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o12 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. April 27, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 � Anchorage, Alaska 99501 C ,A DATA LOGGED APR 29 2U1`,) �.K.BENDER AUG RE: Multi Finger Caliper: 3G-04 Run Date: 2/23/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-04 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20143-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20143-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating CANE Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ ; , Wd L VCO • S APR 14 2016 STATE OF ALASKA — ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L( .' la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 1E ' Suspended❑ 1 b.Well Class: 20na,C 25.105 20AAC 25.110 Development E 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. ' Abend.: 1/ 2016 i L 190-131 /315-768 . 2 3.Address: 7. Date Spudde . 1' Y" 15.API Number: P.O. Box 100360 Anchorage,AK 99510 10/30/1990 v TV 50-103-20143-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 2538'FNL,4985'FEL, Sec 24,T12N, R8E, UM 11/3/1990 KRU 3G-04 Top of Productive Interval: 9. Ref Elevations: KB: 90' 17. Field/Pool(s): 1916'FNL, 879'FWL, Sec 25,T12N, R8E, UM GL 54 BF: Kuparuk River Field/Oil Pool- Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2206'FNL, 922'FWL, Sec 25,T12N, R8E, UM 7751'MD/5780'TVD ADL 25548,ADL 25547 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498675 y- 5988561 Zone- 4 10785'MD/5848'MD AK 2662 TPI: x- 499261 y- 5983903 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 499304 y- 5983613 Zone- 4 1812'MD/1654'TVD 1732'MD/1594'TVD 5. Directional or Inclination Survey: Yes 111(attached) No ❑ 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) 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 SCM40 J . IN 2 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 16" 62.5 H-40 36' 115' 36 115' 18" ±200 Cu. Ft. 9 5/8" 36 J-55 35' 3795' 35' 3018' 11 5/8" 1685 Cu. Ft.AS III, 570 Cu. Ft. Class G 7' 26 J-55 35' 8062' 35' 6106' 9" 200 Cu. Ft. Class G 24. Open to production or injection? Yes r j No ❑ 25.TUBING RECORD If Yes, list each interval open(MIX-IVO of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 7557' 7521'MD/5697'TVD all perfs squeezed off faikMOOueD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. "606 Was hydraulic fracturing used during completion'? Yes❑ No ❑ DATE Per 20 AAC 25.283(i)(2)attach electronic and printed information 2/24114 _ �21FIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement plugs LL 7820'-7540' 37 bbl of 16.5 ppg cement(27 bbl of CemNet) 7750'-7400' 17 bbl of 16.5 ppg cement(12 bbl of CemNet) 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...— Flow Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate - - Form -Form 10-407 Revised 11/2015 ✓'TL 5/R /16 CONTIN D N PAGE 2 Submit ORIGINIAL onl y/9� �'�c3 5 ��� RBDMS �� APR 1 5 2016 • 28.CORE DATA Conventional Co ): Yes ❑ No ❑ Sidewall Cores: es ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1732' 1594' Attach separate pages to this form, if needed, and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk C Top 7640' 5787' Kuparuk C Bottom 7658' 5800' None Kuparuk A Top 7692 5826' Kuparuk A Bottom 7856' 5950' Formation at Total Depth: Kuparuk 31. List of Attachments: '"pQ jj1 ppcgp-,b&S S.-4 tsi Dv;A sit ScIaE,pHtux_ Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler @ 265-6435 Email: COdy.j.pohler(C COp.COm C) P Printed Name: G Eller Title: CTD Engineering Supervisor Signature: Phone: 263-4172 Date: 4-1\likko INSTRUCTIONS General: This form and a 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 1 a: 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 TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • Well Service Summary ' 3G-04 ConocoPhillips Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.00 PU CPU/WELL FILE,TRAVEL TO LOCATION VIA Y-PAD(UNIT ON 3B PAD) Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.00 SPOT UNIT,TGSM,RU .108 WIRE&1.875"TS=RS,5',KJ,5',OJ,LSS.OAL=24.5'INSTALL FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.75 PT W/LRS,RIH W/2.58"CENT,SHOCK ASBORBER&SPARTEK GAUGES,LIGHTLY TAG @ 7838'SLM,PUH FOR STATION STOP. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.50 30 MIN STOP @ 7690'SLM/7718'RKB, Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.25 PUH, 15 MIN GRADIENT STOP @ 7527'SLM/7555'RKB. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.75 POOH 10 MIN LUB STOP. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.50 PT W/LRS,RIH W/3'X WB,BLB&2.50"GUAGE RING,LRS ONLINE HOT @ 1.5 BBLS/MIN, BRUSH N FLUSH GLM'S&2.75"D NIPPLE @ 7519'SLM/7544'RKB,POOH,LRS OFFLINE 65 BBLS TOTAL. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.50 PT W/LRS,RIH W/KJ,3"D-RT W/2.75"CA-2 PLUG,SET @ 7519'SLM/7544' RKB,GOOD PULL TEST,LRS ONLINE TEST PLUG TO 2500 PSI, HOLDING,SHEAR OFF,GOOD,POOH W/O PLUG,BLEED TBG TO 1500 PSI, R/D LRS TO RELOAD. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.00 PT W/GAS,RIH W/3"GS W/2.79"CATCHER&2.5"GUTTED JD(OAL=64")SET @ 7519'SLM, POOH W/O CATCHER,.HARDLINE CREW ARRIVED. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.75 STAND BY FOR AL LINE TO BE RIGGED DOWN. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.50 PT W/GAS,RIH W/KJ,3.5"OK-1 W/1.25"JD,LATCHED GLV @ 2798'SLM/2822'RKB,POOH W/GLV,COT. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.75 PT W/GAS,RIH W/KJ,3.5"OK-1 W/BK-DMY VLV,SET @ 2798'SLM/2822'RKB,BLEED IA f/ 700-400 PSI,GOOD,SHEAR OFF,POOH W/O VLV,COT. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.00 PT W/GAS,RIH W/KJ,3.5"OK-1 W/1.25"JD,LATCHED OV @ 5450'SLM/5466'RKB,POOH W/ OV, SWAB STARTING TO LEAK,CALL VLV CREW TO SERVICE OVER NIGHT. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 0.75 SECURE WELL,PJSM,LDFN,REMOVE FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 1/13/2016 06:00 1/13/2016 19:00 1.00 TRAVEL TO OFFICE,SYNC CPU/TURN IN WELL FILE,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 0.75 PU CPU/WELL FILE,TRAVEL TO LOCATION. Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 0.75 START MAST TRUCK,TGSM,RU .108 WIRE&1.875"TS=RS,5',KJ,5',OJ,LSS.OAL=24.5', STAY ON TRAY Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 3.25 WAITING FOR LRS TO ARRIVE TO PUMP CIRC OUT. Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 4.00 LRS PUMP CIRC OUT 240 BBLS SEAWATER&90 BBLS DIESEL.U-TUBE. Page 1/8 Report Printed: 4/14/2016 t M a 4 1,011 � S Well Service Summary 3G-04 Conoc hithps Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 1.00 STAB ON,PT W/LRS,RIH W/3.5"OK-1 W/BK-DMY VLV,SET @ 5448'SLM/5466'RKB,PT TBG TO 500 PSI,SHEAR OFF,GOOD,POOH W/O DMY VLV, Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 1.00 LRS PERFORMED MIT-T START=2500/680/0 15 MIN=2200/680/0 BUMP BACK UP TO 2550/6800 START=2550/680/0 SAME AS LAST LOST 300 PSI TBG. CONFER W CWG REP,SWAP TO IA. Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 0.75 LRS PERFORMED MIT-IA START=450/2550/0 15 MIN=400/2540/0 30 MIN=400/2540/0 «PASS>> Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 0.50 SECURE WELL,PJSM,LDFN,REMOVE FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 1/14/2016 06:00 1/14/2016 19:00 1.00 TRAVEL TO OFFICE,SYNC CPU/TURN IN WELL FILE, END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 0.75 PU CPU/WELL FILES,TRAVEL TO LOCATION, Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 1.00 START MAST TRUCK,TGSM,RU .108 WIRE&1.875"TS=RS,5',KJ,S',OJ,LSS.OAL=24.5', INSTALL FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 1.00 PT W/GAS,RIH W/3"GR,LATCHED 2.79"CATCHER&GUTTED JD W/PRONG @ 7519'SLM/ 7544'RKB,2 OJ LICKS CAME FREE, POOH W/CATCHER&PRONG, CATCHER EMPTY,COT. Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 1.25 PT W/GAS,RIH W/3"RB,LATCHED 2.75"CA-2 PLUG BODY @ 7519'SLM/7544'RKB,4 OJ LICKS CAME FREE,POOH W/PLUG BODY, Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 1.00 SECURE WELL,PJSM,RDMO,REMOVE FUSIBLE CAP,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 1/15/2016 06:00 1/15/2016 12:00 1.00 TRAVEL TO 2C PAD. Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 1.50 MEET WITH MANAGERS ON JOB SCOPE,WEEKLY SAFETY MEETING,TRAVEL TO 3G PAD Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 1.75 INSPECT TRUCKS,FIRE UP TRUCKS,UNLOAD TRUCKS,PJSM,REHEAD LINE,PICK UP LUBE,MAKE UP PCE,CHECK FIRE,ARM GUN,STAB ON WELL. Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 0.25 PRESSURE TEST TO 3500 PSI, INSTALL FUSABLE CAP,OPEN SWAB Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 0.75 RIH WITH TUBING PUNCH GUN:CH/WB/ROLLER/WB/WB/CCL/GUN Page 2/8 Report Printed: 4/14/2016 • Well Service Summary 3G-04 ConocoPhiillips Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 0.50 CORRELATE AND SHOOT 2"3 SPF 120 DEG PHASED WITH TOP SHOT AT 7540'CCL TO TOP SHOT 2.66'CCL STOP AT 7537.6' Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 0.75 POOH WITH TOOL STRING Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 2.00 BUMP UP,CLOSE SWAB,REMOVEFUSABLE CAP,BLEED DOWN LUBE,BREAK OFF WELL, CONFIRM GUN FIRED,RIG DOWN TOOLS/PCE/LUBE,PAKC UP TRUCK, INSPECT LOCATION Report Start Date Report End Date Dur(hr) Operation Details 1/16/2016 06:00 1/16/2016 14:00 0.50 TRAVEL TO CAMP,SYNC LAPTOP Report Start Date Report End Date Dur(hr) Operation Details 1/17/2016 12:30 1/17/2016 15:00 0.50 TRAVEL TO LOATION Report Start Date Report End Date Dur(hr) Operation Details 1/17/2016 12:30 1/17/2016 15:00 0.50 MADE CONTACT WITH DSO,WELL WALK,MIRU,PJSM AND PT LINES TO 2500 PSI Report Start Date Report End Date Dur(hr) Operation Details 1/17/2016 12:30 1/17/2016 15:00 1.00 BPM BBLS FLUID T/I/O .5 ST DSL 750/750/0 ESTABLISH RATE WITH PRESSURE .5 10 DSL 900/750/0 AT.5 BPM TUBING WAS 900 PSI .75 ST DSL 1000/650/0 ESTABLISH RATE WITH PRESSURE .75 10 DSL 1000/550/0 AT.75 BPM TUBING WAS 1000 PSI 1 ST DSL 1100/550/0 ESTABLISH RATE WITH PRESSURE 1 10 DSL 1100/550 /0 AT 1 BPM TUBING WAS 1100 PSI Report Start Date Report End Date Dur(hr) Operation Details 1/17/2016 12:30 1/17/2016 15:00 0.50 RDMO Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.40 Travel to location. Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.25 PJSM. Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.50 Repair weight cell cable Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 2.25 MIRU. Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 1.40 M/U Milling BHA pull test and 2nd pressure test good Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 1.43 Take injector stack to well.Fluid pack and pressure test both lubricator and surface lines 300/ 4,000. Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 1.44 Open swab valve and RIH 1st WT CK @ 1,833'=2.4 k 2nd WT CK @ 3rd WT CK @ 7,450'=30 K Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 3.70 Tag top of D-Nipple @ 7,531' PUH and bring pump online with S/D @ 1.2 bpm free spin @ 1,700 CP RBIH slowly to start milling several stalls before pattern established Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.35 Finally broke free 7,531.7' RIH about 20' down with pump dry drift back up through nipple and then dry drift back in hole no wieght bobbles Page 3/8 Report Printed: 4/14/2016 • Well Service Summary 3G-04 ConocoPhillips Atmka Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 1.10 POOH pumping displacement down backside Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.30 At surface.Close swab valve.Bring injector stack to rear deck. Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 06:00 1/20/2016 20:00 0.89 Secure location for the night.Return in am to pump cement Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 22:30 1/21/2016 00:00 0.50 TRAVEL TO LOCATION SPOT UP UNIT Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 22:30 1/21/2016 00:00 0.25 PJSM,MIRU PT 3500 PSI Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 22:30 1/21/2016 00:00 0.25 START PUMPING DOWN TBG BBLS BPM TBG IA OA 0 1.0 1100 50 0 15 1.0 1200 50 0 SHUT DOWN Report Start Date Report End Date Dur(hr) Operation Details 1/20/2016 22:30 1/21/2016 00:00 0.50 RIG OFF WELL POST-JOB SAFETY MEETING FLAG AND TAG WING W/INFO. TURN WELL OVER TO DSO Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.50 Travel to location. Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.20 PJSM. Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.94 M/U Cementing BHA w/BJN Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.50 Take injector stack to well..Fluid pack and pressure test both lubricator and surface lines to 300 / 4,000. Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 1.35 Open swab valve and RIH to PBTD 1st WT CK @ 1,850'=2.4 k 2nd WT CK @ 4,633'=14.3 k 3rd WT CK @ 7,650'=32 k Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.06 Corrolate depth with D-Nipple Flag at horsehead again continue RIH after correction made Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 1.00 Tag PBTD at 7,877.5' PUH 5' Flow well for a few minutes and shut in to monitor WHP next shut in well and inject 10 bbls of SSW and shut in well to monitor WHP.(nozzle is clogged PUH out of fill and pump to clear nozzle nozzle cleared.Call 7,820'PBTD as procedure calls for )Make note of what both WHP's return to Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 2.00 Pump 2 TBG volumes of SSW to clean up and load wellbore PJSM with cementers,choke hands and coil crews Cement batched up at 12:30pm Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 1.37 Wait on PowerVis truck coming from MI in Deadhorse Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.42 Pump 5 bbls of F/W and pressure test SLB's surface lines with the SLB Cement Pump Page 4/8 Report Printed: 4/14/2016 • • Well Service Summary m _ , 3G-04 • CorlocoF'hilrps Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.12 Pump 5 bbls 16.5#Neat Cement.... Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.40 Pump 27 bbls 16.5#Cement with 1.5 ppb CemNet WHP=171 IA=0 OA=0 CP=2,522 1 bpm Density=16.80# Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.20 Pump 5 bbls of 16.5#Neat Cement Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.18 Pump 5 bbl F/W spacer Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.30 Switch back to the Halliburton Serva Pump and begin pumping PowerVis Gel behind FAN spacer ensuring 1:1's at 40 bbl Flow Rate Tank(FRT) Rate=.8 bpm CP=3,512 Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.32 Start PUH after 4 bbls above nozzle PUH at 25 fpm Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.35 At squeeze depth of 7,475' stop here and sqeeze cement away problems with PowerVis gel clogging screens stop pumping and swap screens resume pumping last 6 bbls of cement out of coil WHP=676 IA=0 OA=0 CP=2,590 Rate= 1 bpm Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.60 All cement out of nozzle lower pump rate to.5 bpm for pipe displacement and PUH to safety at 4,682'....and hesitate WHP=1,002 IA=0 OA=0 CP=2,715 Clean pickup weight Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.25 Pump up WHP to 1,200 and monitor leaks off slowly to 745 Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.30 Fluid in coil getting close to freezeing open choke and maintain 1:1's while pumping 25 bbls through coil Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.25 Now pump WHP back up to 1,200 for another pressure test P.T.passes Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.40 Launch 3/4"Steel ball bring pump online with PowerVis and start RIH to contaminate cement WHP=804 IA=0 OA=0 CP=2,088 Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.60 Tag top of cement at 7,492' start cleaning out cement Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.70 At desired depth for TOC at 7,535' (plus 5'down jet wash) pump a bottoms up and then leave a 70'PowerVis spacer inbetween the cement and diesel Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 1.40 POOH chasing returns and slowing down at each mandrel and SSSV to wash thoroughly Page 5/8 Report Printed: 4/14/2016 Well Service Summary 3G-04 Con>ocRaPhJ hps Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 0.55 At surface,trap 850 psi on WH.Close swab.Well freeze protected. Bring injector stack to rear deck. Report Start Date Report End Date Dur(hr) Operation Details 1/21/2016 06:00 1/21/2016 22:45 1.50 Secure location for the night and return in am to RDMO. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 1.50 OBTAIN WELL FILE FROM OFFICE,CONFER W/CWG REP. P/U TOOLS FROM Y-PAD SHOP. START&WARM UP MAST TRUCK&UNIT @ CPF3. TRAVEL TO 3G-04. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 1.75 INSPECT LOCATION,TGSM. MASTER VALVE SHUT&FROZEN. HOTSHOT TO 3B PAD FOR HEATER. SWAP WIRE,RE-PACK STUFFING BOX. R/U HEATER TO MASTER VALVE. R/U.108 WIRE,AND 1.875"TS- RS,6',KJ,5',OJ,KJ, LSS. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 0.75 MASTER VALVE THAWED,BUT SWAB IS FROZEN. R/U HEATER TO SWAB&LET THAW. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 0.50 FINISH RIGGING UP. PT LUB W GAS. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 1.25 RIH W/5'x 2"DD BAILER(MULESHOE BALL). TAG TOC @ 7520'SLM(7555'RKB). POOH. CEMENT IN BAILER BOTTOM. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 0.25 M/U KOT. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 1.00 RIH W/KNUCKLED 3 1/2"OM-1,7"EXT,AND 1.60"LIB(ZEROED @ FINGER). LOCATE @ 7417'SLM(7452'RKB). CORRECTION=35',SIT DOWN,TAP DOWN,POOH. LIB SHOWS CHINA CAP. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 0.75 BEGIN RIGGING DOWN. INSPECT LOCATION, PJSM. NOTIFY DSO. COMPLETE. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 06:00 1/25/2016 14:00 0.25 TRAVEL TO 3Q-13. Report Start Date Report End Date Dur(hr) Operation Details 1/28/2016 05:30 1/28/2016 12:30 1.50 MEET W/CWG REP @ KOC,ATTEND WKLY CONF CALL W/SLB MGMT,P/U CPU,TRVL TO 3G. Report Start Date Report End Date Dur(hr) Operation Details 1/28/2016 05:30 1/28/2016 12:30 1.75 ARRIVE @ 3G-04,PJSM,STACK AND LAY DOWN PCE,MAKE UP TOOLS,P/U PCE REMOVE TREE CAP, INSTALL FUSIBLE&NOTIFY DSO,STAB ON,PT W/GAS. TS=DIH,BMC,DCC,DPG,DCR,S/L XO,OJS,KJLSS Report Start Date Report End Date Dur(hr) Operation Details 1/28/2016 05:30 1/28/2016 12:30 1.50 RIH W/2.24"CENTRALIZER, 1.75"SAMPLLE BAILER.TIE IN USING HES CALLIPER LOG DATED 7/31/2015,LOCATE TOP OF CEMENT @ 7549.5'RKB,TAP DOWN TO ACQUIRE SAMPLE,POOH. OOH. *SMALL AMOUNT OF CEMENT IN BAILER. Report Start Date Report End Date Dur(hr) Operation Details 1/28/2016 05:30 1/28/2016 12:30 1.25 INSTALL&PT TREE CAP,REMOVE FUSIBLE&NOTIFY DSO.RIG DOWN DSL. Report Start Date Report End Date Dur(hr) Operation Details 1/28/2016 05:30 1/28/2016 12:30 1.00 TRVL TO 2Z FOR NEXT JOB,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.80 Travel to location. Page 6/8 Report Printed: 4/14/2016 i 0 � - Well Service Summary , 3G-04 ConocoPhttlips +tris Time Log Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.20 PJSM. Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 2.90 MIRU. Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.55 Take i njector stack to the well.Fluid pack and pressure test both lubricator and surface lines 300/ 4,000. Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 1.14 Open swab valve and RIH Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 1.18 Tag TD at 7,750' corrolate depth to CDR tag of TD at 7,747' PUH several feet and continue pumping S/W at 2 bpm until 1.5 tubing volume has been pumped ***Hold PJSM with all hands on location about cement job*** **Cementers start batching right after PJSM** Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.17 Cement batched up switch to S/D and pump 20 bbl pill to freeze protect surface iron and coil past the gooseneck before switching to cementers to start pressure testing with F/W Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.12 Switch to cementers to start pumping 4 bbls F/W before P.T WHP=62 IA=0 OA=0 ***Issues with cementer's Micor-Motion not reading volume pumped *** Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.10 P.T.cementers hardline to 4,500 psi Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.12 P.T.successful continue pumping another 6 bbls of F/W for spacer Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.04 Switch to 2 bbls neat 16.5 ppg cement Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.22 Switch to 12 bbls of 16.5 ppg cement with 1.5 ppb of CemNet Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.04 Switch back to 3 bbls of 16.5 ppg neat cement Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.15 Switch to F/W for displacement of cement out of nozzle WHP=27 IA=0 OA=0 CP=4,116 Rate=Increased to1.3 bpm(cement over the gooseneck now) Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.08 Switch to 40 bbl FRT and check 1;1's Rate back at 1 bpm now Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.30 1:1's verified 2 bbls of cement above nozzle start PUH at 26 fpm Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.20 Nozzle at 7,500' slowly close choke in and apply squeeze pressure of 700 psi pressure holding switch to S/D to allow for 30 min squeeze pressure test bring pump on and finish getting last 4 bbls of cement out of coil TBg prssure inadverdently climbs to 1,900 for 1.5 minutes before choke hand opens choke up when we came back online with the pump WHP back down to 708 and holding steady Page 7/8 Report Printed: 4/14/2016 " i 0 rF Well Service Summary I 10 i 3G-04 C`.avaThillips 1 A Time Log Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.60 @ 6,300' we are now at safety offline with pump after 21 bbls total of diesel pumped stay at this depth for 30 minute sqeeze pressure test load 3/4"steel ball so it's ready to launch when we start pumping PowerVis after P.T. Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.20 Ready to come online,but bottom of hardline downcomer line is frozen place heater on bottom chiicksan and pump neat meth out to tanks to free up line II Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.20 Slowly bleed WHP down to 400 psi and hold steady Switch to PowerVist and launch ball Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 1.00 Ball launched successfully start RIH contaminating cement stringers,etc.down to 7,400' Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 1.10 At 7,400' PUH washing TBG walls and jewlery chasing returns to surface Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.20 At surface.Reciprocate nozzle through tree and across BOPS numerouis times washing possible cement Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 0.40 Close swab valve.Bring injector stack to the rear deck Report Start Date Report End Date Dur(hr) Operation Details 2/11/2016 05:30 2/11/2016 20:00 2.50 RDMO 600 psi trapped on TBG steel ball recovered Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.00 P/U WELL FILES,SYNC CPU,CONTACT DSO,TRAVEL TO Y-PAD FOR TOOLS,TRAVEL TO LOC Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.00 ARRIVE LOC,INSP,PJSM,MIRU 108 WIRE,SWAP TO 1.875"STEM,TS=RS,5',5',OJ,KJ,LSS (OAL 28')CONTACT DSO, INSTALL FUSEABLE Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.00 LRS R/U,PT,RIH W/2.0"X 5'DD BAILER,TAG CEMENT @ 7366'SLM,SWAP TOOLS Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.50 LRS PT,RIH W/3.5"OM-1,LOC GLM @ 5436'SLM/5466'RKB,POOH, BEGIN MIT TBG 2025/50/0, 15 MIN, 1950/50/0,30 MIN 1925/50/0,PASS,CALL CWG REP Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.00 PJSM,FUSEABLE REMOVED,TREE CAP PT,INSP LOC,CONTACT DSO Report Start Date Report End Date Dur(hr) Operation Details 2/16/2016 06:00 2/16/2016 13:00 1.50 TRAVEL TO KCC,CHANGE OUT W/AHERN,CONTINUE TO 1D Page 8/8 Report Printed: 4/14/2016 KUP D 3G-04 ConocoPhiliips -L Well Attribu Max Angle D TD Alaska,Inc.. • Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConomYFriryips 501032014300 KUPARUK RIVER UNIT PROD 52.39 2,100.00 8,089.0 °°° ° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 36-04,4/14/20163.10.49 PM SSSV:TRDP 115 10/16/2014 I Last WO: 36.39 11/5/1990 vertical�nnemano(avwal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,838.0 5/27/2015 Rev Reason:SIDETRACKED TO'A',GLV C/O lehallf 3/18/2016 HANGER;30.80 5/2 In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top IftKB) (ftKB) (°) Des Com Run Date ID(in) 7,890.0 5,975.6 40.59 FISH 43'GeoService Tool Several Unsuccessful FISH 2/19/1994 attempts; See WSR's from 1/27/94 to 2/24/94 . , T .., ,, ..j_. Perforations&Slots Shot Dens Top(TVD) Bhn(ND) (shots/ CONDUCTOR,36 o-1150 t ' IL Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,640.0 7,660.0 5,786.8 5,801.9 C-4,UNIT B, 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase ..ji 3G-04 II7,710.0 7,734.0 5,839.6 5,857.7 A-3,3G-04 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase 7,754.0 7,774.0 5,872.7 5,887.8 A-2,3G-04 1/6/1994 4.0 RPERF 2.5"Titan;180 deg. j SAFETY VLV;1,812.0 9;.:�,.: phasing :vim 7,754.0 7,784.0 5,872.7 5,895.4 A-2,3G-04 1/14/1991 4.0 IPERF 4.5"Expendable Csg Gun;180 deg.phasing Notes:General&Safety End Date Annotation GAS LIFT;2,822.1 5/12/2010 NOTE.CSG Sleeve from bottom Surf Csg hanger to top of 1st collar(54"),10"X 500 wall X65 pipe 8/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/21/2016 NOTE:Milled out D-nipple @ 7,544'10 2.8"OD 1/21/2016 NOTE:Cement from TD to 7531 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;35.0-3,794.6—.- GAS LIFT;5,468.4 ,. al 11. GAS LIFT;7,452.1 . I PBR;7,507.9 PACKER;7,521.4 NIPPLE;7,5.4.8 SOS;7,556.4 -81/ SLOTS;7,543.0-11,002.0—..... APERF;7,840.0.7,680.0 +7 PRODUCTION;35.08,082 2 Liner AU Lateral;7542.8- --- 11,003.0 I APERF;7,710.0-7,734.0—.-- RPERF;7,754.0-7,774.0,— IPERF, 754.0.7,774.0`IPERF,7,754.0.7,784.0 FISH,7.890.0 • • nrilfingOperations Summary (with Timelog Depths) 3G-04 C=onocol'hiliips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Tittlii Log Stert6a�,r,= 8,.h s> `6,dTme. ' D u tnr 6p Cade . u coos :--:;. :;i4 0t�n _ mic8) t Dep {tuui 2/3!2016 2/3/2016 4.00 MIRU MOVE MOB P 14:30,Demob off 3N 0.0 0.0 14:30 18:30 2/3/2016 2/3/2016 3.00 MIRU MOVE 'MOB P 18:30 leave 3N,Arrive at 3G pad @ 0.0 0.0 18:30 21:30 21:30 2/3/2016 2/4/2016 2.50 MIRU MOVE MOB P DeJeep and spot modules,MIRU,Get 0.0 0.0 21:30 00:00 steam up,walkways,and stairways t 2/4/2016 2/4/2016 9.50 MIRU MOVE `RURD P Finish post-rig move checklist.Thaw 0.0 0.0 00:00 09:30 R7 valve. 2/4/2016 2/4/2016 1.00 MIRU WHDBOP NUND P NU BOP RIG ACCEPT 0.0 0.0 09:30 10:30 2/4/2016 2/4/2016 1.00 MIRU ..,WHDBOP RURD P Put koomey on line,rig down BOP 0.0 0.0 10:30 11:30 hanging lines and put on elevators. Grease crew on location.Grease swabs,master,Tangos and R valves. 2/4/2016 2/4/2016 10.00 MIRU WHDBOP 'ROPE P Start BOP test,Test Witness waived 0.0 0.0 11:30 21:30 by Guy Cook,AOGCC 2/4/2016 2/4/2016 2.00 MIRU WHDBOP CIRC P ROPE test complete,Fill coil,test 0.0 0.0 21:30 23:30 inner reel iron and packoffs 2/4/2016 2/5/2016 0.50 SLOT WHDBOP CTOP P Crew change Valve checklist 0.0 0.0 23:30 00:00 2/5/2016 2/5/2016 1.30 SLOT WHDBOP CTOP P Complete valve check list,remove 0.0 0.0 00:00 01:18 nozzle and install floats,Test E-Line, had to change out flow sub 2/5/2016 2/5/2016 1.00 SLOT WHDBOP CTOP P PJSM,PT PDL and TT line,three 0.0 0.0 01:18 02:18 loose connections on TT line 2/5/2016 2/5/2016 1.50 SLOT WHDBOP 'CTOP P PJSM,P/U TWC Lubricator,Pull 0.0 0.0 02:18 03:48 TWC,R/D and load out lubricator 2/5/2016 2/5/2016 0.70 SLOT WHDBOP CTOP P PJSM,PT DS PDL 0.0 0.0 03:48 04:30 2/5/2016 2/5/2016 3.00 SLOT WHDBOP CTOP P Finish rigging up. 0.0 0.0 04:30 07:30 2/5/2016 2/5/2016 1.00 PROW RPEQPT 'PULD P PJSM.MU mining BHA#1 with 2.80" 62.0 62.0 07:30 08:30 D331 mill and 0.9°AKO motor. 2/5/2016 2/5/2016 2.50 PROD1 RPEQPT TRIP P RIH with BHA#1.Tie in to HRZ for a- 62.0 7,539.0 08:30 11:00 2 ft correction.Continue in the hole and tag up at 7539 ft with 5klbs. 2/5/2016 2/5/2016 1.50 PROD1 RPEQPT TRIP T PUH,PUW=33klbs.RB1H and 7,539.0 7,600.0 11:00 12:30 attempt to retag cement.Saw very little motor work and low WOB. Continue washing down seeing occasional cement stringers(7592', 7597,7598), Made decsion to stop at 7,600 ft after not seeing any firm cement. Green cement observed over the shakers at bottoms up. 2/5/2016 2/5/2016 0.50 PROD1 RPEQPT TRIP T Discuss with town. Made decsion to 7,600.0 7,600.0 12:30 13:00 POOH.Mobilized Weatherford Reaves Underreamer and associated equipment. 2/5/2016 2/5/2016 0.90 PROD1 RPEQPT 'TRIP T 'POOH with BHA#1. 7,600.0 62.0 13:00 13:54 2/5/2016 2/5/2016 1.20 PROD1 RPEQPT PULD T On Surface,PJSM,Flow check well, 62.0 0.0 13:54 15:06 Lay downy BHA#1 2/5/2016 2/5/2016 1.20 PROW RPEQPT WAIT T Wait on Weatherford under reamer 0.0' 0.0 15:06 16:18 Page 1114 Report Printed: 51412016 1 • III DriIlirig Operations Summary(with Timelog Depths) &Wells 3G-04 Lonocophillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Tlmo 10 11 Sled T ._.: a rwlia l ...': 0ur(F'i ,phaeii ::„--op `4 1'Qod. title P-T :.; . ,.00819.11011,:, .: �s(1KB) End Oe�i1(l5( 2/5/2016 2/5/2016 1.00 PROD1 RPEQPT PULD T PJSM,P/1.1 BHA#2 Weatherford 2- 0.0' 74.1 16:18 17:18 3/8"Motor and Under reamer dressed with 6"blades for 7"26ppf casing ID. 2/5/2016 2/5/2018 1.80 PROD1 RPEQPT TRIP T Trip in hole,BHA#2 74.1 7,393.0 17:18 19:06 2/5/2016 2/5/2016 0.40 PROD1 RPEQPT DLOG T 7393,PUH to 7360,Log HRZ for no 7,393.0 7,441.0 19:06 19:30 correction,PUW=46K 2/5/2016 2/5/2016 0.20 PROD1 RPEQPT DLOG T Log CCL,Corrected TT @ 7550 7,441.0 7,553.0 19:30 19:42 2/5/2016 2/6/2016 4.30 PROM RPEQPT UREM T PUH to 7500 and shut EDC,Trip in to 7,553.0 7,600.0 19:42 00:00 7560 and bring on pumps,1.7 BPM @ 3107 PSI FS.Multiple stalls getting going.Extremly ratty.Pumped sweeps. 2/6/2016 2/6/2016 5.50 PROD1 RPEQPT UREM T Continue under reaming cement, 7,600.0 7,615.0 00:00 05:30 Multiple stalls,ratty milting,Low ROP, Pump sweeps 2/6/2016 2/6/2016 2.00 PROD1 RPEQPT TRIP T Confer with town,Trip out to inspect 7,615.0 0.0 05:30 07:30 underreamer BHA. 2/6/2016 2/6/2016 0.50 PROD1 RPEQPT OWFF T At surface.Flow check well.Static. 74.0 74.0 07:30 08:00 PJSM for inspecthg BHA. 2/6/2016 2/6/2016 0.50 PROD1 RPEQPT PULD T PUH.Stand back BHI BHA.Pull 74.0 0.0 08:00 08:30 Weatherfod compnents above the rotary table for inspection. Reamer blades are in good condition. Some wear observed on the edges. No chipped cutters or other damage. Made decsion to swap out blades for a new set,and pick up a new weatherford 2-3/8"motor. 2/8/2016 2/6/2016 1.00 PROD1 RPEQPT PULD T Lay down weatherford motor and 0.0 74.0 08:30 09:30 redress the Rives underreamer with new 6"blades.MU underreaming BHA #3 with new weatherford motor and redressed underreamer. 2/6/2016 2/6/2016 1.50 PROD1 RPEQPT TRIP T RIH with BHA#3 with EDC open.Tie 74.0 7,616.0 09:30 11:00 into the HRZ for a-1.5'correction. Continue in the hole and dry lag at 7616 ft. 2/6/2016 2/6/2016 9.40 PROD1 RPEQPT UREM T PUH.POW=57klbs.Close EDC and 7,616.0 7,644.0 11:00 20:24 RIH,Continue underreaming cement from 7616 ft to 7644 ft. 2/6/2016 2/6/2016 0.30 PROD1 RPEQPT WPRT T Back ream uo tp 7605,PUW�0K, 7,644.0 7,644.0 20:24 20:42 2/6/2016 2/7/2016 3.30 PRODI RPEQPT UREM T Continue Under reaming,1.6 BPM @ 7,644.0 7,657.0 20:42 00:00 3400 PSI FS,BHP=2976 217/2016 2/7/2016 3.40 PROD1 DRILL UREM T Continue under reaming cement in 7" 7,657.0 7,672.0 00:00 03:24 casing,1.56 BPM @ 3400 PSI FS, BHP-3077 2/7/2016 2/7/2016 0.60 PROD1 DRILL 'WPRT T Pull wiper to TT with sweeps, 7,672.0 7,672.0 03:24 04:00 PUW=68K 2/7/2016 2/7/2016 4.90 PROD1 DRILL UREM T -Continue Under reaming,1.55 BPM G 7,672.0 7,691.0 04:00 08:54 3400 PSI FS,BHP=3173 2/7/2016 2/7/2016 0.30 PRODI DRILL WPRT T Mini Wiper,PUW=69K 7,691.0 7,691.0 08:54 09:12 2/7/2016 2/7/2016 8.20 PROD1 DRILL UREM T Continue Under reaming,1.58 BPM @ 7,691.0 7,712.0 09:12 17:24 3455 PSI FS,BHP=2960 Page 2/14 Report Printed: 5/4/2016 • ,., Drilling Operations Summary (with Timelog Depths) ^. &Wells 3G-04 Conocof'hi3lips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK -TIM l.49 , Sart Bine 04111n» tluf01 Fhb opcvfl3 A+ r(hr 71016e rx :::-.fin .00131,.,:-:. 04O tf 1 2/7/2016 2/1/2016 0.50 PROD1 DRILL WPRT T Wiper with sweep,PUW=64K 7,712.0 7,712.0 17:24 17:54 2/7/2016 2/8/2016 6.10 PROD1 DRILL UREM T 7712'Ream.1.58 BPM @ 3550 PSI 7,712.0 7,723.0 17:54 00:00 FS,BHP=2980 2/8/2016 2/8/2016 0.10 PROD1 DRILL UREM T Under ream,1.58 BPM @ 3550 PSI 7,723.0 7,723.0 00:00 00:06 FS 2/8/2016 2/8/2016 0.30 PROD1 DRILL WPRT T Wiper to 7571,PUW=62K,Blow down 7,723.0 7,723.0 00:06 00:24 choke B 2/8/2016 2/8/2016 6.00 PROD1 DRILL UREM T Continue to under ream. 1.57 BPM @ 7,723.0 7,732.0 00:24 06:24 3730 PSI FS,BHP=3062 Stall at 7732 ft. PU to 7630 ft.PUW 67 klbs. 2/812016 2/8/2016 3.60 PROD1 DRILL UREM T Continue to under ream.1.57 BPM @ 7,732.0 7,740.0 06:24 10:00 3715 PSI FS,BHP=3050. Discuss with town.Call underream TD early at 7740 ft. 2/8/2016 2/812016 3.50 DEMOB MOVE TRIP T PUH pumping Hi Vis Sweep.OPen 7,740.0 68.0 10:00 13:30 EDC,continue POOH roling the hole over to seawater.Meanwhile,RU LRS and pump diesel freeze protect from 2500 ft. 2/812016 2/8/2016 0.50 DEMOB MOVE OWFF T Flow check well.Static. 68.01 68.0 13:30 14:00 2/8/2016 2/8/2016 0.50 DEMOB MOVE PULD T LD Weatherford Underreaming BHA. 68.0 0.0 14:00 14:30 No damage 2/8/2016 2/8/2016 3.00 DEMOB WHDBOP PULD T PJSM,R/U to set BPV,Gel mis set. 0.0 0.0 14:30 17:30 Debrie in profile.R/U to jet profile and stack 2/8/2016 2/8/2016 3.00 DEMOB WHDBOP CTOP T Start jetting stack and hanger profile, 0.0 0.0 17:30 20:30 TT line frozen,work to thaw, 2/8/2016 2/8/2018 0.70 DEMOB WHDBOP CTOP T PJSM,Jet stack in preperation to set 0.0 0.0 20:30 21:12 BPV 2/8/2016 2/8/2016 1.30 DEMOB WHDBOP CTOP T PJSM,Set BPV,Run profile brush 0.0 0.0 21:12 22:30 with BPV lubricator,Pressure up well to 500PSI.Set BPV,Bleed off tree to 100PSI.Good BPV PT,Rig down BPV crew and load out equipment 2/8/2018 2/9/2016 1.50 DEMOB WHDBOP CTOP T Install test joint and cycle BOPE to 0.0 0.0 22:30 00:00 remove cement debrie,M/U nozzle and jet stack,flush rig 2/9/2016 2/9/2016 1.50 DEMOB MOVE CTOP T Complete flushing rig,Blow down coil 0.0 0.0 00:00 01:30 and rig.Rig down cellar 2/9/2016 2/9/2016 1.50 DEMOB MOVE NUND T Nipple down stack,All fluids off rig. 0.0 0.0 01:30 03:00 RIG RELEASE 03:00 2/19/2016 2/19/2016 4.50 MIRU MOVE RURD T PJSM with PEAK and crew at 06:30 0.0 0.0 06:00 10:30 load Shop on trailer. Pull off 1G-11B. MU jeeps to subs, 2/19/2016 2/19/2016 4.00 MIRU MOVE MOB T PJSM-Mobilize 2 subs and shop to 0.0- 0.0 10:30 14:30 3G pad 219/2016 2/19/2016 3.25 MIRU MOVE MOB T Remove jeeps,prep well,remove tree 0.0 0.0 14:30 17:45 caps,spot Sub and Pits over well. Send truck back to retrieve shop from pervious location. 2/19/2016 2/19/2016 4.25 MIRU MOVE RURD T MIRU.Get steam up,walkways,and 0.0 0.0 17:45 22:00 stairways,complete pl post rig move check list. Page 3/14 Report Printed: 5/4/2016 • • DrilltiOperations Summary (with Timelog Depths) >=; &Welr s 3G-04 Lonocoihiliips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK -Tjme Loi . Stiitlimo End jhtie :> puf.tlY} ti .e .�Code . iivIq Code .Thin PTS -� r �...< " @Kai.�.i: �'1M���.. 2/19/2016 2/20/2018 2.00 MIRU WHDBOP NUND T Nipple up BOPE stack,and secure 0.0 0.0 22:00 00:00 cellar,Check all tree bolts,40 minutes,none found loose. Rig Accept at 22:00 2/20/2016 2/20/2016 3.00 MIRU WHDBOP RURD T Put koomey on line,rig down BOP 0.0 0.0 00:00 03:00 hanging fines and put on elevators. Grease crew on location.Grease swabs,master,Tangos and R valves. Load stack.Lines from test pump froze up.Troubleshooting boiler, steam lines. 2/20/2016 2/20/2016 7.00 MIRU WHDBOP ROPE T Begin initial ROPE test 250!4,500 0.0 0.0 03:00 10:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Guy Cook. 2/20/2016 2!20/2016 1.00 M1RU WHDBOP RURD T RD testing equipment,freeze protect 0.0 10:00 11:00 test pump and lines. 2/20/2016 2/20/2016 3.00 MIRU WHDBOP RURD T PJSM,with rig and valve crews,RU 0.0 0.0 11:00 14:00 lubricator and BPV equipment,test tiger tank line and valve shop lubricator,pull TWC,RD and load out valve shop equipment, 2/20/2016 2/20/2016 0.50 SLOT WELLPR SFTY T Pre-spud with rig crew and personnel. 0.0 0.0 14:00 14:30 2/20/2016 2/20/2016 4.00 SLOT WELLPR CTOP T 'PJSM,RU,and perform pipe 0.0 0.0 14:30 18:30 management cut 1393'of called tubing 2/20/2016 2/20/2016 3.00 SLOT WELLPR CTOP T Perform slack management,good air 0.0 0.0 18:30 21:30 flow thru coil,load coil 35 bbls,large amount of rust in returns,pump stack back 22 bpm. 2/20/2016 2/20/2016 1.00 SLOT WELLPR PRTS T Test inner reel iron and pads-offs, 0.0 0.0 21:30 22:30 good.RD test pump and equipment, freeze protect lines. 2/20/2016 2!21/2016 1,50 SLOT WELLPR CTOP T PJSM-cut 2 ft back to find wire, 0.0 0.0 22:30 00:00 reinstall boot,stab back on,pump slack back 2.2 bpm for 15 minutes,un -stab,cut 25 ft pipe to find wire,cut another 105 ft for total of 1,500 ft cut for pipe management. 2/21/2016 2/21/2016 0.50 SLOT WELLPR CTOP T RD pipe cutting equipment,off load 0.0 0.0 00:00 00:30 cut pipe. 2/21/2016 2/21/2016 3.30 SLOT WELLPR CTOP T PJSM-Prep end of call and MU CTC, 0.0 0.0 00:30 03:48 pull test 36k,Test wire good,MU UQC,re-test line,good.P/T 3,750 psi, good.Skid injector. 2/21/2016 2/21/2016 0.85 SLOT WELLPR PRTS T PJSM-Pressure test PDL's 1,500 psi. 0.0 0.0 03:48 04:39 2/21/2016 2/21!2016 0.50 SLOT 'WELLPR OWFF T Bleed well to 0 psi,Monitor well for 0.0 0.0 04:39 05:09 flow.PJSM-MU BHA 2/21/2016 2/21/2016 1.25 SLOT WELLPR PULD T MU BHA#1,0.0°motor and RB HYC 0.0 51.5 05:09 06:24 2.98"bi-center bit. 2/21/2016 2/21/2016 1.70 SLOT WELLPR TRIP T RIH,with cement milling BHA#4 51.5 7,050.0' 06:24 08:08 2/21/2016 2/21/2016 0.25 SLOT WELLPR DLOG T 7050 ft,Tie into gamma marker 7,050.0 7,112.0 08:06 08:21 correction of minus 1.0 ft. 2/21/2016 2/21/2016 0.50 SLOT 'WELLPR TRIP T 7112 ft,Continue RIH to TOC. 7,112.0 7,396.0 08:21 08:51 2/21/2016 2!21/2016 0.25 SLOT WELLPR TRIP T 7396 ft,Dry tag TOC,PUW 38 k,bring 7,396.0 7,396.0 08:51 09:08 pump up 1.6 bpm at 2300 psi Page 4/14 Report Printed: 5/4/2016 • • • Drilling Operations Summary (with Time$og Depths) &Weills 3G-04 C=cnocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK 7.144 1,14:09 61St.104 . sod rime ai Avi .rte op Cede .: r bode: Tin,.P T X 0rabon i - end oepa,(fKaj 2121/2016 2/21/2016 8.90 SLOT 'WELLPR MILL T 739511,start milling cement,1 k 7,396.0 7,465.0 09:06 18:00 DHWOB,29 fph,getting PUW 50k, every 25 ft pump 5x5 Lo/Hi sweeps 2/21/2016 2/22/2016 6.00 SLOT WELLPR MILL T 7,465 fl. OBM 1.7 bpm at 2,526 psi 7,465.0 7,502.0 18:00 00:00 FS,DHWOB.65k,ROP-10 fph,PUW 55k,pump 5x5 Lo/Hi sweeps, 4 stalls at 7,500 ft(2.938"ID PBR) 2/22/2016 2/22/2016 4.75 SLOT WELLPR MILL T 7,502 ft. OBM 1.7 bpm at 2,526 psi, 7,502.0 7,538.0 00:00 04:45 DHWOB.6k,ROP-10 fph,stall at 7,500 ft(2.938"ID PBR)PUW 54k, mill past,stall at 7,513 ft(2.859"ID Packer)high vibration 4's and 5's and slow milling to 7,528 ft.smoothed out to 7,538 ft.pump sweeps. 2/22/2016 2/22/2016 2.25 SLOT WELLPR TRIP T POOH for pilot hole assembly 7,538.0 51.5 04:45 07:00 2/2212016 2/22/2016 1.25 SLOT WELLPR OWFF T Check well for flow,PJSM,LD milling 51.5 0.0 07:00 08:15 BHA#4 2(22!2016 2/22/2016 0.75 PROD1 RPEQPT PULD T MU,second milling BHA#5 wt 0331 0.0- 62.5 08:15 09:00 and 0.9°ako motor. 2/22/2016 2/22/2016 1.25 PROD1 'RPEQPT TRIP T RIH,with BHA#5 62.5 7,105.0 09:00 10:15 2/22/2016 2/22/2016 0.25 PROD1 RPEQPT DLOG T 7105 ft,Tie into the gamma marker 7,105.0 7,122.0 10:15 10:30 correction of minus 1.5'ft.PUW 49 k. 2/22/2016 2/22/2016 1.00 PROD1 RPEQPT TRIP T 7122 ft,PUW are high,PUH slowly, 7,122.0 7,122.0 10:30 11:30 pumping 10x10 sweep.PUW 38k.lost 12k by pumping sweep,cuttings across shaker, 2/22/2016 2/22/2016 0.50 PROD1 RPEQPT TRIP T 7122 ft,continue RIH 7,122.0 7,445.0 11:30 12:00 2/22/2016 2/22/2016 0.25 PROD1 RPEQPT TRIP T 7445 ft,tag GLM,9k DHWOB, 7,445.0 7,445.0 12:00 12:15 temporarily detained at the bit,worked pipe three times,pipe is free,minus 13k.60k CSW. 2/22/2016 2/22/2016 0.50 PROD1 RPEQPT TRIP T 7445 ft,RIH to 7538 ft. 7,445.0 7,538.0 12:15 12:45 2/22/2016 2/22/2016 1.75 PROD1 RPEQPT MILL P 7538 ft,begin to mill cement,1.63bpm 7,538.0 7,550.0 12:45 14:30 at 2600psi,20°ROHS,1.5 k WOB,10 fph 2/22/2016 2/22/2016 4.15 PROD1 RPEQPT MILL P 7550 ft,Stalling motor,PUW 47k, 7,550.0 7,557.5 14:30 18:39 pump 5x5 sweep,mill ahead at 1.64 bpm at 2600 psi,IA 14,OA 0,Stalling at 7,553 ft and 7,557 ft. 2/22/2016 2/22/2016 0.10 PROD1 RPEQPT MILL P 7,557 ft. Stall,no ROP,call town, 7,557.5 7,558.5 18:39 18:45 PUH and roll TF to 200°ROHS,mill from 7,557.73 ft to 7,578.51 ft with 1k WOB roll TF back to 20°ROHS 2/22/2016 2/22/2016 3.65 PROD1 RPEQPT MILL P 7,558.5 ft. Milling cement 1.64 bpm at 7,558.5 7,600.0 18:45 22:24 2,850 psi,ROP 12 fph,WOB 1.4k, pump 5x5, 2/2212016 2/22/2016 0.75 PROD1 RPEQPT WPRT P Wiper up hole to 7,350,PUW 38k, 7,600.0 7,600.0 22:24 23:09 RBIH 2/22/2016 2/23/2016 0.85 PROD1 RPEQPT MILL P 7,600 ft. Milling cement 1.65 bpm at 7,600.0 7,613.0 23:09 00:00 2,869 psi FS,ROP 16 fph,WOB 1.4k, 2/23/2016 2/23/2016 1.85 PROD1 RPEQPT MILL P 7,613 ft. Milling cement 1.65 bpm at 7,613.0 7,644.0 00:00 01:51 2,797 psi FS,ROP 16 fph,WOB 1.4k, pump 5x5 Page 5114 Report Printed: 5/4/2016 410 • Drilling Operations Summary(with Timelog Depths) ,..:, &Wells 3G-04 conocophillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log -::.::..::.:::: -:.:::.:.:.i::.: :::*:-7.. w-.::- .•:::::,:..A-1 -, ..-„.:_ :..-..:H.k,,::p;-:::i: ::]:r .::.::: ..-;•-::•-:. :.-:::::,k,:i.:. .4pilii.:,:..? -.-,•i:,, ::q?]:: -.-.::::...--.:],:.: !:,:•:i::::::::.i:.:::j,:::j::: :: ::!.,!: ,.-: Stan sten Ton0,...* -,.-End Th!* :::•Pur 04::.•••:;: :eiiii47. •:: ;:-•,z-Op ecolW,:::: ;::Motiltvde- :1tine:Ki i:':',.'::',-.-;:,,--:-....,.,:-oPiNflion,'-',:'-::'',' •:: End Depli intup. 2/23/2016 2/23/2016 0.80 PROD1 RPEQPT WPRT P Wiper up hole to 7,350 ft,PUW 46k, 7,644.0 7,644.0 01:51 02:39 RBIH 2/23/2016 2(23/2016 4.00 PROM RPEQPT MILL P 7,644 ft. Milling cement 1.65 bpm at 7,644.0 7,706.0 02:39 06:39 2,850 psi FS,ROP 16 fph,WOB 1.4k 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT WPRT P 7706 ft,Wiper up to 7560 ft,PUW 50k 7,706.0 7,706.0 06:39 07:09 2/23/2016 2/23/2016 0.25 PROD1 RPEQPT MILL P 7706 ft,BOBM 1.65 at 2700 psi,ROP 7,706.0 7,750.0 07:09 07:24 4 fph,work pipe.IA 0,OA 0 2/23/2016 2123/2016 6.00 PROD1 RPEQPT MILL P 7750 ft,TD cement pilot hole.PUH 7,750.0 7,570.0 07:24 13:24 thru pilot hole to 7530 ft.PUW 46k 2/23/2016 2/23/2016 0.25 PROD1 RPEQPT DLOG P 7570 ft,Tie into the 1(1 marker 7,570.0 7,588.0 13:24 13:39 correction of plus 1.5 ft. 2/23/2016 2/23/2016 1.40 PROD1 RPEQPT MILL P 7588 ft,continue PUH to 7558 ft, 7,588.0 7,545.0 13:39 15:03 backream transition area up to 7545 ft. Dry drift transition,slight stacking 7560 to 7571 2/23/2016 2/23/2016 0.20 PROD1 RPEQPT 'WPRT P Continue trip in hole,tag TD a 7751 7,545.0 7,751.0 15:03 15:15 2/23/2016 2/23/2016 2.20 PROD1 RPEQPT TRIP P Pump sweeps and chase to surface. 7,751.0 62.0 15:15 17:27 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT PULD P At surface,30 min no flow test, 62.0 62.0 17:27 17:57 2/23/2016 2/23/2016 1.30 PROD1 RPEQPT SFTY •P Hold 2015 year review with both crews 62.0 62.0 17:57 19:15 2/23/2016 2/23/2016 1.00 PROD1 RPEQPT PULD P Lay down BHA#5,Pilot hole mill 62.0 0.0 19:15 20:15 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT WWWH P M/U nozzle and jet BOPE and tree 0.0 0.0 20:15 20:45 2/23/2016 2/23/2016 0.90 PROD1 RPEQPT PULD P PJSM,M/U HES Multi finger imaging 0.0 21.8 20:45 21:39 tool,MAJ to coil and surface test.Stab on injector 2/23/2016 2/23/2016 1.90 PROD1 RPEQPT TRIP P RIH BHA#6 HES Caliper 21.8 7,610.0 21:39 23:33 2/23/2016 2/23/2016 0.10 PROD1 RPEQPT DLOG P Correct depth(F., K1 for-3.52' 7,610.0 7,607.0 23:33 23:39 2/23/2016 2/23/2016 0.10 PROD1 RPEQPT TRIP P continue kt to 7742 7,607.0 7,742.0 23:39 23:45 2/23/2016 2/24/2016 0.25 PROD1 RPEQPT DLOG P 7742,Open caliper fingers,start 7,742.0 7,515.0 23:45 00:00 logging up @ 40 fpm 2/24/2016 2/24/2016 0.20 PROD1 RPEQPT TRIP P RBIH for second logging pass 7,515.0 7,742.0 00:00 00:12 2/24/2016 2/24/2016 0.50 PROD1 RPEQPT DLOG P Log 7742 to 7184,PUW=52K 7,742.0 7,184_0 00:12 00:42 2/24/2016 2/24/2016 1.90 PROD1 RPEQPT TRIP P Continue out of we with caliper 7,184.0 25.0 00:42 02:36 2/24/2016 2/24/2016 1.00-PROD1 RPEQPT PULD P At surface,PJSM.Flow check well. 25.0 0.0 02:36 03:36 Lay down BHA#6 2/24/2016 2/24/2016 1.50 PROD1 WHPST PULD l3 PJSM,P/U Whipstock,BHA#7.Make 0.0 72.6 03:36 05:06 up to coil track and surface test 2/24/2016 2/24/2016 2.50 PROD1 WHPST TRIP P Trip in with whipstock,EDC open 72.6 7,578.0 05:06 07:36 2/24/2016 2/24/2016 1.00 PROD1 WHPST TRIP P 7578 ft,PUW 45k©TOC,Continue 7,578.0 7,728.5 07:36 08:36 RIH log K1 marker for tie in correction of minus 2.5 ft. 2/24/2016 2/24/2016 1.50 PROD1 WHPST TRIP P 7728.5 ft.PUW 55k,set TOWS 7,728.5 72.6 08:36 10:06 hIghside at 7718 ft,PUW 55k,POOH Page 6114 Report Printed: 5/412016 • • Operations Summary (with Timelog Depths) >; We 3G-04 Conocol'hillip. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time $-Iwt'1'Mne .. ....:ffn4TYJq. .DurOM). . . - . ` 000.00. 9Cod.3 11�i.P-T- sren , : . ....::.OPe�scn<, .....; ... . : tR1tH) :'- $ndt5epm(tdca} 2/24/2016 2/24/2016 0.50 PROD1 WHPST OWFF P At surface,check well for flow 72.6 72.6 10:06 10:36 2/24/2016 2/2412016 0.75 PROD1 WHPST PULD P LD WS setting BHA#7 72.6 0.0 10:36 11:21 2/24/2016 2/24/2016 1.00'PROD1 WHPST PULD P Swap out risers to a shorter one for 0.0 0.0 1121 12:21 future BHA's.Perform shell test,up to 4500 psi. 2/24/2016 2/24/2016 1.00 PROD1 WHPST PULD P 'MU window milling BHA#8 0.0 0.0 12:21 13:21 2/24/2016 2/24/2016 2.50 PROD1 WHPST TRIP P RIH,with WS milling BHA with 0,8° 0.0 7,580.0 13:21 15:51 ako motor,String Reamer and Diamond Window Mill 2/24/2016 2/24/2016 0.55 PROD1 WHPST DLOG P 7580 ft,Log the K1 correction of 7,580.0 7,589.0 15:51 16:24 minus 1.5 ft.PUW 50k,swap well over to 8.5 ppg drilling fluid,PUW 34k 2/24/2016 2/24/2016 0.10-PROM WHPST WPST P Continue RIH,dry tagged TOWS at 7,589.0 7,718.0- 1624 16:30 7718',PUH,bring pump up,1.5 bpm at 3040 psi,BHP 3172,WHP 3,IA 0, OA 0 2/24/2016 2/25/2016 7.50 PROD1 WHPST MILL P 7717.3',Call pinch point,1.5 BPM @ 7,718.0 7,721.4 16:30 00:00 3000PSI FS,DHWOB=1.2K to 2.4K. Mill window per RP and BOT Rep ._ .__ 2/25/2016 2/25/2016 5.500.0:1 D1 DeWHPST MILL P Continue to mill window exit,1.5 BPM 7,721.4 7,740.0 00:00 05:30 0,71 k @ 2900 PSI FS,DHWOB=2.1K,BOT 0/0 calls BOW @ 7722.7,@ 3:07 2/25/2016 2/25/2016 1.50 15ROD1 WHPST MILL P 7740 ft.back ream window area, 7,740.0 7,719.0 05:30 07:00 seems to be clean, 2/25/2016 2/25/2016 2.00 PROD1 WHPST TRIP P 7719 ft.POOH,Check well for flow at 7,719.0 r 74.3 07:00 09:00 7350 ft.400 psi WHP. 2/25/2016 2/25/2016 0.25 PROD1 WHPST PULD P At surface,PJSM,Undeploy window 74.3 74.3 09:00 09:15 milling BHA 2/25/2016 2/25/2016 1.25 PROD1 WHPST PULD P LD Window milting BHA. 74.3 0.0 09:15 10:30 ""Note:MNIs were in gauge,2.79 no -go. 2/25/2016 2/25/2018 1.00 PROD1 DRILL PULD P 1 PJSM,MU/PD build section BHA 0.0 72.2 10:30 11:30 2/25/2016 2/25/2016 1.85 PROD1 DRILL 'TRIP P RIH,with build section BHA#9,2.3° 722 7,570.0 11:30 13:21 ako motor,USR,and rebuilt bi-center bit. 2/25/2016 2/25/2018 0.25 PROD1 DRILL DLOG •P 7570 ft.correction of minus 2.0 ft. 7,570.0 7,590.0 13:21 13:36 PUW 32k 2/25/2016 2/25/2016 0.40 PROD1 DRILL TRIP P .7590 ft.continue RIH thru pilot hole, 7,590.0 7,740.0 13:36 14:00 RIW 8k 2/25/2016 2/25/2016 1.75 PROD1 DRILL DRLG P 7740 ft,OBD 1.55 bpm at 3480 psi, 7,740.0 7,821.0 14:00 15:45 BHP 3646,WHP 311,IA 2,OA 0 2/25/2016 2/25/2016 0.25 PROD1 DRILL WPRT P 7821 ft.wiper up hole to 7740 ft,PUW 7,821.0 7,740.0 15:45 16:00 38k 2/25/2016 2/25/2016 0.25 PROD1 DRILL WPRT P 7740 ft,Log RA marker no correction, 7,740.0- 7,821.0 16:00 16:15 RBIH 2/25/2016 2/25/2016 0.60 PROD1 DRILL DRLG P 7821 ft,BOBD 1.55 bpm at 3440 psi, 7,821.0 7,871.0 16:15 16:51 BHP 3650,WHP 312,IA1,OA0 2/25/2016 2/25/2016 1.20 PRODI DRILL WPRT P PUH to check surveys,Surveys not 7,871.0 7,871.0 16:51 18:03 clean,Confer with town 2/25/2016 2/25/2016 0.40 PROD1 DRILL DRLG P 7871',Drill,1.5 BPM®3440 PSI FS, 7,871.0 7,893.0 18:03 18:27 BHP=3650 Page 7/14 Report Printed: 5/4/2016 411/ • ,_ Drilling Operations Summary (with Timelog Depths) :_, a Wells 3G-04 ConocoPhiltips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time 149' , Stria tiMe :'Lndltme 01t ii) „ Ftwse 9p0bde �,4kly Cede: Th a PT-X Ir l (IK�} End I ) 2/25/2018 2/2512016 0.40 PROD1 DRILL WPRT P Pull off bottom to discuss,confer with 7,893.0 7,693.0 18:27 18:51 town.Have 50'seperalion from main wen bore.surveys still not usable. Confer with town.Drill 15 more feet to see if surveys will clear up 2/25/2016 2/25/2016 0.20 PROD1 DRILL DRLG P 7893',Drill,1.50 BPM @ 3490 PSI 7,893.0 7,909.0 18:51 19:03 FS,BHP=3670 2/25/2016 2/25/2016 2.30 PROD1 ^DRILL TRIP T 7909 Surveys still not usable,104' 7,909.0 70.9 19:03 21:21 from parent well,Trip out for tool Begin BHI NPT 2/25/2016 2/25/2016 2.10 PROD1 DRILL PULD T Tag up and space out,PJSM,PUD 70.9 72.2 21:21 23:27 BHA#9,PD BHA#10.PDL Pre loaded,Make up to coil and surface test 2/25/2016 2/26/2016 0.55 PROD1 DRILL TRIP T RIH 72.2 2,462.0 23:27 00:00 2/26/2016 2/26/2016 1.50 PROD1 DRILL TRIP T Continue in well 2,462.0 7,570.0 00:00 01:30 2/26/2016 2/26/2016 0.10 PROD1 DRILL DLOG T Log K1 for-2'correction 7,570.0 7,595.0 01:30 01:36 2/26/2016 2/26/2016 0.40 PROD1 DRILL TRIP T 'Continue in well,close EDC,Clean 7,595.0 7,909.0 01:36 02:00 trip through window,Re take surveys 2/26/2016 2/26/2016 1.50 PROD1 DRILL DRLG P 7909',Drill,1.48 BPM @ 3394 PSI 7,909.0 8,002.0 02:00 03:30 FS,BHP=3636 END BHI NPT TIME,2 Hrs. 2/26/2016 2/26/2016 2.00 PROD1 DRILL TRIP P Call EOB,POOH for lateral BHA, 8,002.0 72.2 03:30 05:30 PUW=36K 2/26/2016 2/26/2016 1.00 PROD? DRILL PULD P At surface,PJSM,undeploy BHA#10 72.2 0.0 05:30 06:30 2/26/2016 2/26/2016 1.25 PROD1 DRILL PULD P PU/MU/deploy,change UQS check 0.0 72.2 06:30 07:45 valves,inspect Pac-off,Stab on with coil,tag up,space out, 2/26/2016 2/26/2016 2.00 PROD1 DRILL TRIP P RIH with lateral section,BHA#11 72.2 7,570.0 07:45 09:45 2/26/2016 2/26/2016 0.25 PROD1 DRILL DLOG P '7570 ft,log the K1 marker correction 7,570.0 7,589.0 09:45 10:00 of plus 3.0 ft. 2/26/2016 2/26/2016 0.75 PROD1 DRILL TRIP P 7589 ft.Continue IH to bottom. 7,589.0 8,002.0 10:00 10:45 2/26/2016 2/26/2016 5.00 PROD1 DRILL DRLG P 8002 ft,OBD 1.5 bpm at 3700 psi, 8,002.0 8,225.0 10:45 15:45 BHP 3661,WHP 270,IA 0,OA 0 2/26/2016 2/26/2016 0.25 PROD1 DRILL WPRT P 8225 ft,Wiper up hole to EOB 8002 ft. 8,225.0 8,000.0 15:45 16:00 RBIH 2/26/2016 2/26/2016 0.25 PROD1 DRILL WPRT P 8000 ft,wiper back In hole RIW 8k 8,000.0 8,225.0 16:00 16:15 2/26/2016 2/26/2016 2.00 PROD1 DRILL DRLG P 8225 ft,BOBD 1.5 bpm at 3700 psi, 8,225.0 8,229.0 16:15 18:15 BHP 3620,WHP 265,IA 11,OA 0, Continue to try to get drilling,Fluid tosses close to bottom©.5 BPM 2/26/2016 2/26/2016 1.10 PROD1 DRILL DRLG P 8229 Drilling break,ROP 70 FPH, 8,229.0 8,310.0 18:15 19:21 Returns baric to 95% 2/26/2016 2/26/2016 0.60 PROD1 DRILL WPRT P 8310',wiper to 7775,PUW=37K, 8,310.0 8,310.0 19:21 19:57 Clean trip up and down 2/26/2016 2/27/2016 4.05 PROD1 DRILL DRLG P 8310',Drill,1.5 BPM C 3660 PSI FS, 8,310.0 8,667.0 19:57 00:00 BHP=3675,Swap mud,New mud at bit @ 8636 2/27/2016 2/27/2016 0.60 PROD1 DRILL DRLG P Drill,1.5 BPM @ 3450 PSI FS, 8,667.0 8,710.0 00:00 00:36 BHP=3664 Page 8114 Report Printed: 5/4/2016 l90-1,31 • • 2(0'630) WELL LOG TRANSMITTAL#903062602 To: Alaska Oil and Gas Conservation Comm. February 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /2010, Anchorage, Alaska 99501 RECEIVEMK.BENDER FEB 2 3 2010 RE: Perforation Record: 3G-04 AOGCC Run Date: 1/16/2016 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 3G-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20143-00 Perforation Record(Field Print) SC•ptig� 1 color log 50-103-20143-00 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://) PiF 7.4t • • �w\�������,,s� THE STATE • Alaska Oil and Gas ti.> of TAsKA Conservation Commission 333 West Seventh Avenue leW1 \Th' Air GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Cody Pohler CTD Engineer ConocoPhillips Alaska, Inc. �aN �� 1 P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3G-04 Permit to Drill Number: 190-131 Sundry Number: 315-768 Dear Mr. Pohler: 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 P. oerster Chair DATED this /' L day of January, 2016. RBDMS- JAN 1 1 2016 RECEIVED • STATE OF ALASKA • DEC 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 07- I1 7//6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon '..... Plug Perforations I' ' Fracture Stimulate I— Repair Well I Operations Shutdown F Suspend Perforate r Other Stimulate E Pull Tubing . Change Approved Program 1......, Plug for Redrill Jv., - Perforate New Pool E Re-enter Susp Well E Alter Casing _.._ Other: crn SETUP ` F' . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - --- Exploratory � Development I - 190-131 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic ( Service I 50-103-20143-00 ' 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? none Will planned perforations require a spacing exception? Yes r-- No Fi% KRU 3G-04 9. Property Designation(Lease Number): l943 10.Field/Pool(s): ADL 25548 A 682 /1j .25: L 7- 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): - 8,089' • 6,127' . 7854 . 5948 3995 7890 Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 3,703' 9 5/8 3,795' 3,018' Intermediate Production 7,972' 7" 8,062' 5,724' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7640-7660,7710-7734, - 5786-5802,5839-5858, 3.5 J-55 7,557' 7754-7784 - 5873-5895 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): CAMCO HRP-1 SP PACKER 7521=MD,5697=TVD - SSSV:TRDP 1812=MD, 1654=TVD • 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory EStratigraphic -- Development • 1", Service 14.Estimated Date for 1/11/2016 15.Well Status after proposed work: Commencing Operations: OIL E WINJ r WDSPL E Suspended . 4 16.Verbal Approval: Date: GAS WAG I GSTOR I SPLUG !— Commission Commission Representative: GINJ F .. 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 Cody Pohler Email Cody.J.Pohler(cr�conocophillips.com Printed Name Cody Pohler@265-64 Title CTD Engineer r'7(561 r aio.,,, i<23o/ cts- Signature Phone: 265-6435 [ Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test [t] Mechanical Integrity Test ❑ Location Clearance ❑ Other: 06/0 z 5-f f v 43 ?O p5 1'9 OAP 51J 13 3995 /25-i ) hv-,u 1 ac✓ /JYrY-r.vr 1--e•✓ 4./ f✓.-,cif-C p�Jli, g,p1 a Ctvv+Tri apppi--a ve-d i7iy-20.4viez5�,/l�G) Post Initial Injection MIT Req'd? Yes El No D Spacing Exception Required? Yes ❑ No d Subsequent Form Required: I/0— 4 0 7- APPROVED BY Approved by: / - /� COMMISSIONER THE COMMISSION Date: /_7 „b /� ,„4 Form 10-403 Revise 11/2015 r& p at�i i�valid for 12 onthm the date of approval. �D(��menf.�ylirt,pu�ic eg01C v-rL 1/6/1 vV ^ LLL••• 16o,- �s ���� JNI I G U • • S KRU 3G-04 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 3G-04 is a Kuparuk A-sand producer well equipped with 3'/2"tubing and 7"production casing. Two laterals will be drilled to the north west of the parent well bore with the laterals targeting the different A2 and A3 sand lobes. These laterals will improve the sweep in the producer pattern where 3G- 14A and 3G-19A have been long term shut in. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 7,545' 1r will be milled out to a 2.80" ID. The existing A-sand and C-sand perfs will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand and C-sand perfs in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7,748' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 7,718' MD. Both laterals will be co lmn aterL with 2-3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2"tubing tail. Using the maximum formation pressure in the area of 4578 psi in 3G-12,the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3995 psi. CTD Drill and Complete 3G-04 Lateral: February 2016 Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels. 2. RU E-line: Shoot 2' of holes in the 3'/2"tubing tail at 7541' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the A& C sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. Ar'ac.� 2. 3G-04A Laeraf(A3 sand to north west T a. Drill 2.80"high side pilot hole through cement to 7,748' MD b. Caliper pilot hole c. Set whipstock at 7,718' MD d. Mill 2.80"window at 7,718' MD. e. Drill 3"bi-center lateral to TD of 10,800' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 8,200' MD. 3. 3G-04AL1 Lateral A2 sand a. Kick off of the aluminum billet at 8,200' MD. b. Drill 3"bi-center lateral to TD of 10,900' MD. c. Run 2%" slotted liner from TD up to 7,552' MD, above the whipstock and in the 3- 1/2"tubing. � /o s<� Co4/k'`,'o9 wi�� keet CUrte47 lzke �✓O,47 .W9'7 Co"Ci/ ' rhei or{ tecervcl •,f Page 1 of 2 i.4 Lj' 12/28/2015 • S 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's. 3. Return to production. Page 2 of 2 12/28/2015 • • Proposed 3G-04 CTD Schematic Modified by JGE 12/28/15 3-1/2"Camco TRDP-1A SSSV at 1812'RKB(locked out???) 3-1/2"9.3#J-55 EUE 8rd-Mod Tubing to surface 16"62#H-40 3-1/2"Merla TMPD gas lift mandrels 2822'&5466'RKB shoe @ 115' MD 3-1/2"Camco MMG-2 gas lift mandrel 7452'RKB 9-5/8"36#J-55 shoe @ 3795'MD —....m111 Camco 10'PBR at 7508'RKB Camco HRP-1-SP packer at 7521'RKB 3-1/2"Camco D-nipple at 7545"RKB(2.75"min ID) Note:Will bP rr to 2.80"ID 3-1/2"tubing tail at 7557'RKB li C-sand perfs KOP @ 7718'MD 7640'-7660'MD A-sand perfs 7710'-7734'MD _ - 3G-04A wp04 7754'-7784'MD TD @ 10,800'MD Liner Billet @ 8200'MD Lat#1 --= - =------- Lat#2 3G-04AL1 wp03 TD @ 10,900'MD Top of Liner @ 7550'MD 7"26#J-55 shoe @ 8062'MD I �- KUPD 3G-04 ConocoPhillips Well Attribut Max Angle D TD AI I:k,t I1.t, Wellbore API/UWI Field Name Wellbore Status Ind(") MD(ftKB) Act Btm IRKS) Conoca1411Bips r 501032014300 KUPARUK RIVER UNIT PROD 52.39 2,100.00 8,089.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-04,12/30/2015 8:32:17 AM SSSV:TRDP 115 10/16/2014 Last WO: 36.39 11/5/1990 - vertnuhvn lcal . eyc{outuat).. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,838.0 5/27/2015 Rev Reason:Mandrel Orientations lehallf 8/15/2015 lir °r HANGER;30.9 '`s aiIJ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) ,Set Depth(TVD)... Wt/Len(I...Grade Top Thread • CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB( Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,794.6 3,017.6 36.00 J-55 BTC Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread a.3.w,„„,,,,,„n„„,,e„,„,„„«„,,,,ii Ir.: rT,..,PRODUCTION 7 6.276 35.0 8,062.2 6,106.3 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection • �TUBING 31/2 2.992 30.8 7,557.2 5,724.4 9.30 J-55 EUEBrdABMOD CONDUCTOR 36.0-1150 i ` Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 30.8 30.8 0.17 HANGER MCEVOY GEN IV HANGER 3.500 1,812.0 1,654.4 43.64 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 SAFETY VLV;1,812.0 i 7,507.9 5,687.3 41.33 PBR CAMCO OEJ PBR w/10'STROKE 2.938 I 7,521.4 5,697.4 41.28 PACKER CAMCO HRP-1-SP PACKER 2.859 7,544.8 5,715.1 41.21 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,556.4 5,723.8 41.18 SOS CAMCO PE-500 SHEAR OUT SUB 2.984 GAS LIFT;2,0221 _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 7,890.0 5,975.6 40.59 FISH 43'GeoService Tool Several Unsuccessful FISH 2/19/1994 attempts,See WSR's from 1/27/94 to 2/24/94 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ 1 Top(ORB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SURFACE;35.0-3,794.6 7,640.0 7,660.0 5,786.8 5,801.9 C-4,UNIT B, 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase 3G-04 7,710.0 7,734.0 5,839.6 5,857.7 A-3,3G-04 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase GAS LIFT;5,466.4- 7,754.0 7,774.0 5,872.75,887.8 A-2,3G-04 1/6/1994 4.0 RPERF 2.5"Titan;180 deg. phasing ii, ..:.! 7,754.0 7,784.0 5,872.7 5,895.4 A-2,3G-04 1/14/1991 4.0 (PERF 4.5"Expendable Csg Gun;180 deg.phasing Mandrel Inserts St GAS LIFT;7,452.1 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn d 1 2,822.1 2,313.2 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,276.0 5/28/2015 3:00 2 5,466.4 4,210.8 MERLA TMPD 1 GAS LIFT OV BK 0250 0.0 5/28/2015 5:00 3 7,452.1 5,645.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/30/2015 1:00 I Notes:General&Safety --- End Date Annotation PBR,7,5079 5/12/2010 NOTE:CSG Sleeve from bottom Surf Csg hanger to top of 1st collar(54"),10"X.500 wall X65 pipe WiCli 8/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;7,521.4 NIPPLE;7,544.8 50S;7,556.4 APERF;7,840.0-7,060.0-.-. APERF;7,710.0-7,734.0 RPERF;7,754.0.7,774.0* IPERF;7,754.0-7,794.0 FISH',7,890 040 PRODUCTION;35.0-8,082.2 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the 1 Patricia r 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 proposed 'atrici. .rSteve 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 J.ea i- U.- 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 Jett.* Lie-- 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 Jo.p4i L12- 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 J2ra♦ai La— 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. • X31 2-Cok q2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGEED Anchorage, Alaska 99501 RECEIVM.K.BENDER p 01 RE: Multi Finger Caliper(MFC): 3G-04 A Run Date: 7/31/2015 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 3G-04 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20143-00 SC1NNOCS ) we l 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: Signed1/2"44L#1404f)._&eiveze Pages NOT Scanned in this Well HistOry File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE 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 vadous kinds . [] Other Complete COMMENTS: Scanned by: ~ TO RE-SCAN Notes: · Dianna Vincent Nathan Lowell Date:~,C;~ Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ~~~~1~~D • STATE OF ALASKA • MAY 2 ~ 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~tt~I~r~asC,~ns.~~ 1. operations Performed: Abandon ^ Repair w ell Q Plug Pbrforations ^ St'uYwlate ^ O~ QNrelded repair ARer Casing ^ Pull Tubing ^ F~rforate New Pbol ^ Waiver ^ Time Extensron ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: ~. Permit to Drill Number: Inc. ConocoPhillips Alaska Development ~ Exploratory ^ 190-131 , 3. Address: Stratigraphic ^ Service ^ API Number. 50-103-20143-00 P. O. Box 100360, Anchorage, Alaska 99510 7. Property designation: 8. Well Name and Number: ADL 25548, ALK 2662 ~ 3G-04 Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 8089 feet Plugs (measured) None true vertical 6127 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7521 true vertical 0 feet (true vertucal) 5697 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 0 0 SURFACE 3793 9.625 3793 3016 3520 2020 PRODUCTION 8062 7 8062 6106 4980 4320 SLEEVE 54" patch Tabbed from 10" .500 wall X65 pipe 0 0 0 Perforation depth: Measured depth: 7640-7660, 7710-7734, 7754-7784 True Vertical Depth: 5787-5802, 5840-5858, 5872-5895 „ . i` s +~ ~„' ~ I FM,' ``~~ Tubing (size, grade, MD, and TVD) 3.5, J-55, 7557 MD, 5724 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO 'HRP-1-SP' PACKER @ 7521 MD and 5697 TVD TRDP - CAMCO'TRDP-1A-SSA' @ 1812 MD and 1654 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ^ Development ~ Senrice ^ . Well Status after work: Oil [rj Gas ^ WDSPL Daily Report of Well Operations X GSTOR ^ WAG ^ GASINJ ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or td/A ff C.O. F~rempt•. 310-123 Contact nd/ P Klein Printe a MJ Lov nd Title Well Integrity Proj Supervisors Signa Phone: 659-7043 Date V RBpMS MAY 2 0 2111D~ i~ S" Zo-i a Form 10-404 Revised 7/2009 ~~/~' Submit Original Only • • 3G-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary. 05/03/10 Cut and removed landing ring and conductor, overall length is 86". 05/04/10 Identify hole & mark, clean surface casing for UT/MT inspectors. 05/12/10 05/16/10 Welders welded 54" patch fabbed from 10" .500 wall X65 pipe per mechanical engineer specs. Insulators denso wrapped surface casing. MITOA (passed), Initial SI/0/0 Pressure up with 2 bbls of diesel. Start T/I/O = SI/0/1800, 15 min T/I/O = SI/O/1720, 30 min T/I/O = SI/0/1690, 45 min SI/0/1690, 60 min SI/0/1690. Bled to 20 psi, final T/I/O = SI/0/20. 05/18/10 Instal185" of new conductor. .~ ,~ ; x q a ~~ t, z. w ~ .„ , ,. ;,- ." a ^ .:~ 9 ^ ^ J ~ - ~I ..~. _ ~._ ~a. ~„ . ~. ., ConocoPhillips Alaska, Inc ~'' and cannot be released or published without express `! ~x written consent of ~~~ ConocoPhillips Alaska .~ ~~ ~ x :~ ~k: •`"~ • ., - ConocoPhiilips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 16, 2010 Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3G-04 PTD 190-131 Sundry 310-123 surface casing repair. Please call Perry Klein or MJ Loveland at 659-7043 if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor Enclosures . . f • • ~~Q~~ OCR Q~Q~~Q /,E..a~~~o.~a MJ Loveland Well Integrity Project Supervisor ~ z , ConocoPhillips Alaska, Inc. ''"`~'~ Art _ ~~1 P.O. Box 100360 Anchorage, AK 99510 ,r b .~*- Y Re: Kuparuk River Field, Kuparuk Oil Pool, 3G-04 Sundry Number: 310-123 Dear Ms. Loveland: 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 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. DATED this ~ ~ day of April, 2010. Sincerely, Daniel T. Seamount, Jr. Chair Encl. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 12, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113G-04 PTD 190-131 for surface casing repair. Please call Perry Klein or myself at 659-7043 if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor Enclosures ~~~~~ STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMISS~ APR ]. ~~~~~CATION FOR SUNDRY APPROVALS r~„mmieeinr~ 20 AAC 25.280 ~ ~~~ / 1. Type of Request. Rug for Redrill ~ Perforate New Pool r Repair well ,I , Change Approved Program ~- Suspend Rug Perforations r Pbrforate ~ PUII Tubing ~ Time Extension r Operational Shutdown ~" Re-enter Susp. Well r Stimulate r After casing r Other: SC welded repair r , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ . Exploratory r 190-131 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20143-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 3G-04 9. Property Designation: 10. Field/Pool(s): ADL 25548, ALK 2662 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8089 6127 " Casing length Size MD ND Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 3793 9.625 3793' 3016' 3520 2020 PRODUCTION 8062 7 8062' 6106' 4980 4320 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7640-7660, 7710-7734, 7754-7784 5787-5802, 5840-5858, 5872-5895 3.5 J-55 7557 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - CAMCO 'HRP-1-SP' PACKER MD= 7521 ND= 5697 TRDP - CAMCO'TRDP-IA-SSA' MD= 1812 ND= 1654 12. Attachments: Description Summary of PYoposal ~ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Ma 1.2010 Oil r Gas r WDSPL ~ Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/ Perry Klein Printed Name MJ Loveland Title: Well Integrity Proj Supervisors Signature Phone: 659-7043 Date 04/12/10 'n Sundry Number: ~ ~ ~ „~ ~~ Conditions of approval: Notify Commission so that a representative may witness / J nical Integrity Test r Location Cle arance r Plug Integrity r B OP Test r Mecha // // / Other: ~rrG~GtdC ~hei~i rtoCc.~r"~t.t..~~~Oh o f /~~~ '~ r~~ ~t-c.t^, / v c) r"~ T'~1 ~ oar S ~0 t e~Te P"S rc, s ~ ~ r,, ti n L .Q , Subsequent Form Requir red: ~Q , ~ O APPROVED BY / / G~ / /~ Approved by: COMMISSIONER THE COMMISSION ~ Date: J Form 10-403 Re I G/'~~'/o Submit in u lica ~Dl~rb APR 1910~~ ~ ~ ~ ~ ~ ~ ~- ~ ~ ~~~ `t~/t~ • ConocoPhillips Alaska, Inc. Kuparuk Well 3G-04 (PTD 190-131) SUNDRY NOTICE 10-403 APPROVAL REQUEST 04/12/10 This application for Sundry approval for Kuparuk well 3G-04 is for the repair of a surface casing leak. The well is a Gas lifted producer that was drilled and completed in 1990. On February 20, 2010, a surface casing leak was confirmed and reported to the AOGCC. Diagnostics confirmed a leak in the surface casing at a approximately 36" below surface. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to remove all gas. Freeze protect the T and IA. Perform mechanical integrity test and draw down test on tubing plug to verify barrier. 2. Excavate wellhead location if required. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the damage../ 6. Repair damaged surface casing. Repair options include sleeve patch, seal weld, lap patch, , deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and corrosion inhibiting ° sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. • Page 1 of 1 Regg, James B (DOA) ~ ~~0-13 ~ ~~ ~~ ~ „~„ From: NSK Problem Well Supv [n1617@conocophillips.com] ~v a,23~j~ Sent: Saturday, February 20, 2010 6:49 PM `~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3G-04 (PTD 190-131) Report of suspected SC leak Attachments: 3G-04 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 3G-04 (PTD190-131) was reported to have a suspected near surface SC leak. The TIO prior to identifying the suspected leak was 187/1109/650. The well has been S14 freeze protecte and the OA was bled to 0 psi. A passing TIFL was performed to confirm barriers. Further diagnostics will be comT e'fTwhen the weather breaks to confirm the leak and locate the depth. Once diagnostics have been completed and repair options have been decided upon, the appropriate paperwork will be submitted. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 2/23/2010 KRU 3G-04 PTD 1901310 2/20/2010 TIO Pressures 3 3 3 D. 0. 0. 0. 0. fl . 0_ SC WLKRU3G-04 3000 2700 2100 2100 1800 1500 1200 900 600 300 0 PLOT STAKT 'LIME MINOR TIME PLOT DURATION PLC1T END TIME 22-NOV-09 10:44 MAJOR TIME WEER +1?~3$0:00:00 HRS~`~1`FEB-10 10144 PICK TINE:... _ B-l0 1Oc39:54 SC TItG Nl)iE DESCRIPTION ''>'ALtr~-: LATEST WL3G-09-CHOICE FLOW TUBING CHOSE I76. ~ SCRATCH 58 FLOW TUBING PRESSURE 187. SCRATCH_58 FLOW TUBING TEMP 105. ~ AI-P3G5002-04 GL CASING PRESSURE 1115. ~ 7?7???? ~ ??????? SCRATC}t_58 INNER ANNULUS FRES 1109. ~ SCRATCH_58 OUTER ANNULUS PRES 650. DRILLSITE WELL PREV WELL 3G 04 .NEXT WELL ENTR`. "''"PE OPERATOR ~ OPERATOR VERIFIED ~ SYSTEM AUTO ENTRY ~ BOTH • • - - - m. ~ KUP t"nr~nrnP{~iltir~c-,' i! 1 well attr~e~tes 3G-04 Max Angle & MD 1TD I ------_. ......r -_ I W IltaF°I,UY:1Fleld Name Well Statua ProMnj Type Intel (°) MD (RKB) Aet Btm /ttKB) ' i 50 .-.14300 KUPARUKRIVERUNIT PROD 52.39 2,100.00 8,089.0 h C m M HZS (ppm) Date Annotation End Date KB-0rd (R) Rig Relegsa Data °'~ ~ ~ ~ ~ SSSV: TRDP 100 7/1/2008 Last WO: 36.39 11/5/1990 sr r " - n I i An notation Depth (ttKB) End Date Anndtatlon End Date Last Taq. SLM 7,863.0 1/29/2009 Rev Reason: TAG FILL 1/30/2009 Casin~Stri~s _ _ _ ~ String ID Set Depth Set Depth (ND) String Wt String Sinng OD ~ __ F 1 [ Casing Dosorlptlon pn) (In) Top (RKB) (RKB) (ttKB) (Ibaftt) Orede String Top Thrd tl( CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 CONDUCTOR, 115 E ~ ~ SURFACE 95/8 8.765 0.0 3,793.0 3,016.5 36.00 J-55 r 3 g PRODUCTION 7 6.151 0.0 8,062.0 6,106.2 26.00 J-55 -- TubingStrmc,~s " S '~ St i St i S D h TVD W SAFETV VLV, ~ ~ Tubing Deacrlptlon St I g OD Iln) String ID Ilnl Top (RKB) et Uepth (RKB) r ng et ept ( ) r ng t (RKB) (IbaHt) Grade String Top Thrd telz ~ ~ TUBING 31/2 2.992 0.0 7,557.0 5,724.2 9.30 J-55 EUE 8RD AB MOD Other In Hole All Jewel : Tubin Run & Retnevab_ Ie~Flshzetc_~_______ ~ I Top Depth j (ND) Top Inc! Gns uFT ~' ~ ~ To (RKB) (ttKB) (°) Deacrlptlon Comment Run Date ID (in) • zezz [ . ~ ~ 1,812.0 1,653.8 45.32 SAFETY VLV Camco TRDP-tA-SSA' 1/15/1991 2.813 `- ~"~ ~ ~ 2,822.0 2,313.4 43.77 GAS LIFT MERLA/rMPD/1/GLV/BW.156/1273/ CommenC STA 1 5/26/1998 2.875 ,{ t€t 5,466.0 4,210.6 44.80 GAS LIFT MERLA/TMPD/1/GLV/BK/.188/1321/Comment: STA 2 5/26/1998 2.875 suRFACE. f' { , 7,452.0 5,645.4 41.50 GAS LIFT CAMCO/MMG-2/1.5/OV/RW.1881/Comment: STA3 5/26/1998 2.920 3,793 ~, ' t 7,508.0 5,687.2 40.98 PBR Camco'OEJ' 10'strokePBR 1/15/1991 2.938 l ~ 7 521.0 5 697.0 40.99 PACKER Camco'HRP-I-SP' PACKER 1/15/1991 2.859 : ~ , , 1„ ~- 7,545.0 5,715.1 41.01 NIPPLE Camco'D' Nipple NO GO 1/15/1991 2.750 GnsuFT, 5 ~ r-'~ 7,556.0 5,723.4 41.01 SOS Camco PE-500 1/15!1991 2.984 ' ~:,,--: >'"' 7,557.0 5,724.2 41.01 TTL 1/15/1991 2.984 1 7,890.0 5,975.6 40.59 FISH 43' GeoService Tool Several Unsuccessful FISH attempts; 2/19/1994 See WSR's from 1/27/94 to 2/24/94 ~ ~ GnsuFr, Perfora tions _T- -- --__ ___ 7,45z ~ -- sn t _ ~ Top (ND) Btm (ND) Dena .q Top (RKB) etm (RKB) (RKB) (RKB) Zone Date (ah~° Type Comment 1 7,640.0 7,660.0 5,786.8 5,801.9 C -4, UNIT B, 7/16/2002 4.0 RPERF 2.5" PJ, 120 deg phase 3 G-04 -: - 7,710.0 7,734.0 5,839.9 5,857.9 A -3, 3G-04 7/16/2002 4.0 APERF 2.5" PJ, 120 deg phase { 7,754.0 7,784.0 5,872.8 5,895.4 A -2, 3G-04 1/14/1991 4.0 IPERF 4.5" Expendable Csg Gun; 180 deg. PeR, 7.506 _ I -.-... phasing ) t 7,754.0 7,774.0 5,872.8 5,887.9 A -2, 3G-04 1/6/1994 4.0 RPERF 2.5"Titan; 180 deg. phasing t PACKER, 7,521 ! 1 =, r 1 ...._ - _~ f NIPPLE, 7,545 1 I E 1 L S 1 505, 7,556 ~ ~ ' r 1 [~ I Q TTL, 7,557 [ {:,. i e_-_ J APERF, 7,640.7,660 APERF, , 7.710-7,734 RPERF, 7,754-7,774-~--. IPERF, 7,754-7,784 - FISH 7 890 , , s PRODUCTION, ~I ~. 6,062 TD, 8,069 m "` ~ i ~~~`f '~~~d% C~4~~~ c.~~~.~ N0.5138 Schlumberger -DCS j 2525 Gambell Street, Suite 400 '~, ~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 i ;i ~"} Attn: Christine Mahnken ATTN: Beth ~ ~ ~ ~ 333 West 7th Ave, Suite 100 ~` \ ~ ~•.,~ ~-- Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/18/09 2A-26 604C-00011 OH EDIT (PEX,SSCANNER & CHFR) p -~j9~1 ~~/ 0?J14/09 6 1 1E-170 ANHY-00057 PRODUCTION PROFILE aQ '~ 03/06/09 1 1 f A-f f ANHY-00058 LDL C./ 03/08/09 f 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 36-15 ANHY-00061 INJECTION PROFILE J = "b 03/11/09 1 1 i R-10 ANHY-00063 INJECTION PROFILE C 03/13/09 1 1 2M-16 ANHY-00064 INJECTION PROFILE / , 03/14/09 1 1 ZG-15 ANHY-00065 PRODUCTION PROFILE f'~fL(- ( 03/15/09 1 1 _ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~. • r~ ~J REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ X RKB 90 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora~le, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2536' FNL, 4984' FEL, Sec. 24, T12N, R8E, UM (asp's 498675, 5988560) 3G-04 9' At top of productive interval . Permit number / approval number 1916' FNL, 879' FEL, Sec. 25, T12N, R8E, UM 190-131 / At effective depth 10. APl number 50-103-20143 At total depth 11. Field / Pool 2205' FNL, 4359' FEL, Sec. 25, T12N, R8E, UM (asp's 499302, 5983612) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8089 feet Plugs (measured) true vertical 6127 feet Effective depth: measured 7854 feet Junk (measured) true vertical 5948 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 243 sx AS II 1 15' 115' SUR. CASING 3703' 9-5/8" 870 sx AS III & 500 sx Class G 3793' 3018' PROD. CASING 7972' 7" 300 sx Class G & 175 sx Class G 8062' 6106' Perforation depth: measured 7754'- 7784', 7640'- 7660', 7710'-7734' iii! ii!ii" ill ~i!i true vertical 5873' - 5895', 5785' - 5802', 5840' - 5858' ~' i. ,-i Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7557' MD. :~.i!i;,i ~ ~ ;' .. Packers & SSSV (type & measured depth) CAMCO 'HRP-1-SP' @ 7521' MD. CAMCO 'TRDP-1A-SSA' @ 1812' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 409 791 1159 153 Subsequent to operation 544 930 1465 151 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~, /,//~, ~.,/V~ Title: Wells Team Leader Date Michael Mooned/ ' , Prepared bi/Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · .$C NED AUG 2 1 2002 0EIGli AL SUBMIT IN DUPLICATE Date Comment 3G-04 Event History 07/15/O2 07/16/02 TAGGED FILL @ 7754' RKB, ALL A-2 PERFS COVERED; DRIFTED TBG W/11' X 2.5" HC TO 7754' RKB. [TAG, PERF] PERFORATED 7640' - 7660' AND 7710' - 7734', 4 SPF, 120 DEGREE PHASING, W/POWERJET CHARGES, TAGGED TD AT 7747' SCANNED AUG 2 1 2002~ Page 1 of I 8/13/2002 PI- _LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 August 14, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3G-04 (190-131) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 3G-04. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad ,,SCANNED AUG 2, 1 2002 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 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 1H-07 Other 3G-04 Stimulate 3Q-02 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Anchor&ge AR3B-6003-93 242-2603 STATE OF ALASKA ~ OIL AND GAS CONSERVATION CCMMIS,....,,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well 2. Name of Operator AR00 Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surfaco 2538' FNL, 295' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1916' FNL, 879' FWL, Sec. 25, T12N, R8E, UM At effective depth 2134' FNL, 909' FWL, Sec. 25, T12N, R8E, UM At total depth 2206' FNLr 922' FWLr Sec. 25~ T12Nr R8Er UM 5. Type of Well: Development Exploratory · Stratigraphic 12. Present well condition summary Total Depth: measured 8 089' feet Plugs (measured) true vertical 61 27' feet NoRe Effective depth: measured 7975' feet Junk (measured) true vertical 6 0 4 0' feet NoFle Casing Length Size Cemented Structural Conductor 8 0' 1 6" 243 Sx AS II Surfaco 3760' 9 5/8" 870 Sx AS III & Intermediate 500 Sx Class G Production 8 0 2 7' 7" 300 Sx Class G & Liner 175 Sx Class G Perforation depth: measured 7754'-7784' true vertical 5873'-5895' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J55, 7557' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA, 1812', Packer: Camco HRP-1-SP, 7521' 13. Stimulation or coment squeeze summary A SAND FRACTURE TREATMENT Intervals treated (measured) 7754'-7784' Treatment description including volumes used and final pressure SEE A'I-I-ACHED WELL SERVICE REPORT SUMMARY Perforate Other 6. Datum elevation (DF or KB) RKB 90' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-04 g. Permit number/Approval Number 9o-131 10. APl number I so-103-2014300 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3795' 3013' 8062' 6095' RECEIVED --. 5 1994 .. x. iq'~q P. nn~ ~nmmJ.~RJ[ Anchorage 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Averaoe Production or Iniection Data _ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure --'~ 127 18 760 202 2236// 1 424 706 1172 Tubing Pressure 148 191 16. Status of well classification as: Oil X Gas Suspended Servico 17. I hereby cortify that the foregoing is true and correct to the best of my knowledge. si~ned '/~~~(~' ~ Title Sr. PetroleurnEngineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 01/22/94 TO 01/22/94 CPF-3 DS-3G 3G-04 01/22/94 A SAND REFRAC W/DOWELL. PUMP 150 BBL SLK WTR BD AT 36 BPM, FOLLOWED BY 3 SLK WTR PI/SI'S & 2 GSW MINIFRAC @ 20 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC BREAKDOWN 150 4550 1409 3730 .68 1781 PI/SI~i 25 2996 1528 3860 .70 108 PI/SI~2 25 3039 1546 3875 .71 133 PI/SI~3 25 2960 1550 3930 .71 50 FLUSH 70 2920 1530 3850 .70 30 DATAFRC~i 400 3396 1775 4220 .74 261 DATAFRC~2 200 3551 1812 4230 .75 379 FE ON 1ST DATAFRAC = 30% (DOWELL G FNCTN AND SQ RT). FE#2356% (SMART CLOS TIME), 51% (DOWELL G FNCTN AND SQ RT), CUT PaD FROM 300 BBL TO 160 BBL. PUMPED 16.0 MASS 16/20 CA IN 2 PPA STAGE & 252.5 MASS 12/18 CA IN 4-14 PPA STAGES @ 20 BPM, LAST WHTP=4636 PSI. FLUSH W/70 BBL GW/SLK WTR/SLK DSL @ 20-3 BPM, BUT DID NOT SCREEN OUT WELL. TOT PROP: DESIGN=271.1 MASS, IN FORM=265.6 MLBS W/14.2 PPA @ PERFS. TOT FLUIDS: WATER=1980 BBL, DSL(FLA + FLUSH)=70 BBL, ADD'S=133 BBL. ALL FLUIDS LOOKED EXCELLENT, EXCEPT 6 PPA SAMPLE VERY VISCOUS. ALL SAMPLES BROKE AFTER 12 HOURS EXCEPT 6 PPA, WHICH RETAINED 60 CP VISC AFTER 36 HOURS AT 1501. GEOSERVICE TOOL DID NOT TRANSMIT REAL-TIME DURING FRAC. (VINCENT/BORDES) RECEIVE[.¢ h..i~$1',[~ Oii& P~as {2ms. {.;',;iliii-~i:;s~.'~' Ancho~aoe ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 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 ~5--Iqfl 1F-15 Perforate ~2.-i'~o 1H-1 7 Perforate ~q.-R'5 1Q-12 Stimulate c/.;5_[¢~;1Y-17 Stimulate fib-Cq 1Y-28 Stimulate ~o-IZ, i 3G-04 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB 1 6 1994 Ataska 0il & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 AKA OIL AND GAS COIY,? RVATK C. X3M' REPORT OF SUNDRY WELL OPEHATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing ----..-- Stimulate Plugging Repair well . Perforate X 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 4. Location of well at surface 2538' FNL, 295' FWL, Sec. 24, T12N, At top of productive interval 1916' FNL, 879' FWL, Sec. 25, T12N, At effective depth 2134' FNL, 909' FWL, Sec. 25, T12N, At total depth 2206' FNL~ 922' FWL~ Sec. 25~ T12N~ 12. Present well condition summery Total Depth: R8E, UM R8E, UM R8E, UM R8E~ UM measured 8089' feet true vertical 61 27' feet Plugs (measured) 6. Datum elevation (DF or KB) 9O' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-04 9. Permit number/approval number 90-131 10. APl number 5o-103-20143 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 7975' feet true vertical 6040' feet Junk (measured) Structural Conductor Surface Intermediate Production Uner Perforation depth: Lenglh Size 80' 16" 3760' 9 5/8" 8027' 7" measured 7754'-7784' true vertical 5873'-5895' 243 SX AS II 1 1 5' 870 SX AS III & 3795' 500 SX Class G 300 SX Class G & 8 0 6 2' 175 SX Class G Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J55, 7557' Packers and SSSV (type and measured deplh) SSSV: Camco TRDP-1A-SSA~ 1812'~ Packer: 13. Stimulation or cement squeeze summary A2-Sand reperforation. Intervals treated (measured) 7754'-7774' Treatment description Including volumes used and final pressure 14. True vertical depth 115' approx 3013' approx 6095' approx Camco HRP-I-SP~ 7521' RECEIVED Reperf w/2 1/2" Titan DP/BH ~iun, 4SPF~ 180°~ 90° CCW. Renr~sentafi¥~ Daily ,Average Production or Iniecfion Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsec{uent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 202 2236 16. 1~7~ 1 8 900 ~424 706 1200 Status of well classification as: Water Injector m Oil X Gas Suspended 17. I here/ll~y certify that the foregoing is true and correct to the best of my knowledge. S~jned '~~ 4~, ~'~ 'nt~e Sr. Engineer Form 10-404 Rev 09/12/90 187 176 Sa'vice SUBMIT IN DUPLICATE ARCO Alaska, Inc. RECEIVEL !,/~xiq '-'5 t99/,''. KUPARUK RIVER UNIT WELL SERVICE REPORT _ - . WELL DESCRIPTION OFWORK ..... 'iff ~ .. DATE OONT~OTOR/K~ PERSON ~ ~...~¢:~' 2~ ~ ~:¢': - AFC/CC DAY OPE~TION AT REPORT TIME FIE~ EST: AOOUMU~TED COST I ~ COMPL~E ~ ~NCOMP~E $ ~, ~ ~¢ $ TIME L~E~RY~¢~ ~¢ -- ~ ~1500 ' - , .- PAGEIOF . ~>~;; %~¢ :_.://~-~t~;':;,e-¢/~~¢,F~:.¢~:~ .... ,~,.,.. ............. -~~-;,~ ~e ..... ~n.~,~' ~u~-~:;-,5~ '1~:, ~'.'~,?~l ~ .~ f-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK :.¢~'.:-.,- ;-.;., , .... .., --. ....... Weather / ARRe3P~-O7~I I Temp. t~. °F t Chill Factor J Visibility I-~Wind. Vel. · :" :' "" 50 "F ' l: %~'c~ miles'l"'"~..k,',otsl~~'.,, ~'.,¢~,~ ~-~.':i 298-3486 REMARKS CONTINUED: AOOUM. 8EFWIOE OOMPANY 80A# DAILY ' TOTAL = . ., .. .-- _ . TOTAL FIELD ESTIMATE . ~~~ ' SIGNED KUPARUK PETROLEUM ENGINEERING MORNING REPORT REPORTING: OIL PRODUCED: RWC/DAT/MCV/JTZ 306,766 BBLS DATE: 1/7/94 AMBIENT: r20°F WIND: 9 MPH WIND CHILL: -43°F OIL SHIPPED: 306,766 BBLS 3G-04 REPERF A2 INTERVAL FROM 7754'-7774' W/ 2-1/2" TITAN DP/BH GUN, 4SPF, 180°, 90° CCW. E-LINE TAG FILL 7825' RKB (41' RATHOLE) (SMITH) RECEIVED Anchorage ARCO Alaska, Inc~. ;~ Subsidiary of Atlantic Richfield Comp; WELL IPBDT CONTRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL ~I=HVItJI::: HI=I-'UH I /ooo/ .ao iaao /$$~ /~1~o KUPARUK P~ROLEUM £NGiNEERiNG FEB '1 6 1994 Gas Corls. Commission Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots I Signed ALA~,xA OIL AND GAS CONSERVATION corv,,..iSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well ClassificalJon of Service Well OIL ~ GAS ~ SUSPENDED r~ ABANDONED D SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-131 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20143 4 Location of well at surface 9 Unit or Lease Name ~ ~ .- . ~..-:~.~ 2538' FNL, 295' FWL, SEC 24, T12N, R8E, UM ..... ........ :"'; '~-:' ...... ~: ~']'~ '~-~'~'~ --,.'~'..~TIONS :- ...... KUPARUK RIVER ,: · At Top Producing Interval : ///' .... ~/: )~ I~"FIED 10 Wall Number At Total Depth i ~.~ ~'~? ~! 11 Fie~d and Pool 2206' FNL, 922' FWL, SEC 25, T12N, R83, UM _ _... KUPARUK RIVER FIELD 5 Eleva~on in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 10/30/90. 11/03/90. 1/15/91.I NA feet MSLI 1 17 Total Depth (MD+'rVD) 18 Plug Back Depth (MD+TVD) 119 Direc~onal Survey 20 Depth where SSSV set 21 Thickness of permafrost 8089' MD, 6127' TVD 7975F' MD, 6040' TVD YES [~ NO E~ 1812' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTI~K~ DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 243 SX AS I 9-5/8" 36# J-55 SURF 3795' 12-1/4" 870 SX AS III, 500 SX CLASS G 7" 26# J-55 SURF 8062' 8-1/2" 175 SX CLASS G 24 Perforations open to Production (MD+-FVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7557' 7521' 7754'-7784' W/4-1/2" CSG GUN @ 4SPF MD 5873'-5895' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL IGAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~- FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. "-"~'~/~...Oil.& Gas Cons. · . . - :orm 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 recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7640' 5787' NA KUPARUK C BOT-I'OM 7658' 5800' KUPARUK A TOP 7692' 5826' KUPARUK A BO'T-FOM 7856' 5950' 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_/~.'~ //~ ~~_~ Title AREA DRILLING ENGINEER Date ~x'~ 7/~'J /' /' . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 pedinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil ,..,d Gas Company Well History - Initial Report - Daily instructions: Prepare and submit the "Initial Report" on the first Wednesday alter a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates onJy. District ARCO ALASKA INC. Field KUPARUK RIVER Auth. or W.O. no. AK5091 County. parish or borough NORTH SLOPE ILease or Unit ADL: 25548 ALK: 2662 ITitle COMPLETION IState AK J Well no. 3G%04 Operator ARCO ARCO W I. 55.252072 Prior status if a W.O. Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 01/14/91 ( TD: 0 PB: 7975 SUPV:GB/SK 01/15/91 ( TD: 0 PB: 7975 SUPV:GB/SK 7) IDate 10/30/90 Complete record for each day reported NORDIC 1 IHour 15:30 MOVING WELL 'HOUSE 7"@ 8062' MW:10.6 NaCl/Br MOVE RIG FROM 3G-11 TO 3G-04, ATTEMPT TO SET RIG ON 3G-04, RIG UNABLE TO CLEAR WELL HOUSE, JACK RIG UP TO UPPER LIMIT, UNABLE TO CLEAR, REQUEST CRANE TO REMOVE 3G-05 WELL HOUSE, WAIT ON CRANE DAILY:S21,036 CUM:$596,340 ETD:S596,304 EFC:$1,340,036 ND STACK AND NU TREE 7"@ 8062' MW:10.6 NaCl/Br WAIT ON CRANE TO REMOVE WELL HOUSE ON 3G-05, REMOVE 3G-05 WELL HOUSE, MOVE ON 3G-04, STEAM HEAT WELL HEAD, NU BOPE, TEST BOPE, RU HLS E-LINE, MU GUN #1 AND PERF: 7769'-7784', MU GUN #2 AND PERF:7754'-7769', RD HLS E-LINE, NU RISER AND FLOW LINE, RUN 3-1/2" COMPLETION ASSEMBLY, MAKE UP SSSV AND TEST TO 5000 PSI (OK), CONT RIH WITH COMP ASSEMBLY, MU CIRC JOINT AND DROP BALL, MU TBG HANGER, TEST TO 5000 PSI (OK), SOS BALL NOT SEATED, CYCLE SSSV, PRESS TBG TO 200 PSI, BALL SEATED, DRAIN BOP STACK AND LAND TBG, RILDS, PRESS TBG TO 2500 SPI AND SET PACKER, PRESS ANN TO 1000 PSI, BOLDS, PU AND SHEAR PBR, BLEED PRESS, RELAND TBF AND RILDS, TEST SSSV (OK), PULL LANDING JT, ND BOPE, NU TREE DAILY:S45,165 CUM:$641,505 ETD:S641,505 EFC:$1,340,000 : ':,:W~'a f.)i! & ~;3s Cons. Co!],,rr~issiO~:~ The above is correct ~ Signature ~ ~ For form preparation and distribu~[ion',~ see Procedures Manual, Sectip~ ~0, Drilling, Pages 86 and 87. V Date I Title / Drilling Supt. AR3B-459-1-D Number all daily well history forms conseculively Jas they are prepared for each wel. Page ARCO C_ ~nd Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used tor reporting the entire operation if space is available. I Accounting cost center code District County or Parish JSlate / ARCO ALASKA INC. | AK NORTH SLOPE Lease or Unit Title KRU 3G-04 Well no. KUPARUK RIVER Auth. or W.O. no. AK5091 Operator A.R.Co. W.I. ARCO Date 55.2521 Spudded or W.O. begun SPUD 10/30/90 Date and depth as of 8:00 a.m. 01/16/91 ( TD: 0 PB: 7975 SUPV:GB Complete record for each day reported NORDIC 1 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our ]Prior status if a W.O. I 15:30 RIG RELEASED 7"@ 8062' MW:10.6 NaCl/Br FINISH NU TREE, PULL BPV, SET TP, TEST TREE TO 250/2000 PSI (OK), PULL TP, OPEN SSSV, TEST ANNULUS TO 2500 PSI (OK), SHEAR OUT SOS, BLEED PRES TO 0 PSI, DISPLACE WELL WITH 450' DIESEL, RELEASE RIG DAILY:S120,962 CUM:$762,467 ETD:S762,431 EFC:$1,340,036 Old TD I New TD PB Depth Released rig I Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Producing method Official reservoir name(s) Potential test data _ Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas 2e- :~, Pump.size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Eltec' ... ' corrected The above is correct.,.,.,,, Date For form preparati .... d distriStion, AR3B-459-3-C lNumber all daily well hisfory forms consecutively as they are prepared for each well. Dlvi¢on of Aiii~,,, ~a .... ,. 0 1~ 1 6 ~ 1~ ^ I.. A GyRODATA D~E'''''cIONA ARCO ALASKA !NCORPORATED KUPARUK RIVER UN!T, ~jELL NUHBER 3G-Z~ NORTH SLOPE BoRoUGH, ALASKA. DATE : 06 DECEHBER ~990 GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. KUPARUK RIVER UNIT KRU 3G-4 S,8.37,E ROB SHOUP INC. for Gyrodata Services, Inc. Computation...: SurVey Date...: RKB Elevation.: Job Number .... : API Number .... : 12/05/90 RADIUS OF CURVATURE 11/16/90 90.00 ft AKl190G255 50-103-20143 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 100 0.56 7 200 0.52 7 300 0.93 7 400 4.71 7 500 9.64 VERTICAL-DEPTHS BKB SUB-SEA 100.0 10.0 200.0 ' 110.0 300.0 210.0 399.8 309.8 499.0 409.0 SECTION DIRECTION DISTNCE BEARING 0.3 S 43.94 W 0.9 S 42.00 W 1.8 S 28.38 W 6.2 S 8.16 W 18.1 S 9.73 W RELATIVE-COORDINATES FROM-WELL-HEAD 0.4 S 0.3 W 1.0 S 1.0 W 2.1 S 1.7 W 6.7 S 3.2 W 1.9.1 S 5.2 W CLOSURE DL DISTNCE BEARING /100 0.5 S 43.94 W 0.56 1.4 S 43.30 W 0.04 2.7 S 39.50 W 0.41 7.5 S 25.76 W 3.78 19.7 S 15.22 W 4.93 7 600 12.50 7 700 14.33 7 800 15.92 7 900 18.65 7 1000 22.90 597.2 507.2 694.4 604.4 791.0 701.0 886.4 796.4 979.9 889.9 36.2 S 11.70 W 58.2 S 8.97 W 83.3 S 6.14 W 112.3 S 2.16 W 147.4 S 1.84 E 37.9 S 8.8 W 60.7 S 12.9 W 86.6 S 16.3 W 116.2 S 18.5 W 151.7 S 18.6 W 38.9 S 13.00 W 2.86 62.1 S 12.00 W 1.84 88.1 S 10.69 W 1.60 117.7 S 9.04 W 2.76 152.8 S 6.99 W 4.29 7 1100 27.73 7 1200 30.52 7 1300 31.27 7 1400 32.56 7 1500 35.40 1070.3 980.3 1157.6 1067.6 1243.4 1153.4 1328.3 1238.3 1411.2 1321.2 189.9 S 3.85 E 238.5 S 7.39 E 289.9 S 7.86 E 342.7 S 8.22 E 398.6 S 6.97 E 194.4 S 16.5 W 242.8 S 11.7 W 293.7 S 4.9 W 346.0 S 2.5 E 401.4 S 9.9 E 195.1 S 4.84 W 4.85 243.1 S 2.76 W 2.94 293.7 S 0.95 W 0.76 346.0 S 0.41 E 1.29 401.6 S 1.41 E 2.87 7 1600 37.04 7 1700 39.38 7 1800 43.01 7 1900 48.24 7 2000 51.56 1491.9 1401.9 1570.5 1480.5 1645.7 1555.7 1715.6 1625.6 1780.0 1690.0 457.6 S 5.86 E 519.4 S 5.64 E 585.2 S 6.38 E 656.7 S 7.59 E 733.1 S 9.58 E 460.1 S 16.5 E 521.7 S 22.7 E 587.2 S 29.6 E 658.1 S 38.3 E 733.7 S 49.7 E 460.4 S 2.05 E 1.69 522.2 S 2.49 E 2.34 587.9 S 2.88 E 3.65 659.2 S 3.33 E 5.27 735.4 S 3.87 E 3.54 7 2100 52.39 ~Survey Codes: 1841.6 7/GYRO 1751.6 811.9 S 10.02 E 811.3 S 63.1 E 813.8 S 4.45 E 0.87 (KRU3G4G Bl.17) KRU 3G-4 Page 2 12/05/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 2200 52.02 7 2300 51.59 7 2400 51.84 7 2500 49.92 7 2600 47.72 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 1902.9 1812.9 890.9 S 9.53 E 889.2 S 76.5 E 892.5 S 4.92 E 0.48 1964.7 1874.7 969.5 S 7.70 E 966.9 S 88.3 E 970.9 S 5.22 E 1.20 2026.7 1936.7 1048.0 S 7.45 E 1044.7 S 98.6 E 1049.4 S 5.39 E 0.29 2089.8 1999.8 1125.5 S 5.55 E 1121.8 S 107.4 E 1126.9 S 5.47 E 2.22 2155.6 2065.6 1200.7 S 10.84 E 1196.3 S 118.1 E 1202.1 S 5.64 E 3.64 7 2700 44.50 2225.0 2135.0 1272.7 S 8.98 E 1267.2 S 130.5 E 1273.9 S 5.88 E 3.35 7 2800 43.24 2297.0 2207.0 1342.0 S 8.59 E 1335.7 S 141.1 E 1343.2 S 6.03 E 1.27 7 2900 43.67 2369.6 2279.6 1410.8 'S 9.01 E 1403.7 S 151.6 E 1411.9 S 6.17 E 0.47 7 3000 43.54 2442.0 2352.0 1479.8 S 8.50 E 1471.9 S 162.1 E 1480.8 S 6.29 E 0.27 7 3100 43.67 2514.5 2424.5 1548.8 S 7.79 E 1540.1 S 171.9 E 1549.7 S 6.37 E 0.36 7 3200 43.90 2586.7 2496.7 1617.9 S 7.75 E 1608.7 S 181.3 E 1618.9 S 6.43 E 0.23 7 3300 43.82 2658.8 2568.8 1687.2 S 7.22 E 1677.4 S 190.3 E 1688.2 S 6.47 E 0.27 7 3400 43.69 2731.0 2641.0 1756.4 S 6.08 E 1746.1 S 198.3 E 1757.3 S 6.48 E 0.56 7 3500 43.45 2803.4 2713.4 1825.2 S 6.53 E 1814.6 S 205.9 E 1826.2 S 6.47 E 0.32 7 3600 43.53 2876.0 2786.0 1894.0 S 6.58 E 1883.0 S 213.7 E 1895.1 S 6.48 E 0.08 7 3700 43.49 2948.5 2858.5 1962.8 S 6.33 E 1951.4 S 221.5 E 1963.9 S 6.47 E 0.12 7 3800 42.67 3021.6 2931.6 2031.0 S 3.68 E 2019.4 S 227.4 E 2032.2 S 6.43 E 1.47 7 3900 42.85 3095.0 3005.0 2098.8 S 5.82 E 2087.1 S 233.0 E 2100.0 S 6.37 E 1.01 7 4000 42.96 3168.2 3078.2 2166.8 S 5.79 E 2154.8 S 239.9 E 2168.1 S 6.35 E 0.11 7 4100 42.81 3241.5 3151.5 2234.8 S 6.13 E 2222.5 S 247.0 E 2236.2 S 6.34 E 0.22 7 4200 42.82 3314.8 3224.8 2302.7 S 6.29 E 2290.0 S 254.3 E 2304.1 S 6.34 E 0.07 7 4300 44.11 3387.4 3297.4 2371.4 S 7.51 E 2358.3 S 262.6 E 2372.9 S 6.35 E 1.42 7 4400 45.14 3458.6 3368.6 2441.7 S 9.43 E 2427.8 S 273.0 E 2443.1 S 6.41 E 1.41 7 4500 45.14 3529.1 3439.1 2512.5 S 10.67 E 2497.6 S 285.3 E 2513.9 S 6.52 E 0.62 7 4600 45.02 3599.7 3509.7 2583.3 S 9.77 E 2567.3 S 297.9 E 2584.5 S 6.62 E 0.47 7 4800 44.90 3741.3 3651.3 2724.6 S 9.72 E 2706.6 S 321.8 E 2725.6 S 6.78 E 0.06 'Survey Codes: 7/GYRO KRU 3G-4 Page 3 12/05/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 4900 45.26 7 5000 45.58 7 5100 45.41 7 5200 45.46 7 5300 44.94 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 3811.9 3721.9 2795.4 S 10.07 E 2776.3 S 334.0 E 2796.3 S 6.86 E 0.40 3882.1 3792.1 2866.6 S 9.09 E 2846.6 S 345.8 E 2867.5 S 6.93 E 0.59 3952.2 3862.2 2937.9 S 9.34 E 2917.0 S 357.3 E 2938.8 S 6.98 E 0.21 4022.3 3932.3 3009.1 S 9.63 E 2987.2 S 369.0 E 3009.9 S 7.04 E 0.16 4092.8 4002.8 3080.1 S 8.91 E 3057.3 S 380.4 E 3080.8 S 7.09 E 0.63 7 5400 44.83 4163.7 4073.7 3150.6 S 8.24 E 3127.0 S 390.9 E 3151.4 S 7.13 E 0.35 7 5500 44.78 4234.6 4144.6 3221.1 S 8.34 E 3196.8 S 401.1 E 3221.8 S 7.15 E 0.07 7 5600 44.73 4305.6 4215.6 3291.5 S 8.35 E 3266.4 S 411.3 E 3292.2 S 7.18 E 0.05 7 5700 44.68 4376.7 4286.7 3361.9 S 9.14 E 3336.0 S 422.0 E 3362.6 S 7.21 E 0.39 7 5800 44.69 4447.8 4357.8 3432.2 S 6.40 E 3405.6 S 431.5 E 3432.9 S 7.22 E 1.36 7 5900 44.63 4518.9 4428.9 3502.4 S 6.60 E 3475.5 S 439.5 E 3503.1 S 7.21 E 0.12 7 6000 44.48 4590.2 4500.2 3572.6 S 6,77 E 3545.2 S 447.7 E 3573.3 S 7.20 E 0.17 7 6100 44.33 4661.6 4571.6 3642.5 S 7.24 E 3614.6 S 456.2 E 3643.3 S 7.19 E 0.27 7 6200 43.92 4733.4 4643.4 3712.1 S 5.63 E 3683.8 S 464.0 E 3712.9 S 7.18 E 0.88 7 6300 43.84 4805.5 4715.5 3781.3 S 6.16 E 3752.7 S 471.1 E 3782.2 S 7.16 E 0.27 7 6400 43.88 4877.6 4787.6 3850.6 S 6.01 E 3821.6 S 478.5 E 3851.5 S 7.14 E 0.08 7 6500 43.70 4949.8 4859.8 3919.7 S 6.82 E 3890.4 S 486.2 E 3920.7 S 7.12 E 0.43 7 6600 43.69 5022.1 4932.1 3988.8 S 7.38 E 3959.0 S 494.7 E 3989.7 S 7.12 E 0.27 7 6700 43.87 5094.3 5004.3 4058.0 S 7.62 E 4027.6 S 503.8 E 4058.9 S 7.13 E 0.21 7 6800 42.93 5166.9 5076.9 4126.7 S 6.76 E 4095.7 S 512.4 E 4127.6 S 7.13 E 1.02 7 6900 42.64 5240.3 5150.3 4194.6 S 6.50 E 4163.2 S 520.2 E 4195.6 S 7.12 E 0.31 7 7000 42.80 5313.8 5223.8 4262.4 S 6.88 E 4230.6 S 528.1 E 4263.4 S 7.12 E 0.24 7 7100 42.87 5387.1 5297.1 4330.4 S 6.96 E 4298.1 S 536.3 E 4331.4 S 7.11 E 0.08 7 7200 43.15 5460.2 5370.2 4398.6 S 7.59 E 4365.7 S 544.9 E 4399.6 S 7.11 E 0.41 7 7300 43.51 5533.0 5443.0 4467.2 S 7.85 E 4433.7 S 554.1 E 4468.2 S 7.12 E 0.38 7 7400 41.84 5606.5 5516.5 4534.9 S 7.38 E 4500.9 S 563.1 E 4536.0 S 7.13 E 1.68 ASurvey Codes: 7/GYRO KRU 3G-4 S MEAS INCLN C DEPTH ANGLE 7 7500 41.35 7 7600 41.04 7 7700 41.10 7 7800 40.99 7 7900 40.54 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5681.3 5591.3 4601.3 5756.5 5666.5 4667.2 5831.9 5741.9 4732.9 5907.3 5817.3 4798.5 5983.1 5893.1 4863.8 7 7968 40.60 6034.7 5944.7 X 8089 40.60 6126.6 6036.6 4908.1 4986.8 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 7.30 E 4566.7 S 571.6 E S 8.27 E 4632.0 S 580.5 E S 7.84 E 4697.1 $ 589.7 E S 8.35 E 4762.1 S 599.0 E S 8.50 E 4826.7 S 608.6 E S 8.60 E S 8.60 E 4870.4 S 615.1 E 4948.2 S 626.9 E Page 4 12/o5/90 CLOSURE DISTNCE BEARING 4602.4 S 7.13 E 4668.2 S 7.14 E 4733.9 S 7.16 E 4799.6 S 7.17 E 4864.9 S 7.19 E 4909.1 S 7.20 E 4987.8 S 7.22 E DL /lOO 0.49 0.52 0.20 0.25 0.45 0.11 0.00 ASurvey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-4 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 5 12/05/90 SUBSEA DEPTH 0 100 200 300 400 5OO 600 7OO 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 MEAS DEPTH 90 190 290 390 491 593 695 799 904 1011 1122 1238 1355 1474 1598 1725 1862 2016 2179 2341 25OO 2650 2790 2928 3066 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 0.50 90 0 0 S 43.94 W 0.52 190 0 0 S 42.19 W 0.89 290 0 0 S 29.74 W 4.34 390 0 0 S 10.16 W 9.19 490 1 1 S 9.59 W 12.29 590 3 2 S 11.56 W 14.25 690 5 3 S 9.09 W 15.90 790 9 4 S 6.17 W 18.81 890 14 5 S 2.01 W 23.43 990 21 7 S 2.06 E 28.35 1090 32 11 S 4.64 E 30.80 1190 48 15 S 7.57 E 31.98 1290 65 17 S 8.06 E 34.66 1390 84 19 S 7.29 E 37.00 1490 108 24 S 5.89 E 40.30 1590 135 28 S 5.83 E 46.27 1690 172 37 S 7.13 E 51.69 1790 226 54 S 9.65 E 52.10 1890 289 63 S 9.63 E 51.69 1990 351 62 S 7.60 E 49.91 2090 410 60 S 5.57 E 46.10 2190 460 50 S 9.90 E 43.36 2290 500 40 S 8.63 E 43.63 2390 538 38 S 8.87 E 43.63 2490 576 38 S 8.03 E RELATIVE COORDINATES FROM WELL HEAD 0.29 S 0.27 W 0.97 S 0.92 W 1.94 S 1.63 W 5.96 S 3.07 W 17.58 S 4.94 W 36.37 S 8.44 W 59.62 S 12.74 W 86.33 S 16.32 W 117.43 S 18.54 W 155.99 S 18.45 W 204.85 S 15.70 W 261.82 S 9.21 W 322.08 S 0.93 W 386.66 S 8.03 E 458.71 S 16.34 E 537.89 S 24.31 E 630.60 S 34.72 E 746.13 S 51.79 E 872.88 S 73.75 E 998.54 S 92.53 E 1122.04 S 107.43 E 1232.40 S 124.75 E 1329.17 S 140,12 E 1422.89 S 154.66 E 1517.03 S 168.70 E 2500 3205 43.90 2590 615 38 S 7.73 E 1611.89 S 181.70 E KRU 3G-4 DATA INTERPOLATED FOR 100 Page FT SUBSEA INTERVAL 6 12/05/90 SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 MEAS DEPTH 3343 3481 3619 3757 3893 4030 4166 4304 4445 4586 4728 4869 5011 5154 5296 5437 5578 5719 5859 6000 6140 6279 6417 6556 6694 INCLN TVD MD-TVD VERT ANGLE BKB DIFF CRRT 43.76 2690 653 43.49 2790 691 43.52 2890 729 43.02 2990 767 42.84 3090 803 42.92 3190 840 42.82 3290 876 44.15 3390 914 45.14 3490 955 45.04 3590 996 44.94 3690 1038 45.15 3790 1079 45.56 3890 1121 45.44 3990 1164 44.96 4090 1206 44.81 4190 1247 44.74 4290 1288 44.68 4390 1329 44.65 4490 1369 44.48 4590 1410 44.17 4690 1450 43.86 4790 1489 43.85 4890 1527 43.69 4990 1566 43.86 5090 1604 DIRECTION BEARING 39 S 6.73 E 38 S 6.45 E 38 S 6.53 E 38 S 4.82 E 36 S 5.67 E 37 S 5.89 E 36 S 6.24 E 37 S 7.58 E 41 $ 9.98 E 42 S 9.89 E 41 S 9.74 E 41 S 9.96 E 42 S 9.12 E 43 S 9.50 E 42 S 8.94 E 41 S 8.28 E 41 S 8.35 E 41 $ 8.63 E 41 S 6.52 E 40 $ 6.77 E 40 S 6.60 E 39 S 6.05 E 39 S 6.15 E 38 S 7.13 E 38 S 7.61 E RELATIVE COORDINATES FROM WELL HEAD 1707.13 1801.93 1896.19 1990.23 2082.48 193.93 E 204.43 E 215.24 E 225.26 E 232.58 E 2174.96 S 241.99 E 2267.16 S 251.84 E 2360.81 S 262.94 E 2458.92 S 278.28 E 2557.68 S 296.23 E 2656.18 S 313.17 E 2754.63 S 330.15 E 2854.55 S 347.11E 2954.84 S 363.54 E 3054.50 S 379.99 E 3152.95 S 394.71E 3251.13 S 409.08 E 3348.97 S 424.05 E 3447.10 S 436.22 E 3544.98 S 447.63 E 3642.05 S 459.52 E 3737.95 S 469.53 E 3833.50 S 479.72 E 3928.56 S 490.85 E 4023.48 S 503.21E 5100 6831 42.84 5190 1641 37 S 6.68 E 4117.00 S 514.86 E KRU 3G-4 SUBSEA DEPTH 5200 5300 5400 5500 5600 57OO 5800 5900 6000 MEAS DEPTH 6968 7104 7241 7378 7512 7644 7777 7909 8041 Page 7 12/05/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 42.75 5290 1678 36 S 6.'76 E 42.88 5390 1714 36 S 6.98 E 43.30 5490 1751 37 S 7.70 E 42.21 5590 1788 37 S 7.48 E 41.31 5690 1822 34 S 7.41 E 4208.72 S 525.49 E 4300.72 S 536.62 E 4393.44 S 548.65 E 4486.16 S 561.21E 4574.35 S 572.59 E 41.07 5790 1854 33 S 8.08 E 41.02 5890 1887 33 S 8.23 E 40.55 5990 1919 32 S 8.51 E 40.60 6090 1951 32 S 8.60 E 4660.85 S 584.68 E 4747.14 S 596.81 E 4832.51 S 609.43 E 4917.22 S 622.21 E KRU 3G-4 Page 8 12/05/90 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 22.90 980 890 147 S 1.84 E 152 S 2000 51.56 1780 1690 733 S 9.58 E 734 S 3000 43.54 2442 2352 1480 S 8.50 E 1472 S 4000 42.96 3168 3078 2167 S 5.79 E 2155 S 5000 45.58 3882 3792 2867 S 9.09 E 2847 S DL/ 100 19 W 153 S 6.99 W 4.3 50 E 735 S 3.87 E 3.5 162 E 1481 S 6.29 E 0.3 240 E 2168 S 6.35 E 0.1 346 E 2867 S 6.93 E 0.6 6000 44.48 4590 4500 3573 S 6.77 E 3545 7000 42.80 5314 5224 4262 S 6.88 E 4231 8000 40.60 6059 5969 4929 S 8.60 E 4891 448 E 3573 S 7.20 E 0.2 528 E 4263 S 7.12 E 0.2 618 E 4930 S 7.20 E 0.0 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 12/05/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-4 Section at: S,8.37,E Surveyor..: ROB SHOUP Computation...: RADIUS OF CURVATURE Survey Date...' 11/16/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G255 API Number .... : 50-103-20143 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 295 EWL S24 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING PROJECTED TD MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES . DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 0 0.00 0 -90 0 N 0.00 E 0 N 3794 42.72 3017 2927 2027 S 3.84 E 2015 S 7640 41.06 5787 5697 4693 S 8.10 E 4658 S 7658 41.07 5800 5710 4705 S 8.02 E 4670 S 7692 41.10 5826 5736 4728 S 7.87 E 4692 S 0 E 227 E 584 E 586 E 589 E 7856 40.74 5950 5860 4835 S 8.43 E 4798 S 8062 40.60 6106 6016 4969 S 8.60 E 4931 S 8089 40.60 6127 6037 4987 S 8.60 E 4948 S 604 E 624 E 627 E <KB>O 500 1000 2000 2500 3000 3500 4000 4500 5OOO 55OO 6000 6500 7000 7500 8000 85O0 9000 500 VERTICAL SECTION VIEW j~ .,, 'f L.- I I I ..L L~ ~k'~ I..- ,,._~ L-. L~ I .,L, t~l I ~ V .L L_ffl ARCO ALASKA, INC. KRU 3G-4 i Sect ion at: S B.37 E TVD Scale.' 1 inch = 1000 feet I Dep Scale.' 1 irlch = t000 feet Warker Identification ND TVD SECTN A) KB 0 0 0 B) PROJECTED TD 8089 6t27 4967 .,. i ..... INCLN 0.00 40.60 1 0 500 lO00 i500 2000 2500 3000 3500 4000 4500 5000 Section Departure -I S?£ab Lan: L~ins£tionsl L~nilling, £n£. Marker Iden~ificabion MO N/S A) KB 0 0 N 0 E B) PROJECTED TO 8089 4948 S 827 E PLAN VIEW ARCO ALASKA, INC. KRU 36-4 CLOSURE ..... : 4988 ft S 7.22 E DECLINATION.: 0.00 E SCALE ....... : 1 inch = 800 feet DRAWN ....... : 12/05/90 4OO 0 40O BOO i~o0 16o0 2000 2400 2800 3200 3600 4000 4400 4800 520O 400 0 400 <- NEST · EAST -> .- .. i .___ 800 t200 i600 2000 2400 2800 3200 3600 4000 4400 COMPLETION DA~ ..... _"__'-"'__" _': ....k4ATERiALS iNYENTORY LiST RUL'~ t~U1 Ui'.li..,AL . / ! / ~' ] ~/ CO, CONTACT check off or li~t data as it is received.*list received date for 407. if cored inte~als j .0,~ ~n~,y~i~ 1! d~ ditch intc~als ',,1 I ' ! L nr~ rune uit_'.l ! i I-L i,, S C'Al E' I~P, LL [inchl! O0'l , i ARCO Alaska, inc. Date: February 4, 1991 Transmittal #: 8000 RETURNTO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. Please acknowledge receipt and return one 3 G-0 .9~ Pulse Echo Cement Evaluation Log 10- 3 G'24~ Pulse Echo Cement Evaluation Log I 1 - 3 G- 04K' ~ Pulse Echo Cement Evaluation Log I 1 - 3 G-15'-/~ Pulse Echo Cement Evaluation Log I 1 - 3 G- 2/'2,.X?j Pulse Echo Cement Evaluation Log I 1 - - 3 G- 21 ~ Pulse Echo Cement Evaluation Log '-- 1 1 - 3 G - 04:~, Acoustic Cement Bond Log I 1 - 3 G - 22~ Acoustic Cement Bond Log I 1 - 1 L- 2 2 ~,, Squeeze Record 1- 2 Receipt Acknowledge' Drilling -. 3-90 5229-9682 15-90 6698-9704 16-90 4900-7939 14-90 4500-7815 18-90 6600-9595 23-90 -" 8466-11~513 16-90 4892-7962 18-90 6600-9616 0-91 9200-9800 ~'~-'~------'-- Date' State of Alaska ,-Eiv'E.D FE~ 5 199! Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 21, 1990 Transmittal #: 7964 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-4 1A-19 Receipt LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 12-14-90 AKRBg01048 "~q 7"~ q 12-1 4-90 AKMM901251 Date' - ......... Acknowledged' DISTRIBUTION: Lynn Goettinger State ~~la~ka RECEIVED DEC 2 7 1990 Alaska 011 & ea~ Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 21, 1990 Transmittal #: 7963 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. v"3G-4 Dual Gamma Ray-Compensated 1 1 -3- 90 3738-8089 Neutron Porosity-Simultaneous Formation Density /1 L- 1 2 Dual Induction-SFL (5" Phasor) 1 2- 1 3 - 9 0 0 - 8 0 8 9 ,/1 L-1 2 Compensated Neutron-Litho- 1 2-1 3-90 7250-8065 Density (Porosity) v"l L-1 2 Compensated Neutron-Litho- 12-13-90 7250-8065 Density (Raw Data) ~'1L-12 Cyberlook 12-13-90 7250-8050 v' 1 L- 1 2 Repeat Formation Tester 1 2 - 1 3 - 9 0 74 73 - 790 0 v/I L- 1 2 Dual Induction-SFL (2" Phasor) 1 2-1 3 - 9 0 0- 8 0 8 9 ,/1A-19 Dual Gamma Ray-Electromagnetic 12-1 1-90 6950-7948 Wave Resistivity-Formation Exposure Time v' 1 A- 1 9 Dual Gamma Ray-Compensated 1 2 - 1 1 - 90 6 95 0- 794 8 Neutron Porosity-Simultaneous Formation Density Receipt Acknowledged: ~--J-~---Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) RECEIVED D£C 2 7 1990 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 7, 1990 Transmittal #: 7954 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-4 3G-21 1A-17 1A-17 LIS Tape and Usting LIS Tape and Listing LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return Receipt 11-27-90 1 1-30-90 12-4-90 12-4-90 Acknowledged: AKRB901048 ~'"~ / ~" AKRB901149 7569-8430 1 23-8590 Date: .......... DISTRIBUTION: Lynn Goettinger State~6f Alaska ,-EIVED DEC 1 2 1990 Alaska Oil & ?s Cons, CommisSion Anchorage ARCO Alaska, Inc. Date' December 7, 1990 Transmittal #: 7947 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following Open hole items. and return one signed copy of this transmittal. xJ'3G-04 ~3G-04 ',/3G-21 3G-21 A-17 A-17 ~A-17 1A-17 ~1A-17 M/1A-17 Receipt Please acknowledge receipt Dual Gamma Ray Compensated I 1 - 3 - 9 0 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 1 1 - 3 - 9 0 Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated 1 1 - 1 6 - 9 0 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic I 1 -1 6- 9 0 Wave Resistivity Formation Exposure Time High Resolution Induction DFL 2" I 1 - 2 4 - 9 0 Spectral Density DSN II Log/Raw 1 1 - 2 4 - 9 0 Data w/High Resolution High Resolution Induction Raw X 1 1 - 2 4 - 9 0 and Raw R Spectral Density DSN Log Porosities 11-24-90 w/ High Resolution Microlog 5" and 10" 1 I - 2 4 - 9 0 High Resolution Induction DF.L 5" 1 1 ' 2 4 - 9 0 Acknowledged: -~'?-~-~-/~- - -~-~-~ .... Date' 3738-8089 3738-8089 3888-11698 3888-1 1698 0-8512 4550-8512 0-8512 4550-8512 7600-8490 0-8512 DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown X Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, In(:. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 295 ' FWL,SEC 24,T12N,RSE,UM At top of productive interval 1950' Fnl, 985" FEL, Sec. 25, T12N, R8E, UM At effective depth NA At total depth 2223'FNL, 1025' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 8 08 7 (approx) true vertical 6114 Effective depth: measured NA (approx) true vertical NA Casing Length Size Structural Conductor 8 0' 1 6" Surface 3760 ' 9 5/8" Intermediate Production 8027 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 5. Type of Well: Development X. Exploratory _ Stratigraphic _ Service (approx) (approx) 6. Datum elevation (DF or KB) RKB 90' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-4 9. Permit number 90-131 10. APl number 50-103-20143 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet feet Junk (measured) feet Cemented 243 SX AS II 870 Sx AS III & 500Sx Class G 175Sx class G Measured depth True vertical depth 1 1 5' 115'approx. 3795' 3013 approx) '8062' 6095 (approx) RE6EiVED D EO - 4 1990 Alaska_0il & Gas Cons. C0m~[Ss[0[t. . _~. ._. Anchorage 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation January, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification Oil , X Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /,~. ~,C/), ~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Date / / Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance M Mechanical Integrity Test _ Subsequent form require 10- IApproval No. Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL 81GNEO ElY LONNIE C Approved Co~y Returned SUBMIT IN TRIPLICATE ARC~.-.~ii ,.,,d Gas Company g~, Well History - Initial Report- Daily Instructions: Prepare and submit the "llfllill R~porl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER Auth. or W.O. no. AK5091 County, parish or borough NORTH SLOPE Itease or Unit ADL 25548 ALK 2662 ITitle DRILLING IState AK Well no. 3G-04 Operator ARCO Spudded or W.O. begun ARCO W.I. 55.2521 SPUD Date and depth as of 8:00 a.m. 10/31/90 (1) TD: 2531'(2531) SUPV:JMM 11/01/90 (2) TD: 3820'(1289) SUPV:PDW 11/02/90 (3) TD: 5873'(2053) SUPV:PDW 11/03/90 (4) TD: 7621' (1748) SUPV:PDW 11/04/90 (5) TD: 8087'( 466) SUPV:PDW Complete record for each day reposed DOYON 14 DRILLING @ 2531 MW: 9.1 VIS: 67 MOVE RIG FROM 3G-22 TO 3G-4. NU DIVERTER, MU aHA, SPUD 3G-4 AT 15:30 30-OCT. DRILL FROM 115' TO 2531' DAILY:S58,859 CUM:$58,859 ETD:S58,859 EFC:$1,340,000 RD DIVERTER 9-5/8"@ 3794' MW: 9.7 VIS: 59 DRILL FROM 2531' TO 3820'. WIPER TRIP, POOH, RUN 87 JTS OF 9-5/8", 36#, J-55, BTC CASING TO 3794' CEMENT WITH DOWELL: 870 SX ASIII LEAD CEMENT, 500 SX CLASS G TAIL CEMENT 15.8 PPG WITH 2% SI, .2% D46, .25% D29. DISPLACE WITH 287 BBLS , BUMP PLUG TO 2500 PSI, CIP @ 05:10 HRS 01-NOV. RD DIVERTER. DAILY:S116,659 CUM:$175,518 ETD:S175,518 EFC:$1,340,000 DRILLING AT 5873' 9-5/8"@ 3794' MW: 9.5 VIS: 39 NU BOPE, TEST SAME. MU BHA INCL RLL, RIH. TEST CASING TO 2000 PSI, DRILL FLOAT SHOE PLUS 10' OF FORMATION. TEST SHOE TO 12.7 EMW. DRILL WITH TURBINE TO 5873'. DAILY:S154,558 CUM:$330,076 ETD:S330,076 EFC:$1,340,000 DRILLING @ 7621' 9-5/8"@ 3794' MW:10.6 VIS: 42 DRILL FROM 5873' TO 7312'. POH TO 9-5/8" SHOE AND PERFORM LOT TO 11.3 F/v/W, OK. REAM FROM 7248'- 7312', DRILL FROM ~f TO 7621'. i 3-~:$60,835 CUM:$390,911 ETD:S390,911 EFC:$1,340,000 '?~..i~DP---~ 9-s/8-@ 3794, MW:lO.6 vis: 4o DRILL FROM 7621' TO 8087'. POOH, UNLOAD RLL LOGS. RIH WITH MILL TOOTH BIT, WIPER TRIP TO TD. POOH LDDP. DAILY:S56,045 CUM:$446,956 ETD:S446,956 EFC:$1,340,000 RE( EIVED D E 0 - 4 Alaska 0il & Gas Cons. O0mmisSlor~ Anchorage Signature ~. ~ For form preparetion-an~distribution, see Procedures Manyal,~:)ection 10, ~ Drilling, Pages 86 an~. AR3B-459-1-D INumber all daily wall history forms consecutively as they are prepared for each well. iPsge no. ARC., G..and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filial R~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted _el~:l:k~Jeta~ons are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report comJ~. ~0~:. ahcl representative test data in blocks provided. The "Final Report" term may be used for reporting the entire operation if space is available. I Accounting cost center code :":: County or Parish ITM NORTH SLOPE J AK We!l no. Field Lease or Unit KUPARUK RIVER m,tle' ADL 25548 ALK 2662 3G-04 Auth. or W.O. no. AK5091 J DRILLING cost center prior to plugging and ARCO Date 55.2521 abandonment of this well Spudded or W.O, begun Hour Prior status if a W,O. SPUD 10/30/90 15:30 District ARCO ALASKA INC. Date and depth as of 8:00 a.m. 11/05/90 ( 6) TD: 8087' ( 0) SUPV: PDW Complete record for each day reported DOYON 14 RIG RELEASED 02:00 HRS 7"@ 8062' MW:10.6 VIS: 0 LDDP, RUN 187 JTS 7", 26#, J-55. LOST RETURNS 6000' OFF BOTTOM, DID NOT REGAIN RETURNS. PUMPED 10 BBL ARCO PRE-FLUSH, 35 BBL ARCO SPACER, 175 SX CLASS G CEMENT, DISPLACED WITH 360 BBL 10.6 BRINE. BUMPED PLUG TO 3000 PSI HELD OK. ND BOP, SET CSG SLIPS, INSTALL AND TEST TREE. PUMP 71 BBL DIESEL DOWN ANNULUS TO FREEZE PROTECT. RIG RELEASED AT 02:00 HRS 05-NOV-90. MOVING TO 3G-21. DAILY:S128,348 CUM:$575,304 ETD:S575,304 EFC:$1,340,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD Date PB Depth Kind of rig JType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per Jay Pump size, SPM X length iChoke size T.P. C.P. Water % GOR Gravity Allowable EIlect:..-~ corrected The above is correct Signatur "'~_~.~ /~r~~ Date/, For form preparation ~ distribution, ~ see Procedures Manual, Section 10, u-~ Drilling, Pages 86 and 87, AR3B-459-3-C i as they are prepared for each well. Alaska Oil & Gas Cons. Corn s .umb., e,, da,,y Anchorage o,v,,o, o, TO: THRU: FROM: MEMORANoU'M State of Alaska ALASKA OIL AND GAS COI~SERVATION CO}~ISSION Lonnie C. Sm~j?/ DATE: November 7, 1990 Come_is s ioner / FILE NO: JT.HH. 117.5 TELEPHONE NO: Harold R. Hawkins Petroleum Inspector SUBJECT: RIG/BOPE inspectiop.. AAI KRU 3G-4 Permit .~Io. 90-131 Kuparuk Rv Field Wednesd~ October 31, 1990: I inspected AAI KRU 3G-4 RIG/BOPE inspection on Dovon K_g 1-4'. ~ zound no problems with BOPE from the cellar to the rig floor but ! did find diverter system incorrect. The 10" diverter line had a target installed for the wro~g direction of flow. Also the diverter line was short to pit and was not bifurgated and without two valve and I0" line to divert flow. ~nursda November _ o ~.~: ~_~_ ~, 1970: I talked to Paul ~%ite, AAI company man, =~ou~ t.,~s. ..e in%ormea me along with Louis Grimaldi that the~e infractions would be remedied before the next hole drilled. The Doyon too!pusher said school would, be held with crews on diverter systems. Last BOP test performed was on 10/25/90. No fai].ures. In sun~nary: The RIG/BOPE inspection was~satisfactory. 02-00lA (Rev. 6/89) 20/1UMEMO1,PM3 September 26, 1990 Telecopy.. (907)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3G-04 ARCO Alaska, Inc. Permit No. 90-131 Sur. Loc. 2538'F~L, 295'~qL, Sec. 24, T!2N, RSE, Btmho!e Loc. 2223'F~, t025'F%IL, Sec. 25, T12N, RSE, TjM. 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 pe~its required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincere] v Commi s s ioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO}-~ISSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enclo l--~_. STATE OF ALASKA .... Ab A OIL AND GAS CONSERVATION COMi, ON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill ;~ Redrill -- I lb. Type of Well Exploratory.,.__ Stratigraphic Test _ Development Oil Re-Entry ~ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 90'. Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location et well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 295' FWL, Sec. 24, T12N, R8E, UM Kuoaruk River Unit At top of productive interval (TARGET) 8. Well number Number 1950' FNL, 985' FWL, Sec. 25, T12N, R8E, UM 3G-04 #U630610 At total depth 9. Approximate spud date Amount 2223' FNL, 1025' FWL, Sec 25, T12N, R8E, UM 01-OCT-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-05 8101' MD 2223' ~ TD feet 25' at surface feet 2560 6103' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300' feet Maximum hole anc, lle 45° Maximum su~ace 1840 psi~ At total depth(TVD) 3400 psicj @ 6103' '18. Casing program Setting Depth .. size Specification Top Bottom Quantity of cement Hole Casing Weight Grade couplin~l Length IVD 'I'VD IVD 'I'VD linclude sta~le dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+_200 Cu. Ft. 12.25 9.625" 36.0# J-55 BTC 3830' 35' 35' 3865' 31 10 1685 Cu. Ft. AS III & HF-ERW 570 Cu. Ft. Class G 8.5 7" 26.0#1J-55 AB-MO[ 4064' 35' 35' 4099' 3275 200Cu. Ft. ClassG 8.5 7" 26.0#1J-55 BTC 4002' 4099' 3275' 8101' 6103 Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured deplh True ~..?tLc~al ~_~c[ej~J~h~ ~ i t--, t- Structural RI: I:IV L Conductor Cu. R, Surface Cu. Ft. Intermediate ProductionSEP 2 0 1990 Liner Perforation depth: measuredAlasl~a 0il & Gas Cons. 60mm'tss't0o true verticalAnchorage 20. Attachments Filing fee .~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program .~. Drilling fluid program X Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I here~oy certify that the foregoing is true and correct to the best of my knowledge Signed //~,~~~ ;~ Title Area Drilling Engineer Date -' / ' Commission Use Only ' I Permit~c)NUmber~ ,,,~// I APl50. number/~ ~---- ~:~"'"~'~-~ I Approval date0 C~ /26/C~0 ! See cover letter for .- ~ other recluirements Conditions of approval Samples required ~Y e s .~ N o Mud log required~ Y e s ,'~ N o Hydrogen sulfide measures~ Y e s .,~ N o Directional survey required ,,z~'Yes ~ N o Required working pressure for BOPE 2M; .~ 3._~; ~ 5 M' 1 0 M' 1 5 M Other:_.~/~ --?~ '~'~~/'¢~~.~,~ -- -- - ~ by order of ¢~ 2 Approved by (~ ......~ Commissioner the commission Date Form 10-40t Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-04) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.6-10.0 8.6-9.3 10.7 PV 15-35 5-1 5 10-1 8 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-1 2 8-1 0 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators REEEIVED SEP ?-0 1990 Alaska Oil & Gas Cons. Comm'tss'tof' ;Anchorage Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 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 1850 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3G-04 will be 3G-05. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Inc. Pad 3G, Well No: 4 Propoeed Kuparuk Field, Nor*h Slope, Alaeke 1000 2000 RKB ELEVATION~ 90' t KOP TVD=300 TMD=300 DEP=O 15 BUILD 3 DEG 2l PER I00 FT 27' 33 39 B/ PERMAFROST TVD=1605 TMD=17;37 DEP=515 4.5 EOC TYD=16.51 THD=1801 DEP=560 T/ UGNU SNDS TYD=1775 TMD=1976 DEP=684 rn ;3000 ~ 4000 T/ W SAK SNDS TVD=2420 THD=2889 DEP=1330 B/ W SAK SNDS TVD=2910 TMD=3582 DEP=1821 9 5/8" CSG PT TVD=3110 TMD=3865 DEP=2021 K-lO TVD=3270 TMD=4092 DEP=2181 K-5 TVD=4470 THD=5790 5000 AVERAGE ANGLE 45 DEG 2 HI N 6000 _ 7000 _ TARGET - T/ ZONE C TVD=5828 TMD=7712 DEP=4742 ,_ T/ ZONE A TVD=5845 TMD=77;36 DEP=4759.. % ". B/ KUP SNDS TVD=5962 THD=T901 DEP=4877 ~ TD / LOG PT TVD=6103 TMD=8101 DEP=5018 I I I I 0 1000 2000 ;3000 4000 · VERTICAL SECTION I 5000 I 60OO HOR~~ ..... ONTAL PROdECTI ON SdALE 1 IN. = 1000 FEET 1000 SURFACE LOCAT ! ON' 2538' FNL. 295' FWL SEC. 24. T I2N. R8E m 1000 _ , 2000 _ 3000 _ TARGET TVD=5828 TMD=T?12 DEP=4742 SOUTH 4692 EAST 690 4000 _ 5000 _ TARGET LOCAT[O#, 1950' FNL. 985' FUt. SEC. 25. T12N. RSE ARCO ALASKA. I.e. Pad 3G. Well No' 4 Proposed Kuparuk Field, North Slope, Alaska WEST-EAST 2000 1000 0 1000 ! I 2000 I SURFACE TD LOCATION, 2223' FNL. 1025' Fl/I. SEC. 25. TI2N. RSE S 8 DEG 22 MI N E 4742' (TO TARGET) 50 _ ~ 50 _ 100 _ 150 _ 200 _ 250 . 300 _ 350 _ 1 50 1 O0 ! 500 5O 700 900 1100 150 i 100 O0 3OO 1100 5O 100 100 I r 3OO 3OO 1 $00 1300 ~ 700 O0 700 i ;00 o0 I I '~900 I ~ 100 J ~ ~500 I i 1300 I ! 5O 150 I 0 50 1 O0 1 50 _ 5O .0 _ 5O lO0 _ 150 200 250 300 350 5O lO0 I 150 ,I 2OO I 25O I 3OO I. 700 750 8OO 850 9O0 950 1000 1050 1100 1900 20OO 2000 ~ 2100 % 2100 .700 _ 75O _ 8OO .850 _ 9OO _ 950 .1 000 1050 I100 0 50 100 150 200 250 300 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD , . . , , , , . . 10 11 12 13 14 15 16 17. 18. 19. 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point 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. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. 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. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. ~.JPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 I 5 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"-2000 PSI DRILLING SPOOLWlTH TWO 10" OUTLETS. 5. 10" 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. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 5 4 I I · 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL 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 PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS Company ~fC~ Lease & Well No. ITEM APPROVE DATE YES NO (1) Fe__~e , ,~z", , .,~//~~ 1. Is the permit fee attached .......................................... ~ ~ Lo,c (2 thru (3) Admin ~p/ ~ 9. · (~ ~hru~ 10. (10 and 13) 12. 13. (14 thru 22) (5) BOPE (23 thru 28) 2. Is well to' be located in a defined pool ............................. /__~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~_ 5. Is sufficient undedicated acreage available in this pool ............ ~ __ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequately. Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: Geology,: DWJ _.~ Engineering: .. LCS rev: 01/30/89 6.011 For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/12/13 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/12/13 ORIGIN OF DATA: 3G4 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED Alaska Oil & 6as '~. C,,ns. Oommissior, Anchorage ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G4NEU.COR SERVICE NAME: RLL VERSION #: V 3.26 DATE: 90/12/13 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** NEUTRON DATA CORRECTED FOR 12 FOOT DEPTH SHIFT ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 NPSC MWD P.U. 0 0 0 0 1 4 0 1 68 DEPT 3700.000 3800.000 3900.000 4000.000 4100.000 4200.000 4300.000 4400.000 4500.000 4600.000 4700.000 4800.000 4900.000 5000.000 5100.000 5200.000 5300.000 54O0.O00 5500.000 5600.000 5700.000 580O.O00 5900.000 6000.000 6100.000 6200.000 6300.000 6400.000 65OO.0O0 6600.000 6700.000 DATA VERIFICATION NPSC -999.250 47.090 42.352 41.929 39.895 38.300 39.737 37.147 38.556 36.845 38.182 39.807 34.970 35.985 33.652 34.090 35.849 29.860 34.759 37.373 35.608 37.130 36.747 36.211 36.255 36.863 33.117 35.730 29.919 33.609 33.208 (every 100 FT) ** 6800.000 6900.000 7000.000 7100.000 7200.000 7300.000 7400.000 7500.000 7600.000 7700.000 7800.000 7900.000 8O00.000 8100.000 30.909 34.213 34.068 33.395 35.277 36.838 34.252 47.133 49.377 33.671 28.535 42.254 -999.250 -999.250 71 DATA RECORDS ** FILE TRAILER** FILE NAME: 3G4NEU.COR SERVICE NAME: RLL VERSION #: V 3.26 DATE: 90/12/13 MAX. RECORD LENGTH: 1024 FILE TYPE: EO NEXT FILE NAME: FROM 3700.00 TO 8150.00 FT ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/12/13 ORIGIN OF DATA: 3G4 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/12/13 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER ********** **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/11/26 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COIV[MENTS: PETROLEUM COMPUTING INC.- LIS FORMAT TAPE HEADER ** SERVICE NAME: FEWD DATE: 90/11/26 ORIGIN OF DATA: 3G-4 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G4MWD. DAT SERVICE NAME: FEWD VERSION #: V 3.26 DATE: 90/11/26 MAX. RE CORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-4// API#: 50-103-20143// DATE: 03-NOV-90 LOCATION: 2538' FNL & 295' FWL, SEC 24, TWP. 12N, RANGE SE, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA. <<< COMMENTS >>> NEUTRON AND DENSITY LOGS ARE CALIPER CORRECTED. NO TOOL WEAR COMPENSATION REQUIRED. CERTAIN SECTIONS OF THE UPPER PORTION OF THE LOG WERE GENERATED FROM NON-ROTATING DATA AND SHOULD BE CONSIDERED SEMI-QUANTITATIVE. LOGS THROUGH THE KUPARUK SECTION ARE GENERATED FROM ROTATING DATA. TOOL WEAR COMPENSATION WAS APPLIED BASED ON POST-JOB TOOL CALIBRATION RESULTS. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD CAL MWD NPSC MWD FXN MWD DDN MWD NFO MWD NFl MWD NN0 MWD NN1 MWD FXD MWD DDD MWD FXE MWD DDE MWD GRC MWD ROP MWD RHOB MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD CAL MWD NPSC MWD FXN MWD DDN MWD NFO MWD NFl MWD NN0 MWD NN1 MWD FXD MWD DDD MWD FXE MWD DDE MWD GRC MWD ROP MWD RHOB MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P .U. 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 PPF 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION (every 100 FT) DEPT EWR CAL NPSC NFl NN0 NN1 FXD GRC ROP RHOB 3700.000 -999.250 -999.250 , 2312. -999. 710 -999.250 -999.250 000 2392.000 -999.250 250 -999.250 3800.000 499.400 62.535 , 2235. 314. 635 9.130 46.570 200 2369.600 -999.250 475 2.288 3900.000 517.000 92.675 248 53 5.7 0.0 4.1 35 8.860 41.551 00 2488.000 -999.250 20 2.347 4000.000 559.000 97.196 247 40 4.5 2.0 0.0 14 8.750 40.934 00 2440.000 -999.250 00 2.388 4100.000 535.000 93.423 242 43 4.4 4.0 4.9 26 8.630 37.647 00 2504.000 -999.250 60 2.247 4200.000 577.000 106.238 254 35 4.9 4.0 3.6 55 8.660 39.441 00 2512.000 -999.250 40 2.339 4300.000 545.286 98.703 255 41 3.9 6.5 3.2 08 8.660 41.775 72 2501.714 -999.250 10 2.322 4400.000 556.333 88.902 261 29 4.2 0.6 3.1 38 8.700 39.130 67 2626.667 -999.250 50 2.385 4500.000 543.000 104.731 266 23 3.8 4.0 3.4 35 8.700 36.740 00 2544.000 -999.250 60 2.307 4600.000 588.333 95.689 252 35 3.369 0.000 7. 190 8.750 38.664 2626.667 -999.250 2.354 4700.000 575.000 100.210 253 21 3.2 6.0 0.5 46 00 5O 8.900 41.530 2616.000 -999.250 2.378 4800.000 575.000 97.944 252 31 2.9 0.0 8.1 33 O0 O0 8.800 39.465 2440.000 -999.250 2.386 4900.000 559.000 97.196 269 14 3.1 6.0 5.9 92 00 70 8.570 39.254 2728.000 -999.250 2.356 5000.000 599.000 88.642 266 26 3.1 4.0 0.6 58 00 60 8.630 35.986 2632.000 -999.250 2.308 5100.000 623.000 119.790 276 33 3.3 0.0 7.9 76 O0 8O 8.640 35.462 2744.000 -999.250 2.371 FXN DDD -999.250 -999.250 -999.250 .332 -999.250 .403 -999.250 .549 -999.250 .566 -999.250 .484 -999.250 .583 -999.250 .725 -999.250 .513 -999.250 .546 -999.250 .617 -999.250 .694 -999.250 .943 -999.250 .606 -999.250 .621 DDN FXE .222 -999.250 .405 .973 1.003 .504 .467 .481 .704 .461 .537 .507 .556 .453 .622 .446 .486 .581 .653 .414 .813 .454 .474 .698 .592 .587 .641 .596 1.515 .586 NFO DDE 422.000 .175 518. 600 .575 511.000 .699 519. 000 .870 583.000 .870 569.000 1.299 557.857 .877 575.000 .893 553.000 .781 593.667 1.754 591.000 1.030 567.000 1.639 631.000 1.011 591.000 1.389 607.000 .935 5200. 571. 75. 5300. 607. 99. 5400. 607. 82. 5500. 585. 106. 5600. 519. 103. 5700. 607. 100. 5800. 607. 126. 5900. 623. 151. 6000. 615. 146. 6100. 603. 116. 6200. 615. 133. 6300. 599. 68. 6400. 567. 109. 6500. 615. 116. 6600. 609. 106. 6700. 599. 97. 6800. 611. 77. 000 800 339 000 000 451 000 000 874 000 667 986 000 000 972 000 000 210 000 000 577 000 000 437 000 000 168 000 000 028 000 000 353 000 000 563 000 000 853 000 000 028 000 667 238 000 000 944 000 000 605 2 2795 276 2 2616 100 3 2930 197 2 2744 219 1 2680 238 2 2552 210 .988 .200 .920 .781 .000 .000 .235 .667 .420 .084 .000 .640 .863 .000 .590 .371 .000 .030 2.238 2472.000 246.620 . 2520. 227. . 2608. 267. . 2608. 178. . 2520. 305. . 2824. 262. . 2600. 280. , 2904. 301. . 2728. 303. . 2760. 232. . 2880. 148. 366 000 480 885 000 410 812 0O0 95O 432 000 320 497 000 670 254 000 710 740 000 970 450 000 520 282 000 O3O 286 000 500 8.620 2728.000 2.348 8.580 2616.000 2.340 8.790 2856.000 2.315 8.580 2653.333 2.286 8.620 2696.000 2.378 8.580 2696.000 2.394 8.720 2584.000 2.371 8.690 2536.000 2.302 8.590 2520.000 2.338 8.920 2632.000 2.628 8.590 2557.333 2.407 8.830 2952.000 2.478 8.820 2648.000 2.384 8.620 2888.000 2.446 8.580 2781.333 2.435 8.720 2728.000 2.464 8.500 2800.000 2.464 34.615 -999.250 35.526 -999.250 32.171 -999.250 33.050 -999.250 37.699 -999.250 36.150 -999.250 39.676 -999.250 37.002 -999.250 33.904 -999.250 35.428 -999.250 37.180 -999.250 37.019 -999.250 39.607 -999.250 33.425 -999.250 31.186 -999.250 32.675 -999.250 33.107 -999.250 -999.250 1.449 -999.250 -999.250 -999.250 .644 -999.250 .642 -999.250 .728 -999.250 .762 -999.250 1.563 -999.250 .826 -999.250 .901 -999.250 .851 -999.250 .802 -999.250 -999.250 -999.250 .662 -999.250 .659 -999.250 .735 -999.250 .862 -999.250 1.136 1.148 .827 .769 .539 .659 .588 .678 .473 1.282 .649 .926 .721 .735 .620 .813 .698 .962 .865 1.000 .826 1.009 .547 .617 .487 .719 .561 .763 .481 .967 .580 .901 .761 .776 .653 583.000 2.703 575.000 1.250 655.OOO 1.124 572.333 1.333 551.000 2.778 671.000 1.093 631.000 1.250 623.000 1.471 643.000 1.786 599.000 1.064 617. 667 1.065 583.000 1.053 599.000 1.259 679.000 1.158 569.667 1.282 599.000 1.818 631.000 1.150 6900.000 4.075 8.680 571.000 2736.000 2720.000 94.182 202.700 2.394 34.537 -999.250 7000.000 2.945 8.670 607.000 2712.000 2744.000 88.154 156.300 2.451 -999.250 .867 .830 .588 7100.000 3.864 8.740 591.000 2664.000 2712.000 120.549 236.320 2.495 607.000 1.786 7200.000 4.020 9.010 604.333 2658.667 2690.667 100.111 142.790 2.528 32.653 -999.250 1.053 583.000 -999.250 .926 .688 1.695 7300.000 2.653 8.850 623.000 2520.000 2344.000 188.155 165.550 2.135 31.182 -999.250 7400.000 3.548 8.700 599.000 2632.000 2632.000 118.470 45.440 2.389 37.156 -999.250 7500.000 2.337 8.900 511.000 2296.000 2280.000 105.699 69.500 2.405 -999.250 1.724 623.000 1.111 .709 1.538 7600.000 1.637 8.910 493.000 2392.000 2216.000 108.988 66.280 2.239 -999.250 2.852 623.000 1.235 .989 1.613 7700.000 5.425 8.760 567.000 2776.000 2600.000 80.014 71.550 2.350 -996.250 3.226 695.000 -999.250 6.933 11.111 7800.000 7.199 8.890 695.000 2936.000 3112.000 61.149 93.390 2.420 38.341 -999.250 7900.000 2.752 8.890 559.000 2536.000 2520.000 94.897 64.476 2.349 31.839 -999.250 3.846 623.000 -999.250 4.167 2.038 7.692 8000.000 2.770 8.940 527.000 2568.000 2440.000 97.867 42.110 2.373 44.965 -999.250 3.030 519.000 -999.250 4.167 1.757 4.348 8100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 48.163 -999.250 2.857 503.000 -999.250 2.500 2.319 3.226 ** 636 DATA RECORDS ** 38.585 -999.250 1.818 631.000 -999.250 2.041 1.542 2.857 ** FILE TRAILER** FILE NAME: 3G4MWD.DAT SERVICE NAME: FEWD VERSION #: V 3.26 DATE: 90/11/26 MAX. RECORD LENGTH: 1024 FILE TYPE: EO NEXT FILE NAME: 32.669 -999.250 2.778 663.000 -999.250 2.128 1.217 5.882 44.138 -999.250 4.545 567.000 -999.250 2.857 2.196 7.692 41.210 -999.250 4.167 493.000 -999.250 4.545 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3700.00 TO 8150.00 FT FROM ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: FEWD DATE: 90/11/26 ORIGIN OF DATA: 3G-4 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/11/26 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER ********** STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2536' FNL, 4984' FEL, Sec. 24, T12N, R8E, UM At top of productive interval 5. Type of Well: Development __ X Exploratory __ Stratigraphic __ Service__ (asp's 498675, 5988560) 6. Datum elevation (DF or KB feet) RKB 90 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3G-04 91 Permit number / approval number 1916' FNL, 879' FEL, Sec. 25, T12N, R8E, UM At effective depth At total depth 2205' FNL, 4359' FEL, Sec. 25, T12N, R8E, UM (asp's 499302, 5983612) 190-131 / 10. APl number 50-103-20143 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 115' 16" SUR. CASING 3703' 9-5/8" PROD. CASING 7972' 7" 8089 feet Plugs (measured) 6127 feet 7854 feet Junk (measured) 5948 feet Cemented 243 sx AS II 870 sx AS Ill & 500 sx Class G 300 sx Class G & 175 sx Class G Measured Depth 115' 3793' 8062' True vertical Depth 115' 3018' 6106' Perforation depth: measured 7754' - 7784', 7640' - 7660', 7710' - 7734' true vertical 5873' - 5895', 5785' - 5802', 5840' - 5858' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7557' MD. Packers & SSSV (type & measured depth) CAMCO 'HRP-1-SP' @ 7521' MD. CAMCO 'TRDP-1A-SSA' @ 1812' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 409 Subsequent to operation 544 Representative Daily Average Production orlniection Data Gas-Mcf Water-Bbl 791 1159 930 1465 Casing Pressure Tubing Pressure 153 151 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil_ X Gas__ Suspended_ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Title: Wells Team Leader Questions? Call Mike Mooney 263-4574 Date Prepared b~/ Sharon AIIsup-Drake 263-4612 ,SCANNED RUG 2, 1. 2002. SUBMIT IN DUPLICATE Date Comment 3G-04 Event History 07/15/02 07/16/02 TAGGED FILL @ 7754' RKB, ALL A-2 PERFS COVERED; DRIFTED TBG W/11' X 2.5" HC TO 7754' RKB. [TAG, PERF] PERFORATED 7640'- 7660' AND 7710'- 7734', 4 SPF, 120 DEGREE PHASING, W/POWER JET CHARGES, TAGGED TD AT 7747' SCANNED Page 1 of 1 8/13/2002 PhilLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 August 14, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3 G-04 (190-131) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 3G-04. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad ~C,ANNED/~UG ~ 1 2002
