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Home My WebLink About193-030Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1 2 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1 3 1L-06 50-029-21164-00 n/a Kuparuk River Leak Detect Log Field- Final 7-May-24 0 1 4 1L-06 50-029-21164-00 909298478 Kuparuk River Multi Finger Caliper Field & Processed 8-May-24 0 1 5 1L-06 50-029-21164-00 n/a Kuparuk River Plug Setting Record Field- Final 7-May-24 0 1 6 1L-24 50-029-22170-00 909422478 Kuparuk River Multi Finger Caliper Field & Processed 4-Jul-24 0 1 7 1L-24 50-029-22170-00 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1 9 2A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1 10 2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39155 T39156 T39157 T39157 T39157 T39158 T39158 T39159 T39160 T39161 193-030 218-084184-133 191-066201-210 185-145184-035 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:13:09 -08'00' 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1 T39155 193-030 218 084 • • RECEIVED • STATE OF ALASKA MAY 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well StatuWEILl❑LSOION EEPIZISPLUG OReRr E COMPLAbandoned E TION OtheREP ORT cANOG 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or `'_ 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 011 110 193-030/316-030 3.Address: 7. Date Spudded: .3k1/7...„L„ 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 2/28/1993 50-029-22346-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 619'FNL,796'FEL, Sec 33,T12N, R10E, UM 3/4/1993 KRU 1H-10 • Top of Productive Interval: 9. Ref Elevations: KB: 96 17. Field/Pool(s): 443'FNL, 1187'FWL,Sec 34,T12N, R10E, UM GL: 54 BF: 56 Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 383'FNL, 1557'FWL, Sec 34,T12N, R103, UM 6862/6322 ADL 25639 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 549551 y- 5980083 Zone- 4 7561/6892 ALK 464 TPI: x- 551532 y- 5980273 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 551901 y- 5980336 Zone- 4 1792/1792 1609/1609 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 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 None SIEp JuN1 1 5 2016 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD CASING FT. GRADE TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 40 121 40 121 24 200 sx PF C CMT 9 5/8 36 J-55 40 4394 40 4273 12.25 845 sx Perm E 420 sx ClassG 7 26 J-55 38 7535 38 6871 8.5 210 sx ClassG CMT 24.Open to production or injection? Yes ❑ No j 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): 4 x 3.5 6894 6857/6318 Perforations squeezed off: 6970'-6990'MD/6410'-6426'TVD (p-rA-t'QoN EL) 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. - Was hydraulic fracturing used during completion? Yes❑ No 2 L -1,1,/ 1 /� Per 20 AAC 25.283(i)(2)attach electronic and printed information }1p DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6862-7245 Pumped 40 bbls of Class G CMT LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): WELL PLUGGED FOR CTD SIDETRACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate Form 10-407 Revised 11/2015 '' ' L v//o No CONTINUED ON PAGE 2 bmit ORIGINIAL only" Bola s`ijz�is- RBDMS �� MAY 0 3 20 " • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 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 ND Well tested? Yes ❑ No (] Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1609 1609 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6912 6362 information, including reports,per 20 AAC 25.071. Top of Kuparuk C 6912 6362 Base of Kuparuk C 7122 6534 Top of Kuparuk A 7288 6669 Base of Kuparuk A 7424 6780 Formation at total depth: Kuparuk 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontoloaical report.production or well test results.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my(a) knowledge. /�//� Contact: Keith Herring 263-4321 Email: Keith.E.Herrinaacop.com Printed Name: J. Burke Title: SR.CTD ENGINEER Signature.- Phone: 265-6097 Date: Z-J/to 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 1 b: 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 ND 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 S 1 H-10 DTTMS.JOBTYP SUMMARYOPS 3/3 DRILLING SLB CTU#11: SPOT UNIT AND PREPARE FOR BOP TEST, MILLING SUPPORT- JOB IN THE MORNING. CAPITAL 3/4 DRILLING SLB CTU#11: PERFORM WEEKLY BOP TEST ON BACK DECK. MU SUPPORT- AND TEST BAKER CTC. RIG BACK DUE TO WORSENING WEATHER. CAPITAL 3/5 DRILLING RIH with motor and 2.80" mill to nipple @ 6881'. Correct depth, flag pipe SUPPORT- and mill out nipple. Make dry drift passes and POOH. Ready for cement job CAPITAL tomorrow. In progress. 3/6 DRILLING Run in hole to tag at 7245. Space out 5'and pump 5 bbls FW spacer SUPPORT- followed by 10 bbls cement(neet), 25 bbls cement(with cemnet), 5 bbls CAPITAL cement(neet)and 36 bbls diesel. Lay in cement and pull up to safety at 3600'. Apply squeeze pressure to cement then begin cleanout. Pump/contaminate with 105 bbls of Power Vis down to 6878' followed by slick diesel, chasing returns out of hole. Well ready in 72 hours for slickline tag. Job in progress. 3/10 DRILLING TIE INTO GLM @ 6898' RKB FOR CORRECTION &TAG TOC @ 6860' SUPPORT- RKB. OBTAIN GOOD 15 MIN. X 2000 PSI TBG TEST. READY FOR DHD. CAPITAL 3/12 DRILLING (PRE-CTD) : SV DDT (PASSED). SSV DDT(PASSED). MV DDT SUPPORT- (PASSED). SV PPT (PASSED). SSV PPT(PASSED). CAPITAL L KUPD 1 H-10 ConocoPhiltips 1 : Well Attribut Max Angle D TD w AI;i`H<t.I,)t.. Wellbore APOUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) )p 500292234600 KUPARUK RIVER UNIT PROD 35.94 6,822.90 7,561.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-10,4/26/2016 257:02 PM SSSV:TRDP 50 7/29/2015 Last WO: 6/16/1993 3/4/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,198.0 8/2/2015 Rev Reason:GLV C/O pproven 4/19/2016 HANGER;37.6 H 1 -Casing Strings -ILI-_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED .4.10-;,(---•LCasing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread ISURFACE 9 5/8 8.921 39.8 4,394.3 4,273.2 36.00 J-55 BTC --� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread PRODUCTION 7 6.276 39.2 7,535.0 6,870.9 26.00 J-55 AB-MOD CONDUCTOR;40.0-121.0 Tubing Strings Ili Tubing Description !String 1Top(ftKB) 1Set Depth ft..1Set Depth(TVD)(...1Wt(Ib/ft) !Grade 'TopConnectionMa. 1 ( ) TUBING 4"x35" 43.47637.66,894.06.347.811.00J-55 DSSHTC SAFETY VLV;1,791.7 riirl,. Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 37.6 37.6 0.73 HANGER FMC GEN IV HANGER 4.000 1,791.7 1,791.7 0.73 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 GAS LIFT;2,503.9 3,931.7 3,880.3 27.35 XO Reducing CROSSOVER 4 x 3.5 3.500 6,857.0 6,317.8 35.90 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,857.9 6,318.5 35.90 PACKER BAKER FE-1 PERMANENT PACKER 3.000 6,881.4 6,337.5 35.76 NIPPLE OTIS XN NIPPLE 2.81"POLISHED BORE w/2.75"NO 2.750 GO GAS LIFT;3,983.3 6,893.1 6,347.1 35.69 SOS BAKER SHEAR OUT SUB 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,210.0 6,605.2 35.50 FISH 'BHA left in hole,TOL=13.466' 8/8/2015 7,440.0 6,793.1 35.02 FISH PLUG WEATHERFORD 2.5"IBP-LOST 10/5/2006 DOWNHOLE IN RATHOLE 10/2/2006 SURFACE;39.8-4,394.3 Perforations&Slots GAS LIFT;4,656.5 Shot Dens M Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;5,366.1 - 6,875.0 6,877.0 6,3323 6,334.0 A-4,1H-10 2/2/2016 3.0 APERF 2"HSC/120 6,970.0 7,025.0 6,409.7 6,454.5 C-4,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg GAS LIFT;8,108.5Il - Phasing 6,970.0 6,990.0 6,409.7 6,426.0 C-4,1H-10 10/18/2006 6.0 RPERF 6 SPF,2506 HYPERJET,PENT= GAS LIFT;6,487.2 13.1",EH=0.43" 6,974.0 6,984.0 6,412.9 6,421.1 C-4,1H-10 4/6/2006 6.0 RPERF 2.5"HSD GUN,2506 PJ 11. , HMX,60 deg phase • GAS LIFT;8,809.5 7,034.0 7,048.0 6,461.9 6,473.3 C-3,1H-10 10/7/1993 6.0 APERF EnerJet 01;90 deg Phasing I 7,098.0 7,124.0 6,514.0 6,535.2 C-1,UNIT B, 9/6/1993 6.0'APERF 1 11/16"Strip Gun;0 1H-10 deg Ph 7,310.0 7,345.0' 6,686.7 6,715.3 A-4,1H-10 6/16/1993 4.0 IPERF SWS 4.5"Csg Gun; - SEAL ASSY;6,857.0 Oirientede d 8 deg.CCW f/ PACKER;6,857.9 ' Stimulations&Treatments Min Top Max Btm APERF;6,875.0$877.0-. I Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 6,970.0 6,990.0 6,409.7 6,426.0 FRAC 10/26/200 PUMP C-SAND 6970'-6990'FRAC.W/YF1500 GEL NIPPLE;6,881.4 6 1084720 16/20 CARBO PROP,PUMPED TOTAL OF 112%OF DESIGN,EXTEND 10 PPA STAGE TO 117 BBLS FROM 60.FLUSH W/10 BBLS WF-20 AND 59 I".,, DIESEL.FLUSHED TO COMPLETION,FINAL PUMPING PRESSURE 4556 PSI,ISIP=2593 PSI ' (2260 PSI EST.BOTTOM HOLE PRESSURE). SOS;6,893.1 .i� Cement Squeezes t,) Top(NO) Btm(TVD) RPERF;6,974.06,984.0 i 0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn RPERF;8,970.06,990.0 > 6,916.0 7,230.0 6,365.6 6,621.5 CMT SQZ 10/14/200 FRAC;6,970.0 i 6 WHIPSTOCK;6,994 a r >; 7,025.0 7,245.0 6,454.5 6,633.7 Cement Plug 3/6/2016 pumped cement 6860 to 7245,milled to 7025 FRAC,6,970.0 Le. , 6,970.0-7,025.0 Mandrel Inserts A LATERAL LINER ASSY; f ►. St 6,884.9-10,518.0 i i ati i °^ Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com APERF;7,034.0-7,048.0 1 2,503.9 2,503.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,374.0 4/17/2016 itregAotof 2 3,963.3 3,908.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,380.0 4/17/2016 3 4,656.5 4,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/29/2016 APERF;7,088.0-7,124.0 4 5,385.1 5,099.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,360.0 4/17/2016 5 6,108.5 5,698.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 4/17/2016 FISH;7,210.0 _ 6 6,487.2 6,013.7 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 6/16/1993 8:30 7 6.809.5 6,279.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 4/17/2016 • •-• Notes:General&Safety End Date Annotation 9/23/2010 NOTE.View Schematic w/Alaska Schematic9.0 (PERF;7,310.0-7,345.0-- I I FISH;7,440.0 PRODUCTION;39.2-7,535.0 0 i Operations Summary(with Timeiog Depths) aWels 1H-10 ConocoYhdhps , I. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time -Dur(hr) Phase Op Code Acihnly Code Time P-T-X - Operation (RK(13) End Deplh(91(B) 3123/2016 3/23/2016 3.00 MIRU MOVE MOB P Continue to MOB off 2K-25 to 1H-10 0.0 0.0 10:00 13:00 3/23/2016 3/23/2016 3.00 MIRU MOVE MOB P Northern Energy services trucks on 0.0 0.0 13:00 16:00 location,PJSM load up shop 3/23/2016 3/24/2016 8.00'MIRU MOVE MOB .P Leave 2K pad Mob to 1H 0.0 0.0 16:00 00:00 3/2412016 3/24/2016 4.00 MIRU MOVE MOB .P Arrive at 1 H-de jeep and spot ng on 0.0 0.0 00:00 04:00 1-R 3/24/2016 3/24/2016 6.00 MIRU MOVE RURD P Rig up on 1R-work post rig move 0.0 0.0 04:00 10:00 checklist,Rig up cellar,swap out in micro motion 3/24/2016 3/24/2016 4.00 MIRU WHDBOP NUND P 10:00 Rig accept,Nipple up stack, 0.0 0.0 10:00 14:00 Swap out apapterflanges,4 1/16"tree 3/24/2016 3/24/2016 - 1.00 MIRU WHDBOP RURD P Tighten well head bolts,all loose 0.0 0.0 14:00 15:00 3/24/2016 '3/24/2016 2.00 MIRU WHDBOP RURD P Grease crew here to repair Tango 0.0 15:00 17:00 valve grease port-broken.Fill stack for shell test repair stem packing on same valve 3/24/2016 3/25/2016 7.00 MIRU WHDBOP BOPE P Start BOP test,250 psi low/4200 psi 0.0 0.0 17:00 00:00 high,Witness waived by Bob Noble 3/25/2016 3/25/2016 4.00 MIRU 'WHDBOP BOPE P Continue performing initial BOP test 0.0 0.0 00:00 04:00 3/25/2016 3/25/2016 5.00 SLOT WELLPR CTOP P PJSM,perform pipe management, 0.0 0.0 04:00 09:00 trim 1425 ft of coil. 3125/2016 3/25/2016 2.00 SLOT WELLPR 'CTOP P PJSM,Boot a-line,Fill coil,PT inner 0.0 0.0 09:00 11:00 reel iron,pack offs,and new micro motion install 3/25/2016 3/25/2016 1.00 SLOT 'WELLPR CTOP 'P Pump slack mgmt,cut 57'of pipe and 0.0 0.0 11:00 12:00 find wire.Trimmed 75'for 1500'total 3/25/2016 3/25/2016 1.50 SLOT WFI I PR CTOP P PJSM,Prep coil for connector instal, 0.0 0.0 12:00 13:30 Instal CTC and pull to 35K,Head up e -line to UQC,PT CTC/UQC to 4K 3/25/2016 3/2512016 2.00 SLOT WHDBOP PRTS P PJSM,PT PDL's to 1500 PSI,TT to 0.0 0.0 13:30 15:30 150OPS1 3/2512016 3/25/2016 2.00 SLOT WHDBOP MPSP P PJSM,R/U BPV Lubricator,Pull TWC 0.0 0.0 15:30 17:30 3/25/2016 3/25/2016 1.00 SLOT WHDBOP RURD P Crew change,PJSM, pressure up on ' 0.0 0.0 17:30 18:30 SSSV from 2000 psi to 4500 psi, install fuseable cap on SSV-log onto safety defeat log in doghouse. 3/25/2016 3/25/2016 1.00 SLOT WHDBOP RURD P Perform valve checklist,inspect Top 0.0 0.0 18:30 19:30 Drive. 3/25/2016 3/25/2016 1.50 PROD1 RPEQPT PULD P PJSM,MU pilot hole milling BHA#1 0.0 62.5 19:30 21:00 3/25/2016 3/25/2016 0.75 PROD1 RPEQPT TRIP P RIH,with BHA#1,0.9°bend motor 62.5 1,795.0 21:00 21:45 and new 0331 mill(slick gauge) 3/25/2016 3/25/2016 1.00 PROD1 RPEQPT TRIP P 1795 ft,Tag SSSV 30 fpm at 0.3 bpm, 1,795.0 1,800.0 21:45 22:45 set down 6k,POW 15k,try different TF,no success,pressure up to 1500 psi on the tubing noticed flapper shift down hole,continue RIH thru SSSV clean, 3/25/2016 3/25/2016 1.00 PROD1 RPEQPT TRIP P Continue RIH to tie in depth. 1,800.0 6,740.0 22:45 23:45 3/25/2016 3/26/2016 0.25 PROD1 RPEQPT DLOG P 6740 ft,log HRZ and K1 for baseline 6,740.0 6,785.0 23:45 00:00 corrrection of Page 118 Report Printed: 5/9/2016 III 0 '.n'7.�" Irl h 4 :A.r , ' Operations Summary(with Timelog Depths) 1H-10 Conocol'hillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time Erni Thee , Dur(hr) Phase Op Cade _ Activity Code Time P-T-X Operation - - (fKE) End Depth(MB) (B) 3/26/2016 3/26/2016 0.25 PROD1 RPEQPT DLOG P 6785 ft,continue logging for tie In, 6,785.0 6,862.0 00:00 00:15 correction of plus 1.5 R. 3/26/2016 3/26/2016 6.00 PROD1 'RPEQPT MILL P Tag TOG at 6862 ft,PUW 30k,bring 6,862.0 6,900.0 00:15 06:15 pump up to 1.6 bpm at 2500 psi,swap to vis SW,BHP 3168,IA 808,OA 434 Mill pilot hole. 3/28/2016 3/26/2016 3.20 PROD1 RPEQPT MILL P Stall 3 times here,-7'below TT,most 6,900.0 6,925.0 06:15 09:27 likely 7"casing contact.mill 1'at 180° out 3/26/2016 3/26/2016 4.60 PROD1 RPEQPT MILL 'P 6925,Stall multiple times,Correletes 6,925.0 6,986.0 09:27 14:03 to 7"collar 3/26/2016 3/26/2016 0.40 PROD1 RPEQPT WPRT P 6986,Stall.Pump sweeps and chase 6,986.0 6,986.0 14:03 14:27 to TOG,PUW=35K,Motor work at transition area and TOG 3/26/2016 3/26/2016 4.00 PROD1 RPEQPT MILL P 6986',Mil,1.6 BPM(a3 2280 PSI FS, 6,986.0 7,025,0 14:27 18:27 BHP=3189,ROP=-15 FPH, DHWOB=1.9K 3/26/2016 3/26/2016 1.50 PROD1 -RPFOPT REAM P 7025 ft.TD cement pilot hole,pump 7,025.0 6,862.0 18:27 19:57 5x5 sweep,PUW 32k,PUH,ream transition area,pumping 1.6 bpm at 2230 psi,BHP 3185,WHP 0,IA 565, OA 740 3/26/2016 3/26/2016 0.50-PROD1 RPEQPT OWFF P Check well for flow 6,862.0 6,862.0 19:57 20:27 3/26/2016 3/26/2016 1.50 PROD1 RPEQPT -TRIP 'P POOH,pumping 1.5 bpm at 2130 psi, 6,862.0 62.5 20:27 21:57 EDC dosed.pumping 5x5 sweep at 3931 ft. L 3/26/2016 3/26/2016 0.50 PROD1 RPEQPT OWFF P Check well for flow,PJSM 62.5 62.5 21:57 22:27 3/26/2016 3/26/2016 0.75 PROD1 RPEQPT PULD P LD milling BHA#1,gauge mill 2.78 62.5 0.0 22:27 23:12 OD no-go. 3/26/2016 3/27/2016 0.80 PROD1 RPEQPT PULD 'P MU nozzle,stab INJH,jet slack, 0.0 0.0 23:12 00:00 3/27/2016 3/27/2016 0.85 PROD1 RPEQPT PULD P PJSM,PU/MU Haliburton caliper 0.0 21.8 00:00 00:51 .. tools,and Colilrak tools. 3/27/2016 3/27/2016 0.25 PROD1 RPEQPT PULD P Test Haliburton caliper,looks good, 21.8 21.8 00:51 01:06 tag up and reset counters,RIH, pumping 3/27/2016 3/27/2016 1.50 PROD1 RPEQPT TRIP P RIH,pumping min rate 0.32 bpm,100 21.8 7,015.0 01:06 02:36 fpm,slowing down for jewelry.Drive by K1 no correction_ 3/27/2016 3/27/2016 1.24 PROD1 RPEQPT DLOG P 7015 ft,First pass log up at 40 fpm up 7,015.0 5,980.0 02:36 03:50 to 5980 ft,RBIH to 7015 ft.Second pass log up at 40 fpm up to 5980 ft. 3/27/2016 3/27/2016 1.20 PROD1 RPEQPT TRIP P 5980 ft,POOH pumping 0.8 bpm at 5,980.0 21.0 03:50 05:02 800 psi,IA 317,OA 507 3/27/2016 3/27/2016 1.00 PROD1 RPEQPT PULD P At surface,perform 30 min no flow- 21.0 0.0 05:02 06:02 lay down BHA#2 caliper running BHA 3/27/2016 3/27/2016 2.40 PROD1 WHPST PULD P P/U and M/U BHA#3 whipstock 0.0 73.0 06:02 08:26 setting BHA,M/U to coil track and surface test.Open EDC dre freshwater to in Micro motion and set zero 3/27/2016 3/27/2016 2.10 PROD1 WHPST TRIP 'P Trip in hole with whipstock 73.0 6,795.0 08:26 10:32 3/27/2016 3/27/2016 0.10 PROD1 WHPST DLOG P Log K1 for}1',PUW=32K 6,795.0 6,810.0 10:32 10:38 Page 218 Report Printed: 5/912016 • S 11 11if1 Operations Summary (with Timelog Depths) &Wells 1H-10 Conocorhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tkne End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (5KB) End Depth(5KB) 3/27/2016 3/27/2016 0.40 PROD? WHPST TRIP P Continue in hole,Get to set depth of 6,810.0 7,005.5 10:38 11:02 / 7005.5,TOWS @ 6995.Orient to 10° G -‘,„)\)i LOHS.Bring on pumps see tool shift v @ 3500 PSI,Set down 4K 3/27/2016 3/27/2016 1.50 PROW WHPST TRIP P Trip out after setting whipstock 7,005.5 79.0 11:02 12:32 l 3/27/2016 3/27/2016 1.00 PROD1 WHPST PULD P At surface,30 min flow check.PJSM, 79.0 0.0 12:32 13:32 Lay down BHA#3 whipstock setting. 3/27/2016 3/27/2016 0.50 PROD1 WHPST PULD P M/U BHA#4,window milling BHA 0.0 i 74.3 13:32 14:02 with.6°motor,2.80 window mill and string reamer,M/U to coil and surface test 3/27/2016 3/27/2016 1.90 PROW WHPST TRIP P Trip in 74.3' 6,795.0 14:02 15:56 3/27/2016 3/27/2016 0.10 PROD1 WHPST OLOG P Log K1 for+.5, 6,795.0 6,814.0 15:56 16:02 3/27/2016 3/27/2016 0.70 PROD1 WHPST CIRC P Open EDC and displace to 8.45 PPG 6,814.0 6,850.0 16:02 16:44 floPro 3/27/2016 3/27/2016 020 PROD1 WHPST TRIP P Close EDC,trip in to dry tag whipstock 6,850.0 6,994.3 16:44 16:56 3/27/2016 3/28/2016 7.06 PROD1 WHPST WPST P Call pinch point @ 6693.8,1.5 BPM @ 6,994.3 6,995.7 16:56 00:00 2610 PSI FS 3/28/2016 3/28/2016 4.00 PROD1 WHPST WPST P OBM,window 1.51 bpm at 2700 psi 6,995.7 6,997.9 00:00 04:00 on bottom,BHP 3214,open choke,IA , 499,OA 694 3/28/2016 '3/28/2016 1.30 PROD1 WHPST WPST P 6997.9 ft,Midpoint,time milling 1.52 6,997.9 6,998.8 04:00 05:18 bpm at 2800 psi,BHP 3219,Open choke,IA 231,OA 360 3128/2016 3/28/2016 2.70 PROD1 WHPST WPST P 6998.8',call window exit,Start drilling 6,998.8 7,016.0' 05:18 08:00rathole 3/28/2016 3/28/2016 1.20 PROW WHPST REAM P Make reaming pass per procedure,as 7,016.0 7,016.0 08:00 09:12 drilled,Dry drift looks good 3/28/2016 3(28/2016 1.50 PROW WHPST *TRIP , I/ P Trip out of well,PUW'29K,stop and 7,016.0' 74.0 09:12 10:42 NJ open EDC @ 6753 3/28/2016 3/28/2016 1.30 PROD1 WHPST *PULD 1 ` 7_Al surface,30 Min flow check-good, 74.0 0.0 10:42 12:00 5 F"1 8 ''Lay down window milling BHA#4 r 3/28/2016 3/28/2016 ' 0.90 PROD1 *DRILL PULD \' �IPJSM,P/U BHA#5 Build section BHA 0.0 72.2 12:00 12:54 l/� w 2.35°AKO motor and RR NCC bl �� center,M/U to coil and surface test 3/28/2016 3/28/2016 1.30 PROD1 DRILL TRIP P Trip in hole,EDC open 72.2' 6,780.0 12:54 14:12 3/28/2016 3/28/2016 0.10 PROD1 DRILL r DLOG P Log K1 for+3',PUW=+3' 6,780.0' 6,800.0 14:12 14:18 3/28/2016 3/28/2016 0.20 PROD1 DRILL TRIP •P Continue in well,dean pass through 6,800.0 7,016.0 14:18 14:30 window,tag up at 7016 3/28/2016 3/28/2016 0.30 PROD1 DRILL DRLG P 7016',Drill,1.51 BPM @ 2647 PSI 7,016.0 7,024.0 14:30 14:48 FS,BHP=3253 3/28/2016 3/28/2016 0.20 PROD1 DRILL WPRT P t 7024 high diff pressure-unable to 7,024.0* 6,850.0 14:48 15:00 pump,PUH above TOC 3/28/2016 3/28/2016 0.20 PROD1 DRILL WPRT P Above TOC,open EDC,1.5 BPM with 6,850.0 6,850.0' 15:00 15:12 2200PSI pump pressure 10 PSI diff pressure,Close EDC to test pressures.Stili unable to circulate,.4 BPM @ 1537 PSI Pump,700PSI Diff. 3/28/2016 3/28/2016 1.50 PROW DRILL TRIP T Trip oul to inspect BHA 6,850.0 72.2 15:12 16:42 Page 3/8 Report Printed: 5/9/2016 • c sq ". ' ', �,1,--P x'- Operations Summary (with Timelog Depths) >>=�, ! ;A a 1H-10 Loki]CoPhillip5 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Tyne P-T-X Operation IMKB) End Depth(11KB) 3/28/2016 3/28/2016 0.75 PROD1 DRILL PULD T Check well for flow,Inspect BHA, 72.2 0.0 16:42 17:27 found X-Treme motor to be locked up 3/28/2016 3/28/2016 1.25 PROD1 DRILL 'PULD T MU new 2-3/8"X-Treme motor and 0.0 72.2 17:27 18:42 RR HHC bi-center bit.Surface test coiltrak tools,tag up,reset counters. 3(28/2016 3/28/2016 1.25 PROD1 DRILL TRIP T RiH,build section BHA#6,2.35°bend 72.2 6,780.0 18:42 19:57 motor,and RR bit. 3/28/2016 3/28/2016 0.25 PROD1 DRILL DLOG T 6780 ft,Log K1 ctxrection of plus 1.0 ` 6,780.0 6,800.0 19:57 20:12 ft.PUW 30k 3/28/2016 3(28/2016 0.25 PROD1 DRILL TRIP T 6800 ft,continue RIH thru window. 6,800.0 7,026.0 20:12 20:27 3/28/2016 3/28/2016 1.50 PROD1 l DRILL DRLG T 7026 ft,OBD 1.5 bpm at 2790 psi FS, 7,026.0 7,075.0 20:27 21:57 BHP 3020,Open Choke,IA 284,OA 423 ****Note:5 hrs BHI DT 3/28/2016 3/28/2016 0.25 PROD1 DRILL WPRT P 7075 ft,PUH for corrected WS 7,075.0 6,780.0 21:57 22:12 numbers.PUW 30k 3/28/2016 3/28/2016 0.25 PROD1 DRILL DLOG P 6780 ft,log K1 correction of plus 0.5 ft. 6,780.0 6,800.0 22:12 22:27 3/28/2016 13/28/2016 0.15 PROD1 DRILL DLOG P 6800 ft,RN log RA marker, 6,800.0 7,075.0 22:27 22:36 TOW-6994' BOW-6999' RA -7001.5' 3/28/2016 3/29/2015 1.40 PROD1 DRILL DRLG P 7075 ft,BOBD 1.55 bpm at 2700 psi 7,075.0 7,097.0 22:36 00:00 FS,BHP 3280,open choke,IA 300, OA 426 ****Note:control drilling due to high dgls>47° 3/29/2016 3/29/2016 5.00 PROD1 DRILL DRLG P OBD 1.55 bpm at 2775 psi,BHP 7,097.0 7,168.0 00:00 05:00 3304,open choke,IA 400,OA 485 3/29/2016 3/29/2016 1.00 PROD1 DRILL 'DRLG P 7168 ft,OBD 1.54 bpm at 2751 psi, ' 7,168.0' 7,182.0 05:00 06:00 BHP 3317,open choke,IA 446,OA 510 3/29/2016 3/29/2016 3.30 PROD1 DRILL 'DRLG P OBD,on harder formation,ROP 7,182.0 7,215.0 06:00 09:18 <15FPH, 1.5 BPM at 2712 PSI FS 3/29/2016 13/29/2016 0.20 PROD1 DRILL WPRT P Mini wiper to 7080 ft,PUW'34K,clean 7,215.0 7,215.0 09:18 09:30 trip I 3/29/2016 3/29/2016 3.70 PROD1 DRILL DRLG 'P 7215',Drill,1.55 BPM Q 2721 PSI 7,215.0 7,260.0 09:30 13:12 FS,At 7221'Pumped 15 BBI pill of screen clean to clear possible bit balling.No real change In ROP. 3/29/2016 3/29/2016 3.00 PROD1 k DRILL DRLG P 7260 Pump rest of screen dean pill, 7,260.0 7,305.0 13:12 16:12 no Indication of help,Continue to drill, 1.6 BPM @ 2741 PSI FS,13HP=3340 3/29/2016 3/29/2016 ' 1.80 PROD1 DRILL TRIP P 7305 call End of Bulld-Pump 5 X 5 7,305.0 72.0 16:12 18:00 Sweeps,trip out,PUW=31K 3/29/2016 3/29/2016 0.50 PROD1 DRILL 'OWFF P No flow at surface. 72.0 _ 72.0 18:00 18:30 3/29/20163/29/2016 ' 1.15 PROD1 DRILL PULD P PJSM.LD BRAN,inspect BHA,LD 72.0 0.0 18:30 19:39 motor&bit,no Indication of poor performance,pictures of bit on S:drive.Replace floats and test CC& UQC,good test to 4,000 psi. 3/29/2016 3/29/2016 ' 0.90 PROD1 DRILL PULD P PJSM.MU BHA#7,new motor&RB 0.0 72.5 19:39 20:33 HYC bit Page 4/8 Report Printed: 5/9/2018 zksPi 4-t LIAR 2 201'6 WELL LOG TRANSMITTAL#903100796 4,o( ' a To: Alaska Oil and Gas Conservation Comm. March 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 �2yz � ��E � �''� � � ;_. ,� M.K.BENDEDE 010R RE: Static Bottom Hole Pressure and Perforation Records: 1H-10 Run Date: 2/2/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22346-00 Static Bottom Hole Pressure and Perforation Records (Field Print) 1 Color Log 50-029-22346-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com -n.OV Date: Si ned:� AL -n.4) ®F T� �, � wAN ,v THE STAT• Alaska Oil and Gas tt) - of Conservation Commission Itti-t1 .� �;- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 Main: 907.279.1433 Op.AL AS Fax: 907.276.7542 www.aogcc.alaska.gov 6 201'V3- Keith Herring O C CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-10 Permit to Drill Number: 193-030 Sundry Number: 316-030 Dear Mr. Herring: 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 2/day of January, 2016. RBDMS.L'- JiAw L 5 Z016 • 411 RECEIVED STATE OF ALASKA JAN 1 . R.016 /� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O Cu 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑., Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑Q . Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Cement Squeeze n' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc ' Exploratory ❑ Development 0, 193-030' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510-0360 50-029-22346-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? • Will planned perforations require a spacing exception? Yes ❑ No 0/ KRU 1H-10 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25639, Al K 4G4 Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7561' 6892' 7226' q 6618' ' 3765 7226' 7210'/7440' Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' 1640 670 Surface 4354' 9 5/8" 4394' 4273' 3520 2220 Production 7496' 7" 7535' 6870' 4980 4320 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6970'-6990' ' 6410'-6426' 4"x 3 1/2" 11#/9.3#,J-55 Tbg 3932'!6894' 7310'-7345' ' 6687'-6715' Packers and SSSV Type: Packer-Baker FB-1 Permanent Packer Packers and SSSV MD(ft)and TVD(ft): , 6858'MD and 6318'TVD SSSV-Camco TRDP-4A-RO . 1792'MD and 1792'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/1/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0' 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: Keith Herring @ 263-4321 Email Keith.E.Herrings conocophillips.com Printed Name Keith Herring Title CTD Engineer ///3,2% Signature Phone:263-4321 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\L — 00 Plug Integrity ❑ BOP Test rj Mechanical Integrity Test ❑ Location Clearance ❑ Other: 8bP 7,6-5 i• to 4}ZOO/.3S) (/1'1,125P /S 3�1v,5 ,o ' ) , rD/Vlar Vh /- r -� 75-176775-1767s Zh • 11ltr�v/ aiie-t'plv I' /ac«cvrt otp`rvv- per , ,v 4A--C Z3 - /1Z (4 ) Post Initial Injection MIT Req'd? Yes [i No [V" Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /o_ 4t7-- APPROVED BY Approved by: ai67 COMMISSIONER THE COMMISSION Date: —Z/-/6 F'Vi�r��i4, Submit Form and Form 10-403 Revised 11/2015O Rice fliti�valid for 12 months fromt�e toof apprQyal. ( (�Attachments in Duplicate VTI l !aa`i� L ,1O4 JAN Z 5 2016 • • KRU 1H-10 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 1H-10 is a Kuparuk A-sand and C-sand producer equipped with 31/2" tubing and 7" production casing. The CTD sidetrack will utilize one lateral to target the C3 and C4 sands to accelerate production near 1H-10 and 1H-16. This lateral will be supported by vertical injectors 1H-03 and 1H-22. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail and the XN nipple at 6881' MD will be milled out to a 2.80" ID. The existing A-sand perforations have been covered with a sand plug. A cement plug will be placed on the sand plug and the C- sand perforations will be squeezed with cement. The 3-1/2" tubing tail will be cemented in place and will 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 and C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7025' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 7000' MD. The single lateral will be completed with 2-3/8" slotted liner from TD with the liner top located inside the 3-1/2" tubinct ail. tie f(o f-pc/ /, .6✓ 61 rA pcoPlei Gtr'►//t7 ' bp,1// cop e& ct e4,14v- t4 fe/«-'es Curreyi .)p, Wait! Tii,s w�//, rtierClr�.n 40 reswl 2tr+'e4 i ofe�e�l Using the maximum formation pressure in t e area of 4408 psi in 1H-07, the maximum potential surface ressure, assuming a gas gradient of 0.1 psi/ft, would be 3765 psi. Pe' I/4 CTD Drill and Complete 1H-10 Lateral: March 2016 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 31/2" tubing tail at 6878' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out XN nipple, place a cement plug on sand plug, and cement squeeze the C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. ✓ 2. 1H-10A Sidetrack (C3/4 - sand) ��$ 5 vi-2 ct✓y a. Drill 2.80" high-side pilot hole through cement to 7025' MD b. Caliper pilot hole c. Set top of whipstock at 7000' MD d. Mill 2.80" window at 7000' MD. e. Drill 3" bi-center lateral to TD of 10600' MD. f. Run 2%" slotted liner with deployment sleeve from TD up to 6883' MD. 3. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Me PTD Post-Rig Work Page 1 of 2 1/13/2016 • • 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 1/13/2016 KUP PROD ! 1 H-10 ConlocoP/ fillips ; Well Attributes Max Angle&MD TD Alaska.l lC. Wellbore APIIUWI Field Name Wellbore Status Incl('I MD(ftKB) Act Btm(ftKB) CrwrrYhilkpr 500292234600 KUPARUK RIVER UNIT PROD 35.94 6,822.90 7,561.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-10,8/13/20153.32:34 PM SSSV:TRDP 50 11/5/2014 Last WO: 6/16/1993 3/4/1993 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._,. Last Tag:SLM 7,198.0 8/2/2015 Rev Reason:FISH LEFT IN WELL lehallf 8/13/2015 HANGER;37.6-.11 it Casing Strings lig 51-1 Casing Description OD(in) ID(in( Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 39.8 4,394.3 4,273.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 392 7,535.0 6,870.9 26.00 J-55 AB-MOD Tubing Strings CONDUCTOR;40.0.121.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 4"x3.5" 4 3.476 37.6 6,894.0 6,347.8 11.00 J-55 DSSHTC Completion Details SAFETY VLV;1,791.7 a;1, Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(.) Item Des Corn (in) 37.6 37.6 0.73 HANGER FMC GEN IV HANGER 4.000 SI 1,791.7 1,791.7 0.73 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 3,931.7 3,880.3 27.35 XO Reducing CROSSOVER 4 x 3.5 3.500 GAS LIFT;2,503.9 • 6,857.0 6,317.8 35.90 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,857.9 6,318.5 35.90 PACKER BAKER FB-1 PERMANENT PACKER 3.000 6,881.4 6,337.5 35.76 NIPPLE OTIS XN NIPPLE 2.81"POLISHED BORE w/2.75"NO 2.750 GO V 6,893.1 6,347.1 35.69 SOS BAKER SHEAR OUT SUB ' 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT 3,963.3ill Top(ND) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) 7210.0 6,605.2 35.50 FISH BHA left in hole,TOL=13.466' 8/8/2015 7.440.0 6,793.1 35.02 FISH PLUG WEATHERFORD 2.5"IBP-LOST 10/5/2006 DOWNHOLE IN RATHOLE 10/2/2006 Perforations&Slots onsDen SURFACE;39.8-4,394.3 Top(ND) Btm(ND) D (shotstt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6,970.0 6,990.0 6,409.7 6,426.0 C-4,1H-10 10/18/2006 6.0 RPERF 6 SPF,2506 GAS LIFT;4,656.5 -- HYPERJET,PENT= 13.1",EH=0.43" 6,970.0 7,025.0 6,409.7 6,454.5 C-4,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg GAS LIFT;5,385.1 Phasing 6,974.0 6,984.0 6,412.9 6,421.1 C-4,1H-10 4/6/2006 6.0 RPERF 2.5"HSD GUN,2506 PJ HMX,60 deg phase GAS LIFT;6,108.5 7,034.0 7,048.0 6,461.9 6,473.3 C-3,1H-10 10/7/1993 6.0 APERF EnerJet 18;90 deg • Phasing GAS LIFT;8,487.24 7,098.0 7,124.0 6,514.0 6,535.2 C-1,UNIT B, 9/6/1993 6.0 APERF 1 11/16"Strip Gun;0 1H-10 deg Ph 7,310.0 7,345.0 6,686.7 6,715.3 A-4,1H-10 6/16/1993 4.0 IPERF SWS 4.5"Csg Gun; Oriented 68 deg.CCW f/ High Side GAS LIFT;6,809.5 - Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(ND) _ (ftKB) (ftKB( (ftKB) (MB) Type Date Corn 6,970.0 6,990.0 6,409.7 6,426.0 FRAC 10/26/200 PUMP C-SAND 6970'-6990'FRAC.W/YF150#GEL 6 1084728 16/20 CARBO PROP,PUMPED TOTAL OF SEAL ASSY;6,8570 112%OF DESIGN,EXTEND 10 PPA STAGE TO 117 PACKER;6,857.9i -, BBLS FROM 60.FLUSH W/10 BBLS WF-20 AND 59 • DIESEL.FLUSHED TO COMPLETION,FINAL PUMPING PRESSURE 4556 PSI,ISIP=2593 PSI (2260 PSI EST.BOTTOM HOLE PRESSURE). NIPPLE;6,881.4 Cement Squeezes Top(ND) Btm(ND) SOS;6,693.1 'i: Top(ftKB) 0511(ftKB) (ftKB) (ftKB) Des Start Date Corn Y-. Valve Latch Port Size TRO Run 6,9)6.0 7,230.0 6,365.6 6,621.5 CMT SQZ 10/)4/200 6 RPERF;6,974.0-6,984.0 Mandrel Inserts FRAC;6,970.0 RPERF;6,970.0-6,990.0 - St on Top(ND) ati APERF;6,970.0.7,025.0-♦ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i 2,503.9 2,503.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,345.0 2/6/2007 2 3,963.3 3,908.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/6/2007 APERF;7,034.0.7,048.0- • 3 4,656.5 4,495.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,332.0 2/6/2007 • 4 5,385.1 5,099.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/5/2007 5 6,108.5 5,698.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,318.0 2/5/2007 APERF;7,098.0-7,124.0- . 6 6,487.2 6,013.7 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 6/16/1993 7 6,809.5 6,279.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 2/5/2007 " Notes:General&Safety FISH;7,210.0 End Date Annotation 9/23/2010 NOTE.View Schematic w/Alaska Schematic9.0 IPERF;7,310.0-7.345.0 FISH;7,440.0 PRODUCTION;39.2-7535.0 • . • 1H-10 Proposed CTD Schematic Modified by JGE 1-12-16 4"Camco TRDP-4A-RO SSSV at 1792'MD ID=2.812" 4", 11#,J-55,DSSHTC tubing to 3932'MD 31/2'9.3#J-55 EUE 8rd tubing below 3932'MD 16"62.5#H-40 ,11 at 121'MD 4"Camco KBMG mandrel at 2504'MD 3'/2'Camco KBUG gas lift mandrels at 3963',4657',5385', 9-5/8"36#J-55 at 6109',and 6487'MD 3'/i'Camco MMG-2 mandrel at 6810'MD 4394'MD Baker GBH-22 locator seal assemly at 6857'MD Baker FB-1 packer at 6858'MD(3.0"ID) XN nipple at 6881"MD (2.75"min ID) 3W tubing tail at 6893'MD Hifi? NNW • - r KOP @ 7000'MD C-sand perfs(sqz'd) 6970'-7048'MD ti '-- 7098'-7124'MD !'N Ciu�;�rrS:r�:rrSlS:fir - � A-sand perfs r�'J",Vtt`%;i1SJSU1 7310'-7345 MD r"JJJJ;ruJJJJJJJr 1H-10A ,603 ;s"JJJ;rr;rJ;r rrJ rJ TD @ 10,600'MD JJ,rJJ'J,?,r,•J rJ rJ Covered by fill up to110MOBB s?,?;?;r?,r•r,rs r r Topof Liner 6883'MD 7228'MD B :Ivz,: rS:r:i.^S.::r.R R+: J;r;F;t3:SJ.IJJJJJ 7"26#J-55 at toVerJia= 7535 MD �;xussusuu,�russ rrJJUJJJJJS:iJJJ rr;�1SS:tf:t:::rSs:;g • • • 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 ;Resp�gnsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the /Patrici or Steve 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 proposedtrici or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria 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 for Jermi• j.4Z 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 History tab len+44- 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 change Jeroi, U- 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 1en4+n-i- L4 - Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. 19 .5- 030 • • WELL LOG TRANSMITTAL#902970325 DATA LOGGED Zit /2O1 K.BENDER To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper and Jewelry Record: 1H-10 Run Date: 12/6/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-10 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22346-00 Jewelry Log (Field Print) SCANNED2 r p; 1 color log 50-029-22346-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS ANC@halliburton.com Date:_ Signed: / ' / ..eoczat XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs-of various kinds [] Other COMMENTS: Scanned by: Bevedy Di~than Lowell Date;~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si Scblumbel'ger d, NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 2, '7 Lom CO\1\fniss\on Company: " ¡If, ~ ~ 1 'lût)l ~'. NeD t\\Jo ~r. ,}ioo ",v Field: Well Job# Log Description Date BL 1R-27 11850425 FPIT ¡q / -/0;) 08/18/07 1 31-08 11839638 LDL J"fr(" -rfh\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I rrl' 1£:11 - ~2 07/29/07 1 3G-26 11813071 LDL Jo,o,-h"J"K 07/30/07 1 1R-18 11837482 SBHP/DDL JC71 -' ^'7>?- 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - /~3-(i')ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' {)TI" 11r.~ -(-A.< 08/01/07 1 3H-32 11837483 LDL .Dtf) -Ñ1 I 08/01/07 1 1Y-10 11837485 INJECTION PROFILE . U:t..Œ. Vlf~ -('£" ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' ¡.,/') - {J (Pfr 08/04/07 1 1A-06 11837486 INJECTION PROFILE irrC' l"ir- / If.... 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . AN~ - J(.. ~ 08/06/07 1 2U-08 11813076 LDL W17L ,~-~( 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE J~3. - I~d.. 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()7(' Je}-,r - rA::J 08/08/07 1 2N-327 11837491 SONIC SCANNER Db -q. -0<0") 08/08/07 2N-327 11837491 SONIC SCANNER-FMI ........."""1 .r ,." 08/08/07 3K-01 11632749 PRODUCTION PROFILE . ¡ff(P - Jr)( 08/12107 1 2X-04 11846430 INJECTION PROFILE l J:U' I'$¡3 -II*, 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1rir ~ )::J<1 08/13/07 1 2X-19 11850420 SBHP SURVEY J 0, S" - J"J,<.,- 08/13107 1 1A-20 11850421 SBHPSURVEY ¡~n-JL~ 08114107 1 1F-13 11850422 SBHP SURVEY U':L "\ Js.3 -J1./l.J 08/14107 1 1H-10 11846432 SBHP SURVEY Jq-= -~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY /~ - JC?7r 08/14/07 1 2U-05 11846433 INJECTION PROFILE , ,Tß J!ír.¿;;--{)J"f( 08/15107 1 2D-12 11846434 PRODUCTION PROFILE J frl./ -1""A4 08/16107 1 2H-06 11846435 LDL ¡~£:; - J/ß:), 08/17107 1 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 1 ';}7f' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08122/07 . . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t3 ( 1 1 1 Color CD Kuparuk Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 04/20/07 Field: Well Job# Log Description Date BL 1A-10 11638846 INJECTION PROFILE 04/05/07 1 2L-313 11628996 LDL 04/08/07 1 1 D-137 11628997 INJECTION PROFILE 04/09/07 1 2N-311A N/A USIT 04/06/07 2N-337B 11638852 SCMT 04/11/07 1J-184 11638853 SBHP 04/12/07 1 1H-10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDLlPPROF 04/10/07 1 1 E-112 11638856 INJECTION PROFILE 04/14/07 1 1J-156 11638857 INJECTION PROFILE 04/15/07 1 1J-127 11638859 INJECTION PROFILE 04/17/07 1 1J-105 11628994 USIT 04/06/07 1J-164· 11638858 INJECTION PROFILE 04/16/07 1 o 1J-164. 11638860 INJECTION PROFILE 04/17/07 1 Ie¡ 3 - 0?:/:J Company: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~?R 2. 0 lOa7 "0 ~.r\r'·· I,""ir'p ) C:'~~ Cr)ns · flH",I,_'>'':>' ,,' «;';'~J1~'"' sCANNED APR 2 5 2.007 NO. 4219 Schlumberger [1\ ILr~ ¡\ '. .. \;¡~.". ì~ \~ :\ \ iì~ ìL..--W . )F'/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 - Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tb Avenue, Suite 100 Anchorage, AK 99501 \ Q.3'" 02>0 SCANNED JAN 1 6 2007 Dear NIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1. 0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhil1ips Problem 'Wells Supervisor 6 . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10' 9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11' 2.00 24" 12/16/2006 13.2 12/28/2006 10-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA T1QNS¡ 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate EI dt~;t;·L¡1j·3D Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 193-030 / 306-228 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22346-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 1H-10 8. Property Designation: 10. Field/Pool(s): ADL 25639: ALK 464 Kuparuk River Field / Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 7561' . feet true vertical 6892' feet Plugs (measured) 7440' Effective Depth measured 6985' feet Junk (measured) true vertical 6422' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 4354' 9-5/8" 4394' 4273' PROD. CASING 7496' 7" 7534' 6870' ~((; . , ~, 1 -- ..- Perforation depth: Measured depth: 6970'-7025',7034'-7048',7098'-7124',7310'-7345' true vertical depth: 6410'-6455',6462'-6473',6514'-6535',6687'-6715' Tubing (size, grade, and measured depth) 4" /3-1/2" , J-55, 3932' /6894' MD. RBDMS 8Ft 1 6 2006 Packers & sssv (type & measured depth) pkr= BAKER FB-1 PERM. 6858' Cameo TRDP-4A-RO SSSV @ 1792' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6916'-7230' for cement sqz, 6970'-6990' for frac ./ Treatment descriptions including volumes used and final pressure: refer to attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation 191 - 1043 1275 -- 215 Subsequent to operation 968 - 1175 187 -- 214 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0- Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[2J: GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Guy Schwartz @ 265-6958 Printed Name :.?uy SChwa:é', =- Title Wells Group Engineer ..... Signature (:1'-'-'1 s:~. .0" Phone: 265-6958 Date II-{I.{ -0 C. ~~ "\. Prenared bv Sharon AI/sun-DrakE> 263-4612 (]'- ~ . Form 10-404 Revised 04/2004 ORIGINAL , ,/fb /f./Ý.ðf:, /<t'-l\ \ S-" SU~igina~ oyl: .¿ ~ ////~/~ DATE 9/2/06 9/3/06 9/4/06 9/5/06 9/6/06 10/1/06 1 0/2/06 1 0/3/06 10/4/06 1 0/5/06 1 0/7/06 10/10/06 10/11/06 10/12/06 10/13/06 10/14/06 10/17/06 10/18/06 10/20/06 10/20/06 1 0/26/06 . 1H-10 Well Events Summary . Summary BAILED @ 7288' WLM. FULL BAILERS OF SAND. JOB IN PROGRESS. BAILED SAND AT 7304' WLM. IN PROGRESS. BAILED FROM 7296' TO 7300' WLM. IN PROGRESS. BAILED SAND @ 7302' WLM. IN PROGRESS. BAILED DOWN TO 7303' WLM. ABORT JOB. ATTEMPTED TO REVERSE OUT FILL FORM TOP OF IBP @ 7313' RKB. UNABLE TO REVERSE LOW BHP . POOH AND CALL FOR N2 TO ASSIST IN FCO, RU 2" NOZZLE AND CHECKS. MAKE SECOND RUN WITH 500 SCFM N2 AND SLICK DIESEL TO A FINAL DEPTH OF 7421' CTM. IBP MOVED DOWN 108'. TAG FILL W/2.5" LIB @ 7325' RKB. ESTIMATE 20' ABOVE BTM PERF. LIGHT IMPRESSION OF SAND, NO IMPRESSION OF IBP. RAN 2.25" DD BAILER TAG @ 7334' RKB (EMPTY). RAN 2.65" LIB AND TAGGED @ 7334' RKB LIB INCONCLUSIVE. JOB IN PROGRESS. BAILED FORMATION SAND FROM 7334' RKB TO 7339' RKB. JOB IN PROGRESS TAG TT @ 6855' SLM/6894' RKB TO CONFIRM CORRECTION. BAILED FILL @ 7344' RKB. ***LEFT WELL SHUT IN*** PULLED GLV & SET DV IN STA. #1 @ 2504' RKB. PULLED OV & SET DV IN STA. #3 @ 4656' RKB. ATTEMPTED TO PULL GLV IN STA. #2 @ 3963' RKB. IN PROGRESS. PULLED GLV & SET DV @ 3963' RKB. SET 2.75" XN SV @ 6881' RKB. PT TBG 3000 PSI, GOOD TEST. IN PROGRESS. PULLED CAT SV FROM 2.75" XN @ 8661' RKB. Performed a sand plug from 7,330' RKB to 7,240' RKB. Pumped 22 BBL cement squeeze with aggregate. First attempt with no pressure increase. Staged second attempt (W/aggregate) squeeze pressure of 1,500 PSI achieved. During clean out stage at cement to sand interface squeeze broke down. Cleaned mandrel on way OOH. Well freeze protected with diesel to 2500'. 7.5 BBLS of cement behind pipe. STBY for sleep day. Long squeeze previous day & night C-sands squeezed with 12 BBLS of 15.8 PPG LARC with API FL of 72 ML. FCT= .88(inch). MAX achieved squeeze pressure = 2,350 PSI with well bore full of sea water. 7" casing flushed to hard tag at 7,246.7' CTMD. Well freeze protected to 2,500' RKB. PRESSURE TEST CEMENT SQUEEZE. INITIAL T/IAlOA PRESSURES: 0/1480/440. PRESSURE UP TUBING TO 1600 PSI WITH 1 BBL DIESEL. TP @ 1500 PSI AFTER 15 MINUTES, 1400 PSI AFTER 30 MINUTES. REPEAT TEST SAME RESULTS. LEFT 1400 PSI ON TUBING. PERFORATED: 6970' - 6990',6 SPF, 2506 HYPERJET, PENT= 13.1", EH= 0.43", ./ TAGGED BOTTOM AT 7236' PUMP FB SAND PLUG TO COVER SQU C-SAND PERFS. PUMPED 850 # 20/40 SAND DISPLACED WITH 42 BBLS OF sw AND 23 OF DIESEL 7 BBLS OFF PERFS, WELL PRESSURED OUT 3500 PSI. LET SAND SETTLE AND TAG WITH SL. TOP OF SAND SHOULD BE @ 7200' RKB BOTTOM PERF IS @ 6990' RKB TAGGED SAND PLUG @ 7101' RKB. PUMP C-SAND FRAC.WNF150# GEL 108472# 16/20 CARBO PROP, PUMPED TOTAL OF 112% OF DESIGN, EXTEND 10 PPA STAGE TO 117 BBLS FROM 60. FLUSH W/10 BBLS WF-20 AND 59 DIESEL. FLUSHED TO COMPLETION, FINAL PUMPING PRESSURE 4556 PSI, ISIP= 2593 PSI (2260 PSI EST. BOTTOMHOLE PRESSURE). . 1 H-1 0 Well Events Summary . 10/27/06 Perform N2 assisted FCO to hard tag on cement plug @ 7236' ICoil corrected depth, perfs @ 7075' appear to be continually dumping frac sand with each pass. Heavy frac sand in returns with 1: 1 returns throughout job. Jetted GLM's while PUH. Once @ surface, injected 30 bbls of diesel down tubing for freeze protect assurance. 10/28/06 SITTING DOWN & UNABLE TO DRIFT PASS 6985' RKB, EST. 11' OF OPEN PERFS. SET CATCHER IN XN NIPPLE @6881' RKB. PULLED DV'S @ 5385' RKB, 4656' RKB, 3963' RKB, 2504' RKB. SET GLV'S @ 2504',3963',4656' RKB. IN PROGRESS. 10/29/06 SET OV @ 5385' SLM, PULL CATCHER @ 6881' SLM. JOB COMPLETE. . . ConocoPhillips Alaska, Inc. KRU 1H-10 ~ API: 500292234600 Well Tvce: PROD Angle (â.! TS: 35 dea (â.! 6970 SSSV Tvce: TRDP Oria Comcletion: 3/4/1993 Anale (â.! TD: 35 dea (â.! 7561 sssv Annular Fluid: Last W/O: 6/16/1993 Rev Reason: TAG, SOZ, FRAC, (1792-1793, L GLV C/O 00:4.000) Reference Loa: Ref Loa Date: Last Ucdate: 11/9/2006 Last Tag: 6985 TO: 7561 ftKB Last ~ate: 10/28/2006 Max Hole Anale: 36 ~~ 6823 TVD wt Grade Thread DescriDtion Size Top Bottom CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 9.625 0 4394 4273 47.00 J-55 PROD. CASING 7.000 0 7534 6870 26.00 J-55 Tubing String - TUBING Size I TOD I Bottom I TVD I wt I Grade Thread 4.000 I 0 I 3932 I 3881 I 11.00 I J-55 DSSHTC 3.500 I 3932 I 6894 I 6348 I 9.30 I J-55 EUE 8RD MOD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 6970 - 6990 6410 - 6426 C-4 20 6 1 0/18/2006 RPERF 6 SPF, 2506 HYPERJET, PENT= 13.1", EH= 0.43" 6990 - 7025 6426 - 6455 C-4 35 0 1 0/14/2006 7034 - 7048 6462 - 6473 C-3 14 0 1 0/14/2006 7098 - 7124 6514 - 6535 C-1,UNIT 26 0 1 0/14/2006 B 7310 - 7345 6687 - 6715 A-4 35 4 6/16/1993 IPERF SWS 4.5" Csg Gun; Oriented 68 deg. CCW f/ Hiah Side Stimulations & Treatments Interval Date Type Comment 6916 - 7230 10/1412006 CEMENT SOZ C-sands squeezed with 12 BBLS of 15.8 PPG tARC with API FL of 72 ML. FCT= .88(inch). MAX achieved squeeze pressure = 2,350 PSI with well bore full of sea water. 7" casing flushed to hard too at 7,246.7' CTMD. 6970 - 6990 1 0/26/2006 FRAC PUMP C-SAND 6970'-6990' FRACWIYF150# GEL 108472# 16/20 CARBO PROP, PUMPED TOTAL OF 112% OF DESIGN, EXTEND 10 PPA STAGE TO 117 BBLS FROM 60. FLUSH W/10 BBLS WF-20 AND 59 DIESEL. FLUSHED TO COMPLETION, FINAL PUMPING PRESSURE 4556 PSI, ISIP= 2593 PSI (2260 PSI EST. BOTTOM HOLE PRESSURE). PBR Gas Lift MandrelslValves (6857-6858, St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv 00:3.500) Mfr Cmnt 1 2504 2504 Cameo KBMG GLV 1.0 BK 0.156 1275 1 0/28/200 2 3963 3908 Cameo KBUG GLV 1.0 BK 0.156 1287 1 0/28/200 3 4656 4495 Cameo KBUG GLV 1.0 BK 0.188 1815 1 0/28/200 4 5385 5099 Cameo KBUG OV 1.0 BK 0.250 0 1 0/26/200 5 6108 5698 Cameo KBUG DMY 1.0 BK 0.000 0 3/24/1999 6 6487 6014 Cameo KBUG DMY 1.0 BK-5 0.000 0 6/16/1993 sos 7 6804 6275 Cameo MMG-2 DMY 1.5 RK 0.000 0 3/24/1999 (6893·6894, Other Dluas, eauip., etc.) - COMPLETION 00:3.500) DeDth TVD Type Description ID 1792 1792 SSSV Cameo TRDP-4A-RO 3.313 Perf 6857 6318 PBR Baker GBH-22 3.000 (6974-6984) 6858 6319 PKR Baker FB-1 PERM. 3.000 FRAC 6881 6337 NIP Otis XN Nipple 2.81" POLISHED BORE w/2.75" NO GO 2.750 (6970-6990) 6893 6347 SOS Baker 2.992 6894 6348 TTL 2.992 CEMENT Fish - FISH soz Depth I Description I Comment (6916-7230) 7440 I PLUG ¡WEATHERFORD 2.5" IBP - LOST DOWNHOLE IN RAT HOLE 1 0/212006 Perf (7098-7124) Perf - I-- (7310-7345) - f--- - I-- - I-- e e FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Guy Schwartz Well Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 '2>,ö,D \0\ Re: Kuparuk Field, Kuparuk Oil Pool, 1 H -10 Sundry Number: 306-228 ..... " :ì \"7 "'¿rUn\)" '."1"':.·.N.'.MEtJ ,Ui '.I i .. ' \,..' ';)'Vi'i-'" 'V~'-· \oì -- Dear Mr. Schwartz: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisz...f day of June, 2006 Encl. e Conoc6Phillips e Guy Schwartz Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 June 23, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 2 6 2006 Alaska Oil & Gas Cons. Commission Anchorage Subject: Application for Sundry Approval for 1 H-1 0 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming well work on the Kuparuk weIl1H-10. If you have any questions regarding this matter, please contact me at 265-6958. 6icereIY'~~, G. sZartz ~ Wells Group Engineer CPAI Drilling and Wells GS/skad OR\G\NAL 1. Type of Request: Abandon Rf6r;/z.7)o¿ .i tJu C/q/,£ e~(d-~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 6 2006 APPLICATION FOR SUNDRY APPROVAlka Oil & Gas Cons. Comm¡s~i. n. 20 MC 25.280 ,) (J . o Suspend 0 Operational Shutdown 0 Perforate ¡g¡ ~ð Waiver Other 0 o Repair well 0 Plug Perforations [KJ~d;timulate 0' Time Extension 0 o Pull Tubing 0 Perforate New Pool 0 fJ Re-enter Suspended Well 0 Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3, Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 96' 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 193~030 . 6. API Number: 50-029-22346-00 . 9. Well Name and Number: 1 H-1 0 . 8. Property Designation: . ADL 25639, ALK 464 11. Total depth MD (ft): 7561' , Casing CONDUCTOR SUR. CASING PROD. CASING Total Depth TVD (ft): Effective Depth MD (ft): 6892' . 7316' Length Size 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7083' MD TVD Burst Collapse 7" 121' 4394' 7534' 121' 80' 4354' 7496' 16" 9-518" 4273' 6870' Perforation Depth MD (6970'-7025', 7034'-7048',7098'-7124',7310'-7345' Packers and SSSV Type: pkr= BAKER FB-1 PERM. SSSV= Perforation Depth TVD (ft): 6410'-6455'. 6462'-6473',6514'-6535',6687'-6715' Packers and SSSV MD (ft) 6858' 1792' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 . Gas 0 WAG 0 GlNJ 0 Tubing Size: 4" / 3-1/2" Tubing Grade: J-55 Tubing MD (ft): 3932' / 6894' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16, Verbal Approval: Commission Representative: 0' Service 0 July 10, 2006 Date: Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact: Title: Signature Phone Guy Schwartz @ 265-6958 Wells Group Engineer Date ¿ -..¿3-O(ó Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Form 10-403 Revised 7/2005 ~ ØP~,k6 Submit in Duplicate ,42:> t,- Z8 .~ Other' "'2S"'tf'L. '. /"-;, '" . ~. '--''-'VC;;" ,,"" "\IM....\':)""'- "........\ '-J Subsequent Form Required: \.-\.'C)~ Approved by: e e IH-IO C sand Cement Squeeze and Fracture Stimulation Date: 6-22-06 Background: Well1H-10 was drilled as part ofthe 1993 infill program at 1H. The A sand was fracture stimulated with 133M# of propp ant 7/93, and the well produced 200 bopd and 0% We. The C1 interval was perforated 9/93, and production from this thief zone has been dominant since the perforations were added. Perforations added 10/93 in the C34 intervals provided a small increase in production based on the initial well test, but subsequent well tests indicated that the well returned to the C1 production trend. The 8/99 PPROF indicated that 100% ofthe well contribution was from the C1 interval with the well cycling at 1500-2800 bfpd. The 3/06 PPROF indicated 25% of the total flow was from the A sand at a liquid rate of 800 bfpd. Since January 2006, the well tests have ranged 800-3900 bfpd, and the contribution from the A sand has most likely ranged from 0% to 25% during this time and is hydraulically limited by C1 water cut production. In April 2006 an Inflatable bridge plug was set just below the C34 interval to try to get a C34 only well test. The plug failed after a few days and moved downhole to 7313' md which is in the middle of the A4 perfs. This needs to fished out before proceeding with the cement squeeze operation. A conventional cement squeeze is recommended to shut off water production from the C1 interval in 1H-1O. The WSO squeeze will be followed by re-perforations and a fracture stimulation ofthe C34 interval. The objectives are to shut off the high water' cut Cl interval and produce the A and C34 sand intervals commingled. Successful completion of this work will shut off the 93% WC production from the C1 interval and exploit the reserves at risk in the C34 and A sand intervals in the western area of 1H pad. Outline of Procedure: 1. Pull failed IBP at 7313' md. 2. Pull OV and GLV's and replace with DV's. PT tubing. 3. Spot sand plug over A4 interval. 4. Squeeze C1, C34 interval with cement. Jet out cement to top of A sand plug. 5. Pressure test cement squeeze. 6. Sand back to cover C1 interval (both C1 and A4 sand covered with sand now). 7. Reperfthe C34 interval with 2.5" HSD guns. 8. Fracture stimulate the C34 interval. 9. RU CTU and perform post frac c1eanout to PBTD. A4 and C34 open to flow. KRU 1 H-1 0 i1H-10 Gas Lift MandrelNalve 1 (2504-2505, , Descriotion CONDUCTOR SUR CASING PROD 'A"," '" UI:!IN\::i ~Size I. "!QQ. 1 B~:~2m 3. 6894 TVD Zone 0-6974 64106413 C-4 6974 6984 -6413-~(¡421 C-4 ---,---- C-4 C-3 C-1,UNIT B A-4 6421 - 6455 6462 - 6473 6514 - 6535 Well Type: £'f'ì-ºº---____ Orig 3/4/1993 Completion: last W/O: 6/16/1993 Ref loq Date: W;;~~ Max H~~6823 Size Too Bottom TVD .t Grade Thread 16,000 0 __ 121 121 6250 9.625 0 4394 - 4273 47.00 7.000 0 7534 6870 - 26 I TVD 1 Wt I Grade Thread I I 3881 -1-11.00 I J-55 I DSSHTC I I ~ J-55 I EUE 8RD MOD I StatulL~ TVrJe Comment 4 6 10/7/1993 APERF EnerJet III; 90 deq Phasinq 10 12 4/6/2006 RPERF 2.5" HSD GUN, 2506 PJ HMX, 60 deq phase EnerJet III; 90 deq Phasina EnerJet III' 90 dea Phasino 1 11/16" Strip Gun; 0 deg Ph 35 4 6/16/1993 ¡PERF SWS 4.5" Csg Gun; Oriented 68 deg, CCW fl Hiqh Side Angle @ TS: i 35deq (â) 6970 Anglé @ TO: 135 deg @ 7561 API: 500292234600 SSSV Type: TRDP SSSV (1792-1793. 00:4.000) TUBING (0-3932, 00:4.000, 10:3.344) Annular Fluid: Reference loq: last Taa: 7316 last Taq Date: 3/9/2006 ~-~._.- Rev Reasan: Set IBP, PERF last Update: 418/2006 Gas Lift- MandrelNa!Ve 2 (3963-3964 Gas Lift MandrelNalve 3 (4656-4657, 6984 - 7025 7034 " 7048 7098 - 7124 41 14 26 -- 6 6 6 10/7/1993 APERF 10/7/1993 APERF 9/6/1993 APERF 7310 - 7345 6687 6715 St MO TVD Man Man Type V Mfr V Type VOD latch Port TRO I 0 ---~ Mfr Run Cmnt 1 2504 2504 Camco KBMG GlV 1.0 BK 0.188 1264 3/24/1999 2 3963 3908 Cameo_ KBUG GlV 1.0 BK-5 0.188 1315 3/24/1999 3 4656 4495 Cameo KBUG I OV 1.0 BK 0.250 0 3/24/1999 L[ 5385 5099 Cameo KBUG DMY 1.0 BK-5 0.000 0 6/16/1993 8 Cameo KBUG DMY 1.0 ~..,- BK 0.000 0 W 4 Cameo KBUG DMY 1.0 BK-5 0.000 0 6/16/1 '75 Cameo MMG-2 DMY 1.5 RK~ 0 3/24/1 ~th TVD Tvoe ID 1792 1792 SSSV Cameo 1>, A Dr 3.313 PBR -- 6857 6318 PBR i8kp.r G -1<':;> 3.000 '~Qn ÇQ"Q 6858 ~ 6319 PKR ,8kp.rFi PERM. 3.000 6881 NIP "XN nnlA 2.750 TUBING -- 6893 SOS ker 2.992 (3932-6894, 00:3.500, 6894 I 6348 -. TTl 2.992 102.992) 7083 I 6502 PLUG WEATHERFORD 2.5" IBP w/CENTER OF ELEMENT (â)7083' set 4/6/2006 0,000 sos (6893-6894, 00:3.500) Perf ~ (6974-6984 ) Perf - (6970-7025) - Perf ~ (7034-7048) ---. - 1,--- .- f---- - i-- --, - i-- Perf ,,-, .--, (7098-7124) - 1--'- ,-,- - ~-,-- ------ --- Perf = = (7310-7345) .--- - -'-- - --. - - --- ,-- - ---~~"~- on '" curve .i "" ~ ~ water reserves to ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 April 28, 2006 EfVED MAY 0 1 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 AiS\s~Œ em E~ Gí~S Ct¡;ms. C['tmmission 1~l1c~oH~ge Subject: Report of Sundry Well Operations for 1 H-1 0 (APD # 193-030) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 1 H-1 O. ./ If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )/(. µ( ~ SCANNED MAY 092006 M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad 1. Operations Performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 1 REPORT OF SUNDRY WELL OPERA TIONSaska Oil ~~ Gas COßS. Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other AI'I{:IDJra~]I¡~ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension D Change Approved Program 0 Ope rat. ShutdownD Perforate [] , Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory D 193-030 1 ~ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22346-00 .. 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 1 H-1 0 ~ ) ) "'. C.' E"·' ~~ .!I~"'''"'' [.,"'·"Iì. R II: , ","," ~\ II It'" .~ ¡ "\. ~::.:. "iJ' .~"'" ¡ 'w,¥ 1:"",,,. .."é 8. Property Designati~n: ADL 25639, ALK 464 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool I' Total Depth measured 7561' . 6892' feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured 7316' feet true vertical feet Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size MD TVD Burst Collapse 7" 121' 4394' 7534' 121' 4273' 6870' 80' 4354' 7496' 16" 9-5/8" Perforation depth: Measured depth: 6970'-7025',7034'-7048',7098'-7124',7310'-7345' true vertical depth: 6410'-6455',6462'-6473',6514'-6535',6687'-6715' Tubing (size, grade, and measured depth) 4" 13-1/2" , J-55, 3932' 16894' MD. Packers & SSSV (type & measured depth) pkr= BAKER FB-1 PERM. 6858' SSSV= 1792' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft MAYO 8 2006 Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ Oil-Bbl 50 111 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinç¡ Pressure 489 715 613 964 15. Well Class after proposed work: Exploratory D Development [] Service D Tubinç¡ Pressure 236 242 13. Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[]' GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O, Exempt: WDSPL 0 Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney ß{ A~ Title Phone: 263-4574 Wells Group Team Leader Date f/ ?0'/{5ø Prepared bv Sharon AI/sup-Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL ~lJ ~·"2·Þt. .r?- ~! S~~l. 't O. rigin.al Only '~ ,~ ~5~/%' ) 1 H-1 0 Well Events Summary ) DATE Summary 03/09/0606:00 AM TAGGED FILL WITH 2.7 G/R @ 7316' RKB, EST. 29' FILL. 03/14/0606:00 AM RIH WITH COIL FOR FCO ATTEMPT PUMPING DIESEL. UNABLE TO ESTABLISH RETURNS WITHOUT GAS LIFT. PUMP MINIMUM RATE AND TAG AT 7407' CTMD. TEMPORARILY STUCK COIL AT 7377' CTMD DUE TO CROSS FLOW FROM C TO A SAND. WELL HAS SUFFICIENT RAT HOLE FOR UPCOMING PLUG. 03/27/0607:00 AM RAN A PPROF W/DEFT: SPLITS: 75% C-1 AND 25% A-4 . 04/06/0607:00 AM SET 2.5" WEATHERFORD IBP WITH CENTER OF ELEMENT AT 7083'. OVERAL LENGTH OF ELEMENT IN PLACE IS 7'. FISH IBP's 1" FN WITH 1 3/8" JDC. **** PERFORATED THE INTERVAL 6974'-6984' WITH 2.5" HSD PJ2506, 6 SPF, 60 DEG ,,,/ PHASI NG. SSSV (1792-1793, 00:4,000) TUBING (0-3932, 00:4.000, 10:3.344) Gas Lift MandrelNalve 1 (2504-2505, Gas Lift MandrelNalve 2 (3963-3964, Gas Lift MandrelNalve 3 (4656-4657, PBR (6857 -6858, 00:3,500) TUBING (3932-6894, 00:3,500, 10:2,992) SOS (6893-6894, 00:3,500) Perf (6974-6984) Perf (6970-7025) Perf (7034-7048) Perf (7098-7124) Perf (7310-7345) ConocoPhillips Ala~la, ¡Inc" 1 H-1 0 .;.,---- --~ -=--- --r =ar.. ...~:_-~ .-.-- ... 11.··.·..··.·.···.·11I >< API: 500292234600 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 7316 Last Tag Date: 3/9/2006 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING IubingString -TUBING Size Top 4.000 0 3.500 3932 PerforatiOns Summary Interval TVD 6970 - 6974 6410 - 6413 6974 - 6984 6413 - 6421 6984 - 7025 7034 - 7048 7098 - 7124 6421 - 6455 6462 - 6473 6514 - 6535 6687 - 6715 7310 - 7345 Size 16.000 9.625 7.000 Bottom 3932 6894 Zone C-4 C-4 C-4 C-3 C-1,UNIT B A-4 ) KRU 1-1-10 Well Type: PROD Orig 3/4/1993 Completion: Last W/O: 6/16/1993 Ref Log Date: TD: 7561 ftKB Max Hole Angle: 36 deg @ 6823 Angle @ TS: 35 deg @ 6970 Angle @ TD: 35 deg @ 7561 Rev Reason: Set IBP, PERF Last Update: 4/812006 Top o o o TVD Wt Grade Thread 121 62.50 H-40 4273 47.00 J-55 6870 26.00 J-55 Wt Grade Thread 11.00 J-55 DSSHTC 9.30 J-55 EUE 8RD MOD Bottom 121 4394 7534 TVD 3881 6348 Status Ft SPF 4 6 10 12 41 6 14 6 26 6 35 4 Date Type Comment 10/7/1993 APERF EnerJet III; 90 deg Phasing 4/6/2006 RPERF 2.5" HSD GUN, 2506 PJ HMX, 60 deg phase 10/7/1993 APERF EnerJet III; 90 deg Phasing 10/7/1993 APERF EnerJet III; 90 deg Phasing 9/6/1993 APERF 1 11/16" Strip Gun; 0 deg Ph 6/16/1993 IPERF SWS 4.5" Csg Gun; Oriented 68 deg. CCW fl High Side Gas Lift .' MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2504 2504 Camco KBMG GLV 1.0 BK 0.188 1264 3/24/1999 2 3963 3908 Camco KBUG GLV 1.0 BK-5 0.188 1315 3/24/1999 3 4656 4495 Camco KBUG OV 1.0 BK 0.250 0 3/24/1999 4 5385 5099 Camco KBUG DMY 1.0 BK-5 0.000 0 6/16/1993 5 6108 5698 Camco KBUG DMY 1.0 BK 0.000 0 3/24/1999 6 6487 6014 Camco KBUG DMY 1.0 BK-5 0.000 0 6/16/1993 7 6804 6275 Camco MMG-2 DMY 1.5 RK 0.000 0 3/24/1999 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 1792 1792 SSSV Camco TRDP-4A-RO 3.313 6857 6318 PBR Baker GBH-22 3.000 6858 6319 PKR Baker FB-1 PERM. 3.000 6881 6337 NIP Otis XN Nipple 2.750 6893 6347 SOS Baker 2.992 6894 6348 TTL 2.992 7083 6502 PLUG WEATHERFORD 2.5" IBP wlCENTER OF ELEMENT @7083' set 4/6/2006 0.000 03/30/06 Sc~lunIbepgep NO. 3751 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 \ ø",1J' 0 11° e -'¡ ì .,t " Field: Kuparuk Well Job# Log Description Date BL Color CD Iq)-~· 1 8-06 11213713 PRODUCTION PROFILE W/DEFT (REDO) 02/27/06 1 2T-19 12213723 PRODUCTION PROFILE W/DEFT 03/24106 1 1E-117 11213725 INJECTION PROFILE 03/26106 1 1H-10 11213726 PRODUCTION PROFILE W/DEFT 03/27/06 1 3M-23 11213727 LDL 03/28/06 1 e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ON OR BEFORE A 0 G C C Geol og :i: ca i F' E R ~',t I "I/' D A T A 9:}} .... 030 566a. ..~ .... 0 3 0 . 'i L W: 1... L... r', p , ~ r::, R I L. I. I i',l,3 H I S-r' o k \.' z ,/{d/~/) =~ 9 93 -(.130 SUfRVEY 9 3 "- 0 3 0 C B 'i" 9 ~ '-' 0 :~ 0 CDN 93---0~0 CDR 93 --'0~0 CDR ENI-'tANCEk~ENT .,....~- 8 S D I R iii; C T I O N A L ~ S C t'I i. ~:; S D I R E C T 1,3, i"'d..& I. '-k"._ ' 8050 7 .fi. 'i 0 ~ ".:; t"1 d'.k~.", a- 1 a."* 756 i Cb'..' aa. 1a...-'756'i CC, RiRECTED ~-a 392---7512 d~ 6050..- 7 a. S 0 ~,3H 93 -~030 CBT Ar': dr"y ,'J:itch sarnples r'equir'ed? yes :~'_~d r'e,r::e"J;ved? V,/a:~ 'the we"il cored': yes ~- Anal?'s'i~s & descr:- ~ .... , r',:~,:::e~",/:~(:!'? We'i'/ :s :n compl'~ance ] f ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Aiasl:a 995'! Telephone 907 276 12!5 May 6, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~i~ ~ ~c;1 H-lO Stimulate ~ 5-- 1 H- 14 Perforate q ~_-~ ~ ~--~'i 1H-20 Pedorate ~:~q ~ ?~-~ 1Q-04 Stimulate ~.-'~; 1Y-24 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR050696 (w/o atch) RECEIVED MAY 11 1994 Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 ?,12 ;¥iL: ~ STATE OF ALASKA ALASKA OIL AND ~S CONSERVATION COMMIbSION REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Operation Shutdown __ Pull tubing __ Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address Stimulate X Plugging __ Repair well Perforate Other P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 619' FNL, 796' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 443' FNL, 1187' FWL, Sec. 34, T12N, R10E, UM At effective depth 393' FNL, 1492' FWL, Sec. 34, T12N, R10E, UM At total depth 383' FNL, 1557' FWL, Sec. 34, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7561 feet 6892 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-10 9. Permit number/approval number 93-30 10. APl number 50-029- 22346 11. Field/Pool feet Plugs (measured) Kuparuk River Oil Field/Pool None Effective depth: measured 7 4 4 7 true vertical 6799 feet feet Junk (measured) None Casing Length Structural Conductor 1 2 1' Surface 4 35 2' Intermediate Production 7 4 9 6' Liner Perforation depth: measured 6970'-7025' true vertical 6410'-6455' Size Cemented 1 6" 200 SX PFC CMT 9-5/8" 845SX Perm E 420 SX Class G 7" 210 SX Class G GMT Tubing (size, grade, and measured depth) 4",11#, J-55 @ 3932' & 3.5", 9.3#, J-55 @ Packers and SSSV (type and measured depth) PKR: Measureddepth True vedical depth 121' 121' 4394' 4273' 7534' 6860' , 7034'-7048', 7098'-7124', 7310'-7345' , 6462'-6473', 6514'-6535', 6687'-6715' 6894' Baker 'FB-I' Perm @ 6858'; SSSV: Camco TRDP-4A-RO @ 1792' 13. Stimulation or cement squeeze summary RECEIVED M~Y 11 19~4 14. Nitrogen breakdown of "C" sands on 3/28/94. Intervals treated (measured) ~i,.,~ke ~ ~ (Ja'~ Of'ti'lit, 6970'-7025', 7034'-7048', 7098'-7124' Treatment description including volumes used and final pressure Pumped 80 mscf N2, 4 bbls diesel, followed by 78 mscf N2 until disk sheared at 6500 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 941 475 16 1080 368 Subsequent to operation 1697 189 32 1300 337 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~~ ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT IPBDTW~L~/h'--" /0 I ~447 "' '"NTRACTOR REMAB'~S ~? -- /o%~,' , 7": l&~ ~.,; / J I FIELD- DISTRICT-STATE ! I DATE cc. .ScA: GO-I- [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Oil & Gas Cons. Commissio~ WeatherReport Temp._//0 °F Ichill'-~x~OFact°r°F I Visibility miles /d)knots ARCO Alaska, Inc. Post Office B 00360 Anchorage, A~aska 99510-0360 Telephone 907 276 1215 November 9, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION Perforate Stimulate Stimulate Perforate Stimulate Stimulate Stimulate Stimulate Perforate Other (conversion) Other (conversion) If you have any questions, please call me at 263-4241. . . Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED NOV 1 2 1993 Alaska 0ii & Gas Cons. Com~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ OIL AND GAS C, ONSERVATI~ ~MIL~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing ~ Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 619' FNL, 796' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 443' FNL, 1187' FWL, Sec. 34, T12N, R10E, UM At effective depth 393' FNL, 1492' FWL, Sec. 34, T12N, R10E, UM At total depth 383' FNL~ 1557' FWL~ Sec. 34, T12N~ R10E~ UM 12. Present well condition summary Total Depth: measured 75 61 feet true vertical 6892 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit Effective depth: measured 7 4 4 7 feet true vertical 6799 feet 8. Well number 1H-10 9. Permit number/approval number 93-30 Casing Length Size Structural Conductor I 21 ' 1 6" Surface 43 5 2' 9 - 5 / 8" Intermediate Production 74 9 6' 7" Liner Perforation depth: measured 6970'-7025', true vertical 6410'-6455', 10. APl number S0-029- 22346 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Junk (measured) None feet Cemented 200 SX PFC CMT 845 SX Perm E 420 SX Class G 210 SX Class G GMT Measured depth True vertical depth 121' 121' 4394' 4273' 7534' 6860' 7098'-7124', 6514'-6535', 7034'-7048', 6462'-6473', 7310'-7345' 6687'-6715' Tubing (size, grade, and measured depth) 4",11#, J-55 @ 3932' & 3.5", 9.3#, J-55 @ 6894' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 6858'; SSSV: Camco TRDP-4A-RO @ 1792' RECEIVED 13. Stimulation or cement squeeze summary Acidized "C134" sands on 10/26/93 Intervals treated (measured) 6970'-7025', 7034'-7048', 7098'-71 24' Treatment description including volumes used and final pressure Bullheaded 10 bbl diesel, 7 mscf N2, 64 bbls 10.7% HCl w/500 scl N2. NOV 12 199;} U,t & Oas C0ris, C0mm Anchorage 14. Representative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 71 9 2723 0 475 3O5 Subsequent to operation 1 41 0 820 0 520 275 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 7. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Si~ned · Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ;sion WELL I1-t-- CONTRACTOR Oo ~zL. ARCO Alaska, Inc.~ p Subsidiary of Atlantic Richfield Gompany - D£/vNI$ DOLL REMARKS FIELD - ~.~R~C~T - STATE OPERATION AT REPORT TIME C o,-w/~ WELL SERVICE REPORT 07..7o 0~+5- 07oo Oqlo ..~. ~IP/A.L, ~JHP S£&IAt Pg/lplXl& It) lo 1o+o 1, f %P/~, NOV 1 2 1993 [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp' IChillFact°r IVlsibillty IWlndVel'Report ,~' OF OF C(e~r' miles Oil & Gas Cons, Commission Anchorage ARCO Alaska, Post Offic-' 'x 100360 Anchorage, . ,iaska 99510-0360 7e!ephone 907 276 1215 October 29, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION Stimulate Perforate Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering -".R CO .-1,:3s~a. ~nc. iS a Subsicliary of AtlanticRicnhelclCompany STATE OF ALASKA AI_AoKA OIL AND GAS CONSERVATION COMMIo,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Pull tubing ~ Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 619' FNL, 796' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 443' FNL, 1187' FWL, Sec. 34, T12N, R10E, UM At effective depth 393' FNL, 1492' FWL, Sec. 34, T12N, R10E, UM At total depth 383' FNL, 1557' FWL, Sec. 34, T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 7 5 61 feet true vertical 6892 feet Plugging Perforate X Other __ 6. Datum elevation (DF or KB) RKB 7, Unit or Property name Kuparuk River Unit feet 8. Well number 1H-10 9. Permit number/approval number 93-30 10. APl number s 0-029- 22346 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7 4 4 7 feet true vertical 6799 feet Junk (measured) None Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4 3 5 2' 9 - 5 / 8" Intermediate Production 74 9 6' 7" Liner Perforation depth: measured 6970'-7025', true vertical 6410'-6455', Cemented 2O0 SX PFC CMT 845 SX Perm E 420 SX Class G 210 SX Class G GMT 7034'-7048', 6462'-6473', 7310'-7345' 6687'-6715' Measured depth 121' 4394' 7534' True vertical depth 121' 4273' 6860' RECEtVi. n 0 \! - 199,. Tubing (size, grade, and measured depth) 4",11#, J-55 @ 3932' & 3.5", 9.3#, J-55 @ 6894' Packets and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 6858'; SSSV: Camco TRDP-4A-RO @ 1792' 13. Stimulation or cement squeeze summary Perforated "C34" sands on 7/29/93 Intervals treated (measured) 6970'-7025' & 7034'-7048' Treatment description including volumes used and final pressure 6 spf @ 90° V phasing. 14. Re_oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Alaska u~i a alas Cons. L;ur~raisstu,' Anchorage Tubing Pressure Prior to well operation Subsequent to operation 1 873///-'2900 2 0 4 2 ,/2673 0 800 294 0 800 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned '~~~, ~/~/~/~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date I1--I- SUBMIT IN DUPLICATE ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL !DF. SCRIPT/ON OF WORK 1 H- 10 Perforate C-34 sands D~TE CONTRACTOR / KEY IJERSON KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# . SCA# 997943 - 80223 10/7/93 DAY 1 TIME 0700 0800 Schlumberger / Rathert PBTD (RKB) ]LAST TAG (RKB). DATE 7447' I 7427' - 8/2/93 LOG ENTRY I FIELD COST EST. ACCUMULATED COST $15,252 $15,252 SSSV TYPE / STATUS CAMCO TRDP-4A-RO / In service MIRU pump truck. Held safety meeting. PT'd to 3000 #. SI well and displaced with 80 bbls diesel. RD pump. Stand by for E-line unit. 1000 MIRU E-line. Pressure test to 3000g on BOPs and Lub. separately. NU with 1.375" RS, 6'X 1-11/16" WB, 18" CCL, 22"x 2.125" magnet, 10"x 1-11/16" gun head, 14'x 2.125" V gun. Gun loaded with 6 spf, Enerjet III, RDX charges at 90° phasing, 45° off bottom center. 5' from CCL to top shot. 1155 RIH. Tag fill at 7387' rkb. Tied in with CET log and logged up to GLM #7. 1303 Drop back down to 7200'. Open well to draw down BHP. Pull up to 7029' CCL (7034' top shot). Shoot interval from 7034' to 7048' rkb. SI well and POOH. All shots fired. 1425 Perforate from 7000' to 7025' rkb. 1450 Shut in well and POOH. All shots fired. NU with 30' gun. 5' from CCL to top shot. 1650 NU. with 25' gun. 5' from CCL to top shot. RIH. Drop down to 7130' rkb. Open well. Tie in and pull up to 6995' CCL (7000' top shot). RIH. Drop down to 7030'. Open well. Tie in and pull up to 6965' CCL (6970' top shot). Perforate from 6970' to 7000' rkb. 1628 SI well and POOH. All shots fired. 1700 RDMO. ;Summary: Tagged fill at 7387' rkb. Logged jewelry up to bottom GLM. Perforated C34 sands from 6970' to 7025' and 7034' to 7048' with Enerjet III V phased gun, RDX cha¥~(~,! ,,. ~ i7 F! 90° phased, 45° off bottom center. All shots fired underballanced. J CHECK THIS. BLOCK IF SUMMARY IS CONTINUED ON BACK Weather l Temp. Chill Fa'ctor Visibility I Wind Vel. ]Signed Report [ 42 °F CLR milesl 2 mphI Anchorage INCOMPLETE COMPLETE ,.7. ~ s tra da STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMK,.,.ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 619' FNL, 796' FEL, Sec 33, T12N, R10E, UM At top of productive interval 443' FNL, 1187' FWL, Sec 34, T12N, R10E, UM At effective depth 393' FNL, 1492' FWL, Sec 34, T12N, At total depth 383' FNL, 1557' FWL, Sec 34~ T12N~ 12. Present well condition summary Total Depth: measured 7 true vertical 6 R10E, UM R10Ep UM 5 61 feet 8 9 2 feet 6. Datum elevation (DF or KI~)//~/' RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-10 9. Permit number/approval number 93-30 10. APl number 50-029-22346 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7 4 4 7 feet true vertical 6799 feet Junk (measured) None Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 4 3 5 2' 9 - 5 / 8" Intermediate Production 74 9 6' 7" Liner Perforation depth: measured 7098'-7124', true vertical 6596'-6617', Cemented Measured depth True vertical depth 200 SX PFC CMT 1 21 ' 1 21 ' 845 SX Perm E & 4394' 4273' 450 SX Class G 210 SX Class G CMT 753 4' 6 8 6 0' RECEIVED SEP 2 8 1993 Alaska 0il & Gas Cons. f~rnmis 7310'-7345' 6687'-6715' Tubing (size, grade, and measured depth) 4", 11#, J-55 @ 3932' & 3.5", 9.3#, J-55 @ 6894' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 6858'; SSSV: Camco TRDP-4A-RO %~ 1792' 13. Stimulation or cement squeeze summary Perforated 26' of C1 Sands @ 6 spf on 9/6/93. Intervals treated (measured) 7098'-7124' Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or In!ection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subseguent to operation 2 5 0 3 5 1 90O 200 2 0 0 0 2 2 0 0 1 950 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector m Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FSi ned Title Senior Engineer Fnrm 1 ~3-4134 R~.v tlR/1 ~/RR RI IRMIT IN 1311Pl I(';,ATI:: ;ion ARCO Alaska, Inc.. Subsidiary of Atlantic Richfield Company WELL CONTRACTOR Sc k I~., 10,,~ er - :TOP, ~,~ REMARKS . T'P' 1550 PBDT 7447 ~=344~ FIELD- DISTRICT - STATE OPERATION AT REPORT TiME WELL SERVICE REPORT I DA~'S I DATE I ce. /~ co e%4 Cos4' * 46o~'. 0700 O~lS IO30 0~r ?~g,,-~;0~ : zro'. /~ of' s'4~;? 3~ RECEIVED s E P 2 8 199~ Alaska Oil & Gas Cons. uommission Anchorage r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ] Temp. Chill Factor I Visibility I Wind Vel. Signed °F °FI miles knots ~_'. ~J STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMIb,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing __ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 619' FNL, 796' FEL, Sec. 33, T12N, R10E, UM 8. Well number 1H-10 feet At top of productive interval 443' FNL, 1187' FWL, Sec. 34, T12N, At effective depth 393' FNL, 1492' FWL, Sec. 34, T12N, At total depth 383' FNL, 1557' FWL, Sec. 34, T12N, 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 21 ' Surface 4 3 5 2' Intermediate Production 74 9 6' Liner Perforation depth: measured 7310'-7345' true vertical 6687'-6715' Tubing (size, grade, and measured depth) R10E, UM R10E, UM R10E, UM 75 61 feet 6 8 9 2 feet 9. Permit number/approval number 93-30 10. APl number 50-029- 22346 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None 7447 feet 6 79 9 feet Junk (measured) None Size Cemented 1 6" 200 SX PFC CMT 9-5/8" 845SX Perm E 420 SX Class G 7" 210 SX Class G GMT Measured depth True vertical depth 121' 121' 4394' 4273' 7534' 686O' 4",11#, J-55 @ 3932' & 3.5", 9.3#, J-55 @ 6894' Packers and SSSV (type and measured depth) PKR: Baker 'FB-I' Perm @ 6858'; SSSV: Camco TRDP-4A-RO @ 1792' ;13. Stimulation or cement squeeze summary 14. ~laska 0il & Ga,~; Cons. Cur~rn Fractured "A" Sands on 7/29/93 Anchorage Intervals treated (measured) 7310'-7345' Treatment description including volumes used and final pressure Pumped 22 Mlbs of 16/20 & 83 Mlbs of 12/18 Carbolite ceramic proppant, ftp was 9400 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0- 0- - 0- 50 0- Subsequent to operation 287 39 6 650 200 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. Signed ¢~ ~. ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date ? -Z~ .---~:~ ~' SUBMIT IN DUPLICATE WELL NO' __ (~-I~ AFE: Procedure 'Date- Service Co: _ Annulus Press: _ ~0 ' ~ ~ DATE: Begin Frac- Zone: Test Lines To' Perfs: STAGE _(, i , __ · VOL FLU I D PROP RATE PRESSURE _ ISIP: --- Fluid to Recover: · , _ Sand In Csg: dob Complete' ADC: $ TAlmjk/3100/104 2/27/87 15 Min: _..~',TT_' Avg Press: . ~_'"~o psi FOTt/~/& 5'~ g~ Sand In Zone: ~.o~M '~(~.~~ .. . RECE - -_- _ Rig-$.pervi~~ Anchomgo ARCO Alaska, Inc. Post Office Bu,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 8, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1G-12 Perforate 1H-10 Stimulate 1H-21 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany AR3F~ 600J4 C ARCO Alaska, Inc. Date' August 27, 1993 Transmittal #: 8845 RETURN TO: ARCO Alaska, inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following~ items. receipt and return one signed copy of this transmittal. Please acknowledge q ~-- Ii~o 1H-17 ~i'~--1~ 1H-16 ¢f2.~1%~i 1H-20 Receipt Acknowledged: -~' CDR Enhancement LWD/Depth Corrected -"'CDR Very Enhanced LWD/Depth Corrected ~CDR Very Enhanced LWD/Depth Corrected ~ CDR Enhancement LWD/Depth Corrected -~ CDR Enhancement LWD/Depth Corrected ~ CDR Enhancement LWD/Depth Corrected -~CDR Enhancement LWD/Depth Corrected ..-. CDR Enhancement LWD/Depth Corrected --' CDR Enhancement LWD/Depth Corrected DISTRIBUTION' D&M 2-27-93 2-26-93 5-02-93 1-21-93 1-12-93 3-26-93 4-05-93 4-12-93 4-14-93 Drilling Date: 9678-10337 7848-8422 7O52-7320 9568-9802 8398-8993 7988-8632 4392-7512 5960-9772 5296-10002 Catherine Worley(Geology) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMioolON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well O~L I-~ GAS I---I SUSPENDED F-I ABANDONED [] SERWCE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-30 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22346 J 4 Location of well at surface ,~ 9 Unit or Lease Name vV r , ........ , ! KUPARUK RIVER 619' FNL, 796' FEL, SEC 33, T 12N, R 10E, UM C0~V~p~'¢:~i~'-i~'~~ AtTop Producinglnterval ' AT~-~'""'~ ;:~ 10 Well Number 443' FNL, 1187' FWL, SEC 34, T 12N, R 10E, UM I~.~~~ ~ !-:'?-.~.-"~ 1H-lO At Total Depth~ l V*~P,~FJ~.~ !i .::' .:'! ~Z~/ 11 Field and Pool 383' FNL, 1557' FWL, SEC 34, T 12N, R 10E, UM i ~'~--~-~._ ~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 96', PAD 54' GLI ADL 25639 ALK 464 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 28-Feb-93 04-Mar-93 06/17/93 (COMP)I NA feet MSLI 1 1, Total Depth (MD+TVD) 18 ,lug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thickness of permafrost I I 7561' MD, 6892' TVD 7447' MD, 6799' TVD YES IXJ NO bi 1792' feet MD 1600' APPROX 22 Type Electric or Other Logs Run CDN, CDR, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD :CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 36¢ J-55 SURF 4394' 12.25" 845 SX PERM E, 420 SX CLASS G 7" 26¢ J-55 SURF 7535' 8.5" 210 SX CLASS G CMT 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) 4"/3.5" 11#/9.3# J-55 3932'/6894' 6858' 7310'-7345' W/4-1/2" CSG GUN 4 SPF MD' 6687'-6715' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ,J U L ~ 2 !99~5 Alaska, Oi! & Gas Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 691 2' 6362' BASE OF KUPARUK C 7122' 6534' TOP OF KUPARUK A 7288' 6669' BASE OF KUPARUK A 7424' 6780' ', _?- 31. LIST OF A-I-I'ACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEYS i32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~/¢//~~~ Title ~/~¢'~ /~/'~' ~ '---~ DATE / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 ALASKA INC. DAILY OPERATION PAGE' 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: iH-10 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 25639 464 50-029-22346 93-30 ACCEPT: 02/27/93 05:30 SPUD: 02/28/93 01:00 RELEASE: 06/17/93 03:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 02/28/93 (1) PARKER 245 TD: 759'( o) 03/01/93 (2) PARKER 245 TD: 3717' (2958) 03/02/93 ( 3) PARKER 245 TD: 4414' ( 697) o) DRILLING MW: 9.2 VIS: 79 03/03/93 (4) PARKER 245 TD- 4414'( MOVE RIG F/1H-09 TO 1H-10. ACCEPT RIG @ 17:30 HRS 02/27/93. NU DIVERTER SYSTEM. FUNCTION TEST DIVERTER, CHANGE OUT 30ILSAVER CON & FILL STACK, CHECK FOR LEAKS, CLOSING TIME 40 SECONDS. CUT 90' DRLG LINE. PU BHA, ORIENT MWD, CLEAN OUT CONDUCTOR F/80' TO 121'. SPUD @ 01:00 HRS 02/28/93. DRILL & SURVEY TO 759' TRIP FOR BIT #2 MW:10.5 VIS: 55 DRILL & MWD LOG TO 2032'. CIRC OUT GAS CUT MUD. CONTROL DRILL TO 2145' DRILL TO 2218' CIRC OUT GAS CUT MUD @ 2218' DRILL & MWD SURVEY, SLIDE AS-NECCESSARY TO BUILD ANGLE & CONTROL DIRECTION. PMP SLUG. POH FOR BIT #2, HOLE TRYING TO SWAB ALL THE WAY. CIRC & RECIP 9-5/8" CSG 9-5/8"@ 4394' MW:10.7 VIS: 50 FIN RIH W/BIT #2. CIRC OUT GAS CUT MUD, CUT TO 9.3 PPG. DRILL & MWD LOG TO 4414' CIRC & COND HOLE FOR 9-5/8" CSG. DROP SURVEY, PMP SLUG. POH. LD BHA FOR INSPECTION. RIG TO RUN 9-5/8" CSG, HOLD SAFETY MEETING W/TOOLPUSHER & CO. MAN. RUN 109 JTS 9-5/8" 36# J-55 CSG, SHOE @ 4394' & FC @ 4314'. PU LANDING JT, MU HGR, INSTALL CMT HEAD & RECIP CSG. LD BHA 9-5/8"@ 4394' MW: 9.7 VIS: 34 CIRC & COND MUD WHILE RECIP CSG. PMP 510 BBLS. TEST LINES TO 3000 PSI. HALLIBURTON CMT'D 9-5/8" W/SHOE @ 4394' & COLLAR @ 4314' PMP 20 BBLS WATER, 845 S× PF "E" LEAD, 420 SX PREM "G" TAIL W/ADDITIVES. DISPLACED W/20 BBLS WATER & 314 BBLS MUD. CIRC 142 BBLS GOOD CMT TO SURF-ii.8 PPG. PLUG DOWN & J. C. @ 11:15 AM. PLUG DID NOT BMP. FLOATS HELD. LD CMT HEAD, CSG TOOLS, LANDING JT. WASH OUT STACK. ND DIVERTER. CLEAN & INSTALL 9-5/8" PACKOFF. SCREW ON SPEED HEAD. TORQUE TO 20,000 FT LBS. NU BOP. 39.45' F/RT TO BRADEN HEAD. RU TEST EQUIP. TEST BOP TO 300 & 3000 PSI. AOGCC DOUG AMOS-WAIVED WITNESSING TEST. INSTALL WEAR BUSHING. PU BHA, ORIENT TOOLS, PROGRAM LWD, INSTALL RA SOURCE. SERV RIG. -RIH. TAGGED UP @ 4294' C/O TO FC @ 4314'. CIRC FOR CSG TEST. PRESS UP ON CSG TO 2000 PSI. LEAKED OFF TO 1700 PSI IN 15 MIN. CHECKED SURF EQUIP. PRESS UP ON CSG TO 2000 PSI. LEAKED OFF TO 1300 PSI IN 20 MIN. POOH FOR PKR. LD BHA. WELL: 1H-10 API: 50-029-22346 PERMIT: 93-30 PAGE: 2 03/04/93 ( 5) PARKER 245 TD: 6850' (2436) 03/05/93 (6) PARKER 245 TD: 7561' ( 711) 03/06/93 ( 7) PARKER 245 TD: 7561'( 0) 06/16/93 ( 8) TD: 7561 PB: 7447 DRILLING 9-5/8"@ 4394' MW: 9.6 VIS: 37 PU 9-5/8" PKR & RIH. SET PKR @ 4261'. TEST 9-5/8" CSG F/4261'-SURF TO 2000 PSI FOR 30 MIN. HELD. PRESS DP TO 2000 PSI. LEAKED OFF 175 PSI IN 10 MIN. RELEASED PKR. POOH. LD PKR. PU BHA. ORIENT TOOLS, PROGRAM LWD TOOLS, INSTALL RA SOURCE, TEST MWD @ HWDP. RIH. CUT 96' DRLG LINE. SERVICE RIG & TOP DRIVE. RIH W/2 STDS, FILL DP, DRLG PLUGS & FC @ 4314', C/O GREEN CMT OUT OF SHOE JTS, DRLG FS @ 4394' & NEW HOLE TO 4424' CIRC OUT SOME SOFT CMT. COND MUD FOR EMW TEST. RAN EMW TEST. SHUT WELL IN & PRESS CSG TO 690 PSI W/9.4 PPG MUD, TVD 4273', EMW= 12.5 PPG, HELD. DRLG 8.5" HOLE F/4424'-6850'. MUD WT=10.1 PPG @ 06:00 HRS. ADT 9.0 HRS. RUNNING 7" CSG 9-5/8"@ 4394' MW:10.1 VIS: 40 DRLG 8.5" HOLE F/6850'-7290'. SERV RIG. DRLG 8.5" HOLE F/7290'-7561' CBU FOR SHORT TRIP. MADE 34 STD SHORT TRIP TO SHOE. TIGHT SPOT F/7280'-7300'. RIH. CIRC & COND HOLE FOR CSG. POOH W/DP. REMOVE RA SOURCE, DOWN LOAD LWD TOOLS & LD BHA. PULLED WEAR BUSHING. RU CASERS. HOLD SAFETY MEETING. RUNNING 7" CSG AS PER WELL PLAN. RIG RELEASED 7"@ 7535' MW:10.1 VIS: 0 RUN 7" CSG. CBU @ 9-5/8" SHOE. FIN RIH W/7" CSG. BREAK CIRC @ 5978' MU CMT HEAD. CIRC & COND HOLE & MUD-RECIP CSG. MIX CMT. TEST LINES TO 4000 PSI. SET & CMT'D 7" CSG W/SHOE @ 7535' & FC & 7447' HOWCO CMT'D W/20 BBLS PRE-FLUSH, 50 BBLS SPACER, & 210 SX CLASS "G" W/ADDIVTIVES. DISPLACED W/284 BBLS 10.1 BRINE. RECIP CSG W/FULL RETURNS THROUGH OUT JOB. PLUG DOWN & J. C. @ 1415 PM. TEST CSG TO 3500 PSI FOR 30 MIN. HELD. FLOATS HELD. PU BOP'S. LAND CSG W/155,000% ON SLIPS. CUT OFF 7" SET OUT BOP'S. NU 11"-3000 X 7-1/16-5000 TBG HEAD. TEST TO 3000 PSI FOR 15 MIN. HELD. FREEZE PROTECT 9-5/8" X 7" ANN W/100 BBLS WATER & 70 BBLS DIESEL-2-3 BPM @ 800-1300 PSI. RELEASED RIG @ 2100 HRS 03/05/93. RIH TO PERF A SANDS 7"@ 7535' MW:10.1 NaC1/Br MOVE RIG F/1H-19 TO IH-10. ND TREE. NU 7-1/16" 5000 PSI BOPE. FUNCTION TEST BOPE & FLANGES TO 3000 PSI. RU SCHLUMBERGER WL & MU %1 GUN RUN. ACCEPT RIG @ 0330 HRS 06/16/93. J U 1... 2 ~. !9.93 Alaska, Oil & Gas Cons. [.,ummissio' Anchorage WELL: iH-10 API: 50-029-22346 PERMIT: 93-30 PAGE: 3 06/17/93 (10) TD: 7561 PB: 7447 RIG RELEASED 7"@ 7535' MW:10.1 NaC1/Br RIH W/GUN #1. PERF F/7325'-7345' @ 4 SPF, 180 DEG PHASING W/ALTERNATING CHARGES: 21 GM HJ2 (DEEP PENETRATING) UP & 24 GM 43C (BIG HOLE) DOWN, ORIENTED 68 DEG CCW FROM HIGH SIDE OF HOLE. POH. MU GUN #2 & RIH. PERF F/7310'-7325' AS ABOVE. POH. MU 5.95" GAUGE RING & JB ON WL. RIH TO 7400', THEN POH. NO OBSTRUCTIONS OR TIGHT SPOTS ENCOUNTERED. MU BAKER PKR/TAILPIPE ASSY & RIH. SET PKR @ 6857' POH & RD SWS. RU TO RUN TBG. RUN 3-1/2" X 4" SINGL~ COMPLETION. MU CAMCO SSSV. ATTACH CONTROL LINE & TEST TO 5000 PSI. CONT TO RIH W/4" TBG & C-LINE. TAG PKR, SPACE OUT (NO PUPS NEEDED), & MU HGR. TOTAL OF 92 JTS 3-1/2" & 128 JTS 4" TBG. ATTACH C-LINE & TEST TO 5000 PSI F/10 MIN, OK. LAND TBG & RILDS. PRESS ANN & TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI & TEST F/15 MIN. OPEN SSSV. PRESS TBG TO 2500 PSI, HOLD F/15 MIN. PRESS ANN TO 2500 PSI, HOLD 15 MIN. INCREASE TBG PRESS TO 3700 PSI & SHEAR OUT BALL. LD LANDING JT. ND BOPE. NU FMC 4-1/16" TREE. TEST PACKOFF TO 5000 PSI & TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG. RU PMP LINES. OPEN SSSV. REVERSE CIRC 11 BBLS DIESEL DN ANN & BULLHEAD 6 BBLS DIESEL DN TBG @ 1 BPM, 2350 PSI. SHUT IN WELL, SITP=1250 PSI & SICP=O PSI. BLEED PRESS & SET BPV. SECURE WELL, FINAL SITP=0 PSI & SICP=0 PSI. RIG RELEASED @ 0330 HRS 06/17/93. SIGNATURE: d~perintende~ DATE: R[ CEi'VEB I Alaska Oil a Gas Cons. AI]chora~qe SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE ~'~ ONTINUOUS ~ OOL Oil & Gas ~nons' Curn~'!issio~ · . ~,. Company Well Name Field/Location ARCO ALASKA, INC. lit-10 (619' FNL, 796' FEL, SEC 33, T12N, R10E, UN) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 93146 Locjcjed BV: Date/_~//,/O--L~ ...... Computed By: FORMICA SINES · SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC, 1H-10 RECEIVED JUL. 2 Z ~.,9~.~ AJask~ 0ii & Gas Cons. Comrnissiu~ A]~chorage KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 27-MAR-93 ENGINEER' JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION. MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORZZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 83 DEG 54 MIN EAST COMPUTATION DATE' 14-aPr-93 PAGE I ARCO ALASKA, INC. 1H-lO KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAR-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 oo 500 O0 600 oo 700 oo 80O oo 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 oo 599 99 699 99 799 99 899 98 -96 O0 4 O0 104 O0 2O4 O0 304 O0 404 O0 503 99 603 99 703 99 803 98 0 0 N 0 0 E 0 16 N 55 6 E 0 14 N 65 19 E 0 11 N 27 19 E 0 6 N 6O 4O E 0 17 N 64 33 E 0 31 N 45 51E 0 29 N 36 49 E 0 27 N 51 46 E 0 33 N 4O 52 E 0 O0 0 03 0 42 0 71 0 80 I 08 I 74 2 37 2 95 3 67 0 O0 0 65 0 13 0 09 0 14 0 32 0 11 0 18 0 O0 0 23 0 oo N 0 02 S 0 19 N 044 N 0 68 N 0 81N 121N I 91N 2 47 N 3 04 N 0 O0 E 0 03 E 0 41E 0 66 E 0 73 E I O0 E I 62 E 2 18 E 2 71E 3 36 E 0 O0 N 0 0 E O4 S 53 5O E 45 N 65 9 E 80 N 56 25 E O0 N 46 56 E 29 N 50 55 E O2 N 53 9 E 90 N 48 53 E 66 N 47 38 E 54 N 47 51E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 98 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1899 903 98 98 1003 98 97 1103 97 97 1203 97 97 1303 97 97 1403 97 97 1503 97 96 1603 96 95 1703 95 94 1803 94 0 23 N 30 31E 0 24 N 36 22 E 0 21 N 12 6 E 0 11 N 7 53 W 0 10 N 44 0 W 0 25 S 89 8 W 0 36 S 68 43 W 0 41 S 54 49 W 0 43 S 48 44 W 0 54 S 42 42 W 4 19 4 62 4 97 5 06 5 01 4 56 3 68 2 63 I 61 0 46 0 27 0 24 0 04 0 15 0 23 0 41 0 15 0 24 0 O9 0 28 3 74 N 4 25 N 4 87 N 5 35 N 5 60 N 5 75 N 5 56 N 5 03 N 4 17 N 3 24 N 3 81E 4 19 E 4 48 E 4 52 E 4 44 E 3 97 E 3 11E 2 11E 1 17 E 0 ~1E 5 34 N 45 31E 97 N 44 36 E 62 N 42 36 E O0 N 40 12 E 15 N 38 24 E 99 N 34 38 E 37 N 29 13 E 45 N 22 43 E 33 N 15 43 E 24 N 2 0 E 2000 O0 1999 93 1903 93 2100 2200 2300 24OO 2500 2600 2700 2800 2900 O0 2099 O0 2199 O0 2299 O0 2399 O0 2499 O0 2599 O0 2699 O0 2798 O0 2897 92 2003 90 2103 89 2203 84 2303 72 2403 53 2503 21 2603 79 2702 92 2801 92 90 89 84 72 53 21 79 92 0 52 S 36 55 W 0 58 S 42 7 W I 2 S 32 46 W I 10 S 46 49 E 2 9 S 86 29 E 3 16 N 87 47 E 4 3 N 85 59 E 4 48 N 86 49 E 6 16 N 87 23 E 9 6 N 88 34 E -0 60 -1 75 -2 97 -3 31 -0 41 4 49 10 54 18 55 27 67 40 70 0 19 0 59 0 21 3 17 I O8 0 24 I 89 0 14 2 68 4 43 2 03 N 0 91N 0 58S 2 O1 S 2 71 S 2 77 S 244 S 196 S 147 S 103 S 0 82 W 1 86 W 2 92 W 3 12 W 0 12 W 4 81 E 10 86 E 18 87 E 27 98 E 41 04 E 2 19 N 21 55 W 2 2 3 2 5 11 18 28 41 07 N 63 52 W 98 S 78 46 W 71 S 57 7 W 71 S 2 30 W 56 S 60 2 E 13 S 77 20 E 97 S 84 4 E 02 S 87 o E 05 S 88 34 E 3000 O0 2996 21 2900 21 11 16 3100 3200 3300 3400 3500 3600 3700 3800 O0 3094 O0 3192 O0 3289 O0 3385 O0 3481 O0 3575 O0 3669 O0 3761 3900 O0 3852 30 2998 19 3096 37 3193 65 3289 14 3385 61 3479 19 3573 64 3665 02 3756 30 11 12 19 12 43 37 14 43 65 16 23 14 18 9 61 19 59 19 21 12 64 24 6 02 26 24 N 86 13 E N 86 37 E N 86 46 E N 88 25 E N 86 5 E N 83 53 E N 84 32 E N 85 0 E N 86 2 E N 85 44 E 59 04 78 50 98 89 122 38 149 32 179 03 211 8O 247 04 285 10 327 85 0.26 O. 52 I .43 I .93 I .29 I .92 I 30 1 .39 4 62 2 92 0 18 S 1 2 3 4 7 10 13 16 19 59 4O E 05 N 78 21N 99 22 N 122 52 N 149 29 N 179 53 N 211 73 N 246 61N 284 61N 327 59 40 S 89 50 E 84 E 78 21E 99 73 E 122 69 E 149 27 E 179 88 E 212 98 E 247 94 E 285 62 E 328 84 N 89 14 E 24 N 88 43 E 77 N 88 3O E 76 N 88 16 E 42 N 87 40 E 14 N 87 9 E 36 N 86 49 E 43 N 86 40 E 21 N 86 34 E COMPUTATZON DATE' 14-APR-93 PAGE 2 ARCO ALASKA, INC. 1H-10 KUPARUK RIVER NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY- 27-MAR-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 4000 O0 3940 39 3844 39 29 22 40 3930 54 4014 05 4098 O0 4182 63 4266 50 4351 13 4435 21 4518 26 4601 N 85 19 E 40 31 52 N 86 11E 54 33 21 N 85 59 E 05 33 10 N 85 53 E O0 32 3O N 86 6 E 63 32 2 N 85 11E 50 32 5 N 84 44 E 13 33 5O N 85 2 E 21 33 49 N 84 43 E 26 33 53 N 84 37 E FEET DEG/IO0 FEET FEET FEET DEG MIN O0 4026 O0 4110 O0 4194 O0 4278 O0 4362 O0 4447 O0 4531 O0 4614 O0 4697 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 O0 4780 24 4684.24 33 59 19 4767 19 33 56 11 4850 91 4932 51 5015 91 5097 14 5180 58 5262 51 5345 75 5428 11 34 1 91 34 13 51 34 26 91 34 37 14 34 40 58 34 13 51 33 45 75 33 39 374 62 425 59 479 58 534 55 588 85 642 09 694 98 749 78 805.43 861.13 916.93 972 78 66 74 09 75 65 23 10 52 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4863 O0 4946 O0 5028 O0 5111 O0 5193 O0 5276 O0 5358 O0 5441 O0 5524 6000 O0 5607 94 5511 94 33 45 15 5595 62 5678 17 5762 61 5845 29 5928 83 6010 36 6093 55 6175 65 6256 15 33 34 62 33 20 17 33 21 61 33 51 29 34 21 83 34 22 36 34 22 55 35 33 65 35 39 N 84 38 E N 84 40 E N 84 47 E 1028 N 84 44 E 1084 N 84 44 E 1141 N 84 53 E 1197 N 85 1E 1254 N 84 48 E 1311 N 84 39 E 1367 N 84 46 E 1422 N 84 44 E 1478 O0 47 54 47 59 84 28 74 69 13 6100 6200 6300 6400 6500 6600 670O 6800 6900 N 84 44 E 1533 N 84 45 E 1588 N 84 50 E 1643 N 84 3 E 1698 N 83 11E 1754 N 83 5 E 1811 N 82 53 E 1867 N 81 51 E 1924 N 81 17 E 1983 O0 5691 O0 5774 O0 5858 O0 5941 O0 6024 O0 6106 O0 6189 O0 6271 O0 6352 7000 O0 6434 14 6338.14 35 18 7100 O0 6515 67 6419.67 35 30 7200 O0 6597 07 6501.07 35 30 7300 O0 6678 53 6582.53 35 19 7400 O0 6760 31 6664.31 35 1 7500 O0 6842 21 6746 21 35 1 7561 O0 6892 17 6796 17 35 1 N 81 15 E 2041 04 N 80 49 E 2098 86 N 80 48 E 2156 87 N 80 42 E 2214 78 N 80 21 E 2272 25 N 80 21 E 2329 52 N 80 21 E 2364 46 3.29 2 41 0 70 0 63 1 55 0 8O 2 O9 0 54 0 O6 0 17 23 46 N 374 24 E 374 98 N 86 25 E 27 30 34 38 42 47 52 57 62 20 N 425 78 N 479 75 N 533 59 N 588 53 N 641 30 N 693 07 N 748 09 N 803 25 N 859 11E 425 O2 E 48O 88 E 535 08 E 589 20 E 642 88 E 695 49 E 75O 91E 805 38 E 861 98 N 86 20 E O1 N 86 19 E O1 N 86 17 E 35 N 86 15 E 61 N 86 12 E 49 N 86 6 E 30 N 86 1E 94 N 85 56 E 63 N 85 51E 0 28 0 02 0 28 0 28 0 49 0 29 0 28 0 56 0 41 0 33 67 52 N 914 94 E 917 42 N 85 47 E 72 77 82 88 93 98 103 108 113 73 N 970 89 N 1026 98 N 1082 17 N 1138 27 N 1194 28 N 1251 27 N 1307 40 N 1363 54 N 1418.49 E 1423 55 E 973 27 N 85 43 E 20 E 1029 15 N 85 40 E 05 E 1085 22 N 85 37 E 17 E 1141 58 N 85 34 E 60 E 1198 24 N 85 32 E 29 E 1255 14 N 85 31E 66 E 1311 74 N 85 29 E 30 E 1367 60 N 85 27 E 02 N 85 25 E 0 oo 0 46 0 o8 0 o6 2 29 0 0 0 2 0 02 16 3O 57 55 118 65 N 1473 74 E 1478 51 N 85 24 E 123 128 133 138 145 152 158 166 175 73 N 1528 79 N 1583 77 N 1638 94 N 1693 34 N 1749 08 N 1805 94 N 1861 29 N 1917 06 N 1975 98 E 1533 97 N 85 22 E 82 E 1589 53 E 1643 41E 1699 30 E 1755 35 E 1811 39 E 1868 88 E 1925 72 E 1983 04 N 85 21E 98 N 85 20 E 10 N 85 19 E 32 N 85 15 E 74 N 85 11E 16 N 85 7 E 07 N 85 3 E 46 N 84 56 E 0.42 O. 30 0.31 O. 44 O. O0 0 O0 0 O0 183 78 N 2033 02 E 2041 31 N 84 50 E 192 84 N 2090 21E 2099 08 N 84 44 E 202 13 N 2147 55 E 2157 04 N 84 37 E 211 42 N 2204 80 E 2214 91 N 84 31 E 220 98 N 2261 57 E 2272 34 N 84 25 E 230 61 N 2318 14 E 2329 58 N 84 19 E 236 48 N 2352 65 E 2364 50 N 84 16 E ARCO ALASKA, INC. 1H-lO KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 14-aPr-93 PAGE 3 DATE OF SURVEY: 27-MAR-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 7561 0 O0 -96 O0 0 0 O0 999 98 903 98 0 23 O0 1999 93 1903 93 0 52 O0 2996 21 2900 21 11 16 O0 3940 39 3844 39 29 22 O0 4780 24 4684 24 33 59 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET PEG/lO0 FEET FEET FEET DEG MIN N 0 0 E N 3O 31 e 4 S 36 55 W -0 N 86 13 E 59 N 85 19 E 374 N 84 38 E 916 N 84 44 E 1478 N 81 15 E 2041 N 80 21 E 2364 O0 5607 O0 6434 O0 6892 94 5511 14 6338 17 6796 94 33 45 14 35 18 17 35 1 0 O0 19 60 04 62 93 O0 04 46 0 O0 0 27 0 19 0 26 3 29 0 28 0 O0 0 42 0 O0 0 O0 N 3 2 0 23 67 118 183 236 0 O0 E 74 N 3 03 N 0 18 S 59 46 N 374 52 N 914 65 N 1473 78 N 2033 48 N 2352 000 N 0 0 E 81E 5 82 W 2 40 E 59 24 E 374 94 E 917 74 E 1478 02 E 2041 65 E 2364 34 N 45 31E 19 N 21 55 W 40 S 89 50 E 98 N 86 25 E 42 N 85 47 E 51 N 85 24 E 31 N 84 5O E 5O N 84 16 E Gas .r,'ons. C'or~imissio~. COMPUTATZON DATE' 14-APR-93 PAGE 4 ARCO ALASKA, INC. 1H-10 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAR-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 01 696 01 796 01 896 02 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 O0 696 O0 796 O0 896 O0 -96 O0 0 O0 100 O0 200 O0 300 O0 400 O0 5OO O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 16 N 60 46 E 0 14 N 67 41E 0 11 N 29 21E 0 6 N 54 12 E 0 16 N 63 55 E 0 31 N 46 31E 0 30 N 36 43 E 027 N 51 21E 0 32 N 41 37 E 0 O0 0 O1 0 41 0 70 0 79 1 1 2 2 3 06 71 35 93 64 O. O0 0 85 0 21 0 02 0 22 0 27 0 14 0 11 0 O0 0 23 0 O0 N 0 03 S 0 18 N 0 43 N 0 68 N 0 80 N I 19 N 188 N 2 45 N 3 02 N 0 O0 E 0 01 E 0 39 E 0 66 E 0 72 E 0 98 E 159 E 2 16 E 2 68 E 3 34 E 0 O0 N 0 0 E 03 S 24 12 E 43 N 65 10 E 78 N 56 53 E 99 N 46 55 E 27 N 50 43 E 98 N 53 17 E 86 N 49 I E 63 N 47 37 E 50 N 47 53 E 996 02 1096 1196 1296 1396 1496 1596 1696 1796 1896 996 O0 02 1096 03 1196 03 1296 03 1396 03 1496 03 1596 04 1696 05 1796 06 1896 900.00 O0 1000 O0 O0 1100 O0 O0 1200 O0 O0 1300 O0 O0 1400 O0 O0 1500 O0 O0 1600 O0 O0 1700 O0 O0 1800 O0 0 24 N 29 39 E 0 23 N 36 38 E 0 22 N 13 I E 0 11 N 7 13 W 0 9 N 42 15 W 0 25 N 89 29 W 0 36 S 69 15 W 0 41 S 55 42 W 0 43 S 47 53 W 0 54 S 43 26 W 4 17 4 60 4 96 5 06 5 O2 4 59 3 72 2 67 1 65 0 5O 0 19 0 22 0 O8 0 14 0 19 0 40 0 16 0 23 0 17 0 3O 3 72 N 4 23 N 4 85 N 5 34 N 5 59 N 5 75 N 5 58 N 5 06 N 4 20 N 3 28 N 3 80 E 4 17 E 4 47 E 4 52 E 4 45 E 4 O0 E 3 15 E 2 15 E 1 21E 0 15 E 5 31 N 45 36 E 94 N 44 38 E 60 N 42 42 E 99 N 40 16 E 14 N 38 30 E O1 N 34 50 E 40 N 29 28 E 49 N 22 59 E 37 N 16 4 E 28 N 2 42 E 1996.07 1996 O0 1900 O0 2096.08 2096 2196.10 2196 2296.11 2296 2396.16 2396 2496.28 2496 2596.46 2596 2696.78 2696 2797.20 2796 2898.05 2896 O0 2000 O0 O0 2100 O0 O0 2200 O0 O0 2300 O0 O0 2400 O0 O0 2500 O0 O0 .2600 O0 O0 2700 O0 O0 2800 O0 0 52 S 36 23 W 0 57 S 42 35 W 1 3 S 33 5 W 1 6 S 41 26 E 2 7 S 86 12 E 3 16 N 87 57 E 3 59 N 86 4 E 4 48 N 86 49 E 6 12 N 87 20 E 9 1 N 88 34 E -0 56 -1 70 -2 93 -3 36 -0 54 4 28 10 30 18 28 27 37 40 39 0 13 0 53 0 21 3 14 0 99 0 25 1 90 0 13 2 91 4.42 2.08 N 0.96 N 0.52 S 1.96 S 2.70 S 2.78 S 2.46 S 1.98 S 1.48 S 1.04 S 0 78 W 1 81 W 2 89 W 3 17 W 0 26 W 4 60 E 10 62 E 18 60 E 27 68 E 40 73 E 2 22 N 20 37 W 2 2 3 2 5 10 18 27 40 05 N 62 9 W 93 S 79 45 W 73 S 58 13 W 71 S 5 29 W 38 S 58 50 E 90 S 76 58 E 70 S 83 56 E 72 S 86 56 E 75 S 88 32 E 2999 78 2996 O0 2900 O0 11 16 3101 3203 3306 3410 3515 3621 3728 3837 3949 74 3096 91 3196 85 3296 79 3396 66 3496 72 3596 81 3696 82 3796 O0 3000 O0 11 12 O0 3100 O0 12 46 O0 3200 O0 14 51 O0 3300 O0 16 33 O0 3400 O0 18 28 O0 3500 O0 20 17 O0 3600 O0 21 44 O0 3700.00 25 7 41 3896.00 3800.00 27 53 N 86 13 E N 86 37 E N 86 46 E N 88 22 E N 85 48 E N 84 I E N 84 37 E N 85 25 E N 86 I E N 8S 7 E 59 O0 78 84 99 75 124 11 152 38 183 94 219 28 257 56 300 89 350 37 0 26 0 56 1 46 1 96 1 91 2 20 1.52 2,40 1 . 87 2.69 0 18 S 1 2 3 4 7 11 14 17 21 59 36 E 07 N 79 26 N 100 27 N 124 73 N 152 81 N 184 24 N 219 61N 257 70 N 300 42 N 350 59 36 S 89 50 E 17 E 79 07 E 100 47 E 124 74 E 152 16 E 184 32 E 219 47 E 257 71E 301 08 E 350 18 N 89 13 10 N 88 42 51 N 88 30 82 N 88 13 32 N 87 34 61 N 87 4 88 N 86 45 23 N 86 38 73 N 86 30 COMPUTATION DATE' 14-APR-93 PAGE ARCO ALASKA, INC. 1H-10 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAR-93 KFILY BUSHING ELEVATION' 96.00 FT ENGINEER' JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4064 38 3996 O0 3900.00 31 2 4182 4302 4421 4539 4657 4778 4898 5019 5139 63 4096 33 4196 32 4296 34 4396 76 4496 08 4596 48 4696 01 4796 55 4896 O0 4000.00 33 11 O0 4100.00 33 9 O0 4200.00 32 14 O0 4300.00 31 55 O0 4400.00 33 35 O0 4500.00 33 49 O0 4600.00 33 53 O0 4700.00 33 59 O0 4800.00 33 58 N 85 55 E N 86 5 E N 85 53 E N 86 5 E N 84 45 E N 85 8 E N 84 45 E N 84 37 E N 84 39 E N 84 41E 407 02 470 07 535 82 600 27 662 92 726 33 793 23 860 28 927 55 994 87 2 26 I 10 0 6O I 05 0 46 1 56 0 O0 0 18 0 35 0 15 25 92 N 406 57 E 407 40 N 86 21 30 34 39 44 5O 62 68 74 13 N 469 84 N 535 37 N 599 35 N 661 06 N 725 97 N 791 17 N 858 52 N 925 78 N 992 53 E 47O 15 E 536 48 E 600 96 E 663 12 E 726 76 E 793 54 E 860 51E 928 54 E 995 49 N 86 20 28 N 86 17 78 N 86 15 44 N 86 10 85 N 86 3 74 N 85 57 79 N 85 51 05 N 85 46 35 N 85 41 5260 23 4996 O0 4900.00 34 8 5381 5502 5624 5745 5865 5985 6105 6225 6345 21 5096 54 5196 14 5296 19 5396 46 5496 64 5596 82 5696 59 5796 28 5896 O0 5000 O0 34 22 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 34 38 O0 34 36 O0 33 58 O0 33 38 O0 33 45 O0 33 32 O0 33 19 O0 33 20 N 84 47 E 1062.40 N 84 43 E 1130.48 N 84 53 E 1199.19 N 85 0 E 1268 37 N 84 44 E 1336 56 N 84 42 E 1403 39 N 84 43 E 1470 03 N 84 44 E 1536 68 N 84 46 E 1602 60 N 84 46 E 1668 36 0 18 0 36 0 25 0 35 0 51 0 36 0 O0 0 45 0 12 0 23 80 94 N 1059 80 E 1062 89 N 85 38 e 87 93 99 105 111 117 124 130 136 19 N 1127 40 N 1196 48 N 1264 58 N 1332 78 N 1399 91N 1465 03 N 1532 08 N 1597 02 N 1663 60 E 1130 04 E 1199 96 E 1268 89 E 1337 43 E 1403 80 E 1470 18 E 1537 82 E 1603 32 E 1668 97 N 85 35 E 68 N 85 32 E 87 N 85 30 E 06 N 85 28 E 89 N 85 26 E 53 N 85 24 E 19 N 85 22 E 11 N 85 21E 88 N 85 19 E 6465.74 5996 O0 5900.00 34 20 6586.89 6096 6708'.04 6196 6830 13 6296 6953 26 6396 7075 85 6496 7198 69 6596 7321 40 6696 7443 58 6796 7561 O0 6892 O0 6000.00 34 22 O0 6100.00 34 22 O0 6200.00 35 56 O0 6300 O0 35 23 O0 6400 O0 35 26 O0 6500 O0 35 30 O0 6600 O0 35 15 O0 67O0 O0 35 1 17 6796 17 35 1 N 83 16 e 1735 51 N 83 6 E 1803 N 82 52 E 1872 N 81 22 E 1942 N 81 25 E 2014 N 80 52 E 2084 N 80 48 E 2156 N 80 32 E 2227 N 80 21E 2297 N 80 21E 2364 88 28 28 04 87 11 12 21 46 0 32 0 23 0 31 0 95 0 48 0 41 0 31 0 66 0 O0 0 O0 143 06 N 1730 10 E 1736 01 N 85 16 E 151 159 168 179 190 202 213 225 236 19 N 1798 50 N 1865 86 N 1935 72 N 2006 62 N 2076 O1N 2146 44 N 2217 18 N 2286 48 N 2352 O0 E 1804 89 E 1872 29 E 1942 30 E 2014 37 E 2085 80 E 2156 O0 E 2227 22 E 2297 65 E 2364 34 N 85 12 E 70 N 85 7 E 65 N 85 1 E 33 N 84 53 E 11 N 84 45 E 28 N 84 37 E 25 N 84 30 E 28 N 84 22 E 5O N 84 16 E '~ ~L.., "0o'3 ,..,,.., 2_ 2 i,_~,.,,.. Aiaska Oil & Gas Cons. Anchorage COMPUTATION DATE: 14-APR-93 PAGE 6 ARCO ALASKA, INC. 1h-lO KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUk A GCT LAST READING BASE KUPARUK A PBTD 7" CASING DATE OF SURVEY KELLY BUSHING ELEVATION 27-MAR-93 96.00 FT ENGINEER JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 619~ FNL ~ 796' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4394 O0 6912 O0 7122 O0 7288 O0 7392 O0 7424 O0 7447 O0 7535 O0 7561 O0 4272 94 6362 40 6533 58 6668 74 6753 77 6779 97 6798 80 6870 88 6892 17 4176 94 6266 40 6437 58 6572 74 6657 77 6683 97 6702 80 6774 88 6796 17 38 37 N 176 13 N 194 89 N 210 30 N 220 22 N 223 29 N 225 51N 233 98 N 236 48 N 584 87 E 1982 63 E 2102 82 E 2197 95 E 2257 O1E 2275 1S E 2288 16 E 2337 94 E 2352 65 E R EC E!V E D .. · ' r"~ :'; Alaska. 0i! & Gas Cons. Comrmss~'-,' Anchorage ARCO ALASKA, INC. 1H-lO KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 14-APR-93 PAGE 7 DATE OF SURVEY: 27-MAR-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY .~**~.~ MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A PBTD SURFACE LOCATION = 619' FNL & 796' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6912 O0 7122 oo 7288 O0 7424 oo 7447 O0 7561 O0 6362 40 6533 58 6668 74 6779 97 6798 80 6892 17 6266 4O 6437 58 6572 74 6683 97 6702 80 6796 17 176 13 N 194 89 N 210 30 N 223 29 N 225 51N 236 48 N 1982 63 E 2102 82 E 2197 95 E 2275 15 E 2288 16 E 2352 65 E FINAL WELL LOCATION AT TO: -r~UE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7561.00 6892.17 6796.17 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2364.50 N 84 16 E Gas r3o,qs. Oonirnissi~, Ancho:'age DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL I H-10 COUNTRY USA RUN ONE DATE LOGGED 27 - MAR - 93 DEPTH UNIT FEET REFERENCE 931 46 ....... All inte~-pretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall r~ot. except tn the case of gross or wiff[~ll negligence on our part, be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees These Interpretations are also subject to our General Ten'ns and Conditions as set out In our current price Schedule HELL' 11-1-10 (619' FNL, 796' FEL, SEC 33, T12N, RIOE, UR) HORIZONTAL PROJECTION NORTH 2000 REF 93148 15O0 1 o00 - . 50O -500 -1000 - 1500 SOUTH -2000 -1000 WEST SCALE = I 500 INIFT -500 0 500 1000 1500 20OO 25OO ECEIV .D j U i.. ~ ?. ~993 Alaska Oil & Gas Cons. Anchoraga 3000 EAST WELL- 111-10 (619' FNL, 796' FEL, SEC 33, T12N, RIOE, UR) VERTICAL PROJECTION -1000 -500 0 0 500 1000 1500 2000 2500 i · PROJECTION ON VERT1CAL PLANE 264.00 84.00 : 30O0 84 00 SCALED IN VERTICAL DEPTHS SCALE ~ 1 / 500 ECEIVED Alaska OiJ & Gas Cons. Corm'nissio~ Anchoraga ARCO Alaska, Inc. / Date: June 04, 1993 Transmittal #: 8¢55 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 'Anchorage, AK · 99510-0360 Transmitted below are the following ~ items. receipt and return one signed Copy of ~.~--s-tra-~smittal. CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected HLD%Corrected CH Density HLDT-Corrected CH Density HLDT-Corrected CH Density Please acknowledge Receipt Acknowledged: DISTRIBUTION: D&M NSK 3/2-5/93 4414-7561 3/2-5/93 4414-7561 3/17-20/93 5317-11 034 3/! 7-20/93 5317-11 034 1/9/93 8000-9336 5/18/93 8030-8682 1/8/93 10448-12014 Drilling State .o f. Alaska(+Sepia) Date · ~/~/~~C~l/' VendorPackage(Johnsto'~,;?¢ ~ ~ Kathy Worley(Geology~~ ARCO Alaska, Inc. Date: May 21, 1993 Transmittal #' 8¢48 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 1H-18~G~'LIS Tape and Listing 02-10-93 0~_.~u_. CDR/CDN in 2 Bit Runs, QRO Processed 1H-1 q: LIS Tape and Listing 03-05-93 _--~t~ CDR/CDN & Enhanced Resistivity 1H-:~ LIS Tape and Listing 03-26-93 oW CDR/CDNLis Tape and & EnhancedListing ResistivitY3_20_93 1 H- 1 ,- ~t~L~2., H.09~.oCr . CDR/CDN & QRO Enhanced Resistivity 1 -~.¢t¢~\ LIS Tape and Listing 02-25-93 CDR/CDN In 1 Bit Run, QRO Processed Receipt Acknowledged' Please acknowledge receipt 93067 93112 93115 93128 93O88 Date' DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: April 23, 1993 Transmittal Cf: 8718 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Sub-Surface Directional 03-26-93 93144 Survey Sub-Surface Directional 03-26-93 93145 Survey Sub-Surface Directional 3-26-93 93146 Survey Receipt Acknowledged: DISTRIBUTION: Date: D&M State of Alaska (2 copies) ARCO AlaSka, Inc. Date: April 08, 1993 Transmittal #: 8708 RETURN TO: ARCO Alaska, inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. :~'~1 H-lO 1H10 ~"~ ./1 H-12 -- -~IH 12 HI~ Receipt Drilling Cement Bond Log Cement Evaluation Log Cement Evaluation Log Cement Bond Log - Cement Evaluation Log Cement Bond Log Acknowledge-~~~_~~. State of Alaska(+sepia) 03-26-93 03-26-93 03-26-93 03-26-93 03-26-93 03-26-93 6050-7410 6050-7430 7800-8909 7800-8889 8200-9552 8200-9532 Date' NSK ALASKA OIL AND GAS CONSERVATION COMMISSION February 18, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Kuparuk River Unit iH-10 ARCO Alaska, Inc. Permit No: 93-30 Sur. Loc. 619'FNL, 796'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 363'FNL, 1598'FEL, Sec. 34, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W.( Chairman BY ORDER OF TRR COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~:,,~ printed on recycled paper STATE OF ~ OIL AND GAS CONSERVA~ COMMI.~.,,.. N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redriil D I b Type of Well Exploratory [1 Stratigraphic Test [] Development Oil X Re-Entry J~ Deepen O Service O Devetopment Gas O Single Zone X Multiple Zone ri 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 619' FNL,796' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval ({~ TARGET ) 8. Well number Number 405' FNL, 1,208' FEL, Sec. 34, T12N, R10E, UM 1H-10 #UG630610 At total depth 9. Approximate spud date Amount 363' FNL~ 1~598' FEL~ Sec. 34~ T12N, R10E, UM 2/1 8/93 $200r000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1H-07 7,644' MD 1598' @ TD feet 73' @ 2200' MD feet 2560 6,935' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AA(;: 25.035(e)(2)) Kickoff depth 2625' feet Maximum hole an.qle 35° Ma~mumsu,ace 2534 asia At total death (TVD} 2900 18. Casing program Selling Depth size Specifications Top Bottom Quantib/of cement Hole Casing Weight Grade Coupling Length IV•) 'I'VD ND 'I'VD (include sta~ie dataI 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25' 9.625' 36.0# J-55 BTC 4,350' 41' 41' 4,391' 4,281' 520 Sx Permafrost E & HF-ERW 420 Sx Class G 8.5' 7' 26.0# J-55 BTCMOE 4,430' 41' 41' 4,471' 4r436' HF-ERW 8.5' 7' 26.0# J-55 BTC 3,1 73' 4,471' 4,436' 7,644' 6,935' 210SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured leet Junk (measured) true vertical feet Casing Length Size Cemented ~ M~ ,a~Qr~jd' cle~th~' '~ ?"~rue Vertical depth Structural i!_../ Conductor Surface Intermediate i::' [-' i-~ ~J ~.~, ~,;~ Production .... ~ ..... 't ~' 0 0, ~ Liner ~ ~ .... . .... ., Perforation depth: measured ~r-IP, h !} !'~ 8 true vertical ....... 20. Attachments Filing fee X Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~ Relraction analysis J-1 Seabed report ~ 20 AAC 25.050 requirements X 21.~ruel h .. and correct to the best of my knowledge Sk:J~~" ~./~,/. ~c~,~/~;:~ Title Area Drillin~ Engineer Date ~.. Commission Use Onl~ I I ISee °v°r le"er'°r Permit~;:~._~ 'Number~o APl50. numbero.~. ~-- ~ ~-- ,~ ~--,-~ Approval dato~r ... / ~ _..-? 3 other rocluiroments Conditions of a.oproval Samplas recluired ~ Yes ~ No Mud Io.cl recluired D Yes ~ No Hydro.clan sulfide measures J--J Yes J~ No Directional survey required ]~ Yes r"J No RequimdworldngpressureforBOPE D 2M ~ 3M D 5M D 1OM D 15M Other: O~,,~g,~,~a~ ~.gne~ ~¥ David ~? .Joi~nst°n ~ ' by order of Approved by Commissioner the commission Date -~ Form 10-401 Rev. 7-24-89 Submit in triplicate I · 1 · 1 · Sm ! · 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1H-10 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,391')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (~7,644') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1H-10 Spud to 9-5/8" surface casing Density PV YP Viscosity 9.0-9.6 15-25 15-35 45-75* Initial Gel 10 Minute Gel APl Filtrate pH % Solids 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drillin(] Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2534 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1H-10 is 1H-07. As designed, the minimum distance between the two wells would be 73' @ 2200' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. Casing Design / Cement Calculations 11 -Feb-93 Well Number: 1H-10 Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Fmc. Pressure 4,391 ft 4,281 ft 4,471 ft 4,346 ft 7,644 ft 6,935 ft 3,658 ft 6,965 ft 6,381 ft 9.8 ppg 3,500 psi Maximum anticipated surface pressure 'I'VD surface shoe = 4,281 ft {(13.5'0.052)-0.11}*TVDshoe =1__~ Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 9.8 ppg 6,381 ft 3,252 psi 3152 psiJ Surface lead: Top West Sak, TMD = 3,658 ft Design lead bottom 500 ft above the Top of West Sak = 3,158 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 989 cf Excess factor = 15% Cement volume required = 1,137 cf Yield for Permafrost Cmt = 2.17 Cement volume required =! 520 sxJ Surface tail: TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume ?~,:( !i~-' !ii ;~'} '':~¥ '/~,~, ii-!~ Cmt required Totalin casingcmt Excess factor ~: ~,~Ji:: ~i 'i ~;~:?~ ~ ~ ~,~ ~ ~ment volume required Yield for Cla~ G cmt . ~,~, ':-'~"~':' .... Cement volume required 4,391 ft 386 cf 80 ft 0.4340 cf/If 35 cf 421 cf 15% 484 cf 1.15 420 sxJ Casing Design ! Cement Calculations 11-Feb-93 Production tail: TMD= 7,644 ft Top of Target, TMD = 6,965 ft Want TOC 5001 above top of target = 6,465 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 206 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 223 cf Excess factor = 15% Cement volume required = 256 cf Yield for Class G cmt = 1.23 Cement volume required =[ 210 sxJ TENSION - Minimum Desian Factors are: T(;)b}=l.5 and T(is}=l.8 __ Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud -- - Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! 564000 lb 4,391 ft 36.00 Ib/ft 158076.0 lb 22921.4 lb 135154.6 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 4,391 ft 36.00 Ib/ft 158076.0 lb 22921.4 lb 135154.6 lb 4.7! Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ff) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 415000 lb 7,6~.~. ft 26.00 Ib/ft 198744.0 lb 29375.2 lb 169368.8 lb Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ff) Buoyancy = Weight of displaced mud !~!~ ~'~'/ii i ~; / "~' Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = ~' ~ !i 'i ~.~,:. Design Factor = 490000 lb 7,644 ft 26.00 Ib/ft 198744.0 lb 29375.2 lb 169368.8 lb 2.9J Casing Design ! Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ BURST- Minimum Deslan Factor -- Surface Casing-' Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Production Cig A: :,~'~;~;n~_~'~.f!~ 1. Design Case - Tubing leak while well is SI Inside pres--Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Design Factor =! Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum De. si_an Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I'VD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000q'VD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =! Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =! Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = EXt. Pres. @ Bottom = Design Factor =[ 11-Feb-93 415000 lb 3,173 ft 26.00 Ib/ft 82498.0 lb 12193.6 lb 70304.4 lb 5.91 490000 lb 3,173 ft 26.00 Ib/ft 82498.0 lb 12193.6 lb 70304.4 lb 7.01 3520 psi 2534.4 psi 1.4] 4980 psi 5715 psi 2011 psi 3703 psi 1.3! 4980 psi 7034 psi 3210 psi 3825 psi 1.3J 2020 psi 0.510 Ib/ft 1246 psi 1.61 4320 psi 0.510 Ib/ft 2215 psi 2.0J 4320 psi 0.510 Ib/ft 3534 psi Casing Design / Cement Calculations 11-Feb-93 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID I blft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi UPARUK RIVER Uhl,- 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5, 1(7' HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 2(7' - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 , 6 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ~ OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4` TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3(x)o PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 1~_ UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' -2000 PSI STARTING HEAD 11' - 3(X)O PSI CASING HEAD 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4, 13-5/8' - 5000 PSI PIPE RAMS 13~/8' -5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES ~ 13~/8' - 5(X)O PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13~/8' -5000 PSI ANNULAR SRE 8/22~ Scole li... '50.00, 5o O ! 1500 2700 ~_~d Sf ,, 2,5O 300 pROPOSED 3~ iO 400 450 I I I I ARCO ALASKA, Inc. Structure : Pad 1H Well: 9 - 10 PROPOSED field : Kuparuk River Unit Location : North Slope, Alaska 4100 100 4700 4.900 5100 5300 ~100 1500 5O0 1{30 50 50 100 150 2O0 250 30O 35O 0 V !H-IOCMT.XLS State: Weli: Field: State Permit i- fi~ifi~i. IH. lO Work Sheet: Ktvpan/k R/vet D ate: $3-,.~ Casir~ Ty. pe Easing Size Casing Length Hole Diamete~ Cement r , Cement- Yield Cement- Cubic ft Cement-Cubic Ct Cement- Sacks Cema- Yield Cement- Cubb f( C~t - Cubic It Cement- Sacks -inches - Feet -Inches ~2 ~2 Cement- Yield Cement- Cubic it Cement- Cubic it :!:13 Cement- Cubic it / Vol Cement- Fill Factor Corrducto~ Sudace 18.£¢J0 9.625 80.000 4,350.000 24.000 12.250 0.01~ 520.000 O. 000 2.170 O. OOO 1,1 28.400 200.000 1 ,I 28.400 0.000 420.000 0.000 1.!50 0.000 483.000 0.000 483.000 0.000 0.000 0.000 0.000 200. O00 1,611. 400 1.432 1.183 Linei 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~.DIV/Oi Casing Type Casi~ Size -Inches Casing ~,~p~- Fee! Hole Diamete~ -inche~ Cement- Sacks Cement-Yieid Cement. - Cubic f~. I~1 Cement- Cubic it Ce~nl - Sack~ Cement- Yield Cemen~ - CuWc Jt Cemen~ - Cubic f~ ~2 Cement - Sacks ~3 Cement-Yield ~3 Cement- Cu~c It~3 Cemen~ - Cu~c fi ~3 Cemen~- Cubic It /Vol Cement-!nteival ft Top of Cement- Fee~ Intermediate 1:I1 intermediate ~I2 0.000 0.000 0.000 0.000 O. OOO 0.000 0.~ 0.00 0.00 0.00 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 .:!:iDIV/O! ~IDIV/O! :i:I;D iV/O! ¢.DIV/O! Production 7.000 7,-6.44.000 8.500 210.00 '! .23 ~_58.00 258.30 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 258.30 2,036.96 5,607.0 ~.,1,;,_,?.u,-~,d E)ep'th CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee ~ (2) Loc ~_'?d_ [2 thru8']~" (3) Admin [,~//__.. .~K/~.~...._~ E9 t~hru 13] [10 & 13] [14 thru 22] (5) BOPE ~-/--~. ~"' P-?~- ~.~.., [23 thru 28] Company Lease & Well 0. A~ 1. Is permit fee attached ............ ; .................................. 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is well bore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed ..................... ; .............. 12. Is lease nLrnber appropriate .......................................... 13. Does well have a unique name & n~nber ................................ YES 4, 14. 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. I s conductor st r ing provided ......................................... /~ NO Is enough cement used to circulate on conductor $ surface ............ Will cement tie in surface ~ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is 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 drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~oor? psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS , / '~'29 thru' 31] (7) Contactp~ ~ [32] (8) Addl ~-:.,, -':.-" geology: engineering' DWJ RAD) rev 12/92 jo/6.011 29. 30. 31. 32'. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data"presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' MERIDIAN' UM % TYPE' Exp~~ Redri I I Inj SM Rev 0 --I -FZ --I (-~ I'Ti m g 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. IS ~a~e Ver!f!.catiot~ ?.,isti. no ch!umberq~r Alaska Co!~,:~tlt!nc~ Center' M-APP-1903 !4:0:~l PAGE: '] 3 1 2N 796 9 6.0 !? 96.0,0 54. O0 I~ ~o, ne Veri.f.!.cation c~lt]mberqe? ~laska Cnm:~t. ir~c, Cent-er !4:03 , ,-- . .. , ...... :, ,, APK. S t-~T'r :F¢ f'FUT 138.q6'" DPlI. T,ED I',',TE,~V[I,, /~,1~4' TO 7561'". PnT.~'CIf.;~:hl_, P,~lt,~< ~r.'iSl~'y F'~OCEaE. I~,,G I~SEi_".. 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TABO. ,~ ,RTCE. PAGE 3.3!4 1. 605 0.009 1.881 1.000 I .5c9,, 4.043 1.592 0.000 1.282 1.000 1.535 4,442 1,096 1.000 1.031 1.000 1.191 5 ,. 0 47 i.824 O, 000 O. 686 -999.250 1.849 3.050 2.168 0.000 0.764 t,.ooo 2,169 5.202 1.553 0'000 0.664 -999.250 1.540 3.747 2.610 0.000 0.742 -999.250 TS Ta~,e Ver.t..f. ication ~..,.!.sti]~(3 chl~mhert~ef AlasKa Comput.f.r,q Center 093 14:03 2.~15 A 'F_.R - - I ...... W f) 2.4~5 34. 97. 6. -099. 2. . 37. Ill. 5. -g99. 121 .... 5: -999. 40 . '999. 2. . 4:5 . 1.33. i ' g 99. 32' '999. 29. 91. 7. 4. 55 D R F! 0. ~.! W L', 425 250 DTCK. 456 3 6 ~ D R Fi ,'.'!. 5 00 R A O 9 ~ ~! S ? 723 mlB 250 DICK 05~ 371. !) !;~ H C:]. i,! w 300 R A. ?~ W B 370 ,t,; 81. :,; '~' D 2 50 D T C K. ~ ,,: 0 415 A. TER. M,w'O 099 327 D R H O. ?~! 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M DEF.~WD RP.~WD RTCK.UWD PSER.~IWD RP.~,~WD TARD.~WD RTCK.t4WD PSE~.~WD PEF,N~D RP,~WD RSI.mWD T~BD,~WD PEF,NWD RP.MWD RSI.~D TABD.~WD RTCK.~WD PSEP.~wD RP.MWD TABD.~WD RTCK.~WD PSER.M~D -999.250 1.639 3,845 2.224 0,000 0.62'1 -999,250 2.1a5 3.002 2.010 O.OOO 0,585 -999.250 2.008 3.112 2.064 0,000 0,515 -9~9.250 2.O61 2,719 2,353 0,000 0,469 -999,250 2,367 2,865 2,423 0,000 0,452 -999.,250 2,4~8 2.950 2.960 0.000 0.465 1.000 2.957 IS Tone Verl. flcat, ior~ l'.,J, stJnc~ 8-~P-!993 1.4:C'3 2.3 ! 12 35. 200 6. 020 -a99. 250 ?. 397 2.463 2 352 3o:901:) ~A.~,~ D 73.440 ~iS'i. t:4w D 6.n20 TAE., M'./4D -999. 250 DTCK. ~!WD 3. 116 ,aT~:R. MWD 3,17~ -0. r) l 1 2.886 0.000 0.24.7 -99q.~50 2.850 -0.008 2.457 O.nO0 0°2o2 -Q99.25n 2.490 3.291 O.OnO O. 21.4.. -999,250 3.328 -0.043 3.295 O.O00 0 3.9.,6 -999:~50 3,350 0.0 '77 2. 209 1.000 0,.251 1,000 '2.027 -0.03~ 0 707 0: 0 O 0 1..079 -999.95o 0.685 0.017 0. n 22 0.00 0 !,083 .,,999,250 RSI.V. WD T~BD. MWD RTCK.MWD PSE. R. MhD PFF. ~ WP RSI T~BD. ~WD RTCK. N! pS~;jD. MWD PEF.MWD ~P.~'WD ~SI.MWD RTCK.UWD PSER,~WD OEF.MWD RP,MWD RSI.MWD TABD.MWD RTCK.MND PEE,MWD TABD.MWD RTC~.VWD PSER.MWD P E F. ~ k' D .PSER.~WD PAGE;: 2.998 2.751 0.000 0,425 -999.250 2.737 2.960 2.436 0.000 0.445 -999,250 2.432 2.690 3,153 0.000 0,539 -999.250 3,159 2.759 3,144 0.000 0,622 -999,250 3,176 4.292 2.024 0.000 0,643 1,000 2,099 2.822 0,859 0,000 1,62l '999,250 0,773 4.987 0,711 0,000 1.,625 1,000 0.032 IS ?a~e v~,ri,!J..cat..fon I.,istinq Chlt~mherc.~er ,'.~!.asi,.-za r'ompt,lt, in,'~_ Ce..r~ter Curves aha .1..~ header det~ for each hit rt:tn :1.~ ser~arate files, 7 39 o 7 ~ 96, n. FAST V4, 7561 &41.4.0 756t .T..~ Tar, e ver..i.f i cmt. i nm 11 - , , ..,, - . $ 67.0 67.0 2.65 ~7~. 500 F,,'E~4ARK8; THIS FII,E< CF'!(iTAI~".:tS T~-~TE; SA!~PI.,tNG T..T. CK8 FRUP4 THE AO(}I3 IT [O~',,~ AS S ~2 003 - 999.2 003 - 999.2 O 0 3 - 999.2 4 ~m 00. ! 00 3 -999.2 0 0 3 -999.2 45 C ?. i, 003 -9~9.2 0o3 -999. '2 [~l,, GTCK. (,t0,] -999.~50 NTCK.O03 1..000 DTCK.003 50 09 G?CY,O()3 -~.~99,250 b}TCK, 0 [')3 -999,250 DTCK,003 (~;1 GTCK,003 -999.250 NTCK. 00'3 -999.250 DTCK.003 c~ I (; T C K, 0 (? :] 1,000 {'.~ T C ~:, 003 - 999. ~ 50 D T C K, 003 O0 GTC{.<. 003 -999.250 NTCK.O03 -999.250 DTCK.O03 0l GTCK.OO3 -999.250 M 're ~ . (:)1 [1) 3 -999.250 DTCK.003 0 C, C; T C K. 00 ',] - 990. P 5 C, ~',~ T C .K. 003 - 999.250 [.:, T C K. 003 5O -999.250 -999.25O -999'250 -999.250 -999.250 -999,250 -999.25I) -q99,250 chl~mberqe? Alaska Co~rr~,t]~n,~ ~enter ~' T. .460 ,. '~ m ., 4 6a 9 47 n ~"~ ,! 7 o 9 oO ~ -9o9 003 - ,' .... 0 C .~ - 999 4999 003 500 <3 5 {') o ? o O ~ - 99 5199 oo 9 -9og~ 5:2 o o 0 O 3 .' 00 3 .. .... 003 5 399 O03 - 00.9 003 -~99 993 1.4;03 -099.250 ;; TCi~ ,003 -q99.'2St) I .OCO YTCK.OP3 1 ,000 -999,250 ~,~7'CK. 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