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186-109
Originated:Delivered to:1-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/05/2020 PTD: 1861090 E-Set: 34059 10/07/2020 Abby Bell Originated:Delivered to:1-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 PTD: 1861090 E-Set: 34058 Received by the AOGCC 10/05/2020 10/07/2020 Abby Bell rt RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 “ 2015 Status: COMPLETION OR RECOMPLETION REPORT AND LOCA 1a.Well Stat Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ • Suspended 11 lb.Well cA0f C 20AAC 25.105 20AAC 25.110 Development Q ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 5/20/2015 186-109/315-145 • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 7/15/1986 50-103-20070-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 252'FSL,556'FWL, Sec. 1,T11N, R8E, UM 7/20/1986 KRU 2T-08 Top of Productive Interval: 9. KB(ft above MSL): 117' 17. Field/Pool(s): 1302'FSL, 1347'FEL,Sec. 1,T11N, R8E, UM GL(ft above MSL): 37' Kuparuk River Field/Kuparuk River Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1452'FSL, 1047'FEL,Sec. 1,T11N, R8E, UM 1985'MD/1975'TVD ' ADL 25569 - 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498945 y- 5970233 Zone- 4 7676'MD/6186'TVD 2667 TPI: x- 502321 y- 5971282 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 502621 y- 5971432 Zone- 4 nipple @ 501'MD/501'TVD 2140'MD/2121'TVD 5. Directional or Inclination Survey: Yes ❑(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 na (ft MSL) not applicable 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 %MIK© SEP 0 9 2015 none 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE .---- TOP BOTTOM TOP BOTTOM - HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 37' 115' 37' 115' 24" 234 sx CS II 9.625" 36# J-55 34' 2977' 34' 2798' 12.25" 685 sx AS III, 315 sx Class G 7" 26# J-55 1985' 7600' 1975' 6126' 8.5" 300 sx Class G, 175 sx AS I 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): none none 6995'MD/5658'TVD perfs squeezed: 7188'-7192'MD/5805-5808'TVD . d 202'- 7228'MD/5815'-5835'NDi! 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. F! Was hydraulic fracturing used during completion? Yes❑ No ❑✓ ,�, Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED - - cement plug @ 7200' 16.5 ppg cement cement squeeze 7060-7200 16 bbls of 16.5 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): suspended Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - - .- .___ . . -.---- __-._..___ _..----- 57..,t....itr. 9 1 inic _ . __._....-. 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores. Yes ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. none 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2140' 2121' Attach separate pages to this form, if needed,and submit detailed test information,including reports,per 20 AAC 25.071. Top Kuparuk C 7116' 5749' Base Kuparuk C 7122' 5754' Top Kuparuk A 7169' 5790' Base Kuparuk A 7323' 5908' Formation at total depth' Kuparuk C 31. List of Attachments. daily operations summary,schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, 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: Ron Phillips @ 265-6312 Email. Ron.L.Phillips@conocophillips.com Printed Name: Dan Venhaus Title. CTU Engineering Supervisor Signature: C�^'� Phone: 263-4372 Date: —/k INSTRUCTIONS General. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level 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 5/2015 Submit ORIGINAL Only 2T-08 EOW CTD Schematic Modified by RLP 5-29-15 DS-nipple at 501'MD(2.875"min ID, No-Go) 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing to surface 16",62.5#, H-40 shoe at 115'MD 3-1/2"Camco MMG gas lift mandrels at 2694',4499', 5629',6360',& 6909'RKB (6926'PDC) 9-5/8",36#,J-55 shoe at 2977' MD f r® Baker Locator at 6965'RKB (6982'PDC) Baker 3-1/2"80-40 PBR at 6973'RKB (6990' PDC) Baker FHL packer 6995'RKB (7012'PDC) + DS-nipple at 7078' RKB (7095'PDC) (2.813"min ID, No-Go) 3-1/2"tubing tail at 7091'RKB (7108'PDC) 2T-08AL1 south,TD at 8252' KOP @ 7124'MDN Liner top at 7084'MD ---------------- K�OP @ 7140'MD :__=-------------------- A-sand perfs(sgz'd) 7188'-7192'MD �` ' 7202'-7228' MD —- 2T-08A south,TD at 10,991' Billet @ 7,333' 7",26#casing at 7600'MD 0'-1985': L-80,TC-II 1985'-7600': J-55, BTC 2T-08 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 3/14/2015 SET 2.81"C-LOCK W/FLOW THRU SUB SOFTSET& DUAL SPARTEK GAUGES (OAL=81") @ 7078' RKB.LEFT WELL SI FOR 10 DAY BUILD UP.RETURN LATER.IN PROGRESS 3/25/2015 PULLED 2.81" C LOCK WITH GAUGES @ 7078' RKB. FINAL BHP: 2525 PSI. SET 2.81" CSA-2 PLUG & BAITED PULLING TOOL @ SAME. PULLED GLVs @ 6360', 5629' RKB. SET DV @ 6360' RKB. IN PROGRESS. 3/26/2015 PULLED GLVs @ 4499' & 2694' RKB. SET DVs @ 5629', 4499' &2694' RKB. DDT CONFIRMED PLUG INTEGRITY. PULLED OV @ 6909' RKB. LOADED TBG/IA WITH INHIB SW& DSL. IN PROGRESS. 3/27/2015 CMIT TBG x IA 2500 PSI, GOOD. SET DV @ 6909' RKB. MIT IA 2000 PSI, GOOD. PULLED 2.81"CSA-2 PLUG @ 7078' RKB. READY FOR INJECTIVITY TEST. 4/3/2015 Displaced tubing with 70 bbls seawater. Established injectivity test @ 0.5 bpm @ 450 psi and 1.0 bpm @ 850 psi w/SW. Freeze protected well w/20 diesel. See WSR for details. Note: Unable to perform 0.25 bpm test, minimum rate with pump=0.5 bpm. 4/14/2015 CORRELATED TO HALLIBURTON JEWELRY LOG DATED 8-JAN-2015. PERFORATED 7070'- 7072'WITH 2"3SPF MILLENIUM BIG HOLE CHARGES. PERFORATED 7142'- 7152'WITH 2"6 SPF MILLENIUM DEEP PENETRATING CHARGES. 4/16/2015 RAN BAKER NIPPLE LOCATOR FOR 2.81" NIPPLE AND FLAGGED PIPE AT 7093.3' CTMD. PUMPED 21 BBLS OF 16.5 PPG CEMENT. LAYED IN CEMENT FROM 7340' CTMD TO TUBING TAIL AT 7107' CTMD (CORRECTED) GETTING 1:1 RETURNS. ONCE INSIDE THE TUBING WELL WENT ON VAC, LOST ALL RETURNS. ATTEMPTED TO HESSITATE 3 TIMES AND WAS ABLE TO WORK PRESSURE SLOWLY TO 780 PSI, BUT WOULD NOT HOLD. CONTAMINATE CEMENT DOWN TO 7200' CTMD. IN PROGRESS. 4/20/2015 MIXED AND PUMPED 16 BBLS OF 16.5 PPG CEMENT. LAYED IN 1:1 FROM 7190'AND PULLED TO SAFETY AT 5550' CTMD. SQUEEZED 5.5 BBLS OF CEMENT TO FORMATION BEFORE REACHING 1200 PSI SQUEEZE PRESSURE. CONTAMINATED CEMENT LEAVING TOC AT 7060'CTMD. TRAPPED 600 PSI ON TUBING. READY FOR SLICKLINE TAG IN 72 HOURS. 4/23/2015 TAGGED TOC @ EST. 7066' RKB. MIT TBG 2000 PSI, PASSED. READY FOR DHD. 4/24/2015 (PRE-CTD): TREE VALVE TEST, DDT MV(PASSED), DDT SSV(PASSED), DDT SV (PASSED), PP MV(PASSED), PP SSV(PASSED), PP SV(PASSED). Conoc Phillips Time Log & Summary Wel/view Web Reporting Report Well Name: 2T-08 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/8/2015 3:02:00 PM Rig Release: 5/21/2015 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/08/2015 24 hr Summary Move from 2K-15 to 21-08. Spot rig modules. MIRU CDR2 on 2T-08. Rig accept @ 15:00. Start initial BOPE test,in progress. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Move shop to 2T pad, continue rig down off 2K-15. 01:30 02:00 0.50 0 0 MIRU MOVE SFTY P Safety meeting with PEAK trucks. 02:00 05:30 3.50 0 0 MIRU MOVE MOB P Demob Pits and sub off well, move to 2T pad. 05:30 06:30 1.00 0 0 MIRU MOVE RURD P Arrive on location, PJSM, Prep well for rig,deep cellar due to pad buildup. 06:30 10:00 3.50 0 0 MIRU MOVE MOB P Spot drill sub and pits. 10:00 15:00 5.00 0 0 MIRU MOVE RURD P Hook up interconnect, hook up steam lines, rig up stairs and walkways,check tree flange bolts on very crooked tree(30 min), NU BOP, recheck flange bolts(30 min)add extra riser,safe out rig, hook up remote ESD in ops cab to 21-201 and 2T-39,wells are online and at 12.5-ft centers. NOTE:Accept Rig at 15:00 15:00 00:00 9.00 0 0 MIRU WHDBO BOPE P Start BOPE test,test pressure 3500 psi, annular preventer 2500 psi, witness waived by Lou Grimaldi. 35/09/2015 Complete initial BOPE test, pull BPV. Drill cement pilot hole to 7,170',back ream transition area. POOH w/ BHA#1, flow check at surface, no flow. 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Complete initial BOPE test.Test waived by Lou Grimadi(AOGCC) 03:00 05:00 2.00 0 0 MIRU WHDBO PRTS P Load coil,test inner reel iron and pack-offs, re-test blind rams, good test. 05:00 07:00 2.00 0 0 MIRU WHDBO MPSP P PJSM. Rig-up FMC Lubricator,pull BPV, LD FMC lubricator 07:00 09:00 2.00 0 0 MIRU WHDBO PRTS P PJSM-Pressure test PDL's,TT line, valve check list,pre floor for drilling operations. 09:00 10:18 1.30 0 62 SLOT WELLPF PULD P PJSM-MU BHA#1,cement pilot hole assembly, 0.9 AKO motor and 2.80"no-go D331 mill, install checks, MU to CoilTrak,surface test. 10:18 11:45 1.46 62 7,066 SLOT WELLPF TRIP P RIH with BHA#1 11:45 12:07 0.38 6,890 7,061 SLOT WELLPF DLOG P Tie in to K1 marker at 7120': +14' correction. Page 1 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:07 13:05 0.97 7,061 7,061 SLOT WELLPF DISP P Swap well to 9.8 ppg FloPro mud (leftover from 2K-15). 13:05 13:14 0.16 7,061 7,061 SLOT WELLPF CIRC P Swapped from taking returns to tiger tank to inside and gas was present in returns. Swap back to tiger tank and circulate-15 bbls of 9.8 ppg mud. 13:14 17:41 4.45 7,061 7,170 PROD1 RPEQPI MILL P Close EDC, PUW 30k lb. RBIH to dry tag at 7086'. PU,pumps online at 1.45 BPM, pump pressure 3600 psi. Begin seeing motor work at-7085.6'. Milling ahead-1.45 BPM, pump pressure 4000 psi, ROP 18-20 ft/hr. Stall at 7094.5', PUW 26k. Stall at 7108.02', PUW 27k. WOB increase at-7117'indicates possible casing contact point. PU to above TOC, PUW from 7135.82'=26k. 17:41 21:56 4.25 7,170 7,170 PROD1 RPEQP1REAM P Dry drift set down 1K @ 7,119'. Dress transition area,make several back reaming passes at 180 deg ROHS, improvement, .4 K set down at 7,119'. No improvement last two passes. Call town,try 20 deg ROHS back reaming passes,still seeing .4K @ 7,119',when mill contacts casing. 21:56 22:17 0.35 7,170 7,030 PROD1 RPEQPI DLOG P POOH,Tie-in to K1 for+1' correction. 22:17 23:27 1.18 7,030 96 PROD1 RPEQP1TRIP P POOH w/BHA#1 23:27 23:57 0.50 96 96 PROD1 RPEQP1OWFF P Flow check, no flow. 05/10/2015 Run PDS caliper survey, caliper results indicate good pilot hole. Run BHA#4 whipstock. Set TOWS 7140'. Run BHA#5 window milling assembly.Time drill from 7140'to 7142'at 1 fph. In progress. 00:00 01:00 1.00 96 0 PROD1 RPEQPI PULD P PJSM. LD BHA#1, install nozzle. 01:00 02:00 1.00 0 0 PROD1 RPEQP1CIRC P PJSM.Jet BOP stack, remove nozzle. 02:00 03:30 1.50 0 73 PROD1 RPEQP1PULD P PJSM. PU/MU BHA#2, Caliper assembly,test MWD tools. 03:30 05:30 2.00 73 7,160 PROD1 RPEQPI DLOG P RIH w/BHA#2,tie-in at K1 marker for a+15.5'correction. RIH. 05:30 06:40 1.18 7,160 6,260 PROD1 RPEQPI DLOG P Arrive at 7160'and wait on caliper fingers to open. Fingers programmed to open at 06:22. Log up hole at 50 fpm until fingers close at 06:40. POOH at-100 fpm. 06:40 07:49 1.15 6,260 71 PROD1 RPEQP1TRIP P POOH at-100 fpm. • 07:49 08:19 0.50 71 71 PROD1 RPEQP1OWFF P Tools at surface. Perform no flow test. PJSM for laying down tools on a dead well. 08:19 08:44 0.43 71 0 PROD1 RPEQP1PULD P LD BHA#2. Page 2 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:44 09:14 0.50 0 71 PROD1 RPEQPI PULD P PJSM for MU dummy drift. MU BHA #3:whipstock dummy drift. Good surface test. 09:14 10:44 1.50 71 7,057 PROD1 RPEQP1TRIP P RIH with dummy drift. 10:44 10:56 0.20 7,057 7,057 PROD1 RPEQP1DLOG P Tie in at K1 marker fora+13.5' correction. PUW @ 7057'=30k lb. 10:56 11:08 0.20 7,057 7,165 PROD1 RPEQP1TRIP P Dry drift cement pilot hole area at —11 fpm. No weight fluctuations. 11:08 12:14 1.10 7,165 71 PROD1 RPEQP1TRIP P POOH 12:14 12:41 0.45 71 71 PROD1 RPEQP1OWFF P On surface, no flow, PJSM-laying down BHA 12:41 13:02 0.35 71 0 PROD1 RPEQP1PULD P LD BHA#3 13:02 13:41 0.65 0 74 PROD1 RPEQPI PULD P PJSM-MU BHA#4, OH anchor whipstock assembly. 13:41 15:18 1.63 74 7,020 PROD1 RPEQP1TRIP P RIH with BHA#4 15:18 15:27 0.15 7,020 7,020 PROD1 RPEQP1DLOG P Tie in at K1 marker fora+14' correction. 15:27 15:57 0.50 7,020 7,151 PROD1 RPEQP1WPST P RIH to 7150.53'. Close EDC, bring pumps online, see circulating pressure spike,set down slightly, no downhole movement, PU, and PUW is normal.TOWS 7140', BOWS 7150.53',set 0 degrees of high side. 15:57 17:15 1.30 7,151 74 PROD1 RPEQP1TRIP P POOH 17:15 17:45 0.50 74 74 PROD1 RPEQP1OWFF P On surface, flow check. 17:45 19:18 1.55 74 74 PROD1 WHPST PULD P PJSM. LD BHA#4. PJSM. MU BHA#5 19:18 21:06 1.80 74 7,141 PROD1 WHPST TRIP P RIH w/Window milling assembly, tie-in to K1 for+14.5'correction, continue in hole. Dry tag depth© 7,140.8 21:06 23:57 2.86 7,140 7,142 PROD1 WHPST WPST P Start timing milling whipstock as per well plan @ 1 fph. 1.40 BPM @ 3,650 PSI, BHP=3,435 PSI, CTW=8.5K, WOB=1.5K. 05/11/2015 Time mill window exit to 7,147'. Mill rathole to 7,161, before formation sand in returns decreased to 10%, stopped milling rathole. Back ream window, some motor work from 7,141'to 7,145', make additional back ream passes at 30 L/R. Dry drift clean. POOH to make caliper run. Run PDS caliper survey from 7,160'to 6,260' @ 50 fpm. POOH, LD BHA#6, check data, send data to processing.Wait on caliper data and plan forward. 00:00 05:00 5.00 7,142 7,147 PROD1 WHPST WPST P Time mill window at 1 fph. 05:00 07:54 2.90 7,147 7,161 PROD1 WHPST WPST P Continue milling window 1 and 2 fph per plan 1.4 bpm at 3,491 psi, BHP 3,448 psi,WOB 1.9k, CWT 8.3k. 7,148.6 pick up ROP, mill ahead 1.4 bpm at 3,535 psi, BHP 3,449 psi, WOB.8k, CWT 8k.20%formation sand in returns. 7,156.1-ft, stall, PUW 35k, mill ahead 1.41 bpm at 3,437 psi, BHP 3,450 psi,WOB .4k, CWT 9.5k. 10% sand in returns. Page 3 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:54 10:00 2.10 7,161 7,161 PROD1 WHPST REAM P 7,161-ft, Back ream window, 0°with some motor work and-2k WOB 7,145 to 7,141-ft, RBIH,some motor work,WOB 1.9k, confer with town, back ream 30U30R,dry drift window 0°HS to 7,160-ft. Open EDC 10:00 11:39 1.65 7,161 74 PROD1 WHPST TRIP P POOH with BHA#5 11:39 12:09 0.50 74 74 PROD1 WHPST OWFF P On surface, flow check. PJS-LD BHA 12:09 13:00 0.85 74 0 PROD1 WHPST PULD P LD BHA#5, both mills 2.79"no-go, a little wear on mill side, pics in folder. 13:00 14:27 1.45 0 72 PROD1 WHPST PULD T PDS caliper rep onsite, program tool. PJSM-MU BHA#6 PDS memory caliper assembly,surface test. 14:27 16:51 2.40 72 7,160 PROD1 WHPST TRIP T RIH with BHA#6 EDC closed, tie in to K1 for plus 15-ft correction, continue in hole. 16:51 17:30 0.65 7,160 6,260 PROD1 WHPST DLOG T Arrive at 7160'and wait on caliper fingers to open. Fingers programmed to be fully open at 17:12. Log up hole at 50 fpm until fingers close at 17:30. 17:30 18:30 1.00 6,260 72 PROD1 WHPST TRIP T POOH at—100 fpm. 18:30 19:00 0.50 72 72 PROD1 WHPST OWFF T No flow check 19:00 20:00 1.00 72 0 PROD1 WHPST PULD T PJSM. LD BHA#6, check caliper for data,good data,send to Houston. 20:00 00:00 4.00 0 0 PROD1 WHPST WAIT T Wait on data from Houston and plan forward. Held Pre-spud. It books like we milled off left side of whipstock tray. Continue to wait on town for plan forward. 05/12/2015 Set 3-1/2"monobore XL whipstock: TOWS 7124'at 0 degrees high side. Swap mud to new 9.3 ppg PowerPro system. Run LIB to verify whipstock orientation. Begin milling at 7124.28'at 10 degrees LOHS. 00:00 00:45 0.75 0 0 PROD1 WHPST WAIT T Hold conference call with town on plan forward. Decide to run second whipstock,TOW @ 7,124'. 00:45 04:15 3.50 0 0 PROD1 WHPST WAIT T Call Baker for second whipstock, wait for whipstock arrival. 04:15 05:09 0.90 0 74 PROD1 WHPST PULD T Baker arrived on location. PJSM. MU BHA#7 05:09 07:27 2.30 74 7,135 PROD1 WHPST TRIP T RIH w/3.5" Baker Monobore XL whipstock with OH anchor, upper slip aligned 0 degree highside tray. Tie in to K1 for plus 13.5-ft correction, PUW 30k,continue in hole. 07:27 07:42 0.25 7,135 7,060 PROD1 WHPST WPST T 7,134.53-ft, On depth with whipstock, PU to neutral, release off whipstock at 3,800 psi,stack 5k, PUW 30k,TOWS 7,124-ft, PUH to 7,060-ft 07:42 08:51 1.15 7,060 7,060 PROD1 WHPST DISP T 7,060-ft, Swap mud over to 9.3 ppg PwrPro. 08:51 10:06 1.25 7,060 74 PROD1 WHPST TRIP T POOH with BHA#7 10:06 10:36 0.50 74 74 PROD1 WHPST OWFF T On surface, flow check. PJSM-LD BHA. __ _ _ ___ Page 4 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:36 11:45 1.15 74 58 PROD1 WHPST PULD T LD BHA#7. PJSM-MU BHA#8, 2.48"OD LIB assembly 11:45 13:24 1.65 58 7,125 PROD1 WHPST TRIP T RIH with BHA#8,tie in at K1 for plus 13.5-ft correction, PUW 28k, continue in hole 13:24 14:33 1.15 7,125 58 PROD1 WHPST TRIP T 7,124.73-ft,Tag up,see 3.2k DHWOB, POOH, PUW 28k, clean. 14:33 15:03 0.50 58 58 PROD1 WHPST OWFF T On surface,flow check. PJSM-LD BHA. 15:03 15:54 0.85 58 73 PROD1 WHPST PULD T LD BHA#8, LIB pics(pre run&post run)put in S:drive folder. PJSM-MU BHA#9 window milling assembly#2, 0.6°motor with 2.80"DSM 15:54 17:23 1.49 73 7,061 PROD1 WHPST TRIP T RIH with BHA#9,tie in to K1 for +13.5'correction 17:23 22:30 5.13 7,061 6,753 PROD1 WHPST WAIT T PUH, discuss plan forward with town. 22:30 22:52 0.37 6,753 7,124 PROD1 WHPST TRIP T Decison made to mill with BHA#9. RIH to dry tag at 7124.28'. PU, pumps online, RIH. 22:52 23:58 1.11 7,124 7,125 PROD1 WHPST WPST T Milling from 7124.28'to 7125.36'. In progress. 35/13/2015 Mill casing window(TOW 7124', BOW 7129.6')and rathole to 7124'. Drill build section. In progress. 00:00 03:00 3.00 7,125 7,129 PROD1 WHPST WPST T Milling from 7125.36'to 7129.4' 03:00 04:00 1.00 7,129 7,131 PROD1 WHPST WPST T OBM at 7129.4ft, 1.47 bpm at 2941 psi, BHP 3265,WHP 0, IA 363, OA 0, DHWOB 1.4k, ROP 1.9 fph 04:00 08:30 4.50 7,131 7,145 PROD1 WHPST WPST T Milling rat hole, 1.44 bpm at 3154 psi, BHP 3270,WHP 0, IA 402, OA 0, DHWOB 2.7k, ROP 3.6 fph. Note: Choke cleaned out, heavy shale. 08:30 09:45 1.25 7,145 7,145 PROD1 WHPST REAM T 7,145-ft, TD rathole, back ream window 10°LOHS,20°R/40°L passes, Dry drift window, clean. 09:45 11:00 1.25 7,145 73 PROD1 WHPST TRIP T POOH for build drilling assembly, open EDC,jog at 1,800-ft, choke plugging with shale. 11:00 12:39 1.65 73 0 PROD1 WHPST PULD T PJSM-Un-deploy/LD BHA#9,2.79" no-go on both mills. 12:39 14:15 1.60 0 63 PROD1 DRILL PULD P PJSM-MU build section BHA#10, 2.3°AKO motor with HCC Bi-center bit, Deploy, make up to CoilTrak, surface test. 14:15 15:30 1.25 63 7,010 PROD1 DRILL TRIP P RIH with BHA#10 15:30 15:45 0.25 7,010 7,040 PROD1 DRILL DLOG P Tie in to K1 for plus 14-ft correction, PUW 23k 15:45 15:54 0.15 7,040 7,145 PROD1 DRILL TRIP P Continue in hole,clean through window 15:54 17:15 1.35 7,145 7,215 PROD1 DRILL DRLG P 7,145-ft, OBD 1.5 bpm at 3,380 psi, BHP 3,421 psi,WHP 96, IA 231, OA 0 17:15 17:30 0.25 7,215 7,020 PROD1 DRILL WPRT P 7,215-ft, PUH to log RA, PUW 24, Page 5 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 17:45 0.25 7,020 7,020 PROD1 DRILL DLOG P Tie into the K1 marker correction of 0.0ft 17:45 18:00 0.25 7,020 7,215 PROD1 DRILL WPRT P RBIH to bottom, RIW 14k 18:00 00:00 6.00 7,215 7,300 PROD1 DRILL DRLG P BOBD 1.42 bpm at 3050 psi, BHP 3485,WHP 111, IA 368, 0A 0, getting high DGLS, control drill to minimize DGLS. 05/14/2015 TD build section at 7300'. Drill lateral from 7300'to 8366'. In progress. 00:00 01:36 1.60 7,300 78 PROD1 DRILL TRIP P TD build section early due to high 50°DGLS 01:36 03:27 1.85 78 0 PROD1 DRILL PULD P Tools at surface. PJSM. Pressure undeploy BHA#10(build section assembly). 03:27 04:36 1.15 0 81 PROD1 DRILL PULD P PJSM. MU and pressure deploy BHA #11:2 3/8"0.5 degree AKO X-treme motor and 2.7"x3"Hycalog bi-center bit. 04:36 06:12 1.60 81 7,010 PROD1 DRILL TRIP P RIH with BHA#11 06:12 06:33 0.35 7,010 7,300 PROD1 DRILL DLOG P Tie in to K1 for plus 13.5-ft correction, PUW 24k, RBIH. 06:33 09:54 3.35 7,300 7,580 PROD1 DRILL DRLG P 7,300-ft, OBD 1.5 bpm at 3530 psi, BHP 3,480 psi,WHP 119, IA 288, 0A 0. 09:54 10:36 0.70 7,580 7,140 PROD1 DRILL DLOG P Wiper up hole with MADD pass to 7,140-ft, PUW 25k, 10:36 14:54 4.30 7,140 7,880 PROD1 DRILL DRLG P 7,580-ft, OBD 1.5 bpm at 3,529 psi, BHP 3,514 psi,WHP 120, IA 495, OA O. 14:54 15:18 0.40 7,880 7,150 PROD1 DRILL WPRT P Wiper up hole, PUW 26K. 15:18 15:42 0.40 7,150 7,880 PROD1 DRILL WPRT P Wiper back in hole, RIW 11K. 15:42 20:13 4.52 7,880 8,180 PROD1 DRILL DRLG P 7,880-ft, OBD 1.5 bpm at 3,528 psi, BHP 3,512 psi,WHP 46 psi, IA 622 psi,OA 0 psi. Drill to 8180.05'. 20:13 20:46 0.55 8,180 7,145 PROD1 DRILL WPRT P Wiper up hole from 8180.05'to 7145', PUW 27.5k 20:46 20:55 0.15 7,145 7,169 PROD1 DRILL DLOG P Tie in at RA marker at 7130'for a +1.5'correction. 20:55 21:20 0.42 7,169 8,180 PROD1 DRILL WPRT P Wiper back in hole from 7169'to bottom, RIW 11.5k 21:20 23:59 2.66 8,180 8,366 PROD1 DRILL DRLG P BOBD(8180.05')1.5 bpm at 3481 psi, BHP 3520 psi,WHP 14 psi, IA 688 psi, OA 0 psi. Fault encountered at 8312'. 35/15/2015 Drill A lateral from 8366'to 9627'. In progress. 00:00 01:27 1.45 8,366 8,480 PROD1 DRILL DRLG P OBD at 8366'. 1.5 bpm at 3380 psi, BHP 3567,WHP 25, IA 728, OA 0 01:27 01:54 0.45 8,480 7,319 PROD1 DRILL WPRT P Wiper trip from 8480'to 7319', PUW 27.5k 01:54 02:21 0.45 7,319 8,480 PROD1 DRILL WPRT P RBIH from 7319 to bottom, RIW 10.1k Page 6 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:21 09:09 6.80 8,480 8,780 PROD1 DRILL DRLG P BOBD at 8480'. 1.5 bpm at 3585 psi, BHP 3531,WHP 4, IA 753, OA 0. Stall at 8643'. slow drilling through Anchorite. 09:09 09:39 0.50 8,780 7,580 PROD1 DRILL WPRT P Wiper up hole, PUW 25k 09:39 10:06 0.45 7,580 8,780 PROD1 DRILL WPRT P Wiper back in hole, RIW 11k. 10:06 14:12 4.10 8,780 9,080 PROD1 DRILL DRLG P 8,780-ft, OBD 1.5 bpm at 3,380 psi, BHP 3,585 psi,WHP 63, IA 317, OA 0. Mud swap Note: New mud at bit at 8,818-ft. 1,694-ft drilled w/0.8%solids. 14:12 15:03 0.85 9,080 7,145 PROD1 DRILL WPRT P Wiper up hole for tie in, PUW 27k 15:03 15:12 0.15 7,145 7,170 PROD1 DRILL DLOG P Log RA marker for plus 2.0-ft correction, PUW 27k 15:12 15:51 0.65 7,170 9,080 PROD1 DRILL WPRT P Wiper in hole, RIW 10k. 15:51 19:42 3.86 9,080 9,380 PROD1 DRILL DRLG P 9,080-ft, OBD 1.5 bpm at 3,397 psi, BHP 3,592 psi,WHP 131, IA 255, OA 0. 19:42 20:17 0.59 9,380 9,380 PROD1 DRILL WPRT P Wiper trip from 9380'to 8580'then back to bottom. 20:17 23:59 3.70 9,380 9,627 PROD1 DRILL DRLG P BOBD at 9,380'. 1.5 bpm at 3370 psi, BHP 3620,WHP 95, IA 346, OA 0.AT 9627'at misdnight. 35/16/2015 Drill A lateral from 9627'to 10,535'. In progress. 00:00 00:51 0.85 9,627 9,680 PROD1 DRILL DRLG P At 9627', OBD. 1.5 bpm at 3312 psi, BHP 3652 psi,WHP 74, IA 409, OA 0 00:51 01:42 0.85 9,680 9,680 PROD1 DRILL WPRT P Wiper trip from 9680'to 8680'then back to bottom. 01:42 07:33 5.85 9,680 9,980 PROD1 DRILL DRLG P BOBD. 1.5 bpm at 3400 psi, BHP 3640 psi,WHP 48 psi, IA 437, OA 0 07:33 08:48 1.25 9,980 7,145 PROD1 DRILL WPRT P Wiper trip for tie in, PUW 27k. 08:48 08:57 0.15 7,145 7,170 PROD1 DRILL DLOG P Log RA marker for plus 3.0-ft correction. 08:57 09:57 1.00 7,170 9,980 PROD1 DRILL WPRT P Wiper in hole, RIW 10k 09:57 14:54 4.95 9,980 10,280 PROD1 DRILL DRLG P 9,980-ft, OBD 1.5 bpm at 3,420 psi, BHP 3631 psi,WHP 16, CWT 2k, WOB 1.65k, IA 467, OA 0. 14:54 16:03 1.15 10,280 10,280 PROD1 DRILL WPRT P Wiper trip up hole to 8,700-ft, PUW 27.5k. RBIH, RIW 7k 16:03 21:33 5.50 10,280 10,535 PROD1 DRILL DRLG P 10,280-ft, OBD 1.5 bpm at 3,378 psi,BHP 3,668 psi,WHP 0, CWT 1.8k,WOB 1.4k, ROP 50 fpm, IA 531, OA0 21:33 22:33 1.00 10,535 7,300 PROD1 DRILL WPRT P 10535ft, pump 5x5 sweep,Wiper up hole to 7300ft, PUW 30k 22:33 23:52 1.32 7,300 10,535 PROD1 DRILL WPRT P 7300ft,Wiper back in hole. RIW 9k 23:52 23:59 0.13 10,535 10,535 PROD1 DRILL DRLG P BOBD. 1.5 bpm at 3210 psi, BHP 3770 psi,WHP 43, IA 447, OA 0 35/17/2015 Drill A lateral from 10,535'to 10990'. Page 7 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:20 1.34 10,535 10,542 PROD1 DRILL DRLG P BOBD. 1.5 bpm at 3210 psi, BHP 3770 psi,WHP 43, IA 447, OA 0. Not making much hole,time for agitator. 01:20 04:00 2.68 10,542 84 PROD1 DRILL TRIP P POOH. New mud to the bit at 10,535'. 04:00 05:28 1.48 84 0 PROD1 DRILL PULD P Tools at surface. PJSM. Pressure undeploy BHA#11 (drilling assembly). Bit condition 1-1-BT-N-X-I-NO-BHA 05:28 06:13 0.75 0 0 PROD1 DRILL BOPE P Crew change out, PJSM-Function test BOPs. 06:13 08:43 2.50 0 78 PROD1 DRILL PULD P PJSM-MU and pressure deploy BHA #12(drilling assembly with agitator) .5 AKO motor with HYC Bi-center bit, change out checks,surface test, PJSM-change out pack-offs. 08:43 10:37 1.90 78 7,030 PROD1 DRILL TRIP P RIH with BHA#12, 10:37 10:46 0.15 7,030 7,065 PROD1 DRILL DLOG P Tie into the K1 correction of plus 16.5 ft. 10:46 12:04 1.30 7,065 10,539 PROD1 DRILL TRIP P Continue RIH with BHA#12 12:04 16:55 4.85 10,539 10,840 PROD1 DRILL DRLG P 10,539-ft, OBD 1.40 bpm at 3,592 psi, BHP 3,693 psi,WHP 106, IA 232,OA 0 16:55 17:22 0.45 10,840 9,800 PROD1 DRILL WPRT P Wiper trip up hole, PUW 28k. 17:22 17:46 0.40 9,800 10,840 PROD1 DRILL WPRT P Wiper in hole, RIW 7k. 17:46 21:28 3.70 10,840 10,990 PROD1 DRILL DRLG P 10,840-ft, OBD 1.4 bpm at 3,795 psi, BHP 3,688 psi,WHP 16, IA 417, OA 0. 21:28 23:58 2.50 10,990 78 PROD1 DRILL WPRT P TDA lateral at 10990', pump 10 x10 sweep,perform wiper to the swab valves. 35/18/2015 Run A lateral lower completion(bull nose,65 jts 2-3/8"slotted liner, shorty deployment sleeve)to 10,992'.MU A lateral upper completion. 00:00 00:30 0.50 78 78 PROD1 DRILL CTOP P Tighten reel chain, Reset counters to zero 00:30 01:45 1.25 78 7,040 PROD1 DRILL WPRT P RBIH,to tie in depth. 01:45 02:00 0.25 7,040 7,040 PROD1 DRILL DLOG P Tie into the K1 marker correction of plus 13ft. 02:00 03:30 1.50 7,040 10,991 PROD1 DRILL WPRT P Line up orienter for passing through window, continue RIH to confirm TD. 03:30 06:54 3.40 10,991 78 PROD1 DRILL DISP P Confirm TD, 10991', displace well to 11.4 ppg completion fluid. 06:54 07:24 0.50 100 100 PROD1 DRILL OWFF P On Surface, Flow check, PJSM-LD BHA. 07:24 08:24 1.00 100 0 PROD1 DRILL PULD P LD BHA#12, check coil 20-ft above CTC, Bit condition 1-1-BT-N-X-I-BU-TD 08:24 09:24 1.00 0 0 COMPZ CASING RURD P PJSM-Prep floors for liner run, inspect top drive. Note: Test joit disconnect inspected by BOT TT rep. Brent Lane. 09:24 13:21 3.95 0 2,061 COMPZ CASING PUTB P PJSM-MU bull nose,65 jts of 2 3/8" slotted,shorty deployment sleeve. Page 8 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:21 13:57 0.60 2,061 2,106 COMPZ CASING PULD P PJSM-MU BHA#13 on A lateral lower liner assembly, MU to CoilTrak, surface test. 13:57 17:12 3.25 2,106 10,992 COMPZ CASING RUNL P RIH with A lateral lower liner on BHA #13,tie in at flag for 10.5-ft correction,continue in hole, correction at K1 plus 2.5-ft,continue in hole. 17:12 17:24 0.20 10,992 10,992 COMPZ CASING RUNL P 10,992-ft, PUW 35k, release of liner at 1.38 bpm, PUW 25.5k, reset counters. 17:24 19:45 2.35 10,992 45 COMPZ CASING TRIP P POOH 19:45 20:15 0.50 45 45 COMPZ CASING OWFF P Tools at surface. No flow test. 20:15 20:45 0.50 45 0 COMPZ CASING PULD P PJSM for LD BHA#13(lower A lateral liner running assembly). LD BHA#13. 20:45 00:00 3.25 0 1,640 COMPZ CASING PUTB P PJSM for MU upper A lateral liner. MU ported bull nose, 53 jts 2 3/8", 4.6#, L-80, STL slotted liner, aluminum liner top billet. (BHA#14) Liner weight=6k lb. 35/19/2015 Finished completion on A lateral, Kicked off of billet at 7333', Drilled AL1 lateral from 7333'to 7940' 00:00 02:30 2.50 1,640 8,590 COMPZ CASING RUNL P RIH with BHA#14 02:30 02:43 0.22 8,590 8,629 COMPZ CASING DLOG P Tie in to K1 for+12.5'correction. 02:43 03:02 0.33 8,629 8,929 COMPZ CASING RUNL P RIH.Tag top of lower liner at 8930', PUW @ 8930'=30k, RBIH,pump online at 1.44 bpm, release liner, on bottom. 03:02 04:32 1.50 8,929 44 COMPZ CASING TRIP P POOH 04:32 05:02 0.50 44 44 COMPZ CASING SFTY P PJSM,check well for flow 05:02 05:41 0.65 44 0 COMPZ CASING PULD P LD Liner running BHA#14 05:41 06:59 1.30 0 72 PROD2 STK PULD P MU BHA#15 kick off/drilling assembly,0.9 AKO motor and HYC used Bi-center bit, MU to CoilTrak, surface test 06:59 08:29 1.50 72 7,030 PROD2 STK TRIP P RIH with BHA#15 08:29 08:41 0.20 7,030 7,070 PROD2 STK DLOG P Tie in at K1 for plus 13-ft correction, PUW 28k 08:41 09:41 1.00 7,070 6,943 PROD2 STK DISP P Displace hole to 9.3 ppg drilling fluid. 09:41 10:11 0.50 6,943 7,333 PROD2 STK TRIP P Trip in to dry tag billet 7333, PUH, PUW=26K 10:11 12:23 2.20 7,333 7,336 PROD2 STK MILL P Time mill off liner top billet, 1.4 BPM @ 3160 PSI FS, BHP=3460 12:23 13:29 1.10 7,336 7,380 PROD2 DRILL DRLG P Drill ahead, 10-20 FPH, 1.4 BPM @ 3084 PSI FS 13:29 13:41 0.20 7,380 7,380 PROD2 DRILL WPRT P PUH to dry drift billet,observed small overpull,-700LBs coming up, clean RIH, PUW=26K, 13:41 17:26 3.75 7,380 7,640 PROD2 DRILL DRLG P 7380',drill ahead, 1.4 BPM @ 3060 PSI FS, BHP=3495, RIW=9.9K Page 9 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:26 18:26 1.00 7,640 7,640 PROD2 DRILL WPRT P 7640',Wiper up hole to 7170', PUW 26k 18:26 23:26 5.00 7,640 7,940 PROD2 DRILL DRLG P 7640', BOBD 1.4 bpm at 3110 psi, BHP 3570,WHP 25, IA 137, OA 0 23:26 23:52 0.44 7,940 7,160 PROD2 DRILL WPRT P 7940',Wiper up hole PUW 25 23:52 23:58 0.11 7,160 7,358 PROD2 DRILL WPRT P 7160',Wiper back in hole RIW 11 05/20/2015 TD well 8252', displaced well to 11.4 ppg completion fluid, MU 37 jts of slotted liner,Started RIH 00:00 00:15 0.25 7,358 7,940 PROD2 DRILL WPRT P 7358', Continue wiper in hole back to bottom. RIW 11k 00:15 08:27 8.20 7,940 8,251 PROD2 DRILL DRLG P 7940', BOBD 1.40 bpm at 3100 psi, BHP 3521,WHP 0, IA 152, OA 0 08:27 10:27 2.00 8,251 83 PROD2 DRILL WPRT P 8,251',TD AL1 lateral, pump 10x10 sweep, perform wiper to the swab valves, PUW 26K. 10:27 11:48 1.35 83 7,035 PROD2 DRILL WPRT P 83.2', RIH to tie in depth 11:48 12:00 0.20 7,035 7,059 PROD2 DRILL DLOG P Tie into K1 marker for plus 13.5 ft. correction,WT check 25.5K 12:00 12:42 0.70 7,059 8,252 PROD2 DRILL WPRT P RIH to confirm TD, RIW 12:42 13:24 0.70 8,252 8,252 PROD2 DRILL TRIP P Tag TD©8252 Punp Beaded liner running pill 13:24 15:30 2.10 8,252 89 PROD2 DRILL TRIP P POOH laying in beaded liner running pill, Paint EOP flags @ 6900'and 5800' 15:30 16:00 0.50 89 89 PROD2 DRILL OWFF P Perform 30 Min no flo, PJSM lay down BHA#15 16:00 17:30 1.50 89 0 PROD2 DRILL PULD P Lay down BHA#15-Prep floor to run liner, Inspect top drive 17:30 19:15 1.75 0 0 PROD2 DRILL SFTY P I believe survey discussion with town team. 19:15 22:15 3.00 0 1,168 COMPZ CASING PUTB P PJSM, MU liner assembly 22:15 23:15 1.00 1,168 1,212 COMPZ DRILL PUTB P PJSM, MU BHI tools to liner 23:15 00:00 0.75 1,212 5,172 COMPZ DRILL RUNL P RIH,with AL1 liner assembly with 37 jts of slotted liner with shorty deployment sleeve. 05/21/2015 Release AL1 Liner @ 8252, TOL=7084', Roll well to seawater, Freeze protect from 2500', RDMO, Rig Release 15:00 00:00 00:24 0.40 5,172 7,000 COMPZ CASING RUNL P Continue RIH,with liner assembly 00:24 00:39 0.25 7,000 7,000 COMPZ CASING RUNL P Correction at 5800' EOP flag of plus 12.0'. PUW 29k 00:39 01:24 0.75 7,000 8,252 COMPZ CASING RUNL P Continue RIH with liner to bottom. 01:24 01:39 0.25 8,252 8,252 COMPZ CASING TRIP P 8252', Released liner on bottom 8252', leaving the TOL @ 7084.05' 01:39 03:39 2.00 8,252 2,500 COMPZ CASING DISP P POOH, displacing well to seawater. 03:39 04:57 1.30 2,500 0 DEMOB WHDBO FRZP P PJSM, RU Little Red, PT line 3500 psi,freeze protect well from 2500'to surface. 04:57 05:57 1.00 0 0 DEMOB WHDBO PULD P PJSM, Undeploy BHA 05:57 06:27 0.50 0 0 DEMOB WHDBO PULD P Crew change,Valve check list �_ �� Page 10 of 11 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:27 08:03 1.60 0 0 DEMOB WHDBO PULD P PJSM, PUD BHA#16 and lay down 08:03 10:03 2.00 0 0 DEMOB WHDBO CIRC P PJSM, Pull floats from UQC install nozzle. Stab on well. Pump pre flush,30 BBI inhibitor, and flush 10:03 11:39 1.60 0 0 DEMOB WHDBO MPSP P PJSM, R/U Lubricator, Set BPV, WHP=600PSI 11:39 15:00 3.35 0 DEMOB WHDBO NUND P PJSM, Nipple down stack, check stack bolts-found 7 on tree that needed tightening. Tightened all, RDMO, Rig release @ 15:00 Page 11 of 11 I 2T-08 WELL WORK SUMMARY e DATE SUMMARY POST-RIG WELL WORK 5/25/2015 MADE MULTIPLE MAGNET RUNS TO LINER TOP @ 7078' RKB. RECOVERED REAMINGS & CHUNKS OF METAL. MEASURED BHP @ 7075' RKB: 2936 PSI. SET CATCHER ON LINER TOP @ 7084' RKB. PULLED DV @ 5629' RKB. IN PROGRESS. 5/26/2015 PULLED DV'S @ 4499' &2694' RKB; SET OV @ 5629' RKB. SET GLV's @ 4499' &2694' RKB; (OBTAIN GOOD DDT ON IA) PULLED CATCHER @ 7084' RKB. JOB COMPLETE WELL LOG TRANSMITTAL DATA LOGGED 4/1/2015 M K.BENDER To: Alaska Oil and Gas Conservation Comm. May 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 2 1 2015 RE: Perforating Record: 2T-08 Run Date: 4/14/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20070-00 Same) JUN 1 2 ZQ15 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MA.17.a4orikiV) r��h�""` g PTD /8 ( - ! oq Loepp, Victoria T (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Friday, March 20, 2015 1:16 PM To: Loepp, Victoria T (DOA) Cc: Phillips, Ron L Subject: Amendment to PTD 186-109 Sundry 315-145, Plug KRU 2T-08 for Redrill Follow Up Flag: Follow up Flag Status: Flagged Victoria—As we discussed, the operations summary submitted with the plugging sundry 315-145 that was just approved for KRU 2T-08 failed to include a necessary step. ConocoPhillips intends to perforate the 7" casing at 7142'-7152' MD, which is adjacent to the CTD kickoff depth, in order to cement squeeze this interval. We think the cement squeeze will improve our chance of getting a successful window exit. I have attached an update operations summary and proposed schematic with the revisions shown in red. Please let me know if I can provide you with any further information. 2T-08 CTD 2T-08 Pre rig Summary for Su... schematic.pdf J. Gary Eller SCAMS MAR 2 5 2015 Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 1 KRU 2T-08 CTD Summary for Perfin2 & Plugging Sundry (10-403) Summary of Operations Background Well 2T-08 is a Kuparuk A-sand producer(development)well equipped with 3Y2"tubing and 7" production casing. Two laterals from well 2T-08 will be drilled,one to the south(2T-08A)to augment A-sand production from the suspended 2T-13 and one to the north(2T-08AL1). CTD operations will target the A3 sand. Well 2T-08 was completed into the Kuparuk A-sand interval in 1986 as a single completion. A RWO was performed Feb 2013 replacing the 3-1/2"completion,replacing the top 1985' of 7" casing and cementing the 7"x 9-5/8"annulus up to surface. Prior to CTD operations,the existing A-sand perfs in will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. Immediately prior to cementing the A-sand perfs the tubing tail will be perforated. In addition, we will shoot squeeze perforations adjaLcnt ,,, ih ( l i ) 4.icKO)f depth to reduce the likelihood of problems during the window milling. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A-sand perfs with cement pre-rig,the Nabors CDR2-AC drilling rig will drill a pilot hole to 7170' and set a whipstock in the 2.80"pilot hole at the planned kickoff point. Both laterals will exit through the 7"casing at 7140' MD and will target the A3 sand. Both laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 31/2"tubing. Pre-CTD Work 1. Slickline: Dummy all GLVs. 2. E-line: Shoot 2' of holes in the 3'/s"tubing tail at 7070' MD& 10' of squeeze perfs at 7142'-7152' MD. 3. Coil: Cement squeeze the A-sand perfs bringing cement up into the tubing tail. 4. Slickline: Drift tubing,tag top of cement and pressure test. 5. 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. 2. 2T-08A Sidetrack(A3 sand-south) a. Drill 2.80"high-side pilot hole through cement to 7,170' MD b. Caliper pilot hole c. Set whipstock at 7140' MD d. Mill 2.80"window at 7140' MD e. Drill 3-1/4"bi-center lateral to TD of 11,000' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 7,200' MD 3. 2T-08AL1 Lateral(A3 sand-north) a. Kick off of the aluminum billet at 7,200' MD b. Drill 3-1/4"bi-center lateral to TD of 8,300' MD Page 1 of 2 March 20,2015 c. Run 23/s" slotted liner from TD up to 7,083' MD, inside the 3Y2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 March 20,2015 2T-08 Pre-Rig Schematic Modified by JOE 3-20-15 DS-nipple at 501'MD(2.875"min ID,No-Go) 3-1/2",9.3#,L-80,EUE 8rd Mod Tubing to surface 16",62.5#,H-40 1' !— shoe at 115'MD 3-1/2"Camco MMG gas lift mandrels at 2694',4499',5629', 6360',&6909'MD 9-5/8",36#,J-55 shoe at 2977'MD IJ I —"� Baker Locator at 6965' Baker 3-1/2"80-40 PBR at 6973'MD Baker FHL packer 6995'MD ITOC 7060'MD I D-nipple at 7078'MD(2.813"min ID,No-Go) Tubing tall perfs(a 7070'MD J 3-1/2"tubing tail at 7091'MD Note:All these completion depths(from the tubing tally dated 14-Feb-15) are 17'shallow compared the the Halliburton Jewelry dated 8-Jan-15 which is on depth with the Gearhart CBL log dated 10-Oct-86 and the Squeeze perfs 714T-7152'MD PDC log. A-sand perfs 1 I 7188'-7192'MD 7202'-7228'MD 7" 26#casing at 7600'MD 0'-1985': L-80,TC-II� 1985'-7600': J-55,BTC nip I - 1O � Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, March 20, 2015 1:21 PM To: 'Eller,J Gary' Subject RE:Amendment to Sundry 315-145, Plug KRU 2T-08 for Redrill Gary, These revisions are approved. Please update the approved sundry with these revisions. Thanx, Victoria Victoria Loepp iCANNED MAR 2 « ,1,01,; Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Friday, March 20, 2015 1:16 PM To: Loepp, Victoria T(DOA) Cc: Phillips, Ron L Subject: Amendment to Sundry 315-145, Plug KRU 2T-08 for Redrill Victoria—As we discussed, the operations summary submitted with the plugging sundry 315-145 that was just approved for KRU 2T-08 failed to include a necessary step. ConocoPhillips intends to perforate the 7"casing at 7142'-7152' MD, which is adjacent to the CTD kickoff depth, in order to cement squeeze this interval. We think the cement squeeze will improve our chance of getting a successful window exit. I have attached an update operations summary and proposed schematic with the revisions shown in red. Please let me know if I can provide you with any further information. « File: 2T-08 CTD Summary for Sundry 3-20-15.doc» « File: 2T-08 Pre rig schematic.pdf» 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 1 KRU 2T-08 CTD Summary for Perfing & Plugging Sundry (10-403) Summary of Operations Background Well 2T-08 is a Kuparuk A-sand producer(development)well equipped with 3%"tubing and 7" production casing. Two laterals from well 2T-08 will be drilled,one to the south(2T-08A)to augment A-sand production from the suspended 2T-13 and one to the north(2T-08AL1). CTD operations will target the A3 sand. Well 2T-08 was completed into the Kuparuk A-sand interval in 1986 as a single completion. A RWO was performed Feb 2013 replacing the 3-1/2"completion,replacing the top 1985' of 7" casing and cementing the 7"x 9-5/8"annulus up to surface. Prior to CTD operations,the existing A-sand perfs in will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. Immediately prior to cementing the A-sand perfs the tubing tail will be perforated. In addition, we will shoot squeeze perforations adjacent to the CTD kickoff depth to reduce the likelihood of problems during the window milling. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A-sand perfs with cement pre-rig,the Nabors CDR2-AC drilling rig will drill a pilot hole to 7170' and set a whipstock in the 2.80"pilot hole at the planned kickoff point. Both laterals will exit through the 7"casing at 7140' MD and will target the A3 sand. Both laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 3%"tubing. Pre-CTD Work 1. Slickline: Dummy all GLVs. 2. E-line: Shoot 2' of holes in the 3%"tubing tail at 7070' MD& 10' of squeeze perfs at 7142'-7152' MD. 3. Coil: Cement squeeze the A-sand perfs bringing cement up into the tubing tail. 4. Slickline: Drift tubing,tag top of cement and pressure test. 5. 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. 2. 2T-08A Sidetrack(A3 sand-south) a. Drill 2.80"high-side pilot hole through cement to 7,170' MD b. Caliper pilot hole c. Set whipstock at 7140' MD d. Mill 2.80"window at 7140' MD e. Drill 3-1/4"bi-center lateral to TD of 11,000' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 7,200' MD 3. 2T-08AL1 Lateral(A3 sand-north) a. Kick off of the aluminum billet at 7,200' MD b. Drill 3-1/4"bi-center lateral to TD of 8,300' MD Page 1 of 2 March 20,2015 c. Run 2%"slotted liner from TD up to 7,083' MD, insiae the 3V2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 March 20,2015 2T-08 Pre-Rig Schematic Modified by JGE 3-20-15 DS-nipple at 501'MD(2.875"min ID,No-Go) I 3-1/2",9.3#,L-80,EUE 8rd Mod Tubing to surface 16",62.5#,H-40 shoe at115'MD 3-1/2"Camco MMG gas lift mandrels at 2694',4499',5629', • 19-5/8",36#,J-55 6360',&6909'MD {shoe at 2977'MD J �� Baker Locator at 6965' Baker 3-1/2"80-40 PBR at 6973'MD Baker FHL packer 6995'MD ITOC CO 7060'MD -- D-nipple at 7078'MD(2.813"min ID,No-Go) Tubing tall parts©7070'MD - 3-1/2"tubing tail at 7091'MD Note:All these completion depths(from the tubing tally dated 14-Feb-15) are 17'shallow compared the the Halliburton Jewelry dated 8-Jan-15 which is on depth with the Gearhart CBL log dated 10-Oct-86 and the (Squeeze perts 7142'-7152'MD PDC log. A-sand perfs 7188'-7192'MD 7202'-7228'MD — �6 7",26#casing at 7600'MD 0-1985: L-80,TC-II 1985-7600': L__ J-55,BTC Tye Alaska Oil and Gas \°\1:1 THE STATE -s� � ofALASIt:A Conservation Commission _ _ f }£'= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF *M P. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov W1NV '42 SCOIttl Ron Phillips CTD Engineer °CI \C6ConocoPhillips Alaska, Inc. (i(ji° P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-08 Sundry Number: 315-145 Dear Mr. Eller: 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, al6i/ Cathy P. Foerster Chair DATED this I day of March, 2015 Encl. STATE OF ALASKA r A. ,KA OIL AND GAS CONSERVATION COMPv,..,SION • APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request: Abandon """" Rug for Redrill F7 Perforate New Pool r Repair w ell r Change Approved Program r Suspend 1 Rug Perforations p Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r'. 186-109 ' 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20070-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No r KRU 2T-08 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7676 • 6186 - 7513' ` 6057' ' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115' 115' SURFACE 2943 9.625 2977' 2798' RECEIVED PRODUCTION 5615 7 7600' 6126' MAR 132015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft)• 7188-7192,7202-7206,7208-7228 ° 5805-5808,5815-5819,5820-5835 3.5 L-80 7091 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PRODUCTION PACKER W/4.13-FT PUP MD=6995 TVD=5658 NIPPLE-CAMCO DS NIPPLE w/2.875"PROFILE MD=501 TVD=501 . 12 Attachments: Description Surrrnary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p. • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2015 Oil r Gas r WDSPL r Suspended r . 16.Verbal Approval: Date: VVINJ 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: Ron Phillips @ 265-6312 Email: Ron.L.Phillips@conocophillips.com Printed Name Ron Phillips Title: CTD Engineer ))) Signature h�' Phone:263-6312 Date 3//////` " VVVV Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3(5.-/41 Plug Integrity r BOP Test 1'7-Mechanical Integrity Test r Location Clearance r Other: bop t r5 7`' i_o 3.5_0 v psi (Avt)7 5p >S Z 5,7 3 p s /1A- v1vlcr - pre'ye-vah-r 71--z-5 r i-o Zrev pSr /4/fCfr- fc p/may pIetCtvvrr-h �' 4rpv-ovrd p r r 2° - -,-C z5-. 1 / 2Ci Spacing Exception Required? Yes ❑ No 1E( Subsequent Form Required: /a— 4 0 APPROVED BY Approved by: i •` ' - COMMISSIONER THE COMMISSION Date -/'' _/ r�y(e• I t`o l v Ildlfor 12 mo th r r1the date of approval.l�>'L3/!4 �� ) 'ppl 1 � � 1 � L ` �S _ pp 3-��Required?(Revised �� RBDMS.J� MAR 20 2015 KRU 2T-08 CTD Summary for Perfing & Plugging Sundry (10-403) Summary of Operations ,,' IPSP S 25-73 p 5 i PTP Z5-Z Background ZT—G 8 Well 2T-08 is a Kuparuk A-sand producer(development)well equipped with 31/2"tubing and 7" production casing. Two laterals from well 2T-08 will be drilled, one to the south (2T-08A)to augment A-sand production from the suspended 2T-13 and one to the north(2T-08AL1). CTD operations will target the A3 sand. Well 2T-08 was completed into the Kuparuk A-sand interval in 1986 as a single completion. A RWO was performed Feb 2013 replacing the 3-1/2" completion, replacing the top 1985' of 7" casing and cementing the 7"x 9-5/8"annulus up to surface. Prior to CTD operations,the existing A-sand perfs in will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in this manner. Immediately prior to cementing the A-sand perfs the tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A-sand perfs with cement pre-rig,the Nabors CDR2-AC drilling rig will drill a pilot hole to 7170' and set a whipstock in the 2.80"pilot hole at the planned kickoff point. Both laterals will exit through the 7"casing at 7140' MD and will target the A3 sand. Both laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 31/2"tubing. n'0 ie vec re eet necQSj of, - PfD�Qfpv 1/f R feces�� ln.✓ ( l`'T'�� NIS i n �(/✓�`� / PafOr1617`9y Pre-CTD Work N /'Vb( {Hr/ �✓r IA//149 5/°719"1. Slickline: Dummy all GLVs. -n�� �. d T�vs 2. E-line: Shoot 2' of holes in the 31/2"tubing tail at 7053' MD. G 4/ ie, C4 f Itedly 3. Coil: Cement squeeze the A-sand perfs bringing cement up into the tubing tail. -del 4. Slickline: Drift tubing,tag top of cement and pressure test. rhe fg f ✓U 5. Prep site for Nabors CDR2-AC, including setting BPV ore CvW(t 7 Compp Pro Givice Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. , 2. 2T-08A Sidetrack(A3 sand -south) a. Drill 2.80"high-side pilot hole through cement to 7,170' MD b. Caliper pilot hole c. Set whipstock at 7140' MD d. Mill 2.80"window at 7140' MD e. Drill 3-1/4"bi-center lateral to TD of 11,000' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 7,200' MD 3. 2T-08AL1 Lateral(A3 sand - north) a. Kick off of the aluminum billet at 7,200' MD b. Drill 3-1/4"bi-center lateral to TD of 8,300' MD c. Run 2%" slotted liner from TD up to 7,083' MD, inside the 31/2'tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 1 of 2 March 9, 2015 Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 March 9, 2015 Co U1 N c-i co 10 Oo) M U 0 J cc ^O N Y >• 0o m 0 C N 0 v z m m Z v= Q c H m EO • o - C n .ng E (O)Q 0 w = m� co - Fi W m 'n CD o) Q CD d Q p n u1 0 rn CO g L] (o CJ L Co E0 22 mo Z5 0 VO 0"_°3 0. h CDro O7 (0 N J C a) co m� o7 W Z. 0) Uoo JS)L=L 0 w a - _ C N CVO iN G) 4) 2 o.- CV ch _-(o .. - - C i i co (a (c (0 , i Q co MCO mmm 0 C1) I iia IlLi' _______i U E 0 I Q U U) o�m `"' Na00 b ��� CD o Q co ct Q .'�.. 2 co --i j ((� �h 0-N N u) O t`ti U U �� mN va , p (moo 0co c4 ru co 03 1.0 ,O CD CD CD Co o <N-N CD �!oa) Zo.c ti N rn a)y 0) LO N r-I CO cI Lo0) MM U ..a- o_ D_ fa V cc O y >. 0 O CMO 0Q O N O TS v Z m m Z co 0 Ci— -0 c F O C o E O EEco 2 E co MD M W ca m .N... 0) co M cO co 2 O 0"(--6 I" N Co o' O W O O o n .0+ to J O _co (p O U E 0) V n. ~ C ) co co CO U — co o_ 1 A a C CV (V O N N N fl_- N i i c,-) cC c0 c0 O 0 M Mco m0]m 6 M 1 ii ii I V TinillillArill RI E T TT ,_,_ . I 0 0 0 in 'm0 cr.aa ��� I— 0 a0 a n �2 2 �� CO GNI Q) L S —a1....., >O N N C O C7) CD LO,- CO N N I— � O ' ' V Ea t; CO N O 0)N W 0 CO - N 0 W o co 0)L) CO ai - O CC)Co 0 Q 1-1- N O m N Zo N 0 M 0 KUP PROD 2T-08 ConocoPhillips o Well Attributes Max Angle&MD TD A/aska,Il1C. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) r r.cu,;n,ll,p, 501032007000 KUPARUK RIVER UNIT PROD 4825 1000.00 7,676.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 27-06,3/1/201510:542 AM SSSV:Flapper Locked Out 25 11/1/2014 Last WO. 2/6/2013 40.10 7/22/1986 Vertical schematic factual) Annotation Depth(868) End Date Annotation Last Mod By End Date Last Tag:SLM 7,331.0 12/23/2014 Rev Reason: H2S UPDATE lehallf 3/1/2015 ._... ;...................._.._ HANGER;2 2 6.3 Casing SfHngs Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len IL..Grade lop Thread SURFACE 95/8 8.765 33.6 2,976.8 2,798.4 36.00 J-55 BUTT ,,.. ,, .. IDOL Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread Production 2073 Tie-back 7 6.276 33.6 1,985.0 1,975.3 26.00 L-80 TC-Il -/'.."-"CONDUCTOR:37.0115.0L •w/..r1".Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 1,985.0 7,600.0 6,125.8 26.00 J-55 BUTT - Tubing Strings 1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(INR) Grade Top Connection • NIPPLE:501.4 uzi TUBING WO 3 1/2 2.992 28.3 7,091.0 5,730.9 9.30 L-80 EUE-ABM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 28.3 28.3 0.10 HANGER TUBING HANGER 7"X 3-1/2"McEvoy Type DP-1-D-S-3 2.992 • 5 501.4 501.4 0.67 NIPPLE - CAMCO DS NIPPLE w/2.875"PROFILE 2875 6,965.0 5,635.1 40.57 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/21.74-ft of seals 2.970 • Production 2073 Tie-bads;33.8- spaced out 7-ft 7,905.0 I6,972.9 5,641.1 40.56 PBR BAKER 80-40 PBR 2.990 6,995.3 5,658.1 40.53 PACKER BAKER FHL PRODUCTION PACKER w/4.13-ft Pup 2.940 ' 7,078.3 5,721.3 40.52 NIPPLE CAMCO 2.812"DS NIPPLE 2.812 GAS LIFT;2,694.0 7,089.7 5,729.9 40.52 WLEG 3 1/2"WLEG 2.950 Perforations&Slots f Shot Dens Top(TVD) Btm(TVD) (shotslf Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,188.0' 7,192.0 5,804.8 5,807.8 A-3,2T-08 3/3/2013 5.0 RPERF 6W Ph,Millenium 7,188.0 7,192.0 5,804.8 5,807.8 A-4,2T-08 10/14/1986 1.0 CMT 90 deg.Ph;4"HyperJet SURFACE;33.6-2,976.8- SQZ II _ 7,202.0' 7,206.0 5,815.4 5,818.5 A-3,2T-08 10/14/1986 1.0 CMT 90 deg.Ph;4"HyperJet 1SQZ II GAS LIFT,4.498 9 7,202.0 7,206.0 5,815.4 5,818.5 A-3,2T-08 3/3/2013 5.0 RPERF 60°Ph,Millenium 7,208.0 7,228.0 5,820.0 5,835.3 A-3,2T-08 10/14/1986 4.0 CMT 90 deg.Ph;4"HyperJet SQZ II 7208.0 7,228.0 5,820.0 5,835.3 A-3,2T-08 3/3/2013 5.0 RPERF 60"Ph,Millenium Mandrel Inserts St GAS LIFT,5.629.1 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com - 1 2,694.0 2,596.0 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,230.0 3/11/2013 2:00 __ 2 4,498.9 3,838.7 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,224.0 3/11/2013 5:30 3 5,629.1 4,644.4 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,212.0 3/11/2013 5:30 4 6,360.3 5,179.2 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,202.0 3/11/2013 10:00 GAS LIFT,6.360.3 5 6,909.4 5,592.9 Camco MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 3/11/2013 7:00 Notes:General&Safety End Date Annotation 12/1/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;6.909.4 SEAL ASSY;6,965.0 PER;6.9729 PACKER;6995.3 NIPPLE',7,078.3 WLEG;7,089.7 CMT ;77,118888.°0-.77,119922.001_-- - RPERF,5021 . 1 CMT SO2;7.2020-7.206.0 RPERF;7.208.0.7,228.0 ..-- Cyr SO2;7.208.0.7228.01 - PRODUCTION,1 985.0.7,6000 • 253(02! WELL LOG TRANSMITTAL DATA LOGGED j. 6/2ND01 K BE To: Alaska Oil and Gas Conservation Comm. January 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 6f ED FEB 05 :015 RE: Multi Finger Caliper(MFC) : 2T-08 Run Date: 1/8/2015 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 2T-08 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20070-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'l'I'ENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. CANNEL 1.:(3 ,) j Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:Ma •-4) _E'ot Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) ~,-~wo-Sided RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: Other: DIGITAL DATA [] [~iskettes, No. [] Other, No/Type TOTAL PAGES: y,~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: (at the time of scanning) SCANNED BY; ~"~BEVERL'~Y BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA VD AL (A OIL AND GAS CONSERVATION CONOSION MAR 0 a 2013 REPORT OF SUNDRY WELL OPERATIONS t.Operations Performed: Abandon [ Repair well I✓ Rug Perforations r'- Perforate F Other j,AO C Alter Casing I Pull Tubing ( Stimulate-Frac I"-` Waiver F Time Extension l Change Approved Program FOperat. Shutdown F Stimulate-Other F Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska, Inc. Development ( Exploratory F 186-109 3.Address: 6.API Number: — P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ] Service I 50-103-20070-00 —00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0025569 .. 2T-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7676 feet Plugs(measured) 7078 true vertical 6186 feet Junk(measured) none Effective Depth measured 7513' feet Packer(measured) 6995 true vertical 6057' feet (true vertical) 5658 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 1951 9.625 2977 2798 PRODUCTION 2943 7 7600 6126 Perforation depth: Measured depth: all perfs cemented d1 �� True Vertical Depth: cemented SCANNED AU G 0 Tubing(size,grade,MD,and ND) 3.5, L-80,7091 MD,5731 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PRODUCTION PACKER W/4.13-FT PUP @ 6995 MD and 5658 ND SSSV-CAMCO DS NIPPLE @ 501 MD and 501 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory I— Development l✓ . Service F Stratigraphic F 16.Well Status after work: 'Oil Ii Gas F WDSPL F Daily Report of Well Operations_(XX GSTOR F WINJ F WAG F GINJ F SUSP F SPLUG F 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-487 Contact Erik Nelson ( ,263-4693 Email Erik.Nelsona.conocophillips.com Printed Name Erik Nelson Title Wel ngineer ff/ Signature Phone:263-4693 Z 1/Date / %cZ. /3 REIMS MAR 0 7 2013 .dam r F /13 Form 10-404 Revised 10/2012 �` '@[°, Submit Original Only 8 ConoccphiIlips Alaska,Inc. Wel Conf8'.-2T-08,3/3/2013 600:00 AM Schematic-Actual HANGER,28 CONDUCTOR. 37-115 NIPPLE,501 Production 2013 Tie back, 34-1,985 GAS LIFT, 2,694 SURFACE, 34-2,977 GAS LIFT. 4,499 GAS LIFT. 5.629 GAS LIFT, 6,360 GAS LIFT, 6,909 SEAL.ASSY, 8,985 PBR,8.973 PACKER,8,995 CATCHER, 7,075 NIPPLE,7,078 PLUG.7,078 WLEG,7,090 RPERF, 7,188-7,192 CMT SOZ, 7,188-7,192 ------�_ CMT SQZ, 7,202-7,208 CMT S02, 7.208-7.228 522, RPERF, RPERF, 7,208-7,228 CEMENT CEMENT PLUG,7,080 PRODUCTION, 1,985-7,600�� TD,7,fi76 KUP • 2T-08 Well Attributes Max Angle&MD TD Wellbore APWWI 501032007000 Field Name KUPARUK RIVER UNIT Well Status PROD Ind(°) 48.25 MD MKS) 3,000.00 Act Btm(MB) 7,676.0 Comment SSSV:Flapper Locked Out H2S(ppm) 25 Date 1/17/2010 Annotation Last WO: End Date 2/6/2013 KB-Grd(R) 40.10 Rig Release Date 7/22/1986 Annotation Last Tag:TOC Depth(ftKB) 7,080.0 End Date 1/26/2011 Annotation Rev Reason:WORKOVER Last Mod... osborl End Date 2/25/2013 Casing Strings Casing Description CONDUCTOR String 0... 16 String ID... 15.062 Top(ftKB) 37.0 Set Depth(f... 115.0 Set Depth(TVD)... 115.0 String Wt... 62.58 String... H-40 String Top Thrd WELDED Casing Description SURFACE String 0... 95/8 String ID... 8.765 Top(ftKB) 33.6 Set Depth(f... 2,976.8 Set Depth(TVD)... 2,798.4 String Wt... 36.00 String... J-55 String Top Thrd BUTT Casing Description Production 2013 Tie-back String 0... 7 String ID... 6.276 Top(ftKB) 33.6 Set Depth(f... 1,985.0 Set Depth(TVD)... 1,975.3 String Wt... 26.00 String... L-80 String Top Thrd TC-II Casing Description PRODUCTION String 0... 7 String ID... 6.276 Top(RKB) 1,985.0 Set Depth(T... 7,600.0 Set Depth(TVD)... 6,125.8 String Wt.. 26.00 String... J-55 String Top Thrd BUTT Tubing Strings Tubing Description TUBING WO String 0... 3 1/2 String ID... 2.992 Top(MB) 28.3 Set Depth(f... 7,091.0 Set Depth(TVD)... 5,730.9 String Wt... 9.30 String... L-80 String Top Thrd EUE-ABM Completion Details Top(ftKB) Top Depth (TVD) (ftKB) Top Inc! (1 Item Description Comment Nona- ID(in) 28.3 28.3 0.35 HANGER TUBING HANGER 7"X 3-1/2"McEvoy Type DP-1-D-S-3 2.992 501.4 501.4 0.67 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 6,965.0 5,635.1 40.53 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/21.74-h of seals spaced out 7-ft 2.970 6,972.9 5,641.1 40.53 PBR BAKER 80.40 PBR 2.990 6,995.3 5,658.1 40.53 PACKER BAKER FHL PRODUCTION PACKER w/4.13-ft Pup 2.940 7,078.3 5,721.3 40.57 NIPPLE CAMCO 2.812"DS NIPPLE(CA-2 plug w/3-ft catcher"G"FN) 2.812 7,089.7 5,729.9 40.54 WLEG 3 1/2"WLEG 2.950 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ftKB) Top Depth (TVD) Top Incl (RKB) (1 Description Comment Run Date ID(in) 7,075.3 5,719.0 40.58 CATCHER CATCHER SUB SET ON CA-2 PLUG 2/4/2013 0.000 7,078.3 5,721.3 40.57 PLUG CA-2 PLUG SET IN DS NIPPLE 2/4/2013 0.000 Perforations&Slots Top(ftKB) Btm(ftKB) Top(TVD) (ftKB) Btm(TVD) (ftKB) Zone Date Shot Dens (sh••• Type Comment 7,188.0 7,192.0 5,804.8 5,807.8 A-3,2T-08 3/3/2013 5.0 RPERF 60°Ph,Millenium 7,188.0 7,192.0 5,804.8 5,807.8 A-4,2T-08 10/14/1986 1.0 CMT SQZ 90 deg.Ph;4"HyperJet II 7,202.0 7,206.0 5,817.2 5,820.1 A-3,2T-08 10/14/1986 1.0 CMT SQZ 90 deg.Ph;4"HyperJet II 7,202.0 7,206.0 5,817.2 5,820.1 A-3,2T-08 3/3/2013 5.0 RPERF 60°Ph,Millenium 7,208.0 7,228.0 5,821.5 5,836.2 A-3,2T-08 10/14/1986 4.0 CMT SQZ 90 deg.Ph;4"HyperJet II 7,208.0 7,228.0 5,821.5 5,836.2 A-3,2T-08 3/3/2013 5.0 RPERF 60°Ph,Millenium Notes:General&Safety End Date Annotation 12/12010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details N... Top(RKB) Top Depth (TVD) (ftKB) Top Inc' (°) Make Model OD (in) Sent Valve Type Latch Type Port Size (In) TRO Run (psi) Run Date Com... 1 2,694.0 2,595.9 39.28 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/4/2013 2 4,498.9 3,838.7 45.22 Camco MMG 1 1/2 GAS LIFT DMY RK 0,000 0.0 2/4/2013 3 5,629.1 4,644.6 44.42 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/4/2013 4 6,360.3 5,179.3 41.94 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/4/2013 5 6,909.4 5,592.9 40.54 Camco MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 2/4/2013 • 2T-08 Pre-Rig Well Work • DATE SUMMARY 11/2/2012 (PRE-RIG) CMITTXIA-PASSED; TORQUED T LDS TO 450FT/LBS; RE-ENERGIZED IC PO. T PPPOT- PASSED; T POT-PASSED; IC PPPOT-FAILED WITH LOSS OF 150 PSI IN 1ST 15 MIN & LOSS OF 200 PSI IN 2ND 15 MIN; IC POT-PASSED. LDS FUNCTION TESTED OK. • • ConocoPhitlips Time Log & Summary We1Mew Web Reporting Report Well Name: 2T-08 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/7/2013 1:00:00 AM Rig Release: 2/7/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/05/2013 24 hr Summary Set Nordic 3 down on 2Z-Pad and wait on weather 16:00 00:00 8.00 MIRU MOVE OTHR T Set Nordic 3 down on 2Z-Pad waiting on weather-Phase II field wide- unable to travel. 01/06/2013 Nordic 3 down on 2Z pad waiting on weather. Move Rig from 2Z pad to 2T-08.MIRU. 00:00 09:00 9.00 MIRU MOVE MOB T Set Nordic 3 down on 2Z-Pad waiting on weather-Phase I I field wide- unable to travel. 09:00 11:00 2.00 MIRU MOVE MOB P Move Nordic rig 3 off 2Z Pad to Spine road. 11:00 13:00 2.00 MIRU MOVE MOB P Move Nordic rig 3 from 2Z Pad entrance to 2C Pad Entrance 13:00 15:00 2.00 MIRU MOVE MOB P Move Nordic rig 3 from 2C Pad Entrance to CPF 2 -set down and check tires 14:00 hrs. 15:00 17:00 2.00 MIRU MOVE MOB P Begin moving from CPF 2 to 2B Pad exit. 17:00 19:00 2.00 MIRU MOVE OTHR P Set down for CPF 2 field change out 19:00 23:00 4.00 MIRU MOVE MOB P Begin moving Nordic rig 3 from 2B Pad exit to 2T pad. 23:00 00:00 1.00 MIRU MOVE MOB P Nordic rig 3 set down on 2T-08, PJSM-lay down 30 x 30 around well, set T-mats. 01/07/2013 MIRU. PT kill line at 250/3,500 psi. Lubricate out BPV. Bleed off well and Monitor for flow. Set BPV. ND Tree and NU BOPE. 00:00 02:30 2.50 MIRU MOVE MOB P Continue to set T-mats,ground around tree not level,place tubing spool,cement cross behind well and hang tree in cellar. lay down 100 x 50 with plywood. Nordic Rig was accepted @ 01:00 _ hrs on 1-7-13 02:30 12:00 9.50 MIRU MOVE MOB P PJSM-Move and center over well, level,shim and set down over 2T-08, Set cuttings box and ancillary equipment. Berm up cellar. RU hard line. 12:00 13:00 1.00 MIRU WHDBO PRTS P Blow air through kill line,flush kill line with 15 bbls of SW. Close valves at Tanks. PT kill line at 250/ 3,500 psi-good test. 13:00 15:00 2.00 MIRU WHDBO MPSP P RU lubricator and PT @ 1,000 psi. Pull BPV and bleed off pressure. RD Lubricator. Page 1 of 28 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 MIRU WHDBO OWFF P Open up well and gather pressures. 20 psi TBG,0 psi IA,0 psi OA. Bleed off TBG pressure to 0 psi. Monitor well for flow-No flow. 18:00 18:30 0.50 MIRU WHDBOMPSP P Dry rod BPV 18:30 23:30 5.00 MIRU WHDBO NUND P ND tree, rig up spreader bar and use overhead crane to remove tree. Inspect threads and install test plug. RU 2"hose to OA. (Containment under rig not bermed up as of 21:00,get on it) 23:30 00:00 0.50 MIRU WHDBO NUND P PJSM-NU BOPE to leaning tree. NU BOPE. 01/08/2013 NU BOPE. Conduct BOPE Test 250/3500 psi. Pull BPV. MU Landing Joint and un-land TBG.Circulate well to 8.6 ppg SW. Start pulling 2-7/8"gas lift completion. Corkscrewed Tubing found between joints 8 through 18. 00:00 06:00 6.00 0 0 MIRU WHDBO NUND P Continue to NU BOPE. 06:00 13:30 7.50 0 0 MIRU WHDBO BOPE P RU test equipment,Shell test-Gray loc leaking. Conduct Initial BOPE Test @ 250/3,500 psi w/2-7/8 and 3-1/2"test joints. 48 hr notice was given to AOGCC on 1-6-13 @ 05:30 hrs and Right to witness was waived by Bob Noble on 1-7-13 @ 18:15 hrs. Conduct Draw down System Pressure-2,950 psi After Closure-1,800 psi 200 PSI gain-15 seconds System Pressure-91 Seconds 4-N2 bottle ave.-2,000 psi 13:30 15:30 2.00 0 0 MIRU WHDBO MPSP P Drain stack, Dry rod out the test plug. 15:30 16:00 0.50 0 7,050 COMPZ RPCOM OTHR P MU landing pups, BOLDS,w/TD slacked off. Seen 6 inches of TBG growth,had 24"to block wt of 35k from 25k. 16:00 17:00 1.00 7,050 7,035 COMPZ RPCOM PULL P PU to 115k,45k over estimated string wt of 70k. work up and down from 115k to 50k seen no movement. Pull to 115k and pressure up on TBG string to 980 psi. Work string from 115k to 50k and seen movement continue to pull seals from PBR. Bleed off pressure to zero and continue to pull seals from PBR. Monitor well-diesel cap rising due to out of balance. Close annular and prepare to circulate change hole over to sea water. 17:00 19:30 2.50 7,035 7,035 COMPZ RPCOM CIRC P PJSM,Circulate 8.6 ppg SW to Kill Tank at 4 bpm. ICP 550 psi, FCP 890 psi. Pumped 384 bbls,366 bbls returned. BDHL 19:30 20:00 0.50 7,035 7,035 COMPZ RPCOM PULD P LD Landing Joint. LD Hanger, BDTD Page 2 of 28 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 20:00 20:30 0.50 7,035 7,035 COMPZ RPCOM OWFF P NFT for 30 minutes,static 20:30 00:00 3.50 7,035 5,293 COMPZ RPCOM PULL P PJSM, POOH from 7050'. Up 85k#, down 70k#to 5293'spooling up control line. Recovered 30 of 31 bands. RD Spooler and LD SSSV. 01/09/2013 Continue laying down 2-7/8"gas lift completion. RIH with 7"Casing Scraper ad 6-1/8"bit to 107'-stack out, RIH with Casing Scraper and 4-3/4"Mule Shoe to 145'-stack out, Remove DC from BHA and RIH to 363'- stack out. Pump SW with 776 Friction Reducer and work to 381'-stack out. RIH with BHA#4,6-1/8"Bit and Bit Sub with no problems to 3001'and Reverse Circ 2 BU. POOH and prepare for E-line. 00:00 09:00 9.00 5,293 0 COMPZ RPCOM PULL P Continue POOH with 2-7/8" Completion from 5293'67k#up,61k# down. Tubing in good condition and pull out with little to no over pull. 09:00 12:00 3.00 0 0 COMPZ WELLPF OTHR P Clean and Clear Rig floor of de-completion. Change over to 3 1/2 DP equipment. 12:00 13:00 1.00 0 107 COMPZ WELLPF PULD P PU and RIH w/BHA#1 (Casing Scraper w/6-1/8"Bit)took weight @ 70-ft,worked and was able to reach total depth of 107-ft. Unable make any more hole, POOH and 6-1/8"Bit. 13:00 14:00 1.00 107 237 COMPZ WELLPF PULD P MU 4-3/4"Mule Shoe and RIH w/ BHA#2(Casing Scraper w/4-3/4" Mule shoe)took weight @ 145-ft, worked and was able to reach total depth of 237-ft. Unable make any more hole, POOH and Drop DC's from BHA. 14:00 16:30 2.50 237 381 COMPZ WELLPF PULD P RIH w/BHA#3(Casing Scraper w/ 4-3/4"Mule shoe and"No DC's"took weight @ 363-ft,worked,pumped 5 bpm with 776&SW @ 50 psi was able to reach total depth of 381-ft while working the string. POOH and lay down BHA#3 16:30 21:00 4.50 381 3,001 COMPZ WELLPF PULD P MU BHA#4(6.125"Bit and Bit sub) RIH past 381-ft with no problems. Continue to PU and RIH w/3 1/2 DP to 3,001-ft. Up 70k#,down 82k#. 21:00 22:30 1.50 3,001 3,001 COMPZ WELLPF CIRC P PJSM, Reverse Circulate 160 bbls at 5 bpm. ICP 520 psi, FCP 400 psi. 22:30 23:00 0.50 3,001 3,001 COMPZ WELLPF OWFF P Perform NFT for 30 minute. Static. Move Drill Collars to Drillers Side. 23:00 00:00 1.00 3,001 582 COMPZ WELLPF PULD P POOH to 582', Up wt 48k#. NFT 15 minute,Static. 01/10/2013 Log HES CAST-M from 7048'to surface. Top of Cement Stringers at 2040'. Shoot 240 grain String Shot on Collar at 2002'.Set 3-3/8"IBP at 2500'COE. PT 3000 psi,OK. RIH with Bullnose BHA#5 and Dump 1200# of Sand on IBP. 00:00 01:00 1.00 582 0 COMPZ WELLPF PULD P Continue POOH with BHA#4,6-1/8" Bit and Bit Sub from 582',46k#up. LD BHA#4. 01:00 01:30 0.50 0 0 COMPZ EVALWE PULD P RU Dutch Riser for E-line 01:30 09:00 7.50 0 7,048 COMPZ EVALWE ELOG P PJSM. RU E-Line, RIH WITH CASt-M Cement Bond Log to 7048'. Log out at 50 fpm. Page 3 of 28 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:00 11:30 2.50 0 2,002 COMPZ EVALWE ELNE P RU and RIH w/240 grain string shot and shoot csg collar above TOC @ 2002'.Good fire indication. CCL Stop depth=1992' CCL measurement to Top Shot depth =9.9' Top Shot Depth=2002' Gun OD=2.13" 11:30 14:00 2.50 2,002 0 COMPZ EVALWE ELNE P POOH with E-line-change out BHA &P/U IBP. 14:00 16:30 2.50 0 2,493 COMPZ WELLPF MPSP P MU and RIH w/Baker 3-3/8" IBP (rated for 6,200 psi differential)on E-Line to 2,476.3-ft CCL depth- Center of Element @ 2,500-ft WLM Top @ 2,493-ft. 882 up wt,610 do wt,790 static wt. POOH 16:30 17:00 0.50 2,493 2,493 COMPZ WELLPF PRTS P Close blind rams and pressure up on IBP to 3,000 psi for 5 minutes. Flat lined. Bled off pressure and Open Blind rams. 17:00 18:00 1.00 0 0 COMPZ EVALWE RURD P RD Eline and pull Dutch riser. Load 7"Test Joint 18:00 21:30 3.50 0 0 COMPZ WELLPF OTHR T Night Crew on tower and attempt to blow down kill line. Find Ice plug. Break down Hardline and thaw out. 21:30 23:00 1.50 0 2,418 COMPZ WELLPF TRIP P PJSM. MU BHA#5 Bull Nose Assembly for dumping Sand on IBP. RIH to 2418', up 75k#,down 65k#. 23:00 00:00 1.00 2,418 2,418 COMPZ WELLPF OTHR P Dump 24 sacks(1200#)of Sand on top of IBP set at 2500'. 01/11/2013 Tag Sand above IBP(2500')at 2418'. Change out Lower Pipe Rams to 7"and Test 250/3500 psi-Good. ND BOPE and RU HydroTight to remove Bolts from Casing Flange. 00:00 02:30 2.50 2,418 2,227 COMPZ WELLPF OTHR P Finish Dumping 24(1200#)sacks of sand from 2418'. POOH to 2227'. 02:30 03:30 1.00 2,227 2,227 COMPZ WELLPF OTHR P Let sand settle. Rig Up Kill line after thawed. 03:30 04:00 0.50 2,227 2,429 COMPZ WELLPF TRIP P RIH from 2227'and tag TOS at 2429' 04:00 05:30 1.50 2,429 0 COMPZ WELLPF TRIP P PJSM, POOH to 483', NFT-static, Continue POOH. 05:30 08:30 3.00 0 0 COMPZ WHDBO OTHR P PJSM,Set Upper Test Plug and change out Lower Pipe Rams to 7" 08:30 09:15 0.75 0 0 COMPZ WHDBO BOPE T RU test equipment and Attempt to test 7"LPR's-found Inner bonnet to piston seal had failed and was leaking out weep hole. 09:15 11:30 2.25 0 0 COMPZ RIGMNT RGRP T Open up LPR and change mud seal 11:30 14:30 3.00 0 0 COMPZ WHDBO BOPE P RU test equipment and test 7"LPR's and Annular at 250/3,500 psi Page 4 of 28 • I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:00 1.50 0 0 COMPZ RIGMNT BOPE T Attempt to RD test equipment, during test on annular they had created trap pressure between LPR's and Test joint. Stopped Job. Held PJSM do to change of scope. Discuss options on the safest way to bleed off pressure and bled off pressure. Re-test LPR's at 250/ 3,500 psi. RD Test equipment. 16:00 17:30 1.50 0 0 COMPZ WHDBO NUND P PJSM, ND BOPE 17:30 00:00 6.50 0 0 COMPZ WHDBO NUND P PJSM. Set up for Hydra Tight. Removing stud bolts poved difficult. Unable to break bottom nut and not enough room for nut splitter. Also not enough room to remove bolts from bottom of flange. Removed top nut,drop bolt and cut with cutting torch in order to remove from flange. 01/12/2013 Remove Flange Bolts from Casing with HyrdaTight equipment with 40 inches of 7"Casing Growth. Spear Casing, PU 137k#and Reset Slips. Remove Casing Packoffs and Cut 7"Casing Stub with Wach's Cutter. NU Cement Cross,Valves,and BOPE. ***Phase 3 called at 23:45 hrs*** 00:00 07:30 7.50 0 0 COMPZ WHDBO NUND P Removing Flange Bolts from Casing with HyrdaTight equipment. Start=17,000 psi Number of cycles=191 Total growth=40" Finish=1100 psi 07:30 08:30 1.00 0 0 COMPZ WHDBO RTWH P PJSM remove tubing&attempt to pull pack off with no success. 08:30 09:30 1.00 0 0 COMPZ WHDBO PULL P PJSM M/U 7"casing spear, RIH and latch 7"casing. P/U to 137K on 7" with additional 14"stretch. Re-set casing slips&lay down spear. Total 7"growth=54" 09:30 10:30 1.00 0 0 COMPZ WHDBO SEQP P Load equipment into cellar and load out old tubing spools. 10:30 11:30 1.00 0 0 COMPZ WHDBO CPBO P PJSM-Rig up and cut 7"casing with the box cutter.Complete job and remove equipment from cellar. 11:30 23:00 11.50 0 0 COMPZ WHDBO NUND P PJSM-N/U spools,cement x-over& valves onto wellhead. 11"3M X 13 5/8"5M spool. 13 5/8"5M X 13 5/8"5M DSA 11"5M X 11"5M cmt x-over with valves. N/U BOPE. 23:00 23:45 0.75 0 0 COMPZ WHDBO NUND P PJSM. Fill Stack and Prepare to Shell Test BOPE. Tighten some Flange Bolts on Tubing Spool with Sweeny Wrench. 23:45 00:00 0.25 0 0 COMPZ WHDBO CIRC T Phase 3 Weather Hold 01/13/2013 **Phase 3-Waiting on Weather** Page 5 of 28 Time Logs Date From To Dur S. Depth E._Deoth Phase Code Subcode T Comment 00:00 00:00 24.00 0 0 COMPZ WHDBO CIRC T Phase 3 Weather Hold-Currently no DP in hole-discussed options for contingency for freezing at surface on well bore. Proposals are running in w/6-1/8"bit to 2,300-ft and changing hole over to 170°F Sea water. POOH and Conducting weekly BOP test as soon as Weather permits. 01/14/2013 00:00 00:00 24.00 0 0 COMPZ WHDBO CIRC T Phase 3 Weather Hold 01/15/2013 Dig out after Phase 3, Perform Derrick Inspection, Prepare to repair damaged Wind Walls 00:00 19:00 19.00 0 0 COMPZ WHDBO CIRC T Phase 3 Weather Hold 19:00 21:30 2.50 0 0 COMPZ WHDBOOTHR T Phase 2-Weather Hold Lifted. PJSM. Clear Snow Drifts out of Containment and under Rig and Camp. Clear Cuttings Shoot, Place Heaters on Elevators. 21:30 00:00 2.50 0 0 COMPZ WHDBO EQRP T PJSM. Prep for Wind Wall Repair. Perform Derrick inspection,Clear Cuttings Chute,and Dig out. 01/16/2013 Repair Wind Walls,Shell Test BOPE, Drift 7"Casing to 2426'tag with 6-1/8"Bit and Circulate 80 bbls of 150 degF SW,Cut 7"Casing at 1982'ELMD with Baker 5-1/2"Multi String Cutter. 00:00 11:00 11.00 0 0 COMPZ RIGMNT RGRP T Repair Wind Wall. 11:00 15:00 4.00 0 0 COMPZ WHDBO BOPE P Perform shell test,(no 7"pack off seals in place)pumping down through know 9 5/8"leak pump.3 BPM for 1/2 a barrel. Build 180 psi, slowly settled down to 100 psi, slowly bled down.Stack looked good. Line up 7 test kill lines too 3000 psi. Had one slow leak by kill tank, replace rubber. Re-rest to 3000 psi,held good. 15:00 17:00 2.00 0 2,387 COMPZ RPCOM TRIP P Conduct PJSM.MU BHA#7(6-1/2" Rock Bit). RIH to 2387'. Up 70k#, down 70k#. 17:00 21:30 4.50 2,387 2,387 COMPZ RPCOM CIRC P PJSM with LRS&ASRC. PT Lines- 2500 psi. Pump 80 bbls, 150 degf- 8.6 ppg SW at 180 psi. RD LRS. 21:30 23:30 2.00 2,387 0 COMPZ RPCOM TRIP P POOH and LD BHA 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P PJSM,MU BHA#8(5-1/2")Multi String Cutter 01/17/2013 Spear 7"Casing,Split Stack and remove 7"Casing Slips, NU BOPE and Circulate out Arctic Pack from OA, Start Pulling 7"Casing 00:00 02:00 2.00 0 1,965 COMPZ RPCOM TRIP P RIH with BHA#8 Baker 5-1/2"Multi String Cutter. Page 6 of 28 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:00 02:15 0.25 1,965 1,965 COMPZ RPCOM CUTP P Pump SW at 2 bpm,200 psi. Locate Casing Collar at 2025'N3 RKB, Pull up and locate collar at 1985'. Come up 20'to 1965'(1982' Referenced to ELine Log). Rot Wt 66K,75 RPM,900-1200 ft-lb free torque. Cut casing at 1965'DPMD. Pump 5 bpm,600 psi,riot at 75 rmp torque at 1300-1400 ft-lb. Pressure drop after 6 min. Torque dropped and wt bobble. Good cut indication. 02:15 03:15 1.00 1,965 1,965 COMPZ RPCOM CIRC P Close Annular as planned and circulate SW 60 bbls bottoms up to open top. Monitor Well for flow. 03:15 05:30 2.25 1,965 0 COMPZ RPCOM TRIP P POOH 05:30 10:30 5.00 0 1,965 COMPZ RPCOM CIRC P PJSM.MU 7"CSG spear w/cup. Engauge 7", pull up 1'Casing free. Spot up trucks for circ out. PJSM for circ out with LRS,ASRC,&rig crew. Discuss fluid paths. LRS on line with 90 deg diesel @ 1.5 BPM 200 psi, pumping down 7"CSG,through cut @ 1965'DPMD,taking returns up OA to open top tanks. 10:30 12:00 1.50 1,965 1,965 COMPZ RPCOM CIRC T All diesel pumped,200 bbls.Shut down the pump. LRS truck was not topped off last night. Fueler is on the way.blow down the return line while fueling truck. 12:00 14:00 2.00 1,965 1,965 COMPZ RPCOM CIRC P Get return line lined back up. Begin pumping hot SW, 170 deg,pumping down 7"CSG,through cut @ 1965' DPMD,taking returns up OA to open top tanks. 14:00 15:00 1.00 1,965 1,965 COMPZ RPCOM PULD P Rig down LRS,blow down the lines. 15:00 17:00 2.00 1,965 1,965 COMPZ RPCOM PULL P PJSM,Split stack. Pull up, retrieve 7"slips. 17:00 19:00 2.00 1,965 1,965 COMPZ RPCOM NUND P PJSM.Stab stack back on, hammer up. 19:00 21:00 2.00 1,965 1,965 COMPZ RPCOM OTHR P Load Baker Tools,6-1/4"DCs 21:00 23:00 2.00 1,965 1,926 COMPZ RPCOM PULL P PJSM, Pull Casing to Floor, LD Cut Joint and Spear,Changeout Floors to Pull 7"Casing 23:00 00:00 1.00 1,926 1,650 COMPZ RPCOM PULL P LD 7"Casing from 1926'to 1650'. Up 90k#. 01/18/2013 Pull and LD 7"Casing from 1965'RKB. Test 11"5K BOPE 250/3000 psi witnessed by State Inpector Chuck Sheve. 00:00 04:00 4.00 1,650 0 COMPZ RPCOM PULL P Continue Pulling and LD 7"Casing from 1650'. **Pulled 45 full Casing Joints plus 2 cut Joints- Recovered 12 Centering Guides-Casing Tally Indicates 15 Guides Run on first 47 Joints** 04:00 05:00 1.00 0 0 COMPZ RPCOM PULD P Changeout Floor Equipment. Clean and clear Floor Page 7 of 28 • S Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 09:00 4.00 0 0 COMPZ RPCOM BOPE P Drain Stack and remove 4 Centering Guides. Remove multiple chunks of metal debirs from cetering guides. Clean arctic pack from the stack. Change out Lower Rams from 7"to 2-7/8"x 5"VBRs.MU&set 9 5/8" test pug in csg head. 09:00 16:30 7.50 0 0 COMPZ WHDBO BOPE P Fill stack, ram leaking. Drain the stack,take apart...seal damaged, replace.Test choke while replacing _ seal.Continue with test. 16:30 20:30 4.00 0 0 COMPZ WHDBO BOPE T PJSM,Changeout CMT Valve on Conoco Casing Spool,Changeout Top Drive MudSaver Valve. 20:30 22:00 1.50 0 0 COMPZ WHDBO BOPE P Rig Up and Continue Finish BOPE Test 250/3000 psi. 22:00 00:00 2.00 0 0 COMPZ WHDBO BOPE P Pull Test Plug and Set Wear Ring 01/19/2013 Run 9-5/8"Scraper/Drift Assembly to 375'and set down 8k#, Run 8-1/2"Rock Bit/Drift Assembly to 375' and set down 10k#, Run 6-3/4"Bit Assembly to 1965'-tag. Circulate 30 bbl hi-vis sweep followed by 275 bbls of 150 deg SW(75%Returns). RU HES Eline and Log 40 Arm Caliper and Gyro in separate runs to 1948'. Caliper verifies damaged area in 9-5/8"Casing over 2-ft isolated section at—375'. 00:00 02:00 2.00 0 375 COMPZ WELLPF PULD P PJSM,MU BHA#10(9-5/8"Casing Scraper)and RIH to 375'and stack out 8k#. Up 45k#and down 45k#. Noted Tight spots at 277'and 348'. 02:00 03:30 1.50 375 0 COMPZ WELLPF TRIP P POOH and LD BHA#10. 03:30 04:15 0.75 0 375 COMPZ WELLPF TRIP P PJSM,MU BHA#11 (8-1/2"Bit)and RIH to 375'and stack out 10k#. Up 45k#and down 45k#. 04:15 05:00 0.75 375 0 COMPZ WELLPF TRIP P POOH and LD BHA#11. 05:00 08:30 3.50 0 1,961 COMPZ WELLPF TRIP P PU BHA#12(6-3/4"Bit)and RIH right past trouble area at 375'RIH tag 7"stub @ 1965'. Pull up to 1961' DPMD,park. 08:30 11:00 2.50 1,961 1,961 COMPZ WELLPF CIRC P Pump 30 bbls high vis sweep down DP,taking retrns up 9 5/8"to open top tank.6 BPM @ 640 psi,swap to 150 deg SW,8.5 BPM,choke full open. Return rate about 1 BPM at the tank,slow rate down with no change on return rate.Go back up to 8.5 BPM,pump 275 bbls of hot SW. Shut down pumps,loss of about—80 BBLs during circulation.Monitor well, blow down line. Load up baker tools so E-line can spot up. 11:00 13:00 2.00 1,961 0 COMPZ WELLPF TRIP P TOOH. 13:00 14:15 1.25 0 0 COMPZ WELLPF RURD P OOH. PJSM, RU dutch riser. PJSM with E-line crew. Rig up E-line for caliper log. 14:15 16:00 1.75 0 0 COMPZ WELLPF ELOG P E-line RIH w/Caliper,CCL,tag 7" CSG stub @ 1948'ELM.Try several times but unable to get inside 7" csg. Log caliper to surface. Page 8 of 28 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 16:00 17:00 1.00 0 0 COMPZ WELLPF ELOG P OOH w/caliper. Lay down caliper, MU gyro tool w/gamma. 17:00 20:00 3.00 0 0 COMPZ WELLPF ELOG P RIH w/Gyro tool W/GR and log from 1945'to Surface. 20:00 21:00 1.00 0 0 COMPZ WELLPF ELOG P PJSM, RD HES Eline, RD Dutch Riser. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD P PJSM,Changeout Rig Equipment, Load and Unload Tools-DC,Test Joints,and Mill 7-3/4", Grease Wash Pipe 22:00 23:00 1.00 0 0 COMPZ RPCOM SFTY P PJSM,Set Wear Ring 23:00 00:00 1.00 0 0 COMPZ RPCOM PULD P PJSM, MU BHA#13-7-3/4"x 8-3/8" String Mill Assembly 01/20/2013 Mill out problem area in 9-5/8"Casing at 375'with multiple Double String Mill Assemblies with Flex Joint between. Work up to 8-1/2"x 8-3/4"OD Stacked String Mills Assembly without Flex Joint and continue working area. 00:00 02:30 2.50 0 370 COMPZ RPCOM TRIP P RIH with BHA#13-7-3/4"x 8-3/8" String Mill Assembly to 370'and check parameters. Free Rot 60 rpm, torque 900 ft-lb,pumping 4 bpm at 120 psi. 02:30 03:00 0.50 370 405 COMPZ RPCOM MILL P Ease into it with first 7-3/4"mill at 375'dpm. Torq momentarily jumps to 3000 ft-Ibs,but quickly down to 1100 ft-lbs. Stack out 2000#and let work through in about 5 minutes. Continue down 15'and second String Mill makes contact and Torque momentarily jumps to 2800 ft-lbs. Work at 1100-1300 ft-lbs and stacking 2000#. Work through in 5 minutes. 03:00 04:00 1.00 405 405 COMPZ RPCOM OTHR P BDTD and tighten packing on the Swivel. 04:00 05:30 1.50 405 0 COMPZ RPCOM TRIP P POOH. LD BHA#13 05:30 07:45 2.25 0 374 COMPZ RPCOM TRIP P MU 8-3/8"x 8-1/2"String Mill Assembly(BHA#14)and RIH tag up @ 374'DPMD 07:45 09:00 1.25 374 374 COMPZ RPCOM MILL P Pull-up,kick on pumps. rotate @ 60 RPM, RIH,set 2000#down, 1200 torque,work mill for 1 hour,drift down.8 3/8"mill by passed the obtruction,8 1/2"did all the work. RIH addition 60', no problem.Wash pipe on top drive leaking again. 09:00 11:00 2.00 374 374 COMPZ RPCOM RGRP X PJSM,replace packing in wash pipe. Put back together and test. 11:00 11:30 0.50 374 374 COMPZ RPCOM MILL P Pull back up thru tight spot @ 375' w/pumps on&rotaing @ 60 RPM, smooth up. RIH see slight bobble on weight and top drive torque spiked to 1200.Work area several more times. 11:30 13:00 1.50 374 0 COMPZ RPCOM TRIP P TOOH 13:00 13:45 0.75 0 0 COMPZ RPCOM PULD P On surface, PJSM, lay down BHA, PU BHA Page 9 of 28 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 13:45 17:30 3.75 0 465 COMPZ RPCOM TRIP P RIH W/BHA#14 8 3/4"string mill, tag up @ 289'Work thru with mill pretty easily,work X5. RIH to 374', 60 RPM torque 2k to 4k work thru in about 1 hour.Work string mills several times until smooth. Drift with 8.75"Mill down to 437'. BDTD. 17:30 18:00 0.50 465 0 COMPZ RPCOM TRIP P PJSM. POOH from 465'. Up 60k#. 18:00 19:30 1.50 0 0 COMPZ RPCOM PULD P Mill getting hung up on Wear Ring. MU Wear Ring Pulling Tool and pull Wear Ring. 19:30 21:30 2.00 0 360 COMPZ RPCOM TRIP P Break Down Mills and remove Flex Joint. MU 8-1/2"x 8-3/4"Mills in tandem(BHA#16). RIH to 360'. 21:30 23:15 1.75 360 466 COMPZ RPCOM MILL P Obtain Parameters. 60k#Down, 55k#Up. Rotate 60 RPM,950 Tq. Pump 5 bpm at 60 psi. Tag 3k# down at 376'Bullnose depth. Lower Mill at 364'and Upper Mill at 359'. Milled down with 1-2k#over and Tq from 1000-2300 ft-lb. Approx 30 minutes-fall through. Work Upper Mill with 3500 ft-lb for about 30 minutes-fall through. 23:15 00:00 0.75 466 370 COMPZ RPCOM REAM P Keep working tight spot. 01/21/2013 Work 8-1/2"x 8-3/4"rigid String Mill Assembly through problem area at 375'in 9-5/8"Casing. Continue RIH with rigid BHA and work area at 995'with high torque. POOH and reconfigured BHA with stepped back String Mill size and Flex Joint. Perform additional work on problem area at—995'in preparation for re-running 7" Casin.. 00:00 01:30 1.50 370 466 COMPZ RPCOM MILL P Continue Milling and Reaming through trouble spot at 375'several times untal able to slide through without rotating. 01:30 02:00 0.50 466 1,003 COMPZ RPCOM TRIP P BDTD and continue RIH. 02:00 04:30 2.50 1,003 1,007 COMPZ RPCOM MILL P Tag at 1003'Bullnose depth. Bottom 8-1/2"Mill at 995'and top 8-3/4"Mill at 990'. Work at 60 RPM at 2200 ft-lbs and steady work for 2 hours. Making about—1'an hour. Discuss rigidity of assembly with Baker and concern of snapping off pin between Mills. 04:30 06:00 1.50 1,007 0 COMPZ RPCOM TRIP P Pull out of hole to reconfigure BHA. 06:00 09:00 3.00 0 0 COMPZ RPCOM PULD P Pull wear ring,MU BHA, Re-set wear ring. 09:00 11:30 2.50 0 1,035 COMPZ RPCOM TRIP P RIH W/BHA#17.Stack stacking 5k @ 996. Pull up, pumps on 4 BPM 70 psi work tight area from 996'to 1035'.Continue RIH to just above tbg stub @ 1965'DPMD. 11:30 13:30 2.00 1,035 1,965 COMPZ RPCOM CIRC P Rig up for circulation. Pump 15 bbls sweep,chase with 1.5 volumes 13:30 16:00 2.50 1,965 1,965 COMPZ RPCOM RGRP X PJSM.Slip&cut drill line. Page 10 of 28 • • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:00 18:45 2.75 1,965 0 COMPZ RPCOM TRIP P TOOH to surface. 18:45 19:45 1.00 0 0 COMPZ RPCOM PULD P PJSM, Pull Wear Ring and Reconfigure String Mill assembly. MU 8-1/2"Mill, Flex Joint,8-3/4"Mill (BHA#18) 19:45 20:15 0.50 0 375 COMPZ RPCOM TRIP P Strip over Wear Ring and RIH with Collars and Drill Pipe. 20:15 20:45 0.50 375 953 COMPZ RPCOM TRIP P Continue through tight spot at 375', 4k#down. Continue RIH 20:45 21:45 1.00 953 1,024 COMPZ RPCOM MILL P At 953',obtain parameters. 70k#up and down. Rot at 60 rmp with 960 ft-lbs free torque. Pump 5 bpm at 80 psi. Tag down 5k#at 1008'Bullnose depth. Lower Mill at 996'and upper Mill at 981'. Mill down to 1020'. 21:45 22:15 0.50 1,024 1,032 COMPZ RPCOM MILL P Upper mill starts working with Bull Nose depth at 1024'BN, Lower Mill 1012', Upper Mill 997. Continue Milling and fall through at 1030'BN, Lower 1018', Upper 1003'. 22:15 23:30 1.25 1,032 1,965 COMPZ RPCOM MILL P Tagged Up at 1032'BN, Lower 1020', Upper 1005'. Continue milling to 1035'BN and Fell through. Lower 1023',Upper 1008'. BDTD and continue to RIH to top of 7"at 1965'. 23:30 00:00 0.50 1,965 1,500 COMPZ RPCOM TRIP P POOH 01/22/2013 Continue Milling out problem areas in 9-5/8"Casing,Clean Out 7"Stub to 2,400-ft corrected to ORKB. 00:00 01:00 1.00 1,500 0 COMPZ RPCOM TRIP P Continue POOH with BHA#18. 01:00 02:00 1.00 0 0 COMPZ RPCOM PULD P Stand Back Collars, RU Wear Ring Puller, Remove Ring and LD Pulling Tool, Break out Flex Joint. 02:00 02:30 0.50 0 0 COMPZ RPCOM PULD P MU 8-1/2"x 8-3/4"Stacked String Mill Assy(BHA#19). Strip over Wear Ring 02:30 03:00 0.50 0 943 COMPZ RPCOM TRIP P RIH with Collars and DP. 03:00 03:30 0.50 943 1,008 COMPZ RPCOM TRIP P Obtain Parameters. 70 k#Up and down. Rot 6 rpm, 960 ft-lb free tq. Pump 5 bpm at 80 psi. 03:30 10:00 6.50 1,008 1,025 COMPZ RPCOM MILL P Tag 7k#at 1008 Bull Nose depth, Lower Mill at 996', Upper Mill 991'. Milling down with 2k#and Torque from 1800-3200 ft-lbs. Page 11 of 28 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:00 12:00 2.00 1,025 1,040 COMPZ RPCOM REAM P Continue milling down,broke out @ 1025'DPMD.Another tight spot @ 1035'DPMD but worked through easily. Pull-up and make several passes to clean up down to 1040'. P/U and backreamed up to 990- 1040'twice-clean passes. P/U to 990'-stop ratation and slid down. Had a 7K set down @ 1020' Rotation and reamed up/down 1015 -1025'five passes with light mill work. Stop rotation saw 6K down weight _1020' 12:00 13:00 1.00 1,040 1,917 COMPZ RPCOM MILL P Continue sliding in hole to TD of _1917'. 13:00 14:00 1.00 1,917 1,963 COMPZ RPCOM CIRC P Circulated B/U with Hi-visc sweep @ 5 bpm 110 psi. Slid in for a light tag of 7"stump @ 1965' 14:00 15:30 1.50 1,963 265 COMPZ RPCOM TRIP P TOOH standing back DP. 15:30 19:00 3.50 265 0 COMPZ RPCOM PULD P PJSM-Lay down BHA#18. Kick out big tools,clean up rig floor area. Set wear bushing 19:00 20:00 1.00 0 319 COMPZ RPCOM PULD P PJSM-MU 6-1/8"tappered mill,boot basket,string magnet assembly BHA#20 20:00 23:00 3.00 319 2,397 COMPZ RPCOM TRIP P TIH with BHA#20 on DP to top of stub at 1,968-ft corrected to ORKB, slid thru top of stub and SO 5k at 1,980-ft,set parameters ROT 30 rpm,580 ft/lbs free torque,5 bpm at 180 psi,TIH 2 to 4k WOB pushing junk to 2,400-ft corrected to ORKB 23:00 00:00 1.00 2,397 2,397 COMPZ RPCOM CIRC P Circulate bottoms up 30 bbl high-visc sweep 6 bpm at 220 psi. 01/23/2013 Clean Out 7"Stub. Backoff 7"Casing Stub.Make Triple Connect Dummy Drift to top of csg stub,2k to 4k light throught tight areas 365 to 385-ft and 994 to 1,031-ft. 00:00 00:30 0.50 2,397 2,397 COMPZ RPCOM CIRC P Continue to circulate bottoms up 30 bbl high-visc sweep 6 bpm at 220 psi until clean across shakers,270 bbls. 00:30 02:30 2.00 2,397 0 COMPZ RPCOM TRIP P PJSM-TOOH with BHA#20 from 2,400-ft standing back DP,70k up/dn. Magnet covered with approximatly 10 lbs fine metal shavings,tandam boot baskets had approximatly 1 lb of fines and several small chunks of casing. lay down BHA#20. 02:30 03:00 0.50 0 0 COMPZ RPCOM OTHR P Off load Baker equipment,clean and clear floors. 03:00 04:30 1.50 0 315 COMPZ RPCOM PULD P PJSM-PU MU 7"tbg stub Back-off Assembly BHA#21,fill with diesel. 04:30 09:00 4.50 315 2,189 COMPZ RPCOM TRIP P TIH with BHA#21 on DP filling with diesel every 5 stands to 2189'. Page 12of28 Ili • i • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:00 12:30 3.50 2,189 2,189 COMPZ RPCOM BKOF P PJSM-Power section sitting @ 1985' Lower slips=1992'-pressure up to 600 psi-set down 8K-indication of slip setting. P/U to neutral weight Upper slips=1973'-pressure up to 1300psi-set upper slips,set down 4K-put marker on pipe/rotary table. Pump up to 600 psi-turned half turn -walked up to 3000 psi to ensure slips were set-P/U neutral weigth and sat back into 4K down. Start working stages-950 psi=2/3 turn,850 psi=1/3 turn,650 psi= 1/4 turn, 1000 psi 1-1/2 turn,700= 1/4 turn,continue. 12:30 14:30 2.00 2,189 2,189 COMPZ RPCOM CIRC P Made a total 5-1/4 turns. Drop dart, reverse circ out diesel in tubing,once returns cleaned up pump additional 140 bbls. P/U 2K over to shear out tool. 14:30 15:30 1.00 2,189 315 COMPZ RPCOM TRIP P PJSM-TOOH 15:30 17:00 1.50 315 0 COMPZ RPCOM PULD P Lay down BHA#21 17:00 17:30 0.50 0 0 COMPZ RPCOM OTHR P PJSM-Cange over floors to run 7" equipment 17:30 19:00 1.50 0 163 COMPZ RPCOM PULD P PJSM-MU 7"Triple Connect/ES Cementer Dummy Drift w/string magnet, BHA#22. 19:00 20:45 1.75 163 1,963 COMPZ RPCOM TRIP P TIH with BHA#22 on DP to 360-ft, 55k Up/50k Dn,2 to 4k SO thru tight area 365-ft to 385-ft,continue TIH to 931-ft,55k Up/57k Dn,2k to 3k SO thru tight area 994-ft to 1,031-ft,continue TIH to just above csg stub at 1,963-ft with no problems. 20:45 21:45 1.00 1,963 163 COMPZ RPCOM TRIP P PJSM-TOOH standing back DP from 1,963-ft,65k Up 21:45 23:00 1.25 163 0 COMPZ RPCOM PULD P Lay down 6-1/4"drill collars and BHA #22,approximatly 8 lbs of metal fines on magnet. 23:00 00:00 1.00 0 0 COMPZ RPCOM OTHR P Change over floor equipment,clean and clear floors,off load Baker tools. 01/24/2013 Spear 7"csg stub,circulate out artic-pac and retrieve csg stub.Wash BOP stack, C/0 LPR's to 7"and perform weekly BOP test. Prep and Run 7"Casing per run order. 00:00 00:45 0.75 0 32 COMPZ RPCOM PULD P PJSM-MU Bullnose, Pack-off,7" ITCO Spear w/6.22"grapple, Bumper Sub,String Magnet BHA #23. 00:45 02:00 1.25 32 1,975 COMPZ RPCOM TRIP P TIH with BHA#23 on DP, 65K Up/Dn,engauge TOF at 1,965-ft with stop sub, PU 5k over,back-off 5 turns to release stub, PU 5k drag. Page 13of28 1I • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:15 1.25 1,975 1,975 COMPZ RPCOM CIRC P PJSM-Circulate 30 bbl high-visc sweep 8 bpm, reciprocate pipe 10-ft, work rate up to 10 bpm at 590 psi for 180 bbls,seen sweep and arctic-pack,very little metal fines across shakers,shut down, BDTD. 03:15 04:00 0.75 1,975 1,975 COMPZ RPCOM CIRC P Circulate 120°seawater around 4 bpm at 100 psi until returns clean, 170 bbls,shut down. BDTD. 04:00 04:30 0.50 1,975 1,975 COMPZ RPCOM OWFF P Monitor well 30 minutes,well static. 04:30 05:30 1.00 1,975 32 COMPZ RPCOM TRIP P PJSM-TOOH from 1,975-ft standing back DP,65k Up. 05:30 07:00 1.50 32 0 COMPZ RPCOM PULD P PJSM-Lay down BHA#23 and 19.34-ft csg stub. Pin end on surface,threads look clean. 15#of steel on magnet. 07:00 11:00 4.00 0 0 COMPZ RPCOM MPSP P Jet lower ring&bushing. Pull Wear ring, install test plug.Jet stack to flush all loose medal debris from stack.Swap swizzle stick and jet down to top of plug. 1-2 pounds of medal debris on magnet. 11:00 14:00 3.00 0 0 COMPZ RPCOM SEQP P PJSM-Open up lower rams and swap out to 7"rams.Open cavity doors on upper rams to inspect for excess debris. Found one rolled seal in lower rams. 14:00 20:00 6.00 0 0 COMPZ WHDBO BOPE P PJSM-Start Weekly BOPE test. ***Test Waived by Lou Grimaldi*** 20:00 21:00 1.00 0 0 COMPZ RPCOM OTHR P Change over floors to run 7"casing, bring in 7"casing pups. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD P PJSM-MU and BakerLock Tripple Connect Screw in Sub w/crossover pup,'ES'Cementer.Stopped job when pin end of pup joint was noticed as BTC thread.MU 10-ft pup to cementer. 22:00 23:30 1.50 0 0 COMPZ RPCOM PULD T Pup joints brought in not TC-II box x pin, bring in all 7"pup joints,found lea. 10-ft and lea.15-ft pup joints TC-II bxp out of 7 pups brought out. Pups brought out are BTC bxp or crossover pups TC-II/BTC bxp. 23:30 00:00 0.50 0 433 COMPZ RPCOM TRIP P TIH with Triple connect/'ES' cementer on 7",26#, L-80,TC-II casing joints to 433-ft. 01/25/2013 Run 7"Casing per run order.Test 7"csg. RU Cementers.Open'ES'cementer. Place 10 bbls 15.7 ppg AS1, 60 bbls of 15.7 ppg AS1 w/1.5#/bbl CemNET and 10 bbls 15.7 ppg AS1 in 9-5/8"x 7"OA from 1,980-ft to estimated hole in 9 5/8"casing at 370-ft, had loss of returns @ 38 bbls from completion with no cement returns to surface. Bumped plug and did no flo test. Rig down cement equipment.Confer with town engineer. Perform injectivity test,6 gpm at 130 psi for 20 bbls. Prep for top down job. 00:00 01:30 1.50 433 1,963 COMPZ RPCOM RNCS P Continue to TIH with Triple connect/ 'ES'cementer on 7",26#, L-80,TC-I I casing joints from 433-ft to 1,963-ft, average torque 10,000 ft/Ibs Page 14 of 28 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:30 02:00 0.50 1,963 1,963 COMPZ RPCOM PULD P MU space out pups,crossovers and 6-ft 3.5"IF hadling pup,kelly up to top drive. 02:00 02:30 0.50 1,963 1,985 COMPZ RPCOM RNCS P TIH and screw in to 7",26#,J-55, BTC csg stub at 1,985-ft, 85k Up/Dn, ROT 85k,5 rpm and 800 ft/lbs free torque,torque up to 4500 ft/Ibs,after 9 full turns after seeing totque increase,Overpull 50k. 02:30 03:00 0.50 1,985 1,985 COMPZ RPCOM RURD P RD handling pup and crossover sub, RU head pin and test equipment and hoses,swap over elevators. 03:00 04:00 1.00 1,985 1,985 COMPZ RPCOM PRTS P PJSM-'PU 50k over,test 7"csg to 2000 psi, holding good, pressure test 7"csg to TOS to 2500 psi, record on chart 20 minute with no pressure loss. RD test hoses,off load casing crew. 04:00 04:30 0.50 1,985 1,985 COMPZ CEMEN"RURD P RU HES cement head and manifold, closing plug installed, pressure up casing, HES"ES"cementer opened at 3200 psi. 04:30 07:00 2.50 1,985 1,985 COMPZ CEMEN"CIRC P PJSM w/AES, HES and Nordic 3 crews.Circulate 100 bbls 80° seawater,max 4 bpm off Vac truck at 120 psi.crew change. 07:00 08:00 1.00 1,985 1,985 COMPZ CEMEN"SFTY P PJSM w/SLB, HES„ MI, Baker and Nordic 3 crews and cement pump schedule.Walk lines to check flow paths,valve positions. 08:00 11:00 3.00 COMPZ CEMEN"CMNT T After pre-job fresh water truck broke down prior to SLB mixing cement. Stop job and wait on new water truck. 11:00 13:00 2.00 1,985 1,985 COMPZ CEMEN"CMNT P Prime truck, pump 10 bbls fresh water,pressure test lines and equipment 4000 psi. Cement start time 11:30 - SLB pump 5 bpm at 490 psi 10 bbls 15.7 ppg Artic Set cement(neat)/60 bbls 15.7 ppg w 1.5#bbl CemNet,/10 bbls 15.7 ppg(neat),good returns. Shut down and launch plug,SLB back on line 3 bpm at 280 psi for 3.5 bbls of 15.7 ppg(neat)followed by 12 bbl fresh water. Blow down SLB lines. Close 7"rams,open up mud cross to cuttings box, Nordic 3 on line 5 bpm at 130 psi, 300 strokes in pressure started climbing up to 500 psi. Lost returns to surface 800-850 strokes in, No cement returns to surface-plug bumped at 1235 strokes,pressure up against plug to 1600 psi. No leak off. Page 15 of 28 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:00 16:30 3.50 1,985 1,985 COMPZ CEMEN"OWFF P No flow test for 30 minutes-good test. Pull 50 K on 7"/upweight 135K. Rig down Cement head and start calling for equipment for top up cement job. SLB cementer rigged down for round trip. Start loading out tools from pipe shed.Call out for 1"CS hydrill string. 16:30 20:15 3.75 1,985 1,985 COMPZ CEMEN-CIRC X Rig up Test pump to try and pump diesel down the backside,prior to cement job. Start pumping @ 17:50 hrs.9 gal/min.max output on pump.@ 110 psi. Pumping @ 19:50 hrs.pumping at 150 psi,est. 18 bbls away,with straps on diesel tanks,confer w/ town engineer. 20:15 21:30 1.25 1,985 1,985 COMPZ CEMEN"OWFF X Final pump pressure 130 psi,est. 20+bbls diesel pumped,shut down, monitor well while waiting on SLB cementers and support trucks. 21:30 22:00 0.50 1,985 1,985 COMPZ CEMEN"OTHR X MI spot up SLB cementers,discuss pump schudule, line out rig up. 22:00 00:00 2.00 1,985 1,985 COMPZ CEMEN"OTHR XT Waiting on fresh water, rinsate and super sucker trucks. Fresh water truck on site at 23:00, rinsate truck on site at 23:30, load with BIO pill from pits,called dispatch super sucker froze up, in shop 01/26/2013 Pump 23 bbls 15.7 ppg class"G"AS1 cement down OA.WOC. Raise BOP stack. Perform top job on OA. Land csg in slips w/50k tension.Cut csg.Stand back BOP. Install pack-offs and test. NU new tubing spool. NU BOP. 00:00 00:30 0.50 1,985 1,985 COMPZ CEMEN"SFTY X PJSM with SLB,AES,Cameron and Nordic 3 crews,pump schedule and procedures. 00:30 02:30 2.00 1,985 1,985 COMPZ CEMEN"PUCM X Prime truck,fill lines w/1 bbl fresh water, P/T lines 700 psi, pump 2 bbls fresh water 1.2 bpm at 180 psi, Batch mix cement,at 01:30 begin pumping 15.7 ppg Class"G"AS1 neat cement 1.2 bpm at 200 psi,5 bbls pumped-1.2 bpm at 155 psi, 10 bbls pumped-1.2 bpm at 90 psi, 15 bbls pumped-1.2 bpm at 90 psi,20 bbls pumped-1.7 bpm at 120 psi,23 bbls pumped-1.7 bpm at 125 psi, shut down,pressure dropped to 0 psi,flush lines to cutting box with 5 bbls fresh water. RD SLB cementers. Hose out flow cross valves with fresh water. 02:30 05:00 2.50 1,985 1,985 COMPZ CEMEN"OWFF X OA on vac,monitor 30 minutes,well still on slight vac.shut in and wait on cement 3.5 hrs to 500 psi compresive strength.Off-load 1"CS pipe. clean and clear rig. Page 16 of 28 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 05:30 0.50 1,985 1,985 COMPZ CEMEN-OWFF X Open up OA,static,perform NFT 30 minutes, 05:30 07:00 1.50 1,985 1,985 COMPZ WHDBO PUCM P ND BOP, lift stack,Cement level 20ft down.Top up with cement to surface.Cement top 28"from surface,total 7 sacks of cement. 07:00 10:30 3.50 0 0 COMPZ WHDBO NUND P PJSM Set up Camreon Casing cutter.Set casing slips and cut 7" casing. Rig down remaining 7"from rig floor and 3rd party tools. 10:30 13:30 3.00 0 0 COMPZ WHDBO NUND P PJSM-ND BOP,Cement flow cross,wing valves. 13:30 18:00 4.50 0 0 COMPZ WHDBO NUND P Start installing YB pack off on 7" casing and 7-1/16 5M X 11"3M S-YB Gen IV tubing Spool. 15 minute test on pack offs to 3000 psi. 18:00 19:00 1.00 0 0 COMPZ WHDBO RURD P Load out all spools,valves and excess equipment from cellar. 19:00 23:30 4.50 0 0 COMPZ WHDBO NUND P PJSM-NU BOPE to leaning tree 23:30 00:00 0.50 0 0 COMPZ WHDBO NUND P Change out 7"solids in lower cavity to 2-7/8"X 5"VPR's. 01/27/2013 NU BOP and test. MU and TIH with Milling BHA#25.Mill up cement plug and remaining cement thru ES cementer to TOS. Pressure test 7"Casing.MU and TIH with Concave Mill BHA#26. Dry Mill junk at TOS. MU and TIH with RCJB BHA#27. 00:00 00:30 0.50 0 0 COMPZ WHDBO NUND P Continue to change out 7"solids to 2-7/8"X 5"VBR's. 00:30 03:00 2.50 0 0 COMPZ WHDBO BOPE P PJSM-Fill stack with water, RU test equipment,shell test,Test BOP break and lower VBR's 250/3500, RD test equipment. 03:00 04:00 1.00 0 0 COMPZ CEMEN-OTHR P PJSM-Set wear bushing. load Baker tools to floor. 04:00 05:00 1.00 0 316 COMPZ CEMEN-PULD P PJSM-MU 6 1/8"rock bit,tandem boot baskets,bit sub,string magnet, bumper sub,pump-out-sub,3 stds. DC's BHA#25 05:00 06:30 1.50 316 1,863 COMPZ CEMEN"TRIP P TIH with Milling BHA#25 on DP to 1863'tagged TOC.String weight Up/Down 65K 06:30 09:45 3.25 1,863 1,976 COMPZ CEMEN-MILL P Start milling 5 bpm,270 psi, 80 rpm, 1 -1.5 K torque. Light milling work, hitting stringers,cement returns PH level 11 across the shakers. Hard tag 1973'-Up/Down weight 65K. Milling on rubber plug. Rubber returns 1973.5' Light metal/Alum. returns-1974.4' Slowly work through down to 1976' 09:45 11:45 2.00 1,976 2,416 COMPZ CEMEN"TRIP P Work pipe through ES cementer- then slid down through 65K.Slid down to 1980',seen 5K weight- Start rotating Light Cement bridge at 1980'-1985'-continue sliding to TOS-Stop pumping 50'above sand top.TIH and dry tag. Page 17 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 13:00 1.25 2,416 2,350 COMPZ CEMEN'PRTS P P/U to 2350'Up weight 76K. Blow down the top drive, rig up circ hose, break circulation, line up valves to test 7"casing. Open OA valve to monitor for flow- no flow. Perform and chart 30 minute 7" casing test 250 low/3000 psi high. Passed-30 psi leak off during full test. 13:00 15:00 2.00 2,350 317 COMPZ CEMEN"TRIP P TOOH-Had to stop while TOOH to thaw out frozen return line(1 hour). Continue tripping OOH. 15:00 16:00 1.00 317 0 COMPZ CEMEN"PULD P Lay down BHA#25&P/U BHA#26 16:00 17:00 1.00 0 318 COMPZ CEMEN"PULD P MU BHA#26-6"Concave Mill, tandem boot baskets,bit sub,string magnet, bumper sub,pump-out-sub, 3 stds. DC's BHA#26 17:00 18:00 1.00 318 2,415 COMPZ CEMEN"TRIP P TIH with Milling BHA#26 on DP to TOS,tag up at 2,415-ft,75k Up/Dn 18:00 19:00 1.00 2,415 2,417 COMPZ CEMEN"MILL P Set parameters 8 rpm, 1500 Free torque,5k wob, 1500 to 1800 mill torque to 2,417-ft. 19:00 20:00 1.00 2,417 2,417 COMPZ CEMEN"CIRC P Circulate bottoms up 8 bpm at 920 psi,cement, rubber and aluminum across shakers. 20:00 20:45 0.75 2,417 318 COMPZ CEMEN"TRIP P PJSM-TOOH from 2,417-ft standing back DP to BHA#26. 20:45 21:15 0.50 318 0 COMPZ CEMEN"PULD P Lay down BHA#26,couple small pieces of aluminum in boot baskets. clean and clear floor. 21:15 22:00 0.75 0 323 COMPZ CEMEN"PULD P PJSM-MU 6 1/16"RCJB,bit sub, tandem boot baskets, bit sub,string magnet,bumper sub,pump-out-sub, 3 stds. DC's BHA#27 22:00 23:00 1.00 323 2,420 COMPZ CEMEN'TRIP P TIH with BHA#27 on DP to 2,417ft, 75k Up/Dn, PU to 2,357-ft,set parameters,30 rpm at 1k free torque, 6 bpm at 600 psi,break off and drop 7/8 ball, bring on pump 6 bpm at 950 psi,TIH dry drill to 2,419-ft,bring on pumps 6 bpm at 1000 psi,30 rpm, 1260 TD torque,work to 2,420-ft, unable to work further, PU 15k over, junk, PU to 2,360-ft. 23:00 00:00 1.00 2,360 2,360 COMPZ CEMEN"CIRC P Circulate bottoms up 6 bpm at 850 psi,small amount of metal shavings across shakers. 01/28/2013 TOOH with RCJB BHA#27.TIH with RCJB BHA's#28 and#29.Circulate hole over to clean SW.TIH and retrieve IBP BHA#30.TIH and retrieve original PBR/Packer/Tailpipe ass'y BHA#31. 00:00 01:00 1.00 2,360 323 COMPZ CEMEN-TRIP P PJSM-TOOH w/BHA#27 standing back DP. Page 18 of 28 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:00 01:30 0.50 323 0 COMPZ CEMENT PULD P Lay down, clean out BHA#27, RCJB packed off with cement,formation and metal shavings,recovered brass bolt and complete 5"aluminum ring in 4 pieces. boot baskets empty,3 lbs of metal shavings on magnet. 01:30 02:00 0.50 0 323 COMPZ CEMEN"PULD P PJSM-MU 2nd run 6 1/16"RCJB,bit sub,tandem boot baskets, bit sub, string magnet, bumper sub, pump-out-sub,3 stds. DC's BHA#28 02:00 02:45 0.75 323 2,425 COMPZ CEMENT TRIP P TIH with BHA#28 on DP to 2,417ft, 70k Up/75k Dn, PU to 2,360-ft,set parameters, rot 30 rpm at 1k free torque,6 bpm at 1400psi, 1 to 2.5k TD torque,work to 2,425-ft, unable to work further, PU 15k over,junk around JB, PU to 2,360-ft. 02:45 03:30 0.75 2,425 2,360 COMPZ CEMENT CIRC P Circulate bottoms up 6 bpm at 1400 psi,good amount of green cement w/ fibers,arctic pack,formatiom and small metal shavings across shakers. 03:30 04:15 0.75 2,360 323 COMPZ CEMEINI TRIP P PJSM-TOOH w/BHA#28 standing back DP. 04:15 05:00 0.75 323 0 COMPZ CEMEN"PULD P Lay down and clean out BHA#28, RCJB has 57 ea. 1"x 1"metal centralizer slips,7 pieces of centrlizers 5"x 3"lost during 7" de-complete and assorted metal debris,boot baskets 8 more pieces of centralizer slips for a total of 65 1" x 1"slips recovered. 05:00 05:30 0.50 0 323 COMPZ CEMEN"PULD P PJSM-MU 3rd run 6 1/16"RCJB,bit sub,tandem boot baskets,bit sub, string magnet,bumper sub, pump-out-sub,3 stds. DC's BHA#29 05:30 06:00 0.50 323 2,426 COMPZ CEMEN"TRIP P TIH with BHA#29 on DP to 2426' 06:00 08:30 2.50 2,426 2,470 COMPZ CEMEN"MILL P On Bottom-6 bpm @ 880 psi, rotate 30 rpm, 1K free torque,3K downweight 2426'Burn off, no weight on mill good clean sand across shakers to 2451'.Circ B/U. Continue in hole to 2470'(5ft above fishneck).Circ B/U 3 times until well cleans up. 08:30 10:00 1.50 2,470 323 COMPZ CEMEN"TRIP P PJSM-TOOH. 10:00 11:30 1.50 323 0 COMPZ CEMEN"PULD P Lay down BHA#29. Roughly 3# metal on magnet. 1-5"chunk of metal in reverse basket&small metal chunks in boot basket. 11:30 12:00 0.50 0 6 COMPZ CEMEN"PULD P PJSM-P/U thru-tubing 5.75"PBR fishing retrieval tool. BHA#30. 12:00 13:30 1.50 6 2,456 COMPZ CEMEN"TRIP P TIH-Sit above TOS @ 2456'and circulate well over to seawater,6 bpm @ 485 psi. Up/Down weight 70K Page 19 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 2,456 2,525 COMPZ RPCOM PULL P RIH Pumping 4 born @ 280 psi.Set down @ 2485'pressure increase to 720 psi, P/U to string weight and circulate B/U-clean returns-Stop pumping-RIH and set down on IBP 5K,equalize packer. No change in fluid level at surface. RIH to 2525'to ensure fish on. 14:30 16:00 1.50 2,525 6 COMPZ RPCOM TRIP P P/U to blow down Top drive, Let fluid balance in DP,TOOH with BHA. 16:00 16:30 0.50 6 0 COMPZ RPCOM PULD P Lay down BHA#30 with IBP fish. Looked good.Total of 7 bbls loss while POOH. 16:30 17:00 0.50 0 0 COMPZ RPCOM OTHR P Clean and clear floor,off load Baker tools. 17:00 17:30 0.50 0 312 COMPZ RPCOM PULD P PJSM-MU 3-1/2"Bowen ITCO spear, bumper sub,oil jar, pump-out-sub,3 stds. DC's, intensifier, BHA#31 17:30 23:30 6.00 312 7,020 COMPZ RPCOM TRIP P TIH with BHA#31 on DP stands to 3,020-ft,single in DP from pipe shed to 7,020-ft, 126k Up/108k Dn.drop pump out sub dart. 23:30 00:00 0.50 7,020 7,020 COMPZ RPCOM JAR P Top of PBR at 7,014-ft,engauge at 7,020-ft,work to 125k straight overpull,packer not moving,start jarring at 50 k over,straight overpull to 225k working up to 75k over with 250k straight overpull. 01/29/2013 Retrieve original PBR/Packer/Tailpipe ass'y. Circulate 2x bottoms up. NFT.TIH with Cement mill BHA#32, Mill from 7,169-ft to 7,189-ft fell out and washed down to 7,250-ft, noticed 5 bbl gain, PU to 7,154-ft,shut in annular, 15 bbl total gain in pits.Circulate with another 25 bbl gain,shut in,SIDPP 150 psi,csg=290 psi, make calculations,appropriate notifications.Circulate to keep top drive from freezing up while waiting on new KWF. 00:00 03:30 3.50 7,020 6,985 COMPZ RPCOM JAR P Top of PBR at 7,014-ft,engauged at 7,020-ft, 126k Up/108k Dn, continue to jar at 75k over,work up to 100k over jarring,straight pull to 290k,80 jars and packer pulled free, PU 15k over to 6,985-ft,stand back 1 std. 03:30 05:30 2.00 6,985 6,985 COMPZ RPCOM CIRC P Rig up circulating equipment, pressure DP up to shear pump out sub at 2100 psi.Circulate 2X bottoms up 6 bpm at 720 psi ICP,6 bpm at 820 psi FCP. BDTD. RD circulating equipment. Performed required Derrick Inspection during CBU. 05:30 06:30 1.00 6,985 6,985 COMPZ RPCOM OTHR P Monitor well for NFT 30 minutes. 06:30 11:00 4.50 6,985 312 COMPZ RPCOM TRIP P PJSM-TOOH with BHA#31 and packer ass'y fish from 6,985-ft standing back DP, 135k Up/108k Dn Page 20 of 28 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 312 0 COMPZ RPCOM PULD P Lay down BHA#31 and complete 22.37-ft PBR/PKR and 18.84-ft tailpipe ass'y(41.21-ft OAL). 12:00 13:00 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear floor,off load pipe shed, load tools. 13:00 14:00 1.00 0 316 COMPZ WELLPF PULD P PJSM-MU 6 1/8"rock bit,dual boot baskets, bit sub,string magnet, bumper sub,oil jar,pump out sub,8 DC's, BHA#32 14:00 16:30 2.50 316 7,000 COMPZ WELLPF TRIP P TIH with BHA#32 on DP to 7,000-ft, 127k Up/110k Dn 16:30 17:30 1.00 7,000 7,000 COMPZ WELLPF CIRC P Circulate hole over from seawater to bio visc-seawater,6 bpm at 850 psi. 17:30 20:00 2.50 7,000 7,250 COMPZ WELLPF MILL P Wash down from 7,000-ft 6 bpm at 900 psi,tag TOC at 7,169-ft, 122k Up/106 Dn,Set parameters,SCR pump#1=250 psi @ 20 spm,320 psi @ 40 spm,pump#2=240 psi @ 20 spm,310 psi @ 40 spm, rot 80 rpm,3.5k free torque,5 bpm at 800 psi, mill cement from 7,169-ft to 7,189-ft and fell out,wash down to 7,250-ft. 20:00 21:30 1.50 7,250 7,189 COMPZ WELLPFCIRC P 5 bbl gain in pits noticed, PU to 7,189-ft, monitor well for flow, 10 bbl gain in pits,close annular bag at 20:15 with a total of 15 bbl gain, line up thru choke and gas buster and circulate 2 bpm at 320 psi, noticed another 25 bbl gain in pits while circulating,shut in and moitor 10 min,SIDPP=150 psi,CSG=290 psi. 21:30 00:00 2.50 7,189 7,189 COMPZ WELCTL CIRC P Circulate 56 spm holding 700 psi DPP. need to circulate to keep top drive from freezing up.Calculate and order up 450 bbls 9.6 ppg KWF stored at KIC and 290 bbls KWF from MI swaco Prudhoe. Make appropriate notifications while circulating and waiting on new KWF. Notified CWG Supv at 21:45 pm of kick and annular closure. Notified Town Engineer at 21:50 pm of kick and annular closure. CWG Supv called at 22:10,talked over contingecy plan. Town Engineer called at 22:30,State (Guy Schwarts)verbaly notified,we will provide written notification within 24 hrs,also talked over plan forward, will prepare Kill Sheet and discuss in PJSM Notified AOGCC North Slope rep. John Crisp of annular bag closure at 22:50. Cold weather operating procedure in effect at 22:30,-35 amb temp. Page 21 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/30/2013 24 hr Summary Circulate to keep top drive from freezing up while waiting on new KWF.Circulate initial calculated KWF 9.8 ppg,shut in 100 psi SIDPP/CSG,calculate new KWF,continue to circulate while waiting on 12 ppg NaBr spike fluid from Prudhoe. 00:00 06:00 6.00 7,189 7,189 COMPZ WELCTL KLWL P Continue circulating hold 700 psi at 56 spm with minimal losses, no gains,slow pump rate to 41 spm holding 490 psi,seeing slight gain, hold 550 psi DPP at 41 spm with no losses or gains. KIC upright valves froze up, unable to load trucks,call and wait on all new KWF from Prudhoe 730 bbls total. 06:00 15:00 9.00 7,189 7,246 COMPZ WELCTL KLWL P Continue to Circulate well through manual choke valve @ 2 bpm @ 680 psi SPP and 300 psi Choke manifold pressure while conducting risk assessment with Rig superintendent for stripping through annular to lower Top drive below wind walls to help in preventing freeze up due to extreme cold temperatures. Held PJSM with crew on stripping through the annular and at 09:30 hrs,shut down pump#2 and began stripping procedure from 7,189-ft to 7,248-ft. Tagged and picked up 2-ft. Re-establish circulation at 40 spm @ 940 psi SPP and 580 psi choke manifold pressure. 15:00 21:00 6.00 7,246 7,246 COMPZ WELCTI KLWL P Continue to circulate 9.8 ppg NaCI @ 40 spm @ 320 psi SPP and 250 psi Choke manifold pressure. Temperature in 70°F and 68°F out till 12 ppg NaBr spike fluid arrives. Holding 340 psi DPP with 150 psi choke manifold pressure,9.8 ppg NaCI in/out,70°F in/out, 19 bbls losses. 21:00 00:00 3.00 7,246 7,246 COMPZ WELCTI KLWL P Shut down pumping operations- blow through choke manifold to kill tank with 2"air line to verify secondary options are available. Begin circulating well with 9.8 ppg NaCI @ 2 bpm @ 870 psi with 540 psi choke manifold pressure as per pump schedule, pumped 260 bbls before seeing 9.8 ppg returns with 16 bbl loss. Shut down pump operations and monitor well for 15 minutes had 100 psi on SIDP and SICP. 01/31/2013 Circulate to keep top drive from freezing up while waiting on 12 ppg NaBr Spike fluid for new KWF blend. Blend calculated new 10.5 ppg KWF. Kill Well. Hang BHA#32 under Storm Packer and test. Begin weekly BOPE test. Page 22 of 28 I • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 04:00 4.00 7,246 7,246 COMPZ WELCTL KLWL P Continue to circulate 9.8 ppg NaCI @ 40 spm @ 340 psi SPP and 150 psi Choke manifold pressure. Temperature 70°F in/out till 12 ppg NaBr spike fluid arrives. Spike fluid on site at 00:30, blend 9.8 ppg NaCI up to 10.6 ppg NaBr/NaCI KFW. 04:00 09:00 5.00 7,246 7,246 COMPZ WELCTI KLWL P 420 bbls of 10.5 NABR NACL blended,PJSM-line up pits,set choke and begin with 5 bbls to fill rig system,Begin circulating well with 10.5 heavy NABR NACL @ 2 bpm @ 420 psi with 290 psi choke manifold pressure as per pump schedule, pumped 256 bbls before seeing 10.5 heavy ppg returns. Shut down pump operations and monitor well 15 minutes,well on vac, line up to open choke and CBU 2 bpm at 200 psi,0 psi choke pressure. Monitor well for 10 minutes-No flow 09:00 11:30 2.50 7,246 7,188 COMPZ WELCTL CIRC P Open Annular,Circulate surface to surface @ 2 bpm @ 200 psi with 2 bbl loss. Monitor well for 10 minutes -No flow. Breakout Top drive and blow down Lay down 2 jts to 7,188-ft. 11:30 12:30 1.00 7,188 7,188 COMPZ WELCTI OWFF P Monitor well on trip tank for flow-1st 10 minutes lost.5 bbls,total losses for 1 hr is 1.5 bbls. 12:30 14:00 1.50 7,188 6,898 COMPZ WELLPF TRIP P Bring in Baker Storm packer up beaver slide. POOH w/3 stds from 7,188-ft to 6,898-ft. Wash BOP stack w/side lateral wash tool. 14:00 15:00 1.00 6,898 110 COMPZ WELLPF PULD P PJSM on PU and MU of storm packer assy. PU and MU Baker Storm packer assy and RIH to 120-ft and set same. Hang off 110k, Release off and POOH. 15:00 16:15 1.25 110 110 COMPZ WELCTI PRTS P Close blind rams and pt storm packer at 500 psi(equivalant to 4,040 psi)for 15 minutes. Good test. Bleed off and NFT for 30 minutes-Good test. 16:15 20:00 3.75 110 110 COMPZ WHDBO BOPE P Pull wear ring and install test plug. RU test equipment and service choke.Conduct weekly BOP, annular,choke manifold test.shell test being difficult,pull test plug and replace worn seal, isolate components to verify area of leak. 20:00 00:00 4.00 110 COMPZ WHDBO BOPE T Shell test being difficult,pull test plug and replace worn seal, isolate components to verify area of slow leak. 02/01/2013 Complete weekly BOPE test. Recover Storm Packer.Mill to 7,500-ft.CBU. NFT.TOOH with BHA#32. Page 23 of 28 I i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 09:00 9.00 110 110 COMPZ WHDBO BOPE T Continue to isolate BOPE components to verify area of leak. Pull, inspect(plug in good shape) and reset test plug, unable to get test.bring in tbg hanger and warm up.Cameron rep hotshot for another plug. Install"New"test plug and attempt to test-continue to have issues with bleed off. 09:00 12:00 3.00 110 110 COMPZ WHDBO BOPE P At 09:00 hrs, RIH 2 opposing lock down screws on ported test plug and isolate to LPR's on 3 1/2 test joint. PT at 250/3,500 psi-good test. RD 3 1/2 test joint w/10"donut, PU and MU 3 1/2 IF working joint and screw into ported test plug. Continue to test UPR's, Kill line valve,and manual choke valve. Annular w/ HCR CV,MK valve on mud cross. Good Test. Unscrew 3 1/2 IF working joint and back out 2 opposing lock down screws. Close Blind rams and test CM 2,5,6 and MK on mud cross-11"DSA x CPAI 1 spacer spool had small flange leak. Retest and passed. Continue to test Blind rams,CM 4, 11, 12-Dart valve,and Upper kelly cock leaning on the HCR Kill-passed. Test Blind rams,CM 7,9, 10 and 3. along with lower Kelly cock,3 1/2 IF floor valve and HCR Kill-Good Test. Test Blind rams, HCR Kill,CM 5,8,2 and 3 1/2 EUE 8rd floor valve.-Good Test. RD test equipment and conduct draw down. Starting pressure: 2,950 psi After closure: 1,850 psi 200 psi Build-17 seconds. Full recovery-92 seconds N2-4 @ 2,000 psi. 12:00 12:30 0.50 110 110 COMPZ WHDBO OTHR P Pull test plug and Install wear ring w/ 6.313"ID 12:30 14:30 2.00 110 6,898 COMPZ WELLPF MPSP P PJSM-MU Storm Packer retrieving tool, release storm packer at 110-ft, monitor well on trip tank 30 minutes, 4.4 bbl loss to well,TOOH with storm packer and LD same. 14:30 17:30 3.00 6,898 7,470 COMPZ WELLPF TRIP P PJSM-Continue TIH with BHA#32 from 6,898-ft to top pert at 7,188-ft, wash down 8 bpm at 2300 psi,tag up at 7,470-ft. 17:30 18:30 1.00 7,470 7,500 COMPZ WELLPF MILL P Set parameters 70 rpm,8 bpm at 2400 psi,4k free torque 140k Up/ 95k Dn, 115K rot, mill down 7,470 to 7478-ft 4.5k TD torque 2k wob,wash down to 7,500-ft. Page 24 of 28 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:00 1.50 7,500 7,500 COMPZ WELLPF CIRC P Circulate 30 bbl high visc sweep 10 bpm at 3600 psi 2 hole volumes, 10.5 ppg in, 10.4 out,condition fluids. 20:00 20:30 0.50 7,500 7,150 COMPZ WELLPF TRIP P PJSM-TOOH from 7,500-ft to 7,150-ft, 140k Up. 20:30 22:00 1.50 7,150 7,150 COMPZ WELLPF CIRC P SCR Pump#1=20 spm-80 psi/40 spm-160 si, Pump#2=20 spm-80 psi/40 spm-170 psi,circulate bottoms up 10.5 in/10.4 heavy back 22:00 22:30 0.50 7,150 7,150 COMPZ WELLPF OWFF P Monitor well on trip tank,static 22:30 00:00 1.50 7,150 3,705 COMPZ WELLPF TRIP P PJSM-TOOH from 7,150-ft, 140k Up, standing back DP to 3,705-ft,90k Up. 02/02/2013 Continue TOOH with BHA#32.TIH with Clean out BHA. Slip/Cut drill line. CBU. NFT.TOOH with BHA#34. TIH with HES TCP guns. 00:00 01:30 1.50 3,705 316 COMPZ WELLPF TRIP P PJSM-TOOH from 3,705-ft,90k Up, standing back DP to 316-ft. 01:30 02:30 1.00 316 0 COMPZ WELLPF PULD P Lay down BHA#32,approximatly 3# metal on magnet,2.5"x 1.5"piece of csg, pert junk,cement and frac sand in boot baskets. 02:30 03:30 1.00 0 780 COMPZ WELLPF PULD P PJSM-MU muleshoe, 12 jts DP, double pin sub,7"casing scraper,bit sub, bumper sub,oil jar, 3 stands 4 3/4"DC's, BHA#34,TIH on 1 stand DP. 03:30 05:30 2.00 780 780 COMPZ WELLPF SLPC P Slip/Cut Drill 84-ft Line. 05:30 09:30 4.00 780 7,495 COMPZ WELLPF TRIP P Continue TIH with BHA#34 on DP to 7495-ft 140 up wt,97k do wt 09:30 11:30 2.00 7,495 7,495 COMPZ WELLPF CIRC P Circulate @ 8 bpm @ 2,150 psi w/2 bbl loss. Mix up 35 bbl High visc sweep and pump surface to surface @ 10 bpm @ 3,500 psi. While rotating @ 60 rpm w/4k torque, while reciprocating. 11:30 12:30 1.00 7,495 7,495 COMPZ WELLPF OWFF P Monitor well for flow on trip tank-lost 1.3 bbls. 12:30 17:30 5.00 7,495 688 COMPZ WELLPF TRIP P PJSM. Locate and Drop 2..125"OD drift w/wire. POOH w/BHA#34 from 7,495-ft, 150k Up/100k Dn. 17:30 19:00 1.50 688 0 COMPZ WELLPF PULD P POOH laying down 4 3/4"DC's,CSG scraper assy,and stand back 4 stands of 3 1/2 DP. 19:00 20:30 1.50 0 0 COMPZ WELLPF OTHR P PJSM-Clean and clear floors,Off load Baker tools, bring in HES tools. 20:30 21:00 0.50 0 0 COMPZ PERF SFTY P PJSM with HES rep.and Nordic 3 crew,TCP make up safety and running procedures,check line up in pipe shed. Page 25 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code _Subcode T Comment 21:00 22:00 1.00 0 170 COMPZ PERF PULD P PU MU HES TCP ass'y-bull plug blank,4 5/8"5 SPF Millenium guns, blank section,2 Surge Pro gun sections, Modell) D mechanical fire head w/1.56"no-go, 1 jt.2 7/8" 6.4#, L-80, EUE 8rd tbg.,ported fill disk, 1 jt.2 7/8"6.4#, L-80, EUE 8rd tbg.,2 7/8"RA marker pup,XO sub for BHA#35. 22:00 00:00 2.00 170 5,688 COMPZ PERF TRIP P TIH with TCP ass'y BHA#35 on DP to 5,688-ft, 115k Up. 02/03/2013 TIH with HES TCP guns. RU E-line and correlate pert depths. RD E-line. Position TCP guns and perferate interval 7,188-ft to 7,228-ft. NFT.TOOH with BHA#35. Prep and Run 3 1/2"GL Completion. 00:00 02:00 2.00 5,688 7,242 COMPZ PERF TRIP P Continue TIH with TPC ass'y BHA #35 from 5,688-ft to 7,247-ft, PU, position and space out TCP ass'y at 7,242-ft,mark pipe,make up FOSV and wireline connection. 02:00 03:30 1.50 7,242 7,242 COMPZ PERF ELOG P MI spot HES E-line equipment, make up tools, bring tools to floor. 03:30 04:45 1.25 7,242 7,242 COMPZ PERF ELOG P PJSM-E-line rig up procedure, RU E-line.well loseing appoximatly 1.76 bph on trip tank. 04:45 08:15 3.50 7,242 7,230 COMPZ PERF PERF P RIH w/1-11/16"GR/CCL and correlate TCP RA marker to original SLB log dated 21 july, 1986,Confer w/HES E-line,TCP rep, POOH w/ GR/CCL tool. Found RA marker @ 7,093-ft-placing Top shot at 7,220-ft±. Remove jt#219 and install spacer sub w/RT marker, MU jt 219 RIH to 7,093-ft with RA marker, Pull back to RT mark and land in slips. Lay down jt#219 and MU pup on top of FOSV install firing bar,MU TD SI to monitor pressure on Stand pipe and Choke manifold. Drop bar with RA marker @ 7,061-ft,placing Top Shot @ 7,188-ft and Bottom shot @ 7,228-ft.with tail @ 7,230-ft. Drop bar and Felt guns fire,Monitor well- no influx for 15 minutes. 08:15 08:45 0.50 7,230 7,230 COMPZ PERF OWFF P Monitor well for flow on trip tank for 30 minutes-lost 4.4 bbls. 08:45 16:00 7.25 7,230 0 COMPZ PERF PULD P Held PJSM, POOH laying down 3 1/2 IF DP and pert assy 16:00 17:30 1.50 0 0 COMPZ RPCOM OTHR P Off load Pipe shed,Change out DP running equipment to 3-1/2 TBG equipment and pull the wear ring 17:30 00:00 6.50 0 6,592 COMPZ RPCOM RCST P PJSM, PU,MU and RIH w/3 1/2 Gas Lift Completion as procedure well design to 6,592-ft. 02/04/2013 Run 3 1/2"GL Completion.Spot corrosion inhibited 10.5 ppg at packer. RU Slickline,Set CA2 plug and catcher. RD Slickline. Set packer.Shear PBR.Space out. Land Tubing Hanger.Test pack-offs.Test tubing and IA 3000 psi.Shear SOV. Set BPV,test from below. ND BOPE. NU Tree and test. Freeze Protect. Page 26 of 28 K • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 6,592 7,110 COMPZ RPCOM RCST P Continue to RIH w/3 1/2 Gas Lift Completion as procedure well design from 6,592-ft,MU joints#224á for space out,mark pipe at packer set depth and RIH to 7,110-ftand set in slips. RU circlating equipment. 01:00 02:00 1.00 7,110 7,110 COMPZ RPCOM CIRC P Circulate 30 bbls 10.5 ppg corrosion inhibited NaBr/NaCI brine,chased with 58 bbls 10.5 ppg NaBrNaCI brine taking returns up IA 2 bpm at 100 psi, 1:1 returns. RD circulating equipment 02:00 07:00 5.00 7,110 7,110 COMPZ RPCOM SLKL P PJSM-MIRU Slickline,bring equipment to floor, pressure test equipment 500 psi, RIH with 2.812" CA-2 plug,set at 7,097-ft SLM,test plug to 500 psi,good. POOH, RIH with catcher("G"FN)set on top of CA-2 plug, POOH, RDMO Slickline. 07:00 08:30 1.50 7,110 7,091 COMPZ RPCOM PACK P Pull up to mark on pipe,pressure up tubing to 3000 psi and set packer top at 6,995-ft, PU and shear PBR at 10k overpull, PU above PBR,bring on pump at minimum rate,find top of PBR,shut down pump,and space out, mark pipe, POOH, LD joints #224á. 08:30 09:30 1.00 COMPZ WHDBO NUND P MU McEvoy tubing hanger and landing joint, RIH and re-land completion,up wt.=97,000 lbs.down wt.=77,000 lbs. RILDS. 09:30 12:30 3.00 7,091 COMPZ RPCOM THGR P test tubing to 3600 psi 30 miniute test. IA to 3000 psi test.tested good. Bled off pressure and pressured back up on IA to 1850 psi sheared SOV. 12:30 13:30 1.00 COMPZ WHDBO MPSP P Set BPV @ 500 ft and tested to 1000 psi 10 minutes test and 30 min N FT. 13:30 15:00 1.50 COMPZ WHDBO NUND P ND 11"BOPE stack and rack back. 15:00 17:00 2.00 COMPZ WHDBO NUND P NU Xtree and test to 250/5000 psi 17:00 21:00 4.00 COMPZ WHDBO PRTS P RU test equipment,pressure test tree and pack-offs 250/5000 psi, RD test equipment. 21:00 21:30 0.50 COMPZ WHDBO MPSP P PJSM-Pull Cameron test dart and BPV. 21:30 00:00 2.50 COMPZ WHDBO FRZP P PJSM with LRS, Peak and Nordic 3 crews, RU cellar circulating hoses, P/T lines 3500 psi,freeze protect well down IA taking returns up tubing with diesel,2 bpm at 600 psi ICP. 02/05/2013 Freeze Protect.Set BPV.Secure well.Operations ceased do to-35°F Cold Weather Operations Procedure. Page 27 of 28 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 COMPZ WHDBO FRZP P Continue to freeze protect well down IA taking returns up tubing with 244 bbls diesel,2 bpm,700 psi FCP. RD circulating hoses, RDMO LRS and Peak transport. 02:00 03:30 1.50 COMPZ WHDBO MPSP P Lubricate in BPV and secure well. BDTD.Clean and dress well head. SI pressures 0/0/0.secure cellar. 03:30 08:00 4.50 COMPZ MOVE OTHR P RD support equipment.Clean pits. 08:00 00:00 16.00 COMPZ MOVE DMOB T In preparation to pulling rig off the well, Kuparuk field went on-35°F Cold weather operating at 08:07 hrs. Crews continue to work inside on various projects while waiting for -35°F Cold Weather to lift. 02/06/2013 Operations ceased do to-35°F Cold Weather Operations Procedure. 00:00 00:00 24.00 COMPZ MOVE DMOB T In preparation to pulling rig off the well, Kuparuk field went on-35°F Cold weather operating at 08:07 hrs. Crews continue to work inside on various projects while waiting for -35°F Cold Weather to lift. Clean and Organize Rig,Service Mud Pumps, Modify 6"Fluid Line in Pill Pit,Service Catwalk,Serviced and Tested 2"Block Valves, Paint,C/O Suction Rubber in Pits, Replaced Linkage Bolt in Pits. 02/07/2013 Wait on Weather until 05:30- Warm up Move System,Clean up Cellar Box,Mob Rig to 2N-304 00:00 05:30 5.50 COMPZ MOVE DMOB T In preparation to pulling rig off the well, Kuparuk field went on-35°F Cold weather operating at 08:07 hrs on 2-5-13. Crews continue to work inside on various projects while waiting for-35°F Cold Weather to lift. Clean and Organize Rig,Service Mud Pumps, Modify 6"Fluid Line in Pill Pit,Service Catwalk,Serviced and Tested 2"Block Valves, Paint, C/O Suction Rubber in Pits, Replaced Linkage Bolt in Pits. 05:30 12:00 6.50 COMPZ MOVE DMOB P Cold Weather restrictions were lifted field wide @ 5:38 hrs. Crew began to warm up move system and prepare to pull off well. Crew backed off well and cleaned cellar. Released Nordic Rig 3 @ 12:00 hrs on 2-7-13. Page 28 of 28 • prt, i e(0 0 0 Regg, James B (DOA) From: Nelson, Erik Q [ Erik.Nelson @conocophillips.com] Sent: Wednesday, January 30, 2013 5:52 PM ieiq t (31 I l s To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Robinson, Shon D; Gober, Howard Subject: Well 2T -08 (PTD #186 -109) (AOGCC Sundry #312 -487) Notice of BOPE usage... Mr. Schwartz, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE usage on Nordic 3 with a written report. Date, Time of BOPE Use: 29 January 2013 at - 2000 hrs Well Location / API# / PTD #: 2T -08 Kuparuk River Unit SCANNED APR 1 1 2013 (Sundry # i f applicable) API# - 50- 103 - 20070 -00 app ) PTD# - 186 -109 Sundry# - 312 -487 - Rig Name: Nordic 3 Operator Contact: Erik Nelson 907 - 263 -4693 - Erik. Nelson(a,conocophillips.com Operations Summary: On 29 January 2013 at - 2000 hrs during the RWO on 2T -08 in the Kuparuk River Unit, Nordic #3 was milling through a cement isolation plug that had been bullheade ilIgm surface in order to secure the well on 26 January 2011. One of the objectives of the RWO was to re- establish communication with the Kuparuk A -sand reservoir in order to return 2T -08 to production. As the mill penetrated the upper section of the perforated A -sand interval (7188 - 7192' MD and 5805 - 5808' TVD) the rig crew noticed - 15 bbls gain in the pits. The crew immediately picked up on the workstring and closed the annular ram in order to secure the well. Circulation was begun again and another - 25 bbls pit gain was noted as the choke was stabilized. Fluid in the hole and pit system was - 8.6 lb/gal seawater with Tec -Vis to increase the viscosity to aid in carrying the cement cuttings. SIDPP was 150 psi w/ 290 psi SICP. BOPE Used: Annular Ram and choke manifold valves 6, 5, and 2. -- Reason for BOPE Use: Control flow of fluids from the wellbore due to reservoir differential. Actions Taken / To Be Taken: We have been attempting to kill the well with 9.8 Ib /gal brine circulating through a poor boy degasser and have a sufficient volume of 9.8 lb/gal brine on location. There have been no signs of gas in the pits. A Little Red Services pumping unit is on location in case something goes awry with the rig pumps during the well kill operation. We'll circulate 150% of wellbore volume and monitgr to confirm well is static. Upon confirmation of static conditions we'll trip out of the hole. Once on surface, we will set a test plug and test the BOPE components that were utilized before continuing operations. Let me know if you have any comments and /or questions. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #2040 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 1 w \� � � j; � s 9 THE STATE Alaska Oil and Gas °fALSKA Conservation Commission GOVERNOR SEAN PARNELL OF � 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Erik Q. Nelson Wells Engineer l 00( ConocoPhillips Alaska, Inc. P.O. Box 100360 f� Anchorage, AK AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -08 Sundry Number: 312 -487 Dear Mr. Nelson: SCANNED JAN 1 s 2013 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 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, Daniel T. Seamount, Jr. Commissioner DATED this 2 day of December, 2012. Encl. STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMISOI ' , APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell 17 ' Change Approved Program r Suspend r Plug Perforations r Perforate 17 ' Rill Tubing ' . Time Extension r Operational Shutdow n r Re -enter Susp. Well P , Stimulate Al ter casing g r ' Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' . Exploratory r 186 - 109 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20070 - 00. 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ 2T - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 0025569 . Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7676 ' 6186 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115' 115' SURFACE 2943 12 2977' 2798' RECEIVED PRODUCTION 7566 7 7600' 6126' DEC 242(12 AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Cemented Cemented 2.875 J - 7091 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - CIW TUBING HANGER . MD= 28 TVD= 28 PBR - BROWN PBR • MD= 7050 TVD= 5700 PACKER - BROWN HB -1 PACKER MD= 7067 TVD= 5713 l CMT PLUG - PUMPED & SQUEEZED 10 BBLS OF CLASS G CEME MD= 7080 TVD= 5723 NIPPLE - CAMCO D NIPPLE . MD= 7081 TVD= 5724 SOS - BROWN SHEAR OUT MD= 7091 TVD= 5731 12. Attachments: Description Summary of Proposal p . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17 ' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/1/2013 Oil • r7 Gas r WDSPL r 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: Kelly Lyons / Brent Rogers Email: Erik.Nelson aC�,conocophillios.co Printed Name Erik Q. els Title: Wells Engineer Signature , 20 Phone: 263 -4693 Date: Date: Zyil 2% Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness )67 NZ 7 e Plug Integrity r BOP Test VMechanical Integrity Test Location Clearance r 'iV * 3666 r 5a. I f5 ;s . RBDMS RBDMS DEC 2 8 201 li r s Spacing Exception Required? Yes ❑ No 0 ` Subsequent Form Required: /0 C01 Approved by / COMMISSIONER THE COMMISSION Date: /Z R `--' 0 :R464/NAL � •p roved application is valid for 12 months from the date of approval. �� �,� L (2.!? ' ubmit orm and Attachments in Duplicate k \ . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 24 December 2012 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -08 (PTD 186 -109). Well 2T -08 was drilled and completed in 1986 as an A -sand only producer. In January 2011 well 2T -08 was shut -in due to an unplanned Trans - Alaska Pipeline System (TAPS) proration. After being brought back on -line an increase in the inner annulus (IA) was noted. Subsequent diagnostic work confirmed that the leak point was in either the tubing and /or the packer. However, due to restricted access through the tubing, leak diagnostic tools could not be run. The decision was made to secure well 2T -08 with cement and on 26 January 2011 a cement plug was bullheaded from surface and displaced to the perforations. A subsequent combination mechanical integrity (CMIT) pressure test on 23 February 2011 provided assurance that the perforations had been successfully isolated. As with many wells on the 2A and 2T drillsites subsidence is assumed to be the root cause of the casing and tubing issues in this well. The purpose of this workover is to restore the integrity of the 7" production and 9 -5/8" surface casing strings in order to provide a stronger wellbore to combat the effects of future subsidence and to restore communication with the reservoir. This will be accomplished by pulling the entire existing tubing completion from the well, pulling and replacing the top — 2000 feet of 7" production casing, and cementing the 7" x 9 -5/8" annulus. By cementing the replaced 7" production casing to surface, this will effectively mitigate the surface casing leak and will provide a stronger wellbore. The cement will be removed from across the perforations and a new 3 -W gas lift completion will be run. If you have any questions or require any further information, please contact me at 263 -4693. Regards, Erik Q. Nelson Wells Engineer CPAI Drilling and Wells • • 2T -08 Kupaurk Producer Expense Rig Workover PTD #: 186 -109 Current Status 0 2T -08 is currently SI and the perforations are isolated with cement. Si... Scope of Work ♦ Pull 2 -7/8" J -55 tbg from well ♦ Run 7" csg scraper, run CBL, cut - pull - replace 7" csg above TOC ♦ Pull remaining 2 -7/8" completion ♦ Mill out remaining cement plug across A -sand perforations and re -pert A -sand interval ♦ MU and TIH w/ new 3 - %" L -80 gas lift completion to surface General Well info MASP: 2320 psi Reservoir pressure/TVD: 2379 psi / 5805' TVD (TOP in A -sand) Assuming worst case and using recorded 0 psi at the wellhead at the end placing the cement plug. Wellhead type /pressure rating: FMC Gen IV 3 -1/8" 5M x 7- 1/16" 5M 7- 1/16" 5M x 11" 3M y- BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: CMIT -T + IA passed 02 November 2012 ✓ MIT -T failed 30 January 2011 MIT -OA failed 27 March 2009 Well Type: Producer Estimated Start Date: 01 January 2013 Production Engineer: Thomas Nenahlo RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophillips.com ill • • Proposed RWO Procedure: Pre -Rig Well Work 1. Pre -RWO wellhead diagnostics - PT tbg and csg packoffs and FT LDSs 2. Set FMC Type 'ISA' BPV RU,Test, Pull Tbq, and 7" Csa Evaluation 1. MIRU Nordic #3. Accept Rig, take on fluids, pull FMC Type 'ISA' BPV, and insure well is dead. - 2. Install FMC Type 'ISA' BPV, ND tree, NU 11" 5M BOPE, install blanking plug, function and PT BOPE • to 250/3500 psi and annular to 250/3500 psi 3. Pull blanking plug & FMC Type 'ISA' BPV. Screw in landing jt, BOLDSs, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/ 2 -7/8 ", J -55 EUE -Mod tbg NOTE: If tbg does not come free of the PBR then RU HES E -line and cut tbg in 1 full jt above - PBR 5. MU and TIH w/ 7" csg scraper assembly on 3 -W IF DP. TOOH and lay down same. 6. RU HES E -Line for CAST -M (or RCBL) and string shot. RDMO HES E -Line. TOG 1 . 6,s ' �� 7" Csq Replacement 1. MU and TIH w/ RBP or IBP and set below TOC. PT to 3001 psi and drawdown test same. Dump sand on top of plug. TOOH and lay down RBP /IBP setting tool. 2. ND 11" BOPE and tbg head. Spear r land 7" csg in tension. Cut off 7" csg "growth ". NU 11" 5M BOPE on 11" 3M csg head. --- 't / �( ? NOTE: BOPE is now acting as a diverter due to a surface csg leak at - 330 ft MD with a LLR of 2 bpm. It will be pressure tested once the 7" csg has been removed. 3. MU and TIH w/ Baker MSC. Cut 7" csg with multi- string cutter on drill pipe above TOC. Circ 9 -5/8" x 7" annulus clean. TOOH and lay MSC. . 4. C /out lower BOPE pipe rams to 7" solid body. Function test rams on 7" test jt. NOTE: BOPE is now acting as a diverter due to a surface csg leak at - 330 ft MD with a LLR of - 2 bpm. It will be pressure tested once the 7" csg has been removed. 5. Spear and TOOH laying down 7" csg 6. Set test plug in 9 -5/8" csg head. C /out lower pipe rams to VBRs. PT BOPE w/ 3 - %2' test jt to o 250/3000 psi. , Pull test plug. NOTE: Lower "high" test p essure of 3000 psi due to max casing head working pressure on 9- 5/8" csg head is 3M psi. ✓ 7. MU and TIH w/ 9 -5/8" csg scraper to top of 7" stub and circ clean. TOOH and lay down same. 8. RU HES E -line and run gyro w/ GR and memory caliper in 9 -5/8" csg from 7" stub to surface. RDMO HES E -line. 9. MU and TIH w/ tandem string mill assembly to gauge csg for installation of new 7" csg string. TOOH and lay down same. 10. MU and TIH w/ dummy for 7" csg and Halliburton ES cementer. TOOH and lay down same. 11. MU and TIH w/ back off tool and back off csg stub. TOOH and lay down same. 12. MU and TIH w/ spear and recover csg stub. TOOH and lay down same. '7` 7 13. Set test plug in 9 -5/8" csg head. C /out lower pipe rams to 7" solid body. PT BOPE w/ 3 -'/2" test jt to 250/3000 psi. Pull test plug. NOTE: Lower "high" test pressure of 3000 psi due to max casing head working pressure on 9- 5/8" csg head is 3M psi. 14. MU and TIH new 7" csg w/ Halliburton ES cementer. 15. Screw into top of 7" csg. Pressure test 7" csg to 2500 psi./ • i + r 16. Open ES cementer and pump cement (calculated plus - 25% excess) into 9 -5/8" x 7" annulus Cmt Req'd 15.7 ppg ArcticSet 1 0.93 ft /sk Estimated TOC = 2300 ft MD 75 bbl vol including excess 17. Cmt Pump Schedule (exact volumes will be adjusted according to actual TOC) a. 5 bbls freshwater b. 72 bbls neat 15.7 lb/gal ArcticSet 1 ?u c. Launch closing plug cA4Jr d. Displace w/ 3 bbl neat 15.7 lb/gal ArcticSet 1 e. 5 bbls freshwater f. XX bbls heated seawater (- 90° F) to bump plug 18. WOC. ND BOPE and land 7" on slips. Cut 7" csg and install packoff. NU tbg head and 11" 5M BOPE w/ VBRs in bottom cavity. PT csg packoff to 3000 psi. PT break below tbg head to 3000 psi. Install test plug in tbg head and PT BOPE to 250/3500 psi for 30 min and record on chart. 19. MU and TIH w/ cement milling assembly and mill out cement and plug. Pressure test csg to 250/3000 psi for 30 min and record on chart. TOOH laying down same. 20. MU and TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH and lay down same. 21. MU and TIH with wash shoe and circulate out sand on top of RBP. TOOH and lay down same. 22. MU and TIH w/ retrieving tool. Release RBP /IBP and TOOH and lay down same. Fish remaining 2 -7/8" Completion and Drill Out Cement Plug 23. MU and TIH w/ packer retrieval assembly. TIH to retrieve remaining 2 -7/8" completion. TOOH and lay down same. 24. MU and TIH w/ cement milling assembly and TIH to TOC in the 7" csg. Drill out cmt past btm perfs (7228' MD) and mill out to - 7350' MD. TOOH and lay down same. 25. MU and TIH w/ 7" csg scraper w/ cleanout assembly to PBTD. Reverse circulate 2X BU. TOOH and lay down same. Re -Perf A -Sand and run Pkr on E -line 26. MIRU HES E -Line. Re- perforate A -3 and A -4 sands using 3 -3/8" pert guns. ✓ 27. MU and RIH w/ Baker FHL pkr and 3- tbg tail assembly to set FHL pkr - 7000' MD. 28. RDMO HES E -line 1% v .•t'- " c`� Il « Run 3 - GL Completion 30. MU and TIH w/ 3- L -80 GL completion 31. Load tbg and IA with diesel. Stab seal assembly into PBR and space,Qut. PT tbg 2500 si and IA to 3500 psi 30 min each and record on chart. • Sp - f - 4.G: !' ? 5.944 - - r 32. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packofl's to 250/5000 psi. 33. Pull 2 -way check. Freeze protect well. Set FMC Type 'ISA' BPV. RDMO Doyon 141. b�.rw Post -Rip Work: MIRU HES Slickline 1. Pull SOV from GLM and run GLD 2. Handover to Ops via handover form for POP... KU P a 2T -08 Conoc Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UW' Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) co,,,x.oflall,P, 501032007000 KUPARUK RIVER UNIT PROD 48.25 3,000.00 7,676.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Well Cocas - 27-08, 113112012+0 :0731AM - SSSV: Flapper Locked Out 25 1/17/2010 Last WO: 40.10 7/22/1986 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag TOC 7,080.0 1/26/2011 Rev Reason: WELL REVIEW osborl 1/31/2012 Casing Strings HANGER, 28 mom Milt NW. Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 37.0 115.0 115.0 62.58 H 111`` Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd SURFACE 95/8 8.765 33.6 2,976.8 2,798.4 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.6 7,600.0 6,125.8 26.00 J -55 BUTT M / Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (r... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 27/8 2.441 28.3 7,092.1 5,731.7 6.50 J -55 EUE8rdABMOD Completion Details Top Depth CONDUCTOR, 37 -775 (TVD) Top Incl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 28.3 28.3 0.35 HANGER CIW TUBING HANGER 2.875 SAFETY VLV, { r" 1,829.8 1,824.9 11.87 SAFETY VLV Camco TRDP -1A -SSA (FLAPPER LOCKED OUT 6/16/2003) 2.312 7,050.2 5,700.0 40.64 PBR BROWN PBR 2.347 7,066.9 5,712.6 40.60 PACKER BROWN HB-1 PACKER 2.441 GAS LIFT, 2,653 ` L 7,081.3 5,723.6 40.56 NIPPLE CAMCOD NIPPLE 2.250 7,091.3 5731.1 40.54 SOS BROWN SHEAR OUT 2.375 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc' Top (ftKB) IRKS) (°) Description Comment Run Date ID ('n) 7,080.0 5,722.6 40.57 CMT PLUG PUMPED & SQUEEZED 10 BBLS OF CLASS G CEMENT 1/26/2010 0.000 ACROSS PERFS; TOC @ 7080' SURFACE, . _____, r 1 L 342,977 Perforations & Slots GAS LIFT, Dens 4734 Top (TVD) Btm Shot Top (ftKB) Btm (ftKB) (ftKB) (ftKB) (TVD) Zone Date (FP.- Type Comment I I I 7,188.0 7,192.0 5,804.8 5,807.8 A-4, 2T -08 10/14/1986 1.0 IPERF 90 deg. Ph; 4" HyperJet II GAS LIFT. 7,202.0 7,206.0 5,817.2 5,820.1 A -3, 2T -08 10/14/1986 1.0 IPERF 90 deg. Ph; 4" HyperJet II IlD 5,692 7,208.0 7,228.0 5,821.5 5,836.2 A -3, 2T -08 10/14/1986 4.0 IPERF 90 deg. Ph; 4" HyperJet II Notes: General & Safety _ - GAS LIFT, Date _ Annotation 6,040 t 12/1/2010 10 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, l G 6,389 GAS LIFT, rj rli 6,707 GAS LIFT, 7,005 H PBR, 7,050 PACKER, 7,067 „v .' , k ilig NIPPLE. 7,081 - t 505, 7,091 CMT PLUG, 7,RF. Aq IPERF, 7,188 -7,192 - IPERF, _ 7,202 - 7,206 2q / �> Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run IPERF, AS Stn Top IRKS) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 7208 - 7,228 1 2,653.0 2,563.5 37.87 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,277.0 7/25/1997 cscrteG 2 4,733.5 4,004.2 44.98 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,415.0 7/25/1997 CEMENT 3 5,691.7 4,689.3 44.31 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,405.0 7/25/1997 PLUG, 7,080 4 6,040.4 4,941.3 42.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/17/1997 5 6,389.5 5,201.0 41.85 CAMCO KBMG 1 GAS LIFT GLV BK 0.313 1,555.0 7/25/1997 6 6,706.7 5,439.4 41.03 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/16/1997 7 7,004.7 5,665.6 40.75 MMH 2.875x1.5 1 1/2 GAS LIFT OV RK 0.313 0.0 7/24/1997 PRODUCTION, 347,600 • TO, 7,676 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/10/11 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T -08 Oper. Rep: Martin Walters PTD No.: 186 -109 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 03/01/11 Date AOGCC Notified: 09/09/11 Sundry No.: 311 -023 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 350 ' Photos Taken? Yes IA 20 OA 50 Condition of Wellhead: Wellhead looked to be in good working condition. The flowline and A/L line were still attached. A/L line was blinded. No blind in flowline. There was 450 psi on the upstream side of the A/L. Condition of Surrounding Surface Pad looked to be good clean gravel. Cellar box was about half full of water? There was a wellhouse on the well. Location: The location was verified with the use of a plot plan. Follow Up Actions None Needed: Attachments: Photos (2) REVIEWED BY: Well Schematic Insp. Supry �� / KRU 2T -pad Layout Comm PLB 08/2010 2011- 0910_Suspend_KRU_2T- 08_bn.xls vow y y N ° . rD O oo 0 .. r 11,1', . . - I m il % I1I , O� o ' t ,-- ‘-< i— M i t) t t ij P"" 4 o • bd . te, 1 ■ Cr fa in c N o l ��� IrNo*-4-0"-* o0 1 , - - . ' _ , , fo:.., . .„.. - k } k - 1 ■ t .._... ..:,. _ - -, I ii -. , , , 1 il 11 , . , . . \ , ; 1 r ' I titillitir 2 1 1 1 1 1 . j � 1 111111 it 1 I lillik:\ -- \ i; '-- ii ' , , f li _ , . I ii ,. , , 0 , 0 • i ' IS 1111111 III \ 4R r \ . 0 \ c. \...r • • • 0 ya iy KUP 2T-08 P' 7 '/r'K T *eSF Ccan�acoPlhfllips � �rt�ut�s ' � � -__ Max' 'n1ha' Ma . 7'► Alaska WetlhoreAPUUWI Field Nam, Y&IIStatus Inch') M0( (MD) Act atmCARO) $ 501032007000 KUPARUK RIVER UNIT , PROD 4825 3,000.00 7,676.0 Comment MS (ppm) Dat• AnnoteUon End Date Ka-Ord (R) Rig Release Date "` {re SSSV : FI r Locked Out 25 1/17/2010 Last WO 40.10 7/2211986 . Annotation h a 1 d Date Annotation .... En ...... ____........_, ..... __ ._: r1 � � Last T TOC 7,080 Depth 0 iCEMENT Laat Mod _ end 26/2011 Rev Reason: PLUG 1 Irnasbor 1/28/2011 'Casing Strings , HAA'6ER, 29 -..ma 1.1.• Camn Dow ripdoo Suing 0. Stringl0 ... Top( /100/ Set Dapth(1. Set 0aplh (190)_ String 0A. Si ._ String TOp 1011 CONDUCTOR 16 15.062 37.0 115.0 115,0 87.58 H 'Casing Description - string 0.,. suli,g to .. Top (tdi$) set Depth (T.» set Depth (WE)—. String WL.. String . string Top ihr4 ti ID SURFACE 958 8.765 35.5 2,978.7 2,799.7 36.00 J - 55 BUTT ,a{°..j Casing Description String 0... String ID... Top (008) Set 010/03 St Depth (TVD) - . String Wt_. String._. String Top Thrd a PRODUCTION 7 6 151 33 6 7570 0 6,125 8 26.00 J -55 BUTT TATKETt rt010 ! 'Vii° . _ , _: i Turing Deacriptbn su ng O.. r,g X91 i ID . rap MK/3) Szt 0 pth ii... Tot 0 pin {NO) ... String Rc _ St g 'String T e► r It TUBING 27/8 1 4 l 28.3 7,072 1 5.731 7 6 50 4-55 f EUE8ry1BMOD fi eti iittott[}iitalls _; aweaTdii aiu 3.f ,. ( .. •tea - v Top WWh l ft10 8 Top incI Noma„ 0 -' 806 ( 1') tram DSacrl•I1on Command I0)14 COriwucTOR, 28. 0,35 HANGER CIW TUBING HANGER 2.875 17.115 II � 1,829.8 lliii � GamcoTRDP IASSA (FLAPPER LOCKED IX7T6/16(2003) 2.312 sAFEnVty, 1,93d ,4 7,'2 5 , •. . BROWNPBR 2.347 7,086.9 5,712.6 4060 Waal. BROWN HB-1 PACKER 2.437 7,081. ® CAMCO D NIPPLE .250 GA uFr. _ 7,091. 40.54 • B • • SHEAR OUT .441 2637 �a; .w. P -i : ri 5. . k�. 1 i ,b2" is x Ili, , , t� �, I ll �'„ Y` ` ar ;a T• It Top (MD) 8tm m 03) Dom f(a (a Ka) I zem Data lad.• MIMI comment ill'I' 7,1::.0 7,1 .0 5,:s•.:La -4,2Ta; 10114/1986 1.0 will 900e1. Ph; 4•HyperJetll .. 7,202.0 7, a.. 5,817.2 5,820,1 A -3, 2T -08 10 c IPERF 90 . .. Ph; 4' HyperJet I I suRFACE. , 7,203.0 7 5, 1.5 5,8362 A-3. 27-08 10/14/1986 4. 0 IPERF 90 deg- P6; 4" HyperJet II 13.2979 Notes; General'& Sa fety E nd Date Annotation "S r - 3 12/1/2010 NOTE: VIEW SCHEMATIC w/Aiaska Schemal�c9..0 4.73 _ OAS UST. s692 IP r CAS UST, 0.040 OA/ LIST, SMp litti 8,707 la OAS VFi, ,- iiil 7.00S Pik 7,090 PACKEA,7,E91 (,,'„„1,'^„,'Iy;SO 1 nOPLE. 7.081 — ii .... I I: 901, 1.001 IPERF, 7,163.7,1.2 � 1 {r < wal�dt1 D iPERF, Top {D7apth Top Port 123d•7.2C9 (TVO) Intl OD Valve Latch SD* TRO Run stn Top IRKS) (1/KB) P1 Make Modet (In) Sere Typo Type (59) (Pe0 Run Date Cam„, 1 2,653.0 2,563.5 37,87 CAMCO KBMG 1 GAS LIFT GLV BK 0156 1,277.0 7/2511997 iPER7, 1 .. ' 2 4,733 4,042 44,E CAMCO K8MG 1 GAS LIFT 'GLV 8K 0.250 1,4150 7/251997 3 5,691.7 4,689.3 44.31 CAMCO KBMO 1 GASLUFT GLV BIC 0.250 1,405.0 7/25/1997 , Cacrt9G 4 6,040.4 4,9413 42.12 CAMCO KBMO 1 GAS LIFT WY 81t 0.000 00 7/17/1997 CEMENT PLUG, 700 5 6,389,5 5,201,0 41.5E CAMCO 1(8MG 1 GASLIFT GLV BK 0313 1,555.0 7/25/1997 6 6,706.7 5,439,4 41,03 CAMCO k85G 1 GAS LIFT DMY 8K 0000 0.0 7/16/1997 7 7,004.7 5,665.6 40.75 MMH 2.875x1.5 1 1/2 GAS LIFT OV RK 0,313 00 7/24/1997 0000UCT10N. 34.7.eaaN a, T0, 7,67$ - , ,..., , 1- ,•,,,,- ' , , _ /, ' i NOTE , 0 ; i NO SNOW IS TO BE PLACED IN c. . I , ; ANY RESERVE PIT OR LINED PIT. , r owo i: MS \ r PROD 2A ' K2 r PIT ,.....I [i i' RESERVE PIG TAW I - g 6 c4 , [ PIPELINES PIT — I 0 ma t I mn NMI ill • 4. „AI:CUPID PEIF I . i III 4, 1 i ' 4rAfr /d 'in --- 1 i 1 I [001 Ir • ... 1 1111111111 .. 1 ' il ___ 21 , _,,i 191' 1. 1 11 1. 9 6 7 ll 11 ' W g, CNI hi 4,4 4: ' 1 c... mar..., ,,....... ,, ....., ...., 23 26 26 39 32 it C ?, O. .■ 3 37 20 18 31131 71c4, 22 4 122 I :/- . T ti TO 052A 1 -75."— , 2525 1 25 .1 25 , —PS'^ -1. 28 1 -48 , - 1 25 1 i50* '. 5*- -3. ' A? A ' JR 1 I., VA03 j 1 SPACES 12 SPACES 6 rE 1 6 2 SPACES 045' L3 *�S il ID i .:A 0 12.5' 0 QS .12.5 015' 0 ELT I 2 [ / . i5.. . #4 3 a r a r IS Li sal , E 1 ,.....,,, , 1 , LEGEND FEATURE LOCATION 0 EXISTING PRODUCER I. CAUTION LEGEND 4 EXISTING mizeroR THIS DRILL SITE IS o CONvERTED FROm : - CLEAN SNOW DUMP AREA, ALL EQUIPMENT, )7 RESCUE EQUIPMENT PRODUCER TO INJECTOR CONSIDERED TO BE * SCBA LOCATIONS 2 AaArktoolgeo CONDUCTOR ' • - ENVIRONMENTAL AREA-NO SNOW DUMPING. AN H AREA ig ar i - POwF.RLINE-WATCH CLEARANCEII. KODIAK 1. i I DESIGNATED SAFE AREA (PRIMARY) X EXISTING CONDUCTOR aums E BLOWERS MAY HIT LINES WITH DISCHARGE. „ DESIGNATED SAFE AREA (SECONDARY) 0 PARTIAL TREE , - KODIAK BLOWERS MAY DISCHARGE OVER 'CD , EVACUATION ROUTES DEPENDING ON WIND • PIPELINE& ' !' XXOCK - NO SNOW DUMPING AREA. r - WINDSOCK MEM BARRICADE/ESCAPE ROUTE 0 I AREA: 2T MODULE: XXXX UNIT: D2 11 0 I A LOUNSBURY, INC ..V;,„„ FIRE EXTINGUISHER 1 f : -2: 7 7 7 . - - , 2 7 /v. I, APPROVAL: 7 t : -*C::, 5 5/01/02 Add Well 39, Rev Per 1(02013ACS MRT SCT DA1E: 11/26/99 CAD° FILE'LK6220111 i 7.,,,,. !I 4 5/30/01 Add Wells, Update Title (31k, Rev Per K01039ACS ROL MRT I DRAWING NO. SHEET: REV: n' ,— 14 REV. CuSI DATE REVISIONS .;. '.....1 • • • • ConocoPh Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 10, 2011 p F ! e 011 Commissioner Dan Seamount Gas cons. Cv Alaska Oil and Gas Conservation Commission Arrck7 &qo M s si0r1 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -08 (PTD 186 -109) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2T- 08 (PTD 186 -109). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, A A — a / f// Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA • AND GAS CONSERVATION COMMISSI _ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair s Plug Perforations S Oth ,� Suspended Well p g r Inspection Alter Casing f Pull Tubing r Perforate New Pool fl Waiver F Time Extension f Change Approved Rogram r° Operat. Shutdown f- Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r r 186 - 109 3. Address: 6. API Number: Stratigraphic r Service fi a� P. O. Box 100360, Anchorage, Alaska 99510 -- 50 103 - 20070 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025569 ..2T -08 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: ,s // Total Depth measured 7676 feet Plugs (measured) None true vertical 6186 feet Junk (measured) 7 None Effective Depth measured 0 feet Packer ( asured) 7067, 7067 true vertical 0 feet e vertucal) 5713, 5713 Casing Length Size MD / TVD Burst Collapse CONDUCTOR 193 16 11� `ice 115 SURFACE 5919 9 -5/8 2979 / 2800 PRODUCTION 15166 7 760 / V\ 6126 y 1 OECEivEr) (\ SEP MI. Perforation depth: Measured depth: 7188 -7192, 7 '4 -7206, 08- 7228 True Vertical Depth: 5805-580: : 7- :2 t; 5822 -5836 Ilial ©d & G a d fans. Co Anchorage sn Tubing (size, grade, MD, and TVD) 2.875, J -55, 4 92 MD, 5732 TVD Packers & SSSV (type, MD, and ND) PACK - BROWN HB -1 PACKER @ 7067 MD and 5713 TVD SSS , - CAMCO TRDP -IA -SSA (FLAPPER LOCKED OUT 6/16/2003) 11. Stimulation or cement squeeze sum ary: Nam G Intervals treated (measured): 10s °' 10 is p` Treatment descriptions including •lumes 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 14. Well Class after work: Copies of Logs and Surveys run Exploratory f Development p ` Service fl Stratigraphic fi 15. Well Status after work: Oil IX Gas i 7 WDSPL r Daily Report of Well Operations X GSTOR . . L� u r WIND r W AG r GINJ r SUSP SPLUG r• 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature ,/ Phone: 907 - 659 -7043 Date: 09 -10 -11 „ 97,z R = DMS SEP 14 20 Form 10 -404 Revised 10/2010 ,�`� 4 % /f Submit Original Only • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 'Nell Name: Kuparuk River Unit 2T -08 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 186 -109 Sundry 311 -023 API Number: 50103200700000 Operator: ConocoPhillips Date Suspended: 2/23/2011 Surface Location: Section: 252' FSL, 556' FWL, Sec i Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel Pad Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Rain water on pad Discoloration, Sheens on pad, pits or water: No sheen Samples taken: None Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good. Cycled SSV, SV, MV, IA valve, and OA valve Cellar description, condition, fluids: 6X6 wooden cellar box with gravel. Water in cellar. Rat Hole: No Wellhouse or protective barriers: Wellhouse good Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 350 psi. Not blinded Annulus pressures: IA = 20 psi, OA = 50 psi. AL line has spec blind with 450 psi AL Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: None Operator Rep (name and signature): Martin Walters AOGCC Inspector: Bob Noble Other Observers: Mouser /Bybee /Greenwood Inspection Date: 9/10/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway vehicle . KUP • 2T -08 �Ilips a I Attributes Max Angle & MD TD Wel!bore APUUWI Field Name Well Status Inoi r) MD (ftKB) Act Btm (ftKB) - ,, .�,.,.,'. 501032007000 KUPARUK RIVER UNIT PROD 48.25 3000.00 7,676.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date •.• Wei Congo: - 2T - 08. 1/28/2011 2:0351 PM SSSV: Flapper Locked Out 25 1/17/2010 Last WO: 40.10 7/22/1986 Schematic - ACNa1 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: TOC 7,080.0 1/26/2011 Rev Reason: CEMENT PLUG Imosbor 1/28/2011 - - -- - Casing Strings HANGER, 28 1 " I" Casing Description String 0.., String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 37.0 115.0 115.0 62.58 H Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.5 2,978.7 2,799.7 36.00 J BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 33.6 7,600.0 6,125.8 26.00 J -55 BUTT Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 27/8 I 2.441 I 28.3 I 7,092.1 I 5,731.7 I 6.50 I J -55 EUE8rdABMOD i Completion Details I I Top (TVD) (TVD) Top Intl Nomi... Top (rote) (ftKB) f) Item Description comment ID (in) CONDUCTOR, 28.3 28.3 0.35 HANGER CIW TUBING HANGER 2.875 37 - 115 1,829.8 1,824.9 11.87 SAFETY VLV Camco TRDP- 1A-SSA (FLAPPER LOCKED OUT 6/16/2003) 2.312 SAFETY VLV, 1 7,050.2 5,700.0 40.64 PBR BROWN PBR 2.347 1,830 I O 7,066.9 5,712.6 40.60 PACKER BROWN HB-1 PACKER 2.437 7,081.3 5,723.6 40.56 NIPPLE CAMCO DNIPPLE 2.250 I GAS LIFT, c 7,091.3 5,731.1 40.54 SOS BROWN SHEAR OUT 2.441 2.653 i_-_I Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date OK- Type Comment 7,188.0 7,192.0 5,804.8 5,807.8 A-4, 2T -08 10/14/1986 1.0 IPERF 90 deg. Ph; 4" HyperJet II 7,202.0 7,206.0 5,817.2 5,820.1 A -3, 2T -08 10/14/1986 1.0 IPERF 90 deg. Ph; 4" HyperJet II SURFACE, 7,208.0 7,228.0 5,821.5 5,836.2 A -3, 2T-08 10/14/1986 4.0 IPERF 90 deg. Ph; 4" HyperJet II 35 -2,979 Notes: General & Safety End Date Annotation GAS LIFT, r -. 12/1/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 4,734 GAS LIFT, 5,092 iii L4 GAS LIFT. 1 6,040 1 [F( GAS LIFT. i C- 6,389 GAS LIFT, 6,707 • GAS LIFT, 7,005 L PBR. 7,050 PACKER, 7.067 1 NIPPLE, 7.081 I' I El � SOS. 7,091 E IPERF, 7,188.7,192 Mandrel Details IPERF, = Top Depth Top Port 7.202 -7208 (TVD) Incl OD Valve Latch 5120 TRO Run Stn Top (ftKB) MB) P) Make Model (In) Sery Type Type (In) (psi) Run Date Com... 1 2,653.0 2,563.5 37.87 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,277.0 7/25/1997 7, 208 - 7. IPER2213 F, 2 4,733.5 4,004.2 44.98 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,415.0 7/25/1997 3 5,691.7 4,689.3 44.31 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,405.0 7/25/1997 CEMENT CEMENT 4 6,040.4 4,941.3 42.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/17/1997 PLUG, 7,080 5 6,389.5 5,201.0 41.85 CAMCO KBMG 1 GAS LIFT GLV BK 0.313 1,555.0 7/25/1997 6 6,706.7 5,439.4 41.03 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/16/1997 i 7 7,004.7 5,665.6 40.75 MMH 2.875x1.5 1 1/2 GAS LIFT OV RK 0.313 0.0 7/24/1997 PRODUCTION. 34-7,800N ' T0, 7,878 1 "��I\1r!LW!tram 11111 111 \1l1P- 21\111i!IR�r�t1Lei2 91111 1- 8.11 E01 1.!�� 1�f11f1L"'. " �1111.7r c-.���������������a��� �.� �������������111111."•' .11111L J' POWERLINES ; jam rXFRMR /fir .a., AISr NOTE t.:•:•:•:• :•:. :.:•:•:•:•:•1 I V1 NO SNOW IS TO BE PLACED IN 0, ANY RESERVE PIT OR LINED PIT. GUARD RA0.s 1 PROD _ 26 6m I RESERVE PIT «ATE L PIG Tim L i 1 N PIPELINES PIT 0— PROD 9 N um) 41 �� H �L 1 0 # 1'.A. / /// f / / / / / /II u, Illiall � I L � 4•01 5. til1°1 7 6 I 23 cos, 21 191 I 1 �G i' 26 28 30 32"A ® "' aO .I / .I 1 1 J 9 5 �a'3 2 N N N N N N N - �... a" ® Il Doan c , ,. ♦. p 7-437 ..... 37 20 18 36 38 ® M 22 27 29 31 V. i; ;' N 1 TO DS2A X75' - 1 25 1 2525 1 25'T- 75'�2E3'�- 4 ®�25" 150' "5' 33. 90'� 62.5 - 37.5 %t to a h 15' S SPACES I 2 SPACES 2 SPACES 6 0 2 S S 6 3 SPACES . 3 SPACES • i2 s) 012.5) L 012.5 '— 12.5 ®15' Al2.5 C] l SD,ss / //// / / D ill FEATURE LOCATION LEGEND CAUTION 0 EXISTING PRODUCER LEGEND . EXISTING INJECTOR THIS DRILL SITE IS CONVERTED FROM / / /,L — CLEAN SNOW DUMP AREA, ALL EQUIPMENT. RESCUE EQUIPMENT BE • CONSIDERED TO BE PRODUCER TO INJECTOR * ��10 �# — ENVIRONMENTAL AREA —NO SNOW DUMPING. SCBA LOCATIONS AN H AREA 7, ABANDONED CONDUCTOR POWERLINE —WATCH CLEARANCE!!, XODIAK 19 I DESIGNATED SAFE AREA (PRIMARY) I' EXISTING CONDUCTOR *will BLOWERS MAY HIT LINES WITH DISCHARGE. I 2 I DESIGNATED SAFE AREA (SECONDARY) rP PARTIAL TREE 'YX` — KODIAK BLOWERS MAY DISCHARGE OVER °t]. EVACUATION ROUTES DEPENDING ON WIND PIPELINES. 1 r WINDSOCK {:....I - NO SNOW DUMPING AREA. ® BARRICADE /ESCAPE ROUTE E AREA: 2T MODULE:XXXX UNIT: D2 l; A LOUNSBURY, INC :Ay FIRE EXTINGUISHER �' APPROVAL: DS2T FACILITY EXPANSION • 5 . 5/01/02 Add Well 39, Rev Per K02013ACS MRT ® D ATE: 11 /26/99 CADD FILE: LK622011 FEATURE LOCATION i1 4 = 5 30 01 Add Wells (iodate Title Blk Rev Per K01039ACS ROL MRT DRAWING NO. SHEET: REV: i DATE REVISIONS BY N R pN° CEA -D2TX -3323 001 • 2T -08 (PTD# 186 -109) © ConocoPhillips Alaska, Inc. 0 T his photo is copyrighted ed or by ConocoPhillips and cannot be Alaskareleas, Inc. ��y } published without express ,- written consent of .► $" h z 7 ' ConocoPhillips Alaska 1 " b ar 3 `f z qk r , f, , k Y V Aii' 1 , 4 o RP: , 6 $ .... . - - '1.4itigp' , r AP I . 1 . ,,..„ i i , 4t 1 " - r Y 'I. it Se Va { ,. � ,:," 'kPRamsR ,men li p , e c , ' Ark " � z � , s 141/, 4411‘,41:414rnir/111414r # ,` j - \ 5 1 ,,,,,' ,, ,. ,,, 1 . , ;44,,,i4ii. ' '0 lit it 91 L, I ilii:‘‘. ' - ,,,,, .4,, ,,,,,. i, .... ,... - i INN \ i ..,\ ,...., %, rri 1 ,, 7 . OF ., 4 i 4 4 , Wit Li 4„. ,„ au , . ..„,,, t .. . 4 _ '' i , triria. f 1 : ri 1 , _.........7 likvoitvi, ,, , i , ffifillar ' I ,,,,..c. ...-.?,-* ' 1 11 SIIIII i ''''' ' ' 4'. II/II '"v1 I = a - 1 1 al 1 r ., • 't = - 186 ®109) © 2 T ConocoPhillips Alaska, Inc. T his photo is copyrighted by ConocoPhillips Alaska, Inc. :..... ..,.... ,... -.1 , If; ',.' * _ ., ,,_ .„,..4,,; Y= - - x ' published and cannot without be express released or " ` � written consent of 1 . ConocoPhillips Alaska '4-"t-r-1- 0 R _ r '�;, t - "� ': -r.-w to . qqq. r'a't � �� � z v . #� � � � � 4,, „ „...,. 4 , .,., _ . ..,.....t.k -a 4°, x, v .. :r , #rt' 'R � q��� `. } .".; .::`pro. -r. �.-r i I N V " • i _.._. _, �. t . i � M � 1 } i . 1 , ,, % ° " 4 .1; , ' 1 , *..` Ili i ‘ l vs i a * 0 if . " - . 1 I , vt t . t „"'"' t o 4 r e,i F . kf, . , ., ..., , , 2 ,.., , .‘ 2, , . , it t ., ; . r s. , , ,,,,,,,,,,,,, , 1 rr, II. . .1,41k0. 44 � .7b 1 i I ' I ; I i 1 I I 1,Aait'i, l'I' ' # 1 1 't ' t *14' - 1.°".' 4 i 4 1 1 ' V 7 • • Iv ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 March 1st, 2011 RECEIVE: Commissioner Dan Seamount *Aka o i & Gas Cony, Commission Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 AK 99501 Commissioner Dan Seamount: Enclosed please find a 10 -404 sundry report of operations to plug the perforations of 2T -08 PTD (186 -109). Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, 4 mi* u L o 1. Perry Kl- n ConocoP 111ips Well Integrity Projects Supervisor STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS.' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations p Stimulate r Other r Alter Casing r PuII Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rr Exploratory r * 186 -109 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 .. 50 - 103 - 20070 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 - 2T - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7650 feet Plugs (measured) None true vertical 6150 feet Junk (measured) None Effective Depth measured 7559 feet Packer (measured) 7067 true vertical 6069 feet (true vertucal) 5713 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 0 0 SURFACE (QC) 2943 12 2979 2798 0 0 PRODUCTION 7566 7 7600 6126 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7188 - 7192, 7202 - 7206, 7208 - 7228 True Vertical Depth: 5804 -5807, 5817 -5820, 5822 -5836 E E I � -,, Tubing (size, grade, MD, and TVD) 2.875, J -55, 7091 MD, 5731 ND BAR � i ,, M Packers & SSSV (type, MD, and ND) PACKER - BROWN 'HB -1' PACKER @ 7067 MD and 5713 Woke Oil & Gas Cons. Commission TRDP - CAMCO TRDP -IA -SSA (FLAPPER LOCKED OUT 6/16/2003) @1'84014,114,fyid 1825 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: See summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 155 422 140 220 Subsequent to operation 0 0 80 140 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 15. Well Status after work: Oil r . Gas r WDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 311 -023 contact J Lovela d/ • =,,, Klein Printed ame Per KI -' Title Well Integrity Supervisor Signature - - /� Phone: 659 -7043 Date 3 \ \ \*L6 ' 1 R Mk Oaa 1 s•3- Form 10-404 Revised 10/2010 / � / Submit Original Only • 2T-08 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/26/11 SQUEEZE 10 BBL OF 15.8 PPG "G" CEMENT. DISPLACE TOC - 7080', FREEZE PROTECT WITH 12 BBL OF DIESEL. INITIAL T /I /0 = 650/700/10 FINAL T /I /O = 0/650/10 02/20/11 Initial T /I /0= si 750/640/60. Bleed IA down for C -MIT. Bled OA for approx. 8 hours. Final T /I /O= si 750/50/60. 02/21/11 1 Load Tubing and IA with diesel 02/23/11 CMIT- passed; Initial T /I /0= 690si/690/40; IA FL @ SF; T FL @ SF; Stung into IC PO with 0 +psi. Pressured up IA/T with 2bbls. of diesel T /I /0= 1960/2000/40; IC PO test void 0 +psi. 15min. reading T /I /0= 1880/1920/40; IC PO test void 0 +psi. 30min. reading T /I /O= 1860/1890/40; IC PO test void 0 +psi. 45min. reading T /I /0= 1830/1860/40; IC PO test void 0 +psi. Re- pressured IA/T with .25bbls. of diesel T /I /0= 1970/2000/40; IC PO 0 +psi. 15min. reading T /I /0= 1960/1980/40; IC PO test void 0 +psi. 30min. reading T /I /O= 1940/1970/40; IC PO test void 0 +psi. 45min. reading T /I /O= 1930/1960/40; IC PO test void 0 +psi. Re- pressured IA/T with .10bbls. of diesel T /I /O= 1980/2000/40; IC PO 0 +psi. 15min. reading T /I /0 1980/2000/40; IC PO test void 0 +psi.30min. reading T /I /O= 1980/2000/40; IC PO test void 0 +psi.Bled T /IA. final T /I /0= 140/80/40 • . C S Ls- FAIT [IF [\\\ [LAEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Perry Klein �b� Well Integrity Supervisor ( " _ ConocoPhillips Alaska, Inc. W P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -08 Sundry Number: 311 -023 Dear Mr. Klein: )) FEB t 4 J 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 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, Daniel T. Seamount, Jr. Chair 3 DATED this day of February, 2011. Encl. STATE OF ALASKA 9 (�, C �'""` I � ALASKA. AND GAS CONSERVATION COMMISSIOW " 1 ( APPLICATION FOR SUNDRY APPROVALS 9' A 2 8 '?111' 20 AAC 25.280 A i'c' , Pr p i..3 a Cars_ C : fission 1. Type of Request Abandon ❑ Flug for RedriQ ❑ Perforate New Pool ❑ Repair w ell f Change Approved ram Pro ❑ Suspend e p ❑ Plug Perforations � - Perforate ❑ Pull Tubing ❑ `f lrria )' tron ❑ Operational Shutdow n ❑ Re -enter Susp. Well r Stimulate r Alter casing 9 ❑ Other: Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 186 -109 3. Address: Stratigraphic ❑ Service Q 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20070 - 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 Q No 0 2T -08 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY . Total depth MD (ft): , Total Depth TVD (ft):, Effective Depth MD (tt): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ,. , 5G 0,4-7- � >� 27) 1 7559' 6069' Casing r . J' I f Length / I Size MD TVD Burst Collapse CONDUCTOR 78 16 115' 115' SURFACE (QC) 2943 12 2979' 2798' PRODUCTION 7566 7 7600' 6126' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7188 -7192, 7202 -7206, 7208 -7228 5804 -5807, 5817 -5820, 5822 -5836 2.875 J -55 7091 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER- BROWN'HB -1' PACKER MD= 7067 TVD= 5713 TRDP - CAMCO TRDP -IA -SSA (FLAPPER LOCKED OUT 6/16/200Z MD= 1830 TVD= 1825 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/25/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: /.pi. // WINJ r GINJ r WAG r Abandoned r Commission Representative: S eh w. 1F2..— GSTOR ❑ SPLUG r 17. I hereby certify that t e an c ct to the b st of my knowledge. Contact: MJ Loveland /Perry Klein Printed Na Perry Klein Title: Well Integrity Supervisor Signature Phone: 659 -7043 Date 1-22 -11 Commission Use Only Sundry Number:31 I_0;3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity y�, BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / 0- 10'1 APPROVED BY ®J/ Approved r by: ` � / COMMISSIONER THE COMMISSION "`. Date: r I Form 10 -403 Revised 1/2010 Z.Z. /r n FEB 04 201 C S ubmit in Duplicate • • • ConocoPh i l l s ps RCCENZD Alaska P.O. BOX 100360 !� ANCHORAGE, ALASKA 99510 -0360 yy �tg' r� (��y (� w� �` I •.. sta R : 4 Co ise BA9C�tn, �ISS'Ot► Jan 25th, 2011 1 H � Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a 10 -403 sundry request to plug the perforations of 2T -08 PTD (186 -109). Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, L._ Perry Klein ConocoPhillips Well Integrity Projects Supervisor ak • KUP 2T -08 ConocoPhillips O Well Attributes ax Angle & MD TO Inc. (R Wellbore API /UWI Field Name Well Status Incl ( ") MD (ftKB) Act Btm KB) x ,,1,,,,, 1n 501032007000 KUPARUK RIVER UNIT PROD 48.25 3,000.00 7,676.0 Comment H25 (ppm) Date Annotation End Date K8.03rd (R) Rig Release Date NIA curdle: - 27 OS, 10/342010 1,40 06 PM — SSSV: Flapper Locked Out 25 1/17/2010 Last WO: 40.10 7/22/1986 Schemata - Actual Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: 7,299.0 7/24/1997 Rev Reason: FORMAT UPDATE Imosbor 10/3/2010 Casing Strings String OD String ID Set Depth Set Depth ITVD) String Wt String is 4 Casing Description Tint lint Top (W(8) (RKB) (RKB) (Ibettt) Grade String Top Thrd CONDUCTOR, CONDUCTOR 16 15.062 0.0 115.0 115.0 62.58 H-40 115 SURFAC 95/8 8.765 0.0 2,976.0 2,797.9 36.00 J -55 PRODUCTION 7 6.151 0.0 7,600.0 6,125.8 26.00 J -55 SAFETY VLV, Tubing Strings 1,830 - 0 String OD String 10 Set Depth Set Depth (TVD) String Wt String _ Tubing Description lin) (in) Top (MB) (808) (808) (Ibs/1t) Grade String Top Thrd TUBING 2 7/8 2.441 0.0 7,091.0 5,730.9 6.50 J -55 EUE8rdABMOD Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth GAS LIFT, (TVD) Top Inc! 2,653 Top (MB) (RKB) ( °) Description Comment Run Date ID (in) 1,830.0 1,825.1 11.88 SAFETY VLV Camco TRDP-1A-SSA (FLAPPER LOCKED OUT 10/14/1986 2.312 6/16/2003) SURFACE, - 2,653.0 2,563.5 37.87 GAS LIFT CAMCO/KBMG/1 /GLV /BK/-156/1277/ Comment: STA 1 7/25/1997 2.371 2,976 4,734.0 4,004.5 44.98 GAS LIFT CAMCO/KBMG/1 /GLV/BK/25/1415/ Comment: STA 2 7/25/1997 2.371 �� 5,692.0 4,689.5 44.31 GAS LIFT CAMCO/KBMG/1 /GLV /BK/25/1405/ Comment: STA 3 7/25/1997 2.371 GAS LIFT, F4 L .d 9 6,040.0 4,941.1 42.12 GAS LIFT CAMCO/KBMG/1 /DMY /BK/ // Comment: STA4 7/17/1997 2.371 4,734 �i 6,389.0 5,200.6 41.85 GAS LIFT CAMCO/KBMG/1/GLV /BK/.313/1555I Comment: STA 5 7/25/1997 2.371 6,707.0 5,439.7 41.03 GAS LIFT CAMCO /KBMG/1 /DMY /BW / / Comment: STA 6 7/16/1997 2.371 �� ----�� 7,005.0 5,665.8 40.75 GAS LIFT MMH/2 7/8 X 1.5/1.5/OV/RK/.313// Comment STA 7 7/24/1997 2.347 Gas LIFT, 7,050.0 5,699.8 40.64 PBR Brown PBR 10/14/1986 2.500 5,592 7,067.0 5,712.7 40.60 PACKER Brown'HB-1' PACKER 10/14/1986 2.441 a 7,081.0 5,723.3 40.57 NIPPLE Camco'D' Nipple NO GO 10/14/1986 2.250 7,091.0 5,730.9 40.54 SOS Bro wn SHEAROLfT SUB 10/14/1986 2.441 GAS LIFT, 7,092.0 5,731.7 40.54 TTL 10/14/1986 2.441 6040 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top MKS) Bbn (RKB) (RKB) (8813) Zone Data (eh° Typa Comment GAS LIFT, j 7,188.0 7,192.0 5,804.8 5,807.8 A-4, 2T -08 1 0/14/1 986 1.0 IPERF 90 deg. Ph; 4" HyperJet II 7,202.0 7,206.0 5,8172 5,820.1 AA-34C: -08 10/14/1986 1.0 IPERF 90 deg. Ph; 4' HyperJet II 7,208.0 7,228.0 5,821.5 5,836.2 A-3 2T -0 10/14/1986 4.0 IPERF 90 deg. Ph; 4" HyperJet II GAS LIFT, 6,707 GAS LIFT, 7.005 PBR. 7,050 PACKER, ],06] — - 1 1 NIPPLE 7081 SOS. 7,091 .- T TTL, 7092 IPERF, 7,188 -7.192 IPERF, ----_- 7, 202 -7, IPERF, III II 7208-7.228 PRODUCTION, 7. 600 TD, 7,676 • • Well 2T -08 Proposed Well Suspension 2T -08 is being evaluated for slot recovery. Currently it has subsidence related buckling and the last drift was unable to get past —250'. The well needs to be secured by pumping cement across the formation to isolate the productive zones due to the inability to test multiple barriers. Proposed Well Suspension Procedure: Procedure Cementing Unit 1. MIRU SLB cementer. Mix 10 bbls of 15.8 ppg Class G cement slurry. 2. Pump 10 bbls of 15.8 Class G cement slurry, followed by a nerf ball and displaced w/ 2 bbls of Biozan, 27 bbls freshwater & 12 bbls diesel freeze protect. During pumping hold and monitor pressure on the IA to ensure that the cement is not being pumped into the IA instead of to the perforations. Estimated TOC - 7067' RKB Note: Do not exceed a fracture gradient of .65 psi /ft during the cement job. Slickline 3. Contact AOGCC for State witnessed Pressure test & cement plug tag. - Note: Due to buckling in the tubing, a drift & tag is highly unlikely to tag the TOC. 4. After minimum of 24 hours pressure test cement plug to 2000 psi then bleed tubing to 0 psi. Record pressures. Drift & tag to TOC @ approx. 7067' RKB. Page 1 of jI( j • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 02, 2011 1:41 PM To: 'NSK Well Integrity Proj' Cc: Glessner, Dana; Herrmann, Daniel D Subject: RE: Update 2T-08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, Thanks for the update... as you mentioned until you have the well loaded up on both IA and tubing side will be hard to tell if you were successful. If I understand correctly you have not tried CMIT's on the two wells ? ? ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Wednesday, February 02, 2011 12:21 PM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; Glessner, Dana; Herrmann, Daniel D Subject: Update 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, We pumped both plugs with operational success however are not able to get passing MITTS at this time. 2T -03 has a fairly large leak that might allow us to reattempt the plug. 2T -08 is leaking on the order of 1 gallon per minute at 1000 psi and might prove difficult to retreat. We are in the process of evaluating our options developing our plan forward. I suspect we will attempt to load the backside of the well to better understand our current leak path /s and rates before deciding on a clear path forward. Let myself or MJ know if you have any questions Perry Klein Well Integrity Projects, 907 -659 -7043 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 2:33 PM To: NSK Well Integrity Proj Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, We have discussed the wells internally and agree that they should stay as "plug perfs" for the time being. Based on how the rig workover goes they well status may change to suspended or P &A . Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 2/2/2011 Page 2 of 4 • 444 -3433 (cell) From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Monday, January 24, 2011 1:50 PM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, I've discussed the plan forward for both wells once a cement plug has been placed across the perforations to isolable the reservoir. At this time we plan to attempt a work over similar to past subsidence wells where the tubing is pulled and replaced. The production casing will be pulled and replaced to some point below the suspected damage. Communication will then be reestablished to the reservoir via the original mother bore through some combination but not limited to milling, under reaming , perforating, and fracturing. At this point it looks as if plug perfs is the appropriate check box on the 10 -403 sundry request. On your response I will mail the hard copies to your office. Sincerely, Perry Klein Well Integrity Projects 907 - 659 -7043 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 9:45 AM 1/ b4-Q To: NSK Well Integrity Proj ►� Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, I talked to Commissioner Foerster this morning regarding 2T -03 and 2T -08. You have verbal approval to plug perforations as outlined in the sundry applications. • As we discussed if your intentions are to workover the wells and not sidetrack/P &A we can stay with the "plug perforations" request vs "suspended" . It will still require a witnessed PT and possible tag of TOC. Can you send brief email response on the proposed workover options... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, January 23, 2011 9:43 AM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 10 -403 sundry request to plug open perfs with cement Guy, 2/2/2011 Page 3 of 4 • Thanks for your help. Yes they are very similar in regards to the condition and suspected damage mode. I'm assuming these wells will be worked over and brought back on line, not suspended as was done with the injectors. Thanks for the quick action. I'll touch base with you Monday. Perry From: Schwartz, Guy l (DOA) (mailto:guy.schwartz @alaska.gov] Sent: Sunday, January 23, 2011 9:29 AM To: NSK Well Integrity Proj Subject: Re: 2T -08 10 -403 sundry request to plug open perfs with cement Perry, I reviewed the procedures. They are similar to the other 2T wells we have suspended. We should be able to fast track these two sundries based on the risk potential. I will discuss with Commissioners first thing Monday morning. Regards, Guy Sent from my iPhone On Jan 22, 2011, at 8:33 PM, "NSK Well Integrity Proj" <N1878@conocophillips.com> wrote: Guy, Please find enclosed an outlined procedure and 10-403 request to plug the perforations of gas lifted producer, 2T -08, PTD 186 -109. The hard copies will be mailed promptly. As discussed earlier via phone on 1 -21 -11 the well has a shallow surface casing leak at approximately 330' and buckled tubing that will not drift for a plug past 250' feet. Recently the well has show signs of tubing by inner annulus communication prompting the need for it to be secured. We would like to pump cement Tuesday morning 1- 25 -11. In the past your office has requested us to attempt to tag the cement top post treatment. While I have left that step in our procedure I would ask that the tag not be a requirement in this well. The state of the buckled tubing is such that we risk a stuck or lost tool string when attempting to drift the well which may further complicate future well work. Thank you for your consideration. Please call or e-mail if you have any questions. A well bore schematic has been attached for your convenience. Sincerely, Perry Klein Well Integrity Projects 907 -659 -7043 2/2/2011 • Page 1 of 3 • Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, January 24, 2011 1:50 PM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Guy, I've discussed the plan forward for both wells once a cement plug has been placed across the perforations to isolable the reservoir. At this time we plan to attempt a work over similar to past subsidence wells where the tubing is pulled and replaced. The production casing will be pulled and replaced to some point below the suspected damage. Communication will then be reestablished to the reservoir via the original mother bore through some combination but not limited to milling, under reaming , perforating, and fracturing. At this point it looks as if plug perfs is the appropriate check box on the 10-403 sundry request. —=P 4.iir - On your response I will mail the hard copies to your office. 1. Z'(. c� Sincerely, Perry Klein Well Integrity Projects AddilieD FEB ( WI 907 - 659 -7043 From: Schwartz, Guy L (DOA) [mailto :guy.schwartz @alaska.gov] Sent: Monday, January 24, 2011 9:45 AM To: NSK Well Integrity Proj Subject: RE: 2T -08 (PTD 186 -109) 2T -03 (PTD 186 -142) Perry, I talked to Commissioner Foerster this morning regarding 2T -03 and 2T -08. You have verbal approval to plug perforations as outlined in the sundry applications. As we discussed if your intentions are to workover the wells and not sidetrack/P &A we can stay with the "plug perforations" request vs "suspended" . It will still require a witnessed PT and possible tag of TOC. Can you send brief email response on the proposed workover options... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, January 23, 2011 9:43 AM To: Schwartz, Guy L (DOA) Subject: RE: 2T -08 10 -403 sundry request to plug open perfs with cement 1/24/2011 • 1110 Page 2 of 3 Guy, Thanks for your help. Yes they are very similar in regards to the condition and suspected damage mode. I'm assuming these wells will be worked over and brought back on line, not suspended as was done with the injectors. Thanks for the quick action. I'll touch base with you Monday. Perry From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Sunday, January 23, 2011 9:29 AM To: NSK Well Integrity Proj Subject: Re: 2T -08 10 -403 sundry request to plug open perfs with cement Perry, I reviewed the procedures. They are similar to the other 2T wells we have suspended. We should be able to fast track these two sundries based on the risk potential. I will discuss with Commissioners first thing Monday morning. Regards, Guy Sent from my iPhone On Jan 22, 2011, at 8:33 PM, "NSK Well Integrity Proj" <N1878@conocophillips.com> wrote: Guy, Please find enclosed an outlined procedure and 10 -403 request to plug the perforations of gas lifted producer, 2T -08, PTD 186 -109. The hard copies will be mailed promptly. As discussed earlier via phone on 1 -21 -11 the well has a shallow surface casing leak at approximately 330' and buckled tubing that will not drift for a plug past 250' feet. Recently the well has show signs of tubing by inner annulus communication prompting the need for it to be secured. We would like to pump cement Tuesday morning 1- 25 -11. In the past your office has requested us to attempt to tag the cement top post treatment. While I have left that step in our procedure I would ask that the tag not be a requirement in this well. The state of the buckled tubing is such that we risk a stuck or lost tool string when attempting to drift the well which may further complicate future well work. Thank you for your consideration. Please call or e-mail if you have any questions. A well bore schematic has been attached for your convenience. Sincerely, Perry Klein 1/24/2011 Page 3 of 3 Well Integrity Projects 907 -659 -7043 <2T-08 - 2T 08 10 403 sundry request 1 -22 -1 l.pd� <2T -08.pd <2T -08 Sundry Procedure.doc> 1/24/2011 MICROFILMED 9/11/00 DO NOT PLACE STATE OF ALASKA ALA&~A OIL AND GAS CONSERVATION COMMIS~IO,4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 252' FSL, 556' FWL, SEC 1, T11N, R8E, UM At top of productive interval 1302' FSL, 1347' FEL, SEC 1, T11N, At effective depth 1414' FSL, 1122' FEL, SEC 1, T11N, At total depth 1452' FSL, 1047' FEL, SEC 1, TllN, R8E, UM R8E, UM R8E, UM Present well condition summary Total Depth: measured 7 6 5 0 feet true vertical 61 6 5 feet 12. Effective depth: measured 75 1 3 feet true vertical 6057 feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 943' 9 5/8" Intermediate Production 7 5 6 6' 7" Liner Perforation depth: 6. Datum elevation (DF or KB) RKB 117 7. unit or Property name Kuparuk River Unit 8. Well number 2T-08 feet 9.~Permit n u m,b~r,~o p roval ~ use r?~~_ 10. APl number 50-103-20070-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 234 Sx CS II 115' 685 Sx AS III & 2977' 315 Sx Class G w/100 Sx AS I top job 300 Sx Class G & 7600' 175 Sx AS I measured 7188'-7192', 7202'-7206', true vertical 5804'-5807', 5815'-5818', Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 7092' Packers and SSSV (type and measured depth) 7208'-7228' 5819'-5835' Packer: Brown HB-1 @ 7067'; SSSV: Camco TRDP-1A-SSA @ 1830' 115' 2798' 6125' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 7/18/97. Intervals treated (measured) 71 88'-71 92', 7202'-7206', 7208'-7228' Treatment description including volumes used and final pressure Pumped 202.4 MIbs of 20/40 and 12/18 ceramic proppant into formation, final pressure = 7400 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf WateroBbl Casing Pressure 3 5 8 155 334 1315 419 225 672 1317 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Wells Superintendent Signed Form/10-404 Rev ~8 Tubing Pressure 297 309 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1 (2T-08(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-08 FRAC, FRAC SUPPORT 071 3971 730.2 DATE DAILY WORK UNIT NUMBER 07/1 8/9.7 "A" SAND REFRAC DAY ' OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 ~ Yes O NoI ® Yes O No DS-GALLEGOS CHANEY FIELD AFC# CO# DALLY COST ACCUM COST Signed ESTIMATE KD1390 230DS28TL $124,745 $129,765 ~ '~.,' / Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1050 PSI 2100 PSI 750 PSI 500 PSII 600 PSII ,/550 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 202404 LBS OF PROP IN THE FORMATION W/11.8# PPA OF #12/18 @ THE PERF'S. FREEZE PROTECTED TBG DOWN TO 3400' W/20 BBLS OF DIESEL. MAXIMUM PRESSURE 7400 PSI & F.G. @ (.95) TIME 07:00 09:30 10:30 10:45 11:45 12:45 14:45 15:30 16:30 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC PUMP TRUCK, AND APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). STOOD-BY FOR REPAIR OF DOWELL PUMPS. PT'D BACKSIDE LINES AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 100¢-¢~'., ,;.¢ PSi, PUMP BREAKDOWN W/50# DELAYED XL GW @ 20 TO 15 BPM. VOLUME PUMPED 215 BBLS. uSED 2195 LBS OF #20/40 PROP. MAXIMUM PRESSURE 7300 PSI AND ENDING PRESSURE 5100 PSI. S/D AND OBTAINED ISIP OF 2875 PSI W/F.G. @ (.94). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE DETERMENATION. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 157 BBLS. MAXIMUM PRESSURE 5800 PSI AND ENDING PRESSURE 4900 PSI. S/D AND OBTAINED ISlP OF 2920 PSI W/F.G. @ (.95). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND MONITORED WHTP FOR 15 MINS. VOLUME PUMPED 1364 BBLS. MAXIMUM PRESSURE 6400 PSI AND ENDING PRESSURE 3100 PSI. PUMPED 202838 LBS OF PROP (20912 LBS OF #20/40 & 181926 LBS OF #12/18). INJECTED 202404 LBS OF PROP IN THE FORMATION W/11.8# PPA OF #12/18 @ THE PERF'S. LEFT 434 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED TBG DOWN TO 3400' W/20 BBLS OF DIESEL. STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D THE APC PUMP TRK. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $0.00 $270.00 ,. APC $6,500.00 $6,500.00 DIESEL $200.00 $200.00 DRILLEX $118,046.00 $118,046.00 HALLIBURTON $0.00 $2,750.00 LITTLE RED $0.00 $2,000.00 ~TOTAL FIELD ESTIMATE $1 24,746.00 $1 29,766.00 STATE OF ALASKA /~. /// ALASKA ~jiL AND GAS CONSERVATION CO,,~MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20070 4. Location of well at surface 9. Unit or Lease Name 252' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1302' FSL, 1347' FEL, Sec. 1, TI1N, R8E, UM 2T-8 At Total Depth 11. Field and Pool 1452' FSL, 1047' FEL, Sec. 1, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 117'I ADL 25569 ALK 2667 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 07/15/86 07/20/86 12/15/86'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19.1~r_e_ctionalSurvey 20. Depth where SSSV set ~ 21. Thickness of Permafrost 7650'MD 6165'TVD 7513'MD 6057'TVD YE~ NO~ 1830' feet MD~ 1550' (Approx) 22. Type Electric or Other Logs Run DIL/SP/SFL/GR, FDC/CNL, CAL, GR/CCL/CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5¢ H-40 Surf 115' 24" 234 sx CS II 9-5/8" 36.0¢ J-55 Surf 2977' 12-1/4" 685 sx AS Ill & 315 sx C ass G Performed top job w/100 ~x AS I 7" 26.0¢ J-55 Surf 7600' 8-1/2" 300 sx Class G & 175 sx ~S I . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7092' 7067' 71 88 ' -7192 'MD 5804 '-5807 'TVD w/1 spf, 90~ phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7202'-7206'MD 5815'-5818'TVD w/1 spf, 90~ phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7208'-7228'MD 5819'-5835'TVD w/4 spf, 90~ phasing See attached Addendum, dated 1/1~/87~ for fracture data. 2~/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing 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. *Note: Drilled RR 7/22/86. Well oerforatefl & tuh~nq run 10/14/R~ Form 10-407 Rev. 7-1-80 WC1:180:DANI CONTINUED ON REVERSE SIDE Submit in duplicate 29. K~S 30. O GEOLOGIC MAR FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7116' 5749' N/A Base Kuparuk C -- 7122' 5754' Top Kuparuk A 7169' 5790' Base Kuparuk A 7323' 5908' 31. LIST OF ATTACHMENTS Addendums (dated 11/15/86 & 1/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer /~/_~ ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClassifiCation of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. · ~ Item ~27: MethOd of Operation: Flowing, Gas Lift, ROd Pump, Hydraulic Pump, Submersible, Water In- . jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". . . Form 10-407 ADDENDUM WELL: 9/16/86 9/17/86 10/10/86 2T-8 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. TIH w/CT to 500' &circ diesel to thaw 9-5/8" x 7" ann. Inj 70 bbls diesel & brine into ann, RD. Rn GR/CCL/CBL f/7427' WLM - 5100' WLM. Rn gyro f/7427' - surf. Drilli~ Supervis6~ ADDENDUM WELL: 9/16/86 ~o/~o/86 12/15/86 2T-8 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak; tst OK. Rn GR/CCL/CBL f/7427' WLM- 5100' WLM. Rn gyro f/7427' - surf. Frac'd Kuparuk "A" sand perfs 7188'-7192', 7202'-7206' (1 SPF) & 7208'-7208' (4 SPF) in 8 stages per 12/3/86 procedure using gelled diesel, 100 mesh & 20/40 sand. Press'd ann to 2000 psi w/diesel. Tst ins to 8000 psi; OK. Pmp'd 30 bbls 5% Musol, followed by 43 bbls cln diesel @ 2 BPM & 2400 psi. Stage 1: Pmp'd 90 bbls gelled diesel pad @ 21BPM & 5300-5000 psi Stage 2: Pmp'd 20 bbls gelled diesel pad @ 21BPM, 4900 psi Stage 3: 19 bbls gelled diesel w/1 ppg 100 mesh @ 21 BPM,~4950 psi Stage 4: 163 bbls gelled diesel spacer @ 21BPM, 5000 psi Stage 5: 40 bbls gelled diesel w/3 ppg 20/40 mesh sand @ 21BPM, 4790 psi Stage 6: 36 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 20 BPM, 4900 psi Stage 7: 18 bbls gelled diesel w/ 8 ppg 20/40 mesh sand @ 20 BPM, 5100 psi Stage 8: 43 bbls gelled diesel flush, 19.5 BPM, 5400-5600 psi Total sand in formation: 800# 100 mesh & ±19,800# 20/40 mesh. Approx 350# 20/40 mesh left in csg. Load to recover 429 bbls of gelled diesel 30 bbls 5% Musol & 43 bbls cln diesel. Job complete @ 2040 hrs, 12/15/86. Drilling Supervisor October 22, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60069 Well: 2T-8 Field: Kuparuk, Alaska Operator: E. Sellers Survey Date: October 10, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ,~:. 1 -- K LI PA R U K . :: AL.A?J<A VE:i:?'I" I CAI_ Ei;li:~C:T I ON ('-:AL.(;::LIL~TED'"'""L~L. ONG CI. jFr.3LIRE MEASURE I3EF:'TH Ei; F' E R R V...- S LIN W E L.. I .... :i'-'; I...I R V E- Y I N G C O M F' A N Y i:~ Iq C H f_')IR A 13 [:- A L A S I< A t..UMF L. TAT I ON DATE OCTOBER 14~ 1 "y,:,"'6 F:'A G E -1 .......................... DATE OF oL.IRVEY UCTUDER 10., :1~o6 Bu ....... 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'~ 9 C) 12C). 64 N :374.40 E 3 ?:3..:,._, E :.:::~..,~i...~, '-'"' E 3"6,:_--: 136.4._=,, N 43:3.46 E 4=._,4.41 :::c) E :':: 4:3 1 .=~2' '7/-, N 4 9 7.2 7 E ='-' _' 1 ":' .... . ...... ._,~( )., ._. :7:: 0 E 4.20 .1./- ':' :::(") Iq ..,/: ..... 8'? E .r.] 9 (") 64 ARCO AL_ASKA~ 2T-.8 KUF'ARUK AL. AFi;I<A SPE:'RRY-SI.IN WE"I._I ..... ::,LH, VE¥ ING F:F/MF'ANY INC. CUMF U] AT I ON DATE ~ ........ " 9L::6 JL.]UBER I4~ 1 TRI I ': _ _ · .. E. ~UB:~EA F:I]LIFitSE MEAoI_IREL VERT I CAL VERT Ii~AL I NCL I NAT I ON DEF:'T H DEPTH DE F'TH DEG I'11 N ............... F'AGE <.2 COLIR.:,E DC;G-LEG D I RECT I ON .:,EVER I TV DEGI::~Ei:ES DE-"F.~ / 1 O0 N(;!,!RTH / SOIJ]TF! ...... ,E.:"..O:~iT/..W..,E,,'.E,i.,T,. ............................... SECT ! 01',1 :31 O0 ::-:200 :}):E:O0' :3 400 · -'~ I::." - .- :, ..,' (.) L) .................................................................................................................................................... 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'75 E O. 24 5]_. 9 ~ .81 N '27:43.4 ':~.. 15-: ....'-' ._-,'-' 17 ./-,_ 4- E 0.6, 0 616,. :31 N '.5.':31 O. 10 E'- 2:F. :37. :3:3 E 0 4:3 A37 26 N .,::._76 17 E 2456 64 .-. ,~ eI, E .................. 0 - 67 ,5. 59.0 ::: N 2442. 14 E ~.._,..-' 6. 12 E O. 84 682 · 15 N '25C}::-:, O0 E .,..")='o'=' ........ :::b:- - E O, 45 7 C','.":,. 2 :>?, N :257:3,, 4 ¢!, E :2,'5, ,'5, 5..'::,, 9 .... 15:.': (.). 76 7:31. 12 N 2638. :_--: 1 E"' 5:7 :_34. '5>./:, · . ::ir l" - :=-: KUF'ARUK A L A S I< A '.'2;F'IEFRRY-.-SI_II',i WE-.iL_I .... SI_IF,~VEYINC..i COMF:'ANY A N C: H 0 I::;: A G IE A L.. A.:, I-... A VEI:;~T]:C:AI_ SIEf_':'I'ICIN C:AI....C:LILATED AL..ONC~ C:I_C~SIJF;:IE TRUE MEASLIRED VERT I (::AL. D E P T H ..... 1:) i~F::; T' H C 0 M F' LIT A"r I 0 N D A T E OC:TOBEI:;~ 14, 1 F:'A Gl= .... ' VE:RT ICAL DEF"I'H C:OURSE C:C.~URSE DOG-LEG TO'I"AL I NC:L I NAT I ON D I RECT I ON oEVER I TY RECTANOLILAR C:!~!UR[ I NATES~i! i ;:!!?.::i::i,i~ii !~ERT I CAL [) E 13 Id I N D E G R E E :iii; I.'.1E G / ]. O O N 0 R T H / S O I_1T H E A K.; T / W E .,_z; T .:, E .... F l 0 hi ............................................................ /..,200 6300 640 () 6., 50 () 660('1 · ' 670'0 z.:~7£, 74 0 ~ '':" '"~'i'-' '-? ~ '"'-'"' .... .... ., c .... ~ ...... , N --- ,:,. 7. :~: ~ E Z 9::: 7.41 0 .... 46, :-~'-'~/=,. 6,:2: N ~,_-, =. ,.'"'"':~ ~ · :::_ 2 E .'.'.4 c) 04. :l 7 0 ,, E:() :E:51.09 N 2'.:)52..=_;7 E :::',070. 'i?:>.': I. 1 2 :3 7 6.5:3 Iq :3 () 1:3.6,:=-.: [ii7 :31 ::-.': 6. 'P :3 0. '7:3 903. 1 :F: N ::.:.:07 :'::. :_::5 E 320:7:. :'3!2 ._1%.1 I.I .~ a /=,900 ~:'='""'= .._t ._1 i--, ._1 ~ 700'Cj' ':' ;" :2 4 .... ;-,~-, 1 . '71 (')c) ":: ...... '- . ..... ........ :7.=, 7 · '::' !:5 '72 0 0 5 :.E: 1:3. :2, 9 7:30 0 'S'::i ::: ':¢ '.---¢ 41 '7 -"1. 0 0 59/:, 7, 7:3 7:500 6,046,. 50 '7600 ,'!, '125. :2'7' ' 7650 6.1/:,4-. 65 5544,24. 40 :32 N 6,:'3.50 E P; ..../-, 2 0 .2,......,=' 4. 0 :31 Ixl /_-, :3. ::ii: 0 E 5 6 !?/..:,. :39 4 () 1 '7 Ixl 6:'='.:. 0 E '~;772~";P4 ....... :~:9 49 ...... N'"'2_-;.S:.'1G E' 5850.7:3 ::::F.: .t N 6:3.6'7/ E .5'::~'::'9 F:a'~ '-"-' 1 N 6,3.69 E O. .... ,, ... -_', 0 /-, 0 (.'.):.-E:. 2 '7 :.3 :E: 1 Iq /=, 3./=,'? E 0. 604 7.6,5 :3E; 1 lq 6:--':. 6 9 E (). C~(3 11 :E:6,. I E: N :3/-, 49.75 E :3C-::37.6, r::, 0 0 1 19 9. :E: 2 Iq :3 6, 7 7. :.3.6 E :-E:E:6, E:. 1 5 ]"HE C:ALC:LIL. ATION F'ROC:EDLIRES ARE BASEi] ON 'rile USE OF THREE DIMENSIONAL RADILIS OF CLIRVATLIRE METHOD. ARC:O ALA.:,I'-..A, INC. 2]'-E: KUPARUK · ,-o .·. ALA.:,I-...A SI:::'I!.:.]:?F~Y-F~;LIN WI.:.~:I...I._ SUI'RVEY I NG F:OMPANY A N C H 0 R A G E A L.. A S K A COMF'U]"ATI ON DATE OCI'OBER 14, l':"-'z' F'AF-~F 4 DATE OF SURVEY OCTOBER 10, 1$/86 I-::.'Ei:[:.:L:.Y BUFiH..I...h..!.!.3.. E.';.L..E..V..... ........ .~_.!._!?.........~..:.!!'.-.'! ...F"-' ].': ... OF'E'RA'T'OR-li.::. SEL. L E R S I NI-ER?OLATED VALI...IES FI]IR EVEN lO00 F'EET OF MEA,z, URED DEF TH :::.. "I'R LIE SUB-SE A T O'I'AL :?:::L:::::::? ~:~:::?~::~::.~: .................. HE~SURE[i" U~:RT i,~:~nL.'VERT ]: C:nL ...... [~i~'i:-:?fi/~'~iiSOL'n~ ....... ,~:.~'b,:'R~)'~ NnTES MD-.TVDVE:RT~,:::a_ .... . ........................................................... ..... DEF'TH DEF'TH DEF:'TH NOR]"H / SOLITH EAST / NEST D I F:FERENC:E C:ORREC:T I ON ...................................................................... ............. 4 ('-)() 0 500 () 7000 '7650 · ' '0'. oo '".-.-..t 1 '7.66 .................................. i'-')'"'"6i).. ................... (:)'..'(3o ................................... ',5':·5i!i' ............................... ':-'/9'-) ? 1 '-"-"-' ':~ 1 4 o,-, . . . ...... :,,:,~:... . ;o N '~ 84 a 0 09 0.09 19:::':~ ~]~- 1872. Pi=; :::9 48 N 114 46 E 10 45 10.:37 ":;?:~l:~:: ?i; ............. ~:;~il;~'~::': 7'~; ..................... iT]~.-:~'ii~'"'a' ..................... ~:~:":,. ::::n ...... E: le/,. 34'? 0.0:3 :3:37:3.0:3 :352. :32 N 1:355.54 E 5 ()'?. 41 '? :3. () 4 4 (')76 04 ':;'-' =; ....... : .... 72 N 2042.._,..., =' =:' E 8 (')_/-,_. '~) 6. 2'? 6 . ':~.. ':>.. .............................................................................................................................................. ' 4'~> 11. 'o~4 ii7,::~Z.. 1 ,, ~.4:5 .................... :'""~'A'7 ....... ....... 1 .... ~l ........ N 2702 . 1 ,S E 1088 .76 ...... 24 ': 'F~ 1 N :B 309 :::') E '-"-"-' 76 '-' ~::[/-,/-, ~ 2~ .... ~ 4 I 0 ~ ...., .... 1 .:,.:, o . ..... z._,[) O0 /', 164. ~' ~ 60 ~'7 <~ ~;' ..... ....... :,.~, 1199. '::'"':' . ..... 'I"HE CAL.(]:I..iI....A'/"I(]Ixl F:'RC~L-.:EI"[LIRES ARE." BASED ON THE I...I:.:.';E OF' ]"HREE I)IME:.IxI:---;IOI',IAL. RAI]II_I:::; OF CLIRVATURE ME:.'I"Hf.-.fD. E: F:' Iii': R I:'? Y--?: I...I N W E I.... I .... S I...I R V E Y I N G C (] M P A N Y A hi C H 0 R A G E A I..., A L--:; K A AR"II-".,.,U- AL, A.:,KA,'"' .... '~'" '" ................. Z NC. ' ......... '"' ............. ........... ' ................ ' ................... ' .................... ""'"" .................. - -..' 1 -,:, COMPLITAT Z ON DATE ~:?JF'A. RI::!~j!I ........................ '"'. ........ ' OCTOBER 14, 1986 AL. ASKA ............ F'AGE 5 DATE F~F oURVEY OCTOBER 10, ,,..:,o/. K El_ L. Y BL.IL:.;H I N O EL E V · = I 17. () () F"I". OF'ERATOR-E. SELLERS , ]"RLIE i.:.;'SUB-$EA ............................................... ,],"~!?..A__L. ~i:'!i :~':; !!;!:i;;':'~i!~!!i!i ii!ii!iii!i;!:..::;':.! .... , ......................... VEIR"F ;~ 'i:~!'i:~'i:- VERT I CAI_ RI:E F:T'A NGI...II....AR CO01::~D I NA"FES MD.-TVD VEI:i'i" i CAI_ DEF'T'H DEF:"FH NORTH/SOUTH EA S'I"/WEST D I FF'ERE:.NCE CORRECTI ON ......................... 0 ].17 1 21 '7 ':' .1. 7 ":' 41 '7 4 I::' £:7 .... 1 '7 ,.,.I 6.1 '7 '71 7 7 ?--~ 1 '7 c, 101 '7 1. 0 11 1 7 1 1 17.: 1 7 1..":' 1317 13 1417 14 1517 .'1. 5 161 ::-.: 16 12 o. 0 .00 7.. 00 N :1. ,..,/- . 92 E 1 :':: 00. ('], 0 8.00 N 19. ::::3 E ~ 4(".~'~'7i5-(~ ...... ............................. '-,:]. ....................................... :_--::: N .-":',-._.. 67.. E 15 0 0.0 0 1:3.2::-: 1'4 :36.7 5 E 51. ':";' E' 1 '7. ()0 1 7. 17.'00 17. O0 17.00 .1. 7. ()C.) 1 '7 · ,L-:,,::~, O. 17 O. 0::: 0 '-"- , (). 44 o. '7'.'.!: 1. O:F: O. 6,.'1. '2. :38 1. :31 70.76, E 4.35 1.96 ARCO " ......... ALA.M...A, INU. 2T-8 I-:..LIF AR Jk. A I.... A S K A SF'ERF{'Y-'.zi:UN WEi....L ::.:;L.IRVE-JY 1' NG COMF'~NY A I',1 C H O R A C:i E A I.._ A S I< A PAGE COMF'UTATION DATE OCTOBER 14, lC-' .'~6 OF'ERATOR-E. SE]_L. ERS I~* i~? -fRIJE oLIB-,.,EA TOTAL MEA('3UI::~EE~ VEI::UI* i c'AI .... VERT :r. C:AI_ -iiiiiiSi}":i]:'~l{iCi,]i]]!i"i-::i .... i~iiSORD I NA"I"E S MD-. ]'VIi Vli~."R"I' I CAI... ................................................... fie F'TFI DEF:'TH i]EpTH NOR"I"H/S 0 L.I'I"FI EAS ]" / WEST D I F'FERENC:E CORRE f_::T I ON ...................................................................... ..... 19:2 4 :2 0 2 :fi: 2:2 4 2 3 5 7 2 4 '7:3 2594 2721 · '", ,'", ..: o ._, 7 ........ 3004 .3154 :':i'440 3596 3 "744 3::: 5) 1 4-039 41 ':":' 15) 2C)17. (')C)_ J. 'PO0 , OO 42 . '..'5'6.. N 1;7::: , ,:.... '":"":' E 211 '7. . C)(")_ _ :2:000, 00 ._,~..:,'". 04 N .1 !--,_ 9. .1 I E 2217. ()() ;;it I ()0 ,. OC) 6/S. 65 N 20C:,. '.:.:".:::, E 2:31 '7. (),:} 22 C:, (':, ,, ()(:;, :!::: 2 "'7'7 N :25 O. (') 5 15' 241. 7. ()(') 2:3C)C). (")C) 1()C). '79 N :3(}6.4.8 E ........... ':::' !51 '7. O 0 :.3'7 .t. :36 E ;2:61 '7. ()0 44/S. 80 E 11.95 4.67 1'~'o . 76 6 . 81 2:8.04 '?. '28 4 (). 61 12.5'7 5/-, F:/-, 1/'' 2 .. · -- -- i_~# ..-- '7'7 .=,':' 2(:) '7:':i: 104.49 '.76.90 :.7..: 71 '7. C) O '26 00. C) O 2 ::i:' 1"7' '" (5i} ........ :}-)('? 0 '2 i5 i5 :30 , :31 "5, .--, .~, .~, :34. :35 ... 1 '7. ,:],f') 17. (:) 0 .:,'-' 100 . O,r) .,_'::",_q.._'.';'. 27 N 1 c:, .... .,:, '7 .44 _: 17.0() :3200. 00 :2:06.24 N 11 '7:.3.0(3 Z J 7. O0 :-5-?.iOCi: (:_'-;i~T ................ i".T:i~:-~-:'-~;;?'-~ ..... 1 '27:E:. '2'7 .'.--_ 1 '7.00 :.-_-: 4. ("~ ("). C) 0 :3.5; 9. :3',L:: N 1:38 :'::. '74 E ..................... 17. ()(:) :3::'5',(-)C). (':)C) :385. 10 N .1. 4:--::3.48 E 4:32C'-. ..... :3'717;'"C)0 ..... iS;;S;)0-:"(_50 ............... 410. :30 N 29 E . ' ..... '/. 36 C) O 162 48 N .:,.:, :.. 09 E 14 ("). 4. 9 . i'-i~J'?':'?'~!;"-i~ 6z['1, i~!i:¢' Z 1 :-37. :.3.6 47. :38 .1. '7. ~'-)() 2 :F:: 00 .. 0 () 21. 2. '72:I',1 '74 'P. 84 7 2:3 '7.5:2 49 . ¢:' ":".:, :1.7.()('~ 2900 00 ?}:5:7.0:::: Iq -'":' . Y._, 4:S', 4:3 ............. :-.,._, 6.7'::> .... ..... 285 - =' . :3000, C) C) :::: 59.77 N 'P 62:. 12 E 3:32.96 47. C)1 379.92 46.97 427 . ,:..:¢ 47. :37 474.77 4.7..4'F,' 522. '75 47. 'i?'7 56 6.22 4:3.4 L:: fi;F:'ERRS .... SI_IN WEL. L. Sl...IRVEYINC. i CCUgF:'ANY A b.I C I'-t f: R A (3 E A I_ A S I< A .,:.'-" l'--'q,_ "' ' I'" L. UMFL1ATION DATE I<LIF'ARUK ,- ............................................................................... ] ..::~i ::.. :.;:!.~:.:.:,~i. i:::h:,.~:: ' ~ __ OCTOBER F'AGE 7 IN F~'~A:~ED VALI_IE.-, F.~R EVEN 1~)~} FEET ~F .:,IIB-.-,EA DEF-TH '"' ' :::.':: :': .::":'". '" ~ ~ ~ ..... ~ ~ ~ -- .::",.~.~b~>:~:::~:~:~:::K',O~:,~b:~.F:. TRi_iE ~..LIB. ,~,EA TOTAL ~IEASL.IRED .............~Ef}:):i"(~:'~-~L ~ERT I CAL RECTANGLII....AR COORI] I NgTES ~I]-.,T~D ~VERT I C:gl_ DEF:'TH DEF:'I"H DEF'TH NC~F~'I'H / SOLI"FH EAST/WEST I]I FFEERENCE CORRE:C:T I ON ............................ ....................... . ....................................................................... 4610 '"::'-? 17 00 '"'" - . . ~ o. 43 42.07 ..... . .z, ooO O0 461 '.-.-~7 N 1777.74 E 6'-'-' 4752 4.:39:~:'" !iS 0:2: :2: 517:3 · ..~ ..D · - .J :: 1 '57:2:0 .2.:, 7 C) 60 ('-) 7 ·/:.i 4!2 /_-.,277 64;L 1 6544 66.,77 6'941' 401 421 -4:31 441. 451 46,1 471 4:31 /:1. 91 50 i 511 5":'. ' I 5:31 541 £:." c~ ...I ...! ,1 ._=,61 7. O0 '7. C)O 7. O0 '7. O0 7. O0 '7. O0 5000. (-)0 '-"- . . .. · oZ1 14 N 2:_q7.=;.95 E 5100.00 8 ~ :::. '? 9 N ':2'p 59.76 E Ef:~, 7-: .... -; ':- .................. ;:-T;-T,':;-' '::,E-- ................... :-:;'--" - :' _,z oo. c)<_) ,:,,.:., c, . / .::, N .:,o4o. '7(:) E 5:3 () C). C) 0 9 :;._'-: 4. 49 N ::'-: 120.21 E 54 C)0 ,, 00 96,1.6, 5 !',1 :..5:198.54 E-'. ' '5500 60 .... i..?!~O. (:)7F~ ............ :~i275.91 E 1 160. (37 o4 . z.'-'C.) 1194 ~ :34.5= 1227.77 :3 :'3. 14 12/: O. 57 ::.:.':'2. :2:0 12'P2.91 2,2, :.--.:5 1:324.77 :31. :--:6, ~":; F'I.:.!iI::~ F: Y- S L.I N W E L L. SI..IR V E Y I N G C O M F'A Iq Y i-IN CFIOF;~(:~GE (q.... (-'~ S I< (-'~ · F4RC:O ~5. L. ASF':.'A, I NC. 2T-C~ COMPUTATI ON DAI'E I<LIPARL~K OCI"OBE~R 14~ l .986 (.~I....ASKA .......... F'PlGE: ::.7,-: DATE OF SURVEY OCTOBER 10, 1..,~6 JC!B NUMBER ~K,BO---6OQ~i,,..',~.:~::::?~: , KELLEY B.!:-I.'.!.:.;!"{ I N!:]i. E...L:.E..V...,.., ......... :..'T-~,...,,!,,.!.,?..,.. (,.',.)() F'T. 0 F:'E Fi:A'I" O R-- E:. S E: L L.. E: R S .................... ~"~'~"~i~~El~[""'(~L.,Ll~i~ '~l,~'L,'i:.~"'-~V~ .[ (~i~,' F:'EET OF ::,LIB-._ EA DEFT H "r' R I_1E ..... _.. $ LIB-SE...__.:~ ........................................................... ?~ CI 7' ~,L.~.. M E (.~ SI_IRIS [)' V IE:IR"I" I' 'L.[-~ I..~.l .... VER T I C(~I .... F:~E: C T A N C~ I...11_ ~ F~ C: f3OF~ D-I N ~:.~ 'i:'E~'S................ --~I ~iI::']l I~"~ DE:F"I'H DE:F"f'FI ...... DEF':i:H' NORTH / SOLI'T'H E(~ST / WEE};T D I F'FERENC:E: C:ORFiEC:T I ON '707:3 7204 7 :':: :35 74.6::.'.~ '75:3 'il) "'y ! I:::' / (.2' ,,_1 ~,.! 'THE r':AL_C:LILATInN F'RF[CEDi._IIRES USE A I_INEAR Ilql'E]:?F'OLAI'ICiN BE'I'WEEN 1"HE NE:AREST 20 F:O01" MI-~ (FROM RAF;ILiS OF C:LIRVATLIRE) F'OINTS E;F::'E":F,:F:;:Y-SUI',I WEL..I.. SI...iRVE:Y I NG COMPANY PAE:iIE '.:.) A Iq C H 0 R A E.~ E A I.... A S I< A ARCO Ai._A.:,I-...[:~, I NC, DATE OF ~ JRVEY UtL. TC BER 1 ), 1 :,'o6 '.T::]'-::~ PF~i'tF:'I ..... ITAT I ON DA TE I- .... IF ARLII~ . L !.:.TL~BER 1 4 .- 1986 ,_lOB NUMBER AK-BO-6OO~.!~.~:i:::¢:i.:',?:iilL':~.~:.::. AL..Af:;KA I<I..:-I.._I._Y BI...IE;HINC~ EL. EV, = I 1'7.('~0 F-T. ......................................................................... OF:'ERATOR-E, F;IEI....I...ERS ......................................................................................... M E A :!ii: CI R IE .][.'.~ D [ii: P ]" H V E F;~ T Z (.".: [.'311 .... V E R T I C A L F;: Ii!.'". C T a N (:.:i I...I I... A R C: 00 IR D I N A "f' E'S I_'l E F:' T H I.':l E F:' T H N I.') R l" I"t / F-.'; 0 L.I '1" H E A :.:.'; -I" / W E :3 ]" M A R I< E IR ............... . '7116 712'2 '7:32:2: '7400 751:2: 7,.':,5C~ 56:::6. '.::)7 1051.4.3 N :3:38(). 70 E BA.z,E I<I...IF'ARUI< C I;,2~" -..,v .--, . -- ,. ! ..... # '..eI /,¢1~'~ I'7 !5 1 0 6!=; :I. ':': Iq :':: 4 (')'7 9 0 E T ("IR F'I IF' A RI...IK A ~!!'.:.,'??~* :";is:iS .................. i:"'!['"J."ii.:.,'7-i:'~[-' N 349'./:, ,, :.::.i:5 "E ....... I::' '"'~ £:'" · ..... ,-,., ( ) , '7 3 1 t :3 .t . !~.. :::. N .::,,,=.-...,..::,.'", ::z'". 2'i~> E :!ii; U R V E Y D E F' T H · - %~.... ,., 5'?:.:-::'.~:', 7:.3 '1. :L ,"'_- 2, z-i-:"':: F,I :;ii:,'.'-:. () J., 7() I!.': PL...UF:; BA ....I-... ]"I) ,.':.047. ,,-.r-: .............. ~.'":L ,.-:~:~' ,:.:;'.~:, N 3,:-.'77, 3,::. E: ........ ']iL'r- -~ ..... RL"' '[i'EF;:i:i.:i'~"'["~-i'L.L"E'i:~'~ ' -'"' .................................................................................... 2T-'8 .-., ~ RAJ I GRAF:'H I C SLIM~'iARV _ ~t'~-' "'~__ ' '-' '"" I ' . ....... ~)~1'.'~.~_I V__~)._U~i I.PjG II I I_ [ EF THq, AND :=:PERR_Y_ c,,LIN ..-,L RVEY DATA . ..... ................. ,.': ............... ..:'.',:,:,::: :": ~'!,!.-q-,~ !?i~!~!:,~ :::::,::'.:.::':: ': ................ M E ~ :"-'; U R E [:~ D I:"i: F:' 'T' H ..... · .......................... 'l'VI,'.i ......................... '1-1,.t I Ci<NE:SS W 1' "FH RFF. ~ TO WEL. L. blE~q_~.q 'i"01'"' I<UF-':'r:,.~F~UK E: 71 1/.:., .5¥4.? ,, 4.1 !56:3:2.41 1 .BASE KI..IF'F:~RIJK F: '7i ' .'=i7'";"-' ';;7 56:3.& '.-';'7 1 (").=i 1.43N 33E:(). 7()El · '. ................. -. ....! ..:~ . ..' . . ........... "f'Ed::' .......... KUI:'"~:::~F:~I...II< F-~ 716'"~ .'q'TF.:'? . '?5 !.5<!:,7:2 .75 1 ¢)/','='_ _ ._,. :1E:N :L::4,0'?. 'i;'()E E;~L--;E I<LII--'~RLII-:.'.' A~ ' '-'""'-' .......... 7.:,..:.:, 5'.-.-~07 /-,0 .'-17'_.T~(') 60 1110, 11N '34.s-~/_-, 25E' F'L I h"~ B[:~ F:K ']'[.".~ " 7 ... 1:3 1-, (") .~'~ Z-, '7:3 ': q' '-"-' '"" '":-' ' ................ , ...:, :..,. 73 11 & 2.4,:.. N ._-~ <:, <.) 1 . 70 E "l-o'r~4 DE:F"I"FI £1RIL:.L:_ER ..... .-.z..z..-..,~('_.'). ............................................................ Z_-'L_4..._/:_':.5- ..... ..................................................................................... V, '-' ..... ' ' . 1. ) FRFIM LINEAR E'.X'f'RAF'OLATION BELOW. DEEF'EST' STATIL')N.' .............................. 2) i]!O~"I~;[19'ER-'-F'RFiGR~M-_ '2'-i~;'~;E-R~;':/'--~;'i~'l~ THREE DIMENSIONAL RADIL._-,I'-' OF ULRVATURE-'I' ' , DATA C:ALC:ULATION AND INTERF'OLATION BY RABILIS OF C:URVATLIRE C 0 MF'U T A T I ON I) A T E FIC:TOBER 14., I "::-.,'L"3/:, El A'I" E (;IF ::;l_lFi: V E Y ,'.'.iL-: T I'-IB E R 'l 0-, l '? E:&, .~ioB NUMBER AK-BO-60C)6'.~ KELL¥,.:.B. LJ.~,tC..,!N_, ELEV. = 117.00 FT. NORTH 5GALE ; - I ]NCtt 10 500'.00 / 500.0 KUPARdK ARCO AI. ASKA. 2'i -~ OCTOBER LO. AK-BO !NC. [986 L--~.,~j(J. l'.LJ ttOR 1. Z 9 I',l"[ fii i::~ P~ O.JF- C T ! O N . . 60%. :c 5CRLE 27 -8 qK-88-80089 INCH TO ~500.00 / qBCO qL~SKR, iNC. 8CTOBE8 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. iNDEi: . Reports and Materials to be received by.' _L ' [fate Required Date Received Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test ~eporcs Production Zest RepOrts Log Run Digitized Data Remarks DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND CAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcut~ine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kupamk River Unit 2T Well Data WALTER d. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE, ALASKA 99510.7034 PHONE: (907) 762-2553 Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T1 iN R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, (J~.mes E. Eason Xl)irector cc: J. L. Dees, ARCO Alaska Inc. RE( EIVED APR 1 6 199t Alask~ 0ii .& Gas Cons. Commission ~nchomge r~'..~..,, ~jr,rltr~.~J ,)r3 rec','c:ed paper STATE OF ALA,SKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator AR(~O 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 252' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1302' FSL, 1347' FWL, Sec. 1, T11N, R8E, UM At effective depth 1414' FSL, 1122' FWL, Sec. 1, T11N, R8E, UM At total depth 1452' FSL, 1047' FWL, Sec. 1, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7650' 6165' feet feet 6. Datum elevation (DF or KB) 117' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-08 9. Permit numb,er/approval number 86-1o9 /?- ? / 10. APl number 60-103-20070 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Effective depth: measured 7513' true vertical 6057' feet feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 8O' 16" 2943' 9 5/8" 7566,' 7" measured 7188'-7192', true vertical 5804'-5807', Cemented Measured depth 234 Sx AS I 1 15' 685 Sx AS III & 2977' 315 Sx Class G Top Job w/100 sx AS I 300 Sx Class G & 7600' 175 Sx AS I 7202'-7206', 7208'-7228' 5815'-5818', 5819'-5835' Tubing (size, grade, and measured depth) 2 7/8" J-55 6.5#/FT , EUE, ABMOD, IPC Tail @ 7092' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA, 1830', Packer: Brown HB-1, 7067' True vertical depth 115' 2798' 6125' 13. Stimulation or cement squeeze summary Hydraulically fractured the A and C Sands with gelled water and 16/20 Carbolite. Intervals treated (measured) 7116'-7323' RKB Treatment description including volumes used and final pressure Pumped 1288 Bbls of gelled water and 114,698 Lbs of 16/20 Carbolite. Final WHTP = 5840 psi~j. 14. Representative Daily Average Prq~du(;:ti0n or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 1 29 758 - 0 - 1 1 00 292 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 1351 1262 - 0 - 1 150 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 263 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Fl~'v' 05/1"'~/89 Title Senoir Operations Encjineer SUBMIT,I/N DUtSLICATE · Ieet ARCO Alaska, Subsidiary of Atlantic Richfield Coml~any WELL SERVICE REPORT CONTRACTOR REMARKS tFIELD - DISTRICT. STATE OPERATION AT~EPORT TIME c'~ ~?/.~ ~'e.- t l o'~ 1!2o i2~o 12oZ~ lZo~ ~zl~ IZ~ 700 .F,¢Iof CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ 2. Name of Operator Suspend _ Alter casing _ Repair well Change approved program _ 5. Type of Well: Development ..~ ARCO Alaska. Inc. · Exploratory _ 3. Address ~ Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510~ Service _ 4. Location of well at surface 252' FSL, 556' FWL, Sec. 1, T11N, RSE, UM At top of productive interval 1302' FSL, 1347' FWL, Sec. 1, T11N, R8E, UM At effective depth 1414' FSL, 1122' FWL, Sec. 1, T11N, RSE, UM At total depth 1452' FSL, 1047' FW.L~ Sec. 1, T11N~ R8E, UM 12. Present well condition summary Total Depth: measured 7 6 5 0' true vertical 61 6 5' OR IGIN A L Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8, Well number 2T-08 "~//~, /,-~'- ~ . 9. Permit number 86-109 10, APl number 50-1 03-20070 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet ~ Effective depth: measured 7513' feet Junk (measured) true vertical 6057' feet NCIX~ Cemented Measured depth 234 Sx AS I 1 1 5' 685 Sx AS III & 2977' 315 Sx Class G Top job w/100 sx AS I. 300 Sx Class G 7 6 0 0' 175 Sx AS I Casing Length Size Structural Conductor 8 0' 1 6" Surface 2943' 9 5/8" 7566' 7" Production Liner Perforation depth: 90 degree phasing, 7202'-7206' 90 degree phasing 5819'-5835' True vertical depth 115' 2798' 6125' 1 SPF 90 degree phasing RECEIVED 1989 ;: las 3 Oil & Gas dons, Commissio. ; Detailed operation program Date Suspended measured 7188'-7192' I SPF 7208'-7228' 4 SPF true vertical 5804'-5807', 5815'-5818', Tubing (size, grade, and measured depth 2 7/8" J-55 w/ tbg tail @ 7092' Packers and SSSV (type and measured depth) Brown HB-1 ~ 7067'~ Camco TRDP-1A-SSA @ 1830' 13. Attachments Description summary of proposal_ Fracture stimulate A and C Sands with 1200 BBLS gelled water and 106000 LBS Carbo-lite. 114. Estimated date for commencing operation ~ 15. Status of well classification as: August 7. 1989 l, Oil X Gas __ 16. If proposal was verbally approved,~,/ c~,~ ~ ~,/..~ ?.~ ,~. ][ Name of approver /~ .~i.,A¢, //~. Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.//~ .4'~ /~.-~,.~f~.-'~c~'t.../~~'¢')1 Title Sr. Operations Engineer FOR COMMISSION USE ONLY · · /I 10- Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test_ Location clearance ~ Mechanical Integrity Test~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner [Approval No. &pproved Copy Returned Approved by the order of the Commission Messrs Chambers ano June 27, 1989 Page 3 ,dan Kuparuk Well 2T-08 'A' Sand Re-Fracture Procedure Charge Code: K80496 1. Obtain a 24 hour well test. 2. MIRU Slickline unit. RIH with gauge ring. Tag fill. , RIH with Standing Valve and set in Camco 'D' nipple @ 7081'. Pull DV from 1-1/2"mandrel @7005' Install full open CV. Displace annulus with 197 bbls of 9.8 ppg brine. This volume should leave a pad of 15 bbls (500') of diesel in the annulus. Pull CV. Run DV. Pressure test tubing to 4500 psi. RIH and pull SV. 4. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. ** WELL SHOULD BE CLOSED IN A MINIMUM OF THREE DAYS BEFORE THE REFRAC JOB IS PUMPED.** 5. MIRU fracture equipment. , . . Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Install "Tree Saver" with maximum mandrel I.D. (NOTE: The tree saver will probably need to be set in the 3-1/2" tubing hanger above the 3-1/2" x 2-7/8" x-over collar.) Pressure up the 7" x 2-7/8" annulus to 1500-2000 psi. Pump pre-pad allowing annulus pressure to increase to a maximum of 2000-psi.. Immediately prior to pumping the pad, increase the annulus pressure to 3000 psi, provided the SIWHP is a least 1000 psi. Allow annulus pressure to increase to a maximum of 3500 psi by the end of the pad. Maintain this pessure (3500 PSI) on the annulus throughout the remainder of the job. Pump fracture treatment per the attached schedule. Recommended maximum surface treating pressure is 6500 psi. Record the 5, 10, and 15 minute pressures following the ISIP. Bleed annulus pressure down to a maximum of 2000 psi, before SIWHP declines below 1000 psi. Expected wellhead treating pressure: WHTP = 4430 psig Fracture Gradient = 0.70 psi/ft (5838' TVD) Tubing Friction = 320 psi/1000 ft (7091' MD) @20 BPM If initial pump in pressure exceeds 6000 psi, shut down job Engineering. laska Oil & Anchorage Messrs Chambers ano June 27, 1989 Page 4 'dan . Rig down frac equipment. Follow attached flowback schedule. After well has completed flowback, obtain 24 hour wetl test. The annulus can be displaced with diesel when the next slickline operation takes place on this well. No workover fluids are required. No BOP's are required. The estimated bottomhole pressure is 3000 psi. RECEIVED ,N. IG2 I 9 _-.~*iaska Oil & Gas ~.;.~s. ~;ommi~io~, Anchorage KUPARUK WELL 2T-08 'A° SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6/28/89 STAGE FLUID DESCRIPTION CLF..Nq VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTION LBS S"I'G/CUM BBLS 5 6 7 8 10 I GW PRE-PAD 200.0 2 0 ............................................... SHUT GWPAD 700.0 20 GWw/2 PPG 41.4 20 GW w/4 PPG 51.0 2 0 GW w/6 PPG 71.2 20 GW w/8 PPG 81.3 2 0 GW w/10 PPG 69.4 20 GW w/12 PPG 39.2 20 SLICK DIESEL FLUSH 43.0 +SV 2 0 DOWN 0 - ~ 0 FOR ISIP 0 16/20 M CARBO-LITE 0 2 16/20 M CARBO-LITE 3473 4 16/20 M CARBO-LITE 8567 6 16/20 M CARBO-LITE 1 7932 8 16/20 M CARBO-LITE 2731 5 1 0 16/20 M CARBO-LITE 291 39 1 2 16/20 M CARBO-LITE 1 9770 0 -- 0 200/ 200 50 700/ 900 250 451 945 950 60/ 1005 995 90/ 1095 1055 1101 1205 1145 100/ 1305 1255 60/ 1365 1355 431 1408 1415 TOTAL GELLED WATER = 1203.8 BBLS TOTAL DIESEL = 49.6 BBLS TOTAL SLICK DIESEL = 43.0 BBLS +SV 16/20 M CARBO-LITE = 106197 LBS Stages 1 through 8 are Gelled Water. Stages 1&2 are Gelled Water with 40 Ibs/10(X) gal silica flour and enough breaker for a 6 hour break. ~ges 3 through 8 are Gelled Water with 6 hour breaker and without silica flour. ges 1 through 4 will also contain 5% ArclJc Diesel by volume for additional fluid loss control. ~e 9 should include a volume adjuslment for surface equipment between the wellhead and densitometer. ,~'lis job Is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. fluids should be maintained above 100° F on ~ surface. DEPART~iENT OF NATURAL RESOURCES August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ~James E. Eason y"~Di rector . cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 2, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5844 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Openhole Finals (1 bluel 5" FDC Porosity 7-12-86 "'5" FDC Raw 7-12-86 '~Cyberl ook 7-12-86 2" FDC Porosity 7-12-86 '"-2" FDC Raw 7-12-86 ~ 2" DIL 7-12-86 'C~2T~___~ 5" FDC Porosity 7-21-86 ~ 5" DIL 7-21-86 Caliper Profile 7-21-86 ~ 2" DI L 7-22-86 ~'~'-5" GR thru casing 7-21-86 ~ 5" FDC Raw 7-21-86 2" GR thru casing 7-21-86 Cyberlook 7-21-86 2" FDC Raw 7-21-86 2" FDC Porosity 7-21-86 Receipt Acknowledged: Distribution: ine of each unless otherwise specified) 4915-6728 4915-6702 4915-6702 6100-6600 4915-6702 4915-6702 4915-6702 5100-7624 2982-7650 2982-7636 2982-7650 100-2982 5100-7624 100-2982 2982-7656 5100-7624 ~Alaska 0il & Gas Cons. Commission Date: Anchorage NSK Drilling L. Johnston (vendor pkg) TKKW: pg: 0040 (MF) R a thme 11 Vault (film) D&M ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlleldCompany STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMMI, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~_ Stimulate -- Plugging '_- Perforate ~ Pull tubing _% Alter Casing C Other ~ Comp'fete 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ lnc RKB 117' Feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage¢ AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 252' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-~ At top of productive interval 8. Approval number 1302' FSL, 1347' FEL, Sec. 1, TllN, R8E, UM 324 . At effective depth 9. APl number 1414' FSL, 1122' FEL, Sec. 1, T11N, R8E, UM 50e 103-20070 At total depth 10. Pool 1452' FSL, 1047' FEL~ Sec. 1, T11N, RaE, UH Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 7650 'MD feet Plugs (measured) None true vertical feet 6165 ' TVD Effective depth: measured feet Junk (measured) true vertical 7513 ' M D feet N o n e 6057'TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 234 sx CS II 115'MD 115'TVD Surface 2943' 9-5/8" 685 sx AS I I I & 2977'MD 2798'TVD 315 sx Class G Top job w/lO0 sx AS I Production 7566' 7" 300 sx Class G & 7600'MD 6125'TVD 175 sx AS I Perforation depth: measured - 7188' - 7192'MD 7208' - 7228'MD 7202' - 7206'MD true vertical 5804' - 5807'TVD 5819' - 5835'TVD 5815' - 5818'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 7092' · -.~ ?. '~.~ ' ~. Packers and SSSV (type and measured depth),. HB-1 pkr (~ 7067~ & SSSV L~ 1830' 12. Stimulation or cement squeeze summary i.. ~../ 'i 7 ,.. :,, .J ~,. N/A Intervals treated (measured) !_...,:%,..::::,· Cii~ .":. ....... Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Prior tO well operation ~,~J ~ ~ ~ b=:' '''; ~ j :~ :t ' '";" ;" J :' !' ";'~ Subsequent to operation i~-, !! ~: ....,; :.. ~ .:~ 14. Attachments (Completion Well History, w/Addenddr ?i~t~ 9~,./~23~,a8,6i;=,;.:;_~ Daily Report of Well Operations ~ Copies of Logs and Surveys Run Y-,7_X Gy~'o / 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~¢-~' ~-(~¢"~ ~//~~~~t_~ Associate Engineer Signed Title ! n~M ~ cwn /~ ~: Date Form 10-404 Rev. 12-1-85 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ~s Plugged. Abandoned. or Sold. "Final Report" should be submitteD also when operations are susbended for an indefinite or appreciable ~ength of time. On workoverS when an official test is not required u~on completion, repod, completion and representative test data in 0locks provides. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code Dl~tflct ICounty or Parish /State Alaska North Slope Borough Alaska F~,~d ILease or un, Iw,,, no. Kuparuk River ADL 25569 2T-8 Auth. or W.O. no. ~Tltle AM[ AK0758 [ Completion Nordic 1 API 50-103-20070 Ol~rator A.R.Co. W.I. ~otal number of wells (active or inactive) on this~ Icost center prior to plugging and ARCO Alaska, Inc. 56.24~[ labandonment of this well / Spudded or W.O. begun Date JHour JPrior itltUl If I W.O, Col~plete 10/13/86 / 1400 hrs. I Date and de~h Complete ~ecord for each day reported aa of 8:00 a.m. 10/14/86 10/15/86 7" @ 7600'- 7477' PBTD, RU WL 11.0 ppg Brine Accept rig @ 1400 hfs, 10/13/86. ND master vlv. NU & Cst BOPE. RU Schl, perf f/7208'-7228' @ 4 SPF/90° phasing & 7202'-7206' & 7188'-7192' @ 1SPF/90° phasing. RU & rn 2-7/8" compl, ball did not seat to set pkr. Wait on WL unit. 7" @ 7600' 7516' PBTD, RR 6.8 ppg Diesel RU WL, RIH w/blind box & chase ball to btm, POOH, RD WL. Set pkr &tst tbg to 2500 psi. Shear out of PBR & re-lnd. Tst pkr to 2500 psi; OK. Tst SSSV to 1500 psi; OK. Set BPV. ND BOPE, NU & tat tree to 250/5000 psi. Displ well to diesel. RR @ 1630 hfs, 10/14/86. (Rn 217 its, 2-7/8 6.5~, J-55 AB Mod 8RD EUE tbg w/SSSV @ 1830', HB-1Pkr @ 7067', TT @ 7092') Old TO New TO Released rig Date 1630 hrs. 10/14/86 Classifications (oil, gas, etc.) Oil PB Depth Kind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production 7516' PBTD Rotary Pump size, SPM X length Choke size The a~ove is correct · ! For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 8~ and 87. LP. I Water IDate . ,~ ITitle Oil on test Gas per day GOR Gravity Allowable Effective date corrected ADDENDUM WELL: 9/16/86 9/17/86 2T-8 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. TIH w/CT to 500' & circ diesel to thaw 9-5/8" x 7" ann. Inj 70 bbls diesel & brine into ann, RD. Drilling Supervisor ARCO Alaska, Inc. Post Office BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1235 DATE' 11-7-86 Transmittal #5819 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records .Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T--2 CBL 10-12-86 7000-8786 Run 1 2T-3 CBL 10-12-86 3135-7780 Run 1 2T-5 CBL 10-11-86 3842-7548 Run 1 2T-6 CBL 10-13-86 3400-8007 Run 1 2T-8 CBL 10-10-86 5100-7475 Run 1 2T-9 CBL 10-10-86 2900-6174 Run i Receipt Acknowledged: Distribution: BPAE(1 bl) Unoc Mobil (1 bl+l .Drilling(1 bl) bl+ Alas~ 011 & Gas'Cons. smon Anchorage ) Chevron(1 bl+l se) NSK(1 bl) i bl+l se) ~ Vault(1 film) L. johnston(1 bl+l se) ARCO Alaska, Inc. Extension Exploration TRANSMITTAL. _ FROM: TO: DATE: ADDRESS: Transmitted herewith are the following: Craiq I~osel-v -Arcn Oct. ~O. lqRk Wel I Data ARCO: Kuparuk 2T-3(K-lO sands) 9-12-86 Lis Tape Open Hole 3160.O - 41OO.0 Kuparuk 2T-6(K-10 sands) .-8-21-86 L)s Tape _ Open Hole 3874 - 4210 ~03 ~ - ~ -o/ce/) - 3~7 ~z-~z ~/~ ~KUpa~Uk 2T~S(K-10 sands) ~7-22-86 Lis Tape Open Hole 29~8.5 - ~000.0 RECEIPT ~ / DATE: ....... ACKNOWLEDGMENT: ~-- - ..... ' Return receipt to: ARCO Alaska, Inc.~// Extenstion Exploration ATTN: Lucille Johnston A P. O. Box 100360 Anchorage, Alaska 99510 RECEIVED DEC 2 4 1986 Alaska 011 & Gas Cons. Commission Anchorage Processed By'. L. John.,,' ARCO ALASKA, INC. ' · ": -..:.": - Development GeoScience - TRANSM I TTAL- ·: i . .. / Transmitted herewith are the e- ~- ~ ~/~ ~ ~ " " ?- ~ - ~ ~,,/~ .z', ~ ~-,, ~ ×/~ ~ . Return receipt to: ARCO Alaska, Inc~ ~ ~a~O~& Gas Cons. Commission ~ ' Extenstion Expiration / .... Anchorage ... ATTN: Lucille ~Johnst o~ ANO-~gE' " P. O. Box 10036,0 / ' Anchorage, Alas~9510 o. ALAS, , OIL AND GAS CONSERVATION COM,..iSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon :._- Suspend © Operation Shutdown r~ Re-enter suspended well ~ Alter casing Time extension ~ Change approved program m Plugging C Stimulate ~ Pull tubing-' Amend order '- Perforate = Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, IQc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Rox 100~0 An~hnran~_ AK qq~lfl ~,~n~rllk RivP. r Unit 4. Location of well at surface 7. Well number 252'FSL, 556'FWL, Sec.l, T11N, R8E, UN 2T-8 At top of productive interval 8. Permit number 1290'FSL, 1414'FEL, Sec.l, T11N, R8E, UH (approx.) 86-109 At effective depth 9. APl number 1565'FSL, 1189'FEL, Sec.l, T11N, R8E, UN (approx.) 50-- 103-20070 At total depth 10. Pool 1602'FSL, 1113' FEL, Sec.1, T11N, R8E, UM (approx.) Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7650'MD feet Plugs (measured) None true vertical 6163'TVD feet 7513 ' ND None Effective depth: measured feet Junk (measured) true vertical 6056'TVD feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 234 sx CS II 115'ND 115'TVD Surface 2943' 9-5/8" 685 sx AS Ill & 2977'MD 2810'TVD 315 sx Class G Top job w/lO0 sx AS I Producti on 7566' 7" 300 sx C1 ass G 7600'MD 6124 'TVD _ Perforation depth: measured None [i ~'i:'i!.i~ i:'i:~"'i !i, Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.AttachmentSWell History Description summary of proposal E3 Detailed operations program ~ r~:~.~l~j~ ,Ir' . ~,c. iX 13. Estimated date for commencing operation ~U Ir .] ~1'~ 14. if proposal was verbally approved I ~ ,~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ :~H,)-6/LJ Title Ass°ciate Engineer Date (:~-~_~ d Commission Use Only (DAM) SA/091 Conditions of approval Notify commission so representative may witness I Approval No. .--'7 Iq_.. Plug integrity [] BOP Test [] Location clearance I Approved by ~':Y !¢!~;'~]~ 8., S~lflt Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company '~' Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borough ITM Alaska Alaska North Slope Borough I Field Lease or Unit IWell no. Kuparuk River ADL 25569 I 2T-8 Auth. or W.O. no. ~T t e AFE AK0758 I Drill Rowan 34 API 50-103-20070 Operator I I ]ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ]Date IHour Prior status if a W.O. Spudded 7/15/86 0100 hrs. Date and depth as of 8:00 a.m. 7/15/86 7/16/86 7/17/86 7/18/86 Complete record for each day reported 16" @ 115' 700', (625'), Drlg Wt. 9.5+, PV 10, YP 14, PH 11, WL 9.6, Sol 9 Accept rig @ 1700 hrs, 7/14/86. NU diverter sys. 7/15/86. Drl 12¼" hole to 700'. Spud well @ 0100 hrs, 16" @ 115' 2397', (1697'), Drlg Wt. 9.8, PV 27, YP 22, PH 9, WL 9.4, Sol 8 Drl & surv 12¼" hole to 2397'. 1000', 1.3°, N55E, 1000 TVD, 7 VS, 9N, 5E 1536', 4.5°, N74.8E, 1535 TVD, 23 VS, 15N, 20E 1849', 12.0°, N71.6E, 1844 TVD, 70 VS, 29N, 64E 2255', 24.9°, N70.3E, 2229 TVD, 199 VS, 71N, 186E 9-5/8" @ 297~' 2985', (588'), NU BOPE Wt. 9.6, PV 11, YP 8, PH 9, WL 9.0, Sol 9.5 Drl 12¼" hole to 2985', short trip, C&C, POH. RU & rn 74 jts, 9-5/8", 36#, J-55 HF/ERW csg w/FS @ 2977', FC @ 2895'. Cmt w/685 sx AS III & 315 sx C1 "G"w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 2345 hrs, 7/16/86. ND diverter. Perform 100 sx AS I top job. NU BOPE. 2446', 30.4°, N71.7E, 2397 TVD, 287.14 VS, 99.57N, 269.91E 2940', 46.4°, N75.1E, 2785 TVD, 591.02 VS, 186.76N, 561.04E 9-5/8" @ 2977' 3508', (523'), Drlg Wt. 9.5+, PV 11, YP 4, PH 10, WL 10.0, Sol 9.2 NU & tst BOPE. TIH to FC, tst csg to 2500 psi. DO flt equip & cmt + 10' new hole to 2995'. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 3508". 3226', 47.9°, N75E, 2980 TVD, 800.5 VS, 240.85N, 763.62E 3446', 47.3°, N78E, 3128 TVD, 962.6 VS, 278.78N, 921.59E IHDEFINI/ELY The above is correct For %r~n"~eparmtion ~'~d distribution; see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate , Title Drilling Supervisor ARCO Oil and Gas Company ~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25569 Complete record for each day while drilling or workover in progress 7/19/86 thru 7/21/86 7~22/86 ISlale Alaska rWell no. 2T-8 9-5/8" @ 2977' 7650', (4142'), Cond'g rn Wt. 11.0, PV 13, YP 7, PH 8.5, WL 7.4, Sol 14 Drl & surv 8½" hole to 6604'. Conduct formation tst to 11.5 ppg EMW. RIH, wsh & rm f/6437'-6604', drl to 7336', raise mud wt @ 6800' to 10.8 ppg & @ 7300' to 11.0 ppg. Drl to 7625' (7650' SLM Correction), C&C, POOH. RU Schl, rn DIL/GR/SP/SFL f/7650'-2956', cont w/GR to surf. Rn FDC/CNL f/7650'-6400' & 5500'-5100'. Rn CAL f/7650'-6100', RD Sch. RIH f/cond'g rn. 3810', 47.5°, N72.4E, 3375. 4818', 45.3°, N69.5E, 4075. 5814', 44.5°, N66.2E, 4783. 6310', 42.4°, N65.3E, 5143. 7261', 40.5°, N62.2E, 5857. 7605', 36.0°, N64.7E, 6127. 06 TVD, 1230.24 VS, 347.22N, 1180.64E 24 TVD, 1955.24 VS, 566.66N, 1871.64E 18 TVD, 2654.60 VS, 814.47N, 2526.87E 26 TVD, 2993.29 VS, 954.57N, 2837.88E 72 TVD, 3611.39 VS, 1243.18N, 3395.13E 87 TVD, 3821.66 VS, 1338.37N, 3585.64E 7" @ 7600' 7650' TD, 7513' PBTD, Set 7" slips Wt. 10.9+, PV 22, YP 13, ~H 8.0, WL 8.0, Sol 16 RIH to 7590', wsh to btm, C&C, POOH. RU & rn 186 jts, 7", 26#, J-55 HF/ERW R-3 csg. Cmt w/100 sx 50/50 Cl "G", followed by 200 sx C1 "G". Displ w/ll.0 ppg brine. Pipe stuck @ 7600' w/FC @ 7513'. Slight rtns. Bump plug. CIP @ 0430 hrs, 7/22/86. ND BOPE, set 7" slips. The above is correct see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date ITitle Drilling Supervisor CONFi, IN.DEFINITEL'Y ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska J North Slope Borough Alaska Field ILease or Unit I Well no. Kuparuk River ADL 25569 2T-8 Auth. or W.O. no. ~Title AFE AK0758 I Drilling Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 7/23/86 API 50-103-20070 IA.R.Co. W.I. 56.24% IDate 7/15/86 Complete record for each day reposed I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0100 hrs. 7" @ 7600' 7650' TD, 7513' PBTD, RR 11.0 ppg NaC1 Instl packoff & NU tbg spool, tst to 3000 psi. 7/22/86. RR @ 1200 hrs, Old TD Released rig 1200 hrs. Classifications (oil, gas, etc.) Oil INew TD PB Depth 7650' TD 7513' PBTD IDate Kind of r g 7/22/86 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Producing method Flowing Potential test data Well no. I Date I Pump size, SPM X length Reservoir Choke size The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Producing Interval C.P. Water % !Oil or gas Test time Production Oil on test GOR Gravity Allowable corrected IGas per day Effective date ARCO Alaska. Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE 07-30-86 TRANSMITTAL # 5727 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Open Hole LIS Tapes Plus Please acknowledge receipt and Listings: Schl: One copy of each -~2T-8' 07-21-86 Run #1 ~2T-9~ 07-03-86 Run #3 --2T-12A/07-12-86 Run #1 ~-3K-3f 06-27-86 Run #1 ~--3K-4× 07-04-86 Run #1 ~-3K-5/ 07-12-86 Run #1 0097.5-7669.0 3300.0-6389.0 4885.5-6756.0 0187.0-8929.0 2992.0-8937.5 2388.5-8168.5 EDIT EDIT EDIT EDIT ~omm~ssiop, Receipt Acknowledged: Date: ARCO Alaska. Inc. is a Subsidiary of AtlanticRichtieldComl=anY June 5, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T-8 ARCO Alaska, Inc. Permit No. 86-109 Sur. Loc. 252'-FSL, 556'F%~L, Sec. 1, TllN, R8E, UM. Btm_hole Loc t392'FSL 1092'FEL Sec 1 TllN R8E UM Dear M~r. Kewin: Enclosed is the approved application for permit to drill the' above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. -Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~tru!y~%ou~s, / .. /,,-/// Chai~an of Alaska Oil and Gas Conse~ation Con~ission BY ORDER OF _THE CO~4.1SSION dlf Enclosure CONI:IDF. NI'IA INDEFINII'F.I..Y cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~, STATE OF ALASKA ALASKA ~.~ AND GAS CONSERVATION CC,.,MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill I-iJ lb. Type of well. Exploratory L~ Stratigraphic Test ~ ,Development Oil Re-Entry [] Deepen[]J Service [] Developement Gas [] Single Zone')~,. Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri ver Oi 1 Poo P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 252'FSL, 556'FWL, Sec.1, T11N, RaE, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1290'FSL, 1414'FEL, Sec.1, T11N, RaE, UN 2T-8 #8088-26-27 At total depth 9. Approximate spud date Amount 1392'FSL¢ 1092'FEL~ Sec.l~ T11N¢ RaE¢ UN 06/22/86 $500¢000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and Tva) property line 7605 ' ND 1092' _F"¢ TD feet 2T-9 '~.5'r~ s,Jrfac, e feet 2_~60 f6123'TVD~ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1480 feet Maximum hole angle 45 0 Maximum surface 1670 psig At total depth ¢'VD) 3543 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12~" 9-5/8" 36.0# J-55 BTC 2932' 35' 35' 2967' 2821 ' 685 sx AS I I I & HF-ER~/ 315 sx Class G blend R~," 7" 26.0# .J-~,5 RTC, 7_~71 ' ~4' .~4' 760~,' ¢;17~,' ?f) O .~x C,l~-~.~ G fminim~rr - HF-ER~/ fO(: ,500' above tOD of 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Kuparuk. Present well condition summary Total depth: measured feet Plugs(measured) true vertical feet~lt~U i~ 1[ ' Effective depth: true measured vertical feet feet Junk(measured)e~dil~:I [~ I:!LI ,~llr~ -,~, ~I!it!',-,,. V. casing Length Size Cemented Measur t i , evertca depth Structural Conductor '"~ --. ..... - :, ,., ~, ;~, Surface "': ~ .... :~; ,' ~-~ c- Intermediate ~..'".."':' :': 'i:, ;p Production i'.;:...-',,-i' ,_';! ,._, Liner ~'.. ~..-~_,~ ~ Perforation depth: measured :.. :'.. :. true vertical 20. Attachments Filing fee ,~I Property plat ~ BOP Sketch '.~ Diverter Sketch .Z Drilling .program ~ Drilling fluid program ~ Time vs depth plot I~ Refraction analysis [] Seabed report L~ 20 AAC 25.050 requirements,~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge '. Signed ~ ~, ~~~ ~~---~~ Title Regional Drilling Engineer Da te~//~Z/~, Commission Use Only .PD/PD'27,3 (1') Permit Number ,~' L, --/O~ APl number I Apprc a) 8Dt: I See cover letter 50-- /'~-~:~ o 0 ? ~ 86 for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required ~ Yes ~No Hydrogen sulfide me_,~-~sures D Yes ,~ No Directional survey required ¢ Yes ,~ No Required workin_,,l~Cre~sure/,fl::)r B,,,O~~M;~ '~M; ~ 5M; ~ 10M; [] 15M Other: f /~/f/~~ e,~,//~ . by order of Approved by k ~""-//', ~.~ Commissioner the commission Ddt Form 10-401 Rev. 12-1-85 Sub/r ~ triplicate i -i )ooo ~ooo f , : .. 252' SEC :0' FEI. · ] t ' · ' KUPRRUK R I VER UN I T 20" O I VERTER SCHEMRT I C DESC R I PT I ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLINQ SPOOL W/10" OUTLETS. 7. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINQLE .VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE RENOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. 6 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035; (b) MR I NTENRNCE & OPERRT I ON 4 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DI VERTER L I NES EVERY !2 HOURS. 3. CLOSE AI',INULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. NOT SHUT IN NELL ANY C ! RCUNSTRNCE S. CONFIDEN[IAi IN.DFFIN!TELY S 100840~2 tC < 7 > > 5 4 A¢(~TOR CAPACITY TEST I. C:~EC~ AI~ FILL A~TC~ RESERVOIR TO P~ LEVEL WITH HY[]~AII_IC FLUID. A~ THAT A~TC~ PRES,~ IS ~ PSI WITH 3. ~ TINEo 9]-EN CL_cI'!~'~_ ALL LINITS SINU. TAhEC&J~LY 4. ~ ~ ~ ~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ T~ ~ I~ ~I ~INI~ 13-~" BC~ STACK TEST I. FILL BCI: STAa( ~ (:N(IQ~ MANIFO. D WITH ARCI'IC 2. O.~C~ THAT ALL LOCI< ~ SC:RE~S IN WS_LPEAD A~ FIJLLY RETRACTED. ~.AT WITH RLI~qIN~ JT LII~[ VALVES ADJACENT TO B(]:~ STAQ(. ALi. OT]-E~ 4. ~ UP TO ~.~3~_E~Z-~HCI.D FC~ I0 MIN. IN- (~ PRE'_~__.~ T~ ~ HCI. D FCR I0 MIN. B~ m~n PRESS.I~E TO 0 PSI. LIhE VALVES. (1.__ngE TCP PIPE RAMS ~ H(~ VALVES CN KILL 6.TEST TO 250 PSI Ah[:)~~~ IN STEP 4. ?. CCNTII~JE TESTING ALL ~L-gESo LIhESo AhD CHO(ES WITH A 250 PSI LON AhD 3000 PSI HIGH. TEST AS IN STEI3 4. NOT A ~,LL CLOS~I~ PgSITIYE SEAL Q-E3d~i CI~LY TEST BOTTC~ PIPE ~ TO ~ PSI mN:) 3(x3o Psi. 10. Q_C~E BLIhI) RAMS ~ TEST TO ~ PsI AhD 3{X30 PSI. 11. C;MEN BLIhD RNw~ AhD RETRIEVE-TEST PLUG. MAKE SURE MANIRO.D AhD LI~E$ ARE FULL Cl' NO4-FREE'ZING FLUID. SET ALL VALVES IN CRILLIh~ PC~ITIC]4. 12.- TEST STAhI)PIPE VALVES, KFI I.Y, KFTIY 033(S, [;RILL PIPE SAFETY VALVE. 3000 PsI. 13. RECC;~ TEST IhF~TIC~ CN BL(~ PREVENTER TEST FC]~M, SION, AhD .S~ TO DRILLINO SUI:~Sq~ISC~. 14. PERF~ ~ BC~E TEST AFTER NIPPI..ING t~ AhD ;~EKI..Y THEREAFTER FtI4CTIO4ALLY CI:~TE ~ DAILY. CONFIDENI'IAL.t iNDEFiNiTELY 51CK~,4001 REV. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS -~ DEOASSER! CLEANER R .~. HUD CLEANER STIR _..~,. STIR TYPICAL HUD SYSTEH SCHEHATIC LWK4/ih CONFID-[N'JlAL INDEFINIT[LY DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. nWK5 / ih CONFIDENTIAL II DEFINITEL Y ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 january 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure RE[EIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i i LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. I, TIIN,RSE, U.M. SEC. I~ TIIN, RSE, U.M. Z - Y = 5,970,38~.~3 LAT. 70~9'49.~287'' ~0 - Y : 5,970,~32.65 LAT. 70°~9'46.67~9" X = 498,944.93 LONG.~50"00'30.807'' X = ~98,945.21 LONG.;50000'30.796" ~2' FSL, 556' ~L 0G = 77' PAD = 8~.5 ~52'FSL, 556' F~L 0G ' 76.0 P~D : 8~.7 3 - ~ = 5,970,357.42 ~T. 70~9'48.88~8" ~ : ~ : 5,910,107.7~ ~T. 70"]9'46.4267" X = 498,944.9~ LONG. ~50°00"30.808'' Z : 498,9~5. ~0 LONG. ~50~00' 30.80~" 377' FSL, 556' ~L 0G = 77' PAD : 8~.5 ~27' FSL, 556' F~L 0G ' 75.~ PAD = 8~.7 4 - Y : 5,970,332.46 LAT. 70~9'~.6372'' ~2 - Y : 5,970,082.58 LAT. 70~9'~6.~794" ~ , z = 4~8,9~4.84 LONG.~50=00'30.809" ~ X = 498,9~.98 LONG.~50~00 30.804" 352" FSL 556' ~L 0G = 77' PAD = 8~ 6 'c~ ~02' FSL 556' F~L ~ : 75.7 P~D - 8~.7 5 - Y = 5,970,307.52 LAT. 70°19'48.3919'' '~ 13 - Y : 5,970,057.59 LAT. 70°19'45.9336' I X = 498,944.91 LONG. 150000, 30.808" ~ ~ X : 498,945.08 LONG. 150°00' 30.801" '. 327' FSL, 556' FWL OG = 77' PAD = 81.6 CO ~ 77' FSL, 556' FWL OG ~ 75.5 PAD : 81.6 6- Y = 5,970,282.50 LAT. 70~19'~.1459" ~ ~ ~4 - Y = 5 970,032.60 LAT. 70°19'45 ~79' m. X = 498,944.95 LONG. 150000,30.806. ~ CO (4 o ' . ' ~ ~ ~ X = 498,944.91 LONG.150°O0 30.806" 302' FSL, 556' FWL OG = 77' PAD = 81.7 , _ ~ ~ ~ 52' FSL, 556' FWL OG : 75.3 PAD : 81.7 , c3 ~ 15 -'Y = 5,970,007.69 ~T. 70019'45.4428"m 7 - Y : 5,970,257.54 LAT. 70°19 47.9003" ~ 0 ~ 498,944.93 LONG.150°O0'30 806" X : 498,944.95 LONG. 150°00' 30.806" ~ ~ X 277' FSL, 556' FWL OG = 77' PAD : 81.6 ~ 27' FSL, 556' FWL OG = 75.2 PAD = 81.6 8 - Y 5,970,232.63 ~T. 70°19 47.6553" ~ ~ = ' .~ 16 - Y : 5,969,982.85 LAT. 70°19'45'1985" X : 498,944.96 LONG. 150°00' 30.806'' ~ X = 498,944.88 LONG. 150°00' 30.807" 252' FSL, 556' FWL 0G = 76.9 PAD = 81.6 ~ 2' FSL, 556' FWL 0G = 75.1 PAD = 81.7 9- Y : 5,970.207.62 LAT. 70~19'47.4093" c~J LOCATED IN PROTRACTED X = 498,945.01 LONG. 150°O0'30.804'' ~ SEC.12, TI I N, R8E, U.M. ~m 227' FSL, 556' FWL OG = 76.3 PAD = 81.6 17 - Y = 5,969,957.72 LAT. 70°19'44.9514" X = 498,944.94 LONG. 150°00'30.805" ~3' FNL, 556' FWL OG : 75.~..~D j ~1.6 ~.HORIZ; POSITION$ BASED ON TEM~ MON~ 2T-EAST, 2T-WE & ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ NI9+75, E.II+ 52 PER ER.B. ~ ASSOC. 5.O.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-~I40 rev.~, CERTIFICATE OF SURVEYOR: i HEREBY' CERTIFY THAT I AM PROPERLY rEglSTE~ ED ~ND LICENSED TO ~R~CTiCE LAND ~ ~ SURVEYING IN THE STATE Of ~LASK~ ~D THaT ~.~ ur · ~,s ~ ~~ ~ ~o~,o~ ~v~ ~ MADE BY ME OR UNDER MY SUPERVISION, AND ~_~[ .. ~ t~.~ ~ im THAT AgL DIMENS IONS AND OTHER DETAILS ~ ~ ..' ~ e~ ~ I i I ~' ~ . ~ ARCO Ai~skG, inc ~ /~.~ ~~~ ~ SURVEYED FOR. ~ .......... , .... ~-~ · .. . 1~ v' 'PARUK PROJECT ~,~WN W~ DRILL SITE 2T CONDUCTOR ~.~ ~. No 6~ ~~. ~c~s. .5~, AS-BUILT LOCATIONS 4. . ~,~ ~ F..... 'lC'~-~'''-~'~-~ ...................... )low~. ,o. ~s~ ,~-~ ~tZ.~s~o,~ 5~5 Arctic Bou/evard, Suite 20 1. Anchorage. Alaska 39503 })S~LE N.T.S. JJaOm CHECK LIST FOR NF.W WELL P ITEM APPROVE ~DATE / (2 thru 8) (3) A min 4"t (9 thru 13) 10. '(10 and 1~3) ~ 12. 13. (14 thru 22) (5) BOPE 14, 15. 16. 17. ..,.- ~ 18. 22. (23 t ~ ~23. ...,..... --..-4 2s. r""r"'~ 26. (29 thru 31) Geology: En§iBeering: .' LCS 7.-~'J"~;' B-EW'--'-'~ - WVA JAL ~ev: 04/03/86 6.011 ERMITS Company o Lease & Well No. YES NO REMARKS 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............. 3. Is well located proper distance from propert;'~in; . 11. 11.1111..111~-a.-~ 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 ten-day wait .......................... 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 fresh water zones ....................... 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 !!!i i!!i},i Is adequate wellbore separation proposed ' ............... Is a diverter system required ...................... , .... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~_~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements "INITIAL GEO. " UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. L .T. S T ,'-", ? 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Z ~ ,2' :', ~ ); 2 - % 5, ~ . ?: r_, 0 "5 -9~9. 2530 - ~ ,.:, .-5. ~ < !1" - ?; ? · 2. 5' 0 0 -P ~ 9 . '" 5 9 C, - ...) q .':, -999.£503 5!.074£ -99 _-t,. 2.5 3 O -:299. 2530 - ~99.2 ~ :] 0 -099.2503 -999.2530 ~6.~263 LVP 010,[402 VERXFXCATXON bXSTXNG PAGE R GI~ · *~ ~APE HEADER SERVZCE NAMg IEDXT DATE 186/09t27 ORIGIN ;0000 CONTINUATION ! P'REVXOU$ T&PE I COMMENTS ILXBRAR¥ TAPE ********** EOF ** FX.LE HEADBR rlbg NAME IE'DIT : ,001 1024 ** INFORMATION RECOR'D~ ** MNE# CONTENTS CN NN RANG:,:! TOW, N~ 065, OO4 t.s~o~ §§§ §gi°° °°§lo~2 ~ MNEM CONTENTS ooo 0o0 .ool ** *************************************************************************************** t, VP O~O.H02 VE:R:I:FICATJ~ON I~I$'rlt~C; P~GE 2 * CO~AN¥ · ARCO WELL_ z 2T-8 ¢ '.TY · .ORT" SLOPE BOROUO, lONE. 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