLG P BOBD, 1.85 bpm,Ct 4186,WH 530, 7,625.0 8,125.0 14:24 20:36 CT Wt-5.0 k lbs,WOB 1.64k lbs, ROP 45-230 f/hr,drill ahead to 8100' 11/2/2016 11/2/2016 0.40 PROD1 DRILL WPRT P Planned wiper#2,55K PUW 8,125.0 7,125.0 20:36 21:00 11/2/2016 11/2/2016 0.70 PROD1 DRILL WPRT P RBIH to 8050',wiper up per Geo's 7,125.0 8,125.0 21:00 21:42 while awaiting new targets, RBIH 11/2/2016 11/3/2016 2.30 PROD1 DRILL DRLG P Drill ahead, 1.56 bpm,4285 CP,615 8,125.0 8,260.0 21:42 00:00 WHP,4200 BHP,542 dP,2.6K CWT, 0.9K WOB,AVG ROP 60 FPH,Small drilling breaks at 8165',8188'and 8231' 11/3/2016 11/3/2016 1.10 PROD1 DRILL DRLG P Drilling ahead to 8310 ft. 8,260.0 8,310.0 00:00 01:06 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT T Magnetic interference,unable to get 8,310.0 8,310.0 01:06 01:30 survey 11/3/2016 11/3/2016 1.90 PROD1 DRILL DRLG P Drilling,avg ROP 25 ft/hr. 8,310.0 8,359.0 01:30 03:24 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Wiper up to 8230 ft,51K PUW,while 8,359.0 8,359.0 03:24 03:48 Geo's dicuss invert log and targets. RBIH to drill 11/3/2016 11/3/2016 3.00 PROD1 DRILL DRLG P Drill at 1.7 bpm,-1K with 1K WOB, 8,359.0 8,464.0 03:48 06:48 4650 CP,750 WHP,4160 BHP,560 dP,45 ft/hr ROP. Swap to new mud system#2. New mud at bit 11/3/2016 11/3/2016 1.80 PROD1 DRILL DRLG P New off bottom diff,-370 psi. 1.55 8,464.0 8,475.0 06:48 08:36 bpm,CT 4235 psi,WH 881. Wt-4 k lbs,WOB 1.9 k lbs,ROP 3.4 f/hr. Pump 10/10 sweep, 11/3/2016 11/3/2016 1.00 PROD1 DRILL WPRT P Long wiper PU Wt,53,dry PU. PUH 8,475.0 6,435.0 08:36 09:36 chasing 10/10 sweep. Sent 5x5 timed for the sump. Lots of frac sand back on the bottoms up sweep. Worked pipe/pumps through 7800-7700. Pulled 60 k lbs, worst of it 6780- 6695'. RBIH,min rate,clean,PUH same issues,pulling negative 4-5k lbs WOB, Motor work(torqueing up),& annular packing off. PUH. 11/3/2016 11/3/2016 1.20 PROD1 DRILL DLOG P Open EDC,circulate bottoms up,lots 6,435.0 6,516.0 09:36 10:48 of large shale at the shaker. Close EDC,RBIH min rate to window. Pump up to 12.1 ppg at the window,BHP 3888 psi leaked off to 3868 and stabilized. RIH,tie in W/RA tag for+ 14.5'correction. Reset injector software. 11/3/2016 11/3/2016 1.10 PROD1 DRILL TRIP P RBIH, 6,516.0 8,485.0 10:48 11:54 11/3/2016 11/3/2016 2.30 PROD1 DRILL DRLG P BOBD,holding 12.1 ppg at the 8,485.0 8,536.0 11:54 14:12 window.off bottom diff 395 psi, 1.50 bpm,CT 3977 psi,WH 992 psi. CT Wt-7.2k lbs,WOB 1.56 k lbs,ROP 23 ft/hr. Page 10/29 Report Printed: 11/28/2016 • • ' Operations Summary (with Timelog Depths) ,,,_ 2K-11 cc*hinips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)t End Depth(ftKB) 11/3/2016 11/3/2016 0.20 PROD1 DRILL DRLG P Packed off the annulus,WOB to zero, 8,536.0 8,500.0 14:12 14:24 pulling heavy to 65k lbs,working pipe while lining up across the top to pump down both coil and the back side. Note*checks do not appear to be holding. Reestablish circulation path and work pipe slowly up hole Ct Wt 45 k lbs. 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Pulled wiper trip waiting for bottoms 8,500.0 7,800.0 14:24 14:48 up. No influx,fine cuttings comming across the shaker. 11/3/2016 11/3/2016 0.30 PROD1 DRILL WPRT P RBIH 7,800.0 8,536.0 14:48 15:06 11/3/2016 11/3/2016 5.20 PROD1 DRILL DRLG P BOBD, 1.6 bpm,CT 4249 psi,WH 804 8,536.0 8,668.0 15:06 20:18 psi,CT wt 1 k lbs,WOB 0.64,ROP 14 f/hr. Pumped 30 bbl beaded pill, 1ppb alpine beads,see some improvement in weight transfer,5.8K SOW, 1K WOB,20 to 50 ROP. Continue drilling with short wipers 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Wiper up to 8470',51K PUW, 8,668.0 8,668.0 20:18 20:42 11/3/2016 11/3/2016 1.80 PROD1 DRILL DRLG P BOBD, 1.52 bpm,3950 CP,837 WHP, 8,668.0 8,704.0 20:42 22:30 -3.5K CW, 1.0 WOB,25 ft/hr ROP. 11/3/2016 11/3/2016 0.50 PROD1 DRILL WPRT P Wiper up to 8400',51K PUW,RBIH 8,704.0 8,704.0 22:30 23:00 11/3/2016 11/4/2016 1.00 PROD1 DRILL DRLG P BOBD, 1.50 bpm,3987 CP,813 WHP, 8,704.0 8,734.0 23:00 00:00 -4K CW, 1K WOB,26 ft/hr ROP 11/4/2016 11/4/2016 1.25 PROD1 DRILL DRLG P BOBD, 1.50 bpm,3987 CP,813 WHP, 8,734.0 8,750.0 00:00 01:15 -4K CW, 1K WOB,26 ft/hr ROP. 11/4/2016 11/4/2016 0.50 PROD1 DRILL WPRT P PU off bottom, Pumped 10 bbl Alpine 8,750.0 8,750.0 01:15 01:45 beaded pill w/Lubes(2.5%Lube 776 and 2.5%Lo-Torque),active system has 1%Lube 776 11/4/2016 11/4/2016 3.25 PROD1 DRILL DRLG P BOBD, 1.40 bpm,3890 CP,744 WH, 8,750.0 8,855.0 01:45 05:00 0.4K CW, 1.3K WOB,45 ft/hr, improvment in weight transfer and ROP,see drilling break 8820'cutting down to the top of the lower A4 lobe, pull short wiper at 8829 ft due to vibration,geo steer up for final cross cut to planned TD. 11/4/2016 11/4/2016 1.90 PROD1 DRILL DRLG P Poor weight transfer,ct Wt-4 k lbs, 8,855.0 8,881.0 05:00 06:54 WOB.6k lbs,struggling to RIH. 11/4/2016 11/4/2016 2.20 PROD1 DRILL WPRT P Pull wiper#2 early. Town requested 8,881.0 6,385.0 06:54 09:06 wiper to window to clean sump of build section. Send 10x10 sweeps. POOH wts up to 51 k while pulling through the build,slight motor work and a couple spikes of negative bit weight. Hole appeared relatively clean. Opened EDC,chased cuttings out at 1.85 bpm. Received a good amount of cuttings at the shaker as the hi vis landed. Mostly drill cuttings,very few pieces of shale,(.25-.4"). Page 11/29 Report Printed: 11/28/2016 • • `' Operations Summary (with Timelog Depths) 04 0 2K-11 ConocoPhillps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End.Time Dur(hr) Phase, Op Code Activity Code Time P-T-X Operation, (ftKB) End,Depth(ftKB) 11/4/2016 11/4/2016 0.90 PROD1 DRILL DLOG P Tie into the K1 for a+12'correction. 6,385.0 6,450.0 09:06 10:00 Close EDC. Wt Ck 39.5 k lbs, Calibrate pressure above the window 6450 md,6124 tvd,4061 psi 12.75 equivalent MW. 11/4/2016 11/4/2016 1.00 PROD1 DRILL TRIP P RBIH,slight weight bobbles running 6,450.0 8,881.0 10:00 11:00 through the build. Stripper leaking, packing off. 11/4/2016 11/4/2016 0.50 PROD1 DRILL DRLG P BOBD,struggling to get weight on bit, 8,750.0 8,890.0 11:00 11:30 continuing to have stripper issues, 1000 psi wellhead,holding 2500 psi on stripper to maintain seal. 11/4/2016 11/4/2016 2.70 PROD1 DRILL TRIP T PUH to 6396'to change out stripper 8,890.0 8,883.0 11:30 14:12 pack offs. Down on the pump,monitor BHP,stable,shut 2"pipe rams,shut annular,bleed off at the stump. Replace pack off and extrusion rings. PT,open rams,open annular,RBIH. Tie into the RA tag for a+3.5 correction. continue to RIH. 11/4/2016 11/4/2016 1.80 PROD1 DRILL TRIP P Try multiple times to get back on 8,883.0 8,887.0 14:12 16:00 bottom,coil in lock up with drilling pump rate. Prep and pump 10 bbl lube pill,2.5 x 2 low torque/776. Lubes around,able to slide again, snubbing-3 k lbs, 1 k lbs,WOB 17 f/hr. 11/4/2016 11/4/2016 1.40 PROD1 DRILL WPRT P 1.45 bpm,CT 4220 psi,WH 874 psi, 8,887.0 8,890.0 16:00 17:24 CT Wt-7.7 k lbs, 1.14 k lbs WOB, ROP 17. Locked up,unable to get back on bottom,pumped another 10 bbl lube pill,add lubes to active system 2.25%L776 x 1.75%LTQ. 11/4/2016 11/4/2016 1.20 PROD1 DRILL DRLG P BOBD,snubbing-2K to-7K CW,0.8K 8,890.0 8,917.0 17:24 18:36 WOB,struggle to get WOB, 11/4/2016 11/4/2016 0.30 PROD1 DRILL TRIP P PU for BHA wiper try to get pipe to 8,917.0 8,917.0 18:36 18:54 slide. 11/4/2016 11/4/2016 3.00 PROD1 DRILL DRLG P OBD w/-3K to-7K CW,0.5-1K WOB 8,917.0 8,954.0 18:54 21:54 11/4/2016 11/4/2016 0.40 PROD1 DRILL WPRT P Wiper trip to get weight transfer,51K 8,954.0 8,954.0 21:54 22:18 PUW,tried to turn around at 8865'and 8837,pulled up to 8700'to get RIH. 11/4/2016 11/4/2016 0.70 PROD1 DRILL DRLG P BOBD, 1.5 bpm,4470 psi CP,-7.5K 8,954.0 8,966.0 22:18 23:00 CW, 1K WOB, 15-25 fUhr ROP 11/4/2016 11/4/2016 0.50 PROD1 DRILL WPRT P Wiper trip to get weight transfer,52K 8,966.0 8,966.0 23:00 23:30 PUW,tried to turn around at 8865'and 8837,pulled up to 8700'to get RIH. 11/4/2016 11/5/2016 0.50 PROD1 DRILL DRLG P BOBD, 1.40 bpm,4330 psi CP,-8K 8,966.0 8,974.0 23:30 00:00 CW,0.6K WOB, 10-20 ft/hr ROP 11/5/2016 11/5/2016 1.80 PROD1 DRILL DRLG P Continue OBD, 1.42 bpm,4325 psi 8,974.0 9,001.0 00:00 01:48 CP,925 psi WHP,-7K CW,0.9K WOB 11/5/2016 11/5/2016 0.50 PROD1 DRILL WPRT P Wiper trip,weight transfer,52K PUW, 9,001.0 9,001.0 01:48 02:18 pulled up to 8700', RIH. 11/5/2016 11/5/2016 2.50 PROD1 DRILL DRLG P OBD, 1.45 bpm,4316 psi CP,900 psi 9,001.0 9,015.0 02:18 04:48 WHP,-9.5K CW, 1.2K WOB,less than 10 fUhr ROP. Page 12/29 Report Printed: 11/28/2016 i r ='A. Operations Summary (with Timelog Depths) 2K-11 coPhilGps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)'> 11/5/2016 11/5/2016 0.20 PROD1 DRILL WPRT T Wiper up while BHI troubleshoots lost 9,015.0 9,015.0 04:48 05:00 comms with RigLink. 11/5/2016 11/5/2016 3.00 PROD1 DRILL DRLG P OBD, 1.44 bpm,4315 psi CP,911 psi 9,015.0 9,035.0 05:00 08:00 WHP,-9K CW, Drilling ankerite,at 1.7 f/hr w low diff pressure and 1.1k lbs on bit,break out @ 9020'. 1.4 bpm,CT 4317 psi,CT wt-5.88 k lbs, WOB 1 klbs,ROP 23 f/hr. 11/5/2016 11/5/2016 3.00 PROD1 DRILL DRLG P OBD, 1.44 bpm,4315 psi CP,911 psi 9,035.0 9,048.0 08:00 11:00 WHP,-9K CW. Continuing to encounter ankerite stringers and low ROPs. **Town called TD early. 11/5/2016 11/5/2016 0.90 PROD1 DRILL TRIP P PUH to 8697', start 10/10 low/high 9,048.0 9,048.0 11:00 11:54 vis sweeps down coil. RBIH, tag,sweeps at the bit, Pick up,PU Wt 50 k lbs. Chase sweeps out of hole. 11/5/2016 .11/5/2016 1.60 PROD1 DRILL TRIP P PUH to build section. Pull heavy,53 k 9,048.0 6,523.0 11:54 :13:30 lbs @ 6632',turn around,6720 WOB spike. Work pipe between 6600 and 6800 with diminishing over pulls and motor work. 11/5/2016 11/5/2016 0.60 PROD1 DRILL DLOG P Tie into the RA maker for a+19' 6,523.0 203.0 13:30 14:06 correction,pull through window,clean, open EDC 1.9 bpm,CT 4439 psi. Getting lots of cuttings at the shaker, swapped from choke A to B,some smaller pea gravel sized cuttings, -1/4"at the shaker,mosty fine silt. 11/5/2016 11/5/2016 1.60 PROD1 DRILL TRIP P POOH,jog coil 300'silt and some 203.0 74.0 14:0615:42 gravel at the shaker, POOH,tagged up at surface 11/5/2016 111/5/2016 1.50 PROD1 DRILL TRIP P Trip in hole 74.0 6,461.0 15:42 �17:12 11/5/2016 11/5/2016 0.30 PROD1 DRILL DLOG P Tie in at K1 for+1.5'correction,close 6,461.0 6,461.0 17:12 17:30 EDC,pressure calibration at 6461 ft, trap 4100 psi BHP,watch for 10 min, pressure decreased to 4075 psi. 11/5/2016 11/5/2016 1.80 PROD1 DRILL TRIP P Continue to RIH,sat down worked 6,461.0 9,048.0 17:30 19:18 through tight spots at 6650,6760 ft, back ream pass to 6600 ft,continue to RIH,tight spot at 7670 ft. Tag at 9058 ft. 11/5/2016 11/5/2016 3.20 PROD1 DRILL TRIP P Trip out,laying in 30 bbls of Hi Vis 9,048.0 83.5 19:18 22:30 13.0 ppg K-Formate with alpine beads,2%Klaystop,2%Safe Lube, followed by 13 ppg K-Formate KWF. Perform jog at the tubing tail 6420 to 6480ft. Stops to paint EOP flag at 6602 ft and window flag at 3972 ft, continue to surface,bump up at 83.5 ft. 11/5/2016 11/5/2016 0.50 PROD1 DRILL OWFF P Observe well for 30 min. 83.5 83.5 22:30 23:00 11/5/2016 11/6/2016 1.00 PROD1 DRILL RURD P PJSM,LD BHA#12 over dead well 83.5 0.0 23:00 00:00 11/6/2016 11/6/2016 0.50 PROD1 DRILL BOPE P PJSM,pick up and run safety joint, 0.0 0.0 00:00 00:30 function test BOPE,no failures,lay down test joint Page 13/29 Report Printed: 11/28/2016 • • `,,' Operations Summary (with Timelog Depths) " 2K-11 +ConocoPhittips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2016 11/6/2016 0.40 COMPZ1 CASING PUTB P PJSM on PU and run 13 joints of 2- 0.0 387.0 00:30 00:54 3/8"ST-L slotted liner,stop for BOP drill. 11/6/2016 11/6/2016 0.30 COMPZ1 CASING SFTY P BOP Drill"Running Liner",PU safety 387.0 400.0 00:54 01:12 joint, MU,RIH to space out. 3.5 min response. Debrief in doghouse with crew. While preping to pull out safety joint,observed flow from well. 11/6/2016 11/6/2016 0.80 COMPZ1 CASING TRIP T Closed SSSV,consult town engineer, 400.0 208.0 01:12 02:00 decision to pull out with 13 jnts of liner. Pulled and laydown 7 jnts of liner, directed to shut BOP and monitor SITP. 11/6/2016 11/6/2016 1.00 COMPZ1 CASING OWFF T MU test joint,close upper/lower 2-3/8" 208.0 208.0 02:00 03:00 rams,close TIW,open to WC chk 1 and monitor. SITP built 50 psi and stabilized at 30 min. Continue to monitor,consult town. Plan forward to weight up to potassium formate to 13.1 ppg. ***Note WSR time does not accout for 1 hr falling back, daylight savings time. 11/6/2016 11/6/2016 1.50 COMPZ1 CASING PULD T Install new floats in UQC and PU BHA 208.0 208.0 03:00 04:30 #13. 11/6/2016 11/6/2016 1.00 COMPZ1 CASING PULD T PD BHA#13,bump up at surface 208.0 208.0 04:30 05:30 11/6/2016 11/6/2016 1.70 COMPZ1 CASING TRIP T RIH,start weighting up 12.88 K- 208.0 6,601.0 05:30 07:12 formate kill weight to 13.1 ppg. Lost 9.1 bbls to the formation while RIH. 11/6/2016 11/6/2016 2.60 COMPZ1 CASING OWFF T Bleed wellhead to zero and monitor, 6,601.0 6,601.0 07:12 09:48 60 psi gain in 20 minutes, Pressure started decreasing,at 60 min,WHP is at 42 psi gain over starting pressure. Isolate and zero gauge. Open back up to gauge,WH reading zero. Rig up manual gauge to the stump,also reads zero,Open bleeder at the stump,no flow for a minute, 1 teaspoon flow. S/I gauge still zero. 11/6/2016 11/6/2016 2.50 COMPZ1 CASING OWFF T Continue to build 13.1 kill mud in pit, 6,601.0 6,601.0 09:48 12:18 de inventory process pit,line up to circulate in kill weight fluid. Pump across the top to fill well,no discernable losses. 11/6/2016 11/6/2016 1.70 COMPZ1 CASING CIRC T Line up to pump down coil w/13.1 kill 6,601.0 6,601.0 12:18 14:00 weight K-Formate. Start pumping 0.5 bpm,caught fluid pressure and wellhead©2.46 bbls away. Adjusting choke and pump rate to maintain returns. lost 8.6 bbls to the formation in 38 pumped. 11/6/2016 11/6/2016 3.50 COMPZ1 CASING CIRC T 13.1 ppg kill weight mud at the nozzle, 6,601.0 6,601.0 14:00 17:30 zero pit G/L (7 bbls past theoretical bottoms up,considering losses at 17:30,68.28 bbls out 13.00 ppg mw out) 11/6/2016 11/6/2016 2.25 COMPZ1 CASING CIRC T 13.1 ppg kill weight mud at surface,at 6,601.0 6,601.0 17:30 19:45 104 bbls IN MM vol.shut down,G/L=- 19.4 bbls. Page 14/29 Report Printed: 11/28/2016 • • Operations Summary (with Timelog Depths) as 2, ell,,`,.. r. 2K-11 Cono ►fillips ,,#iackxi Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2016 11/6/2016 1.25 COMPZ1 CASING OWFF T Closed MP Chk B,Monitor WH 6,601.0 6,601.0 19:45 21:00 pressure with Whitey on stump closed for 30 min,0 psi,Open Whitey to half drum and monitor for 30 min,no flow observed,consult town,stick with plan to POOH 11/6/2016 11/6/2016 1.10 COMPZ1 CASING KLWL T Formate falling out in pits,down to 13 6,601.0 6,601.0 21:00 22:06 heavy,weighting up formate back to 13.1 ppg 11/6/2016 11/7/2016 1.90 COMPZ1 CASING TRIP Line-up to pump down coil,at 0.5 6,601.0 208.0 22:06 00:00 bpm,took 3.0 bbls to get returns,start tripping out,stop at 7207.75',paint white window flag,getting 13.1 ppg MW out,continue out,stop at 4103.95 ft,repaint previous window flag that was tied-in at 3972.16 ft(painted blue),stop at 2145 ft to cirulate out 3.8 bbls of 13.0 ppg KWF,let 2 more bbls out at the bit and chase OOH at 50 FPM,saw 13.0 ppg at the shaker, back up to 13.1 ppg,5.5 bbl loss on trip out. 11/7/2016 11/7/2016 1.00 COMPZ1 CASING OWFF T Perform 30 min flow check,well on a 208.0 208.0 00:00 01:00 vac,after 30 min no flow observed. 11/7/2016 11/7/2016 0.70 COMPZ1 CASING PUTB 'T Close U/L 2-3/8"pipe rams to hold 208.0 0.0 01:00 01:42 liner while breaking top connection. Prep rig floor to LD liner assembly. 11/7/2016 11/7/2016 0.80 COMPZ1 CASING PULD T PJSM,opened U/L 2-3/8"pipe rams, 0.0 0.0 01:42 02:30 LD safety joint and 6 joints of 2-3/8" slotted liner. 11/7/2016 11/7/2016 3.00 COMPZ1 CASING BOPE T PJSM, PU and run safety joint,test 0.0 0.0 02:30 05:30 U/L 2-3/8"pipe rams and TIW valve to 250/4700 psi test pressure. Swab valves not holding. Valve crew serviced tree. 11/7/2016 11/7/2016 1.00 COMPZ1 CASING OWFF T Monitor hole for flow. Clean clear rig 0.0 0.0 05:30 06:30 floor of equipment. 11/7/2016 11/7/2016 1.40 COMPZ1 CASING PUTB T PJSM,Fill hole 3 x,2,3.2,and 1.75 0.0 0.0 06:30 07:54 bbls, 6.95 bbls total,prepare liner running equipment. 11/7/2016 11/7/2016 4.10 COMPZ1 CASING PULD P PJSM,Pick up and run 25 joints with a 0.0 1,063.1 07:54 12:00 shorty deployment sleeve. Hole drank 7 bbls of fluid not accounting for liner volume. perform liner running drill, 3.25 minute response time. 11/7/2016 11/7/2016 1.20 COMPZ1 CASING PULD P PJSM,pick up BHA 14,liner running 1,063.0 1,107.0 12:00 13:12 assembly,stab on. 11/7/2016 11/7/2016 1.80 COMPZ1 CASING RUNL P Zero pit G/L,RIH,zero pit G/L,zeroed 1,107.0 5,007.3 13:12 15:00 in/out. lined up down the coil @ min rate,WOB-4.73 k lbs. 20 fph, Minimal losses,increase runing speed to 80 f/hr. Tie into previous blue EOP flag for-5'correction,set WOB to 3.8 k lbs. down on pump,Wt Ck 29.5k lbs,pumping min rate. 11/7/2016 11/8/2016 9.00 COMPZ1 CASING RUNL P Wt ck 43k lbs,RIH,stack weight at 5,073.0 7,910.0 15:00 00:00 6755,PU neutral wt,-40k RBIH, broke through,Worked liner slowly from 6700 to 7748' increase in rate of penetration to 7910. Page 15/29 Report Printed: 11/28/2016 • Operations Summary (with Timelog Depths) . Yi 2K-11 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/8/2016 11/8/2016 7.50 COMPZ1 CASING RUNL P Continue to work lower liner section to 7,910.0 8,025.0 00:00 07:30 bottom,PU to 7990 ft,58K PUW, worked liner back to 8025 ft. 11/8/2016 11/8/2016 3.75 COMPZ1 CASING RUNL P Start 20 bbl beaded pill at 1/2 ppb 8,025.0 8,040.0 07:30 11:15 concentration,at 0.25 bpm/0.19 bpm rate IN/OUT, 13.1 ppg MW IN/OUT (mud balance),park coil while circulating beads,work coil every 15 min,until weight breaks over. 11/8/2016 11/8/2016 1.75 COMPZ1 CASING CIRC P Liner pill at the BHA,(GS spear w/ 8,040.0 8,048.0 11:15 13:00 0.25"port) 11/8/2016 11/8/2016 1.00 COMPZ1 CASING RUNL P Continue to work liner,unable to push 8,048.0 8,048.0 13:00 14:00 liner any deeper,picking up losses footage. Consult with engineer,pump off liner at 8048,37K CW,pull up to 7948',no problem turning around and RIH at 40 FPM, 14K CW. 11/8/2016 11/8/2016 1.50 COMPZ1 CASING CIRC P Reciprocate pipe slowly and circulate 8,048.0 8,048.0 14:00 15:30 while building another 20 bbl beaded pill. 11/8/2016 11/8/2016 2.10 COMPZ1 CASING CIRC P Pump 20 bbl liner pill w/1%KlayStop 8,048.0 6,963.0 15:30 17:36 and 1%Safe Lube,and 1 ppb beads. start at 0.25 bpm IN/0.17 bpm OUT, 730 psi CP,stage rate up to 0.5 bpm IN/0.3 bpm OUT, 1625 psi CP,4549 psi BHP, 14.2 ppg ECD. Remove liner length left in hole 11/8/2016 11/8/2016 0.30 COMPZ1 CASING TRIP P Lay in beaded liner running pill to 6,963.0 6,490.0 17:36 17:54 window, Increase pump rate to attempt to push beads down around liner 11/8/2016 11/8/2016 0.10 COMPZ1 CASING DLOG P Log RA marker for+18' 6,490.0 6,527.0 17:54 18:00 11/8/2016 11/8/2016 0.60 COMPZ1 CASING TRIP P RBIH to push on liner after beaded pill 6,527.0 6,760.0 18:00 18:36 laid in.Clean trip down to set down @ 6760.Work pipe at different speeds and pump rates.Unable to get past. Consult town 11/8/2016 11/8/2016 1.50 COMPZ1 CASING TRIP P Trip out for FCO BHA 6,760.0 62.0 18:36 20:06 11/8/2016 11/8/2016 0.70 COMPZ1 CASING OWFF P Perform No Flow test-good 62.0 62.0 20:06 20:48 11/8/2016 11/8/2016 1.50 COMPZ1 CASING PULD P PJSM,Lay down BHA#14,Shut in 62.0 0.0 20:48 22:18 swabs for ARP HMI software update. Observred 15 PSI increase on MP line,zero on mechanical gauge in 30 min. 11/8/2016 11/9/2016 1.70 COMPZ1 CASING PULD P PJSM,PD BHA#15 with 1.6°AKO 0.0 62.4 22:18 00:00 motor and D-331 slick gauge mill,No pressure on well.Pressure deployed as precaution 11/9/2016 11/9/2016 1.40 COMPZ1 CASING PULD T Continue PD BHA#15 with 1.6° 62.4 62.4 00:00 01:24 motor and D-331 slick Gauge mill. M/U to coil and surface test. 11/9/2016 11/9/2016 1.30 COMPZ1 CASING TRIP T Trip in hole with BHA#15,FCO with 62.4 6,435.0 01:24 02:42 1.6°motor and D331 mill,EDC Open 11/9/2016 11/9/2016 0.20 COMPZ1 CASING DLOG T Log K1 for+7' 6,435.0 6,461.0 02:42 02:54 Page 16/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) . 2K-11 GonocoPtaitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK6)'; 11/9/2016 11/9/2016 0.10 COMPZ1 CASING TRIP T Trip into 6500' 6,461.0 6,500.0 02:54 03:00 11/9/2016 11/9/2016 2.25 COMPZ1 CASING CIRC T Park @ 6500 and displace hole to 6,500.0 6,500.0 03:00 05:15 8.6PPG flow pro,closed EDC 11/9/2016 11/9/2016 2.75 COMPZ1 CASING MILL T RIH an tag at 6650',work down to 6,500.0 6,759.0 05:15 08:00 6759',mill/work pipe to get deeper, pull 58K(10K overpull)twice. Sample collected at 8am was mostly siltstone cuttings with a little frac sand and a few alpine beads 11/9/2016 11/9/2016 1.20 COMPZ1 WELCTL TRIP T Discovered pin holed pipe while at 6,759.0 6,759.0 08:00 09:12 -6730',pull up looking for pin hole,at counter head with depth at 6620'(-77 ft distance from reel to goose neck), shut down pumps and closed choke to trap WHP,pin hole stopped misting, spooled pin hole on to reel,attempt to verify if checks are holding,bleed pump presssure,checks not holding. Hole is not leaking,consult town, 11/9/2016 11/9/2016 2.30 COMPZ1 WELCTL TRIP T Tripped out,pumping down annulus 6,759.0 62.4 09:12 11:30 on MP schedule,at surface,bump up and space out to 62.8'. 11/9/2016 11/9/2016 2.25 COMPZ1 WELCTL PULD 'T PJSM,PUD BHA#14,while on MP. 62.4 0.0 11:30 13:45 Laydown BHA. 11/9/2016 11/9/2016 3.00 COMPZ1 CASING CTOP .T Clear rig floor, MU nozzel on coil, 0.0 0.0 13:45 16:45 PJSM w/SLB,RU N2,blow down coil w/1500 scf for 15 mins to TT, RD SLB N2. I 11/9/2016 11/9/2016 1.25 COMPZ1 CASING CTOP T Bleed off CT N2,PJSM,remove inner 0.0 0.0 16:45 18:00 reel and pressure bulkhead 11/9/2016 11/9/2016 0.50 COMPZ1 CASING CTOP T Crew change, 0.0 0.0 18:00 18:30 11/9/2016 11/9/2016 2.50 COMPZ1 CASING CTOP 'T PJSM,Remove wash pipe from reel, 0.0 0.0 18:30 21:00 Cut CT connector.Dress coil for grapple connector and install.Rig up pull back cable.Rig up sheive to skate. 11/9/2016 11/10/2016 3.00 COMPZ1 CASING CTOP T PJSM,Pull test grapple connector, 0.0 0.0 21:00 00:00 Pull CT back to storage reel and secure,Pull stripper from injector 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T Rig off reel saddle clamps, Pull 0.0 0.0 00:00 04:00 stuffing box brass.rig up to swap reels 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T PJSM with Peak-Swap CT strings, 0.0 0.0 04:00 08:00 install saddle clamps,rebuild PO assembly with new brass and MU to injector. 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T PJSM,layout cable and rig up sheive 0.0 0.0 08:00 12:00 to skate 11/10/2016 11/10/2016 2.75 COMPZ1 CASING CTOP T Dress coil for internal grapple 0.0 0.0 12:00 14:45 connector and install,failed pull test, had to cut off a repeat,passed pull test,ready for stabbing pipe. 11/10/2016 11/10/2016 0.25 COMPZ1 CASING CTOP T PJSM,Stab pipe 0.0 14:45 15:00 11/10/2016 11/10/2016 0.25 COMPZ1 CASING RGRP T Stop for ARP to come off Hi Line to 0.0 0.0 15:00 15:15 replace a breaker. Page 17/29 Report Printed: 11/28/2016 `° Operations Summary (with Timelog Depths) nx t. 2K-11 hiillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/10/2016 11/10/2016 1.25 COMPZ1 CASING CTOP T Begin pulling coil to injector,rig went 0.0 0.0 15:15 16:30 black for 5 min,check rig systems before proceeding with stabbing pipe. 11/10/2016 11/10/2016 1.00 COMPZ1 CASING CTOP T Cut off internal grapple connector. 0.0 0.0 16:30 17:30 MU Baker external connector for chain tension/traction pressure pull test. 11/10/2016 11/10/2016 4.50 COMPZ1 CASING CTOP T Continue install inner reel iron-wash 0.0 0.0 17:30 22:00 pipe-Make up 10K pressure bulkhead,Work on choke calibration 11/10/2016 11/10/2016 1.00 COMPZ1 CASING CTOP T PJSM, Rig up LRS and pump 5 BBL 0.0 0.0 22:00 23:00 60/40 methonal spear into coil 11/10/2016 11/10/2016 0.50 COMPZ1 CASING CTOP T PJSM, Perform pull tests for traction 0.0 0.0 23:00 23:30 pressure vs.tubing loads.All pressures verified at HMI and manual traction pressure gauges.Pulled 50K @ 1260PSI.pulled 70K @ 1800 PSI, pulled 90K @ 2220PSI. RIH 15' between each test looking for marks on CT. 11/10/2016 11/11/2016 0.50 COMPZ1 CASING CTOP T Skid injector cart back to floor and cut 0.0 23:30 00:00 off BOT grapple connector.Prep for crew change out 11/11/2016 11/11/2016 0.50 COMPZ1 CASING CTOP T Crew change,run valve checklist 0.0 0.0 00:00 00:30 11/11/2016 11/11/2016 1.70 COMPZI CASING CTOP T Trim 25'of coil for pull tests, Prep coil 0.0 0.0 00:30 02:12 for connector.Test wire,550MOhms, 62.7 Ohmes. Install CTC and pull to 40K 11/11/2016 11/11/2016 1.30 COMPZ1 CASING CTOP T Head up E-line and test connection 0.0 0.0 02:12 03:30 11/11/2016 11/11/2016 3.00 COMPZI CASING CTOP T Fill coil with water,pressure test inner 0.0 0.0 03:30 06:30 reel iron,MU test plate and PT coil connector. 11/11/2016 11/11/2016 2.25 COMPZI CASING PULD T MU BHA and PD BHA#16,surface 0.0 0.0 06:30 08:45 test tool,voltage not correct. Troublshool BHI tools. 11/11/2016 11/11/2016 1.75 COMPZ1 CASING CTOP T Change out flow sub,retest,still not 0.0 0.0 08:45 10:30 right. BHI called support to trouble shoot,isolated the problem,the polarity was reversed at the collector during the reel swap,reversed the polarity in the MWD office and retest, good test."*need to get Nabors Electrician to swicth the polarity at the collector at next opportune time'"` 11/11/2016 11/11/2016 0.50 COMPZ1 CASING PULD T Proceed with PD 0.0 62.4 10:30 11:00 11/11/2016 11/11/2016 1.30 COMPZ1 CASING TRIP T Trip in with EDC open pumping 12.8 62.4 6,430.0 11:00 12:18 ppg MP schedule. 11/11/2016 11/11/2016 0.20 COMPZ1 CASING DLOG T Tie-in to K1,+14 ft,close EDC 6,430.0 6,447.0 12:18 12:30 11/11/2016 11/11/2016 0.20 COMPZ1 CASING TRIP T RIH at min rate,tag at 6763 ft,come 6,447.0 6,763.0 12:30 12:42 up to 1.37 bpm,3661 pis CP,355 dp free spin Page 18/29 Report Printed: 11/28/2016 • • VA 0 Operations Summary (with Timelog Depths) l 2K-11 Philii;ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End.Depth(ftKB) 11/11/2016 11/11/2016 1.90 COMPZ1 CASING MILL T Trip in with mill,SD at 6760.8 ft,stall 6,763.0 6,780.0 12:42 14:36 2x,mill for 10 min,to 6763 ft,stall with 5K WOB, PU,resume milling,pump 16 bbls of 2%KCL water,at bit at 14:20,6765 ft,all 16 bbls out,mill to 6780 ft with 2K WOB,returns are showing 75-80%silt, 10-15%frac sand 11/11/2016 11/11/2016 0.20 COMPZ1 CASING MILL T PU clean 43 to 46K,run in at different 6,780.0 6,780.0 14:36 14:48 speeds w/pumps on&off,sit down same spot,6780',consult engineer, Plan to resume milling until going far enough to get a survey. 11/11/2016 11/11/2016 4.30 COMPZ1 CASING MILL T Resume milling at 6768 ft, 1.39 bpm, 6,780.0 6,796.0 14:48 19:06 4201 psi CP,940 psi WHP,767 psi dP,2K WOB.At 6778.8 ft take a PUW,43K,go back to milling 11/11/2016 11/11/2016 1.00 COMPZ1 CASING TRIP T Near bit inclination not matching with 6,796.0 2,055.0 19:06 20:06 drilled hole,Consult town,Trip out for caliper 11/11/2016 11/11/2016 1.80 COMPZ1 CASING TRIP T Trip back to bottom to kill well 2,055.0 6,491.0 20:06 21:54 11/11/2016 11/11/2016 1.20 COMPZ1 CASING TRIP T 5 BBIs 13.0 K Formate out of coil.Trip 6,491.0 66.0 21:54 23:06 out following well kill trip sheet 11/11/2016 11/12/2016 0.90 COMPZ1 CASING OWFF T Perform 30 Min flow check-slight 66.0 66.0 23:06 00:00 flow,Shut in and monitor pressure build up,Build 25 PSI,Bleed off and retest 25 PSI. 11/12/2016 11/12/2016 1.80 COMPZ1 CASING PULD T PJSM,PUD BHA#16 and lay down 66.0 0.0 00:00 01:48 11/12/2016 11/12/2016 1.50 COMPZ1 CASING PULD T PJSM,Vac out stack,20 PSI on MP 0.0 0.0 01:48 03:18 line.Shut master and open swabs. Having issues with camera adapter 11/12/2016 11/12/2016 0.50 COMPZ1 CASING PULD T PJSM, P/U BHA#17 HES 24 arm 0.0 24.7 03:18 03:48 caliper and put in well,Skid injector and M/U to caliper BHA#17 go to surface test caliper junction box is wired backwards.Call out electrician to swap out 11/12/2016 11/12/2016 2.50 COMPZ1 CASING SVRG T Service reel,blow down chokes,swap 24.7 24.7 03:48 06:18 polarity at collector J-box,unlock reel, stab on 11/12/2016 11/12/2016 1.50 COMPZ1 CASING TRIP T Trip in w/EDC open,pumping 0.25 24.7 6,420.0 06:18 07:48 bpm+0.3 bpm displacement,getting 0.42 bpm OUT,8.5 bph loss rate. MW IN=13.1 ppg,MW OUT= 13.0 ppg, adding sks of K-Formate. 11/12/2016 11/12/2016 0.30 COMPZ1 CASING DLOG T Log K1 marker,+3.9 ft correction to 6,420.0 6,488.0 07:48 08:06 HES depth. 11/12/2016 11/12/2016 0.80 COMPZ1 CASING DLOG T Trip in to 6620 ft,log 2 caliper passes 6,488.0 6,620.0 08:06 08:54 to 6370 ft 11/12/2016 11/12/2016 1.40 COMPZ1 CASING TRIP T Trip out w/caliper tools 6,620.0 24.7 08:54 10:18 11/12/2016 11/12/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check,no flow 24.7 24.7 10:18 10:48 observed 11/12/2016 11/12/2016 0.70 COMPZ1 CASING PULD T PJSM,close master valve as 24.7 0.0 10:48 11:30 precaution,LD Halliburton caliper tools,reopen MV,close swabs, monitor WHP. 11/12/2016 11/12/2016 0.50 COMPZ1 CASING WAIT T Wait for caliper log results from Town. 0.0 0.0 11:30 12:00 Page 19/29 Report Printed: 11/28/2016 • • " Operations Summary (with Timelog Depths) 2K-11 ` „tips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 11/12/2016 11/12/2016 1.00 COMPZ1 CASING PULD T PJSM,WHP=0 psi,open swabs and 0.0 72.9 12:00 13:00 check for flow,no flow observerd,MU BHA#18,2.625"aluminum anchored billet to CoilTrak,deploy over dead well. 11/12/2016 11/12/2016 1.80 COMPZ1 CASING TRIP T Trip in with EDC's open 72.9 6,430.0 13:00 14:48 11/12/2016 11/12/2016 0.20 COMPZ1 CASING DLOG T Log K1 marker,+2 ft correction 6,430.0 6,472.0 14:48 15:00 11/12/2016 11/12/2016 0.20 COMPZ1 CASING TRIP T Close EDC,get PUW=40K,RIW= 6,472.0 6,588.7 15:00 15:12 12.5K at 15 FPM,orient top slip at 30° ROHS,set top of anchored billet at 6577 ft,bottom at 6588.5 ft(center of slips at 6587 ft). Set down and hold 4K WOB,holds solid, PU clean 11/12/2016 11/12/2016 1.40 COMPZ1 CASING TRIP T Trip out with EDC closed,pumping 6,588.7 72.9 15:12 16:36 13.1 ppg trip schedule,0.51 bpm, 11/12/2016 11/12/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check, 72.9 72.9 16:36 17:06 11/12/2016 11/12/2016 0.90 COMPZ1 CASING PULD T LD BHA#17 Baker#10 setting tool. 72.9 0.0 17:06 18:00 11/12/2016 11/12/2016 1.00 COMPZ1 CASING CTOP T Crew change,Valve checklist,M/U 0.0 0.0 18:00 19:00 nozzle to coil and stab on well,Line up to pump 11/12/2016 11/12/2016 1.00 COMPZ1 CASING CTOP T Jet stack,Test stripper and inner reel 0.0 0.0 19:00 20:00 iron-shell test 11/12/2016 11/12/2016 2.00 COMPZ1 CASING CTOP T Unstab injector and rack back.prep 0.0 0.0 20:00 22:00 for BOPE test,Jetted with bring- Flush stack with water-service stack, tree and rig valves 11/12/2016 11/13/2016 2.00 PROD1 DRILL BOPE P Perform Full bi weekly BOPE test. 0.0 22:00 00:00 Test witnes waived by Bob Noble, AOGCC 11/13/2016 11/13/2016 4.50 COMPZ1 CASING BOPE P Continue full bi-weekly BOPE Test 00:00 04:30 11/13/2016 11/13/2016 2.50 PROD1 DRILL PULD T Complete BOPE test.Flush stack with 0.0 72.1 04:30 07:00 13PPG KFormate,PJSM P/U BHA# 19 Kick off-build section with 2.6° motor and RB HCC Bi Center. Had to work BHA thru tree. 11/13/2016 11/13/2016 0.25 PROD1 DRILL WAIT T Double check&verify valve allignment 72.1 72.1 07:00 07:15 after BOP test,bofore tripping in. 11/13/2016 11/13/2016 1.60 PROD1 DRILL TRIP T Trip in with EDC open,pump 10 bbl 72.1 6,440.0 07:15 08:51 spacer(interface)followed by 8.6 ppg FloPro System 2 11/13/2016 11/13/2016 0.20 PROD1 DRILL DLOG T Log K1 marker,+2.5 ft correction 6,440.0 6,502.0 08:51 09:03 11/13/2016 11/13/2016 1.60 PROD1 DRILL CIRC T 'Swap hole over to 8.6 ppg FloPro 6,502.0 6,502.0 09:03 10:39 11/13/2016 11/13/2016 0.30 PROD1 DRILL TRIP 'T Close EDC,trip in and tag billet at 6,502.0 6,577.0 10:39 10:57 6577 ft,42K PUW,run back in, establish parameters at 1.52 bpm, 3900 psi CP,690 psi WHP,385 psi free spin. 11/13/2016 11/13/2016 4.00 PROD1 DRILL DRLG T Start drilling on billet at 6576.8 ft at 1 6,577.0 6,637.0 10:57 14:57 fph,30°LOHS,6578 ft,drill at 2 fph, 6579 ft drill at 3 fph,kicked off at 6581 ft,drilling build section getting 45° DLS. Page 20/29 Report Printed: 11/28/2016 • • ": ` Operations Summary (with Timelog Depths) 2K-11 Co iocaPhiil®ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End..Depth(ftKB) 11/13/2016 11/13/2016 0.20 PROD1 DRILL WPRT T Pull up to 6550 ft,39K PUW,dry drift 6,637.0 6,637.0 14:57 15:09 billet,no issues,increase rate to 1.70 bpm,4368 psi CP,640 psi WHP,475 psi free spin 11/13/2016 11/13/2016 1.60 PROD1 DRILL DRLG T Continue drilling build section to 6695 6,637.0 6,695.0 15:09 16:45 ft 11/13/2016 11/13/2016 0.20 PROD1 DRILL WPRT T Wiper to allow DD to restart Wellpath 6,695.0 6,695.0 16:45 16:57 and recalc EOB projection. 11/13/2016 11/13/2016 0.50 PROD1 DRILL DRLG T OBD, 1.70 bpm,4594 psi CP,700 psi 6,695.0 6,710.0 16:57 17:27 WHP,714 dP,3K WOB 11/13/2016 11/13/2016 2.10 PROD1 DRILL TRIP T 6710',Call FOB,Avg DLS=51.2°, 6,710.0 71.4 17:27 19:33 PUW=41 K,Open EDC above window and circ in KWF 11/13/2016 11/13/2016 1.00 PROD1 DRILL OWFF T At surface, Perform 30 Min No Flow, 71.4 71.4 19:33 20:33 Build 40 PSI in 30 min.Bleed off and retry.Still building.Consult town.Go to PUD mode 11/13/2016 11/13/2016 1.50 PROD1 DRILL PULD T PJSM, PUD BHA#19 71.4 0.0 20:33 22:03 11/13/2016 11/13/2016 1.80 PROD1 DRILL PULD T PJSM, PD BHA#20,AL1 lateral BHA 0.0 72.2 22:03 23:51 with.4°AKO motor and RR bi center, M/U to coil and surface test 11/13/2016 11/14/2016 0.15 PROD1 DRILL TRIP T Trip in hole, BHA#20 72.2 120.0 23:51 00:00 11/14/2016 11/14/2016 1.40 PROD1 DRILL TRIP T Continue running in hole 120.0 6,440.0 00:00 01:24 11/14/2016 11/14/2016 0.10 PROD1 DRILL DLOG T Log K1 for+3'correction 6,440.0 6,459.0 01:24 01:30 11/14/2016 11/14/2016 0.10 PROD1 DRILL TRIP T RIH to 6491 6,459.0 6,491.0 01:30 01:36 11/14/2016 11/14/2016 1.60 PROD1 DRILL CIRC T Displace 13PPG to 8.6 PPG flow pro 6,491.0 6,491.0 01:36 03:12 11/14/2016 11/14/2016 0.20 PROD1 DRILL TRIP T Shut EDC,PUW=38K, RIH to drill, 6,491.0 6,711.0 03:12 03:24 Clean trip through window 11/14/2016 11/14/2016 5.40 PROD1 DRILL DRLG T 6711',Drill, 1.65 BPM @ 4237 PSI 6,711.0 7,125.0 03:24 08:48 FS,BHP=4110,average ROP=77 fUhr,up to 140 fUhr, At 7110 ft,pump 5x5 Lo/Hi vis sweep. 11/14/2016 11/14/2016 0.40 PROD1 DRILL WPRT Planned wiper trip,39K PUW,pull into 7,125.0 6,440.0 08:48 09:12 window for BHP pressure calibration, perform jog at EO tubing 11/14/2016 11/14/2016 0.30 PROD1 DRILL DLOG Open EDC,tie in to K1 for+2.5 ft 6,440.0 6,510.0 09:12 09:30 correction 11/14/2016 11/14/2016 0.50 PROD1 DRILL TRIP Finish circulating a BU,shut down 6,510.0 6,510.0 09:30 10:00 pumps to take pressure calibration survey at the window with 12.8 ppg EMW,trapped 1158 psi WHP with 9.2 ppg MW. Bled off 50 psi and let pressure build for 20 min to 1219 psi, bled,repeat bled 50 psi and pressure built back to 1220 psi in 10 min, EMW= 13.0 ppg. 11/14/2016 11/14/2016 0.40 PROD1 DRILL TRIP Close EDC,trip in to resume drilling, 6,510.0 7,125.0 10:00 10:24 establish off bottom parameters, 1.65 bpm,4389 psi CP,633 psi WHP,528 psi dP 11/14/2016 11/14/2016 3.10 PROD1 DRILL DRLG Drilling,send 5x5 Lo/Hi vis sweep 7,125.0 7,535.0 10:24 13:30 11/14/2016 11/14/2016 0.50 PROD1 DRILL WPRT Wiper trip,42K PUW,pull up to 6615 7,535.0 7,535.0 13:30 14:00 ft,RBIH Page 21/29 Report Printed: 11/28/2016 • • t Operations Summary (with Timelog Depths) r 2K-11 ConocoPhiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/14/2016 11/14/2016 2.50 PROD1 DRILL DRLG Drilling,averageing 150 to 180 ft/hr,at 7,535.0 7,954.0 14:00 16:30 7710 ft pumped 5x5 Lo/Hi vis sweep, pumped 5x5 Lo/Hi vis sweep before third wiper 11/14/2016 11/14/2016 1.00 PROD1 DRILL WPRT Wiper trip,42K PUW clean pick up, 7,954.0 7,954.0 16:30 17:30 pull up to 6600 ft, RBIH 11/14/2016 11/14/2016 3.00 PROD1 DRILL DRLG Drilling ahead,on bottom parameters, 7,954.0 8,325.0 17:30 20:30 1.69 bpm,4854 psi CP,677 psi WHP, 819 psi dP w/2K WOB,avg ROP 140 ft/hr. 11/14/2016 11/14/2016 1.40 PROD1 DRILL WPRT Wipe trip with a tie-in,46K PUW, 8,325.0 8,325.0 20:30 21:54 clean pick up,wiper up to 6525 ft,tie into RA tag,+6 ft correction,dry drift past billet at 6577 ft clean,RBIH to drill,establish off bottom parmeters, 1.66 bpm,4470 psi CP,680 psi WHP, 524 psi dP, -11/14/2016 11/15/2016 2.10 PROD1 DRILL DRLG Drilling,on bottom parameters, 1.68 8,325.0 8,580.0 21:54 00:00 bpm,4801 psi CP,695 psi WHP,860 psi dP,2K WOB, 114 ft/hr. 11/15/2016 11/15/2016 1.30 PROD1 DRILL DRLG P 8580',Cont drill ahead, 1.68 BPM @ 8,580.0 8,725.0 00:00 01:18 4450 PSI FS,BHP=4535 11/15/2016 11/15/2016 0.80 PROD1 DRILL WPRT P 8725',Wiper to 7725'with 5 X 5 8,725.0 8,725.0 01:18 02:06 sweeps,PUW=46K.Clean trip up and down 11/15/2016 11/15/2016 1.00 PROD1 DRILL DRLG P 8725',Drill, 1.68 BPM @ 4540 PSi 8,725.0 8,900.0 02:06 03:06 FR,BHP=4525,RIW=3.4K @ 1.98K DHWOB 11/15/2016 11/15/2016 2.70 PROD1 DRILL WPRT P Reach Plan TD,Pump 10 X 10 8,900.0 72.0 03:06 05:48 Sweeps,Pull Swab wiper,PUW=46K 11/15/2016 11/15/2016 1.20 PROD1 DRILL WPRT P Wiper back in hole 72.0 6,440.0 05:48 07:00 11/15/2016 11/15/2016 0.20 PROD1 DRILL DLOG P Log K1 for+2'correction 6,440.0 6,458.0 07:00 07:12 11/15/2016 11/15/2016 0.70 PROD1 DRILL WPRT P Trip into 6504'MD(6178'TVD),above 6,458.0 6,708.0 07:12 07:54 window,static BHP survey,4231 PSI, 13.15PPG EMW.Shut in EDC 11/15/2016 11/15/2016 0.60 PROD1 DRILL TRIP P Trip into heel of well 6708'MD(6307 6,708.0 6,505.0 07:54 08:30 TVD,4310 PSI 13.12 EMW,Pull back to cased hole,pump 0.96 BPM with 1:1 returns and ECD=13.6ppg. 11/15/2016 11/16/2016 15.50 PROD1 DRILL WAIT T Wait on 13.4PPG KWF from MI 6,505.0 6,505.0 08:30 00:00 11/16/2016 11/16/2016 4.75 PROD1 DRILL WAIT T Wait on 13.4ppg micronized barite 6,505.0 6,505.0 00:00 04:45 KWF. 11/16/2016 11/16/2016 2.20 PROD1 DRILL OTHR Fluid truck arrives,Mud weight 13.6 6,505.0 6,505.0 04:45 06:57 agitate on truck 30 minutes,still 13.6. Offload to pits,crew change, Mix beads in liner pill T1/16/2016 11/16/2016 1.10 PROD1 DRILL TRIP Close EDC and trip in hole to confirm 6,505.0 8,900.0 06:57 08:03 TD,Tag up @ 8900,clean trip to TD 11/16/2016 11/16/2016 3.80 PROD1 DRILL TRIP Trip out pumping 13.1 beaded liner 8,900.0 66.0 08:03 11:51 running pill followed by 13.6PPG WARP fluid,Paint EOP Flags 6800& 4400 11/16/2016 11/16/2016 0.60 PROD1 DRILL OWFF At surface,Flow check well-good 66.0 66.0 11:51 12:27 test,lost 0.5 bbl/30 min Page 22/29 Report Printed: 11/28/2016 • • Operations Summary (with Timelog Depths) ,0 ''R 10� 2K-11 Conoccehillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKE) 11/16/2016 11/16/2016 1.00 PROD1 DRILL PULD PJSM,Lay down BHA#20 66.0 0.0 12:27 13:27 11/16/2016 11/16/2016 0.50 COMPZ1 CASING OTHR PJM,Prep floor to run liner 0.0 0.0 13:27 13:57 11/16/2016 11/16/2016 5.40 COMPZ1 CASING PUTB PJSM,P/U BHA#21 with non ported 0.0 2,056.0 13:57 19:21 bullnose,67 Jts slotted liner and shorty deployment sleeve. MU to running tools.MU running tools to coil. Tag-up.Ready to RIH. 11/16/2016 11/16/2016 1.00 COMPZ1 CASING RUNL RIH.Walk up speed to 40 FPM, 2,056.0 3,460.0 19:21 20:21 pumping min rate(10 SPM=0.22 BPM),walk speed down to 20 FPM to minimize losses.Lost 2.4 bbls in first 1000'of coil RIH. Erratic pumping in pressure/rate,bypass high pressure screen and swap to Mud Pump#2 @ 3,460'MD. 11/16/2016 11/17/2016 3.65 COMPZ1 CASING RUNL Cont RIH BHA#21. 15-20 FPM 3,460.0 7,283.0 20:21 00:00 pumping min rate.Correct depth @ flag(-5.7 ft).PUW=40k.Cont RIH. 11/17/2016 11/17/2016 1.50 COMPZ1 CASING RUNL P Cont RIH 15-20 FPM pumping min 7,283.0 8,900.0 00:00 01:30 rate(0.22 BPM). Initially stacked out @ 8,212'.Stacked out @ numerous other depths. PUH each time, RBIH. WOB=5k, PUW=48k to 55k.Cont RIH to tag TD. 11/17/2016 11/17/2016 0.25 COMPZ1 CASING RUNL P Tagged TD,PUH to 8,859',RBIH to 8,900.0 6,852.0 01:30 01:45 8,864'to put liner in compression prior to pumping to release. Max pump pressure,5500 psi @ 1.3 BPM with the 13.4 KWF fluid.PUH,liner released.TOL @ 6,852'MD.-40 bbls losses during liner running/setting. 11/17/2016 11/17/2016 4.60 COMPZ1 CASING DISP P PUH to just above window,pump 10 6,852.0 6,506.0 01:45 06:21 bbl hi-vis pill displacing KWF @ min rate(0.22 BPM),losing-4 BPH while pumping. 11/17/2016 11/17/2016 1.20 COMPZ1 CASING TRIP P POOH following MP schedule, 6,506.0 44.0 06:21 07:33 13.4ppg target @ window. 11/17/2016 11/17/2016 2.00 COMPZ1 CASING PULD P PUD BHA#21 liner running tools. 44.0 0.0 07:33 09:33 Flush and lay down 11/17/2016 11/17/2016 1.00 COMPZI CASING PULD P PJSM,PD BHA#22,Open hole 0.0 72.9 09:33 10:33 anchored Billet 11/17/2016 11/17/2016 0.30 COMPZ1 CASING RGRP P Complete Micro motion swap before 72.9 72.9 10:33 10:51 pressuring up PDL 11/17/2016 11/17/2016 1.00 COMPZI CASING PULD P Pressure up PDL-continue PD BHA 72.9 72.9 10:51 11:51 22,M/U to coil and surface test 11/17/2016 11/17/2016 3.90 COMPZ1 CASING PULD T Tool did not pass test-DPS.PUD 72.9 72.9 11:51 15:45 BHA#22 to trouble shoot.C/O PDS. PD BHA#23 and surface test tool.Still having issues.Consult town. Move forward with full deployment.Tag up. tool seems normal. **NOTE:3.5 Hrs BHI NPT** 11/17/2016 11/17/2016 1.35 COMPZI CASING TRIP P Trip in hole BHA#23 anchor billet 72.9 6,440.0 15:45 17:06 11/17/2016 11/17/2016 0.20 COMPZ1 CASING DLOG P Tie-in @ K1 for+5.5'correction. 6,440.0 6,446.0 17:06 17:18 Page 23/29 Report Printed: 11/28/2016 r • ';1.:% ' Operations Summary (with Timelog Depths) z fi;014 2K-11 ifflps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time'' End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/17/2016 11/17/2016 0.30 COMPZ1 CASING TRIP P RIH,close EDC @ 6,493'.Cont RIH to 6,446.0 6,852.0 17:18 17:36 billet setting depth.Set TOB @ 6,840' with anchor @ 180°. 11/17/2016 11/17/2016 1.65 COMPZ1 CASING TRIP P POOH BHA#23.Tag,space-out, 6,852.0 75.0 17:36 19:15 open EDC. 11/17/2016 11/17/2016 1.75 COMPZ1 CASING PULD P PJSM,PUD&LD BHA#23. 75.0 0.0 19:15 21:00 11/17/2016 11/17/2016 2.40 PROD2 STK PULD P PJSM,PU&PD BHA#24,A lateral 0.0 72.0 21:00 23:24 KO assembly(2.4°AKO+HCC RR). CO injector packoffs,tag-up. 11/17/2016 11/18/2016 0.60 PROD2 STK TRIP P RIH BHA#24. 72.0 3,003.0 23:24 00:00 11/18/2016 11/18/2016 0.75 PROD2 STK TRIP P Cont RIH BHA#24(A lateral KO build 3,003.0 6,440.0 00:00 00:45 assembly).Swap chokes due to pressure fluctuations.Cont RIH pumping min rate(0.25 BPM). 11/18/2016 11/18/2016 0.20 PROD2 STK DLOG P Tie-in to K1 for+2'correction. 6,440.0 6,462.0 00:45 00:57 11/18/2016 11/18/2016 0.25 PROD2 STK TRIP P Close EDC. RIH,pumps off @ 6,830'. 6,462.0 6,840.0 00:57 01:12 Dry tag TOB @ 6,840'. `11/18/2016 11/18/2016 1.50 PROD2 STK KOST P PUH,start pumping,RIH,drill, 1.67 6,840.0 6,843.8 01:12 02:42 BPM @ 4466 psi FS,WOB 0.3, CTSW 2.5k.WOB increasing,CTSW decreasing but no motor work. 11/18/2016 11/18/2016 0.35 PROD2 STK KOST P BHA wiper,saw WOB 1 ft higher 6,843.8 6,842.8 02:42 03:03 11/18/2016 11/18/2016 0.40 PROD2 STK KOST P BOBD, 1.68 BPM @ 4333 psi FS, 6,842.8 6,870.0 03:03 03:27 WOB 2.7k,CTSW 3k.Got passed tight area.ROP increased to 70 FPH. 11/18/2016 11/18/2016 0.10 PROD2 DRILL WPRT P PUH for dry drift.Dry drift passed billet 6,870.0 6,870.0 03:27 03:33 with 1k WOB bobble.Cont RIH. 11/18/2016 11/18/2016 4.60 PROD2 DRILL DRLG P BOBD, 1.67 BPM @ 4353 psi FS, 6,870.0 7,200.0 03:33 08:09 WOB 2.4k,CTSW 9.1k,ROP 75 11/18/2016 11/18/2016 1.70 PROD2 DRILL TRIP P 7200',Call end of build,Avg DLS=39°, 7,200.0 73.0 08:09 09:51 PUW=49K 11/18/2016 11/18/2016 2.00 PROD2 DRILL PULD 'P Tag up and space out, PJSM PUD 73.0 0.0 09:51 11:51 BHA#24 build turn BHA 11/18/2016 11/18/2016 1.00 PROD2 DRILL CTOP P Reconfig tool string,run same top half 0.0 0.0 11:51 12:51 run.P/U New hot DGS and Res 11/18/2016 11/18/2016 1.10 PROD2 DRILL PULD P PD BHA#25,A lateral BHA with 0.4+ 0.0 72.0 12:51 13:57 motor and rr bi center,M/U to coil and surface test.Strip on.Tag up and set counters 11/18/2016 11/18/2016 1.60 PROD2 DRILL TRIP P Trip in hole, BHA#25 72.0 6,435.0 13:57 15:33 11/18/2016 11/18/2016 0.20 PROD2 DRILL DLOG P Log K1 for+4',Close EDC,PUW=42K 6,435.0 6,465.0 15:33 15:45 11/18/2016 11/18/2016 1.10 PROD2 DRILL TRIP P Continue in well,clean trip through 6,465.0 7,200.0 15:45 16:51 window and past billets 11/18/2016 11/18/2016 3.80 PROD2 DRILL DRLG P 7200',Drill, 1.68 BPM @ 4550 PSI 7,200.0 7,610.0 16:51 20:39 FS,BHP=4471. Fault#2 called @ 7,471'. 11/18/2016 11/18/2016 0.70 PROD2 DRILL WPRT P Wiper Trip#1 to 6,870'.PUW=48k. 7,610.0 7,610.0 20:39 21:21 11/18/2016 11/18/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4491 psi FS, 7,610.0 7,746.0 21:21 23:21 WOB 0.9k,CTSW 5.9k,73 ROP.New FloPro Mud System#3 at bit @ 7,661'.Cont drilling ahead. Page 24/29 Report Printed: 11/28/2016 • • 0 Operations Summary (with Timelog Depths) 2K-11 ConocciPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS) 11/18/2016 11/18/2016 0.35 PROD2 DRILL WPRT P Stacking, PUH(PUW=52k),BOBD, 7,746.0 7,746.0 23:21 23:42 PUH to swap chokes,blow down Choke A. 11/18/2016 11/19/2016 0.30 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4324 psi FS, 7,746.0 7,773.0 23:42 00:00 WOB 1.5k,CTSW-3.9k, ROP 77. 11/19/2016 11/19/2016 0.25 PROD2 DRILL DRLG P Drilling, 1.68 BPM @ 4368 psi FS, 7,773.0 7,789.0 00:00 00:15 WOB 1k,CTSW 2.7k,ROP 56. 11/19/2016 11/19/2016 0.25 PROD2 DRILL WPRT P Short wiper,PUW=55k. 7,789.0 7,789.0 00:15 00:30 11/19/2016 11/19/2016 1.00 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4368 psi FS, 7,789.0 7,820.0 00:30 01:30 WOB 1.7k,CTSW-4.8k,ROP 32. 11/19/2016 11/19/2016 0.35 PROD2 DRILL WPRT P Short wiper, PUW=41k.Pump 5x5 7,820.0 7,820.0 01:30 01:51 sweeps 11/19/2016 11/19/2016 1.05 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4281 psi FS, 7,820.0 7,872.0 01:51 02:54 WOB 1.1k,CTSW 3k,ROP 40. Drilling through lower A4 sand lobes causing varying ROP. 11/19/2016 11/19/2016 0.60 PROD2 DRILL WPRT P Short wiper to 7,505'.Pump 15 bbl 7,872.0 7,872.0 02:54 03:30 2ppb beaded hi-vis pill. 11/19/2016 11/19/2016 0.20 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4281 psi FS, 7,872.0 7,882.0 03:30 03:42 WOB 1.2k,CTSW 1.6k,ROP 65. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P Short wiper to swap chokes,lower 7,882.0 7,882.0 03:42 03:54 pump rate to 1.5 BPM, RBIH. 11/19/2016 11/19/2016 0.50 PROD2 DRILL DRLG P BOBD, 1.4 BPM @ 3920 psi FS,WOB 7,882.0 7,903.0 03:54 04:24 1.4k,CTSW-2.9k,ROP 36. 11/19/2016 11/19/2016 0.60 PROD2 DRILL WPRT P Pull wiper early,PUW=58K to 6524 7,903.0 6,524.0 04:24 05:00 11/19/2016 11/19/2016 0.10 PROD2 DRILL DLOG P Log RA marker for+6.5' 6,524.0 6,549.0 05:00 05:06 11/19/2016 11/19/2016 0.70 PROD2 DRILL WPRT P Wiper back to bottom 6,549.0 7,906.0 05:06 05:48 11/19/2016 11/19/2016 1.60 PROD2 DRILL DRLG P 7906', Drill ahead, 1.6 BPM @ 4306 7,906.0 7,973.0 05:48 07:24 PSI FS, BHP=4930 11/19/2016 11/19/2016 0.30 PROD2 'DRILL WPRT P BHA Wiper, 100',stacking 7,973.0 7,973.0 07:24 07:42 11/19/2016 11/19/2016 4.50 PROD2 DRILL DRLG P 7973',Drill 1.8 BPM @ 4630 PSI FS, 7,973.0 8,310.0 07:42 12:12 BHP=4510,RIW=1K @ 1.8K DHWOB 11/19/2016 11/19/2016 1.00 PROD2 DRILL WPRT P 8310', 1000'wiper with 5 X 5 sweeps, 8,310.0 8,310.0 12:12 13:12 PUW=51K,clean trip up and down. 11/19/2016 11/19/2016 1.35 PROD2 DRILL DRLG P 8310',Drill ahead,1.6 BPM @ 4550 8,310.0 8,460.0 13:12 14:33 PSI FS,BHP=4465.CTW=3K, DHWOB=1.3,ROP=150 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P BHA wiper,PUW=51k. 8,460.0 8,460.0 14:33 14:45 11/19/2016 11/19/2016 0.50 PROD2 DRILL DRLG P BOBD, 1.6 BPM @ 4627 psi FS,WOB 8,460.0 8,519.0 14:45 15:15 1.2k,CTSW-6k, ROP 134 down to 15. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P 200'wiper trip,PUW=45k. 8,519.0 8,519.0 15:15 15:27 11/19/2016 11/19/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.6 BPM @ 4564 psi FS, 8,519.0 8,633.0 15:27 17:27 WOB1.7k,CTSW-2k,ROP 63. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P 200'wiper trip, PUW=52k. 8,633.0 8,633.0 17:27 17:39 11/19/2016 11/19/2016 1.20 PROD2 DRILL DRLG P BOBD, 1.62 BPM @ 4795 psi FS, 8,633.0 8,667.0 17:39 18:51 WOB 1.3k,CTSW-5k, ROP 29. Multiple PUs due to weight transfer, Max PUW=62k. Page 25/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 ConocoPhiflips A�sska Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code .Time P-T-x Operation (ftKB) End Depth(ftKB) 11/19/2016 11/19/2016 1.50 PROD2 DRILL TRIP P POOH after consulting w town.Geo's 8,667.0 68.0 18:51 20:21 want planned TD(9,550'MD). Rather than continue to fight weight transfer through the lower A4 sand lobes, decide to trip for agitator.Pump 5x5 sweeps.Open EDC @ 6,391'.Cont POOH BHA#25.Tag-up,space out +1.2'. 11/19/2016 11/20/2016 3.65 PROD2 DRILL PULD P PJSM,PUD BHA#25.Skid injector, 68.0 0.0 20:21 00:00 cont.PUD BHA#25.Blew down MWD/Baker motor and LD bit,motor, lower MWD.(Picking up Weatherford motor w next BHA) 11/20/2016 11/20/2016 PROD2 00:00 00:00 11/20/2016 11/20/2016 0.50 PROD2 DRILL BOPE P Function test BOP w test joint. 0.0 0.0 00:00 00:30 11/20/2016 11/20/2016 1.00 PROD2 DRILL PULD P PU tools,start PD BHA#26(NOV 0.0 80.8 00:30 01:30 agitator,Weatherford motor,HYC B7 "XD)bi-center bit) 11/20/2016 11/20/2016 1.00 PROD2 DRILL PULD P Cont PD.CO packoffs,CO floats in 80.8 80.8 01:30 02:30 UQC,MU QC.Test MWD.Stab on WH.Equalize,open rams,tag stripper. 11/20/2016 11/20/2016 0.50 PROD2 DRILL TRIP P RIH BHA#26.Close EDC @ 188'MD. 80.8 226.0 02:30 03:00 Test agitator,feel vibration w hand on coil, 1.7 BPM @ 5400 psi FS, differential=1270 psi within expectations(629 psi for agitator,750 psi for Weatherford motor). 11/20/2016 11/20/2016 1.15 PROD2 DRILL TRIP P Cont RIH BHA#26. 226.0 6,460.0 03:00 04:09 11/20/2016 11/20/2016 0.10 PROD2 DRILL DLOG P Tie-in to K1 for+3'correction. 6,460.0 6,480.0 04:09 04:15 PUW=40k.,Close EDC 11/20/2016 11/20/2016 1.20 PROD2 DRILL TRIP P Cont RIH BHA#26. 6,480.0 8,669.0 04:15 05:27 11/20/2016 11/20/2016 3.30 PROD2 DRILL DRLG P 8669', Drill, 1.72 BPM @ 5566 PSI 8,669.0 8,821.0 05:27 08:45 FS, BHP=4509,CTWt=8.5K @ 1.3 DHWOB,ROP 40-50 FPH 11/20/2016 11/20/2016 0.10 PROD2 DRILL WPRT P 8821', BHA Wiper,PUW=58K 8,821.0 8,821.0 08:45 08:51 11/20/2016 11/20/2016 1.50 PROD2 DRILL DRLG P 8821',Drill, 1.7 BPM @ 5504 PSi FS, 8,821.0 8,880.0 08:51 10:21 BHP=4595 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P 8880',200'wiper trip, PUW=61K 8,880.0 8,880.0 10:21 10:33 11/20/2016 11/20/2016 1.90 PROD2 DRILL DRLG P 8880',Drill1.43 BPM(High Vibration) 8,880.0 8,950.0 10:33 12:27 @ 4800 PSI FS, BHP=4554,Multiple pick ups and short BHA wipers, stacking 11/20/2016 11/20/2016 1.20 PROD2 DRILL WPRT P 8950', 1000'wiper,PUW=59K 8,950.0 8,950.0 12:27 13:39 11/20/2016 11/20/2016 1.50 PROD2 DRILL DRLG P 8950',Drill, 1.49 BPM @ 4925 PSI 8,950.0 9,020.0 13:39 15:09 FS,BHP=4575 11/20/2016 11/20/2016 0.60 PROD2 DRILL WPRT P 9020',Stacking,pull 500'wiper, 9,020.0 9,020.0 15:09 15:45 PUW=61 K 11/20/2016 11/20/2016 0.90 PROD2 DRILL DRLG P 9020',Drill, 1.5 BPM @ 4971 PSI FS, 9,020.0 9,080.0 15:45 16:39 BHP=4550,Hard to get started drilling. Couple of short pick ups to get going, RIW=-3.2K, .8K DHWOB Page 26/29 Report Printed: 11/28/2016 • • Oi; Operations Summary (with Timelog Depths) 2, 2K-11 Cillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P PU for surveys, PUW=53k. 9,080.0 9,080.0 16:39 16:51 11/20/2016 11/20/2016 0.80 PROD2 DRILL DRLG P BOBD, 1.49 BPM @ 4945 psi FS, 9,080.0 9,110.0 16:51 17:39 WOB 0.6k,CTSW-5k to-10k,ROP 100 to 60 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P BHA wiper trip,PUW=58k. 9,110.0 9,110.0 17:39 17:51 -11/20/2016 11/20/2016 0.70 PROD2 DRILL DRLG P BOBD, 1.50 BPM @ 5300 psi FS, 9,110.0 9,146.0 17:51 18:33 WOB 0.6k,ROP 66. 11/20/2016 11/20/2016 0.80 PROD2 DRILL WPRT P 1000'wiper trip,PUW=51k. 9,146.0 9,146.0 18:33 19:21 11/20/2016 11/21/2016 4.65 PROD2 DRILL DRLG P BOBD, 1.61 -1.45 BPM varying speed 9,146.0 9,405.0 19:21 00:00 due to vibration.Small wiper @ 9,263'. CTSW-5k to-10k while WOB typically stayed below 1.5k.ROP varied 8-115 FPH. 11/21/2016 11/21/2016 1.35 PROD2 DRILL DRLG P Cont drill ahead. 1.45 BPM @ 4708 9,405.0 9,446.0 00:00 01:21 psi FS,WOB 1k,CTSW-8k,ROP 30 11/21/2016 11/21/2016 1.10 PROD2 DRILL WPRT P Long wiper trip up,PUW=58k. 9,446.0 6,525.0 01:21 02:27 11/21/2016 11/21/2016 0.20 PROD2 DRILL DLOG P Tie in @ RA for+10.5'correction. 6,525.0 6,565.0 02:27 02:39 11/21/2016 11/21/2016 1.10 PROD2 DRILL WPRT P Wiper trip in. 6,565.0 9,453.0 02:39 03:45 11/21/2016 11/21/2016 2.45 PROD2 DRILL DRLG P BOBD, 1.52 BPM @ 4916 psi FS, 9,453.0 9,550.0 03:45 06:12 WOB 1.3k,CTSW-5k,ROP 40, 11/21/2016 11/21/2016 3.10 PROD2 DRILL WPRT P At plan TD 9550,Pump 10 X 10 9,550.0 72.0 06:12 09:18 sweeps and chase to surface,Open EDC @ 6494.Get static BHP=13.15 11/21/2016 11/21/2016 1.20 PROD2 DRILL WPRT P Tag up,reset counter,RBIH 72.0 6,460.0 09:18 10:30 11/21/2016 11/21/2016 0.10 PROD2 DRILL DLOG P Log K1 for-1.5',Close EDC, 6,460.0 6,481.0 10:30 10:36 PUW=43K 11/21/2016 11/21/2016 1.30 PROD2 DRILL WPRT P Continue in well to confirm TD 6,481.0 9,550.0 10:36 11:54 11/21/2016 11/21/2016 4.80 PROD2 DRILL TRIP P Tag TD @ 9550',Trip out pumping 9,550.0 72.0 11:54 16:42 13.1 PPG beaded liner running pill followed by 13.5 micronized barite in K formate, Paint EOP flags 6350 and 3300'. 11/21/2016 11/21/2016 0.60 PROD2 DRILL OWFF P At surface,Perform 30 Min No flow 72.0 72.0 16:42 17:18 check 11/21/2016 11/21/2016 1.70 PROD2 DRILL PULD P PJSM, Lay down drilling BHA#26- 72.0 0.0 17:18 19:00 crew change out-cont laying down BHA#26 11/21/2016 11/21/2016 0.50 COMPZ2 CASING PUTB P Rig up floor to run liner 0.0 0.0 19:00 19:30 11/21/2016 11/21/2016 1.25 COMPZ2 CASING SVRG P Service top drive, De-ice main drilling 0.0 0.0 19:30 20:45 lines.De-ice traveling block shieves 11/21/2016 11/22/2016 3.25 COMPZ2 CASING PUTB P PJSM, P/U A lateral completion with 0.0 1,140.0 20:45 00:00 non-ported bull nose, 102 Jts slotted liner and shorty deployment sleeve.38 joints in hole at midnight. 11/22/2016 11/22/2016 2.25 COMPZ2 CASING PUTB P Cont PU remaining slotted liner joints. 1,140.0 3,180.0 00:00 02:15 11/22/2016 11/22/2016 0.25 COMPZ2 CASING PUTB P RD tongs,clean up rig floor. 3,180.0 3,180.0 02:15 02:30 Page 27/29 Report Printed: 11/28/2016 I • Operations Summary (with Timelog Depths) _ fix 2K-11 +ConocoPhilliips - A%�k9 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/22/2016 11/22/2016 1.40 COMPZ2 CASING PUTB P PJSM,PU MWD,FVS,shorty 3,180.0 3,180.0 02:30 03:54 deployment sleeve.Strip injector over, CO UQC checks,MU QC.Test MWD. Stab on WH.Tag,set depth.Check inj counter. 11/22/2016 11/22/2016 2.20 COMPZ2 CASING RUNL P RIH BHA#27(A lateral slotted liner). 3,180.0 6,480.0 03:54 06:06 Pumping min rate,tried 50 FPM,walk back down to 20 FPM to minimize losses.Correct to first flag-5.3' correction.PUW=60k. 11/22/2016 11/22/2016 3.90 COMPZ2 CASING RUNL P Cont RIH.Stacking @ 7,336'.Working 6,480.0 8,106.0 06:06 10:00 in hole,letting coil relax,stacking, working forward.Discuss path forward with town.Not an option to leave liner high in tubing.Decide to run liner in two separate runs. 11/22/2016 11/22/2016 2.25 COMPZ2 CASING PULL T POOH,paint flag @ 6,300'.Cont. 8,106.0 3,333.0 10:00 12:15 POOH. 11/22/2016 11/22/2016 0.75 COMPZ2 CASING OWFF T Getting too much return rate while 3,333.0 3,333.0 12:15 13:00 POOH,stop,bullhead 3 bbls downhole. Flow check well.Fill well after flow check.—1.5 BPH losses. 11/22/2016 11/22/2016 0.50 COMPZ2 CASING PULL T Cont POOH,tag-up,space out. Fill 3,333.0 3,167.0 13:00 13:30 hole,flow check while determining path forward.42.7 bbls of KWF left in active system. 11/22/2016 11/22/2016 2.50 COMPZ2 CASING DISP T PJSM,strip off BHA.Line up coil 3,167.0 3,167.0 13:30 16:00 nozzle on sump,displace KWF from coil into active pit for use while pulling &LD liner joints.29 bbls KWF added to active system for—72 bbls on surface.Blow down pump lines,clean rig floor and prepare pipe shed for LD liner. 11/22/2016 11/22/2016 5.00 COMPZ2 CASING PULL T PJSM, LD BHA followed by 52 jnts 3,167.0 1,560.0 16:00 21:00 slotted liner. 11/22/2016 11/22/2016 1.00 COMPZ2 CASING PULD T PJSM, MU BHA#28 with agitator 1,560.0 1,607.0 21:00 22:00 abovet he shorty deployment sleeve, Shut in upper/lower 2 3/8" deplotment rams,Shut in dbl ball valves. 11/22/2016 11/22/2016 0.90 COMPZ2 CASING DISP T Turn coil over to kill weight fluid. 1,607.0 1,607.0 22:00 22:54 11/22/2016 11/22/2016 0.40 COMPZ2 CASING PULD T Make up coil to BHA#28,A lateral 1,560.0 1,607.0 22:54 23:18 slotted liner"bottom",open dbl ballvalves, Open upper/lower 2 3/8" rams,bump up,reset. 11/22/2016 11/23/2016 0.70 COMPZ2 CASING RUNL T RIH W BHA#28,A lat,slotted liner 1,607.0 2,421.0 23:18 00:00 bottom section. 11/23/2016 11/23/2016 4.00 COMPZ2 CASING RUNL T RIH W BHA#28,A lat,slotted liner 2,421.0 6,450.0 00:00 04:00 bottom section,tie into original EOP flag for-8.5'correction. Park at 6450', Zero G/L& monitor returns at min rate for 20 min.no loss Page 28/29 Report Printed: 11/28/2016 • S Operations Summary (with Timelog Depths) 2K-11 Con ocoPhitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/23/2016 11/23/2016 1.40 COMPZ2 CASING RUNL T Wt Chk 40k lbs. RIH Wt 13.6 k lbs, 6,450.0 8,886.0 04:00 05:24 set down 8087'PU Wt 45k lbs . RBIH SD 8075'. pumps on line @ 1.2 bpb, 5500 psi CT pressure,no weight slack off. Down on pumps,PUH, RIH while pumping 1.2 bpm,SD hard at 8086'. Consul w/ town engineer. 11/23/2016 11/23/2016 0.70 COMPZ2 CASING RUNL T PUH to 7966',bring pumps to 1.4 6,450.0 7,992.0 05:24 06:06 bpm,attempt to RBIH,stacked at 7980,attempt twice,no go PU Wts 50k lbs. RBIH to 7992'dry,WOB 4.62 k lbs. Bring pumps to 1.3 bpm, pick up,34 k lbs Set A lat slotted liner,top at 6435'bottom 7992'. 11/23/2016 11/23/2016 3.20 COMPZ2 CASING DISP P Get pits set-up to displace to SW, 7,992.0 6,422.0 06:06 09:18 open EDC,pump hi-vis spacer followed with SW displacing KWF @ 0.3 BPM. 11/23/2016 11/23/2016 1.20 COMPZ2 CASING DISP P POOH BHA#28,pumping 0.9 BPM 6,422.0 2,500.0 09:18 10:30 chasing SW up hole. 11/23/2016 11/23/2016 1.30 COMPZ2 CASING DISP P PJSM,displace upper 2,500'of well to 2,500.0 2,500.0 10:30 11:48 diesel for freeze protect.Prep&test lines.CO customer line plug valve. Pump 30 bbls diesel.Blow down lines, disconnect Little Red Services truck. 11/23/2016 11/23/2016 0.60 COMPZ2 CASING DISP P POOH,laying in diesel.Tag-up,space 2,500.0 42.0 11:48 12:24 out+1.2'CTES counter. 11/23/2016 11/23/2016 2.40 COMPZ2 CASING PULD P PJSM,PUD BHA#28(liner running 42.0 0.0 12:24 14:48 tools+agitator). 11/23/2016 11/23/2016 1.00 DEMOB WHDBOP CIRC P MU nozzle to coil,stab on WH.Flush 0.0 0.0 14:48 15:48 BOP stack 11/23/2016 11/23/2016 2.80 DEMOB WHDBOP MPSP P PJSM,RU lubricator,set BPV, 0.0 0.0 15:48 18:36 negative test. 11/23/2016 11/24/2016 5.40 DEMOB WHDBOP MPSP P Flush&blow down,RD,Blow down 0.0 0.0 18:36 00:00 hard line,empty/clean pits,ND BOPE. Rig Release 12:00 midnight. Page 29/29 Report Printed: 11/28/2016 • ! Cement Detail Report &WeUs 2K-11 ConocoPhillips String: Cement Plug Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 10/7/2016 08:52 10/7/2016 08:52 2K-11 Comment LAY IN 35 BBLS OF 16.5#CEMENT(20 BBLS WITH CEMENT FIBERS) Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Display Cement Fill 6,407.0 6,630.0 Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment LAY IN 35 BBLS OF 16.5#CEMENT(20 BBLS WITH CEMENT FIBERS) Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/14/2016 • 2K-11 Final Schematic Modified by MSC 11/28/16 3-112'9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 3-112 Camco TROP SSSV @ 1815 RKB(locked out???) shoe @ 115' MD 11•INE.-- 3-1/2"Merla TMPD gas lift mandrels @ 2345,3932', 4815,52101,5573RKB 10-314'by 9-5/8" 36#L-80 shoe @ 3-112'Camco NINIG GLV @5941'RKB sii, 2997 MD 3-112'Camco N1MG OV GLV @ 6312'RKB Baker 3-1/T PBR @ 6355 RKB(3"ID) Baker FIB packer @ 6369'RKB(2.892'ID)(6360'PDC) 3-112'Otis XN nipple @ 640T RKB(2.751 min ID) to 2 30"ID for CTD(6397'PDC) 3-112"tithing tail @ 6442 RKB(6431"PDC) I 1 NMI k \ h \ I '1 KOP @ 'MD '11 # # 4 2K-11A(North) IA.-sand perfs h TD 0:550'MD % Liner Bonorn fi 7g5T MD 6574 -6600'MD Liner Too 8435'MD ,-,<RRFRK.40%teqj*:Z,N;V., , 2K-11 APB1(North) TD 0058'MD 2K-1 IAL1(South) Liner Bottom g 2D72:MD TD @ 2900'MD Liner Top og?DOT MD Liner lionorn @ 8884'MD Anchored Binet i§8250'MD Liner Billet g 884G'MD 7"26#J-55 shoe @ 6878'MD a KUP D 2K-11 ConocoPhiDips Well Attribute Max Angle TD Alaska,Ins. ,..,, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(([KB) Conoceffiiuips"€ 501032011400 KUPARUK RIVER UNIT PROD 28.36 4,300.00 6,885.0 •- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2K-11,12/19/201611:21:55 AM 10 11/30/2015 Last WO: 40.09 9/21/1989 Vera*sdwmabc(actua4l Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag-RKB 6,622.0 9/7/2011 Rev Reason:TAG,GLV C/O,PERFORATED, pproven 10/10/2016 1 r'1 PUMPED CEMENT,TAG CEMENT HANGER;31.1 L'..4 = 'Perforations&Slots VI Shot ili Dens ........„.......,..........................., I I uua, Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn .✓titi CONDUCTOR,36.Q1750 6,409.0 6,411.0 6,083.7 6,085.7 A-4,2K-11 10/3/2016 2.0 APERF 6,574.0 6,600.0 6,247.2 6,272.9 A-4,2K-11 10/24/1989 2.0 IPERF 4.5"HSD Csg Guns;180 deg ph sAPETVVw;1.815.0 _ Cement Squeezes I Top(TVD) Btm(TVD) IITop(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 6,407.0 6,630.0 6,081.7 6,302.7 Cement Plug 10/7/2016 LAY IN 35 BBLS OF 16.58 CEMENT(20 BBLS WITH CEMENT FIBERS) GAS LIFT,2,344.7 Notes:General&Safety End Date Annotation 9/3/2003 NOTE:WAIVERED WELL:IA x OA COMMUNICATION 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;35.0-2,997.4 GAS LIFT;3,932.4 I GAS LIFT;4,814.9 r_. GAS LIFT;5,209.7 i ,' GAS LIFT,5,5720 GAS LIFT;5,940.8II 113 IF GAS LIFT;6,312.0 PBR;6,355.1 PACKER,6,368.8 ' o- I NIPPLE,6,407.4 APERF,6403.08,411.0 '.' Z SOS;6,441.0 :.a WHIPSTOCK-MONOBORE; 6,511.0 X70 (PERF;6,574.0-6,600.0 M Display Cement Fill;6,407.0 l.:. Po(B I j PRODUCTION;31.28.877.6 Liner,A Lateral,6,434.7-7,992.0 Leer,AL1 Lateral;6,840.3- I 8,664.0 a KUP SpD 2K-11A Con©c 'hiIIips 4 Well Attributes Max Angle D TD Alaska,Inc, Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ORB) Act Btm(ftKB) peps 501032011401 KUPARUK RIVER UNIT PROD 103.30 6,839.99 9,500.0 +«. °° . , Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) ..Rig Release Date 2K-11A,12/19=16 11;22;45 AM SSSV:TRDP 10 11/30/2015 Last WO: 40.09 9/21/1989 Vertical nohemaac(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason'SIDETRACK,ADD LATERALS, pproven 12/14/2016 HANGER,311 (1 - GLV C/O,SET/PULL CATCHER,CORRECTED �111011 Casing Strings Li I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)...Wt/Lenp...Grade Top Thread L CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED taniam Ltaat itautt°°°°"uururp°r• 1 • i I rata-Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len p...Grade Top Thread SURFACE 9 5/8 8.921 35.0 2,997.4 2,949.0 36.00 J-55 BTC -^-ti CONDUCTOR;36.0-115.0- ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.2 6,877.6 6,282.7 26.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... WtlLen(I...Grade 'Top Thread Liner,A Lateral 2 3/8 1.992 6,434 7 7,992.0. 6,258.7 4.60 L-80 ST-L SAFETY VLV;1,815.0 -( itr.a 9:. Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,991.6 6,258.7 93.16 Non-ported Bullnose-non ported 1.000 GAS LIFT;2,344.7 - Bullnose Tubing Strings j rill 1 Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(k..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING 31/2 2.992 31.1 6,441.8 6,116.2 9.30 J-55 EUE8rdABMOD • Completion Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl c) Item Des Com (in) SURFACE;35.0-2,997.4 31.1 ' 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,815.0 1,815.0 0.67 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE 2.812 GAS LIFT,3,932 4 it 6,355.1 6,030.2 7.80 PBR BAKER PBR 3.000 • 1.1 Ilati 6,368.8 6,043.8 7.73 PACKER BAKER HB PACKER 2.892 GAS LIFT,4,814.911it� .- 6,407.4 6,082.1 7.59 NIPPLE OTIS XN NIPPLE W/2.81"POLISH BORE 2.800 6,441.0 6,115 4 7.65 SOS BROWN SHEAR OUT SUB 3.015 GAS LIFT;5,209.7 ir Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) lig Top(TVD) Top Incl Top(ftKB) (ftKB) ('I Des Corn Run Date ID(in) GAS LIFT;5,572.6 6,511.0 6,184.8 7.80 WHIPSTOCK 3-1/2"Whipstock,Baker Monobore XL,10°LOHS 10/30/2016 0.000 ilMONOBORE 11. Mandrel Inserts GAS LIFT;5,940.8 St ati N Top(340) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1� 2,344.7 2,341.2 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,293.0 11/28/2016 11 2 3,932.4 3,777.4 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,317.0 11/28/2016 GAS LIFT;6,312.0al 3 4,814.9 4,558.1 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 11/28/2016 4 4 5,209.7 4,915.8°MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/30/2016 5 5,572.6 5,261.4 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/20/2003 6 5,940.8 5,620.3 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000° 0.0 9/29/2016 PBR,6,355.1 7 6,312.0 5,987.6 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/2/2016 PACKER;6,368.6 Notes:General&Safety ■a ..1 End Date Annotation NOTE: NIPPLE;6,407.4 ... -n APERF',6,409.0-6,411.0--• L. 50S;6,441.0 . WHIPSTOCK-MONOBORE; a 8,511.0 A_ Ityt': IPERF;6,574.0-6.6000- :. Via, Display Cement Fill;6,407 0 'i''':i.,:',',':-11' 1IKB I kJ' PRODUCTION,31.2-6,877.6 Liner,A Lateral,6,430.7-7,992.0 il L Liner,AL1 Lateral,6,840.3- I 8,864.0 ofi KUP 11110 D 2K-11AL1 ConocoPhillips v Well Attributeir Max Angl D TD Alaska.I;k. Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(15KB) �ps { 501032011460 KUPARUK RIVER UNIT PROD 103.32 6,841.47 8,900.01 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1 2K-11AL1,12/19/201611:23:27 AM SSSV:TRDP 10 11/30/2015 Last WO: I 40.09 9/21/1989 VergWsrhema5c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason SIDETRACK pproven 12/14/2016 HANGER;31.1iti II Casing Strings Caning Description id OD(in) ID(in) Top(DEB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Liner,AL1 Lateral 2 3/8 1.992 6,840.3 8,864.0 6,293.2 4.60 L-80 ST-L .........°„AIWA.UUM....,....°....,. .. .Liner Details 1� aa -"-",CONDUCTOR;38.0. Nominal ID115.0' I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,852.0 6,282.9 102.91 Deployment Shorty Deployment Sleeve 1.920 Sleeve SAFETY VLV;1,815.0 $'? 8,863.6 6,293.2 94.08 Non-ported Non-Ported Bullnose 1.000 Bullnose lit Notes:General&Safety End Date Annotation GAS LIFT;1344.7 - NOTE. • • SURFACE;35.0-2,997.4 GAS LIFT;3,932.41 GAS LIFT;4.814.9 �. GAS LIFT;5,209.7 GAS LIFT;5,572.8 GAS LIFT;5,940.8 GAS LIFT;8,312.0 (.:.. PBM;6,355.1 PACKER;6,368.8 a• ':n r•'IS NIPPLE;8,407.4 APERF;6,409.08,411.0- 14s �,n\ is SOS;6,441.0 ''-T 67.3: A WHIPSTOCK-MONOBORE; 6,511.0 fdJ1 IPERF:6,574 0-6,600.0 P Display Cement Fill:6,407.0 ftKB • • PRODUCTION,31.2-6,877.6 / . ' liner,A Lateral;6,434.7-7,992.0 Liner,AL1 Lateral;6,840.3- L 8,864.0 WELL LOG TRANSMITTAL#903626244 To: Alaska Oil and Gas Conservation Comm. December 7, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DATA LOGGED V 23/zo17 iv1. K.BENDER JAN 09 2017 RE: Multi Finger Caliper : 2K-11 AQ�VV Run Date: 10/26/2016 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-11 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20114-00 Multi Finger Caliper (Field Log) 1 color log 50-103-20114-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SCAHIE® AP2 201 Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: S 4 ne M • • 0T M O a a o Q1— WT - W 0 5° mooO a E . 3 r O Q Y 04 +-' t0 > h c0 ✓ < O . Y r(13r 0 . v O v E v c r r r r r N r r r r r U N N > OP P-. Q. C C � v 0 C )- co 0 a a3 Q 0 -• 1 o U E a Cr 00 O Q O m c-. 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I- a •a d „9• U = _ O (� oo > Z �h \ a 0" OS y 43 '4 _- o CO Z O a N z a te i03 0 u d J J J J J J J J J J I V! 1° ") . 23333333333 w Ity/12......"119 W WZZZZWWlww 'i' > > a' M a' a' > >,> > 2 Y Y EP62 -• - Y Y Y Y Y Y Y Yv vii 11.1 Q Q > > > > Q Q Q Q Er_ a w a a a a a -, :� > > QQQQ > > > > z a N 0 Y Y ? j ? j Y Y Y Y o O ccX in - _ima ,...4w N M N M 1. t0 co O co - m /�, O O 0 n C, co 0 0 r N- O E V 0 0 0 0 0 0 0 O O O 0 0 O d _ O 0 0 0 0 0 0 0 0 0 0 u U U > > > as Li jC_) w �`cc c, Far � 33333 •; rn rn rn rn rn 0 • 3 3 3 - Li wOr ii, O D U U U 0 0 0 0 0 o. Y Q 00 0 0 0 0 0 0 0 0 J•, O O O O O O O O O O A : Q V N u) N v C) C) N N N N F, • v, _l CO .7 O) r O 0 N N h CD ++ _ f1 If l N r M r .7 0 r� N Co N 0 M 0 M 0 r N 0 r - N NNNNNNNNNN y) L f. - O) (") C) r) C) r") O) C) C) O) C 0 a 001 NONONONNNN fC 0 r 0 r 0 0 0 O O L UO UU pp 0 0 0 0 0 0 0 0 0 0 Y +' C 0 ClaY 4 C u) In v) � O in In In )n K) 'y N 0. C �i CQ E v ao ' a C. Y ^ E M• U d Q a 'a Y cc 1 E h' m r1 v v o r T N v N n 4' E ani v -,- E Z r N r r N r' N O ?-+ N Y m C = de ON comMMN � M � QC- N ZNOO To , ' ,6 n• CO c y E E 0 42 CID aoa - 1= a` a F°- 1°- ' OF T� • evi 11/ 7 � THE STATE Alaska Oil and Gas o f®® eesKA. Conservati®n Commission 2_ 333 West Seventh Avenue " '� '_ I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .., Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke CTD CoordinatorJAN 1 3 20g ' ConocoPhillips Alaska, Inc. SCS�k�� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-11 Permit to Drill Number: 189-093 Sundry Number: 316-379 Dear Mr. Burke: 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, Cathy . Foerster Chair DATED this fI' day of August, 2016. RBDMS AUG 1 5 2016 • STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 25 2016 APPLICATION FOR SUNDRY APPROVALS ors else //4 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations Q 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: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q 189-093 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-103-20114-00 7. If perforating: 441 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Nfr KRU 2K-11 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation(Lease Number): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool ADL 25588 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 6870'MD ` 6541'TVD „ 6776'MD - 6446'ND ' 4435 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 155' 16" 115'MD 115'ND 1640 psi 630 psi Surface 2997' 9-5/8" 2997'MD 2949'ND 3520 psi 2020 psi Intermediate Production 6877' 7" 6877'MD 6540'ND 4980 psi 4330 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6547'-6600'MD ) 6247'-6273'ND 3-1/2" J-55 6441'MD Packers and SSSV Type: CAMCO TRDP-1A-SSA Safety Valve Packers and SSSV MD(ft)and ND(ft): ,1815'MD&1815'ND Baker HB Packer . 6369'MD&6044'ND 12.Attachments: Proposal Summary Q Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: _Al 1-Oct-16 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title CTD Coordinator A i 7-Z$-I(c, Signature Phone 265-6097 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3` .A. - 379 Plug Integrity ❑ BOP Test ILJ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 7OU P S-3 gpp hprr55v� G 9rc a / i/7hula✓ /2rrvovt t<E' fie-5t pr-e-55 f 25vo p5,g A/fc. ha/-rip /v ptetA rvi-- apprbv<of pf/ -2"-F1-C ZS, llZC� Post Initial Injection MIT Req'd? Yes Di No C_____- Spacing Exception Required? Yes ❑ No ©' Subsequent Form Required: /£7 — 4 O 7 (lle APPROVED BY Approved by: P934.4410......_, COMMISSIONER THE COMMISSION Date:g-4/4 V77_ 0/111 Co, Submit Form and Form 10-403 Revised 11/2015 r a isid for 12 months' from the date of approval. Attachments in Duplicate -"j ns.5-1/c OII1WAL 1 .7 /� RBDMS /„.c_ Or; 1 5 2010 • • lory ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 252016 July 25, 2016 AOGCC Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to abandon the KRU 2K-11 by cementing up the perforation in order to set up to for CTD operations to drill a dual-lateral out of the KRU 2K-11 using the coiled tubing drilling rig, Nabors CDR2-AC. A sundry application is attached to plug the KRU 2K-11 (189-093) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in 2G-14. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 2G-14 (184-130) — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6097. Sincerely, son Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 2K-11 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 2K-11 is a Kuparuk A-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A4 sand to the north and south of the 2K-11. The laterals will improve production in the 2K-11. Prior to CTD operations the nipple at 6407' RKB will be milled out and the existing A-sand perforations will be squeezed with cement, the 3-1/2" tubing tail will be punched and cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6550' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 6510' MD. All the laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner topoca e i e 3- 1/ • '' - • I.-ell P"/(,'' C Jit o i 'c.'6 e477 ff/et',.GS Pl p fe5uv<f Using /1eGefr'y 7Ka,/(6 sing t e maximum formation •ressure in the area of 5043 psi in 2K-10, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 44352§j. ✓ CTD Drill and Complete 2K-11 Laterals: October 2016 Pre-CTD Work 1. RU Slickline: Dummy off gas lift mandrels; obtain a SBHP 2. RU E-line: Punch tubing at 6409' MD. 3. RU Pumping: Swap hole over to diesel and perform injectivity test 4. RU Service Coil: Mill out nipple set at 6407' MD, and lay in cement plug and squeeze off the A-sand perforations. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 'r,t 5 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. vh c 2. 2K-11A Sidetrack(A4 sand - North) a. Drill 2.80" high-side pilot hole through cement to 6550' MD b. Caliper pilot hole c. Set top of whip-stock at 6510' MD d. Mill 2.80"window at 6510' MD. -- L — — e. Drill 3" bi-center lateral to TD of 9300' MD. f. Run 23/" slotted liner with an aluminum billet from TD up to 6825' MD. Cw 3. 2K-11AL1 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 6825' MD. p7P b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 2%" slotted liner with a deployment sleeve from TD up to 6435' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Page 1 of 2 7/25/2016 • • • Post-Riq Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 7/25/2016 • • , Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Thursday,August 11, 2016 6:24 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-11(PTD 189-093,Sundry 316-379) Plug for Redrill Follow Up Flag: Follow up Flag Status: Flagged 4700 psi,sorry I forgot to include that in the write up Jason 11 ConocoPhil lips Jason Burke Coiled g'ubing Drifting Coordinator (0) 907-265-6097 (.M) 907-231-4568 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 10, 2016 1:51 PM To: Burke,Jason<Jason.Burke@conocophillips.com> Subject: [EXTERNAL]KRU 2K-11(PTD 189-093,Sundry 316-379) Plug for Redrill Jason, What is the BOP test pressure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • 2K-11 Proposed Pre-CTD Schematic Modified by JAB 7/25/16 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 3-1/2"Camco TRDP SSSV @ 1815'RKB shoe @ 115' 3-1/2"Merla TMPD gas lift mandrels @ 2345',3932', 4815',5210',5573'RKB 10-3/4"by 9-5/8" 36#L-80 shoe @ 3-1/2"Camco MMG GLV @ 5941'RKB 2997,MD 3-1/2"Camco MMG OV GLV @ 6312'RKB MEI Baker 3-1/2"PBR @ 6355'RKB(3"ID) Baker HB packer @ 6369'RKB(2.892"ID) 3-1/2"Otis XN nipple @ 6407'RKB(2.75"min ID) 3-1/2"tubing tail @ 6442'RKB •■ A-sand perfs 6574'-6600'MD 7"26#J-55 shoe @ 6878'MD KU P 2K-11 • ConocoPhillips n4Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) canoaolawps 501032011400 KUPARUK RIVER UNIT PROD 2836 4,300.00 6,885.0 ""` Comment 625(ppm) Date Annotation End Date KB-Grtl(ft) Rig Release Date SSSV:TRDP 15 10/28/2011 Last W0: 40.09 9/21/1989 Well Conk; 2K-11 /2042012102254 AM Schema. Actual Annotation Depth(ftKB) End Date (Annotation Last Mod...End Date -- --- Last Tag:RKB 6,622.0 9/7/2011 (Rev Reason:GLV C/O mem 7/20/2012 Casing Strings HANGER,31 ,tz i Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED C Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String TThrd SURFACE 95/8 8.921 35.0 2,997.4 2,949.0 36.00 J-55 ETC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String.. String Top Thrd PRODUCTION 7 6.276 31.2 6,877.6 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd CONDUCTOR. 36-115 TUBING 3 1/2 2.992 31.1 6,441.8 6,116.2 9.30 J-55 EUE8rdABMOD Completion Details01. Top Depth (TVD) Top Incl Nomi... rep(ftKB) (ftKB) 1°) item Description Comment ID(In) SAFETY VLV, or 31.1 31.1 0.38 HANGER FMC GEN IV TUBING HANGER 3.500 1,815 1,815.0 1,815.0 0.14 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 6,355.1 6,030.2 7.81 PBR BAKER PBR 3.000 6,368.8 6,043.8 7.74 PACKER BAKER HB PACKER 2.892 6,407.4 6,082.0 7.51 NIPPLE OTIS XN NIPPLE 2.750 GAS LIFT. 1111 6,441.0 6,115.4 7.62 SOS BROWN SHEAR OUT SUB 3.015 2,345 { Rik Perforations&Slots Shot Top(TVD) Btm(ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment 6,574 6,600 6,247.2 6,272.9 A-4,2K-11 10/24/1989 2.0 IPERF 4.5"HSD Csg Guns;180 deg ph z Notes:General&Safety End Date Annotation SURFACE, A °,' •4. 9/3/2003 NOTE:WAIVERED WELL:IA x OA COMMUNICATION a''2'� 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS UFT, 3,932 ,. 4 F GAS LIFT. GAS LIFT, 5,210 GAS LIFT, 5,573 GAS LIFT. .. 5,941 GAS LIFT _... 6.312 P8R,6,355 PACKER,8369 NIPPLE,6,407 -- - s-SOS,6,441 _-1 Mandrel Details Top Depth Top I Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) I°) Make Model (in) Sery Type Type (ie) (psi) Run Date Com... Mt -se I 1 2,344.7 2,341.2 11.58 MERLA TMPD 1 GAS LIFT GLV BK 0.125 1,349.0 7/22/2003 IPERF. 2 3,932.4 3,777.4 28.02 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,362.0 7222003 6.574-6.600 3 4,814.9' 4,559.6 29.64 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 6/6/1991 1E 4 5,209.7 4,916.5 21.80 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,376.0 7/21/2003 5 5,572.6 5,261.4 15.32 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7202003 6 5,940.8 5,620.3 8.83 CAMCO MMG-2 1 12 GAS LIFT GLV RK 0.188 1,278.0 7202003 7 6,312.0 5,987.6 8.01 CAMCO MMG-2 1 12 GAS LIFT OV RK 0.188 0.0 7/19/2012 PRODUCTION. ' 3t.6.878"\ I , TD,6.885 • • • Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Thursday,August 11,2016 6:24 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-11(PTD 189-093, Sundry 316-379) Plug for Redrill Follow Up Flag: Follow up Flag Status: Flagged 4700 psi,sorry I forgot to include that in the write up Jason ConocoPhillips Jason Burke Colted mud ing Drilling Coordinator (0) 907-265-6097 (SM) 907-231-4568 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 10, 2016 1:51 PM To: Burke,Jason<Jason.Burke@conocophillips.com> Subject: [EXTERNAL]KRU 2K-11(PTD 189-093,Sundry 316-379)Plug for Redrill Jason, What is the BOP test pressure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo©alaska.gov 1 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or �' "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geplogist work)the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer v The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. Pl 0 • • cuc tr 1 cup . o.o U -0 I r. f Y > W v 3 C"' 0 Coo C 0 V) il 0(-9-----`‘'LuZ O C O ra a H. a o o W 7 a 0 ° c 77 l' a a J (O (O CD O O O O rD O m 0 (7 T- ,- t0 . . . . . rO _C U Y Y J '4 Q 0 >. C 7 C C C C C 7 ''� a) O y �- N 0 t0 > > 7 7 > > > > Y C c@ �) 7 7 7 7 7 CD Z Q N N .4 O an- CO O) N N 7 c -O > C Ln 2 Q O O -O E O >. 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Q d d a a. y a > > > a > > > > Y• Y Y Y Y Y Y Y Y C v-i co O W K OMOCI)i O C O X VdONVoo0o0oo0o 0 O O O O O 00000 0 0 0 0 CD =Wc..4 (V U c o U U E�ni 4 5 } C49 › Y } (7 0U' a) Q� _J ® W U o D o 0 0 0 O 0 > N 7 la -' x a U S - . 0 . . . . . o 0 o 0 0 0 O o o E c tD 0 0 0 0 0 0 0 o O o X O 6 6 4 6 (O N M F' Y MMM a s M N CO CO C CD N N N r O M O O N N = Q N NNNNNNNNN T C L 7.7 O) O) 6) M O M a1 6) • O_ O N N N 0 N 0 N N N 0 O Q1 O O O e- O e- O O O co O L O O O O O O O O O 00 C N N u7 N N N in . 'O OU O G. rZ ai E u C O o o+ a oa u U W ix , ° O aJ rn ppM Z ON O M O O �a+ E w O LLI QpJm J C VI MO ammo d N N N N z d Ew 444= a ee2 cal � � i': as CEEcr Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2967 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 09/25/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 2X-14 '}~/'~' l~--~. PROD PROFILE/DEFT 09101/03 2A-24 lq: ~ - ) rt z_[ PROD PROFILE 09/02/03 1 3F-15 ~.¢_~-i.~CL"~ INJECTION PROFILE 09/05/03 1 3S-24 ~ -'-(~"~ INJECTION PROFILE 0S/01/03 3S-09 ~ ~,~~ INJECTION PROFILE 08/02/03 1 3H-07 ] ~?-~ INJECTION PROFILE 08106/03 2K-11 ~q ~~ SBHP SURVEY 08/07/03 ~D-~03 ('~ ~,~ INJECTION PROFILE 08/20103 ~C-174 .~ ~~ INJECTION PROFILE 08/23/03 ~a-~0~ ~-~ ~3432 US~T 0~/~4/03 .... ,,.-., ~, ;. ~ .~.m. ., ~.~ .r--,~./'% DATE: Please sign and return one copy of this transmi*al to Beth at the above address or fax to (907) 561-8317. Thank 1. OPerations Performed: P.u.!! tubing 2. ~ame of Operator REPORT OF SUNDRY WELL OPERATIONS Operation 'Sl';Utd°wn'"_"__ Stimulate X Pluggi'n ' ,, Perforate_ ' ........ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface Alter casing Repair well 5. Type of Well: Development Exploratory Stratigraphic 99510 Service Other 6.' D~tum elevatiOn' (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit ~. Well number" feet _ 46' FSL, 94' FEL, Sec. 2, T10N, R8E, At top of productive interval 1246' FNL, 979' FEL, Sec. 11, T10N, At effective depth 1246' FNL, 979' FEL, Sec. 11, T10N, At total depth 1286' .FNL, 993' FEL, Sec. 11, T10N, '~'2. Present well condition summary Total Depth: measured 6 true vertical 6 UM R8E, UM R8E, UM R.8E, ua 870' 541' Effective depth: measured 6 7 7 6' true vertical 6 4 4 6' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 2 9 9 7 9 5/8" Intermediate Production 6 8 5 4' 7" Liner Perforation depth: measured 2K-11 ........ 9. Permit number/apprOval number 89-93 1'0. APl number 5o-103-20114 11. Field/Pool K.up. aruk River. Oil Pool ....... feet Plugs (measured) feet None feet Junk (measured) feet None Cemented Measured depth True vertical depth 115' 115' 900 Sx AS III & 2986' 2920' 375 Sx Class G 225 Sx Class G 6 2 4 6' 5 9 2 7' 6574'-6600' true vertical 6247'-6273' Tubing (size, grade, and measured depth) 3.5" J-55 set at 6442' Packers and SSSV (type and measured depth) Brown HB @ 6369', Camco TRDP-1A-SSA @ 1815' ,,, ,,, 13. Stimulation or cement squeeze summary 4.5" Casing Gun @ 2 SPF RI ¢I IVED Hydraulically fractured the A Sand with crosslinked gelled water and 12/18 Mesh Carbolite. Intervals treated (measured) 14. Treatment description including volumes used and final pressure placed 14.2~493.~ 12/1.8.. Mesh Carbolite a. nd !.515 bb!.oelled wa..t.er. Fi..nal WH.T..P' = 4400 psi. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 238 836 1 700 272 Subsequent to operation 368 45 8 940 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe,d, Form 10-404 Rev 09/12/90 Title Date SUBMIT IN DUPLICATE .ARCO Alaska, Inc, O Subsidiary of Atlantic Richfield Company 2K-11 I 6776' · 'TRACTOR Dowe 11- Schlumberger REMARKS I FIELD- DISTRICT- STATE N.ql~ I OPERATION AT REPORT TIME Complete *A* SAND RK-FRAC. 0700 MIRU Do~ell Frac. Equil~aent 7*' ~nulus pFessuFed to 35~ (~) WELL SERVICE REPORT IDAY~ IDATEA_10_91 cc: E 82804 c; 197n756 0830 O930 1030 1100 1130 1150 1222 1227 1236 ~.2&l 1249 Be~tn PAd Begin 8ppa ' " " 8etin 12ppa " ,,, . -23, Total pumped - 1637 bbls. !~6 bb!s. 129 bbls, 4100pst 99 bb!~ 39n_r~.~! 115 bbls~ 1251 Flush 38bbls Cd+ 20bbls Diesel, S/D p~mps @ Total GW used = 1515 bbls. Total prop. punped behind pipe - 142,493~ Total prop. pmnped - 143,628~ Total prop. left in tubing- 1,135f Ha=:. pressure = 4500~ ["] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK AIR,LAND, o TRANSP -.,.f, INC. ' I COMBI~ '~J~RM STRAIGHT BILL · OF I[ G AND FREIGHT BILL: 525 WEST 67TH AVE., ANCHORAGE, ALASKA 99~[, 907) 344-5040 ' ORIG .... ,~L NOT-NEGOTIABLE RECEIVED, SUbjec~ the classifications and tariffs in effect, on the date of ~1~~ ATC-COM- 1 3 ALDT Icc-Mc-119402 AI. DT the receipt by the carrier of the property described in the Original Bill of Lading. "BILL TO" OTHER THAN SHIPPER OR CONSIGNEE: 0 . PIECES SPECIAL SERVICES: / DESCRIPTION OF ARTICLES AND CONTENTS. WRIGHTS SLJBJEC1 TO DIMFNSIONAI CORRFCTiON X X = lIABILITY I~" ,' ~' .... " ' 'I ...... :Jell in Iran!Hi (:JJfh(?r'£; JI~.II,HIi:¥ !iJ":lJJ h~'~ ,:, "' ',~ , . , , . ,, . ~ I(~l(~ilSO(J Vi~Jtl(} OI Jlt,s si,Il)merit i~ ~)0 (:l~flrs l)~?l i)nJ,lld [)(.,f [)lecF~ ~uJ)jl}c1 lu a fnitxllnlllT1 el $10 00() i.)or fdllj)l'11(~rtl I ~erT'he released value of the ~roperty. ls hereby stated by the shlpp~e', , not exceeding' .--.J S-"'PPER S SIGN~"E:_ ..~,~ un ' I~~ R~ND 'RANSP'RT 'NC ~' S;',I ....... · S(,cli"n 'l~d,, ...... t this ' ~ EXE E~BY' ~E / ,' ' ' ~ J...¢up~ ~, h; :;~: :~(,',1 ::, '.,.~ consignee I .k_. '~'.~' k~/~" ~/ .) I ~' ~,.~ .....V., ..... ,.":;,~.'~e,~eryof I DFS~mrD rn.m~T RrCnVrD ~NtaOOD ¢" J ~/TI~E / .- , ' ' . '~' a,.d .,' ~ · J:....,I .' ,.., .., CARRIER'S NUMBER DATE t..kN L'~E S S= O~ E R WI S'~<'!~i BI C AT E D CHARGES ARE'ASSUMED TO BE COLLECT. PREPAID COLLECT COMPLETE OmER { SHIPPERS NUMBERS /=-c o-- o~- os-N/ CHARGES I TOTAL ~ . DANGEROUS ARTIC_E.S CERTIrlCArioN. ..~. ..... This is to certify that the above-named Signature of Shipper: .............. · !.~ ..... : .................... : ............................. ~:-~ ' CONSIONEE di~t':· . articles are properly Classified, described; packaged, marked and labeled, and are ~n proper condition for transportation, accor- ding to the applicable regulations of {he Department of .Transportation. ~'~'~' STATEOF ALASKA .... ' 0 R I G I N A ALASKA ~,~L AND GAS CONSERVATION COMMISSION ~ 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG~ ''~: ' r/ ~ ~ ~:~' ,,, 1. Status of Well Classification of Service Well OIL ~ GAS [[] SUSPENDED ~ ABANDONED ~] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 89-93 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20114 , 4. Location of well at surface 9. Unit or Lease Name 46' FSL, 94' FEL, Sec. 2, T1.0N, R8E, UM LOCATION.S Kuparuk River Unit At Top Producing Interval VERIFIED 10. Well Number 1246' FNL, 979' FEL, Sec. 11, T10N, R8E, UM Sur~t 2K-11 At Total Depth ~,. H.~I 11. Field and Pool 1286' FNL, 993' FEL, Sec. 11, T10N, R8E, UM .....'-J Kuparuk River/ , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 154' RKB[ ADL:25588 ALK:2674 Kuparuk 0il Pool 1'2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 09/10/89 9/18/89 10/25/89 - -- feet MSLI 1 6870'MD&6541 'TVD 6776'MD&6446'T\ DYES I_~ NO [] 1815' feet MD -__ 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL/CAL, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD ...... SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE ~TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" S~,rf 115' __ 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) - ' 3½" ,9.3#,J '155 6442 ' 6369 ' 6574'-6600' MD w/4½" HSD @ 2 spf 6247'-6273' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIALU~ED 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) 'bate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ ,, Flow Tubing Casing Pressure CALCULATED,,~ OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,, 25. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REC , VED Form 10-407 Submit in duplicate ~,~ Rev. 7-1-80 WC1/23 CONTINUED ON REVERSE SIDE 29. 30. NAME Kuparuk A GEOLOGIC MARKERS TOPS MEAS. DEPTH 6538' TRUE VERT. DEPTH 6211' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. None 31. LIST OF ATTACHMENTS Gyro 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig ned___ ' .~_(~~m.. '-~ ~-~'L ~.~- Title Area Dri 1 1 ing Engr. Date / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' ~ndicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ~tem 16 and 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Ref~ort" On the first Wednesday after a well is spudded or workover operations ale started. Dai!y work prior to spudding should be summarized on the iorm giv;ng inclus;ve dates only. District Istate AK ARCO ALASKA INC. KUPARUK RIVER UNIT County, parish or borough NORTH SLOPE, ALASKA Lease or Unit ADL: 25588 ALK: 2674 Title COMPLETIONS 2K-11 Well no. Field Auth. or W.O. no. AK3668 Operator ARCO IDate 09/10/89 Hour 04300 IARCO w.I. 55.8533 Prior status if a W.O. Spudded or W,O. begun Date and depth as of 8:00 a,m. 10/24/89 (13) TD: 6870 PB: 6776 SUPV:GB 10/25/89 (14) TD: 6870 PB: 6776 SUPV:GB Complete record for each day reP0~ed NORDIC #1 ND DRYHOLE TREE 7"@ 6855' MW: 0.0 NaCl MOVE NORDIC RIG 1 FROM 2K-12 TO 2K-11, ACCEPT RIG 0530 10/24/89, ND DRYHOLE TREE DAILY:SO CUM:$1,090,944 ETD:SO EFC:$2,791,144 NU 3-1/8" TREE 7"@ 6855' MW: 0.0 NaC1 CONT. ND TREE, NU BOPE & TEST TO 3000 PSI, RU SWS & PERF 6580-6600 & 6574-6580 AT 2 SPF 180 PHASING ORIENTED 30 DEG FROM HIGH SIDE, RD SWS, RU & RUN 3-1/2" SINGLE COMPLETION, TEST CONTROL LINE TO 5000 PSI, DRAIN STACK, LAND TBG, DROP BALL, PRESSTBG TO 2500 PSI, SET PKR, (TBG HELD OK), BLEED PRES PICKUP AND SHEAR PBR, RELAND TBG, RILDS, TEST ANNULUS & PKR TO 2500 - OK, CLOSE SSSV, BLEED TBG TO 1000, SSSV - OK, PRESSURE TBG TO 4600, SHEAR OUT SUB, BLEED PRESSURE, CLOSE SSSV, SET BPV, ND BOPE, NU TREE DAILY:S141,753 CUM:$1,232,697 ETD:S1,232,697 EFC:$1,700,200 The above is~,~rect Sig nature~.,.~ ~ sF~ f~;~c preparation .... 'a~ed Man~J~SedlcSl~inbUlt~,°n' ~ Drilling, Pages 86 and 87, AR3B-459-1-D INumber all dally well history form8 consecutively as they are prepared for each well. iPage no.. ARCO ~,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "F[nai Report" should be submitted a;so when operations are suspended for an indefinite or appreciable length of time. On workovcrs when an official test i~ not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available· County or Parish NORTH SLOPE, ALASKA Field JLease or Unit JWeU no. KUPARUK RIVER UNIT J ADL: 25588 ALK: 2674 K 2K-11 J Title J COMPLETIONSF District ARCO ALASKA INC. Auth. or W.O. no. AK3668 J Accounting cost center code State Operator I AR.Co. W.I. ARCO J 55.8533 Spudded or W.O. begun Date SPUD 09/10/89 Date and depth as of 8:00 a.m. 10/26/89 (15) TD: 6870 PB: 6776 SUPV:GB Complete record for each day reposed NORDIC #1 otal number of wells (active or inactive) on this~ est center prior to plugging and J Jabandonment of this well JHour JPrlor atatus If a W,O, 04300 I RIG RELEASED 7"@ 6855' MW: 0.0 NaC1 CONT. NU TREE, TEST TREE & PACKOFF TO 5000 PSI, PULL TEST PLUG, OPEN SSSV, DISPLACE TOP 200' OFANNULUS AND TBG WITH DIESEL, RIG RELEASED AT 0830 10/25/89 DAILY:S9,837 CUM:$1,242,534 ETD:S1,242,534 EFC:$1,700,200 Old TD J New TD Released rig J Date Classifications (oil, gas, etc.) PB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on te~i Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i~.~rrect Signatu re~ra~~ Date// ':er~l:n°r~'~da;rePreeP>r::i°~d 87'edi~i~n 1;'triVia' ~ & AR3B-459-3-C , L:~ '~' ' ( '~,~ %~. '~'~ are p~epared for each well. J DtvlNon of Atlantl~hfleld~m~ny ARCO ALASKA, INC. WELL: 2K-11 FIELD: KUPARUK RIVER ROUTINE CORE ANALYSIS OCTOBER 1989 FILE 70069 IC OFILMED 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698.0081 · PANAFAX (213) 693-0947 October 18, 1989 Mr. Douglas Knock ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Dear Mr. Knock: Re: Core Analysis File No.: 70069 Enclosed is a final core analysis report for routine core analysis tests performed on material from Kuparuk River 2K-11 well. Laboratory procedures have been included for your reference. We appreciate this opportunity to be of service and trust these data prove beneficial to the development of this reservoir. Sincerely, P~t~'~'~eum T~sting Service, Inc. ~}.':l~-Peter T. SchUler President PTS:rdl Encl. ~ ~'~'~"~ 12051 RIVERA ROAD ~,~'~[~,.~[~ SANTA FE SPRINGS, CA 90670-2289 Client: ARCO Alaska, Inc. Well: 2K-11 Field: Kuparuk River File: 70069 Date: Oct. 18, 1989 ROUTINE CORE ANALYSIS 1. Drill 1" diameter sample plug using mineral oil as cutting fluid, trim to right cylinder. 2. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volume. 3. Vacuum dry at 150°F until weight is stable. Allow sample to cool and weigh to the nearest 0.01 gram. 4. Measure bulk volume using mercury immersion method. 5. Measure sand grain volume using a Boyle's Law helium porosimeter. Calculate porosity, saturations, and grain density. 6. Mount sample in a hydrostatic Hassler-type sleeve using a confining stress of 300 psi. 7. Measure permeability with nitrogen gas using a calibrated flow tube-type permeameter. ! I ! I ] I ! I J J J I I I I J J I i PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 1 70069 November 7, 1989 COMPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE NATER BASE HELIUM AIR OIL NATER TOTAL DEPTH POROSITY PERMEABILITY O/N SATN SATN SATN ft. PERCENT md. RATIO %PV %PV %PV 6519.5 10.6 0.9 0.02 1.2 65.1 66.3 6520.0 11.0 1.4 0.05 2.4 50.6 53.0 6521.05 9.7 <0.1 0.02 1.4 66.2 67.6 6522.05 8.4 <0.1 0.03 2.4 78.2 80.6 6523.0 8.7 0.6 0.02 1.5 84.8 86.3 6524.0 8.0 0.1 0.04 3.3 93.1 96.4 6525.05 8.0 <0.1 0.03 2.5 96.0 98.5 6526.0 8.1 1.0 0.02 1.6 82.6 8~.2 6527.0 10.1 0.3 0.04 2.6 64.0 66.6 6528.0 9.3 <0.1 0.02 1.4 62.3 63.7 6529.0 9.2 0.6 0.02 1.4 7'5.0 74.4 6530.0 8.6 0.6 0.04 3.1 81.6 84.7 6531.05 9.5 0.5 0.03 2.8 96.1 98.9 6532.0 8.9 0.2 0.02 1.7 89.7 91.4 6533.0 8.3 0.2 0.06 5.5 93.3 98.8 6534.05 8.8 0.3 0.04 4.0 93.5 97.5 6535.0 7.8 0.1 0.02 1.8 96.6 98.4 6536.0 7.9 0.2 0.04 4.1 94.5 98.6 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.67 2.66 2.64 2.62 2.60 2.65 2.66 2.64 2.73 2.62 2.64 2.63 2.64 2.63 2.63 2.61 2.58 2.58 NELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sltst; grysh brn, cly [am, fnt odor, m stn, sptd yel fluor Sltst; grysh bm, lam, fnt odor, m stn, sptd ye[ fluor Sltst; grysh bm, cly [am, fnt odor, m stn, sptd ye[ fluor Sltst; grysh bm, cly lam, carb, fnt odor, m stn, sptd ye[ fluor Sltst; grysh bm, c[y [am, carb, fnt odor, m stn, sptd ye[ fluor Sltst; grysh brn, cly lam, fnt odor, m stn, sptd yel fluor Sltst; grysh brn, cly Lam, fnt odor, m stn, sptd ye[ fluor Sltst; grysh bm, c[y [am, fnt odor, m stn, sptd yet fluor S[tst; grysh bm, cly lam, pyr, fnt odor, m stn, sptd yet fluor Sltst; grysh bm, cly tam, fnt odor, m stn, sptd ye[ fluor Sltst; grysh brn, cly tam, fnt odor, m stn, sptd ye[ fluor Sltst; grysh brn, c[y [am, fnt odor, m stn, sptd ye[ fluor Sltst; grysh brn, c[y [am, fnt odor, m stn, sptd yel fluor S[tst; grysh brn, cly [am, fnt odor, m stn, sptd ye[ fluor Sltst; grysh brn, cly Lam, fnt odor, m stn, sptd yet fluor Sltst; brn, cly lam, carb, fnt odor, m stn, sptd yel fluor Sltst; brn, cly [am, carb, fnt odor, m stn, sptd ye[ fluor Sltst; brn, c[y [am, carb, fnt odor, m stn, sptd ye[ fluor I' I I I I I I I | I J J i I I I I I PETROLEUM TESTING SERVICE, INC. Page No. FiLe No. Date 2 70069 November 7, 1989 COMPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO %PV :r~PV %PV 6537.75 8.7 3.2 0.04 3.7 94.1 97.8 6538.05 6.5 0.4 0.03 3.1 96.1 99.2 6539.0 SAMPLE FAILED 6540.2 8.4 3.5 0.07 6.6 92.6 99.2 6541.0 9.6 0.6 0.02 1.4 81.3 82.7 6542.0 9.1 1.9 0.03 2.9 89.9 92.8 6543.05 10.2 1.5 0.05 3.9 80.2 84.1 6544.0 8.7 0.2 0.02 1.5 96.4 97.9 6545.0 9.2 0.9 0.01 1.4 97.3 98.7 6546.5 10.1 5.9 * 0.06 5.9 92.0 97.9 6547.8 9.5 0.1 0.01 1.5 97.9 99.4 6548.4 8.4 <0.1 0.01 0.8 96.9 97.7 6549.1 9.7 <0.1 0.00 0.0 95.9 95.9 6550.6 10.4 1.3 0.05 3.8 83.0 86.8 6551.1 15.4 3.8 1.24 35.1 28.2 63.3 6552.1 9.3 0.3 0.14 10.3 72.7 83.0 6553.0 17.0 28. 2.58 48.4 18.8 67.2 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.68 2.82 2.61 2.63 2.63 2.67 2.71 2.62 2.65 2.60 2.61 2.67 2.64 2.61 2.61 2.63 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY S[tst; grysh brn, cly lam, pyr, fnt odor, m stn, sptd yel fluor C[st; gry, slt Lam, pyr, fnt odor, m stn, sptd ye[ fluor Ctst; grysh brn, sit tam, pyr, fnt odor, m stn, sptd yet fluor Sttst; bm, c[y tam, carb, fnt odor, m stn, sptd yet fluor Sttst; grysh bm, cry tam, fnt odor, m stn, sptd yet fluor Sttst; grysh bm, cry tam, fnt odor~ m stn, sptd yet fluor Sltst; brn, cly [am, pry, fnt odor, m stn, sptd ye[ fluor Ctst; brn, sit lam, carb, fnt odor, m stn, sptd yet fluor Sttst; grysh brn, c[y tam, fnt odor, m stn, sptd yet fluor Clst; gry, sit lam, carb, fnt odor, m stn, sptd yet fluor C[st; gry, slt lam, carb, fnt odor, m stn, sptd ye[ fluor Ctst; gry, lam, n odor, n stn, n fluor Sltst; grysh bm, cry tam, fnt odor, m stn, yet fluor Sst; brn, vfg, stty, carb, fr odor, m stn, yet fluor S[tst; brn, sdy, cry tam, fr odor, m stn, yet fluor Sst; brn, vf-fg, slty, gd odor, m stn, yet fluor FRACTURED J I J I i J j J ! ! J J _ J J I J J i PETROLEUM TESTING SERVICE, INC. Page No. FiLe No. Date 3 70069 November 7, 1989 COMPANY CORE TYPE MUD TYPE HELIUM DEPTH POROSITY ft. PERCENT 6554.0 17.9 6555.05 12.5 6556.0 15.5 6557.0 12.0 6558.1 11.8 6559.4 10.8 6560.0 12.3 6561.1 13.4 6562.0 9.3 6563.0 10.5 6564.1 8.9 6565.0 10.1 6566.0 8.3 6567.1 7.9 6568.0 8.1 6569.0 7.9 6570.1 7.3 6571.0 4.0 ARCO ALASKA INC. 4 INCH FIBERGLASS SLEEVE WATER BASE AIR OIL WATER TOTAL PERMEABILITY O/W SATN SATN SATN md. RATIO %PV :~LoV %PV 20. 2.39 46.0 19.2 65.2 1.6 0.30 16.4 55.6 72.0 6.5 1.47 41.0 28.0 69.0 3.8 0.42 22.8 53.9 76.7 3.0 0.33 19.4 59.7 79.1 1.3 * 0.21 13.5 63.0 76.5 0.6 1.83 47.8 26.2 74.0 0.4 1.66 40.0 24.2 64.2 1.3 0.02 ,1.5 80.4 81.9 0.4 0.33 19.7 59.3 79.0 0.2 0.02 1.6 97.8 99.4 14. 0.12 9.2 75.8 85.0 0.2 0.03 2.5 95.3 97.8 0.3 0.02 1.7 96.0 97.7 0.2 0.02 1.5 97.1 98.6 2.5 0.02 1.7 97.6 99.3 0.3 0.00 0.0 98.2 98.2 0.2 * 0.00 0.0 96.8 96.8 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.64 2.64 2.60 2.61 2.60 2.60 2.63 2.~ 2.61 2.60 2.59 2.58 2.61 2.61 2.59 2.63 2.58 2.59 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sst; bm, vf-fg, Lam, gd odor, m stn, yeL fluor Sst; bm, vf-fg, sLty, cLy Lam, pyr, fr odor, m stn, yeL fluor Sst; bm, vf-fg, sLty, cLy Lam, carb, fr odor, m stn, yeL fluor Sst; grysh bm, vfg, sLty, cLy Lam, fr odor, m stn, yeL fluor Sst; grysh bm, vfg, sLty, cLy Lam, fr odor, m stn, yeL fluor Sttst; grysh brn, sdy, cly [am, fr odor, m stn, yet fluor SI[st; grysh bm, sdy, c[y Lam, fr odor, m stn, ye[ fluor S[tst; bm, sdy, c[y tam, pyr, fr odor, m stn, ye[ fluor Sits[; brn, sdy, cLy tam, fnt odor, m stn, strk ye[ fluor S[tst; bm, sdy, c[y [am, fr odor, m stn, strk ye[ fluor Clst; gry, slt lam, carb, fnt odor, m stn, strk yel fluor SLtst; grysh bm, cry Lam, carb, fnt odor, m stn, strk yeL fluor Ctst; grysh bm, sit tam, fnt odor, m stn, strk yeL fluor Sltst; grysh bm, cry Lam, fnt odor, m stn, strk yet fluor Sttst; grysh bm, cLy [am, carb, fnt odor, m stn, strk yeL fluor Sltst; grysh brn, cly lam, fnt odor, m stn, strk ye[ fluor Clst; gry, slt tam, carb, n odor, n stn, n fluor CLst; gry, slt Lam, carb, n odor, n stn, n fluor * FRACTURED i I I i I i I i I ! J J i, J ! I ~ I PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 4 70069 November 7, 1989 COMPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO ~DV %PV %PV 6572.0 6.9 1.3 0.04 3.9 93.6 97.5 6573.1 8.2 0.7 0.03 2.5 96.8 99.3 6574.0 8.9 0.9 0.01 1.2 97.8 99.0 6575.0 9.1 0.3 0.03 3.0 88.7 91.7 6576.4 18.1 20. 1.12 36.1 32.3 68.4 6577.0 12.1 0.6 0.36 21.6 59.4 81.0 6578.1 14.9 17. 1.26 43.1 34.2 77.3 6579.5 24.5 179. 5.97 63.2 10.6 73.8 6579.9 24.5 151. 8.17 63.9 7.8 71.7 · 6580.6 24.4 140. 1.11 41.9 37.7 79.6 6582.14 24.8 114. 2.90 56.7 19.5 76.2 6583.1 25.7 192. 5.16 65.2 12.6 77.8 6584.0 23.4 66. 3.87 61.3 15.9 77.2 6585.0 25.2 137. 7.46 64.0 8.6 72.6 6586.6 22.6 34. 4.25 61.2 14.4 75.6 6587.1 20.1 55. 2.18 51.5 23.6 75.1 6587.8 22.8 55. 5.89 66.0 11.2 77.2 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.58 2.59 2.60 2.62 2.65 2.63 2.60 2.~ 2.63 2.62 2.61 2.62 2.~ 2.63 2.63 2.61 2.64 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sltst; gry, cly lam, carb, fnt odor, m stn, strk yel fluor Sltst; grysh bm, cLy lam, carb, fnt odor, m stn, strk vel fluor Sltst; grysh brn, cly Lam, carb, fnt odor, m stn, strk yeL fluor Sttst; grysh brn, cry tam, fnt odor, m stn, strk yet fluor Sst; bm, fg, sit Lam, fr odor, m stn, yet fluor Sst; brn, vfg, s[ty, cly Lam, fr odor, m stn, strk yet fluor Sst; brn, vf-fg, sit [am, gd odor, m stn, ye[ fluor Sst; brn, fg, gd odor, m stn, yeL fluor Sst; brn, fg, gd odor, m stn, yel fluor Sst; bm, fg, gd odor, m stn, ye[ fluor Sst; brn, fg, carb, gd odor, m stn, yel fluor Sst; brn, fg, gd odor, m stn, yeL fluor Sst; brn, fg, pyr, gd odor, m stn, ye[ fluor Sst; brn, fg, gd odor, m stn, yeL fluor Sst; bm, fg, gd odor, m stn, yeL fluor Sst; bm, fg, Lam, carb, gd odor, m stn, ye[ fluor Sst; brn, fg, gd odor, m stn, yet fluor I I J I I I I ! I I | ! ! ! I J ! ! ! PETROLEUM TESTING SERVICE, INC. Page No. File-No, Date 5 70069 November 7, 1989 CONPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO %PV %PV %PV 6588.3 22.5 24. 3.45 58.9 17.1 76.0 6589.05 17.6 83. * 1.44 42.7 29.7 72.4 6590.05 10.7 1.2 0.02 1.4 86.7 88.1 6591.1 17.7 27. 1.77 46.3 26.1 72.4 6592.0 22.1 23. 3.82 55.1 14.4 69.5 6593.0 18.2 38. 1.22 42.8 35.0 77.8 6594.2 11.6 16. 1.18 45.9 38.8 84.7 6595.0 SAMPLE FAILED 6596.0 12.8 4.9 0.48 26.0 54.1 80.1 6597.2 18.2 20. 2.78 52.7 18.9 71.6 6598.0 15.0 1.8 1.10 38.3 34.8 73.1 6599.0 20.9 39. 4.93 60.4 12.3 72.7 6600.5 20.5 1.8 2.75 52.4 19.1 71.5 6601.0 11.2 1.4 0.59 29.3 49.3 78.6 6602.0 11.1 5.9 0.50 31.0 62.5 93.5 6603.1 14.0 0.5 1.02 36.8 36.1 72.9 6604.0 4.9 0.9 2.23 55.7 25.0 80.7 6605.0 11.0 0.7 0.31 19.7 63.4 83.1 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.68 2.60 2.60 2.62 2.63 2.81 2.59 2.57 2.62 2.61 2.63 2.59 2.57 2.59 2.59 2.66 2.59 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sst; brn, fg, cly tam, pyr, gd odor, m stn, yet fluor Sst; brn, vfg, s[ty, cry tam, carb, gd odor, m stn, ye[ fluor Sttst; bm, sdy, c[y tam, carb, fnt odor, m stn, strk ye[ fluor Sst; brn, vfg, stty, c[y [am, gd odor, m stn, ye[ fluor Sst; brn, vfg, stty, gd odor, m stn, ye[ fluor Sst; brn, vfg, stty, pyr, gd odor, m stn, yet fluor Sttst; grysh brn, sdy, carb, gd odor, m stn, strk yet fluor Sttst; grysh brn, sdy, carb, fr odor, m stn, strk yet fluor Sst; brn, vf-fg, sit tam, carb, gd odor, m stn, strk yet fluor Sst; brn, vf-fg, sit Lam, carb, gd odor, m stn, strk yet fluor Sst; brn, vf-fg, sLt Lam, gd odor, m stn, strk ye[ fluor Sst; bm, vf-fg, stty, carb, gd odor, m stn, yet fluor Sttst; grysh bm, scly, cry tam, carb, fr odor, m stn, strk ye[ fluor Sttst; grysh brn, sdy, cry tam, carb, fr odor, m stn, strk yet fluor Sttst; grysh brn, sdy, cty Lam, carb, fr odor, m stn, strk yet fluor Sst; bm, vfg, v ~t cmt, gd odor, m stn, yet ftuor Sst; grysh bm, vfg, stty, cry tam, carb, fr odor, m stn, strk yet ftuor FRACTURED PETROLEUM TESTING SERVICE, INC. Page No. FiLe No. Date 6 70069 November 7' 1989 CONPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO %PV ~Lov y~oV 6606.0 10.2 0.9 0.56 34.9 62.7 97.6 6607.0 13.7 0.3 1.72 40.9 23.8 64.7 6608.0 9.2 1.1 0.05 4.0 78.9 82.9 6609.0 9.4 0.1 0.07 5.8 81.6 87.4 6610.1 13.5 1.5 1.26 38.2 30.3 68.5 6611.0 12.9 1.2 0.64 26.8 42.1 68.9 6612.1 11.6 0.6 0.53 24.4 46.0 70.4 6613.0 8.8 0.2 0.04 3.1 78.7 81.8 6614.0 9.4 0.1 0.03 2.2 78.5 80.7 6615.0 11.5 1.0 0.24 15.3 63.8 79.1 6616.0 10.3 0.4 0.06 4.0 69.6 73.6 6617.0 8.5 0.1 0.00 0.0 84.3 84.3 6618.0 10.3 0.8 0.51 20.6 40.6 61.2 6619.0 10.3 6.0 0.08 6.1 77.7 83.8 6620.0 11.8 1.3 0.03 2.4 7'3.2 75.6 6621.0 9.4 0.5 0.00 0.0 87.1 87.1 6622.0 9.3 1.1 0.06 5.1 88.4 93.5 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.58 2.67 2.59 2.62 2.59 2.60 2.61 2.59 2.60 2.60 2.62 2.62 2.62 2.65 2.66 2.58 2.64 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sst; grysh brn, vfg, slty, cry tam, carb, fr odor, m stn, strk yet fluor Sst; grysh bm, vfg, slty, cly tam, pyr, fr odor, m stn, strk yet fluor Sst; grysh brn, vfg, stty, cty Lam, carb, fr odor, m stn, strk yet fluor Sst; grysh brn, vfg, stty, cry tam, fr odor, m stn, strk yeL fluor Sst; grysh brn, vfg, stty, cry tam, carb, fr odor, m stn, yeL fluor SSt; grysh brn, vfg, stty, cry tam, carb, fr odor, m stn, yeL fluor Sst; grysh bm, vfg, stty, cry tam, carb, fr odor, m stn, yet fluor Sttst; gry, scly, cry tam, carb, fnt odor, m stn, strk yet fluor Sttst; gry, sdy, cry tam, carb, fnt odor, m stn, strk yet fluor SLtst; gry, sdy, cry tam, carb, fnt odor, m stn, strk yet fluor Sttst; gry, sdy, cry tam, carb, fnt odor, m stn, strk yet fluor Sttst; gry, sdy, cry tam, carb, n odor, n stn, n fluor Sltst; gry, sdy, cry Lam, carb, fr odor, m stn, strk yet fluor S[tst; gry, sdy, cly tam, fnt odor, m stn, strk yet fluor Sltst; gry, sdy, cry tam, pyr, fnt odor, m stn, strk yet fluor Sttst; gry, sdy, cry tam, carb, n odor, n stn, n fluor Sttst; gry, sdy, cry tam, fnt odor, m stn, strk yet fluor PETROLEUH TESTING SERVICE, INC. Page No. 7 File No. 70069 Date November 7, 1989 COMPANY ARCO ALASKA INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROS I TY PERMEAB I L I TY O/W SATN SATN SATN ft. PERCENT md. RAT I 0 %PV %PV %PV 6623.1 8.6 <0.1 0.02 1.5 82.1 83.6 6624.0 9.7 118. 0.14 11.2 79.6 90.8 6625.2 8.0 3.6 0.00 0.0 92.0 92.0 6626.1 9.4 1.0 0.18 12.5 ~.7 81.2 6627.0 6.9 2.9 * 0.03 2.9 94.4 97.3 6628.0 9.8 3.0 0.00 0.0 89.6 89.6 6629.0 6.7 0.9 0.00 0.0 98.0 98.0 6630.0 11.9 1.4 0.48 15.8 32.9 48.7 6656.0 8.1 0.1 0.00 0.0 66.2 66.2 6659.8 17.7 3.7 1.42 34.8 - 24.6 59.4 6661.0 2.8 <0.1 0.00 0.0 77.8 77.8 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.88 2.59 2.57 2.60 2.57 2.63 2.75 2.75 2.75 2.71 2.67 WELL 2K-11 FIELD KUPARUK RIVER COUNTY STATE ALASKA LITHOLOGY Sttst; grysh brn, sdy, cly tam, pyr, fnt odor, m stn, strk yet fluor Sttst; grysh bm, sdy, cry tam, carb, fnt odor, m stn, strk yet fluor Ctst; gry, sit lam, carb, n odor, n stn, n fluor Sttst; gry, cry tam, carb, fnt odor, m stn, strk yet fluor Ctst; gry, sit tam, carb, fnt odor, m stn, strk yet fluor Ctst; gry, stt Lam, n odor, n stn, n fluor Ctst; gry, sit Lam, pyr, n odor, n stn, n fluor Sst; bm, vfg, sit Lam, pyr, fr odor, m stn, yet fluor Sst; tt gry, vfg, v wt cmt, pyr, n odor, n stn, n fluor Sst; grysh bm, vfg, stty, pyr, fr odor, m stn, yet fluor Sst; Lt gry, vfg, v wt cmt, n odor, n stn, n fluor TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERMEAMETER = 300 psi OIL GRAVITY SUPPLIED BY CUSTOMER = 19 A.P.I. * FRACTURED PETROLEUM TESTING SERVICE, INC. PERMEABILITY AND POROSITY HISTOGRAM CLIENT: ARCO ALASKA INC, STATE: ALASKA FIELD: 2K-11 WELL: KUPARUK RIVER FILE No.: 70069 DATE: OCT. 18, 1989 DEPTH INTERVAL, fi: 6519,5- 6661. 100 90 ~ 8O ~ 70 >2 50 0 30 b. 20 10 ! I · I I I I I I I I ' · ! I , , e : · : I · : : : e , : 0 2 4. 8 8 10 12 Cumulative Frequency ........ Arithmetic Mean 12.0 ..... Median Value 10.1 14 18 18 20 22 24 28 28 30 32 34 38 38 40 42 44 46 POROSITY, percenf 100 -~ 90 80 70 >2 6O ~ 30 >. ::3 10 ;2 ::3 0 100 90 ~ 8O o 70 m 6O >2 SO h. 2O 10 ! -' I I : ! : ! : I : ! : 'i ! ! . , ! · . ! · Cumulative Frequency ........ Geometric Meon 1.6 ..... Median Value 1.1 100 -~ 90 80 70 >~ Z 60 50 0 30 ~. 20:5 10:2 0 (~ · 01 .0: .0~ .08 .18 .32 .84. 1.25 2.5 5. 10 20 40 80 160 320 640 1280 2560 5120 10240 PERMEABILITY, millldorcies PETROLEUM, 'TESTING SERVICE, INC. POROSITY- PERMEABILITY CROSSPLOT CUENT: ARCO ALASKA INC. STATE: ALASKA FIELD: 2K-11 WEI_I~ KUPARUK RIVER FILE No.: 70069 DATE: OCT. 18, 1989 DEPTH INTERVAL, ft : 6519.5- 6661. 1000 100 10 .1 0 10 20 30 40 50 POROSITY, percenf P~-rROLEUM TESTING SERVICE, INC. GRAIN DENSITY- POROSITY CROSSPLOT CUENT: ARCO ALASKA INC. STATE: ALASKA FIELD: 2K- 11 WELL: KUPARUK RIVER FILE No.: 70069 DATE: OCT. 18. 1989 DEPTH INTERVALft : 6519.5- 6661. z 3.50 3.00 2.50 2.00 1.50 0 10 20 30 40 5 0 _ POROSITY, percenf ORIGINAL October 12, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90108 Well: 2K-11 Field: Kuparuk Survey Date: 9/24/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss GTroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank ~ou for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures HICROFILHEO RECEIVED 8537 Corbin Dnve (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 0 .00 -154.00 100 100.00 -54.00 200 200.00 46.00 300 300.00 146.00 400 400.00 246.00 0 0 0 19 0 13 0 19 0 13 COURSE DIRECTION DEGREES DG/ DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE DLS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST N .00 E .00 S 87.30 W .32 N 26.70 W .31 N 82.30 W .27 N 50.00 W .18 VERT. SECT. .00 .00 .00 .01S .28W .17 .15N .65W .24 .37N 1.01W .26 .53N 1.44W .37 500 499.99 345.99 600 599.99 445.99 700 699.98 545.98 800 799.98 645.98 900 899.97 745.97 0 22 0 36 0 40 0 36 0 34 N 89.70 W .25 S 59.30 W .34 S 72.80 W .16 S 77.90 W .09 S 79.10 W .03 .66N 1.91W .39N 2.68W .05S 3.69W .33S 4.76W .54S 5.76W .52 1.18 2.11 2.94 3.67 1000 999.97 845.97 1100 1099.97 945.97 1200 1199.96 1045.96 1300 1299.96 1145.96 1400 1399.95 1245.95 0 23 0 31 0 36 0 37 0 43 S 88.00 W .19 N 51.30 W .34 N 52.40 W .08 N 48.00 W .05 N 53.50 W .13 .64S 6.59W .37S 7.28W .23N 8.05W .91N 8.87W 1.65N 9.78W 4.22 4.38 4.31 4.21 4.10 1500 1499.94 1345.94 1600 1599.94 1445.94 1700 1699.93 1545.93 1800 1799.93 1645.93 1900 1899.92 1745.92 0 39 0 27 0 34 0 39 0 41 N 51.50 W .07 N 41.10 W .23 N 58.80 W .20 N 53.20 W .10 N 56.80 W .05 2.39N 10.75W 4.03 3.05N 11.46W 3.89 3.60N 12.15W 3.81 4.21N 1.3.04W 3.81 4.89N 14.01W 3.79 2000 1999.90 1845.90 2050 2049.84 1895.84 2100 2099.63 1945.63 2150 2149.29 1995.29 2200 2198.77 2044.77 1 20 4 8 6 11 7 4 9 21 S 62.80 W 1.17 S 40.10 W 5.90 .S 35.60 W 4.18 S 32.20 W 1.93 S 29.60 W 4.64 4.68N 15.55W 3.03N 17.23W .54S 19.96W 5.33S 23.17W 11.47S 26.82W 4.82 7.13 11.62 17.39 24.52 2250 2248.05 2094.05 2300 2297.27 2143.27 2350 2346.34 2192.34 2400 2395.05 2241.05 2450 2443.41 2289.41 10 3 10 15 11 49 14 11 15 10 S 30.00 W 1.39 S 30.50 W .45 S 32.50 W 3.23 S 35.60 W 4.92 S 36.40 W 2.02 18.79S 31.01W 26.40S 35.45W 34.56S 40.47W 43.87S 46.79W 54.12S 54.24W 32.92 41.72 51.29 62.54 75.21 2500 2491.62 2337.62 2600 2586.74 2432.74 2650 2633.56 2479.56 2700 2680.20 2526.20 2800 2771.92 2617.92 15 34 20 16 20 50 21 26 25 27 S 36.30 W .78 S 37.40 W 4.71 S 37.30 W 1.14 S 36.30 W 1.40 S 33.80 W 4.14 64.80S 62.10W 89.39S 80.57W 103.34S 91.22W 117.78S 102.02W 150.39S 124.81W 88.45 119.17 136.70 154.71 194.48 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 2900 2861.96 2707.96 3000 2951.27 2797.27 3100 3040.10 2886.10 3200 3128.91 2974.91 3300 3217.64 3063.64 3400 3306.36 3152.36 3500 3395.06 3241.06 3600 3483.67 3329.67 3700 3572.15 3418.15 3800 3660.48 3506.48 DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 26 7 S 33.70 W .66 186.56S 148.98W 27 20 S 34.50 W 1.27 223.80S 174.20W 27 19 S 34.30 W .09 261.69S 200.14W 27 23 S 34.10 W .11 299.70S 225.98W 27 32 S 33.90 W .18 337.94S 251.77W VERT. SECT. 237.99 282.96 328.88 374.84 420.96 27 25 S 34.10 W .14 376.20S 277.57W 27 33 S 34.10 W .13 414.43S 303.46W 27 40 S 34.70 W .30 452.67S 329.64W 27 52 S 35.00 W .25 490.91S 356.27W 28 1 S 36.00 W .49 529.08S 383.50W 467.11 513.28 559.63 606.22 653.08 3900 3748.77 3594.77 4000 3837.04 3683.04 4100 3925.24 3771.24 4200 4013.34 3859.34 4300 4101.36 3947.36 27 59 S 36.00 W .04 567.07S 411.10W 28 4 S 37.20 W .57 604.79S 439.12W 28 9 S 36.70 W .25 642.45S 467.44W 28 17 S 37.60 W .45 680.15S 496.01W 28 21 S 37.80 W .11 717.70S 525.03W 700.02 746.96 794.02 841.25 888.61 4400 4189.48 4035.48 4500 4278.20 4124.20 4600 4367.25 4213.25 4700 4456.11 4302.11 4800 4544.87 4390.87 28 4 S 37.60 W .30 755.11S 553.94W 26 52 S 34.40 W 1.90 792.39S 581.06W 27 16 S 34.30 W .40 829.97S 606.74W 27 19 S 34.50 W .10 867.80S 632.65W 27 32 S 35.00 W .32 905.65S 658.91W 935.79 981.87 1027.38 1073.24 1119.30 4900 4633.54 4479.54 5000 4723.18 4569.18 5100 4814.37 4660.37 5200 4906.68 4752.68 5300 5000.24 4846.24 27 32 S 35.30 W .14 943.46S 685.53W 25 4 S 33.10 W 2.66 980.08S 710.46W 23 21' S 33.20 W 1.71 1014.42S 732.89W 21 49 S 33.40 W 1.53 1046.53S 753.98W 19 27 S 32.50 W 2.40 1076.10S 773.16W 1165.53 1209.83 1250.84 1289.26 1324.49 5400 5095.26 4941.26 5500 5191.29 5037.29 5600 5287.71 5133.71 5700 5384.32 5230.32 5800 5481.57 5327.57 16 51 S 30.50 W 2.67 1102.63S 789.46W 15 31 S 27.70 W 1.54 1126.96S 803.04W 15 14 S 28.70 W .39 1150.34S 815.57W 14 39 S 28.70 W .58 1172.97S 827.96W 12 11 S 28.40 W 2.46 1193.36S 839.06W 1355.61 1383.37 1409.75 1435.44 1458.55 5900 5579.82 5425.82 6000 5678.65 5524.65 6100 5777.58 5623.58 6200 5876.55 5722.55 6300 5975.58 5821.58 9 10 S 29.50 W 3.03 1209.60S 848.01W 8 19 S 28.10 W .89 1222.93S 855.35W 8 29 S 25.60 W .40 1235.97S 861.95W 7 55 S 23.00 W .67 1248.97S 867.83W 8 4 S 21.90 W .21 1261.84S 873.15W 1477.02 1492.17 1506.67 1520.74 1534.38 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 TRUE SUB- SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE DLS TOTAL RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6400 6074.65 5920.65 6460 6134.12 5980.12 6500 6173.75 6019.75 6600 6272.84 6118.84 6700 6371.99 6217.99 7 35 S 21.10 W .49 7 40 S 20.40 W .22 7 48 S 22.20 W .69 7 41 S 20.80 W .22 7 11 S 19.00 W .54 1274.51S 1281.96S 1286.99S 1299.53S 1311.71S 878.14W 1547.68 880.97W 1555.43 882.92W 1560.69 887.87W 1573.85 892.28W 1586.42 6750 6421.60 6267.60 6800 6471.22 6317.22 6870 6540.68 6386.68 7 7 S 19.40 W .19 7 7 S 19.40 W .04 7 7 S 19.40 W .03 1317.60S 1323.44S 1331.63S 894.33W 1592.44 896.39W 1598.44 899.27W 1606.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1606.83 FEET AT SOUTH 34 DEG. 1 MIN. WEST AT MD = 6870 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 214.03 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 1000 999.97 845.97 2000 1999.90 1845.90 3000 2951.27 2797.27 4000 3837.04 3683.04 .00 .00 .00 .64 S 6.59 W .03 .03 4.68 N 15.55 W .10 .07 223.80 S 174.20 W 48.73 48.64 604.79 S 439.12 W 162.96 114.23 5000 4723.18 4569.18 6000 5678.65 5524.65 6870 6540.68 6386.68 980.08 S 710.46 W 276.82 113.86 1222.93 S 855.35 W 321.35 44.52 1331.63 S 899.27 W 329.32 7.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 0 .00 -154.00 .00 .00 .00 54 54.00 -100.00 .00 S .04 W .00 154 154.00 .00 .00 S .55 W .00 254 254.00 100.00 .33 N .77 W .00 354 354.00 200.00 .42 N 1.30 W .00 454 454.00 300.00 .65 N 1.62 W .01 554 554.00 400.00 .62 N 2.28 W .01 654 654.00 500.00 .11 N 3.18 W .01 754 754.00 600.00 .23 S 4.29 W .02 854 854.00 700.00 .45 S 5.31 W .02 954 954.00 800.00 .63 S 6.27 W .03 1054 1054.00 900.00 .61 S 6.96 W .03 1154 1154.00 1000.00 .06 S 7.68 W .04 1254 1254.00 1100.00 .58 N 8.50 W .04 1354 1354.00 1200.00 1.31 N 9.32 W .05 1454 1454.00 1300.00 2.06 N 10.33 W .06 1554 1554.00 1400.00 2.77 N 11.21 W .06 1654 1654.00 1500.00 3.36 N 11.76 W .07 1754 1754.00 1600.00 3.90 N 12.62 W .07 1854 1854.00 1700.00 4.58 N 13.55 W .08 1954 1954.00 1800.00 5.12 N 14.63 W .09 2054 2054.00 1900.00 2.79 N 17.43 W .17 2154 2154.00 2000.00 5.83 S 23.48 W .74 2256 2254.00 2100.00 19.70 S 31.54 W 2.04 2357 2354.00 2200.00 35.91 S 41.33 W 3.83 2460 2454.00 2300.00 56.43 S 55.95 W 6.97 2565 2554.00 2400.00 80.21 S 73.60 W 11.28 2671 2654.00 2500.00 109.57 S 95.94 W 17.88 2780 2754.00 2600.00 143.44 S 120.12 W 26.22 2891 2854.00 2700.00 183.32 S 146.82 W 37.14 3003 2954.00 2800.00 224.96 S 175.00 W 49.08 3115 3054.00 2900.00 267.62 S 204.19 W 61.65 3228 3154.00 3000.00 310.46 S 233.26 W 74.25 3341 3254.00 3100.00 353.67 S 262.34 W 87.00 3453 3354.00 3200.00 396.69 S 291.45 W 99.69 VERTICAL CORRECTION .00 .00 .00 .00 .00 .00 .01 .01 .01 .01 .00 .00 .01 .01 .01 .01 .00 .01 .01 .01 .08 .57 1.30 1.79 3.15 4.31 6.60 8.34 10.92 11.94 12.57 12.61 12.75 12.68 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3566 3454.00 3300.00 439.88 S 320.79 W 112.50 12.81 3679 3554.00 3400.00 483.05 S 350.77 W 125.47 12.97 3792 3654.00 3500.00 526.28 S 381.47 W 138.66 13.19 3905 3754.00 3600.00 569.32 S 412.73 W 151.93 13.27 4019 3854.00 3700.00 612.00 S 444.59 W 165.23 13.30 4132 3954.00 3800.00 654.80 S 476.65 W 178.63 13.40 4246 4054.00 3900.00 697.50 S 509.37 W 192.18 13.55 4359 4154.00 4000.00 740.12 S 542.40 W 205.79 13.61 4472 4254.00 4100.00 782.28 S 574.13 W 218.87 13.08 4585 4354.00 4200.00 824.32 S 602.89 W 231.10 12.23 4697 4454.00 4300.00 866.90 S 632.03 W 243.62 12.53 4810 4554.00 4400.00 909.56 S 661.64 W 256.30 12.68 4923 4654.00 4500.00 952.08 S 691.57 W 269.01 12.72 5034 4754.00 4600.00 992.16 S 718.34 W 280.03 11.02 5143 4854.00 4700.00 1028.71 S 742.24 W 289.16 9.13 5250 4954.00 4800.00 1062.17 S 764.25 W 296.89 7.73 5356 5054.00 4900.00 1091.53 S 782.79 W 302.75 5.87 5461 5154.00 5000.00 1117.80 S 798.22 W 307.30 4.54 5565 5254.00 5100.00 1142.28 S 811.16 W 311.06 3.76 5668 5354.00 5200.00 1166.01 S 824.15 W 314.66 3.59 5771 5454.00 5300.00 1188.12 S 836.22 W 317.80 3.14 5873 5554.00 5400.00 1205.78 S 845.87 W 319.81 2.02 5975 5654.00 5500.00 1219.75 S 853.65 W 321.08 1.27 6076 5754.00 5600.00 1232.79 S 860.43 W 322.16 1.08 6177 5854.00 5700.00 1246.08 S 866.61 W 323.23 1.07 6278 5954.00 5800.00 1259.00 S 872.01 W 324.20 .98 6379 6054.00 5900.00 1271.94 S 877.15 W 325.17 .97 6480 6154.00 6000.00 1284.48 S 881.90 W 326.06 .89 6580 6254.00 6100.00 1297.15 S 886.96 W 326.99 .93 6681 6354.00 6200.00 1309.56 S 891.54 W 327.86 .87 6782 6454.00 6300.00 1321.41 S 895.68 W 328.65 .78 6870 6540.68 6386.68 1331.63 S 899.27 W 329.32 .67 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-11 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 2997 2948.60 2794.60 222.66 S 6538 6211.40 6057.40 1291.77 S 6666 6338.26 6184.26 1307.68 S 6750 6421.60 6267.60 1317.60 S 6775 6446.41 6292.41 1320.52 S 173.42 W 9 5/8" CSG 884.88 W TOP KUPARUK A 890.90 W BASE KUPARUK A 894.33 W SURVEY DEPTH 895.36 W PBTD 6854 6524.80 6370.80 1329.75 S 6870 6540.68 6386.68 1331.63 S 898.61 W 7" CSG 899.27 W TD ,mmmmmmmmmmmmmmm ~ mmm m mm mm m m mm m mm mmm, 2K-11 STRATIGRAPHIC SUMMARY BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 46FSL 94FEL SEC 02 T10N R08E 9 5/8" CSG 2997 2948.60 2794.60 222.66S 173.42W TOP KUPARUK A 6538 6211.40 6057.40 1291.77S 884.88W BASE KUPARUK A 6666 6338.26 6184.26 1307.68S 890.90W PBTD 6775 6446.41 6292.41 1320.52S 895.36W 7" CSG 6854 6524.80 6370.80 1329.75S 898.61W TD 6870 6540.68 6386.68 1331.63S 899.27W COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm, mmmmmm DATE OF SURVEY: 09-24-89 COMPUTATION DATE: 9/25/89 JOB NUMBER: AK-BO-90108 KELLY BUSHING ELEV. = 154.00 FT. 2K-11 KUPARUK ALASKA 09-24-89 SPERR~,-SUN HORTZONTAL DRLG. ---,SVCS . PROJECTTON START TVD = 0 FINISH TVD = 6540.68 SCALE IS 500 FEET/IN DEPARTURE 8000 2SO0 2000 · 1S00 I 1000 500 0 I ,0 -500 1000 1500 2000 .2500 0000 2K-11 KUPARUK ALASKA 09-24-89 SPERR,.~-SUN VERTICAL DRLG. ~'SVCS. PROJECTION START TVD = 0 FINISH TVD = 6540.68 SCALE IS 1000 FEET/IN 1,1 lOOO 2000 8000 4000 $000 0ooo 7000 8870 1606.83 lO~O oobo '/ERTTCAL SECTION DZR£CTZON == O. O0 soho soho ARCO Alaska, Inc. Date: December 6, 1989 Transmittal #: 7620 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the follOwing items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 2 Acoustic Cement Bond Log 9 - 2 4; 8 9 4 5 8 8 - 6 9 0 6 2 K - 1 1 Acoustic Cement Bond Log 9 - 2 3- 8 9 4 9 9 8 - 6 7 7 0 2 K - 0 6 Acoustic Cement Bond Log 9 - 2 2 - 8 9 5 5 0 2 - 7 9 2 0 2 K - 0 5 Acoustic Cement Bond Log 9 - 2 6 - 8 9 5 3 5 6 - 7 8 0 3 2 K - 01 Acoustic Cement Bond Log 9 - 2 3 - 8 9 5 8 3 8 - 8 4 4 0 Receipt Acknowledged: RECEIVED -~:-f .-f./~ at e : ...//_//,4 ......... Anchorage DISTRIBUTION: NSK Drilling KUPARUK ENGINEERING TRANSMITTAL #1320 TO John Boyle - State DATE: November 29, 1989 FROM: Ken Griffin/P. S. Baxter WELL NAME: 2K- 11 CONFIDENTIAL TRANSMITTED HERE~TH ARE A COPY OF THE FOLLOWING: One copy of bulelines for each: 2" Dual Induction - SFL 5" Dual Induction - SFL Compensated Neutron-Litho-Density Compensated Neutron-Litho-Density Cyberlook Sidewall Core Record (Porosity) (Raw Data) 9/11/89 run 1 9/11/89 run 1 9/11/89 run 1 9/11/89 run 1 9/11/89 run 1 9/11/89 run 1 PLEASE RETURN RECEIFF TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO P. O. Box 100360 DEC- ,_ 1989 Anchorage, Alaska 995 101 · RECEIPT ACKNOWLEDGED:/, ..~~.,_.ff~DATE: Anchorage P.T.S. HOUSE RECEIVED 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 SAMPLE ACTIVITY RECORD RECEIVED ~')~i.i'~ TM, ~,,~ ,~ ~oor~ · %,00_ SHIPMENT TRANSFER ~--/DELIVERY PRE PAID ~//COLLECT NORMAL DEADLINE: · I/ , ~ ,, CONTAINERS: PALLETS: OTHER: · DELIVERY BY: DATE: SHIPPED BY: DATE: FINAL DISPOSITION OF MATERIAL, RETURNED TO COMPANY CONSUM~ ¢mo¢,~r:~. "~',BIENT COOL FROZEN J / 97 (9/., I." k~UL o~' hi-gq cs~' on' E/97 01'~/99 ' (~6' ~, 1/95~ ([6 · o()-30 OO '~ 00' hO9 9' ..00'~...~0 9 ,~ : OO.:..I-.O~ ?9. ~:::.~, o~' ~'.'9± · 00' ~ s oo '.in~9 ARCO Alaska, Inc. Date: November 20, 1989 Transmittal #: 7611 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 1 Core Analysis 1 0 - 1 8 - 8 9 7 0 0 6 9 Receipt Acknowledged: DISTRIBUTION: · t e' Atask'a-Oil'~' ~-~s Cons, Anchorage D&M Drilling Franzen Chevron BP Unocal State of Alaska Mobil SAMPLE TO: State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle OPERATOR: Arco TRANSMITT DATE: October 30, 1989 AIRBILL #: n/a AFT#: n/a CHARGE CODE# NAME: KRU 2K-11 SAMPLE TYPE: dry ditch SAMPLES SENT: NUMBER OF BOXES: 2 boxes 3000 - 5250 5250 - 6876 SENT BY: TERESA GORUP UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THiS FORM TO: ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: ABV-100 RECEIVED BY: · Anchorage KUPARUK ENGINEERING TRANSMITTAL # 1311 TO John Boyle - State FROM: Ken Griffin/P. S. Baxter DATE: October 25, 1989 WELL NAME: KRU 2K- 11 CONFIDENTIAL TRANSMITFED HEREWITH ARE ONE COPY OF THE FOLLOWING: One copy of Sidewall Core Report Depth 1592' - 2249' PLEASE RETURN RECEIPT TO: RECEIPT ACKNOWLEDGED: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1269 P. O. Box 100360 Anchorage , Alaska 99 r~ ~'-- ~- ~ ~..~ ~ r,., ./7 October 6, 1989 State of Alaska Sidewall Core Report Well: ARCO 2K-11, KRU APl: 50-103-20114-00 LOCATION' Sec.2, T10N,R8E, 48' FSL, 94' FEL Detail: Depth 1592 16O3 1715 1725 1874 1933 1951 1976 2O98 2106 2110 2118 2126 2130 2150 2176 2177 2178 2193 2247 2248 2249 45 shot gun, 1 misfire, 44 recovered Description Sandstone, porous Sandstone, porous Sandstone, porous Sandstone, porous Sandstone, Sandstone, Sandstone, Sandstone Sandstone, Sandstone Sandstone Sandstone Sandstone Sandstone, Sandstone, Sandstone Sandstone, Sandstone Misfire porous porous porous porous porous porous porous porous porous porous porous porous, porous, porous, oil-saturated oil-saturated oil-saturated Sandstone, porous, oil-saturated Sandstone, porous, oil-saturated Sandstone, porous, oil-saturated JTE-jiz/2o3 2252 2254 2256 2258 2301 2317 2319 2322 2325 2326 2327 2329 2349 2365 2369 2421 2422 2423 2424 2474 2580 2746 2833 J. T. Eggert Geologist Kuparuk Geoscience Sandstone Sandstone Sandstone Sandstone Sandstone, Sandstone, Sandstone, Sandstone Sandstone Sandstone Sandstone Sandstone Sandstone Sandstone Sandstone Sandstone, porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous, oil-saturated porous porous porous, oil-saturated porous, oil-saturated porous, oil-saturated Clay, porosity nil Sandstone, porous, oil-saturated Sandstone, Sandstone, Sandstone, Sandstone, porous, oil-saturated porous, oil-saturated porous, oil-saturated porous ARCO Alaska, Inc. Date: October 18, 1989 Transmittal #: 7574 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ~-' 2K-11 2K-13 OH Edit Tape and Listing OH Edit Tape and Listing OH Edit Tape and Listing Please acknowledge receipt and return 9-18-89 #73482 9-29-89 #73498 1 0-6-89 #73509 Receipt Acknowledged' DISTRIBUTION: ~ 0il & Gas Cons. Commission Anchorage Craig Suchland State o~A-ffiska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend _ 5. Type of Well: Development Exploratory Stratigraphic Alter casing _ Repair well Change approved program _ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 . .Service 4. Location of well at surface 46' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1246' FNL, 931' FEL, Sec. 11, T10N, R8E, UM (approx) At effective depth 1273' FNL, 941'FEL, Sec.11, T10N, R8E, UM (approx) At total depth 1286' FNL, 993' FEL, Sec. 11,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured 6870' feet (approx) true vertical 6541 ' feet Plugs (measured) None RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-11 9. Permit number 89-93 10. APl number 50-103-20114 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 6775' 6434' feet Junk (measured) feet None 13. Casing Length Size Structural 8 0' 1 6" Conductor Surface 2962' 9 5/8" Intermediate Production 68 2 0' 7" Liner Perforation depth: measured · None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Attachments Description summary of proposal Cemented Measured depth True vertical depth 1 15' 1 15' 9O0 Sx AS III & 2997' 2949' 375 Sx Class G 225 Sx Class G 6854' 6509' RECEIVED OCT 1 ? dm 0il & Gas Gon Detailed operation program BOP sketch 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved 15. Status of well classification as: Oil X Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Vo.~.~.. --~ ~,..~-? Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test m Subsequent form require . ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 JApproval No. - ,,~ I.,.:,~pprovod~:,.'o~y / R.~turncd Date /D "'/~-' :~ SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. County. parish or borough DistrictField ARCO ALASKA INC. Lease NORTH or Unit SLOPE, ALASKA KUPARUK ADL: 25588 ALK: 2674 Auth. or W.~KO3O668 Tit e DRILLING 2K-11 Jwell no. Operator ARCO S pu dde d o r_W_..O.,..beg un~FUU jOate 09/10/89 IH°~4 300 ~°. ~v~33 IPrior status f a w,o. Date and depth as of 8:00 a.m. 09/10/89 ( 1) TD: 228'( 228 SUPV:CD 09/11/89 (2) TD: 2534'( 2306 SUPV:CD 09/12/89 (3) TD: 3017' ( 483 SUPV:CD 09/13/89 ( 4) TD: 3233'( 21( SUPV:CD 09/14/89 (5) TD: 5349'( 211( SUPV:TWM 09/15/89 (6) TD: 6515'( 116( SUPV: TWM 09/16/89 (7) TD: 6579'( 64 SUPV:TWM Complete ~)(~%~r ~_a~h day reported DRILLING MW: 8.6 VIS: 98 MOVE AND SPOT RIG OVER 2K-11. NU DIVERTER SYSTEM. MU BIT AND FUNCTION TEST DIVERTER. SPUD WELL 0430 9/10/89. ROTARY DRILL 115'-228' DAILY:S23,150 CUM:$23,150 ETD:S23,150 EFC:$1,700,200 DRILLING MW: 9.3 VIS: 92 REPAIR RIG CONVEYOR CHAIN. RESUME DRILLING 228'-1971'. CIRC BOTTOMS UP AND TOH FOR BHA. KICK WELL OFF AND DRILL AND SURVEY 1971'-2314'. TOH FOR MWD FAILURE. TIH AND CONTINUE KICKOFF 2314'-2534'. DAILY:S69,751 CUM:$92,901 ETD:S92,901 EFC:$1,700,200 TIH FOR CLEANOUT MW: 9.4 VIS: 89 CONTINUE DRILL AND SURVEY 2534'-3017'. CIRC BOTTOMS UP AND MAKE SHORT TRIP,OK CIRC BOTTOMS UP AND TOH, LD MOTOR AND MWD. RU SCHLUMBERGER AND RUN LOG 1, DIL/LDT/CNL/GR/SP/CAL 3005' TO SURFACE. RUN LOG 2 SHEAR WAVE SONIC, 2950'- SURFACE. RUN 3 SWC, 2833'-1592', SHOT 45, 1 MISFIRE, RECOVERED 44. RD SOS. MU BHA WITH HOLE OPENER AND TIH. DAILY:S58,315 CUM:$151,216 ETD:S151,216 EFC:$1,700,200 DRILLING MW: 8.4 VIS: 29 MADE COND TRIP. RAN 9-5/8" 36# J-55 BTC TO 2997'. CMT'D CSG W/ 900 SX AS III LEAD AND 375 SX CL G TAIL. ND DIVERTER AND INSTALL BRADENHEAD. NU AND TEST BOPE. DRILL OUT AND PERFORM PIT=12.5 PPG EMW. DRILLED TO PD. DAILY:S231,325 CUM:$382,541 ETD:S382,541 EFC:$1,931,525 DRILLING MW: 9.0 VIS: 31 DRILL 3233-4906. SURVEY, CIRC AND PUMP DRY JOB. TOH TO SHOE. CCM. RUN LEAK OFF TEST TO 10.8 PPG EMW. TOH. CHANGE TOP STAB ON TURBINE. CHANGE BIT AND ORIENT MWD. TIH DRILL 4906-5349. DAILY:S71,641 CUM:$454,182 ETD:S454,182 EFC:$1,700,200 CONDITION MUD FOR CORE MW:10.3 VIS: 45 DRILLED TO 6015'. ST. PERFORMED PIT=10.8 PPG EMW. DRILLED TO PD. CIRC PRIOR TO CORING. DAILY:S84,957 CUM:$539,139 ETD:S539,139 EFC:$1,700,200 TOH W/CORE 1 MW:10.3 VIS: 50 DROP SURVEY AND TOH TO SHOE. ClRC AND COND MUD AND PERFORM LEAK OFF TEST TO 10.8 PPG EMW WITH NO LEAK OFF. CONTINUE OUT OF HOLE, CHANGE BHA AND PU CORING EQUIPMENT. TIH TO SHOE AND CIRC BOTTOMS UP. STAGE IN TO HOLE AND SPACE OUT TO CORE. CUT CORE 1 6519'-6579'. CIRC BOTTOMS UP AND BEGIN TOH. The above I orrect '.~ DAILY: $75~ 470 CUM:S614~ 609 Signature{ / ~ _ JDate JTitle ' ' ' ~ ' For form preparatio~d'distribution~ see Procedures Man~, Section 10, -- Drilling, Pages 86 and 87. ocr 17 lffi Oil & Gas C0n . C_0malssiq[ .. · - JNumber all daily wall hlstow , ........... tively chOmgei'" they are prepared, ..... . well. Page no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field KUPARUK Date and deptl3 as of 8:00 a.m. 09/17/89 ( TD: 6669'( SUPV:TWM I County or Parish ARCO ALASKA INC. NORTH SLOPE, ALASKA Lease or Unit I ADL: 25588 AKL 2674 Complete record for each day while drilling or workover in progress DO¥ON 14 8) 9~) 09/18/89 ( 9) TD: 6870'( 20 ) SUPV:TWM 09/19/89 ( TD: 6870'( ) SUPV:TWM 09/20/89 ( 11) TD: 6870 PB: 0 SUPV:TWM State AK 2K-11 MU ROTARY BHA MW:10.3 VIS: 48 CONTINUE TOH W/ CORE 1, CUT 60', RECOVERED 60'. CHANGE BITS AND TIH TO SHOE. CIRC BOTTOMS UP AND CONTINUE IN HOLE. CIRC AND WASH TO BOTTOM AND CUT CORE 2, 6579'-6639'. CIRC BOTTOMS UP AND TOH. LD CORE 2, CUT 60', RECOVERED 50'. REDRESS CORE BARREL AND TIH TO SHOE. CIRC BOTTOMS UP AND CONTINUE IN HOLE. WASH TO BOTTOM AND CUT CORE 3 6639'-6669', BARREL JAMMED. TOH W/ CORE 3. LD CORE AT REPORT TIME. START MU BHA. DAILY:S57,011 CUM:$671,620 ETD:S671,620 EFC:$1,700,200 RUNNING LOG 1 MW:10.4 VIS: 38 MU BHA AND TIH TO SHOE, BREAK CIRCULATION AND CONTINUE IN HOLE. BROKE CIRC AT 5280' AND CONTINUE TO BOTTOM. REAM CORED INTERVAL 6485'-6669' AND BEGIN DRILLING NEW HOLE. DRILLED TO 6672' AND LOST 300 PSI. TOil AND FOUND WASHOUT 3 STANDS IN. LD JOINT AND TIH. CONTINUE DRILLING 6672'-6870'. CIRC BOTTOMS UP AND MAKE SHORT TRIP. CIRCULATE WELL CLEAN AND SPOT PILL ACROSS FORMATION. TOH AND RU SCHLUMBERGER. BEGIN LOG 1, DIL/FDC/CNL/GR/SP. DAILY:S93,111 CUM:$764,731 ETD:S764,731 EFC:$1,700,200 RIG DOWN SCHLUMBERGER MW:10.4 VIS: 42 CONTINUE LOGGING RUN 1 DIL/FDC/CNL/SP/GR. RUN 2, SHEAR WAVE LOG. RUN 3 SONIC DIGITAL. RUN 4 LDT/ML. RUN 5 SWC, SHOT 45 RECOVERED 41. RD SOS. DAILY:S136,253 CUM:$900,984 ETD:S900,984 EFC:$1,700,200 CIRC 7" CASING 7"@ 6855' MW:10.4 WBM MU BHA AND TIH. WASH AND REAM TO BOTTOM AND CIRC BOTTOMS UP. MADE 15 STAND SHORT TRIP WITH NO PROBLEMS. CIRC BOTTOMS UP, SPOT PILL AND TOH LDDP. RU AND RUN 160 JTS 7", 26~, J-55 BUTT CASING. CIRC 7" CASING AND PREPARE TO CEMENT. DAILY:S130,532 CUM:$1,031,516 ETD:S1,031,516 EFC:$1,700,200 / ECEIVED OCT ! ? 1989 Oil & 8as Cons, Commissi0 A chorage Well no. The above is correct For form preparation ~n~ distribution see Procedures ManuEl-Section 10, Date Drilling, Pages 86 and 87 ' AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used ~or reporting the entire operation if space is avadable. A; ruling cost center code District ARCO A'r,AsY~. INC. County or Parish Lease NORTHor Unit SLOPE, ALASKA KUPARUK ADL: 25588 AKL 2674 2K-11 T t e DRILLING State Well no. Auth. or W.O. no. AK3668 Operator A.R.Co. W.I. [Total number of wells (active or inactive) on this J~q. CO 55. 8533 Icost center prior to plugging and J abandonment of this well Spudded or W.O. begun Date IHour I Prior status if a W.O. SPUD 09/10/89 ! 04300 Date and depth Complete record for each day reported as of 8:00 DOYON 14 09/21/89 (12) TD: 6870 PB: 6775 SUPV:CD RIG RELEASED 7"@ 6855' MW:10.4 NaC1 CONTINUE CIRCULATING 7" CASING. DID NOT RECIPROCATE DUE TO LOST RETURNS AND STICKY HOLE. RU DOWELL AND CEMENT WELL AS FOLLOWS: PUMP 10 BBL CW 100, TEST LINES TO 3500 PSI, PUMP 35 BBLS SPACER 3000 AND CEMENT WITH 225 SX(45 BBLS) CLASS G WITH ADDITIVES @ 15.8 PPG, DISPLACE WITH 261BBLS 10.4 PPG BRINE. BUMPED PLUG WITH 3500 PSI AND TEST CASING, OK. RELEASED PRESSURE, FLOATS HELD OK. PU STACK AND SET SLIPS. CUT OFF CASING AND NU TUBING SPOOL. TEST PACKOFF TO 3000 PSI, OK. FREEZE PROTECT ANNULUS WITH 70 BBL DIESEL AND RELEASE RIG @ 1530 9/20/89. DAILY:S59,428 CUM:$1,090,944 ETD:S1,090,944 EFC:$1,700,200 RECEIVED ocr t 19119 . ,.¢,s~ 0ii & 6as ConS. ~omml,ss~'. Old TD Released rig New TD PB Depth Date Kind of rig Classifications (oil, gas, etc.) Producing method Potentia~ test data Type completion (single, dual, etc.) Off c a reserve r name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The. above i s,.~, rect.) T~ , Drilling, Pages 86 and 87. AR3B-459-3-C JNumber all daily well history forms consecutively I Page no. as they are prepared for each well. I Division of AllanticRichfleldCompany ARCO Alaska, Inc. Date: October 6, 1989 Transmittal #: 7574 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith is the following item. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 1 Field Copy Tape 9 - 1 8 - 8 9 # 7 3 4 8 2 Receipt Acknowledged: DiSTRiBUTiON: ............................. Date: · "maska- / -&-Gas Cons. C0mmiss[0f Anchorage Craig Suchland State of Alaska ARCO Alaska, Inc. Date: September 29, 1989 Transmittal Ct: 7571 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO- 1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 I 2" MWD Resistivity Gamma 9 - 1 0 - 8 9 3 01 7- 651 5 2 K - 1 1 5" MWD Resistivity Gamma 9 - 1 0 - 8 9 3 01 7- 6 51 5 2K-1 1 2" Dual Induction- SFL '- 9-1 8-89 2999-6840 2K-1 1 5" Dual Induction- SFL ~ 9-1 8-89 2999-6840 2K-11 2" and 5" Raw FDC "--- 9-18-89 6290-6816 2K-11 5" Cyberlook ,~---' 9-18-89 6300-6750 2 K - 11 2" and 5" Porosity Litho-Density/ 9 - 1 8 - 89 6290 - 6830 2 K - 11 2" and 5" Porosity FDC f 9 - 1 8 - 89 6290 - 6816 Receipt Acknowledged: taska Gas Cons. Corem%ss - (iii & Anchorage DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnson) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: September 22, 1989 Transmittal #: 7565 RETURN TO: ARCO Alaska, Inc. Attn: Brianna Knettle Cpf-3 Eng. Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 11 5" Dual Induction 9 - 11 - 89 113- 3003 2 K - 11 2" Dual Induction 9 - 11 - 89 113- 3005 2K-11 Cyberlook 9- 1 I -89 1500-2950 2K-11 CNL Porosity 9-11 -89 113-2976 2K-11 CNL Raw Data 9-11 -89 113-2976 2 K - 12 5" Dual Induction 9 - 08 - 89 1000- 7088 2 K - 12 2" Dual Induction 9 - 08 - 89 1000- 7088 2K-12 Cyberlook 9-08-89 6480-7050 2K-12 CNL Porosity 9-08-89 6480-7064 2K-12 CNLRaw 9-08-89 6480-7064 Receipt Acknowledged: DISTRIBUTION: i-.,.,~. '.~-, · Anchora?? NSK D&M Drilling Franzen State of Alaska(+sepia) L. Johnston(vendor package) M E MORAN Du M State Alaska ALAS~Jk OIL A~D GAS CONSERVATION COMMISSION TO:' Lonn.ie C. Smit~<>~, ,ATE: September 20, 1989 Co~zs s ioner FILE NO: D. BDF. 098 THRU: FROM: TELEPHONE NO: Michael T, Minder '~.~~, SUBJECT: St. Petroleum Engineer Bobby D. Foster!~: .~~. Petroleum InspeCtor BOP Test AAI KRU 2K-11 Permit No. 89-93 Kuparuk Rv Field Tuesda~r !2, 1989, The test began~at 10:00 pm and was ~}sneiu~B-0--~i~i-~--Wf-~he attached BOP test report shows there was one failure. The stem packing in this valve will be replaced, tested and the AOGCC office or I will be notified. In summary, I witnessed the BOP Test AAI's 2K-11. Attachment ~er 18, 1~989, 'I spoke with Jim Spaulding, Doyon tool ~~that the parts to repair the leaking valve were ordered and should be on location in 2 to 3 days. He will notify the AOGCC office when work is complete. 02-001A (Rev. 8/85) General housekeeping Z~ Reserve pi t ~// STATE OF ALASKA MUD SYSTEMS: Visual Trip tank Pit gauge F1 ow monitor Gas detectors ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report BOPE STACK: Annular preventer Pipe rams Blind 'rams Choke line valves HCR valve Kill line valves Check valve Rig Audio Test Pressure DATE Representative ~ Permit # &¢- ~.~ ACCUMULATOR SYSTEM ft Full charge pressure Press after closure psi g Pump incr clos press 200 psig -- min ¢~7 sec Full charge press attained ~ min 2~ sec Controls: Master ~~ Remote~ Blind switch cover~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly / / Lower Kelly Bal 1 type Inside BOP Choke manifold ¢¢~.~ Test pressure Number valves Number flanges Adjustable chokes / Hydraulically operated choke / Test pres sure _.~¢~?~f~O Test pressure &OO/~*~',¢~ , Test pressure ~¢~/~¢"72 TEST RESULTS: Failures Test time ~ hrs Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. days Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) September 7, 1989 Telecopy: (907)276-7542 P. J. Archey Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 Kuparuk River Unit 2K- 1 t ARCO Alaska, inc. Pe~it No. 89-93 Sur. Loc. 46 ' FSL, Btmho!e Loc. 1359' FNL, 94'FEL, Sec. 2, T10N, RSE, UM. 974'FEL, Sec. 11, T10N, R8E, UM. Dear Mr. ~chey~ Enclosed is the approved application for pemit to drill the above referenced well. The permit to drill does not exempt you from obtamning additional pe~its required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this ofiice 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before =he surface casing shoe is drilled. Where a diverter system is required, please also notify this o~fice 24 hours prior to comme~cing equipment i~stallation so that the Commission may witness testing before_drilling below ~he shoe of the conductor pipe. ~r~ ?rul~ yours, C. V. Charriton Chair~n of Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE COPR~iI$SiON dif Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Departmen~ of Environmental Conservation w/o enci. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC...,VIlSSION PERMIT TO DRILL la. Type of work Drill Re-Entry 2. Name of Operator ARCO Alaska~ Inc. 20 AAC 25.005 Redriil ---t lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Deepenr-I Service _- Developement Gas ~ Single Zone ,~ Multiple Zone 3. Address P.O. Box 100360, Anchorage, AK 99510 5. Datum Elevation (DF or KB) 10. Field and Pool 4. Location of well at surface 46' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval (~ target) 1320' FNL, 950' FEL, Sec. 11, T10N, R8E, UH At total depth 1359' FNL~ 974' FEL, Sec. 11, T10N, R8E, UN 12. Distance to nearest I 13. Distance to nearest well property line I 2K-10&2K-12 Conductors _~97_!' at Tn feet ~, ~ ~,,~.~. feet 16. To be completed for deviated wells feet Maximum hole angle34 0 Kickoff depth 207 18. Casing program size Hole Casing 24" 16" 121¢' 9-5/8 8½" 7" o , RKB154' ,Pad 118'GL feet Property Designation ADL 25588 ALK 2674 Unit or property Name Kuparuk River Unit 8. Well number 2K-11 , Approximate spud date 9/24/89 14. Number of acres in property 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 1 661 psig At total deoth CrVD)~I 71 ' Kuparuk River Field Kuparuk River Oil Pool 11. Type Bond (see 20 AAC 25.025) Statewi de Number U630610 Amount $200~000 15. Proposed depth (MD and TVD) 6809' MD 6466 ' TVD feet psig Specifications Weight J Grade J Coupling J Length 2.s# IH- O I 180. l J-ss I BTC J 2931 ' I 2 .o, iJ.2%! BTC j 677s' MD 35 35 34 Setting Depth Top Bottom I TVD ! MD TVD 35' I 115 115' 35' J 2966 2934' i 34, i6809 6466' I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Quantity of cement (include stage data) ±200# CF 6755x A5111 360sx Class G 200sx Class G tail Top of G 500' above Kuparuk Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth True Vertical depth RECEIVED AUG 2 8 989 Alaska 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program ~r Drilling fluid program [~' Time vs depth plot ,~1 Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Y4~_,~ -_'-~~,~_~.. Title Area Drilling Engineer ¢ Commission Use Only PD1/8 (TWM) Number ! APl number J Approval date J Permit? _ ~,,~ 50-- /~ 3 "Zo//¢/ 09 / 07 / 8 9 Conditions of approval Samples required ~_Yes [] No Mud log require.d g Yes ,~'No Hydrogen sulfide measures [] Yes ~ No Directional survey required .,,~i~'Yes [] No Required working' pressure for. BOPE]_I-12M; ~ 3M; [] 5M; [] 10M; [Z] 15M . '"-) by order of Fo rmApproved10-401bYRev( ~ ,. ~',.t"r~ "~ , (_.~~,~,~-~ ' Commissioner the commission See cover letter for other requirements Date ~//~' , Submit I~ trilClicate Date ARCO ALASA. I n e · · .'-]'~x Ped 2K. Wel I No' ll Rev~eed Propoeel Kuparuk Field, North Slope, Alaeka 0 . RI(B ELEVATION, 154' rtl 1000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 B/ PERHAFROST TVD:1424 T/ UGNU SNDS TVD--1544 KOP TVD=207'2 TMD=20?2 DEP=O T/ W SAK SNDS TVD=2163 TMD=2163 DEP=2 9 BUILD 3 DEe 15 PER 1 O0 FT 21 B/ W SAK SNDS TVD=2734 THD--2748 DEP--118 EOC / 9 5/8' CS(3 PT TVD-2934 THD--2966 DEP-'-206 K-lO TVD--3181 THD=5243 DEP=330 HAX[HUH 26 DEG ANGLE 49 MI N K-5 TVD=4573 THD=4803 DEP=1034 RECEIVED 24 BEGIN ANGLE DROP TVD=4950 TMD=5225 OEP=1225 21 DROP 1.5 DEe PER 100 FT 15 AUG 2 8 I989 Alaska Oil & Gas Cons. Commisslon Anchorage 12 END ANGLE DROP TVD=6010 THD=6346 DEP=1577 T/ ZONE C TVD=6110 THD=6448 DEP=1595 T/ ZONE A TVD=6143 T~D=6482 DEP=160! TARGET CNTR TVD=6206 THD=6545 DEP=1612 B/ KUP SNDS TVD=6269 THD=6609 DEP=1623 TD (LOG PT) TVD=6466 THD=6809 DEP=1658 I 1 000 , TARGET ANGLE 2000 1 0 DEG VERTICAL SECTION HOR ~ONTAL PROU~CT[ON o,.;ALE 1 IN. ~ 1000 FEET ARCO ALASA, !ne. Pad 2K, Well No, 11 Revised Propoeal Kuparuk Field, North Slope, Aleeka z o 1 000 m 1 000 _ 2000 _ :3000 . ;)000 2000 I WEST-EAST 1 000 0 I I SURFACE TARGET LOCATIONs 1320' FNL, 950' FEL SEC. 11, TION, RSE 1 000 SURFACE LOCATION~ 4.6' FSL, 94' FEL SEC. 2. TION. RSE TAROET CENTER TVD-6206 TMD-6545 DEP-1612 SOUTH 1366 WEST 856 TD LOCATIONs 1359' FNL. 974' FEL SEC- 11. TION. RSE S 32 DEO 4 HI N 1,4 161 2' (TO TARGET) 25O ,,~ 2OO 150 100 0 50 250 200 150 100 50 0 50 100 500 5OO '""'-1.5..00 O0 ,00 ~00 1100 / l / / / / t t / / / I · '" 27O0 -1-1...0~0 500 · 500 / 1 900 ~';~500 50O' ~ 500 /~ soo / ~,5.00 ! ~.1oo 2500 / / / / / ,7oo "3,300 ~,2_~00 RECEIVED / / / / .., .....- · soo AUG 2 81989 · --- A,'aska Oil & Gas Cons. Commission ~' 29~0.~ "" "50Q. Anchorage -- "'," . --,=o_ .. b I' '~ I ' I ....... ! ' " I 250 200 1 50 1 O0 50 0 250 2OO J 150 _ 100 _0 x~ 1 O0 i _ 150 DRILLING FLUID PROGRAM (2K-11) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.8-9.0 8.7-9.2 9.8 PV 15-30 5-15 1 1-16 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 1 5- 3 0 4 - 8 5 - 1 2 APl Filtrate 10-15 10-20 6 pH 9- 1 0 9.5-10.5 9.0-1 0.5 % Solids 10 +/- 4-7 12-15 Drillino Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Note~: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest wells to 2K-11 are 2K-10&12. These wells are 25' away at surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. G~EI~KL DRILLING PROCEDUP. E KUPARUK RIVER FIELD DEVELOPNE~Ff ~ELLS WITH SUP~FACg HOLE LOGS AND KUPARUK CO~ES 1. HIRU. 2. Install ~4C diverter system. 3. Drill 12¥' hole to 9-5/8" surface casing point according to directional plan. &. Run span hole logs ~hroush surface hole (West Sak) per well plan. 5, Run a~d cement 9-5/8" casing, 6. Install and ~esc BOPE. Teo~ casing co 2000 psis. 7. DF~ ou~ cement and ~0' uev ho~e. ~erfom lea~ff ~es~. 8. Drt~ 8¥* ho~e co core po~u~ according co direc~ioua~ p~au. 9. Core Kupa~k sands as specified ~n ve~l phn. ~h coring complete, continue dri~ius ~'* hole ~o loggias point coca~ depth. Leave ~00' be~veeu PB~ and base of Kupa~k Sands. Il. ~un open hole loss per veil p~au. ~2. ~un and cemeu~ 7' casing. Pressure Ces~ ~o 3500 psis. 13, Do,squeeze arctic pack and ceueu~ in 7' x 9-5/8" a~ulus. ~ ~PE and install ce~oraw Xus tree. 15. Secure veil and re~ease rig. ~un cased hole loss. 17. Hove ~n vorkover r~S, ~ BOPE. 18, PU 7" casing scraper and ~ubinS, TIH Co PB~. Circulate ho~e v~ch c~ean brine and TOH 8~and~ns cubans back. Perforate and run completion asse~y, se~ and ~esc packer. 20. ~ BOPE and tnsua~ ~s ~ree. Change over co dtese~. 22. F~ov ve~ co tanks. Shu~ ~n, 23. secure veil and re~ease Fracture MUD CLEANER LVr~l~h SHALE SHAKERS 8TI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16- 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEI~ VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.03S(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 .7 6 im D]~ #1 I~-r-~/8· ~ PS] Ft~RRA ~ 5TACK I. 16" - ~ ~I T~ ~l~ ~ 4. i~/a- - ~ ~l ~I~ ~ KI~ ~ I~e"-~~I ~E~~I~~~T~. AOCLM.LATOR CAPACITY TEST I. CI.~O( ~ FILL ~TCR ~]R TO ~ LEVEL WITH ~]C FLUID. I~ ~] ~~ ~ T~ ~~T~. 3. ~ T]~ T~~ ~ ~ ~T~~Y 4. ~~~ ~ ~. ~ ~~ L~ LI~T IS 45 ~~ ~I~ ~I~ ~ I~ ~I ~I~ 5 I::~-ra/8' Bi~ STACK TEST I. FILL ~ ST/Il:l( DIESEL. 2. CI~CK THAT aLL ~LY ~~ ~T ~ ~l~ JT LI~ V~ ~ 4. ~~ ~ TO ~~TO~~Z ~~~ ~0~ ~D ~~ TO 0 ~. LZ~ V~ ~ T~ ~ K]~ ~ ~ L]~ ~ ~ TO~~] ~~~ ~ ]N~4. 7. ~Z~ ~~ 8. ~ TCP PIl:~ ~ AN3 CL,CE~ BOTTIIM Pll~ ~ TE~T BOTTCM Pll:~ ~ TO 2~0 P~I ~ 30(10 PSI. g~ ~ BOTTOM PIFI~ ~ BA(X OlJ'r ~ J'r AM) I0. CLO~E: BLII~) R.Nv~ AM) ~ TO 2~0 I="~l ~ 30C0 PSI. MN~FI3.D AN3 LII~.S ARE FI.I.Z. C~' ~ING FLUID, SET ALI. VN.VI~ IN DRILLIN~ Pi~ITICI~ 12. ~r STANDPIPE VALVE~, ~Yo KB.I.Y CCX](~ DRILl PIPE SAFETY VALW., AN3 I~I[3~ Blip TO 250 PSI a~) ~330 PSI. F~ SIGN, ~ ~ TO []~ILLIN~ 5M:~.RVIS~R. ~.B<LY THS~~ ~LI~'TICNN. LY Cl:f;~]~ ~ ~ I ~,. 5100~400 ~ ARCO Alaska, Inc. Post Office Box ~003§0 ^nchorage, Alaska 99510--0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat (Wells 1 - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for any questions, please call me at 263-4618. Si ncerely, - 2K the Pad / / subject wells. If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & Gas Cons. C0mmissi01] Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldC~)mpany ~.~ . ~ SECTION 2, T I0 N.~ R. 8 E., s~ ~1 UMIAT UERIDIAN. ~ SECTION II,~ION., R. 8 E., ~ ~ ~THIS ~ UMIAT MERI DIAN. , N.TS. t:~ ; ~ ~URV~ SECT~O~ a ~t~ SECtiON ~ ~RACTED ~tes: vICI ~ITY MAP I"= ~ ~4~ SECTION CORNER ~ tl ~ I. CO0~INATES ARE ~SE ZONE 4. I sEcr~o~ ~ te:~9 SECT~O~ ~ ~. ALL DISTANC~ SHOWN ARE TRUE. . ~[t 3. ELEVATIONS ARE B.P.M.S.L. ~Z:~S 4. O.G. ELEVATIONS FROM CED- RIXX-331 I, re~4. RECEIVED o. .ONUM . S PI. S / DEC 1 S 1988 s'58REFERENCE, ~9, 65 B 66.FIELD BOOK: L 88-~, p~. 55,56, Welll ,y ASP's , AlaS) a Uil & GL~s Dun:;. ~ ............ DiSt Dist. O.G. ~d ~. ~ ' X' ~)~ ~NGITUDE F.S.L. EEL. Elev. Elev. I 5,938,600.18 498~310 17 ~ 70014'36 519 150°00'49.133'' 296 94 114.0 118.5 ' ~ ' i 2 5,938,575.1~ ~ 498~310.A8 ~ 70° 14' 36.273" 150°00'49.130" 271 113.9 ~! II , 5,938,550.30 498,310.35 ~ 70°14,36.029" 150°0~:49.1}:,, 246' ,,3.0 4 5~938,525.46 498,310.06 ' 70°1 35.784" 150°0 49.1 2~' 113.8 II II , 5 i 5,938,500.19 498,310.12 i 70°1~',3 .536 150o00'49.154 196' 113.8 I 6 ~ 5,938,475.14 498,310.33 ~ 70°1 3 .289" 150o00'49.128'' 171' 113.8 4'35.046" ~ 150000' . . 7 ~ 5,938,450.36 ~ 498,3t0.36 ~ 70°14, ~ 150o00,4AI27" ' 146' i 113.8 8 i 5,938,425.30 498,310.18 70°14, 34.799" i 49.132" 121', 113.8 ,o, oo, , 0oo : I I { 5,938,350.22 498,310.14 70°14' 34.061 " 150°00'49.133'' ) 46' i 113.9 12 i 5,938,325.20 498,310.17 70Ol4'33.815" 150°00'49.131" ~ 21' 94' 113.9 118.5 m ' ~ EN.L I . 69' 94' 13 i 5,938,235.31 498,310.37 70°14'32 930" 150°00'49.125" 113.7 118.5 '14 ) 5,938,210.14 498,310. t6 70Ol4'38.683" 150°00'49.131" 94' ) 113.7 il5 5,938,185.1Z 498,310.16 70°14'32.437'' 150°00'49.131" ) 119' 113.8 16 5,938,160 II 498 310.20 70°14,32.191" 150°00'49.130" 144' 113.8 17 5,938,135.21 498,310.18 70°1 31.946" 150o00'49.130" , 169' ~ m 115.9 t9 5,938,085.20 498,310.27 70014'31.454" 15000 49.127" 21 114.0. 20 5,938,060.14 498,310.22 70°14'31.207" 150°00'49.128" ~ 244' 114.1 21 5,938,035.16 498,310.16 70°14'30.962" 150°00'49.130" ~) 269' ~' 114.0 22 5,938,010.40 I 498,310.19 70o14, 30.718" 150°00'49.129" 29~ 94' 114.0 23 5,937,985.32j 498,310 13 70°!4'30.471" 150°00'49.130'' 31~ = 95' m 114.0 ~4 ~t~7~80.~ 4~8~10.08 70°14~0.~5 I~0°00 4~.1~" ~4' I ~' I 11~.9 ~ I1~.~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ~ ,. ~ ". ~ $ r' - mi : ' ~' ,N ARCO A ska. 3TATE OF ALASKA AND THAT THIS ~..,,,,, ................... ~ ' ' BY ME OR UNDER MY DIRECT SUPER- · · VISIONAND OTHERAND DETA,LSTHAT ALLARED,M[NS,ONSco.R~CV ',~.... ~.,~, .....~;. CONDUCTOR AS-BUILTS , Dole Deacr/p~/'o~ '' ~fe.'11/21/88 I~f.~o. NSK6.211.d4 J m m i iNm imm ~ m m ~m, mm m mil m m mm Well1 ,y ASP's , , A~asi a uil & ~:~ Oun:;. G0,s':,,~:sc:c,". DiSt. Dist. O.G. Pad No. ' X I_~l~dD~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,310.17 70°14'36.519 " 150°00'49.153" 296' 94' 114.0 118.5 ! 2 5,958,575.14 498,310.Z8 70° 14' .36.273" 150°00'49.130'' 271 113.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.128" 246' 113.8 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49. 136'' 222' 113.8 5 5,9 $8,500.19 498,310.12 70° 14' 35.536" 150°00'49.1:54'' 196' I 1:5.8 6 5,9:58,475.14 49 8,310.3:5 70o14'35.289" 150°00'49.12:8'' 171' 11:5.8 4' 35.046" 150°00' 49.127'' 146' i I 1:5.8 7 5,938,450.:56 I 498,:5t0.36 70° 14, , 8 5,9:58,425.:50 498,:510.18 70o14, 34.799" 150°00' 49.1:52'' 121' 11:5.8 9 5,9:58,400.30 ) 498,:509.98 70014,34.555" 150 °0~: 49.1:57'' 96' , 11:5.8 I0 5,958,:575.19 498,510.14 70°! 34.:506" 150°0 49.1:53" 71' : 11:5.9 I I 5,9:58,:550.22 498,:510.14 70°14' :54.061 " 150°00'49.1:53'' 46' i 11:5.9 12 5,9:58,:525.20 498,:510.17 70Ol4'3:5.815'' 150 °00' 49. 1:51'' 21' 94' 11:5.9 118.5 FN.L 1:5 5,938,235.:51 498,310.:57 70°14'32.9:50'' 150°00'49.125" 69' 94' 113.7 118.5 14 5,938,210.14 498,310. t6 70 °14' 3Z.683'' 150°00'49.151" 94' 113.7 15 5,938,185.1Z 498,310.16 70o14'32.43?" 150°00'49.131" 119' 113.8 16 5,938,160.11 498, :510.20 70Ol4' 32. 191'' 150° 00' 49. 1:50'' 144' 11:5.8 17 5,938, 1:55.21 498,:510.18 70°14' :51.946" 150°00' 49.1:50'' 169' ' 115.9 18 5,938, !10.19 498,:510.29 70014' :51.700" 150000'49.127'' 194' 114.0 t9 5,9:58,085.20 498,:510.27 70014' 31.454" 150°00'49.127'' 219' 114.0. 20 5,938,060.14 498,310.22 70Ol4':51.207'' 150°00'49.128'' 244' 114.1 21 5,9 38,035.16 498,310.16 70o 14' 30.962'' 150° 00'49. 1:50'' 269' ,, 114.0 22 5,938,010.40 I 498,:510.19 70014, :50.718" 150°00'49.129" 2904: 94' 114.0 2:5 5,937,985.32j 498,:510 13 70°!4':50.471" 150°00'49.130'' 31~ 95' 114.0 · Il * I 24 5)9:57,960.29 498,:510.08 70Ol4':30.225 150°00 49.152" :544' 95' I 11:5.9 118.5 CHECK LIST FOR NEW WELL PERMITS Company ~rc_rD_ Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee _~P~ ~/zg,//~? 1. Is the permit fee attached .......................................... ~ -- (2) Loc thru (8) (3) Admin~.~-~ . ~ 9. (9 thru 13) 10. (10 a~d 13) 12. 13. (4) Cas~ ,~//r~.~,x?~,,//~, c2_~_3,~7 (14 thru 22) (5) BOPE ~,~-i~'~ (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ............... ' . .... 2. Is well to be located in a defined pool ............................. ..~ 3. Is we~] located proper distance from property line .................. _~_ 4. Is we-~ !ocated proper distance from other wells ................ ' ... 5. Is sufficient undedicated acreage available in this pool ............ ~_ 6. Is well to be deviated and is wellbore plat included ........... ' ... 7. 8. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~P-- Does the well have a unique name and number ......................... Is conductor string provided ........ , ................................ Will surface casing protect all zones reasonably expected to serve as an underground source, of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~¢~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. t (6) OTHER //~_~. ~ (29 thru 31) rev: 01/30/89 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 0 ~Z Well HiStory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. ALASKA COMPUTING CEN'TER -~ SCHLUMBERGER · COMP-&NY NAME : ARCO ALASKA INCo WELL N,~ME : 2K - 11 FIELD NAME : KUPARUK -BOROUGH :' NORTH SLOPE STATE : &L~SKA aPI NUMB!ER : 50-103-20114 REFERENCE ND : LIS TAPE VERIF!CATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 2~-$EP-lg~g 12:51 PAGE: · ~*~ REEL HEADER SERVICE NAME : EDIT DATE : ORIGIN : FLIC REEL NAME : 73~82 C~NTINUATI~N # : PREVIOUS REEL : COMMENT : ARCO ALASKA ~NC., · ,:~ TAPE HEADER SERVICE NAME : EDIT DATE : 89/09/28 ORIGIN : FLIC TAPE NAME : CONT'INU~TI~N e : [ P~EVIOUS T~PE : COMMENT : ARCO ALASKA INC.~ F~LE NAME : EDIT .001 SERVICE : FLZC VERSION : OOIA02 DATE : 89/09t28 MAX REC SIZE ': IOZ~ FILE TYPE : LO L A S T F ! L E : KUPA~UK, 2K-11, KUPARUK, 2K-11, 50-103-20114 5:0-103-20114 COMPANY NAME: ARCO ALASKA INC. WELL: 2K-1! FIELD: KUPARUK BOROUGH: NORTH SLOPE STATE: ALASKA ~PI NUMBER: 50-103-20114 LOCATION: 46' FSL ~ 94' FEL SECTION: Z TOWNSHIP: ION PERMANENT D&TUM: MSL ELEV~,TION: 0 RANGE: 8E LIS TAPE VERIFICA'TIDN LISTING SCHLUM~BERGER ~LASK. A COMPUTING CENTER 28-SEP-198g 12:~1 LOG MEASURED FROM RK8 154 ABOVE PERMANENT DATUM ELEVATIONS K~: 154 DF: 153 GL: 113 DATE LO=~G ~ g: RUN NUMBER: TO DRILLE~: TO LOGGER: ll-SEP-Sg ONE 301 ?' 3010' CASING: 1:6" ~ gRI:LLER DEPTH OF 115' AND LOGGER DEPTH OF 113' BIT SIZE: 12 1/4" @. 3017' TYPE FLUID lIN HOLE: SPUD MUD DENS'ITY: 9.4 PH: 9 VISCOSITY: 84 FLUIO LOSS: 8 MUD RESISTIVITY: 8.9 FILTR~ATE RESISTIVITY: 39.3 MUD CAKE RESISTIVITY: 5.8 617 67 67 TIME CIRCULATION ~NDED: 14::05 ll-SEP TIME LOGGER ON BOTTOM: 17:35 tl-SEP M&XIMUM TEMP RECORDED: 7Z LOGGING DISTRICT: 'LOGGING ENGINEER: WITNESS: PRUDHOE BAY S AR BER gIXON/LOWEN TOOL NUMBERS: ~MM-AA.-774 SGC-SA-50 D~S-C-4908 DIC-OA-IO06 CCSM-AB-366 CCC-B-2765 SNC-HA-3~O NSC-E-801 DIS-EC-1100 IE~-BB-1290 FIELD REMARKS: 3" mINNED STANDOFFS AND A 2' HOLE FINDER USEP: ON THE OIL. N:UTRgN M~TRIX = SANDSTONE, HOLE CORRECTION = C~LIPER.. MATRIX ~ENSITY : 2.65 G/CC,, FILTRATE DENSITY : ~.0 G/CC. BOWSPRING RUN ON CNL TOOL. PAGE: DATE JOB STARTED: 19-SEP-89 JOB REFERENCE NO: 73471 LDP//tN~: R. KRUWELL DATE LCr~GED: RUN NUMBER: Tg DRILLER: 18-SEP-89 TWO 5850 LIS TAPE VE~,IFIC~T!ON LISTING SCHLUMBERGER ALASK~ COMPUTING CENTER .28-SEP-1989 12:51 PAGE: TO LOGGER: 6832 CASING: 9 5/$" @ DRILLER DEPTH OW 2997 AND LOGGER DEPTH OF 2999 TYPE FLUID IN HOLE: LSNO POLYMER DENSITY: 10.4 VISCOSITY: 39 PH: 9.5 FLUID ~LOSS: 4 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2.37 ~ 70 2.15 @ 75 1.19 @ 7'0 TIME CIRCULATION ENgED: ~00:0:0 18-SEP TIME LOGGER ON BOTTOM COlL/FDC/CNL PASS): 05:41 1B-SEP TIME LOGGER ON BOTTOM (SOT PASS): 15:17 1B-SEP TIME LOGGER ON BOTTOM (LDT/MLL PASS): 22,:39 18-SEP MAXIMUM TEMP RECORDED (DIL/FDC/CNL PASS): 139 MAXIMUM TEMP RECORDED (SOT P~SS)= 153 MAXIMUM TEMP RECORDE~ (LDT/MLL P~SS): 153 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDHOE BaY FRITZKE NCKAY/:BO:ND/SALAT TOOL NUMBERS (OIL/~OC/CNL PASS): IEM-BD 1347 O!$-EC 1457 SGC-JC 2249 PGC-J A 1041 TOOL NUMBERS '(SOT PASS): TCM-A5 213 SGC-S A 60 SDC-CA 14 SLS-VB 10 TOOL NUMBERS (LDT/MLL PASS): TCM-AB 213 SGC-S~ 60 NSC-E 750 PCC-H ~ 122 NLM-DC 1338 DIC-D~ 11308 CmC'-A 1.238 PGS-HB 508 TCC-A 79 STM-CA 66 SLR-~!B 44 WDM-AA 546 TCC-A ? 9 DRS-C 4847 PCM-A 154 FIELD REMARKS: DIL/FDC/CNL MAXIMUM DEVIATION : 28.1 DEGREES @4420'. 1-172" STANOOFFS AND 2' HOLE :INDER USED ~N DITD. H,ATR!X DENSITY = 2.65 G/C3 FLUID DENSITY : 1.0 G/C3. NEUTRON MATRIX : S~NO. H:gEE C~RRECTIDN : C~LIPER. NO BOWSPRZNG USED ON CN~. P~O ELEVATION~ 11B~ HIGH RESOLUTION P~SS LO~GEO BUT NOT PRE.SE,,TEO . FILMS. CTCO COMPUTED USING STC PROCESSING. SOURCE INTEGRATED TRANSIT TIME IS THE gTLN CURVE. ~N EXTR~ PASS WAS M~DE ~ETWEEN 55T0~ ~ND 5896' IN ORDER TO OBTAIN ~ BETTER DELT~-T CO~PRESSION~L CURVE. A CONSTANT WAVEF'2RM ~IN : 10 WAS NECESSARY IN ORDER TO DD THIS. THIS P~SS WAS SPLICED INTO THE M~IN PASS TO aBT~IN THE F]NAL LIS TAPE VER'IEI'CATiION LZSTING SCHLUMbErGER ALASKA COMPUTING CENTER 28-SEP-1989 12:5! ,LDT/MLL PRESENTED MAIN PASS. REPEAT PASS CPASS ~1)USED AS :MAIN PASS FOR MICROLOG. THE RE~SON BEING THE FILTER CAKE RESPONSE IN THE ZONE OF ZNTEREST ON THE FIRST P&SS WAS BETTER. ~!~rTR[X DENSITY = 2.65 G/C3 FLUID DENSITY : COMPUTING CENTER ~EM,~RKS: P~SS ~J2. MICROLOG (6861' TO 6705') SPLICED TO. PASS ~ICRDLOG (6705' TO .629~'), GR SPLICED @6694'.. DATE JO6 STARTED: Z6-SEP-$9 JOB REFERENCE NO: 7!:4B2) LDP/ANA: J. KOH~ING PA~E.. FILE - EDIT.O01 ARCO ~L,~SK~ INC. KUPARUK 2K-11 50-10)-2011¢ RUNZ LOG DATA MERGED TO'. RUN1 DAT~ S~MPLEO EVERY-.5000 F~EET DAT~ INCLUDED- TOOL EXTENS ION TOOL TYPE USED NAME D[T-D .DZL DUAL INDUCTION SFL 6832" TO 95' RUN1 MERGED TO RUN2 ~3004~'~ SOT .SOT A~R~Y SONIC 6828m TO 3000I LDT .LOT LITHO DENSITY 6830' TO 6288~ AND 2975~ TO 95~ CNT-A/D/H .CNL COMPENSATED NEUTRON 6796' TO 6290' AND 29.55 FDC .FDC FORMATION DENSITY 6810' TO MiC~DLDG .MLL MICRDLD~ 6802' TD 6295' T~.LE TYPE : CONS TUNI VALU DEFI CN FN ALASKA INC. KUPARUK COMPANY NAME :I~LO NAME -LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKi~ COMPUTING CENTER 28-SEP-1989 12:51 WN A~IN FL SECT T OWN C gUN STAT N AT! ENGI WITN SON PgAT LMF EKB EOF EGL 'TOO B L I TLI 'TCS TLAB TUNT FT FT FT FT FT FT FT FT VALU · 2K- 11 50-103-20114 46' FSL & 94' FEL OZ 1 ON NORTH SLOPE ALASKA A. FRITZKE MCK, AY/BONO/SALAT 548369 M SL RKB 154. 154. 1 53. 1 13. 6 6~02. 6290. 00:00 18-SEP 05:41 18-SEP T~a~LE TYPE : CUR:V OEFI DEPT ILO ILM S FLU SP GR TENS MTEM MRES HTEN DT DTL DTSM COHC COHS COST TT1 TTZ TT) LTT1 LTTZ DEATH CHANNEL NAME IL,-~EEP RESISTIVITY IL-MEDIUM RESISTIVITY SFL UNaVER~G~D SPONTANEOUS POTENTIAL GAMM~ RAY TENSION MUD TEMPERATURE MUD RESISTIVITY HEaO TENSION O E L T A-T DELTA T LC. NG SPACING DELTA-T SHEAR MEASUREMENT COHERENCE VALUE AT COMPRESSIONAL PEAK COHERENCE VALUE AT SHEAR PEAK COHERENCE VALUE AT STONELEY .°EAK TRANSIT TIME 1 TRANSIT TIME 2 TRANSIT TIME ) TRANSIT TIME ~ LONG SPACING TR,~NSIT TIME MODE 1 LONG SPACING TRANSIT TIME MODE Z PAGE: 5 D E F :I WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION "TOWNSHIP RANGE COUNTY ST,ATE OR PROVINCE N~TIDN ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PErMaNENT DATUM ;LOG MEASURED FROM BOTTOM LOG INTERVA, L TOP LOG INTERVAL 'TIME ~CIRCULATION STOPPED TIME LOGGER A.T BOTTOM i I/ IlIllI II I! iIillIIllIIIII LIS TAPE VERIFICATION LI.STING :SCHLUMSERG. ER AL~.SK~ COMPUTING CENTER 2~-SE~-lg~g 12:151 PAGE: OEFI ~L T T 3 LTT4 W:C WFSH DTLN DTL F DTCD GR TENS DPHI RHOB DRH~ QLS ~SS l S LU LL LITH $ S1 S S2 :LSHV S 'S H V $1RH L S RH LURH C AL I GR TENS MTEM MRES HTEN NPHI TNPH TNR~ NPC'R RCNT RCFT CNTC CFTC TENS MRES MTEM HTEN DPHI RH05 ORHO F~DC NFDC CALI TENS LONG SPACING TRANSIT TIME MODE LONG SPACING TRANSIT TIME MODE 4 WARNING iFLAG FOR CDMPRESSION.~L WARNING F'L-~G FOR SHE,~R DELTA-T LONG SP~CING NEAR DELTA-T LONG SPACING FA DE LT,~-T COMPRESSIDN~L GA MM ARA Y TENS ION DENSITY PDR~S'ITY BULK DENSITY DELTA ~P H 0 T 0- E :L E C T R I C F A C T E R QUALITY CONTROL OF LONG SP~:CING ~OR LOT QUALITY CONTROL ON SHORT SP~CING FOR LOT LONG SPACING COMPUTED COUNT ~ATE (LL+LU/2) LONG UPPER ~-2 WINDOW COUNT RATE (LUI+LU2) LONG L~W~R WINDOW COUNT RATE LITHgLOG WINgOW COUNT RATE SHORT SPACING 1 WINDOW COUNT R~TE SHORT SPACING 2 WINDOW COUNT R~TE LONG SPACING HIGH VOLTAGE OUTPUT SHORT SP~CZNG HIGH VOLTAGE LOOP OUTPUT SHO~T SP~CING I DENSITY ~LONG SPACING RH05 (UNCORRECTED) LONG UPPER RHD~ C,~LIPER GAMN,& TENSION MUD TEM'PERATURE MUD RESISTIVITY HEAO TENSION NEUTRON POROSITY THERMAL NEUTRON PDRO.SZTY CALI5R.~TED THERMAL NEUTRON R~TIO NEUTRON POROSITY OUTPUT mROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR TMERN~L COUNTS CORRECTED m~R THmRMAL COUNTS GAMMA RAY TENSION MUD RESISTIVITY MU~ TEMPERATURE HE~C TENSION ~ENSITY POROSITY BULK DENSITY DELTA RHO ~AR mDC COUNT RATE NEaR ~C CgUNT RATE CALIPEe G~MM~ TENSION LIS TAPE VERIFICATION LIS'TING SCHLUMBERGER aLASKA, COMPUTING CENTER 28-SEP-198g 12:51 PAGE: OEFI GR GAMMA RAY HD HOLE DI~,METE~ TENS TENSION ** DAT,~ FORMAT SPECIFICATION RECORD *~ SET 'TYPE- 64~B ** TYPE REPR CODE VALUE I 66 0 2 56 0 4 66 1 5 66 6 73 ? 65 8 68 9 65 FT 11 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVIC~ API APl API API FILE NUM5 NUMB SIZE REPR ID ORDER ~ LOG TYPE CLISS MOD NUMB SAMP ELEM CDDE DEPT FT 548369 O0 ILO DIL OHM~ 548369 07 ILM DIL ~HMM $48369 07 SFLU OIL OHMM 548369 07 SP OIL MV 548'3.69 07 GR OIL ~API 548369 07 TENS OIL L8 548369 07 MTEM OIL CEGF 548369 07 MRES Oil GHMM 548369 07 HTEN DIL LB 548369 07 DT SOT US/F 548369 07 DTL SOT US/F 5~8~69 OT DTSM SOT US/= 5~836g 07 COHC SD'T 5483~9 07 CgHS SOT 548369 07 COST SOT 568369 OT PROCESS (HEX) 000 O0 0 I 1 120 46 0 I 1 120 44 0 1 1 220 01 0 I 1 010 01 0 I 1 310 O1 0 I 1 635 21 0 I 1 635 21 0 I 1 635 21 0 I 1 635 21 0 I 1 6~5 21 0 1 1 635 21 0 1 t 635 21 0 1 1 635 21 0 1 1 635 21 0 1 ! 635 21 0 1 1 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 OOOO000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~,LASKA COMPUTING CENTER 28-SEP-1989 1Z:51 NAME SERV UNIT SER'VICE lO API AP! ~P! API FILE ORDER ,~ ~LOG TYP!E CLASS MOD NUMB TT1 SDT US 5483 69 TTZ SOT US 548369 TT3 SDT US 548369 TT4 SDT US 54;B369 LTT1 :SOT US 548369 L'TT2 SDT US 54B369 LTT3 SOT US 548369 LTT~ SOT US 5~836g W F C S D T 548369 WFSH SOT 548369 DTLN SOT US/F 548369 DTLF SOT US/~ 5~8~69 gTCO SOT US/F 548369 GR SOT GAPI 548369 TENS SOT L~ 548369 DPHI LOT PU 548369 RHD~ LDT G/C3 548369 DRHO LDT G/C3 548369 PEF LOT 548369 QLS LDT 54~369 QSS LDT 548359 LS LDT CPS 54~369 LU LDT CPS 548369 LL LDT CPS 548369 LITH LDT CPS 548369 SSI LDT CPS 548369 SS2 LDT CPS 549369 LSHV LDT V 54~369 SSHV LDT V 548369 StRH LDT G/C3 548369 LSRH LDT G/C3 5483~9 LURH LDT G/C3 548369 CALl LDT IN 548369 G~ LDT GAPI 548369 TENS LD'T LB 548369 MTEM LDT REGF 548369 MRES LOT aHMM 548369 HTEN LDT LB 548369 NPHI CNL PU 548369 TNPH CNL PU 54~369 TNRA CNL 548369 NPOR CNL PU 548359 RCNT CNL CmS 54~369 RCFT CNL C~S 543369 CNTC CNL CmS 54~369 CFTC CNL CPS 54B369 GR CNL GAPI 548369 TENS CNL L~ 548359 MRES CNL gHMM ~48369 MTEM CNL DEGF 54~369 HTEN CNL L5 548369 NUMB NUMB SAMP EL EM 07 6:35 21 0 I 1 1 0 T 635 21 0 I I 1 07 635 21 0 1 I 1 07 635 21 0 1 I I 07 635 21 0 1 1 ! 07 635 Z 07 6,35 07 635 21 0 1 1 07 635 2.1 0 I 1 1 07 635 21 0 I 1 1 60 520 80 0 I t 1 60 520 80 0 I I 1 60 000 00 0 1 1 1 60 310 01 0 1 1 60 635 Z 1 0 1 1 1 00 890 01 0 1 1 1 15 350 02. 0 I 1 1 15 356 O1 0 1 I 1 15 358 01 0 15 354 01 0 1 1 1 15 354 01 0 I 1 1 15 354 01 0 1 1 1 15 1354 OI 0 I I 1 15 354 O1 0 I I 1 15 354 01 0 I 1 1 1.5 354 OZ 0 1 1 1 15 354. 02 0 I 1 1 1 5 354. 00 0 ! 1 1 15 354 00 0 '1 I 1 1 5 3 5 0 02 0 1 1 1 15 350 OZ 0 I I 1 15 350 02 0 I I 1 15 280 01 0 1 1 1 15 310 01 0 I I 1 15 635 21 0 1 I 1 15 635 21 0 1 1 1 15 6)5 21 0 1 1 1 15 635 21 0 I I 1 07 8gO O0 0 1 1 1 07 890 00 0 I I 1 07 420 OI 0 1 1 1 07 890 O0 0 1 1 1 07 420 O1 0 1 1 1 07 420 O1 0 1 1 1 07 420 O1 0 1 I '1 07 420 O1 0 I I 1 07 310 Ot 0 1 1 1 07 635 21 0 1 1 l 07 635 21 0 1 t 1 07 635 21 0 1 1 1 O? 635 21 0 1 1 1 SIZE REPR CODE PROCESS (;HEX) 4 4 4 4 4. 4 4 4 4 4 ~4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 6 8 6 8 68 6'8 6 $ 6 8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6,8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 ooooooOooo 0000000000 0000000,000 0000000000 0000000~000 0,000000000 0000000000 0000000000 0000000000 0000000~000 0000000000 0000000000 000,0000000 0000000000 0000000000 0000000000 0000000000 0000000000 00'0'0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000;0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK~ COMPUTING CENTER 25'-SEP-1989 12:51 PAGE: NAME SERV UNIT SERVICE API API API ~PI FILE NUMB NUMB !SIZE REPR PROCESS IO ORDER ~ :LOG 'TY~PE CLASS MOD NUMB SAMP ELEM CODE (]HEX) DPHI FDC PU 548369 :07 635 21 0 1 1 I ~+ 68 0000000000 RHDB FDC G/C3 1548369 07 350 ~02 0 1 I 1 4 6:8 0000000000 DRHO F'DC G/C3 548:369 07 356 :01 0 I 1 I 4 68 O0000000OO FFDC FDC C~S 548369 0'7 :354 02 0 1 1 1 4 68 0000000000 NFOC FDC CPS 548369 07 354 O1 0 1 1 1 4 68 O0000OO000 CALI 'FDC IN 548369 07 280 O1 0 I 1 I 4 68 0000000000 GR FDC GRPI 5¢8369 07 310 01 0 1 I I 4 68 0000000000 TENS FDC ~L8 548369 07 635 21 0 1 1 1 4 68 0000000000 GR MtL GAPI 548369 07 635 2'1 0 I 1 1 4 68 O000000OO0 MD MLL IN 5483.69 07 635 21 0 I I I 4 68 0000000000 TENS MLL LB 54~369 07 635 21 0 I 1 1 4 68 0000000000 ------ DEPT. 6861.500 ILO.OIL 2.621 ILM.DIL 2.72? SFLU.DIL SP.DIL -27.313 GR.DIL 114.000 TENS.OIL 258:0.000 MTEM. DIL MRES.OIL -999.250 HTEN.9IL -999.250 DT, SOT -999.250 D'TL, SD'T DTSM. SDT -999.250 COHC. SOT -999.250 COHS.SDT -999.250 COS'T. SOT TT1.SOT -999.250 TT2oSDT -999.250 TT3.SDT -999.250 TT4,. SOT LTT1.SDT -999.250 LTT2.SDT -9~9.250 .LTT3.SDT -999.250 LTT4. SOT WFC.SDT -999.250 WFSH. SDT -999.250 DTLN. SOT -999.250 DTLF.SDT DTCD.SDT -999.250 GR.SDT -999.250 TENS.SOT -9'99.250 DPHI.LDT RHOB.LDT -999.250 DRHO.LDT -999..250 PEF.LDT -999.250 QLS.. LOT QSS.LDT -999.250 LS.LDT -999.250 L'U.LDT -999..250 LL.LDT LZ%H.LDT -999.250 SSI.LDT -999.250 SS2.LDi -999.250 LSHV.LDT SSHV.LDT -999.250 SI~H.LDT -999.250 LSRH.LDT -999..250 ~URH.LDT CALI.~DT -999.250 GR.LDT -999.250 'TENS.LOT -999.250 MTEM.LDT MRES.LOT -999.250 HIEN.LOT -999.250 NPHI.CNL 38..652 TNPH.CNL TNRA.CNL 3.251 NPDR.CNL 37.877 RCNT.CNL 1920.535 RCFT.CNL CNTC.CNL 1961.306 CFTC.CNL 614.020 GR.CNL ~14.000 TENS.CNL MRES.CNL -999.250 MTEM.CNL -999.250 HTEN.CNL -999.250 DPHI.FDC RHOB.FDC 2.525 ORMO.FDC 0.034 FFDC.FDC 414.750 NFDC. FDC CaLI.FDC 8.500 GR.FDC 11~.000 TENS.FDC 2580.000 GR.MLL HD.MLL -999.250 TENS.MLL -999.250 DEPT. 6800.000 ILD.OIL 2.027 ILM.DIL 1.979 SFLU.DIL SP.OtL -21.063 GR.DIL 108.188 TENS.OIL 3934.000 MTEM.DIL MRES.DIL -999.250 HTEN.~IL -999.250 DT. SDT 102.300 DTL.SDT DTSM.SDT 98.000 COHC.SDT 0.920 COHS.SDT 0.717 COST.SOT TT1.SDT 655.600 TT2.SDT ~57.200 TT3.SOT 872.000 TT4.SDT LTT1.SDT 1194.000 LTT2.SDT 986.800 LTT3.SDT 1397.600 LTT4.SOT WFC.SDT 0.000 WFSH.SDT 3.000 OTLN, SOT 104.000 DTL~.SDT DTCO.SDT 103.000 GR.SDT 104.875 TENS.SOT 3670.000 DPHI.LOT RHOB.LDT 2.475 DRHD.LDT O. 035 P=.F.LDT 3.611 QLS.LDT QSS.LDT 0.039 LS.LDT 266.750 LU.LOT 253.875 LL.LDT LITH.LDT 58. 500 SS1.LDT 201.750 SS2.LDT 275.000 LSHV.LDT SSHV.LDT 1683.000 SIRH.LDT 2.34~ LSRH.LDT 2.438 LURfl. LDT CALI.LDT 8.539 GR.LDT 104.875 TENS.LDT 408~.000 MTEM.LDT MRES.LDT -999.250 HTEN.LDT -999.250 NPHI.CNL 40.31~ TNPH.CNL 3.446 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.2.50 -999.250 -999.250 -999. 250 -999'.250 -999.250 3'7.877 541.437 2580.000 7.606 573.500 -999.250 2.275 -999.250 102.900 0.250 665.200 1192.800 104.100 10.6)5 0.010 140.000 1236.000 2.455 -999.250 40.752 LIS 'TAPE VERIFICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER TNRA.CNL 3.345 NPDR.CNL CNTC.CNL 2063.609 CFTC.CNL MRES.CNL -99~9. 250 MTEM.CNL RHOB,. FDC 2.465 ORHO.FDC CALI. FDC 8. 531 GR. FDC HD. MLL 8. 688 TENS. MLL D E P T. 6700.000 ii L D. O I L SP.DIL -18.313 GR..DIL MRES.OIL -999.250 HTEN.DIL DTSM.SDT 100.000 COHC.SOT TT1. SOT 665.600 TT2.SDT LTT1.SDT 1202.400 LTT2.SDT WFC.SDT 0.000 WFSH.SDT OTCO.SOT 105. 000 GR.SOT RHOB.LOT 2.445 ORHO.L~T QSS.LOT O. 038 :LS.LDT L I T H. L D T 60.250 S S 1. L D T SSHV.LDT 1685.000 SIRH.LOT CALI.LDT 8.. 586 GR.LOT MRES.LDT -999'250 HTEN.LDT TNRA.CNL 3.'47] NPOR.CNL CNTC.CNL 1982. 262 CFTC.CNL MRES.CNL -999. 250 MTEM.CNL RHO~. FDC 2.~43 DRHO.FDC CALI. F'DC 8. 563 GR.~DC HD.MLL 8.711 TENS.MLL DEPT. 6600. 000 ILD. DIL SP. OIL -37.688 GR. OIL MRES..DIL -999. 250 HTEN.DIL DTSM.SDT 164.000 COHC.SOT T'TI. SOT 5 ~$. 400 TT2. SOT L'TT1. SDT I039.600 LTT2.SDT WFC.SDT 0.000 WFSH. SOT DTCO.SDT 92.000 GR.SDT RHOB.LDT 2.355 DRHO.LDT QSS. LDT O. 011 LS. LOT LITH.LDT BO. 063 S S1.LDT SSHV.LDT 1686. 000 SIRH.LDT CALI.LDT 8.523 GR.LDT MRES.LDT -999.250 HTEN.LDT TNRA.CNL 2.631 NPOR.CNL CNTC.CNL 2562.782 CFTC.CNL MRES.CNL -999. 250 MTEM.CNL RHOB. FDC 2.361 DRHO.FDC CALI.FDC 8.469 GR.FDC HD.MLL 8.758 TENS.MLL DEPT. 6500.0 O0 ILO.OIL Sp. OIL -31. 563 GR.DIL MRES.DIL -999.250 HTEN.OIL DTSM.SOT 175.000 C~HC.SDT TT1. SOT 692. OOO TT2. SOT LTT1.SDT 1220.800 LTT2.SDT 28-SEP-lgBg 12:51 41 - 075 R C N'T o C N L 2006.785 611. 179 GR.CNL 10 8. I88 -999.250 HTEN.CNL -999.250 0.056 FFDC.FOC 507. 500 108.188 TENS.FDC 3934,.000 4084.000 2.. 533 tLM. DIL 2.639 105. 750 TENS.OIL 3924. 000 -999.250 DT. SDT 104.700 0.866 COHS.SDT 0.774 ,460. OOO TT3'SDT 87'?.600 994..400 L T T 3. $ O T 1410.800 10.000 DTLN.SDT I04.900 99.750 TENS.SBT 3564.000 O. 0.26 PEF.LDT 4.246. 27 5. 750 LU.LDT 266. 000 200. 750 SS2.LOT 275.250 2.340 LSRH.LOT 2.418 105.563 TENSoLDT 4172.000 -999.250 NPHI.CNL 42.627 41.S23 RCNToCNL 1976..541 569. 700 ,SR.CNL 105.750 -999.250 HTEN.CNL -999.250 0.017 FFDC.FDC 486.750 105:.750 TENS.FOC 3924.000 3 944.0'00 11.290 ILM. DIL 72. 125 TENS.OIL -999.250 DT. SOT 0.646 COHS.SDT '409.600 TT3.SDT 862.400 LTT3.SDT 0.000 DTLN. SDT 69.438 TENS.SOT -O..OOZ PEF.'LD'T 311. 000 LU.LDT 192. 875 SS2.LOT 2.361 LSRH.LDT 71.:375 TENS.LDT -999.250 NPHI.CNL 29.802 RCNT.CNL 1070. 275 GR.CNL -999.250 HTEN.CNL 0.012 FFOC.FDC 72.125 TENS.FDC 3994.000 1.944 ILM. DIL 110.188 TENS.OIL -999.250 OT. SOT 0.350 COHS.SOT 510.000 TT3.SDT 1008.800 LTT3.SDT 11.153 3844.000 90. 3'00 0.491 766.800 1222.000 88. 500 3524.000 2.477 293.000 273.500 2.355 4024.000 28.419 2801.315 72.125 -99 9.250 587.000 3844.000 2.052 3914.000 104.000 0.420 904.000 1395.600 RCFT.CNL TENS.CNL DPHI o FDC NFDC. ~OC GR.MLL SFLU. OIL MTEM. OIL DTL. SOT COST.SOT TT4., SD'T LTT4. SOT DTLF.SOT DPH I. LO T QL S. L D T LL.LDT LSHVoLDT L U R H. L D'T MTEM.LDT TNPH.CNL R CF T. C NL T E NS. C:NL DPHI.FDC NFDC.FDC GR. MLL SF,LU. DIL MTEM.DIL DTL. SDT COST.SOT TT4.SDT LTT4.SDT DTLF.SDT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FOC NFDC.FDC GR.~LL S~LU.DIL MTEM.OIL OTL. SDT COST.SOT TT4.SDT LTT~.SDT PAGE: I0 561.313 ;3934. 000 I1.2.42 628.000 104.8'75 3.097 -999.250 105. 200 0.250 666.800 1204.400 1.04.4 O0 12.438 -0.019 142. 750 :1235.000 2.424 -999.250 4.2. 385 507.759 3924.000 IZ. 567 585.5O0 105.563 12.264 -999.250 90.100 0.925 588.000 1042.000 88.900 17.861 0.002 164.500 1236.000 2.361 -999.250 29.776 949.893 3844.000 17.490 613.000 71.625 2.668 -999.250 102.700 0.266 701.600 1220.800 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER WFC. SOT 0.000 WFSM. SDT DTCD.SDT 103. 000 GR. SOT RHOBoLDT 2-163 ORHO.LDT QSS.LDT 0.027 LS.LDT LITH.LDT 76. 188 SS1.LDT SSHV.LDT 1686.000 SI~H.LDT CAL'I.LDT 13.0 39 GR.LOT MRES.LOT -999.250 HTEN.LDT TNRA.CNL 3. 847 NPOR.. CNL CNTC,.CNL 1652.896 CFTC.CNL MRES.CNL -99:9.250 MTEM.CNL RHOB.FDC 2.217 DRHO.FOC CALZ. FOC 12. 313 GR. FDC HD. MLL 12.102 TENS.MLL D E P T. 6,4 00 ' 0 00 I L D. D I L SPr. OZL --35. 938 GR-- OIL MRES.DIL -999.250 HTEN.DIL DTSM.SDT 121.375 COHC.SDT TT1. SOT 754. 000 TT2. SOT LTTi. SDT 1327.600 LTT2.SDT WFC.SDT 0°000 WFSH. SDT OTCO. SOT 112. OOO GR.SDT RHOB.LOT 2. 263 ORHOoLDT QSS.LDT 0.039 LS.LOT LI'TH. LOT 93. 063 SSl..LDT SSHV.LDT 1686.000 S1RH.LDT CALI.LDT 11. 227 GR.LDT M R E S. L D T -9 99.2 5 O H'T E :N. L D T TNRA.CNL 4.173 NPOR.CNL CNTC.CNL 16,19.773 CFTC.CNL MRES.CNL -999.250 MTEM. CNL RHOEt. t::DC 2.257 ORHD.FDC CALi. FDC 11. 031 GR.FDC HD.MLL 10.156 TENS.MLL DEPT. 6300.000 ILD.DIL SP.DIL -31.688 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM. SOT 122. 000 COHC. SOT TT1. SDT 716.4 O0 TT2. SDT LTT1.SDT 1274.800 LTT2.SDT WFC.SDT 0.000 WFSH.SDT DTCO. SDT 1 ZO. 000 GR. SOT RHDB.LDT 2./,27 DRHO.LOT QSS.LDT 0.027 LS.LDT LITH.LDT S7. 531 SS1.LOT SSHV.LDT 1686. 000 SIRH.LDT CALI.LDT 9.078 §R.LDT MRES.LDT -$99.250 HTEN.LDT TNRA.CNL 3.6'95 NPOR.CNL CNTC.CNL 1911.730 CFTC.CNL MRES.CNL -999.Z$0 MTEM.CNL RHO~.FDC Z.427 ORHO.FOC C4LI.FDC 8.938 GR.FDC 28-SEP-198:9 12:51 3. 000 DTLN. SOT 109:. 063 TENS. SOT O. 103 PEF.LDT 505.000 LU.LgT 242. 125 S S.2.LDT 1- 848 LSRH.LDT 101.18B TENS.LOT -999.25'0 NPHI.CNL 45.916 ~.~CNT. CNL 437. 560 GR.CNL -999. 250 HTEN.CNL O. 103 FFDC.FDC 110.188 TENS.FOC 3 994. O00 t. 92 Z I L M. D I L 112.125 TENS.DIL -999,., 250 DT. SOT O. 942 COHS. SOT 504. 800 TT3.SDT 1091.600 LTT3.SDT 10.000 DTLN.SOT 113.375 TENS.SOT O. 083 PEF. LDT 416.250 LU.LDT 229. 500 SS2.LDT 2. 004 LSRH.LDT 107.8'75 TENS.LOT -999. 250 NPHI.CNL 48.699 RCNT.CNL 420. 311 GR. CNL -999.250 HTEN.CNL 0.121 FFDC.FDC 112.125 TENS.FDC 3954.000 1.983 ILM.DIL 244. 000 TENS.OIL -999.250 DT.SDT 0.845 COHS.SDT ¢88.000 TT3.SDT 1056.800 LTT3.SDT 10.000 DTLN. SDT 242.875 TENS.SOT Oo 012 PEF.LDT '276. 750 LU.LDT 196.500 SS2.LDT 2.369 LSRH.LDT 229.375 TENS.LOT -999. 250 NPHI.CNL 42.726 RCNT.CNL 548.107 GR.CNL -999.250 HTEN.CNL 0.012 FFDC.FDC 244.000 TEN$.FDC 102. 3504- 9. 475. 357. 3604. 45. 1583. 110. -999. I0:47. 3914. . 3750. I 1 !. O. 976. 1567. 112. 3420. 39 5. 326. 3840. 1531. 11 Z. -999. 994.. 3750. 3770. 113. O. 929. 1504. 112. 3380. 4. 264. 274. 2. 3544. 46. 1853. 244. -999. 499. 3770. 5'00 000 289 O O0 Z 50 O59 000 498 501 188 250 000 000 998 0:00 700 406 400 600 700 000 617 750 750 180 000 069 668 250 000 000 157 000 000 513 60O 000 20O 000 363 250 25O 414 000 131 819 000 25O 750 000 DTLFoSDT DPHI .LDT QL S. LOT LLoLDT LSHV.LDT LURH.LDT M'TEM.LDT TNPH..CNL RCFT .CNL TENS.CNL D PM I. FDC NFDC. FDC .GR.MLL SFLU. OIL MTEM.o OIL OTL. SOT COST-SOT TT4. SOT LTT4,. SOT DTLF.SDT DPHI.LDT QL S .LOT LL.LDT LSH¥.LDT LURHoLDT MTEM..LOT TNPH.CNL RCFT.CNL TENS..CNL DPHI.. FDC NFDC.FDC G R. M L L SFLU.DIL MTEM.DIL DTL. SOT COST.SOT TT4.SOT LTT4. SOT DTLFoSDT DOHI .LOT QLS.LDT 'LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS .CNL gPHI.FDC NFDC.FDC GR.MLL PAGE: 11 99.000 29. 522 -0.045 266.750 1235.000 2. 074 - 999 .. 250 44.814 412..1'74 3914.000 26. 252 821.500 99.8'75 2.341 -999.250 i12'200 0.404 756.400 t337.200 114.600 23.449 -0 .O4Z 218.375 1235.000 2.180 -999.250 46. 870 363. 414 37.50.000 23 · 829 825. 000 108. 563 3.337 -999.250 112.600 0.3'94 717.600 1280.400 113.100 13.527 -0.002 144.625 1235.000 2.428 -999.250 42.258 462.914 3770.000 13.494 585.500 233.125 ~LI$ TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 2~-SEP-1989 1.2:51 HD-ML!L 9.352 TENS.MLL 3824.000 DEPT. 6200. 000 ILO.OIL S P. O I :L - 39.938 G R. D I L MRES.DIL -999.250 HTEN.DIL DTSM. SDT 125.000 CDHCoSDT TT1. SOT 745.6 OD TT2.SDT LTT1.SDT 1.31,8.000 LTT2.SD'T WFC. SDT O.OOO WFSH.SDT D'TCDo SBT 120,000 GR, SBT RHOB.LOT -999,250 DRHD.LDT QSS.LOT -999.2 50 LS.LDT LITH.LDT -999. 250 SSI.LDT SSHV.LDT -999.250 SIRH,LDT 'C A L I. L D T - 999.2 50 G R. L D T MRES.LDT -'999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC..CNL -999.25,0 CF'TC.CNL MRES.CNL -999.250 MTEM.'CNL RHOB.FDC -999.250 DRHO,.FOC CA:LI.FDC -999. 250 GR. FDC HD.MLL -999.250 TENS.MLL DEPT. 6100. 000 ILO.OI:L SP.DIL -36. 438 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM.SDT 126.000 COHC.SDT TT1. SOT 702. $00 TT2. SOT LTT1.SDT 1284.000 LTT2.SDT WFC.SDT , 0.000 WFSH.SDT DTCD.SDT 114. 000 GR. SOT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999. 250 LS.LDT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999. 250 S1RH.LOT CALI.LDT -999. 250 GR.LDT MRES.LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999. 250 CFTC.CNL MRES.CNL -999.250 MTEMoCNL RHBB.FDC -999.250 DRHO.FDC C ALI. FDC -999. 250 GR.FDC HD.MLL -999.250 TENS.MLL DEPT. 6000.000 ILD. DIL SP. DIL -38.875 GR.DIL MRES.DIL -999.250 HTEN.OIL DTSM.SDT 168,000 CCHC,SDT TTI.SDT 657.2g0 TT2.SDT LTT!.SDT 1181.200 LTT2.SDT WFC.SDT O.OOO WFSH. SDT DTC2.SDT 100.000 GR.SDT RHOB.LDT -999.250 ORHO.LgT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SSI.LDT 2.453 ILM. OIL 186.750 TENS.OIL -999.250 BT.SOT ~0,958 COHS. SDT 5~04.400 TT3.SDT 1122.000 LTT3.SOT 3.000 DTLN. SDT 191.250 TENS'SOT -999. 250 PEF.LDT -999,250 LUoLDT -999.250 SS2.LDT -999.250 LSRH.LOT -999.250 TENS.LOT '-999.250 NPHI'CNL -999.250 RCNT,CNL -999.250 GR.CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.Z50 TENS.FDC -999.250 2.. 520 ILM.DIL 124,000 TENS,OIL -999.250 BT. SOT 0.924 COHS.SOT 476.800 TT3.SOT 1054,000 L'TT3.SDT 10.000 DTLN. SOT 114.125 TENS. SOT -999.250 PEFoLDT -999, Z50 LU.LDT -999,250 SS2,LDT -999.250 LSRH. LDT -999.250 TENS.LOT -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 3.220 ILM.DIL 104.688 TENS.DIL -999.250 BT.SOT 0.692 COHS.SDT 456.400 TT3.SDT 974.000 LTT3.SDT 3.000 OTLN.SDT 107.563 TENS. SBT -999.250 PEF.LDT -99'9. 250 LU.LDT -999.Z50 SS2,LDT 2. 632 374 4. 000 1'15. 900 0.526 978.000 1555.200 113.300 336¢.000 - 999.250 -999.25:0 -999.250 -999.250 -99' 9.250 -999. ZS0 -999.250 - 999.250 -999.250 -999.250 -999.250 2,637 377 0., 000 11 .Z, 100 O. 982 924,800 1516.000 115.30~0 3314.000 -999.250 -99 9. 250 -999. 250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.Z50 -999.250 3. 242 3730.000 102.000 O. 26'~ 860.000 1384.400 102.300 3240.000 -999.250 -999.250 -999.250 S F L U. D I L MTEM.DIL DTL o SD'T ,COST. SOT 'TT4. SOT LTT4. SOT DTLF.SDT DPHi.LDT Q:L S. LDT LL.LDT L SHV. LOT L:URH.LDT MTEM.LDT T N P H. C N L RCFT.CNL TENS.CNL DPHI. FDC NFDC.FDC G~. MLL SFLU.DIL MTEM.OIL OTL.SDT COST.SOT TT4. SDT LTT4. SDT DTLF.SDT DPHI.LDT QLS.LDT LL.LDT LSH¥.LDT LURH.LDT MTEMoLDT TNPH.CNL RCFT.C'NL TEN$.CNL DPHI.FDC NFDC.FDC GR.MLL SCLU.DIL MTEM. DIL DTL.SDT COST.SOT TT4.SDT LTT4.SDT D'TL:.SDT DPHI.LDT QLS.LOT LL.LDT LSHV.LDT PAGE: . -999. 115. 0. 74.9. 13:31. 111- -999. -99'9. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. . -999. 114. O. 704. 1276. 115. -999. -999. -999. -999. -999. -999. -999. -999 · -999. -999. -999. -999. . ~01. O. 653. 1176. 103. -999. -999. -999. -999. 12 454 250 200 754 6 O0 6O 0 100 250 250 25O 25O 250 25O 25O 250 250 2.5O 626 250 :000 250 000 800 900 250 25,0 25O 25O 250 250 250 250 2~0 250 25O 250 556 25O 5O0 679 600 800 3OO 25O 25O 25O LIS TAPE VERIFICATION LISTING :SCHLUMBERGER ALASK,~ COMPUTING CENTER SSHV..LDT -999.250 S1RH.LDT CALI.LD'T '-999.2 50 GR.LDT 'M R E S. L O T - 9 9 9. Z :5 O H T E N. ~L O T TNRA.CNL -999.250 N:POR.CNL CNTCoCNL -999.250 CFTC.CNL M~ES. CNL -999.2 50 MT EM.CNL RHOB.FOC -'999.250 DRHO.FDC CALl.. FDC -999.250 GR. FOC HD. MLL -999.250 'TENS.MLL DEPT. 5900.000 ILD.D!L SP.DIL -32.906 GR.OIL MRESoDIL -999.250 HTEN..DIL DTSM. :SOT 168. OOO COHC. SOT TT1. SD'T 685. 600 TTZ.SDT t T T 1. S D T t 2 '~ 0.4 0 0 L'T 'T 2 - S O 'T WFC.SDT O.O00 WFSH.SDT DTCD.SDT 115. 000 G:R'. SOT RHOB.LDT -999.250 DRHD.LOT QSS.LOT -999. 250 LSo,LOT LITH.LDT -999. 250 SSI.LDT SSHV-LDIT -999.250 SIRH.LDT CALI.LDT -999. 250 GR.LDT MRES. LDT -999.250 HTEN.LDT 'TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTCoCNL M R E S. C NL - 999 · 250 M T E M. C NL RHOB. FDC -999.250 DRHO.FDC CtL[. FDC -9 99.250 GR.FDC HD.MLL -999.250 TENS.MLL DEPT. 5800.000 ILD.DIL SP.OIL -26. 125 GR. OIL MRES.DIL -999.250 HTEN.DIL DTSM.SDT 154.000 COHC.SDT TT1. SOT 602. 400 TT2.. SOT LTT1.SDT 1112.000 LTT2.SDT WFC.SDT O.OOO WFSH.SDT DTCO.SDT 97.000 GR.SDT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999.2 50 LS. LOT L ITH.LDT -999.2 50 SS1.LOT SSHV.LDT -999. 250 SIRH.LDT C~,:LI.LDT -999.2 50 GR.LgT MRES.LDT -999.250 HTEN.LDT TNR~.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -9 99. 250 GR. FDC HD.MLL -999.250 TENS.MLL 2B-SEP-1989 12::51 -999.250 L:SRH'LDT -999.250 -999.250 TENS.LOT -99'9.250 -999.250 NPHI.CNL -999.250 ,- 999.250 R C NT. C NL - 999.250 -999. 250 GR.CNL -999.250 -999.250 HTEN.CNL -999.250 -999. 250 FFOC. FDC -999.250 -999.250 TENS.FOC -999.250 ,- 999.250 2. 821 ILM.DIL 131:. 375 TENS.OIL -999.250 DT.SDT O. 882 CDHS.SDT '¢63.600 'TT3. SOT IOZ~.O00 LTT3.SDT 10.000 DTLN.SDT 12.2.625 TENS. SOT -999..250 PEFoLDT -- 999 :. 250 L U - L D T -'999. 250 SSZ.LDT - 9'99. Z 50 L S R H. L g T -999.250 TENS.LDT -999. 250 NPHI.CNL -999.250 RCNT.CNL '-999. 250 GR. CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS. FD:C -999. 250 2. 151 ILM.OI:L 133. 250 TENS.OIL -999.250 DT.SDT O. 94~ COHS. SDT 418.000 TT3.SDT 908. 000 LTT3. SOT 0.000 DTLN.SDT 123.625 TENS. SOT -999.250 PEF.LDT -399.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 2.953 3504.000 ! 07. 0.. 266 904.000 1465.200 11 Z. 000 3210' 000 -999. 250 --99 9.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999..250 -999.250 -999.250 2.264 3434. 000 95. 100 0.420 798..000 1305.200 98.300 310¢.000 -999.250 -999.250 -999.250 -999.250 -999.250 -gO g. 250 -999.250 -999.250 -999.250 -999.250 -999.250 LURH.LDT MTEM. LD'T TNPH.CNL RCFT. C NL TENS. CNL DPHI. F.DC NFDC.FDC GR. MLL S F:L U. O [ L. M'TEM. OIL DTL. SOT :COST. SOT TT¢.SDT LTT4. SOT D'TLF. SOT DPHIoLD'T QL S.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL R C:F T,. CNL TENS.CNL DPHI. FDC NFDC.FDC G R. MLL SFLUoDIL M'T EM. DI'L DTL.SDT COST.SOT TT4.SDT LTT4.SDT DTLF.SDT OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC. FDC GR.MLL PAGE: 13 -999.250 -999.250 .-999.250 -999.250 -999.250 -99'9.250 -999.250 -9'99.250 3.794 - 999.250 108.100 0.250 688. 800 1236.400 111.100 -999.250 -999. 250 -999.250 -999 ,. 250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.209 '-999.250 95.500 0.307 601.600 1098.800 98.400 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. STO0. 000 ILO.OIL SP. OIL -35. I56 GR.O!L MRES-DI~L -999.250 HTEN.DIL DTSM. SOT 104.000 COHC. SOT TT1. SOT 6'74. 800 TT2.SDT LTT1.SDT '1209.600 LTT2.SDT WFC.SOT O.OOO WFSH.SDT DTCO. SOT 108. 000 GR. SOT RHOB.LDT -999. 250 DRHO.LDT QSS.LDT -999.2 50 LS.LOT LITH.LDT -999. 250 SS1.LDT SSHV..LDT -999.250 SIRH.LDT CALI'LDT -999',250 GR.LDT MRES.LDT '-999:.250 HTEN.LDT TNRA,.CNL '-999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MR ES. C'NL -999,250 MTEM.CNL RHOB.FDC '-999. 250 DRHO:.FDC C ALI. FDC -999. 250 GR. FDC HD. MLL -:999. 250 TENS.MLL DEPT. 5600.000 ILO.OIL SP.OIL -37o 563 GR.DIL MRES.D~L -999.250 HTEN.DIL D'TSM. SD'T 174.000 COHCoSDT TT1.SOT 580. 800 TT2. SOT LTT1.SDT 1068.800 LTT2.SDT WFC. SOT O. 000 WFSH. SOT DTCg. SDT 87.000 GR.SDT RHOB.LDT -999.250 DRHO.LDT QSS. LOT -999.2 50 LS. LOT L ITH.LOT -999.250 $ S1.LDT SSHV.LDT -999. 250 SIRH.LDT CAL I.LDT -999.2 50 GR. LDT M~ES.LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.:CNL CNTC.CNL -999. 250 'CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 DRHg.FOC CALI.FDC -999.2 50 GR. FgC HD.MLL -999.250 TENS.MLL DEPT. 5500.000 ILO.OIL SP.DIL -36.500 GR.DiL MRES.DIL -999.250 HTEN.DIL OTSM.SDT 123.375 COHC.SDT TT1. SDT 618. 000 TTZ. SOT LTT1.SDT 1136.000 LTTZ.SOT WFC.SDT 0.000 WFSH.SDT DTCO.SOT 93.000 GR.SDT RHOB.LDT -999.250 DRHO.LDT QS S.LDT -999.2 50 LS.LDT L ITH. LOT -999. 250 S S1.LDT SSHV.LDT -999. 250 SIRH.LDT CAL!. LOT -9 99, Z 50 GR.LDT 28-SEP-1959 12::151 3.25,4 ILM.DIL 135.000 TENS.OIL -999.250 DT. 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FDC HD.MLL -999.250 TENS.MLL DEPT. 5200.000 ILO.OIL SP.OIL -48.125 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM.SDT 157.000 COHC.SDT TTI.SDT 729.600 TT2.SDT 2B-SEP-lgB9 12:51 -999.250 NPHI.CNL -999.250 - g 9 g. Z 50 R C N T. C N L - g g g. 250 -999. 250 GR.CNL -999. 250 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 3.18,4 ILM.OIL 94.375 'TENS.DIL -'999. 250 DT. SOT O. 874 CONS. SOT 4,25. 200 TT3.SDT 917. 600 LTT3.SDT 10.00 O DT L:N. S D T 96.813 TENS.SOT -999. 250 PEF.LOT -999. 250 LU:.LDT -999.250 SS2.LDT --999.250 LSRH.LDT -'999.250 TENS.EDT -999.250 NPHI.CNL -999.250 RCNT.CNL -999. 250 GR.CNL -999.250 HTEN.CNL - 999. 250 FFDC.FOC -999..250 TENS.FOC -999. 250 3.340 330¢.000 95.900 O. 252 807.200 13'13.600 96.000 2930.000 -999.250 -999.250 -999.250 -999.250 - 9 g 9.250 - 99 9.. Z 50 -999.250 -99:9.250 -999.250 -99 9. 250 -999. 250 3.793 ILM.DIL ,3.869 11 9. 563 TENS.OIL 3124.000 -999. 250 OT. SOT 103.800 O. 9:00 COHS.SDT 0.252 502.400 TT3.SOT 929.200 1040.400 LTT3.SDT 1468.400 10.000 DTLN.SOT 102.600 119.438 TENS.SOT 2954.000 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LDT --999.250 -999. 250 TENS.LOT -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -999.250 HTEN.CNL -999.250 -999. 250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 3.684 ILM.DIL 131.000 TENS.DIL -999.250 DT.SDT 0.974 CDHS.SDT 504.800 TT3.SDT 3.727 3044.000 106.000 0.252 937.600 T NPN. CNL RCFT.CNL T ENS.CNL DPHI.FDC N FDC. FDC GR.MLL SFLU. DIL MTEM. OIL DTL. SOT COST. SOT TT4. SOT LTT~. SOT DTLF. SOT DPHI .LOT QL'S.LDT LL.LDT LSHV.LDT LURN.LDT MTEM.LDT TNPH.CNL R C F T. C NL TENS.CNL DPHI. FDC NFDC.FDC GR.MLL SFLU.DIL MTEM. DIL DTL.SDT COST.SOT TT4.SDT LTT~.SDT DTLF..SDT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPHoCNL RCFT.CNL TENS.CNL DPHI.FDC N~DC.FDC GR.MLL SFLU.DIL MTEM. DIL DTL. SOT COST.SOT TT4. SDT PAGE: 15 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.333 -999.250 94.800 0.250 621.200 1112.400 96.500 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 -999°,250 -999.250 -999.250 -999.250 -999.25Q -999.250 3.912 -999.25,0 103.300 0.873 717.200 1255.200 103.500 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -9'99. 250 -999.250 -999.250 -999.250 -999.250 3.925 -999.250 107.700 0.847 717.600 LIS T~PE YERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 2B-SEP-1989 12:51 LT'T1. SOT 1279.200 LTT2.SOT 1063.600 LTT3.SOT WFC,. SOT O. 000 WF:SH.SOT t0.000 DTLN. SDT D T,C O- S D T ! 08 ' 000 G R. S 0 T 135 :.. 25:0 'T E N $. S O T RHO~.LDT -999.250 ORHO.LDT -99'9.250 PEF.LDT QS S.LOT -999.2 50 LS.LOT - 99 9.250 LU.LDT L I T H.. L O T - 999.250 S S 1. t D T - 999.250 .S S 2. L D T SSHV.LDT -9:.~9. '250 SI~HoLO'T -999.250 LSRH.LDT CALI.LDT -999.250 GR.LDT -999.250 TENS.LOT MRES.LDT -999.250 HTEN.LDT -999°250 NPHI..CNL TNRA.CNL -9'99.250 NPOR.CNL -999.250 RCNT.CNL C N T C. C N L -999.250 C F T C. C N L - 999 o 25 O G R. C N L MRES.:CNL -999.250 MTEM.CNL -999. 250 HTEN.CNL RHO~.FDC -999.250 DRHC,.FDC -999.250 FFDC.FOC CALIoFDC -999.2'50 GR.FDC -999.250 TENS. FDC HD. ML:L -99'9. 250 TENS. MLL -999.250 DEPT. 5100. 000 ILD. OIL SP. OIL -M0.563 GR.DIL M~ES.DIL -999.250 HTEN.DIL DTSM. SOT 157.000 COHC.SOT TTloSDT 712.000 'TT2.SDT LTTI. SDT 1292.000 LTT2.SDT WFC. SDT O. OOO WFSM.SDT DTCO. SOT 104. 000 GR. SOT RHOB.LDT -999. 250 DRHD.LDT QS S.LDT -999.2 50 LS.LOT L'ITH.LDT -999. Z50 SSI.LOT SSHV.LDT -999. 250 SIRH.LDT CALI.LDT -999. 250 OR.LOT MRESoLDT -999. ]2 50 HT EN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999. 250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB. FDC -999.250 DRHO.FDC CALIo FDC -999. Z 50 GR. FOC HD. M:LL -999.250 TENS.MLL DEPT. 5000.000 ILD. DIL SPo OIL -37. 625 GR. DIL MRES.DIL -999.250 HTEN.DIL DTSM.SDT 114. 000 CDMC. SOT TT1. SDT 716. 800 TTZ. SOT LTTI.SDT 1300.400 LTTZ.SDT WFC.SDT 0.000 WFSH.SDT DTCD.SOT 117. 000 GR.SOT RHO~.LDT -999.250 DRHO.LDT QS S. LOT -999.2 50 LS.LDT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 SIRH.LDT C~LI.LOT -999.2 50 GR.LOT MRES.LDT -999.250 HTEN.LDT TNR~.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOS.FDC -999.250 gRHO.FDC 3.034 ILM.DIL 164o 750 TENS.OIL -99'9. 250 DT.SOT O. 717 COHS.SOT 477.200 TT3.SDT 1060.000 LTT3.SDT 10.000 DTLN.SDT 168. t 25 TENS. SOT -999.250 PEF.LDT -99'9.250 LU.LDT -999.250 SS2.LDT - 999.25:0 L S R H. LDT -9'99. 250 TENS.LOT -999. 250 NPHI.CNL · - 999.250 R C N T. C N:L -999. 250 GR.CNL - 999. 250 HTEN. CNL -999.250 FFDC.FDC -999. ZSO TENS. FOC -999.250 1.803 ILM.DIL 137.625 TENS.OIL -999.250 DT. SOT 0.963 COHS.SDT 509.600 TT3.SDT 1088.800 LTT3.SDT 10.000 DTLN.SOT 134.875 TENS.SOT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 HTEN.CN~ -999.250 FFDC.FDC 147 8. 800 107. I 00 2850.000 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999-250 - 999.250 -999.250 -999.250 2. 961 3020..000 107.500 0.252 931.600 t.519.600 103. 900 2874. 000 -999.250 -99'9. 250 -99 9. Z 50 - 999.250 -999.2S0 - 999.250 --999.250 -999.250 --999.250 -999.250 -999.250 1.822 298~.000 111.900 0.881 956.400 1520.800 112.900 282¢.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 LTT4. SOT D'TLF. $DT DPHI.LDT QLS'LOT LL.LDT LSHV.LDT LURH,.LDT MTEM.LOT TNPH.CNL RCFT.CNL T E N S. C NL DPHi. FDC N FOC. FDC GR..MLL SFLU.DIL MTEM- OIL OTL. SDT COST. SOT TT.~+. SOT LTT4. SDT DTLFoSDT OPM I. LOT QL S.. LOT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT 'TNPH.CNL RC FT · CNL TENS.CNL DPHI. r:DC N FOC. FDC GR. MLL SFLU.DIL MTEM. DIL DTL.SDT COST.SOT TT4.SDT LTT&.SDT DTLF.SDT DPHI.LDT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC PAGE: 16 1284.000 107.5'00 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999.250 -9'99.250 -999.250 -999.250 -9'99.250 3.317 -999.250 106.200 0.793 716.000 106.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.770 -999.250 112.100 0.440 713.600 1308.400 115.600 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 -999.250 --999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~,~LASK~ COMPUTING CENTER CALI,. FDC -999. 250 GR.FOC H O. ML~L - 9'99.2 50 T f N S. MLL DEPT. 490~0.000 ILD.OIL SP. git -36.1 88 GR.DIL MRES.DIL -999.250 H'TEN.D[L DTSM. SDT 109.000 COHC. SOT 'TT1. SDT 680. 000 T:TO. SDT LTTI.SDT 1263..6 O0 LTT2.SDT WFC.SDT 3.000 WFSH. SDT DTCO. SOT 109.6,25 GR.SOT RHO~.LDT -999.250 gRHD.LDT QS S.LDT -999.. 250 LS.LOT LITH.LDT -999. 250 SSI.LOT SSHV. LDT -999.250 S1RH.LDT C .A L I. L D T - 999.2 50 G R. L D T MRES.LDT -999.Z50 HTEN.LDT TNRAoCNL -999.250 NPORoCNL CNTC.CNL -999. 250 CFT:C. CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC · C ALI. FDC -999. 250 GR. FDC HO.MLL '-999.250 TENS. MLL DEPT. 4800. 000 ILO. OIL SP. OIL -42. 813 GR. OIL MRES.OII -999.2:50 HTEN.OIL DTSM. SDT 111. 000 COHC. SDT TT1. SDT 645. 200 TT2. SDT LTTI.. SOT 1163.200 LTTZ.SDT WFC.SDT 0.000 WFSH.SDT gTCO. SOT 105. 000 GR. SDT RHCB.LDT -999.250 DRHO.:LDT QSS.LDT -9 99. 250 LS.LDT LITH.LDT -999. 250 SS1.LDT SSflV.LDT -999. 250 SIRH.LDT CALI.LD'T -999. 250 GE.LDT MRES.LDT -999.250 HTEN.LDT TNRA.CNL -999. 250 NPOR.CNL CNTC.CNL -999. 250 CFTC.CNL M~ES.CNL -999.250 MTEM.CNL RHOB.FOC -999.250 ORHO.FDC C4LI. FDC -999.2 50 GR.FDC HD.MLL -999.250 TENS.MLL DEPT. 4700.000 ILD.DIL SP. DIL -35.313 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM. SDT 174. OOD CDHC. SDT TT1. SDT 640.8 O0 TT2. SDT LTTI.SDT 1142.800 LTTZ.SOT WFC.SOT 0.000 WFSH.SOT DTCO. SOT IDO. 000 GR. SDT RHOB.LDT -999.250 DRHO.LDT QSS.LOT -9 99.2 50 ES,. LOT 28-SEP-1989 12:51 -999.250 'TENS. FDC -999.250 -999.250 1.711 ILM.DIL 1.732 100. 188 'TENS.DIL 2914.000 -999.250 DT. SDT 111.000 0.250 COHS.SDT 0,.910 475.600 TT3.SDT 934.000 1055.Z00 LTT3.SDT 1480.000 O. 000 DTLN. SOT 107.400 10,4.063 TENSoSDT 2766..000 -999.250 PEF.LDT -999.250 -99 ;9.250 L :U,. L O T - 999.250 -999.250 SS2.LOT -999.250 -999.250 LSRH.LDT -999.o250 -999. ZS0 TENS.LDT -999.250 -999.250 NPHI,.CNL -999.250 -999.250 RCNT.CNL -999"250 -999. 250 GR.CNL -999.2 50 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FDC -399.250 -999.250 TENS.FDC -999.250 -999. 250 4. 540 ILM. DIL t60. 250 TENS.DIL -999. 250 DT. SOT O. 916 COHS. SOT 445.200 TT3.SDT 964.000 LTT3.SOT 10.000 DT:LN. SDT 155.250 'TENS.SDT -9'99. 250 PEF.LDT - 999. 250 LU.~L DT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 TENS.LDT -999.250 NPHI.CNL -999.250 RCNT.CNL -999. 250 GR.CNL -999.;!50 HTEN.CNL -999.250 FFOC.FDC -999.250 TENS.FDC -999.250 4.680 286 ¢.. 000 102.600 0. 933 848.400 136 3.600 99.800 2780.000 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.216 ILM.DIL 3.161 101.188 TENS.DIL 2790.000 -999.250 DT.SDT 102.100 0.896 COHS.SDT 0.523 442.400 TT3.SDT 840.000 955. ZOO LTT).SDT 1344.000 10.000 DTLN.SDT 103.400 10'7.125 TENS.SDT 2610.000 -999.250 PEF.LDT -999.250 -999. 250 LU.L DT -999. 250 GR. MLL SFLU.DIL MTEM.OIL DTL. SOT COST. SOT TT¢. SOT LTT4.SDT DTLF.SDT DPHI.LDT QL ,S. L:DT LL.LOT LSHV.LDT LUR H. LOT MTEM. LOT TN'PH. CNL RCFT.CNL T E N S. C N L DPHIo FDC N F'DC. FD C G R. MLL SFLU.DIL MTEM. DIL OT L. S'O T COST. SOT TT¢.SDT LTT¢.SDT DTLF. SDT D~HI.LDT QLS.LDT LL. LOT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC. FDC GR.MLL SFLU.DIL MTEM.OIL DTL.SDT COST.SDT TT4.SDT LTT~. SDT DTLF.SDT DPHI.LDT QLS.LDT LL.LDT PAGE: 17 -999.250 1.593 -999.250 108.400 0.363 690.400 1271.200 106.500 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.~50 -999.250 -999.250 -999'250 -999.250 -999.2~0 5.023 -999.250 103.000 0.250 645.200 1166.400 99.100 -999.250 -999.250 -999.25:0 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 3.127 -999.250 102.100 0.250 642.800 1150.400 102.600 -999.250 -999.250 -999.250 LIS TAPE VERIFiCaTION LISTING SCHLUMBERGER )LASK=~ COMPUTING CENTER 'LITH.LOT -999. 250 SS1.LDT SSHV. LDT -999.250 S1RH.LDT C ~LI.LDrT -999. 250 GR.LDT MRFS.LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 C~FTC.CNL MRES.CNL -9'99.250 MTEM.CNL RHDB.FDC -999.250 ORHO.FDC CALI.FDC -999. 250 GE.FOC HD. MLL -999.250 TENS. MLL DEPT. 4600.000 ILO. OIL SP. DIL -42.2,50 GR.DIL M~ES. OIL -:999. ZSO HTEN.DIL DTSMo SOT 100.000 COHC.SDT TTlo SOT 642. 000 TT2. SOT LTT1.SDT 11.26.400 LTTZ.SDT HFCoSDT 0.000 ~FSH.SDT DTCg.o SDT 100. 000 GR. SDT RHOS.LDT -999. 250 DRHO.LDT QSS.LOT -999.250 LS.LDT ;LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999. 250 SIRH.LDT CALI..LDT -999. Z 5'0 gR.LDT MRES.LDT -999'250, HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999. 250 CFTC.CNL M R E S. C N L -999. Z 50 M T E M.. C N L RHD~.'FDC -999.200 DRHO.FDC CALI.FDC -999.2 50 GR. FDC HD. MLL -999. 250 TENS.MLL DEPT. 4500. 000 ILO. OIL SP.DIL -39.563 GR.DIL MRES.DIL -999.250 HTE'N.DIL DTSM.SDT 100.000 CDHC.SDT TT1. SDT 655.2.00 TT2. SOT LTT1.SDT 1169.600 LTTZ.SDT WFC.SDT 0.000 WFSH.SDT DTCg. SDT 100. OOO GR. SDT RHO~.LDT -999.250 DRHO.LDT Q SS.LDT -999.2 50 LS.LDT LITM.LD'T -999. 250 SS1.LDT SSHV.LDT -999. 250 SIRH.LDT CALI.LDT -999.2 50 GR.LDT MRES. LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB. 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SOT -999.250 PEF.LDT -999. 250 LU.LDT -999.250 SS2.LOT -999.250 LSRH.LDT -999.250 TENS.LDT -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.250 TEN$.FDC -999.250 3.403 2704. 000 99.8OO 0.339 841.200 1324.0:00 98.200 2590.000 -999. 250 - 999.250 - 999,. Z 50 -999.250 - 9:99. Z 50 -999.250 - 999.2 SO -999.250 -999.250 -999..250 -999.250 Z. 862 2794. 000 100.000 0..339 851.600 1378.800 100.000 2684.000 -999.250 -999.2.50 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 LSHV.LDT LURH.LDT MTEM. LDT TNPH. CNL RCFT.CNL TENS..CNL DPH I. FDC NFDC. FDC GR' MLL SFLU. OIL MTEM.DIL O'TL. SOT CO ST. SOT TT4. SOT LTT4. SOT DT,LF. SDT DPHI.LDT QLS.LDT LL. LDT LSHVoLDT LURH.LDT MTEM.L. DT T NP H. CNL R C F T. C NL TENS.CNL DPHI. FDC NFDC.FDC GR.MLL SFLU. DIL MTEM. DIL DTL. SOT COST.SOT TT4.SDT LTT4. SOT DTLF.SDT DPHI.LDT QLS.LDT LL.LDT LSHV.I. DT LURH.LDT MTEM.LDT TNPH.CNL R CFT. CNL TENS-CNL DPHI.FDC NFOC.FDC GR.MLL PAGE: 18 -999. 250 -999.250 .-999.2S0 -999.250 -999.250 -999. 250 - 999.250 · - 999.2 $ 0 -999.250 3.729 -999.250 99- 600 0.250 639.200 1129.200 98.300 -999.2 -999.250 -999.25~0 -999.250 -999.250 -999.2 S 0 -999.250 -999. 250 -999.250 -999. 250 -999.250 -999.250 3.193 -999.250 I00.200 0.280 653.200 1175.600 100.400 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERZFICATION LISTZNG SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. ¢400.000 ILD. OIL SP. OIL -37.625 GR.DIL MRES.DIL -999.250 HTEN.OIL DTSM. SOT 150. 000 CDHC. SDT T T 1. S D T 62,3.600 T T 2 - S D T LTTI.SDT 1138.40D LTT2.SDT WFC.SOT 0.000 WFSH.SOT gTCO. SOT !go, 000 GR.SOT RHOB.'LDT '-999'250 DRHO.LDT QSS.LDT -999.250 LS.LOT LITH.LDT -999. 250 SSloLOT SSHV.LDT -999. 250 S1RH.LDT CALI.LDT -999. 250 OR.LOT MRES.LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -9'99,250 CFTC.CNL M'RES.CNL -999.250 MTEM.CNL RHOB. FDC -999.2;50 DRHO. FOC CALS.FOC -999. 250 GR. FDC H O. ML L - g g 9.2 50 'T E N S. M L,L DEPT. 4300.000 ILO.OIL SP.OIL -39.625 GR.OIL MRES. DIL -999.250 HTEN. DIL DTSM.SDT 167.000 C~.HC. SOT TT1. SOT 648. OOO TT2. SOT L'TTI.SDT 1157.200 LTTZ.SDT WFC.SDT 0.000 WFSH.SDT DTCO. SOT 100. 000 GR.SDT RHDB.LOT -999. 250 DRHD. LDT QSS.LDT -9gg. 250 LS.LDT LITH.LOT -999. 250 S S1.LOT SSHV.LDT -g'gg.250 SIRH.LDT CALI.LDT -999.2 50 GR.LDT MRES.LDT -999.25,0 HTEN.LDT TNRA.CNL -ggg.250 NPgR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.2150 MTEM.CNL RHOB.FDC -999.250 DRHD.FDC CALI. rDC -9 go. 250 GR. FDC HD. MLL -goo.z50 TENS.MLL DEPT. 4200.000 ILD.DIL SP.DIL -40.750 GR.DII MRES.DIL -999.250 HTEN.DIL DTSM.SDT 157.000 COHC.SDT TT1. SOT 655.6 gO TT2. SDT LTTloSOT 1188.000 LTT2.SDT WFC. SOT O. 0 O0 WFSH. SOT DTCO. SOT 104.0 O0 GR.SDT RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999. 250 LS.LDT LITH. LOT -ggg. 250 S S!. LDT SSHV.LDT -ggg.ZEO SIRH.LDT CALI.LDT -9gg. 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SDT 10.~00 DTLN.SDT 117.688 TENS.SDT -999.250 PEF.LDT -999.250 LU.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 TENS.LDT 3. 372 2810.000 1,0 0.800 0.339 822.000 1338. 800 100.600 2654. 000 -999.250 -999. 250 -999. 250 -999. Z 50 -999.250 -999.250 --999.250 -999=.250 -999.150 -999.250 - 999.250 3.. 049 2650.000 100.100 0,. 250 8¢7. 200 1356.800 99. 800 2 594. O00 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999,.250 -999. 250 -999.250 3.226 2644.000 103.700 0.250 863.600 1401.600 103.300 2504.000 -999.250 -999.250 -ggg. ZEO -999.250 -999.250 SFLU. OIL M'TEM. OIL DTL. SOT COST. SDT TT4.SOT LTT4. SOT DTLF.SDT DPHI.LDT QLS.LDT LL.LDT L S H V. L D'T LURH.LDT MTEM.LDT T N P H. C N L R C F T. C NL TEN S.. CNL DPHI.FDC NFDC.FDC G R. ME L S FL U. O I L MTEM.DIL DTL. SOT COST. SDT TT4. SDT LTT4. SOT DTLF. SDT DPHI. LOT QLS.LDT LL.LDT LSH¥.LDT LURH. LOT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GR.MLL SFLU.DIL MTEM.DIL DTL.SDT COST.SOT TT4.SDT LTT4.SDT DTLF. SOT DPHI.LDT QLS .LOT LL.LDT L SHY. LOT LUEH.LDT MTEM.LDT PAGE: 19 3.283 -999 . 25:0 100.800 0.250 620.800 11.40.000 lO0.OOO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.231 -999.250 100 .. 200 0.448 646.800 1162.400 98.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -ggg.250 3.195 -999.250 103.600 0.256 655.200 1192.000 103.500 -goo.z50 -ggg.250 -9'99.250 -999.250 -ggg.250 -999.250 LXS TAPE VERIFIC.~TION LISTING SCHLUMBERGER ~.L~ASKA COMPUTING CENTE~ MRES,. LOT -999. 250 HTENoLOT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999'2'50 CFTC.CNL M R E S. C N L - :999.250 M T E M. C N L RHOB.FOC -999.250 ORHO.FDC CALX. FDC -999.250 GR.FgC H g. ML L -;999.250 T E N :S. M L L DEPT. 4100. 000 ILO. SP.DIL -47. 063 GR.DIL MRES.DIL -999.25D HTEN.DIL DTSM. SDT 154.000 COHC.SOT Tll. SDT 657.Z00 T'T2. SOT LTTI.SDT .11,95.600 LTT2.SDT WFC,. SOT 0.000 WFSH.SDT gTCO. SDT 106. 000 GR. SOT RHOB..LDT -999. 250 DRHO.LD'T QSS.LDT -99'9. 250 LS.LDT L ITH.LDT -999.250 S Si.LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999. 250 GE.LOT MRES.LDT -999., 250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFT,CoCNL MRES.CNL -999.250 MTEM.CNL RHOS. FDC -999.250 DEMO. FDC CALI,. FDC -999.250 GR HO. MLL -999.250 'TENS.MLL DEPT. 4000. 000 ILD'DI:L SP.DIL -51. 281 OR.git MRES.DIL -999.250 HTEN.DIL DTSM. SDT 15~.000 COHC.SDT TT1. SOT 669. 600 TT2. SOT LTT1.SDT 1201.200 LTT2.SDT WFC.SDT O.O00 WFSH.SDT DT-CD.SDT 107. 000 GR. SOT RHO~.LDT -999.250 DRHO.LOT QSS. LDT -999. 250 LS.LDT L ITH. LOT -999. 250 SS1.LDT SSHV.LDT -999.250 SIRH.LDT C:~LI.LDT -999. 250 GR.LDT MRES.LDT -999. 250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 ORHO.FOC C ~LI. FDC -999.2 50 GR.FDC HD.MLL -999.250 TENS.MLL gEPT. 3900.000 ILO.OIL SPoDIL -43.0~1 OR.OIL MRES.DIL -999.250 HTEN.DIL gTSM.SDT 15).00D COHC.SDT TTI.SDT 684.800 TT2.SDT 28-SEP-1989 12:51 -999.250 NPHI.CNL -999.250 -999. 250 ~CN'T.CNL -999.250 -999° 250 GRoCNL -999.250 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FD~C -999.250 -999. 250 TENS.FDC -999.250 -999.25,0 3.589 ILM.DIL 3-572 i21o750 TENS. OIL 2530.000 -999 250 DT.SDT ;!04,.,,600 0o919 COHS.SOT 0.252 4Z+~. 000 TT3. SDT 866.000 983.600 LTT3.SOT lO. O00 DTLN.SDT 104.200 129. 500 TENS.SDT 2504'000 -999° 250 PEF.rLDT --999.250 -999.2'5;0 LU.LDT -999., 250 -999.250 SS2.LOT -999.250 -999.250 'LSRH.LDT -9gg.ozEO -999.250 TENS.LOT -999.250 -999.250 NPHI.£NL -999.250 -999.250 RCNT.CNL -999.250 -99'9. 250 GR.CNL -999.250 -999.250 HTEN.CNL -999°250 -999.250 FFOC.FDC -999.250 -999. 250 TENS.FDC -999.250 - 99:9.250 3.763 ILM.DIL 127.18,8 TENS.OIL -999. 250 DT.SDT 0.B93 COHS.SOT 453.600 TT3. SOT 999.200 LTT3.SDT 10.000 DTLN.SDT 138.875 TENS.SOT -999..250 PEF.LDT -999..,250 LU.LDT -999.250 SSI.LOT -999. 250 LSRH.LDT -:)99.250 TEN'S.LOT -999.250 N~HI.~NL -999. 250 RCNT.CNL -999. 250 GR.CNL -999.250 HTEN.CNL -999.250 ~FDC.FDC -999.250 TENS.FDC -999.250 3.242 ILM.DIL 97.563 TENS.OIL -999.250 DT.SDT 0.916 COHS.SDT 458.000 TT3.SDT 3.727 2464.000 107.400 0.252 8B0.800 1¢11.600 106.300 2464.000 -999.250 -999.250 -999.250 -999o250 -999.250 -999.250 -999.250 -999.250 -999.250 -ggg.250 -goo. z50 3.130 2490.000 107.600 0.253 B98.000 TNPH.CNL RCFT.CNL TENS.CNL DPHI-FDC NFDC. FDC G~oMLL SFLU.DIL MTEM..OIL OTL. SOT COST.SOT TT4.SDT LTT4.SDT DTLFoSDT DPH~oLDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEMoLDT TNPHoCNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GR.MLL SFLU.DIL MTEM.DIL DTL.SDT COST.SOT TT4.SDT L'TT4.S~T DTL~oSDT DPHI.LDT ~LS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LOT TNPHoCNL RCFT.CNL TENS. CNL DPHI.FDC NFgC.FDC GR.MLL SFLU.DIL MTEM.DIL DTL. SDT COST.SOT TT4.SDT PAGE: 20 --999.2 50 -999 · 2 -999.250 - 999.250 -999.2.50 -999.250 3.784 -999.250 104.200 0.250 656.800 1202.000 103.600 -999.250 ,-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.928 -999.250 106.700 0.250 670.000 1205.600 105.800 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25~ -999.250 -999.250 -999.Z50 3.122 -999.250 107.600 0.296 684.400 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER LTT1.SDT 1217.200 LTT2.SDT WFC.$DT 0.000 WFSH.SDT DTCO. SOT 111. 000 GR.SOT RHOS.LDT -999.250 ORHO.LOT QSS.LDT -999. 250 LS.LDT L ITH.LDT -999'250 S S1.LDT SSHV.LDT -999.250 S1RH.LDT CALI.LOT -999. 250 GR.LDT MRES.LOT -999.250 HTEN.LDT TNRA.CNL -999.250 NP'OR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 ORHD. F:OC CALI.FDC -999. 250 GR.FDC HD.MLL -999.250 TENS.MLL DEP'T. 3800. 000 I'LD. OIL SP. OIL -42. 625 GR. OIL MRES.DIL -999.250 H?EN.DIL DTSM. SDT 117.000 COHC.SDT TT1. SOT 694. 400 TT2. SOT LTT1.SDT 1265.600 LTT2oSDT WFC.SDT 0.000 WFSH.SDT DTCO. SOT 112. 000 GR.SDT RHD~.LDT -999.250 DRHO.LDT ~SS.LDT -999. 250 LS.LDT LITH.LDT -999.250 SSI.LOT SSHV.LDT -999.250 SI~H.LDT CALI.LDT -999.2.50 GR.EDT MRES.LDT -999. 250 HTE:N. LOT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 DRHO. FDC C ALI. mDC -999.2 50 GR.FDC HD. MLL -999.250 TENS.NLL DEPT. 3700.000 [LO.OIL SP.DIL -40. 813 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM. SDT 117.000 CCMC.SOT TT1. SOT 714. 000 TT2.SDT LTTI.SDT 1293.200 LTTZ.SDT WFC.SDT 0.000 WFSH.SDT DTCO. SOT 117. O O0 GR.SDT RHOBoLDT -999.250 DRHO.LDT · QSS.LDT -999.2 50 LS.LOT L ITH. LET -999.2 50 S S1.LDT SSHV.LDT -999.250 SIRH.LDT C ~LI.LDT -999. 250 GR.'L DT MRES.LDT -999.250 HTEN.LDT TNRA.CNL -999.2 50 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999. 250 MTEM.CNL RHO~- ,mDC -999.250 gRHO.FDC 28-SEP-1989 12:51 1020.800 LTT3.SDT 1~31.200 10. OOO DTLN.SDT 108.500 106.563 TENS.SOT 2414.000 -999.250 PEF.LDT -999.250 -999. 250 LU.LD'T -999.250 -999. 250 SS2..[DT -999.250 --999. 2510 LSRH.LDT -999,. 250 - 999.250 · T E N S .. L O T - 999.. 250 -999. 250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -999.250 HTEN.CNL -999..250 - '999.250 F F D C. F D C - 99 9.250 -999.250 TENS.FDC -999.250 -999. 250 3.156 ILM.OIL 3.057 to2. ~3.8 TENS. OIL 2390.000 -999. 250 OT. SOT 111.500 0-89t COHS. SDT 0.321 469.200 TT3. SDT 920.000 1 0,49. 200 LTT3. SOT 1,487.3200 lO.OOO DTLN.S, DT 111.300 114.875 TENS.SOT 2280.000 -999.250 PEF.LDT -999.250 -999. 250 IU.LDT --999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH,.LDT -999.250 -999.250 TENS.LOT -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 - 999. 250 GR. C NL -999. 250 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 3.00.2 ILM. OIL 2.892 106.688 TENS.OIL 2370.000 -999. 250 DT. SDT 114. O00 0.961 COHS.SDT 0.321 489.200 TT3.SDT 944.000 1967.200 LTT3.SOT 1521.200 10o000 DTLN.SDT 112.800 109.250 TENS.SDT 2210.000 -999.250 PEF.LDT -999.250 -999. 250 LU. LDT --999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999. 250 NPHI.CNL -999.250 -~99.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999.250 -999.250 HTEN. CNL -999.250 -:999.250 FFOC.FDC -999.250 L T T 4. :S D T D T L F. SD T D P H I. L D T QLS.LDT LL.LDT L SHV. LB T LURH.LDT MT'EM.LOT TNPH.CNL RCFT. CNL TENS. C'NL DPHI.FDC NFDC.FDC G R. ML L SFLU.DIL MTEM.DIL DTL.SDT COST. SDT TT4.SDT LTT~,. SOT DTLF. SOT DPHI'LDT QLS .LOT LL.LDT L SHV.LDT LURH.LDT MTEM.LDT TNPH. CNL RCFT.CNL TENS.CNL DPHI. FDC N FDC. FOC GR.MLL SFLU.DIL MTEM.DIL DTL.SDT COST.SOT TT4.SDT LTT4.SDT DTLF. 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SOT LTT1.SDT 1218.400 LTT2.SDT WFC. SDT 0.0'90 WFSH.SDT D'TCg. SDT 108.0 OD GR. SOT RHD~.LDT -999.250 DRHO.LDT QSS.LDT -999. 250 LS.LDT 28-SEP,-1989 12:51 -999.250 TENS.FDC -999.250 -999.250 2.830 tLM.OtL 2.766 99.438 'TENS.OIL 2244.00;0 -999. 250 DT. SOT 114. 900 0.961 COHS.SDT 0.321 ~92.000 TT3.SDT 949.600 1084.000 LTT3.SDT 1534.800 10.000 OTLN.SDT 113,,100 100.B13 TENS.SOT 2094.000 -999.250 PEF.LDT -999.250 -999. Z50 LU.LOT -999. 250 -999.250: S S2.LD'T -999.250 -999.250 LSRH.LDT -999..250 -999.250 TENS.LDT -999.250 -999. 250 NPHI.CNL ,-99 9. 250 - 999.250 R C N T. C N L - 999.250 .-999.,250 GR.CNL '-999. Z50 -999.250 HTEN.CNL -999.250 -999.250 FF'DC. FOE -999.250 -999.250 TE NS.'FDC .-99 9.. 250 - 999.250 4.479 I L M. O I L ¢ . 305 105. 500 TENS.OIL 2294.000 - 9:99.250 O T. S O T 1 O 9.700 0.. 906 COHS. SOT O. 321 460. 000 T'T3. SDT 895.600 1020.800 LTT3.SOT 1455.600 10. 000 OTLN.. SDT 109. 200 ,108.438 TENS.SOT 2184.000 -999. 250 PEF.LDT -999. 250 -999.250 LU.EDT -999.250 -999.250 SS2.:LOT -999.250 -999. 250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -999..250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 5.369 ILM. DIL 5.134 94.375 TENS.OIL 2150.000 -999. 250 DT. SOT 10 3. 200 0.905 CDHS.SDT 0.321 448.000 TT3.SDT 898.400 1014.000 LTT3.SDT 14t0.000 10.000 DTLN.SDT 103.$00 99.3?5 TENS.SOT 2144.000 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 GR. MLL SFLU. OIL MTEM. DIL DTL. S'DT COST..SDT TT4. SOT, L TT4. SOT DTLF. SDT DPHI.LDT QLS.LDT LL.LDT L SH V. L D'T LU RH. LOT MTEM..LDT TNPH.CNL RCFT. CNL T E N S. C N L DPHIoFDC NFDC.FDC GR. MLL SFLU.OIL MTEM.DIL DTL. SOT COST. SOT TT4.SDT LTT4. SDT DTLFo SOT OPHI.LDT QLS.LOT LL.LDT LSHV.LOT LURH.LDT MTEM.LDT TNPHoCNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GR. MLL SFLU.DIL MTEM.DtL DTL. SOT COST.SOT 'TT4. SOT LTT4.SDT DTLF. SOT DPHI.LDT QLS .LOT LL.LDT -999.250 2.586 -999.25'0 115.400 0.2'72 716.400 1314.000 113.300 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 4.142 -999.250 109.600 0.289 676.400 1243.200 109.400 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7.304 -999.250 103.000 0.266 679.600 1214.400 104.300 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER L ZTH. 'LOT -9 9'9.2 50 S S1 .LD'T SSHV.LDT -999.250 S1RH.LDT C AL[.LDT -999. Z50 GR.LDT MRES.LDT -999.250 HT EN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 gRHO.FOC C AL1. FDC -99~.. 250 GR.FDC HO. MLL -999. 250 TENS.MLL DEPT. ~300.000 ILO.OIL SP.DIL -46.750 GR..OIL MRES.DZL -999.250 HTEN.DIL DTSM. SOT 141. 000 COHCoSDT 'TT1. SOT 698. 400 TT2.SDT LTTI.SDT 1296.800 LTTZ.SDT WFC. S:DT 0.000 WFSH.SDT DTCO. SOT 111. 000 GR.SOT RHOB.LDT -999. 250 ORHO.LDT QSSoLDT -999.2 50 LS.LDT L ITH. LOT -999.2 50 SS!.LDT SSHV.LOT -999.250 S1RH..LDT CALI.LOT -999. 250 GR.LDT MRES.LDT '-999. 250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -gg9. 250 CFTC.CNL MRES.CNL -999.250 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC C A t I. F D C .- 999.2 50 G R. F D:C HO,. MLL -999.250 TENS.MLL DEPT. 3200. 000 ILO.DI:L SP.DIL -4B. 750 GR.DIL MRES.DIL -999.250 HTEN.D!L OTSM.SDT 121.000 CgHC.SDT TT1. SOT 728. 400 TT2. SOT LTT1.SDT 1302.000 LTT2o'SDT WFC. SOT 0.000 WFSH.SDT DTCO. SOT 117. 000 GR. SOT RHOB.LDT -999.250 DRHO.LDT QSS. LOT -999.2 50 LS.LDT L ITH. LOT -999.2 50 S S1 .LOT SSHV.LOT -999.250 SIRH.LDT CALl.LOT -999. 250 GR.LOT MRES.LOT -9gg.zso HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL MRES.CNL -9gg. 250 MTEM.CNL RHDB.FDC -9'99.250 gRHO. FDC C ALI. FDC -999.2 50 GR. FOC HD.MLL -9'99.250 TENS.MLL 28-SE:P-t989 12:51 - 999. 250 SS2.LDT -99'9. 250 -999.250 LSRH.LDT '-999. 250 -999.250 'TENS.LDT -999.250 -999. 250 NPHI:.CNL -99'9. 250 -999. 250 RCNT.CNL -999.250 · - g 99.250 G R. C NL -99 g. 250 -999.250 HTEN..CNL -999.250 -999.250 FFDC. FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 3.310 ILM. DIL 96. 875 TENS.OIL -999. 250 DT.SDT 0.886 COHS. SDT ~77.600 T'T3.SDT 1072.800 LTT3'SDT 10.000 OTLN.SD'T 9:~. 750 TENS. SOT - 999. ,250 P E F. L 0 T -999.250 LU.LDT -999.250 SS2.LgT -999.250 LSRH.LOT -999..250 TENS.LOT -999.25'0 NPHI.CNL -999. 250 RCNT.CNL -999. 250 GR.CNL -999.250 HTEN.CN'L -999.250 FFOC.FDC -999.250 TENS.FOC -999.250 2 .. 979 233 O. 000 112. g 00 O.B81 941.600 1530.400 111.900 2010.000 -999.250 -999.. 250 -99 9.. 250 -99 9:. Z 5,0 - g 99 :. 250 -999.250 -99'9. Z50 -999.250 -99'9. 250 -999.250 -99 g. :250 4. B2~ ILM. DIL 103.188 TENS.OIL 2210.000 -999. 250 DT. SOT 114.900 0.95:B COHS. SOT 0.953 494.000 TT3. SDT 962.000 1079.200 LTT3.SDT 1528.800 iO.DO0 DTLN.SDT 111.000 102.750 TENS.SOT 1955.000 -999.250 PEF.LDT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.250 -g99.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 - 999. 250 GR. C NL -99 9. 250 -999.250 HTEN.CNL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 LSHV. LDT LURH.LDT MTEM.LDT TNPH.C:NL RCF T. CNL TENS.CNL DPHI. FDC NFDC. FDC GR. MLL SFLU.OIL MTEM.DIL DT L. SOT COST. SOT TT~.SDT LTT4.. SOT D'TLF. SOT DPH'I.LOT QLS.LDT LL.LDT LSHV.LDT L U R H. L D'T MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DP H I. FDC NFDC. GR. MLL SFLU.DIL MTEM. OIL DTL. SOT COST. SDT TT.4. SOT LTT4.SDT DTLF. SOT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TEN$.CNL DPHI.FDC NFDC.FDC GR.MLL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999.250 2.595 -999.250 112.400 0.262 697.600 1297.200 111.700 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.I84 -999.250 113.600 0.250 732.000 1307.600 112.300 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -g99.250 -g99.250 -999.250 23 LIS TAPE VERIFICATION LISTING SCHLUM~BERGER ALASKA COMPUTING CENTER DEPT. 3100. 000 ILO. OIL SP.DIL -50. 500 GR.DIL MRES.DIL -999.250 HTEN.DIL DTSM..SDT 131.000 COHC.SDT 'TT1. SOT 779. 200 TT2. SOT LTT1.SDT t390.400 LTT2.SDT WFC. SOT 0.000 WFSM.SDT DTCO.SDT 129.000 G~. SOT RHOB.LDT -999. 250 ORHD. LOT Q $ S. L D T -999. Z 50 L $, L D T l ITH. LDT -999,Z 50 SSI.LDT SSHV.LDT -999.250 SIRH.LDT C ~LI..LDT -999. 250 GR.LDT MRES.LDT -ggg. 250 HTEN.LDT TNRA.CNL -999'250 NPDR.CNL C N T C. C N L - 9 99.2 50 C F T C. C N L MRES.CNL -999.250 MTEM.CNL RHOB. FDC -999.250 DRHO. FDC CALI. FDC -999,2 50 GR.FOC HO. MLL -999. 250 TENS-MLL DEPT. 3000. 000 ILO.OIL SP.DIL 15.250 GR.DIL M~ES.DIL 12..328 HTEN.DIL D'TSM. SOT 108.000 COHC.SOT TT1. SOT 690,400 TT 2. SOT LTTI.o SOT 1398. OOO LTT2. SOT WFC. SOT 0.000 WFSH.SOT DTCO. SOT 119. 000 GR.SDT RHOB.LDT 2.009 DRHO..LDT QSS.LDT 0.017 LS.LDT LITH. LD'T 186. DO0 SS1.LgT SSHV.LDT 1)19.000 SIRH.LDT CALI.LDT 10.852 GR.LOT MRES.LDT 112,328 HTEN.LDT TNRA.CNL 3.569 NPOR.CNL CNTC.CNL 17'70.564 CFTC.CNL MRES.CNL 12.328 MTEM.CNL RHO~.FDC -999.250 DRHO. FDC C ALI. FDC -999.2 50 GR. FDC HD.MLL -999.250 TENS.MLL DEPT. 2900.000 ILD.D!L SP.DIL -22.500 GR.DIL MRES.DIL 11.594 HTEN.DIL DTSM. SDT -999.250 COHC.SDT TT1. SOT -999. 250 TT2. SDT LTTI.SDT -999.250 LTT2.SDT WFC.SDT -999.250 WFSH.SDT DTCO. SOT -9 99.2 50 GR. SOT RHOB.LDT 2.241 ORHO.LDT QSS.LOT 0.038 L$.LDT IITH.LDT 1Z7. 625 S S1.LOT SSHV.LDT 1319.000 SIRH.LOT C&LI.LDT 12.766 GR.LOT 28-SEP.-1989 12:51 3. 703 ILM.DIL 84.000 TENS.OIL -999,250 DT.SDT 0.938 CO:MS.SOT 524.~00 T'T3. SOT t157.6~00 LTT3. SDT 10. 000 DTLN. SOT 103. 375 TENS. SDT -999,250 PEF. LDT -999 250 LU.LOT -999. 250 SS2.LDT -999. ZSO iLSRH.LDT -999.250 TENS.LOT '-999.250 NPHI.CNL -999. 250 RCNT.CNL -999. 250 GR.CNL -999.250 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS'FDC -999. ~50 4.328 ILMoDIL 75.625 TENS.OIL 1158. 000 OT. SOT 0.896 COHS.SDT 497.600 TT3. SOT 975.200 LTT3.SOT 10.000 OTLN.SDT 72.750 TENS.SOT 0.011 PEF.LDT 589.000 LU. LOT 230. 375 SS2.LDT 1-956 LSRH.LOT 99.438 TENS.LOT 1158.000 NPHI.CNL 40.¢66 RCNT.CNL 504.207 GR. CNL 72.000 MTENoCNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 5.230 ILM.DIL 73.063 TENS.DIL 1003.000 DT.SOT -999.250 COHS.SDT -999.250 TT3.SDT -999.250 LTT3.SDT -999.250 DTLN.SDT -999.250 TENS.SOT 0.028 PEF.LOT 400.250 LU.LDT 224. ,'375 S.S2. LDT 2.131 LSRH.LDT 73.063 TENS.LOT ,3.42 2114-000 125.400 O. 93.2 t 020.400 1634. 124. 700 1805.000 -999.250 '- 9 9 9.250 -9'9 9. 250 - 999. ,250 -999. 250 -999.250 -999°250 - 99 g..250 -999.250 -999.250 -99 9. 250 4.212 2810.000 145. ,200 0.926 872.000 1634. 000 14 9.. 400 1800.000 541.500 353.250 1.998 4,1.101 1841.052 99.438 1158.000 -999.250 -999.250 5.199 2450.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2-625 370.500 321.500 2.213 2450.000 SFLU.OIL MTEM,OIL DTL. SOT COST. SOT TT.4. SOT L T T4. $ O T DTLF. SOT DPHI'LDT QLS.LDT LL.LDT L S HV. LO T ;LURM.LDT MTEM.LDT TNPH. CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GR. MLL SFLU.DIL MTEM. OIL DTL.SDT C 0 S T..S O T TT4.SDT L TT~.. SOT DTLF. SOT D PHI. L O T QL S. LOT LL.LDT LSHV. LOT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHIoFDC NFOC.FDC GR.MLL SFLU.DIL MTEM.OIL DTL. SOT COST. SDT TT¢.SDT LTT4, SDT DTLF. SOT DPHI .LOT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT PAGE: 24 3.07'5 -999.250 122.900 0. T 74 778.800 1393.600 123.000 -999.250 -999. 250 -999.250 -999. 250 -999. 250 -999.250 -999.2 50 -999.250 -999. ,250 -999. 250 -999.250 -999.250 4..047 72. 000 144.700 0.900 700.4'00 1217. 600 14,1.000 35.847 -0.012 31B. 000 2.002 72.000 40.466 478.157 2810.000 -999.250 -999.250 -999.250 5.396 72.313 -999.250 -999.250 -999.250 -999.250 -999.250 24.792 -0.011 215.000 1402.000 2.215 72.313 LIS 'TAPE V~RIFIC~TION LISTING SCHLUMBERGER ~LASK~ COMPUTING .CENTER MRES.LDT 11.59¢ HTEN.LDT TNRA. CNL 3. B 55 NP OR.CNL CNTC.CNL 1796.829 CFTC.CNL MRES.CNL 11.594 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC C AL!. FDC -999. 250 GRoFDC HD. ML:L -999.250 'TENS.NEE DEPT. 2800. 000 ILO.DIE SP.DIL '-39. 750 GR.DIL MRES.DIL 11.734 HTEN.DIL OTSM.SDT -999.250 COMC.SDT TT1. SDT -999. 250 TTZ.SDT LTT1.SDT -999.250 LTT2.SDT WFC.SDT -'999.250 WFSH.SDT DTCD. SDT -999. 250 GR.SDT RHOB.LDT 2.27~ DEMO.EDT QSS.LDT O. 027 LS.]LDT LITH.EDT 105.8 75 SSI.LOT SSHV.LDT ~3~9.000 SI~H.LDT CALI.LOT 13.461 GR.LOT MRES.LDT 11.73~ HTEN.LDT TNRA.CNL 3.763 NPDR.CNL CNTC.CNL 18~9.220 CFTC.CNL MRES.CNL 11.73& MTEM.CNL RHDB.FDC -999.250 DEHD.FDC C ALI. FDC -999.2 50 GR.FDC HD.MLL -999.250 TENS.MLL DEPT. 2700.000 ILO.DIE SP.DIL -48.500 GR.DIL MRES.DIL 12.5-47 HTEN.DIL D'TSM.SDT -999.250 COHC.SDT TT1. SOT -999.250 TTZ. SOT LTTI.SDT -999.250 LTT2.SDT WFC.SOT -999.250 WFSH.SDT D'TCO. SOT -999. 250 GR. SOT RHOB.LDT 2.162 DRHO.LOT QSS.LDT 0.005 LS.LDT L ITH.LOT 136.6 25 S S1.LgT SSHV.LDT t319.000 SIRH.LDT CALI.LDT 12.641 GR.LDT MRES.LDT !2.547 HTEN.LDT TNRA.CNL 4.083 NPOR.CNL CNTC.CNL 1645.891 CFTC.CNL MRES.CNL 12.547 MTEM.CNL RHOB.mDC -999.250 DRHO.FOC C ALI. FDC -9gg. 2 50 GR. FDC HD.MLL -999.250 TENS.NEE DEPT. 2600.000 ILO.OIL SP.gIL -57.500 GR.DIL MRES.DIL 12.875 HTEN.DIL DTSM.SDT -999.250 CgHC.SDT TTI.SDT -9:99.250 TT2.SDT 28-SEP-19:89 12:51 1003. 000 NPHI.CNL 4.4,.36,3 RCNT.CNE 476.623 GR.CNL 72,.313 H'TEN.CNL -999.250 FFDC,.FDC -999.250 TENS.FDC -999. 250 6. 117 ILM.DIL 103.250 TENS.DIE 1028. 000 DT.SDT -999.250 COHS.SDT -ggg. 250 TT3.SOT -999. 250 ET'T3. SDT -999.250 DTLN.SOT -999.25:0 TENS.SOT 0.0:06 PEF.LD'T 363:. 000 LU.LDT Z13. 250 SS2.LDT 2. 240 LSRH.LOT 103. 250 TENS.LOT 1028.000 NPHI.CNL 4,2. 096 RCNT.CNL 52 O. 396 G R. C NL 73.125 H T E N. C NL -999.250 FFDC.FDC -999.250 TENS.FDC - 999.. 250 45.414 1 87 O. 895 73.063 I003.000 -999,250 -999. 250 5.850 2374.000 -999.250 -999.250 -99 g. ,250 -999.250 -999.25'0 ,-999.250 3.041 334. 500 306.1500 2..Z 64 2374.000 43.403 1856.630 103.250 lOZB.O00 -999,. 250 -999.250 4.,671 ILM. DIL 4.508 82.563 TENS.OIL 2354.000 1011.5.00 DT. SOT -99 g. 250 · -999.250 COHS.SDT -999.250 -999.250 TT3.SOT -999.250 -999.250 LTT3.SDT -999.250 -999. 250 DTLN.SDT -999. 250 -999.250 TENS.SOT -999.250 -0. 007 PEF.LDT Z.736 432. 500 LU.LDT 396.750 210.750 SS2.LDT 318.500 2.199 LSRH.LOT 2.168 82.563 TENS.EDT 2354.000 1011.500 NPHI.CNE 49.656 46.433 RCNT.CNL 1688.873 428. 077 GR.CNL 82. 563 72.813 HTEN.CNL 1011.500 -999.250 .~FDC.FDC -999.250 -999.250 TENS.FDC -999.250 -ggg. 250 6.046 ILM.DIL 6.026 78.938 TENS.OIL 2260.000 1016.500 OT.SDT -999.250 -999.250 COHS.SDT -999.250 -999.250 TT3.SDT -999.250 TNPH.CNL R CF T. CNL TENS o CNL DPHI. FDC NFDC. FOC G R. ML L SFLU.DIL MT E M. OIL DTL. SOT COST.SOT TT4.SDT LT'T~. SOT · DTL :F. SOT DPHIoLDT QLS,.LO'T EL.LOT L S H V. L D'T L U R H. L D'T M'TEM.LDT TNP H. C NL RCF. T. CNL 'TEN S. CNL DPHI. FDC NFDC. FDC GR. MLL SFLU. OIL MTEM.OIL DTL. SOT COST.SOT TT4. SDT LTT4.SDT DTLF. SOT DPHI.LDT QLS .LOT EL.LOT LSHV.LOT LURH.LDT M'TEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPH,I. f=DC NFOC.FDC GR.MLL SFLU.OIL MTEM.OIL OTL.SDT COST.SOT TT4.SDT PAGE: 25 44.430 454.354 2450.000 -999-250 -999.250 -999. 250 5.658 73. 125 -999.250 -999.2 50 - 999. Z 50 -999.250 - 999 . 250 22.950 0.004 195.750 1402. 000 2.275 73.125 · ¢ 0. 448 480.639 2374. ODD -999. 250 -999.250 -999.250 4.358 72. !)13 -999.250 -999.250 -999.250 -999. 250 -999.250 29.549 -0.005 234.125 1402.000 2.176 72.813 45.757 388.798 2354.000 -999.250 -999.250 -g 99. 250 6.482 72.688 -999.250 -ggg .250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTEE LTT1.SDT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH.SDT DTCg, SOT -999. 250 GR. SOT RHOBoLDT 2. 202 DRHO.LDT QSS.LDT O. 021 LS.LDT L ITH.LOT i19. 938 SS1 .LOT SSHV.LDT 1320.000 S1RH.LOT CALI.LDT 12. 883. GR.LDT MRES.LDT 12.875 HTEN.LDT 'TNRA. CNL 3.733 NPORoCNL C N T C. C N L 18 O 2.9 64 C F T C. C N L MRES.CNL 12.875 MTEM.CNL RHOB.FDC -999.250 DRHO.FgC CALI. FDC -9 99.2 50 GR. FDC HD.MLL -999.250 'TENSo'ELL DEPT 2500.000 ILO. OIL SP. OIL -67. 500 GR.DIL MRES.DIL 12.992 HTEN.DIL DTSM. SOT -999.250 CDHC.SOT TTI.. SOT -999.250 TT2. SOT LTT1. SDT -999.250 LTTZ.SDT WFC.SDT -999.250 WFSH.SDT DTCD. SOT -999. 250 GR, SOT RHOB.LDT 2. 201 gRHO.LOT Q S $. L g T 0.013 L S · L D T LITH.LDT 1)4.625 S S1.LDT SSHV.LDT 1~19.000 SIRH.LDT C~LI.LDT 12. 531 GR.LgT MRES.LDT 12.992 HTEN.LDT TNR~.CNL 4.167 NPOR.CNL CNTC.CNL 1585.353 CFTC.CNL MRES. CNL 12. 992 MTEM.CNL RHOS.FDC -999.250 D~HO:. FDC C~LI. FDC -999.2 50 GR.FDC HD.MLL -999.250 TENS.MLL DEPT. 2400.000 ILO.OIL SP.OIL -76.000 GR.DIL M, RES.DIL 12.930 HTEN.DIL DTSM.SDT -999.250 CDHC.SOT TTJ. SOT -999.250 TT2. SOT LTT1.SDT -999.250 LTTZ.SDT WFC.SDT -999.250 WFSH.SDT gTCO. SOT -999.2 50 GR. SOT RHOS.LDT 2.182 DRHO.LDT QSS.LDT 0.027 LS.LDT LITH. LDT 1 32.7 50 S S1. LDT SSHV.LDT 1320.000 SIRH.LDT CALI.LDT 13.086 GR.LDT MRES.LDT 12.930 HTEN.LDT TNRA.CNL 3.794 NPOE.CNL CNTC.CNL 1704.170 CFTC.CNL MRES.CNL 12. 930 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC 28-SEP-1989 12:51 -999.250 LT'T3.SDT -999.250 -999.250 DTLN.SDT -999.2.$0 -999.250 TENS.SOT --999.250 0.005 P;EF.LDT 3.012 4 ! 0.250 L U. L D T 3174 .. 250 216.625 SS2o:LDT 318.500 2.174 :LS~H.LDT 2.195 78.938 TENS.LOT 2260.000 1016.500 NPHI,.CNL 4'3.125 43.683 R C NT. C NL ! g 36.483 471. 299 GR.CNL 78. 938 7Z.688, HTEN.CNL 1016.500 -999. Z50 FFDC. FDC -999.,250 -999. 250 TENS.FDC '-999,. 250 -999. 250 8. 131 ILM.DIL 68.188 TENS.OIL 1000. 500 DT.SDT -999.250 COMS.SDT -999.250 TT3.SOT -999.250 LTT3.SDT -999.250 OTLN.SDT -999.250 TENS.SDT O. 007 PEF.LOT 414. 750 LU.LDT 217. 875 SS2oLDT 2. 164 LSRH.LDT 68. 188 TENS.LOT 1000. 500 NPHI.CNL 50.238 RCNT.CNL 391..955 GR.CNL 7t,.000 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC - 999.250 8.585 ILM.DIL 66,.I25 TENS.OIL 1025.000 DT.SDT -999.250 CDMS.SDT -999.250 TT3. SDT -999.250 LTT3.SDT -999.250 OTLN.SDT -999.250 TENS.SOT 0.011 PEF.LDT 431.000 LU.LDT 221.62S SS2.LDT 2.125 LSRH.LDT 66.125 TENS.LDT 1025.000 NPHI.CNL 41.496 RCNT.CNL 459. 642 GR.CNL 69.875 HTEN.CNL -999.250 FFDC.FDC 7. 897 223 O. 00'0 -999.250 -999.250 -999.250 -9'99.250 -999. 250 '-999.250 2. B 44 385.000 324. 000 2.193 2230.000 51.250 1617.¢27 6.8.188 1000.500 -999.250 -9:99.250 8.464 2164.000 -999.250 -999.250 -999.250 -999.250 -g99.250 -ggg.250 2.775 394.750 324.500 2.170 2164.000 44.145 1836.556 66.125 1025.000 -999.250 LTT,4. SOT DTL F. SD'T DPHI.LDT OLS.LDT LL..LDT L SHV. LOT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TEN S. CNL DPHI:.FDC NFDC.FDC GR. MLL SFLU.DIL MTEM. DTL.SDT COST.SOT TT,4. SOT LTT4. SDT DTLF. SOT DPHI.LDT QL S. L D T LL.LDT LSHV.LDT L URH ',LO T MTEM.LDT TNPH.CNL RCFT.CNL TEN S o CNL DPHI .FDC N~DC.FDC GE. MLL SFLU.DIL MTEM. DIL DTL. SOT COST. SOT TT4.SDT LTT4.SDT DTLF. SOT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS. CNL DPHI.FDC NFDC. FDC PAGE: 26 -999.250 -999.25:0 27.I76 0.007 223.250 1.402.000 2.209' 72.688 45.292 431.201 226:0.000 -999.250 -999.250 -999.250 8.583 71.000 -999.250 -999. 250 -999.250 -999.250 -999.250 27.193 -0. 019 222.125 1402. 000 2.193 71.000 49.212 366. 363 2230. 000 -999.250 -999.250 -999.250 8.151 69.875 -999.250 -999.250 -999.250 -999.250 -999.250 28.354 -0.003 233.500 1402.000 2.180 69.875 43.210 456.172 2164. 000 -999.250 -999.250 LIS TAPE VERIFICATZON LISTING SCHLUMBERGER ALASKA CONPUTING CENTER CAL]. FDC -999.2 50 GR.FD.C HD. MLL -999. 250 'TENS. MLL DEPT. 2300. 000 ILO.OIL SP.DIL -97.000 GR.DIL MRES.DIL 12.367' HTEN.DIL DTSM.SDT -999.250 COHC.SOT TT!. SOT -999.25:0 TT2. SOT LTT1.SDT -999.250 LTT2.SDT ~WFCoSDT -999.250 WFSH.SDT DTCO. SOT -999. 250 GR,.SDT RHOS.LOT 2. 057 DRHO.LD'T QSS. LOT 0.018 LS.LDT LITHoLDT !85. SO0 SSI.LOT SSHV.LDT 1319. 000 SIRH.LDT CALI.LDT 13.000 GR.LD'T MRES.LDT 1.2.367 HTEN.LDT TNRA.CNL 3.656 NPOR.CNL C N T C. C N L ! 820.060 C F'T C. C N L MRES.C'NL 12.367 MTEM.CNL RHOB. FOC -9'99.250 DRHO.F'DC C ~:L t. FDC -999.2 50 ~GR. FDC MD. MLL -999' 2 50 TENS. MLL DEPT. 2200. 000 ILD. E~IL SP. OIL -I 15. 813 GR..OIL MRES. DIL 12.203 HTEN.DIL DTSM. SOT -999.250 COHC.SD? TT1. SOT -999. 250 TT2.SOT LTT1. SOT -999. 250 LTT2. SOT WFC. SOT -999.250 WFSH.SDT OTCO. SOT -999.250 GR. SOT RHOB.LDT 2. 102 DRHO.LDT QSS.LDT 0,019 LS.LDT LITH. LOT 162.0 O0 SS1.LDT SSHV.LDT 1319.000 SIRH.LDT CALI.LDT 12,758 GR.LDT MRES.LDT 12.203 HTEN.LDT TNRA.CNL 3.919 NPOR.CNL CNTC.CNL 1677.408 CFTC.CNL MRES.CNL 12.203 MTEM.CNL RHOB.~DC -999.250 DRHO.FDC CALI. FDC -999.2 50 GR. FDC HD.MLL -999.250 TENS.MLL DEPT. 2100.000 ILO.OIL SP.DIL -154.000 GR.DIL MRES.DIL 11.039 HTEN.DIL DTSM.SOT -999.250 COHC.SDT TTI.SDT -999.250 TT2.SDT LTT1.SDT -999.250 LTT2.SDT WFC.SDT -999.250 WFSH.SDT DTCO. SDT --999.250 GR.SOT RHOB.LDT 2.052 DRHO.LOT QSS.LDT 0.019 LS.LDT 28-SEP-1989 12:51 -999.250 TENS.FDC -999.250 16.009 ILM.DIL 45.'406 TENS:.D, IL 1039.000 DT.SDT -999.~50 COHS.SDT -99'9.250 TT3. SOT -999.250 LTT3.S, OT -999.250 DTLN.SDT -999.250 TENS.SOT -0.010 PEF.LDT 526.000 L~U.LDT 214.375 SS2.LDT 2.[07 LSRH.LDT 45.406 TENS.LOT 1 03:9. 000 NPHI.CNL 41. 716 RCNT.CNL ~96. 201 GR.CNL 69. 750 HT!EN. CNL -999.250 FFDC.FDC -999.250 T:ENS.FDC -999.250 16.011 ILM.DIL 56.688 TENS.OIL 1005.000 DT.SOT -999.250 CDHS-SDT -999.250 TT3,.SDT -9'99.250 LTT3.-SDT -999.250 DTLN.SDT --999.250 TENS. SOT -0,. 002 PEF.LDT 489. 500 L~U. LDT 217.625 SS2.LDT 2.109 LSRH.LDT 56.688 TENS.LOT 1005.000 NPHI.CNL 43.316 RCNT.CNL 452.213 GR.CNL 69.813 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 22.058 ILM. DIL 33.375 TENS.OIL 1007.000 OT.SDT -999.250 COHS.SDT -999.250 TT3.SDT -999.250 LTT3.SDT -999.250 OTLN.SDT -999.250 TENS.SOT -0.004 PEF.LDT 537.000 LU.!LDT PAGE: 27 -999.250 GR.MLL -999'250 18.252 SFLU.DIL 2060.000 MTEM.DIL -999.250 OTL. SOT -999.250 COST.SOT -999..250 TT4.. SOT -999.250 LTT4.SDT -999.25.0 DTLF.SDT '-999. 250 DPHI.LOT 2.6,48 QLS.LDT 47 5.5:00 LL. LO T 32¢.250 LSHV.LDT 2.066 LURH.LDT 2060.000 MTEM.LDT 41.6.60 TNPH. CNL 1927.856 RCFT..CNL 45.406 TENS.CNL 1039.000 DPHI.FDC -999.250 NFOC. FDC -999.250 GR.MLL 15.514 SFLU.DIL 1890.000 MTEM.DIL -999.250 DTL. SOT - 999.250 C 0 S T. S O T -999.250 'TT~.SDT '-999,.250 LTT4.$DT -999..250 DTLF. SOT -999,250 ' OPMI.LDT 2.559 QLS.LDT 438.500 LLoLDT 326.500 LSHV.LDT 2.10~ LURH,.LOT 1.890.000 MTEM.LOT 46.597 TNPH.CNL 1748.114 RCFT.CNL 56.688 TENS.CNL 1005.000 DPHI.FDC -999.250 NFOC.FDC -999.250 GR.MLL 22.335 SFLU.DIL 1930.000 MTEM.DIL -999.250 DTL. SOT -999.250 COST.SOT -999.250 TT4.SDT -99'9.250 LTT4.SDT -999.250 DTLF. SOT -999.250 DPHI.LDT 2.246 QLS.LDT 485.500 LL.LDT 29.461 69.750 -999.250 -999. 250 -999,250 -999,250 -999.250 35.965 O. 009 288. 250 1402. 000 2.074 69.750 42. 599 505..435 206:0. 000 -999,250 -999. 250 -99.9.250 16.948 69.813 -999.250 -999.250 -999.250 -999.250 -999.250 33.197 0.018 270.000 1400.000 2.119 69.813 43.426 422.340 1890.000 -999.250 -999.250 -999.250 22.780 70.250 -999.250 -999.250 -999.250 -999.250 -ggg.2sO 36.262 0.009 294.500 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK.& COMPUTING CENTER LITH.LDT 188. 250 S SI..LDT SSHV.LDT 1320. 000 SIRH.LDT CALI.LDT 12. 641 GR. LOT MRES.LDT 11:.039 HTEN.LDT TNRA. CNL 3.480 NPOR.CNL CNTC.CNL 1738. 020 CFTC.CNL MRES.CNL l!.03g MTEM.CNL RHO~.FDC -999.250 DRHO.FDC C~LI. FDC -999. 250 GR. FDC HO. MLL -999.250 TENS.MLL DEPT. 2000. 000 ILO.OIL SP.DIL -1.46. 875 GR.DIL MRES.DIL 11.125 HTEN.DIL DTSMo S'DT -999. 250 COHC. SDT ~TT1. SOT -ggg. 250 TTZ. SOT LTT1.SDT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH.SOT DTCO. SDT -9 99.250 GR. SOT RHDS.LOT 2.084 DRHO.:LDT ~SS.LDT O. 019 LS.LDT L[TH.LDT ! 67,. 000 SSI.LDT SSHV.LDT 1319. 000 S1RH.LDT C ALI.:LDT 12.625 GE .LOT MRES.LDT 11-125 HTEN..:LDT TNRA.CNL 4.008 NPOR.CNL CNTC.CNL 1365.165 CFTC.CNL MRES.CNL 11.125 MTEM.CNL RHOB.FDC -999.250 ORHO.FDC C ALI. FDC '-999.250 GR. FOC HO. MLL -999. 250 TENS.MLL DEPT. 1900.000 ILO.OIL SP.DIL -138.625 GR.DIL MRES.DIL 11.219 HTEN.DIL DTSM.SDT -999.250 COHC.SOT TT1. SOT -999. 250 TT2. SOT LTTI.SDT -ggg.250 LTTZ.SDT WFC. SOT -9gg. 2 50 WFSH. SOT DTCO. SDT -999. 250 GR. SDT RHOB.LDT 2.187 ORHO.LDT QSS.LDT 0.011 LS.LDT LITH. LDT 128. 875 S S1.LOT SSHVoLDT 131g.o00 SIRH.LDT CALI.LDT 12.359 GR.LDT MRES.LDT 11. Zlg HTEN.LDT TNR~.CNL &.160 NPDR.CNL CNTC.CNL 1650.399 CFTC.CNL MRES.CNL 11.219 MTEM.CNL RHOB.FDC -999.250 DRHO.FOC CALI. FDC -999.2 50 GR.FOC HD.MLL -999.250 TENS.MLL 28-SEP-lgBg 12:51 218.875 .SS2.LDT 2.068 LSRH.LDT 33.3.75 'TENS,. LDT 1007.000 NPHI'CNL 37. B 25 R C N T. C :NL 499.674 GR.CNL 70.250 HT~N.CNL -999.250 FFDC. FDC -99'9. ~5:0 TENS.FDC -999.250 21...136 ILM. DIL 36.094 TENS.OIL 1000. SO0 OT.SDT -999. 250 CDHS.SOT -999.250 TT3. SOT -999.250 LTT3.SDT -999. 250 DTLN.SDT -999.250 TENS. SOT O. OOl PEF.LDT 507.750 L U. L D T 220. 125 SS2.LgT 2.080 LSRH.LDT 36. 094 TENS .LOT 1000.500 NPHI.CNL 5. 0.852 R C N'T . C .NL 329.547 G R. C N.L 70.438 HTEN.:CNL -999.250 FFDC.FDC -999.250 TENS.FOC '-999.250 13.656 ILM. DIL 55.250 TENS.OIL 969.000 DT. SOT -999.250 ~COHS.SOT -999.250 TT3.SOT -999.250 LTT3.SDT -ggg.zso OTLN.SOT -99:9.250 TENS.SDT -0.003 PEF.LDT 415.750 LU.LOT 212.375 SS2.LDT 2.199 LSRH.LDT 55.250 TENS.LOT 969.000 NPMI.CNL 4g.lll RCNT.CNL 408.052 GR.CNL 70.938 HTEN. CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 331. 750 193 O. :000 38..609 1884.084 33.3?5 1007,. 000 '-999.250 -9gg. 250 21.685 193 O. 000 - g 9 9.250 .-999.250 -9gg. 250 · -ggg. 250 ,-999. 250 '-'999. 2510 2.525 ,454. 750 331. 500 Z. OBZ 1930.000 4 B. 293 1424. 802 36.094 1000.500 - 9 99. Z 50 -999.250 12.806 1815.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.918 384.250 316.750 2.189 1~1~.000 51-208 1722.351 55.250 969.000 -999.250 -999.250 L S H V. L D T LURH.LOT MTEM,,LDT TNPH.CNL RCFT.CNL 'T E N S. C NL DPHI. FDC NFDC.~FDC G R. MLL SFLU.OIL M'TEM.DIL DTL. :SOT COST. SOT TT4. SDT L'T 74. SDT DTLF. SOT OPHI.LDT QLS.LDT LL.LDT L SHV. LD'T LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC G R. ML L SFLU.DIL MTEM.DIL DTL. SDT COST.SOT TT4.SDT :LTT4. SOT DTLF. SOT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPHoCNL RCFT.CNL TENS. £NL DPHI.FDC NFDC.FDC GR. MLL PAGE: 28 1401.000 2.063 70'250 39.697 501.344 1930.000 -999.250 -999.250 -999.250 23.707 70.438 -999.250 -999°250 -999.250 -999.250 -999.2510 34.279 0.019 280.500 1400.000 ,2. '70.438 51.057 299.365 1930.000 -999.250 -999.250 -999.250 13.588 70.938 -999-250 -999.250 -999.250 -999.250 -999.250 28.069 -0.009 224.750 1400.000 2.195 70.938 49.305 393.B07 1815.000 -9~9.250 -999.250 -ggg.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER DEPT. 1800.000 ILD.DIL SP.DIL -139. 375 GR.OIL MRES.DII 11.383 HTEN.DIL DTSM. SOT -ggg. 250 CCHC. SOT TT1.SDT -999. 250 TTZ. SOT LTT1. SOT -999. 250 LTT2. SOT WFC. SOT .-999.250 WF:SH.SDT DTCO. SOT -9 99. 250 GR, SOT RHO~..LDT 2.292 DRHO.LDT QSS.LDT O. 018 LS.LDT LITH. LOT 103. 313 SS1.LOT SSHV.LDT t319.000 SIRH.LD'T CALI.LOT 1Z. 633 GR.. :LOT MRES.LOT 11. 383 HTEN.LOT TNRA.CNL 3.88I NPOR.CNL CNTC.CNL 1681.271 CFTC.CNL MRES.CNL 11.383 MTEM.CNL RHOB.FDC -999.250 DRHO.Fg~C CALI. FDC -9 99.2 50 GR. FDC HO.MLL -9'99. 250 TENS.MLL O E P T. 1700.000 I L O . D I L SP.OII -149. 375 GR.OI1 MRES.DIL 11.383 MT EN.DIL DTSM.SDT -999.250 COHC.. SOT TTI..,SOT -99'9. 250 TT2. SOT LTTloSDT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH.SOT DTCO. SD'T -999. 250 GR.SOT RHOB.LDT 2. 084 OR'HO.LOT QSS.LDT 0.018 LS.LDT L ITH.LDT 171. 125 S S1.LOT SSHV.LOT 1318.000 SIRH.LDT ,CALI.LDT 12. 320 GR.:LOT MRES.LDT 11.383 HTEN.LDT TNRA.CNL 3.456 NPOR.CNL CNTC.CNL 1651.071 CFTC.CNL MRES.CNL 11.383 MTEM.CNL RHDB.FDC -999.250 DRHO.FDC CALI. FDC -999. 250 GR. FOC HD. MLL -999.2 50 TENS. MLL DEPT. 1600.000 ILO.OIL SP.DIL -160.125 GR.DIL MRES.DIL 11.578 HTEN.DIL DTSM.SDT -999.250 C~HC.SDT TT1. SOT -999. 250 TT2. SOT LTTloSDT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH.SDT DTCO. SOT -999. 250 GR. SOT RHOB.LDT 1.996 DRHD.LDT QSS.LDT 0.015 LS.LDT L ITH.LDT 233.5 O0 S S1.LOT SSHV.LDT 1319.000 SIRH.LOT C,ALI.LOT 1Z. 891 GR.LOT 28-SEP-1989 12:51 15.90 ¢ I L'M. g I L '70. 375 TEN:S. D IL 1006. 000 DT.SDT -999. 250 COHS. SO'T -999.250 TT3.SOT -9'99.250 LTT3.SDT -999. 250 OTLN.SDT -999.250 TENS.SOT 0.003 PEF.LOT 348. 500 LU. LDT 110.125 SSI.LOT Z- 275 LSRH.LOT 70. 375 TENS.LDT 1006.000 NPHI. C'NL 44. 784 RCNT.CNL 444 o 509 G R. 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SOT -999.250 LTT3.SDT -999.250 DTLN.SDT -999.250 TENS.SOT -0.007 PEF.LOT 502.500 L U. ~L D T 215.125 SS2.LDT 2.117 LSRH.LDT 39.125 TENS.LOT 968. 000 NPHI.'CNL 40.152 RCNT.CNL 467. 339 GR.CNL 70.250 HTENoCNL -999.250 FFDC.FDC -'999.250 TENS.FOC -999.250 68,318 ILM.DIL 23.656 TENS.OIL 958.500 DT.SDT -999.250 COHS.SDT -999.250 TT3.SDT -999.250 LTT3.SOT -999.250 DTLN.SDT -999.250 TENS.SOT -0.004 PEF.LDT 595.500 LU.LDT 221.500 SS2.LDT 2.01~ LSRH.LDT 23.656 TENS.LOT 15.557 1845.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2'50 2.982 32 2- 250 304.500 2.. 287 45.955 1745.743 70.375 1006.000 -999.250 -999.250 28.039 172 5. 000 -99 9. 250 -999. 250 -999.250 -999.250 - 99 9. 250 -99'9.250 Z. ¢86 463. 000 324. 500 2.090 1725.000 38.330 1739.937 39.125 968.000 -999.250 -999.250 67.927 1720o000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2-055 541.500 340.750 1.999 1720.000 SFLU.DIL MTEM. OIL DTL. SOT COS T. SOT TT4.SDT LTT4.SDT DTL.F. SOT DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH. CNL R C F T. C N L TEN S. CNL DPHI.. FDC NFOC.FOC GR. MLL SFLU.DIL M T E M. D I L DTL. SOT COST. SOT TT4. SOT LTT4o SOT DTLD. SOT DPHI.LDT QL S. LDT LL.LDT LSH¥'LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT. CNL TENS .CNL DPHI.FDC NFDC.FDC GR. MLL SFLU.DIL MTEM.OIL DTL. SDT COST.SOT TT4.SDT LTT4.SDT DTLF. SDT DPHI.LDT QLS.LDT LL .LOT LSHV.LDT LURH.LDT MTEM.LDT 16.061 70.688 -999.250 '-999.250 -999.250 -999.250 -'999.250 21.710 0.004 1~7.500 1399.000 2.299 70.68B 44.713 441.611 1845.000 -999.250 -999.250 -999.250 41.390 70.250 -999.250 -999.250 -999. 250 -999.250 -999.250 34.321 -0.019 271.000 1398.000 2.090 70.250 40.772 436.792 1725.000 -999.250 -999.250 -999.250 67.152 69.750 -999.250 -999.250 -999.250 -999.250 -999.250 39.631 0. 005 324.750 1399.000 2.002 69.750 LIS TAPE VERIFIC.~TION LISTING SCHLUMBERGER ~'LASKA COMPUTING CENTER MRES.LDT 11. 578 HTEN. LOT TNRA.CNL 3.709 NPOR.CNL CNTC.CNL 1659..1'78 CFTC.CNL MRES..CNL !1.578 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC C ALI. FDC -999.2'50 GR.FgC HQ.MLL -999.250 TENS.MLL DEPT. 1500. 000 ILO.OIL SP.DIL -139. 625 GR.DtL MRES.DIL 11.78'1 HTEN.DIL DTSM.SDT -999.250 COHC.SOT TT1.SDT -999. 250 TT2. SOT LTT1. SOT .-999. 250 LTT2. SOT WFC. SDT -999. 250 WFSM..SDT DTCO. SOT -999.2 50 GR. SOT RHO~B.LDT 1. 762 DRHD.LgT ~SS. LOT O. 021 LS.LgT L ITH. LOT Z6T.~ 50 S S1.LgT S~SHV,.LDT 1318.000 S1RH.LDT C~LI.LDT 14. 992 GR.LDT MRES.LDT 11.781 HTEN.LDT TNRA..CNL 4..344 NPOR.CNL C N'T C. C N L 14 48.6 64 C F T C. C N L MRES.'CNL 1~.781 MT5M.CN:L RHOB.FDC -999.250 DRHO.FDC CALI. FDC -ggg · 2 50 GR. FDC HD.MLL -999.250 TENS.MLL DEPT. 1400. 000 ILO. Oil SP. DIL -1¢0. 375 GR. OIL MRES. DIL 11.859 HTEN.DIL DTSM. SDT -999.250 COflC.SOT TTJ. SOT -999. 250 TT2. SOT LTTl. SDT -ggg. 250 LTTZ.SDT WFC.SDT -999.250 WFSH.SDT DTCg. SOT -999.2 50 GR. SDT RHOB.LDT 2.033 DRHO.'LDT QSS.LDT 0.017 LS.LDT L ITH. LOT 1 86. 625 S S1.LOT SSHV.LDT 1318.000 SIRH.LDT C~LI.LDT 12.625 GR.LDT MRES.LDT 11.859 HTEN.LDT TNR~.CNL 4.16~ NPDR.CNL CNTC.CNL 14'95.309 CFTC.CNL MRES.CNL 11.859 MTEM.CNL RHOB.=DC -999.250 DRHO.FDC C ALI. FDC -999.2 50 GR.FDC HD. MLL -999.250 TENS.MLL DEPT. 1300.000 ILO.OIL SP.DIL -155.750 GR.DIL M~ES.DIL 12.023 HTEN.DIL DTSM.SDT -999.250 COHC.SDT TT1. SOT -999. 250 TT2. SDT 2g-SEP-,lgSg 12:51 95 B. 500 N P H I. C N L 39.939 RCNT.CNL 475' 948 GR.CNL 6'3.750 HTENoCNL -999.250 FFDC.FDC -999.250 'TENS.FDC · -9:99.250 33. 191 ILM. OIL 53.09~ TENS.OIL 1 003. 500 DT.SOT --999.250 COHS.. SOT r--999' 250 TT3.SDT -999.250 LTT3.SDT -ggg. 250 DTLNoSDT -g99.250 TENS.SOT -O. 004 PEF.LDT 881. !500 LU.LDT 231. 000 SS2.LOT 1.784 LSRH.LDT 53. 094 TENS.LOT 1003.500 NPHI.CNL 52. 896 RCNT.CNL 346. 099 GR.CNL 69.188 HTEN. CNL -999.250 FFDC. FDC -999.250 TENS.FDC -999. 250 16.989 ILM.DIL 68. 563 TENS.OIL 1005.500 DT.SDT -999. 250 CDHS. SOT -999.250 TT3.SOT -999.250 LTT3.SDT -999.250 DTLN.SDT -999.250 TENS'SOT 0.001 PEF.LDT 557.000 LU.LDT 222. 625 SS2.LOT 2.029 LSRM.LDT 6B. 563 TENS.LOT 1005. 500 NPHI.CNL 49.104 RCNT.CNL 365. 724 GR.CNL 67.063 MTEN.CNL -999. 250 FFDC. FDC -'999.250 TENS.FOC -999.250 42- 689 I71 5.415 23. 656 95:8. 500 -999.250 -9991.250 32. 702 1735.000 -999.250 -999o 250 -999.250 -999.250 -999.250 -999.250 3.771 831. 500 367. 000 !. 767 1735. 000 5 3.303 1-~¢ 9. RS 2 5.3.094 1003. 500 -999.250 -999.250 14.833 1650.000 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 2.510 510.250 339.500 2.031 1650.000 51.155 1580.243 68.563 1005.500 -999.250 -999.250 324.989 ILM. DIL 179.807 29.938 TENS.DIL 1685.000 1 026. 000 DT. SOT -999. 250 -999.250 COHS.SDT -999.250 -999.250 TT3.SDT -999.250 TNPH. CNL F T. C N L 'TENS.CNL D~H'I. F'DC NFDC. FDC GR. MLL SFLU.DIL MTEM.DIL DTL. SOT COST. SOT T T 4. S D'T LTT~.SDT DTL. F. SOT DPHI.LOT QLS.LDT LL.LDT LSH¥.LDT LURH.LDT MTEM.LDT TNPH.CNL RC~:T. CNL TENS.CNL DPH I. FD C NFDC. FDC G R. ML L SFLU.DIL MTEM. Oil OTL. SOT COST.SOT TT~. SOT L TT~. SOT DTLF. SOT DPHI.LDT QLS .LOT LL.LDT LSHV.LDT LURH. LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GR.MLL SFLU.DIL MTEM.DIL DTL.SDT COST.SOT TT4.SDT PAGE: 30 3g.677 485.301 1'720.000 -999.250 -999.250 -999,250 41.987 69.188 -999.250 -999.25;0 -999.250 -99'9.250 -999.250 53.792 -0.017 465.750 1398.000 1.776 69'188 50.745 325.768 1735.000 -999.250 -999.250 -999.250 14.986 67.063 -999.250 -999.250 -999.250 -999.250 -999.250 37.370 -0.008 302.000 1398.000 2.035 67.063 49.976 354.839 1650.000 -999.250 -999.250 -999.250 1011.469 65.313 -999.250 -999.250 -999.250 LIS TriPE VERIFIC~TZON LZST.IN:,~' ~ SCHLUMBERGER ALASK~ COMPUTING CENTER LTT1.SDT -999.250 LTT2. SDT WFC. SOT -999.250 WFSH.SOT DTCO. SOT '-99:9. 250 GR. SOT RHOB.LDT 2.140 gRHO.LOT QSS. LDT 0.0 54 L$.:LOT LITfl. LDT 192.B75 :S S1.LDT SSHV.LDT 1318o000 SI~H.LDT CALI.LDT 15. 977 GR.LOT MRES.LDT 12.023 HTEN.LDT TNRA.CNL 3.689 NP OR.CNL CNTC.CNL 1494.427 CFTC.CNL MRES.CNL 12o023 M'TEM.CNL RHOB.,~OC -999.250 DRHCoFDC CfiLI.FgC -999..250 GR.. FDC HD. MLL -999. 250 TENS. MLL DEPT. 1200. 000 ILD.DIL SP. OIL MRES.DIL 11.89! HTEN.DIL DTSM. SDT -999.250 COHC.SgT TT1. SOT -999. 250 TT2. SOT LTT1.SDT -999.250 LTTZ. SOT WFC. SOT -999.250 WFSH.SDT DTCO. SOT -999. Z 50 GR. SOT RHOB.LDT 1.924 gRMO.LDT QSS.LDT O.OZ? LS.LDT L !TH.LOT 2~5.375 SS1.LDT SSHV.LDT t31B.000 SI~H.LDT CALI.LDT 17. )59 GR.LgT MRES.LDT 11.891 HTEN.LDT TNRA.CNL 4.052 NPOR.CNL CNTC.CNL 1392.247 CFTC.CNL MRES..CNL 11.891 MTEM.CNL RHOB.FDC -999.250 DRHO. FDC CALI.FDC -999.2 50 GR.FDC HD. MLL -999.250 TENS.MLL DEPT. 1100.000 ILO. OIL SP. DIL -167. 750 GR. OIL MRES.DIL 11.703 HTEN.DIL DTSM.SDT -999.250 CgHC.SDT TT1. SOT -999. 250 TTZ. SOT LTTI.SDT -999.250 LTT2.SDT WFC.SDT -999.250 WFSH.SDT DTCg. SOT -999.2.50 GR. SOT RHOB.LDT 1.759 DRHO.LDT QSS.LDT 0.046 LS.LDT L ITH.LDT 316.5 O0 S S1.LDT SSHV.LDT 1318.000 SIRH.LDT CfiLI.LDT 17.172 GR.LDT MRES.LDT 11.703 HTEN.L-DT TNRa. CNL 4.518 NPDR.CNL CNTC.CNL 1327.749 CFTC.CNL MRES.CNL 11.703 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC 28-SEP-1989 12:51 -999.250 LTT3.SDT -999. 250 DTLN.SOT -999. 250 TENS. SOT O. 112 PEF.LDT 5 6. 2.0 0 0 L U. LDT 259.750 SS2.LOT 1.802 LSRH.LDT 29.938 TENS.LOT 1026. 000 NPHI. CNI 43.56.2 ~C-~T.CNL 402. 040 GR.CNL 65.31'3 HTEN. CN'L -999.250 FFDC.FDC -999,. Z5O TENS.FgC -999. 250 47 . 440 I L M. O I L 33.I25 TENS.OIL 1038.000 DT.SOT -999.250 CDHS.SDT -999.250 TT3.SDT -999.250 iLTT3. SDT -999.250 DTLN.SgT -999.250 TENS.SOT 0.107 PEF.LDT 805. 500 LU.LDT 269. 250 SS2.LDT 1.600 LSRH.LDT .33.1.2.5 TENS.LOT 1038.000 NPHI.CNL 4?.608 RCNT.CNL 346.445 GR.CNL 64. 563 HTEN.CNL -999.250 FFOC.FOC -999.250 TENS.FDC -999.. 250 650.529 ILM. DIL 33.969 TENS.OIL 1011. 500 DT. SOT -999. 250 COHS. SOT -999.250 TT3.SDT -999.250 LTT3. SDT -999.250 DTLN.SDT -999.250 TENS.SOT 0.091 PEF.LDT I 050. 000 lU. LOT 270.250 SSZ.LDT 1.478 LSRH.LDT 33.969 TENS.LDT 1011.500 NPHI.CNL 59.404 RCNT.CNL 299.643 GR.CNL 64.56.3 HTEN.CNL -999.250 FFDC.FDC - 999. - 99 9. - 99 9. 514. 371. 1685. 40. 1-498. 2 9. 1026. -999. -99 9. 45. 165 O. -999,. -999. -999. --999. -999. -999. Z. 749. 415. I 65 0. 46. 1411. 103 8. -999. -999. 171. 1515. -999. -99 9. -999. -999. -999. - 999. 2. 986. 41 8. 1. 1515. 55. 1316. ~3. 1011. -999. 250 25O Z 50 ,438 000 750 027 000 837 993 93B 000 25O 250 408 000 250 250 250 250 250 250 924 000 750 817 000 814 896 125 000 25O 25O 581 00'0 250 250 250 250 Z50 250 645 500 000 668 000 448 514 969 500 250 LT T4,. SOT DTLF. SOT DPH I. LOT QLS.LDT LL. LOT L SHV. LOT LURH. LOT MT E M.L DT TNPH.CNL RCFT.CNL TENS. CNL OPHI .FDC NFDC.FDC GR. MLL SFLU.DIL MTEM. DIL DTL. SDT C 0 S 'T. S D'T TT4. S:DT LTT4. SOT DTLF. SOT OPHI.LDT QLS:.LDT LL.LDT LSHV.LDT LURH. LD'T MTEM..LDT T NPHo CNL RCFT.CNL TENS.CNL OmHI.FDC NFDC.FDC GR. MLL SFLU.OIL MTEM.DIL DTL. SOT COST.SOT TT4.SDT LTT4.SDT DTLF. SOT DPHI.LDT QLS.LDT LL.LDT LSHVoLDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC. FDC PAG E: 3,1 -999.250 -999.2:50 30.899 -0.020 305.000 1397.000 2. 031 65.313 41.828 37.2.133 1685. 000 · -999. 250 -999.250 -999. 250 154.293 64.563 -999.250 .-999. 250 -999. 250 -999.250 -999.250 43.990 -0.024 431.250 1397. OOO 1.831 64.563. 46.314 292.734 1650.000 -999.250 -999.250 -999.250 1011.469 64.563 -999.250 -999.250 -999.250 -999.250 -999.250 53.990 -0.016 557.500 1396.000 1.68B 64.563 56.518 288.322 1515.000 -999.250 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER CALl. FDC -999. 250 GR.FDC HDoMLL -9:99.2'50 'TENS.MLL DEPT.. 1000. OOO ILO. DZL SP..OIL -165.125 OR.OIL MRES.OIL tl.891 HTEN.DIL DTSM. GDT -999. 2150 COHC. SOT TT1.SDT -999. Z50 TT2. SOT LTT1. SDT -999..250 LTTZ.SDT W F C. S D T - 9 '99. Z 50 W F S H · S O T DTCO. SOT -999.2 50 GR. GDT RHOB.LDT 1. 949 DRHO.~LDT Q $ S. L D T 0.. 023 L S- LOT L ITH.LDT 210.125 SS1.LOT SSHV.LDT 1318.000 SIRH.LDT C A L I. L O T 12.992 G R. L D T MRES.LDT 11.891 HTENoLDT TNRA.CNL 4.642 NPOR.CNL CNTC.CNL 140.1.673 CFTC.CNL MRESoCNL 11.891 MTEM.CNL RHOB.FDC -999.250 ORHO.FDC C ALI. FDC -999.Z 50 GR.FD:C HD. MLL -9'99.250 TENS. MLL DEPT. 900. 000 ILO.OIL SP. OIL -169. 875 GR.. OIL 'MRES.DIL 12.023 MTEN.DIL DTSM. SDT -999.250 COHC.SDT TTI:. SOT -999. 250 TT2. SOT LTT1. SOT -999. 250 LTT2. SOT WFC.SDT -999.250 WFSH.SDT DTCO. SOT -9g9. 250 GR. SOT RHOS.LDT 2. 018 DRHO.LDT QS S.LDT O. 010 LS.LOT LITH.LDT 200. 375 SSI.:LDT SSHV.LDT 1317. 000 S1RM.LDT CALI.LDT 15. 203 GR. LOT MRES.LDT 12.023 HTEN.LDT TNRA.CNL 4.334 NPOR.CNL CNTC.CNL 1599.839 CFTC.CNL MRES.CNL 12.023 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -999.2 50 GR. FDC HO.MLL -999.250 TENS.MLL DEPT. BO0. 000 ILD. OIL SP.DIL -171.625 GR.DIL MRES.DIL 12.547 HTEN.DIL DTSM.SDT -999.250 COHC.SDT TT1. SOT -999. Z 50 TT2. SOT LTT1.SDT -999.250 LTTZ.SDT WFC.SDT -999.250 WFSH.SDT DTCD. GDT -999. Z 50 GR. SDT RHDB.LDT Z.089 gRHD.LDT QSS.LDT 0.035 LS.LDT 28-SEP-tg$g 12:!51 -999.250 TENS.FDC -999.250 40. 511 ILM.DII 71.75:0 TENS'.DIL 1024. 000 DT.SDT -999.250 COHS.SDT -99'9.250 TT3,.SDT ,-999.250 LTT3.SDT -999. ZSO DTLN.SDT · -999. 250 TENS. SOT O. O 10 P E F. L 'g T ,55~4. 000 LU. LDT 233.2'50 SSZ.LDT 1.8'96 LSRH.LDT 71. 750 TENS.LOT 1.024.000 NPHI.CNL 69. 586 RCNT.CNL 294. 891 GR. CNL 63.906 HTEN. CNL -999..250 ~FDC.FDC -999..250 TENS.FDC - 999. 250 36.327 ILM.DIL 75.625 TENS.OIL 1030. 000 DT.SDT -999.250 CONS.SOT -999.250 TT3. SOT -999.250 LTT3.SDT -999. 250 DTL'N. SOT -999. 250 TENS.SOT -0.005 PEF.LDT 565. 500 LU.LDT 219.6215 SS2.LDT 2.0~1 LSRH.LOT 75..625 TENS.LOT 1030.000 NPHI.CNL 50.067 RCNT.CNL 385.988 GR.CNL 63.188 HTEN. CN:L -999.250 FFDC.FDC -999.250 TENS.FgC -999.250 -ggg. 250 31.865 1635.000 -999o250 - 999. Z 50 -999.250 -999.250 -999.250 -999.. 250 2. 867 60,4.000 358.500 1.938 5 g. '726 150 O. 299 71.750 1024.000 -999.250 -999.250 28.685 1600.000 --99 9.250 --999.250 -999.250 -999.250 -999.250 -999.250 2. 518 512.500 338.500 2.02! 1600.000 53.016 1653.764 75.625 1030.000 -999.Z50 -ggg. 250 21.140 ILM. DIL 16.524 77.563 TENS.OIL 1520.000 1014. 500 DT. SOT -999. 250 -999.250 CDHS.SDT -999.250 -999.250 TT3.SDT -999.250 -999.250 LTT3.SDT -999.250 -999.250 DTLN.SDT -999.250 -999.250 TENS.SOT -999.250 0.021 PEF.LDT Z.50Z 52~.000 LU.LDT 476.000 :GR. MLL SFLU. DIL MTEM. OIL DTL, SDT COST. SOT TT4. SDT LTT4.SDT DTLF. SOT OPH I. L D'T QLS.LDT LL.LOT LSHV.LDT LURH.LDT M'TEM. LOT T NP H. CNL RCFT.CNL TENS.CNL DPHI. FDC NFOC.FDC GR. MLL SFLU.DIL MTEM. OIL DTL. SOT COST. SOT TT4.SDT LTT4 .;SOT DTLF. SDT DPHI.LDT QLS.LDT LL. LOT LSHV.LDT LURH.LOT MTEN.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI. FOC N~=DC.!=DC GR.MLL SFLU.DIL MTEM.DIL DTL.SDT CDST.SDT TT4.SDT LTT4.SDT DTLF. SOT DPHI.LDT QLS.LDT LL.LDT PAGE: 32 -999.250 47.459 63.906 -999°250 -999.250 -999.250 -999.250 -999.250 42.49! -O.O1Z 352.000 1397.000 1.944 63.906 71.64,5 272.473 1635.000 -999.250 -999.250 -999.250 38.903 63.188 -9'99.250 -999.Z50 -999.250 -999.250 -999.Z50 38.306 0.016 312.250 1395.000 2.033 63.198 373.612 1600.000 -999.250 -999.250 -999.250 13.980 62.156 -999.250 -999.250 -999.250 -999.250 -ggg.250 3.4.005 -0.004 256.000 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER L ITH.LOT 18I. 375 S S1.LDT SSHV.LDT 1318.000 SIRH.LDT CALI.LDT 13. 070 GR.LDT MRES.LDT 12.5.47 HTEN.LDT TNRA,CNL -4.670 NPOR.CNL CNTC.CNL i539.068 CFTC,CNL MRES.CNL 12..547 MTEMoCNL RHO~.FDC -999.250 ORHO.FDC CALl.. FDC -999. 250 GR.FDC HD.MLL -999.250 TENS.MLL 0 E P ~T. 70 ~0.000 I L D. D ! L SP.OIL -174.750 GE. OIL MRES.DIL 11.711 H'TEN.DIL D'TSM. SOT -:999. 250 CDHC.SDT TT1.SDT -999,250 TT2,SOT LTT1,SDT -999.250 LTT2.SDT WFCo SDT -999, Z 50 WFSM,SOT DTCO. SDT -999. 250 GR. :SOT RHOB.LDT 1.836 DRHD, LDT Q S S. L D T 0.0 22 L S. L D T LITH. LOT 322. 250 $ S1.LOT SSHV.LOT 1317.00:0 SIRH.LOT CALI.LDT 16. 156 GR.LDT MRES.LDT 11.711 HTEN.LDT TNRA.CNL 4.3,56 NPOR.CNL CNTC.CNL 1412.196 CFT:C.CNL MRES.CNL 11.711 MTEM.CNL RH08. FDC -999. 250 O~HO.FDC CALI. FOC -999. 250 G~,, FDC HO.MLL -999.250 TENS.MLL DEPT. 600.000 ILD.DIL SP.OIL -178. 500 GR. OIL MRES.DIL 12.125 HTEN.DIL DTSM.SDT -999.250 COHC.SOT TTlo SOT -999.2 50 TT2. SOT LTT1.SDT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH. SOT DTCO. SOT -999. 250 GR. SDT RHOB.LDT 2. 050 DRHO.LDT QSS.LDT 0.044 LS.LDT LITH.LDT 2 09. 125 SS1.LOT SSHV.LDT 131B.000 SIRH.LDT CALI.LDT 13.039 GR.LDT MRES.LOT 12.125 HTEN.LOT TNRA.CNL 4.050 NPOR.CNL CNTC.CNL 1603.168 CFTC.CNL MRES.CNL 12,125 MTEM.CNL RHOS.FOC -999.250 ORHO.FOC C ALI. FDC -9 99. 250 GR. FDC HO.MLL -999.250 'TENS.MLL 28-SEP,-1989 12:51 23'1. 125 SSZ.LDT 1. 998 LSRH.LO'T 77.56:3 'T E N S. L. D T ! 0 ! 4.5 O0 NP H I .. C NL 58,254 RCNT.CNL ]351. '915 GR. C N'L 62,156 HTEN.CNL -999.250 i~FDC.FDC -999.250 TENS.FOC -999. Z 50 793.610 ILM.DIL 23.906 TENS.OIL 1038.000 DT.SDT -999.250 COHS. SDT -999.250 TT3.SDT -999.250 iLTT3.,SDT -999. 250 DTLN.SOT -999.250 TENS.SDT O. 005 PEF.LDT ~01..500 LU.LDT 234.500 SS2.LDT 1.811 iLSRH.LDT 23.9:06 TENS.LDT 1038.000 NPHI.CNL 55.$95 RCNT.CNL 322.426 GR.CNL 64.$13 HTEN.CNL -999.250 FFDC.FDC -999.250 'TENSoFDC -999.250 341.000 2'06B 1520.000 60.198 1561.750 77.563 1014.500 -999.250 -999.250 367.919 1485.000 -999. 250 -999.250 -999,. 250 -999.250 -999.250 '- 99 9. ,Z 50 1.919 745.000 367,750 1.331 1485. 000 5 Z. 962 1459.456 23.906 1038.000 -999.250 -999.250 91.570 ILM.DIL 53.398 60.000 TENS.OIL 1415.000 1021. 000 DT. SDT -999. 250 -999.250 CDHS.SDT -999.250 -999.250 TT3.SDT -999.250 -999.250 LTT3.SDT -999.250 -999.250 DTLN.SDT -999.250 -999.250 TENS.SOT -999.250 0.043 PEF.LOT 2.277 590.000 LU.LDT 540.500 242.500 SS2.LDT 356.250 1. 884 LSRH.LDT 2.000 60.000 TENS.LDT 1415.000 1021.000 NPHI.CNL 48.858 47. 257 RCNT.CNL 1673.135 .404. 997 GR.C NL 60. 000 64.938 HTEN.CNL -999.250 FFDC.F3C -999.250 -999.250 TENS.FOC -999.250 -999.250 L SHV. LOT LURH.LDT MTEM.LDT T NP H- CNL RCFT. CNL TENS.CNL DPHI.FDC N FOC. FDC G R. MLL SFLU.OIL MTEM.DiL DTL.SDT CDST.SDT TT4.SDT LTT4.SDT DTLF. SDT DPHI.LDT QLS.LOT LL.LOT LSHV'LDT LURH.LDT MTEM.LBT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FOC GR.MLL SFLU.OIL MTEM. OIL DTL. SOT COST. SOT TT4.SDT LTT4.SDT DTLF. SDT DPHI.LDT QLS .LOT LL.LDT LSH¥.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL TENS.CNL DPHI.FDC NFDC.FDC GRoMLL PAGE: 33 1395.000 2.074 62.156, 56.780 3;38.650 1520.000 -999.250 -999.25'0 -999.250 1900. 811 64. 813 -999.250 - 999.. 250 -999.250 -999. 250 -999 ~9.326 -0- O08 429.000 1394.000 1.833 64.813 55.335 3t8.4'31 1485.000 -99:9.2'50 -999.250 -999.250 95.887 64.938 -999.250 -999.2~0 -999.250 -999.250 -999.250 36.372 -O.O1S 319.750 1396.000 2.004 64.938 47.449 359.445 1415.00~ -999o2~0 -999.~50 -999.250 LIS TAPE VERIFZCATZON LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEFT. 500. 000 ILO.OIL SP.OIL .-'1,7 8. 525 GR. OIL MRES.DIL 12.109 HTEN.DIL DTSM.SDT -999.250 COHCoSDT TT1. SOT -999.2 50 TT2. SOT LTT1. SOT -999. 250 LTT2. SOT WFC.$DT -999.250 WFSH.SDT gTCO. SOT -999.25-0 GR. SOT RHO3.LDT 1.8.88: DRHO.LDT QS S.LDT 0.023 LS.LOT LITH.LOT 281. 750 SS1.LDT SSHV.LDT 13'18.000 SIRH.LDT C ~LI.'LOT 15. 828 GR.LOT MRES.LDT 12. 109 HTEN.LOT TNRA.CNL 4.405 NPOR.CNL CNTC.CNL 13:52.571 CFTC.CNL MRES.CNL 12.109 MTEM.CNL RH'OB. FOC -999.250 ORHO.FDC CALI.FOC -999. 250 GR.FOC HO. MLL -999.250 'TENS.MLL DEPT. 400.000 ILD.DIL SP.OIL -190. 375 GR. DI,L MRES.DIL 12. 500 HTEN. D:IL OTSM. SOT -999. 250 CDHC. SOT TT1. SOT -9 99.2 50 TT2o SOT LTT1.SDT -999.250 LTT2... SOT WFC. SO'T -9'9'9.250 WFSH.SDT DTCO. SOT -999.250 GR.SDT RHOB.LDT 1.754 ORHD.LDT QS S.LOT 0.021 LS.LDT LITH.LDT 36'3. DO0 SS1.LDT SSHV.LDT 1318.000 SIRH.LDT C A t I. L D T 14.4 69 G R. L D T MRES.LDT 12. 500 HTEN.LDT TNRA.CNL 4. 508 NPOR.CNL CNTC.CNL 1350.550 CFTC.CNL MRES.CNL 12.500 MTEM.CNL RHOS.FDC -999.250 DRHO.FDC CALI.FDC -999. 250 GR. FDC HD. MLL -999.250 TENS.MLL DEPT. 300.000 ILD.DIL SP.OIL -242.875 GR.DIL MRES.DIL 12.992 HTEN.DIL DTSM. SDT -999.250 CDHC.SDT TT1. SDT -999.2 50 TT2. SDT LTT1.SDT -999.250 LTT2.SDT WFC.SDT -999.250 WFSH.SOT DTCO. SOT -999.2 50 GR. SDT RHO~.LDT 1.929 ORHO.LDT OSS.LDT O.O.lO LS.LDT LITH. LOT 2 55.8 75 S Sl.LOT SSHV.LDT 1318.000 S1RH.LDT C ALI. LOT 17.9 84 GR. LOT 28-SEP-1989 12:51 728.481 I:LM. DIL 36.344 TENS.OIL 1031:.000 OT.SDT -999.250 COHS'SOT -999.250 TT3.SDT -999.250 LTT3.SDT -999.250 OTLN..SDT -999.250 TENS.SOT 0.00! PEF.LDT 724.500 L'U.LOT 229.375 SSZ.LDT 1.854 LSRH.LDT 36.344 TENS.LOT I031.000 N'PMI.CNL 52.525 RCNT.CNL 320.423 GR.iCNL 63.09.4 HTEN.CNL -999.Z50 FFDC. FDC -999.250 TENS.FOC -999.250 64.788 tLM.OIL 59.688 TENS.OIL 1011.500 OT.SDT -999.250 COHS.SDT -999.250 TT3.SDT -999.250 LTT3.SDT -999.250 DTLN. SDT '-999.250 TENS.SOT -0.008 PEF.iLOT 904.500 LU.LDT 228.625 $.S2.~LDT 1.796 LSRH.LD'T 59.688 'TENS.LOT lOll. Ego NPHI.CNL 66.955 RCNT.CNL ZB9.720 GR.CNL 60.906 HTEN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 222.466 1440. 000 -ggg. 250 -999.250 - 99 9.250 -999. 250 -999.250 -999.250 2.066 658.000 356.000 1.887 144 O. O00 54.02.3 1371.930 36. 344 1031.000 ,-999.250 -999.250 39.496 132 5-000 - 99 9. :250 -999.250 - 99 9:. Z 50 -999.250 -999. 250 -99'9.250 2.¢38 820.000 363.750 1.762 1325.000 56.562 1400.056 59.688 1011.500 -999.250 -999.250 797. 890 ILM.DIL 1BB.B61 35.500 TENS.OIL 1300.000 1033. 000 DT. SOT -999.2 50 -999.Z50 COHS.SDT -999.Z50 -999. Z50 TT3.SDT -999. Z50 -999.250 LTT3.SOT -999.250 -999.250 DTLN.SDT -999.250 -999.250 TENS.SOT -'999.250 -0.003 PEF.LDT Z.Z19 669.500 LU.LDT 61Z.000 Z25.000 SS2.LDT 352.750 1. 943 LSRH.LDT 1.932 35.500 TENS.LOT 1300.000 SFLU.DIL M T E M. D I L DTL. SDT COST. SDT TT4. SOT LTT4.SDT DTLF. SOT DPHI.LDT OL',S. LOT LL.LOT LSflV.LDT 'LURH.LDT MTEM.LDT TNPH. CNL RCFT.CNL TENS. CNL DPHI. -FOC NF DC. FDC GR. MLL SFLU.DIL MTEM.DIL DTL.SDT C 0 S T. ,S D T TT4. SDT LTT4. SOT DTLF. SOT D P H I. L'D T QL S. LOT LL. LOT L S H V. L D'T LURH. LOT MTEM.LDT TNPH.CNL RCFT .CNL TENS.CNL DPMI.FDC NFOC.FDC GR.MLL SFLU.DIL MTEM.OIL OTL.SDT COST.SDT TT4.SOT LTT4.SOT DTLF.SOT OOHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MT E M. LOT P4GE: 34 1223.960 63.094 -999.250 -999.250 -999.250 -999.250 -g99.250 46'202 0.018 395.750 1395.000 63.~094 51.146 317.168 1440.000 -999.250 -999.250 -999.250 108.373 60.906 -999.250 -999.250 -999.25:0 -999. 250 -'999.250: 54.285 0.037 494.750 1396.000 '1.783 60.906 66.749 314.506 1325.000 -999.250 -999.250 -999.250 1681.385 59.625 -999.250 -999.250 -999.250 -999.250 -999.250 43.727 0.005 363.500 139~.000 1.938 59.625 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER MRES.LOT 12.992 HTEN.LOT TN.RA,.CNL 4.276 NPOR.CNL CNTC. CNL 1452. 917 CFTC.CNL MRES.CNL 12.992 MTEM.CNL RHOB.FDC -999.250 DRHO.FDC CALl. FDC -999. 250 GR.FDC HD.. MLL -999. 250 TENS.MLL DEPT. 200. 000 ZLD. OIL SP. OIL -193. 625 GR.DIL MRES.DIL 12.180 HTEN.DIL DTSM. SDT -999.250 COHC.SOT 'TT1. SOT -999.2 50 TT2. SDT L'TT1, SOT -999.250 LTT2.SDT WFC. SOT -999.250 WFSH. SOT DTCOo SOT -9 99.250 GR. SOT RHOB.LDT 1,958 9RHD.LDT QSS.LDT 0.021 LS.LDT LITH.LDT 216. 875 SS1.LDT SSHV.LDT 131:8.000 S1RH.LDT C ALI.LOT 14. 984 :GR,.LDT MRES.LDT 12.180 HTEN.LDT TNRA.CNL 4.164 NPOR.CNL CNTC.CNL 1408.902 CFTC.CNL MRES.CNL 12.180 MT'EM.CNL RHOB.FDC -999.250 DRHD.FDC CALl. FDC -99:9. 250 GR. FDC HO'. MLL -999.250 TENS,MLL DE:PT. 100.. 000 ILD. SP.OIL -225. 000 GR.DIL MRES.DIL 11.688 HTEN.DIL DTSM. SDT -999.250 COliC.SOT TT1. SOT -g 99. 250 TT2. SOT LTT1. SOT -999. 250 LTT2. SOT WFC.SDT -999.250 WFSH. SDT DTCO. SOT -999.2 50 GR. SOT RHOB.LDT 1.227 DRHO.LDT QSS.LDT -0.157 LS.LDT L ITH. LOT 47. 719 SS1.LDT SSHV.LDT 1320.000 SIRH.LDT C ALI.LOT 15. 297 GR.LDT MRES.LDT 11.688 HTEN.LDT TNRA.CNL 4.632 NPOR.CNL CNTC.CNL 1161.053 CFTC.CNL MRES.CNL 11.688 MTEM.CNL RHOB..~DC -999.250 DRHO.FDC CALI. FOC -999.2 50 GR.FDC HO. MLL -999.250 TENS.MLL DEPT. 94.500 ILD.DIL SP.OIL -244. Z 50 GR. OIL MRSS.DIL 11.734 HTEN.DIL DTSM. SDT -999.250 COHC.SDT TT1. SOT -999. Z 50 TT2. SOT 28-SEP-1989 12:!51 1033 ,. 000 N P H I - C N L 57.,687 RCNT.CNL 330. 040 GR.CNL 59. 625 HTE. N.C NE -999. 250 FFDC.FDC -999. 250 TENS.FDC -999.250 87:. 90:3 ILM.DIL 51.813 TENS.DlrL 995.000 DT.SDT -999.250 C 0 H S .. S D T -999.250 TT3.SDT -999,250 LTTS. SDT -999.250 DTLN. SDT -ggg. 250 TENS. SDT O. 013 PEF.LDT 648.0:00 LU.LDT ,234.375 SS2.LDT 1.895 LSRH,LD'T 51.813 TENS.LOT 995 000 NPHI.CNL 45. 986 RCNT. CNL .343, 0'74 GR.CNL 61.12 5 HTEN.CNL -999.,250 FFDC. FDC -999.250 TENS.FDC -999.250 2000. 000 ILM.DIL 19.344 TENS.OIL 1013.500 DT.SDT -999.250 CDHS.SDT -999.250 TT3.SDT -999.250 LTT3. SOT -ggg.250 DTLN. SOT -999.250 TENS.SOT -0, 924 PEF.LDT 418. 500 LU.LOT 62.688 SS2.LDT -4. 117 LSRH.LDT 19.344 TENS.LOT 1013.500 NPHI.CNL 58.859 RCNT.CNL 259.090 GR.CNL 64.688 HT EN.CNL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 50.617 1448.656 35.500 1 033. 000 -999.250 -999.250 38. 947 1235,000 -99 g. Z 50 - 99 9. 250 -999.250 -999,250 -999,250 -99 9.250 2:. 479 596. 500 360.750 1. 945 1235.000 50.007 1467.441 51.813 g :9 5.000 -99'9,, Z 50 -g99.2'50 1.785 1230.000 --999.250 -999..250 -999.250 -999.250 -999.250 -9gg. 250 19.969 3T1.250 125.000 2.150 1230.000 5B.439 1213.376 19.344 1013.500 -999.250 -999.250 2000.000 ILM.DIL 1.827 25.344 TENS.OIL 1220.000 1 00t. 000 DT. SOT -99 9.250 -999. 250 CDHS.SDT -999.250 -999. 250 TT3.SDT -999.250 TNPH.CNL RCFT.CNL TENS.CNL DPHI:.FDC NFRC,FDC GR. MLL S :FLU. OIL MTEM.DIL DTL. SDT COST. SOT 'TT4. SOT LTT-4. SDT DTLF. SDT DPHI,LDT QLS.LDT LL.LgT L SHV.LDT LURH, LOT MTE M. LO T TNPH.CNL RCFT.CNL TENS.CNL D P H I. F D C NF~C.FOC GR. MLL SFLU.DIL MTEM.DIL 9TL. SD'T COST.SOT TT4. SOT LTT4. SOT DTLF. SDT DPH'I.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT ~TEM.LDT TNPH.CNL RCFT.CNL TEN$.CNL DPHI.FDC NFDC.FDC GR.MLL SmLU.OIL MTEM.OIL DTL.SDT COST.SOT TT4.SDT PAGE: 35 55.190 314.506 1300.000 -999.25:0 -999.250 -999.250 183.442 61.I25 -999.250 -999.250 -999.250 -999.250 -999.250 41.934 -0.009 3:49.500; I395.000 1.95! 61.125 49.075 340.090 1235.000 -999.250 -999.250 .-999.250 7.443 64.688 -999.250 -999.250 -999.250 -999.250 -999.250 86.243 0.232 233.000 1398.000 2.215 64.688 59.168 253.781 1230.000 -999.250 -999.250 -999.250 8.558 64.813 -999.250 -999.250 -999.250 LIS 'TAPE VERIFIC~TION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER LTTI., SDT -9,99.2,50 LTT2. SOT WFC. SDT -'999. 250 WFSH. SOT DTCO. SOT -999.250 GR. SDT RHDB.LDT 1. 830 DRHOo L, DT QSS.LDT -0.110 L S. LOT L I T H. L D T 20. Z O ~ S S I. L D'T SSHV,.LDT 1320.000 S1RH.LDT CALI.LDT 15. 313 GR.'LDT MRES.LDT 11.734 HT'EN.LDT TNR~. CNL 4. 785 NPOR'CNL CNTC.CNL 1267.400 CFTC.CNL M R E S. C N L 11.7 34 M T ~ M · C N L RHOB. FDC -999.250 DRHO.FDC C A L I. F D :C -999.250 G R. F D C HD. MLL -~99.250 TENS.MLL 28-SEP-1989 12:5'1 -999.25,0 LTT3. SOT · -999,250 DTLN. SDT -999.250 TENS.SOT -O. 795 PEF. LDT 188.875 L U. L D T 66.063 SS2.LDT 4.7.93 LSRH.'LDT 25,. :344 TENSoLDT 10 O 1 - 000 N,P H I. C N L 66. 192 RCNT.CN:L 268.. 048 GR.CNL 64.81:3 HTEN.CNL -999.250 FFDC.FgC -999.250 TENS.FDC -999.250 -g99. 250 -999,250 2 8.8;59 17B.250 112,375 2.623 1220.000 6 !. ,221 1380.607 25.34¢ '1001. '-999.250 -999.250 L'TT4. SD'T DTL F. SOT DPHI.LDT QLS.LDT L L. L D T LSHV..LOT LURH.LDT MTEM'LDT 'TNPH. CNL R CF T. CNL TENS. CNL DPH I. FDC NFDC. FDC GR. M'LL PA G E: 36 -g99.250 -g99.250 4.9.694 0.138 99.750 1398.000 2. 695 64.8'13 69.391 262.262 1220.000 -999.250 -999.250 -999.250 **~-'* FILE TRAILER **** .FILE NAME : EDIT .00! SERVICE : ~LIC VERSION : 0'01A02 DATE : 89/09/28 M,AX REC SIZE ; :1024 FILE TYPE : LO LAST FIL~ ~ *~** FILE HEADER ~:*** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001402 DATE : $9/09/28 M4X REC SIZE : 1024 FILE TYPE : LO LAST ~ILE = FILE - EDIT.O02 ARCO AL~SKA INC. KUPARUK 2K-11 50-103-20114 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK,~ COMPUTING CENTER 28-SEP-1989 12:51 PAGE: 37 RUN2 ONLY MICRgLOG DATA DATA SAMPLED EVERY-.1667 FEE'T DATA INCLUDED - T~OL EXTENSI:DN TOOL TYPE USED NAME MICROLOG .MLL MICRO'LOG 6802' TO 6295* TABLE TYPE : CONS TUNt VA,LU CN ARCO ALASKA INC. F N K U P A R UK WN 2K - 11 APIN 50-103-201114 FL 46' FSL E 94' FEL SECT 02 T OWN ! 0 N COUN NORTH SLOPE S TAT A L ASK A NATI ENGI A. FR!TZKE WITN MCKAY/BONO/SALAT SON 5 48369 EPD FT 0. LMF ~PO FT EKB PT 154. EOF PT EGL FT ~13. TO~ PT 6850. DEFI COMPANY NAME FI ELD NAME WELL NAME API SERIAL NUMBER FIELD LOC ATION SECTION TOWNSHIP RANGE COUNTY STATE :OR PROVINCE NAT ION ENGINEER'S NAME ~ITNESS' S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE ~EPT MNOR MINV TYPE : CURV DEFZ DEPTH CHANNEL N~ME MICRO-NORMal RESISTIVITY MICRO-INVERSE RESISTIVITY LIS T~.P:E VERIFi!C~TION LZSTING SCHLUMBERGER ~LASKA COMPUTING CENTER ,.8-.~EP-1989 12; 51 PAGE: ,3 8 *~ OATA FORMAT SPECIFICATION RECORD ** ** ;SET TYPE - 64EB ** TYPE RE:PR 'CODE V~LUE I .66 0 2 66 0 3 73 12 4 66 1 ~ 66 6 ?3 ? 65 8 68 O. 16,5 9 6.5 F T 11 66 8 5 12 68 13 66 O 14 65 iF T 15 66 68 16 66 1 O 66 1 ** SET TY-,mE - CH~N N~&ME SERV UNIT SERVICE ~,PI ~PI AP1 API FILE NUMB NUMB 'SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOO NUMB SAMP ELEM CODE (HEX) DEPT FT 548369 00 000 O0 0 2 1 1 ~ 68 0000000000 MNOR MLL OHMM 54~369 07 635 21 0 2 1 1 4 68 0000000000 MINV MLL OHMM 548369 07 635 21 0 Z 1 I 4 68 0000000000 :** DATA :*~ DEPT. 6851.000 MNOR.MLL 1.330 MINV.MLL 2.055 DEPT. 6800.000 MNKJR.MLL 1. 841 MINV.MLL Z.619 DEPT. 6700.000 MNOR.MLL 1.908 MINV.MLL 2.750 DEPT. 6600.000 MNOR.MLL 6.719 MINV.MLL 8.750 DEPT. 6500.000 MNOR.MLL 1.572 MINV. MLL 1.915 DEPT. 6400.000 MNOR.MLL 1.720 MINV.MLL 1.602 DEPT. 6294.000 ,~NOR.MLL 0.968 MINV.MLL 1.92.4 LIS TAPE VERIFICATIgN LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 28-SEP-1989 12:51 P AGE: ¸39 END OF DATA *:~*'~ FILE 'TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION : DATE : 89/0,9/28 M,~X REC SIZE : !024 FILE TYPE : LO LAST FILE : ~, ~:~ FILE HE~DER FILE NAME : EDIT .003 SERVICE : FLIC VERSIDN : 001A02 D,~TE : $9/09/28 MAX REC SIZE : 1024 FILE TYPE : LAST FILE : FILE - EDIT.O03 AR.CC AL i~SKA INC. KUP&RUK 2K-11 5 0-103-.20114 ~UN2 :DC/CNL HIGH RESOLUTION DATA ONLY D~T,~ SAMPLED EVERY -.1000 FEET D~TA INCLUOED - TOOL EXTENSION TOOL TYPE USED NAME FOC .FOH CNT-a/O/H .CNH FORMATION DENSITY COMPENSATED N:UTRON 6810' TO 62'::)0' 6796' TO 6290' LIS TAPE VERIFICATION LISTING :SCHLUMBERGER ~,LASKA COMPUTING CENTER TABLE TYPE : CONS TUNI CN 28-SEP-.198g 12:S1 V A L U FN WN APIN FL SECT TOWN RANG C DUN $ T AT N ENGZ WITN SON PDAT LMF APg. E KB EOF EGL TOD FT FT FT FT FT FT ARCO ALASKA INC. KgPARUK 2K - '11 5 g-103-20114 /+5' FSL & 94· FEL 1ON NORTH SLOPE ALASKA A. FRITZKE MCKAY/BOND/SALAT 5~B369 ~SL O. 154. 113. 6850. P A G E: ,¢ 0 DEFI COMPANY NAME ~IELO NAME · WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION T 0 W:N S H I P R A N G E COUNTY STATE OR PROVINCE NATION ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER N:UMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEF[ DEPT DPHI RHOB DRHO FFDC NFDC CALI GR TENS NPHI TNPH TNRA NPOR RCNT RCFT CNTC CFTC GR TENS DEPTH CHANNEL NAME DENSITY ,mORO SITY BULK DENSITY DELTA. RHO FAR FOC COUNT RATE NEAR FDC COUNT RATE CALIPER r~AMMA RAY TENSION NEUTRON ~OROSITY THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED ~AR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION LIS T~,PE YERIFICATION LISTING SCHLUMBERGER ALASK. A 'COMPUTING CENTER' 28-SEP-lgSg 12': 51 PAGE: .41 -~ OA, TA FORM~'T SPECIFICATION RECORO ~*~ SET TYPE - 64E5 ~ TYPE REP~ CODE I 66 3 73 5 56, 9 6,5 11 ,56 12 68m 13 66 14 65 15 66 16 66 0 66 VALUE 0 0 76 1 0. 099 FT 13 0 ~'T 68 t 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API ~PI AP1 aPI FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG 'TYPE CLASS MOD NUMB SAMP ELEM CODE DEPT FT 54336,9 O0 DPHI FCH PU 548369 07 RHO3 FDH G/C3 548369 07 DRHO FDH G/C3 548369 07 FFDC FDH CPS 548369 07 NFDC FDH CPS 548369 07 CALl FDH IN 548369 07 GR FDH G~PI 548369 0'? TENS FDH LB 548369 07 NPHI CNH PU 548369 07 TNPH CNH PU 548369 07 TNRA CNH 548369 07 NPOR CNH PU 545369 07 RCNT CNH CPS 548369 07 RCFT CNH C,~S 548369 07 CNTC CNH CPS 548369 07 CFTC CNH CPS 548369 07 G~ CNH GAPI 5483,59 07 TENS CNH L~. 548369 07 PROCESS (HEX) OOO O0 0 3 1 1 4 68 635 21 0 3 1 1 4 68 350 02 0 3 I I 4 68 1356 0 t 0 3 1 I 4 6 8 354 0 ~ 0 3 1 1 4 68 354 01 0 3 I 1 4 68 280 O1 0 3 1 1 4 68 310 01 0 3 I 1 4 68 635 21 0 3 1 1 4 68 ~90 O0 0 3 1 1 4 68 890 O0 0 3 I I 4 68 420 O1 O 3 1 1 4 68 8gO O0 0 3 I 1 4 68 420 O1 0 3 1 1 4 68 420 O1 0 3 1 1 4 68 420 Ol 0 3 1 1 4 68 420 O1 0 3 1 1 4 68 310 O1 0 3 1 I 4 68 635 21 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000, 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000009000 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER DEPT. 6873.399 OPHI.FDH FFDC.FDH 0.000 NFDC.FDH TENS.FDH 2080.000 NPHI.CNH NPOR.CNH 84. 000 RCNT.CNH CFTC. CNH O. 000 GR.CNM DEPT. 6800.000 9PHI.FDH FFDC.FDH 536.000 NFDCoFDH TENS.FOH 13990.000 NPHI.CNH NPOR.CNH 41.722 RCNT.'CNH CFTC.CNH 5 98o661 GR.CNH DEPT. 6700.000 DPHt.FOH FFDC.FDH 523.5:0,0 NFOC.FOH TENS.FDH 3910.000 NPHI.CNH NPO~.CNH 41.854 RCNT.CNH CFT:C.CNH 572.547 ,GR.~CNH DEPT. 6600. 000 OPHI.FDH F~DC.FOH 616.500 N~FDC. FDH TENS.'~DH 3860.000 NPHI.CNH NPOR.CNH ,31.552 RCNT.CNH CFTC. CNH 1057. 502 GR.CNH DEPT. 6500.000 DPHI.FOH FFDC.FDH 931. 500 NFDC.FDH TENS.FDH 3820.000 NPHI.CNH NPOR.CNH 39. 873 RCNToCNH CFTC,. CNH 4 54. 377 GR.CNH DEPT. 6400.0D0 DPHI.FDH FFDC.FDH 803.000 NFDC.FOH TENS.FDH 3794.000 NPHI.CNH NPOR.CNH 44.2'14 RCNT.CNH CFTC.CNH 453. 154 GE.CNH DEPT. 6300. 000 DFHI.FgH FFDC.FDH 530.500 NFDC.FDH TENS.FDH 3710.000 NPHI.CNH NPCR.CNH 42. 800 RCNT.CNH CFTC.CNH 547. 590 GR.CNH DEPT. 6289.300 DPHI.FDH FFDC.FDH 707.000 NFDC.FDH TENS.FDH 3860.000 NPHI.CNH NPgR.CNH 47. 567 RCNT.CNH CFTC.CNH 470.992 GR.CNH 28.-SEP-1989 12:51 280. B23 RHDB.FDH O. gO0 CALI.FDH -0. 162 TNPH.CNH 0.000 RCFT.CNH O=OOO TEN ~ r.,,,. 8.175 RHOB.FDH 693.500 CALI.FDH 41.025 TNPH. CNH 1902..604 RCFT.CNH 110.125 TENS.CNH 12.511 RHOB.FDH 627.000 CALI.FDH 42. 565 TNPH.CNH 1 7 ¢ 9.15:.2 R C F T. C N H 101.813 TENS.CNH 19. 658 RHOB.'FDH 598.500 CALI.FDH 28. 545 TNPH.CNH 2696.456 RCFT.CNH 75.250 TENS.CNH 19. ¢ 43 R H g B. F D H 846.500 CALI.FDH 43° 57.2 TNPH.CNH 1566.425 RCFT.CNH 105.625 TENS.CNH 17.703 RHOB.FDH 786.50D CALI.FDH 45.905 TNPH.CNH 1684.130 RCFT.CNM 116.875 TENS.CNH 11.405 RH@B.FDH 649°000 CALI.FDH 42.092 TNPH.CNH 1813.881 RCFT.CNH 246.125 TENS.CNH 22.126 RHOB.FDH 646.500 CALI.FDH 48.004 TNPH.CNH 1766.166 RCFT.CNH 262. -..900 TENS.CNH -1.984 1. 155 -8. Z74 0.000 ~,o0o 0"" 2.515 8.508 40 .'798 587.706 399 0 ' 000 2.444 8.508 .41.275 506.183 391 O. 000 2.326 8.469 30..29~ 878. 677 3860.000 2.329 11.633 41.724 399.035 3820.000 2.358 10.289 43.772 406.544 3794.000 8. B98 41.614 482.583 3710.000 2.785 8.945 47.558 435.838 3860.000 DRHO. FDH GR.FDH TNRA.CNH CNTC.CNH DRHO. FDH GR.FDH TNRA.CNH CNTC.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH DRHD. FDH GR. FDfl TNRA,.CNH C NYC. CNM DRHO.FDH GR.FDM TNRA.CNH CNTC.CNM DRHO.FDH GR. FDH TNRA.CNH CNTC.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH ORHD. FDH GR.FDH TNRA.CNH CNTC.CNH PAGE: - 6.92 ~, O. 000 0.000 0.000 0.129 110.125 3.381 2022.340 0.048 101.813 3.466 1951. 195 75.250 2.640 2864.198 0.167 105.625 3.724 t619.997 0.136 116.875 3.793 1648.540 0.071 246.125 3.471 1887.022 0.011 262.000 3.798 1796.259 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKa, COMPUTING CENTER 28-SE~-1989 12:9! PAGE: 43¸ *:~** FILE TRAILER ,'*** FILE NAME : EDIT .003 SERVICE : ~L[C VERSION : OOIA02 DATE : 892'09/28 MAX REC SIZE : 1024 FILE TYPE :: LO L A :S T ~ I L E : *~ T~,PE TRAILER ~:~ SERVICE NAME : EDIT DATE : ORIGIN : ~LIC TAPE NAME : '73482 CONTINUATION ~ : [ PREVIOUS TAPE : COMMENT : ARCED ALASKA INC.~ KUPARU:K, ~*~ REEL TR,AILER SERVICE NAME : EDIT DATE : 39/09/2.8 :ORIGIN : ~LIC R~EL N~ME : 7'3482 CONTINUATION ~ : PREVI'OUS ~EEL : COMMENT : ARCO ALASKA !NC., KUP~.RUK~ 2K-il, ~LIS TAPE VERI:IC~TION LISTING COPY O= F!EiLg SOT WAVEFORMS J O ,5 N U ~ B iE ~ '73, ¢ 8,2 COMP&NY N~ME WELL NAM~ FIELO NAME COUNTY ST~T5 APl NUMB!SR ARCO ALASKA, INC. 2K-11 KUPA~UK NORTH SLOPE ALASKA 50-103-2011/, RUN NUMBE~ TWO DATE LSGGEg 15-SEP-$9 SERVICE ~RDER NUMBER 5~836g DATE CgMPUTEO zg-sEP-$9 ~04: 686g.5~ Tg 3150' & F05: ~250' TO 2905' SCHLUMiBERGER OmFSHgRE SERVICES ~La. SK.~ DIVISION COMPUTER CENTER WEST INTEPN~TION~L AIRPORT ROAD ANCWOR~G~, AL~SK,~ 9~518 907/,56Z-265~, SCHLUMBERGER LIST MFi10:£]LI.SA.DAT; 29-SEP-B9 13:55:50 P~GE B REE'L HEADER 5483,6'9 :~* REEL HE ~'O ER SERVICE NAME : F~TSAP DATE : 89/09119 ORIGIN : C SU REEL NAME : CONTINUATION PREVIOU]S ~EEL : COMMENT :: 'S~HLUMBE~GE~ TAPE 'HEADER 548369__ ~ TAPE HEADER SERVICE NAME : FSTSAP D~TE : 89/09/1'9 ORIGIN : CSU T~PE NAME : CONTINU,&TION ~: O1 PREVIDUS 'T~DE : COMMENT : SCHLUM~RG~:R WELL SERVICES CSU TAPE (E~F) ~ILE H~EA. CE~ GTSAP .004 FILE HE~DER FILE NAME : GTSAP .004 SERVICE NAME : PLAY VERSZON ~ : 32.2 DA'TE : M~X. RECo L~N.: 8192 FILE TYPE : PR PREVIOUS FILE DAT,~ ,FOtM~,T SoECI~ICATION RECORD LISTING OF SET 1 ENTRY VaLU~ TYPE 64',EB :DEJECT 0 REDCODE SIZE I 0 66 2 O 66 1 4 1 66 1 5 1 6-5 1 7 IN CH 6 5 ~ 60 7 3 9 .1 I N 6 5 4 11 1 66 1 13 t 66 1 14 .lin 65 4 1 $ 73 66 ! 1 6 1 66 O 9 66 1 SCHLUMBERGER LI.S'T MFAO:E']LIS~ogAT; SET 29- S E P- 8 '9 13:55:50 LZ ST NAME SERV T 0 O, G T S ~ P S TIME GT.SAP ~S ETIM GTS~P S C $ G T S A P '~ / H R OIFF GTSAP F T~SNS GTS~P LBF M~RK GTS~P F T T 1 G T S ~ P U S TT2 GTS~,P US TT3 GTS~P US T'T4 GT SA P U S LTT1 GT;S ~P US LTT2 GTSAP US LTT3 GT :S ~.P US · LTT4 GTS~P US SSLT GTS~P WFtD G'TS~P W~2D GTS,~ P WF30 GTS~P WFAD GTSAP WF1 GTS~,P WF2 GTS~.P WE3 GTSAP WFiN GTSAP WF2N GTS~P WF3N GTSAP WF4N ST'SAP WFSO GTSAP WF6O GTSAP W~7O GTSAP WFBD GTSAP WF5 GTSAP WF6 GTS~P WF7 GTS~P W F 8 G T S ~ P WFSN GTS~P WF6N GTS ~,P WFTN GTS~F WFBN GTSAP wFgo GTS~P WF9 GTS~P DT GTSAP D T L G T S ~ P DTLN GTSAP DTLF GTS~P SPHI GTSAP ITT ~TS~P DLOG GTS~P il F S ~E T UNIT SERVICE 0 R O E R 0 TYPE .4mi AP.I 4PI :~PI FI:LE NUMB NUMB. ~ ~LOG TYP CL:S MDg NUMB 'ELEM SAMP US/: US/F bS/F 60 000 O0 60 6,,')6 2! O 4 60 ,636. 21 0 60 636 21 0 6 O 636 21 O 60 635 21 O 4 60 150 O1 60 522 83 60 522 ,6 0 522 8 60 522 60 522 83 0 60 5 ~Z 2 9 ~ O 4 60 522 83 0 4 60 5,22 ~3 O 4 60 OOC' OD 0 4 60 5,91 O1 0 60 591 02 0 60 5 81 0 60 581 0 60 580 01 0 60' 590 02 0 4 60 580 60 582 01 60 532 02 O 4 50 582 O~ O 60 591 05 0 60 5~ 06 g 4 60 581 OT 0 4 60 5~I 60 580 05 0 60 580 06 0 4 60 580 OT 0 60 5~0 09 60 5,92 05 O 60 582 06 60 532 O? g 4 60 592 O,g O 4 60 581 Og 0 60 5BO 09 0 60 52O 80 0 60 520 80 0 60 520 60 520 8g C, 4 60 890 O1 6D 529 82 6~ 000 OD 0 4 SiZ~ RSP PROCESS CCD (HEX) :1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 50O 500 500 5O0 1 1 1 1 1 1 1 1 50O 50O 50O 500 1 1 1 1 1 50C 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! 1 t 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 4 4 4 2 4 4 2 4 4 4 4 4 4 4 4 2 4 4 4 4 5O0 500 50O 500 4 4 4 4 4 4 4 5OO 500 5OO 50O 4 4 4 4 4 5OO 4 4 4 4 4 4 12~ 73 8200000000 68 8000000000 68 $000000000 49 820000000'0 68 8000020000 68 8000000000 49 8000000000 68 8000000000 68 8000'000000 68 8000000000 68 8000000000 68 8000000000 68 8000000000 68 8000000000 68 8000000000 8000000000 68 9000000000 ,68 9OO00OO00O 68 9000000000 68 9000000000 55 9000000000 56 9000000000 56 9000000000 56 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 5.5 9000000000 56 9000000000 56 9000000000 56 9900000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 68 9000000000 56 9000000000 68 8200000000 68 8200000000 68 8200000000 68 8200000000 68 8200000000 63 8200000000 68 8000000000 S'CHLUMSERGER STCg GTSAP NPK GTSAP DTCO GTSAP DTSM GTSAP RMSC GTSAP PR GTSAP iCDHC GTSAP COHS GTSAP COS'T GTSAP CHE GTSAP SHE G'TSAP STE GTS~P WFC GTS~P WFSH gTS:AP RGR GTSAP GR GTSAP STSG GTSAP HV GTSAP CCSW GTSAP LIST MF,~O:E]LISA.~uA~; 60 000 O0 0 /~ ! 55 264 68 60 000 OD 0 4 I I 2 79 US/F 60 000 OD O 4 I 1 2 ,49 UStF 60 000 O0 O A 1 1 2 49 60 000 08 0 ,4 I I .2 4'9 60 000 00 O 4 1 1 2 49 60 go0 O0 0 4 1 t 2 49 60 000 O0 O 4 1 1 2 49 60 000 O0 O 4 1 ! 2 49 DB: 60 000 O0 0 4 I 1 Z 49 DB 60 000 O0 ,,.,~'4 ! ! 2 49 DS ,60 000 Og 0 4 I 1 2 49 60 000 O0 0 4 t 1 2 49 :60 000 O0 0 4 1 1 2 ,49 GAPi 60 310 01 0 4 1 1 2 49 GAPI 60 310 O1 0 4 1 t 2 49 60 000 OO O 4 ! 1 .2 7~9 V 6 O 000 0 O 0 .4 1 1 2 4 9 6 O 000 00 0 4 I I 2 79 29-5EP-89 9000000000 8000000000 8000000000 8000000000 8000000000 8000000000 8900000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 80'00000000 8000020000 8400000000 8000000000 9000010000 9000010000 13: 55: :50 PAGE D~TA PECORQ 'TYPE 0 DEPT 823260 .liN 6860.5 FT 2091'080¢ M TOD 306602253 TIME 2137. ETIM 2.137 CS 976.5 TENS 2~40. MARK 84. TT1 632. T'T2 432. TT4 827.6 LTT1 1152.8 LTT2 944.7999 LTT3 13,45.2 SSL% -45 WF1D 8854.716 WF2O 6854.483 WF3D 6854.249 WF1 -28 -28 30 30 1 1 I 1 1 ! 1 1 I 1 1 I 1 1 1 1 I t 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 I I I 1 14 8 -10 -26 -32 8 28 34 31 24 7 -6 -19 -23 -18 -9 -14 -17 -13 0 34 24 9 1 I -3 -12 -23 -29 -22 22 22 !3 3 -2 6 6 2 -5 -8 6 6 6 6 DIFF 'TT3 LTT4 WF4D 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 4 -28 20 -12 17 -5 -1 -4 0 1.5 826.7 99 9 1140.4 6854.024 1 1 1 1 ! 1 1 1 1 1 1 1 1 1 1 10 -14 15 -8 31 1 12 2 -3 SCHLUMBERGER LIST -7 -4 I3 -5 18 -15 2 13, 3 -2 -20 -~2 -85 92 40 -69 -92 26 110 107 -2 -1 03 -i~ -27 -9 3a 21 -15 -37 ~6 -27 1 1 1 1 ! 1 1 -I1 --'7 10 -4 15 -I? 1 13 -2 -7 -17 79 -95 --'74 11 53, -78 116 97 -~ t -108 -74 51 ~0 -33 -~ 9 -25 -5 30 37 19 4 -19 -39 -15 -27 1 1 1 1 1 ! 1 -I~ 9 -10 -17 0 12 '--7 -,14 '-10 90 -104 -50 17 60 -85 -87 --40 -110 -64 20 -~8 -23 0 17 1 -22 -41 -~2 52 3O 1 1 1 1 1 1 1 '-I1 ¢ --9 -3 - 1~6 1 12 - 11 1 96 -109 -46 67 84. ,-13 -90 -83 -2.3 ~6 121 71 -109 -53 6 ~ 10 -41 -35 -21 5 37 31 15 -2 -26 -~0 1 30 1 1 1 1 I 1 1 zg-sEP-$g 13:55:50 -3 -9 4 12 - 11 3 -2I 16 9'7 -2.4 -108 -31 28 75 '77 -30 -92 -77 -11 '79 121 55 - 72 -105 -43 20 66 58 0 -4,3 -93 -19 10 '39 ;'9 13 -29 -44. -37 10 6 0 5 -7 13 -3 8 11 -11 4 -22 32 94 -103 - ! ? 34. 67 -45 -93 - 7'0 1 92 119 37 -$5 · - 99 -33 29 69 52 -10 -4'3 -32 -16 16 40 26 11 -9 -32 -45 -33 18 13 -I 1t -6 17 -12 1 tl -10 -z} -95 -6 4. 0 89 -58 -6Z 14 102 114 18 -95 -92 -24 70 -19 -43 -30 -13 Z 1 ~0 -12 -35 -28 SCHLUMBERGER LIST 1 1 1 1 1 1 1 ! 19 -I0 9 -6 -9 -? -B 9 -4 -2 -Zl 6 -102 86 -29 -61 0 ~6 0 -22 -- 12 -6 7 1 1 1 1 1 1 1 - 17 !6 -13 -8 3 -22 -2 -12 0 ? -6 1 -1 -.34 -19 12 94 5O -93 -9 l -14 39 -38 -61 -42 62 59 -12 -17 4 9 19 6 4 1 t ! I I 1 t 1 1 -21 12 -16 0 3 -13 -6 -I 2 -4 2 -3 0 -5 -11 4 -8 -16 20 100 -104 -80 -5 49 87 29 -45 -60 -36 17 66 Sl -24 -53 -12 9 lO -6 8 1 t 1 1 1 1 I 1 1 -18 12 1I 4 -1 2 1 2 -3 -12 8 22 -14 - 32 32 102 ? -110 -67 17 -51 -59 -29 26 69 43 -34 -4 $ 6 11 21 2 -5 9 -2 29-SEP-89 1 1 1 1 1 1 1 1 ? -8 15; -14, Z1 0 19 0 6 -3 1 ? ? 2 0 -11 12 19 -Z 0 -28 -8 lO0 -11) -55 11 68 80 -5~ -58 -22 71 -42 -~ 3 -4 6 12 20 -1 -3 10 13:55:50 I 1 1 1 1 1 1 1 10 5: 15 -11 24 -5 26 14 -5 11 --1 9 10 0 1 -8 16 15 -Z5 -25 -3 60 94 -40 -112 -43 1 B 77 -8 -58 -55 -15 71 22 -48 -36 -1 ? 18 -4 -1 10 -8 1 1 1 1 1 1 1 1 6 16 ? 18 - 13 7.1 1 16 10 --4 9 -3 11 0 -5 ZO 10 -30 -23 2 73 83 -61 -109 -32 25 82 65 -19 -52 -8 5O 68 11 -53 -29 1 ? 16 15 -5 1 9 -9 SCHLUMBERGER LIST --1 2 1 1 i I ! 1 1 t -23 13 -11 --4 -8 2 -3 0 -2 0 ! 2 -4 2 -3 -9 -1 ~2 -1 -53 -26 -72 -113 -49 []LIS~. 3~T; -6 I 23- t9 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 ! -20 16 2 1 1 -1 5 2 -1 6 -4 -9 -I0 -52 -17 34 103 -!06 -38 - 1 '1 -6 ,--~ I ? -!? 31 1 t 1 1 1 1 1 1 ! 1 1 1 ! 1 1 ! 6 --.~ -I1 25 12 0 5 -2 tl 6 -3 9 0 ? -4 -9 -20 -9 46 106 -101 -98 -11 30 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 i0 6 -11 27 --'9 17 0 ? 14 -5 $ -4 9 2 ? -4 -8 -29 -46, -2 106 7 -111 -90 -16 .29 - S E P- 89 -10 -6 t2 II --9 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 ? lB 2 -13 20 -12 14 -2 --? 2 6 -7 19 26 -38 69 1~2 -15 -117 -80 -6 13:55:50 -9 -5 -5 t 5 -11 1 1 1 1 1 1 1 ! 1 1 1 1 1 1 I 1 1 -4 -6 -13 -14 -4 4 -8 9 -6 6 -4 1 2 -6 -6 -4,6 -39 9 79 -36 -IZO -71 5 PAGE ,-9 -5 -4 19 5 -13 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -16 20 -11 --6 0 -13 5 -6 2 -8. 4 -6 -2 -3 2 0 -7 -4 28 -51 -33 15 82 -55 -llB -61 17 SCHLUMBERG:R,~. LIST WF 4 29 41 '54 65 76 84 91 g6 99 100 98 95 88 -S ,-18 -l? -3:5 -43 -49 -55 - 60 -64 -66 - 6B -69 -70 -?0 -69 -57 -63 -58 -51 -43 -34 -25 -15 -4 ? 19 30 42 52 6,2 71 77 ~2 85 86 25 14 3 -7 --16 -25 -33 -39 -44 -47 -49 -51 -51 -51 -49 -47 -45 -43 -40 -38 -36 -34 .-31 -27 -,23 -18 -13 -7 -2 3 9 14 20 35 38 41 44. 45 45 44 42 38 34 29 24 20 16 12 '9 7 4 2 -1 -3 -6 -8 -11 -14 ,-17 -t'9 -22 -25 -26 -28 -30 -31 -31 -3I -29 -26 -23 -18 -13 -9 ! 5 8 11 14 16 18 19 Il Z2 IS 24 25 26 2T 28 2~ 19 2'9 29 28 -~ -8 -14 --Z? -27 30 3.0 I 1 1 1 I 1 ! 1 1 1 1 1 I 1 1 1 1 1 ! 1 I 1 1 1 I t 1 ! 1 1 1 1 1 1 1 1 1 1 I 1 I 1 I I 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 i 1 I 1 1 1 I I I I I I 1 I I I I I I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 I 1 I 1 1 I I I I I I 1 1 1 1 1 1 1 3 T I0 8 -3 -15 -23 -21 -i! 2 14 21 21 17 15 15 11 3 -6 -1i -11 -11 -12 -15 -17 -16 -10 1 14 24 26 20 12 ? 6 4 0 -7 -15 -21 -21 -13 0 1~ 18 15 8 2 0 0 1 2 1 -2 -4 -2 3 7 9 8 6 3 0 -2 -4 -7 -9 -9 -6 -1 5 9 10 t0 8 6 5 3 0 -3 -6 -6 -5 -1 3 SCHLUMBERGER LZST MFAO'E3LISA.DAT; Zg-SEP-Sg 13:55:50 P~GE .10 WFIN WF6D WF5 ? -3. 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O. O. O. O. STCD 63.21.133 1. t!1. 1700. 0.7025459 197. 28.99926 0.3141912 1250. 30.41174 228. 2900. O. 5 372894 20 9. 44.79443 0.7324748 2400. 44.9705~ 0.795398 122 0 0 0.850724 41.2525 3150 105 D. 14.3176 ¢8. 7120 2309 0.3465.53 3 2 3 2 3 1 - 1 -2 -4 - 4 0 2 10 11 7 7 '-3 -3 · -7 -7 -3 -2 4 5 7 7 O 0 4 5 6 7 6 6 0 0 -4 .-4 0 1 7 6 2 1 -3 -3 -3 -2 t 1 ¢ 5 5 5 .3 3 0 0 -3 -3 -3 -3 0 0 3 9TLN 112.6 DTLF 29-S5P-89 13:55:50 PAGE 2 3 3 2 2 3 0 0 0 -3 -4 -4 -4 -4 -3 4 5 i1 11 10 5 3 Z -4 -5 '-5. -7 -6 -6 -1 0 ! 6 6 7 7 ? 6 3 1 -3 -3 -3 -4 -3 -3 1 2 2 7 7 7 5 4 '3 -1 -2 -3 -5 '-5 -5 -3 -3 - 2 2 3 4 ? ? 7 6 5 4 0 -1 -1 -3 -3 -3 -2 -2 -I 2 3 3 5 5 5 5 5 5 3 Z 2 0 -1 -1 -3 -3 -3 -3 -Z -2 1 1 2 111. SPHI 0.3141651 120. 0.8100586 120. 0.9472656 0.5009766 129. 0.5507813 164. O. 9. O. O. O. O. O. 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O. 1400. 10¢. 0.328582 Z 6.646'77 2750. 200. 0. 209 2567 40.81519 2600 · RMSC 1.919 CHE 21.83 RGR 106.9 30.98177 1150. 123. 0.2765132 34.02686. 2650. 210. 0.5.372794 45.458~ PR SHE GR 79 0.2948112 3 4 3 0 0 0.3149414 223. O. O. 0.7856793 9.36264 1150. 192. 0.4953098 41.35117 2600. 164. 0.6857142 0. 31135 19.94 118.1 D.,B, TA RECORD TYPE 0 DEPT 439140 TOO 306613768 TIME 1670. TENS 2190. MaRK 51.53 TI4 712.4 LTT1 1296.8 SSLT -45 W=ID 3652.8 WF! -27 -27 1 1 ! 1 1 I 1 1 ! 1 1 I 1 I 1 1 i 1 1 ! 1 I 1 1 .lin 3659.5 FT .'--_'TIM 11518.04 TT1 713.6 LTT2 1068.4 WFZD 3652.575 30 i 1 1 1 1 1 1 I 1 ! 1 1 1115.4156 CS TT2 LTT 3 WF3D 1069 485 .Z 1526 · 3652.158 DIFF TT3 LTT4 WF4D -0.55 942.7999 1312.4 3651.933 ~CHLUMBERGER LZST MF40: []LI.SA. 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